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Home My WebLink About174-008 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday,April 24,2017 11:03 AM To: Dan Marlowe Cc: Juanita Lovett Subject: RE: K-19 ESP Makeup water(PTD-174-008) Dan, Per our discussion the "make-up water"system you are proposing for K-19 is approved. A similar system has been used previously on a Grayling well with the same issue of low fluid rate starving the ESP pump. All surface safety systems(SSVs)should be function tested once installed to verify proper operation. Regards, Guy Schwartz SGOMED APR 2 ar. 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(Guy.schwartz@alaska.gov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Monday,April 24, 2017 9:52 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Juanita Lovett<jlovett@hilcorp.com> Subject: K-19 ESP Makeup water(PTD-174-008) Guy K-19 ESP is struggling due to not enough inflow to keep the ESP in curve and stable. We would like to add FIW down the backside as suction make-up for the pump.This line will have a flow meter so we can properly allocate our well tests and will have a SSV on the makeup line.This SSV will be tied in so that it shuts in any of the following scenarios • Flowline SSV shuts • ESP drive shutdown • IA pressure hits 500 psig increasing • Water-flood system shutdown (header falls below 2000 psi) Let me know if you have any further questions. Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 1 • • McArthur River Field, TBU II Well: K-19 SCHEMATIC PTD 174-008 API 50-733-20259-00 Hilcorp Alaska,LLC As Completed: 12/31/15 +J it I CASING DETAIL RKBtoSea Level(MLW)=100' (tr RI`E i/L SIZE WT GRADE CONN ID TOP BTM. KB 35' (S " n 24" 157.5 B BTC Surf 381' 1 ' - ( 13-3/8" 61 K55 BTC 12.515 Surf 2,591' 9-5/8" 47 N80 BTC 8.681 Surf 2,591' J r9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 .11_95BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' 7" 29 L80 BTC-KC 6.184 9,769' 13,756' TUBING DETAIL 24"6381' 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I 9,322' 4 N. 13-318"-2591' JEWELRY DETAIL N0 Depth MD Depth TVD OD ID Item 35' 35' Tbg Hanger-OCT-UH-TC-1A-ESP,13x4-1/2"IBT lift&susp, w/4"type H BPV profile 1 9,322' 5.130 - Discharge 2 9,323' 5.130 - Pump(x4) 3 9,410' 5.130 - Intake 4 9,429' 5.620 - Motor 5 9,466' 5.620 - Centrilizer/Anode 6 9,865' 7,109' 5.875 4.000 7"Tie-Back receptacle 9,870' 7,112' 5.875 4.000 7"26-32*Hydraulic Isolation Packer 9,875' 7,115' 5.000 3.900 X/O 4-1/2"LTC Box x 4-1/2"IBT Pin 9,876' 7,116' 4.500 3.958 X/O Pup Joint,4-1/2"IBT 9-5/8" 9,878' 7,117' 4.500 3.958 4-1/2"12.643/L-80 IBT Tubing CMT 7320' 7 12,743' 9,118' 4.950 4.000 X/O Pup Joint,4-1/2"IBT Box x 4-1/2"LTC Pin 12,748' 9,121' 5.000 2.992 X/0 Pup Joint,4-1/2"LTC Box x 3-1/2"EUE Pin 12,749' 9,122' 4.520 2.375 X/0 3-1/2"EUE Box x 2-7/8"EUE Pin 12,750' 9,122' 3.750 2.375 2-7/8"Locator/Seal Assembly/Indexing Muleshoe Guide 1 8 12,750' 9,123' 5.670 3.250 Baker Model D Perm Packer 9 12,760' 9,129' 4.500 3.428 Mesh Excluder Screen 2 10 13,055' 9,323' 3.500 - Bull Plug lEMI 13 PERFORATION DETAIL 4 Zone Top(MD) Btm(MD) TOP(TVD) Btm(TVD) Ft Status 5 G-1 12,175' 12,193' 8,725' 8,738' 18' Isolated 12/28/15 Hae in casing G-1 12,203' 12,215' 8,745' 8,754' 12' Isolated 12/28/15 .. 9.509'-9,525' 9769' 6-1 12,223' 12,226' 8,760' 8,762' 3' Isolated 12/28/15 G-1 12,237' 12,250' 8,770' 8,779' 13' Isolated 12/28/15 L6 G-3 12,373' 12,389' 8,868' 8,879' 16' Isolated 12/28/15 • ' G-4 12,411' 12,417' 8,895' 8,899' 6' Isolated 12/28/15 9-5/8"10,047' _. G-4 12,472' 12,482' 8,937' 8,944' 10' Isolated 12/28/15 G-5 12,570' 12,580' 9,004' 9,010' 10' Isolated 12/28/15 G 15 G-5 12,592' 12,644' 9,018' 9,053' 52' Isolated 12/28/15 G-5 12,594' 12,603' 9,020' 9,026' 9' Isolated 12/28/15 8 G-5 12,610' 12,644' 9,030' 9,053' 34' Isolated 12/28/15 6-5 12,651' 12,671' 9,057' 9,071' 20' Isolated 12/28/15 '., --9 6-5 12,676' 12,685' 9,074' 9,080' 9' Isolated 12/28/15 2 I - G-5 12,677' 12,716' 9,075' 9,100' 39' Isolated 12/28/15 r" G-5 12,691' 12,714' 9,084' 9,099' 23' Isolated 12/28/15 .tea 10 HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-PerfdTCP '91&'02 HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perf'd TCP '91&'02 HK 0-6 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Per?d TCP '91' niI HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perf'd TCP '91' MN HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perf'd TCP'91 &50' • HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perf'd TCP'91 &64"02 M HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perf'd TCP '91' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 Ea HB-7 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) 7"-13 756' HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) PBTD=13,713' TD=13,771' MAX HOLE ANGLE=51 CSD 2304' FISH 13,388 Milled Baker'FB-1'Perm Packer,Baker SBE,XO,Pup jt,X0,Camco WP-1 Nipple,XO,Pup, WLEG OCTG Rotating Hours 1. 13,420 20.50 Baker Model'0'Perm Pkr,5'MOE,X0&3-1/2"Pup it. 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 2- 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: iLL 01/25/16 Tubing 0 Rotating Hours • • r r 88 = $ AS' TA z 1 ! ! ! - A 6 — 6N o r r.-; o , 4 E a z A i, a 2 :. 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A ® t �V _KIK 3� 9 cp IF 1 '1' �_ 10in I K KIDQ -AI _ _ -s K K K -��K ® ,i2 x 1 2X1• CA V T_. o mime, 116 `i 1 !� o 01 gi Al I1u K LIJUIU iiJ .z iS x yr �a �f67: ;�f a+ � ii_i CJD00 '� , 0 O ' .Z7 0 �f:T. e a > ; A 3 v v v 0 J • • Carlisle, Samantha J (DOA) 1:14.t1EtaKi From: Schwartz, Guy L(DOA) Sent: Thursday, March 10, 2016 2:23 PM To: Juanita Lovett; Dan Marlowe Cc: Carlisle, Samantha 1 (DOA) Subject: RE: Please withdraw Sundry#315-496/PTD: 174-008 - King Salmon K-19 Juanita, The AOGCC will withdraw sundry 315-496 as requested. ( acid soak treatment) Guy Schwartz Sr. Petroleum Engineer AOGCCSCANNED 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.com] Sent: Thursday, March 10, 2016 1:46 PM To: Schwartz, Guy L(DOA); Dan Marlowe Subject: Please withdraw Sundry # 315-496/ PTD: 174-008 - King Salmon K-19 Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovettf hilcorp.com 1 RBDMS I-v Mg 21 2016 STATE OF ALASKA • AlIL OIL AND GAS CONSERVATION COMMON �. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations El Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown El Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing❑ Change Approved Program ❑ , Plug for Redrill ❑ Perforate New Pool ❑ Repair Well l] Re-enter Susp Well❑ Other Replace ESP/Isolate_❑ Peres 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 174-008 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20259-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 Trading Bay Unit K-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11.Present Well Condition Summary: Total Depth measured 13,771 feet Plugs measured 13,055&13,441 fe F V Ew� ■ ■ true vertical 9,802 feet Junk measured 13,388 feet Alr JAN 2 5 2016 Effective Depth measured 13,055 feet Packer measured 9,870;12,750; feet 13,388;13,420 true vertical g 323 feet true vertical 7,112;9,122;9,5551; feetAOGCC 9,572 Casing Length Size MD TVD Burst Collapse Structural Conductor 381' 24" 381' 381' Surface 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,322'(MD) 6,755'(TVD) Packers and SSSV(type,measured and true vertical depth) Packers x(4)see 9,870'(MD)7,112'(TVD) SSSV:N/A schematic 12,750'(MD)9,122'(TVD) 13,388'(MD)9,551'(TVD) 13,420'(MD)9,572'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12,808-13,041 Treatment descriptions including volumes used and final pressure: Spotted 71 bbls 7.5%HCL across screens at 12,750'displaced with 77 bbls FIW-Final pressure 300 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 137 104 4814 189 189 Subsequent to operation: 113 77 2661 59 58 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development (] Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPE Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ❑ WAG GINJ❑ SUSP❑ SPLUC 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-515& 315-735 Contact Dan Marlowe (907)283-1329 Email dmarlowee.hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature t°. rL Phone (907)777-8356 Date t 1 iS j It Form 10-404 Revised 5/2015 Z/ /� C _ [Ai DMS L'- JAN Z 6 2016 Submit Original Only • •• McArthur River Field, TBU 14Well: K-19 SCHEMATIC PTD 174-008 API 50-733-20259-00 Hilcor)Alaska,LLC As Completed: 12/31/15 CASING DETAIL RKB to Sea Level(MLW)=100' SIZE WT _ GRADE CONN ID TOP BTM. KB 35' 24" 157.5 B BTC Surf 381' ,41tr} ` ' '+„'t7 13-3/8" 61 K55 BTC 12.515 Surf 2,591' 0,A 4? 9-5/8" 47 N80 BTC 8.681 Surf 2,591' +�+ + " ,r Vs.AO' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' L s 9-5/8" 40 1195 BTC 8.835 3,576' 5,038' t 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' 4 �1 7" 29 180 BTC-KC 6.184 9,769' 13,756' a', TUBING DETAIL 24"@381'' dI 3-1/2" I 9.3 I L-80 I Supermax I 2.992 l Surf l 9,322' aZ i 13-3/8"-2591' JEWELRY DETAIL NO. Depth MD Depth ND OD ID Item 35' 35' Tbg Hanger-OCT-UH-TC-1A-ESP,13x4-1/2"IBT lift&susp, w/4"type H BPV profile 1 9,322' 5.130 - Discharge 2 9,323' 5.130 - Pump(x4) 3 9,410' 5.130 - Intake 4 9,429' 5.620 - Motor 5 9,466' 5.620 - Centrilizer/Anode 6 9,865' 7,109' 5.875 4.000 7"Tie-Back receptacle 9,870' 7,112' 5.875 4.000 7"26-32#Hydraulic Isolation Packer 9,875' 7,115' 5.000 3.900 X/0 4-1/2"LTC Box x 4-1/2"IBT Pin 9,876' 7,116' 4.500 3.958 X/O Pup Joint,4-1/2"IBT 9-5/8" CMT 7320 9,878' 7,117' 4.500 3.958 4-1/2"12.6#/L-80IBT Tubing 7 12,743' 9,118' 4.950 4.000 X/0 Pup Joint,4-1/2"IBT Box x 4-1/2"LTC Pin 12,748' 9,121' 5.000 2.992 X/0 Pup Joint,4-1/2"LTC Box x 3-1/2"EUE Pin t;� I•, 12,749' 9,122' 4.520 2.375 X/0 3-1/2"EUE Box x 2-7/8"EUE Pin i 12,750' 9,122' 3.750 2.375 2-7/8"Locator/Seal Assembly/Indexing Muleshoe Guide 1If' { 8 12,750' 9,123' 5.670 3.250 Baker Model D Perm Packer ,,..., 9 12,760' 9,129' 4.500 3.428 Mesh Excluder Screen ey 2 :K 10 13,055' 9,323' 3.500 Bull Plug x 3 '" a»1 ra 4 1 PERFORATION DETAIL gr Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status G-1 12,175' 12,193' 8,725' 8,738' 18' Isolated 12/28/15 Aw �� 5 .Hole in casing G-1 12,203' 12,215' 8,745' 8,754' 12' Isolated 12/28/15 r. •'r 9,509'-9,525' 9769 `44 (.1 G-1 12,223' 12,226' 8,760' 8,762' 3' Isolated 12/28/15 14' Y ' V'' G-1 12,237' 12,250' 8,770' 8,779' 13' Isolated 12/28/15 6 , 4-0 t 341 G-3 12,373' 12,389' 8,868' 8,879' 16' Isolated 12/28/15 G-4 12,411' 12,417 8,895' 8,899' 6' Isolated 12/28/15 9-518"10,047 '+ 9. G-4 12,472' 12,482' 8,937' 8,944' 10' Isolated 12/28/15 «J G-5 12,570' 12,580' 9,004' 9,010' 10' Isolated 12/28/15 4 _ , G 1-5 G-5 12,592' 12,644' 9,018' 9,053' 52' Isolated 12/28/15 G-5 12,594' 12,603' 9,020' 9,026' 9' Isolated 12/28/15 8G-5 12,610' 12,644' 9,030' 9,053' 34' Isolated 12/28/15 1 '.M G-5 12,651' 12,671' 9,057' 9,071' 20' Isolated 12/28/15 •' ` - 9 - G-5 12,676' 12,685' 9,074' 9,080' 9' Isolated 12/28/15 �.��I3 G-5 12,677' 12,716' 9,075' 9,100' 39' Isolated 12/28/15 �`i G-5 12,691' 12,714' 9,084' 9,099' 23' Isolated 12/28/15 II'ate* -'II 10 HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perfd TCP'91&'02 _,t" HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perfd TCP'91&'02 . ; , 'I'`.7 I° X1""4 {'' HKO-6 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' ,. '1� ',-;1,,,:-:: 14.�; HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perfd TCP '91' , 1i.'?' '" , HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50"02 t""1 HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64"02 w�Z`t �Y . 1 HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' ' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 4� - €1 HB-7 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) 7"-13.756 ". -4.. HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) PBTD=13,713' TD=13,771' MAX HOLE ANGLE=51(r(2304' FISH 13,388 Milled Baker'FB-1'Perm Packer,Baker SBE,XO,Pup jt,XO,Camco WP-1 Nipple,XO,Pup, WLEG OCTG Rotating Hours 1. 13.420 20.50 Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. 24" 58 Rotating Hours 1 3-3/8" 279 Rotating Hours 2. 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: 1LL01/25/16 Tubing 0 Rotating Hours • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/08/2015 -Tuesday Cont. spot rig eq. Clean pits. Well static. Set BPV. N/D tree. M/u sub t/ hanger. Lift threads good. Install blanking sub. N/U BOPE, tq. bolts, r/u accumulator lines, install drip pan, rig floor, wind walls, cellar wall tarps. M/U 3 1/2 tj. mu t/ hanger. Function test BOPE, good. R/u test pump fill hole &surface eq.Attempt to shell test, no go.Troubleshoot for surface leaks, none found, appears hanger is leaking. Send e-mail notification t/AOGCC Jim Regg & Guy Schwartz, & Hilcorp engineer, of wellhead condition, as per Sundry. Wait for response for rolling test approval. 12/09/2015-Wednesday Test BOPE.Test choke manifold 250 low, 2500 high. Had 1 f/p on test#4 valves 5& 6. Serviced, re-tested good. Received approval for rolling test @ 8:56 f/AOGCC, Guy Schwartz. PJSM w/ hands. R/u lines, perform rolling test w/3 1/2 tj, as per approved Sundry, using rig pump.Tested annular, pipe rams, no visual leaks found.Tested blinds, a leak developed on hub connection at wellhead. Re-torque connection & retest no visual leaks.Tested rest of eq. good. Tested gas alarm system & PVT good. RIH w/tj. M/u t/ blanking sub, pull same, 92 breakdown tj. M/u landing jt. P/u on string hanger started moving @ 80k. Cont. p/u t/ 115k, packer came free. Wt dropped t/94k, p/u t/ 120k wk 4 1/2' stretch making no headway. Wk up t/ 127k, no go. R/u t/circulate. P/u t/120k, circulate @ 2.5 BPM, 650 psi, no change in weight.Attempted to s/o, unable t/slack off t/previous depth. Wk string up t/ 150k had gained stretch up but lost down stroke. Monitor hole while waiting for e-line. R/U e-line equipment. M/u 2.50" rtc, 2.50" ema, 1-11/16" ccl, 1-11/16" wt bars and centralizer. Rih w/e-line tag @ 9,295' elm, correlate on depth and fire cutter @ 9,260' elm (indication pipe cut). Pooh w/e-line. M/U 2.650"jet cutter, ccl and wt. bars. Rih w/e-line, correlate cutter on depth and fire cutter @ 9,259' elm, pooh and r/d e-line. 12/10/2015-Thursday R/U pull hanger t/floor, up wt 92-95k. Unable to s/o. R/u spooling eq. L/d landing jt, broke off hanger& I/d.Approval was granted by AOGCC Guy Schwartz to pull packer before resuming BOPE test. POOH 1/d 10 jts, SSSV w/pups, packer w/pups &xo. Secure cable &flat pack w/cannon clamps. M/u hanger& landing jt. Land out same. Pull landing jt. M/u 3 1/2 test jt. Install TWC &test jt. Fill stack&surface eq. Shell test good.Test BOPE, as per AOGCC& Hilcorp requirements following approved Sundry guidelines for Rolling test. Test all BOPE eq. 250 low, 2500 high all good. R/D test jt and test equipment. M/U In pull hgr to r/f and 1/d same. R/u sheaves in derrick, pooh w/3-1/2" tbg. strapping same. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date • K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/11/2015- Friday Finished POOH w/recovered 3 1/2" 9.3# L-80 SuperMax prod tubing-total recovery= 9,219.55' (PM) + 35' elevation = 9,254.55'. All prod tubing and hardware recovered down to RCT cut(9,260' ELM)-flat pack control cable parted — 1.5' below last connection (leaving possible 25' of control line above TOF) and end of ESP cable measured 34' below last connection (ESP cable should be deeper than TOF). R/D Summit spooling units. Cleared and cleaned rig floor. R/D McCoy tongs and R/U Moncla Foster tongs. Began off loading 3 1/2" PH6 workstring from M/V Titon. P/U BJs to tighten two >6" connections on KOTs BHA#1 (8 1/8" Bowen 150 Series overshot Idd w/3 1/2" basket grapple w/ MCP, 6 1/4" x 2 5/8" X-over, 4 3/4" bumper& oil jar, 6-4 3/4" DCs, 4 3/4" Acc jar, 4 7/8" x 2 1/4" X-over sub = 226.90'). Swapped elevators and began picking up 3 1/2" 12.95# PH-6 work string off catwalk-strapping &drifting. 274 jts (8700') at report time. 33 bbl FIW loss for the day= 336 total loss. 12/12/2015-Saturday Continued in hole picking up work string-tagged at 9,269' (291 jts+4' in on#292). Attempted to latch fish with no success. Laid out jt#292. P/U power swivel. M/U 3 1/2" IF safety valve w/x-over&two 8' pups. R/U snub lines and screwed into string.Attempted to latch fish conventionally but failed- latched fish by rotating on TOF for—30 mins. Set grapple and hit jars 5 times at 60k over with no movement. Decision was made to spot 20 bbls acid before continuing to work pipe. Offloaded and spotted ISO w/7.5% HCL and pump from M/V Titon. R/U to pump down tb (w/swivel broke off). Pumped 5 bbls of FIW at 2 BPM 400#s then 20 bbls 7.5% HCL(returns at 15 total bbls pumped) then 40 bbls FIW (tb capacity at cut is 68 bbls). Waited 30 mins before beginning to work pipe again.Jarred on ESP fish at 50k over string weight (160k). Moved fish 4' up hole while working pipe. Decision was made to B/O swivel and 1-8' pup. Changed elevators and continued pulling. Laid out 2nd 8' pup and pulled 1st full stand with 12k overpull. POOH w/KOT BHA#1+ ESP fish- pumping 7 bbls every 20 stands. B/D bha and lid over shot. Pooh with ESP ass'y and laydown same. Complete ass'y recovered, total recovered= 246.15' (2 jts, 2 cut pieces and complete pump assy.) + 25 clamps, Clear r/f of ESP handling tools and install wear bushing. Began M/U KOTs BHA#2 (8 1/2" Varel Rock bit& scraper f/9 5/8" casing). Total fluid loss for the day= 60 bbls/Job total = 396 bbls. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/13/2015-Sunday M/U KOTs BHA#2 (8 1/2" Varel rock bit, casing scraper, 6" x 2 1/4" bit sub, 4 3/4"x 2 1/4" B&0 jars, 4 3/4" x 2 1/4" DCs x 6, 4 7/8" x 2 1/4" x-over).TIH w/9 5/8" C/O assy to 9,225' (145 stands out of derrick).Serviced rig. Ran in singles off catwalk strapping and drifting-tagged at 9,431' w/#297 (48' above end of ESP assy at 9,479')- laid out single. Clean out and dismantle pollution pan. N/D spool. N/U stripping head adapter. P/U power swivel w/single #297. Installed stripping rubber and M/U to string. Landed rubber. Est. drilling parameters, pumping 3 bpm 300 psi, p/u wt= 104 (rot/pu wt=80k), s/o = 64(rot/so=75k), rpm =60, free torq=4k, drilling torque 4-5k, wob=1-2k. Rotate/wash down from 9,431' -9,433' . Pipe plugging, stripper rubber leaking, line up & pump down tbg and unplug same. C/B/U in rev until returns clean and center stack. Cont. rotate/wash down from 9,433', pumping 3-1/2 bpm 500 psi. Pipe plugging. C/B/U until returns clean. B/0 power swivel. R/U pump. Break circulation down tbg. Pump 5 bbls 8.5# F.I.W. 10 bbls 7.5% HCL and displace w/69 bbls 8.5# F.I.W @ 2bpm 200 psi. Let soak for 1 hour. Cont. rotate & wash down f/9,433'-9,438', pumping 3-1/2 bpm 500 psi. Pipe plugging off. Blowing out down tbg as needed. Decision was made to POOH. Reversed btms up. 30 bbls lost thru the day for a total of 426 bbls FIW lost. 12/14/2015- Monday L/D swivel and N/D stripping head adapter. POOH w/KOTs BHA#2 (bit&scraper f/9 5/8" casing). Filled hole at 20 stands out-took 16 bbls. Continued POOH pumping 7 bbls every 20 stands. B/D KOTs BHA#2- no unusual marks on bit or scraper. On loaded prod personnel and worked M/V Titon-off loaded prod personnel. Laid out, measured and M/U KOTs BHA#3 (8 1/2" x 7 3/8" Ocean Wave shoe w/finger basket, 8 1/8" WP ext w/flapper, 7.5' 8 1/8" WP ext, 8 1/8"x 3 1/4" Canfield bushing w/ perforated sub installed, XO, 0 & B jars, 6- DCs,XO).TIH w/BHA#3 to 9,421'. N/U stripper head. Crane malfunctioned, unable to stop load from slacking off. Production electrician repair same. P/u power swivel and install stripper rubber. Cont tih, tag @ 9,438', wash down from 9,438'-9,452', pumping 3-1/2 bpm 750 psi, indication pipe plugging at surface. Remove circulating hoses from manifold and inspect same, nipple plugged w/several pieces of control line. R/U and blow thru manifold "ok". Cont. wash down from 9,452'-9,577', pumping 3- 1/2 bpm 750 psi, c/b/u every jt. recovering scale at btms up. 13 bbls of white scale recovered at report time. 195 bbls of FIW lost in the last 24 hrs for a accumulated total of 621 bbls. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/15/2015-Tuesday Finished cleaning out 9 5/8" casing from 9,577' to TOL at 9,769' (circulating 3 1/2 BPM 750#s). The last 4 1/2"jts were slacked off without circ-the two before those were circ down with no weight loss. Estimated scale bridge from 9,431'to 9,607' w/end of ESP assy at 9,479'. Total recovery of scale — 15 bbls. Circ 2 tb volumes prior to B/O swivel- hole clean. Broke single off swivel and laid both down plus 2nd single. POOH w/ 153 stands pumping 7 bbls every 20 stands. B/D KOTs BHA#3. Recovered fist sized rocks and double fist sized pieces of white scale in both WP baskets. M/U KOTs BHA#4, 6" w/p shoe w/catchers, 7" csg scraper, oil/bumper jars and (6)4-3/4" dc's.Total BHA= 223.38. Tih w/3-1/2" workstring and BHA#4 to 9,728'. Cont p/u 3-1/2 ph6 out of v-door and tih, tag @9,972'. Strap and rabbit same. L/D single. N/U stripper head. R/U power swivel and install stripper rubber. Wash down f/9,972'- 10,131' @ 3-1/2 BPM 750 PSI, wob= 1-3k, C/B/U every jt. Recovering white scale (^'30' every 35 mins). Total scale recovery of 3 bbls. FIW loss today= 70 bbls for a total loss of 691 bbls. 12/16/2015 -Wednesday Continued washing at 3.5 BPM 750#s-at 10,131' we began having to rotate to make hole. At 10,144' we began plugging off. Switched direction of flow back and forth but could not flush plug. Decision was made to pull out of 7" liner because it was getting sticky.,Broke off single and laid down swivel. Hung mud bucket and pulled 7 seven stands- M/U SV and Kelly hose- pressured up back and forth and broke plug loose-trapped plug in standpipe manifold and cleared plug (plug pics in "0' drive)-circ 2 tb volumes then TBI to 10,144'. P/U swivel.,Continued attempting to make hole circulating 3.5 BPM 750#s-tb plugged after 3' of new hole made (TD reached is 10,147'). Failed to flush plug. Decision was made to POOH and change BHA. Laid down single & swivel. N/D stripping adapter.,POOH w/ KOTs BHA #4, shut down due to high winds (44-50 mph),Slip/cut 170' drill line, re-set c-o-m and chk w/drill line. Perform gen. rig maintenance and house keeping w/waiting on wind to subside.,Cont pooh w/7" scraper assy. B/D and L/D bha. removed rocks, scale and junk from 7" finger basket.,N/D pollution pan and halls head adapter spool in preparation to pull wear bushing. 80 bbls FIW lost in last 24 hrs for a accumulated total loss of 771 bbls. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/17/2015 -Thursday Pull wear bushing- M/U test plug on test jt w/ pumpin sub, SV& IBOP. Landed test plug and filled stack. Worked thru leaks found during initial shell test.,Tested all BOPE to 250/low 2500/high as directed by Sundry according to AOGCC & Hilcorp requirements-witness waived by Mr. Regg/AOGCC 2:36 PM 16 Dec15. Performed draw down test on accumulator unit.,Pulled test plug and installed wear bushing- ran in four hold down pins. Laid out test jt- N/U 11" x 13 5/8" 5M spool and pollution pan.,P/U KOTs oil/bumper jar assy and M/U 6" Cross Bar Mill (KOTs BHA#5- 6" x 2 1/4" Cross-Bar mill, 4 3/4" x 2 1/4" B & 0 jars, 4 3/4" x 2 1/4" DCs x 6, 4 7/8" x 2 1/4" X-Over Sub).Total bha= 211.71,TIH w/ BHA#5 to 10,120',N/U stripper head adapter, r/u power swivel and install stripper rubber.,Cont tih tag @ 10,141', Rotate/Wash down from 10,141'-10,275', indication broke thru plug, pumping 4 bpm 600 psi. C/B/U every jt. rpm=60, wob= 2-5k, drilling torque= 6-7k. Cont tih w/no pump or wob, to 10,338'.,pull stripper rubber and r/d power swivel.,Cont tih w/mill assy(strapping and drifting) running singles w/o circ or rotating to 10,990' (at report time). 12/18/2015 - Friday Continued TIH, picking up singles, w/ KOTs BHA#5 (clean out run for 7" casing) from 10,991 to 12,632'-tagged.,P/U swivel w/single- installed stripping rubber and M/U to string. Rotated &washed from 12,632' to 12,759' (PM) tagging top of Baker Mdl 'D' pkr. Circulated 2 tb volumes at 3.5 BPM 750#s. Parameters: P/U w/swivel 158k, S/0 70k, R/W 80k F/T 6500#s, fluid loss— 30 bbls/hr.,B/O single and L/D swivel- N/D stripping head.,POOH w/ KOTs BHA#5 pumping 7 bbls every 20 stands. B/D bha and 1/d mill.,Hang off block, remove brake bands from draw works and install new pads on bands. Re-install bands on d/w and adjust same.,P/U KOT bha #6, Strap and rabbit same. 12/19/2015 -Saturday Finish M/U KOTs BHA#6 screen cleanout run (2 3/8" PH-6 mule shoe jt w/2 3/4" carbide dressed btm blade, 8-jts 2 3/8" 5.95# P-110 PH-6 tb (top jt has dressed 3.25" polishing mill welded on), 4 3/4" x 1 7/8" X-Over sub, 5.969" x 1 3/4" Non-Rotating stabilizer,4 3/4" x 2 1/4" B&O jars, 6-4 3/4" x 2 1/4" DCs, 4 7/8" x 2 1/4" X-Over sub). total bha= 481.46,TIH w/ BHA#6 to 12,715' dpm.,R/U circ hoses to TB and start wash/clean active tank w/troubleshoot brake issue on draw works.,R/U power swivel ,install stripper rubber& cont tih.Taggged @12,751', wash down f/12751'- 13,017' dpm, (polish seal bore @ 12,750') puming 3-1/2 bpm 700 psi. C/B/U every jt.,Began circ 2 tb volumes @ 3-1/2 bpm, 700 psi. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/20/2015 -Sunday Finished circulating 2 tb volumes around at 3.5 BPM 750#s at 12,744'.,Laid down power swivel and pulled/laid down 10 jts of workstring placing EOT at 12,744'. Lined up to send returns to TBF (NPFT signed).,Displaced dirty wellbore fluid with clean 8.4 FIW- pumping 3 BPM 650#s with returns going to TBF-total fluid pumped was 900 bbls. Shut down rig pump.,Lined up to pump with Marlowe pump. Pumped 2 bbls FIW then 71 bbls 7.5% HCL then 77 bbls FIW at 2 BPM 300#s. R/D packed up Marlowe pump to be sent to Grayling tonight.,POOH w/ KOTs BHA#5 (screen cleanout assembly) laying down 90 more jts-to BHA.,B/D BHA laying down all DCs-found oil jars parted at service break- pin broken off. BHA left in hole = 284.33' (dressed mule shoe, 8-jts 2 3/8" PH6 tb, 3 1/4" polishing mill, xo sub, non-rotating stabilizer, 4 3/4" bumper jar, .91' of parted 4 3/4" oil jar). Began laying out/ measuring fishing tools needed for recovery. Drive chain on draw works broke while checking brake function. 12/21/2015- Monday Took off cover and repaired broken drive chain on rig draw works. Installed cover.,M/U KOTs BHA#7 (5 3/4" x 2 5/8" Bowen 150 Series Overshot Ild w/4 3/4" spiral grapple, 4 3/4" x 2 1/4" B &0 jars, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 7/8" x 2 1/4" X-Over sub). Ran in 5 stands and secured well.,Removed brake bands and roughed up brake pads from where they were glazed over. Reinstalled brake bands.Test run same "ok",Cont.tih w/bha #7 out of derrick to 9666'.,P/U 3-1/2" ph6 out of v-door and cont. tih to 12,707' , strap and rabbit same. R/U power swivel & cont.tih pumping 2.5 BPM 440#s-tagged fish at 12,743' and rolled over the top- noticed 150#increase in pump pressure. 12/22/2015-Tuesday Worked pipe a couple more times in attempts to insure a latch on fish (< 1600#s fish weight). R/D power swivel- laid out pup &single.,POOH w/ KOT BHA#7 (overshot/jarring assy)to BHA.,B/D BHA to bumper/oil jars- picked up to view fish in overshot. Continued B/D BHA to fish. L/d fish, Full recovery. P/U & B/D KOT bit scraper assy, L/D (6) 4-3/4" dc's.,Remove pollution pan, N/D stripper head adapter& n/u 13-5/8" riser spool. R/U 4-1/2" test jt, pull wear bushing and install test plug.,R/U test equipment and test bopes with 4-1/2" test jt as per AOGCC & HILCORP specs 250 low/ 2500 high. R/D test equipment and pull test plug.,M/U 3,333.66' of 4-1/2" 12.6# IBT section of isolation ass'y as per tri-point rep. Strap and rabbit same. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/23/2015 -Wednesday Finished M/U isolation assembly(3.03' seal assembly, locator sub, xo, xo, pup, 99 jts of 4 1/2" IBT tb, xo pup, xo, D&L hyd set pkr, seal bore, running nut, xo, xo, bumper sub, xo = 3,372.44'). TIH w/ D&L hydraulic set Liner pkr f/9 5/8" casing as per Tripoint drifting 3 1/2" 12.95# PH6 workstring. Set down at 712' (pkr depth)-4,066' EOTs. Conferred with Tripoint& Hilcorp Engineers, attempted to work pkr free with no success (20-120k). Filled annulus with 31 bbls of FIW and pressured up to 800#s indicating that pins had sheared and both sets of slips were energized. Discussed situation and options w/ Engineer. Decision was made to drop ball and hydraulically set pkr. M/U pumpin sub and halliburton valve in top of string. Dropped 1 1/2" steel ball and M/U Kelly hose.Took 6 bbls to fill tbg then pressured up to 3500#s for 20 mins. Released pressure and B/O hose and pumpin sub. Located jar travel and turned pipe 15 rounds to the right releasing from pkr. POOH w/Tripoint pkr running tool. B/O L/D running tool. M/U KOT BHA#8 (8 1/2" x 2 7/8" Bladed Junk Mill, 6 1/4" x 2 5/8" X-Over, 4 3/4" x 2 1/4" bumper&oil jar, 10-4 3/4" x 2 1/4" DCs, 4 7/8" x 2 1/4" X-Over= 337.78'). R/U Knight McCoy tongs and TIH to 683'. N/D 13-5/8" riser and N/U halls head adapter. R/U power swivel and install stripper rubber. Cont tih, tag @ 707' pm. Rotate/Mill down from 707'-709'pm, pumping 4 bpm 300 psi, drlg. torq =5-7k, wob =4-5k. Pipe plugging. ( determined pipe plugging at surface ). Break surface lines and found return line plugged at connection w/metal shavings and debris. Clean out and circulate through same. Cont. Rotate/Mill down from 709'-710', pumping 4 bpm 300 psi, drlg.torq=5-7k, wob= 4-5k. P/u wt 30k, s/o wt 29k. Total metal in returns= 106#s. B/O R/D swivel. 12/24/2015-Thursday Finished R/D swivel. N/D stripping adapter. POOH from 710' w/ KOT BHA#8 (8 1/2"junk mill). B/D BHA and examined mill. Mill ^ 30%worn. Marks indicate that we're down to a 6" ID. Remainder of box connection could be spinning on pin (that is looking up). P/U 3 1/2" test jt and M/U test plug. Land plug and M/U pumpin, SV and IBOP in top of jt. Attempted to fill stack but had to unthaw pump to mud cross line. Filled stack then had to wrap/heat exposed pumpin, SV& IBOP on test jt. Tested all BOPE equipment to 250#s/low, 2500#s/high as per Sundry according to AOGCC& Hilcorp requirements. Performed accumulator draw down test. Tested w/3 1/2" &4 1/2" tbg. Installed wear bushing. M/U KOT BHA#8 (8 1/2" x 6 3/4" pkr type shoe, 8 1/8"x 3 1/4" Canfield bushing, 6 1/4" x 2 5/8" X- Over, 4 3/4" x 2 1/4" bumper&oil jar, 10-4 3/4" x 2 1/4" DCs, 4 7/8" x 2 1/4" X-Over= 342.66'). TIH w/3-12" ph6 to 690'. N/D 13-5/8" riser spool and N/U halls head adapter. R/U power swivel and install stripper rubber. Cont tih tag @ 710' dpm. Start burning over remainder of seal bore extension. Pumping 3 bpm 150 psi, rpm= 60, wob=4-15k, p/u 30k, s/o 29k. Made approx. 6" by report time. Recovered approx. 27 lbs of metal. No hole made in last 2 hrs. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/25/2015- Friday R/D power swivel and stripping head adapter. POOH from 710'. B/D BHA. Shoe worn 50%on 1 1/2 of the 4 pads. Almost zero wear on 2 1/2 pads. Offloaded NOV mud motors & misc tools from M/V Titon. M/U KOT BHA#10 (8.5" x 6 3/4" pkr type burning shoe, 8 1/8" x 3 1/4" Canfield bushing, 6 1/4" x 2 5/8" X-Over,4 3/4" x 1 1/2" DP X-Over, 5" NOV mud motor,4 3/4" x 1 9/16" DP X-Over, 2- 5" x 1 1/2" boot baskets, 4 3/4" x 2" bit sub, 4 3/4" 2 1/4" bumper& oil jar, 10- Hilcorp 4 3/4" x 2 1/4" DCs, 4 7/8" x 2 1/4" X-Over= 383.07').TIH to 700'. N/U stripping head adapter and P/U swivel w/single. Installed rubber and M/U to string. Landed rubber. Lined up to pump LW. P/U 30k S/O 29k. Began circulating at 100 SPM 350#s 3.5 BPM. Engaged swivel to prevent motor from turning pipe in reverse (" 30 RPM). Est'd shoe RPM is 90. 1600 hrs finished milling over seal bore ext. Eased down 1' and started cutting on pkr. F/711'-713'. Mud mtr stalling out and pressure up to 1200 psi. Work pipe up to 50k (20k over), pipe free. Pooh, dragging 10-15k over, I/d single. Cont pooh to 650', pipe free.Tih to 731', pkr gone. R/D power swivel and halls head. Pooh w/burning shoe bha. L/D (4)4-3/4" dcs, b/d bha and clean out junk baskets. Recovered small amount of metal f/junk baskets and 3' piece of pkr seal bore stuck in shoe. M/U KOT BHA#11 (8 1/8" x 3 3/4" Bowen 150 overshot w/ upper ext, 6 1/4" x 2 5/8" X-Over, 4 3/4" x 2 1/4" bumper& oil jar, 6-4 3/4" x 2 1/4" DCs, 4 3/4" x 2 1/4" Acc jar, 4 7/8" x 2 1/4" X-Over= 229.37'). 12/26/2015-Saturday TIH w/ KOT BHA#11 (overshot,jars& collars)to stand #8. TIH 1/2 speed thru stand #40. Continued in hole to 9,408'. P/U 108k-S/0 55k-tagged fish and latched same. P/U on string and fish pull out of seal bore at 13k over(165k). P/U weight now is 152k-S/O is 75k. SOOH w/fish dragging thru each casing collar(occasionally having to overpull to 180k and work thru connection- unable to cock jars because we could not set down). Pulled two stands then decided to lay down 80 singles in preparation for isolation assembly. Stopped dragging after 23 jts pulled (8,694'). POOH. L/D accel jars, (6)4-3/4" dc's, & oil jars. L/D bumper jars, over shot and 9-5/8" pkr. C/O pipe handling equipment from 3-1/2" to 4-1/2" & cont. pooh w/4-1/2" tbg. laying down 53 jts. Full recovery of isolation assembly. Unable to rack in derrick due to length of jts. P/U KOT oil jars, overshot and 9-5/8" pkr. B/D overshot assy. R/U Pollard s-line equipment. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/27/2015-Sunday R/U Pollard S/L w/full lubricator. M/U rope socket, 10' of 1 3/4" stem, 1 3/4" knuckle, 1 3/4" oil & spang jars w/3.5" magnet. TIH (Run#1)to 12,744' (SLM). Worked magnet several times and POOH. Recovered metal shavings and 3- 1/2 dollars size chunks of packer. Cleaned magnet into bucket.TBI (Run #2) w/same tool string to 12,744' (SLM). Worked magnet as before and POOH. Recovered metal shavings and smaller chunks of milled over pkr. Cleaned magnet into bucket.TBI (Run #3) w/same tool string to 12,744' (SLM). Worked magnet as before and POOH. Recovered metal shavings and even smaller chunks of milled over pkr. Cleaned magnet into bucket.TBI (Run#4) w/ same tool string to 12,744' (SLM). Worked magnet as before and POOH. Recovered less metal shavings this time and 2-flat pieces w/2- more pieces that could be threads. Cleaned magnet into bucket.TBI (Run #5) w/same tool string to 12,744' (SLM). Worked magnet as before and POOH. Recovered —same amount of metal shaving as previous run w/2-flat pieces. Cleaned magnet into bucket.TBI (Run #6) w/same tool string to 10,000' (SLM) (isolation pkr to be set at^'9,900') to see how much metal we would pickup. POOH with same recovery as previous runs. Cleaned magnet into bucket. A total so far of 8#s of metal retrieved from magnet. B/O 3.8" magnet and M/U 2.63" magnet. TIH #7 w/same tool string with different magnet to 12,812' w/o setting down (top of mdl D pkr w/screens attached is 12,751'). POOH. Some metal shavings on magnet. Cleaned magnet into bucket. B/O 2.63" magnet and M/U 3.8" magnet. TIH #8 w/same tool string with different magnet (4.5" magnet will be out for next run). TIH to 10,000', Pooh- recovered metal shavings. B/O 3.8" magnet and M/U 4.5" magnet &TIH #9 w/same tool string w/different magnet to 10,000', POOH, recovered metal shavings. Total shavings recovered= 12LBS. ( Decision made to run 7" isolation ass'y). R/D Pollard s-line equipment. M/U 3' x 3.23" seal assy w/ ratcheting muleshoe, 2,865' 4-1/2" 12.6# IBT TBG and 7" Hyd. Liner Top Packer as per Tri-Point rep. Rabbit same. C/O pipe handling equipment and tih w/3-1/2" ph6, (2 mins per stand), drifting same out of derrick. Approx depth @ Report time=4,396'. 12/28/2015- Monday Continued TIH w/5.87" hydraulic set Liner Top pkr w/ 2,865.16' of 4 1/2" 12.60# IBT tb& 3' 3.23" seal assy with ratcheting mule shoe on 3 1/2" PH6 workstring-drifting all pipe. At 0800 hrs EOT is 5,395' and pkr is 2,517'. Moncla called a 'Stop Work' due to high winds. Derrickman came done because winds was pushing the block to the back of the derrick. Monopod & Dolly recording winds of 40-50 MPH with gusts higher. Put rig crew to work cleaning solids in shaker tank and general house cleaning. Continued RIH w/isolation assembly to liner top at 9,769' (1500 hrs)-went thru with no trouble. CIH to liner top with pkr. Passed thru with no issues.Tagged with seals at mdl 'D' pkr(12,751'). P/U 159k S/O 64k 62.5" of stretch. P/U and spaced out. R/U to circ. Break circ. @ 1 bpm 75 psi, sting into model "D" pkr at 12,751', lost returns and pressure inc to 150 psi. Set 5k down. Drop pkr setting ball, pressure up to 3800 psi on tbg and set 5.87" hyd liner top pkr at 9,869' as per Tri-point rep. Push/pull test same. R/U power swivel and release from pkr as per Tri-pont rep. Lost 45k string wt. Break all connections on power swivel and R/D same. Change out tongs and electrician wire up power pack and trouble shoot same. Unable to back out 3-1/2" ph6 due to tongs slipping. Pooh w/3-1/2" ph6 work string. L/d same. 38 of 320 laid down. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date K-19 Moncla 404 50-733-20259-00 174-008 12/8/15 1/1/16 Daily Operations: 12/29/2015-Tuesday Continued POOH w/Tripoint pkr running tool laying down all PH6 work string. Began offloading work string onto M/V Titon in preparation to P/U production string. B/D L/O Tripoint pkr running tool. Ran in remaining two stands of work string in derrick and laid same down. Loaded out all PH-6 work string. Cleared rig floor in preparation to run in/ stand back production string. Laid out and strapped 1st bundle of 3 1/2" 9.3# L-80 Supermax tb. Ran in tbg drifting and torqueing to mark ("1800#s torque). 160 jts RIH at report time = 5,283'. 12/30/2015-Wednesday Continued running in singles drifting and torqueing to mark(1800#s MUT) from 160 (5,283') to 278 (9,248') singles in hole. POOH w/ 139 stands of 3 1/2" 9.3# L-80 Supermax production string (used). Changed slip dies. Crane crew setup Summit while POOH. N/D 7 1/16" x 11" & 11" x 13 5/8" spool and pulled wear bushing. N/U 11" x 13 5/8" spool. Held PJSM w/all essential personnel on p/u and running ESP ass'y. Assist Summit personnel m/u ESP ass'y. and hang sheaves in derrick.Tih at 2 mins/stand w/ESP ASS'Y and 3-1/2" 9.3# L-80 Supermax prod. string out of derrick- checking continuity every 1,000'. 1,573' in hole at report time (21 stands). 12/31/2015-Thursday Continued running in hole with Summit ESP assy @ 2 min/stand-checking continuity every 1,000'.At 71 stands in (4,886') changed ESP reels and made splice in cable. Continued running in hole with Summit ESP assy @ 1min/stand- checking continuity every 1,000'-from 4,886' to 9,395'. M/U R/U 1-single (9,427'). Perform continuity check. N/D 11" x 13 5/8" spool. P/U tbg hanger on jt of 4 1/2" IBT tbg. M/U hanger w/assistance from NOS rep.Terminate reda cable and all control lines into hanger. Land Hgr. Check continuity(ok). End of ass'y @9466'. B/O landing jt. and install BPV. RID Summit equipment. Remove all tools and tongs from rig floor. R/D floor and N/D BOPE. 01/01/2016- Friday Finished N/U tree w/assistance from NOS rep. Tested hanger void to 250#s low/5000#s high for 20 mins. Pulled BPV and set 2-way check. Shell tested tree 250#s low/5000#s high (leaked internally). Found leak in SSV. Greased and operated same. Pressured up to 5000#s for a good shell test.Turned well over to production @ 1100 hrs. ®F T • • i".-‘)\ 1//7,',s, THE STATE Alaska Oil and. Gas s OfA LAsKAL Conservation Commission t i.tz 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 lliaM' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov January 14, 2016 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit K-19 �� PTD 1740080 Dear Mr. Golis: On January 13, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-19 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment— as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit K-19 prior to the test. The well performance was monitored for three hours with observed gas flow rates less than the regulatory limit and no liquid flow to surface. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system 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 Trading Bay Unit K-19 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 King Salmon Platform. Sincerely, ‘--) Re-2./ James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 01/13/2016 P. I. Supervisor ll FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit K-19 Hilcorp Alaska LLC PTD 1740080 01/13/2016: I traveled to the King Salmon platform to witness a no-flow test on TBU K-19. This well is a packerless ESP completion. Upon arrival I met with Sandy Reynolds and Tim Severson. We discussed the escape route if needed and what was happening on the platform. listened in on their pre-job meeting. The tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no-flow test measuring equipment. I verified the Master, Swab and IA Valves to be fully open and the test gauges attached to the Swab Valve. The pressure and flow measurement devices have recent calibrations. Flow from the meter outlet transitioned back to a 1-inch bleed hose which terminated to a bucket. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 13:45 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 14:45 0.1/0/0 300 0 View gauges 14:45 0.1/0/0 300 0 Open valve to flow meter; gas bled down in 20sec 14:50 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 15:50 0.14/0/0 300 0 View gauges 15:50 0.14/0/0 300 0 Open valve to flow meter; gas bled down in 20sec 15:55 0/0/0 0 0 Closed valve downstream of test gauge to monitor for 1 hr 16:55 0.14/0/0 300 0 View gauges 16:55 0.14/0/0 300 0 Open valve to flow meter; gas bled down in 20sec ' Pressures are T/IA/OA Summary: There was no liquid on any of the bleed downs. TBU K-19 exhibited the characteristics for a no-flow determination. Attachments: Photos (3) : .M4 JUL 2 7 2016 2016-0113 No-Flow TBU K-19 bb.doxc Page 1 of 3 • . No Flow Test— TBU K-19 (PTD 1740080) Photos by AOGCC Inspector B. Bixby 1/13/2016 f xx ¢¢ 4Y tk ;� IY • i 0;ii :41 1 .i. 4111101101 . ..,.. ,...„ . ...._ .....„ , .,,,........,, ,t . , . , :„..4... i 1.,. .-, .. , ilL 1' 1 I • ' .1 - N A . r1 2016-0113_No-Flow_TBU_K-19 bb.doxc Page 2 of 3 • • lion. f� f'Na . '11.1 ....V. ,'' t 74 *'i.. 1 1 4 ‘ * arm s . ,, ,, • ,� ' fix • _. , IIIIIIC: Ali11111111111mmiwatamamiimi. 444. .., ,-, ,, . „ yil. -:17 .......L .,-,_ ----,.. ,,, , , i ,/1 !1. ,,, , • r. i , L. 2016-0113_No-FlowTBU K-19 bb.doxc Page 3 of 3 • S Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, December 17, 2015 4:48 PM To: 'Dan Marlowe' Cc: Stan Golis;Juanita Lovett Subject: RE: K-19 PTD 174-008, Sundry 315-735 Dan, You have approval per this email to move the straddle packer top to 9400 ft as we discussed. The straddle will now cover from 9400 ft to the permanent packer at 12751 ft. The reason for higher packer depth was additional casing damage found uphole during the ongoing RWO operations. Update the MOC with this change and I will file this email in our system as documentation. Regards, Guy Schwartz Sr. Petroleum Engineer SCANNED SEP 2 0 2016 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.aov). From: Dan Marlowe [mailto:dmarlowe@hilcorp.com] Sent: Thursday, December 17, 2015 4:40 PM To: Schwartz, Guy L(DOA) Cc: Stan Golis; Juanita Lovett Subject: K-19 PTD 174-008, Sundry 315-735 Guy I received the Change Approved Program Approval for K-19 this afternoon, The only loose end we need to clear up is moving the isolation packer up to the 9400' range as we discussed—schematic attached Please advise Thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 0 • McArthur River Field, TBU PROPOSED Well: K-19 tnr�rn �l.�.k.,.t.l.t As Completed: Future If ikon) ra09bSee i«apm-tor CASING DETAIL KB SIZE WT GRADE CONN ID TOP BTM. r- r 24" BTC Surf 381' I 13-3/8" 61 K55 BTC 12.515 Surf 2,591' 9-5/8" 47 N80 BTC 8.681 Surf 2,591' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 JL95 BTC 8.835 3,576' 5,038' d 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' 7" 29 L80 BTC-KC 6.184 9,769' 13,756' 24"(4 "' TUBING DETAIL 3-1/2" I 9.3 I L 80 f Supermax I 2.992 I Surf I ±9,150' 4. ` 13-ate"-259V JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 ±9,300' Bottom of ESP Assembly ±9,397' 5.875 4.00 9-5/8"Tie-Back receptacle 2 ±9,400' 5.875 4.00 9-5/8"Packer ±9,405' 5.000 X/0 3 ±9,406' 4.250 3.958 4-1/2"12.604 1-80 IBT Tubing ±12,741' 4.500 X/O ±12,749' 4.500 X/O ±12,750' 3.750 2.401 3-1/4"Locator Tubing Seal Assembly w/lndexing Muleshoe Guide 4 12,751' 5.670 3.250 Baker Model D Perm Packer war 5 12,760' 4.500 3.428 Mesh Excluder Screen 01.T73EP 6 13,055' 3.500 - Bull Plug L. l I .. tPERFORATION DETAIL L" I '/Fns/ Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status WP 6.4 G-1 12,175' 12,193' 8,725' 8,738' 18' Isolated 1 G-1 12,203' 12,215' 8,745' 8,754' 12' Isolated G-1 12,223' 12,226' 8,760' 8,762' 3' Isolated ',.,.IIMIMlrIIIIIMg G-1 12,237' 12,250' 8,770' 778 13' Isolated HolieIIclisa G-3 12,373' 12,389' 8,868' 8,879' 16' Isolated G-4 12,411' 12,417' 8,895' 8,899' 6' Isolated 9759' 3 G-4 12,472' 12,482' 8,937' 8,944' 10' Isolated G-5 12,570' 12,580' 9,004' 9,010' 10' Isolated G-5 12,592' 12,644' 9,018' 9,053' 52' Isolated 11,017 G-5 12,594' 12,603' 9,020' 9,026' 9' Isolated 1~ G-5 12,610' 12,644' 9,030' 9,053' 34' Isolated . 0 iS G-5 12,651' 12,671' 9,057' 9,071' 20' Isolated -., G-5 12,676' 12,685' 9,074' 9,080' 9' Isolated 4 G-5 12,677' 12,716' 9,075' 9,100' 39' Isolated G-5 12,691' :12,714' 9,084' 9,099 23' Isolated A.-...., _. HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Pert d TCP '91&'02 5 HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perfd TCP '91&'02 -( HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' 6 HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perfd TCP '91' HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perf'd TCP'91 &50"02 Eef06 HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64"02 I' HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) r1 ',I_1HB-7 Milled Baker 'FB-1'Perm Packer,Baker SBE,XO, Pup jt,XO, FISH 13,388 PB1D=13,713' 1D=13,771' MAX EANGLE_51��, Camco WP-1 Nipple,XO,Pup,WLEG 1. 13,420 20.50 Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. OCTG Rotating Hours 2. 13,441 1.53 24" 58 Rotating HoursCamco"D"Nipple.Plug set on 1/29/92 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: ill 12/16/15 Tubing 0 Rotating Hours • 1111 OF • w \I%%i SA THE STATE Alaska Oil and Gas of/\ J ®AsKA Conservation Commission .wtsi}t= ==-_ _�y- _ 333 West Seventh Avenue - GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Managersr3/ 0 a Hilcorp Alaska, LLC 17 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock and Middle Kenai G Oil Pools, TBU K-19 Sundry Number: 315-735 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. oerster Chair DATED this IS'day of December, 2015 Encl. 1.0 Ms� moo 0 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Cl'' 't i. (3(k2 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture;( Stimulate ❑ Repair Well Li Operations shutdown❑ & Suspend ❑ Perforate ❑ , Ther Stimulate ® Pull Tubing ❑ Change Approved Program Li • Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Isolate Perls 0• 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC ' Exploratory ❑ Development 0, 174-008 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service Li 6.API Number Anchorage,AK 99503 50-733-20259-00 . 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 / Trading Bay Unit K-19 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0018777 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 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): 13,771 9,802 13,055 • 9,323 • 0 psi 13,055& 13,441 13,388 Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.3#/L-80 9,335 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers(x4)See Schematic&SSSV Packers(x4)394'(MD)394'(TVD) 12,751'(MD)9,123'(TVD)13,388'(MD)9,551'(TVD) 13,420'(MD)9,572'(TVD)&SSSV 339'(MD)339'(TVD), 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: In progress under Sundry#315-515 OIL 0. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ 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 Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature W Phone (907)777-8356 Date CZ- ( 1 ( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -3 ^ � 1 6- Plug Integrity ❑ BOPIlTest TV Mechanical Integrity Test ❑ Location Clearance ❑ 2 : v Other: -V- o p 3 c 4 o P �¢ \110 ,V-C-i OS Post Initial Injection MIT Req'd? Yes ❑ No ❑ �,/ ikelp Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O— 'e / 9{ Approved by: f APPROVED BY COMMISSIONER THE COMMISSION Date: IZ-/S-/5_ ''Kd i ( y (Z f5--.t f PRIG Submit Form and 0RI o Form 10-403 Revised 11/2015 r p I alid for 12 months from the date of appro Attachmentss in Duplicate . -/ V/C/ - • • Well Prognosis Well: K-19 Ililcoru Alaska,LL Date: 12/07/2015 Well Name: K-19 API Number: 50-733-20259-00 Current Status: Oil producer(ESP) Leg: Leg#1 (NE) Estimated Start Date: 12/07/15 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 174-008 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 2,860 psi @ 9,479'(6,857'TVD) 0.417 lbs/ft(8.03 ppg)from downhole gauge on ESP Maximum Expected BHP: 2,860 psi @ 9,479'(6,857'TVD) 0.417 lbs/ft(8.03 ppg)from downhole gauge on ESP Maximum Potential Surface Pressure:0 psi No-Flow Well(07/08/15)-will not flow based on an oil and water gradient of 0.417 psi/ft. Brief Well Summary The K-19 well is currently completed with an ESP which plugged with scale 08/13/15.This work over will replace the plugged pump and cleanout the well,and isolate the G-zone.The G-zone was added during the June 2015 workover and caused extreme scaling issues which plugged the ESP. (d Last Casing Test:06/11/2015 9,509'to 1,500 psi on chart for 30 minutes �/` ' /W g �i! � �� s 1� Brief Procedure: 1. MIRU Moncla Rig#404. 4 3 2. Kill well and circulate Hydrocarbon off of well through ESP or sliding sleeve. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low and 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. ars- Si 5- 6. Cleanout to top of screens at 12,760' circulate well clean with FIW. Attempt to pump through screens and acidize with Hydrochloric if needed, POOH. 7. PU and RIH with G-zone Isolation string setting packer at+/- 12,097' / 8. RIH and land ESP completion. y f, -4.61-4— 9. ND BOP, NU wellhead and test. ASS 10. Turn well over to production. 11. Conduct SVS and No-Flow tests per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed Revised 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. Acid Job Flow Diagram 7. RWO Sundry Revision Change Form • • • 14 McArthur River Field, TBU SCHEMATIC Well: K-19 As Completed: 06/20/2015 Hilcorp Alaska,LLC CASING DETAIL RKB to Sea Level(MLW)=100' KB 35' SIZE WT GRADE CONN ID TOP BTM. *,p, 24" BTC Surf 381' l 13-3/8" 61 K55 BTC 12.515 Surf 2,591' "�.„/ !a 1 9-5/8" 47 N80 BTC 8.681 . Surf 2,591' }s. ? 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' r°.,s +1' v; 9-5/8" 40 JL95 BTC 8.835 3,576' 5,038' '" : 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' ,113 '�s 2 -,, 7" 29 180 BTC-KC 6.184 9,769' 13,756' 24"@ 381 t 7? TUBING DETAIL -X 3 ` 3-1/2" I 9.3 L-80 I Supermax I 2.992 I Surf I 9,335' 13-3/8"-2591' JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 339' 5.180 2.813 SSSV 2 394' 8.500 2.980 Dual String Hydraulic Set Packer w/Vent valve 3 443' 4.500 2.813 X-Nipple 4 9,335' 5.130 Discharge t - _ 5 9,336' 5.130 - Pump(x4) 6 9,423' 5.130 - Intake 7 9,442' 5.620 - Motor 8 9,479' - - Bottom of ESP Assembly 9-5/8" 9 12,751' 5.670 3.250 Baker Model D Perm Packer CMT 7320' 10 12,760' 4.500 3.428 Mesh Excluder Screen �� s `,. 11 13,055' 3.500 - Bull Plug }. ,4 , I ;.J PERFORATION DETAIL r' 4 t� Zone Top(MD) Btm(MD) TOP(TVD) Btm(TVD) Ft Status *•3 ill 5 .1 G-1 12,175' 12,193' 8,725' 8,738' 18' 4-5/8"12 SPF&5 SPF Millennium Guns > �"' G-1 12,203' 12,215' 8,745' 8,754' 12' 4-5/8"12 SPF&5 SPF Millennium Guns r 6 p G-1 12,223' 12,226' 8,760' 8,762' 3' 4-5/8"12 SPF&5 SPF Millennium Guns { - "`_'` G-1 12,237' 12,250' 8,770' 8,779' 13' 4-5/8"12 SPF&5 SPF Millennium Guns 7 i 7 a G-3 12,373' 12,389' 8,868' 8,879' 16' 4-5/8"12 SPF&5 SPF Millennium Guns { 8 G-4 12,411' 12,417' 8,895' 8,899' 6' 4-5/8"12 SPF&5 SPF Millennium Guns s` ` •Hole in casing G-4 12,472' 12,482' 8,937' 8,944' 10' 4-5/8"12 SPF&5 SPF Millennium Guns ±'a •'J 9,509'-9,525' G-5 12,570' 12,580' 9,004' 9,010' 10' 4-5/8"12 SPF&5 SPF Millennium Guns `8769 G-5 12,592' 12,644' 9,018' 9,053' 52' Perf'd'94,95,&'02 w/TCP ani v v y, A. li1 '4 G-5 12,594' 12,603' 9,020' 9,026' 9' 4-5/8"12 SPF&5 SPF Millennium Guns S's +a G-5 12,610' 12,644' 9,030' 9,053' 34' 4-5/8"12 SPF&5 SPF Millennium Guns 9-5/8"10,047' ?` a,,, G-5 12,651' 12,671' 9,057' 9,071' 20' 4-5/8"12 SPF&5 SPF Millennium Guns ,„► - *- G-5 12,676' 12,685' 9,074' 9,080' 9' 4-5/8"12 SPF&5 SPF Millennium Guns 1444 1' G-5 12,677' 12,716' 9,075' 9,100' 39' Perf d'94,'02 w/TCP G-5 12,691' 12,714' 9,084' 9,099' 23' 4-5/8"12 SPF&5 SPF Millennium Guns 9 4 G 1-5 HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perf'd TCP'91&'02 HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-PerfdTCP '91&'02 " 1 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' 10 ;'s HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perfd TCP '91' "t, - C g., HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50"02 • ' 11 "+ HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64"02 i t". HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' * e r 'k e r,zr, HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 '/ , JV4 , -'/•`� HK HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) _ r� r7 HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) lIIIl ;'a1 ,' , E 4.;HB-7 FISH 13,388 Milled Baker 'FB-1'Perm Packer,Baker SBE,XO, Pup jt,XO, 7"-13,756;`- Cameo WP-1 Nipple,XO, Pup,WLEG PBTD=13,713 TD=13,771' MAX HOLE ANGLE=51 A2304' 1. 13,420 20.50 Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. 2. 13,441 1.53 Camco"0"Nipple.Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: JLL 07/16/15 Tubing 0 Rotating Hours • • • 111 McArthur River Field, TBU PROPOSED Well: K-19 HilcorpAlaska,LL(; As Completed: Future RKB to Sea Level(MLW)=100' CASING DETAIL KB 35' SIZE WT GRADE CONN ID TOP BTM. a 24" BTC Surf 381' .' 13-3/8" 61 K55 BTC 12.515 Surf 2,591' "+ ? 9-5/8" 47 N80 BTC 8.681 Surf 2,591' 99: " 40 N80 VTC 8.835 2,591' 3,576' 55/88: 40 1L95 BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' d r 7" 29 L80 BTC-KC 6.184 9,769' 13,756' 24"@381' TUBING DETAIL 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I ±9,335' L 13-3/8"-2591' JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 ±9,479' Bottom of ESP Assembly ±12,094' 5.875 4.00 7"Tie-Back receptacle 2 ±12,097' 5.875 4.00 7"26-32#Hydraulic Isolation Packer ±12,102' 5.000 2.992 X/O 4-1/2"LTC Box x 3-1/2"EUE Pin ±12,103' 4.500 2.992 X/0 Pup Joint,3-1/2"EUE Box x 3-1/2"Supermax Pin 3 ±12,111' 4.250 2.992 3-1/2"9.2#/L-80 Supermax Tubing ±12,741' 4.500 2.992 X/O Pup Joint,3-1/2"Supermax Box x 3-1/2"EUE Pin ±12,749' 4.500 2.441 X/O 3-1/2"EUE Box x 2-7/8"EUE Pin ±12,750' 3.750 2.401 3-1/4"Locator Tubing Seal Assembly w/Indexing Muleshoe Guide 1 9-,,r/3 4 12,751' 5.670 3.250 Baker Model D Perm Packer CMT 7320' 5 12,760' 4.500 3.428 Mesh Excluder Screen C 6 13,055' 3.500 - Bull Plug .mow +, PERFORATION DETAIL Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status G-1 12,175' 12,193' 8,725' 8,738' 18' Isolated " y G-1 12,203' 12,215' 8,745' 8,754' 12' Isolated G-1 12,223' 12,226' 8,760' 8,762' 3' Isolated +* 1 G-1 12,237' 12,250' 8,770' 8,779' 13' Isolated .,,.Hole in casing G-3 12,373' 12,389' 8,868' 8,879' 16' Isolated •';9,509'-9,525' G-4 12,411' 12,417' 8,895' 8,899' 6' Isolated • 9769G-4 12,472' 12,482' 8,937' 8,944' 10' Isolated 21, j, , G-5 12,570' 12,580' 9,004' 9,010' 10' Isolated 2 G-5 12,592' 12,644' 9,018' 9,053' 52' Isolated 9-5/8"10,047' ` G-5 12,594' 12,603' 9,020' 9,026' 9' Isolated •:'} ✓ G-5 12,610' 12,644' 9,030' 9,053' 34' Isolated 1 G-5 12,651' 12,671' 9,057' 9,071' 20' Isolated °` G-5 12,676' 12,685' 9,074' 9,080' 9' Isolated q G-5 12,677' 12,716' 9,075' 9,100' 39' Isolated G-5 12,691' 12,714' 9,084' 9,099' 23' Isolated - __-- HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-PerfdTCP'91&'02 5HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perfd TCP '91&'02 -. HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perf'd TCP '91' i4' 6 HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perf'd TCP '91' ''' _ HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perf'd TCP'91 &50"02 HK OE HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perf'd TCP'91 &64"02 I iii - HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perf'd TCP '91' $,„. , I� _r_'"'" HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) • I=• •' r HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) 1 ,HB7 7"-13,756p�. �+`.� _wiFo ',Z'5` '' Milled Baker 'FB-1'Perm Packer, Baker SBE,XO, Pup jt,XO, PBTD=13,713' TD=13,771' FISH 13,388 MAX HOLE ANGLE=51 Cry 2304' Camco WP-1 Nipple,XO, Pup,WLEG 1. 13,420 20.50 Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. OCTG Rotating Hours 2. 13,441 1.53 24" 58 Rotating Hours Camco"D"Nipple.Plug set on 1/29/92 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: JLL 12/07/15 Tubing 0 Rotating Hours King Salmon Platform . 11 K-19 Current Uilrarp alr.ka.l.l.{; King Salmon BHTA, B-11-A0, 4 1/16 5M FE Tbg hanger, OCT-UH-TC- BTC lift 24X133/8X95/8X4 % 1 R 1A ESP, 13X4 '/Z y and susp, w/4"Type H BPV profile, 3/8 cont control line port •.5 .. Valve, Swab, FMC 120, „4,-7,- 4 1/16 5M FE, HWO, i 60, EE trim �� U� �� Valve, Wing, OCT-120, 4 1/16 5M FE, w/Axelson AM oper, EE trim Valve, Wing, WKM M, N / C A __ 1__ 2 1/16 5M FE, HWO, ,, ,.A AA trim I ti- . • ,I J , Valve, Master, FMC120, �III. & - IMO. 4 1/16 5M FE, HWO, EE �` �' Valve, Wing, FMC-120, 4 1/16 5M s.SFE, HWO, EE trim CAL, /n 0\ Adapter, OCT-A5-ESP, 13 5/8 5M API hub X 4 1/16 5M stdd top,w/2- °91 � � / %control line exits, prepped w/OCT I 41 I= 400-4 pocket . : % .• • ' 1 Y 1 -\ .1-.'"• '40 : All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M "be . 2 1/16 5M FE OCT 20, API hub top X 13 3/8 BTC casing J.� o HWO �_ � a bottom, w/ 1-2 1/16 5M SSO on 1='`�� - �,_� lower section, 1-2 1/16 5M SSO :W.. .. �"''' on middle section, 3-2 1/16 5M z+ .�< SSO on upper section , IP \ 5 [i -. *-i-Tr ° internal lock in ass _140 ®• I A I" Valve, OCT-20, 3 1/8 2M 7� �, +. FE, HWO Starting head, OCT, 21 1/4 2M ri �� „. FE X 24" SOW,w/ 1-3 1/8 2M 1,�,� � if EFO, full set of lockpins • II I J 24" _ E 13 3/8" a 9 5/8" 4 ,/2,i • • Kirig Salmon Platform BOP Stack(Moncla) Hilrnrp:ttarkr,1.1.1: c o 111111 I 111 lel it 111 iii iii .--- 3.74' Shaffer 13 5/8 5M I i 1 111 11t 111 111 b cal 11111. 111 IfMI1 iii 1f1 - _ - H 1 I CI© _ _ ..._ Variable 2 7/8-5 467' Ff- � II ,FI 13 5/8-5000 i_. - 0 {k -�f _Blind Rams fit inn fill rte. __ Choke and Kill Valves 2 1/16 5M w/Unibolt connections for : - 1/11/19/ • 1911 hoses 2.00' JR11 I�• 135/8-5000 �Ort,ii 1 '1�II. 11I I_ Riser,13 5/8 5M FE X 13 5/8 5M API X13 hub 13.70' a u' •o O O U o u OOUQ o u o u o u u o u u o a or. - 6 0 . N CO O vi 10 N. 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Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment#1 Hilcorp Alaska,LLC- BOP Test Procedure: Moncla Rig 404,WO Program—Oil Producers,Water Injectors Pre Rig Move 1) Blow down well,bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips,mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots,notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry,proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks,notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry,proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing,pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 1st valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes,bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. 111 • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • 0 c20 � � k f Co2 o U — ® Ts § 2 E 0 o ali / 2 �� § m « � E a • co O C 2 a 2 k Q > 2 1 O. £ k < -D § / 2 A 0 © Y 1- e k -0 i2E \• .- ƒ 7 %• / � -0 ■ ■ R % 2 � 2 k 0 $ % % �>- E� z & X / @ k2 4. 4 — Z / o u w Q 2 e o ka IL 0 2cs CD__bt 0 C a 0 a) Cl) . O § Jc < _ W k = a) L. 2 -a 2 . - a) t c a) �$ § a) 0) § f / ) Cl) Jp 0 ILI § 2R § � § a. cL m .. Q ai Ca. < @ > o0. Xai § 2 _� ° 2 I— ® L. 2 / ) a E 6 0 x CO < IZ v . - - 0 El° CD ij CC o k0 a) / co E c >.o e 0. a. 0. co V 2 k9 < a • VOF 7,4, �w\1��X77,s� THE STATE Alaska Oil and Gas ti -�s ,' of T Conservation Commission -_ ____ r__:_ A J\ S}(J\ t>Ez 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .aTi�L' OF Main: 907.279.1 433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Dan Marlowe 0 L4._o oT Operations Engineer / Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 95503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU K-19 Sundry Number: 315-515 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. Sincerely, IL"'4)(4- Cathy P. Foerster ciLc- Chair 51- DATED tDATED this ?31 day of August, 2015 Encl. • RBDMS SEP 0 2 2015 RECEIVED STATE OF ALASKA An 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 4S 1-k APPLICATION FOR SUNDRY APPROVALS ,AO � 20 AAC 25.280 1 Type of Request Abandon Cl Plug Perforations❑ Fracture}Stimulate CI Pull Tubing CI Operations shutdown ❑ Suspend❑ Perforate ElOth�Y simulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Replace ESP 0 2 Operator Name 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development 0 174-008 3 Address 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20259-00 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 li Trading Bay Unit K-19 9.Property Designation(Lease Number) 10 Field/Pool(s): ADL0018777 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 13,771 9,802 13,055 9,323 13,055&13,441 13,388 Casing Length Size MD ND Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade: Tubing MD(ft) See Schematic See Schematic 3-1/2" 9.3#/L-80 9,335 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft): Packers(x4)See Schematic &SSSV Packers(x4)394'(MD)394'(TVD)12,751'(MD)9,123'(TVD)13,388'(MD)9,551'(ND)13,420' (MD)9,572'(ND)&SSSV 339'(MD)339'(ND) 12 Attachments. Description Summary of Proposal 0 13 Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ svelopment 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work 9/7/2015 Commencing Operations OIL 0 WINJ El WDSP❑ Suspended ❑ 16.Verbal Approval: Date GAS El WAG ❑ GSTO❑ SPLUG ❑ Commission Representative. GINJ El Op Shutdown ❑ Abandoned El 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Dan Marlowe Email dmarloweta-�hilcorp com Printed Name Dan Marlowe �r /y"��,�Tiiitllee Operations Engineer Signature... /-0-4.._..,_ e .,., rPhone - (907)28� Date 8/21/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number I c* Plug Integrity El BOP Test Ei Mechanical Integnty Test ❑ Location Clearance Cl Other r," UC) rs, &&%ee S it-- ( /443/1 _ 4 r ) Spacing Exception Required? Yes CINo Li Subsequent Form Required: /V — y e y APPROVED BY Q Approved byiktv„) / [�� — C9 COMMISSIONER THE COMMISSION Date. —3/_ /S— OR, 0 /� l / Submit Form and Form 10-403 Revised 5/2015v a p C i n iii444 P3Tid fOr 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: K-19 Hilcoru Alaska,LL Date:08/21/2015 Well Name: K-19 API Number: 50-733-20259-00 Current Status: Oil producer(ESP) Leg: Leg#1 (NE) Estimated Start Date: 09/07/2015 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 174-008 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: 2,860 psi @ 9,479'(6,857'TVD) 0.417 lbs/ft(8.03 ppg)from downhole gauge on ESP Maximum Expected BHP: 2,860 psi @ 9,479'(6,857'TVD) 0.417 lbs/ft(8.03 ppg)from downhole gauge on ESP Max.Anticipated Surface Pressure: 0 psi No-Flow Well(07/08/15)-will not flow based on an oil and water gradient of 0.417 psi/ft. Brief Well Summary The K-19 well is currently completed with an ESP which plugged with scale 08/13/15.This work over will replace the plugged pump and cleanout the well. Last Casing Test:06/11/2015 9,509'to 1,500 psig on chart for 30 minutes -r— Brief Procedure: 1. MIRU Moncla Rig#404. 2. Kill well and circulate Hydrocarbon off of well through ESP or sliding sleeve./ 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low and 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. Cleanout to top of screens at 12,760' circulate well clean with FIW.Attempt to pump through screens and acidize with Hydrochloric if needed, POOH. 7. RIH and land ESP completion. 8. ND BOP, NU wellhead and test. 9. Turn well over to production. 