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208-197
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECENED FEB 19 2019 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ 11Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Sus Well ✓ p ❑ Other: Scale Inhibitor Treatment ❑ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service ❑ 208-197 3. Address: PO Box 100360 6. API Number: Anchorage, AK 99510 50-103-20591-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075, 387207, 387212, 388466, ASRCNPRA02 CRU CD2 -74 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 25007 feet Plugs measured None feet true vertical 7303 feet Junk measured None feet Effective Depth measured 25007 feet Packer measured 17889 feet true vertical 7303 feet true vertical 7083 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3445' 10.75" 3481' 2380' Intermediate 19091' 7.625" 19125' 7385' Production Liner 6115' 4.5" 24350' 7356' Perforation depth Measured depth Slotted Liner Completion, 18235'- 24350' MD True Vertical depth 7192' - 7315' TVD Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 18256' MD, 7239' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker Premier Packer, 17889' MD, 7083' TVD SSSV: Carrico TRMAXX-5E, 2189' MD, 1913' TVD 12. Stimulation or cement squeeze summary: - Intervals treated (measured): 19125'- 25007' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 798 4840 45 876 227 Subsequent to operation: 697 5169 85 971 228 14. Attachments (required per20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 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 Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kavlie.B.Plunkettrobcoo corn yt q Authorized Signature: Date: Q -w-11 Contact Phone: 265-6450 vr' 2/z o /r 9 RBDMS FEB 1 91019 Form 10404 Revised 412017 '-44 L tT Submit Original Only CD2 -74 Scale Inhibition Treatment 1/17/19 Non -Aqueous Scale Inhibitor Squeeze Job pumped from 10:15 hrs to 23:30 hrs on 1/17/19. LRS = Little Red Services • Initial pressure TBG/IA/OA-994/884/662 • LRS pumped 290 bbls Diesel/WAW5206/M209 preflush at 2 bpm, TBG/IA/OA-0/939/674 • LRS pumped 290 bbls 70/30 EG/Seawater and SCW3001WC scale inhibitor main treatment at 2 bpm, TBG/IA/OA — 0/961/657 • LRS pumped 2212 bbls Dead Crude/M209 overflush at 3 - 5 bpm, TBG/IA/OA — 224/934/609 Interval treated: 19125' - 25007' MD STATE OF ALASKA ALO OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment El 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory❑ 208-197 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20591-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075, 387207, 387212, 388466, ASRCNPRA02 CRU CD2-74 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 25007 feet Plugs measured None feet true vertical 7303 feet Junk measured None feet Effective Depth measured 25007 feet Packer measured 17889 feet true vertical 7303 feet true vertical 7083 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 3445' 10.75" 3481' 2380'Su m Mt. c,,,:,--) Intermediate Production 19091' 7.625" 19125' 7385' Liner 6115' 4.5" 24350' 7356' RECEIVED Perforation depth Measured Depth: Slotted Liner Completion, 18235'-24350' MD NOV 14 2016 True Vertical Depth: 7192'-7315'TVD