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197-181
WELL LOG TRANSMITTAL 9905276265 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Packer Setting Record: 1D-121 FEB 0 5 2019 Run Date: 11/13/2018 AOG CC 137181 r January 9, 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 FRS—ANC@halliburton.com 1D-121 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22814-00 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: 0 2zl Gq Signed: V� ®F T� • • 1I//7; THE STATE Alaska Oil and Gas 0, of LAsKA Conseati®n Coissi®n } 333 West Seventh Avenue 4141.-1101-*: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCANNED SEP 1120117 Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-121 Permit to Drill Number: 197-181 Sundry Number: 317-417 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0911.444,s_ Cathy . Foerster Commissioner DATED this r0 day of September, 2017. RBDMS ct" pf. - 7 2017 • • 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Ugh 2 1J' APPLICATION FOR SUNDRY APPROVALS J 7 20 AAC 25.280 1.Type of Request Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well IV Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Sand Aid TrtmtU' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development [] , 197-181 ' 3.Address: Stratigraphic 0 Service ❑ 6.API Number. P. 0. Box 100360,Anchorage,Alaska 99510 50-029-22814-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' KRU 1D-121 ' Will planned perforations require a spacing exception? Yes ❑ No U / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 ' Kuparuk River Field/West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,414' - 4,315' - 3922 • ., 3824 1357 3880 NONE Casing Length Size MD - TVD Burst Collapse Conductor 81' 16" 121' 121' Surface 4,362' 8" 4,402' 4,303' Liner 3,538' 5 1/2 x 2 7/8 3,579' 3,481' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3750-3780,3810-3840,3902- 3652-3682,3712-3742,3804- 2.875" L-80 3,967' 3932,3980-4010 ' 3834,3882-3912 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=BAKER FHL Retrievable Packer • 3712 MD and 3614 TVD PACKER=BAKER Premier Production Packer 1 3885 MD and 3786 TVD PACKER=BAKER Premier Production Packer , 3941 MD and 3842 TVD • SSSV=NONE N/A 12.Attachments: Proposal Summary U Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development U' Service ❑ 14.Estimated Date for 9/11/2017 15.Well Status after proposed work: Commencing Operations: OIL 2• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells E .•.--r Contact Email: Jason.Burke@cop.com Contact Phone: (907)265-6097 Authorized Signaturq' _._...Date: .-.;;-; _.�- COMMI SION USE NLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311- `F VI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No tr. • Spacing Exception Required? Yes ❑ No V Subsequent Form Required: `G—.f- 7 f n q RBDMS Lt, ° - 7 ZU1I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date-6 _ /7 Inn' l' ORIGINAL �` q%�n 46Ia/� Submit Form and 4( Fo 10/4 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Proposed 1D-121 SandAid Treatment 1D-121 is a West Sak D & B producer that has been shut in due to excess sand production. The purpose of the SandAid treatment is to attempt to control the sand production so the well can be brought back on -line to production. Procedure 1. Pump treatment as outlined in the table below: Base Base Cum. Step# Step Fluid Vol. SandAid Slurry Vol. Vol (bbl) (gal) (bbl) (bbl) 1 Initial Displacement 2%KCI 38.7 38.7 38.7 2 Step Rate Test 2%KCI 50.0 50.0 88.7 3 Preflush 2%KCI 29.8 29.8 118.5 4 Main treatment-7% K250 2%KCI 55.4 175.2 59.6 178.1 5 Preflush 2%KCI 29.8 29.8 207.8 6 Main treatment-7% K250 2%KCI 55.4 175.2 59.6 267.4 7 Preflush 2%KCI 29.8 29.8 297.2 8 Main treatment-7% K250 2%KCI 55.4 175.2 59.6 356.8 9 Overflush 2% KCI 134.1 134.1 490.9 10 Displacement 2%KCI 38.7 38.7 529.6 Note:All fluids Except Final Displacement must contain KleenRinse K252 at 3 gpt. The main treatment stages contain SandAid Dispersant at 3 gpt. 2. Displace treatment down the work-string at recommended rate below estimated fracture rate and fracture pressure. 3. Stop pumps, let pressure bleed off into the formation and monitor tubing pressure. 4. Monitor well for 15 minutes. 5. Secure well. 6. Rig down pumping equipment. 7. Leave well shut in for minimum 6 hours. Make sure that the reservoir fluids near the well bore remain un-disturbed. 8. Bring well back on-line in a controlled manner. • i KUPD 1D-121 ConocoPhillips $ Well Attribu Max Angl D TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) c..phiiii, 500292281400 WEST SAK PROD 26.17 2,427.85 4,414.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 12-121,a/30/20178.44:43 AM SSSV:NONE 5 11/10/2014 Last WO: 5/3/2016 12/6/1997 Ventral achemaac:(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 3,826.0 4/17/2017 Rev Reason:CORRECTED IBP TOP pproven 5/23/2017 �( I f.. MEASUREMENT(SAND GONE) ■t 4 asing rings • ���. Casing Description OD(in) ID(in) Top(BOB) Set Depth BOB)( Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER,41.5 EE I. CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED X0 Reducing a4.8 ° I* Casing Description OD(in) ID(in) Top(ftKB) Set Depth BOB)( Set Depth(ND)... WVLen(I...Grade Top Thread SURFACE 7518 6.750 40.2 4,402.0 4,303.4 29.70 L-80 BTCM Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection LINER 5-1/2"RWO 5 1/2 4.950 41.5 3,740.0 3,641.9 15.50 L-80 Hyd 563 '''''ti CONDUCTOR;40.0-121.0 2016 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 41.5 41.5 0.00 Casing 5 1/2"15.S1t L-80 Hydril 563 Casing Cut off Jt recovered 4.950 Intermediate 8.33-ft stub GAS LIFT;2,523.7 a 73.0 73.0 0.00 Casing 5 1/2"15.58 L-80 Hydril 563 Casing 4.950 1,1 3,570.8 3,472.9 3.58 Casing 5 1/2"15.5it L-80 Hydril 563 Casing Pup 4.950 Intermediate GAS LIFT;3,493.2tr 3,577.1 3,479.2 3.49 XO Reducing Crossover sub 5-1/2"Hyd-563 boxx 4.094"National box 3.310 II3,579.1 3,481.2 3.47 SBE Baker 80-32 SBE(4.094"National pin x pin) 3.250 3,588.5 3,490.6 3.37 XO Reducing Crossover sub 4.094"National box x 2-7/8"EUE pin 2.400 STABILIZER;3,536.2 3,599.6 3,501.7 3.25 NIPPLE HES 2.313"X-Nipple 2.312 SLEEVE;3,537.3 1)111 3,694.3 3,596.2 2.49 XO Enlarging Crossover sub 2-7/8"EUE boxx 3-1/2"EUE pin 2.440 STABILIZER;3,541.0. r' 3,695.9 3,597.8 2.49•LOCATOR Baker Locator Spaced out 3'off Fully Located total length 3.000 IN of seals 11.77' GAUGE;3,662.6 3,696.8 3,598.7 2.49 SEAL ASSY Baker Seal Assy 2.920 11 3,699.2 3,601.1 2.48 PBR Baker 80-40 PBR SHEARED 4.000 LOCATOR;3,572.9 ME 3,711.9 3,613.8 2.46 PACKER Baker 3-1/2"x 7-5/8"FHL Retrievable Packer 40k shear 2.430 release i 00 Reducing;3,577.1_ II 3,719.3 3,621.2 2.45 XO Reducing Crossover sub 3-1/2"EUE box 2-7/8"EUE pin 2.420 SEAL ASSY;3,574.0 - 3,731.0 3,632.8 2.43 NIPPLE Camco 2 7/8"2.25"D Nipple 2.250 SBE;3579.11. 3 3,738.7 3,640.6 2.42 WEG WLEG Muleshoe 2.441 XO Reducing.3,588.5 V Tubing Description String Ma...ID(in) Top(ROB) Set Depth(ft...Set Depth(ND)(...Wt(Ib//t) Grade Top Connection 5 TUBING RWO 2016 27/8 2.441 41.5 3,584.8 3486.9 6.50 L-80 EUE NIPPLE:3,599.6 Completion Details • Nominal ID I. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 41.5 41.5 0.00 HANGER FMC TC-1A-EMS w/3-1/2"EUE-8rd Pup Joint 2.900 GAS LIFT,3,844.0 44.8 44.8 0.00 XO Reducing 3-1/2"8rd x 2-7/8"8rd X-0 2.992 3,536.3 3,438.4 5.02 STABILIZER Fluted Wire Protector Sub 2.441 111. 3,537.3 3,439.5 4.97 SLEEVE 2-7/8"CMU Sliding Sleeve(w/2.313"BX-nipple Profile) 2.312 3,541.4 3,443.6 4.80 STABILIZER Fluted Wire Protector Sub 2.441 X0 Enlarging,3,694.3 l 3,552.9 3,455.0 4.32 GAUGE SLB Special Clearance Gauge Mandrel(EUE-8rd pin x 2.388 LOCATOR,3,6959 ME pin)S/N 5939 SEAL ASSY;3,696.0 _ 3,573.0 3,475.0 3.53 LOCATOR GBH-22 Locator Sub 2.441 PBR;3898.2 W PACKER;3,711.9 .fes 3,574.0 3,476.1 3.52 SEAL ASSY Baker 80-32 Seal Assembly 2.441 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection XO Reducing;3,719.3 - A3-SAND 41/2 3.958 3,853.8 3,968.0 3,869.7 12.60 L-80 IBT STRADDLE PATCH Completion Details NIPPLE;3,731.0E-3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not 0) Item Des Com WEG;3,739.7 fl 3,853.8 3,755.6 2.22 SLEEVE "HR"LINER SETTING SLEEVE 5.250 3,866.8 3,768.5 2.21 NIPPLE "RS"PACK OFF SEAL NIPPLE 4.250 (PERF,3,750.0-3,790.0-. 3,884.6 3,786.4 2.20 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 3,940.6 3,842.3 2.15(PACKER BAKER PREMIER PRODUCTION PACKER I 3.875 3,967.3 3,869.0 2131 WLEG WIRELINE ENTRY GUIDE ll 4.000 (PERF;3,910.8-3,940.0- ... Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) BOB)( (°) Des Com I Run Date ID(in) SLEEVE;3,963.9 3.8800 3,7818 220 PLUG-IBE IBP OAL=11.04' 5/10/2016 0.000 NIPPLE;3,868.9 Alw:.. Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PLUG-IB3.884.8 'i9.8 'i 3,880.0 PACKER, 3,750.0 3,780.0 3,651.9 3,681.8 WS D,1D- 1/31/1998 4.0 IPERF 2 1/8"EJ BH;0 deg. :: .. 121 phasing -' • 3,810.0 3,840.0 3,711.8 3,741.8 WS B,10- 1/29/1998 4.0 IPERF 2 1/8"EJ BH;0 deg. 121 phasing PATCH;3,902.0-3,932.0 3,902.0 3,932.0 3,803.7 3,833.7 WS A3,10- 2/17/1998 0.0 PATCH PATCHED OVER 121 w/WORKOVER 10/7/2008 3,980.0 4,010.0 3,881.7 3,911.7 WS A2,10- 1/21/1998 4.0 IPERF 2 1/8"EJ BH 121 PACKER;3,940.6 Mandrel Inserts St ati WLEG;3.967.2 5 N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3 3,644.0 3,546.0 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/30/2016 this in (PERF;3,980.0-4,010.0 the 5 1/2 f liner 1 2,523.7 2,484.4 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 1,469.0 5/10/2016 2 3,483.2 3,385.6 Camco KBMG 1 GAS LIFT OV BKO-3 0.313 0.0 5/10/2016 SURFACE,40.2-4,402.0 KUP00 D 0 1 D-1 21 ConacoPlhillips z= Alaska.Int:. ' CorrocoPtliilips '. ••• 1D-121,8/30/20178;44;43 AM Ver I...:ARnnbc(actual) ate,,, Notes:General&Safety HANGER 41 5 11•'+` End Date Annotation <:. 12/6/1997 NOTE:MONOBORE PRODUCER 00 Reducing;44.8 i IF 12/6/2006 NOTE:WORKOVER#1 10/7/2008 NOTE:WORKOVER#2 II 3/2/2009 NOTE:View Schematic w/Alaska Schematic9.0 -A-'"� ti 11/24/2009 NOTE:3 WELDED SPOTS ON PUMP HOUSING FROM 2.90"TO 2.83" CONDUCTOR,40.0-121.0 7/6/2011 NOTE:WO#3 TBG RKB GREATER THAN SURF CSG RKB DUE TO DIFFERENT RIGS 1/22/2014 NOTE:WORKOVER-2014 5/13/2016 NOTE: GLVs in two strings causes station numbering in mandrel section to be out of order. W. GAS LIFT,2,523.7 at RI GAS LIFT;3,483.2 ili 11 STABILIZER;3,536.2 '':"p®?"' SLEEVE;3,5373 i.! STABILIZER;3,541.4 -1,....- GAUGE,3,5529 LOCATOR 3,572.9 MIR 0 X0 Reducing;3,577.1— 4 SEAL ASSY;3,574.0 m SBE;3,579.1 of 2 00 Reducing,3,5885 lir NIPPLE,3,599.6 it IL GAS LIFT;3,644.0 + Si 00 Enlarging;3,694.3 -+ LOCATOR;3,695.9 MID SEAL ASSY;3,696.8 PER;3,6982 PACKER;3,711 9 ri X0 Reducing;3,7193 NIPPLE;3,731.0 1111 WEG;3,738.7 a` IPERF,3,750.0-3,780 0—. (PERF;3,810.0-3,840 0--. SLEEVE,3,853.8 NIPPLE,3.866.8 i PLUG-IBP,3,880.0-s PACKER,3,884.6 PATCH;3,902.0-3,932.0 PACKER,3,940.6 7 W LEG;3,967.2 —.4(PERF;3,980.0-4,010.0— SURFACE;40.2-4,402.0 • T.- 1 -7- -4.. CUL / ry I-- ).- 6 T M X r or¢ a• > s "' 3 co o N w ti4 ''' T co O ro �.• 4O ,� CU ori U d a C C C O co CO C 'O W +-, C "6 a - 7 t- co a It 3 +-' O E a 6 CO ❑ J U r N N- N. N. 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STATE OF ALASKA AINKA OIL AND GAS CONSERVATION COM ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing E Operations Shutdown Performed: Suspend E Perforate E Other Stimulate Alter Casing Change Approved Program r-- Plug Plug for Redrill fl Perforate New Pool IT Repair Well F Re-enter Susp Well r Other:Pull ESP/Install inner strin ' 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory IT 197-181 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22814-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU 1D-121 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 4414 feet Plugs(measured) None true vertical 4315 feet Junk(measured) None Effective Depth measured 3922 feet Packer(measured) 3712, 3885,3941 true vertical 3824 feet (true vertical) 3614, 3786,3842 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 SURFACE 4362 7 5/8 4402 4303 LINER 3538 51/2 3579 3481 I (5 1/2"xo to 2 7/8"©this depth) :E CEIVED Perforation depth: Measured depth: 3750-3780, 3810-3840, 3902-3932,3980-4010 JUN 0 1 2016 True Vertical Depth: 3652-3682, 3712-3742, 3804-3834,3882-3912 AOGCC Tubing(size,grade,MD,and ND) 2.875, L-80, 3585 MD, 3487 TVD Packers&SSSV(type,MD,and ND) PACKER-Baker FHL Retrievable Packer @ 3712 MD and 3614 ND, PACKER-Baker Premier Production Packer @ 3885 MD and 3786 ND, PACKER-Baker Premier Production Packer @ 3941 MD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None SCAN�EOtl. �� 4Il'., 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 79 2 28 0 162 Subsequent to operation Shut-in - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory F g� DevelopmentService Y Stratigraphic I' Copies of Logs and Surveys Run IT 16.Well Status after work: Oil F Gas la WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR IT WINJ WAG r GINJ IT SUSP IT 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: -WA-- 31C• 20'1 Contact Danny Kane @ 265-6048 Email Danny.Kane ,conocoDhillibs.com Printed Name Danny Kane Title Sr.Wells Engineer Signature Phone:265-6048 Date 3( --i\-40 - 20/G Form 10-404 Revised 5/2015 ATL °l l/ GSubmit Original Only lo4oA( RBDMS L� JUN 0 2 2016 ,ai,'"SF� F • • Operations Summary (with Timelog Depths) 7. 4 s,...r n .�, 1D-121 At ConovaPhiiiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr); Phase - Op Code Activity Code'. Time P-T-X Operation (ftKB); End Depth(ftKS)', 4/21/2016 4/21/2016 2.00 MIRU MOVE RURD P Blow down all the lines in the pits. 0.0 0.0 12:00 14:00 Bridle up the blocks,and lower the cattle chute. RD berming around the sub and pits. 4/21/2016 4/21/2016 2.00 MIRU MOVE MOB P PJSM. Load out the cuttings box, 0.0 0.0 14:00 16:00 mud engineer shack,parts house,and site control shack. Jack up the pits and pull the rig mats from under the pits. Pull the pits away from the sub. Load up the shop and satellite office. 4/21/2016 4/21/2016 1.00 MIRU MOVE MOB P Warm up the moving system,jack up 0.0 0.0 16:00 17:00 the sub,pull mats from under the sub, pull the sub off well 1Q-26,and stage the sub in the middle of the pad to lower the derrick. 4/21/2016 4/21/2016 1.00 MIRU MOVE RURD P PJSM. Finish derrick down checklist 0.0 0.0 17:00 18:00 and lay down the derrick. 4/21/2016 4/21/2016 2.50 MIRU MOVE MOB P Move the sub down the pad and 0.0 0.0 18:00 20:30 position so that the pits can get by the sub. Move the pits to the middle of the pad and install the jeep. Move the pits,satellite office,and shop from 1Q pad to 1D pad. 4/21/2016 4/21/2016 1.50 MIRU MOVE RURD P PU the herculite from the sub and pits. 0.0 0.0 20:30 22:00 Load up the rig mats from around the well. Clean up around well 1Q-26. 4/21/2016 4/22/2016 2.00 MIRU MOVE MOB P Move the sub 1.8 miles from 1Q pad 0.0 0.0 22:00 00:00 to the drilling tool house. 4/22/2016 4/22/2016 6.00 MIRU MOVE MOB P Move the sub 6.8 miles from the 0.0 0.0 00:00 06:00 drilling tool house to 1D pad. 4/22/2016 4/22/2016 1.50 MIRU MOVE MOB P PJSM. Move equipment on the pad to 0.0 06:00 07:30 enable the sub to position on the pad with the wind to the back of the sub. Position the sub with the wind to the back of the sub. 4/22/2016 4/22/2016 1.50 MIRU MOVE RURD P PJSM. Finish derrick raising checklist. 0.0 0.0 07:30 09:00 Raise and pin the derrick. Raise the cattle chute. 4/22/2016 4/22/2016 0.50 MIRU MOVE RURD P Hang the tree in the cellar. 0.0 0.0 09:00 09:30 4/22/2016 4/22/2016 1.50 MIRU MOVE MOB P Reposition the sub on the pad to be 0.0 0.0 09:30 11:00 able to back over well 1D-121. 4/22/2016 4/22/2016 1.50 MIRU MOVE RURD P Lay out herculite around the well. Set 0.0 0.0 11:00 12:30 grating and plywood in the cellar area. Stage wellhead equipment in the cellar area. 4/22/2016 4/22/2016 1.00 MIRU MOVE MOB P Spot the sub over well 1D-121 and set 0.0 0.0 12:30 13:30 rig mats under the sub. Lay out herculite for the fuel tank and set the sub down. 4/22/2016 4/22/2016 2.00 MIRU MOVE MOB P Spot the pits to the sub,set mats 0.0 0.0 13:30 15:30 under the pits,lay out herculite for the pits,and set the pits down. Spot the cuttings tank,filter unit,parts house, and mud engineer shack. . 4/22/2016 4/22/2016 3.00 MIRU MOVE RURD P RU berming around the sub,pits, 0.0 0.0 15:30 18:30 cuttings tank,and fuel tank. Hook up the interconnect. Page 1/12 Report Printed: 5/19/2016 • • -' xx Operations Summary (with Timelog Depths)PAW ,. 1D-121 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB), 4/22/2016 4/22/2016 2.00 MIRU MOVE RURD P Bridle down the blocks,hang bridle 0.0 0.0 18:30 20:30 lines in the derrick,and pin the blocks to the TD. RU the rig floor. Rig accepted at 20:30 hours on 4/22/16. 4/22/2016 4/22/2016 1.50 MIRU WELCTL RURD P Load the pits with 10.3 ppg NaCI/NaBr 0.0 0.0 20:30 22:00 brine with 3%KCI. RU circulating lines for the well kill operation. RU secondary IA valve. After 6 bbls of brine processed through the filtering unit the 10 micron filters plugged off. With the filters available only 80 bbls would be able to be filtered. Discussed with town engineer. Continue to take on 10.3 ppg brine with 3%KCI to the pits without filtering. 4/22/2016 4/22/2016 1.00 MIRU WELCTL MPSP P PU the lubricator and make up 0.0 0.0 22:00 23:00 crossover. RU lubricator to the tree and PT to 1500 psi(good test). Pull 4" H BPV and RD the lubricator. Tubing =900 psi and IA=480 psi. 4/22/2016 4/23/2016 1.00 MIRU WELCTL RURD P RU circulating lines to the tree through 0.0 0.0 23:00 00:00 the choke manifold to the kill tank. Blow steam and air through line to the kill tank and check connections. 4/23/2016 4/23/2016 1.25 MIRU WELCTL RURD P Continue to RU circulating lines for the 0.0 0.0 00:00 01:15 well kill operation. 4/23/2016 4/23/2016 0.25 MIRU WELCTL SFTY P PJSM for the well kill. 0.0 0.0 01:15 01:30 4/23/2016 4/23/2016 0.25 MIRU WELCTL SEQP P Fill and test all surface 0.0 0.0 01:30 01:45 lines/equipment to 3500 psi(good test). 4/23/2016 4/23/2016 2.75 MIRU WELCTL KLWL P Vent gas from the IA(IP=440 psi and 0.0 0.0 01:45 04:30 FP=160 psi). Vent gas from the tubing(IP=640 psi and FP=240). Line up to reverse circulate. Reverse circulate 10.3 ppg NaCI/NaBr with 3% KCI down the IA taking return out the tubing to the kill tank at 2 BPM getting 10.2 heavy ppg brine at surface. Pumped 300 bbls and got back 298 bbls in the kill tank. 4/23/2016 4/23/2016 3.50 MIRU WELCTL OWFF P Monitor the well pressures. Initial 0.0 0.0 04:30 08:00 Pressures: tubing=20 psi and IA= 40 psi. Final Pressures: tubing=25 psi and IA=70 psi. SimOps: Blow down lines and empty the kill tank. 4/23/2016 4/23/2016 0.50 MIRU WELCTL KLWL P Bullhead 10 bbls of 10.3 ppg brine 0.0 0.0 08:00 08:30 down the tubing at 2 BPM=380 psi. Circulate 30 bbls down the tubing taking return out the IA to the kill tank at 2 BPM=100 psi. Shut in the well. 4/23/2016 4/23/2016 1.00 MIRU WELCTL OWFF P Monitor the well pressures. Initial 0.0 0.0 08:30 09:30 Pressures: tubing=40 psi and IA= 160 psi. Final Pressures: tubing=60 psi and IA=200 psi. Page 2/12 Report Printed: 5/19/2016 • • Operations Summary (with Timelog Depths) 1D-121 CxincicaPhillips .. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)', 4/23/2016 4/23/2016 0.25 MIRU WELCTL OWFF P Bleed off 2 bbls. 0.0 0.0 09:30 09:45 4/23/2016 4/23/2016 1.00 MIRU WELCTL OWFF P Monitor the well pressures. Initial 0.0 0.0 09:45 10:45 Pressures: tubing=0 psi and IA=60 psi. Final Pressures: tubing=60 psi and IA= 140 psi. 4/23/2016 4/23/2016 0.25 MIRU WELCTL OWFF P Bleed off 3 bbls. 0.0 0.0 10:45 11:00 4/23/2016 4/23/2016 2.00 MIRU WELCTL OWFF P Monitor the well pressures. Initial 0.0 0.0 11:00 13:00 Pressures: tubing=0 psi and IA=40 psi. Final Pressures: tubing=100 psi and IA= 140 psi. 4/23/2016 4/23/2016 5.25 MIRU WELCTL COND T Increase the brine weight from 10.3 0.0 0.0 13:00 18:15 ppg to 10.6 ppg. 4/23/2016 4/23/2016 1.25 MIRU WELCTL KLWL T Reverse circulate 10.6 ppg NaCI/NaBr 0.0 0.0 18:15 19:30 with 3%KCI down the IA taking return out the tubing through the gas buster to the pits at 2 BPM=141 psi getting 10.6 ppg brine at surface. Pumped 150 bbls and lost 16.5 bbls during the circulation. Shut in the well. 4/23/2016 4/23/2016 1.00 MIRU WELCTL OWFF T Monitor the well pressures. Initial 0.0 0.0 19:30 20:30 Pressures: tubing=10 psi and IA= 30 psi. Final Pressures: tubing=10 psi and IA=30 psi. SimOps: Empty pit#1. 4/23/2016 4/23/2016 0.75 MIRU WELCTL OWFF T Bleed the IA to 0 psi. Attempt to bleed 0.0 0.0 20:30 21:15 the tubing to 0 psi but unable to get the pressure below 20 psi(gas cut fluid). 4/23/2016 4/23/2016 0.75 MIRU WELCTL KLWL T Reverse circulate 10.6 ppg NaCI/NaBr 0.0 0.0 21:15 22:00 with 3%KCI down the IA taking return out the tubing through the gas buster to the pits at 3 BPM=174 psi getting 10.6 ppg brine at surface. Pumped 150 bbls and lost 15 bbls during the circulation. Shut in the well. 4/23/2016 4/23/2016 0.50 MIRU WELCTL OWFF T Monitor the well pressures. Initial 0.0 0.0 22:00 22:30 Pressures: tubing=30 psi and IA= 40 psi. Final Pressures: tubing=30 psi and IA=40 psi. 4/23/2016 4/23/2016 1.00 MIRU WELCTL OWFF T Bleed the IA to 0 psi. Attempt to bleed 0.0 0.0 22:30 23:30 the tubing to 0 psi but unable to get the pressure below 20 psi;getting good 10.6 ppg brine back. 4/23/2016 4/24/2016 0.50 MIRU WELCTL WAIT T Notify town engineer and ordered out 0.0 0.0 23:30 00:00 10.9 ppg NaCI/NaBr brine. Continue to monitor the well pressures. Initial Pressures: tubing=20 psi and IA=0 psi. Final Pressures: tubing=20 psi and IA=0 psi. SimOps: Empty pit#1. 4/24/2016 4/24/2016 0.25 MIRU WELCTL WAIT T Continue to wait for 10.9 ppg brine to 0.0 0.0 00:00 00:15 arrive while continuing to monitor the well. Page 3/12 Report Printed: 5/19/2016 • • Operations Summary (with Timelog Depths) x��a 1D-121 CormooPhillips Gels f:,s Rig: NABORS 7ES Job: RECOMPLETION Time Log ' Start Depth Start Time End Time Our(hr) Phase Op Cede Activity Code Time P-T-X Operation (dtKB). End Depth(ftKE) 4/24/2016 4/24/2016 2.50 MIRU WELCTL COND T Load the pits with 288 bbls of 11.1 ppg 0.0 0.0 00:15 02:45 brine and mix with existing 161 bbls of10.6 ppg brine to make 449 bbls of 10.9 ppg brine. 4/24/2016 4/24/2016 1.00 MIRU WELCTL KLWL T Reverse circulate 10.9 ppg NaCI/NaBr 0.0 0.0 02:45 03:45 with 3%KCI down the IA taking return out the tubing through the gas buster to the pits at 2 BPM=90 psi getting 10.9 ppg brine at surface. Pumped 120 bbls and lost 21 bbls during the circulation. Shut in the well. 4/24/2016 4/24/2016 0.75 MIRU WELCTL OWFF T Monitor the well pressures: tubing= 0.0 0.0 03:45 04:30 20 psi and IA= 10 psi. Bleed the tubing and IA to 0 psi. Monitor the well for 30 minutes and the well is static. 4/24/2016 4/24/2016 0.50 MIRU WELCTL RURD P Blow down and RD circulating 0.0 0.0 04:30 05:00 equipment. 4/24/2016 4/24/2016 0.50 MIRU WHDBOP MPSP P Install 4"H BPV with the dry rod. 0.0 0.0 05:00 05:30 Perform rolling test on the BPV to test the BPV in the direction of flow to the maximum available wellbore pressure. Bullhead 4 bbls down the IA at 3 BPM =300 psi. Bleed off the pressure. 4/24/2016 4/24/2016 2.00 MIRU WHDBOP NUND P RU wire slings to the TD and RU 0.0 0.0 05:30 07:30 slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. Clean and inspect the tubing hanger lift threads. Install the blanking plug. 4/24/2016 4/24/2016 3.50 MIRU WHDBOP NUND P NU the DSA and NU the BOP stack. 0.0 0.0 07:30 11:00 Torque bolts on the DSA and BOP stack. Install the turn buckles and riser. Air up the air boots on the riser. 4/24/2016 4/24/2016 2.00 MIRU WHDBOP OTHR P Change the upper pipe rams from 2- 0.0 0.0 11:00 13:00 7/8"x 5"VBRs to 5-1/2"solid body rams. 4/24/2016 4/24/2016 1.00 MIRU WHDBOP RGRP T Close the doors on the upper pipe 0.0 0.0 13:00 14:00 rams. Door bolt cross threaded. Open the door,clean the threads with a tap,close the door and tighten the bolts. 4/24/2016 4/24/2016 3.50 MIRU WHDBOP RURD P RU BOPE testing equipment. Fill 0.0 0.0 14:00 17:30 BOP stack and choke manifold with fresh water. Space out and mark all the test joints. Shell test and test welds on 2"Demco to 250/5000 psi (good test). Page 4/12 Report Printed: 5/19/2016 • Operations Summary (with Timelog Depths) 1D-121 4;` Conorcehiffips Rig: NABORS 7ES Job: RECOMPLETION Time Log ]] StartDepth Start Time End Time Cur(Er) ` Phase Op Code Activity Code Time P-T-X Operation {MKS) End Depth(MKS) 4/24/2016 4/24/2016 1.75 MIRU WHDBOP BOPE T Conduct initial BOPE: test 2-7/8"x 5" 0.0 0.0 17:30 19:15 VBR's(lower pipe rams)to 250/4000 psi with 2-7/8"and 4-1/2"test joints; test 5-1/2"solid body rams(upper pipe rams)to 250/4000 psi with 5-1/2"test joint;test annular to 250/4000 with 2- 7/8",4-1/2",and 5-1/2"test joints; conducted Koomey drawdown test. The states right to witness was waived by AOGCC inspector Brian Bixby via email on 4/21/16 at 15:22 hours. Tests: 1) Blind Rams,2"Demco,Outer Test Spool Valve,Chokes 1,2,3,&16 (Passed) Note: High pressure test kept leaking off,trouble shot,and determined it was the upper IBOP leaking. Function the upper IBOP and retest passed. Fail/Pass on the upper IBOP. 2) Blinds Rams, HCR Kill,Inner Test Spool Valve,Upper IBOP,Chokes 4, 5,&6(Passed) 4/24/2016 4/24/2016 2.25 MIRU WHDBOP BOPE P Tests: 0.0 0.0 19:15 21:30 3) Blind Rams,Manual Kill,Inner Test Spool Valve,Lower IBOP,Chokes 7, 8,&9(Passed) 4) Super Choke and Manual Adjustable Choke(Passed) 5) Blind Rams,Manual Kill, Inner Test Spool Valve, HT-38 Dart Valve, Chokes 8, 10,&11 (Passed) 6) Blind Rams, Manual Kill,Chokes 8, 12,13,&15(Passed) 4/24/2016 4/25/2016 2.50 MIRU WHDBOP BOPE T Test: 0.0 0.0 21:30 00:00 Attempt to test the annular with the 5- 1/2"test joint but high pressure test failed. Crossover(5-1/2"BTC pin x 3- 1/2"HT-38 box)on top of the 5-1/2" test joint was leaking at the BTC connection. Pulled the test joint,re- torqued the connection,re-installed, and filled the test joint. Test failed a second time due to leaking BTC connection.Pulled the test joint,re- doped, re-torqued,re-installed,and filled the test joint.Test failed a third time due to leaking BTC connection Pulled the test joint,replace the seal ring,re-doped, re-torqued,re- installed,and filled the test joint. Re- test passed. 7) Annular with 5-1/2"test joint, Manual Kill,HT-38 TIW(Passed) Page 5/12 Report Printed: 5/19/2016 • • Operations Summary (with Timelog Depths) o 1D-121 ConocoPhiftips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(11KS)', 4/25/2016 4/25/2016 2.00 MIRU WHDBOP BOPE P Continue to conduct initial BOPE: test 0.0 0.0 00:00 02:00 2-7/8"x 5"VBR's(lower pipe rams)to 250/4000 psi with 2-7/8"and 4-1/2" test joints;test 5-1/2"solid body rams (upper pipe rams)to 250/4000 psi with 5-1/2"test joint;test annular to 250/4000 with 2-7/8",4-1/2",and 5- 1/2"test joints;conducted Koomey drawdown test. The states right to witness was waived by AOGCC inspector Brian Bixby via email on 4/21/16 at 15:22 hours. Tests: 9) Annular with 4-1/2"test joint, Manual Kill,Manual Choke,HT-38 TIW(Passed) 10)Lower Pipe Rams with 4-1/2"test joint,HT-38 TIW(Passed) 4/25/2016 4/25/2016 1.50 MIRU WHDBOP BOPE T 11)Annular with 2-7/8"test joint,3- 0.0 0.0 02:00 03:30 1/2"EUE 8rd TIW(Failed) Unable to get the annular to pass the high pressure test with the 2-7/8"test joint. The annular will be replaced and retested with 2-7/8",4-1/2",and 5-1/2" test joints. 4/25/2016 4/25/2016 0.75 MIRU WHDBOP BOPE P 12)Lower Pipe Rams with 2-7/8"test 0.0 0.0 03:30 04:15 joint,3-1/2"EUE 8rd TIW(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2900 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi=19 seconds Full System=95 Seconds 4/25/2016 4/25/2016 0.75 MIRU WHDBOP RURD T RD BOPE testing equipment. Blow 0.0 0.0 04:15 05:00 down lines and choke manifold. 4/25/2016 4/25/2016 9.00 MIRU WHDBOP RGRP T Pull the riser. ND the Dutch riser 0.0 0.0 05:00 14:00 adapter from the annular unit. Pull the latch head off the annular unit. Remove the failed element. Pull the annular piston and change out the seals on the piston. Install new annular element. Install new seals on the annular cap and install the annular cap. Tighten the LDS, NU the Dutch riser adapter to the annular unit,install the riser,and air up the air boots. 4/25/2016 4/25/2016 1.00 MIRU WHDBOP RURD T PU 2-7/8"test joint and function bag to 0.0 0.0 14:00 15:00 break it in. PU 5-1/2"test joint and fill stack. Page 6/12 Report Printed: 5/19/2016 • • Operations Summary (with Timelog Depths) r, k4igea 1D-121 ConoocThillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ltKB) 4/25/2016 4/25/2016 2.50 MIRU WHDBOP BOPE P Tests after the annular unit was 0.0 0.0 15:00 17:30 replaced to 250/4000 psi. 13)Annular with 5-1/2"test joint, Manual Kill,Manual Choke,HT-38 TIW(Passed) 14)Annular with 4-1/2"test joint, Manual Kill,Manual Choke,HT-38 TIW(Passed) 15)Annular with 2-7/8"test joint, Manual Kill,Manual Choke,3-1/2" EUE 8rd TIW(Passed) 4/25/2016 4/25/2016 1.00 MIRU WHDBOP RURD P RD BOPE testing equipment. Blow 0.0 0.0 17:30 18:30 down lines and choke manifold. 4/25/2016 4/25/2016 0.50 MIRU WHDBOP MPSP T Pull the blanking plug with a joint of 0.0 0.0 18:30 19:00 DP. Check for pressure/gas under BPV and gas was observed. 4/25/2016 4/25/2016 0.50 MIRU WHDBOP RURD T RU circulating equipment. 0.0 0.0 19:00 19:30 4/25/2016 4/25/2016 0.50 MIRU WHDBOP CIRC T Circulate 28 bbls down the tubing 0.0 0.0 19:30 20:00 through the BPV at 2 BPM=200 psi. 4/25/2016 4/25/2016 0.50 MIRU WHDBOP MPSP P Check for pressure/gas under BPV 0.0 0.0 20:00 20:30 (no pressure/gas),pull 4"H BPV with dry rod,and install side port isolation sleeve. 4/25/2016 4/25/2016 1.00 COMPZN RPCOMP RURD P MU landing joint with crossover,HT- 0.0 0.0 20:30 21:30 38 TIW,and 10'DP pup. MU landing joint to the tubing hanger and MU the TD. 4/25/2016 4/26/2016 2.50 COMPZN RPCOMP RURD P RU Centrilift ESP sheave in the 0.0 0.0 21:30 00:00 derrick and connected the trunk. SimOps: Circulate one hole volume down the tubing taking returns out the IA through the gas buster to the pits at 2 BPM=50 psi. 4/26/2016 4/26/2016 0.50 COMPZN RPCOMP RURD P RD and blow down circulating lines, 0.0 0.0 00:00 00:30 choke manifold,and secondary choke. 4/26/2016 4/26/2016 0.25 COMPZN RPCOMP SFTY P PJSM with rig crew and third party for 0.0 0.0 00:30 00:45 POOH with ESP completion. 4/26/2016 4/26/2016 0.25 COMPZN RPCOMP RURD P Fill the gas buster and choke manifold. 0.0 0.0 00:45 01:00 SimOps: BOLDS. 4/26/2016 4/26/2016 0.25 COMPZN RPCOMP PULL P Unseat the tubing hanger at 50K and 0.0 3,694.0 01:00 01:15 shear release the Viking packer at 150K. 4/26/2016 4/26/2016 1.75 COMPZN RPCOMP CIRC P Circulate 89 bbls at 2 BPM=270 psi, 3,694.0 3,694.0 01:15 03:00 shut down the pumps,and monitor the well. Gas still breaking out at surface. Continue to circulate 35 bbls at 1 BPM =58 psi. Lost 71 bbls during the circulation. 4/26/2016 4/26/2016 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 10 3,694.0 3,694.0 03:00 03:15 minutes. The well is on a slight vac. 4/26/2016 4/26/2016 0.75 COMPZN RPCOMP PULL P Pull tubing hanger to the rig floor,Mag 3,694.0 3,636.0 03:15 04:00 check ESP cable,and disconnect ESP cable. Back out and lay down the landing joint. Break out the tubing hanger and lay down the tubing hanger. Page 7/12 Report Printed: 5/19/2016 . • Operations Summary (with Timelog Depths) �� Y�•s, 1D-121 Co co hillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time ' Dur(hr) Phase Op Code Activity Code Time P-T-X + Operation (MKS)', End Depth(fEE), 4/26/2016 4/26/2016 0.50 COMPZN RPCOMP RURD P RU to ESP cable and run rope over 3,636.0 3,636.0 04:00 04:30 the sheave to the spooling unit. Break out HT-38 TIW from the landing joint. 4/26/2016 4/26/2016 0.50 COMPZN RPCOMP PULL P POOH standing back 3 stands of 4- 3,636.0 3,359.0 04:30 05:00 1/2"tubing spooling ESP cable. 4/26/2016 4/26/2016 0.50 COMPZN RPCOMP RURD P Tie in ESP cable into the spooling unit 3,359.0 3,359.0 05:00 05:30 spool. 4/26/2016 4/26/2016 6.50 COMPZN RPCOMP PULL P Continue POOH standing back 4-1/2" 3,359.0 0.0 05:30 12:00 tubing spooling ESP cable to surface. Lay down Viking packer and ESP pump,recover 71 Cannon clamps and 8 SS bands. 4/26/2016 4/26/2016 2.50 COMPZN RPCOMP RURD P Rig down Centrilift spooler and 0.0 0.0 12:00 14:30 equipment. Clean and clear rig floor. 4/26/2016 4/26/2016 0.50 COMPZN RPCOMP SVRG P Service Top Drive. 0.0 0.0 14:30 15:00 4/26/2016 4/26/2016 1.00 COMPZN WELLPR BHAH P Bring BHA equipment to the floor. 0.0 0.0 15:00 16:00 4/26/2016 4/26/2016 2.50 COMPZN WELLPR BHAH P M/U BHA#1 per Baker rep:Casing 0.0 344.0 16:00 18:30 scraper,magnets,boot baskets,etc. with drill collars. 4/26/2016 4/26/2016 3.00 COMPZN WELLPR TRIP P Trip in hole on stands of 4-1/2"IBT-M 344.0 3,600.0 18:30 21:30 tubing from derrick to 3600'. UP WT= 75M#,DN WT=73M#. 4/26/2016 4/26/2016 0.50 COMPZN WELLPR PULD P Pick up crossover and 5 joints of 3- 3,600.0 3,750.0 21:30 22:00 1/2"drillpipe to get casing scraper to target depth. UP WT=80M#, DN WT =73M#. Work casing scraper up and down across target packer setting depth of 3715'. 4/26/2016 4/26/2016 1.50 COMPZN WELLPR CIRC P Circulate 2 BU's. Initial 2BPM @ 180 3,750.0 3,750.0 22:00 23:30 PSI,Final 4 BPM @ 290 PSI. Lost 22.6 BBL,monitor well,taking fluid. Had good returns throughout the circulation--some fluid losses,but approximately the same as under static conditions. Circulate out crude, no solids. 4/26/2016 4/27/2016 0.50 COMPZN WELLPR PULD P Lay down 2 joints of drill pipe,stand 3,750.0 3,100.0 23:30 00:00 back one stand of drill pipe,and lay down 4-1/2"tubing to 3100'. 4/27/2016 4/27/2016 1.50 COMPZN WELLPR TRIP P Continue to lay down 4-1/2"tubing 3,100.0 1,841.0 00:00 01:30 from 3100'to 1841'. UP WT=57M#, DN WT=55M#. 4/27/2016 4/27/2016 1.00 COMPZN WHDBOP MPSP P Pick up Baker storm packer and 1,841.0 1,841.0 01:30 02:30 setting equipment per Baker rep. RIH with single stand of drill pipe and set with mid-element of packer at 98'. Test storm packer to 1000 PSI,good. Stand back drill pipe. 4/27/2016 4/27/2016 1.50 COMPZN WHDBOP MPSP P Pick up Baker G-lock RBP and RIH 1,841.0 1,841.0 02:30 04:00 with 2 joints of drillpipe. Set RBP with mid-element at 74'. Lay down joints of drillpipe and test RBP to 1000 PSI, good. 4/27/2016 4/27/2016 2.50 COMPZN WHDBOP NUND P Begin ND of BOPE,rack back BOPE. 1,841.0 1,841.0 04:00 06:30 4/27/2016 4/27/2016 1.50 COMPZN WHDBOP NUND P Remove all valves,studs,etc.,from 1,841.0 1,841.0 06:30 08:00 wellhead. Page 8/12 Report Printed: 5/19/2016 • • ,,t,„41.00-ObsOperations Summary (with Timelog Depths) a ... 1D-121 ozmocophimps Rig: NABORS 7ES Job: RECOMPLETION Time Log; Start Depth Start Time End Time Our(he) Phase Op Code Activity Code Time P-T-X Operation (EKB)' End Depth(EKE): 4/27/2016 4/27/2016 2.00 COMPZN WHDBOP NUND T Hook up and attempt to pull wellhead-- 1,841.0 1,841.0 08:00 10:00 won't come free. Decision made to cut. PJSM with GBR welder,cut 16" conductor,clean up cellar. Cut 7-5/8" casing. 4/27/2016 4/27/2016 1.00 COMPZN WHDBOP NUND P Set wellhead out of way,clean up 1,841.0 10:00 11:00 cellar. 4/27/2016 4/27/2016 1.00 COMPZN WHDBOP NUND P GBR welder dress-off cut on 7-5/8" 1,841.0 1,841.0 11:00 12:00 casing to prepare for new transition nipple. 4/27/2016 4/27/2016 2.00 COMPZN WHDBOP NUND T Attempt to install transition nipple,no- 1,841.0 1,841.0 12:00 14:00 go. Call town,decision made to work additional dress-off on 7-5/8"casing. 4/27/2016 4/27/2016 5.50 COMPZN WHDBOP NUND P Position weld-on transition nipple on 7 1,841.0 1,841.0 14:00 19:30 -5/8"casing stub,ensure level. Pre- heat and make fillet welds between transition nipple and casing. 4/27/2016 4/28/2016 4.50 COMPZN WHDBOP NUND P Post-heat the transition nipple to 800 1,841.0 1,841.0 19:30 00:00 degrees F. Wrap welds with insulation and wait for metal to cool to ambient temperature. 4/28/2016 4/28/2016 12.00 COMPZN WHDBOP NUND P Waiting for weld to cool to ambient 1,841.0 1,841.0 00:00 12:00 temperature. 4/28/2016 4/28/2016 1.50 COMPZN WHDBOP NUND P Unwrap insulation from welded 1,841.0 1,841.0 12:00 13:30 transition nipple. FMC tests weld area to 1000 PSI with nitrogen,leaking. Diagnose leak,coming from above 7- 5/8"bushing. Call GBR welder to repair weld on top of bushing. 4/28/2016 4/28/2016 2.00 COMPZN WHDBOP NUND T Pre-heat 7-5/8"bushing,weld top of 1,841.0 1,841.0 13:30 15:30 bushing. Test weld to 1000 PSI with nitrogen for 15 minutes,good. Post- heat weld,wrap with insulation and begin cooling process. 4/28/2016 4/29/2016 8.50 COMPZN WHDBOP NUND T Wait for weld to cool to ambient 1,841.0 1,841.0 15:30 00:00 temperature. 4/29/2016 4/29/2016 4.00 COMPZN WHDBOP NUND T Continue to let transition nipple weld 1,841.0 1,841.0 00:00 04:00 cool. Talk with GBR welding supervisor,advised to remove insulation from weld. Remove insulation 4/29/2016 4/29/2016 2.00 COMPZN WHDBOP NUND P Prep to install new well head. Consult 1,841.0 1,841.0 04:00 06:00 with DS operator/POP lead to insure that the orientation of the valving is correct. 4/29/2016 4/29/2016 4.50 COMPZN WHDBOP NUND P Install new FMC Gen V casing head 1,841.0 1,841.0 06:00 10:30 and tubing head,install BOPE stack and riser. Test void of wellhead to 1000 PSI, 10 minutes,good test. 4/29/2016 4/29/2016 1.50 COMPZN WHDBOP PRTS P Set lower test plug,hanging up at 1,841.0 1,841.0 10:30 12:00 upper LDS. C/O gasket. Re-set lower test plug,rig up test equipment,fill stack. Shell test all breaks on stack to 250/4000 PSI for 5 minutes. Good Test. 4/29/2016 4/29/2016 0.50 COMPZN WHDBOP PRTS P Blow down and R/D test equipment. 1,841.0 1,841.0 12:00 12:30 Page 9/12 Report Printed: 5/19/2016 . 4 Operations Summary (with Timelog Depths) ( ,— 1D-121 c `hiHlps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (CKB) End Depth(ttKB)'-. 4/29/2016 4/29/2016 1.00 COMPZN RPCOMP MPSP P M/U G-lock retrieval tool and RIH to 1,841.0 1,841.0 12:30 13:30 74',engage G-Iock. Verify no pressure,pull and lay down G-lock plug and retrieval tool. 4/29/2016 4/29/2016 1.50 COMPZN RPCOMP MPSP P M/U storm packer retrieval tool. RIH 1,841.0 1,841.0 13:30 15:00 and engage storm packer. Verify no pressure under storm packer,pull packer and monitor well. Losing fluid. L/D 3 joints of drillpipe,storm packer and retrieval tool. 4/29/2016 4/29/2016 2.50 COMPZN RPCOMP PULD P Lay down 4-1/2"tubing from 1841'to 1,841.0 344.0 15:00 17:30 344'. 4/29/2016 4/29/2016 1.50 COMPZN RPCOMP BHAH P Lay down Baker casing scraper 344.0 0.0 17:30 19:00 assembly per Baker rep. Clean and clear rig floor. 4/29/2016 4/29/2016 0.50 COMPZN RPCOMP RURD P Pull wear ring. 0.0 0.0 19:00 19:30 4/29/2016 4/29/2016 1.00 COMPZN RPCOMP RURD P Change out running equipment from 4 0.0 0.0 19:30 20:30 -1/2"to 5-1/2" 4/29/2016 4/29/2016 2.00 COMPZN RPCOMP RCST P Pick up and RIH with WLEG,2.25"D- 0.0 500.0 20:30 22:30 nipple with CA-2 plug verified installed,X-O,3-1/2"x 7-5/8"FHL packer,PBR,KBMG with dummy installed,2.313"X-nipple,80-32 SBE, and X-O. RIH on 5-1/2"Hyd-563 csaing. Torque 2-7/8"EUE connections to 1750 Ft-Lbs,Hyd-563 to 6200 Ft-Lbs. RIH to 500'. 4/30/2016 4/30/2016 3.00 COMPZN RPCOMP RCST P Continue to run in hole with 5-1/2"Hyd 500.0 3,740.0 00:00 03:00 -563 from 500'to 3740'. Filling pipe on the fly,topping off every 15 joints. UP WT=75M#,DN WT=73M#. 