10. Conduct SVS and No-Flow tests per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. BOP Drawing 4. Wellhead Schematic Current/Proposed (Same) McArthur River Field, TBU II SCHEMATIC Well: K-19 As Completed: 06/20/2015 Hilcorp Alaska,LLC CASING DETAIL RKBtoSea Level(MUM=WO' K6 35' SIZE WT GRADE CONN ID TOP BTM. c . 24" BTC Surf 381' 13-3/8" 61 K55 BTC 12.515 Surf 2,591' j . 1 - 9-5/8" 47 N80 BTC 8.681 Surf 2,591' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 JL95 _ BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 _ BTC 8.681 5,038' 10,047' MEM 116=1 2 7" 29 L80 BTC-KC l 6.184 9,769' 13,756' 24"@381' , TUBING DETAIL 3 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I 9,335' d 13-3/8"-2591' JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 339' 5.180 2.813 SSSV _ 2 394' 8.500 2.980 Dual String Hydraulic Set Packer w/Vent valve 3 443' 4.500 2.813 X-Nipple 4 9,335' 5.130 - Discharge 5 9,336' 5.130 - Pump(x4) 6 9,423' 5.130 - Intake 7 9,442' 5.620 - Motor 8 9,479' - - Bottom of ESP Assembly , 9-5/8" 9 12,751' 5.670 3.250 Baker Model D Perm Packer CMT 7320' 10 12,760' 4.500 3.428 Mesh Excluder Screen 11 13,055' 3.500 - Bull Plug PERFORATION DETAIL r---- 4 Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status G-1 12,175' 12,193' 8,725' 8,738' 18' 4-5/8"12 SPF&5 SPF Millennium Guns 5 G-1 12,203' 12,215' 8,745' 8,754' 12' 4-5/8"12 SPF&5 SPF Millennium Guns Imorm g G-1 12,223' 12,226' 8,760' 8,762' 3' 4-5/8"12 SPF&5 SPF Millennium Guns G-1 12,237' 12,250' 8,770' 8,779' 13' 4-5/8"12 SPF&5 SPF Millennium Guns G-3 12,373' 12,389' 8,868' 8,879' 16' 4-5/8"12 SPF&5 SPF Millennium Guns 8 G-4 12,411' 12,417' 8,895' 8,899' 6' 4-5/8"12 SPF&5 SPF Millennium Guns Hole in casing G-4 12,472' 12,482' 8,937' 8,944' 10' 4-5/8"12 SPF&5 SPF Millennium Guns ,4, 9,509'-9,525' 6-5 12,570' 12,580' 9,004' 9,010' 10' 4-5/8"12 SPF&5 SPF Millennium Guns 9769' 6-5 12,592' 12,644' 9,018' 9,053' 52' Perf d'94,95,&'02 w/TCP 21 Z.. ihi.. G-5 12,594' 12,603' 9,020' 9,026' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,610' 12,644' 9,030' 9,053' 34' 4-5/8"12 SPF&5 SPF Millennium Guns 9-5/8"10,047' G-5 12,651' 12,671' 9,057' 9,071' 20' 4-5/8"12 SPF&5 SPF Millennium Guns =.---.• G-5 12,676' 12,685' 9,074' 9,080' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,677' 12,716' 9,075' 9,100' 39' Perf'd'94,'02w/TCP G-5 12,691' 12,714' 9,084' 9,099' 23' 4-5/8"12 SPF&5 SPF Millennium Guns 61-5 HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perf d TCP '91&'02 9 __ HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perf'd TCP '91&'02 �` 4 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' -- 1� HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perfd TCP '91' ♦ HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50' 11 HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64"02 HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 • , HK0-6 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) 1.11 / I=I;HB-7 7"-13,756 FISH 13,388 Milled Baker 'FB-1'Perm Packer,Baker SBE,XO, Pup jt,XO, Camco WP-1 Nipple,XO,Pup,WLEG PBTD=13,713' TD=13,771' 1. 13,420 20.50 MAX HOLE ANGLE=51 02304' Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. 2. 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: JLL 07/16/15 Tubing 0 Rotating Hours McArthur River Field, TBU 11 PROPOSED Well: K-19 As Completed: Future Hilcorp Alaska,LLC CASING DETAIL RKBtoSea Level(MLW)=100' KB 35' SIZE WT GRADE CONN ID TOP BTM. 24" BTC Surf 381' a] 13-3/8" 61 K55 BTC 12.515 Surf 2,591' 1 F 9-5/8" 47 N80 BTC 8.681 Surf 2,591' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 JL95 BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BTC 8.681 5,038' 10,047 2L 7" 29 L80 BTC-KC 6.184 9,769' 13,756' 24"@381' TUBING DETAIL 3 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I ±9,335' A 13-3/8"-2591' JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger E 1 ±339' SSSV 2 ±394' Dual String Hydraulic Set Packer w/Vent valve 3 ±443' X-Nipple 4 ±9,479' Bottom of ESP Assembly 5 12,751' 5.670 3.250 Baker Model D Perm Packer 6 12,760' 4.500 3.428 Mesh Excluder Screen 7 13,055' 3.500 - Bull Plug 9-5/8" CMT 7320' PERFORATION DETAIL i Zone Top(MD) Btm(MD) TOP(TVD) Btm(TVD) Ft Status G-1 12,175' 12,193' 8,725' 8,738' 18' 4-5/8"12 SPF&5 SPF Millennium Guns ii., G-1 12,203' 12,215' 8,745' 8,754' 12' 4-5/8"12 SPF&5 SPF Millennium Guns G-1 12,223' 12,226' 8,760' 8,762' 3' 4-5/8"12 SPF&5 SPF Millennium Guns r ' G-1 12,237' 12,250' 8,770' 8,779' 13' 4-5/8"12 SPF&5 SPF Millennium Guns G-3 12,373' 12,389' 8,868' 8,879' 16' 4-5/8"12 SPF&5 SPF Millennium Guns G-4 12,411' 12,417' 8,895' 8,899' 6' 4-5/8"12 SPF&5 SPF Millennium Guns 4 Hole in casing G-4 12,472' 12,482' 8,937' 8,944' 10' 4-5/8"12 SPF&5 SPF Millennium Guns c)'-9,509'-9,525' G-5 12,570' 12,580' 9,004' 9,010' 10' 4-5/8"12 SPF&5 SPF Millennium Guns 9769' G-5 12,592' 12,644' 9,018' 9,053' 52' Perfd'94,95,&'02 w/TCP 21 Ze...sh, G-5 12,594' 12,603' 9,020' 9,026' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,610' 12,644' 9,030' 9,053' 34' 4-5/8"12 SPF&5 SPF Millennium Guns 9-5/8"10,047' G-5 12,651' 12,671' 9,057' 9,071' 20' 4-5/8"12 SPF&5 SPF Millennium Guns .,.a G-5 12,676' 12,685' 9,074' 9,080' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,677' 12,716' 9,075' 9,100' 39' Perf d'94,'02 w/TCP G-5 12,691' 12,714' 9,084' 9,099' 23' 4-5/8"12 SPF&5 SPF Millennium Guns G 1-5 HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perf'd TCP'91&'02 5 HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perfd TCP'91&'02 i HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Pert d TCP '91' 6 HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Pert d TCP '91' -- HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50''02 7 HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64"02 ' = HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 4 , HK 0-6 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) I r-. - �I= I HB-7 7"-13756', FISH 13,388 , Milled Baker 'FB-1'Perm Packer,Baker SBE,XO, Pup jt,XO, r n .--1:'..h Camco WP-1 Nipple,XO, Pup,WLEG PBTD=13,713' TD=13,771' 1. MAX HOLE ANGLE=51 Cr@ 2304' 13,42020,50Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. 2. 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: .ILL 08/21/15 Tubing 0 Rotating Hours . ii King Salmon Platform K-19 Current Hilrurp:Uxirko.LU King Salmon BHTA, B-11-A0, 4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-19 '/z R ' 1A-ESP, 13X4 %/2BTC lift 24X133/8-195/8X4 and susp, w/4" Type H BPV profile, 3/8 cont control line port Valve, Swab, FMC 120, 7,-;"---.2).. G 4 1/16 5M FE, HWO, ►�'' ��, EE trim <iiimigt., Valve, Wing, OCT 120, 4 1/16 5M FE, w/Axelson AM oper, EE trim Valve, WinWKM-M, iIITYi 7 7111nrh1 i Valve, Master, FMC120, r ♦� "'" -■'`;� 4 1/16 5M FE, HWO, EE 00;;11. trim :11.. .. tr. ,4f �' 1 " Valve, Wing, FMC-120, 4 1/16 5M ;.I FE, HWO, EE trim off\- f Adapter, OCT-A5-ESP, 13 5/8 5M toAPI hub X 4 1/16 5M stdd top, w/2- 0 1/2 control line exits, prepped w/OCT • ,111 '— 400-4 pocket VI 4i, ! Alm ; di •,,e,..., i }2, 1 ,.... ,,, ., ; „..,,„.11,,,,, ,, .,— ,-,,,:," ii. „ ea. .. , ,,, , �Zia 1 All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M 11 .E ® 2 1/16 5M FE OCT-20, API hub top X 13 3/8 BTC casing 'ii; 6, (�� ,�.' 1 ,.i.�, HWO bottom, w/ 1 2 1/16 5M SSO on �" \., .jti :,'I: lower section, 1-2 1/16 5M SSO - = - on middle section, 3-2 1/16 5M -, .r a 1.1 SSO on upper section , IP 'J'' -, 9) internal lockpin assy �►Il.,�, °` `, ' 'I -- yip =i ,i, Valve, OCT-20, 3 1/8 2M Starting head, OCT, 21 %4 2M I = FE, HWO .;.., FE X 24" SOW, w/ 1 3 1/8 2M - "rim , imp EFO, full set of lockpins _ ,24" _ = 13 3/8" J9 5/8" 4 1/2" Kling Salmon Platform BOP Stack(Moncla) IIuIt•i,rp tla<I.,I.I.I.( 0 0 l (T�l fel [fll fTfl T1L ...-- 3.74'3.74' Shaffer ^ 135/8SM (Ii n(Til fit If III III1!I III III I CIW-U Variable 27/8-5 4.6T :1E11�111�� IIP 72 2 - �__ SL /f� I I ' - _ �-{ 13 5/8-5000 Ai if _Blind Rams III til 111111 111 Choke and Kill Valves 21/16 SM w/Unibolt connections for hoses !III IW11 111 III . '41!",` 2 I ')f Qe (`7"1:1% ' j .l��ii: ■,t—_",.1:1% ' 111 Ill Ill 111 ill , Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 13.70' Moncla Rig 404 BOP Test Procedure Hiicari�ni,Fk,,IAA Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, King Salmon WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure • Moncla Rig 404 BOP Test Procedure Hilrm•p Alaska,I.Lf. Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure ,,;,cor!, �,n.k,.,.,.,: Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4,9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6, 9. After test,open valves 5& 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. ("OF TyTHE STATE Alaska Oil and Gas ofLASIc:A Conservation Commission � - A wet _-# ` --- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OF ALASY'' Fax 907.276 7542 cCI *13 www.aogcc alaska gov Dan Marlowe Operations Engineer I 74. Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur Field, Hemlock&Middle Kenai G Oil Pools, TBU K-19 Sundry Number: 315-496 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. Sincerely, Cathy P. oerster Chair DATED this /3y of August, 2015 Encl. • RECEIVED STATE OF ALASKA ,,Aiii 12 2UlJ vr--s 8'13113 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1 Type of Request' Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate (Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2 Operator Name 4 Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development 0 174-008 • 3 Address 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 9950350-733-20259-00 • 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❑ Trading Bay Unit K-19 ' 9.Property Designation(Lease Number) 10 Field/Pool(s) ADL0018777 McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft) Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured) Junk(measured)' • 13,771 -9,802 - 13,055 - 9,323 13,055&13,441 13,388 Casing Length Size MD TVD Burst Collapse • Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation Depth MD(ft)' Perforation Depth TVD(ft). Tubing Size: Tubing Grade' Tubing MD(ft) See Schematic I See Schematic 3-1/2" 9 3#/L-80 9,335 Packers and SSSV Type' Packers and SSSV MD(ft)and TVD(ft) , Packers(x4)See Schematic &SSSV Packers(x4)394'(MD)394'(TVD)12,751'(MD)9,123'(TVD)13,388'(MD)9,551'(TVD)13,420' (MD)9,572'(TVD)&SSSV 339'(MD)339'(TVD) 12.Attachments Description Summary of Proposal 0 13.Well Class after proposed work Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ nvelopment 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/27/2015 Commencing Operations' OIL LI, WINJ ❑ WDSF❑ Suspended ❑ 16.Verbal Approval Date GAS ❑ WAG ❑ GSTO❑ SPLUG ❑ Commission Representative GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature 2),, ,,.ycyc— Phone (907)283-1329 Date 8/12/2015 COMMISSION USE ONLY Conditions of approval' Notify Commission so that a representative may witness Sundry Number: 31' - '-I4c( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes Cl No LJ Subsequent Form Required: /0 .,4.1C Y APPROVED BY Approved by. /24„,„„..._ COMMISSIONER THE COMMISSION Date 5—/3 vs— ?i shahs- y/3-/s- z---- 1 j_/L— R G A Lalid l3//� Submit Form and Form 10-403 Revised 5/2015 O ' /[ppro0edla pli anon for 12 months from the a e f a royal.` Attachments in Duplicate RBDMS,c AUG 1 4 2015 • 14 Well Work Plan Well: K-19 Date:08/11/2015 Well Name: K-19 API Number: 50-733-20259-00 Current Status: ESP Lifted Producer Leg: Leg#1 NE Corner Estimated Start Date: August 27,2015 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 174-008 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 2850 psi @ 6,857' TVD ESP Intake Gauge SIBHP Maximum Expected BHP: 4850 psi @ 6,857' TVD (ESP intake Gauge). Well SIBP of 2850 psi plus 2000 psi pump pressure. Max. Anticipated Surface Pressure: 2,000 psi treatment pump pressure limit Well Summary The K-19 is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has decreased substantially since the June 2015 work over. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,000 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump 1320 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 990 gallons of Xylene. c. Pump 4,500 gallons of±15% Hydrochloric Acid d. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with >_150 barrels of FIW for displacement. 5. Shut down pump and let acid soak for >_4 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. As-built Schematic McArthur River Field, TBU SCHEMATIC Well: K-19 As Completed: 06/20/2015 Hilcorp Alaska,LI.0 CASING DETAIL RKBto Sea Level'MLW)=100' KB 35' SIZE WT GRADE CONN ID TOP BTM. 24" BTC Surf 381' 13-3/8" 61 K55 BTC 12.515 Surf 2,591' 1 9-5/8" 47 N80 BTC 8.681 Surf 2,591' ' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 J135 BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BIC 8.681 5,038' 10,047' A - 2 Q 29 L80 BTC-KC 6.184 9,769' 13,756' 24"@381' TUBING DETAIL x 3 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I 9,335' 4 13-318"-2591' JEWELRY DETAIL _ NO. Depth _ OD _ ID Item ___ _35' _ Tbg Hanger 1 339' 5.180 2.813 SSSV 2 394' 8.500 2.980 Dual String Hydraulic Set Packer w/Vent valve 3 443' 4.500 2.813 X-Nipple 4 9,335' _ 5.130 Discharge 5 9,336' _ 5.130 - Pump(x4) 6 9,423' 5.130 - Intake 7 9,442' 5.620 - Motor 8 9,479' - - Bottom of ESP Assembly 9-518" 9 12,751' 5.670 3.250 Baker Model D Perm Packer CMT 7320' 10 12,760' 4.500 3.428 Mesh Excluder Screen 11 13,055' 3.500 - I Bull Plug • h PERFORATION DETAIL , i- - I 4 Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status w:, G-1 12,175' 12,193' 8,725' 8,738' 18' 4-5/8"12 SPF&5 SPF Millennium Guns �'`.. 5 G-1 12,203' 12,215' 8,745' 8,754' 12' 4-5/8"12 SPF&5 SPF Millennium Guns ); 6 G-1 12,223' 12,226' 8,760' 8,762' 3' 4-5/8"12 SPF&5 SPF Millennium Guns h1 --. I G-1 12,237' 12,250' 8,770' 8,779' 13' 4-5/8"12 SPF&5 SPF Millennium Guns 7 G-3 12,373' 12,389' 8,868' 8,879' 16' 4-5/8"12 SPF&5 SPF Millennium Guns Irfi 8 G-4 12,411' 12,417' 8,895' 8,899' 6' 4-5/8"12 SPF&5 SPF Millennium Guns �, Hole in casing G-4 12,472' _ 12,482' 8,937' 8,944' 10' 4-5/8"12 SPF&5 SPF Millennium Guns r, 8 9,509'-9,525' G-S 12,570' 12,580' 9,004' 9,010' 10' 4-5/8"12 SPF&5 SPF Millennium Guns 9769' ZG-5 12,592' 12,644' 9,018' 9,053' 52' Perfd'94,95,&'02 w/TCP G-5 12,594' 12,603' 9,020' 9,026' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,610' 12,644' 9,030' 9,053' 34' 4-5/8"12 SPF&5 SPF Millennium Guns 9-5/8"10,047' _ G-5 12,651' 12,671' 9,057' 9,071' 20' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,676' 12,685' 9,074' 9,080' 9' 4-5/8"12 SPF&5 SPF Millennium Guns G-5 12,677' 12,716' 9,075' 9,100' 39' Pea'd'94,'02w/TCP G 15 G-5 12,691' 12,714' 9,084' 9,099' 23' 4-5/8"12 SPF&5 SPF Millennium Guns 9 } HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perfd TCP '91&'02 ' HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perfd TCP '91&'02 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' - 10 HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perfd TCP '91' • = HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50''02 _- 11 HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perfd TCP'91 &64''02 • HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 iii ' HK 0-6 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) IMI- • ri - O.HB-7 7"-13,756 L' FISH 13,388 Milled Baker 'FB-1'Perm Packer, Baker SBE,XO, Pup jt,XO, T Camco WP-1 Nipple,XO, Pup,WLEG PBTD=13,713' TD=13,771' 1. 13,420 20.50 MAX HOLE ANGLE=51(a-2304' Baker Model'D'Perm Pkr, 5'MOE,XO&3-1/2"Pup Jt. 2. 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: JLL 07/16/15 Tubing 0 Rotating Hours • ti OF T�� w\��yr,44, THE STATE Alaska Oil and Gas of Conservation Commission sa- ALASI�;A Witt `,_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � ;. Main: 907.279.1433 OF ALAS14Q' Fax: 907.276.7542 www.aogcc.alaska.gov August 6, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC "' P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit K-19 SCS AUG 1 3 2033 PTD 1740080 Dear Mr. Golis: On July 8, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit K-19 located on the King Salmon Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit K-19 prior to the test. The well performance was monitored for three hours with resulting flow rates (oil and gas) below the regulatory limits,passing the no-flow test. A fail-safe automatic surface safety valve system 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 Trading Bay Unit K-19 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 King Salmon Platform. Sincerely, Cfce4itti g James B. Regg / Petroleum Inspection upervisor cc: P. Brooks AOGCC Inspectors , STATE OF ALASKA AL KA OIL AND GAS CONSERVATION CON, ,SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑I Operations shutdown ❑ Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Re-enter Susp Well❑ Other: Replace ESP 0 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 174-008 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20259-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0018777 Trading Bay Unit K-19 r 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 13,771 feet Plugs measured 13,055&13,441 feet 'E C E I V E b true vertical 9,802 feet Junk measured13,388 feet JUL 1 7 20i5 Effective Depth measured 13,051 feet Packer measured 394;12,751;13,388; feet AO w CC 13,420 true vertical 9,320 feet true vertical 394;9,123;9,551; feet 9,572 Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet �� r1 True Vertical depth See Schematic feet SCAHNE© AUG Q�N15 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,335'(MD) 6,764'(TVD) Packers and SSSV(type,measured and true vertical depth) Packers(x4)-See Schematic SSSV 339'(MD)/339'(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: 132 111 3553 55 55 Subsequent to operation: 144 110 4752 63 58 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory❑ DevelopmentR 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: 315-250 Contact Ted Kramer Email tkramer(c7hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature -</1‹,, Phone (907)777-8420 Date 7/17/2015 - Art .,.. ..--,,-,.NINA, I McArthur River Field, TBU II SCHEMATIC Well: K-19 HilcorpAlaska,LLC As Completed: 06/20/2015 RKBtoSea Level(MLNI)=100 CASING DETAIL KB 36' SIZE WT GRADECONN ID TOP BTM. 1-v - ! 24" BTC Surf 381' e 13-3/8" 61 K55 BTC 12.515 Surf 2,591' ?'� . 1 9-5/8" 47 N80 BTC 8.681 Surf 2,591' A. `.. 'ti.!. 9-5/8" 40 _ N80 VTC 8.835 2,591' 3,576' / It '4 y 9-5/8" 40 1195 BTC 8.835 3,576' 5,038' v*, tC, 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' q r 2 7" 29 L80 BTC-KC 6.184 9,769' 13,756' i 41/24"@ 38n i TUBING DETAIL ix 3 ii., 3-1/2" I 9.3 I L-80 I Superman I 2.992 I Surf I 9,335' 13318"-2591' JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 339' 5.180 2.813 SSSV 2 _ 394' 8.500 2.980 Dual String Hydraulic Set Packer w/Vent valve"V 3 443' 4.500 2.813 X-Nipple 4 9,335' 5.130 - Discharge 5 9,336' 5.130 - _ Pump(x4) 6 9,423' 5.130 - Intake 7 9,442' 5.620 - _ Motor 8 9,479' - - Bottom of ESP Assembly 9318" 9 12,751' 5.670 3.250 Baker Model D Perm Packer✓ CMT7320' 10 12,760' 4.500 3.428 Mesh Excluder Screen '� i..-X.' 11 13,055' 3.500 - Bull Plug y } (,J PERFORATION DETAIL ,._ 4 !; Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status 4 +1 G-1 12,175' 12,193' 8,725' 8,738' 18' 4-5/8"12 SPF&5 SPF Millennium Guns t.i't 1161 G-1 12,203' 12,215' 8,745' 8,754' 12' 4-5/8"12 SPF&S SPF Millennium Guns it6 14 G-1 12,223' 12,226' 8,760' 8,762' 3' 4-5/8"12 SPF&5 SPF Millennium Guns e7 `- 't" G-1 12,237' 12,250' 8,770' 8,779' 13' 4-5/8"12 SPF&S SPF Millennium Guns ., 7 G-3 12,373' 12,389' 8,868' 8,879' 16' 4-5/8"12 SPF&5 SPF Millennium Guns .1, G-4 12,411' 12,417' 8,895' 8,899' 6' 4-5/8"12 SPF&S SPF Millennium Guns 1.- 8s Hole in casing G-4 12,472' 12,482' 8,937' 8,944' 10' 4-5/8"12 SPF&5 SPF Millennium Guns + •• 4 9,509'-9,525' G-5 12,570' 12,580' 9,004' 9,010' 10' 4-5/8"12 SPF&5 SPF Millennium Guns 9769 J G-5 12,592' 12,644' 9,018' 9,053' 52' Perf d'94,95,&'02 w/TCP , 4 G-5 12,594' 12,603' 9,020' 9,026' 9' 4-5/8"12 SPF&5 SPF Millennium Guns ,( * c± G-5 12,610' 12,644' 9,030' 9,053' 34' 4-5/8"12 SPF&5 SPF Millennium Guns 95/8"10,047' ' .o,'. G-5 12,651' 12,671' 9,057' 9,071' 20' 4-5/8"12 SPF&5 SPF Millennium Guns „y1 s ?''� G-5 12,676' 12,685' 9,074' 9,080' 9' 4-5/8"12 SPF&5 SPF Millennium Guns �' G-5 12,677' 12,716' 9,075' 9,100' 39' Perfd'94,'02w/TCP a. G 15 G-5 12,691' 12,714' 9,084' 9,099' 23' 4-5/8"12 SPF&5 SPF Millennium Guns HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-Perf'd TCP '91&'02 9 t".4,1 - `� HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perf'd TCP '91&'02 ke, - •4 HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perfd TCP '91' 10 j's HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perf'd TCP '91' j j ��t. HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perfd TCP'91 &50''02 ilt 11 ( HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-pert d TCP'91 &64''02 l%,11- HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perfd TCP '91' ,�t � ,' HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 , S „ '�_ ' tHKO-6 HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) Aaa ' HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) "1' 11.1 , ' I€1 HB-7 7"-13,756; FISH 13,388 Milled Baker 'FB-1'Perm Packer,Baker SBE,XO, Pup jt,XO, 17.0 Itelillkilr.11410,-2. Camco WP-1 Nipple,XO,Pup,WLEG PBTD=13,713' TD=13,756' MAX HOLE ANGLE=51 A2304' 1. 13,420 20.50 Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. 2. 13,441 1.53 Camco"D"Nipple.Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: JLL 07/16/15 Tubing 0 Rotating Hours Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 05/24/15-Sunday Continued rev circulating 1 1/2 hole volumes @ 3 BPM 1100 PSI (975 total bbls pumped- losing 15 bbls an hr) (75 bbls loss). Opened well and back side was giving fluid back but slowing down all the while- left well open. Raised derrick and prepped to scope out. Installed drill line and mounted driller's shack- scoped derrick out. Removed return hose and set BPV. N/D tree while securing all derrick lines to bases & beams. N/U 13 5/8" 5k Weatherford BOPE, Quadco finishing up calibration of monitors. 1700 hrs received Summit ESP recovery equipment onboard from M/V Discovery. R/U rig floor and continued tightening down BOPE attaching choke & kill lines+accum lines. Setup V-door, positioned tong power pack. Began spotting Summit equipment. Setup floor supports, hand rails and wind walls around rig floor. Hung McCoy tongs on floor. M/U 3 1/2" test jt w/ported sub, xo, side pump in, safety valve and IBOP. Screwed into hanger and began pretesting BOPE tightening flanges and greasing as needed. 05/25/15 - Monday Pulled BPV and decision was made to weight up .2 point to stop in-flow before proceeding. Sent NPFT to TB for active tank cleanout. Cleaned active tank sending fluids to TBPF. Filled tank w/200 bbls of FIW and began mixing NaCI at 4%to raise weight to 8.6#. Pushed 160 bbls of 8.6#4% NaCI LW to TBF at 1 3/4 BPM 1400#s (total 160 bbls). Shut-in well. Filled tank w/ 160 bbls of FIW and began mixing NaCI to raise weight to 8.6#. Pushed 160 bbls of 8.6#4% NaCI LW to TBPF at 1 3/4 BPM 1400#s (total 320 bbls). Shut-in well. Filled tank w/ 160 bbls of FIW and began mixing NaCI to raise weight to 8.6#. Pushed 160 bbls of 8.6#4% NaCI LW to TBPF at 1 3/4 BPM 1400#s (total 480 bbls). Shut-in well. Filled tank w/ 160 bbls of FIW and began mixing NaCI to raise weight to 8.6#. Pushed 160 bbls of 8.6#4% NaCI LW to TBPF at 1 3/4 BPM 1400#s (total 640 bbls). Shut-in well. Filled tank w/ 160 bbls of FIW and began mixing NaCI to raise weight to 8.6#. Pushed ^'106 bbls of 8.6#4% NaCI LW to TBPF at 1 3/4 BPM 1400#s. 05/26/15 -Tuesday Finished pumping remainder of 8.6#4% NaCI for a total pushed to TBPF of 800 bbls. Shutdown pump and opened well. No flow on TB/flow on casing (shut-in casing and flow on TB). Decision was made to set 2-way in hanger. Left casing open with monitor. Cameron set 2-way check. R/U 4 1/2" test jt w/bleeder sub on btm-side pump in, safety valve and ('n IBOP on top. R/U test lines and performed body test purging air out of system. Tested BOPE to 250#s/low 2500#s/high (as per Sundry) according to Hilcorp and AOGCC requirements with 3 1/2" &4 1/2" tbg-following Moncla 404 test . \ procedure. Performed accum draw-down check. Witness waived by Mr.Jim Regg, AOGCC, 13:30 hrs 25 May 15. B/O test jt and removed Cameron 2-way check. Screwed into hanger w/4 1/2" BTC jt w/safety valve & pump in. Shut-in well to monitor pressures. Mixed 180 bbls FIW w/ NaCI to 8.9#. 1700 hrs 20#s on TB- 25#s on 9 5/8". 1800 hrs 40#s on TB- 40#s on casing. No increase in pressure next 2 hrs. Circulated 8.9# FIW w/9% NaCI around until we got 8.9# back and well was stable. Opened well w/ no flow on either side. Prepared to pull hanger to surface and Moncla discovered that they did not have the correct size dies for their tongs. Called 301 for dies and lined up Knight's McCoy tongs. 05/27/15 -Wednesday Received borrowed 4 1/2" McCoy tong dies from 301. Watched well while waiting. Pulled hanger to surface weighing 96k. B/O hanger and N/U 13 5/8" x 11" 5k spool. Hung Summit sheaves and POOH w/297 jts of 4 1/2" 12.6# BTC production tbg. Broke down Schlumberger ESP completion to top of pumps, shaft locked up. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 05/28/15-Thursday Finished B/D Schlumberger ESP assem-finding that pumps were locked up and shaft was broken in se& assem (^'1' piece). RID Summit recovery equipment. Cleared and cleaned rig floor, BOPs and catwalk area. Packed up, off loaded Summit equipment and Schlumberger ESP tools. Slipped and cut 75' of drill line. On loaded 3 1/2" PH-6 workstring and Knight cleanout tools. M/U BHA#1 (8 1/2" rock Bit, 7" x 2 1/4" scraper f/9 5/8", 5 3/4" x 2" bit sub to workstring). TIH w/ BHA #1 picking up 3 1/2" 12.95# P-110 PH-6 workstring strapping and rabbiting to 6,191' (200 of est. 316 jts in hole). 05/29/15- Friday CONTINUE TIH WITH 9-5/8" CLEANOUT ASSEMBLY. P/U 3-1/2" 12.95# PH-6 TUBING FROM DECK.TAG @ 9,740 KB MEASUREMENTS WITH 10K DOWN. P/U TO 9,725'. R/U KELLY HOSE. BREAK CIRCULATION PUMPING DOWN TUBING TAKING RETURNS UP ANNULUS. PUMP 60 BBLS UNTIL OIL RETURNS STOPPED. LINE UP & REVERSE CIRCULATE (2)TUBING VOLUMES. SHUT DOWN PUMP & HAD GAS MIXED WITH 8.9# FIW RETURNS. REVERSE CIRCULATE (1) HOLE VOLUME (708 BBLS). OPEN WELL, WELL WAS STATIC. POOH WITH 3.5" PH-6 TUBING TO 1,260'. RIG DOWNTIME: MONCLA MCCOY TONGS BROKE BAND, REPAIR SAME. POOH WITH 3-1/2" TUBING. L/D 9-5/8" CLEANOUT ASSEMBLY. P/U BHA#2, (7" CLEANOUT ASSEMBLY), 6" MILL, BIT SUB, BUMPER JARS, (6)4-3/4" DRILL COLLARS, OIL JARS, &X-O.TOTAL BHA LENGH =- 205.75'.205.75'. 05/30/15 -Saturday SERVICE RIG & EQUIPMENT. CONTINUE P/U 7" CLEANOUT ASSEMBLY. TIH WITH 3-1/2" 12.95#TUBING FROM DERRICK TO 9,706'. INSTALL ADAPTOR FLANGE WITH HALLS HEAD RUBBER. P/U POWER SWIVEL& PREPARE TO BREAK CIRCULATION. BREAK CIRCULATION IN REVERSE, 3 BPM @ 620 PSI. ESTABLISH PARAMETERS, P/U WT= 98K, S/0 WT= 46K. WASH FROM 9,706'TO 9,740', ENTER LINER TOP AT 9,740' KB MEASUREMENT&WASH TO 9,745'. REVERSE CIRCULATE (1) HOLE VOLUME DUE TO ENTRAINED GAS IN FLUID. WASH F/9,740' - 9,945' REVERSE CIRCULATING @ 3 BPM @ 620 PSI. TAG SAME @ 9,945'. HALLS HEAD RUBBER FAILED SPRAYING FLUIDS ACROSS DECK. CLOSE HYDRIL& CONTINUE CIRCULATING. CLEAN UP OIL& FLUID FROM DECK. CHANGE OUT HALLS HEAD RUBBER. MILL THROUGH BRIDGE F/9,945'TO 9,947', REVERSE CIRCULATING @ 2.5 BPM & 550 PSI, 65 RPM @ 6500 FT/LBS TORQUE. BROKE THROUGH BRIDGE @ 9,947'. WASH F/9,947' - 10,047' REVERSE CIRCULATING @ 2.5 BPM & 550 PSI. L/D POWER SWIVEL TO BEGIN P/U &TIH WITH 3-1/2" TUBING OFF OF DECK. TIH WITH 3-1/2" TUBING F/10,048' T/10,088',TAG SAME. P/U POWER SWIVEL& BEGIN WASHING @ 0600 HRS. 05/31/15-Sunday WASH F/10,088' - 10233', REVERSE CIRCULATING 2 BPM @ 350 PSI. BEGAN GETTING FINE SCALE BACK ON RETURNS @ 10,233' & PACKING OFF. ATTEMPT TO BLOW OUT PLUG FROM TUBING WITH NO SUCCESS. R/D POWER SWIVEL& REMOVE HALLS HEAD. R/U MUD BUCKET& DRAIN HOSES. PREPARE TO POOH. POOH WITH 3-1/2" 12.95#TUBING (WET STRING)TO BHA. (3) DRILL COLLARS, (1) OIL JAR, & MILL PLUGGED WITH SCALE. CLEAN OUT BHA, UNABLE TO CLEAN (3) DRILL COLLARS, L/D SAME. TIH WITH 6" MILL, BUMPER JAR, OIL JAR, (3)4-3/4" DRILL COLLARS, X-O SUB. BHA LENGH = 114.96'. TIH WITH 3-1/2" 12.95#TUBING FROM DERRICK TO 10,142'. R/U POWER SWIVEL. INSTALL NEW HALLS HEAD RUBBER. BREAK CIRCULATION IN REVERSE PUMPING 2 BPM @ 375 PSI. WASH F/ 10142'-10173'. CLOSE HYDRIL& REVERSE CIRCULATE @ 3.5 BPM &800 PSI, CIRCULATING 1 HOLE VOLUME DUE TO TRIP GAS IN FLUID. MAX GAS 3200 UNITS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/01/15- Monday CONTINUE CIRCULATING GAS ENTRANED FLUID @ 10,173'.TOTAL OF 680 BBLS PUMPED IN REVERSE. WASH & REAM F/10,173'-10,762', REVERSE CIRCULATING 3.5 BPM @ 720 PSI, 45 RPM WITH 7000 FT/LBS TORQUE. GETTING FINE SCALE OVER SHAKERS. CIRCULATING BOTTOMS UP TO BUILD 8.9# FLUID VOLUME. BUILD 120 BBLS OF 8.9# BRINE FLUID. WASH & REAM F/10,762'-11,381', REVERSE CIRCULATING 3 BPM @ 625 PSI, 45 RPM @ 6500-7000 FT/LBS TORQUE, FINE SCALE &SAND RETURNS OVER SHAKER. MAX GAS= 1400 UNITS. LOSSES TO FORMATION DURING CIRCULATION =7BPH. TOTAL LOST LAST 24 HRS= 110 BBLS. REVERSE CIRCULATE PUMPING 2 BPM @ 275 PSI CLEANING WELL. BUILDING 8.9# BRINE FLUID & GENERAL HOUSEKEEPING TO POOH &SET STORM PACKER FOR BOPE TESTING.JOHNNY HILL WITH AOGCC TO WITNESS TEST. 06/02/15-Tuesday REVERSE CIRCULATE @ 3 BPM & 625 PSI TO POOH INSIDE OF 9-5/8" CASING TO TEST BOPE. BUILD 90 BBLS OF 8.9# BRINE &GENERAL HOUSEKEEPING WHILE CIRCULATING. POOH WITH 35 STANDS FROM 11,381'TO 9,193'. REMOVE 13-5/8" X 7. 1/16" ADAPTOR FLANGE, MEASURE &CALIPER HALLIBURTON 9-5/8" 47#STORM PACKER. P/U HALLIBURTON 9-5/8" 47# STORM PACKER &TIH WITH 5 STDS OF 3-1/2" PH-6 TUBING. SET STORM PACKER @ 284' BELOW TUBING HANGER WITH 42K DOWN PER HALLIBURTON PACKER REPRESENTATIVE. RELEASE F/STORM PACKER. POOH WITH 5 STDS& PREPARE TO TEST BOPE. P/U TEST ASSEMBLY&ATTEMPT TO LAND TEST PLUG. HYDRIL ELEMENT NOT FULLY RELAXING. CONTINUE WORKING ON ELEMENT, FOUND ELEMENT TO BE SWOLLEN &ORDER OUT REPLACEMENT HYDRIL. REMOVE SHAFFER TYPE ANNULAR& INSTALL 13-5/8" 5M HYDRIL ANNULAR. TEST BOPE TO 250 LOW & 2500 HIGH PER SUNDRY HOLDING ALL TEST ON CHART FOR 5 MINUTES.TEST GAS ALARM SYSTEMS AND PVT ALARMS (ALL OK).ALL TEST WITNESSED BY JOHNNY HILL WITH AOGCC.TESTED F/REMOTE & FUNCTION TESTED MAIN. L/D TEST ASSEMBLY. TIH TO 312', STING INTO STORM VALVE, RELEASE & POOH. L/D STORM PACKER SAME. N/U 13-5/8" X 7-1/16" ADAPTOR FLANGE. TIH WITH 3.5" 12.95#TUBING F/9,193"TO 10,864'. 06/03/15-Wednesday SERVICE RIG & EQUIPMENT. CONTINUE TIH F/10,864' - 11,350'. P/U POWER SWIVEL& INSTALL NEW HALLS HEAD RUBBER. BREAK CIRCULATION IN REVERSE PUMPING 2.0 BPM @ 500 PSI. WASH & REAM F/11,350' - 12,461', REVERSE CIRCULATING BOTTOMS UP EVERY 63' DUE TO DIME SIZED SCALE LOADING SHAKERS.TOTAL OF 115 BBLS LOST TO FORMATION LAST 24 HRS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/04/15 -Thursday WASH F/12,461' - 12,815', REVERSE CIRCULATING 2 BPM @ 450 PSI & CIRCULATING BOTTOMS UP EVERY 63' @ 3.5 BPM & 775 PSI. GETTING DIME SIZE SCALE OVER SHAKERS. TAG FILL @ 12,815'. MILL& REAM F/12,815' - 12,877', REVERSE CIRCULATING 2 BPM @ 500 PSI, 20 RPM W/7000-7500 FT/LBS TORQUE, CIRCULATING BOTTOMS UP EVERY CONNECTION WITH PEA SIZED GRAVEL ON RETURNS. UNABLE TO OBTAIN RPM WITH POWER SWIVEL @ 12,877', TAGGING & UNABLE TO WASH. CIRCULATE CFS-520 FRICTION REDUCER DOWN ANNULUS @ 1600 HRS. CONTINUE TO TRY& OBTAIN ROTATION WITH POWER SWIVEL WITH NO SUCCESS. RECEIVING MARBLE SIZED GRAVEL OVER SHAKERS. DISCUSS OPTIONS WITH HILCORP ENGINEER, DECISION MADE TO POOH & REMOVE DRILL COLLARS. ORDER OUT 5.5"JUNK MILL, CFS-520 FRICTION REDUCER, & 15 PALLETS OF SALT TO CLEAN DIRTY FLUID FROM WELL. L/D POWER SWIVEL. REMOVE HALLS HEAD RUBBER. PREPARE TO POOH. POOH W/3.5" 12.95#TUBING F/12,877' TO BHA, BREAKING TUBING ON OFF BREAK& DOPING CONNECTIONS. L/D 4-3/4" DRILL COLLARS& 6" MILL. MILL 10%WORN. RECOVERED (2) OLD PIECES OF CARBIDE PAD 2" IN LENGH. P/U 5.5"JUNK MILL WITH DEEP THROAT CIRCULATING PORT, BUMPER &OIL JAR. TOTAL BHA LENGH = 24.39'. TIH WITH 3.5" WORKSTRING FROM DERRICK. DEPTH @ 0600 HRS = 3,992'TOTAL OF 40 BBLS LOST TO FORMATION LAST 24 HRS. 06/05/15- Friday TIH W/3.5" 12.95#TUBING F/3,992' TO 12,557'. PUMP 130 BBLS OF DIRTY 8.9# FLUID FROM RIG TANKS TO TRADING BAY. CLEAN PITS& MIX 200 BBLS OF 8.9# BRINE FLUID TREATED WITH CFS-520 FRICTION REDUCER. TIH WITH 3.5" 12.95# TUBING F/12,557'T/12,862'. P/U POWER SWIVEL& INSTALL NEW HALLS HEAD RUBBER. MIX, PUMP, & DISPLACE 8.9# BRINE TREATED WITH CFS-520 FRICTION REDUCER @ 2 BPM & 700 PSI, SENDING ALL RETURNS TO TRADING BAY.TOTAL OF 893 BBLS DISPLACED FROM WELL. OBTAIN MILLING PARAMETERS, P/U WT= 96K, S/O WT= 60K, ROTATING WT= 82K, 40 RPM WITH 6500-7000 FT/LBS TORQUE, REVERSE CIRCULATING 2 BPM @ 500 PSI. MILL& REAM F/12,877'T/12,960', REVERSE CIRCULATING BOTTOMS UP BEFORE EACH CONNECTION, GETTING FINE GRAVEL&SAND ON RETURNS. LOSSES TO FORMATION AT 15BPH, TOTAL OF 60 BBLS LOST TO FORMATION LAST 24 HRS. 06/06/15-Saturday MILL F/12,960' - 12,991', REVERSE CIRCULATING 2.5 BPM @ 475 PSI, 45 RPM WITH 6500-7500 FT/LBS TORQUE, CIRCULATING BOTTOMS UP EVERY CONNECTION. GETTING BACK LARGE MARBLE SIZE ROCKS OVER SHAKER. UNABLE TO MILL REVERSING OUT @ 12,991' DUE TO LARGER ROCKS PACKING OFF TUBING. MILL F/12,991' - 13,053' PUMPING DOWN TUBING @ 2 BPM &400 PSI, 45 RPM WITH 6500-7000 FT/LBS TORQUE. MILLING 10' SECTIONS & REVERSING OUT ROCKS AFTER EVERY 10' OF HOLE MADE.TUBING BECAME PACKED OFF @ 13,053', UNABLE TO BLOW PLUG OUT. L/D POWER SWIVEL. REMOVE HALLS HEAD RUBBER. PREPARE TO POOH W/WET STRING. POOH W/3-1/2" 12.95#TUBING F/13,053' TO 8,116' WITH WET STRING. BEGAN HEARING NOISE FROM RIGHT ANGLE DRIVE. RIG DOWNTIME: FOUND KEY STOP PLATE ON MAIN CHAIN SPROCKET STRIPPED, BOLTS& KEY STOP WAS 3/4 OUT. AFTER FURTHUR INSPECTION, FOUND TWO GEAR TEETH INSIDE GEAR END OF RIGHT ANGLE DRIVE SHEARED. EXPEDITE MECHANICS, RIGHT ANGLE DRIVE, &WELDER. CUT RIGHT ANGLE DRIVE FREE, REMOVE & CURRENTLY DRESSING OFF TO INSTALL&ALIGN REPLACEMENT RIGHT ANGLE DRIVE. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/07/15 -Sunday RIG DOWNTIME: INSTALL RIGHT ANGLE DRIVE, ALIGN, &WELD SAME. POOH F/8,116'TO SURFACE WITH 3-1/2" 12.95# TUBING. BOTTOM JOINT OF TUBING, JARS, & MILL PLUGGED WITH SAND & ROCKS. MILL CIRCULATING PORTS PLUGGED WITH 2"X1" PIECES OF METAL WITH 2 PIECES OF BANDING MATERIAL INSIDE OF JARS. CLEAN OUT BHA & RIG FLOOR. PREPARE TO TIH. TIH WITH 3-1/2" 12.95#TUBING TO 13,024'. R/U POWER SWIVEL& INSTALL HALLS HEAD RUBBER. BREAK CIRCULATION PUMPING DOWN TBG @ 2.5 BPM &400 PSI, TAG FILL AT 13,045'. P/U TO 13,040' & REVERSE CIRCULATE BOTTOMS UP (89 BBLS) WITH FINE SCALE & FORMATION SAND OVER SHAKERS ON BOTTOMS UP. WASH F/13,045'TO 13,047', REVERSE CIRCULATING 2.5 BPM @ 450 PSI. MILL BECAME PACKED OFF. ATTEMPT TO BLOW MILL OUT PRESSURING UP TUBING TO 3500 PSI &WORKING PIPE WITH NO SUCCESS. L/D POWER SWIVEL. REMOVE HALLS HEAD. R/U MUD BUCKET& PREPARE TO POOH WET STRING. POOH WITH 3.5" 12.95#, WET STRING, DEPTH @ 0600 HRS = 7,713'.TOTAL OF 155 BBLS LOST LAST 24 HRS. 06/08/15- Monday POOH WITH 3-1/2" TBG F/7,713'TO SURFACE (WET STRING). FOUND LAST JOINT OF 3-1/2"TUBING,JARS, & MILL PACKED WITH SAND & GRAVEL. MILL HAD PIECE OF CANNON CLAMP PIN INSIDE ONE PORT& BANDING MATERIAL WITH LARGE ROCKS INSIDE OTHER THREE CIRCULATING PORTS. CLEAN OUT BHA SAME. MEASURE, CALIPER, & M/U BHA#5. 5- 1/2" OCEAN WAVE SHOE WITH FINGER BASKET INSERT, 5-1/2" WASH PIPE EXTENSION WITH UPPER BUSHING, X-O SUB, OIL& BUMPER JARS, X-O SUB. TOTAL BHA LENGH = 37.27'. TIH WITH 3-1/2" 12.95#TUBING TO 13,035'. R/U POWER SWIVEL& INSTALL HALLS HEAD RUBBER. BREAK CIRCULATION IN REVERSE PUMPING 3 BPM &425 PSI. WASH F/13,047' TO 13,055' REVERSE CIRCULATING @ 3 BPM & 500 PSI. CIRCULATE BOTTOMS UP @ 13,055' CONTINUOSLY PLUGGING SURFACE LINES WITH 1" -2" ROCKS. WASH FROM 13,055'TO 13,062', REVERSE CIRCULATING 3 BPM 500 PSI. REVERSE CIRCULATING BASKET BECAME PACKED OFF & FULL. SHUT PUMPS DOWN & PREPARE TO POOH. L/D POWER SWIVEL& REMOVE HALLS HEAD RUBBER. POOH WITH 3-1/2" TUBING F/13,062' TO 7000', TOTAL OF 245 BBLS OF 8.9 BRINE LOSS TO FORMATION LAST 24 HRS. 06/09/15 -Tuesday POOH WITH 3-1/2" PH-6 TUBING F/7,000'TO SURFACE. FOUND LARGE ROCKS WEDGED INSIDE TUBING 10 JOINTS ABOVE JARS. WASHPIPE FINGER BASKET RECOVERED 2" - 3-1/2" ROCKS INSIDE OF BASKET WITH FORMATION SAND & LARGE PIECES OF SCALE. CLEAN OUT BHA. BREAK DOWN JARS & X-O SUBS. CLEAN RIG FLOOR & WORKING AREA OF SAND DEBRIS. P/U HALLIBURTON 7" 26#TEST PACKER &TIH WITH 3-1/2" 12.95#TUBING TO 11,970'. P/U POWER SWIVEL& BREAK CIRCULATION PUMPING 1 BPM DOWN TUBING. SET PACKER @ 12,000' WITH 25K DOWN. ATTEMPT TO TEST CASING @ 12,000'TO 1500 PSI. HAD 500 PSI BLEED OFF IN 8 MINUTES. POOH ATTEMPTING TO TEST @ 11,970' & 11,939' WITH NO SUCCESS. R/D POWER SWIVEL. POOH TO 9,852' WITH 3-1/2" TUBING. P/U POWER SWIVEL&SET PACKER WITH 25K DOWN, ATTEMPT TO TEST CASING 118' BELOW LINER TOP WITH NO SUCCESS. R/D POWER SWIVEL& PREPARE TO POOH. POOH WITH 3-1/2" TUBING, DEPTH @ 0600 HRS=4,790'. BOPE TEST WITNESS WAIVED BY JIM REGG ON 6/9/15 @ 09:11 A.M. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/10/15-Wednesday POOH WITH 3-1/2" 12.95#TUBING F/4,790' TO SURFACE. BREAK& L/D 7"TEST PACKER. PACKER ELEMENTS ALL INTACT WITH NO WEAR. N/D 13-5/8" X 7-1/16" ADAPTOR FLANGE. P/U & LAND TEST ASSEMBLY. TEST BOPE PER SUNDRY, 250 LOW& 2500 HIGH ON CHART FOR 5 MINUTES. ALL TEST DONE WITH 3-1/2" TUBING. TESTED FROM REMOTE & FUNCTION TESTED MAIN PANEL. PERFORM KOOMEY DRAW DOWN TEST. L/D TEST ASSEMBLY& PREPARE TO TIH. P/U HALLIBURTON 9-5/8" 47#TEST PACKER &TIH WITH 3-1/2" TUBING, SETTING PACKER &TESTING CASING @ 5,510', 6,502', 7,495', & 8,484'TO 1500 PSI.ALL TEST GOOD. CURRENTLY TIH TO LINER TOP& PLAN TO TEST @ 9,695' 60 BBLS LOST TO FORMATION LAST 24 HRS. 06/11/15-Thursday e.,5y CONTINUE TESTING 9-5/8" 47#CASING. LOCATE HOLE BETWEEN 9,509'-9,525'. PRESSURED UP CASING TO 1500 LBS& HAD 300 LB BLEED OFF IN 10 MINUTES.TEST CASING @ 9,509'TO 1500 PSI ON CHART FOR 30 MINUTES, HELD SAME. POOH WITH 3-1/2" 12.95#TUBING F/9,509'T/SURFACE. L/D 9-5/8" TEST PACKER. PERMISSION GRANTED BY E-MAIL FROM GUY SCHWARTZ WITH AOGCC TO MOVE FORWARD WITHOUT REPAIRING CASING LEAK. CLEAN RIG FLOOR. PERFORM HOUSEKEEPING IN BOP AREA. MIX 60 BBLS OF 8.9# FLUID. CHANGE OUT ELEVATORS & SLIPS, SLIP & CUT 75' OF DRILL-LINE. PREPARE TO P/U TCP ASSEMBLY. HOLD PREJOB MEETING WITH HALLIBURTON RIG CREW. P/U HALLIBURTON TCP ASSEMBLY, 4-5/8" 12 SPF& 5 SPF MILLENIUM GUNS,TOTAL OF 183' OF LIVE SHOT. TOTAL BHA LENGH = 640.83'. TIH WITH 3-1/2" 12.95#TUBING, DRIFTING PIPE FROM DERRICK, DEPTH @ 0600 HRS= 2,000'. TOTAL OF 60 BBLS OF 8.9# FLUID LOST LAST 24 HRS. 06/12/15 - Friday SERVICE RIG & EQUIPMENT. CONTINUE TIH WITH 3-1/2" 12.95#TUBING FROM 2,000'TO 12,710', DRIFTING PIPE OUT OF DERRICK. SPACE OUT SETTING BOTTOM SHOT @ 12,714' KB MEASUREMENT. R/U POLLARD E-LINE. RIH WITH 1-11/16" GAMMA RAY& LOG F/12,020'TO 11,500'. P/U SPIKE @ 11,944', GAMMA SHOWING RADIOACTIVE SUB 71'TOO HIGH, POOH & LOWER STRING 71'. RIH WITH POLLARD E-LINE & LOG SAME. TOOL SHOWING FAULTY READINGS, PICKED UP SPIKE @ 11,944'. LOWER TOOL STRING &TAG @ 12,226'. GAMMA NOT READING RADIOACTIVE SUB. POOH & ORDER OUT GAMMA RAY FROM POLLARD. P/U BACKUP 1-11/16" GAMMA RAY, RIH & LOG ON DEPTH, P/U RA MARKER SUB @ 12,055' (40' DEEP). POOH WITH POLLARD E-LINE & R/D SAME. L/D 31'JOINT& P/U 9' ON STUMP HOLDING PIPE IN TENSION. DROP HALLIBURTON BAR &WAIT 8 MINUTES, GUNS FIRED PERFORATING INTERVALS F/12,175'TO 12,714'. MONITOR WELL, WELL WENT ON VACCUUM. POOH 3-1/2" TUBING & SPENT TCP ASSEMBLY, DEPTH @ 0600 HRS = 6,810', 70 BBLS LOST TO FORMATION LAST 24 HRS. 06/13/15 -Saturday CONTINUE POOH WITH 3-1/2" 12.95#TUBING F/6,810'TO SURFACE. L/D SPENT HALLIBURTON TCP ASSEMBLY (ALL SHOTS FIRED). CLEAN RIG FLOOR, LOAD OUT SPENT GUNS TO RACK, PREPARE TO P/U 7" CLEANOUT ASSEMBLY. P/U 5-1/2" JUNK MILL, BUMPER & OIL JARS, RA MARKER SUB, &X-O SUB. TIH WITH 3-1/2" 12.95#TUBING T/13,061'. STOP & CIRCULATE MIGRATED OIL FROM SURFACE @ 2,000' & 6,500'. R/U CIRCULATING HOSES, ATTEMPT TO REVERSE CIRCULATE @ 13,061', TUBING BEACAME PACKED OFF WITH POSSIBLE GUN DEBRIS. PRESSURE UP ON TUBING TO 3000 PSI, UNABLE TO BLOW PLUG OUT. R/U MUD BUCKET& PREPARE TO POOH. POOH LAYING DOWN 3-1/2" 12.95#TUBING F/13,061'TO 12,937'. TUBING BEGAN PULLING DRY.TOTAL OF 80 BBLS LOST TO FORMATION LAST 24 HRS. lif Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/14/15-Sunday POOH WITH WORK STRING DUE TO PACKED OFF TBG. L/D 33 JTS OF 3-1/2" 12.95#TUBING FOR WASHING. TUBING BEGAN PULLING DRY @ 12,937'. R/U CIRCULATING LINES, BREAK CIRCULATION PUMPING DOWN TBG @ 2 BPM & 250 PSI. SHUT DOWN PUMPS & LINE UP TO REVERSE OUT. REVERSE CIRCULATE (2) TBG VOLUMES PUMPING 3 BPM @ 500 PSI. RECEIVED FINE METAL SHAVINGS ON BOTTOMS UP. CONTINUE POOH, LAYING DOWN TUBING F/12,937'TO 12,101', TOTAL OF 33 JOINTS LAYED DOWN. N/U 11" X 7-1/16" HALLS HEAD FLANGE. INSTALL HALLS HEAD RUBBER, WIPER RUBBER, & P/U POWER SWIVEL. P/U POWER SWIVEL& BREAK CIRCULATION IN REVERSE PUMPING 2.5 BPM @ 275 PSI. WASH & REAM F/12,101'TO 13,041' REVERSE CIRCULATING 2.5 BPM @ 275 PSI, 80 RPM WITH 6500 FT/LBS TORQUE, REAMING EACH JOINT DOWN TWICE. GETTING SAND & GUN DEBRIS OVER SHAKERS.TAG FILL @ 13,041', ATTEMPT TO MILL& WASH. MILL ASSEMBLY CONTINUOUSLY ATTEMPTING TO PACK OFF& UNABLE TO MAINTAIN CIRCULATION. REVERSE CIRCULATE (2) TUBING VLOUMES @ 13,040' @ 2.5 BPM & 300 PSI. L/D POWER SWIVEL SAME. R/U POLLARD E- LINE. RIH & LOCATE RA MARKER SUB @ 13,052' (ELM CORELATED BACK TO OPEN HOLE LOG). LOG UP HOLE TO 11,800'. POOH WITH POLLARD & R/D SAME. TOTAL OF 340 BBLS OF 8.9# BRINE LOST TO FORMATION LAST 24 HRS. SENDING IN BOPE WITNESS NOTIFICATION TO AOGCC. 06/15/15 - Monday REVERSE CIRCULATE 1.5 TUBING VOLUME PUMPING 2.5 BPM @ 300 PSI. R/D CIRCULATING LINES, REMOVE HALLS HEAD RUBBER & PREPARE TO POOH. POOH WITH 3-1/2" 12.95#TUBING F/13,041'TO SURFACE. L/D JARS, RA MARKER SUB, & JUNK MILL. CLEAR CATWALK & CLEAN RIG FLOOR. CHANGE OUT ELEVATORS & PREPARE TO P/U SCREEN ASSEMBLY. HOLD PREJOB SAFETY MEETING WITH MONCLA CREW & BAKER PACKER TECH. P/U (1) 3.5" SLOTTED JT WITH BULL PLUG, (5) MEDIUM SCREEN JTS, (2) FINE SCREEN JTS,X-O SUB, BAKER MODEL "D" PERMANENT PACKER, PACKER RUNNING ASSEMBLY, & 3.71' PUP JT. TOTAL PACKER &SCREEN LENGH = 301.68'. TIH WITH 3-1/2" 12.95#TUBING, DRIFTING PIPE FROM DERRICK TO 9,740'. 06/16/15-Tuesday CONTINUE TIH, DRIFTING 3-1/2" 12.95#TBG OUT OF DERRICK FROM 9,740'. SPACE OUT, SETTING END OF BULL PLUG @ 13,051', TOP OF PACKER @ 12,750'. S/O WT= 55K, P/U WT= 103K. R/U PUMP LINES. BREAK CIRCULATION & DROP 1- 7/16" BALL& PUMP DOWN HOLE. BALL SEATED WITH 1500 PSI. P/U 10K OVER STRING WT& PRESSURE UP TO 2000 PSI. (SHEARED SAME SETTING PACKER). LOST 4K OF STRING WT INDICATING RELEASE OF PACKER &SCREEN ASSEMBLY. CONTINUE CIRCULATING, PUMPING 3.5 BPM @ 900 PSI. PUMP (1) HOLE VOLUME 803 BBLS, MAX GAS ON BOTTOMS UP = 3800 UNITS. BREAK DOWN CIRCULATING LINES& PREPARE TO POOH LAYING DOWN 3.5" 12.95#TBG. POOH L/D 3-1/2" 12.95#TBG. DEPTH @ 0600 HRS= 1,953'.TOTAL OF 358 JTS LAYED DOWN. LOSSES TO WELL LAST 24 HRS= 160 BBLS. Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date K-19 50-733-20259-00 174-008 5/24/15 6/20/15 Daily Operations: 06/17/15 -Wednesday FINISH POOH LAYING DOWN 3-1/2" 12.95#TBG, TOTAL OF 420 JTS. BREAK X-O SUBS & LAY DOWN BAKER RUNNING TOOL. P/U POWER SWIVEL& BREAK DOWN RENTAL SUBS. LOAD OUT& PREP POWER SWIVEL TO LOAD ON BOAT. N/D 13-5/8"X11" ADAPTOR FLANGE. P/U TEST ASSEMBLY& PREPARE TO TEST BOPE. TEST BOPE PER SUNDRY TO 250 LOW, 2500 HIGH.TESTED ANNULAR & PIPE RAMS WITH 3-1/2" TBG. ALL TEST HELD ON CHART FOR 5 MINUTES. PERFORMED KOOMEY DRAW DOWN &CHECKED PRESSURES ON BACKUP NITROGEN BOTTLES (6 @ 2200 PSI).TESTING PERFORMED FROM MAIN & FUNCTION TESTED REMOTE. BOPE WITNESS WAIVED BY JIM REGG ON 6/16/15 @ 12:24 HRS BY E-MAIL. L/D TEST ASSEMBLY. R/D FOSTER TONGS & R/U MCCOY TONGS. CLEAN RIG FLOOR & PREPARE TO P/U SUMMIT ESP. P/U SUMMIT ESP ASSEMBLY, CENTRALIZER ANODE, GAUGE, 562 SERIES 500HP MOTOR, LOWER & UPPER SEALS, INTAKE, (4) 513 SERIES 068 STAGE PUMPS, DISCHARGE SUB, PRESSURE SUB, X-O, 3-1/2" JT.TOTAL ESP ASSEMBLY LENGH = 146.34'. HANG FLATPACK & RIDA CABLE SHEAVES&TEST PUMP ASSEMBLY. P/U &TIH WITH 3.5" 9.2# L-80 SUPERMAX TUBING, DRIFTING PIPE FROM DECK. 06/18/15-Thursday Continued running in hole with Summit ESP Assem picking up new 3 1/2" 9.2# L-80 Supermax tubing, strapping and drifting same, checking cable insulation and readings every 1,000', placing clamps as needed. Spliced ESP cable at middle of jt#183 = 6,270'. Continued running in hole w/ ESP assem- 225 of 278 jts+ ESP assem in hole = 7,645'. 06/19/15 - Friday Continued running in hole with Summit ESP Assem picking up new 3 1/2" 9.2# L-80 Supermax tubing, strapping and drifting same, checking cable insulation and readings every 1,000', placing clamps as needed. M/U 2.813" X-Nipple w/ XOs on top of jt#267 (442' MD).Add #268 then M[U TriPoint Dual String Hydraulic Se pkr(394' MD)vd XQs and pups+ vent valve. Check readings and cut cable and lines, plumbed all thru pkr. Hooked up ctrl line to vent valve and functioned same. Added jt#269 and M/U SSSV w/ pups (339' MD). Hooked up ctrl line and functioned valve. Continued in hole with final 8 jts of production string, clamping ESP cable, flat pack and 2- control lines as needed. P/U landing jt w/SV and hanger. M/U to string, check, cut and plumb all cables and lines thru hanger. Landed hanger and ran in hold-down pins. R/U pump line and filled tbg. Dropped bar to seal plug in X-nipple. Pressured up to 3800#s and held for 30 mins, released pressure and lined up on the backside. Pressured up to 1000#s and pressure fill off. Pressured up again w/same results. R/D Summit and spotted Pollard SL. Lined up on tbg again and pressured up to 3800#s as per TriPoint and held for 40 mins, released pressure. Lined up on backside. 06/20/15-Saturday Pulled fluid level down in stack and determined that leak was around hanger. Discussed options with engineering and decision was made to N/D BOPs and install tree adapter in order to test pkr set. R/U Pollard SL w/full lubricator-TIH to X- Nipple at 442' and pull prong on 1st run and plug on 2nd run. R/D SL. B/O L/D landing jt. Cameron set BPV. Cleared and R/D floor. Bled down accum unit. N/D Hydril, pipe & blind rams, mud cross and riser. Found 8" of threads in top of tbg head plus majority of hanger seals rolled/torn off. Cleaned and prepped for tree adapter. Summit tested motor lead. Cameron plumbed ctrl lines thru adapter and mounted same. N/U tree w/ master valve minus wing valves. Tested casing (pkr set at 442') to 1500#s on chart for 30 mins w/SSSV& master valve open. Assisted production in completion of tree N/U. Set 2-way check and shell tested tree to 3500#s. Removed 2-way check. Turned well over to production. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg U 115 DATE: 7/08/2015 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector TBU K-19 Hilcorp Alaska LLC SCW4Eri I PTD 1740080 7/8/2015 I traveled to the Trading Bay Unit King Salmon Platform to witness a no-flow test. The rig-up observed was similar to others witnessed on Hilcorp-operated platforms in Cook Inlet. Flow exits the tree cap passing through the following equipment: '/Z-inch to 3/4- inch flow nipple; 3/-inch by 3/-inch flow Tee; 30psi calibrated test gauge on top; 3/-inch quarter turn valve; flow meter; and 1-inch diameter hose to a bucket with water. See attached picture of the rig-up. The following table shows test details: Time Pressures1 Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:30 0/0/0 0 0 valve closed 12:00 0/0/0 0 0 valve closed 12:30 0.1/0/0 <1 0 valve open; very little gas 13:00 0/0/0 <1 0 valve open; very little gas 13:30 0/0/0 0 0 valve open 14:00 0/0/0 0 0 valve open 14:30 0/0/0 0 0 valve open 1 Pressures are T/IA/OA Summary: Small volume of gas (unmeasurable) was observed when the well was open to the no-flow test meter. The gas flow stopped after 1 hour. Initial pressure when the valve was open bled to 0 psi in less than 1 minute. Attachments: Photo Test equipment certifcations 2015-0708_No-FlowTBU_K-19_jh.docx Page 1 of 2 jj Ilk ' t:i,,,, .444i, A'. , aril i {f' il / 1 r 1 t 1/4 4 c _ , • • 0 . .a --,.. 'it ‘t..,„ tr .. 't , 7'. L; 10 , ,,,,,,,,,„:„...›K,2...::::-i_.:,',,,,,,.... 1 2015-0708_No-Flow_TBU_K-19jh.docx Page 2 of 2 I z a u — Eon = —I lith m a o ■ } N g % d -, _. 1/7 ■ M \ c � 1iif n 0 is nn ■ © 0 zo k § - e § ■ ■ 411 . » § " 6 O. " « 2 - i J ` el a g 2 % , � 04. ESE § 1 m W ®® «\, /2 2 2 § � 11 ƒ ° K t b mi g g 51: 49 fit » © 2 ' 0 — @ © ® u c 0 0 su g § 2 gCIT E % 2 2 § ft -0 ■ ■ ® a 7 y u § p m Test Equipment 'traceable to MST _ Pressure range: , • -�/ / { • Date. - _ - ?7,E.SSURE ,'ND CA T 1ONL • • S‘'C. : = ' Test equipment S,'i1: +� expires in 90 days on - - - - . oontac Gina Bogart or Cathy Marshall at KGF X766-6825 'ORP CALIBRATION CERTIFICATE Test Equipment Traceable to NIST 3a..,.ge type: Pressure range: Date: TEST PRESSURE INDICATION Caiibrazed by: Test equipment S/N: _ _� __ This cert;: oate expires in 90 days on For recertificatiai, contact Gina Bogart or Cathy Marshall at KGF 776-6825. PrO X74 - o0 Loepp. Victoria T (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, May 29, 2015 1:54 PM To: Loepp,Victoria T (DOA) Cc: Juanita Lovett Subject: FW: K-19 Planned Program Change Sundry# 315-250, PTD 174-008 Attachments: K-19 Schematic 2015-05-29 Proposed w-Pkr.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, I received an out of Office response from Guy giving you as the backup for him. Please see the e-mail below. For your benefit, we rigged up on K-19 to replace a failed ESP. As we were rigged up to circulate the hydrocarbon off the well we discovered that the well wanted to flow. Because of this, we believe it would be prudent to install a packer and a SSSV in the well. Please let me know if you have any questions or concerns. Sincerely, Ted Kramer Sc.�►p�1E JUN 1 0 2015 Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 From: Ted Kramer Sent: Friday, May 29, 2015 1:42 PM To: Schwartz, Guy L(DOA) (Juy.schwartz@)alaska.gov) Cc: Dan Marlowe; Trudi Hallett; Juanita Lovett Subject: K-19 Planned Program Change Sundry # 315-250, PTD 174-008 Guy, I wanted to let you know of a program change for the above well. Since we had some difficulty killing the well, due to offset injection support, We have decided to run a high set packer in this well and an SSSV. With your approval,we will install this packer and not set it(like was done in K-26RD). If we perform the No flow test and the well passes,we will not set the packer. If it fails,we will run a plug with slick line and pressure up and set the packer. With the packer change, it is also necessary to change to 3-1/2" tubing instead of the 4-1/2"originally planned for. This way we can de-mobe the rig during the 14 day period while the well is stabilizing. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 McArthur River Field, TBU II PROPOSED Well: K-19 As Completed: Future Hi)eori 'Ia ka.I I CASING DETAIL RKB to Sea Level(MLVV)=100' KB 35' SIZE WT GRADE CONN ID TOP BTM 24" BTC Surf 381' 13-3/8" 61 K55 BTC 12.515 Surf 2,591' r'4 9-5/8" 47 N80 BTC 8.681 Surf 2,591' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 1L95 BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' Mili III= t::), 7" 29 180 BTC-KC 6.184 9,769' 13,756' 24"@381' x TUBING DETAIL 3-1/2" I 9.3 I L-80 I Supermax I 2.992 I Surf I ±9,290' 4 13.3/8"-2591' N. JEWELRY DETAIL NO. Depth OD ID Item 35' lbg Hanger 1 ±350' SSSV 2 ±380' Packer w/Vent valve 3 ±400' X-Nipple 4 ±9,482' Bottom of ESP PERFORATION DETAIL 9-5/8" op(MDBtm(MD) TOP(TVD) Btm(TVD) Ft Status CMT 7320' ., , ±12,175 ±12,193' ±8,725' ±8,738' ±18' Future G-1 ±12,203' ±12,215' ±8,745' ±8,754' ±12' Future G-1 ±12,223' ±12,226' 4,760' ±8,762' ±3' Future G-1 ±12,237' ±12,250' _3,770' ±8,779' ±13' Future G-3 ±12,373' ±12,389' ±8,868' ±8,879' ±16' Futur G-4 ±12,411' ±12,417' ±8,895' ±8,899' ±6' Future G-4 ±12,472' ±12,482' ±8,937' ±8,944' ±10' Future G-5 ±12,570' ±12,580' ±9,004' ±9,010' ±10' Future G-5 12,592' 12,644' 9,018' 9,053' 52' Perf'd'94,95,&'02 w/TCP (---- G-5 ±12,594' ±12,603' ±9,020' _ ±9,026' ±9' Future G-5 ±12,610' ±12,644' ±9,030' ±9,053' ±34' Future G-5 ±12,651' ±12,671' ±9,057' ±9,071' ±20' Future G-5 ±12,676' ±12,685' ±9,074' ±9,080' ±9' Future G-5 12,677 12,716' 9,075' 9,100' 39' Perf'd'94,'02 w/TCP 9769' G-5 ±12,691' ±12,714' ±9,084' ±9,099' ±23' Future G-7 ±12,810' ±12,830' ±9,162' ±9,175' ±20' Future L HK-0 12,808' 12,848' 9,160' 9,187 40' Re-Pert d TCP '91&'02 9-5/8"10,647' HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perf'd TCP '91&'02 a HK-1 ±12,885' ±12,890' ±9,211' ±9,214' ±5' ure -r+ HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perf'd TCP '91' HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-Perf'd TCP '91' t -`✓ Cal-7 HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perf d TCP'91&50"02 y"' L HK-3 ±13,063' ±13,087' ±9,328' ±9,344' ±24' Future - 1 HK-3 ±13,094' ±13,130' ±9,± ±9,374' ±36' Future .'..•1 HK-4 ±13,139' ±13,165' ±9,380 ±9,398' ±26' Future '1+i HK-4 13,157' 13,314' 9,392' 9,500' 157' Re-perf'd TCP'91 &64"02 '.4; HK-4 ±13,230' ±13,248' ±9,443' ±9,455' ±18' Future HK-4 ±13,259' ±13,271' ±9,462' ±9,471' ±12' Future '.' HK-4 ±13,300' ±13,312' ±9,490' ±9,499' ±12' Future HK 0-6 HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-Perf'dTCP'91' HK-5 ±13,342' ±13,360' ±9,519' ,2' ±18' Future HK-5 ±13,368' ±13,375' ±9,537' ±9,542' ±7' Future -'` HK-5 ±13,390' ±13,425' ±9,552' ±9,576' ±35' Future HK-6 ±13,460' ±13,495' ±9,599' ±9,623' ±35' Future . E AH8-7 HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 HK-6 ±13,502' 520' ±9,627' ±9,639' ±18' Future 7"-13,756' HK-6 ±13,526' ±13,540' ±9,643' ±9,652' ±14' -Hture PBTD=13,713' TD=13,756' HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) MAX HOLE ANGLE=51 0 2304' HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: 1LL 05/29/15 Tubing 0 Rotating Hours OF Ty $�w\�\ s� THE STATE Alaska Oil and Gas �� 16 OfA T 4 KA Conservation Commission ttistt�="att-:,‘---- 333 West Seventh Avenue GOVERNOR BILL WALKERi Anchorage, Alaska 99501-3572 OF ALAS°' �upNNED M r 1 4 ?0I Main: 907 279 1433 Fax 907 276 7542 www.aogcc alaska goy Dan Marlowe i 4 © ©q Operations Engineer I Hilcorp Alaska, LLC r 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pool, TBU K-19 Sundry Number: 315-250 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. Sincerely, /9;/-444.— Cathy . Foerster Chair DATED thisay of May, 2015 Encl. RECEIVED STATE OF ALASKA APR 2 4 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS s APPLICATION FOR SUNDRY APPROVALS 400C /S 20 AAC 25280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate 0 Pull Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Replace ESP 0 2.Operator Name: 4.Current WeN Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory El Development 0 • 174-008 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20259-00 • 7. If perforating: 8.WeN Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit K-19 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018777- McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): .13,771 . 9,802 ' 13,081 • 9,342 13,441 13,081 Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface Intermediate Production 10,047' 9-5/8" 10,047' 7,227' 5,750 psi 3,090 psi Liner 3,987' 7" 13,756' 9,796' 8,160 psi 7,020 psi Perforation Depth MD(ft): (Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/L-80 9,290 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): FB-1 &Model D Packer /SSSV-NA 13,388'(MD)9,551'(ND)&13,420'(MD)9,572'(ND)/SSSV-N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/1/2015 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: VVI NJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe©hilcorp.com Printed Name / Dan Marlowe /- Title Operations Engineer !// ‘ / Oce-;-7 hone 28� Signature Phone (907)283-1329 Date 4/24/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 - 250 Plug Integrity ❑ BOP Test l7 Mechanical Integrity Test ❑ Location Clearance ❑ Other: -------7(,2Sor) PSC_ 46l ° l 3 r ( A4A-S( = c36 7t's-) Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /C)—9d1 APPROVED BY Approved by: /67 COMMISSIONER THE COMMISSION / Date:s_ q......../5-- Submit _/5 Submit Form and Form 10-403(Revised 10/2012) lOrcRdlpG4IN Adlfor 12 months from the date of approval. Atta me is in Duplicate RBDMS,,M 1.;.''; - 6 2015 Well Prognosis Well: K-19 Hilcorp Alaska,LI) Date:04/24/2015 Well Name: K-19 API Number: 50-733-20259-00 Current Status: Oil producer(ESP) Leg: Leg#1 (NE) Estimated Start Date: 05/01/2015 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 174-008 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)398-9904 (M) Second Call Engineer: Trudi Hallett (907)777-8323 (907)301-6657 (M) Current Bottom Hole Pressure: 2,500 psi @ 9,482'(6,859'TVD) 0.26 lbs/ft(7.02 ppg)from downhole gauge on ESP Maximum Expected BHP: 2,500 psi @ 9,482'(6,859'TVD) 0.26 lbs/ft(7.02 ppg)from downhole gauge on ESP Max.Anticipated Surface Pressure: 0 psi Well will not flow based on an expected oil and water gradient of 0.437 psi/ft. 2 5-tv _cis t: Brief Well Summary The K-19 well is currently completed with an ESP which failed on 04/23/15.This work over will replace the failed pump. Brief Procedure: 1. MIRU Moncla Rig#404. 2. Kill well and circulate Hydrocarbon off of well through ESP or sliding sleeve. 3. Notify AOGCC 48 hours before pending BOPE test.Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low and 2,500psi high. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP. 6. Cleanout to+/- 13,713' attempting removal of both junk packers, circulate well clean with FIW, POOH. M (C' 7. RIH with RTTS to+/- 12,000' pressure test casing to 500 psig for 30 minutesand chart, POOH. 8. Re-perforate per program. 9. RIH and land ESP completion. 10. ND BOP, NU wellhead and test. 11. Turn well over to production. 12. Conduct SVS and No-Flow tests per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. BOP Drawing 4. Wellhead Schematic Current/Proposed (Same) evro King Platform K-19 fri RKB to$ea Level(MLW)=100' KB 35' o Size Type Wt/Grade/Conn ID Top Btm Cement Cement :jr..s I . Sacks Top 24" Structural 381 13-3/8" Conductor 61#,K55,BTC 12.515 35' 2,591 1,425 Surf 24"@ 351, 9-5/8"..........................._Casing......................................._47# N80,BTC 8.681 35' 2,591' 0 9-5/8" Casing 40#,N80,BTC 8.835 2,591' 3,576' 0 ............._.................................................................._._.......................................................................................................,..........................._.... _..................................... 9-5/8p Casing....................................._40#,JL95,BTC. ............... 8.835 ........._3,576'......._...5,038' _...__..........._0... 9-5/8" _......._..._......_Casing 47#,N80,BTC 8.681 5,038' 10,047' 800 7,320' Al . i 7" Liner 29#,L80,BTC-KC 6.184 9,769' 13,756' 13-3/8 2591' Completion:All 4.5"Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-1/2" Tubing 12.6#,L80,Butt,533 SCC 3.958 36' 9,290' Cased Hole ESP Cable- Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12"x 4-1/2"FMC Tbg Hngr 2 9,294' 4.2' 3.813" 5.625" HES 4-1/2"Sliding sleeve(Down open,up close). ., 9-5/8 _.._ CMT 7320' 3 9,341' 3.725" 4.5" HES 4-1/2"XN 3.725"No-Go/3.813" 4 9,350' 2.938" 5.188" XO 4-1/2"IBTC box X 3-1/2"EUE pin j 5 9.352' 130' 5.625" Discharge SUB(depth)w/Schlumberger ESP Com•letion 6 9,482' 1.4' 5.875" Anode Perforation Data .T c Doglegs ZONE TOP BTM Shot Condition ;7ffi;,, -• zr 1,000' 4.18 G-5 12,592' 12,644' 52' Perfd'94,95,&'02 w/TCP `' 'I 1,050' 5.96 12,677' 12,716' 39' Perfd'94,'02 w/TCP 9769' 1,00' 5.10 HB-0 12,808' 12,848' 40' Re-Perfd TCP '91 &'02 e -; 1,150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &'02 1,200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 9-518"10,047 ...'. = G-5 1,250' 5.09 12.994' 13,020' 26' Re-PerfdTCP '91' 2,600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP'91 &50"02 '• = HB-0 HB-4 13,157' 13,314' 157' Re-perfd TCP'91 &64"02 2+ = HB 1 HB-5 13,340' 13,415' 75' Re Perfd TCP '91' 'f,,, HB-2 HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-3 HB-7 13,594' 13,604' 10' Squeezed(Cement) itAiu, ....: ' ' ' = HB-4 13,615' 13,645' 30' Squeezed(Cement) HB-3 u•i . HB-S Milled Baker 'FB-1'Perm Packer, Baker SBE,XO, Pupjt,XO, t -._� FISH 13,388 Camco WP-1 Nipple,XO, Pup,WLEG r"-----1" 1. 13,420 20.50 • Baker Model'D'Perm Pkr,5'MOE,XO&3-1/2"Pup Jt. >� r, HB-7 4p, 2. 13,441 1.53 Camco"D" Nipple.Plug set on 1/29/92 7"-13,756 , PBTD=13,713' TD=13,756' MAX HOLE ANGLE=51 Cad 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours O:\NAU\MCBUWlaska\Depts\CI_Oil_Ops\Fields\TBU\King\Wells\Producers\K-19\Schematics\K-19_Schematic_12-3-08.doc Update CVK McArthur River Field, TBU II PROPOSED Well: K-19 NilcorpAlaaka,LLf. As Completed: Future RKBtoSea Level(MLW)=100 CASING DETAIL KB 36' SIZE WT GRADE CONN ID TOP BTM. .- I - _r tk 24" BIC Surf 381' 13-3/8" 61 K55 BTC 12.515 Surf 2,591' ,r 9-5/8" 47 N80 BIC 8.681 Surf 2,591' 9-5/8" 40 N80 VTC 8.835 2,591' 3,576' 9-5/8" 40 1L95 BTC 8.835 3,576' 5,038' 9-5/8" 47 N80 BTC 8.681 5,038' 10,047' 7" 29 L80 BTC-KC 6.184 9,769' 13,756' 24"@381' TUBING DETAIL 4-1/2" I 12.6 I L80 I Butt,533 SCC I 3.958 I Surf I ±9,290' L 13-3/8--2 ' N., JEWELRY DETAIL NO. Depth OD ID Item 35' Tbg Hanger 1 ±9,482' Bottom of ESP PERFORATION DETAIL 9y8" Zone Top(MD) Btm(MD) TOP(ND) Btm(ND) Ft Status CMT7320' G-1 ±12,175' ±12,193' ±8,725' ±8,738' ±18' Future G-1 ±12,203' ±12,215' ±8,745' ±8,754' ±12' Future 5.-. G-1 ±12,223' ±12,226' ±8,760' ±8,762' ±3' Future G-1 ±12,237' ±12,250' ±8,770' ±8,779' ±13' Future G-3 ±12,373' ±12,389' ±8,868' ±8,879' ±16' Future t' _ i G-4 ±12,411' ±12,417' ±8,895' ±8,899' ±6' Future G-4 ±12,472' ±12,482' ±8,937' ±8,944' ±10' Future ;~ 6-5 ±12,570' ±12,580' ±9,004' ±9,010' ±10' Future t G-5 12,592' 12,644' 9,018' 9,053' 52' Pert d'94,95,&'02 w/TCP G-5 ±12,594' ±12,603' ±9,020' ±9,026' ±9' Future G-5 ±12,610' ±12,644' 19,030' ±9,053' ±34' Future I G-5 ±12,651' ±12,671' ±9,057 ±9,071' ±20' Future G-5 ±12,676' ±12,685' ±9,074' ±9,080' ±9' Future A- G-5 12,677' 12,716' 9,075' 9,100' 39' Perf'd'94,'02 w/TCP . 9769' G-5 ±12,691' ±12,714' ±9,084' ±9,099' ±23' Future G-7 ±12,810' ±12,830' ±9,162' ±9,175' ±20' Future HK-0 12,808' 12,848' 9,160' 9,187' 40' Re-PerYd TCP '91&'02 aeri9-5/8"10,047' ', ,, HK-1 12,882' 12,892' 9,209' 9,216' 10' Re-Perf'd TCP '91&'02 ;b HK-1 ±12,885' ±12,890' ±9,211' ±9,214' ±5' Future gid` -"fIf+ HK-2 12,914' 12,988' 9,230' 9,278' 74' Re-Perf'd TCP '91' HK-2 12,994' 13,020' 9,282' 9,299' 26' Re-PerYd TCP '91' G 1 7 HK-3 13,060' 13,157' 9,326' 9,392' 97' Re-perf'd TCP'91&50''02 NF HK-3 ±13,063' ±13,087 ±9,328' ±9,344' ±24' Future l� HK-3 ±13,094' ±13,130' ±9,349' ±9,374' ±36' Future � .,... HK-4 ±13,139' ±13,165' ±9,380' ±9,398' ±26' Future HK 4 13,157' 13,314' 9,392' 9,500' 1ST Re-perf'd TCP'91&64"02 �, j HK 4 ±13,230' ±13,248' ±9,443' ±9,455' ±18' Future HK-4 ±13,259' ±13,271' ±9,462' ±9,471' ±12' Future HK-4 ±13,300' ±13,312' ±9,490' ±9,499' ±12' Future o HK O-6 HK-5 13,340' 13,415' 9,518' 9,569' 75' Re-PerYd TCP '91' HK-5 ±13,342' ±13,360' ±9,519' ±9,532' ±18' Future ` HK-5 ±13,368' ±13,375' ±9,537' ±9,542' ±7' Future ' HK-5 ±13,390' ±13,425' ±9,552' ±9,576' ±35' Future HK-6 ±13,460' ±13,495' ±9,599' ±9,623' ±35' Future .p, .1 III HB-7 HK-6 13,460' 13,545' 9,599' 9,655' 85' Isolated 1/29/02 kHK-6 ±13,502' ±13,520' ±9,627' ±9,639' ±18' Future 7'-13,756; k.M yfllRSFiF*tR+';. HK-6 ±13,526' ±13,540' ±9,643' ±9,652' ±14' Future PBTD=13,713' TD=13,756' HK-7 13,594' 13,604' 9,687' 9,694' 10' Squeezed(Cement) MAX HOLE ANGLE=51 a 2304' HK-7 13,615' 13,645' 9,701' 9,721' 30' Squeezed(Cement) OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Updated by: AL 04/23/15 Tubing 0 Rotating Hours King Salmon Platform . il K-19 Current 04/24/2015 Hilrnrp:Un.ka.l.l.t, King Salmon BHTA, B-11-A0, 4 1/16 5M FE Tbg hanger, OCT-UH-TC- K-19 1A-ESP, 13 X 4 '/BTC lift 24 X 13 3/8 X 9 5/8 X 4 '/2 R 2' and susp,w/4"Type H BPV profile, 3/8 cont control line port A • _ . Valve, Swab, FMC 120, G r 4 1/16 5M FE, HWO, ►4.7 0 EE trim o r. ';I Valve, Wing, OCT-120, 4 1/16 5M ' u r;;:i FE, w/Axelson AM oper, EE trim Valve, Wing, WKM M, )--K L 2 1/16 5M FE, HWO, T r AA trim _t ', _ NK I / ..I L.w1.,1 ! .: ff` , Valve, Master, FMC120, rc �� •""i, 4 1/16 5M FE, HWO, EE t. iiiimii•--0,1 on a��,trim . �A e i Valve, Wing, FMC-120,4 1/16 5M FE, HWO, EE trim w\ i' � .o C` Adapter, OCT-A5-ESP, 13 5/8 5M eg _ API hub X 4 1/16 5M stdd top,w/2- �/ 'A control line exits, prepped w/OCT MP — •.