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200-055
WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Set Record: CD1-44 Run Date: 2/23/2019 200055 30 72 9 April 12, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-44 Digital Data in LAS format, Digital Log Image file 50-103-20335-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: n qtnqll Signed: RECEIVED MAY 0 8 2019 aoGCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ti is REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Ll Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑Q Re-enter Susp Well ❑ Other: POGLM Tubinc Patchn 2. Operator ConocoPhillips Alaska, Inc 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 200-055 3. Address: P.O. Box 100360 6. API Number: Anchorage AK 99510 50-103-20335-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL00255591 1 ADL0380075 1 ADL0380096 CRU CD1-44 9. Logs (List logs and submit electronic and printed data per 20AA025.071): 10. Field/Pool(s): N/A Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,811 feet Plugs measured N/A feet true vertical 7114 feet Junk measured N/A feet Effective Depth measured 12,811 feet Packer measured 9569 feet true vertical 7114 feet true vertical 6959 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' Surface 2789' 9-5/8" 2825' 2375' Production 10,037' 7" 10,072' 7116' Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 9657' 7001' TVD Packers and SSSV (type, measured and true vertical depth) 4.5" WIDEPACK SLE PATCH PKR 9180' MD 6730' TVD 4.5" WIDEPACK SLE PATCH PKR 9210' MD 6749' TVD PACKER - BAKER S-3 PACKER 9569' MD 6959' TVD WRDP - SSSV 1825' MD 1684' TVD 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: N/A N/A N/A N/A N/A Subsequent to operation: IN/A N/A N/A N/A N/A 14. Attachments (required per 20 MC 25070,25.071,825.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Service ❑ Strattgraphic ❑ 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: Authorized Name: Sara Carlisle Contact Name: Rachel Kautz/Sam Carlisle Authorized Title: II IntegritSupervisor Contact Email: n2549ro�conocoohillios.com 1 Authorized Signature: w i W Dati 3/5/2019 Contact Phone: 659-7126 VrL 3//5//9 Form 10-404 Revised 4/2017 .421? 14 RBDMS MAR 0 7 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2019 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the installation of a retrievable tubing patch and POGLM set in producer CRU CD1-44 (PTD 200-055) to repair the well. Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, �' Sara Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. CRU CD1-44 DESCRIPTION OF WORK COMPLETED SUMMARY DATE OPERATION DETAILS CRU CD1-44 was found to have a leak in the tubing at ^'9205', which was repaired by a POGLM patch set Executive across it 10/19/2018. In December 2018 the well was noted to have declined production, so the POGLM Summary patch assembly was pulled to diagnose the production decline. A FCO was performed, a rock screen installed, and the POGLM patch assembly was re -installed. The well achieved a passing TIFL on 3/4/2019. DRIFT TBG w/ 3.71" GAUGE TO TOP OF POGLM PATCH @ 9184' RKB. ATTEMPT PULL POGLM; UNABLE TO 1/3/2019 PASS 5184' SLM WITH PULLING TOOL. BRUSH N FLUSH TBG WITH 3.79" GAUGE & BLB ASSY DN TO 5000' RKB. IN PROGRESS. RIH WITH FISHING BHA, LATCHED INTO FISH AT 9164' CTMD, GOT 3 JAR HITS AND FISH MOVED UP HOLE 50' HUNG UP AGAIN @ 9114' CTMD, STARTJARRING AGAIN, 38 JAR HITS, FISH MOVED ANOTHER 50' 1/19/2019 BEFORE GETTING HUNG UP AGAIN, START JARRING AGAIN, 10 JAR HITS IN FISH STARTED MOVING AGAIN, WORKED FISH UP AND DOWN, STARTED TO MOVE FREELY UP THE HOLE. OOH WITH FISH. RECOVERED UPPER PACKER AND SPACER PIPE. 90% OF THE ELEMENTS INTACT. JOB IN PROGRESS. RIH RECOVERED LOWER PACKER @ 9217' RKB, OOH ALL ELEMENTS RECOVERED. MAKE UP MOTOR AND 1/20/2019 MILL, RIH TAG NIPPLE AT 9644', OOH PERFORM WEEKLY BOP TEST, JOB IN PROGRESS. RIH WITH JSN, DRIFTED CLEAN ALL THE WAY TO 10,000' CTMD, PU HOLE TO 9600' CTMD, CAME ONLINE STARTED CLEAN OUT, CLEANED OUT DOWN TO 10130' RKB, TAKING 25' BITES AND CHASING ALL THE WAY INTO THE 4.5" TUBING, THE FINAL GEL SWEEP WE CHASED FROM 10130' ALL THE WAY TO SURFACE, WE 2/13/2019 LOST RETURNS AROUND 9670' CTMD FOR JUST A FEW MIN. GOT RETURNS BACK AND CONTINUED OOH. OOH LET WELL FLOW FOR 10 MIN, RBIH DRY DRIFTED TO HARD TAG AT 10194' CTMD. POOH. WELL READY FOR ELINE. SET SLOTTED ROCK SCREEN ON 3.81" XN LOCK @ 9645' RKB. CONFIRM GOOD SET W/ CHECK SET. READY 2/16/2019 FOR E -LINE. SET 4 1/2 WEATHERFORD PACKER @ 9214' RKB ME (ALPCP450003 / OAL 4.69'), SET 4 1/2 ER TEST TOOL @ 2/23/2019 SAME. READY FOR PUMPING. IN PROGRESS CMIT TXIA TO 2500 PSI PASSED. PULLED TEST TOOL @ 9214' RKB. SET 41/2 WFT UPPER POGLM PATCH ASSY @ 9184' RKB w/ 1/4' OV (DAL 30'/ 23'f/ TOP OF PKR TO VLV SN: ALPCP45004 / CPS ALP45005). BLED 2/24/2019 IA DOWN TO VERIFY PATCH IS SET. SET 4 1/2 WRDP (SN: HPS-283) @ 1824' RKB. TOOLS INDICATE GOOD SET UNABLE TO PRESSURE UP CONTROL LINE OR BAL-0 LINE, PUMPED 30 BELS HOT FLUID AND ALLOW PACKING TO SWELL OVERNIGHT. IN PROGRESS. PULLED 4 1/2 WRDP @ 1824' RKB (SN: HPS-283) @ 1824' RKB, REDRESS SAME VLV W/ FREUDENBERG 2/25/2019 PACKING SET 4 1/2 WRDP @ SAME GOOD CLOSURE TESTJOB COMPLETE. TIFL. PASSED Initial T/I/O = 140/1450/950. IA FL @ 9204' (POGLM). SI wellhead @ WV & double block AL. Allow tubing to stack out on its own. Bled IA to 740 psi in lhr. T/I/O = 750/740/895, IA FL unchanged Bled IA to 360 psi in 1hr. T/I/O = 775/360/870, IA FL unchanged Bled IA to 260 psi in 30min. T/I/O = 780/260/860, IA FL unchanged 3/4/2019 Starting T/I/O = 780/260/860, IA FL Unchanged. Monitor for 1 hour. 15 min T/I/O = 790/260/860. 30 min T/I/O = 790/260/855 IA FL Unchanged 45 min T/I/O = 790/260/855 60 min T/I/0 = 800/260/855. IA FL Unchanged Final T/I/O = SI 800/260/855 ConocoPhillips Alaska. Inc. WNS PROD WELLNAME CD1.44 WELLBORE CD1-44 11 COIF R.I.... ON Last Tag Vumlv++mtielsBi) AnmGtbn NNPUNOKBl I End Nve I MO.. I WlNmey _ _.... ....RT ..... Last Tag- CD1-04 Xaggea wwaeR: us ......._........,.,_..... Last Rev Reason .-antan Em bN wmaorc L.n Mm ev Rev Reason: Set Rock ScreenB POGLM palcp 2/252019 CD1-04 deytg G"Ing Strings -11 CaslnB anmPtlw GG llnl IO OUT T.PlnKel Sq CaPavea) 3¢4 DBM171 LVIILen IIITIORRia rwrnma CONDUCTOR In Iwom 16 15.06 36.0 1140 114.0 62.50 1440 WELDED 42 CONDUCTOR Ne,Y 4' x o-ua° easkq basenpimn WON) ID NO Tw IRKa) 8wosgness) sU apn pvej... Wtll,in 11...r.. .PTO. SURFACE 959 8.92 36.4 2,8250 2,3]481 IBTC-M0D cB.Inv CaecxPtlan oolln) to llnl Top IMLBI 3q Deple Ove"set DeP3, Ovuk�� Vlblen lA.. Gra4e rw Tl,nsE PROWCTION ) 828 35.2 10.0713 ),1159 26.00 LA0 E. rvIPP1E+alae Ceslw Mwxpllen oo On) Ib lin) rw MKel 3q Dep11+(NKa 3q DepMnW1... VMan(I janwe rwmiw4 OPEN HOLE 8118 10,0]00 12,811.0 wRDP. +.aNl Tubing Strings Tubing De:cxp0on sXlw MR-113906n)D Toa 1X1(el Sq DegF 11L. see oepiM1 INo1 (.. vn OMnl GMe ton cannecMon TUBING 4112 32.3 9,6520 >,000] 12.60 L -BO IBTM Completion Details lop(T ) Tan Incl Nqn Wl Tw MKaI IRKBI 1') wm o.. Com ID OM 3231 32.3 000 HANGER FMC TUBINGHANGER 4WD sURFACE:sc.628aa- _ 1,824.7 1,883.6 45.11 NIPPLE CAMCO BAL MV 3V 3.812 9,514.5 Qg320 59.05 NIPPLE MES %NIPPLE 3A13 G0.4 uPT; A44].e 9,5683 8958.6 80.98 PACKER BAKERS -3 PACKER 3.8]5 9,644) 6,9949 6199 NIPPLE HES %N NIPPLE. ^ROCK SCREEN INSTALLED 2/182019" 3.725 9,655.6 ),000.0 622 WLEG BAKER WIRELINE GUIDE 3.875 GAsuFC..D.e Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) mP(WO TaPMd rw IMLs) mKN n oa. Can Ran ow ow) 1,0247 1,6838 45.11 DP WRDP-2 SN:HPS-263, FRUEDENBERGPKG) 126 01 .125 8 9,160.1 6,7195 424) UPPER 4.5" ea a rd Upper Wqe k 42019 2.000 PKR ALPCP4 W) " PPERASSY=WCRAL^ 9,181.fi 6,)32.5 4).61 SPACER PIPE 2.8)5' 10rd NU Spacer Pipe 2242019 2.380 9,2(111 6.)43.8 48.10 POGLM 4.5" C-2-9 w! IandeN tp"OV w�O 2242019 1.000 La1N Fisting Neck wrp UPPER wa; e,+ml 8,203.4 6,]45.1 48.1) SPACER PIPE 28)5"1 rd NU Spacer Plpe 2242018 2380 3PA .NKR.UNN4 8204.0 6,]455 48.19 TUGLEAK TUN, Leak WW 3.958 NNNU B.Af1 a 98095 6.)491 48.36WFDANCHOR 4.5" WeaOedord WP Anr3M' ISN:CPS ALP45005) 2242019 2260 TNGLENC.U.0 LATCH ASSY SPACERPIPE...1 wrDANCNOR UTcxAsr 9,210.1 MaWal 48.3] W DL WLR came rd LewerW a ak (N.2232018 2.380 PKR ALPCP450003) a,.a - 9,6443 6,994.9 61.99 ROCKSCREEN J.81J'%N LOCKMROCK SCREEN IDAL=143") 2]1&2019 O.00p wF.LMVERPKR:IC1..1 Frac Summary GUI UFT:vnla .NN Ronan" DnFUenadi C) ProPWnINFORNOURnlB) &122000 s1PP Ma DaM TwwgRles) aroma)tlnk mFNla syapm Vel cMan leell vq slumlbw 1 &112078 10,0]00 12,811.0 s 013 Prepwnt wabnW libj P,ayyanlln Fa,metlm llN 332013 W. I9hngb Twoneores) ii;; Me) an"UNsyebm Vq CINnLEGg Vo19NNy laNl 1 322013 10,0700 12811.0 Mandrel Inserts al XIPPLE:B.5145 nd N T.PIWD) Nlve LI Ponshe MOND TOP Iwo) MKa) Mab. Mo4N OD On) Sa,r Tyye Typ Iml 1 aNa I ennoNe Can 4.307.81 3,M.7 JCAMCO KBG2 I 1 IGAS LIFT JGLV BK BASS 12,0]9.0 j3VI6Q013 2 6,9185 5,184.5 CAMCO KBG-2 I 1 GAS LIFT IGLV BK 0.188 2,014.0 &ta201J J 9,411.3 80)6.0 CAmCO "Ia-2 1 1 GASUFT DV BTM 0.000 0.0 1011&2018 Notes: General & Safety vACKPx asm.T am An mwn &232010 NOTE VIEW SGNEMATIC wIAlaska SCM1ematic9.0 NOTE: TURN kak bund 9 9204' RKB NPPLE veq.T ROGK3CREEH:&W.] 6 g .:e.&s.e 6r PRDouC110N:a2-mmlI R. -RUC: I. Ma FPAC:IO.PMO OPER XIXE fO.NOb11,Rlt 0 STATE OF ALASKA AL OIL AND GAS CONSERVATION COMAION 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 ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory ❑ 200-055 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20335-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559, 380096 CRU CD1-44 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 12811 feet Plugs measured None feet true vertical 7114 feet Junk measured None feet Effective Depth measured 12811 feet Packer measured 9569 feet true vertical 7114 feet true vertical 6959 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2789' 9.625" 2825' 2375' SCANNED NOV ���' Intermediate Production 10037' 7" 10072' 7116' RECEIVED Liner Perforation depth Measured Depth: Open Hole Completion 10072'- 12811' AUG 2 8 2017 True Vertical Depth: 7116-7114 feet Gcc Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 9657' MD, 7001"TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 9569' MD, 6959'TVD SSSV: WRDP, 1825' MD, 1684'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10072'- 12811' 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: 343 300 1277 1263 176 Subsequent to operation: 358 303 1311 1174 185 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E 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 Kaylie Plunkett Email Kavlie.B.Plunkettcop.com Printed Name // — Kaylie Plunkett Title Production Engineer Signature iy.�,/L_. .. f Phone 265-6450 Date 1-2$-1"7 as Vri- 1n/4' /!?- 401611/7 RBDMS 1,1/ 2 8 2017 Form 10-404 Revised 5/2015 Submit Original Only • • CD1-44 Scale Inhibition Treatment 7/27/17—7/28/17 Hybrid Scale Inhibitor Squeeze Job pumped from 00:00 on 7/27/17 to 07:45 on 7/28/17. LRS= Little Red Services - Initial pressure TBG/IA/OA-300/1240/940 - LRS pumped 100 bbls Diesel/WAW5206/M209 preflush at 2.4—3.0 bpm,TBG/IA/OA- 0/1120/870 - LRS pumped 100 bbls Seawater/SCW720 scale inhibitor main treatment at 3.0—4.0 bpm, TBG/IA/OA—0/1060/860 - LRS pumped 1175 bbls dead crude/M209 overflush at 2.0—4.0 bpm,TBG/IA/OA—0/1100/940 Interval treated (MD): 10072'—12811' STATE OF ALASKA • • AKA OIL AND GAS CONSERVATION COMMISSION 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 E Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 200-055 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20335-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559, 380096 CRU CD1-44 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 12811 feet Plugs measured None feet true vertical 7114 feet Junk measured None feet Effective Depth measured 12811 feet Packer measured 9569 feet true vertical 7114 feet true vertical 6959 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' Surface 2789' 9.625" 2825' 2375' Intermediate Production 10037' 7" 10072' 7116' Liner NNED2s-, 23a .fC I . Perforation depth Measured Depth: Open Hole Completion 10072'- 12811' ..:1.1q,," 2 6 True Vertical Depth: 7116-7114 feet 2016 Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 9657' MD, 7001"TVD AOGCC Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3, 9569' MD, 6959'TVD SSSV: WRDP-2, 1825' MD, 1684'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10072'- 12811' 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: 614 377 1273 1334 170 Subsequent to operation: 641 430 1378 1496 174 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development LI 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: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature ig 'iPhone 265-6579 Date 7.12511C, Y71- 3/4 Jb Form 10-404 Revised 5/20154 i�Y�6 RBDMS LI Ftp 'l 6 2016 Submit Original Only • • CD1-44 Scale Inhibition Treatment 1/27/16—1/28/16 Hybrid Scale Inhibitor Squeeze Job pumped from 21:30 on 1/27/16 to 09:06 on 1/28/16. LRS= Little Red Services - Initial pressure TBG/IA/OA- 500/1300/870 - LRS pumped 100 bbls Diesel/WAW5206/M209 preflush at 2 bpm,TBG/IA/OA-0/1160/820 - LRS pumped 100 bbls Seawater/SCW3001 scale inhibitor main treatment at 2 bpm,TBG/IA/OA- 0/1200/760 - LRS pumped 1152 bbls dead crude overflush at 2 bpm,TBG/IA/OA—0/1400/740 Interval treated (MD): 10072'—12811' • F WNS PROD CD1-44 • ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Welmore API/UWI Field Name Wellbore Status ncl/3 MO(ftKB) Act Btm(ftKB) [....,,,,,,, 501032033500 ALPINE PROD I 91.61 12,232.19 12,811.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD1-44,825/20147:40.11 AM SSSV:WRDP Last WO: 43.79 5/21/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET WRDP,REMOVE FRAC hipshkf 8/24/2014 SLEEVE ll) Casing Strings HANGER,32.3 ( I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 if— f, CONDUCTOR Insulated 16 15.062 36.0 114.0 114.0 62.58 H-40 WELDED 4T Casing Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread _� j SURFACE 95/8 8.921 36.4 2,825.0 2,374.6 BTC-MOD I`' Casing Description 00(in) 1D(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 111 PRODUCTION 7 6.276. 35.2 10,071.7 7,115.9 26.00 L-80 BTCM I �it Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WhLen(I...Grade Top Thread li r!!!1 OPEN HOLE 6 1/8 10,070.0 12,811.0 Tubing Strings •_ ,!R Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 32.3 9.657.0 7.000.7 12.60 L-80 IBTM CONDUCTOR Insulated 47; a Completion Details 36.0-114.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Com (in) 32.3 32.3' 0.00 HANGER FMC TUBING HANGER 4.500 1,824.7 1,683.8 45.11 NIPPLE CAMCO BAL-O SSSV 3.812 NWRDP;1;2244..77 IPPLE \ 'c'' 9,514.5 6,932.0 59.85 NIPPLE HES X NIPPLE 3.813 i 9,568.7 6,958.6 60.98 PACKER BAKER S-3 PACKER 3.875 E 9,644.7 6,994.9' 61.99 NIPPLE HES XN NIPPLE 3.725 9,655.6 7,000.0 62.24 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ( Top(ND) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) " 1,824.7 1,683.8 45.11 WRDP WRDP-2(Ser.No.HPV-266) 3/16/2014 2.125 Stimulations&Treatments Mm Top Max Btm Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,070.0 12,811.0 7,115.8 FRAC 3/122008 C-SAND FRAC,335,113#16/30 BADGER SAND SURFACE;36.42,825.0— 10,070.0 12,811.0 7,115.8 RE-FRAC 3/3/2013 RE-FRAC-Pumped 95k pounds of the 327k pound Alpine C formation re-frac design;40-bpm,4340-psi TP.Encountered problems with PCM gel mixing equipment necessitating early flush during 4-ppa t' stage;achieved proper flush with 56-bbl x-link and 56- bbl linear,followed by 56-bbl freeze protect GAS LIFT;4,307.8 "I' Mandrel Inserts St aft D (psi) Run Date m on Top(TVD) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) 1 4,307.8 3,396.7 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 2,079.0 3/16/2013 1 GAS LIFT GLV 'BK 0.188 2,014.0 3/16/2013 0.250 0.0 3/14/2013 2 6,918.5 5,184.5 CAMCO KBG-2 3 9,411.3 6,876.0 CAMCO KBG-2 1 GAS LIFT OV BKO3 Notes:General&Safety GAS LIFT;6,918.5 Gilt End Date Annotation a 8/23/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT;9,411.3 CT. i NIPPLE;9,514.5 i ` 04 PACKER;9,568.7 m NIPPLE;9,644.7 WLEG;9,655.6 fl PRODUCTION;35.2-10,071.7-,, FRAC;10,070.0 RE-FRAC;10,070.0 OPEN HOLE;10,070.0-12,811.0 4 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~:r~_ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) Glor items: o Diskettes, No D Maps: ayscale items: D Other, No/Type D Other items scannable by large scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds TOTAL PAGES: r~ ¢ NOTES: ORGANIZED BY: BEVERLY BREN,~~HERYL MARIA LOWELL [] Other Project Proofing [] Staff Proof By: Date: Scanned (done) PAGES: ? ¢ (at the time of scanning) SCANNED BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELL Isl RESCANNEDBY.* BEVERLY I~VlNCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: Quality Checked (done) Rev1 NOTScanned.wpd s �.,. -. NNW It WV STATE OF ALASKA t 2 ALJ OIL AND GAS CONSERVATION COMWSION REPORT OF SUNDRY WELL OPERATIONS A G CC 1. Operations Performed: Abandon fl Repair w ell I Plug Perforations j Perforate r Other E Alter Casing r Rill Tubing [ Stimulate - Frac I✓ Waiver E Time Extension E Change Approved Program EOperat. Shutdow n (""' Stimulate - Other I Re -enter Suspended Well j"'" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development It/ Exploratory r 200 -055 3. Address: 6. API Number: � Stratigraphic j""" Service E P. O. Box 100360, Anchorage, Alaska 99510 50 - 20335 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559, 380096 CD1 - 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 12811 feet Plugs (measured) none true vertical 7114 feet Junk (measured) none Effective Depth measured 12811 feet Packer (measured) 9569 true vertical 7114 feet (true vertical) 6959 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2789 9.625 2825 2375 PRODUCTION 10036 7 10072 7118 Perforation depth: Measured depth: open hole 10070' - 12811' Kum APR 1 7 2013 True Vertical Depth: open hole 7118' -7114' Tubing (size, grade, MD, and TVD) 4.5, L -80, 9657 MD, 7000 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 9569 MD and 6959 TVD SSSV - CAMCO BAL-0 NIPPLE @ 1825 MD and 1684 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10070' - 12811' Treatment descriptions including volumes used and final pressure: 95000# pumped 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 468 1922 467 -- 170 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I — Development W. Service fl Stratigraphic E 16. Well Status after work: Oil j;� Gas E WDSPL E Daily Report of Well Operations _XXX GSTOR E WINJ r" WAG r GINJ r SUSP E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -047 Contact Robert Blakney (a. 265 -6417 Email Robert. G. Blakney(aconocophillips.com Printed Name Robert : akne Title Completions Engineer Signature / Phone: 265 -6417 Date / ,so 43 vr Form 10-404 Revi etrTY /2+ 'f% 21 2Oij 4 - 4/17/13 Submit Original Only �/--/_, CD1 -44 Frac Summary DATE SUMMARY • • 2/13/2013 STANDBY AT CD3 -119 UNABLE TO ACCESS WELL DUE TO RETURN LINE PLACEMENT FOR COIL SET UP. MOVED TO CD 1 -44. CD1 -40 WAS BEING CIRCULATED TO CD1-44 STANDBY TO RIG UP TO WELL. WAITED ON FREEZE PROTECT. 2/14/2013 DRIFT TBG TO SSSV, LIGHT PRAFFFIN, PULLED WRDP -2 1828' RKB, WRDP -2 HUNG UP @ 432' SLM, IN PROGRESS 2/15/2013 WRDP -2 STUCK IN WELL STARTING @ 434' , WORKED UP TO 232' SLM. 2/16/2013 FISHED OUT 4.5" WRDP -2, DRIFT TBG w/ 3.78" GUAGE RING & 3.94 BRUSH, ATTTEMPT TO SET CAT STANDING VALVE IN XN NIPPLE @ 9656' RKB, TEST FAIL. 2/17/2013 CAT STANDING VALVE " FAIL" SET IN XN @ 9624' SLM( 9656' RKB) PU OUT HOLE , REDRESS CAT STANDING VALVE SET IN XN 9656' RKB, FAIL, PULL CAT OUT 2/20/2013 SET CAT STANDING VALVE IN XN NIPPLE @ 9624' SLM, PULLED OV FROM STATION #3 @ 9408' SLM, LRS CIRCULATING OUT TONIGHT. 2/20/2013 LOAD TBG & IA WITH 250 BBLS OF SEAWATER FROM DRAIN HEADER DOWN TBG TAKING RETURNS UP IA TO PRODUCTION. PUMPED 100 BBLS OF CRUDE FROM HEADER DOWN TBG. U TUBED TBG X IA FOR FREEZE PROTECT. WELL READY FOR SLICKLINE. 2/21/2013 SET DUMMY GLV @ 9408' SLM, MIT @ 3500PSI TBG/ IA, PASS, PULLED CAT STANDING VALVE FROM XN NIPPLE @ 9624' SLM. UNABLE TO PUMP DOWN CONTROL & BALANCE LINES, IN PROGRESS. 