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177-018
RECEIVED STATE OF ALASKA ' ALVA OIL AND GAS CONSERVATION COM ION MAR 1 1 2016 REPORT OF SUNDRY WELL OPERATIONS NOGGL 1.Operations Abandon E Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Other: Installed G/L Completion/ 0 Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Re-enter Susp Well ❑ Installed 5-1/2"Liner 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development[] Exploratory ❑ 177-018 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20301-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Trading Bay Field/Middle Kenai B,C,D&E Oil,Hemlock,West Foreland&Undefined Oil Pools 11.Present Well Condition Summary: Total Depth measured 6,750 feet Plugs measured N/A feet true vertical 6,305 feet Junk measured N/A feet Effective Depth measured 6,683 feet Packer measured 996&4,993 feet true vertical 6,245 feet true vertical 996&4,734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner 4,019' 5-1/2" 5,015' 4,754' 7,740 psi 6,390 psi Perforation depth Measured depth 2,094-6,652 feet cp of r APR 1 9 2016 True Vertical depth 2,058-6,218 feet 2-7/8" 6.5#/L-80 320'(MD) 320'(TVD) Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/L-80 6,027'(MD) 5,663'(TVD) Liner Hgr Packer 996'(MD)996'(TVD) Packers and SSSV(type,measured and true vertical depth) FH Hyd Packer 4,993'(MD)4,734'(TVD) SSSV 309'(MD)309'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 183 467 34 399 210 Subsequent to operation: 68 57 704 936 95 14.Attachments(required per 20 PAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-022 .;,,- Contact 'Contact Trudi Hallett(907)777-8323 Email thallett(p hiIcorp.com Printed Name Stan W.Golis Title Operations Manager Signature t"1` L.' Phone (907)777-8356 Date 3 / ► 1 J 14 Form 10-404Revtsea5201 �/ 91_ BDMS LA_ MAR 1 4 2016 SubmitOrtglrrarOniy 74� /q �/—S-/� R • • il SCHEMATIC Trading Bay Unit Monopod Platform Well #A-32 API #50-733-20301-00 Completed:02/22/16 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=37.90' 20" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf 502' • 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4,451' 221' G! LL 9-5/8" 47 N-80 BTC-KC 8.681" Surf - 6,724' 1I 1 Liner: 5-1/2" 171* L-80 Geo Conn 4.892 996' 5,015' 502' Tubing: 2-7/8" 6.51* L-80 8rd EUE 2.441 Surf 320' / 2-3/8" 4.71* L-80 8rd EUE 2.041 320' 6,027' 111.F.1 FM JEWELRY DETAIL NO. Depth ID 1 Item TBG Hanger w/3-1/2"EUE Lift,3"BPV Type H Profile 309' 2.312 SSSV 2 996' 4.870 Liner Hanger Packer 2 3 2,210' 1.995 GLM-Live(Size 12 port) 4 3,814' 1.995 GLM-Live(Size 12 port) 5 4,946' 1.995 GLM-Orifice(Size 16 port) L i W 3 6 4,969' 1.995 Chemical Injection Mandrel 7 4,993' 1.995 5-1/2"FH Hydraulic Retrievable Packer B Zone 8 5,961' 1.875 _ X-Nipple 9 6,027' 2.375 WLEG 4451' L I Perforation Details c Zone Top - Zone Top(MD) Btm(MD) (TVD) Btm(ND) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open = BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 - CZN 4,591' 4,690' 4,378' 4,464' 99 Open LI 4 = 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN _ 4,840' _ 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze , --\.> C _ 5,041' 5,043' 4,777 4,779 2 Isolated 94 - CZN5,092' 5,110' 4,823' 4,839' 18 Open L L = ozone CZN 5,116' 5,142' 4,844' 4,867' 26 Open / � C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs (d' A = CZN 5,186' 5,216' 4,907' 4,934' 30 Open Id 5 = CZN 5,250' 5,260' 4,965' 4,974' 10 Open l 6 - C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs 0 ® = CZN 5,292' 5,348' 5,003' 5,053' 56 Open 7 = D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs tem = DZN 5,430' 5,460' 5,127' 5,154' 30 Open 4f,` - DZN 5,520' 5,560' 5,208' 5,244' 130 Open (� 7�� _ D 5,530' 5,560' 5,217 5,244 30 Isolated DZN 5,576' 5,610' 5,259' 5,289' 34 Open D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated DZN 5,638' 5,674' 5,315' 5,347' 36 Open X DZN 5,694' 5,722' 5,365' 5,390' 28 Open 18 DZN 5,758' 5,824' 5,422' 5,481' 66 Open 9 = E Zone D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs a-- DZN 5,850' 5,918' 5,505' 5,566' 68 Open - D 5,852' 5,912' 5,507 5,560 60 Isolated Hemlock EZN 5,947' 5,987' 5,592' 5,627' 40 Open - EZN 6,004' 6,026' 5,642' 5,662' 22 Open -West Foreland EZN 6,032' 6,089' 5,667' 5,718' 57 Open L 1 D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open PBTD=6683'(WLM) TD=6750' HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated MAX HOLE ANGLE=30° @ 4600' Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by: JLL 3/9/16 • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-32 Monopod Rig 56 50-733-20301-00 177-018 2/13/16 2/22/16 Daily Operations: 02/13/2016-Saturday N/U riser w/adaptor spool. N/u BOPE,tq flange bolts,checked accumulator bottle pre-charge.Charged t/1000 as needed. Installed flow line w/ground. Rebuild MP#2 pop off&test good. R/u remote BOPE panel. Install upper 2 7/8 x 5 1/2, Blind&lower 2 7/8 x 5 1/2 ram blocks. Install choke&kill lines,accumulator lines, power up accumulator& function tested BOP,good. 02/14/2016-Sunday Install turnbuckles,drip pan,flow nipple. R/u tongs, bails,elevators. Install mouse hole,stock floor w/subs. Install shaker screens. R/u steam lines. Install brushes on RT traction mtr. Installed cellar skirting. M/u 2 7/8 t/j. Filled stack &choke manifold w/water,shell tested 250/2500. Found leak on btm of single gate flange&adaptor flange,tq. same, re-test,good. Notify AOGCC inspector of good shell test,will be out on 7:30 am chopper.Cont. pre-test,check PVT sys&alarms,flow line sensor.Gather subs for 3 1/2 tj. 02/15/2016-Monday Cont. housekeeping while waiting f/AOGCC inspector to arrive.Test BOPE as per Hilcorp&AOGCC regulations,Test witnessed by AOGCC inspector,Jeff Jones.Tested w/3 1/2&2 7/8 tj's, 250 low, 2500 high. Had one FP,choke line valve,functioned, retested good. NOS Rep M/U T-bar to BPV.Opened valve to check pressure beneath. Decision was made to pump again ("'60#s under BPV). Released from BPV. Pumped 80 bbls 3%KCL at 1 BPM 1400#s down tb (taking 8 bbls to fill).Shutdown pump. M/U T-bar again to check pressure-^ 33#s under BPV. Released from BPV and pumped another 80 bbls 3%KCL at 1 BPM 1400#s down tb(taking 8 bbls to fill).Shutdown pump. M/U to BPV and opened same.Zero pressure under valve. Removed valve and M/U landing jt w/SV. B/O hold down pins and P/U on string, moving hanger at 90k(w/bag closed on tb). Packer released.at 125k. Picked up 3'w/string weighing 90k. Began attempting to circ 3%KCL at 1 BPM 2000#s down tb (taking 8 bbls to fill). Pumped 400 bbls w/o returns. Shutdown pump. Monitor well,static. Pump 5 bbls down annulus t/fill hole. 02/16/2016-Tuesday Continued monitoring well,filling tbg on the hr w/6-7 bbls 3%KCL.Attempted to circulate in reverse but pressured up. L/U to production and attempted to flush oil in riser. R/U steam cleaner in cellar and prepped catwalk for E-Line unit. Built KCL volume while waiting on wireline. R/U Pollard E-Line with full lubricator and M/U 1 3/8" HSC Idd 1'4 SPF w/circ TN and perfect undgr_ kr-at 35X-351.-.P.00J-I (all shots fired). R/D/R E-Line unit&personnel. Broke circ caught presure @ 35 bbls.Cont.pumping,got oily returns t/surface @ 60 bbls. Lined up to send oily returns to prod facility.Circulated until returns cleaned up.Calculated loss rate at 36 BPH. Prepped to pull tbg-lined up to continuously fill hole. Pulled hgr to rig floor(still unable to slack off). Summit and NOS disconnected all lines to hanger and B/O L/D same. Held PJSM w/all personnel discussing cutting ESP cable and well shutin procedure. POOH to SSSV. Laid out SSSV, Hydroset pkr,GLM,X-nipple&2 7/8"XO plus all pups(395.65'). R/U Summit sheaves. Well now taking"'56 BPH. POOH w/2 7/8"6.5#L-80 EUE tubing. Laid down 2 singles(tbg in good to excellent condition)then stood back 17 stands(at report time)=2,081'OOH-EOT at 3,825'. • 0 II Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-32 Monopod Rig 56 50-733-20301-00 177-018 2/13/16 2/22/16 Daily Operations: 02/17/2016-Wednesday Finished POOH w/old Summit 4.5" ESP completion assy from 3,825' (continuously filling hole w/3%KCL-"'66 BPH fluid losses). Had scale on O.D.of tbg starting^'4500 to ESP. B/O L/D ESP assy. Found 1st pump section plugged with scale top to btm-no other apparent reason for failure.Cleared and cleaned rig floor. Moved Pollard SL unit into position. Landed wear bushing. R/U SL w/lubricator. M/U 1 3/4"stem x 2,oil &spang jars w/6"gauge.Off loaded Summit equipment and remainder of 2 7/8" EUE tbg plus ESP hardware,SSSV,GLM &X-nipple w/all pups and X- Overs onto M/V Titon.TIH w/6"gauge tagging at 6,518'.Could not get deeper. POOH. R/D/R slickline.Calipered and strapped bit&scraper. M/U 8 1/2" rock bit,7 7/8"x 2 1/4" scraper for 9 5/8"casing,6"x 2 1/4" bit sub,6"x 2 11/16"X-O sub,4 3/4"x 2 7/16"X-0 sub=9.04'. TIH w/bit&scraper on 2 7/8"6.5#L-80 EUE tbg to 2,051'.Worked scraper from 2,050'to 1,954'several times. M/U next stand and slacked off to 2,148'. Picked back up breaking off two singles-putting EOTs at 2,078'. M/U S/V and pumpin w/Kelly hose. Began circ L/W at 4 BPM 424#s. Increased rate to 6 BPM 730#s. 1400 of 4500 stokes pumped at report time. 02/18/2016-Thursday Finished circulating hole clean(L/W)at 2,078'-pumping a total of 450 bbls at 6 BPM 750 PSI (partial returns). B/O Kelly hose, pumpin&S/V. POOH standing back 300.87'of 2 7/8" EUE tbg. Laid down 60 more jts and B/D bit& scraper.Cleared and cleaned rig floor. Removed 2 7/8"x 5 1/2"VBR and Idd 2 3/8" blocks in upper pipe ram. M/U 2 3/8"test jt w/inverted test plug. Pulled wear bushing-turned test plug over,tightened and landed test jt. Lined up to continue filling hole at casing head.Tested pipe rams&hydril to 250#s low/2500#high as per AOGCC& Hilcorp requirements(after repairing leak on single hold down pin). Pulled test plug& B/D same. M/U 5 1/2"test jt w/test plug and landed same.Tested to 250#s low/2500#s high as before. Released pressure and pulled test plug. Flipped test plug over and set wear bushing. B/D 5 1/2"test jt. R/U Weatherford Tong Service and held PJSM will rig and crane crews,Weatherford &Tripoint. Prepped safety valve w/casing connection. M/U WREG on 1st jt of 5 1/2" 17# P-110 Geoconn casing and TIH rabbitting w/4.767"Teflon drift. M/U to specs("'11,000#MUT). 65 of 91 jts of liner in hole at report time=2,852'. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date A-32 Monopod Rig 56 50-733-20301-00 177-018 2/13/16 2/22/16 Daily Operations: 02/19/2016-Friday Finished P/U 5 1/2" 17#P-110 GeoConn liner(from 2,852'to 4,002'). M/U liner hanger packer and running assembly. Circulated tubing volume to stop u-tubing at 4.5 BPM 140 PSI(P/U 78k S/0 72k).Continued running in 5 1/2" liner assembly on 4 1/2"S-135 IF DP and tagged at 5,016' (EOTs)-pkr at 996'. Could not P/U or S/O(stuck at pkr). Discussed options with engineers. Decision was made to adjust completion depths to fit situation (approval from Mr. Schwartz). Dropped setting ball then M/U safety valve&pumpin sub w/kelly hose 15' in the air. Pressured up to 4000#s(after repairing leaks)and held pkr setting pressure f/45 mins(as per Tripoint). Released pressure and lined up to pump down annulus. Pressured up to 1700#s and charted f/35 min. Bled off pressure and worked pipe from 100k to 25k several times to aid/check pkr setting. Released from pkr w/15 rnds RHT. Pulled 1st jt and B/D safety valve/pumpin assy. Lined up to continuously fill hole. Moved 3 stands of 2 7/8"tbg to opposite side of derrick. POOH racking back 41/2" IF DP. B/D Tripoint pkr running assembly. Pulled wear bushing while crane crew offloaded new production string and hardware from M/V Titon. Cleared and cleaned rig floor.Changed out handling tools. Tripoint tallied all components of production string. M/U rotating mule shoe on btm of 1st jt of 2 3/8"4.7#L-80 EUE production tbg and started in hole. R/D Farr tongs because 2 of the 4 dies were unuseable,scarring pipe. R/U Knight McCoy tongs. 479'of—6,027' in hole at report time. 1351 bbls 3% KCL loss last 24 hrs=56 BPH average. 02/20/2016-Saturday Continued running in hole with 2 3/8"4.7#L-80 EUE production tbg from 479'to 1,081'. M/U R/I 5 1/2" FH pkr,chem injection mandrel and GLM w/pups as per procedure(Pollard connected1/4" control line and pressured tested to 5k). Continued R/I 2 3/8" prod string adding GLM#2&3. M/U SSSV w/pups at 5,695' (Pollard plumbed in 1/4" line to SSSV and tested same to 4000#s). M/U R/I 8 jts of 2 7/8" 6.5#L-80 EUE prod tbg. P/U 2 7/8" EUE landing jt w/pup crossed back to 3 1/2" EUE. M/U tbg hanger with assistance from NOS rep and plumbed in control lines. Landed hanger and ran in all hold down pins, placing tubing tail @ 6,027.90',top of packer @ 4,993'. R/U S/V w/pump in sub-dropped bar. Opened annulus and filled tbg w/4.5 bbls. Pressured up to 4000#s f/30 mins(as per Tripoint). Bled off pressure. Lined up to pump down annulus-opened tbg. Filled backside with 13 bbls then pressured up to 1600#s f/35 mins on chart-bled off pressure. R/D pump lines and R/U Pollard slickline. 02/21/2016-Sunday Finished R/U Pollard slickline w/full lubricator(pressure tested to 1500#s). RIH and retrieved drop bar in X-nipple at 5,961',retrieved dummy valves in mandrels at 4,968',4,946',3,814'and 2,210'. Loaded live valves in same then pulled plug in X-nipple. R/D slickline. During W/L ops rig crew skimed oil from pits, performed general house keeping and prepped to skid to A-25 for temp survey. NOS rep landed BPV in tbg head. N/D bell nipple assembly. Bolted up lifting device to annular.Connected trolleys system to lifting device then separated BOPs under single gate. Moved BOPs to the side and attached block to riser. N/D riser and lifted same out of well room, laying it on the pipe deck. Lowered adapter flange into well room and NOS plumbed control lines. Bolted same to tbg head. N/U all tree components.Void tested tbg head to 4800#s good. Pulled BPV and set 2-way check. Continued working toward shell test on tree. 02/22/2016-Monday Tested tree t/5000,good. Pull TWC and turn well over to production. • • P70 /77 -a I g Loepp. Victoria T (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Friday, February 12, 2016 8:30 AM To: Loepp, Victoria T (DOA) Cc: Schwartz, Guy L (DOA); Quick, Michael J (DOA);Juanita Lovett Subject: RE: Monopod A-32 (PTD# 177-018) Sundry# 316-022 Follow Up Flag: Follow up Flag Status: Flagged Thank you,Victoria. Tru,dv From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Friday, February 12, 2016 8:26 AM To: Trudi Hallett Cc: Schwartz, Guy L(DOA); Quick, Michael J (DOA) Subject: RE: Monopod A-32 (PTD# 177-018) Sundry # 316-022 Trudi, Thanx for the update. Approval is granted to use KCI(up to 6%)for workover fluid. Please update the"Changes to Approved Rig Workover Sundry Procedure"form. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission333 W.7th Ave C Q r1 Anchorage,AK 99501 SCANNED MAY 8 2U16 Work: (907)793-1247 Victoria.Loepp(a.alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Trudi Hallett [mailto:thallett@hilcorp.com] Sent: Friday, February 12, 2016 7:52 AM To: Loepp, Victoria T(DOA) Cc: Juanita Lovett; Schwartz, Guy L (DOA) Subject: RE: Monopod A-32 (PTD# 177-018) Sundry # 316-022 1 • Good Morning Victoria/Mike- • Please see note below regarding change to procedure to upcoming rig workover on the Monopod platform.Thanks! From: Trudi Hallett Sent: Friday, February 12, 2016 7:44 AM To: 'Schwartz, Guy L (DOA)' Cc: Juanita Lovett Subject: Monopod A-32 (PTD# 177-018) Sundry # 316-022 Good Morning,Guy- In regards to the Monopod workover on well A-32, Sundry#316-022,we will be using KCI for our workover fluid (up to 6%)—as needed. In the sundry, I stated we will be using filtered inlet water for the entire job.Just wanted to give you a heads up prior to us starting the job.We plan to BOPE test this upcoming Sunday/Monday. If approved,we will update the"Changes to Approved Rig Workover Sundry Procedure"form.Thanks! TrltioLi. Trudi Hallett Operations Engineer Cook Inlet Offshore Asset Team I Hilcorp Alaska,LLC Hilcorp A Company Built on Energy thallett@hilcorp.com 0: 907.777.8323 C: 907.301.6657 2 0', OF 7' w0 //7, �,�s THE STAT• Alaska Oil and Gas • ���\\I//ice A of AL ASKA Conservation Commission.11121 333 West Seventh Avenue w: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager 5COMMED FEB 2 4 Z016 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai B, C, D, and E, Oil and Hemlock Oil Pools, Trading Bay St A-32 Permit to Drill Number: 177-018 Sundry Number: 316-022 Dear Mr. Golis: 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. Foerster Chair DATED this 2#day of January, 2016. RBDMS -- .1A" 2 2 2016 • • RECEIVED • STATE OF ALASKA JAN 1 20 6 ALASKA OIL AND GAS CONSERVATION COMMISSION Q f4 I 2( APPLICATION FOR SUNDRY APPROVALS AO C 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend [1 Perforate ❑ Other Stimulate ❑ Pull Tubing 2 • Change Approved Program ❑ ❑ ❑ ❑ ❑ Other: Install G/L Completion/Ei Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Install Liner r•+n L 1 L Zi?b,t,vt��/ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC _ Exploratory ❑ Development _ 177-018 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20301-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 J Trading Bay St A-32 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018731 - Trading Bay Field/Middle Kenai B,C,D&E Oil,Hemlock,West Foreland&Undefinded Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,750 . 6,305 - 6,683 . 6,245 -378 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2,094-6,652 - 2,058-6,218 3-1/2" 9.3#/L-80 394' 2-7/8" 6.5#/L-80 5,807 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydroset II Packer&TE-5 SSSV 354'(MD)354'(TVD)&329'(MD)329'(TVD) 12.Attachments: Proposal Summary E Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development[] - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/26/2016 OIL E - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett(a'�hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature `-�"t 4kt Phone (907)777-8356 Date 1/12/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2Plug3lle- a 2_1- Plug Integrity ❑ BOP Test L'I Mechanical Integrity Test ❑ Location Clearance ❑ Other: ( Z5a; , ,- 501 •-r-,--f. 1--- Post / s1Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1 Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: C. c.- 's 7 APPROVED BY Approved by: C / / COMMISSIONER THE COMMISSION Date: 7 2./-7 RBDMS LL JAN 2 2 2016 Y' 1-lif-/ /� �i i 1 13Ii� � /,4Submit Form and Form 10-403 Revised 11/2015 J Rt ptl0 lid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: A-32 11iIcorp Alaska,LL Date: 01/12/2016 Well Name: Monopod A-32 API Number: 50-733-20301-00 Current Status: Oil producer Leg: N/A Estimated Start Date: 01/26/2016 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 177-018 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 584 psi @ 2,058'TVD(2,120'MD) based on SIBHP gauge data 1/4/2016 Maximum Expected BHP: 584 psi @ 2,058'TVD(2,120'MD) no new perfs being added ✓ Max.Potential Surface Pressure(MPSP): -378 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary The A-32 well is currently completed as an ESP producer with a high set packer.The re-completion plan involves pulling the failed ESP and running a new completion on gas lift and return to production. L cine 0 z Last Casing Test: On 10/21/2013 the casing was tested to 2,300 psig at 2,080' and charted for 30 minutes. Procedure 1. Skid rig and RU over A-32. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250 psi LOW and 2500 psi HIGH. %" L' ir- L 3. Monitor well to ensure it is static. (Using FIW as workover fluid) (�✓ 7 j `7 4. Unseat hanger and high set packer, pull hanger up to floor height. c_BU. 5. POOH laying down tubing and ESP equipment. U` 6. PU 2-7/8" tbg w/9-5/8" bit/scraper to ±6,000'. POOH. LD same. 7. RIH with 5-1/2" liner, setting packer at±2,000'. 8. Test to 1500 psi charting for 30 min. POOH. LD workstring. 9. P/U 2-3/8"gas lift completion, setting 2-3/8" x 5-1/2" packer @ ±5,950'. 10. Test to 1500 psi charting for 30 min. 11. ND BOPE, NU wellhead and test. 12. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead 5. Proposed Wellhead 6. Fluid Flow Diagram 7. RWO Sundry Revision Change Form • • SCHEMATIC Trading Bay Unit Monopod Platform Well#A-32 API #50-733-20301-00 Completed: 12/25/2014 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=37.90' 20" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 9-5/8" 47 N-80 BTC-KC 8.681" Surf 6724' 221' Tubing: 1 3-1/2" 9.3# L-80 8rd EUE 2.992 Surf 394' -2 2-7/8" 6.5# L-80 8rd EUE 2.441 394' 5,807' AD i 3 4 JEWELRY DETAIL 502'L mow 5 S. NO. Depth ID Item 37.90 6.184 10"TBG Hanger 1 329' 2.813 Baker"TE-5"SSSV CVlJ) 2 354' - 9-5/8 x 3-1/2"Hydroset II Packer 3 371' - GLM ' re-it- �17>x:-c%+.-,- 4 390' - X-Nipple ', 5 394' - 3-1/2"EUE x 2-7/8 EUE crossover 6 5,807' - Discharge,Bolt-On 7 5,809' - Pump(x3) 8 5,866' - Intake = B Zone 9 5,883' - Motor 10 5,906' - Anode 4451'L S Perforation Details = Top C Zone Zone Top(MD) Btm(MD) (ND) Btm(TVD) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open = CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated = CZN 5,092' 5,110' 4,823' 4,839' 18 Open ozone CZN 5,116' 5,142' 4,844' 4,867' 26 Open = C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs _ CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN 5,292' 5,348' 5,003' 5,053' 56 Open 0 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open 6 _ DZN 5,520' 5,560' 5,208' 5,244' 130 Open = D 5,530' 5,560' 5,217 5,244 30 Isolated 7 = DZN 5,576' 5,610' 5,259' 5,289' 34 Open 8 D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated 9 DZN 5,638' 5,674' 5,315' 5,347' 36 Open - 10 DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open E Zone D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs _ DZN 5,850' 5,918' 5,505' 5,566' 68 Open = D 5,852' 5,912' 5,507 5,560 60 Isolated Hemlock EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN 6,004' 6,026' 5,642' 5,662' 22 Open ea Foreland EZN 6,032' 6,089' 5,667' 5,718' 57 Open Z. S. D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open PBTD=6683'(WLM) TD=6750' HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated MAX HOLE ANGLE=30° @ 4600' Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by: JLL 01/22/15 i 0 . 11 PROPOSED Trading Bay Unit Monopod Platform Well#A-32 API #50-733-20301-00 Completed: FUTURE CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=37.90' zo" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 221' L 9-5/8" 47 N-80 BTC-KC 8.681" Surf 6724' 1 Liner: 5-1/2" 17± P-110 Geoconn 4.892 ±2,000 ±6,000 502' Tubing: 2-7/8" 6.5± L-80 8rd EUE 2.441 Surf ±600' 2-3/8" 4.7± L-80 Supermax 2.041 ±600' ±6,030' JEWELRY DETAIL NO. Depth ID Item TBG Hanger 1 ±300' SSSV 2 ±2,000' Liner Hanger Packer 2 3 ±2,191' GLM 1. 4 ±3,793' GLM 5 ±5,011' GIM 3 6 ±5,844' Orifice 7 ±5,910' Chemical Injection Mandrel B Zone 8 ±5,950' Packer 9 ±5,960' X-Nipple = 10 ±6,030' WLEG 4451'L e ibl 4 = = Perforation Details Top C Zone Zone Top(MD) Btm(MD) (ND) Btm(ND) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 1 5 = 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 = CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze = C 5,041' 5,043' 4,777 4,779 2 Isolated CZN 5,092' 5,110' 4,823' 4,839' 18 Open �'. = DZone j., = CZN 5,116' 5,142' 4,844' 4,867 26 Open t* = C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs / CZN 5,186' 5,216' 4,907' 4,934' 30 Open + v //I 17 = CZN 5,250' 5,260' 4,965' 4,974' 10 Open AY = C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs 6id = CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open DZN 5,520' 5,560' 5,208' 5,244' 130 Open = D 5,530' 5,560' 5,217 5,244 30 Isolated = DZN 5,576' 5,610' 5,259' 5,289' 34 Open = D 5,590' 5,606' 5,271 5,286 16 Isolatediii IF 7D 5,630' 5,662' 5,308 5,336 32 Isolated 8 DZN 5,638' 5,674' 5,315' 5,347' 36 Open FM am v/v)- 9 DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open E Zone D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs = DZN 5,850' 5,918' 5,505' 5,566' 68 Open D 5,852' 5,912' 5,507 5,560 60 Isolated /;{'V = Hemlock EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN 6,004' 6,026' 5,642' 5,662' 22 Open =West Foreland EZN 6,032' 6,089' 5,667' 5,718' 57 Open L S. D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open PBTD=6683'(WLM) TD=6750' HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated MAX HOLE ANGLE=30° @ 4600' Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by: JLL 01/12/16 • • Monopod Platform A-32 Current ESP 01/07/2015 Hilrorp Aitaxk 1.I.IA: Monopod Platform Tubing hanger,Seaboard- A-32 ESP-EN,11 X 2 7/8 EUE lift 20 X 16 X 133/8 X 95/8 X and Susp w/2 1/2"Type H 2 7/8 BPV profile,2-''A CC, Prepped for B1 W penetrator BHTA,Bowen,3 1/8 SM X 2.5 Bowen quick union • .>! +,^,. oN Valve,Swab,WKM-M, ®®p\ 3 1/8 SM FE,HWO,DD trim i. ,,air' Valve,Wing,WKM-M, V 000 31/8 SM FE,w/15"OMNI .s._/.0 ):..1111.1111,., operator,DD trim Valv,Wing,WMM, B1 21/16 SM FE,HWO,00 trim 411(0)® Q o ni 41Valve,Master,WKM-M, P 31/8 5M FE,HWO,DD trim Arc Adapter,Seaboard-ESP, wi "` 11 5M rotating flange 2 9/16 5M rotating flange, w/4 5/8 pocket,w/2-14 CCL, ported for BIW penetrator vs 1 line ii in 1� — I Aiiii Opr i E.-- Tubing head,5-8,13 5/8 3M x 1 11 5M,w/2-2 1/16 5M SSO, 1 151 w/BG bottom - w/1-21/165M WKM-M 'NII_I i valves 'I!' „ —AM I�®(0.)®!iII'•1 i.,i 11 0 11 '1 11 Casing spool,OCT-29L,2115 _ ^ r� 2M X 135/83M,w/2- 181 `' I+ 1.II 2 1/16 5M SSO, 13 3/8-00 bottom - ,�•'� ¢`\ C-22 slips installed 'II-11 I 111 ('•_,,;►-�h III f InA ill I I 101 _ o Ilp - Starting head,OCT Type II, 21 V.2M X 20"SOW, + w/4-21/162MSSO Ill hi Iii PSI 16"casing hung off on mandrel _ 13 3/8"casing on C-29 slips 1 '[ lit. -�'! - _r, "-.4,100_,0-4)1 X11'• • �, ` _ .. . 1, :40,......,, ,._:., ii ...,.. il 1 11 ..111_,;.,..1,67;-,1)1101,4 `l ,,,, m 4i-- zo" 16" 13 3/8" 9 5/8" —2 7/8" • • Monopod Platform .11 A-32 Proposed 01/06/2016 I ilm p tlarka-1J.(. Monopod Platform Tubing hanger,SME-CL,11 X A-32 3'A EUE lift and susp,w/3" 20 X 16 X 13 3/8 X 9 5/8 X Type H BPV profile,2-3/8 2 7/8 CCL,Alloy material BHTA,Bowen,3 1/8 SM X 2.5 Bowen quick union II III i III u, n, Valve,Swab,WKM-M, 3 1/8 5M FE,HWO,DD trim ;, f4 iiii.. Valve,Wing,WKM-M, 6 3 1/8 5M FE,w/15"OMNI ,,, ,,, operator,DD trim :: O ",r_ .., Valve,Master,WKM-M, 3 1/8 5M FE,HWO,DD trim °;..* u,� n X2L III Contra - .l Tubing head,5-8,13 5/8 3M x I �T 11 SM,w/2-2 1/16 SM SSO, `�' j--- w/BG bottom - , ()% w/1-21/165MWKM-M — 101 valves . - , I••1 AI n I II ♦- Casing spool,OCT-29L,21''A �C -----,11:10 � 2M X 13 5/8 3M,w/2- Y' LUI 2 1/16 5M SSO, 13 3/8-00 bottom ' C-22 slips installed /- /� jh ( ;•_ 1 II Cm 0 Starting head,OCT Type II, 21%2M X 20"SOW, �R w/4-2 1/16 2M SSO V— k , al 16"casing hung off on mandrel — — 13 3/8"casing on C-29 slips 44, [ jil X11! _ 1111,411014111: ,fl [4, ri .20" 16" 13 3/8" _9 5/8" L_ 2 7/8" • Monopod Platform 2016 BOP Stack(Workover) 01/08/2016 Hilrwp:Unoku_ Rig Floor IIMINge Bottom of air boot flange 4 5'below rig floor 16" Pipe 111 I%1�1111111 \ /n� 4.54' i 111 lil iii 1%1111 26.25' • Shaffer SL 2 7/8-5 Variables 44 2.83 13 5/8 SM Blind I. I1 Ill 11l111 Ill 1.76 ilI10�r� ..al V/i 0l,J�. Iii Ili 111 III I il' w/2 1/16 5M manual and HCR valves for choke and kill lines,w/Unibolt end connections for lines Ill 1/l lil Ill 111 2.83' 411� Sl8rams Ill Ill 111111 111 III 111III 111 Drill deck Riser 14.20' 135/85M FE X135/85M FE Fri-fffit fit 1!1 I!1 IF 111 I!1 Spacer spool 1.5' 135/8 SM FE X 115M al Ill 111111 OI • • 0 I:iii 1.1 1 0 i)! u000UO.DUUUUUU OUu0000U UU 000000UV O • (S)c, ) '‘.... I lk. j 0 Nor' ° 9oa_o O fi aimuu036vuuuuuuu ui3i3cRYa�ffO aht e` • lit II "Z ' =,000uuouuoouuuuuuuouuouououuu00000u P, o ;g._ bill! 0 0 V VOA! O( 21 _ a-5-- ;7&- $a WIN O ' 3 g4._ g E E E u__ tom• O I 3.1: a`l u u 0 3 6$^u o a u u u u u u u i 3 i 3" a 3 f f f u o a 1 Ciii C ,.i, $ o s o iwoe III il A "4111§06m 1 .L aIII�wm E 3 11 2 E 3' 8 3 efi -1. 1-)nn ageIllt a a 41I%Z.so = x a ra ...4.1(Zw0 4l ;& x § € t ] !7 A €8 _V 1 f.5 2 -- -- I i31111__I 2 3 • 38 4 -3' 5 �:-.. s f 1.4 A ,. A V f i f y. — . 1 0 , , ___.__ , , , 4411111•1111 r7-04- . Ism . --"..... . ----r ,, 1 EJ , Id -NJ- 4,I. • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska.1.1.1: Attachment#1 Attachment #1 Hilcorp Alaska, LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru the flare to atmosphere. 2) Load well with FIW to kill well. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Check well is static, shoot fluid levels if necessary. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. Clean and inspect lift threads (screw sub into threads, count the number of turns). Install blanking sub if using one. 2) NU BOP 3) Test BOPE per Monopod Rig#56 BOPE test procedure. Initial Test(i.e.Tubing Hanger is in the Wellhead) Rolling BOP Test 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, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept test 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 BPV and/or have lift-threads prepped for test joint. d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. • • Monopod Rig#56 BOP Test Procedure Hileorp;11„4a.�,i.( Attachment#1 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator or hanger leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC- guy.schwartz@alaska.gov ) and Mr.Jim Regg(AOGCC-jim.regg@alaska.gov )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: 5) With stack out of the test path, test choke manifold. 6) Conduct a rolling test: a. Test the rams and annular with the pump continuing to pump, holding a constant pressure on the equipment (monitor the surface equipment for leaks to ensure integrity). b. Record the pumping rate and pressure. 7) Once the BOPE tests are completed, test the remainder of the system following the normal test procedure (PVT, gas detection, etc.) 8) 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, list pressures and rates. 9) Pull hanger to surface (May require tubing cuts to free tubing) 10) Remove the old hanger, MU a new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. 11) Test BOPE per Monopod Rig#56 BOPE procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Riq 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open M"valves above valve 16, remove sensor above valve 3, and close all standpipe manifold valves. Fill stack w/water through kill line fill BOP and CMV's to top of annular. Close annular preventer X2 to get air out and continue to fill to top of dart valve. Close dart valve and continue to fill until fluid is seen out of CMV#5. Cont.fill till fluid comes out%" valves above CMV 16, close valve 16&4"kill valve on mud line. Open bleed line on standpipe manifold Have a hand in wellhead room w/casing valve open monitoring it open ended or to a gauge during all tests. In freezing temperatures, blow down mud line back through MP bleeder.Shell test. Test w/31/2 TJ 1) Close pipe rams, Open Annular, test CMV 3,5,15& 16, dart valve,pipe rams, 4"demco kill line valve, t/250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests) • • 14 Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,IAA, Attachment#1 2) Close TIW open dart valve, CMV's 8,9,12,13,14 kill line HCR, open CMV 15&4"Demco kill line valve (drain gas buster "U"tube immediately in freezing temps) 3) Close CMV's, 1,7,10,11, manual kill line valve, open CMV's 8,9,12,14, &kill line HCR 4) Close CMV's 2,4,6, open valves 1,7& 13 5) Close HCR choke line, open CMV 2 6) Close manual choke line valve, open HCR choke line valve Preform Accumulator test....then pull Ti With test jt in hole&system up to pressure. 1) Turn off electric& air pumps 2) Record accumulator pressure (+-3000psi) 3) Close Annular, pipe ram's, & her valves, open pipe rams to simulate blinds 4) While pressure is stabilizing check pressure in nitrogen bottles& record. 5) Record accumulator pressure 6) Turn on electric pump& time seconds to pressure up 200 psi, turn on air pumps& time till unit pressures up to 3000 psi&shuts off. (time will start from time electric pump starts till all pumps shut off) 7) Back out test jt&pull, close blinds, install test hose to choke manifold outside valve 5, close valves 2,4,6, open valve 11, choke HCR& inside choke line valve 8) M/U 2 7/8 t/j, close annular,fill test jt w/test pump till tiw/dart valve is full, then close, test 9) Close pipe rams, open annular, close tiw, open dart valve FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Test PVT system 3) Double check all rams and valves, for correct operating position 4) 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. - • • § k # 2Sa a) > WC 03 2a c 2E 0o2 .o / < ka. « — E§ / § t ) a) � § 2 0- c f < k � CD CA\ _0 > = f2� C \.§ 0_ in_ § / no -0 ■ ■ 2 \ � � � k k $ % % �>- c0 2J X CO ° Q £ @ >f \ B q / 2 X > @ a _a , O \ � X \ � g E X » ig - C a) % U & 70 co§ J < _ a) 22 E § / = D ® O 2 -g 2 o .0 / a) 1 \ / a. g a) c �k § C § / / . Cl) ' 0 c LU a) = g co Q 2 > 2 1 o 0. 0_ 43 M « @ 0 o 0. 2 a) x 0 § - 0 & 0 R To (U ,-4o U ; 0 < § q / m a 0 2 S x sk0 < EC - p ..Ell W © % % $ E -0 E 0 a) § a) o e a 2 k < < < E STATE OF ALASKA IV201ED6 ALASKA OIL AND GAS CONSERVATION COMMISSION RECJAN 0 5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install G/L Completion 1=3. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 . 177-018 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Numb- : Anchorage,AK 99503 50-733-, 1301-00 7.If perforating: 8.Well ptame d Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ��/./ Will planned perforations require a spacing exception? Yes ❑ No ❑ 1r •..=ay St A-32 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018731 . Trading Bay Field/Middle Kenai B,C,D&E Oil, 'emlock,West Foreland&Undefinded Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi). .' +�, psi Plugs(MD): Junk(MD): ' 6,750 • 6,305 - 6,683 - 6,245 N/A N/A Casing Length Size MD `O D Burst Collapse Structural / Conductor 221' 20" 221' ,' 221' Surface 502' 16" 502' 5n2' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' '� 4 56' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724 ` •,282' 6,870 psi 4,760 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: %re ill.i. g Grade: Tubing MD(ft): 2,094-6,652 . 2,058-6,218 3-1/2" 4.3#/L-80 394' 2-7/8" ' 6.5#/L-80 5,807 Packers and SSSV Type: `, Pack s n S'SV MD(ft)and TVD(ft): Hydroset II Packer&TE-5 SSSV , ,:', 354'(M 354'(TVD)&329'(MD)329'(TVD) ' 12.Attachments: Proposal Summary 2 Wellbore sche - I r 13.Well C ass after proposed work: Detailed Operations Program ❑ BOP Sketch 0r - / , ' - 10 •ry III Stratigraphic❑ Development Service ❑ 14.Estimated Date for 'V -II Status after proposed work: Commencing Operations: 1/19/2016 o: 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: •S ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the pro -•ure approved herein will not be deviated from without prior written ap• oval. Contact Trudi Hallett(907)777-8323 Email thallettahilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 4, .le Phone (907)777-8356 Date 1/5/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission that a representative may witness Sundry Number: 31 Lt — cb ( Plug Integrity ❑ BOP T-4-.1❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 0 Post Initial Injection MIT Req'd? Yes ❑ No ❑ OM Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 9" APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: w3 113-11‘/}Ili A le �/'t7 0 R G L 1 Submit Form and Form 10-403 Revised 11/2015 I I c�* d for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: A-32 Hilcorp Alaska,LL' Date:01/05/2016 Well Name: Monopod A-32 API Number: 50-733-20301-00 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: 01/19/2016 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 177-018 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 584 psi @ 2,058'TVD(2,120'MD) based on SIBHP gauge data 1/4/2016 Maximum Expected BHP: 584 psi @ 2,058'TVD(2,120'MD) no new perfs being added Max.Potential Surface Pressure(MPSP): -378 psi Using 0.1 psi/ft gradient per 20 MC 25.280(b)(4) Brief Well Summary The A-32 well is currently completed as an ESP producer with a high set packer.The re-completion plan involves pulling the failed ESP and running a new completion on gas lift and return to production. / Last Casing Test: On 10/21/2013 the casing was tested to 2,300 psig at 2,080' and charted for 30 minutes. Procedure 1. Skid rig and RU over A-32. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250 psi LOW and 2500 psi HIGH. 3. Monitor well to ensure it is static. (Using FIW as workover fluid) 4. Unseat hanger and high set packer, pull hanger up to floor height. CBU. 5. POOH laying down tubing and ESP equipment. 6. PU 3-1/2" WS w/9-5/8" bit/scraper to ±2,000'. POOH. 7. RIH with 2-7/8" completion, setting packer at±2,000'. 8. Test to 1500 psi charting for 30 min. 9. ND BOPE, NU wellhead and test. 10. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead 5. Proposed Wellhead 6. Fluid Flow Diagram 7. RWO Sundry Revision Change Form . ti • • SCHEMATIC Trading Bay Unit Monopod Platform Well#A-32 API #50-733-20301-00 Completed: 12/25/2014 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=37.90' 20" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 9-5/8" 47 N-80 BTC-KC 8.681" Surf 6724' 221'] Tubing: 3-1/2" 9.3# L-80 8rd EUE 2.992 Surf 394' 2 2-7/8" 6.58 L-80 8rd EUE 2.441 394' 5,807' a- ii 3 4 JEWELRY DETAIL 502'L 5 NO. Depth ID Item 37.90 6.184 10"TBG Hanger 1 329' 2.813 Baker"TE-5"SSSV 2 354' 9-5/8 x 3-1/2"Hydroset II Packer • 3 371' - GLM 4 390' - X-Nipple 5 394' - 3-1/2"EUE x 2-7/8 EUE crossover 6 5,807' - Discharge,Bolt-On 7 5,809' - _ Pump(x3) 8 5,866' - Intake B Zone 9 5,883' - Motor 10 5,906' - Anode 4451'L Perforation Details = Top C Zone Zone Top(MD) Btm(MD) (ND) Btm(ND) Amount Condition = BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 = CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated = CZN 5,092' 5,110' 4,823' 4,839' 18 Open D Zone CZN 5,116' 5,142' 4,844' 4,867' 26 Open C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs _ CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open 6 _ DZN 5,520' 5,560' 5,208' 5,244' 130 Open = D 5,530' 5,560' 5,217 5,244 30 Isolated = DZN 5,576' 5,610' 5,259' 5,289' 34 Open 8 = D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated 9 DZN 5,638' 5,674' 5,315' 5,347' 36 Open 10 DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open E Zone D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs _ DZN 5,850' 5,918' 5,505' 5,566' 68 Open D 5,852' 5,912' 5,507 5,560 60 Isolated Hemlock EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN 6,004' 6,026' 5,642' 5,662' 22 Open =We st Foreland EZN 6,032' 6,089' 5,667' 5,718' 57 Open 4 1 D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open PBTD=6683'(WLM) TD=6750' HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated MAX HOLE ANGLE=30° @ 4600' Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by:JLL 01/22/15 • • PROPOSED Trading Bay Unit Monopod Platform Well#A-32 API #50-733-20301-00 Completed: FUTURE CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=37.90' 20" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 9-5/8" 47 N-80 BTC-KC 8.681" Surf 6724' 221' Tubing: 2-7/8" 6.5# L-80 8rd EUE 2.441 Surf ±2,200' JEWELRY DETAIL 502'L .1 NO. Depth ID _ Item 111 TBG Hanger 4 1 ±300' SSSV 2 ±1,930' GIM 3 ±1,980' Chemical Injection Mandrel 4 ±2,000' Packer 5 ±2,200' WLEG _ __ B Zone Perforation Details Top Zone Top(MD) Btm(MD) (ND) Btm(ND) Amount Condition 4451'L _ , BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open _= BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 -- C Zone - CZN 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open = CZN 4,840' 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated CZN 5,092' 5,110' 4,823' 4,839' 18 Open FE CZN 5,116' 5,142' 4,844' 4,867' 26 Open C _ 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs CZN 5,186' 5,216' 4,907' 4,934' 30 Open = CZN 5,250' 5,260' 4,965' 4,974' 10 Open = C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs o Zone . CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open = DZN _ 5,520' 5,560' 5,208' 5,244' 130 Open D 5,530' 5,560' 5,217 5,244 30 Isolated = DZN 5,576' 5,610' 5,259' 5,289' 34 Open D 5,590' 5,606' 5,271 5,286 16 Isolated _ D 5,630' 5,662' 5,308 5,336 32 Isolated - DZN 5,638' 5,674' 5,315' 5,347' 36 Open DZN 5,694' 5,722' 5,365' 5,390' 28 Open - DZN 5,758' 5,824' 5,422' 5,481' 66 Open D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs DZN 5,850' 5,918' 5,505' 5,566' 68 Open D 5,852' 5,912' 5,507 5,560 60 Isolated EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN _ 6,004' 6,026' 5,642' 5,662' 22 Open E Zone EZN 6,032' 6,089' 5,667' 5,718' 57 Open D 6,050' 6,052 5,683 5,685 2 Block Squeze • Hemlock EZN 6,134' 6,150' 5,758' 5,772' 16 Open = HEM 6,250' 6,430' 5,860' 6,020' 180 Open est Foreland 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated L 1 WF 6,614' 6,652' 6,184' 6,218' 38 Open PBTD=6683'(WLM) TD=6750' MAX HOLE ANGLE=30° @ 4600' Updated by:ILL 01/05/16 • • Monopod Platform A-32 Current ESP 01/07/2015 Hilrarp Al.uekm,1.13: Monopod Platform Tubing hanger,Seaboard- A-32 ESP-EN,11 X 2 7/8 EUE lift 20 X 16X 133/8 X 95/8 X and Suspw/21/2'TypeH 2 7/8 BPV profile,2-''S CCL, Prepped for BIW penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union II 01 I III Valve,Swab,WKM-M, aro 3 31/85M FE,HWO,DD trim '. 1, 11 ♦ Valve,Wing,WKM-M, IV ' ® ,. 31/85M FE,w/15'OMNI ,�,�,., _ operator,DD trim Valve,Wing,WKM-M, �� 21/165M FE,HWO,DD trim I�S '. 4911 Q I : 0 1s eafWi3Valve,Master,WKM-M, ., (Q' 3 1/8 5M FE,HWO,DD trim 4^ .44 Adapter,Seaboard-ESP, "' '. 11 5M rotating flange x 2 9/16 5M rotating flange, w/4 5/8 pocket,w/2-'r4 CCL, ported for BIW penetrator X4 Control line rm - " ul � ')_ u0 4i :_.: Tubing head,S-8,13 5/8 3M x 11 5M,w/2-2 1/16 5M SSO, III III w/BG bottom 91 w/1-2 1/16 5M WKM-M II I I ® l - valves in) ow ,. „ , ��®lOJ®�I1ire' — �� Casing spool,OCT-29L,21'A Ecti r r 2M X 13 5/8 3M,w/2- li `1 1M1:•: 21/165MSSO, — -- f 13 3/8-00 bottom -/ 1. C\ [; I IMIlrti.)''',,•.;,1111-El=c5i C-22 slips installed jrn I 1.1 ' Starting head,OCT Type II, - �- 21'/2M X 20"SOW, `1- 'a ow i�.- w/4-2 1/16 2M SSO 651 _ (ii181 16"casing hung off on mandrel _— 13 3/8"casing on C-29 slips I l , . - - it_� ISI,-per..,,,.4.0: ��l 1:11111.' i il��lr " n 16, 13 3/8" 1 95/8" 2 7/8" . II • • Monopod Platform A-32 Proposed 01/05/2016 Ililrnrla tle.ku.ili.f, Monopod Platform Tubing hanger,SME-CL,11 X A-32 3 YEUE lift and susp,w/3" 20 X 16 X 13 3/8 X 9 5/8 X Type H BPV profile,2-3/8 2 7/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I u, RE n, Mx, iu Valve,Swab,WKM-M, $CP 3 1/8 5M FE,HWO,DD trim Bk. Valve,Wing,WKM-M, 3 1/8 5M FE,w/15"OMNI •,. ,,, operator,DD trim 1.1i ! © . 1 Valve,Master,WKM-M, ®®O 3 1/8 5M FE,HWO,DD trim ., �O Sip* X. Contrc 0 , .] u = ill ' r Ltla Tubing head,5-8,13 5/8 3M x '., 11 5M,w/2-21/16 5M SSO, Oa w/BG bottom w/1-21165MWKM-M 1 8 '' valves OJ0 �""� (ri7 r s e Casing spool,OCT-291,21''A -. rC '7 l•_ 2M X 13 5/8 3M,w/2- •• 1U1 ` a 1.1 2 1/16 5M SSO, 13 3/8-00 bottom 40-' • - C-22slips installed II 011i J�7 �I�� �I �I-�•'1 SII � 4 - 1.1 (1 ■ Ou 0 0 —' Starting head,OCT Type II, 21''I.2MX20"SOW, 'll:, . Fe w/4-2 1/16 2M SSO tit ` fid is 16"casing hung off on mandrel _— 13 3/8"casing on C-29 slips _ II 1 0:P.. f.:-II) ' ' ONEL„, lie--, ' i I 20" 16" 13 3/8" _9 5/8" 2 7/8" • Monopod Platform 2016 BOP Stack-workover 12/14/2015 HiIrnrp Masks'.MA. Bottom of air boot flange Rig Floor 5'below rig floor 16" Pipe P f irralnain filYITLI rrt fal 3.74' Shaffer 26 25' 135/85M ittlfffiI(h u h Itt 27/8 x5.5 variable Shaffer SL 0 2.83' Blind - 21/16 SM manual and 2 1/16 5M manual and 1.76' HCR valves for c side HCR valves for kill side I II I IIEI'III'I II . Ill I1OIj 46 Iil.lii.lil.iii —44"1"4 II, lull SI u Drill deck Riser 136/8SM FE X 135/85M FE 14.20' 14.20' !IV fit[fill 4-�ti Spacer spool 13 5/8 5M FE X 1.41' 11 5M I III 111111 -I . • • fiF— –VF = 40-- –N- C, ICI T1 3 –IF .C , 4.} F— I. 9w "I -hl--- P. ► 0M"# ► 4 N a w VOWS .4+ , 41.411.11.1.11w44- . 9 O u cy S , I ie V e • E 3 i E_ A E „ f n Pd i IJ 3g a A ' e 3 I. Li ; ► 9aZ 0 W o qa ! o ;°£. tia a 88 & GG a 9 y m c < i12 S a n < z n _ 4 6 ,Aa < S y ,i I" IM 8i ? t 2 DieEg A► OlaZg I► r E m <E E - E S ro < +� QUI IN bi fl < s P o o FL 1Ff 3W S 3S qI 0 VIN 1e o a e o n eIP yy _ ix R° if Al if 1 y °x "Le 0 0 0 3 3 3 3 a l i C 0 f n f n e@.ni m�n a w u = 1 n 3 I �.. �. 'sq. 000nnn,;vg -...,;vg a' uamw..o a a w �. ii rr 0333 v ?f Nf~ Ak 3o I Nal.' ' 4. "i§:55 _ .pi , hmEiR=EgF ( )o da4 oN n n 0 0 0 0 o n n n o n o n o n n o n n n n n n n 0 O n n o n n o 0 o x\ = ( .a 1111. . 9" O s3.sssi n6ufafE E,>Wti..o m.,aosWv m<> b; 0% )o © /#f; o o o`n`-"R v 3 z 3 - i 1, ,^` •,� •� a = L• 3 O .O nn0000 0onnnO OnOnnOnnnnnnn 0OnnOnn OOn _ NG Crl ._ 1 0 41 V_ - o L• a i r Monopod Rig#56 BOP Test Procedure Hilrarp Alaska.Mk: Attachment#1 Attachment #1 Hilcorp Alaska, LLC. BOP Test Procedure: Monopod Rig # 56 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru the flare to atmosphere. 2) Load well with FIW to kill well. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Check well is static, shoot fluid levels if necessary. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. Clean and inspect lift threads(screw sub into threads, count the number of turns). Install blanking sub if using one. 2) NU BOP 3) Test BOPE per Monopod Rig#56 BOPE test procedure. Initial Test(i.e.Tubing Hanger is in the Wellhead) Rolling BOP Test 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, establish static fluid level, shoot fluid level with an echometer gun or tag with slick line to establish static fluid level if necessary. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept test 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 BPV and/or have lift-threads prepped for test joint. d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. • • Monopod Rig#56 BOP Test Procedure x;,eor�,:1i,..ka,IAAAttachment#1 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator or hanger leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC- guy.schwartz@alaska.gov ) and Mr.Jim Regg(AOGCC-jim.regg@alaska.gov)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: 5) With stack out of the test path, test choke manifold. 6) Conduct a rolling test: a. Test the rams and annular with the pump continuing to pump, holding a constant pressure on the equipment (monitor the surface equipment for leaks to ensure integrity). b. Record the pumping rate and pressure. 7) Once the BOPE tests are completed,test the remainder of the system following the normal test procedure (PVT, gas detection, etc.) 8) 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, list pressures and rates. 9) Pull hanger to surface (May require tubing cuts to free tubing) 10) Remove the old hanger, MU a new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. 11) Test BOPE per Monopod Rig#56 BOPE procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Rig 56 BOP TEST Open kill line valve, mud cross valves, all CMV except 15, open X"valves above valve 16, remove sensor above valve 3, and close all standpipe manifold valves. Fill stack w/water through kill line fill BOP and CMV's to top of annular. Close annular preventer X2 to get air out and continue to fill to top of dart valve. Close dart valve and continue to fill until fluid is seen out of CMV#5. Cont.fill till fluid comes out%" valves above CMV 16, close valve 16&4"kill valve on mud line. Open bleed line on standpipe manifold Have a hand in wellhead room w/casing valve open monitoring it open ended or to a gauge during all tests. In freezing temperatures, blow down mud line back through MP bleeder.Shell test. Test w/31/2 Ti 1) Close pipe rams, Open Annular, test CMV 3,5,15& 16, dart valve,pipe rams, 4"demco kill line valve, t/250 low f/5 min, 2500 high f/5 min (straight line time each and remaining tests) • 14 • • Monopod Rig#56 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 2) Close TIW open dart valve, CMV's 8,9,12,13,14 kill line HCR, open CMV 15&4"Demco kill line valve(drain gas buster "U"tube immediately in freezing temps) 3) Close CMV's, 1,7,10,11, manual kill line valve, open CMV's 8,9,12,14, & kill line HCR 4) Close CMV's 2,4,6, open valves 1,7& 13 5) Close HCR choke line, open CMV 2 6) Close manual choke line valve, open HCR choke line valve Preform Accumulator test....then pull Ti With test jt in hole& system up to pressure. 1) Turn off electric& air pumps 2) Record accumulator pressure (+-3O0Opsi) 3) Close Annular,pipe ram's, & her valves, open pipe rams to simulate blinds 4) While pressure is stabilizing check pressure in nitrogen bottles& record. 5) Record accumulator pressure 6) Turn on electric pump& time seconds to pressure up 200 psi, turn on air pumps& time till unit pressures up to 3000 psi&shuts off. (time will start from time electric pump starts till all pumps shut off) 7) Back out test jt&pull, close blinds, install test hose to choke manifold outside valve 5, close valves 2,4,6, open valve 11, choke HCR& inside choke line valve 8) M/U 2 7/8 t/j, close annular,fill test jt w/test pump till tiw/dart valve is full, then close, test 9) Close pipe rams, open annular, close tiw, open dart valve FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Test PVT system 3) Double check all rams and valves, for correct operating position 4) 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. . ' • . 0 n0 / f 7 C / § k 0 2 Q ° 5 0 # .. m .8 0 0 R x 0 0 "Z - \ co / § m 0 * E co ATX o % \ § 0 p 2 0 2 / 3. & x < 2 0 m§ 0w m u) _ c XI co 5 w / � kis _ Q O. § CD0 ea -. 0 / 7 0 01X111- ae. \mo0 c J 2 C 0 !-R2 CD _ > n f ; co ■ 0 / - \ r /x X 2 k - ma x- kf 2 O CD \ o 0 a & * X "t k » ? x m g x a) z 73 �22 § $ A W Z DO CD % e (n § 2f § K � I (0 ° � � %Ts X Cc e � -(-13 E. D ƒ / J�� I \ cy < m \ (0 m . 0 0. / 3 D C § 220 \ & 3 � 0 / m - n 9 0.