4/30/2016 4/30/2016 1.00 COMPZN RPCOMP RURD P Make up X-O's landing joint, 3,740.0 3,740.0 03:00 04:00 circulating head and line up to pump. 4/30/2016 4/30/2016 1.50 COMPZN RPCOMP PACK P Fill lines. Set packer with mid-element 3,740.0 3,740.0 04:00 05:30 at 3715'. Ramp pressure up slowly to 2500 PSI(See packer set at 1700 PSI). Hold for 5 minutes. Bleed pressure down to 1000 PSI for 10 minutes and hold. Good. Bleed pressure off of 5-1/2"and pressure up 5-1/2"x 7-5/8"to 1800 PSI for 10 minutes. Good. All charted. Pressure up to 2100 PSI inside 5-1/2" to assist in shearing PBR. P/U to 80M# and shear out of PBR,verify free and re-tag. P/U 12'to pump. 4/30/2016 4/30/2016 2.00 COMPZN RPCOMP CRIH P PJSM for pumping CI. Pump 10 BBL 3,740.0 3,740.0 05:30 07:30 spacer, 10 BBL 14.5 PPG brine,30 BBLs 14.5 PPG CI brine,turn pumps over to LRS. LRS pumps 33 BBL diesel. Slack off on string and strip through bag to land seals(3'up from fully located). 4/30/2016 4/30/2016 1.00 COMPZN RPCOMP RURD P Verify no pressure. Bleed off lines,rig 3,740.0 3,740.0 07:30 08:30 down and blow down pumping equipment and LRS. Drain joint. Page 10/12 Report Printed: 5/19/2016 •e • IMI - -� Operations Summary (with Timelog Depths) Zift ., 1D-121 ccPhitii Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKh) End Depth(ftKB)` 4/30/2016 4/30/2016 3.50 COMPZN WHDBOP NUND P Hang riser. Split stack and set 0.0 0.0 08:30 12:00 emergency slips. Rig up Wachs cutter and cut 5-1/2"casing. (8.3-ft cut-off joint). 4/30/2016 4/30/2016 2.00 COMPZN WHDBOP WWSP P Install new packoff and RILDS. 0.0 0.0 12:00 14:00 4/30/2016 4/30/2016 2.50 COMPZN WHDBOP NUND P Test packoff void to 4500 PSI for 10 0.0 0.0 14:00 16:30 minutes. Good test. Install riser. 4/30/2016 4/30/2016 2.50 COMPZN RPCOMP RURD P R/U weatherford tongs and 0.0 0.0 16:30 19:00 Schlumberger Camco sheave and spooler for I-wire. Make up gauge and test wire. 4/30/2016 5/1/2016 5.00 COMPZN RPCOMP RCST P Pick up 2-7/8"EUE-8rd completion per 0.0 1,828.0 19:00 00:00 running order. Verify all serial numbers per tallies. NPGM tubing- side gauge mandrel made up with gauge. Test gauge to 5000 PSI for 15 minutes,good. Initial reading 17 PSI, 53 oF. P/U CMU and use 5 SST bands for I-wire around fluted subs and body of CMU. Pick up KBMG GLM with SOV installed. Run Cannon clamp over each coupling. RIH to 1828'. 5/1/2016 5/1/2016 3.50 COMPZN RPCOMP RCST P Continue to RIH with 2-7/8" 1,828.0 3,594.0 00:00 03:30 completion to 3594'. Schlumberger Camco tests wire and gauge every 30 joints,run 117 Cannon clamps,7 single clamps,5 SST bands(total). UP WT=48M#, DN WT=48M#. No- Go shoulders at 3579'. 5/1/2016 5/1/2016 2.00 COMPZN RPCOMP THGR P Make up tubing hanger,landing joint, 3,594.0 3,594.0 03:30 05:30 circulating head,and associated XOs. Make up I-wire to hanger and test wire and gauge. 5/1/2016 5/1/2016 1.00 COMPZN RPCOMP CRIH P Pump 30 BBL spacer,50 BBL SW,60 3,594.0 3,594.0 05:30 06:30 BBL 8.6PPG Cl, 16 BBL SW. Pumping at 3 BPM, Initial pressure= 700 PSI,Final pressure=330 PSI. 5/1/2016 5/1/2016 0.50 COMPZN RPCOMP THGR P Land tubing hanger,RILDS. 3,594.0 3,594.0 06:30 07:00 5/1/2016 5/1/2016 1.50 COMPZN RPCOMP PRTS P Test tubing to 3000 PSI for 15 3,594.0 3,594.0 07:00 08:30 minutes. Bleed tubing to 2200 PSI. Test IA to 3000 PSI for 30 minutes. Shear out,Pump both ways at 2 BPM, 540 PSI. Shut in and monitor pressure. Observe tubing building to 120 PSI. CA-2 plug determined to be leaking,call for slickline unit. 5/1/2016 5/1/2016 7.00 COMPZN RPCOMP SLKL T PJSM for slickline work. Spot slickline 3,594.0 3,594.0 08:30 15:30 unit,bring tools to floor. Rig up slickline unit and equipment at floor. Slickline RIH with 2.313"XX Plug and sets at 3536'SLM. POOH with slickline. RDMO slickline. 5/1/2016 5/1/2016 0.50 COMPZN WHDBOP MPSP P Set TWC,test to 1000 PSI for 5 15:30 16:00 miinutes. 5/1/2016 5/2/2016 8.00 DEMOB RIGMNT RURD P ACTIVITIES FOR DEMOB/STACK OF 16:00 00:00 NABORS 7ES:clean,clear and wash rig floor and wind walls. Clean and wash pits. Page 11/12 Report Printed: 5/19/2016 ',If • • _ � Operations Summary (with Timelog Depths) 1D-121 ronocoPhiiiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time '.. End Time Our(hr),.. Phase Op Code Activity Code'.. Time P-T-X 'r Operation {MKS) End Depth(ftKS).. 5/2/2016 5/2/2016 6.00 COMPZN RIGMNT RURD P Clean pits. Clean sumps under rig 00:00 06:00 floor. 5/2/2016 5/2/2016 4.00 COMPZN RIGMNT RURD P Continue cleaning rig floor,clean 06:00 10:00 under drawworks. 5/2/2016 5/2/2016 2.00 COMPZN RIGMNT RURD P Circulate freshwater through all 10:00 12:00 surface lines,pit lines,cellar lines and choke manifold. Blow down. 5/2/2016 5/2/2016 1.50 COMPZN RIGMNT RURD P Remove saver sub and hydraulic 12:00 13:30 IBOP. 5/2/2016 5/2/2016 10.00 COMPZN RIGMNT RURD P Remove upper,blind,lower rams,coat 13:30 23:30 bonnet internals with VPCI-369 grease,remove all Koomey lines and fittings,label and cap/plug lines and ports. Remove kill line and unbolt flange. Remove choke block and line, break all flanges on stack,rack back stack. 5/2/2016 5/3/2016 0.50 COMPZN WHDBOP NUND P Prep and clean wellhead,begin NU 23:30 00:00 new FMC Gen-V tubing head adapter. 5/3/2016 5/3/2016 4.50 COMPZN WHDBOP NUND P Install new tubing head adapter and 00:00 04:30 make up Schlumberger gauge connection equipment through the adapter. Test gauge,good continuity and good readings(1715 PSI,68.8 oF). Test adapter to 5000 PSI for 15 minutes,good. Install new tree and test to 250/5000 PSI,good test. 5/3/2016 5/3/2016 0.50 COMPZN WHDBOP MPSP P Pull Two-Way Check. 04:30 05:00 5/3/2016 5/3/2016 4.00 COMPZN MOVE FRZP P Little Red Services rigs up to pump 45 05:00 09:00 BBL diesel down the IA at 2 bpm at 1,200 psi,then u-tube with tubing to freeze protect well. RD LRS. 5/3/2016 5/3/2016 0.50 COMPZN WHDBOP MPSP P Install BPV 09:00 09:30 5/3/2016 5/3/2016 1.00 COMPZN MOVE RURD P Install gauges and secure well 09:30 10:30 5/3/2016 5/3/2016 1.50 COMPZN MOVE RURD P Prep for laying over derrick 10:30 12:00 Release Nabors 7ES @ 12:00 hrs on 5-3-16 Page 12/12 Report Printed: 5/19/2016 aN KUP IF 1 D-121 ConocoPhitlips Well Attribut Max Angle TD ° AI sk II.,t Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) CoratoPhmos 500292281400 WEST SAK PROD 26.17 2,427.85 4,414.0 ... Comment H2S(ppm) Date Annotation End Date IKB-Grd(ft) 'Rig Release Date n 10-121,5/19/20166.4828 AM SSSV:NONE 5 11/10/2014 Last WO; 5/3/2016 12/6/1997 Vertical schamanc..(acwal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 3,922.0 1/4/2014 Rev Reason.WORKOVER;GLV CIO.PLUGS lehallf 5/13/2016 PULLED 1..le___.. .11 Casing Strings 1 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth IND)... Wt/Len(I...Grade Top Thread HANGER;41.53. CONDUCTOR 16 15.062 40-0 121-0 121.0 62.50 H-40 WELDED XO Reducing;44.8 + I Casing Description OD(in) . ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I.. Grade Top Thread T. SURFACE 7 5/8 6.750 40.2 4,402.0 4,303.4 29.70 L-80 BTCM Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection LINER 5-1/2"RWO 51/2 4.950 41.5 3,740.0 3,641.9 15.50 L-80 Hyd 563 2016 CONDUCTOR;40.0-121.0 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Com (in) 41.5 41.5 0.00 Casing 5 1/2"15.58 L-80 Hydril 563 Casing Cut off Jt recovered 4.950 Intermediate 8.33-ft stub GAS LIFT;2,523.7 73.0 73.0 0.00 Casing 5 1/2"15.58 L-80 Hydril 563 Casing 4.950 I 3,570.8 3,472.9_ 3.58 Casing 5 1/2"15.56 L-80 Hydril 563 Casing Pup 4.950 1 Intermediate 3,577.1 3,479.2 3.49 XO Reducing Crossover sub 5-1/2"Hyd-563 box x 4.094"National box 3.310 GAS LIFT;3,483.2 ,iii' 3,579.1 3,481.2 3.47 SBE Baker 80-32 SBE(4.094"National pin x pin) 3.250 3,588.5 3,490.6 3.37 XO Reducing Crossover sub 4.094"National box x 2-7/8"EUE pin 2.400 3,599.6 3,501.7 3.25 NIPPLE HES 2.313"X-Nipple 2.312 STABILIZER;3,536.2 - 3,694.3 3,596.2 2.49 XO Enlarging Crossover sub 2-7/8"EUE box x 3-1/2"EUE pin 2.440 SLEEVE;3,5373 Ii.�I 3,695.9 3,597.8 2.49 LOCATOR Baker Locator Spaced out 3'off Fully Located total length 3.000 STABILIZER;3,541.4 / of seals 11.77' PI 3,696.8 3,598.7 2.49 SEAL ASSY Baker Seal Assy 2.920 GAUGE;3,552.9 _i 3,6992 3,601.1 2.48 PBR Baker 80-40 PBR SHEARED 4.000 3,711.9 3,613.8 2.46 PACKER Baker 3-1/2"x 7-5/8"FHL Retrievable Packer 40k shear 2.430 release LOCATOR;3,572.9 3,719.3 3,621.2 2.45 XO Reducing Crossover sub 3-1/2"EUE box x 2-7/8"EUE pin 2.420 3,731.0 3,632.8 2.43 NIPPLE Camco 2 7/8"2.25"D Nipple 2.250 00 Reducing;3,577.1 SEAL ASSY;3,5740 3,738.7 3,640.6 2.42 WEG WLEG Muleshoe 2.441 SBE;3,579.1 y Tubing Description (String Ma...IID(in) (Top(ftKB) Set Depth(ft..JSet Depth(ND)(...I Wt(IbMt) 'Grade (Top Connection 4 TUBING RWO 2016 2 7/8 2.441 41.5 3,584.81 3,486.91 6.501L-80 EUE XO Reducing;3,588.5 * Completion Details Nominal ID NIPPLE;3,599.6 _ Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 41.5 41.5 0.00 HANGER FMC TC-1A-EMS w/3-1/2"EUE-8rd Pup Joint 2.900 44.8 44.8' 0.00'XO Reducing 3-1/2"8rd x 2-7/8"8rd X-O 2.992 3,536.3 3,438.4 5.02'STABILIZER Fluted Wire Protector Sub 2.441 GAS LIFT;3,644.0 3,537.3 3,439.5 4.97 SLEEVE 2-7/8"CMU Sliding Sleeve(w/2.313"BX-nipple Profile) 2.312 3,541.4 3,443.6 4.80'STABILIZER Fluted Wire Protector Sub 2.441 3,552.9 3,455.0 4.32 GAUGE SLB Special Clearance Gauge Mandrel(EUE-8rd pin x 2.388 pin)S/N 5939 XO Enlarging;3,694.3 f 3,573.0 3,475.0 3.53 LOCATOR GBH-22 Locator Sub 2.441 LOCATOR;3,6959 111.. 3.574.0 3,476.1 3.52 SEAL ASSY Baker 80-32 Seal Assembly 2.441 SEAL ASSY;3,696.8 Tubing Description (String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth( D)(...Wt(lb/ft) Grade Top Connection PBR;3,699.2 1 A3-SAND I 41/2 3.958 3,853.8 3,968.0 N3,869.7 12.60 L-80 IBT PACKER,3,711.9 ...• 'e... STRADDLE PATCH XO Reducing;3,719.3 Completion Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Das Com (in) 3,853.8 3,755.6 2.22 SLEEVE "HR"LINER SETTING SLEEVE 5.250 NIPPLE;3,731.0 3,866.8 3,768.5 2.21 NIPPLE "RS"PACK OFF SEAL NIPPLE 4.250 WEG;3,738.7 �.. 3,884.6 3,786.4 2.20 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 3,940.6 3,842.3 2.15 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 --• 3,967.3 3,869.0 2.13 WLEG WIRELINE ENTRY GUIDE 4.000 (PERF;3,750.03,780.0 Perforations&Slots -_ Shot (PERF;3,810.0.3,840.0 Dens Top(ND) Btm(TVD) (hots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com SLEEVE,3,853.8 3,750.0 3,780.0 3,651.9 3,681.8 WS D,10- 1/31/1998 4.0 IPERF 21/8"EJ BH;0 deg. 121 phasing NIPPLE;3,866.8 3,810.0 3,840.0 3,711.8 3,741.8 WS B,10- 1/29/1998 4.0 IPERF 2 1/8"EJ BH;0 deg. 121 phasing 3.902.0 3,932.0 3,803.7 3,833.7 WS A3,10- 2/17/1998 0.0 PATCH PATCHED OVER 121 w/WORKOVER PACKER;3,884.6INII 10/7/2008 3.980.0 4,010.0 3.881.7 3,911.7 WS A2,10- 1/21/1998 4.0 IPERF 21/8"EJ BH 121 PATCH;3,902.03,9320-+ Mandrel Inserts St ah on Top(ND) Valve Latch Port Size TRO Run PACKER;3,940.611+11 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3 3,644.0 3,546.0 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/30/2016 this in the 5 1/2 WLEG;3,9672 MI liner 1 2,523.7 2,484.4 Camco KBMG 1 GAS LIFT GLV BK-5 0.188 1,469.0 5/10/2016 (PERF;3,980.0-4,010.0 _ 2 3,483.2 3,385.6 Camco KBMG ' 1 GAS LIFT OV BKO-3 0.313 0.0'5/10/2016 Notes:General&Safety End Date Annotation 12/6/1997 NOTE'MONOBORE PRODUCER SURFACE;402-4402.0 0 KUP IND 1D-121 ConocoPhillips -:• DOM Alaska,Inc. L o cP„rI p 10-121,5/1912016 6.4828 AM Vertical schematic(actual)1. �1 I If Notes:General&Safety End Date Annotation HANGER;ms IV 12/6/2006 NOTE:WORKOVER#1 00Reducine;44.6 i 10/7/2008 NOTE:WORKOVER#2 3/2/2009 NOTE:View Schematic w/Alaska Schematic9.0 11/24/2009 NOTE:3 WELDED SPOTS ON PUMP HOUSING FROM 2.90"TO 2.83" 11 7/6/2011 NOTE:WO#3 TBG RKB GREATER THAN SURF CSG RKB DUE TO DIFFERENT RIGS CONDUCTOR;40.0-121.0 1/22/2014 NOTE:WORKOVER-2014 5/13/2016 NOTE: GLVs in two strings causes station numbering in mandrel section to be out of order. it GAS LIFT;2,523.7 I: li ilIl GAS LIFT;3,483.2 - t IR I STABILIZER;3,538.2 SLEEVE;3,537.3 illi STABILIZER;3,541 4 = _ GAUGE;3,552.9 LOCATOR;3,572.9 IM XO Reducing;3,577.1 SEAL ASSY;3,574.0 SEE;3979.1 } et XO Reducing;3,588.5 NIPPLE,3,599.6 ii GAS LIFT;3,644.0 E I St XO Enlarging,3,694.3 ■ LOCATOR,3,895.9 AB SEAL ASSY;3,896.8 PER,3,699.2 PACKER;3,711.9 XO Reducing;3,719.3 NIPPLE;3,731.0 WEG;3,738.7 IPERF;3,750.93,780.0 IPERF;3,810.0-3,840.0—. SLEEVE;3,853.8 NIPPLE;3,868.8 PACKER;3,884.6 PATCH;3,902.03,932.0 PACKER;3,940.6 WLEG;3,987.2 IPERF;3,980.0-4,010.0—. 9 [1 SURFACE;40.2-4,402.0 J L OF T • • e ,,,,,,y,,-,„ THE STATE Alaska Oil and Gas �k' '1 ��-"-9IOf/` T /\ K /� Conservation Commission�� � nLnJJL\.1"�W114 ttsif333 West Seventh Avenue Milimir- l't'.', Main: BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 gip ---.a ^,St'.',SP . - Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Kane Sr. Well Engineer ConocoPhillips Alaska, Inc. • t P.O. Box 100360 SCOA6 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-121 Permit to Drill Number: 197-181 Sundry Number: 316-224 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ia)...e_ it Cathy P oerster Chair DATED this 13 day of April, 2016. RBDMS 1I, APR 1 4 2016 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 7 2016 APPLICATION FOR SUNDRY APPROVALS 01-3 44/3//.G 20 AAC 25.280 C AGCC 1.Type of Request: Abandon ❑ Plug Perforations ElFracture Stimulate ElRepair Well El, Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 2 ChangeLLApproved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing E _ Other:th✓9 /-G Cs L 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑✓ - 197-181 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22814-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1D-121 ' Will planned perforations require a spacing exception? Yes ❑ ❑No I 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025650 - Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): / Plugs(MD): Junk(MD): 4414' • 4315' - 3922'- 3824'. 1515 ,,,/- none none Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121' Surface 4358' 7.625" 4401' 4302' Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3750'-3780' , 3652'-3682' 4.5" L-80 3968' 3810'-3840' _ 3712'-3742' 3902'-3932' 3804'-3834' 3980'-4010' , 3882'-3912' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: none PACKER-VIKING ESP FT PACKER,4-1/2"12.6#VAM BXP(SN:VCT-PO-10- , MD=1931 TVD=1929 PACKER-BAKER PREMIER PRODUCTION PACKER MD=3885 TVD=3786 PACKER-BAKER PREMIER PRODUCTION PACKER .MD=3941 TVD=3842 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/16/2016 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Daniel Kane @ 265-6048 _ Email Daniel.Kane@conocophillips.com Printed Name Daniel Kane 265-6048 Title Sr.Wells Engineer Phone Signature Date C-45-4---PP2.-ZC�(4:3COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: k - 224{ Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: 00 rtS L •-D 257.)C)p5,9 fZ5 GO �5-c 4k)vlvIar pre✓r,,*Er ,- o / Post Initial Injection MIT Req'd? Yes ❑ No It-'- RBDMS 1.-t, APR 1 4 2016 Spacing Exception Required? Yes ❑ No / Subsequent Form Required: it - it, 41' / A ' � APPROVED BY / _` Approved by:A PJGJ ! 7i. I SIONER THE COMMISSION Date: — g and Forrr 0 e- eu I u015 .1 ilio l n id fvr 12 uwntlra Guru the dale of aiprvval. Attachments in Duplicate l�TL 4/Z/16 I& HI lc • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 APR 0 7 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC AOGCC April 7th,2016 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover West Sak Producer KRU 1D-121 (PTD# 197-181). Well 1D-121 was spudded and completed in 1997 as a West Sak A-,B-,&D-sand ESP producer. The ESP completion failed in 2002 & the well was temporarily converted to a single-casing gas-lifted producer. In 2005, the well was shut-in for adjacent drilling operations & after being brought back online was unable to produce at prior rates. Additionally,after surface casing corrosion was found on some West Sak single casing wells in 2006,ConocoPhillips no longer allowed gas-lift on 1D-121 as a precaution and a rig work-over was performed in 2006 to re-complete the well with another ESP completion. Since that first work-over, an additional four workovers have been performed to date (five total) all because of downhole ESP component failures. The last ESP completion—installed in October 2015—failed after only 15 days. / Because of 1D-121's propensity for breaking ESP completions,the well was placed on the RWO schedule to convert it to a gas-lifted producer with future jet-pump production optionality. The proposed scope of this RWO consists of pulling the entire existing ESP completion,swapping the wellhead to allow placing an additional casing string,running a 5-'/2"inner casing string with a production packer on bottom,and running a 2-7/8"upper completion to swap the well over to gas-lifted production.J This Sundry is intended to document the proposed work for KRU 1D-121 because of the intent to repair the well,pull tubing, &alter the casing as well as to request approval to workover this well. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kane@conocophillips.com. Sincerely, drat Danny Kane Wells Engineer CPAI Drilling and Wells • KRU 1D-121 Proposed Rig Workover ConocoPhillips Pull ESP, Install Inner Casing String & Gas Lift Completion Original PTD #:197-181 Alaska CURRENT STATUS: KRU 1D-121, a West Sak A-, B-,& D-sand producer, is currently shut-in because of a failed TTC-ESP completion that was recently installed in October 2015. Given the frequent rig work-overs performed on this well for ESP completions(multiple styles),the planned work-over will install an additional casing string to allow the well to be converted to gas-lift as well as to set-up for contingent jet-pump production if needed in the future. Please see below for a history of the well&annuli integrity diagnostics: - 1997—KRU 1D-121 was drilled &completed as West Sak packer-less TC-ESPCP producer. - 2002—ESP completion failed. The well was converted to single-casing gas-lifted producer. - 2003—The well began freezing off&was placed on long-term shut-in. - 2005—The well was brought online,shut-in for adjacent drilling operations, &then would not produce at former rates. o February—Well was brought online. Intermittent production with freezing issues. o September—Well was shut-in for one month for adjacent drilling operations. Upon being brought back online,the well could not be brought back-up to previous production rates. With recent discovery of shallow surface-casing corrosion on 1D West Sak wells,single- casing gas-lift was no longer allowed. Well added to RWO list. - 2006—Surface casing inspected & RWO#1 performed. o September—Surface excavation to inspect for surface casing corrosion. Maximum 20%wall- loss found with surface casing in overall good condition. o December—Rig work-over swapped well to 3-'/2"TTC-ESPCP completion. - 2007—Production suddenly cut in half;sand production plugged ESP completion. - 2008—TTC-ESPCP completion fails& RWO#2 performed. o July—ESP completion fails as a result of a downhole short. o September—Rig work-over pulled &replaced 3-1/4'TTC-ESPCP completion. Pre-rig well work found significant frac sand/fill on top of the ESP pump. A clean-out was performed during the RWO&casing damage was found at the top of the A3 sand perfs. The casing damage was isolated with a straddle-packer assembly prior to installing the new TTC-ESPCP completion. - 2010—TTC-ESPCP completion downhole motor fails(shaft sheared). - 2011—RWO#3 performed to swap to Wireline ESP(WLESP) completion. - 2013—WLESP wireline-retrievable completion pulled after the new technology proved to be unreliable(longest production run of 4 months). - 2014—RWO#4 performed to swap to TTC-ESPCP completion. - 2015—TTC-ESPCP completion fails& RWO#5 performed to swap to TTC-ESP completion. o May—ESP completion fails as a result of a downhole short. o October—Rig work-over performed to swap to TTC-ESP completion. o December—ESP completion fails as a result of a downhole short. Page 1 of 3 • • KRU 1D-121 Proposed Rig Workover ConocoPhillips Pull ESP, Install Inner Casing String & Gas Lift Completion Alaska Original PTD #:197-181 SCOPE OF WORK: The objective of this proposed RWO will be to pull the existing TTC-ESP completion and set the well up for gas-lift production with jet-pump production optionality. The scope of the proposed RWO will be to pull the entire existing 4-1/2"TTC-ESP completion, replace the wellhead to accommodate an additional casing string, run a 5%"inner casing string with a production packer at the base to place above the producing sands, and run a new 2-%8" upper completion to bring the well back on gas-lifted production. ✓ GENERAL WELL INFO: Well Type: West Sak A-, B-,&D-sand Producer. MPSP: 1,515 psig using MPSP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,515 psig=(1,893 psig—(0.1 psig/ft *3,781'TVD)) Reservoir Pressure/TVD: West Sak Mid-Perfs—1,893 psig/3,781'TVD(9.7 ppg EMW) Using last recorded downhole gauge pressure. Wellhead Type: Vetco Gray West Sak Multibowl Gen I (5M Tubing Head) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/2,500 psig(Rams&Annular) MIT Results: MIT-T Passed 11-Oct-2015 End of 2015 RWO MIT-IA Passed 11-Oct-2015 End of 2015 RWO Earliest Start Date: 16-Apr-2016 Production Engineer: Scott Stanley Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com SUMMARY OF PROPOSED RWO PROCEDURE: Completed&Proposed Pre-Rig Work: 1. Function-tested all T LDS. Perform POT& PPPOT on the T pack-offs. 2. Pull GLM#1 DVs&leave pockets open for RWO well kill. 3. Set BPV prior to rig arrival. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Reverse circulate KWF&then bullhead down the tubing. Allow fluid to swap below feed-thru ESP packer. Repeat circulation. Obtain SITP & SICP, if still seeing pressure at surface, repeat previous two-stage circulation allowing fluid to swap through feed-thru ESP packer. Obtain SITP&SICP, if still seeing pressure at surface, calculate new KWF& repeat circulation as necessary. Perform a 30-minute flow check on the TxIA to confirm the well is static. fi« 3. Set BPV, ND tree,set the blanking plug, NU BOPE, &test BOPE to 250/2,500 psig low/high. +, ,4-o 4 L C 4. Pull the blanking plug, pull the BPV,screw in landing joint, BOLDS, &unseat the tubing hanger. 5. P/U on the 4-1A"tubing, pull the feed-thru ESP packer free, and pull the tubing hanger to the rig floor. 6. Verify the well is static&TOH laying down the 4-%" ESP completion. 7. TIH &set a bridge plug at 1,000' MD within the 7-%"casing. Pressure-test to 1,000 psig from above. 8. TIH &set a bridge plug at 500' MD within the 7-%" casing. Pressure-test to 1,000 psig from above. Page 2 of 3 • • KRU 1D-121 Proposed Rig Workover ConocoPhillips Pull ESP, Install Inner Casing String & Gas Lift Completion Original PTD #:197-181 Alaska 9. ND existing Vetco Gen I wellhead. Cut-off surface casing mandrel hanger. NU new slip-on transition nipple, weld as per procedure, &NU new FMC wellhead. 10. TIH & retrieve the bridge plug at 500' MD. 11. TIH &retrieve the bridge plug at 1,000' MD. 12. M/U&TIH w/the 5%"inner casing string with sealbore extension crossed over to a sealbore assembly/PBR& production packer. 13. With the packer on setting depth,spot corrosion-inhibited kill-weight fluid into the IA from above the existing to just above the production packer. 14. With the packer on setting depth, drop the ball & rod, & pressure-up to 2,000 psig to set the stacked packer. Bleed the tubing pressure & pressure-test the IA to 2,500 psig for 5 minutes to verify the packer has set properly. 15. P/U to shear the seal assembly out of the PBR on top of the stacked packer. Sting the seal assembly back into the PBR,space-out three feet from fully-located, mark the pipe, &lay-down two 5-Y2"casing joints. 16. Space-out with 5-1/2"casing pups and M/U the casing hanger&landing joint. 17. Shut-in the annular on the 5-Y2" casing and reverse-circulate corrosion-inhibited seawater chased by diesel to freeze protect the 7"x 5%" annulus while taking returns up the 5-Y2" casing. 18. While stripping down through the annular, sting the seal assembly into the PBR, land the 5-Y2" casing hanger, & RILDS. 19. Pressure-test the 7" x 5-A" annulus to 2,500 psig for 30 minutes while monitoring the 5-Y2" casing for returns. Pressure-test the 5-Y2" casing hanger pack-offs to 4,000 psig. 20. M/U &TIH w/the new 2%8" upper completion to just above the SBE at the base of the 5-%" casing. 21. Sting the seal assembly into the SBE until fully-located, space-out three feet, mark the pipe at surface, & lay- down two tubing joints. 22. Space-out with tubing pups and M/U tubing hanger and landing joint. 23. Spot corrosion-inhibited kill-weight fluid into the 2-%8"x 5-Y2"annulus by pumping down the tubing. 24. Sting the seal assembly into the SBE, land the tubing hanger, & RILDS. 25. Pressure-test the tubing to 3,000 psig&the 3%"x 5-Y2"annulus to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 26. Back-out the landing joint&install BPV. er1 27. ND BOPE, NU tree, install tree test plug, & pressure test tree. 28. Freeze protect the well through the SOV. 29. Set BPV. 30. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. Pull the ball& rod from the RHC plug body set within the 2.25" D Nipple(tubing tail). 3. Install the GLD as planned. 4. Pull the RHC plug body set within the 2.25" D Nipple(tubing tail). 5. Reset well house(s)& re-attach flow line(s). 6. Turn well over to operations. Page 3 of 3 KUP PROD 0 1D-121 ConocoPhillis Well Attributes Max Angle&MD TD e Alaska,Inc. ,. Wellbore API/UWI Field Name Wellbore Status Incl(°i MD(ftKB) Act atm(HK$) ,,,,,...,,," 500292281400 WEST SAK PROD 26.17 2,427.85 4.414.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-121.2/1020164:4756 PM 55SV:NONE 5 11/10/2014 Last WO: 10/6/2015 12/6/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 3.922.0 1/4/2014 Rev Reason:GLV CIO,PULLED ESP 8 SUP- pproven 2/10/2016 STOP.REMOVED ISO(10/26/2015) Casing Strings ----.---- 1- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD),.. Wt/Len(I...Grade Top Thread __. .. CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H40 WELDED HANGER:41S Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread a E[. SURFACE 75/8 6,750 40.2 4.402.0 4.303.4 29.70 L-80 BTCM 4 Tubing Strings Tubing Descriphon Stang Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)I...Wt(Iblft) Grade Top Connection N�CONDUCTOR:40.0-121.0 • t TUBING-W02015 41(2 3.958 41.5 3.693.8 3.595.7 1260 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(n) Item Des Com (in) GAS LIFT tA418 41.5 41.5 0.00 HANGER VETCO TUBING HANGER 3.958 1,931.3 1,929.21 10.04 PACKER Viking ESP FT Packer.4-1/2"12.68 Vam BSP(SN:VCT- 3.878 PO-10-222-2) 3,596.5 3.498.6' 3.28 GAUGE SLB PHOENIX DISCHARGE GAUGE UNIT 3.875 3.654.7 3.556.6 2.66 ESP INTAKE BAKER TTC RECEIVER W/PERFORATED INTAKE 3.665.2 3.567.1 2.55 SEAL BAKER TANDEM SEAL SECTION 3.679.0 3.580.9 2.52 ESP MOTOR BAKER ESP MOTOR PACKER;1.9318 3.690.0 3.591.9 2.50 GAUGE SLB PHOENIX MOTOR GAUGE 3.691.9 3.593.8 2.50 CENTRALIZE BAKER MOTOR CENTRALIZER R i, Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(kJ Set Depth(TVD)(...WI(lb/ft) Grade Top Connection A3-SAND 412 3.958 3,853.8 3.968.0 3.869.7 12.60 L-80 IBT STRADDLE PATCH Completion Details GAS LIFT.2.021,9 Nominal ID Top(HKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 3.853.8 3,755.6 2.22 SLEEVE "HR"LINER SETTING SLEEVE 5.250 3.866.8 3,768.5 2.21 NIPPLE "RS"PACK OFF SEAL NIPPLE 4.250 3,884.6 3,7864 2.20 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 GAS LIFT:3.544.4 3.940.6 3.842.3 2.15 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 3.967.3 3.869.0 2.13 WLEG WIRELINE ENTRY GUIDE 4.000 Perforations&Slots shot ;t Dens GAUGE.3,5965 ei Top(TVD) Blot(TVD) (shote F Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn n 3,750.0 3,780.0 3,651.9 3,681.8 WS D.10-121-1/31/1998 4.0 IPERF 21/8"EJ BH;O deg. phasing 3,810.0 3.840.0 3,711.8 3,741.8 WS B,1D-121 1/29/1998 4.0 IPERF 2 1/8"EJ BH:0 deg. phasing 3,902.0 3,932.0 3,803.7 3,833.7 WS A3,ID- 2/17/1998 0.0 PATCH PATCHED OVER 121 w/WORKOVER ESP INTAKE 3,654.7 Il i 10/72008 SEAL:3.665.2 3,980.0 4,010.0 3,881.7 3,911.7 WS A2,10- 1/21/1998 4.0 IPERF 2 1/8"EJ BH ESP MOTOR;3.679.0 121 GAUGE;3,690.0 , Mandrel Inserts at CENTRALIZER;3,6918 ) of Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(m) Sery Type Type (In) (psi) Run Date Com 1 1.841.8 1,840.7 CAMCO KBMG 1 GAS LIFT OPEN 2/6/2016 .•.• r.- 2 2,021.9 2,017.9 CAMCO KBMG 1 GAS LIFT 'OPEN 2/6/2016 IPERF.J750.0-3780.0F 3 3,544.4 3.446.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/4/2016 20008 y Notes:General&Safety End Date Annotation e. 12/6/1997 NOTE.MONOBORE PRODUCER IPERF:3,810.0-3,840.0 ..-is ie.-. 12/6/2006 NOTE:WORKOVER#1 10/712008 NOTE:WORKOVER#2 SLEEVE.3.853.0 3/2/2009 NOTE'View Schematic w/Alaska Schematic9.0 NIPPLE;3,8668 11/24/2009 NOTE'3 WELDED SPOTS ON PUMP HOUSING FROM 2.90"TO 2.83" 7/6/2011 NOTE:WO#3 TBG RKB GREATER THAN SURF CSG RKB DUE TO DIFFERENT RIGS 1/22/2014 NOTE:WORKOVER-2014 PACKER,3884.64-a • PATCH.3,902.0-3,932.0- PACKER.3,941.6 7 WLEG.3567.2, IPERF;3,980 0-4,010.0- 1 SURFACE 40.2-4,402.0 • 0 • ConocoPhilli ps 1D-121 As-Planned s . 121' MD, 16"62.5#, H-40 2'/e" 6.5#L-80 EUE-8rd f , -4— 2-'/8" x 1" Camco KBMG GLM 4 1 F B 6 imp 4 2-'/a"x 1" Camco KBMG GLM 4 i i i 5-1/2" 15.5# L-80 Hydril 563 —IP- ' s i1 0 t Baker CMD Sliding Sleeve w/Camco 2.313" D-Nipple k x x M '1111- 2'/e" x 1" Camco KBMG GLM 27/8" Schlumberger Gauge Mandrel 3 C R i s , 4.1111 f— Baker 80-32 SBE f— Baker 3-1/2" x 7-%" FHL Packer cif— Camco 2.25" D-Nipple 3750'-3840' MD,West Sak D-and B-Sand Perforations a� -4 — HR Setting Sleeve and RS Pack Off Seal Nipple - 4 4-1/2"x 7-%" Baker Premier Packer 3902'-3932' MD,West Sak A3- Sand Perforations - f--4-1/2" x 7-%" Baker Premier Packer 1511 3980'-4010' MD,West Sak A2- 'f—Wireline Entry Guide Sand Perforations 4402' MD,7-%"29.7#, L-80 Date: January 27,2016 1 Drawn By: Travis Smith STATE OF ALASKA AiIL OIL AND GAS CONSERVATION COM ION - • REPORT OF SUNDRY WELL OPERATIONSti/491,4-1 1.Operations Abandon n Plug Perforations Fracture Stimulate n Pull/* Operations Shutdown E. Performed. Suspend Perforate E Other Stimulate Alter Casing g I— Change Approved Program Plug for Redrill r Perforate New Pool Repair Well r Re-enter Susp Well rOther: E 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory fl 197-181 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22814-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 KRU 1D-121 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 4414 feet Plugs(measured) None true vertical 4315 feet Junk(measured) None Effective Depth measured 4313 feet Packer(measured) 1931,3885,3941 true vertical 4214 feet (true vertical) 1929,3786,3842 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 0 0 SURFACE 4362 7.625 4402 4303 0 0 RECEIVED Perforation depth: Measured depth: 3750-3780,3810-3840,3902-3932,3980-4010 C� i.y� True Vertical Depth: 3652-3682,3712-3742,3804-3834,3882-3912 ?A 6� J .{i <,r.,043NOV 0 2015 AOGCC Tubing(size,grade,MD,and TVD) 4.5, L-80,3694 MD,3596 TVD Packers&SSSV(type,MD,and ND) PACKER-VIKING ESP FT PACKER,4.5 @ 1931 MD and 1929 TVD PACKER-BAKER PREMIER PRODUCTION PACKER @ 3885 MD and 3786 ND PACKER-BAKER PREMIER PRODUCTION PACKER @ 3941 MD and 3842 ND no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE 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 Shut-In Subsequent to operation Shut-In _ 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory fl Development F Service r Stratigraphic FT Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL Printed and Electronic Fracture Stimulation Data FT GSTOR FT WINJ WAG FT GINJ r 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 or Sundry Number required here Contact Travis • 265-6451 Email Travis.T.Smith@conocophillips.com Printed Name r. is Smith / / Title Wells Engineer Signature 404 Phone:265-6450 Date // � �� Form 1�� 14 Revised 5/2015, V 7 /y`' 1"5 RBDMS�,NOV 10 2015 Submit Original Only • • Az Daily Operations Summary 1D-121 +Conoiillips Rig: NABORS 9ES Job: RECOMPLETION Daily Operations Start Data ` Last 24fir Sum 10/6/2015 Move pits away from the sub and move the sub off well 1 D-116. Spot the sub over well 1 D-121. Spot the pits to the sub. Finish rig acceptance checklist and accept the rig at 01:00 hours. Load the pits with 300 bbls of 9.7 ppg brine with 3%KCI. RU lubricator,PT to 1000 psi(good test), pull BPV,and RD lubricator. RU circulating equipment for well kill operation. Test hard line with air and PT hard line with water to the kill tank to 3500 psi(good test). Attempt to kill the well with 9.7 ppg brine with 3%KCI.Final pressures: SITP= 138 psi and SICP=88 psi. Wait for 12.0 ppg NaBr spike fluid to arrive to make new 10.4 ppg KWF while monitoring the well. 10/7/2015 Weight up 9.7 ppg brine with 12.0 ppg NaBr spike fluid to 10.4 ppg brine with 3%KCI while monitoring the well. Reverse circulate 123 bbls of 10.4 brine down the IA taking return up the tubing out to the kill tank at 2 BPM. Got 10.4 ppg brine at surface. Observe the well for flow for 30 minutes, well static. Install BPV with dry rod. ND the tree. Inspect the tubing hanger lift thread and install test dart. NU the BOP stack. Conduct initial BOPE test to 250/2500 psi: test 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2"and 4-1/2"test joint;test annular to 250/3000 with 3-1/2"and 4-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Johnnie Hill via email on 10/6/15 at 12:32 hours.RU GBR tubing tongs. RU ESP cable sheave in the derrick and attach hose. Pull test dart,check for pressure under BPV,and there is gas below BPV. Bullhead 32 bbls down the tubing,check for under BPV,and still have gas below BPV. Line up to circulate and bring the pumps up to 0.5 BPM to fill the gas buster. 10/8/2015 Circulate 78 bbls down the tubing up the IA through the gas buster at 2 BPM. Check for pressure under BPV,no pressure,pull BPV,and install side port isolation sleeve. Screw the TD into the landing joint,unseat the tubing hanger at 125K,and continue to PU to shear the Viking packer at 150K. Circulate out the gas that was below the packer at 3 BPM. Monitor the well for flow for 10 minutes,well on a slight vac. Pull tubing hanger to the rig floor and lay down tubing hanger. Well out of balance;circulate surface to surface at 10 BPM. Monitor the well for flow for 10 minutes, still have gas breaking out at surface. Circulate bottoms up at 2 BPM. Monitor the well for flow for 10 minutes,well on a slight vac. POOH with feed-thru pack ESP completion standing back 4-1/2"tubing and laying down 3-1/2"tubing. Lay down ESP equipment. Unload pulled ESP cable and load new ESP cable into spooling unit. 10/9/2015 MU SLB Phoenix gauge to motor gauge unit. PU, MU,and service ESP assembly. PU first stand of 4-1/2"tubing from the derrick and the string took weight. Test on the ESP cable failed. PU and found the armor on the ESP cable was damaged due to the cable was on the belly of the GLM and contacted the BOP stack. PU to the ESP motor splice,cut splice,re-splice the ESP cable,and test ESP cable. RIH with stands of 4-1/2" tubing from the derrick spooling ESP cable and installing cannon clamps to 253'RKB at midnight. 10/10/2015 Continue to RIH with stands of 4-1/2"tubing from the derrick spooling ESP cable,installing cannon clamps,and testing the ESP cable every 1000'. PU and MU Viking packer.Cut ESP cable and MU splices to the top and bottom of the Viking packer. Test ESP cable(good test).Continue RIH with remaining 16 stands of 4-1/2"tubing from the derrick and 9 single joints of 4-1/2"tubing from the pipe shed. MU landing joint and MU tubing hanger. Install ESP cable penetrators into the tubing hanger. Assembly lower ESP cable connector. 10/11/2015 Continue to assembly lower ESP cable connector. Connect ESP cable connector to ESP cable penetrators in the tubing hanger and test ESP cable. Land the tubing hanger and RILDS. Bullhead 45 bbls corrosion inhibited brine followed by 48 bbls of brine down the IA. Pressure up to set the Viking packer, PT the tubing to 2500 psi for 15 minutes and PT the IA to 1500 psi for 30 minutes. Pressure up and shear the SOV. Install TWC and Pressure up on the IA to 1000 psi to test the TWC from below in the direction of flow for 5 minutes. Perform CPAI BOPE inspection per CPAI Between Well Maintenance(BWM)program. ND the BOP and NU the tree. PT the tree to 250/5000 psi and pull the TWC. Freeze protect the well with 85 bbls of diesel and install BPV. Secure the well and release the rig at 23:59 hours. Page 1/1 Report Printed: 11/3/2015 a KUP PROD1110 1D-121 ConocoPhillips s Well Attributes Max Angle&MD TD Alaska. S Wellbore API/UWI Field Name Wellbore Slates Inel(°) MD MKS) Act Btm(ftKB) r• ,,xot.o;,rv63,is 500292281400 WEST SAK PROD 26.17 2427.85 4,414.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(H) Rig Release Date 1D-121.;.10129/20152;09.in PM SSSV:NONE 5 11/10/2014 Last WO: 10/6/2015 12/6/1997 Vertlaal Schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 3,922.0 1/4/2014 Rev Reason:GLV C/O.SET ESP and SLIP- pproven 10/29/2015 STOP Casing Strings . J N Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED HANGER:41.5 ': '',, CasingDescription OD(in) ID in TopftKB Set Depth ftKB Set Depth(TVD)...WtlLen(I...Grade TopThread P l ) ( ) P (ftKB) P ( ) SURFACE 75/8 6.750 40.2 4,402.0 4,303.4 29.70 L-80 BTCM Tubing Strings 'Mt CONDUCTOR',40.0-121.0 1"'Tubing Description String Ma...ID(in) Top(HKB) (Set Depth(9...Set Depth(TVD)(...IWI(Ib/It) (Grade 1Top Connection Completion 5 41;9 3.958 41.5 3.693.8 3,595.7 12.60 L-80 TAAC Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Intel(') Item Des Com (in) GAS LIFT,1,841.9 41.5 41.5 0.00 HANGER VETCO TUBING HANGER 3.968 1,931.3 1,929.2 10.04 PACKER Viking ESP FT Packer.4-1/2'12.6#Vam BxP(SN:VCT- 3.878 P0-10-222-2) 3,596.5 3,498.6 3.28 GAUGE SLB PHOENIX DISCHARGE GAUGE UNIT 3.875 1. 3,654.7 3,556.6 2.66 ESP INTAKE BAKER TTC RECEIVER W/PERFORATED INTAKE 3,665.2 3,567.1 2.55 SEAL BAKER TANDEM SEAL SECTION PACKER;1,931.3 3,679.0 3,580.9 2.52 ESP MOTOR BAKER ESP MOTOR ta 3,690.0 3,591.9 2.50 GAUGE SLB PHOENIX MOTOR GAUGE 3,691.9 3,593.8 2.50 CENTRALIZE BAKER MOTOR CENTRALIZER R Tubing Dandelion String Ma. ID(In) Top(HKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/t) Grade Top Connection ISO RSP;1,984.9 A3-SAND 41/2 3.958 3,853.8 3,968.0 3,869.7 12.60 L-80 IBT STRADDLE PATCH .11 Completion Details Nominal ID GAS LIFT;2.021.9 4 Top(ftKB) Top(TVD)(ftKB) Top Intl(1 Item Dee Com (In) 3,853.8 3,755.6 2.22 SLEEVE "HR"LINER SETTING SLEEVE 5.250 3,866.8 3,768.5 2.21 NIPPLE "RS"PACK OFF SEAL NIPPLE 4.250 3,884.6 3,786.4 2.20 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 3,940.6 3,842.3 2.15 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 cos u1=T.3,5x4./ 3,967.3 3,869.0 2.13 WLEG WIRELINE ENTRY GUIDE 4.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVDI Top Incl Top(ftKB) (ftKB( (') Des Com Run Date ID(en) 1,984.9 1,981.8 11.93 ISO RBP Weatherford ISO RBP:3.65'OD x 5.98'Long 10/11/2015 0.000 GAUGE,3,596.5 3,612.0 3,514.0 3.12 ESP TTC-ESP&4.5-Packof(100'OAL/36'to KOBE)& 10/27/2015 Set 4.5"Slip-Stop(20.5"OAL)on Packon...ESP 3620' ESP;3,612.0 '+T Perforations&Slots Shot Dena Top(TVD) Bim(TVD) (shofslf Top(ftKB) atm(ftKB) (ftKB) (HKB) Zone Date 1) Type Com 3.750.0 3,780.0 3,651.9 3,681.8 WS D,1D-121 1/31/1998 4.0 IPERF 21/8"EJ BH:Odeg. phasing ESP INTAKE;3,654.7 t i4i 3,810.0 3,840.0 3,711.8 3,741.8 WS B,1D-121 1/29/1998 4.0 IPERF 21/8"EJ BH;Odeg. SEAL.3.865.2 `x ` phasing ESP MOTOR.3,679.0 3,902.0 3,932.0 3,803.7 3,833.7 WS A3.10- 2/17/1998 0.0 PATCH PATCHED OVER GAUGE.3,690.0 -tom 121 w/WORKOVER 10/7/2008 CENTRALIZER;3,891.8 3,980.0 4,010.0 3,881.7 3,911.7 WS A2,1D- 1/21/1998 4.0 IPERF 21/8"EJBH 121 Mandrel Inserts IPERF;3.750.0-3,780.0- St ati on Top(TVD) Valve Latch Pon Slze TRO Run N Top(ftKB) (HKB) Make Model 00(in) Sery Type Type (In) (pal) Run Date Com 1 1,841.8 1,840.7 CAMCO KBMG 1-GAS LIFT OV BK 0.313 0.0 10/26/2015 IPERF.3,810.0-3.840.0- 2 ,810.0-3.840.0- 2 2,021.9 2,017.