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25gca WELL LOG TRANSMITTAL #904326359 To: Alaska Oil and Gas Conservation Comm. December 18, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DATA LOGGEDk i201% M K.BENDER DEC 2 2 2012 RE: Multi Finger Caliper: 2A-22 AOGCC Run Date: 9/25/2017 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 2A-22 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20221-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20221-00 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAL44-1-0,e-/) ✓`�;��"_""C RECEIVED • • STATE OF ALASKA 2017 ALASKA OIL AND GAS CONSERVATI . N COMMISSION NOV a 6 WELL COMPLETION OR RECOMPLETION REPORT la.Well Status: Oil ' Gas❑ SPLUG❑ Other ❑ Abandoned 0 . Suspended ❑ 1b.Well . 40 20AAC 25.105 20AAC 25.110 Development 0 . Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 9/26/2017 . 195-068/317-345 . 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 5/19/1995 50-103-20221-00-00 . 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 766'FSL,227'FWL,Sec 13,T11N, R8E, UM 5/27/1995 KRU 2A-22 Top of Productive Interval: 9. Ref Elevations: KB:41 17. Field/Pool(s): 1745 FNL, 1013'FEL,Sec 16,T11 N,R8E,UM GL:94 BF: Kuparuk River Field/Kupark Oil Pool , Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1676'FNL, 1368'FEL,Sec 16,T11 N,R8E UM 14698/6082 ' ADL 25571 ., 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498621 y- 5960177 Zone- 4 14797/6144 - ALK 2669 TPI: x- 573529 y- 5970070 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 486466 y- 5963037 Zone- 4 N/A 1543/1497 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.6 H-40 41 121 41 121 24 250 sx AS 1 9 5/8 40 L-80 41 4928 41 2937 12.25 820 sx AS III Lead 890 sx Class G Tail 7 26 L-80 38 14787 38 6137 8.5 260 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3 1/2 14265 14103/5716 14727/5789 all perfs squeezed off !t60144 tCX K o 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. ---- ,-..4. 4.- .' Was hydraulic fracturing used during completion? Yes❑ No 0 c jito k Per 20 AAC 25.283(i)(2)attach electronic and printed information ` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Ii�i'dFf=t 14237-14399' 30 bbls 16.5 ppg Class G L,- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised 5/ 17 V7L `I` L51 7� CONTINUED ON PAGE 2 V [,'OV ubmit ORIGINIAL only W' 11�-- , (/f/,j RBDMS S �e - 7 2 17� • 28.CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E I Permafrost-Top Surface Surface �' If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1543 1497 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation @ TPI �► �� X83 Z Awa*w� L K\\p— L -6>asit_ t4SC2- SSl.04, k-,v - ILA 3c 2. S . Formation at total depth: ju7-4q ('I4 y 31. List of Attachments: Daily Operations Summary,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, caleontoloaical report.production or well test results.per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Kai Starck Contact Name: Mike Callahan Pu Authorized Title: CTD Team Lead Contact Email: Mike.Callahanacop.com Authorized ' - '7- Contact Phone: 907-263-4180 Signature: fkiNi Date: 1'- 3 - Z0/ INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only erations Summary (with Timelog Depths) to- 2A-22 conocoPhil lips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/23/2017 9/24/2017 8.00 MIRU MOVE MOB P Trucks to move rig on location-PJSM 0.0 0.0 16:00 00:00 with Peak. Broke drive shaft yoke pulling sub off well @ 18:30. Replacement on location @ 20:30.Off 3M with both modules @ 21:30 enroute to 2A 9/24/2017 9/24/2017 3.50 MIRU MOVE MOB P Continue travels to 2A 0.0 0.0 00:00 03:30 9/24/2017 9/24/2017 1.70 MIRU MOVE MOB P Arrive on 2A pad,de-jeep modules. 0.0 0.0 03:30 05:12 Prep cellar with herculite and plywood 9/24/2017 9/24/2017 1.00 MIRU MOVE MOB P Go to spot sub. Pad soft where gravel 0.0 0.0 05:12 06:12 added to level up.Became stuck.Sow breaks radiator hose. 1 cup spill to pad.Call for Mats-plywood to spot. Wait on Peak mechanic 9/24/2017 9/24/2017 3.30 MIRU MOVE MOB P Leave 2A with one Sow to get shop 0.0 0.0 06:12 09:30 and halfway house.Sow on 3M drive line repaired.Setting mats for spotting rig.Leave 3M with shop and halfway house.At CPF 3 trailer hauling shop looses wheel bearing. Peak mechanic to CPF3 to repair trailer.More mats on 2A.Lay out 9/24/2017 9/24/2017 1.50 MIRU MOVE MOB P Leave CPF 3 with halfway house to 0.0 0.0 09:30 11:00 2A.Arrive on 2A @10:30.Swap out sow on sub 9/24/2017 9/24/2017 2.00 MIRU MOVE MOB .P Mats all positioned.Spot sub on well 0.0 0.0 11:00 13:00 22 9/24/2017 9/24/2017 2.00 MIRU MOVE MOB P Back up pits and spot more mats. 0.0 0.0 13:00 15:00 Spot in Pits 9/24/2017 9/24/2017 2.50 MIRU MOVE RURD P Start working rig up checklist,R/U 0.0 0.0 15:00 17:30 PUTZ,lower stairs 9/24/2017 9/24/2017 4.50 MIRU WHDBOP NUND P Change out stack,grease tree, NU 0.0 0.0 17:30 22:00 BOPE **Rig accept:22:00 hrs 9/24/2017 9/25/2017 2.00 MIRU WHDBOP BOPE P Fluid pack,begin BOPE test at 22:15 0.0 0.0 22:00 00:00 hrs 9/25/2017 9/25/2017 5.00 MIRU WHDBOP BOPE P Continue BOPE test. BOPE test 0.0 0.0 00:00 05:00 completed at 5:00 hrs 9/25/2017 9/25/2017 2.10 MIRU WHDBOP PRTS P PT PDL's&TT line-test gas alarms 0.0 0.0 05:00 07:06 9/25/2017 9/25/2017 1.40 PROD1 RPEQPT PULD P PJSM, M/U BHA#1 to mill cement 0.0 68.5 07:06 08:30 pilot hole,Check pack offs, Install checks in UQC, Make up to coil and surface test 9/25/2017 9/25/2017 2.80 PROD1 RPEQPT TRIP P RIH,Surface test agitator @ 700'- 68.5 14,130.0 08:30 11:18 good 9/25/2017 9/25/2017 0.30 PROD1 RPEQPT DLOG P Log K1 for+7 foot correction, 14,130.0 14,155.0 11:18 11:36 PUW=39K 9/25/2017 9/25/2017 0.30 PROD1 RPEQPT TRIP P Continue in well,Encountered cement 14,155.0 14,217.0 11:36 11:54 stringer @ 14205.Set down, PUH kicked on pump didn't see anything. Continue in to dry tag TOC @ 14217 Page 1/21 Report Printed: 10/17/2017 111 !erations Summary (with Timelog !pths) el i 2A-22 ConocoPhil lips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/25/2017 9/25/2017 4.30 PROD1 RPEQPT MILL P 14217 Tag cement, PUH Pumps on @ 14,217.0 14,340.0 11:54 16:12 1.79 BPM @ 3515 PSI FS, BHP=3335,RIW=8.6K @ 1.1K DHWOB.Cement ROP down to 25-30 ROP @ 14225 and down to TD 9/25/2017 9/25/2017 0.70 PROD1 RPEQPT WPRT P Wiper up hole,PUW=40K, Back ream 14,340.0 14,260.0 16:12 16:54 14285 to 14260 9/25/2017 9/25/2017 2.00 PROD1 RPEQPT REAM P Make reaming passes per procedure 14,260.0 14,290.0 16:54 18:54 160L,LS,20R, LS.Dry drift transition area good 9/25/2017 9/25/2017 0.20 PROD1 RPEQPT OWFF P Shut down and monitor well for 14,229.0 14,229.0 18:54 19:06 pressure build up-No flow 9/25/2017 9/25/2017 2.30 PROD1 RPEQPT TRIP P Trip out,EDC open 14,229.0 80.0 19:06 21:24 9/25/2017 9/25/2017 0.60 PROD1 RPEQPT PULD P At surface, Flow check well,PJSM, 80.0 0.0 21:24 22:00 Lay down BHA#1 on dead well, Mill out @ 2.80 NoGo 9/25/2017 9/25/2017 0.70 PROD1 RPEQPT CTOP P Stab on well with nozzle.Jet stack to 0.0 0.0 22:00 22:42 remove cement debrie. Unstab inject and rack back 9/25/2017 9/25/2017 0.60 PROD1 RPEQPT PULD P PJSM,M/U BHA#2 HES caliper, 0.0 23.1 22:42 23:18 Surface test,cycle fingers.Tag up and set counters 9/25/2017 9/26/2017 0.70 PROD1 RPEQPT TRIP P Trip in with caliper 23.1 3,000.0 23:18 00:00 9/26/2017 9/26/2017 1.80 PROD1 RPEQPT TRIP P Continue RIW with BHA#2(caliper), 3,000.0 14,050.0 00:00 01:48 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P tie in for+4.1'correction 14,050.0 14,231.8 01:48 02:00 9/26/2017 9/26/2017 0.10 PROD1 RPEQPT TRIP P Continue RIH 14,231.8 14,330.0 02:00 02:06 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Caliper log run#1,PUW=42K,50 14,330.0 14,000.0 02:06 02:18 fpm 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT TRIP P Close caliper arms,RBIH 14,000.0 14,330.0 02:18 02:30 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Open caliper arms,caliper log run#2, 14,330.0 14,000.0 02:30 02:42 50 fpm 9/26/2017 9/26/2017 2.20 PROD1 RPEQPT TRIP P POOH,tag up,flow check well 14,000.0 20.0 02:42 04:54 9/26/2017 9/26/2017 0.50 PROD1 RPEQPT PULD P PJSM, LD BHA#2 20.0 0.0 04:54 05:24 9/26/2017 9/26/2017 0.70 PROD1 RPEQPT PULD P PJSM, PU BHA#3 WS Setting 0.0 73.0 05:24 06:06 Assembly,tag up,open EDC 9/26/2017 9/26/2017 2.80 PROD1 RPEQPT TRIP P RIH with BHA#3 73.0 14,136.0 06:06 08:54 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT DLOG P Log K1 for+3'correction 14,136.0 14,162.0 08:54 09:06 9/26/2017 9/26/2017 0.20 PROD1 RPEQPT TRIP P Continue RIH,weight check=43K, 14,162.0 14,317.8 09:06 09:18 arrive at setting depth,close EDC, bring up pumps,release off WS,set down 4.3K WOB,leaving TOWS= 14,307',oriented 10°ROHS 9/26/2017 9/26/2017 2.50 PROD1 RPEQPT TRIP P POOH,PUW=44K,check well for 14,317.8 73.0 09:18 11:48 flow,PJSM for LD&PU,tag up 9/26/2017 9/26/2017 0.50 PROD1 RPEQPT PULD P LD BHA#3 over a dead well 73.0 0.0 11:48 12:18 Page 2/21 Report Printed: 10/17/2017 0 `' Operations Summary (with Timelog Depths) ►.t4 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/26/2017 9/26/2017 0.60 PROD1 WHPST PULD P Reconfigure&PU BHA#4,Window 0.0 74.0 12:18 12:54 Milling Assembly(10'pup,0.6°AKO motor,string reamer,window mill), slide in cart,MU to coil 9/26/2017 9/26/2017 2.50 PROD1 WHPST TRIP P RIH with BHA#4,begin swapping to 74.0 14,135.0 12:54 15:24 used Power Pro 9/26/2017 9/26/2017 0.20 PROD1 WHPST DLOG P Tie into K1 for a+4'correction 14,135.0 14,170.0 15:24 15:36 9/26/2017 9/26/2017 0.40 PROD1 