-'- = 7J * J Qo. ) 3 ■ Z £ CD( ate • S Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday,January 11, 2016 8:50 AM To: 'Trudi Hallett' Cc: Stan Golis;Juanita Lovett; samantha.carlisle@alaska.gov Subject: RE: Monopod A-32 (PTD# 177-018) 10-403 -Application for sundry approval Trudi, AOGCC will withdraw the recently submitted sundry for A-32 (#316-007)as requested. I'll look for the new sundry this week. Guy Schwartz Sr. 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(Guv.schwartz@alaska.gov). From: Trudi Hallett fmailto:thallett(Thilcorp.com] Sent: Friday, January 08, 2016 4:03 PM To: Schwartz, Guy L(DOA) Cc: Stan Golis; Juanita Lovett Subject: Monopod A-32 (PTD# 177-018) 10-403 - Application for sundry approval Hello,Guy— Apologies for any inconveniences. Hilcorp sent a new sundry application over Tuesday to workover the Monopod A-32(PTD#177-018). HOWEVER-The completion design has been changed to a proposed dual.We would like you to just send back or withdraw the sundry application we submitted and I will submit the new one next week. Please feel free to give me a call if you need clarification. Thank you, sir! Have a great weekend.© Thanks- Trudi Hallett hanks- TrudiHallett r./t a/tC i Cook Inlet Offshore Asset Team Hilcorp Alaska.LLC Hilcorp A Company Built on Energy thallett@hilcorp.com 1 ECEIVED STATE OF ALASKA ALA, .OIL AND GAS CONSERVATION COMM-_,ON JAN 2 3 2015 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other El Install ESP Performed: Alter Casing Li Pull Tubing0 Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 177-018 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20301-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 Trading Bay St A-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Trading Bay/Middle Kenai B,C,D&E Oil,Hemlock,West Foreland& Undefinded Oil Pool 11.Present Well Condition Summary: Total Depth measured 6,750 feet Plugs measured N/A feet true vertical 6,305 feet Junk measured N/A feet Effective Depth measured 6,683 feet Packer measured 354 feet true vertical 6,245 feet true vertical 354 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner Perforation depth Measured depth See Schematic feet ,`` , SCANNED - True Vertical depth See Schematic feet 3-1/2" 9.3#/L-80 394'(MD) 394'(TVD) Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 5,807'(MD) 5,466'(TVD) Packers and SSSV(type,measured and true vertical depth) Hydroset II Pkr 354'(MD)354'(ND) TE-5 SSSV 329'(MD)329'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 226 160 0 1140 252 Subsequent to operation: 225 170 320 860 260 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development} Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-547 / Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature � j1Lr V I' /J 60Lacy. Phone (907)777-8420 Date 1/23/2015 Form 10-404 Revised 10/2012 `" • /• 27-_,15, Submit Original Only Of ! /,f— RBDMS .)n JAN 2 6 2015 • . II SCHEMATIC Trading Bay Unit Monopod Platform Well #A-32 API # 50-733-20301-00 Completed: 12/25/2014 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP _ BTM. RKB to TBG Head=37.90' 20" 94 Driven 19.12" Surf 221' Tree connection: 16" 65 H-40 BTC 15.25" Surf _ 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' ., 9-5/8" 47 N-80 BTC-KC 8.681" Surf 6724' 221' Tubing: _ 1 3-1/2" 9.3# L-80 8rd EUE 2.992 Surf _ 394' 1111 2 2-7/8" 6.5# L-80 8rd EUE 2.441 394' 5,807' WM, 3 s 4 JEWELRY DETAIL am 502'L - 5 NO. Depth ID Item 37.90 6.184 10"TBG Hanger 1 ___ 329' 2.813 Baker"TE-5"SSSV 2 354' - 9-5/8 x 3-1/2"Hydroset II Packer 3 371' - GLM 4 390' - X-Nipple 5 394' - 3-1/2"EUE x 2-7/8 EUE crossover 6 _ 5,807' - Discharge,Bolt-On 7___ _ 5,809' - Pump(x3) _ 8 5,866' - Intake = B Zone 9 5,883' - Motor _ 10 5,906' - Anode 4451'L, = Perforation Details = Top C Zone Zone Top(MD) Btm(MD) (TVD) Btm(TVD) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open = BZN 2,478' 2,690' 2,422' 2,625' 212 Open BZN 3,494' 3,586' 3,377' 3,462' 92 Open = C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 = CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open _ CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze = C 5,041' 5,043' 4,777 4,779 2 Isolated -- CZN 5,092' 5,110' 4,823' 4,839' 18 Open DZone CZN 5,116' 5,142' 4,844' 4,867' 26 Open C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs EF_ _ CZN 5,292' 5,348' 5,003' 5,053' 56 Open _ D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open 6 _ DZN 5,520' 5,560' 5,208' 5,244' 130 Open _M D 5,530' 5,560' 5,217 5,244 30 Isolated 7 DZN 5,576' 5,610' 5,259' 5,289' 34 Open g D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated 9 DZN 5,638' 5,674' 5,315' 5,347' 36 Open 10 DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open LE E Zone D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs _ DZN 5,850' 5,918' 5,505' 5,566' 68 Open = D 5,852' 5,912' 5,507 5,560 60 Isolated Hemlock _ EZN 5,947' 5,987' 5,592' 5,627' 40 Open =w,v Fn o,v EZN 6,004' 6,026' 5,642' 5,662' 22 Open EZN 6,032' 6,089' 5,667 5,718' 57 Open Z. D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open PBTD=6683'(WLM) TD=6750' HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated _ MAX HOLE ANGLE=30° @ 4600' Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated _ WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by: JLL 01/22/15 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 10/15/14-Wednesday R/U on well. R/U Eline. Build guns for tubing punch.Shut down gas lift in A-32. Hook up bleed lines.Start bleeding off well through a hose to the header. R/U to circ down tubing. 1230-Tubing 250 psi,9 5/8 Annulus 200 psi.0100-Tubing 250 psi, 9 5/8 Annulus 200 psi.Open well back up on flow line to production header @ 0100.Continue bleeding to header.0300- Shut well in&check pressures-Tubing @ 200 psi.Annulus @ 50 psi. R/U to pump down tubing.Test lines&lubricator to 250/2500 psi.Good.Open up to tubing with 350 psi on the tubing.Start pumping @ 1 bpm. Pressure started dropping and by 10 bbl away pressure was 0 psi. Stage pumps up to 3 bpm with 0 psi on the tubing. Pump 35 bbl total.Shut down pumps.Check tubing pressure&tubing is on vac. R/U wireline with a tubing punch. 20'top shot to btm shot. 75 shots total. .35 average holes expected. Test lubricator to 2500 psi.Open up well.Well still on a vac. RIH with wireline&place top shot @ 5,390' Btm Shot @ 5,414'. Pump 15 bbl 3%KCL down the tubing to assure a column of fluid. Tubing pressure 60 psi before pumping fluid.Shut down pump and fire shots.Good indication of shots firing off of voltage. Monitor pressures.Tubing 0&Annulus 50.Total 3%KCL pumped down the tubing 50 bbl. 10/16/14-Thursday Pooh w/#1 tbg punch(all shots fired).Tbg 200 psi,Annulus 60 psi. Arm#2 tbg punch gun. Rih w/1-11/16"X 20'tbg punch loaded w/73 shots @ .35 exit hole @ 0 deg phased.Tied in to jewelry&placed gun on depth (4'dn from collar on first full jt under pkr) Pumped 15 bbls FIW w/3%KCL and put tbg on vacuum. Fired gun w/perfs f/2,059't/2,079' w/ good indication of fire.Also logged perfs,good. Pooh&monitor well pressure.Tbg built to 340 psi and still climbing, annulus @ 60(all shots fired). Install night cap. Have production open flow line,attempt bleed dn bubble(well flowing oil @+100 psi w/no decline in pressure)appears not to be a bubble. Discuss options with town. Have production test A-32. Well tested in @+1100 bopd. Production shut well in for pressure build up. Mobe perf guns to platform. Monitor pressures/Tubing @ 850 psi. PJSM. Run guns. Bleed off lubricator. M/U 20'of 2" guns with 3 spf.Test lubricator&2500 psi,good. RIH&place top shot @ 2,096'. BTM shot @ 2,116'. 3 spf.Shoot off of CCL&tubing tally. Fire guns.Good indication of fire. Pressures still 850 psi. POOH,all shots fired. M/U Gun run#2.Test lubricator T/2500 psi. RIH with 2"X 20' RTT guns 3 spf,0 phase. Place top shot @ 2,480'&btm shot @ 2,500'. Shoot off of CCL&tubing tally. Fire guns.Good indication of fire. Pressure on tubing 825 psi. POOH &L/D spent guns.All shots fired. R/D circ lines. Hook annulus back up to gas lift. M/U gun run#3 with 2"X 20' RTT Guns 3 spf. RIH &place top shot on depth @ 2,508'. BTM Shot @ 2,528'. Fire guns.Good indication of fire. POOH&all shots fired.Current pressure on tubing 825 psi. R/D wireline. Prep for rig move. 10/17/14-Friday Secure rig&safe out area.Continue prep rig to skid. 12/06/14-Saturday Skid rig. Reinstall storm clamps, hand rails ect. Continue to work on choke manifold. R/U to pump 3%8.6 KCL down well A- 32, build vol.in pits. Pollard prepairing to RIH on well A-32 with tubing punch.assist crane. M/U lubricator on well A-32& P/T T/2,000 psi 10min.test good. RIH W/1-11/16"X 20'tubing punch loaded W/80 shots @ .35 exit hole @ 0 deg phazed.Tie in W/collar locator to get on depth. [2,080'-2,100]Tubing pressure 650psi W/500 psi on casing.pump 20 bbls 3%8.6 ppg KCL W/tubing pressure falling T/0 psi. Fire punch W/good indication punch fired. Log perfs"good" POOH& R/D. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/14/14-Sunday No activity on well. Have production take well off line and let well equalize.Continue to secure rig/prep for slickline. PJSM, R/U Pollard wireline P/T Lubricator T/2,000psi 5/min. Run#1 RIH W/2.29"GR.Tubing pressure at 420 psi and saw fluid level @ 1,320'.Set down on obstruction at upper sliding sleeve WLM 5,328'tag[4]times. Pooh. Run#2 RIH W/1.75"drive down baler&tag fill @ 6,658'set down [3]times Pooh. Run#3 Rih again with 2.29 GR and added a nuckle joint&beveled bottom lip.Work through upper sliding sieve @ 5,329'and lower @ 5,882'continue down and out of tubing T/6,000' Pooh[clean]. RID wireline.At report time rigging up E-line.on last rih had 580 psi tubing pressure&fluid level was at 1,480' Rig up flow line, Building vol.in pit's,tighted adapter spool on riser. 12/15/14-Monday Swap out slick line for Eline unit and grease skid, R/up same,finish chg/out of wellhead bolts on A-12 service choke manifold.Test E-line lubricator t/250psi low/2,000psi high(ok).Tbg @ 650 psi, E-line Rih#1 w/2.25"jet cutter, noted fluid level @+-1,800'Tie in to tbg jewelry and place cutter on depth&sever tbg Cut#1 @ 5,906' Mid jt.Work tools(ok) attempt log cut set dn @ 5,906'wlm(appears tbg has shifted)no chg in tbg pressure. Pooh and re-arm Rih#2 w/1.68" RCT cutter, noted fluid level+-2,520'tie-in to tbg jewerly. Place cutter on depth&sever tbg#2 cut @ 5,425'wlm(3' below collar)work tools(ok)Log cut(can see cut but no separation) No chg in pressure tbg 650psi. Pooh and re-arm. Rih #3 w/2.25"jet cutter and set dn @ 5,425'#2 cut, noted fluid level @ 2,520' tie in to tbg jewelry and place cutter on depth and sever tbg #3 cut @ 5,354'work tools(ok)log cut w/good strong kick on CCL and able to pass thru, no chg in tbg psi @ 650psi,pooh&re arm;Rih#4 w/2.25"jet cutter, noted fluid level @ 2,520'tie in to tbg jewerly and place cutter on depth an sever tbg#4 cut @ 2,552',work tools(ok)attempt log cut and set dn @ 2,552' (appears tbg has shifted)no chg in pressure tbg @ 650psi pooh. R/dn E-line and in stall night cap. R/up circ line on pump in sub of lubricator&remove production line off annulus&r/up circ line on same&test line 250psi low/2,500psi high. Pjsm,check line up. Bullhead dn tubing W/8.8 ppg 3%kcl staging up T/4.5 bbl/min.with 200psi SPP cought pressure at 17 bbls away.As pressure slowly climbed to 300psi started decreasing pump rate in.5 bbl increments back dn to 2 bbl/min W/270psi SPP. @ 90 bbls pumped,shut dn.W/fcp of 275psi. Monitor tubing pressure dropping to"0"in 30 sec and on a vac in 3 min. Bullhead 40 bbl SSP @ 2 bbl/min followed W/6 bbls 8.8 3%kcl to clear surface lines, pressure at 260 falling to 175psi while pumping SSP.Shut down pumping. Monitor well.Tubing pressure down to"0"&on vac in 10 min. @ 15 min started building pressure back up going up to 320psi in 1/hr. Bullhead 170 bbls 8.8 3%kcl followed with 40 bbls SSP&clear surface lines W/6 more bbls 8.8 kcl pumping+-350 bbls total in to well @ 2 bbl/min [hole vol to suspected loss"B"zone @ 2,478'] max pressure while pumping was 660 psi.Shut dn pumping.Tubing went on a vac after 5 min. pull lubricator and install BPV. Pjsm; R/D safety valve&choke valve. Remove tree.Verify lift on hanger @ 3-1/2"eue 8rd.Tie onto stack turn same& move back.Cap chem. lines&lock open sssv. N/U Bope. @ report time picking up test tool's T/build 5"test jt.20"x 16"= 10 psi, 16"X 13-3/8"=60psi, 13-3/8"x 9-5/8"=200psi, 9-5/8"X 2-7/8"=40 psi KCL to well=213 bbls,Sized Salt to well= 82 bbls. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/16/14-Tuesday M/up 5"test jt and r/up test equipment,clear clean clear work areas from nip/up. Fuction test koomey w/new chip(ok) (OC Test hopes on 5"&2-7/8"as per AOGCC regulations,250psi Low/2,500psi High. Perform Koomey test w/one fail/pass unit bolt on kill side tighten bolt&re-test(good).Close blinds Pump 30 bbls 8.7 PPG 3%KCL @ 2 bpm @ 320psi initial pressure dn thru BPV and put tbg on vacuum and remove BPV close blinds an mointor pressure while testing gas alarms in 46 min gained 46 psi,chk for traped pressure spitting gas/air/fluid;Bull head pump 30 bbls 8.7 ppg 3%kcl dn tbg @ 2 bpm initial 55psi w/finial @ 570psi and dn pump, mointor bleed dn 409>30psi in 19 min.Chk for trapped pressure.Still spitting gas/air/fluid. Build pill of 10.00 ppg saturated salt w/3%kcl Pump 20 bbl dn tbg @ 2 bpm @ 320<530 psi, Dn pump and monitor bleed dn 400psi t/195psi in 2 min chk for trap pressure spit and sputtered for few min then died.Open blinds installed landing jt. R/up Pollard slick line&test lubricator 250psi low/2,000psi high(ok). RIH with kickover tool. Latch and pull valve at 1,978'. R/D Pollard slick line. Pump 160 bbls 3%KCL down tubing taking returns to production header at 4 BPM/430 psi.Caught oil returns with 64 bbls pumped and clean fluid at 135 bbls pumped.Shut down pump.Tubing and annulus at 0 psi. Pull landing joint. Install two-way check valve.Test blind rams at 250psi Low/2,500psi High.Good test. Pull two-way check and install landing joint and screw into top drive. Pump 30 bbls 3%KCL to production header at 4 BPM/380psi.Caught clean returns at 6 bbls pumped.Close annular preventer and line up to pump through choke manifold. Back out lock down screws. Pull tubing hanger and release DLH packer at 2,042'with 120 K pulled. Pull up hole 4'.Circulate at 4 BPM/300psi through choke manifold with high of 475 units of gas.Very little oil to surface.Continue circulating 4 volumes until gas at 230 units.Shut down pump and allow gas buster to drain.Open annular preventer. Move pipe up hole 6' but not able to go back down.Continue circulating hole at 4 BPM/250psi getting gas down to 65 units.Shut down pump. Obtain static loss rate at 5 BPH. Pull tubing hanger to rig floor and lay down same.Still not able to go back down hole. Pull 2 joints checking for swab.Circulate bottoms up at 4 BPM/350 psi. High gas of 115 units and background gas of 85 units. 20" x 16"=10psi, 16"X 13-3/8"=60psi, 13-3/8"x 9-5/8"=200psi, 9-5/8"X 2-7/8"=Opsi KCL to well=442 bbls,Sized Salt to well=82 bbls. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/17/14-Wednesday Finish circ total 426 bbls w/6 bph loss rate while circ. R/up slick line. RIH with kickover tool,set dummy valve in GLM @ 1,867'. POOH, pulled tight @ SSSV attempt work thru by hand,no go. Bleed off control line&function same and work tool thru(ok). Finish POOH (valve gone). R/D slick line. 20"x 16"=10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9-5/8"=200 psi, 9- 5/8"X 2-7/8"=0 psi. KCL to well=540 bbls.Sized Salt to well=82 bbls.Circ and stage rate t/8 bpm @ 1500 psi (had 175 psi difference in pump pressure)high gas of 114 units w/62 units back ground)also loss rate increased w/rate t/60 bph. POOH t/SSSV and remove same.Well swabbing and drinking(still unable to go dn)w/+1/8" paraffin on OD of tbg.Circ btm up @ 7 bpm @ 680 psi w/13 bph loss rate. High gas of 100 units&back ground of 50 units.Continue cleaning and l/dn 2-7/8"gas lift completion w/complete recovery= Hanger+71 jts 2-7/8"tbg+4 perforated jts+1 GLM+1 chemical injection mandrel+prk+1/2 cut jt tbg w/30 canon clamps and(14)1/2"SS bands. Est TOF @ 2,552'w/no sign of fill on OD of tbg w/loss rate of 3-5 bph.Clean rig floor and pipe rack. Install wear ring. P/up BHA#1=8 1/8"overshot,double pin sub, bit sub, BS/OJ,XO,9 ea 6 1/2" DC's,XO,Acc Jars=320.78. P/up rabbit and strap 5"5-135" 19.5#drill pipe to 2,533'. Obtain parameters: Up/Dn/Rt=98K/94K/97K. Circulate bottoms up at 8 BPM/220 psi. 520 units gas at bottoms up and tapered off to 120 units. Engage TOF at 2,556'at 4 BPM/70 psi.Saw pressure increase and swallowed fish 9'.Slight pack-off up to 800 psi but broke down to 5 BPM/800 psi rate. Begin jarring on fish and worked up to 200K to fire jars with no movement after 20 jar licks. Had pit gain of 2 bbls and gas increased to 550 units.Close annular and circulate bottoms up through choke manifold at 6 BPM/900 psi.Gas units tapered off to 85 units after full STS circulation. Recovered+/-1.3 bbls of sand.Open annular and allow gas buster to drain.Continue jarring up to 200K while circulating at 4 BPM/650 psi. Fish finally came free after approximately 42 licks.Gained additional 20K pick up weight.Could possibly have second packer as estimated extra weight should be 18K.0 gas units at this point.Circulate bottoms up at 8 BPM/900 psi with max gas of 252 units.Continue circulating until gas at<50 units.5 BPH fluid loss. POOH with BHA#1 with fish. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/18/14-Thursday Air saw all tbg fish from overshot. L/dn jars bumper sub and over shot.Chg handling equipment t/2-7/8"w/loss rate 3 bph static. POOH, l/dn tbg fish w/complete recovery t/#3 cut. ETOF @+/-5,354'(last 6 jts above XA sleeve showed signs of scale/sanded in on OD.XA sleeve was physically open but scaled up. No norm above back ground detected.Clear and clean rig floor. R/dn power tongs&prep for BHA. 20"x 16" =10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9-5/8"=200 psi, 9-5/8"X 2-7/8"=0 psi. KCL to well=708 bbls.Sized Salt to well=82 bbls. P/up BHA#2=8 1/8"overshot w/cut lip guide w/hollow mill, loaded w/2-7/8"grapple no pack off,double pin sub, bit sub, BS/OJ,XO,9 ea 6 1/2" DC's,XO,Acc Jars=320.78'. P/up rabbit and strap 5"S-135 19.5#dp f/2,593't/5,092'. Kelly up, brk circ @ 5,092.'Circ btm/up @ 8 BPM/500 psi with high gas of 460 units and balance well. Loss rate 5 BPH. Brk dn overshot remove cut off fish and grapple and redress over shot. Service rig. RIH w/BHA#2 w/dp out of derrick t/2,593'and monitor static well @ 4 bph loss rate.Obtain parameters: 175 K up, 130 K down, 142 rt at 7K torque. Wash down f/5,092'to 5,330'.Tagged hard fill with 15 set down and not able to wash down. Double checked pipe count and tally.Okay.Wash/ream down from 5,330'and engage fish at 5,362'. Pull up to 210K and move fish up hole 10'while pumping at 7 BPM/400 psi. Unable to move downhole without packing off. Pull and lay down single joint to 5,283'. Circulate bottoms up at 8 BPM/300 psi with max gas of 465 units.Circulate STS volume at 7 BPM/300 psi with max gas of 520 units tapering off to 80 units.Attempted to work pipe down hole during circulation but not able to due to packing off. 11 BPH loss rate. POOH slowly due to over pulls(30K)and swabbing. Pump out from 5,283' to 4,500'at 4 BPM.Able to pull without pumping from 4,500'to BHA.Work BHA#2 and lay down fish. Recovered 4.6' piece of parted 2 7/8"tubing. 12/19/14-Friday Make up BHA#3. RR BHA#2(Redress Overshot w/new grapple). RIH 92'set dn, p/up while bleeding jars. Fish popped free and worked fish uphole t/58'. Unable to pass 58'.After using various techniques had free travel dn but still unable to pass 58'(appears to be a csg collar). Finally was able to hold prk still w/pump pressure and get enough dn weight to cock jars and stage jar licks t/100k and pass 58'pull fish to rig floor. L/dn fish and inspect same. Recovered tubulars to cut#2. Packer was missing one complete top slip segment(+/-1"thick x 3-1/2" long x 3-1/4"wide)and body of prk missing piece and retains slip body(+/-3/4"x 3-1/4") leading edge of top element was wore. Inspect TDS torque tube and support braces. P/up(3) 6-1/2"dc's std back in derrick while waiting on slickline.Service rig monitor static loss @ 3-4 bph while waiting on slickline hands&tools.Cut and slip drlg line.Change dies on top drive pipe handler. P/up BHA#4. RR of BHA#2. RIH slow to 5,408'. 3 BPH loss rate. R/up slick line. RIH W/4.53" magnet w/5"centralizer t/2,000'(no set dn) POOH. No recovery. RR same t/5,362'(no set dn) POOH no recovery. RR same t/tag top of cut @ 5,425' POOH. No recovery. RIH w/ 8.5"gauge ring junk bsk t/200'w/no set dn. POOH. R/dn slickline.Circulate STS at 8 BPM/300 psi with high gas of 580 units tapering off to 55 units. Establish parameters: Up/Dn/Rot=176 K/130 K/147 K at 7 K torque. Engage fish at 5,428' while pumping at 4 BPM/100 psi. Pick up to 195K and fish came free. Pull up to free travel+/-15'and gained 4K over original pick up weight to 180K. 20"x 16"=10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9-5/8"=0 psi. KCL to well=838 bbls. Sized Salt to well=82 bbls.Circulate STS+at 8 BPM/500 psi with high gas of 640 units tapering off to 20 units. Minimal amount of sand at bottoms up. Blow down lines. POOH with BHA#4 slowly. 3 BPH loss rate. r tiHilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/20/14-Saturday Continue POOH slow with BHA#4.Air saw all tbg free of overshot. L/dn jars and overshot.Chg handle equipment t/2- 7/8". POOH I/dn tbg fish w/complete recovery t/#1 cut ETOF @+/-5,906'(last 3 jts above XA sleeve had very light 1/16" Scale on OD,XA sleeve was physically open but starting to scale up.Cut was split from fishing operations. No norm above back ground detected.Service rig and chg/out toggle on dwks for crown-o-matic. 20"x 16"=10 psi, 16"X 13-3/8" =60 psi, 13-3/8"x 9-5/8"=0 psi. KCL to well=953 bbls.Sized Salt to well=82 bbls. M/up BHA#5. RR#3= 8-1/8"overshot w/cut lip guide w/hollow mill, loaded w/2-7/8"grapple w/pack off,double pin sub, bit sub, BS/OJ,XO,9 ea 6 1/2" DC's,XO,Acc Jars=320.78'. RIH w/BHA#5 on 5"dp out of derrick t/5,435'.Circ and balance well @ 8 bpm @ 500 psi w/high gas of 540 units. Close annular divert returns thru wide open choke W/gas units do stream of gas buster 340 units,finish circ w/gas units declining. Down pump.Chk flow.Open annular monitor,ok, 12 BPH loss while circ. Establish parameters: Up/Dn/Rot =195 K/135 K/160 K at 7 K torque. Engage fish at 5,911'while pumping at 8 BPM/300 psi.Chase fish down hole to 5,964' after setting down 10K. P/U to 225K and weight fell off to 200 K. Pull up hole+/-50'with no over pulls.Chase fish down hole to 6,255'picking up drill pipe with no set downs. Loss rate 4 BPH.Circulate through gas buster with wide open choke at 8 BPM/500 psi with high gas of 375 units tapering off to 120 units. 15 BPH loss rate while circulating. POOH 5 stands. P/up rabbit and strap 16 jts of 5"S-135 19.5#drill pipe and RIH out of derrick washing at 8 bpm @ 500 psi to 5,895'. Circulate through gas buster with wide open choke at 8 BPM/450 psi with high gas of 595 units tapering off to 120 units. 12 BPH loss rate while circulating.Chase fish down hole from 6,255'to 6,625'.Set down 15K. Pick back up to 6,605'. (This puts bottom of fish at+/-6,665'). P/U 220 K,S/O 140 K after picking up drill pipe.Circulate through gas buster with wide open choke at 8 BPM/550 psi with high gas of 380 units tapering off to 0 units. 15 BPH loss rate while circulating. Recovered 3 bbls of sand during circulations. Blow down top drive and lines.Static loss rate 3 BPH. POOH slowly with BHA#5. 3 BPH loss rate. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/21/14-Sunday Work BHA#5. Break down and inspect hollow mill, pack-off and grapple and find 1.85" piece of split&rolled up 2-7/8"tbg (in grapple). M/up BHA#6=8-1/8"over shot w/upper ext.&hollow mill container w/cut lip guide loaded w/2-7/8" grapple&pack-off+bumper sub+oil jar+XO+(9)6-1/2" DC'S+XO+Acc jar=317.40'. RIH w/BHA#6 w/5" DP out of derrick and change break on same t/6,353'. Kelly up,circ and balance well @ 8 bpm @ 500 psi w/high gas of 635 units. Close annular,divert returns thru wide open choke w/gas units dn stream of gas buster 340 units,finish circ w/gas units declining. Down pump.Chk flow.Open annular monitor,ok, 10 BPH loss while circ.Service rig.Cut and slip drlg line(150'). Continue circulating at 8 BPM/325 psi until gas down to 20 units. Monitor static loss @ 3-4 BPH. RIH. Establish parameters: Up/Dn/Rt 222K, 142 K, 179 K at 8 K torque.4 BPM/450 psi. Engage fish at 6,625'.Slide over fish to 6,637'&set down 15K. Jar fish at 100K over. P/U weight and free with 16 jar licks. Unable to pull fish uphole without pumping. Pump out at 4 BPM/100 psi from 6,639'to 5,920'.Gas increased to 250 units.20"x 16"=10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9-5/8" = 0 psi. KCL to well= 1028 bbls.Sized Salt to well=82 bbls.Circulate gas out at 8 BPM/350 psi. High gas of 758 units. Recovered .5 bbls of sand during circulation. Loss rate 4 BPH. Pump out at 4 BPM/100 psi from 5,920'to 5,580'. POOH slowly without pumping from 5,580'to BHA without pumping. No over pulls on trip out.4 BPH loss rate.Work BHA#6. Break and lay down fish. Full recovery of fish. M/U BHA#7: Junk mill,3 ea boot baskets,9 5/8"casing scraper, bit sub, string magnet, BS/OJ,XO,9 ea 6 1/2" DC's,XO,Acc Jars=343.12'. 2 BPH loss rate. RIH with BHA#7. 12/22/14-Monday Service rig. RIH w/BHA#7 w/5" DP out of derrick t/6,474'. Kelly up,circ and balance well @ 8 bpm @ 500 psi w/high gas of 520 units.Close annular,divert returns thru wide open choke w/gas units dn stream of gas buster 295 units,finish circ w/gas units declining. Down pump.Chk flow.Open annular monitor,ok, 10 BPH loss while circ.Wash in hole @ 8 bpm F/ 6,474'to tag @ 6,660'. Up pump rate t/14.5 bpm @ 1300 psi wash f/6,660't/PBTD @ 6,685'w/10k.Continue circ clean two complete rounds w/1-1.5 bbls sand back in returns w/high gas of 470 units. Monitor static well @ 3 BPH&skim oil off trip tank&pits. POOH, I/dn 5" DP w/loss rate @ 3-4 BPH.Stand back 5 stands of DP and DC's. Lay down remainder of BHA. Recovered 54 lbs off string magnet and 86 lbs out of boot baskets.20"x 16"=10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9- 5/8"=0 psi. KCL to well=1114 bbls.Sized Salt to well=82 bbls. M/U RTTS and RIH.Set same at 455'.Test annulus at 1550 psi for 15 minutes. Good test.9 5/8"x 13 3/8"annulus remained at 0 psi throughout test. Release RTTS. POOH and lay down DP, RTTS and DC's. 3 BPH loss rate. R/U Weatherford. RIH picking up 2 7/8"tubing.3 BPH loss rate. 12/23/14-Tuesday RIH picking up RR 2 7/8"6.5#8rd EUE tubing.Swap handling equipment t/3-1/2" P/up rabbit and strap(9)jts 3-1/2" 9.3# L-80 tbg t/5,644'. Kelly up,circ and balance well @ 6 bpm @ 1300 psi w/high gas of 667 units,close annular,divert returns thru wide open choke w/gas units dn stream of gas buster 325 units finish circ w/gas units declining. Down pump. Chk flow.Open annular monitor.Okay. 10-12 BPH loss while circ.Circulate @ 8 bpm @ 1820 psi w/loss rate 3-4 BPH. Monitor static well @ 1.5 BPH. POOH standing back tubing. 20"x 16"=10 psi, 16"X 13-3/8"=60 psi, 13-3/8"x 9-5/8"=0 psi. KCL to well=1188 bbls.Sized Salt to well=82 bbls. M/U test joint.Test BOPE at 250L/2500H as per AOGCC sundry regulations.Witness of test waived by Lou Grimaldu,AOGCC.3 BPH loss rate. Rig down test equipment. Lay down test joint.Clear floor. Pull wear ring and M/U'Johnny Whacker'. Flush stack and tubing spool profile. Pulled BPV back out. Rig up equipment to run ESP. Hang sheaves,etc. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 10/15/14 12/25/14 Daily Operations: 12/24/14-Wednesday Pick up/make up ESP assembly. PU motor,Chem injection mandrel w/anode,and press sensor. Fill motor with oil. PU 2 ESP sections and 1st pump. Connect chem inj line and press sensor line to mandrels. Purge lines and test. PU and install 3 clamps on the motor.Connect cable to motor and test same. PU 2 pumps installing clamps. PU ported press sub,discharge, XO, and 1 jt 27/8 tbg. {Set TWC in A-12 and tested tree to 3,000 psi w/production test pump. Good test)Plan is to meg test ESP cable every 1,000'. RIH w/ESP on 2 7/8 EUE out of derrick to 967'installing cannon clamps on 1st 7 jts and every other jt after that. Run meg test on ESP cable. Good meg test. RIH w/ESP on 2 7/8 EUE out of derrick. Meg check every 1000'.3 BPH fluid loss. 20"x 16" = 10 psi, 16"X 13-3/8" =60 psi, 13-3/8"x 9-5/8"=0 psi. KCL to well = 1256 bbls.Sized Salt to well =82 bbls. P/U M/U Hydroset D&L packer. Make splice. Meg check okay. P/U M/U SSSV.Test line at 5000 psi.Good. RIH with 3 1/2"tubing out of derrick installing clamps every other joint. M/U tubing hanger. 12/25/14-Thursday Finish making up tbg hanger.Tie in control lines for bleed line,SSSV, and splice cable. Meg test cable. Break pup out of hanger and MU landing jt w/bar dropping assembly. MU chem injection control lines through hanger and pump through them to ensure they were open. Plug in umbilical cord and meg test.Tested good after we dried it out. Land hanger. [40k on hanger]. Check to make sure hanger was landed and run in LDS. Drop bar. Pressure up dn tbg to 2000 psi to set packer and hold pressure for 15 min. Seen packer shift at 800 psi. Bleed tbg off and pressure up ann to 1500 psi for 30 min on a chart.Good test. Bleed pressure off. Pull landing jt and set BPV. Nipple dn BOPs. PU stack and move to the side. Pull riser. Nipple up tree.Test void at 250 L/5000 high. Install man-u-matic and flow lines.Torque all bolts. 20"x 16" = 10 psi, 16"X 13-3/8" =60 psi, 13-3/8"x 9-5/8" =0 psi. KCL to well= 1301 bbls.Sized Salt to well =82 bbls.Turn well over to production. -T&� A -3-Z PM 1-7-701130 Regg, James B (DOA) From: Marvin Rogers - (C) <mrogers@hilcorp.com> Sent: Wednesday, December 24, 2014 8:30 AM To: Regg, James B (DOA); Grimaldi, Louis R (DOA) Cc: Brooks, Phoebe L (DOA); Juanita Lovett; Rick Brumley - (C); Shane Hauck Subject: Monopod A-32 BOP Test Attachments: Test Chart 12-24-14.pdf; BOP Test Sequence 12-24-14 .xIs; BOP Kuukpik 56 12-24-14.xlsx Jim Regg Here is our BOP test report for A-32. On test #4 we had to re -test the high due to a 1502 hammer union on the pump out sub leaking. It was tightened and re -tested on #5. We didn't count it as a failure because it was on the test equip. Thank You III-filcorp Alaska, LLC r✓iG7r iG�i, ���e�s DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, December 23, 2014 12:41 PM To: Shane Hauck; Grimaldi, Louis R (DOA) Cc: Marvin Rogers - (C); Rick Brumley - (C); Truman Knutson - (C); Ted Kramer; Trudi Hallett; Dan Marlowe; Daniel Taylor; Paul Mazzolini; Luke Keller; Shane Chaffee; Ian Hanna - (C); Chris Russell - (C); Shane Chaffee Subject: RE: AOGCC Test Witness Notification Request: BOPE, 56 monopod A-32 Send your test charts with test report when finished. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 SCANNED DEC 3 12014; 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 Jim Regg at 907- 793-1236 or iim.re�R@alaska.ov. From: Shane Hauck [mailto:shauck(cWlcorp.com] Sent: Tuesday, December 23, 2014 12:30 PM To: Grimaldi, Louis R (DOA) 1 Operation: Drilling: Workover: X - Explor.: Test: Initial: Weekly: X Bi -Weekly: Test Pressure (psi): Rams: 250/2500 Annular: 250/2500 Valves: 250/2500 - MASP: 430 psi MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: STATE OF ALASKA Size/Type Test Result OIL AND GAS CONSERVATION COMMISSION Quantity Test Result BOPE Test Report P Well Sign Submit to: jim.regg(a)alaska.gov Upper Kelly 1 AOGCC.Inspectors(a)alaska.gov Housekeeping P Phoebe. brooks(a)alaska. gov P Contractor: Kuukpik Rig No.: 56 DATE: 12/24/14 Rig Rep.: Knutson/Borgen Rig Phone: 776-6675 Hazard Sec. Operator: Hilcorp Alaska Op. Phone: 776-6675 1 Rep.: Rogers/Brumley E -Mail shauck(a)hilcorp.com P Well Name: TBU A-32 PTD # 1770180 _ Sundry # 314-547 Operation: Drilling: Workover: X - Explor.: Test: Initial: Weekly: X Bi -Weekly: Test Pressure (psi): Rams: 250/2500 Annular: 250/2500 Valves: 250/2500 - MASP: 430 psi MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: BOP STACK: Test Result Size/Type Test Result MUD SYSTEM: Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 NT . Housekeeping P Rig P Lower Kelly 1 NT PTD On Location P Hazard Sec. P Ball Type 1 P nding Order Posted P Misc. NA Inside BOP 1 P #3 Rams 1 2 7/8 x 5 VBR P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 3/8" 5M P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 VBR P Flow Indicator P P #2 Rams 1 13 3/8" Blind P Meth Gas Detector P P #3 Rams 1 2 7/8 x 5 VBR P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" 5M P Inside Reel valves 0 NA HCR Valves 2 1/16 x 3 1/8" P Kill Line Valves 1 2 1/16" 5M 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) 1150 P Quantity Test Result 200 psi Attained (sec) 37 P No. Valves 14 - P Full Pressure Attained (sec) 209 P Manual Chokes 1 - P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 - P Nitgn. Bottles Avg. (# and psi): 6 @ 2320 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 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Had leaking hammer union on side entry sub. Tighten and retest okay. Tested with 2 7/8". Tested H2S and methane gas sensors with no failures. AOGCC Inspection 24 hr Notice Yes Date/Time 12/21/2014 9:15 Waived By Lou Grimaldi ' Test Start Date/Time: 12/23/2014 22:00:00 PM (date) (time) Witness Test Finish Date/Time: 12/24/2014 2:30 Form 10-424 (Revised 06/2014) BOP Kuukpik 56 12-24-14.xlsx 9-t A-3 Z_ Pti) 177cj`Pc HILCORP H BOP TEST SHEET DATE: 24 -Dec -14 RIG CONTRACTOR: Kuukpik RIG # 56 TIME: WELL NAME: A-32 TYPE OF OPERATION - (DRILLING / WORKOVER / OTHER): WORKOVER HILCORP REP: ROGERS/Brumley RIG SUPERVISOR: KNUTSON/BORGEN SUPERINTENDENT: TESTING COMPANY: FREEMAN/HOWELL DP SIZES: 2 7/8" BOP SIZE & RATING: Test # Components Tested Minutes Held (Low/High) Low PSI High PSI Pass/ Fail 1 UPPER PIPE RAMS, 3 1/2" IF TIW VALVE, DEMCO KILL LINE VALVE, CMV 3/5/15/16. 5/5min 250 2500 PASS 2 UPPER PIPE RAMS, 3 1/2" TIW VALVE, HCR KILL, CMV 3/5/8/0/12/13/14. 5/5min 250 2500 PASS 3 UPPER PIPE RAMS, 3 1/2" TIW VALVE, MANUAL KILL VALVE, CMV 1/7/10/11. 5/5min 250 2500 PASS 4 UPPER PIPE RAMS, 3 1/2" TIW VALVE, MANUAL KILL VALVE, CMV 2/4/6 5/5min 250 2500 H2 mmer union leaked 5 UPPER RAMS, 3 1/2" IF TIW VALVE,MANUAL KILL VALVE, CMV: 2/4/6. 5/5min 2500 PASS 6 UPPER RAMS, 3112 IF TIW VALVE, CHOKE HCR. 5/5min 250 1 2500 PASS 7 UPPER RAMS, 31/2 IF TIW VALVE, MAN 5/5 min 250 2500 PASS 8 135/8 ANNULAR, 31/2 TIW VALVE. 5/5 min 250 2500 PASS 9 LOWER PIPE RAMS, 31/2 TIW VALVE. 5/5 min 250 2500 PASS 10 UPPER RAMS, 27/8 TIW VALVE. 5/5 min 250 2500 PASS 11 BLIND RAMS. 5/5min 250 2500 PASS 16 Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 3000 1475 1400 Shaffer 13 5/8" Final Pressure -I- 1150 1150 1150 Re -charge Time 37 Seconds/ 200 psi; 209 Seconds full Average N2 bottles- 2315 psi. charge �7 Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. j HILCORP BOP TEST NOTES Test # - Comments (Passed/failed components, re -test, etc.) TEST #4: LOW PRESSURE PASS. HIGH PRESSURE FAILED DUE TO 1505 HAMMER UNION LEAK ON TEST EQUIPMENT. V -i-1- Mt THE STATE Aflacka Oil and Gas OIAL=�i�o,.L�,-i GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 l=ax: 907.276.7542 Re: Trading Bay Field, Middle Kenai B, C, D, and E Oil, Hemlock Oil, W. Foreland Oil, and Undefined Oil Pools, Trading Bay ST A-32 Sundry Number: 314-547 Dear Mr. Marlowe: 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. DATED this L day of October, 2014. Encl. Sincerely, ACathyFoerster Chair gCMNED OCT 16, 201 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CJ �No ,111-c APPLICATION FOR SUNDRY APPROVALS 20 AAC 25-280 RECEIVED OCT 0 7 2914 0Gy010 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing [D - Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install ESP - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 177-018 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20301-00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NIA Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay ST A-32 " 9. Property Designation (Lease Number): 10. Field/Pool(s): W'S77;570-'77-7— -( I Trading Bay / Middle Kenai C & Hemlock Oil Pools, W,(�/N. /GElw 3'b' E t;j ADL0018731 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6,750' - 6,305' 6,683' - 6,242' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: -----7Tubing MD (ft): 2,094'- 6,652' 2,058' - 6,218' 2-7/8" 6.5# / L-80 5,953' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): DLH Hyd Packer (3) & TE -5 SSSV 2,042' (MD) 2.008' (TVD) / 5,376' (MD) 5,078' (TVD) / 5,930' (MD) 5,576' (TVD) & 305' (MD) 305' (TVD) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q. Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2014 Oil Gas ❑ WINJ ❑ GINJ E]WAG WDSPL ❑ Suspended ❑ 17Abandoned 171Commission 16. Verbal Approval: Date: Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Title Operations Engineer rf�• lfrL.b"r� Si natur Phone 907 283-1329 Date 10/7/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other:-iFZSao HYDl rsi Spacing Exception Required? Yes ❑ No Subsequent Form Required: / d - ( U`� c APPROVED BY Approved by: COMMISSIONER THE COMMISSION / Date:[ U_ /0 Form 10-403 (Revised 10/2012) A01R aGIMAL 12 months from the date of approval. Submit Form and Attachments in Duplicate FI$CMS OCT 13 4 Hilcorp Alaska, LU Well Prognosis Well: A-32 Date:10/07/2014 Well Name: Monopod A-32 API Number: 50-733-20301-00 Current Status: Oil producer (Gas Lifted) Leg: N/A Estimated Start Date: 10/15/14 Rig: Monopod Rig #56 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 177-018 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: --1,847 psi @ 4,273' TVD 0.432 psi/ft based on 2013 pressure data Maximum Expected BHP: -1,847 psi @ 4,273' TVD no new perfs Max. Anticipated Surface Pressure: -430 psi Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary The A-32 well is currently completed as a gas lifted oil well. The re -completion plan involves pulling the existing completion and running an ESP to optimize production: The casing was tested to 2,300 psig at 2,080' on 10/21/2013 and charted for 30 minutes. Procedure 1. MIRU Monopod Platform Rig # 56. 2. Set Back pressure valve, ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. PU E -line and punch tubing above packer at 2,042'. Circulate hydrocarbons from well 4. Unseat Hanger and pick up on tubing. Packers are straight pull release. Attempt to pull together but make cuts above packers as needed to recover completion string. S. POOH laying down production tubing. 6. PU Clean out Assembly, RIH cleaning out to +/- 6,700'. 7. PU and run ESP completion. 8. Set packer and test annulus to 1,500 psig. 9. ND BOPS, NU Wellhead and test. 10. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead SCHEMATIC Trading Bay Unit Monopod Platform Well # A-32 API # 50-733-20301-00 Completed: 10/29/13 CASING AND TUBING DETAIL 221 PB' MAX HOLE ANGLE = 300 @ 4600' RKB to TBG Head = 37.90' Tree connection: SIZE WT GRADE CONN ID TOP BTM. 20" 94 2,120' Driven 19.12' Surf 221' 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 9-5/8" 47 N-80 BTC -KC 8.681" Surf 6724' DLH Hyd Set Packer 7 5,882' 2.312 Baker Model "CMD" Sliding Sleeve w/ BX profile 8 5,930' Tubing: DLH Hyd Set Packer 9 5,948' 2.313 X Nipple 10 2-7/8" 6.5# L-80 8rd EUE 2.441 Surf 5,953' CZN 4,840' 4,860' 4,597' 4,615' 20 Open JEWELRY DETAIL NO. Depth ID Item Btm (TVD) 37.90 6.184 10" TBG Hanger 2,094' 2,120' 2,058' 2,082' 1 305' 2.312 SSSV TE -5 w/ 2.312 "BX" Profile 2 1,974' 2,625' GLM 3 2,024' 2.441 Chemical Injection Mandrel 4 2,042' 4.000 DLH Hyd Set Packer 5 5,329' 2.312 Baker Model "CMD" Sliding Sleeve w/ BX Profile 6 5,376' 4.000 DLH Hyd Set Packer 7 5,882' 2.312 Baker Model "CMD" Sliding Sleeve w/ BX profile 8 5,930' 4.000 DLH Hyd Set Packer 9 5,948' 2.313 X Nipple 10 5,953' 2.500 WLEG Perforation Details Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open BZN 2,478' 2,690' 2,422' 2,625' 212 Open BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated CZN 5,092' 5,110' 4,823' 4,839' 18 Open CZN 5,116' 5,142' 4,844' 4,867' 26 Open C 1 5,120' 5,140' 4,848 1 4,866 20 Squeezed with 100 sxs CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open DZN 5,520' 5,560' 5,208' 5,244' 130 Open D 1 5,530' 5,560' 5,217 1 5,244 30 Isolated DZN 5,576' 5,610' 5,259' 5,289' 34 Open D 5,590' 5,606' 5,271 5,286 16 Isolated D 51630' 5,662' 5,308 5,336 32 Isolated DZN 5,638' 5,674' 5,315' 5,347' 36 Open DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open D 5,765' 5,815' 5,429 1 5,473 50 Squeezed with 600 sxs DZN 1 5,850' 5,918' 5,505' 5,566' 68 Open D 5,852' 5,912' 5,507 5,560 60 Isolated EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN 6,004' 6,026' 5,642' 5,662' 22 Open EZN 6,032' 6,089' 5,667' 5,718' 57 Open D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 51758' 5,772' 16 Open HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 1 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 38 1 Open Updated by: JILL 11/07/13 PROPOSED Trading Bay Unit Monopod Platform Well # A-32 API # 50-733-20301-00 Completed: FUTURE CASING AND TUBING DETAIL RKB to TBG Head = 37.90' Tree connection: 221' 502' 4451' B Zone C Zone D Zone E Zone Hemlock PBTD = 6683' (WLM) TD = 6750' MAX HOLE ANGLE = 300 @ 4600' SIZE WT GRADE CONN ID TOP BTM. 20" 94 1 Driven 19.12" Surf 221' 16" 65 H-40 BTC 15.25" Surf 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) Surf 4451' 9-5/8" 47 N-80 BTC -KC 8.681" Surf 6724' CZN 1 4,591' 4,690' 4,378' 4,464' 99 Open Tubing: 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 2-7/8" 6.5# L-80 8rd EUE 2.441 Surf 5,953' CZN 4,840' 4,860' 4,597' 4,615' 20 Open JEWELRY DETAIL NO. Depth ID Item Top (TVD) 37.90 6.184 10" TBG Hanger Condition KBZN 2,094' 1 ±305' SSSv 2 ±325' Packer 3 ±340' X -Nipple 4 ±355' GLM 5 ±5,900' Bottom of ESP w/ Shroud Perforation Details Updated by: JUL 10/07/14 Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amount Condition KBZN 2,094' 2,120' 2,058' 2,082' 26 Open 2,478' 2,690' 2,422' 2,625' 212 Open 3,494' 3,586' 3,377' 3,462' 92 Open 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 1 4,591' 4,690' 4,378' 4,464' 99 Open 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open CZN 4,840' 4,860' 4,597' 4,615' 20 Open CZN 4,960' 4,970' 4,705' 4,714' 10 Open C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated CZN 1 5,092' 5,110' 4,823' 4,839' 18 Open CZN 5,116' 5,142' 4,844' 4,867' 26 Open C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 1 5,425' 5,455' 5,122 1 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open DZN 5,520' 5,560' 5,208' 5,244' 130 Open D 5,530' 5,560' 5,217 5,244 30 Isolated DZN 5,576' 5,610' 5,259' 5,289' 34 Open D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated DZN 5,638' 5,674' 5,315' 5,347' 36 Open DZN 5,694' 5,722' 5,365' 5,390' 28 Open DZN 5,758' 5,824' 5,422' 5,481' 66 Open D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs DZN 5,850' 5,918' 5,505' 5,566' 68 Open D 5,852' 5,912' 5,507 5,560 60 Isolated EZN 5,947' 5,987' 5,592' 5,627' 40 Open EZN 6,004' 6,026' 5,642' 5,662' 22 1 Open EZN 6,032' 6,089' 5,667' 5,718' 57 Open D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN 6,134' 6,150' 5,758' 5,772' 16 Open HEM 6,250' 6,430' 5,860' 6,020' 180 Open Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF 6,614' 6,652' 6,184' 6,218' 1 38 Open Updated by: JUL 10/07/14 I ilrnrp Ala.ka. 1.1.0 Monopod Platform A-32 20 X 16X 13 3/8 X 9 5/8 X 27/8 Valve, Swab, WK 31/85M FE, HWO, Valve, Master, WKM• 31/8 5M FE, HWO, DD Control Tubing head, S-8, 13 5/8 3M x 115M, w/ 2- 2 1/16 5M SSO, w/ BG bottom w/ 1- 21/16 5M WKM-M valves Casing spool, OCT -291., 21 Y. 2M X 13 5/8 3M, w/ 2- 2 1/16 SM SSO, 13 3/8- 00 bottom C-22 slips installed Starting head, OCT Type II, 21 % 2M X 20" SOW, w/ 4- 2 1/16 2M SSO 16" casing hung off on mandrel 13 3/8" casing on C-29 slips Monopod Platform A-32 Current 10/28/2013 Tubing hanger, SME -CL, 11 X 3 Y EUE lift and susp, w/ 3" Type H BPV profile, 3- 3/8 CCL, Alloy material BHTA, Bowen, 31/8 5M X 2.5 Bowen quick union WKM-M, i/ 15" OMNI DD trim ITUrnrp Ahtrka. MA: Monopod Platform A-32 20X 16 X 133/8 X 95/8X 27/8 BHTA, Bowen, 3 1/8 SM X 2.5 Bowen quick union Valve, Swab, WKM-M, 31/85 FE, H WO, DD trim Valve, Wing, WKM-M, 2 1/16 SM FE, HWO, DD trim Valve, Master, WKM-M, 3 1/8 5M FE, HWO, DD trim Tubing head, S-8, 13 5/8 3M x 115M, w/ 2- 2 1/16 SM 550, w/ BG bottom w/ 1- 2 1/16 SM WKM-M valves Casing spool, OCT -291., 21 X 2M X 13 5/8 3M, w/ 2- 2 1/16 SM SSO, 13 3/8- 00 bottom C-22 slips installed Starting head, OCT Type Ii, 21 %2MX20"SOW, w/ 4- 2 1/16 2M SSO 16" casing hung off on mandrel 13 3/8" casing on C-29 slips Monopod Platform A-32 Proposed ESP 10/07/2014 Tubing hanger, Seaboard - ESP -EN, 11 X 2 7/8 EUE lift and Susp w/2 1/2" Type H BPV profile, 2- h CCL, Prepped for BIW penetrator Valve, Wing, WKM-M, 3 1/8 SM FE, w/ 15" OMNI operator, DD trim Adapter, Seaboard -ESP, 115M rotating flange x 2 9/16 SM rotating flange, w/ 4 5/8 pocket, w/ 2- X CCL, ported for BIW penetrator Monopod Platform 2014 BOP Stack (Workover) 10/07/2014 RECEIVED STATE OF ALASKA ` ALA_ ..OIL AND GAS CONSERVATION COMM-ION NOV 2 7 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well El Plug Perforations ❑ Perforate 0 . Other El Run Completion Performed: Alter Casing ❑ Pull Tubing l] • Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0• Exploratory El 177-018 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20301-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018731 ' Trading Bay St A-32 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): . Trading Bay/Middle Kenai C,Hemlock&West Foreland• 11.Present Well Condition Summary: Total Depth measured 6,750 feet Plugs measured N/A feet true vertical 6,305 feet Junk measured N/A feet Effective Depth measured 6,683 feet Packer measured 2,042,5,376,5,930 feet true vertical 6,245 feet true vertical 2,008,5,078,5,576 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED (`P G 4 e�L D 14 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 2 5,953'(MD) 5,597'(TVD) DLH Hyd Pkr 2,042'(MD)2,008'(ND) Packers and SSSV(type,measured and true vertical depth) DLH Hyd Pkr 5,376'(MD)5,078'(ND) TE-5 SSSV 305'(MD)305'(ND) DLH Hyd Pkr 5,930'(MD)5,576'(ND) 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: 10 180 82 336 •148 Subsequent to operation: 385 554 0 344 120 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development[ • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑., • Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-434 Contact Ted Kramer Email tkramer@hilcoro.com Printed Name Ted KramerTitle Sr.Operations Engineer Signature da‘ ' /fJ Phone (907)777-8420 Date 11/27/2013 H•ZZ .14 R!MS DEC 13 2* Form 10-404 Revised 10/2012 . ,/�f Submit Original Only 6 SCHEMATIC Trading Bay Unit Monopod Platform Well #A-32 API # 50-733-20301-00 Completed: 10/29/13 CASING AND TUBING DETAIL RKB to TBG Head=37.90' SIZE WT GRADE CONN ID TOP BTM. Tree connection: 20" 94 Driven 19.12" 42' 221' 16" 65 H-40 BTC 15.25" 39' 502' 1 13-3/8" 61/68 K-55 BTC , 12.415"(Min) 39' 4451' 9-5/8" 47 N-80 BTC-KC 8.681" 39' 6724' Tubing: 221' 2-7/8" 6.58 L-80 8rd EUE 2.441 37.9' 5,953' JEWELRY DETAIL NO. Depth ID Item 502'L , ; b 2 37.90 6.184 10"TBG Hanger I13 ill , µ0, 1 305' SSSV TE-5 w/2.312"BX"Profile �pu>17/ 2 1,974' GLM =MI4 3 2,024' Chemical Injection Mandrel 4 2,042' DLH Hyd Set Packer 5 5,329' Baker Model"CMD"Sliding Sleeve 6 5,376' DLH Hyd Set Packer B Zone 7 5,882' Baker Model"CMD"Sliding Sleeve 8 5,930' DLH Hyd Set Packer 4451'L , 9 5,948' X Nipple 10 5,953' WLEG = Perforation Details =- C Zone Top _= Zone Top(MD) Btm(MD) (ND) Btm(TVD) Amount Condition BZN 2,094' 2,120' 2,058' 2,082' 26 Open = BZN 2,478' 2,690' 2,422' 2,625' 212 Open = BZN 3,494' 3,586' 3,377' 3,462' 92 Open C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN 4,591' 4,690' 4,378' 4,464' 99 Open 000 5 = 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN 4,812' 4,830' 4,227' 4,589' 18 Open _-6 CZN 4,840' 4,860' 4,597' 4,615' 20 Open = CZN 4,960' 4,970' 4,705' 4,714' 10 Open = C 5,027' 5,029' 4,764 4,766 2 Block Squeeze = C 5,041' 5,043' 4,777 4,779 2 Isolated CZN 5,092' 5,110' 4,823' 4,839' 18 Open D Zone CZN 5,116' 5,142' 4,844' 4,867' 26 Open C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs CZN 5,186' 5,216' 4,907' 4,934' 30 Open CZN 5,250' 5,260' 4,965' 4,974' 10 Open C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN 5,292' 5,348' 5,003' 5,053' 56 Open D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN 5,430' 5,460' 5,127' 5,154' 30 Open = DZN 5,520' 5,560' 5,208' 5,244' 130 Open -- D 5,530' 5,560' 5,217 5,244 30 Isolated = DZN 5,576' 5,610' 5,259' 5,289' 34 Open - D 5,590' 5,606' 5,271 5,286 16 Isolated 000 = D 5,630' 5,662' 5,308 5,336 32 Isolated 7 DZN 5,638' 5,674' 5,315' 5,347' 36 Open MEM 8 DZN 5,694' 5,722' 5,365' 5,390' 28 Open Q4-. 9 DZN 5,758' 5,824' 5,422' 5,481' 66 Open 10 D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs DZN 5,850' 5,918' 5,505' 5,566' 68 Open __ E Zone D 5,852' 5,912' 5,507 5,560 60 Isolated EZN 5,947' 5,987' 5,592' 5,627' 40 Open = EZN 6,004' 6,026' 5,642' 5,662' 22 Open Heniock EZN 6,032' 6,089' 5,667' 5,718' 57 Open D 6,050' 6,052 5,683 5,685 2 Block Squeze =Nest Foreland EZN 6,134' 6,150' 5,758' 5,772' 16 Open 4 HEM 6,250' 6,430' 5,860' 6,020' 180 Open PBTD=6683WLM) TD 6750' Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated MAX HOLE ANGLE=30° @ 4600' WF 6,614' 6,652' 6,184' 6,218' 38 Open Updated by: JLL 11/07/13 Hilcorp Alaska, LLC HiIt.orp.t�a ka.LL(. Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 pally Operations: 09/20/13-Friday Rigging up. 09/21/13-Saturday Rig up wireline,PT lubricator to 2000 psi._Rungauge ring to 4,479'.POOH.RIH w/W/B-0 shifting tool to sliding sleeve at 4,377'to shift sleeve.Good indication but pin was sheared on tool.Pressure up on ann to check for communication.Had good communication. Pump 3%KCL dn tbg taking returns to production.Pump 20 bbls before we seeing pressure on tbg,35 bbls and started getting oil returns.Turned to water and oil at 70 bbls.By 150 bbls it was mostly water.Pump 200 bbls and shut down with a final pressure of 185 psi on tbg and 80 psi on ann.Pressure bled to 0 psi on both sides in 5 min.Rig up to lay dn 4-3/4"DCs and 4"DP out of derrick.Lay dn the 6 DCs and 21 its of DP.