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Home My WebLink About168-080 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate el Other El Gravel Pack Performed: Alter Casing ❑ Pull Tubing El Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development In Exploratory ❑ 168 -080 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20146 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 Trading Bay Unit / G -14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,,,, McArthur River Field / Middle Kenai Gas, Hemlock Oil Pools 11. Present Well Condition Summary: Total Depth measured 16,342 feet Plugs measured N/A feet true vertical 10,593 feet Junk measured 5,269' (fill) feet Effective Depth measured 5,269 feet Packer measured See Schematic feet true vertical 3,816 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 650' 17 -3/4" 650' 649' Surface 6,495' 13 -3/8" 6,495' 4,477' 3,090 psi 1,540 psi Intermediate Production 13,521' 9 -5/8" 13,521' 8,721' 5,750 psi 3,090 psi Liner ,AR � RECEIVED Perforation depth Measured depth See Schematic feet SCANNED JAN 15 2013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 3,536' (MD) 2,878' ( D) Packers and SSSV (type, measured and true vertical depth) (3) Packers (See Schematic) SSSV 302' (MD) / 302' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Isolation squeezes 2,000' - 2,003' above zones of interest. Bottom 3,594' - 3,597' below zones of interest. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 68 150 Subsequent to operation: 0 1970 5 168 258 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El — Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas CI ,, WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPO SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -254 Contact Ted Kramer Email tkramer Printed Name Ted Kramer Title Sr. Operations Engineer Signature —_ Phone 907 777 -8420 Date 1/15/2013 RBDMS JAN 2 8 2013 „sr %1? �" 2- -23 - 13 Form 10 -404 Revised 10/2012 .F.%p /,3 Submit Original Only H . • Grayling Platform SCHEMATIC Well #G -14 Hilkorp Alaska. LI Completed 12/13/2013 RKB = 38.11'Rig Floor to TBG Head C ASING DETAI Size Type Wt Grade Thrd ID Top Btm 1 17 3/4" Surf Csg Spiral 110 /N BTC 15.12 Surf 650' 13 3/8" Csg 61 J 12.52 Surf 6,495' 9 -5/8" Prod Csg 40, 43.5, P BTC Surf 13,521' Top Sqz 47 80 2,000' TUBING DETAIL 2 41/2" 9.2 12.6 L -80 IBT 3.958 Surf 3,536' ' °-- ►4 JEWELRY DETAIL 6,7" 5�, __ 1 NO. Depth ID Item IP 11 1110 = - 7 "` = ' : A 1 302' 3.813 4-1/2" IBT SCSSV 'lo &11 ► �. ?n. 12,13 14 &15 IF ivy 2 1,710' 3.958 4 -1/2" Gasl Lift Mandrel - ie = ; ? , A -4 3 2,876' 3.958 4 -1/2" Gasl Lift Mandrel 1 - Btm Sqz roc@ "'� * 4 *' 'k J , ..° 3597' 4 2,934' 3.813 4 -1/2" IBT "X" Profile Landing Nipple 3,590' ,,."fir" IN Bridge Plu ♦ ,_, . ii _......., ii _......., B Plug LS 5 2,982' 4 9 -5/8" 43 -53.5# AS -1X Retrievable Packer ss 3 1 1 , 629' 6 2,991' 4.125 4 -3/4" Production Overshot 7 3,000' 4.125 X/O 4 -1/2" LTC Box to 5 -1/2" LTC Pin 8 3,065' to 3,162' 4.93 (3) 5 -1/2" L -80 / .008Ga 304 SS GP Screen 4-- 1Athru1H In 9 3,163' 6 9 -5/8" 36 -53.5# Model D Sump Packer B -1 pert e■ 10 3,165' 4 X/O 4 -1/2" Buttress x 4 -1/2" IBT Pin B -2 pert B-3 pert 11 3,187' 3.813 4 -1/2" IBT "X" Profile Landing Nipple w/ "X" Plug B4 pert 2 3 12 3,394' 4 X/O 4-1/2" IBT Box to 5-1/2" EUE Pin 1 owl I 4 BakerSeal asst' 4921'4930 13 3,395' 4.875 4 -3/4' , Production Overshot w/ 4 -1/2" EUE Box 5 14 3,397' 3.938 4 -3/4" Hook Up Nipple w/ 4 -1/2" EUE Pin 7 I ULAN .. I 8 BakerSeal assy 15 3,404' 4.125 X/O 4 -3/4" LTC Box to 4 -1/2" LTC Pin 4946'4966' y 9 16 3,469' to 3,533' 4.93 (2) 5 -1/2" L -80 / .008Ga 304 SS GP Screen I 17 4,950' 9-5/8" 36-53.5# Model D Sump Packer 18 3,620' to 3,628' 2.65" 9 -5/8" 47# x 3 -1/2" AS -1X Packer w/ T -2 Nipple w/ 10 PX Plug in X- Nipple. Plug has prong that stick up above nipple 0 7. 11 B-6 pert Top of fill @6269' PERFORATION DATA C-1 Pert 1,, .e'' . ¢:. Perf C -2 pert 1 �t E , * +' r ;fi ^" iv Zone Top /(MD) Btm /(MD) Top /(TVD) Btm /(TVD) Date Status Feet - , . V A -1 3,105' 3,152' 2,650' 2,675' Future Open 47' A -4 3,494' 3,524' 2,856' 2,872' Future Open 30' .� = vi '0d Casing • TD- 16,342' MDIPBTD5,614' MD Revised By: TDF 1/10/2013 1 • Grayling Platform Y g SCHEMATIC Well # G -14 HiIcorp Alaska, LI Completed 12/13/2013 THIS PAGE CONTAINS DATA FOR THE ISOLATED PORTION OF THE WELL ISOLATED LONG STRING ISOLATED SHORT STRING NO. Depth ID Item NO. Depth Item 1 3,746' Brown H -2 Hyd. Packer la 3,816' 3" 4 -1/4" OD Baker Blast Joint A 3,746' Brown H -2 lb 4,068' 3" 4 -1/4" OD Baker Blast Joint Hyd. Packer lc 4,135' 3" 4 -1/4" OD Baker Blast Joint B 3,785, 3 -1/2" Otis Q ld 4,286' 3" 4 -1/4" OD Baker Blast Joint nipple le 4,336' 3" 4 -1/4" OD Baker Blast Joint if 4,435' 3" 4 -1/4" OD Baker Blast Joint lg 4,708' 3" 4 -1/4" OD Baker Blast Joint NO. Depth Item lh 4,809 3" 4 -1/4" OD Baker Blast Joint IV 5,600' Junk retainers 2 4,881 3 -1/2" Otis XA Sleeve V 5,614' EZSV retainer 3 4,920' 3 -1/2" Baker locator sub VI 6,737' EZSV retainer 4 4,921'- 4,930' 3 -1/2" Baker Seal Assy 5 4,922 ' Packer 6 4,935' 3 -1/2" Otis XA Sleeve 7 4,944' 3 -1/2" Baker locator sub 8 4,946'- 4,956' 3 -1/2" Baker Seal Assy 9 4,950' Packer 10 4,988' 2.65" 3 -1/2" Otis Q nipple 11 4,989' 3 -1/2" Baker mule shoe ISOLATED PERFORATION DATA Zone Top /(MD) Btm /(MD) Top /(TVD) Btm /(TVD) Perf Date Status Notes B -1 3,838' 3,844' 3,039' 3,042' 7/3/1974 Isolated B -1 4,076' 4,080' 3,165' 3,168' 7/7/1974 Isolated B -1 4,135' 4,138' 3,197' 3,199' 7/7/1974 Isolated B -2 4,295' 4,305' 3,283' 3,288' 7/7/1974 Isolated B -2 4,340' 4,350' 3,307' 3,312' 7/7/1974 Isolated B -2 4,444' 4,454' 3,363' 3,369' 7/7/1974 Isolated B -3 4,715' 4,725' 3,510' 3,516' 7/7/1974 Isolated B -4 4,820' 4,830' 3,568' 3,573' 7/7/1974 Isolated B -8 5,077' 5,095' 3,710' 3,720' 12/5/2011 Isolated B -8 5,099' 5,119' 3,722' 3,777' 12/5/2011 Isolated C -1 5,254' 5,274' 3,808' 3,819' 7/7/1974 Isolated covered with fill C -2 5,500' 5,510' 3,943' 3,948' 7/7/1974 Isolated Covered with fill Revised By: TDF 1/10/2013 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 11/01/ ei 5.y R/U slickline to pull SCSSSV from both short and long string. PT lubricator to 2,000 psi. Unable to recover safety valve from short string. RIH with impression block, clean indication of top of locking mandrel. Skid rig to G -14 for workover operations. Rig spotted up. Continue to winterize the rig. 2 - Friday 1 � 3x Slickline crew completed work on long string, recovered the SCSSSV, made 2.70" gauge ring run to 4,933'. Rig down slickline. Dual 3.5" BOP arrived and offloaded with dual handling tools, checked inventory. Rig up derrick, scope to full height, install and tighten guide lines, check all connections and prepare to bull head into the casing. 11/03/12 - Saturday PT lubricator to 2,000 psi. RIH Slickline with fishing string to pull safety valve. Slickline jarred free. Rig up to fish tool string. Ran impression block to top of fish, no wire, clean rope socket. Rig up additional lubricator, and fishing string, RIH, latch and retrieve tools. JDC pulling tool sheared, remove fishing tool string, rig back to original tool string, redress JDC with steel pin and begin jarring on stuck safety valve at 800 Ibs using accelerators and oil jars. Slickline back in hole working to pull SCSSSV, continue jarring with no success. Waiting on unit with hammer to jar on stuck safety valve. 11/04/12 - Sunday Slickline pick up braided cable and heavy weight bars, oil jars, spang jars and JDC pulling tool. PT lubricator to 2,000 psi. RIH to pull Safety valve at 234' WLM, jarring on safety valve in attempt to free from nipple profile. POOH with sheared JDC and check tool string. Wireline crew continue to jar on safety valve, pull safety valve free and lay down heavy tools. Pick up 2.52' OD gauge ring and RIH to Q nipple at 3,785'. Tubing clear enough for permanent bridge plug. POOH. Rig down slickline. Rig up pump and placed 40 bbls down the short string side. Rig up pump to the long string and placed 60 bbls down the tubing. Set pump thru plug in the hanger. Move to the short string, pump 50 bbls to short string, well stable for 10 minutes and gas back at surface, pump 100 bbls to control pressure in short string, monitor pressure for gas at surface. Pump total of 200 bbls so far, well on vacuum for 10 minutes, and gas back at surface, reload rig tank to pump total of 435 bbls and attempt to bring well to stable point. Fluid pump, well on vacuum, monitor for gas pressure at surface. 11/05/11* e '` Pumping fluid in short string side to push gas back to formation, lower zone taking fluid upper zone putting gas back to surface. Rig crew working on BOPE testing unit. R/U E -line. PT lubricator to 2,000 psi. Pick up tool string, run in hole with CIBP, unable to work past sliding sleeve. POOH. Change tool string and RIH with broach tool to clean out scale in sleeve, pump 10 barrels of filter water to clean thru sleeve and joint above the packer. Change configuration of tool string and RIH to make clean out run past sleeve. Landing on top of sleeve with no success getting through. POOH. Rig up pump to short string, pump slowly down tubing while working tools unable to get thru sliding sleeve, pull up hole, increase pump pressure in attempt to flush possible fill. Pick up 1- 7/16" Od gauge and attempt to work past obstruction. Remove everything with the exception of CCL and upper tool string in attempt to confirm depths of obstructions. Work down to what we determine is the Sliding Sleeve, log up hole. Log does not show sleeve, joint above where sleeve should be shows noise which indicates tight or restricted ID's from possible scale or other debris on the ID of the tubing. Rig up slickline tools on the a -line unit and will make full scratcher run to determine if scale, tool parts or other foreign debris is blocking the setting of the CIBP. Rig crews have everything ready to install BOP's, rig floor, winter package and begin testing BOP's if successful with plugging the short and long string. 11/06/12 - Tuesday Discuss operations with a -line, preparation for BOPE test if able to complete plug setting. 1. . ; /12 - Wednesday Rig crew completed nipple up of workover BOP's connect accumulator and function the rams. Nipple up Dual Ram BOP, lower tubing board secure guy wires, hang floor, Shut off rig and disconnect battery to eliminate ECM damage for windwall welding. • i Hilcorp Alaska, LLC Hileorp AIa%ka, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 Daily j.; 'AY fir # 11/08/12 - Thursday Retrieve BPV's for Both strings and Install 2 way checks. Perform BOP full function test and pressure test all BOPE prior to state pp witnessed test in AM. BOP test good. 11/09/12 - Friday Prepare for BOPE test. Wait on AOGCC arrival for witness. Initial BOP test conducted 200 psi low on all BOPE and 2,500 psi high test on Annular, 3,000 psi high test on all BOP'S flange valves, chokes and lines. Flange leak above Annular BOP on spacer spool. Will be corrected tomorrow. Light on remote panel not a fail but needs service. Manifold and Annular pressure adjustments need service. Most repairs will be completed before evening on 11/11. Reconfigure of circulation equipment not accepted by AOGCC, will be returned to positions accepted last BOP test. Winterizing accepted after under floor modifications to secure tarps against wind. Pull Check valves and install BPV's. 1 string accomplished. On recovery of opposite string, retrieving tool lost in top of check valve. Fishing tools ordered for 11/11. will recover tools on top of hanger and resume BPV operation immediately after arrival. 11/10/12 - Saturday Fish running tool. Working on rig winterization. N/D Dual BOP and change ring gasket. N/U Dual BOPE, test Dual BOP's to 200 psi low / 3,000 psi high. BOPE test witnessed by Lou Grimaldi, AOGCC. 11/11/12 - Sunday R/U winterized tank and pump lines. Prepare E -line for pipe recovery ops. Prepare to scope derrick, work pins on well head, verify annulus and all tubing dead. Pull 2 way check from short string. Scope up, install landing joint in SS. Rig up eline. RIH with 2.75 cutter, can't get below SSSV. POOH. RIH with 2.65 cutter pull to 50K =15K over SW cut at W/L 3,659' after tagging plug @ 3,661'. Positive string movement and loss of over pull weight. POOH with W/L rig down same. P/U ring tongs and POOH w 5 jts spooling control line hand up on bottom LS hanger with strap and control line. Continue POOH break out and lay down SSV. Continue POOH with total 116 its 1 SSV and RU E -line. Pull BPV. Install landing joint unlock hanger pins. Go radio silent, RIH with 2.65" cutter. 11/12/12 - Monday RIH with E -line and cut SLS @ 3,629'. POOH and R/D Eline. POOH. Lay down hanger, 8 jts and reel up control line. Lay down SSV. POOH with LS lay down 2 pup joints 116 joints and 1 cutoff. N/D BOPs. Scope down and layover derrick. Change rams in BOP's to 2 -7/8 ". Scope out derrick. Rig up all Schlumberger equipment. Secure BOP winterize. Install test plug. Test BOP's to 250 low. Unable to perform high test due to pump liner and frozen pump issue. Will perform high test after clean out run. M/U BHA 9 -5/8" scraper and x- overs. BHA consisting of 8 -3/8' mill, casing scraper and 2 x -overs total length 16.27'. M/U RIH with work string 2 -7/8" OD DP 10.40# S -135 with 2 -7/8" IF connections. 11/13/12 - Tuesday Cold weather operational safety meeting all crews. 11/14/12 - Wednesday P/U test plug. Retrieve wear bushing. Run test plug, fill riser test 2 -7/8" rams to 250 psi low / 3,000 psi high and chart. Retrieve Plug. Run wear bushing. Retrieve plug and M/U BHA reassemble casing scraper. P/U Rabbit and strap 2 -7/8" Id 10.40# S -15 drill pipe. RIH with 115 joints and tag fish @ 3,634' MD 2' in on joint 115. Reverse circulate hole clean. Drain all lines and prepare to RIH. POOH. Breakout, clean out BHA and lay down same. P/U Tri -Point Sirset IX packer with PX plug in place in nipple, on /off tool and M/U same to DP. RIH and tag up on fish top 3,634'. P/U and space out set packer @ 3,620', lay down 3 jts. R/U pump line and test chart. Test Annulus down tubing and record to 1,000 psi. • Hilcorp Alaska, LLC . Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 ) ierations: 11/15/12 - Thursday Dump 9 sacks 30/50 sand down tubing and chase w 3 BBL FIW. POOH lay down 7 singles and rack back. Break out and lay down BHA. Spot and rig up E -line. Make 2 ea. dump bailer runs, spot 7' of cement on top of sand tag at 3,612'. Third run was bypassed as squeeze shoot dept. is 3,600' and additional cement will be on depth after squeeze. Rig maintenance. Fill hole from water flood operations. R/U E -line and lubricator. RIH 3 -3/8" 3' casing gun loaded 4 spf. make 2 runs shoot squeeze perfs 3,594'- 3,597' and 2,000'- 2,003'. POOH rig down wire line. P/U / M/U test packer. RIH with 33 stands depth of packer is 2,102' set in slips, stab TIW valve. Annulus remains open to monitor well. 11/16/12 - Friday Set packer, attempt to circulate, pump 5 bbls no returns to annulus pumping in lower perf < 1 bpm at 600 psi and climbing . Abort circulate test. Switch over to pump down annulus to upper perfs 2,000'- 2,003'. Immediate pressure build to 1,000 psi hold for 5 min and bleed off. Release packer. RIH 21 stands in derrick and POOH lay down 46 joints leaving packer @ 1,975'. Set packer @ 1,975', pump 5 bbl balanced plug cover perf interval 2,000'- 2,003' release packer lay down 4 joints. Reverse out minimal cement in returns pressure up on annulus 250K shut in against well. Rig down wash down. 11/17/12 - Saturday Build 120 bbls 9.5 heavy brine and KCL. Wind 40 plus MPH, cannot scope down derrick. Off load boat with heater and most gravel pack equipment. Continue working on circulate system. Continue mixing KCL. 11/18/12 - Sunday Open rams. No problem with well control equipment. Cycle BOPs. Pull 19 stands, lose air and Hydraulics. Trouble shoot and repair. Pull all air lines remove ice and trash, change compressor trace and tighten all air lines front to back. Install new air dryer injection pot. POOH with last 11 stands and lay down squeeze packer BHA. P/U and M/U 18.5" MT Bit, 9 -5/8" Scraper, x -over, 2 DC's and RIH to top of cement. Tag cement @ 1,975'. 11/19/12 - Monday R/U power swivel and reverse circulate over shaker. Wash ream and drill cement and stringers from +/- 1,975' - 2,100' chasing plug. Set back power swivel. RIH to PBTD and roll circulate system hole and pit volume to achieve 9.5# 6% KCL throughout. Continue circulate and scope down. Lay down derrick for deck. Continue circulate, raise and scope derrick and tighten guy wires. 11/20/12 - Tuesday Test Choke manifold to 250 -500 psi low 3,000 psi high. All valves good. Continue circulation and rig maintenance. Wait on authorization from AOGCC for 9.2# perforating operations. POOH and lay down squeeze packer verify tally count and depth. Verbal approval via Anchorage office from AOGCC for 9.2 # ops. Contingencies or kill identified as 6 pallets salt on board for .3 ppg increase on 400bbls. 10 pallets sand on dock ready to ship response time will be 4 hours estimated if tide in favor. P/U test plug and retrieve wear bushing, invert plug and start BOP test. initial problems with test plug low2 test only to 200 psi and fail x 2 Pull test plug repair gouge and replace o -ring . test Annular to 250 low and 2,500 psi high. Test pipe rams blind rams and Kill and choke side valves and floor valves to 250 psi low and 3,000 psi high. Witness of test waived by AOGCC. Perform accumulator function test. Pull test plug and drain all inactive choke lines. Rig up Eline. RIH and run GR Junk basket tag up @ 3,600'. Run correlation log and tie into company provided PDF good signature straight forward correlation. POOH. RIH with dump bailer and dump cement on top of original plug at 3,600' + / -. POOH. M/U P/U Model D Sump packer and RIH. Correlate tie in and witness packer set depth with CCL at 3,521'. Set packer closest casing collar at 3,533' packer set depth @ 3,534'. POOH. Rig Down Eline and move eline unit off of catwalk. Spot SLB. P/U M/U TCP Guns and firing head. • • • Hilcorp Alaska, LLC Hilcorp Alaska, LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 qq 11/21/12 4Wednesday ... , ; f RIH and tag packer @ 3,534' pick up 7' to space out guns and set in slips. Lay down single. Install TIW and drop ball. Install kelly and pressure test. With rig pump, pressure up on tubing to 2400 psi. Ball seat sheared, pressure dropped immediately and positive gun movement at floor. Reverse out 2 x tubing volume. Stop circualtion. Well static. Release safety chains and pull 4 stands. Monitor well. POOH racking back WS. Rack back collars for next perf. POOH laying down guns. All shots fired. P/U Mule shoe Centralizer, pup joint, and RIH w pipe from Derrick. Wash down to and through top of sump packer no problems. POOH with DP, rack back in derrick and lay down mule shoe assembly. P/U 2 jt .008 screen, 2 jts centralized blank pipe, hook up nipple, with inner string folly in 2 jts 2 -7/8" CS and 2 pup joints 8' and 10'. P/U x -over and 32 -A packer assembly and x -over. Total length 163.11' with 1.3' latch in assemply. RIH with pipe from derrick 107 joints will be total run. Rig up all lines Injector and SLB pump. Set packer @ 3,378 and test same to 500 psi. Successful test. Start sand @10:10 Pumping at 2 BPM. Pump sand down @ 325 psi + / -. See beginning of screen out 700 -1000 psi. Enough sand out of crossover tool to cover screens, reduce rate to 1 BPM stack sand on 20' blank. Sand pumped is 30/50. Coverage is 1,200# around screens, 500# around blank, 3,003# around perf equal to 10 PPF. Stress GP 5 times 1,200 psi. Release packer /washpipe BHA and POOH. Lay down GP BHA. P/U M/U 8.25" x 4 -1/2" LTC Production OS 5.71' 4.5" IBT x 4.5" EUE x -over 1.3', 5 jts 4.5" 12.6# IBT 204.56', 4.5" IBT X nipple (3.813 profile) 1.7', 2e 4.5" IBT pup joints 21.82', 4.5" Buttress x IBT x -over .69', 4.5" IBT Tubing adapter bottom sub .50', 9 -5/8" x 6" Model D Sump Packer 1.84' (total left BHA will be 253.5'). P/U M/U Shear adapter sub, 2 -3/8 J hydraulic setting tool, 2 -7/8" PH -6 x 2 -3/8" EUE x -over , 2 -7/8" PH- P110 handling pup joint , 2 -7/8" IF x 2 -7/8" PH -6 x -over. RIH with BHA and pipe from Derrick. Overshot went over fish smoothly. P/U and check set down 1 foot high at 3,396' Top packer depth. Overshot has 4 foot extension with seals at guide. Rig up to SLB and test lines to 3,000 psi. Bleed off, pressure up and set Model D sump packer @ 3,162' w/ 3,000 psi. POOH and lay down paker setting BHA. P/U make up Packer Plug 4.55' stick up and M/U to SLB gun assembly OAL 63.65. RIH with 46 stands and tag up in sump packer. Space out guns, drop ball, secure pipe and elevators, close TIW valve and pressure test lines to 2,500 psi. 11/231 2 - Fridayx Open TIW pressure up to 2,400 psi. Gun fire response good. Check Annulus pressure on vacuum. Stabilize well and fill hole with 5 bbls. Well taking 3.5 BPH 9.2# bribne with 6% KCL. POOH. Lay down DC's and guns and rig down SLB TCP. RIH with open ended Tri point overshot. POOH. Close annular, rig up kelly hose and TIW.Pit Volume is 45 bbls, Building Pit Volume to achieve 9.2 ppg 6 % KCL in 35 bbl increments. Utilizing 22 ppb KCL and 62 ppb NaCI . Monitor well. Total fluid pumped in well bore - 65 bbls. Build fluid brine pit volume to 148 bbls. 11.4l12 - Saturda Open tubing and prepare to fill annulus w/ 10 bbls tubing flowing. Shut in line to pump down tubing. Pump tubing volume 20 bbls. Circulation established 10 bbls into pumping tubing volume. Continue circulation. Shut down pumps. Monitor well. Remove Kelly hose and TIW valve. POOH with work string. Make up 8.125" overshot w/o grapple. RIH with pipe from derrick. Rig up SLB cementers ( for pumping only). RIH picking up 4 singles. Pressure test surface equipment to 2,500 psi. Reverse circulate 4 times tubing volume over top of packer plug to remove perforating debris. Total fluid lost 20 BBLs circ stopped and injecting into formation. POOH. String not pulling, wet plug rattled out. Definite scars in overshot indicating plug and snap latch were inside. M/U 8.125" OS with grapple and RIH with pipe from derrick. Work and latch fish snap out snap in to verify. POOH. Plug retrieved. Move organize and M/U GP assembly consisting of 6" snap latch assembly, 3 ea. 30' .008 Ga screens, 2 ea. 30' blank pipe, 1 xo, and 4 -3/4" hook up nipple. OAL 198.94'. Deploy washpipe and packer. RIH w/ pipe from derrick. Space out and land GP. R/U SLB and TriPoint pumping gear and prime SLB. Load sand pots. Pressure test surface equipment to 3,000 psi. 167 bbls total pit volume available. 152 in active and 15 in mix. Set GP tension packer. Test annulus to 500 psi. Get circ rate 1BPM 150 psi 2 BPM 300 psi injection rate 1BPM @ 300 psi 2 BPM at 500 psi. Proceed with GP with 30/50 sand max pumping sand at 2 BPM down DP through GP and around and up through screen up washpipe and up annulus. Pressure seen was 700 psi spike average pumping pressure 200 -300 psi 5,600 sand pumped on formation screen 1 BPM @ 600 (spike 700) with annulus returns choked back 1/2. Open annulus to full returns 1 BPM @ 150 psi. No sand out. Estimate 66# sand per foot in perforations. Shut down pump to let sand settle and dehydrate. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 :7/25/1 N° _n Pump 800# sand 1 bpm@ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 800# sand 1 bpm@ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 1/2 tubing volume to catch /circ 6 -9 bbls. Well is taking fluid at twice rate estabished after perforating which was 3.5 BPH. Pump 800# sand 1 bpm @ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 1/2 tubing volume to catch /circ 6 -9 bbls. Well is taking fluid at twice rate estabished after perforating which was 3.5 BPH. Pump 800# sand 1 bpm@ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 1/2 tubing volume to catch /circ 6 -9 bbls. Well is taking fluid at twice rate established after perforating which was 3.5 BPH. Pump 1200 # sand 1 bpm@ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 1/2 tubing volume to catch /circ 6 -9 bbls. Well is taking fluid at twice rate estabished after perforating which was 3.5 BPH. Pump 1200# sand 1 bpm@ 150 psi. No sand out. Shut down pump to let sand settle and dehydrate. Pump 1 2 tubing volume to catch /circ 6 -9 bbls. @ Y p / g p P p P Well is taking fluid at twice rate estabished after perforating which was 3.5 BPH. Pump down DP @ 1 bpm @ 150 psi. No sand out. Total sand pumped 10,200 #. Release packer sting out WP and lay down 11 joints DP. Circulate well to even out fluid density @ 2 BPM with rig pump. Total losses 1 hour 10 BBL. POOH laying down workstring. Rig down rig tongs RU Weatherford tongs lay down remaining 7 jts of WS and packer BHA. Swap out rig floor equipment to 4.5" handling tools. M/U P/U BHA production 0/S 8.25 OD. Retrievable packer AS1 -X, On Off Tool, x -over 4.5 EUE x IBT. Continue RIH with production. P/U M/U and RIH with 6' 4 -1/2" IBT joint, Flow coupling , x- nipple, flow coupling , 1 jt 4 -1/2 IBT tubing, 1 gas lift mandrel. RIH with production tubing. Latch on Set packer and attempt to pressure test annulus. Full circulation accomplished immediately after 8 bbls. Unable to pressure up. Order PX plug and prong from Pollard. RIH and set Prong in plug. Pressure test injectivity leak gone, able to go 1,000 psi bleeds back slow. Fill hole w 8 bbls, RIH pull prong and both gas lift dummies. Both dummies have very worn seals. Prepare to re run prong for shell test. Will fill tubing from annulus, evacuate air from circ path. Wait on slickline to redress running tool. /12„ Tuesday oa RIH with prong, circulate well through empty GLMs to fill tubing from reverse. Fill 9 bbls. Pressure up on Annulus with TIW closed, pressure up on casing to 1,000 psi. Slow bleed back to 500 then to 300 psi. Repeat and shut in against manifold (isolate pump) 3 more times with bleed off from 1,000 -500 psi slowing each subsequent test and always bleeding to 300 psi and holding. These pressures do not match circulate rate injection rate or squeeze test pressure. Squeeze perfs. and packer can be eliminated leaving only the PX plug as a candidate for the leak. Discussed with production and Senior engineer. Called test good. RIH and retrieve Prong and Plug. Install Gas lift valves (orifice /pressure unknown at this time). Rig down slick line, rig up Weatherford and floor for pulling 5 joints to SSV. Rotate off and release from on -off tool. POOH with 5 Joints and pups to SSSV. Pull Dummy. Install control line and pressure test spool. Install dummy and BPV in hanger and RIH with 5 jts and Hanger and land production. Nipple Down riser, pull BOPs and Riser. Scope down and lay down derrick. Pull riser and BOPS, set tree. Approx. 80 bbls heavy brine and KCL and wash -down to production for transfer to TB. i a a 12 - Saturday - ... ;, ;.,. ._. R/U Pollard wire line. Pressure test lubricator to 2,500 psi. RIH latch and POOH with SSSV. RIH with LIB to 2,975' wlm and sat down. POOH and found nimpression of top of on/ off tool. RIH with 3" JDC pulling tool to 3,180' wlm, unable to latch prong. POOH. RIH with 2" x 5' Ig DD bailer to 3,180' & worked same. POOH and found gun debris in bailer. R/D wireline. .4". 2 s: R/U wire line. Pressure test luricator to 2,500 psi. RIH with bailer and bail gun debris from 3,178' wlm to 3,181' wlm. Hilcorp Alaska, LLC Hilcorp Alaska, LLG Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -14 50- 733 - 20146 -00 168 -080 11/1/2012 12/13/2012 Daily Operations: 12/10/12 - Monday Continue bailing gun debris from tubing from 3,179' wlm to 3,180' wlm. RIH with 3" JDC to 3,180' unable to latch prong. POOH. Pulling tool not sheared, RD wire line and stand by for rig to POOH. 12/11/12 - Tuesday R/U wireline and test lubricator to 2500 psi. Made three trips with 2.5" X 5' bailer to 3,180' wlm and retrieved 3 -1/4 cups of debris. RIH with 3.50" centralized magnet to 3,181' wlm and retrieved 2 pieces of debris. RIH with JDC pull tool to 3,181' and was unable to latch prong. POOH. RIH with 3.50" LIB to 3,181' and had indication of top of prong. RIH with 3" JDC pull tool to 3,181' and was unable to latch prong. POOH. Made three trips with 2.5" X 5' bailer to 3,180' wlm and retrieved 3/4 cups of debris. RIH with 3" JDC pull tool to 3,181' latch prong. POOH. RIH with 2.5" X 5' bailer to 3,182' wlm and POOH with full bailer. Stand by for rig to move hydril. RIH with 2.5" X 5' bailer to 3,182' wlm and POOH with bailer full of fluid no debris. Stand by for rig to test hydril and RIH with milling assy. /12/1 R/U wireline, test lubricator to 2,500 psi. RIH to 3,182' with 4 -1/2" GS latch and pull plug to surface. RIH with SSSV and attempt to set without success. POOH. 12/13/12 - Thursday R/U wireline, test lubricator to 2,500 psi. RIH to 3,182' with 4" GS latch and POOH with SSSV. RIH with 4" X -line with 1 -1/2" x 5" prong to 300'. Set SSSV. POOH. Rig down wireline. . 