WHPST TRIP P Continue RIH,weight check=44K, 14,170.0 14,307.0 15:36 16:00 dry tag TOWS right on depth at 14,307', PUW=44K,bring up pump, RBIH 9/26/2017 9/26/2017 2.00 PROD1 WHPST WPST P Begin milling wiindow in 7"casing as 14,307.0 14,308.8 16:00 18:00 per procedure(tagged TOWS at 14,306.08'pumping 1.8 bpm),FS= 431 psi,CWT=6.6K, 9/26/2017 9/26/2017 4.00 PROD1 WHPST WPST P 1.77 bpm,CT 4196 psi,CT Wt 3.66 k 14,308.8 14,327.0 18:00 22:00 lbs,WOB 1.33 k lbs. Saw mill off @ 14,311.6'-BOW. Bottoms up sample from 14,325'formation sand+ glauconite per Geo. CT 3.9 k lbs, WOB 2.7 k lbs,ROP 10 ft/hr 9/26/2017 9/26/2017 1.00 PROD1 WHPST REAM P Perform back reamin/dressing passes, 14,308.8 14,327.0 22:00 23:00 14300-14,315',as drilled, 10°ROHS, 40°ROHS,&340°ROHS. Little motor work-15-20 psi over free spin. Send 5x5 sweeps.Dry drift clean,PU 30k lbs 9/26/2017 9/26/2017 0.50 PROD1 WHPST OWFF P SBHP/ flow check,park @ 14191' - 14,327.0 14,191.0 23:00 23:30 5741'TVD. IA pressured up from tubing hole at 9426'. Bleed IA to 143 psi observe it slowly build to 173 psi while monitoring. Baker Coil track BHP stabilized at 2506 psi for 8.39 ppg EMW. Flow check at stack- Good. Mud weight in and out tested w pressurized mud balance 8.8 heavy ppg. 9/26/2017 9/26/2017 0.30 PROD1 WHPST CIRC P Establish circulation rate of 1.80 bpm 14,191.0 14,175.0 23:30 23:48 while slowly PUH. CT 4192 psi, Annular 3778 psi, Bore 4198 psi, Expro WH 140,(upstream of micro motion),CTES transducer#6, 17 psi, (downstream of the micro motion). Note,micro motion making more noise than usual and we suspect has impeded flow from some sort of blockage. 9/26/2017 9/27/2017 0.20 PROD1 WHPST TRIP P Park,Open EDC,rate to 2.0 bpm, 14,175.0 13,260.0 23:48 00:00 POOH chasing sweep to surface. 9/27/2017 9/27/2017 2.10 PROD1 WHPST TRIP P Continue to POOH,@-700'out MM 13,260.0 100.0 00:00 02:06 rate and density reading became erattic. Monitored returns,rate and density at the shaker,8.8 ppg heavy, all looks good. Contiune out of hole. 9/27/2017 9/27/2017 1.00 PROD1 WHPST PULD P PJSM,Bleed IA from 589 psi to 209 100.0 0.0 02:06 03:06 psi in 3 min,built back to 390 once S/I. Flow Check-Good,LD BHA#4,Bit 2.79 no go,Mill 2.78 no go,decent whorl pattern in center of window mill. Page 3/21 Report Printed: 10/17/2017 .: s • ._r Operations Summary (with Timelog Depths) 0 2A-22 Conoc©Phiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/27/2017 9/27/2017 1.20 PROD1 DRILL CIRC P Jet Stack,snake and flush out MM, 0.0 0.0 03:06 04:18 retrieved 3 quarter sized pieces of flattened aluminum(billet)from the MM.Blew down choke. Changed out upper Quick connect 9/27/2017 9/27/2017 0.90 PROD1 DRILL PULD P PU BHA#5(agitator,2.3°+AKO 0.0 78.0 04:18 05:12 motor,&RR Hughes bit) 9/27/2017 9/27/2017 2.80 PROD1 DRILL TRIP P RIH,surface test agitator,good 78.0 14,135.0 05:12 08:00 9/27/2017 9/27/2017 0.20 PROD1 DRILL DLOG P Tie into K1 for+3'correction,close 14,135.0 14,163.0 08:00 08:12 EDC,weight check=38K 9/27/2017 9/27/2017 0.30 PROD1 DRILL TRIP P Continue RIH,pumps off-clean 14,163.0 14,327.0 08:12 08:30 through window,RIW=9.2K off bottom,PUH to adjust TF per DD, RBIH 9/27/2017 9/27/2017 0.30 PROD1 DRILL DRLG P OBD,pumping 1.8 bpm,FS=850 psi, 14,327.0 14,351.0 08:30 08:48 CWT=7K,WOB= 1.6K,circ pressure =4753 psi,annular=3754 psi,WHP =0 psi, dp=1151 psi. WOB up to-4.5 K, PU at 14,345', PUW=38K,RBIH&continue drilling, again at 14,352,rate out dropped to 1 bpm 9/27/2017 9/27/2017 0.50 PROD1 DRILL DRLG P BOBD,pumping 1.8 bpm,rate out= 14,351.0 14,367.0 08:48 09:18 1.09 bpm,FS=762 psi, PU at 14,355',PUW=40K,pulling negative WOB up to-4K(possibly hanging up in window), PU at 14,362',PUW=38 K, 9/27/2017 9/27/2017 0.70 PROD1 DRILL DRLG P Go to near total losses at 14,357'(.25 14,367.0 14,390.0 09:18 10:00 bpm returns),returns begin to heal with drilling,improving to.98 bpm returns by 14,387',pump 5 x5 sweeps at 14,387',continue to pull heavy on PU's(negative WOB up to-6K),call EOB at 14,390',returns at-59% 9/27/2017 9/27/2017 0.20 PROD1 DRILL TRIP P Begin POOH,PUW=42K 14,390.0 14,135.0 10:00 10:12 9/27/2017 9/27/2017 0.50 PROD1 DRILL DLOG P RIH to tie into K1 for+0.5'correction, 14,135.0 14,135.0 10:12 10:42 log RA at 14,315',(putting TOW at 14,308'&BOW at 14,314'),continue POOH,close EDC above TOC. 9/27/2017 9/27/2017 2.40 PROD1 DRILL TRIP P Continue POOH,holding 11.4 ppg 14,135.0 78.0 10:42 13:06 schedule,tagged up,space out,WHP at 790 psi 9/27/2017 9/27/2017 1.40 PROD1 DRILL PULD P PJSM for PD&PUD,PUD BHA#5,bit 78.0 0.0 13:06 14:30 came out a 1-1,pumping manage pressure losing-12 bph,observe marks on motor,possibly from window 9/27/2017 9/27/2017 1.10 PROD1 DRILL PULD P Reconfigure&PD BHA#6 Lateral 0.0 78.0 14:30 15:36 Drilling Assembly(agitator,0.5°AKO motor,RR 0-0 HYC B8 Edge),slide in coil,MU to coil 9/27/2017 9/27/2017 2.50 PROD1 DRILL TRIP P RIH with BHA#6,close EDC,surface 78.0 14,141.0 15:36 18:06 test agitator,good 9/27/2017 9/27/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 marker for a+2.5' 14,141.0 14,169.0 18:06 18:18 correction Page 4/21 Report Printed: 10/17/2017 • •rations Summary (with Timelog Depths) 10::11110 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/27/2017 9/27/2017 0.30 PROD1 DRILL TRIP P Wt check,33k lbs,continue to RIH 14,169.0 14,390.0 18:18 18:36 9/27/2017 9/27/2017 1.10 PROD1 DRILL DRLG P Rate 1.80 in, 1.10 out,CT 4600 psi, 14,390.0 14,534.0 18:36 19:42 free spin diff 1040 psi,Annular 3622 psi w choke wide open. CT RIH Wt 8.7 k lbs. OBD,CT wt,6 k lbs,WOB 2.5 k lbs, ROP 160 ft/hr-0.63 bpm losses-38 bbl/hr Losses quickly healed in 15 min of drilling from 40%stabilizing @ 27%- 30 bbl/hr Average ROP over interval drilled- 131 ft/hr average 9/27/2017 9/27/2017 1.80 PROD1 DRILL DRLG P PU @ 14,534'for missed survey,33k 14,534.0 14,777.0 19:42 21:30 lbs,zero WOB,RBIH,BOBD stall @ 14553,PU Wt 37k,returns fell from 1.3 to.7 bpm, second stall 14,556,PU 38 k lbs 1.77 in 1.12 out,CT Wt 3.66 k lbs, WOB 2.7 k lbs,ROP 160 ft/hr IA 1016,OA 280 psi. Mud weight out started falling off@ 14,613'-20:27-not cleaning the hole... 14,731',stacked weigh,ROP dropped, losses increased to-1 bpm, Average ROP over interval drilled- 135 fUhr average 9/27/2017 9/27/2017 0.90 PROD1 DRILL DRLG P PU to rotate HOT,BHA wiper 100',PU 14,777.0 14,855.0 21:30 22:24 Wt 38 k. RBIH 1.80 bpm in,0.78 k bpm out,CT 4600 psi,RIH Wt 6 k lbs,free spin 1140 psi OBD,CT Wt 4 k,WOB 2.5 k lbs,ROP 60-160 ft/hr 14,811', 1.80 bpmin,0.48 bpm out Average ROP over interval drilled-87 ft/hr average 9/27/2017 9/27/2017 0.20 PROD1 DRILL WPRT P Wiper to window-500',PU 40 k lbs 14,855.0 14,365.0 22:24 22:36 send 25 bbl ultra hi vis pill—150k LSRV Losses healed slightly,then dropped again as we drug past 14,457' 9/27/2017 9/27/2017 0.20 PROD1 DRILL WPRT P RBIH RIH Wt 7 k lbs 14,365.0 14,855.0 22:36 22:48 Page 5/21 Report Printed: 10/17/2017 • 0� oOperations Summary (with ith TimelogDepths) ) 2A-22 ConocPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/27/2017 9/27/2017 1.00 PROD1 DRILL DRLG P 1.78 bpm in,0.66 bpm out,CT 4967 14,855.0 15,014.0 22:48 23:48 psi,free spin 1033 psi,6 k lbs RIH Wt OBD,CT wt 4k lbs,WOB 2 k lbs,ROP 150 ft/hr Stall @ 14,890+/-6 bbls high vis out the bit,PU Wt 40 k Rate out dropped from 0.7 bpm to 0.40 bpm as Hi vis was on the back side. Drilling break,up to 380 fUhr,PU to roll hot,PU Wt 41 k,RBIH RIHWt 5 k lbs, 1.8 in 0.40 out,diff 1164 psi OBD,—380 ft/hr,friction pressure from high vis pill on back side exacerbating losses. Pill moving @ 60 ft/min with current returns Average ROP over interval drilled- 160 fUhr average 9/27/2017 9/28/2017 0.20 PROD1 DRILL WPRT P PU Wt 38 k lbs 15,014.0 14,462.0 23:48 00:00 CT weight slowly increased from—36 k to 39 k near the bottom of the window RBIH to jog solids 9/28/2017 9/28/2017 1.20 PROD1 DRILL WPRT P Continue to PUH,order power pro 14,462.0 9,979.0 00:00 01:12 light system(s)in preperation for closed choke drilling. 9/28/2017 9/28/2017 1.10 PROD1 DRILL DISP P Park,down on the pumps,finish 9,979.0 8,179.0 01:12 02:18 preping high vis pill,line up down the back side with power pro,establishing injection, 1 bpm @ 1400 psi WH. Pump 10 x 10 low/hi vis pill down the back side. 9/28/2017 9/28/2017 1.00 PROD1 DRILL TRIP P RBIH, 100 ft/min, lined up down the 8,179.0 14,140.0 02:18 03:18 coil @ 0.6 bpm,pushing sweeps in front,pipe displacement.5 bpm. CT 2198 psi,WH 221 psi 9/28/2017 9/28/2017 0.20 PROD1 DRILL TRIP P Tie into K1 for+6'correction 14,140.0 14,156.0 03:18 03:30 9/28/2017 9/28/2017 0.30 PROD1 DRILL TRIP P Continue to RIH,window clean, WOB 14,156.0 15,014.0 03:30 03:48 spike as well as Ct weigh stack out in the build @ 14,386'. 