2/23/2013 SET 4.5" FRAC SLEEVE @ 1801' RKB. (2 TIMES) UNABLE TO MAINTAIN CONTROL LINE PRESSURE. LRS PUMPED 30 BBLS HOT CRUDE, PACKING HOLDING PRESSURE NOW BUT HAS SLOW LEAK. WELL READY FOR FRAC. * ** *NOTE: WATCH CONTROL & BALANCE LINES FOR THERMAL EXPANSION DURING FRAC * * * ** 3/3/2013 Pumped 95k pounds of the 327k pound Alpine C formation re -frac design; 40 -bpm, 4340 -psi TP. Encountered problems with PCM gel mixing equipment necessitatingearly flush during 4- ppastage; achieved proper flush with 56 -bbl x -link and 56 -bbl linear, followed by 56 -bbl freeze protect. Rigged out PCM to troubleshoot issue. Currently reloading and heating water. WNS CD1 -44 ConocoPhillips ifi Well Attributes Max Angle & MD TD ;5 /8 /494 hN' Wellbore APWWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) aonocarierips 501032033500 ALPINE PROD 91.61 12,232.18 12,811.0 ` "" Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -- SSSV: WRDP Last WO: 43.79 5/21/2000 Well Contip: - CD1 -04, 3/712013 1'.5829 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason GLV 010, FRAC Sly, FRAC osborl 3/7/2013 Casing Strings A 1 Casing Description String O. String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) .. String Wt... String .. String Top Thrd HANGER.32 ; -' r CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 H-40 WELDED Insulated 42" 1 / Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd s SURFACE 95/8 8.921 36.4 2,825.0 2,374.6 BTC - MOD 6, , Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.2 10,071.7 7,117.5 26.00 L - 80 BTCM 4 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 / OPEN HOLE 6 1/8 6.125 10,070.0 12,811.0 1 I Tubing Strings Tubing Description String 0... String ID ... ITop (ftKB) Set Depth (1... !Set Depth (TVD) ... String Wt.. 'St g ... String Top Thrd TUBING 41/2 3.958 32. 9,657.0 7,000.1 12.60 L -80 IBTM t M CONDUCTOR Completion Details Insulated 42', - Top Depth 36 -114 d (TVD) Topincl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) or 32.3 32.3 -0.94 HANGER FMC TUBING HANGER 4.500 1,824.7 1,684.2 46.74 NIPPLE CAMCOBAL -0 SSSV 3.812 NIPPLE, 1,825 FRAC SLEEVE, \ 9,514.5 6,931.9 59.85 NIPPLE HES X NIPPLE 3.813 1,825 9,568.7 6,958.6 60.98 PACKER BAKER S -3 PACKER 3.875 9,644.7 6,994.9 61.99 NIPPLE HES XN NIPPLE 3.725 9,655.6 6,999.4 61.83 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 1— Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 1,824.7 1,684.2 46.74 FRAC SLEEVE SET 4.5" FRAC SLEEVE @ 1801' RKB. (2 TIMES) UNABLE 2/23 /2013 2.750 TO MAINTAIN CONTROL LINE PRESSURE. LRS PUMPED 30 BBLS HOT CRUDE, PACKING HOLDING PRESSURE NOW BUT HAS SLOW LEAK. WELL READY FOR FRAC. ""NOTE: WATCH CONTROL & BALANCE LINES FOR THERMAL EXPANSION DURING FRAC ""' SURFACE, • 38 -2,825 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (MB) (ftKB) (ftKB) Type Date Comment GAS LIFT. ! 10,070.0 12,811.0 7,117,4 RE -FRAC 3/3/2013 RE -FRAC - Pumped 95k pounds of the 327k pound 4,306 1 Alpine C formation re-frac design; 40 -bpm, 4340 -psi TP. Encountered problems with PCM gel mixing equipment necessitating early flush during 4 -ppa _ stage; achieved proper flush with 56-bbl x -link and 56-bbl linear, followed by 56-bbl freeze protect 10,070.0 12,811.0 7,117.4 FRAC 3/12/2008 C -SAND FRAC, 335,1136 16/30 BADGER SAND Notes: General & Safety End Date Annotation GAS LIFT, 8/23/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 6918 GAS LIFT, 9,411 NIPPLE. 9,514 1 ` r PACKER. 9,569 NIPPLE, 9,645 Mandrel Details Top Depth Top Pon ii * s,.. (TVD) Inc( OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... WLEG, 9,656 1 4,307.8 3,396.5 47.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 2 6,918.5 5,184.5 48.60 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 3 9,411.3 6,875.8 54.33 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 2/21/2013 PRODUCTION. 35- 10,072 FRAC, 10,070 RE -FRAC, • o 10,070 OPEN HOLE, ' • 10,070 - 12,811 12,811 V F O TFJ • • .0" I % %-c 4, THE STATE Alaska 011 and as Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O. ' Anchorage, Alaska 99501 -3572 L W Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney SCANNED `MAR 5 2013 Completions Engineer 'AID 0 (] 55' ConocoPhillips Alaska, Inc. o� P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1 -44 Sundry Number: 313 -047 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair I DATED this 1 day of February, 2013. Encl. 411 RECEIVED ' STATE OF ALASKA 9..., JAN 3 12013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO 20 z./� l3 20 AAC 25.280 AOGC 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate p Alter casing r Other: r 2, Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R;i . Exploratory r 200 - 055 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20335 - 00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned pezforations require spacing exception? Yes r No r CO1 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25559, 380096 Colville River Field / Alpine 011 Pool 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): 12811 7114 - 12811' 7114' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2789 9.625 2825' 2375' PRODUCTION 10036 7 10072' 7118' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • open hole open hole 4.5 L - 9657 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 9569 TVO= 6959 SSSV - CAMCO WRDP -2 MD =1825 TVD =1684 . 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development W. Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2013 Oil P. Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney Q 265 -6417 Email: Rot; eft .G,Biaknev((conocophiliips.com, Printed Name Robert la} ne Title: Completions Engineer Signature , Phone: 265 -6417 Date / /3O h3 Commission Use Only Sundry Number:'3 5 0 CO Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No t[� Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2- / - /3 pproved application is valid for 12 months from the date of approval. Form 10-403 (Revis d 10/2012) V r RBDMS FEB 0 4 201" i� o rm and Attachments in Duplicate 1 � \moo ORIGINAL 1/31 i � � • • CD1 - 44 Sundry Application Drilling for CD1 - 44 was completed in May of 2000 targeting the Alpine C formation. The well was completed with 4.5" tubing and stimulated in 3/12/2008 with —135,000#'s of 16/30 Badger Sand. We plan to re- stimulate with a single stage fracture using —350,000#'s of 16/20 CarboLite. We expect the increased production to be 150 bpd if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 2700 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 40 bpm with a maximum expected treating pressure of 3660 psi. Stage 1 • 480 bbls YF12126ST Pad • 221 bbls YF12126ST w/ 2 ppa 16/20 Carbolite • 374 bbls YF12126ST w/ 4 ppa 16/20 Carbolite • 348 bbls YF12126ST w/ 4 ppa 16/20 Carbolite • 611 bbls YF12126ST w/ 7 ppa 16/20 Carbolite • Flush with 106 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 350,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). RB • . 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal until they are clean enough for production.) unt t ey g p ) Cement Evaluation of CD1 - 44 and wells within 1 /4 mile of CD1 - 44 CD1 -44: 7" Casing cement job was pumped on 5/14/2000 as designed, indicating competent cement operations. Cement was displaced at 8 bpm using mud, plugs were bumped and floats held. A pressure test was performed to 5000 psi and held for 10 minutes. CD1 -32: 7" Casing cement pump report on 11/21/1999 shows that the job was pumped as designed. A 41 bbl Tail Slurry at 15.8 ppg was displaced with brine - diesel -brine mix at 6 bpm. Pressure test to 3500 psi was held for 15 minutes and deemed OK. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a 1 /4 mile radius or any other nearby well. RB a WNS • CD1 -44 COtIOCOPIIillIps = Well Attributes Max Angle & MD TD k>C W ellbore API /UWI Field Name Well Status Inc! ( °) MD (nKB) Act Btm (ftKB) Alaska, ca,w..�Pf�ps 501032033500 ALPINE PROD 91.61 12,232.18 12,811.0 "" Co m ment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -- SSSV: WRDP Last WO: 43.79 5/21/2000 Well Caner, - 021 - 442/20/20113 4650 PM Schematic - Actual Annotation IDepih(nKB) (End Date (Annotation (Last Mod...1End Date Last Tag: Rev Reason: SET WRDP Imosbor 2/20 /2011 Casing Strings p += Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) .. String Wt... String ... String Top Thrd HANGER 32 1 , 1 CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 H-40 WELDED ; Casing Description String 0... String ID ... Top (ftKB) Set Depth (f--. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.4 2,8250 2,374.6 BTC -MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd , PRODUCTION 7 6.151 35.2 10,071.7 7,117.5 26.00 L -80 BTCM ;:. Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 ' OPEN HOLE 6 1/8 6.125 10,070.0 12,811.0 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Str ng .. String Top Thrd TUBING I 4 1/2 3.958 1 32.3 9,657.0 I 7,000.1 I 12.60 L -80 IBTM Completion Details Top Depth CONDU Nomi... (ND) Topincl Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 32.3 32.3 -0.94 HANGER FMC TUBING HANGER 4.500 ant NIPPLE, 1.825 1,824.7 1,684.2 46.74 NIPPLE CAMCO BAL-O SSSV 3.812 ISO SLEEVE, 1,825 9,514.5 6,931.9 59.85 NIPPLE HES X NIPPLE 3.813 SAFETY i 82 9,568.7 6,958.6 60.98 PACKER BAKER S-3 PACKER 3875 9,644.7 6,994.9 61.99 NIPPLE HESXNNIPPLE 3.725 9,655.6 6,999.4 61.83 WLEG BAKER WIRELINE GUIDE 3.875 _ Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (5303) (nKB) (°) Description Comment Run Date ID (in) I 1,824.7 1,684.2 46.74 ISO SLEEVE ISOLATION SLEEVE 1/30/2011 2.750 1,824.7 1,684.2 46.74 SAFETY VLV CAMCO WRDP -2 (HPS -375) DUAL CONTROL LINES 2/9/2011 2.125 Stimulations & Treatments Bottom M in Top Max Btm Top Depth Depth SURFACE, Dept D epth (ND) ( 38 -2,825 ftKB) - (8K (ftKB) (ftKB) ( Type Date Comment 10,070.0 102,81... 7,117.4 FRAC 3/12/2008 C - SAND FRAC, 335,113# 16/30 BADGER SAND Notes: General & Safety End Date Annotation 8/23/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 4,308 GAS LIFT A t 6918 GAS LIFT ■ 9411 f� ■ NIPPLE, 9,514 1 'i — i p i- ......... PACKER, 9,569 - .,P NIPPLE, 9645 ', Mandrel Details Top Depth Top Port w LEC.9656 (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (n) (poi) Run Date Com... 1 4,307.8 3,396.5 47.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 2 6,918.5 5,184.5 48.60 . CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 3 9,411.3 6,875.8 54.33 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/14/2008 PRODUCTION, • • 35- 1 0,072 OPEN HOLE, . - 10,070 - 12,811 0 TD (CD1 -44), 12,811 FRAC, 10,070 S • Stimulation Surface Rig-Up 5 Bleed / Ton* ri-)2 Tale Tank "W • Minimum pressure rating on all surface treating cp lines 10,000 psi to • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV 7.1a1MICI • Tree saver used on all fracs rated for 15,000 psi. — t DaD8C ti. • yet 47 )9C1 > )Uj dWfld Pop-Off Tar* ?5 : Ft2 Pump Till:* Pop-Off Tank it Li I Frac Pump r "a: rr-1 Frac Pump Frac Pump j Frac PLEop Fr Pump Ilt" Frac Pump RB • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION , p • ::-) SAAN,'LLE,g igNSEggn-'2gNi ggsWgiDggEi. iNgSig.Rrt 0 RA rRON , i 1 g 1 ; / CONNECTION : i 1 / 34( / 4- k , . , ,,,,-- . ),---- Ar- : / : A,' 4 * * 4 4 5 1 ‹'''''''' 41, EMETTE OAT) ... ..,.., , . / MANUAL OPER.ATED MASTER VALVE g .g.g4rigrir.g. i MRMORMON g mominearer , ' g g tegragenwegat g, 7 cii : g , ',..."4 • , • & f e ar, ,,, ' NV Stinger g Stinger '4\g 1 . 1 lir 7 1 i f 3" f ., LAANCEEEL g gs VENT i I OPEN g •- 4,:g NtVg ! 1 gille rgl. g - ....-2: :VA 0 g . k AN , 01 X. . Ne k ' A , , R OW TEE AND I . . . ... , , . .. i ' WA ';`• 7 ; 4 4 1' 4 VENT VALVE VALVES g g . WELLHEAD f t VALVES as.) QUAD RACKOFF ASSEMBLE IN '*gg jig ''''- '1 g.......... PEACE IN TUBING ( g 4 4 ..1.„.4 ,,,,„„....4... TURREG ggEgg , ; :gg ... gg „ . • The universal tool is rated for 15,000 psi and has 84” of stroke. • Tool ID 2.25" down 4 Y2 tubing and 1.75" down 3 V2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB • CDI-44 Alpine C Frac Model • Frac Design Job Description Step Pump Fluid Name Step Gel Prop. Prop. Nae Rate Fluid Conc. Type and Mesh Conc. (bbl /mi Volw (lb /mga (PPA) III n) _ (gal) 1) PAD 40.0 YF125ST 20160 25.0 0.00 2.0 PPA 40.0 YF125ST 9269 25.0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 15727 25.0 CarboLite 16/20 4.00 6.0 PPA 40.0 YF125ST 14637 25.0 CarboLite 16/20 6.00 7.0 PPA 40.0 YF125ST 25721 25.0 CarboLite 16/20 7.00 Flush 40.0 TJF130 7041 30.0 0.00 Fluid Totals 85513 gal of YF125ST • 7041 gal of WF130 Proppant Totals 349300 lb of CarboLite 16/20 ' I I M odel Initial Fracture Top TVD ftj . Initial Fracture Bottom TVD 7150.0 ft • Propped Fracture Half - Length 408.5 ft EO.T Hyd Height at Well 175.4 ft Average Propped Width 0.357 in • Disclaimer Notice: — This model was generated using vendor supplied modeling software and is based on engineering estimates of reservoir • properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. CD1 -35 �: H�1 -21L1 • D1 -02 • CD2 463 ` CD1 -30 T • :.D1 -3t • CD1 -21 �CD1 -22A I CD2 -28 , • • • • CD2 -13P8. 1 • D2-i7A : D2 -16 ! ` 4: C D1-01 • f • r BERGSCI'lRUND 1 • CD1 -21 PB1 4 ' -19A 1CD 1 -36 i -22 •` '•CD1 -30PB1 • CDY -28P4 • , • 1' 141 • • Al PINE 1A ` CD2 -17 �., �Dl•01 P :1 • CD1 -32PB1 • CDi 4P• F • 'a CD1 -44 , .,. ) . .. . 1 ,,.,%••;•1 �'•l :; ;•.' Legend ' .. ` ""': , `• ` \ , W e ll '• ° �:, Suspended • CD2 -34PB1 r + P +A • .,., i ' Service • r y :� CD•l -4$PB1 '( • Producer • • ■ '• i • Observation t ` t a2 . 34 • Injection: SW • � ' • '•'. `'` • •:ALPINE 1 CD2 -19 ' ♦ Injection: SAPW • \ G • ♦ Injection: PW 2 - 26 i Injection: MWAG • L"D1 -33 ACTIVE, INJ, MG • • ACTIVE INJ, IWAG • • '` • ACTIVE, INJ, GAS • . r C -34 ACTIVE, INJ, DG •' • ACTIVE, INJ, <Null> • ,'Cpl -46 ' CD2 -39r C j 45 \'•, * Disposal • 1/4 Mile Radius •\ \CD2 - :D1ti43 1 -39PB1 • D2 -50 • _ CD2 44 •• •t ALPINE 1B•. • CD1 -38PB �10coP ill ips • 4 • T . ' : D 2 45 CD1 -44 Fracture Radius • CD2 -35A N CONFIDENTIAL CQ1 -38 0 o.zs o.s •• \ •• /�\ I ' Miles •• _ , `` NanugPOD2012 CSR 10242012 • STATE OF ALASKA ALJ OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Ffrrforations f Ferf orate r Other r Alter Casing r Rill Tubing E Stimulate - Frac f" Waiver r Time Extension }- Change Approved Program r Operat. Shutdow n r Stimulate - Other E,-,/ Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r _ - 200 - 055 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic f Service r 50- 103 - 20335 -00 ` og 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25559, 380096, 380075 +• CD1 - 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 12811 feet Plugs (measured) none true vertical 7114 feet Junk (measured) none Effective Depth measured 12811 feet Packer (measured) 9569 true vertical 7114 feet (true vertical) 6959 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2789 9.625 2825 2375 PRODUCTION 10036 7 10072 7118 RECEIVED OCT 1 2 2012 Perforation depth: Measured depth: open hole completion 10070' - 12811' �p Q © n AOGCC True Vertical Depth: 7118' -7114' ,pc N NED JAN L 2.ut" Tubing (size, grade, MD, and TVD) 4.5, L -80, 9656 MD, 7000 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 9569 MD and 6959 TVD SSSV - CAMCO WRDP -2 SSSV @ 1825 MD and 1684 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 290 1508 300 -- 179 Subsequent to operation 589 1910 274 -- 180 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 - Service r Stratigraphic r 16. Well Status after work: Oil p' Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -356 Contact Michael Dammeyer A 265 -6548 Email Michael .Dammeyer @conocophillips.com Printed Name Michael Dammeyer Title: Senior Production Engineer Signature (94---- Phone: 265 -6548 Date /07/' i / i RPT OCT 1 2012 2 to •ISM t--- Form 10-404 Revised 12/2012 ` p(0/12-- Submit Original Only WNS • CDI -44 . ConocoPhillips �� Well Attributes M ax Angle & MD TD ��la,kc1, lilt.. Wellbore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) carocathet, 501032033500 ALPINE PROD 91.61 12,232.18 12,811.0 "°" Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: WRDP Last WO: 43.79 5/21/2000 Well Confiq: - C01 -44, - Actual PM Schematic al Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. Rev Reason SET WRDP Imosbor 2/20 /2011 _._ ___. — Casing Strings u : � x a „ Casing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (TVD) ... String Wt . String String Top Thrd HANGER, 32 r. CONDUCTOR 16 15062 36.0 114.0 114.0 6258 H WELDED t Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.4 2,825.0 2,374.6 BTC - MOD " ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd '1 A PRODUCTION 7 6.151 35.2 10,071.7 7,117.5 26.00 L - 80 BTCM Casing Description String 0... String ID ".. Top (kK8) Set Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd 1 : '''; OPEN HOLE 6 1/8 6.125 10,070.0 12,811.0 , i p 0. Tubinq Strings Tubing Description String 0... String I Top (kKB) Set Depth (1... Set Depth (TVD) .... . String Wt_. String . String Top Thrd ' TUBING 4 1/2 3.958 32.3 9,657.0 I 7,000.1 12.60 L -80 I IBTM Completion Details CONDUCTOR, Top Depth 36-114 (ND) Top Ind Nomi... Top (ftKB) (RKB) (°) Item Description Comment ID (In) 32.3 32.3 -0.94 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1,825 IF 1,824,7 1,684.2 46.74 NIPPLE CAMCO BALD SSSV 3.812 ISO SLEEVE, l 1,825 \\ 9,514.5 6,931.9 59.85 NIPPLE HESXNIPPLE 3.813 SAFETY 1,8 5 v 9,568.7 6,958.6 60.98 PACKER BAKER S-3 PACKER 3.875 9,644.7 6,994.9 61.99 NIPPLE HES XN NIPPLE 3.725 t 9,655.6 6,999.4 61.83 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) E. Top Depth 1 (TVD) Top Inc! ( Top (mg) (ftKB) (°) Description Comment Run Date ID (In) 1,824.7 1,684.2 46.74 ISO SLEEVE ISOLATION SLEEVE 1/30/2011 2.750 1,824.7 1,684.2 46.74 SAFETY VLV CAMCO WRDP -2 (HPS -375) DUAL CONTROL LINES 2/9/2011 2.125 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth SURFACE, Depth Depth (TVD) (ND) 362 -• • (RKB) (ftKB) (RKB) (RKB) Type Date Comment 10,070.0 102,81... 7,117.4 FRAC 3/12/2008 C -SAND FRAC, 335,113# 16/30 BADGER SAND Notes: General & Safety End Date Annotation 8/23/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT. 4.308 E.::: GAS LIFT, _._ )`: 6,918 i i GAS LIFT, -_ -_ � 9.411 _ -- NIPPLE, 9,514 — PACKER, 9.569 NIPPLE. 9.645 a l Mandrel Details WLEG, 9,656 All Top Depth Top Port ;, (ND) Intl OD Valve Latch Size 7RO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Eery Type Type ) n) (psi) Run Date Com... 1 4,307.8 3,396.5 47.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 2 6,918.5 5,184.5 48.60 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 3 9,411.3 6,875.8 54.33 CAMCO KBG -2 1 GAS LIFT OV BK 0.250 0.0 3/14/2008 PRODUCTION, 35- 10,072 OPEN HOLE. 10.070-12.811 TD (C01 -44). 12,811 FRAC, 10.070 • CD1-44 Stimulation Work Summary Job complete. Injection ended 9/30/12 @ 20:50. Injected for —24 hours. 9.2 MMSCF of MI injected. Maximum recorded pressure 1871 psig. f t,' I � j7 9 THE STATE Alaska Oil and Gas F �� °f AL AS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p� Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Michael Dammeyer wt.-- Senior Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 pS"S' Anchorage, AK 99510 < q0 d .. Re: Colville River Field, Alpine Oil Pool, CD1 -44 Sundry Number: 312 -356 Dear Mr. Dammeyer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a Cathy P. Foerster Chair DATED this l / da y of September, 2012. Encl. . • z STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM•ION APPLICATION FOR SUNDRY APPROVALS '=F' 1 4 2012 20 AAC 25.280 ��°° 1. Type of Request: Abandon `" Plug for Redd! r Perforate New Pool (" Repair well r Change�A�PvL �d QCn r Suspend r Rug Perforations r Perforate f Pull Tubing r Time Extension r Operational Shutdow n i— Re -enter Susp. Well "°' • Stimulate j- Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ' Exploratory r 200 -055 • 3. Address: Stratigraphic fl Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20335 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No I CD1-44 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25559, 380096 , > IS Colville River Field / Alpine Oil Pool • 11. Am t 7 , tiv PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12811 7114 ' 12811' 7114' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2789 9.625 2825' 2375' PRODUCTION 10036 7 10072' 7118' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole completion 10070' 12811' 7118' - 7114' 4.5 L - 80 9656 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER MD= 9569 TVD= 6959 SSSV - CAMCO WRDP -2 SSSV MD =1825 TVD =1684 12. Attachments: Description Summary of Proposal p* 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch Exploratory Development F.- Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/28/2012 Oil P . Gas r WDSPL r Suspended F 16. Verbal Approval: Date: WINJ r GINJ r WAG fl Abandoned r Commission Representative: GSTOR fl SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michael Dammeyer @ 265 -6548 Printed Name Michael Dammeyer Title: Senior Production Engineer Signature 10 0 Phone: 265 -6548 Date eVi Y / i Z Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 Z,. 