0 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 10, 2012 8:54 AM To: 'Ted Kramer; Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: RE: Extend work 10-404 on M-16RD and G-14 Ted, A bit of a grey area as far as reporting ... It would be my preference to wait until your slickline work is completed before submitting the 10-404. The work you are describing is directly related to the open 10- 403 so just continue to work to get wells unloaded/ bailed and then send in the final 10-404. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, December 10, 2012 7:58 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: Extend work 10-404 on M-16RD and G-14 Guy and Victoria, SCANNED AUG 2 0 2010 Hilcorp is continuing to work on two gas wells in order to bring them back on line at their full potential. We would like some clarification as to if we should close out the 10-403 with a 10-404 or can we continue this work under the existing 10-403 and submit the 10-404 when we have completed the well efforts? Here is a synopsis of where we are on each well: M-16RD (Sundry # 312-304)- This well is flowing 1.6 MMscfd rate from the upper zone. We lost a lot of completion fluid to the well during the workover and our belief is that the top zone is contributing the gas but the bottom two zones are not. We did take the well to flare over the weekend in an effort to unload the well but although we did see an increase in water rate from 5 bwpd to 15 bwpd, we did not see an increase in gas rate. The plan forward is to rig up slickline and swab the well to see if that will bring in the lower two zones. This work will begin as soon as a slick line crew is available, hopefully tomorrow (Tuesday morning). G-14 (Sundry 312-254) This well did not treat as expected when conducting the top gravel pack. Therefore we elected to leave the plug in the well separating the top zone from the bottom in orde o test the top zone separately. Now that the testing of the top zone is completed, we are on the well with slickline bailing debris in order to pull the isolation plug separating the two zones. We estimate that we have approx.. 10 feet to go to be at the plug. Please advise if this work constitutes continuation of the 10-403 or do we need to close out the 10-404 and move forward. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 12/10/2012 o rn Zo3— (Y -L— (6,$ Og0 • Ferguson, Victoria L (DOA) • From: Ferguson, Victoria L (DOA) Sent: Tuesday, November 20, 2012 11:44 AM To: Ted Kramer Cc: Schwartz, Guy L (DOA) Subject: RE: G-14 Gas Well Sundry Modification to Sundry #312-254(PTD 168-080) Ted, We have reviewed your request to use 9.2 ppg mud weight versus the 9.5 ppg outlined in your procedure which will result in an overbalance of 65 psi to the worst case expected reservoir pressure of 1300 psi(at 2855 ft -TVD). It is expected that weighted material will be located on standby should it become necessary. We have reviewed this with Commissioner Foerster and you have verbal approval to proceed as outlined. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson(aMaska.gov SCANNED AUG ? 0 20113 From: Schwartz, Guy L (DOA) Sent: Tuesday, November 20, 2012 10:48 AM To: Ferguson, Victoria L (DOA) Cc: Ted Kramer Subject: FW: G-14 Gas Well Sundry Modification to Sundry #312-254 Ted, I will pass this on to Victoria... we will discuss first and call you back. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ted Kramer fmailtoakramer(abhilcorp.coml Sent: Tuesday, November 20, 2012 10:27 AM To: Schwartz, Guy L (DOA) Subject: G-14 Gas Well Sundry Modification to Sundry #312-254 Guy, I am writing to ask for a Sundry modification to item 10 of the Sundry procedure approved on July 19, 2012 on the Grayling Gas Well G-14. 1 Item 10 calls for a mud weight of 9.5 ppg. We are finding that with the current cold temperatures coupled with the shallow depth of the formation that we can achieve a mud weight of 9.2 ppg. This mud weight still puts us in a overbalanced position for the well at the top perforation assuming the maximum expected bottom hole pressure of 1,300 psi. at 2,855' TVD. As a safety precaution, we have located weighting material and have it on standby should it become necessary. Please let me know if The AOGCC approves of this change. Thanks, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 Pm i 660& Regg, James B (DOA) From: Wayne Biart - (C) [wbiart@hilcorp.com] Sent: Sunday, November 11, 2012 11:03 PM VZ To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Grimaldi, Louis R (DOA) Cc: Ted Kramer; Juanita Lovett Subject: BOP test report and update G-14 Grayling Attachments: G-14 BOP test 11-9-12.xis All, please see attached BOP test from 11/10. Repairs have nee made to leaking flange, lights on remote we replaced with LEDs. Deck has been rearranged hoses have been organized and circulating system has been set to safe positions. Zone 2 equipment has been ordered for overspeed shut off, explosion proof I alternator, anti static belts, etc. Exhaust has been ordered to take exhaust outside off of mud pump. Remaining is replacement of Nitrogen bottle ..it is on board 3 spares and will be replaced before we start back to work. Well is still plugged and we have not yet started to work. Hilcorp generated Shut down for safety and winterizing should end PM 11/12 and we will start back to work in the wellbore. House keeping has been a major focus and has dramatically improved the last 24 hours. Rig deck will be up to normal clean standards before we start operation. Repairs we all finished today but we have even more improvements to optimize winterization and improve egress routes and equipment access before we actually open up the well and proceed with well plan. Hilcorp safety inspection of the rig deck today was completed as well. Jim, As we shut down to make adjustment and repairs for 2 days would it be possible to place the next BOP test 1 week from the time we actually start working? Test was completed 6 PM 11/11. Estimated start up of operations in well bore is 1800 hours 11/12/2012 Thanks to Lou, for your guidance and education during yesterday's visit. We look forward to your next visit. Thanks and regards Wayne Wayne M Biart Wellsite Manager Grayling Platform Hilcorp,Alaska LLC SCANNED A U 6 Z `r_t, 6 DXJ44 ncrej {` STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regg(cci)-alaska.aov doa.aogcc.Prudhoe.bay aC -alaska.ciov Phoebe. brooksCaD-alaska. qov Contractor: Williams Rig No.: 404 DATE: 11/10/12 Rig Rep.: Steve Solis Rig Phone: 776-6630 Rig Fax: n/a Operator: Hilcorp Alaska LLC Op. Phone: 776-6639 Op. Fax: n/a Rep.: Wayne Biart E -Mail wbiart@hilcorp.com Well Name: TBU G-14 PTD # 1680800 Operation: Test: Test Pressure: Drlg: Initial: X Rams: 200/3000 Workover: X Weekly: Annular: 200/2500 Explor.: Bi -Weekly Valves: 200/3000 Alarm MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: NA Test Result Test Result Annular Preventer Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: FP Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. NA Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P NA MS Misc 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13 5/8" P Pit Level Indicators P NA #1 Rams 1 3 -1/2 Dual FP Flow Indicator NA NA #2 Rams 1 3-1/2 Single P Meth Gas Detector P P #3 Rams 0 Blind P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 21/16 P Inside Reel valves 0 NA HCR Valves 1 21/16 P Kill Line Valves 2 21/16 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1600 P Quantity Test Result 200 psi Attained 44 P No. Valves 10 P Full Pressure Attained 177 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 3 x 1466 CH Misc 0 NA ACC Misc 2 FP Test Results Number of Failures: 2 Test Time: 9_0 Hours Repair or replacement of equipment will be made within 2 days. Notify the North Slope Inspector 659-3607, follow up with written confirmation to Supervisor Jim Regil. Remarks: Flange below Single BOP w/ Dual Rams failed to test ND BOP and change ring gasket repaired and tested 11/11. Bottom of Riser leaked on top of wellhead tightened and test OK. House keeping issues were being resovied by new crews and WSM Nitro enl low bottle will be changed asap. Close time 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Regg Date 11/7/12 Time 0900 Witness Lou Grimaldi Test start 0900 Finish 0600 Form 10-424 (Revised 02/2012) 2012-1109_BOP_Williams404_TBU_G-14_lg • 0 Williams 404 BOPE Test 11-11-12 TBU G-14 (PTD 1680800) — Hilcorp Remarks Flange below Single BOP w/ Dual Rams failed to test ND BOP and change ring gasket repaired and tested 11/11. Bottom of Riser leaked on top of wellhead tightened and test OK. House keeping issues were being resovled by new crews and WSM Nitrogenl low bottle will be changed asap. Close time Annular 41 sec. Close time Pipe rams 7 sec. Accumulator remote lights are faulty Lights replaced with LED. Housekeepeing entire deck washed down hoses organized on going progress. Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 26, 2012 2:03 PM To: 'Tom Fouts - (C)' Cc: Mike Dunn; Ferguson, Victoria L (DOR) Subject: RE: Sundry No. 312 -254/ WeII# G -14 Gas Well (PTD 168 -080) Tom, The changes to the approved program are fairly minor and don't affect the overall scope of the work. Pulling the upper packer vs setting a plug on top of it allows possible reentry into the lower production zones later if needed. The changes are approved as shown in the attached updated procedure. I will file this email as well as the new updated procedure as documentation. Regards, Guy Schwartz SCANNED p 2 Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) (P.S. The first page has incorrect PTD number listed. Should be 168 -080) From: Tom Fouts - (C) [mailto:tfouts @hilcorp.com] Sent: Wednesday, September 26, 2012 12:25 PM To: Schwartz, Guy L (DOA) Cc: Mike Dunn Subject: Sundry No. 312 -254/ WeII# G -14 Gas Well Guy, Sundry No. 312 -254 was approved on 7/19/12, we plan to begin work on this well on 10/2/12 to 10/5/12. There has been a procedural change since the original submittal which I have attached to this email. These changes are highlighted in red in the attachment. My question is, would you like me to request the cancelation of the approved sundry and resubmit, or can we use the attached procedure and proceed. Thanks, Tom Fouts! Construction Manager Hilcorp Alaska, LLC tfouts @hilcorp.com Direct: (907) 777 -8398 Mobile: (907) 351 - 5749 9/26/2012 Well Work Prognosis Well: G -14 HBcorp Alaska, LLC r e k tevy ki../ Date: 09/26/2012 Well Name: G -14 API Number: 50- 733 - 20146 -00 Current Status: Gas Producer Leg: Leg #2 (NE corner) Estimated Start Date: October 4, 2012 Rig: William Rig 404 Reg. Approval Req'd? 403 Date Reg. ApprovalRec'vd: Regulatory Contact: Tom Fouts777 -8398 Permit to Drill Number: .&68-643"16 — D4 ° O First Call Engineer: Mike Dunn (907) 777 -8382 (Office) (907) 351 -4191 (M) Second Call Engineer: Ted Kramer 907 g ( ) 777 -8320 AFE Number: 1221949 Budgeted Cost: The well is currently producing gas from the long string of a dual. The short string has been shut -in since 12/8/11. Current BHP: 224 psi in the LS in the B -8 at 5,077' MD and 3,710' TVD • .06 psi /ft, (1.2 ppg) at top of B -8 sand 210 psi in the SS in the B -1 thru B -4 at 3,838' MD and 3,039' TVD • .07 psi /ft, (1.3 ppg) at top of B -1 sand Max. Expected BHP: 1,300 psi @ 2,855' TVD .456 psi /ft= 8.7 ppg fluid weight Max. Possible SP: 1,244 psi @ surface Using a .02 psi /ft gas gradient to surface Brief Well Summary The G14 is a dual completion gas well that is providing some of the fuel gas for the Grayling platform. The long string (LS) is currently producing 400 mcfd, at 85 psi FTP. It is anticipated to go off -line soon as it will not be able to able to buck the fuel gas line pressure of 60 psi. TheLS is completed in the B8, C1, and C2 sands; howeversand -fill covers most of the C -sand perforations. The short string (SS) has 8 sets of perforations in the B1 to B4 sands but is currently off -line. Due to low BHP, the short- string is unable to flow into the surface production system. All current completions have a secondary take -point in the G18DPN well,but the option to go back to the existing zone (perforations) when compression is installed on the platform should be retained. Notes Regarding Current Wellbore Condition • Well is completed as a dual. • Sliding sleeves in the long string at 4,935', 4,881', and 3,713' are all closed. • Sliding sleeve in the short string at 3,680' is closed. • Dual strings will be removed so a new single, gravel pack completion can be run. • The existing perfs will be temporarily abandoned by setting a CIBP above the top perfs. Procedure: Pre -Rig Up 1. Kill both strings by pumping filtered inlet water (FIW) into each string. Fluid level is not expected to stay full in either string. Rig Activities 2. Move Williams Rig 404 to Leg 2 (NE corner) and skid rig over well G -14. 3. Plumb filtered inlet water (FIW) lines to circulate down the annulus and up the tubing and thru the tree at least two full bottoms -up tomake sure there is no gas in the tubing or annulus. 4. Notify AOGCC 24 hrs before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOPE per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH, the Annular will be tested to 250 psi Low/ 11 • • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 09/26/2012 1,500psi High. Record pressures, fill out the form 10 -424 and send to Jim Regg at AOGCC and Juanita Lovett with Hilcorp. 5. RU E -line. Cut the long string just below the upper packer at 3800' with low flare jet cutter. 6. After cut is made, pull hanger up to floor height by pulling both tubing strings and get upper dual packer to release. Remove hangerand secure strings. Attempt to pull both strings simultaneously with dual handling tools and dual 3 -1/2" rams in upper BOP. There is no .mention of the use of special clearance couplings, so the coupling OD (4.250 ")may not allow the two strings to pass one another. Check coupling OD as soon as one is exposed. If special clearance, it may be possible to pull one string at a time if need be. POOH with completion tubing. LD same, check for NORM. 7. MUCIBP on e -line and RIH to just above long string tubing cut at 3800'. Set same. Dump bail 20' of ✓ cement on top as a cap. 8. MU bit and scraper and RIH on workstring just above the cement on top of bridge plug and displace hole with 9.0 ppg FIW with 6% KCI and weighted with NaCI.This is expected to be approximately .5 ppg over the pore pressure of the new zones.POOH. 9. RU E -line and RIH to perforate for squeeze cementing operations. Perforate 3,600' — 3,605' at 4 spf. Then perforate 2,000' — 2,005' at 4 spf. Note any pressure increase or drop in fluid level. 10. WLOH with E -line. 11. PU retrievable squeeze packer or drillable cement retainer and RIH to 100' below the top perf at 2,100'. Set same. Pump down workstring while taking returns to establish circulation path down work - string and casing and backup through the 9 -5/8" X 13 -3/8" annulus and then back up the workstring X 9 -5/8" annulus. If confirmed, mix cement and pump cement down same path as a "suicide squeeze ". Displace TOC in the workstring below the squeeze packer to 3,200'. Unseat packer and POOH to 100' above top perf to 1,900'. CBU any cement to the catch tank, POOH. If a retainer was used, unsting from retainer, PU, CBU to clear cement. 12. PU rock bit and RIH to TOC. WOC 12 hours. Drill cement to PBD at 3,735'. CBU. 13. If cement drilling was hard, pressure test casing to 1,000 psi and chart for 30 minutes. If soft, wait an additional 12 hours before pressure testing. 14. If casing test is successful, POOH to run gravel pack completion. If unsuccessful, PU retrievable test packer to determine which set of perfs is not holding. Squeeze cement in weak perfs. Drill out. Test same. 15. With successful casing test, MU 7" Big Hole casing perf guns on the workstring to perforate as follows: Zone Interval Feet A -1 3,105' — 3,152' 47' A -4 3,494' — 3,524' 20' Total: 67' 16. Detonate guns. Monitor well for pressure changes or fluid losses. If well does not stay full, use unweightedFlW to fill the hole until hydrostatic balance is achieved. 17. POOH with guns. LD same. Confirm that all charges fired. 18. MU sump packer and RIH. Set packer 8' below bottom perf of bottom interval. POOH. RIH with gravel pack assembly and packer. Mix up sand and place sand into the perfs and behind the screen in the screen X 9 -5/8" annulus per detailed gravel pack procedure. POOH. 19. PU packer and gravel pack assembly and RIH to set screen across upper perf interval. Pump sand and gravel pack upper section per detailed gravel pack procedure. POOH. 20. PU 4 -1/2" tubing and RIH. Install SSSV and control lines to a depth of 300'. Sting into upper packer, space out, land hanger. Test backside to 1,000 psi for 30 minutes. Chart same. 21. ND BOPE and NU X -mas tree. 22. MU swab cup on sand line and swab well until well begins to flow. Unload well, test same. II • • Well Work Prognosis Well: G -14 Ihlenrp ,Alaska. LLC Date: 09/26/2012 Current Wellbore Schematic Rr•.B= 33 11'Rig Floor to TBG Head Casing Detail I Size Type Wt Grade Thrd ID Top Btm 17 -3/4" Surf I Spiral BTC 15.12 Surf 650' 13 3P8" Csg 61 I J-55 12.52 Surf 6,495' 40 z B 11 .' I 9 -5/8" I Prod Csg I 43.5, P110/N -80 I BTC I ( Surf 1 13,521' I 1 ,�,. 2 47 _L C TubingDetail 0 1 an owl T 3 -1/2" Short String 9.2 N -80 Surf 3,785' e 1 ;: 3 3 -1/2" Long String . 9.2 N -80 Surf 4,989_) Li NO. Lnr , ? ' _t rir�;_, Short String E Depth R) Item NO. Death Item 1v 33 1 298' 3 -1/2" Otis ball valve nipple 3 -1/2" Otis & -0p,rt - -= 1 3b 2 3,713' 3 -1/2" OtisXA sleeve _ ( A 257' ball valve 3 3 3,746' Brown H -2 -f d. Packer nipple 3a 3,816' 3" 4- 1 /4 "OD Baker Blast Joint C4 ppr : A 2d B 3680' 3-1/2" oosxA 3b 4,068' 3" 4- 1 /4 ' OD Baker Blas[Joirn , ; sleeve 3e 3c 4,135' 3" 4-1/4" OD BakerBlastJoint ' saps " - - - -' ' 3i 3d { 4286' 3" 4- 1 /4 " OD Baker Blast Joint 1 C I 3,744' 1 Brawn right hand coupling 11 39 3e 4,336' 3" 4 -1/4" OD Baker Blast Joint Brown H-2 1 3h 3f 4,435' 3" 4 -1/4" OD Baker Blast D 3,746' -... Hyd. Packer 8.1 p ' rt ' t i t ; b 3g 1 4 3" 4 -1/4" OD Baker Blast Joint • S ®i�rl HI. «y 3h 4,809 3 "' 4 -1/4" OD BakerBlastJaint E 3,785' 3- 1/2 "OtisO 1 = 1m 1 9 u:1 �n 4 ' ; 4,881 3 -1/2" OtisXA Sleeve nipple 4 s i o' T 5 4,920' 3 -1/2" Baker locator sub 6 4,921'- 4,930' 3 -1/2" Baker Seal Assy 2. s - B 7 4,922 Packer rlinnnas H in t 10 aa•a1a 8 4,935' 3 -1/2" OtisXA Sleeve r a - 11 9 4,944' 3 -1/2" Baker locator sub 10 4,946'- 4,956' 3 -1/2" Baker Seal Assy 11 4,950' ; Packer 12 4,988' 2.65" 3 -1/2" OtisQ nipple 12 13 4,989' _2-1/2" Baker mule shoe PERFORATION DA TA Zone I Top/(MD) Btm/(MD) Top /(TVD) Btm/(TVD) Date Condition Notes i.. B-1 3,838' 3,844' 3,039' 3,042' 7/3/1974 OPEN et out _ _- B-1 4,076' 4,080' 3,165' 3,168' 7/7/1974 OPEN B-1 4,135' 4,138' 3,197' 3,199' 7/7/1974 ':, OPEN B-2 4,295' 4,305' 3,283' 3,288' 7/7/1974 OPEN B-2 4,340' 4,350' 3,307' 3,312' 7/7/1974 OPEN Tpp DTI' WHO B-2 4,444' 4,454' 3,363' 3,369' 7/74974 OPEN c -i rf , B-3 4,715' 4,725' 3,510' ........3,516' 7/7/1974 OPEN _.... C-1 pirt - 1.O'- -. • -, ' � � N B 4,820 4,830' 3,568' 3,573' 7/7/1974 OPEN s u B- 8 5,077' 5,095' 3,710' 3,720' 1275/2011 OPEN B-8 5,099' 5,119' 3,722' 3,777 125/2011 OPEN C-1 5,254' 5,274' 3,808' 3,819' 7/74974 OPEN % covered Wthfill C -2 5,500' 5,510' 3,943' 3,948' 7/7/1974 OPEN Covered with fill NO. Depth Item IV j 5,600' Junk retainers V I 5,614' EZSV retainer VI 1 6,737' EZSV retainer 15.14342' MD1P5T D4614 M 5 -14 Schematic 7- 9- 2012,docx 'IDF: 3 +1[/2012 II • • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 09/26/2012 New (Proposed) Wellbore Schematic • 0 Well Work Prognosis Well: G -14 Ili!carp Alaska. LDP. Date: 09/26/2012 Rft B = 38.11' Rf g Floor to T BG Head Casing Detail Size Type Wt Grade Thrd ID Top Btm 17 -3/4" Surf Csg Spiral BTC 15.12 Surf 650' 13 -3/8" Csg 61 J-55 12.52 Surf 6,495' t s. I 9 5/8" Prod Csg 143.5, P110/N -80 BTC I 8.53 I Surf I 13,521' I Top 2A o Z - 1 47 -� -_ �_ -.. _1. Tubing/Completion Detail _ Description OD 1 PPF Grade 1 Thrd Length Top Btm } Original RKB 7 - +0' ±38.11 Hanger 92 1 ±38.11 ±1.0' It' 4-1/2' Tubing 520 92 L -80 IBT 2,957 ±39.11' ±2,996' .ci . { Ain S� SSSV 5' ±300' 3)300' - Cllr Prm4 ;rk _ AS1 -X Retrievable Pkr 8.25 7' ±2,996' TBD X00' 1 OvrSht,Nipple,X0 9' ' " is 5 -1/2" tubing - 6.050 15.5 L - 60' " ' ib 5 -1/2" GP Screen 5.992 90' " " g I is X0, Snap Latch 2' ' ' id D Permanent Pkr 8.25 3' " 114 port 10 3- 1/2`pupandnipple 25' ' If 3 - 1/2 "Tubing 4.50 9.2 L -80 210' ' 62 PR: - 1 9 OvrSht, Nipple, X0 9 " " ih 5 -1/2" tubing 6.050 15.5 1-80 60' " ' II pod' 5 -1/2" GP Screen 60' ea ;art X0, Snap Latch 2 " " 1 in 1 # 1 Lem,'on..r D Sump Pkr 8.125 2' ±3,535' 4,171 -4,I -- Il - -- --- x ■ f ■ 5 1 �. I �'i B all.rlllll icy ;a ■ 4a a 91,.41' -,111' Long String NO. Depth ID Item 4,989' 3.0" . To be Abandoned Short String i° Na Depth ID Item 3,785' 3.0 To be Abandoned or removed 2:111 Si put - -- Tnp ut'. � eil r c a C2 port ."' PERFORATION DATA .^ - V Zone Top /( Btm/i( Top /i(TV0) Btm/(TV p to Condition Notes A -1 ±3,105' ±3,152' ±2,650' ±2,675' Future A -4 ±3,494' ±3,524' ±2,856' ±2,872' Future -----1 I, --.....1 Vi B-1 3,838' 3,844' 3,039' 3,042' 7/34974 ! To be Temp Abandmed thru 4,076' 4,080' 3,165' 3,168' 7/7/1974' C -2 1 4,136' 4,138' 3,197' 3,199' 7/7/1974 " T E 1ti,:42' M D'P(SI t-Sti 14' MD G14 Propo se d 9 - 26.2012.dot x !ADD: 9/26/2012 • • (T:, p � ; SEAN PARNELL, GOVERNOR h � ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mike Dunn b Sr. Reservoir Engineer I _ C . 0i Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai Gas & Hemlock Oil Pool, TBU G -14 Sundry Number: 312 -254 *AWL) L) JUL 2 6 201 Dear Mr. Dunn: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Q Chair DATED this l b day of July, 2012. Encl. • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JIL 1 201 APPLICATION FOR SUNDRY APPROVALS AO C i iQ. 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations Q • Perforate El • Pull Tubing 151 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Gravel Pack [ . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: •d a,? ■ 7P Hilcorp Alaska, LLC Development ig • Exploratory ❑ 168 -080 • l'I' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20146 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No • Trading Bay Unit G -14 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018730 • McArthur River Field / Middle Kenai Gas, Hemlock Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16,342 10,593 • 5,269 3,816 N/A 5,269' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 650' 17 -3/4" 650' 649' Surface 6,495' 13 -3/8" 6,495' 4,477' 3,090 psi 1,540 psi Intermediate Production 13,521' 9 -5/8" 13,521' 8,721' 5,750 psi 3,090 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,838' to 5,510' 3,038' to 3,948' 3 -1/2" 9.2# N -80 LS /SS Short String 3,785' Long String 4,989' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 3 packers, 2 SSSVs Brown H -2 Hyd. Pkr; (2) Packer & 3 -1/2" Otis Ball Valve Nipple 3,746' (MD) 2,989' (TVD); 4,922' (MD) 3,623' (TVD); 4,950' (MD) 3,639' (TVD) & 298'(MD) 297' (TVD); 257' (MD) 256' (TVD) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 151 Exploratory ❑ Development Ei • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/25/2012 Oil ❑ Gas © • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Dunn Printed Name Mi a Dunn Title Sr. Reservoir Engineer 1.7,44/ Signat Phone (907) 777 -8382 Date 7/11/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J I Z.,.."'' . SC/ Plug Integrity ❑ BOP Test ri Mechanical Integrity Test ❑ Location Clearance ❑ Other: r5 t / P �r " 4i Subsequent Form Required: /0 4 / APPROVED BY Approved by: �y n (L/,� / COMMISSIONER [ T COMMISSION JUL q� Date: 7- /q / _ Form 10-403 evised 1/2001 '' 0 "'`` ^^^^4 ' rrr """ ___"" L o R 1 G 1 N A t eDMS J1 9 Lot i • . •mit in Duplicate VV ' v ,y o. • • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 07/12/2012 Well Name: G -14 API Number: 50- 733 - 20146 -00 Current Status: Gas Producer Leg: Leg #2 (NE corner) Estimated Start Date: July 22, 2012 Rig: William Rig 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 168 -043 First Call Engineer: Mike Dunn (907) 777 -8382 (Office) (907) 351 -4191 (M) Second Call Engineer: Melissa Eisele (907) 777 -8319 AFE Number: 1221949 Budgeted Cost: The well is currently producing gas from the long string of a dual. The short string has been shut -in since 12/8/11. Current BHP: 224 psi in the LS in the B -8 at 5,077' MD and 3,710' TVD • .06 psi /ft, (1.2 ppg) at top of B -8 sand 210 psi in the SS in the B -1 thru B -4 at 3,838' MD and 3,039' TVD • .07 psi /ft, (1.3 ppg) at top of B -1 sand Max. Expected BHP: 1,300 psi @ 2,855' TVD .456 psi /ft = 8.8 ppg fluid weight Max. Possible SP: 1,244 psi @ surface Using a .02 psi /ft gas gradient to surface Brief Well Summary The G14 is a dual completion gas well that is providing some of the fuel gas for the Grayling platform. The long string (LS) is currently producing 400 mcfd, at 85 psi FTP. It is anticipated to go off -line soon as it will not be able to able to buck the fuel gas line pressure of 60 psi. The LS is completed in the B8, C1, and C2 sands; however sand -fill covers most of the C -sand perforations. The short string (SS) has 8 sets of perforations in the B1 to B4 sands but is currently off -line. Due to low BHP, the short- string is unable to flow into the surface production system. All current completions have a secondary take -point in the G18DPN well, so the remaining value of this wellbore are the sands that are up the hole. Notes Regarding Current Wellbore Condition • Well is completed as a dual. • Sliding sleeves in the long string at 4,935', 4,881', and 3,713' are all closed. • Sliding sleeve in the short string at 3,680' is closed. • Dual strings will be removed so a new single, gravel pack completion can be run. • The existing perfs will be abandoned by pumping cement across all perfed zones, and cementing the existing packers in place. Procedure: Pre -Rig Up 1. Kill both strings by pumping filtered inlet water (FIW) into each string. Fluid level is not expected to stay full in either string. Rig Activities 2. Move Williams Rig 404 to Leg 2 (NE corner) and skid rig over well G -14. 3. Plumb filtered inlet water (FIW) lines to circulate down the annulus and up the tubing and thru the tree at least two full bottoms -up to make sure there is no gas in the tubing or annulus. 4. Notify AOGCC 24 hrs before pending BOPS test. Set BPV, ND tree, NU BOPE. Test all BOPE per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH, the Annular will be tested to 250 psi Low/ 1,500 11 • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 07/12/2012 psi High. Record pressures, fill out the form 10 -424 and send to Jim Regg at AOGCC and Juanita Lovett with Hilcorp. 5. PU landing joint and make -up to tubing hanger. Pull hanger out of tubing head to put tubing strings in tension. 6. RU E -line. Cut each tubing string at +/- 3,730' just above the top packer with low flare jet cutter. 