9/28/2017 9/28/2017 1.10 PROD1 DRILL DRLG P 1.65 bpm,CT 4347 psi,WH 473 psi, 15,014.0 15,165.0 03:48 04:54 annular 3714 psi.off bottom diff 1124 psi CT Wt 4.2 k lbs,WOB 2.1 k lbs,ROP 200 ft/hr PU,35 k lbs, increase rate to 1.80 bpm,Ct 4800 psi,diff 1150 psi, annular 3799 psi BOBD CT Wt 5 k lbs,WOB 1.08 k lbs, ROP 150 ft/hr Stall 15,093',PU 39 k lbs,spuded and restarted,new diff 1,337 psi,plugged nozzle? Average ROP over interval drilled- 137 ft/hr average 9/28/2017 9/28/2017 0.10 PROD1 DRILL WPRT P PU 38 k lbs-DD wiper-30' 15,165.0 15,165.0 04:54 05:00 Page 6/21 Report Printed: 10/17/2017 !erations Summary (with Timelog Depths) 0; 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2017 9/28/2017 1.80 PROD1 DRILL DRLG P 1.83 bpm,CT 5007 psi, 1,380 psi diff 15,165.0 15,310.0 05:00 06:48 RIH Wt 6k lbs,WH 836 psi,annular 3775 psi OBD,CT Wt Ok lbs,WOB 2.5 k lbs, ROP 180 ft/hr stall @ 15,195',annular fell off from 3,850 to 3,350 psi at-15,185' 9/28/2017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper up-hole,PUW=40K 15,310.0 14,333.0 06:48 07:12 9/28/2017 9/28/2017 1.30 PROD1 DRILL WPRT P Wiper in-hole,,tied in fora+3' 14,333.0 15,310.0 07:12 08:30 correction,difficulty RIH past 14,375'- 14,380'in the build,PU&attempt various TF's,get by stacking-8K WOB,back ream up through trouble area up to 14,350',RBIH and slide right by 14,375' Stack weight at 14,409',PUW=38K, attempt multiple TF's,no success, attempt with pumps off,no success, creep in with pumps at 1.4 bpm and get by(likely fill) Stack weight at 15,125',PUW=42K, vary TF,no success,creep in at 10 fpm&get by,back-ream up to 15,116' through trouble spot 9/28/2017 9/28/2017 3.60 PROD1 DRILL DRLG P BOBD,FS=1230 psi at 1.8 bpm, 15,310.0 15,610.0 08:30 12:06 CWT=8K,WOB=1.7K,annular= 3440 psi,WHP=346 psi,circ pressure=4793 psi,began pumping PowerPro lite at 15,385',ROP over interval=-83 fph 9/28/2017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper up-hole,PUW=41K 15,610.0 14,609.0 12:06 12:30 9/28/2017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper in-hole,RIW=6.5K 14,609.0 15,610.0 12:30 12:54 9/28/2017 9/28/2017 3.20 PROD1 DRILL DRLG P BOBD,FS=1250 psi pumping 1.8 15,610.0 15,910.0 12:54 16:06 bpm,CWT=5K,WOB=2K,annular =3692 psi,circ pressure=5245 psi, average ROP over interval=94 fph Note:CWT,among other values,was not receiving data in WellLiink from 13:00 hrs-13:53 hrs(MWD resolved issue) 9/28/2017 9/28/2017 0.40 PROD1 DRILL WPRT P Wiper up-hole, PUW=41K 15,910.0 14,895.0 16:06 16:30 9/28/2017 9/28/2017 0.50 PROD1 DRILL WPRT P wiper in-hole,send 5x5,stack weight 14,895.0 15,910.0 16:30 17:00 at 15,816',bring up rate,RBIH& creep through,RIW=5.2K Page 7/21 Report Printed: 10/17/2017 OS Operations Summary (with Timelog Depths) 2A-22 ConocoPhitlips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/28/2017 9/28/2017 4.80 PROD1 DRILL DRLG P BOBD,FS= 1194 psi pumping 1.77 15,910.0 16,087.0 17:00 21:48 bpm,CWT=2K,WOB=2.2 k lbs Pumped 10x10 sweep,exited @ 16,038 bit depth,snub limit set to-3 k CT wt,WOB in creased from 1 k to 2.8k plus,lubes/solids movement is helping weight transfer. Top off pill 1 with new mud 1%lubes to be used for sweeps. PU Wt 41 k lbs BHA wiper struggle to get restarted 4 times. Average ROP over interval drilled-37 ft/hr average 9/28/2017 9/28/2017 0.60 PROD1 DRILL WPRT P PU Wt 41 k lbs,pull 3rd long wiper to 16,087.0 14,145.0 21:48 22:24 window for tie in.-1,757'drug low side on the way out. 9/28/2017 9/28/2017 0.20 PROD1 DRILL DLOG P Tie into K1 tag for+9'correction, 14,145.0 14,206.0 22:24 22:36 bypass high pressure screens 9/28/2017 9/28/2017 0.80 PROD1 DRILL DISP P Line up down the back side,bullhead 14,206.0 14,198.0 22:36 23:24 45 bbls new mud W 2 ppb Alpine drill beads down the backside @ 1.6 bpm bpm,WH 758 psi initial, WH 1940 psi final Pre IA 1333 psi,OA 305 psi,Post la 1706 psi,OA 305 psi PU Wt 39 k lbs 9/28/2017 9/29/2017 0.60 PROD1 DRILL TRIP P RIH,Window clean,small WOB spike 14,198.0 15,625.0 23:24 00:00 at 14,386'near the end of the build,no CT Wt change.small WOB spike 14,915 9/29/2017 9/29/2017 0.20 PROD1 DRILL TRIP P Continue to RIH 15,625.0 16,087.0 00:00 00:12 9/29/2017 9/29/2017 3.70 PROD1 DRILL DRLG P RIHWt 6.8 k lbs, 1.80 bpm,CT 5171 16,087.0 16,332.0 00:12 03:54 psi,Wh 464 psi,annular 3732 psi,diff 1143 psi OBD,WOB 2.5 k lbs,CT Wt-3 k lbs, ROP 54 ft/hr 16,178'PU Wt 38 k lbs,Pumping 10 bbls sweeps of new mud. Struggling to get restarted Average ROP over interval drilled-66 fUhr average 9/29/2017 9/29/2017 0.60 PROD1 DRILL WPRT P Wiper trip#1 -PU Wt 38 k lbs-1812' 16,332.0 14,520.0 03:54 04:30 9/29/2017 9/29/2017 1.40 PROD1 DRILL WPRT P RBIH,spudded in @ 15,144',TF 14,520.0 16,332.0 04:30 05:54 orientation issue,continue in hole. Started stacking out CWT at 16,088'(though not showing in WOB). difficulty working to bottom attempting various pump rates,tagged bottom-9' higher than expected,plan to inspect injector counter Page 8/21 Report Printed: 10/17/2017 • • • 0::, Operations Summary (with Timelog Depths) M,/ 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/29/2017 9/29/2017 3.20 PROD1 DRILL DRLG P BOBD,FS=1,250 psi pumping 1.7 16,332.0 16,419.0 05:54 09:06 bpm,CWT=-6K,WOB=1.8K, annular=3834 psi,circ pressure 5,065 psi,WHP=778 psi PU from 16,360',difficulty RBIH past 16,344',stacking CWT to-8K on multiple attempts,no WOB indication, PUH slow waiting for beaded pill to exit bit,slide right by with beads Stall at 16,419,stack 8K WOB,PUW= 45K 9/29/2017 9/29/2017 3.90 PROD1 DRILL DRLG P Stall a second time attempting to get 16,419.0 16,580.0 09:06 13:00 started 16,419',PUW=42K,annular dropped by-500 psi&CWT increased from-5K to+10K after stalls at 16,419' Drilling ahead pumping 1.8 bpm,CWT =8K,WOB=2K,annular=3,432 psi, circ pressure=4,796psi 9/29/2017 9/29/2017 1.40 PROD1 DRILL DRLG P Continue drilling ahead at 16,580', 16,580.0 16,631.0 13:00 14:24 CWT=4K,WOB=2.6K,annular= 3511 psi,circ pressure=4966 psi, WHP=539 psi 9/29/2017 9/29/2017 1.00 PROD1 DRILL WPRT P Wiper up-hole,PUW=38K 16,631.0 14,314.0 14:24 15:24 9/29/2017 9/29/2017 1.10 PROD1 DRILL WPRT P Wiper in-hole,clean off injector 14,314.0 16,646.0 15:24 16:30 counter,tie into RA tag for+15.5' correction,RIW diminished beginning at 16,545' 9/29/2017 9/29/2017 2.00 PROD1 DRILL DRLG P BOBD,FS=1284 psi pumping 1.8 16,646.0 16,722.0 16:30 18:30 bpm,CWT=-5K,WOB=2.5K, annular=3543 psi,circ pressure= 5118 psi,WHP=361 psi,lost-10 CWT from immediately before WT. Immediately send 5x5 sweeps(5bbl DuoVis w/1%776,5 bbl DuoVis w/beads) Drilled w neutral to slightly neg surface weight w/-2.4 k lbs WOB. CT wt slowly climbed to-5-7k lbs as the effects of the pill wore off. Proactively pumped another 5x5 with @ 200 bbls out the bit from the first pill Average ROP over interval drilled-38 ft/hr average Page 9/21 Report Printed: 10/17/2017 • • Operations Summary (with Timelog Depths) 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/29/2017 9/29/2017 3.70 PROD1 DRILL DRLG P CT Wt-4.5 k lbs,WOB 2.0 k lbs, 16,722.0 16,806.0 18:30 22:12 Annular 3571 psi,WH 477 psi, IA 1128,OA 306 psi PU as sweeps exit the bit, PU Wt 41 k lbs,steady 37 to 39 k Wt while moving. WH climbed to 1020 psi, RBIH 1.80 bpm, RH Wt 5 k lbs,CT 4966 psi,FS 1352 psi, OBD,CT Wt 2 k lbs,WOB 2.2 k lbs, ROP 38 ft/hr CT Wt fell to-8 k lbs,WOB falling off to 1.6 k lbs,little motor work Send 10x10 sweeps to time our for wiper Average ROP over interval drilled- 22.7 fUhr average 9/29/2017 9/29/2017 0.30 PROD1 DRILL DRLG P PU Wt 42 k lbs, 1000'wiper 16,806.0 15,809.0 22:12 22:30 Motor work at 16,447', 16,234', 16,124',and 16,044' 9/29/2017 9/29/2017 0.40 PROD1 DRILL DRLG P RBIH as sweeps exit the bit 15,809.0 16,806.0 22:30 22:54 9/29/2017 9/30/2017 1.10 PROD1 DRILL DRLG P RIH Wt 5.8 k lbs,Annular 3600 psi, 16,806.0 16,834.0 22:54 00:00 WH 400 psi,IA 1066,OA 306 psi 1.5 bpm,CT 4105 psi,FS 912 psi OBD,CT Wt 2 k lbs,WOB 2.4 k lbs, ROP 35 ft/hr Ct Wt diminished to-4.9 k lbs, pumped 5x5 WH to 505 psi Average ROP over interval drilled-25 ft/hr average 9/30/2017 9/30/2017 1.40 PROD1 DRILL DRLG P OBD,CT Wt-4 k lbs,WOB 2 k lbs, 16,834.0 16,865.0 00:00 01:24 ROP 24 fUhr Average ROP over interval drilled-22 ft/hr average 9/30/2017 9/30/2017 1.20 PROD1 DRILL DRLG P PU 48 k lbs,started out as a BHA 16,865.0 14,320.0 01:24 02:36 wiper,attempt to turn around 16,669' failed. Snubbing,PUH at 16,840',PU 46 k lbs.while 2 ppb bead/1% lube/2%LVT pill is completed. Pull heavy Ct Wt from 36 k to 46 k lbs starting at 15,811' POOH for tie in wiper. lots of motor work started at 15,243'fell off at 14,961'. 9/30/2017 9/30/2017 0.20 PROD1 DRILL DLOG P Tie into RA tag for+11'correction 14,320.0 14,349.0 02:36 02:48 9/30/2017 9/30/2017 1.80 PROD1 DRILL WPRT P RBIH,Stack out coil weight briefly at 14,349.0 16,865.0 02:48 04:36 15,903',more significantly @ 16,460' atemept to work coil to bottom, snubbing. Send 5x5 pills,chase to bit while we slowly PUH,PU Wt 36 k lbs. 9/30/2017 9/30/2017 0.60 PROD1 DRILL DRLG P Three false starts,S/D WOB to 2.5 k, 16,865.0 16,865.0 04:36 05:12 @ 16,852,PU 43 k lbs,again at 16,844',PU 38 k lbs,and again at 16,833 PU 45 k lbs. RIH at min rate and dial up the pump as we saw WOB. BOBD, 1.78 bpm,WH 714 psi, CT Wt-2 k k lbs,WOB 2 k lbs,ROP 24 fUhr Page 10/21 Report Printed: 10/17/2017 • Operations Summary (with Timelog Depths) 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/30/2017 9/30/2017 1.20 PROD1 DRILL WPRT P PU 44k lbs,PUH, annular pressuring 16,865.0 14,175.0 05:12 06:24 up, 13.8 ppg ECD at the window. Confer with town.Plan forward is to pull above TOC,open choke&try to establish returns. 