3. G, Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: APPROVED BY L �j Approved by: COMMISSIONER THE COMMISSION Date: / —/ [ — / 2 -- 1 R= D eQ cc vi-r- ORIGINAL P, \'' orn45408 e sgc28I Oi0 Submit in Duplic 1//9//2- CV CD1-44 Conoco Phillips proposes stimulating producing well CD1-44 by injecting enriched gas. • The intent is to increase oil production rate of CD1-44, as this well has never returned to its expected rate since an aqueous scale squeeze on 8/4/12. It is suspected that water may have imbibed into the formation and reduced the near-wellbore oil permeability. Note the potential for the Alpine C sand to imbibe water and reduce oil permeability is documented in SPE 84320. Enriched gas injected into the near-wellbore has the potential to restore oil permeability and suppress the walercut. Proposed treatment procedure: Inject —5-10 MMSCF of enriched gas down tubing over 12-24 hour period, limiting injection pressure to 3000 psi. Leave well shut in for 12 hours after injection. Bring well on production& test well. WNS CDI -44 ConocoPhillips 9 4 Well Attributes Max Angle & MD TD ,R „ , Wellbore API /UWI Field Name Well Status Inc) (°) MD (ftKB) Act 8tm (ftKB) Alaska' Inc' PROD 91.61 12,232.18 12,811.0 cbrnm 501032033500 ALPINE '. Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ”' — SSSV: WRDP Last WO: 43.79 5/21/2000 Well Confia . C91., 0/ 3 46.50 PM Scnemal -A 2/2 Cw 2011 al Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SET WRDP Imosbor 2/20 /2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 32 es �. r CONDUCTOR 16 15.062 36.0 114.0 114.0 62.58 1140 WELDED \ Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SURFACE 95/8 8.921 36.4 2,825.0 2,374.6 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd -- PRODUCTION 7 6.151 35.2 10,071.7 7,117.5 26.00 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ' OPEN HOLE 6 1/8 6.125 10,070.0 12,811.0 Tubing Strings i I Tubing Description Stang 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... Siring Wt... Stang .. String Top Thrd TUBING 14 1/2 I 3 I 32.3 I 9 7,000.1 I 12.60 I L IBTM Completion Details Top Depth CONDUCTOR. 36 -114 (ND) Top Inc) Nom1... Top (ftKB) To (ftKB) ( ( °) Item Description Comment ID (in) 32.3 32.3 -0.94 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1,825 1,824.7 1,684.2 46.74 'NIPPLE CAMCO BAL-0 SSSV 3.812 150 SLEEVE, 1,825 9,514.5 6,931.9 59.85 NIPPLE HESXNIPPLE 3.813 SAFETY 1,825 9,568.7 6,958.6 60.98 PACKER BAKER S-3 PACKER 3.875 1. 9,644.7 6,994.9 61.99 NIPPLE HESXNNIPPLE 3.725 9,655.6 6,999.4 61.83 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) _.. Top Depth (TVD) Top Inc) , 9 Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) a 1,824.7 1,684.2 46.74 ISO SLEEVE ISOLATION SLEEVE 1/30/2011 2.750 1 >•2 1,824.7 1,684.2 46.74 SAFETY VLV CAMCO WRDP -2 (HPS -375) DUAL CONTROL LINES 2/9 /2011 2.125 . Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth SURFACE, .. • Depth Depth (TVD) (TVD) 36 -2,825 (ftKB) (6813) (ftKB) (ftKB) Type Date Comment 10,070.0 102,81... 7,117.4 FRAC 3/12/2008 C -SAND FRAC, 335,1134 16/30 BADGER SAND Notes: General & Safety End Date Annotation — 8/23/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 4,308 GAS LIFT, 6,918 F ==_ GAS LIFT NIPPLE, 9,514 [.., PACKER, 9,589 d NIPPLE, 9,645 1 l t}y Mandrel Details WLEG. 9,656 J ?+ Top Depth Top Port (TVD) Inc) OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 4,307.8 3,396.5 47.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 2 6,918.5 5,184.5 48.60 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 3 9,411.3 6,875.8 54.33 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/14/2008 PRODUCTION, 35- 10.072 OPEN HOLE. 10,070- 12,811 TD (601 -44), 12,811 FRAC. 10,070 STATE OF ALASKF AL/ OIL AND GAS CONSERVAT I,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Fbrforate r Other p... Scale Inhibition Alter Casing r Rill Tubing r Stimulate - Frac r Waiver � Time Extension ` Treatment Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well ""' 1 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 200 - 055 - _ 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 103 - 20335 -00 ~ CO 7. Property Designation (Lease Number): 8. Well Name and Number: AQL25559, 380096 3 g per') I I 1 CD1 -44 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 12811 feet Plugs (measured) none true vertical 7114 feet Junk (measured) none Effective Depth measured 12811 feet Packer (measured) 9569 true vertical 7114 feet (true vertucal) 6959 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114 SURFACE 2789 9.625 2825 2375 PRODUCTION 10036 7 10072 7118 ', RECEIVED Perforation depth: Measured depth: open hole completion 10070'- 12811' AUG 1 5 2012 True Vertical Depth: 7118' - 7114' AOGCC Tubing (size, grade, MD, and TVD) 4.5, L -80, 9657 MD, 7000 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 9569 MD and 6959 TVD SSSV - CAMCO BAL-0 NIPPLE @ 1825 MD and 1684 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10070'- 12811' Treatment descriptions including volumes used and final pressure: 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 810 2611 515 -- 196 Subsequent to operation shut -in for plant turn - around 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 1✓ _ Service r Stratigraphic r 16. Well Status after work: OiI f 7 Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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 none Contact Micheal Dammeyer 265 -6548 Printed Name Michael Dammeyer Title Senior Production Engineer Signature i Phone: 265 -6548 Date l R$DMS AUG 15 2012 � h ' J oz_- iL Form 10 -404 Revised 11/2011 i s f 7/(1' Submit Original Only WNS . CDI-44 �n1, ConocoPhan. s L., I Well Attributes • Max Angle & MD TD N' v . 13 Weilbore APVUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Stir (ftKB) a, hx_ Alaska 501032033500 ALPINE PROD 91.61 12,232.18 12,811.0 Go ocomeeir Comment 112S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: WRDP Last WO: 43.79 5/21/2000 Well Conk] - CD1 -44, 2,20/2011 3:46.50 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SET WRDP Imosbor 2/20 /2011 _ __ Casing Strings `" Casing Description String 0... String ID ... 'Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER.32 ; r CONDU 16 15.062 36.0 114.0 114.0 62.58 H WELDED ., Casing Description String 0... 'String ID ...'Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 36.4 2,825.0 2,374.6 BTC - MOD Casing Description string 0... String ID ... Top (1518) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 35.2 10,071.7 7,117.5 26.00 L BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ■ i OPEN HOLE 6 1/8 6.125 10,070.0 12,811.0 1 Tubing Strings Tubing Description Str 0. String ID ... Top (ftKB) Set Depth (f. Set Dep th (TVD) .. . Str Wt. String ... String Top Thrd TUBING 1 1/2 I 3..958 I 32.3 I 9,657.0 7,000.1 l 12.60 I L. 80 I IBTM Completion Details UCTOR, Top Depth COND 36-114 (TVD) Top Inc! Nomi... TOP (Ttta) (ftKB) (°) Rem Description Comment ID (in) 32.3 32.3 -0.94 HANGER FMC TUBING HANGER 4.500 NIPPLE, 1,825 1,824.7 1,684.2 46.74 NIPPLE CAMCO BAL-0 SSSV 3.812 ISO SLEEVE, 1,625 9,514.5 6,931.9' 59.85 NIPPLE HES X NIPPLE 1813 SAFETY 1. 8 2 V 6 , "` _ 9,568.7 6,958.6 60.98 PACKER BAKER S-3 PACKER 1875 9,644.7 6,994.9 61.99 NIPPLE HES XN NIPPLE 3.725 % 9,655.6 6,999.4 61.83 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 1 (TVD) Top Inc! Top (ftKB) (ftKB) ( ' 1 Description Comment Run Date ID (In) 1,824.7 1,684.2 46.74 ISO SLEEVE ISOLATION SLEEVE '1/30/2011 2.750 1,824.7 1,684.2 46.74 SAFETY VLV CAMCO WRDP -2 (HPS -375) DUAL CONTROL LINES 2/9 /2011 2.125 Stimulations & Treatments Bottom M in Top Max Btm Top Depth Depth SURFACE. ° 1 • Depth Depth (TVD) (P10) 36 -2825 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment _.. _ - 10,070.0 102,81... 7,117.4 FRAC 3/12/2008 C -SAND FRAC, 335,1134 16/30 BADGER SAND Notes: General & Safety E nd Date Annotation ( 8/23/2010 NOTE: VIEW SCHEMATIC wlNaska Schematic9.0 i n GAS LIFT, _ _ i 4,308 f GAS LIFT, 6,918 GAS LIFT, 9,411 NIPPLE 9.514 -- ;I_ PACKER, 9.569 1 NIPPLE, 9,145 t Mandrel Details WLEG, 9,6 4 56 $ Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run Stn Top (11.513) (ftKB) (°) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... 1 4,307.8 3,396.5 47.08 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/972008 2 6,918.5 5,184.5 48.60 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/9/2008 3 9,411.3 6,875.8 54.33 CAMCO KBG-2 1 GAS LIFT OV BK 0.250 0.0 3/14/2008 1 PRODUCTION, Ai- o ' 35- 10,072 OPEN HOLE. ij 10,070 - 12,811 TD (CD1- 44), 12,811 FRAC. 10070 • • Scale Inhibition Treatment: CD1 -44 8/4/2012: Initial pressure TBG /IA /OA — 450/1000/850; Facility pumped 50 bbls SW preflush; LRS pumped 2.7 bbls WAW5206 (113 gal) at 0.4 bpm and facility pumped 25 bbls SW at 4 bpm, 500/1000/850; LRS pumped 27.5 bbls SCW3001WC (1155 gals) at 0.7 bpm and facility pumped156 bbls of SW at 4.7 bpm, 700/1000/850; LRS pumped 2.7 bbls WAW5206 (113 gal) at 0.4 bpm and facility pumped 25 bbls SW at 4 bpm, 500/1000/850; facility pumped 852 bbls of SW over - displacement at 4.3 bpm. STATE OF ALASKA ~~~~~ S ~~ ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~ MAY l 1 2010 t Operations Performed: Abandon ~"` Repair w ell Plug Perforations ~""'" Stimulate ~ ~a~~i011$~~~011 5 7~ Alter Casing Pull Tubing ~""' Perforate New Pool ""°` Waiver ime Extensior~~ Change Approved Program Operat. Shutdown Perforate `" Re-enter Suspended Well ~""` 2. Operator Name: 4. Current Well Status: ,~. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~' Exploratory 200-055 3. Address: Stratigraphic Service '6~API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20335-00 7. Property Designation: 8. Well Name and Number: ADL 25559, 380075 ~CD1-44 9. Field/Pool(s): Colville River Field /Alpine Oil Pool ~ 10. Present Well Condition Summary: Total Depth measured 12811 feet Plugs (measured) None true vertical 7114 feet Junk (measured) None Effective Depth measured 12811 feet Packer (measured) 9569 true vertical 7114 feet (true vertucal) 6959 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 16 114 114 SURFACE 2825 9.625 2825 2375' PRODUCTION 10070 7 10070 7114' Perforation depth: Measured depth: open hole completion 10070'-12811' _ r:~. ~ ~ ' ~vlti ~ ~- ~ ~~~ True Vertical Depth: 7114'-7114' ~+ ~ ' y~1~f Tubing (size, grade, MD, and TVD) 4.5, L-80, 9657 MD, 7001 TVD Packers & SSSV (type, MD, and TVD) PKR -BAKER 'S-3' PACKER @ 9569 MD and 6959 TVD WRDP - CAMCO WRDP-2 BAL-SSA-S - (HJS-20) @ 1825 MD and 1684 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 10070'-12811' Treatment descriptions including volumes used and final pressure: fefer t0 attachment 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1402 2441 222 -- 196 Subsequent to operation 1758 2302 246 -- 187 13. Attachments 1 Well Class after proposed work: Copies of Logs and Surveys run E~loratory """ Development Service "` Well Status after work: Oil ~`', Gas "" WDSPL "" Daily Report of Well Operations XXX " °° " ' WAG " GASINJ ` WINJ SPLUG GSTOR J 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact Brian Barreda (a~ 265-6036 Printed Name Brian Barreda Title WNS Production Engineer Signature I / Phone: 265-6036 Date ~O t.~ ~ O ~ ^, T~V~ C - U ~ / ~=~ [ r Form 10-404 Revised 7/2009 RB~S ~Y ~ 1 Submit Original Only .l ~ry/~~ CD1-44 Well Work Summary DATE SUMMARY 4/11/10 Scale squeeze job pumped 01:00 05:45 hrs on 4/11/2010. Hybrid Squeeze:~7 bbls crude / WAW 5206 mixture (24.4% WAW 5206) at 3.0 BPM with 650# tbg pressure; then pumped 113 bbls SW /SCW 3001 WC mixture (17.7% SCW 3001 WC) at 4 BPM with tbg on VAC; then pumped 13.7 bbls crude /WAW 5206 mixture (24.4% WAW 5206) at 3.0 BPM with tbg on VAC; then over displaced with 1113 bbls crude at 4.5 BPM with tbg on VAC. • Sss~ (1825-1826, OD:3.812) NIP (1825-1826, OD:6.090) Gas lift andrel/Dummy Valve 1 (4308-0309, OD:5.984) Gas Lift 3ndrel/Dummy Valve 2 (6918-6919, OD:5.984) Gas Lift MandrelNalve 3 (9411-9412, NIP (9514-9515, OD:4.500) TUBING (0-9657, OD:4.500, ID:3.958) PKR (9569-9570, OD:7.000) NIP (9644-9645, OD:4.500) W LEG (9655-9657, OD:5.000) PROD CASING (0-10070, OD:7.000, W (:26.00) FRAC 0070-102811) OPEN HOLE ;10070-12811, OD 6 125) Cos~~cc~Pt~ili~s Ai~~ix~, i~~. ALPINE CD1-44 STATE OF ALASKA RECEI!!E® • APR 1 8 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI(~I~~ 41~ ~` Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^/ ~ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPh1111pS Alaska, InC. Development 0 Exploratory ^ 200-055 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20335-00 7. KB Elevation (ft}: 9. Well Name and Number: KBE = 36' CD1-44 8. Property Designation: 10. Field/Pool(s): ADL 25559 ~& 380075 Colville River Field /Alpine Oil Pool - 11.Present Well Condition Summary: Total Depth measured 12811' feet true vertical 7114' - feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURF CASING 2825' 9-5/8" 2825' PROD CASING 10070' 7" 10070' OPEN HOLE 2741' 5-1/2" 12811' Perforation depth: Measured depth: ®®py~~j e`~NGl~GD~OtlF~.~` ~A~ ~ ~ ~~~~ true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9657' MD. Packers &SSSV (type & measured depth) Baker "S-3" Packer @ s5ss Cameo Bal-O landing nipple SSSV @ 1825' 12. Stimulation or cement squeeze summary: Intervals treated (measured} Treatment descriptions including volumes used and final pressure: ~~ ~~~. hft} `t°' } ~; ^nn~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1344 ~ 3472 35 458 187 Subsequent to operation 2562 4642 174 728 219 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ 'Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. !hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exe t 2.~ Contact Tim Schneider Printed Name Tim Sch eider Title Production Engineer Signature Phone Date y- ~~-(j~ Pre ared b Jeanne L. Haas 263-4470 ~r> Form 10-404 Revised 04/2006 ~ ~ ~ ~ /~¢ ~~~ Submit Original Only • CD1-44 Stimulation Results Summary of stimulation job: 3-12-08: Pump frac in one stage: The frac ramped from 2-8 ppa; 2737 bbls slurry, 60 bbls diesel for freeze protect and 102 bbls SW flush. Frac: AIR-40 BPM, AIP-2340 psi, ISIP-1030 psi, 335,113 lbs. 16/30 Badger sand in open hole. Well test: 3/28/08: 2562 bopd, 174 bwpd, 4.6 mmcfpd, 219 WHP • ~~ ~ ~ §° ~~ ~ ~ f SARAH PALIN, GOVERNOR COwT~~~~j~.~=O ~ ~~+~ 333 W. 7th AVENUE, SUITE 100 •~ ii 1.~~~1~~'~~1111~~'iiiiii5~7 ois ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Barreda Production Engineer Conoco Phillips Alaska, Inc. ~~; ~A~ ~ ~ ZO~~ PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-44 - ~~i~A ~'- ~- Sundry Number: 308-020 Dear Mr. Barreda: 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 (907j 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 ants 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 January, 2008 Encl. ~~C~I~~D r~ ~~C~ ~J' ~ STATE OF ALASKA ~ JAN 1 7 200$ '~~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPR~~k~9~~ & Gas Cons. Clammission 20 AAC 25.280 Anchorage 1 . Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^/ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 200-055 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20335-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO ^ s CD1-44 9. Property Designation: ~g ~ D 10. KB Elevation (ft): 11. Field/Pool(s): ~. /7. ADL - 25559 & 3~~dD RKB 36' Colville River Field /Alpine Oil Pool " 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12811' - 7114' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURF CASING 2825' 9-5/8" 2825' PROD CASING 10070' 7" 10070' OPEN HOLE 2741' 6 1/8" 12811' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 9657 Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'S-3' PACKER pkr= 9569' SSSV= NIP ; SSSV SSSV= 1825' ; 1825' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 15, 2008 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: Brian Barreda Printed Name Brlan Barred Title: Production Engineer Signature ,~ ~i'1~.~ ~r-.^e~ti Phone 670-4798 Date 1/16/08 Commission Use Only N i i th esentat C diti f l tif C t i e ma itness Sun~lyur.^ ~~ ©~~ on so a repr on ons o approva : o y omm ss a v y w Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: b 1 ._. ~., ~~. ,f~Iv ~ ~ 200 APPROVED BY Q t Approved by: C M ISSIONER ^ THE COMMISSION Date: ~ (.~ a Form 10-403 Revised 06/2006 Submit in Duplicate • Overview: CD1-44: A hydraulic fracture treatment will be performed in the openhole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU 8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) "--~ 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Schlumberger's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatment. • 100 bbls YF125ST Pad • 100 bbls YF125ST w/ 2 ppa 16/30 White Sand • 170 bbls YF125ST w/ 4 ppa 16/30 White Sand • 250 bbls YF125ST w/ 7 ppa 16/30 White Sand • 40 bbls YF125ST w/12 ppa 16/30 White Sand Repeat treatment above 4 times. • Flush the last stage with linear YF125ST and freeze protect Total Sand: 450,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 1 0 2007 aDO -055 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Irttegrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 2/16/2007 Alpine Field March 31,2007 • • MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Well No CD1-44 PH boo-oS5 Installation/Rig Doyon 19 Dispatched To: AOGCC Date Dispatche 24-May-00 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 ECEIV ED ~I~Y 2 ~ Alaska it & Gas Cons. ommission Anchorage Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 roseQanchorage.anadrillslb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec'97 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2000550 MD 12811 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-44 Operator PHILLIPS ALASKA INC. 7114 Completion Dat 7/20/2000 ~ Completion Statu 1-OIL APl No. 50-103-20335-00-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_go Sample N_.9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret k kk ~ k (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments ADN-TVD 2/5 FINAL CDR-TVD 2/5 FINAL ADN-MD 2/5 FINAL SRVY RPT 9697 1 SRVY RPT CDR~ ~'~-~ 2/5 FINAL 9687 1 VISION 475~MD 2/5 FIELD VISION 475-'1'VD 2/5 FIELD 9963 FINAL Production Profile 2/5 FINAL 2730 9880 2790 2380 2380 2792 0 0 2792 9060 2400 9880 9880 9882 12290 12810 7150 7150 9839 12811 9882 9839 12811 7100 12290 12290 Open Case Open OH OH OH OH OH OH OH OH OH OH ch ch 7/19/2000 09687,,,~2730-9882 3/12/2001 09963 '~9880-12290 8/18/2000 09697 ~2790-12810 7/19/2000 2380-7150 PB1 ' 7/19/2000 2380-7150 PB1 ~ 7/19/2000 2792-9839 PB1 --~ 6/5/2000 SCHLUM 0-1281.1. 8/18/2000 9697,/ SCHLUM CDR/ADN/GR 5/26/2000 SCHLUM 0-9882. PH 7/19/2000 2792-9839 PB1 7/19/2000 9687~"SCHLUM ADN/CDR PB1 8/18/2000 9060-12811 8/18/2000 2400-7100 3/12/2001 996:~..~'9880-12290 Digital Data 3/12/2001 9880-12290 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2000550 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. COLVILLE RIV UNIT CD1-44 Operator PHILLIPS ALASKA INC. MD 12811 TVD 7114 Well Cored? Y ~.~ Chips~ Analysis ~.~ R ~.c.~.iv~.d ? Completion Dat 7/20/2000 Completion Statu 1-OIL Current Status Daily History Received? Y~ N Tops //~Y~f N Formation 1-OIL APl No. 50-103-20335-00-00 UIC N Comments: Compliance Reviewed By: Date: Annular Disposal durin the second quarter of 2001' h(1) h(2) ' h(3) ' Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May01 Jun01 lc-133, lC-19.1, lC-123, lC:19.7 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 MaY 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 i 9¢ Total Volumes into Annuli £or which Disposal Authorization Expired during the second quarter 2001: - ' Total Volume ' ~ Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 · 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- ~/ 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only cD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during the fourth quarter of 2000: ' h(1)~ h(2)' h~3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 Annular Disposal durin the second quarter ~ r2001. h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2.24 1C-27 3533 100 0 3633 0 3633' Jun 01 Jun 01 1C-127 Total Volumes into Annuli Cor which Disposal Authorization Expired during the second quarter 2001: ~ ' Total Volume ' Start End Source Wells Total h(1) Total h(2) TOtal h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus , ID-II 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open. Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06. CD1-40, CD1-- 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQI ~ -~B 20o 'o l ~_ r~.