7. After cuts are made, pull hanger up to floor height by pulling both tubing strings from the cut at the bottom of each one. Remove hanger and secure long string. Attempt to pull the short string with single string handling tools. There is no mention of the use of special clearance couplings, so the coupling OD on each string is assumed to be 4.250" which will not allow the two strings to pass one another. If that.. the case, RU dual string handling tools. POOH with completion tubing. LD same, check for NORM. 8. PU cement retainer and RIH to just above tubing cuts at +/- 3,735'. Set same. Attempt to pump FIW below the retainer into production perfs to establish an injection rate. If successful, mix Class G cement to a volume equivalent to the cased-hole volume in the lower cavity (via LS) and the upper cavity (via the SS). ��- 9. Pump cement and displace with FIW. When all of cement has reached the perforations, pump pressure should rise. Do not pressure up over the frac gradient. As pressure builds, slow pump rate and pressure up to 500 — 1,000 psi over water injection pressure. Hold for 10 minutes, un -sting from cement retainer and reverse out any excess cement that may be in the workstring. CBU at least two bottoms up. 10. With workstring just above the cement retainer, displace hole with 9.5 ppg FIW weighted with NaCI. This is expected to be approximately 1 ppg over the pore pressure of the new zones. POOH. 11. RU E -line and RIH to perforate for squeeze cementing operations. Perforate 3,600' — 3,605' at 4 spf. Then perforate 2,000' — 2,005' at 4 spf. Note any pressure increase or drop in fluid level. 12. WLOH with E -line. 13. PU retrievable squeeze packer and RIH to 100' below the top perf at 2,100'. Set same. Pump down workstring while taking returns to establish circulation path down work - string and casing and back up through the 9 -5/8" X 13 -3/8" annulus and then back up the workstring.X 9 -5/8" annulus. If confirmed, mix cement and pump cement down same path as a "suicide squeeze ". Displace TOC in the workstring below the squeeze packer to 3,200'. Unseat packer and POOH to 100' above top perf to 1,900'. CBU any cement to the catch tank, POOH. 14. PU rock bit and RIH to TOC. WOC 12 hours. Drill cement to PBD at 3,735'. CBU. 15. If cement drilling was hard, pressure test casing to 1,000 psi. If soft, wait an additional 12 hours before pressure testing. 3C vv ' k7 16. If casing test is successful, POOH to run gravel pack completion. If unsuccessful, PU retrievable test packer to determine which set of perfs is not holding. Squeeze cement in weak perfs. Drill out. Test same. 17. With successful casing test, MU 7" Big Hole casing perf guns on the workstring to perforate as follows: Zone Interval Feet A -1 3,105' — 3,152' 47' A -4 3,494' — 3,524' 20' Total: 67' 18. Detonate guns. Monitor well for pressure changes or fluid losses. If well does not stay full, use unweighted FIW to fill the hole until hydrostatic balance is achieved. 19. POOH with guns. LD same. Confirm that all charges fired. 20. MU sump packer and RIH. Set packer 8' below bottom perf of bottom interval. POOH. RIH with gravel ✓' pack assembly and packer. Mix up sand and place sand into the perfs and behind the screen in the screen X 9 -5/8" annulus per detailed gravel pack procedure. POOH. 21. PU packer and gravel pack assembly and RIH to set screen across upper pert interval. Pump sand and gravel pack upper section per detailed gravel pack procedure. POOH. 22. PU 4 -1/2" tubing and RIH. Install SSSV and control lines to a depth of 300'. Sting into upper packer, space out, land hanger. Test backside to 1,000 psi. 14 • • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 07/12/2012 23. ND BOPE and NU X -mas tree. 24. MU swab cup on sand line and swab well until well begins to flow. Unload well, test same. II • 0 Ili Well Work Prognosis Well: G -14 Hilcorp Alaska,( u: Date: 07/12/2012 Current Wellbore Schematic 1 I RRB= 33.11'Rig FIc. rto TBG Heed CasingDetail Size I Type VNIt Grade Thrd ID Top Btm 17-3/4" Surf Csg Spiral BT C 15.12 Surf 650' i 1 13 -3/8" Csg 61 J -55 12.52 Surf 6,495' 40, E ..e.• 1 1 9 -5/8" I Prod Csg I 43 5, I P110/N -80 I BT C I I Surf ( 13,521' I 47 C J y! C(i Tubin g= Detail c, i aE r VIM • 11)12 3 -1/2" Short String 9.2 N -80 Surf 3,785' t-�-._ : 3 3 -1/2" Long String 9 2 N -80 Surf 4,989' Long String, rt `;trr1:= NO, Depth _ ID Item Na Depth Item 1 , 1 298' 3 -1/2" Otis ball valve nipple : 3 -1/2" Otis i I e. ;b 2 3,713' . 3- 1/2 "OtisXA9eeve A I 257' I ball valve • 3„ 3 :3,746' Brown H -2 Fyd. Packer nipple E-.? °.n * 3,1 3a 3,816' 3" 4 -1/4" OD Baker Blast Joint 3 1/2" DOS XA II a 3b 4 3" 4 -1/4" OD Baker Blast Joint B 3,680 -. sleeve • 3c 4,135' 3" 4 -1/4" OD Baker Blast Joint Brown right ' Et fart • 3t 3d 4,286' 3" 4-1/4" OD Baker Blast Joint I 1 r I 3744' 1 a hand coupling ii s 3e 4,336' 3" 4 -1/4" 0D Baker Blast J oint ;h 3f 4,435' 3" 4 -1/4" OD Baker Blast Joint D 3,746' Brown H 2 E' p1" 3g 4,708' 3" 4 -1/4" OD_Baker Blast Joint Hyd. Packer 3 -1/2" Otis Q a 3 0..rr.1..0 3h 4,809 3" 4- 1 /4 "ODBaker Blast Joint E 3,785' ' art r ma r Ili r 4 4,881 3 -1/`2" OtisxA Sleeve _ _____�_ I■; r r 5 4,920' 3 -1/2" Baker locator sub II 6 , 4,921'- 4,930' 3 -1/2" Baker Seal Assy �_ y 7 4,922 Packer to 9Urh.III I I � r r! t 4a'Y9' 8 4,935' 3 -1/2" OtisXA Sleeve 11111M. e i 1 9 4,944' 3-1/2" Baker locator sub 10 4,946'- 4,956' 3 1/2" Baker Seal Assy 11 4,950 Packer 12 ` 4,988' 2.65" 3 -1/2" Otis Q nipple 12 13 I 4,989' 3 -1/2" Baker mule shoe • PERFORATION DATA Zone Top/(MD) Btm/(MD) Top /(TVD) Btm/(TVD) Perf ' Present "p Notes Date 1 Condition 8-1 3,838' 3,844' ' 3,039' 3,042' 7/3/1974 i OPEN N port NM- B-1 4,076' 4,080' 3,165' 3,168' 7/7/1974 OPEN B-1 4,135' 4,138' 3,197' 3,199' 7/7/1974 i OPEN B-2 4,295' 4,305' 3,283' 3,288' 7/7/1974 oPE F•I B-2 4,340' 4,350' 3,307' 3,312' 7/7/1974 i OPEN Top 0 0@Oir' 8-2 4,444' 4,454' 3,363' 3,369' 7/7/1974 I OPEN cane ` "` 8-3 4,715' 4,725' 3510' 3516' 7/7/1974 i OPEN c :nrr 8-4 4,820' 4,830' 3,568' 3,573' 7/7/1974 I OPEN \ B-8 5,077' 5,095' 3,710' 3,720' 12/5/2011 ' OPEN ' B-8 5,099' 5,119' 3,722' 3,777' 12/5/2011 1 OPEN : C -1 5,254' 5,274' 3,808' 3,819' 7/7/1974 r- OPEN ',b cove red with fill • , r C -2 1 5500' i 5,510' 3,943' 3,948' 7/7/1974 1 OPEN Covered with fill VI „f N0. Depth itet�t � "'mums.; , tier IV 5,600' Junk retainers V 5,614' EZSV retainer --4.• VI 6,737' EZSV retainer 1 D ti.612' M D1PBT KC 14' M D G-14 Schematic 7- 9- 2012door •IDF: 7/101/2012 0 • Grayling Platform PROPOSED Well #G -14 Hilcorp Alaska, L RKB = 38.11'Rig Floor to TBG Head Casing Detail i Ii Size Type Wt — Grade Thrd 'r' Btm 17 -3/4" Surf Csg Spiral BTC 15.12 Surf 650' 13 3/8" Csg 61 J 55 12.52 Surf 6,495' 40, � ' ' 1 9 5/8" Prod Csg 43.5, P110/N 80 BTC 8.53 Surf 13,521' Top Sqz 47 2,000' 7_ j s 4 ><___. A Tubing /Completion Detail Description OD PPF Grade Thrd Length Top Btm �` ,. Original RKB ±0' ±38.11 Hanger 9.2 1 ±38.11 ±1.0' 4 -1/2" Tubing 5.20 9.2 L -80 IBT 2,957 ±39.11' ±2,996' —► " Btm Sqz SSSV 5' ±300' CmtRe 3,600' 3,735' AS1 -X Retrievable Pkr 8.25 7' ±2,996' TBD A 1 ,, OvrSht, Nipple, XO 9' la 5 -1/2" tubing 6.050 15.5 L -80 60' " .' u 1b 5 -1/2" GP Screen 5.992 90' " B 1c XO, Snap Latch 2' " Id D Permanent Pkr 8.25 3' II " B -1 pert le 3 -1/2 "pup and nipple 25' " 1 3 -1/2" Tubing 4.50 9.2 L -80 210' " B -2 pert 1 9 OvrSht, Nipple, XO 9 " 1h 5 -1/2" tubing 6.050 15.5 L -80 60' " B-3 perf 5 -1/2" GP Screen 60' " ' 2 B -4perf - 3 XO, Snap Latch 2' " " 1 11 ' 1- 4 Bakersealassy D Sump Pkr 8.125 2' " ±3,535' S 4,921'-4,930 u = 5 6 ■ 7 1 1 — 1 1 k 8 BakerSeal assy _`_._ s _ _ 9,946' 4956' Long String NO. Depth ID Item 4,989' 3.0" To be Abandoned Short String NO. Depth ID Item mi 3,785' 3.0" To be Abandoned 1 B-8 perf a , Top OM LID 5269' C -1 perf C-2 perf PERFORATION DATA Perf Present a NIVV Zone Top /(MD) Btm /(MD) Top /(TVD) Btm /(TVD) Date Condition Notes A -1 ±3,105' ±3,152' ±2,650' ±2,675' Future A -4 ±3,494' ±3,524' ±2,856' ±2,872' Future "."_ Vi B -1 3,838' 3,844' 3,039' 3,042' 7/3/1974 To be Parted Casing Abandoned - — thru 4,076' 4,080' 3,165' 3,168' 7/7/1974 " C -2 4,135' 4,138' 3,197' 3,199' 7/7/1974 " TD- 16,342' MD /PBTD- 5,614' MD G -14 Proposed 7 -12 -2012 TDF: 7/10/2012 • • Well Work Prognosis Well: G -14 Hilcorp Alaska, LLC Date: 07/12/2012 Williams Workover Rig , • Grayling Platform BOP 2012 11' 1 :it iit Itt il! 111 111 Width 4.10' 3.74' Weight 13,1008 111 111 111111 111 Shaffer L Total BOP height above 135 /85M LWS _r` �. 135/85M - 4611 den dimensions , t 1� a _ Length 7.73' ®0 �.. 3.00' 11.48' max Width across body 2.72' Width across flanged i>� outlets 4.00' — Weight9500Ibs 9.00' f �^ , III 111111 III III . f, 1 tiz Mud 1 : ( ° • 1 ! , 1.74' w/ vol 28501bs w/ valves r 4 III iii III III '' 46110 a Riser above drill deck 111 111 This number will vary from well to well 1.00' to 3.00' V Drill Deck 13 5/8 5M Riser 85001bs 15.00' 11 1 111 ��1 111 Spacer Spool 13 5/8 5M X 13 5/8 5M 1.95' 18001bs 111 111 111 ill Crossover Spool 135/85M X 11 5M 18001bs 2.83' 11 1 1 Top of Wellhead • • Ferguson, Victoria L (DOA) From: Mike Dunn [mdunn @hilcorp.com] Sent: Wednesday, July 18, 2012 3:00 PM To: Ferguson, Victoria L (DOA) Subject: RE: TBU G -14 Sundry (312 -254) PTD (168 -080) Yes, If we find we cannot pull the dual with one string at a time and a single ram, we will land the string back in the hanger and replace the rams with dual rams and pull the string as a dual. Mike Dunn 1 Senior Engineer Hilcorp Alaska, LLC Office: (907) 777 -8382 Mobile: (907) 351 -4191. From: Ferguson, Victoria L (DOA) jmailto :victoria.ferguson@alaska.govl Sent: Wednesday, July 18, 2012 2:25 PM To: Mike Dunn Cc: Schwartz, Guy L (DOA) Subject: TBU G -14 Sundry (312 -254) PTD (168 -080) Mike, For pulling this dual completion, will dual rams be used? Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a�alaska.gov 1 STATE OF ALASKA 1 Ik.,t,,1 V 1,111,./ ALASKA" AND GAS CONSERVATION COMMISSI DE REPORT OF SUNDRY WELL OPERATIONS DEC 2 2 2011 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate 11 Ala: tW»r '; Cons. COMMISSION Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension 4 fIchorelle Change Approved Program ❑ Operat. Shutdown ❑ Perforate ig • Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 - Exploratory ❑ 168 -080 ° • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20146 -00 •• 00 - 7. Property Designation (Lease Number): 8. Well Name and Number ADL0018730 [Grayling Platform] Trading Bay Unit G -14 i . 9. Field /Pool(s): r McArthur River Field/ Middle Kenai Gas and Hemlock Oil Pools 10. Present Well Condition Summary: Total Depth measured 16,342 feet Plugs measured N/A feet true vertical 10,593 . feet Junk measured 5,269 (Fill) feet 3,746; 4,922; Effective Depth measured 5,269 feet Packer measured 4,950 feet 2,989; 3,623; true vertical 3,816 feet true vertical 3,639 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 650' 17 -3/4" 650' 649' Surface 6,495' 13 -3/8" 6,495' 4,477' 3,090psi 1,540psi Intermediate Production 13,521' 9 -5/8" 13,521' 8,721' 5,750psi 3,090psi Liner 3,838- 3,844; 4,076- 4,080; 4,135- 4,138; 4,295- 4,304; 4,340- 4,350; 4,444- 4,454; 4,715- 4,725; 4,820- 4,830; 5,077' - Perforation depth Measured depth 5,095'; 5,099' - 5,119'; 5,254-5,274'; 5,500' - 5,510' 3,038- 3,041; 3,165- 3,167; 3,196- 3,198; 3,282- 3,287; 3,307- 3,312; 3,363- 3,368; 3,509- 3,515; 3,567- 3,573; 3,709' - True Vertical depth 3,719'; 3,721'- 3,732'; 3,807- 3,818; 3,924'- 3,948' 3,785' SS MD 3,010' SS TVD Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 #/ N -80 LS /SS 4,989' LS MD 3,660' LS TVD Brown H -2 Hyd. 3,746'; 4,922'; 4,950' -MD 3 -1/2" Otis Ball 298' -MD Packers and SSSV (type, measured and true vertical depth) Pkr, (2) Packer 2,989'; 3,623'; 3,639' -TVD Valve Nipple 297' -TVD 11. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A : t ;. Treatment descriptions including volumes used and final pressure: N/A ' , ,,; ["a t ` ` ` , ' _ , t 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 0 0 69psi 125psi Subsequent to operation: N/A 1,083 0 69psi 130psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ❑ Gas is $ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -312 Contact Billy Applewhite Phone: 263 -7671 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature I - Phone 276 -7600 Date 12/20/2011 RBDMS DEC 22 2011. -a [a�" OO. O1 Form 10-404 Revised 10/2010 Submit Original Only ti • Chevron • Gang Platform Actual We # G -14 - � Revised 12/20/11 RKB = 38.11'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm 17 -3/4" Surf Csg Spiral BTC 15.12 Surf 650' 13 -3/8" Csg 61 J -55 12.52 Surf 6,495' A 9 -5/8" csg is parted at 6,823' 1 9 -5/8" Prod Csg 40, 43.5, 47 P110/N -80 BTC Surf I 13,521' e Tubing 3 -1/2" Short String 9.2 N -80 Surf 3,785' 2 3 -1/2" Long String 9.2 N -80 Surf 4,989' C Long String D t " t r NO. Depth ID Item - 3 1 298' 3 -1/2" Otis ball valve nipple 2 3,713' 3 -1/2" Otis XA sleeve 3 3,746' Brown 11-2 Hyd. Packer 3a 3,816' 3" 4 -1/4" OD Baker Blast Joint 3b 4,068' 3" 4 -1/4" OD Baker Blast Joint III 3c 4,135' 3" 4 -1/4" OD Baker Blast Joint e - pert - 3d 4,286' 3" 4 -1/4" OD Baker Blast Joint • 3e 4,336' 3" 4 -1/4" OD Baker Blast Joint 3f 4,435' 3" 4-1/4" OD Baker Blast Joint B - pert 3g 4,708' 3" 4 -1/4" OD Baker Blast Joint ■ 3h 4,809 3" 4-1/4" OD Baker Blast Joint i 4 4,881 3 -1/2" Otis XA Sleeve B a pert - 5 4,920' 3 -1/2" Baker locator sub • 6 4,921'- 4,930' 3 -1/2" Baker Seal Assy . 7 4,922 Packer 8 4,935' 3 -1/2" Otis XA Sleeve 9 4,944' 3 -1/2" Baker locator sub B a pert 10 4,946'- 4,956' 3 -1/2" Baker Seal Assy B akerseal assy 11 4,950' Packer t l i t 6 4921'.4930 12 4,988' 2.65" 3 -1/2" Otis Q nipple 7 13 4,989' 3 -1/2" Baker mule shoe 'A _ Short String O Bakersaal assy NO. Dept ID Item P I 1 t I _ t a9a6' x966' A 257' 3 -1/2" Otis ball valve nipple 1 B 3,680' 3 -1/2" Otis XA sleeve 1 C 3,744' Brown right hand coupling D 3,746' Brown H -2 Hyd. Packer E 3,785' 3 -1/2" Otis Q nipple 12 NO. Depth Item • IV 5,600' Junk retainers mm 13 V 5,614' EZSV retainer VI 6,737' EZSV retainer 8.8 pert PERFORATION DATA Zone Top Btm Perf Present Notes Date Condition B -1 3,838' 3,844' 7/3/74 OPEN Top of fill @ 6269' B - 4,076' 4,080' 7/7/74 OPEN c -t pert., g` B - 4,135' 4,138' 7/7/74 OPEN ' B -2 4,295' 4,305' 7/7/74 OPEN C - 2 pert r , f .„ fi+bv e x :, e [ - 1, /_ '' - - ' IV B - 4,340' 4.350' 7/7/74 V B -2 B -3 B -4 4,444' 4,454' 7/7/74 7/7/74 4 OPEN s - 4,715' 4,725' 7/7/74 Li ` 4,820' 4,830' 7/7/74 * i +> B - 5,077' 5,095' 12/5/11 OPEN B - 5,099' 5,119' 12/5/11 OPEN C -1 5,254' 5,274' 7nn4 OPEN % covered with fill , C - 5,500' 5,510' 7/7/74 OPEN Covered with fill Parted Casing ai l 6,823' TD- 16,342' MD /PBTD -5,614' MD G -14 Actual Well Schematic 12- 20- 11.docx BCA: 12/20/11 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G - TRADING BAY UNIT G -14 ADL0018730 5073320146 AR4365 99.00 ;a*^k'k. Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Post Production Well 12/2/2011 Services Primary Wellbore Affected Wellbore UWI Well Permit Number G-14 507332014600 1680800 12/2/2011 00:00 - 12/312011 00:00 Operations Summary RU slickline and pressure test lubricator 250psi low/ 2,500psi high. RIH w/ 2.87" GR to SSSV @ 298', POOH. RIH w/ SSSV pulling tool, latch & pull SSSV. RIH with 2.30" GR and tag at 5,256', POOH. RIH with 20' x 2.25 "Dummy gun to 5200' KB, POOH. RD slickline. 12/4/2011 00:00 - 121512011 00:00 Operations Summary RU E -line, pressure test lubricator to 250psi low/ 2,500psi high. RIH with 2 -1/8" Enerjet, 6 spf, 0 degree phase guns and tie in and fire guns at 5,109' top to 5,119' bottom, POOH. 12/5/2011 00:00 - 12/6/2011 00:00 Operations Summary RU E -line, pressure test lubricator to 250psi low/ 2,500psi high. RIH and perforated from 5,099' to 5,109', 5,085' to 5,095', and 5,077' to 5,085' with 2 -1/8" v Enerjet, 6 spf, 0 degree phase. RD E -line equipment. 1216/201100:00.1211 /2011 00:00 Operations Summary RU slickline, pressure test lubricator to 250psi low/ 2,500psi high. RIH w/ AO Ball SSSV, set at 298'. RD slickline and turn well over to production. • • S MIT [E o[F ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager 0 Union Oil Company of California 1 P.O. Box 196247 ` Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit G -14 Sundry Number: 311 -312 Dear Mr. Brandenburg: x b t1N ! d Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As rovided in AS 31.05.080, within 20 days after written notice of this p � Y decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of October, 2011. Encl. • V D' s STATE OF ALASKA •�-. OCT 11 21111 ALASKA OIL AND GAS CONSERVATION COMMISSION �" o APPLICATION FOR SUNDRY APPROVALS ��a 20 AAC 25.280 Masks Oil & Ges Cons. Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Char rogram ❑ Suspend ❑ Plug Perforations ❑ Perforate El Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 . Exploratory ❑ 168 -080 3. Address Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20146 -00 1 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes ❑ No El Trading Bay Unit G -14 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0018730 [Grayling Platform] McArthur River Field/ Middle Kenai Gas and Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16,342 ' 10,593 5,269 3,816 N/A 5,269' (Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 650' 17 -3/4" 650' 649' Surface 6,495' 13 -3/8" 6,495' 4,477' 3,090psi 1,540psi Intermediate Production 13,521' 9 -5/8" 13,521' 8,721 5,750psi 3,090psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3,838- 3,844; 4,076- 4,080; 3,038- 3,041; 3,165- 3,167; 4,135- 4,138; 4,295- 4,304; 3,196- 3,198; 3,282- 3,287; 4,340- 4,350; 4,444 - 4,454; 3,307- 3,312; 3,363- 3,368; 3 -1/2" 9.2 #/ N -80 4,920 4,715 - 4,725; 4,820 - 4,830; 3,509- 3,515; 3,567- 3,573; 5,254 -5,269 3,807 -3,816 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Brown H -2 Hyd. Pkr, (2) Packer and N/A 3,746'(MD)2,989(TVD)/4, 922( MD) 3,623(TVD),4,950(MD) /3,639(TVD) and N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/24/2011 Oil ❑ Gas El WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Billy Applewhite Phone: 263 -7671 Printed Name Timothy C. Brandenburg Title Drilling Manager ry Signature - ' . ..~ .=" , Phone 276 -7600 Date 10/6/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1. 30 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: S v., I t. `vN, , k-c.S \_S c,._S b ESL.... \0 \4„. v v.° , ,o rf 1 Subsequent Form Required: APPROVED BY Approved by 'o OMMIS : r R THE COMMISSION Date: 0 2 '' /Z-( / / / -- iL1 /l • Chevron • Grg Platform IN Well G-14 Actual Revised 9/19/11 RKB = 38.11'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm i 1 17 -3/4" Surf Csg Spiral BTC 15.12 Surf 650" 13 -3/8" Csg 61 J -55 12.52 Surf 6,495' A 9 -5/8" csg is parted at 6,823' 1 9 - 5/8" Prod Csg 40, 43 5, 47 P110/N -80 BTC Surf I 13,521' B Tubing 3 -1/2" Short String 9.2 N -80 Surf 3,785' 2 3 -1/2" Long String 9.2 N -80 Surf 4,989' C Long String 0 1 alaimIti NO Depth ID Item 3 1 298' 3 -1/2" Otis ball valve nipple 2 3,713' 3 -1/2" Otis XA sleeve 3 3,746' Brown H -2 Hyd. Packer 3a 3,816' 3" 4 -1/4" OD Baker Blast Joint E 3b 4,068' 3" 4 -1/4" OD Baker Blast Joint 3a 3c 4,135' 3" 4 -1/4" OD Baker Blast Joint 8.1 pert = 3b 3d 4,286' 3" 4 -1/4" OD Baker Blast Joint II 3e 4,336' 3" 4 -1/4" OD Baker Blast Joint 3c 3f 4,435' 3" 4 -1/4" OD Baker Blast Joint ai 0 - pert c 3d 3g 4,708' 3" 4 -1/4" OD Baker Blast Joint I 3h 4,809' 3" 4 -1/4" OD Baker Blast Joint 3e 4 4,881' 3 -1/2" Otis XA Sleeve B pert 3f 5 4,920' 3 -1/2" Baker locator sub li 6 4,921'- 4,930' 3 -1/2" Baker Seal Assy 39 7 4,922' Packer li 3h 8 4,935' 3 -1/2" Otis XA Sleeve 9 4,944' 3 -1/2" Baker locator sub II 84 pert = 10 4,946'- 4,956' 3 -1/2" Baker Seal Assy ' 4 BakerSeal asst' 11 4,950' Packer 5 6 4921'4930 12 4,988' 3 -1/2" Otis Q nipple 1,#1 # 1 7 13 4,989' 3 -1/2" Baker mule shoe _ _ 1 " 8 Short String 9 o Bakerse Q. Depth ID Item Lt( 1 49464966 A 257' 3 -1/2" Otis ball valve nipple 1 B 3,680' 3 -1/2" Otis XA sleeve C 3,744' Brown right hand coupling D 3,746' Brown H -2 Hyd. Packer E 3,785' 3 -1/2" Otis Q nipple 12 NO. Depth Item R IV 5,600' Junk retainers 13 V 5,614' EZSV retainer VI 6,737' EZSV retainer PERFORATION DATA Zone Top Btm Perf Date Present Notes Condition B -1 3,838' 3,844' 7/3/74 OPEN Top of fill ia 5269' B -1 4,076' 4,080' 7/7/74 OPEN C -1 Pert ** `-t+t ` B -1 4,135' 4,138' 7/7/74 OPEN t w , B - 4,295' 4,305' 7/7/74 OPEN C a - , '.f , 1 , ,, r 44 y -# IV B - 4,340' 4.350' 7/7/74 v 4,444' 4,454' 7/7/74 OPEN ® B - 4,715' 4,725' 7/7 /74 OPEN t a# 1A B - 4,820' 4,830' 7/7/74 aid `�ya: ¢ C - 5,254' 5,274' 7/7/74 OPEN '/. covered with fill I. i': -_ C - 2 5,500' 5,510' 7/7/74 OPEN Covered with fin J Vi Parted Casing 6,823' q ,' 4 . tall e.< TO = 16,342' MD /PBTD= 5,614' MD G -14 Current Well Schematic 9- 19- 11.docx BCA: 9/20/11 Chevron • Grg Platform iiiitt. Proposed Well - # G -14 Revised 9/19/11 RKB = 38.11'Rig Floor to TBG Head Casing & Tubing Size Type Wt Grade Thrd ID Top Btm I 17 -3/4" Surf Csg Spiral BTC 15.12 Surf 650' 13 -3/8" Csg 61 J -55 12.52 Surf 6,495' A 9 -5 /8" csg is parted at 6,823' 1 9 -5/8" Prod Csg 40, 43.5, 47 P110/N 80 BTC Surf I 13,521' B Tubing 3 -1/2" Short String 9.2 N -80 Surf 3,785' C , 2 3 - 1/2" Long String 9.2 N -80 Surf 4,989' Long String D 1 M I Mt t NO. Depth ID Item 3 1 298' 3 -1/2" Otis ball valve nipple 2 3,713' 3 -1/2" Otis XA sleeve 3 3,746' Brown H -2 Hyd. Packer 3a 3,816' 3" 4 -1/4" OD Baker Blast Joint E 3b 4,068' 3" 4 -1/4" OD Baker Blast Joint 3a 3c 4,135' 3" 4 -1/4" OD Baker Blast Joint e - pert 3b 3d 4,286' 3" 4 -1/4" OD Baker Blast Joint i 3e 4,336' 3" 4 -1/4" OD Baker Blast Joint 3c 3f 4,435' 3" 4 -1/4" OD Baker Blast Joint 8.2 pert gd 3g 4,708' 3" 4 -1/4" OD Baker Blast Joint 3h 4,809 3" 4 -1/4" OD Baker Blast Joint 3e 4 4,881 3 -1/2" Otis XA Sleeve 8 pert 3f 5 4,920' 3 -1/2" Baker locator sub III 6 4,921'- 4,930' 3 -1/2" Baker Seal Assy 3 g 7 4,922 Packer II 3h 8 4,935' 3 -1/2" Otis XA Sleeve 9 4,944' 3 -1/2" Baker locator sub B t peg 10 4,946'- 4,956' 3 -1/2" Baker Seal Assy "' 4 ■ BakerSeal assy 11 4,950' Packer 5 6 4921'-4930 12 4,988' 3 -1/2" Otis Q nipple It1 I 7 13 4,989' 3 -1/2" Baker mule shoe =_ _IE_ ■ " 8 Short String a. 9 o e a ke rseal assy NO. Depth ID Item 1 " _ 1 *' I 1 4946' - 4.956' A 257' 3 -1/2" Otis ball valve nipple - i 1 B 3,680' 3 -1/2" Otis XA sleeve C 3,744' Brown right hand coupling D 3,746' Brown H -2 Hyd. Packer E 3,785' 3 -1/2" Otis Q nipple 12 NO Depth Item 1 IV 5,600' Junk retainers 13 V 5,614' EZSV retainer "" VI 6,737' EZSV retainer BB pert proposed PERFORATION DATA Zone Top Btm Perf Present Notes Date Condition B - 3,838' 3,844' 7/3/74 OPEN Top of fill @ 6269' B -1 4,076' 4,080' 7/7/74 OPEN C -1 pert s ar a . p B - 4,135' 4,138' 7/7/74 OPEN 1' ''''',.''..1-1,.', B -2 4,295' 4,305' 7/7/74 OPEN C - 2 pert [a G`, ti , " ' ' IV B -2 4,340' 4.350' 7/7/74 OPEN V B -2 4,444' 4,454' 7/7/74 OPEN t "' B - 4,715' 4,725' 7/7/74 OPEN a .".11 I., y pr ` < B - 4,820' 4,830' 7/7/74 OPEN B - +/- 5,076' +/-5,096' Proposed 44-4,.. B - 8 B - +/.5,099' +/- 5,119' Proposed ✓ y VI C -1 5,254' 5,274' 7/7/74 OPEN '/. covered with fie 4g 3 C -2 5,500' 5,510' 7/7/74 OPEN Covered with fill t4PC • .* Parted Casing t- 6,823' • 4 *+s 4.,.„- -:„ - . .w Y'] n Y TD- 16,342' MD /PBTD-6,614' MD G -14 Proposed Well Schematic 9- 19- 11.docx BCA: 9/20/11 5 Chevron • Trading Bay Unit to. Well # G -14 10 /5 /11 OBJECTIVES: • Add the B8 zone Current BHP: 132 psi @ 3,882' TVD Max Downhole Pressure: 550 psi @ 3,775' TVD (Based on offset well information) MASP: 506 psi (Based on a pressure gradient of 0.0116 psi/ ft TVD) PROCEDURE SUMMARY: 1. RU Slickline. Pressure test lubricator 250psi low /2,500psi high. 2. RIH with gauge ring and tag fill at ( + / -) 5,269'. 3. RIH with dummy gun to ( + / -) 5,150'. 4. Rig down slickline. 5. RU Eline. Pressure test lubricator 250psi low /2,500psi high. 6. Perforate the B8 sand from +/- 5,099' to +/- 5,119' and from +/- 5,076' to +/- 5,096'. 7. Rig down E -line. 8. Turn well over to production. Unoc.~i Nor-~l Amc Oil & Gas Division Te~e0none ~90~ 2TS-76GQ AlasKa Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. A/~chorage, Al{ 99504 At,n: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor, but I hope this will meet your needs. Yours very truly, Regional Drilling Manager GSB/lew GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR LEG //3: LAT = 60050' 22.569" LONG --151 °36' 46.519" "Y" COORD. "X" COORD. WELL # FSL 2,502,352.30 212,272.70 1804 1 2 3 4 5 6 7 8 9 l0 ll 12 2,502,346.65 2,502,350.14 2,502,354.64 2,502,358.05 2,502,358.77 2,502,356.46 2,502,352.20 2,502,347.99 2,502,345.80 2,502,350.83~ 2,502,354.60 2,502,351.47 212,269.32 212,266.48 212,266.55 212,269.49 212,273.94' 212,277.80 212,279.28 212,277.68 212,273.75 212,2'70.89 212,272.33 212,274.88 FEL ,,, , LEG #4: LAT = 60°50' 22.832" LONG =151°36' 48.042" 2,502,380.80 212,197.90 1409 13 14 15 16 17 18 19 20 21 22 23 24 LEG #l: LAT : 60o50, 23.575" LONG =151°36' 47.505" LEG #2: LAT: 60050, 23.313" LONG =151°36, 45.982" 2,502,374.34 2,502,376.65 2,502,380.90 2,502,385.11 2,502,387.30 2,502,386.45 2,502,382.96 2,502,378.46 2,502,375.05 2,502,378.50 2,502,381.63 2,502,382.27 2,502,455.60 2,5O2,427. l0 G-22 1789 1413 G-21 1802 1415 G-26 1806 1415 G-25 1810 1412 G-24 1810 1408 G-20 1808 1404 1804 1402 G-36 1800 lq04 G-34 & RD 1798 1408 G-23 & RD 1803 1411 G-33 1806 1409 G-27 & 28 1803 1407 1831 1486 212,196.66 G-14A 1825 1487 212,192.79 G-19 1827 1491 212,191.32 G-13 1831 1493 212,192.92 G-15 1835 1491 212,196.85 G-5 1838 1487 212,201.28 1837 1483 212,204.12 G-3 1833 1480 212,204.05 G-2 1829 1480 212,201.11 G-11 1825 1486 212,198.27 G-lO 1829 1483 212,195.72 G-17 & RD 1832 1488 212,199.71 G-7 1832 1484 1906 1880 37 38 39 40 41 42 43 44 45 46 47 48 2,502,421.45 2,502.,424.94 2.502,429.45 2,502,432.85 2,502,433.57 2,502,431.26 2.502,427.00. 212,226.40 (Reserved for Compressors) G-12, RD & 2 1874 G-31 1878 G-4 1882 G-1 1886 G-9 1886 G-18 1884 G-14 1880 G-30 1876 G-8 & RD 1874 G-6 1879 G-32 1BB2 G-16 1879 212,301.20 212,297.82 212,294.98 212,295.05 212,297.99 212,302.44 212,306.31 212,307.78 2,502,422.80 212,306.18 2~'502,420.60 ............. 2'12',302.25 2,502,425.63 212,299.39 2,502,429 40 212,300.83 2,502,426.27 212,'303.38 1458 1383 1386 1 389 1389 1 386 1382 1378 1376 .... 1378 ....... 1 382 1385 1383 1381 10 / : ,o 3. oo, ' 1.orm No. P-.4 I%EV'. ~,- 1-70 STATE oF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMrT IN DUPLICATE MONTHLY REPORT O'F :DRILLING AND WORKOVER OPERATIONS OIL ~ GA8 WKLL WELL [] NAME OF OPIgRATOR OTHER UNION OIL COMPANY OF CALIFORNIA 3. ADDI~F-~'OF OP.~.&TOR ...... 909 West 9th Avenue~ Anchorage, Alaska '4'."~)CA'nON O~ w~,- ' ..... 99501 Conductor #43; Leg #2, 1880'N & 1576'W from the SE corner. Section 29: TgN, RI$%~, S. M. - 13. REPORT ToTA~ DIPPS' AT E/XlD OF MONTini, CFL~NGES IN HOLE SIZE, CASING AlqT) CEME2gTING 50-133-20146 ~ 'LE~S~ESIGNATION A.X'D SERIAL NO. ADL-18730 7 IF INDIA~, ALOT1EE OR TRIBE NAME 8. L,~IT.FARM OR LEASE NAME Trading Bay Unit 9 WELL NO State G-14 10.' FLE~"A_ND POOL. OR WILDCAT _ McArthur River Field-Hemlock I1. SI~.C., T., R., 1~{.. (BO~POM HOL~ omd~-rrv~ Section 34: T9N, R13W, S. M. 12. PERMIT NO, '68-80 JOBS INCLUDING DEPTH SET AND VOLUM'E'S USED, PEP,,FORATIONS, TESTS AND RESULTS FISHING JOB~ JU'~TK LN HOLE A.ND SIDE-TRACKED HOLE A. lXrD AJaY OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Commenced operations onWell G-14 to convert to a Dual 'q~' & "C" Zone gas producer @ 12:01 am, 6/22/74. Operations for the month of July up to completion are as follows: Stabbed into ret. @ 4470' & cmtd. 9 5/8"~13 3/8" annulus w/ 175 sx. "G" cmt. Ran 8 1/2" bit & CO to 4250'. Ran 9 5/8" RTrS tool & set @ 3730' Had communications up 9 5/8"-13 3/8" annulus between perfs @ 3940' to 3950' & pgrfs @ 3650' to 3660'. Set ret. @ 3910' & cmtd. 9 5/8"-13 3/8" annulus w/ 150 sx. "G" cmt. RIHw/ 8 1/2" bit to 3850'. RIH w/ RTTS & set @ 3558' Squeezed perfs from 3650' to 3660' w/ 100 sx. "G" cmt, Pooh w/ 9 5/8" RTTS[ RIHw/ 8 1/2" bit. CO to 3895'. Circ. ~ cond. mud. Pooh. Perf.. the A-5 Sand from 3834' to 3844' @ 4 hpf. RIHw/ DST tool & set @ 3727' w/ tail @ 3748' to test the A-5 Sand. Press. dry DP to 1000 psi w/ platform gas. Opened tool @ 9:30 pm, 7/3/74w/ 1000 psi. Press. increased to 1190 psi in 10 mins. Flowed well for 44 mins. initial flow period. Well flowed gas & rat hole fluid. Closed in tool @ 10:25 pm, for 1 hr. & 28 mins. initial SI press. Reopened DST tool for final flow period @ 12:00 pm, ates 5 FLOW Am .rF/ 1 hr'. 1200240UPsi Stabil~zd" iatc~ 2 hrs. 400 psi %93 ~ i ~ i974 ' 2 hrs. 600 psi 7.96 ~ 1 hr. 800 psi 7.63 DI¥ISION 0IL AND 1 hr. 1000 psi 6.23 ~ggA~ Closed tool @ 7:00 am, 7/4/74 for 3 hrs. final SI press. Released DST pkr. Rev. out. Pooh. RIH w/ 8 1/2" bit ~ CO to 5607'. RIH w/ 9 5/8" RTrs & tested squeezed perfs to 500 psi diff. Form No, P--4 REV. STATE OF ALASKA SUBMrr m 'nU'.LICA"m OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS I._. WELL WELL OTHER ~. NA~r OF O~rR~TO~ 3. ADDRESS OF' O~ERATOR 4. LOCATION OF w~ % APl NU~ERICAL CODE 6 LEASE DESIGI~ATION AND SEHIAL NO. IF INDIA~. ALOTT'EE OR TRIBE NAME 8. L~.'IT F.