=1 400-4 pocket al R-4,i II 0 11 ifi°1' i g, .im , C =. . a All unihead annular valves, Unihead, OCT type 3, 13 5/8 5M I 2 1/16 5M FE OCT-20, API hub topX 13 3/8 BTC casing ' . 4 i. HWO bottom,w/ 1-2 1/16 5M SSO on h'- - '_ ___ �� lower section, 1-2 1/16 5M SSO on middle section, 3-2 1/16 5M -I; SSO on upper section , IP internal lockpin asst' = 3 ��r�a °^�:� ° it'Hi' ■i,�' Lr Valve, OCT-20, 3 1/8 2M Starting head, OCT, 21 %4 2M ®l 111, ;.0 n.. \ FE, HWO FE X 24" SOW,w/ 1-3 1/8 2M - '- ;o�._.''°l� I 16f EFO, full set of lockpins / 124" _13 3/8" 9 5/8" 4 ,/A" King Salmon Platform • ii 2013 BOP Stack(Moncla) Hilrnrp Alawka.I.IA. 09/19/2013 vi/ mil lil 11� I Iililllift ii 3.74' Shaffer 13 5/8_5M I I I I If TIi ITI i1 1 111111.11111111.111 I!I III I I I! I _� - CIW-U ,. - _. 1 �._ Variable 27/8-5 4.67' �1. — - _� - i lU 13 5/8-5000 ��., _c Blind Rams iii III 1i1 III Iii Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses Itlill I11 III I11 i rio i 2.00' Ylf i ‘11111111114 - III Ill Iii Ili iii III III III,)I1 III Riser,135/85M FE 5 13 5/8 5M API#13 hub 13.70' Moncla Rig 404 BOP Test Procedure Hilcorp:%!aka.►,r.� Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead} If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,IAA- c) #1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure Hikurp Alaska.1.11: Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4,9. After test, open valves 3&4. Leave 9 closed. iii) Valves 5, 6,9. After test, open valves 5&6, leave 9 closed. iv) Valves, 7, 8,9. After test, open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday, April 30, 2015 1:00 PM To: Schwartz, Guy L (DOA) Subject: RE:TBU K-19 RWO (PTD 174-008) Guy Per your request, a worst case calculation yields the following assuming we hit gas. (Known surrounding wells show this is not realistic) Max expected BHP 2500 psi at esp gauge TVD 6859. This extrapolates to 3180 psi at the top pen`TVD 8725 Using 0.1 psi/ft gradient to 8725 TVD yields 873 psi Revised Max Anticipated Surface pressure is therefore 3180-873 = 2307 PSI From: Schwartz, Guy L(DOA) [ lailto:guy.schwartz@alaska.gov] Sent: April 29, 2015 11:10 AM To: Dan Marlowe Subject: TBU K-19 RWO (PTD 174-008) Dan, Since you are perfing new zones I would like a better estimate of worst case MASP ( some of the zones might have higher than expected BHP) Also, in future I would like to see something besides 0 psi for the MASP... this is basically a worst case number not expected. I would think there is always a chance for at least for some pressure at surface . Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 Page 1 of 1 ~J ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 1:16 PM To: Chantal Walsh -Petrotechnical; Steve Tyler Cc: Nigel Bonnett (Nigel.Bonnett@chevron.com) Subject: TBU K-19 (174-008) Chantal, Steve and Nigel, I am belatedly reviewing the operations reports submitted with the 404s for the work accomplished on these wells in November. I think we have spoken regarding the level of operations detail provided in the past. Is there a "next higher" level of detail that can be provided? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC ~ ~ ~~^y " ~b~.++y'ZGn~~#r~ iw~ ~ i J . .. `;: £_ ~1 ~ ~t 2/9/2009 g /-a~~ TATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERAT~4NS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Oiher ~ Ran ESP Completion Performed: Alter Casing ~ Pull Tubing~ PerForate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown~ Perforate ~ Re-enter Suspended Well ~ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ - Exploratory^ 174-008 , 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-733-20259-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 100' ~ King Saimon Platform, K-19 _ 8. Property Designation: 10. Field/Pool(s): ADL0018777 [King Salmon Platform] McArthur River Field/ Hemlock & G-Zone Oil 11. Present Well Condition Summary: Total Depth measured 13,771' , feet Plugs (measured) 13,441 true vertical 9,802' feet Junk (measured) 13,081' - Effective Depth measured 13,081' feet true vertical 9,342' feet Casing Length Size MD ND Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302 3090 psi 1540 psi Surface 2,591' 9-5/8", 47# N-80 2,591' 6870 psi 4760 psi 985' 9-5/8", 40# N-80 3,576' 5750 psi 3090 psi 1,462' 9-5/8", 40# JL95 5,038' 6830 psi 3330 psi 5,009' 9-5/8", 47# N-80 10,047' 7,225' 6870 psi 4760 psi Intermediate Production Liner 3,987' 7" 9,792' 9,792' 8160 psi 7020 psi Perforation depth: Measured depth: See Attached Schematic True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 9,290' Packers and SSSV (type and measured depth) N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to weli operation: 0 0 0 75 0 Subsequent to operation: 265 0 3595 75 75 14. Attachments: 15, Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-360 Contact Chantal Walsh 263-7627 Printed Name Timothy C. Branc~Qnburg Title Drilling Manager J~__ _.. ~.... __..~- , Signature ~~' ~_~' %` -- Phone 263-7600 Date 12/3/2008 _....,_ ~"'~ ~ s~,'~,~6z,° ~`~~' "; t~ i 1 1~; Form 10-404 Revised 04/2006 ~ " ~.~,,, Submit Original Only ~~ ~~~ _. :,~; . za~~ ~ ~s-aB^- zssr e-yg~ io,oar Ke 35~ 9&8" CMT 7320' - co-s H&3 T'- 73.756;' ~ r• PBTD =73,713' TD = 73,756' MAX HOLE ANGLE = 51 (a~ 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cement To 24" __ ............._...._.._......... 13-3/8" 9-5/8" ............ 9 5/8" _9-5/8" _9-5/8" ............. 7" ........ ........ ....... Structural ..........................__.._.._.._.._ Conductor _ ......... .......Casin.9......_. . _Casmg........ _ Casing ......_Casin.9............. Liner .... ... .... .. _..............._..................._.........._.............................__....._...... 61#, K55, BTC ........................ .......................... .... . . ....._. ......................._47#,.._N80,...BTC.................. _....... 40# N80 BTC _40# JL95 BTC _...... .. ........................_47#, N80,..BTC.................... 29#, L80, BTC-KC ....... ....... . ....... ............................._....... 12.515 _..... __ ........8,68.1.._..__ 8 835 _8.835 ......._8,681.......... 6.184 .............................._... 35' ... ...........35~............ 2,591'....... 3,576' ....._5,_038' ..... 9,769' 381 .............._._.................. 2,591' ......_2,591..~......... 3 576' .... S,038' ....._10,047'..... 13,756' ............................................ 1,425 _._.... _.. ._..............._~.............._... .................._0............... 0 _. ...___..._800............... ......__........... Surf ..... .__.._...._......_.. _ . ._.. _....... . ._......_7,320' Completion: All 4.5" Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-1/2" Tubing 12.6#, L80, Butt, 533 SCC 3.958 36' 9,290' Cased Hole ESP Cable - Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1/2" FMC Tbg Hngr 2 9,294' 4.2' 3.813" 5.625" HES 4-1/2" Sliding sleeve (Down open, up close). 3 9,341' 3.725" 4.5" HES 4-1/2" XN 3.725" NaGo ! 3.813" 4 9,350' 2.938" 5.188" XO 4-1/2"IBTC box X 3-1/2"EUE pin 5 9.352' 130' 5.625" Discharge SUB (depth) w/ Schlumberger ESP Completion 6 9,482' 1.4' S.875" Anode Perforation Data Doglegs ZONE TOP BTM Shot Condition 1,000' 4.18 G-5 12,592' 12,644' 52' Perfd '94, 95, &'02 w/ TCP 1,050' 5.96 12,677' 12,716' 39' PerPd '94, '02 w/ TCP 1,00' S.10 HB-0 12,808' 12,848' 40' Re-PerfdTCP '91 &'02 1,150' 4.98 HB-1 12.882' 12,892' 10' Re-Perf'dTCP '91 &'02 1,200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 1,250' S.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2,600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP '91 & 50' '02 _ _ HB-4 --- 13,157' 13,314' --- 157' Re-perFd TCP'91 & 64"02 HB-5 HB-6 HB-7 13,340' 13,415' - 13,460' 13,545' 13,594' 13,604' 75' Re-Perfd TCP '91' ---- _. _ 85' Isolated 1/29/02 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pupjt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 gaker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pu Jt. 2. 13,441 1.53 Camco "D" Ni le. Plu set on 1/29192 K-19 Actual Schematic 12 3 2008.doc Page 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update CVK ~ ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K-19 TRADING BAY UN IT K-19 ADL0018777 5073320259 AR4466 100.00 .; . :.b °' iy• ~~y`~.~. ~,. _ N aKU.. :~ ^:~~. :i~x ,~~ ,~ 'i~ ~ ;~~ °3+6~ ~s ~' ~~" k aTM~ Nz '4,e;'"~.,.~'.c Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig Pull kill string and run an ESP completion. 11/3/2008 11l19/2008 Work Over (MRWO) Primary WellboreAffected Wellbore UWI Well Permit Number K-19 5073320259-00 1740080 Mobe CUDD onto well. 11iM2Q0$ OQ:OQ -1't/5/2~081~0:06 ;_..~~ ~~~~ ;_ ~ #~.; ~„ . ~~: : . ' w: , ' ,, Operations Summary Nipple up BOPS. Begin testing BOPs. Contacted Jim Regg and left messages on Slope pager to give 24hr notice for testing BOPs. `'~:1%5/2008 00~:00 -11/6l2008 OO:QO , ~~" ~~'~ ` ` ~ T~' ~~ rr' ` ,"° '" n ; Operations Summary Tested BOPs to 250 si low and 3000 si hi h. Good. Circulate wellbore with 3% KCL water. Pump total of 820 bbls. Lost rate of 17.5 bbls/hr during circu a ion. ~.r. _ . „~ 'k /6f2008 Of~;00:~ 11i7C2~~ ~."D0:00 ~ x. ~„ , r~ K , ~ ,~~ ~ ~ ~~~.~ ' -~~ ~ ,~~ «., ~ ~.::~,~~~ ~ ' Operations Summary Loss rate 8.8 bph. Pull hanger. Break out and LD hanger. Pooh w/ 4.5" killstring. RU slickline. RIH w/ 8.5" GR and junk basket. Assembly stuck at 9538' RKB. 11t7f2b1? f ;Q .QQ t 11/8/20d~ 00:0(t . ~.u :~~ ~`~ ~~ ~ ~ ~ k ~ ~ ~"3~ Operations Summary Jar GR free. POOH w/ GR and junk basket Change to 6" GR and junk basket. RIH and sit down at 11,947'. Jarring on GR, losses went from 12 BPH to zero.~ac -off, no losses. Continue working to free tool. Losses return to 20 bph. 1~ O VYt Y~~:OV ~~ E~ ~~~ y`'~ k £ y~ ~~ Operations Summary Well losses at 15 bph. RIH w/ cutter, cut and POOH with 200' of wire. Rehead and RU sheave. RIH w/4.5" bell guide and pulling tool BHA. Engage cutter @ 11,947' POOH w/ slickline and cutter bar._ RD slickline. RU eline. RIH on braided line and pulling BHA. Engage fish, unable to jar free. POOH with wireline tools. RD eline. ..: ~ ~ ~~ ~< ~ '~ ~~ ~~ i~ ~~ ~~ OQ$ dQ.00 , , , ;~ ~ . s ~:- . .. ~~ Operations Summary RU for BOP test. Work equipment. PU fishing BHA. ~~~~or24os oo:ua i tt . ~ ~ v~~ ~ ~ ~ { ~ ~ y ~ ~b~ t~ ry ~-_~~ Operations Summary RIH with fishing BHA on 3-1/2" tubing to 3066', XO to 4-1/2" tbg. RIH and tag liner top at 9769'. Continue in hole and circulate to 11,857'. ~~ ._. , .u~ ~ ~ ~ , ~ _, .. - ~ ~ ~x ~ ~~ ~ , ~ 2048 O(~ OQ ` Operations Summary Contacted AOGCC for 24 hour BOP test notice. Witness waived. Continue RIH, tag fish at 11,933. Work gently, turn on pumps. Chase fish to 12,792'. Limited by tubing to contiue. 20 boh losses. POOH with tubinq and fishinq BHA. No recovery of fish. RU Slickline. RIH with 4.55" LIB. Tag solid at 12,910'. POOH. RD slickline. Testing BOPs. 250 psi low and 3000 psi high, witness waived by AOGCC Bob Noble. ~, ~ h 11/13120b8e.OQi ~,-„'~~'~~~~ ~' ' r .~~~ ;i :.a~~; S=~F ~ ~ ~~~`~ '"°> Operations Summary MU fishina BHA. RIFf on 3-1/2" tba (20 its)i Continue to TIH on 4-1/2". Run in slow w/overshot from 11,838' and stackout at 12,975'. Attempt to spud down on fish, no progress. POOH. ~v.,r , ~ ~ ~nn~~nn~n~s~: ~Tr~~)~nns~nn rin~.kr, ~~~; ..a.. ., ~,_ ,.~..: ~~~r~ ~ ~: ~ ~~~~~w~~5~~, ~:.~ =~~ . POOH. Pulling wet. LD 3-1/2" tbg. Breakout, LD fishing assembly BHA fi~f'~~5/200$ 00:00 -19t18/20 '°04~ iY~= ' ~~ ` ;`: : ~ k`~~ ;` ~ ~~ ~ r` ,:~' ~ Operations Summary MU ESP equipment. Prep ESP equipment. RIH with anode, guage, motor section, pumps. ~ ~~ ~ ~ ~a~ ~~i~~rzou's oa~~o = ~~i~~iaa ~~oa ; ' ~ ~ ~ ~ ~ Operations Summary Continue making up ESP completion, and completion jewlery. RIH on 4-1/2" IBT tubing. Meg cable every 1000'. Make and test cable splice. ~'1l17~2008 OOt00 -1114~1 Q08 00:00 ~ ~~ ~ -~''- ~__. ; : ~~~~': . '~ ~ ~ ~ Operations Summary Continue. RIH with completion. MU tbg hanger. Back out landing joint, splice penetrator. Land and test (2000 psi/5min) tubing hanger. Nipple dwon BOP. Contnue to ND BOP. NU tree. Test same 250 psi low, 5000 psi high - • MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 28, 2008 SUBJECT: No-Flow Test Unocal /King Salmon PLT K-19 PTD-1740080 Trading Bay Unit November 28, 2008: I traveled to Chevron's Unocal King Salmon Platform in Cook Inlet to witness a No-Flow Test on well K-19. On my arrival on the platform I met with Chevron-Unocal Lead Operator Greg McGahan and we discussed the operational details of the test. Mr. McGahan indicated that the well pressure had been bled down and the wellbore was open to the tree cap with no plugs or restrictions. Well K-19 has an electric submersible pump (ESP) installed and was lined up from the tree top swab valve through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) to a 1" hose which terminated in an open top drum. The flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas and liquid flow from the well did not exceed 900 SCF or 6.3 gals. hourly flow rate during the test and well K-19 meets the AOGCC requirements for a No-Flow status determination. Summary: I witnessed a successful No-Flow Test on Unocal's Trading Bay Unit well K-19 on the King Salmon Platform. Well No-Flow Tesf Data Operator: Unocal /Chevron _ Operator Re Greg McGahan AOGCC Rep: Jeff Jones Field/Unit/Pad TBU / Kine Salmon PLT Well: K-19 Tinto t~'e!! IYo~+' _ COttl i)t ('ills ~ Gas Li uid 835 am < 180 scfh No significant amount Start Test 905 am < 180 scfh No significant amount 935 am < 180 scfh No significant amount 1005 am < 180 scfh No significant amount 1035 am < 180 scfh No significant amount 1105 am < 180 scfh No significant amount 1135 am < 180 scfh No significant amount End Test Produced to open top container through Arntor-Flow meter model #3461-03T0 calibrated 6/27/08 Total liquid produced: less than 1 cup. This well has an ESP (electric submersible pump) installed. '~ Attachments: none CC: Chris Meyers, Wayne Johnson (Unocal) RJF 09/19/02 Page I of 1 No-Flow TBU King Salmon PLT K-19 11-28-08 .IJ.xls • • _. __ ._ ~, _W. _, ,, SARAH PALIN, GOVERNOR t~~TT~~++ ~T~r~-t7~~1aT ®~ Aisil iZ0~7 333 W. 7th AVENUE, SUITE 100 ®1s~7~Rs~ii~is ~®~`ii,7S''i®lt ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Unocal = ~ r ~~ ~~ PO Box 196247 '~~``~~ ~ v ~ ~~ Anchorage AK 99519 ,~ Re: McArthur River Field, Hemlock & G-Zone Oil Pool, King Salmon Platform K- I9 Sundry Number: 308-360 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ Uday of October, 2008 Encl. t%~~~ ~~ STATE OF ALASKA ~O~\~ ~ u-~ AL~4 OIL AND GAS CONSERVATION COM ON ' APPLICATION FOR SUNDRY APPROVALS ` ~n AAC ~s ~~n 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Run ESP Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Q Exploratory ^ 174-008 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20259-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No^ Kin Salmon Platform, K-19 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018777 Kin Salmon Platform 100' ' McArthur River Field /Hemlock & G-Zone Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,771' 9802' 13,081' 9342' 13,441' 13,081' Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2591' 2,302' 3090 1540 Surface 2591' 9-5/8", 47#, N80 2591' 6870 4760 985' 9-5/8", 40#, N80 3576' 5750 3090 1462' 9-5/8", 40#, JL95 5038' 6830 3330 5009' 9-5/8", 47#, N80 10,047' 7225' 6870 4760 Intermediate Production Liner 3,987' 7" 13,756' 9,792' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6# L-80 9,453' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 10/19/2008 16. Well Status after proposed work: Commencing Operations: Oil^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature _ ~~~ ~a_,~ , _..~i~ope 276-7600 Date 10/6/2008 ~ ... c._.. ,, t`-" COMMISSION USE ONLY ,..-~-. Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `" ~~'- ~~ Plug Integrit y ^ BOP Test `~ Mechanical Integrity Test ^ Location Clearance ^ ~~~^^ r Other: ~vV V '~ S i ~ Q ~ S `~ C _ C c C~O~1 ~I~C~CS~~ ~CS~ ~.1©C°~U`C~.~~T~~.~SJ~~ vvd~~°~ s~C~ COhC~~C ~ t " o G ~~J ~ Subsequent Form Required: ~~ APPROVED BY ,~ J ~~ ~ 2a / Approved by: COMMISSIONER THE COMMISSION Date: ~L)/ _~~..t~..~.~~.? r ~- 411,1 ~ r LGJH /4',~-'~r'oz Form 10-403 Revised 06 ~ ~x, t Submit in Duplicate ~~'~~~~~~~~ ~~,,~~c~ _ King Platform K-19 RKBto Sea Level (MLW) _ K635' ~ ~' ~-. i V 2a° ~ 3ar 13318"-2591' 95/8„ CMT 7320' sala^ to,oar - c-s He-o - cas •HB-1 H B-2 HB-3 HB-4 HB-3 HB5 HB-6 H B-7 7"- 13,758'~~- PBTD =13,713' TD =13,756' MAX HOLE ANGLE = 51(ta 2304' ding Bay Unit II K-19 Size Type Wt/ Grade/ Conn ID Top Btm Cement Cement Sacks To 24 Structural 38,1 13-3/8" Conductor _. 61#, K55, BTC 12.515 35' 2591' 1425 Surf _.. 9-5/8" Casing _ 47#, N80 BTC .._8.681 35' 2591' 0 __.. 9 5/8" . Casing 40# N80 BTC _8 835 2591,'...... .3576 0 9-5/8" ....... . Casing 40# JL95 BTC __8 835 3576' 5038' 0 __ _ _ 9 5/8" _ _Casing _ _ _ 47#,N80, BTC _8.681 5038' 10,047 800 _ 7320',,,,,,,, 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' Completion Jewelry Detail # Depth tlD OD Item 3 9,453' 3.958" 4,5" 4-1/2" L-80 12.6# Buttress Kill String w/ Half MS . Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' S2' Perfd '94, 95, & '02 w/ TCP 1050' 5.96 12,677 12,716' 39' Perf'd '94, '02 w/ TCP 100' 5.10 HB-0 12,808' 12,848 40' Re-Perfd TCP '91 & `02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &'02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 1250' 5.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP'91 & 50"02 HB-4 13,157' 13,314' 157' Re-perfd TCP'91 & 64"02 HB-5 13,340' 13,415' 75' Re-PerPd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pupjt, XO, Camco WP-1 Nip ple XO, Pup, WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pup Jt. 2. 13,441 1.53 Camco "D" Nipp le. 1']t~y sPt ~~? 1129192 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours K-19 Actual Schematic 9 23 2008.doc Page 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update CVK King Platform K-19 ~'roposed RKH to Sea Level (MLW) _ KB 35' :. i :.; I ::. ~. ~ za^ ~ 3s 13-318"- 2591' 9.5/8" 10,04T r'- King Salmon Platform Trading Bay Unit Well K-19 Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cement To 24" 13-3/8" 9 5/8' 9 5/8" 9 5/8 9 5/8 7" _ Structural Conductor ,Casing ___Casing Casing .Casing Liner 61#, K55, BTC 47#, N80 BTC 40#, N80, BTC 40# JL95 BTC 47# N80 BTC 29#, L80, BTC-KC 12.515 8.681 ,,,,,,,8.835 8 835 8 681 6.184 35' 35' 2 591' 3 576 5 038 9,769' 381 2,591' 2 591' 3 576' 5 038' 10 047' 13,756' 1,425 0 0 0 800 Surf 320 Completion: All 4.5" Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-112" Tubing 12.6#, L80, Butt, 533 SCC 3.958 36' 9,463' Cased Hole Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1/2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile 2 9,463" 3.725" 5.625" HES 4-1/2" Sliding sleeve (Down open, up close). 3 9,510' 3.813" 4.5" HES 4-1/2" XN 3.725" No-Go / 3.813" 4 9,517' 5 9,576' 2.922" 5.188" XO 4-1/2"IBTC box X 3-1/2"EUE pin Schlumberger ESP Pump Perforation Data Doglegs ZONE TOP BTM Shot Condition 1,000' 1,050' 4.18 5.96 G-5 12,592' 12,644' 12,677' 12,716' 52' 39' Perfd '94, 95, & '02 w/ TCP Perfd '94, '02 w/ TCP 1,00' 5.10 HB-0 12,808' 12,848' 40' Re-PerFd TCP '91 8'02 1,150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &'02 1,200' 1,250' 2,600' 6.30 5.09 6.46 H13-2 HB-3 12,914' 12,988' 12.994' 13,020' 13,060' 13.157' 74' 26' 97' Re-PerFd TCP '91' Re-Perfd TCP '91' Re-perFd TCP '91 & 50' '02 HB-4 13,157' 13,314' 157' Re-perfd TCP'91 & 64' '02 HB-5 13,340' 13,415' 75' Re-Perfd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 13,615' 13,645' 10' 30' Squeezed (Cement) Squeezed (Cement) 95/8" CMT 7320' - co-s iB~ I FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pup jt, XO, H6~ IG_S Camco WP-1 Nipple, XO, Pup, WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pup Jt. 2. 13,441 1.53 Camco "D" Nipple. Plug set on 1/29/92 PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 Ce? 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours K-19 Proposed Schematic 9 23 2008.doc Page 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update CVK Chevron ~ ~ King Salmon Platform Well # K-19 10/6/08 OBJECTIVE: • Rerun ESP pump completion using Cudd unit. PROCEDURE SUMMARY: 1 Mobilize Cudd rig onto K-19. 2 PJSM - ND Tree - NU BOPE -All LP mud Lines -All HP Mud Lines -Flow Glass - Test all lines -TEST BOPE Equipment to 250psi low/3000psi high. PJSM -Circulate well, displace well to inlet water, insure standing column of fluid in 3 well, displace returns to production -Flow check well -Pump salt pill as needed - Flow check we1L 4 POOH w/ 4-1/2" tubing (kill string). 5 PJSM - RU Slickline - RIH w/ junk basket/GR to 9769'. 6 PJSM - RU Slickline -Run Gauge ring to bottom, tag bottom 7 PJSM - RU ESP handling equipment/ (Spooler, sheaves, ...} 8 PJSM - RU Crane & Schlumberger to run ESP -Run ESP to +/-9,750'. 9 PJSM - ND BOPE - NU Tree -Pressure Test. 10 Release Cudd Pressure Control. K-19 REVISED BY: CVK 10/6-08 r _____._ _ _ . ... ., e ~:: .,. ~ • STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMM~ON - REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Q Ran kill string • Performed: Alter Casing ~ Pull Tubing Q• Perforate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown~ Perforate ~ Re-enter Suspended Well ~ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ~^ " Exploratory^ 174-008 . 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-733-20259-00 7. KB Elevation (ft): 9. Well Name and Number: 100' . King Salmon Platform, K-19 8. Property Designation: 10. Field/Pool(s): ADL0018777 [King Salmon Platform] McArthur River Field/ Hemlock & G-Zone Oil • 11. Present Well Condition Summary: Total Depth measured 13,771' ~ feet Piugs (measured) 13,441 true vertical 9,802' • feet Junk (measured) 13,081' Effective Depth measured 13,0$7' feet true vertical 9,342' feet Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302 3090 psi 1540 psi SurFace 2,591' 9-5/8", 47# N-80 2,591' 6870 psi 4760 psi 985' 9-5/8", 40# N-80 3,576' 5750 psi 3090 psi 1,462' 9-5/8", 40# JL95 5,038' 6830 psi 3330 psi 5,009' 9-5/8", 47# N-80 10,047' 7,225' 6870 psi 4760 psi Intermediate Production Liner 3,987' 7" 9,792' 9,792' 8160 psi 7020 psi Perforation depth: Measured depth: See Attached Schematic _ , , rp :.,;.~.~''~~~!~~d.,~' ~~.1 ~.;{ _ _ ~UU~ True Vertical depth: See Attached Schematic Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 9,453' Packers and SSSV (type and measured depth) N~A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 55 . 0 Subsequent to operation: 0 0 0 75 ~ 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ~~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil Q' Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-297 Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager 10/ D 8 ~~''~ ~ ~"~~ ' "~ ate 6/200 Signature Phone 263-7600 ~ _ -~ Form 10-4041~evised 04/2008 ' ,~'~'` p ~a ~ ,~( ~ ~~~~j `~ ~ ~~ i~ ~~`~Submit riginal Only . ~ } /o • 7.~ i RKB to Sea Level (MLW) _ K835' 0. 7~~ :'.: iH r Y, 24" ~ 38T 13318"- 2591' 9bI8" CMT 7320' 9.a~e^ ~o,oar : G-5 ~ He-o-cas • H8-1 H&2 HB-3 HB-4 ~1 HB-3 H85 HB-6 .. H&7 7"- 13,756' PBTD=13,713' TD=13,756' MAX HOLE ANGLE = 51(aa 2304' Klll Platform K-19 King Salmon Platform g Trading Bay Unit Well K-19 Last Completed 05-12-2008 ', Size Type WU Grade/ Conn ID Top Btm Cement Cement Sacks To 24" . Structural .. . . ..... ......... 381 ......... . 13-3/8" Conductor . .. . . ...... .. 61#, K55, BTC .. ....... ........ 12.515 ........ 35' 2591' 1425 ................... Surf 9 5/8" Casing 47#, N80 BTC 8.681 35' 2591' 0 9 5/8" ... Casin~ 40# N80, BTC . 8.835 2591' 3576' .... 0 9-5/8" Casing .... ...... 40#, JL95 BTC _... __...._ _. ....... 8.835 ... 3576' S038 ..... 0 _ . ._..... . . ......... 9 5/8" _ Casing ___ 47#,N80, BTC ___... __ 8 681 _.._._ 5038' 10,047 _. 800 7320' 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' _ ................... Completion Jewelry Detail # Depth ID OD Item 3 9,453' 3.958" 4.5~~ 4-1/2" L-80 12.6# Buttress Kill String w/ Half MS . Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' 52' Perfd '94, 95, &'02 w/ TCP 1050' 5.96 12,677' 12,716' 39' Perfd '94, '02 w/ TCP 100' 5.10 HB-0 12,808' 12,848' 40' _ Re-Perf'd TCP '91 &'02 1150' 4.98 HB-1 -- --_ 12.882' 12,892' _._._.------- _. _. - --__. 10' -- --.._. _.__ --- - Re-Perfd TCP '91 &'02 ------ _-----_ _ 1200' 6.30 HB-2 12 914' 12,988' 74' Re-Perf'd TCP '91' 1250' 5.09 12.994' 13,020' 26' -___ Re-Perfd TCP '91' __ _ 2600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP '91 8~ 50' '02 HB-4 13,157' 13,314' 157' Re-perf'd TCP'91 8~ 64"02 HB-5 13,340' 13,415' 75' Re-Perfd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pupjt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 gaker Model 'D' Perm Pkr, 5' MOE, XO & 3-1 /2" Pu Jt. 2. 13,441 1.53 Camco "D" Nipp le. Plu set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/S" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours K-19 Actual Schematic 9 23 2008.doc Paqe 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update CVK ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) K-19 TRADING BAY UNIT K-19 ADL0018777 5073320259 AR4466 100.00 al~ `" ~~ ~ 3~ f Primary Job Type Job Category Objective Actual Start Date Pump Repair Major Rig 8/27/2008 Work Over (MRWO) K-19 5073320259-00 1740080 C-a O s .~ ~:z ~.`.~. X~ } ,~. ,~ ~ 8/2712008 00:00 - 8/28/2008 ~OOs00 ~ ~ ~ °.~'.<~• ~; ~~. :, ' ': ,:~. ~ : • Operations Summary Contacted AOGCC Chuck Sheve about upcoming BOP test. Mobe from K-01 RD2 to K-19. RU wireline . RIH w/ 3.80" gauge ring to 9,583' WLM. POOH RIH with 3.813" standing valve and set same in XN nipple at 9560'. Pressure up to 2500psi for 15 min. and bleed off pressure. OK. „~~ . ~. , . F ; °~_r~., , ~ 8~~$/2Q08~~00:00 -~8l2912008~-0O:OQ~ ~ ~ ~ ~ ~ t,v~ ~:~'~~ ~ v~ ~~ .~~r.. Operations Summary RU Slickline and shift sliding sleeve. Pump through same. RD slickline. ND tree, NU BOP. $/2~t2~0$~0~ ~~ ~ 8130/2008 OQ~00 ~ ~ ~ ~ ~ ~ ~ ~~` ~~° ` ~ `~~~ Operations Summary Operations shut down due to crews returned to Louisiana due to hurricane. 8f30/2008 00:00 - 8131f~0(i8 Ob:00 ~ ~ ~ `~~~ ` Operations Summary Operationai shutdown. 813'il~`008 00:00 - 911l2008 00;00 $"~~ ~~`~~° Operations Summary Operational shutdown. SI'~lZOi~" b~~~ < 812i2008 00•00 * ' ~° ~ '' ~ ~ °~~,~~ Operations Summary Operational shutdown. 9/1.~2008 OO:OQ'- 9/3J2Q08~ 00:00;,; r. ~ ~ ~x ~ <~~ ';~ ~ ~ Operations Summary Operational shutdown. 9/3/20QS~.OQ:00 - 9/4/2008 00:00 ~ ~ ~`~ ~-;` , ~ ~ ~ Operations Summary Operational shutdown. 9/4/20b8 QO:Ot~`~"916f~008 00:00 ~ • ~~' ; ~ ~ ; ~ ~ ~~,~~~.r;~': Operations Summary Operational shutdown. ~;{" *Yr: SJ612008 00:00 - 9l6/2008 OOt00 ' Operations Summary Operational shutdown. 9/6/2008 00:00 = 9t7k~ ~~ ~~~ OIF' ~fi~; ~ ~ ~ ~> °~~°x. Operations Summary Operational shutdown. $%7~~~~'~tf~,~1~ ~`' 91$f2008 00 00 ~ ~ _~ ~ ~ ~ '~~`~~' Operations Summary Operational shutdown. ~18f2008 00:00 - 9/9/2008 00:00 ~ ~- ~`~ Operations Summary Operational shutdown. 9/9/2008 OQ:00 . 9/10/2QQ8 OO:OQ r,~~~~w . ~" '~~ Operations Summary Operational shutdown. Contacted AOGCC to give notification of BOP test and operation startup (possibly the afternoon of the 11th). 91~t~f2008 OO~QO'` 9f~'~/~OQ$ 60`00 ~ ~~ ~~,E { ~.~~ ~ . ~~ ~ ~~ ~~* ~" ~~ ~~ ~~ ~~ ~ Operations Summary Operational shutdown. Contacted AOGCC Chuck Scheve to give notification of upcoming BOP test. 9C1112008 00•00 - ~M~f~ $ ~Q~k`~ ~ ' ~,.." ; ~' ~- '~' ;~ ~'`x ~~' Operations Summary Contacted AOGCC about resuming operations and upcoming BOP test. Mobe Cudd Unit onto well. 8~1~l~t~~t~0 00 9/13/2008 00 b0 ~ ~~ ~` ~ ~~ ~ ~ ~ ` Operations Summary BOP test 3000 high and 250 low. Test witnessed by AOGCC Chuck Sheve. Circulate well. Pull hanger to window. Test penetrator splice. Tested good. Break out hanger, lay down same. POOH w/ESP equipment. 20bph loss rate. . ,, E~;;r~ ` ~~~ 9[13/1~008 00:00 - 9/14I2008 40t00 "~ u, ~ ~, ~ A`` m~ ~'~ ~~ ~a;" ~ ~>r, i ~ ` u > _ ~, m„~'~~~~r~~~ ~~ Operations Summary continue to POOH w/ ESP, spooling cable.~ 12 bph loss rate. RU slickline, pull standing valve out of ZN nipple. Continue to POOH w/ completion. . ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name Legal Weli Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) K-19 TRADING BAY UNIT K-19 ADL0018777 5073320259 AR4466 100.00 . ~„ D~FI O" a ~~ „x ~' ; ~~, i' ~ ~~ ~ , v,4., . . <<., . ~ .~ . ~ ~ , i'.. . ,.~. ~ . ..~ x Mx .i xr'. . 9l14I2008 00:00 - 9/151~Od~`~t1~{10 ~ , ~ ~~ *~ ' ° ` .. .._ . . . ~,.re s•* £ . ~ . . s~ ~. _ _ ... , z Operations Summary POOH with completion. Found burnt cable 15' above motor lead splice. Recovered afl jewlery, clamps and superbands. Top pump section did not turn, 2nd and 3rd sections turned freely. Motor megged good. PU muleshoe & RIH with 4-1/2" killstring to 9532' (original RKB). Circulate well with 600 bbls 3% KCL FIW w/ 1/2% Baracor 100 corrosion inhibitor. '., < ~ ~,..-. ~ , ~t~O~:OQ:00.-8/'~6f2008D0:00 n ~ ~,,,. Aa• .~ ~~~ ~~ ~£~~; Operations Summary Nipple down BOP and nipple up dry hole tree. Test void and tree to 5000psi. ' 9M6/2008 00:00 - 9f1TI~008 OQ:00 ~ ~ ~~ ~~ ` °~; ~~ t~ ~ Operations Summary Demob. ~~~~~~~~~ s ~ STATE OF ALASKA ~ ~ ~(~(~~ ~ ALASKA OIL AND GAS CONSERVATION C~~~SION . ~ REPORT OF SUNDRY W~~~~~~~r~~~~:~~+~r~ ~ n~~ =t~€`:~~'~~: 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Re-Run ESP ~ Performed: Alter Casing ~ Pull Tubing Q Perforate New Pool ~ Waiver ^ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ^ Re-enter Suspended Well ~ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory^ 174-008 . 3. Address: PO Box 196247, Anchorage, Alaska 99519 Stratigraphic~ Service~ 6. API Number: 50-733-20259-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 100' ' Trading Bay Unit, K-19 ~ 8. Property Designation: 10. Field/Pool(s): ADL018777 #19, Cook Inlet Basin, Offshore McArthur Field / Hemlock & G-Zone 11. Present Well Condition Summary: Total Depth measured 13,771' • feet Plugs (measured) 13,441' true vertical ggp2~ . feet Junk (measured) 13,081' Effective Depth measured 13,081' feet true vertical 9342' feet , C ~ a~ ~ ~ ~~ ~~ ~ ~ ~z ~ _~ i: ~ . + s:~ia;.a . , X::".~M`~.i Casing Length Size MD ND Burst Collapse Structural 381 24" 381' Conductor 2591' 13-3/8", X55 2591' 2302' 3090 1540 Surface p591' 9-5/8", 47#, N80 2591' 6870 4760 985' 9-5/8", 47#, N80 3576' 5750 3090 1462' 9-5/8", 47#, N80 5038' 6830 3330 5009' 9-5/8", 47#, N80 10,047' 7225' 6870 4760 Intermediate - Production - Liner 3687' 7", 29#, L80 9769 - 13,756' 9792' 8160 7020 Perforation depth: Measured depth: Reference Attachment True Vertical depth: Reference Attachment Tubing: (size, grade, and measured depth) 4-1/2" 12.6#, L80 9513' Packers and SSSV (type and measured depth) N/A Packer Less N/A - No-Flow Status 12. Stimulation or cement squeeze summary: No Stimulation work this activiry Intervals treated (measured): Treatment descriptions including volumes used and final pressure: No treatments this activity 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 233 41.9 3818 65 65 Subsequent to operation: 272 131.9 3236 70 75 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run None Run Exploratory~ Development Q Service ~ Daily Report of Well Operations Attached 16. Well Status after work: Oil ~^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-110 dated April 17, 2008 Contact Timothy C. denburg ~ ~~°, ~~, ~~~4 ~~ 200~ prepared by Jack R Newell 263-7832 Printed Na Title Drilling Manager ~e r T.v~ 1~r'a.~.~.~ .il^~ Si t ~'" P 263 7657 D t n ~"~a gna ure , ` e hone a - ~..~ ~~, ! ~ ~ i ~t /~l 1_ ~ 2 ~~S'~'d" G•~G.ag Chevron 909 West 9Th Avenue Anchorage, Alaska 99501 ADL18777 #19, Cook Inlet Basin Perforation Data: K-19 ZONE INTERVAL MD TOP BTM Footage DESCRIPTION G-5 12,592' 12,644' S2' Perf'd '94, 95, &'02 w/ TCP 12,677' 12,716' 39' Perf'd '94, '02 w/ TCP HB-0 12,808' 12,848' 40' Re-PerFd TCP '91 &`02 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &`02 HB-2 12,914' 12,988' 74' Re-PerFd TCP `91' 12.994' 13,020' 26' Re-Perfd TCP '91' HB-3 13,060' 13.157' 97' Re-perFd TCP '91 & 50' `02 HB-4 13,157' 13,314' 157' Re-perf'd TCP'91 & 64' `02 HB-5 13,340' 13,415' 75' Re-Perfd TCP `91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) ~ • ~ • hevroi ..`~.` ~ RKB to Sea Level LW) _ KB 35' ~~ ~'- i:' r± • i 24° L,ID 381' ~II . 133/8"- 2591' _ __ ; 9-518~~ CMT 7320' ~ 45I8" 10,047' co-s H&7 7"- 13,756' . PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 ~ 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3l8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours WBD 18777 K-19 05 12 200 K1I1 Platform K-19 Kin Salmon Platform ;',! g Tra ing Bay Unit I j Wellbore Schematic We I K-19 !; Las Comoleted 05-12-200~ ~~~'i Size Type WU Grade/ Conn ID Top Btm Cement Cement Sacks Top 24" Structural 381 13-3/8" Conductor _ 61#, K55, BTC 12.515 35' 2591' 1425 Surf 9-5/8 _ Casing _.... 47#, N80 BTC 8.681 35' 2591' 0 9-5/8" Casing _ 40#, N80 BTC 8.835 2591' 3576' 0 9-5/8" Casing 40#, JL95 BTC 8.835 3576' 5038' 0 9-5/8" . _ Casin;Z---. _47#,N80, BTC----- --• 8.681 5038' 10,047' 800 -- -"--"------'-'-- 7320' 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' Completion: All 4.5" Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-1/2" Tubing 12.6#, L80, Butt, 533 SCC 3.958 36' 9513' Cased Hole Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1/2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile ____ _ . 2 9513" ___ _ 3.725" 5.625" _____ ----_ __ _ _ HES 4-1/2" Sliding sleeve (Down open, up close). 3 9560' 3.813" 4.5" HES 4-1/2" XN 3.725" No-Go / 3.813" 4 9567' 2.922" 5.188" ~ XO 4-1/2"IBTC box X 3-1/2"EUE pin 5 9574' .6' 5.375" Discharge Head and Sub (538/540 Series) -_. 6 9576' 50' ___ _ 5 375" - -- . 3 Schlum Pumps: S5000N CR-CT 69 STB 538/540 -_ _ _ - . -- -__------ RLOY BTHD, 1.00 INC M-TRM, AFLAS, ARZ --.. _ _____ _ 7 9625' 6' 125" 5 AGH: G40-80 CR-CT-540/540 CS BTHD< 1.00 INC M-T - . RM, AFL, ARZ, NI-RST Shaft- 1.00 INC 625 _____ _- 8 9631' 4' S.375" Schlumberger Intake 9 9632' 18' 5.625" Schlumberger Top Protector / Bottom Protector _.___ __.. __ ____ _ _.-- ------ -- _- _ _ _ _ _. _------ _. __---- Schlum Tandem Motor Upper / Lower, 270 HP 1560V 10 9650' 32' 5.625" 104 Amps 60 Hz Model 562, 9, F091, Dominator RX-UT, CS M-TRM XD AS 11 9693' 6' 875" S Motor Base Adapter / Phoenix MDT-XT Type 1-420 . AFL (A346) / Anode w/chem. Inj lines (Base a~ 9693') Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' 52' Perf'd '94, 95, &'02 w/ TCP 1050' 5.96 12,677' 12,716' 39' Perf'd '94, '02 w/ TCP 100' S.10 HB-0 12,808' 12,848' 40' Re-Perfd TCP '91 &`02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-PerPd TCP '91 &'02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-PerPd TCP '91' 1250' 5.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP'91 8 50"02 HB-4 13,157' 13,314' 157' Re-perfd TCP '91 8 64' '02 HB-5 13,340' 13,415' 75' Re-PerFd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pup jt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 gaker Model'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pu Jt. 2. 13,441 1.53 Camco "D" Ni le. Plu set on 1/29/92 B.doc Paqe 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update 5-12-2008 ~1 r ~Chevron ~ Chevron - Alaska ~ Daily Operations Summary Well Name K-19 Field Name McArthur River API/UWI 507332025900 Lease/Serial ADL0018777 CHEVNO AR4466 License No./Prope... 1740080 Orig KB Elev (ftK6) 100.0 Water Depth (ft) JQbs ~ ;,~, ~ '~°~',, <,:~. n~~. "~.~ ~ ~ ~ ~ ~. ,, . . ~ ~ u ~; ,, . . y,... ~y~ . •~ ~ aa ; ~: Job Cat Type AFE No. QC Eng Workover ESP UWDAK-R8028-E... ~.> ~,. ~ ~. ~ . :._ ~. 4 5/5/2008 00:00 - 5/6/2008 00:00 Operations Summary PJSM - Circulate well, monitor losses - Mixed 30 BBL's Saturated Salt Pill - 90 BBI's Salt Pill - Squeezed to 600 PSI - Set BPV - ND Tree - NU BOP 5/6/2008 00:00 - 5/7/2008 00:00 Operations Summary PJSM - MU BOPE Test Equipment - Test BOPs, 250 psi low, 3000 psi high. Test Witness waived by AOGCC. Well losses 1.5 BPH - POH 4-1/2" Tubing and ESP Completion 5/7/2008 00:00 - 5/8/2008 00:00 Operations Summary PJSM- Continue to POH ESP completion - Well taking proper hole fill - Current static loss @ 1.5 BPH 5/8/2008 00:00 - 5/9/2008 00:00 Operetions Summary PJSM- Continue to POH w/ failed ESP completion - Current static loss @ 1 BPH 5/9/2008 00:00 - 5/10/2008 00:00 Operations Summary PJSM & JSA: RU for crane operations, LD ESP Assembly - All pieces retreived from well - NO Fish in hole - Set up replacement ESP - PU to RIH 5/10/2008 00:00 - 5/11/2008 00:00 Operations Summary PJSM - RIH ESP Assembly - Perform electronics diagnosis through instrumentation, All Good - Static Fluid Losses: .25 BPH 5/11/2008 00:00 - 5/12/2008 00:00 Operations Summary PJSM - Continue to RIH new ESP, perform electronic parameter diagnostic on pump, all ok - PU landing joint previously used - prepare to MU hanger 5/12/2008 00:00 - 5/13/2008 00:00 Operations Summary PJSM and JSA - MU hanger, make ESP and control line connections, land hanger, RD ESP equipment, NDBOP, Pull Riser, Install tree and test, Rig down and skid rig to K-22. Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 18, 2008 3:31 PM To: Newell, Jack R [FEP] Cc: Brandenburg, Tim C Subject: TBU K-19 (174-008) Jack, I am reviewing the 404 submitted documenting the recent workover on this well. Is there a greater levei of detail available? The level of detail provided is insufficient for me to adequately review the operations. Call or message with any questions. Tom Maunder, PE AOGCC 8/1$/2008 King Salmon K-19 Workover Page 1 of 1 w ~ Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Friday, September 14, 2007 10:08 AM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Harness, Evan; Buster, Larry W Subject: King Salmon K-19 Workover `~~ ~~ Tom, Chevron is moving from the K-30RD Workover to K-19 ESP pull and replace Workover. We will be cleaning out the 9-5/8" casing, running a USIT log and confirming integrety, followed by a cleanout of the 7" liner, prior to rerunning an ESP pump in the well. We will perform a "no-flow" test within two weeks of bringing the well back on line. We understand we do not need to submit a 403 form for this operation. Please let me know if you would like more information on this well. Chantal Walsh 263-7627 10/15/2008 BOPE test Page 1 of 1 • s Maunder, Thomas E (DOA) From: Farrell, Robert [Alaska Pipe Recovery] [RFDL@chevron.com] ~ ' ~ h~ ,_r~ Sent: Friday, August 29, 2008 7:02 PM ~.J To: aogcc_prudhoe_bay@admin.state.ak.us; Regg, James B (DOA); Fleckenstein, Robert J (DOA); Maunder, Thomas E (DOA) Cc: Hammons, Darrell; Harness, Evan; Tyler, Steve L; Walsh, Chantal [Petrotechnical]; Bothner, Joseph A. Subject: BOPE test To whom it may concern: Since my a-mail yesterday to inform all of our BOPE test things have changed our crews on the King Salmon have been sent to Louisiana because of Hurricane Gustav.At this point in time I do not know when our BOPE test will be but I will inform you as soon as we know when our crews will return. THANK YOU BOB FARRELL DRILL SITE MANAGER MIDCONTINENT ALASKA BUSINESS UNIT RIG 907-776-6698 CELL 907-252-8696 FAX i-866-663-0723 Maunder, Thomas E (DOA) ~N~~ SAP ~ ~ 20D8 From: Farrell, Robert [Alaska Pipe Recovery] (RFDL@chevron.com] Sent: Thursday, August 28, 2008 $:42 AM To: aogcc_prudhoe_bay@admin.state.ak.us; Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: Hammons, Darrell; Harness, Evan; Brandenburg, Tim C; Walsh, Chantal [PetrotechnicalJ; Maunder, Thomas E (DOA) Subject: Bope TEST To whom it may concern: I spoke to Chuck Sheve Wednesday and he ask me to contact ]im Regg about the King Salmon. K-19 initial ROPE test telling him it would be today or early Friday we had some extra wireline work come up and the time frame will be late Friday early Saturday.Mr Regg was not in so I called Mr. Maunder and he ask me to revise my time frame by a-mail THANK YOU BOB FARRELL DRILL SITE MANAGER MIDCONTINENT ALASKA BUSINESS UNIT RIG 907-776-6698 CELL 907-252-$696 FAX 1-866-663-0723 • • SARAH PAL1N, GOVERNOR ~58A OIL ~ S 333 W 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T COM11iI551O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 i Re: McArthur River Field, Hemlock/G Oil Pool, King Salmon Platform K-19 Sundry Number: 308-297 Dear Mr. Brandenburg ~~~l~~~f~ AU a N v 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of August, 2008 Sincerely, Cathy . Foerster Commissioner Encl. STATE OF ALASKA ~~ ~~~~08 ~ A~ OIL AND GAS CONSERVATION COM~IOI~~JG ~+ ®200~~fa~ ~ APPLICATION FOR SUNDRY APPROVALS CommissiA>7 ~~ 20 AAC 2s.2ao t?il & Gas Cons po 1. Type of Request: Abandon ^ Suspend ^ 'onal s own Perforate ^ nC er ^ Other Q Alter casing ^ Repair well ^ lug Perforations ^ Stimulate ^ Time Extension ^ Run Kill string Change approved program ^ Pull Tubing^ ~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Q , Exploratory ^ 174-008 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20259-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No 0 Kin Salmon Platform, K-19' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL0018777~ Kin Salmon Platform 100" McArthur River Field /Hemlock & G-Zone Oil 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,771' 9802' ~ 13,081' 9342' 13,441' 13,081' Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2591' 2,302' 3090 1540 Surface 2591' 9-5/8", 47#, N80 2591' 6870 4760 985' 9-5/8", 40#, N80 3576' 5750 3090 1462' 9-5/8", 40#, JL95 5038' 6830 3330 5009' 9-5/8", 47#, N80 10,047' 7225' 6870 4760 Intermediate Production Liner 3,987' 7" 13,756' 9,792' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6# L-80 9,618' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 8/26/2008 16. Well Status after proposed work: Commencing Operations: Oil 0 ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 6-7600 Date 8/18/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ ~ ~" j Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~ ~S r ~~~ ~ ~ ~~ Subsequent Form Required: ut~ ~` J APPROVED BY ~~ ~~ / C ( j T/_~.~-"~ COMMISSIONER THE COMMISSION Date: ~ ~ Approved by: ~ Form 10-403 Revi ed 06/2Q06~ ~ ~ I A (~ ~ ~~~% `~ ~ ~QQS Submit in Duplicate Chevron • • King Salmon Well # K-19 8/18/08 OBJECTIVE: • Pull tubing and ESP pump. PROCEDURE SUMMARY: 1 MIRU Slickline. RI Shift Sldg Slve Open. RD Slickline 2 Mobilize rig onto K-19 3 PJSM - ND Tree - NU BOPE -All LP mud Lines -All HP Mud Lines -Flow Glass -Test all lines -TEST BOPE Equipment (PULL & PEEK) Remove BPV. PUMU Landing Joint. BO LDS. PU tbg hanger. Pull tbg to first splice below hngr. 4 Cut cable below splice. Meg cable downhole. If cable megs good, resplice cable below hngr & land same. If cable still shows short downhole, raland tbg hngr and continue with WO. 5 PJSM - RU ESP handling equipment/ (Spooler, sheaves, power washer, ...) 6 PJSM -Circulate well, displace well to inlet water, insure standing column of fluid in well, displace returns to production -Flow check well -Pump salt pill as needed -Flow check well 7 POOH w/ 4-1/2" tubing & ESP Equipment. LD ESP equipment. 8 RIH w/ 4-''/z" Kill String. Land same. 9 PJSM - ND BOPE - NU Tree -Pressure Test 10 Release Cudd Pressure Control 11 Place well on operational shutdown while investigating source of ESP failures. K-19 REVISED BY: CVK 8-18-08 King Platform K-19 Wellbore Schematic RKB to Sea Level (MLW) _ ~y„ 13-3/8"- 2591' 9-5/S" CMT 7320' 9-5/8" 10,04T -G06 fib-2 HB-3 ' HB-5 T'- PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 (tD 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours King Salmon Platform Trading Bay Unit Well K-19 Size Type Wtl Grade/ Conn ID Top Btm Cement Cement Sacks To 24" Structural 381 13-3/8" Conductor 61#, K55, BTC 12.515 35' 2591' 1425 Surf 9-5/8" Casing 47#, N80 BTC 8.681 35' 2591 0 9-5/8' ,,,,,,,,, Casing _ 40#, N80 BTC ........ __ _-„8..835 2591' 3576' 0 9-5/8' .,... ,.,, _ Casing 40# JL95 BTC 8 835......... 3576' 5038' 0 9-5/8" Casing,,,,,,,,,,,, 47#,N80 BTC .._ ...,,..8.681 5038' 10 04T 800, 7320' 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' Completion: All 4.5" Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-1/2" Tubing 12.6#, L80, Butt, 533 SCC 3.958 36' 9513' Cased Hole Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1/2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile 2 9513" 3.725" 5.625" HES 4-1/2" Sliding sleeve (Down open, up close). 3 9560' 3.813" 4.5" HES 4-1/2" XN 3.725" No-Go / 3.813" 4 9567' 2.922" 5.188" XO 4-1/2"IBTC box X 3-1/2"EUE pin 5 9574' .6' 5.375" Discharge Head and Sub (538/540 Series) 6 9576' 50' 5 375" 3 Schlum Pumps: S5000N CR-CT 69 STB 538/540 RLOY BTHD, 1.00 INC M-TRM, AFLAS, ARZ 7 9625' 6' 125" 5 AGH: G40-80 CR-CT-540/540 CS BTHD< 1.00 INC M-T - . RM, AFL, ARZ, NI-RST Shaft- 1.00 INC 625 -- 8 9631' -- 4' - - 5.375" Schlumberger Intake 9 9632' 18' 5.625" Schlumberger Top Protector /Bottom Protector Schlum Tandem Motor Upper /Lower, 270 HP 1560V 10 9650' 32' 5.625" 104 Amps 60 Hz Model 562, 9, F091, Dominator RX-UT, CS M-TRM XD AS 11 9693' 6' 5 875" Motor Base Adapter /Phoenix MDT-XT Type 1-420 . AFL (A346) /Anode w/chem. Inj lines (Base @ 9693') Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' S2' Perfd '94, 95, & '02 w/ TCP 1050' 5.96 12,677' 12,716' 39' Perfd '94, '02 w/ TCP 100' 5.10 HB-0 12,808' 12,848' 40' Re-PerfdTCP '91 &'02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &'02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 1250' 5.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2600' 6.46 HB-3 13,060' 13.157' 97' Re-perFd TCP '91 & 50"02 HB-4 13,157' 13,314' 157' Re-perFd TCP 91 & 64' `02 HB-5 13,340' 13,415' 75' Re-Perfd TCP '91' ------ HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) -- 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pup jt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pu Jt. 2. 13,441 1.53 Camco "D" Nip le. Plu set on 1/29192 WBD 18777 K-19 05 12 2008 doc Page 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update 5-12-2008 RKB to 6ea Level ~INLW) _ KB 35 za" ~ 1338~~- 25sr 9-518" 10,047 King Platform K-19 Proposed F= 'H&3 HB-5 ~~~HB-7 T'- sala^ CMT 7320' cow PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 (tD 2304' ng Bay Unit K-19 Size Type Wt/ Grade/ Conn ID Top Btm Cement Cement Sacks To 24" Structural 381 13-3/8" Conductor 61#, K55, BTC 12.515 35' 2591' 1425 Surf 9-5/8" ... .............Casing . .. . 47# N80, BTC 8.681.......... 35'........ 2591' 0 9-5/8" . . . Casing __...._ 40#, N80 BTC 8.835 2591' 3576' 0 9 5/8" - __ _ _Casrng___ _ 40# JL95 BTC _..8 835 3576' 5038 _ 0 9 5/8" Casing _ 47# N80, BTC 8 681 5038' 10 047 800 7320' 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' Completion: All 4.5" Butt Collars are Special Clearance Collars with Manganse Coated Connection 4-1/2" Tubing 12.6#, L80, Butt, 533 SCC 3.958 36' 2,800' Cased Hole Completion Jewelry Detail # Depth ID OD Item 3 2,800' 3.958" 4,5" 4-1/2" L-80 12.6# Buttress Kill String" Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' S2' PerFd '94, 95, & '02 w/ TCP 1050' 5.96 12,677' 12,716' 39' Perfd '94, '02 w/ TCP 100' 5.10 HB-0 12,808' 12,848' 40' Re-Perfd TCP '91 &'02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-Perf'd TCP '91 & '02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 1250' 5.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2600' 6.46 HB-3 13,060' 13.157 9T Re-perfd TCP '91 & 50' '02 HB-4 13 157' 13,314' 157' Re-perfd TCP '91 & 64' '02 HB-5 13,340' 13,415' 75' Re-Perfd TCP '91' -- HB-6 --. - 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pupjt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO 8~ 3-1/2" Pup Jt. 2. 13,441 1.53 Camco "D" Nipp le. Plug set on 1/29/92 OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours K-19 Proposed Schematic 8 18 2008.doc Page 1 of 1 K-19 API 50-733-20259 PTD: 174-008 Update 8- 14-2008 Page 1 of 1 ~ w Maunder, Thomas E (DMA) From: Walsh, Chantal [Petrotechnical] [1NaIshC@chevron.com] Sent: Friday, August 22, 2008 8:52 AM To: Maunder, Thomas E (DOA) Subject: K-19 (Permit to Drill #174-008) Tom, The K-19 (Permit to Drill #174-008) ESP well recently went down with less than two months on production. We are still on the King Salmon platform with the CUDD hydraulic workover unit and would like to utilize it to pull apart the well to investigate why the pump went down immediately after the K-01 RD work. This could potentially put us in the situation of being ready to move on the well as early as this Sunday, pending your expedited approval of the 403. Thank you for the consideration of this request. Please contact Steve Tyler at 263-7649 at the office or myself on my cell phone, 227-0952. Chantal Chantal Walsh PRA Contract Engineer, P.E. walshc a~chevron.com Chevron North America Exploration and Production MidcontinentlAlaska SSU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message, If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7892. 8/22/2008 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 11:43 AM To: 'Buster, Larry W Cc: Alexander, Steve [TWT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: - - ) Larry„ et aln ~.-- ~ ~ ~ ~ ~ _ v~ ``' Thanks much. Tom IRdlaunder. PE AOC;CC From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Thursday, May 29, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [TINT']; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Tmrra,o Thanks. Also, on the current King Salmon wor#c, we are running 2-718" x 5-112" VBR's in the top and t~irr~hears in the bottom of our double gate.. Regards,. Lanny Larry W. Buster Drilling Engineering Manager MidContinent/Alaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 Ibuster@chevron.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 5:04 PM To: Buster, Larry W Cc: Alexander, Steve [TWT']; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Larry. et ale Thanks m€~ch for the reply. There is no need to resubmit the sundry, When it is returned= the hand changes grill be ev~ent_ lm, this case so of the 6nformatian fisted. is from K-12. not K-12RD~ As this exchange has shown. it is important to keep the paperwork consistent workover to workover on a given platfonrrr. On piatforrres ~srhere the rig. cannot or ill not actually be employed, it is probably best to state upfront i~ the CUDD • Page 2 of 3 unit or same other piece of equipment is being employed. One last question, are you employing VBRs? Call or message with any questions. I will plan to place a copy of your reply in the respective well files, Tom Maunder, PE AOGCC From: Buster, Larry W [mailto:LBuster@chevron.com] Sent: Wednesday, May 28, 2008 4:51 PM To: Maunder, Thomas E (DOA) Cc: Alexander, Steve [TVVT]; Walsh, Chantal [Petrotechnical]; Hammons, Darrell Subject: RE: K-12RD (178-057) Tom, We are planning to da the abandonment work on the K-12RD with the CUDD 340 unit currently on the King Salmon Platform. Please advise if we need to re-submit the proposed program for the 10-403? Also, we are submitting a 10-401 for the proposed K-12RD2 today. Lastly, We are using the 3K (double gate and annular} on ail of the King Salmon Wells using the CU[}D 340 un Thanks and Regards, lorry W. Buster [?rifling Engineering Manager Mi€iiContinentjAlaska Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501-3322 Tel: (907) 263-7853 Cell: (907) 250-0374 Fax: (907) 263-7884 lbuster@chevron.cam From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 28, 2008 3:37 PM To: Walsh, Chantal [Petrotechnical] Subject: K-12RD (178-057) Chantal, Would you please forward to Steve Alexander. I don't have his email. Steve, I left you a message. The Commission has received the sundry application to plug this well. Will this work be done using the Cudd HWO unit presently on the platform? If so, then the plan should state this. It is also noted in your letter that you will submit the proposed redrill for sundry approval. The redrill will require a new permit to drill. • Page 3 of 3 Also, a question for both of you. Which BOP stack arrangement is being used on King? This latest sundry has a 2 ram stack with annular which does meet the 3K requirements. I checked back on the 3 sundri tly approved for other wells and 2 have 3 ram stacks (K-22RD and K-01 RD2) and 1 the 2 ram stack K-19). I probably should have caught the difference when they came through, but as I remember they got split up due to questions. Thanks in advance. Tom Maunder, PE AOGCC C] ~~'~s~ Il L l~~ ~~~ (,` ~~'~w~ ~SG,~ ALASSA OIL A1~TiD GAS CO1~T5ERQA'1'IOl~T COM1~II551O1~T Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 ~~y~~Q APR ~ ~ 2008 Re: McArthur River Field, Hemlock/G Oil Pool, TBU K-19 Sundry Number: 308-110 Dear Mr. Brandenburg: o$ ~~,~- o Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~/ Cathy P. Foerster Commissioner DATED this ~ day of April, 2008 • SARAH PALlN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Encl. __ STATE OF ALASKA ,~ AF'R 0 1 2008 ALA OIL AND GAS CONSERVATION COMMON C~'1 APPLICATION FOR SUNDRY APPROVE & Gas Cons. Commission 20 AAC 25.280 Anctioraae 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ RE-Run ESP Change approved program ^ Pull Tubing 0 Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Chevron/ Union Oil Company of California Development ^ Exploratory ^ 174-008 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20295-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No D Kin Salmon Platform, K-19 ° 9. Property Designation: V . 10. KB Elevation (ft): , 11. Field/Pool(s): ADL018777 #19, Cook Inlet Basin, Offshore 100'''' • McArthur River Field /Hemlock & G Zone 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,771' • 9802' 13,081' 9342' 13,441' 13,081' Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381 Conductor 2591' 13-3/8", x55 2591' 2302 3090 1540 Surface 2591' 9-518", 47#, N80 2591' 6870 4760 985' 9-5/8", 40#, N80 3576' 5750 3090 1462' 9-5/8", 40#, JL95 5038' 6830 3330 5009' 9-5/8", 47#, N80 10,047' 7225' 6870 4760 Intermediate - Production - Liner 3987' 7", 29#, L80 9769' 13,756' 9792' 8,160 7,020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Reference Attachment Reference Attachment 4-1/2" 12.6# L80, BTC 9618' Packers and SSSV Type: Packer-less Completion Packers and SSSV MD (ft): Packer-less Completion No flow potential No SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development^ Service ^ 15. Estimated Date for May-08 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Newell - 263-7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ne 263-7657 Date 19-Mar ~` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ g _ ~ I v Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ('~ W t Other: ~jD~~ i P'Si ~d ~ ~~S~•- ~'<f3~ ~ ~ v~ ~ ~~C~l (~ 1 ?~ ~yL~~~L~~~ ~ - C Subsequent Form Required: ~~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: `t' '(/ J ~~ Form 10-403 Reyissed O6l2Q06 ~ ~' ~\ f ~ ~ `~ ~C bjry~n '~tey Z. C~3 Chevron. 909 West 9Th Avenue Anchorage, Alaska 99501 ADL18777 #19, Cook Inlet Basin Perforation Data: K-19 ZONE INTERVAL MD TOP BTM Footage DESCRIPTION G-5 12,592' 12,644' 52' PerFd '94, 95, & '02 w/TCP 12,677' 12,716' 39' Perfd '94, '02 w/ TCP HB-0 12,808' 12,848' 40' Re-Perfd TCP '91 & `02 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 & `02 HB-2 12,914' 12,988' 74' Re-Perfd TCP '91' 12.994' 13,020' 26' Re-Perf'd TCP '91' HB-3 13,060' 13.157' 97' Re-pert'd TCP '91 & 50' `02 HB-4 13,157' 13,314' 157' Re-perf'd TCP '91 & 64' `02 HB-5 13,340' 13,415' 75' Re-Perfd TCP `91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) • :] Chevron ! . Trading Bay Unit K-19 ESP Change Out Revision #0: 03/13/2008 OBJECTIVE: • Change out of the K-19 ESP completion, re-run new ESP completion and return to production operations as an ESP artificially lifted well. PROCEDURE SUMMARY: • Prepare well for workover operations coordinating with platform operations, shift sliding sleeve, equalize. • MIRU: Work over rig on King platform to Leg 1, slot 6, well #K-19, blind and prep surface production piping as needed. • PJSM - RU ESP handling equipment/ Spooler, sheaves, power washer, ...) • PJSM -Circulate well, displace well to inlet water, insure standing column of fluid in well, displace returns to production -Flow check well -Pump salt pill as needed -Flow check well • PJSM - De-completion Operations -Hanger & Surface Dis-connections • PJSM - ND Tree - NU BOPE -All LP mud Lines -All HP Mud Lines -Test all lines -TEST BOPE Equipment • PJSM -Recover ESP Operations -Hanger & Surface disconnects -Inspect all for corrosion, pull cables to spooler as POH • PJSM - POH w/ Completion - LD as pulled -Inspect all for corrosion, cable knicks, flat pack damage, threads ...)Ensure proper hole fill • PJSM - RU Crane -Recover ESP ,disconnect as needed • PJSM - RU Slickline Recover lost pieces of ESP completion pulled. • PJSM - RU Crane & ESP contractor to run ESP -Run ESP Completion • PJSM - ND BOPE - NU Tree -Pressure Test • TURN OVER TO OPERATIONS -Operate well as an ESP artificial lifted oil producer. K-19 Recomplete Objective and Procedure Summary.doc REVISED BY: JRN 03/13/08 RKB KB 35' ~„ 13.3J8"- 2591' 9-5/8" CMT 7320' 9-5/8" 10,04T cow HB3 HB-7 T'-13,756' PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 (a~ 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks Cement Top 24" .................................................. 13-3/8" 9-5/8° ............. 9-5/8" ............. 9-5/8" ............. 9-5/8" ............. 7" Structural .......................................................... Conductor ............._Casi n..g............... ............._Casi_n..9............... ..............Casi_n.9............... ..............Casi_n.g............... Liner ......................................................................................................... 61#, K55, BTC ..................._47#,.._N_80.~.._BTC...................... .....................40#, _N80, BTC .................................................... .................._40#, JL95, BTC.................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ....................._47#, N80,.._BTC....................... 29#, L80, BTC-KC ...................................... 12.515 ....._8.681....... 8.835 ...................................... ....._8.835........ ......8.681......... 6.184 ................................... 35' ........._35.x............ 2591' ................................... .....3576'...... .,.._5038'....... 9769' 381 ........................................ 2591' ......_2591..~......... 3576' ........................................ ........5038.~......... ...._10, 047.x..... 13,756' ............................................ 1425 ................._~.................... 0 ............................................ ................._~.................... ............_800............... ............................................ SurF ....._..._.._............................ ............................................ ............................................ ..........7320.x........... Completion 4-1/2" Tubing 12.6#, L80, BTC 3.958 36' 9618' Cased Hole Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1/2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile 2 9564' 3.813" Sliding sleeve (Down open, up close). 3 9611' 3.725" HES 4-1/2" XN 3.725" No-Go / 3.813" 4 9618' 2.922" XO 4-1/2"IBTC box X 3-1/2"EUE pin 5 9625' 13' Discharge Head and Sub (538/540 Series) 6 9626' 50' 3 Schlum Pumps: S5000N CR-CT 69 STB 538/540 RLOY BTHD, 1.00 INC M-TRM, AFLAS, ARZ 7 9676' 6' AGH: G40-80 CR-CT-540/540 CS BTHD< 1.00 INC M-T RM, AFL, ARZ, NI-RST Shaft- 1.00 INC 625 8 9682' 4' Schlumberger Intake 9 9686' 18' Schlumberger Top Protector /Bottom Protector 10 9695' 32' Schlum Tandem Motor Upper /Lower, 270 HP 1560V 104 Amps 60 Hz Model 562, 9, F091, Dominator RX-UT, CS M-TRM XD AS 11 9747' 10' Motor Base Adapter /Phoenix MDT-XT Type 1-420 AFL (A346) /Anode w/chem. Inj lines (Base @ 9753') Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' 52' Perf'd '94, 95, &'02 w/ TCP 1050' 5.96 12,677' 12,716' Perf'd '94, '02 w/TCP 39' 100' 5.10 HB-0 12,808' 12,848' ___ 40' Re-Perfd TCP '91 &'02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 &'02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-Perfd TCP `91' 1250' 5.09 _ 12.994' 13,020' 26' Re-Perf'd TCP `91' 2600' 6.46 HB-3 13,060' 13.157' _ 97' Re-perf'd TCP '91 & 50' '02 HB-4 13,157' 13,314' 157' Re-perfd TCP '91 & 64' '02 HB-5 13,340' 13,415' 75' Re-PerFd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pupjt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1 /2" Pu Jt. 2. 13,441 1.53 Camco "D" Nipple. Plug set on 1/29/92 WBD 18777 K-19 10 04 07.docPa~e 1 of 1 K-19 APt 50-733-20259 PTD: 174-008 ~„ 13-318"- 2591' s-s1a" CMT 7320' ti' &518" 10,04T co-s PBTD =13,713' TD = 13,756' MAX HOLE ANGLE = 51 ~ 2304' OCTG Rotating Hours 24" 58 Rotating Hours 13-3/8" 279 Rotating Hours 9-5/8" 584 Rotating Hours 7" 17 Rotating Hours Tubing 0 Rotating Hours • Size Type Wt/ Grade/ Conn ID Top Btm Cement Cement Sacks To 24" Structural 381 13-3/8" Conductor 61#, K55, BTC 12.515 _ 35' 2591' 1425 Surf 9-5/8" Casing 47#, N80, BTC - 8.681 35' 2591' 0 _ _ _ 9-5/8" Casing 40#, N80, BTC 8.835 2591' 3576' 0 9-5/8" Casing 40#, JL95, BTC 8.835 3576' - 5038' 0 -_ 9-5/8" Casing 47#,N80, BTC 8.681 5038' 10,047' 800 7320' 7" Liner 29#, L80, BTC-KC 6.184 9769' 13,756' Completion 4-1/2" Tubing 12.6#, L80, BTC 3.958 36' 9540' Cased Hole Completion Jewelry Detail # Depth Length ID OD Item 1 35' 3.958" 12" x 4-1 /2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile 2 9540" 3.813" Sliding sleeve (Down open, up close). 3 HES 4-1/2" XN 3.725" No-Go / 3.813" 4 9570' 2.922" XO 4-1/2"IBTC box X 3-1/2"EUE pin 5 13' Discharge Head and Sub (538/540 Series) 6 50' 3 Schlum Pumps: S5000N CR-CT 69 STB 538/540 RLOY BTHD, 1.00 INC M-TRM, AFLAS, ARZ 7 6' AGH: G40-80 CR-CT-540/540 CS BTHD< 1.00 INC M-T RM, AFL, ARZ, NI-RST Shaft- 1.00 INC 625 -._..._.W._.. __._ 8 4' Schlumberger Intake 9 18' Schlumberger Top Protector /Bottom Protector Schlum Tandem Motor Upper /Lower, 270 HP 1560V 10 32' 1 04 Amps 60 Hz Model 562, 9, F091, Dominator RX-UT, _. _ CS M-TRM XD AS _ _._ 11 9700' 10' Motor Base Adapter /Phoenix MDT-XT Type 7-420 AFL (A346) /Anode w/chem. Inj lines (Base @ 9753') Perforation Data Doglegs ZONE TOP BTM Shot Condition 1000' 4.18 G-5 12,592' 12,644' 52' Perfd '94, 95, & '02 w/ TCP 1050' 5.96 12,677' 12,716' 39' Perfd '94, '02 w/TCP 100' 5.10 HB-0 12,808' 12,848' 40' Re-PerPd TCP '91 & `02 1150' 4.98 HB-1 12.882' 12,892' 10' Re-Perfd TCP '91 & '02 1200' 6.30 HB-2 12,914' 12,988' 74' Re-PerPd TCP `91' 1250' 5.09 12.994' 13,020' 26' Re-Perfd TCP '91' 2600' 6.46 HB-3 13,060' 13.157' 97' Re-perfd TCP '91 & 50' '02 HBO 13,157' 13,314' 157' Re-perf'd TCP '91 & 64' `02 HB-5 13,340' 13,415' 75' Re-PerPd TCP '91' HB-6 13,460' 13,545' 85' Isolated 1/29/02 HB-7 13,594' 13,604' 10' Squeezed (Cement) 13,615' 13,645' 30' Squeezed (Cement) FISH 13,388 Milled Baker 'FB-1' Perm Packer, Baker SBE, XO, Pup jt, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pu Jt. 2. 13,441 1.53 Camco "D" Ni le. Plu set on 1/29/92 WBD 18777 K-19 Pronosed 10 04 07.doc Paae 1 of 1 K-19 API 50-733-20259 PTD: 174-008 • King Salmon K-19 BOP Stack HWOU 13 5/8" Hydril 5M 3.9' S5" Test Pressure: 250/3000 psi A,III.B 3 1N6"SM x 4 1116"5M DSA A 4 1/16" 5M Foster HCR Valve B 4 1/16" SM Manual gate valve C 3 1/16" 5M Manual gate Kill line D 3 1116" 5M Manual gate Kill line 13 518" 5M Mud Cross 2.24' 13 5/8" 5M Riser 13.60' ~„ ~~ 27" I 14" Top Deck 10.90' 12.67' Top of FMC Type OBS King Salmon Platform: RU Ding ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Walsh, Chantal [Petrotechnical] [WalshC@chevron.com] Sent: Wednesday, April 16, 2008 6:01 PM To: Maunder, Thomas E (DOA) Cc: Hammons, Darrell; Tyler, Steve L Subject: King Salmon Platform: RU Drawing Attachments: circdrawing two mud pumps ks-19.jpg; ks k-19 deck skid layout.jpg; ru ks well-ks-19.jpg Tom,.. Please find attached the rig: up diagrams for the Cudd Unitwe wi1E be utilizing; on the upcoming Keg campaign.. Please contact me if you have further questions or require more information: 1Ne are looking at an early May start date far the work. Chantal. Walsh Chevron Project Manager (907) 263-7E27 4/17/2008 'Ht.,it: '" f'Ihw~lnrth Irrw, '." iai3 Wncu " ~. Pcr~ A Ytf f .inc Ak~r•1 T>F 4 int. '1 :•. l..fi•..' 