~ . o 4,3 ° ° PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attaChed the revised report with the volumes disposed into surface casing by production casing annuli dUring the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader RECEIVED PM/skad JUL 1 9 2001 CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files Alaska 0il & Gas Cons. Commission Anchorage Annular Dis ~osal durin the second quarter of 2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1C-133, 1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli Cor which Disposal Authorization Expired during the second quarter 2001: ' Total Voiume - Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _X Change approved program _ Pull tubing _ Variance _ Per/orate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development _X RKB 36' feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 530' FNL, 3008' FEL, Sec. 5, T11 N, R5E, UM (asp's 385695, 5975600) CD1-44 At top of productive interval 9. Permit number / approval number 2432' FNL, 1092' FWL, SEC. 6, T11 N, R5E, UM (asp's 379601, 5973794) 200-055 At effective depth 10. APl number 50-103-20335 At total depth 11. Field / Pool 5243' FNL, 216' FEL, Sec. 36, T12N, R4E, UM (asp's 378332, 5976283) Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured 1281 1 feet Plugs (measured) true vertical 7114 feet Effective depth: measured 1281 1 feet Junk (measured) true vertical 71 14 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" lO cu yds Portland Type 3 114' 114' SURF CASING 2825' 9-5/8" 426 sx AS m LW, 230 Sx C~ass G 2825' 2375' PROD CASING 10070' 7" 125 Sx Class G 10070' 7114' OPEN HOLE 2741' 6.125" 12811' OPEN HOLE RECEIVED Perforation depth: measured None true vertical None AJaska ON & Gas Cons. Commission Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 9657' MD. Anchorage Packers & SSSV (type & measured depth) BAKER 'S-3' PACKER @ 9569' MD. CAMCO BAL-O LANDING @ 1825' MD. 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: April 21,2001 16. If proposal was 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. Questions? Call Michael Erwin @ 265-1478. Sig Title: Alpine Production Engineer Micha( I Erwin Prepared b? Sharon AIIsu~-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval no. ,~.,i C, Plug integrity __ BOP Test __ Location clearance I -- Mechanical Integrity Test_ Subsequent form required 10- ORIGINAL SIGNED ~" · . D Taylor Searnoun~ Approvedby_orderoftheCommlsslon Commissioner Date ~' '~ / Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CD1-44 Conversion operations will commence following ice road construction on or about April 1,2001. Completion is expected on or about April 15,2001. This procedure is designed to clean out and stimulate a newly drilled producer. The goal is to remove filtercake, drilled solids, and polymer from the openhole completion. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with diesel. 2. Spot +/-150 bbl. of DS 8% f~acid plus inhibitors in 6% KC1 brine (8.6 ppg) in the openhole interval. ~ 3. Close the rams and squeeze away approximately 50 bbl at 1 bpm. Release pressure. 4. POOH and RD coil tubing. 5. Allow the breaker to soak for 4-6 hours. 6. Return the well to production. ?T~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pertorate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 530' FNL, 3008' FEL, Sec. 5, T11N, R5E, UM At top of productive interval 2432' FNL, 1092' FWL, SEC. 6, T11N, R5E, UM At effective depth At total depth 5243' FNL, 216' FEL, Sec. 36, T12N, R4E, UM 5. Type of Well: Development __X Explorato~___ Stratigraphic__ Service__ (asp's 385695, 5975600) (asp's 379601, 5973794) (asp's 378332, 5976283) 6. Datum elevation (DF or KB feet) RKB 36' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-44 9. Permit number / approval number 200-055 / 10. APl number 50-103-20335 11. Field / Pool Colville River Field / Alpine Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 14' SURF CASING 2825' PROD CASING 10070' OPEN HOLE 2741' Size 16" 9-5/8" 7" 6.125" 12811 feet 7114 feet Plugs (measured) 12811 feet 7114\ feet Junk (measured) Cemented Measured Depth True vertical Depth lO cu yds Portland Type 3 114' 114' 426 Sx AS III LW, 230 Sx Class 2825' 2375' G 125 Sx Class G 10070' 7114' 12811' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 9657' MD. BAKER 'S-3' PACKER @ 9569' MD. CAMCO BAL-O LANDING @ 1825' MD. '~(~' C%'ssio~ 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 2815 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 2969 2 2697 2888 0 Casing Pressure Tubing Pressure - 206 2O8 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sigll ~,,~ ~ ~ Title Alpine Production Engineer Michael Erwih I Form 10-404 Rev 06/15/88 · Prepared by Sharon Al/sup-Drake 263-46t~-.~ ~ SUBMIT IN DUPLICATE CD1-44 Description of Work Completed CT Formic Acid Treatment 4-21-01 FORMIC ACID TREATMENT COMPLETED. PUMPED 155 BBLS OF DOWELL 8% FORMIC ACID W/95 BBLS LAYED IN FROM 12436' BACK TO 10070' ACROSS THE OPEN HOLE & 60 BBLS BEING SQUEEZED IN. RETURNS AVERAGED .8 TO 1 DURING PLACEMENT OF ACID. UTILIZED BOTH THE PIPE STRAIGHTENER & FDR TO ATTAIN DEPTH, BUT SHORT OF TD (12811'). APPEARED TO HAVE A HARD TAG @ 12436'. FREEZE PROTECTED WELLBORE DOWN TO 2000' W/DIESEL. WELL AWAITING FLOWBACK. 4-22-01 FORMIC ACID FLOWBACK COMPLETED. FLOWED BACK 353 BBLS OF LIQUID ( 100 BBLS OF DIESEL, 123 BBLS OF CRUDE, 117 MSCF OF GAS, & 130 BBLS OF SPENT FORMIC ACID WATER). RETURN SAMPLES HAD A GEL LIKE CONSISTANCY TO THEM. USED LIFT GAS TO UNLOAD AND FLOW. TURNED WELL BACK INTO THE FACILITY Zoo. o ~5' ~.oo - Ioo Zoo-lOG Annular Disposal durin ; the first quarter o£2001: '- ' h(1) 1~(2) ' h(3~ 'Total for Previous New Start End Source Wells ...Well Name Volume Volume Volume Quarter Total Total Date Date , CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 COl-33, cm-NQ1, CO1-10, cm-28 2N-318 12276 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314 · CD1-43 30552 100 0 30652 385. 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21 CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14 1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37, 1D-39 1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39 1J-03 13020 100 I 0 13120 0 13120 Mar.'01 Mar.'01 1J-09, 1J-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the first quarter 2001: ......... Total Voiume - ' Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1L-28 9837 100 0 9937 Open, Freeze prOtected March 2000 April 2000 1L-20A, 1L-26A CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A, CD 1-09, CD 1-06 CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD1-44, CD1-41, CD1- 19A cD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05 CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1 30 PHILLIPS AlaSka, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 April 24, 2001 RECEIVED APR ~ 5 2'.00t Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, First Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which disposal aUthorization expired during the first quarter of 2001. PleaSe call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ProActive Diagnostic Services, Inc. W £L AAIt $MI i L To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton/Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 ' Lo6 Dm~AL MYLAn / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM BLUE LINE Open Hole I I 1 (~ I - L~ ~ ~, ~ rr'f.'~ t~ 0 ~ Res' Eval. CH I ~' I ~ I /,~-- Mech. CH ..... ,, , Caliper Survey 1 Rpt or 1 Color Signed · Print Name: ProActive Diagnostic Services, Phone:(907) 245-8951 Fax:(907) 245-8952 Date RECEIVED ~AR 1 ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage Inc., 310 K Street Suite 200, Anchorage, AK E-mail: pdsanchorage~.memorylog.com Websitc: ,.. 99501 : ,,.. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th AvenUe, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposal during th~. fourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 ...... CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 ,. , 1D-36 30104 100 0 30204 0 30204 2N-305 280 t00 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil E] Gas D Suspended D Abandoned r-1 Service FI 2. Name of Operator~ 7. Permit Number Phillips Alaska, Inc. r'~2~C-"A,'ll~' 200-055 3. Address ~ 8. APl Number P. Q. Box 100360, Anchorage, AK 99510-0360~ 50-103-20335-00 & 50-103-20335-70 4. Location of well at surface ~ 9. Unit or Lease Name 531' FNL, 2272' FWL, Sec. 5, Tll N, R5E, UM (ASP: 385696, 5975601) ~' i-: - '.' ~ Colville River Unit At Top Producing Interval ' : i 10. Well Number 2432' FNL, 1092' FWL, Sec. 6, T11 N, R5E, UM (ASP: 379601,5973794) -?, 2.~ .~.~ CD1-44 & CD1-44PH At Total Depth .~ ~. 11. Field and Pool 36' FSL, 216' FEL, Sec. 36, T12N, R4E, UM (ASP: 378333, 5976283) ~ . ~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial' N0. ' Alpine Oil Pool RKB 36 feet~ ADL 25559 & 380096 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~ 15. Water Depth, if o~hore 16. No. of Completions May 5, 2000 May 19, 2000 May 20, 2000 ~ N/A feet MSL 1 I 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) ~19. Directional Suwey ~20. Depth where SSSV set 21. Thickness of Permafrost 12811'MD/7114'TVD 12811' MD / 7114' TVD YES ~ No ~J 1825' feetMD 1669' 22. Type Electric or Other Logs Run G~Re~NeuFDens 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEME~ING RECORD AMOUNT PULLED 16" 62.5~ H-40 Su dace 114' 42" 10 cu yds Portland Type 3 9.625" 36~ J-55 Sudace 2825' 12.25" 426Sx AS III LW, 230 sx Class G 7" 26~ L-80 Sudace 10072' 8.5" 125 sx Class G 0D1-44 PB1 cement plug dressed off to 9060' to start CD1-44 sidetrack 24. Pedorations open to Production (MD + TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9657' 9569' 6.125" OH completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9882'-9278' Plug ~1'48 bb~ 15.8~PPG Class G 9278'-8895' Plug ~2: Pump 31 bb~ 17.0 ppg Class G 27. PRODUCTION TEST ! ¢ I [ ! A I Date First Production Method of Operation (Flowing, gas li,, etc.) U E I g I I ~ b Waiting on Facili~ Stad-Up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A , ,EEEIVE ) ~_.'j. ;::,. uu,,~. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME CD1-44 Top Alpine TD CD1-41 PH Top Alpine TD MEAS. DEPTH 10016' 12811' 9882' TRUE VERT. DEPTH 7110' 7114' 7218' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diese 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6034 Signed ~',~- I¢%, ~',~](~. Title Drilling Team Leader Date G. C, Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED SEP 2 5 · :,. Alaskr~ 0il & kr~chorage Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -- WELL:CD1-44 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:05/05/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20335-00 05/04/00 (D1) MW: 0.0 VISC: TD/TVD: 114/114 (114) Move rig. SUPV:LUTRICK / REILLY Move and R/U 0 PV/YP: 0/ 0 APIWL: 0.0 05/05/00 (D2) MW: 9.4 VISC: 250 PV/YP: 15/115 APIWL: 21.0 TD/TVD: 2014/1814 (1900) DRILLING ~ 2601' SUPV:LUTRICK / REILLY Move rig to pad, rig up. Accept rig @ 0230 hrs.. Pre-spud meeting. Function test diverter. Drill from 114' to 545' w/gyro surveys. Drill from 545' to 2014' 05/06/00 (D3) MW: 9.8 VISC: 75 PV/YP: 17/24 APIWL: 14.0 TD/TVD: 2835/2382 ( 821) N/U BOPE. SUPV:LUTRICK / REILLY Drill from 2014' to 2835'. Circ hole clean w/hi vis sweep. Wiper trip to 1450'. Circ hole clean w/hi vis sweep. POOH. PJSM. Run 9-5/8" casing to 2825'. Circ and condition mud. 05/07/00 (D4) MW: 9.6 VISC: 44 PV/YP: 8/20 APIWL: 22.0 TD/TVD: 2835/2382 ( 0) DRILLING ~ 3470' SUPV:LUTRICK / REILLY PJSM, pump bio wash and cement. N/D diverter. N/U BOPE and test. RIH to 1574'. Hold kick drill. Hold stripping drill. Drill out cement and 20' of new hole to 2855' CBU. 05/08/00 (D5) MW: 9.6 VISC: 44 PV/YP: 8/24 APIWL: 6.0 TD/TVD: 5856/4456 (3021) DRLG AT 6425' (WIPER TRIP AT 5948'- OK) SUPV:DONALD LUTRICK Perform 16.0 ppg FIT. Displace hole w/clean mud. Drilling from 2855' to 4330' Circ hi vis sweep. Wiper trip to shoe. No problems. Drilling from 4330' to 5856' 05/09/00 (D6) MW: 9.6 VISC: 43 PV/YP: 7/26 ApIWL: 6.9 TD/TVD: 8135/5996 (2279) DRLG AT 8800' SUPV:DONALD LUTRICK Drilling from 5856' to 5948' Circ hi-vis sweep. Check flow. Wiper trip to 4320'. No problems. Drilling from 5948' to 7565'. Circ hi-vis sweep. Wiper trip to 5940'. No problems. Drilling from 7565' to 8135' Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/10/00 (D7) MW: 9.7 VISC: 50 PV/YP: 11/21 TD/TVD: 9882/7220 (1747) LAYING DOWN BHA. SUPV:SCOTT REYNOLDS APIWL: 5.5 Drill from 8135' to 8994' Pump hivis sweep. Circulate until hole is clean. Wiper trip from 8994' to 7565'. No hole problems. Drill from 8994' to 9753'. Lost returns, hole taking 210-300 bph. Pump medium nut plug pill. Pull above loss zone and circulate. Drill from 9753' to 9823' After drilling 5' of new hole, hole taking > 250 bph. Drill ahead while mixing a 40 bbl-50ppb, 50/50 mix II/nutplug pill. Continue drilling. Total losses 320 bbls. Drill from 9823' to 9882'. CBU, circulate until hole clean. Monitor well, static. Spot LCM pill ~ 9882' 05/11/00 (D8) TD/TVD: 8900/6532 ( SUPV:SCOTT REYNOLDS MW: 9.6 VISC: 40 PV/YP: 7/17 0) RIH WITH BHA #3 APIWL: 5.8 POOH wet 10 stands. Good hole fill. Pump dry job. Monitor well - static. POOH to HWT. RU to run 3.5" DP. RIH to 9882' Wash from 9790' to 9228' Circulate and condition mud for cement plugs. PJSM. Pump cement plug #1. Pump cement. POOH to 9278'. Pump cement plug #2. Pump cement. POOH to 8895' 05/12/00 (D9) TD/TVD: 9588/6970 SUPV:SCOTT REYNOLDS MW: 9.6 VISC: 42 PV/YP: 11/22 688) DRILLING AHEAD @ 9816' APIWL: 5.4 RIH to 2771' Break circulation. RIH to 8858'. Wash to 8905' Drill cement to 9060' Circulate hole clean. Time drill from 9060' to 9083' Drill from 9092' to 9588' 05/13/00 (D10) TD/TVD:10080/7116 SUPV:SCOTT REYNOLDS MW: 9.7 VISC: 41 PV/YP: 12/22 492) RIH W/7" CASING. APIWL: 5.1 Drill from 9588' to 10080'. Circulate around hivis sweep. Monitor well, static. 12 stand short trip to 8960'. No hole problems. Circulate around hivis sweep. Monitor well, static. POOH. tight ~ 8700'. Screw in, wash and ream from 8700' to 8370'. POOH on trip tank. Work through tight spots from 8275' to 8175' Pump dry job, monitor well, static. Continue to POOH working tight spot ~ 4350' 05/14/00 (Dll) TD/TVD:10080/7116 SUPV:SCOTT REYNOLDS MW: 9.6 VISC: 42 PV/YP: 10/18 0) RIH W/BHA#4. APIWL: 5.5 Run and Baker lock first 4 joints of casing. Check floats, circulation established. Continue to run 7" to 2787' Run 7" casing to 9955', tight hole. Wash casing from 9955' to 10071'. PJSM. Pump cement job. Bumped plug and floats held. Set pack-off and test to 500/5000 psi. Test BOPE. Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/15/00 (D12) MW: 9.2 VISC: 60 PV/YP: 13/29 APIWL: 3.4 TD/TVD:10080/7116 ( 0) TRIPPING OUT TO TROUBLE SHOOT LOW ROP. SUPV:SCOTT REYNOLDS/PAT REILLY Cont. test BOPE. Spill drill. RIH. CBU. 9-5/8" x 7" LOT EMW 14.8. Drill float equipment and cement. Drill from 10080 to 11100'. Circ and cond. mud. FIT to 12.5 ppg. Displace w/flo-pro. 05/16/00 (D13) MW: 9.2 VISC: 57 PV/YP: 13/31 APIWL: 3.5 TD/TVD:10550/7123 ( 470) DRILLING ~ 10849' SUPV:SCOTT REYNOLDS~PAT REILLY Drill from 10100' to 10179'. Motor stalling easily. Monitor well, pump out 5 stands to 9699', fill trip tank. POOH wet. RIH. Mad pass from 10091' to 10179' Drill from 10179' to 10550' 05/17/00 (D14) MW: 9.2 VISC: 59 PV/YP: 14/30 APIWL: 3.6 TD/TVD:l1567/7132 1017) TIH WITH BHA #6 SUPV:SCOTT REYNOLDS/PAT REILLY Drill from 10550' to 11567'. MWD failed, circ/sweep-monitor. Pump out from 11567' to 9702' Monitor well, static. POOH wet and slow to 9000' 05/18/00 (D15) MW: 9.2 VISC: 62 PV/YP: 13/33 APIWL: 3.6 TD/TVD:12251/7121 ( 684) DRILLING @ 12450' SUPV:SCOTT REYNOLDS~PAT REILLY Continue POH, monitor well @ 3781' C/O MWD, inspect motor and bit. RIH. Mad pass log from 11470' to 11567' Drill from 11567' to 12251' 05/19/00 (D16) MW: 9.2 VISC: 27 PV/YP: 1/ 2 APIWL: 0.0 TD/TVD:12811/7114 560) POOH TO RUN 4-1/2" COMPLETION. LOSSES ~ 12 BPH. TOTA SUPV:SCOTT REYNOLDS/PAT REILLY Drill from 12251' to 12811' Pump lo/hi vis sweep around. Circulate hole clean. Pump out to shoe with no hole problems. Monitor well, static. RIH to TD @ 12811'. Pump lo/hi vis sweep around. Circulate hole clean. PJSM. Displace Flopro with brine. 05/20/00 (D17) MW: 9.2 VISC: 27 PV/YP: 1/ 1 APIWL: 0.0 TD/TVD:12811/7114 ( 0) DISPLACING TO 9.6 INHIBITED BRINE AND DIESEL FOR FREEZ SUPV:SCOTT REYNOLDS POOH to shoe. Monitor losses. RIH w/tailpipe assembly, packer. Run 4.5" tubing and jewelry. 05/21/00 (D18) MW: 9.2 VISC: 27 PV/YP: 1/ 1 APIWL: 0.0 TD/TVD:12811/7114 ( 0) RIH W/SCRAPER ASSEMBLY. SUPV:SCOTT REYNOLDS ND BOPE. NU tree and test seals to 5000 psi, good test. Set packer. Set BPV and secure well. Release rig 8 0830 hrs. 5/21/00. SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00029 Sidetrack No. Page Company PHILLIPS ALASKA, INC. Rig Contractor & No. DOYON - RIG #19 Field ALPINE FIELD Well Name & No. PAD CD#1/44 PH1 / 44 Survey Section Name CD1-44 PH1 MWD BHI Rep. D NEWLON WELL DATA ~___j I 1 of 3 Target TVD (FT) Target Coord. N/S Slot Coord. N/S -529.91 Target Description Target Coord. E/W Slot Coord. E/W 2273.92 Target Direction (DO) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 253.16 SURVEY DATA Total Coordinate Date Survey Hole Course Vertic,~l Depth Direction Length TVD Section N(+) / S(-) E(+) / W(-) (IT) (DD) (FT) (FT) (FT) (FT) 0.00 0.00 0.00 0.00 0.00 0.00 05-MAY-00 114.00 0.00 114.00 114.00 0.00 0.00 0.00 05-MAY-00 179.00 255.00 65.00 179.00 0.43 -0.11 -0.41 05- MAY-O0 297.00 272.86 118.00 296.95 3.59 -0.18 -3.70 05-MAY-O0 385.00 262.35 88.00 384.80 8.50 -0.51 -8.73 05-MAY-00 475.00 265.75 90.00 474.45 16.23 -1.29 -16.57 05-MAY-00 563.00 269.13 88.00 561.76 26.85 -1.72 -27.53 05-MAY-00 654.00 267.40 91.00 651.45 41.64 -2.21 -42.83 05-MAY-00 743.00 261.81 89.00 738.62 59.24 -3.95 -60.70 05-MAY-O0 832.00 264.31 89.00 825.36 78.85 -6.34 -80.47 05-MAY-00 922.00 257.45 90.00 912.59 100.81 -9.92 -102.33 05-MAY-00 966.00 254.65 44.00 954.97 112.62 -12.78 -113.80 05-MAY-00 1011.00 250.66 45.00 998.01 125.73 -16.71 -126.31 05-MAY-00 1105.00 241.85 94.00 1086.62 156.78 -29.50 -154.88 05-MAY-00 1199.00 242.01 94.00 1173.18 192.69 -46.73 -187.18 05-MAY-O0 1296.00 244.11 97.00 1260.08 235.10 -66.19 -225.60 05- MAY-00 1391.00 245.62 95.00 1342.51 281.82 -86.22 -268.35 05-MAY-00 1487.00 248.07 96.00 1423.02 333.77 -106.73 -316.42 05-MAY-00 1581.00 248.79 94.00 1499.27 388.54 -126.92 -367.54 05-MAY-O0 1676.00 249.02 95.00 1573.79 447.28 -148.12 -422.49 05- MAY-00 1771.00 247.53 95.00 1645.18 509.71 -171.34 -480.69 05-MAY-00 1867.00 246.30 96.00 1713.19 577.03 -197.91 -542.98 05-MAY-O0 1962.00 247.55 95.00 1778.12 645.97 -225.09 -606.78 06- MAY-00 2057.00 246.55 95.00 1843.07 714.90 -252.12 -670.62 Grid Correction Magn. Declination Magn. to Map Corr. 0.000 25.810 25.810 Depths Measured From: RKB ~ MSL~ SS~ Calculation Method MINIMUM CURVATURE Map North to: OTHER Build Rate Build (+) Drop (-) Walk Rate Right (+) Left (-) 0.00 1.15 1.46 1.89 1,99 3.78 2.83 3.84 2.80 -1.90 1.55 -6.28 Comment TiE IN POINT 9 1/2" M1C 1.5 DEG AKO Gyro Single Shot Survey 1.33 2.81 1.68 -7.62 2.57 -6.36 3.51 -8.87 3.77 -9.37 3.50 0.17 3.70 2.16 3.46 1.59 3.22 2.55 2.65 0.77 2.72 0.24 3.52 -1.57 4.02 -1.28 0.16 1.32 -O.20 -1.05 EET ~ SURVEY CALCULATION AND FIELD WORKSH Job No. 0450-00029 Sidetrack No. Page 2 Company PHILLIPS ALASKA. INC. Rig Contractor & No. DOYON - RIG #19 Field ALPINE FIELD Well Name & No. PAD CD#1/44 PH1 / 44 Survey Section Name CD1-44 PH1 MWD BHI Rep. D NEWLON WELL DATA Target TVD (~---r) Target Coord. N/S Slot Coord. N/S -529.91 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SSQ Target Description Target Coord. E/W Slot Coord. E/W 2273.92 Magn. Declination 25.