~M OR LEASE NAME 9 w~LL NO 10 FIELD A-ND POOL, OR WILDCAT I*~ SEC, T.. R.. M. (BOTTOM HOLE os,r~'~ 1~-. PJ~LMIT N'O 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/ND VOLLrlVIES USED, PgP~FO'RATIONS, TESTS A/ND RESULTS FISHING JOB~ JLq~K IN HOLE AND SIDE-TRACKED HOLE A~ND ANY OTHER SIGNIFICANT CHJkNGF,$ IN HOL~ CONDITIONS TBUS G-14 Cont... Ran dual 3 1/2" tbg. string. Stabbed into perm. pkr. @ 4922'. Tested 500 psi. Spaced out & landed tbg. Set dual hyd. pkr. @ 3746' & tested to 500 psi. Installed BPV' s. Removed BOPE. Installed & tested x-mas tree. Displ. tbg. & mmulus w/ inhibited pkr. fluid. Displ. tbg. strings w/ 1100 psi gas. REL_E~_~D RIG,. @,,, 1,,2:00 Noon.:,.,, 7/1.,6/,7,4. ,, ~ / ~a mt ~~nu~- __ · · N~--Rt~ort on ~is f~ il required ~r ~ cQllfldQr Jth% [tJQrdllll ~ the ltOt~ Ot OplrOt~, Grid must ~ filed in dupli~le with the oil and gas co~ervatbn commiflfl bythe 15~ of the suec~ding ~n~, ~le~ otherwise dwected. Doc, !jnt Transmittal Union ,!Company of Cai: ia unlen DATE SUBMITTED ACCOUNTING MONTH 8/.5y74 TO FROM Ho W. Kugler J. Ao Packard ATO il & Gas Division State of Alaska 3001 Porcusine Drive Anchorage ........ Anchorage, AK 99504 TELEPHONE "O. TRANSMITTING THE FOLLOWING: ,. ,,, TBU, G-l,4 .... 2" 5" Comp° Neutron-Fm. Density Run 1 6/22 /74 1 Sepia and 1 BL · · : ,, · . . . · .. Please acknowledge receipt k)y signin,~ and returning :one coPy of this do,;ument tr~nsmi':tal. DATE' /2 / FORM 369 (REV 2/70) PRINTED IN U.S.A. REV. 1-10-73 Submit "Intentions" in Triplicate "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) 5, APl NUMERICAL CODE 50-155-20146 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME O,L F1 GAS i-F! WELL L---J WELL LJ.~ OTHER Z----kN~M.,E OF OPERATOR 3. ADDRESS OF oPER~..~ 909 West 9th Avemze~.....Am..chorap;e., A].aska 99501 4. LOCATION OF WELL At su trace Conductor #4~, Leg #2, 1880'N & 1376'$¥' from the SE corner. Sectio~: 29. T9N, P23 1',], S. ~,{. 13. ELEVA'FIONS (Show whether DF, RT, GR, etc.) 99RT above 14. Check App,'opriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME Trading7_,:, Ba? bSa. it 9. WELL NO. State G-14. iO. FIELD AND POOL, OR'WILDCAT ~dcArtl}ur ~,iver ~ield-~-e. nlocJ<~ 11o SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 34' 12. PERMIT NO. 68-80 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I FRACTURE TREAT SHOOT OR ACIDIZE L~ REPAIR WELL (Other) PULL OR ALTER CASING ! ! MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF F~ REPAIRING WELL F~ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) '*See ~eJ. ow, (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. eTo convert to a Dual "B" & "C" Zone gas pro&~cer. - · 1. Rigged up over well. 2. CO 9 5/8" csg. to ETD @ 6393'. 3. Displ. mud in wellbore ~/ 76#/cu. ft. KCL salt wtr. workover fluid. 4. Ran CNL-FDC-GR & CBL Logs. 5. Squeezed for zone 'isolation above "B" Zone Sands, between "B" Zone & "C" Zone Sand & below "C" Zone Sands. 6. Perforated the A-S Sm~d from 3834' to 3844' & DST. 7. Perforated the "B" Zone Sand B-i, B-2, B-3 as shmm below: SAND INTERVAL FOOTAGE ~ 4076-'7 40-8-6 ' --T0x-- B-1 4138' -4148 ' 10' B-2 ~295'-4305' 10' B-2 4340' -4350' 10' B-2 4444' -4454' 10' B-3 4715'-4725' 10' B-4 4820'-4830' 10' C-1 5254' -5274' 20' ~.-?. 5500'-55] fl' 10' Form ~ 0-403 I~EV. 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION.FOR PERMtT-J' for such proposals.) 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. 1. OIL r'"'"l GAS F'"I 7. if INDIAN, ALLOTTEE OR TRIBE NAME .. WELL WELL L.-.J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME ~ ADDRESS OFOPERATOR 9, WELL NO. 10, FIELD AND POOl, OR WILDCAT 4. LOCATION OF WELL At surface ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ FRACTURE TREAT Il. _ . SHOOT OR ACIDIZE ~ I 1 REPAIR WELL _ _ PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~] REPAIRING WELL FRACTtJRE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING i ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. TBUS G-14 Cont... 8~ 10. t)erforated the. C-1 & C-2 Sand as sho~m on pg. 1. Run dual 2 7/8" tbg. string & accessories w/ a single perm. pkr. between the "B" & "C" Zone Sands & a dual pkr. above the B-1 Sand. Put. well on production test. 16. I hereby/certify that the f. otegc~tng is true and correct [ i /// / -.~,, t ., ' ~' /, i// District Drlg, Ft~t. DATE- 8/10/74.' (ThiS~'Pace for State office use) API~VED BM · .. CONDr~ION5 OF APPROVAL, IF ANY: ) TITLE See Instructions On Re ~ese ' ~ ' ---- ' l~zrm No. P--4 REV. STATE O,"~LASKA OIL AND GAS CONSERVATION COAAAAITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT lin DUPLICATE ~'ELL ~*ELL OTHEI~ 2. NAME OF OP~I~,ATOR UNION 0IL COMPANY OF CALIFORNIA 3. ADDRESS OF OP~ATOR 909 West 9th Avenue~ Anchorage, Alaska 4. LOCATION OF WELL 99501 Conductor #45, Leg #2, 1880'N ~ 1376'W from the SE corner. Section 29: TgN, R13W, S. M. 50-153-20146 LEASE DESIGNATION AND SEI~IAL NO. ADL - 18730 IF INDIA]~, ALOI'¥~E OR TRIBE NAME 8. L~.'IT F.~ OR LEASE NA341E Trading Bay Unit 9 w~ NO State G-14 10 FLFJ~D AND POOL, OR %VILDCAT McArthur River Field-Hemlock l~ s~c~ T.. R., X~. (~O~O~ HOn~ Section 54- TgN, R13W, S. M. , 68-80 REPORT'"'~OTAL DKP%~H AT END OF MONT/-I, CPL~NGES IN HOLE SIZE. CASING AN'D CEI%IF2~TI~G jobs iNCLUDING DEPTH SET AIW-D VOLUM~ USED, PEI~FORATIONS. T-F~STS A/W/) PdgSULTS FISHING JOINS JU/~K l/~ HOl2g AND $IDE-/q~ACKED HOLE A2qD A. ATY O'I~rIER SIGNIFICANT C}{.AN~ IN HOI~ CON-DITIONS Commenced operations on well G-14 to convert to a Dual "B" ~ "C" Zone gas producer @ 12:01 am, 6/22/74. Removed x-mas tree. Installed ~ tested BOPH to UOC0 specs. RIHw/ 8 1/2" bit ~ 9 5/8" csg. scraper to 6393'~TD. iDisplaced mud in wellborew/ W0 fluid. Ran CNL-FDC-GR Log from 6593' to 3000', Perforated 9 5/8" csg. w/ 1 5/8" csg. puncher from 5688' to 5692' and from 5596' to 5400'. Unable to establish circ. in 9 5/8" X 13 5/8" annulus. RIHw/ 4" csg. gun ~ perf. from 5688' to 5698'. RIHw/ cmt. ret. Tool hung up @ 5686' ~ set while logging collars. RIHw/ 4" csg. gun ~ perf. from 5685' to 5675'. Ran ~ set cmt. ret. @ 5614' Squeezed for zone isolation w/ 650 sx. Class "G" cmt. in two stages. RIH ~/ 4"csg. gun ~ perf. for zone isolation between the B-4 Sand and the C-1 Sand from 5050' to 5060'. Ran ~ set cmt. ret. @ 4990'. Squeezed for zone isolatignw/ 300 sx. Class "G" cmt. RIHw/ cant. RIHw/ 4" csg. gun ~ perf. from 3940' to 5950' for zone isolation between the B-1 Sand ~ rheA-5 Sand. Ran ~ set. cmt. ret. @ 3880'. Squeezed perfs, w/ 300 sx. Class"G" cmt. RIHw/ 4" csg. gun ~ perf. from 3650' to 3660'. Ran ~ set cmt. ret, @ $600'. Squeezed perfs w/ 300 sx. Class "G" cmt. RIHw/ 8 1/2" bit ~ CO 9 5/8" csg. to 5607'. RIHw/ 9 5/8" RTTS tool ~ set @ 4639'. Had communication up 9 5/8" X 15 3/8" annulus between perfs @ 5050' to 5060' ~ perfs @ 4500' to 4510'. ,Ran ~ set cmt. ret. @ 5023'. Cmt. 9 5/8" X 13 3/8" annulus w/ 100 sx. Class "G' cmt. RIHw/ 8 1/2" bit ~ CO. to 5000'. RIH w/ RTTS tool ~ set @ 4168'. Had communication up 9 5/8" X 13 3/8" annulus between perfs @ 4500' to 4510' ~ perfs @ 3940' to 3950'. Set cmt. ret. @ 4470'. Now: Prep. to cmt. 9 5/8" X 13 3/8" annulus between perfs @ 3940' to 5950' ~ perfs @ 4500' to 4510'. NOTE -- Report on ~is f~ is required ~r ~ calendar ~thl regardMss ~ [he ,tat~ of ope~t~, and must ~ filed in dupliffite with the oil and gas co~ervatbn commiflfl bythe 15~ of the succ~4ing mn~, ~le~ otherwise dirscted. Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL [~ GAS D OTHER WELL I~ WELL 2, NAME OF OPERATOR UNION 0IL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL Atsurface Conductor #45, Leg #2: 1880'N ~ 1376'W from SE corneT. Section 29: TgN, R15W, S. M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 99'RT above MSL. 14. CheCk Appropriate Box To Indicate Nature of Notice, Re !5~ APl NUMERICAL CODE 50-135-20146, 6. LEASE DESIGNATION AND SERIAL NO. ADL-18750 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay thit 9. WELL NO. State G-14 (32-34) 10. FIELD AND POOL, OR WILDCAT HcArthur River Field-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 34: TgN, R13W, S. M. 12. PERMIT NO. 68.80 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) *See Below. PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. *To convert to a Dual "B" ~ "C" Zone gas producer. PLAN OF PROCEDURe: 1. Rig up over well. 2. CO 9 5/8" csg. to ETD @ 6393' 5. Displace mud in wellbore w/ 7~#/cu. ft. KCL salt water workover fluid. 4. Run CNL-FDC-GR { CBL Logs. 5. Squeeze for zone isolation above "B" Zone Sands, between "B" Zone & "C" Zone Sand below "C" Zone Sands. 6. Perforate "B" Zone Sands BI, B2, B5 ~ B4 as determined from logs. 7. Run dual 2 7/8" tubing string ~ accessories w/ a single permanent packer between the , Sands and a "B" ~ '~' Zone Sands a dual packer between the B2 ~ B5 dual packer above the B1 Sand. ~ 8. Thru tubing perforate the C1 ~ C2 Sands as determined from log ~ '~' g 0 ~q t~ 9. Put well on production test. ESTIb~T~D OPERATION TI~E' Twelve (12) Days .~',. ..... ...... _ .... · · "" '..;~u tq CF O;~ AND 16. I hereby certify that the foregoing is true and correct SIGNE D. on DATE 5/6/74 (This space for State office use) APPROVEDBY ~~ ~- CONDITIONS OF~PRb-VA~', iF AN';': - TITLE~ DATE See Instructions On Reverse Side 5-/7 APproved Retur.n~e~d~ CONSERVATION ORDER NO. 80 Page 2 September 30, 1969 Township 8 North, Range 14 West, Seward Meridian Section l' All Section 12' E~, NW¼ Township 9 North, Range 13 West, Seward Meridian Secti on 9: S½ Section 14: SW¼ Sections 15 through 17: All Section 18: S½ Sections 19 through 22: All Section 23: W½ Section 26: W½ Sections 27 through 34: All Sect i on 35: NW~ Township 9 North, Range 14 West, Seward Meridian Section 24' E½ Section 25' E½ Section 36' NE¼ Rule 1. Definition of Pools. (a) The McArthur River Hemlock Oil Pool is defined as the accumulation of oil common to and which co--th the accumulation found in the Union Grayling No. lA well between the depths of 9,372 feet and ~27~__9~)9 9,897 feet. (b) The McArthur River Mid e K_enai Gas Pool is defined as the accumu- lation of gas common to and which correlates with the accumulation found in the Union Trading Bay Unit No. G-18 well between the depths of 5,360 feet and 6,010 feet. (c) The McArthur River Middle Kenai "G" Oil Pool is defined as the accumulation of oil common to and which corr'~lates with the accumu- lation found in the Union Oil Company of California Trading Bay Unit State No. G-7 well between the drilled depths of 9,116 feet and 9,695 feet. (d) The McArthur River West ~d Oil Pool is defined as- the accumulation of oil comm~ and which correlates with the accumu- lation found in the Union Oil Company of California Trading Bay Unit State No. G-7 well between the drilled depths of 10,208 feet and l l, 208 feet. Form P~3 BEV. 9.3~-67 STATE d,F ALASKA i Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION; ,COMMIT'TEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this fora for proposals to drill or to deepen or plug back to a dif£ierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) '5. AP1 N~CAL CODE ' 50-133-201~6 6. LEASE DESIGNATION A_]~D SERIAL NO. ADL 18730 2. NAME OF ~ OPERATOR ~_._.~a 0il Comlmn 3. ADDRESS OF OPERATOR 507 I/. Horthern Li~hts Blvd., Anchor&se. Ak. 99503 4. LOCATION 0'F WELL 7; IF INDIA.N, ALLO'r'ri!~ OR TRIBE NAM~ 8. UNIT, FARA~I OR LEA. SE NAME Tradin~ Bay Unit 9. ,W.~/~L NO. -- Sf~a~e ~-l& (32-34) " i0. F~ ~D POOL, O~ corner Section 29, TgH, RI3W, Slt. il. SEC.;'T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVAtiONS (Show whether DF, RT, OR, etc. 99" aT above HSL. I ,-68-8o 14. Check Appropriate Box To I,n,d',ica*e Nlature o~ NOti'ce, Report, or. Other. Date NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I [ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI.ETE --_ . SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ...Seat, 34, TgH, Ri3W, SI(. 12. ~,~[][T l%TO. SUBSEQUENT REPORT OF: WATER 8ItUT-OFF REPAIRING WEI~L FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONME~T* (Other) NOTE: .Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 1~. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 5116/69= 5/17/69= 51L01697 5/22169: Hove rtz to Conductor #43, Leg #2, TaU Stutr, e G-l$. Circulate'& kill vel1 v/85# smd. Pull & lay dovn 4-1/2" tbs, RI with 8-1/2" bit & d.'p. CleaUml~ coal frma 66x2' - 6870'. ci~c clean, goal runnins,badly. PC)H, Ran SehXunborger Ga, ma-h7 leutronLos 6800' - 1000'. Set El; drill bridse plus on wire line @ 6600'. l~essure teat above plus to 155o', - oK. shot '4-X/2" holes in 9=S/S"' ess S 6525'. ha Sqz mid 9-5/8" cog th~u holee @ 6525' v/2500 sx Clue "Gu mC in 7 eta,ce. Kal s~~ pr~~e 20~. ~a v/~z ~. ~ '~h 8-~/2" b~, ~ ~op ~t e 63~'. ~ out ~t 6334' - 6590', vo~ rrm 65~' to BP 9 6600'. ~~ ~ ~ S~6600'. GO b~ up~E esi s~ub aXo~ eide of l~ esi s~t~ fern 6823* - 7154~, Bit ~~ up 0 this ~t. ~R, RX v/~p i ~ e 7145~. Plugged o~ ~1e v/4~ ~ "G" ut. ~X~ up Co 6859' i e~e~at~ eX~.. ~~er~ , Form REV. 9-30-67 ~hbmit "Intentions" in Triplicate & "Subsequent Reports" in l~uplicate STATE O'F ALASKA OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS ON WELl.5 (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER1VIIT~" for such proposals.) 0IL ~-~ OAS ~--] WELL WELL OTHER 2. NAME OF OPERATOR ~on~ ,OLI Cm~pauy 3. ADDRESS OF OPERATOR 4. LOCATION O,F WELL At surface ELEVATIONS (Show whether DF, RT, GR, etc. ) page ~. API NUIVIERICAL CODE 6. LEASE DESIGNATION AJ~D SERIAL NO. 7. IF I~I~, ~O~ OR ~IBE 8.. UNIT, F~ OR ~SE N~E T~~ hy ~tt $~te 9. ~L NO. 10~ F~ ~ ~O~, O~ ~1. SEC., T., B., M., (BOT~ O~E~IVE) [2. P~T ~O. ~s0 14. Check Appropriate Box To I~ncl:i'cate Niat'ure of N~oti'ce, Report,~ or 'Other 'Data NOTICE OF INTENTION TO: TEST WATER BHUT-0FF ~ PULL OR ALTER CASING · ·. SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL ~ FRACTURE TREAT I--I MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASINO SHOOT OR ACIDIZE X ABANDONS SHOOTING OR ACIDIZINO ABANDONMENTs REPAIR WELL CHANGE PLANS (Other) (Other) (NOTE: Report 'results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertineut details, and give pertinent dates, including estimated date of starting any proposed work. . c~ 8=o0 p.u. 5123/69. "&'" ant d'p,,, lh~le GU eb~ hud w/§O00~, abandoned 6:00 a.m'. JUN 1 115E9 D!VI~dON OF Ott AND OA~ A/i 16. I hereby cer~y t~e fo~l~g~ln~As ~rue_ and eorre~ BIG~D !.I V kB;~. ~) DATE (ThiB Bpace for ~; ' %~ ' '~ App~val on co~ttton that the top of the 9 5/8" casing wt11 be plugg~ wtth at least 50 feet of c~nt and capp~ ~f~n~~~~ts~ ~e platfom. Approved Copy Returned Union O~1 Compan aliforn~a 507 W. Northern ~-,!~bi.~ Blvd., Anchorage. Alaska 99503 Telephone (907) 277-i401 May. 20, 1969 Hr. Homer Burrell, Director Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99S04 Dear Mr. Burrell: Attached per your request find tw3. c_q_opies of Directional Survey for Trading Bay Unit G-18 and TB ~G-~along with corrected copy of Form P-7, Well Completion Report, TBU G-17. Very t;ruiy yours, Distric~ Drii~ing Superintendent BET :mg 1 Enclosures 21 i%9 DIVISION Of O:L AND GAS ANC~,G~ ® G-14 Abandonment (cont.) Present Status of Well 17-3/4" C 600' 13-3/8" C 6493' * 9-5/8" C 13521' 7" liner cmt 13275' - 16166' w/ETD 16114' * Baker 7" model "F,' pkr set @ 15135' with 3-1/2" & 4-1/2" tubing s~abbed into pkr Perfs: 7" liner perfed 15226' - 15248' 15272' - 15292' 15294' - 15326' *a). 9-5/8" casing is parted @ 6823'. Lower section milled or partial milled out 6823' - 6838'. b). 4-1/2" tbg cut & pulled from 6821'. Tubing collapsed & milled (or partially milled) 6821' - 6838'. c). Open hole cavity 6823' - 6838' contains a coal section which sloughs & runs & has created an extreme washed out condition. Lower csg section is laYing in washed out Cavity out of reach making re-entry impossible. d). Hemlock Zone perfsi'15226' - 15326' are open - W/wellbore full of mud & oil. Hole aboVe 6838'. full' of 85# mud. Proposed Abandonment Procedure 1. Move over Conductor #43, Leg #2, well G-14. 2. Circ clean w/mud (85#). Remove tree & install BOE. 3. Pull tbg (presently hung open ended @ 6716'). Clean out to 6823' (base of upper 9-5/8" csg section). 4. Perforate four (4) 1/2" holes @ 6525' (Below base of 13-3/8" csg). Set EZE drill BP @ 6600' +-. 5. Squeeze cement 9-5/8" csg thru perfs @ 6525' to eliminate pressure communication or fluid movement from above parted 9-5/8" casing. 6. Clean out cment & BP. CO thru 9-5/8" csg Stub @ 68~3' & circ clean alongside of lower 9-5/8" section. 7. Hang open end dp @ 6972' +- & plug w/300 sx +- cmt. Circ clean @ 6823'. 8. Set cmt retainer in 9-5/8" csg @ 6750' +-. Sqz cmt open hole cavity below 9-5/8" stub @ 6823' to eliminate pressure communication or fluid movement from below parted casing. 9. Lay cmt plug above retainer 6750' - 6400' +-. 10. Leave casing full of mud. Remove BOE. Install 10" 5000# flange on top of tubing head tapped w/2" full opening valve. 11. Suspend well. Move rig. Estimated Abandonment Date: Start - 5/14/69 RECEIVED 1 3 !9 Form 1~3 ( & "Subsequent Repom" m gup!i~te OKG ~ STATE O'F ALASKA KL¥ .___.,z~-~--. OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS O,N WELLS (Do riot use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 0I'L [] OAS [] WELL WELL OTHER 2. NAME OF OPERATOR Union 0il,Companyof California 3. ADDRESS OF OPERATOR 507 W. Northern-Lights Blvd., Anchorage, Alaska 99503 4. LO:CATIO~ O~ WELL ltsur£ace Conductor #43, Leg #2, 1880'N & 1376'W of SE corner Section 29, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT above MSL ~4. Check Appropriate Box To I~nd:i,cate Nlature of NOti'Ce, Re -~. API NUMiiIRICAL CODE HWK ~ 50-133-20146 6. LEASE DESIGNATION ~ SER~ NO. - ADL 18730 --- FI~ --,,.,------~ ?. IF Ii~rDIAH, ALLOTTEE OR TRIBE NAME 8.' UNIT, FAi~NI O,R LEASE NA/%IE Trading Bay Unit,~ 9. WELL NO. State G-14 (32-34) 10.FIELD ~ PooL, OR WILDCAT Mc. Arthur River - Hemlock 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) sec. 34, T9N, RlgW, SM. 12. PER/V~T NO. 68-80 ~ort, or Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I { PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE I I ABANDONS ~EPAIR WELL ~_~ CHANGE PLANS EUBSEQUENT REPORT OF: WATER SItUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEKTs (Other) (NOT~: Report 'results of multiple completion on Well t Other) Completion or Recompletion Report and L'og form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Trading Bay Unit State G-14 (32-34) was drilled as an east flank Hemlock Zone water injection well. The well was placed on production to clean up the wellbore prior to commencing injection. While producing, the 9-5/8" casing collapsed and, parted at',,682~. Re-entry and repair was attempted unsuccessfully, and the well lost as an injector. It is proposed to squeeze cement the 9-5/8" upper casing section and squeeze cement the open hole cavity below the part to eliminate pressure communciation or fluid movement from within the wellbore, and abandon the lower casing section. 1 3 1969 DIVi$1ON OF OIL AND GA5 ANC~E TITLE O/st. Drlg. Supt. DATE 5/12/69 TITLE F~' ~ ' DATE See ~nstructlons On Reverse Side Approved ~op~/ Returned UNION O1L CO. OF CALIFORNIA ALASKA DISTRICT Transmittal TO: STATE OF ALASKA G. ti. Laughbaum, Jr. DATE' April 16, 1969 FROM' WELL NAME: _[JBj~gn_~__T.B_.U G-1_4_~(!4-~ 3_4~ ....... Transmitted here'with are the following- Run No. Sepia Blue Scale 2I! Induction Electrical Log Dual Induction Laterolog Bt.!C Sonic/Caliper Log BttC Sonic/Gamma Ray BHC Sonic/ Caliper/Gamma Ray Log Formation Sonic Log (Fs) Dens.ity-,Gamma Log Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) CDM or High Resolution Dipmeter CDM Safety Print CDM or Printout CD?4 or Poiywog Plot · CDM PolaF..Plots Proximit y-b!icrolog/Cal iper Log Gamma Ray-Neutron Log Gamma Ray Collar I,og Cement Bond Log Mttd 1 o g Core Descriptions, Conventional, No. Core Descriptions, Sidewall' Core' Analysis Core Chips Sample Cut Drill Stem Test Direct' ' ~.ona~ Surveys RECEIVED APR 17 1969 DIVISION OF OIL AND GAS ANCHORAGE Receipt acknowl, edged· ~.~ i~.~ Date'_~z~ .......... · Return receipt to' Union Oil Co. of California, 2805 DcnalJ, St. Anchorage, Alaska 99503 Rochelle Carlton REV. 9-90-6; * &..."$~bSe~lue't~"RFb'5'~s~' ~n'-Duplicate STATE OF ALASKA MAR 3 1969 OIL AND GAS CONSE:"¥ATIONi COMMITT, EF.,, ,~DIV? SUNDRY NOTICES AND REPORTS ON W. EL~I~ (Do not use this form for proposals ~o drill or ~o ~eepen o~ 9~g b~k ~0 a dfffie~e~t ~e~. Use "A~C~O~ ~O~ ~--" ~o~ s, uc~ 1. O,L GAS Fl WELL WELL OTHER 2. NA!VIE OF OPERATOR Union 0il Company of California ADDRESS O~ OPERATOB 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LO'CATION. O~ WELL At~urf~ Conductor 43, Leg #2, 1880'N & 1376'W of SE corner Sec. 29, T9N, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 99' RT above MSL 14. Check Appropriate Box To [n,dicate NEat'ute 'of N~otke, Re -~. API NbSFIFFJCAL CODE 50-133-20146 'b~J~, DET~IGNATION ~WD SERL~L ADL 18730 7; IF INDIA~I, ALLOTTEE OR TRIBE NA1VIE 8. UNIT FA/RA~ OR LEASE N~N~E Trdding Bay Unit: 9. WELL NO. State G-14 (32-34) I0. FIE~D ~ l~OOb, OR WILD,CAT /' McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE : OBJECTIVE) . 34, TgN, R13W~ SM. Sec 12. PEI~/ViIT NO. ~" 68-80 ~ort, or 'Other 'Data NOTICE OF INTENTION TO: EUBSEQUENT REPORT OF: TEST WATER SHUT-OFF PULL OR ALTER CASING WATER SItUT-OFF REPAIRING WELL j FRACTURE TREAT J I MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZINO ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) , (Other) Convert for water injector (NOTE: Report results of multiple completion on Well Completi?n or Recompletion Report and Log form ) 15. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including-estimated date of starting an.y proposed work, It is proposed to conduct a water injection test, TBU State G-14 (32-34), Hemlock Zone, subject to decisions rendered as a result of Conservation Order #71. PROPOSED PROCEDURE: 1. Move over conductor 43, leg 2, well G-14. 2. Through tubing perforate Hemlock water aquifer 4-1/2" hpf 15344-15458, 15484-15506, 15526-15762, 15784-16080. 3. Return well to production via gas lift, till formation fluid cleans up. 4. Kill well, pull tbg & remove all gas lift mandrels. Re-run tbg w/expansion Joints. 5. Place well on injection test. ESTIMATED STARTING DATE: March 10, 1969 16. I hereby eertify~f/the fo ue and correct sz~rmD ,, '/,/~r / l'n.~ Yaiie¥) APPROVED BY /~ ' ,~' ~' [ ~' * ~'~; ~ - ~. TITLE Dist. Drlg. Supt. DATE 2/28/69 TITLE See '~nstructions On Reverse Side l~n,a No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union Oil Company of California ADDRESS OF OPEI~ATbR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 L~DCATION (>F W~TJT. ,,,, I 50~133-20146 OKO_.. ir KLV /~ ~= / ~L 18730 HWK ~ 8. ~IT,F~ OR LEASE N~E ~ Trading Bay Unit 10. FI~ ~ND P~L. OR WILDCAT McArthur River - Hemlock II. SEC.. T., R., M.. (BOSOM HO~ O~~ Sec. 34, T9N, R13W, SM. 12. P~IT 68-80 ConduCtor 43, Leg 2, 1880' N & 1376' W from SE corner Section 29, T9N, R13W, SM. 13. REPORT TOTAL Dt~TI~ AT E/~D OF MON~, CI~IA_~'GES IN HOLE SIZE, CASING ~ CEA~EI~TING JOBS INCLUDING DEPTH SET A~q) VOLUATES USED. PF2{FO.I{ATIONS. T]~STS ~ RESULTS. FISHI/~G JO~.S, JLrfqK IN HOLE ~D SIDE,/q~ACKF2D HOLE AND /%l~Y OTHER SIGNIFICA/~T CI-IAN~ES IN I~IOI~ COBrDITIONS. T,Ih~!,NG,,,,,,,BAY UNIT STATE G-14 (~32,,,3,,4), JANUARy 1969 Pulled off Baker expansion joint, displaced diesel w/Inlet wtr. Pulled and laid down tbg. Picked up 5" d.p. & wireline spear. RI to 3243'. PO, recovered estimated 14,200' wireline.. RI w/outer barrel of expansion jt to top of lnr @ 13,275'. Unable to work outer barrel into lnr. POH. Ran rope spear to top of expansion jt @ 15, 119'. POH & recovered 150' of wireline. RI w/Baker expansion jt retrieving tool. Recovered tool & pkr. Perfd four 1/2" hpf. 15294'15272, 15248-15'226, set Baker F-1 pkr on wireline@ 15135'. Ran 3-1/2"& 4-1/2" tbg with 2-7/8" tail complete w/gas lift equipment. Stabbed into pkr @ 15135' w/tail to 15227'. Landed tbg, installed tree, and displaced hole w/diesel oil through sleeve valve @ 15092'. RIH w/shifting tools, closed sleeve., & pressure tested tbg & pkr to 1000# - OK. Prep to install gas lift valves & place well on production via gas lift. RIG RELEASED 12:00 Noon 1/6/69. 14. I hereby certify tha~ ~ Ior~go~i~ [s true ~ correct . 2/6/69 _ ,,,~,,~ ~,~_~:7.,.,,,~, NOTE--~e~o~ on this fo~ is required for each calendar month, regardless of the status of operations, and mu~ ~ filed in dupli~te with the Division of Mines & ~inerals by the 15th of t~ succeeding month, unless othe~ise dire~ed. / Form P--7 ~ SUBMIT IN DUPLIC~ STATE OF ALASKA ,Seeothe~ structions on OIL AND GAS CONSERYATION COMMITTEE reverse WELL COMPLETION OR RECOMPLETION REPORT AND LOG* i1~1 la. TYPE OF WELL: O,L [] GAS ~-] ~] WELL WELL , ray Other b. TYPE OF COMPLETION: ~ BACK RESVR. Other WELL OVER EN r~. NAME OF OPERATOR Union 0il.. Company of California · 3. ADDRESS OF OPERATOR 5~O7 W. No.g~'he.i~n. Ligh,~s Bl~d., Anchorage, Alaska 99503 i. LOCATION 0F W!ELL~Rd~'OrtJ~IOCatio'n At su~ace ~ ~ ' 6 ~W ,. 1880~. 137 · ~f SE.corner-See. 29, TDN~ R13~ Leg 2~ At t~ prod. tnter~al ~p6rtea~ bdow ~-, 371~'S &~'9958'E of surface location· ~ total aep~ ~? <~ . ~ ~f xu~m~caL com~ ~ 50--133--20146 ~L 18730 ~. ~IF ~, ~O~ O~ TRIBE Ma 8.~u~,F~ OR L~SE N~E :;~Trading Bay Unit ,, State G-14 (32-34) 10~ ~ ~D P'~L, OR WIghT ~cAr thur River-Hemlock , ~:~S~C. 34 T9N, R13W, sM. , 44'27' S & .10,293'E of surface location '12~ '~I~T · ii 68'80 la. D~,~E ~I~J-DiDED [14. DATE,::T.D;"!q~.. CHED {'i5. DAT~ CO,1VIP ]$<USP ~ A~. 116.~' ~EVA~O~S CD'F, RKB, Rm, ]'~, ~C)'/17, ~. 1017/68-,; , [ 12120/68,, ,[ : L-1/6/69~ I 99' R.T. above:MSL I la T~'D~H ~ & TVb~,. P~UG, ~CX' MD & ~n~; ~,.~LT~ CO~.. [ il." ' '{~ER~AL~ ~,[LLED BY CABLE TOOI ~. PRODUCING ~V~S), ~;D~ ~S COM~TION~oP, BOSOM, N~E (~ AND ~) ~" [2~s:W~ DIREC~O,N~ _'~ Top 'Hemlock Peris, !}i~,-!i~ ~.-t~l~-~l{t.v~. ? t s~v~~ Bottom Hemlock Per~s" '1~.-1~26 .~ i8t~-t~104 VD } i Yes .24. ~ E~CT~C AND OT~ ~GS'EU~~ ~.iL, Ga~a Ray,..']S0nic, .~, '& correla[ion Log , ~ ~ ,,',,~ , ,~. '7' ' '; : CAS~G ~ (Re.re all ~tri~s set in well) ...... HO~ SIZE C~IENTING ~O~T PU~ 70O 1: 2400 ~ ,, , ...',,,..< ! ...... -ACID, SHOT, F~CT~, C~T 152~6-15248 perfs 4 hpf <~., [ ~5272-1529Z * JAN 2 4 I .... 7 ~ '; ,,~,~,nu nF 91~ AND [ '1 C ' I WELL STA~S (~odu~ or D~TE ~RST P~ODUC~ON ~ODUCTION METHOD (Flowh~g, gas lift, pump~g~ze and type of p~p) 1/8/69 gas lift ~,,~t-~n~ producing ~ oe ~ms~. [~o~s ~ '[~o:~ s~z [P~?~ soa o~. ~c~. WAiSt. ~/~9/69 12 124/ iGC-Om ~O ~W, ~B~G ~G ~S~ [~~ O~BBL. G~. WA~B~. [O~ G~-~ (~.) ~1. vmeos~r~os OF ~as (S0td. ~,ed ~or ~el. vented, etc.) ' .... ~ ]TEST WITNESSED BY ~ ] T.K. ~uir S2. LIST O~' A~ACHMENTS ~ ~, i : 33. I hereby certify tha o .~gojn/l Itnd attached information ts complete aiad correct as determined from all:available records ~ TITLE >' D~st. Drlg. Supt. DATE SIGNED 1/22/69 INSTRUCTIONS General: This form is desigged frOr submittincj_-~.a-complet:~ c-. c~ '- ~tnd correct well completion report and I on " :~11 h/pes of~an.zls ond leases;in Absk,i2 ' .... .. :-':~ :.'~ < ~tem: 16: I~dicate which elevation is._us'~ed aS'Ereference (where' not otherwise sbLbW'n)?for dept~!'-rne,~-6re- ~.: . .. ! -'. ~ :.; -ment's giv~':~ in ather spaces on this f~m ~nd "~lt, .r~ 202-:~Ad 22:: I~z;this w_ell is~;..coml~le~d fo·[ sepa~at.6 pra-duction ~om more."X;th'ari:r, one interval zone :}(m~[fiple:~pletiori~ so s. Ute i.~ ite~ ~:~, an}~t in it,:fin 2~'~show the;pr¢.:lucin~ :[ht~'rval, or intervals, _ opOi), bo.~m(s) an~name~{~) (ifZan¥~:foi~onl¥ ~he infe~val~eported i}ij item 30. ,.%ubmit a separate r~port :' ~page) on4hm '.fbrm, adequately4denlCfied, for~each a'~Cl~io.hal interval to be seCer0tely produced, show- ~ing.;{he ~i:itdit'ional data Pertinent. to - "-...ff ' -~' ~_. _ ," .... '' '"'item~6: '~cks"Cerr~:nt": Attach'~d ~..r._::.'. .. ... ~.. .... supplemeo~al records for~this well--should sho~ the details of an~, mul- - '-.:tiple' stage cem:_entir~_' and the I~catic~9:: of.i the:'cementing'Fit6b[.[ '"~- :-'--' ~'~. .:Jt~nt'! tS..~ubm~' a sZeparate corn~pletion .-'report on thisform f~ each;~'nterval to be separately produ~e~:l. -~'- 7~(Se~'linstri~ctio~'.for items 20 and'22'.'aboge) ~ ~ ,..~, · . ~ 34. SU]kXM'ARY. _ OF FOP,.1V[ATION_,FI'ES~ ...IiVCLUbtN(; Ii~Ei:tVAL~--,]-F.~TED. PRE~iJ~:I.E DATA ~ ,li,,llCOV[3:l. llj2{ OF OIL~':G.A.~. ' ; ;_-~' 35. ~, ~ ~--, ,~ ~ '~"~ ..... ' .