[Monitor pressure on tbg and ann while laying dn DP,Both pressures=0 psi]. Pump dn tbg 7.3 bbls before we caught pressure. Pump another 7.5 bbls and started getting oil back. At a total of 25 bbls pumped started getting water back. Continued getting water and gas back and shut down at 70 bbls pumped.Pressure bled to 0 psi on both sides.[2 BPM 175 psi].Lay down 53 jts of 4"DP out of derrick.Pump dn tbg at 1 BPM 120 psi.Pump 3.8 bbls before catching pressure on tbg,and 10 bbls before we got oil back at ann.At 14 bbls started getting water back,shut dn at 15 bbls,Both ann and tbg bled to 0 in about 2 min.Lay down 40 jts of 4"DP out of derrick.Total jts 115 LD. Pump dn tbg at 1 BPM 135 psi,Pump 6 bbls before catching pressure on tbg. At 9 bbls we got water/gas back-at 10 bbls got oil back-at 14 bbls we started getting water back-min gas back-shut dn at 25 bbls. Both ann and tbg bled to 0 in about 1 min.Lay down 39 jts of 4"DP out of derrick.Total 153 jts LD.Pump dn tbg at 1 BPM 135 psi,Pump.5 bbls before catching pressure 45 psi on tbg,at 2.3 bbls we got oil back-at 3 bbls we started getting water back-min gas back-shut dn at 25 bbls.Both ann and tbg bled to 0 in about 1 min.Lay down 26 jts of 4"DP out of derrick.Total 179 jts LD. Crane loading 4"DP on boat. Lay down 42 jts of 4"DP out of derrick.Total 221 jts LD. Pump dn tbg at 1 BPM 135 psi.Pump 3.5 bbls before catching pressure on tbg and got a spurt of oil then to water no gas back shut dn at 25 bbls. Both ann and tbg bled to 0 in about 1 min.Lay down 16 jts of 4"DP out of derrick.Total 237 jts LD+3 jts on deck=total 240 jts. Pump dn tbg at 1 BPM 135 psi.Pump 3 bbls before catching pressure on tbg with gas/water then to water at 8.5 no gas back shut dn at 25 bbls. Both ann and tbg bled to 0 in about 1 min. Service rig.RD circ equip-set BPV. Blow down Kelly. Prep to ND tree and NU BOPE. Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls Daily Loss rate average-0 bph BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=0 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=0 lbs.Total metal recovered=0 lbs 09/22/13-Sunday Nipple dn tree.Pull tree out of well room.Set new tbg spool in well room.Prep hanger and tbg spool.Screw pup in top of hanger to check threads.Cut T off side of tree while in cellar so it can be pulled through the rotary.Set riser,Nipple up BOPs,Hook up lines, Turn buckles,Install drip pan and flow nipple.Function test BOPS. PU and rig up test equip.Test BOPs-annular-choke manifold- lines to 250 psi low and 2500 psi high as per AOGCC-HAK-Kuukpik procedures. No failures - Witness of test was waived by Jim Regg,AOGCC 9/22/13-0844 hrs.RD test equip-pull TWC- clear floor. Fill hole-12 bbls. MU 5"DP landing jt-TIW-head pin to pull hgr. Circ gas out of well 1 bpm-100 psi-25 bbls pumped. Back out LDS. Pull hgr free with 50k(w/blocks)-fill well 15 bbls.Cont. pull hgr.to floor. Circ/cond well-5 bpm-675 psi. Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 0 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-0 bph BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=0 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=0 lbs.Total metal recovered=0 lbs Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 09/23/13-Monday Break down hanger and landing jt.Lay dn 15'pup.PU just enough to get the tailpipe out of the packer.RU circ head on tbg.Circ at 6.3 BPM at 998 Psi.Starting gas units 425,Gas dn to 200 units.Lay dn circ head. Hole taking 10 BPH._P09H Laying do 2-7/8"tbg and coiling up SSSV control line.Lay dn SSSV.Cir/cond well-8 bpm-1300 psi-310 bbls pumped-350 gas units. LD 138 jts 2-7/8"tbg-5 glm- sliding sleeve-seal assy-landing nip-wleg. Clear/clean floor of tbg tools.Install wear ring-1/2 bph loss. PU/MU BHA#1 - 2-7/8" HES shifting tool-3-1/2"full circle spear-8-1/8"xo-6-1/4"oil jar-6-1/4"pump out sub-6-1/8"xo-9 ea 6-1/2"dc-6-3/16"xo-oal 297.55'. RIH with BHA#1,CBU-2 bpm 970 psi.Engaging packer at 4,390'.Fluid loss today 3%KCL 150 bbls.Total 3%KCL loss 150 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1/2 bph BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=0 lbs. Recovered 0 lbs from Boot Baskets. Boot Basket total=0 lbs.Total metal recovered=0 lbs 09/24/13-Tuesday Engage packer at 4,390'. Slide tool into packer 4'.Set dn 65k to shift packer sleeve and shear packer pins. PU and pull 50k over. Pkr didn't release.Slack back off and cock jars,Jar twice w/50k over,Twice with 55k over,Twice with 75k over.Packer released when we slacked back off.PU to 4,360'and monitor well.Hole taking 0 BPH.Blow Kelly dn and set it back. POOH slow keeping a close eye on the displacement.Stand back DCs and pull tools to surface.Didn't have the packer on.Check out retrieving tool and prep it to run again.When shifting spear by hand a segment fell off.Lay dn tool and PU spear.RIH with spear.PU Kelly and establish parameters. Engage pkr at 4,390', attempt to pull pkr free with a straight pull of 50k over,Jar on packer at 75k over and PU to 100k over,Packer wouldn't come free,Release spear,and monitor well.Hole not taking any fluid.POH and lay dn spear.PU packer milling Assem:8- 1/2"packer Mill w/4'extension,XO,Triple Connect Sub,3 Boot Baskets,Bit Sub,Bumper Sub,Oil Jars,Pump Out Sub,XO,9 DCs,XO= 322.21'.Service Rig.TIH from 416'to 4,363'.Lay down 1)single.PU Kelly.Break Circulation and establish parameters @: 6.5 BPM w/550 PSI, 125k UP, 110K DN, 1120K Rot, 55-60 RPM, 3K Off BTM TO.Tag top of Packer @ 4,392'. Mill over Packer with 10-13K WOB,4-8K TO.Return Flow=45%@ 66 SPM.Continue to Mill Packer @ 7 BPM w/775 PSI. 10-13K WOB,4-8K TQ.Return Flow=45% @ 66 SPM. Milled packer loose @ 4,396'. Chase Packer to bottom @ 4,455'.Circulate bottoms up with 466 Units Gas at bottoms up. Set Back,Blow Down Kelly,Flow Check Well.Well Static.Trip out of the hole from 4,455'to BHA.Rack back DC's. Break off and L/D Packer Mill BHA. Clean out Boot Baskets.PU BHA#4.Packer Spear.Fluid loss today 3%KCL 12 bbls.Total 3%KCL loss 162 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1/2 bph BPH.Recovered 14 lbs from Ditch magnets. Ditch magnets total=14 lbs. Recovered 95 lbs from Boot Baskets. Boot Basket total=95 lbs.Total metal recovered=109 lbs. 09/25/13-Wednesday RIH with spear assem BHA#4=3-1/4"Spear w/3.885 catch,XO,Bumper Sub,Oil Jars,Pump Out Sub,XO,9 DCs,XO=303.82.Break circ and get parameters.Engage packer at 4,455'and attempt to pull pkr free. Attempt to jar packer free jarring up to 175k over up wt.,packer wouldn't move.Monitor well. Blow dn Kelly and POOH. Lay dn Spear. PU packer mill BHA#5=8-1/2"packer mill w/3- 1/8"PRT extension,XO,Triple connect sub,Three 7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,Pump Out Sub,XO,9 DCs,XO= 322.21. RIH to 4,423'. Hole is not taking any fluid.Cut drilling line 100'. PU Kelly and break circulation and establish parameters. Tag top of packer @ 4455'.Mill from 4,455'to 4,456.5'with 18-20k WOB, 4-8K TQ, 4-7 BPM w/650 PSI,142K PU,115K SO,132K Rot, 70 RPM @ 80 to 180 Amps. Rack Back Kelly.Lay down 1)single to 4426'.Monitor well with no flow.TOH from 4,426'to 322'(BHA). Rack back drill collars.Break and lay down Packer Mill.Clean out Boot Baskets and recover 33 lbs Metal.PU BHA#6=3-1/4"Spear w/ 3.885 catch,XO,Bumper Sub,Oil Jars,Pump Out Sub,XO,9 DCs,XO,Accelerator Jar.Total Length BHA=224.97. RIH with Spear Grapple Assembly from 225'to 4,424'.Pick up Kelly,break circulation @ 5 BPM w/450 PSI.Wash down to TOF. Saw pressure increase @ 4,456'with stinger.Engage Grapple and jar on packer with 200K to 250K over string wt.Jared Packer up hole roughly 2'to 4,454'. Monitor well and inspect derrick before pulling out of the hole.Fluid loss today 3%KCL 12 bbls.Total 3%KCL loss 162 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1/2 bph BPH.Recovered 20 lbs from Ditch magnets.Ditch magnets total=34 lbs.Recovered 33 lbs from Boot Baskets. Boot Basket total=128 lbs.Total metal recovered=162 lbs. Hilcorp Alaska, LLC 1,Hcorp Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations; 09/26/13-Thursday POOH with spear. Recovered 1.70'of packer.Remove pkr from spear. Change out grapple on spear. RIH 4,423',tag and engage fish at 4,456',Set dn 50k to seat spear. PU to 200k[65k over]and fish came free. Set back down and tag out at same spot. PU to 150k [15k over]and fish came free again.Hole not taking any fluid.Set Kelly back and POOH.No recovery. Grapple was released and bottom was pinched.Service rig.Put new 3.885 grapple[will go down to 3.812]on spear and RIH to 4,392'. PU single to 4,424'. MU Kelly.Establish parameters:7 BPM w/675 PSI,132K UP,120K DN,126K Rot,60 RPM @ 80 amps.Engage and spear into fish.PU with 10-15K drag.Appear to have fish.Set back and blow down Kelly.Lay down single.Monitor well with no flow or losses.TOOH slowly from 4,392'to 255'(BHA). Rack back DC's.Lay down Accel Jar.Break down and lay down packer fish(15.5').Recovered 2 fully intact slip dies with fish.PU BHA#9 as follows:Mule shoe coupling, 2 jts 2-7/8"tubing, XO, PxP XO, 9-5/8"Scraper, 2-7"Boot Baskets, Bit Sub w/float, Lub Bumper Sub, Pump out sub, XO, 9-6 1/2"DC's, XO,Total BHA Length=383.19.Total Length Mule shoe to Scraper NO GO=65.00'. TIH from 383'to 4,456'.PU Kelly,Break circulation @ 8 BPM with 300 PSI.Work through top of Packer @ 4,471' UP 134K,DN 120K.Wash down from 4,471'to 4,536'with 2-7/8"tubing inside Gravel Pack Blank Joint.No Go on top of Packer at 4,471'with 9-5/8"Scraper.2-7/8"tubing/Mule Shoe to Scraper No Go=65.00',minus 4,536'clean out depth =4,471'Top Of Packer.Note:Gas Units @ Bottoms Up=712,Circulate hole clean.Set back Kelly.Monitor Well for Flow.Lay down 2)jts,Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 166 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1/2 bph BPH. Recovered 0 lbs from Ditch magnets. Ditch magnets total=34 lbs.Recovered 0 lbs from Boot Baskets. Boot Basket total=128 lbs.Total metal recovered=162 lbs. 09/27/13-Friday POOH and lay dn BHA. Clean boot baskets,recovered 45 lbs with 80%metal and 20%sand.Rig up E-Line equip.MU 1-11/16" TBG punch an RIH. Couldn't get past 4,504'. POOH and checked tool.MU 3-1/2"magnet with jars and RIH w/E-Line to 4,504. POOH recovering two 4"slivers and fines.Rig down wireline.PU clean out assem BHA#10=Mule Shoe Coupling,3 its 2-7/8"tbg,XO,XO, Boot basket,9-5/8"csg scrapper,2 Boot Baskets,Bit sub,Bumper Sub,Oil Jars,Pump Out Sub,XO,9 DCs,XO=414.97.TIH with clean out BHA.Work through top of packer @ 4,471'to 4,487'.PU Kelly and single.Break circulation @ 9 BPM with 400 psi.Wash down from 4,487'.Hit and work through obstruction @ 4,520'.Increase pump to 10 BPM w/500 PSI and continued to wash down to 4,559'. PU 135K,DN 120K,PU hole 40'to 4,519'.Circulate hole clean @ 10 BPM w/500 PSI.Had 526 units gas @ bottoms up. Shut down pump and RIH with no pump and no obstructions to 4,559'.Blow down and set back Kelly.Monitor well with 1 BPH Static Loss.Lay down Single.TOH from 4,487'to 414'.Rack Back Drill Collars,Lay down BHA.Clean out Boot Baskets and recover 33 lbs Metal.Clear and clean rig floor. Rig up E-Line with 1-11/16" TBG Punch.TIH with punch and did not have problem passing through Packer @ 4,470'.Locate 10'Blank joint @ 4,506'Correlated CCL to UNOCAL Tubing Tally dated 5/29/89.RIH and punch holes from 4,528'to 4,530'.POOH. Lay down tubing punch. MU Tubing Jet Cutter.Correlate to CCL and Tubing Tally. Cut blank pipe above gravel pack screens @ 4,530'.POOH and rig down E-Line.Fluid loss today 3%KCL 0 bbls.Total 3%KCL loss 166 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-1/2 bph BPH.Recovered 70 lbs from Ditch magnets. Ditch magnets total=104 lbs.Recovered 36 lbs from Boot Baskets. Boot Basket total=164 lbs.Total metal recovered=200 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name _API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 09/28/13-Saturday PU BHA#11=Packer retrieving tool,XO,Bumper Sub,Oil Jars,Pump Out Sub,XO,6 DCs,XO,Acc Jars=231.20. RIH to 4,449',space out,get parameters.Engage packer at 4,470'. Bleed jars and PU to 200k.No movement. Jar at 250k with a straight pull of 275k,Bring pump on while jarring and maintain 1000 to 2000 psi. After 15 hits with the jars the fish came free on the down stroke and packed off pumping the fish up the hole.Shut pump down an PU until pressure bled down.Establish circ at a max of 3 BPM.When rate was increased it would pack off.Circ gas out with a high of 466 units of gas.POOH working through tight spot approx.every 80'.Pipe hung up at 3,885'.Attempt to work free.No movement. Jar on string at 225k with no movement. Break connection at 10'in the air and rig up headpin. Circ through cmt hose and continue to jar on fish at 225k. Fish came free after 18 licks.POOH to 3,452'and fish hung up again. PU sng and work dn to 3,480'.MU headpin and cir bottoms up to clear debris from around packer.POOH f/3,480'to 231' with 5k to 15k overpull.Did not see any over pulls coming through well head.Lay down Acc Jar,rack back drill collars.Lay down fish. Recovered 3.49'of packer and 1 slip die from previous packer.Service Rig.MU BHA#12: 8-1/2"Junk Mill, 4 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar,Pump out Sub,XO,9ea.6-1/2"DC's,XO.Total Length=323.45'.TIH with BHA#12 from 323'to 3,400'.Slow down trip speed and watch for fish.Tagged fish @ 3,847'.Confirm solid tag with 20K Dn/Wt.Original TOF @ 4,470'. TOH from 3,847'to PU Packer Mill/Retrieval Tool.Rack back drill collars.Break off and lay down Junk Mill.Add 3.28' extension to PRT.MU BHA#13:PRT Extension 10.70',8-1/2"Paker Mill,4 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar,Pump out Sub,XO,9ea.6-1/2"DC's,XO.Total Length=350.25'.TIH from 350'to 3,760'. 36 Stds,PU 1)single,10'Pup,1) Single to 3,833'.PU Kelly,Break Circulation and establish parameters:5 BPM w/240 PSI, 134K PU,120K DN,120K Rot.Single in hole with Kelly looking for top of fish to 3,896'.Did not encounter fish.Set back Kelly.Lay down single and 10'pup joint.TIH with DP from derrick f/3,855'. Fluid loss today 3%KCL 8 bbls.Total 3%KCL loss 174 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-0 bph BPH.Recovered 8 lbs from Ditch magnets.Ditch magnets total=112 lbs.Recovered 38 lbs from Boot Baskets. Boot Basket total=202 lbs.Total metal recovered=314 lbs. 24 hour notification of upcoming BOPE Test sent to AOGCC via e- mail on 9-28-2013 @ 12:55 AM.Test witness waived by Chuck Sheve via phone call from North Slope. 09/29/13-Sunday RIH looking for fish f/3,936't/4,463'where we started taking wt. Circ at 10 BPM at 800 psi and mill on fish with 4k wt on bit.Make a couple inches and set down 20k on tool.Slid down to 4,470',PU with a 4k over pull,Set back down and put a extra 25k dn,PU with a 4k over pull,[had a full bottoms up circ with no gas].POOH slow with several 15k over pulls up to the first 3,000'.Lay dn BHA and fish. Recovered 66'of fish and all the missing packer dyes from both packers.Flush stack and rig up to test BOPs.Pull wear bushing,land test plug.Test BOPE.Test Hydril to 250 psi low and 2500 psi high on 5"and 2-7/8". Test all other BOP equip to 250 psi low and 2500 psi high.Test upper pipe rams w/5"and 2-7/8".Perform accumulator test.Witness of test waived by Chuck Sheve,AOGCC.Rig down test equipment.Set Wear Bushing.Service Rig.Change out Hawk Jaw.TIH with 4 stands of 5"DP from off drillers side.TOH Laying down same for working singles.Prep to PU BHA#14. MU BHA#14: 8-1/2"Wave Bottom Shoe,13 jts 7-5/8"Xline Wash pipe,XO Bushing,1 jt 8-1/8"TSWP Wash Pipe,8-1/8"Wash Over Boot Basket,XO PxP,2 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar,Pump out Sub,XO,9ea.6-1/2"DC's,XO,Acc Jar. Total Length=734.61'.Run 1 stand DP on top of BHA,install FOSV.Fluid loss today 3%KCL 8 bbls.Total 3%KCL loss 174 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 bph BPH. Recovered 8 lbs from Ditch magnets.Ditch magnets total=120 lbs.Recovered 1 lbs from Boot Baskets.Boot Basket total=203 lbs.Total metal recovered=323 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 09/30/13-Monday RIH to 4,523'and tag fill.Kelly up and bring on pump at 10 BPM 500 psi.Wash to top of blank cut off at 4,530'.Wash and mill over screens to packer at 4,900'.Sand coming back solid across shakers during milling and highest gas units were 712 units.Mill on packer with shoe while circ hole clean.Make about 6"and pressure started climbing.Continue circ 2 bottoms ups at 9 1/2 BPM until sand cleaned up at shakers.Recovered 20 bbls of sand.Pull up to 4,586'and monitor well.Hole is taking 9 BPH static.Wait 20 min. RIH to check for fill and tag at 4,899'.POOH with wash pipe from 4,899'to 730'(BHA). Lay down Acc Jar.Rack back DC's.Lay down 5)jts of wash pipe.Stand back 9 jts wash pipe in derrick.Clean out and recover 2 lbs of mostly sand from junk baskets.Swap out Bumper Sub and Jars with new set.PU BHA#15: 8-1/8"Overshot w/5"Catch,6-1/4"Lub Bumper Sub,Oil Jar,Pump Out Sub,X Over,9 ea.6-1/2" Drill Collars.X Over, Accel Jar. TIH 1)std to 406'.Install FOSV.Total Length BHA=316.45.Service rig and change out Hawk Jaw.TIH with BHA#15 from 400'to 4,483'.PU single to 4,515'.PU Kelly.Break Circulation and establish parameters:@ 7 BPM w/200 PSI, PU 142K, SO 125K, Rot 132K.Wash over top of fish @ 4,530'. Had 800 Psi increase in pump pressure. Set 20K Dn on fish,PU to 200K (58K over)Fish pulled free.Cont to PU hole with 8-10K drag.Blow Down set back Kelly, drop bar to shear circ sub.MU head pin and shear open circ sub @ 1500 psi. Lay down single.Static Loss @ 10 BPH.TOH with fish(gravel pac screens)from 4,483'to 316'.Lay down Acc Jar,Rack back DC's.Fluid loss today 3%KCL 169 bbls.Total 3%KCL loss 343 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbl.Daily Loss rate average-7 BPH.Recovered 27 lbs from Ditch magnets. Ditch magnets total=147 lbs.Recovered 2 lbs from Boot Baskets. Boot Basket total=205 lbs.Total metal recovered=352 lbs. 10/01/13-Tuesday POOH laying down gravel pack screens.Recovered all the screens,the snap latch assem,and the seals4Hole taking 12 BPH].RIH with 3 stds of washpipe out of derrick and POOH laying do same.MU BHA#16: 4-3/4"Ser 400 Hyd PRT Spear, 4-1/4"PRT Extensions, 8- 1/2"Paker Mill,Triple connect Sub, 4 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar, XO,9ea.6-1/2"DC's, XO, Accelerator Jar. Total Length=345.55'. Service Rig.TIH from 440'to 4,828'.Lay down 2)singles. PU 20'Pup jt. PU Kelly.Establish parameters and Mill packer from 4,900'to 4,902'@ 7 BPM,430 PSI,60-80 RPM,5-8K TQ,WOB 5-20K.Packer free at 4,902'.PU hole with 50-60K over.Blow down and set back kelly.Monitor Well with 12 BPH static loss.TOH with fish from 4,900'to 345'. Had 10-25K over pulls.Last over pull @ 3,500'. Lay down Accelerator.Stand Back DC's.Lay down BHA and fish.Clean out boot baskets and recovered 102 lbs of mostly sand.MU BHA#17: 8-1/2"Mill Tooth Bit,4 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar,Pump out Sub,XO,9ea.6-1/2"DC's,XO. Total Length=321.48'.TIH from 320'.Tag fill @ 4,912'.Lay down 7 singles from derrick to drill with.PU Kelly.Establish parameters and wash and ream from 4,912'to 4,942'@ 05:30. 5 BPM w/130 PSI 154K PU, 130K SO,140K Rot.60 RPM w/4-5K off btm TQ. 8-15K on btm TQ w/3-4K WOB. Fluid loss today 3%KCL 269 bbls.Total 3%KCL loss 612 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls. Daily Loss rate average-7 BPH.Recovered 77 lbs from Ditch magnets. Ditch magnets total=224 lbs.Recovered 0 lbs from Boot Baskets. Boot Basket total=205 lbs.Total metal recovered=352 lbs. 10/02/13-Wednesday Continue to wash and ream from 4,912'.Drill CMT retainer from 41959'to 4 961'_5-10 BPM w/130-400 PSI,154K PU,130K SO, 140K Rot.40-70 RPM w/4-5K off btm TQ. 8-15K on btm TQ 10-25K WOB.Wash and ream 4,961'to 5,056'.Drill CMT from 5,056'to 5,076'.Drill CIBP from 5,076'to 5,091'w/560 units gas @ btm up.Monitor well with 10 BPH loss rate.Set back Kelly.Chase plug with stands to no go @ 5,151'.TOH laying down 45 jts DP from 5,151'to 3,826'.TIH from 3,826'and tag @ 5,151'.Lay down single,PU Kelly.Continue to wash and ream from 5,151'to 5,353'.5-10 BPM w/130-450 PSI,170K PU,125K SO,145K Rot.40-70 RPM w/4-5K off btm TQ.8-15K on btm TO 10-25K.(Sand,Cement and oil @ shakers.)Hole unloading sand and Cement.PU off bottom and CBU @ 10 BPM with 420 PSI.No gas @ bottoms up.Continue to wash and ream from 5,353'to 5,413'.5-10 BPM w/130-450 PSI.170K PU,125K S0, 145K Rot.40-70 RPM w/4-5K off btm TQ.8-15K on btm TQ 10-25K.CBU in preparation to POOH.No gas or increase in debris at bottoms up.Set back Kelly.Monitor well with 9 BPH static loss.TOH from 5,413'to 320'.Stand Back Drill Collars.Break off bit.Break off and clean out Boot Baskets.Fluid loss today 3%KCL= 289 bbls.Total 3%KCL loss= 901 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-12 bph BPH.Recovered 285 lbs from Ditch magnets.Ditch magnets total=509 lbs.Recovered 102 lbs from Boot Baskets.Boot Basket total=307 lbs.Total metal recovered=816 lbs. Hilcorp Alaska, LLC Hile,,rNAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date •End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/03/13-Thursday MU BHA#18: 8-1/2"Mill Tooth Bit,4 ea 7"Boot Baskets,Bit sub with float,Lubricated Bumper Sub,Oil Jar,Pump out Sub,XO, 9ea.6- 1/2"DC's,XO. Total Length=321.48'. TIH from 320'.Tag fill @ 4,912'. Lay down 7 singles from derrick to drill with. PU Kelly. Continue TIH to 5,404'.L/D top single jt#162.PU Kelly and Establish parameters @ 10 BPM,410 PSI,186K PU,130K 50,150K Rot.Dry tag top of fill @ 5,413'.Drill CMT from 5,413'to 5,420' 9.5 BPM,395 PSI,10-15K WOB,7-8K TQ. Continue Drill hard CMT from 5,420' to 5,545'.10.5 BPM,500 PSI,25K WOB,80 RPM,7-8K TO,ROP 40-100 FPH.Soft CMT @ 5,546'.PU 195K,SO 130K,Rot 150K.Drill soft CMT/Sand from 5,545'to 5,925'.10.5 BPM,500 PSI,15-25K WOB,80 RPM,7-8K TQ ROP 200-300 FPH,PU 205K,SO 127K, Rot 156K. Drill soft CMT/Sand from 5,925'to 6,003'10.25,500 PSI,15-20K WOB,80 RPM,7-8K TQ ROP 100-200 FPH,PU 205K,SO 127K,Rot 156K.Started taking weight at 6,003'25-28K WOB.(CMT Retainer).Circulate and establish good returns.Drill CMT Retainer and hard CMT from 6,003'to 6,038',8-10 BPM,510 PSI,25-27K WOB,40-80 RPM,7-14K TQ ROP 6-7 FPH,PU 205K,SO 127K,Rot 156K.Fluid loss today 3%KCL= 214 bbls.Total 3%KCL loss= 1115 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-9 BPH. Recovered 237 lbs from Ditch magnets.Ditch magnets total=746 lbs.Recovered 148 lbs from Boot Baskets.Boot Basket total=447 lbs.Total metal recovered=1193 lbs. 10/04/13-Friday Continue drilling hard CMT from 6,039'to 6,068',10 BPM,500 PSI,25-30K WOB,40-80 RPM,10-15K TO,ROP 6-7 FPH,PU 210K,SO 135K,Rot 160K.5 BPH Static Loss. Continue drilling CMT from 6,068'to 6,097',10 BPM, 500 PSI,25-30K WOB,40-80 RPM,10-15K TQ ROP 6-7 FPH,PU 210K,SO 135K,Rot 160K.5 BPH Static Loss. Drill CIBP @ 6,097'-6,099',10 BPM,500 PSI,20K WOB, 40-80 RPM, 60 RPM,8-13K TO,ROP 6-7 FPH,PU 210K, SO 135K, Rot 160K. Chase plug to 6,108'.5 BPH Static Loss.Circulate Bottoms UP after drilling plug @ 10 BPM,475 PSI with minimal gas at bottoms up.Wash and ream from 6,108'to 6,171'6 BPM,175 PSI.Circulate out 983 Units gas and 30 viscosified fluid @ Bottoms up.Continue to wash and ream from 6,171'to 6,478'.Max gas from 6,171'to 6,478' =700 units.Drill cement from 6,478'to 6,532'.Tag top of old packer at 6,532'. Attempt to mill on or move packer down hole. Stack 30k WOB Rotating.PU off bottom and confirm tag @ 6,532'.Set back Kelly.Lay down 1)jt,Monitor well.Well static.TOH from 6,500' to 320'. Hole taking calculated hole fill.Stand Back Drill Collars.Break off bit.Break off and clean out Boot Baskets.Recovered 138 lbs Metal from Boot Baskets.PU packer mill BHA#19=8-1/2"packer mill w/3-1/8"PRT extension,XO,Triple connect sub,4ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO Total BHA Length=325.19.RIH with 1 Stand 5"DP.Install floor valve in preparation to Slip and Cut drill line.Fluid loss rate @ 0 BPH @ 05:30.Fluid loss today 3%KCL= 45 bbls. Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-5 BPH.Report Time Loss Rate=0 BPH.Recovered 342 lbs from Ditch magnets.Ditch magnets total=1088 lbs.Recovered 138 lbs from Boot Baskets.Boot Basket total=447 lbs.Total metal recovered=1535 lbs. Sent 24 hr notification of up coming BOPE test to AOGCC via on line Test Witness Notification Form on 10/5/2013 @ 12:50 AM. 11 Hilcorp Alaska, LLC liilcorpAlaska.LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/05/13-Saturday Continue to PU packer mill BHA#19=8-1/2"packer mill w/3-1/8"PRT extension,XO,Triple connect sub,4ea.7"Boot Baskets, Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO Total BHA Length=325.19.RIH with 1 Stand 5"DP. Install floor valve in preparation to Slip and Cut drill line.Fluid loss rate @ 0 BPH @ 06:00.Slip and cut 275'of drill line. Service Rig. This from 325'to 6,514'.PU Kelly, Establish parameters @ 5 BPM,390 PSI,217K PU,135K SO,170K Rot.60 RPM,12K TO.Tag TOF @ 6,532'.Attempt to mill bull nose through top of packer. Encountering pack off issues.Attempt various times to mill packer with no success.Set back Kelly.Monitor well with 0 BPH loss rate.TOH from 6,532'to 325'. Stand Back Drill Collars.Break off Packer Mill.Break off and clean out Boot baskets.Recovered 105 lbs Mostly CMT from Boot Baskets.PU BHA#20=8-1/2'x 6"Wash Over Shoe,Catcher Bushing with Finger Basket,X over Bushing,1)Jt 7-5/8"Xline Wash Pipe, X over Bushing 7"Xline BX x 7-5/8"Xline Pin,VACS Tool, XO Pin x Pin,4ea.7" Boot Baskets,Bit Sub,Bumper Sub,Oil jars, XO,9 DCs,XO.Total BHA Length=361.93. TIH from 361'to 6,520'.Taking returns over the shaker to active system.Clean trip tank and sand Trap.PU Kelly,Establish parameters @ 8 BPM,960 PSI,222K PU,140K S0, 170K Rot.40-60 RPM,12-13K TO, 2-10K WOB.Tag TOF @ 6,532'. Wash and mill over junk from 6,532'to 6,572'.Adjusting parameters as needed.Stage pump to 10.5 BPM @ 1600 PSI.Could not make any more hole after 6,572'.No gas circulated to surface during milling operations.Circulate bottoms up @ 10 BPM with 1575 PSI.Monitor well with no flow or losses.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 150 lbs from Ditch magnets.Ditch magnets total=1238 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total= 447 lbs.Total metal recovered=1685 lbs. Jim Regg with the AOGCC waived witness to BOPE Test on Sat 10/5/2013 12:24 PM via e- mail. 10/06/13-Sunday TOH from 6,532'to 325'. Stand Back Drill Collars. Break off Packer Mill Shoe.Lay down wash pipe.Break off and clean out Boot Baskets.Recovered 130 lbs Mostly Metal/CMT/Sand from Boot Baskets.Recover pieces of wireline and perf gun debris from catcher sub.Cleaned the sand trap.Pull wear bushing.Flush Stack with Jonnie Wacker.Rig up BOPE Test Equipment.Test BOPE. Test Hydril to 250 low and 2500 psi high on 5"and 2-7/8".Test all other BOP equipment to 250 low and 2500 psi high.Test upper pipe rams w/5" and 2-7/8".Perform accumulator test. All test pass.Witness of test waived by Jim Regg,AOGCC. Rig down Test equipment.Set Wear Bushing.Clean and organize rig floor.PU BHA#21=8-1/2"x 6"Wash Over Shoe,Catcher Bushing with Finger Basket,X over Bushing, 1)Jt 7-5/8"Xline Wash Pipe,X over Bushing 7"Xline BX x 7-5/8"Xline Pin,VACS Tool,XO Pin x Pin,3ea.7"Boot Baskets,Bit Sub, Bumper Sub,Oil jars,XO,9 DCs, XO.Total BHA Length=357.70.TIH from 361'to 6,547'.PU 1)single.PU Kelly.Establish parameters @ 9 BPM,1277 PSI,224K PU,137K SO,167K Rot.40-60 RPM,12-13K TQ,2-5K WOB.Tag TOF @ 6,574'. Wash and mill over junk from 6,574'to 6,600'. Adjusting parameters as needed.Stage pump to 10.5 BPM @ 1530 PSI.Could not get past 6,600'.Pulling 50K over string wt.before break over.Gained 3K additional UP wt 0 Units gas circulated to surface during milling operations. Set back Kelly.Lay down 2)singles.Monitor Well with no flow or losses.TOH from 6,547'.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH. Report Time Loss Rate=0 BPH Recovered 168 lbs from Ditch magnets.Ditch magnets total=1406 lbs.Recovered 44 lbs from Boot Baskets.Boot Basket total=491 lbs.Total metal recovered=1897 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name _API Number Well Permit Number Start Date _End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/07/13-Monday TOH from 5,830'to 357'.Encounter over pulls @ 6,430';5,600';4,160'.Stand Back Drill Collars.Break off Mill Shoe.Lay down wash Pipe.Break off and clean out Boot Baskets.Recovered 46 lbs Mostly Metal//Sand from Boot Baskets.Recover 25'of fish,3 pc of tbg, and 1 perf gun from wash pipe.Service Rig.Repair Cat shaft disconnect valve on Drillers Council.PU BHA#22=8-1/2"x 6"Wash Over Shoe,Catcher Bushing with Finger Basket,X over Bushing,1)Jt 7-5/8"Xline Wash Pipe,X over Bushing 7"Xline BX x 7-5/8"Xline Pin, VACS Tool, XO Pin x Pin, 3ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO.Total BHA Length=357.70.TIH from 361' to 6,547'.L/D 1)single.PU Kelly.Establish parameters @ 9 BPM,1200 PSI,225K PU,135K 50,171K Rot.40 RPM,12-13K TQ,2-5K WOB.Tag TOF @ 6,600'.Unable to rotate on fish.Make several attempts to mill with no success.Set 20K DN Wt on fish with no rotation.Pulling 25K over string wt.before break over.0 Units gas circulated to surface during milling operations. Fluid Losses @ 0 BPH while circulating. Set back Kelly. PU 1)single(66 stds).Monitor Well with no flow or losses.TOH from 6,515'to 375'.Stand Back Drill Collars.Break off Mill Shoe.No fish in wash Pipe.Break off and clean out Boot Baskets.Recovered 0 lbs.Mostly Metal/CMT/Sand from Boot Baskets.Redress catcher sub.PU BHA#23=8-1/2"x 6"Wash Over Shoe, Catcher Bushing with Roller Dogs,X over Bushing,1)Jt 7-5/8"Xline Wash Pipe,X over Bushing 7"Xline BX x 7-5/8"Xline Pin,VACS Tool, XO Pin x Pin,3ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO.Total BHA Length=357.63.TlH from 361'to 6,547'.L/D 1)single.PU Kelly.Establish parameters @ 10 BPM,1480 PSI,225K PU,135K SO,171K Rot.40 RPM,12-13K TQ,2-5K WOB.Tag TOF @ 6,600'. Mill over fish from 6,600'to 6,605'@ 05:30.0 Units gas circulated to surface during milling operations. Fluid Losses @ 0 BPH while milling.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 193 lbs from Ditch magnets.Ditch magnets total=1599 lbs.Recovered 92 lbs from Boot Baskets. Boot Basket total=583 lbs.Total metal recovered=2182 lbs. 10/08/13-Tuesday Milling on junk from 6,600'to 6,612'.Circ @ 10 BPM/1470 PSI.UP WT 225K,DN WT 136K,ROT 167K.No progress @ 6,612'.Flow check-well static.Kelly Down.(P/U single#198)POOH from 6,612'to 1,021'.TOH from 1,021'-357'.L/D BHA,observe well,Static.L/D BHA#23.Break off and clean out Boot Baskets.Recovered 23 lbs Mostly Metal/Sand from Boot Baskets.Clean rig floor.PU BHA#24= 8-1/2"x 6"Wash Over Shoe,Catcher Bushing unbaited,X over Bushing,1)Jt 7-5/8"Xline Wash Pipe,X over Bushing 7"Xline BX x 7- 5/8"Xline Pin,VACS Tool,XO Pin x Pin,3ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO.Total BHA Length=357.63. Service Rig.TIH from 361'to 6,547'.L/D 1)single.PU Kelly. Tag at 6,610'-puw 225k-sow 135k-rtw 173k-rpm 55/trq 13k-wob 3/5k. Milling from 6,610'to 6,612.5'tried various parameters to make hole-unable to make anymore hole-very fine slivers of metal at shakers and magnets.Circ to clean well at max rate-same fine slivers of metal across shakers and magnets as while milling but not as much.POOH to inspect BHA.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 205 lbs from Ditch magnets.Ditch magnets total=1804 lbs.Recovered 23 lbs from Boot Baskets.Boot Basket total=606 lbs.Total metal recovered=2410 lbs. Hilcorp Alaska, LLC Hilcorp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/09/13-Wednesday L/D BHA.Break Boot Baskets,L/D Jars/Bumper Sub,P/U Break off shoe and washpipe bushing.Break VACS Tool and Top Sub off.L/D Washpipe single and empty Boot basket.Well is Static.PU BHA#25=8-1/2"x 6"Wash Over Shoe,Box tap Assembly,1)Jt 7-5/8" Xline Wash Pipe,X over Bushing,7"Xline BX x 7-5/8"Xline Pin,VACS Tool,XO Pin x Pin,3ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO.Total BHA Length=357.63'.Service Rig,draw works,over ride clutch,traveling block,crown cluster,hawk jaw, and rotary table.Well is Static. TIH from 359'to 6,597'.Fill pipe at 3,500',7 BPM,TIH space out w/20'pup.Fill pipe up WT=217K,DN WT=138K,RT WT=165K @ 18 RPM/10 KTQ while pumping @ 10 BPM/1500 PSI.Washed F/6,597'.Tagging top of fish @ 6,600'. TIH L/D 20'pup.Wash from 6,577'-TOF @ 6,608'.Work TQ(10K-12K)into fish @ 6,609'until 3 wraps IN/3 OUT @ 14 KTQ.P/U to 170K& work DN to 10K.P/U to 250K fish came free w/No jarring.3K UP drag.Slack off to 6,609'.Same Tag.TOOH Observe well:Static.Set Kelly back.POOH 609'-357'. L/D-BHA#25-no recovery-no distinguishing marks on inside or outside to indicate on fish.Clean floor. MU BHA#26-5 blade 8-1/2"Junk Mill, 4 ea 7"boot bskts,6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2" DC,6-1/16"xo=OAL 322.64'. RIH with BHA#26 filling pipe at 20 and 40 stds,CBU at 6,575'.Start precautionary washing from 6,575'- 6,604'.Tag fish at 6,604'-milling on junk with various parameters from 6,604'-6,612'.—100 lbs metal recovered from milling.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss=1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average- 0 BPH.Report Time Loss Rate=0 BPH.Recovered 205 lbs from Ditch magnets.Ditch magnets total=1804 lbs.Recovered 23 lbs from Boot Baskets. Boot Basket total=606 lbs.Total metal recovered=2410 lbs. 10/10/13-Thursday Continue milling junk from 6,604'to 6,611'.10 BPM/1140 PSI,80 RPM/13-16 KTQ.Varied parameters to mill through junk at 6,612'. TOH -flow check:Well Static.Kelly down,blow down.POOH from 6,612'to 322'.L/D BHA#26 stand back 3 stands collars.L/D junk mill and boot baskets.Cleaning Rig/Platform.Removed ODS Doghouse from Derrick. Service Rig. Clean Junk Baskets-recovered 21 lbs metal.PU BHA#27=8-1/2"x 6"Wave bottom shoe, X over Bushing,1)1t 7-5/8"Xline Wash Pipe,X over Bushing,7"Xline BX x 7- 5/8"Xline Pin,VACS Tool,XO Pin x Pin,4 ea.7"Boot Baskets,Bit Sub,Bumper Sub,Oil jars,XO,9 DCs,XO.Total BHA Length=357.70'. TIH 356'to 6,577'- Fill pipe @ 2,250'-4,145'-6,577'.L/D sgl on std 66.P/U Kelly-obtain parameters-puw 221k-sow 130k-rtw 165k- rpm 50-trq 13k-bpm 10-psi 1500.Tag TOF at 6,609'.Milling with various parameters-could not get over fish.Monitor well static- POOH. L/D BHA#27.PU BHA#28-8-1/2"x 6"Saw Tooth Shoe,8-1/8"xo,8-1/8"Catcher Bushing w/roller dogs,8-1/16"xo,1 Jt 7- 5/8"Xline Wash Pipe,7-15/16"xo-7-3/8"vacs tool,7-3/8"xo,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4"bump sub,6-1/4"oil jar,6- 1/8"xo,9 ea 6-1/2"DC,6-3/16"xo=OAL 362.56'.Well is static.RIH with BHA#28.Service rig,draw works,over ride clutch,traveling blocks,crown cluster,Kelly spinner/swivel. Cont.RIH to 3,200'.CBU to circ air out at 8 bpm-1000 psi. Cont.RIH to 6,583'.L/D sgl. CBU air out at 10 bpm-1500 psi. Obtain parameters-puw 222k-sow 136k-rtw 164k-rpm 50-trq 13k-bpm 10-psi 1500.Wash from 6,583'-tag at 6,609'.Mill/Wash over fish from 6,609'.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 302 lbs from Ditch magnets.Ditch magnets total=2151 lbs.Recovered 21 lbs from Boot Baskets.Boot Basket total=627 lbs.Total metal recovered=2778 lbs. 10/11/13-Friday Continue milling from 6,610'to 6,612'.11 BPM/1824 PSI,Flow 52%,70 RPM/13-15 KTQ,2-8 KWOB. Varied parameters.TOOH Flow Check:Well Static.Kelly Down,Blow down.POOH 6,612'to 3,583'. TOOH 3,583'to 362'.L/D BHA#27.Observe well:Well Static.Set back 3 stds.L/D saw tooth shoe,catcher bushing/roller dog,JT/Washpipe,vac tool,3 XO bushings,4 junk baskets,and Jars/Bumper sub.Clean Rig/Platform/Rig floor.M/U BHA#29.PU BHA#29-8-1/2"6 blade Junk Mill,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4" bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2"DC,6-3/16"xo=322.64'.Well is static.RIH with BHA#29.CBU at 2,217'-4,110'- 6,567'to remove air from brine.Obtain parameters-puw 220k-sow 132k-rtw 169k at rpm 50-trq 13k. Tag TOF at 6,610'.Mill from 6,610'to 6,615'-hard milling spot at 6,612'. 40k over pull set jars off lx-able to rotate up/down to 6,615'.Monitor well:Well static.POOH to inspect mill and boot baskets.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss=1160 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 175 lbs from Ditch magnets. Ditch magnets total=2326 lbs.Recovered 28 lbs from Boot Baskets.Boot Basket total=634 lbs.Total metal recovered=2960 lbs. Hilcorp Alaska, LLC Iliicorp Alaska.LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/12/13-Saturday TOH from 6,575'to 322'.L/D BHA#29.Clean out boot baskets,recovery 21 lbs/metal. P/U BHA#30-8-1/2"6 blade Junk Mill,4 ea 7" boot bskts, 6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"XO,9 ea 6-1/2"DC,6-3/16"XO=322.64.Well is static.Cut Drilling Line:124'.TIH 322'-6,575'.Fill pipe&CBU @ 2,217' 10 BPM/920 PSI through Circ hose.Fill pipe&CBU @ 4,110'10 BPM/1000 PSI through Circ Hose,Kelly up-puw 220k-sow 128k-rtw 166k at 50 rpm/13k trq-10 bpm-655 psi-tag at 6,613'.Milling at 6,613'-made footage to 6,616'-start taking wt-stall out.P/U tripping jars-at 40k over-cont to torque up-work back down to 6,616'. Shakers tripped out-electrician working on shaker.Monitor well-well static. Blow down Kelly.POOH to inspect mill,boot baskets,work on shaker.Prep for weekly BOPE test.Fluid loss today 3%KCL=0 bbls.Total 3%KCL loss= 1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 192 lbs from Ditch magnets.Ditch magnets total=2518 lbs.Recovered 21 lbs from Boot Baskets.Boot Basket total=655 lbs.Total metal recovered=3173 lbs. 10/13/13-Sunday TOH from 5,058'to 322'.L/D BHA#30.Cleaned boot baskets recovered 69#s/Metal.Install/Remove wear bushing.Pull wear ring, Flush Stack with Jonnie Wacker.P/U BOP Test tool.Set Test Plug&M/U 5"Test Joint.Test BOPE.Test Hydril to 250 psi low and 2500 psi high on 5"and 2-7/8".Test all other BOP equipment to 250 psi low and 2500 psi high. Test upper pipe rams w/5"and 2-7/8". Perform accumulator test.All test pass.Witness of test waived by AOGCC Inspector Chuck Scheve 10/13/13 at 1030 hrs.Rig down Test equipment. L/D test equip. Install wear ring. Clear rig floor of test equip. M/U BHA#31-8-1/2"bit(no jets),4 ea 7"boot bskts, 6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"XO,9 ea 6-1/2"DC,6-3/16"XO=320.64'.RIH with BHA#31. CBU to get air out of fluid at 3,162'and 6,573'.Rig up and install#2 shaker. Circ/cond well while pumping old fluid to Production in prep to change over to new fluid.Change out mud system to new 3%KCL 8.6 ppg-4.5 bpm-250 psi to production.TBU-470 bbls new brine in well. Ship 922 bbls to production. Flush out choke man,kill line,blow down Kelly,choke man,drain degasser.U tube-well static. POOH with BHA#31.Fluid loss today 3%KCL= 0 bbls.Total 3%KCL loss=1160 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=0 BPH.Recovered 111 lbs from Ditch magnets. Ditch magnets total= 2629 lbs.Recovered 69 lbs from Boot Baskets.Boot Basket total=724 lbs.Total metal recovered=3353 lbs 10/14/13-Monday Cont.clean pits&mix brine. L/D BHA#31.Clean boot baskets,recovered 28 lbs/metal. P/U BHA#32. Service rig. Service&inspect draw works,hawk jaw,Kelly,rotary table,blocks&crown.Cont.clean pits&mix brine. TIH from 1,633'to 6,558'.P/U sgl.RIH to 6,590'.M/U TIW vlv in jt#209-cont in hole.Fill hole,S/D hole fill pump,set down at 6,616'to activate Bailer.Observe fluid in stack dropped indicating Bailer is open.Function Bailer 4x-13.5 bbl total fluid loss. POOH with BHA#32-well is static. L/D BHA.Service rig and clean floor of Bailer tools. M/U BHA#33- 8-1/2"sawtooth shoe,8.25"xo,5-7/8"roller dog bushing,8-1/4"xo,1 jt 7-5/8" wash pipe,7-15/16"xo,7-3/8"vacs tool,6-3/8"xo,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2"DC,6-3/16"xo=363.27'. RIH with BHA#33-fill pipe at 30 stds and at 6,557'.Obtain parameters-puw 224k-sow 131k-rtw 165k-trq 14.5k/70 rpm-8 bpm/940 psi. Attempt to engage fish at 6,616'using various parameters-pump on/off with rotation/ with out rotation-spud on fish max wt 35k-well loss at 7 bph. POOH to inspect BHA.Fluid loss today 3%KCL=99 bbls.Total 3%KCL loss=1259 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-8 BPH.Report Time Loss Rate=8 BPH. Recovered 28 lbs from Ditch magnets.Ditch magnets total=2857 lbs.Recovered 23 lbs from Boot Baskets.Boot Basket total=747 lbs. Total metal recovered=3404 lbs. Hilcorp Alaska, LLC HileurpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/15/13-Tuesday LID BHA#32. Clean out boot basket Recovery=0.5 lbs/metal. Service rig,service&inspect draw works,hawk jaw,Kelly,rotary table,blocks&crown.Static loss rate=6 BPH. M/U BHA#33- 8-1/2"6 blade junk mill,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4" bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2"DC,6-3/16"xo=323.63'. TIH from 323'to 1,839'. TIH from 1,839-to 6,596'.Fill pipe @ 3,165'.Circulate and Condition.Fill Pipe CBU @ 19 BPM/600 PSI -fluid loss 7 bpm.Obtain parameters-UP WT=225K,DN WT=128K,RT WT=167K @ 55 RPM/13 KTQ,Pumping @ 10 BPM/575 PSI.Dry tag @ 6,616'.Stall out @ 6,612'.Jar @ 50 K Over. Work DN to 6,617'by increase/decrease pump/rpm rate.Fluid,CBU-to clean hole-very fine metal shavings at shakers.Fluid loss 1 bpm. POOH to inspect BHA.L/D BHA-recovered 15 lbs metal.Fluid loss 1.5 bph. M/U BHA#34.M/U BHA#33-8-1/2"6 blade junk mill,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2"DC,6-3/16"xo=323.63'.RIH with BHA #34. Fill pipe at 3,500'-Break circ on btm 6,550'.Obtain parameters-puw 224k-sow128k-rtw167k @ 55 rpm/13k trq-10 bpm/ 575 psi. Tag at 6,614'-work down to 6,617'.Fluid loss today 3%KCL=70 bbls.Total 3%KCL loss=1329 bbls.Sized Salt Pill 0 bbls. Total sized salt pill loss 0 bbls.Daily Loss rate average-3 BPH.Report Time Loss Rate=1 BPH.Recovered 139 lbs from Ditch magnets. Ditch magnets total=2796 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=747 lbs.Total metal recovered=3543 lbs. 10/16/13-Wednesday Mill on junk f/6,616't/6,623'.Mill at various parameters w/pumps running from 5 BPM to 10 BPM,Running 60 to 100 RPM w/14 to 20k torque.Last 2'everything smoothed out with torque and we should be cleaned out to the top of the Otis Packer.Circ bottoms up at 10 BPM while working pipe up and rotating dn.Work boot baskets.POOH to BHA.Stand back DCs.Break dn mill and boot baskets. Clean boot baskets-recover 20 lbs metal shavings 21 lbs cmt/sand.Service rig.MU BHA#35-3-1/4"pilot spear ext-6-1/4"muncher pilot mill,6-1/4"xo,4 ea 7"boot bskts,6-1/2"bit sub,6-1/4"bumper sub,6-1/4"oil jar,6-1/8"xo,9 ea 6-1/2"DC,6-3/16"xo-oal 325.61'.RIH with BHA#35.Fill pipe at 6,598'=Obtain parameters-puw 223k-sow 130k-rtw 67k at 10 rpm/13 trq. Tag tof at 6,623'.Work into packer using various parameters-cycle pumps(4-10 bpm)-rpm(40-70)-wob(1-10k)-psi(400-2900 psi).Stinger is stalling and packing off(1095psi-1850psi)at 6,621'. Work down to 6,623'-stinger still pressuring up-(1595 psi-2900 psi)pressure drops to 450 psi intermittently. Packer turning and moving down hole,stopping at 6,627'.Metal/sand returns have dropped. CBU. Rack back and blow down Kelly.Monitor well.Fluid loss 0.5 bph. POOH to inspect BHA. Fluid loss today 3%KCL=48 bbls.Total 3% KCL loss=1377 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls Daily Loss rate average-2 BPH.Report Time Loss Rate=2 BPH.Recovered 350 lbs from Ditch magnets.Ditch magnets total=3146 lbs.Recovered 56 lbs from Boot Baskets.Boot Basket total= 803 lbs.Total metal recovered=3949 lbs. 10/17/13-Thursday POOH and lay down BHA.Pilot spear extension had worn down carbide and marks showing it had been run down inside the packer. Pilot mill also had worn marks indicating it had been on top of packer.Recovered 12.5 lbs from boot baskets.Loss rate 2 BPH.PU BHA #36=Spear w/3.88 grapple,3 XOs,4 boot baskets,Bit sub,Bumper sub,Oil jars,X0,9 DCs,Acc jars,XO=339.52'.Service rig.Service hawk jaw,Drwks,Crown,Kelly,and Blocks.RIH to 6,592'and fill pipe. Also filled pipe 1/2 way in the hole.Establish parameters and wash down to top of packer at 6,627'started to pressure up.Shut pump down and set down 10k on spear.PU 20k over up wt.Didn't move fish.Slack back off and set 20k down,PU to 260k which was 35k over.Jars bled back to 245k and went off.Fish came free.PU to 6,602'.Put pump back on at 5 BPM with a 50 psi increase.Go back down and string pressured up at 6,627'.PU and string pulled free with 20k overpull.PU to 6,590'and circ hole clean.Set Kelly back and POOH slow.Inspect BHA#36-Marks on 3.25"bullnose of the 3.88"grapple indicated it engaged packer^'1/2"-bullnose disengaged when string was picked up.MU BHA#37=Spear w/3.198 grapple,2 XOs,4 boot baskets,Bit sub,Bumper sub,Oil jars,XO,9 DCs,Acc jars,XO=338.45'.RIH with BHA#37-fill pipe at 3,180'/ 6,591'.Establish parameters-puw 225k-sow 135k at 5 bpm-1570 psi.Tag at 6,626'set down 10k-sd pumps wt fell off-set dn 10kat 6,629'.PU with 35k overpull, jarring"'125 x at 35k-75k over, jar with pumps on/off,no movement.Jar down,no movement-pull up to 325k straight pull after jar tripped with pumps on-no movement. Release from packer.Break Kelly.Blow down, stand back, conduct post jarring rig inspection.Fluid loss 1.5 bph. POOH to inspect BHA.Fluid loss today 3%KCL=37 bbls.Total 3%KCL loss= 1414 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-2 BPH.Report Time Loss Rate=1.5 BPH. Recovered 103 lbs from Ditch magnets.Ditch magnets total=3249 lbs.Recovered 13 lbs from Boot Baskets.Boot Basket total=816 lbs.Total metal recovered=4065 lbs. • Hilcorp Alaska, LLC Hileorp Afaka,IAA: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/18/13-Friday POOH with spear.Stand back DCs,Lay dn spear assem.PU BHA#38=8-1/2"X 6-1/2"Crown washover shoe,XO bushing,Top sub,4 boot baskets,Bit sub,Bumper sub,oil jars,XO,9 DCs,XO.=327.17'.RIH to 3,200'.Fill pipe.RIH to 6,595',Fill pipe and get parameters. Tag at 6,625'.Mill over packer f/6,625't/6,629'using various parameters of weight-rpm-pump rate-rubber was observed across the shakers.Circulate and condition well-no more rubber across shakers-blow down and rack back Kelly.POOH for BHA change.LD BHA -recovered 5-3/4"OD x 4-1/4"ID x 5-1/4"long (collar/sleeve?)from inside wash shoe,pieces of slips from boot basket-recovered 70 lbs metal from boot bskts. Fluid loss 1 bph.MU BHA#39-Spear w/3.198 grapple,2 XOs,4 boot baskets,Bit sub,Bumper sub,Oil jars,X0,9 DCs,Acc jars,XO=338.45'.Service rig.RIH with BHA#39.Fluid loss today 3%KCL=47 bbls.Total 3%KCL loss=1461 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-2 BPH.Report Time Loss Rate=1.5 BPH.Recovered 63 lbs from Ditch magnets.Ditch magnets total=3312 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=816 lbs.Total metal recovered=4127 lbs. 10/19/13-Saturday RIH to 6,590'with BHA#39=Spear assem with 3.198 grapple,Two XOs,4 Boot Baskets,Bit Sub,Bumper sub,Oil jars,X0,9 DCs,X0, Acc jars,=338.45'.Fill pipe,work dn to fish circ at 4 BPM 1020 psi. Engage top of packer at 6,625',Slack off to 6,629'and Pump pressure increased 100 psi,PU with very slight overpull,Work up and down several times looking for a better indication that we have the fish.Circ Bottoms up.POOH.Drained the stack and backed out the lockdowns before we pulled through the wear ring.Pulled wear ring on Packer.Lay dn 2.84'of fish [packer]and one dye off packer.Break dn and clean Boot Baskets,Recovered 22.5 lbs of iron from boot baskets.Set wear ring back in.Strap and PU BHA#40=8-1/2"X 6-1/2"Crown wash over shoe,XO bushing w/fingers,XO bushing,1 jt 7-5/8"wash pipe,7-3/8"VACS tool,XO,4 boot baskets,Bit sub,Bumper sub,oil jars,XO,9 DCs,XO,Accel Jar=373.74'. RIH with BHA#40-fill pipe at 6,595',Obtain parameters-puw 230k-sow 140k-rtw 167k-10 bpm/1500 psi-washing from 6,595'to 6,627'.CIRC/cond shakers blinding off with sand.Milling from 6,627'to 6,640'using various parameters of pump rate-wob-rotating wt-"2 bbls sand back and red and black cement rubber plug on top of flt collar.Circ/cond well-break off-blow down-stand back Kelly-monitor well 2 bph loss. POOH to inspect BHA.Fluid loss today 3%KCL=42 bbls.Total 3%KCL loss=1503 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1.75 BPH.Report Time Loss Rate=1.75 BPH.Recovered 225 lbs from Ditch magnets.Ditch magnets total=3537 lbs.Recovered 70 lbs from Boot Baskets.Boot Basket total=886 lbs. 10/20/13-Sunday Break dn and clean BHA.Recovered 1'off the bottom of the packer,all the packer dyes and 94 lbs from the boot baskets.Also recovered 2'of 6"cmt cores.Clear floor.Pull wear ring and rig up to test BOPs.Test all BOP equip to 250 psi low and 2500 psi high,All tests passed.Witness of test was waived by Jim Regg,AOGCC-but required e-mail of our test chart along with our test form.Rig down test equip and set wear ring.PU BHA#41=8-1/2"Eight blade junk mill,4 boot baskets,Bit sub,Bumper sub,Oil jars,XO,9 DCs, XO,Acc jars=335.34'.RIH to 3,631',fill pipe,slip and cut drilling line 125'. RIH t/6,619',fill pipe,tag at 6,639'.Mill f/6,639't/6,681'. Float collar was at 6,640'and cmt was from 6,641't/6,681'.Circ hole clean.POOH to BHA at 1,500'.Fluid loss today 3%KCL=29 bbls. Total 3%KCL loss=1532 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1.2 BPH.Report Time Loss Rate=1 BPH.Recovered 197 lbs from Ditch magnets.Ditch magnets total=3734 lbs.Recovered 94 lbs from Boot Baskets.Boot Basket total=979 lbs.Total metal recovered=4713 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 1a Cy0perationt: .a 10/21/13-Monday Finish POOH and lay dn BHA.Recovered 32-1/2 lbs from boot baskets.Service rig,inspect drwks,hawk jaw,blocks,crown,Kelly, rotary table,rig tongs,slips,and elevators.Clean rig floor.Rig up E-Line to run logs.RIH w/CCL,Gamma Ray,#25 junk basket,and 8.156 GR.Tag at 6,683'WLM,correlate with old log and adjust depth to 6,677'.Change out tools,PU a GE caliper log and RIH to 6,200',Run caliper log to surface.Rig down wire line.Run 2 stds of 6"DCs,PU RTTS and RIH to 2,080',Set packer,Pressure up on csg to 2300 psi,Hold pressure for 30 min and record on chart.POOH to RTTS,PU storm packer on top of RTTS,RIH 1 std,Set packer and test to 1500 psi.Release from storm packer and POOH.Drain stack,Pull wear ring,Nipple dn BOPs in prep to Pick Stack.PU stack. Remove old tbg spool,dress csg stub for new tbg spool and install spool.Tighten bolts on spool.Fluid loss today 3%KCL=23 bbls. Total 3%KCL loss=1555 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-1.2 BPH.Report Time Loss Rate=1 BPH.Recovered 10 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 32 lbs from Boot Baskets. Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. 10/22/13-Tuesday Finish tightening spool.Test tbg spool to 2500 psi for 15 min.Nipple up BOPs.Install new target Ts on Kill and Choke lines.Get all the BOP equip hooked back up.Pickup test equip,install test plug and prep to test stack.Perform Shell test on stack,testing all flanges. Test to 250 psi low and 2500 psi high.Everything held.Lay down test tools and install wear ring.PU storm packer retrieving tool on stand.RIH engage storm packer,release RTTS.Monitor well.POOH and lay dn RTTS and Storm Valve.Stand back 1 DC.MU bit sub and 8-1/2"bit on DC and RIH.Run two more DC and continue RIH on DP to 6,681,no fill.Circ bottoms up w/#1 pump while rigging up to displace,Pumping dirty KCL to production w/#2 pump.Continue pumping dirty fluid to production w/#2 pump while displacing well with clean KCL w/#1 pump. Building Volume while pumping.Flush all surface equipment and tankage to production.Shipped 740 bbls to production.Monitor Well with no flow or losses.TOOH from 6,681'to 280'.Stand back DC's.Lay down BHA.Service rig, service and inspect Hawk Jaw,Draw works,Crown,Blocks,Kelly,Rotary Table,etc..Wait on perf guns.Continue cleaning pits.Fluid loss today 3%KCL=0 bbls.Total 3%KCL loss=1555 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average- 0 BPH.Report Time Loss Rate=1.5 BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. 10/23/13-Wednesday Continue cleaning pit equip.Install new 200 mesh screens on shakers.Perform derrick inspection.Rig dn slickline.Waiting on Perf guns.Guns to be loaded out from OSK @ 06:00 call out.General house keeping.Fluid loss today 3%KCL=0 bbls.Total 3%KCL loss= 1555 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=1.5 BPH Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs. Total metal recovered=4755 lbs. 10/24/13-Thursday Make up safety jt and stand back off drillers side.Rig up to PU guns.Have PJSM with everyone involved.RIH picking up 4-5/8",6 SPF ✓�P Millennium perf guns from#1 to#66.Continue to RIH picking up 4-5/8",6 SPF Millennium perf guns from#66 to#150.PJSM on picking up guns.Continue to RIH picking up 4-5/8",6 SPF Millennium pert guns from#150 to#202. String Wt 67K,Change over to 2 7/8"handling equipment. Pick up Model IIID Firing Head, 1 jt 2-7/8"eue, Ported Fill Disk, 1 jt 2 7/8"eue,RA Sub,XO to DP.RA Sub to Top Shot=99.62'.Change over to 5"DP handling equipment.Break Down and lay down safety joint.TIH with Perf Guns on 5"Drill Pipe from 4,662'to 6,652'(21 stds).Pick Up single,Tag bottom @ 6,684'DP Measurement.Lay down single.PU 10'pup,space out and park @ 6,659.65'(bottom shot @ 6,658.41)(6.41'Deep)UP WT 155K.DN WT 110K.Rig up E-Line to correlate guns on depth. Fluid loss today 3%KCL=0 bbls.Total 3%KCL loss=1555 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 0 bbls.Daily Loss rate average-0 BPH.Report Time Loss Rate=1.5 BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/25/13-Friday Run gamma on E-line and correlate.Send log to town to confirm guns 1'high.Town confirmed.Rig up to drop bar and pump.Set guns on depth.Rig up take fluid level shots.Check to make sure fluid level recorder was working,Drop bar,Guns fired at 0843 hrs with a very good indication of ignition.Fluid level fell out of sight.Attempt to shoot fluid levels for 10 min but couldn't get a good reading. Fill hole,it took 24.5 bbls to get fluid back to surface.Circ through choke manifold getting gas and oil back over shakers.Had a high of 530 units.Loss rate started at 72 BPH and after a circ it went down to 20 BPH.Loss rates were while circ at 5 BPM and 300 psi.Raise mud wt to 8.8 while still circ through the choke at 5 BPM 300 Psi,Gas units came down to 340 units,Spot balanced 15 bbl 10.7 ppg size salt pill and shut pump down.Monitor well for 1/2 hr.Had 100 psi SICP.Weight up hole and surface system to 9.8 ppg.Losses increased again to 28 BPH while circulating through the choke.Shut down pump,open annular and monitor well with 20-24 BPH static losses.Pump and spot 15 bbls sized salt pill circulating conventional with 135 max gas units.Circulate across top of the hole through the kill line while waiting on sized salt pill to fall.Build 9.8 ppg volume,Fill trip tank with 9.8 ppg while circulating across the top of the hole with the kill line to the active.Static losses @ 28 BPH @ 23:00 hrs.Pump and spot 15 bbls sized salt pill. Rig down circulating equipment,lay down 10'pup joint.Prep to TOH with 5"Drill Pipe.Static losses @ 35 BPH @ Midnight.TOH standing back 20 stands 5"Drill Pipe.Install floor valve in top of stand 21 in hole.Make up safety joint for laying down guns and monitor well.PJSM on laying down guns.POOH and stand back stand 21.Static losses @ 18 BPH.Change over to 2-7/8"handling equipment.Lay down firing head assembly.POOH laying down 4-5/8"perf guns.(30 guns out).Static losses @ 12 BPH @ 03:45 hrs.Make up safety joint. Monitor Well.Fluid loss today 3%KCL=180 bbls.Total 3%KCL loss=1735 bbls.Sized Salt Pill 45 bbls.Total sized salt pill loss 45 bbls. Daily Loss rate average-7.5 BPH.Report Time Loss Rate=12 BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. 10/26/13-Saturday POOH laying down guns.Had a total of 54 guns laid down.Install safety jt.Service rig and clean floor.POOH laying down guns.Have 127 guns laid down at 1500 hrs.Hole taking 2 BPH.Shut down and move some mud products to the pill pit area.Building 40 BBL size salt pill.Continue POH laying down guns.Have 167 perf guns laid down.Secure well.Pressure wash rig floor.Monitor well and hole taking 2 BPH.Continue POOH laying down perf guns from 840'to surface.Rig down perf gun handling equipment.Lay out and tally 2- 7/8"tubing and jewelry.Clean rig floor with pressure washer. Continue to clean pit.Pull wear bushing.Loss rate @ 2BPH Static @ 03:00 hrs.PJSM on running completion.Rig 2-7/8"handling equipment.Run in hole picking up 2-7/8",6.5#,EUE Mod.8rd tubing completion from surface to 1,050'.Losses @ 2 BPH.Fluid loss today 3%KCL=61 bbls.Total 3%KCL loss=1796 bbls. Sized Salt Pill 45 bbls.Total sized salt pill loss 45 bbls.Daily Loss rate average-2.5 BPH.Report Time Loss Rate=2 BPH.Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. t Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-32 50-733-20301-00 177-018 9/20/2013 10/29/2013 Daily Operations: 10/27/13-Sunday Continue RIH picking up 2-7/8"completion to 3,930'.PU Chemical injection mandrel.Rig up sheaves and hook up control line. Continue RIH picking up 2-7/8"completion to 5,649'. Install SSSV and rig up control line spool.Test control line to 5000 psi for 15 min. Continue RIH picking up 2-7/8"completion,installing clamps and bands on control lines.MU hanger,install control lines through hanger,Pressure up on SSSV,land out hanger,UP WT 54K,DN WT 47K,Weight on hanger 29K.Run in lockdowns.Ran 2-7/8",6.5#, EUE Mod.8rd tubing completion as follows:X nipple w/2.313"profile w/RHC plug installed,9-5/8"DLH Hyd Set PKR,1 jt tbg,Baker Mod CMD Sliding Sleeve w/2.312"BX Profile,15 jts tbg,9-5/8"DLH Hyd Set PKR,1 jt tbg,Baker Mod CMD Sliding Sleeve w/2.312"BX Profile,101 jts tbg,9-5/8"DLH Hyd Set PKR,Chemical Inj Mandrel,1 jt tbg,Gas Lift Mandrel,51 jts tbg,TE-5 Safety Valve w/2.312'BX' Profile,8 jts tbg,Tubing Hanger w/Pup.Ran 178 jts Total.Pressure up down tbg to set packers.When pressure reached 2900 psi we had a good indication of packers setting.Continue pressure up to 3500 psi and hold for 15 min.Bleed pressure off.Pressure up down ann to 1500 psi to test upper packer for 5 min.Good test bled press off.Pull landing jt and set BPV,Nipple down BOPS,N/D and lay down Drill Riser.Continue cleaning pits and all associated equipment.Land and N/U Tree.Test TBG Head adapterte-5000-psi.Test good.Pull BPV and set TWC.Test Tree to 5000 psi,Test good.Pull TWC. Assist production in installing production Choke.Finished cleaning pits and started building 3%8.6 ppg KCL fluid.Clean up and organize rig areas.Prep rig for skid to A-16.Waiting on weather to transport slick line operator to pull DGLV,set GLV,retrieve RHC and open sleeves.Note:Still on weather hold due to high winds and poor visibility.Fluid loss today 3%KCL=34 bbls.Total 3%KCL loss=1830 bbls. Sized Salt Pill 0 bbls.Total sized salt pill loss 45 bbls.Daily Loss rate average-2 BPH.Report Time Loss Rate=0.Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs. Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. 10/28/13-Monday Still on weather hold.Mixing new 3%8.6 ppg vol for next well.Clean up and PU work areas.Prep rig for skid to A-16.PU 3"lubricator and rig up on A-32.Rig up slickline,test lubricator to 2000 psi.RIH to pull Bar Drop.POOH with Bar Drop.Lost string wt @ 300'(SSSV Depth.)Wire parted at rope socket.Discovered the control lines for the SSSV and Chemical Injection Mandrel were reversed when tied in to Production.The Chemical Control Mandrel has rupture disc good for 5000 psi.Pressure up to 3000 psi on Chem control Line assuming it was opening the SSSV.Corrected surface line hookup of control lines.Call out for fishing tools for slick line.Slick line tools on board @ 04:00.Rig up slick line to fish Bar Drop tool string. Reconfigure slick line lubricator for longer tool string.PT Lubricator. Fluid loss today 3%KCL=Obbls.Total 3%KCL loss=1830 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 45 bbls.Daily Loss rate average-2 BPH.Report Time Loss Rate=0. Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. 10/29/13-Tuesday RIH with slickline and engage slickline tools that were dropped down on RHCP and drop bar.POOH and recover slick line tools but drop bar sheared pin and stayed down on RHCP at 5,947'.Re-dress tool and RIH with a 2"JDC,latch onto drop bar and POOH.Recover bar.RIH to pull dummy valve&installed live valve GLM at 1,973',and change the dummy valve from the chemical injection mandrel to a live valve at 2,033'slm. RIH w/at 2-3/8 GS to 5,947'and pull the RHC plug from the x nipple at 5,947'.RIH w/BO self releasing sleeve shifting tool to 5,344'tap three times,pass thru with no problems,continue to 5,900'and did not tag sliding sleeve at 5,882'. POOH check tool found same sheared,repin w/steel pin RIH and shift sliding sleeve at 5,329'and 5,882'POOH w/no problems. Rig down slick line and turn well over to production. Release rig @ 24:00 hrs.Fluid loss today 3%KCL=Obbls.Total 3%KCL loss=1830 bbls.Sized Salt Pill 0 bbls.Total sized salt pill loss 45 bbls.Daily Loss rate average-2 BPH.Report Time Loss Rate=0 Recovered 0 lbs from Ditch magnets.Ditch magnets total=3744 lbs.Recovered 0 lbs from Boot Baskets.Boot Basket total=1011 lbs.Total metal recovered=4755 lbs. A--3z- Rb 1770Iejb .Reg g, James B (DOA) From: Ted Kramer [tkramer@hilcorp.com] Sent: Monday, October 28, 2013 7:03 PM To: Regg, James B (DOA) Cc: Stan Golis; Chet Starkel; Larry Greenstein; Juanita Lovett Subject: Hilcorp Position on Monopod A-32 Not Testing BOP Annular Before Running the Completion Attachments: 20131028182149703. pdf SCANNED OCT 0 9 216 Jim, As requested in our phone conversation this afternoon I am writing this to document Hilcorp's position as to why we did not test BOPE before running the completion on A-32. Simply put, Hilcorp did not test BOPE prior to running the completion because we were not in a "Well Control" situation. No "Kick" was taken, and no unusual "Gain" to the wellbore was realized. The Well Site Manager on location, Marvin Rogers, contacted me Friday evening and told me that after perforating earlier that day that we had spotted a 15 bbl sized salt pill because well A-32 had taken some fluid after the Tubing Conveyed Perforating (TCP) guns were fired and that we had closed the annular in order to circulate off perf gas through the gas buster. We also discussed weighting up our workover fluid to control the gas in case there was an influx into the well beyond the expected perf gas generated after firing the TCP guns. Lastly, we discussed notifying the Commission as a precautionary measure to let them know what was occurring just in case we encountered more than perf gas. I instructed Mr. Rogers to send an e-mail to the AOGCC (as a precautionary measure) to let the AOGCC know what had occurred so far. Mr. Rogers then sent the e-mail dated October 25, 2013 5:44 PM Note: Closing the annular and circulating TCP gas through the gas buster is a common practice in the Cook Inlet Operations. The reason it is done in this manner is because it is common the get a small gas "burp" when circulating off perf gas. This "burp is small and does not last very long and then dissipates. This coupled with the small size of our platforms make using the gas buster necessary to insure that no carryover from the "burp" escapes the platform and lands in Cook Inlet. Mr. Rogers received no reply from the AOGCC overnight so he sent a second e-mail On Saturday morning with an update on what was occurring with Monopod Well A-32. Although Mr. Rogers begins the e-mail with the phrase, "Update on our well control issue:" one only has to read the next sentence to realize that there was no "well control" issue. We increased our weight to 9.8 PPG and the well was dead. We then opened the well up and spotted 2 more sized salt pills to control fluid loss and came out of the well with the TCP guns. On Saturday October 26, 2013 at 7:31 PM, Mr. Rogers sent a third e-mail to the AOGCC notifying the Commission that The following day was our normal BOPE testing day but that we would have our completion landed and BOPE's nippled down by that afternoon so we would in essence not be testing BOPE's. On Monday October 28, 2013 at 9:28 AM, Jim you sent an e-mail to Mr. Rogers asking him to send you the results of the BOPE testing after the perf guns were pulled and before running the completion. You stated in your E-mail that we were, "required to test BOPE used for well control before next wellbore entry (running 'completion)". Hilcorp maintains that we were not required to test BOPE because there was no reason to. In summary, Hilcorp maintains that there was no "Well Control" situation encountered on Monopod Well A-32 nor was there any "routine use of the equipment may have compromised its effectiveness", therefore, 20 AAC 25.285 (f) (2) does not apply. Hilcorp also states for the record that we acted in good faith when we apprized the Commission what was occurring on the Monopod Well A-32 because we believed that the potential for a "Well Control" situation existed. However, good planning and execution on Mr. Rogers part prevented a "Well Control" situation from occurring (email chain attached). Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 Regg, James B (DOA) 1-7-76160 From: Marvin Rogers - (C) [mrogers@hilcorp.com] Sent: Monday, October 28, 2013 9:41 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Schwartz, Guy L (DOA) Subject: RE: Landing completion before BOP test due Well I guess we failed that test! We did not re -test the BOPS after we got the guns out of the hole. We turned around and ran our completion and had it landed out at 1700 hrs on 10-27-13. 1 am very sorry we failed to do the test before we ran completion I know that ignorance of the rules is no excuse. Marvin Rogers From: Regg, James B (DOA) [mailto:jim.regg(cbalaska.gov] Sent: Monday, October 28, 2013 9:28 AM To: Marvin Rogers - (C); DOA AOGCC Prudhoe Bay Cc: Schwartz, Guy L (DOA) Subject: RE: Landing completion before BOP test due Send me results of BOPE testing done after pulled perf guns and before running completion. Required to test BOPE used for well control before next wellbore entry (running completion). Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Marvin Rogers - (C) [mailto:mrogers@hilcorp.com] Sent: Saturday, October 26, 2013 7:31 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Subject: Landing completion before BOP test due Monopod A-32; Our Weekly BOP test is due tomorrow the 27`h, but we should have our completion landed and start to nipple down BOPS by tomorrow after noon. Currently laying down the last few perf guns. Thank You Uffilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com ] -7 Jo I Regg, James B (DOA) From: Marvin Rogers - (C) [mrogers@hilcorp.com] Sent: Saturday, October 26, 2013 7:56 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Ted Kramer Subject: RE: Wt up to kill well after pert on A-32 Update on our well control issue: By 2100 hrs last night we had our wt up to 9.8 PPG and the well was dead. We opened everything up and spotted 2 more size salt pills because our loss rate was up. Currently POH laying do guns. Hil.corp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com From: Marvin Rogers - (C) Sent: Friday, October 25, 2013 5:44 PM To: aogcc.inspectors@alaska.gov; Regg, James B (DOA) (jim.regg(5alaska.go Cc: Ted Kramer Subject: FW: Wt up to kill well after perf on A-32 Gentlemen: We are working A-32 over on the Monopod. We finally got the well cleaned out to 6681'. We have done all our well work with 8.6 KCL and the well has been taking 1 BPH. We ran 4560' of guns in the hole and shot them off at 8:43 this morning. (This put our circ point at 2026']. The fluid [8.6 KCL] fell in the hole and it took 24.5 bbls to get the hole full. After circ about 10 min we started seeing a little gas in the ann so we shut the hydril and circ through our choke manifold. As we continued to circ the gas units came up to 500 units and we started seeing a lot of oil at the shakers. We decided to wt up and when we got to 8.7 the gas went down to 375 units. We continued to wt up to 8.8 and the gas units went down to 340 units. At that point the hole was taking 20 to 25 BPH losses. We decided to spot a balanced 15 BBL 10.7 ppg size salt pill and shut the well in to let the pill find the thief zone. After one hr of being shut in the ann had built up to 100 psi. We opened the choke slightly and bled the gas off down to 35 psi and started getting fluid. We shut the choke back in and brought the circ system wt up to 9 ppg over the next % hr period. The pressure built back up to 95 psi. We then started to displace the well down to 2026' with our 9 ppg KCL holding 100 psi back pressure on the choke. Our losses to the well went down to 8 to 10 BPH. When we got bottoms up the gas units went up to 2000 units and we started getting about 50 % oil over the shakers. This only lasted for a few minutes and the gas and the oil died down. The gas units only went down to 350 to 400 and seem to be hanging there. Currently we still have the hydril closed, circ through the open choke, and are weighting our circ system up to 9.8 ppg. We calculated that 9.7 should bring our wt up to hold back the formation, so we decided to wt up to 9.8 to give us a safety factor. We will make sure the well is dead before we start POH and we will shut down and monitor the well again 1 std before we get to the guns. We also have a safety jt ready so we can make it up, run it into the stack and shut the well in while we while we are laying down the guns. Thank You U-lilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E-Mail: mrogers@hilcorp.com z4( S)ak At 3Z pm 17 1 080 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, October 21, 2013 2:36 PM (� � i 0 f 21 k l 3 To: 'Marvin Rogers- (C)' Subject: RE: Monopod rig 56 A-32 BOP test Explanation is sufficient. No failures. Jim Regg AOGCC 333 W.7th Ave,Suite 100 2 d)1 Anchorage,AK 99501 SCANNED 907-793-1236 From: Marvin Rogers - (C) [mailto:mrogers(ahilcorp.com] Sent: Monday, October 21, 2013 1:23 PM To: Regg, James B (DOA) Subject: RE: Monopod rig 56 A-32 BOP test Jim -We have a 4 hr chart recorder and we raise the pin in between tests. Sometimes if we have troubles we will have to use 2 charts but if everything goes smooth we can get it all on one chart by raising the pin. We will make a note on the report stating this. -This was a test pump operator issue. He was running out of water in his test pump tank so they stopped to fill it. -On test#4 they did get some air in there when we swapped the valves. Had to work the air out to get a good test. -When we start the test pump we have a regulator at the pump that is backed off.The pump operator tightens down the regulator to increase the pressure. As the pressure increases it gets erratic jumping from 200 to 400 psi.To dampen this we put a needle valve on the sensor for the chart,and pinch it back to restrict the flow. If it is not pinched back enough it will look like it's way past the required pressure.You can see this on almost every test. It looks like it goes a couple hundred psi higher than required. I apologize for the confusion on the chart. I can personally guarantee all our BOP equip passed all the tests. If you would like me to change the#4 CMVs to fail pass I can change and re-submit. We will strive to eliminate these issues in the future. Marvin Rogers From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, October 21, 2013 12:06 PM To: Marvin Rogers - (C) Subject: RE: Monopod rig 56 A-32 BOP test Appears the rig used a 4 hour chart for 8 hour test. Should be explained when the recorded time or pressure does not match the chart. Explain pressure signature at beginning of high pressure test#1 (bag,dart, demco kill, CMV 15, 16,5); stopped and held at approx 1000psi before bumping up to approx 2700psi. Appears to be several attempts to get a passing low pressure test on CMVs 2,3,4,6 (test#4)—fail-pass? Low pressure test on blinds (test#5) cycled to over 500psi twice before locking into good solid 250psi test; what was going on here? Jim Regg AOGCC 1 • • • 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-7934236 From: Marvin Rogers - (C) [mailto:mrogers@hilcorp.com] Sent: Sunday, October 20, 2013 3:44 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: Monopod rig 56 A-32 BOP test llHilcorp Alaska, LLC Marvin Rogers DSM Monopod Platform [907] 776-6675 E-Mail: mrogers @hilcorp.com 2 • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION (� BOPE Test Report Submit to: jim.regq nalaska.00v AOGCC.Inspectors alaska.gov phoebe.brooksaalaska.qov Contractor: Kuukpik Rig No.: 56 DATE: 10/20/13 Rig Rep.: Knutson/Wares Rig Phone: 907-776-6675 Rig Fax: Operator: HILCORP Op. Phone: 907-776-6670 Op. Fax: Rep.: Rogers/McInnis E-Mail mrogers @hilcorp.com Well Name: Trading Bay St A-32 PTD# 1770180 - Operation: Drlg: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: 250-2500 • Annular: 250-2500 - Valves: 250-2500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P - Well Sign P Upper Kelly 1 P Housekeeping: P - Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 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 P P Annular Preventer 1 135/8" 5M P Pit Level Indicators P P #1 Rams 1 27/8-5-VBR P Flow Indicator P P - #2 Rams 1 135/8'Blinds • P • Meth Gas Detector P • P #3 Rams 1 27/8 5M P H2S Gas Detector P P • #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3-1/8" 5M • P Inside Reel valves 0 NA HCR Valves 2 3-1/8" 5M P Kill Line Valves 2 3-1/8" 5M P • Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 • P - CHOKE MANIFOLD: Pressure After Closure 1350 - P - Quantity Test Result 200 psi Attained 40 - P - No. Valves 16 P Full Pressure Attained 195 - P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P • Nitgn. Bottles (avg): 2400 CH Misc 0 NA ACC Misc NA / Test Results Number of Failures: 0 Test Time: 8.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: jim.regg @alaska.gov Remarks: Tested upper pipe rams and bag on 5"and 2 7/8" 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Regg Date 10/19/13 Time 07:13 AM Witness Test start 08:00 Finish 1600 Form 10-424 (Revised 11/2012) 2013-1020_BOP_Kuukpik56_TB_State_A-32.xlsx • • BOPE Test Chart—Monopod Rig 56 Trading Bay State A-32 PTD 1770180 10/20/2013 OOP rest. order J0-2a-J3 f'rsf Tests ,done l.>I'M 5" 1 ,8a8, IIArf t/a1vc, Demeo 101/,'19e, eilt s 15, /d, 5 2 lifter /Qams, 7-.774/, meg K;//, c/W5 3,12, 13, 111-, q 3 nmu«l 11;11 Pt1v5 /, 10, I/, 7 en'?1/5 2, 3, 4L, 5,1 Mnis last 3 Tests ,p&r2P WA 278 ‘,1 l�e fJer' iJ Gl r+�s, /�C14 'A 4e, lower ke/fy 7i j3ag, 1'1412cral CAeke S /vw6r /Q�rn s, W,p er ke//I • 2013-1020 BOP_Kuukpik56_charts_TB_State_A-32.docx Page 1 of 2 0 • 1 10 N NNN ,---'',-- „,..-- ---,...40001-- --- I-- -_ - - - , -- -- ,- ,\ . ..,. . \,. ./ voct- % ,/ /' „,, As, - - - \, -- 0,1-__--- ___ ' _ - ..• '•-•\;\< \ I \,‘. \ \ --' L-0 / ,,,,A,..,. \-• -,, s,„ \ \, , , ' , , . . . mP-5000-AHR t4C , - , ,GHAR, ' - ' ■ \ \ ' \ \ '1, \ '. I ■ , . 'F' -r AKFN . , _ . •--_____- - --------__. i i 6 4- ial ---------„,: , , , 110fio4 5&ore t 10.2o-13 L , - - -„, \ //-60 - / // , / - 7 \ - .--:-:------;0-°- - -.1,----/ .../, - 7 y N / _ - - - 7 / -- - 7, - ---,. ----...„---„, - - / ---- --- ---- -------r- - - ,--,- ■.„, ,., "---. / '^. -------- ___ ___-f OCO'C' __-,---- --- '."---./ ---"----- -----i-- ----±- _------- 1- ----' /-- --------- , 3 V 20 13-1020_BOP_Kuukpik5 6_charts_TB_S tate_A-32.docx Page 2 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, September 19, 2013 8:48 AM To: 'Dan Marlowe' Cc: Ted Kramer; Juanita Lovett; Bettis, Patricia K (DOA) Subject: RE: A-32 PTD 177-018 - Sundry update to # 313-434 Dan, My apologies for not following up on email. The Commission approves your updated completion with straddle packers to isolate different sections of the perforated zones as proposed in the attached well sketch. The sundry conditions also required a spacing exemption to be approved before production commences Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office SCANNED OCT 0 9 2014 From: Dan Marlowe [ nailto:dmarlowe(a hilcorp.cor ] Sent: Tuesday, August 27, 2013 2:17 PM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Juanita Lovett Subject: A-32 PTD 177-018 Guy This is the next well in our Monopod program. I have attached the Sundry we submitted on 8-8-1.3 that you are currently reviewing We had a completion design change that will allow us to selectively produce the zones — see attached revised schematic The procedure will remain the same other than steps 21 & 22. Infested of running in with a permanent packer and then stabbing into the seals, We will now run in with hydraulic set packers and land the completion then pressure up to set the packers. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarloweCc)-hilcorp.com HilcoM A Company Built on Energy PROPOSED Trading Bay Unit Monopod Platform Well # A-32 API # 50-733-20301-00 Completed: Future RKB to TBG Head = 37.90' MAX HOLE ANGLE = 30° @ 4600' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 94 1 Driven 19.12" 42' 221' 16" 65 H-40 BTC 15.25" 39' 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) 39' 4451' 9-5/8" 47 N-80 BTC -KC 8.681" 39' 6724' X Nipple 10 +5,931' WLEG ±4.464' Future Tubing: 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 2-7/8" 6.5# L-80 8rd EUE 2.441 37.9' 1 ±5,931' CZN ±4,840' ±4.86 ±4,597' ±4,615' Future JEWELRY DETAIL NO. Depth Length ID Item Top (TVD) 37.90 .80 6.184 10" TBG Hanger Cameron DC -B 3-1/2" EUE BIRD Type 1 BPV Condition BZN ±2,094' 1 ±300' SSSV (2875-A-09 Cannon Clamps) 2 ±1982' GLM 3 ±2034' Chemical Injection Mandrel (2875-A-02 Cannon Clamps) 4 ±2044' Packer 5 ±5,369' Sliding Sleeve 6 ±5,400' Packer 7 ±5,889' Sliding Sleeve 8 ±5,920' Packer 9 ±5,930' X Nipple 10 +5,931' WLEG Perforation Details Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amount Condition BZN ±2,094' ±2.120' ±2,058' ±2,082' Future BZN ±2,478' -2.690' ±2,422' ±2,625' Future BZN ±3.494' 9 r ±3,377' ±3,462' Future C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 CZN ±4.; ±4,378' ±4.464' Future 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 CZN ±4,812' ±4,83(, ±4,227' ±4,589' Future CZN ±4,840' ±4.86 ±4,597' ±4,615' Future CZN ±4,960' ±.: ±4,705' ±4.714' re C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated CZN ±5,092' ±5,110' ±4,823' ±4,839' Future CZN ±5.116' ±5.142' ±4.844' ±4,867' Future C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs CZN ±5,186' ±5,216' ±4,907' ±4,934' Future CZN ±5,250' ±5,260' ±4,965' ±4.974 Future C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs CZN ±5,292' ±5.34£ ±5.003' Future D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN ±5,430' ±5.46(" ±5,127' ±5.15: ure DZN ±5,520' ±5,56(' ±5,208' 'ure D 5,530' 5,560' 5,217 5,244 30 Isolated DZN ±5.57 ±5.610 ±5,259' ±5,289' Future D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated DZN ±5,638' ±5,67-. ±5,315' ±5,347' Future DZN ±5,694' ±5.722' ±5,365' ±5,390' Future DZN ±5,758' ±5,824' ±5,422' ±5,481' Future D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs DZN :10' ±5.918' ±5,505' ±5,566' Fuh, D 5,852' 5,912' 5,507 5,560 60 Isolated EZN ±5.947' ±5.987' ±5,592' ±5,627' Future EZN ±6.004' ±6,026' ±5,642' ±5,662' Future EZN ±6,032' ±6,089' ±5.667' ±5,718' Future D 6,050' 6,052 5,683 5,685 2 Block Squeze EZN ±6,134' ±6,150' 58' ±5,772' pure HEM ±6.250' ±6,430' 60' ±6,02C' Future Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated WF ±6.614' ±6x6- 16,184' ±6,21, Future Updated by: JLL 08-20-13 VOF T4 • • I%% sv THE STATE Alaska Oil and Gas ®f l 1s Conservation Commission rk,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF ��. ,>r, Anchorage, Alaska 99501-3572 ALAS ��� 1� 1�2. �t Main: 907.279.1433 og Fax: 907.276.7542 Ted Kramer Sr. Operations Engineer l -1,0 g Hilcorp Alaska, LLC I r 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C & Hemlock Oil Pools, Trading Bay ST A-32 Sundry Number: 313-434 Dear Mr. Kramer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. This approval is subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. Hilcorp Alaska, LLC assumes the liability of any protest to the spacing exception that may occur. Please note other 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, G ,D Cathy . Foerster Chair DATED this it-day of September, 2013. Encl. ,� , E I V E D • III STATE OF ALASKA i� © AUG Q 8 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO G CC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod El " Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El • Pull Tubing O 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 Exploratory ❑ Development p 177-018 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20301-00 • 7.If perforating: 8.Well Name and Number: I What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes IJ No❑ Trading Bay ST A-32 • 9.Property Designation(Lease Number): 10.Field/Pool(s): • ADL0018731 ' Trading Bay/Middle Kenai C&Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6,750' • 6,305' 4,960' 4,705' 4,960',6,009',5,075'&6,092' 6,540'&4,934' Casing Length Size MD TVD Burst Collapse Structural Conductor 221' 20" 221' 221' Surface 502' 16" 502' 502' 1,640 psi 630 psi Intermediate 4,451' 13-3/8" 4,451' 4,256' 3,090 psi 1,540 psi Production 6,724' 9-5/8" 6,724' 6,282' 6,870 psi 4,760 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4590'-4690',4800'-4860' 4377'-4464',4562'-4615' 2-7/8" 6.4#N-80 4,434' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model D,Baker SC-1,Otis"VST"Packers/ Otis SSSV 4901'(MD)4652'(ND);4470'(MD)4272'(ND);4391'(MD)4203'(ND)/321'(MD)321'(ND) 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development El Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/1/2013 Commencing Operations: Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer@hilcorD.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature�7 � �� Phone (907)777-8420 Date 8/8/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 s2•/J� to, / Plug Integrity ❑ BOP Test V( Mechanical Integrity Test ❑ Location Clearance ❑ C_I/ Other: Z.570Ors,,/3 pr° 1 7'K `"/b l/'c(Judi-0 Pt CGIc)m WCV ip �/ pc^ u-cJ 7' -C-nu-e-ihA 'eJ? /1.604--- q p Spacing Exception Required? Yes 1.1 No ❑ Subsequent Form Required: to- y �O R�3�$`llle5 OCT 1 0 201-3-\\ APPROVED BY Approved by: 1A t COMMISSIONER THE COMMISSION Date: g- - 7_5 VpR V N ^ ' pp Submit Fo P and CV Form 10-403(Revised 10/2012) Approve a tl I li f rr�irrin`nths from the date of rov r'/ Attachments in Duplicate • • Well Prognosis Well: A-32 Hiicorp Alaska,la. Date:08/7/2013 Well Name: Monopod A-32 API Number: 507332030100 Current Status: Oil producer(Gas Lifted) Leg: N/A Estimated Start Date: September 1, 2013 Rig: Monopod Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 177-018 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Trudi Hallett (907)777-8323 (0) AFE Number: Current Bottom Hole Pressure: 1,944 psi @ 4,725' (4,494' TVD) Calculated from 2009 pressure survey during Redoubt Volcano SI. Maximum Expected BHP: 2,507 psi @ 6,150' (5,771' TVD) Max.Anticipated Surface Pressure: 2,252 psi. (Using all gas in tubing from 5,771'TVD to surface and a .044 psi/ft. gas gradient.) Note: A gas gradient was used in calculating the Max. Anticipated Surface pressure because the E zone has the potential to produce normally pressured natural gas. Brief Well Summary The A-32 well is currently is currently completed as a gas lifted oil well. The most recent well test shows that the well makes 14 bopd and 81 bwpd. This well was last worked on in May of 1989. The re-completion plan involves pulling the existing completion,cleaning out all screens,CIBPs and Cement retainers to a PBTD depth of 6,700'. The well will then be perforated adding both new zones and re-perforating existing intervals. A new gas lift completion will then be ran. 1. MIRU Monopod Platform Rig#56. 2. RU Slick line and RIH with shifting tool and open sleeve at 4,377'. 3. Circulate three percent KCL to kill well and to circulate Hydrocarbon off of the well. 4. Set Back pressure valve,ND Wellhead, NU BOP and test to 250psi low/2,500psi high.(Note: Notify AOGCC 24 hours in advance of test to allow them to witness test). 5. RU e-line and RIH with tubing cutter to 4,385'(+/-). Unseat Hanger and pick up on tubing. Cut tbg. RD E-line. 6. POOH laying down production tubing. 7. PU RIH with Pkr retrieving tool. Engage pkr and retrieve same. If Packer unsets,go to step 9. Otherwise,continue with step 8. 8. PU RIH with Packer milling and retrieving assembly. Mill over and retrieve packer at 4,390'. 9. RU E-line. RIH with cuter and Cut Screen at selected intervals. RD E-line. 10. PU and RIH with 9-5/8"Milling assembly. Burn over Baker SC-1 Packer at 4,470'. POOH with Milling Shoe. 11. RIH with Spear,Spear and retrieve pkr at 4,470'. Spear and retrieve sand screens from 4,470— 4899'. • • Well Prognosis Well: A-32 Hilcorp Alaska,LLD Date:08/7/2013 12. PU RIH with Milling shou and burn over Baker Model D sump packer at 4,901'. POOH with Packer. 13. PU bit and Clean out assembly. RIH to to 4,960'to cement retainer and drillup same. Continue drilling out the cement retainers and CIBPs down to 6,540'. POOH with Bit. 14. PU RIH with Shoe to fish at 6,540. Burn over and retrieve fish at this depth. (note: may require a spear to recover packer). Circulate hole clean, POOH with shoe. 15. PU Clean out Assembly,RIH cleaning out to 6,700'+/-. 16. RU E-line. RIH With Gamma Ray CCL tool to 6,690'. Log hole from this depth up to 502'. POOH with E-line. 17. PU RTTS Packer. RIH to 2,080'+/-and set packer. Pressure up on back side and pressure test casing to 2,300 psi. Chart same for 30 minutes. POOH with RTTS packer. 18. RU TCP perforating Company. PU TCP guns building string into the well. Run guns into well on work string and Correlate on depth with E-line. Place guns on depth and fire guns. 19. PU on guns and circulate out pert gas. Monitor well for 1 hr shooting fluid levels to determine fluid loss. Fluid loss should diminish over time. 20. Once well is stable,POOH with TCP guns. b21. PU Permanent packer and RI well on work string to setting depth of 50'above the top ,,t perforation. Set packer. 22. PU completion string consisting of SSSV,and GLMs,on 2-7/8"8rd EUE L-80 production tubing. Space out and set seals into packer. Hang off tubing. 23. ND BOPs, NU Wellhead and test. ' ' `�eS / c_42, i' 2-4001,3,.., /3°""`° 24. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Proposed Wellhead. • • Trading Bay Unit . 11 SCHEMATIC Monopod Platform Well #A-32 API #50-733-20301-00 Completed 5/30/89 RKB to TBG Head=37.90' CASING AND TUBING DETAIL Tree connection: SIZE WT GRADE CONN ID TOP BTM. 20" 94 Driven 19.12" 42' 221' 1 16" 65 H-40 BTC 15.25" 39' 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) 39' 4451' 9-5/8" 47 N-80 BTC-KC 8.681" 39' 6724' 221' Tubing: 2-7/8" 6.4 N-80 BTC 2.441" 37.9' 4434' ji 2 1 502'L JEWELRY DETAIL NO. Depth Length ID Item 37.90 .80 6.184 10"TBG Hanger Cameron DC-B 3-1/2"EUE 8RD Type 1 BPV 2.44 3-1/2"EUE 8RD x 2-7/8"BTC x-over 1 321 2.50 5.963 OTIS Type XXO SSSV Landing Nipple.(ID=2.313") _., , li 2 6.92 2.313 5 each 2-7/8"BST Gas Lift Mandrels(4.75"Major OD)at 998',2031', (TYP•) 2987',3838',4342' 3 4377 3.31 2.313 Model Otis Model XA Sliding Sleeve(3.75"OD,Opens Up) 4 4390 6.33 3.88 Otis Model"VST"9-5/8"x 3.88"(Versa-Trive packer)(43.5-53.58) with 3 5.15'seal bore extension and 5.77'mill out extension. '3.JIB 5 4390 2.44 Otis Str.Slot Seal Assembly(4.47"OD),4 molded seal units(3.05"ID, �®� 3.93"OD),3 extension spacers(3.05"ID,3.88"OD) 6 4423 1.30 2.313 Otis X Landing Nipple(2.313"ID) 4451'L t_t , 7 4435 .68 2.44 Mule shoe guide iii 4 8 4470 4.74 4.75 Baker 96A4-47 SC-1 Packer 6 5 Gravel Pack Installation,Blank Pipe(4506'-4558'),5"x.012"screen 7 (4558'-4878') 4899 1.26 3.00 Baker Model 190-47 Snap Latch(6.00 OD) 8 9 4901 4.75 Baker Model D sump Packer �, 10 4960 Cement Retainer 11 5075 Baker CIBP 12 6009 Cement Retainer 6096 CI 14 6540 Baker Jun k Packer" —- C-7 PERFORATION DATA o 47-5 ZC-n7e 5 �, Opened 5/25/89 tion C 5,027' 5,029' 2 Block Squeeze -•=111 9 C 5,041' 5,043' 2 Isolated C 5,120' 5,140' 20 Squeezed with 1C0 sxs ...... emi., C 5,285' 5,345' 60 Squeezed with 100 sxs 10 D 5,425' 5,455' 30 Squeezed with 250 sxs D 5,530' 5,560' 30 Isolated — D 5,590' 5,606' 16 Isolated 5065'5075' D 5,630' 5,662' 32 Isolated 11 / AVA7 D 5,765' 5,815' 50 Squeezed with 600 sxs D 5,852' 5,912' 60 Isolated C and D D 6,050' 6,052' 2 Block Squeze — Hemlock 6,260' 6,4W 140 Isolated — Hemlock 6,430' 6,560' 130 Isolated s WNW. 12 6010'-6096' 13 14 — Hemlock 4 a PBTD=4960' TD=6750' MAX HOLE ANGLE=30° @ 4600' Updated by: iLL 08-06-13 • • Trading Bay Unit ' . n PROPOSED Monopod Platform Well #A-32 API #50-733-20301-00 Completed: Future RKB to TBG Head=37.90' CASING AND TUBING DETAIL Tree connection: SIZE WT GRADE CONN ID TOP BTM. 20" 94 Driven 19.12" 42' 221' ] , 1 16" 65 H-40 BTC 15.25" 39' 502' 13-3/8" 61/68 K-55 BTC 12.415"(Min) 39' 4451' 9-5/8" 47 N-80 BTC-KC 8.681" 39' 6724' 221' '; Tubing: 2-7/8" 6.5# L-80 8rd EUE 2.441 37.9' ±2075' 2 , 502'L JEWELRY DETAIL • I NO. Depth Length ID Item 37.90 .80 6.184 10"TBG Hanger Cameron DC-B 3-1/2"EUE 8RD Type J BPV P - 1 ±300' SSSV 2 ±1982' GLM imp 3 ±2034' Chemical Injection Mandrel leaw 4 ±2044' Packer 5 ±2075' WLEG B Zone 4451'L 1 _ Perforation Details = Top Zone Top(MD) Btm(MD) (ND) Btm(ND) Amount Condition BZN ±2,094' ±2,120' ±2,058' ±2,082' Future = C Zone BZN ±2,478' ±2,690' ±2,422' ±2,625' Future = BZN ±3,494' ±3,586' ±3,377' ±3,462' Future C-7 4590 4690 4,377 4,464 100 Opened 5/25/89 - CZN ±4,591' ±4,690' ±4,378' ±4,464' Future = 47-5 4,800' 4,860' 4,562 4,615 60 Opened 5/25/89 = CZN ±4,812' ±4,830' ±4,227' ±4,589' Future = CZN ±4,840' ±4,860' ±4,597' ±4,615' Future CZN ±4,960' ±4,970' ±4,705' ±4,714' Future = C 5,027' 5,029' 4,764 4,766 2 Block Squeeze C 5,041' 5,043' 4,777 4,779 2 Isolated = CZN ±5,092' ±5,110' ±4,823' ±4,839' Future CZN ±5,116' ±5,142' ±4,844' ±4,867' Future = C 5,120' 5,140' 4,848 4,866 20 Squeezed with 100 sxs = CZN ±5,186' ±5,216' ±4,907' ±4,934' Future = DZone CZN ±5,250' ±5,260' ±4,965' ±4,974' Future = C 5,285' 5,345' 4,996 5,050 60 Squeezed with 100 sxs = CZN ±5,292' ±5,348' ±5,003' ±5,053' Future D 5,425' 5,455' 5,122 5,149 30 Squeezed with 250 sxs DZN ±5,430' ±5,460' ±5,127' ±5,154' Future DZN ±5,520' ±5,560' ±5,208' ±5,244' Future D 5,530' 5,560' 5,217 5,244 30 Isolated DZN ±5,576' ±5,610' ±5,259' ±5,289' Future • D 5,590' 5,606' 5,271 5,286 16 Isolated D 5,630' 5,662' 5,308 5,336 32 Isolated - DZN ±5,638' ±5,674' ±5,315' ±5,347' Future DZN ±5,694' ±5,722' ±5,365' ±5,390' Future DZN ±5,758' ±5,824' ±5,422' ±5,481' Future D 5,765' 5,815' 5,429 5,473 50 Squeezed with 600 sxs = DZN ±5,850' ±5,918' ±5,505' ±5,566' Future D 5,852' 5,912' 5,507 5,560 60 Isolated EZone EZN ±5,947' ±5,987' ±5,592' ±5,627' Future EZN ±6,004' ±6,026' ±5,642' ±5,662' Future EZN ±6,032' ±6,089' ±5,667' ±5,718' Future D 6,050' 6,052 5,683 5,685 2 Block Squeze _ EZN ±6,134' ±6,150' ±5,758' ±5,772' Future = HEM ±6,250' ±6,430' ±5,860' ±6,020' Future Henlock Hemlock 6,260' 6,400' 5,869 5,993 140 Isolated Hemlock 6,430' 6,560' 6,020 6,136 130 Isolated -West F°W nd WF ±6,614' ±6,652' ±6,184' ±6,218' Future 4 PBTD=4960' TD=6750' MAX HOLE ANGLE=30° @ 4600' Updated by: JLL 08-08-13 • • Monopod Platform 2013 BOP Stack IliIr„r,,:+Li,,+kn.11.1.4. 03/12/2013 Rig Floor Bottom of air boot flange A IIJ III 5'below rig floor II 16” 14.72' 9.50' Pipe III III Illllliii 111.111 ill III III III III•III 3.74' Iil 111 Ill III I!I 26.25 Shaffer LXT 2 7/8-5 Variables 2.50' 13519 SM -.__... _. 44 -- Blind ND r/� I '1 1.76 Q�l,� I I I I. i. � '®1 � 13585MFEXFE w/3 1/8 5M EFO w/2 1/16 5M Choke and Kill valves w/Unibolt end connections for lines III ili III III 111 2.83' — Dual Cameron Flex rams III,lit Ill 111 III +OM 111 III III I1I V Drill deck Riser 14.20' 135/85M FE X 135/85M FE III .II iii:1 I' I1 Spacer spool 1.5' 135/85M FE X113M I 1 1 I I Wellhead @ 15.00' , , . • • Monopod Platform A-32 Current/Proposed 08/08/2013 Ililrari:%lii+ka.1.1.5. Monopod Platform Tubing hanger,CIW-DCB- A-32 FBB,11 X 3'/EUE 8rd lift 20 X 16 X 133/8 X 95/8X and susp,w/3"Type H 2 7/8 BPV profile,1/8 non continous control line port, 6'/4 neck,Alloy material BHTA,Bowen,3 1/8 5M X 2 34 Bowen Union 1 a Tree,Block,CIW-F,11 5M 1 FE X 3 1/8 5M,single + 49 I- 6%pocket prepped for _.0 0 0I IrI II 1 control line exit,EE trim �f , _� . 1.1 1l1 Tubing head,CIW-DCB, _ , 13 5/8 3M X 11 5M, __ 8 ,I I. w/2-2 1/16 5M SSO, III Ifal X bottom prep , 'l_- -M u 10�I:'1 l Jr u1 _ ,1 1�._ Casing spool,OCT-29L, ,• tip `' `j n. 21%2M X 13 5/8 3M,w/ 2-2 1/16 5M SSO, -� '- 6 13 3/8-00 bottom I I_l I-tIrI,W _.►,III$I* i J Starting head,OCT Type II, - -.n- 21 34 2M X 20"SOW, 161 `i iii 111 w/4-2 1/16 2M SSO - 16"casing hung off on mandrel 13 3/8"casing on C-29 slips .J!1 NI —:10.'".11 i.,-1, '' 1.1 Ed r.' . ' '' i III �� l1 ,I . I� i 20" 16" 13 3/8" 9 5/8" 2 7/8" e e FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 19,2005 ~...-~ .. Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 ~(;N~NEr "". (p. 't \~" h' .;. RE: No-Flow Verification Trading Bay State A-32, PTD 177-018 Dear Mr. Myers: On December 16, 2005 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's Monopod platform, Trading Bay State Well A-32. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for several hours. The well demonstrated an immediate gas flow rate of 180 standard cubic feet per hour at surface, dropping to no flow within 10 seconds. The subsurface safety valve m~y be removed from service in Well A-32 based on this no- flow test result. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.:265. The subsurface safety valve must be returned to service if the well demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Monopod platform. Sincerely, ~- '0'? ~ìfÙ¡¿J b ' 1\ f?tf( James B. Regg { r Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORAN~M e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. supervisor'K11' (1J9~'> DATE: December 16, 2005 THRU: FROM: Lou Grimaldi, Petroleu m Inspector SUBJECT: No-Flow Test Unocal, Monopod TBU A-32 Trading Bay Unit PTD 177-0180 NON-CONFIDENTIAL Friday, December 16, 2005: I witnessed a No-Flow verification on Unocals well Ä-32 on the Monopod platform. Following is a timeline and well status during test. 1330 Arrive location, tubing/casing open to atmosphere with no flow evident. 1350 Well shut-in @ 0 psi 1420 3 1/2 psi, Open well to atmosphere with <180 scf/hr flow evident. No flow within 1 minute. 1430 Shut-in well @ 0 psi. 1500 3 psi, Open well to atmosphere with <180 scf/hr flow evident. No flow within 1 minute. 1515 Shut-in well @ 0 psi. 1530 1 psi Open well to atmosphere with <180 scf/hr flow evident. No flow within 10 seconds. 1535 No gas flow, shut-in well. 1555 1 psi Open well to atmosphere with bare whisper. No gas flow within 10 seconds. 1615 Well open to atmosphere, no flow evident. Conclude test. SUMMARY: TBU well A-32 passed its no flow verification. NON-CONFIDENTIAL CC' ~ 2005-1215 _No-Flow_TBF _A-32_lg.doc MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor O~t~o,-,'° \ State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 5, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Monopod Platform Trading Bay Field T.hum. dav, April 5, 200!:. I traveled to UNOCAL's Monopod Platform and witnessed the semi annual safety valve system testing. Lead operator Gary Smith conducted the testing today; he did a thorough job and was a pleasure to work with. As the AOGCC Safety Valve System test report indicates lWitnessedthe testing of 18 wells and 53 components, with four failures: The pilot on well A-02 tripped at 26 psi and was repaired and passed a retest. This well has had the SSSV removed for repair since 2/24/00 and has not been re-installed. Well A-11 has had the SSSV removed for repair since 11/7/99 and has not been re-installed. I indicatedto Mr. Smith that these SSSV's must be repaired and re-installed and successfully tested in a timely manner or the two wells shut in. Well A-06 SSSV failed to close and will require maintenance. Wells A-13 and A-21 have been certified as "no flow" status and do not have SSSV's installed. While on location i inspected the platform and found it very clean and it appeared to be in excellent condition. Summa.ry.: I witnessed the semi annual Safety Valve System testing at Unocal's Monopod Platform in the Trading Bay Field. M0nopod Platform, 18 wells' 53 components, 4 failures, 7.5% failure rate. Platform inspection conducted, A ..ff~achment: SVS TBF Monopod Platform 4/5/01 JJ NON-CONF, IDENT,,IAL SVS TBF Monopod Platform 4-5-01 Alaska Oil and Gas Conservation Commission Safety ValVe System Test Report Operator: UNOCAL Operator Rep: Gary Smith AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Date:, Field/Unit/Pad: Trading Bay Field Monopod Separator psi: LPS 65 HPS 4/5/01 Well Permit Separ Set ~ T~t Test Test Date ~l, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE I I I I I I I A-01~ 1901470~ 65 45 42 p P P O~ A~2 .... 16604~'0 "65 45 ' 26 3 P, -~n~3 :?: 4/5/01 ' , , OI,~ A-03~3' 1971306~ 65 45 42 p p P OIL A-~ , 1670020 A-06 1670250 65 45 45 P P ;43 OI~ A-07 1670460 65 45 '42 p P P OIL A-09~ ~ 1810360 ' . ..... , A-10 1670760 A,-tl 17~40 65 '~5 ~ 43 P P ;~ OIL A-13 '1680620 65 45 ~ 41 p P OIL~ 1, .~ "' ' ' ' A-14 '1680270 A-15., '1680330 65 45 " 45 e ' P e ' OiL A-16~' "1880380 '" 65~ '45 41/42 e ~ 'e ...... OIL A-17~ 1810670 65 45 43 p P P OIL A'18 1680760 65 45 47 P p P OIL ~, , , ,, A'21 1700470 65 45 46 P P OIL A-22 1700310 "65 45 ~ P P e OIL , ~A-23 1700590 A-23 DPN 1720200 A-24~ 1810400 65 45 4'1 p P P ' OIL A-27~1 1970630 ' ' ~5 45 43 p p' p ~ 'oIL A-28~ " '1890920 " 65 45 45' P P P 'OIL A-30 1730140 A-32 ~: 1770180 65 45 44~ P P e OiL , .... , ,, ,, Wells: 18 Components: 53 Failures: 4 Failure Rate: 7.5% r-'190Da¥ Remarks: A-13 & A-21 reported as No-Flow wells. SSSV's removed for repair: A-02 out since 2/24/00, A-11 out since 11/7/99. .A.?02 pilot repaired and retested "OK". A-06 SSSV failed to close. A-16 RD is a dual completion. 4/9/01 Page 1 of 1 SVS TBF Monopod Platform 4-5-01 JJ Unocal North Americ; Oil & Gas Division Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. GSB/lew Yours very truly, G a~S.~ u s~h' (~'-"-~"' . Reglona1 Drilling Manager CONDUCTOR 1 · 2 3 4 5 6 7 8 9' lO 11 12 13 14 15 16 17 18 19 20, 21 22 ._.~.__2'~ 24 25 26 27 28 29 30 31 22 MONopOD CENTER FROM SOUTHEAST CORNER, SECTION 4, T9N "Y" = 2,523,126 LAT. -- 60o53' "X" : 218,871 LONG. = 151o34' "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133 8 2,523,137.6 2,523,138.8 2,523,138.8 2,523,137'.2 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 2,523,133.9 2,523,120:9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0. 2,523,122.6 2,523,119.2 "X" COORD. 218,880.9 218,883.2 218,883.9 218,883.2 218,881.3 218,876.8 218,873.0 218,869.0 218,864.6 218,861.1 218,858.8 218,858.1 218,858.8 218,860.7 218,865.2 218,869.0 218,873.0 218,877.4 218,875.7 218,878.6 218,870.8 218,873.9 .~. ?.'~ ~ ~?.6 ._~9. 218,867.0 218,878.1 218,863.9 .218,875.0 218,865.1 218,868.1 218,871.1 218,863.4 218,866,3 4 3.51" ' mOeho,,,..,~ 0o.0/0/./88,{//,/ WELL # FSL FEL L ,, A-28 1621 554 A-25 1617 551 A-30 1612 551 1608 551 A-27 1605 '553 , A-23 1601 557 A-21 and RD 1600 561 A-22 1600 565 A-14 1601 570 A-13 1604 573 A-17 1608 576 A-8 1612 577 A-15 1616 577 A-24 and RD 1620 574 A-29 1624 570 A-9 and RD 1625 566 A-19 1625 562 A-18 1624 558 A-11 1619 559 A-3 1616 556 ,. A-1 1618 564 A-7 1615 561 A-4 1611 .._ A-6 1600 ' :568 A-32 1607 556 A-12 and RD 1617 571 A-20 1604 559 A-2 1613 570 A-16 1610 566 A-26 1606 563 A-10 1609 571 A-5 and RD 1605 568 1 &2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,SION 5~ REPORT OF SUNDRY WELL OPERATION 1:{ I 1 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well -x-- Pedorate ~ Other __ 2. Name of Operator 5. Type of Well: Development ~CAL ) Exploratory __ 3, Address Stratigraphic __ Service __ 4. Location of well at sudace Monopod Plat form Conductor#25 1607' N & 556' W, F/SE Corner, Sec. 4, T9N, R13W, S.M. At top of productive interval 4595' MD, 4380' TVD, 404' S & 861' W F/Surface Loc. At effective depth 4960' MD, 4704' TVD, 126' N & 818' W F/Surface Loc. At total depth 6724' MD, 6281' TVD, 745' N & 334' W F/Surface Loc. 6. Datum elevation (DF or KB) feet 7. Unit or Property name ~m~ n~ Rmv 8. Well number TBS A-32 ,, ,, 9. Permit number/approval number 77-18/9-059 10. APl number 50-- 133-20301 11. Field/Pool "C" Zone 12. Present well condition sUmmary Total depth: measured true vertical 6724 ' feet 6281 ' feet Plugs(measured) Cmt Ret @ 4960' & 6009' Bridge Plug @ 5075' & 6092' Effective depth: measured true vertical 4960 · feet 4704 · feet Junk(measured) Packer @ 6540' Fill @ 4934' Casing Length Structural Conductor 221 ' Surface 502 · Intermediate 4451 · 6724' Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 20" 13-3/8" 9-5/8" Driven 500 sxs 502' 502' 2200 sxs 4451' 4254' 2000 sxs 6724' 6281' 4590'-4690', 4800'-4860' RE£1 IVED true vertical 4376'-4464', 4561'-4615' j,a, j ~.