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOft[~ 30m~ lOmQ Vert. Sec. Azim. 253.16 Magn. to Map Corr. 25.810 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /$(-) E(+) /W(-) I DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per lO0 FT) Drop (-) Left (-) 06-MAY-O0 MWD 2152.00 46.49 246.88 95.00 1908.31 783.52 -279.42 -734.05 0.39 -0,29 0.35 06-MAY-O0 MWD 2247.00 46.28 247.90 95.00 1973.84 851.95 -305.87 -797.54 0.81 -0.22 1.07 06-MAY-O0 MWD 2343.00 46.27 246.55 96.00 2040.20 920.95 -332.72 -861.51 1.02 -0.01 -1.41 06-MAY-O0 MWD 2438.00 45.73 248.22 95.00 2106.19 988.94 -359.00 -924.58 1.39 -0.57 1.76 06-MAY-O0 MWD 2534.00 45.71 247.56 96.00 2173.22 1057.38 '-384,87 -988.26 0.49 -0.02 -0.69 06-MAY-O0 MWD 2629.00 45.65 247.01 95.00 2239.59 1124.99 -411.12 -1050.95 0.42 -0.06 -0.58 06-MAY-O0 MWD 2724.00 46,70 248.95 95.00 2305.38 1193.24 -436.80 -1114.49 1.84 1.11 2.04 06-MAY-O0 MWD 2759.00 46.82 248.16 35.00 2329.36 1218.65 -446.12 -1138.22 1.68 0.34 -2.26 08-MAY-O0 MWD 2921.00 46.44 250.03 162.00 2440.61 1336.11 -488.14 -1248.22 0.87 -0.23 1.15 6 3/4' M1/XL 1.2 DEG AKO 08-MAY-O0 MWD 3017.00 46.02 248.47 96.00 2507.02 1405.27 -512.70 -1313.04 1.25 -0.44 -1.63 08-MAY-O0 MWD 3112.00 46.41 246.31 95.00 2572.76 1473.50 -539.07 -1376.35 1.69 0.41 -2.27 08-MAY-O0 MWD 3303.00 46.23 246.92 191.00 2704.67 1610.73 -593.90 -1503.13 0.25 -0.09 0.32 08-MAY-O0 MWD 3495.00 46.35 246.26 192.00 2837.34 1748.60 -649.04 -1630.49 0.26 0.06 -0.34 08-MAY-O0 MWD ' 3685.00 46.35 244.79 190.00 2968.49 1884.85 -705.99 -1755.61 0.56 0.00 -0.77 08-MAY-O0 MWD 3874.00 46.05 247.90 189.00 3099.33 2020.27 -760.72 -1880.53 1.20 -0.16 1.65 08-MAY-O0 MWD 4065.00 46.55 245.62 191.00 3231.29 2157.47 -815.21 -2007.39 0.90 0.26 -1.19 08- MAY-o0 MWD 4255.00 47.38 248.43 190.00 3360.97 2295.53 -869.39 -2135.23 1.17 0.44 1.48 08-MAY-O0 MWD 4445.00 47.09 248.03 190.00 3489.98 2434.50 -921.12 -2264.77 0.22 -0.15 -0.21 08-MAY-O0 MWD 4635.00 47.11 249.14 190.00 3619.32 2573.24 -971.93 -2394.34 0.43 0.01 0.58 08-MAY-C0 MWD 4826.00 47.28 248.86 191.00 3749.10 2713.00 -1022.15 -2525.17 O. 14 0.09 -0.15 08-MAY-O0 MWD 5016.00 47.12 249.09 190.00 3878.20 2852.04 -1072.17 -2655.29 0.12 -0.08 0.12 08-MAY-O0 MWD 5206.00 46.78 248.71 190.00 4007.90 2990.50 -1122.15 -2784.83 0.23 -0.18 -0.20 08- MAY-O0 MWD 5396.00 46.70 248.13 190.00 4138.11 3128.39 -1173.04 -2913.50 0.23 -0.04 -0.31 08- MAY-O0 MWD 5587.00 45.83 247.29 191.00 4270.15 3265.77 -1225.38 -3041.19 0.56 -0.46 -0.44 " uRVEY ( ALCULATION AND FIELD WORKSHEET Job No. 0450-00029 Sidetrack No. Page 3 of 3 Company PHILLIPS ALASKA, ING. Rig Contractor & No. DOYEN - RIG #19 Field ALPINE FIELD Well Name & No, PAD CD#1/44 PH1 / 44 Survey Section Name CD1-44 PH1 MWD BHI Rep. D NEWLON i i I~~1~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -529,91 Grid Correction 0.000 Depths Measured From: RKB ~] MSL[~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W 2273.92 Magn. Declination 25.810 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10m[~ Vert. Sec. Azim. 253.16 Magn. to Map Corr. 25.810 Map North to: OTHER i ii i iii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (IT) (FT) (Fl') (F'I') (Per 100 FT) Drop (-) Left (-) 08-MAY-O0 MWD 5777.00 46.52 246.68 190.00 4401.72 3402.05 -1278.98 -3167.35 0.43 0.36 -0.32 09-MAY-O0 MWD 5968.00 46.03 246.52 191.00 4533.74 3539.17 -1333.79 -3294.03 0.26 -0.26 -0.08 09-MAY-O0 MWD 6157.00 45.53 245.49 189.00 4665.55 3673,56 -1388.87 -3417.77 0.47 -0.26 -0.54, 09-MAY-O0 MWD 6349.00 47.09 248.32 192.00 4798.18 3811.54 -1443.27 -3545.47 1.34 0.81 1.47 09-MAY-O0 MWD 6539.00 47.13 247.41 190.00 4927.50 3950.15 -1495.72 -3674.41 0,35 0.02 -0.48 09-MAY-00 MWD 6729.00 46.90 245.45 190.00 5057.05 4088.17 -1551.29 -3801.79 0,76 -0.12 -1.03 09-MAY-O0 MWD 6920.00 48.61 247.57 191.00 5185.46 4228.60 -1607.61 ,3931.47 1.22 0.90 1.11 09-MAY-O0 MWD 7110.00 49.09 247.28 190.00 531.0.49 4370.95 -1662.53 -4063.57 0.28 0.25 -0.15 09-MAY-00 MWD 7301.00 49.17 247.11 191.00 5435.47 4514.60 -1718.52 -4196.71 0.08 0.04 -0.09 09-MAY-O0 MWD 7490.00 49.05 246.94 189.00 5559.19 4656.66 -1774.28 -4328.26 0.09 -0.06 -0.09 09-MAY-O0 MWD 7680.00 48.23 247.17 190.00 5684.74 4798.46 -1829.88 -4459.58 0.44 -0.43 0.12 09-MAY-00 MWD 7871.00 46.95 247.45 191.00 5813.55 4938.74 -1884.28 -4589.68 0.68 -0.67 0.15 09-MAY-O0 MWD 8061.00 45.95 249.54 190.00 5944.46 5075.98 -1934.78 -4717.78 0.96 -0.53 1.10 10-MAY-OO MWD 8252.00 46.01 247.99 191.00 6077.20 5212.91 -1984.52 -4845.80 0.58 0.03 -0.81 1 O-MAY-00 MWD 8442.00 45.72 248.15 190.00 6209.50 5348.74 -2035.45 -4972.29 0.16 -0.15 0.08 10-MAY-00 MWD 8633.00 45.22 247.44 191.00 6343.45 5484.30 -2086.90 -5098.35 0.37 -0.26 -0.37 10-MAY-O0 MWD 8824.00 44.94 246.07 191.00 6478.32 5618.69 -2140.27 -5222.62 0.53 -0.15 -0.72 -- 10-MAY-00 MWD 9012.00 44.66 243.31 188.00 6611.73 5749.70 -2196,89 -5342.35 1.05 -0.15 -1.47 10- MAY-00 MWD 9206.00 45.41 250.42 194.00 6748.91 5885.96 -2250.70 -5468.43 2.62 0.39 3.66 10-MAY-O0 MWD 9395,00 45.86 252.36 189.00 6881.07 6021.00 -2293.81 -5596.48 0.77 0.24 1.03 10-MAY-00 MWD 9584.00 45.81 252.33 189.00 7012.76 6156.56 -2334.92 -5725.67 0.03 -0.03 -0.02 10-MAY-O0 MWD 9806.67 46.98 251.19 222.67 7166.33 6317.74 -2385.40 -5878.79 0.64 0.53 -0.51 1e-MAY-e0 MWD 9882.00 46.98 251.19 75.33 7217.72 6372.79 -2403.16 -5930.92 0.00 0.00 0.00 Projected Data - NO SURVEY ...... J ~J IJ .~J II j j .J j J 'j J iL J J J m . J ' m .~J j j j j iii ~1 J ~,~ J .u j j j ./ J J L i ii i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00029 Sidetrack No. Page I of 3 Company PHILLIPS ALASKA, INC. Rig Contractor & No. DOYON - RIG #19 Field ALPINE FIELD Well Name & No. PAD CD#1/44 PH1 / 44 Survey Section Name CD1-44 MWD BHI Rep. MILCHAK/GEHRES WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -529.91 Grid Correction 0.000__ Depths Measured From: RKB ~] MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2273.92 Magn. Declination 25.810 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m[~ 10m0 Vert. Sec. Azim. 331.92 Magn. to Map Corr. 25.810 Map North to: OTHER ii SURVEY DATA ,,, Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (,F~ (FT) (F-D (FT) (Per 100 F'r) Drop (-) Left (-) MWD 9012.00 44.66 243.31 6611.73 576.39 -2196.89 -5342.35 TIE IN POINT 12-MAY-O0 MWD 9081.00 44.84 245.95 69.00 6660,74 578.67 -2217.70 -5386.24 2.71 0.26 3.83 6 3/4" M1X 1.45 DEG AKO ,, 12-MAY-00 MWD 9116.00 45.76 250.79 35.00 6685.38 581.47 -2226.86 -5409.35 10.17 2.63 13.83 __ 12-MAY-00 MWD 9148.00 46.39 254.76 32.00 6707.57 585.82 -2233.67 -5431.36 9.15 1.97 12.41 ,, 12- MAY-O0 MWD 9177.00 47.38 258.49 29.00 6727.39 591.19 -2238.56 -5451.95 9.99 3.41 12.86 , 12-MAY-O0 MWD 9211.00 48.40 263.88 34.00 6750.20 599.52 -2242.42 -5476.86 12.13 3.00 15.85 12-MAY-00 MWD 9243.00 49,45 268.65 32.00 6771.23 609,46 -2243.98 -5500.91 11.70 3.28 14.91 12-MAY-O0 MWD 9273.00 50.13 272.14 30.00 6790.60 620.39 -2243.82 -5523.82 9.17 2.27 11.63 .... 12-MAY-O0 MWD 9306.00 50,73 276.26 33.00 6811.63 633.97 -2241.95 -5549.18 9.79 1.82 12.48 12-MAY-O0 MWD 9338.00 51.42 279.95 32.00 6831.74 648.67 -2238.44 -5573.82 9.23 2.16 11.53 12-MAY-O0 MWD 9369.00 52.62 283.47 31.00 6850.82 664,31 -2233.47 -5597.73 9.75 3.87 11.35 12- MAY-O0 MWD 9402.00 54.03 286.85 33.00 6870.53 682.44 -2226.55 -5623.27 9.26 4.27 10.24 12-MAY-O0 MWD 9434.00 55.54 290.34 32.00 6888.99 701.46 -2218.21 -5648.04 10.08 4.72 10.91 12-MAY-O0 MWD , 9464.00 57.14 293.84 30.00 6905.62 720.63 -2208.81 -5671.17 11,08 5.33 11.67 12-MAY-O0 MWD 9496.00 58.93 296.82 32.00 6922.56 742,43 -2197.19 -5695.70 9,68 5.59 9.31 12-MAY-00 MWD 9526.00 60.43 299.46 30.00 6937.71 763.95 -2184.98 -5718.53 9,09 5.00 8.80 -- 13-MAY-00 MWD 9558.00 60.82 300.18 32.00 6953.41 787.57 -2171.11 -5742.72 2.31 1.22 2.25 13- MAY-OO MWD 9591.00 61.30 300.29 33.00 6969.37 812.15 -2156.57 -5767.67 1.48 1.45 0.33 13-MAY-O0 MWD 9623.00 61.63 300.33 32.00 6984.66 836.09 -2142.38 -5791.94 1.04 1.03 0.12 -- 13-MAY-O0 MWD 9654.00 62.15 300.51 31.00 6999.27 859.41 -2128.54 -5815.52 1.75 1.68 0.58 13-MAY-00 MWD 9687.00 64.10 302.78 33.00 7014.18 884.83 -2113.09 -5840.57 8.52 5.91 6.88 13-MAY-O0 MWD 9713.00 65.98 304.64 26.00 7025.16 905.59 -2100.01 -5860.18 9.71 7.23 7.15 13-MAY-O0 MWD 9749.00 68.38 307.10 36.00 7039,12 935.40 -2080.56 -5887.06 9.17 6.67 6.83 13.MAY~OO MWD 9782.00 69.60 308.33 33.00 7050.95 963.50 -2061.72 -5911.43 5.08 3.70 3.73 SURVEY CALCULATION AND FIELD WORKSHEET Job No. o o-ooo Company PHILLIPS ALASKA, INC. Rig Contractor & No. DOYON - RIG #19 Well Name & No. PAD CD#1/44 PH1 /44 Survey Section Name CD1-44 MWD WELL DATA i J i J ii Sidetrack No. Page Field ALPINE FIELD 2 of 3 BHI Rep. MILCHAK/GEHRES Target TVD (FT) Target Coord. N/S Slot Coord. N/S -529.91 Grid Correction 0.000 Target Description Target Coord. E/W Slot Coord. E/W 2273.92 Magn. Declination 25.810 Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m[~ 10m~] Vert. Sec. Azim. 331.92 Magn. to Map Corr. 25.810 SURVEY DATA Total Coordinate Date Survey Hole Course Vertical Depth Direction Length TVD Section N(+) / S(-) E(+) / W(-) (FT) (DD) (FT) (FT) (F'r) (FT) 13-MAY-00 9843.00 312.20 61.00 7070.57 1017.17 -2024.39 -5955.47 13-MAY-O0 9877.00 313.73 34.00 7080.18 1048.02 -2002.16 -5979.34 13-MAY-O0 9909.00 316.23 32.00 7088.50 1077.57 -1980.32 -6001.19 13-MAY-00 9939.00 319.39 30.00 7095.58 1105.84 -1958.72 -6020.76 13-MAY-00 9970.00 322.87 31.00 7102.09 1135.61 -~935.12 -6039.78 13-MAY-O0 10011.00 325.67 41.00 7109.09 1175.64 -1902.33 -6063.36 16-MAY-00 10126.30 330.85 115.30 7118.66 1290.20 -1804.70 -6123.72 16-MAY-00 10218.00 329.14 91.70 7120.44 1381.82 -1725.31 -6169.57 16-MAY-00 10312.00 329.50 94.00 7121.59 1475.72 -1644.47 -6217.53 16-MAY-00 10405.00 331.58 93.00 7122.51 1568.68 -1563.50 -6263.26 16-MAY-00 10498.00 330.61 93.00 7123.85 1661.66 -1482.10 -6308.21 17-MAY-O0 10590.00 332.59 92.00 7125.17 1753.65 -1401.18 -6351.96 17-MAY-O0 10683.00 332.59 93.00 7127.12 1846.62 -1318.64 -6394.76 17-MAY-O0 '10774.00 333.26 91.00 7129.27 1937.58 -1237.64 -6436.17 17-MAY-00 10867.00 332.57 93.00 7131.53 2030.54 -1154.86 -6478.50 17-MAY-00 10960.00 332.32 93.00 7134.14 2123.50 -1072.45 -6521.51 17-MAY-O0 11052.00 333.57 92.00 7135.76 2215.46 -990.53 -6563.35 17-MAY-00 11145.00 332.33 93.00 7136.04 2308.45 -907.70 -6605.64 17-MAY-00 11236.00 333.20 91.00 7135.19 2399.43 -826.80 -6647.28 17-MAY-00 11329.00 334.89 93.00 7134.16 2492.36 -743.19 -6687.98 18-MAY-00 11418.00 334.26 89.00 7133.76 2581.26 -662.81 -6726.19 18- MAY-00 11513.03 333.54 95.03 7133.08 2676.23 -577.47 -6768.00 18-MAY-O0 11603.93 335.57 90.90 7131.48 2767.01 -495.41 -6807,04 18-MAY-O0 11695.53 334.35 91.60 7130.13 2858.47 -412.43 -6845.81 Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) 5.38 6.34 4.18 4.50 3.97 7.81 5.13 10.53 5,06 11.23 7.24 6.83 6.23 4.49 0.12 -1.86 0.77 0.38 -0.48 2.24 -0.08 -1.04 0.08 2.15 -0.88 0.00 0.56 0.74 -0.62 -0.74 0.15 -0.27 1.15 1.36 0.67 -1.33 0.87 0.96 -0.63 1.82 -0.19 -0.71 0.51 -0,76 0.79 2,23 -1.1 6 -1.33 Depths Measured From: RKB ~] MSL~ ssE~ Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment 4 3/4" M1X 1.2 DEG AKO 4 3/4" M1X 1.2 DEG AKO 4 3/4" M1X 1.2 DEG AKO ,- SURV CALCULATION AND FIELD WORKSHEET Job No. 0450-00029 Sidetrack No. Page 3 of 3 -= I :~1 Company PHILLIPS ALASKA, INC. Rig Contractor & No. DOYON - RIG #19 Field ALPINE FIELD Well Name & No. PAD CD#1/44 PH1 / 44 Survey Section Name CD1-44 MWD BHI Rep, MILCHAK/GEHRES WELL DATA -- Target TVD (~-~ Target Coord. N/S Slot Coord. N/S -529,91 Grid Correction 0,000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2273,92 Magn. Declination 25.810 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ff~ 30m~ 10m~ Vert. Sec. Azim. 331.92 Magn, to Map Corr. 25.810 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FT) (FT) (F-r) (FT) (Per 100 FT) Drop (-) Left (-) -- 18-MAY-00 MWD 11786.00 91.23 335.17 90.47 7128.92 2948.82 -330.60 -6884.38 1.36 1.02 0.91 ..... 18-MAY-00 MWD 11879.57 90.55 332.76 93.57 7127.47 3042.31 -246.54 -6925.44 2.68 -0.73 -2.58 ~ , , 18-M^Y-00 MWD 11973.39 91.06 333.53 93.82 7126.15 3136.10 -162.85 -6967.82 0.98 0.54 0.82 18-MAY-00 MWD 12064.59 90.62 332.31 91.20 7124.81 3227.28 -81.66 -7009.33 1.42 -0.48 -1.34 18-MAY-00 MWD 12155.33 91.13 333.06 90.74 7123.42 3318.00 -1.05 -7050.96 1.00 0.56 0.83 18-MAY-00 MWD 12232.17 91.61 333.74 76.84 7121.59 3394.79 67.64 -7085.36 1.08 0.62 0.88 19-MAY-00 MWD 12302.95 90.00 330.46 70.78 7120.59 3465.55 130.17 -7118.47 5.16 -2.27 -4.63 19-MAY-00 MWD 12339.94 90.27 329.98 36.99 7120.51 3502.53 162.28 -7136.84 1.49 0.73 -1.30 19-MAY-00 MWD 12385.10 90.58 330.07 45.16 7120.17 3547.66 201.40 -7159.41 0.71 0.69 0.20 .,, 19-MAY-O0 MWD 12435.38 90.89 330.23 50.28 7119.53 3597.91 245.00 -7184.43 0.69 0.62 0.32 19- MAY-00 MWD 12528.31 90.62 329.72 92.93 7118.30 3690.77 325.45 -7230.93 0.62 -0.29 -0.55 19-MAY-00 MWD 12622.72 91.27 329.46 94.41 7116.74 3785.10 406.86 -7278.71 0.74 0.69 -0.28 19.MAY.00 MWD 12714.78 90.45 330.76 92.06 7115.36 3877.10 486.67 -7324.58 1.67 -0.89 1.41 19-MAY-O0 MWD 12752.81 90.86 330.59 38.03 7114.93 3915.12 519.82 -7343.20 ' 1.17 1.08 -0.45 19-MAY-00 MWD 12811.00 90.86 330.59 58.19 7114.05 3973.28 570.51 -7371.77 0.00 0.00 0.00 Projected data - NO SURVEY -- ., Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 398 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine 8/7/00 Color Well Job # Log Description Date BL Sepia Prints CD ~D1-44 20267 CDR/IMPIADN/GR -~ C1~ Ir'{ 000520 1 CD1-44 20267 MD CDR/IMP/ADN/GR 000520 I 1 CD1-44 20267 TVD CDR/IMP/ADN/GR 000520 1 1 CD1-06 ~J'l C- 20311 USlT 000704 1 2000 Alaska 0il & Gas Cons. ~0mmissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax t° (907) 561-8317. Thank~noCuh.0rage. 7/10/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 320 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-44 PB1 20266 CDR/ADN ~ ~/'~;~"~ 000510 1 CD1-44 PB1 20266 CDR MD 000510 1 1 CD1-44 PB1 20266 CDR TVD 000510 1 1 CD1-44 PB1 20266 ADN MD 000510 1 1 CD1-44 PB1 20266 ADN TVD 000510 I I RECEIVED SIGNED _ DATE: JUL 1 9 .o000 Please sign and return one copy of this transmittal to Sherrie at the above address or fax t° (907) s~J~ ~.ii~ Gas Cons. L;0mmissi0n · ~o~lge MWDILWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-44 ~;),OO' O~'~' Date Dispatche 2-Jun-00 Installation/Rig Doyon 19 Dispatched By: Nathan Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 RECE VED JUN 0 ~ 2000 AI~ ~ka 0il & Gas Cc ,~s. Commission Anchor ~ge Received By: (~~~v/~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 mse~nchorage.anaddll.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-44 API number ............... : 50-103-20335-00 Engineer ................. : Rathert Rig: ..................... : Doyon 19 State: ................... : Alaska Survey calculation ~ethods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 19.50 ft KB above permanent ....... : 0.00 ft DF above'permanent ....... : 55.90 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 331.92 degrees 19-May-2000 15:27:32 Page ORI6 ,JAL Spud date ................ : 05 May 00 Last survey date ......... : 19-May-00 Total accepted surveys...: 128 MD of first survey ....... : 0.00'ft MD of last survey ........ : 12811.00 ft 1 of 6 Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 04-May-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.81 degrees Magnetic dip ............. : 80.48 degrees ..... 'MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.81 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] AnChoTage ANADRILL SCHLUMBERGER Survey Report 19-May-2000 15:27:32 Page 2 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 114.00 0.00 0.00 3 179.00 0.75 255.00 4 297.00 2.47 272.86 5 385.00 4.13 262.35 6 475.00 5.92 265.75 7 563.00 8.41 269.13 8 654.00 10.96 267.40 9 743.00 12.34 261.81 10 832.00 13.52 264.31 11 922.00 15.03 257.45 12 966.00 16.16 254.65 13 1011.00 17.74 250.66 14 1105.00 21.28 241.85 15 1199.00 24.57 242.01 16 1296.00 28.16 244.11 17 1391.00 31.45 245.62 18 1487,00 34.54 248.07 19 1581.00 37.03 248.79 20 1676.00 39.61 249.02 21 1771.00 42.95 247.53 22 1867.00 46.81 246.30 23 1962.00 46.96 247.55 24 2057.00 46.77 246.55 25 2152.00 46.49 246.88 26 2247.00 46.28 247.90 27 2343.00 46.27 246.55 28 2438.00 45.73 248.22 29 2534.00 45.71 247.56 30 2629.00 45.65 247.01 (c)2000 ~Lnadri!l IDEAL ID6 0C 07] 0.00 114.00 65.00 118.00 88.00 90.00 88.00 91.00 89.00 89.00 90.00 44.00 45.00 94.00 94.00 97.00 95.00 96,00 94.00 95.00 95.00 96.00 95.00 95.00 95.00 95.00 96.00 95.00 96.00 95.00 TVD depth (ft) 0.00 114.00 179.00 296.95 384.80 474.45. 561.76 651.45 738.62 825.36 912.59 954.97 998.01 1086.62 1173.18 1260.08 1342.51 1423.02 1499.27 1573.79 1645.18 1713.19 1778.12 1843.07 1908.31 1973.84- 2040.20 2106.19 2173.22 2239.59 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 0.00 0.00 0.00 0.00 0.00 0.10 -0.11 -0.41 1.58 -0.18 -3.70 3.66 -0.51 -8.73 6.67 -1.29 -16.57 11.44 -1.72 -27.53 18.21 -2.21 -42.83 25.08 -3.95 -60.70 32.28 -6.34 -80.47 39.42 -9.92 -102.33 42.29 -12.78 -113.80 44.71 -16.71 -126.31 46.87 -29.50 -154.88 46.88 -46.73 -187.18 47.79 -66.19 -225.60 50.24 -86.22 -268.35 54.78 -106.73 -316.42 61.02 -126.92 -367.54 68.19 -148.12 -422.49 75.09 -171.34 -480.69 80.97 -197.91 -542.98 87.02 -225.09 -606.78 93.22 -252.12 -670.62 98.99 -279.42 -734.05 105.54 -305.87 -797.54 111.96 -332.72 -861.51 118.46 -359.00 -924.58 125.61 -384.87 -988.26 131.97 -411.12 -1050.95 0.00 0.00 0.43 3.70 8.75 0.00 0.00 TIP - 0.00 0.00 MWD - 255.00 1.15 GYR - 267.16 1.50 MWD 6-axis 266.65 2.00 MWD 6-axis 16.62 27.59 42.89 60.83 80.71 265.56 266.43 267.04 266.27 265.50 2.02 MWD 6-axis 2.87 MWD 6-axis 2.82 MWD 6-axis 2.00 MWD 6-axis 1.47 MWD 6-axis 102.81 114.52 127.41 157.66 192.93 264.46 263.59 262.47 259.21 255.98 2.52 MWD 6-axis 3.09 MWD 6-axis 4.36 MWD 6-axis 4.89 MWD 6-axis 3.50 MWD 6-axis 235.11 281.86 333.93 388.83 447.70 253.65 252.19 251.36 250.95 250.68 3.82 MWD 6-axis 3.55 MWD 6-axis 3.51 MWD 6-axis 2.69 MWD 6-axis 2.72 MWD 6-axis 510.31 577.93 647.19 716.45 785.44 250.38 249.97 249.65 249.40 249.16 3.66 MWD 6-axis 4.12 MWD 6-axis 0.97 MWD 6-axis 0.79 MWD 6-axis 0.39 MWD 6-axis 854.18 923.52 991.83 1060.56 1128.50 249.02 248.88 248.78 248.72 248.64 0.81 MWD 6-axis 1.02 MWD 6-axis 1.39 MWD 6-axis 0.49 MWD 6-axis 0~4~MWD ~axis C£1V JU l 0 5 000 Alaska Oil & Gas CO.~S. Commissior ANADRILL SCHLUMBERGER Survey Report 19-May-2000 15:27:32 Page 3 of 6 Seq Measured Inc1 Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2724.00 46.70 248.95 95.00 32 2759.00 46.82 248.16 35.00 33 2921.00 46.44 250.03 162.00 34 3017.00 46.02 248.47 96.00 35 3112.00 46.41 246.31 95.00 36 3303.00 46.23 246.92 191.00 37 3495.00 46.35 246.26 192.00 38 3685.00 46.35 244.79 190.00 39 3874.00 46.05 247.90 189.00 40 4065.00 4.6.55 245.62 191.00 41 4255.00 47.38 248.43 190.00 42 4445.00 47.09 248.03 190.0.0 43 4635.00 47.11 249.14 190.00 44 4826.00 47.28 248.86 191.00 45 5016.00 47.12 249.09 190.00 46 5206.00 46.78 248.71 .190.00 47 5396.00 46.70 248.13 190.00 48 5587.00 45.83 247.29 191.00 49 5777.00 46.52 246.68 190.00 50 5968.00 46.03 246.52 191.00 51 6157.00 45.53 245.49 189.00 52 6349.00 47.09 248.32 192.00 53 6539.00 47.13 247.41 190.00 54 6729.00 46.90 245.45 190.00 55 6920.00 48.61 247.57 191.00 56 7110.00 49.09 247.28 190.00 57 7301.00 49.17 247.11 191.00 58 7490.00 49.05 246.94 189.00 59 7680.00 48.23 247.17 190.00 60 7871.00 46.95 247.45 191.00 [(c)2000 Anadrill IDEAL ID6 0C 07] TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 2305.38 2329.35. 2440.61 2507.02 2572.76 2704.67 2837.34 2968.49 3099.33 3231.29 3360.97 3489.98 3619.32 3749.10 3878.20 400$.90 4138.11 4270.15 4401.72 4533.74 4665.55 4798.18. 4927.50 5057.05 5185.46 5310.49 5435.47 5559.19 5684.74 5813.55 139.21 142.16 156.86 165.71 172.24 -436.80 -1114.49 -446.12 -1138.22 -488.14 -1248.22 -512.70 -1313.04 -539.07 -1376.35 183.54 194.84 203.49 214.00 225.64 -593.90 -1503.13 -649.04 -1630.49 -705.99 -1755.61 -760.72 -1880.53 -815.21 -2007.39 238.02 -869.38 -2135.24 253.35 -921.12 -2264.77 269.50 -971.93 -2394.34 286.77 -1022.15 -2525.17 303.89 -1072.17 -2655.29 320.77 -1122.15 -2784.83 336.43 -1173.04 -2913.50 350.36 -12.25.38 -3041.19 362,46 -1278.97 -3167.35 373.72 -1333.79 -3294.03 383.38 -1388.87 -3417.77 395.48 -'1443.27 -3545.47 409.90 -1495.72 -3674.41 420.83 -1551.29 -3801.80 432.18 -1607.61 -3931.47 445.91 -1662.53 -4063.57 459.18 -1718.51 -4196.71 471.90 -1774.28 -4328.26 484.66 -1829.88 -4459.58 497.90 -1884.28 -4589.69 'Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 1197.03 1222.53 1340.28 1409.59 1478.15 248.60 248.60 248.64 248.67 248.61 1.84 MWD 6-axis 1.68 MWD 6-axis 0.87 MWD 6-axis 1.25 MWD 6-axis 1.69 MWD 6-axis 1616.21 1754.92 1892.25 2028.57 2166.61 248.44 248.29 248.09 247.98 247.90 0.25 MWD 6-axis 0.26 MWD 6-axis 0.56 MWD 6-axis 1.20 MWD 6-axis 0.90 MWD 6-axis 2305.44 2444..93 2584.09 2724.20 2863.59 247.85 247.87 247.91 247.96 248.01 1.17 MWD 6-axis 0.22 MWD 6-axis 0.43 MWD 6-axis 0.14 MWD 6-axis 0.12 MWD 6-axis 3002.42 3140.78 3278.78 3415.83 3553.82 248.05 248.07 248.05 248.01 247.96 0.23 MWD 6-axis 0.23 MWD 6-axis 0.56 MWD 6-axis 0.43 MWD 6-axis 0.26 MWD 6-axis 3689.19 3827.97 3967.18 4106.11 4247.45 247.88 247.85 247.85 247.80 247.76 0~47 MWD 6-axis 1.34 MWD 6-axis 0.35 MWD 6-axis 0.76 MWD 6-axis 1.22 MWD 6-axis 4390.52 4534.94 4677.81 4820.41 4961.42 247.75 247.73 247.71 247.69 247.68 0.28 MWD 6-axis 0.08 MWD 6-axis 0.09 MWD 6-axis 0.44 MWD 6-axis 0.68 MWD 6-axis RECEIVED JUN 0 5 2000 ANADRILL SCHLUMBERGER Survey Report 19-May-2000 15:27:32 Page 4 of 6 Seq Measured Incl Azimuth % depth angle angle - (ft) (deg) (deg) 61 8061.00 45.95 249.54 62 8252.00 46,01 247,99 63 8442.00 45.72 248.15 64 8633,00 45.22 247.44 65 8824,00 44,94 246,07 Course length (ft) 190.00 191,00 190.00 191,00 191,00 TVD · Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 5944.46 6077,20 6209.50 6343,45 6478.32 513,65 -1934,77 -4717,78 530,02 -1984,52 -4845.80 544,62 -2035.45 -4972.29 558,57 -2086.90 -5098.36 569,97 -2140,27 -5222.62 5099.10 5236,42 5372.78 5508.94 5644.16 247,70 0.96 247,73 0.58 247.74 0,16 247.74 0,37 247..72 0.53 Srvy Tool tool qual type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 66 9012-.00 44,66 243.31 67 9081,00 44,84 245,95 68 9116,00 45.76 250.79 69 9148.00 46,39 254,76 70 9177.00 47.38 258,49 188,00 69,00 35,00 32,00 29.00 6611.73 6660,74 6685,37 6707.57 6727.39 576.38 -2196,89 -5342.35 578.67 -2217,70 -5386,24 581,48 -2226,85 -5409,35 585,82 -2233.67 -5431.36 591,20 -2238,56 -5451.95 5776.42 5824.92 5849,78 5872,73 5893.63 247.65 1.05 247,62 2.71 247,62 10.17 247,64 9.15 247.68 9.99 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 71 9211,00 48,40 263,88 72 9243.00 49,45 268.65 73 9273.00 50.13 272.14 74 9306.00 50,73 276,26 75 9338,00 51,42 279,95 34.00 32,00 30.00 33,00 32,00 6750.20 6771.23 6790,60 6811,63 6831,74 599,52 -2242.41 -5476.86 609,47 -2243,98 -5500.92 620.39 -2243.81 -5523.82 633,97 -2241,95 -5549.18 648,67 -2238,44 -5573,82 5918,14 5941.00 5962.16 5984.96 6006,50 247,73 12,13 247,81 11,70 247.89 9.17 248,00 9.79 248.12 9.23 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 76 9369.00 52,62 283,47 77 9402.00 54.03 286.85 78 9434.00 55,54 290.34 79 9464.00 57.14 293,84 80 9496,00 58,93 296,82 81 9526,00 60.43 299.46 82 9558.00' 60.82 300.18 83 9591.00 61,30 300.29 84 9623.00 61.63 300,33 85 9654.00 62.15 300.51 31.00 33.0O 32.00 30.00 32.00 30.00 32.00 33.00 32.00 31.00 6850.82 68.70.53 6888.99 6905.62 6922.56 6937,71. 