AOGCC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 18256' MD, 7239'TVD �'! Packers and SSSV(type,measured and true vertical depth) Packer: Baker Premier Packer, 17889' MD, 7083'TVD SSSV: Camco TRMAXX-5E, 2189' MD, 1913'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 19125'-25007' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 731 487 926 1316 218 Subsequent to operation: 791 533 847 1284 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 1] 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: N/A Contact Anu Sood Email Anu.Sood@cop.com Printed Name Anu Sood Title Production Engineer Signature Phone 263-4802 Date 1/1444— rT-L Z l t 1 17" - RDDMS ��NOV 1 6 2016 Form 10-404 Revised 5/2015 Submit Original Only • S CD2-74 Scale Inhibition Treatment 10/17/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from 09:15 hrs to 20:15 hrs on 10/17/16. LRS= Little Red Services • Initial pressure TBG/IA/OA—774/1258/579 • LRS pumped 261 bbls Diesel/WAW5206/M209 preflush at 4 bpm,TBG/IA/OA—510/1204/542 • LRS pumped 261 bbls 70/30 MEG/Water and SCW3001WC scale inhibitor main treatment at 4 bpm,TBG/IA/OA—0/1078/489 • LRS pumped 2149 bbls Dead Crude overflush at 3.1-4 bpm,TBG/IA/OA—440/1165/534 Interval treated: 19125'-25007' MD n1 WNS • CD2-74 COnOCOhhillipS "s ate'. Well Attributes I Max Angle&MD TD Alaska IncWellbore API/UWI Field Name Well Status :Incl(°) MD(kKB) Act Atm (ftKB) Lmvoxvf'1015n 501032059100 ALPINE PROD 18,124.00 25,007.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:TRDP Last WO: 36.30 6/28/2009 Well Config:HORIZONTAL-CD2-74,11/161701212:13:36 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 11/16/2012 HANGER,31 ° - Casing Strings Casing Description String 0... 'String ID...Top(ORB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd P. CONDUCTOR 16 15250 36.0 114.0 114.0 62.50 H-40 WELDED Insulated CONDUCTOR Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd Insulated, SURFACE 103/4 9.950 36.0 3,481.0 2,379.6 45.50 L-80 BTC-M 36-114 ti Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd 1111 INTERMEDIATE 75/8 _ 6.875 34.2 19,124.8 7,384.6 29.70 L-80 BTC-Mod ii Casing Description String 0... String ID...Top IRKS) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd IL SAFETY VLV, _ SLOTTED LINER 41/2 3.958 18,234.7 24,350.0 7,356.0 12.60 L-80 SLHT 2.189 Liner Details ,. ,,„. Top Depth (ND) Top incl Nomi... Top(ftKB) (MB) (°) kern Description Comment ID(In) SURFACE, ealh : ► 18,234.7 7,233.0 72.98 SLEEVE 'HR'LINER SETTING SLEEVE 5.750 363,481 GAS LIFT, 6,629 18,247.2 7,236.6 73.11 NIPPLE RS-Packoff Seal nipple 4.890 GAS LIFT, { _ 18,249.7 7,237.3 73.14 HANGER RS-Packoff Seal nipple 4.880 13.352 --. 18,259.6 7,240.1 73.25 XO BUSHING XO BUSHING 5.5"x4.5" 3.940 22,249.8 7,358.2 89.89 Swell Packer 3.958 GAS LIFT, 17.83122,532.2 7,360.2 90.24 Swell Packer 3.958 PAKER. v -, meas ",.