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/11/2015 SLEEVE,3,853.8 4 3 3,544.4 3,446.6 CAMCO KBMG - 1 GAS LIFT SOV -BK 0.000' 0.0 10/27/2015 20000 NIPPLE;3.888,8 Notes:General&Safety End Date Annotation 12/6/1997 NOTE:MONOBORE PRODUCER 12/6/2006 NOTE:WORKOVER#1 PACKER,3,884.8 10/7/2008 NOTE:WORKOVER#2 3/2/2009 NOTE:View Schematic w/Alaska Schematic9.0 11/24/2009 NOTE:3 WELDED SPOTS ON PUMP HOUSING FROM 2.90'TO 2.83" PATCH.3.902.9-3,932.0- I 7/6/2011 NOTE:WO#3 TBG RKB GREATER THAN SURF COG RKB DUE TO DIFFERENT RIGS 1/22/2014 NOTE:WORKOVER-2014 PACKER.3.540.6 'r"" I WLEG.3.967.2 , IPERF.3.980.0-4,010,0- e. SURFACE;40.2-4402.0 - ~ Pages NOT Scanned in this Well History File , XHVZE This page identifies those items that were not scanned during the initial scanning pr~ject. They are available in the original file and viewable by direct inspection. I q '1,- / g / File Number of Well History File PAGES TO DELETE RESCAN ,4// .~Olor items - Pages; Complete 0 Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original' - Pages: 0 0 Other.. Pages: DIGITAL DATA [) Diskettes, No. [J Other, NofType 'OVERSIZED [) ,Logs of various kinds [J Other COMMENTS: I Or 't~ scannedbyAMiIdn!d~reIhe Na1hanLoweIl Date.:3.5. ()J... Is! ~ 0 TO RE-SCAN t Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: 151 • • WELL LOG TRANSMITTAL I I. PROACTIVE DIAC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 N . , ? psi AUG ,c1 0 Z f U 1) Correlation Log 02- Jul -11 1D-121 1 CD 50- 029 - 22814 -Q iSr0 2) ) q 7A4 Signed : I\ , 14,, Date : a a E1 I Print Name: ..,, •1- C3 k l..f v,,3 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)2454952 E-MAIL : PDSANCHORAGEAMEMORYLOG.COM WEESITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmitialSheets \ConocoPhillips_Transmit.docx ( (7 7 - • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Wave Sonic: 1D-121 Run Date: 7/2/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -121 f � Digital Data in LAS format, Digital Log Image files , 0 1 CD Rom 50- 029 - 22814 -00 WaveSonic Field print 1 Color Log — 50- 029 - 22814 -00 r fi , WaveSonic Processed print 1 Color Log i 50- 029 - 22814 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 2-S0 (It() • • WELL LOG TRANSMITTAL PROACTIVE DiAgNOS7ic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 02- Jul -11 1D-121 1 Report/ 1 CD 50-029- 22814 -00 2) Signed : Date : eia, g � •S t l Print Name: R. w o,M 1 1 k w k J PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 - 8952 E -MAIL : PDSANCHORAGE(d MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhilhps_Transmit.docx / 9 1 • • Memory Multi-Finger Caliper Log Results Summary mart' Company: ConocoPhillips Alaska, Inc. Well: 1D -121 Log Date: July 2, 2011 Field: Kuparuk River (West Sak) Log No.: 10162 State: Alaska Run No.: 3 (2 x MTT, 1 x MIT) API No.: 50- 029 - 22814 -00 Pipet Desc.: 7.625" 29.7 Ib. L -80 Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvil.: 3,629 Ft. (MD) 1 Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : 1 Depths referenced to gamma ray on Western Atlas Multipole Accoustic Log dated December 3, 1997. This log was run to assess the condition of the 7.625" surface casing with respect to corrosive and ' mechanical damage, as well as to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate the 7.625" surface casing logged appears to be in good condition with ' respect to corrosive and mechanical damage. No significant wall penetrations or areas of cross - sectional wail loss are recorded throughout the 7.625" surface casing logged. Although no significant I.D. restrictions are recorded, the caliper recordings indicate mild buckling with slight areas of ovality from —430' to —750' and — 1,310' to —1,470'. An overlay of the centered and off - center caliper recordings highlighting the areas of mildly buckled 7.625" surface casing is included in this report. Although PDS has run a Magnetic Thickness Tool (MTT) twice in this well, this is the first time a PDS caliper has been run. MAXIMUM RECORDED WALL PENETRATIONS: 1 No significant wall penetrations (> 15 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall Toss (> 8 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the surface casing logged. 1 1 1 Field Engineer: E. Gustin Analyst: C. Waldrop Witness: L. Hinkel 1 ProActive Diagnostic Services, Inc. P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS4memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk River (West Sak) Well : 1D-121 Date : July 2, 2011 I Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing. Maximum I.D. Depth 3 -D Log (Off - Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) I 6 inches 8 1ft:700ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° Minimum I.D. 6 inches 8 I Nominal I.D. 6 inches 8 =. iJ ��...�``rr -- -.1... 50 _ II ���� = _ . 1 �..a..i��. _ - il __ ����111� 100 _ �. ______ �•��I������ 1•111111111111•11111111 15 0 lc 1 ... ■ ;1■■.1111 _ ■ EIMIIIMMINIENE 20 Mallalr1inallEll _ 1 ■...i1,u.... 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Nominal I.D. 6 inches 8 I Minimum I.D. i 6 inches 8 Maximum I.D. _ I Depth 3 -D Log (Off -Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) I 6 inches g 1ft:700ft I 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I I I • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 7.625 in (46.9' - 3601.3') Well: 1D-121 Field: Kuparuk River (West Sak) Company: ConocoPhillips Alaska, Inc I Country: USA Survey Date: July 02, 2011 I I Approx. Tool Deviation ■ Approx. Borehole Profile 1 49 1 10 428 I 20 845 1 30 1268 1 40 1677 - c Z s I c v a. 0 50 2098 — 1 60 2516 1 70 2935 I 80 3351 I 8 6 3601 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 86 I I I • • I PDS Report Overview T Body Region Analysis I Well: 1D-121 Survey Date: July 02, 2011 Field: Kuparuk River (West Sak) Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7.625 ins 29.7 ppf L -80 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 7.625 ins 29.7 ppf L -80 6.875 ins 7.625 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) 100 Penetration body 111• Metal loss body 0 50 100 80 0 60 C 40 10 C 1 20 E E 0 20 E 1 0 to 20 to 40 to 85% over 20% 40% 85% E Number of joints analysed (total = 87) 30 1 87 0 0 0 40 111 Damage Configuration ( body ) 10 50 : I AMOR MO 60 5 1 70 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 80 MIMI I Number of joints damaged (total = 1) 1 0 0 0 0 Bottom of Survey= 86 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in 29.7 ppf L-80 Well: 1D-121 Body Wall: 0.375 in Field: Kuparuk River (West Sak) I Upset Wall: 0.375 in Nominal I.D.: 6.875 in Company: ConocoPhillips Alaska, Inc Country: U Survey Date: July 02, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 47 0 0.02 5 1 6.90 Pup 1 49 0 0.04 11 1 6.84 2 92 U 0.03 7 2 6.83 3 137 0 0.02 6 2 6.84 4 180 () , 0.02 5 2 6.83 I 5 223 0 0.02 6 2 6.84 6 266 0 0.02 6 2 6.84 7 308 0 0.04 9 5 6.88 ■ 8 351 0 0.04 10 6 6.84 I 9 393 0 0.03 8 3 6.84 10 428 0 0.04 10 5 6.87 Slight Oval due to Mild Buckling. ■ 11 469 0 0.04 9 3 6.83 • 12 509 0 0.04 12 5 6.84 Slight Oval due to Mild Buckling. ■ I 13 552 0 0.04 10 4 6.82 Slight Oval due to Mild Buckling. ■ 14 590 0 0.04 11 3 6.86 Slight Oval due to Mild Buckling. ■ 15 633 0 0.04 12 3 6.85 Slight Oval due to Mild Buckling. • 16 675 0 0.04 11 6 6.86 ■ 17 717 0 0.04 10 5 6.84 Slight Oval due to Mild Buckling. 18 759 0 0.03 9 2 6.82 19 802 0 0.04 12 5 6.81 II 20 845 0 0.04 10 4 6.79 ■ 21 887 0 0.04 10 3 6.82 ■ I 22 929 0 0.04 11 0 6.81 23 970 0 0.03 7 2 6.85 24 1013 0 0.03 7 2 6.87 25 1057 0 0.03 9 2 6.83 I 26 1099 0 0.03 7 2 6.82 27 1138 0 0.03 9 2 6.82 R 28 1181 0 0.04 11 2 6.86 ■ 29 1225 0 0.04 11 3 6.84 I 30 1268 0 0.03 8 3 6.83 31 1309 0 0.05 12 3 6.84 Slight Oval due to Mild Buckling. ■ 32 1352 0 0.04 11 4 6.82 Slight Oval due to Mild Buckling. ■ 33 1393 0 0.04 12 3 6.84 Slight Oval due to Mild Buckling. ■ 34 1432 0 0.04 10 3 6.84 Slight Oval due to Mild Buckling. ■ I 35 1472 0 0.04 11 3 6.81 36 1515 0 0.03 7 2 6.82 37 1556 0 0.02 6 1 6.88 38 1594 0 0.03 7 2 6.84 I 39 1635 0 0.03 8 1 6.84 40 1677 0 0.02 6 1 6.84 41 1719 0 0.03 7 2 6.86 42 1762 0 0.02 6 2 6.84 I 43 1805 0 0.03 7 2 6.80 43.1 1846 0 0 0 (1 6.78 TAM Port Collar 44 1849 0 0.03 9 1 6.86 45 1891 0 0.02 5 2 6.87 I 46 1934 0 0.02 6 2 6.84 47 1974 0 0.03 7 2 6.83 48 2016 0 0.02 5 2 6.84 d I Metal Loss Penetration BoBody y Page 1 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.62 5 in 29.7 ppf L-80 Well: 1D-121 Body Wall: 0.375 in Field: Kuparuk River (West Sak) I Upset Wall: 0.375 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in Country: USA Survey Date: July 02, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I. D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 2056 0 0.03 7 2 6.83 50 2098 0 0.02 6 2 6.87 51 2140 0 0.02 5 1 6.83 52 2183 0 0.06 15 2 6.85 Shallow Pitting. I 53 2225 54 2262 0 0.03 8 2 6.86 0 0.02 6 2 6.83 55 2305 0 0.04 11 2 6.85 56 2347 0 0.03 7 2 6.82 57 2389 0 0.03 7 2 6.85 I 58 2431 0 0.04 9 2 6.88 59 2474 0 0.02 5 2 6.86 60 2516 0 0.02 5 2 6.87 61 2558 0 0.03 7 2 6.87 I 62 2601 0 0.02 6 2 6.86 63 2643 0 0.02 6 2 6.84 64 2686 0 0.02 5 2 6.84 65 2728 0 0.02 6 2 6.84 I 66 2770 0 0.03 7 2 6.85 67 2813 0 0.03 7 2 6.86 68 2855 0 0.02 6 I 6.84 69 2897 0 0.02 5 1 6.83 70 2935 0 0.02 6 2 6.82 III 71 2975 0 0.02 5 2 6.86 72 3018 0 0.02 5 1 6.85 73 3056 0 0.03 7 2 6.82 74 3098 0 0.02 6 1 6.86 I 75 3139 0 0.02 6 I 6.82 76 3182 0 0.02 6 1 6.81 77 3224 0 0.02 5 2 6.86 78 3267 0 0.02 5 2 6.86 I 79 3309 0 0.02 6 1 6.87 80 3351 0 0.02 6 2 6.84 81 3393 0 0.03 7 2 6.88 82 343 5 0 0.02 6 1 6.84 I 83 3477 0 0.03 9 2 6.84 Lt. Deposits. 84 3519 0 0.03 8 2 6.84 U. Deposits. 85 3561 0 0.04 9 2 6.83 Lt. Deposits. 86 3601 0 0.03 7 2 6.82 Lt. Deposits. Penetration Body Metal Loss Body I I I Page 2 I I I • s I PDS Report Cross Sections I Well: 1D -121 Survey Date: July 02, 2011 Field: Kuparuk River (West Sak) Tool Type: UW XR MFC 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 ins 29.7 ppf L -80 Analyst: C. Waldrop I I Cross Section for Joint 13 at depth 565.907 ft Tool speed = 50 I Nominal ID = 6.875 Nominal OD = 7.625 '1� Remaining wall area = N/A Tool deviation = 0° 1 ( \ 1 1 1 1 ‘ \ I Minimum I.D. = 6.860 ins Slight Oval due to Mild Buckling I I I I I I • • I 0 ConocoPhillips Alaska, Inc. KRU 1D-121 1D-121 4414 ( i � API: 500292281400 Well T PROD (ca d Wire #2 + SSSV Type: None Oriq Completion: 12/6/1997 Angle Angle @ TD: TS: 2 eq deg (rD I OD:1.000) 373698' Annular Fluid: Last W /O: Rev Reason: Waivered Well I Reference Log: Ref Loq Date: Last Update: 12/30/2003 Last Taq: 3793 TO: 4414 ftKB Last Tag Date: 1/31/1998 Max Hole Angle: 26 deg (a? 2428 TUBING 1 r i Casing String - ALL STRINGS (03654 Description Size Top Bottom TVD Wt Grade Thread O 2.875, CONDUCTOR 16.000 0 121 121 62.50 H-40 102.441) SURFACE 7,625 0 4402 4303 29.70 L 80 Tubing String - TUBING I Size Top Bottom TVD Wt Grade Thread 2.875 0 3654 3556 6.50 L -80 EUE 8RD MOD P erforations Summary Interval TVD Zone Status Ft SPF Date Type Comment - 3750 - 3780 3652 - 3682 WS D 30 4 1/31/1998 IPERF 2 1/8" EJ BH; 0 deg. PUMP • J ! phasing ( 36463675, i 3810 - 3840 3712 - 3742 WS B 30 4 1!29/1998 IPERF 2 1/8" EJ BH; 0 deg. OD:6.000) _ phasing 3902 - 3932 3804 - 3834 WS A3 30 4 2/17/1998 IPERF 2 1/8" EJ BH I L 3980 - 4010 3882 - 3912 WS A2 30 4 1/21/1998 IPERF 2 1/8" EJ BH r — Gas Lift MandrelsNalves Seal Section St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Viv (3676 pininimminimmii Mfr Run Cmnt 00:6.750) 1 3589 3491 Camco KBMM OV 1.0 BK 0.188 0 _9/25/2002 (1) 1. NO CHECK Other (plugs, eguip., etc.) - JEWELRY Depth TVD Type Description ID Gearbox _ 37 37 Wire # 1 Raychem Heat Trace (Bottom Depth 1309') 0.000 I (3689 37 37 Wire # 2 ESP Electric W/I Wire Cable (Bottom Depth 3698') 0.000 00:5.250) 3632 3534 Handling 2 7/8, 6.5#, EUE 8rd Mod 2.441 Pup 3633 3535 GAUGE BAKER SENTRY GAUGE @ DISCHARGE OF PUMP 2.875 I -= 3636 3538 GAUGE BAKER SENTRY GAUGE @ PUMP INTAKE 2.875 Motes 3646 3548 PUMP Tubing Retrievable Pump w/ Flex shaft and intake (180TP2000) 0.000 (36913698, 3676 3578 Seal GSFT DB HL PFS 0.000 OD:5.625) _ Section SURFACE 3689 3591 Gearbox 9:1 525 Series 0.000 �� 3691 3593 Motor PC ESP 57 HP 1315/26 KMH 0.000 I (04402, 00:7625, General Notes W t29.70) Date Note 12/30/2003 WAIVERED WELL: T x IA COMMUNICATION IN PACKERLESS WELL; FAILED ESP I I Perf (3750-3780) I Perf (3810 -3840) I I Perf ( 3902 -3932) I Perf (3980-4010) I STATE OF ALASKA ALASKA ®AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Rug Perforations r Stimulate r Other f E� ci° Alter Casing r Pull Tubing ,e Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p" Exploratory r " 197 - 181 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22814 - 00 - n etker 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 . • 1D 9. Field /Pool(s): r+ Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 4414 feet Plugs (measured) None true vertical 4315 feet Junk (measured) None Effective Depth measured 4313 feet Packer (measured) 1969, 3885, 3941 true vertical 4214 feet (true vertucal) 1966, 3786, 3842 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 SURFACE 4362 7.625 4402 4303 ' I'► 3t _s l_ 2.0ii J ; y Perforation depth: Measured depth: 3750'- 3780', 3810'- 3840', 3902'- 3932', 3980' -4010' True Vertical Depth: 3652'- 3682', 3712'- 3742', 3804'- 3834', 3882' -3912' Tubing (size, grade, MD, and TVD) 4.5, L -80, 3693 MD, 3595 TVD Packers & SSSV (type, MD, and TVD) PACKER - VICKING ESP FEED -THRU PACKER @ 1969 MD and 1966 TVD PACKER - BAKER PREMIER PRODUCTION PACKER @ 3885 MD and 3786 TVD PACKER - BAKER PREMIER PRODUCTION PACKER @ 3941 MD and 3842 TVD NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development gi Service r Stratigraphic r 15. Well Status after work: Oil IV Gas — WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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 J. Brett Packer a(, 265 -6845 Printed Name J. Brett Packer Title Wells Engineer Signature -72;e4 "'??"--‘, Phone: 265 -6845 Date WEE // 1( Form 10 -404 Revised 10/2010 RBDMS JUL 2 7 2011 e,/ ?. k Submit Original Only 7644 r �i °� • KUP • 1D -121 C cOP fl111 2 Well Attributes Max Angle & MD TD Wellbore APIIU WI F ld Name Well State Intl ( °) MD (ftKB) Act Btu) (ftKB) �' "r 500292281400 l WEST SAK PRO 26.17 2,427 85 4,414 0 caps - F^ n s1` Comment (ppm) nt H25 Dab An taboo I End Date KB -Grd (ft) Rig Release Date edc- AClual 1 ]:26;41 AM ' 1 t SSSV t Tag 3,594 0 6/8/2006 Rev Reason WORKO O R 1/6/2011 12/6/1997 5dkm - Annotation (Depth (ftK Annotation ) ( End Date Annotation i L t Mod... End Dab g� J ninam 7/17/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd Pll PP' CONDUCTOR 16 15.062 40.0 121.0 , _ 121 0 62.50 H Ir ,.,. Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND). String Wt... String... String Top Thrd s SURFACE 7 5/8 6.750 402 4,402.0 4 303 4 29.70 L-80 Tubing Strings HANGER, 4t g s g Tubin Description i String 0 String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) . Stnng Wt... String String Top Thrd CONDUCTOR, TUBING WO 4 1/2 3.958 I 415 I 3,692.9 3 1260 L 80 IBTM 40 -121 Completion Details 'Top Depth (ND) Top Intl Nomi... ii Top(ftKB) (ftKB) ( °) Item D crimson Comment ID (in) 41.5 41.5 0.00 HANGER VETCO CWCT 11' z 4 5" TUBING HANGER AND HANGER JOINT t,■ 1,968.5 1,965.3 1127 PACKER NICKING ESP FEED-THRU PACKER 4500 3.878 GAS 1 1 111 50 3 3,410.6 4.22 GUAGE GUARDIAN DISCHARGE PRESSURE SUB 3.958 1 3,615.2 3,517.2 3.08 MOTOR UPPER MOTOR SHROUD 3.830 �0 j 3,628.9 3,530.9 2.94 MOTOR LOWER MOTOR SHROUD 3.830 3,642.6 3,544.5 2.79 CONNECTOR PUMP CAN ASSEMBLY AND FIXED WET CONNECTOR SYSTEM 3.830 3,655.3 3,557.2 2.66 PIPE ASSY UPPER TAIL PIPE ASSEMBLY 3.833 PACKER, 1,969 -- 3,681.9 3,583.8 2.36 COUPLING B PROFILE 3.833 IF 3,683.5 3,585.4 2.35 PIPE ASSY LOWER TAIL PIPE ASSEMBLY 3.958 lit 3,691.0 3,592.9 2.35 PROFILE NO GO ISOLATION SLEEVE ADAPTER 3.800 Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd A3 - SAND 4 1/2 3.958 3,853.8 3,968 0 3,869.7 12.60 L - 80 IBT GAS LIFT,_ . STRADDLE PACK 2,084 Completion Details Top Depth I (ND) Top Intl Nomi... Top (ftKB) (ftKB) (1 Item D ription GommeM ______ ID (in) 1: 3,853.8 3,755.6 2.22 SLEEVE "HR" LINER SETTING SLEEVE 5.250 GUAGE, 3,506 - 3,866.8 3,768.5 2.21 NIPPLE "RS" PACK OFF SEAL NIPPLE 4.250 3,884.6 3,786.4 2.20 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 3,940.6 3,842.3 2 -15 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 1, 3,967.3 3,869.0 2.13 WLEG WIRELINE ENTRY GUIDE 4.000 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens MOTOR,3,615 -- - i k I Top (ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Data (sh... Type Comment _ 3,750 3,780 3,651.9 3,681.8 WS D, 10-121 1131/1998 4.0 IPERF MOTOR, 3,629 — - S � . � ERF 2 1/8" EJ BH; 0 deg. phasing CONNECTOR, _ T 3,810 3,840 3,711.8 3,741.8 WS B, 1D -121 1/29/1998 4.0 IPERF 2 1/8" EJ BH; 0 deg. phasing 3,643 3,902 3,932 3,803.7 3,833.7 WS A3, 1D-121 2/17/1998 0.0 PATCH PATCHED OVER wNVORKOVER 10/72008 COUPL _ 3,980 4,010 3,881.7 3,9117 WS A2, 10 -121 1/21/1998 40 IPERF 21/8" EJ BH l Notes: General Sr Safety PROFILE, End Date Annotation 3,691 12/6/1997 NOTE: MONOBORE PRODUCER 3/2/2009 NOTE: View Schematic w/ Alaska Schematic9.0 11/24/2009 NOTE: 3 WELDED SPOTS ON PUMP HOUSING FROM 2.90" TO 2.83" WERE, -� -'. 3,]50 -3,]80 .win IQ o t - t_ : W/z_ G.--c• si ,.... s..... / IPERF,_ J. P 3.810 -3.SM10 ' I �,� G B � `/ I - SLEEVE, 3,854 1 NIPPLE, 3,867 iii 7 4- 9 Z 7- it PACKER, 3,885 1 PATCH, 3,902 -3,932 MOW AMP _ — . Mandrel Details >a PACKER, 3,941 - „_ Top Depth Top ' -- I P Port ' - - _t (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (7 Make Model (in) Sery TYpe Typo (in) (psi) Run Date Com... 1 1,850.3 1,849.1 / 04 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 7/6/2011 2 2,083.7 2,077.7 15.32ICAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 7/102011 WLEG, 3,967 PERF,_ 3,980�,Ot0 WNW SURFACE, 40-4,402 - TD, 4,414 1D-121 Well Work Summary ' DATE' SUMMARY 4/2/10 PRE RWO UPPER T -POT ( PASS., UPPER T -PPPOT ( PASSED ), LOWE -POT ( PASSED ), LOWER T -PPPOT ( FAILED ), IC -POT ( PASSED ), IC -PPPOT ( PASSED) FT -LDS ALL NORMAL. 4/15/10 RAN MTT LOG FROM 200' SLM TO SURFACE ( DID NOT OBTAIN GOOD DATA ). 4/17/10 GAUGE TBG TO 2.845" TO 550' SLM. RAN 3 PDS MTT LOG PASSES FROM 220' TO SURFACE & BACK TO 220' (5hz/ 8hz/ 10hz). JOB COMPLETE. 3/19/11 LOG SLB EMIT PIPE SCANNER AND MULTIFINGER CALIPER FROM SURFACE TO 250'. LOGGED 3 PASSES WITH EMIT, TWO AT 1800 FPH AND 1 AT 300 FPH. JOB COMPLETE. 6/15/11 MEASURED SBHP @ 3625' RKB (1561 psi) & GRADIENT @ 3525' RKB (1520 psi) IN PROGRESS. 6/16/11 REPLACED SOV W/ DMY VLV @ 3525' RKB. P/T TBG TO 1500 PSI, PASSED. COMPLETE. 6/17/11 PRE RWO T- POT(INCONCLUSIVE DUE TO LACK OF PRESSURE), UPPER T -PPPOT (PASSED), LOWER T -PPPOT (FAILED) GRAY LOC SEAL RING (PASSED) FT -LDS ALL NORMAL. 7/8/11 PRESSURE TEST IA TO 1500 #.PASSED.BLED IA ACCORDING TO DECOMPRESSION SCHEDULE TO RELEASE PRESSURE FROM ESP CABLE.SET 3.79" X 38" OAL CATCHER ON WRP @ 2093' SLM.PULLED 1" DV FROM 2083' RKB 7/8/11 SET 1" DUMMY VLV @ 2083' RKB. COMPLETE. MOVE TO 1R-31 Pevt 7/10/11 PULL DV @ 2083' RKB. SET SOV @ 2083' RKB. PULL CATCHER @ 2064' SLM. IN PROGRESS. 7/11/11 PULLED WRP @ 2069' SLM. COMPLETE. eG JO ConocoPhiIIips Time Log & Summary WeRwew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/28/2011 4:00:00 AM Rig Release: 7/8/2011 5:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/28/2011 24 hr Summary Completed Well 1D-123. Release Well. RDMO. 03:00 05:00 2.00 0 0 MIRU MOVE MOB P Stage mats and set up "T" mats on 1D-121. Move in and set down over well. Accept Nordic Rig 3 at 04:00 hrs 05:00 07:00 2.00 0 0 MIRU MOVE RURD P Berm up and Spot auxiliary equipment. RU hardline and Filteration lines. 07:00 09:00 2.00 0 0 COMPZ WELCTL PULD P Lubricate out BPV. Open up well and obtain pressures: 240 psi TBG, 400 psi IA 09:00 11:30 2.50 0 0 COMPZ WELCTL CIRC P RU circulating lines. PT 250/3,000 psi. Vac out kill tank (140 bbls). 11:30 13:00 1.50 0 0 COMPZ WELCTL CIRC P Reverve circulate 198 bbls heated 8.6 ppg w/ 3 % KCL @ 3 BPM ICP 450 psi FCP 290 psi till cleaner fluids to surface, shut IA and bullhead 50 bbls to formation. 13:00 14:30 1.50 0 0 COMPZ WELCTL OPNW P Monitor well 30 mins TBG 180 psi IA 150 psi. Vac out 160 bbls from kill tank, release truck to offload. 14:30 15:30 1.00 0 0 COMPZ WELCTL CIRC P Reverve circulate 160 bbls heated (160 degree) 8.6 ppg w/ 3 % KCL @ 3 BPM ICP 290 psi FCP 220 psi till cleaner fluids to surface, shut IA and bullhead 50 bbls to formation. 15:30 17:00 1.50 0 0 COMPZ WELCTL OPNW P Monitor well 30 minutes TBG 110 psi IA 110 psi. Decision made to weight up to 9.3 KWF. 17:00 03:00 10.00 0 0 COMPZ WELCTL KLWL P Transfer fluid to make room to build & mix 9.3 ppg KWF. Filter same. 06/29/2011 MIRU at 1 D -121 Well Slot. Accept Rig. Attempt to kill Well. Weight -up and filter new calculated Kill Weight Brine. 00:00 05:00 5.00 0 0 COMPZ WELCTL KLWL P Continue to build and filter 9.3 lb /gal 3% KCL Brine. Filter Pods plugged. Change out 2 Micron Filter Cartridges. Resume filtering fluids. Transfer filtered fluids from storage Tank to Rig Pits. Prep to circulate Well with filtered 9 3 lb /gal KCL Brine. 05:00 06:00 1.00 0 0 COMPZ WELCTL KLWL P Load pits with 9.3 ppg KWF 06:00 07:30 1.50 0 0 COMPZ WELCTL KLWL P Pump 170 bbls KWF down IA & up tubing @ 3 BPM ICP 150 psi FCP 160 psi. Page 1 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 0 0 COMPZ WELCTL OPNW P Monitor well for flow, well on slight vac. Set BPV. 08:00 09:00 1.00 0 0 COMPZ WELCTL NUND P ND tree 09:00 14:00 5.00 0 0 COMPZ WELCTL NUND P NU BOPE 14:00 15:45 1.75 0 0 COMPZ WELCTL RURD P RU test equipment, shell test to 3,000 psi. 15:45 22:00 6.25 0 0 COMPZ WELCTL BOPE P Perform initial BOPE test. Function & PT BOP rams and choke manifold to 250/3,000 psi, PT Annular to 250/3,000 psi. Perform Koomey draw down test. AOGCC waived witness of test, waived by Matt Herrera @ 11:40 on 6/29/11. Rig down Test Equipment. 22:00 23:00 1.00 0 0 COMPZ RPCOM THGR P PJSM. Monitor Well. Pull Blanking Plug. Pull BPV. Install Isolation Sleeve. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig up Floor to pull the Completion. Rig up small Spooling Unit to spool Heat Trace Cable. Pick -up Landing Joint and screw into Tubing Hanger. Screw into Top Drive. 06/30/2011 Kill Well with 9.3 lb /gal 3% KCL Brine. ND Production Tree, NU BOP Stack. Test BOPE at 250/3,000 psi. Pull Tubing Hanger to the Floor. 00:00 00:30 0.50 0 3 COMPZ RPCOM THGR P PJSM. BOLDS. Pull Tubing Hanger free at 150K. Pull Tubing free at 80K. 00:30 01:30 1.00 3 3 COMPZ RPCOM CIRC P PJSM. Bring Rig Pump on Line. Catch fluid with 10 bbls (static FL was at — 220 -ft). Circulat Well at 5.9 bpm /400 psi with filtered 9.3 lb /gal 3% KCL Brine. Total volume circulated = 185 bbls. Recovered a large crude oil cap. 01:30 03:00 1.50 3 COMPZ RPCOM TRIP P PJSM. Pull Tubing Hanger to Floor at 80K with no problems. Remove Penetrators. String Cables over Sheaves. Trip out standing back 3 1/2" Tubing in the Derrick while removing Clamps and spooling ESP, Heat Trace, TEC Cables. (Number and tally tubing stands). 03:00 10:00 7.00 COMPZ RPCOM TRIP P PJSM, POOH 3 1/2" ESP completion from 3,652 -ft to 27 -ft. Weight off bottom 80K. Not all bands & clamps match run tally per Centralift. One SS bands missing, no clamps appear to be missing or out of place. 10:00 12:00 2.00 0 COMPZ RPCOM PULD P PJSM. Lay down motor assembly and ESP equipment. 12:00 14:00 2.00 0 0 COMPZ RPCOM OTHR P Offload ESP equipment & motor assembly from rig floor. Clean& prep rig floor for clean -out run. Load BHA equipment. Page 2 of 11 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 17:00 3.00 0 1,021 COMPZ RPEQP1PULD P MU BHA #1 clean -out assembly. MU 20 jts PAC pipe & remaining BHA. RIH on one stand 3 1/2" TBG. Secure Well for Conoco /Phillips a required safety stand -down. 17:00 19:00 2.00 1,021 1,021 COMPZ RPEQP1SFTY P Hold safety stand down both crews and majority of third party contracts. Discussed the hand and finger injuries that have occurred in the Kuparuk River Unit in the last month. 19:00 22:30 3.50 1,021 3,940 COMPZ RPEQPI TRIP P Resume operations. Continue to trip in with 3 1/2" Tubing from the Derrick. Entered the top of the Straddle Packer assembly at 3,854 -ft with no problems. Found top of Fill at 3,940 -ft. ( bottom perfs, 3,980' - 4,010' are covered). Up Weight = 78K. Down Weight = 74K. 22:30 00:00 1.50 3,940 4,016 COMPZ RPEQPI CIRC P Wash down to 4,016 -ft at 3.0 - 4.0 bpm /280 - 325 psi. Encountered several "hard spots ". Attempted to reverse circulate at 3.0 bpm /300 psi. However, due very poor to no returns, the reverse circulating attempt was aborted. Circulated Well at 5.0 bpm /630 psi. with hot filtered 9.3 lb /gal 3% KCL Brine. X7/01/2011 Finish circulating Well with Hot Brine. Re- confirm top of Fill at 4,016 -ft. Trip out. LD BHA #1. PU and trip in with Baker RBP and Pkr. Test Csg. Release Pkr. Trip out. Trip in with open -ended Tbg. Spot Sand on top of RBP. Trip out. Prep for E -Line Logs. 00:00 01:30 1.50 4,016 4,016 COMPZ RPEQP1CIRC P Continue to circulate Well. Total volume pumped 290 bbls. Pull -up hole. Monitor Well . Prep to Trip out. Run back in hole and tagged again at 4,016 -ft. 01:30 06:30 5.00 4,016 0 COMPZ RPEQP1 TRIP P Trip out with 3 1/2" Tubing standing back in the Derrick. Change over to handle 2 7/8" PAC Drill Pipe. Continue to single down the 2 7/8" PAC Drill Pipe to the Pipe Shed. 06:30 07:30 1.00 0 0 COMPZ RPEQP1PULD P Unload BHA #1 and Load BHA #2 07:30 10:30 3.00 0 3,650 COMPZ RPEQPI TRIP P MU BHA #2. TIH w/ BHA on 3 1/2" TBG to 3,650 - ft.Center of RBP element, set RBP. PUH to 3,600 -ft, set test packer and test RBP to 1,500 psi for 15 minutes, release test packer. 10:30 12:00 1.50 3,600 3,600 COMPZ RPEQPI DHEQ P Center of RBP element, set RBP. PUH to 3,600 -ft, set test packer and test RBP to 1,500 psi for 15 minutes, release test packer. Page 3 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 3,600 2,060 COMPZ RPEQP1 DHEQ P TOH w/ test packer to 2,060 -ft, set test packer. PT below packer to 1,500 psi for 15 mins, test charted. PT above test packer or backside to 1,500 psi for 15 mins, test also chated. RD test lines. 14:30 16:30 2.00 2,060 0 COMPZ RPEQP1 TRIP P TIH w/ test packer standing back TBG in derrick. 16:30 20:00 3.50 0 3,600 COMPZ RPEQP1 TRIP P TIH w/ 3 1/2" TBG open ended to spot 250# sand above RBP @ 3,600 -ft. Wait on Sand to settle (Clear Pipe Shed of 2 7/8" PAC Drill Pipe and Baker Tools). 20:00 00:00 4.00 3,637 0 COMPZ RPEQP1 PULD P PJSM. Up Weight = 65K. Down Weight = 65K. Ease in looking for Top of Sand. Found TOS at 3,937.0 -ft. POOH with 3 1/2" Tubing and single down to the Plpe Shed. J7/02/2011 Tag Sand. Single down 3 1/2" Tbg. RU E -Line Unit. Log Well. RD E -Line. Install 4 1/2" Pipe Rams. RU S -line. PU 4 1/2" Tbg. Wash Sand. Release and POOH with Baker RPB. 00:00 02:00 2.00 273 0 COMPZ RPEQP1 PULD P Run in the 3 stands of 4 3/4" Drill Collars. POOH and single down to the Pipe Shed. 02:00 02:45 0.75 0 0 COMPZ EVALWE RURD P PJSM. Rig up E -Line Unit. 02:45 06:30 3.75 0 0 COMPZ EVALWE ELOG P RIH. Record a Gyro, GR/CCL Log from 3,606 -ft back to surface. Lay down logging string. 06:30 10:00 3.50 0 0 COMPZ EVALWE ELOG P MU PDS 40 Arm extended reach caliper /GR /CCL on memory. RIH to 3,620 -ft, log up to surface. Lay down logging assembly. 10:00 13:00 3.00 0 0 COMPZ EVALWE ELOG P MU Baker Atlas Vertilog assembly. RIH to 3,625 -ft. Log up to surface, check data, decision made to run upper 1,000 -ft again. Rerun Veritilog from 1,000 to surface. Lay down logging assembly. 13:00 15:00 2.00 0 0 COMPZ EVALWE ELOG P Change out E -line units to seven conductor unit for Cross Dipole Sonic log. 15:00 21:30 6.50 0 0 COMPZ EVALWE ELOG P MU Cross Dipole sonic logging assembly. RIH to 3,610 -ft, log up to surface. Questionable logging data. Re -run Log. Same results. LD logging tools. (Load, drift, and tally 4.5" completion Tubing in pipe shed). 21:30 22:00 0.50 0 0 COMPZ EVALWE RURD P PJSM. Rig down and release E -Line Unit. 22:00 00:00 2.00 0 0 COMPZ WELCTI PRTS P PJSM. Pull Wear Bushing. Install Test Plug. Change Pipe Rams in the Upper Gate to 4 1/2" Solids. Rig up test equipment 07/03/2011 RU S -Line. Pick -up and drift 4 1/2" Completion Tubing. RD S -Line. Wash Sand. Release Baker RBP at 3,650 -ft. POOH and stand Back 4 1/2" Tbg. Prep for ESP Completion. Page 4 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 0 0 COMPZ WELCTL PRTS P Pressure test 4 1/2" Pipe Rams at 250/3,000 psi. Test Annular with the 4 1/2" Test Joint at 250/3,000 psi. Rig down test equipment. Pull Test Plug. Install Wear Bushing. 02:30 04:30 2.00 0 1,002 COMPZ RPCOM PUTB P PJSM. Pick up Baker Retrieving Tool. Single in with 32 ea Joints of 4 1/2" 12.6 lb /ft, L -80, IBT -M Tubing from the Pipe Shed. Make -up Torque = 2,4000 psi. Stop to rig -up S -Line. 04:30 06:00 1.50 1,002 1,002 COMPZ RPEQP1SLKL P PJSM. Rig -up S -Line to drift the 4 1/2" Tubing with a 10' x 3.800" Drift. POOH. 06:00 07:30 1.50 1,002 1,999 COMPZ RPCOM PUTB P PJSM. Pick up Baker Retrieving Tool. Single in with 32 ea Joints of 4 1/2" 12.6 lb /ft, L -80, IBT -M Tubing from the Pipe Shed. Make -up Torque = 2,4000 psi. Stop to rig -up S -Line. 07:30 08:30 1.00 1,999 1,999 COMPZ RPEQP1 SLKL P PJSM. Rig -up S -Line to drift the 4 1/2" Tubing with a 10' x 3.800" Drift. POOH. 08:30 10:30 2.00 1,999 1,999 COMPZ RPCOM OTHR P Change -out ESP cable spool, old for new ESP cable. 10:30 11:30 1.00 1,999 3,017 COMPZ RPCOM PUTB P PJSM. Pick up Baker Retrieving Tool. Single in with 32 ea Joints of 4 1/2" 12.6 lb /ft, L -80, IBT -M Tubing from the Pipe Shed. Make -up Torque = 2,4000 psi. Stop to rig -up S -Line. 11:30 13:00 1.50 3,017 3,017 COMPZ RPEQP1 SLKL P PJSM. Rig -up S -Line to drift the 4 1/2" Tubing with a 10' x 3.800" Drift. POOH. 13:00 14:00 1.00 3,017 3,640 COMPZ RPCOM PUTB P PJSM. Pick up Baker Retrieving Tool. Single in with Joints of 4 1/2" 12.6 lb /ft, L -80, IBT -M Tubing from the Pipe Shed. Make -up Torque = 2,4000 psi. Stop to rig -up S -Line. 14:00 16 :00 2.00 3,640 3,640 COMPZ RPEQP1 SLKL P PJSM. Rig -up S -Line to drift the 4 1/2" Tubing with a 10' x 3.800" Drift. POOH. RDMO S/L equipment. 16:00 17:00 1.00 3,640 3,648 COMPZ RPEQP1CIRC P Reverse circulate out sand above RBP, release RBP, let element relax, pump bottoms up. 17:00 21:00 4.00 3,648 0 COMPZ RPCOM PULL P Monitor well. Pump dry job. POOH w/ RBP standing back TBG. Lay down Baker Retrievable Bridge Plug (complete). Pull Wear Bushing. Clear and clean Floor. 21:00 00:00 3.00 0 COMPZ RPCOM RCST P PJSM. Prep to run 4 1/2" Outer ESP Completion. String ESP Cable over Sheave. String I -Wire over Sheave. Begin to pick -up Outer Completion sections. 07/04/2011 Continue making -up the Outer Completion sections. RU S -Line to drift the tubing and the Outer Completion section. Found an obstruction in the Pump Can section. Worked the obstruction out the end of the Tailpipe. Page 5 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:30 6.50 0 264 COMPZ RPCOM RCST P Continue to make -up the Outer Completion sections as designed. RIH to 264 -ft. Had to torque collar to get good cable alignment to 3,000 #. 06:30 08:00 1.50 264 264 COMPZ RPEQP1 SLKL P RU S/L equipment. Drift collar with 10' x 3.80" drift to 150 -ft. POOH. 08:00 09:30 1.50 264 1,123 COMPZ RPCOM RCST P RIH w/ completion to 1,123 -ft as per tally. 09:30 10:30 1.00 1,123 1,123 COMPZ RPEQP1SLKL P RU S/L equipment. Drift with 10'x 3.80" dummy drift to 1,074 -ft, set shallow in pump can assembly. POOH. 10:30 15:30 5.00 1,123 1,123 COMPZ RPEQP1SLKL P RIH w/ 3.80" LIB to 1,077 -ft, set down once, POOH. LIB showed round lip on one side and one mark outer edge of LIB that looks like centralizing nub below pump can assembly. Look at spare pump can assembly on surface for clues, decison made to run polished 3.80" tapered swage. POOH. RIH w/ tapered swage , set down at 1,077', 1080', 1,082'. Able to work through to 1,086 -ft, unable to work through restriction. POOH. Tapered swage had polished metal ring with 3.00" ID around swage. Decision may to pull completion. 15:30 19:00 3.50 1,123 83 COMPZ RPCOM PULL T POOH from 1,123 -ft w/ ESP Outer Completion to troubleshoot restriction below pump can assembly. 19:00 20:30 1.50 83 83 COMPZ RPEQP1SLKL T RU S -Line and run in with the 3.803" x 12' Drift. Obstruction was left at 45 -ft. Set down at the 3.800" "No -Go" at 83 -ft. Did not see any sign of the obstruction. Ran a —3.80" Tapered Swedge and passed through the "No -Go" and out of the WLEG. Saw no bobbles. Pull back inside with no problems. Ran back in with the 3.803" x 12' Drift just to make sure. Tagged the "No -Go" once again at 83 -ft. Obstruction is gone. Rig down S -Line. 20:30 23:00 2.50 83 560 COMPZ RPEQP1 RCST T Run back in with 4 1/2" Outer Completion to 560 -ft. 23:00 00:00 1.00 560 560 COMPZ RPEQP1SLKL T Rig up S -Line and run in hole with a 3.800" x 12' Drift. Tagged the "No -Go" at the expected depth of 560 -ft. Rig S -Line back. 07/05/2011 Continue running the Outer Completion Section. MU ALC /Centrilift Pump, Motor, and Seal Sections. Rig up S -Line to run the Inner Completion Section. Locate and latch WLESP into Outer Completion Test electrical connection. No test. POOH to trouble shoot WLESP. 00:00 01:00 1.00 560 1,129 COMPZ RPEQP1TRIP T Resume running the WLESP 4 1/2" Tubing. Stop to rig up S -Line for drift run. Page 6 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 1,129 1,129 COMPZ RPEQP1SLKL T Rig up S -line. Run in with the 3.800" x 12' Drift. Tagged the "No -Go" at the expected depth of 1,129 -ft. POOH. Rig back s -Line. 02:30 08:30 6.00 1,129 1,129 COMPZ RPCOM PULD P Resume planned completion operations per program. Pick -up and service ALC /Centrilift Motor and Seal sections. Check free rotation of the Motor and the Pump. Fill Motor and Seal Section with oil. 08:30 09:30 1.00 1,129 1,129 COMPZ RPCOM SLKL P RU SLU w /.125 wire, 11' x 2.125" stem, KJ, LSS, motor w /wet connect. 09:30 10:30 1.00 1,129 1,129 COMPZ RPCOM SLKL T RIH w /QC, 4.5" GS pinned w/ 1/4" brass. Latched into ALC motor,centrilist seal assy, 1120' slmd. PUH and saw small overpull, firing alignments pins out, puh to 1086' slmd, pull bind, 400# over. Unable to set DN.POOH to inspect tools. 10:30 11:30 1.00 1,129 1,129 COMPZ RPCOM SLKL T Re -pin 3 phase wet connect. 11:30 13:00 1.50 1,129 1,129 COMPZ RPCOM SLKL T RIH w /re- pinned tools. Set DN, Fired orientation pin. PUH and locate J -slot, pulled bind to 1500 #, test 3 phase. Test not good. Hand tap 5 times, POOH, GS sheared. 13:00 14:00 1.00 1,129 1,129 COMPZ RPCOM SLKL T Re -pin, Test pump, RIH w /pump for added weight and to try and help connect. Set DN @ 1050' slmd. Test Electric system. No Test. POOH 14:00 15:00 1.00 1,129 1,129 COMPZ RPCOM SLKL T Re -pin and RIH and latch pump and POOH. 15:00 16:00 1.00 1,129 1,129 COMPZ RPCOM SLKL T Lay DN Pump. Re -pin and RIH to pull Lower section of ESP motor. Rig down S -Line. 16:00 20:30 4.50 1,129 1,129 COMPZ RPCOM PULD T Trouble shoot and tear down equipment sections. Found a small amount of water in one of the Motors. 20:30 22:30 2.00 1,129 1,129 COMPZ RPCOM PULD T Bring "back -up equipment to Pipe shed. Put Plug Head Assembly together. Service and chech -out same. 22:30 00:00 1.50 1,129 1,129 COMPZ RPCOM PULD T Pick -up the Plug Head Assembly. Continue to service. Fill with oil. 07/06/2011 ✓ Continue to make -up and service "back -up" ESP Inner Completions Sections. Rig up S -Line to run the Inner Completion Section. Continue to run the remainder of the 4 1/2" WLESP Completion as designed. 00:00 03:00 3.00 1,129 1,129 COMPZ RPCOM PULD T Pick -up and service Tandom Motors and Seal section. Make -up to the Plug Head Assembly. Service and QC the lower section of the ESP assembly. Page 7 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:30 3.50 1,129 1,129 COMPZ RPCOM SLKL T Rig up S -Line. Latch the lower ESP assembly with a wireline GS Spear (tool string hanging weight = 1,050 Ibs) Run in hole. Set down at 1,126 -ft. Shear pins. Pick -up 30 feet to orientate. Slack off. Lower ESP section is latched in. Check cable readings on surface. GOOD ! Shear off and POOH with S -Line tool string. 06:30 07:45 1.25 1,129 1,129 COMPZ RPCOM SLKL P Make up and Run in hole with D &D packoff assembly. Sting into PBR and jar and set Pack -off. 07:45 09:15 1.50 1,129 1,129 COMPZ RPCOM PRTS P Fill tubing and install TIW valve. Pressure test chart pack -off to 2000 psi for 10 mins. Good Solid test. Check and Test ESP cable /motor /pump electrical integrity.Rig diown testing equipment and TIW valve. 09:15 10:30 1.25 1,129 1,129 COMPZ RPCOM SLKL P MU &RIH with tubing stop on Slick -line. Jar down and set tubing stop on top of Pack -off. POOH with slick -line setting tools after checking ESP components. 10:30 10:45 0.25 1,129 1,129 COMPZ RPCOM SFTY P PJSM. 10:45 12:15 1.50 1,129 1,712 COMPZ RPCOM RCST P Continue to run in hole with ESP completion to the first GLM.MU GLM and handling PUPS with three joints of tubing, crossover pups and Viking packer assembly. 12:15 17:30 5.25 1,712 1,712 COMPZ RPCOM OTHR P Stop and Terminate TEC wire 3' above packer, feed TEC wire through the packer and secure w/ 1/2" NPT swage -lock fitting. Install BIW Packer Penetrator and splice the ESP Cable to the Penetrator. Check ESP Cable and TEC wire. Good. 17:30 18:30 1.00 1,712 1,937 COMPZ RPCOM RCST P Continue to RIH with the 4 1/2" Completion Tubing, ESP Cable, and the TEC Wire. Stop to drift tubing. 18:30 19:30 1.00 1,937 1,937 COMPZ RPCOM SLKL P Rig up S -Line. Drift the Tubing down to 1,010 -ft. Good. POOH and rig down. 19:30 21:00 1.50 1,937 2,958 COMPZ RPCOM RCST P Continue to RIH with the 4 1/2" / Completion Tubing, ESP Cable, and ✓ the TEC Wire. Weight up = 74K. Weight down = 72K. Stop to drift tubing. 21:00 22:00 1.00 2,958 2,958 COMPZ RPCOM SLKL P Rig up S -Line. Drift the Tubing down to 1,106 -ft. Good. POOH and rig down. 22:00 22:45 0.75 2,958 3,611 COMPZ RPCOM RCST P Continue to RIH with the 4 1/2" Completion Tubing, ESP Cable, and the TEC Wire. Weight up = 84K. Weight down = 82K. Stop to drift tubing. Page 8 of 11 Time Logs • • Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 22:45 23:30 0.75 3,611 3,611 COMPZ RPCOM SLKL P Rig up S -Line. Drift the Tubing down to 805 -ft. Good. POOH and rig down. 23:30 00:00 0.50 3,611 3,611 COMPZ RPCOM RCST P Drift Tubing Hanger and the Hanger Joint (3.833 "). Pick -up Tubing Hanger and Hanger Joint. 37/07/2011 Make -up Tbg Hanger install Penetrator. Make top ESP and TEC Splice. Land Hanger. RILDS. Install BPV. ND BOP Stack. NU Tree. Test Tree. RU S -line. Set WRP. Pump Gel - Diesel down IA. Set Pkr. Set Catcher Sub. Pull DV from lower GLM. Freeze Protect Tbg. 00:00 05:30 5.50 3,611 3,692 COMPZ RPCOM RCST P Make -up Tubing Hanger. Install Side -Port Isolation Sleeve. Install Penetrator. Make top ESP Cable splice. Make top TEC Wire splice. Perform electrical integrity checks. Land Tubing Hanger at 3,692 -ft ORKB. Up Weight = 84K. down weight = 84K. Inspect visual alignment. Perfect. RILDS. 