- -.. .... ' ................ ' , ' ~ MEAS. DEPTH 'I~RU'~ VI~I.T.D.~PTH ?: :-'-: ,z · '~ ':. '; ..- - ;:;. ':'~ H~lock 15,226 975Z'. T~ ~.. · . ' .. ~ ;-'i " . .~. CO~ DATA. A~AC~I.BRIE~ D~CRIP~ONS.~F LIT~O~Oy. POnOSITY, FRAC~R~, {~PP~T DI~ '~ ' ~ y-' ,-, -- a AND D~CEC~I~HOWS~OF OIL. G~ OR WA~. ":Z L'-: - - ' - 0 ' ' . - NoNE - · u~ ~ .... '.: -2' 6q: .~C '.. . · ..... ; i ' "~ :~ : ,' ' ' '" Z- .. <,~ ~ ..... . . .: - ~ "L-; ~ ... --~ >. . . , .' ,.. , ,I ,I I I :J UNIT I,'LLL th, r':-14 [:IL[J) ~,lcArthur River I:ield 6/22/74 i6,342'TD 6393'ETD 6/25/74 16,342'TD 5614'E~ Cmt. Ret. 6/24/74 16,342'T[ 4990'E~ Cmt. Ret 6/25/74 16,342'T[ 4451 ETD Cmt. Ret 6/2 16,342'T[ 3600'ETD Cmt. Ret. 6/27/74 6~28/ 16,342'TD 3900'ETD Cmt. 16,342'2~) 5607 ' ETD Junk 16,342 'Ti~ 5607 ' ETD Junk 16,342 '.TD 44:70 'ETD Cmt.Ret (Footage 0') Commenced operations @ 12:01 ~rm, 6/22/74. Removed x-mas tree. Instal. led & tested I;;OPi! to UOCO specs, .Rill w/ bi, t & csg. scraper & CO 9 5/8" csg, to E,,9.~ , Displ. old mud v:/ fi].tered inlet x~r. t,,Imxea,up & displ, filtered Inlet ~r. w/ 75#/ cu. ft. 5% KCL-salt ~r. Pooh. RI.I Schl~berger & ran CNL-~)C-GR Log from 6393' to 3000' Rill w/ 1 5/8" csg. puncher & shot 4 hpf from 5688' to 5692'. Press2 up csg. to 2500 psi- ~able to establish compri, cation between 5688' to surface in 9 5/8" X 13 7/8" a~ul.us. Rill w/ 1 5/8" csg. p~cher & shot 4 hpf from 3396' to 3400', (Footage 0') Rill w/ 9 5/8" RTTS & set @ 5647'. Press. up DP to 1800 psi- unable to circ. in 9 5/8" X 13 7/8" annulus from 5688' to 3400'. Pooh. RIII w/ 4" csg. gun & perf. from 5688" to 5698' @ 4 hpf. RIt! w/ cmt. ret. on ~%. Tool htmg up @ 5686' & set while logging collars. RI[[ w/ 4" csg. gnm & perf. from 5675' to 5685' @ 4 hpf. Rill w/ cmt. ret. on I,'!L & set @ 5614'. RIH w/ 3 1/2" DP & stabbed into retainer @ 5614-'. Pumped into perfs. @ 15 cu. ft/ rein'w/ 1500 psi. ~4ixed & pt~nped 500 sx. Class "G" cmt. Displ. cmt. into perfs, w/ final press, of 800 psi-no squeeze. Cleared perfs w/ 25 cu. ft. of ~.~cr. Pulled out of retainer & (Footage 0') WOC. Stabbed back into ret. @ 5614' (below C-1 Sand) & squeezed stage #2 on perfs, from 5657' to 5685' w/ 150 sx. Lo-filtrate Class "G" crat. to a final pressure of 1600 psi. Poot~ v:/ ret. stinger. RU WL unit & perf. for zone isolation between the B-4 Sand & the C-1 ' Sand from 5050' to 5060'. Pressure increased to 450 psi on csg. immediately after perf. SI well for 9 hrs. WOC. Bleed off pressure. Closed blind. rams & pm~ped into per.fs from 5050' to 5060' w/ 1200 psi. Ran j~mk basket & gauge ring to 5080 . Ran cmt ret. & set @ 4990'. Stabbed into ret, ~ squeezed for zone isolation w/ ~00 sx. Lo-filtrate Class "G" cmt. to a final pressure of 950 psi. (Footage 0') Till w/ 4" csg. gun & perf. from 4500' to 4510' for zone isolation between the B-2 & B-3 Sand. Ran 9 5/8" cmt. ret. & set @ 4450', Squeezed perfs, w/ 300 sx. of Lo-filtrate Class "G" Qnt. to a final press, of 1000 psi. Pooh w/ ret. setting tool. (Footage 0') WOC. TIH w/ 4" csg. gun & perf. 4 hpf between the B-1 & A-5 Sand from 3940' to 3950'. Set ret. @ 3880'. Squeezed perfs, w/ 300 sx. Lo-filtrate Class "G" cmt. to a final pressure of 1000 psi. TIIt w/ 4" csg. gun & perf. 4 hpf above the A-4 Sm~d from 3650' to 3660'. Set ret. @ 3600'. Squeezed ~erfs. w/ 300 sx. l~-filtrate Class "G" cmt. to a final pressu~'e of 1000 psi. (Footage 0') TIH w/ 8 1/2" bit. Drlg. cmt. ret. @ 3600' & CO to ret.'@ 3880' Drlg. ret. @ 3880'. . (Footage 0') Drlg. out ret. @ 3880', 4450' & 4990' plus cmt. from squeeze work. (Footage 0') CO well & pushed junk to 5607'. (bt~. ret. set @ 5614'). ~.,Iade bit & scraper run to ETD @ 5607'. .(Fo@rage 0') P~nn 9 5/8" RTTS tool & set @ 4639'. IIa. d co~nunicati.e, ns up 9 5/8" - 13 3/8" annulus between perfs @ 5050' to 5060' & perfs. 0 4500' to 4510' Set ret. 0 5023'. & ~t, 9 5/8" - 13 3/.8" ~umu!.us w/ 100 sx., Lo-fi~tra. te "G" ~nt. I'~m~ 8 1/2~' bit & CO to 5'000'. No cmt. opposite · · - from 4500' to 4510' Set I[!~S O 4168' Iiad co~munmcat~.on,> up 9 ,~/S annulus between perfs O 4500'-to 4510' & perfs O 3940' to 3950'. ~;et ret. 4470~. lfLL ILLL l lu, (:::-i4 F IL.l J) },Ichrtllur River Fie!.d 7/1/74 7/2/74 7/:5/74 7/4/74 7/5/74 7/6/74 7/7/74 -:16,342 VTD 3910'ETD ~nt. ret. 16,342 'TD 391.0 'ETD cmt. ret. 16,342'TD 4470'E~) CmL. ret. 16,342'TD 4470'ETD Ont. ret. 16,342'TD 5607 ' ETD j~nk on ret. 16,342'TD 5607 ' ETD jtmk on ret. 16,342 'TD 5607 ' ETD jlmk on ret. ____D.E.T_AI[_LLF_S OF OPF~?_&Tjf~L!S_z__DESCRLPTIOI~S !~ RESULTS (Footage 0') Rill. Stabbed into ret. @ 4470' & cmtd. 9 5/8" - 13 3/8" -' ,,',, - ~ 8 2" bit ~, ('~] to 4250'. armulus w/ 175 sx. Lo-f~ltrate G cmt. lmm 1/ . ~ . ... . _ .... ,, P~,=, 9 g/8"' I{TTS'tool &' set O 3730'. tTad communicat5_ons up 9 5/8" -' 1.3 ~ulus between perfs ~ 3940~ to 5950v [ perfs 0 5650~ to 5660 . Set ret. 3910' & mtd. 9 5/8" - 13 3/8" a~ulus %4 150 sx. Lo-filtrate "G" mit.. w/ 10% s~d. Pooh w/ret, stinger. (Footage 0') RIH w/ 8 1/2" bit to 3850'. Pumped into perfs from 3650' to 3660' @ 2 cu. ft./min, w/ 750 psi. Pooh. RIII w/ RTTS & set @ 3558~. Squeezed perfs from 3650' to 3660' w/ 100 sx. Lo-filtrate "G" cmt. w/ 10% sand to a final press, of 1000 psi. P~ess. annulus to 1100 psi. Released R~S & pulled to 3498' holding 1000 psi on perfs. W©C. Released press.-cmt, stayed in place ok. (Footage 0')- Poohw/ 5/8" ~ITS. Rill w/ 8 1/2" bit. I)r].g. crnt. from 3640~ · e d to 3660' & from 3688' to 3857'. CO to 3895'. C~rc. q con . mud. Spotted 30 bbls'Drill-S pill & perfs, the A-5 Sand from 3834' to 3844' @ 4 tpf. RI}I w/ DST tool & set @ 3727' w/ tail ~ 3748' to test the A-5 Sand. · Press. dry DP to 1000 psiw/ plateaUS-gas. Opene--a"~ol @ 9:30 pm, 7/3/74 w/ 1000 psi. Press. increased to 1190 psi in 10 mins. Flowed well for 44 mins. initial flow period. Well flowed gas & rat hole fluid. Closed in tool @ 10:25 pm, for 1 hr. & 28 mins. initial-SI press. (Footage 0') Re-opened DST tool for final flow period @ 12'00 pm, 7/3/74. Flowed gas for 7 hrs. @ the following DP press. & flow rates' FLOW'PERIOD DP YSI 'RATE i'[{CF/D ---I-iF. Sthb'ilize rate 2 hr. 400 8.93 2 hr. 600 7.96 1 hr. 800 7.63 1 hr. 1000 6,23 Closed tool @ 7:00 am, 7/4/74 for 3 hrs. final. SI press. Rev. out gas above DST tool. Released DST pkr. Rill to 3817' w/ tail. @ 3838' I~.ev. out gas cut. mud. Pooh. Rltlw/ 8 1/2". bit. Drlg. cmt. ret. @ 39].0;, hard cmt. to 4210' & cmt. stringers to 4333'. (Footage 0') Drlg. cmt. ret. @ 4470', 4517' & 5023' plus cmt. from squeeze work. Rltlw/ 8-1/2" bit & 9 ~/8" csg. scraper to 5607'ETD. (Footage 0') Rltt w/ 9 5/8" RTrS & set g 3986'. Tested for communication between perfs @ 3940' to 3950' & from 3834' to 3844' w/ 500 psi. differential-test ok. Set R/TS @ 4417' & tested for co~mmication between perfs @ 4500' to 4510' & from 3940' to 5950' w/ 500 psi differentai!. Had slow bled off of press. Set RTTS @ 4605" & tested for conmmication between @ 5050' to 5060' & from 4500' to 4510'. Co~mmicated around w/ 300 psi @ 3 cu. ft./min. Pooh. Rill w/ 9 5/8" cmt. ret. on WL & set @ 5085' & 4980'. RItI W/ 3 1/2" DP & stabbed into ret. @ 4980'. Press. DP to 500 psi-no communication.between perfs from 5050' to 5060' & from 4500' to 4510'. Pooh. Rill w/ 9 5/8" ~FI'S & tested blank from 4510' to 4980'- test ok. Pooh. Rltt w/ 8 1/2" bit. Drlg. cmt. ret. @ 4980' & 5085'. CO 9 5/8" csg. to 5600'. Circ. & cond. mud to 76#/ cu. ft. (Footage 0') Spotted clean Drill~S pill opposite "B" & "C" Zone perf. intervals. Perf. the following intervals w/ 4" csg. guns w/ 4 hpf. SAND I k~ERVAL FOOTAGE B-1 4138'-4148' 10' B-2 ' 4295'-4305' 10' B-2 4340' ~4350' 10' B-'2 4444' -4454 ' 10' B-3 4715'-4725' 10' B34 4820'-4830' 10' C-1 5254'-5274' 20' C-2 . 5500'-5510' 10' , , lUil OIL d '\LIt L ! i,li WELL ii.>, I,'LLL l lU, G- 14 F ii.U) ,~,,IcArtl'nrr River 7/7/74 (cont..) 7/8/74 7/9/74 7/i0/74 7/ii/74 7/i2/74 7/1.5/74. 7/14/74 7/15/74 7/16/74 16,342 'TD 5607 ' t~'i'l) jlmk on ret. 16,342 'TD 5607'ETD junk on ret. 16.,342 'TI) 5607 'ETD junk on ret. 16,342 'TD 5607'ETD junk on ret. 16,342'TD 5607 ' ETD junk on 16,342 'TD 5607'ETD j ulrlk ret. 16,342 ' TD 5706'ETD junk on ret. 16,342 'TD 5600'ETD '~ 16,342'TD 5600'ETD 16,342'TD 5600'ETD ...~)Z~TAI~_F OPERJ'_(Li-G_'S~_~_IL~f.:SCRiFFIOi~S & RESULTS RII-i w/ bit & scraper to +5300'. RI}! w/ 9 5/8" X 4 3/4" ]laker Model "])" pem~. pkr. & set @ 50i0'~ Rigged up to rLul dual 3 1/2" tbg. (Footage 0') Ran dual. 3 1/2" tbg. string as pr@grained. Stabl)ed into perfm, pkr. @ 5010'. Tested pkr. Communicating around pkr. w/ 250 psi. Set plug in "Q" Nipple @ 5050' & tested LS w/ 500 psi-ok. Rigged tip to rrm Radio-active Tracer. (Footage 0') Ran Tracer Survey Log. Circ. & cond. mud.. Pooh w/ dual tbg. string. Rill w/ 6" bit & 7" csg. scraper. }!ad tight spot @ 565'. t~brked to 615- '. (Footage 0') RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5007'. Circ. & cond. mud. Pooh. RIH w/ RTTS & set @ 4995' Communicated between the "C" & "B" Zone perfs w/ 200 psi. Ih~lled up iq set R]~'S @ 4549'. Commtmicated between Upper & Lower "B" Zone perfs. Pooh. RII! w/ burnover shoe & pkr. picker. Hilled over pkr. @ 5007'. Pooh. (Footage 0') RIll w/ 8 1/2" bit & 9 5/8" csg. scraper to 5590'. Rill w/ ?4ITS & Pd~P. Straddled squeeze perfs @ 5050' to 5060'. Communicated to annulus w/ 200 psi. Straddled C-1 perfs @ '5254' to 5274". Perfs. communicated to anm~lus Pooh. RIHw/ gauge ring.& junk basket to 5150'. .Ran & set. ont. ret. @ 5090' ~o 5030'.' RIItw/ DP. 'Stabbed into cmt.' ret. @ 5030'. Squeezed perfs from 5050' to 5060' w/ 150 sx. "G" cmt. ~ 10% sand. (Footage 0,) WOC. RIH w/ 8 1/2".bit. ~rlg. fire cmt..from 4723' to $075' plus cmt. ret. @ 5030'. Made scraper trip to 5075'. (Footage 0') RIM w/ ~FTS & set @ 5010'. Tested for communication between squeeze perfs @ 5050' to 5060' & "B" Zone perfs w/ 500 psi negative & positive differential-ok, RIH ~ 8 1/2"-bit & drlg. firm cmdr. from 5075' to 5090' plus crat. ret. @ 5090'. (Footage 0') Ran I'/L gauge ring & junk basket to 5000'. Ran & Set 9 5/8" X ~4 3/6" Baker Model "D" perm. pkr. @ 4950'. RIII w/ seal assy~ on 3 1/2" DP & stabbed into peru. pkr. @ 4950'. Co~anunicated armmd pkr. x~/ 300 psi. Rill W/ RTTS & set @ 4940'. Tested for communication between "B" & "C" Zone perfs.. w/ 500 psi positive differential-ok. Reset ]gl'rs & tested @ 4935', 4930' & 4920'-ok. Ran gauge ring & junk basket to 5600'. Ran Baker Hodel "F-i" perm. pkr. & set @ 4922'. Stabbed into pkr, w/ DP.' Tested to 500 psi. No commtmication. RU to run dual tbg. string. (Footage 0') Ran dual 3 1/2" tbg. string. Stabbed into peru. pkr. @ 4922'. Tested 500 psi.- Spaced out & landed tbg. Set dual hyd. pkr. ~ 3746' & tested to 500 psi. RU 1.'¥~ tmit & opened "XA" sleeve in SS @ 3680' & LS @ 3713'. Closed "XA" sleeve in LS @ 4935'. Installed. BPV's. , , . (Footage 0') Removed BOPE. Installed & tested x-nk~s tree. Displ. tbg. & am~ulus w/ inhibited pkr. fluid. Displ. tbg. strings w/ 1100 psi gas. Released rig @ 12:00 Noon, 7/16/74. FINAL Pd~PORT RIG !L!!I,F:ASI]D @ ]_2:00 NOON, 7/16/74 UI,IIO['I OIL COHPAI,IY OF CALIFOllI,IIA I'&LL 1' "' DATE ETD DETAILS OF 0PEPATIONS, DESCR1PTIOHS & RESLfl._'[S TUBING DETAIL SHORT STRING JTS . LENGTH BOTTOM TOP 3 1/2" Otis "Q" Nipple 3 1/2" 9.20# N-80 Butt. Tbg. 1 9 5/8" x 3 1/2" x 3 1/2" Brown Hyd. pkr. Mdl. H-2 Brown righthand coupling 3 1/2" 9.20# N-80 Butt. Tbg, 2 3 1/2" Otis "XA" Sleeve 3 1/2" 9,20# N-80 Butt. Tbg. 111 3 1/2" Otis Ball Valve Nipple 3 1/2" 9.20#'N-80 Butt,' Tbg. 7 3 1/2" 9.20# N-80 Butt. Tbg. 3 1/2" 9.20# N-80 Butt. Tbg, 3 1/2" X 3 1/2" Butt. Cameron tbg. hgr. Landed below zero 0.93 3785.70 3?? '~, .77 32.30 3',' ' 47 6.77 1.40 60,13 3.80 3410.39 ,4.34 210.48 6..05 10,00 1 00 38.11 3'/" .", 70 37'1:4.30 3684.17 3680.37 269.98 265.64 55.16 49.11 39.]]_ 38,11 --0-- f - liLL ' Tt~ING DETAIL L(!~G STP, Ii % x · LO I'TO,., TOP JTS. IJ~NG'I~ ! ~ ' " 3 1/2" Baker ~.ble Shoe 3 1/2" Otis "Q"]nipple 3 1/2" 9.20# N-80 Butt. tbg. 1 3 1/2" Butt. X 8 rd. x-over 3 1/2" Baker seal assy. 3 1/2" Baker locator sub 3.1/2" 8rd. X Butt. x-over 3 1/2" 9.20#'N-80 Butt. Pup 3 1/2" Otis ."XA" sleeve 3 1/2" 9.20# N-g0 Butt, Pup. 3 1/2" X 4 1/2" Butt. x-over 3 1/2" Baker seal assy. 3 1/2" Baker locator, sub 3 1/2" Srd X Butt. x-over 3 1/2" 9.20# N-80 Butt. Pup 3 1/2" 9.20# N-80 Butt. tbg. 1 3 1/2" Otis "XA" sleeve · 3 1/2" 9.20# N-80 Butt. tbg. 1 4 1/4" OD X 3" ID Baker blast jts. " :chg, Z' 3 1/2" 9.20fl i~-80 Btltt,. 4 1/4"OD X 3"ID Baker blast jts. 3 1/2': 9.20#. N-80 But'c. tbg. 8 3 1/2" 9;20# N-80 Butt. Pup 4 1/4"OD X 3"ID Baker blast jt. 3 1/2" 9.20fi N-80 Butt. tbg. 2 4 1/4"OD X 3"1I) Baker blast jr. 3 1/2" 9.20# N-80 P;utt. tbg. 1 4 1/2"OI) X 3"ID Baker blast jt. 1 3 1/2" 9.20# .N-80 Butt. tbg. 4 3 1/2" 9.20# N-80 Butt. Pup. 4 1/4"OD X 3"ID Baker blast jr. 3 1/2" 9.20# N-80 ?~utt. tbg. 1 3 1/2" 9.20# N-80 Butt. Pups 4 1/4"OD X 3"ID Baker blast jt., 3 1/2" 9.20# N-80 Butt. tbg. 7 4 1/4"OD X 3"ID Baker blast, jts. 3 1/2" 9.20# N-80.Butt. tbg. 2 9 5/8" X 3 1/2" X 3 1/2" Brown I-{yd. pkr. I',lodel I-i-2 3 1/2" 9.2# N-80 Butt. tbg. 1 3 1/2" Otis "XA" sleeve 3 1/2" 9.2# N-80 Butt'. tbg. 3 3 1/2" 9.2# N-80 Butt. Ih~p. 3 1/2" 9.2t! N-80 Butt. tbg. 108 3 1/2" Otis ball valve nipple 3 1/2" 9.2# N-80 Butt. tbg. 8 3 1/2" 9.2# N-80 Butt. Pup, 3 1/2" 9.2# N-80 Butt. Pup. 3 1/2" X 3 1/2" Cameron tbg, hanger Lm'~.ded below zero 0.75 .93 31.35 1.14 10.01 1.70 .92 4.11 3.80 4.12 1.18 8.55 1.48 .33 6.84 28.15 3.80 · 32,09 39,40 62.40 39.4O ' 244.59 8.10 19.70 59.88 39.40 30.35 19.70 120.86~ 9.95 19.70 31.24' 16.20. 19.70 213.05 39.40 63.29 6.77 29.03 3.80 92.10 10.10 3308.60 4.34. 242.60 6.10 10.12 1.00 38.11 Baker t,,bdel "D" 9 5/8" production ret. set @ 4950' Hax. bore 4 3/4" Ba]~er ?.Iodel "F" 9 5/8" production ret. set @ 4922'. ?,'lax. bore 6.00'" Otis "Q" nipple 3.75"o]) 2,625"ID. Otis "XA" sleeve 4.25"OD 2.75"ID. Otis ball valve nipple 3.875"oD 2.76"ID. '' P, rown Hodel 1I-2 9 S/S" hyd. pla:. 8.25' OP. set on . 2.8()"II) I,f:; 2,87"!t~ 4990.03 4989,28 4988.35 4957. O0 4955.86 4.94.5.85 4944.15 4943.25 ,1939.12 4935.32 4931.20 4930.02 4921.47 4919,99 4919.66 4912.82 4884.67 4880.87 4848.78 4809.39 4746.98 4707.58 4402.99 4454.89 4435.19 4375.31 4335.91 4305.56 4285.86 4:1.65.00 4155.05 4155.35 4104.11 4087,91 4068,21 3855.16 3815.76 3752;47 374.5.70 3716.67 3712.87 3620.77 3610.67 302.07 297.75 55.33 49.23 39.11 38. ].1 O' Rotary 38.11. tbg. hgt. ~.', :~ ~.~ ....... ~ N-80 Buttress to 3786' LS 3 1/2" 9.2~f N-80 Buttress to 4990' SHORT 1. 3 1/2" ()t'is Ball Valve '2. 3 1/2" ~)ti.s XA Sleeve 3. 9 5/8" X 3 1/2" X 3 1/2" ~rown !~kr. 4. 3 1/2"~OIis Q Nipple (Btm.) TOP ID 266' 2',760 3680' 2.750 3746' 2.8, 3786' 2.625 17 3'/4" spiral weld @ 600'. LONG STRING TOP ID A. 3 1/2" (Otis Ball Valve 298' 2.76 B. 3 1/2" ()tis XA Sleeve 3713' 2.75 C. 9 5/8" Dual Brown Hyd. pkr. D. 4 1/4"OD Baker Blast E. 4 1/4'*OD Baker Blast. j F. 4 1/4' OD Baker Blasi j G. 4 1/4" Om Baker Blast .il. H. 4 1/4" OD Baker Blast j t. I. 4 1/4'OD Baker B'!ast: j i. J', 4 ]_/4"0[) Baker Blast it, K. 4 1/4"OI) Baker Blast 3746' 3816' 3.00 3855' 4068' 3.00- '4088' 4135' 3.00 4155' 4285' 3.00 4306' 4336' 3.00 4375' 4435' 3.00 4455' 4708' 3.00 4747' 4809' 3.00 4849' TD 16,342i E?D 5600' 9 5/8" X 3 1/2" X 3 1/2" Brown Hyd. -pkr. Mdl. H-2 @ 3746'." 9 5/8" Baker Mdl F-1 Perm. pkr. @ 4922 2:><:: 9 5/8" Baker Mdl D Perm. pkr. @ 4950'.. 13 3/8"'61# J-SS Csg. @ 6493'. .. Junk retaSners on top of EZSV to 5600'. EZSV retainer @ 5614'. Cmt. sqz. thru perfs. @ 5675'-85' 5688'-98' EZSV retainer @ 6737'. 9 5/8" csg. parted @ 6823', *Original completion had. 9 5/8" csg. to ].3,521' ____~ii~-7 ..... [ COMPLETION SCHEMATIC r I S~ --~--7--[ TRADING BAY UNIT STATE ~G-14 is' .,~ Recompletion ~ ~ . Comp]eted 7~16/64 ~ · I UNiOt'~ OIL COMPANY O, C,-~LIFO~,,tIA . FOFIM 247 (N~' 6 ., . . .,_ _.~ TRADING BAY UNIT STATE G-14 cont. LONG STRING (cont..) ~ i_D~D L 3 1/2" Otis XA Sleeve 4881' M 3 1/2" Baker ~oc~or sub 4920 N 3 1/2" Baker Sea]. Assy. O 3 1/2" Otis XA P 3 1/2" Baker Locator sub. 4944' Q 3 1/'2" Baker Seal Assy, 4946' R. 3 1/2" Otis Q Nipple 4988' S. 3 1/2" Baker Mule Shoe (Btm.)' 4990' 4921' 4935' UNION OIL CO. OF CALIFORNIA R~;PAIFt RECORD SHEET A PAGE NO, ' "~ ' ' ;",_~)i,~ .!~ ':'" ~ "" ' "-r,,¢~A,,'v EN~.INEER x, Wa~ona Joh'nson TUBING HEAl) Histor~r '-'~'~*~** ~ ':" ~' ]. : , , . '-~/ "----~ ..... 9 2~: .......... '; .................. 7%-'T'%'~ ~ ............ ' ~ ~--,... '7:.:-~:::,,~ :,:';~;,-....~ ..... ;.Z~ .L. ' .... ' -, ,..::':;;, c.. :' ~-,-:., '~ ,:.,~'-,- ~.- ..... ROTARY D!-{!VE BUSHIi'~G 600' 6493' 13,521 17 514' 9 3 1/2: Spiral 47,43.5,40 12.6, 9.2¢f l%ld j 2--55 | Cmt:'d w/ 2400 sx, EI m~x w/ 4..50 sx. '%" Cmt'd w/ 650 ex. "g" w/ 2% Ca. C12 & 50 ex. "g" Pll0,N-80[ Csg. parted @ 6823'. See csg. detail. N-.80 See well schematic. PERFOP,.AT~NG RECORD .2/g9/68 1/4/69 i/4/69 5/22/74 6./22/74 6/23/74 6/25/74 6/24/74 6/25/74 6/26/74 6/26/74 ___Ltt!~..B v A L 15,294-15,326 15,272~15,292 15,226-15,248 5,688- 5,692 3,396- 5,400 5,688- 5,698 5,675- 5,685 5,050- 5,060 4,500- 4,510 3,940- 3,950 3,650- 3,660 E.T.D ..... 16,114 16,114 16,114 5,607 5,607 5,607 5,607 5,607 5,607 5,607 5,607 I-;em..Prod., Hem..Prod, For Sqz. To cement 9- 5/8"x13-3/8" annulus to surface For Sqz. For Sqz. For Sqz. For sqz. For Sqz. For Sqz. Abandoned Abandoned .abandoned Sqz. 6-24-74 Perf. w 1-5/8" csg. puncher - unable to circ. - lef~ open. Sqz. 6-24-74 Sqz. 6-24-74 Sqz. 6-24-74 resqueezed 7--II-74 Sqz. 6-25-74 Sqz. 6-26-74 Sqz. 6-26-74 resqueezed 7-2-74 8/74 "A" "B" & "C" INITIAL PtlODUCTi~ ~i% AFT~ 8370 Daily rato is Aug~ average :for both strings. WELL '" O" v ..... HIST.~R. PRIO.n TQ REPAIR LAST N,¢. h~._O}:.~gznal Completion) "' " .__J~~lg.~! ~ OMPLETION r~,~*,-~.~. ~. ~ 'rp ' ' ' J · ' -' 9 - ~7 , :PRODUCING N ,ERVA.r¢'_~nL~_~Z~%~..~,,~ ....... · !T,.AL PRODUCTION fAST R.EGULAR PROD. & DATE: ...... '~.~:? ,~ w ~b-n on t-cmlocl, 8 _.omrleu:; a.. 'A., B , 6 C dry_gas_producer ........ ~*,oo~, FO}~ ~EP,*,Tm ........ ~__~_.d ...... [;.t___;. ..... .c: ..... '0 ..... "_'%;_~_.!.L.!L 22 '_L' .......... L'... '_' Form D-IOOI~B UNION OIL CO. OF CALIFO' NIA SHEET la 2 REPAIR RECORD PAGE NO .......... BAY bi,II .WELL NO._ G-14 FIEL~ ~ .... F3. el_a ,~]..AJ..~, ~ ~}: ,Jmr River ' ~ ~ ........................................................... APPR. OV EL! .... ...... ~ u, IJ enu. e, DATE 7/3/74 7/7/74 7/7/74 7/7/74 17/7/74 7/7/74 7/7/74. 7/7/74 7/7/74 7/7/74 INTERVAL 3834.-3844' 4076-4086 4138-.4148 4295-4305 4340-4350 4444--4454 4.715-4725 4820-4830 5254-5274 5500-5510 E. T. D RFASON PRESENT CONDITION TYPE: 5607' For DST - A-5 Sand Open for production 5607 Gas Production Open for production B-1 5607 Gas Production Open for production B-1 5607 Gas Production' Open. for production B-2 5607 Gas Production Open for production B-2 5607 Gas Production Open for production B-2 5607 Gas Production Open for productiOn B-3 5607 Gas Production Open for production B-4 5607 Gas Production Open for production C-1 5607 Gas Production Open for production C-2 CASING HEAD:__ Shaffer 12" 900 series 3000# KD w/ 1-2" side outlet 13-3/8" csg. head CASING HANGER:__Shaffer 12" nominal 9-5/8" Model K-D, L-S CASING SPOOL:_ None TUBING HEAD: Cameron DC-B12 3000# x !0" 5000# w 5000# studded outlet 'I~JBING HANGER' 10" Nominal DC-B w/ 3-1/2" Butt. BI~4 & 3-1/2" EUE 8RD Top -,- ,~ , 10" z UBII'.G HEAD TOP' 5000# MASTER VALVES: 3-1/2" Bore Master & Swab Valves - 3" S1M#'' ,HRISJ'MAS TREE TOP CONN.' 3" SM# S Bolt .xmas tree. Cap w/ dual 3-1/2" EL[E UNION OIL CO. OF CALIFORNIA DRILLING RECORD WORK OVER SHEET D I~'AG E NO. Trading Bay Unit State LEASE DATE 4/24/69 25 26 27 DI E. T. D. .RECEIm IAY 1 3 I$ION OF OIL AN WELL NO. G=14 ,, FIELD McArthur River DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Completed laying down "G" Drill pipe. P~ Knuckle joint w/mule shoe. Picked up new S-135 drill pipe. Ran k~uckle joint to 6972'. Pulled up to 6825 & dropped plug to actuate KJ (13" reach). Free travel to 6828. After repositioning several times, believe went in 9-5/8" csg. RI to 6838' where mule shoe stopped. POH. PU 8" lead impression block. Could not get below Cameron head. RD riser & recovered 8 dp rubbers. NU & ran 6 stands where IB stopped. RIH 12 stands w/spear. POH. RD riser & BOPs ~ recovered five dp rubbers. Nipple Up. RIH w/Impression block 6 stands where it stopped. POH. RIH w/spear to 6825'. Circ 1 hr. POH, no recovery. RIH w/impression block, stopped 10 stands in hole. POH. RIH w/spear to 6825, circ 400 vis pill of mud around, no rubber in mud returns. POH. Recovered one dp rubber. RIH w/wash pipe w/spring steel catchers. POH & recovered 4 dp rubbers. 9 RIH w/impression block stopped @ 2694'.POH. RIH with 8-1/8" wash pipe. POH. Recovered 3 dp rubbers. RIH w/8" impression block on jt dp. Impression not conclusive. POH. RIH w/8" impression block on drill collar w/stab @ top & botom. Stopped @ 6840'. POH. Impression same as #1. RIH w/box tap. Touched bottom @ 6840, rotated & circulated to 6864', no contact w/fish. POH. RIH w/box tap on Knuckle joint (13" displacement) worked box tap from 6825 to 6840'. No contact w/fish. POH. Ran 214 its 4-1/2" tbg open ended.HUng tbg @ 6715. ND BOP.& set Cameron ~ree. Operation temporaril~ Suspended. RIG RELEASED @ 9:00 PM (4/27/69). Move to G-16 to complete drilling. UNION OIL CO. OF CALIFORNIA DRILLING RECORD WORK OVER , LEASE.._ Trading Bay Unit State DATE E.T.D. 4/16/69 17. 19 2O 21 22 18 1969 23 DIVISION ^Ncl · SHEET D . PAGE NO VgELL No..G-14WO FIELD ..... McArthur River DETAILS Of OPERATIONS, .DESCRIPTIONS & RESULTS Moved rig over hole. Removed Xmas Tree. Insta-led BOE. Attempted to pull tbg. Unable to do so. Pumped 85 bbls 82# /cu.ft. mud down tbg to kill well. Dia-Log ran free point. Tool stopped @ 4998'. Ran impression block which indicated that a section of an Otis shifting tool which had been lodged in the Camco valve at 4998. Ran 3-1/4" magnet on wireline. Recovered 1/2 of on lock nut. Unable to pick up anymore ~unk. RU Otis. Dislodged shifting tool w/spear permitting the pieces of the tool to fall to bottom. Dia-Log ran free point. Fnd tbg to be free @ 6800' & stuck @ 6900'. Shot 4 holes @ 12,020' w/"B-J" tbg perforator in an attempt to break circulation. Unable to do so. Shot 4 holes @ 8006' But was unable to break circulation. Dia-Log ran jet cutter (3.750" O.D~) and stuck same @ 6821'. Could not work same free necessitating the firing of the cutter and cutting Off the tbg @ this depth. Broke circulation & & pumped out amts of coal that at times the two shakers were unable to handle it. Some pieces were the size of soft balls. Circulated hole clean. PUlled & laid down 217 its of 4-1/2" tbg, jewelry and 12' stub of shot off tbg. This stub was collapsed on bottom 8". PU overshot, BS, oil jars & 20 jts H.W. dp. Unable to run overshot below 6823' due to tight hole (collapsed csg). POH. Overshot had indications that tbg stub was into the mill control. RIH w/bit'to clean out coal & condition mud. Increased mud weight from 80# to 83# to control gas. RIH to 6823' w/short catch overshot. Unable to catch fish. POH. Marks on overshot indicated something had been between overshot body & mill control. Ran impression block. Schlumberger ran collar locator which indicated that 9-5/8" was parted at a coupling. Pick up 8-1/2" skirted mill. Milled to 6831'. POE. Mill had signs of tbg being on the inside. RIH with 8-3/8" impression block. No Good. RIH with 8-1/8" skirted mill. Washed out fill fro~ 6800' to 6831'. Circulated & conditioned mud. Increased weight to 86#/ftJ. Milled from 6831'-6838'. POH. Mill indicated that iron was on the inside. RIH with 7-1/2" shoe on 7-1/4" wash pipe. Circulated out coal fill from 6814' to 6838'. Washed to 6898'. POH. No marks on inside of wash pipe indicating that tools were outside of the 9-5/8" csg. Ran collar locator to check bottom & collars. Set down @ 6824'. Unable to get into opeq hole. RIH w/knuckle joint & mule shoe in an attempt to find bottom section of 9-5/8" csg, but due to coal sloughing, it was necessary to POH & lay .do~m knuckle joint & mule shoe. RIH w/open end drill pipe w/teeth welded, on bottom joint. Circulated out coal fill from 6685 to 6898. Circulated hole clean @ 6898. RU Schlumberger. Ran IES log thru dp to 5820 where' log stopped. Due to the light weight & flexibility of the ES tool, it was necessary to run the thru dp DIL. Logged from 6909-6654. Log indicated open hole from .6834-6909. Unable to detect top of fish. Rig down loggers. POH. Laid down rented "G" drill pipe. Attempted to kill well pumping mud down tu-bin~. Pumped 560 bbls mud when mud circ to surface'(no diesel ahead of mud). Mud in 75-76#, mud out 72-73# after degasser. Recovering large amts of coal, plugging choke manifold. TP (pumping) 1500# w/chokemanifold press varies 100-300#. - DRILLING RECORD LEASE Trading Bay Unit Star,VELL NO. FIELD LOCATION. G-14 SPUD DATE CONTRACTOR TYPE UNIT DRILL PIPE DESCRIPTION PAGE NO._ COMP. DATE RIG NO..' - PERMIT NO SERIAL NO ' T.D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER ELEVATIONS: WATER DEPTH tL T. TO OCEAN FLOOR IL T.' TO MLLW IL T. TO DRILL DECK IL T. TO PRODUCTION DECK APPROVED: . DEPTH ~EVIATION' 'BIT JET DEPTH · "' DATE DEPTH NO. SIZE MAKE TYpE SIZE OUT FEET HOU,,R.,S ANN. JET DIRECTIONAL [] 12/13/68 15101 50 8-1/2" HTC XDG 3-12 15271 .170 6-1/2 '1,7,0 328 . 15 15459 52 " HTC X55R " 15622 164 12 · "' "' 'T26 B-8' ........ " 17 15778! 54 " Reed SCM " 1583] 53 '-'5 " " T-3 B-1 ...... 20 16264 58 "' HTC XDR 3-11 1634~ , 78 4-1/2[ " ' '" T-4 B-2 . , , , . , , . . , ..... LEASE FIELD LOCATION PERMIT NO. T.D. Trading Bay Unit Stat~exr~LL NO M~Ar thur 'River Leg #2, Conductor #43 68-80 DEVIATION (B.H.L.) COMPANY ENGINEER DRILLING RECORD G-14 SERIAL NO.ADL 18730 T.V.D. 10516o72' SPUD DATE 10/6/68 CONTRACTOR WODEC0 TYPE UNIT National 1320 UE DRILL PIPE DESCRIPTION 5" H~ghes X hole 125 O0 ~235.60 BIT RECORD DEPTH &DEVIATION' 'BlT JET ' DEPTH // .' VERTICAL .DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. JET DIRECTION. AL ~ · 10/7/68 337 1 15" HTC OSC2A 3-5/8 · 623 286 5-1/2 T~1 'B.-1 7 623 HO1 22" servcc Exp. 620 283' ' '4 ' 8 · 628 HO2 22" ,, Exp.. . 620 9 623 1RR 15" 'HTC OSC3A 3-15 .623! Cle~n Out ~mt & d'ril2IC-mt''In Conductor , . 17-3/4"shoe ; 10 623 2 12-1/4" HTC OSCIG 3-24 984 361 i'3-1/2 ' DDrld ' 10 984 2RR.. HTC OSCIG 3-13 2546 1562 8-1/2 , 120 502 T-6. B-2 OG 1/4 ... '-11 2546 3 " -' Globe ST3G 3-13 3824 1278 8-1/2. -" " T 6 B-2 ' 13 ' 4675 5 " HTC OSCIG 3-15 5418 743 12'1/.2 " ' I T--5 'B--2 " 14 ~ZO~ 7 " Reed Y~IAG open' 6251 43 4 " " Dynadrilled 14 6251 8RR ,, ,, ,, 3_15 6310 59 3 ." . ,,. TL2~, B-1I · 15 I6310 9 " " " 3-24 6587 88 5'1/2 100 T'i Bi3 15 6587 10 " HTC ' OSCIG 3-24 '66'50' 63 3-1/2 " T-2 B-1 ' i6 600 RO3 17 Smith Cony 2883 2283 20-1/2 60 " T'-3~ B-2 17' 2283 R04 " ' I " " 4202 1319 ' 14 60 T-6' B-6 " ' 20 5115 ,~O6 " " ... " 5904 789 13-1/2 80 Engine rprd-two pumps 20 5904 ~O7"' " " " " 6604 578 ' i2 ' 80 25 5110 11 12.-1/4 HTC OSCIG 3-14 6483 1373 .... 9 100 375' Cleuned out cmt 27 6483 llRR " " " '" 6'6'50 67 2 " ":' "'' " "' . 29 8191 15 " HTC OSCIG ." 8416 225 10 - " " T-6 B-3 30 8416 16 " Smith DGHJ " 8791 375 10 " "' T-6 B-5~ ' 30 8791 17 " " "' " 9132 341 9 ' ,, 'l, 405 T-6 B24 i . 1 9573.. 19 " HTC ODG " 9829 256 11 "'] " ' "' 2 9829 20 "' Smith DGH " 9896 67 '5-1/2 " " '-' ' 2 9896 21 " Globe . ST3G " 1'0175 279 10 ~" " 3 10175 22 " Reed. YTIAG " 10400 225 10-1/2 " " ' 4 10400 23 " Globe ST3G " 10619 219 "' ' " ". · 5 10619 24 " Smith DGH " 10908 289 ' '9 " ~" 6 10908 25 '~ Globe ST3G " 11234 326 11 " " · 8 11552 27 · " , Globe ST3G " 11836 284 'i0-1/2 " '" T-7 B-60.G. 1/2'". _ 8 11836 28 " Smith K2HJ " 12035 199 12' ~ i " " T-7 B-2 9 12035 29 " Smith DGHJ " 1235~ 324 ~0-1/21 " " T-7' B'3 '" ' " B-2 O.G. 1/2" .. 10 12359 30 " _ Globe ST3G '~" 12496 137 8 I. T-6' 10 12496 31 " Smith K2HJ " 12593 97 7-1/2 " '~ ' T-4' · B-30G 1/4" . 11 12593 32. "- HTC ODV " 12756 163 "8-1/2 " " T-5- B-3 'l ,, 1.4 12926 34 " Smith K2H 3-24 . 12926 0 3~ 9.: DDrld, wall stuck · 15 12983 36 " Globe' MT3G 3-14 13080- .97 5 115' 352 16 13080 37 " Smith K2H 3-15 1'3302 222 -1'1 " " ' " .' 17 13302 38 ",, Smtth.~ K2H 3-15~ 13484 182 - 10 ,, ,, 18 L3484 39 I ' ' Smith KGH I' '' 13534 ....50 2 . ." " Pull for 9'25/8''- C.~,~ · 12/5/68 13534 40 8-1/2 Sec. S4TG '3-15 13725 'i91 .4-1/2 170 '32~ T-6 B-3 .,. 6 13725 41 " Sec. S4TG 3-'12 13942 217 6-1/2 '" "· ' ' 6 13942 42 " Smith K2H. " 14089 147 " " "' ' 7 14089 43 " Sec S4TG " 14280 191 5 . " " ' .... 