The URL can be used to link to this page

Home My WebLink About191-099 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission � DATE: Tuesday,September 22,2015 TO: Jim Regg ` _e�'6 6 G11Zslis P.I.Supervisor SUBJECT: Mechanical Integrity Tests ` HILCORP ALASKA LLC G-14ARD FROM: Jeff Jones TRADING BAY UNIT G-14ARD Petroleum Inspector SCANNED Ai, 7 ti Lift, Src: Inspector Reviewed By; P.I.Supry.1.-e- -- NON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name TRADING BAY UNIT G-14ARDAPI Well Number 50-733-20189-01-00 Inspector Name: Jeff Jones Permit Number: 191-099-0 Inspection Date: 8/27/2015 Insp Num: mitJJ150906055728 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min G-14ARD TType Inj w TVD 8776 Tubing 1660 1660 1 Well, 1660. 1660 Type_ I SPT p — -- - 2230 � --- --- PTD 1910990 T e Test; Test psi 2194 - IA 380 2250 2230 - 2220 - __T Interval?sum' P/F P / OA 238 238 238 240 L Notes: 1 well inspected,no exceptions noted. - Tuesday,September 22,2015 Page 1 of 1 • • Brooks, Phoebe L (DOA) PSD - [q l'OcM0 From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Saturday, September 19, 2015 8:50 AM To: Brooks, Phoebe L (DOA) Subject: RE: MIT Grayling 08-27-2015 Attachments: G-04rd Schematic 2015-08-27.doc; G-07 Schematic 2015-08-26.doc; G-12RD3 Schematic 2015-09-18.doc; G-14ARD Schematic 2015-09-18.docx Just got them Phoebe. The G-04RD you should already have, but here are the rest. Larry Original Message From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, September 10, 2015 11:21 AM To: Larry Greenstein Subject: RE: MIT Grayling 08-27-2015 Larry, Would you please send me the schematics on these wells (G-04RD, G-07, G-12RD3, and G-14ARD) so I can verify the Packer TVDs? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793- 1242 or phoebe.brooks@alaska.gov. Original Message From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] Sent:Tuesday, September 08, 2015 9:49 AM To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: MIT Grayling 08-27-2015 1 SCHEMATIC 4. McArthur River Field,TBU Well: G-14ARD Hileorp Alaska,LI.0 Completed: 08/19/15 RKB to TBG Head =42.6' CASING AND TUBING DETAIL Tree connection: MD MD TVD s SIZE WT GRADE CONN ID TOP BTM. BTM. CMT L . . 17-3/4" .312 wall Weld Surf. 522' 520' 700 sx 13-3/8" 61 K-55 Butt 12.515 Surf. *1390'-1460' 1361' 2500 sx 9-5/8" 47 N-80 Butt 8.681 Surf. 7970' 6455' 2950 sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 4-1/2" 12.60/13.55 L-80 BTC Ext. 3.598 Surf 10,932' Polycore *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL " NO. Depth Depth ID Item (MD) (TVD) 7715' V " 42.6' 42.6' Tubing Hanger 1 10,297' 8,284' 3.980 7"Hydraulic Packer w/15'seal assembly 7970' 4 L. / 2 10,905' 8,779' 3.980 7"Hydraulic Packer 3 10,922' 8,793' 2.810 X-Nipple 4 10,932' 8,801' 2.992 Wireline Re-Entry Guide ® 1"7 5 11,448' 9,250' CIBP ill- Casing Block Sqz 10,348-10,350 6 11,451' 9,252' 4 Otis Model"BWH"Perm Pkr Casing Block 7 11,463' 9,263' 4 Seal Bore Ext. Sqz 10,848-10,850 8 11,535' 9,328' Expandable Bridge Plug 2 � 9 12,093' 9,841' 4.00 Otis Model"BWH"Perm Pkr. ,11 10 12,098' 9,845' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin 11 12,103' 9,850' 2.313 Otis"X"Nipple G-zone 12 12,110' 9,586' 2.44 WLEG Top of Cement btm 12,111' 11.428' 13 12,866' 10,559' (2)Junk Retainers 6 6 ► ,/ 7 I Perforation Details TVD TVD Last Perf Top of Cement Zone MD(Top) MD(Btm) (Top) (Btm) Amt Date Present Cond. 11,518' 8 .. B_1 G-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open B-4 G-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open 12,093' ► 11101 . 9 G-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open G-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open 10 G-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open 11 G-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open ♦ 12 HB-1 11,519' 11,523' 9,314' 9,318' 4' 08/20/13 Isolated WF-2 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated WF-3 HB-4 11,820' 11,935' 9,589' 9,695' 115' 08/20/13 Isolated WF-4 WF-2 12,227' 12,317' 9,965' 10,049' 90' 08/20/13 Isolated TOF 12,625' WF-5 WF-3 12,332' 12,473' 10,063' 10194' 141' 08/20/13 Isolated 44-1/10 WF-6 WF-4 12,477' 12,524' 10,198' n a 10,241' 47' 08/20/13 Isolated WF-5 12,564' 12,568' 10,279' 10,282' 4' 08/20/13 Isolated 'lWF-7 WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated :>`<' ��, �!% 13 WF-6 12,667' 12,719' 10,374' 10,422' 52' 08/20/13 Isolated ETD= 12,868' TD= 12,939' WF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated RKB to MLLW ELEV= 103' MAX ANGLE=42.9°@ 4692' Revised 09/18/15 by JLL STATE OF ALASKA � AL OIL AND GAS CONSERVATION COW/1)310N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Re-enter Susp Well❑ Other: Convert to Injector ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number Name: Hilcorp Alaska,LLC Development FA Exploratory Ti 191-099 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20189-01 SEP 1 8 2015 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit G-14ARD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): t OG V C N/A McArthur River Field/Middle Kenai G Oil,Hemlock Oil&West Foreland Oil Pools 11.Present Well Condition Summary: Total Depth measured 12,939 feet Plugs measured 11,448&11,535 feet true vertical 10,627 feet Junk measured 12,625 feet Effective Depth measured 11,428 feet Packer measured (4)See Schematic feet true vertical 9,232 feet true vertical (4)See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 522' 17-3/4" 522' 521' Surface 1,390' 13-3/8" 1,390' 1,361' 3,090 psi 1,540 psi Intermediate 7,970' 9-5/8" 7,970' 6,467' 6,870 psi 4,760 psi Production 5,224' 7" 12,939' 10,620' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet � NOV True Vertical depth See Schematic feet SCOW NE NO Y 1 6 20)5 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 10,932'(MD) 8,801'(TVD) Packers and SSSV(type,measured and true vertical depth) (4)Packers-See Schematic SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10,848-10,850—Perf'd interval squeezed with 4bbls 15.8#class G cement with squeeze pressure @ 3,066 psi. 10,348'-10,350'—Perf'd interval squeezed with 12.8 bbls 15.8#class G cement with squeeze pressure @ 3,100 psi. 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 94 125 Subsequent to operation: 0 0 2551 208 2005 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory❑ Development Service F] Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL[J Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 2 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-381 Contact Trudi Hallett Email thallett(a�hilcorp.com Printed Name Trudi( Hallleett Title Operations Engineer Signature att1 't L a—"2.��2�`''1 Phone (907)777-8323 Date 9/18/2015 Form 10-404 Revised 5/2015 cl.,21.(j Submit Original Only 41.*j, RBDMS SEP 2 z 7P • 11 • SCHEMATIC 0 McArthur River Field,TBU Well: G-14ARD Il lloorp 114-6a.1.11', Completed: 08/19/15 RKB to TBG Head=42.6' CASING AND TUBING DETAIL Tree connection: MD MD ND SIZE WT GRADE CONN ID TOP BTM. BTM. CMT dl 17-3/4" .312 wall Weld Surf. 522' 520' 700 sx 13-3/8" 61 K-55 Butt 12.515 Surf. *1390'-1460' 1361' 2500 sx 9-5/8" 47 N-80 Butt 8.681 Surf. 7970' 6455' 2950 sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 4-1/2" 12.60/13.55 L-80 BTC Ext. 3.598 Surf 10,932' Polycore *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL NO. Depth Depth ID Item (MD) (ND) 7715' \� v 42.6' 42.6' Tubing Hanger /�J /� 1 10,297' 8,284' 3.980 7"Hydraulic Packer w/15'seal assembly 7970'L ,) __ 2 10,905' 8,779' 3.980 7"Hydraulic Packer 3 10,922' 8,793' 2.810 X-Nipple • I t Lam)7' 4 10,932' 8,801' 2.992 Wireline Re-Entry Guide IF.� 1 ^---'" Casing Block 5 11,448' 9,250' CIBP i 6Sgz I 10,348-10,350 6 11,451' 9,252' 4 Otis Model"BWH"Perm Pkr Casing Block 7 11,463' 9,263' 4 Seal Bore Ext. S10qz ,848-10.850 8 11,535' 9,328' Expandable Bridge Plug 2 0.105 7______ X 3 9 12,093' 9,841' 4.00 Otis Model"BWH"Perm Pkr. q 10 12,098' 9,845' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin ".iil 11 12,103' 9,850' 2.313 Otis"X"Nipple G-zone 12 12,110' 9,586' 2.44 WLEG Top of cement f btm 12,111' 11,428' 13 12,866' 10,559' (2)Junk Retainers 5 6 • 7 ›111 Perforation Details � TVD TVD Last Perf Top of Cement Zone MD(Top) MD(Btm) Amt Present Cond. 11,518' (Top) (Btm) Date 8 B-1 0-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open B-4 G-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open 12,093' 9 G-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open G-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open 10G-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open 11G-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open 12 HB-1 11,519' 11,523' 9,314' 9,318' 4' 08/20/13 Isolated WF-2 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated WF-3 HB-4 11,820' 11,935' 9,589' = 9,695' 115' 08/20/13 Isolated WF-4 WF-2 12,227' 12,317' 9,965' 10,049' 90' 08/20/13 Isolated TOF 12,625' = WF-5 WF-3 12,332' 12,473' 10,063' 10194' 141' 08/20/13 Isolated c ''T ` WF-6 WF-4 12,477' 12,524' 10,198' 10,241' 47' 08/20/13 Isolated WF-5 12,564' 12,568' 10,279' 10,282' 4' 08/20/13 Isolated WF-7 :r WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated •-'-.7 13 WF-6 12,667' 12,719' 10,374' 10,422' 52' 08/20/13 Isolated ETD=12,868' TD=12,939' WF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated RKB to MLLW ELEV=103' MAX ANGLE=42.9° a@ 4692' Revised 09/18/15 by 1LL • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 07/31/15-Friday Skidded rig from G-07 to G-14ARD 8'South. R/D skid jacks and secured rig. Installed stairways from deck to rig walkway. Positioned mud pump&choke house connecting lines to each. Moved gas buster and set stairway from pipe deck to rig walkway. Set power swivel in place. Scoped up derrick and secured guy lines. Connected all electrical services and laid out accum lines.Started on deck cleanup. Attempted to set BPV but had to remove side-entry test spool first. Cameron set BPV. N/D tree N/U BOPE. Hang rig floor and install stands,floor pieces and hand rails. 08/01/2015-Saturday Dressed rig floor with Foster tongs,slips,elevators and wrenches. M/U 3 1/2"test jt w/blanking sub and landed same. Pretested BOPE(except blinds)to 250#s low/3500#s high(tested annular to 2500#s_ B/O landing jt and pulled BPV. Removed blanking sub and re-landed test jt. Lined up to pump down tubing.Tbg filled at 15 bbls and pressured up to 900#s @ 3/4 BPM (no returns).Switched around to pump down annulus. Pumped 188 bbls down annulus 3 BPM 0 PSI before getting partial returns. Pressure increased to 600#s @ 2 BPM w/.5 bbls/min returns. Switched back to LW pumping 3/4 BPM 1000#s w/no returns. Switched back to rev pumping 2 BPM 600#s getting partial returns at 160 bbls(—1/4 returns-fluid would drop whenever pump was stopped). Continued pumping with pressure increasing to 750#s.Started getting oil back after another 230 bbls pumped. Installed'T'on casing line and pumped 60 bbls of oil/FIW mix to TBF. Continued pumping in rev 2 BPM 750#s getting—1/4 oily returns. 08/02/2015-Sunday Continued pumping in rev at 2 BPM 750#s w/ 1/2 BPM returns until returns cleaned up. Pumped 80 bbls of oily returns from shaker tank to TBF. Pumped out active tank to TBF. B/O circ line and pulled 3 1/2" landing jt. Installed BPV and M/U blanking sub on test jt. Screwed back into hanger. Attempted to make 1st BOPE test but would not hold 3500#s. Backed out landing jt and XO stayed in hole(8rd conn backed off). Drained stack and unbolted at THF. Picked up and found that 4 1/2" IBT thread had crossed and we were pumping thru BPV. Removed XO sub and inspected threads. Bolted stack back together and pulled BPV. Installed 2-way check.Cleaned up threads on XO sub. Filled stack. Tested all BOPE 250#s low/ 3500#s high (tested annular 250#s low/2500#s high)with 3 1/2" tbg as per Hilcorp and AOGCC requirements. Performed accum draw-down test. Gas detectors bump tested by Total Safety. Witness waived by Mr. Bob Noble,AOGCC(by phone). B/O test jt and retrieved 2-way check(fluid dropped out). M/U landing jt and screwed into hanger full nine rounds. Change out Foster tongs for McCoys while backing out hold down pins. Picked up on string and hanger came off seat at 125k. Drug up to 145k before turning loose,weighing 125k w/slight drag. Pulled hanger to floor. Chained down stack while Cameron &Summit worked hanger. Broke off hanger and laid same down. Held PJSM with Summit, rig&crane crews. Pulled 2 jts and R/U sheave w/ESP cable. Pulled 2 more jts and R/U flat pack cable. POOH laying down 3 1/2" IBT-M production tubing with Summit spooling up cables, pumping 3 bbls every 20 jts. 104 of 340 jts OOH at report time. 08/03/2015-Monday POOH/to Summit ESP assembly, laying down 3 1/2" IBT-M production tubing, pumping 3 bbls disp every 20 jts. 1030 hrs changed out ESP cable spool. Assisted Summit personnel B/D ESP assembly then R/D packed up Summit to be loaded out. Inspected crown sheaves while slipping and cutting 200'of drill line. Changed transmission oil in rig draw works while back loading Summit and taking on work string. Pumped 40 bbls FIW down casing. M/U 6"Varel bit on 3 1/2" 12.95#PH6 work string spacing scraper 14 jts up hole. BHA=14.28'. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 08/04/2015-Tuesday TIH w/6"Varel rock bit w/7"scraper(14 jts up hole)(BHA= 13.60'), picking up 3 1/2" 12.95#PH6 work string off pipe deck,strapping and drifting same. 2000 hrs went thru TOL at 7,715'(P/U 75k S/O 52k-tagged lightly and turned to drop in). Tagged at 11,197' (10' in on#361) P/U 108k S/O 66K. Pulled 27k over to free string. Laid out two jts and removed floor section, pollution pan, 13 5/8"x 11"spool. N/U 13 5/8"x 7 1/16"spool w/stripping head. R/U power swivel w/single. Installed stripping rubber and M/U to string. Began pumping(@ 11,148')in rev at 3 BPM 0 PSI.Got partial returns(—1.5 BPM out)at 137 bbls. Pumping now at 2.5 BPM 220 PSI. 08/05/2015-Wednesday Continued pumping in rev at 11,148' 2.5 BPM 220 PSI getting—1.5 BPM returns. Pumped a total of 350 bbls.Shut down pump. P/U#359 on swivel&M/U to string.Turned swivel torque up to 7000 ft/lbs and added 1 drum of CFS-520 to active tank. Worked thru tight spot from 11,187'to 11,197'.Once thru that interval we started making steady hole(sand in returns now). Washed down to EOJ at 11,402'.Circ two tbg volumes. 1680 bbls pumped/—671 bbls lost. 13/0 L/D swivel. N/D stripping head. Pulled above perfs to 10,131'(20 stands)w/7"cleanout assembly. Pumped oil&dirty fluids from active and shaker tanks to TBF.Cleaned^'6 bbls of sand from both tanks. Pulled OOH w/7"cleanout assembly-pumping 4 bbls FIW every 10 stands. 88 of 183 stands OOH at report time(5,950'). 08/06/2015-Thursday Continued pumping in rev at 11,148' 2.5 BPM 220 PSI getting—1.5 BPM returns. Pumped a total of 350 bbls.Shut down pump. P/U#359 on swivel&M/U to string.Turned swivel torque up to 7000 ft/lbs and added 1 drum of CFS-520 to active tank. Worked thru tight spot from 11,187'to 11,197'.Once thru that interval we started making steady hole(sand in returns now). Washed down to EOJ at 11,402'.Circ two tbg volumes. 1680 bbls pumped/—671 bbls lost. B/0 L/D swivel. N/D stripping head. Pulled above perfs to 10,131' (20 stands)w/7"cleanout assembly. Pumped oil&dirty fluids from active and shaker tanks to TBF.Cleaned—6 bbls of sand from both tanks. Pulled OOH w/7"cleanout assembly-pumping 4 bbls FIW every 10 stands. 88 of 183 stands OOH at report time(5,950'). 08/07/2015-Friday TIH from 6,221'to 8,702'. Stopped and installed SV. R/U pump lines to circ oil from well. Decision was made to clean tanks prior to cement job. Transferred fluid from shaker tank to TBF and cleaned tank while pumping out active tank. Shut rig pump down and changed 2-swabs and 1-valve. Finish transferring fluid from active tank to TBF and cleaned tank. Lined up and displaced hole with clean FIW sending returns to TBF 2 BPM 500 PSI (592 total bbls). Stung into CRET at 10,830'- set 20k down. Held PJSM w/Halib cementing crew and rig crew. R/U to cement down tbg. Pressured tested lines to 3500#s.Attempted to pump into btm perfs at 1500#s. No indication of circ or injection. Pressured up. Set 30k down on ret and attempted to circ/inject again-no go. Set 40k down with same results. P/U &attempted to wash down to CRET at 3 BPM 500#s. Pressured up when we entered retainer with no indication of circ or inj. Set at top of CRET&washed for 30 mins. Landed in ret again. Pressured up to 2500#s down tbg-lost 350#s in 5 mins, 700#s in 10 mins,900#s in 15 mins. No fluid rise in annulus,slight fall. Pressured up on annulus(to check upper perfs)to 2500#s. Lost 450#s in 1 min,800#s in 2 mins, 1070#s in 5 mins. Released pressure. Plan forward to be discussed with Hilcorp&Halib Engineers. • • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 08/08/2015-Saturday Waited on response from Mr.Schwartz regarding requested procedure change due to inability to circ thru isolation perfs at 10,848-50' &10,348-50'. Attended fire and abandon rig drill. Received permission to proceed and developed squeeze procedure for lower perfs with assistance from Hilcorp and Halib Engineers. R/U Halib cementing equip and held PJSM. Pressure tested iron to 4000#s. Released pressure and opened valve. Pressured up to 2500#s and held for 15 mins, observing bleed off rate. Pulled out of retainer and pumped 5 bbls FIW-then 4 bbls 15.8#, 1.17 yield,5.10 gal/sk,class G cmt at 2 BPM 130 PSI,then 75.6 bbls FIW at 3 BPM 510 PSI.Shutdown pump. Stung out of retainer and well u-tubed. Closed hydril and laid down single. Pulled 3 stands and opened bag to stabilize well. Pulled 3 more stands to 10,467'. POOH w/Halib cementing stinger and running tool pumping 3 bbls every 10 stands. BOPE test witness waived by Mr. Regg 7:58 PM 8/8/2015. Offloaded Halib pumping unit and on loaded Pollard ELine equipment. Reversed 1 1/2 tubing volumes at 3 BPM 600 PSI. 1/2 bbl cmt in returns. Slacked off string and landed in retainer setting 40k down. Halib came on line again and pumped 3 bbls FIW w/ending pressure 3,066#s. Shutdown Halib pump. 08/09/2015-Sunday Finished POOH w/Halib stinger and running tool. B/D tools.Cleared floor. N/D 13 5/8"x 7 1/16"spool. R/U 13 5/8"x 11" spool. R/U 3 1/2"test jt w/pump in,SV&IBOP. M/U perforated sub and test plug. Landed same and filled stack. Tested all BOPE equipment to 250#s low/3500#s high(tested hydril to 250#s low/2500#s high)as per Hilcorp and AOGCC requirements. Performed accum draw-down test.Total Safety tested all gas detectors. Witness waived by Mr.Jim Regg 7:58 PM 8/8/2015. Broke down test jt and cleared floor. R/U Pollard ELine w/lubricator. M/U (Run#1)5.90"gauge ring/ junk basket w/CCL.TIH to 10,470 and pulled correlation strip. POOH and B/D tool string. M/U (Run#2)Halib 5.80" composite CRET/BP w/#20 setting tool and CCL.TIH to 10,470'and correlated on depth. Logged into position and set composite CRET at 10,385'. POOH& R/D Pollard ELine. M/U mule shoe on 3 1/2" 12.95#PH6 work string and TIH to 10,365' (167 stands). R/U pump lines and flushed tb w/1+volume of FIW. R/U Halib cementing and held PJSM. Filled lines w/2 bbls FIW&Tested lines to 4000#s. Opened well and pumped 5.7 bbl spacer,then 12.8 bbls of 15.8#, 1.17 yield, CO.,‘ 5.1 gal/sk,Class G cement,then 2.3 bbl spacer followed by 71.2 bbls FIW displacement. S ql" 08/10/2015-Monday Broke off cementing lines after spotting 12.8 bbl of cmt 10,073'to 10,360'then pulled 7 stands slowly followed by another 7 stands. Reverse out 1 1/2 tb volumes at 2.4 BPM 330 PSI. M/U Halib cementing lines again. Pumped 8.5 bbls of FIW at 1/2 BPM with pressure increasing to 3100#s. Bled down to 700 PSI then held that pressure for 22 mins.4 bbls total fluid returned to tank(—4.5 bbls cmt squeezed into perfs). 2nd Squeeze to 3100#s pumped additional .5 bbls into perfs. Bled back to 700#s, 3rd squeeze added another.25 bbl. Bled pressure to 500#s. Closed safety valve at rig floor and R/D Halib. Bled 425#s pressure off tbg slowly and POOH from 9,503' w/work string&muleshoe, pumping 3 bbls every 10 stands. Prepared rig floor to run 4 3/4" BHA. M/U Knight BHA#1(6"Varel rock bit,4 3/4"x 2 1/4"oil&bumper jars,4-4 3/4"x 2 1/4" DC,xo). Trouble with Foster tongs.Changed out to McCoys. TIH w/cement/plug drilling BHA to 3,256'(50 stands). • . Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 08/11/2015-Tuesday M/U Halib storm pkr w/valve and set same at 126'.Tested to 2500#s on chart. Unscrewed from top of valve and POOH. R/U to lift BOP stack. Unbolted at top of tbg head and P/U stack. N/D old tbg head spool and N/U new tbg head spool. Tested void to 500#s low,good test.Tested high to 3000#s, leaking. Found that'0' ring was cut. Replaced same and tested to 3000#s f/15 mins,good test. Installed valve on spool and lines on mud cross. Bolted BOPS/risor to tbg head and filled stack.Closed blinds and tested to 2500#s f/15 mins on chart,good test. Released pressure. TIH to 126'and screwed into Halib storm pkr. POOH w/same and 8/0 tools. M/U to string and continued running in hole with 6" bit,jars&collars to 10,055',tagging up. Laid down 12 singles and RIH 6 stands. N/D 13 5/8"x 11" spool-N/U 13 5/8"x 7 1/16"spool with stripping head. R/U power swivel. 08/12/2015-Wednesday Drilled cement from tag(10,055')to 10,370'(20'below perfs @ 10,348-50:3 BPM (ca 400 PSI, 60 RPMs at 6600 ft/lbs torque(cement ratty at first). Circulated tbg clean after each jt. Closed pipe rams and pressured up on annulus to 2500#s w/mud pump. Pressure held for—20 sec then started leaking off. Checked for surface leaks, none. Drilled another 10'of hole to 10,380'and circ tbg clean. R/D power swivel pulling stripping rubber. Reconfigured test setup to isolate as much as possible and lined up to test thru test pump. Pressured up to 2500#s with same leak. R/U power swivel and broke circ at 3 BPM 400 PSI in rev. Drilled from 10,380'to 10,390' breaking thru 1st plug.Circ tbg clean. RI 2 more singles w/swivel to 10,448'. Circ tbg clean. R/D swivel. RIH to 10,830 tagging on composite CRET. R/U swivel and drilled thru retainer with some plugging issues. Continued RIH w/singles on swivel to 10,940' at report time. 08/13/2015-Thursday Circulated tbg clean at 10,940'3 BPM 400 PSI. Cleaned oil,dirty fluid and cement sludge from active tank(fluids to TBPF, solids to shaker tank to be moved to cutting boxes once onboard). Filled active tank w/180 bbls of FIW. Flushed thru surface lines searching for plug. Found same and cleared lines. Displaced well with clean FIW, reversing at 2 BPM 500 PSI sending returns to TBPF. Lined up thru shaker and established drilling parameters. Drilled thru remainder of CRET then thru BP at 10,950'. Rotated thru tight spot at 10,990'. R/D power swivel and continued in hole to 11,405'. R/U circ lines and rev'd 237 bbls at 3.5 BPM 400 PSI 3/4 returns. B/O circ lines and N/D 13 5/8"x 7 1/16"spool w/stripping head. N/U 13 5/8"x 11"spool. POOH w/cleanout assem weighing 150k. 34 or 181 stands OOH=9,272' EOTs. 08/14/2015-Friday POOH w/6" bit,jars&collars from 9,272'to Knight BHA. B/D L/O Knight DCs&jars. M/U 6" bit w/scraper f/7"casing. TIH w/bit&scraper on 3 1/2" 12.95#PH6 work string to 10,996'(177 stands). R/U circ lines and started reversing at 2 BPM 0 PSI.Took 92 bbls to break circ. Increased rate to 3 BPM 300 PSI. Pumped additional 200 bbls losing—50 bbls. POOH w/bit&scraper(177 stands). B/D tools&cleared floor. Changed out handling tools on floor and strapped new 4 1/2" 12.60/13.55#BTC Ext Polycore tbg. Making up Tripoint tandem 5.87" Hydraulic set pkr assembly. • • f4,ti Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 08/15/2015-Saturday Finished M/U Tripoint 5.87"tandem hydraulic set pkr assembly=674.65' (601.89' between pkrs). TIH w/tandem pkr assembly as directed by Tripoint Rep. Had to work btm pkr thru top of liner at 7,715'.Top pkr went thru with no trouble. Went to 10,928' (PM)with EOTs. P/U 122k,S/O 60k. R/U Pollard ELine. M/U 1.70" GR/CCL and TIH to 10,940'.Correlated to reference log and POOH. Determined that top pkr was at 10,297'(CC @ 10,319')and btm pkr was at 10,904' (CC @ 10,898'). Tripoint dropped bar to seal plug. R/U pump lines to tbg and filled same.Took 8.5 bbls to fill. Pressured up to 3800#s and held for 30 mins. Slacked off to 40k(20k below slack off). P/U to 150k(28k above pickup). Lined up to fill annulus.Took 74 bbls of FIW to fill. Pressured up to 2600#s( 122 stks=4.5 bbls f/2600#s)and held on chart for 30 mins, good test. Released pressure. Positioned string in jar travel (94k)and put in 15 rnds RHT. Released torque and got 5 rnds back. Put in 10 more rnds RHT and got 5 back. P/U on string and we were released from tandem pkr assembly. POOH from 10,272'w/Tripoint running tool, laying down 3 1/2" PH6 work string. Pumped 3 bbls displacement every 20 jts. 208 of 366 OOH at report time=4,926'. 08/16/2015-Sunday Finished POOH w/Tripoint pkr running tool, laying down all 3 1/2" PH6 work string. 1000 hrs B/D tools then ran in remaining stands in derrick. B/D L/D same. Changed out two air pumps on accumulator unit. Performed BOP accumulator draw down test. Drained and cleaned active tank in preparation to mix pkr fluid.Sent returns to TBPF. M/U 4 1/2"test jt minus test plug.Ordered 2nd test plug. Total Safety performed checks on all gas detectors. M/U plug on test jt and opened casing valve. Landed same. Filled stack w/FIW and closed annular. Tested all BOPE to 250#s low/3500#s high (tested annular to 250#s low/2500#s high)as per Hilcorp and AOGCC requirements. Mr. Bob Noble/AOGCC waived BOPE test witness over the phone 11:40 AM 8/16/15. R/D test jt. Began off loading work string and on loading production string from M/V Resolution. Changed out handling tools on rig floor. Held PJSM w/Tripoint,crane&rig crews. M/U Tripoint seal assembly on new 4 1/2" 12.60/13.35#L-80 BTC Ext Polycore tbg(strapping,picking up,drifting and torqueing to triangle). 145 jts+seals in hole at report time=4,498'. 08/17/2015-Monday Continued RIH w/ 13'Tripoint seal assembly picking up new 4 1/2" 12.60/13.55#L-80 BTC Ext Polycore tbg from 4,498'to 10,257'.Strapping, picking up,drifting and torqueing to mark. P/U 106k S/O 60k. Landed seals and marked pipe.Closed pipe rams and pressured up to 2675#s f/15 mins, held solid. Released pressure and pulled OOH at 9k over.Spaced out and M/U hanger. Lined up to pump pkr fluid in rev sending returns to TBPF. Pumped annular volume of FIW w/^'1.94% CRW132 corrosion inhibitor at 2 BPM 350#s sending returns to TBPF. B/O lines and added full jt&pup.Slacked off and landed hanger w/5k down on seals. Ran in all hold down pins. Pressured up to 2650#s on 9 5/8" annulus and held for 30 mins on chart,60#leak off, bled off pressure. Went thru test sequence three more times with no better results. Point of leak undetermined. No pressure on tbg at any time. R/U Expro S/L w/lubricator.TIH to retrieve drop bar but POOH w/no recovery. • • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 7/31/15 8/19/15 Daily Operations: 08/18/2015-Tuesday Expro S/L recovered drop bar from X-nipple at 10,922'. Decision was made to reset bar and test tubing. TIH w/S/L and reset bar at 10,922'. Lined up to pump down tbg-pressured up to 2700#s and held on chart for 30 mins w/60#leak off. No visible leaks at surface. No increase in casing pressure. Released pressure. Lined up to pressure up thru kill line.Set 2- way check and filled stack.Closed blinds and pressured up to 2750#s against hanger,held f/30 mins w/no leak off. Continued testing casing and tubing looking for leaks, rerouting paths and isolating components searching for source of or explanation for leak offs. Monitored gauges on both sides while testing. Lined up on casing and pressured up to 2900#s. Immediate 40#s increase on tbg as before. Watched chart for 3 hrs 15 mins until a trend of stabilizing was noticed. Total pressure loss of—400#s.Tbg pressure never increased beyond the initial 40#s. 13 3/8" pressure held at 142#s. Bled off pressure.R/U Expro S/L and TIH w/JDC pulling tool. Latched drop bar in X-nipple at 10,922'and POOH. B/D tools. TIH w/ GS Pulling tool and latched plug in same X-nipple. POOH and B/D tools. R/D/R Expro S/L. B/O landing jt and assisted Cameron installing BPV. Cleared rig floor and R/D same. N/D 13 3/8" BOP stack. Assisted Cameron and production personnel N/U tree and preparing same for service. 08/19/2015-Wednesday Continued prepping tree to be put in service and well to be turned over to production. Tested void on tbg head 250#s low/ 5 mins 5000#s high-good. Pulled BPV and installed 2-way check.Shell tested tree to 4500#s f/15 mns. Turned well over to production. 7gtk 6 - '0-Tab PrN CcuOi,j Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> Sent: Wednesday,August 19, 2015 7:09 AM `!�ef To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Cc: Trudi Hallett; Ted Kramer; Dan Marlowe Subject: G-14ARD W/O Preliminary MIT-IA Attachments: work over MIT G-14Ard 2015-08-xx.xlsx N ® 1 • • STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rialaska.00v AOGCC.Inscectors(d?alaska.gov phoebe.brooksaalaska.aov chris.wallace(rilalaska.gov OPERATOR: Hilcorp Alaska,LLC `e/1 8(1l'15 FIELD/UNIT/PAD: McArthur River/Trading Bay Unit/Grayling Platform DATE: 08/18/15 OPERATOR REP: Daniel Duckworth AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 35 Min. 60 Min. J Well G-14Ard Type Inj. N . TVD 8,284- Tubing 0 40 • 40 40 Interval 0 P.T.D. 191-099 Type test P Test psi 2071 / Casing 2675 - 2520- 2530 • 2530 P/F P Notes: Workover MITIA-IA pressures taken off chart -• OA 142 - 142 142 142 • Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F - Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) work over MIT G-14Ard 2015-08-xx.xlsx Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, August 13, 2015 11:38 AM To: 'Dan Marlowe' Cc: Juanita Lovett;Ted Kramer;Trudi Hallett Subject: RE: G-14ARD, PTD 191-099, Sundry#315-381 Dan, Verbal approval granted to change the completion as per your new schematic. Variance also granted to move upper packer to approximately 700 ft from the top perforation per 20 AAC 25.412 (b). The two cement block squeezes should stop any vertical movement of fluids in the 7" annulus. ... unfortunate that they would not hold pressure but not unexpected. Guy Schwartz Senior Petroleum Engineer AOGCCSEED AUG 1 4 2015 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:[his e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Thursday, August 13, 2015 10:42 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett; Ted Kramer; Trudi Hallett Subject: RE: G-14ARD, PTD 191-099, Sundry #315-381 Guy As discussed last night the squeezed perfs aren't holding pressure. The best way to insure long term annular integrity is to run a second packer to isolate both sets of block squeeze holes. Per 20 AAC 25.412(b), I request a variance for the alternate packer depth.The revised proposed schematic is attached. The sand isolated between the packers is the F14 gas sands with the upper confining coal expected between 10,283' & 10,291'. Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowet hilcorp.com Hilcorp A Company Built on Energy 1 • Original Message From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: August 08, 2015 2:03 PM To:Trudi Hallett Cc: Daniel Duckworth-(C);Ted Kramer; Dan Marlowe Subject: Re: G-14ARD, PTD 191-099,Sundry#315-381 Trudi, As we discussed move forward as planned contingency. Not likely to get circulation behind pipe. Looks like cement is better than expected by looking at CBL log. Guy AOGCC Sent from my iPhone >On Aug 8, 2015,at 9:43 AM, "Trudi Hallett"<thallett@hilcorp.com>wrote: > Hello Guy, >Just wanted to give you a heads up and get your thoughts with our plan forward on the Grayling well G-14ARD (PTD 191-099, sundry attached—Waterflood injector conversion). >We began our pre-work for our cement job with FIW injection (to establish circulation) after perfing and stinging into our cement retainer. Unfortunately we are unable to establish any circulation. At most we were pumping 1/2 bpm @ 2500 psi not getting any circulation. At this point it appears what we are pumping is going into the formation and appears we don't have a communication path. Hilcorp requests that we proceed forward with a squeeze job on both set of perf intervals and proceed with the proposed procedure. > Please let us know if this will satisfy the state or if the AOGCC requires add'I diagnostics or work to be performed before we move forward. >I am available on my cell for you to discuss further. >Thanks- > >Trudi >Trudi Hallett I Operations Engineer >Cook Inlet Offshore Asset Team I Hilcorp Alaska, LLC Hilcorp A Company > Built on Energy thallett@hilcorp.com<mailto:thallett@hilcorp.com> >0: 907.777.8323 >C: 907.301.6657 ><10-403-G-14ARD-Approved 2015-06-30.pdf> 2 . , . 14 PROPOSED McArthur River Field,TBU Well: G-14ARD Hilserp Alaska,LLf. 10 s "." Completed: Future • RKB to TBG Head=42.6' CASING AND TUBING DETAIL Tree connection: MD MD ND SIZE WT GRADE CONN ID TOP BTM. BTM. CMT L 17-3/4" .312 wall Weld Surf. 522' 520' 700 sx 13-3/8" 61 K-55 Butt 12.515 Surf. *1390'-1460' 1361' 2500 sx 9-5/8" 47 N-80 Butt 8.681 Surf. 7970' 6455' 2950 sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 4-1/2" .,u/13.55 80 SIC Ext. 3.598 Surf ±10,928' Polycore *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL NO. Depth Depth ID Item (MD) (ND) 7715 QI Z 42.6' 42.6' Tubing Hanger LSI 1 100' 8,287' Packer w/15'seal assembly 7970'Z , 2 ±10,900' 8,774' Packer 3 ±10,919' 8,790' X-Nipple 4 ±10,928' 8,798' Wireline Re-Entry Guide 1 /0 3''''' Casing Block 5 11,448' 9,250' CIBP Sqa 10,348-10250 6 11,451' 9,252' 4 Otis Model"BWH"Perm Pkr 1° acing Block 7 11,463' 9,263' 4 Seal Bore Ext. qz 10,848-10,850 8 11,535' 9,328' Expandable Bridge Plug Ie Hc‘'(_..,_ "!A 2 X 3 9 12,093' 9,841' 4.00 Otis Model"BWH"Perm Pkr. 4 10 12,098' 9,845' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin t COY 11 12,103' 9,850' 2.31 Otis"X"Nipple G-zone 3 Top of Cement (!2 R 4' 12 12,110' 9,586' 2.44 WLEG 11,428• - btm 12,111' 5 13 12,866' 10,559' (2)Junk Retainers MIESIOM 7 Perforation Details Top of Cement Zone MD(Top) MD(Btm) ND ND Amt Last PerfPresent Cond. 11,518' Ii! .!I (Top) (Btm) Date 8 ' ` B-1 G-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open B-4 G-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open 12,093' 411 9 G-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open 6-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open 10 6-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open w. - 11 G-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open / ‘ 12 HB-1 11,519' 11,523' 9,314' 9,318' 4' 08/20/13 Isolated = WF-2 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated c WF-3 HB-4 11,820' 11,935' 9,589' 9,695' 115' 08/20/13 Isolated WF-4 WF-2 12,227' 12,317' 9,965' _ 10,049' 90' 08/20/13 Isolated TOF 12,625' = WF-5 WF-3 12,332' 12,473' 10,063' 10194' 141' 08/20/13 Isolated WF-6 WF-4 12,477' 12,524' 10,198' 10,241' 47' 08/20/13 Isolated -• • WF-5 12,564' 12,568' 10,279' 10,282' 4' 08/20/13 Isolated • WF-7 ' WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated / CTS . ` WF-6 12,667' 12,719' 10,374' 10,422' 52' 08/20/13 Isolated ETD=12,868' TD=12,939' WF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated RKB to MLLW ELEV=103' MAX ANGLE=42.9° ag 4692' Revised 08/13/15 by 1LL �K G-iib Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> Sent: Sunday, August 09, 2015 7:20 PM To: Regg, James B (DOA) 7 I Subject: G-14ARD BOPE Test Charts & Forms Attachments: G-14ARD BOPE Test Report 9Aug15.xlsx; BOPE test 8-9-2015.pdf STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Jim regg@alaska.gov AOGCC.InspectorsCa aaska qov phoebe.brooks( .alaska.gov Contractor: Moncla - Rig No.: 404 - DATE: 8/9/15 Rig Rep.: Terry Davis Rig Phone: 907-776-6757 Operator: Hilcorp Alaska Op. Phone. 