05:30 10:00 4.50 0 0 COMPZ RPCOM NUND P PJSM. Set BPV. Drain BOP stack, and lay down landing joint. Nipple down BOP's. 10:00 10:30 0.50 0 0 COMPZ RPCOM OTHR P Perform electrical integrity system check. 10:30 11:30 1.00 0 0 COMPZ RPCOM NUND P PJSM. NU tubing head and tree. Test Tree to 5000 psi for 15 mins. 11:30 12:00 0.50 0 0 COMPZ RPCOM MPSP P Pull BPV and Set two -way check valve. 12:00 13:30 1.50 0 0 COMPZ RPCOM PRTS P PJSM. Rig up testing equipment. Chart and Pressure test tree to 250/5000 psi for 30 mins. Rig down testing equipment. 13:30 14:00 0.50 0 0 COMPZ RPCOM MPSP P Pull two -way check valve. 14:00 14:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM, with HES personnel and Rig crew. HES had crew change -out. Perform another PJSM with new crew. 14:30 19:00 4.50 0 0 COMPZ RPCOM SLKL P Rig up slick -line equipment and load tools and lubricator to the Rig floor. Pressure test Lubricator. Run in with a 4 1/2" KO -1 with LIB. Locate the GLM at 2,083 -ft ttmd. Flag line. POOH. Lay down Tool String. 19:00 22:00 3.00 0 0 COMPZ RPCOM PLUG P Make up and set timer on the Halliburton Setting Tool Package. Pick up Weatherford WRP. Pressure test Lubricator. Run in with the WRP. Stop at flag. Check odometer depth. Good. Park the WRP in the middle of the first full tubing joint at 2,115 -ft, below the lower GLM. Wait for the pre -set timer count down to begin the setting sequence. Set WRP. POOH Set back S -Line. Page 9 of 11 II Time Logs • S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 23:00 1.00 0 0 COMPZ RPCOM PRTS P Fill Tubing with 9.3 lb /gal 3% KCL Brine (1.75 bbls). Pressure test the WRP at 1,000 psi x 10 minutes. Record on chart. Good. 23:00 00:00 1.00 0 0 COMPZ RPCOM FRZP P PJSM. Rig up Lil' Red. Pump Gel - Diesel down the 7 5/8" x 4 1/2" Annulus to serve as a packer fluid and to freeze protect the 7 5/8" x 4 1/2" Annulus. Packer depth = 1,968 -ft. Beginning rate = 2.5 bpm /600 psi. Final rate = 2.3 bpm/750 psi. Total volume pumped = 66 bbls. X7/08/2011 Set Pkr. Pressure test Csg and Pkr. Bleed Csg pressure down per schedule. RU S -Line. Set Catcher Sub. Pull DV from lower GLM. Freeze protect Tbg with Diesel. Set DV in lower GLM. RD S -Line. Set BPV. Perform elect checks. Secure Cellar. Release Rig. RDMO. 00:00 01:00 1.00 0 0 COMPZ RPCOM PACK P Perform pre electrical integrity checks. Good. Lil' Red pressure test line at 4,500 psi. Good. Begin Packer setting sequence per Viking Packer Serviceman. Pressure up on the Tubing at 1.0 bpm to 4,000 psi. Hold x 5 minutes. Gradually bleed pressure off to "0" psi. Once again bring pressure up at 1.0 bpm to 4,000 psi. Hold x 5 minutes. Bleed pressure back to "0 ". Record on chart. Perform post electrical integrity check. Good. 01:00 02:00 1.00 0 0 COMPZ RPCOM PRTS P Hook up Lil' Red to the 7 5/8" x 4 1/2" Annulus. Pressure up on the Annulus with Diesel to 1,500 psi. x 30 minutes. Record on chart. Casing and Packer Good. 02:00 05:30 3.50 0 0 COMPZ RPCOM PRTS P Bleed pressure from the Annulus in gradual steps following the decompression schedule (start = 1,500 psi, final = "0" psi). 05:30 07:00 1.50 0 0 COMPZ RPCOM SLKL P PJSM. Rig up S -line and Tools. RIH and Set Catcher Sub. POOH and Remove setting tools. R/U and RIH and Pull Dummy Valve. Rig back Slick -line. 07:00 08:30 1.50 0 0 COMPZ RPCOM FRZP P PJSM. MIRU Hot Oil Pumping Unit. Freeze Protect Tubing with 35 bbls of Diesel down to 2000 ft at 2 bpm, ICP =400 psi and FCP =200 psi. R/D Hot Oil Unit. 08:30 10:30 2.00 0 0 COMPZ RPCOM SLKL P PJSM. MIRU Slick -line Unit and Too string. PT Lubricator, RIH and set Dummy Valve in lower GLM. POOH and Lay down tools and equipment from Rig Floor. RDMO Slick -line Unit. 10:30 11:00 0.50 0 0 COMPZ RPCOM MPSP P Rig Up Setting Tool and BPV and Set to secure tree. Page 10 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 0 0 COMPZ RPCOM OTHR P Make Final Electrical Integrity Test on Down -hole ESP Equipment. Good Test. 11:30 17:00 5.50 0 0 COMPZ MOVE DMOB P Dress Tree. Prep Rig and Location For Rig Move. Release Rig At 1700 hours. FTP =0 psi / Final IA 0 psi. Page 11 of 11 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, July 06, 2011 8:50 AM To: 'Packer, J.Brett' Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: 1D-121 (PTD #197 -181) Brett, I am minimally familiar with the new ESP completion and do realize that extra time is needed to install and run this " it is new to the slope (or anywhere) and components "generation completion. As t ) onents needs to checked and re- p 9 P P ( Y checked it will take longer. I agree it doesn't make sense to pull the completion out of the ground to perform a BOP test and in fact may be more risky than continuing to run the ESP into the well. Your request to extend weekly the BOP test is granted. Of course if you have to pull out the well completely for some reason to start over you would be required at this point to perform the BOP test. Keep me posted on your progress as well as the slope inspectors. Regards, Guy Schwartz �) i ; Senior Petroleum Engineer ,' J�' ' AOGCC 793 -1226 (office) 444 -3433 (cell) From: Packer, J. Brett [ mailto: J. Brett.Packer @conocophillips.com] Sent: Tuesday, July 05, 2011 10:25 PM To: Schwartz, Guy L (DOA) Subject: 1D -121 (PTD #197 -181) Guy, I'm writing to inform you of our current situation and kindly request an extension to our weekly BOP test scheduled on Wednesday 7/6/2011. We had given Lou Grimaldi 36 hours notice prior to our upcoming BOP test, fully expecting to be done before that time, but due to complications and another setback this afternoon, we are still in the process of running the ESP completion. We have been keeping Lou apprised of our status. Background This well is incorporating a new innovative technology that we've been working on the past two years in conjunction with Artificial Lift Company out of Great Yarmouth, U.K. It is the first well of it's kind to be run in Alaska and involves running a completely wireline retrievable ESP system. This system allows the pump, seals, and motor to all be run thru- tubing and connect to the power cable via a down -hole wet connect. This differs from our normal thru- tubing ESP's in that they have the motor & seals run on the bottom of the tubing, and only the pump is wireline retrievable. The benefits of this new system include the ability to replace the pump, seals, and motor using conventional wireline methods, avoiding the need for an expensive workover rig, and also the ability to access below the tubing tail and cleanout with CTU if necessary. We successfully tested this technology over the past year in a well down in West Texas. This completion involves two steps, the first being to run the outer completion consisting of the pump can w/ downhole wet connect, motor shrouds, and a discharge pressure sub. The second step is to rig up Slickline to run the wireline ESP motors, seals, pumps, and connect it to the wet connect via a downhole plug -arm assembly. Current Progress We started making up our outer completion on Sunday evening (7/3), expecting it to take a full 24 hours to 7/6/2011 Page 2 of 2 • complete. Seeing as how this is a new service company and a very technical completion, it took significantly longer to make up the outer completion BHA than we are used to when it comes to ESP's. Nevertheless, when we got to a depth of 1123', and we were ready to start making up our inner completion. We drifted the tubing and outer completion BHA and tagged up high. Subsequent Slickline runs indicated we had some unknown obstruction in our downhole assembly. We ended up pulling out to the top of the BHA and then drifted it again, this time drifting all the way to bottom, so whatever the obstruction was must have become dislodged and fallen downhole. We lost 11 hours dealing with this issue. Today, we began making up the inner completion and successfully got the motors and seals installed. Everything still seemed to be on schedule for landing the completion tonight, but when we ran the pump section, we somehow lost electrical integrity of our ESP system. We ended up pulling the pumps, seals, and motor and discovered water in our motors. We have removed the wet motors and are in the process of servicing our backup motors to be run in the hole. This is where we are currently at as of 7/5. Current Plan Forward From here on out, the procedure involves running the motors & seals in on Slickline, running the Pump section on Slickline, then the tubing packoff and slipstop on Slickline. Once the inner components are successfully set, the rest is just running the 4 -1/2" tubing and packer the remaining 2600' to land the hanger. I'm estimating if everything should go as planned, we will be at least another 24 hours before this completion is landed, and then an additional 24 hours to finish up the well. The reason it will take a full 24 hours to set the inner components and run only 2600' is due to the time it takes to services the motors and seals, installing clamps, as well as making splices of the ESP cable and TEC wire above the packer, which is also a new addition to West Sak ESP wells. Once landed, to finish up the well involves pumping gelled diesel on the backside, rigging up Slickline to set a WRP below the packer to be able to pressure up against to set the packer, and then ND BOP's and NU tree & testing. As I'm sure you are aware, ESP completions are different in that once you start running them, you can't stop and set a storm packer to be able to do a BOP test, due to the ESP cable and TEC wire in the hole. We started running this completion on 7/3, fully expecting to be done by the time our weekly BOP test is due on Wednesday (7/6), but due to the complications we've seen and the setback this afternoon, it's looking like we'll be well into Wednesday night just to get this completion landed. If we were to have to stop running this completion for the BOP test, it will be a very time consuming task and involve pulling the 1000' of tubing, disconnecting the ESP cable and TEC wire, and breaking apart our very technical outer completion BHA; and based upon how long it took to initially make up the BHA, this whole process would set us back at least another 1.5 days by the time we got it all made up again. The well has been cooperating nicely, it has been static since we got it killed on 6/29 with losses at a constant -7.5 bbls /hr. We have seen no gas to surface, and since we began running this completion on 7/3, even without any circulation, the well has not had any issues. A recent SBHP was run on 6/15/11 prior to the workover and measured 1561 psi at 3527' TVD, equivalent to 8.51 ppg. The MPSP is 1208 psi based upon the current SBHP and a 0.1 psi /ft gradient. We are currently using 9.3 ppg brine KWF. We are currently in the middle of running this ESP completion and I am formally requesting an extension to our weekly BOP test to allow us time to finish running this completion. I look forward to your response. Thank You, Orett Packer Ong et Wells Workover Engr. 907 - 265 -6845 (office) 907 -230 -8377 (cell) 7/6/2011 • • FT J 7- / sq ConocoPhillips West Sak 1 D -121 4 -1/2" WLESP w/ ESP FeedThru Packer AJ L Conductor: 16 ", 62.5#, H -40 4 Y2 Completion Surface Casing: • XX Jts. 4 W, L-80, IBTM -SCC tubing 7.625 ", 29.7 #, L -80 BTCM • 4'/" x 1" KBMG Mandrel • 3 Jts. 4 '/2', L -80, IBTM -SCC tubing J4 4 -1/2" x 1" KBMG Mandrel • 4 %" x 7 %" Viking Packer X F— Viking Packer (- 2,000' TVD) J. 4 -1/2" x 1" KBMG Mandrel • 3 Jts. 4 W, L -80, IBTM -SCC tubing • 4 W x 1" KBMG Mandrel • XX Jts. 4' W', L -80, IBTM -SCC tubing • Guardian Discharge Pressure Sensor • Guardian Discharge Press. Sensor • 3 Jts. 4 '/ ", L -80, IBTM -SCC tubing U ALC Rig Deployed Equipment s` • Upper / Lower Motor Shrouds ' N. N • Pump Can Assembly 000 • Wet Connect g • 'B' Profile 3 r. Wireline Deployed Inner Completion • No-go / Isolation String Adapter N i % `o 0 m EI' E ag aQ N.....- IN..- - 9: A3 Straddle Packer Assembly • WELL LC? TRAN~'11~1/TTAL lo° PrtoAcme Diagnosric SertvicES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Magnetic Thickness Tool 15 Apr-10 1 D-121 1 Report 50-029-22814-00 2) Print Name: ~~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-mall : pdsanchorageCa~memorylog.com WESSrrE : www.memorvloa.com C:\Documents and Settings\Diane Williams\Desktop\Trensmit_Conoco.~ac • • Memory Magnetic Thickness Tool ~, Log Results. Summary Company: ConocoPhillipsAlaska, Inc. Well: 1D-121 Log Date: April 15, 2010 Field: West Sak Log No.: 10623 State: Alaska Run No.: 2 API No.: 50-029-22814-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE MOD Top Log Inivl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 211 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 Top Log Intvl.: Surface Pipet Use: Surtace Casing Bot. Log Intvl.: 211 Ft. (MD) Pipe3 Desc.: 16" 62.5 Ib. H-40 Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" casing, and 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison of the current to the previous log run on this well (June 14, 2006) show similar intervals of significant metal loss in the top 52' of the well bore. A change in tubing between the current and previous logs, combined with a noticeable improvement in data quality in the 5Hz pass made in the current logging procedure make a direct comparison of the current and previous logs impractical. The percent metal loss indications recorded in the current 5Hz pass appear to represent little, if any growth in the metal loss recorded in these intervals during the time between logs. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval 0' - 211'. Changes in metal volume are relative to the calibration points at 64' and 138', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3,5" tubing, 7.625" casing and 16" conductor pipe. Three log passes at 5Hz, 8Hz and 10Hz were made over the logged interval. A log plot overlay of the average overall metal thickness recorded by all three passes is included in this report. All three passes indicate significant metal loss features over the same intervals (13' -18'), (22' - 28') and (39' - 52'), with the relative metal loss indicated in the 5Hz pass listed below: A maximum --7% circumferential metal loss is indicated in the interval between 39' and 52' in the 5Hz pass. A maximum ^~4% circumferential metal loss is indicated in the interval between 13' and 18' in the 5Hz pass. A maximum -5% circumferential metal loss is indicated in the interval between 22' and 28' in the 5Hz pass. A maximum -3% circumferential metal loss is indicated in the interval between 192' and the bottom of the interval logged in the 5Hz pass. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: {281) 565-1369 E-mail: PDS~`memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~~~- -~~ 1 • • Intermittent indications of apparent lines of isolated metal loss are recorded by the MTT throughout the logged interval in the 5Hz pass. A log plot of the entire 5Hz pass is included in this report. This pattern is also apparent in the comparison log plot of the individual MTT sensor readings at 5Hz and 10Hz included in this report. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or {888} 565-9085 Fax: {281) 565-1369 E-maii: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 A a`~"` ~E"s SHz, ~ and 1 aHz Passes Delta M~I Thickness Overlay Q~ ~`'s ~'~` 1 D-121 April 15, 2010 RI°ACTIVE DIACINOSTIC SERVICES Database File: d:\warrior\datal1d-12111st calibrationloverlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Mon Apr 26 17:32:52 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (5Hz} (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (10Hz} (%) 50 0 20 Delta Metal Thickness 2010 40 I I I I I I I I ~C-Fib- Delta Metal Thickness 2010 f10Hz) I 60 Delta Metal Thickness 2010 of 16" 80 i A o`ti~,wE"s R~rded Magnetic Thickness L~ Data - 5Hz Pass Q~ ~n7 N 1 D-121 April 15, 2010 P11°l~CTIVE ~NEjN°STIC SERVICES Database File: d:lwarriorldatal1d-12115hz pass.db Dataset Pathname: 5Hz.1 Presentation Format: 1.8 scale Dataset Creation: Tue Apr 27 15:06:12 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 -- - - - _ _ Li S - n e pee i Tree -- -.~ ! -- ~- I I i - ~ -- _ Tu bing Co llar ~ ~Hanger~ -Pup- - ~ ~ _-_ ~_; ~. ~ D lt M t l T hi k - e a e a c ness Tubing Jt. 1 ' a 4% Metal Loss -- ~ 20 -- 5 % M eta l Lo ss- T bi C ll u ng o ar ~ ~ A ar ent Line of I sola ted Met al L oss p 40 ~' M t l L A arent Li ne o f Isolated M etal Loss e a o ss ~, Cas ing Goll a Tubing Jt. 2 ~ ~ 7 % M eta l Los s _, 1 ~ ~ 1 ~ Tubing Co lla ~ ~ __ - --- - - - - ° -I i i - _ _F T bi Jt 3 ~ u ng . .:A pparent Line of Isol ated Me tal Loss Botto m o f 16 " Conductor 80 ~.. C ing Co lar ~ ~ r-_ l l -I _ Tu bing Co llar ~--~ - - i ~ - ~ ~~ - ~ - - • 1 DO Tubing Jt. 4 ' Apparent ' I 120 Tu bing Co lla ~ - - - -- - _ Casing Co llar ' Tubing Jt. 5 140 ' n ~ Tubing Co llar ~ 160 -_ _ - ___ T bi Jt 6 u ng . Casin Co llar ' 180 Tu bing Co llar ' 3% Met al Lo ss Tubing Jt. 7 00 2 ' Delta Metal Thickness i ' Line Spee ' -50 Delta Metal Thickness (%) 50 0 Line Speed (ftlmin) -200 1_8 -7 Line of Isolated Metal rent Line of Isolated Metal nt Line of Isolated Metal MTTPD1 (rad) MTTP12 (rad) 11.8 3 ~~.~wEus,, ~ ,Comparison - 5Hz & 10Hz~TT Passes =moo ~~,~~ 1 D-121 April 15, 2010 Pn°Acrivc Dinynosric SEaviccs Database File: d:lwarriorldatal1d-12115hz & 10hz comnparison.db Dataset Pathname: merge Presentation Format: 1.8&3.2p Dataset Creation: Tue Apr 27 15:57:25 2010 Charted by: Depth in Feet scaled 1:480 1.8 M TTP01 (5Hz) (ra d) 11.8 3.2 MTTP 01 (10Hz) (r ad) 13.2 -10 5Hz Delta Mtl. Thickness (%} 10 -7 M TTP12 (5Hz) (ra d) 3 -5.6 MTTP 12 (10Hz) (r ad} 4.4 -10 10Hz Delta Mtl. Thickness (%) 10 10H P D t ~ __, _ - Hz Pas s D at z a ss a a i - 10Hz Delta Metal Thickness_~ Hz Delta Metal Thickness ~ I '~^ i - ` _ ii - ! - - 1 _ :. 100 i 1-~ ~J--i ^ - -- . 4 s- I 200 1.8 MTTP01 (5Hz) (rad} 11.8 3.2 MTTP01 (10Hz) (rad} 13.2 -10 5Hz Delta Mtl. Thickness (%} 10 -7 MTTP12 (5Hz} (rad} 3 -5.6 MTTP12 (10Hz) (rad) 4.4 -10 10Hz Delta Mtl. Thickness (%) 10 ConocoPhillips =.t1~,:.., Is:: HANGER. 41 CONDUCTOR, 49-121 HEAT TRACE, 42 ESP MANDREL 2 3fi'. ESP MANDREL. 3535 C-,4UGF. 3 E11 INTAKE, 3,652 SEPL. 3.65] GEAR BOX. 3,671 MOTOR, 3 612 SLEEVE, 3,854 NIPPLE, 3867 PACKER, 3.885 PATCH, 3 992-3,932 PACKER, 3,941 WLEG, 3,967 IPERF, 3,9604 010 KUP 1 D-121 I Attributes An le 8 MD TD WNlhare A%NWI 500292281400 PINtl Name We118tffius I ~ ND pgce) WEST SAK PROD 26.17 2,427.85 Act Etrn ptKB) 4,414.0 Camrrlerd N2S Ippm) Dale SSSV- NONE 10 7/10/2009 Ampt3ian Last WO: End Date K6-Drd IR) t0.r7/2008 Rlg Release Date 72/6/1997 gmptatlon Depgl QII~) Last Tag: 3,594.0 Erb Date Amatatlan Last Nlotl ... 618/2006 Rev Reaso¢ Poll Pomp Assy. GLV C?O knosbor Er1tl De[e 3/24/2010 Casin Strin s Casing Descdptlon CONDUCTGR Suing 0... 16 S[dng ID ... 15.062 Top QIKB) 40.0 Set Depth h... 121.0 SR Depth (ND)... 721.0 Suing WL.. 62.50 SMng... H-00 Suing Top Thrd . ~...b ~..e-...r-..... ~.....q ~... -....q ... ... ..q. ~......~ -.....ter... ~.... -....y...~....~... ......ry...... -.....e ... -.....y ...~. ...... A3-SAND 41/2 3.958 3.853.8 3.968.0 3,869.7 12.60 L-80 IBT STRADDLE PACK Com letion Details Top Depth IT~01 Top N1d Nomi... Irwd Strll Tap lRl(BII m ) I (11 McKe I Nbtld I (~ Serv I vTYPe I TYDe I Pn) IThIPSII~I Rin Dale ILOm..I SURFACE, 404 492 TD, 4 414 Page 1 of 1 Regg, James B (DOA) ~ ~`~?- lam( .~, _ _ _ From: NSK Problem Well Supv [n1617@conocophillips.com] ~ 1~~~\,~ Sent: Wednesday, March 24, 2010 8:33 AM ~~OL y To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schw~i~tz, Guy L (DOA) Cc: NSK Problem Well Supv; Pierson, Chris R Subject: 1 D-121 (PTD 197-181) Report of failed ESP Tom, Jim, Guy West Sak ESP producer 1 D-121 (PTD 197-181) has a failed ESP. Slickline diagnostics indicate the motor has failed and will not turn. The well will require a RWO to repair and will remain SI until that time. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 3/24/2010 -~, ~~~~t.- ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~~~'`i ~' 1. Operations Pertormed: 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. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 197-181 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22814-00 ' 7. KB Elevation (ft): 9. Well Name and Number. RKB 41', Pad 71' 1 D-121 8. Property Designation: 10. Field/Pool(s): ADL 25650 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 4414' feet true vertical 4315' . feet Plugs (measured) Effective Depth measured 3594' feet Junk (measured) true vertical 3496' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4361' 7-5/8" 4402' 4303' Perforation depth: Measured depth: 3750'-3780', 3810'-3840', 3902'-3932', 3980'-4010' ' ' ' ' ~~t h~~~ RR {Q~ ~~~~' YL 11 ,i, ~U~t~ ' ' ' ' true vertical depth: 3652 -3682 , 3712 -3742 , 3804 -3834 , 3882 -3912 Tubing (size, grade, and measured depth) 3.5", L-80, 3681' MD. Packers &SSSV (type & measured depth) Baker Premier production pkrs @ 3885', 3941' no SSSV 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 Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 116 3 .286 -- 167 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 work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packe~;~ Title Wells Engineer 1~~~~ Signature Phone: 266-6845 Date Pre a b haron Allsu Dr k 263-4612 Form 10-404 Revised 04/2006 ~ ~ ~ ~-~ ~ ~ ~ ~ f_.5 ~ ~~ ~"" ~ ~ `~~~ Submit Original Only !'j .. ~ i'~ L~ ~,,~.oi /.alt • ~. ~ KU P 1 D-121 n ~ 1 C01~0~~~'i il~llp5 Well Attributes ~ _ al,1y;,, r;. Wellbore APVUWI Field Name Well Status ProNlnj Well Typa Incl (°) MD(flK8) TD (maxi (fl 500292281400 (WEST SAK ~ (PROD 26.17 ~ 2,42785 I 4,414.0 mant H25 (Pprn) C to (Annotation End Data Da 'KBJird (RJ (Rig Release Date °°° t2t a Wdl C fl iD SSSV' NONE 5 J e: z ~ et I 711/2008 Last WO: 10/7/2008 _ ~ 12/6/1997 , _ - - On o _ _____-_ _. Baru , notation IDe h H ~~~--- A pt ( KB) End Data I ~-- 'Annotation : -_. 'End Data Last TaDt 3,594.0 6/8/200 6 ~iRev Reason WORKOVER I 10/11/2008 HANGER. 41 ESP MANDREL. 2,361 ESP MANDREL. 3,535 GAUGE, 3,611 INTAKE, 3.652 - SEAL, 3,657 - GEAR 80%, asn MOTOR. 3.672 - IPERF, TAr. 3,750-3,]60 IPERF. _ 3,810-3,840 SLEEVE, 3,854 NIPPLE. 3.86] PACKER. 3.885 - - PATCH. 3.902-3.932 3.901 -- Desorption (String O... (String lD ...TOp (ftK6) (Set Depth (t...Set Depth (TVD1 ... H-00 EUE MOD Top Deplh (ND) Top Top (ftK6) (ftK6) Intl l°) Rem Description Comment _ ID (in) 41.5 41.5 0.00 HANGER ABB Vetco Gray TBG2.02' Hanger w/30.95' 3 1/2" L-80 EUE 8rd Mod J7 2.950 3,611.1 3,513.1' 3.13 GAUGE 3 12" EUE 8rd AB Mod Tubing w/ Guardian Sidemount carrier 2.992 3,652.41 3,554.41 2 69 INTAKE TTC Crossover Cplg w/ Pedorated intake 2.992 3,6571 3,559 O 2.64 SEAL Tandem Seal Section GS63D6 0.000 3,670.9 3.572.8 2.36 GEAR BOX GRU 525 9:1 0.000 3,672.2 3,574-1 2.36 MOTOR ESP Motor 57 hp KMHG 1315VI26A 0.000 3,679.0 3,580 9 2.36 CENTRALIZER Motor Centralizer Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Sal Depth (rvDl . __ ,. String Wl... Stri... String Top Th rd A3-SAND 41 /2 3.958 3.853.8 3,968.0 3,869.7 12.60 L-80 IBT STRADDLE PACK Com le tion Det ails , Top Deplhl ~ (ND) Top ' Top (RKB) (ftK6) ' Incl (°) Rem Description Comment _ -_ _ ID (in) 3,853.8 _ 3,755.6 2.22 SLEEVE "HR" Liner Setting Sleeve 5.250 3,866.8 3,768.51 2.21 NIPPLE "RS" Pack off Seal Nipple 4.250 3,884.6 3,786.41 2.20 PACKER Baker Premier Production Packer 3.875 3,940.6 I 3,842.3', 2.15 PACKER Baker Premier Production Packer _ 3.875 3,967.3 3,869.0 2.13 WLEG WIRELINE ENTRY GUIDE 4.000 Other In Hole ireline retrievable lu s, valves um s fish et c. Top Depth (TVD) ~, Top Top (ftK6) (ftK6) ' Incl (°) ~ Description Comment Run Date ID (in) 10.0 10.0 O.OOiHEAT TRACE HEAT TRACE 10/7/2008 0.000 Perfora tions Shot '~ Top (NDI' Bim (ND) Dens T_op (ftK6) Bfm (NK81 ~ (RKB( (RKe) Zorn _ Dale (sh-~ Type Comment __ 3,750.0 3,780.0' 3,651.91 3,681.8 WS D, 1D-121 1/31/1998 4.0', IPERF 2 1/8" EJ BH; 0 deg. phasing 3,810.0 3,840.0 ~'I 3,711.8 3,741.8 WS B, 1 D-121 1/29/1998 4.0 IPERF 2 118" EJ BH; 0 tleg- phasing 3,902.0 3932.0 3,803.7 3,8337 WS A3, 1D-121 2/17/1998 0.0 PATCH PATCHED OVER w/WORKOVER 10/7/2008 3,980.0 4,010.0 _ -_ 3,881.7 3,911.7 WS AZ, 10-121 1/21/1998 4.0 IPERF - 2 1/8" EJ BH Mandre l Details ',Top Depth, Top ~ (FVD) i Incl OD Valve Latch Port Size TRO Run (Stn Top (RKB( (RKB) '' (°I Make Model (in) Serv Typa Type (in) (psi( Com... Run Dab 1 2,360.7 2,338.0 26.37 Camco KBMG 1 ESP , DMY I BK-5 0 0.0 10/7/2008 3 3,535.3 3,437.4 3.94 Camco KBMG 11i ESP ', DMY BK-S 0 0.0 10/7/2008 W LEG. 3 967 IPERF. 3,980J,010 SURFACE. OJ,402 TD, 4,414 ;7 Cor~o~t~Phiips Time Log & Summary ~e,~~~, ~~~ R~o°~,~g Report Well Name: 1 D-121 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/30/2008 6:00:00 AM Rig Release: 10/7/2008 3:30:00 PM Time Logs _ _ Date From To Dur S. Depth E Depth Phase Code 5ubcode T Comment I 9/30/2008 _ 24 hrsummarv MIRU Nordic Rig 3 on 1 D-121. RU and Test kill lines. lubricate out BPV. Circulate and kill well w/ 8.9 ppg KWF. Increase KWF to 9.5 .Circulate and kill well. Set BPV and ND Tree. 05:00 06:00 1.00 COMPZ MOVE MOB P Move off 1 D-127 and Move in and set down on 1 D-121. Berm up and Spot auxilia a ui ment. 06:00 10:00 4.00 COMPZ RPCOM OTHR P Accept Nordic Ri 3 @ 0600 hrs. Loading pits w/ 8.9 Brine and RU Kill lines to kill tank. 10:00 11:30 1.50 COMPZ RPCOM OTHR P Lubricate out BPV 11:30 22:00 10.50 COMPZ WELCTL CIRC P PJSM. PT kill lines to 3000 psi. Initial T/IA press = 370/290 psi. Circ 360 bbl of 8.9 ppg brine 3 bpm @ 410 pis, IA choked to 350 psi to kill tank. Shut in T/IA press = 120/120 • psi. Lost 17 bbl to hole fill. Circ an additional 100 bbl. Shut in press T/IA = 10 psi. Unload kill tank and load fluids. Circulate additional 100 bbl. Shut in press after 20 min T/IA = 40/40. Weight up to 9.5 ppg Circulate 158 bbl @ 2 bpm @ 50 psi ICP. Lost 13 bbl to formation. 22:00 22:30 0.50 COMPZ WELCTL OWFF P Weil on slight vacumm 22:30 23:00 0.50 COMPZ WELCTI OTHR P PJSM, Set BPV. 23:00 00:00 1.00 COMPZ WELCTL NUND P ND Tree 10/01 /2008 Continue to ND Tree and NU BOPE. Test ROPE 250/3,000 psi and Annular 250/2,500 psi. Circulate well wl130? diesel and follow w/ 160? Seawater w/ 6% KCL, Chase out of the hole w/ 9.5 KWF to Ti er tank. 00:00 03:30 3.50 COMPZ WELCTL BOPE P NU 11" BOP 03:30 12:00 8.50 COMPZ RPCOM SFEQ P Begin testing 11" BOP - 250/3,000 and 250/2,500 Annular. 24 hr notice was given to AOGCC @ 0730 hrs on 9-29-08. Witness of Test waived by Bob Noble 2000 hrs on 10-1-08. 12:00 15:30 3.50 COMPZ RPCOM WOEQ NP Blind rams would not test. Change wear plate on blind rams. Continue to test, Tested ood. 15:30 16:00 0.50 COMPZ RPCOM OTHR P Pull Blanking plug and attempt to. ull BPV -had pressure build up underneath. 16:00 17:30 1.50 COMPZ RPCOM CIRC P RU pump lines, pump 40 bbl of 9.5# down TBG taking returns to Tiger Tank. ~..~..~.._ ~ _~ ~ Page 1 cf 7 ~~ i ..Time Logs _ _ _ ____ Date From To Dur S De th E. De th Ph se Code Subcode T Comment 17:30 18:00 0.50 COMPZ RPCOM OTHR P _ Pull BPV. 18:00 18:30 0.50 COMPZ RPCOM OTHR P Blow down line to Tiger Tank. 18:30 19:30 1.00 COMPZ RPCOM CIRC P Circulate 160 bbl of 9.5 ppg KWF @ 4 b m 290 si. 19:30 20:00 0.50 COMPZ RPCOM OWFF P Monitor well 20:00 21:30 1.50 COMPZ RPCOM CIRC P RU and Circulate w/ Little Red Services 50 bbls of 130? Diesel followed by 170 bbls of 160? 8.6 ppg Sea water w/ 6% KCL to clean build u off of exterior of ESP Com letion. 21:30 22:00 0.50 COMPZ RPCOM OTHR P Monitor well while RU to circulate w/ ri SITP 100 si, SICP 50 si. 22:00 23:00 1.00 COMPZ RPCOM CIRC P RU and Circulate out hot fluids w/ 9.5 ppg KWF, taking 120? returns to Tiger Tank. Circulating @ 4 bpm @ 290 psi ICP and 300 psi FCP. Had 30 bbl loss to formation before recoverin 9.5 returns. 23:00 23:30 0.50 COMPZ RPCOM OWFF P Monitor well, Blow down line to Tiger tank and stra TT. 23:30 00:00 0.50 COMPZ RPCOM OTHR P MU landingjt 10/02/2008 Unland hanger and pull to rig floor. Check integritity of ESP cable, TEC wire, and Heat trace. Lay down hanger and landingjt. String up sheeves and POOH w/ 3 1/2 completion string. Inspect ESP components and lay down. MU and RIH w/ 6.75" C/O string, tag @ 3,911', not able to C/O past. Pooh and change BHA f! 6.75" OD Bit to 4.875" MM Mill. RIH to 3,910' and C/O to 3,914'. 00:00 00:30 0.50 3,706 3,665 COMPZ RPCOM OTHR P BOLDS and Unland han er @ 125k and Pull to ri floor 75k u wt. 00:30 01:00 0.50 3,665 3,635 COMPZ RPCOM OTHR P Test ESP cable, TEC wire, and Heat Trace. Un hook from penetrators and la down han er and landin 't. 01:00 02:00 1.00 3,635 3,635 COMPZ RPCOM OTHR P Start ESP and Heat Trace cables over sheeves. 02:00 08:30 6.50 3,635 0 COMPZ RPCOM TRIP P POOH w/ ESP com letion f/ 3,635'. Fill hole with 3x dis lacement. 08:30 11:00 2.50 0 0 COMPZ RPCOM PULD P Lay down ESP assembly. Clean and clear floor. Motor spline (shaft) broken at pump eye connection. Pot head connection was burnt. Pulled 465 x 5' clamps, 94 dual channel clamps, 14 single channel clamp, 4 x 3' clamps, 3 x 2' clamps, 1 end shoe, 4 SS bands. All bands and clam s retrieved the were run. 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR P PJSM. Change out ESP spool with crane. 12:00 13:30 1.50 0 0 COMPZ RPCOM PULD P Chan a out floor a ui ment to RIH with DP. Clean and clear floor. Set wear rin . 13:30 15:00 1.50 0 3,780 COMPZ RPCOM TRIP P PJSM. RIH with clean out BHA on 3-1/2" DP to 3780'_. Up wt = 87K#, down wt = 83K#. Rage ~ of ~ • i Time Logs _ _ __ _ __ ___ _ ______ Date From To Dur S De th E. De th Phase Code Subcode T Comment 15:00 16:30 1.50 3,780 3,908 COMPZ RPCOM FCO _ P RIH to 3911' and tag up. PU and start pumping 8 bpm and rotating at 50 rpm. Sit down at 3911'. Work at same depth for 5 min sitting down and torquing up 15K# with no progress. PUH 30' and circulate bottoms up, only minor amount of fine returns. RIH without pumping or rotatin and sat down 15K# at 3911'. 16:30 19:30 3.00 3,908 295 COMPZ RPCOM TRIP T POOH to cleanout BHA# 1. 19:30 20:00 0.50 295 0 COMPZ RPCOM PULD T Stand back DC's and Break off 6.75" OD bit. 20:00 21:00 1.00 0 318 COMPZ FISH PULD T Bring tools to rig floor. MU and RIH w/ 4.875" OD MM Millin ass . 21:00 22:30 1.50 318 3,903 COMPZ FISH TRIP T RIH w/milling BHA to 3,903' 22:30 00:00 1.50 3,903 3,914 COMPZ FISH MILL T MU Top drive, gather parameters: 90k up wt, 85k do wt, 90k Rot wt, circulating @ 8 bpm @ 2,100 psi. Rotating @ 50 rpm's @ 1,550 ft/Ibs torque. Tag up 3,910' and attempt to work thru w/ 7 - 10k, Torque 2,500 - 3,000 ft/Ibs., circ. @ 8 bpm @ 1,950 psi. Clean out to 3,914' as of midni ht. 10/03/2008 Continue to C/O f! 3,914' to 3,962'. CBU. POOH and Change out 4.875" OD MM mill for 6.75" Tri Cone bit. RIH to 3,911' and rotate thru to 3,962' and continue to Clean out to 4,350'. Recoverin fine Westsak sand. 00:00 02:30 2.50 3,914 3,952 COMPZ FISH MILL T Continue to C/O from 3,914' to 3,952'. 90k up wt, 85k do wt, 90k Rot wt, circulating @ 8 bpm @ 2,100 psi. Rotating @ 50 rpm's @ 1,550 ft/Ibs torque. working down w/ 7 - 10k, Torque 2,500 - 3,000 ft/Ibs., circ. 8 b m 1,950 si. 02:30 04:30 2.00 3,952 3,960 COMPZ FISH MILL T Continue to C/O from 3,952' -slowed pump to 4 bpm @ 700 psi. Rotating @ 50 rpm's @ 1,550 ft/Ibs free torque and torquing up to 2,700 ft/Ibs. Pump 31 bbl high visc sweep @ 3,962' depth. one SS Band was recovered on DP just above tool jt. Made 50' in 5 hrs. Mill is spinner without torque, may be spinning on ~unk. POOH to ins ect mill. 04:30 06:30 2.00 3,960 0 COMPZ FISH TRIP T Pooh f/ 3,960' to surface. Mill showed some wear ,but no obvious metal to metal wear. Old SS band found on DP when pulled to surface. Previous pull report from 9/12/2006 stated that all clamps and SS bands were retrieved. Count from this pull accounted for all clamps and SS bands. 06:30 07:30 1.00 0 0 COMPZ FISH RURD T PJSM. Break down 4.875" junk mill asembl and ri u 6.750" bit. ParJ~ 3 cif 7 r' Time Logs _ _ __ _ __ _ _ _ e T Comment Da_ te_ From To Dur S De th E De th Phase Code Subcod 07:30 09:00 1.50 0 3,900 COMPZ FISH _ TRIP T RIH with 6.750" bit to gauge hole down to 3960' prior to running 6.75" junk basket. Bit at 3900', up wt = 93K#, down wt = 85K#. 09:00 18:00 9.00 3,900 4,135 COMPZ RPCOM FCO P RIH and sit down 15K# at 3913'. PU and start pumping 8 bpm @ 930 psi and rotating at 50 rpm. RIH and sit down weight at 3913' and torque increased from 2000 psi to 8000 psi and broke back. Walked through and and started working down hole. Sitting down 10K# to 15K# and working downhole with no torque increases from 2000 psi. Working through fill at about 30 fpm. Only. fine silt in the returns, no frac sand observed. POSSIBLE CASING DAMAGE AT TOP OF "A" SAND PERFS AT 3913'. EACH PASS UP OR DOWN WITH THE BIT AT THIS DEPTH CAUSES THE STRING TO SIT DOWN OR OVERPULL AND IF THE STING WAS ROTATING THE TORQUE WOULD INCREASE. 18:00 00:00 6.00 4,135 4,350 COMPZ RPCOM FCO P Continue to clean out fill f/ 4,135' to 4,350'. 93k up wt, 85k do wt, 87k ROT wt @ 70 rpm w/ 1,550 ft/Ibs. free torque w/ 2,200 ft/Ibs. C/O torque. Circulating @ 4 bpm @ 320 si. 10/04/2008 Continue to C!O f/ 4,350' to 4,414' PBTD. CBU. POOH and talk w/ANC about well bore damage. RIH w/ 3 1/2 EUE TBG to 3,918' tag and PU. RU HES and RIH w/downhole camera. POOH and RIH w/ LIB on slickline. 00:00 02:30 2.50 4,350 4,414 COMPZ RPCOM FCO P Continue to Clean out from 4,350' to 4,414' PBTD. 93k up wt., 85k do wt., 87k ROT wt w/ 1,550 ft/Ibs free torque, w/ max torque of 2,200 ft/Ibs @ 70 rpms. Circulating @ 4 bpm @ 320 psi. Mix and pump 30 bbl hi-visc sweep and Chase out of the hole @ 8 b m 1,100 si. 02:30 03:30 1.00 4,414 3,901 COMPZ RPCOM OTHR P Blow down top drive and POOH to 3,901' and Rih slowly to 3,911', set down 40k. PU and Screw in TD, rotate @ 20 rpms and set down, torque up to 6,000 ft/Ibs. PU and slide down again torquing up to 6,500 ft/Ibs and falling through. Shut down rotation and slide through to 3,990'. Pull back throu h w/ 15k over ull. 03:30 06:00 2.50 3,901 0 COMPZ RPCOM TRIP P Continue to POOH from 3,901' to surface. 06:00 08:00 2.00 0 0 COMPZ RPCOM OTHR P Break down and offload Baker tools, change out floor equipment and clean and clear ri floor. F'~r~¢ 4 of 7 Time Logs Da e From_ To Dur S De th E. Depth Phase Code Subcode T Comment _ 08:00 11:00 3.00 0 3,890 COMPZ RPCOM TRIP T PJSM. RIH with 3-1/2" tubing, preparing to run video log to identify casin restriction at 3913'1 Tagged and sat down 10K# at 3919'. PUH to 3890'. 11:00 13:00 2.00 3,890 3,890 COMPZ RPCOM RURD T RU Halliburton video logging unit. 13:00 14:00 1.00 3,890 3,890 COMPZ EVALWE CIRC T Circulate 70 bbl of 9.6 ppg filtered brine (tbg vol + 1000' of IA). Bullhead 20 bbl down the tb . 14:00 15:30 1.50 3,890 3,890 COMPZ EVALWE ELOG T RIH with video camera. Lens blacked out after camera exited tubing tail at 3890'. POOH with camera. 15:30 16:00 0.50 3,890 COMPZ EVALWE OTHR T Clean lens, install centralizer on camera. Circ tubing volume (35 bbl) down the tubin . 16:00 18:00 2.00 COMPZ EVALWE ELOG T RIH with video, bullhead down the tubing 2 bpm @ 170 psi. Observed and tagged obstruction in the casing ~30 ft below tubing string. Unclear what the actual obstrution is. POOH with video camera. RD video logging unit. 18:00 20:00 2.00 3,890 0 COMPZ RPCOM TRIP T POOH with the 3-1/2" tubing -stand back. 20:00 21:30 1.50 0 COMPZ RPCOM WOEQ T Discuss options w/ WO engineers and call out for slickline to RIH w/ 5.95" OD Lead impression block to dama a to confirm video. 21:30 23:30 2.00 COMPZ RPCOM OTHR T Held PJSM w/ rig and slickline crews. RU slickline. 23:30 00:00 0.50 COMPZ RPCOM OTHR T RIH w/ 5.95" OD LIB. 10/05/2008 Continue to RIH w/ LIB on slickline. RD slickline and PU, MU and RIH w/ 6.75" OD string mill assy. Dress bads of in CSG. POOH and MU Straddle PKR ass .RIH and Set. Release off and POOH. 00:00 02:30 2.50 COMPZ RPCOM OTHR T Continue to RIH w/ 5.95" OD LIB and set down @ 3,918', work spanges jars. POOH and veiw LIB, take photos and RIH w/ Same LIB redressed and set down in same spot. Work spange jars harder and POOH. Compare to run #1. Take hotos and RD slickline. 02:30 03:00 0.50 COMPZ RPCOM OTHR T RU to RIH 6.75" OD String mill assy. 03:00 03:30 0.50 0 349 COMPZ FISH PULD T PU and MU 6.75" OD String mill assy. RIH w/ 4.75" OD Tapered Bull nose, 1-4.75" OD DC, 6.75" OD String mill, 6 - 4.75" OD DC's, 4.75" OD Lub. Bumper sub, 4.75" OD Fishin Jar, 3 - 4.75" OD DC's to 03:30 06:00 2.50 349 3,850 COMPZ FISH TRIP T RIH w/ 6.75" OD String mill assy. on DP. Bottom of the mill assembly (bullnose) @ 3850'. Up wt = 92K, down wt = 85K. 50 RPM = 1770 psi of torque. Pumping 8 bpm @ 1000 si. T~acge 5 of 7 Tme Logs ____ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 09:00 3.00 3,850 4,100 COMPZ FISH MILL T RIH, tagged with bullnose at 3910', work through. Tagged with mill 32' lower (length between bullnose to bottom of mill). Mill was worked hard for ~4 ft. Make several passes and worked 50ft length concentrating on the milled area. Run mill assembl down to 4100' bull nose de th. 09:00 10:30 1.50 4,100 4,100 COMPZ FISH CIRC T Circulate bottom up while rotating and reciprocating DP. Pump 140 bbl Reverse circulate 35 bbl viscous pill followed 135 bbl of brine. 10:30 13:30 3.00 4,100 0 COMPZ FISH TRIP T PJSM. POOH with milling assembl , standin back 3-1/2" DP 13:30 15:30 2.00 0 0 COMPZ RPCOM PULD T Off loading milling tools. Loading straddle packer assembly and handling equipment. Change over to TBG a ui ment. 15:30 18:00 2.50 0 134 COMPZ CASING PUTB T PJSM, PU and MU straddle acker ass nd inner strip . 18:00 19:00 1.00 134 134 COMPZ CASING OTHR T ange over o equipment 19:00 21:00 2.00 134 3,968 COMPZ CASING RUNL T RIH w/ Straddle Packer assy on 3 1/2 DP to 3,968'. 21:00 22:00 1.00 3,968 3,854 COMPZ RPCOM PACK T Get on depth w/ packers w/ 87k up wt, 83k do wt. LT (a) 3,854', PKR #1 COE 3,888' PKR #2 COE @ 3,944' and WLEG 3,968'. Drop ball and RU to Set w/ Rig test pump. Pressure up to 1,200 psi to start setting PKR's, then increase to 4,000 psi for 10 minutes, increasing to 4,400 psi for 5 minutes and Shear out ball catcher 4,750 si. 22:00 22:30 0.50 3,854 3,854 COMPZ RPCOM OTHR P RD test equipment. 22:30 00:00 1.50 3,854 110 COMPZ RPCOM TRIP P POOH and stand back DP to 110' 10/06/2008 Lay down Setting assy. Pull wear ring and wash stack. PU and MU ESP Components and service. RIH on 3 1/2 TBG com letion. Make finals lice and land. 00:00 01:30 1.50 110 0 COMPZ RPCOM PULD P Lay down Setting tool and inner strip . 01:30 03:00 1.50 0 0 COMPZ RPCOM OTHR P Pull Wear Ring and wash stack. 03:00 10:00 7.00 0 80 COMPZ RPCOM PULD P Held PJSM w/ Centrilift and Rig crew. PU and MU ESP Components and Guardian au e. 10:00 20:30 10.50 80 3,600 COMPZ RPCOM RCST P RIH with 3.5" ESP completion and heat trace cable. 20:30 21:30 1.00 3,600 3,630 COMPZ RPCOM OTHR P MU landing joint and hanger. Install enetrators. 21:30 23:30 2.00 3,630 3,630 COMPZ RPCOM OTHR P Make final Splice on heat trace, ESP cable and TEC wire. Connect to entrators. [~~ge f oaf 7 Time Logs Date From To Dur S De th E. De th Phase Code Subcode T __ _ Comment 23:30 00:00 0.50 3,630 3,681 COMPZ RPCOM HOSO P Test conductivity and Land hanger. RILDS. 10/07/2008 Set BPV and N D BOPE 00:00 01:00 1.00 0 0 COMPZ RPCOM SFEQ P Test Upper and Lower hanger seals. 