6953,41 6969,38 6984,66 6999.27 664,31 -2233,47 -5597,74 682,44 -2226.55 -5623.27 701.46 -2218.20 -5648.04 720,63 -2208.81 -5671.17 742.43 -2197,19 -5695,70 763.96 -2184,98 -5718.53 787,58 -2171,11 -5742.72 812,15 -2156,57 -5767.67 836,09 -2142,38 -5791,94 859,41 -2128,53 -5815.52 6026,86 6048,03 6068.02 6086.13 6104.81 6121.74 6139,43 6157,67 6175,47 6192,82 248.25 9.75 248.40 9.26 248.56 10.08 248.72 11.08 248.91 9.68 249.09 9.09 249.29 2.31 249,50 1.48 249,70 1.04 249,90 1,75 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD. 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 86 9687.00 64.10 302.78 87 9713.00 65.98 304.64 88 9749.00 68.38 307.10 89 9782.00 69.60 308.33 90 9843.00 72.88 312.20 [(c)2000 Anadrill IDEAL ID6 0C 07] 33.00 26,00 36.00 33.00 61,00 7014.19 7025.16 7039.12 7050.95 7070.57 884,83 -2113,09 -5840.58 905,60 -2100,01 -5860,18 935.41 -2080,56 -5887.06 963.50 -2061,71 -5911.43 1017.18 -2024,38 -5955.48 6211.08 6225,09 6243,90 6260,64 6290.14 250.11 250.28 250.5.4 250.77 251.23 8.52 MWD 6-axis 9,71 MWD 6-axis 9,17 MWD 6-axis 5.08 MWD 6-axis 8.06 MWD 6-axis RECEIVED JUN 0 5 2000 Ata.~ka Oil ~ ~s C~s Com~iss~or, ANADRILL SCHLUMBERGER Survey Report 19-May-2000 15:27:32 Page 5 of 6 Seq Measured Incl Azimuth Course TVD % depth angle angle length depth' - (ft) (deg) (deg) (ft) (ft) 91 9877.00 74.30 313.73 34.00 7080.18 92 9909.00 75.57 316.23 32.00 7088.50 93 9939.00 77.11 319.3,9 30.00 7095.58 94 9970.00 78.68 322.87 31.00 7102.09 95 10011.00 81.65 325.67 41.00 7109.09 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 1048.02 -2002.15 1077.58 -1980.31 1105.84 -1958.72 1135.61 -1935.12 1175.65 -1902.33 -5979.34 -6001.19 -6020.77 -6039.78 -6063.36 6305.64 251.49 6.01 6319.49 251.74 8.52 6331.37 251.98 11.45 6342.21 252.23 12.09 6354.78 252.58 9.89 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 96 10126,30 88.83 330.85 97 10218.00 88.94 329.14 98 10312.00 89.66 329.50 99 10405.00 89.21 331.58 100 10498.00 89.14 330.61 101 10590.00 89.21 332.59 102 10683.00 88.39 332.59 103 10774.00 88.90 333.26 104 10867.00 88.32 332.57 105 10960,00 88.46 332.32 115.30 91.70 94.00 93 .'00 93.00 92.00 93.00 91.00 93.00 93.00 7118.66 7120.44 7121.59 7122.51 7123.85 7125.17 7127.12 .7129.27 7131.53 7134.14 1290.20 -1804.70 1381.83 -1725.30 1475.72 -1644.47 1568.68 -1563.50 1661.66 -1482.10 1753.65 -1401.18 1846.62 -1318.64 1937.58 -1237.64 2030.54 -1154.86 2123.50 -1072.44 -6123.73 -6169.57 -6217.53 -6263.27 -6308.21 -6351.96 -6394.77 -6436.17 -6478.50 -6521.51 6384.12 253.58 7.67 6406.27 254.38 1.87 6431.33 255.19 0.86 6455.47 255.98 2.29 6479.98 256.78 1.05 6504.67 257.56 2.15 6529.31 258.35 0.88 6554.09 259.12 0.93 6580.63 259.89 0.97 6609.10 260.66 0.31 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 106 11052.00 89.52 333.57 107 11145.00 90.14 332.33 108 1123.6.00 90.93 333,20 109 11329.00 90.34 334.89 110 11418.00 90.17 334.26 92.00 93.00 91.00 93.00 89.00 7135.76 7136.04 7135.19 7134.16 7133.76 2215.47 2308.45 2399.43 2492.36 2581.26 -990.53 -6563.35 -907.70 -6605.64 -826.79 -6647.28 -743.18 -6687.98 -662.80 -6726.19 6637.67 261.42 1.78 6667.71 262.18 1.49 6698.50 262.'91 1.29 6729.15 263.66 1.92 6758.77 264.37 0.73 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 111 11513.03 90.65 333.54 112 11603.93 91.37 335.57 113 11695.53 90.31 334.35 114 11786.00 91.23 335.17 115 11879.67 90.55 332.76 95.03 90.90 91.60 90.47 93.67 7133.08 7131.48 7130.14 7128.92 7127.47 2676.23 2767.02 2858.48 2948.83 3042.42 -577.47 -6768.00 -495.40 -6807.04 -412.43 -6845.82 -330.61 -6884.40 -246.46 -6925.50 6792.59 265.12 0.91 6825.05 265.84 2.37 6858.23 266.55 1.77 6892.33 267.25 1.37 6929.88 267.96 2.67 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 116 11973.39 91.06 333.53 117 12064.59 90.62 332.31 118 12155.33 91.13 333.06' 119 12232.17 91.61 333.74 120 12302.95 90.00 330.46 (C)2000 Anadrill IDEAL ID6 0C 07] -- 93.72 91.20 90.74 76.84 70.78 7126.15 7124.81 7123.43 7121.59 7120.59 3136.10 3227.28 3318.00 3394.79 3465.55 -162.86 -6967.83 -81.66 -7009.35 -1.05 -7050.98 67.63 -7085.37 130.17 -7118.49 6969.74 7009.82 7050.98 7085.'70 7119.68 268.66 269.33 269.99 270.55 271.05 0.99 MWD 6-axis 1.42 MWD 6-axis 1.00 MWD 6-axis 1.08 MWD - 5.16 MWD - RECEIVED JUl',] 0 5 2000 ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 19-May-2000 15:27:32 TVD Vertical Displ Displ depth section +N/S- '+E/W- (ft) (ft) (ft) (ft) 121 12339.94 90.27 329.98 36.99 7120.51 122 12385.10 90.58 330.07 45.16 7120.17 123 12435.38 90.89 330.23 50.28 7119.53 124 12528.31 90.62 329.72 92.93 7118.30 125 12622.72 91.27 329.46 94.41 7116.75 Page 126 12714.78 90.45 330.76 92.06 127 12752.81 90.86 330.59 38.03 Survey projected to TD 128 12811.00 90.86 330.59 58.19 6 of 6 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 3502.53 162.28 -7136.86 7138.70 271.30 3547.66 201.39 -7159.42 7162.25 271.61 3597.91 245.00 -7184.44 7'188.62 271.95 3690.78 325.45 -7230.94 7238.26 272.58 3785.10 406.86 -7278.72 7290.08 273.20 7115.36 3877.10 486.67 -7324.59 7340.74 273.80 7114.93 3915.12 519.82 -7343.22 7361.59 274.05 7114.06 3973.29 570.50 -7371.79 7393.83 274.43 1.49 MWD 6-axis 0.71 MWD 6-axis 0.69 MWD 6-axis 0.62 MWD 6-axis 0.74 MWD 6-axis 1.67 MWD 6-axis 1.17 MWD 6-axis 0.00 MWD - [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED 0 5 ;1000 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska Inc. Field .................... : Colville River Well ..................... : CD1-44PH Spud date ................ : 05 May 00 Last survey date .......... : il-May-00 API number ............... : 50-103-20335-70 Engineer ................. : Dammeyer Rig: ..................... : Doyon 19 State: ................... : Alaska il-May-2000 08:06:18 Page 0R G NAL Total accepted surveys...: 71 MD of first survey ....... : 0.00 ft MD of last survey ........ : 9882.00 ft 1 of 4 Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Magnetic dip ............. : 80.48 degrees Depth reference .......... : Drill Floor GL above permanent ....... : I9.50 ft KB above permanent ....... : 0.00 ft DF above permanent ....... : 55.90 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-} ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 253.16 degrees Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 04-May-2000 Magnetic field strength..: 1144.65 HCNT Magnetic dec (+E/W-) ..... : 25.81 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1144.65 HCNT Reference Dip ............ : 80.48 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.81 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6 0C 07] RECEIVED 26 000 Alaska Oil & Gas Cons. Commission Anchorage ANADRILL SCHLUMBERGER Survey Report il-May-2000 08:06:18 Page 2 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 3 179.00 0.75 255.00 65.00 4 297.00 2.47 272.86 118.00 5 385.00 4.13 262.35 88.00 6 475.00 5.92 265.75 7 563.00 8.41 269.13 8 654.00 10.96 267.40 9 743.00 12.34 261.81 10 832.00 13.52 264.31 11 922.00 15.03 257.45 12 966.00 16.16 254.65 13 1011.00 17.74 250.66 14 1105.00 21.28 241.85 15 1199.00 24.57 242.01 16 1296.00 28.16 244.11 17 1391.00 31.45 245.62 18 1487.00 34.54 248.07 19 1581.00~ 37.03 248.79 20 1676.00 39.61 249.02 21 1771.00 42.95 247.53 22 1867.00 46.81 246.30 23 1962.00 46.96 247.55 24 2057.00 46.77 246.55 25 2152.00 46.49 246.88 90.00 88.00 91.00 89.00 89.00 90.00 44.00 45.00 94.00 94.00 97.00 95.00 96.00 94.00 95.00 95.00 96.00 95.00 95.00 95.00 26 2247.00 46.28 247.90 95.00 27 2343.00 46.27 246.55 96.00 28 2438.00 45.73 248.22 95.00 29 2534.00 45.71 247.56 96.00 30 2629.00 45.65 247.01 95.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) lOOf) 0.00 0.00 0.00 0 114.00 0.00 0.00 0 179.00 0.43 -0.11 -0 296.95 3.59 -0.18 -3 384.80 8.51 -0.51 -8 .00 .00 .41 .70 .73 474.45 16.23 -1.29 -16.57 561.76 26.85 -1.72 -27.53 651.45 41.64 -2.21 -42.83 738.62 59.24 -3.95 -60.70 825.36 78.85 -6.34 -80.47 912.59 100.81 -9.92 -102.33 954.97 112.62 -12.78 -113.80 998.01 125.73 -16.71 -126.31 1086.62 156.78 -29.50 -154.88 1173.18 192.69 -46.73 -187.18 1260.08 1342.51 1423.02 1499.27 1573.79 1645.18 1713.19 1778.12 1843.07 1908.31 235.10 -66.19 -225.60 281.82 -86.22 -268.35 333.77 -106.73 -316.42 388.54 -126.92 -367.54 447.28 -148.12 -422.49 509.71 -171.34 -480.69 577.03 -197.91 -542.98 645.97 -225.09 -606.78 714.90 -252.12 -670.62 783.52 -279.42 -734.05 851.95 -305.87 -797.54 920.95 -332.72 -861.51 988.94 -359.00 -924.58 1057.38 -384.87 -988.26 1124.99 -411.12 -1050.95 1973.84 2040.20 2106.19 2173.22 2239.59 0.00 0.00 0.00 0.00 0.43 255.00 3.70 267.16 8.75 266.65 16.62 265.56 27.59 266.43 42.89 267.04 60.83 266.27 80.71 265.50 102.81 264.46 114.52 263.59 127.41 262.47 157.66 259.21 192.93 255.98 235.11 253.65 281.86 252.19 333.93 251.36 388.83 250.95 447.70 250.68 510.31 250.38 577.93 249.97 647.19 249.65 716.45 249.40 785.44 249.16 854.18 249.02 923.52 248.88 991.83 248.78 1060.56 248.72 1128.50 248.64 Srvy Tool tool qual type type 0.00 TIP - 0.00 MWD - 1.15 GYR - 1.50 MWD 6-axis 2.00 MWD 6-axis 2.02 MWD 6-axis 2.87 MWD 6-axis 2.82 MWD 6-axis 2.00 MWD 6-axis 1.47 MWD 6-axis 2.52 MWD 6-axis 3.09 MWD 6-axis 4.36 MWD 6-axis 4.89 MWD 6-axis 3.50 MWD 6-axis 3.82 MWD 6-axis 3.55 MWD 6-axis 3.51 MWD 6-axis 2.69 MWD 6-axis 2.72 MWD 6-axis 3.66 MWD 6-axis 4.12 MWD 6-axis 0.97 MWD 6-axis 0.79 MWD 6-axis 0.39 MWD 6-axis 0.81 MWD 6-axis 1.02 MWD 6-axis 1.39 MWD 6-axis 0.49 MWD 6-axis 0.42 MWD 6-axis RECEIVED MAY 2_6 2000 Alaska 0il & ,~as Co~s. ,C~s~ ANADRILL SCHLUMBERGER Survey Report il-May-2000 08:06:18 Page 3 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2724.00 46.70 248.95 95.00 32 2759.00 46.82 248.16 35.00 33 2921.00 46.44 250.03 162.00 34 3017.00 46.02 248.47 96.00 35 3112.00 46.41 246.31 95.00 36 3303.00 46.23 246.92 191.00 37 3495.00 46.35 246.26 192.00 38 3685.00 46.35 244.79 190.00 39 3874.00 46.05 247.90 189.00 40 4065.00 46.55 245.62 191.00 41 4255.00 47.38 248.43 190.00 42 4445.00 47.09 248.03 190.00 43 4635.00 47.11 249.14 190.00 44 4826.00 47.28 248.86 191.00 45 5016.00 47.12 249.09 190.00 46 5206.00 46.78 248.71 190.00 47 5396.00 46.70 248.13 190.00 48 5587.00 45.83 247.29 191.00 49 5777.00 46.52 246.68 190.00 50 5968.00 46.03 246.52 191.00 51 6157.00 45.53 245.49 189.00 52 6349.00 47.09 248.32 192.00 53 6539.00 47.13 247.41 190.00 54 6729.00 46.90 245.45 190.00 55 6920.00 48.61 247.57 191.00 56 7110.00 49.09 247.28 190.00 57 7301.00 49.17 247.11 191.00 58 7490.00 49.05 246.94 189.00 59 7680.00 48.23 247.17 190.00 60 7871.00 46.95 247.45 191.00 TVD Vertical Displ Displ Total depth section +N/S- +E/W- disp1 (ft) (ft) (ft) (ft) (ft) 2305.38 2329.35 2440.61 2507.02 2572.76 2704.67 2837.34 2968.49 3099.33 3231.29 3360.97 3489.98 3619.32 3749.10 3878.20 4007.90 4138.11 4270.15 4401.72 4533.74 4665.55 4798.18 4927.50 5057.O5 5185.46 5310.49 5435.47 5559.19 5684.74 5813.55 1193.24 1218.65 1336.11 1405.27 1473.50 -436.80 -1114.49 -446.12 -1138.22 -488.14 -1248.22 -512.70 -1313.04 -539.07 -1376.35 1610.73 1748.60 1884.85 2020.27 2157.47 -593.90 -1503.13 -649.04 -1630.49 -705.99 -1755.61 -760.72 -1880.53 -815.21 -2007.39 2295.53 -869.38 -2135.24 2434.50 -921.12 -2264.77 2573.24 -971.93 -2394.34 2713.00 -1022.15 -2525.17 2852.04 -1072.17 -2655.29 2990.50 -1122.15 -2784.83 3128.39 -1173.04 -2913.50 3265.77 -1225.38 -3041.19 3402.05 -12'78.97 -3167.35 3539.17 -1333.79 -3294.03 3673.57 -1388.87 -3417.77 3811.54 -1443.27 -3545.47 3950.15 -1495.72 -3674.41 4088.17 -1551.29 -3801.80 4228.60 -1607.61 -3931.47 4370.95 -1662.53 -4063.57 4514.60 -1718.51 -4196.71 4656.66 -1774.28 -4328.26 4798.46 -1829.88 -4459.58 4938.75 -1884.28 -4589.69 At DLS Srvy Tool Azim (deg/ tool qual (deg) I00f) type type 1197.03 1222.53 1340.28 1409.59 1478.15 248.60 1.84 MWD 6-axis 248.60 1.68 MWD 6-axis 248.64 0.87 MWD 6-axis 248.67 1.25 MWD 6-axis 248.61 1.69 MWD 6-axis 1616.21 1754.92 1892.25 2028.57 2166.61 248.44 0.25 MWD 6-axis 248.29 0.26 MWD 6-axis 248.09 0.56 MWD 6-axis 247.98 1.20 MWD 6-axis 247.90 0.90 MWD 6-axis 2305.44 2444.93 2584.09 2724.20 2863.59 247.85 1.17 MWD 6-axis 247.87 0.22 MWD 6-axis 247.91 0.43 MWD 6-axis 247.96 0.14 MWD 6-axis 248.01 0.12 MWD 6-axis 3002.42 3140.78 3278.78 3415.83 3553.82 248.05 0.23 MWD 6-axis 248.07 0.23 MWD 6-axis 248.05 0.56 MWD 6-axis 248.01 0.43 MWD 6-axis 247.96 0.26 MWD 6-axis 3689.19 3827.97 3967.18 4106.11 4247.45 247.88 0.47 MWD 6-axis 247.85 1.34 MWD 6-axis 247.85 0.35 MWD 6-axis 247.80 0.76 MWD 6-axis 247.76 1.22 MWD 6-axis 4390.52 4534.94 4677.81 4820.41 4961.42 247.75 0.28 MWD 6-axis 247.73 0.08 MWD 6-axis 247.71 0.09 MWD 6-axis 247.69 0.44 MWD 6-axis 247.68 0.68 MWD 6-axis RECEIVED MAY 26 000 Alaska Oil & Gas Co~s. G~mission Ar~chorage ANADRILL SCHLUMBERGER Survey Report Il-May-2000 08:06:18 Page 4 of 4 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 8061.00 45.95 249.54 190.00 62 8252.00 46.01 247.99 191.00 63 8442.00 45.72 248.15 190.00 64 8633.00 45.22 247.44 191.00 65 8824.00 44.94 246.07 191.00 66 9012.00 44.66 243.31 188.00 67 9206.00 45.41 250.42 194.00 68 9395.00 45.86 252.36 189.00 69 9584.00 45.81 252.33 189.00 70 9806'.67 46.98 251.19 222.67 Last Survey pro~ected to TD 71 9882.00 46.98 251.19 75.33 TVD depth (ft) 5944.46 6077.20 6209.50 6343.45 6478.32 6611.73 6748.91 6881.07 7012.76 7166.33 7217.72 Verti sect (ft 5075. 5212. 5348. 5484. 5618. cai Displ Displ Total At DLS Srvy Tool ion +N/S- +E/W- displ Azim (deg/ tool qual ) (ft) (ft) (ft) (deg) iOOf) type type 98 -1934.77 -4717.78 5099.10 91 -1984.52 -4845.80 5236.42 74 -2035.45 -4972.29 5372.78 30 -2086.90 -5098.36 5508.94 70 -2140.27 -5222.62. 5644.16 247.70 0.96 247.73 0.58 247.74 0.16 247.74 0.37 247.72 0.53 5749.70 -2196.89 -5342.35 5776.42 5885.96 -2250.70 -5468.44 5913.50 6021.00 -2293.80 -5596.48 6048.31 6156.56 -2334.92 -5725.67 6183.46 6317.75 -2385.40 -5878.79 6344.32 247.65 1.05 247.63 2.62 247.71 0.77 247.81 0.03 247.91 0.64 6372.79 -2403.16 -5930.93 6399.30 247.94 0.00 MWD MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)2000 Anadrill IDEAL ID6 0C 07] __ -- RECEIVED 2 6 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ii-~-¥~-I~-~"f--request: Abandon_" Suspend- ........... O~ratisi~i-~-h-6-t-8-b-~-fi--_- ................. A-~---4-h-~F~i~F-~-~i~-~i-~-&F- .......................................................................... Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Annular Injection - X 2. Name of Operator 5. Type of Well: 6. Datum eleva~on (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 56' feet 3. Address Exploratory_ 17. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. LocaUon of well at surface 8. Well number 531' FNL, 2272' FWL, Sec.5, T11 N, R5E, UM CD1-44 At target (7" casing point in Alpine)) 9. Permit number / approval number 2372' FNL, 1077' FWL, Sec 6, T11 N, R5E, UM .... per APD 2OO-55 At effective depth 10. APl number 50-103-20335-00 iAt total depth 11. Field / Pool 42' FS..L., 212' FEL, Sec.36, T12N, R4E, UM ...... per APB Colville River Field/Alpine Oil Pool 12. Present well condition' summary Total depth: measured 12811 feet true vertical 7114 feet 0RI61NAL ;Effective depth: measured 12811 feet true vertical 7114 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114 Surface 2789' 9.625" 426 sx ASL3, 230 sx Class G 2825' 2374' Production 10036' 7" 125 sx Class G 10072' 7116' CD1-44 is as an open hole production well. ltwas suspended after being completed with 4-1/2" tubing...R It is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 3 '! 2000 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: June 30, 2000 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that/t~e foregoing is true and correct to the best of my knowledge. Signed //~,/L~ Title: Drilling Team Leader Date ,/~ / - v '~ot FOR COMMISSION USE ONLY Conditions of appro ify Commission so representative may witness Approval I,' Plug integrity BOP Test__ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- ~ ~ ORIGINAL SIGNED BY ,__A__p_Eoved by order of the Commission D Taylor S...e.amount . commissioner Date _~_-__.._-"'~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Casing Detail Well: CD1-44 9 5/8" Surface Casing Date: 5/7/00 r-HILLIPS Alaska, Inc. ' ~'"'~ A ~suDsidiary or PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 36.40 FMC Gert V Hanger 2.41 36.40 Jts 3 to 66 64 Jts 9-5/8" 36# J-55 BTC Csg 2708.83 38.81 Davis Lynch Float Collar 1.53 2747.64 Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 74.11 2749.17 Davis Lynch Float Shoe 1.76 2823.28 2825.04 TD 12 1/4" Sudace Hole 2835.00 RUN TOTAL 38 BOWSPRING CENTRALIZERS - I per jt on Jt #1 - ~12 (On stop rings of Jt ~1 & ~) ~14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64 7 Jts left out ~67 - ~73 , ...... :51 2000 ,~aska 0~ & Gas C~s. Commi~ion Anchom9~ Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 154k Dn Wt -130k Block Wt - 70k Supe~isor: Lutdc~oilly ARCO Alaska, Inc. Cementing Details Well Name: CD1-44 Report Date: 05/06/2000 Report Number: 1 Ri~ Name: Doyen 19 AFC No.: 998C07 Field: Alpine ! Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: I % washout: 9.625" 12.25" 46I 2825 2748I 33 Centralizers State type used, intervals covered and spacing Comments: Ran 38 Bow Springs - 1 per jt 1st 12 jts and every other jt to surface Mud Weight: PV(prior cond): PV(after cond): YP(prior cend): YP(after cond): Comments: 9.9-9.8 21 17 45 24 Gels before: Gels after: Total Volume Circulated: : 33/69/75 13/34/41 850 bbls · Wash 0 Type: Volume: Weight: Comments: 40 8.4 iBiozan w/6 sx coarse nut plug · SPacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LWI 70 426I 10.7 4.42 Additives: 30% D53, 0.6% D46, 1.5% D79, 1.5% S1, 50% D-124, 9% D44 Tail cement 0 i Type: I Mixwtrtemp: I No. of Sacks:' Weight: J Yield: Comments: GI J I 170 230 15.8 1.15 Additives: · 0.2% D46, 0.3% D65, 1% S1 DisPlacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 9.5 bpm 9.5 bpm 154k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' 10 fpm 130k Theoret ca Displacement: Actual Displacement: Str. Wt. in mud: 212 214 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:5/7/00 Yes Yes Time:02:00 Remarks:Full return through out job. Approx 100 bbls 10.7 cement to surface. Cement Company: IRig Contractor: IApproved By: DOYEN I Lutrick / Reilly DS eske Oil & Gas Cons. CornmJ ion ARCO Alaska, Inc. A, chorage Daily Drilling Report i AFC No. I Date Rpt No I Rig Accept - hrs Days Since Accept/Est: 2.9 / 2.9 998C07 105/07/2000 4IAMI 05~04/2000 02:30:00 Rig Relase - hrs: Well: CD1-44 Depth (MD/TVD) 2855/2394 Prev Depth MD: 2835 I Progress: 20 Contractor: DOYON Daily Cost $ 299554 Cum Cost $ 592344 Est Cost To Date $ 625000 Rig Name: Doyon 19 Last Csg: 9 5/8" @ 2825 Next Cs~l: 7" @ 10064 Shoe Test: Operation At 0600: Drilling @ 3470'. Upcoming Operations: Drill ahead to TD 9853'. MUDDATA: ~RIL~iNGDATA [ i BI, DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOP/DIVERT LAST BOP/DRILL LSND 2835 2 N TST 05/07/2000 05/04/2000 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.6ppg 135 8 1/2 05/07/2000 04/27/2000 VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 44sqc 155 HYC N SPACE 04/09/2000 03/07/2000 PV/YP SO WT TYPE TYPE TYPE FUEL & WATER 8 / 2O 120 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3230 10 / 17 / 22 22656 APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1450 22,0 05/02/2000 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 93 natal/30 Tin 10.5 2833 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8,5% 10 22 CD1-23 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F 9 191bbl 1300 I 1430 I I 0,2 / 0.0 / CD1-44 MBT I PUMP NO WOE 2 WOE 2 RATE (bpm) WIND SPEED 6 26.0 I 121 I 0-12 3h LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 10° lO.8 5.s I 6.o I I 153- 203 LGS SPM 1 TFA TEA INJECTION FLUIDS CHILL FACTOR °F 1.21 5.1% 621 561 I 0.557 Water Base Muds 1680 PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2 ,92 221 I 238l I 11 111 111 111 111 I I I I I 50 11 Other 150 DAILY MUD SPS 1 BIT COST BIT COST Other CONTRACTOR 26 $16845 30 I 40 I 30 I 40 200 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbi) MISC PERSONNEL 5 $32006 2251 27512501 I I I I I I 2080 3OO COMPANY MUD wm GRADE GRADE TOT FOR WELL (bbl) SERVICE 16 MI 9.6111 III II 32881 PERSONNEL TOTAL 49 ~PS ~ODEI HOER SECT IPHASE OPS I OPERATIONS FROM 0000- 0000 12:00 AM 02:00 AM 2.00 CEMENT SURF Casing and PJSM- pump 35 bbl bio wash-5 bbl H20-test-50 bbl 10.5 # Cementing spcr-10.7 # lead cmt-47 bbl 15.8 # tail-20bbl H20 disp w/rig 192 bbl. 02:00 AM 03:00 AM 1.00 CEMENT SURF Casing and L/D LJ-clean floor. Cementing 03:00 AM 03:30 AM 0.50 CEMENT SURF Casing and Jet diverter riser. Cementing 03:30 AM 04:30 AM 1.00 NU_ND SURF Other N/D diverter-riser-flowline. 