907-776-6757 Rep.: Danny Duckworth E-Mail dduckworth@hilcorp.com Well Name. TBU G-14ARD PTD# 1910990 - Sundry# 315-381 Operation Drilling Workover: X Explor. Test: Initial: Weekly: X Bi-Weekly: Test Pressure(psi). Rams 250-3500 Annular 250-2500 Valves: 250-3500 MASP. 2039 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P Upper Kelly 0 NA Housekeeping P - Rig P - Lower Kelly 0 • NA PTD On Location P • Hazard Sec. NA Ball Type 2 . P . Standing Order Posted P - Misc. NA Inside BOP 1 - P • 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 . P #1 Rams 1 . 2 7/8"x 5" - P . Flow Indicator NA NA #2 Rams 1 blind - P . Meth Gas Detector P . P #3 Rams 0 NA 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 • 2 1/16" - P Inside Reel valves 0 NA HCR Valves 1 2 1/16" - P • Kill Line Valves 3 -' 2 1/16" , P • Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 P . CHOKE MANIFOLD: Pressure After Closure(psi) 1950 - P . Quantity Test Result 200 psi Attained(sec) 36 P No.Valves 10 - P Full Pressure Attained(sec) 152 P - Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 - P Nitgn. Bottles Avg. (#and psi): 6@2200 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 / Test Time 4.5 • Hours Repair or replacement of equipment will be made within NA days. Notify the AOGCC of repairs with written confirmation to.AOGCC.Inspectors@alaska.gov Remarks. Tested w/3 1/2"&4 1/2"tb. Witness waived 7.58 PM 8/8/15. / AOGCC Inspection 24 hr Notice Yes Date/Time 8/1/15 6:29 AM Waived By Jim Regg Test Start Date/Time: 8/9/2015 9:30 (date) (time) Witness Test Finish Date/Time: 8/9/2015 14:00 Td— C tu.• k - Form 10-424(Revised 06/2014) G-14ARD BOPE Test Report 9Aug15 xlsx 11 „. BOP EQUIPMENT TESTS Rig.MONCLA 404 Operator. HILCORP Location: GRAYLING Date 8/9!2015 Lease No:ADL-0018730 Well No,G-14ARD Previous Test Date 8/2/2015 Test Station Used:REMOTE BOP EQUIPMENT PERIODICAL TESTS TEST LOW TEST HIGH TEST REMARKS NO Pressure Time Pressure Time Record all items tested,failed test and repairs 1 250 6 2600 6 ANNULAR 2 250 5 3700 5 3 5"PIPE RAMS,M I,M2,MI0,K3,IBOP 3 250 5 3550 5 SAFETY VALVE,K-2,M-3,M-4,M-9 4 250 5 3600 5 K-1,M-5,M-6 5 250 5 3500 6 SUPER CHOKE,BODY TEST MANUEL 6 2400 2 1850 2 MANUEL CHOKE 6 1800 2 1250 3 SUPER CHOKE 7 250 5 3500 5 C2 8 250 5 3550 5 C1 9 200 36 SEC 3000 152 SEC KOOMEY DRAW LIND 10 225 8 3550 5 BLINDS,M-7,M-8 11 275 6 3750 6 4-1/2"PIPE RAMS 12 250 6 3550 6 4-1/2" ANNULAR FLUID USED:8.5 DRILL WATER CHECKLIST ACCUMULATOR TEST Does all equipment hold pressure without excessive pumping? INITIAL PRESSURE 3000 PSI - Yes® No D Is ACCUMULATOR VOLUME—GALLONS Yes IE Noto❑r void clean and reservoir filled to proper level? Closing Ending Volume To Is maximum allowable casing pressure posted on the rig floor? Item Time Pressure Close Open Yes® No❑ Annular Are accumulator end remote station tagged as to their function? 2-7/8 X 5 Rams Yes® No❑ BLIND Rams Is there a spare annular packing element on board? Annular packing element Yes® No❑ ' Rams NIA N/A At least one set of rem inserts Yes ElNo❑ - Rams N/A N/A Bonnet seals Yes® No 0 CHOKE HCR Drill crews instructed to function pipe and blind rams each trip? Yes EI No KILL HCR N/A N/A Are HCR valves closed after testing? Final Pressure 1e50,' 3000 ' Yes 0 No El - TOTAL TIME TOAre both kill line valves closed after testing? RECHARGE 39 152 ( Yes❑ No Do all rig personnel meet regulatory agency requirements? Yes El No - SIGNOFFS Toolpusher:TERRY DAVIS/GAMALIEL SALAS Operator Rep.:DAN DUCKWORTH NOTES:NITROGEN BOTTLES AVG.2200 PSI V Driller: JOSHUA NOEL!SCORY DEMOUCHET INITIAL 200 PSI BUILD UP ON KOOMEY Other: • RECHARGE=36 SECONDS NOTE:All pressures are In PSI ROPE T — Atekvc.tit.4v4 tit Pj 1 k 60 0 tc` _ S / ,850° NsNN / 3000 +-- — \ \ \''' ''''' N� 3° ti. r /7Vi `\ t0 0 \\ / \ \ 0 O o°/ / \00 .------- -----,., -----../0 *IV \\ rs 3/ / / / , ' , 0 -1 / / / Xy, oh o ..'.. 1 , / : Z>'''' ':.--"--1 ' ,,- --. -,20 °42. s\ , \, \ \\(1 _ ' t- / 81 i I "500o-loR - o / Cti, 1 4 \ 1`` ' II TAKfN oFF M1 CA O O IpMP c o1: çoc:: 77 o o IN 8 rt; O\ ' ��ne °' \ 1 '// \\\ (gAA / 11,,,,E))/ 1 \ ° t / / i s\ '‘ 00 '''''t)t-___ --- — ----- ' CF3C)\_,'''' / / /\ \ // / I oc, 4:,,,,,,,,,,,.,:, . -___ ___---'--- , ..•-•' 7 / o / ,// / i pe--- ---57 -Mchc ia4o4 ó('l/15 of Zfc 6t 0 - yam, . \ i �� . / /. ,„/„..---,,- 3500 i` -• .-:-,:--\''' •-.N'�x 4 \ 'O // / ' Z' . ,/ ,/...-5°() -----7-- 1-• — ,-A, –1-- : - ''''-. ''''- ' ''' 1'0 ' % , / y/ . -, -.7,<----....:000 ____-----i----- ---7----1-__ . -------: ---. \ 0 \ ' • \ - --I----7———. 1 ' `,..,.t N ?),\ , \ 4/./. / . ' '-' .' -----'-'>''' ,500 ��-- . , `•N So \ \K \ �J <30 °T . \ \ \ /// / 'Z''''''tpC). ---'7------ '• -. -----------'-',5 N \'' . '\ \ \ \ \ / . • i \ \ . r' O O 7 /// p1C,„,,\,,,,,,-0.._____,:::.5-00,0,..,0T, 1.h,‘,-- - \ \ \ \ \ , \ \ F, I o 1 ( ARS Np' .1 ,} ,i , i. 'I N N o0 o f- 1 pH / �. I ; , ' 1 I '.. tocio• SAKFN pFF r, O c n N I I 1 :; al P\11 ON N l 6,• �P -t 1.,....4c.).7 0 i _� %.0-.1 0,110 r .„- -• 0.1.00'5 siq 15 /0j 1 140Fo _ AAS % % , \ \ 4, - - t‘,._ ////- ../ / \\:\\.\\-\ >H\::\\\ o04.,,,,, ..,, _.,_ • i ____ „ 7.- . / ; . / // , \ \ °O\\ OH�\ J o /; OZ O °°°46 N N\\\\ / -\ � - — i 000 /' / i/ 42 / ,tea? i oos� ' ti .— / p SPF 1--r- r- McMck 404 (13191/5 P6 3/ 5" • 60/ -�� asoo z . \ _3500 \ /% �, `y _ `J 3000- \ \\ - / .,,;/7-' - :---- -� -- `z� -2500 — \ 2000 -_ \\ ' 0 / Z Z' ,__ . \\:\\\\\ 4' / x-1500 ___L______--....1 _ ,\ o-ppp / i / �\ \\ i, ted` ///// / •-1000 \ • \ \ �s oo °o / ,of - o \ ° \\ 000 / 500 f o0 00 y ' / "1i TO ,. (5se \ \ \ , \\ / O i lo7 o ' \: \ \ ' ' ! o CHART N0. _ MC MP-5000-IHR V \ d \ , l I. t. / (' METER � t- I� i [ '� '-4 -- 1 'UHART PUT pry `.�-• 1 I 1 l i `i .{_..I \I I 1 IAY,EN OF J ! 1 . ' - i ' ' \ ' \ '4\ LOCATkiN CTat - - M ' ;',, '�1 `_. \\• , \ \\,, REMARKS 1doy��.�T��YA � � j�,O 1I � � _ ' O \ 47 i j l l \\ oos�\ M�� / ,'. 00 o j / jo 4,,... (.,7 • / / c:) .. / 0 000 s,V� � r � ow o0o sem. \\ \ --- ' o o // % oc"S") CI \ - -_,.........._____ _.,-- / //1, _,..z. . /// /// /e 4//, \ .----� 000z f .\ � - oos - O i>•'•-/ (/ / \ . -,...,. ---7 7./ N. _ OOSY— j- r 2 5 ( ou- f-si- -Om act.404_ ol.1/1 c io --- _. , ----- ----.- 00- ------- ---------_____--- _______ ------ ------- - --- -- --.... --... ,. - _ _ -- ,--- _„...----- A000 -- -----_ -----___ .. ...--- ,,,..----___.-- •--- . . ------ S---.... .•---- N. „„-- , __...-- __,,,..„3-.. , • ._ ..,..„.„ -,...,,, ••.,,,,,, / - -- ,!_,------"------ --- ----7-----7'----- --_, •,: ,"'''NN. \ • ----________----, , / '...---"- __I,----- -----7-------------- "--,-. --, . s. \\ • 7 . -'' •---- • ------3 ---__.__ — • i \ ''N .,, '-\' \ \ _... ....--------- --__ ----- \ • ..-- . ..---",---1______.-L____:____ 0 . ..\-\ 0 7/.-- "•-•., •,,,,,N•N\N\.., Tro 0 „iv / - --r .• \ \ _1_---------__ . ---.., •., ,..,,, . oc,>. . \ \ \ . '''‘ 500 — ' •' ''',., rt, ,V\ \ \ \ \ \• ',33 \ \ '\ \ \ 1 \ o'n \ \ \ • • 'k,t:s\ • / , s a / / . •Ce 6•:Z* ,....- \ \ \ / / • / -,',. k . 1 / /'R , 8 -,-... f.,..1 / _,•-• o \\_ir .-\\--- --• 7 1. E , , I f •1 ; .1 I 2 T 8 -i: .z,.! , 1 tr.: _ 7, Q1'3° --- - x- i ( , 0 . , : 1 \ \ ' I 1' 1 .z- .i g t _i_ • . . , . ,. . .,.•4 . ) • .1 ) ,.! I 1 '1--.. 8, I . I / I / • l,: ; ;lee /1‘' / / ,/ ,--"9--- , ? , 2 I /1. I i . I \. • \ , \ .1% kJ . .\.. -...,.r / / "..-- . / / / „' ,,,a • ,,,. i / / ,--,....._0 0 1.7. c't...."__ -...,4:9__ 4.4- 0 / \ 0 N'9)1...:-.'"-•'- _ . :, ' - .,.,/”. / ' ,, / / / 0 4... • , i • ....„ . - __ - _r„ _;.... _ . . • 00\• N,,...,,,,.... 00- - ' ilik ' / .•„_ , / , k\ 0 'PeNN° N _- -------' 00 0 4' , , • /74(/ I / 4 / r -----._-______ _,.... '.___,--- ,...--"" -7. . • ' ,/to ,/ , • • -_____ .__clog?, ,.---"" --- / / 1 --- /- ----__ • oti/ 0/ ' NNN,,,, ',''s-,-,_ - -----------____L _-•.1 -0 '___- - -- ji& it •• // . - • --____ -----------,--• .. . , 00 -----• -- . I • / ''."Fr )).1 Z // g __-- . at.' ; 4 • • - --___ . -___„____ • _._--.-- ____.------- ,,,,....- ...-- ... r' \,,..7 . — ----,---_, -----------;-______.—--- ___-- _,... ----- --________ ---- -..„, .-. ,.., „,..,.... -.... OV------___ ---------__ __----- .•p -......_ 'ES Igl,s P55-15 50 _ __ ____ _ __ _- 55 ...,... 500...„- ,..._ --- —___--r- \`'e..,,.. GJ �t7 - „ 7,„,- 000 '.__ o0 a 7/2/' *?/ O00 _ BOO......,/,.. ` \ ` \ 1 / 2/ 7i / / // vtoo/�/l ' ,,000 i` T ---- --/0'0' o� \• \' > >\ \� ,` / // / / ,goo _- 2``- oQ�,� \� �• \ \l \ \t `` f r /f / , ' v \\\_.\\ � '-. \ \ \ \ \ \ L. / ! j Q ddd \ v \ V ,Ny \ ‘, A , ' / / / // / \ , {3 o ---I- .Af i , 1 ` ` 1 , n OII, I ' ' t{ N�o oa G ` ocNT ` soO , N oO O FAy9P1, O O o li 11 IOO 4,9 , 5?”' O' i \ _ OO 1 \ , A o OWi � , It sF j , / 1 I \ v /�'k,, \ A \ 04, / / r / / / / / or \ � - \ " � ry , 1 � / i/ / l1.,;:i I1 � � , \\ s -„, 04-,,..., ------ ---- o /,/- / \ / /\ \ \ / /� ‘ \\N\ \ ..\\ \ \ s,„ \ ,,... 4.),,,.1,1, ,47..„...:: _______ii,_-4-- -_________ voc:-, 7,, ,,• ,,,,, ,,,,,,,„„, 1.16.,,,, / /////i \ \ s:\\\\\ 00,e, ,,... ..,,,...:::-_----___, ___ _______---a000z ,:17, ,/,/ 10 // / co y\ \ \ , N '` '`,., '-- .._ ----____ ___4.----- __ 0 ,,- - ./ / ci ��_ - _ sn s, --- oZ � , of Tye \�177, sv THE STATE Alaska Oil and Gas j--7-14-47 M of T Conservation Commission4ASKA /LI _ 333 West Seventh Avenue 1' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 11r."•°OF nnq Main' 907.279.1433 ALAS*P' �) 7 'V 1S Fax: 907.276 7542 SC ItD JUL www.aogcc.alaska gov Trudi Hallett ` O 1 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock and West Foreland Oil Pools, TBU G-14ARD Sundry Number: 315-381 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this of June, 2015 Encl. • tt.' JVED STATE OF ALASKA JUN 18 0(7S C/z //s 2t,I� ALASKA OIL AND GAS CONSERVATION COMMISSION ;$ F� _ APPLICATION FOR SUNDRY APPROVALS --k '�, e-,:_ - 20 AAC 25.280 1.Type of Request Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well Ei Re-enter Susp Well ❑ Other: Convert to Injector CI 2.Operator Name. 4 Current Wel Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development Il• 191-099.' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20189-01 . 7 If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes El No[ Trad'ng Bay Unit G-14ARD - 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 • McArthur River Field/Middle Kenai G Oil,Hemlock Oil&West Foreland Oil Pools • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft). Effective Depth ND(ft): Plugs(measured). Junk(measured) • 12,939 • 10,627 • 12,625 • 10,335 11,448&11,535 12,625(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 522' 17-3/4" 522' 521' Surface 1,390' 13-3/8" 1,390' 1,361' 3,090 psi 1,540 psi Intermediate 7,970' 9-5/8" 7,970' 6,467' 6,870 psi 4,760 psi Production 5,224' 7" 12,939' 10,620' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft). Perforation Depth ND(ft) Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.3#/L-80 10,870 Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft) BWH Perm Packer(2)/SSSV•NA • 11,451'(MD)9,252'(ND)&12,093'(MD)9,841'(ND)/SSSV:NA 12.Attachments Description Summary of Proposal D '13.Well Class after proposed work Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 .1velopment 0 Service 0 ' 14 Estimated Date for 15.Well Status after proposed work: Commencing Operations. 7/15/2015 OIL ❑ WINJ I] • WDSP❑ Suspended ❑ 16 Verbal Approval: Date: GAS 0 WAG ❑ GSTO[] SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature j ffeteCat Phone (907)777-8323 Date 6/18/2015 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number: / 15. 3v Plug Integrity CI BOP Test Mechanical Integrity Test la Location ,Clearance CI Other I(is A0,, o be 1� &(c errtip +�1 � w/` ,. 1t0 S0©©. 5 JP 1 -U r5 .. ,U.0 •T,- ( IKA S, 2 0 3 „,,� X- Spacing Exception Required? Yes ❑ No d Subsequent Form Required: i) y cif APPROVED BY / C Approved by' �"-- COMMISSIONER THE COMMISSION Date: /( — 3 — / ty �-,2�/-/$ �Tl�u ��2��i5 ORIGINAL RBDM JUL - 1 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate W ‘,/Z 2iZof.f Well Work Prognosis Well: G-14ARD Hilcorp Alaska,Ili, Date: 06/17/2015 Well Name: G-14ARD API Number: 50-733-20189-01 Current Status: Producer Leg: 4(SW Corner) cv---\ftn Estimated Start Date: July 15, 2015 Rig: Rig 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 191-099 First Call Engineer: Trudi Hallett Office: 907-777-8323 Cell:907-301-6657 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell:985-867-0665 AFE Number: Current Bottom Hole Pressure: 2,926 psi @ 8,866ft TVD/11,008ft MD 0.33 psi/ft grad based on static PIP (6/15/2015) Maximum Expected BHP: 2,926 psi @ 8,866ft TVD/11,008ft MD 0.33 psi/ft grad based on static PIP (6/15/2015) Max Anticipated Surface Pressure : -2,039 psi Using 0.1 psi/ft gradient to top perfs @ 8,866'TVD per 20 AAC 25.280(b)(4) Brief Well Summary Grayling G-14ARD is currently a shut-in ESP producer completed in the Middle Kenai G-Zone. His1Qr_ically,G-__ 14ARD was completed as a Hemlock only waterflood injector. In 2013, Hilcorp isolated the Hemlock and re- completed uphole and converted the G-14ARD to a G-Zone only ESP producer. Recent reservoir studies indicate G-14ARD is better utilized as a G-Zone only waterflood injector due to the low injectivity in the G-Zone in this area of the field coupled with the poor oil production rates. Hilcorp would like to convert this well to a waterflood injector in the G-Zone only. f This application for Sundry approval outlines the procedure for pulling the current ESP and converting the well to a waterflood injector.An area of review is needed for the conversion. No new perforations or reperfs will be added during this workover. The last 7"casing test was completed Aug. 29, 2013.A CIBP was set @ 11,448, dump bail 30 gallons cement, - waited 3 hours and pressured up to 1500 psi and charted for 15 min.Tested good. AOR(status of wells within 1/4 mile radius of injection zone): API_WellNo Permit Well CurrentStatus Zonal isolation(method) G-Zone Top Per @ 11,080' Little to no 50-733-20189-01 191-099 G-14ARD S/I Producer cement above 11,480' MD 5/29/1992 Segmented CBL �1,c( •�. S z.• Top of G-Zone is @ 10,061'. Sqz'd 10,E0'- 50-733-20073-01 167-085 G-06 P&A'd below 9695' 11,354'. Retainer set at 9,695' and squeezed w/350 sx sx CI "G" cement. 4/06/1982 Top of G-Zone is @ 10,720'. Sqz'd and 50-733-20267-01 198-064 G-08 P&A'd below 10,684' aband'd HK perfs w/350 sx CI "G" cement. No open G-Zone perfs. 7/4/1978 111 Well Work Prognosis Well: G-14ARD HaeerP aiARk,.I.1.t, Date: 06/17/2015 Procedure: 1. MIRU Rig 404 over G-14ARD. 2. Notify AOGCC 48 hours before pending BOPE test. 3. Set BPV, ND tree, NU BOPE. 4. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250 psi LOW and 3,500 psi HIGH. 5. Circulate hydrocarbon out of well. 6. POOH laying down completion. "''� �r% / 7. PU and RIH with 7" CO assembly to+/- 11,400'. POOH and LD same. 8. RIH w/ RBP to 10,975' and set. Dump 20' of sand on top of RBP. 9. PU and RIH with perf guns and perforate ±10,950-±10,940'. And ±10,850-±10,840. 10. POOH with perf guns. . .0-- 11. PU and RIH with cement retainer to ±10,930' and set. RU cementers, establish circulation. S'i- 57 12. Pump cement through retainer and circulate same up through upper perfs at ±10,840'. Sting out of retainer, PU above top shot, clean up cement out of the work string, POOH with WS. WOC. 13. PU 9-5/8"storm packer, RIH and set same at 200' and hang off string. Pressure test to 2,500 psi and chart. 14. Release from storm packer, POOH. Replace tbg head. Re-rig BOPE. 15. Test all flange breaks to 2500 psi and chart. 16. RIH, engage storm packer, release same, POOH, LD storm packer. 17. PU and RIH with clean out assy, cleanout/mill cement to±11,000'. LD same. 18. RU Eline. RIH with Cement Bond Log tool to verify isolation above Top G-Zone perf @ 11,008'. RD Eline. 19. PU and RIH with injection string. 20. Set pkr @ +/- 10,000' and pressure test to 2,500 psi and chart for 30 min. 21. Conduct work-over MIT-IA 22. Set BPV, NU tree, and test same. 23. Turn well over to product' n. 24. Schedule initial MIT-IA ith AOGCC within 2 weeks of stable injection as per regulations. Attachments: --- '(,4 0 1. Area Of Review Map I 2. Current Well Schematic "_°�...., 3. Proposed Well Sdhematic "`-...,_. 4. Current Wellhead Diagram 5. Proposed Wellhead Diagram 6. BOP Stack 7. Rolling BOP Test Procedure • J V W 1 p 6 LL yP 5 w1 Li 21,1 11= 2 v Q v O .Zr m o v a c .- V J J O C CD 0 'y D " u I v a1 N -c C O v, m I I / N W ........-6` II I / \! ° i I _ E o m O ^LI_ rn M/ I 1 N (.9 a a) I i----, � JJ I I YC CO o. . o 1 q I Y -tea v/i `^ 1 I �� }' -C IY o / \I " Oa>, v > v0i o '� N i —t ---- I N . 0 - Ily . ..., 1 di \ '`\W Co I i I n 1 A • gir 4111 _ . . ' ' ,/........,,..Aiiitir-, , Jur— -42i Y o N Ln ra a.) C °Ct N 0 U rol CO 0O Ln o " / ° +-.. 4__. °o N ca 4'; 41/41111N\v c C9 v, o 03 n C.) m 2 "O aN I 0 ' 2 . . 0 oi N 09 g Q 0 Y G a 6 cn ~ ,--,{rn QY -01a) f -C 0'C -r,rn m '7 _ c m 41 g: 1 z - N rr , r -� -k .�_. rn r- _ • j r,-,!;0 'tt . =.=b,--- 1 rn ulin --,m 7-k -= 7- 'mI r- c, ' IIIIIIIIIIIIIl111n�„„IIIIIIIIIIIII111111111I11111111I1111 Co QIP (7,„ ,, 1.�-., CZ: (7;0-- ch n,, �o .�. 1� -‹ a30 ' r- x = AK00006199 ,,. (m a -r, -,-, I fes. n C z . . � N 1 -Al I rn ,' . rn rte, ,� CI r-, i z, j 'T I to n -ri r, i r I m .� © * r C: ` I • n c c rr; r-- rn�ca�col-- rr(cxs _ r,J ED j- . . Ui010 — rJNLC u. -< �,. 1 cn; --3 r-t in , r- cn COCOm 01 a> 0 = r crt r- -1 Cl a - z r ul Ix, , m 1� ' co.--+: T rai— icr, 71 rn Cl'7 9 , ' J rn s - m W - rn; 1 [ i 7 1 —11 i ^'' :: s M I �r7 • :,,,. , ,,,,, ' , , 1 , , X , m } . .�.. n � iv. t 3 _ -....4 . rr t I> 71 CO rri C7 c-) 7c. 1...1 G? E i ? ` - - omo . Q' N �J , 101 -9 ,n cin < m r.,... 4 m I c C us i 1 w w -4 a r-- z z z T a n loo,tirn I I p c r O O rn o m z - -- a 7 LI m cn - -1C (I) 01' 0 yea Z c> car m N/1.4::. rn r, m CO, J m r-- 3 ; , O H :i7 m' r7 m cn ar 3 m a I s I ' 073n . 51zHZ f ,�, c co m rn 7 c r -4 rn -{tj) mti) ril-»! X m Z co c { m 3 H r - {jccnc> I zz- r mmraz - cpi n ax x 70 z r '" - m x n n, m c 1 3 m 0 cn m C7 D r D o n a) I 0 H m _ c%- U) x o m o C C Z D x O -.< a Z 3 w'r I 'V Z111 - z r rr r a - m m Z Q co a -`r N I CSU W --I __ 7 -Z-H w `rt m o tDx CCft- rn 0 u71-•.1 Lc:. , o m 0 c.0l m n 2 = rn m -1 rn m -I D C) I U) ZZ O ; 0 m S -d Z t -i 0 m m n rn 3 I ' m i -.c r- F O m C rn REMARKS LOG TIE0 TO SBT 24-MAY-92 . LC73 PURPOSE ; TO EVALUATE. SQUEEZE JOB. L ----1 EQUIPMENT DATA RJN TRIP TOOL SERIAL NO, SERIES O. POSITION 1 1 SBT 11538 1424 X A CE N T I I I GR 73468 1309XA %..,, ."d ...§4 P' 11:17.47-4: CEMENT MAP 7" LINE x t f R3 S -:2,:'�.3'Jhx!MWWIE nvewmot=- a.. -maiF� o-Am.... T », , "0,0.42,.1-:- xx Wuntcea sr=a b '�' xs r E:.« ' ' ''��air„.„..,w�«.'_°- :,,,i',e u ''.1 Z. i.: ' �� s ;z�;.,�' '' �rara' �..I-... � ' e� ♦**i+ki****N#+hi +►91F*#i***#**** iii►+►M+it-1�rY�l��!#ei+RAYi..., *! 11 ' rlir r .4 ,. .44,' 44 , r..04.1 iiiimINNENI iiirKlihror. iiiiiiii Mt 1 VI 1 t f . amil 1)'.1 1 e e A k 41 : + t S 0.4 inilli "s. litf s; . tor ' p t e s _[ 4 } t I It tt tttr 1 I _ — " " III _ { I - e _.. 1. P r _ { I it i iii Ems"y '"°r'T � :.'t 11:1' %r E i = 1 t i �A. - ., 1 Iniummiiii I , ..}4 ... ` - t- r .f - ; -- r , , -4 I it) } iww a :Al — # t Io, 4.! ' (I_ Ct.jr jW I' Milan — _. r f l , ( 4 ,( .. z �r _ P' , t J*4 1: -t f -4- • ' -•"44 -- 11 <1''' ll'Is-'--. '', y F --___9 ___. ._. #I�w�"�" ..._ 0 _... . -, Yy *:10t + ._ a —i_ a s - i' a. a — �_, j.. tic ° ",y, "A r �i 1 i sissii11111111•11111111111111•1 .. ;. ;. .s .i......• ___1..., .....7. ...... . I. *. W ..,,.. ...4..... _ . .1 ' ---,,. ', i 1 4: ,,,,, .. ....,,,.,_, .....1, d ...... ._._ _._.4 _v _ d : r^r i � 1 � .. iii., -+ wiiimi t... IF __ _ _.___AP 1111=11111111 ' .ii!,. i f Rif--�..�4.___� i . _.L. q lip. -«- __.___._. _.. �t Jh), ; _I. ,,,, it ....._ 4 -,--- - .....,. 77' t 'of. il i i ... ,I, lo: ,1 I i .. *)7111,,,4) •- voismill ? } . ,. 9 i • e _ • '' 9 I d E , a - ^ k1 } E ti t - *flitilItir4M111.11V.111 , -- . • - r. i,., il; , , , - „,......,,,,,,,,,..... , _ __, _„.____ ,1/4, ,- -t- i , Li I 1 ,i,t i - R i e , r w:. r t , • 1 g ?� + ! ,, x ' ,,i-,..,,,,,i, ,,,,,, :.,,,,:j.,.., ! ,,F _ .._ } , ' ...... --{ is -R- _— g y w s d a 6 I a M . _ . p .- . _:._ -. _ -wry.• ......_ o -. __ .., _, --.-..-, Y ff , 4 jizH c 7/ t .— _ ._ ftft .u 4 1 "1`-" S 4 B ..,. 1 -e°•.. i._ f ¢ f 1 A 6 { .«.,,.,.._.... .�,.._._... i.' ' J 7 # py Ej � � J I i -- " w. t i �� E y - t 1� ' .d_+ —` . *=_„ s �a� i mi • 3` 44t w �� y d S E lit '.' ; ; 47, , E * i— : 5 maim . i x .4__ ___.___,__,,,t, - _ 1 ,, -�`t tai h Ink, # r i f 1 N! I — I i _ I.: t ,t it ' - 1` 1 ; I ___, : , i_...,....i 1.1' 1) _ W_ a"- ot i ,. — 1—imit ...._! _ 4 .-----1--- ... -------- , g - -- — ; ,gi;1 i re _- _______ 4 . „ _ : , , A , ,.,._. ....., r t. ,n A,..5 —r Fr y ' e { i r $ w ! ( {, ) ( Ill) }y i _ t E 7 i _ 1 , t y... .ii_ % ..3....,..._, } ..._...� i''''' . ( {. r^' „ ..... i:j 1 11, , 1 t MIA _gym__ e -2 q 6�- '..,,,,L,.. 1 —i a "-^---"- 't,x. 4, ,- A H. SCHEMATIC McArthur River Field,TBU Well: G-14ARD Hilmrp Alaska,LLC Completed: 09/07/13 RKB to TBG Head=42.6' CASING AND TUBING DETAIL Tree connection: MD MD ND SIZE WT GRADE CONN ID TOP BTM. BTM. CMT Zi 17-3/4" 312 wall Weld Surf. 522' 520' 700sx 13-3/8" 61 K-55 _ Butt _ 12.515 Surf. *1390'-1460' 1361' 2500 sx 9-5/8" 47 _ N-80 Butt 8.681 Surf. 7970' 6455' 2950 sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 3-1/2" 9.3 L-80 IBT-M 2.992 0' 10,780' *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL NO. Depth ID Item 7715 Q 42.6' Tubing Hanger Q 1 10,780' Head Bolt On Discharge 2 10,782' Pump(x 4)DR1750 CR-CT97 STG 400/400 150 CS VTHD 7970'L, , 3 10,869' Intake DRS,400/400 RLOY 1 4 10,871' Protector(x2)Maximus,LSBSB-S/LT,400/456 2 5 10,887' Motor 456 10,4106 Maximus 3 _ 4 6 10,944' Bottom of ESP-Centralizer II 5 6 ' ty 7 11,448' CIBP tip.' 8 11,451' 4 Otis Model"BWH"Perma Pkr G-zone 9 11,463' 4 Seal Bore Ext. , t,- Top of Cement {3 10 11,535' Expandable Bridge Plug 11.428' t{�D P PI '°'' R " •9wPr"' Alli. 01 '' 11 12,093 4.00 Otis Model"BWH"Perma Pkr. 7 12 12,098' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin 8 :or 9 : •6113 12,103' 2.313 Otis"X"Nipple • 14 12,110' 2.44 WLEG Top of Cement 11s18 btm 12,111'iimaiiiiiiiiw - 10 15 12,866' (2)Junk Retainers B-1 = B-4 Perforation Details 12,093' \ x 11 ND ND Last Perf Zone MD(Top) MD(Btm) Amt Present Cond. (Top) (Btm) Date - . 6-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open 12 13 6-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open • 14 G-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open WF-2 6-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open 6-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open = WF-3 0-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open HB-1 11,519' 11,523' 9,314' 9,31.8' 4' 08/20/13 Isolated WF-4 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated HB-4 11,820' 11,935' 9,589' 9,695' 115' 08/20/13 Isolated TOF 12,625' = WF-5 WF-2 12,227' 12,317' 9,965' 10,049' 90' 08/20/13 Isolated v'" r4 WF-6 W F-3 12,332' 12,473' 10,063' 4 d 10194' 141' 08/20/13 Isolated , � `` , "t WF-7 WF-4 12,477' 12,524' 10,198' 10,241' 47' 08/20/13 Isolated si ` 42.rg WF-5 12,564' 12,568' 10,279' "4:,,$°v� ,,�, �6� 10,282' 4' 08/20/13 Isolated ° t-COW: `.-,` 15 WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated ETD=12,868' TD=12,939' WF-6 12,667' 12,719' 10,374' 10,422' 52' 08/20/13 _ Isolated RKB to MLLW ELEV=103' WF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated MAX ANGLE=42.9°@ 4692' Revised 10/08/13 by iLL ll• PROPOSED McArthur River Field,TBU Well: G-14ARD Hileorp Aleaka,1.11. Completed: Future RKB to TBG Head=42.6' CASING AND TUBING DETAIL Tree connection: MD MD ND SIZE WT GRADE CONN ID TOP BTM. BTM. CMT dl 17-3/4" .312 wall Weld Surf. 522' 520' 700 sx 13-3/8" 61 K-55 Butt 12.515 Surf. *1390'-1460' _ 1361' 2500 sx 9-5/8" 47 N-80 Butt 8.681 Surf. 7970' 6455' 2950 sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 4-1/2" 12.60/13.55 L-80 BTC Ext. 3.598 Surf ±10,020' Polycore *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL NO. Depth ID Item 7715' x42.6' Tubing Hanger 1 ±10,000' Packer w/15'seal assembly PKI- 2 ±10,010' X-Nipple 7970'43 ±10,020' Wireline Re-Entry Guide 1 \'t 4 11,448' CIBP i 2 5 11,451' 4 Otis Model"BWH"Perm Pkr :B 3 r•< 6 11,463' 4 Seal Bore Ext. C1: . S� 7 11,535' Expandable Bridge Plug l` 3 8 12,093 4.00 Otis Model"BWH"Perm Pkr. G-zone 0f. 9 12,098' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin Top of Cement 11,428' - 10 12,103' 2.313 Otis"X"Nipple 4 11 12,110' 2.44 WLEG btm 12,111' 5i � 12 12,866' (2)Junk Retainers . 6 i • Top of Cement 11,518' 7 Perforation Details = B-1 Zone MD(Top) MD(Btm) TVD TVD Amt Last Perf Present Cond. B-4 (Top) (Btm) Date ff.12,093' >< B G-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open G-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open . G-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open 9 10 G-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open 11 G-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open WF-2 G-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open HB-1 11,519' 11,523' 9,314' 9,318' 4' 08/20/13 Isolated - WF-3 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated HB-4 11,820' 11,935' 9,589' 9,695' 115' 08/20/13 Isolated - WF-4 WF-2 12,227' 12,317' 9,965' 10,049' 90' 08/20/13 Isolated WF-5 WF-3 12,332' 12,473' 10,063' 10194' 141' 08/20/13 Isolated TOF 12,625' - WF-4 12,477' .12,524' 10,198' - 10,241' 47' 08/20/13 Isolated WF-6 WF-5 12,564' 12,568' 10,279' 10,282' 4' 08/20/13 Isolated WF T WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated WF-6 12,667' 12,719' 10,374' 12 10,422' 52' 08/20/13 Isolated �4 �tWF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated ETD=12,868' TD=12,939' RKB to MLLW ELEV=103' MAX ANGLE=42.9°0 4692' 0.,...:-.4.././..M.,... II Grayling Platform G-14ARD Current Ililrurp Ala+ku.l,IA. Grayling Platform Tubing hanger,CIW-DCB-ESP, G-14ARD 11 X 4''A IBT lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 4"type H BPV profile,5'''A EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,4 1/16 5M FE X 7"-55A II top ■ ail. Valve,swab,WKM-M, 4 1/16 SM FE,HWO, \!'};, Cross,stdd,4 1/16 5M X T-24 3 1/8 5M X 2 1/16 5M Dig mom 1 Valve,wing,WKM-M, K ,�� Valve,WKM-M,3 1/8 5M FE,w/ I 21/165MFE,HWO, IWO- ! T-24 F. �` 1 1 L MA-16 operator M ilk f Valve,lower master,WKM-M, 4 1/16 5M FE,HWO,T-24 Adapter,CIW-Toadstool,11 5M Stdd X 4 1/16 5M FE,prepped for 5'/4 EN neck,2-'/%npt continuous _ I . control line ports,BIW penetrator 1 s port Tubing head,CIW-DCB, o , 13 5/8 3M X 11 SM o.:, _ lel w/2-2 1/16 5M SSO, isi ,•—• X bottom i Valve,WKM-M,2 1/16 5M FE, ad C i HWO,DD 111 Qty 2 Il I ilii 1111 1 NO Casing head, z Shaffer KD, - 135/83MX ' 13 3/8 SOW,w/2-2" rCd LPO, 1 h [ --15 Si• 2"LP CIW ball valve i" II Grayling Platform G-14ARD Proposed 06/09/2015 Hilrnrp:%Inskn.ILIA: Grayling Platform Tubing hanger,CW-CCL,11 X G-14ARD 4''A BTC lift and 4''A BTC 13 3/8 X 9 5/8 X 4 1/2 susp,w/4"Type H BPV profile,2-3/8 CCL,6'''A extended neck,17-4PH stainless steel BHTA,Bowen,4 1/16 5M X 7"-5 SA Bowen Union Full Stainless Steel III III liff Valve,Swab,WKM-M, O C`(-0r e it 41/16 5M FE,HWO,FF trim � 0 O O' Valve,Wing,WKM-M, 3 1/8 5M FE,w/15"Safeco al iii operator,FF trim N / Full Stainless Steel Valve,Master,WKM-M, 111 dm SII 4 1/16 5M FE,HWO,FF trim AlriF Adapter,Cactus,11 5M stdd X 4 1/16 5M,w/6''A pocket, "' "' 2-''A CCL exits,Full Stainless 1Steel 13� Tubing head,CW,13 5/8 3M 11) II II 111 /by x 115M,w/2-2 1/16 5M �. /� 0 SSO,w/HPS bottom I I �� w/1 2 1/16 5M WKM M I ��-m t4l' avesr— MI Casing head, Shaffer KD, i i 1 I ■ Hi i 135/83MX =_ ' C�' ' 13 3/8 SOW,w/2-2" Ill 1 l I ism. LPO, I I 11 ') • BuP Stack Moncla 02/25/2015 Ifilrnrp Alit+kn.1.1.1. 2015 Workovers BOP Drawing Moncla 4.54' P r"Hydril 111 GK 13 5/8-5000 i!, 0..!. I!. iu 4.67' - CI u � r 2 7/8-5 variables or Cameron dual flex rams Blinds adle r�rr�rr�ri�rnr Kill Side 1� „ Choke side 2.00' 3 1/8 5M w/HCR 3 1/85Mw/HCR 1.00'to 2.00' r!rrtfr III Drill deck 11.00' Riser 13 5/8 5M FE X 13 5/8 5M FE r rtfi rtnrtfi rt r 1111 III ISP rir I I Spacer spool 2.00 13 5/8 5M FE X 13 5/8 5M FE rir rir rir rir iii • Moncla Rig 404 BOP Test Procedure Hileorp Alaska,I ,: Attachment#1 .�, Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure • Moncla Rig 404 BOP Test Procedure HilcorpAlaeka,LLC Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. • Moncla Rig 404 BOP Test Procedure Hilrorp Alaska,LI.c Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Schwartz, Guy L (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Wednesday, June 24, 2015 2:06 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K (DOA);Ted Kramer Subject: RE:G-14ARD Inj Conversion (PTD 191-099) Follow Up Flag: Follow up Flag Status: Flagged Guy, Please see our revisions in red below. I apologize for packer depth,as it should be±10,900'.That is just my mistake. The rest of your concerns regarding the cement job have been discussed with Ted and are addressed below in the revised procedure. Please call me with concerns and questions. I am on my cell—as we are in Kenai. Procedure(REVISED): 1. MIRU Rig 404 over G-14ARD. 2. Notify AOGCC 48 hours before pending BOPE test. 3. Set BPV, ND tree, NU BOPE. 4. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250 psi LOW and 3,500 psi HIGH. 5. Circulate hydrocarbon out of well. 6. POOH laying down completion. 7. PU and RIH with " O assembly to+/-11,400'. POOH and LD same. _ 8. RIH w/ RBP t 10,825' dila S L. Dump 20' of sariu un Cup ui ruN. (0412-S " 9. PU and RIH with perf guns and perforate±10,850-±10,840'. And ±10,350-±10,340. 10. POOH with perf guns. 11. PU and RIH with cement retainer to ±10,830' and set. RU cementers, establish circulation. If circulation is established, go to step 12 and then skip to 14. If no circulation, perform steps 12 and 13, then proceed to step 14. 12. Pump cement through retainer and circulate same up through upper perfs at±10,345'. Sting out of retainer, PU above top shot, clean up cement out of the work string, POOH w/WS. 13. RIH set open ended just below top set of perfs @ ±10,360, Pump a block squeeze (down squeeze) cement thru top perfs. PU above top shot, clean up cement, POOH w/WS, WOC. 14. PU 9-5/8"storm packer, RIH and set same at 200'and hang off string. Pressure test to 2,500 psi and chart. 15. Release from storm packer, POOH. Replace tbg head. Re-rig BOPE. 16. Test all flange breaks to 2500 psi and chart. 17. RIH, engage storm packer, release same, POOH, LD storm packer. 18. PU and RIH with clean out assy,cleanout/mill cement to±10,850'. LD same. 19. Perform test w/WS to pressure test squeeze perf just above retrievable bridge plug. Test to 2500 psi for 15 min and chart. POOH w/WS. 20. RIH with RBP retrieving tool. Clean out sand and retrieve RBP. POOH. 21. RU Eline. RIH with Cement Bond Log tool to verify isolation above Top G-Zone perf @ 11,008'. If circulation squeeze is not successful in step 12, also run a water flow log. RD Eline. 22. PU and RIH with injection string. 23. Set pkr @ +/- 10,900' and pressure test to 2,500 psi and chart for 30 min. 1 24. Conduct work-over MIT-IA 25. Set BPV, NU tree, and test same. 26. Turn well over to production. 27. Schedule initial MIT-IA with AOGCC within 2 weeks of stable injection as per regulations. Thanks- Tridtai. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, June 23, 2015 4:26 PM To: Trudi Hallett Cc: Bettis, Patricia K(DOA) Subject: G-14ARD Inj Conversion (PTD 191-099) Trudi, I have some questions and concerns in your procedure to convert G-14 to water injection. 1) Since there is very little cement in the upper perf area the suicide sqz(100 ft interval from 10950-850') is needed. However,the sqz. will be below the packer so there is no way to tell if and when the sqz holes ever start leaking. 2) The packer is over 1000 ft above the perf interval ...200 ft is required by 20 ACC 25.412(b) unless it is justified. 3) Your procedure never pressure tests the sqz perfs. 4) Are you planning on downsqz of cement to the perf area also? (ie shut in returns during sqz) 5) 500 ft of cement is required above hydrocarbon zones by regulation 20 AAC 25.030(d)(5) Give me a call tomorrow to discuss... Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~//~- ~¢~~ File Number 0f Well History File PAGES TO DELETE RESCAN [] Color items- Pages: n Grayscale, halftones, pictures, graphs, charts- Pages: [3 Poor Quality Original - Pages: Other- Pages: DIGITA~I~ATA * Diskettes, No. ( Other, No/Type OVERSIZED · . · , · · [] ' Lo~s-ofvarious kinds . [] Other Complete COMMENTS: Scanned by: Seve~ ~ann~Nahan Lowell 11 __ i i_ , i , ! , TO RE-SCAN Notes: - Date: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: isl ' STATE OF ALASKA • ALAI OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well 6 i Plug Perforations 151 Perforate El Other 0 Convert to Producer 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❑ Exploratory❑ 191-099 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service El - 6.API Number: Anchorage,AK 99503 50-733-20189-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 , Trading Bay Unit/G-14ARD . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G Oil Pool • 11.Present Well Condition Summary: Total Depth measured 12,939 feet Plugs measured 11,448&11,535 feet true vertical 10,627 feet Junk measured 12,625(fill) feet 1 Effective Depth measured 12,625 feet Packer measured 11,451 &12,093 feet true vertical 10,335 feet true vertical 9,252&9,841 feet Casing Length Size MD ND Burst Collapse Structural Conductor 522' 17-3/4" 522' 521' Surface 1,390' 13-3/8" 1,390' 1,361' 3,090 psi 1,540 psi Intermediate 7,970' 9-5/8" 7,970' 6,467' 6,870 psi 4,760 psi Production 5,224' 7" 12,939' 10,620' 8,160 psi 7,020 psi Liner Perforation depth Measured depth See Schematic feet SC.ANNED 1\10y 1 a 2[11,6 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,870'(MD) 8,749'(ND) BWH Perm Pkr 11,451'(MD)9,252'(ND) Packers and SSSV(type,measured and true vertical depth) BWH Perm Pkr 12,093'(MD)9,841'(ND; SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 490 78 100 Subsequent to operation: 0 0 0 320 3000 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Fl ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil El . Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-409 Contact Ted Kramer Email tkramert hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature t"'C-zi .. ` 7�j� Phone (907)777-8420 Date 10/8/2013 /o. r RBDMS OCT 11 2013 Form 10-404 Revised 10/2012 444172e/,//3 Submit Original Only • • McArthur SCHEMATIC River Field,TBU Well: G-14ARD Hileorp Alaska,1.Lf. Completed: 09/07/13 RKB to TBG Head=42.6' CASING AND TUBING DETAIL Tree connection: MD MD TVD SIZE WT GRADE CONN ID TOP BTM. BTM. CMT dl 17-3/4" 312 wall Weld Surf. 522' 520' 700 sx 13-3/8" 61 K-55 Butt 12.515 Surf. *1390'-1460' 1361' 2500 sx 9-5/8" 47 N-80 Butt 8.681 Surf. 7970' 6455' 2950sx 7" 29 N-80 Butt 6.184 7715' 12,939' 10,575' 800 sx Tubing: 3-1/2" 9.3 L-80 IBT-M 2.992 I 0' 10,780' *Window.Original 13-3/8"shoe @ 4477' JEWELRY DETAIL NO Depth ID Item 7715 42.6' Tubing Hanger 1 10,780' Head Bolt On Discharge 2 10,782' Pump(x 4)DR1750 CR-CT97 STG 400/400 150 CS VTHD 7970'L , 3 10,869' Intake DRS,400/400 RLOY i 1 4 10,871' Protector(x2)Maximus,LSBSB-S/LT,400/456 at 2 5 10,887' Motor 456 10,4106 Maximus ®: 3 - 4 6 10,944' Bottom of ESP-Centralizer IN 5 6 7 11,448' CIBP r/ 8 11,451' 4 Otis Model"BWH"Perma Pkr G-zone 9 11,463' 4 Seal Bore Ext. Top or cement -p� 10 11,535' Expandable Bridge Plug 11,428 #5 7 At"l a:a► zlrr +'�- ''1/ 11 12,093 4.00 Otis Model"BWH"Perma Pkr. 12 12,098' 2.44 Crossover,4-8 UN pin X 2-7/8"BTC pin 8 13 12,103' 2.313 Otis"X"Nipple 9 Top or Cement ' 14 12,110' 2.44 WLEG 11,518' V btm 12,111'aiiiiiiiiiiiiie 10 15 12,866' (2)Junk Retainers • B-1 B-4 12,093' Perforation Details j><,,, 11 TVD TVD Last Perf Zone MD(Top) MD(Btm) (Top) (Btm) Amt Date Present Cond. G-1 11,008 11,054 8,866' 8,905' 46' 09/01/13 Open 12 13 0-2 11,074 11,102 8,922' 8,946' 28' 09/01/13 Open • '14 0-2 11,138 11,147 8,977' 8,985' 9' 09/01/13 Open • WF-2 0-3 11,177 11,191 9,011' 9,023' 14' 09/01/13 Open - 0-4 11,224 11,274 9,051' 9,095' 50' 09/01/13 Open WF-3 G-4 11,298 11,313 9,116' 9,130' 15' 09/01/13 Open HB-1 11,519' 11,523' 9,314' 9,318' 4' 08/20/13 Isolated - WF-4 HB-1 11,576' 11,597' 9,366' 9,385' 21' 08/20/13 Isolated HB-4 11,820' 11,935' 9,589' 9,695' 115' 08/20/13 Isolated WF-5 WF-2 12,227' 12,317' 9,965' 10,049' 90' 08/20/13 Isolated WF-6 WF-3 12,332' 12,473' 10,063' - 10194' 141' 08/20/13 Isolated WF-4 12,477' 12,524' 10,198'• WF-7 10,241' 47' 08/20/13 Isolated WF-5 12,564' 12,568' 10,279' 10,282' 4' 08/20/13 Isolated (MIZ 411111Z \ WF-5 12,564' 12,651' 10,279' 10,359' 87' 08/20/13 Isolated ETD=12,868' TD=12,939' WF-6 12,667' 12,719' 10,374' 10,422' 52' 08/20/13 Isolated RKB to MLLW ELEV=103' WF-7 12,751' 12,787' 10,452' 10,485' 36' 08/20/13 Isolated MAX ANGLE=42.9°c 4692' Revised 10/08/13 byJLL Hilcor p Alaska, LLC • , llikorp Alaz.ka,u.