~,2-7/8", 6.4#, N-80 BT&C @ 4434' Tubing (size, grade, and measured Baker Model D sump pkr ~ 4901 d~u; ., ,, · Baker Model "SC-i" pkr ~ 4470' Packers and SSSV (type and measured depth) Otis "VST" pkr ~ 4391', SSSV ~ 321' 13. Stimulation or cement squeeze summary Pressure packed 4800'-4860' with 69 sx 20-40 sand @ 3400 psi t Pressure packed 4590'-4690' with 58 sx 20-40 sand @ 3200 .psi. Intervals treated (measured) Gravel pack 4590'-4860' with 115 sx 20-40 sand @ 1500 psi. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 79 66 1 770 psi ~bingPressure 70 psi 294 200 188 800 psi 230 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations x__ 16. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the :[oregoing is tr~e and correct to the be. st of my knowledge, f_/o-~ ~~f_~~--Ct~y D. Roberts ~5~ Environmental Engineer Signed ,,/? - - -- (~) Title Form 10-404 Re~'(~6/15/88 Date SUBU T INi U L C^TE A-32 GRAVEL PACK AND DETAIL SUMMARY DETAIL DESCRIPTION 1. Baker SC-1 packer 9-5/8" x 4-3/4" ID 2. Upper Extension; 190-47 3. Port Collar, 190-47 4. Seal Bore - 4-3/4" ID, 190-47 5. Lower Extension, 190-47 6. X-Over: 5" 8rd x 6-5/8" 8 Rd 7. Pup - 5", 15.5# J-55 blank 8rd 8. Jt.-5", 15.5# J-55 blank 8rd 9 SSWW Liner-5" x 0 012" 8rd 10. O-Ring Seal Sub 11 SSWW Liner-5" x 0 012" 8rd 12. Snap Latch-Baker #190-47 13. Baker model "D" sump packer JOB SUMMARY LENGTH TOP BOTTOM (FT.) (FT.) (FT.) 4.74 4470.61 4475.35 5.23 4475.35 4480.58 1.84 4480.58 4482.43 0.75 4482.43 4483.18 21.89 4483.18 4505.07 0.85 4505.07 4505.92 10.25 4505.92 4516.17 42.06 4516.17 4558.23 320.29 4558.23 4878.52 1.00 4878.52 4879.52 20.22 4879.52 4899.74 1.26 4899.74 4901.00 4901.00 On 5/28-29/89 Baker Sand Control successfully gravel packed the "C" zone perfs (4590'-4690', 4800'-4860') with a total of 115 sxs 20-40 mesh Ottawa Sand. This is 117% of theoretical fill calculations. The final pack pressure test was 1500 psi-lock up. Schlumberger's gravel pack log showed 100% sand coverage from 4503' to 4900'. UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 1 of LEASE TRADING BAY STATE WELL NO. A-32 FIELD MONOPOD PLATFORM DATE E. T. D. 05/18/89 05/19/89 05/20/89 05/21/89 05/22/89 05/23/89 05/24/89 05/25/89 DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Skid rig to access A-9. Rigged up wireline on A-32. Attempted to pull ball valve. Slipped off valve. Changed tools. Pulled valve but unable to close tree valve. Reset valve and pulled tools. Added more lubricator. Recovered ball valve. Skid rig over A-32 . Circulated & Opened "XA" sleeve @ 4464' killed well. Check for flow. Set back pressure valve & removed tree. Nippled up BOPE & tested. Attempted to pull seals from packer (150,000# pull on TBG). RIH with jet cutter. 4496' Cut tubing @ 4452' WLM. POH laid down Wireline. Circulated. POH. Laid down tubing. Press test BOPE to Unocal specs. RIH with Bowen 7-5/8" overshot & 3-1/2" grapple. Engaged fish @ 4450' DPM. Jarred with 90,000# overpull. No movement. POH w/overshot. RIH with 8-1/8" washpipe with 8-1/2" flat bottomed mill shoe. Washed from 4477' to PKR @ 4495'. Milled packer 4495'-4496'. 4497' Continued milling to 4497'. POOH & laid down wash pipe. Made up overshot & RIH. Engaged fish @ 4450' and POOH. Recovered tubing fish & packer. RIH with 8-1/2" mill & junk sub. 4930' Continued RIH with 8-1/2" mill & junk sub. Tagged fill & 4725' & cleaned out to 4900'. Circulated, conditioned & POOH. Picked up 8-1/2" bit & casing scraper. Tagged fill @ 4863'. Cleaned out to 4932' when scraper hung up. Worked scraper & parted X-over below Kelly. Screwed into fish, circulated & worked free. POOH with scraper. Picked up 8-1/2" bit & junk sub. RIH & tagged fill @ 4870'. Cleaned out to 4930'. Tagged solid junk. 4930' Circulated @ 4930'. Pumped a sand scour & flocculant. Circulated & POOH laying down 3-1/2" DP. Cleaned active system & began filtering fluid. RIH picking up 3-1/2" PH6 tubing. Tagged fill @ 4917' & cleaned out to 4930'. Circulated & filtered fluid until clean. Laid a high viscosity pill across the perforations. POOH for perforating guns. 4930' Made up 6" guns & RIH. Positioned Vann Big Hole T.C. guns on depth W/GR/CCL. Perforated "C-Zone" 4590'-4690', 4800'-4860' 8 HPF w/500 Psi draw down. Reverse circulated & POOH. Made up 8-1/2" bit & scraper & RIH. Tagged fill @ 4901' & cleaned out to 4930'. Filtered fluid for mini-fracture. UNOCAL DRILLING RECORD ALASKA REGION PAGE NO. 2 of LEASE TRADING BAY STATE WELL NO. A-32 FIELD MONOPOD PLATFORM DATE E.T.D. 05/26/89 4780' 05/27/89 4934' 05/28/89 4934' 05/29/89 4934' 05/30/89 4934' DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Finished filtering fluids & POOH. Made up packer & RIH to 4750'. Set packer & obtained breakdown rates & pressures. Pressure packed the Lower "C" zone from 4860' to 4800' with 50 bbl HEC pre-pad @ 7 BPM & 3400 psi. Followed by 28 bbl or 82 sx 20-40 sand slurry @ 7 BPM & 3400 psi. Displaced pack with pad to the end of tubing. (ISIP-2600 psi, FSIP 1600 psi after 1-1/2 hours). Total sand in place 69 sx or 111# per foot of perf. POOH & laid down packer. RIH open ended & laid sand plug to 4780'. POOH & picked up packer & RIH to 4540'. Set packer @ 4540'. Obtained breakdown rates & pressures on the upper "C" zone from 4690' to 4590'. Pressure packed zone with 26 bbl of HEC pre-pad followed by 26 bbl or 82 SX 20/40 gravel. Pumped 7 BPM @ 3200 psi. Began to displace gravel when pressure increased to 4800 psi after 31 bbl pumped. (ISIP 2800 psi, FSIP 400 psi after 1 hour) total sand in place 58 sx or 58# per feet of perf. POOH, picked up 8-1/2" bit & RIH. Tagged sand @ 4672' & cleaned out to 4934'. Filtered fluid @ 4934' & POOH. Picked up sump packer & RIH. Set packer @ 4900' & POOH. Picked up 5" gravel pack screen (.012 gauge), SGI packer & gravel packing tools. Set packer @ 4470'. Tested gravel packing tools. Mixed & pumped 40 bbl (115 sx) 20-40 sand to sand out @ 1/4 BPM & 1500 psi. Reversed out 18 sx sand. Total of 97 sx sand in place (98%). Waited on pack for 2-1/2 hours & retested at .75 BPM & 950 PSI. Repacked zone with 7 BBL (20 sx) 20-40 sand to 1/4 BPM & 1800 psi. Reversed out 2 sx of sand. Waited on pack for 1-1/2 hours and tested to 1500 psi with very slow bleed off. Closed port collar & POOH. Placed 115 sx sand away or 117% of theoretical. Rigged up wireline & ran gravel pack logs (showed good pack). Made up 9-5/8" Otis "VST" packer & RIH. Set packer @ 4390' & tested. POOH & laid down 3-1/2" workstring. Running 2-7/8" production tubing. Cont. RIH w/2-7/8" 6.4~ N-80 single string completion. Stabbed into pkr. Tst seals-OK. Landed tubing with tail at 4434'. Set BPV. ND BOPE. NU and tst tree. RR at 1200 hfs 5/30/89. M EMORAN DU M State of Alaska Lonnie C. Smit,~-- ~, 30 Z989 TO: Commissioner . FILE NO: D. HRH. 0 3 0 THRU: TELEPHONE NO: Michael T. Minder ~.,~'~. SU~ECT: BOP Test Sr, Petroleum Engineer Union TB~A32 Monopod P1 t rrm Permit No. 77-18 Trading Bay Oi 1 Pool FROM: Harold R. Hawkins Petroleum Inspector Friday, May 19, 1989, I left Anchorage at 3:15 pm to Kenai by ERA, a~rivingai'~n~:{-:~-i~:4:45 pm and at Union Monopad platform at 5:00 pm. Stand by for BOP test. Saturday, May 20, 1989, I witnessed the BOP test on TBU-A-32 for U~ii~n--b{I:~ :~~ 'warPlane failure. I filled out an AOGCC field report which is attached. In surr~ary, I witnessed the BOP test on Union oil's TBU-A-32 well, the failure was the outside kill valve. Union to call when tested. Also the blinds, dart and ball floor valves were not tested. ~2bing had to be pulled to test. Attachment Comment: On 5/22/89, I received a call from Mike McCall, he stated that the outside kill valves were replaced and tested ok on 5/20/89 and on 5/21/89 the lower pipe rams, inside BOP safety valve, and CSO were tested ok. M.T.M. O&O .Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E, Inspection Report Well Operator ~/~,'/~ Location: Sec ~ Drilling Contractor ,~X ~Tg Location, GeneraI Ri Well Sign~/~ Representative. Permit ~/ ~.~-/ /~.- Casing Set Representative ACCUMULATOR SYSTEM General Housekeeping Z~ Rig ~/~ Reserve Pit , Zf/~ Mud Systems Visual Audio Trip Tank '~-'/ Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve· Kill Line Valves Check Valve Test Pressure Test Results: Failures Full Charge Pressure ~'~-~ psig Pressure After Closure, /.~P psi~ Pump incr. clos. pres. 200 psig 229- min--- sec. Full Charge Pressure Attained: ~ . min~ sec. Controls: Master z~/~? Remote Blinds switch cover Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold No. Valves No. flanges Kelly and Floor Safety Valves Test Pressure .f~ Test Pressure ~~ Test Pressure _.~..~ Test Pressure (/~'4~ Test Pressure Adjustable Chokes 6f~'~C ~ ~-'~ /~'~fZ~~- d/~' Hvdrauically operated choke ~ ff7~ Test Time ~ hrs. Repair or Replacement of failed equipment to be made within .~ days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor '""~' STATE OF ALASKA AL/-,~,r,,A OIL AND GAS CONSERVATION coMMI,. APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon __ Suspend_ Alter casing ~ Repair well m Change approved program __ Pull tubing __ Variance __ 2. Name of Operator ! 5. Type of Well: Union 0il Company of California (UNI~CAL) Development,Z,_ Exploratory __ 3. Address ! Stratigraphic_ P.O. Box 1~0247, Anch, Ak., 99519-0~47 Service__ 4. Location of well at surface 1607' N, 556' W of SE cot. Sec 4, T9N, R13W, S.M. At top of productive interval 404' S and 861' W of Surface Loc: 4595' ND, 4380' TVD At effective depth 126' N and 818' W of Surface Loc.: 4960' MD, 4704' TVD At total depth 745' N and 334' W of Surface Loc.: 6724' ND, 6281' TVD Operation shutdown ___ Re-enter suspended well m Plugging ~ Time extension ~ Stimulate ~ Perforate ~ Other 6. Datum elevation (DF or KB) RT 101' MSL 7. Unit or Property name Tradlng Bay Field 8. Well number TBS A-32 9. Permit number 77-18 10. APl number 50-- 133-20301 , 'i1. Field/pOol Tyonek "C" Zone feet 12. Present well condition summary Total depth: measured true vertical 6724 ' feet 6281 ' feet PlugS(measured) Cmt. Ret $ 4960' and 6009' Bridge Plug $ 5075' and 6092' Effective depth: measured 4960 ' feet true vertical 4704 ' feet Junk(measured) Packer $ 6540' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 221 ' 20" Driven Sudace 502 ' 16" 500 sxs 502 ' 502 ' Intermediate 4451' 13 3/8" 2200 SXS 4451' 4254' Production 6724' 9 5/8" 2000 SXS 6724' 6281' Liner Perforation depth: measured true vertical See Attached ~bing(size, grade, andmeasureddepth) 3 1/2", N-80, 9.2# $ 4576' MD JA;'; ;' .0il & Gas Cons..C0mr issi0.il Packers and SSSV (type and measured depth) "~ ~[lll;horag8 0tis W.B. Perm Pkr ~ 4500~; Camco TRB-6 SSSV ¢ 294' MD 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing oPeration_ ~ 15. Status of well classification as: February, 1989 I 16. If proposal was verbally approVed I Oil I Name of approver Date approved ~ ServiCe 17. I hereby ce~__~t ~e¢~ct to the best of my knowledge. signed Roy ~oberts -S-~Y.., Title Environmental Englneer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity .__ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form required 1"~-_ 01/17/89 J Approval No. ~ -- ~)~,5'- ~' Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Apo?oved Copy Returned ..... ~ C~.om, missioner Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment Trading Bay State TBS A-~2 Description Summary of Rroposal . . . 0 . . . 10. 11. 12. Move in and rig up. Kill well. Install BPV's, remove tree, install and test BORE. Rull and lay down existing single ~ 1/2" completion. Mill over and recover Otis WB permanent packer at 4500'MD. Clean out to retainer at 4960'MD. Tubing convey existing perforated interval at 8 SRF. 0-7 4595' - 4685' 47-5 4835' - 4855' RIH with sump packer, 5" wire wrapped screen, centralizer and production packer. Gravel pack the zone through a bypass tool, squeeze pack and repeat squeeze as necessary. Clean out wire wrapped screen to 4760' MD. Run single 2 7/8" completion. RDMO. Place well on production. Note: 0019n/105 Anticipated SBHR is 1970 psi. '~Ja~ka Oil .& Gas Gons. Ocmmis~io~ ~mhorage Perforation Detail Zone Hemlock I1 II II II II IICII tl I! Measured Depth 6430 - 6560 6260 - 6400 5852 - 5912 5765 - 5815 5630 - 5662 5590 - 5606 5530 - 5560 5425 - 5455 5285 - 5345 5120 - 5140 4835 - 4855 4595 - 4685 True Vertical Depth 6019 - 6135 5868 - 5993 5506 - 5560 5429 - 5473 5307 - 5336 5271 - 5286 5216 - 5244 5122 - 5149 5005 - 5050 4847 - 4865 4593 - 4611 4381 - 4460 Comments Isolated ;! ;! ;! ;! Isolated Rroducing Rroducing 0019n/106 ICHOKE MANIFOLD !SEE DRAWING I TO MUD PUMPS & CEMENT UNIT HYDRAULIC ~ ANGLED.. FILL UP LINE .... ! 'k HYDRIL :.. ,~ PIPE R.:,MS VALVE ,r- '- PIPE RAMS ti # I~. . -,..,,..,-.-- ( "- ~ -- ~'"~'-'~'FROM MUD PUMP, & CEMENT UNi' NTRA ~TOR FURNISHED OPERA TOR FURNISHED WELL NAME: RIG CONTRACTCR: RIG: · STACK PRE,SC URE RA TING: CHOKE LINE SfZE & MSP; .. NOTE: ALL CHANGES MUST HAVE WRITTEN AFPROVAL BY THE DISTRICT DRILLING SUPERINTENDENT NOTES' 1. HYDRAULIC VALVES OPEN AUTOMATICALLY WHEN DIVERTER IS CLOSED. 2. FLEX HOSE (f/z) IS TO BE USED IF NECESSARY WITH DDS' APPROVAL. .o · .,, DEPT. APPROVAL B.~._...y¢.;_ 6/'; 7~86 , ........ 1 3 5/8"E OF E STAC'-" aM OR 1OM ~ . . ALL WORK:OVEF:; OPERATIONS UNION OIL COt~..'.'; .... ':' OF CALIFORNIA -'.,:..4.,?,R,'r.E. :.[ sc^~,, N 0 N F A-32 w.o. .... KB'O' T UBtN.G, DETAIL I. CAMCO TRB-6 SAFETY VALVE-~94.5' ?.-5 CAMCO "K!~UG" G. LM~S AT, ~)?.03LO?.' i · . $)3P.77,23'i 4)3991.53'~ 5)4429.65' 6. OTIS "X/~' SLIDING SLEEVE AT 4464,6' ?. LOCATCR SUB AT 4498.2~ 8..OTIS TYPF. W.B. PERM. PACKER- W/II.4~ ~EAL ASSEMBLY ' "3. OTIS X NIPPLE AT 4541.80' I0. MULE SHOE AT 4575.a9' PERFORATION R,E~CORD ~2,dT'E ltYT'£,qV,~L 7A4/77 4595' -- 468~' 0-7 sd, ~OPEN 7/1~77 4835' ~ ~5' 47-5 sd,~OPEN .... Tbg. Hngr,- 32.6' ~ 16",65¢~ H"4'O CASING XT 50'~'_ lAKER MODEL "K" RETAINER-4,~.~O' ~ ,.~ ~-~ -CBS. A-32 ! WELL SC}-tE M~TIC '.$T,',RTEO :4/~/i~ CC~?,,.~T£~ 4 !.~/'~. 9'~8", 4.7¢, N"-- 80 CASING AT 6, ?2_4.' //¢,?"~",' 3~'2~' TUBING i FOR PERF. INFO, BELOW RET, SEE WELL HISTORY. PRESENT MONOPOD PLATFORM A-,32 ORAVEL PACK PROPOSED ~ 5-;/8" 6~ & 68# K--55 Csg @ 4451' X.-~' '~ ~.; Perm 5-~/2" 4576' -. 4595'-4685' =-- PERFS L 4815'-4855' =--- (130') Cement: 7/ :////////M'-}., ~ Pkr @ 449g' O.D. WWS in 20-CO(US) .Ottawa Gravel Pack 4590'-4690' PERFS 4800'-4860' (~ 60') Sump Pecker Retainer @ 4960' 9-5/8" 47# N-80 © 6724' f . STATE OF ALASKA ~ " ALASKA ,~IL AND GAS CONSERVATION C~,.vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address P. 0. BOX 6247 ANCHORAGE, AK. 99502 4. Location of Well 1607' N & 556' W from SE corner of Section 4, T9N, R13W S.M. 5. Elevation in feet '(indicate KB, DF, etc.) -- !0!' Rt above MSL 12. I6. Lease Designation and Serial No. ADL - 18731 Check Appropriate Box To Indicate Nature of Notice, Report, or NOTICE OF INTENTION TO: .(Submit in Triplicate) Perforate . [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing 7. Permit No. 77-18 8. APl Number 5°-133-20301 9. Unit or Lease Name Trading Ray 10. Well Number A-32 11. Field and Pool Trading Bay "C" Pool )ther Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following interval was reperforated in April, 1981- 4,685 - 4,594 C-7 Sand RECEIVED .JUL 1 ~I9~J Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~------------J~. ~:~ .__ ~,~A._ Title DISTRI CT ENGINEER The space below for Commission use U. CASE Date ,June ~_4~ !981 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403/ Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ,i , STATE OF ALASKA ~ ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. ., DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator COMPANY OF CALIFORNIA 3. Address ;HORAGE,'AK. 99502 4. Location of Well 1.607' N & 556' W from SE corner, of Section 4, T9N, R13W S.M. 7. Permit No. 77.18 8. APl Number 50- 133-20301 9. Unit or Lease Name Tradinq Bay State 10. Well Number A-32 11. Field and Pool Trading Bay "C" Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. above HSL ADL - 18731 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) · Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate the following'interval' 4,685 - 4,594 C-7 Sand Subsequent ~7o~.k Rcpo~tecl ' o, Form No. I_0~ I:)a~cd ~I_.~/~__1 £C£1VEO JUL if i~] /~n¢:~orage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~ ~~~ C%~ E_ The space below for Commission use S Conditions of Approval, if any: Approved by SIC-flED Form 10-403 Rev. 7-1-80 Title DT%TR!CT ENGINEER Approved COpy Retur?ed By Order of COMMISSIONF~ the Commission Date June ~z~, !98! Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION · Hoyle H. Hamilton · Chairman '~Thru: nonnie C. Smith ~ Commissioner ~ Ha rol d R.' Hawkins Petroleum Inspector June 8, 1981 Witness No Flow Test on Monopod Platform, ~ Well No. A-28 a~ Union Oil, Trading Bay Unit. June 1,. 1981: I 'was on the Monopod Platform, for Union Oil to witness safety valve tests that failed· initial tests, and also to witness two no-flow test's (subject of this report). I brought back the pressure charts and the flow meter data that was taken from midnight May 31, to 3:00 PM; June 1, 1981 on wells A-28 and A-32 to demonstrate the no flow test's condi- tions. The starting tubing pressure was 225 p.s.i.g, on A-28 and 235 p.s.i.g, on A-32. ~fnen I arrived on the platform at 9~15 AM the two well's were lined up to flow through the skimmer tanks. I asked the supervisor to turn the flow on the two wells to the separators, well no. A-28 was set up to run through' separator #2 at 9:45 AM. The meter register at 9:20 AM was 77035503 on well no. A-28 and 77035503 at 3:00 PM. The tubing pressure was 2 pounds, indicating no flow. Well no. A-32 was flowing through separator #1. The meter register at 10:00 AM read 438450.4 and at the finish of the test at 3.-00 PM read 438519.4. The tubing pressure read 55 p.s.i.g. Thus indicating the well was still flowing. Also the chart on the Barton .... meter showed the well was producing through the separator. In summary, I witnessed the no-flow of well's no. A-28, and well no. A-32, on the Monopod platform for Union Oil. I recommend no SSSV required, in well no. A-28. I do recommend that a SSSV is required and installed in well no. A-32. . . I : · NO. / . F~rm No. 10-~04 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-133-2031 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 'WELL OTItER WELL 8. UNIT FARM OR LEASE NAME 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, Anchorage, Alaska 99502 4. LOCATION OF WELL 1607'N & 556'W from S.E. Cor., Sec. 4, T9N, R13W, S.M. Trading Bay State 9. WELL NO. TBS A-32 10. FIELD AND POOL, OR WILDCAT Trading Bay "C", "D", Hemlock I 1. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 12. PERMIT NO. 77-18 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. 4/1/8o 6750' TD 4960' ETD (ret.) 13 3/8" C. 4451' 9 5/8" C. 6724' Began operations on A-32 at 00:01 hrs. 4/1/80. RIH w/ Meyer's W.L. and opened "XA" and set "X" plug in "X" nipple at 4543'. Pressure tested tubing to 5000 psi - OK. Retrieve "X" plug. Have 300 psi on tubing. Wait on frac. equipment. 4/2/8o 6750' TD 4960' ETD (ret.) 13 3/8" C. 4451' 9 5/8" C. 6724' Offload frac. eqUipment. Rigged up Dowell and pressure test lines. 4/3/80 6750' TD 4960' ETD (ret.) 13 3/8" C. 4451' 9 5/8" C. 6724' Test lines and frac-pack "C" zone thru 3½" tbg. w/ 176,000# sand. Offload frac. equip. M.U. small BOP's and flowlines. RIH w/2¼" drag bit on 1¼" CS hydril tbg. to 4664'. Circ. out gas cut fluid. RIH to 4765' & plugged bit. Pooh. 4/4/80 6750' TD 4960' ETD (ret.) 13 3/8" C. 4451' 9 5/8" C. 6724' RIH w/O.E, tbg. and C.O. sand f/4732' to 4951'. Pumped viscous sweep every 70' of hole. Circ. for 2¼ hrs. Pooh laying down 1¼" tbg. RIH w/W.L. & sinker bar and tag ETD @ 4943'. Pooh. Released rig @ 24:00 hrs. 4/4/80. RECEIVED !' "O 1980 14 I hereby~rtify that J, lte for~ing me and ~}rrect' ~ .... · ,~. ~ .~ ~'~ 7/// ~/ -- uxs~. urxg. Supt. 5/2/80 SIGNE~~~- [ ~~/~ ~ ~TLE / ~ DATE ' NO~-Be~orl on this lo~m is required ~r~ah ~al~ndar month, re~ardl~ o lh~ ~alu$ of o~rllio~, an~ ~u~ ~ ti1~ in ~u~li~al~ ~ilh lh~ oil and ~as conservation ~Ommilt~ b~ lh~ l~th ot the su~edin~ monlh,unl~ olh~i~ direlY, Form 10-403 REV. 1-10~73 Submit "1 ntentions' in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL ~ OTHER 2. NAME OF OPERATOR UNION OIL ~COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL Atsurface 1607'N & 556'W FROM S.E.' COR., SEC. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20301 6. LEASE DESIGNATION AND SERIAL NO. kD~,-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME TRADING BAY STATE 9. WELL NO. TBS A-32 10. FIELD AND POOL, OR WILDCAT TRADING BAY "C" "D" HEMLOCK 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SEC. 4, T9N, R13W, S.M. 12. PERMIT NO. 77-18 =orr, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SNOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multlDle completion on Well COml~letlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS: (Clearly state all Dertlnent gletells, anti give pertinent dates, Including estimated clate of starting any proposed work. The following work was performed on well TBS A-32, Monopod Platform: 1. Moved rig #56 over Conductor #25, TBS A-32, and rigged up. 2. Displaced hole w/FIW and pressure-tested tubing. 3. Frac-Packed the "C" zone. 4. Cleaned out hole to ETD using 1¼" tubing. 5. Placed well on Production. RECEIV!:D · APR 1 4 1980 Alaska 0i~ Ancnu~aw~ 16. I hereby certify that the foregoing is true and correct u / 0 (This space for State office u~) Dist. Drlg. Supt. DATE 4/ll/80 APPROVED BY . CONDITIONS OF APPROVAL, IF ANY'. TITLE DATE See Instructions On Reverse Side Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 5. APl NUMERICAL CODE 50-133-:20301 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR CEASE NAME Trading Bay State 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, Anchorage, Alaska 99502 TBS A-32 4. LOCATION OF WELL At surface 1607'N & 556'W from S.E. CDr., of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Check Appropriate Box To Indicate Nature of Notice, Re 14. NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [__..._j FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 10. FIELD AND POOL, OR WILDCAT Trading Bay "C", "D", Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 12. PERMIT NO. 77-18 ~)ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTEI Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all ixrtlnent (letalls, and give pertinent dates, Including estimated date of starting any proposed Work. In order to Frac'-Stimulate the "C" zone sands of well TBS A-32, Monopod Platform, it will be necessary to perform the following procedure: PLAN OF PROCEDURE: le 2. 3. 4. 5., Move Rig #56.°var Conductor #25, TBS A-32, and rig up. Pressure test single 3½" tubing string w/"X" plug. Fracture stimulate "C" Zone sands thru existing tubing. Clean out tubing and casing to 4960' ETD w/lq' tubing. Put well on production. ESTIMATED TOTAL TIME: + 7 Days RECEIVFD 0il & ((- '; 16. I hereby certify that the foregoing is true and correct (T his space forl~tate of~, .._f ../i' CONDITIONS OF APPROVAL, IF A~ Dist. Drlg. ~Supt. , DATE 3/24/80 COMMISSIONER BY ORDER OF THE See Instructions On Reverse Side DATE Approved Copy Returned . Fozm No. 10404 REV. 3-1-70 STATE 'OF ALASKA ' OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DL~LICATE ~ 5. APl NUMERICAL CODE 50-133- 20301 ~" 6. LEASE DESIGNATION AND SERIAL NO: - . _ ADL-18731 : 7. IF INDIAN'ALOTTEE OR TRIBE NA~ME ' ', 8. UNIT FARM OR LEASE NAME TRADING BAY STATE "'i 9. WELL NO. TBS A-32 ---i 10. FIELD AND POOL, OR WILDCAT ' - - He Tradin9 Bay - "C",; '!D,'.,.: m~o 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL coMpANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 99502 4. LOCATION OF WELL 1607' N & 556' W from SE corner of SEc. 4 T9N, R13W, S.M. 12. PERMIT NO. 77-18 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 RESUL.T~..FISHING. JO.BS?JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN BOLE CONDITION~.!' · ) ~ ~ ~ 9/3/78 6750' T Ski~ rig .over A-32. ~Rig up Meyers Run cutter. Pull 6260' ETD ~i'.~i~msC~ifjE~bh'g~ }~'S~6~O~tring. DisPlaced S.S. annulus 13 3/8"@4431' w/F.I.W(m~R~.~up on L.S. & bullhead 45 bbls safe seal 9 5/8"@6720' pill down L.S. across Hemlock Zone. Rig up Meyers open XA @4978' in L.S. bullhead 50 bbl safe seal pill across "D" zone. Rig up Meyers. Close XA @4978' open XA @4453' L.S. Circ. L.S. Take returns off annulus and S.S. Rig up Meyers and close XA @4453', open XA @4905' in L.S. Spot 30 bbl safe seal pill between hydraulic pkr. across "D". Rig up Meyers ~'-close XA @4905'. 9/4/78 6750' TD 6260' ETD 13 3/8"@3! ' Opened "XA" @4453' in L.S'. X-over to .5% KCL thru "XA" in L.S. (DiSplaced annulus first then S.S.) Installed BPV's removed tree, installed & tested BOPE to 2500 psi - OK. Pumped dow~ S.S. taking returns off annulus until clean. R.U. weathford to pull dual. Spotted 30 bbls 8 PPB dril-s w/20 PPB safe seal out "XA" in L.S. @4453' Relanded S.S. Pulled dual 3 1/2" strings w/140M & Parted S.S. & L.S. POOH Laying down 3 1/2" dual strings. 9/5/78 6750' TD Finished Pooh w/dual 3 1/2" Comp. Assy. Found L.S. parted 6260' ETD in "XA" @+4456' & S.S. @+4488'. Both above triple Pkr. 13 3/8"@4431' @+4490'.-(Note: Bottom-2 Jts. of Tbg. &,,both "XA" 9 5/8"@6720' sTeeves severely corroded). RIH w/ 8 3/8 impression block & tagged 2 3/8" dip tube string @+4435'. POOH w/I.B. (I.B. showed 2 3/8" collar looking up) --made up 5 3/4" over shot w/ 2 7/8" grapple & RIH attempted to engage fish @+_4435'. No Luck. POOH , redressed O.S. w/ 2 3/4" grappel. RIH 14. I hereby ~y that the~regg$~ is true and correct SIGNE~----~/--~:;_/~-/r~~''~/"~'=-~ T,TLE DISTRICT DRILLING SUPT. DATE 10/17/78 NO~'-Report on this form is required for each calendar 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. 9/6/78 9/7/78 9/8/78 & attempted to engage fish @+4435'. POOH & rec. 1 Jt. of 2 3/8" side string ~ remainder of L.S. (Note' While working tools on fish the 2 3/8" Jt. stabbed into the remainder of "XA"' on L.S. side and pulled it out ,of hole when fishing tools were POOH. L.D. fish. R!H w/ 5 3/4" O'.S, w/ 2 3/4" grapple to fish for remainder °f'2 3/8" side-string (Note' Fish still in Hole' 1 Jt of 2 3/8" side string, 1-3' Pup 3 1/2" on short string & Otis triple Pkr. w/ remainder of Comp. Assy. below triple Pkr. 6750' TD Completed RIH w/O.S, w/ 2 3/4" grapple & attempted 6260' ETD to engage fish - no luck. POOH redressed O.S. w/ 13 3/8"@4431' 2 3/8" grapple. RIH w/ O.S. w/ 2 3/8" grapple & 9 5/8"@6720' engage fish. R.U. dialog W.L. & RIH w/ 2 3/8" TBG. cutter still couldn't get thru fish. Trip W.L. for undersize 2 3/8" cutter - still couldn't get thru fish. POOH & R.D.W.L. Pulled 2 3/8" side string free & POOH w/same. Rec. the remainder of 2 3/8" side string & shear out sub. RIH w/ 5 3/4~'' O.S. w/ 3 1/2' control mill & 3 1/2" grapPle engage fish & POOH. Rec. 3 1/2" buttress X 3 1/7" 8RD cross-over. RIH w/ 5 3/4" O.S. w/ 3 1/2" grapple. Fish kept slipping off grapple w/ about +5OM# P.U. Wt. POOH redressed O.S. w/3 3/8" grapple. Fish kept-slipping off w/+25M# P.U. Wt. POOH redressed O.S w/ 5 3/4" guide shoe. Sta-rted in hole w/ O.S. & well started flowing. RIH to +4450' & circ. out approx. 8 bbls of oil & 10 bbls of gas. -SIDPP= +380 psi SICP= +_340 psi w/ oil and gas cut mud (+_60 pcf in ho-le). 6750' TD Completed circ. out of oil & gas cut mud. Bullheaded 50 6260' ETD bbls of 6#/bbls Dril-s, 14#bbls safe seal and 20% CACL2 13 3/8"@4431' down D.P. to stop lost circ. Displace well w/20% 9 5/8"@6720' CACL2 Brine. Shut in well - dead. POOH. Changed Hydril rubber. L.D.O.S. PU 3 1/2" spear on 9' of ext. Well started to fl ow again. RIH and cir. out +10 bbls of entry (OIL & GAS). Circ. well around +70#/C.F~ in and out. Shut in well' SIDPP=+200 psi, SI-CP= +160 psi (Need +77 PCF to kill well)~ Circ. well thr-u choke holding 300 PST back press while incresing mud wt. to 77 PCF. 6750' TD Circ, & cond.,W.O, fluid to 77+ PCF. Bullheaded 50 bbls 6260' ETD pill of 6 PPB Dril-s & 14 PPB Safe Seal to loss circ. zone. 13 3/8"@4431' Followed pill w/ 35bbls of 77+PCF brine. POOH L.D. spear. 9 5/8"@6720' RIH w/ 3 1/.2" grapple in 5 3/4" O.S. Engage fish & pulled l15+M# & fish came loose. Circ. well for 2 HRS. w/ 77 PCF in & out (2 full circulations). POOH to triple Pkr. (well took right amount of fluid coming out) L.D. triple Pkr. & 100' of Comp Assy. under triple. Well started blowing out L.S.-stabbed into L.S. w/ safety valve & RIH w/ Comp. Assy. on 5 Std. of D.P. & Dual Pkr. set itself @815'. (BTM of :Assy @2055'). 7 ~ 6750' TD Bullheaded 150 bbls of 79 PCF brine down D.P. & 6260' ETD 20 bbls down annulus. Followed w/80 bbls of 13 3/8"@4431' 84 PCF down D.P. & 20 bbls down annulus. Bleed 9 5/8"@6720' annulus off. (SICP 250 PSI). Pump down D.P. holding 600 PSI on Csg. taking partial returns thru choke. Pull up to BPV. Bleed D.P. to 0 PSI Pooh & L.D. dual pkr. 8 9/10/78 6750' TD L.D. 4 Jts. under dual. Well flowing again. 6260' ETD RIH w/ Comp. Assy. on 5° D.P. to 6100' & 13 3/8"@4431' Circ. out oil & gas cut mud. Build 83 PCF 9 5/8"@6720' gel-mud & X-over well to same. 9 9/11/78 6750' TD 6540' ETD (Junk) 13 3/8"@443l' 9 5/8"@6720' L.D. remainder of prod. equipment. RIH w/ PKR Picker & Mill over & rec. top 1' of Pkr. RIH w/ bit & D.O. & push Pkr. to 6540'. 10 9/12/78 6750' TD Set Baker Retrievamatic @4550' & tested 9 5/8" Csg. 4964' ETD above tool to 2500 psi - OK. POOH. RIH w/ gauge ring 13 3/8"@4431' & junk basket to 6200' Set Baker "N" Bridge Plug @6096'. 9 5/8"@6720' Perf'd 2-.3" HPH f/6056' to 6052'. Set Baker "K" cmt. Ret. @6009'. SQZ'D perfs f/6050' to 6052' w/ 300 sxs CL "G" w/ .75% D-31, .5% D-19, & .1% D-6 (Initial rate 6cf/min. @1300 PSI, final pressure of 3cf/min @600 PSI) PUll out of ret. & up to 5104'. Rev. ,c, lean. POOH. Set Baker "N" B.P. @5075. Perf'd 2- 3 @4964. SQZ'D perfs f/5027' to 5029' w/lO0 sxs CL. "G" w/ .75% D-31, .5% D-19 & .1% D-6 (Initial press. 10 cf/min. @2800 psi, final press. 4 cf/min @2600 psi) Had communication up annulus during entire SQZ. ll 9/13/78 6750' TD POOH after squeeze. RIH w/ Baker Retrievamatic w/ 5065' ETD stimulating valve and set pkr. at 4549' w/3500 feet water 13 3/8"@4431' cushion. Had medium blow for 5 min. Declined to slight 9 5/8"@6720' blow throughout test. Reversed out. Recovered 90 c.f. of entry. POOH. RIH w/ 8 1/2" bit. Drilled out cmt. ret. @4964'. C.O. cement to 5065'. Replaced cmt. cut mud w/75 PCF CACL2. 12 9/14/78 6750' TD Circ. & cond. CACL2 W.O. fluid f/75 to 78 PCF & built VIS 4960' ETD to +40 SEC. w/ 1PPB Safe-Vis-X, well gas cutting mud 13 3/8"@4431' prior to building VIS. POOH. Perf'd 4-.3" holes f/ 9 5/8"@6720' 5041' .to 5043' for resqueeze of above "D" Sand. RIH w/ cmt. ret. on D.P. & set @4960. 13 9/15/78 6750' TD COmpleted circ. btms up w/. 78#/ CACL2 & stabbed into 4960' ETD cmt. ret. @4960'. Attempted to break down sqz. perfs 13 3/8"@4431' 5027' to 5029' to 5041' to 5043'. Perfs held 3000 psi 9 5/8"@6720' equiv. 1.20 PSI/Ft. POOH - Reran ret. Stinger & Stim. valve on dry D.P. Dry tested perfs to atmospheric press. - 30 min. - OK. Rev. out gas cut mud from "C" Zone. Increased mud wt. 81#. POOH. Ran 9 5/8" csg. scraper and 8 1/2" bit to top of ret. @4960'. POOH. Ran Baker Model "B" circ. washing tool. · 14 15 9/16/78 9/17/78 6750' TD 'Located perfs @4815' to 4855'. Spotted acid 12% HCL, 4960' ETD 3% HF,7% sOlvent, .4% A-170, 5% W-5. Washed 13 3/8"@4431' "C" Zone perfs 4815' to 4855' w/ acid. Located 9 5/8"@6720' perfs 4685' to 4595' & washed w/ identical acid mixture. Held 1500 psi on csg. while washing perfs. Shut in well 1 hr. Circ. Btms. up & (had 340 PPM H2S in W.O. fluid) POOH. Ran Otis Type W.B. perm pkr. on W.L. and set @4500' above "C" Zone perfs. Ran 1/2" tbg. comp. assy. 6750' TD Stabbed into]~r~ pkr. @4500' - Pkr. failed to 4960' ETD. test. Set plug in "X" nipple @4543'. Tested tbg. to 13 3/8"@4431' 2500 psi - Held ok. Found Hydril on rig pump 9 5/8"@6720' leaking. Retested pkr. and held ok. Spaced out & landed 3 1/2" tbg. w/locator sub 1', above perm pkr. Remove BOPE & installed X-mas tree and tested w/5000 psi. Displaced tbg & csg. w/ F.I.W. thru "XA" @4465' Closed "XA" and pulled in "X" nipple. Released rig @ 1~'00 NOON. 9/17/78. Form 10~_~, RE~ 1- ~O~7~3 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL L_J OTHER 2. NAME OF OPERATOR UNION 0IL CO. OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASI~ 99502 4. LOCATION OF WELL At surface 1607' N & 556' W from SE corner of Sec. 4, T9N, R13W,S.M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 101' RT Above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20301 6, L~SE DESIGNATION AND SE NO. ADL 18731 7, IF INDIAN, ALLOTT[[ OR TRIB[~NAME 8. UNIT, FARM OR LEASE NAME' ' TRADING BAY STATE ~ _ , 9. WELL NO. TBS A-32 ~ 10, FIELD AND POOL, OR WlLD~AT/"'~:;~ * T~ABTNR RAY - "E" .11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. 12- PERMIT NO. 77-18 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L.--J PULL OR ALTER CASING L-..J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER sHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) See Below REPAI RING WELL ALTERING CASING ,,' · ABANDONMENT* (NOTEt Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent details, and give pertinent dates, Including estimated date of starting any proposed work. ISOLATED "C","D" AND HEMLOCK ZONES AND TEMPORARILY ABANDONED THE "D" AND HEMLOCK SANDS AND ACID SOLVENT WASHED THE "C" ZONE IN TBS A-32 AS FOLLOWS' Removed tree, installed and tested BOPE. RE,CEIV_FD . . Pulled and layed down existing dual string 3 1/2" production equ i pment. Cleaned out with 8 1/2" bit to ETD of 6540'. B~ock squeezed fo~ zone ~sol~[~on peffs 6050' ~o 6052' ~i~h 300 cm~. ~hru cm~. ~e~. a~ 6009' end .B.P. ~ 6096'. Block squeezed for ~sol~on peffs 5027' ~o 50Z9' ~h 100 sxs cm~. ~h~u cm~. re[. ~ 4964' ~nd B.P. ~[ 5075'. 5. Cleaned out with 8 1/2" bit to ETD of 5065'. e Perfed 4-.3" holed from 5041' to 5043'. Tested perfs for zone isolation thru cmt. ret. at 4960' - OK. 16. I hereby certify that the foregoing is true and correct (This spa ate office usa) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- Dist, Drlg. Supt T IT LE ' DATE TITLE DATE See Instructions On Reverse Side CONT'D' e Acid solvent washed "C" zone perfs 4815' to 4855', 4685' to 4595' with 23 gal/ft. 12% HCL 3% HF 7% Mutual solvent 4% A-170, .5% W-5. ' ' , · e Ran single string 3 1/2" production equipmen~ with perm. pkr. at 4500'. 9. Removed BOPE, installed and tested tree. 10. Placed well on gas lift produCing from the "C" Zone. RECEIVED O(;T Division of Oil & Union Oil and Gas Division: Western Region Union Oil Company .,alifornia P.O. Box 6247, AnchOrage, Alaska 99502 Telephone: (907) 276-7600 union August 9, 1978 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99510 Dear Mr. Hamilton' Transmitted for approval and information are the following duplicates of State forms that were not received 'in y. our office .via our transmittal of July 26, 1978: TBUS G-12RD-2 TBS A-11 TBS A-14 Completion Report Subsequent Abandonment Sundry Notice Sundry Noti ce II II II II II II S i ncerely yours, lender Dist. Drlg. Supt. Form 10-403 REV. 1-10-73 Submit "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L ITl GAS I---1 WELLl~ i WELL! I OTHER NAME OF OPERATOR Union O'il Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL At surface '1607'N & 556'W from SE corner of Sec. 4, T9N, R13W, S.M. 13. ELEVATIONS (Show whether OF, RT, GR, etc.) 10I'RT above MSL .. 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-133-20301 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 :7. IF INDIAN~ ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State WELL NO. TBS A-32 10. FIELD AND POOL, OR WILDCAT Tradinq Bay. - "C", "D", Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. .. 12. PERMIT NO. 77-18 )orr, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~. MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ~e~ [-)e'~ DW SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING C~ASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. To isOlate the "C", "D" and Hemlock Zones, temporarily abandon the "D" and Hemlock sands and acid/solvent wash the "C" Zone in TBS A-32. PROCEDURE' · 2. 3. 4. 5. . 7. 8. 9. !':' Move rig over A-32 and rig up. Remove tree, install and test BOPE. Pull and lay down existing dual 3 1/2" prOduction equipment. O;,vision Clean out to ETD with bit and scraper. . ~-~ .... Test for zone isolation between Hemlock-"D" and "D"-"C" thru cement retainers set at +6200' and +4900', respectively. Squeeze as required. Note' This tempor~ril~c,qband~ns the wellbore below +4900'· , Acid/solvent wash all Zone perforations with 5% ~CL and 7% solvent· Run single string 3 1/2" production equipment· Remove BOPE, install and test BOPE. Place well on gas lift producing from "C" Zone 'sand. ESTIMATED OPERATING TIME' ESTIMATED START DATE' August 21, 1978 20 days 16. I hereby certify that the foregoing Is true and correct 2~-dlm k. galiender CONDITIONS OF OVAL, IF ANY'. · 'See Instructions On Reverse Side 7/25/78 DATE APproved -opy Returned Union Oil and Gas'"'~,ion: Western Region tJn~on Oil Company Of California t-) O. Box 6247, Anchorage, Alaska 99502 Telepl~one: (907) 276-7600 union October 20, 1977 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 RE' TBS A-20,~ MONOPOD PLAI~uRM Dear Mr. Gilbreth' Enclosed for your files are two (2) copies of the Well Compl.etion Report for the above captioned projects. Sincerely yours, *'J:~m ~.~ Call ender Di's"~7 Drlg. Supt. Encl. sm cc- USGS Division of Lands Marathon Oil Co. SUBMIT IN DIJI'~.Z¢ATE* STATE OF ALASKA (see other In- st ructions on reverse side! OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: b. TYPE OF COMPLETION: .~'rw ~-~ wonK ~-l WgLI, OVER oxt, ~ ~As [2 WELL WELL DEEP-[----] PLUG[---] EN BACK 2. NAME OF OPERATOR Union Oil Company of Calif{~rnia 3. ADDRESS OFOPERATOR P.O. Box 6247 Anchorace. Ak AP1 NUNIEI{ICAL CODE 50-133-20301 LF_.A~E DESIGNATION A-ND SERIJkL biO. ADL-18731 IF INDIA.N, ALLOTTEE OR TRIBE NA_M.E 8. UNIT,FA-HIVI OR LEASE NAME Tradin9 Bay State 9. WELL NO. TBUS 032 S AND POOL, OR WILDCAT Section 4' t~n, R13W, S.M 4. LOCaTmN Or ~o£LLd(Reoort location c. learly a~d in accordance with any State requiremeats)* At'surface nuctor 25, Monopod Platform 1607'N & 556'W of SE n. SEC.,T.,R..M..(BOTTOMaO~ corner section 4' TgN, R13W, S.'M. om~c~IvE> *t to~ ,rod. int~rva~ ,epo~ted b~,o~ 35'S & 860'W of~ surface location or 1572'N~p~1416,W of SE corner sedtion 4' TgN, R13~, S.M. At total 756'N & 325'W of surface location or 2363'N & 88l'W of SE corner, section 4: T9N, R13W, S.M. 77-18 5-20-77 6-15-77 8-9-77 RT lOl' Above MSL 6750 TMD/ 6304 TVD [ ~ow~.~, 2 ROTA"Q__67.~l,TO0'.S 22. PRODUCING INTerVAL(S), OF THIS COMi:rI.2gTIO~NI--TC~P, BOTTOM, NAME (MD AND TVD)* "C" Zone Top 4595' TMD 4380 TVD Bottom 4855' TMD 4610'TVD 24. TYPE ELECTRIC AND OTHI/2{ LOGS RUN Dual kat..er, lo_q, GR, BHC Sonic, FDC-CNL-GR, GR-CBL-VDL . , . 25. CASING RECORD (Report all strings set in well) 20" [ ':' 94~ I H-4n'! 221" I 20" ! Drivan tn ppl' NONE 16" 65# [ H-40[ 502'~ ~.~.26~,, ICMTD to smufaie 870 CF 133_/8" [ 61~ A ~1 ~_~ [ 4451'" ~JL17. o ~ CMTD to 'smmfaCe 130(} CF 9 5/8"i. 47~ -'1 N--~O[ 6724'I ~ 12 1/4"l CMTD w/ 2300 CF 26. LINER i~ECO~ 27. TUBING RECOPY) T - ' · ~ ' ' i '" "" ' 28. PERFORATIONS OPKJq TO Pi~)DUC~ON (interVal, ;iz'g and number) ' 4 hpf w/ 3 1/8 csg gun "C" ZOne 4595-4685/90' INTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL ! SURVEY MADE J Yes A-MOUNT PULLED NONE NONE .,NONE DEPTH SET (MD) ~ PACKER SET (MD) 29, ACID, SHOT, F:~A, CT(JRE, CEAIENT SQUEEZE, ETC. 4815-4855/40' 3e. PKODUCTION D"EPT~II 1NTEiRVAL (MD) 4595-4855 AMOUNr .,'d'qD }21ND OF MA'I~i?-,'AL USED Acidized- 4000 .qal .15 HCL DATE FIRST PFiODUCTION 8'10-77 DATE OF TEST, I~ouRs TEST:n) '[CI:OXE S~ZE IPROD'N FOR I :' I t I 80 1 :s~. 66 [ 978 [=:'~°u~*~i ]'60 111 32. £XST o~ AT{kCH~XE.~TS PRODUCTION METHO'D (Flowh~g, gas lifi, pumping--size and type of pump) GAS LIFI OIL,--BET,. 'WELL STATUS (Producing or snut-ln) ProdtJcina G.a.S--1VLCF. WATErC--13BL. [ GAS-OIL IL~TiO W~BBL. ]OIL ~g~VITY-~I I 4. J 2L2 ..... ~,~. TEST WITNESSED BY Jim Watson 33.'I herebY- lief%fy that the._.fore~oing a.nd attached information is complete and corre'ct as determined from all-avitlable records · ~l..' ~/. (-),~,_ .~..__. Dist. Orlg___~. 5upt__. ____ ._... __!p/20___.~/?~7 ._ *(See Instructions and Spaces lot Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed fo~ subr.~tt~ng a complete and correct well completion report end log on all types of lanJs and leases irt Alaska. Item: 16: Indicate which elevation is used as reference (where not other,vise shown) for depth measure- rnents given in cther spaces on this form and in any attachments It~m~ ]0, ~ncl 22:: If this well is completed for separate production from more than one interval zone (multiple completior0, so state ~n item 20, and in rte,'- ?2 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separale report (page) on this form, adequately identified, for each additional interval to be seperately produce.q, show- ing the adiditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item ~28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '34. SUMM'AlrtY OF IPORMATION TESTS IN('I,UI)IN(; INTF, IIVAI., TE,~TEr). PI]£,KqUII£ DATA AND '~,C0VEIIlES OF OIL. GA[~. ,'15. G ~D~I.,OG I C MARKEP, S WATEII AND MUD i N ANI'IE MEAS, DE'PTI{ ~U~ VKIIT. Flow test 5506'-5508' gas rate stabilized @ 1.5 MMCF/D .......... Flow Test 5530'-5912' (106' perfs) gas flowed @ 8.6 MMCF/D w/ 700 psi surface C-7 sand 4592' 4380' pressure D Zone 5422' 5123' Flow test 5530'-5912' @ 4.5 MMCF/D E Zone 5941' 5591' F1 ow test 5285' -5345' gas fl owed @ 2.5 MMCF/D G Zone 6115' 5790' F1 ow test 6260' -6560' oil rate of 165 BOPD w/ 30% cut Hemlock 6250' 5867' Flow test 6260'-6560' rate of 19 BOPD w/ 30% cut W. Foreland 6576' 6157' Flow test 4595'-4855' oil rate of 92 BOPD, 304 BWPD i i i i i mill · i i iii i ii ii i! , i i' i i ARB B-1~!/2~'"'Plq. I.,) $~I:I~O~&ZS O~ ()lb, --~.AS OR WAT~.. ~[ i i i i i i i ii , ..... , .... r ....... SUBMIT IN DUFLICATE* STATE OF ALASKA (See other In- st ructions on reverse side) OIL AND GAS CONSERVATION CO/~MITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: oIL ~xs ~ W~LL ~ WELL DRY Other. b. TYPE OF COMPLE~ON: 2, NAME OF OPERATOR . . 3. ADDRESS OF OPERATOR ,:/.;~',t ~; ' :: "~ :'~ 4. ~,OC~TION 0F WELL'-(Re~0rt location c~eari~ and in accordance with any State requirements)* At su~ace 22. PRODUCING INTERVAL(S), OF THIS COMI~LETIO'N--TOP, BOTTOM, NAME (MD AND TVD)* Top, 6260 TMD 5868 TVD Hemlock Bottom 6560 TMD 6135 TVD LS. API NUiVLF, R/CAL CODE 6. LF.A~E DF_~IGNATION A. ND SERIAL NO. "/. IF INDIA.N, ALLOTTO:E OR TRIBE NA/VI~ 8. UNIT,FAIllVI OR LEASE NAME 9. WELL NO. :i-i:~BuS A-32 L OBJECTIVE) At top prod. int,rvalreported below586'N & 472~hI of. sur2[~g,e ~t,i~n. or 2193'N & 1028'W of SE corner section ~: ivm, M. At total depth 12. PERNiIT NO. ~ I-IOWM. A NY* I~OTARY TOOLS ' ' CABI,E TOOLS ' 23. WAS DIRECTIONAL ! SURVEY MADE 24. TYPE ELECTRIC AND OTHER LOGS RUN CA~SLN G SIZE i CASING RECORD (Report all strings set in well) WEIGPIT, LB/FT. DEPTH SET (1VID) PIOLE SIZE 26. LINER IR~ECORt) 28. PERFORATIONS OPTM TO PRODUC21~LON' (interval. size and number), 6260-6400/140' 4 hpf Hemlock 6430-6560/130' w/4" csg gun CF~%~LNTING RECOP~ i A~MOUNT pUT.I,KT) ~27. FUBING - DEP~ SET (~D) ~ PACI~ER SET (MD) SC~L~ (MD) SIZE , ACID. Si~OT, F~A~TURE, C~iENT SQUEEZe, ~C. D~i iNT~V~ (MD) [ AMOUNT ;~D ~2IND OF MA~Z?dAL USD 51Z0-5140 ~ SQZD w/ 100 sx Cl. G ;g315-5345 [ SQZD w/ ]00 ~x Cl. G cmt 54z5-5455 ~ SQZD w/ 200 sx Cl. G cmt cont. on back , 30. PRODUCTION OIL--BBL. G.%S--1VICF. DaTE O1' TEST. [}{OURS TESTED ' [CIIOI{E_ SiZE]PROD'N FOR 4 . ~ -9/27/-77 . [ =--~BL ~-. Ph%%!OD ~OW, ~BIN~ ~CAS~G PRESS~ [CAL~~ OI . .1 73: . al. mseosn'~o~ or ,~s (8old, u,ed lot tuel, vented, etc.) Il9. ] V4'ELL STATUS (Producing or shut- in) producing WATEIt,-BBL. [ GAS-OIL P~A. TIO .3_ . I 3 1 ...... WATEH~-BBL. I OIL GRAVITY-~I (CO~.) I I 3z.0 I Jim Watson 82. LIST OF ATTACHMENTS GAS--~CF. 3078 33. I hereby c~y that the forg~o,ing and attached information is complete and correct as determined from all-available records ._ ........ ii *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is des,gned for submitting a complete and correct well completion report and log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given ,ncther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p,c.Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a--separate report (page) on this form, adequately identified, for each 'additional inte, val to' be seperately produceJ, show- ing the ack:litional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shouIJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~cl. (See instruction for items 20 and 22 above). 35. G IDOL,OG I C' WAT~[t. AND MUD NAM~ * 29. cont .... ~,~a~. 6~ ~v~.'b~, 5765-5815 SQZD w/ 255 sx Cl. "G" cmt 626~-6560 Stimulate w/ 2000 gal 7~% HC1 & 12,500 gal 12-3 mud acid 6510-6560 Frac w/ 45,000 gal gelled & treated 6% KCl water & 95,50~ 0f 20/40 sand. 6300-6350 Frac w/ 45,000 gal gelled & treated 6% KC1 water & 95,50~ 0f 20/40 sand. . .. : ~g. COn. E" DATA. A~rAcII B~IE~' D~C~PI~O~S O? LITI.IO~OGY, POROSITY, ~AC~R~. AND~ ~'~ECT~t~> SUOWS O~ OtC, G~S O'~ xVAm~. ..................... :orm D- 1001-~, UNION OIL. CO. OF CALIFORNIA R~_PAIR RECORD LEASE TRADING BAY STATE WELL NO__A-32 CONTRACTOR PARKER DRILLING COMPANY ?IELD - TRADING BAY TYPE UNIT OILWELL 96-1600 5EGAN' 4/1/80 COMPLETED. 4/4/80 ELEVATIONS: GROUND ?ERMIT NO. 77-18 SERIAL NO. ADL-18731 / CASING HEAD 2OMPA_~Y E~GI:.TEER Wat;~, Boul~r.a~ ~ ~ TUBING HEAD qPPRO¥ ED_~S. ~2~._ ~_~2~.'/~.-'~~/_//f~/ ROTARY DRIVE BUSHING 110' ' '' -- 'I I// CASING & TUBING RECORD ..... SHEET PAGE NO. to MLL%: -sZZE I .~.~.E~ TH ! WE:.~HT-- G~ADE I I:~EI~ Al::{ IK ~' 20" Z21' 94(; Drive Pip~,~ Pre-Driven. 16" 502' 65(/ H-40 Butt~ Cmt'd. thru shoe w/500 sx. "G" w/Gel & 200 sx. "G" neat. Cmt'.d annulus thru stinger w/50 sx. "G" w/10% sand. 13 3/8' 4451' 61(/ & 68(/ K-55 Butt Cmt'd thru shoe w/928 sx. "G" w/Gel & 200 sx. "G" neat. Cmt' thru D.V. @ 2199' w/878 sx. "G" w/Gel & 200 sx. "G" neat. PERFORATTNG RECORD ~ATg INTEl=IV-AL ~.T.D. ' REASON .... PRESENT CONDITIO~ 6/19/77 5506'-5508' 6645' F.C. Isolation Sqz. Sqz'd w/100 sxs. 6/22/77 '6510'-6560' " " Production Lower Hemlock. 6/23/77 6300'-6350' " " " Hemlock. 6/'25/77 6260'-6300' " " -" " ", 6350 ' -6400' " " " " " 6430 ' -6510 ' " " " " 6/27/77 5852'-5912' 6200' ret. " "D" zone 57-2 " 5765'-5815' " " " "D" zone 56-1 sqz' d w/600 sxs. " 5630'-5662 ' " " "- " 54-9 " 5590 '-5606 ' " " " " 54-5 " 5530'-5560' " " " " 53-8 " 5425'-5455 ' " " " " 53-0 sqz' d w/250 sxs. , INITIAL PRODUCTION AFTt DATE I INTERVAL NET OIL CUT GRAV. Q.P. T.P. c~HOKE MCF GOR REMARKS · · . · .. . · , . t (' V " .. . Aj~'--- 0il . . . . : . -.; . . ..,' ',." . . · : . . 9/17/78 "C" zone f'cff zone 2OMPLETION DATE: PRODUCING :NTERVAL: :NITIAL PRODUCTION' WELL HISTORY PRIOR TO REPAIR -- LAST COMPLETION NO. 4595' -4685' , 4835 ' -4855 ' 265/262, 1.1% LAST REGULAR PROD. & DATE: t'C" zone ~UMULATIVE PRODUCTION' %EASON FOR REPAIR: To frac. pack the "C" zone. / \"V IZLI_ I 'ZCOi~I.3 $ I-I D.' ;""f A PAG[' t, IO. TRADING BAY STATE ';'f!?.f,1) Trading Bay ,OCATION -- WELl, NO A-32 SPUD DA'fi'; 4/1/80 COMP. 1)A CO?..vL'IIACTOi~. Parker Drilling Co. TYPZ' UNY[' Oilwell 96-1600 4~4~80 RIG NO .... ,.b,.,,~MIt ~0. 77-18 DEVIATION (B.II.L.) COMPANY. ENGI"~EER,, SIZE 9 5~/8" V;EIGlfT ' 9.2t/_ _ SERIAL NO. ADL_-]._8.2.3~ T.V.D. Watson, Boulware TI-tREAD GRADE Butt. ELEVATIONS: Vd;VI'ER 1)l']lYl'iI IL T. TO OCIt:AN FLOOR 11. T. TO ~,I LI.,W 11.'1'. TO DHILL DISC.', R.T. TO PIIOIPUCTION DECK CAoli'TG .... ,~., D I-1P T ! [ Butt. N-80 6724' 4576' IIE',IAi{i<S Cmt'd thru shoe w/2000 sxs. cl. "G" w/.75% D-31~... .3%~__D-!9, & .1% D-6. Single tbg...string w/Otis prod. pkr. @ 4500'. PERFORATING RECORD 5852'-5912-- 6187"' r~tJ Production]. Isolated" zone 3/-z so. '"' 5590'f5606' 'r " Isolated "D" zone 54-5. sd. " ' 5530''5560' " " Isolated "D" zone 53-8 sd. 7/10/77 5315'-5345' 5400' ret. ' ' ' "' Isolated "C" zone 51-6 sd. . . ~/11/77 52B5''5345' -' " " 51-6 sd. Sqz'd w/100 sxs. _ _ " 5120'-5140' '5095' .ret. " 5023 sd. Sqz'd w/.100 sxs. 7/13/77 4655'-4685' " " "C" zone C-7 sd. Open ..... 7/14/77 4595'-4655' " " " " " 7__/1517__! 4835'-4855' " ....... " " 47-5 " 8/6/77 _ ~530'-6550' 66452 F.C'. " Hemlock Isolated. . 8/7/77 6~30'-6530' " " ' I " " '' ' ' " 6260'-6400' " " " " 9_~ 6050~-6052' 6096' B..P. B.S. Sqz'd W/300 sxs. t%%u, ret.@ 600 '. " ~n?7'-5~?q' 5075' B.P. " Sqz'd w/100 sxs. thru ret.' @ 4964'. , 9/i3/78 ~04i'~5043' 5065' cmt. "~C°uld not break' down peris w/1.2 psi/ft, grad. _ -- , DATE IIITEiRVAL INITIAL PIRODUCTION .N~T Olnl cut.'.:'tCm,,._~_.l C.P. T.P. · . TYPE:' Cameron & OCT GOB .! ' CASING HEAD:. 20" 2000 psi OCT ."Uni-head". CASING HANGER: OCT 13 3/8'-' & 9 5/8" type "d-22" slips 20" 2000 psi x 12".'3000 psi OCT CASING SPOOL: TUBING HEAD' 10" '5000 p~i. x 12'! 