9/30/2017 9/30/2017 1.30 PROD1 DRILL CRC P PUH slowly from 14,175',open choke, 14,175.0 14,120.0 06:24 07:42 pumping 1.8 bpm,rate out stablized at 1.08 bpm,-60%returns,circulate bottoms up,annular at 3459 psi,begin pumping 5x5 sweeps 9/30/2017 9/30/2017 0.10 PROD1 DRILL DLOG P Begin RBIH,tie-in for+4'correction 14,120.0 14,163.0 07:42 07:48 9/30/2017 9/30/2017 1.60 PROD1 DRILL WPRT P Continue RIH,attempting to hold 14,163.0 16,885.0 07:48 09:24 between 11.4 ppg-12.2 ppg,unable to maintain returns and pressure schedule,close choke&continue to RIH Work to pass 16,792',stack 3.5K WOB at 16,854',PUW of 59K from 16,823'with-6K WOB 9/30/2017 9/30/2017 1.50 PROD1 DRILL DRLG P OBD,CWT=-7.7K,WOB=1.9K, 16,885.0 16,919.0 09:24 10:54 annular=3740 psi,WHP=717 psi, circ pressure=5039 psi Began sending 5x5 sweep at 16,907', annular to 3800 psi,ROP avg=23 fph 9/30/2017 9/30/2017 2.10 PROD1 DRILL DRLG P PU from 16,919',PUW=47K,OBD, 16,919.0 16,980.0 10:54 13:00 FS=1400 psi pumping 1.8 bpm,CWT =-6K,WOB= 1.7K,annular=3790 psi,WHP=832 psi,ROP avg=29 fph 9/30/2017 9/30/2017 3.60 PROD1 DRILL DRLG P PU from 16,980',PUW=48K,FS= 16,980.0 17,053.0 13:00 16:36 900 psi pumping 1.5 bpm,OBD,CWT =-7.7K,WOB=1.2K,annular=3786 psi,WHP=844 psi,pumping sweeps as required,bring rate back up to 1.8 bpm PUW=46K from 17,022', 10 bbl beaded pill coming around,drilling at 17,025 wtih-9.4K CWT,WOB=1.4K, PUW=47K from 17,053',RO avg= 20.3 fph 9/30/2017 9/30/2017 2.80 PROD1 DRILL DRLG P OBD,CWT=-10K,WOB=1K, 17,053.0 17,086.0 16:36 19:24 annular=3861 psi,WHP 899 psi, pumping pillls as required,gained-5K CWT with beads coming around. 9/30/2017 9/30/2017 0.30 PROD1 DRILL WPRT P PU Wt 44k lbs,planned 500'wiper. 17,086.0 16,380.0 19:24 19:42 Faierly clean,one spike to 55k. Pumped pill timed out for turnaround. 9/30/2017 9/30/2017 3.10 PROD1 DRILL WPRT P RBIH,RIH Wt-3k lbs,WH 62 psi, 17,086.0 17,090.0 19:42 22:48 Annular 3804 psi RIH wt fell of to as low as-10 k lbs,as we ran out of seeep,pump more. WOB spikes 16,778 and 16,788, cleaned up around 16,828 and deeper 9/30/2017 10/1/2017 1.20 PROD1 DRILL WPRT P OBD,CT Wt-10 to 0,WOB 2-3.5 k 17,086.0 17,090.0 22:48 00:00 lbs,low differential pressure.ROP-5 Page 11/21 Report Printed: 10/17/2017 .: •01 0 Operations Summary (with Timelog Depths) 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2017 10/1/2017 0.60 PROD1 DRILL DRLG P OBD,CT Wt-10 to 0,WOB 2-3.5 k 17,090.0 17,090.0 00:00 00:36 lbs,low differential pressure. ROP-5 Start pumping 90 bbl beaded sweep to bit, Paint white TD flag at horses head 10/1/2017 10/1/2017 1.10 PROD1 DRILL WPRT P PU Wt 48 k lbs,Pulled 60 k(20 over0 17,090.0 14,140.0 00:36 01:42 @ 16,910 and 16,292'up to-1 k WOB. 10/1/2017 10/1/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 for+9'correction 14,140.0 14,168.0 01:42 01:54 10/1/2017 10/1/2017 0.90 PROD1 DRILL CTOP P Bleed IA from 1466 psi,to 950 psi, 14,168.0 14,168.0 01:54 02:48 S/D pumps,observe pressure while parked w sensor at 5725'TVD. Coil track pressure fell from 3496 to 3446 psi in 36 min 11.57 ppg EMW 10/1/2017 10/1/2017 1.50 PROD1 DRILL CTOP P Online w pumps,creep up hole while 14,168.0 13,957.0 02:48 04:18 slowly working choke open. Establish returns, 1.2 bpm in 0.86 bpm out. Build weighted liner running pill and KW while circulating bottoms up in the cased hole. Load coil with 47 bbl beaded pill to aid RIH,TD conformation 10/1/2017 10/1/2017 1.40 PROD1 DRILL TRIP P RIH to confirm TD,enter open hole as 13,957.0 17,092.0 04:18 05:42 pill started exiting the bit,confirm TD at 17,092' 10/1/2017 10/1/2017 4.20 PROD1 DRILL DISP P POOH laying 11.9 ppg liner running 17,902.0 78.0 05:42 09:54 pill at KWF to surface,painted EOP flags at 16,038'&13,178',not getting KWF out on surface,at 175'form surface,rate out began to drop at -4500', well is taking-1.25 bpm in and 0 bpm out,unable to fill hole 10/1/2017 10/1/2017 2.10 PROD1 DRILL WAIT T Confer with town,well is taking 1.25 78.0 78.0 09:54 12:00 bpm with no 11.9 ppg fluid back to surface,decision made to bull-head 8.5 ppg DuoVis to window,if well is dead,carry on,if there is flow at surface,RBIH and obtain SBHP. Shut pumps down with 15 bbl bull- headed(1725'MD, 1679'TVD),choke closed,hole stablized,confer with town,decison made to RIH to 2000' and circulate 11.2 ppg KWF, displacing 15 bbl of 8.5 ppg DuoVis to surface. BHP=23 psi WHP+.052(8.5 ppg) (1679')+.052(11.9 ppg)(5838'-1679') =3339 psi,or 11.0 ppg EMW 10/1/2017 10/1/2017 1.70 PROD1 DRILL DISP P RIH,water down KWF,&circulate in 78.0 2,500.0 12:00 13:42 11.2+KWF from 2500',includes rolling coil to 11.2 ppg at 1.25 bpm, MW out climbs 10/1/2017 10/1/2017 0.80 PROD1 DRILL DISP P Begin POOH pumping 11.2 ppg KWF 2,500.0 78.0 13:42 14:30 to surface, MW out climbs to 11.9 ppg with bit at 2100',all 8.5 ppg out of the hole and begining to get some original KWF out of the hole,IA=959 psi Page 12/21 Report Printed: 10/17/2017 . • Operations Summary (with Timelog Depths) 2A-22 conocoPhillips 1i:r.k Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2017 10/1/2017 1.70 PROD1 DRILL PULD P Check well for flow,good(on a vac), 78.0 0.0 14:30 16:12 get loss rate,PJSM,LD BHA#6,loss rate at-14bbl/hr,loss rate dropped to 7.5 bbl/hr, bit came out a 4-2 10/1/2017 10/1/2017 2.00 COMPZ1 CASING PUTB P PJSM,PU liner(ported bull-nose,27 0.0 1,125.0 16:12 18:12 jnts slottted,liner top billet),loss rate at 7.5 bbl/hr 10/1/2017 10/1/2017 0.80 COMPZ1 CASING PULD P Pick up BHA,checked pack offs- 0.0 1,075.0 18:12 19:00 good,tagged up set counters, 10/1/2017 10/1/2017 3.20 COMPZ1 CASING RUNL P RIH,Returns fell off. Confirmed coil 11,215.0 14,231.0 19:00 22:12 marks(3 minor indentions,not from slipped blocks)at 1347'from EOP. Continue to RIH,80 ft/min,pumping 0.34 bpm in 0.24 bpm out,loosing- 0.33-0.4 bpm. Lost all returns @ 8031',partial retuns as coil speed slowed for GLM @ 10,723',fell off. 10/1/2017 10/1/2017 1.30 COMPZ1 CASING RUNL P stop,PU Wt 33 k lbs,Tie into White 14,213.0 17,062.0 22:12 23:30 window flag in tension for-10.5' correction. **Coil track pressure parked,pumps down,3136 psi,bit depth 14221'TVD sensor 5306' calculated BHP 11.37 ppb EMW Contiue to RIH Start picking up WOB @ 14,700' S/D 17,086'drive by on flag was-+2' correction PU,Wt 40 k lbs,RBIH S/D 17,0885, squat neutral coil,4 K WOB, Pumps online 1.5 bpm,CT 3900 psi, PU,35 k lbs,-0.95 WOB. Lost-50 bbls while RIH 10/1/2017 10/2/2017 0.50 COMPZ1 CASING TRIP P Stop to reset depth,line up pump 17,062.0 15,044.0 23:30 00:00 accros the top, POOH,paint yellow flag @ 15044.19' 10/2/2017 10/2/2017 0.30 COMPZ1 CASING TRIP P Continue to POOH 15,044.0 14,100.0 00:00 00:18 10/2/2017 10/2/2017 0.20 COMPZ1 CASING DLOG P Tie into the K1 for a+14.5'correction 14,100.0 14,137.0 00:18 00:30 Lost 12 bbls while POOH. 10/2/2017 10/2/2017 0.50 COMPZ1 CASING DLOG P Park @ 14,137 bit depth,5727.6 TVD 14,137.0 14,137.0 00:30 01:00 monitor bottom hole pressure. Innitial 3365 psi-11.29 ppg Open up bleed on the floor,fill hole till fluid at the stack,S/D well on a vac 5 min coil track 3362 psi-11.28 ppg Verify MW at inlet 11.23 ppg with scale. 10 min coil track 3362 psi-11.28 ppg -took 1.6 bbls to refill hole. 30 min coil track 3358 psi-11.27 ppg Readding BHP of killweight fluid less the slow leak off. 10/2/2017 10/2/2017 2.70 COMPZ1 CASING TRIP P Continue to POOH puming across the 14,137.0 110.0 01:00 03:42 top-Lost 89 bbls of KW Page 13/21 Report Printed: 10/17/2017 Operations Summary (with Timelog Depths) 2A-22 k Conocc�Philiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/2/2017 10/2/2017 0.80 COMPZ1 CASING TRIP P At surface,WH 0 psi,open at stack, 110.0 0.0 03:42 04:30 well on a vac,flood up to the half drum,S/D. Well on a vac. Fill well after ten min 1.9 bbl fill up. PJSM. LD BHA#7 over a dead well.hole fill 2 bbls in 30 min. Flat spot on pipe-8' back from CC. Plan to UT prior to RIH w BHA#9. 10/2/2017 10/2/2017 0.60 COMPZ1 CASING BOPE P PJSM,PU safety joint,perform weekly 0.0 0.0 04:30 05:06 BOP function test Hole fill 1 bbl 10/2/2017 10/2/2017 2.00 COMPZ1 CASING PUTB P Clear clean floor,prep to run liner. 0.0 966.0 05:06 07:06 PJSM,PU upper liner run#2(ported bull-nose,24 jnts slotted liner,&liner top billet),keeping the hole full 10/2/2017 10/2/2017 0.60 COMPZ1 CASING PULD P PU BHA#8 liner running tools,slide in 966.0 1,011.0 07:06 07:42 cart,MU coil,tag up,EDC closed 10/2/2017 10/2/2017 4.00 COMPZ1 CASING RUNL P RIH with Upper LinerAssemlby,no 1,011.0 16,014.0 07:42 11:42 returns to surface pumping.37 bpm, begin to see small returns at-2100', stop at 2177'to establish returns to surface&ensure the hole is full (pumping across the top),continue RIH with no returns to surface Tied into window flag for a+0.31' correction,weight check at window= 35K,clean through window,began taking weight at-14,800'(WOB spikes to 5K),cleaned up by-15,600, arrive at set depth,PUW=40K,RBIH, release off liner on depth,PUW=36K, TOB-15,050' 10/2/2017 10/2/2017 2.80 COMPZ1 CASING TRIP P POOH,flow check well,PJSM,losses 16,014.0 44.0 11:42 14:30 at-9 bbl/hr 10/2/2017 10/2/2017 1.00 COMPZ1 CASING PULD P LD BHA#8,UT flat spot on coil(-8' 44.0 0.0 14:30 15:30 up from EOP),minimum value at.150" wall thickness,within spec to not cut coil,checked pack-offs 10/2/2017 10/2/2017 2.00 PROD2 STK PULD P PJSM,PU BHA#9 AL1 KO/Drilling 0.0 78.0 15:30 17:30 Assembly(agitator,0.5°-AKO motor, RB Hughes bit),tag up,set counters, EDC closed 10/2/2017 10/2/2017 2.00 PROD2 STK TRIP P RIH with BHA#9,surface test agitator, 78.0 14,140.0 17:30 19:30 good 10/2/2017 10/2/2017 0.20 PROD2 STK DLOG P Log K1 for +31'correction,inspect 14,140.0 14,140.0 19:30 19:42 and clean BHI counter,dirty, 10/2/2017 10/2/2017 1.20 PROD2 STK DISP P Line up to pump across the top.bull- 14,140.0 14,140.0 19:42 20:54 head 68 bbl DuoVis down the backside,pumping to 11.5 ppg at the window,annular=3427 psi,WHP 1270 psi,pumped away 68 bbl,lined up on coil. Change out injector counter,re-tie in for a 0'correction 10/2/2017 10/2/2017 0.80 PROD2 STK TRIP P Continue RIH,dry tagged TOB at 14,140.0 15,048.0 20:54 21:42 15,048',PUW= 32K,RBIH Page 14/21 Report Printed: 10/17/2017 • Operations