7 14280 '44 "~ Reed YTIAG " 144'69 189 5-1/2 ' " " ._ 8 14469 45 " Sec. S4TG " 14651 182 6-1~2 " " ...... 9 14651 46 " Globe ST3G " 14832 181 6 " " Lost..3 cones _ 10 1.48~2 47 I I" HTC ODV " 14859 27 2-1/2 Drld on ink I i0 14859...t. 48 " Sec.. $4TC : " 1&977 118 ' 6. 170 328 .. ELEVATIONS: WATER DEFrH R.T. TO OCEAN FLOOR R.T. TO MLLW R.T. TO DECK R.T. TO PRODUCTI APPROVED: LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO.-- ''~ Trading Bay Unit State %VELL ~?a nGd o ln4m e n tFiELD McArthur River DATE 5/16/69 17 19 20 2I E.T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6823 6823 Moved rig frc;m G-16. RIGGED UP-' :Attempted to circulate 85~ mud. After pumping 280 bbls, the annUlus plugged w/coal. Unable to circulate. · Installed back pressure valve in tbg hanger. Removed tree. NU riser & BOP's. Pulled tbg hanger. Circulated w/85~ mud & killed well. Pulled and laid down 4-1/2" tbg. RIH with 8-1/2" bit & dp washed from 66.13' to 6870'. Circulated out large quantitys of coal. Attempted to run Gar tuna-Ray Neutron Log. Unable to get log down. Fished out nine dp rubbers. LRan Gamma-Ray Neutron log from 6800' to 4000'. Set wire line "EZ" drill BP@ 6600'. Closed rams & pressured csg w/1500~. Held OK. Perforated 9-5/8" csg with four 1/2" holes @ 6525'. Ran & set RTTS pkr @ 6338'. Pumped into formation @ rate of 2 ft3/min w/1200~% cemented thru peris w/300 sx Class "G" neat cmt. Max press 2800~. Final press 1200~. Cleared peris. CIP@ 12:00 Midnight 5/18/69. WOC 4 hrs. Pulled pkr loose & circulated bottoms up. Re-set pkr @ 6338'. Job ~1: Broke down w/1400~. Pumped mud away @ rate of 12 ft3/min @ 2000~. Reset pkr @ 6338'. Sqz Job ~2: Cmtd w/300 sx Class "G" mixed w/sea wtr. Unable to obtain sqz. Cleared peris v~roc 4 hrs. Broke down cmt job w/2000~. Bled off to 1200~. Mixed & pumped 300 sx Class "G" cmt. Pressure built steadily to 2800f~ then broke back tb 1500~. Staged last 50 ft3. No sqz. Cleared peris. ~ArOC 5 hrs. Cmt job broke down w,/1800~,. Job ~%4: Mixed & pumped 400 sx. Class "G" mixed w/sea wtr. Maximum standing pressure was 1500~. Staged last 50 ft3, cmt job broke again while pumping w/2100~. No sqz. Cleared peris. CIP 11-00 PM 5/19/69. Tsts.sqz Job ~4 after 8 hrs WOC. Broke down @ 1600,~. Sqz Job ,~5- Mixed & pumped 400 sx Class "G" cmt. Pumping pres sure3s lowly increased to 2500~%. Would bleed off to 1250~. Staged last 30 ft' . No sqz. Cleared peris. WOC 6 hrs. Tstd cmt Job ,~5. Would ;not hold 1900~. Sqz Job f~6: Mixed & pumped 400 sx Class "G"-cmt. Results same as Job ~Swith the exception the standing pressure was 1700~. Cleared peris.' CIP 9 pm 5/20/69. WOC 4 hrs. Pulled pkr loose. Circultaed & conditioned mud. Reset pkr. Tstd Sqz Job ~6. Broke down w/1950~. Sqz Job ~7: Mixed & pumped 400 sx Class "G". Max press (pumping) 2400~ @ 6 ft3/rninute. Shut down pump press slowly decreased to 1800~. AFter 10 min. Pumped 4 ft3. Press increasing to 1900~. Then broke back to'1700~. Unable to obtain sqz over displaced 21cu.ft. clearing peris. CIP 8 am 5//21/69. WOG 6 hrs. Pressured peris w/2000 psi for 25 min. No loss of pressure. Pulled pkr loose. POH. RiHw/d.a. top of cmtring @ 6334'. Drld cmt from 6334' to 6580'. Closed rams & pressure tstd csg w/1500f: I0 min OK. Drld cmt to 6590. Void from 6590 to top of BP @ 6600t. ~ UNION OIL CO. OF CALIFORNIA DrilliNg RECORD .. SHEET D PAGE NO.i 4 LEASE Trading Bay Unit State WELL NO, ii G."!.4, FIELD. Mc.Arthur River Abandonment DATE 5/22/69 23 24 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 7154 6393 Drld BP, n~) cmt below plug. Washed & CO to 7057'. $ CO w/bit to 7110. POH to PU Globe bskt to attempt to PU remains of EZ Drill Plug. RIH w/same & drld to 7111', Where it stopped. POH & · recovered 1 pack-off rubber, 2 small pieces of metal & several large chunks of coal. RIH w/bit & drld to 7154', would not drill. No excess torque. POH. Bit shows no sign of being on metal. Survey: @ 7154, 50°'(original hole approx 540-550).. Believe hole to be sidetracked. Rih w/oedp @ 7145. Mixed & pumped 400 sx Class "G" cmt w/Inlet wtr pr_eceded by 50 ft3 of caustic wtr. Pulled to 6859' & reversed out 304-ft3 cmt. Pulled up to 6487'. CIP@ 1-00-am 5/23/69. WOC. RIHw/bit & scraper , fnd top cmt @ 6834'. Cloased rams & pumped in form. @ 1400% @ 470 gpm. POH & PU Howco EZ drill retainer. RIH w/same set @ 6737'. Mixed & pumped 400 sx Class "G" cmt w/Inlet wtr. Pressure gradually increased to 2000~.. Shut down pressure dec to 1850%. Pumped less than 1 ft3/min. Press inc to 2000~. PU out of retainer & reversed out 50 ft3 cmt Mixed & pumped 150 ft3 Glass "G" cmt spotted on top of retainer. Theoretical top of cmt 6393'. POH & 1.d. dp. ND BOP & riser. Installed 10' x 900 Series flange w/2" 5000% valve. Well PLUGGED AND ABANDONED. RIG RELEASED @ 6:00 a.m. 5/24/69 UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. Trading Bay Unit State LEASE. DATE E.T.D. 3/9/69 19 23 V~ELL NO. G-14 FIELD McArthur River DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Checked 9-5/8" x 13-3/8" annulus pressure. SHut In pressure equaled 530 psi, bled to 0 psi. 12 hr build up to 580 psi. Connected Halliburton unit to well. Pumped into annulus between 9-5/8" x 13-3/8" casing @ 20 ft3/min @ 750#. Mixed & pumped 500 sx Class "G" w/l% CFR-2 @ 4 bbl/min w/press increasing to 1700# broke to 1250#, increased to 1500#. Shut Down pressure 950#. Last 100 sx had 5% CaCl2; After 8 hrs, 950#. Bled to 0#. 9-5/8" x 13-3/8" annulus, 525#. 9-5/8" x tubing, 1430# pressure between 9-5/8" & 13-3/8" required 15 minutes to bleed to 0 psi. Shut in pressure built to 200# in 10 minutes. Connected Halliburton unit to well. Pumped water into annulus @ the rate of 40 ft3/min @ 600 psi. Mixed & pumped 35 sx BJ Gyp-Seal followed w/10 ft3 of wtr into annulus @ a maximum pressure of 1000 psi. Immediate shut in 0#. CIP @ 12:45 PM. 9-5/8" x tubing annulus remained constant @ 1430# indicating no communication between casing strings. LEASE. DATE 3/5/69 UNION OIL CO. Of CALIFORNIA ~ DRILLING RECORD SHEET D PAGE NO. Trading Bay Unit State . G-14 McArthur River VVELL NO. . . FIELD .... E. T. D. DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS RIG RELEASED from G-12 @ 9:30 am 3/5/69. Moved rig from G-12 to G-14 Conductor #43 and attempted to perforate Hemlock Water Aquafer for conversion as an injector. Perforating gun stopped @ 15,750'. Spudded and worked gun to 15,910'. Unable to go deeper. POH w/perf gun & rigged down Schlumberger. Prepared to move back to G-16. RIG RELEASED @ 12:00 Midnight 3/5/69. Will have to move over well, pull tubing and clean out prior to Perforating Hemlock Water Aquafer. UNiO I Oil CO. OF CALIFORNIA WELL RECORD ~ SHEET C I=AGE NO.. LEASETrading Bay Unit State .WELL NO. .... G~14 FIELD McArthur River CASING & TUBING RECORD SIZE WEIGHT I' THREAD GRADE DEPTH ']~EMA,~[KS I~l I ' 17-3/4" Spiral Weld ..... 600 cmtd w/650 sx.G. w/2% CaC12 & 50. sx G w/4% 13-3/8" 61# seallock J-55 6493 .... cmtd .w/2,400 sx 'BJ mix w/45~ sx "G'" 9-5/8" 47#,43.5~,40# buttr~ss P-110,N-~I0 13521 see 9-5/8" casing detail . . ' 7" 29# buttress N-80 16166 - cmt w/600.sx CFR.2 top lnr hngr 0 13275. , · 3- ~ /2 I I ~ 2 [ ' 6 0 , ~ ' 2 0 buttress Mi-si0 i 15227 see t ~ ~ d e t ~ ~ 1 · ' ' x i i ~ , · . ' ' i ~ERFORATING RECORD DATE ~NTE~VAL ' .E.T.D~' REASON ~P~ESENT CONDITION' . 12/29/6~ 15294-153~6 ·16114' nrodudt~on onen perforated .w/ _s~llpp.~guns,I 1/4/69 15272-15292 16114' nr~duet~nn on~n no~orn~o~ ,,/A" ~t1~ 15226-15248 16114 nro~tlet~ nn orion " " ' ".. " . . .. · ,, . · ,~ ..... ]i - .... · . . . . . ~ , . , i · , .... ' ' ' . ............ . .......... . . ..... · - i. i i , , . . · . . ,~ , , ~ i , . i, , i , INITIAL PRODUCTION DATE INTERVAL N~E~901L CUT.. GRAV .... C.P, T.P. i C'HOKE 1/19/69 15226-15326 2~2% 33.1 150 124 185 808 ,°n gas lift · . . . · · . · · . ' · · ', i . ii _ · - . · i i, . · · , , , . · · .. . i i · · · , , · · · , . , ........ ~ ........ WELL HEAD ASSEMBLY,, TYPE: ' ' CASING HEAD: Shaffer 12" 900 series 3000// KD w/l-2" side outlet ~3-3/8" casing h.ead " CASING HANGER' Shaffer 12" nominal 9-5/8'" bIodel K-D, K-S CASING SPOOL:. TUBING HEAD:.. Cameron DC-B12 [2" 3000# x 10'" 5000# w/5000# 'studded outlet TUBING HANGER: Cameron single 4-1/2" x 10" buttress bottom x 4-1/2" EUE top Single String Solid Block Log Type Cameron bottom flange to 5000# TUBING HEAD TOP' MASTER VALVES: UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET PAGE NO. LEASE Trading Bay Unit State. · . WELL NO.. G-14 FIELDMC. iAr thurI River DATE 10/7/68 · 10 11 & 12 13- 14 15 16 - 19 2O 21 22 E.T.D. 623 623 623 2546 5206 6208 6310 6615 6650, 6650 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Spudded 15" hole @ 3:30 AM 10/7/68. Drld to 623'. Opened 'hole to 22". : Commenced running 17-'3/4" spiril weld Csg, . 17-3/4" csg stopped @ 340'. Pulled & laid down csg. Reran 18-5/8" mill. Milled from 337-352. Reran csg, unable to go below 340-'. Pulled & laid down csg. Ran 22" HO & reamed from 337-345. On metal @ 345'. Reran 18-5/8" mill & rereamed from 345-347. Recovered what appeared to be a section of piling. Ran & cmtd 15 its 17-3/4" spiril weld csg w/duplex shoe @ 600'. Cmtd w/650 sx Class "G" w/2% CaCl2 followed w/50 sx Class "G" w/4% CaCl2. Ail cmt mixed w/Inlet-wtr.i Good cmt returns to surface. CIP @ 5:00 AM 10/9/68. WOC 2-1/2 hrs. ND Riser, cutoff 17-3/4" csg & installed 20" Hydril. Tstd same w/600 psi, no good. Removed Hydril & rewelded same. Tstd Hydril 600 psi for ~0 minutes OK. Drld-out cmt from 598-623. POH to pickup DDrl. DDrld to 623. Ran building assembly and built angle to 53° @ 2546'. Drld & surveyed to 5206'. Drld & surveyed to 6208. POH w/dull bit to run DDrld to combat right turn. DDrld 6208-6251. PO dull bit on DDrl. Chngd bit RIH, DDrl plugged. POH, ran new DDrl. DDrl would not operate. POH~ RIH-w/follow up assembly. Drld from 6251' to 6310'. POH to drilling assembly prep to dril to 6500'. RIH w/drlg assembly. Drild & surveyed 12-1/4" directional hole to 6499'. POH, RI w/DDrl from 6499' to 6587'. POH, RI w/follow up assembly & drilled to 6615. brld & surveyed to 6650. PO, RI w/17" HO & fnd obstruction @ 540. POH & picked up 15" bit.. RI to 600' w/no obstruction. POH & picked up 17" HO & reamed fm 540-570'. POH & trip in w/17" HO to 600'. POH, RI w/new 17" HO & continued reaming. While opening hole @ 5115' pipe torqued then freed backing off pipe @ 65'. 'Caught fish, recovered 17 its dp leaving top of fish @ 608', 8 ft below shoe of 17-3/4" csg. Ran 9-5/8" overshot w/16" guide on btm of a bent jr. Recovered all of fish. Opened 12-1/4" hole to 17" Opend hole to 6645'. PO to run csg. RU to run 13-3/8" csg. Ran 37 its 13-3/8" 61# J-55 buttress csg, 1-XO, 128 its 13-3/8" 61# J-55 seal lock csg. Float shoe on btm of jt #1, self fill differential collar on btm of jt #2. Struck bridge @ 6493'. Stuck & unable to circ. Cmtd thru open efided drill pipe hung @ 6425' w/RTTS pkr. set @ 586' w/300 sx Class "G" cmt mixed w/Inlet wtr. Pumping press 2000# psi, shut in press 1300# psi, released press. Float held OK. CIP 9:00 PM 10/22/68 WOC. -.. 13-3/8'' Casing Detail Bottom Top Length Jts. Descriptign 6494.74 6492.71 2.03 6492.71 6449.91 42.80 6449.91 6447.94 1.97 6447.94 4933.44 151'4.50 4933.44 4897.56 35.88 4897.56 +5.00 4902.56 6499.74 36 1 '128 166 · Howco 13-3/8" Float Shoe Jt #1 13-3/8" 61# J-55 butt cs Howco 13-3/8" self fill diff. Jt #2. thru #37 13-3/8" 61# J-5~ butt csg. Jt #38 X-O Jt #39 thru #166 13-3/8" 61# J-55.seal lock csg. Landed 5' above R.T. UNION OIIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO. LEASE Trading Bay Unit State . . VV-ELL NO. ' G-14 'FIELD - ~!cArthur River DATE 10/23/68 24 25 26 27 10/28/69 to 11/2/68 3 4 -' 12 13 14 & 15 16 17 18 19 E, T, D, 6650 6650 6650 6650 7366 10066 10212 12756 12926 12983 13080 13325 13534 13534 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Ran Schlumberger temp survey twice. Tool not functioning properly. Incon- conclusive results. RD Schlumberger. RI to 6417'~w/oedp'to circ. Made up flow nipple~& hose fm 13-3/8" csg to pits. Circ & cond mud. POH & RU ~chlumberger perf gun. RI w/sam-PO & ran CBL log. PO, RI again w/perf gun & perfd 5 holes 0.46" DIA @ 6438. PO, & RD Schlumberger. · Broke circ w/400 psi. 340 gpm @ 1100 psi. Cmtd thru perfs @ 6438 w~00 sx Class "G" cmt mixed 1/2 cu.ft, perlite per sack 6% gel& 1% DJ~l'followed by 450 sx Class "G". Ail cmt mixed w/Inlet wtr. Displaced w/5400 cu.ft, mud. CIP @ 7:45 AM 10/25/68. 1026 cu.ft, ex~ess emt to surface. WOC 6 hrs. Cut off c~g, reinstld 12" 900 Series Shaffer "KD" csg head. Welded plat over space covering the top of the 17-3/4" & 20" to the 13-3/8" w/a bleed press line, du~ to a gas seep b~tween the 13-3/8" and17-3/4". ! . Tstd weld on csg'head to 3000# OK.' Instld. Hydril & double Shaffer. Tstd ~6PE. Ran in, fnd hard cmt. @ 5110'· Drld out hard cmt fm 5110' ~o 6445'. Drld cmt out of CSg to 6488'. PO shot 5 holes w/Schlumberger gun @ 6483'. Ran Howco RTTS tool., set @ 6485'. Fnd communication between perfs @ 64'38' and 6483' @ 800 psi. Set RTTS tool @ 6360'.. ,Sqzd200 sx "G" cmt_~ Sqzd · ~u ' 160 sx. away, leaving top of cmt @ 6405' tlad 3 breakdowns ur~ng sqz job 3500 psi, 2800 psi & 2000 psi. Max p~ess 4500 psi, .Final sqz press 2500 psi,i h~ld one hour. CIP @ 3:15 pm 10/26/68. PO made up drlg assembly· Fnd top of cmt @ 6405' and firm cmt to 6488' w/no voids. CO cmt & shoe to 6540. CO cmt & reamed hole fm 6540 t~ 6650. Drld & surveyed to 7366'. Drld & surveyed to 10066. POH for bit chng @ 10175' hit tight spod @ 734~' Stuck pipe, bit @ 7599' top stab @ 7340'.' Bumped pipe free. Worked pipe out of hole by drlg up thru sections7~3~40-733~2, 7062-70~53_,~6~2~9-6805 & 6547-6538~ Chngd drlg assy. Drld to 10212. Drld & surveyed to 12756'. Drld & surveyed to 12926. PO to run DDrl. Unable to work weigh~ down to bit due to wall sticking. PO changed bits & drlg assy. Reran DDrl. Tools continued to wall stick. Released press fm Hydril pulsation damper on mud pump causing pump to jar pipe allowing weight to be transfered to bit. DDrld to 12983' turning hole to the right. Reamed DDrl run, drld & surveyed 12-1/2" hole fm 12983-13080. Lost 5-1/2 hrs Instlg new brake blocks. . Drld & surveyed to'13325. Tight hole & bridges 1270D-12950. Drld & surveyed fm 13325-13534. Cond hole for 9-5/~" csg. Hole in bad condo Worked drill string out of hole· 'Stuck @.7529'~. Worked same free.' PO, 1.d. bent Hevi-Wate Drill pipe. RU to run 9-5/8"'csg. Ran & cmtd 330 its 9-5/8" csg (See Csg. Detail). Cmtd thru shoe_~_~1000 sx Class "G" w/l% CFR-2. Bumped plug w/2000 psi. Released press. Float held OK. CIP 8:15 pm ND, set 9-5/8" slips, cut off 9-5/8" csg, Instld & tstd tbg head. Tstd head w/3000 psi - OK. UNION OIL CO. OF CALIFORNIA DrILLiNG RECORD SHEET D PAGE NO. Trading Bay Unit State LEASE · V~LL NO. G-14 FIELD. [ .McArthur River DATE 11/20/68 1214168 6' 9 10 11 12 13 -14 15 & 16 17 18 19 E.T.D. 13849 14832 14905 14977. 15271 15459 15545 15831 15970 16O34 16196 16306 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Description 9-5/8" Casing Detaii Jts Length TOp Bottom Float Shoe 47# P-il0 butt csg. Float Collar 47# P-il0 butt csg. Self-Fill Diff. Collar 47# P-110 butt c~g. 47# N-80 butt csg. 43.5# N-80 butt csg. 40# N-80 butt csg. 43.5# N-80 butt csg. 47# N-80 butt csg. Landed below zero Total · 1'72 1 35.14 1.60 1 41.20 2.06 33 1339.89 51 2077.15 2217.80 149 6126.98 29 1191.94 12 451.70 34.00 330 1.3521.18 13519.46 13484.32 13482.72 13441.52 13439.46 12099.57 10022.42 7804.62 1677.64 485.70 34.00 --0-- 13521.18 Laid down monel drill collars. Pulled rat & mouse hole. Temporarily suspended operations in order to move rig to Conductor 42 to drill G-18. RIG RELEASED 4:30 AM 11/20/68. Rig Released from G-18 @ 6: AM 12/4/68. Moved rig to G-14. RU BOPS, tstd blind rams to 2000// OK. L.D. all 7-3/4" drill collars & "G" drill pipe. RI w/DA. Tstd pipe rams to 1500# & Hydril 'to 1000# OK. C~rc to cond mud, Drld self fill-float collar-shoe & cmt. 13439-13534. Drld & surveYed to 13725'. PO for NB. Tight hole 50' off btm. RI w/bit#41. Reamed fm 13650 to 13725. Drld to 13849'. C0nt to dril & survey to 14832. PO w/bit #46. Lft 3 cones in hole. RI w/Globe ink bskt~ Recvrd one cone. Reran jnk bskt. Cored to 14834'. Recvrd small core of'sand but no ink. RI w/° bit & ink sub. Drld on ink & drld new hole to 14859. PO, recvrd bearings & pieces equivalent to one cone. RI w/ bit #48. No indications of any Ink in hole. While drlg ahead @ 14905' coupling on R.T. parted. Pulled into shoe of 9-5/8" csg. Remvd rotary in order to repair coupling. Completed repairing R.T. Ran back to btm &cont drlg to 14977~ PO for bit chng. PU an additional 45 j ts "G" drl pipe & rubbered same. Drld & surveyed to 15271'. Drld & surveyed to 15459', lost 2 cones off button bit after 10 hour run. Fished cones w/ink bskt. RI w/HTC X55R bit. · Drld & surveyed to 15831'. . Drld & surveyed to 15970'. · Drld & surveyed to 16034', PO for bit change @ 16018. PO for 2 wash outs @ 16034'. RI & reamed 50' to btm. Drld & surveyed to 16153'. Trip for NB. RI & reamed 70' to btm Drld 8-1/2" hole to 16196'' Cont drlg to 16264. Trip out for NB.. RI & reamed 60' to btm. Drld to 16306'. Lost pump press. PO to ck for hole in d.p. UNION OIL CO, OF CALIFORNIA DRILLING RECORD SHEET D · PAGE NO · . LEASE Trading Bay Unit State VCELL NO. G-14 FIELD MClArthur River DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12/21/68 22 23 24 25 26 163~2 16342 16342 16342 16342~ 16114 Fnd wash-out. RI w/bit #58. Drld & surveyed hole to 16342'. -C~:rc 1-1/2 hrs' to condition hole for logging. .PO & RU Schlumbe?ger. Ran DIL logging.tool. Stuck @ 15427'. RU & began strip over,of Schlumberger line. After rng 85 stands in hole swivel on Schlumberger line parted. Chained out of. hole. Fish neck & swivel did not pass thru overshot. Pulled Schlumberger line out of hole, repaired swivel. Pulled 11000# check for line part Stripped over Schlumberger line to 15427 w/pump on-@ 8 5PM 400# press. No indication of Sonde. Ran overshot to 15498', no chang~ in pump press-. Pulled up one stand. Ran back on stand, followed w/Schlumberger line. Acted like fish was in overshot. Attempted to pull line out of rope socket, line parted 600' from surface. PO w/overshot, no recovery. Picked up shot made spear. RI w/same to 30th stand. Took weight. PO, recoVered approximately 1000',. of line. . " ~'~ RI w/spear to 34th stand, took weight. Ran ~n 3 more stands, turned 10 rounds, PO. Rec. approx, 1000' line on spear. Tied on to Schlumberger line. Pulled remaineder of line & DIL sonde out of hole. RI, reamed 60' to btm. Circ l~l/2'hrs on btm. PO, RU Schlumberger DIL sonde & RIH. Ran DIL & Sonic logging tools, no problems. RI w/HRD sonde, stuck @ 14020'. Tried POH. Logging tool pulled up to 13920. Pulled 11,600# on Schlumberger line. Logging tool would come no further. StripPed in over Schlumberger line to fish. When overshot reached fish, wire line tension & pump press increased. Pulled on SchluMberger line trying to part same @ rope socket. Line parted approx 300' below surface. Chained out 5. stands d.p. Fnd Schlumberger line. Pulled on same, parted approx 1200' below surface. Pulled 9 stands, fnd Schlumberger line. Pulled line out of rope socket. Rec. all of line. POH, did not recover HRD sonde. RIH w/overshot to __ fish for logging tool & to cond. hole to run lnr. . Finished POH. Did' not recover HRD logging tool. RU to run 7" lnr. Ran 7" 69 its (2860.63') 29# N-80 buttress, set @ 16261 on TIW lnr hngr top @ 13370 Pumped 100 Ft3 wtr, mixed & pumped 600 sx Class "G" cmt w/l% CFR-2 W~Inlet wtr. Displaced w/1932 Ft3 mud. Bumped plug w/3000#. Checked floats OK. CIP @ 7:45 PM. Did not attempt to circ out. Pulled · wet for 5 stands. POH & picked up 8-1/27 bit & 9-5/8" csg scrapper. 7" Liner Detail Bottom Top Le n_~_ng_~ Jts. Descript_i_on 16166.02 16163.65 2.37 16163.65 16123.67 39.98 16123.67 16121.87 1.80 16121.87 13301.22 2820.65 13301.22 13275.63 25.59 2860.63. 68 69 Baker "G" Shoe 7" 29# N-80 Buttress Baker "G" Collar 7" 29# N-gO Buttress TIW Hanger Assembly 7" 29# N-80 Buttress w/s,c, collars RIB w/ 8-1/2" bit & csg scraper. Fnd top of lnr 95'"high. Measured out of hole. Top of lnr hngr @ 13275'. No cmt on top of tnt. RIH w/6" bit & csg scraper. Drld cmt fm 16027-16114. Inidcations are that this is the top of the TIW landing collar. Displaced mud w/Inlet wtr. Pressured csg & lnr lap w/2500 psi 10 minutes OK: UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D :PAGE NO. LEASE Trading Bay. Unit State VFELL NO.. G-14 FIELD · McArthur River DATE E.T.D. 12/27/68 28 29 16114 16114 16114 16114 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Laid down all d.p. & collars in order to ship same to beach for .inspection; (tuboscoping). RU & commenced rng tbg & associated jewelry. Ran tbg to depth of 15,570'. Displaced Inlet wtr w/diesel. 'Pulled tbg up hole to 15173' & set Baker Packer @ 15139'. Un-Jayed from Baker Expansion Joint. Pulled up & install-ed Otis Ball Valve. Spaced.out & landed tbg w/outer sleeve of ekpansion jt 2 ft abo~e"J" lugs. RD BOE & · Riser system. Installed & tstd Cameron tree. Tstd w/3000 psi OK. RU · Schlumberger & ran Gamma Ray Corrleation Log thru tbg. Unable to pull back into tbg. 'Tubing Detail #1 -,. ~J_ts. Description Length T_~ Bottom 52 188 1 %84 j ts Landed below zero 38.00 Tubing Hanger 1.00 8 4-1/2" 12.60#'N-80 butt tbg 248.33 - 4-1/2" Otis Ball Valve 3.00 55 4-1/2" 12.60# N-80 butt tbg 1706.15 4-1/2" Camco KBM 1000# 7.37 4-1/2" 12.60# N-80 butt tbg 1611.15 4-1/2" Camco KBM -970# 7.37 4-1/2" 12,60 N-80 tbg 1374.26 4-1/2" Camco KBM 940#.' 7.37 39 4-1/2" 12.60 N-80 tbg 1209.14 4-1/2" Camco KBM 920# 7.37 35 4-1/2" 12.60 N-80 tbg 1092.45 4-1/2" Camco KBM 910# 7.37 4-1/2" 12.60 N-80 tbg 5847.42 --4-1/2" butt.x 3-1/2" X-O 1.20 61 3-1/2" 9.20 N-80 tbg 1894.27 3-1/2" Otis X-O sliding sleeve 3.70 1 3-1/2" 9.20 N-80 butt tbg 30.57 3-1/2" 9.20 N-80 tbg pup 8.15 Baker Telescoping Exp. Jt. 23.85 Telescoping Jt expanded out 2.20 Baker Hydraulic Packer 7.23 3-1/2" Otis "X" Landing Nipple 1.25 3-1/2" 9.20 N-80 tbg 31.'38 3-1/2" Baker Shear Sub 1,18 TOTAL 15172.73 0 38.00 38,00 39.00 39,00 287.33 287.33 290.33 290.33 1996.48 1996.48~ ' 2003.85 -2003.85 3615.00 3615.00 3622.37 3622.37 4996.63 4996.63 5004.00 5004.00 6213.14 6213.14 6220.51 6220.51 7312.96 7312.96 7320.33 7320.33 13167.75 13167.75 13168..95 13168.95 15063.22 15063.22 15066.92 15066.92 15097.49 15097.49 15105.64 15105.64 15129.49 15129.49 15131.69 '15131.69 15138.,92 15138.92 15140.17 15140.17 15171.55 15171.55 15172.73 Note: Baker Telescoping Expansion Joint was spaced out 2 ft above "J" lug. to re-jay set down with left hand torque. (Need 1/4 of a turn on btm). Weight of complete string w/drag included is 180,000#. Baker Packer = 7" Model "F-H" Hydraulic set w/40,O00# shear ring. Worked logging'tool back into tbg. PO, repaired rope socket. Reran tool and logged fm 16114-15175. Ran 36'ft of 2" Scallop Guns & perfd fm 15326 to 15294. Unable to pull guns back into tbg. Guns stuck in' shear sub. Attempted to kill well by pumping down tbg but unable to do so because maximum pressure was limited to 3000 psi by low pressure connections on Schlumberger lubricator. RU wire T-Bar & pulled wire into. Line parted 650' below Rotary. Removed lubricator & installed top cap of tree. Unable to break formation do~ w/4800 psi. Pumped 444 cuft in 8 hrs into formation w/maximum press of 4800 psi. Well flowed back almost entire 444 cult. Made float valve out of ball valve dummey. Lnded same in ball valve. Removed Xmas'Tree. LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAGE NO .... Trading Bay Unit State IYELL NO. .G-14 .. .FIELD McArthur River 10 DATE 12/31/68 1/1/69 5&6 E.T.D. 16114 16114 16114 16114E0 16114ED 16114ED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Pulled tbg hngr &.stripped BOP over tbg. Installed & tstd BOPE. Unable to "J" into Baker Expansion Jr. Pulled 'off expansion jr, Displaced diesel w/64.5# Sodium Chloride wtr. Commenced pulling tbg out of hole. Pulled & laid down 484 its of tbg. Picked up wire line spear & d.p. Ran spear to 3243, caught & recovered approximately 14,000' of wire line. Commenced picking up 3-1/2" & 5" d.p. to fish for Pkr & expansion jr. / RIB w/outer barrel of expansion jt to p~ll pkr but unable to run same th~u lnr hngr. POH. .. Ran rope spear. Recovered approx 1,500. wire line. Ran expansion jr., overshot. Retrieved expansion jr, mandrel &'Baker tlydraulic pkr. Ran spear to recover remaining wire line & gun. Recovered approx 150- 5/16" wire perforting line & rope socket. 3-1/2" d.p. Laid d ownS.- \ \ Ran Dresser Atla~ 4" carrier jet guns. Perforated w/4 hpf fm 15272-15292 & 15226-15248. Set Baker Model F wireline pkr @ 15135' (wireline measure). Ran tbg as shown in tubing detail as follows: Tu. bing _Det_ail #2 Jts. 55 -- 52 44 39 35 .88 62 Description KB Elevation Tubing hanger 4-1/2" butt. tbg. 4-1/2" butt pup jt Otis ball valve landing nipple 4-1/2" butt tbg.' Camco KBM'- 1000# 4-1/2" butt. tbg. Camco KBM - 970# 4vl/2" butt tbg. CamcoKBM - 940# 4-1/2" butt tbg. Camco KBM - 920# 4-1/2" butt. tbg. Camco KBM - 901# 4,1/2" butt tbg. 4-1/2" butt x 3-1/2" XO 3-1/2" butt tbg. Otis type XO .sliding sleeve 3-1/2" butt tbg. Otis type X landing, nipple 3-1/2" butt pup jt Minus weight on.pkr Baker locator sub Baker seal assembley w/extra seals 2-7/8" butt tbg. . . Muel shoed collar 38.00 1.00 247.53 6.18 292.71 3.00 1706.15 2001.86 7.37 1611.15 3620.38 7.37 1374.26 5002.01 7.37 1209.14 6218.52 7.37 1092.45 7318.34 7.37 5847.42 13173.13 1.20 1924.94 15099.27 3.70 31.38 15134.35 1.25 10.15 -2.00 1.40 15145.15 19.00 62.91 .70 15227.76 ~8-6 its Totals 15227.76 Landed' tbg in Cameron head w/Cameron 4-1/2". hngr- Instld ball valve controls. Instld Xmas Tree. Chnged 'over fm 64.5# sal~wtr to Inlet wtr followed by 38,600 gals. diesel. Closed XO sleeve above pkr-.w/Dresser Atlas line. RIG RELEASED: 12:00 Noon 1/6/69. UNl ,.. q OIL OF CALl DRILLING RECORD ... ,EASE. Trading .Bay.,, Unit Sta~ELL NO G-14 SPUD DATE 'IELD M,cAr thur River AbandonmentCONTRACToR. .OCATION. TYPE UNIT PERMIT NO SERIAL NO.' ' T.D. T.V.D DEVIATION (B.H.L.) COMPANY ENGINEER .. SHEET A PAGE NO. . 1 COMP. DATE .. RIG NO.__ DRILL PIPE DESCRIPTION. ...... ELEVATIONS: WATER DEPTH IL T.'TO OCEAN FLOOR - IR. T. TO MLLW tL T. TO DRILL DECK IR. T. TO PRODUCTION DECK APPROVED: . B!,T.RECORD MUD,VEL. DEPTH & DEVIATi'ON · BIT JET DEPTH VERTICAL DATE DEPTH~ NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. JET 'DIRECTIONAL [3 5/17,/6,9 6823. 1R.R 8-1/2" ...... Reed YT1AG - Clean out. ran ' -' . .............. ............. . .......... . ............... ............ ..... ,, .... .... , ..... .... · ., ...... . , - ..... , , .................. r .............. ...... ........... .... . - ....... , .... '! . -- - . · , .. ......., UNI, " OIL 'CO.' Of CALIFC. . MUD RECORD SHEET B PAGE NO.. LEASE Tra~-',_ing Bay Unit State TYPE WELL NO.G-14 I I FIELD McA. rt, hur River Abandonment DISTRIBUTOR DEPTH WEIGHT I VIS, C. W. ~,. PH SALT OIL SANDI SOLIDS 19 6823 86 , i 5 5 i iI 3'0 10 .,,5 25500 8 1/2 13 · 20 6823 86 515 3.0 10.5 25000 8 i/2 '13 . ,- 21 6823 79 45 ' 3,2 10.31 2.5000 8' 1/2 13 22 6400 79 40 4,0 10,0 25000 8 1/2~ 13- Drld cmt , ., , ,, ' , _ , . , , , ,, , , . , , 1 , ,, , ,, , , , , , . . , , , , . - , ,,, .............. ,, LEASE UNION OIL CO. OF CALIFORNIA DRILLING RECORD - SHEET D oo PAGE NO Trading Bay Unit State 'j WELL NO G-14 FIELD McArthur River /~5&ndonme-nt DATE 5/'16/69 17 18' 19 20 21 E.T.D. 6823 6823 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Moved rig fr6m G-16. RIGGED UP: AttemPted to circulate 85~% mud. After pumping 280 bbls, the annulus plugged w/coal.