01:00 01:30 0.50 0 0 COMPZ RPCOM OTHR P Lay down landing jt. Install isolation sleeve and TWC. 01:30 07:00 5.50 0 0 COMPZ RPCOM NUND P ND BOPE. Change UPR's to 3.5" and LPR's to 4.5" 07:00 09:00 2.00 0 0 COMPZ RPCOM NUND P Test ESP cable and heat trace cable. NU tree. 09:00 10:00 1.00 0 0 COMPZ RPCOM SFEO P Pressure test packoff void and tree to 5000 si. Pull TWC. 10:00 12:30 2.50 0 0 COMPZ RPCOM FRZP P Test ESP and heat trace cable. Freeze protect well down to 2500'. Bullhead 85 bbl down the IA and 22 bbl down the tubin . 12:30 13:30 1.00 0 0 COMPZ RPCOM OTHR P Set BPV. 13:30 15:30 2.00 0 0 COMPZ RPCOM OTHR P Clean pits and change out ESP spool with crane. Release Nordic Rip 3 at 15:30 hrs. SITP=500 psi, SICP=500 si. l~~ar~~ 7 csf 7 1D-121 (PTD #197-181) Page 1 of Z~ Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Thursday, October 30, 2008 10:14 AM To: Maunder, Thomas E (DOA) Subject: 1 D-121 (PTD #197-181) Tom, As discussed yesterday regarding 1 D-121 (PTD # 19?-181), original plans were to pull the ESPCP, cleanout to PBTD, and re-run the ESPCP. During the workover, we discovered casing damage in the A3 perfs at 3911', and ended up running a straddle patch across this perf interval. it was decided to isolate this perf interval because it was not the primary producing sand, and we feared that the future production of this well would be jeopardized if we were to leave this interval open, as we had found frac sand on top of our pump prior to the workover. Workover Details 10/2/08 Ran in the hole w/ a 63/4" mill tooth bit and tagged up at 3911' (top of the A3 sand perfs). Worked it for awhile, but made no progress. POOH. 10/3/08 MU 4.875" OD milling assembly and RIH to 3910', milled to 3914' and then continued to cleanout to 3962' at which point the mill was spinning w/o torque, so we POOH to inspect the mill. RIH w/ 6.75" bit, sat down at 3913', worked through with increasing torque and set down weight through this section. Finished cleaning out to 4414'. Decided to run a video log to look at the casing in that section. 10/4/08 RIH w/ 3 1/a" tubing, tagged up at 3919', PUH 30' and set tubing in the slips. RU video logging unit & RIH w/ video and tagged obstruction at 3919' . Could not get a clear picture of what was going on. 10/5/08 RIH w/ 5.95" OD LIB and set down at 3918'. No clear impression. Rana 2nd LIB, still no clear impression except some gouges on the outside edge of the LIB which indicated casing damage. RIH w! 4.75" bull nose wash tool and 6.75" string mill. Tagged up at 3910' and worked through. Made several passes through damaged section. Decided to isolate this casing damage w/ a straddle patch assembly. Set the straddle patch from 3884' - 3940' spanning the A3 sand perfs. 10/6/08 Ran ESPCP completion, RDMO. This casing damage was unexpected and we dealt with it in a way that we think wiH extend the life of this well and keep the ESP online. I apologize for not informing you of our intentions, once it was decided to patch this interval. Please let me know what steps we need to take to rectify this. Thanks, 11/16/2008 . . . "_,",,1-1 V 1-U JAN 1 1 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 197-1811 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22814-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 10-121 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 4414' feet true vertical 4315' feet Plugs (measured) Effective Depth measured 3594' feet Junk (measured) true vertical 3496' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4361' 7-5/8" 4402' 4303' Perforation depth: Measured depth: 3750'-3780',3810'-3840',3902'-3932',3980'-4010' true vertical depth: 3652'-3682',3712'-3742',3804'-3834',3882'-3912' SCANNED JAN 2 5 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 3675' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) I reatment deSCriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation SI Subsequent to operation Si 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: n/a Contact Howard Gober Printed Name Howard Gober Title Wells Group Engineer 'A,I01- Signature . -f-'-<" -'~ ð Phone 24?3 --tfZ.W Date ....,- , Prpnared bv Sharon AI/sun-Drake 263-4612 I I r~t\\OMS 8Ft. " 'Ii ~ Form 10-404 Revised 04/2004 ORIGIÎ~AL :/; tI dO! S~16;þ . . SURFACE (0-4402, 00:7.625. Wt:29.70) ConocoPhUlips Alaska, Inc. KRU 1 D-121 GAUGE (3659-3660, 00:3.500) INTAKE (3675-3680, 00:3.500) Seal Section (3680-3693, 00:5.130) 3693 3695 3703 3595 3597 3605 CENTRILlFT 538 SERIES 11.4:1 CENTRILlFT 76 HP KMH 1360 MOTOR CENTRALIZER 0.000 0.000 0.000 Gearbox (3693-3695, 00:5.380) Motor (3695-3703, 00:5.620) Perf (3750-3780) Perf (3810-3840) Perf (3902-3932) Perf (3980-4010) Conoc~hillips We/Mew Web Reporting Time Log Summary 12/07/200600:00 06:00 6.00 MIRU MOVE MOB 06:00 07:30 1.50 COMPZ RPCOII. RURD 07:30 08:30 1.00 RPCOII. OTHR 08:30 10:30 2.00 RPCOII. RURD 10:30 15:00 4.50 COMPZ RPCOII. CIRC 15:00 22:00 7.00 COMPZ RPCOII. CIRC 22:00 00:00 2.00 COMPZ RPCOII. CIRC Rig down. Pull off 1 D-38, spot ESP s ooler on ri floor with ASRC crane. P RDMO. Move rig from 1 D-38 to 1 D-121. Reconfigure BOP stack. Move over 1D-121 and rig up. Accept Rig @ 0600, 12/7/06. P Berm up cellar. Lower tarps around wheels. Spot cuttings box. RU lines to kill well. P Pull Vetco-Gray BPV using lubricator. 520 si SITP. P RU lines to kill well. RU slips & power tongs for 2-7/8" tubing. Service mud manifold and choke manifold valves. Test lines to 500 si. RU LRS. P PJSM. PT lines to 2500 psi. LRS pump 60 bbls diesel, 2 BPM, 1100 psi, 150 deg F. Switch to filtered Sea Water off truck & LRS pump 210 Bbls, 2 BPM, 1050 psi, 150 deg F. Close choke and inject 30 Bbls SW, 2 BPM, 1250 psi. LRS ISIP 400 psi, 520 psi on driller's panel gauge. 300 psi at 1 hr. Unload 50 Bbls SW into its. NP Discovered we had connected return line to side outlet from tubing, all fluids pumped across top of well, not down hole, except for injection. Call MI mud plant for more filtered warm SW, and call back LRS unit. Drop return line down to 7-5/8" X 2-7/8" annulus. Blowdown lines. RU LRS. Load 3-1/2" tubing in pipe shed, drift & strap same. Bring in ESP equipment. Bring in & RU spooler & sheave for Ray Chem heat trace. Wait for filtered SW to arrive. P Load of seawater on location. LRS PT lines to 2500 psi. LRS pump 60 bbls diesel down tubing @ 150 deg, 2 BPM, 1250 psi taking returns out IA. Switch to filtered seawater and pump 300 bbls @ 150 deg, 2 BPM, 1270 psi, closed choke and bullhead last 30 bbls to formation. 12:00 13:00 1.00 LRS completed pumping 300 bbls of 3% KCL seawater, bull heading final 30 bbls to formation. Final tubingllA pressure 500 psi. Close choke. Rig down LRS. Monitor well 30 minutes. TubingllA pressure stabilized at 350 psi. Calculate KWF at 10.5 ppg, with 100 si over balance 11.0 COMPZ WELC1 WOEQ NP Call for KWF to be mixed. Stand by for KWF from Prudhoe. Load & strap 120 joints tubing in pipe shed, all tubing drifted with 2.867", while waiting on fluids. Install accumulator lines to Hydril double gate, loosen doors to install rams. Replace hydraulic lines on Eckel power tongs. Line up vac trucks with 400 Bbls of 10.9+ ppg filtered KW brine to ri suction. COMPZ WELC1 KLWL P PJSM. SITP & SICP 250 psi. Pump 50 Bbls 8.7 ppg filtered SWfrom pits, 3 BPM, 580 psi ICP, 270 psi Choke. Follow with 10.9+ ppg brine, 3 BPM, 580 psi ICP, 280 psi Choke, 320 psi FCP, 0 psi Choke. Lost about 50 Bbls getting 10.9 ppg brine back to surface. COMPZ WELC1 OWFF P Monitor well. Fill hole, 9 Bbls after 45 minutes, 12 BPH loss rate. Offload 175 Bbls 10.9+ ppg brine into pits, water back to 10.5 ppg with 3% KCI water. Send truck for remaining brine at mud plant, to be cut back to 10.5 , 180 Bbls before dilution. COMPZ WELC1 NUND P Set 3" H-BPV. ND Vetco-Gray ESP tree. Install Gray plug off tool. NU BOPE. Tighten flanges on "new" Hydril double gate. Install 2-7/8" pipe rams and blinds in double gate. Fill hole, 26 Bbls after 6 hrs (Shut-in time). RU to test BOPE. Witnessing of test waived by Chuck Scheve, AOGCC Field Ins ector. COMPZ WELC1 BOPE P Test BOPE for 27/8" & 3 1/2" pipe. FunctionlPT BOP rams and choke manifold to 250/2500 psi, annular to 250/2500 si. COMPZ WELC1 BOPE P Continue with BOP test. Good test. Ri down test e ui men!. COMPZ RPCOr-. PULD P Pull BPV, Set isolation sleeve. Make up landing joint, BOLDS, pull tubing hanger to rig floor, pull hanger free @ 85K, string weight 70K. Monitor well, well drinkin sli htl . COMPZ RPCOr-. CIRC P Circulate hole volume of 10.5 ppg KWF. Monitor losses, about 10 BPH. Finish prep. Centrilift & Ray Chem tools. 03:00 10:00 7.00 10:00 12:00 2.00 13:00 20:00 7.00 20:00 00:00 4.00 12/09/200600:00 02:00 2.00 02:00 03:00 1.00 03:00 05:00 2.00 PJSM. RD cables from penetrators. LDLJ & Vetco-Gray tubing hanger. POOH LD 2-718" tubing & ESP completion, spooling up ESP power cable & heat trace cable. POOH to motor lead, remove same. 14:00 15:30 1.50 COMPZ RPCor\ PULD P Disassemble & LD ESP assembly. All bands, cable guards, clamps, and rotectolizers were recovered. 15:30 16:00 0.50 COMPZ P Clear & clean rig floor. 16:00 17:00 1.00 COMPZ P Change upper pipe rams from 2-7/8" to 3-1/2". 17:00 19:00 2.00 COMPZ P RU test equipment. Set test plug. Test upper pipe rams, lower pipe rams, & ba to 250 si & 2500 si. 19:00 20:30 1.50 COMPZ RPCOII. PULD P PJSM. Spot crane. Remove spool of old ESP cable and spool of old heat trace cable. Hoist in new heat trace cable and ESP power cable. Set ower cable in s ooler. 20:30 22:30 2.00 COMPZ RPCOII. PULD P Box up old pump assembly. Change out floor equipment to 3.5". Make up test acker assembl . 22:30 00:00 1.50 0 3,000 COMPZ P RIH wI test packer assembly on 3.5" tubin to 3700' MD. 12/10/200600:00 01:30 1.50 3,000 3,700 COMPZ P Continue in hole with test packer to 3700' MD. Set packer and test casing to 2500 psi. Monitor pressure 30 mins, good test. Bleed pressure off, release test acker. 01:30 03:30 2.00 3,700 0 P POOH wI test packer assembly standin back 3.5" tubin . 03:30 05:00 1.50 COMPZ P Lay down test packer assembly, prep ri floor for com letion run. 05:00 08:00 3.00 COMPZ P PJSM. Make up 3.5" ESP motor assembl . 08:00 12:00 4.00 P Meg motor, OK. MU ESP power cable. Install Guardian gauge. MU gauge wire and test. MU Joint #1, MU KBMG GLM Assy (1" DV), RIH 2 stands. 12:00 13:30 1.50 0 700 COMPZ RPCOII. RCST P Crew change - PJSM. Continue RIH with 3-1/2" ESP completion, stands from derrick to -700'. 13:30 14:00 0.50 700 700 COMPZ RPCOII. PULD P RU Ray Chem heat trace cable over sheave. Install beginning of heat trace in middle of Joint #21 (will be at -3000' when landed . 14:00 16:00 2.00 700 1,288 COMPZ RPCOII. RCST P Continue RIH installing protective clamps on ESP cable and heat trace cable. MU 2nd KBMG GLM Assy (1" DV) on to of Joint #38. 12/11/2006 00:00 02:00 2.00 3,130 3,705 P 02:00 03:00 1.00 3,705 P 03:00 05:30 2.50 P 05:30 06:30 1.00 P 06:30 07:30 1.00 P 07:30 09:00 1.50 P 09:00 11:00 2.00 P 11:00 13:00 2.00 P 13:00 15:00 2.00 P 15:00 16:00 1.00 RPCDr\ OTHR 16:00 18:00 2.00 RPCOtl. RURD Continue RIH installing protective clamps on ESP cable and heat trace cable. Making integrity checks on heat trace and power cable every thousand feet. Continue RIH installing clamps on ESP cable and heat trace cable to 3705' MD. Make up tubing hanger with 30.72' joint of tubing. Make up landing joint to han er. Install enetrators in han er. Splice ESP power cable and heat trace cable to penetrator below han er. Test penetrators. Drain stack. Land hanger. 80K# PUW, 75K# SOW, 34K# Blocks. RILDS. Test seals to 5000 psi, OK. Pull isolation sleeve from hanger. Set BPV. PJSM. ND BOPE. NU Vetco-Gray tubing head adapter and tree (originals re-run). Test void & tree to 5000 si, OK. Pull BPV. RU circulating lines. LD 2 stands of tubing from derrick and oft load. Start cleanin its. RU LRS hot oil unit. Test lines to 2500 psi. Freeze protect well. Reverse circulate 64 Bbls diesel into lA, 2 BPM, 700 psi to 975 psi, 400 psi at shut down. Switch lines and inject 16 Bbls diesel into tubing, 2 BPM, 700 psi to 1100 psi, 450 psi initial shut down. Puts diesel to 1870' MD in tubing & IA. 10.5 ppg brine below there. P RU lubricator & set BPV. 400 psi SITP,400 si SICP. P RU crane. Remove ESP cable spool from spooler. Install empty spool for pulling ESP on 2T-203. finish cleaning pits. Released Rig @ 1800 hrs, 12/11/06. . 'y/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 \Vest ih Avenue, Suite 100 Anchorage, AK 99501 \lb\ \,\1/ SCANNED JAN 1 () 2007 Dear l\Ilr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l Loveland at 907-659-7043, if you have any questions. Sincerely, ~--/cO~ Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 10-138 200-048 11'7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . RECEIVED OCT 0 2 2.006 Alaska Oil & Gas Cons. Commission Anchorage ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 September 28, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operati ocoPhillips Alaska, Inc. wells ID-120 (PTD 197-221), and ID-12 (PTD 197-181). he reports record the completion of the surface casing excavation, inspectIon, an repair on each well. Also included are two paper copies of the previously faxed 10-403 application for Sundry Approval to add a ~4' extension on the conductor ofwelllD-133 (PTD 197-206). Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. æµ Problem Well Supervisor Attachments ¡ C{i- 1 fS\ Kt:la::lvt:u . . OCT 0 2 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF S NDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Repair Well I ill Plug Perforations 0 :r;..~ Pull Tubing 0 Perforate New Pool 0 Operat. ShutdownD Perforate 0 Stimulate 0 Waiver 0 Anchorage o Time Extension 0 o Other Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 112' Exploratory Service Re-enter Suspended Well 5. Permit to Drill Number: 197-181/ 6. API Number: 50-029-22814-00 4. Current Well Status: Development 0 Stratigraphic 0 o o 9. Well Name and Number: 10-121 8. Property Designation: Kuparuk River Unit /191.. t.'~(,9) 11. Present Well Condition Summary: 10. Field/Pool(s}: Kuparuk River Field / West Sak Oil Pool Total Depth measured 4414' 4315' . feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured feet feet true vertical Casing Structural CONDUCTOR SURFACE Length Size MD TVD Burst Collapse 121' 4290' 16" 7-5/8" 121' 4402' 121' 4303' Perforation depth: Measured depth: 3750-3780' 381-3840',3902-3932',3980-4010' true vertical depth: 3652-3682,3712-3742,3804-3834,3882-3912' Tubing (size, grade, and measured depth) 2-7/S", L-SO, 3654' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA NA NA Subsequent to operation NA NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oíl0 GasD WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-209 Contact Printed Name Signature Title Phone WI Project Supervisor Date Form 10- 4 Revised 04/2004 0 R 1 G 1 N A L . .. 1 D-121 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 9/10/2006 Conductor removal for SC inspection, Initial T/I= S1/600. Cut Conductor off @ 13' from top of ,/ mandrel hanger. Shot IA FL @ 100' . Welders then split and removed conductor sections. We then chipped away solid cement revealing surface casing in excellent condition. Minor Surface corrosion on SC @ 10' - 12' . Final T/I= S1/600. 9/11/2006 Called AOGCC state inspector (John Spaulding) @ 4:55 p.m. and notified him again about the visual insepction he said that he mayor may not be over to witness 9/14/2006 ME reported that SC still has a 4000 psi pressure rating so no need to patch, wrap SC w/denso and hooch for conductor replacement. 9/19/2006 Weld Conductor Sleeves. T/I=O/O. Assist welders with Conductor patch weld. 12' 9" conductor reinstalled w/circ nipple. Ready f/cement. lD-121 (PTD 1971810) FL inspection report . . Tom, Per Sundry # 305-031, well 1 D-121 (PTD 1971810) is required to have quarterly flowline inspection reports submitted to AOGCC when the well is on production. This email is to notify the Commission that this well has not been brought on production since 01/05/06, therefore no flowline inspection will be completed at this time. There are no plans to bring the well on production at this time. If the well is brought on line, a flowline inspection will be completed in 3 months. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 SCANNED SEP 14 20D!3 1 of 1 9/14/20069:12 AM e e WELL LOG TRANSMITTAL PRoAcrive DiAGNOSTic SERvices, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1] 2] 3] 4] 1<17-/8( 5] 6] 7] 8] Signed: Print Name: 1C - 119 MTT Report 16-May-06 1C - 121 MTT Report 16-May-06 1C - 131 MTT Report 14-Jun-06 ..-'. r~"~:C . J:~ C'f'"' 1.>. ~. f> o"!·) 10 - 127 MTT Report 14-Jun-06 ¡:J;.;¡/\v ,t;...... , 10 - 121 MTT Report 14-Jun-06 10 - 109 MTT Report 15-Jun-06 10 - 120 MTT Report 15-Jun-06 1 0 - 111 MTT Report 1 5-Jun-06 MJ òU Date: 1/ J u ~ ~ ~ ~ µ D \.U o-.,lI'À~ 0 k l Cl.~¿ PRoAcTivE DiAGNOSTic SERViCES, INC., I}O W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANCI10RAGE, AK 99<718 Pl1oNE: (907)24<7;89<71 FAX: (907)24<;;89<72 E;MAil: pdSANd¡ORAGE@¡,IEMORY!OG.CGfVJ WEbsiTE: MEMORyloG.COM c: \My Documents\ W ork\ DistributionLablesNew\ Transmit_Original. doc I I I I I e e Memory Magnetic Thickness Tool Log Results Summary /\/\Cb\ \0\\ Company: ConocoPhillips Alaska, Inc. Well: 1D-121 Log Date: June 14, 2006 Field: Kuparuk Log No. : 8033 State: Alaska Run No.: 1 API No.: 50-029-22814-00 Pipe1 Desc.: 2.875" 6.5 Ib EUE Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 190 Ft. (MD) Pipe2 Desc.: 7.625" 29.71b Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 190 Ft. (MD) Pipe3 Desc.: 16" 62.5 lb. Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) I Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. I I I I I I I I I I I I I COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total metal thickness of the 2.875" tubing, 7.625" production casing, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 2.875" tubing, 7.625" casing, and 16" conductor pipe. The total volume of metal encountered by the MIT's generated AC magnetic wave between the surface and the bottom of the 16" conductor pipe in this well exceeded the tool's rated capacity for transmission of a full clean signal. However, the data recorded appears to provide a relative indication of total metal surrounding the tool. with several intervals indicating significant metal loss. The reported percentage metal loss intervals in this report are not considered to be a percentage of any particular volume of metal. but merely a relative correlation of indicated metal loss throughout the logged interval. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 190'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show four intervals of metal loss. A maximum of (-20%) circumferencial metal loss is recorded in the interval between 45' and 52'. A maximum of (-16%) circumferencial metal loss is recorded in the interval between 39' and 43'. A maximum of (-15%) circumferencial metal loss is recorded in the interval between 21' and 27'. A maximum of (-14%) circumferencial metal loss is recorded in the interval between 8' and 18'. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 2.875", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 2.875" tubing or 16" conductor. I Field Engineer: R. Richey & J. Halvorsen Analyst: M Tahtouh & J. Burton Witness: T. Sendon I Pro.l;ctive Diagnostic Services, Inc. I ~'.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fa:<: (281) 565-1369 E-mail: PDS@mernorylog.com Prudhoe Bay Field Office Pllone: 659-2307 Fax: 659-2314 I I I I I I - ------- ------ -- - -- --~----- cI2s. Magnetic .1 (8H£ Pass) Illvl'\lltí\)\) p~ DiAqN€:JtS:ric SEmJicES,. IN(::. Database File: d:\warrior\data\1 d121\1 d121. db Dataset Pathname: log8H.1 Presentation Format: 1.8 scale Dataset Creation: Fri Jun 23 11 :26:21 2006 by Calc Sondex Warrior VI. 0 Charted by Depth in Feet scaled 1:150 . ~. . S8 (%) 50 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 y= - I ~ I I --I--~ -~ -~. ---- --- ~- -.- +~ --. -. Tree - ubing Hang - _Pup Jt._ ~ I I "'-1--14% Met~1 Loss- 1\ I -- ~ :J 27/8" I .II I Jt. 1 - mc? 5/8" Casing Collar ~ I 20 I I I I ¡.....15% Metal Loss- I I , , 1 --2 7/8" Colla I I I _ - 40 % Metal Loss I 5/8" i . ¡ Collar - I I ;II'- 20% Metal I , ì I - 27/8" -- Jt. 2 - ~.- 60 - 2 718" ( - 1- -- of 16" Conductor - '* 80 If L ! .- 1- --t- i .-.- ~.~ -... -- ." - ". I I I I I I I I I I I I I í---- ! ;5 ~> :. þ m ,~ r~ ie7l8" Jt. 3 :iIO :2 7/S" Colla t 100 ¡.¡i -- --- - I 27/8" I I-- Ji. 4 I-- , ~ 1- 120 - I J-I ~ f-- ~_.~ - .2 7/8" Colla - I Collar I i i 140 f-.~ - - . i-- - 27/8" ..- Jt 5 -.-- -.--- , --..- 1f\O I I I ¡ 1--- --- 75/8" ?asing Coll~r7/8" Jt 6 ,. , - 180 '-- C---_ ~ ~ .- '---- ~ ~. f-... -.-- - -2 718" Col ! I I II -.- ,--. .~-- ~..^- ---~ _._~ f--.~.- ~~ -"."--- I I ._._~ ---, I I ! i I -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11_8 -7 MTTP12 (rad) 3 I I II I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I II cI2s- Detail Metal Loss ures 8' - 21' p~ Di........,..,.ic; SE""i""", ¡""". Database File: d: \warrior\data\ 1 d121 \ 1 d121. db Dataset Pathname log8H.1 Presentation Format 1.8 scale Dataset Creation: Fri Jun 2311 :26:21 2006 by Calc Sondex Warrior V7.0 Charted by Depth in Feet scaled 1 :60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 ~UbinguHang Jt I I I i -.-. r ¡" ;:- :- «; ~ 14% Metal Loss- ~ I > ~ I '1 ) I - '-~ ..- ¡-- I ~ i ;,. '« I ~? '> 27/S" I ::¡ I I I < :. .~~ ~(: ~Çs I Jt. 1 \ « þ ~ ~ .! - ~-- - ¡.. 75/8" Casing Collar ot. ! 20 ¡ é:/ I l I ;, ) <: """ ""-15% Metal Loss- ~ ~ - Œl -, ~ ~ . $# \ ..-' , I ~r I-- ~. -~------ 1<" ---- ..¿ -~ <; I I I ¿ ~ ~ e-- I 2 7/8" -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 I I I I I I I I I I I I I I I I I I I ctrk Detail Metal Loss F ures - 52! PR:OAcriVE OiAqNO§.TK; SiEmCB,. INC. Database File: d:\warrior\data\ 1 d121 \1 d121 db Dataset Pathname log8H 1 Presentation Format: 1.8 scale Dataset Creation: Fri Jun 23 11 :26:21 2006 by Calc Sondex Warrior V7.0 Charted by Depth in Feet scaled 1 :60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 27/8" C I , [? 1 40 , I ~ 16% Metal LOiS ~ I I I ~ 1< I I I I T -L l.:, I 5/8" Casing Collar - ~ ~ , - +-1+ >-1 ~ ,~ r ~ l I f t ...... 20% Metal Loss I ?' I> c-_ _L. i {> I'" 2 7/B" ~ I > 1- .~'h~ $.\ , Jt 2 1-- ~l --- ..- ~ --- ;=> -=f=1 I----- , I .........- j~ ... --~ - ^-~- ..- 60 - I----- > - 5. 1_", - f--- , , , 1 1-- ,- I )-1 "- 2 7/8' .. ^-~- ~._.._-_.. ~ .. ·50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 -7 MTTP12 (rad) 3 I I I I I I I I I I I I I I I I I I I TUBING (Q,3654 00:2875. 102.441) PUMP (364&3675. 006.000) GeiJrbox (3689·3691 00:5.250) II:) 0.000 0.000 2.441 2.875 2.875 0.000 0.000 0.000 0.000 Note WAIVER ED WELL: T x IA COMMUNICATION IN PACKERLESS WELL: FAILED ESP Pert (3750-3780) Pert (3810-3840) Pert (3902-3932) Pert (3980·4010) [Fwd: ConocoPhillips Excavation & Repair Project] ) ) Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 To: Lou Grimaldi <Iou_grimaldi@admin.state.ak.us>, John Spaulding <john_spaulding@admin.state.ak.us>, John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones <jeffjones@admin.state.ak.us>, Chuck Scheve <chuck_scheve@admin.state.ak.us>, Jim Regg <j ij'n _ regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom Subject: Date: From: To: CC: -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NIB78@conocop}::¡':~..,l;L1:ps. com> tom maunder@adrnin.state.ak.us Ns'K·-weIT····..iñ·t'e·g·r:I..t"y····..·Pr·o']........·....<·Ñ'i"S..7·8@conocoph ill ip S . corn>..., aogcc 12.Tu~~~Q-1)ay@a.dmin. sta.t.e. <3.k.. us ,SCAfNNEJ) JUN \~-\"ð-\ \';'\-\~\ 2 1 2006 Tom: I don't remember how much of our plans we have shared with you on excavating and repairing wells at 1C & 1D pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However,~e will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «1C and 1D Casing Repair List AOGCC.xls» «SPE-100432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 Content-Type: application/vnd.ms-excel 1 C and ID Casing Repair List AOGCC.xls Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword lof2 6/26/20067:51 AM ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates PRIORITY NAME TYPE PTD# LEAK DEPTH (ft) ---.---- 1 1 C-121 INJ 201-080 4 -,-."._--- ..----.----- - .- - 2 1 C-131 INJ 201-185 7 -.- _·_·___·.._··_u____ . 3 1 0-1 09 INJ 197 -235 5* 4 1 0-111 INJ 198-166 5* 5 INJ 197-221 7 \~\- \ )5\ ~ 6 --...., Gas Lift 197-181 None 7 Gas Lift 198-109 None 8 1 0-132 INJ 198-121 5 9 10-136 INJ 200-046 None 10 10-137 INJ 200-047 None _L..__...."O'." 11 10-138 INJ 200-048 8 12 10-139 INJ 200-049 None ..~--_.._-_.... -.-,~ n 13 1 C-119 INJ 201-139 16 .____. .__n .__ .., _,_",_,_ _,,.......,.,...__...........--_,_~_,____---.--..---, _, 14 . .....~..~.:~.1..~~.c:.._:..:..........,~ Jet Pump 201-220 None 15 1'D-135 ESP 197 -184 None -, ... ,-,~,.'.,'~..';~.~~~~~~~,.~,.....:. ...~_..,:.:. ..~ ) 16 1'D-141 Gas Lift 200-112 None Notes: COMMENTS I STATUS - -----------,,-..,,-- Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2.10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 lUJlUì ru. . ß\ ~ ifl..JLb ~''''''7 r& Ift)I.' ,1\ v' 1 V" ' i'\ "",1;\\ Iu nl' j\ '\ o J'~LíU e ! / FRANK H. MURKOWSKI, GOVERNOR / ¡ ! / ¡ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI.ASIiA. OIL AND GAS CONSERVATION COMltlISSION MJ Loveland WI Project Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 V-\1- \6'] Re: Kuparuk River Field, West Sak Oil Pool, 1D-121 Sundry Number: 306-209 " 1, ¡;, 2\)l\tJ ';"'i'4N"~EU .JU\\) .L (, ~:Jv!-~, Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this$ay of June, 2006 Encl. IQ":}-I7'1 e Conoc~illips Alaska e P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECE\VED J\JN 1 3 2006 , C"I'M1Îssion . **a on & Gas t,Ü )S. v Anchorage -¥"" June 9, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approval to pro actively inspect and repair the production casing if needed for ConocoPhillips Alaska, Inc. wells ID-121 (PTD # 197-181) and ID-127 (PTD # 198-109). Neither well indicates any signs of a production casing leaks, however they are both drilled in an area where near surface production casing leaks have been a problem. Please call me or Jerry Dethlefs at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Sincerely, U ::L(f ~ -- Well Integrity Project Supervisor Attachments () ~s , r~/""¡!'/ ,.:llb _ RECEIVED \ '_ f'- ~ ()lr&./'t.lU<r _ ý , - STATE OF ALASKA .trc, It'""' JUN 1 3 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV A~'8ska Oil & Gas Cons. Commission 20 MC 25.280 Anchorage 1. Type of Request: Abandon D Suspend D Operational Shutdown D Alter casing D Repair well 0 Plug Perforations D Change approved program D Pull Tubing D Perforate New Pool D 2. Operator Name: 4. Current Well Class: - ConocoPhillips Alaska, Inc. 0 Development 3. Address: Stratigraphic D Perforate D Waiver D Other D Stimulate D Time Extension D Re-enter Suspended Well D Exploratory D Service D P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 112' 5. Permit to Drill Number: 197-181 6. API Number: 50-029-22814-00 ' . 9. Well Name and Number: 10-121 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit A1;:n, Z,Ç"'S"'D .b1> ¿.. ('3 -ob Kuparuk River Field /West Sak Oil 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): - -44141 43151 ~ Casing Length Size MD TVD Burst Collapse CONDUCTOR SURFACE 121' 4290' 16" 121' 4402' 121 4303 7-5/8" Perforation Depth MD (ft): 3750-3780' 381-3840',3902-3932',3980-4010' Packers and SSSV Type: no packer no SSSV - - 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Perforation Depth TVD (ft): 3652-3682, 3712-3742, 3804-3834, 3882-3912' Packers and SSSV MD (ft) Tubing Size: 2-7/8" no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Commencing Operations: 16. Verbal Approval: Commission Representative: . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Loveland / Signature ~./ ~ ~Á- / .- July 1, 2006 Date: Contact: Title: Phone 659-7043 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 6890 4790 Tubing Grade: . L-80 Tubing MD (ft): 3654' ~ Service D Plugged D WINJ D Abandoned D WDSPL D Dethlefs/Loveland WI Project Supervisor Date ~9 :rUIU"'lŸ.6 Sundry N~r, 0 _ ;:;), Cf1 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D 00.. ~~(I"...,>~'-L~," c..,. ~\c......"" ,13. 0'.1 ...;...,\ ~~'> ~\.'ó 6.."",,!:o'~ <-(\.~,....\ S"'",,",", F,"" R"",,.,, '-\~~. RBDMS BFl JUN ! 5 1006 App","'" 'y . --;~~ f:O~NER ~~~~~~".':':;'ON Form 10-403 Revised 7/2005 ~ R MN A L Date: b-/~ob ¿Šz? C· 1'3 '"Ö~ sUbAu~C:7J_D6 e e ConocoPhillips Alaska, Inc. Kuparuk WelllD-121 (PTD 197-181) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 9,2006, This application for Sundry approval for Kuparuk well1D-121 is for the proactive inspection ./ and possible repair of the production casing near surface. This well is a single casing gas lifted producer that has no surface casing. It was completed in 1998 and has been produced by ESP and gas lift. This well is in an area that has a recent rash of production casing leaks to surface and is directly adjacent to injection welllD-120 which did. 1D-121 has shown no signs or ., indications of a production casing leak however ConocoPhillips requests approval to pro actively excavate ~ 10', cut a window in the conductor and inspect the production casing in this well. If damage is present a pa~~h will be installed. With approval, repair of the production casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well as needed with KWF and load the tubing and IA with appropriate weighted brine and diesel rreeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4, Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. A wiridow will he Ci.it in approximately the top ten feet ofconductòdóprovide access to ilie- production casing for inspection. Notify AOGCC Inspector for opportunity to inspect, 6. CP AI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to wa~~.-- 12. File 10-404 with the AOGCC post repair. ~M.~\~& NSK Problem Well Supervisor 6/9/2006 e e ConocoPhmips AtaskaJ Inc. KRU 1D-121 : HI API: 500292281400 Well Type: PROD Angle @. TS: deg @. Wire #2 .Jt.".u...~ SSSV Type: None Orig Completion: 12/6/1997 Anale @ TD: 2 dea ía> 4414 (37-3008, Annular Fluid: Last W/O: Rev Reason: Waivered Well 00:1.000) ] Reference Loa: Ref Loa Date: Last Update: 12130/2003 :~¡:¡§~{::: (:::::;::.... Last Tag: 3793 TD: 4414 ftKB I!r Last Taa Date: 1/31/1998 Max Hole Anale: 26 dea @. 2428 CasinQString "ALL S1~INQ$·.·· TUBING : Description I Size I Top I Bottom I TVD I Wt I Grade I Thread (0-3654, CONDUCTOR I 16.000 I 0 I 121 I 121 I 62.50 I H-40 I 00:2.875, SURFACE I 7.625 I 0 I 4402 I 4303 I 29.70 I L-BO I 10:2.441) · Tübingstring" TUBING" : Size I Top I Bottom I TVD I Wt I Grade I Thread : : 2.875 I 0 I 3654 I 3556 I 6.50 I L-BO I EUE 8RD MOD .. ·Þerfö¡-ätiôns. Summarv.·· Interval TVD Zone Status Ft SPF Date Type Comment u 3750 - 3780 3652 - 3682 WSD 30 4 1/31/1998 IPERF 2 1/8" EJ BH; 0 deg. PUMP phasina (:J646.J675, 3810 - 3840 3712 - 3742 WSB 30 4 1/29/1998 IPERF 2 1/8" EJ BH; 0 deg. 00:6.000) phasing 3902 - 3932 3804 - 3834 WSA3 30 4 2/17/1998 IPERF 2 1/8" EJ BH 3980 - 4010 3882 - 3912 WSA2 30 4 1/21/1998 IPERF 2 1/8" EJ BH .GÌlsl.;i~ .MÌlndr'èls/Viili(ès.··" Seal Section St MD I TVD I Man Man Type I VMfr I V Type I V OD I Latch I Port I TRO I Date I Vlv (3676-3689, Mfr Run Cmnt 00:6.750) 1 I 35891 34911 Camco I KBMM I I OV I 1.0 I BK I 0.188 I 0 19/25/2002 I (1) 1. NO CHECK Otherll luris;ë u¡p~ 'etcj-JI:WËL~Y.·. : Depth TVD Type Description ID Gearbox 37 37 Wire # 1 Raychem Heat Traèe (Bottom Depth 1309') 0.000 (3689-3691, 37 37 Wire # 2 ESP Electric W/I \lIMe Cable (Bottom Depth 3698') 0.000 00:5.250) 3632 3534 Handling 27/8,6.5#, EUE 8rd Mod 2.441 Pup 3633 3535 GAUGE BAKER SENTRY GAUGE @ DISCHARGE OF PUMP 2,875 3636 3538 GAUGE BAKER SENTRY GAUGE @. PUMP INTAKE 2.875 Molor 3646 3548 PUMP Tubina Retrievable Pump wI Flex shaft and intake (180TP2000) 0.000 (3691-3698, 3676 3578 Seal GSFT DB HL PFS 0.000 00:5.625) Section SURFACE 3689 3591 Gearbox 9:1 525 Series 0.000 (~, 3691 3593 Motor PC ESP 57 HP 1315/26 KMH 0.000 00:7.625, WI:29.70) Date ' INote , . " ,." ., : 2I30/2003/WAIVERED WELL: T x IA COMMUNICATION IN PACKER LESS WELL; FAILED ESP : -' f- Perf - I-- (3750-3780) _: I-- Perf _: I-- (3810-3840) -: '1-- = '-.= - ,.- -. - - -: - -.f- - - -'f- - - ==:1= - == Perf -'f- - (3002-3932) - f- - -; - -'r- - - f- :- Perf ==:- '= -; :- (3980-4010) - - -; -: - -; - -' ,- Quarterly Flowline inspections lD-121 (PTD 197-181) June '06 e e Tom, Per Sundry # 305-031, well 1 D-121 (PTD 197-181) is to have quarterly flowline inspections completed when the well is online. The email is to notify the Commission that this well has remained SI since 01/05/06, therefore the flowline inspection was not completed. If the well is brought on line a flowline inspection will be completed in 3 months. Let me know if you have any questions. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 í£CANNED JUN 1 ~~ 2D05 '\ 1 of 1 6/12/2006 12:02 PM 1 D-121 (PTD 197-181) - Quarterly FL inspection report e e Tom, 1 D-121 was SI on 1/ 5/06 due to continual hydrate problems on gas lift. The current plan is to leave the well SI until a RWO repairs the ESP. Since there were less than 30 days of flow time since the last flowline inspection, no flowline corrosion inspection has been completed since the last quarterly report was submitted on 12/1/05. 10-121 is a failed ESP will operating under sundry approval 305-031 for reverse flow gas lift with production up the IA. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 ~CÅJ~N~~); .,..:,_ ';;i; 1 of 1 ~~ ~~'Ç~ ~\.~ 6/12/2006 12:02 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well D Pull Tubing D Ope rat. ShutdownD 25 2005 Stimulate D Other. D L\\::ask"" )" I"> ' '.d~;'" Waiver 121 rTl'me~>tte~i?rn'[;Q~ge Re-enter Suspended Well 0 5. Permit to Drill Number: 197-181 6. API Number: 50-029-22814-00 Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE Perforation depth: Plug Perforations D Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 121 Stratigraphic 0 Exploratory 0 Service D 9. Well Name and Number: 10-121 10. Field/Pool(s): 'West Sak Oil Pool measured 4414' feet true vertical 4315' feet measured feet true vertical 6276' feet Length Size MD 121' 16" 121' 4290' 7-5/8" 4402' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4303' Measured depth: 3750-3780,3810-3840,3902-3932,3980-4010 md true vertical depth: 3652-3682,3712-3742,3804-3834,3882-3912' SCANNED FES 242005 Tubing (size, grade, and measured depth) 2-7/8", L-80, 3654' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 0 0 40 115 15. Well Class after proposed work: Exploratory 0 Development 0 Service D 16. Well Status after proposed work: oil0 Gas 0 WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. ExelT)pt: 30S- éJ ~I Oil-Bbl 0 200 CasinQ Pressure Tubinq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X 254 WDSPLD Contact Brad GathmanlMJ Loveland @ 659-7224 Printed Name. Brad Gathman / /' Ti~e Problem Wells Supervisor Signature /~~ þ'J; ¿ -~. Ph~~ALo05 907-659-7224 Date ¡qFehð(ç Form 10-404 Revised 04/2004 IW."""" S BFL FE8 2 S 2005 Submit Original Only 1 D-121 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/16/2005 Return well to production with reverse flow gas lift, (Gas lift down tubing production up annulus) 2/17/200411 nitiate quarterly flowline inspections ) ) FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA ORAND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 , I C7 - I ~ I Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99501 Re: West Sak 1D-121 Sundry Number: 305-031 Dear Mr. Dethlefs: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls~n a iday or weekend. A person may not appeal a Commission decision to Superior" our: unless rehearing has been requested. to. Inc r ~, , ./ "-- .N "--- DATED thisiL day of February, 2005 Enc!. SCANNED FEB 1 5 2005 ) ConocJP'hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 / /f6 \ \C\ February 9, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. West Sak well1D-121 (PTD 1971810). The approval request regards gaslift production of the well with a failed ESP. Please call Brad Gathman or MJ Loveland at 659-7224 or me at 659-7043 if you have any questions. Sincerely, f?-/C~ Jerry Dethlefs Problem Well Supervisor Attachments OR\G\NAL 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit ) ) 4/(( r~ ; ~ j)., t'Ç¡Ç\~ [!"~) {':c "'Øw~i~er ,'\f7"~' Annular Disp. .'~-r'r,¡,:! Time Exte~-s;~~' ~ tJ } '~ Other 0 Re-enter Suspended Well 0 4. Current Well Class: Development - 0 Stratigraphic 0 Exploratory 0 Service 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 0 0 0 Suspend 0 Repair well 0 Pull Tubing 0 Perforate 0 Stimulate 0 5. Permit to Drill Number: 197 -181 6. API Number: 50-029-22814-00 9. Well Name and Number: 1 D-121 10. Field/Pool(s): West Sak Oil Pool Size MD 16" 121' 7-5/8" 4402' TVD 121 4303 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): 44141 4315' Casing Length Perforation Depth MD (ft): 3750-3780, 3810-3840,3902-3932,3980- 4010 md Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~rry Dethlefs /) Signature 7-e.e.-e-d C'J~ Commission Use Only CONDUCTOR SURFACE 121' 4290' Perforation Depth TVD (ft): Tubing Size: 3652-3682,3712-3742,3804-3834,3882-3912' Packers and SSSV MD (ft) 2-7/8" 02/15/05 Date: no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-7224 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Burst Collapse Tubing Grade: Tubing MD (ft): L-80 3654' Service 0 Plugged 0 WINJ 0 Abandoned D WDSPL 0 Gathman/Loveland 659-7224 Problem Well Supervisor Date «hA.s- Sundry Number: dèJS--03! Mechanical Integrity Test 0 Location Clearance 0 ~C ~O¥'\ ~ \eF.~\{'I) ù':>? \û~~J. ... S<..H'<;)"'ì «-'( r\~ "> ,;}/I5"" -0 1 OR\G\NAL RBDMSBFLFEB141005,/.( COMMISSIONER ~~~~~~~~~ION Date: PJ!;/¡ () INSTRUCTIONS ON REVERSE Submit lD~I;cate '-- ) ) ConocoPhillips Alaska, Inc. WestSak WelllD-121 (PTD# 1971810) SUNDRY NOTICE 10-403 VARIANCE REQUEST 2/09/2005 The purpose of this Sundry Notice is for approval to extend the length of Sundry #303-258 for a 24-month period. The approval is for gaslift production ofa failed ESP producing well. West Sak we1l1D-121 was placed on temporary gaslift in September 2002 after the ESP pump failed. Temporary piping was installed in the wellhouse to enable lift gas injection down the tubing with production up the annulus (IA). Sundry Approval 302-304 (10/3/2002) allowed the well to be gaslifted in this configuration for one year. Sundry Approval 303-258 (9/2/2003) extended the period for another year, until 10/1/2004. However, the well ';~~ shut in on . 8/30/2003 and the temporary piping was dismantled because of safety and operational concerns and a permanent gaslift line was installed (hardline was replaced with permanent piping). A baseline flowline inspection was done on 10/19/02 with subsequent inspections showing no eros~on (inspection form attached). lD-121 produced -244 bopd with an ESP and ~223 bopd~ gash ft.. ~ ßd"- b~ \' cJ ~ The previous approvals allowed lift gas to be injected down the tubing with resulting production up the annulus (IA). ConocoPhillips proposes in this request to: 1. Continue producing the well in it's "non-conventional" arrangement; i.e., gaslift is injected down the tubing with resulting production up the IA to the flowline; 2. Continue the quarterly flowline inspection schedule that was previously approved for this well with submittals to the AOGCC; 3. Approve the production request for 24 months from the approval date. 4. Review the conditions with the AOGCC at the end of the approved period for a plan forward. ~t ~.Q \\ ~'7~O~ \?