(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 8/14/2013 9/7/2013 Daily Operations: 08/14/13-Wednesday Spot&R/U equipment. Pressure test lubricator 500 psi low/1,200 psi high. RIH with 2.62"gauge ring.to 12,636'slm. Unable to locate 2.313"Otis nipple @ 12,103'. POOH&R/D slick line.Call out EVCAM down hole camera technician& e-line. 08/15/13-Thursday Spot equipment&rig up on well. Pressure test lubricator 500 psi low/1,200 psi high.G-14ARD holding 1400 psi&not bleeding down. R/U grease injector package,strip thru&re-head e-line. R/U on well. P/U downhole EVCAM camera&begin RIH. Depth @ 0600 hrs=11,400'down hole fluid cloudy&unable to obtain visual. Production lining up waterflood to inject intoG-14ARD well @ 2 bpm to clear up down hole fluid. 08/16/13-Friday Increase waterflood to 1.75 bpm&2000 psi. Fluid down hole clear&able to obtain visual with camera. Locate Otis X-Nipple on upper packer @ 11,493'.Tail joint below Otis nipple appeared to be broken off. RIH to 12,060'&locate top of joint. POOH&flag line @ 11,518'(25'below x-nipple)POOH&L/D e-line&EV downhole camera. 08/17/13-Saturday No operations to report. 08/18/13-Sunday No operations to report. 08/19/13-Monday No operations to report. 08/20/13-Tuesday Rig up on well. Pressure test lubricator 500 psi low/1,200 psi high. RIH and set e-line plug at 11,535'. 08/21/13-Wednesday Held safety meeting and JSA review w/production and day crew.Test Lubricator to 1400 psi. Made 4 runs w/2"x 50'dump bailer. Dumped a total of 27,3 gal cement at 11,535' . EST TOC @ 11,518', POOH, RD E-line unit. Notified Mr. Regg w/AOGCC of pending rig move on 8/23/13. 08/22/13-Thursday SITP 850 psi. SICP 500 psi.Start beeding pressure off well. Prepare to move rig in. 08/23/13-Friday Held safety meeting and JSA review w/day crew. Removed goat stand from rig. Removed derrick from rig. Removed draw works from rig. Tried to bleed pressure off.Well was producing appr 500 BPD(water)at 450-500 psi. SWI and pressure climbed to 600 psi w/in a couple hrs. Held safety meeting and JSA review w/night crew. Move and spot carrier on base beam and assemble. Installed Draw works and A-frame. 08/24/13-Saturday; Held safety meeting and JDA review w/day crew. Install and raise derrick.String up blocks.Set pump and start laying pump lines. Modify and set Cat walk. Set stairs and air compressor.Spot Power swivel and Rig in Power choke. 08/25/13-Sunday Held safety meeting and JSA review w/day crew.SITP 700 psi. SICP 400 psi. Bled casing to 0 psi. Filled work w/170 bbls FIW and start weighting fluid up 9.8 PPG. Start unloading boat w/36 pits salt,6 pits KCL and e-line unit. Notified State-24 hr notice for BOP test-Waived by Jim Regg. Scope derrick up. RU e-line unit. Held safety meeting and JSA review.Test lubricator to 1200 psi, test good. RIH w/6'string shot,correlate to pkr at 11,406'WLM,pull up and fired string shot at 11,393'. POOH. RIH w/2.375" chemical cutter,cut tbg at 11,393'. POOH. Gained 500 psi on casing. POOH. RD ELU. Pump 130 bbls 9.9 PPB water at 3 BPM.Start mixing 170 bbls 9.9 wt fluid. Hilcor p Alaska, LLC • , Ilarurp_tiaska. A' Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 8/14/2013 9/7/2013 ly Operations 08/26/13-Monday Held safety meeting and JSA review.Continue to mix 150 bbls brine to 9.9 PPG.SICP 450 psi. Pump 150 bbls 9.9 ppb fluid down tbg.SICP 200 psi. Mix another 160 bbls 9.9 PPG fluid. Pump 160 bbls 9.9 fluid down tbg.SICP 150 psi. Mix and pump another 160 bbls 10 PPG fluid. SICP 110 psi. Mix 160 bbls#10 and pump 100 bbls,for a total of 700 bbls pumped. Install back pressure valve, ND Production tree, NU Riser. 08/27/13-Tuesday Held safety meeting and JSA review w/day crew. NU and Function BOP. Pull back pressure valve and install dbl check. Perform full test on BOP. Tut Blind rams 200 psi low/3 QQQosi,_high. Witness of test waived by Jim Regg,AOGCC. Put thread lock on collar. Screwed back onto X/0, backed off in same spot.Screwed back on to X/0, pulled hanger up far enough to dump fluid out of riser and BOP,pulled up to 116K and decided to set back down. Replaced seal lock,screwed back onto X/O and backed out-recovered X/O.Screwed into and pulled dbl check from hanger. Pulled up to 115K-slacked off to 90K. Pulled up to 125K-slacked off to 80K, repeat. Pulled up to 1•15K and set brake-wait 4 min and tbg came loose String wt 94K. remove tbg hanger, POOH LD and strapping production tbg.At report time 2500'-3.5"-9.3#-Hydril LD. Continue LD prod string. 08/28/13-Wednesday Held safety meeting and JSA review w/day crew, EOT at 8900'+/-. Continue POOH while LD and strapping 3.5"9.3#L-80 Hydril tbg.Continue POOH while LD and strapping 3.5"9.3#L-80 Hydril tbg. Recovered Seal assembly.Change out Power tongs and prepped to RIH. MU BHA which consist of 6" PDC bit,7"Scraper, Bit sub and X/0 while strapping and PU 3.5" PH-6 tbg off racks. At tower change EO Bit at 3500'+/-. 08/29/13-Thursday Held safety meeting and JSA review w/day crew. Bit and scraper at 3500'.Continue RIH while strapping and PU 3.5" PH-6 WS off racks.Tagged Pkr on jt#364 at 11,457'KB tbg measurement. RU and Rev/Cir 2 bottoms up. POOH w/Bit and Scraper while standing back tbg.At end of tower end of bit and scraper at 6500'. 08/30/13-Friday POOH with BHA#1 scraper assembly. Hold JSA for running bridge plug.RU Fline.with 7L22,1Miyens bridge plug.Test lubricator to 2000 psi.Go on radio silence while making up firing head to bridge plug setting tool. RIH to 200'.Continue RIH with bridge plug on E-line with CCL to 11,451'top of packer.Tagged packer,checked casing couplings,correlated packer also to previous run during chemical cut.Set bridge plug at 11,448'PU E-line set back down tagged bridge plug. POOH with E-line. Held safety meeting and JSA review w/night crew. PU/MU cement dump bailer on E-line,(30 gallons cement)50" long carriers.TIH to top of bridge plug at 11,451'. Duma cement. POOH w/bailer.RD ELU.,Wait 3 hrs for cement to set up.Test and chart CIBP-1500 psi for 15 min.Test good. Bled pressure to 0 psi. RIH w/ 3.5" PH-6 WS. At report time EOT @ 7800'+/-. 08/31/13-Saturday Continue TIH to 11,335' @ 08:00.Shut in well,displace wellbore fluids to Trading Bay. Mix 3%KCL/FIW completion fluid 170 bbls at a time and displace hole volume.260 sacks KCL material/650 bbls FIW. POOH with 3 1/2"workstring.Continue POOH standing back WS.SD to build a gasket for face plate on transmission 09/01/13-Sunday Shut down for rig repairs. Make gasket for rig transmission face plate. POOH with open ended workstring. Hold JSA on TCP gun procedures. PU/MU TCP perforating assembly TIH at 15-20 stands per hour per instructions. RU and RIH w/e-line and found marker jt to 19.5'deeper than needed. POOH w/e-line.Confirm w/engineer. Re-space tbg. RIH w/e-line and found marker jt to be on target. POOH and RD e-line.Test TIW valve and flow line to 2500 psi. Break circulation. Drop ball and pump 1 BPM as per instructions. Ball seat-pressured up to 2500 and perforated as per procedure.Tbg went on a light vac.Start POOH w/gun while LD WS. Hilcorp Alaska, LLC • _tIa.kaa,L►c Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-14ARD 50-733-20189-01 191-099 8/14/2013 9/7/2013 Daily Operations: 09/02/13-Monday Continue POOH with TCP guns laying down in singles. 140 joints OOH,shut down for rig repairs. Begin POOH with TCP laying down in singles. Received notification form Lou Grimaldi that the BOPE test witness is waived. All shots fired. RIH w/4-stands tbg out of derrick. POOH LD. Remove Wear Bushing and install test plug.Start BOP test. 09/03/13-Tuesday Testing BOPE. Rigged up to test BOPE. Installed test plug,2 way check failed.Ordered another test plug with 2 way check. Installed test plug good. Begin testing BOPE equipment.Test Rams 250 psi low/3,000 psi high.Witness of test waived by Lou Grimaldi, AOGCC. Begin picking up production string in singles with crane.T-M Production tbg. At report time EOT @ 7700'. Continue RIH while PU Production tbg off racks. Install Wear Bushing.Strap/PU/MU and RIH off racks w/3.5" L-80 IB. 09/04/13-Wednesday Continue TIH with 3-1/2" IBT-M production tubing to 10,700'. POOH with production tubing racking back in derrick in doubles. Hold pre-job safety meeting&JSA review on P/U&TIH w/ESP Assembly.Spot ESP equipment on deck and rigging up to run ESP motor. Install power to conex.Test spooler power pack. P/U ESP assembly with ESP Technitions,making Umbilical cord tie-ins& connecting Flat Pack control lines. 09/05/13/-Thursday PJJ/MU ESP assembly.Currently running in hole.Wear bushing was determined to be in well head.Ordered 12 new canon clamps. POOH with ESP assembly. New canon clamps arrived. Reassemble ESP TIH.Continue in hole to 4,756'. Bottom of ESP at 4,886'. 09/06/13-Friday Continue RIH with ESP assembly. Make 2 splices. Finish running ESP. R/D ESP equipment.Continue RIH with ESP. M/U tie in hanger.Test same. Land hanger. 125 PU-66 slack off weight on production string. N/U tree.Turn over to production for motor start up. 09/07/13/13-Saturday Finish N/U tree.Assist production in motor start up as needed.Wait on all clear from production before moving rig. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,July 03, 2013 8:32 AM To: 'Juanita Lovett' Cc: 'Fisher, Samantha J (DOA)' Subject: RE: Sundry Cancellation for#312-227 - Grayling G-14ARD (PTFYI92-O99 TBU G-14ARD Perf, repair well, pull tubing 191-099 Sundry will be withdrawn... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell SCANNED FEB 2 0 2014 907-793-1226 office From: Juanita Lovett [malltc:jlovet*'uhiic orp.ccn_] Sent: Tuesday,July 02, 2013 4:03 PM To: Schwartz, Guy L(DOA) Subject: Sundry Cancellation for# 312-227 - Grayling G-14ARD Guy, Please withdraw the above mentioned sundry. Thank you, Juanita Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Office: (907) 777-8332 Email: ilovett �hiico p.com 1 Page 1 of 2 • Schwartz, Guy L (DOA) G — / ` b i l R U From: Schwartz, Guy L (DOA) PTD <- OBI 1 Sent: Monday, September 17, 2012 5:03 PM I To: 'Mike Dunn' Subject: RE: Sundry #312 -227 Ok.. setting Thru tubing plug + cement is approved to isolate lower perfs. This email is sufficient notification .. will place it in wellfile. This does not change the scope of work as proposed. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Mike Dunn [mailto:mdunn @hilcorp.com] Sent: Monday, September 17, 2012 4:59 PM To: Schwartz, Guy L (DOA) Subject: RE: Sundry #312 -227 No, it is not in place of, it is in addition to. We will still isolate the existing perfs as described with the CIBP. Mike Dunn ( Senior Engineer Hilcorp Alaska, LLC SCANNED 614AY 0 2 2013 Office: (907) 777 -8382 Mobile: (907) 351 -4191 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, September 17, 2012 4:58 PM To: Mike Dunn Cc: Tom Fouts - (C) Subject: RE: Sundry #312 -227 Mike, I don't see in the procedure anywhere about setting a plug in the lower packer assembly? Is this packer in place of the CIBP to be set at 11570' to isolate the B -1 ./ B-4 perfs as well? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Mike Dunn f mailto:mdunn@ hilcorp.coml Sent: Monday, September 17, 2012 4:17 PM To: Schwartz, Guy L (DOA) Cc: Tom Fouts - (C) Subject: FW: Sundry #312 -227 9/17/2012 Page 2 of 2 Guy, we are unable to set a plug in the lower packer. There is a washed out check valve in there. In its place (so we can temporarily isolate the West Foreland) we want to set a thru- tubing plug (cement basket with cement) above the bottom packer. The attached (approved) procedure does not change. Is there an approval we need for this pre -rig wireline work, or just this as a notification? Thanks Guy Mike Dunn 1 Senior Engineer Hilcorp Alaska, LLC Office: (907) 777 -8382 Mobile: (907) 351 -4191 9/17/2012 • • luicE 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 Mike Dunn " t J t� Sr. Reservoir Engineer ✓ Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99524 Re: McArthur River Field, Hemlock Oil Pool, West Foreland Oil Pool, Middle Kenai G Oil Pool Trading Bay Unit G -14ARD Sundry Number: 312 -227 ��2. L ' ED JUL 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 P/ Foerster Chair, tommsisioner DATED this day of July, 2012. Encl. • , 7 4/. I 07S T/7 / STATE OF ALASKA ` 1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redd! ❑ Perforate New Pod ❑ Repair WeH G - Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing 0 _ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 191 -099 ` 3. Address: Stratigraphic ❑ Service ❑ • 6. API Number. 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50- 733 - 20189-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. RECEIVED property line where ownership or landownership cianges: V� Spacing Exception Required? Yes ❑ No El Trading Bay Unit G -14ARD ' JUN 1R 2Q12. 9. Property Designation (Lease Number): 10. Field/Pool(s): i, / � u, - GC ADL0018730 McArthur River Field / Hemlock Oil, West Foreland Oil Pools 11. PRESENT WELL CONDITION SUMMARY • L '41 'Z- Total Depth MD (ft): Total Depth TVD (ft): - Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,939 10,627 12,625 10,335 N/A 12,625' Casing Length Size MD TVD Burst Collapse Structural Conductor 522' 17 -3/4" 522' 521' Surface 1,390' 13 -3/8" 1,390' 1,361' 3,090 psi 1,540 psi Intermediate 7,970' 9 -5/8" 7,970' 6,467' 6,870 psi 4,760 psi Production 5,224' 7" 12,939' 10,620' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment #1 See Attachment #1 3 -1/2" & 2 -7/8" 9.3# & 6.4# N -80 11,526' & 12,122' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis Model BVVH Perm. Packer & N/A Packer: 11,451' (MD); 9,252' (TVD); No SSSV 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/27/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ G 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 Mike nn Title Sr. Reservoir Engineer Signatur j /,�r Phone (907) 777 -8382 Date 6/18/2012 „ > " „7 COMMISSION USE ONLY �] Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 Z' 2.2 ' Xf Plug Integrity ❑ BOP Test X n V F, Mechanical Integrity Test Location Clearance ❑ Other: I e . (� P 1 3000 ps i iV G. hit/ i h 5p /c r- ct .5 % h di 'Zia t Subsequent Form Required: / 1)-40 7 _ • APPROVED BY Approved by: fr . - I„.__ COMMISSIONER THE COMMISSION Date: 7 - 3 - Ra®ins 7 t. 0 L r ORIGINAL I N Z� . l Form 10 -403 Revised 1/2010 £ / C, / A L 4 Submit in Duplicate U • Hilcorp Alaska, LLC Attachment #1 G -14ARD Present Well Condition Summary - Perforation Data June 18, 2012 Zone MD TVD HB -1 11,519' - 11,523' 9,314' - 9,318' HB -1 11,576' - 11,597' 9,366' - 9,385' HB -4 11,820' - 11,935' 9,589' - 9,695' WF -2 12,227' - 12,317' 9,965' - 10,049' WF -3 12,332' - 12,473' 10,063' - 10,194 WF -4 12,477' - 12,524' 10,198' - 10,241' WF -5 12,564' - 12,568' 10,279' - 10,282' WF -5 12,564' - 12,651' 10,279' - 10,359' WF -6 12,667' - 12,719' 10,374' - 10,422' WF -7 12,751' - 12,787' 10,452' - 10,485' • • Well Work Prognosis Well: G -14ARD Hilcoep Alaska, Lac Date: 06/18/2012 Well Name: G -14ARD API Number: 50- 733 - 20189 -01 Current Status: Active Injector: H Leg: Leg #4 (SW corner) Estimated Start Date: June 27, 2012 Rig: Williams Rig 404 Reg. Approval Req'd? 403 _ Date 403 submitted: June 18, 2012 Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 191 -099 First Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) Second Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) AFE Number: 1221770 Budgeted Cost: Pressures: The well is currently injecting. When the well is shut -in periodically, pressure bleeds down to 0 psi within 24 hours and fluid level falls below surface. The estimated bottomhole pressures are based on previous static surveys, fluid level shots, and observations of surrounding wells. Current BHP: — 4000 psi @ 9480' TvD /11700' MD .42 psi /ft, (8.1 ppg) at mid pert of Hemlock Max. Expected BHP: — 3500 psi @ 9200' TVD .38 psi /ft G -zone is more de- pressured Max. Possible SP: 0 psi Using 0.435psi /ft SW gradient to surface Brief Well Summary G -14ARD is an active Hemlock injector, currently injecting approximately 5000 bwpd. The West Foreland is open below a check valve in the nipple of the lower packer assembly, but fill is preventing water from entering the West Foreland. The bottomhole location of this well is no longer well suited for a Hemlock injector, with G- 12RD3 being converted to injection at a downdip location on the eastern flank. The G -14ARD location is however in a good position to support G -zone offtake in a number of surrounding wells including M -31RD, G- 08RD, and G -21RD. It would also support G -zone offtake from any new wells drilled or sidetracked north of this area. The plan is to temporarily abandon the West Foreland and Hemlock perforations with a drillable bridgeplug. The G -zone will then be perforated and the well placed back on injection as a G -zone only injector. The well is expected to take between 2000 and 3000 bwpd. 11 Notes Regarding Wellbore Condition • A check valve is stuck in the X nipple at 12103' • The West Foreland is covered with fill. Little if any water is going into the West Foreland due to tubing restrictions and fill. • Tubing integrity and casing integrity are intact. Recent pressures are 2900 psi tubing pressure (while injecting) and 0 psi casing pressure. Procedure: 1. Skid Williams Rig 404 over the G -14ARD well slot. Raise mast. Prepare for wellwork operations. 2. Plumb FIW lines to circulate down the annulus and up the tubing, when the tubing is pulled out of the packer. 3. Notify AOGCC of pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3000 psi HIGH. 11 • • Well Work Prognosis Well: G -14ARD Hilrorp Alaska, LLC Date: 06/18/2012 4. PU landing joint and make -up to tubing hanger. Tug on tubing to pull seal assembly out of packer. If unsuccessful, RU E -line and jet cut tubing just above packer. 5. Pull hanger up to floor height. Install stripper rubber. Circulate at least 2 bottoms up to adequately clean hole. 6. POOH with completion tubing. LD same, check for NORM. 7. PU packer milling assembly. Mill packer using stripper rubber and reverse circulation method. If losses are low, continue with plan. If losses are too high to circulate fill and /or metal shavings, pump polymer /salt pills as necessary to reduce fluid losses. Circulate hole clean of metal shavings. Use magnets at surface to catch metallic debris. Pluck packer out of hole. 8. After milling and retrieving packer, PU a full gauge mill with open jets and a casing scraper and scrape the casing down to 11570', just above the top perf of Hemlock. POOH. 9. MU drillable CIBP and RIH and set same at 11570'. Test casing to 2500 psi for 30 minutes. If the pressure does not decline more than 200 psi in 30 minutes; oceed onward. POOH for f r 200' to set storm packer. 10. PU 9 -5/8" storm packer and RIH to 100' and set same. Test packer. Release from storm packer, POOH. 11. ND BOP and install a new tubinghead. NU BOP, test BOPs. RIH, pull storm packer, POOH with CIBP setting tool. LD same. 12. MU Schlumberger TCP guns on workstring and RIH. RIH with E -line or memory GR tool on slickline. Position guns to perforate as follows, using the Hilcorp Digital Database Log (DDL) as the reference log. Proposed Perforations Zone Interval Feet G - 1 11,008' — 11,054' 46 G - 2 11,074' — 11,102" 28 G -3 11,138'- 11,147' 9 G -4 11,177' - 11,191" 14 G - 5 11,224' — 11,274' 50 G - 1 11,298'- 11,313' 15 G - 2 11,344' — 11,363' 19 G - 3 11,367' — 11,406' 39 G - 4 11,427' — 11,442' 15 G - 5 11,481' — 11,499' 18 Total: 253 13. When the guns detonate, the G -zone will be overbalanced with a full column of FIW in the well. The well is expected to drink fluid until the fluid level finds the balance point between reservoir pressure and the column of fluid in the well. There is no need to circulate the hole, following the perforation event. After detonation, monitor well by shooting a fluid level. It is OK to fill the hole periodically. Do not pump polymer and /or salt to slow the fluid loss. Once the well is determined to be static, POOH. 14. POOH with guns. LD same. Confirm that all charges fired. 15. PU 4 -1/2" packer and 4 -1/2" tubing. RIH. Space out and set packer at 10,850'. Land the tubing hanger, and pressure up backside to confirm packer is set. Hold 2500 psi for 30 minutes for the casing MIT test. If the pressure does not decline more than 250 psi in 30 minutes, the well has passed the Workover 11 • • Well Work Prognosis Well: G -14ARD }Iilcoep Alaska, LLC Date: 06 /18/2012 MIT. Provide Larry Greenstein with the pressure test results and the completed 10 -426 form for the MIT. 16. Set BPV. ND BOPE and NU tree. Test tree. 17. Turn well over to Production Supervision (TOPS) for start of injection. 18. Within 2 weeks of stable injection, schedule an Initial MIT with AOGCC. Provide the AOGCC 24 hour notice prior to the MIT test. All pressure test results and completed 10 -426 are to be provided to Larry Greenstein immediately following the test. I�� • • • Well Work Prognosis Well: G -14ARD Hilcorp Alaska, LLC Date: 06 /18/2012 As -built (Old) Wellbore Schematic CASIdGAND TUBDIGDETAIL MD MB TVD R KB to TB G Head = 42.6' SEE Wl' GRADE CONN m TOP BTM. BTM. _ CMT T rep connection: 17.304" .312 wall Will S. 522' 520' 700 S 13348" 61 K55 Bet 12315 S. 0 1390' - 1460' 1361' 2500 sr A 45/8" 47 17-00 Bet 8681 S. 7970' 6155' 1950 ix T' 29 N80 BM 6.184 7715' 12939' 10,75' 800 sc Wing. 31/2" 93 N-80 SL. 2992 0' 11,526' 17/8" 6.4 14-80 SL. 2.441 12099' 12,112' 0 Wallow. Ctg¢el 13348" doe 1§ 4477' JEWELRY DETAIL NO. _ Dept _ ID Derr 42 6' 3.148" C1W Tubing Hangar 7715' ® S 1 11 52' 299 Stare. Mot Locator Seal Assy. w/ 10 27 ' of seals. 2 1 1 151' 4 A 0 Otis Mode 1 `B WH " Parnal Air. t9t0'G 3 11;163' 400 Seal Bore EX. 4 11,493' 2.75 Olds `5C'Profile Nipple 1 5 11 ,525' 299 WLEG Lain 11 ,526' 11,451' 2 6 12093 400 QtMode 1`BWH "Peruaplr. e 3 7 12 488' 2.44 Crossover ,4-8 UN pin X2.7/8 "BTCpin 4 ■ e 8 12,103' 2.313 Otis ` 3C'Nipple w.thli ofuriciown size, 5 t 54z-, 4/11/93 II Pa.^S 9 12,1 10' 2.44 WLEG btu 12 ,1 11' z B -1 FISH 2haiedRetatas 508/92 ® 12,866' 2 Jutted Manors 513WN2 @ 12866' 1'. B -4 STIMULATIONS 55 bbls 7.5% HCL, 78 bbis 6.5% X 1.596 mud acid. 60492 Wt -5, 6 & 7 12998' . ' 9 bbls 7.596 HCL. 27 bbis 6.596 X 1.5' mud acid. 6/92 ID -1 • OILIER WORK 7 J' Tagged br611 to /2.18750R 65/95 ® 12102' ++ 8 r a 9 c. \\ Tubing is coated with TK-99 thermoplastic nylon resin. 4 -- :-y '.''` - W F •2 II I W F -3 PERFORATION DATA �EM a. !Mil Perf Present Ccndtion WF•4 NM � M X00� 'F�'ca '' s WF -5 I® ®®' O_______ i. n ' byection. L'L`BMUtkil�1lMR. 'MI rIMIIIIIIIIIIIL YELL M.24 ion- _ W F -g GAM MMIRME��1 • fY� a • , , -. . NEEEINNEtill ®�C'r Vii• nbrl ' i 111E -7 Gal . tt♦=BLUER WASINDH:7rTY� u, - • ... • 1inkli=F1111111Lii1O�cAIIIIG' n br . - - ion. / ETD = 12,868' TO = 12,939' RKBto MLLW ELEV= 103' MAX AN GL E = 42.9 150 4692' Revised 04/30/12 byMDD • Well Work o II Well: Pr G -14ARD gnosis HilcorP Alaska, LLC Date: 06/18/2012 Proposed (New) Wellbore Schematic Prep osed Weithore Schematic COMMAND TIffi4GDBTAH MB MD TVD R KB to T BD Head = 42.6' SZE WI GRADE CONN ID TOT DTM. DTM. CMT Tree connection: 17 -3A" .312 14411 Weld She. 522' 520' 700 et 133E" 61 K55 Bun 12315 S. 0 1390' - 1460' 1361' 2500 sc 4 N. 9•5J8" 47 } 80 Bun. 8681 Suf. 1970' 6455' 2950 T' 29 NS0 Bite 6.184 7715' 12939' 10375' Ma Mew 4.1x2" 116 1,80 BTC Mod 3956 0' +f 10850' v Widow. �.1 13-3+8" sive ® 4477' 7715' E JEWELRY DETAIL T9T0'/1 \ , W. Dunk _ 42 ULC01 1 1 +J -10 50 3.875 Baker "S-3" hydraulic set Packer 10s°0 C 2 2 +1- 10855' 4.940 Mill out Extension I • 3 3 +/- 10885' 3.813 "'AN" nipple ' ` t 4 +1- 10915' 3.960 Vvireline Entry Guide f 0-zone 1. J r1 1��1 ii 57 r- �'�— t t a 3 r B -1 PROPOSED PERFORATION DMA v one Top Btm Amt Accvn. Date Present Candtion SPF last COr. G -1 ±11,008 ±11,054 46' 5 Future TCP pert B - G -2 ±11,074 ±11,102 28' 5 Future TCP perf 121398* G-2 ±11,138 ±11,147 9' 6 Future TCP pert r7 r G-3 ±11,177 ±11,191 14' 6 Future TCP perf G-4 ±11,224 ±11,274 50' 6 Future TCP pert G-4 ±11,298 ±11,313 15' 6 Future TCP pert A G-5 ±11,344 ±11,363 19' 6 Future TCP pert G-5 ±11,367 ±11,406 39' 6 Future TCP perf WF - 2 G-5 ±11,427 ±11,442 15' 6 Future TCP pert = W F.3 G-6 ±11.481 ±11,499 18' 6 Future TCP pert z W F -4 Z. W F -5 s WF -6 . = W F -7 ETD = 12,868' TO = 12,939' RKBto MLLW ELEV =103' MAX ANGLE = 42.9 64692' '.17.2012.doc Revised 06 /1711 byMDD • • Well Work Prognosis Well: G -14ARD Hikorp Alaska, Lac Date: 06/18/2012 Williams Workover Rig Grayling Platform BOP 2012 III Wdth 4.18' 3.74' Weight 13,1008 1311} r /1 111 f1 I$l Shaffer LWS - Total BOP height above - -- drill deck 135 /B 5M LWS 135A BM _ 9.48' min - dimensions 11.48' max Length 7.73' — ® : 3.00' Width across body 2.72' - Width across flanged V outlets 4.00' Weight9500Ibs — a. 9.00 111111 111 111 . Mud Cross ll � I { irii r 1.74' r 2850150 w /valves _ j `f iii III III III • Riser abovedri8 deck This number will vary from well to well 1.00'to3.00' D0Il Deck 13 515 5M Riser 8500150 1500 I I 111 �. Spacer Spool 135/85M X 135/85M 1.95' 180015s 1 111 Crossover Spool 135/85MX 115M 1800Ibs 2.83' 111 111 Top of Wellhead • • Ferguson, Victoria L (DOA) From: Larry Greenstein [Ireenstein @hilcorp.com] Sent: Thursday, June 28, 2012 4:29 PM To: Ferguson, Victoria L (DOA) Subject: Area of Review for G -14ARD Attachments: G 14ARD AOR MAP.pdf; G -08 (PTD168- 010).pdf Good Afternoon, Victoria. Thanks for the good news on the commingled waterflood fluids for TBU, it sure made Mike happy when I told him about it this AM. Here is the info for the AOR for the G -14ARD well. The'/ mile radius area shows only one well penetrating the G -Zone close by, the G -08 (P &A'd) well. Attached is a pdf of the AOR, with all nearby wellbores, and a pdf of the abandonment info for the G -08 well (now redrilled as G- 08RD). There appears to be a lot of cement across the G -Zone and Hemlock in the old abandoned G -08 well which should provide plenty of isolation for the new perfs proposed for the G -14ARD well. Let me know if you need anything else. Thank you. Larry it 1 - 0 $ G -04RD; ,3,• Z sa M -29 ` IIIG -20 i / 2 308 / 1/ i G -33 / -G -31 r N.� °z G-1 ORD A h� ^ 1 020 "z js 7 e^ u 4 4 / 9 ? S • /S ys G -02 343 ..f " " ' v' G -07 G -06RD G 34RD A497 2 • •So ^M -14 G-21RD • • . a — G-06 0 634 � ry A 0 ' •• . 3 • B 3 • •`?z3z �6 •0 5° • P r oposed • • • • • 90 95 00 9 •» 299 Perforation • • • IV 3.266 ,�. interval • G -16 >84 -,c JSr< G -24 • eM1 G -21. • G40 ri' p • • 1y / . � • • - G -30 • ,.4. 729 al •' � y f • Q •4,691 10093 03 ^ I O� • a9, 2os 457 9% 347 • ;9 , G- 14ARQ if HILCORP ALASKA, LLC ti • a> 9.135 • _,, : MCARTHUR RIVER FIELD MZO ton3 • a' B � " 1 G -03RD2 \ • MEe. MAP .� N � .. •'a \ •••• • 41�ARO40R • G -11 G 02RD G -08R D ••• • G -03PB2 o 46 • -9,5 • •" • . 34 .... , 0 G -08' FEET G -031 �� M- 31A_prop • )112-28 R POSTED WELL DATA 1 •: •g 090 •.9 or 6M o G Zone • t Label ° " G -26, D -30 R 529 a Hemlock top TBU GZN -CUM OIUOPRI(MBO) . '� 225 3 •644 G -26 RD 448 G -,23RD • q }` GZt�- MIDDLE K�NAIG Teo GZN - CUn IJW(W) TBU _TO_DATE t D -30RD • • s 9N159^5° WELL SYMBOLS _D - 07RD 666 " • y0 a G-23 t • aI Well Gas Well tasi D -07 G-36 Y Dry Hole l 3 D- 07RD2� 720 IJ�f Injem °n wen OD-01 / D -30RD • %b 4 B �j ' , yam" !- 14 94H db O Wed Type Not Listed R �a �, ,,y Plugg & Abandoned 011W 64 c� •6 247 # Plugged & Abandoned Gas Va ?151 • 1!� B 5roi Abandoned Well ...i. Converted Water -Input Wel . 14 Abandoned Water Injector 312 ' L tia Shu<W OBI Wed • 3 " D -29 Vl •,' 0 Lease gas well G -36DPN r'' -12RD2 x Shut -in Water Injector June 27 2012 PFTRA fi17117115 11' AM • • Forn.No. P -4 - SUBMIT IN DUPLICATE f . REV. 3 -1 -70 (` r STA "L OF ALASKA I DO, 11 OIL AND GAS CONSERVATION COMMITTEE 5. API 8 c IFO� 500 - 1133 -2033-20 085 c Ear / MONTHLY REPORT OF DRILLING 6. LEASE DESIGNATION AND S E R I A L EP4G I' i 'I ---,- 2 EN, ADL -18730 i ! , AND WORKOVER OPERATIONS 1. 7. IF INDIAN-ALOTTEE OR TRIBE NAME - ' ` OIL ® GAS ri -. WELL WELL OTHER 31, 2. NAME OF OPERATOR & UNIT FARM OR LEASE NAME 1 "- ' _ ' Union Oil Company of California Trading Bay Unit - 1 2 ,- L 3 ADDRESS OF OPERATOR 9. WELL NO. I 3 G ^!. `( P. 0. Box 6247, Anchorage, Alaska 99502 TBUS G -8 (32 -33) j REV I 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT I DRAFT (— C onductor #45, Leg 2: 1874'N & 1382'W McArthur River Fi to k from the SE corner. Section 29: T9N, 11. SEC. T. R. M. (BOTTOM HOLE CONFER R13W, S.M. OBJECTIVE) FILE Section 33: T9N, R'T3i7 3. i 12. PERMIT NO. 68 -10 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE - TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 1 7/2/78 12,175'TD Commenced operations on TBUS G -8RD @00:01 hrs 7/2/78. 7910'ETD Skidded rig from TBUS G -12RD to TBUS G -8RD and RU. Loaded (cmt ret) tbg w/ FIW. Pulled ball valve from 307'. Opened "XA" 13 3/8" csg sleeve @10,731' w/ W.L. Stuck W.L. tool @9000' while @3103' 9 5/8" pulling out. Worked free. Pulled W.L. tools out of hole. csg @10,965' Spotted 50 bbls Safe -Seal, Dril -S pill across perfs. (381434) Removed X -mas tree. Installed 12" 3000 psi BOPE & tested to UOCO specs. Pulled tbg out of perm pkr @10,762'. Closed hydril & pumped 500 bbls of oil cut water out of annulus. 2 7/3/78 12,175'TD Pooh laying down 4 1/2" tbg & prod equip. RIH w/ 8 1/2" 7910'ETD bit & 9 5/8" csg scraper. CO to pkr @10,762',- Pooh. RIH (cmt ret) and set cmt ret @10,684' on 5" DP. 13 3/8" csg @3103' 9 5/8" csg @10,965' (381434) 3 7/4/78 12,175'TD Squeezed to abandon Hemlock perfs w/ 350 sx Cl "G" w/ .75% 7910'ETD 0 -31, .5% D -19 & .1% D -6 mixed @118 PCF. Broke down @3000 t Spi (cmt ret) psi. Final press of 4800 psi. Pooh. Ran gyro 10,650' to 7 13 3/8" csg surface. RIH w/ junk basket & gauge ring to 8500'. Ran @3103' 9 5/8" CCL from 8500' - 6500'. Perf 4 holes @7928' to 7930'. csg @10,965' Set cmt ret on W.L. @7910'. R E C E I V E D (381434) AU Q 1 6 1978 D vision of 0ii a d Gav Gan■ervation Anchor 14. 1 hereby fy,that the forego ng is / e and rreer ' SIGNEr• t .t __� .' Dist. 2i#_§. DATE 8/15/78 ire R. Callender �- NOT - Report on this form is required for eic (ender month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. • • l l 4 7/5/78 12,175'TD Squeezed perfs from 7928' to 7390' w/ 200 sx Cl "G" w/ 7910'ETD .75% D -31 and .3% D -19 mixed @118 /PCF. Broke down 010 CFM cmt ret & 3000 ppi. Final press of 4600 psi. CIP @05:35 hrs 13 3/8" csg 7/5/78. Rev out. Pooh. Perf 4 - 1/2" holes from 7830' 3103' 9 5/8" to 7831'. RIH & set sqz tool @7756'. Squeezed perfs csg 10,965' from 7830' to 7831' w/ 195 sx C1 "G" w/ .75% 0 -31 & .3% D -19. Broke down @3300 psi & 10 CFM. Final press of 4100 psi. CIP @16:20 hrs 7/5/78. Pooh. 5 7/6/78 12,175'TD RIH w/ bit & CO cmt from 7810' to 7835' & stringers to 7910'ETD 7910'. Conditioned mud 07910' for window. Pooh. RIH cmt ret w/ Servco section mill #1. Milled window in 9 5/8" 13 3/8" csg csg 7820' to 7831'. (11' in 5 1/2 hrs). Pooh. RIH 3103' 9 5/8" w/ mill #2. Milled window in 9 5/8" from 7831' to 7835'. csg 10,965' 6 7/7/78 7769'ETD Milled window in 9 5/8" csg from 7835'- 7859'. cmt plug 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' 7 7/8/78 7769'ETD Drld 7859' to 7885'. (Mill #2 14'' in 8 1/2 hrs, Mill cmt plug #3 10' in 5 hrs, Mill #4 9' in 5 hrs, Mill #5 11' in 4 13 3/8" csg hrs, Mill #6 10' in 3 hrs). Total window cut 65' from 3103' 9 5/8" 7820' to 7885'. Pooh & LD Servco tools. window 7820'- 7884' 8 7/9/78 7769'ETD RIH & equalized 100 sx of Cl "G" cmt w/ .75 D -31 & 10% cmt plug sand thru open ended DP hung @7910'. Pumped 200 CF water 13 3/8" csg ahead, 70 CF behind & displaced w/ 690 CF of mud. CIP 3103' 9 5/8" @02:10 hrs 7/9/78. Rotated "DCB" spool, installed & window 7820'- tested new "R" seal. Built up new mud. Tested BOPE as 7885' per UOCO specs. RIH & tagged cmt 07722'. CO cmt to 7769'. 9 7/10/78 7871'TD WOC until 10:00 hrs 7/10/78. Polished off plug to 7826'. 45' Footage Pooh. RIH w/ BHA #1 & Bit #1 for DD run #1. Oriented 13 3/8" csg tool 90 right of high side w/ eye tool. DD from 7826'- 3103' 9 5/8" 7871'. window 7820'- 7885' 10 7/11/78 8195'TD DD from 7871' to 7896'. Pooh. RIN w/ BHA #2 & Bit #3. 324' Footage Directionally drld from 7896'- 8195'. 13 3/8" csg 3103' 9 5/8" window 7820'- 7885' • ' • • S/9/78 � ', • ( Bus G -8 RD Mc ARTHUR RIVER FIELD GRAYLING PLATFORI►I CooK INLET, M ASI( A Presen+ Proposed L I zli [LH HL Z iI 35r A j iv a 390' 1346" his X55 63103' caitt( whe300 sx 3 !x" dual 4, 5 sfriaya w /eLft1 4t&" tb5 e °.+ :+ 8300' Otis triple hyd pkr 8380' #np 1" liner i 8670'-8730' .seei.ion mi/kd is 9i Arc i se Per maw, 8700' ij • `, �� :may` i Cm f ref Q 87 ,, 7 ��,, 0 ,,, ' ,, :i Kr. EgB s∎.1 Rt r}' a a for sea�ibr+►li�C% _ CMt res a /0759 -•Ie ► =� et tb aIfidp*ubt lntr /a a ti *. �, 10762' 014 _p pkr �� ` 1 1 0 �� , 11++ l ip f / I082e' tap �" /I� " -.- _V •"cp. ` "�►'' stone pert'S / ..9 "4a5,411t�'BQaP O As r`., b.. ; ("_ 160') b2 /0945 erred is 2 siiges 43.3003x 4 / 1 =1095' MO uy fly 6rkdor ` r ; ` I ; ,AN- r ■_ ■T. 0870' 0.1-4 perm pkr Hemlock perPs staid for abag) don meat / `. I I18O- /112 / 0' ` � ll pb opsti i p 110W- II790' t- � ME 11850' e,nt at ►='ii ►' -∎ E ae/o -u940' �a � = Hemlock per4 C is0614 / ��= ` 7 "Z9a nso mee rte 11960' - 17.050' TD 11690' - 8.480 carf3 47251 i &inZ' ETD CPC) TD 12175' �% %`i" Z90 N-80 liar 12170 " ell. cmf'd u ,/R40 sx Page 1 of 1 • i Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Wednesday, November 17, 2010 11:08 AM To: McMains, Stephen E (DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: TBU G -30 (169 -047) Thanks Steve, it will be right now. Larry From: McMains, Stephen E (DOA) [ mailto :steve.mcmains @alaska.gov] Sent: Wednesday, November 17, 2010 8:58 AM To: Greenstein, Larry P Subject: RE: TBU G -30 (169 -047) The change has been made, injection volumes deleted on G -30 and added to G14A. From: Greenstein, Larry P [ mailto :Greensteinlp @chevron.com] Sent: Wednesday, November 17, 2010 7:58 AM RaftV NOV 1 8 NIL To: Maunder, Thomas E (DOA) Cc: McMains, Stephen E (DOA); Lambert, Steve A Subject: RE: TBU G -30 (169 -047) Tom, Looks like the AOGCC database got messed up. It had to be something simple and it turns out it is. No idea how this happened, but here is what is wrong. !C , _ ®� Atta t ng hard copy scans of the 2005 months in question. The only well that is 50/50 Hemlock/West orelan 's -14 The volumes attributed to G -30 rightfully belong to G- 14ARD. The hard copy scans attached show C that we reported it that way, but somehow the AOGCC database got the volumes assigned to G -30 (a shut -in producer). Our OFM database has the volumes correctly entered, but the Chevron WPH database also has them incorrect. We'll be correcting that database also. Hope this helps. If you concur, have McMains give me a call to rectify. Larry From: Maunder, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Tuesday, November 16, 2010 10 :12 AM To: Greenstein, Larry P Subject: TBU G -30 (169 -047) Larry, I happened to look at this well file while looking at production wells completed in multiple zones. This is probably not critical since the well, according to our record, has not produced since June, 2002. In the "production record" we have, it shows that — 500 mbbls of water was injected into the well in the 3 months September — November, 2005. Do your records show this? The record shows a 50 — 50 split between the Hemlock and W. Foreland pools. Any light you or your colleagues can shed on this will be appreciated. Tom Maunder, PE AOGCC 11/17/2010 ~ MEMORANDUM To: Jim Regg ' l'~'"( ~l~(~~( P.I. Supervisor FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 27, 2009 SUBJECT: Mechanical lntegrity Tests iJrIION OIL CO OF CALIFORNIA G-14ARD TRADING BAY UNIT G-14ARD Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: TRADING BAY iJNIT G-14ARD API Well Number: 50-733-20189-01-00 Inspector Name: Bob Noble Insp Num: mitRCN090827114618 Permit Number: 191-099-0 - Inspection Date: 8~26/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ G-14ARD IType Inj. ~'~' TVD 92sz -~ IA o 2aoo ~ 2aoo zaoo P.T.D 1910990 TypeTest SPT Test psi 2400 ~ QA 240 240 240 240 Interval 4YRTST P~ P ~ Tubing 2800 2800 2800 2800 Notes: N1~J~„ ~"eS~-PrPSSv~-~ ~~o~ Z3i 3P5; ~ y~ r~ 't ~"F ~, ..