Summary (with Timelog Depths) 0.ry 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB) 10/2/2017 10/3/2017 2.30 PROD2 STK KOST P Begin milling off billet(15,046' 15,047.0 15,058.0 21:42 00:00 pumping),pumping 1.43 bpm,rate out =.63 bpm,annular=3503 psi,CWT= 12K,WOB=.7K,circ pressure=3892 psi,milling on an open choke with -49%returns,climbs to-58%returns, off billet at 15,052' 10/3/2017 10/3/2017 0.40 PROD2 DRILL DRLG P Drilling ahead on AL1 lateral 15,058.0 15,095.0 00:00 00:24 10/3/2017 10/3/2017 0.40 PROD2 DRILL WPRT P PU Wt 35 k lbs,min rate see-1k lbs 15,095.0 15,095.0 00:24 00:48 WOB whilepulling up past the billet. Returns check with open choke Rate in Rate out %retuns 1.3 0.9 70 1.5 0.79 53 1.6 0.79 50 RBIH,down on the pumps,400 lb WOB spike as we passed the billet 10/3/2017 10/3/2017 1.30 PROD2 DRILL DRLG P 1.42 bpm in,0.76 bpm out,Ct 3842, 15,095.0 15,230.0 00:48 02:06 diff 760 psi OBD,CT Wt 8.7 k lbs,WOB 1.6 k lbs, ROP 100 fUhr-returns less than 60% After 20 min drilling returns healed to 0.80 bpm .57% Stall 15163,PU 41 k lbs Pump 5x5 sweep,returns increased from 0.8 to 0.87 bpm as the low vis exited the bit Average ROP over interval drilled- 104 ft/hr 10/3/2017 10/3/2017 2.10 PROD2 DRILL DRLG P Returns fell to 0.70,suspect we 15,230.0 15,383.0 02:06 04:12 crossed fault B, PU @ 15,241'36 k lbs OBD, 1.42 bpm in,0.70 bpm out,Ct 4131, CT Wt 5.0 k lbs,WOB 1.0 k lbs,ROP 90 ft/hr Returns slowly healed to 0.75 bpm/ 53% Pull 100'BHA wiper @ 15,364'PU Wt 36k lbs, Returns 0.78 bpm W PUH,0.66 W RIH BOBD 1.42 bpm in,0.73 bpm out,CT 3877 psi,FS 770 psi CT Wt 0,WOB 1.02,ROP 35 ft/hr Average ROP over interval drilled-73 fUhr 10/3/2017 10/3/2017 0.50 PROD2 DRILL WPRT P Pu Wt 36 k lbs,Wiper trip-1058', 15,383.0 14,325.0 04:12 04:42 slight neg WOB at the billet. 10/3/2017 10/3/2017 0.20 PROD2 DRILL DLOG P RBIH,Tie into the RA tag for+5' 15,383.0 14,354.0 04:42 04:54 correction. 10/3/2017 10/3/2017 1.70 PROD2 DRILL CIRC P PUH above cement pilot hole,open 14,354.0 14,204.0 04:54 06:36 EDC,pump 5x5 sweep all the way around.S/D close EDC,close choke. 10/3/2017 10/3/2017 0.60 PROD2 DRILL TRIP P RIH 14,204.0 15,383.0 06:36 07:12 Page 15/21 Report Printed: 10/17/2017 Operations Summary (with Timelog Depths) 0 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2017 10/3/2017 3.70 PROD2 DRILL TRIP P 1.77 bpm,CT 5411 psi,FS 1075 psi 15,383.0 15,800.0 07:12 10:54 OBD,CT Wt 5.4 k lbs,WOB 1.9 k lbs, ROP 128 15,390,PU 38 k lbs CT Wt 0.6 k lbs,WOB 2.4 k lbs,ROP 170 ft/hr 15,525',PU 39k lbs 15,654',PU 39k lbs 15,758', PU 39k lbs CT Wt-5 k,WOB 1.4 k lbs, ROP fell off to less than 100 Average ROP over interval drilled- 113fUhr 10/3/2017 10/3/2017 0.30 PROD2 DRILL WPRT P Pu Wt 39 k lbs-wiper to above the 15,800.0 14,947.0 10:54 11:12 billet-853' 10/3/2017 10/3/2017 0.30 PROD2 DRILL WPRT P RBIH,RIH Wt 2.6 k lbs 14,947.0 15,800.0 11:12 11:30 10/3/2017 10/3/2017 3.90 PROD2 DRILL TRIP P 1.78 bpm,FS 1042 psi 15,800.0 16,202.0 11:30 15:24 OBD,CT Wt 3 k lbs,WOB 1.4 k lbs, ROP 153 15,933'PU 43 k CT Wt-5 k,WOB 0.9 k lbs,ROP dropping off to 50 ft/hr Pump 5x5 sweep 1%Low torque and 776 Pre CT Wt-3k,WOB 0.9 K ROP 55 ft/hr Post CT Wt-1 k lbs,WOB 1.8 k lbs, ROP 126 ft/hr Average ROP over interval drilled- 103 ft/hr 10/3/2017 10/3/2017 0.40 PROD2 DRILL TRIP P Pu Wt 39 k,wiper 250' 16,202.0 16,202.0 15:24 15:48 turn around @ 15,950 RBIH 10/3/2017 10/3/2017 2.00 PROD2 DRILL DRLG P 1.78 bpm,CT 5058 FS 1012 psi WH 16,201.0 16,385.0 15:48 17:48 911 psi,IA 1450 psi,OA 300 psi OBD,CT Wt 2 k lbs,WOB 1.0 k lbs, ROP 100 Average ROP over interval drilled- fUhr 10/3/2017 10/3/2017 0.45 PROD2 DRILL WPRT P Wiper up hole,PUW 40 k 16,385.0 15,767.0 17:48 18:15 10/3/2017 10/3/2017 0.35 PROD2 DRILL .WPRT P RBIH,pumping 5x5 sweep 15,767.0 16,363.0 18:15 18:36 10/3/2017 10/3/2017 0.25 PROD2 DRILL WPRT P Wiper up hole,PUW 46 k 16,363.0 16,216.0 18:36 18:51 10/3/2017 10/3/2017 0.25 PROD2 DRILL WPRT P RBIH,pumping 5x5 sweep 16,216.0 16,380.0 18:51 19:06 10/3/2017 10/3/2017 0.75 PROD2 DRILL WPRT P Wiper to the window,PUW 46 k 16,380.0 14,110.0 19:06 19:51 10/3/2017 10/3/2017 0.25 PROD2 DRILL DLOG P Log the K1 marker correction of plus 14,110.0 14,168.0 19:51 20:06 18.5' 10/3/2017 10/3/2017 1.50 PROD2 DRILL CIRC P PUH,bullheading 50 bbl bead/lube pill 14,168.0 13,900.0 20:06 21:36 down the back side,0.5 bpm at 1,736 psi 10/3/2017 10/3/2017 1.00 PROD2 DRILL WPRT P Wiper back in hole„cloised choke, 13,900.0 16,380.0 21:36 22:36 pumping 0.28 bpm at 2,125 psi, Page 16/21 Report Printed: 10/17/2017 S • 0_:::-. Operations Summary (with Timelog Depths) .ry 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/3/2017 10/4/2017 1.40 PROD2 DRILL DRLG P BOBD, 1.76 bpm at 4,600 psi FS, 16,380.0 16,498.0 22:36 00:00 BHP 4000 psi,closed choke, IA 1,426, OA 307,CTWS=2 k,DHWOB=1.8 k, ROP=83 fph ****Pump 2-5x5 sweeps 10/4/2017 10/4/2017 0.70 PROD2 DRILL DRLG P OBD, 1.76 bpm at 5,100 psi,BHP 16,498.0 16,547.0 00:00 00:42 4,002,Closed choke, IA 1,375,OA 308,CTSW=4 k, DHWOB=1 k 10/4/2017 10/4/2017 3.75 PROD2 DRILL DRLG P OBD, 1.76 bpm at 4,743 psi,Closed 16,547.0 16,790.0 00:42 04:27 choke,BHP dropped 400 psi,to 3,684, IA 1,374 psi,OA 308,CTSW= 8.0 k,DHWOB=2.8 k,ROP 166 fph 10/4/2017 10/4/2017 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 41 k 16,790.0 15,090.0 04:27 04:57 10/4/2017 10/4/2017 0.70 PROD2 DRILL WPRT P Wiper back in hole,RIW 15,090.0 16,790.0 04:57 05:39 10/4/2017 10/4/2017 5.60 PROD2 DRILL DRLG P RIH Wt 4.4 k lbs, 1.79 bpm,CT 4860 16,790.0 16,957.0 05:39 11:15 psi,FS 1096 psi, WH 500 psi,IA 1198 psi,OA 312 psi OBD,Ct Wt 2-0 k lbs,WOB 2-3 k lbs, ROP 80-10 ft/hr @ 16,955',differential pressure dropped to-1000 psi while OBD and -2k WOB PU,48 k lbs,free spin diff returned to 1090 psi RBIH diff increased to 1200 psi then fell off rapidly to less than 1000 psi while OBD w WOB. Motor still appears to be working,WOB drilling off. ROP 30 ft/hr average over interval drilled 10/4/2017 10/4/2017 1.30 PROD2 DRILL WPRT T PU wt 40 k lbs,Wiper up hole, 16,957.0 14,189.0 11:15 12:33 Diferential pressure varying from as high as 1500 psi to as low as 1000 psi while POOH at 1.8 bpm. Once above the cement pilot hole,parked,Open EDC, 10/4/2017 10/4/2017 2.30 PROD2 DRILL WPRT T Continue to POOH replacing pipe 14,189.0 75.0 12:33 14:51 voidage. 10/4/2017 10/4/2017 0.90 PROD2 DRILL 'PULD T Bump up,space out,PUD BHA#9 75.0 0.0 14:51 15:45 10/4/2017 10/4/2017 1.10 PROD2 DRILL PULD T Break off bit,motor and agitator. Bit 0.0 75.0 15:45 16:51 rated 2-1. Air blow freely through agitator,motor appears to work with air. Bit of black rubber found in bit. check/replace pack offs. 10/4/2017 10/4/2017 1.50 PROD2 DRILL CTOP T check/replace pack offs. 75.0 75.0 16:51 18:21 10/4/2017 10/4/2017 0.25 PROD2 DRILL PULD T Stab on,complete PD BHA#10 0.0 75.0 18:21 18:36 10/4/2017 10/4/2017 0.25 PROD2 DRILL TRIP T RIH,close EDC,testes agitator 75.0 600.0 18:36 18:51 10/4/2017 10/4/2017 2.35 PROD2 DRILL TRIP T Continue RIH pumping 0.30 bpm @ 600.0 14,100.0 18:51 21:12 2,062 psi 10/4/2017 10/4/2017 0.25 PROD2 DRILL DLOG T Log K1 marker correction of plus 19.0' 14,100.0 14,130.0 21:12 21:27 10/4/2017 10/4/2017 1.00 PROD2 DRILL TRIP T Continue RIH to bottom 14,130.0 16,958.0 21:27 22:27 10/4/2017 10/5/2017 1.55 PROD2 DRILL DRLG -P OBD, 1.80 bpm at 4918 psi,BHP 16,958.0 22:27 00:00 3,785,WHP 505, IA 1,159,OA 298, Page 17121 Report Printed: 10/17/2017 0, Operations Summary (with Timelog Depths) .ti 2A-22 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2017 10/5/2017 1.30 PROD2 DRILL DRLG P OBD, 1.78 bpm at 5,106 psi,BHP 17,029.0 17,122.0 00:00 01:18 3,906,WHP 788(closed choke), IA 1,307,OA 302 10/5/2017 10/5/2017 0.30 PROD2 DRILL WPRT T PUH,notice counter not working,PUH 17,122.0 16,818.0 01:18 01:36 to log formation marker @ 16,818' 10/5/2017 10/5/2017 0.25 PROD2 DRILL DLOG T Log formation correction of plus 30.0' 16,818.0 16,911.0 01:36 01:51 10/5/2017 10/5/2017 0.25 PROD2 DRILL WPRT T RBIH to bottom,RIW 5 k 16,911.0 17,122.0 01:51 02:06 10/5/2017 10/5/2017 2.00 PROD2 DRILL DRLG P BOBD, 1.77 bpm at 4,700 psi FS, 17,122.0 17,190.0 02:06 04:06 BHP 3,913,WHP 813,IA 1,319,OA 302,CTSW=minus 1.3 k, DHWOB=1.3 k,ROP 44 fph 10/5/2017 10/5/2017 1.90 PROD2 DRILL DRLG P OBD, 1.78 bpm at 5,186 psi,BHP 17,190.0 17,251.0 04:06 06:00 3,956,WHP 876,IA 1,389,OA 303, CTSW=minus 4.7 k,DHWOB=1.3 k, ROP 40-60 fph Average ROP over interval drilled 32 ft/sec 10/5/2017 10/5/2017 4.90 PROD2 DRILL DRLG P OBD, 1.78 bpm BHP 3,996,WHP 17,251.0 17,501.0 06:00 10:54 957,IA 1,1546,OA 304, Ct Wt-5 k lbs,WOB 1.6 k lbs,ROP 40 Struggled to build angle,getting thrown down,dove and inverted Average ROP over interval drilled 51 ft/sec 10/5/2017 10/5/2017 0.30 PROD2 DRILL WPRT P Pu Wt 44 k lbs,BHA wiper,struggled 17,501.0 17,096.0 10:54 11:12 to turn around, turned into 405'wiper 10/5/2017 10/5/2017 0.60 PROD2 DRILL WPRT P RBIH,struggle to get below 17,339', 17,096.0 17,501.0 11:12 11:48 sweeps on the back side. Once sweeps 5 bbls out continue to RIH. 10/5/2017 10/5/2017 2.00 PROD2 DRILL DRLG P OBD, 1.78 bpm BHP 3,996,WHP 17,501.0 17,569.0 11:48 13:48 957,IA 1,1546,OA 304, Ct Wt-5 k lbs,WOB 1.6 k lbs,ROP 120-10 Average ROP over interval drilled 34 fUsec 10/5/2017 10/5/2017 0.80 PROD2 DRILL WPRT P Pu Wt 42 k lbs,wiper,WH increased 17,569.0 15,200.0 13:48 14:36 from 980psi to 1585 psi-2369'wiper 16,711'pulled heavy,55 k lbs,-0.6 k WOB CT weight and WOB cleaned up after 16,500' 10/5/2017 10/5/2017 0.80 PROD2 