\'Dt)0C~2) ")\ ,,,,,--Q. OC-\õ~~c dOO""S.. , \.. (¡¡~ \- ~ \c> \>-J \ '\ Nc '\ "-<;,. ?~'--~ 0 "" \NOt. ~ '17,.\ - 0 ~ -9 d\ J "'-ù .\. \ ",¿h Co. -tE. (). r-, 't \J m \, \ u"\ S . O.?~w\-\~ '.ð'ù\L<?". CS?~.'~."'.\r'rD\N. '~\\~~s b~E'~ f2^V~~~' . <A?\)\()~J. \Nc\« \s \'G ~«s\ -\b,ç~<:,>h. vJG\h ., C ~I ~\O-¡,,,,> \-ò \"'\~'\Q\e.- \-\'-G. .\I'-\~p~C\-'ìé)Î\ f~\CU~ Þ Th -.j \ Ö\0 '::> \, t.<. C CC: (\1\ f \'\s- \-.c,,~ ", -L . tcCÒ ('^.~~£;) aPf'00Q \, Æfìvl~- '>~ :>/ t ¡ ~O~ ) The following is the inspection log results: 1 D-121 Special Inspection Request Log DS1D 1D-121 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of #of Worst Case Damage Inspection B, I, N Comments Inspection Locations Wall Loss % Grade 10/19/02 6 B 0% A Base Line Inspection 10/21/02 6 N 00/0 A 1 - Day Follow-up Inspection 11/04/02 6 N 0% A 2-Week recur inspection 11/20/02 6 N 0% A 2-Week recur inspection 12/05/02 6 N 0% A 2-Week recur inspection 01/06/03 6 N 0% A Monthly Inspection Interval 01/29/03 6 N 0% A Quarterly Inspection Interval 04/30/03 6 N 0% A Quarterly Inspection / No Changes 07/27/03 6 N 0% A Quarterly Inspection / No Changes ) ~ cOnOCOPhiIliPSI~12~Ska.ht~. r API: 500292281400 Wire # 2 ~ SSSV Type: None (37-3698, i Annular Fluid: 00:1.000) - 't.. ~~ - Reference Log: ~.:';,.'. Last Tag: 3793 .~.: . ., Last Date: 1/31/1998 ~ !. ~ ~ ì ~ ì w ".I I W I TUBING (0-3654, 00:2.875, 10:2.441 ) PUMP (3646-3675, 00:6.000) Seal Section (3676-3689, 00:6.750) Gearbox (3689-3691, 00:5.250) Motor (3691-3698, 00:5.625) SURFACE (G4402, 00:7.625, Wt:29.70) Perf (3750-3780) Peri (3810-3840) Perf (3902-3932) Peri (3980-4010) 1 i! ~ ~ I '1 if I 1.I'j I t, : [ . ~ I ¡ ~ S ~ i ¡ ~ ~ I ! ~ i ¡ I I I I ¡ ~ I j =1= oIÍ~ .: ~ I Id!1 Ii ~; !~::I ;;" 4\ i, !II'" ". "'IIii~ < !la.h,'\~ .~It.r u . ~t. ~if ~""' '''"'1 ~~~: ;¡.'!¡ ~i. '''''1' . "g. "."."" _.1 ..~~!jl~! i..."," =f ) KRU 1 D-121 TVD 3652 - 3682 3712 - 3742 3804 - 3834 3882 - 3912 Type Wire # 1 Wire # 2 Handling Pup GAUGE GAUGE PUMP Seal Section Gearbox Motor Top 0 Well Type: PROD Orig Completion: 12/6/1997 Last W/O: Ref Log Date: TD: 4414 ftKB 26 2428 Angle @ TS: deg @ Angle @ TD: 2 deg @ 4414 Rev Reason: Waive red Well Last Update: 12/30/2003 Max Hole Description CONDUCTOR SURFACE Size Size 16.000 7.625 Top Bottom TVD Wt Grade Thread 0 121 121 62.50 H-40 0 4402 4303 29.70 L-80 TVD Wt Grade Thread 3556 6.50 L-80 EUE 8RD MOD Bottom 3654 Status Ft SPF Date 30 4 1/31/1998 Interval 3750 - 3780 3810 - 3840 3902 - 3932 3980 - 4010 Zone WSD Type Comment IPERF 2 1/8" EJ BH; 0 deg. phasing IPERF 2 1/8" EJ BH; 0 deg. phasing IPERF 21/8" EJ BH IPERF 21/8" EJ BH WSB 30 4 1/29/1998 WSA3 WSA2 30 4 2/17/1998 30 4 1/21/1998 St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 3589 3491 Cameo KBMM 1. NO CHECK OV Date Vlv Run Cmnt 0 9/25/2002 (1 ) 1.0 BK 0.188 Depth TVD 37 37 37 37 3632 3534 3633 3535 3636 3538 3646 3548 3676 3578 3689 3591 3691 3593 Description Raychem Heat Trace (Bottom Depth 1309') ESP Electric W/I Wire Cable (Bottom Depth 3698') 2 7/8, 6.5#, EUE 8rd Mod ID 0.000 0.000 2.441 BAKER SENTRY GAUGE @ DISCHARGE OF PUMP BAKER SENTRY GAUGE @ PUMP INTAKE Tubing Retrievable Pump w/ Flex shaft and intake (180TP2000) GSFT DB HL PFS 2.875 2.875 0.000 0.000 9:1 525 Series PC ESP 57 HP 1315/26 KMH 0.000 0.000 Date Note WAIVERED WELL: T x IA COMMUNICATION IN PACKERLESS WELL; FAILED ESP -1- ¡ -"--- FW: ID-121 Quarterly Inspection Results ) ) Subject: FW: ID-121 Quarterly Inspection Results From: NSK Problem Well Supv <n1617@conocophillips.com> 'Date: Fri, 11 Feb 2005 13:17:44 -0900 To: Thomas Maunder <tom ßaunder@admin.state.ak.us> \~\ \<\"\/ Tom, You are right there is a more current inspection report version than what was submitted in the 1 0-403. I have forwarded you a copy in the email below. The well was SI 10/30/03 and the inspection schedule terminated at that time. We will re initiate the inspection schedule upon Sundry approval to flow the well. let me know if I can provide any more data. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Corr DS Coord Sent: Friday, February 11, 2005 1: 12 PM To: NSKProblem .Well Supv . . . Subject: FW: 1D-121 Quarterly Inspection Results Here you go MJ! If you need anything else let me know. George -----Original Message----- From: NSK Carr DS Coord Sent: Sunday, February 01, 2004 1:28 PM To: CPF1 Prod Supv Cc: CPF1 Prod Engr; CPF1 DS Lead Techs; CPF1 Control Room; NSK Carr Insp Piping; NSK DS Fac Engr; NSK Full Field Prod Engr; NSK Engr&Corr Supv; NSK Problem Well Supv; NSK Carr Vessel Insp; NSK Corr Chem&Monitoring Subject: 1D-121 Quarterly Inspection Results JohnNan, On 1/31/04 we completed our quarterly follow-up inspection on the drillsite 10-121 riser and flowline. This inspection was originated due to our agreement with the AOGCC over concerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-1022-F4.4) due to production of this well through the annulus. The results are as follows: Action Items: None 1 of2 2/11/2005 1 :33 PM FW: 1 D-121 Quarterly Inspection Results ') ) Damage Summary: No changes were noted from our previous inspection performed on 10/27/03. This inspection consisted of Ultrasonic inspection of the 2 elbows located at the wellhead on the 3" .production line and Radiographic inspection on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for our inspection summary on 1 0-121. Future Inspection Plans: We will continue to re-inspect these locations on quarterly inspection frequency in accordance to the schedule agreed upon with the AOGCC as referenced in your e-mail dated 11/21/02. All UT data and film is on file with the Corrosion Dept. and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or AI Dahlquist at ext 7773. Thank you, George Foley OS Inspection Coordinator NSK-39 n 1 016@2conocophi!!ips.com Office: (907) 659-7209 «10-121 Inspection Log.xls» ID-121 Inspection Content-D~s~ription: 1D-121 Inspection Log.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 2/11/2005 1 :33 PM ') ) 1D:121 Special Inspection Request Log Ds1D 1D-121 Revised Date: 2/1/04 GMF - 2 in. Annulus flowback inspection 8, I, N - (8 - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of #of Worst Case Damage Inspection 8, I, N Comments Inspection Locations Wall Loss % Grade 10/19/02 6 B 0% A Base Line Inspection 10/21/02 6 N 0% A 1 - Day Follow-up Inspection 11/04/02 6 N 0% A 2-Week recur inspection 11/20/02 6 N 0% A 2-Week recur inspection 12/05/02 6 N 0% A 2-Week recur inspection 01/06/03 6 N 0% A Monthly Inspection Interval 01/29/03 6 N 0% A Quarterly Inspection Interval 04/30/03 6 N 0% A Quarterly Inspection / No Changes 07/27/03 6 N 0% A Quarterly Inspection / No Changes 10/27/03 6 N 0% A Quarterly Inspection I No Changes 01/31/04 6 N 0% A Quarterly Inspection / No Changes P:\Tracking SS\1D-121 Inspection Log-1.xls CP AI 1 st Quarter 2004 Flowline Inspections Subject: CPAI 1st Quarter 2004 Flowline Inspections From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 04 Apr 200414:07:31 -0800 To: "Tom Maunder AOGCC (E-mail)" <tom_maunder@admin.state.ak.us> Tom: Attached are the latest flowline inspection reports for ConocoPhillips note that wells lD-105A and lD-121 are both shut-in with reservoir problems inspections. We will resume the inspections if and/or when the wells return and inspections will continue, but the well will (hopefully) get a workover annular flow. wells that have annular flow. Please and we have suspended the flowline to production. Well 3H-05 is flowing this summer and will no longer have Please call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 «lD-10SA Qrty Inspection.doc» «lD-121 Qrty Inspection.doc» «3H-05 Qrty Inspection.doc?> Content-Description: 1D-105A Qrty Inspection.doc ;lD-IO5A Qrty Inspection.doc Content-Type: applicationlmsword Content-Encoding: base64 . .. .-.....- 7 \~~ -\~\ Content-Description: 1D-121 Qrty Inspection.doc ID-121 Qrty Inspection.doc Content-Type: applicationlmsword Content-Encoding: base64 Content-Description: 3H-05 Qrty Inspection.doc . 3H-O5 Qrty Inspection.doc : Content-Type: applicationlmsword I : Content-Encoding: base64 I of 1 4/5/20047:46 AM -----Original Message----- From: NSK Carr OS Coord Sent: Sunday, February 01,20041:28 PM To: CPH Prod Supv Cc: CPH Prod Engr; CPF1 DS Lead Techs; CPF1 Control Room; NSK Carr Insp Piping; NSK DS Fac Engr; NSK Full Field Prod Engr; NSK Engr&Corr Supv; NSK Problem Well Supv; NSK Carr Vessel Insp; NSK Carr Chem&Monitoring 10-121 Quarterly Inspection Results Subject: JohnNan, On 1/31/04 we completed our quarterly follow-up inspection on the drillsi 1 D-121 ris rand flowline. This inspection was originated due to our agreement with the AO Cover oncerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-1 D - .4) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 10/27/03. This inspection consisted of Ultrasonic inspection of the 2 elbows located at the wellhead on the 3" production line and Radiographic inspection on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for our inspection summary on 1 D-121. Future Inspection Plans: We will continue to re-inspect these locations on quarterly inspection frequency in accordance to the schedule agreed upon with the AOGCC as referenced in your e- mail dated 11/21/02. All UT data and film is on file with the Corrosion Dept. and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or AI Dahlquist at ext 7773. Thank you, George Foley DS Inspection Coordinator NSK-39 n1016@conocophillips.com Office: (907) 659-7209 LJuarterly I'lowline inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "n1617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1 D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1 D-110A: PTD 2000390, Sundry #302-227 1 D-121: PTD 1971810, Sundry #302-304 1 D-127: PTD 1981090, Sundry #353-057 1D-129: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1D-102 Insp Log.xls)(See attached file: 1D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) ,/,'l'r:-~ i Name: 3H-05 Quarterly Inspection Log.xls :~] 3H-05 ......... Quarter y Inspection Log~xls/: Type'. EXCEL File (appl cation/msexce ) Name: 1D-102 Insp Log.xls 1 Type: EXCEL File (application/msexcel)l Encoding: base64 ~]1 D-105 Inspection Lo.q.xls Name: 1D-105 Inspection Log.xls t Type: EXCEL File (application/msexcel)ii Encoding: base64 ]~1D-110 Insp .Lo,q..xlsI Type: EXCEL File (application/msexcel)] ] .I Encoding: base64 Type: EXCEL File (application/msexcel)iI Encoding: base64 iI I1 D-127 Inspection Loq,xls Type: EXCEL File (application/msexcel)! Encoding: base64 I 1 of 2 :~,.,OAt'~;; I~EO ~'~ 200,,~ 10/6/2003 3:17 PM L~uarl. erly llowline inspection reports I Name: 1D-129 Inspection Log.xls 1D-129 Inspection Loq.xls Type: EXCEL File (application/msexcel) Encoding: base64 ,¢/~ [~-~ 1Do140 Inspection Lo.q.xls Name: 1D~140 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding' base64 of 2 10/6/2003 3:17 PM 1D-121 Special Inspection Request Log DS1 D 1D-121 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of I Worst Case I Damage Inspection Inspection B, I, N I Wall Loss % Grade I Locations I 10/19/02 6 B 0% A 10/21/02 6 N 0% A 11/04/02 6 N 0% A 11/20/02 6 N 0% A 12/05/02 6 N 0% A 01/06/03 6 N 0% A 01/29/03 6 04/30/03 6 07/27/03 6 Comments Base Line Inspection 1 - Day Follow-up Inspection 2-Week recur inspection 2-Week recur inspection 2-Week recur inspection Monthly Inspection Interval N 0% A ~ Quarterly Inspection Interval N .... 0% -- ' ~'A _...j~uarterly Inspection / No Changes .j_-~--NJ-- 0% ~ Quarterly Inspection / No Changes ConocoPhillips Nina Woods/MJ Loveland Problem Well Supervisor P.O. Box 100360, NSK 69 Anchorage, AK 99510-0360 Phone 907-659-7224 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 70` Avenue, Suite 100 Anchorage, AK 99501 August 24, 2003 Dear Mr. Maunder: Encl. osed please find a 1.0-403 Sundry Notice variance :request for Phillips Alaska, Inc., West Sak well 1D-121. The variance request is to extend the length of Sundry (#302-304) to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call MJ Lovelan.d or myself at 907-659-7224 :if you have any questions. Since~)ej~, ConocoPhillips Problem Well Supervisor ORIBINAL 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 _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _X 2. Name of Operator ConocoPhillips Alaska, Inc, 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 179' FNL, 599' FEL, Sec. 23, T11N, R10E, UM At top of productive interval At effective depth At total depth 717' FNL, 868' FEL, Sec. 23, T11N, R10E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service_ (asp's 560490, 5959485) (asp's 560225, 5958945) 6. Datum elevation (DF or KB feet) RKB 112 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-121 9. Permit number/ap.j~oval number 197-181 10. APl number 50-029-22814 ~' 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured 4414 feet Plugs (measured) true vertical 4315 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented CONDUCTOR 121' 16" 9 cu yds High Early SURFACE 4290' 7-5/8" 426 sx AS III, 384 sx Class G Measured Depth 121' 4402' True vertical Depth 121' 4303' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3750-3780,3810-3840,3902-3932,3980-4010 md 3652-3682,3712-3742,3804-3834,3882-3912tvd 2-7/8",6.5#, L-80 Tbg @ 3654' MD. Packerless completion with no SSSV RAYCHEM HEAT TRACE (BOTTOM DEPTH 1309') 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedNine d$~~~ Title: Problem Well Supervisor Questions? Call Nine Woods/MJ Loveland 659~7224 Date 8/26/03 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ~.& ~)"~-G.._~;..~ tO ~ _ .,"-, , I Approval ear t~ce Plug integrity_ BOP Test_ Location cl a _ Mechanical Integrity Test Subsequent form required 10- .... Approved by order of the Commission ~,~'~--~ ~¢--,,.--,-,.. ~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Wire 1 D-121 (37-3698, OD:I.000) (0-3654, 0D:2.875, ID:2.441) PUMP (3646.3675, OD:6,000) Seal Section (3676-3689, OD:6.750) Gearbox (368~691, OD:5.250) (3691-3698. 0D:5.625) SURFACE (0-4402. 0D:7.625. Wt:29.70) KRU 1D-121 APl: 500292281400 SSSV Type: None Annular Fluid: Reference Lo LastTa 3793 1/31/1998 - ALL STRINGS CONDUCTOR SURFACE TUBING Size 2.875 0 Perforations Summary Interval TVD 3750-3780 3652-3682 3810-3840 3712-3742 3902-3932 3804-3834 3980-4010 3882-3912 Gas :Lift MandrelS/ValVeS Well Type:I PROD Orig 112/6/1997 Completion:I Last W/O:I Ref Loci Date:I TD:14414 flKB Max Hole An~lle:126 deg (~ 2428 Size Top Boffom TVD 16.000 0 121 121 7.625 0 4402 4303 Angle (~ TS:ldeg @ Angle @ TD:I2 deg @ 4414 I Wt Grade Thread 62.50 H-"40I I 29.70 I L-.80 I Bottom TVD Wt Grade I Thread 3654 3556 6.50 L-80 I EUE 8RD MOD IZone I StatuslFt ISPFI Date I Type I Comment WSD I I30 I 4 11/31/19981 IPERF 12 1/8"EJBH;0deg. I I I I I Iphasing ws B I I 30 I 4 11/29/19981 IPERF 12 1/8" EJ B'H; 0 deg. I I I I I Iphasing WSA2 I I 30 I 4 11/21/199811PERFI21/8"EJBH Vlv Cmnt 'I. NO CHECK Wire # 1 Wire # 2 Handling GAUGE GAUGE PUMP Seal Section Gearbox Motor Description Heat Trace ESP Electric W/I Wire Cable (Bottom Depth 3698') 2 7/8, 6.5#, EUE 8rd Mod BAKER SENTRY GAUGE (~ DISCHARGE OF PUMP BAKER SENTRY GAUGE (~ PUMP INTAKE Flex shaft and intake (180TP2000) GSFT DB HL PFS ID 0.000 0.000 2.441 0.000 0.000 0.000 0.000 9:1 525 Series 0.000 PC ESP 57 HP 1315/26 KMH 0.000 Peri (3750-3780) Perf (3810-3840) Peri (3902-3932) Perf (3980-4010) ConocoPhillips Alaska, Inc. Kuparuk Well 1D-121 (PTD# 1971810) SUNDRY NOTICE 10-403 VARIANCE REQUEST 8/14/2003 The purpose of this Sundry Notice is for approval to extend the length of Sundry #302-304 for a temporary 12-month period. West Sak well 1D-121 is an ESP completion that operates under Sundry (#302-304) approval to produce with gaslift down the tubing after the ESP failed. The original Sundry was approved for 1.2 months, which expires on 10/01/03. A baseline inspection was done on 10/19/02 with subsequent inspections showing no erosion. The latest production test on 7/21/03 recorded 215 bopd, 50 bwpd with 375 mscfd of lift gas. The current sundry was approved on 10/03/02, which allowed lift gas to 'be injected down the tubing and production up the annul'us. ConocoPhillips proposes to maintain an inspection schedule that was approved for all identical Sundry requests. Future Inspection Plans: Recurring Quarterly inspection schedule will be as follows: Submit inspections on a quarterly basis to the AOGCC. ConocoPhillips proposes that the AOGCC approve the above variance request for twelve months from the approval date. Attached is a wellbore schematic. OR!6INAL The following is the inspection log results: 1D-121 Special Inspection Request Log DS1 D 1 D-121 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of Inspection # of Inspection Locations Worst CaseI N Grade B, I, IWall Loss °/oI Damage /'0% ~ 0% 0% \ 0% \ 0% 0% | 0% 0% ! 10/19/O2 1 O/21/O2 11/04/02 11/2O/O2 12/05/02 01/06/03 01/29/O3 O4/30/03 O7/27/O3 B N N N N N N N N Comments Base Line Inspection 1 - Day Follow-up Inspection 2-Week recur inspection 2-Week recur inspection 2-Week recur inspection Monthly Inspection Interval Quarterly Inspection Interval Quarterly Inspection / No Changes Quarterly Inspection / No Changes Summary by Month: Individual Well Production 2002 Jan Feb Mar Apr May Jun Jul Au~ Sep Oct Nov Dec Meth Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 31 8 12 28 31 Oil 8,280 7,416 8,175 7,762 7,891 7,979 8,182 8,146 1,982 3,680 4,972 6,131 Wtr 2,921 2,834 2,262 2,206 2,097 2,! 36 2,143 1,934 484 1,080 1,020 1,789 Gas 1,377 1,118 1,321 1,459 1,541 1,475 1,464 1,479 369 805 839 1,029 2002 Totals: Oil 80,596 Water 22,906 Gas 14,306 CumOil 528,045 CumWtr 89,149 Cum Gas 106,841 2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 29 30 Oil 6,530 6,042 7,232 7,409 5,866 6,092 6,524 Wtr 1,896 1,744 2,162 2,182 1,548 2,046 2,277 Gas 801 1,128 2,418 2,077 1,101 1,302 1,299 2003 Totals: Oil 45,695 Water 13,855 Gas 10,126 CumOil 573,740 CumWtr 103,004 CumGas 116,967 Page 2 Summary by Month: Individual Well Production Well Name: KUPARUK R1V U WSAK 1D-121 Field/Pool: KUPARUK RIVER, WEST SAK OIL 1998 Jan Feb Mar API: 50-029-22814-00-00 Permit to Drill: 1971810 Sales Cd: 40 Acct Grp: 104 Final Status: 1-OIL Apr May Jun Jul Aug Operator: CONOCOPHILLIPS ALASKA INC Current Status: 1-OIL Sep Oct Nov Dec Meth Flowing Flowing Days 10 31 Oil 971 10,422 Wtr 789 500 Gas 318 4,756 1998 Totals: Oil 110,468 Water 3,070 1999 Jan Feb Mar Apr May Flowing Flowing Flowing Flowing Flowing 30 31 30 31 31 10,321 10,458 11,586 12,557 11,774 385 321 316 115 30 5,464 5,264 4,015 3,325 3,970 Gas 30,971 Cum Oil 110,468 Jun Jul Flowing Flowing Flowing Flowing 30 31 30 31 10,374 10,603 10,762 10,640 6 35 232 341 639 1,339 605 1,276 Cum Wtr 3,070 Aug Sep Cum Gas 30,971 Oct Nov Dec Meth Flowing Flowing Flowing Days 31 28 31 Oil 10,307 9,530 10,628 Wtr 514 573 1,200 Gas 1,239 3,566 2,096 1999 Totals: Oil 129,111 Water 19,038 2000 Jan Feb Flowing Flowing Flowing Flowing Flowing 30 31 30 31 31 11,336 11,598 11,194 11,512 11,226 1,357 1,565 1,598 1,833 2,066 1,206 1,946 1,788 1,671 1,685 Gas 22,084 CumOil 239,579 Mar Apr May Jun Jul Flowing Flowing Flowing Flowing 30 31 30 31 10,503 10,323 9,639 11,315 2,119 1,925 1,979 2,309 1,526 2,031 1,443 1,887 Cum Wtr 22,108 Aug Sep Cum Gas 53,055 Oct Nov Dec Meth Flowing Flowing Flowing Days 31 29 31 Oil 12,616 13,040 15,782 Wtr 2,272 2,318 2,808 Gas 2,174 2,054 3,098 2000 Totals: Oil 117,540 Water 19,705 2001 Jan Feb Flowing Flowing Flowing Flowing Flowing 30 3l 30 31 31 13,354 10,949 7,657 7,865 7,708 2,082 1,554 1,333 1,207 1,149 2,884 2,291 1,320 1,513 1,653 Gas 23,146 Cum Oil 357,119 Mar Apr May Jun Jul Flowing Flowing Flowing Flowing 30 31 30 31 7,011 7,274 6,986 7,298 1,028 1,099 1,274 1,581 1,540 1,693 1,516 1,410 Cum Wtr 41,813 Aug Sep Cum Gas 76,201 Oct Nov Dec Meth Flowing Flowing Flowing Days 31 28 31 Oil 7,378 6,556 7,489 Wtr 1,734 1,572 1,794 Gas 1,323 1,210 1,363 2001 Totals: Oil 90,330 Water 24,430 Flowing Flowing Flowing Flowing Flowing Flowing Flowing Flowing 30 31 30 31 31 30 31 30 7,219 7,600 7,387 7,460 7,370 7,313 7,833 8,293 1,731 1,776 1,818 2,121 2,195 2,258 2,469 2,407 1,172 1,432 1,304 1,254 1,374 1,255 1,556 1,535 Gas 16,334 Cum Oil 447,449 Cum Wtr 66,243 Cum Gas 92,535 Flowing 31 8,432 2,555 1,556 Tuesday, September 02, 2003 Page I Quarterly Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "n1617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) Name: 3H-05 Quarterly Inspection Log.xls ~__~3H-05 Quarterly Inspection Loq.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~1D-102 Insp Log.xls Name: 1D-102 Insp Log.xls t Type: EXCEL File (application/msexcel)1 Encoding: base64 I.¢,'-' Name: 1 D-105 Inspection Log.xls :~[¢[~ 1D-105 Inspection Lo,q.xls Type: EXCEL File (application/msexcel) Name: 1D-110 Insp Log.xls r~l D-110 EXCEL File I nsp Lo,q.xls Type: (application/msexcel) Encoding' base64 ¢~1D-121 Inspection Log.xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 1 of CANNED 'JUL 1 2.003 7/14/2003 10:39 AM 1D-121 Special Inspection Request Log DS1D 1D-121 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of B, I, N Inspection 10/19/02 B 0% 10/21/02 N 0% A 11/04/02 N 0% 11/20/02 N 0% 12/05/02 N 0% 01/06/03 N 0% 01/29/03 N 0% A 04/30/03 N 0% # of Inspection Locations 6 6 6 6 6 6 Worst Case I Damage Wall Loss %1 Grade Comments Base Line Inspection 1 - Day Follow-up Inspection 2-Week recur inspection 2-Week recur inspection 2-Week recur inspection Monthly Inspection Interval Quarterly Inspection Interval Quarterly Inspection / No Changes West Sak Well 1D-121 One Day Follow-up Inspection Subject: West Sak Well 1D-t21 One Day Follow-up Inspection Date: Wed, 23 Oct 2002 16:51:15 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak.us Tom: Attached is a corrosion inspection on West Sak well 1 D-121. The inspection shows no damage. Please call if you have any questions. Jerry Dethlefs ConocoPhillips Problem Well Supervisor ..... Forwarded by NSK Problem Well Supv/PPCO on 10/23/2002 04:50 PM ..... NSK Full Field Prod Engr 10/23/2002 09:38 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: 1D-121 One Day Follow-up Inspection Ryan Dunn / Jason Brink Phillips Alaska Inc. Kuparuk Fullfield / West Sak Production Engineers ph: (907) 659-7061 fax: (907) 659-7314 ..... Forwarded by NSK Full Field Prod Engr/PPCO on 10/23/2002 09:38 AM NSK Corr DS Coord 10/22/2002 02:36 PM To: CPF1 Prod Supv/PPCO@Phillips cc: CPF1 DS Lead Techs/PPCO@Phillips, NSK Corr Insp Piping/PPCO@Phillips, NSK DS Fac Engr/PPCO@Phillips, NSK Corr Vessel Insp/PPCO@Phillips, NSK Engr&Corr Supv/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips Subject: ID-121 One Day Follow-up Inspection Carey/VVarren, On 10/21/02 we completed our one day follow-up Radiographic and Ultrasonic inspection of well 1D-121. This inspection was requested by the Drillsite Leads after we establish baseline inspection data prior to production of this well through the annulus. The results are as follows: Action Items: None 1 of 2 ,~CANNE~,~ NOV .'j. g ;)002 10/24/2002 7:27 AM West Sak Well 1 D~121 One Day Follow-up Inspection Damage Summary: No damage on the one day follow.up inspection data has been noted. Our inspection consisted of Ultrasonic inspection of the wellhead riser and radiographic inspection of the divert tee and lower elbows to the Test & Production Headers. Enclosed is an inspection summary for this well. Future Inspection Plans: We now inspect this well on a bi-weekly inspection schedule for the next 2 months (through December 2002) as indicated in the Sundry request to the state. All film and data is on file with the Corrosion Group and available for your review. If you have any further questions please contact Chuck/George at ext 7209, or Al Dahlquist at ext 7773. (See attached file: ID-121 Inspection Log.xls) Thank you, George Foley/Chuck Froiland DS Inspection Coordinators NSK 39 n1016@ppco.com Office: (907) 659-7209 [~,,!,D-121 Inspection Log~xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 2 of 2 C NNED NOV 1 g 2002, 10/24/2002 7:27 AM 1D-121 Special Inspection Request Log DS 1 D 1 D-121 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) I #°f Date of Inspection B, I, N Inspection Locations 10/19/02 6 B 10/21/02 6 N I Worst Case ! Damage Wall L°ss %1 Grade 0% A 0% A i i i Comments Ba~ Line Inspection Day Follow-up Inspection Oct 02 02 08:34a P?~ I~ELLS GROUP 907 c;59 7314 p.2 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 _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other_X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 179' FNL, 599' FEL, Sec, 23, TllN, R10E, UM At top of productive interval At effective depth At total depth 717' FNL, 868' FEL, Sec. 23, T11N, R10E, UM 5. Type of Well: Development _X Exploratory __ Strafigraphic __ Service__ (asp's 560490, 5959485) (asp's 560225, 5958945) 6. Datum elevation (DF or KB feet) RKB 112 feet 7. Unit or Property name Kuparu k River Unit West Sak Oil Pool 8. Well number 1D-121 9. Permit number / approval number 197-181 10. APl number 50-029-22814 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SURFACE 4290' Size 16" 7-5/8" 4414 4315 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Eady 426 sx AS II1.384 sx Ciass G Measured Depth 121' 4402' True vertical Depth 121' 4303' Perforation depth: measured 3750-3780, 3810-3840, 3902-3932, 3980-4010 md true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3652-3682, 3712-3742, 3804-3834, 3882-3912 tvd 2.7/8",6.5#, L-80 Tbg @ 3654' MD. Packerless completion with no SSSV RAYCHEM HEAT TRACE {BOTTOM DEPTH 1309') 13. Attachments Description summar7 of proposal _X Detailed operations program _ 14. Estimated date for commencing operation I 15. Status of well classification as: October 2, 2002 16. If proposal was verbally approved Oil .._X Gas _ Name of approver Date approved Service 17. I hereby certify that the foregoing Is true and correct to the best of my k~owledge, BOP sketch _ Suspended _ Questions? Call Pete Nezaticky 659-7224 Signed ~.,,1 / j ,~ Title: Problem Well Supervisor Pete Nezaflck " ";' ¢-./ ' y ,/"'g¢'~ / L,,~'/ FOR COMMISSION USE ONLY ,// ~/ , conditions of approval: Notify Con'~nission~o representative may witness PIug integrity__ BOP Test__ Location clearance ~ Mechanical Integrily Test~ Subsequent form required 10-,,. Date 10/02/02 Approval no. ";Zj 0 Z - 50 ~,~ Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 SCANNED NOV 0 5 2002 1 D-121 WEST SAK WELLHEAD AND PIPING DESIGN LIFT GAS " CHECK VALVE BLIND FLANGE £ ( t 3 i! 2" 2" TO 3" X-OVER I I EXTRA THICK WALLED 3" TEE SET @ 500 PSI SET @ 70 PSI -----( 0-- PILOT SWITCH 0 o ConoCOPhillips Peter Nezaticky Problem Well Supervisor P.O. Box 100360, NSK 69 Anchorage, AK 99510-0360 Phone 907-659-7224 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 September 19, 2002 Dear Mr. Maunder: Enclosed Please find a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., West Sak well 1D-121. The variance request is for approval to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well sche'matic. Please call Jer:ry Dethlefs or myself at 907-659-7224 if you have any questions. Sincerely, Peter Nezatic~' ~ NOV 0 5 2002 RE.£E.I'VED SEP 2 4' 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /'~ r.-/5 APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 179' FNL, 599' FEL, Sec. 23, T11N, R10E, UM At top of productive interval At effective depth At total depth 717' FNL, 868' FEL, Sec. 23, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical 4414 4315 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service_ (asp's 560490, 5959485) (asp's 560225, 5958945) feet Plugs (measured) feet 6. Datum elevation (DF or KB feet) RKB 112 feet 7. Unit or Property name '~nO:,nt "~" ......... IVI~.~II i%~y i ~ ~,.~1 II L 8. Well number 1D-121 /' 9. Permit number / approval number 197-181 10. APl number 50-029-22814 11. Field / Pool Effective depth: measured true vertical Casing Length CONDUCTOR 121' SURFACE 4290' Size 16" 7-5/8" feet Junk (measured) feet Cemented 9 cu yds High Eady 426 sx AS III, 384 sx Class G Measured Depth True vertical Depth 121' 121' 4402' 4303' Perforation depth: measured true vertical r'ubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3750-3780,3810-3840,3902-3932,3980-4010 md 3652-3682,3712-3742,3804-3834,3882-3912 ~d 2-7/8",6.5#, L-80 Tbg @ 3654' MD. Packerless completion with no SSSV RAYCHEM HEAT TRACE (BO'FrOM DEPTH 1309') R CEI"VEO 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation October 2, 2002 / 16. If proposal was verbally approved Name of approver Date approved Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~~.c~c_~/ Title: Problem Well Supervisor Pete Nezaticky Questions? Call Pete Nezaticky 659-7224 Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval Plug integrity_ BOP Test_ Location clearance _ q Mechanical Integrity Test_ Subsequent form required 10- t~ ~ ,olo,l' oo , ORiO;NAL $1GN;-D DY Commissioner Date/(~i;~5/~ ~.- Approved by order of the Commission [3 Taylor Seamount, ' - Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. West Sak Well 1D-121 SUNDRY NOTICE 10-403 VARIANCE REQUEST 9/19/02 The purpose of this Sundry Notice is for approval to temporarily g/aslift West Sak producer 1D- 121 that is completed as an ESP (electric submersible pump) welI. The ESP has failed a3~d a workover is required to pull and replace the ESP, and is expected to occur during 2003.~ The well makes approximately 250 bopd via ESP, a majority of which may be possible to produce on f gaslift. / Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate will be 1000,1500 mcfd./' Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 150-200 BOPD. The basic gaslift and production facilities layout for )D-105A (under construction) will be identical to the current ID-110A and ID-102 layout~ Phillips has presently started fabrication and will install a new 3" annulus flowline on 1D-102 to replace the existing 2" flowline prior to production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design is being implemented for 1D-110A and 1D-102 as a pro-active measure, even though there was no indication of active / erosion in the 2" line that was on well 1D-110A.) Velocity calculations have been done with maximum anticipated flow rates of 200 BLPD and 2 MMcfd up the annulus and through the 3" annular flow line. Production pressure is J approximately 230 PSIG. The maximum velocity through the NPS 3" sch 160 A333 Gr6 line will be 60 ft/s. There have been five (5) solids shakeouts on well 1D-121 since September 2001 and they range from 0.0% to 0.20% by volume. Phillips intends to take production shakeouts both initially and/ periodically to monitor future performance. Below is a table of recent well test information. Future Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows: Inspect after 1 day of production or gas lift kickoff and bi-weekly once stable production is established. Inspections will be decreased to monthly intervals after two-months of inspections providing degradation is not detected. As an extra safety feature, a valve handle to the IA API valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. Phillips proposes that the AOGCC approve this request for a time period not to exceed 12 J' months from the approval date. If a workover is not completed within that time period, the , CANNEE~ NOV 0 5 2002 AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. Well 10-121 Oil Producer (Production with ESP in operation) FTP FTT Oil Water WC Form gas Form GOR Form GLR ESP speed Well Name Choke Position PSIG DEG F BOPD BWPD % mcfd scf/stb scf/stb 121 100 202 84 270 64 19 52 192 155 121 100 197 84 275 62 18 51 186 152 121 100 211 85 275 64 19 49 179 145 121 100 215 84 281 61 18 49 175 144 121 100 189 84 275 64 19 50 181 147 121 100 214 84 281 66 19 48 171 139 121 100 204 85 269 64 19 53 197 159 121 100 199 84 281 66 19 54 192 155 121 100 201 83 259 62 19 48 184 148 121 100 235 83 263 66 20 49 185 148 HZ 33 33 33 33.4 33.4 33.4 33.4 33.4 29.9 29.9 ,SCANNED NOV 0 5 2002 PH LUPS Alaska, nc, A Subsidiary 01' PHILLIPS PETROLEdM COMPANY (373698 O0:1000) OD:2875 iD:24dj ?U 06:6000} (36763688 0D:6750} 500292281400 SSSV · None Annular Fluid: WelIType:IPROD Odg 12/6/1997 Completion: Last W/O: Angle @ TD: 2 deg @ 4414 Rev Reason: Reset SOV Date:l 9/17/2002 3793 4,414 ftKB Date: 1/31/1995 CONDUCTOR SURFACE Size 2875 F 0 Interval TVD 3750-3780 3652,~3682 3810-3840 3712-3742 3902-3932 3804-3834 3980-4010 3882-3912 Thread 0 0 Botiom TVD 3654 3556 Thread EUE 8RD MOD Comlllent 2 1/8" EJ BH;0deg 2 1/8" EJ BH; 0 deg 2 1/8" EJ BN OD:5250) (3~91-3698 OD:5625) (0~02 OD:7625 W[2970) Description ESP Electric W/I Wire Cable (Boltom Depth 3698') 7/8.6 5#, EUE 8rd Mod 0000 0.000 2441 BAKER SENTRY GAUGE @ DISCHARGE OF PUMP BAKER SENTRY GAUGE {B~ PUMP iNTAKE 0000 0000 0000 GSFT DB NIL PFS 0000 525 Series 0000 PC ESP 57 HP 1315126 KMH 0000 (37504780) Per1 (3~23932) 197-181-0 KUPARUK RIV U WSAK 1D-121 50- 029-22814-00 ARCO MD 04414 ~ TVD 04315~ ~$mt~etion Date: _2/16/98 Completed Status: I-OIL Current: T Name Interval Sent Received T/C/D D 8211 1 ~P~Y MPT/GR/EWR4 OH 12/31/97 12/31/97 L BHPROF tF~N~AL-'126-4415 OH 2 L CMTMAPLOG 00 ' - ' :" CH 2 L o. L DGR/EWR4-MD ~/F~AL 121.4414 OH .. . L DGR/EWR4-TVD ~AL 121.4315 OH L LDT/CN ~I~AL 126.4415 OH L MAC/GR b~2 100.4408 OH 5 L MAC/GR b~FIN~ 100-4408 OH L 8STVD ~r~ 126-4415 OH L SW CORE RCD ~r-~AL 3383-4078 OH 5 R MWD SRVY ~'~RRY 0.4414. OH Daily Well Ops [!/~- h/9 Was the well cored? 3/10/98 3/13/98 2/23/98 2/26/98 3/10/98 3/13/98 12/31/97 12/31/97 12/31/97 12/31/97 3/10/98 3/13/98 12/4/97 12/12/97 1/3/98 1/6/98 3/10/98 3/13/98 3/10/98 3/13/98 12/19/97 12/24/97 Are Dry Ditch Samples Required? yes ~ And Received~.y~.a~--~ Analysis Description Received2- yes ~ .... Sam~' Comments: Thursday, February 03, 2000 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 30, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-121 (Permit No. 97-181) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-121. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development ORIGINAL RECEIVED ;~ska 0ii & ~as Cons. ~0mmissi0n Anchorage TWM/skad 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 r~ GAS ~ SUSPENDED [] ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-181 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360~~ ~_~_ 50-029-22814 4 Location of well at surface 1~~,~ 9 Unit or Lease Name At Top Producing I nte~al,~ 701' FNL, 850' FEL, Sec. 23, T11N, R10E, UM ~ West Sak 1D-121 At Total Depth ~ ~}-(~ ..... ~ . 11 Fiold and ~ool 5 filovalion in foot (indicate KB, DF, etc.) ~ ~ koaso D~i~nation and Sofial ~o. W~t Sak Oil ~ool ~KB 41', ~ad 71'~ ~Dk 25~$0 AkK 4~8 12 Dato30.~ov.07Spuddod 13 02-Doc-07Dat° T.D. ~oachod 14 ~atol O-Feb-OsG°mP', Susp. or ~and. 15 Wator~A~epth, ii offshorofoet MSk 1 ~ ~o.1 of Complelions 17 Total ~opth {MD+~) 18 ~lu~ Back Depth {MO+~D) 10 Diroctional Su~og 20 Dopth whero SSSV sot 21 Thicknoss of po~afrost 4414' MD & 4315' ~D 4313' MD & 4214' ~D YES ~ NO U NA feet MD 1652' APPROX 22 Type Ele~dc or ~her Logs Run G~R~, FDC/CNL, CBL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.58~ H-40 SURF. 121' 24' 9 cu yds High Eady 7.625' 29.7~ L-80 SURF. 4402' 9.875' 426 sx AS III, 384 sx Class G 24 Pedorations open to Production (MD+~D of Top and Bo~om and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2.875' 3698' 3810'-3840' MD 3712'-3742' ~D 3750'-3780' MD 3652'-3682' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 3902'-3932' MD 3804'-3834' ~D DEPTH INTERVAL (MD) M AMOUNT & KIND OF MATERIAL USED 3980'-4010' MD 3882'-3912' ~D 3750'-3780' MD, 3810'-3840' see a~achments ~ spf 3902'-3932' MD, 3980'-4010' MD 27 PRODUCTION TEST Date First Production~ 9/98 Method of OperatiOnGas(FIowing,Lift gas lift, etc.) Date of Test Hours T~ted PRODUCTION Fei OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE ] GAS-OIL RATIO ~2~9E 4.00 TEST PERIOI: 62 28 2 0~ 494 Flow Tubing Casing Pr~sure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 209~ -] 5 24-HOUR RATE: 362 171 14 0° 28 CORE DATA Bdef d,cdption of lithology, porosity, fractur--, apparent dips and presence of oil, gas or water. Submit core chips. Anchorage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 3746' 3648' Base West Sak Sand 4184' 4086' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ _f ,, ,,~ Prepared by Name/Number Sharon Allsup-Drake/263-4612 E. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/11/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-121 WELL_ID: AK9029 TYPE: AFC: AK9029 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:il/30/97 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22814-00 11/30/97 (D1) TD: 1634' (1634) SUPV:GRW MW: 9.3 VISC: 285 PV/YP: 37/51 APIWL: 7.2 DRILLING @ 2169' Move rig from 1D-129 to 1D-121. Rig accepted @ 0430 hrs. 11/30/97. Nipple up diverter stack. Function test diverter. Drill from 121' to 1634' 12/01/97 (D2) TD: 4310' (2676) SUPV:GRW MW: 9.1 VISC: 285 PV/YP: 30/44 RIH W/HOLE OPENER Drill from 1634' to 4310' APIWL: 7.2 12/02/97 (D3) TD: 4414' (104) SUPV:GRW MW: 9.2 VISC: 290 PV/YP: 30/50 APIWL: 7.0 RUNNING MAC LOG . Drill from 4310' to 44~r[ Safety meeting. Run FDC/CNL and 45' sidewall cores.~" 12/03/97 (D4) TD: 4414'( SUPV:GRW 0) MW: 9.2 VISC: 308 PV/YP: 34/48 APIWL: 6.2 CEMENTING Run MAC tool. RIH to 2145' hit bridge. Safety meeting. Run 7-5/8" casing. 12/04/97 (D5) TD: 4414'( SUPV:GRW 0) MW: 9.2 VISC: 221 PV/YP: 22/56 APIWL: 7.4 CLEANING OUT CEMENT Finish running 7-5/8" casing to bottom. Cement 7-5/8" in 2 stages. 12/05/97 (D6) TD: 4414'( SUPV:GRW 0) MW: 9.0 VISC: 49 PV/YP: 11/11 APIWL: 12.8 RUNNING TUBING Drill cement stringers from 1780' to 1847' Drill stage collar at 1847' and cement to 1862' Cleanout to 1948' Drill cement to 4314' 12/06/97 (D7) TD: 4414'( SUPV:GRW 0) MW: 8.7 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 RIG RELEASED @ 1900 HRS. 12/6 Run 3.5" tubing. Perform Hog wash treatment. Freeze protect well. N/D BOPE. N/U tree and test to 5000 psi, OK. Released rig @ 1900 hrs. 12/6/97. End of WellSummary for Well:AK9029 Date: 2/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-121 WELL_ID: AK9029 TYPE: AFC: AK9029 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:il/30/97 START COMP:02/11/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22814-00 02/11/98 (C8) TD: 4314' PB: 4314' SUPV:MC 02/12/98 (C9) TD: 4414' PB: 4314' SUPV:MC 02/13/98 (C10) TD: 4414' PB: 4314' SUPV:MC 02/14/98 (Cll) TD: 4414' PB: 4314' SUPV:MC 02/15/98 (C12) TD: 4414' PB: 4314' SUPV:MC NU BOPE MW: 8.7 BRINE Move in rig up on well 1D-121. Accept rig @ 1500 hrs. 2/11/98. Displacw well with brine. DRILLING OUT CARBOLITE MW: 8.7 BRINE Pump filtered brine. ND tree. NU BOPE and test to 250/3000. RIH w/3.5" drill pipe to drill out carbolite. MW: 8.7 BRINE Drill out carbolite from 3744'- 4302' POOH, pulling tight in spots. Circulate, rotate and reciprocate drill string while loading ESP cable and heat trace. RD SLICKLINE UNIT MW: 8.7 BRINE Reverse in caustic SL wash and brine. Prepare to run radioactive trace log. RIH W/2-7/8" COMPLETION MW: 8.7 Run Protechnics radioactive trace log. Run 2-7/8" completion. BRINE 02/16/98 (C13) TD: 4414' PB: 4314' SUPV:MC RIG RELEASED MW: 8.7 BRINE RIH w/ESP pump and 2-7/8" completion string and ESP cable. ND BOPE. NU tree. Test pack off to 5000 psi. Test tree 250/5000 psi. Freeze protect well. 02/17/98 (C14) TD: 4414' PB: 4314' SUPV:MC RIG RELEASED MW: 8.7 BRINE Secure well. Release rig @ 0200 hrs. 2/17/98. Move from 1D-121 to 1D-105. End of WellSummary for Well:AK9029 ARCO Alaska, Inc. WELL 1D-121 DATE 01/21/98 DAY 2 JOB SCOPE PERFORATE, PERF SUPPORT KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) DALLY WORK CEMENT BOND LOG AND PERFORATE W/2 1/8" EJ BH OPERATION COMPLETE KEY PERSON YES YES SWS-BAILEY Initial Tbg Press10 PSI Initial Inner Ann0 PSI Final Inner Ann10 PSI DAILY SUMMARY ISUCCESSFUL Final Tbg Press 0 PSI JOB NUMBER 0111981333.7 UNIT NUMBER 8337 SUPERVISOR SCHUROSKY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI RUN JEWELRY TIE-IN LOG, PERFORATE 30'(3980'-4010'), W/2 1/8" EJ BH, RUN LEE TOOL CMT(SLIM BOND LOG TOOL) TIME LOG ENTRY 12:30 MIRU SWS #8337. HOLD BUMPER SAFETY MEETING AND DISCUSSED BUSY PAD AND WIND CHILL HAZARDS. 