3000 psi CIW type "DC-~'. ' TUBING IIANGER: Single 3½" CIW. TUBING tIEAD .TOP" 10" 5000 psi. MASTER VALVES: . . CH Ii !STa. IAS 'FR I']E TO P CON N.: 3½" EUE. PAGE LEASE Trading Bay State UNIO I OIL CQ'-'PA h' OF CALIFORNIA lfCO IN~LL ~'..I0, TBS A-32 FIELO Trading Bay "C", "D", Hemloc 4/1/8o 2 4/2/80 3 4/3/80 4 4~4~80 6750' TD 4960' ETD (let.) 13 3/8" C. 4451' 9 5/8" C. 6724' 6750' TD 4960' ETD (~mt.) 13 3/8" C. ~451' 9 5/8" C. 6)24' 6750' TD 4960' ETD (~et.) 13 3/8" C. ~451' 9 5/8" C. 6 24' 6750' TD 4960' ETD (: et.) 13 3/8" C. ~451' 9 5/8" C. 6724' DETAILS OF OPERATIONS, DESCRIPTIO~IS g RESULTS Began operations on A-32 at 00:01 hrs. 4/1/80~ RIH w/ Meyer's W.L. and opened "XA" and set "X" plug in "X" nipple at 4543'. Pressure tested tubing to 5000 psi - OK. Retrieve "X" plug. Have 300 psi on tubing. Wait on frac. equipment. Offload frac. equipment. Rigged up Dowell and pressure test lines. Test lines and frac-pack "C" zone thru 3½" tbg. w/ 176,000# sand. Offload frac. equip. M.U. small BOP's and flowlines. RIH w/2¼" drag bit on 1¼" CS hydril tbg. to 4664'. Circ. out gas cut fluid. RIH to 4765' & plugged bit. Pooh. RIH w/O.E, tbg. and C.O. sand f/4732' to 4951'. Pumped viscous sweep every 70' of hole. Circ. for 2¼ hrs. Pooh laying down 1¼" tbg, RIH w/W.L. & sinker bar and tag ETD @ 4943'. Pooh. Released rig @ 24:00 hrs. 4/4/80.~ .... ~ · :DESCRIPTION' TUBING DETAIL" ~2.'MUle'.Shoe' <(3"l/2"'"But~ x '3 1/2'.' 9.2~."B~tti::tb "3 1/2"..I'X'!.Nippl~ 3' 1/2" ~3 1/2'!' BU~%j~'.4'. 'N.U:~ ~5" Seal'A~em~i~~ Perm.' Per';::"@ 4500'~ Locator 3 'l/2"'B~tt" 4'1/2,' N.U.''X-Over ":3 1/2'".[!'XA"' S " iff3.1.1/2".'9.. . 2#'=Butt~ ):.'3'1/2" KBUG G.L.M: 9.2# Butt~j/tb 9.2# But KBUG G': 9.2# BUtt~:::''t KBUG 9.2#' TRB Safety'Val~e:' 9~2# Butt tb ' - . Butt· Butt.' x 3 1/2"'BRDX-Ove=~ J.,3 1/2". !~'~"-' 1/2,' -" ..'3 1/2" . . . :/.'!3 1/2" ~'::3 1/2" . -:' 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" Cameron Hah Landed below KB: ...-:-.,~-;. ~-., :. :.-.. _ . , .-:-.,,;,.., ,/.. - ,.. ~.; . . ' '., :'.' :? "~ N U'i X-Over "'LENGTH';' ' BOTTOM : .. ;..f..,...~/..., ::..'. :..v. )'("%71' :;" 4576.60' 4575.89' · ' '"" 4575 89".i('-"4574 97. 31'~'73':::) 4574.97.'...J"/ 4543.24.".". .... ~.' ?;'4543 30 s' 3 "_: ':' 4511 25' ":' ' 4510.42 ' 'i 11.37 'j:.i'..'4510 "4~99. . .:!!.::, ~, :.: '. 4499.05~'.i 4498,20 '/::?.~.":'/449S. 20' ,::/':.:: 4497.23,' 28' 59' :' 4497 23"i:i'/':''4468 6471 i~.04"iiJi~{/.'4468.64".:':~' 44.64'.60'i;" : 28'35' '.'? 4464 60"i':i7.:i.4436 25, O..:-'. 4436.25"./!']" 4429.65 431.52 ':ii'~!~ 4429.65."?':.:{i:{J'3998.13":'~ · . ..... ' '~ !~';"'"' 3991.'53 .6.60" '" 707' 70'...,:~i'i:' 3991 53' '.;V '3283 83 ! . · ., :: ,',?..,..L ,. '"" " .....' '?.::' 3277.23 .:. 6: 60 ':;.,.! .3283 ·'83 ' · i239 61"~:':"-.'3277 23"t'i"~'~' 203'7 ':6: 60,;?: 2037.62 2031.02 · 1727/.94' ):.::!"2031.02':, ::"303.08' '8.60' l/:ii 'j": 303· 08 :256 26~'i::?~'F'294 48' 38 · ' ;L;..i~ . 4'. 10 ~':.:i?~:~i!:::"' 38.22 '"' .. ,,,..?:! (~.:.?? :?': 52...'.~-:-,-, 34 .;'.33.60 ;' 1. O0"'t"}:::~!~[:::!,: 33. 60 32.60 ~ 3 HANGER:' ~ i , Ill Tubing Detail 1. 3 1/2" Camco TRB-6 Safety Valve - 295' 2. 3 1/2" Camco GLM- 2,032' 3. 3 1/2" Camco GLM- 3,278' 4. 3 1~2"'Camco GLM - 3,992' 5. 3 1/2" Camco GLM- 4,431' 6. 3 1/2" "XA" Sleeve - 4,465' 7. Locator - 4,499' 8. Otis Perm. Packer- 4,500' (11' of seals)' 9. 3 1/2" "X" Nipple - 4,'5'43' · 4 1/2" Mule Shoe - 4,577' 11. Baker Model "K" Ret. - 4,960.' ~502' - 16" 65f/ H-40 Buttress csg. 4451' - 13 3/8" 61 & 68# K-55 Buttress Csg. 8 11 I "C " Zone 4595' - 4685' 4835~ - 4855' DATE J Trading Bay State Well A-32 W.O. j ~.---- ........ Wel_l Schematic · ' 9/78 ..... --j c,,_ ......... ....... ~ ~_ ~_ ....,,__ _ ......._ ...... _. ~ .... _ 6724' - 9 5/8" 47# N-80 Buttress .... -- ] --.~ AL__ __ i. o~^'~-- , cks. ___.___J A/'P'D, DATE ' i i i · ~ - '~-~ :otto D-IOO1-A UNION OIL CO. OF CALIFORNIA REPAIR RECORD LEASE TRADING BAY STATE WELL NO. A-32 ?IELD TRADING BAY }EGAN: 9/3/78 COMPLETED 9/17/78 ?'ERMIT NO. 77-18 ,~qD~IAL NO~.A~.-lg73] LOMPA',:Y F_,,NGI:TEER ~ / , ./////%~ /./ .,,~.,,.,, / U ~ CASING & TUBING RECOR_D 20" 221' 94# Drive Pipe Pre-driven SHEET A PAGE NO. 16" CONTRACTOR _~RILLING CO. TYPE UNIT OILWELL 860 MOD ELEVATIONS: GROUND CASING HEAD TUBING HEAD ROTARY DRIVE BUSHING t10' to MMU. REMARKS 502' 13 3/8" 4451' 65# 61# a 68# H-40 Butt. {-55 Butt· Cmt'd thru shoe w/500 sxs. "G" w/Gel & 200 sxs. "G" neat. Cmt'd annulus thru stinger w/50 sxs. "G" w/10% sand. Cmt'd thru shoe w/928 sxs. "G" w/Gel & 200 sxs. "G" neat. Cmt'L thru D.V. @ 2199' w/878 sxs. "G" w/Gel & 200 sxs. "G" neat. RATING RECORD DAT]~ IN'r£RVAL ~.T.D. REASON PRESENT CONDITIO.,N/,.~, :~- · 5/19/77 5506' 5508' 6645 F.C. [so'lation S tz Sqz'd w/100 sxs ~-.~ -- · · ~. : 6/22/77 6510' 6560' " " Production Lower Hemlock '~ ~'~ /" "-. 6/23/77 6300'- 6350' " " " Hemlock ~/~-.~. · 6/25/77 6260' - 6300' " " " " ..... '""'' " 6350' - 6400' " " " " " ~'"'""' " 6430'- 6510' " " " " ~'"~'"~,~,-~ 6/27/77 5852' - 5912' 6200' ret. "D" Zone 57-2 '' " 5765' 5815' " " " Sqz'd w/600 sxs. "D" Zone 56-1 " 5630' - 5662' ' " " " "D" Zone 54-9 " 5590' - 5606' " " " "D" Zone 54-5 " 5530' - 5560' " " " "D" Zone 53-8 " 5425' - 5455' " " " Sqz'd w/250 sxs. "D" Zone '53-0 , ' DATE I INTERVAL NET OIL CUT GRAV. C.P. T,p, CHOKE I MCF GOR ... 10/04/7~ "C"Zone 76 0% Gas lifted 10/06/7~ " " 23 34% Gas lifted 10/10/71~ " " 262 1.1Z 225 . .. . 10[14/7~ " " 193 1.5g 220 . · 11/08/7~ ,, ,, 167 5.6% 165 12/02/7~ " ~' 121 0% 120 : . · · · , · · · . · , . . ,. ., · .... WELL HISTORY PRIOR, TO REPAIR LAST COMPLETION NO.. 1 '" ZOMPLETION DATE: 8/9/77 PRODUCING ~NTERVAL: Hemlock: 6260'-6560': "D". Zone: 5425'-5912' : ."C", 7. on~..: 4595 '-5~/,5 '. :NITIALPRODUCTIO~: H~'nlocIr: 78/60, 23%,'3078 MCF/D, ''Ct' Zone: 164~Q: 2.4%; 143 LAST REGULAR PROD. & DATE: Hem1 ock 2UMULATIVE PRODL'TCTION' %EASON FOR REPAIR: To temporarily abandon the Hemlock and "D" Zonem ~nd r~onmpl~t~ as a "C" Zone producer. SHEET A UNION OIL CO. Oi-- CAL. IFO', i",IIA '~/VELL RECORD PAGE NO, LOCA~ ION NO. SPUD DATE COt, · RttCTOI%, %YP~. UNIT COMP. DATE RIG NO. , DRILL PiPE DESCRIPTION PEXMIT NO. SERI.M_, NO. T.D. T.V.D. .DEVIATION (B.H.L. COMPANY ENGINEER. SIZE [ WEIGHT 9 5/8" 47#. 3 1/2" 9.2# THREAD Butt Butt GRADE N-80 N-80 ELF;CATiONS: WATER DEPTH R.T. TO OCEAN FLOOR IR. T. TO MLLW R, T. TO DPdLL DECK R.T. TO PRODUCTION DECK APPROVED: CAS_I_.5J~ & TUBING RECORD DEPTH 6724' 4576' REMARKS Cmt'd thru shoe w/2000 sxs Cl. "G" w/.75% D-31, _ .3% D-19, and .1% D-6 Single tbg. strin~ w/Otis prod, pkr. @ 4500'. PERFORATING RECORD D~TE t I[LT_E1TVAL F~T~D .... ~F_~B_ON P~ESE~T CONDITLQ_~[. ~ 7/~/77 5852'-5912' 6187' reg. Production Isolated "D" Zone 57-2 sd. ... "' 5590'-5606' " " Isolated "D" Zone 54-5 sd .... ~ ". 5530'-5560' " " Ilsolated "D" Zone 53-8 sd ..... 7~%0/77 531~'-5345' 5400' ret. __ " Isol'ated."C" Zone 51-6 sd. 7/11/77 5285'-5345' " " S~z'd w/100 sxs. '51-6 sd. " 5120'-5140' 5095' ret. " Sq~'d w/100 sxs. 50-3 sd~ ..... ~'/13/77 46~.5.'-4.685' "' " Open "C" Zone .._ C-7 sd. . ~./14/77 4595'-4655' ' ,, ,, Open "C" Zone C-7 sd. .. .,. 7./15/77 4835'-4855' " " Open 'iC" Zone .47-5'sd. 8/6/77 6530'-6550' 6645' F.C.' " Isolated Hemlock ~/7/77 6430'-6530' ,, "' h ~Isolated Hemlock " 6260'-6400' " " lIsolated Hemlock · ,? 9/12/78 60~0'-6052' 6096, B.'~. B.S. Sqz'd w/300 sxs. thru ret.' @ 6009' ,, 5027,_-5029, 5075' B.'P. B.S. ' Sqz,d w/10~ sxs. thru ret. @ 4964' ..... ~/i3/78 5041'-5043' ~065' cmt.... B,S. tCould not.break down peris w/l~2 pSi/ft, gra~[.~ · , ,, INITIAL PHODUCTION . DA.T'E_ 'I'.'ITERVAL NET OIL CUT .... GRAV. C.P.. T.P. I .CP[OKE ~__~C.F GoB .! · . · · .. ,%,VELL~_SSEi~4BLY TYPE: CASING HEAD:... CASING HANGER: CASING SPOOL: TUBING HEAD: TUBING HANGER' TUBhNG tlEAD TOP' MASTER VALVES: MAS FR~_.E TOP CONN.:_ LEASE UNION OIL COMPANY OF CALIFORHIA WELL RECORD WELL NO. FIELD SHEET D PAGE NO. 3~ DATE 9/3/78 9/4/7'8 9/5/78 9/6/78 ETD 6750' T 6260' ETD 13 3/8"@4431 9 5/8"@672O 6750' TD 6260' ETD 13 3/8"@4431~ 9 5/8" @ 6720' 6750' TD 6260' ETD 13 3/8"@4431 9 5/8"@6720' 6750' TD 6260' ETD 13 3/8"@4431 9 5/8"@6720' DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Skid rig over A-32. Rig up Meyers. Run cutter. Pull B.U.'s f/Long & Short String. Displaced S.S. annulus w/F.t.W. Rig up on L.S. & bullhead 45 bbls safe seal pill down L.S. across Hemlock Zone. Rig up Meyers open XA @4978' in L.S. bullhead 50 bbl safe seal pill across "D" zone. Rig up Meyers. Close XA @4978' open XA @4453' L.S. Circ. L.S. Take returns off annulus and S.S. Rig up Meyers and close XA @4453', open XA @4905' in L.S. Spot 30 bbl safe seal pill between hydraulic pkr. across "D". Rig up Meyers & close XA @4905'. Opened "XA" @4453' in L.S. X-over to .5% KCL thru "XA" in L.S. (Displaced annulus first then S.S.) Installed BPV's removed tree, installed & tested BOPE to 2500 psi - OK. Pumped down S.S. taking returns off annulus until clean. R.U. weatherfordto pull dual. Spotted 30 bbls 8 PPB dril-s w/20 PPB safe seal out "XA" in L.S. @4453'. Relanded S.S. Pulled dual 3 1/2" strings w/14OM@ & parted S.S. & L.S. POOH Laying down 3 1/2" dual strings. Finished Pooh w/dual 3 1/2" Comp. Assy. Found L.S. parted in "XA" @+4456' & S.S. @+4488'. Both above triple Pkr. @+44901. -(Note: Bo_~tom_~.~O__~S.,~,.,~f Tbg~. & sTeeves s~.ve~e~ly~..c~Q~?oded..). RIH w/ 8 3/8" impression block ~t~ag'g~d'~}~8~'d~'~'~tLlbe' String @+_4435'. POOH w/I.B. (I.B. showed 2 3/8" collar looking up) made up 5 3/4" over shot w/' 2 7/8" grapple & RIH attempted to engage fish @+4435' No Luck. POOH , redressed O.S. w/ 2 3/4" grappel.-RIH & attempted to engage fish @+4435'. POOH & rec. 1 Jt. of 2 3/8" side string ~ remainder of L.S. (Note: While working tools on fish the 2 3/8" Jt. stabbed into the remainder of "XA": on L.S. side and pulled it out of hole when fishing tools were POOH. L.D. fish. RIH w/ 5 3/4" O.S. w/ 2 3/4" grapple to fish for remainder of 2 3/8" side-string (Note: Fish still in Hole: 1 Jt of 2 3/8" side string, 1-3' Pup 3 1/2" on short string & Otis triple Pkr~ w/ remainder of Comp. Assy. below triple Pkr. Completed RIH w/O.S, w/ 2 3/4" grapple & attempted to engage fish - no luck. POOH redressed O.S. w/ 2 3/8" grapple. Rt~H w/ O.S. w/ 2 3/8" grapple & engage fish. R.U. dialog W.L. & RIH w/ 2 3/8" TBG. cutter still couldn't get thru fish. Trip W.L. for undersize 2 3/8" cutter - still couldn't get thru fish. POOH &,R.D.W.L. Pulled 2 3/8" side string free & POOH w/same. Rec. the remainder of 2 3/8" side string & shear out sub. RtH w/ 5 3/z$" O.S. w/ 3 1/2' control mill & 3 1/2" grapple engage fish & POOH. Rec. 3 1/2" buttress X 3 1/2" 8RD cross-over. RIH w/ 5 3/4" O.S. w/ 3 1/2" grapple. -Fish kept slipping off grapple w/ about +5OM# P.U. Wt. POOH redressed O.S. w/3 3/8" grapple. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE WELL NO. FIELD 10 DATE 9/7/78 9/8/78 9/9/78 9/10/78 9./11/78 9/12/78 cmt ETD 6750' TD 6260' ETD 13 3/8"@4431 9 5/8"@6720' 6750' TD 6260' ETD 13 3/8"@4431 9'5/8"@6720 6750' TD 6260' ETD 13 3/8"@443' 9 5/8"@6720 DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS Fish kept slipping off w/+25M# P.U. Wt. POOH redressed O.S w/ 5 3/4" guide shoe. Sta-rted in hole w/ O.S. & well started flowing. RIH to +4450' & circ. out approx. 8 bbls of oil & 10 bbls of gas. SIDPP: +380 psi SICP= +_340 psi w/ oil and gas cut mud (+_60 pcf in h~le). Completed circ. out of oil & gas cut mud. Bullheaded 50 bbls of 6#/bbls Dril-s, 14#bbls safe seal and 20% CACL2 down D.P. to stop lost circ. Displace well w/20% CACL2 Brine. Shut in well - dead. POOH. Changed Hydril rubber. L.D.O.S. PU 3 1/2" spear on 9' of ext. Well started to flow again. RIH and cir. out +10 bbls of entry (OIL & GAS). Circ. well around +70#/C.F]- in and out. Shut in well' SIDPP=+200 psi, SICP= +160 psi (Need +77 PCF to kill well)]- Circ. well thr-u choke holding 300 PsT back press while increasing mud wt.. to 77 PCF. Circ. & cond. W.O. fluid to 77+ PCF. Bullheaded 50 bbls pill of 6 PPB Dril-s & 14 PPB Safe Seal to loss circ. zone. Followed pill w/ 35bbls of 77+PCF brine. POOH L.D. spear. RIH w/ 3 1/2" grapple in 5 3/4" O.S. Engage fish & pulled l15+M# & fish came loose. Circ. well for 2 HRS. w/ 77 PCF in & out (2 full circulations). POOH to triple Pkr. (well took right amount of fluid coming out) L.D. triple Pkr. & 100' of .Comp Assy. under triple. Well started blowing out L.S. Stabbed into L.S. w/ safety valve & RIH w/ Comp. Assy. on 5 Std. of D.P. & Dual Pkr. set itself @81 5'. (BTM of Assy @2055'). Bullheaded 150 bbls of 79 PCF brine down D.P. & 20 bbls down annul us. Followed w/80 bbls of ' 84 PCF down D.P. & 20 bbls down annulus. Bleed annulus off. (SICP 250 PSI). Pump down D.P. holding 600 PSI on Csg. taking partial returns thru choke. Pull up to BPV. Bleed D.P. to 0 PSI,Pooh & L.D. dual pkr. 6750' TD L.D. 4 Jts. under dual. Well flowing again. 6260' ETD RIH w/ Comp. Assy. on 5" D.P. to 6100' & 13 3/8"@4431' Circ. out oil & gas cut mud. Build 83 PCF 9 5/8"@6720 gel-mud & X-over well to same. 675O' TD 6540' ETD (Junk) 13 3/8"@443 ' 9 5/8"@6720 L.D. remainder of prod. equipment. RIH w/ PKR Picker & Mill over & rec. top 1' of Pkr. RIH w/ bit & D.A. & push Pkr. to 6540'. 6750' TD ' Set Baker Retrievamatic @4550' & tested 9 5/8" Csg. 4964' ETD above tool to 2500 psi --OK. POOH. RIH w/ gauge ring 13 3/8"@443 ' & junk basket to 6200'. Set Baker "N" Bridge Plug @6096'. 9 5/8"@6720 Perf'd 2-.,3" HPl~ .,f/6050' to 6052',. Set B,aker "K" cmt. Ret. @6009 . '~S-Q~Z' D:':'perfs 'f/6050 to 6052 w/ 300 sxs CE "G'~'.:w/ ....... ~5%~_D~31, .5% D-19, & .1% D-6 (Initial rate ~.~"<~(' 6cf/min. @1300 PSI': f_inal'~essure of. 3cf/min @600 PSI)? 'P~Ii' 0~'~ of ret-, & up~-{~--'~l~)~'~[- Rev. cie~n'. POOH. %et Baker "N" B.P. ~5075. Perf'd 2-.3'~ ~-mF ~/5027'-5029'. set ret.' ~ 4964'. s( "d perfs f/5027' to 5029' w/lO0 sxs CL. "G" w/ .75% D-31, .5% D-19 & .1% D-6 (Initial press. 10 cf/min. ~2800 psi, final press. 4 cf/min ~2600 psi) Had communication up anntJl~J~ d~Jrina ~ntir~ S~7_ UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE WELL NO. FIELD 11 12 13 14 15 DATE 9/13/78 9/14/78 9/15/78 9/16/78 9/17/78 ETD 6750' TD 506 5' ETD 1 3 3/8"@4431 9 5/8"@6720' 6750' TD 49601 ETD 13 3/8'I@4431 9 5/8"@6720 6750' TD 4960' ETD 1 3 3/8"@4431 9 5/8"@6720' 6750' TD 4960' ETD 1 3 3/8"@4431 9 5/8"@672O 6750' TD 4960' ETD 13 3/8"@4431 9 5/8"@6720' DETAILS OF OPERATIONS,DESCRIPTIONS & RESULTS POOH after squeeze. RIH w/ Baker Retrievamatic w/ stimulating valve and set pkr. at 4549' w/3500 feet water cushion. Had medium blow for 5 min. Declined to slight blow throughout test. Reversed out. Recovered 90 c.f. of entry. POOH. RIH w/ 8 1/2" bit. Drilled out cmt. ret. @4964'. C.O. cement to 5065'. Replaced cmt. cut mud w/75 PCF CACL2. Circ. & cond. CACL2 W.O. fluid f/75 to 78 PCF & built VIS to +40 SEC. w/ 1PPB Safe-Vis-X, well gas cutting mud prior to building VIS. POOH. Perf'd 4-.3" holes f/ 5041' to 5043' for resqueeze of above "D" Sand. RIH w/ cmt. ret. on D.P. & set @4960. Completed circ. btms up w/ 78#/ CACL2 & stabbed into cmt. ret. @4960'. Attempted to break down sqz. perfs 5027' to 5029' to 5041' to 5043'. Perfs held 3000 psi equiv. 1.20 PSI/Ft. POOH - Reran ret. Stinger & Stim. valve on dry. D.P. Dry tested perfs to atmospheric press. - 30 min. - OK. Rev. out gas cut mud from "C" Zone. Increased mud wt. 81#. POOH. Ran 9 5/8" csg. scraper and 8 1/2" bit to top of ret. @4960'. POOH. Ran Baker Model "B" circ. washing tool. Located perfs @4815' to 4855'. Spotted acid 12% HCL, 3% HF,7% solvent, .4% A-170, .5% W-5. Washed "C" Zone perfs 4815"to 4855' w/ acid. Located perfs 4685' to 4595' & washed w/ identical acid mixture. Held'1500 psi on csg. while washing perfs. Shut in well 1 hr. Circ. Btms. up & (had 340 PPM H2S in W.O. fluid) POOH. Ran Otis Type W.B. perm pkr. en W.L. and set @4500' above "C" Zone perfs. Rap 3 1/2" tbg. comp. assy. Stabbed into perm pkr. @4500' - Pkr. failed to test. Set plug in "X" nipple @4543'. Tested tbg. to 2500 psi - Held ok. Found Hydril on rig pump leaking. Retested pkr. and held ok. Spaced out & landed 3 1/2" .tbg. w/locator sub 1', above perm pkrT Remove BOPE &."installed X-mas tree and tested w/5000 psi. Displaced tbg. & csg. w/ F.I.W. thru "XA" @4465' Closed "XA" and pulled in "X" nipple. Released rig @ 1~'00 NOON. 9/17/78. COMPLETION DATE:, 9/]7/78 APPROVED DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS TUBING DETAIL ' DESCRIPTION LENGTH .71' .92' 31.73' t.44' 30.55' '83' 11.37' .85' .97' 28.59' 4.04' 28.35' 6.60' 431.52' 6.60' 707.70' 6.60' 1239.61' 6.60' 1727,94' 8.60' ·256.26' 4 1/2" Mule Shoe 3 1/2" Buttress x 4 1/2" N.U. X-Over 3 1/2" 9.2# Butt· tbg. 3 1/2" "'X" Nipple -- 3 1/2" 9.2# Butt. tbg. 3 1/2" Butt. x 4 1/2" N.U. X-Over 5" Seal Assembly Perm. Per. @ 4500' .. Locator Sub 3 1/2" Butt. 'x 4 1/2" N.U. X-Over -3 1/2" 9.2# Butt. tbg. 3 1/2" "XA" Sleeve ',!-;:,'. .. "" 3 1/2" 9'.2# Butt. tbg.' ":-:-"' " 3 1/2" KBUG G,L.M. 3 1/2" 9.2# Butt. tbg. 3 1/2" KBUG G,L.M. 3 1/2" 9.2# Butt· tbg. .. 3 1/2" KBUG G,L.M. 3 1/2" 9.2# Butt. tbg. :_i .'.'.L' :-:~ '"'~'. 3 1/2" KBUG G.L.M ..... 3 1/2" 9.2# Butt. tbg. ' 3 1/2" TRB Safety Valve 3 1/2" 9.2# Butt tbg. BOTTOM TOP 4576.60' 4575.89' 4575.89' 4574.97' 4574.97' '.'4543.24' 4543.24' ·4541.80' 4541.80' ,~ 4511.25' 4511.25' 4510.42' 4510.42' ·4499.05' 4499.05' 4498.20' 4497.23' 4468.64' 4464.60' 4436.25' 4429.65' 3998.13' 3991.53' 3283.83'' 3277 23' 3277 23' 2037 62' · · . ':~ :.7 - 2037·62' '2031.02' 2031.02' .,;{303.08' '"' 303 08' .~L~:' 94 48' t.~ , .,:. ~.,,: 294 48~ ,:'.'.!:;',,'38 22' . · :.'~"..:..: · · , . '·4498.20' 4497.23' 4468.64' . 4464.60' '" '4436.25' .. 4429 65' 3998o13' 3991.53' 3283.83' 3 1/2 Butt· Pup . ' .' ::-.'.... :' · .4.10 - 38. .,:.~!.~,'..:,34.12' Il 1! :' ': -, ' · I ' :·:~: i~: t., 3 1/2 Butt· x 3 1/2 .BRD X-Over '.::,.,: ~-:, ...52 :..' 34.12 !,:,.;.,~:::~,;'33.60 Cameron Hanger '::'"':,.::!-"i:::::i".:'.:i.~:.' ~!':;-.:':'=i::/'/:.~.. '". ":,": :i,::i":"!'i,~'.:'l.00' ':',,'!::33'.60'' ?i?~}!'32.60' :~'~'"'"'~";' 'Landed below KB "~ :-.~:-~?-.:'"::::~':;',:'~{~:://:?::'~".', ':,':-, ~-;./-.:-":.'j:.:32.60' :':':~::'32.'60' ~'7 :-';:" ,~'," -" ::' "' ~ ~i:::~:-.":. '" ~:'~ ::~.~:.~':.'-.':.:':~ :-;'??- ': - :';.-:" ;'.'.' "~: .:.:~ '":...'.: .-'..-'.- :L',nt~: ?.:.,':~.;:'".:'.?:'"::-~'?~:'~?~:'''~ '.;7~'~' ~.: .- . .:.- : ..-.. ,-.. -. ; ,:,.::.-:~..:.:~ ::. ~...., ..'.-:' .: ..: .,..,. 7,. . ,,,:'~. '...~ : '/L~ . ,: - ..? ~;::.. ,,? :i,:,~:-. :'' :~-:: '-,' - - . ':: -,-/,~: ,_.; '7' ": ": :~ ::?7 ? ~:.;-::,> · ~:'; >'.:... '~ '-:. '.: :.?:~' '/'~-:: ~,~ -. :"~' ':': : '.: ~.r: ; ::" ::~ ~ ~ '_ :-.:':' ~ ,'~::~':~':?";: '.'j:' :' ~::~"'~: ~':" ' :::, .":' ', -. "'.;'.' :'"?' :' .: '-' :-"'. '~: ~"-/ :. ~ ~'" : :'~' '~- - L:t:~b'~'. ''~ ":~ ~t'.'~'~?:~'~?"~'~.t-?':'/::¥~X":":~";:: ?:;~::'~;:t'~'~'"/J:~ ::~' '''~ /~'~"~5~ ? '~.":'77:~,:~:~'~:'::' '. '.' ~. J':'" "".:~¥ ;:-'.~:F' ': ~.'' '~ !'~-'~': / ':' ,: :~:'' ".,~t' ' :~''~t:'~ ~ ~*:~ qJi-~'t :': '~'-~;' '9:: ": '7~', - , %~' :'~ ~ ~:~-:.~':',~)'-~'.'~t;. "::' ::-':'"?~:.:'~' .:L '::/::"' :C::~: ~:'~?:::'' ?'~::'~:::~"'~; L~'?':': ~L '.'?:~?''.::':'::~r:'::.~:~:~ :~ ~.~ .:? ?_.:? ~:~'< '?~A''/:'~'~''~:::'' ~'~?f?':~::q:'L'~'.~'~:/'~':,':~??~*<?',',,?'~; :' ~.~:~ ~:, ~:?,-~,:~- :~ ':~: ~:, ~?~'.?,'?: :~?.~ .: ~:~-::.:~:?~L: ~ ??:':~::Li~;~:.~:--~~ '~./' :~:i~'::~:. 't~' :::"t~: '~':.:.~:~:~': ~':.:: ~::'':~ ~:';: ~;:~:~'::'f'~:::'~ :~t';~,:'~"~,,,~,, ~:'''~'~" '"' :~:?~'~:~ ~'"~J~ ~ ~. '-~.. _':~'..':t~ ~:?':. ~'-:;L.??'~'-?'7 ::-/)'. ~..:" '":~ .. : :' .... :' :-~" :. ~'- 4' ?:::,-5:~ ~ ':~,~:t:_~ ~: .~-~,-::~. ,.~. L.,:, i~-' ;,~Y' , ,;:,~L ~-'~. ¥'., -'---': :~-.'~?/~:':~. ~'.~>~:~r~-~.ttt,.'~- .~.¥:~,:.?:~':.'t.'fiF;,:..N,'~ ~-~:~<~,'~,:'.,~:~::: ~ ~ ~:,~:~,,.".~.,(Y~ ,~ · ";~%,5~?~?->'-,, 47.:~: TUBING HANGER' - - ' .... - .. ·?~::..---_ . : _,.· ::~:..·::..',/_:':::?_..:::'.-.....:/:-?-:-:-...--:.:-::.i:: :'?'.-..:::::;:-,:':::_:::.-/:.·-:.::~:?..!:'·.:·::.'-:..: :: _ :._~. ,.~ ,:.:, .::-.-~-:.-:_~.._ ,-,:.-.~-·-,,~ ,. -. '. -,? ~.:. ...... --'~:·~<-: .~- · .:::_-. ,.:....?,- ~.'".:::,.:,. ,.~ ,. ,. ',~,'-,!~,;).~? ',. . :?-.'%.: ? .?,-~?:,_,~',-.~,:/~_:; ~ _ . ...-..?.. , %~-..~ -' . . - .. . TUBING HEAP TOP' Tubing Detail 1. 3 1/2" Camco TRB-6 Safety Valve - 295' 2. 3 1/2" Camco GLM- 2,032' 3. 3 1/2" Camco GLM- 3,278' 4. 3 1/2" Camco GLM- 3,992' 5. 3 1/2" Camco GLM- 4,431' 6. 3 1/2" "XA" Sleeve - 4,465' 7. Locator - 4,499' 8. Otis Perm. Packer - 4,500' (11' of seals)' 9. 3 1/2" "X" Nipple - 4,543' 10. 4 1/2" Mule Shoe - 4,577' · Baker Model "K" Ret. - 4,960' 502' - 16" 65# H-40 Buttres.~ csg. --. ~ 4451' - 13 3/8" 61 & 68# K-55 Buttress Csg. lilY. I 11 Well Schematic IL ~ J I I I J I I Jl 6724~ - 9 5/8~ 47# 51-80 Buttress DATI~ . . ~ __.~.~ 9~78 III ........ ' i Trading Bay State Well A-32 W.O. .o UP,liON OIL CO. CD,-C/\LIFORi,,I IA ~/VELL PECORID-, : SH ,'--~T A £;I, iASE _T3j~DING, BAY STATE _WELL NO. A-32 i?IEI,D TtlAD ING BAY LOCATION MONOPOD PLATFOP~M C0~DUCTOR f/25' 1607' N 556' W of S.E. Corner'Of Sect.4, T9N R13W S.M. PE2MIT'NO. 77-18 T.D. 6750' SERIJJ~ NO ADL 18731 T.V.D. 6304 ' .* SPUD DATE 5/20/77 COMP. DATE_ 8/9/77 COb.~TiiACTOD, PARKER P,,IG NO ..... TYPE UNIT. OILWELL 860 Mod. DRILL PiPE DESCF'IPTION '45"i/2" ''Q'' i,~~.''E'' &~onn.S-135 ELEVATIONS: 5VATER DEFI'H th T.. TO OCEAN FLOOR ~.T. TO MLLW 110' DEVIATION (B.H.L.) 756' N 325' 'W of-surface COMPANY ENGINEER WESTER, CHRISWELL, WATSON SIZE WEIGHT THRE~'D GRADE .... 20" 94~ DRIVE ' PIPE ,16" ' 65 ~ BUTTRESS BUTTRESS R.T. TO D!'ULL DECK_ 33.60'. . TUBING RECORD H-40 K-55 DEPTH REMARKS ~1 ' PRE-DRIVEN .' 502' CMT."D THRU SHOE W/500 SX~ n-~"-W/ GEL & 200 sxs "G" NEAT. CMT. 'D ANNULUS THRU STINGER W-/ 50 SXS "G" W/10% SAND. 4451' CMT'D THRU SHOE W/928 SXS "G" .W/GEL & 200 .. I SXS "G" NEAT THRU DV M2199' W/878 SXS. __,. "G"...,W/_G.EL & 2_ .~_~00 SXS..,"G" NEAT. PERFORATING RECORD ~/.19/77} 550S~5508 ._6645' F.C. ~ ISO~TION SqZ. SQZ'D W/100 SXS ~6/22/77[ 6510-6560 "' " PRODUCTION OPEN LOWER HEMLOCK ?;6/23/77 6300-6350 " " " ., " HE~OCK ~/25/7~ .6260-6300 " " " " " " '" 6350-6400 · " " - "" .... " " " . " '6430-6510 " " " .... 6/27/77 '5852-5912 6200 ret.. " .... " " "D" ZONE 57-2 " "576~-5815 - '"' '" SQZ'D W/600 SXS "D" ZONE 56-1 -- ..... _ " 5g~-5662 " " OPEN "D" ZONE 5'499 " ' 5590-5606 " " " " " 54-5 " 5530-5560 " " I " -" " 53-8 " '5&~5_5455 " ,, ~ SQZ'D W/250 SXS" ,, 53_0 _ 7/S/77 ~ 5852-~912 6187 ret. " OPEN " " 57-2 ,, . 5590-5606 " ,, ,, ,, ,, 54_5 ' __" .. 5~0.~5560 '" ...,, ,, ,, ,, 53~8 7/10/77 5315,5345 5400 ret. " ~ " irC" ZONE 51-6 7/11/77 5285-5345 " " . .,.~ SQZ"D W/100 SXS ''" " 51-6 " $1~9-~140- ] 50~'.ret. " ~__ '~Q~'D w/!0~ SXS " " 50L'3 --~ INITIAL PRODUCTION DX+'~ .... I:i~E__~.VAL N-ZTOIL [ CUT [ GRA. VJ C.P. T.P. i CI~OFIE.. ~,__~CF GO~ '[' REJ:iI.,~.;~5 _.810../77 I'C" Zone ~60 i2.4% '.27.2 9-78 66 .1 143 894 '12 HR TEST · ' .. ON GAS LIFT.· 810/77 ~E~mOCK 60 23%.. 32.0 973 320 307,8 51300 4'HR TEST ' · ON GAS LIFT. .. , , · TYPE: CAMERON & OCT . -o : 20"" CASING HEAD:. 2000 PSI OCT.-"UNI-HEAD" RECE:iVED CASING CASING TUBING ~ANGER: OCT' 13 3/8" & 9 5/8" TY?E "C-22" SLIPS 20" SPOOL: 2000 PSI X 12" 3000 PSI OCT :. _l,% ' - ,,___,~ HEAD' 10" 5000 PSI X12 3000 PSI CIW ~PE TUBING 'DUAL 3 1/2" CIW "DCB" 10" ' ' TUBING tlEAD TOP' 5000 PSI " MASTF, R VALVES: CIW 2- 3 !/8" MASTERS & 2-3 1/8" SWAB VALVES : ,5,~[..k,~ TiIEE TOP CONN.:_3 1/2" EUE ON CIW DUAL ..- 3 1/2" TREE. UNION OIL. CO. CAI_I : . -- "" '--' "' IA, ,..,, ,,., XNELL I~ECORD SHEET A PAGE b!O. __ [;EASE ·_WELL NO · i;'I£LD __ LOCATION PEIiMIT NO: SERI.~J~ NO T.D. T.V.D. DEVIATION (B.H.L.) COMPANY ENGINEER SIZE [ V,'EI Gl'iT 9. 5/8" 477/'- 3 1/2" -9.2# 2 7/8"I' 6.4# 3 1/2" 9.2# 2 3/8" ~ ,4.6# . THREAD · BUTTRE S S BUTTRESS BUTTRESS BUTTRESS BUTTRESS 10 RD . SPUD DATE CONTRACTOR TYPE UNIT_ DRILL PiPE DESCRIPTION COMP. DATE RIG NO .... ELFWATIONS: WATER DEFrH R.T. 'to OCEAN FLOOR I1. T. TO MLLW Il. T. TO DK£I,L DECK R.T. TO PRODUCTION DECK APPROVED: CASING ~ TUBING RECORD G3 ^D__Z --'~3~.p_T~ R~.N ;~ R ~ s N-80 6724 CMT. 'D THRU SHOE W/2000 SXS "G" W/ .75% D-31, .3% D-19, & .1% D-6. N-80 4426' LONG STRING N-80 ~426 ' -62].6 ' LONG STRING N-80 4505 ' SHORT STRING N-80 ~429 '-49, .7 ' SIDE STRING ~947 '-611:4 ' SIDE STRING PERFORATING RECORD DAoT_E ItLTE.MJfAL E.T2D. · t:'LE~?~IL "C" Pil~EI[T CO_[LD_ITLO_~[ ___ --~./13/77 4655-4685 5095' ret. PRODUCTION OPEN ZONE C-7 7/14/77! 459524655 " " ' " " " " ,, , ~7/15f77i 4835-4855 " " " " " 47-5 · , -- ._816/77 6530-6550 .... 6645! F C. " -- " HEMLOCK __8/7/78. 6430-6530 · "' " " " ""- 6260-6400 " " " " , . ,. , ., · . · INITIAL PRODUCTIO~I . D. ATE' lltT_~.R,VAL N_ET OIL" CUT ... GRAV. I C.P. T.P. j'. CHOk'E ~'iC--F GO~ '.1,' ' lq .F._/d,~,.l~7~ . · · , WELL t!E~_S S EM DJ.~Y TYPE: CASING HEAD:. CASING ~IAN G,-R.. CASING SPOOL: TUBING 'HEAD: TUBING HANGER: TUBING tlEAD TOP' MASTER VALVES: --.. CHRISTMAS 'FRI£E TOP CONN.: Trading Bay State ~,'.,~LL "~ A-32 Trading Bay Fi eld .~ATE ITEM 3. 4. 5. ET~ JT~. 1 11 DESCRIPTION TRADING BAY STATE A-32 16"...Casi. ng Detai.1 16" Casing Shoe 16" H-4-O 65# csg 16" Casing Float Collar 16" H-40 65# csg Landed Bel ow R.T. Total 16" FOOTAGE 1.65 41.01 1 415.99 42.41 BOTTOM 5(12.66 501.01 460. O0 458, 42,41 JTS. 12 FOOTAGE 457.0n' TOP 5rtl .O1 4~n.nn 458.4o 42.4.1 .'~-,,'~-[ Trading Bay State Trading Bay Field ]ATE ITEM , . 2. 3. 5. 6. 7. 8. 9, ET] JTS. 1 45 5 53 gETA[LS CF CPE:Z.',T[C~:S, 7_,E.SC2IPT:C::S ~ ~=-~'".T,S TRADING BAY STATE A-32 13 3/8" Casing Detail DESCRIPTION FOOTAGE BOTTOH 13 3/8" Casing Shoe 13 3/8" 68# Butt csg. 13 3/8" Dowell Float Collar 13 3/8" 68# Butt. csg w/catcher 13'3/8" 68# Butt. csg 13 3/8" 61# Butt. csg 13 3/8" Dowell DV Collar 13 3/8" 61# Butt csg Landed Below R.T. 1.93 45.41 1.60 46.02 1949.30 204.5O 2.94 2162.30 37.00 4451.on 4449.n7 44n3.66 44n2.o6 4356.o4 24n6.74 22n2.24 2199.30 37.no Total Jts. 13 3/8" 68# Butt. Total Jts 13 3/8" 61# Butt. JTS. 47 58 105 FOOTAGE 2040.73 2366.53 44O7.80 TOP 4449.n7 44n3.6~ 44n2.n6 4356.n4 24n~.74 22n2.24 2199.3o 37.00 -0~ Trading Bay State .'.LLL ,,,0, A- 32 Trading Bay Field 2~TE ITEM . 2. 3. 4. 5. 6. 7. '8. 9. 10. ETD QTY. 1 2 1 10 s ,1 30 ,1 12.4 166 TRADING BAY STATE A-32 9 5/_8 Casing Detail -, DESCRIPTION FOOTAGE BOTTOM 9 5/8 Casing Shoe Dowel l Jts. 9.5/8"csg Butt. 47# 9 5/8 Float Shoe Powell Jts. 9 5/8 csg Butt. 47# Pup Jt. 9 5/8 csg Butt. 47# Jts. 9 5/8 csg Butt. 47# Pup'Jt: 9 5/8 csg Butt. 47# Jts. 9 5/8 csg Butt. 47# Landed Below RT. Cut off - to beach Total Jts. TOP 1.85 6724.27 6722.42- 76.14 6722.42 6646.28 1.62 6F46.28 6644.66 403.78 6644.F6 6240.88 14.95 624n.88 6225.93 1197.11 6225.93 5028.82 9.90 5028.82 5018.92 4979.62 5018.92 39.30 35.60 39.30 3.70 3.70 3.70 -0- *123 full Jts & 1 cut off · Centerlizers ltl', 30', & 60' above shoe and one on every other it. up to 4200'- cemented w/ 2000 sx Class "G" Cement w/.75% D-31 .3~ D-lg & .1% D-6 - Cement in place 3-10 a.m. 6-18-77 Trading Bay State ~',[L]_ ;lO, A-32 FIEL Trading Bay Field 2ATE ETD """-'"' ' '"' .... LENGTH 1.52 .80 30.58 l .00 1.00 9.75 15.10 1.15 85 27.97 4.25 56.35 6.80 416.84 6.8O 529.10 6.80 118.03 4.25 29.92 .75 7.57 .60 27.67 4.25 177.94 5.15 28.65 4.15 121.30 28.16 4.25 30.57 4.10 .73 JTS. 2 14 18. '4 TRADING BAY STATE A-32 ,LONG STRING TUBING DETAIL ITEM Otis muleshoe guqde 2 7/8" 8rd 3 1/4" x 2 9/16" X-over 2 7/8" 8r° pin x 2 7/8" butt box 2 7/8" 6.4# N-80 butt tbg w/o coupl.~ng X-over 2 7/8" butt box X 2,7/8" 10'" box Otis "X" nipple 2 7/8" 10r° pin X butt box 3 1/4" T~ 2.313 2 7/8" 6.4# N-80 butt tbg pup joint Otis seal assembly (15 se~s-).for 9 5/8" WD pkr 3 1/4" x 2 3/8" Otis locator sub f, or 9 5/8" WD pkr 3" x 2 3/8" X-over 2 7/8" 10r° pin X 2 7/8" butt box 3" x 2 3/8" 2 7/8" 6.4# N-80 butt tbg w/o coupling Otis "XA" sleeve 2 7/8" butt X butt box 3 9/16" x 2.313 2 7/8" 6.4# N-80 butt tbg Camco KBMG-LT gas lift valve mandr'el. 5 3/4" x 3½" 2 7/8" 6.4# N-80 butt tbg Camco KBMG-LT gas lift valve mandrel 5 3/4" x 3½" 2 7/8" 6.4# N-80 butt tbg Camco KBMG-LT gas lift valve., mandrel 5 3/4" x 3½" 2 7/8"X6'4#"A N-80 butt tb9 Otis "sleeve 2 7/8" b~t box X but box 3 9/16" x 2.313 2 7/8" 6.4# N-80 butt tbg X-oVer 2 7/8" butt pin x 2 7/8" 8rd box Otis 9 5/8" 47# x 2 7/8" x 2 3/8" dual hydraulic pkr X-over 2 7/8" 8r° pin x 2 7/8" butt box 2 7/8" 6.4# N-80 butt tbg w/o coupling Otis "XA" sleeve 2 7/8" butt box x butt box 3 9/16" x 2.313 2 7/8" 6.4# N-80 butt tbg 2 7/8" 6.4# N-80 butt tbg pup joint 2 7/8" 6.4# N-80 butt tbg 2 7/8" 6.4# N-80 butt tbg pup joint 2 7/8" butt blast joints 3 3/4" x w 3/8" 2 7/8" 6.4# N-80 butt tbg w/o coupling Otis "XA" sleeve 2 7/8" butt box x butt box 3 9/16" x 2.313 2 7/8" 6.4# N-80 butt tbg -- 2 7/8" 6.4# N-80 butt tbg pup joint X-oveF 2 7/8" butt pin x 2 7/8" 8r° box DEPTH {top) 6215.85 6182.50 6157.65 6156.50 6123.43 6060.28 5636.64 51~0.74 4978.46 4940.22 4907.70 4691.81 4570.51 4~38. lO :..E,:EE Trading Bay State Trading Bay Field Z~TF_ ET3 cont. 9.72 .70 30.55 1 3.65 29.31 1 71 7.O0 211.61 7 10.10 426.45 14 7.00 ~202.35 7 ~.i' 10.20 1549,34 18 7.00 '958.64 31 7.00 1283.93 42 5.15 .185.23 6 5.12 246.71 8 2.50 240. O9 8 28.04 1 1.00 6,183.80 201 jts 33.60 BKDB, 6,217.40 Finall Hanging Deptf t Otis 9 5/8" 47# x 3½" x 2 7/8" x 2 3/8" triple hydraulic pkF " X-over 2 7/8" 8rd pin x 2 7/8." butt box 2 7/8" 6.4# N-80 butt tbg Otis "XA" sleeve 2 7/8" butt 3 9/16" x 2.313 2 7/8" 6.4# N-80 butt tbg X-over 2 7/8" butt pin x 3½" butt box Otis 3~" RW4 gas lift valve mandrel 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg pup joint 3½" 9.2# N-80 butt tbg Otis 3½" RW4 gas lift valve mandrel 3½" 9.2# N-80 butt tbg 3½'.' 9.2# N-80 butt tbg pup joint 3½" 9.2# N-80 butt tbg Otis 3½" RW4 gas lift valve mandrel 3½" 9.2# N-80 but tbg Otis 3½" RW4 gas lift valve mandrel 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg pup joint 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg,.pup.joint 3½" 9.2# N-80 butt tbg Otis 3½" ball valve landing nipple 2 3/4" id 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg w/o co'upling 3½" butt CIW split type dual tbg hanger Total 2 7/8" & 3½" tubing 4492.98 4458.n8 4421 .n6 3765.90 2997.Ol 2o31.37 302.73 33.60 · ~:, ~ Trading Bay State A-32 LEASt_ ¥. LL i',O, F T Trading Bay Field SATE EI~D DETA' ° CPE?/,T ..... ~=c:" ~ ~L~ OF [,.~..~, ?~ESCRIPTIC:,S ~ .... Length -90 -72 .72 8.15 3.72 .82 30.59 4.00 '59.22 7.00 644.50 7.O0 757.62 7.00 962.50 7.00 212.48 5.15 582.05 5.12 890.56 2.50 243.02 28.10 1.00 4471.44 33.60 BKBD 4505.04 F ina 1 JTS. 1 2 21 25 31 7 19 29 8 1 144jts. Hanging Depth TRADING BAY STATE A-32 SHORT STRING TUBING DETAIL ITEM Otis "XN" nipple 3½' butt 4 1/4"x2.635 3½" butt N-80 coupling X-over 3½" but pin X 3½" 8rd box 4½" x 3½" Otis 9 5/8" 47# x3½" x 2 7/8" x 2 3/8" triple hydrat]lic pkr ~d 3½" 9.2# ~-8~d8' tbg. pup joint X-over 3½ 8 pin x 3½" butt box 4½" x 3½" 3½" 9.2# N-80 butt tbg Otis "XA" sleeve 3½" butt 4 1/4" x 2.75" 3½" 9.2# N-80 butt tbg Otis 3½" RW4 gas lift valve mandrel 3½" 9.2# N-80 butt tbg Otis 3½" RW4 gas lift valve mandrel 3½" 9.2# N-80 butt tbg Otis 3½" RW4 gas lift valve mandrel- 3½" 9.2# N-8O butt tbg Otis 3½" RW4 gas. lift valve mandrel 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg pup joint 3½" ~.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg pup joint 3½', 9.2# N-80 butt tbg Otis 3½" ball valve landing nipple 3½" 9.2# N-80 butt tbg 3½" 9.2# N-80 butt tbg w/o coupling 3½" butt CIW split type dual tbg hanger .. Total 3½" tbg' RECEIVED .JAN · Alasi-;a 0~1 & ('~ r,~-'-~,, C -- DEPTH (top) 4504.14 4494.55 4455.42 4389.20 3737.70 2973.08 2003.58 3O5.72 Trading Bay State Trading Bay Field ETS LENGTH .40 1 .:00 59.49 .68 8.38 377.98 9.83 26.50 8.08 506.82 18.50 8.05 128.11 22.30 .78 7.57 1.17 78 244.65 1.00 120.60 .35 .70 60.02 2.14 : 50 .85 .76 9.22 .65 16.1.8 JT~. 12 16 TRADIHG BAY STATE A-32 SIDE STRING TUBING DETAIL IZEM 1½" od bull pl~g w/ l0rd box X-over 1½" lO'" pin x 2 7/8" butt box 3 1/4" od 2 7./8" 6.4# N-80 butt tbg. X-over 2 7/8" butt pin x 1½ IJ box 3 1/4" od Camco KBMG-LT gas lift valve mandrel 1½" x 1" 1½" 2.76#,:'J-55 IJ tbg 1½".2.76# J-55 IJ tbg pup joint Otis telescoping joint 1½" IJ 2 3/4" x 1" Camco KBMG-LT gas lift valve mandrel 1½" x 1'i 1½" 2.76# J-55 IJ tbg Otis telescoping joint 1½" IJ 2 3/4" x 1~ Camco KBMG-LT gas lift valve mafidrel 1½" x 1½" 2.76# J-55 IJ tbg Otis telescoping joint 1~" 3/4" " §~rdIJ 2 x 1 3~.,, .4ra ,, ,, X-over 3~"~ IJ pin x -~ box box 4 x 1 Otis 9 5/8" 47# ~ 2 7/8" x 3½" dual hydraulic pkr 3½" 9.2# N-80 8ro tbg pup joint X-over 3½" 8rd pin x 2 3/8" butt box 2 3/8" 4.6# N-80 butt tbg X-over 2 3,/8" butt pin x 2 3/8" 8rd box 2 3/8" 8ra blast ,joints 3" x'l 7/8" X-over 2 3/8" 8ro pin x 2 3/8" butt pin 2 3/8" butt coupling 2 3/8" 4.6# N-80 butt tbg 2 3/8" 4.6# N-80 butt tbg pup joint Otis telescoping joint 2 3/8" butt pin x 2 3/8" lOrd box 3½" x 1 7/8" 1½" X-over 2 3/8" lOrd pin x IJ box X-over 1½" IJ pin x 2 3/8" 8rd box Otis 9 5/8""47# x 3½" x 2 7/8" x 2 3/8" triple hy. draul ic pkr X-over 2 3/8" 8rd pin x 2 3/8" butt box 2 3/8" 4.6#, N-80 butt tbg DEPTH 6124.27 6O54.74 5632.35 5O98.98 4940.22 4692.92 4572.O2 4492.48 4430.65 PAGE 10 ~ i Well Schematic A-32 Ji i Tradi_ng Bay Field 20" 94# Drive pipe @ 221' .. 16" 65#, H-40, Butt, @ 502' ~13 3/8# 61 & 68# K-55, Butt @ 4451' 5/8 47# N-80 Butt @ 6724' I Started 5-20-77 Completed 7-23-77 i _11 ii - -- -,, AI"P'D. S ~.AL~. .... --. ; CKD. ; i PAGE 11 UNIO I OIL CO .PA/N OF CALIFORNIA RECORD ,. ~'~-U_ I~O, TBS A-32 FIELD · PAG DETAILS OF OPEPATIONSo DESCRIPTIOI)S & RESULTS 1 5/20/177 2 5/21/77 5/22/77 . · 4 5/.23/.7 ? · 5 5/24/7 6 5/25/71 7 5/26/7 500' TD 20" csg. @221' · 513'TD 20" csg..@ 221' 16" csg. · @502' : · 785 'TD 20" csg. @221' :. 16'" csg. @502' 1502 'TD 1001 ' KOP 20" csg. @221 ' 16" csg. @502' · 2632 'TD 20" csg. @221 ' 16" csg. @502' 3018'TD 20" csg. @221 ' 16" csg. @502' 3477'TD 20" csg. @221' 16" csg. @502' (Footag'J 500"). Skidded rig from TE~'A-13 to TBS A-32 @12:01 p.m. 5/20/77. Installed 20" riser & hydril. C.O. 20" conductor to 2n21'. Drilled 17 1/2:' hole to 231' Pooh. Ran 18" O.u. mill & dressed out partially coliapsed 20" conductor shoe. Ran 17 1/2" bit, BHA #1 & drilled from 231 to 500'. (Footage 13'). Dri.lled"fr~.m"-50~)'~' t-o'j512~''''. .,.Opened '.17 1/2" · hole to 26" O.D. 'to 513'. Spotted 150 b[~l. Sgel ~$.]..l'...--..P~ooh to run csg. Ran 12 jt.s. 16" O.D. 65# H-40 Butt. casing & set w/ shoe @502' - F.C. @460'. · '(Footage 272') Cemented btm. stage w/ 500 sx. Class "G" w/ 8% gel followed by 200 Sx. Class "G" neat. CIP @4:00 a.m. 5/22/77 Cemented top 16" to effect seal & isolate holes in 20" conductor'-w/ 50 sx. Class "G" & 10% sand. CIP @6:10 a.m. 5/22/77. Tested 16" packoff w/ 450 psi,. o.k..Reinstalled 20" hydril and tested to 500 psi o.k. Ran '12 1/4" bit BHA #2. Drilled 12 1/4'" hole-to 785'. · (Footage 717'). Cont. drlg 12 1/4" hole from 785' t'o 1001.'. Dropped survey and pooh. RIH w/ dyna drill & oriented at' IO0(T'KOP. Dyna drilled & surveyed 12 7/4, hOle from lO01' . to 1205' Pooh w/. dyna drill. RIH w/ 12 1/4" bit on follow up BHA #~. 'Drilled and surveyed 12 1/4" hole from 1205' to to 1502'. (.Footage ll30'). Cont. drlg. 12 1/4" hole w/ follow up building BHA #4 from 1502' to 1838'. Pooh. RIH w/ locked BHA #5 Drlg 12 1/4" hole from 1838' to 2632'. (Footage 386'). Pooh, picked up 12 1/4" bit #5 on dyna drill. (BHA #6). TIH. Oriented tool w/ scientific eye steering tool for right hand turn and slight angle build. Dyna drilled from 2632' to 2769' Pooh w/ DP. Re ran Bit #5 on BHA #7. Follow up assy. and dri·lled.12 1/4" hole from' 2769' to 3018'. (Footage 459'). Completed pooh. RIH w/ bit #6 on BHA #8~ Drlg. 12 1/4" hole from 3018' to 3403' Pooh. RIH w/ bit #7 on. dyna drill (BHA #6)' Oriented t~ol w/ scientific eye steering tool for right hand turn and slight angle build. Dyna drilled from 3403'-to 3477'. R. ig dwn. steering tool. 8 ...i.'5/27/77 · 9 .5128177 . . o . l~ 5i29/~7 . o Ill - 5/30/77 12 5/31/77 13 6/1/77 14 6/2/77 SFZET D I ilOtl OIL C[I-iPAtN OF CALIFO .IIA ,13.L IE]CORD I',ELL FIELD. · DETAILS OF OPEPATIONS, DESCRIPTI~tIS & RESULTS 3790'TD 20" csg. @221 ' 16" cig. 0502' 4006 'TD 20" csg. @221 ' 16" csg. @502' 4280 'TD 20"' csg. @221' 16" csg. @502' 4480 'TD 20" csg.: @221' 16" csg.- @502' (Footage 310'). Pooh w/ dyna drill. RIH w/ 15" bit on BHA ¢9. Rea~ed 16" float collam;_-.& shoe @502"" Pooh. RIH w/ 12 1/4" bit on BHA¢9,: Drlg 12 1/4" hole from 3477' to 3686' Pooh. RIH w/ 12 1/4" bit on dyna drill (BHA ¢'10). Oriente~ tool w/ scientific eye steering tool for right'hand turn. Dyna drilled from' 3686' to 3790'. (Footage 216'). Continued dyna drilling from 3790' 'to 3796' (Turned hole 18 deg. right'& buil.t 1/2 deg. Pooh w/ dyna drill. RIH w/ 12-1/4" bit'on BHA ¢11. Reamed dyna drill run ir. om 3686' to 3796' Drlg 12 1/4" hole to 3846' .PoOh. RIH v4/ 12 1./4" bit on 'd~na drill (BHA ¢12). OrienteJ'dyna drill w./ scientific eye steering tool for right hand turn dyna drilled from 3846' to Z~O06'. (Turned hole 19 deg. right & dropped 3/4 deg.). Pooh w/ dyna dril.1. --(-FoOtage 274'.)' .RIH W/ 12 1/.4" bit on BHA ¢13. Reamed . dyna drill run from 3846' .to 4006'. D. rlg 12 1/4" hole to 4126'.. Pooh. RIH w/ 12 1/4" bit' on dyna drill (BHA ¢14)' . Oriented dyna drill .for right hand ...turn.. and slight angle build. Dyna drilled from 4126' to 4280'. (Turned hole 26" deg. right & built 1-/4 deg. Pooh w/ dyfla drill. RIH w./ 12 1/4" bit on BHA ¢15. Reamed dyna drill ~un from 4126' to 4280'.' (Footage 200'). Drilled 12 1/.4" h°le f. rom 4280'. to'.~340" .' Pooh. RIH w/ 12 1/4" bit on dyna drill (BHA ¢16). Oriented dyna drill for build. Dyna drilled 12 1/4, hole from 4340' to 4413' Pooh. Laid dwn. dyna drill. Ran 12 1/4" bit on follow up assy. (BHA #17). Drlg 12 1/4" hole to 13 .3/8" csg. point @4480' 4480' TD ' 20" csg. @221' 16" csg. @502' -. · 4480'TD 20" csg.' @221' (Footage 0'). Circ. & cond. mud for logging at 4480'. Pooh. Laid dwn. 90 jtS. of 5" DP. Rigged up Schlumberger. Schlumberger checked TD at 4476' WLM. Ran DIL-GR, ' FDC-CNL-GR & BHC Sonic from TD to 16" csg. shoe at 502' Rigged dwn. Schlumberger. RIH w/ 17 1/2" expandible hole opener. Opened 12 1/4" hole to 17 1/2" from 502' to 534'. (footage 2.988 (:opened) ' Continued.opehilng.12 l/4'.', hole to. 17 1/2" from 534' to 2151'. Tripped'fo'r'hole Opener change. Opened 12 1/4" to 17 1/2" from 2151' to 3522'. 16" csg.. @502' 4480'TD 17 1/2" 'hole 4298' 20" csg. @221' 16" csg. @502' (.Footage Z76' (opened).- Opened 12 !/4" hole to 17 1/2" w/ expandible hole openers fronl 3522' to 4298'. Tripped to change hole opner @3522' 4050-'-' and 4298' .- -]ASE UNIO I OIL COt. NN OF. CALIFORt.IIA ELL I CORD FIEL3 SHEET P^G No, ~TE 15 16 17 18 6/3/77 6/4/77 6/5/77 6/6/ 4480'TD 20" ~c'S§'. ' @221 ' 16'" cSg. @502' ! : ., 4480 'TD 13 3/8" csg. shoe' @4451' : 20" csg. @221' ' i 16" 'csg. ' @502' !1 II . II II DETAILS OF OPEPATIONS, DESCRIPTIOtlS & RESULTS _(Footage 0'). Finished TIH w/ 17 1/2" underreamer on BHA #19. Opened,12 1/4" hole to 17 1/2" to 4460'. Pin twisted off GBR stab 81' abo,ve hole opener @4460'. Top of fish @4359' Ran 15" lip guide w/ overshot & jars (BHA #20). Engaged fish ~4359' & pooh. Recovered total fish. Reran -17 1/2" underreamer on BHA #21. Opened 12 1/4" hole to 17 1/2" from 4440' to 4460'. Circ. & cond. hole to run 13 3/8" csg. Pooh. Laid dwn. 17 1/2"' underreaming assy. RU to run 13 3/8" surface casing. Power tong unit failed. Ran 106 jts. 13.3/8" 61'# & 68# K-55 Butt. Casing w/ Spinning rope & rig tongs. Landed 13 3/8" casing w/ shoe @4451'. DV tool @21.99'. Unable to circ 13 3/8" casing annulus to surface. Suspect loss of returns @16" csg. shoe @502'. Cemented btm. stage 928 sx. C1 "G" cmt. w/ 2 1/2% pre-hydrated gel followed by 200 sx. C1 "G" neat. Displaced btm. stage. 'Plug did not bump'w/ 100 cu. ft. overdisplacement. Cmt. in place @ 4'00 p.m. 6/4/77. Dropped bomb to open DV stage cmt collar ports @2199'. Opened ports w/ 1800 psi o.k. Unable ~o circ. to sur. face. Pumping in below' 16" csg. shoe w/ 400 psi. Cemented top stage w/ 8.78 sx. C1 "G" w/ 2 1/2% pre-hydrated gel 'followed by 200 sx. C1 '~G" neat. Closed ports in DV tool @2199' w/ 2750 psi, held o.k' Cement in place @7'30 p.m 6/4/77. Dropped wrap around slips & hung off 13 3/8" casing Removed 20" hydril & riser. Installed'13 3/8" casing head spool. Installed 13 5/8" BOPE & tested to UOCO speci.fications. RIH w/ 12 1/4" bit (BHA #22) to 2199' Tested pipe'rams and csg. to UOCO specifictions. Drilied DV @2199' and tested to UOCO specifications o.k. Ran in and tagged cmt. @4330'. · Drilled cmt. to plug catcher @4356'.~ Drilled firm cmt. to float collar @4402' Drilled to 4433' and retested csg. o.k. Drilled cmt. shoe @44~1'. CO to 4480'. Tested csg. seat and formation to .65 psi/ft, gradient (TVD 4259') o.k. Pooh. Cleaned out rat hole at cement below casing shoe at 4451' to TD at 4480' w/ BHA #22. Pooh. RU scientific tool gyro survey and ran gyro from 200 to 4400'MD. BHA location at 4400'MD is 130.20S and 856.25'W of surface location. Trip in hole w/ BHA #22 to casing shoe at 4451'. Displaced well at csg. shoe w/ FIW. Cleaned surface mud tanks and rebuilt active mud system w/ 5% KC1 and XC polymer.' Pooh w/ BHA #22. Ran 12 1/4" bit on dyna drill w/ 2 deg. kick sub (BHA #23). 19 .... .61.71177 20 618/77 21 6/9/7~ 22 6/10/77 23 6/11/77 24 6/12 25 6/1 UNION OIL CO"'?h'N OF CALIFO ,IIA ,ELL RECORD .. I'/ELL FIELD ·. SPZET D DETAILS OF OPEP~kTIONS, DESCRIPTIOtlS & RESULTS " 4673'TD 4859 'TD · :. . 5152 'TD 5381 'TD ' 5690'TD 5965 'TD 6309'TD (Footage 193'). Completed trip i·n hole w/ dyna drill to TD @4480' Oriente~ dyna drill fo~:.maximum right'hand turn' Dyna drilled from 4480' to 4525'. Pooh w/ dyna drill. Trip in hole w/ 12 1/4" bit on follow up assy. BHA #24. Dressed out dyna drill run. Drilled from 4525' to 4577'. Survey at .4548' 28'1/2 deg. due North Drilled from 4577' to 4639'. Survey at 4609' 28 3/4 de~'. N1E. Drilled from 4639'to 4673'. Survey at 4644' 28 3/4 degJ N1E Pooh w/ follow up assy. #24. Picked up dyna drill. Trip in hole w/ dyna drill 12 1/4" assy. '#25 to TD at 4673'. 'Oriented dyna drill for right hand turn. (FoOtage 186'). Dyna drilled from 4673' to 4733' Pooh w/ dyna drill 12 1/4" assy. #25. Trip in ~le w/ 12 1/4" follow-up assy. #26. Reamed dyna drill, run and drilled from 4733' to.4794'. Survey at 4760' 27 1/2 deg. NI.OE. Circ~& cond .mUd.tO rUn lo.g. -Pooh. RU'Schlumberger and ran DIL correlation tog from 4451~ to 4794'. RD Schlumberger. Trip in hole w/ dyna drill BHA #27 'Oriented for right turn at 4794'. 'Dyna drilled 'fr°m'4794' to 4859' ..... m (' · · . · o (-'Footage 293'). Pooh w/ dyna drill at 4859'r Trip ~n hole w/ 12 1/4" bit on follow up ass~. BHA. #28. Reamed dyna' drill run from 4794' to 4859'. Drlg from 4859' to 4996'. Survey a~"4966' 26 deg. N24E. Pooh for bit change. RI~ w/ 1.2 1/4"]'~it #)8 ~ , on follow up assy. BHA #28. Drlg from 4996' to 5090'. Survey at 5060' 25 deg' N24E. Drlg from 5090' toI 5152' Circ. Dropped survey at 5152'. Survey misrun. Pooh w/ BHA #2~.' (Footage 229'). RIH w/ 12 1/4" bit #19 on dyna drill (BHA #29). Oriented dyna drill w/ scientific eye steering tool for right hand turn. Dyna drilled 12 1/4" hole from 5152' to 5161'. 'Steering tool not working. Pulled steering tool & cut out 150' of shorted line. Re-ran steering tool. Continued dyna drilling 12 1/4" hole from 5161' to 5217'. Pooh w/ dyna drill. RIH w/ 12 1/4" bit #20' on follow up assy. BHA #30. Reamed dyna drill run from 5152' to 5217'. Drlg & surveyed 12 1/41' hole from 5217' to 5381'. (Footage 309').· Cont. drlg 12 1/4" hole from 5381' to 5434'. Pooh for bit change. RIH w/ 12 1/4" bit #21 on BHA #30. Drlg. & surveyed 12 1/4" hole from 5434' to 5639'. Tripped for bit change. Redressed 6 pt. reamer to,retard slow angle drop. RIH w/ 12 1/4" bit #22 on BHA #30. Drlg & surveyed 12 1/4" hole from 5639' to 5690'. : (Footage 275'). Continued drlg 12 1./4" hole from 5690' to 5720'. Pooh. RIH w/ bit #23-on sli~iht angle building assy. BHA'#31. Drlg 12 1/4" hole fromm"5720' to 5851' Pooh. RIH w/ bit #24 on~-BHA #30-, Drlg & surveyed 12 1/4" ~ole.from 5851' to 5965'. (Footage 344'). Pooh. .RIH w/ 12 1/4" b. it #25 on slight angle building assy. BHA #31. Drlg 12 1/4" hole from 5965' to 6130' Tripped for bit. RIH w/ 12 1/4" bit #26 on BHA #30. Drlg 12 i/4" hole from 6130' to 6309'. Pooh for bit change. - ASE DNI I OIL C[I.?N'N OF CALIFORNIA o, . FIELD SHEET PA6r- l'b,. ~TE 26 27 28 29 30 31 6/1 6/1 6/1 6/17 6/1~/7 . 6/19/7 6519'TD 6750'?D 6750 'TD : : 6750'TD ETD 6645! (fl. collar 9 5/8" csg @6724' 6750'TD~ ETD 6645:' (fl. col!la 6750'TD - 6645 'ETD (fl. colla · DETAILS OF OPERATIONS, I)ESCRIPTIOtiS & RESULTS (FoOtage 210') Pooh. RIH w/ 12 1/4"'bit #27 on BHA #30. Drlg 12 1/4" holet, from 6309' to 6439'.' Tripped for bit. RIH w/ 12 1/4" bit #28 on BHA #30. .Drlg 12 1/4" hole from 6439' to 6519'. Ran W.L. survey. (Footage 231'). Finished W.L. survey. Lost 500 psi pump press. Trip for hole in 5" DP at 493' and new bit. Ran 12 1/4" bit #29 on BHA #33 and drilled 6519' to 6600' in 4 1/2 hrs. Trip for new bit. Ran 12 1/4" bit #30 on BHA #32 and drilled 6600' to 6750' in 5 hrs. Ran W.L. survey. (Footage 0'). Tripped out to 13 3/8" csg. at 4451.'. RIH to 6750'. Circ. & cond. mud for logging' Pooh. RU Schlumberger. Ran -DLL GR BHC Sonic and FDC CNL GR from 6740' to 4451'. (Footage 0"). Completed running FDC CNL log from 6740' to 4451'. Ran GR CBL VDL log inside 13 3/8" csg. from 4451' to surface. CBL log indicated cement outside'13 3/8" csg. above 16" shoe @502'. RD Schlumberger. RIH w/ 12 1/4'" bit to 6750'. Circ. & cond. mud for csg. Pooh, hole condition good. RU &..ran 166 its. of 9 5/8'~ 47# N-80 Butt. csg. to 6724' w/ float collar @6645' Footage 0'). Circ. well clean. Mixed & pumped 2000 sx. of Cl, G cmt. w/ 0.75% D-31, 0.3% D-19 and 0.1% D-6. Preceded cmt. w/ 200 cu.ft, of caustic water & 200 cu.ft, of filtered inlet water. Displaced cmt. to float collar @6645' & bumped plug w/ 2000 psi. Checked floats, held o.k. Landed 9 5/8" csg. on slip type hanger. Cut off 9 5/8" landing it. Removed BOPE. Installed & tested 12" 3000# x 10"'5000# tbg. spool. Skidded rig from TBS A-32 to TBS A-2.to set plug in TBS A-2 long string. while waiting on cement. Skidded back over TBS A-32.. Installed & tested BOPE. (Footage 0'). RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 6645'. Pooh. RU Dresser Atlas. Ran multi shot gyro survey from 6600' to 4500'. Ran GR CBL Signature log 6644'to 3750'. RIH w/ 6" sqz. gun & perf for zone isolation sqz. from 5506' to 5508'. RD Dresser Atlas. RIH w/ 9 5/8" sqz. pkr & set @5393'. Unable to break dwn. sqz. perfs 5506' to 5508' w/ 3000 psi, equiv, to 1.08 psi/ft, gradient. Pooh w/ sqz. pkr. UNI I OIL CALIFO .IIA ,EI_L I ECORD FASE I ELL FIELD ~E 32 6/20/77 34 6/22/71 35 6/23/7 : · : : II II II il · : II II DETAILS OF OPEPATIONS, I)ESCRIPTIOIIS & RESULTS Pooh w/ 9 5/8" sqz. pkr. RIH w/ 9 5/8" test pkr & set @5468' to diff. test perfs 5506' to 5508'.. Press. DP w/ gas to llO0 psi & opened tool @6:10 a.m. Bleed off. gas press. & flow tested perfs. Well stabilized @ plus or minus 1500 mcr/day gas w/ 145 psi @ surface. Shut in tester on surface @ l:lO p.m. Surface pressure stabilized @710 psi in 45 mins. Rev. out gas & gas cut. mud w/ slight trace of oil. Pooh w/ test pkr. Pressure bombs recorded as follows' Initial hydrostatic' Initial flow· Final flow Final ° shut in 2643 psi 336 psi 336 psi 994 psi RIH w/ 9 5/8" sqz. pkr & set @5424'. Broke dwn. perfs 5506' to '5508' @3100 psi (1..10 psi/ft, gradient)' and pumped in @ 3 cu.ft./~in w/ 2300 psi. Mixed & pumped lO0 sx. of C1G cmt. w/ 0.75% D-31, 0.3% D-19 and 0.1% D-6. Initial pump in press. 2000 psi - 6 cu.ft./min. Sqz. 70. sx. of cmt. into perfs to a final press, of 3200 psi. Held press, for 30 mins. Bleed off press-& cmt. stayed in place. Released pkr & reversed out. .. (Footage'O'). Completed re~ out. Pooh. Picked up:BOPE & repositioned tbg. spool. Installed & tested BOPE. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Cleaned out hard cmt. from 5424' to 5520' and cmt. stringers to 5530' 'Tested 9 5/8" csg. to 2500 psi o.k. RIH to float collar @~645'. Displaced mud w/ 5% KC1 inlet water. Pooh. Finished pooh w/ bit. Perf. 9 5/8" csg. in lower Hemlock using Dresser Atlas 4" casing gun 6510' to 6560'. Ran 9 5/8" Baker ret. Sqz. pkr on 5" DP and set @6472'. RU to frac. Frac. Hemlock perfs 6510' to 6560' w/ 45,000 gal. gelled and treated 6% KCL water · and 95,500# 20/40 sand as follows: pumped :2,000 gal 12-3 mud acid @SBPM & 4400 psi 5,000 gal frac pad 5,000 gal frac fluid w/ 1/2 ppg sand @14 BPM & 4200 psi 12,000 gal frac fluid w/ 1 ppg ll,O00 gal frac fluid w/ 2 ppg 9,000 gal frac fluid w/ 3 ppg 8,000 gal frac fluid w/ 4 ppg. 4,800 gal frac fluid displacement @14 BPM &4600 psi Shut well in and pressure bled to 3000 psi in 1/4 hr. and held 3000 psi for 3/4 hr. Bled pressure to 600 psi and reversed out sand. Back fl owed well. Continued.back flowing ~ell, Back flowed well a total of 14 hrs. Pooh w/ retrievable pkr. RU Dresser Atlas. RIH w/ 4" csg. gun & perf the upper Hemlock from 6300' to 6350' '@4 hpf. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Tagged. sand fill @6511' Cleaned out fill to 6644'. Circ. & cond. W.O. fluid. Pooh. RIH ~/ 9 5/8" RBP & retrievable pkr. t . DNIOf OIL OF CALIFO .IIA RECORD D 36 6/24/77 . - , 37 38 · _ 6/26/7.7 II II 6750 'TD 6200' (cmt. ret:.) : II II DETAILS OF OPERATIONS, DESCRIPTIO~IS & RESULTS RIH w/ 9 5/8" RBP & stimulation pkr. Set 9 5/8" RBP @6450' & tested t..o 2500 psi. Set 9 5/8" stimulation pkr @6258'. RU to fracture stimulate uppe~_...Hemlock perf,' 6300 to 6350' Broke dwn. perfs w/ 4200: psi. Fracture stimulated the upper He~lock w/ 45,000 gal gelled frac pad w/ 4% KC1 and 95,500// 20/40 sand as fol 1 ows- · 2,000 gal. 12-3 mud acid 5,000 gal frac pacl~ 5,000 .gal. frac pad w/ 1/2 ppg sd 12,000 gal frac pad w/ 1-~pg sd 11,000 gal frac pad w/ 2 ppg sd 9,000 gal frac pad w/ 3 ppg sd 8,000 gal-frac pad w~ 4 ppg sd 4,800. gal frac pad · Final pumping rate 5 BPM @4300 psi. Shut dwn. pump. Press. bled to 2000 psi in 1 h~.. Rev. out. Pooh w/.'stimulation pkr. RIH w/ retrievi.6g, tool for RBP. Washed out sand from 6301' to 6450' Retrieved 9 5/.8" RBP@6450'.. RU Dresser~Atlas. RIH w/ GR CBL logging tools. Tagged sand fill @6580' Logging tools 'not working. ~..RD.Dresser Atlas. -RIH w/'8 1/2~' bit & 9 5/8" csg. scraper. Cleaned out sand from 6580' to 6644'" Pooh. .. . RU Dresser Atlas. Worked on logging tools 2 1/2 hrs Ran GR CBL Signature log from 6633 to 4500'. Log quality pooK'~ RIH w/ 4". cased carrier guns & perforated the Hemlock formation from 6260' to 6300' 6350' to 6400' and 6430' to'6510' Ran & set 9 5/8"'re~. On DP @6200'. Tested cmt. ret w/ 25~0 psi. RU to run tbg. Ran 9 5/8" x 4 1/2" Otis hyd. pkr on 4 1/2" gas lift string. Pkr stopped @560'. Pooh. Gauge ring on rebuilt Otis pkr out of round Ran Baker 9 5/8" x 4 1/2" hyd. pkr on 4 1/2" gas lift string. Spaced out & landed tbg w/ pkr @4498'. RU W.L. unit. ·RIH w/ W.L. plug. Unable to work thru XO sleeve @4461' Re-ran plug & set in XN nipple @4536'. Press tbg. w/ 2500 p~i & set 9 5/8" hyd pkr @4498'. Pulled W.L. plug - plug stuck in XO sleeve 'at 4461'. Jarred plug free w/ Dresser Atlas unit. Ran W.L. shifting to open XO sleeve @4461'.. Unable to latch into sleeve RD W.L. unit. o . ~TE 39.. ,].6/27/7~ 7 40 -6/28/~7 41 6/29}77 42 6/~0/ II II II II II II II II . OIL cor. NN OF CALIFO iIA [ I LL RECORD . . . FIELD S 2ET D DETAILS OF OPEPATIONS, DESCRIPTIOIIS & RESU1_TS .. Finished removing BOPE. Installed CIW 4 1/2" sinqle X-mas tree. Gas.'lifi~ed 22~bbls worko.ver fluid out'bf hole to ~ctive mud system. Dresser Atlas perforated 9 5/8,' csg. in "D" Zone 57-2 sand w/ 4 SPF. using 3 1/8" csg. gun under 500 psi drawdown condition 5852' to 5912'. Perforated in two runs and flowed well 1/2 hr between runs then flowed 4 hrs after completing and recovered-workover fluid w/ no gas. Perforated 56-1 .sand as above 5765'. to 5815' and flowed well recovering workover fluid w/ no gas. Perforated 54-9' sand as above 5630' to5662' and flowed'recovering-no gas or' oil. Perforated 54-5 sand 5590' to 5606' and-53-8 sand 5530' to 5560' as above w/ slight incr6ase in gas. Perforated 53-0 iand 5425' to 5455' as above w/ 'substantial increase in gas. Stuck perf gun in tbg. @795'. Attempted to pull out of rope socket and gun 'came free w/ 2600# and moved up hole cutting W.L. Pulled W.L. and now rigging up to fish perf gun. Bled dwn. ga'S.press on annulus to 500 psi. RIH w/ 1 7/8" sinker .bars to 640'. -Sinker bars. hanging up On. approximately 70' of elec. W,L. left .in-tbg. Pooh. Ldaded tbg. w/ 5% KC1 water. Waited on-~fog.to' clear.