04:30 AM 05:30 AM 1.00 NU_ND SURF Other N/U Uni-head and test. 05:30 AM 06:30 AM 1.00 NU_ND P1 Other N/U ROPE. 06:30 AM 07:00 AM 0.50 PREP P1 Other PJU to test. 07:00 AM 11:30 AM 4.50 ROPE P1 Other Test ROPE-witnessed by John Crisp AOGCC. Service top drive-H2S drill @ 1030 hrs 1.5 min. 11:30 AM 12:00 PM 0.50 PREP P1 Other PJU bails-elevators. 12:00 PM 12:30 PM 0.50 PREP P1 Other RIH w/DP off rack-stand back 21 std. 12:30 PM 04:00 PM 3.50 BHA P1 Other M/U BHA-Ioad source-shallow test MWD. 04:00 PM 05:00 PM 1.00 TRIP_IN P1 Making Hole RIH T/1574'-D1 kick drill @ 1700hrs 50 sec. 05:00 PM 06:30 PM 1.50 SAFETY P1 Other Stripping drill w/both crews. 06:30 PM 07:30 PM 1.00 PREP P1 Other Retrieve dart and floor valve and P/U 15 jts DP T/2050'. Daily Drilling Report: CD1-44 05/07/2000 Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-44 Date: 5/7/00 Reason(s) for test: Supervisor: Donald Lutrick [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,825' TMD 2,374' TVD Mud Weight: 9.6 ppg Hole Depth: Length of Open Hole: 2,855' TMD 2,395' TVD 30' 2418 Press EMW = 0.052 xTVD + Mud Weight 790 psi 0,052 x 2,374' EMW = 15.94 ppg + 9.6 ppg Pump output = .101 BPS Fluid Pumped = 1.4 BBL BLED BACK = 1.1 BBLS 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,1 O0 psi 2,500 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1.200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi Ostk 2 stk 4 stk 6 stk 8 stk lOstk 12stk 14stk 16stk 18sfk 20stk 22stk 24 stk 26stk 28stk 30stk 32stk 34stk 36stk 38stk 40stk 42stk 44 stk 46stk 48stk 50stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ~ 0 stks 60 psi .................. [....2.~t..k..s. ...... ..2.2..O...p.s.i .... j .................. [_...4..s.t..k..~. ...... ..3.4._O_..p~i....j .................. [....S.~t_.k..s. ...... __4.S..O...p. sj .... j .................. [.__.8..s.t..k..s. ...... ..S.S..O.._p_s_i .... j .................. [.._tO...s.t..k.s. ...... .?.4..o...p. sj .... j .................. [...~.2...s.t..k~. ..... ..7.3..0___p~! .... j .................. [..1.4..~t_.k~.+....7~.O...p.s.! .... j , i i .................. J, .............. ,I, .................. i i i i i .................. J. .............. ,j, .................. i i i ! , i i .................. ii" .............. i .................. J .................. [ .............. , .................. j i i .................. [ .............. J ................. 4 i ! .................. i .............. J .................. .................. [ .............. i .................. .................. ! .............. i .................. i i i i I i i ,- ................. ,F .............. T .................. .................. [ .............. i ................. SHUT IN TIME ' SHUT IN PRESSURE .................. ~' .............. 'r .................. 0.0 min I ; 790 nsi .................. F .............. T .......... c ...... -t 10min : : 785nsi ...... · - ........... ~ .............. } .......... cz ..... -! .... _2__.o...m.L~_..__[ .............. i .... .7..~_o__~.t..4 .... .a....o...m_L~___..[ .............. i .... _7_.7.o..t~.L._4 .... .4. .. 9_ . .m. Ln....[ .............. i .... .~.o..p..s__L_.4 50min ~ ~ 750nsi ...... ' ........... I- .............. ½ .......... r ...... .... .............. i .... _7__4.0._m___4 .... .............. i .... .7.4..0__m.__4 8 0 min I : 730 nsi ...... ' ........... I- .............. ½ .......... ['- ..... -! .... ~'-9--m-L~----[ .............. i .... -7-2--°--?~-L--4 lO.Omin I 0~,~, , I 71 -~; ' .................. J. .............. j, ................. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [ 2stks ~ 150psi ~ 4stks ~ 360 psi ................. [___~_s...s.t..k.s.. ...... _l_,_4_~.O__p__s..i .... i [ 22 stks 2,010 psi ~ 27 stks .... .2:.5._2..O...p.s_] .... j SHUTINTIME , , , .... _O_..O...m.i.n..__[ .............. j .... .2.,_.5_l_.O...p_s.i .... j 5.0 min : : 2,495 psi lO.Omin.~ ~ 2,480psi 15.0min ~ ~ 2,465 .................. [ .............. , ..................... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-44 Date: 5/15/00 Supervisor: S.D. Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X Casing Setting Depth: 2,825' TMD 2,374' TVD 7" 26# L-80 BTCM CSG TOC Hole Depth: 9,987' TMD 7,102' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 7,162' EMW = Leak-off Press· + Mud Weight 0.052 x TVD = 682 psi + 9.3 ppg 0.052 x 2,374' EMW for open hole section = 14.8 ppg Used cement unit Riq pump used YES #2 Pump output = bbls pumped Fluid Pumped = 15.7 bbls Fluid Bled Back = N/A 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 ONE MINUTE TICKS ..-e-- LEAK-OFF TEST ~CASING TEST LOT SHUT IN TIME --~,--- CASING TEST SHUT IN TIME TIME LINE 10 BARRELS NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT BBLSPRESSURE ................ ~ ....... ~)- ............ ~-~,-~ ...... ................ I ...... i:~ ......... '~'i;-,;i .... ................ I ..... ',~:~ ......... '~"~'~i'" ................ ! ..... '~:~ ......... '~,"~a"' ................ I ..... -~:~ ......... '~,"~,'a'-- ................ ! ..... '.~:~ ......... '~'F~-a'" ::::::::::::::::::::::::::::::::::::::::::::::::: ~ 7.0 288 psi ................ I ..... -~:~ ......... -~--~-a--- ................ I ..... -~:~ ......... -~-~,-a--- ................ I ..... ~-~:~ ........ -,i:~--~,-a--- ................ I ..... ~-~:~ ........ -~-~--~,-,;i--- ................ I ..... ~-~:~ ........ ~:~--~,-a--- ................ I ..... ~-~:~ ........ -~-¥-~,-~i--- ................ I ..... ~-~:~ ........ -~:~¥-~-a--- ................ I ..... ~-~:~ ........ -~¥-~,-;i--- ................ I ..... ~-~:~ ........ -~,--~-;i--- ................ ! ..... ~-~:~ ........ -~)--~-a--- ................ I ..... ~-~:~ ........ -~--~,-a--- ................ 4 ..... .1.5_:.7. .... ~.._?..5..6..p_?.! .... I I I ' I i i SHUT IN TIME ~ SHUT IN PRESSURE 0.0 min = ~ 656 psi '-"l':b- ........ min I ............... 1---~-~-~--~,-a.... '--~:~- ........ m~n I ............... I---'~'-~'~F- ........~.o-~i;,'"! ............... I'"'~¥'~,'~F- "-:~:~)"~i~'-! ............... I'"'~"~-~i'" 5.0 min ~ , 591 psi "'Eb--~i~'", ............... !-'"~:G'~F- 7.0 min ~ = 586 psi "-;:b"~i;,'-'1 ............... I'"'~¥'~,-~i'" '--~:~--~-"! ............... I--'~¥-~'a'-' ................ ~ ............... 1'-~'-~-a'" ._.!_°.-..°__.m_Ln_j ............... ~ ................. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ................ i I i i i i i i i ................ + ............... + ................. I i i i i i i ................ +, ............... +, ................ ! ! , ! ................ t ............... t ................ 'I,, ................ ½ ............... ½ ................. I i i i i ................ i i i i ................ i i i i ................ i i i i i ! ................ f ............... f ................ I ! ................ t ............... t ................ 'I,, i i i i i i ................ t ............... t ................ ! ................ t ............... t ................ I ................ t ............... t ................ I i i i i i i I SHUT IN TIME J SHUT IN PRESSURE ........... 7 .... 0.0 m~n ................ f ............... f ................ '!, 1.0 min , , , ................ t ............... t ................ '!, 2.0 min , , , 3.0 min ........... · ' .... t ............... t ................ -i 4.0 m~n , ................ · i i i 5.0 mln , , , ................ + ............... + ................4. · i i i 6.0 m~n , , , "-~:~--r~;C't ............... t ................ I ................ t ............... t ................ 'I,, 8.0 min · --~:8--~r¢,---t ............... t ................ I ................ t ............... t ................ 10.0 min ................ 15.0 rain 20.0 ................ · i i i 25.0 m~n , , , ................ ._3..°.-9_.m. Ln_..i ............... i ................ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Modified by Scott Reynolds Colville River Field CD1-44 Production Well Completion - as built 16" Conductor to 114' Completed 05/21/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1825' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines Cd1-44PH - cement kick off plug at 9060' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2825' MD / 2374' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve (sheared out) WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2421' MD diesel cap Tubing Supended with diesel to lowest GLM / 9.2 ppg brine below Completion Tubing 4-1/2", Camco 4-1/2", Camco 4-1/2", Camco 4-1/2", Hanger 12.6#/ft, IBT-Mod Tubing BAL-O SSSV Nipple 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing KBG-2 GLM (3.909" ID) 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4-1/2" tubing joints (2) HES "X" (3.813" ID) 4-1/2" tubing joint (1) Baker S3 Packer 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 4-1/2" 10' pup joint WEG (+/- 62 deg) MD 32' 1825' 4308' 6918' 9411' 9514' 9569' 9645' 9657' TOC @ +/- 9390' MD £000 Anchorage 7" 26 ppf L-80 BTC Mod Production Casing @ 10072' MD / 7116' TVD Well TD at 12811' MD / 7114' TVD Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 30, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-44 Dear Sirs: Phillips Alaska, Inc. hereby requests that CDI-44 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. Please find attached form 10-403 and other pertinent information as follows: . 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Copy of the Daily Drilling Report covering surface casing cementing. Casing and Formation Test Integrity Report (LOT at surface casing shoe). Formation LOT on 9-5/8" x 7" casing annulus. CD1-44 Well Completion Schematic. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, ,~~~)~ Brian Robertson Senior Drilling Engineer CC. CD1-44 Well File Alpine Files Doug Chester Gracie Stefanescu ANO-382 Anadarko MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman DATE: May 15, 2000 THRU: Blair Wondzell P.I. Supervisor FROM: Lou Grimaldi ~ Petroleum I ns'pector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Doyon rig 19 Arco/Phillips CD1-44 200-055 Colville River Field, Alpine Operator Rep.: Scott Reynolds Contractor Rep.: Mark Egholm Op. phone: 263-3000 Rig phone: 263-3003 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 250/3500 MISC. INSPECTIONS: P/F Location Gen.: P Sign: Housekeeping: P Rig cond: PTD On Location P Hazard: Standing Order: P P/F P Annular: p~ BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8 P Pipe Rams I 3 1/2X6 P Lower Pipe Rams I 3 1/2X6 P Blind Rams I 13 5/8 P Choke Ln. Valves I 4" P HCR Valves 2 3&4" P Kill Line Valves 1 3" P Check Valve 0 Choke: 250/3500 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly I P Ball Type I P Inside BOP I P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P -- H2S Gas Detector P P -' CHOKE MANIFOLD: Quantity P/F No. Valves 16 P Man. Chokes I P Hyd. Chokes 1 P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 P After Closure 1450 ~" P 200 psi Attained :38 P Full Pressure 3:23 P Blind Covers (All Stations):. P N2 Bottles (avg): 4 @ 1900 PSI Test's Details This rig consistantly performs well during BOPE tests. The crew seems well trained in the test procedure which helps the test move along quickly. The equipment is well maintained and in the past I have only witnessed failures due to normal wear on components. Although the the rest of the Alpine pad is extremely busy and congested the area surrounding the rig is orderly and clean. I felt compelled to congratulate Scott Reynolds (Co. Rep.) and Mark Egholm (ToolPusher) on their operation which I feel is the best on the North Slope at this time. · (' 3 hfs) of failures: Total Test Time' Number cc: Alpine Drillinq en.qineer Attatchments: None BOP DOYON 19 CRU 5-15-00 LG 5/22/00 MEMORANDUM State of Alaska TO: Alaj~ka Oil and Gas Conservation Commission Robert Christenso DATE: May 7, 2000 Chairman THRU' Blair Wondzell, P. I. Supervisor FROM' John CrisP~,/~ ~_< SUBJECT: Petroleum/lhspector BOP Test Doyon 19 Colville River CD1-44 PTD 200055 March 11, 2000' I traveled to Arco Alaska's Colville River Field to witness the initial BOP test on Doyon 19 drilling well CD1-44. The AOGCC BOP test report is attached for reference. The Rig is in excellent condition. All Rig personnel involved with this test were very familiar with BOP equipment & test procedures. SUMMARY: I witnessed the initial BOPE test on Doyon Rig 19 drilling well CD1- 44 in the Colville River Field. BOP test Doyon 19. Test time 4 hours. No failures. Attachments' BOP Doyon 19 5-7-00jc cc; NON-CONFIDENTIAL BOP Doyon 19 5-7-00jc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Drlg. Rig No. Operator: Arco Alaska Inc. Well Name: Alipine 0D1-44 Casing Size: 9 5/8" Set @ 2844' Test: Initial X Weekly Other 19 PTD # Rep.: Rig Rep.: Location: Sec. 200-055 DATE: 5/7/00 Rig Ph.# 907 263-3000 Donnie Lutrick Ron Matteson 5 T. 11N R. 5E Meridian UM Test MISC. INSPECTIONS: · Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Quan Pressure P/F I 250/3,500 P I 250/3,500 P I 250/3,500 P 1 250/3,500 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 25O/2,5OO P I 250/3,500 P 1 250/3,500 P I 250/3,500 P 1 250/3,500 P 2 250/3,500 P I 250/3,500 P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3,500 P 36 250/3,500 P 1 YES Functioned Functioned YES ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 P 1,500 P minutes 26 2 minutes 52 YES Remote: 4 Btls. @ 1950 psi. ave. Psig. sec. sec. YES Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - I nspe~:t.~1L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp ~on 195-7-00jc ALASKA OIL AND GAS Doug Chester CONSERVATION COPlPllSSION Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Colville River Unit CD 1-44 ARCO Alaska, Inc. Permit No: 200-055 Sur Loc: 53 I'FNL, 2272'FWL, Sec. 5, T11N, R5E, UM Btmhole Loc. 42'FSL, 212'FEL, Sec. 36, T12N, R4E, UM Dear Mr. Chester: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data,, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pcrmit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longcr than one )'car. The pcrmit to drill does not exempt you from obtaining additional permits rcquircd by law from other govcrnmcntal agencies, and does not authorize conducting drilling operations until all othcr required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be givcn to allox¥ a rcprescntativc of thc Commission to witncss a test of BOPE installed prior to drilling new hole. Notice may be givcn by contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christcnson~ P.E. Chair BY ORDER OF T.X~ COMMISSION DATED this ~ day of May, 2000 dlf/Enclosurcs cc~ Department of Fish & Galne. Habitat Section w/o encl. Depamnent of Environmental Conservation xv/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 & 380096 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 531' FNL, 2272' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 2372' FNL, 1077' FWL, Sec. 6, T11 N, R5E, UM CD1-44 #U-630610 At total depth 9. Approximate spud date Amount 42' FSL, 212' FEL, Sec. 36, T12N, R4E, UM 05/01/2000 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Property line Alpine CD1- 45 12,800 MD Crosses T11N to feet 9.9' @ 200' Feet 2560 7,117'TVD feet T12N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 91 o Maximum su~ace 2510 psig At total depth (TVD) 3215 at psig 7000' TVD.SS 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casin~ Weight Grade Couplin~l Length MD TVD MD TVD (include sta~)e data/ 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2844' 37' 37' 2881' 2400' 546 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 10027' 37' 37' 10064' 7121' 118 sx Class G N/A 4.5" 12.6# L-80 I BT-M 9487' 37' 37' 9524' 6965' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural EIVED Conductor REC Surface Intermediate LPirn°edrUCti°n 0 RI ¢1 L 000 Perforation depth: measured true verticalAlaska 0ii & Gas Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch Alll[J~'i~l~Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify,~at the foregoing is true and correct to the best of my knowledge Signed /~/¢_~ C~--~~~ ......... Title Drilling Team Leader Date ~//~(~'/~ ~ Commission Use Only ' / ~' Permit Number ' - 'v"~.~,_,~,,._ ~".,~,/IiAPl numberI .;~..-/ ~) I See coverletter for 50- ,/"'(~--~ .~._~ ~',~"" i Appr°va' date~-,'''' · -. Other r.e.,quirements Conditions of approval Samples required Yes ~) Mud log required Yes f""'-No'~ Hydrogen sulfide measures Yes ~L_...,./Directional survey required ~ No Required working pressure for BOPE 2M /~"M) 5M 1 OM 15M Other: 4 :~!!~/-~L. ~iaN~D ~Y by order of~"~' ~" / _...~) Approved by ~,~,.¢.-~).~J~ It ('~',hrl.~t~n_~nn Commissioner the commission Date / Form 10-401 Rev. 7-24-89 Submit in triplicate Alpine: CD1-44PH (Pilot Hole) & ~, t-44 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 Y2" hole to a point +/- 100' TVD below the base of the Alpine Sand. Set 500 ft cement plug #1 from TD to +/- 9353'. Set 353 ft cement plug #2 from +/- 9353' to +/- 9000'. RIH with drilling assembly. Dress off plug #2. Kick off at +/- 9116' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency- set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 F2, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus. . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Set BPV and secure well. Move rig off. RECEIVED APR 10 2000 A~aska Oil & Gas Cons. Commission Anchorage Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-45 will be the closest well to CD1-44 (9.9' at 200' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.8' at 261' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations.on well CD1-44 will be injected into the annulus of a permitted well. - The CD1-44 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CDI-44 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4~599 psi 7,240 psi 6,154 psi RECEIVED APR 10 2000 0il & Gas Cons. Comm~ssi~ Anchorage CD1-44 & CD1-44 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 ½" Section - 6 1/8" point- 12 ¼" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 <10 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and Dual-FIo starch will be used for viscosity and fluid loss control respectively. RECEI,/ED APR 10 000 A~aska 0ii & Gas C0~'~s. Anch0r~e Colville River Field CD1-44PH Pilot Hole - Prior to Sidetracking RKB - GL: 37' Updated 04/05/00 9.8 ppg drilling mud in hole Wellhead Cement Plug ~. 16" Conductor to 114' 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2881 ' MD / 2400' TVD cemented to surface APR 10 ~000 Alaska Oil & Gas Cons. comm~ssio~ Anchorage Top of cement plug dressed off to 9116' MD / 6707' TVD (+/- 46 deg inc.) Top Alpine Reservoir at 9689' MD / 7103' TVD Pilot Hole TD at 9853' MD / 7216' TVD (+/- 46 deg inc.) Top of Cement Plug #1 at +/- 9353' 500 ft Colville River Field CD1-44 Production Well Completion Plan 16" Conductor to 114' Updated 04/05/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD = 1868' MD Isolation Sleeve with DB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2881' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope Tubing Supended with diesel to lowest GLM Completion MD TVD Cd1-44PH - cement kick off plug at 9116' MD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1868' 1700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4329' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 6935' 5200' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 9423' 6908' 4-1/2" tubing joints (2) HES "X" (3.813" ID) 9492' 6948' 4-1/2" tubing joint (1) Baker S3 Packer 9524' 6965' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 9589' 6997' 4-1/2" 10' pup joint WEG (+/- 62 deg) 9600' 7003' Note: THERMAL centralizers installed between 2400' TVD (=2881') and 4500' TVD (=5921 ') Baker S3 Packer at +/- 9524' TOC @ +/- 9390' MD (500' MD above top Alpine) tVED Well TD at 12800' MD / APR 10 2000 7117' TVD Top Alpine at 9890' MD / 7102' TVD Alaska Oil & Gas Cons. Oommls$ion Anchorage 7" 26 ppf L-80 BTC Mod Production Casing @ 10064' MD / 7121' TVD @ 89 deg Colville River Field CD1-44 Production Well Completion Plan Formation Isolation Contingency Options Updated 04/05/00 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4"x 0.049" s/s control line @ 1700' TVD = 1868' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2881' MD / 2400' TVD cemented to surface Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch (A) Bonzai ECP Assembly Baker ZXP Packer (4.75" ID) Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) Muleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 9390' MD (500' MD above top Alpine) cr'ctVED Camco KBG-2 GLM (3.909" ID) ~ '~lf,,.~.~[~,j & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi ~,~ set 2 joints above the X landing nipple APR102000 AJaska Oil & Gas C~s. ~mmission .... Baker S3 Packer set at +/- 9524' ~or~e Well TD at 12800' MD / ~"~ ~. 