14:30 FINISH R/U. P/'T TO 3000 PSI. RIH W/CPLC-CGRS-6' 2 1/8" HD WT. 15:00 TIE-IN TO SPERRY EWR4 LOG DATED 2-DEC-97. FOUND T.D. AT 4311'. LOG GR/CCL AT 60 FPM. 15:45 POOH DESCENT #1. 18:30 RIH W/SCMT 1 11/16" LEE TOOL CEMENT BOND LOG. 20:00 SCMT SHOWED POOR BONDING. CONSULTED WITH SWS DISTRICT ON LOG QUALITY CONTROLS. FAXED IN LOG SECTIONS FOR CONSULTATION. CONSENSUS WAS THAT LOG WAS READING CORRECTLY AS CALIBRATED. 23:00 AT SURFACE WITH SCMT. RIG DOWN SCMT. ARM 2 1/8", 30' EJ BH STRIP. P/T TO 2500 PSI. RIH W/GUN- MPD-CCL-WT. 01:30 SHOT GUN WITH GOOD INDICATION ON CURRENT AND TENSION. POOH 02:00 AT SURFACE. GUN FIRED. START R/D. 03:30 FINISH R/D. LEAVE LOC.. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-121 FRAC, FRAC SUPPORT 0122982006.2 DATE DAILY WORK UNIT NUMBER 01/23/98 PUMP "A-2" FRAC DAY OPERATION COMPLETE I SUCCESSFUL 1 YES I YES Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSII 0 PSII 0 PSI DAILY SUMMARY KEY PERSON DS-YOKUM SUPERVISOR JOHNS Final Inner Ann I I 0 PSI Initial OuterAnn I 0 PSI I Final Outer Ann 0 PSI PUMPED 50,000# 16/20 PROPPANT WITH PROP LOCK AND RA TRACER TO A-2 FORMATION. WELL SCREENED OUT SHORT OF PUMPING JOB DESIGN OF 150,000#. GETTING WELL READY TO FRAC A-3. TIME LOG ENTRY 07:00 MIRU DOWELL, HOT OIL PUMP, APO SUPPORT, HALIBURTON PROP LOK AND PROTECNIC RA TRACER. 12:00 HELD JOB SITE SAFETY MEETING WITH 20 PEOPLE ON SITE. 12:40 SET TREE SAVER AND PT TREATING LINE. 13:00 PUMPED IMPULSE TEST W/20 BBLS DIESEL, 20 BPM AND 2750 PSI. SHUTDOWN FOR CALCULATIONS. 14:00 PUMPED BREAKDOWN 20 BPM HEC GEL 34 BBLS AND PUMP OVER DISPLACEMENT WITH 60 BBLS HEC GEL. SHUT DOWN FOR ISIP 760 PSI AND PUMP PULSE TEST. 15:00 PUMP DISPLACEMENT DOWN TUBING AND UP CASING TO TANK54 BBLS, PUMP 30 BBLS DATA FRAC INTO PERFS 15 BPM AND 1812 PSI. 16:00 PUMPED 40 BBLS DIESEL DOWN 7" CASING INTO FORMATION. 16:20 PUMP45 BBLS PAD 5 BPM AND 705 PSI. 16:25 PUMP 2 PPA STAGE WITH 2700# PROPPANT, 15 BPM AND 845 PSI. 16:43 PUMP RAMP UP FROM 2 PPA TO 8 PPA PROPPANT, 15 BPM WELL SCREENED OUT WITH 3023 PSI. 16:55 REVERSED FROM CASING TO OUT TUBING WITH 190 BBLS DIESEL. TURNED WELL OVER TO SLICKLINE FOR TAGGING PROPPANT TOP. ARCO Alaska, Inc. WELL 1D-121 DATE 01/24/98 DAY 3 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK UNIT NUMBER RUN GR COMPARISON PRE-FRAC VS POST FRAC AND PERFORATE 8337 KEY PERSON SUPERVISOR YES YES SWS-BAILEY SCHUROSKY Initial Tbg Press I Final Tbg Press I Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 250 PSII 200 PSII 0 PSI 0 PSI 0 PSI 0 PSI OPERATION COMPLETE I SUCCESSFUL KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) JOB NUMBER 0111981333.7 DALLY SUMMARY RAN PRE-FRAC VERSES POST-FRAC GR COMPARISON. MOST OF FRAC WENT INTO PERFORATIONS FROM 3980'-4010'. I PERFORATED FROM 3902'-3932'. TIME LOG ENTRY 07:00 MIRU SWS # 8337 W/BAILEY - WOOTEN - MASCARELLA. TOO MUCH EQUIPMENT IN THE WAY. HAD TO HAVE APC MOVE A TANK BEFORE ABLE TO RIG UP 10:00 P/T TO 2500 PSI. RIH WITH GR-CCL. COULD NOT GET THROUGH VALVE ON TREE SAVER ABOVE SWAB. RIGGED UP HEAT HOSE TO VALVE AND STARTED THAWING. 12:00 FINISHED THAWING VALVE. RIH WITH CPLC-CGRS-6' 2 1/8" HD WT. 13:00 14:00 LOG GR COMPARISON PASS FROM T.D. (4239') TO 3200' AT 3600 FPH. AT SURFACE. RIG DOWN GR/CCL. OPTAIN RADIO SILENCE AND SHUT DOWN WELDING. ARM GUN, P/T TO 2500 PSI, AND RIH W/30' 2 1/8" EJ BH, MPD-H, CCL-L. 16:00 TIE-IN TO SWS PDC DATED 21-JAN-98. LOG INTO POSITION AT 3897' TO SHOOT FROM 3902' TO 3932', 4 SPF, EJ BH CHARGES WITH 9.69" PENETRATION AND 0.57" ENTRY HOLE. 17:00 AT SURFACE. START R/D. 18:30 FINISH R/D. LEAVE LOC. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL 1D-121 JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0122982006.2 DATE DAILY WORK UNIT NUMBER 01/28/98 "A3" SAND FRAC OPERATION COMPLETE YES Initial Tbg Press 250 PSI DAY 5 SUCCESSFUL I KEY PERSON YES I DS-YOAKUM DAILY SUMMARY SUPERVISOR CHANEY Final Inner Ann I I 4O0 PSI Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI "A3" SAND FRAC COMPLETED. SCREENED OUT AT END OF JOB. INJECTED 105004 LBS OF PROP IN THE FORM W/8# PPA OF #16/20 @ THE PERF'S ALL PROP TREATED W/PROPLOCK ALSO HAS RA TRACER (ANTIMONY) ADDED. MAXIMUM PRESSURE 3200 PSI & F.G. (.65). WELLBORE FREEZE PROTECTED W/DIESEL. TIME 06:30 09:30 10:00 11:00 11:30 12:35 LOG ENTRY MIRU DOWELL FRAC EQUP, HES PROPLOCK EQUIP, LRS HOT OIL UNIT, AND APC VAC TRUCKS. HELD SAFETY MEETING (19 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 4500 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. VOLUME PUMPED 20 BBLS. MAXIMUM AND ENDING PRESSURE 2775 PSI. S/D AND OBTAINED ISIP OF 1011 PSI W/F.G. @ (.61). STOOD-BY AND MONITORED WHTP FOR 1 HR. PUMP BREAKDOWN W/50# HEC & 3% KCL SW @ 20 BPM. SLURRY VOLUME PUMPED 70 BBLS. MAXIMUM PRESSURE 2600 PSI AND ENDING PRESSURE 2100 PSI. STEPPED RATE DOWN AT THE END OF STAGE TO 1290 PSI. S/D AND OBTAINED ISIP OF 833 PSI W/F.G. @ (.65). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME OF 3.1 MINS @ 735 PSI. PUMP DATAFRAC W/50# HEC & 3%KCL SW @ 5 TO 20 BPM. SLURRY VOLUME PUMPED 70 BLS. MAXIMUM AND ENDING PRESSURE 2050 PSI. S/D AND OBTAINED ISIP OF 787 PSI W/F.G. @ (.65).STODD-BY FOR CLOSURE. CLOSURE TIME 3 MINS @ 705 PSI. PAD = 50 BBLS. PUMP FRAC W/50# HEC & 3% KCL SW & PROPLOCK @ 5 TO 20 BPM. SCREENED OUT. SLURRY VOLUME PUMPED 730 BBLS. MAXIMUM AND ENDING PRESSURE 3200 PSI. REVERSED OUT TBG W/180 BBLS OF DIESEL AND CLEARED TBG (RETURNS 1 FOR 1). PUMPED 116353 LBS OF #16/20 PROP. INJECTED 105004 LBS OF PROP IN THE FORMATION W/8# PPA OF #16/20 @ THE PERF'S ALL PROP TREATED W/PROPLOCK ALSO HAS RA TRACER (ANTIMONY) ADDED. PROP ON THIS STAGE NOT DYED. LEFT APP: 3800 LBS OF SAND IN THE WELLBORE, AND EST TOP OF FILL TO BE @ 3860'. LEFT WELLBORE FULLY FREEZE PROTECTED W/ DIESEL. 13:15 STARTED R/D. CHECKED OUT ALL EQUIP AND HARDLINES FOR RADIOACTIVE BACKGROUND. ALL CHECKED OUT OK NO HEALTH OR ENVIROMENTAL HAZARDS PRESENT. 14:30 15:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D RD COMPLETED. WELL SECURED AND NOTIFIED DSO OF STATUS. TURNED WELL OVER TO S/LINE OPERATIONS FOR TAG. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL 1D-121 DATE 01/29/98 DAY 6 JOB SCOPE FRAC, FRAC SUPPORT DALLY WORK "B" SAND FRAC OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 600 PSII 600 PSI 600 PSI DALLY SUMMARY KEY PERSON DS-YOAKUM JOB NUMBER 0122982006.2 UNIT NUMBER SUPERVISOR CHANEY Final Inner Ann Initial Outer Ann I Final Outer Ann 600 PSI 0 PSII 0 PSI "B" SAND FRAC COMPLETED THRU FLUSH. MAXIMUM PRESSURE 2700 PSI & F.G. (.68). INJECTED 99200 LBS OF PROP IN THE FORM W/10# PPA OF #16/20 @THE PERF'S. ALL PROP COATED W/PROPLOCK AND RA TRACER (SCANDIUM) ADDED. WELLBORE FREEZE PROTECTED W/DIESEL. TIME LOG ENTRY 06:00 09:30 09:45 10:45 11:15 12:00 MIRU DOWELL FRAC EQUIP, HES PROPLOCK EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (18 ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D THE HIGH PRESSURE LINES TO 4500 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. SLURRY VOLUME PUMPED 20 BBLS. MAXIMUM AND ENDING PRESSURE 2700 PSI. S/D AND OBTAINED ISIP 1250 PSI W/F.G. (.69). STOOD-BY AND MONITORED WHTP. PUMP BREAKDOWN W/50# HEC & 3% KCL SW @ 20 TO 15 BPM. SLURRY VOLUME 87 BBLS. MAXIMUM PRESSURE 2900 PSI AND ENDING PRESSURE 1150 PSI. STEPPED RATE DOWN AT THE END OF THE STAGE. S/D AND OBTAINED ISIP OF 870 W/F.G. @ (.68). PULSED FOR CLOSURE. CLOSURE TIME 6 MINS @ 740 PSI. PUMP DATAFRAC W/50# HEC & 3% KCL SW @ 15 BPM. SLURRY VOLUME PUMPED 66 BBLS. MAXIMUM 1755 PSI AND ENDING PRESSURE 1650 PSI. S/D AND OBTAINED ISIP OF 751 PSI W/F.G. @ (.65). STOOD-BY AND MONITORED WHTP FOR CLOSURE. CLOSURE TIME 4 MINS @ 645 PSI. PAD VOLUME = 33 BBLS. DISPLACED 40 BBLS OF DIESEL DOWN THE ANNULUS. PUMP FRAC W/50# HEC & 3% KCL SW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. SLURRY VOLUME PUMPED 565 BBLS. MAXIMUM PRESSURE 1700 PSI AND ENDING PRESSURE 1400 PSI. PUMPED 100655 LBS OF #16/20 PROP. INJECTED 99200 LBS OF PROP IN THE FORMATION W/10# PPA OF #16/20 @THE PERF'S. ALL PROP COATED W/PROPLOCK AND RA TRACER (SCANDIUM) ADDED. LEFT 1455 LBS OF PROP IN THE WELLBORE AND EST FILL @ 3790'. WELLBORE FREEZE PROTECTED W/DIESEL. 13:00 STARTED R/D. 14:00 15:00 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL 1D-121 DATE 01/29/98 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK PERFORATE, PERF SUPPORT DAY OPERATION COMPLETE I SUCCESSFUL 4 YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn1250PSI 250PSI 0PSI DAILY SUMMARY IKEY PERSON SWS-DALEBOUT Final Inner Ann I I 0 PSI JOB NUMBER 0111981333.7 UNIT NUMBER SUPERVISOR BLACK I' Initial Outer Ann Final Outer Ann 0 PSI 0 PSI PERFORATED "B" SAND FROM 3810 - 3840' ELM WITH 2-1/8" EJ BH @ 4 SPF, 0 DEG PHASED & ORIENTED TIME LOG ENTRY 22:45 MIRU SWS (DALEBOUT & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (30' 2-1/8" EJ/CCL/WT) TL - 37'. PT BOPE TO 2000 PSI. 01:00 RIH TO 3840' ELM. TIE IN 1/21/98 SWS GR/CCL DEPTH CONTROL LOG. PERFORATE "B" SAND FROM 3810 - 3840' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED & ORIENTED. GOOD SURFACE INDICATIONS. LOG UP & POOH. 02:45 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 04:00 RD COMPLETE. LEAVE SI AWAITING "B" SAND FRAC. \ ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL 1D-121 JOB SCOPE PERFORATE, PERF SUPPORT JOB NUMBER 0111981333.7 DATE DALLY WORK UNIT NUMBER 01/29/98 PERFORATE, PERF SUPPORT OPERATION COMPLETE I SUCCESSFUL NO I NO Initial Tbg Press Final Tbg Press I Initial Inner Ann 275 PSI 275 PSII 0 PSI KEY PERSON SWS-DALEBOUT DAY 4 SUPERVISOR BLACK Final Inner Ann I I 0 PSI Initial Outer Ann I I 0 PSI Final Outer Ann 0 PSI DAILY SUMMARY I ATTEMPTED TO PERFORATE "D" SANDS FROM 3750-3780' ELM. TAGGED HARD BOTTOM @ 3771' ELM (+/- 10' SHALLOW W/ I I FILL). WILL RE ATTEMPT AFTER FCO. I TIME 20:45 22:15 23:30 00:30 LOG ENTRY MIRU SWS (DALEBOUT & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (30' 2-1/8" EJ BH @ 4 SPF, O DEG PHASED & ORIENTED/CCL/WT) TL-37'. PT BOPE TO 2000 PSI. RIH & TAGGED HARD BOTTOM @ 3771' ELM. PU & CONFIRMED TAG @ 3771' ELM (SHALLOW +/- 10'). POOH. AT SURFACE. DISARM GUNS & BEGIN RD. COMPLETE RD. LEAVE FOR CTU CLEANOUT. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-121 FRAC, FRAC SUPPORT 0122982006.2 DATE DAILY WORK UNIT NUMBER 01/31/98 "D" SAND FRAC DAY OPERATION COMPLETE SUCCESSFUL 8 YES YES Initial Tbg Press I Final Tbg Press I Initial InnerAnn 300 PSII 500 PSII 300 PSI DAILY SUMMARY KEY PERSON DS-YOAKUM SUPERVISOR CHANEY Final Inner Ann I I 50O PSI Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI "D" SAND FRAC COMPLETED THRU FLUSH. INJECTED 98171 LBS OF PROP IN THE FORM W/10# PPA OF #16/20 @ THE PERF'S. ALL PROP COATED W/PROPLOCK AND HAS RA TRACER (IRIDIUM) ADDED. MAXIMUM PRESSURE 2700 PSI & F.G. (.68) .TBG AND CSG FREEZE PROTECTED W/DIESEL. TIME 08:00 09:30 10:15 11'15 12:00 13:00 LOG ENTRY MIRU DOWELL FRAC EQUIP, HES PROPLOCK EQUIP, LRS HOT OIL TRUCK, APC VAC TRUCKS, & PROTECHNICS EQUIP. HELD SAFETY MEETING (20 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 4100 PSI. PUMP IMPULSE TEST W/DIESEL @ 20 BPM. SLURRY VOLUME PUMPED 20 BBLS. S/D AND OBTAINED ISIP OF 1085 PSI W/F.G. @ (.65/. STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP BREAKDOWN W/50# HEC - 3% KCL SW & DIESEL. SLURRY VOLUME PUMPED 103 BBLS. MAXIMUM PRESSURE 2600 PSI AND ENDING PRESSURE 1400 PSI. S/D AND OBTAINED ISIP OF 1223 PSI W/F.G. @ (.69). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 6 MINS @ 1095 PSI. PUMP DATAFRAC W/50# HEC - 3% KCL SW & DIESEL. SLURRY VOLUME PUMPED 168 BBLS. MAXIMUM AND ENDING PRESSURE 2000 PSI. S/D AND OBTAINED ISIP OF 1190 PSI W/F.G. @ (.69). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 3.6 MINS @ 1133 PSI. PAD = 85 BBLS. PUMP FRAC W/50# HEC - 3% KCL SW. COMPLETED THRU FLUSH. SLURRY VOLUME 640 BBLS. MAXIMUM AND ENDING PRESSURE 2000 PSI. PUMPED 99171 LBS OF #16/20. INJECTED 98171 LBS OF PROP IN THE FORMATION W/10# PPA OF #16/20 @ THE PERF'S. ALL PROP COATED W/PROPLOCK AND HAS RA TRACER (IRIDIUM) ADDED. LEFT 1000 LBS OF PROP IN THE WELLBORE AND ESTIMATE FILL TO BE @ 3700'. TBG AND CSG FREEZE PROTECTED W/DIESEL. 14:00 STARTED R/D. 14:30 15:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. F:VD COMPLETED. WELL SECURED AND NOTIFIED DSO OF STATUS. WELl' READY FOR "NORDIC" COMPLETION. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-121(W4-6)) WELL 1 D-121 DATE 01/31/98 DAY 6 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK PERFORATE, PERF SUPPORT OPERATION COMPLETE I SUCCESSFUL YES YES Initial Tbg Press I Final Tbg Press1300 PSI 300 PSI Initial Inner Ann 0 PSI KEY PERSON SWS-DALEBOUT JOB NUMBER 0111981333.7 UNIT NUMBER SUPERVISOR BLACK Final Inner Ann I I 0 PSI Initial OuterAnn I 0 PSI I Final Outer Ann 0 PSI DALLY SUMMARY PERFORATE "D" SANDS FROM 3750 - 3780' ELM W/2-1/8" EJ BH @ 4SPF, O DEG PHASED & ORIENTED TIME LOG ENTRY 04:00 MIRU SWS (DALEBOUT & CREW). TGSM & JOB OVERVIEW. MU GUN ASSEMBLY (30' 2-1/8" BH/CCL/WT) TL- 35'. PT BOPE TO 2500 PSI. 06:15 RIH TO 3758' CCL ELM & TAG BOTTOM (BOTTOM OF TOOL @ 3793'). TIE IN & PERFORATE FROM 3750 - 3780' ELM W/2-1/8" EJ BH @ 4 SPF, O DEG PHASED & ORIENTED. GOOD SURFACE INDICATIONS. LOG OFF & POOH. 07:45 AT SURFACE. ALL SHOTS FIRED. BEGIN RD. 08:30 RD COMPLETE. TURN OVER FOR "D" SAND FRAC. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC WS / 1D-121 500292281400 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 113097 MWD SURVEY JOB NUMBER: AKMM80028 KELLY BUSHING ELEV. = 112.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. · 00 .00 -112.00 0 0 N .00 E .00 121.00 121.00 9.00 0 0 N .00 E .00 378.09 378.08 266.08 0 34 N .07 E .22 831.36 831.33 719.33 0 42 N 4.75 E .03 1011.96 1011.88 899.88 1 39 S 8.59 W 1.31 .00N .00E .00 .00N .00E .00 1.28N .00E -1.15 6.33N .24E -5.79 4.88N .06W -4.35 1383.25 1382.92 1270.92 2 '28 S 15.70 W .23 1667.81 1667.21 1555.21 2 31 S 16.75 W .02 1764.03 1763.23 1651.23 4 28 S 16.71 W 2.03 1858.80 1857.49 1745.49 7 21 S 21.65 W 3.08 1954.01 1951.48 1839.48 10 52 S 22.97 W 3.70 8.14S 3.03W 8.64 20.08S 6.51W 20.89 25.72S 8.20W 26.69 34.91S ll.50W 36.40 48.85S 17.26W 51.45 2047.81 2043.06 1931.06 14 3 S 21.17 W 3.41 2143.45 2135.09 2023.09 17 25 S 21.93 W 3.53 2239.12 2225.36 2113.36 21 12 S 21.42 W 3.95 2332.85 2311.99 2199.99 23 39 S 24.65 W 2.93 2427.84 2398.14 2286.14 26 10 S 26.27 W 2.74 67.63S 91.76S 121.17S 154.06S 190.17S 24.83W 71.65 34.38W 97.51 46.06W 129.06 60.10W 164.76 77.32W 204.77 2618.64 2569.79 2457.79 25 36 S 25.24 W .38 2808.92 2741.88 2629.88 24 55 S 24.91 W .36 2904.11 2829.19 2717.19 22 0 S 25.49 W 3.08 2999.19 2917.72 2805.72 20 45 S 26.36 W 1.35 3094.59 3007.60 2895.60 18 24 S 29.56 W 2.71 265.18S 113.52W 288.06 338.73S 147.93W 369.24 373.02S 164.06W 407.13 404.19S 179.20W 441.78 432.45S 194.14W 473.74 3188.76 3097.58 2985.58 15 52 S 33.09 W 2.90 3284.15 3189.90 3077.90 13 13 S 33.34 W 2.79 3380.27 3283.96 3171.96 -10 30 S 36.66 W 2.91 3475.71 3378.21 3266.21 7 32 S 35.63 W 3.12 3571.44 3473.47 3361.47 3 32 S 35.61 W 4.17 456.18S 208.52W 501.38 476.23S 221.64W 525.16 492.45S 232.92W 544.69 504.52S 241.76W 559.43 512.04S 247.15W 568.55 3666.26 3568.15 3456.15 2 32 S 32.65 W 1.08 3853.02 3754.75 3642.75 2 13 S 41.57 W .26 4042.60 3944.20 3832.20 2 4 S 41.46 W .08 4232.33 4133.79 4021.79 2 12 S 39.71 W .08 4351.40 4252.78 4140.78 2 7 S 42.46 W .11 516.20S 249.99W 573.53 522.39S 254.62W 581.13 527.70S 259.33W 587.98 533.07S 263.92W 594.82 536.46S 266.88W 599.17 4414.00 4315.34 4203.34 2 7 S 42.46 W .00 538.18S 268.45W 601.40 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 601.41 FEET AT SOUTH 26 DEG. 30 MIN. WEST AT MD = 4414 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 206.19 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 4,414.00' MD ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC WS / 1D-121 500292281400 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 113097 JOB NUMBER: AKMM80028 KELLY BUSHING ELEV. = 112.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH -EAST/WEST DIFFERENCE CORRECTION .00 .00 -112.00 1000.00 999.93 887.93 2000.00 1996.52 1884.52 3000.00 2918.48 2806.48 4000.00 3901.62 3789.62 .00 N .00 E .00 5.22 N .01 W .07 .07 57.44 S 20.81 W 3.48 3.40 404.45 S 179.33 W 81.52 78.04 526.55 S 258.31 W 98.38 16.8'5 4414.00 4315.34 4203.34 538.18 S 268.45 W 98.66 .29 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM-CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC WS / 1D-121 500292281400 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 113097 JOB NUMBER: AKMM80028 KELLY BUSHING ELEV. = 112.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR.COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -112.00 112.00 112.00 .00 212.00 212.00 100.00 312.00 312.00 200.00 '412.01 412.00 300.00 .00 N .00 E .00 N .00 E .00 N .00 E .62 N .00 E 1.62 N .00 E .00 .00 .00 .00 .00 .00 .00 .01 .00 512.01 512.00 400.00 612.02 612.00 500.00 712.03 712.00 600.00 812.03 812.00 700.00 912.04 912.00 800.00 2.61 N .00 E 3.63 N .01 E 4.86 N .tl E 6.09 N .22 E 7.33 N .32 E .01 .00 .02 .01 .03 .01 .03 .01 .04 .01 1012.08 1012.00 900.00 1112.12 1112.00 1000.00 1212.17 1212.00 1100.00 1312.26 1312.00 1200.00 1412.36 1412.00 1300.00 4.87 N .06 W 2.02 N .49 W 1.02 S 1.03 W 5.19 S 2.20 W 9.35 S 3.37 W .08 .04 .12 .04 .17 .05 .26 .09 .36 .09 1512.45 1512.00 1400.00 1612.55 1612.00 1500.00 1712.65 1712.00 1600.00 1813.00 1812.00 1700.00 1913.91 1912.00 1800.00 13.52 S 4.54 W .45 .09 17.75 S 5.80 W .55 .10 22.06 S 7.10 W .65 .10 29.96 S 9.63 W 1.00 .35 42.37 S 14.54 W 1.91 .90 2015.87 2012.00 1900.00 2119.30 2112.00 2000.00 2224.82 2212.00 2100.00 2332.87 2312.00 2200.00 2443.29 2412.00 2300.00 60.70 S 22.11 W 3.87 1.97 85.21 S 31.75 W 7.30 3.43 116.44 S 44.20 W 12.82 5.52 154.08 S 60.11 W 20.87 8.04 196.28 S 80.33 W 31.29 10.42 2554.56 2512.00 2400.00 2665.44 2612.00 2500.00 2775.98 2712.00 2600.00 2885.53 2812.00 2700.00 2993.07 2912.00 2800.00 240.14 S 101.71 W 283.48 S 122.14 W 326.14 S 142.09 W 366.63 S 161.02 W 402.25 S 178.24 W 42.56 11.27 53.44 10.89 63.98 10.54 73.53 9.55 81.07 7.55 3099.23 3012.00 2900.00 3203.74 3112.00 3000.00 3306.82 3212.00 3100.00 3408.75 3312.00 3200.00 433.71 S 194.86 W 459.56 S 210.72 W 480.42 S 224.43 W 496.43 S 235.86 W 87.23 6.16 91.74 4.51 94.82 3.08 96.75 1.93 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC WS / 1D-121 500292281400 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/19/97 DATE OF SURVEY: 113097 JOB NUMBER: AKMM80028 KELLY BUSHING ELEV. = 112.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3509.74 3412.00 3300.00 3610.05 3512.00 3400.00 3710.15 3612.00 3500.00 3810.24 3712.00 3600.00 3910.31 3812.00 3700.00 507.78 S 244.10 W 97.74 1.00 513.98 S 248.53 W 98.05 .30 517.83 S 251.04 W 98.15 .11 521.15 S 253.53 W 98.24 .09 524.05 S 256.10 W 98.31 .08 4010.38 3912.00 3800.00 4110.45 4012.00 3900.00 4210.52 4112.00 4000.00 4310.59 4212.00 4100.00 4414.00 4315.33 4203.33 526.83 S 258.56 W 98.38 .07 529.54 S 260.95 W 98.45 .07 532.43 S 263.39 W 98.52 .07 535.34 S 265.85 W 98.59 .07 538.18 S 268.45 W 98.67 .07 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 3/9/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11903 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Open Hole) Well Job # Log Description Date BL RF Sepia LIS c~ _. I~ ~ ..~. ~-~Z~CT~ Tape WS 1D-121 (G5) 97559 LDT/CNL 971202 1 WS //)-121 (GS) 97559 CNL 971202 I 1 WS 1D-121 (G5) 97559 LDT 971202 I 1 WS 1D-121 (G5) 97559 SSTVD 971202 I 1 WS 1D-121 (G5) 97559 BOREHOLE PROFILE 971202 I 1 ,. , WS 1])-121 (GS) 97559 SID~-I~J~L CORE R~CORD 971202 I 1 . S I G N E D: ~-~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 2/23/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11853 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive . Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1D-117 ~O-;27~ -- CEMENT MAP LOG 980126 I 1 1 D- 121 ~ ~7 - / '~ / --- CEMENT MAP LOG 9 S 01 21 I 1 1 D- 1 3 0 ~7 - ? ~' ~ FOUR ARM CALIPER W/FMS 9 71 1 0 5 I 1 1 D- 13 0 ~ CEMENT BOND LOG 9 8 01 1 0 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 03-Jan-98 Well Name Services Bluelines R. Sepia Film West Sak 1D-121 MAC/GR (computed log) 1 1 Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 q December 31, 1997 MWD Formation Evaluation Logs 1D-121, AK-MM-80028 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-121: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22814-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22814-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, A~aska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company I~1 I~ I I__1-- I I~ I~ S E F! ~./I I-- I:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-121, AK-MM-80028 December 31, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22814-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 19-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-121 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 4,414.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company State ,~,~ Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 04-Dec-97 Well Name Services Bluelines R. Sepia Film West Sak 1 D-121 MAC/GR 1 1 ,i ~qch0r~ge Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor ~ ¥.~_~ ,r~ .... October 16, 1997 . ,, Alaska Oil and Gas Conse~ation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill, Addendum Letter #1 West Sak 1D-121 (G5) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: Pursuant to the recent conversation with AOGCC staff regarding the above referenced APD, please note ARCO Alaska, Inc. is making some minor modifications to the original plan of operations for the well. With regard to annular pumping operations, please be advised that the incidental drilling fluids generated from the drilling of the above referenced well will not be hauled to WSI-01 and KRU 1C-12 as indicated in the original APD package dated September 17, 1997. Instead, the waste will be hauled to the nearest permitted disposal well, or it will be pumped down the surface / production casing annulus of an existing well on DS 1D. This plan should be in agreement with requirements set out by AOGCC staff. Please note that the anticipated spud date for this well is November 19, 1997. If you have any questions or require further information on this matter, please contact Tom McKay at (907) 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Attachments CC: West Sak 1D-121 (G5) Well File Tom Brockway ATO-1207 Mike Zanghi ATO-1276 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany TONY KNOWLE$, (~OVEF~NOFt ALAS~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 16, 1997 Thomas W. McKay, P.E. Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: West Sak 1D-121(G5) ARCO Alaska, Inc. Permit No. 97-181 Sur. Loc: 181'FNL, 598'FEL, Sec. 23, TllN, R10E, UM Btmhole Loc: 668'FNL. 837'FEL, Sec. 23, T11N, R10E, UM Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by laxv from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling belo~v the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si ' Chairman BY ORDER OF THE COMMISSION dlffenclosures Department ofFish & Game, Habitat Section w/o encl. Department of Envinomment Conservation w/o encl. ' -"-' STATE OF ALASKA ALAu..,-~ OIL AND GAS CONSERVATION COMMISS, PERMIT TO DRILL 20 AAC 25.O05 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test I--I Development Oil X Re-Entry [] Deepen El Service ]-I Development Gas El Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 181' FNL, 598' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 668' FNL, 837' FEL, Sec. 23, T11N, R10E, UM WEST SAK 1D~121 (G5) #U-630610 At total depth 9. Approximate spud date Amount 668' FNL, 837' FEL, Sec. 23, T11N, R10E, UM 1 0/1 9/97 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-04 4374' MD 668'~ TD feet 57.1' @ 720' feet 2560 4273' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 750' feet Maximum hole angle 29.6° Maximum surface 1 251 psig At total depth (TVD) 1 644 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +200 CF 9.875" 7.625" 29.7# L-80 BTC-MO[14333' 41' 41' 4374' 4273' 389 Sx Arcticset III & 406 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Productionlntermediate -~'_% ~ ~t¢¥'~ ¢: ,,~ ..,! ¢ Liner Perforation depth: measured ~'~' i'!'? ~ ~_-{ ~,9.,~ ? true vertical 20. Attachments Filing fee X Property plat [~] BOP Sketch X DiNerter Sket(Jh" ~X ....... Drilling program X Drilling fluid program X Time vs depth plot El Refraction analysis [] Seabed rep'~)Tf~ El 20 AAC 25.050 requirements X 21. Iherebycertifythattheforegoingistrueandcorrecttothebestofmyknowledge Signed'~~''k~''~'' ~'~//~'/~ ~/~ ~~~/ Title Drill Site Develop. Supv. Date Commission Use Only Permit Number I APl number I Approval date i re~!re~dd [ ~E]3 i see cover letter for ¢7-/~/ 50-0~..~--- ~----~-- <~2/'~ other requirements Conditions of approval Samples required El Yes ~] No Mud Icg Yes J~ No Hydrogen sulfide measures El Yes ~ No Directional survey required ~ Yes El No Required working pressure for BOPE ~ 2M FI 3M ~ 5M El 1OM El 15M Other:Original Signed By David W, ,J0hnst0r~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Suj Drill and Case Plan for West Sak 1D-121 (G5) Frac-for-Sand Control Producer General Procedure: , Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE' Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. . Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3,000 psi. , Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. . Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 4-1/2" x 7-5/8" Baker retrievable packer and 4-1/2" tubing "deadstring". TIH to packer setting depth above West Sak. Circulate filtered brine to desired level. 11. Set packer on depth. Pressure test tubing and tubing annulus in preparation for off-rig frac jobs to follow. 12. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well. 13. Release rig. TWM, 911 6/97 Page 1 Stage Stage 8. Completion Plan for West Sak 1D-121 (G5) Frac-for-Sand Control Producer Four-Staqe, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. 2. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. 1 3. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. 6. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. 2 Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 10. Page 2 11. 12. Stage 13. 14. 15. 16. 17. Stage 18. 19. 20. 21. 22. 23. 24. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. Perforate Stage 3 overbalanced, and POOH with E-line. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. Perforate Stage 4 overbalanced, and POOH with E-line. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. RIH with slickline and set plug in tubing tail. POOH with slickline. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Page 3 Pull Deadstringl Clean Out Well, Run ESP and Production Tubing 25. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 4-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. 26. Pull back pressure valve, and pressure test tubing and annulus. 27. RIH with slickline and pull plug in tubing tail as required. POOH with slickline. 28. Pull tubing hanger and release Baker retrievable packer above West Sak sands. Circulate well to clean brine as required. 29. TOH and lay down deadstring and Baker retrievable packer. Change rams to 3-1/2" and pressure test same unless VBR's are available. 30. Pick up rock bit and casing scraper and TIH with workstring. 31. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. 32. Circulate well to clean brine. TOH with workstring. Change rams to 2-7/8" and pressure test same unless VBR's are available. 33. Pick up Centrilift PCP-ESP (progressive cavity ESP) on 2-7/8" production tubing. 34. Run in well with PCP-ESP pump with power cable and data gathering information wire attached to tubing. 35. Attach Raychem heat trace cable attached to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 36. Position PCP-ESP at desired depth, and set tubing hanger and run electrical penetrators through same. 37. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 38. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 39. Release rig and turn well over to production. TWM, 9/16/97 Page 4 DRILLING FLUID & PROGRAM, PRESSURE CALCULATIONS DRILLING AREA RISKS West Sak 1D-121 (G5) Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties' Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 8-15 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.6-10.0 ppg 35 20-35 5-15 10-35 5-10 8.O-9.5 8-12% Drilling Fluid System' Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 50-100 sec/qt to drill gravel beds. Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. Page 1 MASP (Maximum Anticipated Surface Pressure): Since a string of surface casing is not planned for the West Sak 1D-121 (G5) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,574' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WSI-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak top to surface, the following MASP can be computed' MASP : (3,574 ft)(0.46 - 0.11 psi/ft) = 1251 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7-5/8" 29.7# L80 BTC casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring and packer will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the packer and deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Page 2 Drilling Area Risks: Drilling risks in the West Sak 1D-121 (G5) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-121 (G5). Well Proximity Risks: The nearest existing well to West Sak 1D-121 (G5)is KRU 1D-04. minimum distance between the two wells would be 57' @ 720' MD. As designed, the Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS 1D, or another KRU drill site. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr)in pumping operations. The West Sak 1D-121 (G5) surface casing / production tubing annulus will be filled with diesel and/or non- freezing brine after setting the 7-5/8" combination surface / production casing and prior to the drilling rig moving off of the well. Page 3 West Sak 1-01 Annulus Availability ARCO requests permission to utilize the West Sak 1-01 ("W$1-01") annulus for ann~ular pumping of waste incidental fluids generated from the drilling of the West Sak 1D-12~ (G5) well. The WS1-01 well was drilled in 1989, and is located on a gravel pad appr¢<imately 0.5 miles west of KRU 1D pad. The WS1-01 9-5/8" x 13-3/8" annulus remains ~lSen, and a recent injectivity test confirmed its ability to receive fluids. The WSl-01 well ~r~cords show that a total of 1,401 bbls of mud, water and diesel have been pumped intb this annulus since the well was drilled. · ,. ARCO further requests a waiver on the limitation of 35,000 bbls per annulus, hereby requesting that the WS1-01 annulus be permitted to receive a maximum of 50,000 bbls of fluid from the West Sak drilling operations proposed for the'West Sak Phase lA development project on 1D pad. The WS1-01 annulus has a"fhigh level of mechanical integrity as evidenced by the well records and cement bond Ioginformation. As a side note, it is estimated that the West Sak Phase lA wells, consisting of fourteen (14) wells will generate approximately 84,000 bbls of waste to be disposed of. The WS1-01 well was a vertical well with 13-3/8" surface casing set through the permafrost to a depth of 2,699' MD/TVD. The 13-3/8" surface casing was successfully cemented to surface, and the 13-3/8" shoe was tested to an equivalent of 12.0 ppg EMW after drill out. Later, the 9-5/8" production casing was set at atotal depth of 4,230' MD/TVD. This casing was cemented back to a depth of 2,860' MD/TVD, as confirmed by cement bond log. In addition, to ensure zonal isolation, a cement inflatable casing packer was run and cemented in the 9-5/8" casing at a depth of 3,370' MD/TVD. Thus, the WS1-01 13-3/8" x 9-5/8"/annulus is fully capable of receiving waste fluids, and has demonstrable integrity both above and below the receiving zone for the fluids. The receiving zone would be intervals above the Ugnu formation which would be considered non-commercial, non-hydrocarbon bearing zones in this area. . /' KRU 10-12 Annulus ,, Availability The next available acnnulus in the KRU in the vicinity of KRU 1D pad is the 10-12 well drilled in the fall of 1996¢ This annulus has not been used for annular pumping, but it remains open and has the required mechanical integrity to receive wastes. The 9-5/8" surface casing in this .v~ell was set and cemented using a stage collar. Approximately 129 bbls of cement were/circulated to surface during the stage job. / The subsequent leakoff test was conducted to 14.1 ppg EMW, calculated using the standpi/Ce pressure at the point of leakoff. Thus, the well's surface / production casing annulus has the required integrity to receive annular pumping wastes. ARCO further reqybsts a waiver on the limitation of 35,000 bbls per annulus, hereby requesting that the 10/'12 annulus be permitted to receive a maximum of 50,000 bbls of fluid from the West Sak d~lling operations proposed for the West Sak Phase lA development project on 1D pad. TVVM, 9116/97 Page 4 Creof.~ by ~nch For T McKay Oote plotted : 26-Aug-~7 P~ot Reference is w5 1D-121/G5 Version ~2. Coo~f~tes c~ ~n fe~ reference slot ~121. T~e Ve~cel Oep~s ere reference ~8 (Pork~ 250 50O 750 lOOO 1250 1500 1750 2000 2250 2500 2750 5000 5250 3500 3750 4OOO 4250 4500 RKB ELEVATION: 112' Structure : Pod 1D Well : ~l~pe, AlaskaI Field : Kuporuk River Unit Location : North <- West (feet) 240 200 160 120 80 I I I I I I I I ] I I . 206.19 AZIMUTH 543' (TO TARGET) EST. SURFACE LOCATION: 181' FNL, 598' FEL SEC. 25, TllN, RIOE B/ PERMAFROST TVD=1632 TMD=1632 DEP=O KOP TVD=1750 TMD=1750 DEP=0 3.50 7.00 DLS: 3.50 de9 per 100 fi lO.~O MAXIMUM ANGLE 1 4.00 17.50 29.62 DEG 21.00 ~ Ugnu Sands 24.5O k 28 O0 !8'00 ~EOC TVD=2559 TMB=2596 DEP=214 \ 27.00 kBEGIN ANGLE DROP TVB=2698 TMB=2756 DEP=293 24.00 21.00 X~T/ UGNU SNDS TVD=2959 TMD=3045 DEP=416 // 18.00 ~t TD - Casing Pt ~,/~ TARGET - West Sok A3 15.00 ~ BLS: 3.00 deg per 100 ft 12.00 9.00 6.00 3.00 T/ W SAK SNDS/EOD TVD=3642 TMD=3743 DEP=543 TARGET - W SAK A3 TVD=3784 TMD=3885 DEP=543 B/ W SAK SNDS TVD=4073 TMD=4174 BEP=543 J LTl) - CSG PT TVD=4273 TMD=4374 DEP=548 i i i I i i ] 0 250 500 750 Vertical Section (feet) -> 40 o I I ~ EOC Begin Angle Drop TARGET/TD LOCATION: 668' FNL, 837' FEL SEC. 23, T11N, RIOE TARGET TVD=3784 TMD=3885 DEP=545 SOUTH 487 WEST 239 4O 8O 120 160 TARGET ANGLE VERTICAL 2OO 0 _,}_ 240 ,~, 280 I v 520 360 4OO 440 480 52O Azimuth 20§.19 with reference 0.00 N, 0.00 E from slot #121 Creo~eO O~ ~.¢. For: T McKay Do~e p~otted : Plot Reference is ~ 1D-121/C3 Version ~2. Caa~inates are in fe~ reference stat. ~121. ~e Ve~a] Dep~s ore r~ence ~B (Pa~ 80 40 40 8O 12o 160 2OO 240 280 32O 560 400 440 48O 52O 560 600 640 ARCO Alaska, Inc. Structure : Pad 1D Well: G5 Field : Kuperuk River Unit Location : North Slope, Alaska <- West (feet) 400 360 520 280 240 200 160 120 80 40 0 40 80 120 160 200 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 ~ 000 ~ 1000 2000f / 2~ oo.,' / / 2200.,' .,._1000 1400 1500 1 600 1700 / ~ / 230o/ / .... ~1000 1500~.._. 1_59-°'-"' .... /24oo / 1600.~ ....... / / 1700. ...... / 2500 _ 1..8- 9'g ......... ,/" -~1000 900 ............. ,," ',. 1300 (~'"' /26o0 .....-]~ 'XN14o0 /, \, oo ,, ./ w/1100 ./2700 ,-/" '~00 k16°° / // /.- ..~ / ./" ,/'1300 ,,," k 1700 2800 e"' .,'"' .,'" /' ~ / .-' .,'1400 // "~ 1800 ,,,"," / // ~_~ooo \ 2900X' /1500 M 000 ~'~"~'--7-_-: ..... ,,'? ,,' // .... 1400 ...... ~ ........ 1 600 .",,' ," ~ lOO/! i goo k ............... ~ ooo / .,' 3o~ % ilOOO \ -~a~, ,," / /1600 /__ r .... \ ," /,,' //1200 ! .." ;'~oo / / 3~oo~ 1~o~o~o~ ,'" ,",'" / i ~'I?_? 2000 \ ....-;7oo,,;..oo i,,oo \ .,," /~3oo / i \ 1100/ ,~' 5400 1400 / ~oo/ ? i 13oo ¢' ooo/" _/ i I~l I i I i I i I i i i i I i ~71 i I i I i I ..... 400 ;360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 <- West (feet) 80 40 120 16O 200 0 240 f- 280 '-~ 520 I v 36O 400 44O 480 520 560 6O0 640 ARCO ALASKA, Inc. Pad 1D G5 slot #121 Kuparuk River Unit North Slope, Alaska $-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker Hughes INTEQ REPORT Your ref = WS 1D-121/G5 Version #2 Our ref = prop2205 License : Date printed : 26-Aug-9? Date created : 16-Apr-9? Last revised : 26-Aug-97 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.536,w149 30 36.341 Slot Grid coordinates are N 5959483.692, E 560490.432 Slot local coordinates are 181.00 S 598.00 W Projection type: alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEA/~ANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8610'>,,6,Pad 1D MSS ¢3311-8200'~,,7,Pad 1D PGMS <O-80?O~>,,3,Pad 1D PGMS <O-7502*>,,4,Pad 1D PGMS c0-8930'>,,5,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS c0-9783*>,,2,Pad 1D PGMS <O-8365t>,,1,Pad 1D WS 1D-129/J3 Version #2,,J3,Pad 1D WS 1D-124/G3 Version #2,,G3,Pad 1D WS 1D-130/H4 Version #3,,H4,Pad 1D WS 1D-133/J5 Version #3,,JS,Pad 1D WS 1D-135/G? Version #3,,GT,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Aug-92 182.0 20.0 680.0 4-Aug-92 302.0 460.0 460.0 4-Aug-92 178.0 20.0 880.0 4-Aug-92 57.1 720.0 720.0 4-Aug-92 59.4 1040.0 1040.0 16-0ct-96 185.6 2981.4 2981.4 4-Aug-92 297.8 420.0 420.0 4-Aug-92 417.5 1000.0 1000.0 26-Aug-9? 210.0 300.0 300.0 26-Aug-9? 90.0 880.0 880.0 26-Aug-97 225.0 600.0 600.0 26-Aug-9? 270.0 280.0 280.0 26-Aug-9? 345.0 780.0 780.0 ARCO Alaska, Inc. West Sak -~,)-121 (G5) Stimulation, Diagram Four (4) Stage Frac-for-Sand Control with 4-1/2" Deadstring 6" Conductor @ 80' . ~ Stage Tool Placed 200' +/- TVD Below Permafrost 4-1/2" Deadstring to Frac Through, Off-Rig 4-1/2" x 7-5/8" Baker Retrievable Packer D Sand Frac'd with Resin Coated Proppant - B + A4 Sands Frac'd with Resin - Coated Proppant A3 Sand Frac'd with Resin - Coated Proppant - A2 Sand Frac'd with Resin - Coated Proppant 7-5/8" Combination Surface/ Production Casing, Cemented ~to Surface TWM, 9/15/97 West Sak 1D-l~,i Four (4) Stage J (G5) proposed Corr, r~letion Diagram Frac-for-Sand Control Completion ~. 16" Conductor @ 80' 2-7/8" Production Tubing Heat Trace Through Permafrost Stage Tool Placed 200' +/- TVD Below Permafrost Power Cable for ESP Mandrel/Valve to circulate well for freeze protection purposes ESP Pump Section ESP Gearbox ESP Motor Section ARCO Alaska, Inc. - D Sand Frac'd with Resin - Coated Proppant - B + A4 Sands Frac'd with Resin - Coated Proppant - A3 Sand Frac'd with Resin _- Coated Proppant - A2 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/ Production Casing, Cemented ~-to Surface TWM, 9/15/97 KUPARUK RIVER UNIT - WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 6 I4 I 5 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE ¢ OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 7 ,6 , 13 5/8" 5000 PS, BOP STACK West Sak Operations - Producer Wells 1. 