DRILL WPRT P RBIH,struggle to get below 17,339', 15,200.0 17,569.0 14:36 15:24 sweeps on the back side. Once sweeps 5 bbls out continue to RIH. 10/5/2017 10/5/2017 1.50 PROD2 DRILL DRLG P OBD, 1.81 bpm BHP 4078 psi,WHP 17,569.0 17,591.0 15:24 16:54 980,CT 5060 psi,FS 1020 psi Ct Wt 3 k lbs,WOB 3 k lbs,ROP 20 Average ROP over interval drilled 15 ft/sec 10/5/2017 10/5/2017 0.40 PROD2 DRILL WPRT P Pu Wt 40 k lbs,Geo wiper 17,591.0 17,015.0 16:54 17:18 10/5/2017 10/5/2017 0.40 PROD2 DRILL WPRT P RBIH,RIW 6 k 17,015.0 17,569.0 17:18 17:42 Page 18/21 Report Printed: 10/17/2017 • • Operations Summary (with Timelog Depths) 014 2A-22 ConocoPhill Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/5/2017 10/5/2017 0.75 PROD2 DRILL DRLG P BOBD, 1.79 bpm at 5,074 psi FS, 17,569.0 17,601.0 17:42 18:27 BHP 4,110,WHP 920,IA 1,497,OA 303 10/5/2017 10/5/2017 1.25 PROD2 DRILL WPRT P TD called,wiper up hole,PUW 40 k 17,601.0 14,100.0 18:27 19:42 10/5/2017 10/5/2017 0.25 PROD2 DRILL DLOG P Log the K1 marker correction of Plus 14,100.0 14,163.0 19:42 19:57 28.0' 10/5/2017 10/5/2017 0.25 PROD2 DRILL TRIP P RIH to window 14,163.0 14,290.0 19:57 20:12 10/5/2017 10/5/2017 3.50 PROD2 DRILL CTOP P Static Pressure Survey: Final ECD 14,290.0 14,290.0 20:12 23:42 11.6 ppg TIME: 20:00 -23:30 WHP: 930 - 761 AP: 3710- 3480 IA: 1497 -1182 10/5/2017 10/6/2017 0.30 PROD2 DRILL TRIP P RIH to confirm TD 14,290.0 15,281.0 23:42 00:00 10/6/2017 10/6/2017 1.15 PROD2 DRILL TRIP P Continue RIH to confirm TD 17,619' 15,281.0 17,619.0 00:00 01:09 10/6/2017 10/6/2017 1.30 PROD2 DRILL TRIP P PUH slowly while mixing liner running 17,619.0 17,210.0 01:09 02:27 pill 10/6/2017 10/6/2017 0.20 PROD2 DRILL TRIP P RBIH while mixing liner running pill 17,210.0 17,549.0 02:27 02:39 10/6/2017 10/6/2017 0.50 PROD2 DRILL TRIP P PUH while mixing liner running pill 17,549.0 17,386.0 02:39 03:09 10/6/2017 10/6/2017 0.40 PROD2 DRILL TRIP P Line up to coil and start pumping liner 17,386.0 17,246.0 03:09 03:33 running pill,continue to creep uphole 10/6/2017 10/6/2017 0.20 PROD2 DRILL TRIP 'P RBIH to time out Liner running pill 17,246.0 17,619.0 03:33 03:45 10/6/2017 10/6/2017 1.40 PROD2 DRILL DISP P PUH laying in 50 bbl 11.5 ppg liner 17,246.0 14,238.0 03:45 05:09 running pill Paint Yellow EOP flag @ 14160' 10/6/2017 10/6/2017 1.10 PROD2 DRILL DISP P PUH slowly while bullheading 11.5 14,238.0 14,127.0 05:09 06:15 ppg KW fluid down the CT by tubing annulus. Stage pums up to 1.5 bopm,WH 850 psi, 10/6/2017 10/6/2017 2.30 PROD2 DRILL DISP P S/D,Observe well head pressure. 14,127.0 14,127.0 06:15 08:33 Initial 156 psi, after 10 min WH 96 psi,open choke to shaker,bleed 0.5 bbls S/I WH stabilizes© 87 psi Bleed another 0.4 bbls to shaker WH stabilized at 80 psi. off load 12.0 ppg NaBr from truck Start building 11.8 ppg KW fluid Monitor pressure WH fell slowly to 18 psi while building KW fluid 10/6/2017 10/6/2017 0.60 PROD2 DRILL TRIP P Start displacing the coil with 11.8 ppg 14,127.0 10,878.0 08:33 09:09 KW fluid while PUH Paint white window flag at 10878.34' KW fluid at the bit 10/6/2017 10/6/2017 2.00 PROD2 DRILL TRIP P At surface,flow check,well on a vac, 10,878.0 102.0 09:09 11:09 lost 138 bls of KW on the trip from the window to surface. 10/6/2017 10/6/2017 1.00 PROD2 DRILL PULD P LD over a dead well, Inspect pipe flat 102.0 0.0 11:09 12:09 spots,0.10"8 ft back. Hole fill 8.5 bbls Page 19/21 Report Printed: 10/17/2017 . • 0 0111 rot Operations Summary (with Timelog Depths) 2A-22 ConoaoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/6/2017 10/6/2017 4.00 COMPZ2 CASING PUTB P Bring in 1 additional R2 slotted joint to 0.0 1,589.4 12:09 16:09 ad to tally for seal bore space out, Prep rig floor for running liner,shelter adjusting roller on CTS counter to 2" pipe from 2-3/8"pipe. PU, 1st R2 slotted joint,MU 3 blanks to the bottom and cap w non ported bull nose. Run 2nd R2 slotted joint and top w 78 joints of R3,8 blank joints of R2 and a seal bore deployment sleeve. (3437.29')filling the hole every 5 joints. Drift lodged in joint#18,found joint full of wood shavings. Cleared drift,re drifted joint,-clean,carried on. 10/6/2017 10/6/2017 2.00 COMPZ2 CASING PUTB P Continue PU/MU of AL1 liner 1,589.4 2,624.6 16:09 18:09 assembly 10/6/2017 10/6/2017 0.50 COMPZ2 CASING PUTB P Crew change,PJSM,inspect liner 2,624.6 2,624.6 18:09 18:39 running equipment and safety joint. perform valve check list. 10/6/2017 10/6/2017 1.15 COMPZ2 CASING PUTB P Continue PU/MU AD liner asembly 2,624.6 3,437.2 18:39 19:48 10/6/2017 10/6/2017 1.20 COMPZ2 CASING PULD P PU/MU,Coiltrak tools,and BOT 3.0 3,437.2 3,481.4 19:48 21:00 GS,stab into PBR,Hanging weight 25 k on blocks,surface test MWD tools (good test),stab INJH,open rams 10/6/2017 10/6/2017 2.00 COMPZ2 CASING RUNL P RIH,with AL1 liner assembly, 3,481.4 14,284.2 21:00 23:00 pumping beaded pill min rate down the backside. 10/6/2017 10/6/2017 0.25 COMPZ2 CASING RUNL P Correct to the EOP flag 14281.46', 14,284.2 14,284.2 23:00 23:15 plus 7.44' 10/6/2017 10/7/2017 0.75 COMPZ2 CASING RUNL P Continue IH 14,284.2 16,590.0 23:15 00:00 10/7/2017 10/7/2017 2.35 COMPZ2 CASING RUNL P Continue to work liner to bottom 16,590.0 17,235.0 00:00 02:21 10/7/2017 10/7/2017 1.00 COMPZ2 CASING RUNL P Continue to work liner to bottom,IA 17,235.0 17,619.0 02:21 03:21 1024,OA 286 10/7/2017 10/7/2017 0.25 COMPZ2 CASING RUNL P Liner is on bottom,PUW 59 k,set 17,619.0 17,619.0 03:21 03:36 down minus 8 k CTSW, DHWOB 0 k, set back down 8 k CTSW,bring pump online at 1.75 bpm at 4,000 psi,PUW 33 k, 10/7/2017 10/7/2017 0.25 COMPZ2 CASING TRIP P PUH for a tie in 17,619.0 14,090.0 03:36 03:51 10/7/2017 10/7/2017 0.25 COMPZ2 CASING DLOG P Log the K1 correction of plus 17.5' 14,090.0 14,120.0 03:51 04:06 10/7/2017 10/7/2017 0.25 COMPZ2 CASING DISP P Perform BHSP sensor depth 14,105.6' 14,120.0 14,120.0 04:06 04:21 MD,5,717'TVD BHSP 11.625 ppg, 3,456 psi AP 10/7/2017 10/7/2017 0.60 COMPZ2 CASING DISP P Line up SW down the coil,displace CT 14,120.0 13,921.0 04:21 04:57 to seawater. 10/7/2017 10/7/2017 0.60 COMPZ2 CASING TRIP P Attempt to lift KW fluid,stage pumps 14,120.0 13,921.0 04:57 05:33 up slowly,No returns,well on a vac. 10/7/2017 10/7/2017 1.70 COMPZ2 CASING TRIP P Line up with seawater down the back 13,921.0 57.0 05:33 07:15 side,displacing well bore to seawater taking returns to the formation while pulling out of hole. 125 bbls pumped. WH climbed from 0 to 902 psi. Page 20/21 Report Printed: 10/17/2017 ID 9 0 .k Operations Summary (with Timelog Depths) 2A-22 Cor►ocoPhiilips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/7/2017 10/7/2017 1.50 COMPZ2 CASING PULD P PJSM,bump up,space out,PUD BHA 57.0 0.0 07:15 08:45 #11,LD same. 10/7/2017 10/7/2017 0.70 DEMOB WHDBOP FRZP P PJSM,LRS,PT,3500 psi,equalize, 0.0 0.0 08:45 09:27 open up and bullhead 30 bbls diesel down the tubing.Final WH pressure 1200 psi. 10/7/2017 10/7/2017 1.50 DEMOB WHDBOP MPSP P PJSM,Pull QTS,Instal ASRC BPV 0.0 0.0 09:27 10:57 lubricator,Set BPV, RD lubricator. Final pressure under the lubricator 1000 psi. 10/7/2017 10/7/2017 1.00 DEMOB WHDBOP CIRC P Reinstall QTS,stab on w nozzle,jet 0.0 0.0 10:57 11:57 stack while turning coil over to fresh water for next well BOPE test. 10/7/2017 10/7/2017 3.00 DEMOB WHDBOP CTOP P Cut flat spot out of pipe,20'1", 0.0 0.0 11:57 14:57 rehead,pull test to 38 k-good. Rehead e-line,PT to 4,000 psi. Pull QTS,install night cap. Lock out storage reel 10/7/2017 10/7/2017 1.00 DEMOB WHDBOP RURD P Blow down.Pull night cap,vac down 0.0 0.0 14:57 15:57 stack. Bore 0 scope the stack 10/7/2017 10/7/2017 2.05 DEMOB WHDBOP RURD P ND and RD in prep to move off.Move 0.0 0.0 15:57 18:00 shop and halfway house spot on 2K- pad. ""Note:Rig Released 18:00 10/7/2017 10/7/2017 DEMOB Trucks back on location,PJSM, 0.0 18:00 18:00 Page 21/21 Report Printed: 10/17/2017 • • 2A-22A and 2A-22AL1 Completed Wellbore Schematic Modified by TH 12-Oct-2017 3-1/2"DS Nipple(min ID 2.812")@ 532.6'MD 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 121'MD 3-1/2"Camco MMG gas lift mandrel @ 3342',7554', 10,757', 12,955',and 14,018' 9-5/8"40#L-80 shoe @ 4928'MD Baker 3-1/2"PBR @ 14,080'MD(2.98"ID) Baker FHL packer @ 14,103'MD(2.93"ID) 3-1/2"Camco DS landing nipple @ 14,153'MD(2.812" min ID, No-Go) Poor Boy Overshot @ 14,205' Liner Top @ 14,181'MD Baker KBH-22 Anchor SA @ 14,226'MD Baker SAB-3 Packer @ 14,227 with Northern Solutions LTP 3-1/2"Camco D landing nipple @ 14,242'MD(milled out to 2.80"min ID,No-Go) 3-1/2"WLEG @ 14,263'MD -41 ii. Tubing tail Perfs D-Nip milled to 2.80"ID 14,237'-14,239'MD @ 14,242'MD for cement squeze KOP @ 14,308'MD 3-1/2"XL Monobore WS set in cement pilot hole C/A-sanderfs p 2-3/8"Solid Liner from 2A-22AL1 TD @ 17,619'MD 14,302'-14,317'MDLT-14,434'MD 2-3/8"Slotted Liner 14,330'-14,348'MD 14,352'-14,378'MD — .1 ==� ____________ ____ ____________________________________J 7"26#L-80 shoe Ported Bull Nose @ 14,787'MD KOP for AL1 off LT Billet /Deployment Sleeve 2A-22A TD @ 17,092'MD @ 15,047'MD @16,015'MD 2-3/8"Slotted Liner ' KUPD • 2A-22 Conocol'hillips / &- Well Attribute Max Angle&MD TD t'Idtis., 1t1{, Wellbore APBUWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(ftKB) al)ida 501032022100 KUPARUK RIVER UNIT PROD 75.59 4,189.53 14,797.0 ... Comment H2S(ppm) Date Annotation End DateKB-Grd(5) Rig Release Date 2A-22,11/6/201710;32.55 AM ,..e 120 12/5/2016 Last WO: 9/29/2014 I 45.90 6/11/1995 Vertical athematic( ti* 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,1 •r Last Tag.RKB 14,399.0 8/8/2017 Rev Reason:TAG,LINER TOP PACKER,GLV pproven 10/31/2017 HANGER,38.4 �,I•0/ C/O,SET 3 PATCHES(1-Leak,2-Proactive) Tubing Strings rl Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Original 3 1/2 2.992 14,207.0 14,264.6 5,811.9 9.30 L-80 ABM-EUE .....................r.,.,.,.,. cc.Completion Details 1110 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) .