~~.,,~~~M lt3!'+~ssd`+1.° ..~ - .... ..,-}~1< Thursday, August 27, 2009 Page 1 of 1 Grayling G-14 MIT • • Page 1 of 3 i~ ~ - Regg, James B (DOA) From: Lambert, Steve A (salambert@chevron.com] ,',~ ~~IZ ~L'~ Sent: Friday, June 12, 2009 2:09 PM C( ~~-~~ To: Regg, James B (DOA); Owen, Claude D; Greenstein, Larry P Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT Attachments: A-25RD Pressure Data 6-11.xlsx ~ Jim we will add G-14ARD to the TIO report and leave the well shut-in until the waterflood is restarted and the t/ well has passed the MIT. We have a similar situation with well A-25RD on the Monopod. This well was due for an MIT on May 5, 2009 but ,~ the waterflood has been on a severely restricted status since April 13. The well was shut-in at that time and has not been returned to injection. We will not return the well to injection until the well has passed the MIT. The injection plot for A-25RD is attached. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Ex loration and Production ; y -~ ~ ~~, ~ ~ .v 909 West 9th Avenue, Anchorage Alaska 99501 Tel 907 263 7658 salambert@chevron.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, June 12, 2009 9:30 AM To: Lambert, Steve A; Owen, Claude D; Greenstein, Larry P Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT Thank you for the explanation -sounds like the delay in performing MIT was unavoidable. My preference would be to have an inspector witness the MIT while the well is injecting (with well thermally stable). Since waterflood is SI and in lieu of doing an MIT right now, I suggest adding (until well is put back on injection) G-14ARD to the "CI Master Well List TIO Report" that Larry Greenstein provides to us monthly. What do you think? Jim Regg ~~~. AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Lambert, Steve A [mailto:salambert@chevron.com] Sent: Thursday, June 11, 2009 5:55 PM To: Owen, Claude D; Greenstein, Larry P; Regg, James B (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W; Cole, David A Subject: RE: Grayling G-14 MIT 6/12/2009 Grayling G-14 MIT ~ • Page 2 of 3 Jim attached is the injection plot for well G-14ARD. Yau are correct the MIT was due on April 6. As you can see from the plot, the well was shut-in for the period March 01, 2009 to April 18, 2009 due to a failure in the injection flowline. The flowline was repaired and the well was returned to injection on April 19 and remained on injection until April 27 when most of the waterflood was shut-in. As you stated there were issues with the volcano which affected operations during this period of time. The platform oil production was shut-in on April 5 and remains shut-in. Steve Lambert Senior Advising Petroleum Engineer Chevron North America Exploration and Production 909 West 9th Avenue, Anchorage Alaska 99501 Tel 907 263 7658 salambert@chevron.com From: Owen, Claude D Sent: Thursday, June 11, 2009 12:03 PM To: Greenstein, Larry P; Martin, J. Hal; Lambert, Steve A Subject: FW: Grayling G-14 MIT From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, June 11, 2009 10:23 AM To: Owen, Claude D Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W Subject: RE: Grayling G-14 MIT Our records indicate the MIT for TBU G-14ARD (PTD 1910990) is on a 4-year test cycle and was due April 6 (last test done 4/6/2005). Why the delay in testing? I understand there may be some issues with shutdowns caused by Redoubt volcano - is the well currently injecting? Looks like G-14ARD did inject 28 days in February, none in March, and 9 days in April (don't have May data in our system yet). Please have someone send us a plot of pressure data (tubing, inner annulus, outer annulus) for past 90 days for review. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Owen, Claude D [mailto:owenc@chevron.com] Sent: Wednesday, June 10, 2009 3:54 PM To: Regg, James B (DOA) Cc: Myers, Chris S; Johnson, Wayne E; Bartolowits, Paul D; Liebenthal, John W Subject: Grayling G-14 MIT Mr. Regg, Chevron Grayling Platform needs to perform a state witnessed mechanical integrity test on well G-14 A RD. At 6/ 12/2009 Grayling G-14 MIT ~ • Page 3 of 3 your convenience, please have one of your representatives contact the facility to schedule a date and time for the test. Thank you, Dave Owen Lead Operator Chevron Grayling Platform 907-776-6630 6/12/2009 l~c~ ~'- 14r~ ~~'~ g-14ard Pressure Observations 3000 2500 2000 w N d d 1500 1000 500 -Hours ~ - V Tubing --- - _ _. -- - _ ~9 5/8" X13 3/8" 2/28-3/01- Well was shut in due to flow line repair X20" - Rate 4/27 - Waterflood shut-in 10/29/08 12/18/08 02/06/09 Time 03/28/09 05/17/09 6000 5000 4000 «: I 3000 ~ 2000 1000 ~~ 0 07/06/09 `~~~F~~~~a~ STATE OF ALASKA ALA~OILAND GAS CONSERVATION COti~I~ ~i?~9 REPORT OF SUNDRY WELL P,/Ery 10y }$N'•[_~„SI~y. rtp m p ~p ~.~~~S~C C2 4=i44 L7~~CS ~J VMII'~• ~iti5iPT11SSi®it 1. Operations Abandon Repair Well Plug Perforations Stimulat Other ~ .Cancellation of reperf Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program Q Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory^ 191-099 ' 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^~ 6. API Number: 50-733-20189-01 ` 7. KB Elevation (ft): 9. Well Name and Number: 105' AMSL Trading Bay Unit G-14ARD 8. Property Designation: 10. Field/Pool(s): ADL0018730 [Grayling Platform] McArthur River /Hemlock Oil & West Foreland Oil Pools' 11. Present Well Condition Summary: Total Depth measured 12,939 feet Plugs (measured) N/A true vertical 10,627• feet Junk (measured) 12,625' Effective Depth measured 12,625 feet true vertical 10,335 feet ~,,,,,'~,''j,t~~w, j~ F fi `' ~,$ ~ ut,~; Casing Length Size MD TVD Burst Collapse Structural Conductor 522' 17-314" 522' 521' Surface 1,390' 13-3/8" 1,390' 1,361' 3,090 psi 1,540 psi Intermediate 7,970' 9-5/8" 7,970' 6,467' 6,870 psi 4,760 psi Production 12,939' 7" 12,939' 10,620' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 3-1/2" & 2-7/8" 9.3# & 6.4# N-80 11,526' & 12,112' Packers and SSSV (type and measured depth) Otis Permanent Paker / N/A 11,451' / N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bb! Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^ Service Daily Report of Well Operations N/A 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-253 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 2/10/2009 Form 10-404 Revised 04/2006 ~~tl~~ Z'~°'9 Submit Original Only ~ ~r~~ ~~~~~ r. 7! ETD = 12,868' TD = 12,939' RKB to MLLW ELEV = 103' MAX ANGLE = 42.9° ~ 4892' SCHEMATIC G-14ARD.rtf 2 3 4 5 6 7 Actual 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 N-80 7" 29 N-80 Tubing: 3-1/2" 9.3 N-80 2-7/8" 6.4 N-80 Window. Original 133/8" shoe @ 4477' Trading Bay Unit Well # G-14ARD Completed 6/9/92 CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. CMT Weld Surf. 522' 520' 700 sx Butt 12.515 Surf. ^ 1390' - 1460' 1361' 2500 sx Butt 8.681 Surf. 7970' 6455' 2950 sx Butt. 6.184 7715' 12,939' 10,575 800 sx S.L. 2.992 0' 11,526' S.L. 2.441 12,099' 12,112' NO. Denth ID JEWELRY DETAIL Item 42.6' 3-1/2" CIW Tubing Hanger 1 11,452' 2.99 Straight Slot Locator Seal Assy. w/ 10.27' of seals. 2 11,451' 4.00 Otis Model "BWH" Perma Pkr. 3 11,463' 4.00 Seal Bore Ext. 4 11,493' 2.75 Otis "X" Profile Nipple 5 11,525' 2.99 WLEG btm 11,526' 6 12,093 4.00 Otis Model "BWH" Perma Pkr. 7 12,098' 2.44 Crossover, 4-8 UN pin X 2-7/8" BTC pin 8 12,103' 2.313 Otis "X" Profile Nipple 9 12,110' 2.44 WLEG btm 12,111' FISH 2 Junked Retainers 5/28/92 @ 12,866' 2 Junked Retainers 5/31/92 @ 12,866' STIMULATIONS 55 bbls 7.5% HCL, 78 bbls 6.5% X 1.5% mud acid. 6/4/92 WF-5 , 6 & 7 9 bbls 7.5% HCL, 27 bbls 6.5% X 1.5% mud acid. 6/6/92 HB-1 SLICKLINE WORK Tagged fill w/ 2.25" swedge 7/19/08 @ 12,625' Tag XO w/2.74" GR 7/18/08 @ 12,098 REVISED: 8/12/97 DRAWN BY: SLT RKB to TBG Head = 42.6' Page 1 of 1 Maunder, Thomas E (DOA) From: Bonnett, Nigel (Nigel.Bonnett) [Nigel.Bonnett@chevron.com] Sent: Thursday, February 19, 2009 8:58 AM To: Maunder, Thomas E (DOA) Cc: Kanyer, Christopher V; Tyler, Steve L; Rose, Jim [Contractor] Subject: RE: An-17 (177-075) and G-14ARD (191-099)` Morning Tom, Anna-17 was a coil tubing intervention, originally planned as a precursor to performing a well. redrill operation after wells Anna-24 and Anna-32RD. However, with further analysis, the required redrill workscope resulted in marginal economics. So no operations were performed on Anna-17. G-14ARD perforating operation was cancelled due to lack of Partner support. In future, where we have cancellation of planned work which has been permitted, we will include a brief explanation as requested. Rgds, Nigel From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, February 18, 2009 3:57 PM To: Rose, ]im [Contractor] Subject: An-17 (177-075) and G-14ARD (191-099) Jim, 1 am reviewing the 404s submitted to closeout the sundries for work on these wells. Could you provide a little further information for the files? Thanks in advance. If future work is cancelled, please include a short explanation with the 404. Thanks in advance. Tom Maunder, PE AOGCC ~~ 2/19/2009 • • I ~. ~ ' ~ I ~~ r A -....~ ~.~ ~,'--~ m~ ~~ ~ c.~~ SARAH PAL/N, GOVERNOR ALA5SA OIL A1QD GA,S / COI~SERQA'1`IO1~T COA'id-TIS5IOI~T /~ 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 r~ PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager r O UNOCAL ' ~, PO Box 196247 ~ a Anchorage, AK 99519 Re: McArthur River Field, Hemlock/West Foreland Oil Pool, TBU G-14ARD Sundry Number: 308-253 ~~~NE~ JUL ~ ~: 2~Q8 Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ay of July, 2008 Encl. t~ ' STATE OF ALASKA {~' ~.1 p ~,~'2w~ AL~ OIL AND GAS CONSERVATION COMII~ON ~ ~ ~ ~ LaQ~ ~ H APPLICATION FOR SUNDRY APPROVA~~ 20 AAC 25.280 nl~oira t"a.(A ~'~~: ~~r;~ C;r~~r~~,i~sir~n 1. Type of Request: Abandon^ Suspend ^ Operational shutdown^ Perforate ^~ ~~.-,; -~- .1/µai~er^ Other^ Alter casing^ Repair well ^ Plug Perforations^ Stimulate^ Time Extension ^ Change approved progran^ Pull Tubing^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^ Exploratory ^ 191-099 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20189-01 ' 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-14ARD ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018730 [Grayling Platform] 42.6' McArthur River /Hemlock Oil /West Foreland Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12,939' 10S6~C' /p(,~71 ~ 12,625' '1.0;239' /~~~, ~y. lA 12,625' Casing Length 1•( Size MD ND Burst Collapse Structural Conductor 522' 17-3/4" 522' 521' Surface 1,390' 13-3/8" 1,390' 1,361' 3090 psi 1540 psi Intermediate 7,970' 9-5/8" 7,970' 6,467' 6870 psi 4760 psi Production 12,939' 7" 12,939' 10,620' 8160 psi 7020 psi Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" & 2-7/8" N-80 11,526' & 12,112' Packers and SSSV Type: Packers and SSSV MD (ft): Otis BWH Permanent Packer a 11,451' and N/A 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q J 15. Estimated Date for 7/25/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^Q WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature hone 276-7600 Date 7/16/2008 yJ ~ - ~~- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ . Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form quired: ~Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S ~~ JUL ~ 2008 '~,/, Form 10-403 Revised 06/2006 (~~} ~ ~ ~ ~ ~ ~ ` Submit m uplicate U L ~ ,. /B.~ ~: uNOCa~~ • 7'. 7! ETD = 12,888' TD = 12,939' RKB to MLLW ELEV = 103' MAX ANGLE = 42.9° @ 4692' SCHEMATIC G-14ARD.doc Trading Bay Unit Actual Well # G-14ARD Completed 6/9/92 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 N-80 7" 29 N-80 Tubiug: 3-1/2" 9.3 N-80 2-7/8" 6.4 N-80 CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. CMT Weld Surf. 522' 520' 700 sx 3utt 12.515 Surf. ^ 1390' - 1460' 1361' 2500 sx 3utt 8.681 Surf. 7970' 6455' 2950 sx 3utt 6.184 7715' 12,939' 10,575 800 sx ..L. 2.992 0' 11,526' >.L. 2.441 12,099' 12,112' Window. Original 133/8" shoe @ 4477' 3 4 5 i 7 NO. Depth ID JEWELRY DETAIL Item 42.6' 3-1/2" CIW Tubing Hanger 1 11,452' 2.99 Straight Slot Locator Seal Assy. w/ 10.27' of seals. 2 11,451' 4.00 Otis Model "BWH" Perrna Pkr. 3 11,463' 4.00 Seal Bore Ext. 4 11,493' 2.75 Otis "X" Profile Nipple 5 11,525' 2.99 WLEG btm 11,526' 6 12,093 4.00 Otis Model "BWH" Perma Pkr. 7 12,098' 2.44 Crossover, 4-8 UN pin X 2-7/8" BTC pin 8 12,103' 2.313 Otis "X" Profile Nipple 9 12,110' 2.44 WLEG btm 12,111' FISH 2 Junked Retainers 5/28/92 @ 12,866' 2 Junked Retainers 5/31/92 @ 12,866' STIMULATIONS 55 bbls 7.5% HCL, 78 bbls 6.5% X 1.5% mud acid. 6/4/92 WF-5, 6 & 7 9 bbls 7.5%HCL, 27 bbls 6.5% X 1.5% mud acid. 6/6/92 HB-1 SLICKLINE WORK Tagged for fill w/ 2.1875 GR 6/5/95 @ 12,102' PERFORATION DATA Zone To Btm Amt Accum SPF Last Perf Date Present Condition 11,519' 11,523' 4' 4 5/25/92 CmtSgzholes H&1 11,576' 11,597' 21' 8 6/5/92 Open forlnection. HB-4 11,820' 11,935' 115' 8 6/5/92 for In'ection. WF-2 12,22T 12,31T 90' 8 612/92 Open forlnjection. WF-3 12,332' 12,473' 141' 8 6/2192 Open for Injection. 1IVF~ 12 477' 12 524' 47' 8 6/2/92 Open for Injection. 12,564' 12,568' 4' 4 5/25/92 CmtSgzhdes WF-5 12,564' 12,651' 87' 12 6/2/92 Open for Injection. WF-6 12,66T 12,719' S2' 8 6/2/92 Open for Injection. WF-7 12 751' 12 78T 36' 8 6/2/92 n for In action. REVISED: 8/12/97 DRAWN BY: SLT RKB to TBG Head = 42.6' uNOCa~~ • Trading Bay Unit Proposed Well # G-14ARD Completed 6/9/92 7. 7S 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 N-80 7" 29 N-80 Tubing: 3-1/2" 9.3 N-80 2-7/8" 6.4 N-80 Window. Original 133/8" shoe @ 4477' CASING AND TUBING DETAIL MD MD TVD CONN ID TOP BTM. BTM. CMT Neld Surf. 522' 520' 700 sx tuff 12.515 Surf. ^ 1390' - 1460' 1361' 2500 sx tuff 8.681 Surf. 7970' 6455' 2950 sx lutt 6.184 7715' 12,939' 10,575 800 sx LL. 2.992 0' 11,526' LL. 2.441 12,099' 12,112' NO. Denth ID JEWELRY DETAIL Item 42.6' 3-1/2" CIW Tubing Hanger 1 11,452' 2.99 Straight Slot Locator Seal Assy. w/ 10.27' of seals. 2 11,451' 4.00 Otis Model "BWH" Perma Pkr. 3 11,463' 4.00 Seal Bore Ext. 4 11,493' 2.75 Otis "X" Profile Nipple 5 11,525' 2.99 WLEG btm 11,526' 6 12,093 4.00 Otis Model "BWH" Penna Pkr. 7 12,098' 2.44 Crossover, 4-8 UN pin X 2-7/8" BTC pin 8 12,103' 2.313 Otis "X" Frofile Nipple 9 12,110' 2.44 WLEG btm 12,111' FISH 2 Junked Retainers 5/28/92 @ 12,866' 2 Junked Retainers 5/31/92 @ 12,866' STIMULATIONS 55 bbls 7.5%HCL, 78 bbls 6.5% X 1.5% mud acid. 6/4/92 WF-5 , 6 & 7 9 bbls 7.5%HCL, 27 bbls 6.5% X 1.5% mud acid. 6/6/92 HB-1 SLICKLINE WORK Tagged for fill w/ 2.1875 GR 6/5/95 @ 12,102' 3 ?• 5 i ETD = 12,868' TD = 12,939' ' RKB to MLLW ELEV = 103' MAX ANGLE = 42.9° @ 4692' SCHEMATIC_G-14ARD Proposed.doc III PERF ORATION DATA Zone Top Btm Amt Accum SPF Last Perf Date Present Condition 11,519' 11,523' 4' 4 5/25/1992 CmtSgzhdes HB-1 11 576' 11 59T 21' 8 6/5/1992 O en for Injection. Pro sed re ert HB-2 11,690' t1, 740' S0' 8 Proposed Proposed HB-4 11 820' 11 935' 115' 8 6/5/1992 O en for Injection. Pro sed re ert WF-2 12,227' 12,31 T 90' 8 6/2/1992 Open for Injection. WF-3 12,332' 12,473' 141' 8 6/2/1992 Open far Injection. WF-4 1 477' 12 524' 47' 8 6/2/1992 Open for Injection. 12,564' 12,568' 4' 4 5/25/1992 CmtSgzhdes WF-5 1 564' 12651' 87' 12 6/2/1992 Open for Injection. WF-6 12,667' 12,719' S2' 8 6/2!1992 Open for Injection. WF-7 12,751' 12 78T 36' 8 6/2/1992 O en for Injection. REVISED: 8/12/97 DRAWN BY: SLT RKB to TBG Head = 42.8' Chevron Procedure Summary • Well: G-14ARD Facility: Grayling Platform Field: McArthur River Objective: Add perf and reperfs to Hemlock Bench Sands Procedures: 1 Rig up slickline. Drift/gauge well to prep for perforating and test BOPE's. Rig down slickline 2 Rig up Eline unit. RIH with RST to 11,950' and log up thru jewelry to 11,400'. POOH. 3 PUMU dummy gun. RIH. 4 Pick up guns, RIH repeforate the proposed B-1 zone at 11,576'-11596' (+/-). POOH. 5 RIH peforate the proposed B-2 zone at 11,690'-11,740' (+/-). POOH. 6 RIH repeforate the proposed B-4 zone at 11,860'-11,900' (+/-). POOH. 7 Rig down Eline unit and secure well. G-14ARD Procedure Summary CVK Page 1 7/15/2008 TO: ) Jim Regg J I P.I. Supervisor 1'\tlt¡q4-' Z7/ù5" State of Alaska Alaska Oil and Gas Conservation Coml1 )n DATE: Thursday, April 07, 2005 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA G-14ARD TRADING BAY UNIT G-14ARD \..' :""., o'\~ ~::'. ,d \~\ MEMORANDUM FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: ~~ -:1 ..r P.I. Suprv -.JP:~ Comm Well Name: TRADING BAY UNIT G-14ARD Insp Num: mitLG050407064854 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-733-20189-01-00 Permit Number: 191-099~0 Inspector Name: Lou Grimaldi Inspection Date: 4/6/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I G-14ARD Type Inj. S TVD 9240 IA 480 2400 2400 2400 P. T. I 1910990 TypeTest SPT Test psi 2310 OA 300 320 330 320 Interval 4YRTST P/F P Tubing 3400 3400 3400 3400 Notes: Well tested while onboard for SVS tests. IA checked for fluid to surface. Good test. ~CANNED MAY :3 1. 2005 Thursday, April 07, 2005 Page 1 of 1 Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com ") J?r ~o?9 ) UNOCAL Debra Oudean G & G Technician Date: September 17, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 ~I.I.IDI G-14A ~ELL-' L~!"PE_~~~!lr~~~M~!!111~~V A~~O~G~DJ~~~~~~Jc~I~~PE!!' ¡G-14AjRSTSIGMA¡5INCH 7/16/20041700-7410 ! 21 11 11 o! ,-_.. "w-,,,w~.,,.w,,,,~,,,,.-_.~,,w......._-,.w.~~._,w.;.._-_.......__...,-_."""''''.-''-'''W-w''.Ww'''--~''''''-~'''-ww-~-~'''-'w-'w.'~w'~.~"w"",_,,,,,~"',,w,,,,,,,~'w,,..,_J ~(';ANNE(: NOV {1 5 2L1Qt¡ nll1g one copy of this transmittal or FAX to (907) 263-7828. ~/¡iç/ Date: THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 E E PL E W M A TE R IA L U N D E THIS M A R K E R R ~ STATE OF ALAS ~" ALASKA oIL' AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: X Plugging: Time extension: Stimulate: Change approved program: Pull tubing: X Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: KB: 103' feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247, Anchorage, AK 99519 Stratigraphic: Service: X Trading Bay Unit 4. Location of well at surface Grayling Platform Leg # 4, Conductor # 13 8. Well number 1,825' FSL, 1,487' FEL, Sec. 29, TgN, R13W, SM G-14ARD At top of productive interval 11,005' MD 9. Permit number 1,351' FNL, 1,520' FEL, Sec. 33, T9N, R13W, SM At effective depth 10. APl number 50- 733-20189-01 At total depth 12,939' MD 11. Field/Pool 1,775' FNL, 901' FEL, Sec. 33, T9N, R13W, SM McArthur River/Hemlock & "G" Zone 12. Present well condition summary Total depth: measured 12,939' feet Plugs(measured) RECEIVED true vertical 10,631' feet Effective depth: measured 12,868' feet Junk (measured) J,~,,'~ 2 0 1998 true vertical 10,575' feet Naska 0ii & Gas Cons. commissl011 Casing Length Size Cemented Measured depth TrLl~~apth Structural Conductor 520' 17-3/4" 700 sx 522' 520' Surface 1,390' 13-3/8" 2,500 sx 1,390' 1,361' Intermediate Production 7,970' 9-5/8" 2,950 sx 7,970' 6,445' Liner 5,224' 7" 800 sx 12,939' 10,631' Perforation depth: measured (See attachment) true vertical ORIGINAL Tubing (size, grade, and measured depth) 8-1/2", 9.2#, N-80 @ 11,526' 2-7/8", 6.4#, N-80 From 12,098' to 12,111' Packers and SSSV (type and measured depth) Otis BWH perm. pkr. @ 11,451' & Otis BWH perm. pkr. @ 12,093' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 2/1/1998 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~~ ~~ Title: Drilling Manager Date: 1/15/1998 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No.,,, Plug integrity.~ BOP Test ~ Location clearance I Mechanical Integrity Test Subsequent form required 10- oo~'~ ~ ~,~ ~,.e~~.- David W. Johnston Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLIO PERFORATION DATA SHEET GRAYLING G- 14ARD Perforated Hemlock. Zone HK-1 Zone HK-4 Zone Interval MD 11,576' - 11,597' 11,820' - 11,935' Interval TVD 9,369' - 9,388' 9,592' - 9,698' Perforated West Foreland. Zone WF-2 Zone WF-3 Zone WF-4 Zone WF-5 Zone WF-6 Zone WF-7 Zone Interval MD 12,227' - 12,317' 12,332' - 12,473' 12,477' - 12,524' 12,564' - 12,651' 12,667' - 12,719' 12,751' - 12,787' .... ~nterval TVD 9,968' - 10,052' 10,066' - 10,197' 10,200' - 10,244' 10,282' - 10,362' 10,378' - 10,425' 10,455' - 10,489' UNOCAL Grayling Well eI4ARD Rig Workover AFE #130251 Workover Procedure Objective: The objective of the workover on G-14ARD is to gain access to the G-zone. The well is currently a water injector in the Hemlock and West Forelands formations. The proposed workover will remove the existing packer above the Hemlock and cement squeeze above proposed G-zone perforations. After milling out the squeeze cement and retainers, the new completion will be run above the G-zone. After the rig workover, perforations will be added with through-tubing guns and injection will occur into all 3 zones: G-zone, Hemlock and West Forelands. Pre-Workover Slickline Wok: There is currently a choke in the lower packer assembly between the Hemlock and West Foreland intervals. Debris from milling the upper packer during the workover could lodge or cover the choke making future removal of the choke impossible. Therefore, this choke should be removed by slickline prior to the workover and can be replaced after the workover. Shutting in Injection: G-14Ard should be shut-in several days prior to the workover to allow for well pressures to stabilize. The well should go on vacuum. However, if it does not, then pumping higher density fluids may be required prior to pulling the tubing. Estimated Formation Pressure: Hemlock and West Forelands formation pressure is estimated to be 0.4 psi/ft. Workover Procedure: 1. Check tubing for pressure. Ensure annulus is full of liquid. 2. Install back pressure valve. ND tree. 3. NU BOPE, pull BPV and install 2-way check. Test BOPE with 24 hr notice given to AOGCC for witness. 4. Pull 2-way check valve. Engage tubing hanger with landing joint. Kill well with FIW if necessary. 5. Pull tubing 10' and monitor well, circulate FIW down tubing and up annulus (1-1/2 well volumes) to ensure well is clear of gas. 6. POOH laying down tubing. 7. MU Otis BWH packer milling/retrieving assembly. 8. PU 3-1/2" drill pipe and RIH with packer mill/retrieval assembly. Mill BWH packer at 11,451' 9. POOH with packer assembly. 10. RU Schlumberger E-line unit. Procedure.DOC 1/14/98 UNOCAL ) Grayling Well I4ARD Rig Workover AFE #130251 11. Set 7" bridge plug with E-line at 11,000'. 12. POOH with E-line setting tools. Pressure test annulus to 2200 psi. 13. Make up squeeze perf gun, RIH and perforate squeeze holes at 10,090'-10,092'. 14. POOH and RD E-line unit. 15. RIH with 7" EZSV squeeze retainer on drill pipe. 16. Set EZSV above squeeze perfs at 10,070'. Establish injection into squeeze perfs. 17. Mix cement and pump cement squeeze below retainer. 18. After squeeze pressure obtained, unsting from retainer and reverse circulate drill pipe clean. 19. POOH with drill pipe. 20. RIH with 6" mill and 7" casing scraper. 21. Tag cement retainer, WOC if necessary. 22. Drill up retainer, cement and bridge plug. 23. Cont RIH with scraper to top of lower packer assembly at 12,093'. 24. Circ hole clean and POOH LDDP. 25. Run completion with hydraulic set permanent injection packer and 3-1/2" tubing. 26. Land hanger, drop ball to set packer at 10,830'. Pressure test annulus to 2200 psi. 27. Pressure up to blow out ball. 28. Set BPV and ND BOPE. NU tree and retest annulus to 2200 psi with AOGCC witness for injection well MIT. 29. Release rig. Start water injection. 30. RU Schlumberger and perforate the following intervals: G-1 11005'-11050' G-2 11070'-11100' G-3 11175'-11190' G-4 11220'-11270' G-5 11340'-11405' HB-3 11750'-11,820' HB-4 11820'-11935' Reperf AOGCCproc.DOC 1 / 14/98 3" KILL L~NE WITH TWO 5" 5M VALVES I d,,' KILL LINE FROM MUD PMP & CEMENT UNIT NIPPLE l 13-5/8" 5000 PSI ANNULAR PiPE RAMS BLIND RAMS I ~ FLOWLINE 13-5/8" 5M FLANGE ! ' PIPE RAMS DOUBLE GATE 5M 15-5/8" 5M FLANGE r..,..__l 4.,, CHOKE LINE WITH ONE REMOTE & I MANUAL 4." 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 15-5//8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE RISER ! · ] 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M SPOOL 13-5//8'' DOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (db,::l UNOCAL) , ,I '"' "DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 6/24./91 MIXING PIT 40 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM 185 BBLS VOLUME PIT TRIP TANK 45 BBLS 185 BBLS SUCTION PIT il J DESILTER J : ' I SHAKER SHAKER I J · · i I I---- .......... I --CENTRIFUGE RESERVE PIT 475 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO &: VISUAL WARNING DE'VICES. EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 5) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PiT SCHEIvlATIC DRAWN ElY: DAC APP'D: GSEI SCALE: NONE DATE: 11-50-89 FIKB to TBG Head = 42.6' 7715' 797; 11,451' 12,098' B-1 --- B-4 WF-2 WF-3 WF-4 ETD = 12,868' TD = 12,939' RKB to MLLW ELEV = 103' MAX ANGLE = 42.9° @ 4692' G-14ard.doc SIZE wr GRADE CASING AND ~BING DETAIL MD CONN 1D TOP Trading Bay Unit Well # G- 14ARD Completed 6/9/92 MD TVD BTM. BTM. CMT 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 N-80 7" 29 N-80 Tubing: 3-1/2" 9.3 N-80 2-7/8" 6.4 N-80 Window. Original 13-3/8" shoe @ 4477' Weld Surf. 522' 520' Butt 12.515 Surf. (~ 1390' - 1460' 1361' Butt 8.681 Surf. 7970' 6455' Butt 6.184 7715' 12,939' 10,575' S.L. 2.992 0' 11,526' S.L. 2.441 12,099' 12,112' 700 sx 2500 sx 2950 sx 800 sx 42.6' 1 11,452' 2 11,451' 3 11,463' 4 11,493' 5 11,525' btm 11,526' JEWELRY DETAIL ID Item 3-1/2" CIW Tubing Hanger 2.99 Straight Slot Locator Seal Assy. w/10.27' of seals. 4.00 Otis Model "BWH" Perma Pkr. 4.00 Seal Bore Ext. 2.75 Otis "X" Profile Nipple 2.99 WLEG ,,, FISH 6 12,093 4.00 7 12,098' 2.44 8 12,103' 2.313 9 12,110' 2.44 btm 12,111' Otis Model "BWH" Perma Pkr. Crossover, 4-8 UN pin X 2-7/8" BTC pin Otis "X" Nipple w/chk of unknown size, 4/11/93 WLEG 2 Junked Retainers 5/28/92 @ 12,866' 2 Junked Retainers 5/31/92 @ 12,866' STIMULATIONS 55 bbls 7.5% HCL, 78 bbls 6.5% X 1.5% mud acid. 9 bbls 7.5% HCL, 27 bbls 6.5% X 1.5% mud acid. 6/4/92 WF-5, 6 & 7 6/6/92 HB-1 SLICKLINE WORK Tagged for fill w/2.1875 GR 6/5/95 @ 12,102' PERFORATION DATA Accum Last Zone Top Btm Amt SPF Peff Date Present Condition 11,519' 11,523' 4' 4 5/25/92 Cmt Sqz holes HB-i 11,576' 11,597' 21' 8 6/5/92 Open for Injection. HB-4 11,820' 11,935' 115' 8 6/5/92 Open for Injection. WF-2 12,227' 12,317' 90' 8 6/2/92 Open for Injection. W F-3 12,332' 12,473' 141' 8 6/2/92 Open for Injection. WF-4 12,477' 12,524' 47' 8 6/2/92 Open for Injection. 12,564' 12,568' 4' 4 5/25/92 Cmt Sqz holes WF-5 12,564' 12,651' 87' 12 6/2/92 OPen for Injection. WF-6 12,667' 12,719' 52' 8 6/2/92 Open for Injection. WF-7 12,751' 12~787' 36' 8 6/2/92 Open for Intection, , REVISED: 8/12/97 1%1~ A~X/NT E~V. ~T 'T' RKB to TBG Head = 42.6' Tree connection: 7715' 7970' 10,830' 12,098' Prop G-Zone Perfs 11005'- 11405' Sqz'92 B-1 B-4 W F-2 WF~3 WF~4 WF-5 WF-6 WF-7 ETD = 12,868' TD = 12,939' RKB to MLLW ELEV = 103' MAX ANGLE = 42.9° @ 4692' Proposed G-14ARD.DOC SIZE GRABE Trading Bay Unit Well # G- 14ARD Proposed 3/98 CASING AND TUBING DETAIL MD MD TVD CONN 1D TOP BTM. BTM, CMT 17-3/4" .312 wall 13-3/8" 61 K-55 9-5/8" 47 N-80 7" 29 N-80 Tubing: 3-1/2" 9.3 N-80 2-7/8" 6.4 N-80 Window. Original 13-3/8" shoe @ 4477' Weld Surf. 522' 520' Butt 12.515 Surf. fl) 1390' - 1460' 1361' Butt 8.681 Surf. 7970' 6455' Butt 6.184 7715' 12,939' 10,575' Butt 2.992 0' 10,900' S.L. 2.441 12,099' 12,112' 700 sx 2500 sx 2950 sx 800 sx NO. Depth 42.6' 1 10,820' 2 10,830' 3 10,840' 4 10,870' 5 10,899' btm 10,900' 6 12,093 7 12,098' 8 12,103' 9 12,110' btm 12,111' JEWELRY DETAIL ID Item 3-1/2" CIW Tubing Hanger 2.99 Straight Slot Locator Seal Assy. w/10.27' of seals. 4.00 Perma Pkr. 4.00 Seal Bore E~ 2.75 '~" Profile Nipple 2.99 WLEG 4.00 Clis Model "BWH" Perma Pkr. 2.44 Crossover, 4-8 UN pin X 2-7/8" BTC pin 2.313 Otis "X" Profile Nipple 2.44 WLEG FISH 2 Junked Retainers 2 Junked Retainers STIMULATIONS 55 I~ls 7.5% HCL, 78 I~ols 6.5% X 1.5% mud acid. 9 bbls 7.5% HCL, 27 I~ls 6.5% X 1.5% mud acid. SLICKLINE WORK Tagged for fill w/2.1875 GR 5/28/92 @ 12,866' 5/31/92 @ 12,866' 6/4/92 WF-5, 6 & 7 6/6/92 HB-1 6/5/95 @ 12,102' PERFORATION DATA Accum Last Zone Top Btm Amt SPF Perf Date Present Condition G-1 11,005' 11,050' 45' 6 Proposed New Perfs G-2 11,070' 11,100' 30' 6 Proposed New Perfs G-3 11,175' 11,190' 15' 6 Proposed New Perfs G-4 11,220' 11,270' 50' 6 Proposed New Perfs G-5 11,340' 11,405' 65' 6 Proposed New Perfs 11,519' 11,523' 4' 4 5/25/92 Cmt Sqz holes HB-1 11,576' 11,597' 21' 8 6/5/92 Open for Injection. "HB-3 11,750' 11,820' 70' 6 Proposed New Perfs HB-4 11,820' 11,935' 115' 8 6/5/92 Open for Injection. HB-4 11,820' 11,935' 115' 6 Proposed Reperf W F-2 12,227' 12,317' 90' 8 6/2/92 Open for Injection. W F-3 12,332' 12,473' 141' 8 6/2/92 Open for Injection. W F-4 12,477' 12,524' 47' 8 6/2/92 Open for Injection. 12,564' 12,568' 4' 4 5/25/92 Cmt Sqz holes W F-5 12,564' 12,651' 87' 12 6/2/92 Open for Injection. W F-6 12,667' 12,719' 52' 8 6/2/92 Open for Injection. 'W F-7 12,751' 12,787' 36' 8 6/2/92 Open for Injection. 390' Total Proposed Perf and Reperf REVISED: 01/14/91~ DRAWN BY: TAB TO GAS BUSTER /\ , _ TO DERRICK VENT TO WELL CLEAN TANK 3-1/8" AUTOMATIC CHOKE / FROM CHOKE LINE AUTOMATIC CHOKE VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES 00WNSTREAM OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: OSB SCALE: NONE DATE: 11/26/89 PERMIT 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 91-099 9~-099 DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS SURVEY 6ARM DIP D 100-12820, GYRO L 1400-7918 6ARM DIP L 1400-7918 BHV/6ARM DIP DIL/HRI DIL/HRI/DCO DIL/SG DIL/SG L 1450-7829 L 1402-7837 L 1402-7837 L 1402-7837 L 1402-7837 DIP COMPUTATIONS L 1500-7800 FWS L 6100-7791 FWS L 6100-7791 HRI L 1400-7829 HRI L 1400-7829 MUD L 1425-13050 SBT L 100-7700 SBT L 11600-12857 SBT L 11600-12857 SBT L 7700-12862 SD/BD SD/BD SD/DSN SD/DSN TVD PLOTS L 1400-7799 L 7799-7842 L 7799-7842 L 7799-7842 L 1402-7837 407 DAILY WELL OP SURVEY DRY CUTTINGS DRY DITCH R COMP DATE: 06/09/92 R 02/27/92~9/92 R 100-12820, GYRO S 1410-7710, *MEMO* S 7710-13050,SS#840 Page: Date: RUN .1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 05/16/94 DATE_RECVD 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 10/16/92 10/21/92 10/16/92 10/16/92 06/26/92 06/26/92 06/26/92 06/26/92 06/26/92 10/05/92 10/05/92 06/26/92 04/23/92 06/04/92 AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS 91-099 5309 Page: 2 Date: 05/16/94 RUN DATE_RECVD T 1376-12862, OH&CH-HRI/GR 1-2 06/26/92 Are dry ditch samples Was the well cored? Are well tests required.~yes n~~~ei'ved? Well is in compliance I'ni%--a~i · ' 1 COMMENTS required? yes ~And received? ye~ yes ~~Analysis & description received? yes ~ Unocal North America~ Oil & Gas Division ~ ~ Unocal Corporation P,O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITFAL October 21, 1992 TO: Larry Grant FROM: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION Kirk Kiloh P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION G-14A RD ~ ('~ ~ Transmitting as Follows: Sepia Segmented Bond Log 5-29-92, 7" Liner Pass After Squeeze PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED BY: '"' / RECEIVED DATED: OCT 2 1 1992 Alaska Oil & Gas Cons. Commission Anchorage Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907} 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITI'AL October 15, 1992 TO: Larry Grant FROM: 3001 PorcUpine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION G-14A ~q~5~ff~ Transmitting as Follows: I Sepia Acoustic Cement Bond Log, Halliburton, 3-26-92 I Sepia Acoustic Cement Bond Log, Halliburton, 3-29-92 Kirk Kiloh P O Box 196247 Anchorage AK 99519-6247 M. ASKA REGION G-14A RD q/~q? ~'I~epia Segmented Bond Log 7" Liner Pass Prior to Squeeze 5-24-92 2 Sepia Segmented Bond Log 7" Liner Pass After~tli~ze 5-29-92 ~ia(1 Sepia and 1 with Waveforms) Segmented Bond Log 9 5/8" Casing RECEIVED 0CT 1 6 1992 Naska 0il & Gas Cons. Commita!01l Anchorage PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED BY: ..~~ ~ DATED: --~'~IL AND' STATE OF ALASKA ,~-~, D ~[ I u i ~. ,~ ALAS~' i :~.~ GAS CONSERVATION COk ~SION WELL COMPLETIbN OR RECOMPLETION k PORT AND LOG 1. Status of Well Classification of Service Well OIL [-] GAS ~-] SUSPENDED ~ ABANDONEDC SERVICE [~ Water Injection _ 2. Name of Operator 7, Perm;t Number Union Oil Company of California (UNOCAL) 91-0099 / 92-069 (change approval) 3. Address 8, APl Number P. O. Box 196247, Anchorage, Alaska 99519 50--733--,20189--01 4, Location of well at surface Leg #4, Conductor #13 ;~ ...... , ........ ,~ .... 9, Unit or Lease Name 1825' FSL and 1487' FEL, Section 29, TgN, R13W, S,M. i'~ COMPLeTiON i'~~lll~ ~ Trading Bay Unit AtTop Producing Interval I ~...~TT~j, [.~ 10. Well Number 1459' FNL and 3972' FWL, Section 33, TgN, R13W, S.M. at 11576' I~ ~ G-- 14A Redrill ID VERIFIED At Total Depth ~ 11, Field and Pool 1761' FNL and 4395' FWL, Section 33, TgN, R13W, S.M. at 12939' i ,u - "'~ McArthur River Field , , 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Hemlock 103' RKB above MLLWI ADL 18730 , , 12. Date Spudded 2/27/92 13. Date T.D. Reached 5/1 !/92 IJ 14' Date c°mP" Susp' °r Aband' 115' Water Depth' if offshore 116' N°' °f C°mpleti°ns 6/09/92 ,, 125 Feet MSL one 17' T°tal Depth (MD+TVD)10' Plug Back Depth (MD+TVD)10' Directi°nal Survere-~ 120' Dopthwhere sssV set12930' MD/10631'TVD 12868' MD/10575'TVD YES [~ .. ,sEa feet MD 1211 Thickness Of PermafrOst 22. Type Electric or Other Logs Run SBT/VDL/GR/CCL; GYRO SURVEY (NO OPENHOLE LOGS) 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 17-3/4" Surface 520' 22" 700 sxs 13-3/8' 61 # J-55 Surface 4477' 17-1/2" 2500 sxs Section milled f/1390' to 1460' MD 9-5/8" 47# N--80 Surface 7970' 12-- 1/4" 2950 sxs 7' liner 29# N-80 7715' 1 2939' 8-1/2' 800 sxs , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) [ PACKER SET (MD) HB-I: 11576'- 11597' MD (9369'-- 9388' TVD) 3--1/2" 11526' MD Perm pkr @ 11452' MD HB-4:11820'- 11935' MD (9592'-- 9698' TVD) Perm isolation pkr @ 12093' MD WF--2: 12227'-- 12317' MD (9968'- 10052' TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WF-3: 12332'- 12473' MD (10066'- 10197' TVD) DEPTH INTERVAL {MD) I AMOUNT & KIND 0F MATERIAL UsED WF--4: 12477'- 12524' MD (10200'-- 10244' q'VD) 12564'- 12787' 55 bbls 7.5% HCL + 78 bbls 6.5% HCl-/1.5% HF WF-5: 12564'-- 12851' MD (10282'-- 10362' TVD) WF-6: 12667'- 12719' MD (10378'- 10425' TVD) 11576'- 11597' 9 bbls 7.5% HCL + 27 bbls 6.5% HCL/1,5% HF WF-7: 12751'-- 12787' MD (10455'- 10489' TVD) 27 PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.) 