1'; i1 iu tic' ii,;Ncr __ i ,J i': '~ ~"~., ~ ~~ v 7'' S'vj~,/'PlFlrnn tt r,if S 't'u t I 3+ a" I~,r ird, --~,~ ~' f drl'~ltfU[ HLY7C i ~' t :~rn4rk Wi-* Hrrwr. CaantanY Yt9rn AaT-vn)fma w~ a n' I3 w,,. <..- BvP~ .. t3nY Vat' .~ :, i = Its 341 ~4 2"3~Y21~ero.~+ ?c~ .p ~~ _~ ,~ n1._ ~1~ ]tt3 Y 1" A'a tit.~s ~..~~ t`t+t 4"'i,duty Iir l •: (•h.•ta T,ino 7 ~ ~a,lale iL,at .a.. -~ '" ra„« tk.x~. Trmtrrlur .~r FMatrrft z" °++' . ~- I- Ait FT~wv . N.rnq, lA.oii,rtr! 2 aq+c" ~ ~ '~. ~ . ~ ,mod -- ?° i'.1IY71~alf! 1't~CI! 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L;'1• j .__I~ . _ } _ [ s _.-.._ '.... -.~•] ""`''fir, .3~ .7FK .Ri~i.P~ _,. ;`Zf~ k7~ ~ ~ tip, E~~fi~°) 55' ~ ers~t b ~-. ~ ~ -:: r J ~,~_ ~" ~ ~"k!' r~e7 ~r~.~ `mss!: . - _-- ~ ~ - , a., mL .~_. _ -- ~, Elr~•a~tnY1 .t~ -I - -A~~._ _._~.._ - - --- ~ ,.. ~ I ;t; ~.~ ,. 3a•x~;r ~ ~ ; - __-Y--- -- _ I ~ _ ,. • ~.0~i ~41~ ~C f i X~f ,I 3~i J ' ~~. _... __._ ~. _..._.. _._ _.._._._____._. ___ __-. _._.._ _-_._..____ ~.~w ~~ rrrr ,~ .lii:T[tfi ~~t:~ .~1 r I ~ ~c ',.fl:'!_ ~_ __ ~ ~~ .. i{.n ~ ,.,. ~stSt:[Tf..~G ~• I_~ ;~*• 3Sb p u.~,C~ ~ ~ 1 -_ ' • • Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: Tuesday, April 15, 2008 8:10 AM To: 'Walsh, Chantal [Petrotechnical]' Cc: Tyler, Steve L Subject: RE: Cudd Unit Drawings for upcoming King Salmon work Hi Chantal, Any news on the drawing(s)? Tom -----Original Message----- From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Friday, April 11, 2008 2:47 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L Subject: Cudd Unit Drawings for upcoming King Salmon work Tom, Chevron will be using the Cudd Unit for the upcoming work on the King Salmon Platform. The updated rigup illustration has been requested and I will get it to you next week. Have a great weekend. Chantal (907)227-0952 -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 09, 2008 10:09 AM To: Walsh, Chantal [Petrotechnical] Subject: FW: [Fwd: BOPS Proposal] -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, December 16, 2004 7:51 AM To: Jim Regg Subject: [Fwd: BOPE Proposal] Here are the equipment drawings. -------- Original Message -------- Subject: BOPE Proposal Date: Tue, 14 Dec 2004 08:26:28 -0900 From: Buster, Larry W <lbuster@unocal.com> To: tom_maunder@admin.state.ak.us CC: Harness, Evan <eharness@unocal.com> Tom, We have worked up a proposed BOPS diagram for the CUDD HWO on the King Salmon Platform. I have attached the diagram for your review. As you can see, the proposal eliminates chicksan hard line in the critical flow paths and uses rotary and circulating hoses. Also, the Choke Manifold in the system is a unocal owned skid mounted unit. I have attached a diagram of this manifold. «unocal king salmon circdrawing one mud pumps revl.jpg» «KS manifold.xls» 1 • Chevron Francisco Castro Technical Assistant January 3, 2008 To: AOGCC Mahnken, Christine R 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~ . ~ . ~ Chevron North America Exploration and Production 909 W. 9th Avenue Anchorage, AK 99501 Telex .907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com ~~~~~~~ JAS ~ 2~~£ ~~~~ 'NELL LOG TYPO ~ SCA.LE ~ LOG D?.TE ~~JTEn SAL RUN ~~ B- LOGGED # ~ LINE -- ~i ~_ - _ J- -I-- - ~' - ---'~ ULTRA SONIC IMAGING LOG -FIELD PRINT CEMENT AND CORROSION 150 - K-19 EVALUATION 5" 21-Sep-07 9720 1 1 ~~1- D~`~ ~ LS ~'S ~5 ~~' L ~ i NOTES - ~~ FILhr1 ~ OD ~ ~S' I PDS, _~_ D~`~_~ _~ PDS Please acknowledge receipt by signing and returning one copy of thi~~1~ brit; 't`c~l" F ti`9.07 263 7828. Received By: Date: z ; _: -_ ~~t __. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS /~ 1.Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Run ESP Performed: Alter Casing ^ Pull Tubing 0 Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory^ 74-008 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20259-00 7. KB Elevation (ft): Number: 9. Well Name a RKB to Tubing Head = 35' . K-1 ~ ~ 8. Property Designation: ' 10. FieldlPool(s): O ~ King Salmon Platform/Cook Inlet ADL Oo~8,7~ McArthur River Field Hemlock / G Zone ~ p 11. Present Well Condition Summary: ~ ~„ ar *"' ~ cy Total Depth measured 13,771 feet Plugs (measured) 13,441' ~ ~ ~ 'A ..mod true vertical 9802 ~ feet Junk (measured) 13,081' ° ~ ~ Effective Depth measured 13,081' feet ~F~!,~~,~ ND~I ~ ~(}~~ ~ ~ Q true vertical 9,342' feet N ti' 0 Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-318" 2,591' 2,302' 3,090 psi 1,540 psi Surface 10,047' 9-518" 10,047' 5,183' 6,870 psi 4,750 psi Intermediate Production Liner 4,077' 7" 13,756' 9,792' 8,160 psi 7,020 psi Perforation depth: Measured depth: 12,592' - 13,645' (See attached schematic) True Vertical depth: 8270' - 9718' (See attached schematic) Tubing: (size, grade, and measured depth) 4-1 /2" 12.6 # 9,618' Packers and SSSV (type and measured depth) Baker Mod D @ 13,420' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: tx ~~~ ~~~f°' 4=~~.. (((({{ {{11 n f ~ /, i ~ ~ { / -. 1FSf F R' ~ ,f IVIj? 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 283 351 3713 70 75 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run USIT Exploratory ^ Development ~ Service ^ Daily Report of Well Operations attached 16. Well Status after work: Oil ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N!A if C.O. Exempt: n/a Contact Chantal Walsh - 263-7627 Printed Name Timothy Brandenburg ,. _~ Title Drilling Manager .~ ~ Signature Phone 907-276-7600 Date r d - ~ ~- V Form 10-404 Revised 04/2006 '~~( (? ~~ ~- ~t~~C Submit Original Only r_7 Ah Chevron Chevron - Alaska SWW Daily Operations Summary Well Name Field Name APIIUWI Lease/Serial Ong KB Elev (ftKB) Water Depth (ft) K-19 McArthur River 507332025900 JADLOO18777 100.0 Primary Job Type Primary Wellbore Affected ESP Main Hole Jobs Primary Job Type Job Category AFE No. Objective Actual Start End Date OC Engineer ESP Workover R7020 9/14!2007 Daily Operations 9/14/2007 00:00 - 9/15/2007 00:00 Operations Summary Skid rig from K-30 to K-19. Pump/circulate Hydrocarbons from wellbore. Clean fluid @ 900 BBLs pumped. Monitored well. Lost 20 bbls in 1/2 hr. Mix 85 bbls of sized salt. 9/15/2007 00:00 - 9/16/2007 00:00 Operations Summary Mix 85 bbls of sized salt pill. Mix 30 bbls of satuated salt pre & post pads. Pumped 10 bbls of pre -pad, 70 bbls of sized salt pill, 10 bbls of post pad. Displace with 71 bbls of 3% KCI. Final squeeze pressure was 1250 psi. ND tree. NU BOPE. 9/16/2007 00:00 - 9/17/2007 00:00 Operations Summary Conduct BOPE test. 9/17/2007 00:00 - 9/18/2007 00:00 Operations Summary BO LDS. Pull tbg hngr to rig floor. LD same. Pulling OOH with tbg while spooling cable. 9/18/2007 00:00 - 9/19/2007 00:00 Operations Summary Laid down Production TBG. Recovered the ESP 9/19/2007 00:00 - 9/20/2007 00:00 Operations Summary Laid down Centerlift pump. Full recovery of ESP equipment, clamps and bands. WU 8-1/2" mill & 9-5/8" scrapper BHA. Install wear bushing. RIH w/ CO assy. 9/20/2007 00:00 - 9/21/2007 00:00 Operations Summary RIH with Csg scrapper/ bit BHA. Circulate while RIH. AT 5,904' CBU. Cont to TIH. Tagged top of liner. Installed Kelly, PU 10' and CBUx2. Start to POOH. 9/21/2007 00:00 - 9/22/2007 00:00 Operations Summary Finish POOH w/ CO BHA # 1. UD Same. R/U Eline. PUMU USIT tool. Schlumberger surface equipment problems. Losses @ 9 bph 9122/2007 00:00 - 9/23/2007 00:00 Operations Summary Loa csq w/ USIT from 34' to surface. RD Eline. PU RTTS Sqz pkr. RIH w/ same. Losses @ 6 bph 9/23/2007 00:00 - 9/24/2007 00:00 Operations Summary GIH w/ RTTS PKR. Set RTTS PKR & 9791'& 6594'. Test 9 5/8" to 800 & 1000 psi for 30 min. OK. POOH. Lost 97 bbls last 24hrs. 9/24/2007 00:00 - 9/25/2007 00:00 Operations Summary POOH w/ RTTS PKR. LD same. Replaced the bag in annular preventer. N/U Same. Conduct BOP test w/ AOGCC Rep on location. 9/25/2007 00:00 - 9/26/2007 00:00 Operations Summary Pull Test Plug. M/U BHA # 2. TIH. Tag fill @ 13,055'. 9/26/2007 00:00 - 9/27/2007 00:00 Operations Summary CBU @ 13,040'. Drop ball. Circ w/ Jet basket. RI to 13,055 while washing w/ reverse basket. Work to 13,058'. POOH. 9/27/2007 00:00 - 9/28/2007 00:00 Operations Summary Finish TOOH. LD BHA. Basket recovered small pieces of metal and small pebbles. MU Junk Mill BHA with boot baskets. TIH to 12, 127. Monitor well for losses (current 2-3bbls/hr). 9/28/2007 00:00 - 9/29/2007 00:00 Operations Summary RIH w/ C/O assy. Tag fill @ 13,056'. CO to 13 116'. POOH. 9/29/2007 00:00 - 9/30/2007 00:00 Operations Summary POOH. Recovered BHA # 3. Clean string magnet and Boot Subs. Recovered (3) Cannon clamp pins, 6" piece of 1-1/4" Super band, (7) marble size rocks and (1) rock over 1" in diameter. P/U New Junk Mill & TIH. ~~ r 1 Chevron ~~ Chevron -Alaska li SWW Daily Operations Summary Well Name Fiefd Name API/UWI Lease/Serial Orig KB Elev (ftKB) Water Depth (fti K-19 McArthur River 507332025900 ADL0018777 100.0 Daily Operations 9/30/2007 00:00 -10/1/2007 00:00 Operations Summary RIH w! C/O BHA. Wash/Ream & Cleanout from 13,048' to 13,139'. No Further Progress. POOH. DSM Notes: Notified AOGCC @ 1830 hrs of ROPE test on Sep 30. Called Jlm Reggs office @ 1850 hrs. Chuck Sheve called back & confirmed date. Call Reggs on Monday I 10/1/2007 00:00 - 10/2/2007 00:00 Operations Summary PU to 9675', above TOL. RIH dry tag top of junk/fill @ 13,123' JBM (13,081 RKB). POOH. AOGCC- called Reggs at 0845 hrs. & 1000 hrs. 10/2/2007 00:00 - 10/3/2007 00:00 Operations Summary Continue to POOH. LD BHA. RI w/ test plug. Set same. 10/3/2007 00:00 - 10/4!2007 00:00 Operations Summary Finished BOPE test. PU ESP a ui ment. 10/4/2007 00:00 -10/5/2007 00:00 Operations Summary Finished PU of ESP equipment. RIH w/ same. 10/5/2007 00:00 - 10/6!2007 00:00 _ Operations Summary Finish cable splice @ 5,035' Qoint 157). Cont to RIH w/ 4 1/2" tubing. MU hngr in window. MU control lines to hngr. Test hanger. Tbg Hngr landed 18:15 hrs. P/U Wt.158K S/O Wt. 56K. Landing depth (Btm of pump) 9,753' original RKB. RD Schlumberger, LD landing joints. Break down flow line and drilling nipple. ND BOPE. Ran In WeN: 306 joints of tbg, 4 bands below motor splice, 6 pump clamps, 7 protectolizers, 2 motor clamps, 157 cannon clamps. 1016/2007 00:00 -1017/2007 00:00 Operations Summary Finish ND ROPE (note cleaned stack as we set it down). NU tree. Pressure test void and shell test tree. OK. Worked to LD D.P. & Tools. 10/7/2007 00:00 - 10/8/2007 00:00 Operations Summary LD DP. Rigging down HWO Rig. Demobing same. I 10!8/2007 00:00 -10/9/2007 00:00 Operations Summary I Continue Demobe from King Platform _ 10/9/2007 00:00 -10/10/2007 00:00 Operations Summary Continue Demobing HWO rig from King Platform. 10/10/2007 00:00 -10/11!2007 00:00 ~ Operations Summary I Continue Demobing HWO Rig and equipment. 10111/2007 00:00 - 10/12!2007 00:00 Operations Summary Continue Demobe of HWO rig. I 10/12/2007 00:00 - 10/13/2007 00:00 ~ Operations Summary I Finished Demobe. Release K-19 well to Production. ~ Chevron • ~ Kin Salmon Platform g Well # K-19 Completed 10/04/07 RKB to TBG Head = 35' ~ec~~c ~\'rl "I't RI'~r rIPTAII 2,591 TOC 7320' USIT 09/07 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,591' 9-5/8 47 N-80 BTC 8.681 35' 2,591' 9-5/8" 40 N-80 BTC 8.835 2591' 3,576' 9-5/8" 40 JL-95 BTC 8.835 3,576' 5,038' 9-5/8 47 N-80 BTC 8.681 5,038' 10,047' Liner 7" 29 L-80 BTC-KC 6.184 9769' 13,756' Tubin : /m roved Buttress Tubin 4-l/2" 12.6 L-80 BTC 3.958 36 9618' iFWFt.RV IIFTAIi. 9,769' 10,047' GS G-5 HB-0 G-6 HB-1 HB-2 `r r ~' ~ HB-3 f`~ ' HBd HB-5 1,2 HB-6 HB-7 NO. De th Len th ID OD Item 35' 3.958 12" x 4-1/2" FMC 8rd Tbg Hngr w/ Type "H" BPV Profile 9564' 3.813 Sliding sleeve (Down open, up close). 961 l' 3.725 HES 4-1/2" XN 3.725" No-Go / 3.813" 9618' 2.938/2.922 XO 4-1/2"IBTC box X 3-1/2"EUE pin 9625' 1.3' NA Dischazge Head and Sub (538/540 Series) 9626' S0' NA 3 Schlum Pumps: SSOOON CR-CT 69 STB 538/540 RLOY BTHD, 1.00 INC M-TRM, AFLAS, ARZ 9676' 6' NA AGH: G40-80 CR-CT-540/540 CS BTHD< 1.00 INC M-T RM, AFL, ARZ, NI-RST Shaft- 1.00 INC 625 9682 4' NA Schlumberger Intake 9686 18' NA Schlumberger Top Protector /Bottom Protector 9695 32' NA Schlum Tadem Motor Upper /Lower, 270 HP 1560V 104 Amps 60 Hz Model 562, 9, F091, Dominator RX-UT, CS M-TRM XD AS 9797' l0' N.4 Motor Base Adapter /Phoenix MDT-XT Type i-420 .4FL A346 /Anode w/chem. In' lines Base 9753' FISH 13,388 Milled Baker `FB-1' Perm Packer, Baker SBE, XO, Pup t, XO, Camco WP-1 Ni le, XO, Pu , WLEG 1. 13,420 20.50 Baker Model `D' Perm Pkr, 5' MOE, XO & 3-1/2" Pup Jt. 2. 13,441 1.53 2.'75 Camco "D" Nipple. Plug set on 1/29/92 PERFORATION DATA Zone Top Btm Amount Condition G-5 12,592' 12,644' S2' Perfd '94, '95 & '02 wl TCP 12,677' 12,716' 39' Perf'd '94 8 '02 w/ TCP HB-0 12,808' 12,848' 40' Reperf'd TCP'91 &'02 HB•1 12,882' 12,892' 10' Reperf'd TCP'91 &'02 HB-2 12,914' 12,988' 74' Reperf'd TCP '91 12,994' 13,020' 26' ReperFd TCP'91 HB-3 13,060' 13,157' 97' ReperFd TCP '91 & 50' in'02 HB-4 13,157' 13,314' 157' ReperFd TCP '91 & 64' in'02 HB-5 13,340' 13,415' 75' Reperf'd TCP '91 HB-6 13,460' 13,545' 85' Isolated 1/29/92 HB-7 13,594' 13,604' 10' Cmt Sqzd 13,615' 13,645' 30' Cmt Sqzd PBTD = 13713' TD = 13771' MAX HOLE ANGLE = 51 ° ~ 2304' K-19 Actual Schem 10-04-07.doc REVISED: 11 /6/07 CRW • - - SARAH PALtN, GOVERNOR ~~ ® ~~ ~~ 333 W. 7th AVENUE, SUITE 100 ~-7~~~~~®1py ~® ~-a~+$®~ ANCHORAGE, ALASKA 99501-3539 ~.i 1i~~ ss77ss77 PHONE (907) 279-1433 FAX (907) 276-7542 October 16, 2007 Mr. Chris Myers Field Superintendent Unocal PO Box 19627 Anchorage, Alaska 99519 RE: No-Flow Verification c~' APR ~ ZOD~ Trading Bay Unit K-19, PTD 174-008 Dear Mr. Myers: On_October 12, 2007 an AOGCC Petroleum Inspector witnessed a "no flow- test'' at Unocal's King Salmon platform, Trading Bay Unit Well K-19. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated an initial flaw of 1500 standard cubic feet per hour, quickly falling to an immeasurable rate while open to atmosphere. Well pressure built to 1 psi during the shut-in monitoring period. A subsequent flow test confirmed the first flow results, with well pressures falling to less than 1 psi and gas rate rapidly falling to immeasurable flow. No liquid hydrocarbons were present at surface. The subsurface safety valve may be removed from service in Well K-19 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 King Salmon platform. Sincerely, ;'~i ~ ) ~- Cathy/. Foerster Commissioner cc: Bob Fleckenstein • MEMORANDUM .--~.. TO: Jim Regg (P.I. Supervisor) j~~ ~ ~L`7/ r~5 (~ 7 Petroleum Engineer I l ~/~j THRU: FROM: Lou Grimaldi ~.~~-;t~~~~ Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 12, 2007 SUBJECT: No Flow test TBU K-19 i King Salmon Platform Trading Bay Field PTD 1740080 I witnessed a No-Flow test on Chevron's well TBU K-19 aboard the King Salmon platform. The test went well with no fluid produced to surface and the gas flow so low as to be immeasurable. A new 60 psi gauge with 1 psi increments and a Erdco flow meter with a span of 180 scf to 1800 scf were used. I ran ashut-in and bleed sequence three times with similar results (as noted below). The well appears to meet no-flow criteria. This well appears to meet the No-Flow criteria. r:nmmantc 0840 1.5 1500 Flowin to atmos here o en casin vent valve. Flow at 1500 scf 0845 <1 900 Flowin to atmos here. 0900 <1 300 Flowin to atmos here. 0905 <1 <180 whis er Flowin to atmos here. Shut-in well. 0935 <1 SI Shut-in for build u . 1015 1 1800 O en well to atmos here 1016 <1 1500 Flowin to atmos here. 1017 <1 1100 Flowin to atmos here. 1020 <1 450 Flowin to atmos here. 1023 <1 200 Flowin to atmos here. 1025 <1 <180 Flowin to atmos here. 1030 <1 <180 whis er Flowin to atmos here. 1045 <1 <180 whis er Flowin to atmos here. Shut-in well. 1145 1 1800 O en well to atmos here 1146 <1 1500 Flowin to atmos here. 1147 <1 900 Flowin to atmos here. 1148 <1 700 Flowin to atmos here. 1150 <1 400 Flowin to atmos here. 1152 <1 <180 Flowin to atmos here. 1155 <1 <180 whis er Flowin to atmos here. 1200 0 <180 whis er Flowin to atmos here. Shut-in well. 1300 1 1800 0 en well to atmos here 1301 <1 1600 Flowin to atmos here. 1302 <1 1200 Flowin to atmos here. 1303 <1 700 Flowin to atmos here. 1304 <1 500 Flowin to atmos here. 1305 <1 200 Flowin to atmos here. 1306 <1 <180 Flowin to atmos here. 1310 <1 <180 whis er Flowin to atmos here. 1330 <1 <180 whis er Flowin to atmos here. Conclude test. ~'~ ~ SS V ~~vvL ~,d ,'\ltt.' c Pagel of 1 No Flow TBU K-19 10-12-07 LG.xls 10/15/2007 . . FRANK H. MURKOWSKI, GOVERNOR AI~ASKA OIL AM) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 18, 2006 Mr. Chris Myers Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit K-19, PTD 174-008 Dear Mr. Myers: On July 10, 2006 an AOGCC Petroleum Inspector witnessed a "no flow test" at Unocal's King Salmon platform, Trading Bay Unit Well K-19. The well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. The well demonstrated no gas or fluid flow while open to atmosphere, and no pressure build-up during a shut in monitoring period. The subsurface safety valve may be removed from service in Well K -19 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 c1eanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the King Salmon platform. Sincerely, ./'~. . /~ ...\.......-;) 1/ ~~~~~ .~~~~ 9 ? Petroleum Inspection Supervisor cc: Bob Fleckenstein Ale;, it76 STATE OF ALASKA "c ALA. OIL AND GAS CONSERVATION COM ION l\UG 0 8 ¿LJ06 REPORT OF SUNDRY WELL OPERA TION~laska Oil & Gas Cons. Commission Kt:L,L-1 V L-U . 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Othèr ~ Ruñ ESP Performed: Alter Casing D Pull Tubing 0 Perforate New Pool D WaiverD Time Extension D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: r/I¥lO(. Name: Development 0 Exploratory D 74-0008-0 /7 ~~JFJg() .ðCú 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service D 6. API Number: 50-733-20259-00 7. KB Elevation (ft): 9. Well Name and Number: RKB to Tubing Head = 35' K-19 8. Property Designation: 10. Field/Pool(s): King Salmon Platform/Cook Inlet McArthur River Field/ HemlocklG-Zone 11. Present Well Condition Summary: Total Depth measured 13,771 feet Plugs (measured) N/A true vertical 9,802 feet Junk (measured) 13,388' Effective Depth measured 13,713 feet ·.:.r· .,~ ,;_. G . , <"'0"" I\U' lId: L '~;Cì true vertical 9,765 feet .,...,.... ..... ~.... Casing Length Size MD TVD Burst Collapse Structural 381' 24" 381' 381' Conductor 2,591' 13-3/8" 2,591' 2,302' 3,090 psi 1,540 psi Surface 12,782' 9-5/8" 12,782' 9,143' 6,870 psi 4,750 psi Intermediate Production Liner 4,077' 7" 13,756' 9,792' 8,160 psi 7,020 psi Perforation depth: Measured depth: See atached schematic True Vertical depth: See attached schematic Tubing: (size, grade, and measured depth) 4-1/2"/3-1/2" L-80, 12.6/9.2 ppf 9,585'/11,789' Packers and SSSV (type and measured depth) Baker Mod D @ 13,420' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: RBDMS BFL AUG 1 4 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 383 354 3854 60 80 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run N/A Exploratory D Development 0 Service D Daily Report of Well Operations Attached 16. Well Status after proposed work: Oil0 Gas D WAG D GINJ D WINJ D WDSPL D 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: 306-194 Contact Printed Name Timothy C. Brandenburg Title Drilling Manager - -c20-¿\ ~ Signature r / Phone 907-276-7600 Date K ...z~ r Form 10-404 Revised 04/2004 ()R I GINA b:~D;¿Jf Submit Original Only . Chevron 1&1 . . King Salmon Platform Well K-19 ESP Workover Summary Dailv W orkover Summary: 7/1/06: Accept HWO and start to rig-up. 7/2/06: Continue to R!U HWO. 7/3/06: Continue to R!U HWO. 7/4/06: NID Tree and N/U BOPE. Continue to R!U HWO. 7/5/06: Test BOP to 250/3000 psi. Install landing joint. Circulate well with 3% KCL brine. 7/6/06: Continue to pump 3% KCL brine. R!U e-line. RIH and punch holes in tubing from 11,813.5' to 11818.5'. POOH. RID e-line. Pump 60 bbl Sized salt LCM pill and pump into place. Circulate well clean with 3% KCL brine. 7/7/06: Monitor well. Circulate well with 3% KCL brine. Perform platform drills. Pull and LID tubing hanger. Pull and stand-back tubing joints. 7/8/06: Continue to pull failed ESP completion. 7/9/06: Continue to pull failed ESP completion. LID ESP BRA. 7/10/06: M!U clean-out BRA and RIH on tubing work string to 11,952'. 7/11/06: Continue to RIH to 13,085'. Attempt to work past. No go. Circulate with 3% KCL brine thru mud motor and rock bit, but unable to wash deeper. Circulate well and observe. POOH. 7/12/06: Finish out of hole. Test BOP to 250/3000 psi. Clean rig. 7/13/06: P/U ESP BRA. RIH on tubing. 7/14/06: Continue to run ESP on 3-1/2" x 4-1/2" tubing. 7/15/06: Continue to run ESP on 4-1/2" tubing to 11,789'. M!U tubing hanger and land same. 7/16/06: Run tubing hanger lock-down pins and test hanger. RID BOPE. RID HWO. 7/17/06: N/U and test tree. Continue to RID HWO. Release HWO. AOGCC K-19 ESP Workover 10-404 Summary RKB to TBG Head = 35' Tree connection: 2,591' 9,769' 10,047' 1,2 PBTD = 13713' TD = 13771' MAX HOLE ANGLE = 51° @ 2304' K-19 Actual Schem 07-15-06 G-5 G-5 HB-O& G-6 HB-1 HB-2 HB-3 HB-4 HB-5 HB-6 HB-7 CASING AND TImING DETAIL SIZE WT GRAUE CONN II) TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,591' 9-5/8 47 N-80 BTC 8.681 35' 2,591 ' 9-5/8" 40 N-80 BTC 8.835 2591' 3,576' 9-5/8" 40 JL-95 BTC 8.835 3,576' 5,038' 9-5/8 47 N-80 BTC 8.681 5,038' 10,047' Liner T' 29 L-80 BTC-KC 6.184 9769' 13,756' Tubing: Improved Buttress Tubinl{ 4-1/2" 12.6 L-80 BTC 3.958 35 9585' 3- 112" 9.2 L-80 BTC 2.992 9585' 11,789' JEWELRY DETAIL OD Hem 12" x 4- 112" FMC 8rd Tbg Hngr wi Type "H" BPV PrQfile Crossover 4-112" IBT Box X 3-112" IBT Pin. Crossover 3- !/T' IBT Box X 3- !/2" 8rd Pin GC 6100 213 stage and 532 HP motor ESP NO. Ue 1. 35' 2. 9586' 3. 11,789' 4. 11,790' FISH 13,388 1. 20.50 2. II) 3.958 2.992 2.992 PERFORA nON DATA 8tm Condition Top 12,592' 12,577' 12,808' 12,882' 12,914' 12,994' 13050' 13,157' 13,340' 13,460' 13,594' 13,615' REVISED: 8/1/06 LWB . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . ~'¿Î' DATE: P. I. Supervisor' ï( 11 (\'VI o!P August 11 , 2006 FROM: Chuck Scheve, SUBJECT: Petroleum Inspector King Salmon Platform No Flow Trading Bay Unit K-19 PTO# 1740080 Fridav. August 11. 2006: I traveled to Unocal's King Salmon Platform and witnessed a no-flow test on well K-19. I arrived on location and found the well bled off and opened to atmosphere with no flow of gas or fluid evident. The well was shut in and observed with no pressure build up observed and no flow when reopened. I recommend Well K-19 on the King Salmon Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Well K-19 meets the AOGCC requirements for no flow status. ~~ANNED SEP (J 3 7.DDY: r6 H ~ e rP 'I! ìP U e AI,ASIiA ORAND GAS CONSERVATION COJDIISSION FRANK H. MURKOWSKI, GOVERNOR Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ,\ ,,,, '. ')r\m') _. ..' ......,. .t::......¡;\.. I. it\1 i. t.; c...u~- ¡JC^'''''t~~~t; '. d. - - 'CJ~ /0 \1l{ Re: McArthur River Field, Hemlock Oil Pool, K-19 Sundry Number: 306-194 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiS~ day of June, 2006 Enc!. 1. Type of Request: DO ~i<j ~~ . /~ STATE OF ALASKA ALA Oil AND GAS CONSERVATION COMM.ON hie.. APPLICATION FOR SUNDRY APPROVALS \. 20 MC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend Repair well D Pull Tubing 0 Waiver Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: A Exploratory D 74-0008-0 1'14t:>e>ÐD .f..'tJ,. Service D 6. API Number: Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: Development Stratigraphic o D PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to Tubing Head = 35' 8. Property Designation: King Salmon Platform/Cook Inlet 11. Total Depth MD (ft): 13,771 . 50-733-20259-00 9. Well Name and Number: K-19 10. Field/Pools(s): McArthur River Field/Hemlock, G Sands PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 13,713' 9,765' n/a Total Depth TVD (ft): 9,802' Casing Structural Conductor Surface Intermediate Production Liner Length 381' 2,591' 12,782' Size TVD 24" 381' 13-3/8" 2,302' 9-5/8" 9,143' Burst 3,090 psi 6,870 psi 4,077' 7" Perforation Depth TVD (ft): See Attached Schematic 7" Baker Mod D Junk (measured): 13,388' Collapse· 1,540 psi 4,750 psi 13,756' Tubing Size: Tubing Grade: L-80 7" @ 13,420' 8,160 psi 7,020 psi Tubing MD (ft): 11,844' 9,792' Perforation Depth MD (ft): See Attached Schematic Packers and SSSV Type: 4-1/2" X 3-1/2" Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: J 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: 6/14/2006 Oil 0 Gas D Plugged D WAG D GINJ D WINJ D 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry W. Buster 263-7853 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ne 907-276-7600 Date b - 2.. - Of- COMMISSION USE ONLY Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Service D Abandoned WDSPL D D Other: ?>c:.aCJ ".;, ~V'-\~>-\ û~ ~e:..~~~'d. 0R~"f_:..:\~\<;¡,,-,,-?-\V'-... o..t...(..e.\~ '9..,;J1 \J ,~~~ \ E..':::>\> '\I.;)a,\..a~c¡x ~ ci:c)~~~. r,ç ~<t' \ '\ ~ c..\~Q.~~ Û~ ~ ~t (' -~, (\' ' t--..<{;...~ "-C~~\.Q~ ,-" ~~" \t:cJ . APPROVED BY THE COMMISSION Approved by: Date: RBDMS BFL JUN ] 3 2006 Form 10-403 Revised 07/2005 ~ ¿,. tø ·6' S~;r);ð Chevron ~ IIIijííII e e King Salmon Platform Well K-19 ESP Workover OBJECTIVE: Pull the existing ESP assembly. Clean-out the casing as required. Run replacement ESP - assembly. PROCEDURE SUMMARY: 1. Shut off gas lift gas and bleed pressure off annulus. 2. RIH and punch holes in tubing just above the ESP. 3. Circulate well with 3% KCL in Filtered Inlet Water. 4. Set BPV and N/D tree on Well K-19. N/U BOPE and CUDD HWOU. Test 13-5/8" BOPE (see attached diagram) to 250/3,000 psi. 5. Circulate well with 3% KCL in Filtered Inlet Water and pump sized salt LCM pill if required. 6. POH w/ existing completion. . ' \ . C"\ ...\ 7. Make clean-out run into the 7" casing if required.~ :S:~ ~Cc.. \ \ , > . c.. ~Q~'.0 C'-J t S) 8. Spot LCM pill if required and POOH. Q. ~C!.."'-.) "'o"~o~ .. '> ~~\"J~~ I 9. R/U and run ESP assembly on 4-1/2" x 3-1/2" tubing c/w gas lift mandrels to +/- 11,800'. ~?JI1 10. Install BPV. RID CUDD HWOU. N/D BOPE. N/U and Test Tree. ~(~-o<::. AOGCC K-30RD ESP WO Summary 1 of 1 June 2, 2006 61.0 K-55 12.515 47 N-80 BTC 8.681 40 N-80 BTC 8.835 40 JL-95 BTC 8.835 47 N-80 BTC 8.681 2,591' 9,769' 7.063 7.063 7.063 7.063 7.063 7.063 2.867 5.968 2.867 5.968 2.867 5.968 2.992 2.992 5.13 5.13 5.13 5,13 5.62 4.25 8.0 2.00 10,047' 9749 10,406 10,93! 1.50 0.50 17.44 17.44 1.06 6.89 6.89 G-S G-S 33.90 4.28 1.97 HB-O& G-B 9614' 11.844 ' 4-1/2" FMC 8rd Tbg Hngr 4-1/2" GLM# 1 SFO-2 wi pups, 4' on btm & 6' on top. 4-1/2" GLM #1 SFO-2 w/ btm & 6' on top, 4-1/2" GLM #1 SFO-2 wi pups, onbtm & 6' on top. 4-1/2" GLM #1 SFO-2 wi pups, 4' & 6' on top. 4-1/2" GLM # 1 SFO-2 wi pups, 4 'on btm & 6' on top. 4-1/2" GLM #1 SFO-2 wi pups, 4' on btm & 6' on top. 3-1/2" GLMAX-1.0 wi pups, 4' on btm & 6' 3-1/2" GLM #4 GLMAX~1.0 wi pups, 4' onbtm & 6' Qntop. 3-1/2" GLM #4 GLMAX-1.0 wi pups, 4' on btm & 6' on top. Pup Joint, 3-1/2", 9.2#, L-80, box Discharge Housing (SN# 50556), 8rd box up Upper Pump Section 71 Stage, Type GC6100 Lower Pump Section 71 Stage, Type GC 6100 Intake Housing, Bolt on (SN# 41 G20661 Tandem Sea! Section Motor, Type 562 Series, 418 HP, 2610V, 98 Amp, Model KMH Phoenix MS-l Sensor Gauge Motor Centralizer Aluminum Anode HB-2 12. HB-1 FISH 44.00 13,388 HB-3 HB-4 HB-S HB-6 HB-? paTD = 13713' TD = 13771' MAX HOLE ANGLE = 510 @ 2304' K-] 9 Actua] Schem 03-24-02 REVISED: 3/24/02 SLT 9 Test Pressure: 250/3000 psi 3 1/1S"SM x 4 1/16"SM DSA A 41/16" 5M Foster HCR Valve B 4 1/16" 5M Manual gate valve C 31/16" 5M Manual gate Kill line D 31/16" 5M Manual gate Kill line 55" 34" 27" ¡ 14" 10.90' 12.67' ~!~ OIL A~D GAS CONSERYATI O~ COM)lISS10~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Jim Harrison Unocal Alaska PO Box 196247 Anchorage, AK 99501 Dear Mr. Harrison: December 11, 2002 Unocal submitted a Sundry application dated October 16, .2002, requesting approval to pump 1000 barrels of seawater into the 9-5/8" by 13-3/8" annulus of Well K-19, King Salmon Platform, McArthur River Field, offshore Cook Inlet. Unocal states the objective is "to flush out any residual diesel in the leak path which has been allowing intermittent bubbling of diesel to the surface." The sheen near the King Salmon platform has been attributed to annular disposal of oil-based drilling fluids that occurred in Well K-19 from July 8, 2001 to September 21, 2001. The first indication of a sheen occurred on September 13, 2001. Unocal has held several meetings with interested stakeholders, namely ADEC, USCG, CIRCAC, and AOGCC, to discuss the intermittent sheen - the cause, source, potential leak path, and options available to remedy the situation. The most recent meeting held November 19, 2002, focused on gaining a better understanding of the leak path to surface for the disposed fluids that are causing the sheen around the King Salmon Platform. A clear understanding is critical to the successful implementation of remedial actions. Unocal indicated that studies to date have not conclusively determined the leak path for the disposed fluids to the seafloor. Based on uncertainty of the leak path and Unocal's representation at the November 19 meeting that pumping would not be pursued during the winter months, the Commission denies your Sundry application at this time. The Sundry application is attached. In lieu of pumping 1000 barrels of seawater into K-19, Unocal committed to 3 action items: 1. Reconfirm surface casing shoe integrity in Wells K-19, K-18RD, and K-6RD. Wells K-19 and K-6 were used for annular disposal; Well K-18RD casing shoe is within a reasonable zone of influence of the injected fluids in K-19. Unocal has confirmed that shoe integrity tests will be completed and information provided to the AOGCC by December 20, 2002. 2. Revise the current sheen monitoring effort to be more scientific. Data provided by Unocal indicates the sheen occurrence may be less frequent but cannot be conclusively stated without a regimented monitoring program that includes a time Jim Harrison December 12, 2002 Page 2 of 2 3~ component (duration of observation). The revised monitoring plan was provided to AOGCC on December 11, 2002. Sheen monitoring reports should be provided to the Commission at least monthly. Perform an analysis of shallow seismic data near the well penetrations to determine if there exists a communication path for disposed fluids to surface. This work should be completed and reported to the AOGCC by February 7, 2003. Please contact Jim Regg at 793-1236 should you have any questions regarding the contents of this letter. Sincerely, chsli Taylor(J Chair cc~ Capt. Ron Morris, USCG Gary Foley, ADEC Mike Munger, CIRCAC King Salmon Sheen Monitoring Worksheet Month/Year DEC 02 Day Slack Slack Slack Slack Sheen- Yes or No Sheen Wind Seas Tide Tide Tide Tide If Yes- Estimated size Location Speed & Calm/Height Flood Ebb Flood Ebb and/or number of drops (Mark on Direction Leg/Well Slot Diagram) 12/01/02 NA NA 12/02/02 10:49 Yes/257 small drops East side 14.5/284 Calm/6 inches 12/02/02 16:37 Yes / 209 small drops East side 14.7/286 6"/1' 12/03/02 11:35 None observed due to 4'/6' high seas 12/04/02 12:20 Yes/80 small drops North east end 1 '/1.5' 12/05/02 13:05 Yes/50small drops East side 15/274 1 '/2' 12/06/02 07:51 13:51 Not observed due to s/s project and psd 12/07/02 09:34 No sheen observed 3.2/300 calm 12/07/02 14:38 Yes/60 small drops Eastside 5.1/324 calm 12/08/02 15:32 Not observed due to psd 12/09/02 10:27 Yes/25 small drops North east end 4.3/348 calm 12/09/02 17:30 Not observed dark 12/10/02 11:30 Yes/59small East side 8/10/285 1' to 1.5' drops/61arge King Salmon Sheen Monitoring Worksheet Month/Year DEC 02 Instructions for Monitoring 1. Consult tide tables and fill in slack tide times prior to beginning of month. 2. During daylight hours, post watch for sheen 15 min prior to slack tide through 15 min post slack tide. 3. If ice coverage in prohibiting sufficient monitoring in the vicinity of the platform please make note in the "Sheen Yes or No" comumn. 4. If a sheen is identified, estimate size and/or number of drops (if minimal) and draw on leg/well slot map. Utilize a new leg/well slot map each month. 5. This information is to be reported monthly to the USCG. A hard copy of the data will remain aboard the facility. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Tim Billingsley Drilling Engineer October 16, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Dan Seamount Sundry Application (Form 10-403) McArthur River Field King Salmon Platform, Well K-19 Application for Annulus Flush Commissioner Seamount: Enclosed is a Sundry Application (Form 10-403) for King Salmon Well #K-19. This well is currently a Hemlock/G-zone producer on electric submersible pump. Unocal requests permission to pump 1000 bbls of seawater into the 9-5/8" x 13-3/8" annulus at K-19 as described on the attachments. The objective of this proposed operation is to flush out any residual diesel in the leak path which has been allowing intermittent bubbling of diesel to the surface. Unocal realizes that this problem will be difficult to solve and this proposed procedure may not result in any tangible benefit. However, this simple flushing of the annulus should be relatively risk free and could result in some further knowledge regarding the problem even if it does not mitigate the problem. If there are any questions, please contact me at 263-7659. Sincerely, Tim Billingsl~y.-/' Drilling Engineer AOGCC cover letter K-19 10-16-02.doc Tim B illingsley i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular Flushing 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number 699' FSL & 76' FEL of Sec. 17, T9N, R13W, SM King Salmon K-19 At top of productive interval 9. Permit number At effective depth 10. APl number 2668' FSL & 2937' FEL of Sec 11, T9N, R13W, SM 50- 733-20259-00 At total depth 11. Field/Pool 2648' FSL & 2974' FEL of Sec 11, T9N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 13,771 feet Plugs (measured) true vertical 9766 feet Effective depth: measured 13420 feet Junk (measured) None true vertical 9572 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 381' 24" Circ to Surf 381' 381' Surface 2591' 13-3/8" 1750 sx circ to surf 2591' 2302' Intermediate Production 10047' 9-5/8" 800 sx Class G 10047' 7227' Liner 3987' 7" 1000 sx 9769'- 13,756' 9792' Perforation depth: measu red 12592'- 12644', 12677'- 12716', 12808'- 12848', 12882'- 12892', 12914'- 12988', 12994'- 13020', 13060'- 13090', 13096'- 13314', 13340'- 13415', 13460'- 13545' true vertical 9001'-9053', 9074'-9100', 9160'-9186', 9209'-9215', 9230'-9279', RECEIVED 9282'-9301 ', 9326'-9349', 9350'-9484', 9502'-9553', 9582'-9638' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 @ 9614', 3-1/2", 9.2#, L-80 @ 11,844' OCT 1 6 2002 Packers and SSSV (type and measured depth) None Alaska 0il & 13. Attachments Description summary of proposal: x Detailed operations program: BOP ske~eh':hQ!'.'8¢jt~ 14. Estimated date for commencing operation 15. Status of well classification as: 11/1/2002 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify thaLth%foregoing is true and correct to the best of my knowledge. Signed:..'".,~-~, Tim Billingsley Title: Drilling Engineer Date: ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness~-~ IAppr°val i°?/'~¢ ~ Plug integrity~ BOP Test Location clearance Mechanical Integrity Test Subseq~enl ~~ Approved by order of the Com' ~oner ~ ~ t, ~ ~ ~t I I~ i Commissioner Date Form 10-403 Rev 06/15/88 ORiGINAl SUBMIT IN TRIPLICATE Proposed Procedure for K-19: 1 Observe sheens (as currently being done) before pumping test to provide a good baseline. Observe sheens closely throughout and after this proposed pumping operation. 2 RU seawater injection line with choke manifold to K-19's 9-5/8" x 13-3/8" annulus. 3 Prepare to monitor all pressures on K-19: tbg x 9-5/8", 9-5/8" x 13-3/8" and 13-3/8" x 24". 4 Prepare to monitor offset 4 wells' 9-5/8" x 13-3/8" and 13-3/8" x 24" annuli (K1 RD, K- 3RD, K-11, K-18) 5 Mobilize oil spill recovery boat for possible spill clean-up during and after pumping operation. 6 Initiate injection down K-19's 9-5/8" x 13-3/8" annulus while closely monitoring all offset annulus pressures and K-19's pressures. 7 Do not exceed 500 psi on K-19's 9-5/8" x 13-3/8" annulus. This is less than the 1500 psi limit placed on disposal operations in 2001 due to K-19 is currently on ESP production instead of gas lift production as was the case in 2001. Therefore, the gas lift pressure of 1020 psi on the inside of the 9-5/8" will not be present now to help prevent collapsing the 9-5/8" casing during the proposed pumping operation down the 9-5/8" x 13-3/8" annulus. The weak point is the 9-5/8" 40#@ JL-95 casing at 5003' MD/3937' TVD which has a collapse rating of 3330 p_si~ A seawater gradient of 0.45 psi/ft would be equivalent to 1772"~si at the 3937'-I-VD depth.. A surface pressure limit of 500 psi added to the liquid gradient would be a total external collapse force of 2272 psi. The fluid level inside the 9-5/8" on ESP pump operation is below this point so there is not bj~ck-up internal pressure to prevent collapse. The 2272 psi in collapse force is 68°~of the collapse rating for new casing. This is an acceptable limit for proposed pumping operation. It is nearly identical to the 1500 psi limit allowed on disposal operation in 2001 which would have resulted in 69% of the collapse rating of the 9-5/8" casing taking into account the 1020 psi in gas lift pressure inside the 9-5/8" casing acting to back-up the collapse force of the disposal operation. 8 Do not exceed 4 bpm to prevent erosion in the wellhead area. 9 Pump a total of 1000 bbl of water down K-19's 9-5/8" x 13-3/8" annulus. This volume is arbitrary and subject to discussion. The annulus volume to the 13-3/8" shoe at 2591' is .0622 x 2591'- 161 bbls. The above proposed 2000 bbl would be 12 times the annulus volume and 7% of the total volume disposed in 2001. 10 Stop injection. Report all offset wells' and K-19's annulus pressures before, during and after the pumping operation. 11 Note sheen observations before, during and after pumping operations. 12 Dismiss oil spill response boat after pumping operation ceases if no significant increase in spill occurrence is observed. 13 Continue monitoring for sheens on every slack tide. 10-16-02 Sundry application procedure.doc Tim Billingsley UNOCAL RKB to TBG Head = 35' Tree con nection: 9,769' 10,047' ---- HB-3 _-- --_HB-4 HB-5 PBTD = 13713' TD = 13771' MAX HOLE ANGLE = 51° @ 2304' Trading Bay Unit Well # K-19 Completed 03/24/02 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 12.515 35' 2,591' 9-5/8 47 N-80 BTC 8.681 35' 2,591' 9-5/8" 40 N-80 BTC 8.835 2591' 3,576' 9-5/8" 40 JL-95 BTC 8.835 3,576' 5,038' 9-5/8 47 N-80 BTC 8.681 5,038' 10,047' Liner 7" 129 IL-S0 ] BTC-KC I 6'1841 9769'I 13,'756' Tubing: Improved Buttress Tubing 3-1/2" 9.2 L-80 BTC 2.992 9615' 11.844' JEWELRY DETAIL NO. Depth Length II) OD Item 35 3.958 12" x 4-1/2" FMC 8rd Tbg Hngr 1. 2635 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 2. 4770 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 3. 6175 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 4. 7382 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 5. 8284 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 6. 9074 3.833 7.063 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top. 7. 96.1.4 1..10 2.992 C.rossover 4-1/2" x 3-1./2" 8. 9749 2.867 5.968 3-1/2" GLM g4 GLMAX-1.0 w/pups, 4' on btm & 6' on top. 9. 10,406 2.867 5.968 3-1/2" GLM g4 GLMAX-1.0 w/pups, 4' on btm & 6' on top. 10. 10,931 2.867 5.968 3-1/2" GLM g4 GLMAX-1.0 w! pups, 4' on btm & 6' on top. 9.48 2.992 Pup Joint, 3-1/2", 9.2g, L-80, IBTC 11.. 1.1,844 94.80 4.18 HP (562 Series) ESP Assembly 1.50 2.992 Swage Adapter, 3-1/2" 8rd pin X 3-1/2" IBTC box 0.50 Discharge Housing (SNg 50556), 3-1/2", 8rd box up 17.44 5.13 Upper Pump Section 71 Stage, Type GC 6100 17.44 5.13 Lower Pump Section 71 Stage, Type GC 6100 1.06 5.13 Intake Housing, Bolt on (SNg 41 G20661 6.89 5.13 Tandem Seal Section 6.89 5.62 Motor, Type 562 Series, 418 HP, 2610¥, 98 Amp, Model KMH 33.90 4.25 Phoenix MS-1 Sensor Gauge 4.28 8.0 Motor Centralizer 1.97 2.00 Aluminum Anode FISH 13,388 44.00 Milled Baker 'FB-I' Perm Packer, Baker SBE, XO, PUp jt, XO, Camco WP-1 Nipple, XO, Pup, WLEG 12. 13,420 20.50 Baker Model 'D' Perm Pkr, 5' MOE, XO & 3-1/2" Pup Jr. 1.3,441 1.53 2.75 Camco "D" Nipple. Plug set on 1/29/92 PERFORATION DATA Zone Top Btm Amount Condition G-5 12,592' 12,644' 52' Perf'd '94, '95 & '02 wi TCP 12,677' 12,716' 39' Perf'd '94 & '02 w/TCP HB-0 12,808' 12,848' 40' Reperf'd TCP '91 & '02 HB-1 12,882' 12,892' 10' Reperf'd TCP '91 & '02 HB-2 12,914' 12,988' 74' Reperf'd TCP '91 12,994' 13,020' 26' Reperf'd TCP '91 HB-3 13,060' 13,157' 97' Reperf'd TCP '91 & 50' in '02 HB-4 13,157' 13,314' 157' Reperf'd TCP '91 & 64' in '02 HB-5 13,340' 13,415' 75' Reperf'd TCP '91 HB-6 13,460' 13,545' 85' Isolated 1/29/92 HB-7 13,594' 13,604' 10' Cmt Sqzd 13,615' 13,645' 30' Cmt Sqzd K- 19 Actual Schem 03-24-02.doc REVISED: 3/24/02 SLT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 100' feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Trading Bay Unit/ P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: McArthur River Field 4. Location of well at surface 8. Well number 699' FSL & 76' FEL of Sec. 1, T9N, R13W, SM King Salmon K-19 At top of productive interval 9. Permit number/approval number 2825' FSL & 2937' FEL of Sec 11, T9N, R13W, SM 74-0008-0 At effective depth 10. APl number 2668' FSL & 2937' FEL of Sec 11, T9N, R13W, SM 50- 733-20259-00 At total depth 11. Field/Pool 2648' FSL & 2974' FEL of Sec 11, T9N, R13W, SM McArthur River Field / Hemlock 12. Present well condition summary Total depth: measu red 13,418' feet Plugs (measu red) true vertical 9,571' feet Effective depth: measured 13,360 feet Junk (measured) true vertical 9,531 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 381' 24" Circ to Surf 381' 381' Surface 2591' 13-3/8", 61# 1750 sx circ to surf 2591' 2302' Intermediate Production 12,782' 9-5/8", 47# 800 sx Class G 12,782' 9143' Liner 4,077' 7", 38# 1000 sx 13,756' 9792' Pe rfc ratio n depth: measu red 12592'- 12644', 12677'- 12716', 12808'- 12848', 12882'- 12892', 12914'- 12988', 12994'-13020', 13060'-13090', 13096'-13314', 13340'-13415', 13460'-13545' true vertical 9001'-9053', 9074'-9100', 9160'-9186', 9209'-9215', 9230'-9279', 9282'-9301', 9326'-9349', 9350'-9484', 9502'-9553', 9582'-9638' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 11,844' Packers and SSSV (type and measured depth) ~ 94.8'1ong ESP @ 11,844', Baker FB-1 packer @12,6!6!.; Baker D Isolation pkr @ 13,420' RFCFIVF I..~ 13. Stimulation or cement squeeze summary , Intervals treated (measured) JU~k~ 0 4 2002 Treatment description including volumes used and final pressure AJ~.ska 0il & 6as C0rl$. C;om~~ Anchora~le 14. Representative Daily Averaqe Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 206 BOPD 320 Mcfpd 1954 BWPD 1100 psi 80 psi Subsequent to operation 300 BOPD 390 Mcfpd 2300 BWPD 70 psi 50 psi 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signe._ _ Title: ,~¢~,~"/~ ~¢~_~'/2~¢.~,¢~- Date: ~///~. Form 10-404 Rev~6/15/88 SUBMIT IN DUPLICATE....... 13-Mar-02 14-Mar-02 15-Mar-02 16-Mar-02 17-Mar-02 18-Mar-02 19-Mar-02 20-Mar-02 21 -Mar-02 22-Mar-02 23-Mar-02 24-Mar-02 King K-19 Daily Report of Operations March 13 to March 24, 2002 Skidded rig over K-19. Continue skidding rig over K-19. RU pump line to well. Pump 102 bbls of 3% KCI/FIW down tbg. Pump 295 bbls down annulus. ND tree. NU BOPE. Finish BOPE NU. Test BOPE. Pull BPV. RU land joint. PU unseat tbg hngr, pull seal out of pkr. LD tbg hngr. Trip out LD 4-1/2" tbg. Finished LD 4-1/2" completion. Test blind rams. PU Milling BHA. PU & RIH w/3- 1/2" DP. Finished PU 3-1/2" DP. PU & RIH 5" DP. Finished PU of 5" DP. Mill pkr @ 12656'. Chased pkr to 13,388'. Pump 2 sweeps. CBU. POOH standing DP in derrick. BO LD milling BHA & 47 jts of 3-1/2" DP. PU/MU 722' of TCP guns & equip. RIH on DP. Finished RI TCP guns on depth. RU E/line. Correlate guns on depth. POOH & RD E/line. Set pkr, drop bar, fire guns. Perforated G-5, G-6, HB-1,3 & 4. Release pkr. CBU. RU slickline to fish bar. Fished bar. RD slickline. Trip OOH w/TCP guns. LD TCP equipment. RU ESP running equip. PU & RIH w/ESP BHA on 3-1/2" tbg. PU 4-1/2" tbg. Continue RIH w/ESP completion on 4-1/2" tbg. Finished RIH w/ESP Completion. PU/MU tbg hngr. Made final splice. Land tbg w/ ESP @ 11,844'. ND BOPE. NU tree. Test void to 5k psi. NU wing valves. Release rig. RKB to TBG Head = 35' Tree SIZE 1%3/8" %5:8 !Liner ~, Trading Bay Unit Wdl # K-19 Completed (}3/24/02 CASING AND T;L BING DETAIL GRADE K-55 N-80 N-80 JL-95 N-80 [ Tubing: lmprovedBu~ress lRl?i.~g [4-1/2" 126 ~L-80 BTC 3958 } 3~- '[9~ JEWELRY DETAIL Item 12" x 4d/2" FMC 8rd Tbg Hugr 4-1/2" GLM ~l S FO-2 w/pups, 4' on Nm & 6' on top 4-1/2' GI.M ~t SFO-2 w/pups, 4' on btm & 6' on top 4-1/2" GI.M ~ 1 SFO-2 w/pups, 4' on btm & 6' on top 4-1/2" GLM ~1 S FO-2 w/pups. 4' on btm & 6' on top. 4 I/2" GIM ~1 SFO-2 w/pups, 4' on btm & 6' on top 4-1/2" GLM gl SFO-2 w/pups, 4' on btm & 6' on top Cro ;e~ 4/? 3/2' 3-1/2" GI.M ~4 GLMAX-I 0 w/pups. 4' on btm & 6' on top %1/2" GI,M !i4 GLMAXd 0 ;~/pups. T on btm & 6' on top %1/2" GLM #4 GI.MAX-I 0 x~/pups. 4' on btm & 6' on top Pup Joint, ~ 1/22 92#, L-80. IBTC 418 HP (562 Series) ESP Assembly Swage Adapter, 3-1/2" 8rd pin X 3-1/2" IBTC box Discharge Housing (SN# 50556L 3-1/2". 8rd box up Upper Pump Sect/on 7 / Stage, Type GC 6100 Lower Pump Section 71 Stage, Type GC 61 O0 5 13 Intake Housing, Bolt on (SN# 41G20661 I alldem Seal Section Motor, Type 562 Setdes, 418 HP, 26[0V, 98 Amp. Model KMH Phoenix MS~I Sensor Gauge 80 Motor Centralizer Aluminum Anode 2 PBTD = 13713' TD = 13771' MAX HOLE ANGLE = 51° @ 2304' M/lied Baker 'FB-I' Perm Packer, Baker SBt. XO. })up it, XO. Camco WP-I Nipple, XO, Pup, WLEG Baker Model 'D' Perm Pkr, 5' MOE. XO & 3-1/2" Pup Jt PERFORATION DATA Zone Top Btm Amount Condition G-5 ~ ii 1~,592' 12,644' 52' Pe~f'd '94, '95 & '02 w/TCP 12,677' 12,716' 39' Per~d '94 & '02 w/TCP '--~B-0 12,808' 12,848' 40' Reperf'd ~-CP '91 & '02 HB-1 12,882' 12,892' 10 HB-2 12,914' 12,988' 74' Reperf'd TCP '91 12,994' 13,020' 26 HB-4 13,157' 13,314' 157' Reperf'd TCP '91 & 64' in '02 HB-5 13,340' 13,415' 75' ReperPd TCP '91 HB-6 13,460' 13,545' 85' Isolated 1129192 HB-7 13,594' 13,604' 10' Cmt Sqzd K- 19 Actual Schem 03-24-02 REVISED: 3,24/02 SLT ~KA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 20, 2001 UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 Re: No-Flow Verification TBU Well K-17 TBU Well K-19 TBU Well K-24RD2 PTD 173-001 ....... . ....... PTD 201-141 Gentlemen: On November 14, 2001 AOGCC Petroleum Inspector Lou Grimaldi witnessed "no-flow" tests on Wells K-17, K-19, and K-24RD2 at UNOCAL's King Salmon Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on King Salmon Platform and proceeded to observe the wells. Over the course of the three (3) hour witnessed period, the test performance of TBU wells TBU Well K-17 (173-001), K-19 (174-008) and K-24RD2 (201-141) demonstrated that the wells are incapable of unassisted flow of hydrocarbons to the surface. Therefore, these wells need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safety valve ("SSSV") system. However, these wells must be equipped with fail-safe automatic surface safety valve ("SSV") systems capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason any of the wells become capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well files on board King Salmon. Sincerely, Thomas E. Maunder, P.E. Sr. Petroleum Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Camille O. Taylor~,~,~ DATE: ~,, Chair Tom Maunder, P. I. Supervisor November 14, 2001 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test Unocal Steelhead K-19 McArthur River Field TBU PTD 174-008 NON-CONFIDENTIAL Wednesday, November 14, 2001: I witnessed a No-Flow verification on UNOCAL's King Salmon platform wells #K19 in the McArthur River field. Following is a timeline and well status during test. 1000 Well flowing at less than 180 scf, no fluid. Shut-in well 1020 SITP 1 psi, Open well. Flow initially at 1000 scf and dropped to 400 scf. 1030 Shut-in well due to gas alarm. 1125 SITP 1 psi, open well to atmosphere. Flow initially less than 180 scf and dropped to bare whisper., 1 t30 Shut-in well 1300 SITP 5 psi, Open to atmosphere. Flow initially 1800 scf decreased to less than 180 scf (bare whisper) Note: The gauge used to check flow was incable of measuring below 180 scf or above 2000 scf. This well exhibited inability to flow to surface unassisted and l recommend it be granted No-Flow status. This well is due for a workover during which a ESP will be installed. I explained to Mark Atkins (Platform Foreman) that any cleanout, perforating or other stimulation will require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's King Salmon platform well #K-19 in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson/Mark Atkins (Unocal) Attachment: None No-Flow UNOCAL TBU K-19 11-14-01 LG.doc Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-766(~ UNOCALe OCT B 2001 Alaska Oil & Gas Cons, Commission Anchorage October 25, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Commissioner Heusser: Attn: Re: Commissioner Julie Heusser Report on Annulus Disposal McArthur River Field, King Salmon Platform, Well K-19 Enclosed is the final report on annulus disposal for K-19 as required by the Sundry Application Approval #300-323 dated 2/9/01. Attached is the daily summary of disposal volumes in K-19's annulus while drilling at K-18RD2 and K-24RD2. The following is the total volumes disposed in K-19's annulus by drilling well source. Well OBM Waste Slurry, Seawater Flush, bbls Total Bbls bbls K-18RD2 7113 12685 19798 K-24RD2 4029 5220 9249 Total 11142 17905 29047 As you know, a sheen was observed on the east side of the King Salmon platform beginning on Sept 12, 2001. Annulus disposal was stopped on K-19 on 9/21/01 when it was determined that the most likely source of the sheen was oily waste disposal in K-19's annulus. The remaining of the drilling waste while finishing drilling K-24RD2 was disposed down K-6's annulus. All annulus disposal operations were ceased on the King Salmon platform on 10/15/01. A table is attached showing the pertinent dates, volumes, depths and other information regarding the annulus disposal in relation to the sheen. Another spreadsheet is attached with sheen observations taken from 9/21/01 up to the present at 10/24/01. As you can see, a small sheen is still intermittently present but does appear to be lessening in frequency and volume. Four offset annuli were monitored during each annulus disposal episode on K-19. Attached are the annulus pressures of the four nearest wells to K-19 and a map showing these wells. None of the offset monitoring indicates a problem developed during the disposal operations. The one anomaly is the pressure fluctuation on K-18 which was due to K, 18 being shut-in for adding perforations and then gas lift production resuming. This caused the annulus pressure to fall and rise due to thermal effects. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. AOGCC K-19 final report.doc Sincerely~ Dan Williamson Drilling Manager Tim Billingsley RECEIVED . Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of K-I T Drilling Wastes From King Salmon K- 18RD2 ^lasl aoil Gas Cons. Commission Maximum Allowable Injection Pressure 1500 psi on FIW, 1200 psi on 10.5 ppg slurry Ancl~0rage TVD 13 318" Casing Shoe Depth 2591' MD/2302' TVD' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total Hole Feet No. No. BPM Pressure PPG Volume Volume Slurry's Flushes Size Drilled 7/8/2001 tst inj 1 3 225 na na 200 200 8.5 na 7/8/2001 1 2 2.5 225 8.6 170 290 170 490 8.5 0 7/9/2001 2 3 2.5 225 9 422 305 592 795 8,5 0 7/11/2001 3 4 25 200 9,8 205 290 797 1085 8.5 688 7/12/2001 4 5 2,5 200 9.8 158 290 955 1375 8.5 438 7/12/2001 5 6 2.5 200 10.1 171 290 1126 1665 8,5 454 7/14/2001 6 7 2.5 200 9.9 167 290 1293 1955 8.5 355 7/14/2001 7 8 2,5 160 10,5 173 290 1466 2245 8.5 344 7/15/2001 8 9 2,5 200 10,2 163 290 1629 2535 8.5 445 7/16/2001 9 10 2,5 200 9,8 138 290 1767 2825 8,5 216 7/17/2001 10 11 2,5 150 9,9 164 290 1931 3115 8,5 266 7/17/2001 11 12 2,5 175 9,9 179 290 2110 3405 8,5 417 7/18/2001 12 13 2.5 200 10.3 156 290 2266 3695 8.5 252 7/19/2001 13 14 2,5 200 9,8 165 290 ' 2431 3985 8.5 189 7/20/2001 14 15 2,5 190 10,1 153 290 2584 4275 8,5 206 7/21/2001 15 16 2.5 190 10.2 151 290 2735 4565 8.5 263 7/22/2001 16 17 2,5 190 9.6 150 290 2885 4855 8.5 160 7/23/2001 17 18 2.5 200 9.3 140 290 3025 5145 8.5 160 7/25/2001 18 19 2.5 210 10,1 150 290 3175 5435 8.5 175 7/26/2001 20 21 2.5 195 9,7 158 290 3333 5725 8.5 128 7/28/2001 21 22 2,5 200 9.8 173 290 3506 6015 8.5 182 7/28/2001 22 23 2.5 190 10.3 182 290 3688 6305 8.5 224 7/30/2001 23 24 2,5 190 9.6 175 290 3863 6595 8.5 239 7/31/2001 24 25 2.5 190 9.7 1'62 290 4025 6885 8.5 173 8/1/2001 25 26 2,5 200 9,4 210 290 4235 7175 8,5 SD trap 8/2/2001 26 27 2.5 200 10.2 200 290 4435 7465 8,5 28 8/3/2001 27 28 2,5 200 10 192 290 4627 7755 8,5 379 8/4/2001 28 29 2,5 200 10,1 182 290 4809 8045 : 8,5 421 8/5/2001 29 30 2,5 200 9.8 175 290 4984 8335 8,5 386 8/7/2001 30 31 2,5 200 10,2 160 290 5144 8625 8,5 346 8/9/2001 31 32 2.5 200. 9.7 160 290 5304 8915 8,5 0 8/9/2001 32 33 2,5 190 10,3 164 290 5468 9205 8,5 134 8/10/2001 33 34 2.5 200 10.5 162 290 5630 9495 8.5 270 8/11/2001 34 35 2,5 260 - 240 290 5870 9785 8,5 8/11/2001 35 36 2.5 200 10,2 148 290 6018 10075 8.5 - 8/12/2001 36 37 2,5 205 10,5 165 290: 6183 10365 8,5 116 8/14/2001 37 38 2,5 200 9,9 120 290 6303 10655 8.5 TD 8/15/2001 38 39 2,5 240 10 100 290 6403 10945 8,5 TD 8/16/2001 39 40 2,5 220 10,1 80 290 6483 11235 8,5 TD 8/16/2001 40 41 2,5 240 10,2 125 290 6608 11525 8,5 TD 8/17/2001 41 42 2,5 260 9,8 225 290 6833 11815 8,5 TD 8/20/2001 42 43 2,5 200 9 90 290 6923 12105 8.5 TD 8/21/2001 43 44 2,5 205 9.2 65 290 ' 6988 12395 8,5 TD 8/23/2001 44 45 2,5 200 9,6 125 290 7113 12685 Clean up Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of K-19 Drilling Wastes From King Salmon K-24RD2 Maximum Allowable Injection Pressure 1500 psi on FIW, 1200 psi on 10.5 ppg slurry ~TVD 13 3/8" Casing Shoe Depth 2591' MD/2302' TVD' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total Hole Feet No. No. BPM Pressure* PPG Volume Volume Slurry's Flushes Size Drilled Depth 8/30/2001 1 0 2.5 100 8.5 415 0 415 0 9-5/8 0 8004' 8/30/2001 2 0 2.5 125 8.3 170 0 585 0 9-5/8 0 10887' 8/31/2001 3 1 3.5 200 9.2 1020 290 1605 290 9-5/8 0 10812' 9/5/2001 4 2 2.5 225 10.3 155 290 1760 580 8.5 265 11058' 9/5/2001 5 3 2.5 200 10.4 148 290 1908 870 8.5 272 11330' 9/6/2001 6 4 2 140 10.4 151 290 2059 1160 8.5 289 11619' 9/8/2001 7 5 2 400 10 157 290 2216 1450 8.5 69 11688' 9/10/2001 8 6 2.5 190 10.4 167 290 2383 1740 8.5 141 11829' 9/11/2001 9 7 2.5 225 10.5 50 290 2433 2030 8.5 292 12121' 9/11/2001 10 8 2.5 250 10.1 154 290 2587 2320 8.5 362 12191' 9/12/2001 11 9 2.5 250 10.3 74 290 2661 2610 8.5 189 12380' 9/13/2001 12 10 2.5 160 10.4 167 290 2828 2900 8.5 190 12,570' 9/13/2001 13 11 2.5 270 10.4 69 290 2897 3190 8.5 72 12,642' 9/15/2001 14 12 2.5 200 9.9 165 290 3062 3480 8.5 459 13,083' 9/16/2001 15 13 2.5 210 10.2 170 290 3232 3770 8.5 0 13,082' 9/17/2001 16 14 2.5 200 9.9 153 290 3385 4060 8.5 0 13,083' 9/18/2001 17 15 2.5 200 9.3 161 290 3546 4350 8.5 37 13,170' 9/19/2001 18 16 2.5 240 10.2 174 290 3720 4640 8.5 160 13330' 9/20/2001 19 17 2.5 245 10.1 159 290 3879 4930 8.5 190 13520' 9/21/2001 20 18 2.5 215 10.0 150 290 4029 5220 8.5 136 13656' Discontinued OBM Cutting slurry Injection due to lab reports of match of sheen noticed around platform Possible breach to surface *Injection Pressure is the highest injection pressure observed while injecting King Salmon Annulus Disposal 10/15/O 1 K-6RD K-19 Comment Surf Location NW Leg NE Leg Sheen on East side 13-3/8" shoe 2186' MD/2088' TVD 2591' MD/2302' TVD Shoe direction NE of platform SW of platform Sheen on East side 13-3/8" cmt (:;mt to surf 800 cuft cmt to surf 13-3/8" LOT 15.0 ppg in 1988 11.3 ppg in 1974 Agrees with Disposal Ann. Disp. Dates Ann Disp Volumes 3/21 to 4/25 5/14 to 6/28/01 9/22 to 10/15/01 14,717 bbls 10,645 bbls 4737 bbls Total - 30,099 bbls 7/8 to 8/23 8/30 to 9/21 19798 bbls, K-18RD2 9249 bbls, K-24RD2 Total = 29,047 bbls Sheen on 9/12 From K-1 RD2 From K-13RD2 From K-18RD2 From K-24RD2 From K-24RD2 10-15-01 AOGCC at end of disp.doc Tim Billingsley King Salmon Platform Sheen Log Sheet Note the following items at each high and Iow slack tide occurring during daylight hours Wind Wind ,Approx. size Sheen Recent Grind & Time/Date direction Speed Tide Seas of sheen Location Inject Activity (Azimuth) MPH ebb/flood Calm/Height 9/21/01 0945 325 23 High / slack 2' - 3' None N/A 0200/0600 150 bbl slurry South of Leg 9/21/01 1700 300 10 Low Slack 1' - 2' Very light Sheen #2 None since last mentioned South of Leg 9/22/01 1050 300 3.5 High / Slack Calm Very light Sheen #2 None since last mentioned Last of ebb N. of L#1 & S. tide & Iow Several small Leg #2 (See 9/22/01 1715 300 3 Slack Calm Sheens map) None since last mentioned (K-6) 9/22/01 1550 to 1620 Drops (FIW) and injection ongoing 9/23/01 1230 16 10 to 15 Hi / slack 2' -3' IProminent) E. of L#2 at preset time Drops 9/24/200112:30 240 12 Hi / slack 2'-3' IProminent) S/Y Landing Currently Injecting K-6 Drops 9/24/01 19:23 60 5 Low Slack 1' IProminent) SE corner 9/24/2001 13:25 Drops 9/25/01 7:10 6 10 Low Slack 1' (Prominent) East side None since last mentioned Drops 9/26/01 9:37 308 6 Low Slack 2' IProminent) SE corner None since last mentioned Drops Less than 9/26/01 16:40 350 12 High / slack 3to4ft last sighting N/E None since last mentioned 9/27/01 11:55 36 6 Low Slack <1' None 9/26/2001 20:10 Drops 9/28/01 High / slack (Prominent) 9/28/2001 12:05 9/29/01 None 9/30/01 12:20 Low Slack 16-20 drops SE 9/29/2001 20:40 10/1/01 13:00 Low Slack 40-50 drops NE 10/1/2001 2:20 10/2/01 NO Sheen None since last mentioned Drops 10/3/01 317 15 Low Slack 2' (Prominent) S/E 10/3/2001 20:45 Drops Less than 10/4/01 8:25 322 20 High / slack 2' to 3' last sicjhting N/E None since last mentioned 10/4/01-14:35 9 17 Low Slack 2' 50 to 60 Drops East side None since last mentioned Drops 10/5/01 0930 279 16 High / Slack 1' -2' IProminent) East Side None since last mentioned Drops 10/5/01 1420 330 2 Low Slack Calm (Prominent) East Side None since last mentioned 10/6/01 1030 131 31 High Slack 3' - 4' No Sheen N/A None since last mentioned 10/6/01 1550 137 28 Low Slack 3' - 4' No Sheen N/A None since last mentioned Drops East & 10/7/01 1030 14 7 High / slack Calm / 1' (Prominent) Northeast 1850 hrs 10/6/01 128 bbls. 10/7/01 1810 112 3 Low / Slack Calm No Sheen N/A None since last mentioned 10/8/2001 11:06 South 15 High/Slack 1.5/2ft 20/30 drops S/E Corner None since last mentioned 10/9/2001 13:00 273 18.5 High/Slack 1/2ft 20/30 drops S/E Corner None since last mentioned 10-10-0112:30 52 1.7 High/Slack <1' 5 to 6 drops N/E corner None since last mentioned 10/11/2001 2:30 270 10 High/Slack 1' NO Sheen East side None since last mentioned 10/12/2001 2:30 73 3.9 High/Slack <1" NO Sheen East side None since last mentioned 10/13/01 11:30 320 9 Low/Slack l-2ft NO Sheen N/A 10/13/01 08:15to 11:15 10/13/01 17:30 280 13 High/Slack 1-2 ft 5 to 6 drops East side None since last mentioned 10/14/01 11:15 270 15 Low / Slack 1' 5 to 6 drops East side None since last mentioned 10/14/01 17:45 300 17 High/Slack 1' NO Sheen N/A None since last mentioned 10/15/01 11:30 50 2 Low/Slack 1' NO Sheen N/A 8:50:00 AM last injection 10/16/01 12:30 148 4.5 Low/Slack <1' NO Sheen N/A None since last mentioned 10/17/01 12:14 300 10.6 Low/Slack 2' 40to50 drops East side None since last mentioned 10/18/01 10:30 121 8 High/Slack Calm 40to50 drops East side None since last mentioned 10/19/01 10:00 296 20 High/Slack 1' 2' NO Sheen N/A None since last mentioned 10/19/01 15:30 301 7 Low Slack Calm NO Sheen N/A None since last mentioned 10/20/01 10:30 295 10 High/Slack 1' NO Sheen N/A None since last mentioned 10/20/01 16:15 301 15 Low / Slack 1' NO Sheen N/A None since last mentioned 10/21/01 11:00 268 6 High / Slack Calm 30-40 drops South East None since last mentioned 10/21/01 16:30 270 2 Low/Slack Calm 10 - 20 Drops South Leg 2 None since last mentioned 10/22/01 11:15 276 13 High/Slack Calm No Sheen N/A None since last mentioned 10/22/01 16:15 308 7 Low/Slack 1' 10 drops South/East None since last mentioned 10/23/01 13:00 260 8 High/Slack 1' NO Sheen N/A None since last mentioned 10/24/01 12:30 267 8.5 High/Slack 1' NO Sheen N/A None since last mentioned K-1RD2 Annulus Injection Pressures 13 3/8" x 9 5/8" and 24" x 13 3/8" 350 3OO 25O 200 150 lO0 50 13 3/8" x 9 5/8" 24"x 13 3/8" Injection Times K-3 Annulus Injection Pressures 13 3/8" x 9 5/8" and 24" x 13 3/8" 140 120 lO0 80 60 40 20 13 3/8" x 9 5/8" 24"x 13 3/8" -- Iniection Times K-11 Annulus Injection Pressures 13 3/8" x 9 5/8" and' 24" x 13 3/8" 14 12 10 13 3/8" x 9 5/8" 24"x 13 3/8" i ,. / ' o o o o o o o o o o o o o o o o Injection Times K-18 Annulus Injection Pressures 13 3/8" x 9 5/8" and 24" x 13 3/8" 140 120 lO0 80 60 40 20 13 3/8" x 9 5/8" 24"x 13 3/8" Thermal effects of stopping and starting gas lift production / ! I o o o o o o o o o o o o o o o o Injection Times K-19 Annulus Injection Pressures 13 3/8" x 9 5/8" and 24" x 13 3/8" 3O0 25O 200 lO0 50 13 3/8" x 9 5/8" 24"x 13 3/8" / / 11,/1//i 1 ': I I i i o .O.o o o Injection Times K J I(-1 KI ---~1,000 2,000 i SCALE IN FEET I I 2284'(K-15RD) -- 2400: 769'(K-4~D ~_~:,- 3,000 K~ M-30 21 McArthur River Field King Salmon Annular Disposal Subject: MeArthur River Field King Salmon Annular Disposal Date: Fri, 21 Sep 2001 17:09:16 -0800 From: Jack Hartz <jack_hartz~admin.state.ak.us> Organization: AOGCC To: Julie Heusser <julie_heusser~admin.state.ak.us> CC: Daniel T Seamount JR <dan_seamotmt~admin.state.ak.us>, Thomas E Maunder <tom_maunder~admin.state.ak.us>, Jane Williamson <Jane_Williamson~admin.state.ak.us>, Stephen Mcmains <steve_mcmains~admin.state.ak.us>, "Lisa M. Weepie" <lisa_weepie~admin.state.ak.us>, Camille Taylor <cammy_taylor~admin.state.ak.us> Dan Williamson just called re: subject disposal in K-19 well annulus. There have been some mystery sheens appearing around the KS platform off and on for a couple of weeks and apparently some lab work has shown some similarity with oil in mud disposed. Unocal and ADEC are investigating the situation. Dan request to stop disposal in K-19 and to switch to K-6 annulus until they figure out where the sheens are sourced. They have not used the K-6 for several months. Dan thought the volume disposed in K-6 was about 25K bbls. I gave him verbal approval. Does anyone know if Wendy tracked the AD volumes? >>>>>Steve McM can you check this out? >>>>Lisa - copy this to McArthur River Well K-19 well file Permit No. 1740080, API 7332025900 Thanks, Jack Jack Hartz <jack hartz~admin.state.ak.us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission 1 of 1 9/24/01 6:30 AM Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe 08/01/01 / '7 %0 RECEIVED AUG 0 i 2001 Alaska Oil & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn' Re: Commissioner Julie Heusser Proposed Drilling Waste from Monopod Platform to King Salmon Platform ,, Approved and Proposed Annulus Disposal Wells Well K-6RD (Approved) Well K-12RD Well K-19 (Approved) Well K-25 Well K-26RD Commissioner Heusser: Unocal requests permission from the AOGCC to dispose of drilling waste from proposed drilling on the Monopod platform in the above annuli on the King Salmon platform. Sundry Applications (Form 10-403) for King Salmon Well's #K-6RD, K-12RD, K-19, K-25 and K-26RD have been submitted to you. Two wells, K-6RD and K-19, were approved and the remaining three have been on hold pending whether more than two annuli will be required to dispose of all of the drilling waste. The two approved annuli, K-6RD and K-19, have been used as annulus disposal wells for drilling waste generated by drilling on the King Salmon platform at K-1RD, K-13RD2, K-18RD and will be used .for the upcoming K-24RD. After K- 24RD is completed, no more drilling will be done on the King Salmon platform and the crews will move to Monopod to drill one to two wells as follow-up wells to the highly successful K- 13RD2 (8000 BOPD). There will also be one or more workovers on Monopod while the rig is active but workover waste will not be transported to King Salmon for annulus disposal. It is unknown at this time how many annuli will be needed at the King Salmon to handle all of the waste from the Monopod without exceeding the 35,000 bbl limit on any one annulus. Therefore, Unocal requests a waiver from the AOGCC for all 5 of the above King Salmon annuli as described in 20 AAC 25.080(d) (4) "Unless the operator demonstrates that compliance with a limitation established in 1-4 of this subsection is imprudent, the commission will not authorize disposal of drilling waste: ... (4) through annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste." Unocal believes it is more prudent to utilize existing equipment on the King Salmon platform to dispose of drilling waste from the Monopod platform than to haul and store waste at other locations. The grind and inject unit and disposal annuli on the King Salmon platform have AOGCC letter Monopod Waste to King. doc Tim Billingsley proven to be an efficient, safe and environmentally attractive means of disposing of oil based mud cuttings. Unfortunately, there is not as much room on the Monopod platform as the King Salmon platform and the grind and inject unit can not be moved to the Monopod. There will be one to two wells drilled with oil based mud on the Monopod platform and the ultimate disposal of the cuttings are in question. The cuttings could be hauled to Bruce platform and ultimately injected into a disposal well there. However, this would be a longer process due to lack of equipment currently on Bruce, summer-only operating situation currently at Bruce and lower throughput capacity at Bruce that would limit injection and necessitate long term storage of cuttings in drums. The big advantage of the King Salmon grind and inject unit is that it can process cuttings as soon as they are generated. Cuttings could be hauled from Monopod in 25-bbl rental totes. The rental totes could be quickly dumped into the 300 bbl receiving tank of the grind and inject unit and return to Monopod for more cuttings. This would be much better than hauling and storing the cuttings as would be the case on the Bruce platform or other disposal options. The Mon0pOd-King Salmon relationship has many characteristics that are beneficial regarding this disposal proposal. The Monopod platform is only one platform to the north of the King Salmon. The proposed wells on the Monopod will be drilling to the south and will be targeting the same Northern Nose geologic feature that K-13RD2 is currently completed in. The Monopod and King Salmon Platform have the same ownership, Unocal and Forest Oil. Therefore, it would be environmentally and economically more prudent to transport oil based mud cuttings from the Monopod platform to the King Salmon platform where annulus disposal will be quick and storage problems will be minimal. Please respond with your decision regarding this request for waiver of 20 AAC 25.080(d)(4) in a timely manner. If the waiver is not granted, there will be significant planning required to provide a viable alternative to the cuttings disposal problem. The proposed drilling on the Monopod platform should commence in October 2001. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager Re: K-19 ann disposal application Subject: Re: K-19 ann disposal application Date: Wed, 07 Feb 2001 11:51:36 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Billingsley, Tim -Contract" <billita@unocal.com> Tim, Thanks for the information and the proposed monitoring plan. When the spider map is available for K-19, it would be something to add to the file. At this time we should not need anything further. The application has been forwarded recommending approval. Tom "Billingsley, Tim -Contract" wrote: > Tom, > We are putting together a spider map showing all of the King 13-3/8" casing > points and their proximity to the K-19 proposed annulus disposal 13-3/8" > shoe point. > The 4 closest wellbores will be K-1RD, K-3RD, K-11, K-18 which we propose > monitoring the 9-5/8"x 13-3/8" annulus on these four wells prior to and > after injecting into K-19's annulus. > I will get the map to you as soon as it is ready but it may be a few days. > Do you need map for approval of K- 197 > Once we get approval for K-19 and receive your conditions for approval, I > will be sending you 4 other King annulus proposals for back-up to K- 19 > plugging (K.6RD, K-12RD, K-25, K.26RD) Thanks, Tim Billingsley 263-7659 Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 2/7/01 11:51 AM 3883 .3383~ 33,.7? 34.00; K-L6 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Dan Williamson Drilling Manager January 23, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Leak-off Test Information, Surface Casing McArthur River Field King Salmon Platform Application for Annulus Injection on K-19 Commissioner Heusser: During out phone conversation on 1/22/01 regarding the K-19 annulus disposal application, you requested information on surface casing leak-off test information on all wells within a ~ mile radius of K-19. Enclosed is a form summarizing this information for all of the wells at King Salmon platform. In the 1960's and 1970's, leak-off tests were not done on a regular basis. There were LOTs performed on only 7 of the 24 surface casing shoes at King Salmon. Two of these tests, K-25 and K-26, were done after the 9-5/8" was pulled and the wells redrilled with open hole kick-offs 200'-550' below the 13-3/8" surface casing shoe. Also, you inquired about any prior annulus disposal at King Salmon. There has not been any annulus disposal at any of the King Salmon wells according to Unocal and ARCO records and production personnel on the platform are not aware of any prior annulus injection at King Salmon. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Sincerely, _~ .- Dan Williamson Drilling Manager RECEIVED JAN ?., 3 2.001 Alaska Oil & Gas Cons, Commission Anchorage AOGCC cover letter LOT K-19.doc Tim Billingsley King Salmon Platform Surface Casing Leak-off Test Summary Well Surf Csg Size Shoe MD ShoeTVD LOT, ppg Comments K-1 RD 13-3/8" 2384' 2147' No leak-off test performed below 13-3/8" shoe, 11/2/67 K-2RD 13-3/8" 2372' 2298' No leak-off test performed below 13-3/8" shoe, 11/10/67 K-3RD 13-3/8" 2506' 2337' No leak-off test performed below 13-3/8" shoe, 10/68 K-4RD 13-3/8" 2880' 2769' No leak-off test performed below 13-3/8" shoe, 1/15/68 K-5 13-3/8" 2476' 2252' No leak-off test performed below 13-3/8" shoe, 2/26/68 K-6RD 13-3/8" 2186' 2088' No leak-off test performed below 13-3/8" shoe, 2/26/68 K-7RD 13-3/8" 3618' 3039' No leak-off test performed below 13-3/8" shoe, 7/9/68 K-9 13-3/8" 2492' 2360' No leak-off test performed below 13-3/8" shoe, 5/28/68 K-10RD 13-3/8" 4998' 3883' No leak-off test performed below 13-3/8" shoe, 1/24/69 K-11 13-3/8" 2470' 2400' No leak-off test performed below 13-3/8" shoe, 10/3/68 K-12RD 13-3/8" 2510' 2429' No leak-off test performed below 13-3/8" shoe, 12/5/68 K-13RD 13-3/8" 5011' 4166' No leak-off test performed below 13-3/8" shoe, 1 2/9/68 K-15RD 13-3/8" 2401' 2284' No leak-off test performed below 13-3/8"'shoe, 2/18/69 K-17 13-3/8" 2183' 2032' 10.6 2/5/73, pumped into formation at 150 psi with 9.2 ppg mud @ 2257' MD/2091' TVD K-18 13-3/8" 2477' 2283' 10.3 6/4/73, pumped into formation at 125 psi with 9.3 ppg mud @ 2492' MD/2295' TVD K-19 13-3/8" 2591' 2302' 11.3 3/1/74, pumped into formation at 325 psi with 8.6 ppg mud @ 2637' MD/2336' TVD K-20 9-5/8" 4999' 2899' No leak-off test performed below 9-5/8" shoe, 7/17/69 K-21 RD 13-3/8" 2714' 2390' No leak-off test performed below 13-3/8" shoe, 5/23/75 K-22RD 13-3/8" 5493' 4825' 11.3 2/17/75, pumped into formation at 550 psi with 9.1 ppg mud @ 5560' MD/4852' TVD K-23 13-3/8" 5005' 3940' 12.5 2/9/78, pumped into formation at 625 psi with 9.5 ppg mud @ 5070' MD/4000' TVD K-24RD 13-3/8" 5712' 4229' No leak-off test performed below 13-3/8" shoe, 10/28/79 Originally known as K-16, no LOT on 3/23/69. K-25 had 9-5/8" cut and pulled and an open hole kick-off: LOT on 6/26/85 @ 2202' K-25 13-3/8" 1997' 1997' 11.5 @ shoe MD/2202' TVD with 9.1 ppg mud pumped away @ 250 psi. Originally known as K-8, no LOT on 4/16/68. K-26 had 9-5/8" cut and pulled and an open hole kick-off: LOT on 12/23/93 @ 2946' K-26 13-3/8" 2571' 2396' 14.6 @ shoe . MD/2716' TVD with 8.7 ppg mud pumped away @ 735 psi. K-30RD 13-3/8" 2187' 2012' No leak-off test performed below 13-3/8" shoe, 1/29/70 Tim Billingsley KS surf csg cmt and LOTsummary.xlsLOTs 1/23/01 K-19 Annular Disposal Evaluation Subject: K-19 Annular Disposal Evaluation Date: Mon, 22 Jan 2001 09:30:25 -0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: Tom Maunder <tom_maunder@admin.state.ak. us>, Wendy D Mahan <wendy_mahan@admin.state.ak. us> Morning All, I just spoke with Tim Billingsley re the outstanding info needed before we can complete our review of Unocal's request to perform annular disposal down King Salmon well K-19. Cement Info on wells winthin 1/4 mile radius: Is already included as an attachment with the original submission. LOT Info on wells within 1/4 mile radius: Tim will compile and submit. He indicates that not all of the wells on the platform may have had LOT's done. I asked him to include those wells in his summary and to simply note "no LOT performed". Previous Annular Disposal on the platform:Per Tim Billingsley research there has been no previous annular disposal down any well on the King Salmon platform. Tim also indicates they expect to begin drilling on the King Salmon platform about this time next month. Julie 1 of 1 1/22/01 9:30 AM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALd Dan Williamson Drilling Manager December 28, 2000 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Dan Seamount Sundry Application (Form 10-403) McArthur River Field King Salmon Platform, Well K-19 Application for Annulus Injection Commissioner Seamount: Enclosed is a Sundry Application (Form 10-403) for King Salmon Well #K-19. This well is currently a Hemlock/G-zone gas lifted producer. Unocal requests permission to dispose of oil-based mud and cuttings from the upcoming drilling program at King Salmon into the 9-5/8" x 13-3/8" annulus at K-19. The planned drilling program will potentially more redrills at K- 18RD and a Jurassic redrill from a yet-to-be determined King Salmon well later in the first half of 2001. There will also be subsequent Sundry Applications for annulus disposal at 4 other wells at King Salmon in case the K-19 annulus becomes plugged during disposal operations. These proposed disposal annuluses are K-6RD, K-12RD, K-25 and K-26. The attached pages provides information required under 20 AAC 25.080 regarding annulus disposal including a summary of all the surface casing cement jobs at King Salmon. The expected start date for annulus disposal is January 20, 2001 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263-7677 or Tim Billingsley at 263-7659. Dan Williamson Drilling Manager RECEIVED DEC 3~I000 Alaska Oil & Gas Con~.~mission Anchorage AOGCC cover letter K-19.doc Tim Billingsley STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: Annular Injection 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 100' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface ,/ -'/ 8. Well number 699' FSL & 76' FEL of Sec. 1, T9N, R13W, SM King Salmon K-19 At top of productive interval 9. Permit numbe~/. 2825' FSL & 2937' FEL of Sec 11, T9N, R13W, SM 74-0008-0 At effective depth 10. APl number 2668' FSL & 2937' FEL of Sec 11, T9N, R13W, SM 50- 733-20259-00 At total depth 11. Field/Pool 2648' FSL & 2974' FEL of Sec 11, T9N, R13W, SM McArthur River/Hemlock Pool 12. Present well condition summary Total depth: measured 13,418 feet Plugs (measured) true vertical 9,571 feet Effective depth: measured 13,360 feet Junk (measured) None true vertical 9,531 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 381' 24" Circ to Surf 381' 381' Surface 2591' 13-3/8" 1750 sx circ to surf 2591' 2302' Intermediate Production 12,782' 9-5/8" 800 sx Class G 12,782' 9143' Liner 4,077' 7" 1000 sx 13,756' 9792' Perforation depth: measured 12592'-12644', 12677'-12716', 12808'-12848', 12882'-12892', 12914'-12988', 12994'-13020', 13060'-13090', 13096'-13314', 13340'-13415', 13460'-13545' ' true vertical 9001'-9053', 9074'-9100', 9160'-9186', 9209'-9215", 9230'-9279', 9282'-9301', 9326'-9349', 9350'-9484', 9502'-9553', 9582'-9638' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, N-80 @ 9688', 3-1/2", 9.2#, N-80 @ 12,660' Packers and SSSV (type and measured depth) Baker FB-1 packer @ 12,616', Baker D Isolation pkr @ 13,420', 4-1/2" Camco TRDP-4A tubing retrievable SSSV @ 274' 13. Attachments Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 1/15/00 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: ~ iamson Title: Drilling Manager Date: /z. ~' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity.__ BOP Test Location clearance. I Mechanical Integrity Test~ Subsequent form required 10- ~"<Z~ ~ RECEIVED DEC B 8 Z00O oRiGiNAL $1('-'., /* ¥: I.)t';', ORIGINAL SIGNED BY D Taylor Sea:mc)om Approved by order of the Commissione/A~aska Oil & ~ (T~.~lt~x:)E~ias~U nt -, AndloFcge Commissioner Date (~"' ~2_. Form 10-403 Rev 06/15/88 AFE #140086 ORIGINAL SUBMIT IN TRIPLICATE Information Required for Annulus Disposal of Drilling Waste 20 AAC 25.080 1 Annulus to be used for disposal' K-19, 9-5/8" x 13-3/8" annulus, 13-3/8" shoe is at 2591' MD/2302' TVD. 2 Depth to the base of freshwater aquifers and permafrost There is no permafrost at the King Salmon platform. At the 13-3/8" casing shoe depth of 2591' MD/2302' TVD, the formation waters exceed 6000 ppm chlorides. Aisc, there is a fresh water exemption for wells at the King Salmon platform. Strati_qral~hic description of the interval exposed to the open annulus and other information sufficient to support a commission findinq that the waste will be confined and will not come to the surface or~ except toh the extent allowed under (e) 1 of this section, contaminate freshwater The 13-3/8" shoe' is at 2591' MD/2302' TVD. This corresponds to the Middle Tyonek formation. The waste is expected to be confined within this strata as this is the primary gas trap in the McArthur River Field with no evidence of surface breaching. 4 List of all publicly recorded wells within 1/4 mile~ and all publicly recorded water wells within one mile~ of the well that will be receiving drilling waste The attached plat shows the adjacent wells to King Salmon K-19. 5 Types and maximum volume of waste to be disposed of and the estimated density of the waste slurry The waste will consist of 9.0 ppg oil base mud with small concentrations of drill cuttings mixed with high concentrations of fresh wash water (appx. 90/10 ration of water/OBM). The density of the waste will be appx. 8.8 ppg. Seawater will be injected ahead and behind the waste slurry injections. The estimated maximum volume from the four redrills to be. disposed of is 8,000 bbls OBM/water and 26,000 bbls seawater. Description of any waste souqht to be determined as drillinq waste under (h)(3) of 20 AAC 25.080(h)(3) Other substances that the commission determines upon al~l~lication are wastes associated with the act of drilling a well permitted under 20 AAC 25.OO5. None at this time. 7 Estimate of the maximum anticipated pressure at the outer casinq shoe durin.q disposal operations and calculations showincl how this value was determined. An injectivity test was performed on the 9-5/8" x 13-3/8" annulus of K-19 on 10/25/00 and ---~1000 BWPD was injected at 1500 psi. This 1500 psi will be the maximum injection pressure while disposing of mud and cuttings down the K-19 annulus. The proposed 1500 psi limit on injection pressure will not cause a problem with 13-3/8" casing burst or 9-5/8" casing collapse as shown in item #9. RECEIVED DE 8 Z000 -- ['-'--~Z)~c,~--.~"'X,~Alaska 0il & Gas Cons. Commission \, Anchorage uJ uJ Details that show that the shoe of the outer casinq is set below the base of permafrost, if present, and any freshwater aquifer~other than freshwater excepted under (e)(1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include (A) cementing records; and (B) a cement quality Icg or formation integrity records; The 13-3/8" shoe was set at 2591' MD/2302' TVD which is below any freshwater aquifer. (A) The casing was cemented on 2/27/74 with 1425 sx (2533 cuff or 451 bbls) of 13.1 ppg lead cement and 325 sx (67 bbls) of 15.8 ppg tail cement. Full returns were observed throughout the job with 800 cuft (143 bbls) of 13.1 lead cement circulated to surface. (B) No bond Icg was run on the 13-3/8" casing. The leak-off test after drilling out below the 13-3/8" casing shoe on 3/1/74 was 11.3 ppg EMW. 9 Details that show that the inner and outer casinq strings have sufficient stren_~th in collapse and burst to withstand the anticipated pressure of disposal operations: The 13-3/8" outer casing in K-19 is 61#, K-55 which has a burst rating of 3090 psi for new pipe. Therefore, the anticipated maximum injection pressure of 1500 psi will not be a problem and will only be 49% of new pipe. The 9-5/8" inner casing in K-19 is as follows: 47#, L-80 from surface to 2556', collapse rating = 4750 psi 40#, N-80 from 2556' to 3541 'MD/2976' TVD, collapse rating = 3090 psi 40# JL-95 from 354.1' to 5003'/3937' TVD, collapse rating = 3330 psi 47# USS-95 from 5003' to TD of 10,047'., collapse rating = 5080 psi The collapse force exerted by the anticipated maximum injection pressure to 1500 psi on the 9-5/8" x 13-3/8" annulus would be: (1500 psi + (8.8 ppg x .052 x TVD)) minus the internal gas lift pressure on the 9-5/8" x tbg inner annulus which is 1020 psi. The worst case would be at the bottom of the 40# N-80 which would be: ((1500 psi + (8.8 ppgx.052x2976'))-1020 psi =1841 psi = 60% of new collapse rating or the bottom of the 40# JL-95 which would be: ((1500 psi + (8.8x.052x3937'))-1020 psi = 2282 psi = 69% of new collapse rating These collapse pressure should be acceptable and there will be a requirement placed on the annulus disposal crews to verfiy that the K-19 inner annulus does have 1020 psi in gas lift pressure before injecting in the outer 13-3/8" x 9-5/8" annulus. The injectivity test on 10/25/00 indicated the formation below 2591' MD/2302' TVD %~ '~,~,'\~ will readily take fluid at 1500 psi. The actual disposal pressure will be probably be less than 1500 psi but will not be allowed to exceed 1500 psi. 10 The downhole pressure obtained durinq a formation inteqrity test conducted below the outer casing shoe; On 3/1/74, a leak-off test was performed after drilling out the 13-3/8" shoe to 2637' MD/2336' TVD with 8.6 ppg mud. The pressure built to 325 psi before leaking off which equates to a 11.3 ppg EMW. There was no indication that any circulation was observed at surface so this would indicate a frac gradient of .59 psi/ft. On 10/25/00, an injectivity test with 8.5 ppg filtered inlet water was performed down the 9- 5/8" x 13-3/8" annulus of K-19. The test injection rate was 1000 BPD at 1500 psi. The 13-3/8" x 24" annulus was monitored during this test. There was no communication up to the 24" conductor set at 381' during the injectivity test. Due to the Iow frac gradient and the record of good 15.8 ppg tail cement around the 13-3/8" shoe, all of the injection was entering the formation below the 13-3/8" shoe and not migrating around and up the outside of the 13-3/8" casing shoe. As per 20 AAC 25.080(e)(2), Unocal requests the AOGCC to grant an exception for the downhole disposal pressure exceeding the downhole pressure obtained during the formation integrity test conducted below the outer casing shoe in 1974. The proposed maximum disposal pressure of 1500 psi at the surface with 8.8 ppg disposal slurry as opposed to the 325 psi with an 8.6 ppg mud during the leak off test in 1974 is justified due to the good 15.8 ppg tail slurry pumped at the 13-3/8" casing shoe with cement circulated to surface, the evidence of no communication up to the 24" conductor shoe at 381' during the injectivity test, and the geological interpretation that the Middle Tyonek formation is sufficiently confined with no evidence of surface breaching in the McArthur River Field. 11 Identification of the hydrocarbon zones, if any, above the depth to which the inner casing is cemented; The 13-3/8" shoe is at 2591' MD/2302' TVD and the 9-5/8" shoe is at 12,782' MD. There was no bond Icg run on the 9-5/8" casing but 800 sx of 15.5-15.8 ppg cement were pumped for the 9-5/8" casing on 3/27/74 with a calculated top of cement at 8560' MD. This calculated TOC is based on the following: 800 sx x 1.15 yield x.1781 = 164 bbls of cement pumped Job notes on 3/27/74 state that "25 bbls of mud were lost while displacing cmt" 164 bbls - 25 bb.ls - 139 bbls of cement net Float track: 87' x .0732 bbl/ft of 47# csg - 6.4 bbls Rathole -10104'TD - 10047' csg shoe = 57'x .0146 bbl/ft of 12-1/4"hole - 8.3 bbls Cement behind pipe - 139-6.4-8.3 = 124.3 bbls ,, ' No caliper, annulus size - .0558 bbl/ft of 12-1/4 hole x 9-5/8" csg Cement behind pipe - 124.3 bbl/(.0558x1.5 for est 50% washout) - 1485' of cement TOC = 10,047' - 1485' = 8560' The open annulus in K-19 is therefore from 2591' MD/2302' TVD to 8560' MD/6260' TVD which is in the Middle Tyonek of the Northwest Feature of the McArthur River Field. This interval is Iow on structure and there are no hydrocarbon zones present. 12 The duration of the disposal operation, not to exceed 90 days; Unocal requests permission to use K-19's 9-5/8" x 13-3/8" annulus for oil based mud and cuttings disposal for more than 90 days. It is anticipated that the workover/drilling program at King Salmon will be 4 workovers and up to 4 major redrills which could last from January 10, 2000 to September 1, 2000. Disposal operations for the drilling mud from the four drilling wells should be completed by October 1,2000. 13 Whether drillinq waste has previously been disposed of in the annular space of the well and, if so, a summary of the dates of the disposal operations~ the volumes of waste disposed ofT and the wells where the drillinq waste was clenerated; No drilling waste has previously been disposed of in the annular space of K-19. 14 The well where the drillinq waste to be disposed of was or will be generated; The 2001 proposed drilling program consists of K-1RD, K-13 RD, possibly K-18RD and possibly a Jurassic test from a King Salmon well to be determined. There will also be 4 workovers at K-15RD, K-24RD, K-30 and K-20. Fluids from these four workovers will not be disposed of in the K-19 annulus. 15 If the operator proposes not to comply with a limitation established in (d) of this section~ an explanation of why compliance would be imprudent; Compliance with section (d) limitations as outlined below will not be a problem. The commission will not authorize disposal of drilling waste (1) in a volume greater than 35,000 barrels through the annular space of a single well. (2) For a period longer than one year through the annular space of a single well (3) Into a hydrocarbon-bearing stratum; or (4) Through the annular space of a well not located on the same drill pad or platform as the drilling operation generating the drilling waste. 16 Any additional data required by the commission to confirm containment fo drillin(~ waste; ARCO Alaska, Inc. Traaing Bay Unit - King Salmon Platform .We! K- 19 API : 733-20259-00 Spud Date: 2-22-74 Completion Date: 5-17-91 Original RKB:100' MD Hanger Type: FMC 4-1/2" BTCx12" Top of Hemlock: 12808' Max Hole Angle: 51 deg @ 2304" MD Annulus Fluid:Sea water Last Revised: 6-17-91 All Depths are RKB MD to Top of Equlpment. Well Type: Producer New [~ Worko.v, er ~Z1 RKB foHanger: 35 Angle at Perforations: 46° Reason: New Completion Jewelry 1 274' 2 9688' 3 12581' 4 12616" 5 12646' 6 12660' 7 13420' 8 13441' 9 134,53" Camco TRDP-4A SSSV (ID = 3.813") 4-1/2" x 3-1/2" Cross-over Otis "X" Nipple (I.D. = 2.813") Baker "FB -1" Perm Packer Camco .'.w_p:]" Selective Nipple Tubing tail Baker Mod. "D" Perm Packer Camco "D" Nipple w/2.750" NoGo Tubing Tail 3 4 5-6 Casing and Tubing Size Wela'ht Grade 8 13-3/8" 61# K-55 9 9-5/8" 47# J-95 10 40# VSS-95 11 7" 29# 12 4-1/2" 12.6# L-80 13 3-1/2" 9.3# L-80 14 Gas Uft Information Thread ToD Bottom 35" 2591" 35' 10047' 9679' 13756' BTC 35' 9688' BTC 9688" 12660' Depth Stn. TVD Mandrel TYpe Valve 2532' 1 2260' MA 4-1/2" CM-2 4445" 2 3576' MA 4-1/2" CM-2 6133" 3 4678" MA 4-1/2" CM-2 7526" 4 5591' MA 4-1/2" CM-2 8611" 5 6293" MA 4-1/2" CM-2 9509" 6 6877' MA 4-1/2" CM-2 10285" 7 7388" MA 3-1/2" CM-2 10995" 8 7881" MA 3-1/2" CM-2 11669' 9 8367" MA 3-1/2" CM-2 Casing Casing Casing liner Tubing Tubing Latch PortSz TRO Psc R K 16 1165 1220 RK 16 1175 12:Xl R K 20 1230 1182 R K 20 1230 1163 RK 24 1285 , 1136 RK 24 1280 1118 R K 24 1275 1101 RK 24 1265 1079 RK 24 1200 999 7,9 Perforation Data - DIL depths Zone ToD-MD/SS Perf Irlterval FT SPF. 0 12808'/9161' 12808-12848'40 4/9 1 12880'/9208" 12882-12892' 10 9 2 12910'/9227" 12914-12988'74 9/13 12994-13020' 25 9/13 3 13059"/9324' 1306~13090'27 9/13 13096-13157' 61 9/13 4 13157"/9388' 13157-13314'157 5/13/17 5 13338'/9516" 13340-13415'74 9/21 6 13456"/9597' 1346G1~" 41 5 7 13555'/9662' 13594-13604' sqzd 13615-13645' sqzd PBTD = 13713' MD TD = 13771"MD Datum = 13099' MD (9350' SS, 9450' TVD) Gauge Ring and Fill Level Data Date ~;ize Depth .C. ommerlts 5-4-91 13713' Final wa Depth RECEIVED ^laska Oil & Gas Cons. Commission An~or~e King Salmon Platform Surface Casing Cement Summary Well Surf Csg Size Shoe MD Shoe TVD Cmt Volume, sx Comments K-1 RD 13-3/8" 2384' 2147' 2608+80 Tag firm cmt at 82', pump 80 sx top job with cmt to surf K-2RD 13-3/8" 2372' 2298' 2608+450 Lost returns during prima~ iob, pump 450 sx top job @ 350' with cmt to surf K-3RD 13-3/8" 2506' 2337' 1560 No top iob required No cmt to surf on 3675 sx primary job. Top job found TOC @ 125', pump 125 sx with K-4RD 13-3/8" 2880' 2769' 3675+125 good cmt to surf K-5 13-3/8" 2476' 2252' 1625 Cmt returns to surf K-6RD 13-3/8" 2186' 2088' 1550 Cmt returns to surf K-7RD 13-3/8" 3618' 3039' 1600 650 sx 1st stage and 950 sx thru DV tool @ 1480' K-9 13-3/8" 2492' 2360' 1625 No top job required K-10RD; 13-3/8" 4998' 3883' 2255 1300 sx 1 st stage, 955 sx thru DVT @ 1511 ', 335 sx cmt returns to surf K-11 13-3/8" 2470' 2400' 1550 Cmt circ to surface, 500 cuff K-12RD 13-3/8" 2510' 2429' 1500 Cmt circ to surface, 150 sx. K-13RD 13-3/8" 5011' 4166' 1050+200 650 sx 1st stage, 400 sx thru DVT @ 2509', 200 sx top job @ 180' with 25 sx to surf K-15RD 13-3/8" 2401' 2284' 1550 Cmt circ to surf, 500 cuff K-17 13-3/8" 2183' 2032' 1371 Cmt circ to surf, 350 cuff K-18 13-3/8" 2477' 2283' 1800 Cmt circ to surf, 1030 cuff K-19 13-3/8" 2591' 2302' 1750 Cmt circ to surface, 800 cuff K-20 9-5/8" 4999' 2899' 2325 1400 sx 1st stage, 925 sx thru DVT @ 1396', circ 150 sx cmt to surf on 2nd stage K-21 RD 13-3/8" 2714' 2390' 1775 Cmt circ to surface, 798 cuff K-22RD 13-3/8" 5493' 4825' 2200+500 1500 sx 1st stage, 700 sx thru DVT @ 2881 ', 500 sx (905 cuft) bradenhead top job K-23 13-3/8" 5005' 3940' 2387 Cmt circ to surface K-24RD 13-3/8" ~ 5712' 4229' 2412 Cmt circ to surface, 798 cuft K-25 13-3/8" 1997' 1997' 1260 Originally known as K-16, cmt circ to surface K-26 13-3/8" 2571' 2396' 1750 Originally known as K-8, cmt circ to surface, 420 sx. K-30RD 13-3/8" 2187' 2012' 1490 Cmt circ to surface Tim Billingsley KS surf csg cmt summary.xls 12/21/00 M DLE RIVER ST 2 K I8 FORELAN K-19 ~ K 3RD G-29RD K- 4RlY K 7 K - 2 RD ~ {OH) N-6 K 1 } M Unocal Corporationii It Oil & Gas Operations ~ 909 West 9th Avenue, P.O. ~ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) October 19, 1995 Alaska 0CT 2 $ ~995 Alas~ i~i~ & Gas Cons. Commissio~ A~chorage Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: King Salmon Platform Well K-19 APl Number 50-733-20259-00 On June 10, 1995 the following intervals were perforated in Well K-19: BENCH TOP (MD) BOTTOM (MD) FEET G5 12,592 12,642 50 TOTAL 50 Very truly yours, '/i '? ~ · ' Candace Williams Attachment ,(' ,~,,, '~TATE OF ALASKA ,,,' ALASKA OIL AI~L~ GAS CONSERVATION CO~,,,,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pluggi~ __ Pull tubing After casin~l Repair well 2. Name of Operator 5. Type of Well: Development ~x UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory __ 3. Address Stratigraphic __ P.O. BOX 196247 ANCHORAGE~ AK 99519- 6247 Service 4. Location of well at surface Leg 1, Cond. 6, King Salmon Platform Perforate X Pull tubin,q Other 6. Datum elevation (DF or KB) 100' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 699' N, 76' W from SE Cor., Sec. 1, T9N, R13W, SM At top of productive interval 2825' N, 2937' W from SE cor., Sec. 11, T9N, R13W, SM At effective depth 2668' N, 2937' W from SE Cor., Sec. 11, T9N, R13W, SM At total depth 2648' Nr 2974' W from SE Cor. r Sec. 11~ T9N~ R13W~ SM 2. Present well condition summary Total depth: measured 13,418 true vertical 9,571 feet Plugs (measured) feet Effective depth: measured 13,360 feet Junk (measured) true vertical 9,531 feet K-19 9. Permit number 74-0008-0 10. APl number 50-733-20259-00 11. Field/Pool McArthur River/Hemlock Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2591' 13-3/8" 2,591' 2,302' Intermediate Production 12,782' 9-5/8" 12,782' 9,143' Liner 4,077' 7" 13,756' 9,792' 13. 14. Perforation depth: measured 12592-12644; 12677-12716; 12808-12848; 12882-12892; 12914-12988; 12994-13020; 13060-13090; 13096-13314; 13340-13415; 13460-13545 true vertical 9001-9053; 9074-9100; 9160-9186; 9209-9215; 9230-9279; 9282-9301 9326-9349; 9350-9484; 9502-9553; 9582-9638 Tubing (size, grade, and measured depth) ~. .,' 4-1/2", 12.6#, N-80 @ 9675'; 9.2# N-80 @ 12,782' ~, Packers and SSSV (type and measured depth) Baker F-1 pkr. ~ 12~707'; Brown isolation pkr. (~ 13r420' Stimulation or cement squeeze summary ~JC'r ~. ~ ~ Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. Commission ~nch0rage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 6/8/95 311 189 612 1170 90 --Subsequent to operation 6120/95 329 119 709 1140 120 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the fox i is tr ~ n c rec e~best of my knowledge. Signed G. RussellSchmidi{~ -~~tle Drilling Manager Date j~0/~/~_(~ Form 10-404 Rev 06/15/88 ~ SUBMIT IN DUPLICATE Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 April 5, 1995 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: On August 26, 1994 the following intervals were perforated in well K-19 (AP150-733-20259-00) in the McArthur River Field: BENCH TOP (MD) BOTTOM (MD) G5 12,622 12,644 22 G5 12,677 12,716 39 TOTAL 61 Sincerely, ,. ., FEET RECEIVED APR 2 0 199,5 Alaska Oil & Gas Cons. Co~mission Anchorage STATE OF ALASKA ALAS( , OIL AND GAS CONSERVATION ~ MMISSlON REPOR'r OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Pull tubing __ Alter casing__ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Plugging __ Perforate X__ Repair well __ Pull tubing __ Other__ 5. Type of Well: Development X_ Exploratory __ Stra§graphic __ Location of well at surface King platform, Leg #1, Conductor #6 699' N, 76' W from SE Cor., Sec. 1, T9N, R13W, SM At top of productive interval 2825' N, 2937' W from SE Cor., Sec. 11, T9N, R13W, SM At effective depth 2668' N, 2937' W from SE Cor., Sec. 11, T9N, R13W, SM At total depth 2648' N, 2974' Wfrom SE Cor., Sec. 11, T9N, R13W, SM 6. Datum elevation (DF or KB) KB: 100' 7. Unit or Property name Trading Bay Unit 8. Well number K-19 feet 9. Permit number/approval number 74 -0008 -0 10. APl number 50-733-20259-00 11. Field/Pool McArthur River/Hemlock, G 12. Present well condition summary Total depth: measured 13418 feet true vertical 9571 feet Effective depth: measured 13360 feet true vertical 9531 feet Plugs (measured) Junk (measured) ORIGtNA, L Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured depth True vertical depth 2591' 13-3/8" 2591' 2302' 12,782' 4077' Perforation depth: measured 9-5/8" 12,78Z 9143' 7" 13,756' 9792' 12622-12644,12677-12716,12808-12848,12882-12892,12914-12988,12994-13020, 13060-13090,13096-13314,13340-13415,13460-13545 true vertical 9038-9053, 9074-9100, 9160-9186, 9209-9215, 9230-9279, 9282-9301,9326-9349, 9350-9484, 9502-9553, 9582-9638 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 9675'; 9.2#, N-80 @ 12,782' Packers and SSSV (type and measured depth) Baker F-1 pkr. @ 12,707'; Brown isolation pkr~j~3(4~2~' ~ ~/~, r~ 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) AiDE 2. 0 199,5 Treatment description including volumes used and final pressure Anchorat~..~ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Copies of Logs and Surveys run Daily Report of Well Operations __ 17. I her~;)y ce[tify that_the foregoing is t.rue..and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 311 151 629 1130 100 341 // 26 641 1140 100 Status of well classification as: Oil X_ Gas __ Suspended __ Service SUBMIT IN DUPLICATE Unocal North Americap Oil & Gas Division ? Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 August 15, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforat~ the following intervals in well K-19 (API# 50~733-20259-00) on the King platform. BENCH 'roP (M, D,I BOTrOM (MD,) G-5 12,622 12,644 22 G-$ 12,652 12,672 20 G-5 12,677 12,716 39 TOTAL 81 FEET STATE OF ALASKA ALASK,.i ~IL AND APPLICJ.., ION 1. Type of request: Abandon __ Suspend __ Alter Casing__ Repair well Change approved program __ 2. Name of Operator Unocal 3. Address P.O. Box 196247 Anchorage, Alaska 99519-6247 4. Location of well at surface Pull tubing __ Variance __ 5. Type of Well: Service__ King Salmon Platform, Leg 1, Conductor 6 Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension __ Stimulate __ Perforate X Other 6. Datum elevation (DF or KB) KB: 100' 7. Unit or Property name Trading Bay Unit 8. Well number 699' N, 76' Wfrom SE Cor., Sec. 1, T9N, R13W, SM At top of productive interval 2825' N, 2937' Wfrom SE Con, Sec. 11, T9N, R13W, SM At effective depth 2668' N, 2937' W from SE Con, Sec. 11, T9N, R13W, SM At total depth 2648' N, 2974' W from SE Cor., Sec. 11, T9N, R13W, SM 12. Present well condition summary Total depth: measured 13418 feet true vertical 9571 feet Effective depth: measured 13360 feet true vertical 9531 feet RECEIVED Ai~,,sk~ u~i & Gas Con~, Commi: Anchor:.:~e Plugs (measured) Junk (measured) K-19 9. Permit number 74 -0008 -0 10. APl number 50-733-20259-00 ~i~loField/Pool McArthur River/Hemlock feet Casing Length Size Structural Conductor Surface 2591' 13-3/8' Intermediate Cemented Measured depth True vertical depth 2591' 2302' Production 12782' 9 -5/8" 12782' 9148' Liner 4077' 7" 13756' 9792' Perforation depth: measured 12808-12848, 12882-12892, 12914-12988, 12994-13020, 13060-13090,13096-13314, 13340-13415, 13460-13545 true vertical 9160-9186, 9209-9215, 9230-9279, 9282-9301,9326-9349, 9350-9484, 9502-9553, 9582-9638 Tubing (size, grade, and measured depth) 4-1/2" 12.6#, N-80, BTC @ 9675'; 3-1/2', 9.2#, N-80, BTC @ 12782' Packers and SSSV (type and measured depth) Baker F-1 pkr. @ 12707', Brown isolation pkr. @ 13420' 13. Attachments Description summary of proposal X_ Detailed operations prograrn,~__ BOP sketch Questions? Call John Paul McKee @ 263-7680 or Ralph Holman @ 263-7838 14. Estimated date for commencing operation J15. Status of well classification as: August 25, 1994 16. If proposal was verbally approved Oil X_ Gas _ Suspended __ Name of approver Date approved Service 17. I here[~lcertif~that t~gl~irlg is truj~N~d correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required 10- JApproval No. Approved by the order of the Commission Original Slgnea ~:~, David W. Johnston Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE August 19, 1994 King Platform, W~ll K-19 P¢ff0ra~ing Procedure 1. Hold safety meeting. 2. Rig up electric line unit. 3~ Pressure test lubricator to 2500 psi for five minutes. Note: A pump-in sub with a valve is required. 4. Shut down all welding and radio transmissions. . Run in hole and perforate intervals as instructed by Unocal wimess. (When gun is 200' below surface, welding and radio transmissions may resume.) . Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL G-5 12,622-12,644 22 G-5 12,652-12,672 20 G-5 12,677-12,716 39 FEET TOTAL: 81 /~UG 2 4 ~994 Gas Cons. Commissio' Anchora~'a ~I~ STATE OF ALASKA ~' ALAo¢~ OIL AND GAS CONSERVATION COMMI~ION O REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown w Alter casing Repair well 2. Name of Operator UNOCAL Corporation (ARCO Alaska. Inc. is sub-ooerator~ '3. Address P. O. Box 100247, Anchorage, AK 99519 Stimulate w Plugging Perforate X X Pull tubing ~ Other ~ 6. Datum elevation (DF or KB) 5. Type of Well: Development Exploratory Stratigraphic Service 100' RKB 7. Unit or Property name Trading Bay Unit 4. Location of well at surface Leg 1, Conductor 6, King Salmon Platform 699' FSL, 76' FEL, Sec. 1, T9N, R13W, SM RECEIVED At top of productive interval 2825' FSL, 2937' FEL, Sec. 11, TgN, R13W, SM At effective depth DEC - 2 1991 2668' FSL, 2937' FEL, Sec. 11, T9N, R13W, SM At total dept Naska 0il & Sas Cons. C0mmiss 2648' FSL, 2974' FEL, Sec. 11, T9N, R13W, SM 12. Present well condition summary .......... Total Depth: feet measured 1 3,7 71' feet Plugs (measured) true vertical 9,803' feet 8. Well number K-19 9. Permit number/approval number 7~-~ 7/187/91-077 10. APl number 50-733-20259 01~. Field/Pool McArthur River {Hemlock) Effective depth: measured 1 3,71 4' feet Junk (measured) true vertical 9,763' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,591' 1 3-/8" 2,591' md 2,302' tvd Intermediate Production 10,047' 9-5/8" 800 Sx Class G 10,047' md 7,226' tvd Liner 4,077' 7" 1000 Sx Class G 9,767'-13,756' md; 7045'-9,800' tvd Perforation depth' measured 12808'-1840', 13060'-13090', 12882'-12892', 13096'-13314', 12914'-12988', 12994'-13020', 13340'-13415', 13470'-13545' 9281'-9298', 9605'-9655' true vertical 9159'-9180', 9208'-9215', 9229'-9277', 9325'-9345', 9349'-9499', 9517'-9568', Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 @ 9,688' md X 3-1/2" 9.3# L-80 @ 12,660' md; 3-1/2" Tbg tail @ 13,453' below Isolation Pkr @ 13,420' md Packers and SSSV (type and measured depth) Baker 'D' Perm Pkr ~ 13~420' md~ Baker 'FB-I' Perm Pkr ~ 12~616'~ Camco 'TRDP-4A' SSSV @ 274' md 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re.oresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water- Bbl Casing Pressure Tubing Pressure Prior to well operation () Subsequent to operation () 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,~lnedForm 10-4q~Re~)5,17,~; ~)~~ Title ~;b-~ ~-~,~) ,, SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT K-19 KENAI BOROUGH TRADING BAY UNIT MCARTHUR FIELD ADL 17594 50-133-20259 7-187 APPROVAL: 91-077 ACCEPT: 04/11/90 06:00 RELEASE: 05/17/90 13:00 OPERATION: WORKOVER RIG: KING SALMON/ARCO #58 AFE: AD7028 WI: 18.1000% 04/18/91 ( 1) TD: 0 PB:13710 SUPV:RWS 04/19/91 (2) TD: 0 PB:13710 SUPV:RWS 04/20/91 (3) TD: 0 PB:13710 SUPV:RWS 04/21/91 ( 4) TD: 0 ?B:13710 SUPV:RWS 04/22/91 ( 5) TD: 0 PB:13710 SUPV:RWS 04/23/91 ( 6) TD: 0 PB:13710 SUPV:RWS 04/24/91 (7) TD: 0 PB:13710 SUPV:RWS POH LD TBG MW: 8.5 FSW FIN NUBOPE, TEST BOPE,KILL WELL AND MONITOR WELL, HELD SAFETY MEETING, POH WITH TBG DAILY:S108,272 CUM:$108,272 ETD:S108,272 EFC:$909,000 RIH W/ PRT TOOL MW: 8.5 FSW CONT POH W/ TUBING, CO FLOOR EQUIP,UNLOAD BOAT,PU PACKER RETRIEVING TOOL AND START PU DP AND RIH DAILY:S29,634 CUM:$137,906 ETD:S137,906 EFC:$909,000 POH W/ PKR MW: 8.5 FSW PU 3.5" DP & RIH,BREAK CIRC,CONT TO RIH,MILL 1' OF PACKER SQUEEZE LITESAL PILL CONT MILLING F/12707 T/12710,PU AND DRAG PACKER T/12677,MONITOR WELL NO LOSS, STAND BACK KELLY AND POH SLOWLY DAILY:S26,454 CUM:$164,360 ETD:S164,360 EFC:$909,000 MW: 8.5 FSW LD MILLED PACKER, PU 6" BIT AND RIH,DRLG JUNK AND CEMENT F/ 13394 T/ 13406, DRLG HARD CEMENT F/ 13406 T/ 13413,HARD DRLG T/13418,PUMP PILL AND POH, CONES GONE OFF OF BIT, SLIP AND CUT DRLG LINE DAILY:S3,459 CUM:$167,819 ETD:S167,819 EFC:$909,000 RIH W/ MILL MW: 8.5 FSW PU 6" BLADED JUNK MILL AND RIH,PU KELLY AND TAGGED JUNK AT 13415,MILL JUNK T/ 13420,POH W/ MILL, PU NEW MILL AND RIH REFACE 12 JTS OF 3.5" DP,CONT RIH. DAILY:S19,858 CUM:$187,677 ETD:S187,677 EFC:$909,000 POH W/REV CIRC JNK BSKT MW: 8.5 FSW , RIH W/MILL TO 13415 , BREAK CIRC, CIRC & WASH F/13415-13417' MILL JUNK FROM 13417'-13419', POH LD MILL & JB, CLEAN OUT BASKETS ( FULL OF PERF GUNS), PU & RIH W/REV CIRC GLOBE BASKET & BOOT BASKETS, BREAK CIRC, WASH F/13418'-13419' TOO FILL BOOT BASKETS, DROP BALL, PUMP DOWN & SEAT IN REV BASKET POH, 10-30K# EXCESS DRAG F/150', DAILY:S19,918 CUM:$207,595 ETD:S207,595 EFC:$909,000 RIH W/MILL MW: 8.5 FSW POH, LD GLOBE BSKT, & BOOT BSKTS, LITTLE METAL IN GLOBE-BOOT BSKTS FULL, RIH W/6" MILL & BOOT BSKTS, TAG JUNK @ 13220', PU KELLY & WORK JUNK FREE, TAG BTM @ 13419', FAN BTM & ATTEMPT TO FILL BSKTS, MILL ON JUNK F/13419-13421, NO TORQUE HARD MILLING, POH W/MILL, LD BOOT BSKTS-FULL, RIH W/NEWW 6" BLADED MILL & BOOT BSKTS. DAILY:S19,188 CUM:$226,783 ETD:S226,783 EFC:$909,000 I CEIVED DEC - 2 199' Alaska OJJ & Gas Cons. Commission Anchorage WELL: K-19 OPERATION: WORKOVER RIG: KING SALMON/ARCO #58 PAGE: 2 04/25/91 ( 8) TD: 0 PB:13710 SUPV:BRB 04/26/91 (9) TD: 0 PB:13710 SUPV:BRB 04/27/91 (10) TD: 0 PB:13710 SUPV:BRB 04/28/91 (11) TD: 0 PB:13710 SUPV:BRB 04/29/91 (12) TD: 0 PB:13710 SUPV:BRB RIH W/ WASHOVER SHOE MW: 8.5 FSW RIH W/JUNK MILL TO 13404', BREAK CIRC, WASH TO 13421', WORK JUNK BSKTS, NO FILL, MILL JUNK F/13421'-13422', POH, EXCESSIVE DRAG IN 7" CSG, LD CLEAN OUT JUNK BSKTS, PULL WEAR RING, SET TEST PLUG, TST BOPE 250 PSI LOW 3000 PSI HIGH, TST ANN 250 & 2000 PSI, LD TST PLUG, RUN WEAR BUSHING, RIH W/WASHOVER SHOE. DAILY:S20,508 CUM:$247,291 ETD:S247,291 EFC:$909,000 LD FISH MW: 8.5 FSW FRIH W/WASHOVER SHOE, BRK CIRC @ 13412', MILL OVER FISH F/13422'-13435', CIRC HI VIS SWEEP, SET DOWN 25000# ON JUNK, SET BACK KELLY POH, JUNK ON TOP OF SHOE WORK OUT OF HOLE TO 13287', PIPE PULLED FREE, POH, NO DRAG, BREAK & CLEAN JUNK BSKTS, LD MILL SHOE, BADLY WORN, MU 5-3/4" OVERSHOT W/2" BASKET GRAPPLE,R RIH, BREAK CIRC, WORK OS OVER FISH, SAW INCREASE IN PUMP PRESSURE, POH, RECOVER 9.44' 2" OD WIRELINE WT BAR, LD FISH, DAILY:S20,665 CUM:$267,956 ETD:S267,956 EFC:$909,000 POH MW: 8.5 FSW PU BHA AND RIH TO CATCH FISH,POH NO FISH,MU IMPRESSION BLOCK RIH,C&S DRLG LINE,FINISH RIH,TAG FISH,CIRC BOTTOMS UP,POH DAILY: $20,611 CUM: $288,567 ETD: $288,567 EFC: $909,000 POH MW: 8.5 FSW POH W/ IMPRESSION BLOCK, MU OVERSHOT,RIH,PERFORM PLATFORM FIRE DRILL, SECURE WELL, WORKED OVER FISH, POH LD 10' OF FISH RIG SERVICE,MU IMPRESSION BLOCK, RIH, SET IB AND POH DAILY:S18,411 CUM:$306,978 ETD:S306,978 EFC:$909,000 POH MW: 8.5 FSW POH W/ IB,MU MILL AND RIH,BREAK CIRC, TAGG JUNK AT 13434,MILL T/13510,POH DAILY:S21,462 CUM:$328,440 ETD:S328,440 EFC:$909,000 04/30/91 (13) TD: 0 PB:13710 SUPV:BRB POH MW: 8.5 FSW LD MILL AND BOOT BASKETS,PU WO SHOE,RIH,CUT AND SLIP DRLG LINE,RIH,BREAK CIRC AND WASH OVER FISH F/13512 T/ 13520 REVERSE CIRC,POH, LD WO SHOE,MU OVERSHOT RIH,BREAK CIRC, TAG FISH @ 13517,POH DAILY:S19,985 CUM:$348,425 ETD:S348,425 EFC:$909,000 05/01/91 (14) TD: 0 PB:13710 SUPV:BRB POH MW: 8.5 FSW POH, CHANGE OUT OVERSHOT,RIH, TAGGED FISH,POH,NO FISH,REPAIR RIG, RIH W/ GRAPPLE TAG FISH, POH DAILY:SO CUM:$348,425 ETD:S348,425 EFC:$909,000 05/02/91 (15) TD: 0 PB:13710 SUPV:BRB 05/03/91 (16) TD: 0 PB:13710 s £ £1V£D DEC - 2. 1991 POH W/ FISH MW: 8.5 FSW FIN POH W/ IMP BLOCK, PU OVERSHOT AND RIH,WORK ON RIG,WASH OVER FISH,PULLED 20K BUT GRAPPLE SLIPPED,POH, HELD SAFETY MEETING, REDRESS OVERSHOT,RIH,CUT AND SLIP DRLG LINE,RIH, GRAB FISH, PULLED 150K OVER, FISH FREE,POH W/ FISH BACKED OUT RIG MOB COSTS OUT OF DAILY COSTS. DAILY:S-33,773 CUM:$314,652 ETD:S314,652 EFC:$909,000 TESTING BOPE MW: 8.5 FSW CONTINUE POH W/ FISH, LD FISH & FISHING BHA, PU BLADED MILL, SERVICE RIG, TIH WASH & REAM TO 13502, TAG CMT & JUNK, MILL TO 13591, RETAINER AT 13575, MILL QUIT, POH, LD 6" MILL & 4 BOOT BASKETS & CLEAN OUT, PULL WEAR BUSHING, SET TEST PLUG, TEST BOP'S. DAILY:S19,585 CUM:$334,237 ETD:S334,237 EFC:$909,000 ,Alaska Oil & Gas Cons. uomrnkssion Anchorage WELL: K-19 OPERATION: WORKOVER RIG: KING SALMON/ARCO #58 PAGE: 3 05/04/91 (17) TD: 0 PB:13710 SUPV:RWS 05/05/91 (18) TD: 0 PB:13710 SUPV:RWS 05/06/91 (19) TD: 0 PB:13710 SUPV:RWS 05/07/91 (20) TD: 0 PB:13710 SUPV:RWS 05/08/91 (21) TD: 0 PB:13710 SUPV:RWS 05/09/91 (22) TD: 0 PB:13710 SUPV:RWS 05/10/91 (23) TD: 0 PB:13710 SUPV:RWS 05/11/91 (24) TD: 0 PB:13710 SUPV:RWS 05/12/91 (25) TD: 0 PB:13710 SUPV:RWS POH W/ MILL MW: 8.5 FSW TEST BOPE,PU MILL AND RIH,RIG REPAIR,MILL ON CMT AND JUNK CIRC, POH W/ MILL WORK ON IRON ROUGHNECK, CONT POH DAILY:S19,585 CUM:$353,822 ETD:S353,822 EFC:$909,000 POH W/ SCRAPER MW: 8.5 FSW LD MILL, PU & RIH W/ CSG SCRAPER, SHIP CONTAMINATED PIT FLUID TO TRADING BAY CIRC HOLE CLEAN, POH LD SCRAPER, CUT AND SLIP DRLG LINE,RIH W/ 7" SCRAPER, CIRC HOLE CLEAN, POH DAILY:S52,627 CUM:$406,449 ETD:S406,449 EFC:$909,000 C 0 PACK-OFF MW: 8.5 FSW POH & LD SCRAPER, PU BP AND RIH, SET @ 9858,TEST SAME TO 500 CHANGE OUT 9-5/8 PACK-OFF, TEST PACK-OFF TO 5000PSI,REPLACE LDS. DAILY:S20,024 CUM:$426,473 ETD:S426,473 EFC:$909,000 SBT LOGGING MW: 8.5 REPLACE LDS,PULL STORM PACKER, TEST CASING TO 2500PSI RETRIEVE RBP POH,RU ATLAS AND RUN VERTILOG AND SBT FSW DAILY:S31,640 CUM:$458,113 ETD:S458,113 EFC:$909,000 RIH W/ TCP MW: 8.5 FSW RD ATLAS,RIH W/ SCRAPER, REVERSE CIRCULATE,POH,HELD SAFETY MEETING, PU PERF GUNS RIH, RABBIT EACH STAND DAILY:S24,658 CUM:$482,771 ETD:S482,771 EFC:$909,000 POH W/ PERF GUNS MW: 8.5 FSW RIH W/ TCP,RU ATLAS AND CORRELATE LOGS,C 0 LOGGING TOOLS CORRELATE LOGS,OK, RD ATLAS, ADD 11 FEET TO STRING, PU FLOW CONTROL HEAD,DROP BAR, GUNS FIRED, UNSET PACKER, REVERSE CIRC 18 BBLS INFUX OF DIRTY FLUID,VERY LITTLE GAS, RD CIRC LINES POH W/ PERF GUNS DAILY:S20,357 CUM:$503,128 ETD:S503,128 EFC:$909,000 RU TO RUN PKR MW: 8.5 FSW LD PERF GUNS,ALL SHOTS FIRED,MU BIT AND RIH,CLEAN OUT WELL C&S DRLG LINE, ADJ BRAKES,WORK JUNK BASKETS,POH,LD DP,RU ATLAS TO RUN ISOLATION PACKER DAILY:S20,816 CUM:$523,944 ETD:S523,944 EFC:$909,000 RUNNING COMP STRING MW: 8.5 FSW RUN BAKER D PACKR, SET @ 13420,RUN BAKER FB-1 PACKR, SET @ 12645,RU TO RUN CA, RUNNING CA DAILY:S108,530 CUM:$632,474 ETD:S632,474 EFC:$909,000 SET TEST PLUG MW: 8.5 FSW FIN RUNNING CA, TAGGED PACKER, CIRC INHIBITOR, SPACED OUT AND LANDED TUBING SCREW IN LDS,RU PRECISION TO RUN TEST PLUG, DAILY:S195,133 CUM:$827,607 ETD:S827,607 EFC:$909,000 RECEIYED DEC - 2 99} Alaska Oi~ & Gas Cons. Commission Anchorage WELL: K-19 OPERATION: WORKOVER RIG: KING SALMON/ARCO #58 PAGE: 4 05/13/91 (26) TD: 0 PB:13710 SUPV:RWS 05/14/91 (27) TD: 0 PB:13714 SUPV:RWS 05/15/91 (28) TD: 0 PB:13714 SUPV:RWS 05/16/91 (29) TD: 0 PB:13714 SUPV:RWS 05/17/91 (30) TD: 0 PB:13714 SUPV:RWS SETTING PROFILE PLUG MW: 8.5 FSW SET TEST PLUG, FILL HOLE,TEST PLUG STILL ON RUNNING TOOL,RUN 2 FOR TEST PLUG, PLUG DID NOT SET,RUN PACK-OFF,TRY TO TEST NO GGOD, RIH AND FOUND TEST PLUG HAS FALLEN TO BOTTOM, LOOKED FOR G PLUG, RU TO RUN PLUG IN SLIDING SLEEVE DAILY:S24,315 CUM:$851,922 ETD:S851,922 EFC:$909,000 JARRING ON TBG PLUG MW: 8.5 FSW COULD NOT LOCATE X NIPPLE,RU TO CIRC WELL, REDRESS PLUG AND RUNNING TOOL, WORKED TOOL F/ 12645 T/11686 LOOKING FOR OTIS SSSV X PROFILE,COULD NOT FIND IT ORDERED OUT DD PLUG,MU DD PLUG AND RIH,PLUG SET EARLY @10360,POH,PU RETRIEVING TOOL AND RIH, RETRIEVED DD PLUG, POH,REDRESS TOOL AND RIH, PLUG SET @10360, PU PULLING TOOL AND RIH,LATCH ONTO PLUG AND JARR UP THE HOLE TO 10170,PLUG STUCK, JARR AGAIN, DRAG PLUG UP TO 10050,PLUG STUCK AGAIN,WORKING ON STUCK PLUG DAILY:S58,194 CUM:$910,116 ETD:S910,116 EFC:$909,00 RIH W/ CA MW: 8.5 FSW WORK STUCK PLUG IN TUBING T/9864,SHEAR OFF RUNNING TOOL, RIH W/ NEW TOOL, WORK PLUG LOOSE,POH, RD SLICKLINE,RU TO PULL TBG LD 4.5" TBG, RACK BACK 3.5"TBG BREAK OUT SLIDING SLEEVE, SEND ASSEMBLY TO KENAI TO REDRESS,RECIEVE SS,MU SS AND RIH W/ PLUG IN PLACE. DAILY:S30,695 CUM:$940,811 ETD:S940,811 EFC:$909,000 NU TREE MW: 8.5 FSW RIH W/CA, SPACE OUT AND LAND TBG IN NUETRAL, TEST TBG T/ 2500 TEST SSSV AND PACKER T/ 2500,TEST CONTROL LINES,LD LANDING JOINT,ND FLOWLINE AND NU FMC WELLHEAD,TEST HANGER PACKOFF. DAILY:S33,937 CUM:$974,748 ETD:S974,748 EFC:$909,000 RIG RELEASED MW: 8.5 FSW FINISHED NU, TEST TREE 250&5000PSI,RU PRECISION WL, RETRIEVE PX PLUG, RD PWL TURN WELL OVER TO PRODUCTION DAILY:S183,664 CUM:$1,158,412 ETD:S1,158,412 EFC:$909,000 SIGNATURE: DRILLI~~{~UPR~T DATE: D£O - 2 ~Cborage ARCO ALASKA INC. Cook Inlet Engineea/ng #540 TRANSMISSION TO:. COMMISSIONER COMPANY: AOCK2C DATE: 5/24/91 FROM: Victoria Fer~uson COMPANY: ARCO Alaska, Inc WF.I J~ NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia rape & Line Folded Rolled M}tlar listing SRU 32A-33 PFC LOG 1 1 ACBL 1 1 SRU 242-16 DUAL BURST THERM DEC 1 1 TBU K- 19 VERTILOG 1 1 SEGME~ BOND LOG 1 1 · Return reciept to ARCO ALASKA, Inc. ATrN: JudY Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Date: A ,~ OIL AND GAS CONSERVATION COM ,- .,,uN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Alter casing _ Repair well _ Plugging _ Change approved program_ Pull tubing ~. 2. Name of Operator I 5. Type of Well' I Development X UNOCAL (ARCO Alaska. Inc. Sub Ooeratorl Exploratory _ 3. Address I Stratigraphic _ P. O. Box 190247, Anchorage, AK 99519 I Service _ 4. Location of well at Leg 1, Cond.6, King Salmon Platform 699°N & 76'W from SE corner, Sec. 1, T9N, R13W, SM At top of productive interval 2825'N & 2937'W from SE corner, Sec. 11, T9N, R13W, SM At effective depth 2668'N & 2937'W from SE corner, Sec. 11, T9N, R13W, SM At total depth 2648'N & 2974'W from SE corner, Sec. 11, T9N, R13W, SM 12. Present well condition summary _ Re-enter suspended well _ Time extension Stimulate Variance _ Perforate _ Other X $. Datum elevation (DF or KB) RKB 100 7. Unit or Property name Trading Bay Unit 8. Well number K-19 9. Permit number 7-187 10. APl number 50-1 33-20259 11. Field/Pool Hemlock_. ,,EC[IVED feet Total Depth: measured 1371 O' feet Plugs (measured) true vertical 976 O' feet Effective depth: measured 1 342 6' feet true vertical 9 5 6 0' feet Casing Length Size Structural Conductor Surface 2 5 91 ' 1 3 - 3 / 8" Intermediate Production 1 0 0 4 7' 9 - 5 / 8" Liner 4 0 7 7' 7 Perforation depth: measured See attached sheet retainer(measured) Cemented Measured depth True ve~ical depth 2591' 2302' 1OO47' 7226' 13756 9800' true vertical 13, Tubing (size, grade, and measured depth 4-1/2", 12.6#, N-80, BTC W/ 3-1/2", 9.2# N-80, ABMOD @ 12782'MD .Packers and SSSV (type and measured depth)Baker F-1 packer @ 12707' MD Camco SSSV TRB-6 @ 303' MD Attachments Description summary of proposal _~. Detailed operation program _ BOP sketch ..~ 14. Estimated date for commencing operation April 1, 1~)~1 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Suspended _ 16. Service 17. I hereby .certify that the foregoing is true and correct to the best of my knowledge. couu ss , us o., Sgned ~~ %, (~,.~_~ Title 'ConditiOns of ap'prbval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance Mechanical Integrity Test Subsequent form ORIGINA'-L SIGNED BY LONNIE C. SMITH Approved by the order of the Commission require 10- ~c4' Commissioner IApproval No¢~.~ ~ ~ ~ Form 10-403 Rev 06/15/88 Approved Copy Returned L_ SUBMIT IN TRIPLICATE TBU K-19 WORKOVER GENERAL PROCEDURE PRE RIG 1. . Fill well with filtered inlet water with 2% KCI. Pump kill pills as necessary. Remove grating etc. from around tree in preparation for rig arrival. RIG OPERATIONS 1. Skid rig over TBU K-19, leg #1, slot 6. 2. Ensure well is standing full of 2% KCI/FIW. Pump kill pills as required. Set BPV. 3. ND tree. NU BOP and test same. 4. POH with 4-1/2" X 3-1/2" completion string (special handling procedures will be necessary due to presence of LSA scale) 5. GIH, mill over and retrieve 7" Baker F-1 packer at 12,707'. 6. Drill out retainer at 13,426' MD and recover packer left at 13,494' MD. Clean out to PBTD of 13,710' MD. 7. Make both a 9-5/8" and 7" scraper run to PBTD at 13,710' MD, do not rotate unless absolutely required. 8. GIH w/7" retrievable bridge plug to 9750'+. Replace the 9-5/8" x 13-3/8" packoff. 9. Test casing to 2500 psi for 30 minutes. If communication exists to 13- 3/8", do not exceed 500 psi. 9. If casing does not test, leave bridge plug set, POH and PU a 9-5/8" packer and isolate leak. 10. LD packer. Run a vertilog (or equivalent) in 9-5/8". Repair leak with either a casing patch, squeeze or both, depending on the depth of the leak. 11. GIH and retrieve the bridge plug. 12. Make a scraper run to PBTD and circulate hole clean. 13. RU wireline and run a CET (or equivalent) from PBTD to TOC or the minimum depth for the log, whichever is higher. 14. Evaluate channeling behind casing and squeeze as required. 15. Make a scraper run to PBTD and circulate hole clean. 16. GIH w/tubing conveyed perf guns and perforate Benches 0 - 6 under- balanced. 17. POH and LD DP. 18. RU wireline and make a gauge ring/junk basket run. Run a wireline set isolation packer. Then run a wireline set permanent packer. 19. Run a 4-1/2" X 3-1/2" completion with GLM's. 20. ND BOP. NU tree. Release rig. Estimated pressure: 3400 psi @ 9450' TVD - Hemlock K-19 APPLICATION FOR SUNDRY APPROVALS PERFORATION DEPTHS Existing perforations Interval 2808'-1 2882'-1 2914'-1 2994'-1 3060'-1 3096'-1 3157'-1 3341 '-1 3460'-1 3504'-1 3594'-1 3615'-1 2848' 2892' 2988' 3019' 3O87' 3157' 329O' 3415' 348o' 3545' 3604' 3645' 4O 10 74 25 27 61 133 74 2O 41 Squeezed off Squeezed off Planned perforations Interval MD 2808'-1 2882'-1 2914'-1 2994'-1 3060'-1 3096'-1 3157'-1 3340'-1 3470'-1 2840' 2892' 2988' 3020' 3090' 3157' 3314' 3415' 3545' 32 10 74 26 3O 61 157 75 75 TVD 9159'-9186' 9208'-9215' 9229'-9277' 9281 '-9298' 9325'-9343' 9349'-9391' 9391 '-9483' 9518'-9568' 9599'-9612' 9628'-9655' TVD 9159'-9180' 9208'-9215' 9229'-9277' 9281'-9298' 9325'-9345' 9349'-9391' 9391 '-9499' 9517'-9568' 9605'-9685' jt/mac 01/8/91 ARCO Alaska, Inc. Bay Unit - King Salmon Well K- 19 733-20259-[X] Spud Date: 2-22-74 Completion Date: 7-7-79 Original RKB:100' MD Hanger Type: OCT 12"X4-1/2" Top of Hemlock: 12808" Max Hole Angle: 51 deg lJ 2304' MD Annulus Fluid:Sea water Last Revised: 2-28-91 All Depths are RKB MD to Top of Equipment. Well Type: Producer New rJ Workover J~l RKB to~-Ianger: 35" Angle at Perforations: 46° Reason: Gauge Ring Data 2-4 Jewelry 1 2 12707' 3 12781' 4 12782' 5 13426' 6 13494' SSSV TRB-6 ID = 3.813" Baker "F -1" Baker shoe & shearout sub Tubing tail Retainer set 7-4-79 Packer pushed to 13494' 7-4-79 Car, lng and Tubing 8 13-3/8" 61# K-55 9 9-5/8' 47# J-95 10 40#VSS-95 11 7" 29# 12 4-1/2" 12.6# N-80 13 3-1/2' 9.2# N-80 35' 2591' 35' 10047' 9679' 13756' BTC 35' 9675' BTC 9675' 12782' 14 Gcls Lift Information Depth Stn. TVD Mandrel 2592' 1 2275' CA4-1/2" MMA R-20 4892' 2 3838' CA4-1/2" MMA R-20 6632' 3 4973' CA 4-1/2" M MA R-20 7815' 4 5754' CA4-1/2' MMA R-20 8631' 5 6289' CA 4-1/2" M MA R-20 9167' 6 6641' CA4-1/2" MMA R-20 9635' 7 6947' CA 4-1/2" M MA R-20 10101' 8 7253' CA 3-1/2' KBUG BK 10603' 9 7536' CA 3-1/2' KBUG BK 10944' 10 7839' CA 3-1/2' KBUG BK 11351' 11 8133' CA 3-1/2' KBUG BK 11792' 12 84,50' CA 3-1/2" KBUG B K I~"~'~' 13 8760' CA 3-1/2' KBM BK 12668' 14 9055' CA 3-1/2' KBM BK Casing lirmr Tubing Tubing Perforation Data Zone ~ 0 12808'/9161' 1 12880'/9208' 2 12910'/9227' 3 13059'/9324' 4 13157'/9388' 5 13338'/9516' 6 13456'/9679' 7 13555'/9667' - DIL depths ~.[Ul]~ll~.~ FT SPF 12808-12848' 4D 4 12882-12892' 10 4 12914-12988' 74 4/8 12994-13019'25 4/8 13060-13087'27 4/8 13096-13157'61 4/8 13157-13290" 133 8/12 13341-13415'74 4/16 13460-134~" 2D Below 13504-13545" 41 Retainer 13594-1360# sqzd 13615-13645' sqzd Latch PortSz TRO Psc RK 1/4 1195 1200 RK 5/16 1235 1180 R K 3/8 1~%J~_ 1170 RK 7/16 1~_~_ 1160 R K 7/16 1~_~_ 1150 R K 1/2 1490 1140 RK 1/2 1485 i135 BK-2 5/16 1470 i130 BK-2 5/16 1465 1120 BK-2 5/16 1460 1110 BK-2 5/16 1455 1100 BK-2 5/16 14,50 1090 BK-2 5/16 1445 1080 BK-2 5/16 orifice Gauge Ring and 12-29-86 2.3' 1332(7 6-11-86 2.5' 12654' 6-11-86 1.5' 13322' 6-28-87 1.9' 12627 PBTD = 13710' MD TD = 13771' MD Datum = 13099' MD (9350' SS, 9450' 1VD) 12-20-87 2.1" 12638' 12-20-87 1.9" 1332(7 1-22-90 1.9" 13322' RII Level Data fill; fight at 12659' no deeper tagged fill no deeper, damaged gauge ring would no deeper tagged fill tagged fill ARCO Alaska, Inc. PROPOSED SCHEMATIC Well K- 19 AP~: 733-20259-00 Spud Date: 2-22-74 Original RKB:1017 MD Hanger Type: OCT 12"X4-1/2" Top of Hemlock: 12808' Max Hole Angle: 51 deg O 2304' MD Annulus Fluid:Sea water Last Revised: 2-28-91 All Depths are RKB MD to Top of Equipment. Tr~ ~g Bay Unit - King Salmon Pla~,. ,n Well Type: Producer New E~ Workover [~] RKB to~-Ianger: 35" Angle at Perforations: 46° Reason: Jewelry 1 303' SSSV TRDP-4A - 3.813' 2 12670' Permanent Packer 3 12745' Tubing tall 4 13420' Isolation Packer 5 13440' Tubing tall Casing and Tubing Size Welaht Grade Thread 8 13-3/8" 61 ~P K-55 9 9-5/8' 47# J-95 10 40# VSS-95 11 7* 29# 12 4-1/2" 12.6# N-80 BTC 13 3-1/2" 9.2# N-80 BTC To~ Bottom 35" 2591' Casing 35' 10047' Casing Casing 9679" 13756' liner 35" 9675" Tubing 9675" 12782" Tubing 14 Gas Uft Information Depth Stn. TVD Mandrel Tv~e Valve Latch PortSz TRO Psc 4 MANDRELS - 4 1/2" 5 MANDRELS - 3 1/2" 2-3 Perforation Data - DIL depths Zone ToD-MD/SS ~ FT SPF 0 12808'/9161' 12808-12840' 32 8 12840-12848 sqzd 1 12880'/9208' 12882-12892' 10 8/12 2 12910'/9227' 12914-12988' 74 8/12 12994-13020' 26 8/12 3 13059"/9324' 13060-13090" 30 4/8/12 13096-13157" 61 8/12 4 13157"/9388" 13157-13314" 157 4/12/16 5 13338'/9516' 13340-13415' 75 8/20 6 13456'/9679" 13460-13470' sqzd 13470-13545" 75 4/8/12 7 13555"/9667" 13594-13604' sqzd 13615-13645" sqzd PBTD = 13710' MD TD = 13771" MD Datum = 13099" MD (9350' SS, 9450' TVD) Gauge Ring and Fill Level Data Date Size Depth Comments · 13-,5/8" 3000, PSI BOP STACK ANNULAR PREVENTER 6 PIPE RAMS $ BLIND RAMS, 4 1, FMC TYPE III UN~F. AD 2.13-5/8" $000 PSI NUB X 3000 PSI FLANGE ADAPTER 3, 13-5/8" - 3000 PSI DRILLING SPOOL 4.13.5/8' - 3000 PSI BUND RAMS 5.13-$/8'- 3000 PSi PIPE RAMS 6.13-5/8' ~ 3000 PSI ANNULAR ACCUMULATOR CAPACITY TEST sop, STACK T~ST ". 1. FILL ~ STAGK AND MAN~ WITH ARCTIC DIESEl, 2. CHECKTI-IAT AU. ~ ~ ARE IRJU.Y RET1RACTEI~ PREDETERMINE DEPTH THAT TEST PLU~ WlI. L SEAT AND SEAT 10. IN WEU. HEAD. RUN IN LOCK-DOWN ~::~REW~ IN HEAD. 3. CLOSE ANNULAR PREVEN3-gR AND CHOKES ~ BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOlD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZF. RO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE IRAIV~. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNST~EA~ PRESSURETO Z:~RO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSi DOWNSTREAI~ BLEED SYSTEM TO ZERO PSI. 9. OPEN PII:~ RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOL~ CLOSE BUND RANIS AND TEST TO 3000 PSt FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AN LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN TH,=. DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY 13. RECORD TEST INFORMAT1ON ON BLOWOUT PREVENTER TEST FORM. AND SEND TO DRILLING SUPERVISOI~ 14. PERFORM COIVPt.ET=_ BOP=. T;ST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. JG NOVEMBER 9, 1 (FOR TBU WELLS) ~WACO D ('-~'$000 DIAPHRAQM CHOKE LINE E ADJ. CHOKE tK (N ~0 HYDRIL PIPE RAMS BLIND RAMS TEST SEQUENCE ON VALVES ! #1 A-K-P-Q-E-M-T #2 B-G-F-D-S-R #3 H-SWACO CHOKE-C- ADJUST CHOKE-O #4 J-I #5 L #6 N P R CHECK VALVE CHOKE MANIFOLD & KILL LINE W/B.O.P. ON KING PLATFORM 10-3-77 t TO POOR BOY DEGASSER 3','-50,00PSI. MANIFOLD ALL VALVES 3" LO--TORC EXCEPT SWACO SUPER CHOKE _' ii ,' ,. 5000 PSI DIAPHRAGM SHAFFER SHAFFER ADJUSTABLE. ADJUSTABLE CHOKE BODY CHOKE 3 4 1 2"VALVE 4" VALVE CHOKE LINE 2" LINE 2" CEMENT LINE Z KILL LINE Unocal North Arnen~' Oil & Gas Division ~ Unoc.m C~n3or~tton P.O. Box ~ 90247 Anchorage. Alaska 99519-0247 Teief3nane ~90~ 276-76(30 Alasxa 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. Yours very truly, G . Regional Drilling Manager GSB/lew KING SALMON PLATFORM FROM SE CORNER SEC. 17, TgN, R13W CONDUCTOR LEG ~l' "Y" COOR. "X" COOR. WELL #' FNL 2,511,762 213,819 K-21 & RD 688 2,511,761 213,815 K-30 687 2,511,764 213,811 K-18 690 2,511,768 213,810 K-17 694 2,511,772 213,812 K-23 (23-19) 698 2,511,773 213,817 K-19 699 2,511,770 213,821 K-22 & RD 696 2,511,766 213,822 K-20 692 LEG //.2' 2,511,690 213,768 9 l0 ll 12 13 14 15 16 2,511,686 213,772 K-15 & RD 611 2,511,684 213,768 K-9 610 2,511,687 213,763 K-4 & RD 613 2,511,691 213,762 K-11 617 2,511,695 213,765 K-13 & RD 621 2,511,696 213,769 K-2 & RD 622 2,511,694 213,776 K-7 & RD 619 2,511 , 689 21 3,774 K-5 615 LEG #3' 17 2,511,723 213,712 18 2,511,721 213,708 19 2,511,724 213,703 20 2,511,728 213,702 21 2,511,732 213,705 22 2,511,733 213,709 23 2,511,731 213,713 24 2,511,726 213,714 Leg #4' 2,511,799 213,760 K-8 725 2,511,798 213,756 K-1 & RD 724 2,511,'801 213,752 K-10 &'RD 727 2,511,805 213,751 K-16 731 2,511,809. 213,753 K-12 & RD 735 2,511,810 213,758 2,511,807 213,762 K-6 & 24 736 2,511,803 213,763 K-3 &'RD 729 25 26 27 28 29 30 31 32 FWL 74 78 82 83 81 76 72 71 121 126 130 131 128 124 120 l!9 133 135 141 142 140 135 130 TELECOPY NO: (907) 276-7542 April 27, 1989 Mr. Gerry Graham District Operations Manager Unocal P. O.'Box 190247 Anchorage, AK 99519-0247 Re: No Flow Tests King Salmon Platform Wells K-I, K-2, K-9, K-19 McArthur River Field Dear Mr. Graham~ On March 15 and 16, .1989, Harold Hawkins a representative of the Commission witnessed portions of the no-flow tests on each of the subject wells. A review of the test data indicates that these wells are no longer capable of unassisted flow of hydrocarbons to the surface. The Commission hereby authorizes removal of the subsurface, safety valve from these wells, on condition that should any subsequent operations be performed that may alter the unassisted flow condition of a well, another no-flow test would be conducted to verify continued no-flow status for that well. Sincerely, bonnie u. ~mith Commissioner BY ORDER OF THE CO}~{ISSION dlf~ 10. }fTM. 1 Mr. R. H. Larson. Production Supervisor ~AAI Cook Inlet Operations P. O, Box 1400 Kenai, AI~ 99611 REPOR STATE OF ALASKA OIL AND GAS CONSERVATION Ci[ SION OF SUNDRY WELLOPERATIONS 1. Operations performed: Operation shutdown Alter Casing [] Other Stimulate [] Plugging Perforate ~ Pulltubing ~ March 26, 1987 5. Datum elevation(DF or KB) 100' KB 2. Name of Operator UNOCAL (ARCO Alaska, Inc, is sub-o~erator) 3. Address P.O. Box 190247, Anchorage, AK 99519 4. Location ofwellatsurfaceLeg 1, Cond. 6, King Salmon Platform. 699'N & 76'W from SE corner, Sec. 1-9N-13W-~! 6. UnitorProperty name Trading Bay Unit 7. Well number K-19 At top of productive interval 2825'N & 2937'W from SE corner, Sec. ll-9N-13W-SM At effective depth 2668'N & 2937'W from SE corner, Sec. ll-9N-13W-SM At total depth 2648'N & 2974'W from SE corner, Sec. ll-9N-13W-SM 8. Approvalnumber 7-178 9. APInumber 50-- 133-20259 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 13418' feet 9571' feet Effective depth: measured 13360' feet true vertical 9531' feet Casing Length Size Structural Plugs (measured) RE'CEIVED JUL 3 0 1987 Junk (measured) Alaska Oil & Gas Certs. Commissio~ Anchorage Cemented Measured depth True Vertical depth Conductor Surface 2591' 13-3/8" 2591 ' 23~2 ' Intermediate Production 12782 ' 9-5 / 8" 12782 ' 9143 ' Liner 4077' 7" 13756' 9792' Perforation depth: The following intervals were reperforated on March 26, 1987: Bench 0 12808-12848'MD 9160-9186'%VD; Bench 1 12882-12892'MD 9209-9215' TVD; Bench 2 12914-12984'MD 9230-9275'TVD; Bench 2 12994-13014'MD 9282-9295' TVD; Bench 3 13060-13080'MD 9326-9339'%VD; Bench 3 13096-13116'MD 9350-9364' TVD; Bench 4 13152-13192'MD 9388-9416'TVD; Bench 4 13244-13264'MD 9452-9465' TVD; Tubing (size, grade and measured depth) 4¥', 12.6#, N-80 BTC @ 9675' MD, 3~", 9.2¢J, N-80 BTC @ 12782' MD. Packers and SSSV (type and measured depth) Baker F-1 pkr. @ 12707' MD, Brown isolation pkr. @ 13420' MD. 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation 14. Attachments Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 895 280 733 1100 718 228 1078 1160 Daily Report of Well Operations Tubing Pressure 120 168 Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10.404/R¢~.- 12.1-85' -Roy D. Roberts Title Environmental Engineer - Date T/28/87 - Submit in Duplicate Feet * Note' Lubricator was pressure tested to 2500 psi prior to well operations. JUL 3 o 1987 Alaska Oil & Gas Cons. commissio'~ Anchorage ALA .