- Unable to circulate. .Installed back pressure valve in tbg hanger. Removed tree. NU riser & BOP's. Pulled tbg hanger. Circulated w/85~ mud L killed well. Pulled 'and laid down 4-1/2" tbg. RIH with 8-1/2" bit & dp washed from 6613' to 6870'. Circulated out large quantitys of coal. Attempted to run Gatt&ua-Ray Neutron Log. Unable to get log down. Fished out nine dp rubbers. LRan Gamma-Ray Neutron'log from 6800' to 4000'. Set wire line "EZ" drill BP@ 6600'. Closed rams & pressured csg w/1500~. Held OK. Perforated 9-5/8" csg with four 1/2" holes @ 6525'. Ran a set RTTS pkr @ 6338'. Pumped into formation @ rate of 2 ft3/min w/1200~ cemented thru perfs w/300 sx Class "G" neat cmt. Max press 2800~. Final press 1200~. Cleared perfs. CIP@ 12:00 Midnight 5/18/69. WOC 4 hrs. Pulled pkr loose & circulated bottoms up. Re-set pkr @ 6338'. lob ~%1: Broke down w/1400~. Pumped mud away @ rate of 12 ft3/min @ 2000~. Reset pkr@ 6338'. Sqz lob ~2: Cmtd w/300 sx Class "G" mixed w/sea wtr. Unable to obtain sqz. Cleared perfs WOC 4 hrs. Broke down cmt job w/2000~. Bled off to 1200~:. Mixed & pumped 300 sx Class "G" cmt. Pressure built steadily to 2800~ then broke back tb 1500~,. Staged last 50 ft3. No sqz. Cleared perfs. WOC 5 hrs. Cmt job broke down'w/1800~. lob ~%4: Mixed & pumped 400 sx. Class "G" mixed w/sea wtr. Maximum standing pressure was 1500~. Staged last 50 ft3 , cmt job broke again while pumping w/2100~. No sqz. Cleared pelfs. C!P 11:00 PM 5/19/69. W©C. Tsts sqz Job ~4 after 8 hrs WOC. pumped 400 sx Class "G" cmt. 2500~,. Would bleed off to 1250,~. Broke down @ 1600~,. Sqz Iob ~5' Mixed Pumping pressure3slowly increased to Staged last 30 ft , No sqz. Cleared perfs. WOC 6 hrs. Tstd cmt lob ~5. Would ;not hold 1900=~. Sqz lob ~6. Mixed & pumped 400 sx Class "G"-Cmt. Results same as lob ~5 with the exception the standing pressure was 1700~. Cleared perfs.' CIP 9 pm 5/20/69. WOC 4 hrs. Pulled pkr loose. Circultaed & conditioned mud. Reset pkr. Tstd Sqz Job ~6. Broke down w/1950~. Sqz Job ~7: Mixed & pumped 400 sx Class "G". Max press (pumping) 2400~@ 6 ft3/rninute. Shut down pump press slowly decreased to.1800~; AFter 10 min. Pumped 4 ft3. Press increasing to 1900,!~. Then broke back to'1700~. Unable to obtain sqz over displaced 21 cu.ft, clearing perfs. CIP 8 am 5//21/69. WOC 6 hrs. Pressured perfs w/2000 psi for 25 min. No toss of pressure. Pulled pkr loose. POI-{. RIHw/d.a. top of cmtring @ 6334'. Drld Cmt from 6334' to 6580'. Closed rams & pressure tstd csg w/1500~ t0 rain OK. Drld cmt. to 6590. Void from 6590 to top of BP@ 6600'.. ~ LEASE UNION OIL CO. OF CALIFORNIA DrilliNg RECORD. Trading Bay Unit State DATE E.T.D. 5/22/69 23 SHEET D 24 7154 6393 VMELL NO. G-I4 .FIELD iMcArthur River Aba ndonme nt, DETAILS Of OPERATIONS, DESCRIPTIONS & RESULTS Drld BP, rm cmt below plug. Washed & CO to 7'057'. CO w/bit to 7110. POH to PU Globe bskt to attempt to PU remains of EZ Drill Plug. RIHw/same & drld to 7111', Where it stopped. POH & .recovered 1 pack-off rubber, 2 small pieces of metal & several large chunks of coal. RIH w,/bit & drld to 7154', would not drill. No excess torque. POH. Bit shows no sign of being on metal. Survey: @ 7154, 50° (original hole approx 540-550).. Believe hole to be sidetracked. Rib w/oedp @ 7145. Mixed & pumped 400 sx Class "G" cmt w/Inlet wtr preceded by 50 ft3 of caustic wtr. Pulled to 6859' & reversed out 304 ft3 cmt. Pulled up to 6487" CIP@ 1:00 am 5/23/69. WOC. RIH W/bit & scraper , fnd top cmt @ 6834". Cloased rams & pumped in form. @ 1400f~ @ 470 gpm. POH & PU Howco EZ drill retainer. RIH w/same set @ 6737'. Mixed & pumped 400 sx Class "G" .cmt w/Inlet wtr.. Pressure gradually increased to 2000~. Shut down pressure dec to 1850~. Pumped less than 1 ft3/min. Press inc to 2000~%.. PU out of retainer & reversed out 50 ft3 cmt. Mixed & pumped 150 ft3 Class "G" cmt spotted on top of retainer. Theoretical top of cmt 6393'. POH & 1.d. dp. ND BOP & riser. Installed 10' x 900. Series flange w/2" 5000~% valve. Well PLUGGED AND ABANDONED. RIG RELEASED @ 6:00 a.m. 5/24/69 . OIL CO. OF CALIF( ,_ , NIA DRILLING RECORD LEASE F/ELD ,, Mc. Arthur River SHEET A PAGE NO. Trading, B.ay Unit Sta~ELL NO. G-14 SPUD DATE Abandonmen tCONTRACTOR oo COMP. DATE .. RIG NO.. LOCATION- TYPE UNIT DRILL PiPE DESCRIPTION, ELEVATIONS: %VATER DEPTH PERMIT NO, ' SERIAL NO. I~ T.'TO OCEAN FLOOR .... ' ' ' R.T. TO MLL%V . T.D. ~ T.V.D. , · ', IR. T. TO DBILL DECK ~' . DEVIATION (B.H.L.) R.T. TO 'PRODUCTION DECK COMPANY ENGINEER , -, APPROVED: 'I ' BIT RECORD ' i ' MuD.VEL. DEPTH & DEVIATION ' BIT JET DEPTH' VERTICAL [2] DATE DEPTH 1~O. SIZE MAKE TYPE SIZE OUT FEET HOURS, ANN. ,JET 'DIRECTIONAL, 5/17/6,9 6823 .1RR 8-!./2" Reed YT1AG - Clean out r ~n , .i , . 21 I 1RR 8-1/2""' Reed YT1.AG - Drld )ut cm~ & Britg.e., p[,qg I I ........ , , , , - ,. , ...... . . ......... , , , ...... ........ .......... ..... , , , ..... . ....... . . , , , , - 3 MUD RECORD PagE NO.__ LEASE Trading Bay Unit ·State WELL NO. G-14 FIELD McArthur River TYPE DISTRIBUTOR. DATE I DEPTH WEIGHT I VISC. W.L.. PH SALT OIL SAND SOLIDS REMARKS · 9/68 620 71 38 8.7 9.0 9000 1 ' .' ' ~ .. , lO 800 75 46 ~.4- I 9 . 21OOOO 1 9% DDrld 11 2900 76 45 7.6 9,4 1!000 l-1/2 10. Ii ',.. 12 4100 77.5 56. 6.6 9.5 11500 2 - .12' ' 13 5417 78 53 6,2 9,6 11000 l-1/2 12 ' ....... 14 6225 79 55 6 5 9,4 12000! 1· '14 15 6251 79 51 6,6 9,2 11000 1-1/2 12 ~ . · .. . . · .16' 1359 .79 4O 5,0 9,5 1100O t-1/2 10 i - .. 18 3011 80 54 5.4 9.2 10000 1-1/2 11 Opened"h0ie 'to 17" 19 4889 80 43 ~.3 9.6 11000 l-1/2 11 ' ~ · 20 5291 79 42 5.0 9.7 11000 1,1/2 10 Fished & opened hole 21 . 6263 79 44 5.2 9.3 ] ] 000 1-1/2 q Openod bm] 29 7937 71 47 4.8 9.8 11500 · TR 1 10 . ' i 30 8400 73 49 5 11' ~11000 TR l-1/2i 11 ' . ~1 ggqq 7~ ~0 4.q 10.4 ]]0~0 ~/4i 8' . i 'l ~1/]/68 q~46 71.5 $~ 4.8 9.q 11000 ~)4! 8 ' ..i 2 9829 72 50_ 4.8 9.6 1]000 1 I 9 i i 4 10318 73 . 51 4.9 9.0 11000 1' 8 . · 5 ' lO.,'~g 7.3 48 4.8 9kO 11000 7 3/4 .9 '- . R 109q~ 72 50 4.4 "9.2 11 500 6 1/2 8 I 7 11~40 71. 52 4.8 9.6 .120O0 5 1/2 . 8 Poor hole condition 8 11500 70.5 53 4.6 9.5 12500 4 1/2 8 ' - - "- . 9 11840 74 52 4.2 10.8 11000 3 1/2 10 iChngd fm XC to Lignosulphonate '10 12~4~ 73 56 4 10.5i 11500 5 1/2 9 Hole condition improved · . 11 17360 73 5?_ 4.2 1.0.8 1]000 . 6 1/2 10' Hole condition imoroved _ 12 12~93 73 59 4.0 10.5: 14000 7 1/4 9 lq 177R7 ?& ~R A.& 1~.4 12000 5 · I 12 . · .... '!4 17996 75 55 &_-q . lO.& 170o0 '5 I. 12 15 12959 73 53 /,.~ 9~ 11500 5 1 1l · 16 13060 73 5n &:5 Q.a ]4000 5 3/4 11 - . . 17 '~ 2~q 73 61 A. 3 q_. 5 l~Oo .'5 1 1'2 18 13404 7q 56, t,_~ 0.5 ]AOOO 5 1 ll 19 ~a. v~ 5a A_~ q_~ ~4000 .4 3/4 10 ' - ,~a/a~ .i'5~0 75 47 3~8 9.9 15500 6 172 11 . --' ~' ~- 14173 73,5 48 3.6 9.6 15000 5 1/2 12 :~8 14469 - 73 47 3.4 9.5 15500 6 3/4 12 9 14760 '73.5 51 - 3.6 9.4 16000 5 -1/2 13 .... 10 14832 73 53 3.4 9.5 15500! 4 1/2 12 .11 14850 73 42 4.5 10.2 15000 5 3/4 10 Fished for cones 12 15076 74 47 4.3 10.3 19000 5 1 11 Added NaCi' to system 13 · 15270 74 45 4.2 10.3 19500 5 3/4 11. ' 14 15455 74 46 4.1 10.4 19500 7. 1. 12 . _ ... 15' 15550 74 45 4.4 10.4 29500 6 3/4 12. 16 15775 74 43 4.2 10~4 29500 6. . 3/4 11 . 17 15831 74 44 , 4.1 9 29000 5 1/2 10 -· · 18 16018 73,5 52 4.0 10 29000 4 1/2 10 19 16036 74 50 .4.2 9.8 29500 4 ·1/2 11 . · - 20 16'222 73 52 4,1 9.6 29000 4- 3/4 10 21 16342 73,5 48 4.2 9,7 28500 5 ' 1/2 11 24' 16342 74 50 4.4 9,4 28000 4 3/41 12 , . ~5 ]6342 74 5 51 4 2 9 3 27500 3 1/2 13' 11' 16114 Inl,~t wtr weight,.~d w/ ;odium ]hlori, ie" ~/1/6q 64.5 37500 Fishe~ ~o"~ Schlumberger Line · · ? 64.5 . 37500 Fished~ for packer. . _ · . , · . · · . · · · · . · . . ' . , · · . , , OIL CO. OF CALIFC IIA MUD RECORD SHEET B PAGE NO LEASE Trading Bay._Unft State .. TYPE WELL NO G-14 FIELD McArthur River Abandonment DISTRIBUTOR, , i i J ] -- I ' I L' i ~ SALT -~OIL SAlaD ~ SOLIDS REI~A1RI~S DATE I DEPTH WEIGHT VISC. W. , 5/18/6~ 6823 87 54 2.9 1.0.5 26000i 8 1/2 13 ' ' I 19 6823 8161 55 3.0 10.5 25500 8 1/2 ' 13 , I I 20 6823 86 55 3,0 10.5 25000. 8 1/2 13 . 21 6823 79 45' 3.2 10.3 25000 8' 1/2 13 22 6400. 79 40 4,0 10,0 25000 8 1/2-~ 13~- Drld cmt ,, , ,, . · · ..... - · , ,, , .. . , · , . · · . , ,, , . .. , , , .... ,, , , · , ~ ' · , ..... · , ., ....... - . . , , · ....... , , ......... , , , , . '1 ' .......... .... , , , , , · ' .i · , ..... · · · . .... , , · ' . · · · _ ,, , · ..... , . , -- '.~U','I~~. ,. , OIL COgD/NNY wELL NO. ,G-l~ D E C~ ,-;--I-~-F-- ALL 'F~ECOR D OF "SURVEY" CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE ~t-_ o', '.'~- ~': -: .-, _ 'U~ DEPTH ~GLF ? :,EPTH SEA DIREC 625 0 a5 52~.97 525.97 N 20 E 3.39 N 75'1..3 '"15 750".77 ' 651.77 N 70 E 5.80 ri '7~2 ~ 0 78i.69 682.69 N 82 E O.IO N 8~A 6 0 B~5.3~ 746.34 'N-75 E 1.83 N DOG LEG DISTANCE ANGLE DEG/,I. 0OFT DI ST~'~CE "<. · '3,57 N 20 ~ 0 E 0,27~ 0,00 _ 1-~.77 ;'4 ~o ~+~ 3 E J,~29 7.38 32,'/J N 7~ ~7 Z9 E 3,7~Z 1.22 E 7.93 E 10. O7 E g39 9 15 937.13 838.13 N 85 E -9.13 N 31.~3 E 1~55 19 ~5 1~39,89 t3~0,~9 S 88 E ...... t9~5 '25 15 lnlO,71' 1 ~I1,71 $ 85""5 2~56 47 C) 2152.99 2053.3q N 89 g ~:.q25 57 ~5 2.514,~T 2'a15.97 S 88 E 0.722 8,6~ N 147.16 E 1~'?.4i ,'~ 80 3d i~ E 6.99 · 0.20 S 687.74 E- 681.7~ S 2.33 11.83 S 123~.5u E iZ3d.6~ S o~ 27 9 E U.9~O 11~7.93 5_. , ' .~ ~. ' ~,5 57 15 3275,1~ 3179,1~ S ~6 E 75,29 5 2~34.1o E 443~.3~ S aS/5 55 a~ 3a03.70 330'~%7U S B5"'E ~1,98-5- Z6Z4.9/ ..... ' 823. 59 ; .... ' & 1 5 15 ~279,99 ~l@O,q9 S 78 = 358.6~ · ' .......... s 8191 59 0 5322.59 52 .... B't, ]. 6'-6'0 ' o" ~,,,'~ 5 ,'09 --..5-~' ' ' " WON - 3 ZZ E,.99 S 1~ 133~ vT'TOETI 3~N~O]D 2qO~,,,~O±iO~ ' 60'~gOTT O~?'I O~'~T.OTT,. . L~O'T ~'6~OT ~8¢ '0 ~ Z~ TT L~ 9 9~.~60TT ~ TO'T£ZCT ~ §I'IO~ 3 gE' S I6*~OOI I6'lvlOI gV 9v ~LL~T 3 9T -~ ~T ng'~g~OT nOn.m 3 6 Z gL S OL g TL'~g~OT ] 9~'0~98 g ~L'g£gg TL 9 oI'~L~Ol 3 G~'~T/.6 9 ~9'E~£ 3 gg 9 06'9g~6 Z/'~Ca6 3 09'~g~6 S 61'6E0~ ~ 9~ 9 ~_.~_/ 9 ~*~026 ~ go'g999 S £g*gj..~Z 3 I~ $ 16'0_ ~B . ~L g 96'~T6 /3 ~g'gzgg' g ~I'~2 3 Z~ 9 ~'O~Z~ ~L ~ L6'9606 ~ ~9'~LLg S OB'~O~.Z 2 ~§S 6~.0Li6 ~L ~ OL'gL6g 2 99*gggg 9 ~G'LZ~Z . 2 9G 9 g9'090~ gL 9 G6'6g~g_/42 6g'~T~g S L~'TZOZ 2 Lg S .Og'I6~L 9L 9 O0'~T£g ~.,gE'£gOg 9 90'9~6I ~9'1~v6 0 9P Z£6~I 06'gg£6 0 g~ Igg~I ~E'L'EE6 0 9~ 69~ · ~'~96g 0 gg 6~0~1 ~L'~Ogg gT £g E~'6E~ ~I'~ 9~0~I ~9'8~1W Cg g~ 9GLUT 6~'96EL 0'~ O~ 6~" LL ~ ~'TOT~ 3 .6g'~6PL S LT'hTgT T6T'T 3 i~T Z/. S L6'I.L~L 3 Z6'g69L S ~6'Z69T gl. 9 Tg'T~9L 3 Z6"LL'~L $ gL ~ IO*~L~gLZL 9 gL*vLSI gL 9 ~g'[/.'~L 2 Bg'g~TL 9 le¢'o ;3 zz ~,LE"O 3 [E: ,496'0 ~ ZT TI 6L 9 ~6'~It! ~ ~L*LB69 S T~ 6L 9 ZI'606g /13 00'98L9 S TO*9gZI 2 gg'~9~9 9 90'g9lI ~ 2 ~G.'gg~9 9 O/'ggOl 3 Lg '$ gS'g9~L B6'Lgg£ 0 Eg 9£~I1 3 6g S ~I'~6~L ~T'£6~L ~ L~ Zg~IT 2 19 9 ~£'080L ~£'6LIL gI 6~ ~II .~__~9 9 gg'~B99 ~9'~8L9 Og g~ 6190I 2 ~9 g ~I'2[g9 g1'1£99 0 L~ OOvOI TgZ'T ~ O~ ~ 8L 9 ~6'L999 ..... ~T6.,*O ...... 3_Z~ g.Z O~ g ~Z'LZC9 69 S £f~'~619 £I~'Z6~9 Gl 6'~ 9696 69 9 OI,'OGI9 01'6'~9 0~; 6'~ 6Z66 IL 9 ~g'~g6G +~g'~g09 0£ I~ 07_ cj Ig'6OLg I¢-,'gO$C5 0 L~j,,.,.i{£t6,~u .. , / . . DEPTH DEPTH SEA DI'FFE'REN'CE CORRECTION -' toTAL"' cOO'ROi aAT~s 399 399. 300. 0 &99 499. 400. 0 599 599. 500. 0 699 699. . 600. o 799 799. 700. 0 900 899".' 8'0'0. 1 1002 999. 900. 3 5 8 i'i 110~ 1099. 1000. 12.07 1199. 11C0. 1"310 12'99. "1200. la13 1399. 1300. 1'520 I699.' 1~00'. 1631 1599. 1500. 32 ..... 17~1 1699. 1'6'00. 42 1852 1799. 1700. 53 ....... 199~" ' 1~'99. 1800. 95 ..... 21~1 1999. lqO0. 1~2 22~8 2nn5 2621 2~09 2996 3183 3'371 35~8 ,, ~115 /+666 0.57 3.03 - ~ ' 4 .""/~ o-~ o 6.5'/' 8.99 8.2'1 2099. '"2OO'O. 189 2199. 2100. '2a6 2299.' 220~. 3'22 23~9. 2330. alO Z'499. Z~O0. 497 2599. 2500. 2699'~ 2600. "672 27~9. 2700. 759 zBqg,' 2~00. 848 2q99. 2900. 931 3199. 3100. 1101 3299.. 3290. ........i185 3399. 3300. 1267 '3A99, .... 3~0'0." -1398 3599. 3500. 1~28 36V~. "~600. "'I~US 3799. 3700. 1588 3999, 3900, 1773 4'099, ~000:, 'iB68 ~199, ~100, 1962 0 0 0 0 1 2 2 3 3 7 11 i0 1 1 '42 .~7 57 /6 88 87 87 88 87 85 85 82 81 80 8O 94 94 g.lO '2.00 ~.11 4.94 3.07 A.'20 0.90 O.il 5.~2 i6.40 27.54 45.01 S 66.70 $ 78'.0b'5 91.35 S 114.2W S 7.70,5 5O27 13 ,,_ 53,87' 184.53 S ~ .... 5772 257.0~ S . 596 i zV~+":'~+'6' ~ 5161 3~1,90 S ~ ......... i iii .... ' ~,~ ...... 42~w. 4zOO. 20~. i ~ ........ ~o~-*-O0 "~' · N 137,16 E N ...... h Z21.92 ~ S ' 268.90 E S '315.8~ E s' ' 4't'6;'~"'E S 523.26 E S 6'30.'4'9 N 751.29 E S 105~.89 E '$ " l~'I'~'.gB g S 1371.68 E' S 1688.~7 E 2001.27 E 2~11.~4 ...... z4b..~,~ ~.-. .- 2617.82 E 29'13·65 3209,~9 3531,18 3855,51. E ..... ''-'~UU.i·~ . ,. - . . . "6?o4 ' z+49,~. '"~.~+00.' '2Zo'~ "-fz ..'":- : ".:.:':-: - :~.:. 6878 - ". .~5'99'--t::'~'::.~500. 2279 ' .: ,,';. 7~ ' .:']'.~.':...~ 451.96 ~ ~ : ~ ''' : ~:~ ::.::':" ~ ~ , ' ~.' ;''''A ~ : ~.:::: --..~. ~ : --.':. : .' ' ~.: '~ ' .... ..... '' .' . ': ''' ''~' '~''' :~--'~''' '''--' '~ ' :'--': '--':': ' : '' ~': : .1'''' '''-- : '',- ~' T ' r -- '-- : ' ' ' , ~.''~-- : ' '. . ' ' : ' '' ', ''' ''' .... ~ : ', .... "''' ...... · , r ~ '' .............. '' ' ' ':' ~ ...... ' '' ..... ' ' ' ~: : '' :' ' ....... ' ~' b30o69 S ~712'o18 E' 570'°06 S · bi.J,9~ S 499Z.i7. E. 3232 7C1.3/ S 5>'9i /5b,2~. 5 ~,+'/.8i E ~lg.!J S DSu~'J.26 E ooi.1/ iS p'/69.~6 E : .:4.7 .99d.13 S ~.j~0.37 ~ .':..",.:':".."":.84". 1~5C,.,7~ S ilT..~a S 65d2.54 5 i3g'O.'~ i' S 69,jD.26 i3'a3.~.4 S,. '/00'o.'4~ ;-' i:3h. 9.g6 S'' 710b.62 ~ i43~.io .S -7i~o'.39 = i~+~2.51 S 729i.97 '= 2~2~,i,5' S 2 Z '2 2 ~'05~,57 S'. ' 9~7.90 E ~"~9,0~'~' . '95'5'~','07'E 3219.52.S' 9~.18..:23'E · 42 5272 3298.79 S 96~0.~2 E 531a 3380.1'9 S 9741.45 E .. ,:-i;7,,;,,i:i;,.',,,.-.,.,9'~+99o'- 9400. 5358 ~.4 3~.65,02 s ~uo.~ E "' "<;.~%~-~?:.:t.'.'~':959.9~ 9500, 540.2 4~ 3~50,0~ S 985~,3'~ E , 5443 548'3 5525 5570 .3635.34 371-d . '/~ 3~C9.3Y 5515 5566' 5'717.. 51" 420~.. 90 . . . . ~ , : -- '_ -:: - F~~!'. '.r,.~SU~,.,., ,~),- I ~. S 99i2.01 S 9'961.A,B - E S' i3007.65" ::.- S i 0052. ,92 S 10097.8'4 g $ i'01'42.56 E $ 10i57..11 E .~,_~;..&:·.:....... :'. '" 0 O: i:?:i.:: .5. 2. 2.. z,, 5125 · 715 o 6 B S ~/ :53 ::30 · ~ 6 E y/ DRILLING CONTROL CORP. =.~v NO. , t _, BU~VEY DATA SHEET COMPANY Union O!,! Ccx~pany DAT£ Dec~ec 1968 Jos NO ....... WELl TBU G-14 FIELD Cook Inle% COUNTY., STATE,,. Alaska TRUE RECTANGULAR COORDINATF, S MEASURED DRIFT DEVIATION' DRIFT DEPTH .ANGLE VERTICAL COURSt~ DIRECTION .. - REMARKS . . . ; DEPTH NORTH SOUTH F.,AST WEST · . 352 ' ' 352 00 /~_qSE .VIEDVEI::~IC. AL TO THIf DEP"I~: '625. 0° 45' 624 98 3 57 N 20° E 3 35 i 22 · 751 3° 15' 750 78 7 [4 N 70° E 5i79 7 93 782 4° 00' 781 70 2 16 N 82° ~ 6 09 1~ 07 846 6° 00' 845 35 6 69 N 75° ~ 7 82 ~6 54 . 939 9° ~5' 937 ~4 14 ~5 N 85° ~ 9 12 31 44 ~39 ~1° 45' 1~32 94 40 72 N 87° ~ 1~ 25 72 11 ~455 13° 45~ 1439 87 75 11 $ 88~ E 8 63 147 17 ~865, 25° 15' 18~0 70 174 89 $ 85° E 6 61 32[ 39 2366 47° 00' 2152 38 366 41 N 89~ E 20 6~7 73 ., 2546 53o 15' 2260 08 144 23 N 89° E 2 32 83~ 94 3026 57° 45~ 2516 2~ 405 ~4 $ 88° E 11 84 1237 64 3707 57° 45~ 2879 60 575 ~4 S 88° E 3~ 94 1813 2] 4446 57© [5, 3279 38 62~ 53 $ 86° E 75 30 2433 24 4675 56° 45~ 3404 94 ~9~ 51 S 85° E 92 00 2624 02 54~7 56© 15~ 38~7 17 6~6 ~5 $ 8~° E [88 51 3233 38 6208 59© 00' 4224 53 678 ~2 $ 77° E 341 03 3894 02 63[0 56© ~5~ 4281 20 84 91 $ 78° E 358 66 3976 98 6499 58° 00' 4381 35 ~60 28 S 76© E 397 43 4132 50 66~ 54° 45~ 4445 ~9 91 ~6 S 82° E 410 ~6 4223 07 6650 54° 00' 4468 9~ 31 55 S 80° E · 415 64 4254 ~4 6866 54° ~5~ 4595 [0 175 ~1 $ 79° E 449 09 4426 22 7487 55° 0O~ 495[ ~ 508 72 S 74° E '589 30 49~5 25 7802 . 57° 00' 5122 87 264 18 S 74° E 662 12 5169 20 7903 57° 30' 5177 13 85 [8 ~. S 73° E 687 02 5250 65 ............... , , m ..... DRILLINGsugv~yCONTROLDATA. 811~ITCORP' s.eeT no. 2 .,, COMPANY . . . Union Oil Ccmpan¥ DATE, December 1968 JoB No. WELL TBU G-14 . F~ELD Cook' Inle% COUNTY ..... STATE, Alaska TRUE RECTANGULAR COORDINATF_~ MEASURED DRIFT DEVIATION DRIFr VERTICAL , . REMARKS DEPTH ANGLE COUBSE DIRECTION " ' DEPTH NORTH SOUTH EAST WEST · 8191 59° 00' 5325146 246 86 S 70° E 771 45 5482 62 8416 60° 00' 5437 96 194 85 S 69° E 841 28 5664 53 8791 60° 00' 5625 46 324 75 S 69° E 957 67 5967 72 9132 57° 00' 5811118 285 99 S 70° E 1055 48 6236 46 9573 51° 30' 6085 70 345 13 S 71° E 1167 85 6562 78 . 9829 49° 30' 6251 95 194 66 S 69° E 1237 62 6744 52 9896 49° 15' 6295 69 50 76 S 69° E 1255 81 6791 91 10,175 48° 30' 6480 56 208 96 S 68° E 1334 09 6985 65 10,400 47° 00" 6634 01 164 55 S 65° E 1403 63 7134 78 10,619 45° 30' 6787 51 156 20 S 63° E 1474 54 7273 96 10,908 51© 00' 6969 38 224 59 S 64° E;I~ 1573 00 7475 85 · 11,234 49° 15' 7182 19 246 99 S 61° E 1692 74 7691 86 11,552 47° 45' 7396 01 235 38 S 59° E' 1813 97 7893 62 ~ 11,836 52° 00' 7570 87 223 79 S 57° E ~ 1935 85 8081 31 112,035 52© 00' 7693 39 156 81 S 5?° E 2021 25 8212 83 12,359' 50° 30' 7899 48 250 00 S 56° E 2161 05 8420 09 12,496 50° 30' 7986 62 105 71 S 51° E 2227 58 8502 24 , 12,756 48© 30' 8158 90 194 73 S 56° E 2336 47 8663 68 12,926 49© 45' 8268 74 129 ~5 S 54° E I' 2412 74 8768 65 13,016 48° 15' 8328 67 67 15 S 52°'E 2454 08 8821 57 13,080 50° 45' 8369 16 49 56 S 51° E 2485 27 8860 09 · 13,302 53° 15' 8501 98 177 89 S 49° E 2601 98 8994 34 13,725 51© 15' 8766 74 329 89 S 47° E 2826 96 9235 61 13,942 54° 00' 8894 29 175 56 S 47° E · 2946 69 9364 01 [/ ~14,089 55© 00' 8978 61 120 42 S 46° E 3030 34 9450 63 i~, ....... ~ , ..... ~ , , · , , DRILLING CONTROL CORP. a,~v .o. 3 81I]~V~Y D&T& eOM.ANY. ~nion Oil C~~y .... DATE .~C~ 1968 .... ~os No ..... wEc~ ~U G-14 F~EUD C~k ~let COUNTY ..... S~ATt ~aska ~ ~T~G~R ~~A~ · ~ASU~ DRI~ D~IA~ON D~. DE~ ANG~ VER~CAL CO~E D~N .... - .... RE~~ D~ NO~ ~U~ , ,, ~ST ~T 14,280 52° 00' 9096 21 150 51 S 43° E 3140' 42 9553 28 14,469 46° 00' 9227 50 135 95 S 39° E 3246 07 9638 84. 14,651 45° 00' 9356 19 ' 128 69 S 38° E 3347 48 9718 07 14,832 46° 00' 9A81 92 130 20 S 35© E 3454 13 9792 75 14,977 46° 00' 9582 65 104 30 S 35° E 3539 57 9852 57 15,1'01 45° 30' 9669 56 88 45 S 32~ E 3614~ 58 9899 44 15,271 44° 00' 9791 84 118 10 S 31° E 3715~ 82 9960 26 15,459 45° 30' 9923 61 134 10 S 27° E 3835~ 30 10,021 15 15,625 46° 00" 10,038 93 119 41 S 27° E 3941 70 10,075 37 15,778 · 46° 45' 10,143 76 111 44 S 25° E 4042 70 10,122 47 16,018 48° 45' 10,302 00 180 44 ' S 23° E 4208 80 10,192 97 16,153 49° 30' 10,389 67 102 65 S 25° E 4301 83 10,236 35 16,246 48° 00' 10,451 90 69 11 S 25° E 4364 47 10,265 56 16,342 47° 00' 10,517 37 70 21 S 25°. E ~ 4428 10 10,295 23 .~S~ ~1,205.~23' S .660 43' E . .... ,, ,, ' ~ ~ , . .. : . ..... m .......... ,, .. i !!.. i . . ii/ . . J .11 i i i i, aEPORT and PLAN of SUB-SURFACE SURVEY UNION OILCOMPANY · B.U. G '14 COOK INLET, ALASKA JOB NO._ DRILLING CONTROL CORPORATION LONG BEACH, CALIFORNIA OIL --"-'~,,'=LL ,%!O. G-14 OBJECT!VE aNGLE S'70E ALL CALCULATIONS ~ECOR'D OF SURVEY PERFOR>4ED BY I B M ELECTRONIC COMPUTER TRUE --,~:.. , ~ -_- .~.!- -'L DEOTH ~,~GLF ~ DEPTH 5un 5TCI-FT DtREC D-E~, 625 0 45 5-24.97 526.97 N 20 E 751 3 15 750.77 '651.77 N 70 E 7~2 4 0 781.69 682.69 N 82 E DOG LEG DEG/100FT DI$1,,,~CE :;], _....---..,,.,.,~ -] _ -: -: U N '_ -' D ! 5TANC'E ANGLE ,-.,j,' - U.6O ,~,' u.~ ',',i __L: -'~'." : 3.35 .N 1.22 E '3.57 ,N 20 O. 0 E 0.27~ 0.OO o. I0 N 10.07 g £i.77 ;'~ bu ~ 3 6 J,~+29 7.38 1.85 ~ 16.~ ~ 1'8-~29 ,~'~ ~ 39' 16 E' ' 3.'2-61 _ / · p~ _ - /~ - U. 14'?.41 .'~ 8o 3S 1~ E 0.722 68Z.'74 S o~ 5m ~9 E ~,~9~ i23~,64 S 0~' 27 9 E 0.9~0 11~7.9~ 939 0 15 937.13 838.13 N85 E 9.13 N 3t.~3 lg55 13 45 1~9,89 1340.~9 $ 88 E 8.64 N 147.16 ' -i965 25 15 1~10,71 1'/11,71 ' 5 85 E 6,59 5- ' ~Z1,39 2~56 47 f) 2152.39 2053.34 N 89 E 0.20 S 687.74 . . , ~ 11,83 $ lg3~o54 ~25 57 a~ 251~.q7 2415 97 5-~8 .. :.] ./ . . · "~ - ~. U · ~,5 57 15 3275.1~ 3179,1~ S ~6 E 75.29 S 2~3..lo E ~43~.3~ S ~o 13 4417 56 15 4R15,93 ' 3w16.9~ S 81 E 188.49 S 3234,3~ E 323~.di S S6 39 52 E 0,~5~ ~03,~ .'i .... ' - ' ' ;-_~ ,_ 320 ~109 55 "~ 79 S 82 E 410 1~ S '~Zz4.01E 4~43.88 S 84 27 14 E >. . 6611 54 45 4~44,79 4345, _,:. ., . .-_. -__ -o . :-:- . 6866 54 45 4592,24 4093,24 S '79 E 449.30 S 4428.~ E 44~i,07 $ 8~ 1.2 23 E 8191' 59 0 5322,59 5.2 " '..:'$791 '~0.: 0 .§622.59:5~2~.5'9 $' (:9' E:-~':".' 957,89-.S.' 59~9.8~ E,: ~0~,~.~7 S 80' ~.~ '. ~' E ' O,UOu'' ': ':.' 59~?.~0'' ~ ' / 0 5808,3-1 5709,31 S _~1 30 6082,84 5983.84 S ~ .8~9~6 a9 30 6249,10 6150-10 $ 49-15. 6292,83 6193,83 S 10175 a8 30 6a77,70 6~78,70 S lOaO0 ~7 0 6631,15 &532,15 S 10619 45 30 678&,6~ 6685.65 S 10'908 51 0 6966,52 6867,52 $ 70 E 1055,70 S 6238,'59 ~ 6327,24 S 80 2'3 42 E .... 0'.9i5 71E 1168,06 S 6564,88 E 6667e9O S 79 54 40 E 1,261 69' 5 i237-82 S 69 E' 1256,01 S 6794,00 E 6909.12 S 79 31 33 E 0e37~ 68 E 133~,29 $ 6987,74 'E ' '7i13.9~ S 79 11 .... 22 5 0,381 65 E i~03.84 $ 7136,S8 ~ 72.73,64 $ 7~ ~J 18 5 1,191 63 ~ 147~.75 S 7276,05 5 7424,01S 78 32 31E 0,951 64 E 1573,21S 7~77,92 E 7641,61S -/~ 7 9 E 1,920 1123a 49 15 7179.32 7080.~2 S 61 E 1692.94 S 7693.92 E 7~77.97 5 77 35 26 E 11552 47 45 7393,14 7294,14~ S 59 E 1814,17 S 7~95.69' E ~101,4~ S 77 B 35 E 0,667 11836 52 0 7557,98 7468,98 S 57 E i936,06 S 8083.38 E 8312,00 S 76 31 50 ~ 1,590 7186,61 7~0~ · 9~ 12035 52 0 7690,50 12359 50 .... 3'0'7896,59 12756 48 30 ~159,65 8060.65 S 56 E 12026 aq ~5 8269e~9 ~i70,49 S 54 13016 a8 15 8329,42 8230,42 S 52 E 13080 50 a5 8369,91 8270,91 S 51 13302 53 15 8502,74' 8403.74 S 49 13"942 54 0 8878,~3 8779.93 140~9 55 0 8963',24 886~.24 $ 46 laa69 46 0 9227,21"'9128,21 S 7591.50 S 57 E 2021.47 S 8214.89 E 8459.95 S 76 10 32 E O,OOu 779?"'59 "S 5'6 E 216'1,27 S' 8422','i6"'~ 8695,05 S 75 36 26" E 0.5'22 232~,5~ S 8~8,6~ E 897~,70 S ?~ ~8 13 E U,~04 2'403,80 S 8773,63 E 9096.97 $ 74 40 ~1E ' 1,19~ 2445e14 S .8826.54 E 9i~.96 S 74 30 98 E 2,364 2476.33 S 8865.06 E 9204,43 S 74 23 34 E 4.083" 2593.03 S 8~.~0 E 93~5,~3 S 7~ ~5 34 ~ 1.331 2'946,t9 S 9377.98' ~ "'9829.87 S 72 .33 34 E ' 0,2~'8 3029,79 S 9~64.60 E 9931.72 S '72 1~ ~b E ~.877 3242.23 S 9636.6'~ E t0t67.~3 S 71 2~ 16 E 2.760 la~32 a6 0 ia977 a6 0 15101 a5 30 15271 a4 0 ' 15aSq a5 30 15778 a6 ~5 IAOi~ ~ a~ 16153 a9 30 la651 45 0 9355.90 9256.90 S 38 E 9aS1,6a g382.6a S 35 E 3450.29 S ~7~0.53 q532,36 qa83,36 S 35 E 3535,73 S 98~0,56 9669,28 9'570,28 ' 5'32 E" 3610,74 S 9897.2~ 9791,56 9692.56 S 31 E 3711,96 S 9~58.05 0923,33 982~,33 S 27 c 3831,4a S 10018.9~ 101~1,91 10042,91 S 25 E ~0~2.0~ S 1~1i7,1~ i0300,15"10'20"1o'15' S 23 ~ 42~8;'1"2 S 1'0i6'7,62" 103~7,83 102~B.83 S 25 E a301.15 .S 10231,01 163a2 ~7 0 10516,"7~ '1~4'1'7,7'2 S ~'5 ~OTTO~ ~OLF CL'O-~"URE 11201,1~ FEET &T"$ 66 43 22 E 89~1.94 ., 99~0.U6 E 10275.1o S 71 u 3~ E V.67~ 10£73.51 1038u.71 S 70 35 13 z 1,309 10465.71 S 70 1~ 16 E u.uOo 10555.30 'S'69"57'2~ E ' 'i,779 10627.39 S 09 ~ ~D E 0.97D '10'726,55 S 69 ~ 19'"E ' 1,69'7 10~94,68 SOo i3 19 E 0,99o !iOkg.52 ~ 67 33 22 £ 1.037 1!09do36 S ~7 11 5~ E 1.gEO 11201,14 $ ~ w3 ~2 E .... 106£7',07 10~9,44 ...... 110'1~, 50 11085.09 ,,. , . · MEASURED DEPTH AND OTHER DATA FOR 'EVERY EVEN 100 FEET OF SOB SEA DEPTH- .11 , Il Ill, Il Il 11 , I Il I I tl I I 111 I I , I I I , J , · ........... . ..... ~_~t- .. - ' R CAL ' MEASURED-' -VERT 'CAL". SUB,' MD TVD , .' .--' VE -TI :.".-~-, ,'- . - '.-.... - ,..-'. ,,-'., ,...,,.,.""~".¢,"-"". ,."; .-. ~ --:-.:.-~ ~.:.: ~.,'. . , ~ · ='?~ :. ,' -.~ _ -- ..... .. ,, . ..: ::, .,..-,, :.:.- ~ ~ ~ ~ ~ ~ ..,' - .- ~.J,~ - 47. ~ ~: ~,, ~ ,~ .... '~ ??f,~' ~' ~'' .,y . '~:,., ,, t ,s ~ .L~, , ., DEPTH DEPTH SEA DIFFER'ENCE CORRECt'ION ....... '¢'OTAtL ' cb'ORDINATES ............... :'=~---' 399 399. 300. 0 0 0.57 ~99' ~99. ....... ~00. 0 0 599 599. 500. 0 O' ,-~ .~ 3.03 ,, 699 699"; .... 600'. 0 799 799. 700. 0 0 ~ ~ ~ 6.57 900 899. ' 800. 1 1'.--."- -,--~ ~ 8.59 loo 99. 9oo. 3 ti0~ 1099. 1000. 5 2 ~ ~ 10.89 ~ 10.70 1207 1199. llCO. 8 1310 ' '1299. ..... 120~. lfl13 1399. 1300. 1~ 3 8.99 t520 la99. i~00. 2t 7 6.21 1631 1599. 1500. 1741 1699. 16'00. ~2 1852 1799. 1700. 53 ....... i9'9a 1899. 1800.. 21al 1999. 1900. 1~2 2288 2099. "200'0. .... 189 2'621 1 i0 2,00 il ~.11 42 4e9~ .aT 3.07 0.93 0.ti 3558 37A5 ~1!~ 5027 " 5387 ,o 5772 ' 596/ 6161 ? 111 .................... ~+7 57 2199. 2100. 2a6 2299. 2'200. 322 2MOQ 23Q9. 2330. al0 88 5.42 2996 d499, '"'Z~O0. ;' 49/ 87 318q 2599. 2500. 584 87 3371 2699, 2'600. 672 88 2799. 2700. 759 87 2899,' Z~OO; 846 2q99. 2900. 931 65 ~9. 3"000, I~15 3199. 3100. 1!01 85 3299. 3200. 11~5 3399. 3300. 1267 82 3499. 3~OO.' '134B 3599. 3500. la28 80 "' 36V~.' '36u0. ..... lbO's 3799. 3700. 1588 80 3899.' ~00~ i67~ 91 3999, 3900. 1773 94 ~09~. 4000. 'l'u~ A199. ~100. 1962 94 ........ '~2'9W. ~200." 20~i 27.94 66.70 91.35 114.2W 137.70 g57.03 331,90 N 0.21E N 1.10 E . _ N De AY'" ~ ' N 11.83 E -' 'N Z~.'Z4'"E'' ----' N ~o27 E - N 65,o'5-E N 88.25 E N 137.16 E N ..... ~7~'.~"~-% N Z21.92 L S S '315.8~ E ,,, 'S '' ~i'6.O~""~ S 523.26 E $ ' 630.~9'g N 751.29 E N 896';~0 E S 105.4.89 E , S 1371.68 E 1~30e07 S1688.~7 'S '184~.1~ h S 2311.44 ~ S 2617.82 E S 29'13.65 E S 3209.g9 E' ,, 5 3531,18 5 b '3b~,~"~ , S 3855.51E . , ,, · 6532 4399, 4300, 2133 86 ~+01,13 S 4'159.85: E a,?o~ 4'~.~'~. .....~',,:+OO.' 2Zo'~ i2 ..... , ...... 92'~-.i3-'~ ....... ~z~u,u3 ,E- 2'~,':-f~~'~... . 6878 . ' ~599...;:.~500. 2279 .- 7226 4799, 4'700. 2427 74 b30.69 S 4712.18 7~01- 4899. 4800. 2502 75 570.00 S ~8~9.46 7580 4999. 4900. 2581 79 oiv.9o S 499Z.i"; 7763 5009, 5000. 2664 83 55).43 S 51~o.ZO £ 7951 5iq9. 5100. 2752 88 7C1.3~ S 81~5 52'99. ~3A~ 5.399. 8544 5499. 5aO0. 8931 5699. 5600.' 3232 87 99'J.1'3 9115 i~SC,.-,'w S 0,'25,07 E 579'9. 5700. 33i6 84 - , 9278 " 5~.o9. 5~0. '%77~ 03 9,a38 5ag9. 5900. 3~'b° 50 959~ 6OqO. 5030. 3~oo ~,0 9905 .,520~. 10056 6399. 1o2o6 lO35,'3 i0~+o7 108'01 10958 lllil 11263 I lZ.,. 12 11552 1'1724 11886 ].20'4'8 12206 ' 12393" 1'25-14 12664 12S17 12970 13129 1329'6 'l 3z, 66 1363'~ 13~06 1~,140 14'2'8 ~. "14~+ 2 8 9199 .......... . .- · _.l.~ ': : ...... ....... j-~. '- 63'3.3, 3657 5i 6a~9. 6a00. ~7~'7 bO S 65QW. 65~ ~74.4 47 3'798 '~4 3~a3 z.,.5 5F,:>,O · 39 :) ~- ................. 59 ~c~'"'3,,, ,; , 995':-. 57 75~ ('" :Z.'· ~i2 7 I-C'9. 4. C 6"- 52 · .., ,-; ~3 50 6699. 6~99. 6999. 7199. 7399. 7a09. 7~(30. ~225 62 7599. 7500. &2~7 62 769'9'"~ 760~, ~3~'9 ' ' 62 7709. 77~ ,,. ?=9~ '7o00. a5!5 51 8099. 8000. a555. ~199. ~190. 46ia 8209.' 9230'. a~71 ~399. 5300. a730 8409. ~400. a797" 8599, 8500. 4867 8699, ..... ~6O'O. 8799, 97{)0, 50d7 8899~ 'RR'O0" 8999, ~900. 5141 9099, .... 9000. 5'18'5 9100, 5229 53 53 ~9 67 70 70 ?i ~3 i17~,:~ S 6502 i215,~v 5 6-o9i,o5 i25s.6~ 5 c:ovo.~6 i3~9.Z~ S ' 7!0D.6~ -- , iae2.5i S 7Z91,97 loio.2o S 7~oi.9~ f 9299. '9200'~' 5272 43 3298.79 9399. 9300. 5314 42 3380,19 ~550o0Z 9741.45 la857 9499. 9400, 5358 150'0'1 9599. 9500. 5402 aa 151a2 9699, 9600. 5443 al 3635.34 15282 9799, q'?O0, 5483 aD 371d,Vv 15'~'24 98o9, o800, 5525 g2 15569 9999, ogO0, 5570 45 15715. 10009, lOOOO, 5616 46 S 9961,~U ~ s s ~0052.92 E 'aO00.bo S !~097.~4 = 15865 10199, lOlOO, 5686 16016 10299, 102(':.3. 57i7 Pt' 4101.9~ 51' 3 lO14Z.~o INTEROOLAT'FD"'V~LUES eOR EVE~ 'it)SO vE~$UqFD VF~TIC~L St.J~ DEOTN : ~OT~ ~a 100~ 2000- 3000 5000 · 6000 7000 8000 10000 11000 ~, 12000 , 13000 [ -laO00 -' 15000 16000 ~ __ ._, J~._ _ i. ,t ... ... 49.!2 ~6q. 4'~. 479.56 522a. 5125. 715.68 5736."' b'53'!o 10i7.8g A361.' 6262. t285.19 ~Z6':,' 7 692~. 1606,99 7568, 7569. 20u6.45 83t8, ~ZI9. 2~37~,7'9'" S q~12, ~813. 2979.15 9598, 9499, 10288, 10189, ai95,66 i{ Drill Pipe or Tubing ................ Reversing Sub ...................... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly X. 0.ver sub Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ O, D. Jo Do 5II 2.25" 2,764" 11 5" 5" 5" 5" .87" ' .'75" 3.06" 3.06" 1.75" 2.44." Multiple CIP Sampler ............... Extension Joint .................... AP Running Case .................. II Hydraulic Jar .................... VR Safety Joint .................. Pressure Equalizing Crossover ......... Packer Assembly ................... 8.25" Distributor ........................ Packer Assembly ................... Flush Joint Anchor Per.for. a.ted, p.~.pe Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ 2 7/8" 3 7/8" 3 7/8" Packer Assembly ................... Distributor ........... / ............ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Temp case Blanked-Off B.T. Running Case ........ Total Depth ....................... 3 7/8" TICKET NO. .... 49371 fi LENGTH II 3546' 184.16' 3.75' 5.02' 1 4.10' 4.10' 5.02' 2.61' 4.58' ,. DEPTH 10.10' 4.90' 4.90' 3508' 3731.93' 3736.93" 3741' 3745.13' 3754.55' 3772' 3777.24' 3778.74' 3910' PBD IroRI4 IIIIT-.-PIqlNTED IN U.B.A. EQUIPMENT DATA LITTLI'I. d Ticket ' FLUID SAMPLE DATA Date 7-4-74 Number 493715 ',~_ Sampler Pressure P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Gas of Job }t00K WALL District ANCHORAGE cc. Oil cc. water Tester W.A. BOLES Witness - cc. Mud Drilling Tot. Liquid cc. Contractor PARKER DRILLING COHPANY SH S Gravity. ° APl @ °F. E Q U I P M E N T & H O L E D A T A Gas/Oil Ratio cu. ft./bbl. Formation Tested - RESISTIVITY CHLORIDEcoNTENT Elevation - Ft. Z Net Productive Interval. - ,Ft. Recovery Water ~ @ __ °F. ppm All Depths Measured From Kal 1v bushj na Recovery Mud ~@~°F. ppm Total Depth 3910' PBD Ft. Recovery Mud Filtrate~ @ __ °F. ppm Main Hole/Casing Size 95/8" 40// O Mud Pit Sample ~ @_ °F. .ppm Drill Collar Length .... 