-5-.hrs. 'to. 'load out fish~n'g tool~ RIH w/ W.L. spear to .640'..Rec. '26 1/2' of elec. W.L. Re' ran W.L.'s:p6ar twice, no recovery. Had indications of gun being al.ong side. of wire. Ran blind box to 640' & cut w'ire on top of gun head.' Ran W.L. overshot & engaged top of 3 1/8" csg.-gun @640'. Jarred on fi.sh 4 hrs. Fish moved up hole. 13'~.to 627'.'- Sheared' .out. safety release on overshot. Pooh. RD Dresser Atlas. Finished RD Dresser Atlas. Flowed well 5 1/2 hrs.'to recover .'; filtered inlet water w/ FTP = 1400 psi and CP : 280 .psi. Lubricated 200 bbl drilling mud dwn. annulus. 'Pumped 50 bbls 5% KC1 water w/ Dril-S down tbg. to 53-0 sand perfs 5425' to 5455'. killed well circulating dwn. annulus thru gas lift valves and out tbg. Installed back pressure valve and removed X-mas tree. Installed BOPE and tested to 3000 psi. Released pkr w/ 50,000# overpull and circulated well clean conventionally. Layed dwn. 4'1/2" tbg. and found perf gun in gas lift valve at 2016'. All fish recovered. Continued laying dwn. tbg. Completed laying dwn. 4 1/2" tbg.'& accessories.. RIH w/ 8 1/2" bit & 9 5/8" csg.. scraper. Cleaned out fill from 6174' to 6200'ETD. Circ. out gas cut mud. Pooh. RIH w/ 9 5/8" stimulation pkr on dry DP & set @5483' (below suspected gas entry from 53-0 sd). Press DP w/ 1050 psi gas. Opened tester at 1:42 p.m. Had no pressure increase on surface .in 15 min. Bled.off gas at surface. Rat hole fluid surfaced in 55 m~n. Had gas to surface at 2:55 p.m. Flow tested well at plus or minus3.1MM SCF/day w/ 900 psi at surface. Released stimulation pkr & rev. out gas. Pooh. 'Removed pressure bomb from stimulation pkr. RIH--W~ stimulation pkr on dry DP. ~3 ~4 :5 OIL .PAIN OF CALIFO 'IIA RECORD I,, I_L Ii0, FIELD._ · '~TE DETAILS OF OPEPATIONS, DESCRIPTIOtlS & RESULTS 7/!/77' .. 'TD RIH w/ 9 5/8" stimulation pkr on dry DP & set aboVe the "D" Zone 'ETD @5368". Press .DP w/ l lO0..psi gas. Opened tool @ 6'05 a.m. cm.t. ret) . Surface press. '.increased"~'~" 1140 psi in 20 min. Bled off gas 3 3/8" csg.] preSs to 500 psi. Had rathole fluid @ surface @7'05 a.m. Flow 5/8" csg.: · 724' - o . 7/2/77 ' . 5750 'TD- 5690 'ETD o · : : (est.' top o~f cmt. ) 13 3/8" csg!.. @4451' 9 5-/8" csg, '. @6724' . tested well to stabilize rate. RU GO-International to run spinner and temp survey. Tools failed on two runs, repaired same. Ran-spinner.& temp survey while flowing.well @ plus or minus 8.6MMSCF/day iw/ 700 psi @ surface. Survey showed major gas entering from 5770"to 580~'-in 56-1 sand perfs (5765'-5815') and gas entering from 5430' ~o 5440' in 53-0 sand perfs (5425",5455'). Gas. from 56-1 sand cross flowing into the 54-9 sand'penfs (5630' tO 5662'). Had no indication of.g~s moving behind pipe on temperature survey. RD GO International. Shut in ~ell at 12'00 p.m. midni-te 7/1/77. · . . Rev.'oUt gas .Relea§ed stimulation pkr. P. ooh. RIH'w/ 9 5/8" cmt '.'ret on DP & set below the 56-1 sand @5830' RIH w/ 9 5/8" sqz, pkr.& set at 5677' Broke dwn. 51=6.sand ~erfs. 5765' to 5815' w/'..16OO..psi & pumped in at 16 CFM.w/ 2000 psi. Mixed 300 sx. of C1 !~G''- Cmt,'w/ O..75%D-31.."Displaced.cmt.,'to Sqz..tOol & closed bypass ' Fluid Communicated between DP & 'annulus' '-Released sqz. pkr & rev. out Cmt. Reset tooq & press to'2000 psi w/ no communication. Pooh to change'out s.qz. pkrs. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5830'..Circ. btms. up. Pooh." RIH w/ 9 5/8" sqz pkr.& set.. @5690'. Pumped into 5]-6'~and ~erfs. @ 16 CFM w/ 2000 psi. Mixed & pumped 300 sx of CI'"G" cmt.'w/ 0.75% D-31 (ll'8#/~u.'ft. slurry). Sqz. 255 s'x into the 56-1 sand perfs for abandonment:to.a final'pressure of 4500 psi 1.28 psi/ft, gradient). Press. bled to 4000 psi in lq mins & held (1.18 psi/ft, grad). Bleed off press. Released sqz. pkr & · rev'. out. Rec. approximately 18 sx. of cmt. 7/3/77 6750'TD . 5473'ETD ' (cmt.) 13 3/8" csQ. @4451' 9~/8" csg, @6724' · Rooh w/'sqz, pkr. RIH w/ 9 5/8" cmt. ret & set below the 53-0 sand '@5478'. RIH w/ 9 5/8".sqz. pkr & set @5330'. Broke dwn. the 53-0 sand perfs-5425' to 5455' w/ 2000 psi. Pumped into the 53-0 @ 9 CFM w/ 2600 psi & 16 CFM w/ 2800 psi. Mixed & pumped 250 sx. of C1 "G" cmt. w/ 0.75% D-31 (l l8#/cu, ft. slurry). Sqz. 200 sx. of cmt. into the 53-0 sand .perfs for abandonment to a final press of 4700 psi (1.37 psi/ft, grad). Press bled to 3900 psi in 8 min. & held. (1..21 psi/ft, grad). Bled off press. Released sqz. pkr & rev. out. Rec. approximately' 26 sx of cmt. Pooh w/ sqz. pkr. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. WOC 6 hrs. Drlg out hard cmt. from 5336 to 5473' Press. tested abandoned 53-0 sand perfs w/ 2500 psi o.k. Poo~. UNIOI'I OIL CQI':PAJ' ' OF CALIFO ,IIA I' JLL I LCORD L.EASE 'ELL NO, FIE ~)ATE 46 47 48 49 5O 7/4/77 7/5/77. 7/6/77 7/7/77 7/8/77 ETD 6750 'TD 5825' ETD 13 3/8" csg. @4451 ' 9 5/8" csg. @6724' 6750 'TD ETD 6187' (junk on cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750 'TD 6187 'ETD (junk on cmt. ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750'TD 6187' ETD (junk on cmt. ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750 'TD 6187 'ETD 13 3/8" csg. @4451' 9 5/8" cs§. @6724' DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS RIH w/ 9 5/8" stimulation pkr on dry DP & set above the abandoned 53-0 sand perfs at 5388'. Press DP w/ 1150 psi gas & opened tool at 2:20 a.m. Had no increase of press on surface. Bled off gas press to 0 psi & left tool open 1 1/2 hrs with no entry. Shut in at surface, no press build up in 1/2 hr. Released test pkr & rev. out. Test o.k. Pooh w/ 9 5/8" stimulation pkr. RIH w/ 8 1/2" bit. Drlg out hard cmt. from 5473' to cmt. ret @5478'. Drlg out cmt. ret @5478'. RIH & tagged hard cmt. at 5696'. Drlg out hard cmt. from 5696' to 5757'. Tripped for bit. RIH w/ 8 1/2" bit & 9 ~5/8" csg. scraper. Drlg out hard cmt. from 5757' to 5825'. Circ. & cond. W.O. fluid. Circ. & cond. W.O. fluid. Pooh w/ bit & scraper. RIH w/ 9 5/8" stimulation pkr on dry DP &'set above the 56-1 sand @5726'. Press. DP w/ 1150 psi gas. Opened tool & bled off gas press, to 0 psi. Tested the abandoned 56-1 sand perfs (57655815') at atmospheric for 4 hrs. Had constant medium blow on bubble tube. Rev. out. Rec. approximately 17 cu.ft, of rathole fluid in DP, no gas. Released tool & RIH to 5825' Rev. out. No sign of oil or gas. Pooh w/ test pkr. RIH w) 8 1/2" bit. Drlg out cmt ret @5830'. Drlg out cmt. ret. @5830' & cleaned.out to 6187' (Junk & fill on cmt. ret. @6200'). Circ. & cond. W.O. fluid. Circ. & cond. W.O. fluid. Pooh. RU & ran 4 1/2" temporary prod. string w/ 4 1/2" sidepocket mandrels. Spaced out & landed tbg. w/ 9 5/8" x 4 1/2" Baker Model FH Hyd. pkr @5329' RU W.L. unit. Ran & set plug in 4 1/2" "XN" nipple @5369' ~ress. tbg. & set 9 5/8" pkr @5329' w/ 3000 psi. Retrieved piug..Tested pkr w/ 500 psi o.k. Opened "XA" sleeve @5293'. Installed BPV. Removed BOPE. Finished removing BOPE. Installed test X-mas tree and tested to 5000 psi. Displaced hole w/ filtered inlet water and closed Otis sleeve @5293'. Put well on test and unloaded filtered inlet water in annulus in 8 hrs. and started making gas at 1.8 MMCFPD rate. Tested for 8 hrs. at 1.8 - 2.2 MMCFPD rate w/ tbg. press of 150-95 psi No formation fluid entry during test. Moved rig over TBS A-2 to retrieve plug while testing TBS A-32. Skidded rig from TBS A-2 to TBS A-32. RU Dresser Atlas. RIH w/ 3 1/8" cased carrier gun & differentially reperfed the following sands at 4 HPF: San d I n terval Footage 57-2 5852-5912' 60' 54-5 ' 5590-5606' 16' 53-8 5530-5560' 30' UNION OIL CCFP/ ' Y e,¢ CALIFORNIA ¥,ELL I<LCOILD LEASE I' LL NO, FIELD ~TE 51 7/9/77 52 7/10/77 53 7/11/77 54 7/12/77 ETD 6750 'TD 5400 'ETD (cmt. ret. ) 13 3/8" csg. 9 5/8" csg. @6724' 6750'TD 5400'ETD 13 3/8" csg. @4451 '. _. .:~ 9 5/8" csg. @6724' 6750'TD 5400' ETD (cmt. ret.) 13 3/8" cs§. @4451' 9 5/8" csg. @6724' 6750'TD 5095'ETD 13 3/8" csg. (Cmt. ret.) 13 3/8" csg. 4451 ' 9 5/8" csg. @6724' DETAILS OF OPERATIONS, DESCRIPTIOIIS & RESULTS Placed well on production test. Performed W.L. work on TBS A-2 while testing TBS A-32. Tested "D" Zone at plus or minus 4.5 MMCF/day gas w/ 115 psi tbg. press for 9 hrs. after rePerforating. No fluid entry during test. Killed well w/ 65#/cu.fl~. KCL fluid. Installed BPV's. Removed X-mas tree. Installed & tested BOPE. Picked up on 4 1/2" tbg. & released 9 5/8" hyd. pkr @5329' Pooh w/ 4 1/2" gaslift string. Ran & set 9 5/8" cmt. ret. above the "D" Zone @5400',. RIH w/ 4 1/2" gaslift string to production test the "C" Zone. Spaced out & landed tbg. w/ 9 5/8" Otis hyd. pkr at 4479'. Set pkr and tested w/ 500 psi. Opened "XA" sleeve at 4444' & displaced KCL.W.O. fluid.w/ filtered'inlei~ ~Vater.' Closed "XA" sleeve. Removed BOPE. Installed X-mas tree & tested. Gaslifted out 264 bbls of filtered inlet water from tbg. and annulus. RU Dresser Atlas. RIH w/ 3 1/8" cased carrier & differentially perforated the 51-6 sand from 5315' to 5345'. Completed differentially perforating the 51-6 sand from 5285' to 5345' w/ 3 1/8" cased carrier guns. Tested the 51-6 sand at plus or minus 6MMSCF/day w/ tbg. press, increasing from 1240 psi to 1450 psi in 3 hrs. No fluid entry. SI tbg. press - 1850 psi. Differentially perforated the 50-3 sand from 5120' to 5140' w/ 3 1/8" cased carrier gun. Flow tested well on 16/64 choke w/ tbg. press, increasing from 1550 psi to 1750 psi in two hrs. (suspect choke icing). No fluid entry. S.I. tbg. press ~ 1900 psi. Killed well w/ 66#/cu.ft. KCL W,O. fluid. Installed BPV. Removed X-mas tree. Installed & tested BOPE. Picked up on 4 1/2" tbg. & released 9 5/8" Otis hyd. pkr at 4479'. RIH to 5350'. Circ. out gas cut. mud Finished circ. out gas cut mud and condition W.O. fluid. Pooh w/ temporary completion tbg. and equipment. Ran Dresser Atlas Multiple Spaced Neutron Log 5400' to 4400'. Ran 9 5/8" Baker cmt. ret on 5" DP and set at 5236'. Broke dwn. 51-6 perfs 5285' to 5345' w/ 3100 psi and PI @ 3.5 CFPM - 3100 psi. Squeezed 51-6 perfs w/ lO0 sx C1 "G" cmt. w/ .75%'D-31 mixed @ 118 lbs/cu.fto to a final pressure of 4600 psi (1.33 psi/ft.) and displaced cmt. 10 cu.ft, below ret. Pressure bled to 3700 psi in 5 min. and held 3700 psi (1.16 psi/ft.). Pulled out of retainer and reversed hole clean. Pooh w/ DP. Ran 9 5/8" Baker cmt. ret. on 5" DP and set @5095'. Broke dwn. 50-3 perfs 5120' to 5140' w/ 3200 psi and PI @ 8 CFPM - 3800 psi. Squeezed 50-3 perfs w/ 100 sx. C1 "G" cmt. w/ .75% D-31 mixed @ 118 lbs/cu.ft, to a final pressure of 4800 psi (1.40 psi/ft.) and displaced cmt. 10 cu.ft, below ret. Pressure bled to 3800 psi in 5 min. and held 3800' psi (1.20 psi/ft). Pulled out of retainer and reversed hole clean. Pooh w/ DP. PAGE UNIO[1 OIL CCtIP/V Y OF CALIFOP ,IIA I' ELL I(LCOILD ZA,SE I'ELL NO, FIELD ~ATE 55 56 57 58 59 7/13/77 7-/14/77 7/15/77 7/16/77 7/17/77 ETD 6750'TD 5095'ETD (cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724'. 6750'TD 5095'ETD (cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750'TD 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750 'TD 13 3/8" cs§. @4451' 9 5/8" csg. @6724' 6750 'TD 5400'ETD (cmt. ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' DETAILS OF OPERATIONS, DESCRIPTIOI.IS & RESULTS Finished pooh w/ DP. RIH w/ 4 1/2" temporary gas lift completion string and landed tbg. w/ Baker 9 5/8" hyd pkr @4480'. Set pkr and tested to 1000 psi. Removed BOPE and installed 4 1/2" X-mas tree. Opened Otis XA sleeve @4444' and gas lifted workover fluid out of hole to active mud system. Differentially perforated 9 5/8" csg. in C-7 sand w/ 4 HPF using 3 1/8" casing gun 4655-4685'. Finished RD Dresser Atlas. Tested C-7 perfs 4655' to 4685' o,n gas lift for 6 hrs. at 850-430 BOPD rate cut 3-1% w/ GOR of less than 100. Differentially perforated remainder of C-7 sand w/ 4 HPF using Dresser Atlas 3 1/8" casing gun 4595'-4655'. Tested entire C-7 sand 4595'-4685' on gas lift for 3 hrs at 1090-1000 BOPD rate cut less than 1% w/ GOR of 920-587. Differentially perfed 47-5 sand as above 4815'-4835'. Tested C-7 and 47-5 sands on gas lift for 5 hrs at 1060-910 BOPD rate cut 7-1% with GOR of 280-350. Rig to perforate after testing C-7 and upper 20' of 47-5 sands. Differentially perforated lower 20' of 47-5 sand w/ 4 HPF 4835'-4855' using Dresser Atlas 3 1/8" casing gun. Tested entire C-7 and 47-5 sands on gas lift for 6 hrs at 1100-900 BOPD rate cut less than 1% with GOR of 400. Shut well in and bled off pressure. Displaced DP w/ workover fluid and filled annulus. Opened XA sleeve @4444' and circulated hole clean cutting work over fluid from 66#/cu.ft. to 60#/cu.ft. Installed BPV and removed tree. Installed BOPE and tested. Released pkr and circ. hole clean. Unable to move pkr below perfs to circ. Pooh and laid dwn. 4 1/2" tbg. Changed rams in BOPE. RIH w/ Baker pkr picker to 5090' and displaced hole w/ fresh 5% KC1 water workover fluid to remove oil contaminated fluid. Attempted to enter retainer at 5095' w/ pkr picker without success and sheared pins on tool. Pooh and repaired pkr picker. RIH w/ pkr picker and could not enter retainer, shearing pins on tool. Pooh w/ pkr picker. RIH w/ bit #33 and drilled retainer @5095' in 1 1/2 hrs. Drilled hard cmt. 5097-5231' in 1 1/2 hrs and circulated hole clean. Pooh w/ bit. RIH w/ 9 5/8" test pkr and could not set pkr. Pooh and change out pkr. RIH w/ test pkr and set @5084'. Loaded DP w/ 1100 psi gas pressure. Opened tool and bled gas pressure to 200 psi. Dry tested 50-3 sand perfs 5120-5140' for 1 hr w/ no entry. Displaced DP w/ workover fluid and circ. hole clean. Pooh w/ pkr. RIH w/ bit #34 and drilled retainer @5236' in 2 hrs. Drilled hard cmt. 5238' to 5374' in 3 1/2 hrs and circ. hole clean. Pooh w/ bit. RIH w/ 9 5/8" csg. scraper. UNION OIL CCIiP/VCf OF CALIFORNIA ICLL I<LCOl® ASE I'ELL NO. FIELD ~TE 60 61 62 63 7/18/77 7/19/77 7/20/77 7/21/77 ElD 6750 'TD 5400 I ETD (cmt ret) 13 3/8" csg. @4451' 9' 5/8" csg. @6724' 6750 'TD 6645 'ETD (float col lal 13 3/8" csg. @4451 ' 9 5/8" csg. @6724' 6750'TD 6623' ETD (prod pkr on F. C. @6645' ) 13 3/8" csg. @4451 ' 9 5/8" csg. @6724' 6750 'TD 6160' ETD (perm pkr) 13 3/8" cs§. @4451' 9 5/8" csg. @5724' DETAILS OF OPERATIONS, DESCRIPTIOI,IS & RESULTS Finished RIH w/ 9 5/8" bit and csg. scraper to 5400' and pooh. Ran 9 5/8" test pkr on dry 5" DP and set @5230' Loaded DP w/ 1100 psi gas pressure, opened tool and pkr failJd. Pooh and changed out packers. Ran new 9 5/8" test packer and set~@5230'. Loaded DP w/ 1100 psi gas pressure and opened tool to dry test 51-6 sand perfs 5285'-5345' Bled pressure to 200 psi and shut in DP. Had gas entry wit~ pressure building to 600 psi in 20 min. Flow tested 51-6 perfs for 2 1/2. hrs @.5 to 2.5 MMCFGPD rate W/ 60-200 psi flowing tbg. pressure. Shut well in and pressure stabiliz6 @1800 psi after 30 min. Reversed out gas and circ. well clean and pooh. Ran 8 1/2" bit #35 and drilled out retainer @5400'. Drlg out cmt. ret. @5400'. RIH & cleaned out junk from 6187' to 6200' Drlg on cmt. ret. @6200' for 3 hrs. Pooh w/ 8 1/2" bit. ) RIH w) 8 1/2" pkr mill. Drlg out cmt ret @6200' RIH to 6645'. Circ. out gas cut W.O. fluid. Pooh. RIH w/ 8 1)2" bit & 9 5/8" csg. scraper to 6645'ETD. Circ. & cond. W.O. fluid. Pooh. RU Dresser Atlas. RIH w/ 8 3/8" gauge ring & junk basket. Unable to work gauge ring below 3453'. Pooh. RD Dresser Atlas. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 6624'. Circ. & cond. fluid. Finished circ. hole clean at 6645' and pooh w/ bit & scraper. Ran 8.375" O.D. gage ring and junk catcher on W.L. to 6300'. Set 9 5/8" Otis permanent pkr on W.L. @6200' above Hemlock zone. Ran 10' Otis seal assy. on 5" DP and stung into pkr @6200'. Packer not set properly, failed to test. Pushed pkr to 6260' w/ less than 5000# weight and circulated thru DP w/ 500 psi. Pooh. Laid dwn. locator sub & seal assy. Ran packer mill on 5" DP and pushed pkr to 6623'. Unable to push below 6623' - fill on top F.C. @6645' Circ. hole clean and pooh. Set 9 5/8" Otis perm pkr on W.L. @6i60'. Ran 10' Otis seal assy. on 5" DP and set in pkr @6160' w/ 30,000#. Pressured DP to 500 psi with no leakoff. Pooh and changed rams in BOPE to run completion tbg. Ran 15' Otis seal assy. and Camco GLV's on 2 7/8" tbg. with side string of 1 1/2" tbg. Finished running dual tbg. strings. Long string 3 1/2" x 2 3'/8" landed @6217' w/ locator sub on 15' Otis seal assy. @6157' giving 3' standoff from Otis perm pkr @6160' above Hemlock perfs 6260' to 6560'. Otis dual hyd pkr landed @4940' above "D" Zone perfs 5530' to 5912' and lower "C" Zone perfs 5120' to 5345' (squeezed off). Otis triple hyd pkr landed @4492' above "C" Zone perfs 4595' to 4855'. Gas lift side string 1 1/2" x 2 3/8" landed @6130'(30' above perm pkr) and extends to 4434' (61' above triple hyd pkr). Short string 3 1/2" tbg. landed @4503' in triple hyd pkr. Spaced out and installed CIW dual 3 1/2" hangers. Installed lubricator and tested long string seal assy. and perm pkr @6160' to 350 psi with no circulation. Set W.L. plug in long string "XA" sleeve @4978'. Set dual hyd. pkr @4940' w/ 900 psi and tested long string tbg. 4978' to surface to 3000 psi. Retrieved plug and opened sleeve @4978'. Tested dual hyd pkr to 350 psi with no circulation and closed sleeve. Set W.L. plug in short string "XN" nipple @4503'. Set triple hyd pkr @4940' w/ 1200 psi and tested short string tbg. JASE UNION OIL COHPANY OF CALIFOPC IA I', LL I LCORD $'£LL NO, FIELD -~TE 64 65 7/22/77 7/23/77 7/25/77 7/26/77 ETD DETAILS OF OPERATIONS, DESCRIPTIOHS & RESULTS 4503' to surface to 3000 psi. Retrieved plug and tested triple hyd pkr to 350, psi w/ no circulation. Finished testing triple hyd pkr @4492' and retrieved plug from XN nipple. Opened XA sleeves @4907' and 4458' and displaced hole w/ filtered inlet water. Closed sleeves'and started unloading fluid with gas lift. Moved rig to facilitate W.L. work on A-18 and A-2 while testing A-32. ,, * Unloaded l°ng string'tbg, in 8 hrs. Neither tbg. string producing consistent measurable amount of fluid. Alternated shutting in tbg strings to try to kick off each string for 24 hrs. Tested wells intermittently for a total of 48 hrs with no conclusive test but neither string producing any consistent amount of fluid. Short string producing by heads for first 24 hrs. Production Test Tested C Zone perfs thru short string for 4 hrs w/ no fluid recovery and shut in for surveys. Ran W.L. temperature and BHP surveys indicating well lifting from bottom GLV @4387' w/ bottom hole operating pressure of 233 psi and no fluid entry. Tested Hemlock perfs thru long string for 18 hrs w/ production increasing to max of 165 BOPD rate cut 30%. Ran W.L. BHP survey indicating well lifting from #4 GLV @4419' and none of side string dip tube GLV operating. Repaired bean in surface choke and prep to remove bottom GLV in dip tube to check for plugging of dip tube. Acidized TBS A-32 short string tbg. w/ 12% Hcl + 3% HF. *Unloaded short string in 8 hrs and produced small amount of oil while unloading. PAGE u iIOrl OIL CF CALIFO?CIIA ~[; FC~L)T1 LFJLSE IlO, TBS A-32 FIELD 2ATE ElD DETAILS OF OPEP~TiONS, DESCRIPTIOIIS & RESULTS 66 8/6/77 67 8/7/77 68 8/8/77 69 8/9/77 6750'TD 6160' ETD (perm pkr 13 3/8" csg@4451 ' 9 5/8" csg@6724' 6750'TD 6160' ETD (perm pkr] 13 3/8" csg@4451 ' 9 5/8" csg@6724' 6750 'TD 6160' ETD (perm pkr 13 3/8". csg@4451 ' 9 5/8" csg@6724' 6750' TD 6160' ETD (perm pkr) 1 3 3/8" csg@4451 ' 9 5/8" csg@6724' Moved rig over A-32 at 12:01 a.m. 8/6/77. RU Dowell on short string tbg. Treated "C" zone perfs 45.95'-4855' w/ 4000 gal 15% HCl containing .4% A-130, .5% W-35 & 7% U 66 followed by 10,000 gal..P-20 solvent. Displaced w/ 30 bbl diesel. RU GO Int. on long s~tring'tbg. Perforated 9 5/8" csg. in Hemlock w/ 4JSPF using 2~1/8'' bi-wire guns 6530'-6560' and lost 30' wire from guns in hole.. Ran 2 1/8" perf gun and could not get below 6196' in 2 7/8" tbg. Ran 2 1/4" sinker bars and could not get below 6196'. Ran 2 1/4" blind box and could not get below 6196'. Ran 1 1/2" sinker bars to 6220' out end of tbg. Ran 2" blind box to 6220' out end of tbg. Perforated 9 5/8" csg. in Hemlock w/ 4 ISPF using 2" "go winder" steel .carrier 6530' to 6500'. Could not get' back thru "X" nipple in tbg. @6182' and pulled out of rope socket. Ran sinker bars and drove gun out of tbg. Perforated as above w/ 2" casing gun 6500'-6470' and could not get back thru "X" nipple @6182'. Pulled out of rope socket. Ran tbg. cutter and cut 2 7/8" tbg. @6180' in pup joint above X nipPle. Reperforated 9 5/8" csg. in Hemlock w/ 4JSPF using 2" GO Int. "gowinder" carrier gun 6440' to 6470'. Perforating done w/ well shut in w/ 390 psi tbg. pressure and .hole loaded w/ diesel to 5100' (approx. 850 psi BHP). Perf gun split. Loaded hole to 3700' w/ diesel (approx. 1320 psi BHP). Perf as above 6430'-6440' and 6340' to 6400'. Could not get thru X over from 3 1/2" to 2 7/8" tbg. w/ perf gun after perforating 6340' to 6370' due to perf debris. Produced well for 3 hrs to clean up trash in tbg. and well heading too much for measurable rate. Loaded hole w/ diesel to 3700' and perforated as above 6260' to 6340'. Completed perf @9:00 p.m. and set ball valve. Long string on production 23 hrs at an average rate of 14 BOPD after unloading diesel.. Short string on production 3 hrs ~nd unloading solvent 'and acid water. Solvent soaked on formation approx. 80 hrs. Have 363 bbls of solvent, acid and diesel to recover. D~ILLII',~G lAUD RECORD COMPANY Un~on 0il WELL A-32 CONTRACTOR Parker Drilling Company BAROID DIV ~ ' N L induo r,es, Inc. STATE Alaska COUNTY. ~fo.~.~. ~n~,,~h UOCAr,ON Cook ~nlet CASING PROGRAM: SEC ~TWP~ RNG 16 _;.~ o, 502 3/8 inch 5/8 i.ch o, 6,728 ............ -'z],,z ! D' ~ '" DATE. ~EPTH WEIGH"~ VISCOSITY Yp GELS pH FILTRATION FILTRATE ANA'LYSIS SAND RETORT CEC 'J977 leer lb/gal Sec APl PV 10 sec/ Strip I-I mi HTHP Cake Pm ~MJ Cl Co % Soleil! Oil Water Mud, '['~ 'Kt~ REMARKS AND TREATMENT ~ OF ~°F 10 min Meter~ APl ~ °F~s ppm ppm % ~ % me/mi 5-20 3~ 67.0 37 ' 8.0 .... Drill ahead. 5-21 506 67.0 100~ 9.5 5-22 795 67.0 33 6 7 2/ ~ 9.0 3.'3 2 .3 1.C 12K 3~ .5 4~ 96 12.0 Flocc~ated mud 5-23 ],500 70.0 ~0 11 16 11/16 9.0~ ~ 2 .2 .~ 8~00 160 .5 6 9~ 13.0 48 1.4 5-2~. 2.620 73.0' &O 8 28 20/22 8.7 pfc,.3 2 .1 ~ 1ZK 320 .8 9 91 18.O .29 6.C ?.educe wt.f~lt..v~. 5-25 3~018 72.0 35 7 17 20~28 8.631.'3 3 .1:~ 14K 840 .8 12 88 20.0 545.C ' ' 5-26 3.Z7772.0 ~O 6 !8 16/21 9.019.~3 3 .7~1.~ 14K 9~ .8 12 8819.0.' 30:c.c D~a .drill 5-27 3:7Oq vp.oi 38 10 14 q/15 8.6!2.S 2 .2 .8 14K 1000 1.0 12 88 15.0~55 !.2~AddinE water. 5-28 Z.~006 71.0 34 5 5 /,~ g: ~.O 1A.~ 2 .A 1.2 I~K 920 .8 1] 89 12.5 ,~8 .~ 5-29 ~;308 70.0~ 40 9 11 $~1~ q.6~ll.~ 2 .51,~ II:K 6&O 1.5 12 88 22.5.45 .~D.~ma drill,add prehyd.gel 5-30' l:AdO 70,0 38 7 14 12]/2PJ Q.O~I~.'S 2 .A .q ]~K g~ .7~ lC 90 20.0 ,~ q.~FOH to log. 5-31 /,./,~ 71.0 38 7 'IA 12/pl, -g.O 1i. ~ 2 .3 ,q I&K gSO .7~ ]_C 90 20.0 ,A2.1.i RIH w/hole opener 6- 1 ~;~2072.0 39 10 19 ~272/, 6.0'17.) 2 .1 .~ I&K 8SO .7{ ]_C 90 18-O,&&l.~Coen hole 6- 2 ~,28C 73.0 4& 10 ~ 12/~ 9.013.~23.C 2 .2 .( 12K 600 .7~ 1] 89 22.0,&4'].cAdd ~rehydrated gel 6- 3 ~.46C 7~.0 Z8 lO 2~ 14/24 ~.~12.521.( 2 .1 .~12500 800 .7~ ]] 89 25.0(~A2 2.2POH to r~ casin~ 6- 4 4,A6C 7~,.0 Z8 10 ~ 14/~ ~_~12. 5 21.C 2 .1 .~12500 800 .7' 11 89 25.0 ~Z2 2.2 Cemented without ret~ns 6- 5 &,A~ 66.5 . :;iaole..uo BOPs 6- 6 Z,ASC 6~.0 36 6 7 ~/ 4 lO.1 ]6. ) 1 .8].~ 30K 3~ -P~ 3 97 12.0 .5( Y/:Build K'C1-XC Polar 6-7 ~,70] 67.0 40 ]/:12 5/15 9.6 ~.~ 24.C 1 .3 .~ 30K 3~ 1-6( 5 95 17.O .62 ZSDrilling 6- 8 4,8'59 68.0 48 14 15 5/16 9.2 7.[23.6 1 .2 .~28500 ZOO 1.0( 6 9~ 22.5 .5~ .8~POH'to log 6- 9 5,152 7~.O ~9 17 20 5/19 8.8 7. ~ P4.C I 'l .~29000 320 1,5(L 9 .... 91 25.0 .5~1.3 P?m desilter & desander ~10 5.37~ 72.0 ~ 12 13 4/10 9.0 8.0 ~.C 1 .2 .~26000 3~ !.O( 10 90 25.0 .~E .5 " 6-11 5~69C 7p o ~ ]5 ].7 5/19 8 6 R.~, 22.~ 1 .2 .~26500 400 .7' 11 89 22.5 .Sfl-OAdd KC1 to raise Cls- 6-12 5,946 +/[~ ~6 16 !8 5/19 8.7 7.3 22.~ 1 .2 .~,27000 360 1.0( lZ 86 25.0 .56~1.0 :~ 6-13 6~28~ 71.0 41 ]] ]7 6/18 9.2 8.523.~ 1 .2 ,~2~00 420 .7 11 89 21.0 .A6!Z~Drill ahead 6-14 6,40C 72.0 41 11 Pq 6/17 9.~ 7.~22.C 1 .3 .837000 Z80 .7:;~1 89 23.0 .~32.~Dr~]_l ~bead , '6-15 6,75C 72.0 40 11 1~ 6/19 ' 9.8 7.~2~.C 1 .3 .~34000 240 ~.O~ 11 89 25.0 .'f,61.TT.D, hole 6-]_6 6,75C. 72,0 ~.4 q/. ~2~ 7/21 0.2 7 I. 2],C ~ .3 ~ ~!O00 2~0 q n() ~! ~a 2~ O .L/~_ ~_:~_~ 6-17 6,75 72.0 45 lA 123! 6/19 9.0 7 '! 2~ .O il .2 .~29000 ~0 1'0~,~ 1; 8$ 25.0 .4~2.2 RIH to clean out 6-]~ 6,75f]_72.o] g5 ]-~ 'P3 6/~9 9.0 7.~ 21.c ] .2 .~29000 600 1.0()12- 8~ 25.o .A62.2 ~:"~*nt q 6_]o 6.7~c 72.o~ ~3 1/~ P~ 5,/]9 9.~ 7_qo2. C I 3 .~j/~u_ .~-25.0 ....... _ ._ . ~o-o 680 1.0~) 1~ S~' . -' ' , , ,~, 72.0J ~ ]6 16 &/19~ lO.O 8.~ 22.8 ] .1 .525000 3~ .75 1~ SS 22.5 .5~ .~Eaverse out Snuceze 6-21 6.75,q 64.0 28 ~2AO00 ..f*! KC! to se~wat?r .-, ~, ~,~ ~, . A ....... ~.~,.~ , , ..... STOCKPOINT R~g Tenders Dock DATE 06--2&--77 BAROID ENGINEER R. L. Dewees, Richard K. Thomas TOTAL DEPTH Union Oil Company of California COMPANY. ,, WELL A-32 CONTRACTOR Parker Drilling Company 5TOCKPOINT Rig Tenders Dock DATE 06--24--77 BARO D DtVt O l N L ndus ries, Inc. STATE Alaska 16 inch at 502 ft. COU.TY Kenai Borough . 13 3/8 i.ch o, ~.,~51. ft. LOCATION Cook Inlet 5EC~TWP~RNG~ 9 5/8inch ot 6,728_h. BARO~DENG~NEER R.L. De,.~es, ~chard K. Thomas TOTAL OEPTH 6,750 CASING PROGRAM: ---- , n, .. -- , DATE DEPTH WEIGHT VISCOSITY Yp GELS pH FILTRATION FILTRATE ANALYSIS SAND RETORT CEC Sec APl PV 10 sec/ Strip [3 mi HTHP Cake Pm %t CI Ca % Solids Oil Water Mud, REMARKS AND TREATMENT feet lb/gal ~ °F ~°F 10 min ~4eterO APl ~°F32nds - .-,. ppm ppm % % % me/mt ~6-2~ 6,750 65 32 ' ,, Released fr'0m rig. ' .... .f-- , ~ , .x~ .... ~, . · ' I '_L...; ~' .... ,.. ' ,,. m ,, m m m ,~i~ ~ATERIAL AMOUNT COST MATERIAL AMOUNT COST' · MATERIAL ~MOUNT COST $ $ '~ $ Aq~gel' 924 11,559.~ Soda' Ash" ' 75 .. ~,733.25 Parafdr=ald,,hyde .... 10 '659.~0 BAROID DIVISION Baroid 875 9~196.25 SAPP 5 393.55 XC Pol~er 51 .20,637.66 Caustic Sod~ . 110 3,081.10 Wall-Nut ~O~ ~42.60 Tech. Servi~.e' ~_.~ Bicarb.of S~da A 122.~2 Sodi~ Nitr~te 2~ 92.00 36 days ~ 1~5.00 INDU~RIES O-Broxin 66 1,877.70 ~x. ex, .... ~: i2: 1,6~76 60 3.OO _,2~ 23 ..Drispac 156. 24,Z53~00 Potas. Chlo:~ide 545 19,336.60 %tUD ~AIERI~h~ ' D~yage Used (Iota~ ' sa~es ~a~ ' - ~ ........ D~ILLIHG r~UD ~EC0~D TOTAL CO~T '. BIT RECORD .. /' _o, CONTR^CTO, P;~ ~ K ~,/:-~, R~G NO Rig COLLARS: OD X ID X LENGTH MO. / DAY / YR. J.P.-DRILLERS ' COMPANY ~/~//O ~/ FIELD ~, RIO SIZE X X SPUD / / LEASF WELL NO, /g ' ~ PUMP NO. 1 X__.X UNDER SURFACE' / / STATF ]'] ~. ~ ~ COUNTY~ PUMP NO. 2 DRILL PiPE UNDER I~ER. ~/ / WATER SOURC~ SEC./ T'SHIP/RANGE MUD TYPE TOOL JOINT TOTAL DEP~ __/ . / FUEL SOURCF Ver. JETS - 32nds FE~ ~' PUMP PUMP NO 1 PUMP NO. 2 MUD PROPERTIES Dev Dull. Cond.~ ~/8 RUN SIZE MAKE TYPE SERIAL Reg. R or RO DEPTH CUM. 1000 R.P.M. PRESS. Liner SPM Liner SPM Wt. ~L. F.V. P.V.Y.P T B G NO. NO. 1 2 3 OUT FEET HOURS HouRPERHOURS LBS. Date i.~ ~,,~ ~t1~ ~x~ ~ 3~ ~ /~../~, ~2 '1'~ I~ ~.:~'~ /itc .~,~.~.~ ~~¢~ ~.:~,. t~. Z~ ":':'/~ .... . . .. ~ ~ ~ ~ ~ , , ...... -~ONTRACTOR RIG NOl RIG MAKF COLLARS: OD X ID X LENGTH MO. / DAY / YR. T.P.-DRILLERS COMPANY FIELD RIG SIZF X 1( SPUD /., . / LEASE WELL NO. PUMP NO. 1 X~X UNDER SURFACE __/ / STATE COUNTY. PUMP NO. 2 DRILL FIPF -' UNDER INTER. ~/ /,__ WATER SOURCF SEC./ T'SHIP/RANGF MUD TYPE. TOOL JOINT. TOTAL DEPTH ,/ . / FUEL SOURCF Ver. JETS - 32nds FEET WI'. PUMP ;UMP NO 1 PUMP NO. 2 MUD PROPERTIES Dev. Dull. Cond. l~ 1/e Date RUNNo. SIZE MAKE TYPE SERIALNo. Reg.1 2R or RO3 DEPTHouT FEET HOURS HouRPER HOuRsCUM' 1000LBS. R.P.M. PRESS. Liner SPM Lin'~r SPM Wt. W.L F.V.P.V.~Y.P, T. B G , , ~ 7, ....... , ..... GR[AT LAND DIR[CTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY UNION OIL OF CALIFORNIA COMPANY ~_~ ~o~o~o~ ~-~ ~ WELL NAME 0 COOK INLET; TRADING BAY ~ LOCATION AL-577 D-6 JOB NUMBER SINGLE SHOT & GYRO TYPE SURVEY 6-2a-77 DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. 2,3"'"' n I0 199.9c:;' 9~,99 $21.OOE '"' ' ' ' ,.,,,,.41 S 0,i6 g O,aa S 22 2C 0 '.:' C),006 -,3.,,',,+ ........ ,..'L~:'..~ ............. ',.q .......... E ............... ..2:.2.%.__.9_~ !~.~....,.. ~_~ S.?L%.,..P/.O_F. 2._,.A:.2..._~ ........................... A.._E~_3_ 2.,..~...6...,....~.... ~. ~......~. S ......... ~ ........... ~ ~L.~...¢_.i~. ,..~'. ..... _q_.:.~.._r.~__. ........ .0_.__~..~ _3.:0'9.9'9 298,99 ?';66,00E 0,65 S 0,56 E 0.86 S 40 26 27 '~7. 0,!60 -'" ,,, _ !...,' ,,,. D..~. ...... 5"'""'",..,,.,, :9 30 499.9''c, 398.99 NSO,OOE 0.46 .,.~': 1,18 E i.27 S 68 28 37 ~ 0.250 -0,,,~$' .... 6,'"n 1 45 509.97 498.97 SS~.uO:- 0.,~3 : 3.05 E 3.18 $ 74 ~+8 16 E i,251 -i.9'7 ___-'7~.,,,~.~_ ..... _!_~__(?_ ...... ,5~__._gv,_zA ....... ~.~_._, ._~:~ ............. ~.7..~_._~_.0_E_ .............. i_~,.:.,__, .:: ................ ¢_._._..¢A__E .......................... ?___.__x_.? ........ ........... ¢,_ ........... .~.._._~_ ~__._~ .,5__o_ ................................ ._-._E_,_.',2_Z ,~OC ....... 1 1~ 799,90 698,90 527,,.~ua -~,38 $ 7,49 : ,22 S 65 4.0 33 :."' n.,,251 -6.06 cOO O 4.,5 899.89 798.,. .,89 533,00E 4.89. $ 8,36 E'. 9.69 S Dc' 39 0 E 0,500 --1,8.0 ............... 'f ....................................................................................................................................................................................................................................................................................................... ~ '" ."" ................... : ........................................................... 4 .~(,~ 999.88 898.g8 N52.0©;:, 5.05 5 9.3~ .... E 10.60 S 61 ~,~'~ 58 E ~:i.250" -8.3,: ..................1100; 4 ;:"30 .............. 1099.76x---;'-: .................. 998,76r ........... : ............................ 540,00.N~'";' .............. 7.18-- ........ o7-- ....................... 11.37~'-;"'-,,:. .................. ,1.3.45'"'~' ................ o7: ...... ,57:: ..................... 42';: 17 ';'= ......... --~--7 ,";';~.. % · ,L ,::, 2 ........... _.~.~ '~ . ,.% o.,,,,.,., 123!). o., 1.5 ~1g°.02.. i098.,02 545,00W 16.00. 5 ~.29,., '::', ..... 16.'*z.,,.., $ 11 37 2°> ¢",.., 4.752 -16.00 ..... 'f'ES'i;F"'i"5-T¢. , . ................ .f-2--~-:T;-4'~ ................... i"f"Fg-:'};'~)' ................. '~"~"A"-;"5'57;I ................................ 'Zf-;':¢T"'"~ ....... ~~, ....................... ~'~'Tg'g ............ S'"'"i"~ .............. ~'~ ........... i"i ........... i:;: ............................. i"';¥:3'T ............................... ~..7 .................. laO0 12 0 1395,53 i294,53 S52,00W 4(:,63 S 24.40 W 47,39 $ 30 59 34 W 1.262 -2. 1DO0 14 30 1492,86 i391,86 S52.00W 54.74 S 42,46 i4 69,28 S 37 48 11 '¢; 2,50C -33,52 1600 16 20 1589,25 i488~25 $51,00W 71.29 S 63,27 W 95,~2 S 41 35 24 W' 1,842 -40,5i ........1 o ,.,, ,..,7;"7':;-r~ ..................... 19 'E..,. .......... i779.:';,!=- ...... ,Tx ......... 1678 · ~) 17 ...... ~--2E-'= .................. $51 · 0 OW'"' .................... ;"-; .......... 11.,,..,,47--Z~- ~.. .............. ='-~,q¥--7---~ ~ u. 8 i ~'-t'7.~ ...................... i56.+7'-: ..... Z .............. ,,E--7-':'::"M..p 2~: 75-'17., ~,,, ................... 7:--0.~26.2--";'-:-"":' ........................... ~'":-::57.74 ---~="?i~'-~-~ ~.., 0 ~ ............. ~- ........ ~ ~' ~ ~ · :.:,g--5-Z-¥'-~7=- ................. 1867 · ... ~i ....... ~- $:~ 1.50¢.~::"~'i:-'"'""'-"'-~-7 .......... I~ -,. · ~g'"'w--';~ ..... ~..:~ .......... 161....5'-:-:'--F-~---U?~,,, ............. 2 ~ .A.. ~0~ ....... :--': ........ $:: ............. ~0;- ......... ~].~ ............ iJ'~r'::-~F-"i:i,, ,..~ ,, .~ .:~ ~F ....... :;-2-';': .......................... -- ~ ::., ::U:":-E .... ~"F ..... - z ~-~0-5'--i-'~i ...... ~-:-- ........ 'fi~-'&-~-';-~-~- ....... ~-~'~-f;~-z; ......... 7~"~--f,-dot-";~' ....... 1'7 i'~i~:~-S- .... .~.¥~-;-~ ~'-q:-' ....... ~-~37~,"S--~'~'Y'-'~'-~----'Z~7-'~,7 .............. ,~i'~"-~'~ ................. z-~:.-S-;'-'~-:~j: ......... ,~20,') 18 /4.5 2157,76 2056,76 S~3.5u~,',~ 191,5'7 S 212,52 ~,.,,' 286,12 S 47 5~ 6 '4 0.359 92.09 '-~'-F[q-;-~._3..,,,...., ......... 1..Tq" ...... .30~ ............. ,.:.; ~..,. 2 · ~ ~:5""7~-¥-~'"=' ..... 2~51.5Z ~:----' ';; ........... 5~ ~ · OOv.~=;"- ....... ';'~ ................ 2~0.58"---- ............ S --;: "':z~S. 1'~-q'7 ............ $-~-7-~'STZ~'--'-'~'"'-'~-'~ ....... 2-'~' ........ 5"'~'-'"'?~~ .................. ~-'~-'~5"~ .................... ;J~'~J-'~"'~-~' ..... ........ r,-%-F ........... ~ ......................... 7-~7S ......'7: ....... ~:' -., ................... ~T ......... ~"-':'-' .......... T~'-----;c--,.-,-:------~ z 4 ~. o 1 ,.~ o ~ ~,'..,,. 7,4 ~ z ~,-~-~; .... s,:, ~ · ~ o w ~. ~ o · z s s ~ ~ 2~-S-$---t:.F .......... -S~'~-7~i'--~ .... S'-~?--'~¥"-:~TZ"T;~ .................. 5";-~"~-~ .................... :'---i-~-%-~)".ii ........ . , ALL CA. LCUL,,,,TIOi";S. 7 T;~UE f.!EAS. ,~,IFT VERTICAL ;.,EP TN ANGLE D~PTH -q~A ~ i,~EC : D ~,I D E G, B200 21 45 3104,76 3003,76 $82,QOk~ 311,75 S 4~9.89 v, 589.14 4200 22 30 4028.53 3927.53 ;~z2.00w 2i0.64 S 839.08 W 865.11 $ 75 54 2~ ~*,, ~.086 137.76 4300 23 BO 4120,58 4019.58 NIO,OOW 173,15 S 849.83 W 867,29 S 78 28 59 ~¢,J 2.154 480(.; 26 55 4561.15 4460.15 N18.00E 60,56 ?,,i 847.68 W 849.84 ~ '"' ~ ~ ~ I~ ~ ~ ~ ,-~ ~ .... ~ 4.00 Z6 ~. 4650.44 4~49.44 N~6.00~ iO~,B7 ,',, 8g0.82 w ~37.~1 ._!~..gfi__~A_~D~.~?s,.~_~! ....... ~.~!Z~..~.! ....... ?:~.~...Rg_: .... ~.!_:~_2 .... t,: ....... :.:p_:}~_ w ............... RECORD OF SURVEY ALL CALCULATIONS PERFORXED ~Y ,I: ~, ? EL'.'::CTRONIC CO~',~PUTER _i.2r":SAS" DRIFT VERTICAL SUB D~IrT~ .......... ~_ TOT**L17 C~-~uRuI'\ATBb.~i..7~...~;..Z, ....... , ........... Z"~Z C L wO ....... ~ U ,x :: ~ o:~vL~x~ TY~..~..~..~...2..7~ .... ~_.~ ............. CTiw.',,,.~?.~ DEP TH ANGLE DEPTH ¢ ¢ ......... , ,,¢~ ........... ,..,. ~.- 5500 25 20 5189.19 5088.19 ?.i/+0.OOE 321.72 .,',i 686.1,~ 'e,. 757,82, ?; 64 52 43 .... ~,,,,; ................ 0_~_..5..5..~ ........................ 6500 27 0 6081.~9 5980,59 NO1.00E 670,15 N 399,91 Y 780.a0 N 30 ~9 37 '¢~ 0.170 ....... .~..72..~_!_7 ......... !.9_ ....... ~.25_2.53 .......... _0..!A~_~_..~._3 ........... 0S_!.,..P_9_g Z~__?.?...~'...O_.._.~¢_ ............... ~&..t¢.&,_E .............. fl...k~:.,.O_.g....;:¢:! ...~__; !_7....?¢. 0.._.~.5~_.~_.~ ,., .,,.'.,'~., 7, ~ ,,~ , ,~ ,., .iZ,,, ,,.~.1 .r ~ ............... O--l~. ,~.,.~..~--! ................ A!,,,~. ~,, ,,~ , ~r, ! ......... ~':4, S. ! i~ ~, ,,,~. , ~,. g I ,,,},,.~. ,.~. i ,~, ,:~ ....... r::?, .................... ~ t i. ~., 9__i ...... ~':',. ............. ,~.~..}--, ,l~l,.! ~ ........ ~:!. , , ,%!,, !.. =,... ,!y ~ .......... !,, !,. ,,: )5~', (!,. ,,~ ,, ~, ,.~, .~ TRUE ............. . DEPTH DEPTH D I STA;~CE A~:,GLi SEA _Z?_,__.~.~.~O.~.~. ~.%~.~ ~P!.!~_~_7 _!.~_~__Z_ -. ~..~..~ ~.~.?_ ~ ~._a_.7_5 , .,~ . ~ 2 A ,_.?_~ TOP 31-SSD 3895 3747,33 294.25 S 761,45 W 81~,34 S ! 9Z.,.,,,.,,~,.~:5_,...~,~!~ .................. ,E, U3_ ~,.,.~0! , ,7 ~ TOP 46-6CL 4740 4507.77 3~,24 N 854,92 ~' 855,60 :~ 87 42 22 '.{ ~4.06,77 T~? .... ~_~_~, ~_ ......... E.%! E ~_~..~_.~ ?.,~ TOP 48-75D 4952 4696,90 123,~0 N 820,50 W 829,71 r'~ 81 27 11 ~', 4595.90 ~___5_.~Tw' ~0-~S~ ...... -=114 ...................... ~4841.51 ......................................... 188.602___.._~_:,.~ ......................... 7o7.781__ '_ =~'~. ........... ~ lu,o ~'i_~i_.i.~. ........... .'__._..i~, 7~ ...... ~21.1 .............................................. 9 ~= 474~. 5 ln.__. ~ ~ ~ TOP 53-0SD 5~22 51i8,79 29~,70 N 707,37 W 766,69 N 67 18 4~ W 50i7,79 TOP 53-8SD 5488 5178,35 317,77 N 689,44 W 759,15 N 65 i5 i5 ~.~ 5077,35 TOP 54-5SD 5590 5270,63 351,25 N 661,75 ~'..' 7z+9.20 i"'~ 62 2 28 W 5169,63 TOP 56-lSD 5755 54t9,10 407,76 N 617,18 W 7~9,72 ~:4 56:2 53 W 5318,10 TOP 57-2SD 5851 5504,78 441.56 N __T_Op__5!.-. ._I S D_ ..... 5j)__l ............... .5.__~)_~_,..~.:8_ ............................ _4_TA:!k_ T"~P~.... 5~-7SD 6006 5643,52 494,49 N 545,69 W 736,41 N 47 4°., 3 :."~: 5542,52 TOP 60-OSD 61..32 5755,20 540,00 N 50<>,i8 ~ 742,2t N 43 19 3 ~..'~ 5654,20 TOP 60-5SD 6179 5796,75 557,17 N 495,49 W' 745,6~ !"~ 41 58 z+7 ;5: 5695,75 TOP 61-tSD 6210 5824,18 568,41 N 4e6,42 W 748,12 N 40 ~3 19 W 5723.].5 ~ 8" " ?,: 39 , TOP HE?iL, 6~50 5859,58 5 2,82 N 470~62 W 751,6.; 9 27 '~'~' 5758,5~ ~..P ,, FOPE 6576 6149,25 696,27 N 377,20 W 791,88 N 28 26 4~ W 004~:,2; ?. · TOld=' :','!C ~S~J~ E D V~RTICAL SU~ ,:,'i L,-T VD V~xT I CAL DEPTI4 ~EPTH SEA DIFFEtRENCE CO~ECTION TOTAL CCORDiNATZS 501 501, 400 0 0 3.46 S i.i9 601 601, 500 0 C 9,84 S ~.09 801 801, 7C0 0 0 3.40 S !.eD1 ........... 9. Q.G 0 O 5..~0.~ ~ 9,3.~ llO1 1101. lOOO 0 0 7,24 S ii,32 !,2,,{:! ~ !~.~2 !,~ !. ~, ,09 ! ! !E~,~,...~ ~ 1304 1301. 1200 2 i 28.40 S 9,79 1406 1401, 1300 a 2 4i,35 1717 1701, 1600 16 5 93,57 S 90,24 1823 1801, 1700 22 6 115,15 S 116,58 i928 1901, 1800 27 5 136,75 2034 2001, 1900 33 6 158,35 $ 170,16 ~,,,!~,,~ !!9_!,~ ~.,20..0 ~,,~ > !Z,Sh!!,,,..,,,~ 2246 220!, 2100 45 6 200,37 S 22~,2i 2351 2301, 2200 50 5 220,58 S 250,78 2456 2401~ 2300 55 5 241,42 $ 275,60 2561 2501. 2400 60 5 260.87 2875 2801, 2700 7& 5 293,12 $ 386,88 3088 3001, 2900 87 7 305,61 8 459,t2 3196 3101. 3000 94 7 311.54 $ ~.98.41 3304 3201. 3100 103 9 316.82 S 538.46 DBPTH DEPTH SEA, D I FFER E!";CE CORRECT I O~'x TOTAL CO©RDINATES 4503 4301. 4200 202 4732 4501, 4400 231 .~..~._ ~..5_ .~ ~P.. !.. ~ ~. ~_ 0.9 2...~..4~ k ~ l_?_. ,... _0 .~. JY ~ .~ ~ ...~ ~e:. ~ 51.80 4901. 4800 279 11 213.11 N 772.~8 5513 5201. 5100 312 11 325.98 N 682.57 5623 5301, 5200 322 10 362.04 N 652.82 .... : :, .................................................................5847 5501, 5 00 4. ............. 14_> 6 13 6409 6001. 5900 408 12 638.88 6634 6201, 6100 433 ............................................................................................................................................................................................................................................................................................................... TRUE :,~EASU -'-°, EO" VC~T ~ ~.CAL $ L; ,.':.,, Z:.EPTH DEPTH SEA TOTAL. COORD I;4ATES IS00 999, 898, 5,05 S 9,31 2000 1968, 1867, 151,50 $ 161,47 5000 ~739~ &63Se 1~2,65 6000 5638, 5537. 492.41 ".>., : "r:PT:: :":-:T~.' /.', ,:-, · ~ *' z-,~ 2 ."~ & q :': ! :. ~-, ';' 1 L~ ~ ? _ q i ?: _: '! ~ q '7 - ¢-, A_ .', :. ¢ / .:: ¢': '.: : : "~ '7 · : ';, ;: ,:' :.? -' ....................................................................................................................... T=:':"' .... =,~.~,,.~:____509:,':""-'" ~: '"" i 4,.,31,41Z:_.1 ....... l ~,~.2¢ZL'I ........ 11 ........ Z,~ .............. 71'Z'7.:"::7 't,~ ......... :,~,_~2~:,:.¢'::"'~'" ~':, :,~ ..... -z,L.:~. ~ ': "" ' ........... :~..:_:.:,~::' .... "' ' .......... >.,? :0-:SL- 5i!4 4J55,01 220,55 N 772.35 ~,.'. 805.32 ' '7~+ ? 2c? .; L'7;:2.31 - ...... ?:?:. _. <.: ..... ~::_~z., z.~..d..~ P.-~_,~..,..~.:_.,. ~..~'..~..p_,_~..~! ....... TO[:~ 57-2SD 585! 551:),54 4L~7,2i :",~ T(,:..?~p..~ IS'D 5951 .:oC,:9,~.,,:: ]"",p /..r}--~:.q~ ~. 1 MO ~; ~ '~ / - : c :-w -- ~ .'-,,', '- ~ "7: ...... ~ ..... ::::::::::::::::::::::::::::::::::::::::: :~:~;:-~::~----:~ ............................. :¢-:5.-:h ................. :::----~..:~ ............ ::: ...... Y ...... :.::;: -::: t:'"::.:::-'":i': : ...... ~ ~..~- _7,, ~ ..... --: ;,.,~' ;-::: r:;, ~ ;: . ; . ..- . . . .. TVD: 63,21~ TMD 6000: HORIZONTAL :VIEW SCALE I"- 200' UNION OIL COMPANY OF CALIFORNIA MONOPOD WELL NO. A-:32 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT ALL DEPTHS SHOWN ARE TVD 4400 5~00 5 600 4000 ~ 3600 $ 200 _~"2000 =~~,~,~' 2400 2 800 VERTICAL SECTION SCALE I"= I000' UNION OIL COMPANY OF CALIFORNIA MONOPOD WELL NO. RADIUS OF CURVATURE MAGNETIC SINGLE-SHOT 400 800 ' 1200 1600 2000- 2400' 2800 - 200 $6O0 ALL DEPTHS SHOWN ARE TVD )0 4; 5 600 6000 TVD = 6 321t TMD e 6 750' __C__O. MPLE T.~LO ~._AEP~ _OR_T_ ............. ~'YROSCOPI C:- SURVEY .RADIUS OF CURVAlqJRE PlETHOD OF cOMPUTAT_!_O_N_S- ,.CONPUTED FOR S-C-~EN_T..[_FIC DRILLING CONTROLS BY ALL CALCULATIONS PERFORHED BY ......... 6- .................... 0 .....:. ,' ......... , ....................... - ~ - .q ..... 0 ........... .~0.o_ .......... ~!,._9.0 ..... ~s!}.,O.qE .............. ~o_,.g.q_S_ ................ .0..,oo ..... AO_O .... .o._. ~.~ ......... !..9,9_9 ...... _-!,_0o_ ....... .S.a.!.. OO.E_ ............... _9_,.~.~_ ~_ ............ o.? 0~__ .~g.O ...... 0__~o_ ............ _!??;_99 .......... ?_e_,.9.?. ...... !!.l_~.O_O.E ................ 0.~.~..__$ .................. O.?.i..~_..~ ~ ~_}_0._0_ ...... ~ 5 299.99 __J~?_~.~9_...__~_~,,~?O.q,~E ...... 0.60 S 0.28 E ~.9_o_ ..... 0___~.5 .... _~..97_.,.~9 ............ 2 9.8,~_~ B6 ~.,_0. 0_£ ............. .0., 6.5, ..s .............. _o_,_~_6.._E ___5_0o ...... 9_.30 ........ ~._.9..79e ...... 3. .9_~ _, 9_ 9 ..... NsO,OOE. ............. 9_,fi6_.S .............. J_.,_.JA_E ........ : ......... ._~,.~.7 S'_ 68_2B.:.~?__E ............. 0..,.250 -0,89 ___?_Og. ....... .~_ _~_0 ...... 6_99_._9.3 ...... 598.._93 576,00E ......... 1,93_..S .......... §_,...6.6._.E. ........................ 5..;~ ~.g_....S_ 7 ! 8 ...... ~+_ E ........... O:Z_50 .................. ._-._~_.._0__~ ........ ...... _~_0_~....~ ~5 ?~9.9.0 ........ 698,90 .... $27,00E ........ 3_.38...~ ......... 7.,~+9 1_o2o _ q_3o ....... 799_.~.8 .......... ~9S.,8.8 NS2.oPE ......... 5.;.0_5 ~;-~: .......... .9.3.!~.E _A~_00 .... ~0_~5 ........ ~.z97~_~.~_ .... ~z~6_~,~ ..... S~..8.oo 27.95 s 9.30 ~v ~9.~6 $ ~e ~ ~ w ~.5o~ '-2~.o~ 1~"'~, J2 0 1395.53 I29~.~ S52,00W ~0.63 S 2~.~0 W ~7.39 $ 30 59 ']~"W 1,262 -27.69 1600 I6 20 1589.25 1~88e25 $51.00~ 71.29 S ,~ 6~,27 '---- ' ~-.-'- ................................................ ~ ....... '. ~ ............................................... ' ' ~ . ~ ~ · ~ 0 2300 18 ~0 2252,52 2151.52 &53.00W 210,68 S 238,11 , -TRUE -78.87 ANGLE DEPTH $U0 _ DR__ILF~T __~_ SEA DIREC TOTAL COORDINATES ' ~. 16 ~5 2538,30 2~37,~0 555e00~ 267.~:9 & 309,48 ~ ~09e06 ~. 28 0 ~2L0,~3 4109.6~ N 7,OOW 130,20 $ 856,25 W 866,09 S 81 21 '12 W 4,5~8 218,45 ~5~_~ 26 55 ~739e73 ~638,73 Ni7.OOE 142e67 N 810e73 W 823,19 N 80 i i i ! i lO L~ f0 IO)O )0 I0 i i DEPTH . DEPTH -SE~- -~i'~FERENEE ~.0~_~ ................. ~901~. 3800 ~61 9 253,05 S 808,B~ 5180 ~901, ~800 279 11 .213.11 N 772.38 55: ~01, ~100 ~12 11 325,98 N 682,57 5735 5~01, 5300 333 ~ ........... 570!, ....... 663~ 6201e' 6100 433 13 716,30 N 359,79 6747 .............. 63_Q~9. "~000 2918, 2817, 300°39 S 428,10 ~000 384~e 3742e ' 269,95 $ ' 792,30 5000 47~9, ~638, 1~2e65 N 810,74 SD 82:5.ilb - --~S E CTION SCALE T.M D 6750 ' ooo'. Union Oil and Gas r'"-'~""~; Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907)276-7600 eptember 12, 1977 'Mr. Hoyle Hamilton ~.-~ Division of Oil & Gas 3001 porcupine Drive, Anchorage, AK 99504 RE: MONOPOD PLATFORM KBU 13-8 KENAI GAS 'FIELD Dear Mr. Hamilton- Enclosed for your information are three (3) copies of the Monthly Report of Drilling & Workover Operations for the above captioned projects. ,. Sincerely ryours,.,.. ¢,... ........ dim.X~R. Cal lender Dist. Drlg. Supt. cc' USGS .Harry Lee Marathon Oil Co. Form No. REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL ~X~ WELL $. APl NUMERICAL CODE 50-133-20301 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 GAS [] 7.IF INDIAN'ALOTTEE OR TRIBE NAME WELL OTHER 2. N*MEDF OPF.,RA1;OR,, union Ull CO, of Calif. s. UNIT FARM OR LEASE NAME Trading Bay State 3. A~J~.RE~ OF~A~O~47 9. WELLNO. · , Anchorage, AK 99502 TBS A-32 10. FIELD AND POOL, OR WILDCAT Trading Bay Field 4. LOCATION OF WELL Conductor 25, Monopod Platform, 1607'N & ~5~..~'~ ~ ~/E D SE Corner, Section 4: T9N, R13W, S.M. - S EP i 4 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 4' T9N, R13W, S.M. 12. PERMIT NO. 77-18 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOL]~I~,I~A~IN~;I~A~uC~N~I~]~ ~LUDiNG DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOB~I~I~IOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 66 8/6/77 67 68 6750'TD Moved rig over A-32 at 12:01 a.m. 8/6/77. RU Dowell on short 6160'ETD string tbg. Treated "C" zone perfs '4695'-4855' w/ 4000 gal (perm pkr)15% HC1 containing .4% A-130, .5% W-35 & 7% U 66 followed by 13 3/8" 10,000 gal. P-20 solvent. Displaced w/ 30 bbl diesel. RU GO csg@4451' Int. on long string tbg. Perforated 9 5/8" csg. in Hemlock w/ 9 5/8" 4JSPF using 2 1/8" bi-wire guns 6530'-6560' and lost 30' wire from csg@6724' guns in hole. Ran 2 1/8" perf gun and could not get below 6196' in 2 7/8" tbg. Ran 2 1/4" sinker bars and could not get below 6196 8/7/77 6750'TD Ran 2 1/4" blind box and could not get' below 6196'. Ran 1 1/2" 6160'ETD sinker bars to 6220' out end of tbg. Ran 2" blind box to 6220' (perm pkr)out end of tbg. Perforated 9 5/8" csg. in Hemlock w/ 4 ISPF using 13 3/8" 2" "go winder" steel carrier 6530' to 6500'. Could not get back csg@4451' thru "X" nipple in tbg. @6182' and pulled out of rope socket. 9 5/8" Ran sinker bars and drove gun out of tbg. Perforated as above w/ csg@6724' 2" casing gun 6500'-6470' and could not get back thru "X" nipple '@6182'. Pulled out of rope socket. Ran tbg. cutter and cut 2 7/8" tbg. @6180' in pup joint above X nipple. 8/8/77 6750'TD Reperforated 9 5/8" csg. in Hemlock w/ 4JSPF using 2" GO Int. 6160'ETD "gowinder" carrier gun 6440' to 6470' Perforating done w/ well (perm pkr)shut in w/ 390 psi tbg. pressure and ~ole loaded w/ diesel to 13 3/8" 5100' (approx. 850 psi BHP). Perf gun split. Loaded hole to csg@4451' 3700' w/ diesel (approx. 1320 psi BHP). Perf as above 6430'-6440" 9 5/8" and 6340' to 640D'. Could not get thru X over from 3 1/2" to 2 / csg@6724' tbg. w/ perf gun after perforating 6340' to 6370' due to perf 7 8" debris. Produced well for 3 hrs to clean up trash in tbg. and well heading too much for measurable rate. Loaded hole w/ diesel to 3700' and perforated as above 6260' to 6340'. Completed perf @9:00 p.m. and set ball valve. Y ce~ thatlhe fore.~0~g i~ tlue a~d c4~lec t _ 14' siGhNe~¢~~iTLE . . DATE ~.tb~a. tL,,~' NOTE-Report on this form is required for each calendar 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. 69 8/9/77 6750'TD Long string-on production 23 hrs at an average rate of 14 BOPD after 6160'ETD unloading diesel. Short string on production 3 hrs and unloading (perm pkr)solvent and acid water. Solvent soaked on formation approx. 80 13 3/8" hrs. Have 363 bbls of solvent, acid and diesel to recover. csg@4451' 9 5/8" csg@6724' Union Oil and Gas F !ion' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union August 15, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 RE:~ MONOPOD PLATFORM KBU 13-8 KENAI GAS FIELD Di"R C. :2 ENG .5 ENO 2 o_EoE- '3 GEOL' REV SEC CONFER: ' .. FILE: Dear Mr. Hamilton' Enclosed for your information are two (2) copies of the Monthly Report for the above captioned projects. Sincerely yours, · Callender , Drlg. Supt. sm cc' Marathon Oil Co. USGS Harry Lee RECEIVED AUe 1 $1977 Divislor~ of Oil add Gas ¢on$~r,,,ation Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-133-2030] 6. LEASE DESIGNATION AND SERIAL NO. ADL 18731 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Union Oil Co. of Calif. Trading Bay State 3. ADDRESS OF OPERATOR 9. WELL NO. 909 W. 9th Ave, Anchorage, AK 99502 TBS A-32 4. LOCATION OF WELL Conductor 25, Monopod Platform, 1607'N~5fl'W of SE Corner, Section 4: T9N, R13W, S.M. ~_EIV~D AU8 1 5 1977 10. FIELD AND POOL, OR WILDCAT Tradin9 Bay Field 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. ~- T9N, R13W, S.M. 12. PERMIT NO. 77-18 43 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE 5~[~[C~[~3II~t~ .~]D~~N~..JDBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS i~'i~[ffi~"JO~S~J~N~l~ tI~ED~Ig~'I}I~ACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 7/1/77 6750 'TD ETD 6200' (cmt. ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' RIH w/ 9 5/8" stimulation pkr on dry DP & set above the "D" Zone @5368'. Press DP w/ 1100 psi gas. Opened tool @6:05 a.m. Surface press increased to 1140 psi in 20 min. Bled off gas press to 500 psi. Had rathole fluid @ surface @7:05 a.m. Flow tested well to stabilize rate. RU GOInternational to run spinner and temp survey. Tools failed on two runs, repaired same. Ran spinner & temp survey while flowing well @ plus or minus 8.6MMSCF/day w/ 700 psi @ surface. Survey showed major gas entering from 5770' to 5800' in 56-1 sand perfs (5765'5815') and gas entering from 5430' to 5440' in 53-0 sand perfs (5425'5455'). Gas from 56-1 sand cross flowing into the 54-9 sand perfs (5630' to 5662'). Had no indication of gas moving behind pipe on temperature survey. RD GO International. Shut in well at 12:00 p.m. midnite 7/1/77. 