� -^ Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd TUBING 4.5x3.5 3 1/2 I 2.992 I 31.2 I 18,255.7 I 7,239.0 9.30 L-80 EUE 8 rd NIPPLE,17,999 I., Completion Details LOCATOR, Top Depth 18,230 ....J (ND) Top Incl Nomi... Top(MB) (ftKB) F) Item Description Comment ID(in) 31.2 31.2 -0.01 HANGER FMC TUBING HANGER 4.500 147.1 147.1 0.08 XO-reducing CROSSOVER 4.5x3.5 3.000 WLEG,18,255 2,189.0 1,912.7 58.98 SAFETY VLV CAMCO TRMAXX-5E 2.812 17,889.0 7,082.5 71.04 PACKER BAKER PREMIER PACKER 2.890 17,998.6 7,118.1 71.04 NIPPLE HES'XN'NIPPLE w2.75"NO GO 2.750 18,230.1 7,231.6 72.93 LOCATOR FLUTED NO GO LOCATOR SUB 2.970 18,254.8 7,238.7 73.19 WLEG 2.990 NTERMEDIATE, 1 1 Perforations&Slots 34-19,125 Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date j(sh... Type Comment 19,595.8 19,600.6 7,378.9 7,388.2 6/24/2009 1.5 PERFP Alternating blank/4.7'pert pups 19,774.7 19,779.5 7,377.2 7,377.2 6/24/2009 1.5 PERFP Alternating blank/4.7'pert pups PERFP, 19,59619601 20,283.2 20,288.0 7,378.5 7,378.6 6/24/2009 1.5 PERFP Alternatingblank/4.7'perf pups 20,496.0 20,500.8 7,377.1 7,377.1 6/24/2009 1.5 PERFP Alternating blank/4.7'perf pups PERFP, 19,77519,779 i ; : I _' 20,718.1 20,722.9 7,375.4 7,375.3 6242009 1.5 PERFP Alternating blank/4.T pert pups _ 20,892.4 20,897.2 7,374.2 7,374.1 6/24/2009 1.5 PERFP'Alternating blank/4.7'perf pups PERFP, - -�- 21,581.2 21,586.0 7,365.8 7,365.8 6242009 1.5 PERFP Alternating blank/4.7'pert pups 20,283-20,288 _. • 21,801.0 21,805.8 7,361.0 7,360.9 6242009 1.5 PERFP Alternating blank/4.7'perfpups PERFP, i-T-a 22,022.7 22,027.5 7,358.8 7,358.8 6/24/2009 1.5 PERFP Alternating blank/4.7 pertpups 20.420.501 22,199.8 22,204.6 7,358.9 7,358.8 6/24/2009 1.5 PERFP Alternating blank/4.7 perfpups PERFP, -22,855.2 22,860.0 7,349.4 7,349.2 6/24/2009 1.5 PERFP Alternating blank/4.T perf pups 20.716z0.723 23,033.1 23,037.9 7,345.7 7,345.7 6009 - 1.5 PERFP Alternating blank/4.7 perf pups 23,688.8 23,693.6 7,357.2 7,357.1 6/24/2009 1.5 PERFP Alternating blank/4.7 perf pups PERFP, L I e i I '._ p• -p•� 23,945.7 23,950.5 7,355.6 7,355.6 6/24/2009 1.5 PERFP'Alternating blank/4.7'perfpups 24,123.7 24,128.4 7,358.2 7,358.2 6/24/2009 1.5 PERFP Alternating blank/4.7'perf pups PERFP, 21,581-21,586 Notes:General&Safety End Date Annotation PERFP, 7/17/2009g Hit NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 21,801-21,806 we III PERFP, 7ll. :.. - 22,023-22,027 . PERFP, VIII _ 22.200-22.205 a I Mandrel Details Top Depth Top Port PERFP, E- (TVD) Incl OD Valve Latch Size TRO Run III22,855.22,860Stn Top(ftKB) (mKB) F) Make Model (in) Sery Type Type (In ( ) ) yp ) (psi) Run Date Com... 1 6,628.9 3,400.8 71.84 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6262009 PERFP, 23,033-23,038 0 Mit. 0 2 13,352.2 5,599.8 70.47 CAMCO KBMG 1 GAS LIFT GLV -BK 0.188 1,706.0 7/162009 ■ 3 17,831.0 7,063.9 7122 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 7/16/2009 23, PE3.RFP, 1= twig g= .689-26941 23,9462 PE3,951FP. R PERFP, 24.124-24,128 a 11-.11 SLOTTED LINER, 18,23524,350 TO,25,007 ! • ConocoPhillips Alaska P.O. BOX 100360 S E I VE -y ANCHORAGE, ALASKA 99510 -0360 �ti`.'.�I`' (��}1 April 01, 2011 Mirka 1 & Gay Cons, Commission 'ct►orage Commissioner Dan Seamount Alaska Oil & Gas Commission -197 333 West 7 Avenue, Suite 100 PPR 8 2'0i a cA Anchorage, AK 99501 «� �' G� D"' Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CO2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 510" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 _ 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a _ 6" n/a 5.25 3/27/2011 GC?2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011