184,16 I.D. - :;o Drill Pipe L.ength,3546'I.D,2.764" Mud Pit Sample Filtrate __ @ __ °F, .ppm Packer Depth(s) 3754' Ft. Mud Weight vis cp Depth Tester Valve 3736' Ft. TYPE AMOUNT · Depth Back Surface Bottom Cushion Gas 1000# PSI Ft. Pres. Valve 3732' Choke Choke 5/8" ..... Recovered Feet of . ~ Recovered Feet of Recovered Feet of O O RecoveredFeet of M A I L E D Recovered Feet of i~ I}III ~n ,F~-7~ Remarks SEE PRODUCTION TEST DATA SHEET '~ u~m.,~ I I i iiii iii ii ii i I Gauge No. 3646 Gouge No. 3647 Gauge No. 3636 TEMPERATURE TIME Depth: 3741 Ft. Depth: 3745 Ft. Depth: 3772 Ft.., 12 ~,our Clock 48 Hour Clock 48 Hour Clock Tool 3rd ~xx4~) Est. 1 10 °F. Blanked Off rl(~ Blanked Off nn Blanked Off yes Opened 9' 27 P.M. cz Opened 4th A.M. :3:: Actual °F. Pressures Pressures Pressures Bypass 11: 10 ~.~. Field Office Field Office Field Office Reported Computed ...... Initial Hydrostatic 1 554 1559 1561 1570 1597 1579 Minutes Minutes ~o Flow- Initial1153 1056 1230 1249 1267 1228 _~ Final 1310 1315 1335 1341 1340 1312 54 50 C~osed in 1345 1364 1352 1368 1377 1357 88 90 '~o F~ow ~t~a~ 1241 1256 1213 1216 1211 1221 ~°'F~ Final - 1214' 1265 1261 1267 1263 434 436 __Closed in - _ 1352 1359 1377 1 347 247 247 Initial ~'J Flow- ~ ..... Final Closed in .... F_!.n..a_l._Hydrostatic CTE CTE 1561 1615 1597 1641 - ..... CTE = char': time exp ired. ~Ri~a( at the ~nd of 327 minutes ~'hen chart time ex[,ired. ~C)RM lat---PRINT£D IN U.$,A. FORMATION TEST DATA Ticket Date 7-4-74 493715 · F L U I D S A M P L E' O A T A Number Page Sampler Pressure , , P.S.I.G. at Surface Kind Halliburton of Job HOOK WA_~LL District ANCHORAGE Recovery: Cu. Ft. Gas cc, Oil cc. Water Tester W, A, BOLES witness - , cc. Mud Drilling Tot. Liq.id¢c. Controctor PARKER DR'ILLING COMPANY SM S Gravity. ° APl @ °F. .,,, EQU I PM E N T & H O L E DATA Gas/Oil Ratio , cu. ft./bbl. Formation Tested. RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval ,Ft. Recovery Water ~ @ All Depths Measured From .......... Recovery Mud @ °F, .ppm' Total Depth Ft.' Recovery Mud Filtrate ~ @ ~ °F, .ppm Main Hole/Casing Size Mud Pit Sample ~ @ ~ °F. .ppm Drill Collar Length I.D, Mud Pit Sample Filtrate ~ @ ~ °F. .ppm Drill Pipe Length I.D,, Packer Depth(s). Ft. Mud Weight vis cp Depth Tester Valve, Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft, pres, Valve Choke Choke Recovered Feet of .... Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Fourth Gauge ,,, Gauge No. 3637 Gauge No. Gauge TEMPERATURE TIME .... Depth:3777Ft. Depth: Ft. Depth: Ft.i, 12 Hour Clock Hour Clock Hour Clock Tool A.M. - Est. °F. Blanked Off .yes ,., Opened A.M. Actual °F. Pressures " Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed Initial Hydrostatic 1595 1572 Minutes Minutes ~ Flow Initial 1331 1089 I,,~,--., ' Final 1302 1 302 '1 Closed in 1354 1244 .. ~*o Initial 1234 1223* c o Flow , ~o-: Final Closed in Initial ._~.o Flow' ~_~ Final Closed in , Final Hydrostatic CTE £TE ........ CTE = char,, t~me exp' red. *Rea,~l at the {,nd Of 355 minutes ~then chart time expired. .. z fORM 181--PRINTED IN FORMATION TEST DATA LITTLUr'$ g$1~74 SM ti/7] ~ Casing perfs, i~Bottom choke ', Surf. temp °F Ticket No4937!5 Page Gas gravity .... Oil gravity, GOR Spec. gravity , ,,Chlorides ppm Res. @ °F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED i Date Choke Surface Gas Liquid Time a.m. Size Pressure Rate Rate Remarks psi MCF BPD 07:00 1000 Shut in manifold on surface- pressure went to 1200# PSI ..... 07'03 1290 Closed in DCIP 07:07 900 Bled pressure off to 900 # PSI 09:57 900 Surface pressure 10:00 Reversed out 10:10 Mud to the surface 11'10 Pulled loose and ran 90: stand to ...... get below perforations. Circulated out gas pockets. , / ..... FORI4 18'~PRINTED IN PRODUCTION TEST DATA i , Gauge No. 3646 DePth 3741 ' Clock No. 6729 12 hour No. 493715 I rst I First Second Second Third Third Fi Flow PeriodI Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure TimeDef~.PS~GTimeDef~.t-~-~PS~GTim~Def~.PS~GTimeDef~'-~-~.~GTimeD~f~.P~GTimeDef~.-t~Ipc`~G Temp. Log Temp. Temp. Log Temp. Temp. Log Teml~. .000" Corr. .000" t~ Corr. .000" Corr. .000" Corr. .000" Corr. .000" Corr. o . 0000 1056 .0000 1315 .0000 1256 ~ .0718 1335 .0607 1348 .3120-.< 1348 2 .1436 1261 11214 1352 .5934* 1153 3 .2154 1282 .1821 1352 1.0764 1172 Chart time exF,ired. . .2872 1324 .2428 1355 1.3110-C 1172 s .3590 1315 .3035 ':1357 1.5594 ll90 a .3642 1359 2.0424 1199 7 .4249 1361 2.1180-C 1193 8 .4856 1362 2. 2530~**1214 9 .5463 1364 2.5254 - )o .6070 1364 3.0084 - ll 12 13 14 15 Gouge No. 3647 Depth 3745' Clock No. 10054 48 hour i 0 .0000 1249 .0000 1341 .0000 1216 .0000 1261 ) .0176 1274 .0146 1357 .0700-,< 1298 .0352'~ 1354 2 .0352 1307 .0292 1359 .1424' 1155 .0752 135.~ 3 .0528 1321 .0438 1361 .2583 1176 .1152 135.~ 4 .0704 1333 !.0584 1362 .3200-C 1179 15.~? s .0880 1341 .0730 1364 .3742 llg.~ _lQ.G? 13.~.~ ,, a · 0876 1 364 . 4g~ll 1 7 . 1022 1366 . .~1 8 . 1168 136B . 6~16~ 1 ??.G 31 E? 1 _~E7 9 .1314 136R _6110,-r 122.~ 3_~E? !357 ~o .1460 1368 _ 777fl 1261 3950 !359 11 12 13 , 14 15 Reoding Interval 1 ~) q 70 25 Minutes REMARKS: *Fir_~t int~_rval ~ ~qual tO 86 minutes_ ** First interval is equal to _7_7 minutes. S = surface closure ~ = chnkp nhannm ***Read at the end of , · . ., SPECIAL PRESSURE DATA . First I First Second Second 'lhird 'lhird Flow Period[ Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure .... Time Deft, T. emp,-?$1GTime Deft, I,,,0g -P$1GTemi~, Time Dell, T~emp,'-PSlG Time Deft, LOg Temp, TemD. TemD. ,000" Corr. ;000"~, ...... Corr' ,000,, ~:orr. .000'"u corr. ~00o" corr. .oo0" ~ Co,'r. 2 ,0336 1309 .0308 ...... 1342 .1460' 1167 .0799 1344 ,, ,,, , .... 3 .0504 1311 .0462 1344 .2648 1191 .1224 1344 4 .0672 1311 .0616 1346 .3280-C 1i93 .1649 1344 s .0840 1312 .0770 i~ 1347 3836 1208 .2074 1346 a .0924 1349 .5024 1211 .2499 1346 7 .1078 1351 .5280-C 1211 .2924 1346 8 .1232 1353 .6212 1230 .3349 1346 9 .1386 1355 .6700-C 1230 .3774 1347 lO .1540 1357 .7400 1263 .4200 1347 12 13 14 C;augeNo. 3637 Depth 3777' Clock No. 4485 12 hour,., o !. 0000 . 1089 .0000 1302 .0000 1244 1 0692 1314 .0585 1330 .3010-S 1328 2 1384 ,1253 .1170 1333 .5719' 1160 3 2076 J1270 .1755 133~ 1.0.374 llF~0 C.h~ri-. i:~m~ 4 .2768 J1308 .2340 1338 1.2630-t' llg4 s . 3460 130~ .297.~ 133Fi 1_ .~O?q l l 6 _ 3.Gl C) 1 .~4F) 1 .q6R4 l?rll .4Og.~ 1~42 2-0380-( 1 7 9 g? 6_:; 1344 2_ 4339 - ]o _~_~n !345 _~_8994 - 12 14 15 , Reading Interval ,10 9 70 · 25 Minutes REMARKS: *First interval is equal to 86 minutes. **First interval is equal to 22 minutes. S = surface closure C = 'choke change ***Read at the end of approximately 355 minutes when chart time expired. SPECIAL PRESSURE · . DATA 'Each Horizontal Line Equal to 10'00 p.s.i. F~rm No, REV. 9-30-G7 1. 0IL WELL STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'I-rEE SUBMrr IN DUPLICATE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS [] GA8 [] OTHER WELL NAME OF OPEI{ATOR Union 0il Company of California ~'iADDRESSOFOPEI{ATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCA~ON OF WELL Conductor 43, Leg 2, 1880'N & 1376'W from SE corner Section 29, T9N, R13W, SM. API N~IE~C~L CODE 50-1.33-20146 8. L~SE DESlGNA~ON AND S~IAL NO. ADL 18730 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. I/NIT FA~A{ Oil LEASE NA2/E Trading Bay Unit g. WELL NO. State G-14 (32-34) 10. FLE/2) AND POOL, OR W/LDCAT McAr thur River-Hemlock 11. SEC.. T,. R., 5i.. (BO/'TOM HOI~E Sec. 34, T9N, R13W, SM. 12. P~IT NO. 68-80 '13. REPORT TOTAL DEPTH AT END OF MONTH, CIiA~N'GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/ND VOLLrNFES USED, PE/{FORATIONS. TESTS ~ I~ESULTS. FISHING JOB~. JU/~K IN HOLE AJqD SIDE-TRACKED HOLE AND A,NY OTH2EI% SIGNIFICANT C'H,A_N~E~ IN HOLE CONDITIONS. TRADING BAY UNIT STATE G-14 (32-34), DECEMBER 1968 Rig Released from G-18 to G-14 @ 6:00 AM 12/4/68. RU BOP, tstd w/2000#. RI w/drlg. assembly. Drld out cmt in shoe of 9-5/8't @ 13,521'. Drld 8-1/2" hole to 14,832'. PO for bit change, left 3 cones in hole. Ran junk basket, recovered one cone. Drld to 15,459'. Left 2 cones in hole, ran in with junk basket & recovered same. Drld to 15,831'. Had earthquake, checked derrick for damage. Drld to 16,342'TD. Ran Schlumberger DIL log. While logging, stuck tool @ 15427', stripped over line w/~.p. & ran to 15,498', wire line parted 600' below Rotary Table. PO, no recovery. Ran wire line spear, recovered all wire line & tool. Ran Schlumberger DIL & Sonic Logs. RanHRD, log stopped @ 14020. While attempting to PO, tool stuck @ 13,920. Stripped over line, pulled line out of rope socket. Did not recover tool. Reran fishing tool, no recovery. Left HRD Son4e on bottom @ 16,342'. Ran 7" 29# N-80 lnr w/Baker "G" shoe @ 16,166, Baker "G" collar @ 16121' & TIW lnr hngr top @ 13,370'. Cmtd w/600 sx Class "G" cmt w/l% CFR-2 mixed w/Inlet wtr. CIP 7:45 PM 12/25/68. CO to top of lnr, CO inside lnr to 16,114'ED. Displaced mud w/Inlet wtr. Tstd lap to 2350# - OK. Ran 4-1/2" & 3-1/2" tbg w/tail hung @ 15,570'. Displaced wtr w/diesel w/tbg tail @ 15,570'. Pulled tbg to 15,173', pkr @ 15,139'. Set pkr. Released fm "J" on Baker Expansion Jr., pulled 8 singles tbg. Instld Bail Valve. Ran tbg with overshot skirt on expansion jr. 2' above "J" lugs. Lnded tbg on do-nut. RD BOE. Instld & tstd tree. Ran Schlumberger Gamma Ray CBL thru tbg. Ran 32' of 2" scallop gums. Perfd 15326-15294. Unable to pull guns into tbg thru shear sub. Attempted to kill well, unable to do so. Pulled wire line in two @ 650'. Instld tbg plug in ball valve~.,e~, removed 7mms. Tree. Now prep to disengage expansion jt & kill well w/ weighted salt wtr to pull tbg. RECEIVED , JAN 1 ? 19Fo 14. I he.byt'Pl~illlllll~~ the f, re~l$l~e ~ ~ - ~~G ' sm~~~ Dist. DrlK. Supt. o~ 1/10/69 N015~s f~m ~s r~u~red for each ~e~dar m0.~h, regard[ess of the s[a%us w~t~ the D~v~s~0, 0{ ~,es ~,era~s by the 15%b ~ %he succeed~,9 month, un~ess 0~he~se R,E-W** STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN IFU-PLICkTE MONTHLY REPORT OF ~D-RILLING AND WOR'KOVER OPERATIONS NAME OF OPEi%ATOR Union 0il CO. of California ADDRESS OF OPEi~TOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 LOCA~ON OF w~ Conductor #43, Leg 2, 1880'N, ~ 1376'W from SE corner Section 29, T9N, R13W, SM. AP! NUA~EI~/C~%L CODE 50-133-20146 6. LEASE DESIGI~ATION AND S~IAL NO. ADL 18730 ?. IF INDIA]~, ALOTYEE OR TRIBE NAME 8. %7NIT,F~l~ OR LEASE NAME Trading Bay Unit 9. \~/ELL State G-14 (32-34) 10. }'L~I~D ~%-ND POOL,-OR WILDCAT Mc Arthur River-lteml0¢k 11. SEC., T., R., M., (BOT~fOM HOL.I~. oB.rzcrrv~ Sec. 34, TgN, R13W, SM. 12, PERMIT NO 68-80 REPORT TOTAL DEPTH AT E2~D OF MOl~'r~. CI-I~GES IH HOLE SIZE. CASING ~2N-D C]SNIF~/qNG JOBS INCLUDING DEPTH SET ~ VOLU/VI~ USED PF-~Oi~TIOI~S. ~ESTS ~ RESULTS. FISHING JOBS. JLrNK IN HOLE ~ND SIDE-/qR3kCKED HOLE AI~-D A~TY OTHER SIGNIFICA/~TT C~,~F,S IN HOI.~ COI~ITIONS. Trading Bay Unit State G-14 (32-34), November, 1968 Drld 12-1/4" hole from 9573' to 12,926'. Dynadrill 12 926'-12 983' for right hand turn. ' ' Drld to 13,534'. Circ'and conditioned for csg. Ran 330 its 9-5/8" 40# 43-1/2# 47# csg. Hung w/shoe @ 13,521, float collar @ 15,482, and Differential Fill-Up Collar @ 13,439'. Cmtd thru shoe w/1000 sx. Class "G" cement mixed w/10% CFR-2. CIP 8:15 p,m., 11-19. Landed 9-5/8" c.sg. Removed BOP ~ riser. Installed tubing head ~ Xmas T~ee. Shut well in. ffELL TEMPORARILY SUSPENDED ~ 4:30 a.m., 11-20-68. drill '~ ~complete, then resume opt on G-14. Will move to G-18, DIVISION OF~O. IL AND GAS fi~'; I ~J/ltd ~= Dist. Drilling Supt. ~^~ 12-12-68 v I I . NOTE--Repo~ on th~s for~ is required for each ~lendar month, regardless of the status of operations, anO mu~ ~ filed in dupli~te with the Division of Mines & ~inerals by the 15th ~ the succeeding month, unless othe~ise directed, .M,~ of Of,]...4nd GmJ please of .qV~ for pemit FORM SA - iB 125.5M 8/67 MEMO.RANDUM FROM: Sta,te o,f AI,a s ka DATE SUBJECT: Form No. P--4 REV. 9-2~67 STATE OF ALASKA OIL AND GAS CONSERVATIO. N COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF :DRI. LLING AND WORKOVER OPERATIONS 2, NAME OF OP~TOR Union 0il Company of California 3. ADDRESS OF OPER,A. TOR 507 W. Northern. Lights Blvd.~ Anchorase~ Alaska 99503 , 4. LOCATION OF WELL CondUctor #43, Leg 2, 1880'N & 1376'W from SE corner Section 29, T9N, R13W, SM. AP1 NUMERICAL ~ODE LEASE DESIGNATION AND SERIAL NO. ADL 18730 i?. IF INDIA]~, ALOTTEE OR TRIBE NAME 8, Lr~IT,FA~RA{ OR LEASE N;~ME Trading Bay Unit 9. WELL NO. State G-14 (32-34) 10. FID ~-ND POOL. OR %VILDCAT McArthur River -Hemlock ll. SEC:, T., R., M., (BO/'TOM HOLE o~.mcrnn~) Sec.. 34, T9N, R13W, SM. ~-, P~MIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA.NGES IN HOLE SIZE, CASING A/ND CEA/IENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED. PF_~O~FOP~ATIONS. I~__~STS A/XrD RESULTS. FISHING JO~.S. JUNK IN HOLE ~2~D SIDE-TlR2%CKED HOLE ANT) A_NY OTHER SIGNIFICANT CI-L~NGES IN HOI~ CONDITIONS. TRAD. ING..BAY UNIT STATE G,1..4 (32-3.4), OCTOBER 1968 SPUDDED: 3:30AM 10/7%68 Drld 15" hole to 623, opened hole to 22". Ran & cmtd 15 its 17-3/4" csg, hung w/duplex shoe @ 600'. Cmtd w/650 sx Class "G" mixed w/2% CaC12 followed by 50 sx Class "G" w/4% CaC12. Directionally drilled 12-1/4" hole to 6650'. - Opened 12-1/4" hole to 17" to 4950'. HO torqued up & released backing dp off one stand under rotary table. Unable to screw into fish, ran overshot, recovered 17 its dp. Re-ran overshot, recovered all fish. Continued opening 17" hole to 6645'. Rani~6jts 13-3/8" 61# J-55 buttress csg. Csg stopped @ 6493'. Unable to circulate 'pumping mud to formation. Squeezed cmted shoe w/300 sx Class "G" cmt mixed w/Inlet wtr. Ran cmt bond log. Perfd 4 1/2" holes @ 6438. Circ freely to surface. S Cmtd w/2400 equivalent sx Class "G" cmt mixed with 1/2 cu.ft, perlite, 6% Gel &' 1% D-31. Installed 12" S-900 csg head, riser & BOE - tstd OK. RI w/12-1/4" bit, drld hard cmt 5110-6483'. Perfd 4 1/2" holes in shoe jnt @ 6483'. Set pkr @ 6458'. Had communication between perfs @ 6483' & 6438'. PO, set pkr @ 6360'. Sqz cmtd holes 64~' & 6483' w/200 sx Class "G" cmt. "~" ' RI w/12-1/4" bit, drld on firm cmt 6405-6493. CO to 6650. Drld to 9573, direction- ally. Now drilling. RECEIVED 1,968 DIVISION OF OIL AND NOTE--Kepo~ o~ %~s form i~ required for each ~le.~ar monk, regardless of the status oi o~era%io.% a~ mu~ ~ filee i. dupli~te with the Divisio. cf ~i.~s & ~i.erals b~ the 15th of the succeedi.9 mo.th, u.less otbe~ise dire~ed. Robert T. Anderson District La~ ~':~=~-~'.- -_-- Union Oil Compan~*")3alifornia 2805 Denali Street, Anchorage. Alaska 99503 Telephone (907) 277-1481 union DIRECTOR'S OFFICE Date Noted /-~-/.C ~__~._ ~Lands / '"- ! 'Minerals-- .v/ ~ "' "~ , 'Water Forestry -" AS.m~ - .. Ane Area ..... October 9, 196fi I~'f0 ......... ~ : ;~e Gmnment / . '", :~ ,' ? Director Division of Lands 344 Sixth Avenue Anchorage, Alaska 99501 WEST FORELAND AREA State of, Alaska ADL 18750, WFore-5 Dear Sir: In accordance with the provisions of the captioned oil and gas lease, Trading Bay Unit State G-14, drilling from the Grayling Platform located on State Lease ADL 17594 was spudded on October 7, 1968. The proposed bottom hole location of said well is approximately 2,340' South and 1,370' West from NE comer, Section 34, T9N, R13W, SM. on said captioned lease. Very truly yours, Robert T. A~iderson / :orm 40t ~,NC-A {New 7/67~ Forr~ REV'. 9~30-6~ SECOND REVI~ STATE O,F ALASKA OIL AND ~GAS CONSERVATION CO,MMITTEE SUBMIT IN TR; (O%her instructio, reverse side) APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TyPE OF WORK DRILL [~ DEEPEN i--I PLUG BACK [] b. TYPE OF WELL OIL ~ OAS ~-~ 8INGLE [] MULTIPLE ~_~ WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99505 4.LOCATION OF_WELL Atsurface Conductor #43, Leg 2, 1880'N & 1376'W from SE corner Sec. 29, T9N, R13W, SM At pro~sed prod. zone Top Hemlock - 1980'S & Z280'~.. ~f~om NE comer Sec. 34, T9N~ R.13W~ SM ~-':::~' ' ~ ..... 13. DISTANCE IN MILES AND DIRECTION F-~OM NEAREST TOWN OR POST OFFICE'~ ~. 25 air miles NW of Kenai, Alask~ 14. BOND INFORMATION: Statewide Pacific Insurance Company B-55572 ' '~ TYPE Surety and/or No 15. DISTANCE FROM PROPOSED* lift. NO. OF ACRES IN LEASE~: ... LOCATIONTO NEAREST ][ ~' : : 3,840 :~ : PROPERTY OR LEASEhli~E; FT. "(' 4,5 0 0 ' ~ (Also to nearest drig, unit, if any) .- .... 18. DISTANCE FROM PROPOSED LocATIoN* ] i9. PROPOSED DEeP'TH ' .... TO NEAREST WELL DRILL. INi, G~ COMPLETED. ! ' OR APPLIED FOR, FT. 2,9.4o.,. . ,i...'.,.: 4,. l.S,;s% z o.., S V0 AP1 ~0~133-20146 6.LE~SE DESIGNATION A_ND SER/AL NO. ADL 18750 ?. IF INDIAN, ALT.~TTEE OR TH/BE NA~E 8. LrNIT~FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-14 (32-34) 10. FIELD AND POOL, O1% WILDCAT McArthur River - Hemlock 11. SEC.-, T., R., M., (BOTTONI HOLE OBJECTIVE) Sec. 34, T9N, R13W, SM 1~.. .. '~' .... ~ ...... ~:~.100,000.00 Amount 117';' >N~.O. A~C'P~ES ASSIGNED TO THiS WELL 160 20. ROTARY 'OR CABLE TOOLS · -, . .... ~.~Rot arm 21, ELEVATIONS (Show whether DF, RT, C-R, etc.) 99' RT Above MSL 23. PROPOSED CASING AND CEMEi~TING PRoGRAEVI APPROX, .DATE WORK WILL START* · ~ October 5, 1968 , 22" 17-5/4" .512 Wall ~piral qeld - 600' 1200':S:~k§"":' ~1[ 17-1/8" 15-3/.8~, ,61~,. ., J-S5 ,, 6400' .,3500 .~ 12 1/4,, 9-5/8~ . 40,45.5,47~ Ngp . 14.,44;0'... ...... .25.09" ~ ~..sacks... ~ ~15~ . 8-1/2" 7"" Cement 17-5/4" casing in 22'"hole at'600i[ Install 20"' Hydrill.' Cgment 13-3/~" casing in 17-1/8" hole at '6,400'. Install BOE. Drill 12~l/4¢r:i~reeii°nal~'holb to 14,440'±. Run electric logs. Cement 9-5/8" casing at 14,440'. Drill 8½" directi6nal hole to 15,580'. Run electric logs. Cement 7".Liner 14,340 - 15,580'.. co;.~lete fo~production. Bottom Hole LocatiOn· ApprOximately 2',340'S'& 1370'W fr~m'~NE Corner Sec. 34, T9N, R13W, SM ¥ e u l S~'O ~ IN ABOVE SPACE DESCR/BE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zof~e. If pr(~posal is to drill or deepen direct 2onally, give pertinent data on s~bsurface locations and measu~d and tr~e vertical depths. Give blow, ut preventer program. 24. I hereby ce~~~an~, ~,rrect~ ,,"~' (This space for State office use) C~{DITIONS OF APPROVAL, IF ANY: ISAMPLES AND CORE CHIPS RF_~U~ OTHER RE~U~: [W~o DYES j DIRECTIONAL SURVEY REQUIRED ~'YES E] NO PERM1T NO_ ( P'/=~ ~''~''~C~' APPROV~_~ By DATE October 5, 1968 t A.P.I. ~CAL CODE APPROVAL DATE 10-4-68 THOMAS R. MARSHAll; ~ Executive Secretm~y District Land Manager *s,. mm,,,~o., o~i%%~'s~°~ f,~onservotion Ca~mmil'~oe G- A $-5 ~J G '¸4 G-I (14-29) D-II UNION- MARA(~H 0 N I ADL- 17594 t t I / I ! 1 ! I ! I I D-.5 (~4- 29 / G-II D-I \ \ \ \ \ \ \ (14-28) ~' G'6 (S4'ZS) \ \ \ G- $\\ D-7 T9N- RI3W \ G-12 /v UNION ~- PROP. TOP HEMLOCK · ~' -,... Thio 14,~ · .~ z~, PROP. BHL TMD 15,5B0' TVD ~0~520' UNION - MAR'A THC~N ADL 18730 PAN AM. N. REDOUBT-S~ OIL COMPANY OF CALIFORNIA ALASKA DIS-TRI CT WELL LOCATION MAP UNION OIL CO. OPERATOR 'UNION TRADING BAY STATE UNIT G-14 DATE OCT. 1968 SCALE I" = 2000' e I000' zoo0' [ [' ['["Ir i [ [ f I I ..... ~-8 . TMD 15,~0~, D- I ' ' X , ' '. D-II ' ~ ~ D-7 , I--/'~' ~ [9~N- E~W ~ ' ADL- 175~4~ X ~-12 UNION-MAR'ATHnN J PAN AM. UNION OIL COMPANY OF CALIFORNIA":', ' ~ ALASKA DISTRICT WELL LOCATION MAP: UNION OIL CQ OPERATOR UNION TRADING BAY STATE UNIT G-14, DATE OCT. ! 9 68 :"~'~ ' " SCALE I"= ~000' e DO0' , ZOO0' - . '. ~ , · rr~ltu~ Bay Un:re 6-14 Onion Otl Company o~ California, ~ otx ~ ef cmx~ Dear Sf,r: !~~ .please £Led the approvmd, rovt~,ed ~ppl~tton ~r ~ 'to d~tll tl~ rm~~ umtl. V~ell s~mpl# mi SUBMIT IN TRI]~ TE Fo~ P--1 F{ ~ ~ $--6~ (Other instruction~ .~ reverse side) ~ REIt. 9;30-67 STATE, O'F ALASKA OIL AND GAS CONSERVATION ,COM:MITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL~{] DEEPEN I--I PLUG BACK b. TYPE OF WELL OIL __~_ (lAS[] SINGLE ~ MULTIPLE[] WELL , WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 1880'N & 1376'W from SE~orner NO. OF ACRES IN LEASE 3,840 ,1.4,900' ,~,~ & 10,, S50,,VD 4. LOCATION O,F WELL Atsurface Conductor #43, Leg 2, Sec. 29, T9N, R1SW, SM At pro,posed prod. zoo..^__ U^--~.: ~non, S ~ 1980 ' E___fro~m~ corner ~uF ll~ln~ Sec. 3.4, T9N, R1SW, SM m, mST~C~ m ~m~s .~B ~m~CTZO~ ~_~OU N~*~s~ ~ow~ o~,~OST o~~ . 23 air miles ~ of~ Stateuide Pacific Insurance Company B-55372 Surety and/or No. 15. DIST~C~ ~OM P~O.POSED* LO.CATION TO NEAREST PROPERTY OR (Al~ to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED TO NEAREST WELL DRILLING,, COMPLETe, . ~1. ELEVATIONS (Show whether D~, 99~ RT above MSL - 23. ~D 'C~TING' PROGR~ 6. LF~SE DESIGNATION A_ND SERIAL NO. ADL 18730 8. UNIT~FARiVl OR LEA~SE NAME Trading Bay Unit 9. WELL NO. State G-14 (22-34) 10. FIELD AND POOL, O'R WILDCAT McArthur River '"- Hemlock 11. SEC.-, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T9N, R1SW, SM 12. $100,000.00 [?. NO. ACI:IES ASSIGNED TO THiS WELL 20. ROT~.RY~OR CABLE TOOLS ..,~..Ro, t.,~rY AI:~PROX. DATE WORK WILL STAHT* October 1, 1968 SIZE OF HOLE SIZE OF CASING ,, 6 , ~" i ~AIE i rl .' S~iNG DEP~3 ~,y :.' ..,... :q ,.> 'f QuANTiT,' 'r , :[..,,.,,:,~ CEMEN~ . 22" 17-5/4" ~2~all Spiral Weld - 600' '<"4'200 sacks 17-I/8,' 13-3t8" ~'~... , ~, J,55 6200f ..... ,}~Q, sacks . 12~" 9-5/8~' 40'~,.5¢,47~',,N~P.' ' i, ~3,860' :: .... ";" ~',~ac,k¢ , 8~,, 7" .¢ ~.~... u,80 ~15760 , z4900 500 sacks ,,, , . , ., . . , . ,~ Cement 17-3/4" in 22" hole at 600'. Install 20".:Hydrill. Cement 13-5/8" casing in 17-1 :..~62'00.:'. Install BOE. Drill 12~":'xdi:rectional hole to 13,860'±. Run Electr: :ement 9-5/8" casing at 13,860'. Drill 8½" directional hole to 14,900'. Run E1 s. Cement 7" Liner 13,760' - 14,900.'. Complete for production. cation - Approximately 2,220'S & 2,580'E from NW corner Sec. 34, TgN, R13W, Bottom Hole IN ABOlrg SPACE DESCKIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zo~e. If Proposal is to drill or deepen direct-onally, give pertinent data on st~bsurface locatior~ and measured and true vertical depths. Give blowout preventer program. /] ~,'t//.~ ~eby cert~~ i~lt~ ~ /ll & ~*=, September 24, 1968 O~ ~~: I s~L~ ~D CO~ C~ R~~ ' ~ ~ DI~ON~ SURVEY ~~ A.P.L ~C~ CODE I FTM aN° ~ - i3~ -- ~ ' ' T~la~a Oil &_Gas District Land Manager DATE Fom-n REV. 9-30-6; SUBMIT IN TRIP[ i? ~/I ~ 'e ~, (OtherreverseinStructiOnsside) STATE OF ArLASKA E OIL AND GAS CONSERVATIO'N ,COMMITTEE APPLICATION FOI~ PERMIT TO DRILL, DEEPEN, OR PLUG BACK TYPE OF WORK DRILLI{~] DEEPEN ["-] PLUG BACK [-1 APl 50-133-20146 §. . . 6.LEASE DESIGNATION ~ SERIAL NO. ADL 18730 ~'. IF INDIA/q, ALLOTTEE OR TRIBE NAME b. TYPE OF WELL OIL ~ OA8 [~ SINGLE ~ MULTIPLE[] WELL WELL OTHER ZONE ZONE 2. NAME O17 OPERATOR Union 0il Co~pan¥ of California 3. ADDRES~ O~ OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 8. UNIT~FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-14 (22-34) 10. FIELD AND POOL. O'R WILDCAT 4.LOCATIO~q O~ WELL At,surfaceConductor #45, Leg 2, 1880'N ~ 1576'W from SE c ~o~r Sec. 29, TgN, R13W, SM Atpr°'~°sedpr°d'z°_?_O_p Hemlock: 1980'S ~ 1980'E f=om NW co Sec. 34, TgN,. R13W, SM 13. DIST~CE IN MILES AND D~ECTION F,%OM NEAREST TOWN OR,POST OFFICE' ' ' 14. BOND INFO~A~ON: Statewide Pacific Insur~ce Co~y TYPE Surety and/or No. 15, DISTANCE FROM PRO,POSED* ~+ '116. NO..~~ I~ LEASE ,;" , PROPERTY OR LEASE LINE. FT, ' 3060' (A~ to nearest drig, unit, if any) 1~. DISTANCE FRO~ PROPOSED LOCA~ON* TO NE~R~S~ W~LL D~ILLING. COMPLETED. OR APPLIED FOR, FT. 4400' ~:,~ !0,350 McArthur River - Hemlock 11. SEC.-, T., R.. M.. (BOTTOM HOLE Sec. 34, T9N, R13W, SM 12. : .... ,, ~.., $1oo,ooo. oo A,moun'l; 17. N~O. ACRES ASSIGNET) TO THiS WELL :.'"~ :":~'.~..' 160 ~0,. 'Ro~,f,6~ eABLE TOO~ 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) ~.. ,: :22~ APPROX. *DATE WORK WILL START* 99' RT above MSL October 1, 1968 .... QUANTITY OF CEMENT 22" 17-3/4" .312 Wall% ,.~iral Weld - 600' '~+"I'200 Sacks 17--~/8" 13-$/8" ,.., ~T~ ,, ~,~/ J, 55, 6200' ," ~~aCks 12~" 9-5/8", 40#143~,g71 I~P.,, , 13860' 8h" 7"" , ','2 '~~ ' N'80 13760 '/14900 . :., ...~; ':SOO"' Sacgs - -.; . '~ ... . ' ... .. . ,. ,..,~.) ,...'. Cement 17-3/4" 'Casit~in 22" hole at 600'. Install 20"..Hydrillr;+...?:':Cement 13-3/8" casing in 17.-1/8" hole. at.6~,,~. Install.'~0E..-.Dri11...12~,:~irec~ional::hole~'.to 13,860'-+. Run Electric Lo~s. Ceme~}9-5/8' casin8 at 15,850~. Drill 8~' directional hole to 14,900~ R~ Electric Lo~s..~ent 7" Liner 1~,750~ - 14,900~. C~mplete for production. ~otto~ Hole Loca~"- ApprOXimatelY 2,220~S ~ '2,580'E i~i'-~ c°~er' Sec. ~4, TgN, RI~N, "? '~ d ~~BO~ SPA~ D~BE ~OPOSD. PR~: If ~1 ~.~ dee~n or p}~ ~: give ~ ~n p~e~ p~d~lve ~ ~d pro~s~ ~w produ~e ~. Ii pr~ ~ ~ ~fll or d~n ~e~_o~ly, g~ve ~en~ ~m on ~os~a~ ~ ~a m~a ~ue venal de~Gi~ blo~t preventer p~gr~. 24. I hereby ce~ify~~ is ~e ~d ~e~ ~ ~~~~~~ DA~September 24, 1968 ~District L~d M~ager S~GN~ (~is spa~ for S~te offi~ ~) ~~ONS OF ~PROV~, IF ~: SA1VIPL~ AND CORE CHIPS REQUIRED [] ~ ~NO DIRECTIONAL SURV~EY I:~EQLYI~ . ~YES []NO . 68-80 PERMIT NO_ , ., - · ? ' tOTHER REQUIREMENTS: A.P.I. NI/MER/CAL CODE 50-133-20146 9-30-68 Executive Secretory TITL~I,~-I-- ,'~.. -, ~ DA~ *See Inmudion, 9-30-68 D-5 D-I \ \ G-7 (14'28)" \ \ G.$\\ . -\ TgN- RI3W \ \ 10¢34-~3) INION- M'ARATH¢~I ADL 1873C PROP TARGET LOC ~'~. TMD 13,B60 .e'~. TVD 9640 'PROP BH LOC ? TMD 14,900 '3 -/~' Tvo ',o,~5o UN ION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION MAP- 'UNION OIL' CO OPERATOR '. UNION TRADING BAY STATE UN-iT · ' ' ('14-34) DATE' ~'PRI t':'/9"68' :" "' '::?:: '!.: '..::~!?:!~:' :..':: ':'i" i:::"':!.:::': SCALE I": 2000' 0 ' K';'Lr~- '2000" FORM SA. lB t25.5M 8,67 MEMORANDUM TO: r'- State of Alaska FROM: SUBJECT, FORM SA- I B 125.5M 8/67 MEMO~RANDUM State of Alaska FROM: SUBJECT: (Other instructions on ForUm P--1 reverse side) P~EV. 9-30-67 STATE OF A. LASKA OIL AND GAS CONSER'VATION ,CO,MMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL )IX] DEEPEN [-] PL IBINGLE~ OIL ~--~0 OAS ~--] OTHER ZONE WELL WELL 2. NAME OF OPE~:LA. TOR Union 0il Company of California 3' ADDRESS O~F OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL Atsurface Conductor 44, Leg 2, 1876'N & 1378'W fro Sec. 29, T9N, R13W, S.M. At proposed prod. zone Top Hemlock: 660 ' N Sec. 34, TgN, R1.3W, S.M. 13. DISTANCE IN MILES AND DIRECTION FilOM NEAREST TOWN O 23 air miles NW Alaska 14. BOND INFOILMATION: Statewide Pacific TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED*: LOCATION TO NEAREST PROPE~RTY OR LEASE LINE, FT~ (Also to nearest drig, unit, iS any) 18. DISTANCE FROM PROPOS TO NEAREST WELL DRILLING, COMPLETED~ OR APPLIED FOR, FT. 3000' corner SW corner OFFICE,* 21. ELEVATIONS (Show whether DF, RT, C-R, 99' RT above MSL 23. )any B#55372 SIZE OF HOLE 22" 17-1 12- 8-1 OF OF ACR~ IN,LEASE 5840.00 15,450"MD & 10,300'VD PROPOSED CASI~G AN-D'CEN[ENTiNG PROGRAM"- ~R"~6~' DEPTH .312 wall - 600' 14100.15450 61# 29# J-55...~ API 50-133-20146 ~6. LEASE DEMIGNATION ~ SERIAL NO. ADL 18750 ?. IF INDIAN, AI./X)TTE~ OR TPJ~E 'NAA~E 8. UNIT~ FARM OR LEASE NA1VIE Trading Bay Unit 9. WELL NO. State G-14 (14-34) 10. ~D AND POOL, O~ WILDCAT McArthur River - Hemlock 11. SEC.-, T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T9N, R13W, S.M. 12. '~':' $100,000.00 A~noun~ ASSIGNED TO TH;S V~ELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX.. {1ATE WORK WILL START* S, eptember 20~ 1968 QUANTITY OF CEMENT in 17 el TD+. casing in 22" hole at 600'. Install 20" Hydrill. ~.Cement 13-3/8" casing hole at 6500'. Install BOPE. Drill 12¼', directional hole to 14,200'±. Run ic logs. Cement 9-5/8" casing at 14,200'. Drill 8½" directional hole to 15,450' Run electric logs. Cement 7" l~ner 14,100' - 15,450'. Complete for production. Bottom Hole Location: Approximately 20'N.~ 1580'B from SW corner Sec. 34, T9N, R15W, S.M. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give c~ata on present productive zone and proposed new productive zofie. I£ Proposal is to drill or deel~n dJrect-ona/ly, give pertinent data on substtrface locations and rneasur~d and true vertical depths. Give bloveout preventer program. /ereby certify th/iSmii~:Forgg0iAg is True and Correct / / . (~is spa~ for S~te offi~ ~) C~ONS OF ~PROV~, IF ~: S~L~ ~D CO~ C~ ~~ u ~ ~NO [n~ON~ S~Y ~~ _ ~ ~NO ~_~.~-. , ...... ~::.'~ ' .."'~ ~rf .; ~ee InfuSions O~~~i~mmittee aTnm District Land Managez tOTHER RE~U~: A.P.I. ~CAL CODE 5'0- DATE (S-IA $-5 K-4 ~ 11_K'9 (~-4 (12-26) G-I (14-29) D-II UN ION- MA R A?I:ION I AD]_- 17594 / / / I I I 1 I I I I I I I D-5 (:5 / G-II / D-I D-$ D-7 \ \ \ \ \ \ l:gN- RI3W ~8-35) ~ ~ PROP TOP H. LOC \ ~.'. TMD 14,200 xo' 1'VD 9580 \ 0-12 U-M 0 DL O-14 ~ PROP BH LOG TMD 1G~4GO TVD 10~300 /v UN ION OIL COMPANY OF CALIFORNIA ALASKA DISTRICT WELL LOCATION MAP UNION OIL CQ OPERATOR UNION TRADING BAY STATE UNIT G- ( 14- 34) DATE APRIL 1968 e 'Jooo' ' zooo' SCALE I"= 2000' i i i'1 I i ! i i I J