6/10/92 (injection) water injection 7350 bwpd @ 2900 psi surface pressure Date of Test Hours Tested PRODUCTION FOF OIL--BBL GAS--MCF WATER--BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD FIowTubing CaSing Pressure CALCULATED OIL-BBL GAS--MCF WATER--BBL OIL GRAVITY-APl (corr) Press. 24- HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R'ECEIVED None 0 CT - 5 1992 AJaska Oil & Gas Cons. Commission Anchorage Form 10-407 rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hemlock 11576' MD 9382' TVD None Top West Foreland 12143' MD 9887' TVD RECEIVED A ~ska Oil & Gas Go~. Oommtssiot~- Anohoraga 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Gary S. Bush G~:~-~~'~ ~-.~, Drilling Mgr August 17, 1992 Signed ...,. Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. ' OS-OB OONN~¢HON$ 1) P~RM PKR WI 4" SEAI..$ (~ 11452' 18-818", 81~ 2) ~ ~DING NIPPLE ~ 11~) ~ 114~' ~OP O~ WINDOW ~) ~ ~D/NG NIPPL~ (2-H~) ~ 121~' ~-~ eu~ Z ~ ~.e~ ~'~oeu~u~m 0 O T - 5 19 9 ~ (A CiO S ~MU~ ~0) Oil & Gas Cons. Com~ts~to~ ~ ~ 4 WF-2 1222X'- 12317'MD Anchorage x5 WF~ 12~2'- 12473'MD WF~ 124~'- 12~24'MD == WF-5 125~ ' - 12~1' MD ~ ~2~'~o Z ~ w~-~ ~'- ~8~'~o Alask UNOCAL TUBULAR DETAIL WELL #: G-14 A-RD GRAYLING PLATFORM PAGE 1 of I DATE: APRIL 20, 1992 AFE NO.; 301406 STRING: 9-$/s~, 47~, N-80 & L--80(11 JTS.), B~$$ CASINO FOREMAN: EVA~ HARNESS 1 HOWCO 9-5/8" SUPER SEAL 2 FLOAT SHOE 1.45 7968~55 7970i ~T.#1- Z 2 JOINTS 9-5/8", 47#, L-80 BLrlT. CASING (w/CENTRALIZER ON EA.) 8.681 90.14 7878.41 7968~55 1 HOWCO SUPER SEAL 2 FLOAT COLLAR 1.05 7877.36 7878.41 yr#3- 11 9 JOINTS 9-5/8", 47#, L-80 BUTT. CASING (w/CENTRALIZER ON EA.) 8.681 375.27 7502.09 7877.36 #1z - zz 11 JOINTS 9-5/8", 47#, N-80 BUTT. CASING (w/ CENTRALIZER ON EA.) 8.681 475.07 7027.02 7502.09 #~3- 1361 114 3TS. 9-5/8", 47#, N-80 BWIT. CSG. (w/CENTRALIZER EVERY3rd..IT.) 8.681 4985.13 2041.89 7027.02 #137-~5o 14 JOINTS 9-5/8", 47#, N-80 BWIT. CASING (w/CENTRALIZER ON EA.) 8.681 618.87 1423.02 2041.89 #~sl-~sz 2 JOINTS 9-5/8", 47#, N-80 BLrl~RESS CASING (NO CENTRALIZERS) 8.681 89.48 1333_54 1423.02 #1s3-16~ 10 JOINTS 9-5/8", 47#, N-80 BLYIT. CASING (w/ CENTRALIZER ON EA.) . 8.681 436.57 896.97 1333.54 #1~-t79 17 JOINTS 9-5/8", 47#, N-80 BUTTRESS CASING (NO CENTRALIZERS) 8.681 729.19 167.78 896.97 #tao-~a~ 2 JOINTS 9-5/8", 47#, N-80 BUTT. CASING (w/CENTRALIZER ON EA.) 8.681 90.78 77 167.78 xr#1sz 1 JOINT 9-5/R', 47#, N-80 BLrlTRESS CASING (NO CENTRALIZERS) 8.681 34.13 42.87 77 RKB TO TOP OF DCB 42.87 0 0 0 0 0 0 0 0 0 0 NOTE: LAID DOWN JT.#183. & CUT 11.44' OFF YF.#182 WHICH WAS ORIGINALY 45.~7' LON(3. 0 0 0 0 0 Gl 0 0 0 o! ¢ I::t) o o OCT - 5 IO92 o 0 0 0 0 0 W~LL DA STRING: MA Y 19, 1992 7' 29~, N-80 BLt2'I'RES$ CASING PAGE I o£ 1 AFE NO.: ~o14o6 FOREMAN: ~VAN HARNF. SS 1 1 TIW FLOAT SHOE 2.4 12936.6 12939 JT.#1 1 JOINT 7" 29#, N-80, BLVI~RESS CASING (w/ CENTRALIZER) 6.184 44.89 12891.71 12936.6 ,, 2 1 TIW FLOAT COLLAR 1.8 12889.91 12891.71 JT.$~2 1 JOINT 7" 29#, N-80, BUTI'RESS CASING (w/ CENTRALIZER) 6.184 44.85 12845.06 12889.91 3 1 TIW LANDING COLLAR 0.82 12844.24 12845.06 J-T.#3 1 JOINT 7" 29#, N-80, B~ESS CASING (w/ CENTRALIZER) 6.184 44.94 12799.3 12844.24 4-13 10 JOINTS 7" 29#, N-80, BUTI'. CASING (w/ CENTRALIZER ON EA.J'T.) 6.184 431.56 12367.74 12799.3 1 7" 29#, N-80, BUTI'RESS PUP JO INT (w/ CENTRALIZER) 6.184 20.03 12347.71 12367.74 14-26 13 JOINTS 7" 29#, N-80, BLVI~. CASING (w/ CENTRALIZER ON EA. J-TO 6.184 564.17 11783.54 12347.71 1 7" 29#, N-80, BUUI'RESS PUP JOINT (w/CENTRALIZER) 6.184 19.9 11763.64 11783.54 27-31 5 JOINTS 7" 29#, N-80, BUTT. CASING (w/ CENTRALIZER ON EA. JT.) 6.184 191.51 11572.13 11763.64 sz-lo~ 78 .1TS. 7" 29#, N-80, BU'YI'. CASING (w/ CENTRALIZER ON EVERY 3rd fl'.) 6.184 3251.35 8320.78 11572.13 ilo-H4 5 JOINTS 7" 29#, N-80, BU'UI'. CASING (w/ CENTRALIZER ON EA. YI'.) 6.184 203.29 8117A9 832038 ns-n6 2 JOINTS 7" 29#, N-80, BUTI~RESS CASING (NO CENTRALIZERS) 6.184 85.86 803133 8117.49 ~7-1zz 6 JOINTS 7" 29#, N-80, BU'U1~. CASING (w/ CENTRALIZER ON EA. JT.) 6.184 256.35 777528 8031.63 yr.#1~3 1 JOINT 7" 29#, N-80, BLGTRESS CASING (NO CENTRALIZERS) 6.184 44.34 7730.94 777528 4 1 TIW 9-5/8", 47# x 7" LINER HANGER 15.27 7715.67 773094 DTHTYPE S HYD HANGER #609085 ;S-6 PACKER w/ RPCB #6090~6 771537 0 TOP OF LINER 771537 0 ol 01 0 0 0 0 0 0 0 0 0 0 0 o 0 ~t~-r - ~ 1_q~9 o Aiaska oi& ~asCons.Gomm~oo, 0 A.u, ~O~agu o 0 0 o !, UNOCAL TUBULAR DETAIL W~JJ~ t}t: G-14 A--RD GRAYLING PLATFORM PAGI~ 1 o£ 1 DATE: JUNB 08, 1~)2 AI~'E NO.: 30140~ STRING: 3-1/2", 9.$#, L-80, CS-CB HYDRIL TUBING FOREMAN: DON BYRNB 1 1 WIRELINE RE-ENTRY GUIDE 0.66 11524.93 11525.59 2 1 JOINT 3'1/2", 9.3#, L-80, CS-CB HYDRIL TUBING 2.992 30.79 11494.14 11524.93 3 1 "X" NIPPLE 1.08 11493.06 11494.14 4 1 JOINT 3-1/2", 9.3#, L-80, CS-CB HYDRIL TUBING 2.992 30.88 11462.18 11493.06 5 1 SEAL ASSEMBLY - 4" OD 4 10.27 11451.91 11462.18 1 OTIS PERM. PACKER; 7'k 4" w/8' SEAL BORE EXT., #212 BWH 70400-A 6 PACKER WAS DRILL PIPE SET - ALL MEASUREMENTS ARE DPM 12.24 11451 11463.24 377 JOINTS 3-1/2", 9.3#, L-80, CS-CB HYDRIL TUBING 2.992 11398.71 53.2 11451.91 7 1 3-1/2", 9.3#, L-80 CS-CB HYDRILPUP JOINT 2.992 9.71 43.49 53.2 8 1 3-1/2", 9.3#, L-80 CS-CB HYDRILPUP JOINT 2.992 2.37 41.12 43.49 9 1 3-1/2", 9.3#, L-80 CS-CB HYDRILPUP JOINT 2.992 2.74 38.38 41.12 10 1 CIW TUBING HANGER 0.75 37.63 38.38 CORRECTION: SLACKOFF 5.24' TO STACK OUT WEIGHT ON PACKER -5.24 42.87 37.63 ROTARY TABLE ELEVATION = 42.87' 42.87 0 42.87 0 0 ,.. 0 0 0 0 0 0 0 0 0 0 0l 0~ ol Ol 0 0 I"('F i V I-'1) o 0 OOT - 5 !992 o Aiaska 0il & Gas L;ons. L;ommis'~ io~ o 0 Anchorage o 0 0 ,,. 0 UNOCAL TUBULAR DETAIL 1 1 BELL WIRELINE RE-ENTRY GUIDE 0.73 12110.27 12111 2 1 2-7/8" 6.4#, N-80 PUP JOINT 2.441 6.09 12104.18 12110.27 3 1 "X" NIPPLE 1.08 12103.1 12104.18 4 1 2-7/8" 6.4#, N-80 PUP JOINT 2.441 5.08 12098.02 12103.1 5 1 XO 0.39 12097.63 12098.02 6 1 OTIS 7" PERMANENT PACKER 3.25 4.53 12093.1 12097.63 12093.1 0 0 0 0 0 0~ 0 0 0 0 0 0 0 01 0 0 0 0 0 0 0 0 0 0 0 0 0 RJ=Cl:{vl:n o o ~r~'T' _ ~ 1~10t) 0 Alaska 0il & ~as Cons. Commisslo, o gnohorago o 0 0 0 0 WELL #: 0-14 A-RD GRAYLING PLATFORM PAGE 1 of 1 DATE: JUNE 04, l~r2 AFE NO.: STRING: ISOLATION PACKER ASSEMBLY FOREMAN: WELL HISTORY TBUS G-14A REDRILL AFE 301406 2~27/92 2/28/92 2/29/92 R ¢EIV£D OCT - 5 ' 992 Alaska Oil & Gas Cons. Commissio~ Anchorags COMMENCE OPERATIONS ON TBUS G-14A REDRILL AT 0001 HOURS. RIG UP TO PUMP DOWN THE TUBING. TEST SURFACE LINES TO 3500 PSI. KILL WELL WITH 9.4 PPG NACL/FIW BRINE BY BULLHEADING 211 BBLS DOWN THE 3-1/2" TUBING AT 115 GPM WITH 2800 PSI. TUBING PARTED BELOW THE HANGER. PRESSURES TRACK ON THE 3-1/2" X 7" AND 7" x 9-5/8" ANNULUS. MONITOR WELL-ON SLIGHT VACUUM. ATTEMPT TO SET BACK PRESSURE VALVE - PROFILE THREADS GONE. NIPPLED DOWN THE TREE TO THE MASTER VALVE. LOOKED INSIDE THE WELLHEAD. VERIFIED THAT THE BACKPRESSURE VALVE THREADS WERE GONE AND THERE IS A PIECE OF JUNK PROTRUDING FROM THE TOP OF THE 7" CASING STUB INTO THE CENTER OF THE WELLBORE. PREPARED TO NIPPLE UP THE BOPE. CONTINUED NIPPLING DOWN THE PRODUCTION TREE. CONTINUED NIPPLING DOWN THE PRODUCTION TREE. MONITORED WELL - TAKING 0.9 BPH OF BRINE. CLEANED AND CHECKED LANDING JOINT THREADS IN THE TUBING HANGER. NIPPLED UP THE BOPE. INSTALLED THE LANDING JOINT. PRESSURE TESTED THE UPPER PIPE RAMS TO 3000 PSI AGAINST THE TUBING SPOOL. LEAKING OFF SLOWLY - APPEARS TO BE LEAKING THROUGH THE LANDING JOINT THREADS. PULLED THE TUBING HANGER WITH 30K OVERPULL. PICKED UP AND TIGHTENED THE KELLY. WASHED THE DCB BOWL AREA WITH THE KELLY AND SET THE TEST PLUG. TESTED THE CHOKE MANIFOLD, RAM PREVENTERS, AND FLOOR VALVES TO 300 PSI (LOW) AND 3000 PSI (HIGH). ATTEMPTED TO TEST THE ANNULAR - FAILED. CHANGED OUT THE ELEMENT AND TESTED TO 300 PSI (LOW) AND 2100 PSI (HIGH). OUTSIDE KILL LINE VALVE WOULD NOT TEST. RAN AN OVERSHOT DRESSED WITH A 4-3/4" GRAPPLE AND TAGGED THE TOF AT 76' TM - NO RECOVERY. RAN A 4-1/2" GRAPPLE - NO RECOVERY. SPEARED THE FISH AND RECOVERED 75' OF 3-1/2" TUBING. TUBING SEVERELY CORRODED AND SCALED. TOF AT 161' TM - TOP SPLINTERED AND ROLLED OVER. RAN A ROLLING DOG OVERSHOT WITH 19' OF EXTENSION - SLIPPED OFF FOR NO RECOVERY. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 2 OF 27 3/01/92 3/02/92 3/03/92 R'E¢ E i V E D OCT - 5 !99 A~a_-~,i)j} & Gas Oo~s. Gomm~ssio~ -"~--~- ~chorags MADE TWO RUNS WITH A ROLLING DOG OVERSHOT WITH NO RECOVERY. RAN IN WITH A 3-7/8" GRAPPLE TO 153' TM AND ENGAGED THE FISH. BACKED OFF AND RECOVERED 9' OF FISH. RAN IN WITH A 4-1/4" GRAPPLE AND ENGAGED THE FISH AT 162' TM - RECOVERED 122' OF FISH. RAN IN WITH A 3-1/2" GRAPPLE AND MILL CONTROL TO 282' TM. MILLED OVER AND ENGAGED THE FISH - BACKED OFF AND RECOVERED 1083' OF FISH. RAN IN WITH A 3-1/2" GRAPPLE AND ENGAGED THE FISH AT 1365' TM. PICKED UP 5k OVERPULL AND THE FISH PARTED - RECOVERED 313' OF FISH. TOP OF FISH IS SPLIT AND SPLINTERED. RAN IN WITH A 3-1/2" GRAPPLE TO 1650' TM. WORKED DOWN TO 1677' TM WITH NO APPARENT ENGAGEMENT. TRIPPED TO CHECK TOOLS - RECOVERED 5' OF FISH. MADE UP A 5-3/4" X 3- 1/2" HOLLOW MILL WITH 19' OF EXTENSION. RAN IN AND MILLED OVER THE TOF AT 1675' TM. RIG DOWN FOR 1.5 HOURS DUE TO ELECTRICAL PROBLEMS WITH THE DC-DC DRIVE. MILLED OVER THE FISH FROM 1675' TO 1682' THEN WASHED DOWN TO 1695'TM. RAN IN WITH A 3-1/2" HOLLOW MILL AND GRAPPLE. MILLED OVER THE FISH FROM 1675' TO 1678' TM THEN SLACKED OFF TO 1680' TM - NO RECOVERY. REMOVED THE GRAPPLE AND RAN IN TO THE TOP OF FISH AT 1675' DPM. MILLED OVER THE FISH TO 1682' DPM. RAN IN WITH A 3-1/2" GRAPPLE AND ENGAGED THE FISH AT 1682' DPM. BACKED OFF AND RECOVERED 1.3' OF FISH WITH THREADS ON BOTTOM. ESTIMATED 17' OF FISH MISSING IN THE HOLE IN PIECES. RAN IN WITH A 4-1/4" GRAPPLE AND ENGAGED THE COLLAR OF THE FISH AT AT 1683' DPM - BACKED OFF AND RECOVERED 2256' OF FISH (PIN LOOKING UP ON NEW TOF). RAN IN WITH A 3-1/2" GRAPPLE AND ATTEMPTED TO ENGAGE THE FISH AT 3932' DPM - NO SUCCESS. CIRCULATED BOTTOMS UP. TRIP FOR A BURNOVER SHOE. RIG DOWN FOR 0.5 HOURS DUE TO ELECTRICAL PROBLEMS WITH THE DC-DC DRIVE. COMPLETED TRIP OUT - RECOVERED 4 PIECES OF TUBING JUNK IN THE GRAPPLE. RAN IN WITH A 6" OD X 4-7/8" ID BURNOVER SHOE AND MILLED OVER THE FISH FROM 3932' TO 3967' DPM. RAN IN WITH A 3-1/2" GRAPPLE AND ENGAGED THE FISH AT 3933' DPM. WORKED RIGHT HAND TORQUE INTO THE STRING TO TIGHTEN THE CONNECTIONS. PULLED 200K (132K OVER UP WEIGHT). RIGGED UP DIALOG AND ATTEMPTED TO MAKE A 2.375" GAUGE RING RUN - SET DOWN AT THE TOP OF THE FISH. RIGGED DOWN DIALOG. RIGGED UP TO MAKE A DEEP TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY P~GE 3 OF 27 3/03/92 (cont) 3/04/92 3/05/92 RECEIVED OOT - § 1 92 Oil & 8as Cons. Commission ~chomos BACKOFF. HELD A SAFETY MEETING. APPLIED ONE ROUND OF LEFT HAND TORQUE AND PULLED 202K - FISH CAME LOOSE. PULLED SEVEN STANDS AND CIRCULATED OUT THE LIGHT FLUID THAT WAS IN THE ANNULUS. BUILT VOLUME AND MONITORED THE WELL. TRIPPED TO CHECK RECOVERY. CONTINUED LAYING DOWN THE 3-1/2" TUBING FISH. RECOVERED 11391' OF TUBING, ONE "XA" SLEEVE AND ONE BAKER SEAL ASSEMBLY. STRING PARTED ONE JOINT BELOW THE SEAL ASSEMBLY (BETWEEN THE PERMANENT PACKERS). RAN IN WITH THE 3-1/2" TUBING WORK STRING AND PULLED OUT LAYING DOWN SAME. LAID DOWN FISHING TOOLS. MADE UP A 6" BIT AND 7" CASING SCRAPER TO 15235' DPM. PICKED UP THE KELLY AND CIRCULATED DOWN TO 15246' DPM. CIRCULATED WELL CLEAN. CONTINUED TO CIRCULATE WELL CLEAN. PULLED OUT OF HOLE WITH THE BIT AND SCRAPER. RIGGED UP HLS WIRELINE. RAN IN WITH CBL/VDL/GR/CCL TO 1900' WLM - SET DOWN. TRIPPED TO CHECK TOOLS - FOUND TUBING DEBRIS IN THE BOW SPRING CENTRALIZER. RAN IN HOLE TO 5000' WLM AND LOGGED UP TO 2000' WLM. PIPE APPEARS TO BE FREE ABOVE 4500' WLM. RIGGED DOWN WIRELINE. MADE UP A CEMENT RETAINER ON 3-1/2" DRILL PIPE AND RAN IN HOLE. TAGGED THE "FB-I" PACKER AT 15246' DPM. PULLED UP TO 15243' DPM, CIRCULATED ONE DRILL PIPE VOLUME, AND SET THE RETAINER. BACKED OUT THE RUNNING TOOL AND STABBED BACK IN FOR AN INJECTIVITY TEST. APPLIED 1500 PSI TO THE BACKSIDE. ATTEMPTED TO BREAK DOWN THE PERFORATIONS WITH 6000 PSI - NO LEAKOFF. PULLED OUT OF THE RETAINER AND STABBED BACK IN. PRESSURED TO 6800 PSI - NO LEAKOFF. RESET THE STINGERAND REPRESSURED TO 6000 PSI - NO LEAKOFF. DISCUSSED ABANDONMENT OPTIONS WITH MIKE MINDER OF THE AOGCC. OBTAINED PERMISSION TO LAY A CEMENT PLUG ON TOP OF THE RETAINER AT 15243' DPM TO ABANDON THE HEMLOCK PERFORATIONS FROM 15304' TO 16492' MD. MIXED AND DISPLACED TO BALANCE 100 SXS (119 CU FT) "G" CEMENT WITH ADDITIVES MIXED TO 15.5 PPG. CEMENT IN PLACE AT 2250 HOURS. CALCULATED TOP OF CEMENT AT 14672' MD (571 LINEAR FT). PULLED UP TO 14406' DPM AND REVERSED CLEAN. TBUS ~-L4~ REDR~LL (iI~FE 30~406~) WELL H~STORY P~GE 4 OF 27 3/06/92 3/07/92 3/08/92 RECEIVED OCT - 5 !992 .Oil .a Gas Cons. Commission Anchorag~ PRESSURE TESTED THE CEMENT PLUG ON TOP OF THE CEMENT RETAINER AT 15243' MD. PULLED OUT OF HOLE LAYING DOWN THE EXCESS 3-1/2" DRILL PIPE. REMOVED THE BOPE STACK. REMOVED THE "DCB" TUBING SPOOL. INSTALLED A SPACER SPOOL. INSTALLED THE BOPE STACK. PRESSURE TESTED THE STACK BETWEEN THE 7" CASING AND THE CSO RAMS TO 3000 PSI. MADE UP 7" MECHANICAL CASING CUTTER. SPACED OUT AND CUT THE CASING AT 3720' DPM. PULLED OUT AND LAID DOWN THE CUTTER. CHANGED THE TOP PIPE RAMS TO 7" RAM BLOCKS AND TESTED SAME. MADE UP A GUIBERSON PACKOFF, SPEARAND BUMPER SUB ON 5" S-135 DRILL PIPE. ENGAGED THE 7" CASING WITH THE SPEAR. ATTEMPTED TO PULL THE 7" CASING FREE. SLIPS CAME FREE AT 157K OVERPULL. CONTINUED TO PULL UP TO 250K OVERPULL WITH APPROXIMATELY 1.3' OF PIPE MOVEMENT. RIGGED UP AND CIRCULATED THE CASING - HAD GOOD RETURNS. CIRCULATED AND WORKED STUCK CASING. RIGGED UP DIALOG FOR A FREEPOINT SURVEY. FOUND THE FOLLOWING READINGS: 1968'= 0% ; 1844'= 20% ; 1802'= 58% ; 1760'= 64% . MADE UP A 7" CEMENT RETAINER WITH A BRIDGE PLUG KIT ON 3-1/2" DRILL PIPE AND RAN IN HOLE. SET BRIDGE PLUG AT 3820' (100' BELOW 7" CUT) TO ISOLATE THE LOWER SECTION OF 7" CASING. TRIPPED FOR A 7" MECHANICAL CASING CUTTER. RAN IN AND CUT THE 7" CASING AT 1800' DPM. TRIPPED FOR A 7" CASING SPEAR WITH A GUIBERSON PACKOFF. ENGAGED THE CASING AND PULLED CASING UP HOLE 3' WITH 50K OVERPULL. CIRCULATED BOTTOMS UP THROUGH THE CUT AT 1800' DPM. PULLED OUT OF HOLE LAYING DOWN 7" CASING - JOINT #5 HAD A 1' SPLIT AT 10' BELOW THE COLLAR. RECOVERED 41 JOINT AND ONE CUTOFF FOR 1756' TOTAL. CHANGED UPPER PIPE RAMS TO 3-1/2" BLOCKS. LAID DOWN FISHING TOOLS. MADE UP A HYDRAULIC CASING CUTTER AND RAN IN TO 3725' DPM. CIRCULATED AND INCREASED FLUID WEIGHT TO 9.9 PPG. PRESSURE TESTED TO 1500 PSI THE 9-5/8" PACKOFF, SECONDARY SEAL, AND API RING AT THE TOP OF THE 13-5/8" 5M SHAFFER STARTING HEAD. LOCATED THE PREVIOUS CUT IN THE 7" CASING. ATTEMPTED TO CUT THE 9-5/8" CASING THROUGH THE 7" CASING AT 3720' DPM - DID NOT GET A GOOD INDICATION OF A CUT. ATTEMPTED TO CIRCULATE THE 13-3/8" x 9-5/8" ANNULUS AGAINST THE UPPER PIPE RAMS WITH 1500 PSI - NO SUCCESS. ATTEMPTED TO TBUS ~-L4& REDRILL (AFE 30L406&) WELL H~STORY PAGE 5 OF 27 3/08/92 (cont) 3/09/92 I 'EEEIVED OCT - 5 992 OJj & Gas Cor~s. Commission Anchorag= 3/10/92 PUMP DOWN THE 13-3/8" x 9-5/8" ANNULUS WITH 500 PSI - NO SUCCESS. TRIPPED TO CHECK CUTTER KNIVES - LOST ABOUT 1" OF LENGTH. REPLACED THE KNIVES AND RAN IN TO 3720' DPM. LOCATED THE OLD CUT AND ATTEMPTED TO CUT THE CASING STRINGS. TRIPPED TO CHECK KNIVES - NO SIGNIFICANT WEAR. ATTEMPTED TO CIRCULATE THE 13-3/8" x 9-5/8" ANNULUS AGAINST THE UPPER PIPE RAMS WITH 3000 PSI - NO SUCCESS. ATTEMPTED TO PUMP DOWN THE 13-3/8" x 9-5/8" ANNULUS WITH 1300 PSI - NO SUCCESS. HAD QUITE A BIT OF TROUBLE WITH THE BLIND SHEAR RAMS LEAKING - CHANGED TO BLIND ONLY BLOCKS. INSTALLED THE VBR BLOCKS IN THE TOP CAVITY OF THE DOUBLE GATE TO FREE UP A SET OF CARRIERS. NIPPLED DOWN THE BOPE AND REMOVED THE CIW "WF" CASING SPOOL. API RING GROOVE IN THE STARTING HEAD LOOKED GOOD -CLEANED UP THE FLANGE FACE. REMOVED THE 9-5/8" CASING PACKOFF AND WELDED THE CASING SLIPS TO THE CASING STUB. NIPPLED UP THE BOPE. TESTED AGAINST THE BLIND RAMS AND 13-3/8" CASING TO 1500 PSI. MADE UP A 9-5/8" CASING SPEAR AND PACKOFF. ENGAGED THE 9-5/8" CASING WITH THE SPEAR AND PACKOFF. WORKED THE PIPE WITH 220K TO 420K OVERPULL. FREE POINT AT 1017' BY STRETCH CALCULATION. PRESSURED THE 9-5/8" CASING TO 1100 PSI WHILE WORKING PIPE - NO MOVEMENT. RIGGED UP DIALOG AND RAN A FREEPOINT SURVEY. PIPE FREE AT 850'. PIPE 100% STUCK AT 860'. RIH WITH 502' 3-1/2" TBG ON 3-1/2" DRILL PIPE AND TAGGED THE BRIDGE PLUG AT 3820' DPM. RECEIVED APPROVAL FOR THE CEMENT PLUG FROM MIKE MINDER OF THE AOGCC. MIXED AND PUMPED 57 CU FT OF CLASS G CEMENT MIXED TO 15.8 PPG. CALCULATED TOP OF THE CEMENT AT 3550'. PULLED UP TO 3500' DPM AND REVERSE CIRC. RIH WITH AN 8-1/2" BIT AND TAGGED THE TOP OF THE 7" CASING AT 1800' DPM. CIRC. PRESSURE TESTED THE CASING AND CEMENT PLUG TO 1500 PSI, OK. POOH. RIGGED UP DIALOG TO RUN STUCK PIPE LOG (ACOUSTIC) IN THE 9-5/8" CASING FROM 1800' TO 400'. RIH WITH A MECHANICAL CUTTER AND ATTEMPTED TO CUT THE CASING AT 800', NEG. RIH AND CUT THE 9-5/8" CASING AT 800' DPM, QUESTIONABLE CUT. POOH. ENGAGED THE 9-5/8" CASING JUST BELOW THE WELL HEAD AND ATTEMPTED TO PULL FREE. RIH AND CUT THE CASING AT 810' DPM. ENGAGED THE 9-5/8" CASING JUST BELOW THE WELL HEAD. RECOVERED TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 6 OF 27 3/10/92 (cont) 3/11/92 3/12/92 3/13/92 RECEIVED OOT - ,5 992 AJaska Oil & Gas Cons. Commission Anchorage 765' OF 9-5/8" CASING. RIH WITH A 12-1/4" BIT AND CLEANED OUT TO 810' DPM. CIRC. POOH. RAN A 64 ARM CALIPER LOG FROM 810' TO THE WELLHEAD, CASING OK. TESTED THE BOPE TO 500 PSI LOW AND 3000 PSI HIGH. TESTED THE VBR RAMS WITH BOTH 3-1/2" AND 5" DRILL PIPE. TESTED THE ANNULAR PREVENTER TO 500 PSI LOW AND 2100 PSI HIGH. RIH WITH 9-5/8" CASING CUTTER. CONT'D RIH WITH 9-5/8" CASING CUTTER AND ATTEMPTED TO CUT THE 9-5/8" CASING AT 882', NEG. POOH. RIH AND CUT THE CASING AT 885'. POOH. RIH WITH A SPEAR AND ENGAGED THE FISH AT 810', RECOVERED 74' OF 9-5/8" CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 885' DPM. POOH. PICKED UP 9-5/8" MECHANICAL CUTTER AND CUT THE 9- 5/8" CASING AT 920' AND 1010'. POOH. RIH WITH A 9-5/8" SPEAR AND JARRING ASSEMBLY. ENGAGED FISH AT 885' AND JARRED WITH 225K OF OVERPULL. CONT'D TO JAR ON FISH AT 885'. NO MOVEMENT. RELEASED FROM FISH AND POOH. RIH WITH CASING CUTTER AND ATTEMPTED TO ENTER CASING STUB, NEG. POOH. LEFT DRAG BLOCK IN THE HOLE. RIH AND CUT THE 9-5/8" CASING AT 907'. POOH. RIH AND ENGAGED THE FISH AT 885'. JARRED FREE. POOH AND RECOVERED 20' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 907'. RIH AND ENGAGED FISH AT 907'. JARRED FISH, NO RECOVERY, DID JAR FISH UP THE HOLE TO 896'. RIH AND ENGAGED FISH, JARRED FISH, NO RECOVERY. LOST GRAPPLE IN THE HOLE. SERVICED RIG. MADE TWO TRIPS WITH A MAGNET AND RECOVERED A PIECE OF THE GRAPPLE. RIH WITH A 9-5/8" CASING SPEAR AND ENGAGED THE FISH AT 907'. JARRED FISH, NO RECOVERY. RIH WITH AN 11- 3/4" x 10-3/4" BURN SHOE AND 4 JOINTS OF 11- 3/4" WASH PIPE. ATTEMPTED TO ROTATE OVER THE FISH AT 89~, NEG. POOH. RIH WITH THE BURN SHOE AND 1 JOINT OF WASH PIPE. ATTEMPTED TO WASH OVER THE FISH, MADE 8" POOH. RIH WITH A CRIPPLED BURN SHOE AND 1 JOINT OF WASH PIPE. ATTEMPTED TO WASH OVER THE FISH AT 896', NEG. TBUS G-14A REDRILL (~FE 301406A) WELL HISTORY PAGE 7 OF 27 3/14/92 3/15/92 3/16/92 3/17/92 RECEIVED OCT - § 199 Alaska Oil & Gas Cons. Comm'tssio~ RIH WITH A BOWEN ITCO SPEAR AND ATTEMPTED TO ENGAGE FISH, NEG. RIH WITH A MODEL B SPEAR AND ENGAGED FISH, JARRED, NO RECOVERY. POOH. RIH WITH A MODEL B SPEAR AND ENGAGED FISH, NO RECOVERY. RIH AND ENGAGED FISH AT 896', JARRED DOWN TO 904'. JARRED FISH FREE. POOH. RECOVERED 15' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 920'. POOH. RIH AND ENGAGED FISH AT 920'. SPEAR PULLED LOOSE. ATTEMPTED TO ENGAGE TWICE MORE, SAME RESULTS. POOH. POOH. RIH AND ENGAGED THE FISH AT 920'. JARRED FISH, NO MOVEMENT, JARS FAILED. RIH AND ATTEMPTED TO CUT THE CASING AT 940', NEG. POOH. RIH AND CUT THE 9-5/8" CASING AT 940'. POOH. RIH AND ENGAGED THE FISH AT 920'. RECOVERED 19' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 940'. POOH. ENGAGED FISH AT 940' AND JARRED UP 5'. JARRED DOWN 3'. RECOVERED 20' OF CASING. RIH WITH A BOWEN SPEAR AND ATTEMPTED TO ENGAGE FISH AT 960'. POOH. RIH WITH AND CUT THE 9-5/8" CASING AT 984'. POOH. ENGAGED FISH AT 960' AND JARRED LOOSE. RECOVERED 24' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 984'. RIH AND ENGAGED FISH AT 984' UNABLE TO SET THE JARS OFF. RELEASED FROM FISH AND POOH. RIH AND ENGAGED FISH AT 984', JARRED FREE, RECOVERED 26' OF CASING. RIH WITH 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 1010'. CIRC. POOH. RIH WITH A CASING CUTTER. TAGGED FILL AT 1485'. CUT CASING AT 1062'. CIRC. POOH. ENGAGED FISH AT 1010'. JARRED ON FISH AT 1010'. JARS PULLED IN TWO AT THE TOP OF THE MANDREL. SERVICED RIG. RIH AND ATTEMPTED TO ENGAGE THE MANDREL, NEG. POOH. RIH AND ENGAGED THE FISH RELEASED FISH AND POOH RECOVERING JARS AND SPEAR. RIH WITH A CASING CUTTER AND CUT THE 9-5/8" CASING AT 1025'. ENGAGED FISH AT 1010' AND JARRED FREE, RECOVERED 15' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT TO 1025'. RIH AND ENGAGED FISH AT 1025', RECOVERED 36' OF CASING. RIH WITH A 12-1/4" BIT AND CASING SCRAPER AND CLEANED OUT CEMENT TO 1062'. TBUS G-~4A REDRILL (AFE 30~406A) WELL HISTORY PAGE 8 OF 27 3/18/92 3/19/92 3/20/92 3/21/92 3/22/92 RECEIVED ~S~ ~i[ & Gas Cons, POOH. PRESSURE TESTED THE BOPE TO 300 PSI LOW AND 3000 PSI HIGH. PRESSURE TESTED THE ANNULAR PREVENTER TO 300 PSI LOW AND 2100 PSI HIGH. RIH WITH AN 8-1/2" BIT AND CLEANED OUT INSIDE THE 9-5/8" CASING FROM 1475' -1800'. CIRC. POOH. CUT THE 9-5/8" CASING AT 1770' AND 1342'. POOH. ENGAGED THE 9-5/8" CASING FISH AT 1062'. JARRED ON FISH, NO PROGRESS. RAN A FREE POINT LOG WHICH INDICATED PARTIALLY FREE PIPE AT 1100'. RELEASED FROM FISH AND POOH. RIH AND CUT 9- 5/8" CASING AT 1102' AND 1142'. ATTEMPTED A CUT AT 1182', NEG. POOH. ENGAGED FISH AT 1062'. JARRED FISH UP THE HOLE 1', JARS FAILED. JARRED DOWN, NO MOVEMENT. RIH WITH AN 8-1/2" BIT TO 1050'. POOH. RAN A CASING INSPECTION LOG FROM 1056' TO SURFACE, OK. RIH WITH AN 8-1/2" BIT TO 1798' AND CHANGED OVER TO 9.7 PPG GEL MUD. POOH. CONT' POOH. RIH WITH A FLAT BOTTOM MILL AND MILLED 9-5/8" CASING FROM 1062' TO 1088'. CIRC. POOH. RIH AND ENGAGED FISH AT 1088', RECOVERED 15' OF CASING. RIH WITH A 12-1/4" MILLING ASSEMBLY AND CLEANED CEMENT FROM 1088'-1103'. MILLED 9-5/8" CASING FROM 1103' TO 1106'. CONT'D MILLING 9-5/8" CASING FROM 1106' TO 1110'. POOH. RIH AND ENGAGED FISH AT 1110', RECOVERED 32' OF CASING. RIH WITH A 12-1/4" MILLING ASSEMBLY AND MILLED 9-5/8" CASING FROM 1142'-1152'. CIRC. RIH AND CUT 9-5/8" CASING AT 1186' AND 1228'. POOH. ENGAGED FISH AT 1152', RECOVERED 34' OF CASING. RIH WITH A 12-1/4" MILLING ASSEMBLY AND CLEANED OUT CEMENT FROM 1152' TO 1186'. MILLED 9-5/8" CASING FROM 1186' TO 1191'. CIRC. POOH. RIHAND ATTEMPTED TO ENGAGE FISH AT 1191', NEG. POOH. PRESSURE TESTED THE 9-5/8" CASING TO 1000 PSI, OK. RIH AND ENGAGED FISH AT 1191', RECOVERED 37' OF CASING. POOH. RIH WITH A 12-1/4" MILLING ASSEMBLY AND CLEANED CEMENT FROM 1188'-1228'. MILLED 9-5/8" CASING FROM 1228' TO 1233'. CIRC. POOH. RIH WITH A 12-1/4" MILL AND MILLED 9-5/8" CASING FROM 1233' TO 1278'. POOH. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 9 OF 27 3/23/92 3/24/92 3/25/92 3/26/92 OCT - 5 :.Ojl.a Gas (:;ohs. ', Anchorage MILLED 9-5/8" CASING FROM 1278' TO 1312'. CIRC. ENGAGED FISH AT 1312', RECOVERED 30' OF CASING. RIH WITH A 12-1/4" MILL AND CLEANED OUT CEMENT FROM 1312' TO 1342'. MILLED 9-5/8" CASING FROM 1342' TO 1354'. CIRC. POOH. RIH WITH AND CUT THE CASING AT 1390', 1429', AND 1469'. THE CUT AT 1469' IS QUESTIONABLE. POOH. ENGAGED FISH AT 1354', RECOVERED 34' OF 9-5/8" CASING. RIH WITH A 12-1/4" MILLING ASSEMBLY AND CLEANED OUT CEMENT FROM 1354' TO 1388'. MILLED 9-5/8" CASING FROM 1388' TO 1394'. CIRC. POOH. RIH AND ENGAGED FISH AT 1394', RECOVERED 32' OF CASING. MILLED 9-5/8" CASING FROM 1427' TO 1434'. CIRC. POOH. RIH AND ENGAGED FISH AT 1434', RECOVERED 34' OF CASING. RIH WITH A 12-1/4" MILLING ASSEMBLY AND CLEANED OUT CEMENT FROM 1434' TO 1469'. MILLED 9-5/8" CASING FROM 1469' TO 1474'. POOH. RIH AND WITH A CASING CUTTERAND TAGGED AT 1506', ATTEMPTED TO CUT 9-5/8" CASING AT 1504', NEG. POOH. RIH WITH A 12-1/4" MILL AND MILLED 9-5/8" CASING FROM 1474' TO 1478'. MILLED 9-5/8" CASING FROM 1478' TO 1531'. CIRC. POOH. TESTED THE CASING TO 1000 PSI, OK. TESTED THE BOPE TO 300 PSI LOW AND 3000 PSI HIGH. TESTED THE ANNULAR PREVENTER TO 300 PSI LOW AND 2100 PSI HIGH. RIH AND MILLED 9-5/8" CASING FROM 1531' TO 1546', HIGH TORQUE. POOH. MILL IN GAUGE. RIH WITH THE SAME MILL. RAN IN AND MILL CASING FROM 1546' TO 1550'. TRIP TO CHECK MILL - OD WEAR HAD ROUNDED OFF CUTTING STRUCTURE 2" UP FROM THE FACE OF THE MILL (5/16" UNDERGAUGE AT THE CUTTERS). RAN IN HOLE WITH MILL #6 - TAKING WEIGHT AT 1533'. PRESSURE TESTED CASING - HOLE TAKING FLUID AT 3.5 BPM WITH 420 PSI. WORKED THRU TIGHT SPOT AT 1533'. MILLED CASING AT 1550' -NO PROGRESS. TRIP TO CHECK TOOLS - SEVERE CENTER WEAR. PRESSURE TESTED CASING - PUMPED AWAY. RIGGED UP DIALOG AND RAN CALIPER LOG FROM 1550' TO SURFACE. RAN GYRO SURVEY FROM 1550' TO SURFACE. LAY DOWN 3-1/2" DRILL PIPE FROM DERRICK. PICK UP AND BREAK DOWN TRI- STATE FISHING TOOLS. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 10 OF 27 3/27/92 3/28/92 REEEIVED OCT - 5 ~laS~ fiji .& Gas Cons. ~, ~chorag~ MAKE UP CEMENT RETAINER AND RIH TO 1520'. BREAK CIRCULATION AND TEST LINES TO 3000 PSI. PERFORM INJECTIVITY TEST - 1 BPM AT 650 PSI. BLED TO 575 PSI IN 2 MINUTES AND STABILIZED. TESTED BACKSIDE TO 500 PSI. MIXED AND PUMPED 200 SXS "G" CEMENT WITH ADDITIVES AT 17 PPG FOLLOWED BY 5 BBLS FIW AND DISPLACED WITH 22 BBLS OF 9.9 PPG MUD. SQUEEZED THRU THE RETAINER WITH A FINAL RATE OF 1 BPM AT 1000 3/27/92 (cont) PSI. PRESSURE BLED TO 750 PSI IN 3 MINUTES AND STABILIZED. CIP AT 0435 HRS. REVERSED OUT A TRACE OF CEMENT AND 5 BBLS OF WATER. TRIPPED OUT AND LAID DOWN THE SETTING TOOL. RIGGED UP HLS AND PERFORATED 8 SQUEEZE HOLES FROM 1464' TO 1467'. MADE UP A CEMENT RETAINER ON DRILL PIPE. RAN IN AND SET THE RETAINER AT 1420'. RIGGED UP CEMENTERS AND TESTED SURFACE LINES TO 3000 PSI. PERFORMED INJECTIVITY TEST - 1.2 BPM AT 750 PSI WITH NO RETURNS TO SURFACE. ATTEMPTED TO TEST THE BACKSIDE TO 500 PSI - NO GOOD. PUMPED DOWN THE DRILL STRING WITH RETURNS UP THE ANNULUS. TRIP OUT WITH THE SETTNG TOOL. TEST CASING -TAKING FLUID AT 500 PSI. RAN IN WITH AN RTTS PACKER AND SET SAME AT 1408' WITH THE TAIL AT 1419'. TESTED THE BACKSIDE TO 1000 PSI. PERFORM INJECTIVITY TEST. RESET RTTS PACKER AT 1377'. ATTEMPTED TO SQUEEZE -LOCKED UP WITH 2000 PSI WHEN THE CEMENT HIT THE RETAINER AT 1420'. REVERSED THE DRILL PIPE AND PULLED THE PACKER LOOSE. CIRCULATED ONE HOLE VOLUME THE LONG WAY. TRIPPED FOR A 12-1/4" BIT AND BOOT BASKET. WASHED FROM 1370' TO 1420'. DRILLED RETAINER AT 1420' AND PUSHED SAME TO 1517'. CIRCULATED WELL CLEAN. CLEANED CEMENT OUT OF THE FLOWLINE. CONTINUED TO CLEAN OUT CEMENT PLUGGED FLOWLINE. TRIPPED FOR RTTS PACKER WITH BYPASS AND TAIL ASSY. SET RTTS AT 1416' WITH THE TAIL AT 1437'. TESTED THE BACK SIDE TO 1000 PSI. ESTABLISHED INJECTIVITY WITH THE RIG PUMPS. PULLED PACKER LOOSE AND RESET AT 1376'. TESTED SURFACE LINES TO 3000 PSI. ESTABLISHED AN INJECTION RATE OF 1.5 BPM WITH 950 PSI. MIXED AND PUMPED 26.5 BBLS OF "G" CEMENT WITH ADDITIVES AT 17 PPG FOLLOWED BY 10 BBLS FIW AND DISPLACED WITH 20.5 BBLS OF 9.7 PPG MUD. CLOSED THE PACKER BYPASS AND STARTED INJECTING SLURRY AT 1.5 BPM WITH 550 PSI. PRESSURE INCREASED TO 950 PSI AT 1/2 BPM WITH 6.5 BBLS AWAY. PRESSURE LOCKED UP TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 11 OF 27 3/28/92 (cont) 3/29/92 3/30/92 RECEIVED OOT - § 199: Alaska Oil & Gas Cons. CommisSion Anohorag~ AT 1400 PSI. BLED BACK TO DISPLACEMENT TANK TO CLEAR THE OBSTRUCTION. CONTINUED THE DISPLACEMENT AT 1 BPM WITH 600 PSI. HAD A GRADUAL BUILD TO A FINAL SQUEEZE PRESSURE OF 950 PSI AT 0.9 BPM. SHUT DOWN THE PUMPS AND THE PRESSURE BLED TO 550 PSI IN 12 MINUTES. CEMENT IN PLACE AT 0910 HRS. CONTINUED TO MONITOR PRESSURE.- BLED TO 225 PSI IN 4 HOURS. BLED BACK THE REMAINING PRESSURE, RELEASED PACKER AND CIRCULATED BOTTOMS UP. TRIP FOR CLEANOUT ASSEMBLY. DRILLED FIRM CEMENT FROM 1434' TO 1465' AND LESS FIRM CEMENT FROM 1465' TO 1517'. CIRCULATE WELL CLEAN. TRIP FOR WIRELINE GUNS. PERFORATE SQUEEZE HOLES FROM 1388' TO 1390' (TWO MISFIRES DUE TO BAD CAPS). CLOSED BLIND RAMS AND PERFORMED INJECTIVITY TEST - CASING HELD 1000 PSI. PREPARED TO RUN CEMENT BOND LOG. RAN CCL/CBL FROM 1506' TO SURFACE. MADE UP SECTION MILL AND RAN IN HOLE. MILLED SECTION IN 13-3/8" CASING FROM 1390' TO 1460'. CIRCULATED WELL CLEAN. TRIPPED TO CHANGE TOOL TO UNDERREAMER ARMS. RAN IN HOLE WITH UNDERREAMERAND ATTEMPTED TO BREAK CIRCULATION AT THE TOP OF THE WINDOW -MILL PLUGGED. TRIPPED TO UNPLUG TOOL -FILLED WITH METAL SHAVINGS AND CEMENT. RABBITED DRILL PIPE IN HOLE BREAKING CIRCULATION EVERY 4 STANDS. UNDERREAMED SECTION TO 20" FROM 1390' TO 1460'. CIRCULATED WELL CLEAN. TRIPPED FOR 5 STAND TUBING TAIL ON OEDP. CONDUCT A LEAKOFF TEST ON 13-3/8" SHOE -TESTED TO 18.4 PPG EMW (0.96 PSI/FT). CONTINUED IN HOLE AND WORKED INTO THE STUB AT 1460'. CIRCULATED AND CONDITIONED MUD AT 1517'. LAID IN A BALANCED KICKOFF PLUG AND SQUEEZED THE CASING SHOE AS FOLLOWS: PUMPED 10 BBLS FIW; 30 BBL 2% CAUSTIC FIW; 10 BBLS FIW; 59 BBLS "G" CEMENT WITH ADDITIVES MIXED TO 17 PPG; 4.5 BBL FIW; AND 16 BBLS DISPLACEMENT MUD. PULLED OUT OF CEMENT TO 1142' AND REVERSED OUT 30 BBLS OF WATER. SQUEEZED AWAY 10 BBLS CEMENT AT 1/4 BPM AGAINST THE UPPER PIPE RAMS WITH 920 PSI. PRESSURE BLED TO 800 PSI IN 6 MINUTES AND STABILIZED. CEMENT IN PLACE AT 1035 HRS. WOC. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 12 OF 27 3/31/92 4/01/92 1410' 4/02/92 1592' RECEIVED OOT - § 1992 AJaska 0i~ & Gas Cor~s. Oommissio~ A~chorag.-., 4/03/92 2680' CONTINUED TO WAIT ON CEMENT - PRESSURE STABILIZED AT 310 PSI. BLED OFF SQUEEZE PRESSURE AND TRIPPED FOR CLEANOUT ASSEMBLY. RIH AND DRILLED SOFT TO FIRM CEMENT FROM 1306' TO 1370'. CIRCULATED WELL CLEAN. PULLED OUT LAYING DOWN DRILL PIPE AND COLLARS. TEST CASING TO 1000 PSI FOR 15 MINUTES. NIPPLED UP WEAR BUSHING HOLD DOWN FLANGE ON TOP OF THE 13-3/8" CASING HEAD. REMOVED 27-1/2" ROTARY TABLE SKID. INSTALLED 37-1/2" ROTARY TABLE SKID. INSTALLED A NEW STABILIZATION PLATE AROUND THE 13-3/8" CASING AT THE TOP OF THE 17-3/4" CASING STUB. REINSTALLED THE BOARD FLOOR AROUND THE ROTARY TABLE. CHANGED THE TOP PIPE RAMS TO VBRRAM BLOCKS. TESTED BOPE: FLOOR VALVES AND RAM PREVENTERS TO 300 PSI 3/31/92 (cont) (LOW) AND 3000 PSI (HIGH); ANNULAR PREVENTER TO 300 PSI (LOW) AND 3000 PSI (HIGH). OUTSIDE KILL LINE VALVE FAILED TO TEST. REPLACED VALVE AND RETESTED. FINISHED TESTING BOPE. SET WEAR BUSHING. MADE UP BIT #3 ON BHA #1 (12-1/4" STEERABLE MOTOR ASSY). RAN IN HOLE PICKING UP HWDP. CLEANED OUT HARD CEMENT FROM 1370' TO 1394'. PROGRAMED THE TELECO SURFACE EQUIPMENT TO DISPLAY TOOL FACE. TIME DRILLED OFF THE PLUG FROM 1394' TO 1410'. TIME DRILLED OFF THE PLUG FROM 1410'TO 1486'. CIRCULATED WELL CLEAN. PULLED TO SHOE AND PERFORMED A LEAKOFF TEST. PUMPED INTO FORMATION AT 0.25 BPM WITH 795 PSI WITH 10.1 PPG MUD. LOT = 20.6 PPG EMW. CLEANED MUD PITS. RAN IN TO 1486' AND CHANGED OVER TO 10.6 PPG PHPA MUD SYSTEM. DRILLED 12-1/4" HOLE FROM 1486' TO 1516'. ATTEMPTED TO RUN SCIENTIFIC GYRO CHECK SHOT - WOULD NOT GO THRU JARS. CIRCULATE AND BUILD SURFACE VOLUME. TRIP FOR BHA CHANGE. MADE UP BIT #4 ON BHA #2 (STEERABLE MOTOR). RAN IN HOLE TO 1516'. RAN GYRO CHECK SHOT AT 1506'. DRILLED FROM 1516' TO 1581'. RAN GYRO SURVEY WITH MULTIPLE SURVEYS THRU THE KICKOFF POINT. DRILLED FROM 1581' TO 1592'. DIRECTIONALLY DRILLED AND SURVEYED 12-1/4" HOLE FROM 1592' TO 2426'. CIRCULATED AND CONDITIONED MUD TO REMOVE CUTTINGS GAS (2100 UNIT - MAX). SHORT TRIPPED TO 1910' - HOLE GOOD (180 UNITS TRIP GAS). DRILLED 12- 1/4" HOLE FROM 2426' TO 2680'. CLEAN FLOW LINE AND CIRCULATED BOTTOMS UP FOR TRIP. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 13 OF 27 4/04/92 3353' TRIPPED FOR BIT AND BHA. MADE UP BIT #5 ON BHA #3 (LOCKED UP ROTARY) AND RAN IN HOLE. DRILLED 12-1/4" HOLE FROM 2680' TO 2977'. UNPLUGGED FLOW LINE. CIRCULATED AND CONDITIONED MUD. DRILLED FROM 2977' TO 3353'. CIRCULATED BETWEEN CONNECTIONS TO CONTROL CUTTINGS AND MUD PROPERTIES. CLEANED MUD DITCH. MADE A SHORT TRIP TO 2662'. TIGHT FROM 3160' TO 3120' AND 3020' TO 2840' WITH SOME SWABBING. 4/05/92 4001' RIH TO 3353' AND CIRCULATED BOTTOMS UP - 450 UNITS OF TRIP GAS. DRILLED 12-1/4" HOLE FROM 3353' TO 3849'. CIRCULATED WELL CLEAN FOR TRIP. TRIP FOR BIT AND BHA CHANGE. TIGHT HOLE FROM 2628' TO 2640'. MADE UP BIT #6 ON BHA #4 AND RAN IN HOLE. DRILLED 12-1/4" HOLE FROM 3849' TO 4001'. 4/06/92 4800' DRILLED 12-1/4" HOLE FROM 4001' TO 4464'. CIRCULATED WELL CLEAN FOR TRIP. TRIP FOR BHA CHANGE. MADE UP BIT #6RR ON BHA # 5 AND RAN IN HOLE. DRILLED 12-1/4" HOLE FROM 4464' TO 4800'. 4/07/92 5120' DRILLED 12-1/4" HOLE FROM 4800'-4931'. UNPLUGGED FLOW LINE. DRILLED 12-1/4" HOLE FROM 4931'-5075'. POOH. PRESSURE TESTED BOPE TO 300 PSI LOW AND 3000 PSI HIGH. TESTED THE ANNULAR TO 300 PSI LOW AND 3100 PSI HIGH. RIH WITH A ROTARY ASSEMBLY (PDC BIT) AND DRILLED FROM 5075' -5120'. 4/08/92 5658' DRILLED 12-1/4" HOLE FROM 5120' TO 5196' (PDC BIT). CIRC. POOH. RIH WITH A ROTARY ASSEMBLY (INSERT BIT). DRILLED 12-1/4" HOLE FROM 5196'-5658'. 4/09/92 6077' DRILLED 12-1/4" HOLE FROM 5658'-6007'. CIRC. WIPER TRIP TO 5162'. DRILLED 12-1/4" HOLE FROM 6007'-6077'. DRILL CUTTINGS LINE PLUGGED. CIRC. WIPER TRIP TO 3714'. 4/10/92 6340' RECEIVED CONT'D THE WIPER TRIP TO 3714'. DRILLED 12- 1/4" HOLE FROM 6077' - 6133'. THE #3 ENGINE WENT DOWN ON OVERHEAT. DRILLED FROM 6133' - 6327'. CIRC. POOH. RIH WITH A STEERABLE ASSEMBLY (PDC BIT). DRILLED FROM 6327'- 6340'. MUD MOTOR FAILED, COULD NOT GET A DIFFERENTIAL PRESSURE. CIRC. POOH. Alaska Oil & Gas Cons. Commission Anchorag8 TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 14 OF 27 4/11/92 6611' CONTINUED POOH. RIH WITH A STEERABLE ASSEMBLY (INSERT BIT). DRILLED 12-14/" HOLE FROM 6349'-6611' (CORRECTION RUN). 4/12/92 6950' DRILLED 12-1/4" HOLE FROM 6611'-6659' . WIPER TRIP TO 5967'. DRILLED 12-1/4" HOLE FROM 6659 ' - 6950 ' (ROTATED THE STEERABLE SYSTEM). 4/13/92 7027' DRILLED 12-1/4" HOLE FROM 6950'-6976'. CIRC. POOH. RIH WITH A ROTARY ASSEMBLY AND A PDC BIT. REAMED FROM 6897' - 6976'. DRILLED 12-1/4" HOLE FROM 6976' -7027'. DRILLED THE FIRST TWO FEET AT 5 FPH, 40' AT 30 FPH AND THE LAST 9' AT 1-2 FPH. CIRC. POOH. 4/14/92 7295' CONT'D POOH. TESTED BOPE TO 300 PSI LOW AND 3000 PSI HIGH, OK. TESTED THE ANNULAR TO 300 PSI LOW AND 2100 PSI HIGH, OK. RIH WITH A ROTARY ASSEMBLY AND A BUTTON BIT. DRILLED 12-1/4" HOLE FROM 7027' -7295'. 4/15/92 7645' DRILLED 12-1/4" HOLE FROM 7295 - 7356'. CIRC. WIPER TRIP FROM 7356' TO 6054'. DRILLED 12-1/4" HOLE FROM 7356' - 7633'. CIRC. WIPER TRIP FROM 7633' TO 6486'. DRILLED 12-1/4" HOLE FROM 7633' - 7645'. 4/16/92 7840' DRILLED 12-1/4" HOLE FROM 7645' TO 7840'. CIRCULATED BOTTOMS UP AND TRIPPED OUT OF HOLE FOR WIRELINE LOGS. BASED ON MUD LOG CORRELATION, AN ADDITIONAL 110' WILL NEED TO BE DRILLED TO REACH THE CASING POINT. HAD SOME TIGHT HOLE FROM 7555' TO 7276' AND AT 5950'. PREPARED TO RIG UP HLS. HLS HAD AN ELECTRICAL SHORT IN THEIR WIRELINE. STRUNG BLOCKS TO 10 LINES FOR CASING JOB WHILE WAITING ON HLS. CONTINUED TO WAIT ON HLS. 4/17/92 7840' E EIVED O0T - 5 992 .Oil & Gas Cons. Commission" Anchorag~ CONTINUED TO WAIT ON HLS TO REPAIR SHORT IN WIRELINE - RIG DOWN FOR 7 HOURS. FOUND SHORT IN ONE OF THE PLUG-IN CONNECTORS ON THE SPOOL. MADE UP TOOLS FOR LOGGING SUITE #1. RAN HRI/GR/SP/BCS FROM 7841' WLM TO SHOE AT 1400' - HAD TROUBLE WITH THE SONIC TOOL ABOVE 5000' WLM. MADE UP LOGGING SUITE #2. RAN DIL/SDL/DSN/GR/CAL IN HOLE AND TAGGED UP AT 7841' WLM. LOGGED REPEAT SECTION. RAN BACK TO BOTTOM AND BEGAN LOGGING UP - HAD PROBLEM WITH THE LOAD LINE SENSOR. TRIPPED TO REPAIR CONTROL HEAD. RERAN SUITE #2 TO BOTTOM AND BEGAN LOGGING UP. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 15 OF 27 4/18/92 7936' 4/19/92 7970' 4/20/92 7970' 4/21/92 8215' RECEIVED OOT - § AJaska Oil & Gas Cons. Commission Anchorag~ FINISHED RUNNING LOGGING SUITE #2. CHANGED OUT TOOLS FOR LOGGING SUITE #3. RAN IN HOLE SIX ARM DIPMETER/GR/CAL AND TAGGED UP AT 7841' WLM. LOGGED INTERVAL FROM 7841' WLM TO 1400' (13-3/8" WINDOW). MADE UP BIT #8RR ON BHA #12 AND RAN IN HOLE TO 7840'. DRILLED 12-1/4" HOLE FROM 7840' TO 7936'. DRILLED 12-1/4" HOLE FROM 7936' TO 7970'. CIRCULATED AND CONDITIONED MUD FOR CASING. TRIP OUT FOR CASING - HAD TIGHT HOLE AND SWABBING FROM 7852' TO 7606'. MADE A 10 STAND WIPER TRIP. CIRCULATED AND CONDITIONED MUD. TRIPPED OUT OF HOLE AND LAID DOWN THE BHA. INSTALLED 9-5/8" RAM BLOCKS AND TESTED DOOR SEALS TO 2500 PSI. RIGGED UP CASING EQUIPMENT. RUN 9-5/8" 47# N-80 CASING. CONTINUED RUNNING 9-5/8" CASING AND TAGGED BOTTOM AT 7970'. CIRCULATED AND CONDITIONED MUD FOR THE CEMENT JOB. RECIPROCATED CASING 30' - UP WT: 450K / DOWN: 175K. CEMENTED 9- 5/8" CASING AS FOLLOWS: 5 BBLS 11 PPG DUAL SPACER; TESTED SURFACE LINES TO 2000 PSI; 35 BBL 11 PPG DUAL SPACER; 10 BBL FIW; 20 BBL 9.8 PPG SUPERFLUSH; 10 BBL FIW; BOTTOM PLUG; 1800 SXS (2502 CU FT) TRINITY LITE CEMENT WITH ADDITIVES MIXED AT 13 PPG; 1150 SXS (1322 CU FT) "G" CEMENT WITH ADDITIVES MIXED AT 15.8 PPG; TOP PLUG; AND 580 BBL MUD DISPLACEMENT. DID NOT BUMP PLUG. FLOATS HELD. MIXED AND PUMPED CEMENT AT 6 BPM. DISPLACED AT 10 BPM. HAD FULL RETURNS. RECIPROCATED CASING THRU THE FIRST 200 BBLS OF DISPLACEMENT. CIP AT 0915 HRS. WASHED OUT BOPE AND CASING HEAD. WAITED ON CEMENT FOR 7.5 HOURS. PICKED UP BOPE. PULLED 320K AND SET SLIPS. CUT OFF 9-5/8" CASING AND INSTALLED SHAFFER SEAL ASSEMBLY. INSTALLED CAMERON "DCB-S" SPOOL. PRESSURE TESTED SEALS AND API RING TO 3000 PSI. NIPPLED UP BOPE. CHANGED UPPER PIPE RAMS TO 5" RAM BLOCKS. REPLACED OUTSIDE KILL LINE VALVE. TESTED 9-5/8" CASING TO 3000 PSI AGAINST THE CSO RAMS TO 300 PSI (LOW) AND 3000 PSI (HIGH). TESTED FLOOR VALVES AND RAM TYPE PREVENTERS TO 300 PSI (LOW) AND 3000 PSI (HIGH). TESTED ANNULAR PREVENTER TO 300 PSI (LOW) AND 2100 PSI (HIGH). PULLED TEST PLUG AND INSTALLED WEAR BUSHING. MADE UP BIT #11 ON BHA #13. RAN IN AND TAGGED CEMENT AT 7850' DPM (27' HIGH). DRILLED CEMENT, FLOAT COLLAR AT 7877' AND CEMENT TO 7960'. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 16 OF 27 4/21/92 (cont) 4/22/92 8453' 4/23/92 8742' 4/24/92 9118 ' 4/25/92 9417' 4/26/92 9781' 4/27/92 10002' 4/28/92 10255' RETESTED CASING TO 3000 PSI. DRILLED SHOE AT 7970' AND 10' OF NEW HOLE. PERFORMED A FORMATION INTEGRITY TEST. PRESSURED FORMATION TO 3000 WITHOUT A BREAKDOWN. SHUTDOWN PUMPS AND PRESSURE BLED TO 2935 PSI IN 5 MINUTES AND THEN STABILIZED. FORMATION INTEGRITY TEST = 18.5 PPG ( 9.8 PPG MUD, SHOE @ 6479' TVD ). DRILLED AN ADDITIONAL 5' AND REPEATED THE TEST. DRILLED 8-1/2" HOLE FROM 7985' TO 8215' - DROPPING ANGLE ( 1.5 DEG/100'). CIRCULATED WELL CLEAN FOR TRIP. TRIPPED FOR BHA. MADE UP BIT #llRR ON BHA #14 (1 DEG BENT HOUSING STEERABLE MOTOR). SURFACE TESTED MOTOR. RAN IN HOLE TO SHOE. FILLED PIPE. STRUNG BACK TO 8 LINES ON THE BLOCKS. DRILLED 8-1/2" HOLE FROM 8215' TO 8453' (SLIDING AND ROTATING). CONTINUED TO DRILL 8-1/2" HOLE WITH STEERABLE MOTOR ASSEMBLY FROM 8453' TO 8742'. TRIP FOR NEW BIT. MIXED AND PUMPED DRY JOB. WORKED AND ROTATED THROUGH TIGHT HOLE FROM 8426' TO 7970' (SHOE). MONITORED WELL AT SHOE FOR FLOW. MIXED AND PUMPED DRY JOB. POOH. CONTINUED TO POOH. RIH WITH A STEERABLE MOTOR ASSEMBLY. DRILLED 8-1/2" HOLE FROM 8742'-9118'. CIRCULATED. POOH. TIGHT FROM 8860'-8984'. CONTINUED TO POOH. RIH WITH A ROTARY ASSEMBLY. REAMED FROM 9004'-9118'. DRILLED 8-1/2" HOLE FROM 9118'-9417'. CIRCULATED. POOH. CHANGED OUT 17 JTS OF HWDP. RIH. DRILLED 8-1/2" HOLE FROM 9417'-9781'. THE HOLE ANGLE DROPPED DURING THIS RUN. . CIRCULATED. POOH, HAD TO BACK REAM FROM 9538'-9460'. CONTINUED TO BACK REAM FROM 9460'-9351'. CONTINUED POOH. RIH WITH A STEERABLE MUD MOTOR ASSEMBLY. REAMED FROM 9689'-9781'. DRILLED 8-1/2" HOLE FROM 9781'-9954'. CIRCULATED. WIPER TRIP TO 9954'-9289'. DRILLED 8-1/2" HOLE FROM 9954'-10002'. DRILLED 8-1/2" HOLE FROM 10002'-10136'. CIRCULATED. WIPER TRIP FROM 10136' -9411', BACK REAMED FROM 10,056'-9815'. DRILLED 8- 1/2" HOLE FROM 10,136' -10,255'. CIRCULATED. POOH. TBUS G-14A REDRILL (AFE 301406&) WELL HISTORY PAGE 17 OF 27 4/29/92 10572' 4/30/92 10763' 5/01/92 10938' 5/02/92 11524' 5/03/92 11553' 5/04/92 11775' 5/05/92 12070' R ¢I IVED OOT - 5 1992 Alaska Oil & Gas Cons. CommissiOn Anchorage CONT'D TO POOH. TESTED BOPE TO 3000 PSI HIGH AND 300 PSI LOW. TESTED THE ANNULAR PREVENTER TO 300 PSI LOW AND 2100 PSI HIGH. RIH WITH A ROTARY ASSEMBLY AND DRILLED 8- 1/2" HOLE FROM 10,255'-10,572'. TRIPPED FOR WASHOUT. HAD TROUBLE WORKING BY TIGHT SPOT AT 10284. CONT'D WORKING THROUGH TIGHT SPOT FROM 10,284'-10232'. FOUND WASH OUT. RIH AND DRILLED 8-1/2" HOLE FROM 10572'-10583'. POOH FOR WASHOUT. DRILLED FROM 10583'- 10763'. DRILLED 8-1/2" HOLE FROM 10763'-10826'. POOH FOR WASHOUT. DRILLED FROM 10826'- 10836'. TRIPPED FOR BIT. TESTED THE BOPE TO 5000 PSI HIGH AND 300 PSI LOW. TESTED THE ANNULAR PREVENTER TO 300 PSI LOW AND 3000 PSI HIGH. RIH WITH A ROTARY ASSEMBLY AND DRILLED FROM 10836'-10938'. DRILLED 8-1/2" HOLE FROM 10938'-10999'. SHORT TRIP TO 10441'. DRILLED FROM 10999- 11246. SHORT TRIP TO 10556'. DRILLED FROM 11246'-11432'. SHORT TRIP TO 10691'. DRILLED 8-1/2" HOLE FROM 11432'-11524'. CIRCULATED. TRIP FOR BIT AND BHA. RIH WITH A ROTARY ASSEMBLY. REAMED FROM 11500'- 11524'. DRILLED 8-1/2" HOLE FROM 11524'- 11553'. DRIVE BUSHING SLIPPED. CIRCULATED. POOH. CHANGED OUT KELLY AND THE DRIVE BUSHINGS. RIH TO 11553'. DRILLED 8-1/2" HOLE FROM 11553'-11758'. TORQUE GOT VERY HIGH. TRIPPED TO CHECK BIT (8-8-2). MADE UP BIT #19 ON BHA #21 AND RAN IN HOLE. FILLED PIPE AT THE SHOE. SAFETY REAMED FROM 11728' TO 11758'. DRILLED 8-1/2" HOLE FROM 11758' TO 11775'. DRILLED 8-1/2" HOLE FROM 11775' TO 11947' WITH HIGH ROTARY TORQUE. SHORT TRIP FROM 11947' TO 11441' - TRIP WENT WELL. DRILLED FROM 11947' TO 12070'. PENETRATION RATE SLOWED DOWN THE LAST 10 FT. CIRCULATE BOTTOMS UP. TRIP FOR BIT - CHANGED OUT NEAR BIT STABILIZER DUE TO WEAR. MADE UP NEW BIT AND RAN IN HOLE. TBUS G-~4A REDRILL (AFE 30~406A) WELL HISTORY PAGE L8 OF 27 5/06/92 12070' 5/07/92 12319' 5/08/92 12567' 5/09/92 12694 ' 5/10/92 12889' RECEIVED OCT - 5 1992 Alaska Oil & Gas Cons. Comm'tssJon Anchorage CONTINUED RUNNING IN HOLE TO 12004'. PICK UP KELLY AND WASHED DOWN TO 12034' STUCK PIPE. SPOTTED A 10 % BIODRILL 1402 PILL AROUND THE BHA. JARRED UP - NO GOOD. PERFORMED A MANUAL BACKOFF. SPACED OUT THE DRILL STRING AND PICKED UP THE KELLY. SCREWED BACK INTO THE FISH. DOWN JARRED FISH FREE. WORKED THROUGH TIGHT SPOTS FROM 12034' TO 11910'. CHECKED ALL BREAKS IN THE BHA - LAID DOWN DAMAGED STABILIZER, X-OVER, AND LEAD COLLAR. MADE UP NEW BIT AND BHA. RAN IN HOLE AND TESTED TELECO MWD TOOL. CONTINUED RUNNING IN HOLE CHECKING THE TORQUE ON ALL CONNECTIONS. WASHED AND REAMED FROM 11942' TO 12070' - HIGH ROTARY TORQUE. DRILLED 8-1/2" HOLE FROM 12070' TO 12231'. MADE A SHORT TRIP FROM 12231' TO 11722' -HAD TO WORK SEVERAL SPOTS. DRILLED 8-1/2" HOLE FROM 12231' TO 12319' - HOLE ANGLE DROPPING 1.8 DEG PER 100 ON LAST SURVEY. CIRCULATE BOTTOMS UP AND INCREASED BIODRILL CONCENTRATION TO 3 PERCENT. TRIP FOR BHA CHANGE - TIGHT FROM 12259' TO 12079'. COMPLETED TRIP OUT OF HOLE. MADE UP BIT #22 ON BHA ~23. TESTED TELECO MWD TOOL AND RAN IN HOLE. WASHED AND REAMED FROM 12227' TO 12319'. DRILLED 8-1/2" HOLE FROM 12319' TO 12452'. MADE A WIPER TRIP TO 11947' - TIGHT FROM 12390' TO 12042'. DRILLED FROM 12452' TO 12462'. LOST PLATFORM POWER FOR 30 MINUTES - DID GET OFF BOTTOM. DRILLED FROM 12462' TO 12567' - HIGH TORQUE. TRIP FOR BIT AND BHA CHANGE. COMPLETED TRIP OUT OF HOLE. LAID DOWN 9 JOINTS OF HWDP. MADE UP BIT #23 ON BHA #24. PERFORMED WEEKLY BOPE TEST. TRIPPED IN HOLE. WASHED AND REAMED FROM 12538' TO 12567'. DRILLED 8-1/2" HOLE FROM 12567' TO 12694'. HIGH TORQUE - UNABLE TO ROTATE ON BOTTOM. TRIP TO CHECK ASSEMBLY -BIT GOOD. FOUND ELECTRICAL PROBLEM WITH THE ROTARY TABLE. RAN IN HOLE AND REAMED FROM 12661' TO 12694'. DRILLED 8-1/2" HOLE FROM 12694' TO 12889'. MADE A WIPER TRIP - TIGHT AT 12784' AND 12759' TO 12571'. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 19 OF 27 5/11/92 13050' 5/12/92 5/13/92 5/14/92 OCT - Alask~ 0ii & G~s Cons. Gomm%ss%O~ Anchorage REAMED FROM 12758' TO 12889'. DRILLED 8-1/2" HOLE FROM 12889' TO 12967'. LOST 1200 PSI PUMP PRESSURE. PULL OUT OF HOLE LOOKING FOR A WASHOUT. FOUND WASHOUT IN JOINT #46 FROM ROTARY TABLE. TRIPPED BACK IN HOLE. WASHED AND REAMED THE LAST 30' TO 12970'. DRILLED FROM 12970' TO 13050' TD. CIRCULATE WELL CLEAN AND CONDITION MUD. PULL OUT OF HOLE - TIGHT AT 12608', 11682' AND 10108'. CONTINUED PULLING OUT OF THE HOLE. LAID DOWN TELECO TOOL. RIGGED UP HAS WIRELINE. MADE UP SUITE #1 ( HRI/BCS/GR ) AND RAN IN TO THE 9- 5/8" SHOE AT 7970'. CONTINUED IN HOLE. SET DOWN AT 8454', 8591', 8654' AND 8768' - NO PROBLEM WORKING THRU THESE SPOTS. CONTINUED IN AND SET DOWN AT 9830' - ATTEMPTED TO PICK UP WITH 5100# AND THE UNIT SKIDDED OFF ITS BLOCKING. REPOSITIONED THE UNIT AND WORKED STUCK WIRELINE - NO SUCCESS AT 8700# PULL. RIGGED UP TO STRIP OVER WIRE WITH 5" DRILL PIPE. STRIPPED OVER TO 2568' DPM AND THE WIRELINE PULLED OUT OF THE SURFACE ROPE SOCKET. RIGGED UP 1-1/4" HANDLING EQUIPMENT AND BOPE. MADE UP WIRE ROPE SPEAR ON 1-1/4" TUBING AND BEGAN FISHING FOR WIRELINE INSIDE THE 5" DRILL PIPE. CONTINUED FISHING WIRELINE INSIDE THE 5" DRILL PIPE. ENGAGED THE WIRELINE AT 400'. PULLED OUT OF HOLE SLOWLY TO 15' BELOW THE ROTARY TABLE - WIRELINE PARTED WITH 8.5K PULL (RECOVERED 30' OF WL). LAID DOWN 1-1/4" FISHING TOOLS. PULLED OUT OF HOLE WITH 5" DRILL PIPE. MADE UP A WIRE ROPE SPEAR ON 5" DRILL PIPE AND BEGAN FISHING WIRELINE. RECOVERED 1368' OF WIRE IN SIX RUNS BETWEEN 213' AND 1753'. RECOVERED THE REMAINDER OF THE WIRELINE (8412') IN THREE RUNS - PULLED OUT OF WEAK POINT. MADE UP A 5-3/4" OVERSHOT WITH A 7" GUIDE DRESSED WITH A 3-3/8" GRAPPLE AND RAN IN TO THE SHOE. CIRCULATED AND CONDITIONED MUD. CONTINUED IN TO 9748' AND SAW A 300 PSI INCREASE IN PUMP PRESSURE - POSSIBLY THE LOGGING TOOL. CHASED LOGGING TOOL TO 12255'. TRIPPED TO CHECK RECOVERY - NONE. LOGGING TOOL APPEARED TO BE LARGER OD THAN REPORTED BY HLS. CHANGED TO 3-1/2" GRAPPLE AND RAN IN HOLE. TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 20 OF 27 5/15/92 CONTINUED TO RUN IN TO 12255' - HOLE STICKY FOR THE LAST STAND. TRIPPED TO CHECK RECOVERY -NONE. MADE UP A BIT AND RAN IN TO CLEAN OUT TO THE TOP OF THE LOGGING TOOL. CIRCULATED BOTTOMS UP FROM 10402'. CONTINUED IN TO 12258'. REAMED FROM 12258' TO 12886' - VERY TOUGH REAMING (HIGH TORQUE, PACKING OFF, TOUGH TIME GETTING WEIGHT TO BIT). BAD SPOTS AT 12258', 12585', 12695', AND 12750'. WORKED FROM 12846' TO 12886' FOR 3 HOURS - UNABLE TO WORK DEEPERAND KEEP THIS SECTION OPEN. HAVING PROBLEMS PACKING OFF AND STICKING DRILL PIPE. 5/16/92 CONTINUED WORKING THE SECTION FROM 12846' TO 12886' AN ADDITIONAL 4 HOURS - NO PROGRESS. TRIPPED TO CHECK TOOLS. STABILIZERS PACKED OFF. BIT WAS UNDERGAUGE, HAD BROKEN TEETH, AND HAD SKIDDED THE CONES IN SEVERAL PLACES. DEFINITE SIGNS OF RUNNING ON THE LOGGING TOOL. PERFORMED WEEKLY BOPE TEST TO 5000 PSI. RAN IN HOLE WITH NEW BIT AND BHA TO CONTINUE CLEANING OUT TO THE LOGGING TOOL. SLIPPED AND CUT DRILLING LINE ON THE TRIP IN THE HOLE. ATTEMPTED TO REAM OUT TIGHT SPOT FROM 12866' TO 12886' - HOLE WOULD NOT STAY OPEN. WORKED AS DEEP AS 12897' BUT LOST HOLE BACK TO 12879'. DECIDED TO CALL THIS TD. CIRCULATED BOTTOMS UP. WIPE HOLE TO 9-5/8" SHOE. 5/17/92 CONTINUED WIPER TRIP - NO PROBLEM GETTING BACK TO 12879'. CIRCULATE AND CONDITION MUD. TRIP FOR CASING. RIG UP TO RUN 7" LINER. RAN 5223' OF 7" 295 N-80 BUTTRESS LINER. MADE UP TIW LINER HANGER/PACKER WITH RUNNING TOOL. CONTINUED TO RUN IN WITH LINER ON 5" DRILL PIPE. 5/18/92 CONTINUED IN WITH THE LINER TO 12879'. CIRCULATED AND RECIPROCATED THE LINER. RIGGED UP AND TESTED SURFACE CEMENTING LINES. PUMPED CEMENT JOB WHILE RECIPROCATING PIPE 50' AS FOLLOWS: 40 BBL DUAL SPACER; 15 BBL FIW; 20 BBL SUPERFLUSH; 15 BBL FIW; 1323 CU FT "G" CEMENT WITH ADDITIVES MIXED TO 15.8 PPG; DROPPED DRILL PIPE DART; DISPLACED R~CEIVED WITH 10 BBL FIW FOLLOWED BY 41 BBL MUD. DRILL PIPE PARTED 2.7' BELOW THE TOOL JOINT ON THE FIRST JOINT BELOW THE ROTARY TABLE 0el-~ ~99~ WITH 525K ON THE HOOK. SHUT DOWN CEMENT Alaska 0i~ & Sas Oons. Commi~°n PUMPS AT 0520 HRS. FILLED HOLE WITH 31 BBLS. Anchor~ MADE UP A 7-5/8" OVERSHOT DRESSED WITH A 5" MILL CONTROL, HIGH PRESSURE PACKOFF, AND 5" TBUS G-14A REDRILL (AFE 301406&) WELL HISTORY PAGE 21 OF 27 5/18/92 (cont) BASKET GRAPPLE. RAN IN AND ENGAGED THE FISH AT 78'. PICKED UP 200K ON THE HOOK. PRESSURE STRING TO 1800 PSI AND FLUID BEGAN TO MOVE. PRESSURE DROPPED BACK TO ZERO WITH GOOD RETURNS AT THE FLOWLINE. RELEASED FROM THE LINER HANGER. PUMPED A TOTAL OF 39 BBLS AND THE PRESSURE INCREASED TO 2000 PSI AND HELD. INCREASED PRESSURE TO 3000 PSI TO SET THE LINER HANGER SLIPS. PICKED UP OUT OF THE LINER HANGER. SET BACK DOWN WITH 50K TO SET THE LINER TOP PACKER. PULL OUT AND LAY DOWN SETTING TOOL. PRESSURE TEST LINER LAP AND CASING TO 3000 PSI FOR 30 MINUTES AGAINST THE BLIND RAMS. CHANGED THE UPPER PIPER AMS TO 2-7/8" x 5" VBR BLOCKS AND TEST SAME. INSTALLED WEAR BUSHING. MADE UP A 6" BIT ON 4-3/4" DRILL COLLARS. RAN IN PICKING UP 3- 1/2" DRILL PIPE. CROSSED OVER TO 5" DRILL PIPE AND CONTINUED IN THE HOLE. 5/19/92 TAGGED THE LINER TOP AT 7715'. SET DOWN AT 7727'. DRILLED WIPER PLUG. CLEANED OUT HARD CEMENT FROM 7727' TO 9044'. 5/20/92 CONTINUED DRILLING OUT CEMENT FROM 9044' TO 9075'. TRIP FOR BIT. RAN IN WITH A 6" PDC BIT AND DRILLED CEMENT FROM 9075' TO 10459'. 5/21/92 CONTINUED DRILLING OUT CEMENT FROM 10459' TO THE LANDING COLLAR AT 12830'. TESTED CASING TO 3000 PSI. DRILLED THE LANDING COLLAR AND CLEANED OUT CEMENT TO THE FLOAT SHOE AT 12871'. TESTED THE CASING TO 3000 PSI. 5/22/92 PULLED OUT LAYING DOWN 5" S-135 DRILL PIPE (UNOCAL STRING TO BE RETIRED). RAN IN WITH A 6" BIT WITH TANDEM SCRAPERS PICKING UP 5" S- 135 DRILL PIPE (HOMCO RENTAL). ATTEMPTED TO R ~CEIV E D WORK INTO THE LINER TOP AT 7715'. WORKED DOWN TO 7719' AND COULD NOT WORK DEEPER. TRIPPED TO CHECK TOOLS - LEFT ONE CONE IN THE HOLE AND FOUND THE SCRAPER DRESSED FOR 001-~ ]99~ WRONG CASING (7-5/8"). PERFORMED WEEKLY ROPE 0iJ&6asCons. Gommission TEST - ANNULAR PREVENTER FAILED THE HIGH Ancho~go TEST. REMOVED FLOW NIPPLE TO INSPECT ANNULAR. 5/23/92 REPLACED THE ANNULAR ELEMENT. RETESTED TO 2100 PSI. INSTALLED FLOW NIPPLE AND SET WEAR BUSHING. RAN IN WITH A 6.059" TAPERED MILL AND TANDEM SCRAPERS. WASHED AND REAMED THROUGH THE LINER TOP FROM 7708' TO 7743'. WORKED THE SCRAPER THROUGH THE LINER - TOOK WEIGHT AT 7710', 7717' AND 7725'. SMOOTHED TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 22 OF 27 5/23/92 (cont) 5/24/92 5/25/92 OOT - 5 1992 Oil & Gas Cons. Anchorag~ 5/26/92 UP AFTER THREE PASSES. CONTINUED IN HOLE TO 12871'. CIRCULATED WELL CLEAN. TRIPPED OUT FOR CASED HOLE LOGS. RIGGED UP ATLAS WIRELINE. RAN IN HOLE WITH SBT/GR/CCL LOG. CONTINUED TO RUN SBT/CCL/GR LOG FROM 12871' TO SURFACE. RAN GYRO SURVEY FROM 12871' TO SURFACE. BOND LOG SHOWED TOP OF CEMENT IN WF-5 BENCH. MADE UP AN EZSV ON A BAKER SETTING TOOL. RAN IN ON ATLAS WIRELINE AND SET THE RETAINER AT 12589'. ATTEMPTED TO GET OFF THE RETAINER - SETTING TOOL DID NOT RELEASE. WORKED WIRE UP TO 9000# ON THE WEIGHT INDICATOR. RIGGED UP A "T" BAR TO PULL OFF THE ROPE SOCKET. PULLED THE WIRELINE LOOSE WITH THE BLOCKS. RECOVERED THE SETTING TOOL WITH THE TENSION SLEEVE PROPERLY SHEARED. RAN IN WITH A 4' x 4" 4 HPF SQUEEZE GUN AND SHOT HOLES FROM 12564' TO 12568'. MADE UP AN EZSV ON A BAKER SETTING TOOL AND RAN IN HOLE. SET THE RETAINER AT 12534'. ATTEMPTED TO GET OFF THE RETAINER - SETTING TOOL DID NOT RELEASE. WORKED THE WIRE AT 4800# OVER NORMAL PICKUP. RIGGED UP A "T" BAR AND PULLED THE WIRELINE LOOSE WITH THE BLOCKS. RECOVERED THE SETTING TOOL WITH THE TENSION SLEEVE PROPERLY SHEARED. RAN IN WITH A 4" x 4" 4 HPF SQUEEZE GUN AND SHOT HOLES FROM 11519' TO 11523'. WELL BEGAN TO FLOW. PULLED OUT WITH WIRELINE (5.5 BBL GAIN). RAN IN WITH OPEN ENDED DRILL COLLARS WITH A DART VALVE ABOVE THE FIRST STAND. RAN COLLARS, 51 STANDS 3-1/2" DRILL PIPE AND 1 STAND OF 5" DRILL PIPE (24 BBL TOTAL GAIN). SHUT-IN AND MONITOR WELL - PRESSURE BUILT TO 240 PSI IN 2 HOURS. BLED PRESSURE TO ZERO (2.5 BBLS). PRESSURE BUILT BACK UP TO 180 PSI IN 45 MINUTES. BLED OFF PRESSURE AND CONTINUED TO RUN IN HOLE TO 12512' (ADDITIONAL 25.6 BBL GAIN - 49.6 BBL TOTAL). CIRCULATED OUT INFLUX HOLDING CONSTANT BOTTOM HOLE PRESSURE - NO GAS/DARK FLUID ON BOTTOMS UP. SHUT-INAND OBSERVED WELL - PRESSURE STABILIZED AT 255 PSI. WEIGHTED UP BRINE WITH NACL TO 9.2 PPG. CIRCULATED WELL WITH 9.2 PPG KILL WEIGHT BRINE. MONITOR WELL - HOLE TAKING 0.8 BPH FLUID. TRIPPED FOR EZSV STINGER. TAGGED RETAINER AT 12529' DPM. CIRCULATED ONE DRILL PIPE VOLUME. RIGGED UP HALLIBURTON CEMENTING LINES. PRESSURE TESTED ANNULUS TO 1000 PSI - LEAKED OFF TO 600 PSI. TESTED SURFACE LINES TBUS G-14& REDRTLL (AFE 301406A) WELL H1'STORY PAGE 23 OF 27 5/26/92 (cont) 5/27/92 5/28/92 OCT -- § 992 ~r~c~orage TO 7000 PSI. STABBED INTO THE RETAINER FOR AN INJECTIVITY TEST. PUMPED AWAY AT 1.2 BPM WITH 2650 PSI. BROKE FREE AFTER 3 BBLS AND ESTABLISHED CIRCULATION THROUGH THE UPPER PERFORATIONS AT 3BPM WITH 1225 PSI. MIXED AND SPOTTED A 23 BBL HI-VIS PILL FROM THE TOP OF THE RETAINER TO THE UPPER PERFS. PUMPED CEMENT JOB AS FOLLOWS: 10 BBLS DRILL WATER; 70 BBLS "G" CEMENT WITH ADDITIVES MIXED AT 15.8 PPG; 10 BBLS FIW; AND 159 BBLS 9.2 PPG BRINE DISPLACEMENT. CIP AT 1700 HOURS. UNSTABBED AND CIRCULATED OUT THE LONG WAY - 25 TO 30 BBLS CEMENT BACK. PULLED UP TO 11425'. STRUNG BACK THE BLOCKS TO 8 LINES AND CHANGED OUT THE KELLY. RAN IN TO 11519' AND PERFORMED AN INJECTIVITY TEST. PRESSURED UP TO 920 PSI WITH 7.5 BBLS AWAY. BLED TO 825 PSI IN 5 MINUTES. PRESSURED UP TO 2590 PSI WITH 9.5 BBLS AWAY. BLED TO 2110 PSI IN 5 MINUTES. RAN IN TO 11981'. MIXED AND SPOTTED TO BALANCE A 25 BBL HI-VIS PILL. PULLED UP TO 11610'. MIXED AND PUMPED TO BALANCE 115 CU FT "G" CEMENT WITH ADDITIVES. PULLED UP TO 10863' AND REVERSED WELL CLEAN - DID NOT SEE ANY CEMENT. HOOKED UP AND TESTED SURFACE CEMENTING LINES. SQUEEZED AWAY 9 BBLS AGAINST THE UPPER PIPE RAMS WITH A FINAL SQUEEZE PRESSURE OF 2930 PSI. CIP AT 0400 HOURS. HELD SQUEEZE PRESSURE TO 0840 HOURS. BLED BACK 2 BBLS TO BLEED OFF 200 PSI AND PULLED OUT OF HOLE. LAID DOWN EXCESS PIPE IN THE DERRICK. MAKE UP A BLADED MILL ON A CLEANOUT ASSEMBLY AND RAN IN TO 11242'. WASHED DOWN TO 11260'. CLEANED OUT CEMENT STRINGERS AND RATTY CEMENT TO 11409'. WASHED DOWN TO 11469'. TESTED THE CASING TO 2500 PSI AGAINST THE UPPER PIPE RAMS. CLEANED OUT CEMENT STRINGERS TO 11532'. WASHED DOWN TO 11563'. CIRCULATED WELL CLEAN. PRESSURE TESTED SQUEEZE HOLES FROM 11519' TO 11523'. PRESSURED UP TO 2500 PSI - LOST 150 PSI IN 10 MINUTES. REPESSURED TO 2500 PSI - LOST 700 PSI IN 30 MINUTES. CONTINUED TO RUN IN TO 12534' - HAD TO WASH THROUGH SPOTS AT 12112', 12328', 12421' TO 12529'. DRILLED RETAINERS AT 12534' AND 12589'. CHASED RETAINER JUNK TO 12866'. DRILLED ON JUNK TO 12868' - SLOW PROGRESS. CIRCULATED WELL CLEAN. TRIPPED FOR BOND LOG. RIGGED UP ATLAS WIRELINE. RAN SBT/GR/CCL FROM 12860' TO TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 24 OF 27 5/28/92 (cont) 5/29/92 5/30/92 5/31/92 R'ECEIVED OOT - 5 AJaska Oil & Gas Cons. Commissio~, Anchorage 9850'. WAITED ON FIELD PRINT OF THE LOG - TROUBLE WITH THE PLOTTER AND COMPUTER. CONTINUED TO WAIT ON FIELD PRINT OF LOG. PERFORMED WEEKLY TEST ON CHOKE MANIFOLD AND FLOOR VALVES WHILE WAITING ON LOG PRINT. RERAN LOG FROM 12868' TO 10620'. RETESTED UPPER SQUEEZE PERFORATIONS FROM 11519' TO 11523' TO 2500 PSI - BLED TO 1800 PSI IN 30 MINUTES. SET AN EZSV ON WIRELINE AT 11540' AND RIGGED DOWN ATLAS. FINISHED WEEKLY TEST ON THE BOP STACK. MADE UP AND RAN IN WITH A EZSV ON DRILL PIPE TO 11496'. SET THE RETAINERAND RIGGED UP SURFACE LINES. APPLIED 2000 PSI TO THE BACKSIDE. ATTEMPTED TO BREAK DOWN THE SQUEEZE HOLES WITH 5200 PSI. UNSTABBED AND PUT ADDITIONAL RIGHT HAND TURNS INTO THE STINGER. STABBED BACK INTO THE RETAINER AND ATTEMPTED TO PUT 3000 PSI ON THE BACKSIDE - BLED TO 2500 PSI. PRESSURED THE SQUEEZE PERFORATIONS TO 4500 PSI - HELD GOOD. UNSTABBED FROM THE RETAINER. PRESSURED UP TO TEST THE CASING - PUMPED AWAY AT 1.7 BPM 2550 PSI. TRIPPED FOR 7" RTTS PACKER TO ISOLATE THE LEAK. RAN IN AND SET THE RTTS AT 7760'. PRESSURE THROUGH THE PACKER TO TEST THE 7" LINER - HELD 3000 PSI. PRESSURE THE BACKSIDE AND PUMPED AWAY AT 1.7 BPM WITH 2500 PSI. TRIPPED FOR 9-5/8" RTTS PACKER. RAN IN AND SET THE PACKER WITH THE TAIL AT 7615'. ESTABLISHED AN INJECTION RATE OF 3 BPM ,AT 2800 PSI WITH 30 BBLS OF BRINE. SQUEEZED THE LINER LAP WITH 348 CU FT "G" CEMENT WITH ADDITIVES. REVERSED OUT 11 BBLS OF GOOD CEMENT. RELEASED THE PACKER AND PULLED 10 STANDS. RIG DOWN FOR 9 HOURS TO REPAIR THE HIGH DRUM AND OVERRIDING CLUTCH. FINISHED RIG REPAIR. TRIPPED FOR 8-1/2" CLEAN OUT ASSEMBLY. TAGGED CEMENT STRINGERS AT 7486'. WASHED DOWN TO 7505'. CLEANED OUT FIRM CEMENT TO 7651'. CLEANED OUT RATTY CEMENT TO 7692'. CLEANED OUT FIRM CEMENT TO THE LINER TOP AT 7706'. CIRCULATED WELL CLEAN. TRIP FOR 6" CLEAN OUT ASSEMBLY. CLEANED OUT CEMENT STRINGER FROM 7706' TO 7793'. RAN IN TO 11496'. PRESSURE TESTED THE CASING TO 3000 PSI FOR 30 MINUTES. DRILLED THE RETAINERS AT 11496' AND 11540'. PUSH THE JUNK TO 12866'. TBUS G-L4~ REDRZLL (Z~FE 30L406&) WELL HZSTORY P~GE 25 OF 27 6/01/92 6/02/92 6/03/92 RECEIVED O0T - § !992 Alaska Oil & Gas Cons. Commissio~ Anchorage 6/04/92 MILLED ON RETAINER JUNK FROM 12866' TO 12868'. CIRCULATED BOTTOMS UP. TRIP FOR 7" CASING SCRAPER. HAD TROUBLE WITH DRAG. CIRCULATED BOTTOMS UP FROM 12581'. CONTINUED OUT TO 12116' WITH EXCESSIVE DRAG. RAN BACK TO BOTTOM AND PUMPED AROUND A 100 BBL HI-VIS SWEEP. TRIP OUT WITH THE MILL. RAN A CASING SCRAPER TO 12868'. CHANGED OVER TO CLEAN FIW. TRIP FOR PERFORATING ASSEMBLY. PICKED UP VANN SYSTEMS/HRS TUBING CONVEYED PERFORATING ASSEMBLY. RAN IN FILLING THE DRILL PIPE FOR A 500 PSI UNDERBALANCE. SPOTTED THE GUNS ON DEPTH BY DRILL PIPE MEASUREMENTS. RIGGED UP ATLAS AND RAN A GR CORRELATION LOG. SET THE PACKER AND RAN A CONFIRMATION LOG. PERFORATED THE WEST FORELAND WITH 4-5/8" 25 GRAM DEEP PENETRATING CHARGES AT 8 HPF AS FOLLOWS: WF- 2 12227'- 12317'; WF-3 12332'- 12473'; WF-4 12477'- 12524'', WF-5 12564'- 12651'; WF-6 12667'- 12719'; WF-7 12751'- 12787'. REVERSED THE DRILL PIPE CLEAN. CIRCULATED ONE ANNULAR VOLUME. WELL TAKING 120 BPH. PULLED OUT AND LAID DOWN PERFORATING ASSEMBLY. RAN IN WITH A MILL AND CASING SCRAPER. SLIPPED AND CUT THE DRILLING LINE ON THE WAY IN THE HOLE. CONTINUED RUNNING IN WITH THE CASING SCRAPER TO 12868'. CIRCULATED BOTTOMS UP TAKING RETURNS TO PRODUCTION - SLIGHT OIL SKIM. WELL TAKING 18 BPH OF FIW. PULLED OUT OF HOLE. PERFORMED A 30 MINUTE INJECTION TEST INTO THE WEST FORELAND AGAINST THE BLIND RAMS. INITIAL INJECTION RATE WAS 3.5 BPM AT 1170 PSI. PRESSURE INCREASED TO 2000 PSI AT 27 MINUTES INTO THE TEST. FINAL INJECTION RATE WAS 2.9 BPM AT 2000 PSI. PRESSURE BLED TO ZERO PSI IN 4.5 MINUTES. WELL TAKING 30 BPH RATE. MADE UP RTTS AND RBP ON DRILL PIPE AND RAN IN HOLE. SET RBP AT 12800'. PULLED UP AND SET THE RTTS AT 12533'. RIGGED UP AND TESTED ACID LINES TO 5000 PSI. HELD PRE-JOB SAFETY MEETING. ACID STIMULATED WEST FORELAND WF-5 THRU WF-7 AS FOLLOWS: 55 BBLS 7.5% HCL WITH ADDITIVES; 78 BBLS 6.5% HCL/1.5% HF (MUD ACID) WITH ADDITIVES; 104 BBL AMMONIUM CHLORIDE WATER. ESTABLISHED COMMUNICATION WITH THE WF-4 PERFORATIONS ABOVE THE RTTS AT 55 BBLS INTO THE AMMONIUM CHLORIDE STAGE. SHUT IN THE ANNULUS AND FINISHED THE ACID JOB. INITIAL TBUS G-14A REDRILL (AFE 301406A) WELL HISTORY PAGE 26 OF 27 6/04/92 (cont) 6/05/92 6/06/92 OCT - 5 A)aska Oil & Gas Oo,~s. ~omm~ssio~ Anchorag{) INJECTION RATE WAS 3 BPM AT 3500 PSI. FINAL INJECTION RATE WAS 3.2 BPM AT 1900 PSI. PULLED THE RTTS LOOSE AND RAN IN TO 12800' TO LATCH THE RBP. TRIP FOR ISOLATION PACKER. MADE UP PERMANENT PACKER WITH 2-7/8" TAIL ASSEMBLY AND RAN IN ON DRILL PIPE. SLIPPED AND CUT 500' OFF THE DRILLING LINE TO GET RID OF A BAD SPOT. DROPPED THE SETTING BALL AND SET THE PACKER WITH 3000 PSI PRESSURE. SHEARED OUT WITH 50K OVERPULL. WELL TAKING 30 BPH. TRIP FOR ISOLATION PLUG. RAN IN AND SET A "JP" ISOLATION PLUG IN THE TOP OF THE ISOLATION PACKER. TESTED THE CASING TO 3000 PSI - BLED OFF 300 PSI IN 30 MINUTES. RETESTED AND LOST 175 PSI IN 20 MINUTES. CHANGED OVER TO CLEAN FIW. TRIPPED FOR PERFORATING ASSEMBLY. MADE UP VANN/HRS TCP GUN ASSEMBLY. RAN IN FILLING PIPE FOR UNDERBALANCE. SET THE GUNS ON DEPTH BY DRILL PIPE MEASUREMENTS. RIGGED UP ATLAS WIRELINE. RAN GR CORRELATION LOG. RESET PACKER AND RAN CONFIRMATION LOG. RIGGED UP SURFACE AND SHOT DETECTION EQUIPMENT. PERFORATED HEMLOCK WITH 4-5/8" 8 HPF 25 GRAM DEEP PENETRATING CHARGES AS FOLLOWS: HB-1 F/ 11576'-11597'; HB-4 F/ 11820'-11935'. PULLED PACKER LOOSE AND REVERSED THE DRILL PIPE CLEAN. WELL TAKING 10 BPH OF FIW. TRIP FOR CASING SCRAPER. LAID DOWN GUN ASSEMBLY. RAN 6" MILL AND 7" CASING SCRAPER TO 12093'. DISPLACED HOLE WITH CLEAN FIW TAKING RETURNS TO PRODUCTION. TRIP FOR RTTS AND RBP. RAN IN AND SET THE RBP AT 11953'. PULLED UP AND SET THE RTTS AT 11792'. RIGGED UP AND TESTED SURFACE LINES. PERFORMED AN INJECTION TEST ON HEMLOCK HB-4 AS FOLLOWS: 0.25 BPM @ 1600 PSI; 0.75 BPM @ 1975 PSI; 1 BPM @ 2400 PSI; 1.25 BPM @ 3575 PSI. BLED TO ZERO IN 9 MINUTES. MOVE RBP TO 11614' AND RESET THE RTTS AT 11544'. INJECTED INTO HB-1 AT 0.6 BPM WITH 4000 PSI. ACIDIZED AS FOLLOWS: 9 BBLS 7.5% HCL WITH ADDITIVES; 27 BBLS 6% HCL/1.5% HF WITH ADDITIVES; 50 BBLS 2% AMMONIUM CHLORIDE WATER; DISPLACED WITH 153 BBLS FIW. FINAL RATE = 2.18 BPM AT 3400 PSI. PRESSURE BLED TO ZERO IN 3.5 MINUTES. TBUS G-14A REDRILL (iI~FE 30L406&) WELL HISTORY PAGE 27 OF 27 6/07/92 6/08/92 6/09/92 MONITOR WELL - TAKING 12 BPH OF FIW. TRIP FOR PLUG PULLING TOOL. WASHED OVER AND LATCHED THE PLUG IN.THE ISOLATION PLUG AT 12093'. PULLED PLUG AND MONITORED WELL - TAKING 40 BPH OF FIW. TRIP FOR PERMANENT PACKER. RAN IN AND SET OTIS "BWH" PACKER AT 11451'. TESTED THE BACK SIDE TO 1000 PSI. SHEARED OUT OF THE PACKER WITH 35K OVERPULL. TRIPPED OUT LAYING DOWN THE 3-1/2" DRILL PIPE. CONTINUED LAYING DOWN 3-1/2" DRILL PIPE AND PACKER SETTING TOOL. LAID DOWN 4-3/4" COLLARS AND EXCESS 3-1/2" DRILL PIPE IN DERRICK. RIGGED UP TO RUN COMPLETION. RAN 3- 1/2" 9.2# L-80 TUBING WITH CS-CB CONNECTIONS AND TK-99 INTERNAL COATING HYDROTESTING TO 5000 PSI. FINISHED RUNNING SINGLE 3-1/2" INJECTION COMPLETION. LANDED THE SEAL ASSEMBLY IN THE PERMANENT PACKER AT 11451' TM. TESTED THE BACKSIDE TO 3000 PSI. SPACED OUT, INSTALLED THE TUBING HANGER, AND LANDED THE INJECTION COMPLETION WITH 5K UNDER DOWN WEIGHT ON THE LOCATOR SUB. RAN IN THE LOCKDOWN SCREWS AND PACKED OFF THE HANGER. PERFORMED A MECHANICAL INTEGRITY TEST - GOOD TEST WITNESSED BY AOGCC INSPECTOR LOU GRIMALDI. NIPPLED DOWN BOPE. INSTALLED AND TESTED SINGLE INJECTION TREE. RIGGED DOWN EQUIPMENT FOR MOVE TO TBUS G-29 REDRILL. RELEASED RIG AT 2400 HOURS ON 6/09/92. RECEIVED O0T - ,5 1992 Alaska Oil & Gas Cons, Commissior~ Anchorage S¢ienti{ic Drilling International 13511 Westwind Drive Anchorage. Alaska ggSIS Finder Survey For UNOCAL CORPORATION ANCHORAGE. ALASKA ORIGINAL Interpolated 1~' Measured Depth Intervals Revised 23 June 1992 RgB to 103' Crom 99' Well Number Site Location Site Location Site Location : 6- 14A-RD : Trading Bay Unit. McArthur River Field : Kenai Peninsula BOrough : Cook Inlet, A1 aska Sob Number : 4SF6(~SBZ~I8 Latitude : 6&.838 Survey Date(s) : Z4 May 1992 S.D.I. personnel : A1 Kudrle Calculation Method : Tangential Survey Depth Zero : RKB Proposal Direction : AZ IZ3.13 (S56.87E) Depth Unit : Feet RKB to MSL : 1~3 Feet RECEIVED JUN 2 6 1992 Alaska Oil & 8as Cons. Commission Anchorage Comments : · Azimuths referenced to true north · Survey run in 9-5/8" casing and T" liner to TD SCIENTIFIC DRILLING UNOCAL Corporation G-i4A-RD Neaeured Vertical Vert. Depth Depth Section 0.0 e.ee l~e.e 99.99 zee.e 199.99 e.9 3~e.e z99.99 1.3 4e~. · 399.99 1.2 s~¢z). · 499.99 I. z G~)e. · s99.92 4.9 ?e~. · 699. e2 18.2 Bee. e 796.8e 38. i 9ee.e 893.43 58.8 Ieee. · 9 89.49 78.2 i l~e.e 1e84.91 1~.3 1Z~. e '11-79.3e 128. · 13ee.e IZ73.58 156, I 14~.e 1367.92 185.3 i5~.e 1461.46 zi8.5 i6~.e 1554.79 252.1 17ee.e 1647.33 287,6 iBee.e 1738.72 325.8 19ee.e 1828.16 369.z zeee.e 1916.3e 415.5 zlee.e zee3.z4 464,3 zzee.e ze88.z6 516,6 z3ee.e 2171.14 572,3 z4~).e z251.37 G3Z.e 25~.e 23z8.e7 696, l ZF:R~.e 24e3.64 ?BI,G ZT~.e 2479,34 826.9 Z8~.e 2555.41 891.8 zgee.e 2631.72 956,5 3~,e 27e8,29 leZe. 8 31~.e 2784.95 le85.e 32~(~.e ZSGI.5e 1149.3 33ee.e z938.ze IZI3.5 34~.e 3elS.e6 lZ77.5 3s~.e 3egz,e7 1341.3 36ee.e 3169.33 14e4.8 37~.0 3246.6G 14G8.2 Outrun Survey Inc Az tmuth Beg Beg e.66 z19.76 e.61 127.91 e. 19 126. le e. 13 z15.41 2.11 124.8e 7.7e 115.7e 1z.e9 le5.~4 14.9e 86.81 16.14 77.34 17.42 8e.74 19.28 9e;ZE 19.48 9e.46 19.36 94.7e ze.71 le2.88 zl.e3 lez.gz zz.z7 leZ.41 23.95 le3.55 26.57 leS.Be 28.19 IIZ.~ 29.61 113.77 31.77 IIG. 3e 34.e3 118.66 36.65 IZe. 9e 39.92 IZ1.8~ 4e.91 IZI.96 4~.81 122.22 4e.47 122.51 4e. Z6 IZZ.74 4e.~4 122.9e 39.95 IZ3.~4 4e.~5 IZ3.Ze~ 39.92 123.17 39.'77 123.24 39.64 IZ3.38 39.41 123.53 39.35 123.53 .page I Date = 24 Hay 1992 Coord{ nat es 13-1 eg Latitude Departure / e. 885 e. 741J e. 66 1.545 e. lC e.91 1 · 736 e. 37E e. 42 1.9ZS 0.24E e. Z3 I. 845 e. 26E e. 1 '7 3.94S 3.Z8E 2.13 9.755 15.36E 5.63 I 5. 199 35. SgE 4.73 13.755 GI.ZTE 5.e7 7.665 88.39E 2.81 2.856 117.93E I.SI 3.ee5 150.956 3.5Z 3.265 184.3~E ~.ZI 5.98S Z17.346 1.42 13.67S 251.6ZE 3.11 ZI.89S 286.8eE e.32 3e.e46 323.6ZE 1.25 39.555 363.Z9E 1.74 53.9S6 4eS.63E 3.44 71.655 449.42E Z.19 91.575 494.64E 1.6S 114.905 S41.84E 2.51 141.746 59e.946 Z.Se 172.385 642.16E 2.92 Z~6. ZeS 696.7eE 3.32 24e.8S6 752.25E I.~ Z75.7e5 8eT.S4E ~.19 31e.585 862.286 0.39 345. 536 916.64E e. 2 6 38e. 475 970.64E e. 2 5 415.485 leZ4.47E e. IZ 45~.715 le78.31E e. 15 465.8ZS I 13Z. e3E e. 13 5Ze. 885 1185. 536 e. 1S 555.985 I 2 38. BeE 0. I G 591 .~,GS 1291.736 0. Z4 SZ 6. eSS 1344.58E e. 07 SCIENTIFIC DRILLING UNOCRL Corporation G-14R-RD Heasured Vertical ¥ert. Depth Depth Section 3800.0 33z4.09 1531.5 39~.0 3401.13 159s.2 4~.0 3477.33 1660.0 41~.0 3552.96 1725.4 42~0. · 3627.77 1791 . 7 Outrun Survey Inc RztMuth Oeg Oeg 39.26 123.50 39.60 I23.44 40.36 123.57 40.86 IZ3.70 41.57 123.82 43~.0 3701.93 1858,8 42.13 123.89 4400.0 3775.39 1926.7 42.73 123.97 450~.0 3848.67 1994,7 42,88 124.24 46~0.0 3921.89 2062,8 42.93 124.46 4700.0 3995.03 2130,9 42.99 I24.86 48~.0 4068.13 2199,1 4900.0 4141.5~ 2267,0 SOQ~.O 4214.74 2335.1 · 51~.0 4287.93 2403.2 SZQ)¢Z), 0 4361.41 2470.9 53~.0 4434.93 2538.6 54~.0 4508.85 26~5.8 55~.0 458Z.56 2673.2 S60~.0 4657.09 2739.7 57~.0 4732.19 2805.4 SBee.e 4807.85 2870.5 sgee.e 4883.58 2935.5 seee.e 4959.93 2999.6 6100.0 503s.54 3~53.4 62~0.0 5113.54 3126.6 43.03 I25.08 42.80 I25.34 42.91 I25.43 42.95 I25.55 42,71 125.85 42.68 IZ6.38 42.33 I26.65 42.52 126.98 41.82 127.68 41.32 I28.30 40.84 128.75 40.77 I29.13 40.23 129,B8 40.~ 130.48 39.64 130.78 630~.0 5190,41 3190.1 39.77 130.36 64~)~.0 5265,59 3255.8 41.25 127.37 65~0.0 5339.77 3322.8 42.11 125.21 66~.0 5413.15 3390,8 42.79 123.53 S7~.0 5487,45 3457.7 42.02 122.80 SBee. O 5562,61 3523. 69~).0 5638,10 3589. 7~)0~.O 5713,90 3G54. 7100.0 5789.90 3719. 7Z~.0 5866,08 3784. 73~. · 594Z. 3Z 74~N~. · 6019.18 7S~N). · 6~J5.97 7r::v~)~. e 617Z .45 6 41,27 120,54 1 40.98 12~.~S 2 40.71 120.32 Z 40.54 lZ1.15 · 4~,38 121.65 3848.7 40.32 122.87 3912.6 39.78 123.64 3976.7 39.63 I23.95 4~841.1 40.11 1Z4.?I .p~e 2 Date : Z4 Hay 1992 Latitude Oeparture /I~¢t 661.015 1397.3SE 0.09 696.145 1450.546 0.34 73 I. 955 1504. 506 0.77 768.255 1558.936 0.50 805.18S 1614.076 0.72 842.58S 1669.75E 0.56 880.495 1726,036 0.60 918.786 1782.Z86 e. Z4 957.325 1638.446 0.16 996.295 1894.406 e. Z8 1035,515 1950.246 0,1G 1074.615 2~5.676 0.29 1114.285 2061.156 0.13 II53,906 Z116.596 0.09 1193.625 2171.576 0.32 1233.835 ZZZ6.14E 0.36 IZ74.03S Z260.166 0.39 1314.675 2334.176 0.29 1355.435 2386.936 0,84 1396.355 2438.756 0.65 1437.Z85 2469.746 0.56 1478.506 2540.4~ ~.25 1519.73S 2590.106 0.65 1561.465 2638,996 0.56 1603.136 2687.306 0.40 1644. 556 2736. ~SE e. 30 1664.57S 2766.456 Z. 44 1723.236 2843. 246 1.67 1760.76S 269'9 . 676 I . 32 1797, ~2S 2956.136 0.92 1830.536 3012.946 I. 68 1863.37S 3~69.716 0.43 1696.3~6 312G.(~ZE 0.3Z 1929,926 3181.646 ~.57 1964.1 IS 3236. 676 0.48 1999.226 3291.OIE 0.66 ZO34.S65 3344.286 0.73 2070.43S 3397.426 0. ZI 2107.125 3450.386 0.56 SCIENTIFIC DRILLIN6 Outrun Survey UNOCRL Corporation 6-14R-RD Heaeured Vertical Vert. Inc Oepth Depth Section Oeg ??ee.O 6249.02 4105.4 40.03 7800.0 6325.42 41S9.8 40.18 7900.0 6401.81 4z34.3 40.19 8~.0 6479.92 4296.6 38.64 81~).0 6559.12 4357.6 37.6z Rzt.uth Deg 1ZS.Z4 IZS.SI 1ZS.4? IZS. I6 IZS.S1 8200.0 6641.79 4413.9 34.Z4 8300.0 6721.96 4473.6 36.71 8400.0 6801.02 4534.8 37.75 8500.0 6879.99 4596.1 37.85 8See.e 6959.30 4657.0 37.53 IZ3.24 121.82 121.01 120.85 121.47 8700.0 7037.86 4718.9 38.22 8800.0 7113.76 4783.8 40.63 89~N).0 7187.77 ~4850.9 42.Z6 9~.0 7Z63.29 4916.2 40.95 9100.0 7339.16 4981.1 40.65 IZI.S8 119.13 119.22 118.39 117.67 7416.41 5044.3 39.42 7493.92 5107.2 39.19 7572.83 5168.6 37.89 7650. Z1 5231.8 39.30 77Z9.95 5292.2 37.11 118.01 117.92 IZ0.10 119.96 123.66 97%e.0 7809.35 5353.0 37.45 9800.0 7887.49 5415.3 38.61 9900.0 7964.06 5479.5 40.03 1~.0 8~4Z.69 5541.3 38.15 101ee.0 8121.32 5602.8 38.16 124.23 IZO.e3 120,27 IZI.51 117.72 8zee. z8 5663.8 37.85 8z80.36 57z3.3 36.79 8360.95 5782.2 36.3~ 6441 . 5% 584 ! . I 36.34 852Z.16 5899.9 36.24 116.88 116.83 116.94 116.85 117.28 10700.0 8604.16 5956.9 34.92 1~800.0 6667.95 6011.4 33.08 le9ee. O 87'71.98 6065.5 3Z.82 11~.0 8857.18 SI17.8 31.57 Iilee.0 6943.17 6168.7 30.59 118. I20. 119. 119. 119. 84 08 40 69 IIZee. O 9030.15 6218.0 29.56 11300.0 9118.99 6263.9 Z7.33 11400.0 9208.48 6308.4 26.50 11500.0 9Z99,63 6349.5 Z4.Z6 119. 1Z0. IZ0. IZZ, 74 95 08 51 page 3 Date : 24 Hey 1992 Coordinates Latttude Departure D-leg Z323.215 3754. SeE 3.63 2 354.725 3805. 306 Z. 60 Z 386. Z 6S 3657.776 I . 1S 2417.725 3910.456 0.14 2449.535 3962.40£ 0.50 248Z.015 4015.056 0.71 2513.71S 4071.936 Z.90 2546.535 4130.6ZE 1.63 Z577.70S 4188.28E 1.41 2607.955 4245.986 0.56 Z637.775 430Z.046 l.ZS ZSST. 3SS 4357.886 0.23 Z698.166 4411.026 1.88 2729.795 4465.906 1.41 Z763.Z4S 4516.12E 3.17 Z797.445 4566.396 0.48 Z8Z8.67S 4620.416 Z.84 2861.09S 4675.976 1.43 2893.37S 47Z8.646 2.04 zgzz. IZS 4783.336 Z.34 2949.866 4838.~6E 0.60 Z976.90S 4891.51E 1.~S 30,8r3.TZS 4944.29E 0.49 3030.466 4997.16E 0.07 3~57.576 5~49.?~E 0.27 3085.18S 5099.84E !.60 311Z.496 5147.09E 1.95 3138.846 5194.47E 0.5? 3164.545 5240.09E 1.2S 3169.825 5284.43E 0.90 3214.295 5327.27£ I. 13 32 37.9 1 S 5366. 656 2.30 3Z Se. Z 85 5405. Z 66 0.9 Z 328Z. 366 5439. 946 2.45 2144.23S 350Z.9Z£ 0.35 2181.715 3555.446 0.23 ZZZe.075 3607.33£ 0.62 ZZSS.91S 3657.756 1.57 2292.37S 3707.446 1.09 SCIENTIFIC DRILLING UNOCRL Corporation 6-14R-RD Neasured Vertical Uert. Depth Depth Section 11600.0 9391.08 6390.0 11700.0 9482.60 6430.2 118~,~.0 9574.26 6470.2 119~,.0 9666.12 6509.7 1200,~.0 97S8.39 6S48.3 121~,0.0 9850.80 6586.5 1ZZ~.O 9944.03 SSZZ.S I230~.0 1~37.~,4 6659.2 124~.0 10130.~ 6695.8 IZSee.e 10ZZZ.99 6732.5 IZG~.O 10315.70 6769.8 I27~.0 1~408.40 6807.Z I28~.0 10501.79 6842.8 I2820.5 10520.95 6850.1 Outrun Survey Inc Rztmuth Beg Deg 23.86 I20.63 Z3.77 IZ0.79 Z3.56 IZZ.Z8 23.29 IZI.31 22.67 IZZ.TS Z2.48 IZ3.18 ZI.ZO lZG. I6 21.55 I26.93 Z1.54 I28.71 Z1.66 I28.32 ZZ.O! I29.45 ZZ.eZ IZ8.19 20.95 127.65' Ze.83 1Z7.80 page 4 Date : Z4 Nay 1992 Coordt nates D- 1 e~ Latitude Departure /l~)tt 3302.995 5474.75E 0.88 3323.62S 5S09.37E 0.12 3344.975 5543.17E 0.63 3365.515 5576.95E 0.47 3386.375 5609.36E e.84 3407.29S 5641.3GE e. ZS 3428.6ZS 5670.56E 1.69 3450.69S 5699.9ZE 0.45 3473.65S 5728.56E 0.66 3496.54S 5757.53E 0.19 3520.365 5786.47E 0.55 3543.545 5815.95E 0.47 3565.385 5844.Z6E 1.09 3569.85S 5850.02E 0.