16"- STARTING HEAD 2_ 11" - 5000 PSI HORIZONTAL TUBING HEAD 3. 11"-5000 PSI X 13-5/8"-5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. TWM, 9/16/97 8 , 7 6 5 4 3 1, 13 5/8" 5000 PS, BOP STACK West Sak Operations - Injector Wells ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- STARTING HEAD 2. 7-1/16" - 5000 PSI TUBING HEAD 3. 7-1/16"-5000 PSI X 13-5/8"-5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" 5000 PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8"-5000 PSI PIPE RAMS 6. 13-5/8"- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" - 5000 PSI ANNULAR TWM, 9/17/97 19/02/97; A~ PC AS-BU:., PER K~ Kg7082ACS , L COORDINATES SHO~ ARE A.S.P. ZONE 4, N.A.D. 2Z SEA LEAL. ALL D/STANCES SHO~ ARE TRUE. 2. BASIS OF LOCA UONS AND ELEVAUONS ARE D.S. 1-D PIT C O ~ 1 .MONUMENTS PER LHD AND ASSOCIA ~S. J, CONDUCTORS ARE LOCA~D ~TH/N P~OFRACTED SEC~ONS ~4 ~ 2J, TO.SHIP ~ NOR~, RANGE ~0 EAS~ U.M. 4. OATE OF SUR~: 8/25, 29 ~ 50/97, F/ELD BK L97-24, 5. DRILL Sl~ l-O GRID NOR~ iS ROTATED 00' 01' 05" ~ST FRO~ A.S.P. ZONE 4 GRID NORTH. 6. SEE DRA~NG NSK-5.5-~ FOR AS-BUILT LOCADONS OF CONDUCTORS ~1 THROUGH ~8. hTM ( ~;~*:"' '"'.~ ~' · /~-~ ,/ ~ ~ ~CINITY MAP ~ ..... ~.~.... ~I. ESSIONA~ ~ W~I No. 'y. A.S.P.s 'X' LA TITUOE LONGITUDE ~ ~ ~ ! E~ ELE~ , ! ~ S,~c. 14, T. 11 N. R. 10 E. 'FS.L. FE.L. ! ! ' 105 5,959,798.99 ~ 560,490.57 70" 18' 0Z6~7' t49" 30' ~6.263" t34' 595' 70.5' 62.0' ~06 5,959,768.93 ~ 560,490.67 70" 18' 02.~41" 149" 30' ~6.268" 104' 595' 70.4" 62.~' ~09 5,959,72~.89 I 560,490.60 70" 18' 0L898' 149" 30' ~6.280" 59' 596' 70.4' 62.7' S,~c. 23, T. 11 N., R. IO E. FN.L, FE.L. 115 5,959,60~.9~ 560,490.68 70" 18' 00.7~8" 149" 30' ~6.306" 6~' 597' 70.4" 6~.4' tt7 5,959,573.95 ~ 560,490.65 70" ~8' 00.42~" t49" 30' ~6.~4" 9~' 597' 70.~' 63.4' 118 5,959,558.95 560,490.68 70" tS' 00.276" i 149" 30' ~6.~6" ~06' 597' 70.4' 6~.4' 1~9 5,959,51~.86 560,490.72 70" 17' 59.8~2' 149" 30' ~6.~26" 15~' 598' 70.6' 66.0' ! 120 5,959,499.0~ 560,490.77 70" 17' 59.686" . ~49" 30' ~6.327" ~66' 598' 70.6' 66.0' ' 121 5,959,48~.89 560,490.67 70" ~7' 59.5~8" ~ ~49" ~0' ~6.335" 18~' 598'- 70.5' 66.0 124 5,959,393.96 560,490.70 70" ~7' 58.65~" I /49" 30' 36.~55" 27~' 599' 70.~' 65.0' i ~ , 129 ' 5,959,27~.92 560,490.79 70" I7' 5Z472" i 149" ~0' ~6.~80' ~9~ 600' 70.~' 68.2' 1~0 : 5,959,259.09 560,490.81 70" I7' 5Z326" 149" ~0' ~6.~83" 406' 600' 70.5' 68.2' ~ I 5,959,21~.89 560,490.68 70" ~7' 56.882' ~ 149" ~0" ~6.397' 45~' ! 600' 70.4' 69.0' 135 ~ 5,959,~9.02 560,490.80 70" ~7' 56.146' 149" 30' ~6.412" 526' ~ 60~' 70.5' 69.4' SUR~YOR'S CERERCA ~ ~ HE~EeY CE~n~Y THOr ~ ~ ~O~E~LY ~ES~S~EO ~NO UCENSED TO ~CnCE ~NO SU~.NS ~N STATE OF ALASKA AND ~r ~lS PLAT REPRESENTS X~ LOUNSBURY A SURLY DONE BY ME OR UNDER MY DiRECt~m~~/j~[ ~ ASSOCIATES, INC. SUPER~SiON AND ~AT ALL DIMENSIONS AND O~ER DETAILS ARE CORRECt AS OK AUGUSt JO, 199Z ~~-~~ e~s~ suR~o~ AREA' 1D ~ULE ' XX UNIT' D1 A R C O A m a s k a, I n c. SAX ,.,SE, - CO. DUCTO,S AS-BUILT Wdl A.S.P.s LA TITUDE LONGITUDE ',-"-SEC.,,,,,-SEC. PAO O.S. No. 'Y' 'x' ~d~ ~'~ E~v.ELEV. $,."C. 14, T. 11 N., R. 10 E. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.637" 149" 30' 36.265' 154' 595' 70.5' 62.0' 106 5,959,768.9`7 560,490.67 70' 18' 02.$41" 149" ,.70' 36.268" 104' 595" 70.4' 62.3' 109 5,959,723.89 560,490.60 70' 18' 01.898" 149' ,,,TO' ,.,T6,280" 59" 596' 70.4' 62.7' S,,.c. 23, T. 11 N., R. 10 E. F.N.L. F.E.L. 115 5,959,605.95 560,490.68 70' 18' 00.718" 149' 30' 36.$06' 61' 597' 70.4' 63.4' 117 5,959,573.95 560,490,65 70' 18' 00.42`7" 149' ,30' 36.314" 91' 597' 70.4' 63.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' 30' ,.76.316" 106' 597' 70.4' 6,3.4' 119 5,959,515.86 560,490.72 70' 17' 59.832" 149' ,70' ,,76.326' 15I' 598' 70.6' 66.0" 120 5,959,499.01 560,490.77 70' 17' 59.686" 149' ,30' 36,327" 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70" 17' 59.558" 149' 30' ,.76.335" 18I' 598'- 70.5' 66.0 124 5,959,$95.96 560,490.70 70' 17' 58653" 149" 30' 36.`755" 27I' 599' 70.3' 65.0' 129 5,959,273,92 560,490.79 70' I7' 57.472" 149' `70' 36.`780" `791' 600' 70.,1' 68.2' 130 5,959,259.09 560,490.81 70' I7' 57.`726" 149' ,70' ,76.38,5" 406' 600' 70.5' 682' 133 5,959,213.89 560,490.68 70' 17' 56.882" 149' 30' ,76.397" 45I' 600' 70.4' 69.0' 135 5,959,1,:79.02 560,490.80 70' 17' 56.146" 149' 30' ,76.412" 526' 601' 70.5' 69.4' SENT BY:ARCO ALASKA ~'Vl DATE I BY I Ct( lAPel ,:'--")ESCRIPllON l~V. DATE BY ? .... '1 APl:' O£SCmP'TK)N LEGEND sE~ SHEET ~ 2 FOR ~S ~O L~TION INFORMATION o ~x/sn~ co~c~s ARCO Alaska, Inc. ~~ST SAK PHASE ' - ~ C~OUCTORS AS-BUILT m61~10 9/02/97 CEA-D1DX-610~IO 1 or 2 2 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor September 17, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-121 (G5) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. Please find attached information as required by 20 AAC 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 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements detailed in ARCO's testimony for West Sak Pool Rules governing the West Sak development project. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) 7) 8) 9) 10) Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-121, such as shallow gas. There have been eight (8) Kuparuk wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. Please notel.: that ARCO requests permission to use two (2) well annuli which/'~ are not located on KRU 1D pad, and that ARCO requests that the(, 35,000 bbls disposal limitation be increased for these two annuli / in order to accommodate the predicted volume of waste to be generated from the West Sak Phase lA development operation.{ The Phase lA development includes the drilling of fourteen (14) i West Sak wells from the KRU 1 D pad. ARCO requests that the WSI-01 and 1C-12 wells be permitted to receive 50,000 bbls of// waste each for the West Sak Phase lA project. Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development welt, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is October 191 1997. If you have any questions or require further information, please contact Tom McKay at (907) 265-6890. Sincerely, Thomas W. McKay, P.E. Senior Drilling Engineer Attachments CC: West Sak 1D-121 (G5) Well File Tom Brockway ATO-1207 Mike Zanghi ATO-1276 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 · WELL PERMITCHECKLISTCOMPANY ..../,~,,,.,.~ WELL NAME [..L,/~/,-~,~P /~)-/'~/~ PROGRAM:expEidev~redrllElservrlwellboresegDann. disposalparareql] FIELD&POOL ~ ?('~/_~"Q~ INIT CLASS ~-~ ,,)-45~,'/ GEOLAREA ~,~?~:~ UNIT# //t,,7~::~ ON/OFFSHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS ENGINEERING 14. Conductor string provided ................... (~) N 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... ~N 17. CMT vol adequate to tie-in long string to surf csg ........ N 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... Y N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 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 ................. Y(~ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ 31. Data presented on potential overpressure zones ....... Y ~ /L,/,,/)'-'/ ; 32. Seismic analysis of shallow gas zones ............. Y//N 33. Seabed condition survey (if off-shore) ............. /'Y N 34. Contact name/phone for we,ekly,orog, ress reports ...... / Y N lexp~ora~ory only] GEOLOGY: RPC//~C~ ENGINEERING' COMMISSION: JDH ~ RNC~ CO Ex> Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . ....... SCHLUMBERGER ....... COMPANY NAM~ : ARCO ALASKA, INC. WELL NAME : WEST SAK 1D-121 (GS) FIELD NAME : KUPARUKRIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 50-029-22814-00 REFERENCE NO : 97559 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/03/ 4 ORIGIN : FLIC REEL NAME : 97559 CONTINUATION # : PREVIOUS REEL : COM~ENT · ARCO ALASKA INC, WEST SAK 1D-121 (GS), KUPARUK, API #50-029-22814 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/03/ 4 ORIGIN · FLIC TAPE NAM~ : 97559 CONTINUATION # : 1 PREVIOUS TAPE : COM~fEiTT : ARCO ALASKA INC, WEST SAK 1D-121 (GS) , KUPARUK, API #50-029-22814 TAPE HEADER Kuparuk River Unit OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA RUN 1 JOB NI]M~ER: 97559 LOGGING ENGINEER: Morrison OPERATOR WITNESS: Whitlock SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING West Sak 1D-121 (GS) 500292281400 ARCO Alaska, Inc. SCHLUMBERGER WELL SERVICES 4-MAR-98 RUN 2 RUN 3 23 liN IOE 181 598 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 126.0 70.00 110.49 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 3RD STRING PRODUCTION STRING REMARKS: THIS IS THE DATA FROM THE OPEN HOLE LOGS RUN 2-DEC-97. THE LOGS WERE DEPTH SHIFTED TO THE SPERRY MWD GR. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE · 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE .............. SDN CNT $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4414.0 118.0 4397.0 118.0 BASELINE DEPTH 88888.0 4365.5 4337.5 4322.0 4291 5 4277 5 4233 0 4219 0 4173 5 4157 0 4132 0 4093 5 4057 5 3965 5 3955 5 3943 5 3891 5 3849 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT .............. 88888.0 4365.5 4338.0 4322.0 4292.0 4277.5 4233.5 4219.0 4173.0 4155.5 4132.0 4094.0 4057.5 3965.0 3955.5 3943.0 3891.5 3848.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3835.0 3811.0 3782.0 3773.0 3732.5 3698.0 3685.5 3672.5 3634.5 3620.5 3614.0 3595.0 3577.5 3561.5 3553.0 3536.5 3502.0 3480.0 3468.0 3456.0 3445.5 3374.5 3365 0 3351 5 3340 5 3324 5 3304 5 3290 5 3269 5 3262 0 3231.5 3217.5 3175.0 3150.0 3121.5 3091.5 3035.0 3012.0 2987.5 2968.5 2886.0 2853.5 2809.5 2796.0 2786.5 2777.5 2756.0 2752.5 2726.5 2708.0 2699.5 2644.5 2639.0 2632.5 2594.0 3834.0 3810.5 3782.0 3772.5 3732.5 3698.5 3685.5 3672.0 3634.5 3620.0 3614.0 3594.5 3577.5 3561.0 3552.0 3536.0 3502.0 3479.5 3468.0 3455.5 3445.5 3374.0 3365.5 3351.5 3341.0 3324.5 3305.0 3290.5 3269.0 3262.0 3232.0 3217.5 3174.5 3150.0 3121.0 3091.5 3034.5 3012.0 2987.0 2968.5 2885.5 2853.5 2809.0 2796.0 2787.0 2779.0 2756.5 2752.5 2726.0 2708.0 2699.0 2644.5 2638.0 2632.5 2593.5 4-MAR-1998 16:29 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 2587.0 2578.5 2545.5 2498.5 2491.5 2233.5 2221.0 2203.5 2173.5 2134.5 2116.0 2095.5 2086.5 2079.0 2073.0 2066.0 2023.5 2002.5 1988.0 1955.5 1950.0 1789.5 1782.5 1774.5 1761.5 1716.5 1715.0 1699 0 1588 5 1558 5 1543 5 1477 0 1468 0 1451 0 1445 5 1378 0 1370 5 1356.0 1348.0 1333.5 1328.5 1319.0 1308.5 1295.0 1279.0 1274.5 1217.0 1203.5 1200.0 1195.0 1180.0 1164.0 1141.0 1130.5 1125.0 2587.0 2579.0 2545.5 2498.0 2491.5 2233.0 2221.0 2203.0 2173.5 2135.0 2116.0 2095.0 2087.0 2079.0 2072.5 2064.5 2023.0 2002.5 1987.5 1956.0 1950.0 1788.5 1782.0 1773.5 1761.0 1716.5 1715.5 1699.0 1589.0 1558.0 1543.5 1476.5 1467.0 1451.5 1445.5 1378.5 1370.5 1356.5 1349.5 1333.5 1327.5 1319.5 1308.5 1295.5 1280.0 1275.0 1217.0 1203.0 1199.0 1195.5 1180.0 1163.5 1141.0 1131.0 1125.0 4-MAR-1998 16:29 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 1101.5 1102.0 1090.5 1091.5 1078.5 1078.5 1040.0 1040.5 1035.5 1036.5 1031.0 1032.5 1023.5 1023.5 1018.5 1018.0 996.0 997.0 979.0 979.5 947.5 948.5 938.5 939.0 901.0 901.0 895.0 894.5 880.5 880.5 863.0 864.0 837.5 839.0 829.5 83 O. 0 814.0 814.0 788.0 787.5 786.0 786.0 769.0 768.5 760.0 760.5 728.5 728.5 727.0 726.5 714.0 714.0 682.5 683.0 678.0 677.5 668.5 668.5 633.5 632.0 623.5 624.0 619.0 619.0 563.0 562.5 547.5 547.5 536.5 536.0 527.5 527.5 524.5 524.0 520.0 520.5 517.5 517.5 508.5 508.0 503.5 502.5 489.0 487.5 484.0 483.0 468.0 468.0 405.5 405.0 360.0 360.0 341.5 342.0 332.0 332.0 296.5 296.0 286.5 286.5 224.0 223.5 220.5 220.5 192.0 192.5 144.5 144.5 142.5 142.0 4-MAR-1998 16:29 PAGE .. LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:2~ PAGE '. 134.0 133.0 100.0 99.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. $ REMARKS: PASS NO. M~ERGE TOP MERGE BASE THIS IS THE CLIPPED AND EDITED DATA FROM THE MAIN PASS OH DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 i i 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUM~ SAMP ELEM CODE (HEX) NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 4418.000 GR.SDN -999.250 TENS.SDN 2947.000 CNTC. CNT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 ENPH. CNT -999.250 CNEC. CNT CFEC. CNT -999.250 TNPH. CNT -999.250 CALI.SDN -999.250 DRHO.SDN PEF. SDN -999.250 RHOB.SDN -999.250 DEPT. 4000.000 GR.SDN 68.974 TENS. SDN 2827.313 CNTC. CNT CFTC. CNT 558.002 FCNT. CNT 522.578 NCNT. CNT 2023.148 CRAT. CNT NRAT. CNT 3.861 NPHI.CNT 37.648 E1VPH. CNT 46.691 CNEC. CNT CFEC. CNT 395.218 TNPH. CNT 39.471 CALI.SDN 9.977 DRHO.SDN PEF. SDN 2.607 RHOB.SDN 2.113 DEPT. 3000.000 GR.SDN 41.468 TENS.SDN 2267.313 CNTC. CNT CFTC. CNT 567.008 FCNT. CNT 528.219 NCNT. CNT 2082.719 CRAT. CNT NRAT. CNT 4.009 NPHI.CNT 41.133 ENPH. CNT 45.490 CNEC. CNT CFEC. CNT 408.867 TNPH. CNT 40.873 CALI.SDN 10.358 DRHO.SDN PEF. SDN 2.278 RHOB.SDN 2.061 DEPT. 2000.000 GR.SDN 67.451 TENS.SDN 1642.688 CNTC. CNT CFTC. CNT 410.344 FCNT. CNT 381.563 NCNT. CNT 1797.875 CRAT. CNT NRAT. CNT 4.503 NPHI.CNT 50.206 ENPH. CNT 55.515 CNEC. CNT CFEC. CNT 340.125 TNPH. CNT 55.231 CALI.SDN 10.192 DRHO. SDN PEF. SDN 2.596 RHOB.SDN 2.101 DEPT. 1000.000 GR.SDN 87.484 TENS.SDN 947.719 CNTC. CNT CFTC. CNT 441.420 FCNT. CNT 404.813 NCNT. CNT 1680.016 CRAT. CNT NRAT. CNT 3.770 NPHI.CNT 39.547 ENPH. CNT 49.174 CNEC. CNT CFEC. CNT 346.588 TNPH. CNT 43.099 CALI.SDN 10.718 DRHO.SDN PEF. SDN 2.890 RHOB.SDN 2.084 DEPT. 118.000 GR.SDN 22.352 TENS.SDN 716.000 CNTC. CNT CFTC. CNT 265.444 FCNT. CNT 262.101 NCNT. CNT 1307.021 C~T. CNT NRAT. CNT 5.133 NPHI.CNT 52.476 ENPH. CNT 102.080 CNEC. CNT CFEC. CNT 201.030 TNPH. CN~f 62.909 CALI.SDN 22.553 DRHO.SDN PEF. SDN 2.410 RHOB.SDN 1.171 -999.250 -999.250 -999.250 -999.250 2007.984 3.631 2421.234 0.007 2082.922 3.858 2469.313 -0.008 1768.125 4.451 2252.500 0.012 1672.908 3.755 2176.051 0.005 1204. 490 4.599 1729. 269 -0. 038 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUF~L~gY LDWG TOOL CODE START DEPTH CNT 118.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 4365.5 4365.5 4337.5 4338.0 4322.0 4322.0 4291.5 4292.0 4277.5 4277.5 4233.0 4233.5 4219.0 4219.0 4173.5 4173.0 STOP DEPTH 88.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT 88888.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4157.0 4132.0 4093.5 4057.5 3965.5 3955.5 3943.5 3891.5 3849.0 3835.0 3811.0 3782.0 3773.0 3732.5 3698.0 3685.5 3672.5 3634.5 3620.5 3614.0 3595.0 3577.5 3561.5 3553.0 3536.5 3502 0 3480 0 3468 0 3456 0 3445 5 3374 5 3365 0 3351 5 3340 5 3324 5 3304 5 3290 5 3269 5 3262.0 3231.5 3217.5 3175.0 3150.0 3121.5 3091.5 3035.0 3012.0 2987.5 2968.5 2886.0 2853.5 2809.5 2796.0 2786.5 2777.5 4155.5 4132.0 4094.0 4057.5 3965.0 3955.5 3943.0 3891.5 3848.5 3834.0 381 O. 5 3782.0 3772.5 3732.5 3698.5 3685.5 3672.0 3634.5 3620.0 3614.0 3594.5 3577.5 3561.0 3552 0 3536 0 3502 0 3479 5 3468 0 3455 5 3445 5 3374 0 3365 5 3351.5 3341.0 3324.5 3305.0 3290.5 3269.0 3262.0 3232.0 3217.5 3174.5 3150.0 3121.0 3091.5 3034.5 3012.0 2987.0 2968.5 2885.5 2853.5 2809.0 2796.0 2787.0 2779.0 4-MAR-1998 16:29 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 2756.0 2752.5 2726.5 2708.0 2699.5 2644.5 2639.0 2632.5 2594.0 2587.0 2578.5 2545.5 2498.5 2491.5 2233.5 2221.0 2203.5 2173.5 2134.5 2116.0 2095.5 2086 5 2079 0 2073 0 2066 0 2023 5 2002 5 1988 0 1955 5 1950 0 1789.5 1782.5 1774.5 1761.5 1716.5 1715.0 1699.0 1588.5 1558.5 1543.5 1477.0 1468.0 1451.0 1445.5 1378.0 1370.5 1356.0 1348.0 1333.5 1328.5 1319.0 1308.5 1295.0 1279.0 1274.5 2756.5 2752.5 2726.0 2708.0 2699.0 2644.5 2638.0 2632.5 2593.5 2587.0 2579.0 2545.5 2498.0 2491.5 2233.0 2221.0 2203.0 2173.5 2135.0 2116.0 2095.0 2087.0 2079.0 2072.5 2064.5 2023.0 2002 5 1987 5 1956 0 1950 0 1788 5 1782 0 1773 5 1761 0 1716.5 1715.5 1699.0 1589.0 1558.0 1543.5 1476.5 1467.0 1451.5 1445.5 1378.5 1370.5 1356.5 1349.5 1333.5 1327.5 1319.5 1308.5 1295.5 1280.0 1275.0 4-MAR-1998 16:29 PAGE: 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 1217.0 1203.5 1200.0 1195.0 1180.0 1164.0 1141.0 1130.5 1125.0 1101.5 1090.5 1078.5 1040.0 1035.5 1031.0 1023.5 1018.5 996.0 979.0 947.5 938.5 901.0 895.0 880.5 863.0 837.5 829.5 814.0 788.0 786.0 769.0 760.0 728.5 727.0 714.0 682.5 678.0 668.5 633.5 623.5 619.0 563 0 547 5 536 5 527 5 524 5 520 0 517 5 508 5 503 5 489 0 484 0 468 0 405 5 360.0 1217.0 1203.0 1199.0 1195.5 1180.0 1163.5 1141.0 1131.0 1125.0 1102.0 1091.5 1078.5 1040.5 1036.5 1032.5 1023.5 1018.0 997.0 979.5 948.5 939.0 901.0 894.5 880.5 864.0 839. 0 830.0 814.0 787.5 786.0 768.5 760.5 728.5 726.5 714.0 683.0 677.5 668.5 632.0 624 0 619 0 562 5 547 5 536 0 527 5 524 0 520 5 517 5 508 0 502 5 487.5 483.0 468.0 405.0 360.0 4-MAR-1998 16:29 PAGE: 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 12 341.5 332.0 296.5 286.5 224.0 220.5 192.0 144.5 142.5 134.0 100.0 342.0 332.0 296.0 286.5 223 5 220 5 192 5 144 5 142 0 133 0 99 0 ~S: THIS IS THE CLIPPED AND EDITED CH DATA FROM THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB AUJI4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GRCH SDN GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 13 NAME SERV UNIT SERVICE API API API API FILE NUMB NtrM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CArT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 TNPH CNT PU-S O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 118.000 GRCH. SDN 22.352 TENS. SDN 716.000 CNTC. CNT CFTC. CNT 265.444 FCNT. CNT 262.101 NCNT. CNT 1307.021 CRAT. CNT NRAT. CNT 5.133 NPHI.CNT 52.476 ENPH. CNT 102.080 CNEC. CNT CFEC. CNT 201. 030 TNPH. CNT 62. 909 DEPT. 89.000 GRCH. SDN 21.359 TENS. SDN 670.000 CNTC. CNT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 ENPH. CNT -999.250 CNEC. CNT CFEC. CNT -999.250 TNPH. CNT -999.250 1204.490 4.599 1729.269 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFZE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 14 FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NU3~ER : 1 DEPTH INCREMENT: O . 5000 FILE SU3~iARY VENDOR TOOL CODE START DEPTH LDT 4414.0 CNTG 4398.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 118.0 118.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDTD LITHODENSITY CNTG EPITH. NEUTRON GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TE3IPERATURE (DEGF) RESISTIVITY (OtH4M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 2-DEC-97 8C0-609 1030 2-DEC-97 1500 2-DEC-97 4414.0 4418.0 126.0 4397.0 1800.0 TOOL NUMBER DRS-C 4824 CNC-GA SGC- SA 9.875 126.0 126.0 Spud Mud 9.10 290.0 8.5 90.0 5.110 65.0 5.560 67.0 3. 420 65.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 15 MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX.. MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to I DEC 1997 Sperry Sun GR Bowspring on CNL Density calibrated after job due to out of date CALS that **** THIS IS THE RAW OH DATA FROM THE MAIN PASS**** $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE ~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GR LDT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) FCNT CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNT PU O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNT PU O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNT PU O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN O0 000 O0 0 3 1 1 4 68 0000000000 DRHOLDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 4428.000 GR.LDT 139.515 TENS.LDT 1156.000 CNTC. CNT CFTC. CNT 491.360 FCNT. CNT 459.834 NCNT. CNT 1868.897 CRAT. CNT NRAT. CNT 4.000 NPHI.CNT 40.677 ENPH. CNT 30.427 CNEC. CNT CFEC. CNT 402.700 TNPH. CNT 42.321 CALI.LDT 2.929 DRHO.LDT PEF. LDT 2.860 RHOB.LDT 2.237 DEPT. 4000.000 GR.LDT 67.776 TENS.LDT 2864.000 CNTC. CNT CFTC. CNT 556.479 FCNT. CNT 510.734 NCNT. CNT 2029.355 CRAT. CNT NRAT. CNT 3.710 NPHI.CNT 38.480 ENPH. CNT 46.143 CNEC. CNT CFEC. CNT 395.776 TNPH. CNT 39.293 CALI.LDT 10.010 DRHO.LDT PEF.LDT 2.557 RHOB.LDT 2.100 DEPT. 3000. 000 GR.LDT 40. 716 TENS. LDT 2299. 000 CNTC. CNT CFTC. CNT 561 . 017 FCNT. CNT 500. 896 NCNT. CNT 2060. 086 CRAT. CNT NRAT. CNT 3. 921 NPHI. CNT 41. 441 ENPH. CNT 43. 630 CNEC. CNT CFEC. CNT 412.345 TNPH. CNT 40.956 CALI.LDT 10.301 DRHO.LDT PEF. LDT 2. 291 RHOB. LDT 2. 058 DEPT. 2000.000 GR.LDT 67.966 TENS.LDT 1629.000 CNTC. CNT CFTC. CNT 401.323 FCNT. CNT 370.412 NCNT. CNT 1756.575 CRAT. CNT NRAT. CNT 4.547 NPHI.CNT 51.140 ENPH. CNT 57.018 CNEC. CNT CFEC. CNT 332.452 TNPH. CNT 56.470 CALI.LDT 10.202 DRHO.LDT PEF.LDT 2.618 RHOB.LDT 2.095 DEPT. 1000.000 GR.LDT 86.249 TENS.LDT 999.000 CNTC. CNT CFTC. CNT 469.657 FCNT. CNT 442.863 NCNT. CNT 1724.147 CRAT. CNT NRAT. CNT 4.083 NPHI.CNT 41.805 ENPH. CNT 50.140 CNEC. CNT CFEC. CNT 342.205 TNPH. CNT 39.129 CALI.LDT 10.716 DRHO.LDT PEF.LDT 2.907 RHOB.LDT 2.082 1842.726 3.829 1920.414 0.069 1997.174 3.685 2410.347 0.007 2063.464 3.878 2437.977 -0.008 1749.276 4.512 2232.833 0.011 1681. 402 3. 902 2169. 863 O. 010 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 17 DEPT. 118.000 GR.LDT CFTC. CNT 232.868 FCNT. CNT NRAT. CNT 5.448 NPHI.CNT CFEC. CNT 211.212 TNPH. CNT PEF. LDT 2.039 RHOB.LDT 22. 778 TENS. LDT 196. 010 NCNT. CNT 60. 071 ENPH. CNT 97. 315 CALI. LDT 1.102 685.000 CNTC. CNT 1132.153 CRAT. CNT 109.211 CNEC. CNT 16.317 DRHO.LDT 1210.094 5.095 1874.044 -0.153 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~9~ARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH LDT 4414.0 4190.0 CNT 4398.0 4190.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): 2-DEC-97 8C0-609 1030 2-DEC-97 1500 2-DEC-97 4414.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 18 TD LOGGER (FT) : TOP LOG INTERVAL (?T) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 4418.0 126.0 4397.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDTD LITHODENSITY CNTG EPITH. NEUTRON GR GA~P4A RAY $ TOOL NUAf~ER DRS-C 4824 CNC-GA SGC-SA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 9.875 126.0 126.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) : 290.0 MUD PH: 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATUPoE (DEGF) : 90.0 RESISTIVITY (OI~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 5.110 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 5. 560 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 3. 420 MUD CAKE AT (BHT) : 65.0 67.0 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 1 DEC 1997 Sperry Sun GR Bowspring on CArL Density calibrated after job due to out of date CALS that ****THIS IS THE RAW OH DATA FROM THE REPEAT PASS**** $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELaM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 GR LDT GAPI O0 000 O0 0 4 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 4 1 1 4 68 0000000000 Iv-RATCNT O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNT PU O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNT PU O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNT PU O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDT IN O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDT G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDT O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LDT G/C3 O0 000 O0 0 4 i 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 20 DEPT. 4427. 500 GR. LDT CFTC. CNT 370. 638 FCNT. CNT NRAT. CNT 5. 667 NPHI. CNT CFEC. CNT 541 . 615 TNPH. CNT PEF. LDT 2.371 RHOB.LDT DEPT. 4190.000 GR.LDT CFTC. CNT 558.096 FCNT. CNT NRAT. CNT 3.746 NPHI.CNT CFEC. CNT 436.985 TNPH. CNT PEF. LDT 2.937 RHOB.LDT 134. 664 TENS. LDT 346. 857 NCNT. CNT 65.109 ENPH. CNT 106.317 CALI.LDT 2.204 102. 001 TENS.LDT 526. 751 NCNT. CNT 36. 076 ENPH. CNT 36. 021 CALI.LDT 2.338 1134.000 CNTC. CNT 2003.087 CRAT. CNT 20.272 CNEC. CNT 2.931 DRHO.LDT 2865.000 CNTC. CNT 1966.546 CRAT. CNT 39.361 CNEC. CNT 10.255 DRHO.LDT 1975.037 5.424 2075.549 -0.006 1958.269 3.528 2451.035 0.022 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 118.0 88.0 $ LOG HEADER DATA DATE LOGGED: 2-DEC-97 SOFTWARE VERSION: 8C0-609 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 21 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 1030 1500 4414.0 4418.0 126.0 4397.0 1800.0 2-DEC-97 2 -DEC- 97 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDTD LITHODENSITY CNTG EPITH. NEUTRON GR GAFk4A RAY $ TOOL~ER DRS-C 4824 CNC-GA SGC-SA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 9. 875 126.0 126.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) : 290.0 MUD PH : 8.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 90.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 5. 110 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 5. 560 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 3. 420 MUD CAKE AT (BHT) : 65.0 67.0 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Depth Correlated to 1 DEC 1997 Sperry Sun GR Bowspring on CNL Density calibrated after job due to out of date CALS that ****THIS IS THE RAW CH DATA FROM THE MAIN PASS**** $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAlV ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 GRCHLDT GAPI O0 000 O0 0 5 1 1 4 68 0000000000 TENS LDT LB O0 000 O0 0 5 1 i 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNT PU O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNT PU O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNT CPS O0 000 O0 0 5 1 1 4 68 0000000000 TNPH CNT PU O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 118.000 GRCH. LDT 22.778 TENS.LDT 685.000 CNTC. CNT CFTC. CNT 232.868 FCNT. CNT 196.010 NCNT. CNT 1132.153 CRAT. CNT NRAT. CNT 5.448 NPHI. CNT 60.071 ENPH. CNT 109.211 CNEC. CNT CFEC. CNT 211.212 TNPH. CNT 97.315 1210.094 5.095 1874.044 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-MAR-1998 16:29 PAGE: 23 DEPT. 89.000 GRCH. LDT CFTC. CNT 460.425 FCNT. CNT NRAT. CNT 3.863 NPHI.CNT CFEC. CNT 342.680 TNPH. CNT 25.373 TENS.LDT 451.575 NCNT. CNT 37.803 ENPH. CNT 38.045 700.000 1643.492 46.249 CNTC. CNT CRAT. CNT CNEC. CNT 1621.216 3.641 2089.415 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/03/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/03/ 4 ORIGIN · FLIC TAPE NAME : 97559 CONTINUATION # : 1 PREVIOUS TAPE : COM~_JTT . ARCO ALASKA INC, WEST SAK 1D-121 (GS), KUPARUK, API #50-029-22814 **** REEL TRAILER **** SERVICE NAME : EDIT DATE - 98/03/ 4 ORIGIN : FLIC REEL NAME : 97559 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, WEST SAK 1D-121 (GS), KUPARUK, API #50-029-22814 Sperry-Sun Drilling Services LIS Scan Utility Wed Dec 24 11:33:37 1997 Reel Header Service name ............. LIST?E Date ..................... 97/12/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Scientific Tape Header Service name ............. LISTPE Date ..................... 97/12/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment RecOrd TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: MWD RUN 1 AK-MM-80028 P. SMITH G. WHITLOCK RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M C OF]LM D 1D-121 500292281400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 24-DEC-97 23 liN 10E 181 598 .00 111.00 70.50 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 4414.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. WELL 1D-121 REACHED A TOTAL DEPTH OF 4414'MD, 4315'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Con~nent Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH STOP DEPTH 121.5 4374.0 121.5 4374.0 121.5 4374.0 121.5 4374.0 121.5 4374.0 121.5 4381.5 121.5 4415.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR EQUIVALENT UNSHIFTED DEPTH 121.5 142.5 144.0 147.0 152.0 159.0 159.5 162.0 187.0 190.5 192.5 204.0 205.0 205.5 207.0 209.5 212.5 213.5 220.5 223.5 226.5 229.5 230.0 237.5 239.5 242.0 255.0 262.5 265.0 267.5 275.0 280.0 284.0 286.0 287.0 289.5 291.5 300.5 304.0 314.0 318.0 322.0 324.5 332.0 333.5 337.0 339.5 340.5 342.0 344.0 345.0 351.0 353.5 355.5 360.0 362.5 364.0 365.5 366.5 368.0 121.0 142.0 144.0 146.5 155.5 160.0 161.5 163.5 187.5 191.0 192.5 204.5 205.0 206.5 208.0 209.5 213.0 214.5 221.5 224.0 225.5 229.5 231.0 237.5 239.5 243.5 255.5 264.0 266.5 270.0 276.5 280.0 285.0 286.5 287.5 290.5 291.5 302.0 305.0 313.5 316.5 322.0 323.5 333.0 334.5 336.0 337.0 340.5 342.0 344.0 345.5 351.5 353.0 356.0 360.5 362.5 364.5 366.0 366.5 368.5 371.5 374.5 395.0 398.5 400.5 405.0 407.5 410.0 414.5 416.5 423.0 425.5 427.0 429.5 434.5 437.5 438.5 440.5 442.0 452.0 454.0 461.0 463.0 464.5 468.0 470.5 476.5 527.5 534.0 536.0 537.0 538.5 542.0 544-.0 546.0 548.0 550.5 553.5 555.0 558.0 559.5 560.5 562.5 582.0 586.5 588.0 610.5 612.5 613.5 616.0 617.5 619.0 636 0 641 5 654 5 656 0 659 5 662 0 675 0 678 0 372.0 375.5 395.0 398.5 401.0 404.5 408.5 410.0 414.0 417.0 424.0 425.0 427.5 431.5 435.0 438.0 439.5 441.0 443.0 452.5 454.5 461.5 463.5 465.5 467.5 470.5 477.5 529.5 536.5 537.0 538.5 539.5 543.5 546.5 548.0 550.5 552.0 556.0 557.5 560.0 561.0 563.0 565.0 582.5 587.0 589.5 611.5 613.5 615.0 617.5 619.5 621.5 638.5 647.5 656.5 658.5 661.5 663.5 676.5 679.0 680.5 681.5 692.5 694.0 695.0 696.5 698.0 699.5 700.5 700.5 703.0 704.0 714.0 716.0 717.5 717.0 721.0 724.0 724.0 724.5 725.0 726.5 726.5 727.0 727.5 728.5 728.5 730.5 732.0 733.5 734.5 736.0 755.5 754.0 756.5 757.0 760.0 760.0 773.0 774.0 774.5 774.5 775.0 776.5 779.5 781.0 784.0 785.0 786.0 786.5 788.0 789.0 791.0 791.5 792.0 792.5 800.0 801.0 807.0 808.0 811.0 809.0 813.0 814.5 814.0 816.0 820.5 819.0 821.5 820.0 823.5 823.0 824.5 825.5 830.0 829.5 837.0 835.0 · 873.0 874.0 875.5 876.5 878.0 878.5 879.0 881.0 880.5 882.0 882.0 883.5 884.5 887.0 890.0 891.5 892.5 893.5 894.5 895.0 901.0 902.0 904.5 903.5 1012 . 5 1012 . 5 1018.5 1019.0 1058.0 1058.0 1063.0 1063.5 1071.5 1075.0 1078.0 1078.5 1082 . 0 1082.0 1089.0 1087.5 1122.5 1121.5 1124.5 1125.5 1127.0 1131.0 1138.5 1196.5 1200.0 1201.5 1203.5 1214.0 1217.0 1220.0 1221.5 1226.0 1276.0 1283.0 1295.0 1308.5 1309.5 1311.5 1312.5 1314.0 1319.5 1321.5 1333.5 1340.5 1351.5 1356.0 1369.0 1370.5 1373.0 1375.0 1377.5 1391.5 1393.5 1407.5 1409.0 1410.5 1416.5 1419.0 1420.5 1436.0 1473.0 1474.0 1476.5 1496.0 1498.5 1500.5 1510.5 1523.0 1528 0 1535 5 1539 0 1541 5 1543 5 1545 0 1547 0 1553 0 1554 0 1556 0 1125.0 1126.0 1127.0 1130.5 1138.5 1196.0 1201.0 1202.5 1205.0 1214.5 1217.5 1220.0 1223.5 1227.0 1276.5 1283.0 1292.5 1307.0 1308.5 1309.5 1311.5 1312.0 1319.0 1321.0 1336.0 1342.0 1351.5 1355..0 1367.5 1370.0 1372.5 1374.0 1376.5 1390.0 1392.5 1406.5 1407.0 1412.0 1419.0 1421.5 1423.0 1437.5 1475.5 1476.5 1480.5 1497.5 1500.0 1502.0 1515.5 1525.0 1527.5 1536.0 1540.5 1542.5 1545.0 1547.0 1548.5 1554.0 1555.0 1557.0 1558.0 1560.5 1564.0 1568.0 1569.0 1572.5 1574.0 1602.0 1605.5 1611.5 1614.0 1619.0 1622.0 1641.0 1644.5 1654.5 1657.0 1658.0 1659.0 1662.0 1663.5 1670.0 1673.0 1680.5 1683.5 1685.0 1695.0 1697.5 1698.0 1699.0 1716.5 1720.5 1740.0 1746.0 1748.5 1750.5 1756.0 1782.5 1793.0 1797.5 1826.0 1855.0 1858.0 1859.5 1862.0 1863.5 1897.5 1901.0 1909 5 1911 5 1913 0 1918 0 1918 5 1919 5 1922 5 1923 0 1924.5 1927.5 1928.5 1930.0 1559.0 1561.5 1563.5 1567.0 1569.0 1573.5 1574.0 1603.5 1606.5 1610.0 1612.5 1618.5 1621.5 1642.0 1645.0 1653.5 1655.5 1658.0 1659.0 1662.0 1662.5 1668.0 1671.0 1678.5 1682.5 1686.0 1693.5 1695.0 1696.5 1698.0 1716.0 1720.0 1740.0 1746.5 1749.5 1750.5 1756.5 1782.0 1792.0 1796.0 1826.0 1855.5 1858.0 1860.0 1863.5 1865.0 1896.0 1900.5 1906.0 1907.5 1908.5 1915.0 1915.5 1916.5 1918.0 1919.5 1921.5 1924.0 1927.0 1928.0 1934.5 1937.0 1938.0 1940.5 1950.0 1951.5 1964.0 1966.5 1987.5 199(~. 0 1992.0 1995.0 1997.0 1997.5 2000.0 2002.0 2006.0 2007.5 2017.0 2019.0 2020.5 2023.0 2060.5 2073.0 2091.0 2095 5 2100 0 2114 0 2116 0 2117 0 2120 5 2123.5 2143.0 2145.0 2152.0 2153.5 2155.0 2156.5 2158.5 2160.0 2168.0 2171.0 2172.0 2173.5 2175.5 2176.5 2178.5 2197.5 2199.0 2200.5 2203.5 2206.0 2208.5 2213.5 2215 5 2217 5 2219 0 2221 0 2230 0 2233 5 1933.0 1936.0 1938.0 1939.0 1949.5 1950.5 1963.5 1966.5 1987.0 1988.5 1990.0 1993.0 1995.0 1996.0 1998.5 2000.5 2003.5 2005.5 2016.0 2017.5 2019.0 2021.5 2060.0 2073.5 2090.5 2094.5 2098.5 2112.5 2114.5 2116.0 2119.0 2122.5 2141.0 2144.0 2151.0 2153.0 2154.5 2155.5 2157.5 2160.0 2167.0 2169.0 2170.5 2172.0 2174.0 2176.5 2177.5 2196.0 2198.5 2200.5 2202.5 2204.0 2208.5 2212.5 2214.5 2216.5 2219.0 2220.0 2229.0 2233.0 2238 2240 2241 2259 2260 2266 2275 2277 2281 2285 2287 2293 2295 2296 2302 2310 2312 2317 2324 2328 2330 2333 2339 2342 2344 2345 2350 2351 2355 2357 2360 2362 2363 2364 2371 2375 2376 2378 2380 2402 2405 2424 2429 2431 2433 2436 2442 2444 2446 2447 2454 2456 2459 2461 2464 2465 2466 2470 2472 2476 .5 .0 .0 .5 .5 .0 .5 .5 .0 .5 .0 .5 .5 .0 .0 .0 .0 .5 .0 .0 .5 .0 .0 .5 .5 ,5 .0 .5 .5 .5 .0 .0 .0 .5 .0 .0 .5 .0 .5 .0 .5 .0 .5 .0 .0 0 0 5 0 0 0 5 0 0 5 0 5 0 0 0 2237.5 2238.5 2239.5 2258.0 2260.0 2266.5 2275.0 2276.5 2280.0 2284.5 2287.0 2293.0 2294.5 2296.5 2301.5 2309.5 2311.5 2316.5 2323.5 2327.0 2329.5 2333.5 2339.0 2343.5 2344.5 2345.5 2350.0 2351.5 2355.0 2357.5 2359.0 2361.0 2362.5 2364.0 2370.0 2374.5 2375.0 2377.0 2380.5 2400.0 2403.5 2426.5 2429.0 2431.0 2433.0 2435.0 2441.0 2444.0 2445.0 2446.5 2453.5 2456.0 2458.0 2460.5 2465.5 2467.0 2468.0 2469.0 2473.0 2476.5 2483.5 2489.0 2491.0 2492.0 2494.5 2496.5 2498.0 2501.5 2504.5 2508.0 2509.0 2510.0 2511.0 2513.0 2515.0 2517.0 2530.0 2534.0 2538.5 2541.5 2544.5 2546.0 2547.0 2567.5 2578.5 2581.5 2583.5 2585.5 2587.0 2588.5 2594.0 2596.5 2601.5 2603.5 2617.5 2623.5 2632.5 2634.0 2659.0 2662.5 2664.5 2676.0 2699.0 2705.5 2707.5 2708.0 2714.0 2717.0 2719.5 2724.5 2726.5 2728.0 2730.0 2731.5 2735.0 2736.0 2739.0 2789.5 2793.5 2794.5 2484.0 2489.5 2490.0 2491.0 2494.5 2495.5 2497.0 2502.0 2505.0 2507.5 2508.5 2510.0 2511.0 2514.0 2514.5 2517.5 2530.5 2533.0 2537.5 2541.0 2544.0 2545.5 2546.5 2567.0 2577.0 2580.0 2583.0 2585.0 2589.0 2590.0 2597.5 2599.0 2601.0 2603.5 2616.0 2621.5 2633.0 2633.5 2660.5 2664.5 2666.5 2677.0 2700.5 2708.0 2708.5 2710.0 2715.5 2719.0 2721.0 2727.5 2728.5 2729.5 2730.0 2733.0 2736.0 2738.0 2739.5 2790.5 2794.5 2796.5 2796.5 2799.0 2801.0 2802.0 2805.0 2807.0 2815.5 2853.5 2856.5 2862.0 2865.0 2886.0 2901.5 2907.5 2927.5 2930 0 2932 5 2940 0 2948 5 2951 5 2953 5 2968 5 2969 5 2970 5 2978 0 2980 0 2985 5 2987 5 2990 5 2991 5 2993 5 3010 0 3010 5 3012.5 3032.0 3034 5 3036 5 3039 0 3042 0 3048 5 3051 5 3065.5 3067.0 3075.5 3083.5 3085.0 3086.5 3088.0 3091.5 3094.0 3121.5 3124.5 3127.0 3127.5 3129.5 3130.5 3132.0 3133.0 3137.0 3143.0 798.5 801.5 803.0 804.0 808.0 809.0 817.0 855.5 858.0 865.0 867.5 886.5 902.0 909.0 929.0 931.0 934.0 941.0 951.0 953.5 955.5 969.5 971.5 973.0 980.5 982.0 987.0 989.0 993.0 995.0 996.5 009.0 012.5 014.5 033.5 035.0 037.0 040.5 042.0 051.0 055.5 066.5 069.0 077.5 083.0 085.5 088.5 089.5 092.5 095.5 122.5 125.0 127.5 128.5 129.5 131.5 132.5 133.5 138.0 143.5 3146.0 3147.5 3150.0 3164.5 3166.0 3170.0 3171.5 3173.5 3175.0 3178.5 3211.5 3212.5 3214.5 3217.5 3219.0 3228.5 3230.5 3231 5 3232 0 3233 0 3235 5 3241 5 3245 0 3256 0 3262 0 3263 5 3267 0 3269.5 3271.5 3290.5 3291.0 3296.0 3300.0 3301.5 3313.5 3317.0 3320.0 3322.0 3325.0 3330.5 3332.0 3333.0 3334.0 3349.0 3351.5 3353.0 3354.0 3355.0 3356.5 3358.5 3359.5 3365 0 3367 5 3368 5 3371 0 3374 0 3375 0 3382.0 3385.5 3388.0 3146.0 3147.5 3152.0 3165.5 3168.0 3172.0 3173.5 3175.0 3177.0 3179.5 3211.5 3213.5 3215.5 3217.5 3220.0 3228.5 3230.5 3231.0 3231.5 3234.0 3236.0 3241.5 3245.5 3257.5 3263.0 3265.0 3269.5 3271.0 3272.0 3290.0 3292.0 3297.0 3302.0 3304.0 3315.0 3319.0 3321.5 3324.5 3327.0 3332.0 3333.0 3334.5 3336.0 3351.5 3353.5 3355.0 3356.5 3357.5 3359.5 3360.5 3362.0 3367.5 3370.0 3372.5 3374.0 3375.5 3379.0 3384.0 3387.0 3390.0 3392.5 3395.0 3397,0 3400.0 3402.0 3409.5 3412.5 3416.0 3417.0 3418.5 3422.0 3437.5 3439.5 3440.5 3445.5 3447.0 3448.5 3454.0 3455.5 3457.0 3463.5 3467.5 3471 0 3480 0 3494 0 3495 5 3497 0 3498 0 3499.0 3502.0 3504.5 3510.0 3515.0 3529.5 3535.0 3541.5 3561.5 3567.5 3575.0 3577.5 3586.5 3592.0 3595.0 3614.0 3620.0 3623.5 3634.5 3679.5 3685.0 3686.0 3708.5 3718.0 3753.5 3757.0 3764.0 3768.5 3772.5 3775.0 3778.5 3779.5 3394.0 3398.0 3400.5 3402.5 3403.0 3412.5 3414.5 3418.0 3419.5 3420.5 3424.5 3440.5 3443.0 3443.5 3448.5 3449.5 3451.0 3456.0 3458.5 3459.5 3465.5 3468.0 3472.5 3481.5 3496.0 3497.0 3498.5 3500.0 3502.0 3503.5 3506.0 3512.5 3518.5 3531.5 3537.5 3544.0 3562.5 3568.5 3577.0 3579.5 3589.5 3594.5 3597.5 3615.0 3621.0 3625.0 3635.5 3682.0 3687.5 3688.0 3711.0 3719.5 3756.5 3759.5 3766.5 3769.0 3775.0 3776.0 3781.5 3783.0 3780.5 3782.0 3786.0 3809.0 3811.0 3820.5 3822.5 3826.5 3858.5 3860.5 3877.5 3880.5 3882.0 3887.0 3891.5 3893.0 3902.5 3909.0 3917.0 3920.5 3943.0 3944.5 3945.5 3.952.5 3955.0 3968.5 3971.0 3973.5 3976.5 4004.0 4013.5 4023.0 4025.0 4037.5 4038.5 4044.5 4046.0 4057.5 4063.0 4065.5 4066.5 4115.0 4117.5 4119.0 4120 5 4122 5 4126 5 4130 0 4132 0 4135 5 4173 0 4178.0 4180.0 4182.5 4187.0 4191.5 4192.5 4194.0 4196.0 4204.0 3784.5 3785.0 3786.0 3810.0 3813.5 3822.0 3825.0 3827.0 3860.5 3862.0 3878.5 3880.5 3881.0 3886.5 3891.0 3893.0 3903.5 3908.5 3918.0 3920.5 3943.5 3945.5 3947.0 3953.5 3956.0 3970.0 3973.0 3975.5 3977.5 4006.0 4013.5 4023.0 4025.0 4039.0 4040.5 4045.0 4047.0 4058.5 4062.5 4067.5 4068.0 4116.5 4119.0 4120.5 4121.0 4122.0 4127.0 4130.5 4133.0 4137.5 4176.5 4184.5 4185.5 4187.0 4189.0 4190.5 4191.5 4193.0 4195.0 4205.5 4212.0 4214.0 4215.5 4217.5 4217.5 4220.5 4219.0 4222.0 4258.0 4262.0 4259.5 4264.5 4274.5 4274.5 4290.5 4290.5 4291.0 4291.5 4292.0 4292.5 4293.5 4293.0 4305.5 4306.0 4307.5 4308.5 4312.0 4312.5 4315.5 4316.5 4318.0 4317.0 4322.0 4323.0 4360.0 4360.0 4362.5 4362.0 4363.5 4364.0 4365.5 4365.5 4415.0 4415.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 121.0 4414.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Size Nsam Rep Code Offset' Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 121.5 4415 2268.25 ROP 10.1465 883.914 247.26 Nsam 8588 8588 First Reading 121.5 121.5 Last Reading 4415 4415 GR 11.3183 114.587 56.5448 8521 RPX 0.5816 2000 63.5536 8506 R?S 0.6011 2000 91.0731 8506 RPM 0.5984 2000 96.4773 8506 RPD 0.7158 2000 143.981 8506 FET 0.0658 3.7474 0.349041 8506 121.5 121.5 121.5 121.5 121.5 121.5 4381.5 4374 4374 4374 4374 4374 First Reading For Entire File .......... 121.5 Last Reading For Entire File ........... 4415 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE suMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 121.0 4374.0 RPD 121.0 4374.0 RPM 121.0 4374.0 R?S 121.0 4374.0 RPX 121.0 4374.0 GR 121.0 4381.5 ROP 121.0 4415.0 $ LOG HEADER DATA DATE LOGGED: 02-DEC-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 4414.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAPR~A~RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 121.0 4414.0 .0 26.2 TOOL NUMBER P089ICRG6 P0891CRG6 9.880 9.9 SPUD MUD 178.80 285.0 9.0 450 7.2 5.000 3.730 5.500 4.000 35.6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 24 28 Name Min Max Mean DEPT 121 4415 2268 GR 11.3183 114.587 56.5326 RPX 0.5816 2000 63.1274 RPS 0.6011 2000 90.8975 RPM 0.5984 2000 96.9901 RPD 0.7158 2000 144.488 ROP 10.1465 883.914 247.442 FET 0.0658 3.7474 0.349296 Nsam 8589 8522 8507 8507 8507 8507 8589 8507 First Reading 121 121 '121 121 121 121 121 121 Last Reading 4415 4381.5 4374 4374 4374 4374 4415 4374 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4415 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/12/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