~;,¢ STATE OF ALASKA · , ,)IL AND GAS CONSERVATION CO .... ,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _- Suspend 2 Operation Shutdown ~ Re-enter suspended well ..-_ Alter casing - Time extension '-' Change approved program Z Plugging~- Stimulate_ Pull tubing '-' Amend order" Perforate X'__ Other 2. NameofOperator UNOCAL (ARCO Alaska, Inc. is sub-operator) 3. Address P.O. Box 190247, Anchorage, AK 99519 4. Locationofwellatsurface Leg 1, Platform. 699'N & 76'W from SE corner, 1 ~~f productive interval 2,825'N & 2,408W from SE corner, Sec. Ateffectivedepth 2,668'N & 2,937'W from SE corner, Sec. Attotaldepth 2,648'N & 2,974'W from SE corner, Sec. Cond. 6, King Salmon Sec. 1-9N- ll-9N-13W-SM ll-9N-13W-S] ll-9N-13W-S]~ 5. Datum elevation (DF or KB) 100' :KB feet 6. Unit or Property name Trading Bay Unit 7. Well number K-19 8. Permit number 9. APl number 50-- 133-20259 10. Pool Hemlock . Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13,418 ' feet Plugs (measured) 9,571 ' feet 13,360 ' feet Junk (measured) 9,5 31 ' feet Casing Structural Conductor Surface Intermediate Production Liner * Perforation depth: The Length Size Cemented Measured depth True Vertical depth 2,591' 13-3/8" 2,591' 2,302' 12,782' 4,077' following Bench 0 12808-12848'MD 9160- Bench 2 12914-12984'MD 9230- Bench 3 13060-13080'MD 932'6- Bench 4 13152-13192'MD 9388- ~bing(size, gradeand measureddepth) 4½", 12.6#, N-80 BTC @ 9675'MD, 3½", 9.2#, N-80 BTC @ 12782'MD PackersandSSSV(typeand measureddepth) Baker ~ .... 1 pkr. @ 12707' MD, Brown isolation pkr. @ 13420' MD. 12.Attachments Descriptionsummaryofproposal ~ Detailedoperationsprogram [] BOPsketch I~ 9-5/8" 12,782' 9,143' 7" 13,756' 9,792' intervals will be reperforated in March, 1987: 9186'TVD; Bench 1 12882-12892'MD 9209-9215' TV£ 9275'TVD; Bench 2 12994-13014'MD 9282-9295'TVD'; 9339'TVD; Bench 3 13096-13116'MD 9350-9364'TVD; 9416'TVD; Bench 4 13244-13264'MD 9452-9465'TVD. 13. Estimated date for commencing operation March 20, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I here ...c.e. rti,f.,y thc, t...t~e...~z.e..going is true and correct to the best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ,¢ .../ -~ .~ [] Plug integrity [] BOP Test [] Location clearanceI Approved by Form 10-403 Rev 12-1-85 Commissioner ~'b~ order of ~// / ~--¢ I the commission Date ~-'"'/ ""¢ ! I Submit in triplicate * Note' Lubricator will be pressure tested to 2500 psi prior to well operations. MEMORANnUM State of Alaska CONSERVATION CO~lI'~ ION ALAS~OI_.?~ .~D GAS TO: ~Ci ,.. erton DATE: March 17, 1986 FI LE NO.' m, EWS, 2 THRU' Lonnie C.' Smith /;~'-:".," TELEPHONE NO.: Commissioner '" ..... ~ FROM: Edgar W, Sipple~ Petroleum Inspector SUBJECT: No Flow Test ARCO TBU #K-19 McArthur River Oil Pool Thursday, March 13, 1986: The No Flow Test on ARCO's K-19 commenced at 2:30 p.m. and was concluded at 7:30 a.m. Friday, March 14, 1986. The water cut on this well is 44%. The gas lift was shut off on this well at 2:30 p.m. Tuesday, March 13, 1986. This well was diverted into the Production Separator until it stopped flowing. The total amount of liquids from this well during the test was 125 bbls. After the well stopped flowing it was opened up to the atmosphere into a 55 gal. drum. There was a small amount of gas with no liquid flowing from the well. This condition was continued for 10 hours with no liquids, only gas. The operator installed a manifold and closed the well in for 1 hour and 30 minutes. There was 5 psi buildup, with no liquid, only gas, when the well was reopened to the atmosphere. Attached to this report is the flow chart from the Production Separator. In summary, I witnessed the No Flow test on ARCO's King Salmon #K-19 well, and verified that it is' incapable of unassisted flow. 301 A ( Rev 10-84) , · CHART NO, 0 METER ~ · CHART PU~_ON_.~ " TAKEN OFF LO CAT I 0 N AMERICAN METER DIVISION .\' \ © © Wd c? .// :51 Al l- DJ- ALAUtlA ALASKA OIL AND GAS CONSERVATION COMMISSION ~.:,,~., .~',~ ~," ............................... _ .............................. DRILLING WELL [] COMPLETED WELL E.l OTHER D 2. Name of Operator Union Oil Compa_~y of California_ 3. Address 909 West 9th Avenue~ Anchorag.e, Alaska 4. Location of Well Surface: 699' N, 76' W'of SE, §ec 1, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 12'. 99501 J6. Lease Designation and Serial No, 7. Permit No. 8. APl Number 50.-133-20259 9. Unit or Lease Name ADL-18777 10. Well Number K-19 1I. Field and Pool McArthur River Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF IN1-ENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) '(Submit in Duplicate) Perforate [] Alter Casing [] Perforations F:~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] .Repai'r Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling .Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted F.orm 10-407 for each completion.) 1;3. Describe Proposed or Completed Operations (Clearly state all pertinent details anti give pertinent dates, including estimated date of starting any p'roposed work, for Abandonment see '20 AAC 25.105-170). On December 9,.1979, Schlumberger perforated the following interVals at 4 SPF with 2-1/8 in. perforatimg guns. Bench 2 12921-12935 ft. CBL 12944-12983 ARCO Oil & Gas Company is suboperator. ' s~.e T~t~e Di str~i:at Drl g__Sugeri nte.~dent j_~.._~..el.ow f__or Commission use I Co~,,l~t~ons of Approval, if any: Date ~_e...r__S_.,t..' 1983 By Order of Approvecl by .............................................................. COMMISSIONER the Commission Da~e ............................ Form 10-403 Rev. 7-1-80 Submit "lnte,tions" in Triplicate and "Subsequeni Reports" i~ Duplicate ALASKA Oil.. AND GAS CONSERVATION COMMISSION d" .... 1. DRILLING WELL L-] COMPLETED WELl. LO OTFIE R [] 2, Name of Operator _ . Unipn_O_it_gompany of Alaska, .... 3. Address 909 West 9th Avenue, Anchorage, A1as__~L~99501 -4' Location of Well Surface: 699' N, 76' W of SE, Sec 1, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 12'. J 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50-133-20259 9. Unit or Lease Name AD]. 18777 10. Well Number K-19 11. Field and Pool McArthur River Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ' NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) '(Submit in Duplicate) Perforate [] Alter Casing r-I Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] .Repai'r Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates° including estimated date of starting any Proposed work, for Abandonment see 20 AAC 25.105-170). Schlumberger perforated the following intervals at 4 SPF using 2-1/8 in. guns on September 4 through 9, 1979. Bench 3 4 CBL 13111-13131 13135-13155 13162-13226 13246-13288 . 13341-13362 13368-13389 ARCO_Oil & Gas Company is sub-operator., 14.1J J ~ ,~/~her~rtify th~at tl]~tfo~r~g is tr!.,e and correct t,o the best o, my kno','~!edge. T ~.o,_~, ~._f_o r___C_, o m r n i s s i o n use Da,eNov'e'mber 8, 1983 By Order of Approved by ............. COMMISSIONER the Commission Date ............................... ~d Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent F~eporls" in Duplicate b I Al [- UP ALAbt\A ALASKA OIL, AND GAS OONSERVATION OOMMISSi'ON , DRILLING WELL [] COMPLETED WELl_ L-] 2. Name of Operator Union Oil ComPany of Califo'rnia 3. Address 909 West Ninth Avenue, Anchorage, Alaska 4. Location of Well Surface': 99501 699' N, 76' W of SE, Sec 1,'T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) 100' RKB 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 5o- 133-20259 9. Unit or-Lease Name .ADL .18777 10. Well Number K-19 11. Field and Pool McArthur River . Hemlock OTFIE R [] 12'. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SL.IBSFQUENT REPORT OF: (Submit in Triplicate) '(Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] .Repair Well r.~ Change Plans [] [Repairs Made [] Other [] Pull Tubing D Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describ~ Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any ~oposed work, for Abandonment see 20 AAC 25.105-170), , Schlumberger perforated the following.intervals With 2-1/8 in. guns on July 13 and 14, 1979. Bench SPF CBL-ft 4 4 8 4 5 4 4 13162-13204 13204-13246. 13246-13288 13341-13362 13382-13403 ARCO Oil & Gas CompanY is sub-oPerator. 14. t h ng is true and correct to the best of my kno,,'~ledge.. Signed '~,~''~_~.__/~_~~ Title District,Drlg' Superintendent 7 / ' 2 --r--'-.--.'~,~-~ ..... Co d~,j,~Sns of Approval, if any: ' November 8,1983 Date By Order of Approved by COMM ISSION[:R tile Commit;sic.',n Date ............................. Form 10.403 Rev. 7-1-80 Submit "Intentions" in Triplicate and °'Subsequent Reports" in Duplicate ALASKA O~l., AND GAS CONSERVATION COMMISSION ................................... DRILLING WELL [] COMPLETED WEL.t. Ej( 2. Name of Operator Union 0il Company of Californ±a 3. Address 909 West Ninth Avenue~ Anchorage, Alaska 4. Location of Well 99501 Surface: · 699' N, 76' W from SE, Sec 1, T9N, R13W, SM OTFIE R [] Elevation in feet (indicate KB, DF, etc.) 100' RKB 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50---133-20259 9. Unit or Lease Name ADL 18777 10. Well Number K-19 11. Field and Pool McArthur River Hemlock 12'. Check Appropriate Box To Indicate Nature of Notice, Report, or Oliver Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well g Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~07 lot each completion.) SUBSEQUENT REPORT OF: {Submit in D~plicate) Altering Casing [] Abandonment [] Other [3 [] [] [] 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). On June 26, 1979, Dresser Atlas perforated the following intervals at 4 SPF using a 2.6 in. gun.' Bench 5 13341-13362 ft. CBL ' 13370-13412 ft. CBL ARCO_Oil~ & Gas Company is sub-operator. 14. I~ J ' /~'~ ~' ~~ hC/rreS¥ 4rtify tha~t the~e~g is true and correct to the best of my know!e".:e. . S,~.~d~~~~~ T,t,eDistrict Drlq Superintendent Date November 8, 1983 By Order of Approved by CONi,%iISSIC"~ER the Commission Date .................................. Form 10-403 Rev. 7-1-[,'0 Submit "Intentions" in Triplicate , and "Subsequent Reports" in Duplicate ,,, STATE OF ALASKA ii" ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator Union Oil Company 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: 699'FSL, 76'FEL, SEC 17, T9N, R13W SM LEG #1, Conductor #32 King Salmon Platform, Cook Inlet 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number 50- 9. Unit or Lease Name Trad~n~ Bav Unit 10. Well Number K-19 1 1. Field and Pool, McArthur River Field Hemlock Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REP'ORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~, Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans l~ Repairs Made ?] Other [] Pull Tubing E~ Other [] Pulling Tubing ~--~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ,/ The following intervals were reperfo~ated on August 25-28, 1983 in Well K-19: March 25, 1974 May 30, 1974 5" DIL Dep. th 5" CBL Depth Bench Feet 12,808-12,848 12,811-12,851 H-1 40' 12,882-12,892 12,885-12,895 H-2 10' '"--12,914-12,934 12,916-12,936 H-2 20' 12,948-12,988 12,950-12,990 H-2 40' 12,994-13,014 12,996~13,016 H-2 20' 13,060-13,080 13,061-13,081 H-3 20 13,096-13,116 13,097-13,117 H-3 20 13,132-13,152 13,133-13,153 H-3-4 20 13,163-13,183 13,164-13,184 H-4 20 13,204-13,244 13,204-13,244 H-4 40 13,250-13,290 13,250-13,290 H-4 40 //,¢7'"/~ £ //,;r//- 290 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Form 10-403 Date ~ Submit "Intentions" in Triplicate ':~',"{~'i Form 10-403 ..... ' ' ' Submit "1 ntentlons" in Tripllca',e ... · ," & "Subsequent Report~" in Duplicate ~'. STATE OF~ ASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not usa this form for proposaSs to drill or to deepen Use ,,APPLICATION FOR PERMIT--" for such proposals.) of California* NAME OF OPERATOR Union 0±l Co. 99502 3. ADDRESS OF OPERATOR .. P. O. Box 6247,:Anch.ora.ge,'AK 4. LOCATION OF WELL · ' Atsu~e 699' N and 76" W of- -SE 'Corner of' ... Sec 17, TWN 9·N, .Range' i3W,.' SM · - . !i:t ,. :'. . .' q NUMF_R ICAL CODE '~d-133-20259 :6. LEASE D~--SIGNATION AND SERIAL NO. ADL-18777 7. IF INDIAN, ALLO i IEE OR TRIBE. NAME NONE 8. UNIT, FAR.~,$ OR LEJ~C,E NAME .m. r = a -~ '"~ Unit. 9. WELL NO. T..B.U. K-19 FIELD AND POOL, OR WILDCAT McArthur River -(Hemlock-) .'. ].3, ELEVATIONS (Show whether DF, RT, GR, etc.) . · · . .... '.. - ' v 100'"" .~l'd~"- ' · · ~.. ::.z~,.,, · Check Appropriate Box To lndi~ate Na~'re of Notice,. Report, or Other Data 11. SEC~, T.. R., M,, (BOTTOM HOLE OBJF_CTIVF) Sec. 19, T9N, R13W, SM..· . .- .!2. PERMIT NO. ·. . : · NOTICE OF iNTENT ION'TO: ... . PuL~. OR ALTER CAS'N~ ~ MULTIPLE COMPLETE ' ABANDON'*. ' - . CHANGE PLANS TEST WATER SHUT~)FF F RACTU'R E TR EAT SHOOT OR AClDIZE (Ot~e~) ,. SUBSEQUENT REPORT OF: WAT ER SHUT-O FF' R EPAI R lNG WELt. FRACTURE TREATMENT ALTERING,' CASING SHOOTING OR ACIDIZ1NG ABANDONMENT* {Other) · , , (~OTE: R'epo~ results 0f multiple completion on Well ComDleUon or Recomplation ·Report' and. LOg form.) · ZE~, DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly stat. e all pertln, ent details, and. give pertinent dates, inctuctinB estimated date of startlh9 any proposed wort<. The'following Hemlock 12997' - 13018' . 13065" - 13086' Zones were Perforated DIL DIL @ 4 JSPF. *ARCO Oil & Gas Company, Suboperator 1G,. I hereby ~%~orLgoin9 i$ t.r-ie an~t"con'ec.t sm..Eo ..... C,.. H. Case TITLE District Eng_~. [This space for State office use) APPROVED BY ,, CONDITIONS OF APPRO.VAL, IF ANY: .- TITLE DATE ....... See Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submit "1 ntentions" In Triplicate I' & "Subsequent Reports" In Duplicate STATE OF A~S~ OIL AND GAS CONSERVATION COMMI~EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL ~ 50-133-20259 At su trace 6. LEASE DESIGNATION AND SERIAL NO. ADL-18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL L...J OTHER NONE 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil Co. of California * Trading Bay Unit ~ ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 6247, Anchorage, AK 99502 T.B.U. K-19 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT McArthur River (Hemlock) 699' N and 76' W of SE Corner of Sec 17, TWN 9N, Range 13 W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 19, T9N, R13W, SM 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING, CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLIED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We intend to perforate the following Hemlock Zones: 12997' - 13018' DIL 13065' - 13086' DIL These intervals have not previously been shot. *ARCO Oil & Gas Co. Suboperator 16. I hereby certify that the foregoing is true and correct SIGNED ~ TITLE (This space for State ,~_ ~e) APPROVED BY I' ( /~~ ~ATI IF--' See Instructions On Reverse Side DATE ) ,-ip.-g0,, Form SUBMIT IN DUPL.1, .... TE* STATE OF ALASKA (see other ~n- structlons on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* 5. APl NUMERICAL CODE 50-133-20259 6. LEASE DESIGNATION AND SERIAL NO. / ADL 18777 la. TYPE OF wE,,: GAS WELL n--] DRY F--] Other b. TYPE OF COMPLETION: NEW WORK ~ DEEP- PLUG DIFF. WELL ~1 OVER L~J EN J-"l ["-I RESER. BACK [] Other 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL (report location clearly and in accordance with any State requirements)* At surface 699' N & 76' W from At top prod. interva~ reported below At tot~e~' S & 2832' W from 2654' S & 3202' W from Cr, Sec 17, T9N-R13W, SM NE Cr Sec 19, T9N-R13W, SM NE Cr, Sec 19, T9N-R13W, SM 7. If INDIAN, ALLOTTEE OR TRIBE NAME None 8. UNIT, FARM OR LEASE NAME tradina Bay Unit , I 9. WELL NO." K-19 W0 /.~-'~" 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N-R13W, SM ,. 12. PERMIT NO. 74-8 18. TOTAL DEPTH MD&TVD 119. PLUGBACK MD&TVDI20. IF MULTIPLECOMPL., 13,771 'MD &'9766' T~DDE~T~420'MD 9572'~vDH°WMA~ngle 22. PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BO'rTOM, NAME (MD & TVD)* Hemlock Bench 4' 13,156' MD, 9391' TVD Bench 5' 13,322' MD, 9505' TVD 21. ROTARY TOOLS All 13,322' 13,434' INTERVALS DRILLED BY CABLE TOOLS I None /23. WAS DIRECTIONAL 9505 '" ~VDsuR'vEY MADE 9582' '~VD No 24. TYPE ELECTRIC AND OTHER LOGS RUN 25. CASING RECORD (Report all strings set In well) 9-5/8" 40 & 47# I N-801 10047' 12-1/4"1~ &lOk 95 ~ USS 95 I J 26. LINER RECORD SIZE I TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) 7"I9,769' 13,756' Exi'stinq 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 29. 2.6" @ 4 HPF Bench 4 13,162' 13,288' DIL Bench 5 13,341' 13,362' 13,370' 13,391' 13~391' 13~412' 30. CEMENTING RECORD AMOUNT PULLED Exi stinq 27' ' I .TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) I 3-l/2'' 9,674' I 4-1/2" 3QQ' 12,6~0' ~,C,:2, 3,: :CT, ,",q~CTU~C., CEMENT SQUEEZE, E"T'~. DEPTH INTERVAL (MD) _ 13,412' - 13,4211' PRoDucTION DATE FIRST PRODUCTION iPRODUCTION METHOD (Flowing, gas lift, I~Umplng--slze and tYPe of pump) I WELL STATUS (Producing or 7/2/79 I Gas Lift I shut-In) Producing DATE OF TEST. HOURS TESTED ICHOKE SIZE PROD'N FOR OIL-BBL. GAS-MOF. WATER-BBL. IGAS-OIL RATIO 9/9/79 12 I 3" PER,OUr_ I 572 154 0 J 269 FLOWTUBING CASING PRESSURE ICALCULATED OIL-BBL. GAS-M~(~F'. WATER-BBL. IOILGRAVITY-API (CORR.) I I I 31. DISPOSITION OF GAS (Sola, used for fuel. vented, etc.) i ~., L.. i~L,~ W'~8~ BY · / 32. LIST OF ATTACHMENTS AMOUNT AND KIND OF MATERIAL USED 200 sx Class "G" 33. i hereby certify t~ foregoing ancl/~ttach~ Inforrgatlon Is complete and correct as determined from ~lj,~IL~a~lqlbl,,eilr~ec~[dS'~ :~ ~ i , ~ ~: , ~., ~: ~ , , ~ , ~ ~ ~ ' ; ~r .~ ~ ~ SIGNED //,34 ,~/'~/TITLE DlST. ur/g bup~ ' ' * DATE _ I! / ...... / /I · (See instructions and Spaces for Additional Data on Reverse Side) *Atlantic Richfield Company is sub-operator. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing 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 interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple 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. SUMMARY OF FORMATION TESTS INCLJDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH TRUE VERT. DEPT Top of Hemlock 12,808' 9160' Bench 2 12,870' 9201' Bench 3 13,032' 9307' Bench 4 13,156' 9391 ' Bench 5 13,322' 9505' Bench 6 13,434' 9582' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Document Transmittal Union Oil Company of C~ nia unlen DATE SUBMITTED ITO H. W. Kugler Alaska O & G Cons. Cctv. 3001 Porcupine Drive Anchorage, AK 99504 1979 ~.~ c. Warthen Union Oil CQmpany A~p.o. BOX 6247 Anchorage, AK TELEPHONE NO. TRANSMITTING THE FOLLOWING: TBU K-19 (32-19) Set Bluelines · 1 GEOL 12 STAT T~ I CONFER: Date: FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. lmor'm ~o. P--4 I~L'V. ~- I-?0 STATE '~ ALASKA SUBMIT lINT D'U'PLICA'I~ OIL AND GAS CONSERVATION COMMll-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~A.ME OF OP~LATOR Union Oil Company of California* ADSAESS OF O~m~,TO~ 909 W. 9th Ave. Anchorage, Alaska 99501 LOCATION OF WELL Surface' 699' N & 76' W from SE cr Sec 17, T9N, R1 3W, SM 50-1 33-20259 ~ LF~kSE DESiGNA~'qON AND SERIAL NO. ADL 18777 IF INDIA]q[ ALOT [~:;E OR TRIBE 8. L.~IT FARA'[ OR LEASE Trading Bay Unit 9 WELL -%'O K-19 (32-19) WO I0 FfFJ~D A_ND POOL. OR WILDCAT McArthur Ri ver I1 SEC . T.. iR.., M. (BO'iTOM HOLE Sec 19 T9N, R13W, SM 12, PERblIT i~O 13. REPORT TOTAL DEPTH AT END OF MO]NT~.'I, C~-IA~NGES IN HOLE SIZE, CA,..q. ING AND CEIVIENT!NG JOBS INCLUDING DEPTH SET AATI) VOLUlVlES USED, PER~ORATIONS. ~-F-STS A/NrD RESULTS FISHIkTG JOBS JU/~[K LN HOLE AND SIDE-T~CKED HOLE A2%TD A/~Y OT~IER SIGNIFICANT CI-IA~G~S IN t{OL~ CONDITIONS Mixed 753 BBLS of Dril-S WO fluid e/fresh water and filled annulus w/640 BBLS .... Mixed 520 BBLS Dril-S WO fluid w/fresh water. 4-1/2" X 9-5/8" annulus bled to 2550 psi. Attempted to bullhead 20 BBLS Dril-S pill below Pkr @ 13,000'. RU B.J. test line w/5500 psi. Pumped total 38 BBLS. Close in & bled annulus off to prod. TBG & annulus. Accepted Rig @ 1600 Hrs 6-21-79. Per- forate TBG~?two 3/8" holes @ 12,990'. ND tree & NU BOPE & tested. Pulled pkr loose. Spotted w/36BBL Dril-S pill & POH. Set Baker F-1 pdr @ 12,700' on WL. RIH w/TBG & seal assembly. PU & circ well clean..w/FIW. POH. RIH w/TBG checking each connection for torque & drifting every 3000' w/WL drift. Tubing tail @'12,782'. ND BOPE, NU Tree & tested. RU DA lubricator. Perf'd 13,391' - 13,412';.13,370' - 13,391'; 13,341' '13,362'. Turned well to test seperator. Ran GLV survey. Ran DA Nuclear Flow Log. Miss run on same - POH to check tools. *ARCO Oil and Gas Company is sub-operator. JUL i 4 979 14. I hereby that the~or~oing is true and correct smt~m:~~'. ,~~r~/'~.~.~__./m~~:.n.~ Dist Drlg Superintendent.= July 13, ~9~9 ~TE--RePort on this form is required for eac~ calendar ~nt~ regardless of the ~tatus of operations, a.d must ~ filed In duplicate with the otl and gas conservation commiffee by the 15~ of the suet.ding month,uflle~ otherwise directed. ~,orm 10-~,03 P.~V. 1-t0-73 Submit '*Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L I~1 GAS ~ WELLIAI WELL OTHER NAME OF OPERATOR Union Uil Company of California* ADDR~S OF OPERATOR 909 W. 9th Ave., Anchorage, AK 4. LOCATION OF WELL At surface 99501 699'N & 76'W from SE cr Sec 1/, T9N-R13W, SM 13. ELEVATIONS (S.ow whether DF, RT, GR, etc.) lO0' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20259 6. LEASE DESIGNATION ADL ].8777 8. UNIT, FARM OR LEASE 9. WELL NO. [ K-i9 W0 iP' iI 10 FIELD AND POOL OR WIL~CA~ .... · ' -i-'_ '1 McArthur River - He~-,ac, l(~,~';-- / 11. SEC.,T, R., M., (BOTTOM H~BJECTIVE) ' Sec 19, T9N-RI3W, SM 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) clPannHt and reperforate SUBSEQUENT REPORT OF: WATER SHUT-OFF' ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING ,, SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 'Kill well by bullheading down tubing stri'ng with Dril-S pill. ND tree, NU and test BOPE. The BOPE will be tested weekly thereafter. Pull existing 3 1/2" completion. Run bi't and casi.ng scraper and clean hole to PBD. Run permanent packer on WL and set @ +12,700'MD. Run 4 1/2" x 3 1/2" tapered tubing string. ND BOPE and NU tree. Existing Perf's 13,232' single perf · -~13,345' - 13,415' 13,504' - 13,454' Proposed Additional Perf's 12,9i'2' - 12,935' DIL 12,948' - 12,986' DIL 13,U96' - 13,292' DIL *ARCO Oil and Gas 'Company is sub-operator. oa ~o~ ~o. 16. I hereby ~,~rt/ify that the foregoing is true and correct ~,, (Tl~.~l~ace for State office use) TITLE District Drlng Superintenden~ATE June 18, 1979 APPROVED BY~'~ CONDITIONS O~ APP~VAL, IF ANY: TITLE See Instructions On Reverse Side DATE .... Union Oil and Gas I~" Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union October 12, 1977 Mr. O. K. Gilbreth Division ofOil & Gas 3001 Porcupine Dri've Anchorage, AK 99502 '-~n: Western Region RE: TBU K-19 KING SALMON PLATFORM Dear Mr, Gilbreth: Enclosed for your information are two (2) copies of the Well Completion form for the above .captioned project. Sincerely ~fe.ur s, k,.j.~ ~al 1 ender Di'st. Drlg. Supt sm cc: Marathon Oil Co, Skelly Oil Co. Getty Oil Co. Amoco Production Co. Phillips Petroleum Co, uSGS' Division of Lands H. C. Lee Form P--7 I SUBMIT IN DU!LICATE* STATE OF ALASKA (se~oth~rtn- al ructions on reverse side! OIL AND (;AS CONSERVATION COMMITTEE i WELL cOMPLETION OR REfOMPLETION REPORT AND LOG* t.. TYPE OF W~L: OH, ~ ~A8 ~ ~RY ~ Other WELL WELL b. TYP~ OF CO~PLE~O~: WgLL OV~fi ~ DACK R~SVR. Other 9, NAME OF OPERATOR Union 0il Company of California ADDRESS OF OPERATOR 909 W. 9th Avenue~ Anchorage~ AK 99501 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* ,~t s.,qace 699'N & 76'%4 fr SE cr Sec 17, TgN-R13W, SM At top prod. interval reported below 2391'S & 2510'W fr NE cr Sec 19, T9N-R13W, SM At total depth 2654'S & 3202'W fr NE cr Sec 19, TgN-R13W, SM 9-7-77 i 5-27-74 I ! ~377~'~ 9766'TVD[~3,570'~ 967~'X~[ ~z~ I All ' Hemlock 12,816' - 13,597'~ 9,152' - 9,651'TVD Gamma Ray CASING SIZE 24" 13-3/8" 9-5/8, S. API NUlVLF_,RICAL CODE 50-133-20259 6. LF. ASE DESIGNATION A-ND SERIAL NO. ADL 18777 7. IF INDIA-N, A/.J. XD'i-r~E OR TRIBE NA.M~ 8. UNIT,F~R-NI OR LEASE NAME Trading Bay U.nit 9. WELL NO. K-19 (32-19) 10. FLED AND POOL, OR WILDCAT McAt thur River-Hemlock I1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N-R13W, SM 12. PERbIIT NO. 74-8 RT, GR, 5q"C)* Il?. ~. CASINGHEAD · INTERVALS DRILLED BY ,' ! CABLE TOOLS None 23. WAS DIREC;I'iO'NAL m ~, CASING RECORD (Report all strings set in well) WE!GI-IT, LB/FT. ~. GRiA_D.E .i DEp~ SET (~) ~ HO~ SIZE C~nNTI~G RECO~ i57'5~ !B I J8i'_ 30" Circ to surface 61~f '~ K-55 I 2~591' 17-1/2" 1750 sx circ to surface 40 & ~7¢~ IN-~0 I ~n;n47' ' l JLa5 uss , FLOW, TUBING 120 3f. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) Fuel ~12-!/4"~ 800 sx class "G" I SURVEY MADE ,1 Yes 26. ' LINER I:LECOIGD . I 27. TUBING RI~COI%D .-__ ' 1~. 7q6' ...... 4-1/2" 9713' ,[ 1 3000' 28. PESO.RATIONS OP~ TO PRODU~'~ (Interv¢, size and number) 29. ACID, Si~OT, F~CTU~, C~E:NT SQUEEZe, ~C. 1-7/8" 0 12,816' 12 965' 13 075' 13 232' 13,~03~, 13,516~, 13,597~ ~'1/2" S~F f/13,3~5~-13,375~ 13,395-13,~5 13,~60-13,~8'0~, 13,50~-13,~5~ ~0. '"'~ ..... '*' [ .~ Producing 9-25-77 [ Gas Lift .... 94% IdASme pRESSU~ ICALm~ OI~BBL. ~ss. I 760 [~-~ou~ 33. S2. L~'ST 0~" ATTACHMENTS I TEST WITNESSEDBY Workop~e~ Summary I hereby 9~rtif~ that thelfo~goin.9~and attached information is complete and correct as determined from alI:available"records S zON~~/'/~.~? [J/L~,'"~ ~~~LE D ist'. Drlg. S,pt. D ATS ]0/] 2/77 *(See Instructions and Spaces [or Additional Data on Reverse Side) DEPT'iI I1N'T]~RVAL (MD) [ AMOUNT AND KIND O,F ~TEm~L U~ ]3 : 594 ' -13 ~ 645 '.l.p.erf's scueezed w/lO0 ~x class [;'G" amt ' . AMOUNT PULLED General. This form is designed for submitting a complete and correct ~'e; completion repo.~l and leg or~ all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shc;,,~,m) for depth measure- merits given in ether spaces on this lorn-., and in any Items :20, and 22:: If ti~is well is completed for separate production frorn r',~ore than one inlerva! zone (mulliple completion) so state ~n item 20, and in ite'~.~ 22 show the prcJucing interval, or i~te:va!s, top(s), bottom(s) and name (s) (if any) for only the interv-~! reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produceJ, show- ing the additional data pertinent to such interval. Item:J6: "Sacks Cement": Attached supplemental records for this ,,,,,,ell shoul:J 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 iterr, s 20 and 22 above). 114. SUMMAIt¥ O[,' I"OIIMA'I'ION 'rF_~'l'S IN('LUI)IN(; INTERVAL TF~S'FED. PllE.SSURE DATA A.ND ,RECOVERIES OF OIL. GAS. 35. G EOloOG lC M A IR K EP,..~ WATER AND MUD i ,, NAME ..... 1 ' f T ..... i r- i WORKOVER SUMMARY K-19 (wo) Completed RU @ llAM 9-7-77. Loaded csg annulus w/sea water, displaced tbg w/sea water and perforated tbg @ 12,692'. Circ and cond mud, installed back pressure valve and removed xmas tree. NU and tested BOPE, okay. Pulled completion assembly, changed rams and tested BOPE, okay. RU and perf'd 13,645-13,615', 13,604-13,594' and 13,395-13,375' w/4 spf. Ran DST tools and set RTTS @ 13,570'. Opened tool and started test. Well filled DP and died. Reversed out water cushion and Hemlock formation water w/skim of oil on samples. POH w/RTTS, RIH w/bit and scraper and circ out. RU WL unit and set E-Z drill retainer @ 13,570. Ran stinger and set retainer @ 13,580'. Sqz'd perf's 13,594-13,645' w/100 sx class "G" cmt, reversed out. Ran and set bridge plug @ 13,438'. Ran RTTS and tagged BP. PU RTTS to 13,218' and tested w/7500 psi, okay. Tested surface equipment, okay. Fractured well thru perf's @ 13,345-13,415' and POH. Ran bit and tagged sand @ 13,260', washed down to BP. Worked DP to swab perf's. No fill. Drilled BP and hard cmt 13,550-13,570' on retainer. POH. Ran GR log 13,570-12,700'. Ran RTTS tool and set @ 13,438'. Held 710 psi annulus and tested down DP w/5000 psi. Pressure held for 3 min and broke back to 2750 psi DP and 575 psi on annulus. Repeated test w/similar results. POH, ran isolation pkr on WL and found 30' of fill. RIH w/DP and circ out 32' of sand to BP @ 13,570'. POH and ran Brown isolation packer on WL. Set packer @ 13,420' w/tail @ 13,459'. RIH w/stinger on DP and tested isolation packer w/2000 psi, okay. POH and LD DP. Changed rams and tested okay. Pulled bowl protector. PU and ran 3-1/2" X 4-1/2" completion assembly w/tail @ 13,069' and packer @ 13,000'. Changed out seal on tubing hanger, NU and tested tree. Displaced mud w/filtered inlet water "inhibited 686" biocide. Set and tested packer. 'Released well to'Production De?t @ 0600 hfs 9-25-77. 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 2. NAME OF OPERATOR Union Oil Co. of Calif. 3. ADDRESS OF OPERATOR 909 W. 9th Ave. Anchorage AK 99501 4. LOCATION OF WELL 699'N & 76'W fr SE cor Sec 17, T9N R13W, s.M'." ' .... :: ·. :-~ ~ ~.~.i ',S~i '' ~:~ 5. APl NUMERICAL CODE 50-133-2052q 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. K-19 (32-19) 10. FIELD AND POOL, OR WILDCAT McArthur River HPmlock 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 19 T9N R13W S.M. 12. PERMIT NO. 74-8 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. Completed RU @ llAM 9-7-77. Loaded csg annulus w/sea water, displaced tbg w/sea water and perforated tbg @ 12,692'. Circ and cond mud, installed back pressure valve and removed xmas tree. NU and teSted BOPE, okay. Pulled completion assembly, changed rams and tested BOPE, okay. RU and perf'd 13,645-13,615', 13,604-13,594' and 13,395-13,375' w/4 spf. Ran DST tools and set RTTS @ 13,570'. Opened tool and started test. Well filled DP and died. Reversed out water cushion and Hemlock formation water w/skim of oil on samples. POH w/RTTS, RIH w/bit and scraper and circ out. RU WL unit and set E-Z drill retainer @ 13,570. Ran stinger and set retainer @ 13,580'. Sqz'd perf's 13,594-13,645' w/lO0 sx class "G" cmt, reversed out. Ran and set bridge plug @ 13,438'. Ran RTTS and tagged BP. PU RTTS to 13,218' and tested w/7500 psi, okay. Tested surface equipment, okay. Fractured well thru perf's @ 13,345-13,415' and POH. Ran bit and tagged sand @ 13,260', washed down to BP. Worked DP to swab perf's. No fill. Drilled BP and hard cmt 13,550-13,570' on retainer. POH. Ran GR log 13,570-12,700'. Ran RTTS tool and set @ 13,438'. Held 710 psi annulus and tested down DP w/5000 psi. Pressure held for 3 min and broke back to 2750 psi DP and 575 psi on annulus. Repeated test w/similar results. POH, ran isolation pkr on WL and found 30' of fill. RIH w/DP and circ out 32' of sand to BP @ 13,570'. POH and ran Brown isolation packer on WL. Set packer @ 13,420' w/tail @ 13,459'. RIH w/stinger on DP and tested isolation packer w/2000 psi, okay. POH and LD DP. Changed rams and tested okay. Pulled bowl protector. PU and ran 3-1/2" X 4-1/2" completion assembly w/tail @ 13,069' and packer @ 13,000'. Changed out seal on tubing hanger, NU and tested tree. Displaced mud w/filtered inlet water "inhibited 686" biocide. Set and tested packer. Released well to Production Dept @ 0600 hfs 9-25-77. 14. ! hereby certify^that ~he foregoing js true andn~correct NOTE-Report on this ~orm is required ~or each calendar month, regardle~ of the status o~ operations, and mu~ be filed in duplicate ~ith the oil and gas conservation committ~ by the 15th of the succe~ing month,unl~ otherwise directS. Form ~0-403 ~' Submit "1 ntentions" in Triplicate .~.'~' REV. 1-10-73 ~ & "Subsequent Reports" In Duplicate ~[ STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5, APl NUMERICAL CODE 50-133-20259 6. LEASE DESIGNATION AND SERIAL NO. ADL 18777 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OW~LL~I WELLGAS O OTHER 2. NAME OF OPERATOR 8. UNit, FARM OR LEASE NAME Union Oil Company of California* Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. K-19 (32-19) 4. LOCATION OF WELL At surface 699'N & 76'W fr SE er Sec 17, T9N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 100 ' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 19, T9N, R13W, SM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER 5HUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ['~ REPAIRING WELL FRACTURE TREATMENT: ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We propose to cleanout well to 13,710' PBTD. Additional zones at 13,615 - 13,645'~, 13,594 - 13,604' will be perforated and tested. These zones will either be included in re-completion or cement squeezed depending on test results. The interval 13,375 - 13,395' will be perforated. The interval 13,345 - 13,415' will be fractured. The interval 13,574 - 13,594' will be perforated and included in re-completion if the above newly tested interval was not cement squeezed. The well will then'be placed back on production. A 3000 psi double Shaffer gate and GK Hydril BOP will be installed and tested weekly. *Atlantic Richfield Company is sub-operator. 16. I hereby c/ertlf~/that the f0,f~gc{l~true and correct .. 0.'( : T,TLE Dist. Drlg. Supt. DATE 9/7/77 (Thl~ sped~ for State office use) APPROVEDBY ~~J~~, ~[ CONDITIONS O~P~R~/A~.. IF ANY; TITLE See Instructions On Reverse Side Approved Copy Union Oil and Gas Division: Western Region Union Oil Companyl .lifornia P.O. Box 6247, Anchorage, Alaska 9959,Z~ Telephone: (907) 279-76871 ' : '"' ~ ~. ,:.~. . .... ~ '? 'i.'~:~ ' ~-*--~ ": ×' :'- ~,¥l Mr. Tom Marshall ~ ~:~c '~--' Division o~ Oil State of Alaska 3001 Porcupine D~ive Anchorage, Alaska 99504 RE: WELL HISTORIES KING SALMON PLATFORM Dear Mr. Marshall: Enclosed for your files are two (2) copies each of the Well Histories for TBUS K-1 WO, K-18, K-12 WO, K-10 Rd, K-4 Rd. and K-19, King Salmon Platform. Also enclosed are copies of the Directional Surveys for TBUS K-22, both the original and the redrill, and the Gyro Survey. Very truly yours, Jim R. Callender District Drlg. Supt. sk Encl. cc: Marathon Oil Go. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Go. Skelly Oil Go. Standard Oil Co. USGS - Mr. Rodney Smith Document Transmittal Union Oil Company of Calif union DATE SU~,MITTED ACCOUNTING MONTH 7/23/74 TO FROM Harry W o Kugler John Ac Packard A~ State Oil & Gas Division AT 3001 Porcupine Drive Anchorage Anchorage, AK 99504 rELEPHONENO. TRANSMITTING THE FOLLOWING: I I ; Atlantic Richfield Company Trading Bay Unit K-19 (32-19)1: Final Logs (Bluelines & Sepial ) 2" 5" DIL 2" 5" Sonic 2" 5" CN-Fmo Den. sity 2" 5" CN-Fmo Densit. y Raw Data 5,, CBL ¥-,?,:?]tGt'~ ...... ;:" ...... ' Please acknowledge receipt h~ signim and returning one copy of this Do :ument T :ans m:ttal, ...... / Date: FORM 369 (REV 2/70) PRINTED IN U.S.A. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ,~:[~.~';.t/j'%,~js. API NU~IF_.I~ICAL COD[ 50-[33-20259 6. L~E D~IGNAr~oN .~D SER~L NO. O m,oN w EI.I. ~ - TYP~ OF COMPLE~ON: s,~,~ o~ o~o~ Trading Bay Unit Union 0il Company of California ~'t~'~i~.'{'~'}~ ()7 OiL ~?~[J ~./~o. ~,~ o~ o~,o~ ,~?~'.J-~heACi~'. r-~9 (32-19) 909 W. 9th Avenue, ~chorage~ AK 99501 ~0. Lat,,trax ut w~:~.[ (Report Jocation cIea,'IU and tn accordance with any State requirement,)' HcArthur River-Hemlock ~t surface 11. S~C., T., ~., M., (BOTTOM HO~ 699'N & 76'W fr SE cr Sec 17, T9N, R1SW, SM At top prod. interval reported below 2391'S 8 2510'W fr NE cr Sec 19, T9N, R13W, SM .kt total dep~ 2654'S & 3202'W fr NE cr Sec 19, T9N, R13W, SM 13. DATE SPUDDED !16. 2-22-74 5-27-74 6-13-74 Sec 19, T9N, R13W, SM 12. PEP.MIT ~0. 74-8 F_J, EVATIONS (DF, RKB, ~T, GR, BTC)* {17. ELEV. CASINGItEAD 100' RKB , ~ '114. DA. TE T.D. REdX-CYItgD [15. D~T~ COMP S.USP O/1 ABAND. · I HOW~q-A-NY* ROTARY TOOLS CABLE T001.$ 13771'MD 9766'TVD/13710'MD 9727'TVD | Single 381' to 13771' 22, PI~,ODUCING !NT~RVAL(S), OF TI{IS CO,MPL~TIOi~I--TGP, BOTTOM, NAME (MD AND TXr~)''' 2'3. WAS DIRECTION~L ! SUR,VEY 1V[ADE Hemlock 12816'-13597' MD 9152 '-9651' TVD Yes DIL, GR-Sonic, & Formation Density-Neutron logsl Gamma Ray- 24. TYPE ELEC'TillC AND OTHFKtt LOGS RUN Cement Bond Log~. Sper,ry Sun Gyro survey 25. CASI2~I C; SIZE CASING I:tEC:ORD (Report all strings set in w'M1) ' 24" 157.5# [ B I 381'~ 30" Circ to Surface 13-3/8" 61# , K-SS , ,2591' 17-1/2' 1750 ix cite tn 9-5/8." 40~ g 47#/ N-80 ! 10047;. 12.1-/4~,. ~nn ax c~ ,,a,, , p 9s: Utsgs , , 1 ,, 7". _ t ~769' t,3756'[,ooosx i ,_,.~2,, 9744, p-1/2x3-1/2) ,~ ~,. . ~r~ a".I.9744- ~ 2769 ' 28. PE~FO~A'I'IONS OP~N' TO PRODUCED (1nScrval, size and number) 2~. ACID, S'[~OT, lr;I~C't'URE, C2',tENT SQU~2Z~, ETC. 1-7/8"13403,, O 1351612816' ,'' 1359712965' ." , 1307:5 ' , 132321 , ......... D~Px'ii lrc].~VAL (MD) I. A~,I:OUNr A~D 1.2ND OF MA.2'SZaAL US~ 4--1/2" SPF f/1334513375' 1339513415' Saeezed l~n~r 13460-13480' 13504-13545' I II I II 30, PIIOD UCTION ~A'f'H6_9_F[RST 74PftOD UCTION [ PIIODUCT1ONG~s liftMI;l ['IUD (Flowing, ga.; lkf~, pumping--size and type of pump', [II V¢ I:)bLz~tu~-inSTATUSp~Od~ing) (Producing or DaTm UP rgST, ~iOU~S TES.T~ ' ]CI1OXE] S.[ZE IT~T~P~OD'Nk'~i~!oDPO'I{ OI~-BBL. G.A.~M. CF. W'7di'~BB~. ] GAS-OIL rU~TIO 6-16-74 , 24 [ 3" I ~' l 4370 [ 976 [ 18 [ 223 ~V, TUBING CA~I. NG P~ESSU~ ICAI,C~T~ OII~BB~. GAS--MC?. WA.~--BBL. loin G~AVITY-~I vx~s}50 1180 4370 ] 976 I 18 33.4 31. VlS~OSlTiON OF C~S (Sold, used for fuel, .vented, etc.) ]TEST WITNESSED BY Fuel Don Farrls ~2. lAST O~ ~TTACHMENTS 22. Open hole lo~5 [ directSonal m,rv~.v I hereby cer. J,~ that the.f~orego~[ng, and atta.~ed information 1~ comlSlete and correct as determined from all-available records ............... vim l<; c ,my~lq~l~r : , , *(See Instructions and Spaces For Additional Data on Reverse Side) General: This form is designed for submitlin9 a complete and correct ,¢,.el[ completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (whe-e not otherwise sho,,vn) for depth measure- ments given in other spaces on this form and in any attac'~)?.~ents. Items :20, and 22:: If this well is completed for separatc production from: more than one interval zone (multiple completion), so state in item 20, and ir~. item 22 show the p:cducir-~g int6rval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interva! reported in item 30. Submit a separate report (pa0e) on this form, adequately identified, for each additional interval to be separately produced, show- ing the ackJitional data pertinent fo 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). , 2. 3. 4. 5. 7. 34. SUMMAItY O~' FORMATION TE~S'I'S IN('L,UI)IN(; INT~,,F[VAL TF~STED. I)H~URE DATA ~ ~OVERI~ OF OIL. GAS. 35 GD~IC MARK~ WAT~ AND MUD Schlumberger FIT test - Hemlock Bench ~6 ~ 13597', IFf 4422, FFP 4428, ISIP 4511, FSIP 4518. Rec 10, 200 cc wtr, 2600 ppm cl, 0.42 cu ft gas FIT Test - Hemlock Bench ¢6 9 13516' IFP 4416 FFP 4416 ISIP 4475 FSIP 4475, Tyonek 6129 4697 Rec 8500 cc water, 2600 ppm cl, 1500 cc mud, 200 cc sand. FIT Test - Hemlock Bench ~5 O 13403', IFP 3929, FFP 3938, ISIP 4034, FSIP 4043 Hemlock 12809 9211 Rec 5740 cc oil & 3500 cc water, 3500 ppm cl FIT Test - Hemlock Bench ¢4 8 13232' IFP 3552, FFP 3562 ISIP 3691 FSIP 3701, WF 13690 9777 Rec 10200 cc water, 2800 ppm cl FIT Test - Hemlock Bench ¢3 ~ 13075', IFP 127, FFP 105, ISIP 3549, FSIP 3352, BHL 13721 9807 Rec 49 cc oil, 49 cc mud, 2 cc sand, 0.3 cu ft gas FIT Test - Hemlock Bench ~2 ~ 12965' FSIP 3568 ~ ~-- ;:':"..- ~'Recovered 39cc oil, 57 cc wa~r.l_15 cc sa~d. 0.7 c~ Ft , . a.~ ~z'rz~n'z~ s~,ows os om, G~ on FIT Test - Hemlock Bench Sle 12816', ZFP 127, FFP 105, ISIP 35~2, FSZP 3524, Rec 1200 cc water, 2800 ppm cl . AtlanticRichfieidCompany Dail "Wetl History-Initial Report lnstruclions: Pre. Dare and su0mit the "Initial Rel)ort" on the first Wednesday after a well is spudded or workover operations are started. Oai~y worx prior to spudding should be summarized on the form giving inclusive dates only. District . SOt;TH gZ~_S KA Fieid McARTHU~ Ri~ER FIELD Auth. or W.O. no. 199303 Count'/or Parish , , Lease or Unit TBU KING SALMON PLATF0_~4 Title DRILL DEVELOPMENT ~'~ELL ISt~te ALASIfA ' jWelt nO. t. K-19 Operator ATLANTIC RIC~FI~,D C0~,~.~ Spudded or W,O. begun IHour ,,, 5~oo AM IA:R.Co's W.I. IPrior Status if a'W.O. Spud Date and depth as of 8:00 a.m. 2-22-74 410 ' 2-25-74 2386' 2-26'74 2627 ' 2-27-74 2627' 2-28-74 26 27 ' 3-1-74 2627' I Date . 2-22-74 Complete recora for each day reported TBU K-19 ( 32-19 ) - COOK INLET 410' (53') - Drilling.-: MW 8.3#, Vis 72, ~ 18. RU & repair rig. Test Hydril. Made up drlg setup, RIH to 357'. Displace water w/mud, built mud volume. Prep to spud, rotary amp gage Shorted out & burned. Disconnected gage. Spud 5 AM 2-22-74. Cleaned out & drilled 17-1/2" hole to 410 ' . TBU K-!9 (32-19) - COOK INLET 2386' (1976') - POH- MW 8.9#, Vis 47, WL 21. Drilled 17-~/2" hole to 596', ran SS gT'ro survey. POE, ran 12-1/4" bit w/ Turbo #1; oriented tool; drilled w/Turbo to 991', trip. Ran Turbo #2 setup_; drilled to 1296', trip. Ran drilling assembly, drilled 12-1/4" hole to 2338', trip. Ran Turbo #3, orient & drill to 2386', could not get tool to btm to orient, POH, check subs, reran, Could not get down, POH. Survey: 596' 1-1/2° S27E 1579' 24° S53W 904' 7° N53W - 2304' 47-1/2° S55W 1057' 11-3/4° N82W . TBU K-19 ( 32-19 ) - COOK iNLET 2627' (241') - Opening 12-1/4" hole to 17'1/2" ~ 1452'-~fW 9.1#, Vis 48, WL Ran drlg assembly & drilled to 2627', survey, PO}{. Ran 17-1/2" bole'opener, opened 12-1/4" hole to 17'1/2" from 596-1452'. Survey: 2401' '49-3/4° S57W 2496' 47,1/4° S59W 2562' 45-3/4° S59W TBU K-19 ( 32-19 ) - COOK INLET 2627' (0') - RU to run 13-3/8" csg. '" Opened 12-1/4" hole to 17-1/2" to 2627'. Circ 1 hr, pulled up to 24" csg, ran back to btm OK, circ 3-1/4 b_rs, POH. RU to run csg. TBU K-t9 (32-19) ' COOK INLET (13-3/8" ~ 2591') ' . 2627' (0') - ND 20" Hydril & riser - MW 9.0#, Vis 45, WL 24. Ran 64 [ts 13-3/8" 61# K-55 butt csg; set ~ 2591'. Landed Unihead, circ 2-1/2 b_rs, pump 70 bbl water, cemented w/1425 sx Class G ~.~/2.31 prehydrated gel ~ !3.1#/gal & 325 sx Class G ~ 15.6#/gal. Good circ t_hru out; circ cement to surface. CIP 11:59 PM 2-27-74. 1800 psi; released pressUre, floats OK. ND 20" BOP & riser assembly. TBU K'19 (32-19) - COOK INLET (13-3/8" ~ 2591') 2627' (0') - Testing BOPs. ND 20" Hydril & riser, installed Unihead valves & 20" packoff. NU 12"' 3000 psi BOP stack, choke & kill lines. Test BOP, rePair leaks. Test Hydril w/1500 psi OK, test pipe rams w/3000 psi OK. Testing blind, rams The above is correct . ~-~) -._. / ~i~.~re ..___~...~ .~.- / ....; ,- ./ '.,,~-~-?U:~,,<-. ;,'I' .?-?~,,~ ~,: Title T'-' T TTT? = FF DISTR_~T DR~L.~,G SUP~R~±SOR AP3B-459-l-B ' · [Number ali daily weii history forms consecutively ~Page no. las they are prepared for each well. '- - : · .' '- AtlanticRichfieidCompany Daily Well History -Interim instructions; This form is used during drilling or workover operations. If testing, coring, or perforating; show· formation name in describing work performed. Number ail drill stem tests sequentially. Attach descriotio¢~ of all cores. Work performed by Producing Section will be reoorted on "interim" sheets until final completion. Repo~ official or representative test on "Final" form. 1) Submit "interim" sheets when filled out bu! not less' frequently than every 30 days, or (2) on Wednesday of t,~e week. in which oil string is set. Submit weekly for workovecs and following setting of oil string unlii completion. District Field Date and cepll~ as of 8:00 a.m. t !County or Parish S0b~H ALASKA ~_ease or Unit Mc.~RTHUR RIVER FIELD TBU [~'r,fG SA~,[0N PLATF~OPaM complete record for each day while drilling or workover in progress 3-4-74 4547' 3-5-74 5490' 3-6-74 6354' 3-7-74 6763' 3-8-74 - 7199' 3-11-74 8052' IState AZ~u.S.~~ tWell no, TBU K-19 (32-19) - COOK IN-~ET (13-3/8" ~ 2591' ) 4547' (1920') - Drilling - MW 9.3#, Vis 36, WL 19.4. Finished test blind rams to 3000 psi OK. Trip in to 2506 , test csg to 1500 psi, bled to 1300 psi, held. Drilled plug & float ~ 2506-2508'; no cement to 2518'. Drilled soft cmt to 2588', hard cmt to 2591'. Cleaned out to 2627', drilled to 2637', trip out, ran gyro. Drilled 12-1/4" directional hole to 4366', trip. Had dr~g p ]ulling stabilizers back into 13-3/8" shoe. RIH & drilled to 4547'. Survey: 2756' 44° S60W .. 2944' 43-1/2° S60W 3824' 46° S60W 329!' 44-1/2° S60W 4300' 48-1/4° S60W : - TBU K.-19 (32-19) ~ COOK i~T (13-3/8" ~ 2591' ) 5490' (943') - Drilling - MW 9.7#, Vis 47, ~q5 10. Drilled 12-1/4" directional hole to 5121', trip; drag as stabilizers pull up into csg. Held kick drill. RIH, drilled to 5490', drilling. Survey: 4714' 49-1/4° S60W 5071' 49° S6!W TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591' ) 6354' (854') - Drilling - ~gg 9.6#, Vis 40, WL 12.5. Drill to 5970', trio_. Change BHA, trip in. Drilled. ahead. Survey: 5920' 49° S62W TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591' ) 6763' (409') - C-iH w/bit #1i - MW 9.5#, Vis 40, WL 12' Drilled ahead. Work on rotary table. Su_wey ~ 6335', stranded sandline. Dr!d to 6763'. POH. Moved & cut drill line. RIH w/bit #11 on BHA #8. Survey: 6335' 49-1/2° S63W 6713' 48-3/4° S65M ~U K-19 (32-19) - COOK I_-~._~T (13-3/8" ~ 2591' ) -- : 7199' (436') - Trip out - MW 9.5#, Vis 45, WL 12. RI w/bit #!1, drilled to 7199'. Pump in dry job, start out of hole, pipe wet Circ &cond mud, POH. ~ TBU K-!9 (32-19) COOK I~mET (13-3/8" ~ 259t' ) 8052' (853') - ~illing - ~&I 9.5~, Vis 40, WL 8.0.~' Drilled to 7533', trip. ~illed to 7846', POH. Test r~s & manifold to 3000 psi, Hy&il to 1800 psi. RIH, drilled to 8052'. S~eT: 7~48' 48-~/2° s6~ 7533' 4~3/4° sTtw The above is correcl ~' Signature ~-~:: .... ..-...>;' --/.~: :?' ~: Fo'F'fo[~ preparation and distribution see Proced~r~.'s Manual Section 10, IOate Title DISTRICT DRILLING SUPERVISOR Drilling, Pages 88 and 87 AR3B-459-2-A INumber al! daily well history forms consecutively as they are prepared for each well, JPage no. AtlanticRichfieldCompany DailY Well History-Interim ;nstruct~ns: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I dr',;I stem tests sequentially. Attac~ description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until finat completion. Reco~ official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) .~n Wednesday oi t,~e week in which oil string is set. Submit weekly for workovers and following setting'of oil string until completion. District Fieid RI-V-ER Fi-ELD Date and cel~tn es o! 8:C0 a.m. 3-12-74 8283' 3-13-74 8558' 3-1.4-74 878!' 3-15-74 90h3' 3-18-74 914'9' 3-19-74 9149' County or Parish Lease or Unit KING S_ rgI~ION PLATFORM Complete record for each day while drilling or workover in progress IWell no. . I'- K-19 TBU K-19 (32-19) - COOK INLW. T (13'3/8" ~ 2591') 8283' (231') - Drilling - MW 9.5#, Vis 38, WL 10. Drilled to 8173~, P0H for bit. Tite spots 7985-6400'. changed stabs, moved drlg line, LD 15 jts Grade E DP, PU 15 jts Grade G. RIH, ream 50' to btm, drill. . Survey: 7533' 48-3/4° S71W - NOTE cORRECTION 8123' 49° S73W TBU K-19 (32-19) - COOK I~ET (13-3/8" ~ 2591') 8558' (275') - GIH w/bit #16. Drilled to 8558' P0H Tire on 16th & 22nd stands. Changed out Stab cut: , · , drlg line. Started in hole. Summrey: 8508' 49° S74W ' TBU K-19 (32-19) - COOK INLE~ (13-3/8" ~ 2~91' ) 8781' (223') - Drilling - ~ 9.5#, Vis 37, WL 9.0. Finished in hole, drilled to 8687', made 25 stand short trip, worked thru tire spots on 1st, llth & 24th stands. Ran to btm, drilled ahead. TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591') 9043' (262') - Drilling- MW 9.6#, Vis 39, WL 7.5. Drilled to 8811', EMD #1 overheated. Drilled ahead on E~ID #2, generator powering rotary failed. 'Made 30 stand short trip while repairing EMD #1, 1st & llth stands tire. Ran back in hole, 'gashed 15' of fill, drilled ahead. TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591') 9149' (!06') - Inspecting BHA as POH - MC/ 9.6#, Vis 43, WL 7.5. Drilled to 9149', drop survey, POH, tire on 14th & 15th stands.' While rotating thru tire spot, DP backed off 5 stands & 1 single below rotary. POH, LD single. RIH & screw into fish ~ 1881'. PU off btm w/full wt of string, circ. PU 40' , lost 60000# wt. POH, left 5 j.~'s HWDP & BHA in hole; total 382' w/top ~ 8766'; all DP recovered in good cond. WIH & screwed into fish, circ, pulled 14 stands. PU kelly, worked out 9 singles; pulled 2 stds. PU kelly, DP pin broke 4 singles below rotarY, POH. RIH w/overshot, caught Screwed into fish circ fish ~ 1914', POE w/fish, le~u B/~A in hole. RIH, , clean, pulled 19 std & single; PU kelly & broke circ; jarred 3-1/2 hrs w/ bit @ 8332'; top stab ~ 8102'; jarred free. POH w/DP; had ! bent jt DP; inspecting BHA as POH. Survey: 9099' 49° S74W TBU K-19 (32-19) - COOK I~TLET (13-3/8" ~ 2591') 9149' (0') - LO P-110 DP. Finished inspecting BHA, kelly saver sub, safety valves & kelly. Found cracks in X-over sub between h~gDP & BHA & in top square collar. Tested choke manifold & pipe rams to 3000, Hydril to 1500 psi. Slipped & cut drlg line. RIH w/B_F~ #7 w/keyseat wiper to 2.3 stands off btm, LD P-110 DP for inspection; will PU ~reviously inspected P-Il0 off rack to run in to btm. JDate ITit,. DisTRIcT DRILLING SU?E~RVISOR Fgr form preT. a,_*~n and C~stribution see Prccecures ,,!anuai Sec:ion 10, Dr!iling, Ps~es ~6 and 87 AR3B~. '9-2-A ~ Number all daily well history forms consecutively las they are prepared ;or each well. ^ , 3 AtlanticRichfieldCompany Daily Well History-Interim In$lructJons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number a;I drill stem :ests sequentially. Attact't description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, fiepo~ off=cial or reorese~ta[~we {est on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday off the v~eek in which oil stung is set. Submit weekly for workovers and following setting et oil string until completion. District Field Date and cleptn as of 8:00 a.m. I C'°untY Or Parish S 0 5"~_-[ _/LL&S K_& . Lease or Unit McARTh~JR PJDf~ FI~.~T. ,D TBU KING SALMON PLATFORM Complete re. cord for each day while drilling or workover in progress 3-20-74 9149' 3-21-74 9389' 3-22-74 9489' '3-25-74 10085 ' 3-26-74 1010 4 ' 3-27-74 10104' For'form prepar.a~i0n ~ distribution see Procedures''~,lan'-,=-; Section 10, Drilling, Pages 56 acc 57 IState IWeil no. TBU :4-19 (32-19) - COOK INLET (13-3/8" ~ 2591') 9149' (0') - 0=btm prep to drill ahead- MW 9.8#, Vis 48, W~ 6.8. Finished LD ~-ll0 D~. ?U Grade E DP & pre~iomsly inspected P-]10 DP. Ream 6702 to 7609', RIE to 8108', circ 1-1/2 hr. RIH to 8863', ream to 8969'; clean out 8969' to btm ~ 9149'; on btm prep to drill ~ 6 AM 3-20-74. . LD btm TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591') 9389' (240') - Trpg - ~g 9.8#, Vis 41, WL 7.8. Dr!d 9149-9389', circ& POH. Tight intermittently 9300' up to 7600' 30 jt Grade E DP. Change out drlg jars, start back in hole. Survey: 9339' 49° S73W TBU K-!9 (32-19) ' COOK INLET (13-3/8" ~ 2591') 9489' (100') - POH w/bit #18 - ~D 9.8#, Vis 40, WL 6.6. RIH :~/bit #18, PU 30 jts P-110 DP. Drilled ahead to 9489'. Lost 400 psi pump pressu_~e, check pumps & flow volume meter OK. Pump in pill & POH. Trip out now ~ 2400'; trip good, tite ~ 8580' & 7003'. . TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 259t' ) 10085' (596') - Drilling - MW 9.8#, Vis 46, WL 7.2. P0H look for washout. Change square stab'& btm monel collar. Moved drlg line. R/W, found washout 22-1/3 stds off btm, RI to btm OK. Drill to 9693', drop survey, POH. Tite 9349', 8628', 7124'. RIH w/bit #20, drilled to 9904', drop sur"¢ey, POH. Tite 9192-7200'. Slip & cut line. RIH, LD 20 jts Gd E; PU 20 jts P-110. Work thru lite spot ~ 8667', ream 60' to btm. Drilled ahead. Su_~ey: 9643' 49° S73W 9854' 49° S76W TBU K-19' (32-19) - COOK INLET (13-3/8" ~ 2591') 10104' (19') - Stringing up 10 lines to run 9-5/8" csg - MW 9.8#, Vis 44, WL 7.4. Drilled to 10104', circ& drop su_~ey. Circ & cond mud for log, measure out of hole. Measured 11' short. RU Schl, ran DIL, worked thru tile spots, logged 10068-2585'. Logging complete ~ 2:30 A_M 3-26L74. Start stringing up 10 lines. SurTey: 10054' 49° S76W csg. TBU K-19 (32-19) - COOK ZNI~ET (13-3/8" ~ 2591') 10104' (0') - ~unnins 9-5/8" csg. St_~ung up 10 lines. Trip in hole, circ clean, POH. RU to run 9-5/8" IDate iTitle DISTRICT DRILLING SUPERVISOR AR3~-459-2-A I Number all daily well history forms consecutively as they are prepared for each well. . no. 4. AtlanticRichfieidCompany Daily Well History- nterim lr~tmctions: This form, is used during drilling or wor~over operations. J f testing, coring, or perforating, show formation name in describing work performed. N,.'..'nber a,I drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets u~tiJ final cc-rnoienon. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) cn Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. County or Parish - . i State F;e;d S0b~H _' T-LLAS!CA. Mc.a_R ~rR RIVER Lease or Unit TBU KING SAi240N PLATFORM Ca:e and ceptn as of 8:C~ a.m. 3-28-74 10104' 3-29-74 10104' 4-1-74 10423' 4-2-74 10655' 4-3-74 10693' 4-4-7h 10733 Complete record for each day while drilling or workOver in progress tWell no. ,, TBU K-19 (32-19) - COOK INLET (13-3/8" @' 2591' ) (9-5/8" @ 10047' ) : 10104' (0') - Pulling test plug- MW 9.'7#, Vis 44, ~ 8.0. ' Ran 246 jts 9-5/8" 40# & 47# N-80, JL95 &-USS95 butt csg; set ~ 10047'. LOst mud returns 15 its off btm. Broke circ w/full returns, circ hole clean. Cmtd w/800 sx Class G cmt w/0.2% HR-7, 1.0% CFR-2 preceded w/80 bbl water. Lost total 25 bbl mud while displacing. Bumped plug CIP 9:30' PM R'~7-74, floats held OK. ND cmtg head & landing jr. Installed csg packoff in Unihead & tested to 5000 psi OK. Set test plug, tested pipe ram & blinds to 3000 psi, Hydril to 1500 psi OK. PU on test plUg without backing out holddown screws; test plug hung up in head. TBU K-19 (32-19) - COOK I~mET (13-3/8" ~ 2591') (9-5/8" ~ 10047') 10104' (0') - GIH to drill out - ~d 9.7#, Vis 44, wL 8.0. Pulled test plug out o£ Unihead. Set out stack & riser~ Replaced & repaire~[ Unihead holddown screws. NU riser & BOP,-test rams to 3000 psi OK,.Strung back to 8 lines. LD 12-1/4" B~EA, PU 3 - 6-1/8" clrs & 8-1/2" bit. TBU K-19 (32-19) - COOK INLET (!3,3/8" ~ 2591' ) (9-5/8" ~ 10047') 10423' (319') - Trip in hole - MW 9.5#, Vis 37, WL 6.0. Top mint ~ 9933'. Tested csg, had pin hole leak on Unihead. Dr!d float clr ~ 9951'. Rewelded Unihead. Tested csg 1500 psi OK. Drld to 10066'. Tested formation ~ csg shoe to 10.6# equiv OK. POH. Make up BHA. Installed DP rubbers. WIH to btm of csg. Broke circ. Stuck DP. Worked free-w/B80000#. Lost pump press. POH. Found cracked pin on P-110 DP 5 stands & a single off btm. Check BHA OK. Repair lock on hook.- %~IH, bit plugged ~ 10272'. POH, unplug bit. Drld to 10423'. Dropped survey tool. Pulled 4 stands. Ran sand_line & lost overshot. P0H & recovered survey tool. Survey: 10377' 47-1/4© S78W . TBU r-19 (32-19) - COOK INLET (13-3/8" 0 2591') (9-5/8" 0 100~T') 10655' (232') - P0H - MW 9.6#, Vis 39, WL 5.6. . - Drill 10423-10655'. '-' TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591') (9-5/8" ~ 10047') 10693' (38') - P0H- ~g 9.7#, Vis 38, WL 5.8 Ran bit #24, ETD #4, 1-1/2° bent sub, orient sub. RU & run SS steering tool. Short in D-A line & cut off 100'. Directionalty drilled 10655-10693'. Pulled steering tool. Start out of hole. - TBU K-19 (32-19) -COOK INLET (13-3/8" ~ 2591') (9-5/8" 0 10047') lO733' (4o') - GIH - MW 9.6#, Vis 39, WL 5.2. POH. Change bent sub to 2-1/2°, LD bumper sub. Slip line. R!H w/bit #25 ETD run #5. Ream 30' to btm. RU steering tool. Drill 10693-10733', RD steering tool & POH. LD ETD & RIH w/bit #26 & drilling assembly. Survey: 10609' 44© S79W 7ne ahoy9 }S correct ./?/" _:nature ~ ~5/ /./~ " '~. .¢[_.... :, '~.:_ .," Fc,; form 2repara:;c~ ~,~ distribution sse Procedures--.'-,t3~ual Secuon 10, CdJling, Pages 86 and 87 IDate IT[tie DISTRICT DRILLING SUPER¥-o0R A.? 3 Number all daily well history forms consecutively ,lPaqe no. as they are prepared for each well. 1 _ . . ~ . . ::: -~:~ ~-.';:~ AtlanticRichfieidCompany Daily Wetl History- interim tnst,-uctions: This fo-"~ is used during ddlling or work.vet ol:)eradons, Jf testing, coring, or perforating, show formation name in describing work performed. Number a;l .rill s;em :ests s.e~3uentiaHy. ;,tract1 c;escri~don of ali cores. Work performed by Producing Section Will be reported on "Dnterim" sheets until final completion. Report D;ficiai or reoresenla[ive tesl on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, Or (2) on Wednesday ot :~.e week in which oid string is set. Submit weekly for work.vets and following setting oD oil string until completion. lCounty or Palish District Fie!d jLease or Unit KING SA/2ZDN PLATFORM Well no. Date and dep:n as of 8:00 a.m. 4-5-74 109 30 ' 11560 ' 4-9-74 11589' 4-10-74 11735' 4-11-74 11807' 4-15-74 12242 ' rcomplete record ,~or each day while drilling or wW'kover in progress TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591' ) (9-5/8" ~ 10047') 10930' (197') - Drilling - MW 9.9#, Vis 40, WA 5.4. Slip line, finished in hole w/bit #26. Swivel Packing failed, PU to 9-5/8" csg, re~air~ packing. Ran to btm, drilled 10733-!0863' '. ~ dropped survey, pulled up into esg, retrieve sU~'vey. Ran to btm, drilled 10863-10930, drlg'. Survey: 10833' 42-1/4° S77W TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9,5/8" ~ 10047') 11560' (630') - RU' steering tool - MW 9- 7#, Vis 41, WL 5- 6. ~ Drilied to 10939', survey, trip, tile spot ~ 10839'. Ran bit #27, drld. t° 11154', survey, POH. },~de' up ETD #6, RIH. RU steering tool. Survey: 10909-' 42° S7~ 11313' 45° S77W - ~ 11114' 43-1/4° S77W 11520' 46-3/4° $78W TBU K-19 (32-19) - C00K INLET (13-3/8" @ 259!') (9-5/8" ~ 10047') 11589' (29') - Testing BOP. Finished RU steering tool. Orient ETD #6. Drilled 11~60-1!589'· Start out w/~gL & steering tool, top sheave broke, RU new sheave, line stranded. P0H w/steering tool. RD WL & P0H w/ETD #6, work thru tile spots OK. Set test plug, test Hydril 1500 psi, rams w/3000 psi, repaired leak ~ Unihead 'clamp. Prep to GIH w/limber hookup. _~BU K-19 (32-19)- COOK INLET (13-3/8" ~ 2591') (9-5/8'' ~ 10047') 11735' (146') - Drilling - 55~ 9.7#, Vis 40, ~fL 5.6. Slip & cut drlg line, changed out ring gasket between Unihegd & BOP, ~TU BOP & test blind rams to 3000 psi OK. LD turbodrill, RIH w/bit #31 to 11460'. Ream to btm ~ 11589', drill ahead. ~U K-!9 (32-19) - COOK I~TLET (13-3/8" ~ 2591') (9-5/8" ~ 10047') - 11807' (72') - Drilling- }~ 9.7#, Vis 42, WL 5.6. Drill to 11742', trip. RI w/bit #32, hit bridge ~ 11293', LD 2 stands. Broke circ, pipe stuck, worked free, could go down but could not move up. RI}{ to 11450' , positioned keyseat wiper ~ 11267', reamed & worked tile spot until free, reamed to TD. Drilling ahead ~ 6 AM. TBU K-19 (32-19) - CO0~ INLET (13-3/8'' ~'2591') (9-5/8" ~ 10047') 12242' (435') - Dr_illing - MW 9.6#, Vis 40, WL 6.0. Drld to 11852' suacvey trip Tile spots ~ 10750' & 10550' Drld to 12052' ---- , , · · , drop survey, pull 22 stds w/lst 6 stds tile. Retrieved sUrvey. POH to change · B~A. Dr_Id to 12107', bit torqued up, bushing jumped out of table, pipe parted. Screwed back in, PU to 300000#, jumped pin, POH. Pin parted 2 stds & dbt down. RIH, screwed in, POH. Had 3 its 5" pll0 DP w/bad pins or'boxes; I jt bent Pi!0; 9 its bent Grade E DP; 2 its bent kS,~DP..Changed out jarS & RIH w/bit #34 ~]d to 12169' survey & trip Drld t° 12242' Su=~vey: 11813' 49-3/4° S76W 12012' 53-1/4° S73W 12119' 55-1/4° S73W The above is coffee: / Si § n atu r_~.,....-~ .... ~.> /' For form pre~arats~ a~d :~s:ri~u:ion see Procedures Ma~u~; Secficn 10, Drilling, Pages ~5 &r,o ~7 Title DISTRICT D~LLING SUP_ER~,~SOR AR3B-459-2-A Number afl daily well histow forms consecutively as they are prepared, for each well.,%:' AtlanticRichfieldCornpan " Well History-interim instructions: This form iS used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Numcer a;; dntl s',em te~ts sequentially. Attach descrhstion of all cores. Work performed by Prodacing Section will be reported on "interim" sheets until final ccrncie[ion. Report oHicial or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every S0 days, or (2) cn W~nescay ol the week in which oil string is se{. Submit weekly for workovers and following setting of oil string until completion. District ,=ieid ~ate and ~.eoth as of .5:CO Rm. County or Parish J Lease or Unit - ~&I~MON PLATFOP~4 M.m~RTh-OR RI~R FIELD ~U ~NG ~ Complete reco~d for each day While ddiHng or workover in progress h-16a74 12458' ~-17-74 !~o39 ' 4-!8-74 12639 ' 4-19-74 12639 ' 4-22-74 -1 " _2039 ' JState T . Well no. ' TBU K-19 (32-19) - COOK INLET (13-3/8" (~ 2591') (9-5/8" @ t0047') 12458' (216') - Drilling - TM 9.9#, Vis 49, W-L 5,4. Drld to 12367', dropped survey, started out of hole, Pulled into rite spot w/bit ~ 10460', worked pipe 2-1/2 hfs, unable to make any upward progress. Rig w/WL & retrieved survey. RIH w/bit to btm & drld ahead~ raise mud w-t & viscosity. : Survey: 12317' 54-1/2° S74W TBU K-19 (32-19)- COOK INLET (13-3/8" ~ 2591:) (9'5/8" ~ 10047') 12639' (181') -GiH w/overshot - MW 9.8#, Vis 550, ~L 6. · Drld to 12639' circ dro~ survey 'Draw~.rorks mOtor failed Cleaned & dressed armature & installed new. brushes P0H to 10460' tire spot.. PU kelly, circ & work Pipe. Drill pipe pin parted ~ 219'. }tade up overshot w/bumper sub on 5" DP. ~3U ~-19 (32-19) - COOK IN~T (13-3/8" ~ 259t') (9-5/8" ~ 100~7') 12639' (0') - Jarring on stuck DP w/bit @ 12639' - MW 9-8#,Vis 53, WL 5-8. RIH w/8-1/8" x 6-1/4" overshot & bumper sub on 5" DP. Drawworks #2 motor failed. Repaired motor, worked on #1 generator. Engaged fish ~ 2360', pulled 350000# to set. overshot. RU Go Int'l string shot, backed off ~ 265.8' w/2nd attempt. POH, LD overshot & 17 its Pll0 DP for inspection. Moved & cut 300' drill line. RIH & screwed into fish ~ 2658' @ 10:45 PM 4-17-74. Circ OK. Jarred on stuck DP 7-1/4 hrs to 6 AM 4-18-74, pipe movement to bumper sub OK. Spot 80 bbl IMC Lubrikleen pill. 1 " ' ' TBU K-19 (32-19)- COOK INLET (3-3/8 ~ 2591 ) (9-5/8" ~ 10047 ) 12639' (0') - RU Schl, prep to run free pt. Work stuck DP. RU Dialog on Go Int'l line. Free pt tools stopped ~ l12GO', threw slack in' line, PU, sheave failed, fouled line. Bad spot in line, POH,' released Go ~ 4 AM 4-19-74. RU Schl w/Dialog tools. TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591' ) (9~5/8'' ~ 10047') 12639' (0') - Circ & cond mud, prep to backoff - MW 9.6#, Vis 50, WL 7-O- RIH w/dialog free pt & backoff. Spudded & worked tools from 11165-11368'. LD free pt. Ran backoff w/collar locator to 12488'. Attempted to backoff, unsuccessful. Reran 'free pt. Spudded & worked tool from ]_1168-11300'. LD free pt. Backed off 5" DP ~ 9910' inside 9-5/8" csg. LD P-1t0-DP Installed new brake blocks & strung, up 10 lines PU S-13~ DP, 5 - 6-1/4" DCs & fishing jars. Screwed into fish. Jarred & worked fish 9 hrs. N° movement of fish. Bumper sub working @ 12437'. Ran dialog free pt to 12480', Could not work deeper. Good stretch, but no .torque ~ 12480'. Good torque ~ 1185~' but none ~ 11916'. Ran string shot & attempted to back off ~ 12488' & 11804' without success. Reran backoff, could not get back to '11804['. Attempted backoff ~ 11742'. Backed off high ~ 10801'. Screwed back into fish. Circ to cond hole. The aso.,e is correct /' L ' ' ' ' --?/'- For · ~,m crag~rat;~' a~d distribution Ss~ ~roce~rJs Manual Section 10, Dn',;;ng. ~aSes 86 and 87 JDate jTitle DISTRICT DRILLING SUPERVISOR A P3 ~'-9-2-A Number all daily well history forms consecutively as they are prepared for each well. JPage no. 7 AtlanticRichfieldCompany Daily Well History-Interim Instructions: This form is used during drilling or work@veT operations. If testing, coring, or perforating, show formation name in describing work performed. Number all dr, il stem '.ests sequen!iaily. Attach description of ail cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report c~ficial or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not less frequently than every 30 days, or (.2) on Wednesday of the week in which oil slring is set. Submit weekly for work@veTs and following setting of oil string until completion. .'District I County or Parish SOUTH A.T~,~.S KA I{~IAZ i Lease or Unit M c~&R~"EfJ-R RIVER . TBU KING SALM~N PLA~0P~M IState.-/3~_x~S T'~/~ IWoII no. ,'Date and depth as of 8:00 a.m. 4-23-74 12639' 4-2~-74 12639' 4-25-74 12639 ' TD 4-26-74 12639 ' TD 4-29-74 10165' 4-30-74 10257' Complete record for each day while drilling or work@veT in progress . 'i~U K-19 (32-19) - COOK Ti~-~'rZ' (13-3/8" ~ 2591' ) (9-5/8" ~ 10047' ) 12639' (0') - Gl( w/reaming assembly - ~ 9..