~ Bottom Hole Location= Measured Depth = 128Z0.5 Horiz. Di~pl. Closure Dir. = 6853.Z13 = 1ZI.393 AOGCC GEOLOGICAL idATERiALS iNVENTORY' LIST COMPLETION DATE b/ t ? 1,~''~- CO. CONTACT .... ~_.v/~.c..,~/ check off or list data as it is received.*list received date for 407. if not uired list as NFl 407 l * /o/~/?~ q drillin9 histo~ ! ~ I s.~eyJ / ! ~"" tests~A~ core descriptio~ cored inte~als core analysis j~ d~ ditch inte~ais .... digital data ' ~ ~ ~~ ~,,,,~) LOG ~,n=, ,r~_ i RUN INTERVALS SCALE ..... NO. {to the nearest foot~ ... (inchl100'] i ii ii I IL I1 ' ' ffl ( T r , . i i ...... / ~ ~1'~ ~ , ,~'~ / /V~ ~ 7a~7 ii ~1 i i LOG TYPE ' RUN iNTEFIvAj's scaLE _. .~ NO. {to the nearest foot~ (inchl100'J t :"~l ~1i ........ ~j' ,, i ~ ' I 38) ' .,t~! ....... i, ,,,11,1 , ,1 i 'l~l ': ' '"' ''~ ' ~ " ' I .... I , I I ALASKA OIL AND GAS CONSERVATION COMMISSION' WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 SEPTEMBER 24, 1992 GARY BUSH UNION OIL COMPANY OF CALIFORNIA P O BOX 190247 ANCHORAGE, ALASKA 9 9 519 RE:' 91-0139 TRADING BAY UNIT G-1RD COMPLETION REPORT 67-0047 TRADING BAY UNIT G-1 P&A PAPER WORK 91-0099 TRADING BAY UNIT G-14ARD COMPLETION REPORT 68-0080 TRADING BAY UNIT G-14 P&A PAPER WORK 69-0055 TRADING BAY UNIT G-14A P&A PAPER WORK 72-0021 GRANITE PT STATE 32-13 P&A PAPER WORK DEAR MR. BUSH, OUR FILES INDICATE THAT UNION OIL COMPANY OF CALIFORNIA IS THE OPERATOR OF THE REFERENCED WELLS. WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS FOR PLUGGING AND ABANDONMENT OR WELLS PRODUCING. AUGUST MONTHLY PRODUCTION REPORTS INDICATE THAT TWO WELLS ARE PRODUCERS FOR THIS YEAR. WE HAVE NO PAPER WORK (407 FORM) SHOWING THE COMPLETIONS FOR THESE WELLS OR PLUGGING AND ABANDONMENT OF THE ORIGINAL WELL (AS INDICATED). ACCORDING TO 20 AAC 25.010(C), "THE OPERATOR SHALL FILE WITH THE COMMISSION WITHIN 30 DAYS AFTER COMPLETION, ABANDONMENT, 'OR SUSPENSION OF THE WELL A WELL COMPLETION OR RECOMPLETION REPORT (FORM 407) AND ALL INFORMATION REQUIRED BY 20 AAC 25.070 AND 20 AAC 25.071." IT IS THE OPERATOR RESPONSIBILITY FOR COMPLIANCE WITH COMMISSION REGULATIONS. THIS PAPER AUDIT PROCESS IS GOING TO BE AN ON GOING PROCEDURE AS FACTS BECOME KNOWN, I HOPE YOU CAN CORRECT THESE SITUATION AS QUICK AS POSSIBLE. PLEASE LET ME KNOW IF THERE IS ANY PROBLEM WITH SUBMITTING THESE FORMS AS REQUIRED IN A TIMELY MANNER. S I NCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN Unocal North American/,.~. Oil & Gas Division r ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITYAL June 26, 1992 HAND DELIVERED TO: Larry Grant FROM: Kirk Kiloh 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Trading Bay Unit, McArthur River Field, G-14A well, AP1 # 507332018901 One each 2" and 5" sepia, and two each 2" and 5" bluelines as follows: Spectral Density, Bulk Density Spectral Density, Dual Spaced Neutron High Resolution Induction//~ Full Wave Sonic II ,/./~/ Six Arm Dipmeter (Pad correlations) ~ /~S~ Arm Dipmeter (Hole volume caliper) Dipmeter Computation 8'x2'x60° Dual Induction Short Guard .~,,'/-/~ ~.,/~ .//~ Dual Induction HRI Deep Curve Overlay Dual Induction HRI Side by Side Presentation RECEIVED JUN 2 ¢ 1992 Alaska Oil & Gas Cons. Commission Anchorage One each ,5,"~ps follows: SBT 9-5/8 ca~ing ~'/ ~) SBT presqueeze ( ?U /~ ~ SBT postsqueeze ( ? 9 ''/ J One each 2" and 5" sepia, and two each 2"~,~d 5" bluelines as follows: Borehole Volume for Six Arm/Djpmeter High Resolution Induction Dual Induction Short Guard Spectral Density Bulk Density ~ Plots - Mag: Declination Spectral Density Dual Spaced Neutron Full Wave Sonic II ,/~ '~ One each Digital Log LIS Tape and Listing One each sepia and blueline Epoch mudlog / One, 3-1/2" floppy disk and one gyro survey table by Scientific Drilling PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITI'AL By s,~I~ ~ ~~I~ o~ ~o~. ~~ ~o~. DATED: REC~.IVED JUN 2 6 ~99;! Alaska Oil & Gas cons. Gommlssion Anchorage Unocal North America~ Oil & Gas Division ' ! Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCAL ) DOCUMENT TRANSMITYAL May 28, 1992 HAND DELIVERED TO: Larry Grant FROM: Kirk Kiloh 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Trading Bay Unit, McArthur River Field, G-14A RD 3 boxes of dry samples: £ / 7,710- 9,450' 9,450- 11,100' 11,100- 13,050' RECEIVED Alaska Oil & Gas Cons. Commission Anchorage PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITFAL BY SIGNING AND RETURNING ONE COPY. THANK YOU. RECEIVED ~~~~ ~,~/ DATED: Unocal North AmericaE-~--~, Oil & Gas Division Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region May 20, 1992 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 G-14A RD SAMPLES Dear Larry: RECEIVED Alaska Oil & ~a~ &::,.,,~ ~mn~aJl~,Oj~ Pursuant to your telephone conversation of May 20, 1992, concerning inadequate washed and dried samples from 1560-1590' and 1620-1650' in Trading Bay Unit G-14A RD, I have contacted Epoch Mud Logging, vendor for this well, and have checked Unocal's set of samples to determine if adequate sample amounts exist which could be sent to you. I regret that in both intervals overall sample recovery was minimal and the amount which you received will have to be acceptable. I apologize, but as you are aware this situation does occur during the drilling of a well. In the past, as I hope in all future wells, Unocal will be able to provide the State with more than an adequate amount of washed and dried cuttings. Sincerely, Kirk D. Kiloh Senior Development Geologist KDK/pg cc: Wellfile Unocal North Americ~ Oil & Gas Division Unocal Corporation P.O, Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL DOCUMENT TRANSMITYAL Alaska Region April 23, 1992 TO: La~ Grant FROM: ~rk ~admg Bay Unit' Mc~hur ~v~i22;t'tT~x 2'°ws: .... ' 4 boxes of d~ cuttings ~ ~~~~~ ~~~ PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY SIGNING AND RETURb~ING O])IE COPY. THANK YOU. -4--0 APR OIL AND GAS CONSERVATION COMMIL 5N APPLICATION FOR SUNDRY APPROVALS Operation shutdown -- Re-enter suspended well __ Plugging ~ Time extension m Stimulate ~ Perforate __ Other 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well ~ Change approved program )4' Pull tubing __ Variance __ 2. Name of Op.e[ or /-~ (~)2~of,Well' Union O~ Company of California (~NO ~velo~ment.~_ - ] Exploratory 3.~d.d~e.ss Box 196247, Anch., AK, 995191-6247 Stratigraphic__ ! Service 4. Location of well at sudace Leg # 4, Conductor # 13, 1825' FSL & 1487' FEL, SEC. 29, T9N, R13W, SM At top of productive interval Hemlock @ 15304' MD 12003' MD, 1597' FNL & 4182' FWL, SEC. 33, T9N, At effective depth R13W 6' D a~l[~:~lCva~0~ ( %F~(~B(~ MS~et 7. Unitor~e~[~eBay Unit 8. Well number G-14ARD 9. Permitnumber · SM 91-0099 10. APInumher 50-- '7 33-20189-01 11. Field/Pool McArthur River/Hemloc ~totaldepth 1913' FNL & 4492' FWL, SEC. 33, T9N, R13W, SM 16,575' feet PlugS(measured) 10,404' feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 16,522 ' feet Junk (measured) true vertical 10,3 7 5 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural 520' 17-3/4" 700 sXS 520' 520' Conductor Surface 4477' 13-3/8" 2500 SXS 4477' 3389' 12,190' 9-5/8" 2450 SXS 12,190' 8072' Intermediate 11,700' 7" (Tieback) 1000 sxs 11,700' 7797' Production 4,875' 7" 800 SXS 11,700 '-16 ,¢%7~5~ ~.~7797 ' -10,404 Liner RECE IVl V Perforation depth: measured See Attached true vertical Single 3-1/2", MAR 2 ? 1992 Alaska 0il & Gas Cons. Commisstot Anchorage 9.2#, N-80, Speclal clearance Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) buttress w/tail @ 15,859' TM Baker FB-1 packer @ 15,800' Baker FB-1 packer @ 15,5~ 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation 115. Status of well classification as: February 26, 1992 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Water Injector 17. I hereby certify that the for¢~gi ng is true and correct to the best of my knowledge. Signed GARY S. BfL,TE~,~~' '~ ~ %~,¢~[,~'itle~RGZONA'1'. DRZT.T.ZNG ]~,AGER Date -...~>/~.~/ ~ O ' FOR COMMISSION USE ONLY Conditions of approval: Notify O~rCmis~'i'~n so representative may witnessI] Approval N o,,.~,..~/ Plug integrity ~ - BOP/Test ~ - Location clearance__ ~.., ,., Mechanical Integrity Test .X_ Subsequent form required 10- --r-,,, / ,,. ,... ,..:! L;.:.:q'~y / ORIGINAL SIGNED BY ...... ~i: ~.._7__~_~ ...... Approved by order of the Commissioner LO,N]~ C SMITH Commissioner Date Form !0-403 Rev 06/15/88 SUBMIT IN TRIPLICATE T1L%DING B~Y UNIT TBUS G-14A REDRILL DRILLING PROCEDURE 1. SKID RIG #55 OVER TBUS G-14A, LEG #4, CONDUCTOR #40. 2. KILL WELL WITH FIW WEIGHTED WITH NACL AS NEEDED. 3. INSTALL 13-5/8" 5M BOPE AND TEST TO 3000 PSI. 4. RECOVER EXISTING 3-1/2" SINGLE INJECTION COMPLETION. 5. SET A 7" CEMENT RETAINER AT 15243'. LAY A CEMENT PLUG (100 SXS) FROM THE TOP OF THE RETAINER TO 14672' TO ABANDON HEMLOCK PERFORATIONS FROM 15304' TO 16522' DIL. 6. SET A 7" CEMENT RETAINER AT 3820'. LAY A CEMENT PLUG (50 SXS) FROM THE TOP OF THE RETAINER TO 3550' TO ABANDON THE LOWER SECTION OF 7" CASING. 7. CUT AND RECOVER 7" CASING TO 1800' AND RECOVER THE 9-5/8" CASING STRING TO 1550'. RUN CBL FROM 1550' TO SURFACE. 8. SET A DRILLABLE BRIDGE PLUG IN THE 13-3/8" CASING ABOVE THE CASING STUBS AT 1520'. 9. LAY A 50' CEMENT PLUG ON TOP OF THE BRIDGE PLUG AT 15~0' TO COMPLETE ABANDONMENT OF THE CASING STUBS. 10. SQUEEZE FOR STABILIZATION, AS NEEDED. 11. MILL A WINDOW IN THE 13-3/8" AUXILLARY CASING FROM 1390' TO 1470'. 12. LAY A KICK OFF PLUG FROM 1500' TO 1300' 13. KICKOFF AND DRILL 10' OF FORMATION. PERFORM A LEAKOFF TEST. SQUEEZE SHOE, IF NECESSARY. REDRILL 12-1/4" HOLE FROM 1390' MD (1363' TVD) TO 7704' MD (6300' TVD). 14. RUN LOGS. RUN AND CEMENT 9-5\8" SURFACE/PRODUCTION CASING AT 7704'. 13. DRILL FLOATS AND 10' OF FORMATION. PERFORM A LEAKOFF TEST. SQUEEZE SHOE, IF NECESSARY. REDRILL 8-1/2" HOLE FROM 7704' MD (6300'TVD) TO 13523' MD (10712' TVD). 14. RUN LOGS. RUN AND CEMENT 7" LINER FROM 7520' MD TO RECEIVED 15. CLEAN OUT LINER. TEST LAP AND SQUEEZE, IF NECESSARY. MAR 2 ? 1992 Alaska Oil & Gas Cons. commiSsior' Anchorage 16. CHANGE OVER TO COMPLETION BRINE. PERFORATE WEST FORELAND BENCHES 1 THRU 7. ACID STIMULATE IF NECESSARY. 17. SET PERMANENT PACKER ABOVE THE WEST FORELAND. SET ISOLATION PLUG. 18. PERFORATE HEMLOCK BENCHES 1 AND 4. ACID STIMULATE IF NECESSARY. 19. RECOVER ISOLATION PLUG. RUN SINGLE COMMINGLED INTERNALLY COATED INJECTION COMPLETION. RECEIVED I~AR ~/' 1992 Alaska Oil & Gas Cons. Commission Anchorage TRAD'rNG B~Y UNIT TBUS G-14& REDRILL ~NTICIP~TED ~RESSURES~ ,NAX, IMUM SURFACE PRESSURE C~LCUL~TION FOR HUD WEIGHT 13-3/8" CASING SHOE DEPTH 13-5/8" C/~ING SHOE FRAC GI~tDIENT TD OF 9-5/8" CASING POINT PORE PRESSURE GI~DIENT' 10.6 PPG = 0.551 PSI/FT ~?d' MD /~6~. ' TVD 0.90 PSI/FT 7704'MD / 6300t TVD 0.460 PSI/FT 0.0 PSI/FT A~SUME THaT 25~ OF THE WELLBORE IS DISPLACED DURING A GAS KICK ( HOLE FILLED WITH 75~ MUD AND 25~ GA~ ). M~XIMUM SURFACE PRESSURE = BHP- MUD/GAS HYDROSTATIC PRESSURE liSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(6300 FT * .460 psi/ft) -((.75 (6300 FT * ~551 PSI/FT)) + (.25 (6300 FT * 0 PSI/FT))) 294 PSI ,M~X,. IMUM SURFACE PRESSURE C~LCUL~TION FOR. 8-1/2" HOLE MUD: WRIGHT i 9-5/8" CASING SHOE DEPTH 9-5/8't CASING SHOE FRAC GRADIENT TD OF 7'* CASING POINT PORE PRBSSURB' GRADIENT GAH~ GRADIENT 9.6 PPG = 0.500 PSI/FT" 770'4' MD / 6300' TVD 0.95 PSI/FT 13523' MD / 10712' TVD 0.460 PSI/FT' 0.0 PSI/FT ASSUME THaT 25~ OF THE WELLBORE'ZS DISPLACED DURING KZCKi ( HOLE FZLLED WITH 75~ MUD-~ND 25~ GAS' ). MAXIMUM SURFACE PRESSURE'-- BHP- MUD/GAS HYDROSTATIC PRESSURE MSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(10712 FT * .'460. pSi/ft) -((.75(10712 FT'* .500 PSI/FT)) + RECEIVED MflP = 911 PSI' MAR 2 7 1992 Alaska 0il & Gas Cons. Commission Anchorage 17-1/2' @ S20' 13-3/8", 61 # J-55, Bu'Fr @ TOP OF WINDOW 9-S/8', 47#, N-80, BUTT @ 7704' MD 7', 29#, N-80, BUTT UNER @ 13523' MD 1) 2) 4) TUBING DETAIL 3-1/2', 9.2#, N-80 TUBING W/TK-99 COATING & HYDRIL CS-CB CONNECTIONS · XA" SLIDING SLEEVE PERMANENT PKR @ 11900' MD · X' LANDING NIPPLE (3-1/2') WIRELINE RE-ENTRY GUIDE PERMANENT PKR @ 12600' MD · X" LANDING NIPPLE (2-7/8") RE-ENTRY GUIDE TOP OF 7", 29# N-80, Bu'Fr UNER @.7400' MD HEMLOCK HB-1 HEMLOCK HB.,4 · RECEIVED MAR 2 7 1992 Alaska 0il & Gas Cons. Anchorage WEST FORELAND BENCHES 1 THRU 7 WELLTBUS G-14ARD PROpOsED'CQMPLETiON UNION OIL COMPANY OF CAUFORNIA (dba UNOCAL) i ii i iii i i i DRAWN: Gl:lB SCALE: NONE DATE: 1-25-92... =1 MSP CALC PAGE 2 THE GREATEST HYDROSTATIC PRESSURE AT THE 9-5/8" SHOE (HPsh) IS WHEN THE GAS BUBBLE REACHES THE SHOE, IF A CONSTANT BHP IS APPLIED. A CONSERVATIVE ESTIMATE WOULD BE THE MAXIMUM SURFACE PRESSURE (MSP) PLUS THE HYDROSTATIC PRESSURE AT THAT CASING DEPTH (HPcsg). HPsh = MSP + HPcsg HPsh = 911 PSI + ( 6300 FT * .500 PSI/FT ) = 4061 PSI FPsh = FRAC GRAD * TVDshoe FPsh = 0.95 PSI/FT * 6300 FT = 5985 PSI HPsh = 4061 PSI IS LESS THAN THE FRACTURE PRESSURE AT THE 9-5/8" SHOE, FPsh = 5985 PSI AND THEREFORE ADEQUATE TO HANDLE THE WELL KICK. THIS SCENARIO IS CONSIDERED EXTREME, SINCE A 240 BBL ENTRY IS REQUIRED TO DISPLACE 25 PERCENT OF THE WELL BORE. RECEIVED MAR ~ 7 199~ Alaska Oil & Gas Cons. (;ommisSiOn Anchorage TRADING BAY UNIT TBUS G-14A REDRILL MUD PROGRAM PLUG AND ABANDONMENT MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH 9.4 TO 9.6 PPG 50 TO 70 SEC/QT 8 TO 15 CP 15 TO 25 #/100 SQ FT 9 TO 10 13-3/8" WINDOW MILLING MUD WEIGHT FUNNEL VISCOSITY 9.6 TO 10.0 PPG 70 TO 100 SEC/QT 12-1/4" HOLE SECTION I 9-5/8" .CASING 1535' TO 5000' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS SOLIDS 9.6 TO 11.0 PPG 40 TO 55 SEC/QT 8 TO 18 CP 12 TO 20 #/100 SQ FT 9 TO 10 8 TO 10 CC 3 TO 6 PERCENT 5000' TO 7704' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ ZOO SOLIDS 9.6 TO 11.0 PPG 40 TO 55 SEC/QT 12 TO 20 CP 12 TO 20 #/100 SQ FT 9 TO 10 6 TO 8 CC 18 TO 20 CC 7 TO 10 PERCENT RECEIVED MAR ? 199: Alaska Oil & Gas Cons. Commission Anchorage MUD PROGP, AM PAGE 2 8-1/2" HOLE SECTION I 7" CASING ??04' TO 13523' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ 2O0 SOLIDS 9.1 TO 9.6 PPG 45 TO 55 SEC/QT 12 TO 10 CP 8 TO 16 #/100 SQ FT 9.5 TO 10.5 4 TO 6 CC 15 TO 18 CC 5 TO 8 PERCENT RECEIVED MAR ~ ? 1992 Alaska Oil & Gas Oons. [;ommissior~ Anchorage GREAT LAND DIRECTIONAL DRILLING, INC. Corporate office 1111 East 80th Avenue Anchorage, AK 9951.8 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for UNOCAL CORPORATION Well ......... : G-14A-RD (P10) Field ........ : McAURTHUR RIVER Section at...: 122.23 KB elevation.: 103.00 ft Computation..: RADIUS OF CURVATURE Prepared.: 03/26/92 STATION IDENTIFICATION TIE-IN END BUILD & TURN 9-5/8" CASING PT TARGET A TARGET B TOP WEST FORELAND TD 7" LINER SHOE PROPOSED WELL PROFILE MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST 1400 1500 1600 1700 1800 19.89 1373 1270 157 21.11 1466 1363 186 22.49 1559 1456 219 24.00 1651 1548 255 25.60 1742 1639 294 1900 27.30 2000 29.06 2100 30.88 2200 32.75 2300 34.66 1832 1729 337 1920 1817 383 2006 1903 432 2091 1988 485 2174 2071 540 2400 36.60 2500 38.57 2590 40.38 7704 40.38 11711 40.38 2256 2153 598 2335 2232 659 2405 2302 716 6300 6197 4028 9353 9250 6624 12460 12460 13495 13523 40.38 9923 9820 7109 40.38 9923 9820 7109 40.38 10712 10609 7780 40.38 10733 10630 7798 DIRECTION REL-COORDINATES DL/ AZIMUTH FROM-WELLHEAD 100 86.32 10 N 191 E <TIE 91.71 10 N 226 E 1.4 96.51 7 N 263 E 1.5 100.75 2 N 302 E 1.7 104.51 8 S 343 E 1.8 107.84 20 S 386 E 1.8 110.80 36 S 430 E 1.9 113.45 54 S 477 E 1.9 115.82 76 S 525 E 2.0 117.97 102 S 574 E 2.0 119.91 130 S 625 E 2.1 121.69 161 S 677 E 2.1 .123.16 192 S 726 E 2.1 123.16 2004 S 3499 E 0.0 123.16 3424 S 5672 E 0.0 123.16 3689 S 6078 E 0.0 123.16 3689 S 6078 E 0.0 123.16 4056 S 6640 E 0.0 123.16 4066 S 6655 E 0.0 Alas/<a Oil & Gas Cons. Commission Anchorage UNOC^L CORPOR^TION Hcrk~r [dentlftcot, ton H3 ~ ~ I~ A> TIE-IN ~4~ ]~ 1~ t~ ~ B> END BUI~ g ~H. ~ 24~ 716 4~ C> 9-5/8' CASI~ PT ~ ~00 4~ 4~ D> T~G~A H7~t 9~ 8~4 4&~ D TARG~ B 124~ g~ 71~ 4&~ F) TD [34~ ~07t2 ~80 4~ ~ G-14^-RO (PLO) VERT I C^L SECT I ON V I EW Section at: 122. 23 TVD Scale.: I inch- 1500 feet R EE E IV E ?' LINER SHOE 19529 10799 ~/9S 4~9~ Scale. 1 Inch = 1500 feet JOravn ..... : 09/26/92 MAR 2 ? 199 ;o-~ ~ I Alaska Oil & Gas Cons. I Land Directional iD-- Ai ~ ~ IIIIII1~111111111~11111111111111 ~ IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII \ II I I I III III I I!11 I II II III I iD-- ~ I I I I I I I I I I I I I I I I } I I I I I I I I I I I I I I I .~ IIIIIIIIIIIIIIIIIIIIIIIIIIIII111 ~ "~, I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII 0-- ~ ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I IIIIIlllllllllllllllllllllllllll ~ ~ IIIIIIIIIIIIIIIIIIIIIIIIIIIIIII1 .... , . Illlllllllllllllllllllllllllllll 0 ..... ''' '~ ~1IIII IIIIIIIIIIIIIIII!11111111111 I' ~ IIII I III IIIIIII IIIIIII I I IIII III I ~ '~ I I I I I I II I I I I I I I I II I I I I I I I I II IIIIIIII Illllllllllllll[I, iiiillll ~ ' J JlJll Il I I I I I I I I Il I I I '~ ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ', '~ I I I I I I I I I I I I I I I I I I I I I ~ ~ IIIIII IIIIIIIIIIIIIIIII I IIII '~ h u~ok~l~b~6 kd~ol~Ho~l I I I I I I I I I I I I t I I I ] " ] '~ I I I I I I I ~ I I I I II I II I I I II I I I I I I~, I I I I I I I I I~11 I I I I I I I I I I I I I I I I I I I I I · I I I I I I I I I I~l I I I I I I ! I I I I I I I I I I I I I [ ] ~1 I I I I I I I I I I II I I I I I I I I I I.I I I I I I I I I I I I I~l I I I I I I I I I I I I I I { I I I I I~1 III I I III I I I!1 I I I I I ~1 I I I I I I I I I I I I I I I~d I I I I I I I I I III Ill I~llllll Illll I I I I I I I I I I I I~1 I ~ ~ I I I I ~ I I ~ I I I ~ I I'1~ I I I I I I I I I I I I I~ I I I I I I I I I I I I I I I I I I I'"kJ { { I I I I I I I ! I I ~ I I I I I II I I I I I I I I II I I1'% ,,,,,,,, ! I I I I I III I I I I I I I I I~l I I i I I I III I I I I I I I.I I I I I I I I I I I~1 I I I I I I I I I I I I I I I I I I I I I I I I I'1 I I I ~t'~--I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I-I I I I I I I I I I I I I I I IIIIIIIIIIllllllll II Illl Il I I I I I I 0 750 1500 2250 9000 9750 4500 5250 8000 8750 ?500 ~250 8000 8150 S~ctlon Departure ~mission I Qr at Land Directional 'Drll G-14^-RB (PLO) PLAN VTE , CLDSURE ..... , 778[ ft ot Azimuth 12~42 DECLINATIDN.~ 22.99 E SCALE ....... m !tnch = 1500 feet DRAWN; ...... , 02/28/92 UNOCAL CORPORAT I ON Harkar I dantlf lcatlon ND N/5 E/W A) TIE-IN 1400 lQ N I91 E B) END BUILD 8, TURN 2590 192 S 726 E C) 9-5/8' CASING PT 7704 2004 S 2499 E D) TARGET A 11711 9424 S 5672 E E) TARGET B 124§0 3689 S 6078 E F) TD 13495 4058 S 6640 E G) 7' LINER SHOE 13529 4066 S 6~5 E · Illllll Ililll IIIllll lllil{ Illllll IIIIII IIIIIII Itllll IIIIIII IIIIII IIIIIII IIIIII IIIIIII II1111 . Illllll IIIIII I ~- -~ IIIIIII IIIIII '~ ~ I I I I I I I I I I I I I ~. ~ I I I I I I I I I I I I I '~ '~ I I I I I I I i I I I I I ~. I I I I I I I I i I I I I ~ ~. I m I I I I I I I I I I I ~ ~ IIIIIII IIIIII ' ~ IIIIIII IIIIll ~ ~x I I I I I I I I I I I I I , '% % Ill I Il I Il I Ill ' · ~. IIIIIII IIIIII ~. 'x I I I I I I I I I I I I I N~ \ '' Illllll Illlll '~' x I I I I I I I I I I I I I ~ ~ IIlllll Illlll I ~ ~ ~ I I I I I I I I I I I I I %~ N mllllll IIIll) ~. N~ ! I ! I I I I I I I I I I '~ ~, I I I I I I I I I I I I ' ~ II I I I I I II I I I ! ~ ,~ I I I I I I I I I I I ] ~ ~ Illllll IIlll ~ IIIIIII I!!11 N I I ! I I I I I'! ! I ) ~N~ I NII I I I I I I I I %~. I I~1 I I I I I I I ! ~b I I I~l I I I I I I I I I I I\1 I I I I I I I ll t[kll I[[[[ ) i ___L ........... L ___L .............. L . ~ 750 O 750 ] 500 ~50 3~0 ~750 4~0 ~50 5000 ~50 7500 9250 6000 9750 10~0 I 1250 12000 12~0 <- WEST = EA~ -> (I~.GO (c)92 GI4,AP9 B1.30 12m 25 PM ~) FROM:KONICA FAX, T0:2637884 ..~.AR 2G, lgg2 3:26PM GREAT LAND DIRECTIONAL DRILLING INC. P. 02 i~ I I1,... I ii III .I IIIII ijJ. i Close Ar)pro,ch Analysis ~J' I II ii · I1£ iiil iii W;~ G-14A Redrlll 1400' MD KOP .... . .... · ji Iii I i M~Aurthur River iiii I I · IIIII _ III1_ i iii; c,....y UNOCAL Corporatio,n. .... Iii i . i i I u I 11 ~ ,' ,TT~-o~~ George-Buck ' i1_ II I I .. III i i "~1~ March 26, 1992 i1 i i,, i .~1 I ill t II .il F- -- I1". I ~1 I I1_ _. I : .... WELL CROSSINGS , ~ ! ! L I I I I IU I Ju ' I - Illl · ,CfM.lng Well IVD TVD DI.tance Above/Below ii:- . G-33 3830 1496 2340 ABOVE __1.11 I I L--I I --[J[I III- G-20 1734 1587 1147 ABOV; 0-21 4461 2939 1522 ABOVE M-01 3-532 4802 1270 BEL6W ......... ~..... , M-28 . 3628 5080 1452 BELOW ...... M-25 6111 5273 838 ABOVE II i1! ii ii 11 _ILL .i i M-20 ?602 5312 2350 ABOVE i Il I I i i Ill . ,,,, Il G-21 7771 5635 2136 ABOVE M-27 3823 5939 2116 BELOW M-3 .... 4752 " 6453 1701 BELow ,,1 m I i II I ,i I , i I I I II -- i)ij~W lULl II ELLS WITHIN 100 FEET OF PROPOSED WELL v¥ ~ '" . _ II ~ ~., I'r _1 Ih · Cloee App,a&eh D~n~ Ran~ wl~ wall I il I $. IL i ill ]il G,14~ 0 1500 1373 to 19 I0 G-il 66 15~ 1373 to 1952 I I.. Ii i II I 0-08 49 1600 1373 tO 1609 .. iii w... G.."...d ,o.,,. W'd. C~o.-~.., ,,,, .. 0,10t8D D 0-1~ 0 I II 0.40 D ~-~o o I I II _ I L! .... 0,01 0 G,21 0 i iii OM:I~ O 0-22 '0 i II O,,OIRD G 0-23 G . ....... · . i .._jl~ iii i , , i Pi_ i i i 1. ~ ~ 0.~7 o I Lit J, II ! 0.04RD O 0.28 0 .~ i.u io -- 0.os G O.~lll o i. i - . ,~ , .,1 0.G81~ CI 0.81 G iii _- L I I I I 0.07 e 0.O2 O , .,~-.., i -- III i i I~ . ~,..,.. ,.,, i i 0'0~) O 0-34flo 0 L . JII I i II : ~'IOIW o O*$1IDm Q Il i I I 11II l O-I 1 4l M.I · _Lii, _1 I I _ ........... 0.t4 O M.6 O 0.14A a M-13 O , ,,~.. . ....... 0-t6 O M-14 O ..... ~ ... ~-18 G M,16 O .%.. , ,, ii _1 0.17 · M-16 o 1. ii i ILl I I i ~1,17R0 O M-27 O II II ..... - __~ · * .i i._.1L ii i G. llDflH 4) Id-lL~ U L. [i i i Suwey Statuet P - Planned 13 - MWO G -Gyro Survey i I · UIII I I I.J. l__ ._ I I I _ _ · i,... I I_ -- coMMENTS .., '" , , · r' ...1'" _ I ...... , I'111 ,,'r' ' t . , .... t , t The profile for G-14A redrill wes computed from parameters supplied by Unocal Corporation, This profile consists of a KOP 1~1400 MD 1373 TVD, with a constant tangential dooleg of 2.26~1100. The constant dogie0 consists of a 36.84· turn to the right to an azimuth of 123.16 & an 20.49~ inclination build to 40.38a. This turn and build is completed at 2590 MD, 2405 I'VD, and the final inclination and direction is held to the target st 11711 MD, 9353 TVD, and the TD at 13523 MD, 10712 TVD, The profiles for the existing wells in the Grayling Platform area were computed from directional surveys supplied by Unocal Corporation and or Marathon Oil Company. G-14A redrtll will have 10 crossings with existing wells in the are~, as outlined above. The close .pproaohing well, to G-14A RD within 100fl are shown ,hove, ,ro~l.tl~ ~O~t,~th~j}.o. where ~ the well separation distance exceeds 100 ft. I-/v I- I) I, .. ' · ,. ' ' I1" '1 , ,m., ~ I I I __ __ ~ ANALYSIS BY: _q_ D. Aklostsd ~' CHECKED BY: D. Thompson MAR 2 7 1992 Alaska 0il .A Gas Cons. Commissio~ Anchorage Unocal North Americ?~' Oil & Gas Division .~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region February 28, 1992 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Change of Approved Redrill Program, Well G-14A Lease Number ADL-18730 Dear Mr. Crandall: Union Oil of California, as Operator of the Trading Bay Unit, hereby requests approval for changes in the redrill program approved under permit 91-99 dated 7/15/91. The 8-1/2" hole section will be deepened through the base of the West Foreland reservoir to 13727' TMD (10712' TVD). The well will be completed as a commingled Hemlock Benches 1 and 4 / West Foreland Benches 1 through 7 water injector. The location for the Hemlock will optimize the peripheral flood on the east side of the main feature by moving the point of injection closer to the offset crestal withdrawal points. The additional pressure support will augment recovery by 1.8 MMBO. The location in the West Foreland will provide an additional peripheral injection point in a reservoir that is lacking overall pressure maintenance. This well will increase sw~e~ efficiency augmenting recovery by 1.2 MMBO.N~CE~VED Your approval of this request will be appreciated. MAR - 2 1992 Very truly yours ,Alaska Oil & Gas Cons. t;omm'~ss'to~ ,., ~chorage $ ush · Re~ona~ Drilling Hana~er attachments ~tz- Tvo 0 R I § I N A L AL-A~KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOFI SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __X Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator . . ! 5. ~_~o~Well: 6. Union 0il Company of California (~NO_~ALOevelopment__ Dxu~eCe---n~'r--~) MS~eet J Exploratory __ 3~_Ad~ress ............ K, 995191624? Stratigraphic 7. t'.O. UOX ±~bZ~/, ancn., a 'F ServiceZ Unit°~P~[Y~3rn~ay Unit / 4. Location of well at surface Leg #4, Conductor #13, 1825' FSL & 1487' FEL, SEC. 29, T9N, R13W, SM At top of productive interval Hemlock @ 15304' MD 2649' FNL & 2822' FWL, SEC. 34, T9N, R13W, SM At effective depth At total depth TD '@ 16575 ' MD 3583' FNL & 3362' FWL, SEC. 34, T9N, R13W, SM 8. Well number G-14A~ 9. Permit number 10. APl number 50-- '~33-20189-~! 11. Field/Pool McArthur River/Hemloc] 12. Present well condition summary Total depth: meaS'ured true vertical 16,575' feet Plugs (measured) 10,404 ' feet Effective depth: measured 16,522 ' true vertical 10,375 ' feet Junk (measured) feet Casing Length Size Structural 520 ' 17- 3/4" Conductor Surface 4477 ' 13-3/8" 12,190 ' 9-5/8" Intermediate 11,700' 7" (Tieback) Production 4,875 ' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 700 SXS 520' 520' 2500 SXS 4477' 3389' 2450 SXS 12,190' 8072' 1000 SXS 11,700' 7797' 800 SXS 11,700'-16,575' 7797'-10,404' See Attached RECEIVED true vertical MAR - 2 1992 Nas_ka Oil & Gas Cons. OommiSS'~or~ Tubing (size, grade, and measured depth) ~nchorage Single 3-1/2", 9.2#, N-80, Special clearance Packers and SSSV (type and measured depth) buttress w/tail @ 15,859' TM Baker FB-1 packer @ 15,800' Baker FB-1 packer @ 15,52~ ' 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencingoperation 15. Status of well classification as: February 26, 1992 16. If prQDosal wa~s_~erb8ll¥ approved Oil Gas Suspended MiKe. Mlncter 2/28/92 -- -- -- Name of approver Date approved Service Water In j ector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedG~Y S. BUS}~, o,.,~ C~ (~,.~,~.tle~EGIONAL DRILLING M~NAGP,,R Date ~ 0 ' FO" COMMISSION USE ONLY Conditions of approval: NOtify Co'mfnission so representative may Witness Plug integrity __ BCP/Test __ Location clearance __ Subsequent form required 10- ~-O ~ Mechanical Integrity Test ~)(_ . ORIGINAL SIGNED BY LONNIE O, SMITH Approved by order of the Commission I Approval No. /'.'~ i'.~ ~3 ;'or ~; d C; ~:-!3'; Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TRADING BAY UNIT TBUS G-14A ORIGINAL BOLE PERFORATION RECORD MEASURED DEPTH 15,304' - 15,340' 15,380' - 15,431' 15,464' - 15,540' 15,572' - 15,630' 15,664' - 15,700' 15,734' - 15,785' 15,815' - 16,050' 16,080' - 16,280' 16,310' - 16,522' TRUE VERTICAL DEPT[{ 9,782' - 9,747' 9,768' - 9,796' 9,813' - 9,853' 9,870' - 9,901' 9,919' - 9,938' 9,956' - 9,983' 9,999' - 10,123' 10,139' - 10,245' 10,261' - 10,373' REC£iV£D UAR - t t992 Alaska Oil & Gas Cons. Corniness'ton Anchorage TRADING BAY UNIT TBUS G-14A REDRILL DRILLING PROCEDURE 1. SKID RIG #55. OVER TBUS G-14A, LEG #4, CONDUCTOR #40. 2. KILL WELL WITH 64 PCF SPUD MUD. 3. INSTALL 13-5/8" 5M BOPE AND TEST TO 3000 PSI. 4. RECOVER EXISTING 3-1/2" SINGLE INJECTION COMPLETION. 5. SET A 7" CEMENT RETAINER AT 15170'. DOWN SQUEEZE WITH 300 CU FT OF CLASS "G" CEMENT TO ABANDON HEMLOCK PERFORATIONS FROM 15304' TO 16522' DIL. 6. CUT AND RECOVER 7" CASING FROM 3700'. 7. SET A 9-5/8" CEMENT RETAINER AT 3690'. CUT AND RECOVER 9- 5\8" CASING FROM 3500'. LAY A 250 CU FT CEMENT PLUG FROM THE RETAINER INSIDE THE 9-5/8" CASING AT 3690' TO 3300' TO ABANDON THE CASING STUBS. 8. RUN CBL FROM 3400' TO 1400'. SQUEEZE FOR STABILIZATION, AS NEEDED. MILL WINDOW IN 13-3/8" CASING FROM 3050' TO 3130'. 9. LAY CEMENT PLUG FROM 3300' TO 2800'. CLOSE THE UPPER PIPE RAMS AND BRAIDEN HEAD SQUEEZE THE 13-3/8" CASING SHOE. 10. KICKOFF AND DRILL 10' OF FORMATION. PERFORM A LEAKOFF TEST. SQUEEZE SHOE, IF NECESSARY. REDRILL FROM 3050' TO 11240' (12-1/4" HOLE). 11. RUN LOGS. RUN AND CEMENT 9-5\8" CASING AT 11240'. 12. DRILL FLOATS AND 10' OF FORMATION. PERFORM A LEAKOFF TEST. SQUEEZE SHOE, IF NECESSARY. REDRILL FROM 11240' TO 13727' (8-1/2" HOLE). 13. RUN LOGS. RUN AND CEMENT 7" LINER FROM 10940' TO 13727'. 14. CLEAN OUT LINER. TEST LAP AND SQUEEZE, IF NECESSARY. 15. CHANGE OVER TO COMPLETION BRINE. 'PERFORATE WEST FORELAND R£CElX/£D 16. SET PERMANENT PACKER ABOVE THE WEST FORELAND. SET ISOLATION PLUG. B~R 17. PERFORATE HEMLOCK BENCHES 1 AND 4. ACID STIMULATE~iaska0iI&GasG°ns'G°m~Is~ 18. RECOVER ISOLATION PLUG. RUN SINGLE COMMINGLED INTERNALLY COATED INJECTION COMPLETION. TI~.DIN~ B~Y UNIT TBUS G-14A REDRILL ANTICIPATED PRESSURES: MAXIMUM SURFACE PRESSURE CALCULATION FOR 12-1/4" HOLE MUD WEIGHT 13-3/8" CASING SHOE DEPTH 13-5/8" CASING SHOE FRAC GRADIENT TD OF 9-5/8" CASING POINT PORE PRESSURE GRADIENT GAS GRADIENT 72 PCF = 0.500 PSI/FT 3050' MD / 2582' TVD 0.90 PSI/FT l1240'MD / 8790' TVD 0.450 PSI/FT 0.0 PSI/FT ASSUME THAT 25% OF THE WELLBORE IS DISPLACED DURING A GAS KICK ( HOLE FILLED WITH 75% MUD AND 25% GAS ). MAXIMUM SURFACE PRESSURE = BHP - MUD/GAS HYDROSTATIC PRESSURE MSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(8790 FT * .450 psi/ft) -((.75 (8790 FT * .500 PSI/FT)) + (.25 (8790 FT * 0 PSI/FT))) MSP = 659 PSI THE GREATEST HYDROSTATIC PRESSURE AT THE 13-3/8" SHOE (HPsh) IS WHEN THE GAS BUBBLE REACHES THE SHOE, IF A CONSTANT BHP IS APPLIED. A CONSERVATIVE ESTIMATE WOULD BE THE MAXIMUM SURFACE PRESSURE (MSP) PLUS THE HYDROSTATIC PRESSURE AT THAT CASING DEPTH (HPcsg). HPsh = MSP + HPcsg HPsh = 659 PSI + ( 2582 FT * .500 PSI/FT ) = 1950 PSI FPSh = FRAC GRAD * TVDshoe FPsh = 0.90 PSI/FT * 2582 FT = 2323 PSI RECEIVED It AR - 2_ 1992 Alaska Oil & Gas Cons. CommisstOt~ Anchorage HPsh = 1950 PSI IS LESS THAN THE FRACTURE PRESSURE AT THE 13-3/8" SHOEv FPSh = 2323 PSI AND THEREFORE ADEQUATE TO HANDLE THE WELL KICK. THIS SCENARIO IS CONSIDERED EXTREME, SINCE A 418 BBL ENTRY IS REQUIRED TO DISPLACE 25 PERCENT OF THE WELL BORE. MSP CALC PAGE 2 MAXIMUM SURFACE PRESSURE CALCULATION FOR 8-1/2" HOLE MUD WEIGHT 9-5/8" CASING SHOE DEPTH 9-5/8" CASING SHOE FRAC GRADIENT TD OF 7" CASING POINT PORE PRESSURE GRADIENT GAS GRADIENT 72 PCF = 0.500 PSI/FT 11240' MD / 8750' TVD 0.90 PSI/FT 13727' MD / 10712' TVD 0.450 PSI/FT 0.0 PSI/FT ASSUME THAT 25% OF THE WELLBORE IS DISPLACED DURING A GAS KICK ( HOLE FILLED WITH 75% MUD AND 25% GAS ). MAXIMUM SURFACE PRESSURE = BHP - MUD/GAS HYDROSTATIC PRESSURE MSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(10712 FT * .450 psi/ft) -((.75(10712 FT * .500 PSI/FT)) + (.25(10712 FT * 0 PSI/FT))) MSP = 803 PSI THE GREATEST HYDROSTATIC PRESSURE AT THE 9-5/8" SHOE (HPsh) IS WHEN THE GAS BUBBLE REACHES THE SHOE, IF A CONSTANT BHP IS APPLIED. A CONSERVATIVE ESTIMATE WOULD BE THE MAXIMUM SURFACE PRESSURE (MSP) PLUS THE HYDROSTATIC PRESSURE AT THAT CASING DEPTH (HPcsg). HPsh = MSP + HPcsg HPsh = 803 PSI + ( 8790 FT * .500 PSI/FT ) = 5198 PSI FPSh = FRAC GRAD * TVDshoe FPsh = 0.90 PSI/FT * 8790 FT = 7911 PSI HPsh = 5198 PSI IS LESS THAN THE FRACTURE PRESSURE AT THE 9-5/8" SHOE, FPsh = 7911 PSI AND THEREFORE ADEQUATE TO HANDLE THE WELL KICK. THIS SCENARIO IS CONSIDERED EXTREME, SINCE A 240 BBL ENTRY IS REQUIRED TO DISPLACE 25 PERCENT OF THE WELL BORE. RECEIVED MAR - 199 Alaska Oil & Gas Cons. Comm'~ssion .'.Anchorage. TRADING BAY UNIT TBUS G-14A REDRILL MUD PROGRAM PLUG AND ABANDONMENT MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH 70 TO 72 PCF 50 TO 70 SEC/QT 8 TO 15 CP 15 TO 25 #/100 SQ FT 9 TO 10 13-3/8" WINDOW MILLING MUD WEIGHT FUNNEL VISCOSITY 70 TO 72 PCF 70 TO 100 SEC/QT 12-1/4" HOLE SECTION I 9-5/8" CASING 3200~ TO 5000' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS SOLIDS 70 TO 72 PCF 40 TO 55 SEC/QT 8 TO 18 CP 12 TO 20 #/100 SQ FT 9 TO 10 8 TO 10 CC RECEIVED 5000' TO 7000' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ 200 SOLIDS MAR - 2 ~992 Alas..ka .Oil .& Gas Cons. Commission 72 TO 75 PCF ~chomge 40 TO 55 SEC/QT 12 TO 20 CP 12 TO 20 #/100 SQ FT 9 TO 10 6 TO 8 CC 18 TO 20 CC 7 TO 10 PERCENT MUD PROGRAM PAGE 2 7000' TO 11240' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ 200 SOLIDS 72 TO 75 PCF 45 TO 55 SEC/QT 12 TO 20 CP 12 TO 20 #/100 SQ FT 9 TO 10.5 4 TO 6 CC 15 TO 18 CC 7 TO 10 PERCENT 8-1/2" HOLE SECTION I 7" CASING 11240' TO 13727' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ 200 SOLIDS 68 TO 72 PCF 45 TO 55 SEC/QT 12 TO 10 CP 8 TO 16 #/100 SQ FT 9.5 TO 10.5 4 TO 6 CC 15 TO 18 CC 5 TO 8 PERCENT RECEIVED Alaska Oil & (~as Cons. Anchorage BELL NIPPLE I FLOWLINE ,3" KILL LINE WITH TWO 3" 5M VALVES I ,J ...... d; KILL LINE FROM MUD PMP & CEMENT UNIT 13--5/8" 5000 PSI ANNULAR PIPE RAMS BLIND RAMS I PIPE RAMS I .1 ,, I ,i 1,.3-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" SM FLANGE · ]4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4" 5M VALVE ,]. I CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5,/8" 5M FLANGE RISER I 1 10" 5M x 1,.3-5/8" 5M ADAPTER CAMERON 5M SPOOL RECEIVED MAR - 2 1992. Alaska 0il & Gas Oons. OomCSS'ton ;knchorage 13-5/8" DOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC APP'D: 6SB SCALE: NONE DATE: 6/24/91 MIXING PIT 4-0 BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM 185 BBLS VOLUME PIT TRIP TANK 4-5 BBLS 185 BBLS SUCTION PIT 125 BBLS DEGASSER 67 BBLS J DESILTER 'J 240 BBLS SHAKER SHAKER ~CENTRIFUGE RESERVE P IT 4-75 BBLS NOTE: THE SYSTEM WILL BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO & VISUAL WARNING DEVICES. UmOCAL EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4) PIT LEVEL INDICATOR (VISUAL &: AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE 10) MIXING PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN BY: DAC APP'D: GSB SCALE: NONE DATE: 11-30-89 TO GAS BUSTER /\ TO DERRICK VENT .3-1/8" 3-1/8" I I I TO WELL CLEAN TANK 3-1/8" AUTOMATIC CHOKE FROM CHOKE LINE AUTOMATIC CHOKE RECEIVED ~,~AR - ~ t992 Alaska 0il & Gas Cons. Commission Anchorage VALVES UPSTREAM OF CHOKES ARE 10,000 PSI GATE TYPE VALVES DOWNSTREAM OF CHOKES ARE 5,000 PS! GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 CASING AND TUBING DESIGN WELL TBUS G-14A REDRILL CASING STRING 9-5/8" and 7" FIELD McARTHUR RIVER FIELD BOROUGH GRAYLING PLATFORM STATE ALASKA DATE ~/26/91 DESIGN BY D. A. CHUDANOV HUD WT. I #/g, HYD GR. I psi/ft. MUD WT. II HYD. GR. II psi/ft. M.S.P. pst:,, 0.50 PSI/FT GRADIENT ON OUTSIDE, VOID ON INSIDE FOR COLLAPSE 0.50 PSI/FT GRADIENT ON INSIDE, VOID ON OUTSIDE FOR BURST CASING SIZE 1. 9-5/8" INTERVAL Bottom Top LENGTH 11,240' 0 11,240' (8750 TVD) DESCRIPTION Wt. Grade Thread 47# N-80 BUTTRESS 29# N-80 BUTTRESS 7" 13,727' 10,940' 2787' (10712' TVD) (~3517' TVD) WEIGHT TENSION MINIMUM W/ BF -top of STRENGTH W/O BF ×× section TENSION lbs lbs 1000 lbs 528,280 528,280 1,161 ,, 80,823 80,8~3 746 TDF 2.2 9.2 COLLAPSE PRESS. ~ bottom psi COLLAPSE INTERNAL RESIST. BURST MINIMUM tension PRESSURE YIELD pst CDF psi psi BDF 4375 4750 1.1 4375 6870 1.6 5356 7020 1.3 5356 8160 1.5 h- I'-- .10 .50 0 .?0 .~0 .90 EFFECT OF AXIAL TENSION ON COLLAPSE FOR LONE STAR STEEL CO. CASING Foruulae: ' Collapse.