�ti CONDUCTOR;41.0-121.0- 14,225.8 5,788.0 52.60 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 14,226.7 5,788.6 52.58 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 NIPPLE,532.6 - 14,242.0 5,797.9 52.22 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 14,262.7 5,810.6 51.73 WLEG WIRELINE ENTRY GUIDE,ELMD @ 14258'ON SWS 2.992 I PERF 8/17/2001 Mandrel;3,341.5 i Perforations&Slots Shot Dens I Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB351) (ftKB) Zone Date ft) Type Com 14,302.0 14,317.0 5,8 . 5,844.4 C-4,2A-22 6/28/2000 4.0 APERF 2 1/2"HSD DP,180 deg SURFACE;40.9-4,928.0—�- ` ph Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(Ib) Date Mandrel;7,553.9 . 12/9/2002 ,; ,E Stimulations&Treatments Vol Clean Pump PATCH;8,585.0 I Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) ( 1 14,302.0 14,378.0 12/9/2002 PATCH;8,615.0. 11 Notes:General&Safety End Date Annotation PATCH;9,399.0- ',� 6/1/2008 NOTE:TUBING PUNCH BETWEEN SAB-3 PACKER 8 CA-2 PLUG IN TUBING STUB,9 SHOTS w/ENTRANCE HOLE OF 0.19 PATCH;9,414.0 I 11/9/2008 NOTE:View Schematic w/Alaska Schematic9.0 PATCH;9,447.0 'Ii 11/5/2014 NOTE:2.81"DS N.P.@14152'RKP MAY BE DAMAGED FROM PULLING PLUG ON 11 514 PATCH;9,620.0 1 PATCH;8,850.0 ,, Mandrel;10,757.4 tir it jaji impi Mandrel;12,955.0 Mandrel;14,017.9 LOCATOR;14,072.2 SEAL ASSY;14,073.2 PBR;14,079.5 - 2 PACKER;14,102.6 - III III IL NIPPLE,14,152.9 ';; ..._. ill PACKER,14,180.0 ..I OVERSHOT;14,205.4 SEAL ASSY;14,225.8 PACKER;14,228.7 .1 . I I NIPPLE;14,242.0 E I WLEG;14,282.7 APERF;14,302 0.14,317.0 Whipstock;14,307.0 '� i 1 PRODUCTION;38.3-14,787.0 FRAC;14,302.0 H_Latera.14.181 81,fi1B.0 KUPOD • 2A-22A ConocoPhillips $ Well Attrialir Max Angle&MD TD /'ilii 1,,,..., Wellbore API/UWI Field Name Wellbore Status ncl(`) MD(ftKB) Act Btm(ftKB) �BBp 501032022101 KUPARUK RIVER UNIT PROD 94.80 16,980.22 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2A-22A,41/6/201710:33:43 AM SSSV:NIPPLE 120 12/5/2016 LAST WO: 9/29/2014 45.90 6/11/1995 vempal schemahc.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,36.4 ,,I'i i .._Last Tag:RKB 14,399.0 8/8/2017 Rev Reason:Side Track jennalt 11/2/2017 ill asing Strings Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread .....,r.Jnr......r...,,o....n.,..„.,.,n,n„ (I!. (Cr'1 CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD En) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 40.9 4,928.0 2,936.7 40.00 L-80 BTC ( II Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WiLen p...Grade 'Top Thread CONDUCTOR,41,0-121 0^ IIPRODUCTION 7 6.276 38.3 14,787.0 5,886.6 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread A Lateral tit it Ai Tubing Strings 2 3/8 1.992 15,048.0 17,091.5 5,943.4 4.60 L-80 STL NIPPLE;532.6 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 364 14,212.5 5,780.0 9.30 L-80 EUE 8R4 Mandrel;3,341.5 , Completion Details IP Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Com (in) 36.4 36.4 0.00 HANGER FMC TUBING HANGER 2.992 l 532.6 532.6 1.64 NIPPLE DS NIPPLE 2.812 SURFACE,40.9-4,0280 14,072.2 5,698.7 56.28 LOCATOR LOCATOR SUB 2.970 la 14,073.2' 5,699.2 56.26 SEAL ASSY SEAL ASSY..STICK-UP=7-ft. SWALLOW=14.6-ft 3.000 Mandrel;7,553.9 it st 14,079.5 5,702.7 56.10 PBR BAKER POLISH BORE RECEPTACLE 2.980 14,102.6 5,715.7 55.54 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 PATCH;8,585.0 I 14,152.9 5,744.6 54.31 NIPPLE CAMCO DS NIPPLE 2.812 i PATCH;8,615.0 j. 14,205.4 5,775.7 53.08 OVERSHOT POOR BOY OVERSHOT...SWALLOW=5.5-ft. 3.620 • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PATCH;9,399.0 E !'..' Top(TVD) Top Incl '_? `- Top(ftKB) (ftKB) (3 Des Corn Run Date ID lin) PATCH;9,417.0 1 8,585.0 3,983.4 73.60 PATCH UPPER PIIP PATCH ASS'Y=2.72"PIIP(SN: 10/15/2017 1.600 PATCH;9,4470 '[ `. CPP35119(25.25'x 2 1/16"SPACER PIPE 8 LATCH SEAL(SN:CPAL35068)OAL=30.87'/ PATCH;9,620.0 MID ID=1.60" PATCH,9,650.0i f 8,615.0 3,991.9 73.53 PATCH LOWER 2.72"PIIP PACKER(SN:CPP35132)OAL 10/14/2017 1.620 =4.01/MIN ID=1.625 9,399.0 4,220.0 72.78 PATCH UPPER 2.72"PIIP(SN:CPP35127)11.60'OF 2 10/14/2017 1.620 Mandrel;10,7574 1/16"SPACER PIPE 8 LATCH SEAL ASSEMBLY 1 la (SN:CPAL350059)17.07'OAL/MIN ID= 1.62" ((15'MID ELEMENT TO BTM)) irt9,414.0 4,224.5 72.76 PATCH 3.5"PBR(SN;CPBR35004)30'x 2 1/16"SPACER 10/13/2017 1.620 Mandrel;12s55.0 McPIPE 8 LATCH SEAL ASS'Y(SN:CPAL35050) OAL=32.75'/1.62"ID 0 9,447.0 4,234.2 72.72 PATCH 2.72"PIIP PACKER(SN:CPP35117/4.01"OAL/ 10/132017 1.620 1.62"ID) Mandrel;14,0179 , g 9,620.0 4,285.9 72.62 PATCH 2.72"PIIP(SN:CPP35108)25.5'SPACER PIPE 8 10/12/2017 1.625 all. I LATCH SEAL ASSEMBLY(SN:CPAL35066/OAL =30.86') MI LOCATOR;14,072.2 ili 9,650.0 4,294.8 72.87 PATCH 2.72"PIIP PACKER(SN:CPP35131/1.625"ID/ 10/12/2017 1.625 SEAL ASSY;14,073.2 GAL PBR;14.079.5 = 14,180.0 5,760.6 53.68 PACKER CATCHERON LINER TOP PACKER w/1.781 R 10/10/2017 PACKER,14,102.6 NIPPLE(OAL=5.372') 14,307.0 5,838.2 51.62 Whipstock 9/26/2017 1.000 Perforations&Slots NIPPLE;14,152.9 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PACKER;14,180.0 14,330.0 14,348.0 5,851.6 5,860.5 C-4,2A-22 8/17/2001 4.0 APERF 2.5"HSD Alternating BH/PJ,180 deg phase 14,352.0 14,378.0 5,862.2 5,869.8 A-3,2A-22 6/12/1995 4.0 IPERF SWS TCP Type BH UP; 180 deg ph;oriented 90 CCW f/highside OVERSHOT;14,205.4 (111 a__ Stimulations&Treatments SEAL ASSY,14,225.8 Proppant Designed(Ib) I Proppant In Formation(Ib) 'Date PACKER;14,226.7 If.,111.. 12/9/2002 Mandrel Inserts ._ St NIPPLE;14,242.0 ati 111 on Top(TVD) Valve Latch Port Size TRO Run N, Top(RKB) (ftKB) Make Model OD lin) Sew Type Type ON (psi) Run Date Com Ilk 1 3,341.5 2,503.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,313.0 10/16/2017 WLEG;14,262.7 -, 2 7,553.9 3,707.5 CAMCO KBMG 1 GAS LIFT OV BK 0.188 0.0 10/19/2017 1 3 10,757.4 4,606.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/28/2014 EXTE APERF;14,302.0-14,317.0 NDE Whipstock;14,307.0 D FRAC;14,302.0 '. 4 12,955.0 5,251.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/30/2014 P}CG ' AL Lateral;14,181.8-17,6190 5 14,017.9 5,669.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/10/2017 APERF;14,330.0-14,348.0 Notes:General&Safety (PERF;14,352.0-14,378.0 End Date Annotation NOTE:WO 9/29/2014 PRODUCTION;383-14,787.0 iI i 1 A Lateral;15,048-0-17091.5 i KUP /ROD • 2A-22AL1 CQnoCoPhii ips Weir Attribu Max Angle&MD TD Alaska,inc - Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cwacothtlltps 501032022160 KUPARUK RIVER UNIT PROD 96.55 17,587.27 17,619.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2A-226L1,11/64201710134;51 AM 120 12/5/2016 45.90 6/11/1995 Vartacal scherre0c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Rev Reason:Side Track jennalt 11/2/2017 HANGER',36.4 a Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread r# r. ruw AL Lateral 2 3/8 1.992 14,181.8 17,619.0 4.60 L-80 STL Stimulations&Treatments I Proppant Designed(Ib) Proppant In Formation(Ib) Date 12/9/2002 -ham CONDUCTOR;41.0-121.0 NIPPLE;532.6 Mandrel;3,341.5 SURFACE;40.9-4,928.0 Mandrel;7553.9 PATCH;8,585.0 PATCH;8,615.0 €:t PATCH;9,399.0 PATCH,9,414.0 PATCH;9,447.0 PATCH;9,620.0 PATCH;9,650.0 Mandrel,10,757.4 Mandrel,12,955.0 Mandrel;14,017.9 LOCATOR;14,072.2 SEAL ASSY;14,073.2 PBR;14079.5 PACKER;14,102.6 •' NIPPLE;14,152.9 PACKER,14,180.0 OVERSHOT;14,205.4 SEAL ASSY,14,225.8 PACKER 14226.7 "'— NIPPLE,14,242.0 WLEG;14,262.7 APERF;14,302.0-14,317 0 Whipstock;14,307.0 PRODUCTION,38.3-14,787.0 FRAC;14302.0 AL Lateral',14,181.8-17,619.0 RECEIVED n5-oGic6 2:6G 34( SEP 2 9 2017 WELL LOG TRANSMITTAL#904142932 AOGCC To: Alaska Oil and Gas Conservation Comm. August 2, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA Lo«:: M. K.BENDER SCOW RE: Multi Finger Caliper : 2A-22 Run Date: 7/1/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2A-22 Digital Data(LAS),Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20221-00 Multi Finger Caliper (Field Log) 1 color log 50-103-20221-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:(*) ,/algadigk..,4:)_a_ tat IP0 • 0 l9 l� v _ t ..nn Lc H 1 • r 0 q ¢ ,SI > +� Cr2r1 v 2 2 N C7 5. . b4 +-' CU T (0 N 0 NW N;, ( 4 'O f6 FQ- •Y L../ v AL r a +-+ 0 o 2 rc Y W+ coC -C ci, Q @ Q QOw n n n a a coVI N O Q nC) a) a) C) m o) a OE '' -C -0 7 7 a 3 a a aO W 7 q q q q q q o U ,17 Q1 C in 1_ O N If) h CO 0 @ 4" V) Q N N 6 + u - (B O J Qz ZQ 0 v Q7 E E.) a O 0 0 0 0 0 0 O O p w J J J J J J J OA r- - O •y W W W W W W W v, O 'C U I LL LL LL LL LL LL LL a) CC) 1- < < < < < < < 'v C C) < ZZZZZZZ a r a) 0 a1 LL LL LL LL LL LL LL K > y ) L O _a � au ,i) °a ,�vu ° p 0) z U O t Z .>0 U 2 < aa) CO U c a id 1, O 0 J 0 0 0 E 2 Y +` O w 0 cc re Et la 0 u \ G mJaa °' i- w a N{ G E-r O v 1 fi 4:1) 0a U y w LO W U > 0 \ 0..., it a ms RI ., O r• z OJ x , w ° I • �., W u d J J J J J J J +., Z ro W on 41111113-10 a) .,.._ _ 4 .,v, / E w w w w w w w ° w > > > > > > > L haz Y Y Y Y Y Y Y CtCeWCLCLCCCtv T < < < < < < q CL a a a a a a E0. o CI DDDDDDD Y Y Y Y Y Y Y �. Oa f6 IliN.. W O O O N CMC) X In .