7117' TVD 5 ........ ..... 7" 26 ppf L-80 BTC Mod Production Casing @ 10064' MD / 7121' TVD @ 89 deg CD1-44 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well · Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2881 / 2400 14.2 1086 1532 7" 10064 / 7121 16.0 3222 2510 N/A 12800 / 7117 16.0 3220 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: . 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG - Fracture gradient at the casing seat in lb./gal 0.052 - Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP - Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 } D = [(14.2 x 0.052) -0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) - 3222 - (0.1 x 7121') = 2510 psi Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) - 3222 - (0.1 x 7121') - 2510 psi CEIVED APR 10 2000 A~aska 0ii & Gas Cons. Anchorage Alpine CD1-44 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 T I __ ):;,m I {;SS['IRI~I UJ[ ~'EIGt IT I ~/ ~ _ I [ - i - 1 -1500 -2500 -3500 PR -4500 -5500 -6500 -7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT R~:_CEtVED APR 10 2000 Alaska Oil & Gas Cons° Commission Anchorage Alpine, CDI--~4PH & CD1-44 Well Cementing Requirements 9 5/8" Surface Casing run to 2881 MD/2400' TVD. Cement from 2881' MD to 2381' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2381' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (2381 '-1669') X 0.3132 ft3/ft X 1.5 (50% excess) = 334.5 ft3 below permafrost 1669' X 0.3132 ft3/ft X 4 (300% excess) = 2090.9 ft3 above permafrost Total volume - 334.5 + 2090.9 = 2425.4 ft3 -> 546 Sx @ 4.44 ft3/sk System: 546 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 -> 230 Sx @ 1.17 ft%k System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft%k 7" Intermediate Casing run to 10064' MD/7121' TVD Cement from 10064' MD to +/- 9390' MD (500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (10064' - 9390') X 0.1268 ft3/ft X 1.4 (40% excess) = 119.6 ft3 annular volume 80' X 0.2148 ft~/ft - 17.2 fts shoe joint volume Total volume = 119.6 + 17.2 = 136.8 ft3 => 118 Sx @ 1.16 ft3/sk System: 118 Sx Class G + 0.2% D046 antifoamer, 0.27% D065 dispersant, 0.20% D800 retarder, 0.20% D046 anti-foam and 0.25% D156 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk CD1-44PH Cement Plug #1: 9853' MD to 9353' MD = 500'. Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 500' X 0.3941 ft3/ft X 1.15 (15% excess) = 226.6 ft3 => 196 Sx @ 1.16 ft3/sk CD1-44PH Cement Plug #2: 9353' MD to 9000' MD = 353'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 353' X 0.3941 ft~/ft X 1.15 (15% excess) = 160.0 ft3 => 160 sx @ 1.00 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement R?_C, Ei,/ED APR 10 2000 AJlaska 0ii & Gas Cons. Commission An~orage ARCO Alaska, Inc. Structure: CD#1 Field : Alpine Field Well : 44PH1 Location : North Slope, Alaska 400 400 BOO 1200 1600 2000 2400 2800 3200 5600 4000 I--' 4400 I 4800 5200 56OO 60O0 6400 6800 7200 7600 400 ESTIMATED RKB: 56' KOP 3.00 6.00 DLS: 5.00 deg per 100 fl: .?0~ .Beg~n Trn to Tgt; 1 14.88 17.85 DLS: ;3.00 deg per 100 ft 20.82 25.80 West Sok 26.78 29.77 52.75 .35.74 ~.gFof~ost EOC Creeled b~ ~michoe~ For: B Roberteon Dote plotted: 5-Apr-2000 Plot ~ference ~lno~ Tree Ve~cal ~1 om ~fe~n~ ~mo~ RKB, C40 9 5/8 Csg Pt. C$0 C20 253.16 AZIMUTH 6350' (TO TD) ***Plane of Proposal*** AVERAGE ANGLE 46.31 K5 K2 APR 10 2000 Alaska Oil & Gas C(~3s. Commission Anchorage Albian-97 Albion-96 i i i i I I [ 400 800 1200 1600 DLS: 9.00 deg per 100 ft i i i i i i ii i ii ! [ [ i i i 2000 2400 2800 5200 3600 4000 4400 4800 5200 Vertical Secfion (feel) -> Azimuth 25.3.16 with reference 0.00 S, 0.00 E from slot #44 HRZ Miluv{ Alpine AiDJ Base Al Ta 5600 6000 6400 Creeled by bmichoel ];o:r: B. Robertson Dote plotted: ,~l-ldor-2000 Plot Reference is 44 Vers;on C~rd~netes ere ~n fe~ r~erence ale[ ~. True Verticol Depths ore r~erence E~[moted RKB. ARCO Alaska, Inc. Structure : CD#1 Well: 44 Field : Alpine Field Locoflon: North Slope, Alaska R=eEiVED APR Alaska Oil & Gas Con~. Commission Anc~or~e 331.98 AZIMUTH (TO ***Plone of Proposol*** 6460 6650 ssoo · -- 6970 I V 7140 7510 7480 TARGET ANGLE 89.14 DEG ~ ,~.o' ~'Os I I I I I t I I I I I I I I I I I I I I I I I I I I I I II I I I I I I I I I I I I I I I I 340 510 680 850 1020 11 go 1560 15.T~ 1700 1870 2040 2210 2580 2550 2720 2890 5060 3250 3400 3570 3740 3910 4080 4250 VerticalSection (feet)-> Azimuth 351.92 with reference 0.00 N, 0.00 E from slot #44 Creoted by bmf¢iqoel For: B, Robertson Dote ptotted: 51-Mot-2000 Plot Reference is 44 PHI Ve~ion ~5. Coordlnotes ore in feet reference slot ~44. True Verticot Depths ere reference £~imeted RKB 1600 1200 800 400 400 800 1200 1600 2000 2400 28O0 3200 INT~O ARCO Alaska, Inc. Sfructure: CD#I Well : 44PH1 Field : Alpine Field Loooflon: North Slope, Alosko <- West (feet) 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 5600 5200 2800 2400 2000 1600 1200 800 400 0 400 I I I [ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I C01-44 TD LOCATION: 42' FSL, 212' FEL SEC. 56, T12N, R4E ESTIMATED SURFACE LOCATION 531' FNL, 2272' FWL SEC. 5, T11N, R5E CD1-44 INTERM PT LOC: 1489' FNL, 606' FWL SEC. 6, T11No RSE End Bid/Tm - In[ermdPt/Beg Bid/Tm CD1-44 TGT/CSG PT LOCATION: 2372° FNL, 1077' FWL SEC. 6, T11N, RSE E~ose Alpine Begi~/eT~[~ Permofrost ~60 A~ 3 Csg Pt. Revised TD-Csg Pt M;luveoch Tgt -EOC - CsgPt )ins ~RZ ~ion-96 r: =iVED APR 10 2000 ~aska Oil & Gas Co~s. An~0rage CD1-44 PH1 TD LOCATION: 2349' FSL, 1252' F'WL SEC. 6, T11N, RSE i i i i i i i i i i ! i t i i i i i i i ii i II i i i i I i i i i I I I i i i 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 5600 5200 2800 2400 2000 1600 1200 800 400 0 400 <- West (feet) 1600 1200 800 400 400 0 800 ,..-I- 1200 ~' I ¥ 3200 28O0 2400 2000 1600 Created by bm~choel For: B. Robert. son Dote plotted: ,51-Mor-2000 Plot Reference ~ 44 PHI Version Coordinates ere in fe~ r~erence slot ~. true Vertical Depths ere r~erence E~imoted RKB. ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Well : 44PH1 Looafion : Norfh Slope, Alaska Point KOP Begin Trn to Tgt West Sak Permafrost EOC C40 C30 9 5/8 Csg Pt.~ C20 K3 K2 Albion -97 Albion-96 iHRZ K1 LCU Miluveach A Alpine D Alpine Base Alpine Target PROFILE MD 500.00 655.35 1066.09 1668.50 1852.94 2564.25 2875.49 2881.28 3403.86 4928.20 5249.57 7701.82 8369.17 9042.51 9356.44 9495.96 9624.25 9656.09 9689.39 9757.1 6 9852.97 COMMEN T DATA Inc Dir TVD North East V. Sect 0.00 260.00 300.00 0.00 0.00 0.00 10.00 260.00 651.64 -5.04 -28.57 28.81 22.79 251.52 1046.00 -58.54 -145.46 150.59 40.79 248.15 1556,00 -150.05 -441.05 465.61 46.51 247.62 1689.65 -197.89 -558.71 592.08 46.31 247.62 2181.00 -593.70 - 1054.29 1103.99 46.51 247.62 2396.00 -479.57 -1242.59 1327.98 46.51 247.62 2400.00 -480.97 -1246.26 1552.15 46.31 247.62 2761.00 -624.85 -1595.66 1708.25 46.51 247.62 3814.00 -1044.44 -2614.83 2805.27 46.31 247.62 4056.00 -1152.91 -2829.70 5056.56 46.31 247.62 5750.00 -1807.96 -4469.27 4801.58 46.31 247.62 6191.00 -1991.66 -4915.46 5281.66 46.31 247.62 6656.00 -2176.96 -5565.52 5766.10 46.51 247.62 6875.00 -2263.44 -5575.55 5992.17 46.31 247.62 6968.00 -2501.29 -5667.50 6091.15 46.51 247.62 7058.00 -2557.16 -5754.61 6184.91 46.51 247.62 7080.00 -2545.95 -5775.90 6207.83 46.31 247.62 7105.00 -2355.09 -5798.1 6 6251.79 46.51 247.62 7136.00 -2568.24 -5850.10 6266.17 46.51 247.62 721 6.00 -2400.12 -5907.55 6549.52 Deg/1 O0 0.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Created by bmlchoel For: B. Rober[son Date plotted: 51-Mar-2000 Plot Reference ~s 44 Version ~§. Coordinates ore ~n feet reference slot '[rue Vertical Depths are reference £st[moted RKB. [NTKQ ARCO Alaska, Inc. Structure : CD#1 Well : 44 Field : Alpine Field Locaflon; Norfh Slope, Ah~$ko RECEIVED APR 10 2000 Point KOP - Beg BId/Trn K1 LCU Miluveach A Alpine D Alpine Tgt- EOC - CsgPt Bose Alpine Tgt-lntrm Pt/Beg BldW End BId/Trn PROFILE MD Inc 9115.92 46.51 9565.65 51.50 9530.58 58.57 9727.54 68.77 9795.89 72.65 9889.69 78.37 10063.99 89.14 10596.65 89.14 11064.21 89.14 111 65.63 90.66 Alaska Oil & Gas Cons. Cornmission COMM ENT Dir TVD North East 247.62 6706.89 -2197.27 -5414.69 276.81 6875.00 -2220.56 -5597.56 292.90 6968.00 -2185.23 -5726.90 308.98 7056,00 -2094.12 -5876.70 513.84 7078.00 -2052.58 -5925.76 320.48 7102.00 - 1984.60 -5986.71 551.98 7121.00 -1840.92 -6082.56 551.98 7126.00 -1547.50 -6258.80 551.98 7156.00 -958.04 -6552.59 331.92 7136.17 -868.54 -6600.08 V. Sect Deg/lO0 610.08 0.00 675.79 9.00 767.67 9.00 918.56 9.00 977.56 9.00 1066.97 9.00 1258.86 9.00 1571.46 0.00 2258.96 0.00 2340.38 1.50 Revised TD-Csg Pt 12800.00 90.66 ,331.92 7117.35 573.33 -7369.38 3974.64 0.00 ARCO Alaska, Inc. CD#1 44PH1 slot #44 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 44 PH1 Version #5 Our ref : prop3918 License : Date printed : 3-Apr-2000 Date created : 16-Mar-2000 Last revised : 31-Mar-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 31.887,w150 55 39.614 Slot Grid coordinates are N 5975600.944, E 385695.944 Slot local coordinates are 529.73 S 2273.87 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD#1 PMSS <0-7331'>,,1PHi,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <0-8350'>,,26PH1,CD#l PMSS <7755-11134'>,,26,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <0-10897'>,,3,CD#1 PGMS <0-10255'>,,WD2,CD#1 41 Vers.#9,,41,CD#1 PMSS <475 - 8166'>,,41PHi,CD#1 PMSS <7182 - ???'>,,41,CD#1 CD1-43 Version #7,,43,CD#1 19A Version#3,,19A,CD#1 PMSS <0-10548'>,,19,CD#1 CD1-34 Version #7,,34,CD#1 Closest approach with 3-D Last revised Distance 28-Jun-1999 29-Feb-2000 27-Jun-1999 15-Mar-2000 4-Jan-2000 22-Sep-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 28-Jun-1999 13-Feb-2000 14-Feb-2000 26-Aug-1999 4-Jan-2000 22-Dec-1999 4-Jan-2000 28-Jun-1999 4-Jan-2000 23-Dec-1999 16-Mar-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 18-Aug-1999 4-Jan-2000 25-Oct-1999 15-Ju1-1999 23-Jan-2000 23-Jan-2000 4-Jan-2000 28-Jun-1999 26-Mar-2000 26-Mar-2000 30-Mar-2000 23-Mar-2000 28-Jan-2000 28-Jun-1999 15-Mar-2000 219.4 429.7 429.7 190.1 49.7 49.7 17.4 9.9 9.9 37 0 59 5 59 5 69 8 73 4 73 4 73 4 86.7 120.0 120.0 167.5 178.9 178.9 199.8 209.9 280.1 280.1 309.9 389.0 389.0 409.9 1361.6 1829.0 29.0 29.0 9.1 1999.2 249.4 100.1 Minimum Distance method M.D. Diverging from M.D. 300.0 200.0 200.0 100.0 311.1 311.1 411.1 200.0 200.0 388.9 333.3 333.3 311.1 566.7 566.7 566.7 411.1 100.0 100.0 400.0 322.2 322.2 311.1 100 0 100 0 100 0 100 0 300 0 300 0 300 0 322.2 6740.0 333.3 333.3 333.3 1533.3 311.1 200.0 300.0 200.0 200.0 100.0 311.1 311.1 1744.4 200.0 200.0 388.9 333.3 333.3 311.1 566.7 566.7 566.7 411.1 100.0 100.0 400.0 322.2 322.2 311.1 100 0 100 0 100 0 100 0 300 0 300 0 300 0 322.2 6740.0 333.3 333.3 9100.0 1533.3 311.1 200.0 RECEIV ED APR 10 Alaska Oil & Gas Co~s. Commissi~ Anchorage ARCO Alaska, Inc. CD#1 44 slot #44 Alpine Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 44 Version #5 Our ref : prop3544 License : Date printed : 3-Apr-2000 Date created : il-Aug-1999 Last revised : 3-Apr-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 31.887,w150 55 39.614 Slot Grid coordinates are N 5975600.944, E 385695.944 Slot local coordinates are 529.73 S 2273.87 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9236'>,,22,CD#1 PMSS <0-7331'>,,tPH1,CD#1 PMSS <5946 - 10289'>,,1,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <0-10224'>,,39PHi,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-8844'>,,45PHi,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-12055'>,,40,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <562 - 12134'>,,37,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PHi,CD#1 PMSS <0-8168'>,,35,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <10016 - 11136'>,,32,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <0-8350'>,,26PHi,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-10796'>,,24,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <0-9357'>,,16PHi,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <9499 - 14515'>,,5,CD#1 PMSS <0-10504'>,,5PHi,CD#1 PMSS <0-10897'>,,3,CD#1 PGMS <0-10255'>,,WD2,CD#l 41 Vers.#9,,41,CD#1 PMSS <475 - 8166'>,,41PHi,CD#1 PMSS <7182 - ???'>,,41,CD#1 CD1-43 Version #7,,43,CD#1 CD1-34 Version #7,,34,CD#1 19A Version#3,,19A,CD#1 PMSS <0-10548'>,,19,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-Jun-1999 29-Feb-2000 27-Jun-1999 15-Mar-2000 4-Jan-2000 22-Sep-1999 23-Dec-1999 4-Jan-2000 16-Nov-1999 28-Jun-1999 13-Feb-2000 14-Feb-2000 26-Aug-1999 4-Jan-2000 22-Dec-1999 4-Jan-2000 28-Jun-1999 4-Jan-2000 23-Dec-1999 16-Mar-2000 6-Mar-2000 1-Nov-1999 28-Jun-1999 18-Aug-1999 4-Jan-2000 25-Oct-1999 15-Ju1-1999 23-Jan-2000 23-Jan-2000 4-Jan-2000 28-Jun-1999 26-Mar-2000 26-Mar-2000 30-Mar-2000 23-Mar-2000 15-Mar-2000 28-Jan-2000 28-Jun-1999 219.4 429.7 429.7 190.1 49.7 49.7 17.4 9.9 9 9 37 0 59 5 59 5 69 8 73 4 73 4 73 4 86 7 120 0 120 0 167.5 178.9 178.9 199.8 209.9 280.1 280.1 309.9 389.0 389.0 409.8 1361.6 1828.9 29.0 29.0 9.2 100.1 1999.2 249.4 300.0 200.0 200.0 100.0 309.8 309.8 412.8 200.0 200.0 387.1 329.5 329.5 309.8 566.7 566 7 566 7 406 4 100 0 100 0 400 0 329 5 329 5 309 8 100 0 100 0 100 0 100 0 300 0 300.0 261.1 319.6 6740.0 329.5 329.5 329.5 261.1 1533.3 309.8 300.0 200.0 12800.0 12200.0 309.8 309.8 12600.0 200.0 200.0 387.1 329.5 329.5 309.8 566.7 12800 0 566 7 10700 0 12800 0 12800 0 400 0 329 5 329 5 309 8 100 0 100 0 100 0 100 0 300 0 300.0 261.1 319.6 11126.3 329.5 12100.0 9100.0 261.1 1533.3 12440.0 RECEIVED APR 10 2000 Alaska Oil & Gas Cons. Commission Anchorage 3[~/5/8~ AJR MRT Per AO¢~'~IACS 3/12/~IAJR MR"I, Per AOOO01ACS ~X\~~~ ~ ~ ~THISSURVE~ VICINITY MAP NOT TO SCALE 70 6 ~ 13 ~O12 17 · 16 19~ ~ 21 ~ / 23.'22 25 · e24 ~' 29~28 310~3e N / ~o'~ +,¢ RECEIVED ~// APR 10 2000 37~36 39 ee 3s G~/ ~a~a al & Gas C~s. ~mmissio ~ · e4e ~0r~e · 3e%2 ~ LEGEND · 5ee44 · EXISTING CONDUCTORS ~ / o PLAN CONDUCTOR LOCATION ARCO Alaska, Inc. ~[ A~INE PROJECT ~ CD1 WELL CONDUCTORS Subsidiory of Atlentic Richfield Compony AS-BUILT LOCAUONS LK665D1 3/5/90 CE-CD10-663DI ~ OF 3 3 Per AO~-'~IACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC 5, T 11 Well 'Y' 'X' Let, (N) 70' 20' `34,922" CD1-! CD1-2 CD1-3 CD1-4 CD1-5 CD1-6 CD1-7 CD1-8 CD1-9 CD1-10 CD1-11 CD1-12 CD1-13 CD1-14 CD1-15 CD1-16 CD1-17 CD1-18 CD1-19 CD1-20 CD1-21 ,CD1-22 CD1-23 CD1-24 CD1-25 CD1-26 CD1-27 CD1-28 CD1-29 CD1-30 CD1-31 CD1-32 CD1-53 CD1-54 CD1-35 CD1-36 CD1-37 CD1-'`38 CD1-59 CD1-40 CD1-41 CD1-42 CD1-4.3 CD1-44 CD1-45 5,975,904,92 5,975,897,89 5,975,890,99 5,975,88`3,8.3 5, g75,876.67 5,975,869,89 5,975,848,42 5,975,841.54 5,975,820,00 5,975,812,97 5,975,798,86 5,975,791.81 5,975,784,91 5,975,777,92 5,975,770,66 5,975,763,76 5,975,756,46 5,975,749,31 5,975,742,40 5,975,735, `34 5,975,728,10 5,975,721.21 5,975,714,15 5,975,707,14 5,975,700,17 5,975,685.92 5,975,671,88 5,975,664,72 5,975,657,49 5,975,650.51 5,975,645,79 5,975,636,34 5,975,629.19 5,975,622,37 5,975,615,01 5,975,607,63 5,975,600.75 5,975,593,74 385,999,99 385,992,91 385,985,82 385,978,79 385,971.58 385,964,83 385,943,41 385,936.18 385,915,06 385,908.00 385,894,08 385,886.84 385,879,88 385,872.81 385,865.67 385,858,49 385,851,10 385,844.44 385,837.30 385,830,26 385,823,14 385,816.08 385,809,10 385,802,20 385,794,75 385,780.68 385,766.54 385,759,65 385,752,52 385,745.44~ 385,738.44 385,731,37 385,724, 52 385,717,40 385,710,21 385,702,97 385,696.00 385,689,04 150' 55' 30,868" 70' 20' 34,852" 150' 55' `31,071" 70' 20' 34,783" 150' 55' 31,275" 70' 20' 34,711" 150' 55' 31,478" 70' 20' 34.640" 150' 55' 31.685" 70' 20' 54,572" 150' 55' 31,879" 70' 20' 34,358" 150' 55' 32,495" 70' 20' 34.287" 150' 55' 32.703" 70' 20' 34,074" 150' 55' 33,311" 70' 20' 34,004" 150' 55' 33,514" 70' 20' 33,865" 150' 55' 53,914" 70' 20' 33.795" 150' 55' 34.123" 70' 20' 33,724" 150' 55' 34,323" 70' 20' 33,654" 150' 55' 34,526" 70' 20' 33,581" 150' 55' 34,732" 70' 20' 33,512" 150' 55' 34,938" 70' 20' 35,440" 150' 55' 34,151" 70' 20' `35,368" 150' 55' 35.342" 70' 20' 33.299" 150' 55' 35.548" 70' 20' 33.229" 150' 55' 35,750" 70' 20' 33,156" 150' 55' 35,955" 70' 20' 33.088" 150' 55' 36.158" 70' 20' 33,017" 150' 55' 36,359" 70' 20' 52,947" 150' 55' 36,558" 70' 20' 32,877" 150' 55' 36,772" 70' 20' 52.735" 150' 55' 37.177" 70' 20' 52,595" 150' 55' 57,584" 70' 20' 32,524" 150' 55' 37,782" 70' 20' 52,451" 150' 55' 57,987" 70' 20' 32.381" 150' 55' 38.191" 70' 20' 32,315" 150' 55' 38,391" 70' 20' `32,240" 150' 55' 38,595" 70' 20' 32,168" 150' 55' 38,797" 70' 20' 52,101" 150' 55' 38,997" 70' 20' 52,027" 150' 55' 59,204" 70' 20' 31,954" 150' 55' 39,412" 70' 20' 31.885" 150' 55' 39.613" 70' 20' 51.815" 150' 55' 39,813" , CDI-22 CONDUCTORREcEivWAS AS-BUbO/l l/g8 APR 10 ~-000 A~0~e ARCO Alaska, nc. Subsidiary of Atlantic Richfield Compony CADD FILE NO, DRAWING NO: LK663D1 Per A00(~01 ACS N, R 5 E, UMiAT MER[DIAN Sec Line O/S FNL FWL (;nd Pad LOUNSBURY ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCA'rlONS SHEET: CE-CD10-665D1 2 OF 3 REV; 3 Per AOr ....31ACS Per AOOOO1ACS NOTES 1, ALL COORDINATES ARE ALASKA STATE PLANE, ZONE 4, NAD 27, 2, ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL, ORiGiNAL GROUND ELEVATIONS ARE iNTERPOLATED FROM MICHAEL BAKER JR, DWG, CE-CD10-102, SHT 1, REV, 0, :3, BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS :3 & 4 BY LOUNSBURY & ASSOCIATES, 4, DATE OF SURVEY: WELL CONDUCTORS 10, 1:3, 14, & 16-19 WERE AS-BUiLT :3/10/99, REF,FIELD BOOK L99-20, PAGES :3-11, CONDUCTORS 1-3 WERE AS-BUiLT 3/25/99, REF: FIELD BOOK L99-24, PG, 28-:31, CONDUCTORS 4-6, 9, 20, 21, 23-:30, & :35 WERE AS-BUiLT :3/29/99, REF: FIELD BOOK L99-2:3, PG, 65, 67-7:3, CONDUCTORS 36-4:3, & 45 WERE AS-BUILT 4/6, 4/9/99, REF: FIELD BOOK L99-26, PG, :35-:38, & 48, WELL CONDUCTOR 54 AS-BUiLT :3/11/00, REF: FIELD BOOK L00-09, PAGES 2 & 4, WELL CONDUCTOR 44 AS-BUiLT :3/20/00, REF: FIELD BOOK L00-09, PAGE 5:3, RECEIVED APR 7 0 000 A/asia Oil A Gas Cons. Comm~ion Anchorage .- 49th ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Compony SURVEYOR'S CER TfFf CA TE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 5/20/00, LK663D1 3/5/99 LOUNSBURY ASSOCIATES, INC, E%INEERS PLANNERS SURVEYORS ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCA'I'[ONS CE-CD10-663D1 I SHEET"3 OF 3 REV: 3 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 7, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill 0D1-44 (& 0D1-44 PH) Dear Sirs: RECEIVED APR 10 2000 Aia~a Oil & Gas Cons, Commission A~ch0ra~e ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is May 01, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-44 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 46©. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as an open hole producer. At the end of the work program, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. Proposed cementing program and calculations. 10. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 11. Updated conductor 'as built' drawing showing the surface position of CD1-44. Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, h . ! Brian Roberfson Senior Drilling Engineer ARCO Alaska I,,~c is a Subsidiary of AttanticRichfieidCompany Attachments CC: CD1-44 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin G racie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com RECEIVED APR 10 2000 A~aska 0il & Gas Cons. Commission Anchorage CO.Alaska, Inc. PAYABLES Bo'X': '~102776 ,orage. AK:.:9951'O¥2'77 CHECK NUMBER 205093841 MARCH 13, 2O00 73~426 839 0997579 st :National Bank of 'Chicago-0710 Chicago, Illinois Payable Through Republic Bank ShelbyYille, Kentucky STATE :OF ALASKA ALASKA 'OIL. &. :GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE TRACE NUMBER: 20509384 ! *** VOID AFTER 90 DAYS *** EXACTLY ********.***:lO0 DOLLARS AND O0 CENTS $*********.**100.00 "' aO-q.o"q:IBh :.,' '-~'Ofi ~t~Oh-a~F-,:a.f:':: oqq?E;?q,' WELL PERMIT CHECKLIST FIELD & POOL COMPANY ,,~-/',,., ~. _,~. ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11 _,_._R .O~,TIE 12. INIT CLASS ENGINEERING APPR DATE ..y WELL NAME~/)/--e-/'~/ PROGRAM: exp ~ GEOLOGY Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~ ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N /, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory ,o~y] Y N dev .~ redrll serv~ wellbore seg ann. disposal para req __ _AREA Y N UNIT# ON/OFF SHORE ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (~ N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... (:~ N l~lxo~_l' !/O¢,.5-r~ ~, "¢~k~ ~ }~OTo /5,~o"rH-~ to surface; v~ ~JJ<:)lT_.~oo (C) will not impair mechanical integrity of the well used for disposal; (~ N ' (D) will not damage producing formation or impair recovery from a ~ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ~'~ N ~: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: co .. o Z o Z -i c:\msoffice\wordian\diana\checklist (rev. 02/17/00)