44 7/2/77 6750 'TD 5690'ETD (est. top of cmt. ) 13 3/8" csg. @4451' 9 5/8" csg. @6724' Rev. out gas. Released stimulation pkr. Pooh. RIH w/ 9 5/8" cmt. ret on DP & set below the 56-1 sand @5830'. RIH w/ 9 5/8" sqz. pkr & set at 5677'. Broke dwn. 51-6 sand perfs. 5765' to 5815' w/ 1600 psi & pumped in at 16 CFM w/ 2000 psi. Mixed 300 sx. of C1 "G" cmt. w/ 0.75% D-31. Displaced cmt. to sqz. tool & closed bypass. Fluid communicated between DP & annulus. Released sqz. pkr & rev. out cmt. Reset tool & press to 2000 psi w/ no communication. Pooh to change out sqz. pkrs. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 5830'. Circ. btms. up. Pooh. RIH w/ 9 5/8" sqz pkr & set @5690' Pumped into 51-6 sand perfs @ 16 CFM w/ 2000 psi. Mixed & pumped 300 sx of C1 "G" cmt. w/ 0.75% D-31 (ll8#/cu.ft. slurry). Sqz. 255 sx into the 56-1 sand perfs for abandonment to a final pressure of 4500 psi 1.28 psi/ft, gradient). Press. bled to 4000 psi in 10 mins & 14. I hereby ce~y/th~ the f~r~go/ng is true an~ corr~t_.~x ~ / SIGNED ///~'~/~'~ /~ '~-~, ~EL' TITLE P~St~ Dr!g.Supt. D*TE8115177 / NOTE-Report on this form is required for each calendar 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. held (1.18 psi/ft, grad). Bleed off press. Released sqz. pkr & rev. out. Rec. approximately 18 sx. of cmt. 45 7/3/77 6750 'TD 5473 'ETD (cmt.) 13 3/8" csg. @4451' 9 5/8" csg. @6724' Pooh w/ sqz. pkr. RIH w/ 9 5/8" cmt. ret & set below the 53-0 sand @5478'. RIH w/ 9 5/8" sqz. pkr & set @5330'. Broke dwn. the 53-0 sand perfs 5425' to 5455' w/ 2000 psi. Pumped into the 53-0 @ 9 CFM w/ 2600 psi & 16 CFM w/ 2800 psi. Mixed & pumped 250 sx. of Cl "G" cmt. w/ 0.75% D-31 (ll8#/cu.ft. slurry). Sqz. 200 sx. of cmt. into the 53-0 sand perfs for abandonment to a final press of 4700 psi (1.37 psi/ft, grad). Press bled to 3900 psi in 8 min. & held. (1.21 psi/ft, grad). Bled off press. Released sqz. pkr & rev. out. Rec. approximately 26 sx of cmt. Pooh w/ sqz. pkr. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. WOC 6 hrs. Drlg out hard cmt. from 5336 to 5473' Press. tested abandoned 53-0 sand perfs w/ 2500 psi o.k. Poo~. 46 7/4/77 6750'TD 5825 'ETD 13 3/8" csg. @4451' 9 5/8" csg. @6724' RIH w/ 9 5/8" stimulation pkr on dry DP & set above the abandoned 53-0 sand perfs at 5388'. Press DP w/ 1150 psi gas & opened tool at 2:20 a.m. Had no increase of press on surface. Bled off gas press to 0 psi & left tool open 1 1/2 hrs with no entry. Shut in at surface, no press build up in 1/2 hr. Released test pkr & rev. out. Test o.k. Pooh w/ 9 5/8" stimulation pkr. RIH w/ 8 1/2" bit. Drlg out hard cmt. from 5473' to cmt. ret @5478'. Drlg out cmt. ret @5478'. RIH & tagged hard cmt. at 5696'. Drlg out hard cmt. from 5696' to 5757'. Tripped for bit. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Drlg out hard cmt. from 5757' to 5825'. Circ. & cond. W.O. fluid. 47 7/5/77 6750'TD ETD 6187' (junk on cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' Circ. & cond. W.O, fluid. Pooh'w/ bit & scraper. RIH w/ 9 5/8" stimulation pkr on dry DP & set above the 56-1 sand @5726'. Press. DP w/ 1150 psi gas. Opened tool & bled off gas press to 0 psi. TeSted the abandoned 56-1 sand perfs (57655815') at atmospheric for 4 hrs. Had constant medium blow on bubble tube. Rev. out. Rec. approximately 17 cu.ft, of rathole fluid in DP, no gas. Released tool & RIH to 5825' Rev. out. No sign of oil or gas. Pooh w/ test pkr. RIH w~ 8 1/2" bit. Drlg out cmt ret @5830'. Drlg out cmt. ret. @5830' & cleaned out to 6187' (Junk &,fill on cmt. ret. @6200'). Circ. & cond. W.O. fluid. 48 7/6/77 6750'TD 6187' ETD (junk on cmt. ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' Circ. & cond. W.O. fluid. Pooh. RU & ran 4 1/2" temporary prod. string w/ 4 1/2" sidepocket mandrels. Spaced out & landed tbg. w/ 9 5/8" x 4 1/2" Baker Model FH Hyd. pkr @5329'. RU W.L. unit. Ran & set plug in 4 1/2" "XN" nipple @5369'. Press. tbg. & set 9 5/8" pkr @5329' w/ 3000 psi. Retrieved plug. Tested pkr w/ 500 psi o.k. Opened "XA" sleeve @5293'. Installed BPV. Removed BOPE. / 49 7/7/77 6750 'TD 6187' ETD (junk on cmt. ret) 13 3/8" csg. @4451 ' 9 5/8" csg. @6724' Finished removing BOPE. Installed test X-mas tree and tested to 5000 psi. Displaced hole w/ filtered inlet water and closed Otis sleeve @5293'. Put well on test and unloaded filtered inlet water in annulus in 8 hrs. and started making gas at 1.8 MMCFPD rate. Tested for 8 hrs. at 1.8 - 2.2 MMCFPD rate w/ tbg. press of ~C'. 150-95 psi No formation fluid entry during test. Moved rig over TBS A-2 to retrieve plug while testing TBS A-32. 31 ~2 7/8/77 7/9/77 7/10/77 6750 'TD 6187' ETD 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750'TD 5400'ETD (cmt. ret.) 13 3/8" csg. 9 5/8" csg. @6724' 6750'TD 5400'ETD 13 3/8" csg. @4451' 9 5/8" csg. @6724' Skidded rig from TBS A-2 to TBS A-32. RU Dresser Atlas. RIH w/ 3 1/8" cased carrier gun & differentially reperfed the following sands at 4 HPF: Sand Interval Footage 57-2 5852-5912' 60' 54-5 5590-5606' 16' 53-8 5530-5560' 30' Placed well on production test. Performed W.L. work on TBS A-2 while testing TBS A-32. Tested "D" Zone at plus or minus 4.5 MMCF/day gas w/ 115 pSi tbg. press for 9 hrs. after reperforating. No fluid entry during test. Killed well w/ 65#/cu.ft. KCL fluid. Installed BPV's. Removed X-mas tree. Installed & tested BOPE. Picked up on 4 1/2" tbg. & released 9 5/8" hyd. pkr @5329'. Pooh w/ 4 1/2" gasl~ft string. Ran & set 9 5/8" cmt. ret. above the "D" Zone @5400 RIH w/ 4 1/2" gaslift string to production test the "C" Zone. Spaced oUt & landed tbg. w/ 9 5/8" Otis hyd. pkr at 4479'. Set pkr and tested w/ 500 psi. Opened "XA" sleeve at 4444' & displaced KCL W.O. fluid w/ filtered inlet water. Closed "XA" sleeve. Removed BOPE. Installed X-mas tree & tested. Gaslifted out 264 bbls of filtered inlet water from tbg. and annulus. RU Dresser Atlas. RIH w/ 3 1/8" cased carrier & differentially perforated the .51-6 sand from 5315' to 5345'. 7/11/77 6750'TD 5400 'ETD (cmt. ret.) 13 3/8" csg. @4451' 9 5/8" csg. @6724' Completed differentially perforating the 51-6 sand from 5285' to 5345' w/ 3 1/8" cased carrier guns. Tested the 51-6 sand at plus or minus 6MMSCF/day w/ tbg. press, increasing from 1240 psi to .1450 psi in 3 hrs. No fluid entry. SI tbg. press - 1850 psi. Differentially perforated the 50-3 sand from 5120' to 5140' w/ 3 1/8" cased carrier gun. Flow tested well on 16/64 choke w/ tbg. press, increasing from 1550 psi to 1750 psi in two hrs. (suspect choke icing). No fluid entry. S.I. tbg. press - 1900 psi. Killed well w/ 66#/cu.ft. KCL W.O. fluid. Installed BPV. Removed X-mas tree. Installed & tested BOPE. Picked up on 4 1/2" tbg. & released 9 5/8" Otis hyd. pkr at 4479'. RIH to 5350'. Circ. out gas cut. mud / ~4 ~5 ~6 ~7 7/12/77 7/1J/77 7/14/77 7/15/77 7/16/77 6750'TD 5095'ETD (cmt. ret. ) 13 3/8" csg. 4451' 9 5/8" csg. @6724' 6750'TD 5095 'ETD (cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724'. 6750'TD 5095'ETD (cmt ret) 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750'TD 13 3/8" csg. @4451' 9 5/8" csg, @6724' 6750'TD 13 3/8" csg. @4451' 9 5/8" csg. @6724' Finished circ. out gas cut mud and condition W.O. fluid. Pooh w/ temporary completion tbg. and equipment. Ran Dresser Atlas Multiple Spaced Neutron Log 5400' to 4400'. Ran 9 5/8" Baker cmt. ret on 5" DP and set at 5236' Broke dwn. 51-6 perfs 5285' to 5345' w/ 3100 psi and PI @ 3.5 ~FPM - 3100 psi. Squeezed 51-6 perfs w/ 100 sx C1 "G" cmt. w/ .75% D-31 mixed @ 118 lbs/cu.ft. to a final pressure of 4600 psi (1.,33 psi/ft.) and displaced cmt. 10 cu.ft, below ret. Pressure bled to 3700 psi in 5 min. and held 3700 psi (1.16 psi/ft.). Pulled out of .retainer and reversed hole clean. Pooh w/ DP. Ran 9 5/8" Baker cmt. ret. on 5" DP and set @5095'. Broke dwn. 50-3 perfs 5120' to 5140' w/ 3200 psi and PI @ 8 CFPM - 3800 psi. Squeezed 50-3 perfs w/ 100 sx. C1 "G" cmt. w/ .75% D-31 mixed @ 118 lbs/cu.ft, to a final pressure of 4800 psi (1.40 psi/ft.) and displaced cmt. 10 cu.ft, below ret. Pressure bled to 3800 psi in 5 min. and held 3800 psi (1.20 psi/ft). Pulled out of retainer and reversed hole clean. Pooh w/ DP. Finished pooh w/ DP. RIH w/ 4 1/2" temporary gas lift completion string and landed tbg. w/ Baker 9 5/8" hyd pkr @4480'. set pkr and tested to 1000 psi. Removed BOPE and installed 4 1/ 2" X-mas tree. Opened Otis XA sleeve @4444' and gas lifted workover fluid out of hole to active mud system. Differentially perforated 9 5/8" csg. in C-7 sand w/ 4 HPF using 3 1/8" casing gun 4655-4685'. Finished RD Dresser Atlas. Tested C-7 perfs 4655' to 4685' on gas lift for 6 hrs. at 850-430 BOPD rate cut 3-1% w/ GOR of less than 100. Differentially perforated remainder of C-7 sand w/ 4 HPF using Dresser Atlas 3 1/8" casing gun 4595'-4655', Tested entire C-7 sand 4595'-4685' on gas lift for 3 hrs at 1090-1000 BOPD rate cut less than 1% w/ GOR of 920-587. Differentially perfed 47-5 sand as above 4815'-4835'. Tested C-7 and 47-5 sands on gas lift for 5 hrs at 1060-910 BOPD rate cut 7-1% with GOR of 280-350. Rig to perforate after testing C-7 and upper 20' of 47-5 sands. Differentially perforated lower 20' of 47-5 sand w/ 4 HPF 4835'-4855' using Dresser Atlas 3 1/8" casing gun. Tested entire C-7 and 47-5 sands on gas lift for 6 hrs at 1100-900 BOPD rate cut less than 1% with GOR of 400. Shut well in and bled off pressure. Displaced DP w/ workover fluid and filled annulus. Opened XA sleeve @4444' and circulated hole clean cutting work over fluid from 66#/cu.ft. to 60#/cu. ft. Installed BPV and removed tree. Installed BOPE and tested. Released pkr and circ. hole clean. Unable to move pkr below perfs to circ. Pooh and laid dwn. 4 1/2" tbg. Changed rams in BOPE. RIH w/ Baker pkr picker to 5090' and displaced hole w/ fresh 5% KC1 water workover fluid to remove oil contaminated fluid: Attempted to enter retainer at 5095' w/ pkr picker without success and sheared pins on tool, Pooh and repaired pkr picker. RIH w/ pkr picker and could not enter retainer, shearing pins on tool. Pooh w/ pkr picker. RIH w/ bit J#33 and . drilled retainer [a5095' in 1 1/2 hrs. Drilled hard cmt. 5097-5231' in 1 1/2 hrs and circulated hole clean. ~9 7/17/77 6750'TD pOoh w/ bit. RIH w/ 9 5/8" test pkr and could not set pkr. Pooh 5400'ETD and change out pkr. RIH w/ test pkr and set @5084'. Loaded DP (cmt. ret) w/ 1100 psi gas pressure. Opened tool and bled gas pressure to 13 3/8" csg. 200 psi. Dry tested 50-3 sand perfs 5120-5140' for 1 hr w/ no @4451' entry. Displaced DP w/ workover fluid and circ. hole clean. Pooh 9 5/8" csg. w/ pkr. RIH w/ bit #34 and drilled retainer @5236' in 2 hrs. @6724' Drilled hard cmt. 5238' to 5374' in 3 1/2 hrs and circ. hole clean. Pooh w/ bit. RIH w/ 9 5/8" csg. scraper. ;0 7/18/77 6750'TD 5400' ETD (cmt ret) 13 3/8" csg, @4451' 9 5/8" csg. @6724' Finished RIH w/ 9 5/8" bit and csg. scraper to 5400' and pooh. Ran 9 5/8" test pkr on dry 5" DP and set @5230'. Loaded DP w/ llO0 psi gas pressure, opened tool and pkr failed. Pooh and changed out packers. Ran new 9 5/8" test packer and set @5230'. Loaded DP w/ 1100 psi gas pressure and opened tool to dry test 51-6 sand perfs 5285'-5345'. Bled pressure to 200 psi and shut in DP. Had gas entry with pressure building to 600 psi in 20 min. Flow tested 51-6 perfs for 2 1/2 hrs @.5 to 2.5 MMCFGPD rate w/ 60-200 psi flowing tbg. pressure. Shut well in and pressure stabilize¢ @1800 psi after 30 min. Reversed out gas and circ. well clean and pooh. Ran 8 1/2" bit #35 and drilled out retainer @5400'. 7/19/77 6750'TD Drlg out cmt. ret. @5400'. RIH & cleaned out junk from 6187' to 6645'ETD 6200' Drlg on cmt. ret. @6200' for 3 hrs. Pooh w/ 8 1/2" bit. (float collar) RIH w~ 8 1/2" pkr mill. Drlg out cmt ret @6200' RIH to 6645' 13 3/8" csg. Circ. out gas cut W.O. fluid. Pooh. RIH w/ 8 1~2" bit & @4451' 9 5/8" csg. scraper to 6645'ETD. Circ. & cond. W.O. fluid. Pooh. 9 5/8" csg. RU Dresser Atlas. RIH w/ 8 3/8" gauge ring & junk basket. Unable @6724' to work gauge ring below 3453'. Pooh. RD Dresser Atlas. RIH w/ 8 1/2" bit & 9 5/8" Csg. scraper to 6624'. Circ. & cond. fluid. 7/20/77 7/21/77 6750'TD 6623'ETD (prod pkr on F.C.@6645') 13 3/8" csg. @4451' 9 5/8" csg. @6724' 6750'TD 6160 ' ETD (perm pkr) 13 3/8" csg. @4451' 9 5/8" csg. @5724' Finished circ. hole clean at 6645' and pooh w/ bit & scraper. Ran 8.375" O.D. gage ring and junk catcher on W.L. to 6300'. Set 9 5/8" Otis permanent pkr on W.L. @6200' above Hemlock zone. Ran 10' Otis seal assy. on 5" DP and stung into pkr @6200'. Pakcer not set properly, failed to test. Pushed pkr to 6260' w/ less than 5000# weight and circulated thru DP w/ 500 psi. Pooh. Laid dwn. locator sub & seal assy. Ran packer mill on 5" DP and pushed pkr to 6623'. Unable to push below 6623' - fill on top F.C. @6645'. Circ. hole clean and pooh. Set 9 5/8" Otis perm pkr on W.L. @6160'. Ran 10' Otis seal assy. on 5" DP and set in pkr @6160' w/ 30,000#. Pressured DP to 500 psi with no leakoff. Pooh and changed rams in BOPE to run completion tbg. Ran 15' Otis seal assy. and Camco GLV's on 2 7/8" tbg. with side string of 1 1/2" tbg. Finished running dual tbg. strings. Long string 3 1/2" x 2 3/8" landed @6217' w/ locator sub on 15' Otis seal assy. @6157' giving 3" standoff from Otis perm pkr @6160' above Hemlock perfs 6260' to 6560'. Otis dual hyd pkr landed @4940' above "D" Zone perfs 5530' to 5912' and lower "C" Zone perfs 5120' to 5345' (Isqueezed off). Otis triple hyd pkr landed @4492' above "C" Zone perfs 6595' to 4855'. Gas lift side string 1 1/2" x 2 3/8" landed @6150'(30' above perm pkr) and extends to 4434' (61' above triple hyd pkr). Short string 3 1/2" tbg. landed @4503' in triple hyd pkr. Spaced out and installed CIW dual 3 1/2" hangers. Installed lubricator and tested long string seal assy. and perm pkr @6160' to 350 psi with no circulation. Set W.L. plug in long string "XA" sleeve @4978'. Set dual hyd. pkr @4940' w/ 900 psi and tested long string tbg. 4978' to surface to 3000 psi. Retrieved plug and opened sleeve @4978'. Tested dual hyd pkr to 350 psi with no circulation and closed sleeve. Set W.L. plug in short string "XN" nipple @4503'. Set triple hyd pkr @4940' w/ 1200 psi and tested short string tbg. 4503' to surface to 3000 psi. Retrieved plug and tested triple hyd pkr to 350 psi w/ no circulation. ~5 7/22/77 7/23/77 7/25/77 7/26/77 Finished testing triple hyd pkr @4492' and retrieved plug from XN nipple. Opened XA sleeves @4907' and 4458' and displaced hole w/ filtered inlet water. Closed sleeves and started unloading fluid with gas lift. Moved rig to facilitate W.L. work on A-18 and A-2 while testing A-32. * Unloaded :l'ong string tbg. in 8 hrs. Neither tbg. string producing consistent measurable amount of fluid. Alternated shutting in tbg strings to try to kick off each string for 24 hrs. Tested wells intermittently for a total of 48 hrs with no conclusive test but neither string producing any consistent amount of fluid. Short string producing by heads for first 24 hrs. Production Test Tested C Zone perfs thru short string for 4 hrs w/ no fluid recovery and shut in for surveys. Ran W.L. temperature and BHP surveys indicating well lifting from bottom GLV @4387' w/ bottom hole operating pressure of 233 psi and no fluid entry. Tested Hemlock perfs thru long string for 18 hrs w/ production increasing to max of 165 BOPD rate cut 30%. Ran W.L. BHP survey indicating well lifting from #4 GLV @4419' and none of side string dip tube GLV operating. Repaired bean in surface choke and prep to remove bottom GLV in dip tube to check for plugging of dip tube. Acidized TBS A-32 short string tbg. w/ 12% Hcl + 3% HF. *Unloaded short string in 8 hrs and produced small amOunt of oil while unloading. TO Document Transmittal union Harry Kugler State Div. of Oil & Gas TRANSMITTING THE FOLLOWING: DA'I ~ SUbMI'FTL. D 7-27-77 FROM [3ot} Warthen AT Anch. TELEPHONE NO. complete set of Sepias and bluel'nes Please sign & return one copy t~ this offi, / Date' / FORM 1-2M02 (REV. 11 72) PRINTED IN U S.A. 02.-001B STATE of ALASKA FROM: . DATE : JJ/ly 26 # 19'~P SUBJECT: Uni(~ ~ ~, Well A-32 · ra4/z~ Bay F~em Union Oil and Gas D'%n: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 union Telephone' (907)276-7600 July ll, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 RE' TBS A-32 MONOPOD PLATFORM Dear Mr. Hamilton' Enclosed for your information are two (2) copies of the Monthly Report for the above captioned well. Sincerely you'rs, · J-i:m-.R. Cal 1 ender Dist. Drlg. Supt. sm cc' H. C. Lee USGS Marathon Oil Co. STATE OF ALASKA SUBM~ ~ OgeUCA~ Oii. AND OAS CONSERVATION COMMII-I'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS REC v .u UnSon 0~1 Compsny of C81iforn~8 909 West Ninth Ave., AnChorage, AK ~,~[,~?.,~,,, Conductor 25, Monopod Platform, 1607'N & 556'W of SE Corner. Section 4: T9N, R13W, S.M. ~5 Alii NUZVIERICAL CODE 50-133-20301 LEASE DES:GI~tATION AN'D SERIAL NO. ADL-18731 '7 IF II~DIA]ff ALOTiEE Ol~ TRIBE NAME 8. L~,,'IT FARM OR LEASE NA. ME Trading Bay State ion TBS A-32 10 FL~_-!_-~ A-'qD POOL. OH WILDCAT Trading Bay Field 11 SF~, T.. R. M. (BOSOM HOLE OB.mCrlVE) Sec. 4- T9N, R13, S.M. 1~. PERMIT i~O 77-18 13 14 15 16 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE. CASING AIN-D CF_,IVIENTING JOBS INCLL'DING DEP~ SET ~ VOL~ US~. p~O~TIONS. ~TS ~ ~SUL~ FISHI~TG JO~ JL~K ~ HO~ AND SIDE-~CK~ HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS 6/1/77 4480'TD 20" csg. @221 ' 16" csg. @502' (Footage 2988' (opened). Continued opening 12 1/4" hole to 17 1/2" from 534' to 2151'. Tripped for hole opener change. Opened 12 1/4" to 17 1/2" from 2151' to 3522'. 6/2/77 4480 'TD 17 1/2" hole 4298' 20" csg. @221 ' 16" csg. 0502' (Footage 776' (opened). Opened 12 1/4" hole to 17 1/2" w/ expandible hole openers from 3522' to 4298'. Tripped to change hole opner @3522' 4050' and 4298' 6/3/77 4480 'TD 20" csg. @221' 16" csg. @502' (Footage 0'). Finished TIH w/ 17 1/2" underreamer on BHA //19 (Opened 12 1/4" hole to 17 1/2" to 4460'. Pin twisted off GBR stab 81' above hole opener @4460'. Top of fish @4359'. Ran 15" lip guide w/ overshot & jars (BHA #20). Engaged fish @4359' & pooh. Recovered total fish. Reran 17 1/2" underreamer on BHA #21. Opened 12 1/4" hole to 17 1/2" from 4440' to 4460' Circ. & cond. hole to run 13 3/8" csg. 6/4/77 4480 'TD 13 3/8" csg. shoe @4451' 20" csg. 0221" 16" csg. @502' Pooh. Laid dwn. 17 1/2" underreaming assy. RU to run 13 3/8" surface casing. Power tong unit failed. Ran 106 jts. 13 3/8" 61# & 6.8# K-55 Butt. casing w/ spinning rope & rig tongs. Landed 13 3/8" casing w/ shoe @4451'. DV tool @2199'. Unable to circ 13 3/8" casing annulus to surface. Suspect loss of returns @16" csg. shoe @502'. Cemented btm. stage 928 sx. C1 "G" cmt. w/ 2 1/2% pre-hydrated gel followed by 200 sx. Cl "G" neat. Displaced btm. stage. Plug did not bump w/ 100 cu.ft. '¢'l~e"b'~er~ffY-~/~J~e'°i~'i~?~an~lm°~re~'~ Dist Drlg. SuPt ~ 7/11/77 ~. t.al ~ , . NOTE--Report on this fora is required for eO~ calendar ~ths regardless of the status of operations, and must ~ flied In dupll~te with the oil and gas aonlervatbn commiffee by the IB~ of the SuecNding mn~, ~le~ Otherwise directed. 17 overdisplacement. Cmt. in place @ 4-00 p.m. 6/4/77. Dropped bomb to open DV stage cmt. collar ports @2199'. Opened ports w/ 1800 psi o.k.- Unable to circ. to surface. Pumping in below 16" cs§. shoe w/ 400 psi. Cemented top stage w/ 878 sx. C1 "G" w/ 2 1/2% pre-hydrated .gel followed by 200 sx. C1 "G" neat. Closed ports in DV tool @2199' w/ 2750 psi, held o.k. Cement in place @7'30 p.m 6/4/77. Dropped wrap around slips & hung off 13 3/8" casing Removed 20" hydril & riser. Installed 13 3/8" casing head spool. 6/5/77 " '' m . . 18 6/6/77 " " Installed 13 5/8" BOPE & tested to UOCO specifications. RIH w/ 12 1/4" bit (BHA #22) to 2199' Tested pipe rams and csg. to UOCO specifictions. Drilied DV @2199' and tested to UOCO specifications o.k. Ran in and tagged cmt. @4330'. Drilled cmt. to plug catcher @4356'. Drilled firm cmt. to fl oat collar @4402'. Drilled to 4433' and retested csg. o.k Drilled cmt. shoe @4451'. CO to 4480'. Tested csg. seat and formation to 65 psi/ft, gradient (TVD 4259') o.k. Pooh. Cleaned out rat hole at cement below casing shoe at 4451' to TD at 4480' w/ BHA #22. Pooh. RU scientific tool gyro survey and ran gyro from 200 to 4400'MD. BHA location at 4400'MD is 130.20S and 856.25'W of surface location. Trip in hole w/ BHA #22 to casing shoe at 4451'. Displaced well at csg. shoe w/ FIW. Cleaned surface mud tanks and rebuilt active mud system w/ 5% KC1 and XC polymer. Pooh w/ BHA #22. Ran 12 1/4" bit on dyna drill w/ 2 deg. kick sub (BHA #23). 19 6/7/77 4673'TD 20 6/8/77 4859 'TD (Footage 193'). Completed trip in hole w/ dyna drill to TD @4480' Oriented dyna drill for maximum right hand turn. Dyna drilled from 4480' to 4525'. Pooh w/ dyna drill. Trip in hole w/ 12 1/4" bit on follow up assy. BHA #24. Dressed out dyna drill run. Drilled from 4525' to 4577' Survey at 4548' 28 1/2 deg. due North. Drilled from 4577' to'4639' Survey at 4609' 28 3/4 deg. N1E. Drilled from 4639'to ~673' Survey at 4644' 28 3/4 deg. N1E. Pooh w/ follow up assy. #2~. Picked up dyna drill. Trip in hole w/ dyna drill 12 1/4" follow up assy. #25 to TD at 4673'. Oriented dyna drill for right hand turn. ' . Dyna drilled from 4673' to 4733' Pooh w/ (Footage 1~6 ) /4" dyna drill 12 1 follow up assy. #25. Trip in ~ole w/ 12 1/4" follow up assy. #26. Reamed dyna drill run and drilled from 4733' to 4794'. Survey at 4760' 27 1/2 deg. NIOE. Circ. & cond. mud to run log. Pooh. RU Schlumberger and ran DIL correlation log from 4451' to 4794' RD Schlumberger. Trip in hole w/ dyna drill BHA #27. Oriente~ for right turn at 4794'.. Dyna drilled from 4794' to 4859' 21 6/9/77 5152'TD (Footage 293'). Pooh w/ dyna drill at 4859'. Trip in hole w/ 22 6/10/77 5381 'TD 23 6/11/77 5690'TD 24 6/12/77 5965'TD 25 6/13/77 6309'TD 12 1/4" bit on follow up assy. BHA #28. Reamed dyna drill run from 4794' to 4859'. Drlg from 4859' to 4996'. Survey at 4966' 26 deg. N24E. Pooh for bit change. RIH w/ 12 1/4" bit #18 ~on follow up assy. BHA #28. Drlg from 4996' to 5090'. Survey at 5060' 25 deg. N24E. Drlg from 5090' to 5152'. Circ. Dropped survey at 5152' Survey misrun. Pooh w/ BHA #28. Footage 229'). RIH w/ 12 1/4" bit #19 on dyna drill (BHA #29). Oriented dyna drill w/ scientific eye steering tool for right hand turn.' Dyna drilled 12 1/4" hole from 5152' to 5!61'. Steering too- not working. Pulled steering tool & cut out 150 of shorted line. Re-ran steering tool. Continued dyna drilling 12 1/4" hole from 5161' to 5217'. Pooh w/ dyna drill. RIH w/ 12 1/4" bit #20 on follow up assy. BHA #30. Reamed dyna drill run from 5152' to 5217'. Drlg & surveyed 12 1/4" hole from 5217' to 5381'. (Footage 309'). Cont. drlg 12 1/4" hole from 5381' to 5434'. Pooh for bit change. RIH w/ 12 1/4" bit #21 on BHA #30. Drlg. & surveyed 12 1/4" hole from 5434' to 5639' Tripped for bit change. Redressed 6 pt. reamer to retard slow angie drop. RIH w/ 12 1/4" bit #22 on BHA #30. Drlg & surveyed 12 1/4" hole from 5639' to 5690'. (Footage 2.75'). Continued drlg 12 1/4" hole from 5690' to 5720'. Pooh. RIH w/ bit #23 on slight angle building assy. BHA #31. Drlg 12 1/4" hole from 5720' to 5851'. Pooh. RIH w/ bit #24 on BHA #30. Drlg & surveyed 12 1/4" hole from 5851' to 5965'. (Footage 344'). Pooh. RIH w/ 12 1/4" bit #25 on slight angle building assy. BHA #31. Drlg 12 1/4" hole from 5965' to 6130' Tripped for bit. RIH w/ 12 1/4" bit #26 on BHA #30. Drlg 12 i/4" hole from 6130' to 6309'. Pooh for bit change. 26 6/14/77 6519'TD 27 6/15/77 6750 'TD 28 6/16/77 6750'TD 29 6/17/77 6750'TD 30 6/18/77 31 6/19/'77 ETD 6645' (fl. collar) 9 5/8" CSg. @6724? '. 6750'TD ETD 6645' (fl. collar) 6750 'TD 6645 'ETD (fl. collar) (Footage 210') Pooh. RIH w/ 12 1/4" bit #27 on BHA #30. Drlg 12 1/4" hole from.6309' to 6439' Tripped for bit. RIH w/ 12 1/4" bit #28 on BHA #30. Drlg 12 1/4F' hole from 6439' to 6519'. Ran W.L. survey. (Footage 231'). Finished W.L. survey. Lost 500 psi pump press. Trip for hole in 5" DP at 493' and new bit. Ran 12 1/4" bit #29 on BHA #33 and drilled 6519' to 6600' in 4 1/2 hrs. Trip for new bit. Ran 12 1/4" bit #30 on BHA #32 and drilled 6600' to 6750' in 5 hrs. Ran W.L. survey. (Footage 0'). Tripped out to 13 3/8" csg. at 4451' RIH to 6750'. Circ. & cond. mud for logging. Pooh. RU Schlumberjer. Ran DLL GR BHC Sonic and FDC CNL GR from 6740' to 4451'. (Footage 0'). Completed running FDC CNL log from 6740' to 4451'. Ran GR CBL VDL log inside 13 3/8" csg. from 4451' to surface. CBL log indicated cement outside 13 3/8" csg. above 16" shoe @502'. RD Schlumberger. RIH w/ 12 1/4" bit to 6750'. Circ. & cond. mud for csg. Pooh, hole condition good. RU & ran 166 jts. of 9 5/8" 47# N-80 Butt. csg. to 6724' w/ float collar @6645' Footage 0'). Circ. well clean. Mixed & pumped 2000 sx. of C1 G cmt. w/ 0.75% D-31, 0.3% D-19 and 0.1% D-6. Preceded cmt. w/ 200 cu.ft, of caustic water & 200 cu.ft, of filtered inlet water. Displaced cmt. to float collar @6645' & bumped plug w. 2000 psi. Checked floats, held o.k. Landed 9 5/8" csg. on slip type hanger. Cut off 9 5/8" landing jt. Removed BOPE. Installed & tested 12" 3000# x 10" 5000# tbg. spool. Skidded rig from TBS A-32 to TBS A-2 to set plug in TBS A-2 long string while waiting on cement. Skidded back over TBS A-32. Installed & tested BOPE. (Footage 0'). RIH w/ 8 1/2" bit & 9 5/8" csg. scraper to 6645'. Pooh. RU Dresser Atlas. Ran multi shot gyro survey from 6600' to 4500'. Ran GR CBL Signature log 6644 to 3750'. RIH w/ 6" sqz. gun & perf for zone isolation sqz. from 5506' to 5508'. RD Dresser Atlas. RIH w/ 9'5/8" sqz. pkr & set @5393'. Unable to break dwn. sqz. perfs 5506' to 5508' w/ 3000 psi, equiv, to 1.08 psi/ft, gradient. Pooh w/ sqz. pkr. 32 33 34 35 6/20/77 6/21/77 6/22/77 6/23/77 Pooh w/ 9 5/8" sqz. pkr. RIH w/ 9 5/8" test pkr & set @5468' to diff. test perfs 5506' to 5508' Press. DP w/ gas to llO0 psi & opened tool @6-10 .a.m. Bleed o~f gas press. & flow tested perfs. Well stabilized @ plus or minus 1500 mcf/day gas w/ 145 psi @ surface. Shut in tester on surface @ l:lO p.m. Surface pressure stabilized @710 psi in 45 mins. Rev. out gas & gas cut mud w/ slight trace of oil. Pooh w/ test pkr. Pressure bombs recorded as follows: Initial hydrostatic Initial flow Final flow Final shut in 2643 psi 336 psi 336 psi 994 psi RIH w/ 9 5/8" sqz. pkr & set @5424' Broke dwn. perfs 5506' to 5508' @3100 psi (1.10 psi/ft, gradiJnt) and pumped in @ 3 cu.ft./min w/ 2300 psi. Mixed & pumped lO0 sx. of C1 G cmt. w/ 0.75% D-31, 0.3% D-19 and 0.1% D-6. Initial pump in press. 2000 psi - 6 cu. ft. /mi n. Sqz. 70 sx. of cmt. into perfs to a final press, of 3200 psi. Held press, for 30 mins. Bleed off press & cmt. stayed in place. Released pkr & reversed out. (Footage 0'). Completed rev. out. Pooh. Picked up BOPE & repositioned tbg. spool. Installed & tested BOPE. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Cleaned out hard cmt. from 5424' to 5520' and cmt. stringers to 5530' Tested 9 5/8" csg. to 2500 psi o.k. RIH to float collar @~645'. Displaced mud w/ 5% KC1 inlet water. Pooh. Finished pooh w/ bit. Perf. 9 5/8" csg. in lower Hemlock using Dresser Atlas 4" casing gun 6510' to 6560'. Ran 9 5/8" Baker ret. sqz. pkr on 5" DP and set @6472'. RU to frac. Frac. Hemlock perfs 6510' to 6560' w/ 45,000 gal. gelled and treated 6% KCL water a6d 95,500# 20/40 sand as follows: pumped 2,000 gal 12-3 mud acid @5BPM & 4400 psi 5,000 gal frac pad 5,000 gal frac fluid w/ 1/2 ppg sand @14 BPM & 4200 psi 12,000 gal frac fluid w/ 1 ppg 11,000 gal frac fluid w/ 2 ppg 9,000 gal frac fluid w/ 3 ppg 8,000' gal frac fluid w/ 4 ppg 4,800 gal frac fluid displacement @14 BPM &4600 psi Shut well in and pressure bled to 3000 psi in 1/4 hr. and held 3000 psi for 3/4 hr. Bled pressure to 600 psi and reversed out sand. Back flowed well. Continued back flowing well. Back flowed well a total of 14 hrs. Pooh w/ retrievable pkr. RU Dresser Atlas. RIH .w/ 4" csg. gun & perf the upper Hemlock from 6300' to 6350' @4 hpf. RIH w/ 8 1/2" ~bit & 9 5/8" csg. scraper. Tagged sand fill @6511' Cleaned out fil. to 6644'. Circ. & cond W.O. fluid. Pooh. RIH ~/ 9 5/8" RBP & retrievable pkr. 36 37 38 6/24/77 6/25/77 II II 6750 'TD 6200' (cmt. ret.) 6/26/77 " " RIH w/ 9 5/8" RBP & stimulation pkr. Set 9 5/8" RBP @6450' & tested to 2500 psi, Set 9 5/8" stimulation pkr @6258'. RU to fracture stimulate upper Hemlock perfs 6300 to 6350' Broke dwn. perfs w/ 4200 psi. Fracture stimulated the upper He~lock w/ 45,000 gal gelled frac pad w/ 4% KC1 and 95,500# 20/40 sand as fol 1 ows: 2,000 gal. 12-3 mud acid 5,000 gal frac pa. 5,000 gal frac pad w/ 1/2 ppg sd 12,000 gal frac pad w/ 1 ppg sd l l,O00 gal frac pad w/ 2 ppg sd 9,000 gal frac pad w/ 3 ppg sd 8,000 gal frac pad w/ 4 ppg sd 4,800 gal frac pad Final pumping rate 5 BPM @4300 psi. Shut dwn. pump. Press. bled to 2000 psi in 1 hr. Rev. out. Pooh w/ stimulation pkr. RIH w/ retrieving tool for RBP. Washed out sand from 6301' to 6450' Retrieved 9 5/8" RBP@6450'. RU Dresser Atlas. RIH w/ GR CBL logging tools. Tagged sand fill @6580'. Logging tools not working. RD Dresser Atlas. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper. Cleaned out sand from 6580' to 6644'. Pooh. RU Dresser Atlas. Worked on logging tools 2 1/2 hrs. Ran GR CBL Signature log from 6633 to 4500'. Log quality poor. RIH w/ 4" cased carrier guns & perforated the Hemlock formation from 6260' to 6300', 6350' to 6400' and 6430' to 6510' Ran & set 9 5/8" ret. on DP @6200'. Tested cmt. ret w/ 25~0 psi. RU to run tbg. Ran 9 5/8" x 4 1/2" Otis hyd. pkr on 4 1/2" gas lift string. Pkr stopped @560'. Pooh. Gauge ring on rebuilt Otis pkr out of round Ran Baker 9 5/8" x 4 1/2" hyd. pkr on 4 1/2" gas lift string. Spaced out & landed tbg w/.pkr @4498'. RU W.L. unit. RIH w/ W.L. plug. Unable to work thru XO sleeve @4461'. Re-ran plug & set in XN nipple @4536'. Press tbg. w/ 2500 psi & set 9 5/8" hyd pkr @4498'. Pulled W.L. plug - plug stuck in XO sleeve at 4461'. Jarred plug free w/ Dresser Atlas unit. Ran W.L. shifting to open XO sleeve @4461'. Unable to latch into sleeve RD W,L. unit. 39 6/27/77 40 6/28/77 Finished removing BOPE. Installed CIW 4 1/2" single X-mas tree. Gas lifted 220 bbls workover fluid out of hole to active mud system. Dresser Atlas perforated 9 5/8" csg. in "D" Zone 57-2 sand w/ 4 SPF using 3 1/8" csg. gun under 500 psi drawdown condition 5852' to 5912'. Perforated in two runs and fl owed well 1/2 hr between runs then flowed 4 hrs after completing and recovered workover fluid w/ no gas. Perforated 56-1 sand as above 5765' to 5815' and flowed well recovering workover fluid w/ no gas. Perforated 54-9 sand as above 5630' to5662' and flowed recovering no gas or oil. Perforated 54-5 sand 5590' to 5606' and 53-8 sand 5530' to 5560' as above w/ slight increase in gas. Perforated 53-0 sand 5425' to 5455' as above w/ substantial increase in gas. Stuck perf gun in tbg. @795'. Attempted to pull out of rope socket and gun came free w/ 2600# and moved up hole cutting W.L. Pulled W.L. and now rigging up to fish perf gun. Bled dwn. gas press on annulus to 500 psi. RIH w/ 1 7/8" sinker bars to 640' Sinker bars hanging up on approximately 70' of elec. W.L. lift in tbg. Pooh. Loaded tbg. w/ 5% KC1 water. Waited on fog to clear 5 hrs. to load out fishing tools. RIH w/ W.L. spear to 640'. Rec. 26 1/2' of elec. W.L. Re-ran W.L. spear twice, no recovery. Had indications of gun being along side of wire. Ran blind box to 640' & cut wire on top of gun head. Ran W.L. overshot & engaged top of 3 1/8" csg. gun @640'. Jarred on fish 4 hrs. Fish moved up hole 13' to 627' Sheared out safety release on overshot. Pooh. RD Dresse~ Atlas. 41 42 6/29/77 6/30/77 II II Finished RD Dresser Atlas. Flowed well 5 1/2 hrs. to recover filtered inlet water w/ FTP = 1400 psi and CP : 280 psi. Lubricated 200 bbl drilling mud dwn. annulus. Pumped 50 bbls 5% KC1 water w/ Dril-S down tbg. to 53-0 sand perfs 5425' to 5455'. killed well circulating dwn. annulus thru gas lift valves and out tbg. Installed back pressure valve and removed X-mas tree. Installed BOPE and tested to 3000 psi. Released pkr w/ 50,000# overpull and circulated well clean conventionally. Layed dwn. 4 1/2" tbg. and found perf gun in gas lift valve at 2016'. All fish recovered. Continued laying dwn. tbg. Completed laying dwn. 4 1/2" tbg. & accessories. RIH w/ 8 1/2" bit & 9 5/8'~' csg. scraper. Cleaned out fill from 6174' to 6200'ETD. Circ. out gas cut mud. Pooh. RIH w/ 9 5/8" stimulation pkr on dry DP & set @5483' (below suspected gas entry from 53-0 sd). Press DP w/ 1050 psi gas. Opened tester at 1:42 p.m. Had no pressure increase on surface in 15 min. Bled off gas at surface. Rat hole fluid surfaced in 55 min. Had gas to surface at 2:55 p.m. Flow tested well at plus or mi n us 31. :-l:~M SCF/day w/ 900 psi at surface. Released stimulation pkr & rev. out gas. Pooh. Removed pressure bomb from stimulation pkr. RIH w/ stimulation pkr on dry DP. 02~01B STATE of ALASKA Divisical of Oil an~ Gas TO: FROM: DATE : SUBJECT: Jtme 22, ].977 Oil's Failure to ~ DO~ fo~ B~ C21ec~ ~he ~11 has ~ been ck-/~~T.D, at~ t~e 9 5/8" casJr~ cel~ted. Union Oil and Gas [/'"~.on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union June 15, 1977 Mr. Hoyle Hamilton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 sm cc' Dear Mr. Hamilton' EncloSed fg,~--y~~Cormation are three (3) copies of the Monthly Report found TBS A-13. ~ Sincerely x~_'m R.] Callender Dis~ct Drlg. Supt. Marathon Oil Co. USGS Harry Lee R E C E!V ~.:~ P J U N 1 5 1977 Division of Oit & Ga~ O~n~,~rva[ion Anchorage No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICAT~ A~'I NU~,mmCAL CODE 50-]33-2030] LEASE DESIGNATION AND SERIAL 1%1'0. ADL-18731 '7 IF INDIA]~. AL~T~/~ O]{ TRIBE OIL ~ GAll ~--] W~LL V~LL OTHIER 2, NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPEP,~TOR 909 West Ninth Avenue, Anchorage, AK 99502 4 LOCA~ON OF WFJ.,L Conductor 25, Monopod Platform, 1607'N & 556'W of SE Corner. Section 4' T9N, R13W, S.M. 8. L~,'IT FAP,~ OR LEASE NAME Trading Bay State 9 WELL N'O TBS A-32 l0 FL~,LD A_ND POOL. OR %VILDCAT Tradina Bav Field SEC. T., ~. M [BOTTOM HOLE o~ Sec. 4: T9N~ RI3W~ S.M. '"13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~NGES IN HOLE SIZE, CASING AND C~M[ENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. PERFORATIONS. TESTS A_N-D RESULTS FISHING JOBS Jbq~IK I.N HOLE AND SIDE-TI~CKED HOLE AND ANY OTHER SIGNIFICANT Clq3%NGES IN HOL~ CONDITIONS 5/20/77 500'TD 20" csg. @221 ' (Footage 500'). Skidded rig from TBS A-13 to TBS A-32 @12-01 p.m. 5/20/77. Installed 20" riser & hydril. C.O. 20" conductor to 221'. Drilled 17 1/2" hole to 231' Pooh. Ran 18" O.D. mill & dressed out partially collapsed 20" conductor shoe. Ran 17 1/2" bit, BHA #1 & drilled from 231 to 500'. 5/21/77 5/22/77 5/23/77 513'TD 20" csg. @ 221' 16" csg. @502' 785'TD 20" csg. @221' 16" csg. @502' 1502 'TD 1001 ' KOP 20" csg. @221' 16" csg. @502' (Footage 13'). Drilled from 500' to 513'.. Opened 17 1/2" hole to 26" O.D. to 513'. Spotted 150 bbl. gel pill. Pooh to run csg. Ran 12 jts. 16" O.D. 65# H-40 Butt. casing & set w/ shoe @502' - F.C. @460'. (Footage 272'). Cemented btm. stage w/ 500 sx. Class "G" w/ 8% gel followed by 200 sx. Class "G" neat. CIP @4:00 a.m. 5/22/77. Cemented top 16" to effect seal & isolate holes in 20" conductor w/ 50 sx. Class "G" & 10% sand. CIP @6:10 a.m. 5/22/77. Tested 16" packoff w/ 450 psi, o.k. Reinstalled 20" hydril and tested to 500 psi o.k. Ran 12 1/4" bit BHA #2. Drilled 12 1/4" hole to 785'. (Footage 717'). Cont. drlg 12 1/4" hole from 785' to lO01'. Dropped survey and pooh. RIH w/ dyna drill & oriented at IO01'KOP. Dyna drilled & surveyed 12 1/4" hole from 1001' to 1205' Pooh w/ dyna drill. RIH w/ 12 1/4" bit on follow up BHA #~. Drilled and surveyed 12 1/4" hole from 1205' to to 1502'. i , ~4.,h,,b,,n~,~~~-~,,~.~-~ =~_m Dist. Drla. g,mt. nA~ 6/15/77 oil and gas ~onservatbn commiffee b~the I~ of the suoe~in9 mon~, ~le~ otherwise d~re~ted. 5/24/77 5/25/77 5/26/77 2632 'TD 20" csg. @221' 16" csg. @502' 3018'TD 20" csg. @221' 16" csg. @502' 3477 'TD 20" csg. @221 ' 16" csg. @502' (Footage ll30'). Cont. drlg. 12 1/4" hole w/ follow up building BHA #4 from 1502' to 1838'. Pooh. RIH w/ locked BHA #5. Drlg 12 1/4" hole from 1838' to 2632'. (Footage 386'). Pooh, picked up 12 1/4" bit #5 on dyna drill. (BHA #6). TIH. Oriented tool w/ scientific eye steering tool for right hand turn and slight angle build. Dyna drilled from 2632' to 2769'. Pooh w/ DP. Re ran Bit #5 on BHA #7. Follow up assy. and drilled 12 1/4" hole from 2769' to 3018'. (Footage 459,). Completed pooh. RIH w/ bit #6 on BHA #8. Drlg. 12 1/4" hole from 3018' to 3403' Pooh. RIH w/ bit #7 on dyna drill (BHA ~6). Oriented tJol w/ scientific eye steering tool for right hand turn and slight angle build. Dyna drilled from 3403' to 3477'. Rig dwn. steering tool. 10 ll 5/27/77 5/28/77 5/29/77 5/30/77 3790'TD 20" csg. @221' 16" csg. @502' 4006'TD 20" csg. @221' 16" csg. @502' 4280 'TD 20" csg. @221' 16" csg. @502' 4480 'TD 20" csg. @221' 16" csg. @502' (Footage 310'). Pooh w/ dyna drill. RIH w/ 15" bit on BHA #9. Reamed 16" float collar & shoe @502'. Pooh. RIH w/ 12 1/4" bit on BHA~9. Drlg 12 1/4" hole from 3477' to 3686'. Pooh. RIH w/ 12 1/4" bit on dyna dri. ll (BHA #10). Oriented tool w/ scientific eye steering tool for right hand turn. Dyna drilled from 3686' to 3790'. (Footage 216'). Continued dyna drilling from 3790' to 3796' (Turned hole 18 deg. right & built 1/2 deg. Pooh w/ dyna drill. RIH w/ 12 1/4" bit on BHA #11. Reamed dyna drill run from 3686' to 3796' Drlg 12 1/4" hole to 3846' Pooh. RIH 2/ 12 1/4" bit on d~na drill (BHA #12). OrienteJ dyna drill w/ scientific eye steering tool for right hand turn. dyna drilled from 3846' to 4006' (Turned hole 19 deg. right & dropped 3/4 deg.). Pooh w/ dy~a drill. (Footage 274'). RIH w/ 12 1/4" bit on BHA #13. Reamed dyna drill run from 3846' to 4006'. Drlg 12 1/4" hole to 4126'. Pooh. RIH w/ 12 1/4" bit on dyna drill (BHA #14) Oriented dyna drill for right, hand turn and slight angle ~uild. Dyna drilled from 4126' to 4280' (Turned hole 26 deg. right & built 1/4 deg. Pooh w/ dyna d~ill' RIH w/ 12 1/4" bit on BHA #15. Reamed dyna drill run from 4126' to 4280'. (Footage 200'). Drilled 12 1/4" hole from 4280' to 4340'. Pooh. RIH w/ 12 1/4" bit on dyna drill (BHA #16). Oriented dyna drill for build. Dyna drilled 12 1/4" hole from 4340' to 4413'. Pooh. Laid dwn. dyna drill. Ran 12 1/4" bit on follow up assy. (BHA #17). Drlg 12 1/4" hole to 13 3/8" csg. point @4480' 12 §/31/77 4480' TD 20" csg. @221 ' 16" csg. @502' (Footage 0'). Circ. & cond. mud for logging at 4480'. Pooh. Laid dwn. 90 jts. of 5" DP. Rigged up Schlumberger. Schlumberger checked TD at 4476' WLM. Ran DIL-GR, FDC-CNL-GR & BHC Sonic from TD to 16" csg. shoe at 502' Rigged dwn. Schlumberger. RIH w/ 17 1/2" expandible hole opener. Opened 12 1/4" hole to 17 1/2" from 502' to 534'. Union Oil and Gas D~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlll, n May ll, 1977 Mr. Hoyle Hami 1 ton Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Hamilton' EnClosed for your approval are three (3) copies of the Sundry Notices and Reports on Wells forms for TBS A-32, Monopod Platform. Sincerely yours, ~.~Ck~al'l enter~ ~..,-.,.- , 'D-i-.~l~,~)rl g. Supt. For~10-403 REV. 1-10-73 Submit *'intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use thls form for proposals to drtll or to deepen r~ Use "APPLICATION FOR PERMIT--" for such proposals.) O,L ~ GAS r-1 W E LL,lr~r~J WELL1 I OTHER 2. NAME OF OPERATOR Union Oil Company of California ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchorage, Alaska 99502 4. LOCATION OF WELL At su dace Conductor 25, Monopod Platform, 1607'N & 556'W of SE Corner Section 4' T9N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RT to MLLW llO' 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20301 6. LEASE DESIGNATION AND SERIAL NO. DL-18731 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradi~g Bay State ~,. 'wEo-:~o. TBS A-32 10. FIELD AND POOL, OR WILDCAT Sec. 4: T9N, R13W, 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4: T9N, RI3W, 12. PERMIT NO. 77-18 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Redesign casing program SUBSEQUENT REPORT OF: WATER SHUT-OFF r""-I REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Holes have been cut in the 20" conductor for utilization as a water source well. which could prevent returns coming to surface. The hole for the 16" conductor will have to be drilled and opened with filtered inlet water and slugged periodically with gel pills to clean out fill. As a result, the 16" casing programmed for 1000' will probably have to be set at +500' Also the 13 3/8" casing design has been slightly altered to accomodate-the ~irectional program. Shown below is the new 13 3/8" casing design. 13 3/8" Casing Design ~ Footage Description Weight Acc. Wt. S.F.T. S.F.C. O-2617'TMD O-2551'TVD 2617' 61# K-55 Butt. 159,637 292,849 3.28 1.11 2617'-4576'TMD 2551'-4375'TVD 1959' 68# K-55 Butt. 133,212 133,212 8.02 0.89 Note- Collapse on 13 3/8" 68# K-55 Butt. csg. would be applicable only if fluid level were removed to the 3750' TVD level w/ 75#/cu.ft. mud in the csg. annul us. 16. I hereby certify that the foregoing Is true and correct · ',,Klm 1"( ua I I e~er Dist. Drlg. Supt. DATE . 5/11/77 (This space for State o][flce u~) See Instructions On Reverse Side DATE Returned Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OiL 63 GAS r-I WELU 'E~I' WELL ~ OTHER 2. NAME 9.F OPERA, kT.Q,R unlonulI Company of CalifOrnia 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99502 4.LOCATION OF WELL Atsu~a. Conductor 25, Monopod Platform, 1.607' N &~556' W of SE Corner, Section 4' T9N, R13W, S.M. 13. ELEVATIONS (Show whether.DF, RT, GR, etc.) RT to MLLW 110' 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 50-133-20301 6. LEASE DESIGNATION AND SERIAL NO. ADL-18731 7, IF INDIAN, ALLOTTEE OR TRIBE NAME 8, UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. TBS A-32 lo~. FIE,Lp AND_ POOL~ .OI~W, ILDCAT Ira(ling uay I-lei (i 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Secti0n 4: T9N, R13W $.M. 12. PERMIT NO. 77-18 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Change in Surface Location I SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ORIGINAL SURFACE LOCATION: Conductor 27, Monopod Platform, 1604'N & 559'W of SE Corner. T9N, R13W, S.M. REVISED SURFACE LOCATION: Conductor 25, Monopod Platform, 1607 'N &556 'W of SE Corner. T9N, R13W, S.M. Section 4' Secti on 4' RECEIVED MAY - 1977 Division of 0il and O.~s C~mrvation 16. I hereby certify that the foregoing is true and correct (This space for State office use) APPROVED BY , CONDITIONS OF APPROVAL, IF ANY: TITLE Dist. Drlg. Supt. 4/29/77 DATE DATE See Instructions On Reverse Side Aprll 7, 1977 Trading Bay State A-32 Unten 0t'1 ~~ of Cailfor~ta State Permit I~. 77-18 Jtm R. Ca11~ Otstrtct Or!1tt~g Superintendent Unten 0tl ~ ef California 909 .West #InCh Avonae Anchor~, Alaska ~ Dear Sir: Enclosed is the approved appllcatton for permtt to drill the above referenced well at a location tn Section 4, Tewnshtp gN, Range 13W, SM. Well samples, core chips and-a mud log are not required. A directional survey is requlr~. l~mny rivers in Alaska and-their drainage systems have been classified as tlapertant for t~ spa~tng ~[ mtgra'tt~n of anadeomwJs fish. Operations in these areas are subject to A:, 1G. S0.870 and the regulations promlgated t~under (Title $, Ataska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- ment of Fish and Game.. Pollution. of a~Ly waters, of the State is prohibited by.AS 46, Chapter. 03, Article 7 and the regulations promulgated thereunder (Tttle 18, AlasKa _ A~lmlnistra:tlve Code, Chapter.70) and by the Federal Water Pollution Control Act, as amended. Prior to ~ing operations you may be contacted by a t~sentattve of t~ Departaent of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Oepartment of Labor is being notified of the issuance of this permit to drtll. To aid us in scheduling field work, we would appreciate your notifying this office within 48 ~rs at~er the well is spudded. We would also like to be notified so t~t & represen~tt~ of the' Division.may be present to witness testing of blowout preventer ~eq~l~nt before surtace castng shoe is drilled. 'L~ o/~ a~ue& Ldmo~ ~4rl ~ 'dOS~Adi~dfls 'doq~'l ~Lo 'L:m8 o/~ UOI4eA~OSuo:) Let~l~U3 ~o 'L~ua o/~ uo~o,~aS ~l.q~ 'am~-pu~ qs:~ '~o , adASOL~U3~ ~ent~pw oD~j~o s&q0, ~v~l,6 oSe~Ld luaauopuecie do uo&:~~s ~o ~a :~ u! LL6 L 'Z. L~d~r Form I0-- 401 ~-~/- I-- 1--71 DRILL OA~ WELL Ill,. TTPM OF WORK b. TYPI~ Or WliLL OIL WIlLt*. 2. NAME OF OPERATOR S~BMIT IN 'r'Rll A'IZ ~ t r S ~'~ r ye id ~ OIL AND GAS CONSERVATION COMMITTEE' APR - 5 1977 ,,~ .... , PERMIT TO DRILL OR DEEPE~is. ion of DEEPEN OTHBR , . 8INGLm [--] M J' J'.T J Plo J, J--'l ZONg ZONE lin(on Oil Comoany of..California goo West Ninth.Avenue. Anchoraae. Alaska 99502. ~i',.OCATIONOFW~-LLA,,ul-,,:e Conductor 27, Mon~pod Platform, 1604'N & 559'W of SE Corner. Section 4: T9N R13W, S.M. /a~ ak~,~ ~,,,.o~o~,~,~o~.~o,~ "C" Pool ~top of C-7 Sd.) 1605'-- & 1415'W of SF Corner. Section 4: TgN. R13W, SM "D" Pool (too of ~3-0 Sd) J 13. DISTANC~ IN-M1L~ AND DIRECTION ~.O~ ~BA.~ST TOWN OR P~y~'&' 1190 Wof SE ' '" 27 air miles north of Kenai Corner. Sec..4.;T9N,R13W,.JsM 14. ~OND I~FO~A'TION: S~wide Surety and/or No. United Pacific Insurance Co. B-55372 15. DISTANCE FROM PROPOS~* [18. ~O. OF ACR~ IN LEASE LOCATION TO NEAREST J 3 PROPERTY OR LEASE LIN~, ~. 875' , 840 (Also to nearest drig, unit, i{ any) . 18. DISTANCE FROM PROPOSED LOcA~ON" ' J IV. PHO~S~ b~' o~ ~PPL,S~ ~o,. ~. 700' to A-7 [ 7373' TMD 6275'TVD 21. ELEVATIONS (Show whether DF. RT. CR. etc.~ RT to MLLW 110' API No. 50-133-20301 U.~IT FARM OPw,LEASF..~IA.ME iraa~ng ~ay b~a~e 9. WELL NO. TBS A-32 10j FIELD AND POOL. OR WILDCAT Trading Ba? 'Field Il. SEC.. T.. R.. M., fBOTTOM HOLE OBJECTIVE) Sec. 4' T9N, R13W SM ~o,,-, $100,000.00 17' ~O. ACR~gS ASS[GNE'D'' ' ' TO ~.,s W~.LL 80 20. ROTARY OR CABLE TOOLS Rotary 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING' WEIGHT PER' FOO~ GRAD~ S~TrL~G D]~:~H quantity of cement · '22" ' ' 16" ....... 75# 'J-55 '+10O'O"IVD Cmt. to surface ~ , ' '11 I/2''~ '13 3/8" 61~ &'68# K=55' 4500'TMD Cmt. to surface ,12','1/4,,9'.5./8,"' 4!.~' .. N-80..74,/3~' ,... "^s re~u~re~ _ , · PLAN OF PROCEDURE 1. Move rig #56 over Conductor #27 & rig up. Repair hole in 20" conductor. 2. Drlg. 17 1/2" vertical hole to +_1000'TMD. Open hole to 22". 3. Set 16" csg.-@ +1000' & cmt. to surface. 4. Drlg. 12 1/4" hole to K0P @+_ILO0'. Drilled 12 1/4" directional hole to +_4500'. ~ ABOVE SPAC'~ P~SC~m.~BE P~OPOSI~) PRO~RAM: If _.pt~ponl Is to deepen, 6~¥e, d~t~ ..on p. rese.nt p.?~uctiv,e zone. ~t.~ new nro'ductive zone. If ~_ro~l~_saI is to al'lit O1' ~pen direct, tonally, give Pertmen.. aata On Suosur~ace l~.auons J~na mea&u,r~ a ~.~ 'vert~-'~TXdepths- Oiv'e-bi~wo-u~ ~ev-~ter' prog,ram.' (Thi},'~ for State office use) CONDITIONS OF A.PPROVAL, IF ANY: ' ' ! SAMPL~:S AND CORE CHIPS R.I~IUI~mI:D j M'U'D LO'C ~ ~ ~ AP, ~nuc.~ COD~ YES G NO 50-1 33-20301 .Auri.l 7, 1977 ~,~ April 7, 1977 'l ~]'H .. · '.LN30N 31NI~13dl3S 9NI-I']I~IO · Igl~lgla 3N/..A~] -IVAOSdd'd N31il~'a BAYH iSAPl S39N~H3 ]3~ : 3±ON . 3XOH$ ' ¢?.mt Ii/~ uqul2 ~ I t i i' I . i , · ! I , i , i -i i i t t I !' j _j . I · I j I ! ,'. t I I i i I L ' j " .1 _!ii, , I I [ . : I ? CASING DESIGN 13 3/8" CASING DEPTH FOOTAGE DESCRIPTION WEIGHT ., ACC. WT. S .F .T. S .F. C 0-2500' (2450') 2500' 61# K-55 Buttress 152,500# 288,500# 3.3 1.2 2500-4500'(4250') 2000' 68# K-55 Buttress 136,000# 136,000# 7.9 4~f.8/7*.4W'A · . · Col.lapse on 13 ~/8" csg. would be applicable only if fluid level inside csg. were removed 3900'TVD level,w/ 72# mud in csg. annulus. 9 5/8" CASING 0-7473' (6275'TVD) 7473' 351,231# 351, Z31# 3.1 1.5 9 5/8" 47# N-80 Buttress PERMIT TO DRILL OR DEEPEN (10-401) -2- 5. Log well as directed. Open 12 1/4" hole to 17 1/2". 6. Set 13 3/8" csg. @+4500' & cmt. to surface. 7. Drlg 12 1/4" directional hole to +7473'TMD. 8. Log hole as directed. 9. Run 9 5/8" csg. to 7473' & cmt. as required. 10. Complete well as a dual "C"-"D" Producer as determined from logs. DRILLING & COMPLETION TIME- Drilling Time Co,mpletion Time TOTAL TIME Thirty Seven (37) Days Ei~_hteen (18,) da~v.s Fi fty-Fi ve (55) dass PERMIT TO DRILL OR DEEPEN (10-40) -3- TARGET LOCATION Target A: "c" oil pool (top C-7 Sd.). approximately 20'S & 840'W of the surface location, or 1605'N & 1415'W of the SE corner. Section 4' T9N, R13W, S.M. Ta_~y_~et B- "D" oil pool (top 53-0 Sd.). approximately 340'N & 615'W of the surface location, or 1970'N & l190'W of the SE corner. Section 4' T9N, R13W, S.M. Bottom Hole' Approximately 670'N & 310'W of the surface location, or 2300'N & 880'W of the SE corner. Section 4' T9N, R13W, S.M. RECEIVED ., - ~dV 6 xx. ~x, ~~xxxxxxxxxx,.xxx. ,xLx~. ~' CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks .1. Is the permit fee attached ..................... 2. Is well to be located in a defined pool .............. 3. Is a registered survey plat attached ' 4. Is well located proper distance from property line ......... 5. Is well located .proper distance from other wells .......... ~ /~~ 6. Is Sufficient undedicated acreage available in this p°ol ...... 7. Is well to be deviated ....................... a/~ ~. Is operator the only affected party ............... ~9~C~ 9. Can permit be approved before ten-day wait ............. ~/~[ 10. Does operator have a bond in force .................. ~/q,~-- z~. ll. Is a conservation order needed ................. 12. Is administrative approval needed . ................ 13. Is conductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings ~?~' Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones .......... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~~ psig 20. Has DMEM approved Plan of Operation ................ Additional Requirements' Approval Recommended' Geology' Engineerinq' TRM --JAL-~ HHH JCM 0~14 HWK .fV~a K~, ECS ~.~RAD~ Revised 11/17/76