~, Vis ~4, WL 6.4. ' . Circ& cond, ·work pipe, c~e loose. POH, rec 10 std & dbt of ~P. Total t005' top of fish ~ 10902'. PU fishi~ assembly, of 1 jt DP, b~per su~, jars, 5 DC, accel jars, ~H. Fishing ass~b~ stuck while ~IH ~ 10521', top of j~s ~ 10284'. PU ke~, work free in 5 ~n. POH & PU re~ng aSs~b~. TBU K-19 (32-19) - COOK INLET (13-3/8" ~ 2591') (9-5/8" ~ !0047') 12639' (0') - GIH w/fishing assembly - MW 9-9#, Vis 55, WL 6.0. RIH w/reaming assembly to shoe of 9-5/8" csg, circ out. Reamed from 10047- 10629', considerable coal. over shaker. POH w/5 stds OK. Ran back & reamed 10629-10806'. Washed without rotating 10806-10882'. Circ hole clean. P0H OK & PU fishing assembly, started in hole. " TBU E-19 (32-19) - COOK I~LET (13-3/8" @ 2591') (9-5/8'" ~ 10047,) 12639'TD 10435'PBD - Testing BOP & WOC. RIH w/fishing assembly, circ btms up ~ top of fish ~ 10902'. Went past top of fish 15'; PU & screwed into fish on 3rd attempt. PU to 260000# total wt, came loose. Screwed back in. PU & fish came loose again w/t0000-20000# above normal wt & drag. Apparently bad box looking up. P0H & LD fishing tools. WIH w/OEDP to 10873', circ out. Spotted 200 sx Class G cmt w/l% CFR-2 & 0.3% HR-7. CIP 9:30 PM 4-24-74. Pulled 10 stands, rev out. Circ out, POH, slip & cut line, test BOPE. ~rBu ~-19 (32-19) - COOK ~,T/_,ET (13-3/8" @ 2591') (9-5/8" ~ I004T') 12639'TD 10435'PBD - W0C & repair rig - MW 9.8#, Vis 49, WL 6. Tested BOPE to 3000 psi. Circ out green emi &cond mud ~ 10450'. RIH to I0435'. S~otted 225 sx G cmt plug w/l% CFR-2 & 0.2% HR-7 mixed ~-16.8 ppg. CIP 10 PM 4-25-74. Pulled 10 stds wet. Circ out 54 bbls cmt contaminated mud. Circ& cond mud. POH. TBU K-19 (32'19)- COOK INLET (13-3/8" @ 2591') (9-5';8''' @ 10047') 10165' (18') - Sidetrack - Drilling --MW 9.8#,-Vis 43, WL 5.4 Repaired rig while' WOC. PU 30 jts HWDP. RIH to 10010'. Cond mud & CO to 10277'. DO cmt f/10277 to 10285'. Circ& cond mud. POH. RIH w/OEDP to 10277'. Spotted 20 sx G cmt plug w/l% CFR-2 & 0.2% HR-7 mixed @ 16~7 ' ppg. CIP @ 11'30 AM 4,27-74. PU 12 stds &circ out POH. RIH w/bit to 9908 & washed to 10042'. Circ &cond mud. WOC total of 20.5 hrs. DO firm to cmt f/10042-10147. POH. RIH w/diamond bit & Turbodrill. Oriented 80° to left. Drilled 10147-10165'. TBU K-19 (32-19) - COOK INLET (15-3/8" @ 2591') (9-5/8" @ 10047') 10257' (92') - Drlg w/Turbodrill & diamond bit - MW 9.8~, Vis 43, wL 5.6 Drilled 8-1/2" directional hole f/10165-10257' w/turbodrill & diamond bit. Oriented Turbo & surveyed w/Sperry Sun steering tools. KOP in sidetracked hole @ 10147'. Survey' 10187' 46-3/4° S76W The above is correct Signature For form oTe'6arat;o~and distribution see Proceeures Mansal Section 10, Drilling, Pages 86 and 87 IOate ITitle SOUTH AI~ESK~ DISTRICT DRILLING SUPVR. AR3B--4.59-2-A Number all daily well history forms consecutively as they are prepared for each welt. - AtlanticRichfieldCompany Daily Well History- Interim Instmctien~: This !srm is used dudng drilling or workover go@rations. If reeling, coring, or perforating, show formation name in describing work performed. Humber all drill stem tests sequenl, ially. Attach description ut ali cores. Work performed by Producing Section will be reported on "Interim" sheets untii final completion. Report olficial or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, Or (2) ,on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. Dis;rio! ICounty or Parish SOUTH AL.kS KAI KENAI Fie~d Ikease'°'r Unit McARTHUR RIVER I TBU KING SALMON PLATFORM IState AL&SEA ,'Veil no. K_lg Da:e and depth zs of 8:0~0 a.m. 5-1-74 10312' 5-2-74 10354' 5-5-74 10404' 5-6-74 10924' 5-7-74 11034' 5-8-74 11034' 5-9-74 11046' 5-10-74 11161' 5-13-74 11445' Complete reCord for each day' while drilling or workover in progress TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591')(9-5/8" @ 10047') 10312' (55') - Drlg w/Turbo - ~B~ 9.8#, Vis 45, WL 5.8 · Directional drilled 8-1/2" hole f/10257-10288' w/Turbo & diamond bit., POH. LD diamond, bit & 2° bent sub. RIH w/Turbo #8, mill tooth bit &:S° bent sub. Rmd kick off interval f/10147-10288'. Oriented Turbo w/ SperTy Sun steering tools. Drilled 10288-10312'. Survey' 10247' 45-3/4° S76W TBU K-19 (32-19) - COOK INLET (13-'3/8" @ 2591') (9-5/8" @ 10047') - 10354' (42') - Drlg w/Turbo #9 - MW 9.9#, Vis 47, WL 5.4 Drilled w/Turbo f/10312-10354'. POH for bit @ 10320' RIH w/Turbo #9, 8-15/32" diamond bit & 3° bent sub. TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591')(9-5/8" @ 10047') 10404' (50') 0 Trip - ~ 9.9#, Vis 49, WL- 4.8 Drilled w/Turbo #9 f/10354~10404'. POH for BHA. TBU K-19 (32-19) - COOK INLET (13'3/8" @ 2591') (9-5/8" @ 10047') 10924' (520') - Drilling - MW 9.9#, Vis 47, WL 4.7- Drilled 8-1/2" directional hole 10404-10924!. Survey' 10764' 47° S77W TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9-5/8" @ 10047') 11034' (110') - Rig Repair - ~B~-9.9#, Vis 48, WL 5.0 Drilled 8-1/2" directional hole 10924-11034'. Survey & trip. Run Turbo- drill #10 & BHA. Replacing drawworks motor. Survey' 10984 ' 46-1/4° S79W TBU K-lg (32-19) - COOK INLET (13-3/8" @ 2591')(9-5/8" @ 10047') 11034' (0') - Picking up bottom hole drilling, assembly - MW 9.9#, Vis,48, WL 5' Changed motor on drawworks. Set load limOt on main generator. Generator ground, ed out. Repaired same. Motor #2 not taking load. FOund super excitation diodes burned out. Bypass diodes. Pull to run bit. TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9-5/8" @ 10047') 11046' (12') - Drlg w/Turbodrill #10 - MW 9.9#, Vis 46, 'WL S.0 WIH w/8-1/2" bit. Bridge at 10630'. Ream 10945-11034'. Circ. POH. GO in hole w/Turbodrill #10. TBU K-lg (32-19) - COOK INLET (15-3/8" @ 25gl')(g-5/8" @ 10047') 11161' -(115r) - POH w/Turbodrill #10 - MW 9.9#, Vis 46, WL S.0 Turbodrill #10 - 11034-11161'. TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9-5/8" @ 10047') 11443' (282') - Drilling w/Turbo & diamond bit - bB~ 9.9#, Vis 49, WL 5.2 Directional drilled 8-1/2" hole f/11161-11443'. The above riS correct. ---'. . '"~'r' Signature ~'* ...~f ..... "~ // ' / see Procedures M~ual geetion 10, Dr~Hing, Pages 86 and 87 JDate jTitJe J SOUTH ALASmi DISTRICT DRILLING SUP,~Rk,,SOR A,~3B.-459-.2-A jNumberall daily well history forms consecutively as they are prepared for each well.t~_:' ' jPage no. 9 - ( AtlanticRichfieidCompany Daily Weii History-interim }r:.sfruclions: This form i.~ used during drilling or workover ooeralions. If testing, coring, or perforating, show formation name in describing work performed, Number aH drill stem tests sequentially. Attach description of eli cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2.} on Wednesday Pt the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District JState SOUTH AL&SKA Kenai ALASKA Field JCounty or Parish L.~ase' or Uhi'~ TBU KING sAD, ION PLATFOP~H . . record for each day while drilling or workover in progress blcARTh'tJ R RIVER Date anr~ depln -s of 8:C~3 a.m. lComplete JWell ~0' 5-14-74 11534' 5-15-74 11733' 5-16-74 11926' 5-17-74 12217' 5-20-74 12778' 5-21-74 12987' 5-22-74 13100' 5-23-74 13277' The nbove is correc: ~._-.; .~: ~/ ..-k~'; ~'7~..--~.--~"~' For form preparation ~d'distribution s~e Procedures Ma~l Secdon 10, Drilling, Pages 86 and 87 TBU K-19 (32-19) - COOK INI~ET (13.-3/8" @ :2591')(9-5/8" @ 10047') : - 11534' (91') - Drilling - MW 9.9#, Vis-47, WL 5.0 Drilled 8-1/2" directional hole w/Turbo #1 & diamond bit f/t1443.11479,. Tripped for angle building BHA. Rind 11354-11479' following diammd bit run Drilled 11479-11554'. Survey' 11461' 42-3/4° S73W ' ' ~ - ' TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9-S/8" @ 10047') 11733' (199') - Drilling - MW 9.9#, Vis 45, WL 5.0 Drilled 8-1/2" directional hole f/11534-11733'. Installed new diodes in D.C. generator control unit. Survey- 11530' 42-1/4o S70W ~ . ~ TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591')(9-5/8" @ 10047]) 11926' (i93') '- Drilling - MW. 10.0#, Vis 43,: ~L 5.2 : Drilled 8-1/2" directional hle f/11733-11926'. Hole condition good on trip. Survey: 11700' '45-1/4° S76W TBU K-19 (32-19) - COOK INEET (13-3/8'' @ 2591') (9-5/8" @ 10047')_ 12217' (291') - Drilling - ~D/ 10.1#, Vis 47, WL S.0 Drilled 8-1/2" directional hole f/I1926-12076'. Hade wiper trip to csg shoe. Drilled to 12217'. Survey' 12041' 45o S74W ' TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591:~) (9-S/8" -@ 10047') 12778' (561') - Drilling - blW 10.1#, Vis 49' WL 4.8' Drilled 8-1/2" d£rectional ho-le f/12217-12778'. Made-bit trips @ 12262' ~ 12657' 8 wiper trip to csg @ 12486~. Tested BOPE-to 3000 psi. Surveys: 12212' 42° 879W, 12607' 48o S73W - TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591')(9-5/8~, @ 10047') 12987' (211') - POH - MW 10.2#, Vis 47, WL 4.8 -- Drilled 8-1/2" directional hole f/12778-12894'. Made 10 Std wiper trip. Drilled to 12987'. Pulled thru tight spots @ 10400-10419' & 10092-10137 w/90,000# net. Survey' 12937' 49° S71W TBU K-19 (32-19) - COOK INLET (13-3/8" @ '2591') (9-5/8" @ 10047')' 13100' (113') - Drilling - MW 10.2#, Vis 50, WI 4.8 Replaced Hydril rubber & tested to 1600 Psi. RIH. Drilled 8--1/2'! directional hole f/12987-13100'. TBU K-19 (32-19) - COOK INLET (13-3/8" @ 2591') (9'5/8t' @ 10047') 13277' (177t) - Tripping - MW 10.1#, Vis 48, WL 4.6. Drilled 8-1/2" directional hole f/15100-13188t. blade 14 std wiper trip. Hole condition OK. Drilled to 13277'. POH. Drilled up thru tight hole F/11797-11790' in 2, hfs ~ f/10372-10368 in 1-1/2 hrs. Bit 1't out of gauge~ Survey:; 13227t 51-1/2° S69W - SOUTH ALASKA DISTRICT DRILLING SUPERVISOR AR3 B-4,,59-2-A ,. J Number all daily well history forms consecutively jPage no. for each _ J ' 10 Jas they are prepared well. AtlanticRichfieidCompany Daily Well History-Interim ,'r-,~truct/~ns: This form ;$ used during drilling or ',orkover operations. Il' testing, coring, or perforating, show formation name in describing work performed. drill stem '.ests sequentially. ^ltacn cescriotion of ail cores. Work performed by Producing Section will be reported on "Interim" sheets until final Report otficial .or representative test on "Final" form. I) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) ~¥_~cr, e~day of ~,ne week in which oil string is set. Submit weekly for workovers and following setting of oil s:ring until completion. F: ~;d SOLiTH AL~S KA County or Parish KENAI IState blcARTHUR RIVER KING SALMON PLATFOI%M Ca:e =_nd depth Complete record for each day while drilling or workover in progress as cf ~:C-"] a.m. . ALASKA Lease or Unit tWell no, TBU I K-19 5-24-74 13450' 5-28-74 13771 ' TD 5-29-74 13771 ' TD 5-30-74 13710' 5-31-~4 13710' TBU K-19 (32-19) - COOK INLET '(i3-3/8" @ 2591') (9-S/8" @ 10047') ' - 13450' (i73') Drilling - MW 10.2#, Vis 48, WE 4.2 RIH. Rind & washed to btm f/13177-13277'. Drilled 8-1/2" directional hole f/15277 13407'. blade 20 etd wiper trip. Drilled up thru 8' tight spot @ 12363' in 1 hr. Ran back to btm OK. Drilled to 13450'. TBU K-19 (32-19) - COOK INLET (7" liner 9769~13756') _ 13771' TD (521') -POH Drilled 8-1/2" directional hole f/13450-13574'. Made wiper trip & drilled up thru tight spot f/10677-10665'. Circ & cond hole for logs. Ran DIL, GR-Sonic & Formation Density-Neutron logs f/Schl TD 13561 to csg shoe. RIH w/bit & drilled to 13771'. Made 3 etd wiper trip. 'Circ & cond hole for liner. POH. Ran 93 its (398-7') 29# N-80 X-line liner w/BOT hydraulic MCliner w/type SS long sleeve (6'-) tie back assembly w/o flapper & packing rubber, Ran 68 centralizers. Stuck liner 15' off btm. Circ & worked liner. Liner remained stuck w/shoe @ 13756'. Top of liner @ 9769'-w/278' lap, catcher sub @ 13710': & landing collar @ 13667'. Set liner hanger w/approx 200,000# wt on hanger. Pumped 100 cuft Howco MF II pre-fluSh & cmtd w/400 sx cl "G" w/l% CFR-2 & 0.3% HR'7 followed by 600 sx Cl "G" w/l% CFR-2 & 0.2% HR-7. Mixed cmt @ 15.8 ppg. Dropped wiper plug & displaced w/10 BFW & 313 BM @ 5-8 BPM. Max pumping press 1900 psi. Plug bumped w/2400 psi & held OK. CIP @ 5':-10 AM 5-28-74' PU. DP pulled wet for 5 stds. Survey: 13574' 50° S68W TBU K-19 (32-19) - COOK INLET (7" liner 9769-13756') 13771' TD - RIH- MW 9.9#, Vis 43, WL S.0 POH. LD 93 its S" E DP, 30 its HWDP, Monel DC.'s& stabs. MIH w/8-1/2" bit & 9-5/8" csg scraper. Broke circ'@ 8000'. FIH to top of liner @ 9769'. No ' cmt on top of liner. Circ. PU. Test lap w/2500 psi. Bled to 2200 psi & held for 10 min. POH. PU 3-1/2" DP, 4-3/4" DC, 6" bit & 7" csg scraper. . ~ FBU K-19 (32-19) - COOK INLET (7" liner 9769-13756'). 13710' PBD - Rng CBL - bg~ 9.9#, Vis 43, WL.5.8 RIH w/6" bit & 7" csg scraper. CO cmt contaminated mud & soft cmt f/13576-13667' DO firm cmt f/13667-13710' Check landing collar @ 13667'. Circ hole clean. Tested csg & liner lap w/2500 psi Bled off to 2100 psi in 5 min. POH RIH w/ GR-CBL log & Schl checked TD @ 13697' WLM. ' TBU K-19 (32-19) - COOK INLET (7" liner 9769-13756') 13710' PBD - Testing liner lap - ~ 9.9#, Vis 42, WL 5.8 Ran Gamma Ray-Cmt Bond Log f/Schl WL depth 13698-9766'. Top of cmt @ 10434' w/good bonding. Ran Fmtn Density-Neutron f/13698-11903' & Sperry Sun Gyro f/13600-2000' @ 100' stations. RIH w/9-5/8" RTTS pkr to test & sqz liner lap. · ¥~e a:c,e is dorrect / IDate ITitle SOUTH ALASKA DISTRICT DRILLING SUPERVISOR FL; f¢-m 2r;eparatior,..~nd distrioution sd=_ =,2--_edures ~'.,~hudl Section 10, D" ',r~. ;a~es 86 and 8,7 I Number ali daily well history forms consecutively as they are prepared for each well. tPa~e no. AtlanticRichfieldCompany Daily Well History-interim (nslruc,qcns; This form is used during drilling or workover ooeralions. ~f testing, coring, or perforating, show formation name in describing work performed. N,_,m. Der ~;I drill stem :gsts sequentially. Attach descriotion of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final ce.repletion. Rgport official or representative test on "Final" form. !) Submit "Interim" sheets when filled out but not less frequently than every ,30 days, or (2) on Wednesday et the week in which oil string is set. Submit weekly for workovers and following setting of oil st.ring unlit completion. District Field " 1 State SOUTH ALASKA . ICounty or Parish - KENAI ILJase 0m~ Unit I SA O, ALAS~ twe. n,~ 19 McARTHUR RIVER Date and teem Complete record for each day while drilling or workover in progress as cf 8:00 a.m. 6-3-74 13710' TBU K-19 (32-19) - COOK INLET (7" liner 9769-13756') ' 13710' PBD - RIH w/8-1/2" bit & scraper - b~ 9.9#, Vis 39, WL 8 Ran Sperry Sun Gyro survey. RIH w/ RTTS tool. Broke fmtn down @ 2BPM @ 2500 psi. Squeezed liner lap w/200 sx class "G" cmt w/l% CFR-2 & .2% HR-7. Mas press 2800- psi. Final press 2500 psi. POH W/RTTS tool. RIH w/8-1/2" bit & 9-5/8" csg scraper. Drilled cmt f/9662' to top liner. POH w/8-1/2" bit. RIH w/6" bit & 7" csg scraper. CO liner to 13710'. POH w/6" bit. RIH w/DST tools. Set pkr @ 9706' Ran WSO test; IHP 3708 psi, IFH 1230 psi, ISIP 1780:psi, FHP 3708 psi, FFP 1780 psi, FSIP 3067 psi, BHT 130©. Net fluid rise 3100'. POH w/DST tools. RtH w/RTTS. Pmpd into fmtn @ 2 BPM @ 3000 psi Squeezed liner lap w/150 sx class "G" cmt w/'2% HR-7 & 1% CFR-2. Pumped into fmtn@ 3500-4500 psi. Final press 4600 psi. POH w/RTTS. RIH w/8-1/2" bit & 9-S/8" csg scraper. : 6-4-74 13710' 6-5-64 13710' Tr:e above is correct ~_. For fo~ ~7~tm.~nd distribution s~9 Pr~cg~ures MamJal Sec[ion 10, TBU K-19 {52-1R) - COOK INLET (7" liner 970R-15756') 13710' PBD - POH w/6" bit ~ scraper - MW 9.9#, Vis 39, WL 7.4 ROS bbl cmt contaminated mud @ 9662' after squeezing liner lap. POH. RIH w/8-1/2" bit & 9-5/8" csg scraper. CO firm cmt 9655' to top of liner @ 9769'. POH. Ran 6" bit & 7" csg scraper to 13710'. No cmt in top of liner. TBU K-19 (32-19) - COOK INLET (7" liner 9769-13756') 13710' PBD - Running FIT #2 @ 13516' - ~fl~ 9.9#, Vis 39, WL 7.4 Trip out w/6" bit. Ran WSO test w/pkr set'@ 9706' w/2000' filtered inlet wtr- cushion to test liner lap squeeze. Tool open 62 min 'w/wekk blow for 5 min then dead. Took 123 min FSI. POH. Had 90' rise recorder @ 9721' - IH 3705, ISI 614, IF 614, FF 614., FSI 688, FH 3680. Ran Schl collar log. Ran FIT #1 @ '13597' testing Hemlock Bench 6. Tool' open 15 min w/4000 psi IF, 4000 psi FF, 16 min FSIP 4300 p~i, tip 5000 psi, HP 5167 psi on Amerada recorder. Re-coverT' trace of oil, 10,200 cc wtr, 0.62 cf gas & 0.2 cf shot gas. Wtr salinity 2700 ppm chlorides. ID'~te ITitle SOUTH ALASKA DISTRICT DRILLING SUPERVISOR A RS B--459--2-A jNumber ail daily ;veil history forms consecutively as they are prepared ,'or each well. _ AtlanticRichfieidCompany D' ily Well History-Interim Instructions: Th,s 'orr- is us,ed Curim:j. drillin<j o*' ~,orkover oceration$. If testing, coring, or perforating, show formation name in describing work performed. Number a;l dr/ii ~.m :_~$~$ secuentially. Arta¢~ d~*~c~ption of ail cores. Work performed by Producing Section will be repoded on "Interim" sheets until finat comoiedon. Recc,,~ c?'c:~, or r-ecres,e.~tati-~e '.est on "Fi.aF' form. 1t Submit "Interim" sheets when fi!led out but not less frequently than every 30 clays, or (2) on V;leCnesda~, cf :~e ~,.~e~t ;n ~,ngch oO string is seL Sui~mit wee.[Jy for worXovers and foiiowing setting of oil string until completion. Dis{rict Field 5{c_~R ~ ~4UR RIFER County or Parish L~a-~e o¢ Unit TBU KENAI KING SA~.HON PL&TFOP~M Istat~- ALASKA IWellI~°' ,19 Date and cel~m as of 8:00 6-6-74 13710' 6-7-74 13771 ' TD The above is :c"=.c: ~;" Complete rt, corci for each oay while ddliing or workover in progress TBU K-19 (52-19) - COOK INLET (7" liner 9769-13756') 13710' PBD - Laying Down DP - MW 9.9#, Vis 39, ;WL 7 Ran FIT's as follows (Hemlock Benches'6 thru 1) ~ FIT Depth. Form Flow Time IF FF SI FSI 'aC . 13516 Bench #6 1S min 45'50 4450 16 min 4500 5100 g750 · #2 Rec .0 cc oil, 8500 cc water, 0.38 cf gas (all shot gas), wtr 3200 ppm #3 15403 Bench #S 16 min 4000 4000 IS min 4100 Rec SSS0 cc oil, 3515 cc wtr, 185 cc BS,: 11.14 cf gas, 0.2. cf shot gas, wtr 3500 ppm cl 13252 Bench #4 15 min 3200 3750 15 min 5590 Rec 10,200 cc wtr, .19 cf gas, .19 cf shot gas, wtr 2800 ppm cl . #S 13075 Bench #3 1S min 100 100 16 min 3500 Rec 49 cc oil, .0 cc wtr, 1 cc sand, .38 cf gas, 38 cf shOt gas 4980 475O #6 12965 Bench #2 1S min 3000 775 20 min 3450 4750 Rec 396 cc oil, 57 cc oil, 57 cC wtr, 115 cc sand, 1.1 cf gas, 0.4 cf shot gaS (No wtr salinity - not enough to test) - ~7 12816 Bench #1 15'min 3000 i00 15 min 3285 4840 Rec trace oil, 1200 cc wtr, .4 cf gas, .4 cf shOt gas - .RD Schl. RIH w/6" bit & 7" csg scraper to 13710'. Circ 5-3/4 hrs. POH. . TBU K-19 (32-19) - COOK INLET (9-5/8'-' csg @ 10047', 7;'. liner 9769'13756') 13771' TD, 13710' PBD - Running 4-1/2" 12.6# & 3-1/2" 9.2# N-80 Buttress tbg. 5B¥ 9.9~, Vis 39, WL 7.2. LD 5" & 3-1/2" DP, 4-3/4" & 6-1/4" DC's. Pull bowl protector. Install 4-1/2" tbg rams. Test rams. Ran 3-1/2,' & 4-1/2" tbg comple tion assembly including 3-1/2" guide shoe, B0T shear out sub, Otis "X" nipple 30 above shear out sub, 7" BOT HIRSP Husky pkr 60' above shear out sub, 6 ea 3-1/2" KBUG mandrels w/BK vlvs & 8 ea 4-1/2" MMG mandrels-w/R-20 vlvs & mandrels spaced as per completion program 9800 ft @ 6Y00 ~M 6-7-74. IOate ITitle -SOUTH ALASKA DISTRICT DRILLING SUPERVISOR see Procecures.'~,! ar[._-'; £ect:cn i0, Drilling, Pe~es ~.5 z'~C £7 AR38-4C-¢.3-~ 2 ...A Numb'er all daily well history forms consecutively IPage no. as they are prepared for each well. ' AtlanticRichfieldCompany - Daiiy Well History-Interim Instruction,,: This form is used during drilling or workover operations. If testing, coring, or perforating, 'show formation name in describing work performed. Number all ~dil stem tests sequenlially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Reoor~ off;cial or representative test crt "Final" form. 1) Submit "Interim" sheets whert filled out but not less frequently than every 30 days, or on Wednesday of th~ week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of $:C,0 a.m. J County or Parish ' SOUTH ALASKA J KENAI 'lLease of Unit ' ' blcARTHUR RIVER I TBU KING SALMON PLATFORM Cc;replete record for each day while drilling or workover, in progress 6-10-74 13771 ' TD 6-11-74 13771 ' TD 6-12-74 15771 ' TD The above is correct Sig.~t~,e .... '/'¢.?"-? '";/ '""- For form preparation and distribution see Procedures.M'anual Section 10, Drilling, Pagas 86 and 87 IState ALASKA tWell no. . K-19 TBU K-19 (32-19) - COOK INLET (9-5/8" Cs~ @ 10047' 7" liner 9769-13756') 13771' TD, 13710' PBD - Perforating - 'Diesel Oil :- FIH w/4-1/2" x 3-1/2" tbg completion assembly.. Landed tbg. 'Installed BPV. ND BOPE. Installed & tested Xmas tree w/5000 psi. Displaced mud w/filtered inlet wtr & wtr w/DO. Set BOT hydraulic pkr @ 12698' & sheared out ball w/4200 psi-, Tbg guide shoe @ 12769'. RU lubricator & .tested to 2500 psi. RIH w/Schl 2" scallop gun to 13490'. Tools stopped. POH. Added sinker bar. Reran gun to 13531'. Tools stopped. Spudded & worked gun. POH. PU additional sinker bars.. TBU K-19 (32-19) - COOK INLET (9-5/8" csg @ 10047', 7" liner 9769-13756') 13771' TD, 13710' PBD - Flowing well on GL : : POH w/perf gun. Unloaded well on GL. Prod well to test separator 6 hfs to clean up. Test meter failed, no rate available. Cut 10% wtr w/16000 ppm . chlorides 6 17% solids. : ' TBU K-19 (32-19)- COOK INLET (9-5/8" @ 10047', & 7" liner 9769-15756,) 13771' TD, 13710' PBD - Flowing Flowed perfs f/13535-13545' on GL a total of 40 hrs to Clean up. TeSted On GL @ rate of 1800 BFD .w/10% wtr & 1.5% solids.. Perf'd f/13395-134i5'- under dz-aw- down conditions w/Schl 2" scallop gun w/4 Hyper jet SPF. Gas lift .compressor & two shipping pumps down for repairs. Tested well on natural flow @ 1056 BFD, 33.4°API, 1% wtr & 1% solids. - ITitle * I DISTRICT DRILLING SUPERvISoR - SOUTH IOate A.~3B-4.59-2-A Number all daily well history forms consecutively nd. as they are prepared for each well. /{tianticRichfieidCom pany Daily Well History-Final Report ]-Instructions= Preoare and submit the "Final Report" on the fi'mt Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.- / "Final Relx~rt" should ,3e submitted also when operations are susoended for an indefinite or appreciable length of time. On workovers when. an otticial test is not f' required uF, o~ c~3molefion, reoort completion and representative test data in blocks provided. The "Final Report" form may be used [or reporting the entire operation if soace is availaole. · District SOUTH ALASKA Field blcARTHUR RIVER FIELD Auth. or W.O. r~. 199303 County or Parish Lease Or Unit KENAI KING SALMON PLATFORM Title DRILL DEVELOPMENT ;fELL Accounting cost center code. Operator ! ATLANTIC EICHFIELD COHP~NY ._.~.. A.R. co. w.~. . ' 12.9% Spuoded or W.O. begun O~te Spud 2-22-74- Date and ceo~ as of 8:00 Old TD Complete record for each day reported I~tat n~bh6~r of wells (active"o'r inactive) on this~ - : V ~:-.~: est center prior to plugging and / '~ '.-. -- k- ~..:: '-"- band~ment of this well J "' ."/:'~ -/ '~: t TBU K-19 (32-19)·--,COOK INLET (9-5/8'.' csg @ 10047', 13771'. TD, 13710':PBD - Perforating .. Tested @ rate of 2400 BPD w/3% wtr. cut. f/perfs 13595-15415' RU 6:~tested lubricator. Perf'd ~dey~do~ w/4 H~er .jet_:_SPF w/Schl._ scallop g~ ~/15504-1353~':--6 15460-1o4~',_Cle~ed up.- for-8'.hrs a m~:rate, of 3840 BFD-w/i% -BS6W. . -'.~' .. "--" ' . ..- ...... ..:,::,?:~C '. ..... : ,: ' --' TBU:K-19 (32-19) ;'.:' COOK [NAET '~9-5/8" csg' e10047 13771~ TD, 13710 ~ :PBD . SI Well 6 bled:.o~f,~ul~ due .to-.-le~ng s~ab vlv. Perf~d 4 Hyperjet SPF S~1::,2" scallop gun..f/13345-13375~. Attested to ck PBD p~'.-a. 13545~.. Worked tools e .13546~. Tools stick~ng,~. Clewed up peres tested well on GL::971/2 hfs e m~ r~te of 4100 BOB w/0.8~ presso~ do~ ~o~ ~epairs. Shor~ of g~ Eot GL. Turned'well over-to production . _- 6-13-7~ 13771' TD 6-14-74 13771' TD Released rig Classifications ~o41, ga~, etc,) 0ii Producing me~oO _ ~as Lift Pctential test ca':a I PB Depth 13771' 13710' · Kind -of rig Rotary . 'l Type completion (single, dual, etc.) ! ~Sin=le. 4 1/_ & 3,. 1/2 ,tapered-gas lift I Officiai reservoir name(s) I Hemlock New TD Date ..6-1~-74 [we[! no. ;~3a:e Reservoir Producing Interval Oil or ga~ ]Test time Production ! Oii on test ;Gas per day , , I I K-191 6/21/74 Hemlock !Benches 5 & 6 Oil 8 hr 5271 BOPD 1170 MCFD Pump size, SFM X ie'~,2:h Choke size T.P. C.P, Water %- GOR Gravity Allowable Effective date corrected [ , , 5"[ - N/A I N/A 175 1200. 0.4% 222 Date The above is corr.-~c,: . / Signature .. ~..-~"~'.~ '~ i/ '- ~ see Procecu~ '~a~. Section !0, DFHing, Fa~ ~ ~ ~7. Title ' SOUTH ALASKA DISTRICT DRILLING SupERvISo . '. '; ':C:.': ' COv;;~L:~TIO''~ '-~E~O~]' JU,E ~:'~ 19'?a ATLA;',iTIC RICHFIELD OIL COo T~.".d KELLY BUSHING ELEVATION TANGENTIAL v..ETHOD OF CO>'PUTATIOPiS PREPARED FOP, ADDCO ~Y Fo ~'.';, LI.'%DSEY R E COr-:.D OF ALL CALCULAT ',-,:,S PERFORiv, ED 3Y SJi-;V~Y ~ a ~ ELECTPr'N~C C 0!< P U T E i:{ TRU!f .ME/!So DRIFT VERTICAL SUB DRIFT DEP~'H A¢,!GLE DEPTH SEA . DIREC P :,! DEG. TOTAL cook, i) C L. 0 S U D I STANCE RES ANGLE D M S 3P. 1 596 633 723 904 936 997 ' ' 057 { zt7 117~ 1241 1256 !~96 1,579 ]930 2112 2 240 l 249A 256 ' 2756 . ~294fl 1 t 14 .15 17 17 22 26 33 42 51 45 43 44 4 .98 2500¢')~ 2 . 92 495092 .5, ,91 532.91 3 ,75 622.75 4 .2~ 715,28 ! . 37 802.37 4 . O0 834,, O0 3 .97 293.~F .44 952,a4 .65 1010,65 .59 106.9,58 ~80 S 19 595 S 35 632 722 N 51 i,,.,' p, 1 ~:, "' 902 93a N 64 W 993 N 75 W 1052 N 89. ~'~ i!!0 S 1169 S 67 1229 S 54 W 1244,1..5 '. !1~z~,15 S 53 W 9 1372.,75 1273, 5. S 52 W 159¢., 0~. 1438,C8 S 53 1746,78 1646,7~ S ~5 W 1956,35 1856.35 S 55 W 2076,52 1976,52 S 55 21~+.1,11 20Al,!! S 59 W 2253.45 2153~48 S 59 .0395,36 22°5,36.. S 60 W °53~' ..... .60 2a30.60 S 81,04 N 48042 E 76092 N 51,30 E 77,03 !"1 .~Or ~.94 E 80,49 i'< 46,67 E 87,08 ~'. 40.C.E, E 93039 ',, 29.1a E 9 ~:: . "< '-' .,, 5~ 24 98,22 5: 13.98 Z 98,69 i 0.49 F 95,92 89.7~.., N 2~.2~ W T8.92 N 43.1~ W 75,25 N 46.73 W 43.96 N 88,06 W 4,74. S 152.70 W 84,73 S 266,93 ].92,9~ S ~21,50 W 278,{~4 S 544,16 W 316,12 S 696,19 W 351.46 S 665,01 W 375,50 S 705.02 W 44'!,6~.., ~q 819,60 W 506~9~, S ~'~2.70~.. '~": 940"+0 92.45 92.35 93. Cz+ 95 97,84 9~.6o 99,21 98069 96090 94010 89,97 N 89.43 M 9~ ,42 152,77 S a63,57 s 611,44 s 683,56 s 752,]8 s 796,78 93i~92 tC 61 ~ 57 S 61 S 61 S 61 DOG LEG SEVERITY DEG/iOOFI .0,000 0,275 4,98~ 3,285, 20~'71 3.497 2.4i9 4.350 5,806 5,313 5.180 6.494 2,575. 3,401 2,333 30014 2,92b ~,818 4o4.12 2,105 10894 1,091 0,532 .. -75 -'? C' -69, -'61 -49 ~22 10 , 143 . .279 463 60~ 680, .74.7 924 10 ~'5~ A. RECOqD OF 5L.',!,tVEY ALL ~LC~LAT[O:XS PEi'.~FOP,>",aD GY f '3 ,v ELFCTR f~[C COh':PUTER TRUE ' · r- i'-~ ,"'~EAS. DRIFT VL,xTICAL SUB D,'.IFT D~¢TH_. AFiGLE DEPTH ~-..C=A ~,'~I~t:C.- D M DEG. TOTAL C,DORD I A:ATES 3,291 45 0 2775.96 2675,96 S 50 W 3,824 47 0 3139,47 3039,47 S 60 W 4300 49 15 3450,!8 33!50.18 . S 60 W 4714 49 30 37!9,05 36t9,05 S 60 W 5071 48 15 3956,77 3856,77 S 6! W 5920 49 45 4505.33 4405.23 S 62 W 6335 49 30 477a.~5 4674.~5 S 66 W 6713 48 15 5026.56 4926.56 S 66 W 7148 48 30 5314.80 52!4.80 S 69 W 7533 48 45 5558,54 54.68,64 S 72 W 8123 49 0 5955~72 5855,72 S 74 W ~508 49 0 6208,30 6108,30 S 74 W 909n 49 0 6596,03 6496,03 S 74 W 9339 49 0 6753,49 6653.z~9 S 73 W 9643 fl9 15 6951.93 6851.93 S 73 W 9854 49 0 7090.35 6990.35 S 75 W 10054 49 0 722!,57 7121.57 S 77 W 629,63 S 1145,19 ~°4,5~ S 1462.7e 1004.84 S 1795.07 1162~24 S 2067~70 129i,37 S 2300.65 1595,5~ S 2872.73 1723,91 S ~156.41 1~4~62 S ~414,04 1965,~7 S 3718,20 2054,82 S S993.49 2177,55 S 4421~52 2257,64 S z. 7C'O . 83 2Z~0.59 S 5129.5~ 2433.54 S ~302.80 2500.8~ 5 5523.03 2539,40 5 5677.55 2573.35 S 5824.62 101.4.7_47_ 30 .... 7284,.a0. 7!.84,a0 S 75~ W. 2587.61 S fi891,69 W 10247 45 45 ... 7~54,17 7254, ].7 S 76 W 10400 43 451 7464,70 7364,70 S 73 W 10623 46 ~0 . 75!8,20. 7513,20 S 75 W 10764 z+7 0 '771z+,36 761a,36 S 77 W 10984 46 15 7866,49 7766,49 S 79 w 11274 43 30 8076,85 7976.85 S 78 W 11451 42 45 8214,17 8].14,17 S 73 W 11530 42 15 8265,25 8165,25 S 70 W 11700.45 15 8354~93 . 8284~93 S 76 W 12041 45 0 8626~05 8526,05 S 74 W 12212.43 0 8751,11 8651~11 S 79 W 2604.94 S 5961,19 W 2635.88 5 6.062,37 W 2677,74 S 6218.62 W 2700,94 S 6319,09 W 273].~26 S 6475.09 W 2772,77 S 6670.36 W 2809o~8 S 5791.74 W 2825~75 S 6835.3/+ W 2854,95 S 6952~49 W 2921~42 S 7184.,27 W 2943,67 S 7298,75 W CLOSURES D i STA:NC E A:4GLE D M . S !306.87 S 61 11 51 W SEVER I TY SECT I 9FG/iOOFT DISTA 0.288 1297. 159&.61 S 60 55 21 W . 0.375 ...... 1592, 235'[.17 S 50 45 39 W 2371.96 S 60 39 35 W 263:~.30 S 60 41 39 W 3286,15 S :~0 57 5 w 3601,31 S 61 13 7 W 3~82,4! S bi 33 56 W 4205,67 S 6;.;. 8 23 W 449t~13 S 62 46 20 W .492b,65 S 6'J 46 46 W 5214.86 S 64 20 47 W 5655~07 S 65 6 15 W 583z~54 S 65 20 55 W 6062.86 S 65 38 18 W 6219~58 S 65 54 8 W 6367~76 S 68 9 49 W 6434.89 S 66 17 20 W 6505.50 S 66 23 43 W 6610.61 S 66 30 3 W 6770,64 S 66 42 11 W 6872~12 S 66 51 24 w 7027.56 S 67 7 ~6 W 7223,70 S 67 25 41 W 7350.05 S 67 31 26 w 7396~40 S 67 32 22 W 7515.84 S 67 40 30 W 7755~54 S 67 52 16 W 7870.00 S 68 2 6 W 0.473 2039, 0.060 2351, 0.409 .. 2615. 0.i9~ ...... 3259. 0,372 3574, 0.518 .. 3856, 0.519 4182. 0.588 4A'70o 0,259 . 4913, 0.000 O,OOC 0.314 0.082 1.082 0.377 1~801 5202. · 5646, 5'827, 6056, 6214. 6363 · ..... 6~_31.. 2,275 ...... 6!~02 . 1.901 6607° ]. ,387 ............... 6768~ 1,092 .... 6870- 0.74.4 ... 7026,~ 0.979 7223,, 1,871 7349,, 3~025 _ 7395, 3,010 . 7515° 0,422 . 7755, 2.343 .. 7869~ ,RECOIqD ~,, SURVEY ALt. C:'-ILCUI..ATIO,NS P:z:'tF:O.'.R?F'D E'Y ! B ? =L. FCT~O.N[C COhiPUTF_~ T R U E x'.EAS, DO. IFT VE:qTICAL SU~ DRIFT DEPTH ANSL~: DEPTH SEA DIREC 0 M DES, TOTAL COORDINATES .L260~ ~+8 0 9015,42 89!5,42 S 73 W i273'/ 40, 0 9231,92 9i31,92 S '?1 W 1322'7 51 30 9412,~+5 9312,45 S 69 '~¢ 13577 50 0 96...3'7,42 9537~42 S 69 W 13721 47 30 9'73a,71 9634,71 S 67 W 3029,49 S 7579,46 ~..'.' 3110,58 S 79i4,95 W 919!,91 S R025,83 W 3287,99 S 8277,14 W 3329,48 5 8374,87 W ~OTTON~ HmL= CL. OSUR~ 9012~43 F== ...... . ...... ~T AT S 68 19 9 W CLOSURES b I STANCE /INGLE D M S 5162,48 S 68 12 48 W Ballo25 S 68 17 45 W 3632,19 S 58 18 52 W ~906,29 S 68 20 6 W 9012~43 S 68 19 9 W DOG LEG SEVERITY DEG/iOOFT 1.655 Oo 546 !.012 0.~+29 2,026 SECTIC D: STAi'~ 8162,z 8411,~ 8o38,0 8906.; 9012,z HEASt!Rc:i~ ........ b~:PTH AND OTHE',,, DATA FOR ~'wr:'RY,.,.,~. E V [{ 100 FEET 0 F S U [:J SEA DFPTHo .5: E ASUR E D D[:{P T '.--~ 400 5O0 600 .{ 700 .. 801 902 ........ 100_3 1106 12!0 . 1425 1537 t65.3 1774 1902 · 20.36 21~2 23.39 24a6 2626 2901 3042. 3154 .3326 3473 3610 3?66 ........ 3917 407 0 , 4531 4585 ....... 4836 T P, V E:RT I C,AL D E P '[ H 400. 500, 600, 700, 800. 900, 1000o 1100o 1200o 1300, 1400° 1500, 1600. ],700o 1800° 1900. 2000, 2100. 2200, 2300, 2400~ 2500. 2600. 2700. 2800° 2900, 3000. 31.00. 3200, 3300, 3400, 3500. 3600~ .. 3700° .... 3800° D-T VD SEA ~' I F F ~:'": ._NC~: 300. 0 400, 0 500. 0 600° 0 700. 1 ~,,,0. 2 900, .3 1000, 6 11 "" 0 10 12NO. 16 13 00 · 25 ],500° 5.3 1500, 74. 17,00. !02 1800. 136 1 900, 182 20~0~ 23° 2100, 286 220 ('! ° 326 2300. 362 2~00° 401 2500° 442 2600, 484. 2700, 526 2~00 ,. · 573 2900~ 6]9 .3000~ 666 3 10 0 · 7 ! -I o, ? ,-', 0 ...... ,..,.. 770 3300. 823 3400~ 877 35,r}O ~ 93] 3500° 985 3700° 1036 VE RT ! CAL CORRECT I ON 0 0 0 0 1 1 t 9 12 21 2~ 34. 57 4? 4O 36 39 41 4.2 42 47 4,6 47 '34 54 TOTAL COORDINATES 80,67 78°75 76~93 79°62 85,99 93.22 98,27 96.43 84.°2~ 62,35 3~,23 6~55 28,47 66,80 112.21 163°85 224, o15 292,39 347.79 397°19 4,4.3~89 492,17 541.65 591.6~ 642o52 696°14, 749°75 8O3,37 859,66 917°69 975,72 1034~00 1092°5z.~ 115],08 t206,21 48,67 50°01 51.25 47°75 4.1~17 29,44 12,59 11,14 35.80 64.51 98.32 137.70 ].86~59 24.1,~2 306e].8 379,94 466,05 566°70 658o91 742°58 823,4'? 907,10 992,80 1079.,40 116'?,51 1260°38 1353.25 1543~61 16z~4,12 1744.,63 t845°58 194'6.~8 204.8,37 2147~02 E E E E E E E W W W W W W W "'ir'"-ASUr>c:b D~°T~"t Ar`..``..`` OTHEc' DATA FOR EV'I::'RY E\,'?''' 0 ,.._ ........... .......... . :lC FF_ET OF S!.JF!. SEA "," ¢:,~, S U R F '.') V'-' ET I C" L S~ ~[-; r'.; D--'. T V D VEr,:'T I CAL DF. PTH D'E~'i'il $¢'A D:[FFERr-'' "-' . -,,",:Cc CC)R -. ~:. C T I C)i'., TOTAl,. 513¢ 52'33 5502 .5?5 '? .5912 6065 6220 6523 6673 6~!24 6975 7125 7277 7429 7'733 78[~6 8038 8190 8495 8648 8800 8953 9105 925 '? 9410 956:3 9716 9 ~ 5 9 10021 10169 3900° 3800° lOB6 50 1260,53 S 2245,~01 4000,, ~ q'"O, ........ 4100, 4000~ 1193 55 1370,79 S 2450~02 4200. z+l, 00. 1247 54 14.26~ 25 S 2954.32 4300, 42'00 ~ 1302 55 1481.70 S 2653~62 4400, 43.20, 1357 55 153'/~ 16 S 2762,-72 4500. 4400~ 1412 55 1592~62 S 2867~22 z+6OO, 4.500. 146.{, 54 164'4, !6 S 2972.40 4700~ 4600~ ..... 1520, ..... 54 16~,49 S ~077,64 4800. a7''~ ...... ....... ,;. 157~ 53 174~.37 S 3182,!~'' 49 C C) ~ z+ 80 r~ ·... ,. 1.~23 ... 5n .. 179 o, 94, .. 5000, 4900. 167~ 50 1896~9], S 33~36.86 5!00, 5000. 172z- 51 ].678,36 S 3491,54 5200~ 5100, 1775 51 1915~87 S 3597,06 53(.)0 ~ 5200~ 1826 51 195'q03B S 3702~58 5400~ 5SOO, 1877 51 1995,39 S 3S10~60 9500, 5400. 1929 52 2050.63 S 3919,04 5600~ 55C)(), 1981 52 2064~78 S 4028~16 5!00, 5600~ 2033 52 2096,47 S 4138,74 5800~ 5700~ 20.'86 53 21.i'.8,1S S 4249~32 59n0~ ..... =800, 2~p.~..: 52 2!5c:.~89 S 4359,~0.. 6000~ 5900~ 2!90 52 2191,59 S 6100, 6000, 224~ 53 222~,3C S 4561,06 620'0 ~ 6180, 2295 52 2255~0i S 4691,64. 6300, 6200, 234. R 53 2286,72 $ 4802,22 6400, 6~'~0._,,, 240a,., 52 231qe4~.. ~~c 4e1,2.80. 6500. 6:400, 2453 5~ 2350.1a S 5023.3r~ 6600. 6~00~,, 2505 52 238],o2 ., S 51.$3~ q4 . 6700~ 6600. 2557 52 2415.55 S 6BO0~ 6700, 2610 53 24.4.9,33 S 5354., 4-! 69'00 ~ 6800. 2663 53 2481~, 26 S 5455~40 7()00 ~ 6900~ 2716 5~ 251/+~26 S 5576~69 7100~ 7000~ 2769 53 254].~90 S -/200~. mlO(.)~, 2821 ~52 2~67~7°.~, ~.. S 5~(}0~4,..., . 7300~ 7200., .~8E, 9 .... 48 2~ 91.4~~ , S 5907 ~ 23 .... ~. _. ~;,.. T~ AND 'Fl", ':"- DATA TRUE: ~"~F.ASUr~ED \,ERTICAL Si.'5 RD-TV[) \:r:F<TICAL DE.~ '[ ?~ DEP i't4 SEA [) i F F E: R t'-_?,C L' CORI-;.t: C T i Ok 'r 0'i' A L COORD i ?,iAT'-S 1031a 7400. 73r'~' ...... ~ 291 41 10451 7500~ 74'30, 29,51 41 10597 7{'00 ~ 7500* 2997 a6 10743 7700, 76'00, 3043 46 l()E~ 7800, 7700, 308~ 11030 7900, 7300. 313C 42 11168 8000. 79'00. ~!6~ 1.1306 F!O0, 8000. 3206 38 1 la4.> R200, ~ ].C:O, 5242 .... , ,, ~., 11579 8300, P2(}O, 3279 37 11721 8400~ F. 3{)O ~ 3321 42 ]1~63 ~500, 8kO0, 33~3 12 C O 4 8600, , ~ .~ .'D 0 ·. 12!a2 8700. 8600, 3~42 38 1~295 8~OOG ~700. 348:: 43 12a35 8900. 8800, 3535 5C 125 fi 4 9 C 00 · ~'9 C) 0. B 52 z,. 4. 9 12736 9100, 9()00, 3636 52 12888 9200, 910'0. 368~. 52 13046 93C, 0. q2 .... 132.07 9400, 9300. 3807 6t 13363 9500, 9400, 3863 56 13519 960.0, 9500~ 3919 56 2617,77 S 2645,50 S 2672,7'3 S 2697°47 S 27!9.C) 1 S 273'z. g7 S 2757.60 S 27'i'9,02 S 28 O 6 ~ 05 ~' 28?,4.23 S 2659,11 S 2 F {~ 6.67 S 2914.23 S 2934,57 S 2959 · 54. S 2992,01 S ~ 024 ~ 4~ S ~06i. ! 7 $ ~C. 9~'~, 62 S 3141,25 S ~!06,30 S 3229~30 S 3272. O! S 6003 ~ 14 609 t:". , 30 6200 63 (.;-'.~, 0 6'rOd · 91 6506,19 6599,01 6690,81 677°., , 2 l 6869~35 7063 7199,22 7251,95 7350.66 7456.87 0 7563 · 7780.22 7894~g9 f~012,21 8124,23 8235,69 DFflTH .. 1©00 4900 .5 '~00 5000 VO00 800 '~ ~000 120O0 13r,,O~ V A L L.i E S F '" R E V FZ ;".~ v-'~ I '"" · ~.. ?;, L., [') ":: ? T r, 996, .1873o 2.5 '~ 32r'.'_,.. o 4557 o 52']6,, 58V5~ 657,,io 7186, 8597. 92.7! ~, 1 00~ S U E S E A F'" - 0"" " ,,,.L C",.,R [) I..._; . ATFS.. 149o97 S 3dO,1] 526°75 S 966'. 99 ,%91o20 S 159!~,2a 1265,69 S 225!+,92 1622,,!e S 2927,46 !925.65 S 3614,72 2!5!.97 S 4.~22,29 2359.99 5 505'7,76 ~5~-~,- 1° ~ 2913,a2 $ '?156,q0 3128,25 S 7860,98 :'.O~iDLETIO"4 REPORT JUNE. 5, 1974 _ _ . ~IL,~NTIC RICHFIELD OIL CO· TBLJ K-19 ;ELLY hUSHING' ELEVA7 I©~' lOG FY, ~ADIUS CF CURVATURE METHOD CF COMPUTATIC.",i -- :~REPA~ED.FOR ADDCO BY..F. "~, LINDSEY..AND ASSOC. I ___ --L'_ 7 :': T ..... tT-;'Lf:'L/.'-_-'A'-'-_ 7_ .... _'/-: i'__.. -'--. ........................................................ .... ..................................... ..¢.,EA5, D~I=T VERTICAL SUB DRIFT TOTAL COORDINATES .C L O S..U R F S ~EVFRITY_ _5.ECTLO..i.! )ER_TH ..ANGLE DEPTH ........ SEA DIREC DISTANCE ANGLE .__ DEG/100E. T .... DIS ,Ah._¢ ............. D ..... Y~ ..................................... D ..... 381 1..~5 380,98 ...... 59.6..1...20 .595.90 ._~95,?0 S3 75,89 N 51.04 E .,. 63.3 _..0 35 632,89 532 75,5! N 50,76 E ..... 723 3 30 722·82 . 622 77.03 ?4 ~7,95 E ..... 81_6. 5 ~5_.. 815,52 . 715 82,04 N 42,38 E _..90~ ....~ 15 902. 5 802 .. 86,55 ~-! 33,90 E ..... 935 '~ A5 934,50 83~ 90,77 N 29,72 E ....... 9~.7 10 30 . 99~,5¢ _ 89~ 9~,25 FI 20,16 E .... 1057 13 .0 1053,38 ... .953 95,95 N ..8,08 E .... 1.1.17_14.. 0.._11!1,72 1011 94,~6 F-! 5,84 W ._11.7.8 .15 ...0 ..... 1.!70,78 1070 9.0,40 N 20,42 W 1[ o._IV._IS.. 12~5,67 .... 1].45 139.6..22 .0 ......... 1377,50 .... 1'277 _15..~...26 15 ....... 15.44,47 .... 1~44 ._1830 33 45 .1761,59 ._2112 42 _.0.. 1984,!0 2304 51 ..... 15 ....... 2115,81 ..2401' 48 15 2178.48 2496 46 15 ....... 255245 0 2756 43 0 __29~4 44 0 3291 45 0 ..22~2,95 2289,12 2429.66 2565,03 2812,53 3182.76 1661 1884 2015 207~ _2!~2 2189 2328 2465 2712 3082 5,0CE · 89 N72,0OW ,82 F:51,00W ,52 N45,00W .PS N6C,00W ,50 N64,COW ,64 N76,00W ,38 N88,OOW · 72 579,00W · 78 S67,00W · 33 $5~,00W · 67 553,00w · 50 552.00w , z, 7_..553,OOW · 69 S55,00W .!C 555,00W ,el 555,00W · z, 8 $59,00w · 96 S59,00w . 12 559,O0W · ~6 S~0.~0k~ ~ · $60,,. · 53 S60.00~ · 76 S60,OOW 91,46 N 33 55 26 E _. 0,243 ................... 90,98 N 33 54 37 E ..... 3,167 .......... -.Z5.,15 90,7.4 N $1 .54 !0 E _ _4,049 .................... -_7.3,t,1 92,35. N 27 19._11 E_._ 2,549 .................. _. 94·82 N 20 56 51._E ......... .4,045 ..................... _"-6~_,J,~ 95,52 .N. 18 7 53__E .... 2,5.04 ................ --51.,2~ ... 96.39_.a~ 12 4 20 E 4,~%8 ................. ..._5.3.,.59 ....... 95,29 N ~ 48 55 E ............ 6.°4.85 ................. ,...~.3,,_11 95.04 N 3 31 .43 W _.5.682 .............. .-_2_9.._76 92.68 N 12 43 .59 W .5,_513 ................. 79.24 50.62 5.10 __ 68,60 167,82 247,7e 288.09 32a,01 348,31 416,70 481,41 603,02 794,71 8 1.87. _ r'L ............ 35...50 ..,W ...........89.: 24....N ...... 23 39,05 _76,35 135,67 237,!3 378,83 493,02 555,09 614,89 655,32 771,43 883,50 1094,13 1426,16 26.. Zf9 .it~ ..................... Y.,..1.~ ....................... W 88,34. N 26 14 18 W ._ 2.596 ......... W .... 9.1.61 N 55_27 5__W .......... 3,406 ....................... _.5.2.~.1:~ W ......... 135,77 N._.87 50 .4.0._W ............ 2..,.332 ..................... 12 .4.. , ...0 ,.:;n :~ 246,85 S 73 51 52 W .3..,028 .................. 2~ ..414.33 S 65-.6 24 W ........ 2,926 ............... ._.,~_14.0~ 551.79 S 63 625,40 S 62 .... 695,04 5~.62 742,14 S 62 876,79 S 61 1006,15 S 61 124~,30 S 61 1632,6~ S_~0 19 . 1 W ........ 4,818 ....................... 54.9,.., 34 15..W ........ 4., 314 ........... 52Z, 36 12 . 46 .W. ............ 2,105 ............. 6..9.1,_12 O 31_W ........... 1,894 ..................... _"L3.2., 73 3 7 ._.23 ._W ....... 1 · 08 7_ .................. .8_7_.0.. ,_9.. ~ 24 52 _W ........... 0., 532 .................. 9_9.S'., __ 8 20....W .............. 0 .. 2..8.s ................... ! 2.~ %._? 52 18..W .... --0,375 ............... 1 61-9-, 2.2 RECu,-:D OF ........... ALL__.CALCULATIONS PE:RF©RN~:j,F) BY SURV=Y B M ELECTR©NIC CO~,:PUTE-i ..................... ERUE ................................................................................................................................................. DOG_LEG ...... ~EAS, D~I_F.T VERTICAL .... SUB. _ DRIFT ...... TOTAL COORDINATES _C...L 0 S U R E S ......... SEvERIIY ............ SE.CII.3 OER_TH ANGLE ........ DE?TH ............. SEA ..... DIREC ........................... DISTANCE .__ ANGLE ..... DEG/iOOFT .......... DI.STAN~, ............. ? ..... U DEG. D_. ~ .S .......................................... I ..... __a{ ....................................................... ) 49 15 3500.47 3400.47 ~ ............ S60,00~'; ................................ 971,91.$ 1733.0'8 '~-'- 1~ ..... 47~_~9. 30 3770,03 .. 3~70,03 $60,00W 1129~02 S.. 2005,21 W 23 _5,07.1 4.8__],5 400~,B3 ..... 3904,83 _.5~2~0._~9___45 ~561,~1 4461.81 _ S62 ..6335-49 30 ~830,64 4739,64 S64 6%13 .48 1.5. 5079,26 ~979,24 S66 ..... 2148_.~.~ 30...5358,19 5265,1.9.. S69 .... 7.533..~8 45 5622,~7 ~522,~7 S72 _8123 49 .0 60!0,72 5910,72 S74 ...8..5.0~. ~9 0_ 6263,30 6163,30 9099 ~9 0 6651,C= 6551,C3 S74 .... 9339 49 ..... 0 6808,~9 6708,49 S73 ..... 9663 49 15 7007,63 6907,~3 S73 __985~..~9 ..... 0 7145,~1 .7045,51 $76 · OOW 1261,q4_$ .... 223~,25 W ....... 25 · OOW,. ~557.17,S.~ 2802,33 W 32 · 0CW.. 1710,69 S .... 30B4,01 W · ~.0t~ 1831,07 S 3342,0~ W ,00W '1955,4~ S_ 36~2,~ W ,00W .. 2051,97 S 391~,74 W · OOW 2181,E0 S ~339,73 W · OOW 2261,89 S ~619,0~ W · 00W 2384,~3 S, 50~7,79 W · 00W 2~36,28 S 5221,46 W · OOW 250~,~8 S 5~41.28 W · OOW 25~6,12 $ ..5595,01 W .35 38 48 55 ~7 ~9 01,21 S 60 37 6 .W ...... O,O6~ .......... 2280,9{:. 70,12 .S _50 36 ..21 W ......... 0,.407 ............ 254.3-_,..4f 10,78 S 60 47 ..... 3 W ........ 0,199 ................ 3.18.3.,._7'- 25,70 S 50 58 5& .W ........... 0,371 ............. 10,77 S 5t 16 58 W ....... 0,512 ............. 3~,14 S _51 ~5 i. 5._W .......... O.,521 .............~_10.7.,.9.~ 19,88 S 52 20 .20.W .............. 0,591 ........... .4395,5' 57,32 S 63 1~ 32 .W ....... 0,250 ................... 48_3.9,4~{ ~3,12 S 63 54.34..W ........ 0,000 ....... 5128,5i 82,80 .S .64. ~2 ~i W ................. O,0O0 ............ 5532,.3.':' 6t,8T _5.5~ .... 5g .~2 N'{ ............ 0,314 .................. 89,~7 S 65 17 35 W 0,082 ..... ~981.,.2f. ~T,10 S 65 31 52 W ........ 1,078 ................. !_01 z, 7 .!,o/"" 10k .3 10623 .1.0764 10.984 11~51 .115 ~ 0 .!.1700. ~5 15 8436,63 120~.1 45 0 . 8577,22 12212 43.. 0...8800,22' 12507 ~'8 O. g077,00 .12937 q9 0 9295,66 7276,72 _7176,72 $77 ~.7._3.0 .... 7338,64 7238,6~ 578 ~5.45 7407.32. 730.7.32 576 .43 ~5 7515,97 ..... ~!5,97 S73 .~.6__3.0 ...... 3673,30 2573,30'..._575 ...47 .... 0 7769,91 4615 _43 30 ..... 8125,48 ...~2. 45 .... 8262,97 ~2 15 8313,8~ · OOW 2581,35 S 5741.78 W ...... 6295,35. ,OOW 2596,37.S 5809,51 W 6363,30 .OOW 2612,72 S.~ 5880.33 W ..... 6434.,64 ,OOW 2641,50 S 5984,11 W 6541.19 ,COW 2685,05 .S 6135.99 W ..... 6697,76. .. 7669,91 $77,00W 2709,90 S ,6235.54 W 6799,03 7821.00 S79.00W 2743.14 S 6392,05 W. 6955.80 .8026,~8 S78,00W 2783,93 S 6592,53 W .7156,24 8162,97 S73.00W 2815.93 S 6716.25 W 7282.68 8213.94 STO.OOW 2830.72 S 6760,45 W '7329.17 .8336,63 S76.00W 2865.07 S 6872,81W 7~46.08 0577,22 S74,90'W 2927,61 ,S 7106.21 W. 7685.65 8700'22 S79.00W 2955,33 S 7221,67 W 7802.98 8977.©0 S73,00W 3023,43 S 7494.83 W 8081,68 9195.66 STI,OOW 3099,80 S 7729.87 W 8328,25 S S 65 S. 66 S 66 S 55 S 66 S 65 S 67 S 67 S 67 S S S S S 47 ~ 2 10 21 30 46 W .... 0,37_7 ......... 62..8.9_,_7_[: 9 W ...... 1., 793 ......... 535.8,1.- '3.7 W ........... 2,248 ......... 5.~30,C 56 W' I.~66 .................. .58 W ..... 1,402 ................. 6694,2? 39 'W ...... 1.100 .................. 62.9 '5,3ii' 24 W 0.7.36 ........... 59-52. 6 _ 22. W ......... 0 · 976 ........... :Z..i..5.4 ,_2 15 ll.W ......... 1,846 ..............32.81 16 48 W ......... 2.,998 ................. .~32.8.,.1 6.7. 22 .12 _..W ........3,121 ............... _7_~.~5., 2~ 67..36 33 W .......... 0,~2.0 ................ .75.83.,2 57 ~4 .38 W ......... 2,281 ........... ~8 1 50 W ....... le72.~ 8081 6~ ..... 8 5~ W ..... .0,552 ................. g32g,2~ ............................... RECOP..D OF SURVEY ......... t ........................ ALL CALCULATIO~'4S PERFO,R;'."ED 7, Y I B M ELECTRONIC CO?,qF;UTE;~, .................................................................. ............................... TRUE ......................................................................... .... DOG LEG ...................... .N~.EAS,__DRIFI~ .... VERTICAL SUB DRIFT TOTAL COORDI~NATES C L O S U R E .S .... SEVERITY ........... SEC'[.I.C .DEP..TH_._.ANGLE DE._P. TH . SEA DIREC .... DISTANCE __ ANGLE ._ DEG/iOOFT .......... DtST. A~"~ .............. D ~,~... ....... DEG, ................................. D bi S ' , ._13721 47. 30 9797.46 9697,46. 567.00¢2 3313,73 S 8292,76 W 5930.32 S 68 13 .... 7 W ' ...2,005 ................ 8g.3.3.,-3.~ L BOTTO>~ HOLE CLOSURE 8930.32 FEET AT S 68 . ............................................................................................................ ...................................................................... - ....................................................................................................................................................................................................................... .................................................................... !ASURED DEPT.M. AND OTHER DATA FOR _._ ~,'E.ASIJRED ........ VE'RT! CAL SUB ......... DEP.TH ........ DEP. T--i SEA EVERY EVEN 100 FEET OF SUE SEA DEPTH. ........................................................... ,'VlD-TVD _ VE.RT :[CAL .............................................. DIEFERENCE CORRECTION ..TOTAL .. COORDINATES .................................... 500 ............. 500,__ z*O0 . _ 0 _. 0 77,92 .N 49,76 E .............................................. 1- 600 600. 500 0 0 75.81 N 51.08 700 700, 600 0 0 76,36 N 49.00 F_ ............................................. 800 800. 7'00 0 0 80,98 IN ........:43,49 E ............... --'( 901 900, -q. O0 1 1 ............... 88.33 N 34,25 E ............................................ .......... 1002.. 1000 · 900 2 1 9 ~.~ · ,~,. 7. N 1~'~,26 E ......................................... '_ .!. ............. 1105 ....... 1100, ....... lO00 z+ ........ 2 ................ 9.5,34_N ........ 2,98 W .................... · 1208 ........ 1.200, 1100 8 4 .... 86.87 N ...... 27.61 W ._ -1313 1300, 1200 lB 5 .. 68.46 N 53,26 W ................................................................ la20 1~00, 1300 20 7 45,03 N 83,53 W ..... ~.~3o ....... ~oo.. ~4oo ~_9 ~ ..... ~,.~.~ ,'~~.7~, ~,, ............ i'"i.i'i.ii'..i'. ............................ F 1641 1600, 1500 41 12 11,96 S 1.58,54 W · . 1876 1800, 1700 76 19 83.67 $ 258,65_..W t ...... 2002 1900. 1800 102 26 126.86 S B20,~4 W .................................................... '~. ....... 213~ 2000. 1900 1~4 32 176.19 5 ~93.78 W ................................................ ... 2279 2100, 2000 179 45 236,80 S 477,B~ W .......................................................... 2z~33 2200, 2100 233 54 300,36 S 575,51 W , 2~77 2~00, 2200 277 44 ~53 76 S 664 41 W _ ~..'. 2716 2400, 2300 316 39 402,97 S 747,74 W ....... 29~9 ........ 2600, 2500 ~92 39 _ .498,45 S 913,02 W ......................................................... 3133 ................. 27.00,. _.2500 432 .............. 40 547,38 S ........997,76 W ...... ~15 2900, 2800 __ 515 . _ 42 .647.11 S 1170,51 ....... 3558 ..... 300.0, 2900 558 43 .... 698.42 S 125..9,37 W ............................................................ ........... 3703 . 3100, 3000 603 ... 45 ...... 750,69 S .. 1349,92 W ............................................................. L .......... ~8~9 ...... 3200, ~zoo 6~9 46 ..... 803,86 s ~4¢2,0~ w . '. .................. ~.~ " ~oo. ~oo ~ __ ,,~ ......... ~.4~ s ~.~ ................... ~,147 ...3400, 9300 747 50 914,96 5 1633,39 W ....................................................................... ................... .4299 ...... 3500. 3400 799 ............ 52 .............. 971,5~ S ....... 1732,43 W .............. 4~52 ....... 3600, 3500 852 53 ......... 1029,53 S 1832,87 W ................................................................ 4606 3700. 3600 906 54 _ 1087.93 S 1934,12 W ................ ................................................ _ ' 4_~60 .............. 3800. . 3700 .... 960 54 .......... 1146.48 S 2035,52 W .................................................... : ....... L ~EASURED DEPTH.AND OTH R. DATA ho . . --~ . - .. FY .... EVERY EVEN 100 FEET OF_SUb SEA.. DbrTH. ............................................................................ TRUE .................................................. .................. DEP.TH ......... DEPT?{ SEA DIFFERENCE CORRECTION TOTAL...COORDINATES ........................................................................ ............... 4913 ............. 3900., ...... 3800 1C13 .......... 53 ~. 1203,55 .......... 5063 4000, 3900.__1063 _.. 50 _ 1258,54 ...... 5214 ....... 4100. 4000 1!14 . . 51 . . 1313,23 5366. 4200, 4100 1!66 52 1367,84 5518 ...... 4300, . . 4200 1218 ..... 52 ......... 1422,66 { _5671 ................. 4400. .... 4300 1271 .......... 53 . ._ 1477.69 ....... 5~25 _4500, 4400 1324 53 . _ 1533.10 ............... 5979 ...............4600, ..... 4.500 .... 1379 ...................... 55 .......................... 158~.,23.S .......... 6133 ................ 4?.00, ........... 4.600 1433 ............ 54. ._1642.13 1488 ..... -55 1694,89 41 53 1745,72 94 _53 ......... 1794,22 44 . .......... 50 ...... 1840,39 6288 .. .4800, 4700 ......... 6.441 4900, 4800 ............. 6594 ........... 5000. 4900 .......... 6744 .... 5100, 5000 .... 6894 ......... 5200. ~!00 ................ 704_5 ..... 5300.._ 5200 7196 5400, 5300 ......... 73~7 5500, 5aO0 7498 5600, 5500 7650 5700. 5600 7~02 5800. 5700 ................. ~954 .... 5900, 5~00 · 8106 60~0, ..... 5900 "( 825~ 6100, 6000 8411 6200, 6100 ................ 8564 ............ 6300, 6200 .......... 87.16 .6aO0. 6300 ........ 8869 6500, 6400 ........ 9021 . 6600, 6500 .......... 9173 6700. 6600 ....................... 9326 ........ 6800, 6700 ............ 9478 6900, 6800 .................. 9631 ....... 7000. 6900 .................. 9784 ..... 7100, 7000 9~37 7200. 7100 ................ 10089 ................ 7300. ~200 15 15 16 1694 1'745 . _ 1796 18z, 7 1898 195C 2002 2054 2 106 2159 2211 2264 2316 236~ 2421 24'/3 2526 2578 2631 2684 2737 2789 ..... 50 51 .... 51 51 51 52 52 .:_ 52 .1884,.63 S 1927.36 S 1968,22 S 2007,01 S 2043.67 S 2078,77 S 2112,8~ S .2146,0z~ S 21-/~,25 S 2210,09 S 2241.71S 2273,53 S 52 53 ...................... 52 2305.16 S .... 53 _. 2336.94 S 52 ...... 2368,61 S 5'2 2400,37 S 53 ............. 2433,4]. S 52 2466.96 S 53 ......... 2500,83 S 53 ..... 25~2,8~ S 53 2561,05 S ........ 52 ....... 2587.23 S 2135 · 74 W ............................................... 2234,03 W ................ 2333,01 W .......................................... 24"".:z.60 W. .................................................. 2533,30 W ........................................... 2635,13 W .......... 2738,43 ~' ............................................................. .... 2842 , 19. W ............................................ 2946.41 W ........................................................ 3051,7~ w ................................................................ 3156,72 W 3260,57 W ........................................................... _. 3363,20 .W ................................................................... 3466,11 W ......................................................... . ~3570,63 W ...................................................... 3676.05 '^' , 3782.43 W ................................................................ 3889 · 74 W 3998 , 52 W 4107.74 W ............................. 4217,37 W ........................................... ', . ~327,~0 4438,39 W 4m4 . w 4659.61 W 4769.93 W .................................................... 4S80.77 W ................................................................ 4991.20 W 5101,43 W .................................................... 5212,08 W .................................... 5321,87 W ...................................................................... 5z+32.59 W ................................................................ 5543,83 5655,8~- W ....................................................................... 5767,62 W ~EASURED . . DEPTH AiND OTHER DATA MEASURED DEPTH 1037,9 1O518 10662 10808 10953 11097 11237 .11375 11511 11649 1].790 11931 12073 12211 12350 12493 1264.1 12792 12943 13098 13257 13416 13573 TRUE VERTICAL DEPTH 7400, 7500. 7600. 7700. 7800. 7900. 8000. 8100. 8200. 8300, 8400. 8500. .. _ 8600. 8700. 8800. 8900, 9090, 9100, 9200, 9390. 9400. 9500, ,.. 9600, 9700. FOR EVERY SUB MD-TVD SEA DIFFERP:%CE ._ .7300 2836 7400 2878 7500 2918 7600 2961 7'700 3008 7800 3053 7900 3097 8000 3137 8],00 3175 8200 3211 8300 3248 8aO0' 3290 8500 3331 8600 3373 8700 3411 8800 3450 8900 3493 9000 354.1 9100 35ql 9200 3643 9300 3698 9400 3757 9500 3816 9600 3873 E VEl 100 FEET OF SUB SEA ,VE~ T I CAL CO,RRFCT Iu:, TOTAL 47 42 40 43 47 45 44 4O 38 36 37 42 42 38 39 48 50 52 55 59 59 57 D~!' P T H · 2610,83 S 2637.05 S 2664.,89 S 2692,22 S 2717.0~~, S 2738.81 S 2758.86 S 2778.69 $ 2799,92 2826.43 5 2855.79 S 2880.80 S 2906.58 S 2933,67 S 2955.17 S 2975.41 S' 3000.49 S 3030,87 S 3065,10 S 3101.28 S 3140,99 S 3184,55 S 3228.85 S 3272.08 S COORDIhATE$ ................................................... 5 8 7 2 · 6 7 W ....... 5969,39 w 6063.24 W 6163.27 W 6267.02 W 6370,06 ~'~' 6471,51 W 6567.79 6699.92 W 6748 , 40 W 6838,10 W 6934,69 7031.27 W 7128,01 W 7221,00 W 7315,52 W 74.14,75 _. 7519.00 W 7626,48 W 7734", ! 5 W 7845 · 79 W 7961.51 W 8076.92 W · 8189.53 W RPOLATED VALUES FO,q EVt'_iI', 1000 TRUE ...... ~,,.; ~' r..Ir- ..... A..URE .:..,, VERT I CAL SUB DEP TH DE' P Tiff SEA ......... 1000 ............ 997, .. 897 .......... 2000 ...... 1898. 1798 . 3000 ..... 2505, .__ 2505 4000 330!, 3201 .... 5000 3957, 3857 ~,000 4613, 4513 "(' 000 . 527(?o 5170 8000 5929, 5829 ........ 9000 _ .. 658.6, __ 6486 ... 10000 724-1, _7141 llOOO 7932, 7832 _. 12000 8648. 8548 ..... 13000 ..... 9336, 9236 FE~I:. OF .. ~,'iEASURE D TOTAL COO DE'-OTH. · . 94,39 · 126.22 · 500.39 , 859,50 · 1235.63 . 1595.64 · 1914.82 · 2155.90 ' .... 2364.24 . 2572.09 · 2745.35 , 2919,67 , . 3115,52 RD I NATE$ 17 , 62 E 319.42 W 917.2a W 1538,3~ W 2192,88 W 2855,32 W 3539,38 W 4250,63 W 4975 , 97 W 5702,09 ~Ii 6403 · 38 W 7078 ~ 32 W 7774~95 W D~ RECT~O~AL , '. SU-~.VEY REPORT FOR ATLANTIC RICHFIELD COMPANY GYROSCOPIC DIRECTIONAL MULTISHOT TYPE OF SURVEY' SURVEY DEPTH: FROM Surface . FT. TO 4.13,600 ' FTe LEASE:, FIELD: TRADING BAY UNIT McArthur River.- WELL NO. K~19 COUNTY/PARisHKenai Peninsula Borough STATF Alaska SU-3'16851 DATE OF SURVEYL May 30, 1974 ~os NO. SU-3-16874 OFFICE: Anchorage, Alaska SPERRY'SUN WELL SURVEYING COMPANY ATLANTIC RICHFIELD COMPANY TRADiN'~--B'AY-'U~J'i'T '~ELL NO. K-19 MCARTHUR RIVER ALASKA ANCHORAGEt ALASKA .. COMPUTATION D~TE JULY 12,1974 :.~ PAGE DATE OF SIjRVEY_M_A.X' SURI~'i~'[--~;P, OSCOP[ C MULTISHOT SURVE JOB NUMBER SU-3-1687~ + 16851 KELLY BUSHING ELEV. = [00.00 F~.~, ZERO POINT* INCLINOMETER AT KEE TRUE SUB-SEA COURSE COURSE DOG-LEG " IOTAL ME n S UR-~'D- ..... -V E R T-I C A'E ...... ~-RTJ'CA L- .....i'~d [~-J~-A TI-ON-" 6 ~-R E CTI ON ...... -S'Ev E'~ ITY .... -R E-C T'~i d'O-~'AR .... C0-0R6 J~'/~'i E S DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IOO NORTH/SOUTH EAST/WEST VERTICA SECT ,IrP:, ( 0 0-~'00 -100o00 0 0 S O. 0 ii 0.00 0.00 0.00 50 49.99 -50.00 0 13. S 53.33, W 0.44 0.05 S 0.07 W 0.©' 100 99,99 -0.00 0 8 S 25.4.4 W 0.25 0.16 S 0.17 W 0.2:. i"50 ................. i"q §-~"-~ ~- .......... ~--~-~ "-9-9- ................ -~ ...... 'i"2 .......... ~'--2~'~~19" "~' ................... -0 .'i5 ..................... 0 "29" S ...................... O' ." 2 3" "W ....................... 0'. 3 .ii'. 200 199.99 99.99 0 15 S 14.27 E 0.31 0.48 S 0.24 250 " 249.99 149.99 0 33 $",33.87 E 0.65 0.79 S' 0.08 W 3,00 299.99 199.99 1 13 S 29.33 E 1.34 ..'1-45 S 0.31 E 0.2 350 349,97 2.49.97 1 14 $ 25. 4 E 0.20 2.40 S 0.80 E 0. I 400 399.96 299.96 ..... I 42 S 17.49 E 1.01 :3.59 S 1.25 E 0.2 4 5'0 .................... -44-9:94 ......................... 37+'~'":'~'~ .................. i- ........ ~ ...... ~ ......... ~'~'7 ~ .... ~ ....... : ................... 1,'~ 0': ........................ '4', 7 ~.'-'§ .................................. 1'" 5-1" E 500 499.93 3'99.93 ! 10 S 21.89. E 0.70 5,70' S 1.74 E 0.5. 550 549.93 449.92 0 45 S 27.85 E 0.86 6.46 S 2.08 E 0.5, ~ o o 599. ~'"~ ..... :"' .... ~'~:~-~§-'~- ......... O---SO- ........ ~---~'~+-,'"~'Y'"~ ................ . ....... 3=o0 .............................. '6;g 0-'-"~ ................. ~ -"'~o '"E' ......................... 650 649.91 549.91 I ~5 H 56.69 W 1.86 6.02 S 0.94 E 1.4". 700 699.86 599.86 3 11 N 49.94...W 2.92. ................ 4.71 .... S :. ....0.,_..7 5... . ~ ......................... 75"0 .............. 749'~'73 ............. 6:4"~-~"73 ....................... ~'"'""z~O' ............ ~'"'2"9".-17 W 2.96 Z.49 S 3.36 W .~ ' 800 799.5'2 699.52 5.' 50 N 51.18 W 2.36 0.43 N 6.88 W 6k. . 850 849.21 749.21 6' 50 N 54.59 W 2.13 3.74 N 11.28 W 9.0.:'.' ........... :"-~'0'6-- ........ -8':~"8 ';' 7' ?- ............. ~-Y9-~"~'7-? ................. '§- .... -2-'~+-'-: ......... ~-'-g'~','24--'~ .............. 3'::'~'2 ..................... ?"~'f'Y"-'N .......................... 16','94-"'w ........................ 950 948.19 848.19 9 4 'N 69.74. W 2.63 10.23 N 23.86 Id 18.2.: 1000 997.,46 89'7.46 10 30 N 79.14 W 4.28 12.46 N 32.03 W 2.4.9' 1 o s 0 ................... f o~+ ~"24 s' .............. ~ ~-~""4'5 ................ 'f~ ........... '3'2 ........... §'-'89','6'0' u 6; 0,4" ............. 13- 2 8 N 4'1- 93" 1100 1095.15 995.15 1.3 42 S 79.94 W 4.95 , 12.20 N 53.19 W 4.4.6" 1150 ' 114.3.66 '.1'04'3.66 ' 14 18 S 69.65 ~ 5.11' 9.02 N · 64.81 W '56.= 1'20.0 ............. 119[. 97 .............. 'i"0'9"i"'97 ............. -1'5 ...... 40 ............... :" 'S-'" 58.'50 ' W 6'"36 ................................ 3.35'"-N ...................... 76,36" W ........................... -69.4 1250 1239.88 1}39.88 17 33 S 52.82 k: 4.96 4.73 S 88.12 vI 83.3 . 13.00 .............. 128'?.34 ................. !.187,34 ........................ 19 ........ .5 .................... S...._51,29....~ .... 3.21 ..................... 1400 1381.07 1281.07 21 41 S 51.54 W 1500 1473.20 1373.20 24 2 S 51.84 W 1600 . 1563.55 1463.55 26 41 S 52.41 W 1700 1651.56 ........ 1'5'51,'5~ 30 ............ 0 ............ S 53"82 W ....... 14.39 S 100.50 W 98..4 2.60 36'11 "S 127.73 W i31.s 2.35 60.18 S" 158.21 W 169.2' 2.66 86.4'7 S 192.02 W 210oz 3.38 ......... i'14.9'3 S ..... 230.00 W ..... 256. ATLANTIC RICHFIELD COMPANY HCARTHUR RIVER ALASKA K-19 ANCHORAGEs ALASKA .. C o M-P-~i~'i-I JULY 12j1974 PAGE' 2 ' DATE OF SURVEY ~AY 30, 1974 SURW-EL~YROSCCpIC MULTISEOT-~uRvE'- JOB NUMBER SU-3-1687q + 16851 KELLY BUSHING ELEV, : 100.00 FT. ZERO-~CiNT~ IN'C['iNoMEiER-~'~--~B-~-' ,, TRUE SUB-SEA COURSE COURSE DOG-LEG .. TOTAL --NEA-~'Ug ED--'c ....... ~/E-RT ICA'i- ..... -Q ERTiC'A[ ..... INC[i NAT I ON:'-~'i RE CT'I O~ ....... S EVER I TY -" REC'TAN GU[~R---COORD I N~iE'$ DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION .......... .............. 1800 1736,64 1636.64 33 22 S 55.11 W 3.43 145,43 S , 1900 1818.43 1718.43' 36 52 S 55.80 W 3.52 178.0.B S 320.13 W 363.69 2000 1896.5.4 1796.54 ~0 25 S 56.77 W 3.56 212.65 S. 372.05_.W ..................... ................. 2100 ............. 1'97 O'j-7 0 ............ 18~'6";-~ 0 43--"~"~ ..........Y'"'5'6 Jg6-''W .................. 3,48 ................... 249. q6'-"S ................ ~28.12 V~ 490.67 ~2.oo 2o4O. ql ~9~o.~ ~7 ~3 s ~a.~ w 3.~ ~s8.~9 s 4se.c~ 2300 2105.27 2005.27 51 24 S 57.36 H, 3.69 329.96 S 552.02 N 635.82 ............... ~ : ...................................... ; .... : .................... ~ 2400 2169,78 2069.73 48 14 5'58. 1 W 3.20 370.80 S 616.58 N 711.03 2500 2237.82 2137.82 46 0 S 58.49 N 2.26 409.36 5 678.87 N 783.28 2550 2272'85 2172.85 ~5 · 3. S 58.25 N 1.93 4~8.06 S 709.25 N 818.47 260 o .................. 23'082~ '~'"~- ............. 2 z'6 ~'2"~ ~ ............. -4'~- ....... ~' ~ ............ ~'-'6 2. '3 o' "' ~"; ....... . ................ 6.52 ........... :-% 5' 37-s ............. 739,5 z" ~ 853" 0'4' .2700 2381.54 2281.54 q3 2 S 62.84 W 0.53 q76.9.2.S 800.30 W 921.24 2800 2.~.4,.~.~ ....... _2~_~.4.~}.~.___ 43 30 S 62.60 ~ 0..49. 508.33 S 861.21 ~ 989.51 29'60- ....... 252 6.67 ~ 2426.67 43 ......... :'--6'2'-2'3'-6-W .................... O"2qi .................... "5402'23"-S .................. 922',~'8 .... W .................. io'5"~"2-:o- 3000 2598.17 2498.17 q4 49 S 62.51 W 0.93 572.56 S 984.46 W 1127.90 3100 2669.00 2569.00 .45 0 S.62.3~ ~ .0.22 '605.24..S ................. !047-0q 3200 .............. 273'~..-69 ...........263'~"6--~ ............... .......~ ................ ~'"~2'.2'0'"W ..................... 0"11 ................ 638'16 S 1109.6q w 1268.5.q 3300 2809.96 2109.96 '45 40' S 62.70 w 0.72 671.06 S 11]2.72. w 1339.< 3400 2879.22 2779.22 46 . 40 s 62.59 w 1.00 704.20 S 1236.78 w j'~o ~ .............. 29'~"'8 '12'0- ............... 2 d~'d '2 '2 o ": ........ :'-"4"~ ........... ~ ........... ~-"-62" '~5- ~ .............................. 0 ,'~ 5i- .............. ~ 37.5'5 ..... s ................... 13 O l 2'04 3600 3017.18 2917.18 46 40 s 62.45 w 0.57 770.9:8 s 1365.26 w 1555.46 3100 30.85.27 298~.27 47 30 s 62.51 w 0.83 804.82 s 1430.20 w 1628.38 ,3800 3152.85 3052.85 47 28 S 62.'70"'W 0.15 .................... 838273 S 1495.64 W 1701.79 3900 3219.98 3119.98 48 12 S 62.64 ~ 0.73 872.76 S 1561.49 W 1775.61 ~000 .......... 3266. z,~ ..31e~.44 48 30. S 62.34 ~ 0.38 .~07.28 S 1627.76_~ ................... !8.5.0...~.~.I 4100 3352.3i ............... 3252.,'37 .................. 49 ............. O' ...... : ...... S'""62.~1 N ..................0,'.50 942'i-4 -S ............... ~i69~"37 ~ 192~.86 4200 3.417.4~ 331.7.6~ 49 30 s 62.42 ~ 0.50 977.22 s 1761.52 w 2000.29 4300 3482.32 3.~2.32 ..................... ~9 ......... 5.~ ........... ..... S..62.'15 ~ 0.~5 1012.69 s ...... 182~.03 ~ 2076.20 '-'~ .................. ~'4.00 3546.51 ............. 344<s.51 50 1~ s 61.89 ~ 0.39 1048.66 s 1896.75 ~l 2152.50 ~:' 4500 3610.35 3510 35 50 25 S 62.60 W 0.57 ... 1964.86 W 2229.10 1084.51 S 3739.58 36'39 55: 49-":'"3'5 ................. S 62.'84, w 0 11 1154.40 S 2100.56 w 2381.16 ATLANTIC RICHFIELD COMPANY --T~'ADING 'BAY- UN'! T ...... '~E-[-I_-'-No' 'K-19 MCARTHUR RIVER ALASKA SPERRY.SUN WELL SURVEYING COMPANY ANCHORAGE· ALASKA COMPUTATION DATE dULY 12_,1974 PAGE 3'- DATE OF SURVEY MAY 30, 1974 SURWEL GYROSCOPIC NULTISHOT SURVE JOB NUMBER SU-3-1687q + 16851 KELLY BUSHING ELEVo = 100.00 FT. ZERO POINT* INCLINOMETER AT KBE TRUE SUB-SEA ---~'~'~SU~E]I~-7~ .... VERTiC-AE ....... VERTICAL DEPTH DEPTH DEPTH COURSE I[-INAT 16N DEG MIN COURSE DOG-LEG DIRECTION ...... SEVERITY DEGREES DEG/IO0 TOTAL RECTANGULAR .... c-O0-RSI-N A-T ~ $- ......... NORTH/SOUTH EAST/V~EST SECTIOD~ 4900 3869.91 3769.91 48 55 S 63. 3 W 0.50 1223.43 S 2235.64 W 2532.3,~: 5000 3936.04 3836.04 48 17 S 6'3,.47. IN ...... .... 0.71 ............ 1257.19_...S .............. 2302.63 W ............. 26077.1C 5'i00' ............. /*0"02.-8-3- ........ 3902'8'~ ....... ~"j ........ 54 S 63.33 W 0.40 1290.51 S 2369.17 W 2681.30 5200 4069.68 3969.68 48 12 S 63. 4 W 0.37 1324.06 S 2435.54 W 2755.43 5300 4136.35 4036..35- .............. __4B____! 0_____S_..._63... 4.4.....W ................ 0...30 ........... 1'357.,6 2_..S ...........2_502 ,_09_w ........... 2829. 5~'0'~)- .......... :-'4.202".~/~ .............. 41'02.76 48 36 5.63.48 W 0.43' 1391.03 S 2568.97 W 2904.2,T 5500 4268.82 4168.82 48 43 $ 6.3.20 W 0.24 1424.71 S 2636.0.7 W 2979.13 5600 4-33.4-5.9 4234.59 .49 2 S 63.58 W 0,43 1458..45 $ 2703.41 W 3054.2,~ 57 cio ............... 43'9.9 ~ 71. ............. 4299 ' 7'i' ......... ] ...... --"~;~ ..... ~-2-"~ ......... $'i-'~'3', 93'' 'w ................. .0.72 ............ "1'492'0i ......$ ......... 2771 .'48 w ................3''129.9 5800 446.4.49 q364.49 49 3'3 S 64. 4 W ,0.18 1525.42.S 2839.94 W 3205.95 5900 4529.11 4429.11 49 56 S 64. 9 W 0.38 1558.80 S 2908.57 W 3282.1l 6000 4593.37 44.93.37 50 6 S 64.47 ~ 0.3.4 1592.05 S 2977.60 W 3358..5'!~ 6100 4657.24 4557.24 50 30 S 64,51 W 0.40 1.625.19 S 3047.04 W '3435.4£'. 6200 4721,11 4621,11' 50 7 S 65.61 W 0.93 1657.63 S 3116.81 W 3512.26 6300 ................ 4785'05 ............... 'Z~685 '-(~5- .... ~ 0"'"~']~- ..... -S-""65-~ 32- W ....................... 0.'35': ............. i-689.56'-S ............ 3186.75 W ........ 3589.0f~ 6400 4850.28 4750.28 48 10 ,S 66.36 W 2,35 1720.58 S 3255.88 W 3664.~ 65 oO .............. 9.9.16.~54. ............... 48 16 ,=5'4 ...................... _4. 8._..'._ _5_.0 ....... S__..6.._6_-_6_ 7_...W ......................... 0 ? 70.'. .............. 1750.43 _S. ................. 3324? 57~..W ................ 3739_._~ 6600 4982.45 '4882.45 48 42 S 67. 6 W 0.32 1779.97 S 3393.72 W 381.4.8'? 6700 5048.60 4948.60 48 29 S 67.79 W 0;59 1808.76 S 3462.97 W 3889.87' 6800 5114.69 501:4.69 48 46 S 68.41 W 0.54 1836.75 S 3532.60 W 3964.91 69'0'0 ................... 51'80;~5~ ................. 5080"59 .................... '48 .......... ~]; ............ -S'-"~8"-82 'iN .................. 