~ resistance in tension X (Collapse pressure ratify) Burst Pressure - ~[SP +. Depth ( ]{yd. Gr. II --.5) JiF (Bouyancy Fac'tot) = ~.oo- (o.o~5] x ~u~ wt. z) Calculations: I.OO O .10 .20 .30 .40 .50 .60 30 .80 .90 1.00 TENSION LOAD AXIAL LOAD FAOTOR,;(~- BODY YIELD STRENGTH 17-1/2" @ 520' 13-3/8", 61# J-55, BU~-F ~ @ 3200' MD TOP OF WINDOW 9-5/8", 47#, N-80, BU~-F @ 11240' MD Z 7", 29#, N-80, BUTT LINER @ 13757' MD 1 ~ 2 TUBING DETAIL 3-1/2", 9.2#, N-80 TUBING W! TK-99 COATING & HYDRIL CS-CB CONNECTIONS 1) "XA" SLIDING SLEEVE 2) PERMANENT PKR @ 11900' MD 3) "X" LANDING NIPPLE (3-1/2") 4) WlRELINE RE-ENTRY GUIDE 5) PERMANENT PKR @ 12600' MD 6) "X" LANDING NIPPLE (2-7/8") 7) RE-ENTRY GUIDE TOP OF 7", 29# N-80, BUTT LINER @ 10940' MD HEMLOCK HB-1 HEMLOCK HB-4 RECEIVED ~,~AR - 2 ~992 Alaska Oil & Gas Cons. Commissio Anchorage WEST FORELAND BENCHES 1 THRU 7 WELL TBUS G-14ARD PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1-15-92 v VII _ WELL TBUS G-I A WORKOgER CASING & ABANDONMENT DETAIL DA TE INTERVAL 9105169 15,304'-15,340' 15,380-15431' 15,464'-15.540' 15,572'- 15,630' 15,664'-15,700' 15,7'34'- 15, ? 85.' 15,815'-16.050' 16,080'- 16,280' 16o310'- 16.408' 16,408'-16.522' 9/30172 16,190'-16.200' 16,172'-16.182' 16,124'- 18,134' 16,100'-16,110' 16,030'- 16.040' 15,914'-15,924' 15,895'- 15905' 15,8,42'-15,852' 15,815'- 15.825' 10/05172 15,308'-15.318' 15,322'-15,332' 15,464'-15,474' L) Rotary Table Measurement at 0.00' II.) Cameron Tubing Hanger at 38,00' II1.) 17 314°, 0.312' Wall, SDiral Weld Casing at 520' IV.) 13 318', 61~, J-55 Casing at 4477' V.) Top ?°, 29,~, N-80 Liner at 11.?00' with 7°, 20~,, N-80 Tie Back to Surface VI.) 9 5/8°, 47~, N-80 & P-1 I0 Casing at 12,190' VII.) Bottom ?'. 29~,, N-80 Liner at 16,575'". TUBING DETAIL 3 1/2", 9.2~, N-80 TUBING 1.) 4 1/2' x 3 112° Crossover at 39.00' 2.) 3 112' Otis 'XA' Mandrel at 15.219.06' 3.) Baker Locator at 15,254.04' 4.) Baker Model 'FB-I' Packer with Seal Asseml~ly from 15,254.99' to 15.271'.29' 5.) 3 112' Otis Flow Control Mandrel at 15.767.92' 6.) Baker Model 'FB-I' Packer with Seal Assembly from 15,800.89' to 15.817.99' 7.) 3 112' Otis 'X' Nipple with Collar at 15,826.13' 8.) 3 1/2' Otis 'Q* Nipple with Collar at 15.856.51' 9.) Bottom ol Mule Shoe at 15,658.91' PERFORATION RECORD CONDITION Open for Injection ,, 1s.51e:-lS s2e' .. le.ael,-le:ael' " ~ e.azo,- le.~,eo' " ~e.aeo -le.4oo° 16 415;-16,425; , 18:482 -18,492 WELL TBUS G-14A WORKOVER .... WELL SCHEMATIC RECEIVED MAR - 2 1992 Alaska .0il & Gas Cons. Commission Anch0ra~e GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 well ......... : G-14A RD (P5) Field ........ : McARTHUR RIVER Computation..: RADIUS OF CURVATURE LEGAL DESCRIPTION Surface ...... : 1824 FSL 1486 FEL S29 T09N R!3W SM Tie-in ....... : 1943 FSL 222 FEL S29 T09N R13W SM Target.A ..... : 1600 FNL 1100 FEL S33 T09N R13W SM Target B ..... : 1924 FNL 763 FEL S33 T09N R13W SM BHL .......... : 2374 FNL 297 FEL S33 T09N R13W SM Prepared ..... : 02/20/92 Section at...: S,50.37,E KB elevation.: 103.00 ft LOCATIONS° X ASP ZONE 4 Y 212196.66 2502374.34 213463.27 2502462.37 217783.19 2498813.22 218113.07 2498481.40 218568.78 2498020.61 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN MEAS INCLN DEPTH ANGLE 3050 54.75 3100 54.04 3200 52.65 3300 51.31 3400 50.01 VERT-DEPTHS SECT BKB SUB-S DIST 2582 2479 2611 2508 2671 2568 2733 2630 2796 2693 DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 3500 48.76 '2861 2758 3600 47.56 2928 2825 3700 46.43 2996 2893 3800 45.35 3066 2963 3900 44.35 313.7 3034 898 N 86.93 E 928 N 88.00 E 989 S 89.79 E 1051 S 87.51 E 1113 S 85.13 E 1177 S 82.67 1240 S 80.11 1305 S 77.45 1369 S 74.69 1434 S 71.84 119 N 1264 E <TIE 121 N 1305 E 2.0 122 N 1385 E 2.0 120 N 1464 E 1.9 115 N 1541 E 1.9 · 107 N 1616 E 1.9 96 N 1690 E 1.8 82 N 1762 E 1.8 65 N 1832 E 1.8 44 N 1899 E 1.7 4000 4100 4200 4300 4400 43.42 3209 3106 42.57 3282 3179 41.80 3356 3253 41.12 3431 3328 40.54 3507 3404 1500 S 68.88 E 1565 S 65.83 E 1630 S 62.68 E 1695 S 59.44 E 1760 S 56.11 E 21 N 1964 E 1.7 5 S 2027 E 1.6 34 S 2088 E 1.6 66 S 2146 E 1.6 101 S 2201E 1.5 END DROP & TURN 9-5/8" CASING PT TARGET A 4500 4600 4691 11240 11968 40.05 3583 3480 39.66 3660 3557 39.40 3730 3627 39.40 8790 8687 39.40 9353 9250 1824 S 52.72 E 1888 S 49.26 E 1946 S 46'06 E 6091 S 46.06 E 6552 S 46.06 E 139'S 2254 E 1.5 179 S 2303 E 1.5 218 S 2346 E 1.4 3103 S 5340 E' 0.0 3423 S 5672 E 0.0 TOP HEMLOCK 11968 TOP W. FORLAND TGT B 12706 TD 13727 7" LINER SHOE 13727 39.40 9353 9250 39.40 9923 9820 39.40 10712 10609 39.40 10712 10609 6552 S 46.06 E 7019 S 46,06 E 7665 S 46.06 E 7665 S 46.06 E 3423 S 5672 E 0.0 3748 S 6010 E 0.0 4198 S 6476 E 0.0 4198 S 6476 E 0.0 RECEIVED - 2 199'2 Alaska Oil & Gas Cons. commission Anchorage OCAL CORPORA- 'ON Marker Identification A) TIE-IN END DROP !; TURN C) 9-5/8' CASING PT D} TARGET A E) 7' LINER SHOE TD MD 8K8 SECTN INCLN 3050 2582 BGB 54.75 469t 3730 t946 39.40 tt240 8790 809! 39.40 tt968 9353 6552 39.40 13727 t07~2 7885 39.40 13727 10712 7665 39.40 G-14A RD (P5) VERTICAL SECTION VIEH Section at: S 50.37 E TVD Scale.' 1 inch = 1200 feet Dep Scale · ! inch = !200 feet [~?,AR - 2 1992 Alaska 0il & Gas Cons. CommisSion Anchorage 600 t200 tB00 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 Section Oepart:ure Sreat Land D~rect~onal ~r~ll~n9 G_]4A RD ....... PLAN VIE~ CLOSURE · 7716 ft at S 57.05 E DECLINATION.: 23.00 E SCALE ....... : ! inch = t500 feet DRAWN ' 02/24/92 ............ - 'UNOC~'L CORPORATIO'~ Marker Identification MD N/S Al TIE-IN 3050 ti9 N i264 E BJ END DROP ~ TURN 469! 2!B S 2346 E CJ 9-5/B' CASING PT !!240 3~03 S 5340 E DJ TARGET A ~!968 3423 S 5672 E EJ TARGET B !2706 3746 S 60tO E FJ TD {3727 4!98 S 6476 E GJ 7' LINER SHOE !3727 4!gB S 6476 E 750 0 750 !500 2250 3000 3750 4500 5250 6000 6750 7500 B250 <- NEST · EAST -> 9000 9750 tO500 !!P.50 !2000 i2750 GREAT LAND ,9IRECTIONAL DixlLLING INC. Close Approach Analysis w~, G-14A Redrill F~o,,~ McAurthur River com...~ UNOCAL Corporation A~£.~o. Don Chudanov D.t. February 28. 1992 WELL CROSSINGS Crossing Well TVD TVD Distance Above/Below G-14 3111 3224 113 BELOW G-33 9573 3922 5651 ABOVE M-13 4908 4165 743 ABOVE M-01 4708 4343 365 ABOVE M-28 4518 4651 133 BELOW M-25 7075 4983 2092 ABOVE G-06 6543 5024 1519 ABOVE M-29 8841 5066 3775 ABOVE M-27 4264 5967 1703 BELOW WELLS WITHIN 100 FEET OF PROPOSED WELL Close Approach Distance Range with well TVD G-14 65 2945 2800 - 3100 M-28 71 4590 COMMENTS Welle Cor~de~ed for thla Welle Cor~tdered for thle analy~le analy~te G-01RD D G-19 G G-40 D G-20 G G-O1 G G-21 G G-O2 G G-22 G G-O2RD G G-23 G G-03 G G-24 G G-O3RD1 G G-26 G G-O3RD2 G G-26 G G-04 G (3-27 G G-O4RD G G-28 G G-06 G G-2g G G-06 G G-30 G G-O6RD G G-31 G G-O7 G G-32 G G-08 G G-33 G G-O8RD G G-34 G G-09 G G*34RD G G-10 G G-38 G G-lORD G G-38DPN G G-11 G M-1 G G-12 G M-2 G G-12RD G M-3 D G-13 G M-4 D G-14 G M-6 G G-14A G M-13 G G-16 G M-14 G G-16 G M-16 G G-17 G M-26 G G-17RD G M-27 G G-18 G M-28 G G-18DRN G M-29 G Survey Status: P = Planned D = MWD G =Gyro Survey The profile for G-14A redrill was computed from parameters supplied by Unocal Corporation. This profile consists of a KOP @ 3050 MD 2582 TVD, with a constant tangential dogleg of 2.25°/100. The constant dogleg consists of a 47° turn to the right to a heading of S 46.06 E & a 15.35° inclination drop to 39.40°. This turn and drop is completed at 4691 MD, 3730 TVD, and the final inclination and direction is held to the target at 11968 MD, 9353 TVD, and the TD at 13727 MD, 10712 TVD. The profiles for the existing wells in the Grayling Platform area were computed from directional surveys supplied by Unocal Corporation and or Marathon Oil Company. G-14A redrill will have 9 crossings with existing wells in the area, as outlined above. There are 2 close approaching wells to the proposed G-14A redrill profile. These wells are outlined above. G-14 comes within 100' ft of the proposed profile in the range from 2800' to 3100' TVD. ANALYSIS BY: CHECKED BY: D.,~,hompson //M. Monroe .~,/.l J ? ~/'~. _ _/~,.---, RECEIVED - 2 1 92 Alaska 0il & Gas Cons. commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 15, 1991 Gary S Bush Regional Drlg Mgr UNOCAL P O Box 190247 Anchorage, AK 99519 Re: G-14ARD Trading Bay Unit UNOCAL Permit No. 91-99 Surf Loc 1825'FSL, 1487'FEL, Sec 29, T9N, R13W, SM Btmhle Loc 1913'FNL, 4492'FWL, Sec 33, T9N, R13W, SM Dear Mr Bush: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it· wishes to witness. Sincerely, Alaska Oi and G s Conservation Commission BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl · ! STATE OF ALASKA ALASKA ~-,!:. AND GAS CONSERVATION C'~-"'hMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill .~I lb. Type of well. Exploratory [] Stratigraphic Test = Development Oil Re-Entry .'--_ Deepen.~l Service ~ Developement Gas - Single Zone ~ Multiple Zone - 2. Name of Operator 5. Datum Elevaiion (DF or KB) 10". Fiel'd and Pool (0]~3CA5) Onion 0il Company of ~lif0~ia 103' ~T ~ve ~L feet ~c~ River ~%~%90247, ~ch., ~ 99519 '6.~[~ DesignatiOn Field '4. Location of well at surfa6e 7. Unit or property Name 11. Type Bond ,,.e zo **c 25.;'~5~' I825' FSL & 1487' F~, ~C. 29 ~9~, ~3W, S.~. ~adino ~v 0~Jt 0aired Pac. ~. At top of productive inte~al 8. Well number Number 12,~3' ~, 1597' ~ & 4182' ~, ~. 33, Tgi, RI3W, S~ ~S G-14~ 062-9269 ,, At total depth 9. ApprOximate spud date Amount ..!913' ..~ & 4492' ~ ~C. 33 TgN,. RI3W, ~ 7-20-91 S200.~0 12. Distance to nearest 13. Distance to nearest W~ll 14. Numbe~ of acres in property 15. ProPosed depth (,D ,,~ ~VD~ property line 3367' feet 66' (~S G-14) feet 17,299 (~~) 12,?~' ~ 9,9~' ~ feet 16. To be completed for dev'iated wells 17. Anticipated pressure {,, ~ AAC 25.035 ~.)~)) ..... Kickoff Oepth 32~ feet Maximum hole angle 55, Maximum sudace 743~sig At total OeDth UVD) ~455 psig 18. C~sing program ........ ... "Setting Depth ' ' size Specifications Top Bottom Quantity of cement .... 'o,e t'" c" ng We,gh, lG 'UelCo p,ing, j ~ngth MD I TVD I "MD. ~.. ~D . (include stage'~ata) ~2-1/4" 9-5/8" 47~ ~-80 ~tt 1~240' S~f S~f ~1240' 87~' 2375 sxs .. ~:8-1/2" 7" 29; ~-80 ~tt 1760' 1~40' 85~7' 127~' 9~' 6~ sxs i9.~obe~ompleted~0r'R'edri~l, Re, ntb, and D~'epeno~erations.' ' ~~1 V ~~ ~ ~ "%lr~ Present well condition summa~ Total depth: measured feet Plugs (measured) true ve~ical ~6575' feet J U L - 9 [0404~ Effective depth: measured [6522~ feet Junk (measured) Alaska 0ii & Gas Cons. C0m~S~0~ true vedical feet ~0375' Anchorage Casing ~ngth Size Cemented Measured depth True Ve~ical depth Structural 520~ ~7-3/4" 7~ SXS 520' 520 Conductor Sudace 44?7' ~3-3/8" 2~ SXS 4477' 3389' Intermediate 12190' 9-5/8" 2450 SXS 12190' 8072' Production 117~' 7"(tie~ck) 1~ sxs 117~' 7797' Lin er 4875 ' 7" 800 sxs 117~ '-16575 ' 7797 ' -10404 ' Peroration depth: measured true ve~ical ~ Attac~at "~rf Record" 20~'A~achments Filing fee ~ ~r0peRy plat Q BOP Sketc6 ~ DiVerter'Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed reDoR ~ 20 AAC 25.050 requirements '2i. I hereby ~'~ify that the foregoing is true an'~ correct to the best of my knowledge " ~ ~v Commission Use Only Pe~it Number J'API number J App~va~date .... ] see cover letter ?/- I - / -o I ! other e. ,reme.t. .... , ,, ~. · , ,, ~ " , ~ , . , Conditions of approVal Samples required ~ Yes ~No Mud Icg,required ~ YeS ~No ...... Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ~ N6 Required working pressure for BOPE ' ~2M; ~ 3M; ~ SM; ~ 10M; ~ 15M Othe~ ~~ ~ by order of Approved.~~ Commissioner the commission Date Submit in triplicate Unocal North America-'S Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Robert T. Anderson Manager, Lands Alaska Region June 28, 1991 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska McArthur River Field Application to Redrill and Complete, Well G-14A Lease Number ADL-l$730 Dear Mr. Crandall: Union Oil of California, as Operator of the Trading Bay Unit, hereby requests approval to redrill, complete, and inject into the subject well to the east side of the main feature to provide injection support for the Hemlock reservoir producers, pursuant to Rule 5, Conservation Order No. 80. Benches (sub-intervals) 1 and 4 will be injected into as part of the ongoing Hemlock pressure maintenance program augmenting recovery by 1.8 MMBO. The location for G-14A-RD Will optimize the peripheral flood on the east side of the main feature by moving the point of injection closer to the offset crestal withdrawal points. Your approval of this request will be appreciated. Very trul~urs, / ~ cc: D. A. Chudanov E. J. O'Donnell R. C. Warthen RECEIVED d U L - 9 1991 Alasiia.Oil .& Gas Cons. Commission ,, ~ch~rage TRADING BAY UNIT TBUS G-14A REDRILL DRILLING PROCEDURE 1. SKID RIG #55 OVER TBUS G-14A, LEG #4, CONDUCTOR #40. 2. KILL WELL WITH 64 PCF SPUD MUD. 3. INSTALL 13-5/8" 5M ROPE AND TEST TO 3000 PSI. 4. RECOVER EXISTING 3-1/2" SINGLE INJECTION COMPLETION. 5. SET A 7" CEMENT RETAINER AT 15470'. DOWN SQUEEZE WITH 200 SXS OF CLASS "G" CEMENT TO ABANDON HEMLOCK PERFORATIONS FROM 15304' TO 16522' DIL. 6. SET A 7" CEMENT RETAINER AT 3800'. CUT AND RECOVER 7" CASING FROM 3700'. LAY A CEMENT PLUG FROM 3800' TO 3600' TO PLUG THE 7" CASING STUB. 7. SET A 9-5/8" CEMENT RETAINER AT 3500'. CUT AND RECOVER 9-5\8" CASING FROM 3400'. 8. RUN CBL FROM 3400' TO 1400'. SQUEEZE FOR STABILIZATION, AS NEEDED. MILL WINDOW IN 13-3/8" CASING FROM 3200' TO 3300'. 9. LAY CEMENT PLUG FROM 3500' TO 3000'. CLOSE THE UPPER PIPE RAMS AND BRAIDEN HEAD SQUEEZE THE 13-3/8" CASING SHOE. 10. KICKOFF AND DRILL 10' OF FORMATION. PERFORM A LEAKOFF TEST. SQUEEZE SHOE, IF NECESSARY. REDRILL FROM 3200' TO 11240' (12-1/4" HOLE). 11. RUN OPENHOLE LOGS. 12. RUN AND CEMENT 9-5\8" CASING AT 11240'. 13. DRILL FLOATS AND 10' OF FORMATION. PERFORM A LEAKOFF 12700' (8-1/2" HOLE). Kr. tEIv 14. RUN LOGS. JUL - RUN AND CEMENT 7" LINER FROM 10940' TO 15. 16. CLEAN OUT LINER. TEST LAP AND SQUEEZE, IF NECESSARY. 17. PERFORATE HEMLOCK BENCHES HR-1 AND HB-4. 18. RUN SINGLE INTERNALLY COATED INJECTION COMPLETION. TRADING BAY UNIT TBUS G-14A ORIGINAL HOLE PERFORATION RECORD MEASURED DEPTH 15,304' - 15,340' 15,380' - 15,431' 15,464' - 15,540' 15,572' - 15,630' 15,664' - 15,700' 15,734' - 15,785' 15,815' - 16,050' 16,080' - 16,280' 16,310' - 16,522' TRUE VERTICAL DEPTH 9,782' - 9,747' 9,768' - 9,796' 9,813' - 9,853' 9,870' - 9,901' 9,919' - 9,938' 9,956' - 9,983' 9,999' - 10,123' 10,139' - 10,245' 10,261' - 10,373' J U L - 9 t99'~ 'A]a$~ 0i~ .& G~s Oo~s. (;~mm'~ssion 'Anchorage TRADING BAY UNIT TBUS G-14A REDRILL ANTICIPATED PRESSURES: MAXIMUM SURFACE PRESSURE CALCULATION FOR 12-1/4" HOLE MUD WEIGHT 13-3/8" CASING SHOE DEPTH 13-5/8" CASING SHOE FRAC GRADIENT TD OF 9-5/8" CASING POINT PORE PRESSURE GRADIENT GAS GRADIENT 72 PCF = 0.500 PSI/FT 3200' MD / 2648' TVD 0.90 PSI/FT l1240'MD / 8750' TVD 0.450 PSI/FT 0.0 PSI/FT ASSUME THAT 25% OF THE WELLBORE IS DISPLACED DURING A GAS KICK ( HOLE FILLED WITH 75% MUD AND 25% GAS ). MAXIMUM SURFACE PRESSURE = BHP - MUD/GAS HYDROSTATIC PRESSURE MSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(8750 FT * .450 psi/ft) -((.75 (8750 FT * .500 PSI/FT)) + (.25 (8750 FT * 0 PSI/FT))) MSP = 656 PSI THE GREATEST HYDROSTATIC PRESSURE AT THE 9-5/8" SHOE (HPsh) IS WHEN THE GAS BUBBLE REACHES THE SHOE, IF A CONSTANT BHP IS APPLIED. A CONSERVATIVE ESTIMATE WOULD BE THE MAXIMUM SURFACE PRESSURE (MSP) PLUS THE HYDROSTATIC PRESSURE AT THAT CASING DEPTH (HPcsg). HPsh = MSP + HPcsg HPsh = 656 PSI + ( 2648 FT * .500 PSI/FT ) = 1980 PSI FPsh = FRAC GRAD * TVDshoe FPsh = 0.90 PSI/FT * 2648 FT = 2383 PSI HPsh = 1980 PSI IS LESS THAN THE FRACTURE PRESSURE AT THE 13-3/8" SHOE, FPsh = 2383 PSI AND THEREFORE ADEQUATE TO HANDLE THE WELL KICK. THIS SCENARIO IS CONSIDERED EXTREME, SINCE A 418 BBL ENTRY IS REQUIRED TO DISPLACE 25 PERCENT OF THE WELL BORE. MSP CALC PAGE 2 MAXIMUM SURFACE PRESSURE CALCULATION FOR 8-1/2" HOLE MUD WEIGHT 9-5/8" CASING SHOE DEPTH 9-5/8" CASING SHOE FRAC GRADIENT TD OF 7" CASING POINT PORE PRESSURE GRADIENT GAS GRADIENT 72 PCF = 0.500 PSI/FT 11240' MD / 8750' TVD 0.90 PSI/FT 12700' MD / 9900' TVD 0.450 PSI/FT 0.0 PSI/FT ASSUME THAT 25% OF THE WELLBORE IS DISPLACED DURING A GAS KICK ( HOLE FILLED WITH 75% MUD AND 25% GAS ). MAXIMUM SURFACE PRESSURE = BHP - MUD/GAS HYDROSTATIC PRESSURE MSP = BHP - (3/4 MUD + 1/4 GAS) MSP =(9900 FT * .450 psi/ft) -((.75 (9900 FT * .500 PSI/FT)) + (.25 (9900 FT * 0 PSI/FT))) MSP = 743 PSI THE GREATEST HYDROSTATIC PRESSURE AT THE 9-5/8" SHOE (HPsh) IS WHEN THE GAS BUBBLE REACHES THE SHOE, IF A CONSTANT BHP IS APPLIED. A CONSERVATIVE ESTIMATE WOULD BE THE MAXIMUM SURFACE PRESSURE (MSP) PLUS THE HYDROSTATIC PRESSURE AT THAT CASING DEPTH (HPcsg). HPsh = MSP + HPcsg HPsh = 743 PSI + ( 9900 FT * .500 PSI/FT ) = 5693 PSI FPsh = FRAC GRAD * TVDshoe FPsh : 0.90 PSI/FT * 9900 FT = 8910 PSI HPsh = 5693 PSI IS LESS THAN THE FRACTURE PRESSURE AT THE 13-3/8" SHOE, FPsh = 8910 PSI AND THEREFORE ADEQUATE TO HANDLE THE WELL KICK. THIS SCENARIO IS CONSIDERED EXTREME, SINCE A 228 BBL ENTRY IS REQUIRED TO DISPLACE 25 PERCENT OF THE WELL BORE. TRADING BAY UNIT TBUS G-14A REDRILL MUD PROGRAM PLUG AND ABANDONMENT MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH 64 TO 68 PCF 50 TO 70 SEC/QT 8 TO 15 CP 15 TO 25 #/100 SQ FT 9 TO 10 13-3/8" WINDOW MILLING MUD WEIGHT FUNNEL VISCOSITY 64 TO 70 PCF 70 TO 100 SEC/QT 12-1/4" HOLE SECTION ( 9-5/8" CASING ) . 3200' TO 5000' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS SOLIDS 65 TO 70 PCF 40 TO 55 SEC/QT 8 TO 18 CP 12 TO 20 #/100 SQ FT 9 TO 10 8 TO 10 CC 3 TO 6 PERCENT 5000' TO 7000' SECTION MUD WEIGHT FUNNEL VISCOSITY PLASTIC VISCOSITY YIELD POINT PH API FLUID LOSS HPHT @ 200 SOLIDS 70 TO 75 PCF 40 TO 55 SEC/QT 12 TO 20 CP 12 TO 20 #/100 SQ FT 9 TO 10 6 TO 8 CC 18 TO 2O CC 7 TO 10 PERCENT RECEIVED J U L - 9 1991 Alaska Oil & Gas Cons. Oommlssiou '_Anchorage HUD PROGRAM PAGE 2 HUD WEIGHT FUNNEL VISCOSITy PLASTIc VISCOSITy YIELD POINT APl FLUID LOSS SPST @ 200 SOLIDS 70 TO 75 PCF 45 TO 55 SEC/QT 12 TO 20 CP 12 TO 20 #/100 SQ FT 9 TO 10.5 4 TO 6 CC 15 TO 18 CC 7 TO 10 PERCENT 8-1/2. SOLE SECTION ~ MUD WEIGST FUNNEL VISCOSITy PLASTIC VISCOSITy YIELD POINT API FLUID LOSS SPST @ 200 SOLIDs 65 TO 72 PCF 45 TO 55 SEC/QT 12 TO 10 CP 8 TO 16 #/100 SQ FT 9.5 TO 10.5 4 TO 6 CC 15 TO 18 CC 5 TO 8 PERCENT R ¢EIVED J U t - 9 t99t alaska Oil & Gas Cons. Commiss ~.chorage WELL TBUS G-14A REDRILL CASING STRING 9-5/8" and 7" FIELD BOROUGH CASING AND TUBING DESIGN McARTHUR RIVER FIELD GRAYLING PLATFORM STATE ALA$~ DATE §/26/91 DESIGN BY D. A.. CfIUDANOV 1. ).IUD WT. I #/q. HYD GR. I psi/ft. MUD WT. II #/g. HYD. GR. II , . 0.50 PSI/FT GRADIENT ON OUTSIDE, VOID ON INSIDE FOR COLLAPSE 0.50 PSI/FT GRADIENT ON INSIDE, VOID ON OUTSIDE FOR BURST CASING SIZE 1. 9-5/8" 7" 2. 3. INTERVAL Bottom Top LENGTH 11,240' 0 11,240' (8750 TVD) DESCRIPTION Wt. Grade lhread 47# N-80 BUTTRESS 29# N-80 BUTTRESS 12,700' 10,940' 1760' (9900 ~VD) (8517 TVD) psi/ft. M.S.P. ps1. WEIGHT IENSION MINIMUM W/ BF -top of STRENGTH W/O BF ×× section TENSION lbs lbs 1000 lbs 528,280 528,280 1,161 TDF COLLAPSE COLLAPSE INTERNAL PRESS. · RESIST. BURST MINIMUM bottom tenslon PRESSURE YIELD psi psi CDF psi psi BDF 2.2 4375 4750 1.1 4375 6870 1.6 5!~040 51,040 746 14.6 , .,~ 4950 7020 1.4 4950' 8160 1.6 v vi VII -- WELL TBUS G-IAA WORKOVEfl CASING & ABANDONMENT DETAIL I.) Rotary Table Measurement at 0.00' II.) Cameron Tubing Hanger at 38.00' III.) 17 3/4', 0.312" Wall, Spiral Weld Casing at 520' IV.) 13 3/8', 61.*, J-55 Casir~g at 4477' V.) Top 7', 29**, N-60 Liner at 11,700' with 7', 20**, N-80 Tie Back to Surface VI.) 9 5/8', 47~, N-80 & P-110 Casing at 12,190' VII.) Bottom 7', 29~', N-80 Liner at 16,575"x TUBING DETAIL , 3 1/2", 9.2#, N'80 TUBING 1.) 4 112' x 3 112' Crossover at 39.00' 2.) 3 112' Otis 'XA' Mandrel at 15,219.06' 3.) Baker Locator at 15,254.04' 4.) Baker Model 'FB-1° Packer with Seal Assembly from 15,254.99' to 15,2;'1.29' 5.) 3 112' Otis Flow Control Mandrel at 15,767.g2' 6.) Baker Model 'FB-1° Packer with Seal Assembly from 15,800.89' to 15,817.99' 7.) 3 1/2' Otis 'X' Nipple with Collar at 15,826.13' 8.) 3 1/2' Otis 'Q' Nipple with Collar at 15,856.51' 9.) Bottom of Mule Shoe at 15,858.91' PERFORATION RECORD WELL TBUS G- DA TE INTERVAL 9105169 15,304'- 15,340' 15,380-15431' 15,464'-15,540' 15,572'-15,630' 15,664'- 15,700' 15,734'- 15,785/ 15,815'- 16,050' 16,080'- 16,280' 16,310'- 16,408' 16,408'-16,522' 9/30/72 16,190'-16,200' 16,172'-16,182' 16,124'-16,134' 16,100'-16,1 10' 16,030'- 16,040' 15,914'- 15,924' 15,895'-15905' 15,842'- 15,852' 15,815'- 15,825' 10/05/72 15,308'-15,318' 15,322'-15,332' 15,464'-15,474' 15,516'-15,526' 16,251'-16,261' 16,270'-16,280' 16,390'- 16 400' 16 4 15;-16~425; 16~482 -16,492 14A W0flKOVER CONDITION Open for Iniection 0, . 0, WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA ANCH~I;'AGE, ALASKA . :: REC IVED · ' JUL 9t99]- A~ska Oil & Ga: Cons. Comrnissio[~ ,, . oo . o~Aw~ 8HE ¢~0. ~ SC^LC NON Ir 17-1/2" @ 520' J-55, BUTT @ 5200' MD TOP OF WINDOW 47//, N-80, BUTT 240' MD 7", 29#, N-80, BUTT LINER @ 12700' MD Z 1 TUBING DETAIL 3-1/2", 9.2#, N-80 TUBING W/ TK-99 COATING &:: HYDRIL CS-CB CONNECTIONS 1) "FA" SLIDING SLEEVE 2) PERMANENT PKR @ 11900' MD 3) "X" LANDING NIPPLE 4) RE-ENTRY GUIDE @ 11960' MD TOP OF 7", 29# N-80, BUTT LINER @ 10940' MD PROPOSED PERFORATiONS~ ~ ~ V E D HEMLOCK HB- 1 HEMLOCK HB-4 JUL- ]99~ Alaska Oil & Gas ohs. Commissiou Anch rage WELL TBUS G-14ARD PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 6-24-91 MIXING PIT 40 BBLS MIXING PIT iS A ONE LEVEL BELOW THE ACTIVE SYSTEM TRIP TANK 4-5 BBLS 185 BBLS VOLUME PIT 185 BBLS SUCTION PIT 125 BBLS DEC. ASSER 67 BBLS I DESILTER I 24.0 BBLS SHAKER SHAKER ~CENTRIFUGE RESERVE PIT 4-75 BBLS NOTE: THE SYSTEM Will BE EQUIPPED WITH A DRILLING PIT LEVEL INDICATOR WITH AUDIO & VISUAL WARNING DEVICES, EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 3) (2) SHAKERS 4-) PIT LEVEL INDICATOR (VISUAL & AUDIO) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS 8) DESILTER 9) CENTRIFUGE lo) M~X~NG PIT UNOCAL GRAYLING MUD PIT SCHEMATIC DRAWN BY: DAC APP'D: GSB SCALE: NONE DATE: 11-30-89 BELL NIPPLE 13-5/8" 5000 PSI ANNULAR I FLOWLINE ,5" KILL LINE WITH TWO 3" 5M VALVES ! ~'f; ri',,, KILL LINE FROM MUD PMP & CEMENT UNIT I PIPE RAMS BLIND RAMS ,I I PIPE RAMS I 13-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" 5M FLANGE 4" CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4." 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWINO) 13-5/8" 5M FLANGE SINGLE GATE 5M 13-5/8" 5M FLANGE RISER [m i I I I I i 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL RECEIVED J U L - 9 t991 Alaska Oil & Gas Cons. Oom~ Anchorage 15-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 6/24/9 ftss'tot~ TO GAS BUSTER /\ TO DERRICK VENT TO WELL CLEAN TANK /\ 4--1/16" 3-- 1/8" . 3-- 1,,/8" i AUTOMATIC ~~ CHOKE / FROM CHOKE LINE 4-1/16" 3-1/8" AUTOMATIC VALVES UPSTREAM Of CHOKES ARE 10,000 PSI GATE TYPE VALVES DOWNSTREAM OF CHOKES ARE 5,000 PSI GATE TYPE CHOKE MANIFOLD GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbe UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 <KB> o i400 9800 i~200 UNOCAL A : ~4A % \ \, 55 deg 6-]4A REDRILL VERTICAL SECTION VIE Section at: S 56.~6 E TVD Scale.' ! inch = 1400 feet Dep Scale.' ! inch = 1400 feet Orawn ..... · 06/14/9! im Sce~t L~n# DjcectJona] Mackec Tdentification HE) TVD SECIN INCLN A) KB 0 0 0 O. O0 B} KOP DROP ~/ TURN 2.5 3200 2668 ~084 55.00 C] END ~.0/100 DROP 4800 3756 2175 39.00 D) END 2.50/100 TURN 5140 4020 2387 39.00 E) TARGET - TOP HEMLOCK 12003 9353 6615 39.00 F) TD - BHL 12706 9900 7048 39.00 % _ Naska Oiil& Gas Cons. ~400 2800 4200 Section DepaPtupe F~ 5600 7000 r~m'tss'to~ /V UNOCAL Marker Identification MD N/S E/W A) KB 0 0 N 0 E 6] KOP DROP 1/ TURN 2.5 3200 t24 N t386 E C) END t.0/t00 DROP 4800 20t S 2481 E D) END 2.50/i00 TURN 5140 342 S 2642 E E) TARGET - TOP HEMLOCK 12003 3422 S 5669 E F] TD 12706 3738 S 5979 E tt00- 2200 3300 4400 · 55OO 6600 0 <- WEST ' EAST -> G- AA REDRILL PLAN VIEW CLOSURE ..... : 705! ft S 57.gg E DECLINATION.: 23.75 E SCALE ....... : ! inch = 1~00 feet DRAWN ....... : 06/~4/gl , , , -.... G-t4A "~"., .,.., ,.~ LL REE'EIV,c ' JUL - 9 19~9~1 Alasl~ Oil & Gas Cons. l;ommissi°n 4400 5500 S 44.5 E tt00 2200 3300 GREAT LAND DIRECTIONAL DRILLING, INC. Client .... : UNOCAL CORPORATION Field ..... : McARTHUR RIVER Well ...... : G-14A REDRILL Section at: $,56.26,E 06/14/91 Computation...: RADIUS OF CURVATURE RKB Elevation.: 99.00 ft ~ Magnetic Dcln.: 23.75 E PROPOSED WELL PROFILE Target: 1600 FNL 1100 FEL Sec 33 T9N R13W MARKER IDENTIFICATION MEA$ INCLN VERT-DEPTH$ SECT DIRECTION REL-COORDINATES DL DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD /100 KB 0 0.00 0 -99 0 N 90.00 E 0 N 0 E KOP DROP 1/ TURN 2.5 3200 55.00 2668 2569 1084 N 87.00 E 124 N 1386 E <TIE END 1.0/100 DROP 4800 39.00 3756 3657 2175 S 53.'00 E 201 S 2481 E 1.92 END 2.50/100 TURN 5140 39.00 4020 3921 2387 S 44.50 E 342 S 2642 E 1.00 TARGET - TOP HEMLOCK 12003 39.00 9353 9254 6615 S 44.50 E 3422 S 5669 E 0.00 TD - BHL 12706 39.00 9900 9801 704.8 S 44.50 E 3738 S 59~9 E 0.00 GREAT LAND DIRECTIONAL DRILLING, INC. 1111 E. 80th Anchorage, Alaska 99518 349-4511 6-24-91 Don Chudanov UNOCAL Grayling Platform Well G-14A Redrill Close Approach Analysis Don: We have examined the potential intersections of well G-14A Redrill with the other wells in the Grayling Platform area. The analysis starts at the sidetrack KOP. The profile for G-14A Redrill was computed from design parameters specified by UNOCAL. The other wells were calculated from surveys provided by UNOCAL. The closest well to G-14A Redrill is G-14 which is 66 feet away at 3050 TVD BKB and remains within 200 feet from the KOP at 2668 TVD BKB to 3370 TVD BKB. G-14A Redrill has four crossings with other wells in the Grayling Platform area. Crossings with M-27, G-06, and G-06 Redrill exceed 1000 feet of separation. The other crossing is: Well TVD BKB G-14AR TVD G-14AR is: G-14 3198 3293 95 ft above TVD's have been adjusted to the Kelly bushing of G-14A Redrill. Analysis by: Z'~f ///'~,~~,~. Checked by: ~M'~ E. Mighell Checked by: D. Thompson RECEIVED d U L - 9 t991 Alaska Oil & Gas Cons. Commission Anchorage I ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (1). Fee ,./?~ .... F/~/~! ,, [2 thru 8] (3) Admin (4) Casg [8] [9~ru 13] [10 & 133 [14 thru 22] le e 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. C5) BOPE [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other (6) Addl '['29- thrt] :~1]' 29. 30. 31. 32. geology' DWd~ R PC:.~?c~' eng i neer i ng~.i MTM___~._ LC S BEW.~~ RAD ~) rev 03/29/91 jo/6.011 Company ~/~__~ / · YES NO Is permit fee attached ............................................... Is well to be located in a defined pool ............................... _~_ Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... . , Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... ~.. Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ . ...... Will cement tie in surface & interTnediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. ~ ., Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams ~ descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to~-'O~:)~ psig ..... Does choke manifold comPly w/API RP-53 (May 8~) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. INITIAL GEO1 UNIT ON/OFF POOL CI~ASS STATUS AREA ~ SHORE Lease & Well ~ /g~/._ /~'7,:;~,~ '~'~(_X REMARKS Additional remarks' -~/.~ ~;~,'~ /.L.' .,.e S-ld~ 3~"o' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' .. No special 'effort has been made to chronologically organize this category of information. Tape Subfi%e 2 ~s type: LIS TAPE HEADER CO NAME: 0NION OIL OF CALIFORNIA WELL: G-14A-RD FIELD: MCARTHUR RIVER COUNTY: KENAI STATE: ALASKA SURFACE LOCATION: PLATFORM GRAYLING SECTION: 29 TOWNSHIP: 9N RANGE: 13W LIS TAPE CREATED BY: LIS TAPE CREATION DATE: COMMENTS: ATLAS WIRELINE SERVICES 15-JUNE-92 THIS TAPE CONTAINS HALLIBURTON LOGGING SERVICE OPEN HOLE DATA FOR RUN 1 (DATED 17-APR-92) & RUN 2 (1 PASS FROM DOWN LOG, DATED il-MAY-92). ALSO INCLUDED IS THE GAMMA RAY CURVE FROM ATLAS WIRELINE SERVICES CASED HOLE SBT TOOL (DATED 24-MAY-92). HALLIBURTON LOGGING SERVICE CURVE MNEUMONICS HAVE BEEN MAINTAINED. RUN 1: 1376' - 7840' HRI/DIL/FWS2/GR SDL/DSN/GR RUN 2: 7867' - 9812' (DOWN LOG) HRI/GR 7680' - 12862' (CASED HOLE) GR from ATLAS WIRELINE SBT LOG. PHYSICAL TAPE FILE 1) MAIN PASS RUN 1 (with merged GR's) TAPE FILE 2) REPEAT PASS RUN 1 TAPE FILE 3) DOWN LOG PASS RUN 2 (RAW - UNSHIFTED) TAPE FILE ONE IS RUN 1 MAIN PASS WITH MERGED GAMMA RAY CURVES. THREE SEPERATE GR CURVES ARE INCLUDED: GR ... MERGED Gm (RUN 1 HRI/DIL/FWS2 GAMMA) GRD ... MERGED GR (RUN 1 SDL/DSN GAMMA) GRS ... ORIGINAL GR FROM SBT (CASED HOLE) GR & GRD ARE MERGED FROM 3 SEPERATE SOURCES, THEY ARE: Surface - 7765.0 ft. from HALLIBURTON open hole run 1 dated 04-17-92. 7765.0 - 7880.5 ft. from ATLAS WIRELINE SBT log dated 05-24-92 (cased hole). 7880.5 - 9734.25 ft. from HALLIBURTON open hole run 2 dated 05-11-92. This was a down log pass and was depth matched to the ATLAS WIRELINE SBT log. 9734.25 - T.D. from ATLAS WIRELINE SBT log dated 05-24-92 (cased hole). All gamma ray depth matching and splicing was performed on 06-06-92 by ATLAS WIRELINE SERVICES. DEPTH MATCHING FOR RUN 2 (DOWN LOG) DATA TO ATLAS SBT DATA WAS DONE WITH THE FOLLOWING DEPTH PAIRS: OBSERVED DEPTH ACTUAL DEPTH FROM DISPLACEMENT GR FROM RUN 2 ATLAS SBT GR RECEIVED JUN 2 6 1992 Alaska 011 & Gas Cons. Commission Anchorage 7894.000 .... 7885.750 ..... -8.250 7981.756 .... 7972.750 ..... -9.000 7992.250 .... 7983.250 ..... -9.000 7999.000 .... 7991.500 ..... -7.500 8028.250 .... 8019.750 . . . . . -8.500 8076.000 .... 8067.000 ..... -9.000 8079.000 .... 8070.500 ..... -8.500 8229.250 .... 8220.250 ..... -9.000 8252.250 .... 8243.250 ..... -9.000 8263.250 .... 8254.750 ..... -8.500 8277.500 .... 8270.750 ..... -6.750 8316.750 .... 8307.000 ..... -9.250 8347.500 .... 8339.000 ..... -8.500 8377.500 .... 8368.500 ..... -9.000 8396.500 .... 8386.250 ..... -10.250 8493.500 .... 8484.500 ..... -9.000 8550.000 .... 8539.750 ..... -11.250 8554.250 .... 8543.750 ..... -10.500 8559.500 .... 8548.500 ..... -11.000 8585.500 .... 8575.250 ..... -11.250 8626.250 .... 8615.750 ..... -10.500 8724.000 .... 8714.250 ..... -9.750 8750.250 .... 8739.750 ..... -10.500 8758.500 .... 8747.750 ..... -10.750 8790.000 .... 8779.000 ..... -10.000 8797.250 .... 8788.250 ..... -9.000 8969.500 .... 8958.500 ..... -11.500 9070.250 .... 9058.250 ..... -12.500 9077.250 .... 9065.750 ..... -12.000 9085.250 .... 9074.250 ..... -11.000 9125.500 .... 9114.250 ..... -11.250 9174.750 .... 9162.250 ..... -12.500 9185.250 .... 9173.250 ..... -12.000 9239.000 .... 9226.250 ..... -12.750 9324.000 .... 9311.250 ..... -13.250 9348.000 .... 9334.000 ..... -14.000 9432.500 .... 9421.500 ..... -11.000 9452.750 .... 9440.500 ..... -11.750 9514.250 .... 9499.500 ..... -14.000 9583.000 .... 9570.750 ..... -12.250 9591.500 .... 9578.750 ..... -12.750 9602.250 .... 9591.250 ..... -11.000 9616.750 .... 9604.000 ..... -12.750 9690.250 .... 9676.000 ..... -13.000 9719.000 .... 9705.000 ..... -13.000 CN : UNOCAL WN : TBU G-14A RD FN : MCARTHUR RIVER COUN : KENAI STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 32 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 68 1 GAPI 2 GRS 68 1 GAPI 3 DT 68 1 US/F 4 ITT 68 1 5 HDRS 68 1 OHMM 6 HMRS 68 1 OHMM 7 HMCN 68 1 MMHO 8 HDCN 68 1 MMHO 9 DFL 68 1 OHMM 10 GRD 68 1 GAPI 11 FDSN 68 1 CPS 12 NDSN 68 1 CPS 13 SPHI 68 1 DECP 14 NPHI 68 1 PU-S 15 NRAT 68 1 C/C 16 DPHI 68 1 PU-S 17 DRHO 68 1 G/C3 18 RHOB 68 1 G/C3 19 FSDL 68 1 CPS 20 NSDL 68 1 CPS 21 PE 68 1 BN/E 22 CALI 68 1 IN 23 BS 68 1 IN 24 ILM 68 1 OHMM 25 ILD 68 1 OHMM 26 CILD 68 1 MMHO 27 SGRD 68 1 OHMM 28 SP 68 1 MV 29 DLOD 68 1 LB 30 DLOI 68 1 LB 31 TEND 68 1 LB 32 TENS 68 1 LB 4 4 05 428 97 1 4 4 82 825 99 5 4 4 47 654 93 0 4 4 82 825 99 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 05 428 97 1 4 4 82 825 99 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 61 603 31 6 4 4 24 454 38 1 4 4 82 825 99 5 4 4 89 342 95 6 4 4 68 098 32 5 4 4 82 825 99 5 4 4 82 825 99 5 4 4 56 189 67 6 4 4 96 425 75 0 4 4 82 825 99 5 4 4 66 671 33 6 4 4 67 982 05 6 4 4 12 622 05 6 4 4 82 825 99 5 4 4 75 501 85 0 4 4 82 825 99 5 4 4 82 825 99 5 4 4 94 017 77 6 4 4 94 017 77 6 * DATA RECORD (TYPE# 0) 930 BYTES * Total Data Records: 6595 Tape File Start Depth = 12893.000000 Tape File End Depth = 1352.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 128 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1523446 datums Tape Subfile: 2 6704 records... Minimum record length: Maximum r~cord'length: 62 bytes 930 bytes Tape Subfile 3 is type: **** FILE HEADER **** LIS DBUN WN CN FN FL LONG LATI SECT TOWN RANG COUN STAT CTRY LUN RUN APIN WITN TLAB BHT MRT ST DFT DFD DFV DFPH DFL MST RMS MFST RMF MCST RMC RMB RMFB RMCB EKB EDF EGL EDP BS CS CW1 CBD1 CBL1 CSD DMF LMF BLI TLI PD DATE CBF APD TCS DL : F : TBU G-14A RD : UNOCAL : MCARTHUR RIVER : CONDUCTOR 13 LEG 4 : 0.0000 : 0.0000 : 29 : 9N : 13W SM : KENAI : ALASKA : USA : 9000 : 1 : 50-733-2018901 : KILOH, HARNESS : 2157 : 138.0000 : 0.0000 : 0.0000 : FRESH MUD : 0.0000 : 0.0000 : 0.0000 : 5.4000 : 60.0000 : 1.2000 : 72.0000 : 0.7000 : 70.0000 : 1.8000 : 0.5500 : 0.0000 : 0.0000 : 103.0000 : 0.0000 : 0.0000 : 0.0000 : 12.2500 : 13.3750 : 0.0000 : 0.0000 : 0.0000 : 1402.0000 : KB : KB : 0.0000 : 0.0000 : MSL : 4-17-92 : 0.0000 : 103.0000 : 20 : 0.0000 DD MSS MFSS MCSS UNIT Ri : 0.0000 : FLOWLINE : CIRC : CIRC : F : CHLORIDES DETERMINED TO BE 8500 PPM FROM CHART BOOK * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 31 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 DLOD HRI 68 1 2 GR HRI 68 1 3 DT FWS2 68 1 4 ITT FWS2 68 1 5 SPHI FWS2 68 1 6 HDRS HRI 68 1 7 HMRS HRI 68 1 8 HDCN HRI 68 1 9 HMCN HRI 68 1 10 DFL HRI 68 1 11 TENS HRI 68 1 12 GRD DIL 68 1 13 FDSN DSN 68 1 14 NDSN DSN 68 1 15 NPHI DSN 68 1 16 NRAT DSN 68 1 17 DPHI SDL 68 1 18 DRHO SDL 68 1 19 FSDL SDL 68 1 20 NSDL SDL 68 1 21 PE SDL 68 1 22 RHOB SDL 68 1 23 CALI SDL 68 1 24 ILM DIL 68 1 25 ILD DIL 68 1 26 CILD DIL 68 1 27 SGRD DIL 68 1 28 TEND DIL 68 1 29 DLOI DIL 68 1 30 BS SDL 68 1 31 SP DIL 68 1 LB 4 GAPI 4 US/F 4 4 DECP 4 OHMM 4 OHMM 4 MMHO 4 MMHO 4 OHMM 4 4 GAPI 4 CPS 4 CPS 4 DECP 4 C/C 4 DECP 4 G/C3 4 CPS 4 CPS 4 4 G/C3 4 IN 4 OHMM 4 OHMM 4 MMHO 4 OHMM 4 4 LB 4 IN 4 4 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 * DATA RECORD (TYPE# 0) 902 BYTES * Total Data Records: 162 Tape File Start Depth = 7861.250000 Tape File End Depth = 7578.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 124 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 36289 datums Rep Code: 73 1 datum Rep Code:. 79 Tape Subfile: ~ Minimum record length: Maximum record length: 2 datums 171 records... 62 bytes 1024 bytes Tape Subf~le 4~is type: **** FILE HEADER **** LIS DBUN WN CN FN FL LONG LATI SECT TOWN RANG COUN STAT CTRY RUN OS1 APIN TLAB BHT MRT ST DFD DFV DFPH DFL MST RMS MFST RMF MCST RMC RMB RMFB RMCB EKB EDF EGL EDP BS CS CW1 CBD1 CBL1 CSD DMF LMF BLI TLI APIF PD DATE CBF APD TCS DL DD : F : TBU G 14A RD : UNOCAL : MCARTHUR RIVER : CONDUCTOR 13 LEG 4 : .0000 : .0000 : 29 : 9N : 13W SM : KENAI : ALASKA : USA : 2 : NONE : 50-733-2018901 : 0 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : 103.0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : .0000 : K.B. : K.B. : .0000 : .0000 : 0 : MSL : 5-11-92 : .0000 : 103. 0000 : 0 : .0000 : .0000 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 DLOD 3HRI 68 1 2 GR HRI 68 1 3 HDRS 3HRI 68 1 4 HMRS 3HRI 68 1 5 HDCN 3HRI 68 1 6 HMCN 3HRI 68 1 7 DFL3 HRI 68 1 8 SP HRI 68 1 9 TENS 3HRI 68 1 LB 4 GAPI 4 OHMM 4 OHMM 4 MMHO 4 MMHO 4 OHMM 4 MV 4 4 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 4 00 000 00 0 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 312 Tape File Start Depth = 7867.500000 Tape File End Depth = 9812.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet 36 **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 1601267 datums Rep Code: 73 1 datum Rep Code: 79 2 datums Tape Subfile: 4 319 records... Minimum record length: 62 bytes Maximum record length: 1024 bytes Tape Subfi~le 5"is type: LIS **** TAPE TRAILER **** COMCEN 92/05/22 DENV 0 1 **** REEL TRAILER **** COMCEN 92/05/22 DENV TBUG14A 1 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 17 JUN 92 10:07a Elapsed execution time = 10 minutes, 36.5 seconds. SYSTEM RETURN CODE = 0