0'. 31 ............ -ie64'"18 $ ................ 36'02.63 ............. 4'040':'i"1 7000 5245.62 5145.62 _ .... : ........... 7100 ............ 5309.87 ................. 5209.87 7200 7300 7400 : 7.500 · 7600 7700 7800 50' 5 S 68.26 W 1.36 49 58 S 69.60 W" 1.03 5375.31 52'75'3f ................... ~'~ ........ i'6- .............. ~-"-70 '-9~5'1~ 1'98 5441.76 5341.76 48 27 $ 71.24 iN 0.28 5.507.68 54"[37.68 49 4 S 71.42 W 0.63 5573.73 547-3.73 48 15 S 72.55 W 1.17 5639.42 5539.4-2 49 37 S 72. 0 W 1.42 5703.78 5603.78 50 16 S 72.i4 W 0.66 5767.82 ............ :5667.82 ................. 50 ............ 5 ................ S'--'72.15 '~ ...... O. 19 1891.97 S 3673.32 W 4116.06 1,919.52 S 3744.83 W 4192.6 1'945.04' S ............... :38'I'5 '98 1969.24 S 3886.68 W 4342.80 1993.31 S 3957.92 W 4417.8L,, ........ 2016.53 S. 4029.31 W 4492.7,:;. 2039.49 S 4101.12 W 4567.87 .. 2C63.05 S 4173.9~ W 4644.19 2'C86.60 S 4247.04 w "'4720.7 SPERRY-SUN INELL SURVEY ATLANTIC RICHFIELD COMPANY --TRA'D-~NG'-'-BAY--'uNII=---WFLL NO. K-19 MCARTHUR RIVER ALASKA 'ANCHORAGE' ALASKA .. COMPUTATION o~T-~ JULY 12,1974 PAGE '4 ' DATE OF SURVEY MAY 30, 1974 SURWEL GYROSCOPIC MUL'TISHOT SURVE~ JOB NUMBER SU-3-I6874 + I685I KEL_Ly_ B U_SH !_._N G__._E L_E V._,_.__--__ _!O0_._O_~__.F.~_.-_._. ZERO POINT* INCLINOMETER-AT KBE TRUE SUB'SEA COURSE COURSE DOG-LEG ............... ..: ..... ]'.O_T_AL ......................... MEASURED VE RT-I'c~'~- VERI=~CAl' .... ~ ~-~-~-i-N"~i' I--[~-~--'--o i'-R'E C T-I 0 N .... SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG NIH DEGREES DEG/iO0 NORTH/SOUTH EAST/~EST SECTION 7960 5~-i-:'-76 57-~'~-~6 50 25 S 72.38 W 0.38 2-~-~)'-6-~---S- .........-~-~12-0'~-27 w 4797~-~ 8000 5895,6,5 5795.65 50 10 S 72,43 W 0.26 -2133.27 S 4393.60 tN 4874,09 8100 5960.21 5860.21 49 25 S 72.63 W . 0...76 2156.20 S 4466..44;_...W ............... ~95.0._,.20.. .... 8200 ...........6'~2'5.3'7 ................. 5;~-2'5'~'37 49 15 S 72.69 W- 0.18 ...........2178.81'"S .......... -q'538.84 W 5025.77 8300 6090.87 5990.87 48 55 S 72.85 W 0.36 2201.19 S 4611.02 W 5101.05 8400 6156.36 6056.36 49 15 S 73.,16 W 0.41 2223.28_S ......... 5683.28,_w ............... _5_1..%6_.___~ 85'00 ........... ~2'~;[f~:~)-- ........-(~'i2'1'~"~0 .............. 4-6 ......... ~'~ ...... '~'""':f~'; 3''W ................. 0-67 .....'"~ .......... '2'245..42 S .4756.13 ~ 5252.10 860'0 6286.14 6186.14 49 .5 S 73.68 W 0.97 2267'.'20 S 4828.98 W 5327.78 8700 '6351:02 ........... .62.51.02 ..............5_0_ ................ .0...__ ...... ~_.7..~3~ ! 8 ..W 0.99 ...... i] 2.288~90.. S ............. ..4901.,90 .._W .............. 5403....49. .......... 8'8'00 ............ 61~i"5.77 6315.77 49 18 S 73.10 W 0.70 2'311.00 S 4974.83 U 5479.37 8900 6430.76 6380.76 49 38 S 73.81 W 0.63 2332.6.4 S 5047.69 W 5555.00 9000 6545.56 64~5.56 49 35 S '73,29 W 0,~0 2354.21 ,S 5120_,73 W ................ 56_30.:~7.. 9100 -'66--i'~)',-45 .....~-5"~-6"'-4-~ ....... ~-9---3'6 .............. ~--$"~'i*-'79'- -W ............. -0;'~9' .........2-3~-5;7'7- ~ ................. 5'193.7o w . 5706.47 920:0 667'5.50 6575.50 49 20 S 74.3'3 W 0.44 2'396.63 S 5266.72 W 5781.96 9300 6740.67 6640,67 ................ :~...9.. ......... 20 ............... ~__7.3.,_96 .W .................... 0.28 .............. 24.17.35 S ........... 5339.69_W ............ 58..57,..3~ 9400 .......... 6805'74 ......... -6705.74 49 28 S 74.28 W 0.28 2438.12 .S 5412.72 W 5932.80 6870,93 6770.93 49 10 S'74.59 W 0.38 2.458.47 S' 5485.77 W 6008.[ 950O 9 6.0 0 ............. 693 6.....2_.6 ........... _6._8__a..6__? ~.6 49_ _;_!.5_ ......... S.__7...~, .4_,~..... ~ ................. O-16 ................. .2..4. 7.8.- 69 s ................ 5.5 ~.8 ,.7 2 _.'u ..................... 6 0.83.,3' 9700 7001,33' 6901.33 49 34 S 74,62 W 0.35 2498,95 S 5631.91 W 6158,71 9800 7066.23 6966.23 49 30 S 75,23 W 0.~7 2518.74 S 5705.37 W 6234.20 '9900 , 7131.45 70'31.45 49 5 S 76,31 W 0,92' 2.537.37 S 5778.84 W 6309.26 i 0 000 ................. :?-1'9~--g-7 ........... 70 %:"6-/ ..................... ~"9 ........ -3'6. ............... iS-'75, ~ o, s 3 2 555- 5 9 s ....... ..... 5 ~ 52 .'Az w .............. ~ 3"~ 41'2 7' 10100 7261.80 7161.80 49 13 S 75.44 W 0.44 2574.38 S 5925.94. W 6459.43 10200 7328.37 .7228.37 47 18 S. 75.33 W 1.91 2593.21 S 5998.13 W ................ 6533-37. .... i0-30© ....... .'"'"'7397,'82 ................... 7.:2'9'7,8~ .......... - ......... ~4 ....... ~3- ...................... 5I'-7~'.'81 ....W ................... 2.-80 .............. 2612'32"'-'S ................. 6067.47 W 6604.80 10400 7469.01 7369.01 44 30 S 71. 6 W 1.94 2633.51 S 6134.40 W 6674.77 ..................... I. 05.00 ......... 7539,97 ................ 74 ~'9 - 9.7 ..................... 45 ............... 5 ....................... S.._..7.2,58_ W .......... !, 22 ... 10600 7609.96 7509.96 46 ' 5. S 73.51 W 1.20 10700 7678.36 7578.36 47 3'5 S 74. 6 W 1.55 10800 7746.51 ......... 7..6.z:.6,.51 .................. 4_6 ...... 30 ........... S__...75. 8.W 1.31 ........................ 10900 7815.24 7715.24 46 40 S 75.83 W 0.57 2655.48 S ....... 6201.33 W .......... 67~45.0~ 2676.31 S 6269.65 W 6816.16 2696.67 S 6339.68 W 6888.69 . 2716.14 S 6410.22 W 6961.3.5 2734.38 S 6480.53 W 7033..3~ SPERRY-SUN WELL SURVEYING COMPANY ATLANTIC RICHFIELD COMPANY -¥R-~'D'ING'-B-~Y 'UNIT--WELL NO. K-19 NCARTHUR RIVER ALASKA 'ANCHORAGEs ALASKA .. COMPUTATION DATE JULY ' 12,1974 PAGE 5 DATE OF SURVEY?AY 301..1974 S'Uk'~/E-J~'"'~YROSCOPI C MULTISHOT SURVEY JOB NUMBER SU-3-16874 + 16851 KELLY BUSHING ELEV..= 100.00 FT. ZERO POINT* INCLINOMETER'AT KBE TRUE '-~E AS t~l~D v E-R TI CA-Ii DEPTH DEPTH SUB-SEA COURSE COURSE ' DOG-LEG TOTAL V ER-T'I~-A L I NC L I NAY I-O-~q--D-~ R ECT iON---SEVER I IY RECTANGULAR COORDINATES VERTICAL DEPTH DEG MIN 11000 7883.91 7783.91 iIlO0 7953.63 7853.63 11200 8025.26 7925.26 11400 .8170.53 8070.53 1.1500 8244.1B 8144.13 46 35 45 0 43 30 43 30 43 10 42 5 DEGREES DEB/lO0 NORTH/SOUTH EAST/WEST SECTION · S 77.39 W 1- 13 27-~i-'~-:~'-'-~ ..........~i~-~i-~--2'3--~ ........... S 76.32 W 1.76 -2767.51 S 6621.03 W 7175.92 S 74.-.,3 W , 1.99 2785.10 S 6688.54. W ........... __72_4.5~..Q7___ S 73.74 W - 0.47 2803.98 S 6754.73 IR 7313.48 $ 73.14 W 0.53 2823.54 S 6820.51 W 7381.77 · S 68.22 W 3.50 2845.90 S 6884.38 ¥1 7449.36 11700 8389.47 8289.47 45 25 S 69.66 W 2.46 . 2895',16 S 7012.56 W 7586.64 ............. 1!,8 0 0 ............... _84 59.--...~. :Q.. ................ ~ 359.'3 O--: ................ 5.6 .......... ']..0--' ........ .S .... 6~ .78 .!.~ W ...................... O, 59 ............29.19.9 5.... S ......... .707 70. W 7.6.58,. 1..8_ ..... 11900 8529.08 8429.08 45 30 12000 8599-48 8499.48 4-5 0 12100 86'7'0.75 8570.75 4.4 5 12200 8743.00 ...8643.00 .43. 23 12300 8815.41. 8715.41 43 :. 50 S 71.42 IR 1.25 294'3.73 S ..7147.26 W 7729.71 S 71. 4 W 0.57 2966.58 S. '7214.50 W 7800.60 i S 71.28 W' 0.93 2989.23 S 7280.89 W 7870.62 ; S 72.94 W 1.34 3010.47 S 734.6.66 W 7939.54 ! S 70.38 W -1.82 3'032.17 S 7412.11'IR 8008.34 124.00 8886.73 8'786.73 415 10 S 72 20 W 1.84 3054 64 S 7478 49 W 8078 28 ~ ................ ~ ' e e .......... 12500 8956.08 8856.08 47 0 S 71.22 W 1.96 ' ' 3077.25 S 7546.87 W 8150..1~. : 12609 9023.58 8923.58 48 5 S 70.98 W 1.09 310I..15 S 7616.67 ..W 8223. 7( . _!. 2].7.. 0.0 .......... 9.08.9-.~.6_ ............... .8._9...89.746 ................. .4_9._ ..... 30._..: ........ S ...... 69.? ~! ~ ..................... 1.79 ............ 31.26.58 .......S .............. 7687.46..~ .................. 82.9.. 8.-73_ ...... 12800 9154.90. 9054.90 48 45 S 70.74 W 1,~19 3152.29 S 7758.56 W 8374,48 12900 9220-61 9120.61 49 5 S 71...4 W 0.4'0 3176.97 S 7829.78 W 8~49.74 ' ...... ~3000 .................. 9.28 5.,.6.1 ................. 9!85,6! ........................ 49___.:5_0 ............... S......~9. ~4...W 1.43 ................. 3:202.66_ S ................ :..7901 ' 29 W 8.525:.66 ..... 13100 9352.57 9252.57 46 5 S 67.66 W 3.97 3229.78 S 7970.40 W 8599.89 13200 9421.66 9321.66 46 30 S 65.50 ~ 1.61 3258.51 S 8036..72 W 8672.15 ' .. . 13300 ............ 94.90.13 ...............9.390~.13. .................. ~_7 .............. ~ .............. S._:.92-13 W 2.52 .................. 3290.67 S' 8102.09 w 87:~.4:.8:3 ........ 1'3.400 , 9558.75 94.58.75 46 15 "S 62.39 w 0.85 3324.'53 'S ..............8166.47 w '8817.23 13500 96'25.71 9525.71 49 40 S 63.87 W 3.58 3358.06 S 8232.71 W 8891.24 13600 9690.82 959'0.82 49 5 S 62.80 ~ 1.00 3392.12 S 8300.54 W 8966.90 :,. HORIZONTAL DISPLACEMENT = 8'966.90 FEET AT SOUTH, 67 CEG. 46 MIN. WEST .......... THE ..... C'~[c u ["AT I oN P R-C, C'-E'DU t~'~ S'--A'~E- 'i~-A--S-E-o---~i'~-':f H E-I]'S-E'-'6-F' Ti:iR E'E-' D I MEN S'i"~N A,L -' R A ~I uS .... c F ...... CuR v ~ T U RETM E :["~ ~D i~' ................ ATLANTIC RICHFIELD COMPANY --'j'RA'DING"'BAY UNIT'--I~]E-I~'L--'No. K-19 MCARTHUR RIVER ALASKA SPERRY-SUN ANCHORAGE,,, ALASKA JULY '12,1974 ALASKA PAGE 6 gATE OF SURVEY MAY 30, 1974 -suRWEL GYROSCOPIC 'MULTI sHoT'--S'O~-{)(' JOB NUMBER SU-3-16874 + 16851 KELLY BUSHING ELEV. : 100.00 FT. ~-E R-O-'-~-D I-'-NY *'I NC LiN'oRE T-E R" 'AT -' k-B-E ....... KELLY BUSHING ELEV. = IO0.O0 FT. INTERPOLATED VALUES FOR EVEN '1000 FEET OF MEASURED DEPTH .. . . · . . , TRUE ' SUB-SEA TOTAL .. MEASURED VERTICAL VERTICAL RECTANGULAR COORDINA'TES MD-:TVD VERTICAL DEPTH DEPTH ' DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 0,00 -.100.00 0.00 0.00 0.00 ___!000 ............... -.99_7...' 5 6. ............. 8,97_~ ~6 ....................... .!_.2_-_56____N._ ............ .3..2.03., W 2..5 3 20'00 1896.54. 1796.54 212.65 S 372-05 W 103.45 100.91 3000 " 2.598.17 2.498.17 572.56 S 984.46 W 401.82 ', 298.36 4000 3286..q4 3186.44 907.28 S 1627.'76 W 713.55 311.73 ' 5000 '3936.04 3836.04 1257.19 S 2302.63 W 1063.96 350.40 6000 4593.37 449~.~7 1592.05 S 2977.60 W 1406.63 342.66 ......... 7_000 .............. 5245;62 ........... }!,,4 5.,..6 2...; ............ 189.! ? 97,....S ................. 36 7.3.32 .~ 17.54.., 3~_ ............... 13000 ........... 9285.61 .. 13600 9690.82 8000 5895.65 5795.65 2133.27 S 4393.60 W 9000 6545.56 6445.56 2354.21S 5120.73 W 10000 .............. 7196.67 ................ :70,96:,67. ...... ................... ................. 5852.42. W 11000 ' '7883.91 ~783.91 2751.22 S 6551.23 W 12000 85'99.48 8499.~8 2966.58 S 7214.50 W 9~'85.61 3202.66 S 7901.29 W 9590.82 3:392.12 S 8300.54 W 2104.34. 349.97 245,4.43 350.09 2803.33 348.89 · . 3116.08 312.75 3400.51 284.43 3714.38 313.87 3909.18 194.79 THE CALCULATION PROCEDURES ARE BASED'GM THE USE OF THREE DIMENSIONAL RADIUS £:F CURVATURE METHOD. ATLANTIC RICHFIELD COMPANY TRADING ~iAY- UNI'T ..... ~-E-L-~-NO. K-19 MCARTHUR RIVER ALASKA SPERRY-SUN WELL SURVEYING CON. PANY PAGE ANCHORAGE, ALASKA DATE OF SURVEY MAY 30t 1(974 --COMPUT-A-~'i'-~--D~TE ............................. SURwEL -G'YROSCOP I C MULTI SHOT JULY 12,1974 ,IDB NUMBER SU-3-1687q + 16851 ................................................. KE.LL_.Y._'_BU_SHI_NG___ELEv . ...: 10_Q: Q_O_.._.FI' ZERO POINT* INCLINOMETER AT KBE TRUE SUB-SEA TOTAL .-'. _M EA].s_.u.R E_D. ................... ~_E R~ ICAL ........... _v.. E_R_'.T !. ~..A__I.= ....... R_E.. C. _T._AN. Gu L.A R__C__O .O_R D ! NAT E S ............. M D-.TV D ................... V.E RTIC AL DEPTH DEPTft DEPTH .NORTH/SOUTH EAST/INEST ..DIF'FERENCE CORRECTION ' 0 0.00 -100.00 0.00' 0.00 0.,00 0,00 , ~ 100 ' 100.00 0o00 0.16 S 0.17 W 0.00 0.00 200 .............. 20 0..00 .................]9~.,_00 0.48 S 0,,.2~'.. U ................... Q.O 0 ............................................ g.. 00 300 300.00 200.00 1.45 S. 0.31 E 0-00 0.00 400 r 400,00 300,00 3,59 S 1,25 E 0,03. 0,02 500 ..................... 50.0.,00 ................ 59..O,...t.g.~ ....................... _ ..... 5.,~,79.......S ........................ 1,,74...E 0.,06 9,02 .......... ' ' ~oo ~oo. oo 5oo.oo ~.6o s 1.9o E 0.0'7 0.01 .?00 700.00 600.00 4.7.0 S 0.76 U " 0.13 0.:06 800 8oo.oo voo.oo o..4~ N ~.~ ~ 0.47 o.aa :~'6"i .............. ~ ..... eo'o','o"6 .............. ~6'6"~'0'6 .................. ~ .... : ...... ~'2"~'-"~ ......................... i7;'lO-'U ............................ 1,2'3 .................... ~ ..... 1002 1000.00 900.00 12.53 N 32. __ .............................. 110t 110 O.O O ........... ! 000., 0.0 ! 2,..00..N ................. 54' 1208 " 1200.00 . ' ,1100.00 2.17 N 78~ ,. 1313 1'300.00 1200.00 17.17 'S 103. 1420 1400.00 1300.00 40.79 S 133. 1529 1500.00 1400.00 67.70 S 167. ... 1641 1600.00 1500.00 97.89 S '207. 1756 1700.00 1600.00 131.93 S 253. 52 W 2.58 1.34 35 W .~.99 2.40 28 W 8.3'3 '3.34 97 W 1'3.4.1 5.07 62 W 20.36 6.95 B1 W 29,.44. 9.07 013 W 41.03 11.59 58 W 56.49 15.45 .. SPERRY-SUN WELL S-0~'~'~'¥iN~---C-q'M'P~Y ..... -: ............................................................ PAGE ANCHORAGEt ALASKA ATLANTIC RICHFIELD CONPANY DATE OF SURVEY MAY 30, 1974 ~-T R-AD I NG'- BAY' UNIT ..... ~-E'L[-"NO-;'--K'="i'~- .................. ~i]iM'POT A'Tj O'NTM DATE ........................... SURwE[ 'GYROS COP I C MUL T I SHOT ..... MCAR'THUR RIVER JULY 12,1974 JOB NUMBER SU-3-16874 + 16851 ALASKA KELLY BUSHING ELEV. = 100.00 .......... Z'ER 0'-po i'NT, '- 1-NC k'-I -N oM'E T ER-'- A T---KB £: INTERPOLATED' VALUES FOR EVEN 100 FEET OF 'SUB-SEA DEPTH TRUE SUB-SEA TOTAL ..' ." '.'. ME A.S U RE,D_ ............... y E...R TI C :~.L_ ............ _~E.,R_T I C.A_L ......... R_EC.~..A._N.G U L A R ....... C, OOR D I N AT E $ ........ RD--.TVD'· ................... V E_R'!.!_C.._/!.L ................................................................. DEPTH D.~PTH DEPTH NORTH/SOUTH EAST/~jEST DIFFERENCE CORRECTION . , 1.8.7.7 ............ .! _80 o. ,_ 09 ............ !. 7. O_o. t_.O.o_. ........................ !,7_.o.,.. 37..... s ..................... } o 8..,. 8 9..u .......................... 77, o 9 .............................. Z. 0,59 ............................................................. 2004 1900.00 1800.00 21.4.28 S 374,54 W 104.56 27.46 2141 2000.00 '"' 1900.00 265.35 S 452.33 W 141.20 36.64 22_9_!_ ........ 2.1.0 O- ,0.0. ............ 20_o_o:.,..Q O_ ......... _,3_2_6_._~.{~___S. ......... ...5_5 6,_..54.__w...' ................. 19.1.61 ....................... 5.0, 244.5 2200.00 2100.00 388.63 S 645.15 ~ '2~5.24 53.62 2587 2300.00 2200.00 4.41.40 S 732,21 W 287.98. 42.73 2725 2400.00 2300.00 .484.78 S' 815.62 W 32.5.24 37.25 ' 2862 2500.00 2400.00 '528.34 S 899.75 W 362.99 37..75 3002 2600.00 2500.00 57.3.40 S 986.06 W 402.56 39.5'7 3 !4:3 ................ 2.70.0. _,_.g_O ................. ._2.60.._O_~...O0 .................... ._6.~..9._...~.6_.4_.,_S .................... !...074- 49 14 ...................... .~ 4 3,84. Z+ 1., 27 ............................................................... ....................... 3721: ...... 3 loo. oo ."'=-:".'-30Oo. oo 3870 3200.00 3100.00 4020 3300.00 3'200.00 .4172 3400.00 '3300.00 4327 3500.00 3400.00 ~q'83 3600.00 3500.00 3285 2800.00 2700.00 666.38 S 1163.65 3430 ' 2900.00 2800.00 714..3.4 S 1256.34 3574 3000.00 2900.00 762.56 S 13.49.11 912.24 S 1444.46 862.49 S 1541.64 914.39 S 1641.34 96'7.65 S 1743.20 1022.49 S 1847.59 1078.7Zt S 195'3.74 -.' 485.73 41.89 530.28 4/,. 54 574.95 44.67 621.7S 46.83 670.02 48.22 720.46 50.44 772,82 52.36 827.4.3 54.61 · .- 883.74 56.30 ATLANTIC RICHFIELD COh',PANY ' T'~'ADING BAY 'UNIT ..... MCARTHUR RIVER ALASKA S ~-E R~-~' ' --s-U-N- -~ E L-[---S UR V ~ Y I N~"- ~0 M ~ AH Y ..........~ ......................... ' ............................................ PAGE ANCHORAGE, ALASKA DATE OF SURVEY MAY 3.0, 1974 COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT-'~-g?' JULY 12,1974 JOB NUMBER SU-3-16874 + 16851~. KELLY ·BUSHING ELEV. - 100.00 F -, ZERO POINT* INCLINOMETER AT KF~ INTERPOLATED VALUES FOR EVEN 100 FEET OF , . "TRUE SUB-SEA TOTAL · MEASURED . "VERTICAL VERTICAL RECTANGULAR. COORDINATES .... ~j'E'PTH-- ................... = ....... DEP'T H ............................ OEP-TH ............... NOR Ti:iTSOUTH ............ EAs T/WE ST SUB-SEA DEPTH 4000.00 1339~42 S 2465.77 W 4100.00 1389o62 S 2566.16 W 4200.00 144'0.72 S 2667.80 W .............. 4300'00 ...................... i~'92"i6-"'~ ............... 2771.78 W 4400.00' 1543.6.8 S 2877.46 W 4500.00 1595.47 S 2984.76 W. 4600.00 1647o20 S 3093.80 W 4700,00 1697,10 $ 3203.16 W 4800.00 1742,93 S 3.307.19 W ,. ~D-TVD "' 'VERTIC D'I FFERENC' E ......... C'OR R~'CT .'938.97 55 993.04 54 1045.75 52 1095.717 .............................. 50 1145.48 49 1195.81 50 1247,27, 51 1300,.44 53 1354,79 54 4638 3700,00 3600,00 1133.18 S 2059,23 W 47~3 .................. ~8~0'~"0-.~ ................. ~-~ ~'0 ~'0~ .................... 'i"~8 ~'~'~5-~ ..................... .'21:63,'54 W 4945 3900.00 <- 3800.00 1239,04 S 2266.37 W 5095 4000.00 3900.00 ]1289,11 S 2366.37 W 5245 4100.00 5395 4200.00 55.47 4300.00 5700 4400.00 5854 4500.00 6010 4600.00 6167 4700.00 6323 4800.00 64.74 4900.00 . 6626 5000.00 4900.00 1787,76 S 3412,11W 162'6,58 5100.00 ' 5000.00 1830.58 S 3517.01 W 1677,70 14.10.33 55 1467.07 56 1523.43 56 1574,86 51 51 · 51 3623.28 W 1729,44 51 3733,81 W 1784,65 55 3842.14 ~ 1837,08 52 3949.52 W 1888.27 .51 6777' ................ 6929 ......... 5200.00 ~100,00 .......................... !8.72.1S S 7o8 53oo.oo 52oo.oo 1915.42 s :' '7237 5400,00 5300.00 195.4.06 S 7388 5500.00 5400.00 1990.49 S AL , ION ,07 .70 .71 .46 ........................ .16 ' - .34 .54 ,74 ,36 .42 .71 '12 .74 .20 .42 .18 ATLANTIC RICHFIELD COMPANY --~R-ADiNG 'B'-AY-' UNI'T ..... ~L-[--NO, K-19 · MCARTHUR RIVER ALASKA SPERRY-SUN WELL SURVEYING COMPANY ' .PAGE 10 ANCHORAGE, ALASKA DATE OF SURVEY MAY 30, 1974 COMPUTATION DATE SURWEL GYROSCOPIC MULTISHoT---~UR~" JULY 12,1974 JOB NUMBER SU-3-16874 + 16851 KELLY ·BUSHING ELEV. = 100.00 F~.' -' ZE~RD--PoINT~ iN-cI"INo~-E'i:ER- AT-'--'K-~-t. , INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T R U E S U B- S E A TOT A L ' MEASURED ·VERTICAL VERTICAL RECTANGULAR COORDINATES ND-TVD VERTICAL --~ ~. P'T'[J- ............................... DE-PTM .................. D E-P-i=~t ........ NOR~ H/ S"D-Ui~ F~ ..........TEA-ST /WEsT ...... D'I FF E"R E N'~'-~- ........... C'O'R'R ECT iO-N ........................................................ ............. 27.539 .............. _5600: o O: .............. 5.5.0,.0 ,,0, o ....................... ,202 :~ ;,.3,6_..._ $ ................. .4..057....,3 8 w ................ 19'39,4.4,..: .............................. 51.. 16 7694 5700'00 5600.00 2061.66 S /,169.61 'W 1994.08 54.6.4 7850 5800'.00 5'700.00 2098.3'.9 S 4283-69 W " 2050'18 56.09 8 0.06_:. ............ 59 0..0.. 00 ........ .5_8_00..,.~ 0.__..: ......... ~.! ~.~...8_5_., s_ .......... 5_ 3? 8.56__._W_ .................. 2 i 0 6.7 ~ ......................... 5 6.60 ..................................................................... 8161 6000.00 5900.00 2170.04. S 4510,73 W. 2161.12 54.34 ,8313 6100.00 '6000.0:0. 2204.28 S 4621.02 W 2213.89 52.76 8467 6200.00 6100.00 2238.06 'S 4732-03 W 2267.07 53.18 8621 6300.00 6200.00 2271.69 S 4844.32 W 2321.15 8775 6400.00 6300.00 230.5.67 S 4957,29 W 2375,81 8929 6500,00 64,00.00 2338,95 S 5069.4,2 W 2429.70 9083 6600.00 6500,00 2372,35 S 5181.95 W 2483.90 9237 6700,00 6600.00 , 2404.33 S 5294,1'7 W .2537.59 9391 .................. 6800;00 ............. 67.0,0..,,.00 ............... 2436.,30.,.....S ................... 5406.,25 W 2591, 15 9544 6900.00 6800.00 2467.41 S 5518.19 W 2644..45 53.29 .9697 '7000.00 6900.00 2498.54, S 5630.40 W 269'7.95 53.49 ............. 9.851 ............. 7100. O0 ............ 7_000..00 ...................... _2.528.: 7.2 S ................ 5743. W ......... 2751.9,4 53.99 10005 .7200.00 7'100.00 25'56.54 S 5856.20 'W 10158 7300.00 . 7200.00 2585.41 'S 5968.34 W 10303 7400.00 7300.00 2612.93 S 6069.54 W 54.08 54.65 ( ......................... ..5._3... ? ~ 9 ................. _-_ ............................................ :u 54,20 53.68 53.56 2805-12 ....................... 53.17 ............................................................. 285~.1~ 53.00 2903.06 44.93 ATLANTIC RICHFIELD COMPANY --'~R'A'D I NG"BAY- UN1 =!' ..... WEll'- NO. K- 19 MCARTHUR RIVER ALASKA SPERRY-SUN WELL S. URVEYIR-~- -C-~'~ANY ANCHORAGE, ALASKA "" C O M pu T~T-i.d N----D-~T JULY 12.,1974 PAGE 11 DATE OF SURVEY NAY 30~ 197-4 SURWEL GY2OSCOPIC MULTI SHOT SURVE'~ JOB ~NUMBER SU-3-1687A + 16851 KELLY BUSHING ELEV. = 100,00 FT. ZERO POINT~ INC'LINoME:TER AT--'~B-E--- INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH (' o TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ND-TVD VERTICAL '---D~'~TH ....................... .'DEPTH DEPTH .........NORTH/souTH ............ EAST/WEST ..... DIFFERENCE 1044.3 7500.00 7400.00 .2643.37 S ..'6163.24 W 29.43.4'6 40 39' ........................................ , ............................................................................................... , ..... :,. ............... 10585 7600.00 7500.00 2673.37 S 6259'73'W ........ .2985"63 .... 42.17 10732 7700.00 ' 7600.00 2703.17 S 6362.45 W 303.2.07 .46..43 110.23 7900.00 7800.00 275.4.93 S 6567'82 U 3123.39 .45.60 11165 8000.00 7900.00 2'778.67 S 6665.44 U 3165.17 41.77 ....... ~..~..~.~3 ............ 8.!iO0.~..Q~ .............. ~0.00~?00 ........................ 28~.~..5.6...._S ................ 6756.74 w 3203.03 37.85 ................................... , ............... 11440 8200.00 8100.00 2.8:31.93 s 6846.60 w 3240.24 37.20 11575 8300.00 8200.00 2864.60 S 6931,83 W 3275.6.5 35.40 117.1.4 ............... 8400.00 ................. 8~.0.:0.,~9 .................... 2.8~8.,.88_....~ ............. _792.2._~?...~ ........... 3314.99 39.34 11858 8500.00 8400.00 2934.28 S 7119.21W 3358.50 ......................... 1200;0 8600.00 8500.00 2966.75 S 7214-.99 W 3400.73 42.22 ' .- ~ 21~ 0 ............8700.00 ................. 8600,..00 .............. 299.8...-.. ~.! ..... S ................. 7307 .. 71 12278 8800,00 8700.00 3027.20 S 7398.17 12.418 8900.00 8800.00 3058.72 S 7491.20 12564 9000.00 8900.00 3092.59 S 7591.83 12716 9100.00 '9000.00 3130.90 S 7699.02 " 12868 9200.00 9100.00 3169.24 S 7807.29 ..-- ......... 1302.~ ........ 930.0. O0 ............. 9200,0~ ............................ 3.~8.~ 6.! .... S ........... 7.916,98 'W 34,40 W 3478 W 3518 W 356~ W .3616 W 3668 o71 39.97 .6'3 37.9.2 .82 40.18 .69 45.87 .'2 3 ........................ ~1'~53 ............................................................... · 52 52.29 3722.10 53.57 .-, SPERRY-SUN -WE-I-L-'"~i]R~'~Yi-~--COMP-A~-Y .............. ' PAGE' 12 ANCHORAGE· ALASKA ATLANTIC RICHFIELD COMPANY DATE OF SURVEY MAY 30· 1974 ---~'R'AD'iNG BAY UNIT WELL NO'-"-~-~'"~ ........................ '~-O~'J)U=T~TION--DATE ......................... SURWEL GYRoScoPI C MULTISHOT---'~[JR-V'E~' I,iCARTHUR RIVER ,JULY '12,1974 JOB NUMBER SU-3-16874 + 16851 ALASKA · KELLY BUSHING ELEV, = .100,00 FTi,,-- ............................................................. Z'ERo"- ~'0 iNT-~, I'Nc L I NOMET'ER-'"AT'-k-B'EI o INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASURED V ER.~_I.C.A~ ........... _VE.R.T !.c ~,L .......... _R ECT..AN_~.U_L AR CqORDINATES MD-TVD V'ERTICAL · ~D-E--iS'T H ..................... DEPTH DEPTH NORTH/SOUTH EAST/~EST DIFFERENCE CORRECTION · . · .. . · 13168 "940Q.00 '9300.00 3249.'0z, S 8015,,94 W .... ']3768.52.]_ ......................... q..6.q2 ............ 1'3314 ............ 95'00'00 ................... '~J'4 0~'~'00 ....................... ~'295' 6'~''S ............ 811i,.48. W B81q.q9 45.97 13~60 9600.00 9500.00 ~344.91 S 8206.2.4 W ~860.82 ,~6..32 . 13600 9690.82 9590°82 3392.12 S 8300.5,4 U 3909.18 48.35 THE CALCULATION PRO, C~DURES USE A LINEAR INTERPOLATION BETWEEN T H E N E A R E S I 20. _:F._~.~I ? ...M..D ....... {. F_B.D~_.... R A.D..! P_S_....O._F_......C U_R.V.A.!U R E..) ..... P 01 N T S ~. ......... ATLAHTJC RICHFIELD OlL.'.C.O., TBU..,K.-.i9 ......... .' .:' ' ' ' K[LI.,¥ .gUSHING ELEVA?IOS iO0_.Ft., ....,, ~ ..... z ............. '. .......... ' ..... -_-.- ................................................. '"'~ ..... RADILI$ OF' CURVATURe" 'N.I~THC~D OF' COMPUTA'r.ZON '- . · ................... :. :..; ....... - .................................... , ............ ........... eRE. PARED FOR ADD¢O. F:$Y...F..,. M-, .... LIND,SEY.. AND..ASSQC,..,_BBB .................. ~ ..................................... : .......................................................... ,. .~ .... , ~ .................. ~ ....... . ........... , .~ ....... ~.,,,,. ..................... , ..... ~-~ .... i. .............. , ......... ~ .... * ....................................................... .., ........... .~.:.:- :.: .... ----"- --R~:co(<~..u.~:.. ~URVEY ............. - ........... ' ...................... - ................................................................................. ............................ /~LL' CAL'~:~jLATIoN~ ~ERFORIgED' .i~"? -I._. t:1 N. ELECTRONIC.. CO.hlPUTER .................................................... .... ~ ......................... ...~ .... ,.; ......... ~ -~1 .... o ....... :, ' ' "' ............................... .. "?"" Tr~u~ ' . _Doc~ L~o ......... ....... .-,(AS,, [)RIFT VERTICAL ........ SUB ....... :..DRIFT ..: ....... .TOTAL. COORDINATES ............... C._.L...O....$_..U..R .E..S ............. SEVERITY ................ ,SFCT .....DEPTH ANGLE D M 24 2~ 27 29 32 3B1 1 4.5' 596 t 2o 633 0 35 723 3 3O I6 5 45 04 .q 1.'3 .36 ~ 4.5 97 lo 3O 57 13 0 1 '?14 0 7.~ 15 0 41 i7 0 56 17 ~6 9~ .22 0 7q 26 19 30 33 z~5 1.2. 42 '0 o~ 5! 15 · 96, ~'~., 15 62 q.5 0 56 t, 3 0 91 45 .0 2t~ ,57 0 DEPTH .. SEA..... DIREC ................!. ..' .......................... ; .......... i..DISTANCE............ ANGLE ........ DEG/iOOFT ..... DIST. ..................... DEO, ............................................................................ ..... D .... N...5 ......................................... 632.89 .......532. 722,82 622, 819,52 715. 902,85 802. 934,50 834, · . 99~,6~ Bgq, ...... 10~3,38 ...... 953, 11~,1,72 1011., ... ..... . 12t~5,67 1149, 15~t+~47 14t~4. 1761,69 198~,10 1B84, 2115,~1...2015, . .. 228~,12 2189, 242.8,66 2~12,53 3182,76 27.12,5',3.. S60.,;00',¢~ ....{:0.3,,02 .S...10.~,',~,13.._W., , 12q, 9:30 $..61 ,0 20 W 0,288 3082~.7&-'. .~0'00,~ ....... 794,71 $. 142~,16 W...i632,b3..~ 60 ,q~ 18 W 0,375 , : · . . ........... · ......... ,..:.. *-,...~. · ,~..,...~.., I .... .~ ....... -,.,-.,. ' ..... ~ ....... .. · .. ,... m- ..~, ...... ~ ...... . ..... ..... ........ ~- ...,..~..- -. ,~ ....,*e~.~--.. ..... ,. ....... ~ .... ~ ...... 90...S35,.00E .........75,B9 N .........5.1,Ot+..E ............ 91,A6.. N..33...5~.26 E ............ 0~,2~,3 ....... --75 89. NT2eOOW ....... 75,51.N ...........50,7'6..E ............... 90,98..N..33_51~...37 E ...... 3,167 .............. 82 N~I,OOW ...... 77~03 N ...... 117,9~. ~ ...........~.0,74 N..31..5~..10 E ...... ~OA. 9 .... ,73 52 N45,00W 82.,0t~.N ....... 42,38 E 92,33..N 27..19. 11 E ...... 2,549 ..-69 50 N64,00W ..... 90.,77..N ........ 29,72..E ............. 95,52.N lB ....... 7_.53 E ..... 2,50~ 6q N76~-OOW ......... 9.4.,26 .... N ....... 20,16 .... E ............. 96,39 N.._12 ....../~.._20 E . . 4,SAB ,-53 7~ .... 57~,OOW .......... ~,8~ N .......... 5,8~_..W ........... ~5,Ot...N ..... 3 .31..q3 W .........5,682 ...... -29 33. :$54,00W ........ 81,87LN ........ 3.5,50...K ............... 89,2~N...23_26~79. ?t ............ 7.,14~ ........... 67 S53,00~ ............?'9,24 ..... N ......... 39,05...~.~ ......... 88 ,3i ..N .26 ..lq .18 ~ ..... ~,5.96 ........ 50... ~5~,OOW .......... 50,62.N .........76,35...~. ...... 91,bl._N 56. ~7.. 5 }g ...... 3,406 · 52 6e ..S35,oou ...... 68,6o..s ........ 237,13.._w ............ a~o,a.5., s...y3...51. 5z..w ........... 3,028 ............ 10. S55,00W .... .167,82..~ ......... 378,B3..W..~ .... ~1~.,33..S 66. 6...2~ W ....... 81 $55,oow ........ 2 f, 7,-~ ;l..$ 9 -~ . . ........... " _ ...... ~'3, 2..W 551,79..S 63 ..... 19 ...... I N.. ~..018 -~ i~ ~ ~ 3 ,, '' ' '¢ ¢' 4: _ . . · .... -,, ........ .... ,.~.~. ~., :,~4,,:~.,...W ....... ~95~,0~.$. 68..~ _.~6 .... W ....... 66 S60,.O. OW /r16,70. ~ . '771e~.3' ~4 876,79..$ 61 37 23 W ...1,087 03 S60,OOW 4. r]l,A1 S 8f13~50 W 'I0'06,15' 5 61 24 52 W 0,532. ..... ~F ~ 4t. ...5~9 .... 69! ....... 737 07 r) ,'29O ·. General: This form is designed for subn,,!'.ing :, .c,l,t'-~t:'e ~:"~ ,. ,; ', .:.c ; ,...c.l: .:c. mt.~l,.,',i:m reD,w~ .~r.a Icg o~', all lypes of lands and leases in Alaska. Item: 16( Indicate which elevation is used as reference (where hal o~herwise shown) for depth measure- ments given in clher spaces on Ibis forn~ and in any a~lachmenls. ltoms-~0, and 22:: If ~his well is completed for separalc, prcduc~ion from more ~t~an one interval zone (multiple completion), so slale in i~en~ 20, and in ite,n 22 show the p~c:tucin9 inlcrval, or intervals, top(s), bottom(s) and name (s) (if any) for only the inlerv41 reported in item 30. Submit a separale repor~ (page) on this ~orm, adequately identified, for each additional inte~w~l Io be seperately produce~t, show- ing the a~litional data perlinent 1o such intervM. item26: "Sacks Cement": Attached supplementa~ records for this well shoulJ show the details of any mul- tiple stage cementing and the Iocalion of Jhe cementing tool. Item 2B: Submit a separate completion re~rt on Ibis form for each interval to be separately produc~. (~e instruction for items 20 and 22 above). 24. ~UM.MAIL¥ O1,' F'OII..'VI'ATION 'FE'2'FI'.~ lhlt'LUI)iN(; IN'I'EI{V'A~ 'TF-Ci'FED. IHI?."kqUI'{C DATA /u~D ILECOVEIIIES OI.' OIL. OAS, ~VA'I'EII AND MUD 1. Schlumberger FIT test - Hemlock Bench #6 @ 13597', IFP 4422, FFP 4428, ISIP ,~511,~ FSiP 4. q18..._. . Re¢ 2. F~T Test- Hemlock 3ench #6 Rec 8500 cc water, 2600 ppm el, 1500 cc mud, 200 cc sand. 3. FIT Test - Hemlock Bench ~5 0 13405~, IFP 5929, FFP 3958, ISIP 4054, FSIP 4043 Rec 5740 cc oil ~ 3500 cc ~ater, 3500 ppm cl 4. FIT Test - Hemlock Bench ~4 0 13232~, IFP 3552, FFP 3562, ISIP 3691, FSIP 5701, Rec 10200 cc water, 2800 ppm cl 5. FST Test Hemlock Bench ~3 0 13075~ IFP 127, FFP 105, !SIP 3549, FSIP 3552 ~ec 49 cc o51, 49 cc mud, 2 cc sand, 0.3 cuft gas C '!T Tes~ - Hemlock Bench ~2 0 12'965~, FSIP 3568 Recovered 39cc oil_, .5.7 cc_?tgt_er,l!5 c_c sand, 0.7 c~,. Ft_g~s ......... ....... 7, FIT Test - Hemlock Bench #i @ 12816", IFP 12'7, FFP 105~ ISIP 3312, FSIP 3324, Rec 1200 cc water, 2800 ppm el 't2 onek Hemlock WF BIlL 35. G iDOLZ)G 1 t~ M A IO{ F.l/-q HAM~, 1 6i29 12809 13690 13721 4697 9211 9777 9807 · . _ HF.A$ DF. PT · . 7! 4 . 9099 9339 9643 ~8~4 · . . lO0~q .- ~mo .. 0 1 0 3 3 RECORD'OF · . ALL CALCULATIONS PS'RFORMED B-Y · TRUE DRIFT VERTICAL ANGLE ' DEPTH' , SUB SEA · . '34'00 ~670 ~904 4730 4979 5268 552~ 59]0 6~51 6708 49 1.5 3500.47 49 BO 3770~03 48 15 40~4,83 49 4!) 4§61,81' 49 30 4830,64 48 15 5079,24 48 30 5368,1g 48 45 5622,67 49 0 6010,72 49 0 626 3 · 30 4g 0 6651,03 49 0 6808.49 7007,43 6907 7145"51'-7045 7276"72 7176 7338,64 7238 7407.~32 7307 7515,97 7e, 15 ...7673,30 ..7.57~ 49 15 49 0 .. 49 0 47 30 45 45 43 45 46 30 suRvEY.: .......... B M ZLECTRoN!c CONPUTER · DRIFT TOTAL COORDINATES ¢ L 0 .$ U R E S .... SEVERITY 5ECTI DIREC DISTAN¢~ .... AN6L~ DEG/iOOFT DISTA DEO, ....................: ..... '' D .M $ .47 ,64 ,24' ,19 ,30 ,'49 · 43 .... "s O.O'Ow S60,OOW .... 1129,02..$__2005,,21 W ............ 2301,21_$ .... 60..37.. 6.Vl._ S61,OOW.. 1261,Q4 $ ...2239,25..W 2570,12 $ 60 562,00W 1567,17 5...2802,33 W 3210,78 ,5 60 S64,00W 1710,69. S ..... -3084~.01.. W ........ 3526,70 .S. 60 566,00W -1831,02 S 3342,06 W .... 3810,77 8.61 ._ ~69,0'0W .1955,44 574,00W 2181,80 'S 4339,73. W 4857,32 S 63 574,00W .22~1,89 ~ q619,04 W ..5143,12 S 63 $74~00W 2304 83 S ..5047 . ...... 577,00W 258P, 35 S 57~1,78 W 6295,35 $ 65 . STB,OOW 2596,37 S 5809~51W 6363,30 S 65 . .. 36.21W 47 3 W 58 58 W .... 0,371 16 58 W 0,512 46 15 Vt 0,521 20..20 W... 0,59~ . 18 32 W 0,260' 54 34 W O~O00 42 41W ..... 0,000. 59 lZ .w.. 0o3i9 17 35 W ... 0,082 31 52 W 1,078 47...33 W 0,377 55 9 W 1,795.. .32'. ..... $76,00W 2612,72 $ ...... 5880,3_3 W .........6t,.34,'64. $..66.. 2...~?..W ......... 2,240 .... 0,473 .... 1969, ... 0,060 ........ 2280, 0,407 2547, 0,199 Iii B1B3, 3498. 3782° 4107, 4396~ 4839, 512~. 5752, 5981. 6140~ .. 6289, 6358. 6~30, · 97' ST~,,oow 2641,50_.$... 59g~.,X. 1]W .... '.65t~,1,19..$.66 10 56 w -. 1,866 .......... 6537, .,30.. 575,00~/.I.]_2685,05 .... $ ..... 6135',.99..W. ]...669.7,76.. ~. 66..'.21. 58 W ......... 1,402 ....... 6694, 10764 47 0 10984 46 15 · . . 112.74 /43 30 114,61 42 45 115.30 42 15 11700 ~5 15 12212 43 0 126O7 q8 .0 -. ....... 12937 · 7769,91 ..... 7669,91 .... $77.,.00W .....2709,90.....~ ......6235_,64 W ' ...6799,0~'$......66:30_39 W ..... 1,.100 ........... 6796, 7921,00 7821,00...$79,00w 2743,I4 5 .... 6.392~05 W '6955,80 ~.66-._~6 2'4 W ..... 0,736 .. 6953, [~126,4~ . 8026,48 ~78,00w .... 2783~9~ $ . 65P2~93.W ........ 7156,26 8 67 6.22.W 0,976 .. 7154, . 8262,97 B162,97 ..573,00W..... 28.15,93...$ ......6716,25...~I_- ......7.282,68..5 6~...15.,.11.W ........ 1,846 ....... 7281, 8313,84"'8213,,84 570,00W 2830,72 5__.676()*~5...~ .... .7529,17. $ 67 16 48 W . . 2,998 - 7~28, .."8800,22. ~"t-O0~ S7~,00W...295'5,33 $ _7~'!,67'w ........... ~O0~,PO. $.6Y.~.38 W 8,2'81 . . .7802'~ 'g'077,00 8977,00 573*0()Wm 30.2~,4.~....& _.J494,B~_W ..... 8081,68 S 68 X-50 W 1,728 . . OOB1, . ............... ALL CA~¢ULATZ0'NS PE~-FORt4ED "BY" i' [~ '~4 '~'T~io'NzC Co~uTC~ ....................................... . ........ ~..~-. .... ..-~ ~....~ ...... T~'-..'.-.' ~.-"'. ......... ~.~". ~.'.. ...... ',.~'."L.~_;~ ........... ,. '..'.,'L'~..~.~'.~.'~.~.L'..~'~ ......... '...~. ~..~ .... ~.L',~._.~. ~, ~..~..~i~L..~'~ 7~'.~T'~.'.~'~.'~' ~.~L"~ .... ~ ~ '. '~..~._ ~., '. t~u~'- ............. ........................................ : .............. ~ .................................................................. ' ....... FleAS." 'DR [FT V~RT[cAL ............... SOB ........... DR'['F~' ................ ~'6TA~ .... ~66~D'j~.~'~'~-',]:-']]"L- SEVER J'FY SECT .......... "".~-~'TE~'~'~""~'~'~"~-'~ .... ~.~.~.~. ~o~ Lc~ .. ......... DE~TH AAJGL~ DEPTH SEA ........D~REC ' ' ., . D hl . ~.~' ' DEG. D[STA~.E ............ ANGL~ ....... DEG/IOO'FT -D~ST. ........................................................................... ~ ......... : ..... ' ..................... : .... ~: .......... ' ............ O ..... ~ ....... $ .............. ' .... ........ ~ . . . ~ .............. _ ........ ' ..... ....... ~ST.2t ~? ~o ~gz,4(,._.~7,~k~."~..f6.~.,~o~z ...... ~.33.t.~.,~.~..:~ ..... ~.9~.,.'[~_.~ ........ ~..9~o,~_~.._.6~..Z.~ ...... 7..~ ............. ~,oo~.. '322 z~o0 ~o0 · 6OO 7O 0 8OO 90~ 1002 110~ · . _. 12n8 1313 1530 1641 1757 1876 200a . 213~+ 2279 '1' 2t~33 2:~77 271(, 285A.' ....... ~-'"' ' 2993 31.33 ~.7~ ~415 ..... 3703 3 [tt~. 9 ,3997 · I+299 6760 AO0* 300 500, 400 600, 500 .... . 700, 600 . . ~ ..... ~ .,.. . ..~, , 800, 700 900, 800 "'lloo'; ....... looo _ 1200~ 1100 _. 1~00, 1200 1 ~00, 1.300' 1500, 1400 1600 1700 1800 1.900 2000 2100 '-' .... 2200 ......... 2200 2600 ........... 0 .................... : .................. 0 ........... 8. 0 · 49. _...N ............... t~ 8,61 ... E .... .............................................. 0 ..................... 0 ............................... 77~92 N ........ 69~76 E ............ 0 ,. 0 - 75,81 N 51,08 E ..,. .............................. : ........................................... 80,98 N /+3.,49 E .. 1 ....... ; ........ .: ..... :.: _..-.. ! ................................. 8.8 ~3 ~...N ........... 3 ~., . ..15oo ~,1 .......................... 1~. .................................... 1:, · 1600 ........... 57 .- 16 65. , 1700 76 19 83, · ' 1900 ...... l':~t, ........ · 2000 179 ......... 65 ................. 236, , ' '2too ...... 23.~ .................. : ...... -i~/+ ' ................................ ~OOo , .... 2200 ........ 277 · ..... 2300 ...... 316 ........... :.' .... 39 .......................... 402' · ~53 ~7 ......... . .......................... · ' .:"2 oo .. 5'.':.':- , .. 2600 432 40 . .7oo .... .......................... , .......... 2800 ........ ~15 ,~2 ..... .647, ~, - 2900 558 3000 riO.3 t, 5 750, 3100 ....... 669 ............... '~.." O 0 5''': ~; ": ', :"' . . 3300 7A. 7 ~0 916o 3t~O0 799 ..... 5~ ... 971~ 3500 ~52 53 i029~ 3riO0 906 .... 54 lOaT, ........ 2500' ' 2600 2600 .. 2700 2800 2900 3000 · 3100~ . 3200, "~ ~.. ':: a 3400 ~ 3500, 3600. 3700, 3800~ 2~.~ .............................................. 47_...~ ........... 1.9.26.._E ........................................................ 36 N 2,98..W ............... 87 N ........... 27,61W 46 N 53,26 W 03 N 83,53 W 93 N 118· 76 W 96._S ........... 158~5.6..~ .................................. 76 ~ ........ a0~o96..~ ................. 67 $ 258.65 W 86 $ 320,3~ W 19 S 390.78 W .' . 80 S ~77,34 W ~6"' $: ..... ~7~,~1' 'w .............. 76"'& ............... 664~1'"W ......... : ....................... 97-'S ....... ,'7~'7~'?~ ~ ........................ 29.'~ ..... 82~,'60 W ................ 3700. gl0 45 S 913, 38 $ 997 11 $ 1170, ........ 42 S 1259 86 5 ...... 1662 .... .... ~6 S 1633, 56 S 1732 ~3 S 1832~ 98 S 193~ .. " hlEA$11RES.DF:'p.TH].AND."OTFIE'~.'.:.~ATA' ~{5'R E;VERY ~'V.Eh lO0 I',F,:ET.]'.O.F..&d.B.$EA DEPTH'~_ ..................................... . ................................... , ..... TRUE,= ...................... ,-. ..... ,. ..... : .......... - , . ......................................... ......... ' .... t4EAsuR,F,D ....... VER'FICAI,"SUB'" '~D-TVtSi. '"'.' ,' ii' ..' '¥~RTICAL.' · . ....... . . ' ...... .......... D[PTH ' i DEPTH.· SEA_DiFFERENCE ............ CORRECTION ............ TOTAL ....... COORDINATES ........................... .................................................... 5063 4000~, 3900 .. 1063 .............. 50 ' 125fl,54 .S .... 2234,03 W ................... 5214 .5366 5671 5'779 6133 '6288 6441 6594 6?44 6 70~5 7196 '7247 749 ~ 765d 7~02 7954 8290 8564 8716 8869 9021 9326 9631 97R4 9937 0089 4 4200, 4300 ~ 4400, 'q, ? 0.0 · 4ilO0, 4900. 5000, .5200, 5300, 5400, 5500~ 5600° ,. 5700, 5800, 5900, 6i00, 6200, 6300, 6400 * 6.900, 6600, 6700, 6?00, 7000, 7200. 7300, 4000 . . 4100 · . . 4200 · 4300 44 O0 1218 52....... 1422,66 S... 2533, .... 1271 ........................ 53 ........................ 1477,69._$ .... 2635, ! 324 .................:.'-. ~ .................. i533,10..._S ......2_738 ~ O1 w .................. 6o..w ...................................... 30 w ....... 13. W ...... ~...: ................ 43 __W ............................. : .... ~.~ 500 4600 4700 4-800 4900 5000. ~00 5200 '3300 ~,q. O0 5500 5600 5700 51t00 5900 600(.) 6100 6200 6300 '6400 6500 6800 6 ? 90 1 3 ;:-c: 5',' .;..? :.~ .'3 ,,, 23 S 1433 ~4 ........... 1642,13 .5 .._ 2946,4i 1z~88 ....... r' ' .......... !...55 ....................... 169/4..89 S ..... ~0§1,"'/'8 1541 .., ~3 ........ 174~~72 S ---. 3156,72 1594 ......... "..j.,.~ 3 ................ 1794,~2 ~ 3~60,57 1644 ................. 50 ............. X840,39,"S ..... i..~3363~20 169~ ..... 50 .... .. . ~884~63 S 3466',11 1745 ........... 51 ................ X9~7~36 ~ 3570,63 ..1796 .............................. 5X .............................. X968~2,.8 ....... 3676,05 1847 51 ......... 2007,01 S ..3782'43 ............. 1950 ................. 52 .................... 2078,77.'5 ..... 2002 ............ 52 ............ 2112,88..5 ...... 4107,76 ~09~ ... ~2 ......... 2!46~04.E 2106 52 217~,25 S .... 4327,40 ........................ 2159 ~3 2210,09 S ... 4438,39 ................................ 2211 ~2 2241,71 S 4548,67 .................... : ............... . 2264. ~3 2273,53 S ._.4659,61 2316 .............. 52 .............. 2305,X6.S .. A769,93 2369 53 ............... ~336,94 S 4880.77 2473 .~2 .... ~400,37 S ~1'01,43 2'5~& t'3 ........ 3433', 41 8 .... 5212,0~ 6I-~00_ ..257~ ................... 52 .......................... :~40'6,91:) .~ ....5321,87 6900 2631-' ........ {}3 ........ ~!300, B~ 8 5~32,59 7000' 2684 ..... 53 ..... 2532~88. S 5543,83 7200' . 27'0~ ............ ~2 ............... ~987, Z3' . ~-.'"'-,~. ........... ~ .................. ~, ,~, ~o . ..... ,~ .... ~.' .... ~ ................... 4,,. ...... ~...~..-~,~.....~. .... .~.~.,~ ........ ~....~.'.J ...... ,,~ ............... ~ .......... '-.-: ...... ' . ......... ..,, ,,, ..... , ,~,r, ,. ,~., ~..~...,,~4,,~,.,~,...~,,*,,~~, .,.. ~.,.-,,.,...-,.~.,.,,.-.. ..... ~ .... . · .... ..,.~. ,. .... ~, ............ ~.,,.,.,., ~,,,.,.~.-.~..,,,,~ .. .............. ,, .......... .,..~,~ ,,o... ......... . .. ' ....... ....................... TRtJE" · :.. ........................ '., ....... : .................. _.~ ...... ;~ ........................................... -'~ ............ : ......................................................... ' ....... ................ ~EAS'LJR~D ........9ERTiCAL- SUB ' MD'"",'TVD VERTICAL ......... :. ......... .... ...................... ~r..~ t~. ]..i..':..i ..... ~-':R~..,.'L.s.-r.A..'~F.r..~R.~'~C~.Z_'-Z .C.o~.,.CCZ Z.O.N. ............ _rox^~.. 'Co'o~'i~ ~A.TESL.Z'.'.;;"'.~.Z.'_'.i'.~'".. ]".'i.". .... . .......... 1037~ 7500, ..... 7400 2[878 .......................... 62 .............................. 2637.05 5..:...5969,39 ht 10518 ........ 7600, .... 7500 2918 t~O 2664,89 S ..... 606:~, 2z~ .............. :),o662 7700° .76;00 2961 .............................. t~3 ................................. 2692°22 5 ........ 6163,27...w,' .......'... ................. :10808 ...........i' 7800, 'i17.'7700.."i'1'3008 .................... t, 7 .......................... 2717,0.,3 ,5.. ¢,267,02 W o~ ....... 7~oo. ........ 7800 .... ~o~ .......................... ~ ............... , ........... ~.~.~8., ~ ~.. s .......... ~.o.,o~. 1097 ......... BO00--. ......... 7900 .....30~T ' -~-;+,. ......................... 2758.,86 .5.......61'¢,71,5!,.h~ ............................... ..- 1237 .......... 41~.~:0, 80OF, ._. 2413 ........... ~0 2778,69. $ 6~6.7.,79.. .... - ·. ~ ~ '? ,. ................................. ~ .............................................. t'~7~ ....... ~2.0o,'.".~'.ii' ~oo ~17~ ,38 · z?~.~z s...6~..9~..~t ............. 1511 8300, 8200'"3211 36 .......................... 2826,.'!.3 $ ...... 67.~8.,~0..W .................................... 1649 ........... fl t,,O0 ;' .... [1300 ..... :92-'~ 8 ........................... 37 28.55 79"S 6fl38.!0 1.7'00 8,~00, .... 8 t,,OO ....... ~290 .......................... ~Z ....................... ,?..8.80 ,. 80.._ S ........... 693~., 69... ~/ ............................. ~'9'~ .... '- ~-r, oo...i.'i'i'~Oo'i'.i.~:~l ............................ ~1 ............................ ~_90~,..,~r~ 5 ........ ?o~1.27_..~,~ ......................... '" 207t 8700, 8600 3.~7~ - 42 2933.67 $ 7128,01 2211 ~t.800,'- 8700 -3411 ............ 38 ...................2955,17 5 7221,00 ~' ....... 2350 8900, ...... 8n. o0"- 3450 .............. ~9 ...................... 2975','4.1" '.S ........ 73 I"~, 52 ,,t .......................... 249~ .................... 9000' ........fig00 ...... 2,4,93 ................... ; .......... 4'3 ................................. $000; 4.9"'S ........7t+ ;I. 4'; 7 5' ' ~,,/ ......................................... 7 .... 26/.;1 ....... .'1100, 9000" ~541 .............. ~n, ......... · ....... 30~0o87 ,S .... 7~19,00 d ....................... 2792' 9200. .... 9]00." 3591 ................_ 50 ................ ~065,'10-'-'S' 7626.A, 8'~ ................................ 29z~3 9300, "9200 -"3643 "~:"' 52 .......................... ~101.'~28'"5 ....... 773z~',lS'tq ....................... 3098 9400. "'9300 ' ~698 ............... 55 ......................... ~140';99 S ....... 7845.79 ~f .................. ~.~ .... ~oo-. .... ~.o~ ~'~?' ............ " .......... ~) .......................... ~,~'~ 's ....... 7~c,z'.'~z .... ~ ............................... ~'" .:'Zi.7.-.ii ...... i.'_.".''~,:~6 .............. ~6.oo; ....... ~oo ....... .~r~t4; .............................. t,,~ ....................... :~"s~2. rf;~'.:,:,"'~ ........... r~ov~-,.~'z "~, ............ , ................................. ............ .t 3 ~.?.~ ;7 '.; .... ' '.'.'..??.o.o'..-'.i-;'.~).~0.0.';;'..~.~ ?~. ....... Y-'-Z-,_Z,7_.7..~.~7'._-"Z.; ..... ;'77.-Z..".-;.~..?'.2.';.o ~.'L.S'Y_'ii~'a~ · .............. · .. . . , .. . .................. - ................ ,.~ ................ , ................ . ............................. ~ -.~...= .................... "'.'N£A';oURED. VliR T ICAL' ..... SUB,"''' .... .!""~" '~' .... : 'co DEPTH DEPTH · SEA ..... ~ .... ~TAL.. ORD ATE~' ...................... ~ ...... ~-.--~ ............... ............... · ............. ~ ...... .. .. . .... ~ ........... ........ ..,..., ......... ' -~ , . - . ~ ... · .... · .................... · ........... ~ ' ~ ................... ............... ~000 .... -. 1098, ..~.1T98, ................ laS,~-~., ' ~1.9~62'W " . ............... ~ ...... ',.~ ........................... ~000 .... 2605, 2~09, 500,89 S .917~24 W ~, · ~, ..-~ ..' ...... ....... ~000 39~7, .... ~8~7, ..... 12~5~6~ 5 ..... 21.92,88..W ..................... :: ............................................... ]']]"~ ...... _.~ooo..'."" z~a~, z,~, .... ~b9~.6** .s.. 2~-~,,~2 w ..................................... ....... 7000 " 5270, 9170, .... 1-914,.82..5 .~39~8-W .............................................. % ......... 8ooo .... 592g, ...~829, .... 2i5~90 8...]~ 425o,6~..w .......................................... ]]',~ ............ :. ,. · ............ ... ............ -9000 6~86~' 6486, . 23~+,2~ 8 ...... 497~9%. W ..................... - ........... ....... 10000 72~41, 7141, 2572,09 8 .... 11000' 79~2, ?B~2~ 27/~9.~ ~.._640~8...W ............................................................................. ,. ................ 12000 .... ~6~8, ~5t~8~ 2919-,67 S. .7078,~2 W .................... . - .................. . ..-.~. .......... .. , ............ .................... ... ........ ~ ........ -- . ........................... ......... . Form No, P--4 RJL'V. $- I-?0 STATE C~i~ ALASKA OIL AND GAS CONSERVATION COMMI'I-rEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS wELl, WELL OTHER 2. N~ME OF OP~:I~.~TOR UNION 0IL COMPANY OF CALIFORNIA 3. AD'DRESS OF OPEI~2k~R 909 West 9th Avenue, Alaska 99501 4. LOCA~ON OF WF_J~L Leg #1, Conductor #6, King Salmon Platform. 699'N & 76'W from the SE corner. Section 17: TgN, R13W, S. M. SUBMFr IN I~L~LICA~Ig API NLK%{ER/CA.L CODE 50-133-20259 LF--ISE DESIGNA~"~ION AND SERIAL NO. ADL-18777 ~T IF INDIA]~, ALOTTEE OR TRIBE NAME 8. L.~IT F.~iA~ OR LEASE Trading Bay Unit 9 WELL N'O State K-19 (32-19) 10. FT~.T~r~ A_ND POOL. OR WILDC~%T _ McArtbur River-I{emlock 11 SEC., T., R., I%{.. (BO~rOl%{ HOLE Section 19' T9N, R13W, S. M. 1~. PEI~MIT NO. 74-8 13.REPORT TOTAL DE~TI-I AT END OF MONTH, CHA~NGES IN HOLE SIZE. CASING AND CE2VlENTING JOBS INCLUDING DEPTH SET ;dXV/) VOLLrN~ USED~ PF~Zll~OP~%TIONS. T~F~TS ~ Iq.ESULTS FISHING JOB~ JLrNK IN HOLE A/~D SIDE-/q~ACKED HOLE A. ND ;~NY OTIzI]gR SIGNIFIC~NT C~GF~ IN HOI~ C~DAEDITIONS. KING SALMON PI,ATFORM TBUS K-19 for June, 1974. Ran WSO test (net fluid rise 3100'). Squeezed liner lap w/ 150 sx. Class "G· cmt. CO liner to 13,710'PBTD. Ran WSO test (net fluid rise 91'). Ran FIT @ 13,597', 13~6~, 13,403', 13,232", 13,075', 12,965', 12,816' Tested BOPE on 6/7/74..~. ~ 1/2" X 3 1/2" tbg. completion w/ 14 GI.~'s & ~RB-6 safety valve. NU & tested x-mas tree w/ 5000 psi. Displaced mud w/ diesel and set pkr. @ 12,698'. Perf 4 t~f from 13,345' to 13,375', 13,395' to 13,415', 13,460' to 13,480' and from 13,504' to 13,545'. Turned well over to production & Released Rig @ 12:00 Midnite, 6/13/74. RIG RELFASED @ 12'00 MII)NITE, 6/13/74. FINAL REPORT. Atlantic Richfield Company, Sub-~)erator smmm q ~[~ ~. L;aixencr~r T~TL~ Dist, Drlg, Sup. t. 7/12/74. DATE NOTE ~Report on this form is required for .each calendar month~ regardless of the etotus of operations, and must be flied 'in duplicate with the oil and gas conlervatJon committee by the 15th of the ~ucceeding month, unle~ otherwlie directed. R,L'V. ~- I-?0 STATE OF' ALASKA SUBMIT IN DUPLICA'I~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. HA.ME OF OP~TOR * Union Oil ,Company of California 3. ADDRESS OF OPEP,.ATOR 909 W. 9th Avenue, Anchorage, AK 99501 4 LOCATION OF W Leg #1, Conductor #6 KING SALMON PLATFORM 699'N & 76'W fr SE cr Sec 17, T9N, R13W, SM APl NL'A. iERICAL CODE 50-135-2-259 LEASE DESIGNATION AXD SERIAL NO. ADL 18777 IF INDIART ALOTT'EE OlR TRIBE NAME 8 L~.'IT FARM OR LEASE NAME Trading Bay Unit 9 WELL NO K-19 (32-19) I0 FLF-~.F3 A-ND POOL. OR WILDCAT McArthur River - Hemlock 11 SEC . T.. R. M (BO'I~I'OM HOLE o~,r~-'n-v-~ 2830' S & 3130' W fr NE Cr Sec 19, T9N, R13W, SM 12 PF'~tIIT NO 74-8 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AiN-D VOLLrlVrES USED, PERFORATIONS, TESTS A/ND RESULTS FISHING JOBS Jb~i~fK IN HOLE AND SIDE-TIR.ACKED HOLE AND ANY OTHER SIGNIFICANT CI--LA, NG~.S IN HOLE CONDITIONS TBU K-19 (32-19) for May, 1974 Drilled 8-1/2" directional hole f/10312-13574'. Ran DIL, GR-Sonic & Formation Density-Neutron logs f/13561-10047'. Drilled 8-1/2" directional hole f/13574-13771' TD. Ran 3987' 7" 29# N-80 X-line liner w/BOT hydraulic MC liner hanger f/7769~i2 .......... 13756'. Cemented w/1000 sx class "G" cement. Cleaned out w/6" bit to 13710' PBD. Ran Gamma Ray-Cement Bond Log f/13698-9766'. Top of cement @ 10434' w/good bonding. Reran Density-Neutron log f/13698'-11903'. Ran Sperry Sun Gyro survey f/13600-2000'. Squeezed liner lap w/200 sx class "G" cement. Drilled out cement f/9662' to top'of liner. RIH w/6" bit & 7" csg scraper to CO inside 7" liner on 6-1-74. Tested BOP to 3000 psi. Replaced Hydril rubber & tested to 1600 psi on 5-21~74. JUil ! 8 'i!ii74 *A~Pa~tic Richfield Company, Sub-Operator .... ~~,,.~_~~.-~_.. District Drlg. Supt. r,.~, 6 14 74 oil Qnd gQS aonservatlon ~ommlfee by the IS~ ot ~he suGar,lng moflth, uflle~ Gtherwis~ ~r~ted. ~o.P-~ STATE . ~,..,,,SKA 1R~V. ~- 1-70 !5. AP/ NUA~ERICAL CODE SUBMIT IN IYo'PLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS 50-133-20259 6 L-E~kSE DESiGNA~ON AXD S~IAL NO ADL 18777 WrLL W~;LL OTHER 2. NA_ME OF OP~P~ATOR * Union Oil Company of California 3. ADDRESS OF OPERATOR 909 W. 9th Avenue~ Anchorage~ Alaska 9950~ 4. LOCATION OF WFJ-J- Leg #1, Conductor #6 KING SALMON PLATFORM 699'N & 76'W fr SEcr.Sec'..17, T9N, R1SW, SM 8. L~IT F.~RA~ OR LEASE N.~ME Trading Bay Unit 9 WELL NO K-19 (32 19) 10. FTYS?) AND POOL. OR %VILDCAT .McArthur River - Hemlock II. SEC.. T., R., M.. ~OTTOM HOLE oB,rmCT~ '2830' S & 3130' W fr NE Cr Sec 19, TgN, R13W, SM 12. PERMIT NO. 74-8 13. REPORT TOTAL DEPTH AT END OF MONT~. CHANGES IN HOLE SIZE. CASING AIN-D CE1VIF~NTING JOBS INCLUDING DEPTH SET A/q'O VOLT3/VfES USED. PER~ORATIONS. TESTS A/ND RESULTS, FISHING JOBS. JU~TK LN HOLE A_ND SIDE-~CKED HOLE AND ANY OTHER SIGNIFICA. NT CI-IANGES IN HOI.~ CONTDITIONS. TBU K-19 (52-19) for April, 1974 , Drilled 8-1/2" directional h°le'from 10423,' to 12659'. Drill pipe Parted~ Jarred on stuck pipe.'Backed off @ '10902', and left ~1737' of'drill tools in hole. Plugged'back w/a total of 625. sx cement.'. Dressed off cement plug to 10147,. Sidetracked hole @ 10147'. Drilled'8-1/2".directional hole from 10147 to'10312'.. Tested BOPE to'5000 psi on 4-10-74 and 4-26-74.. Drilling @ 10312'.on 5-.1-74:. MAY '.! 6 i97zi. *Atlantic Richfield Company, .Sub-Operator hereby cez~ify that the foregoing.is tru~and correct s~~~~ ~(~ ~T~.---- Dist. Drl~. Supt. D*~ 5/14/74 NOTE--Report on this form il required for each calendar ~nth~ regardless of the Itotus of operations, and must ~ filed In duplicate with the oil and gas conlervation commiffle by the 15th of the succ~dlng month, unle~ otherwile directed. Rrm No. I=--4 l~v~. $- I-TO STATE ~ ALASKA OIL AND GAS CONSERVATION COMMli-I'EE MONT'HLY REPORT OF DRILLING AND WORE<OVER OPERATIONS 1. WELL WELL OTHER * Union Oil Company of California 3. ADDRESS OF OPE2:b~TOR 909 W. 9th Avenue, gnchorage, Alaska 99501 4. LOCATION OF WF.J.J. 699'N & 76'W fr SE cr Sec 17, TgN, Rt~,~, SM SUBMrT [N DL?LICAT~ { ~i ~u~.m~]~:''~ CODE 50-133-20259 LEASE DESiGnATION AND SES:.KL NO ADL 18777 7 IF INDiA}~'. AI.,OTTEE OR YR',BE ~AME L.~IT F.~'t.-M OR LEASE NAME Trading Bay Unit WELL NO t(-19 (32-19) 10. FIY.,LD AND POOL. OR WILDCAT McArthur River-Her:lc ck 11. SEC., T.. R.. M. (BOTTOM Sec 19, T9N, R13~'[, SM 12. PER.MIT lvO. 74-8 13. REPORT TOTAL DEPTH AT LND OF MONt.-l, CHAZGES IN MOLE SIZE, CASING AND CFAILNT~NG JOBS INCLUDING DF_OTH SET AN~ VOLL~ES USED, PE~O~TIO~S. ~TS ~ ~SUL~ FISHING JO~ JL~'K LX HOI~ ~D SIDE-'~CKED HO~ ~ND ~Y O~{ZR SIGNIFIC~T ~G~ ~ HOLE ~ITIONS, K-19 (32-19) from 3-1-74 to 4-1-74 Tested blind rams to 3000 psi OK, casing to 1500 psi OK. Cleaned out to 2627', drilled to 2637', trip out, ran .gyro. Drilled 12-1/4" hole to 7846'~ POH. Tested rams and manifold to 3000 psi: Hydril to 1800 psi. Drilled ahead to 9149' backed off DP while tripping for bit. Recovered same. Drilled from 9149-10104'. Set 246 joints of 40# & ~47# N-80 JL95 and USS 95 buttress 9-5/8" csg ~ 10047'~ cement w/800 sx Class G cement. CIP 9:30 PM 3-27-74. Land csg, tested packoff to 5000 psi, test rams to 3000 psi OK, test Hydril to 1500 psi OK. Cleaned out 9-5/8" csg, drilled shoe and 19' of formation and tested to 10.6 ppg equivalent OK. Drilled from 10066-10423'. APR J. 5 I974 * Atlantic Richfield Company, Sub-Operator ;~'¢ ' 4/5/74 NOTE: --Report on this form is required for each colendor mOnth%tegordtes$ of the status of operetions, and must bo filed Indupliccte with the oil end {Iai conlerva~{on committee bythe 15~h cf the ~ucceeding month, unica1 otherwise directed. Union Oil Company~,~'' California union ~arch 19, 1974 Mr. Homer Burrell Division of Oil ~ Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 I DRAFT _] sec I CONFER: FILE: RE: TBUS K-19 (3Z-19) Dear Mr. Burrell: Enclosed is our Monthly Report of Drilling Operations for the above captioned well. Very truly yours, R. Callender District Drilling Supt. sk Enclosures (2) cc: Arco Marathon Standard Skelly Amoco Phillips . F'~rm No, P--4 1R.~V, 3- 1-70 STATE Or A[..A, SKA OIL AND GAS CONSERVATION COMMI'I-1'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~LL NAME (DF OPERATOR *Union 0il Company of California 3. ADI~)RESS OF OPEP,.ATOR 909 W. 9th Avenue~ Anchorage, Alaska 9950] ~OCA~ON OF W~-'.'- 699'N & 76'W fr SE cr Sec 17, TgN, R13W, SM SUBMIT IN DUPLICATE APl NU~ffEmCAL ~ODE 50-133-20259 6 LF-,a~SE DESiGI~Ax"ION A.\'D SERIAL NO. ADL 18777 ? IF INDIAN, ALOTT~E OR TRIBE NA¥iE 8. L-~IT F.~RA{ OR LEASE NAME Trading Bay Unit 9 %VEIL NO K-19 (32-19) 10. FLF_J.~ A_ND POOL, OR WILDC~.T McArthur River-Hemlo ak 11. SEC.. T., R.. M.. (BO'I~I'OM HOI.~ o~g'Ec'r~ Sec 19, TgN, R13W, SM 12, PEiq-MIT 1~0. 74-8 REPORT TOTAL D21PTH AT END OF MONTH, CHANGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AAT~ VOLUMES USED, PER~ORATIONS. T'F~STS AN'D RESULTS. FISHING JOB$, JLrNK IN HOLE AND SIDE-/RACKED HOLE AND AJqY OTHER SIGNIFICANT CHANGF~ IN HOL~ CONDITIONS, Spudded well at 5:00 AM 2--22-74. Drilled 17-1/2" hole from 357' to 596'. Ran gyro survey. Ran in hole with 12-1/4" Turbodrill and drilled to 2386'. Opened 12-1/4" hole to 17-1/2" to 2627'. Ran 64 jts (2558') 13-3/8" 61# K Butt csg with self fill float equipment csg set at 2591' with float collar at 2507'. Pumped 70 bbls water ahead of 1425 sx G with 2.3% prehydrated gel at 13.1 ppg and 325 sx G neat at 15.8 ppg. NU BOPE and Hydril. Testing Hydril and BOPE on 3-1-74. * Atlantic Richfield Company, Sub-Operator smN~f:2~!~}'i~o: hi~,~rim~i:l,~:u~, ~;2 Distr~'ct Drip. glint. ~A~ 3/18/74 t ed for each ar month1 regardless of tho status of operations, and must be filed in duplicate with tho otl and gas conservation commiffee by the IDth of the succeeding month,unle~ otherwise directed. February !1, 1974 Re: Trading Bay Unit K-19 (32-19) Union 011 Co. of Calif., Operator Permit No. 74-8 Mr. Robert Anderson Unlon Oil Company of .California 909 W. 9th Avenue Anchorage, Alaska 99501 Dear Sir: Enclosed ts the approved application for,~ermit to drill the above referenced well on or about Febr.uary $, 1974 from= the King Platform. tCell samples and cb're chips are not required. A directional survey is required. Pollution of any waters of the State ls prohibited by AS 46, Chapter 04, Article. 7 and the regular'Ions promulgated thereunder (Title.18, Alaska Administrative Code, Chapter 70)and by the Federal Water.Pollution Control Act, as amended. Prior to commencing operations you may' be contacted by a ~epresentatlve of the Department of Environmental Conservation. In the event of suspension or abandonment pi. ease give this .office adequate advance notlficatton so that we may haveaw[tness .present. Very truly yours., ,.,'/,..:;.,, )'./ Thomas R, Marshall, Jr. Executive Secretary ^taska Oil and Gas Conservation Committee Enclosure cc,: Department of Fish and Game., Habitat Section w/o encl. Depart~t of En. vironmental Conservation ~/o encl. Robert T. Anderson District Land Manager union Union Oil and Gas ~' ~sion' W~'"~.rn Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99!i01 DIR _!__] Telephone' (907) 279-7681 --i-''c' '~''~ 5 ENG February 5, 1974 ....... ~'G'E6L-~'-'- REV DRAFT 'CONFER: State of Alaska ~L~: Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Application to Drill Trading Bay Unit K-19 (32'-19) McArthur River Field Gentlemen: Union Oil Company of California, Operator for the Trading. Bay Unit, requests your approval to complete the Trading Bay Unit K-19 well in the Hemlock Oil Pool pursuant to Rule No. 5, Conservation Order No. 80. This proposed Hemlock well is to improve recovery from a final crestal withdrawal point on the Northwest feature. Very truly yours, HWR:jb cc: Working Interest Owners Trading BAy Unit Robert T. Anderson Oil. AND GAS ~'CHORAGu ~ Porto P--1 REV. STATE OF ALASKA SUBMIT IN TR[~'~ ~ATE (Other mstructi~ n reverse side) OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 11. TYPE OF WO[~K DRILL I~ DEEPEN [~ PLUG BACK b. TYP~ OF WELL WELL WELL OTHER ZONE ZONE 2. NAME OF OPE~=L~TOR 3. ADDRESS O~' OPF~NDR k~ U ~, K-19 ( 32-19 ) 909 W. 9th Avenue, Anchorage, Alaska 9 10. FIELD AND P¢,OL. OR WILDCAT -0 !a7, - ~e~fh~r River-HenZoek A~ SU~ce · ~ Y [ ~.. s~c., z., ~.. ~.. ~o~o~ 699'N & 76'W fr SE er Sec 17, TgN, R13~,./,~(Z][".I iSj'; (]~L ,~"~D GA, HOLEOmECTIVE) At pro. seal prod, zone " 2560'S & 2520'W fr ~ cr Sec 19, TgN, R1BW, ~,[CHORA~ [Sec 19, TgN, R1BW, SM 13, DISTANCE IN MILES AND DIRECTION FAOM NEAREST TOWN O~ POST OFFICE' 12. 24 miles ~ of Kenai APl # 50-133-20259 5. 6.LE, ASE DESIGNATION AND -~q/AL NO. ADL-~8777 ?. IF INDIAN, A/J.~TTEE OR Ti~ABE NA.5/LE 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 14. BOND INFOI:LMATION: TYpEStatewide Surety and/orNo. Federal Insurance Co. #8011-34 15. DISTANCE FROM PROPOSED* I16. NO. OF ACRES IN LEASE LOCATION TO NEAREST I PROPERTY OR LEASE LINE, PT. 2830 ' ] 1902 (Also to nearest drig, unit, if any) ~8. DISTANCE FROM PROPOSED LOCATION* i 19. PROPOSED DEPTH ! TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, PT. ~____! bOO ~o~t $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 80 20. ]ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 22. APPROX, DATE WORK WILL START* 100 ' KB February,~/8], 1974 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI)E SETTING DEPTH QUANTITY OF C~MEN% 30" ~24" 157.5# B 381' Circ to surface 17-1/2" 13-3/8" 61# K-55 2700' Circ 1750 sx Class G to surface ~ 12-1/4" 9-5/8" '40 & 47#' N-80 ~0~r~~~Z,~¥.'.:lS~0 sx Class G ~;//,~ /...., ~-'-~' ,,8-1/2" 7" ~'~ .... 2~# N-80 ~137'00'~"',300 sx Class G We propose to directionallY ~rill from 600' to TD at 13,700'TD. The angle will build to 49°. Top of the Hemlock will be 9090'TVD+ with TD at 9700'TVD+. We propose to use a 20" 2000 psi WP annular preventer on the 24" conductor while drilling 17-1/2" hole to 2700'+. There will be 12" 3000 psi preventers and Hydril on the 13-3/8" and 9-5/8" casing with pipe and blind rams. * Atlantic Richfield Company-Sub Operator IN ABO~;"~ SPAC~ DESC'R/BE PROPOS~T) PR(~R~M: I~ p~l ~s to dee~n or plug ~, g~ve ~ on present p~u~ve zo~ ~d pro~ ~w produ~ive ~e. If propel is ~ drill or d~n d~ect~onally,, give pert~ent ~ on subsu~a~ ~at~ ~d meas~ ~d ~ue ve~ical dept. Give blo~at preventer p~gram. 24, I hereby ce~lfy SrGN~ , TI~ (This space for State office use) SAMPLES AND CORE CHIPS [] YES DIRECTIONAL SURVEY )g~YES [] NO CONDITIrO~S OF APPROVAL, IF ANY: ., :'" ' O'I"HEE REQUIREMENTS: See Transmittal A.P.I. N-o-M. Ig~CA.L CODE ._~ -/3 ~ ~ ~o Letter --t / / Executive Secretary APPROVED BeA~ /' , ._ TITLe, ~ *See Inmuction, On Reverse Side 1974 February II, 1974 l_ ARCO MID. RIVER ST 2 TO 10295 / / 15 ARCO McARTHUR ST. No. I TD 10255 ' ~.-.~ 44'17r"~ ~KING PLATFORM ..... , '->- ...... ' ..... cF_ _.. ~ ~ -- ~-'~-';-?-~.. / - 31x-19 0.. ..- 12 ._~ .,, .,... ..,. // / \ \\x_ x,~x x,, - "-~. ~.~ _o- - - ...- ~'- ' . / / // v42-1]~. -', .-' -" /× / \ x.q.x\ \ '". \\ ""'~-_ '"--.~-,. 12- 22 ~ - .-" ~.- ../ ./ < x,\ x \ '\ \lO "--~._kJ ARcO '~'12-.20 // \ ',', \ 'x x. '*. '"--.. W F U NO 3 ×/ ' // \ XK'\ \x. \."'x \~11 '~'--~ TO 9768 /'/ / \ / 20 \ --. \ , ... / \x,,, x 'x x,,~ / \ \ \ x \ \ '0', 32-20 ' \ xx x\ x\ \ \ x \ \ k x\ \\ '"'"x / ./ / / / / ./ / / / / / / I 30 29 28 ~'--~32-22 \ x \ \ 12X- 27 27 ATLANTICRICHFIELD COMPANY ALASKA DISTRICT WELL LOCATION MAP TRADING BAY UNIT STATE K-19 (~2-19) .q I- 18- 74 ~,-a, = ,"- o n,-,n' '0.: I000. 2000, AtlanticRichfieldCompany Hole Casing Size Size 30" 24" 17-1/2" 13-3/8" 12-1/4" 8-1/2" 9-5/8" 9-5/8" 9-5/8" 9-5/8" North American Producing Division North Aias~{ istrict Post Officebox 360 Anchorage, Alaska 9950'1 Telephone 907 277 5637 February 7, 1974 Mr. Karl Vonderahe State of Alaska Department of Natural Resources Oil & Gas DivisiOn 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Vonderahe: In regard to your telephone conversation of February 6, 1974 with Mr. Jim Keasler in which You requested additional information and clarification of Atlantic Richfield's Application for Permit to Drill the Trading Bay Unit K-19 (32-19), here is our revised proposed casing program for the well: Weight Per Foot Grade 157.5# B 61# K-55 Setting Quantity of ~ Cement 381' (existing) Circ to surface. 2700' Circ to surface w/1350 sx 47# N-80 0-3000' 40# N-80 3000-5550' 40# JL-95 5550-7050 ' 47# USS-95 7050-12150' Class G w/2.3% prehydrated gel + 400 sx Class G. 900 sx Class G w/0.2% HR-7 and 1,0%. CFR-2. 29# N-80 11900-13700.' 480 sx Class G w/0.3% HR-7 and 1.0%. CFR-2. ,~ ~ ,~ Please call if you need further information. Very truly yours, L. N. Bell Dist. Drilling Supt. LNB :11 cc: Mr. Jim Callender Company Lease & Well No. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1. Is well to be located in a defined pool ................. /~ 2. Do statewide rules apply ........................ m Is a registered survey plat attached ........ , ......... 4. Is well located proper distance from proper, ty line ........... /¢~m~ . t Is well located proper distance from other wells ............ .~;¢- Is sufficient undedicated acreage available in this pool ........ 7. Is well to be deviated .............. 8. Is operator the only affected party ................... ~ __ 9. Can permit be approved before ten-day wait ............... ~/¢ ., 10. Does operator have a bond in force ................... A/caE ll. Is conductor string provided .............. - ....... 12. Is enough cement used to circulate on conductor and surface ..... 13. Will cement tie in surface and intermediate or production strings ..... ~_ ____ 14. Will cement cover all possible productive horizons ........... ,l~'.q! 15. Will surface casing cover all fresh water zones ............ 16.. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. 'Will all casing give adequate safety in, collapse and tension ...... 18. Does BOPE have sufficient pressure .rating ............... ¢¢¢4 ~dditional Requirements: ~, ~~>~' ~;:,~</ ~~ .:~- ~ +~ ~~ -'App ro Va 1~-Recommended: ~! ~}-(!;;-~/ _ OKG ; HWK ' '~y~-. - LCS : ! :! i ' '-!-. ', '.--~ :'-':-;- '- K'; ~}-~-- 'K-':-.-! ! !---i '~-::--' l' ,, , -.- :--~-~-~-:: !-.-i'-i ' . "- .t 1 : ~ . -"-: ' '--i-!-~-- ' ' ,. -- -~ .~ .~--l-- . . . , ~ - ":-",'~-, ~,,: 'r~--'-fl-~-i · i ,, j ?--$ i .... -l-~'F----;--I-~-~, ..... :--[--! ""_-~-h-~'~-'- _.iTi--:_ -i :'-!- · ---. --~ ..... : i- .............. 1--~T--F---_i !_,._ . .... ~ ...... ;.L ; '_' ~ ' ' ' -;J!L'i_:~_-~ .... .--i--: ~ ' I ' · - ......... I- --' : : 'K"T~-? 'ii!iL ----r--i--!-: --~ '-~ ; i I4- : i . : I I i i , 5._1. ' I ! i i i i I I i-i_._~.~__~__+___ 7-I I : i --F-'i ...... F' t t