� O 0 O O O . N �y r , 0 0 0 0 0 0 0 y v o o O O O O o NMIM vii N N N r r; C LIJI N V co co M Cl) Cl)oV) C Vco. r Ly 0 0 0 0 0 0 0 C Occ x u W a w O O O O O O C . 0 0 0 0 0 0 0 ao CC r-, o o v o N- • 0 N CO N- V CO N- r O N. N CO CO CO CO In to ° U (N O O CO CO CO CO N N N N N N N N i __ R M T O) O) T Cn C) a) an O N N N N N NL Q1 O O O O O O 0 0 0 0 0 0 0 a+ 0• a) 0�0 C N 1!') LI) In to to Cr) Q U aa w in a) t13 a) <0 tZ Y o w C C 133 L 1-_- _, v q o� 2 To ° a` 'a a a) m Q N r o q - - }, W z a-+ z N O O a.+ NCC co c a q l0 N -I N r -) Ni 2 N z Vii Y 1--1 t w C 4' a) Le) i Ca N 4 cu CO .i al co O y a LO q H a a Q • �F � 0 • • 40.-A,7,-.&A THE STATE Alaska Oil and Gas ti -sem of ®® sKA Conservation Commission S r#xft333 West Seventh Avenue "�,,�*R., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o Main: 907.279.1433 ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov William R. Long SWIM AUG 1 12()17. CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-22 Permit to Drill Number: 195-068 Sundry Number: 317-345 Dear Mr. Long: 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, 61:13g1_,_ Hollis S. French Chair, Commissioner DATED this Zo day of July, 2017. RBDMS AUG - 9 2017 • • RECEIVED • STATE OF ALASKA JUL 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 v Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: LI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development E, 195-068 ' 3.Address: Stratigraphic ElService ❑ 6.API Number: •t,3 PO Box 100360,Anchorage AK 99510 . 50-103-20221–W _p> 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A• KRU 2A-22 - Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25571 ' Kuparuk River Field/Kuparuk River 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): 14797 6144 14340 5864 3245 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 121 121 1640 670 Surface 4887 9.625 4928 2937 5750 3090 Intermediate Production 14749 7 14787 6138 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14302-14317,14330-14348, 5835-5844,5852-5864, 3.5" L-80 14265 14352-14378 5866-5882 Packers and SSSV Type: Baker FHL Retrievable Packer Packers and SSSV MD(ft)and TVD(ft): 14103 MD/5716 TVD Baker SAB-3 Permanent Packer 14227 MD/5789 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7-Aug-2017 OIL ❑ 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: 1 I'il'a.r+–t P, Lo Contact Name: William R. Long 4.7 Authorized Title: ern E l‘it.eer-- Contact Email: William.R.Long@ConocoPhillips.com _ Contact Phone: 907-263-4372 Authorized Signature: �1/ Date: 2'/-J,J-20�� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t7- 3 `f S Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3017 fiz-5 f �G 4 vv° 5 �`ffrr1 afC / `- /�ce- lh 01��j'°vd Post Initial Injection MIT Req'd? Yes ❑ No l /p`t o o z/f e 25-- II 2 (LJ • Spacing Exception Required? Yes ❑ No Subsequent Form/ Required: /G — 4 0 7 APPROVED BY Approved by: • I COMMISSIONER THE COMMISSION Date: -J' (ZP,114 \{�/� �"• �4S �� 6 ' CJ 7/27/20/7 Submit Form and QI1' g�\Form 10-403 Revised 4/2017 1"�1, diNAsvalid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 252017 AOGCC June 24, 2017 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to plug the KRU 2A-22 (PTD#195-068) by cementing up the perforations to allow CTD operations to drill a dual-lateral out of the KRU 2A-22 using the coiled tubing drilling rig, Nabors CDR3-AC. A sundry application is attached to plug the KRU 2A-22 perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the perforations in this manner. Attached to this application are the following documents: - 10-403 Sundry Application for KRU 2A-22 - Operations Summary in support of the 10-403 sundry application - Proposed CTD Schematic - Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, 4/r/ William R. Long ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 2A-22 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 2A-22 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production liner. The CTD sidetrack will utilize two laterals to target the A and C sands to the west of 2A-22. The laterals will increase resource recovery and throughput. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 14,227' RKB and the "D" nipple at 14,242' RKB will be milled out to a 2.80" ID. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 14,340' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 14,310' MD. The two laterals will be completed with 2-3/8" slotted liner from TD with the final liner top located inside the 3-1/2" tubing tail. Using the maximum formation pressure in the area of 3,832 psi in 2A-20, the maximum potential surface pressure in 2A-22, assuming a gas gradient of 0.1 psi/ft, would be 3,245 psi. BOP test pressure will be 4000 psi. CTD Drill and Complete 2A-22 Laterals: September 2017 Pre-CTD Work 1. RU E-line: Punch 2' of holes in the 3W tubing tail below packer at 14,227' RKB. 2. RU Pumping Unit: perform injectivity test down the tubing. 3. RU Service Coil: Mill out "D" nipple, tag TD, perform memory caliper log, and cement C- sand perforations up to the holes in the tubing tail. 4. RU Slickline: Tag top of cement and pressure test cement. 5. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2A-22A Sidetrack (West) a. Drill 2.80" pilot hole through cement to 14,340' MD b. Caliper pilot hole c. Set top of whipstock at 14,310' MD and mill 2.80" window d. Drill 3" bi-center lateral to TD of 18,000' MD. e. Run 2%" slotted liner with an aluminum billet from TD up to 15,150' MD. 3. 2A-22AL1 Lateral (West) a. Kick off the aluminum billet at 15,150' MD. b. Drill 3" bi-center lateral to TD of 18,000' MD. c. Run 2%" slotted liner with deployment sleeve from TD up into 3-1/2" production tubing. 4. Collect static bottom hole pressure, freeze protect, ND BOPE, and RDMO Nabors CRD3- AC. Post-Rig Work 1. Return to production Page 1 of 1 7/24/2017 • • 2A-22 Proposed CTD Schematic Modified by WRL 20-Jul-2017 3-1/2"DS Nipple(min ID 2.812")@ 532.6'MD 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H-40 — — shoe @ 121'MD 3-1/2"Camco MMG gas lift mandrel @ 3342', 7554', 10,757', 12,955', and 14,018' 9-5/8"40#L-80 shoe @ 4928'MD ---.011111111 Baker - Baker 3-1/2"PBR @ 14,080'MD(2.98"ID) Baker FHL packer @ 14,103' MD(2.93"ID) 3-1/2"Camco DS landing nipple @ 14,153' MD(2.812" min ID, No-Go) Poor Boy Overshot @ 14,205' Baker KBH-22 Anchor SA @ 14,226' MD Baker SAB-3 Packer @ 14,227 3-1/2"Camco D landing nipple @ 14,242'MD(2.75"min ID, No-Go) Needs to be milled out to 2.80'ID KOP @ 14,310'MD C/A-sand perfs 14,302'- 14,317'MD 14,330'-14,348'MD2A-22AL1 wp02 TD @ 18,000'MD 14,352'-14,378'MD -� _--_-_ 7"26#L-80 shoe 2A-22A wp03 @ 14,787'MD TD @ 18,000'MD KUP D 2A-22 Conoc©Philhps 1 Well Attribute Max Angle D TD NIa4k�,.1,.,, Wellbore API/UWI Field Name Wellbore Status incl(°) MD(ftKB) Act Btm(ftKB) oto,-' 501032022100 KUPARUK RIVER UNIT PROD 75.59 4,189.53 14,797.0 .«.< Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2A-22,.7/25/20175:52:44 AM SSSV:NIPPLE 120 12/5/2016 Last WO: 9/29/2014 45.90 6/11/1995 Varanl.schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 14,348.0 6/6/2017 Rev Reason:H2S,TAG pproven 6/7/2017 HANGER;36.4 116111 Casing Stnngs 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len g...Grade Top Thread r SURFACE 9 5/8 8.835 40.9 4,928.0 2,936.7 40.00 L-80 BTC ' Casing Description OD(in) ID TopftKB Set Depth ftKB Set Depth(ND)... WILen(I...Grade Top Thread 9 P (in) ( ) P ( ) P PRODUCTION 7 6.276 38.3 14,787.0 6,137.6 26.00 L-80 BTC-MOD Tubing Strings ^-^CONDUCTOR:41.0121.0 S Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014 31/2 2.992 36.4 14,212.51 5,780.0 9.30 L-80 EUE 8Rd gi Completion Details Nominal ID NIPPLE,532.6 Top(ftKB) Top(ND)(ftKB) Top Incl V) Item Dec Com (in) 36.4 36.4 0.06 HANGER FMC TUBING HANGER 2.992 4 532.6 532.6 1.64 NIPPLE DS NIPPLE 2.812 4 14,072.2 5,698.7 56.28 LOCATOR LOCATOR SUB 2.970 Mandrel 3,341.5 r 14,0732 5,699.2 56.26 SEAL ASSY SEAL ASSY..STICK-UP=7-ft.SWALLOW=14.6-ft 3.000 14,079.5 5,702.7 56.10 PBR BAKER POLISH BORE RECEPTACLE 2.980 14,102.6 5,715.7 55.54 PACKER BAKER FHL RETRIEVABLE PACKER 2.930 14,152.9 5,744.6 54.31 NIPPLE CAMCO DS NIPPLE 2.812 I 14,205.4 5,775.7 53.08 OVERSHOT POOR BOY OVERSHOT...SWALLOW=5.5-ft. 3.620 su41-n<:I-:no y n.92a o-.- l Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING Original 31/2 2.992 14,207,0 14,264.6 5,811.9 9.30 L-80 ABM-EUE Completion Details Mandrel:7,553.8 - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top 1061(') Item Des Com (in) 14,225.8 5,788.0 52.60 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.000 14,226.7 5,788.6- 52.58 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 14,242.0 5,797.9 52.22 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 Mandrel 10,7574 I 14,262.7 5,810.6 51.73 WLEG WIRELINE ENTRY GUIDE,ELMD @ 14258'ON SWS 2.992 ti PERF 8/17/2001 Perforations&Slots Shot Mandrel;12,955.0 Dens Top(ND) Btm(ND) (shots/ 4 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Coin 14,302.0 14,317.0 5,835.1 5,844.4 C-4,2A-22 6/28/2000 4.0 APERF 21/2"HSD DP,180 deg ph • 14,330.0 14,348.0 5,852.4 5,863.6 C-4,2A-22 8/17/2001 4.0 APERF 2.5"HSD Alternating Mandrel:14,017.9BH/PJ,180 deg phase 14,352.0 14,378.0 5,866.1 5,882.3 A-3,2A-22 6/12/1995 4.0 IPERF SWS TCP Type BH UP; 180 deg ph;oriented 90 CCW f/highside LOCATOR;14,0722 Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(lb) Date SEAL ASSY;14,073.2 12/9/2002 - PBR;14,079.5 Stimulations&Treatments PACKER;14,102.8 Vol Clean Pump Stg p Top(ftKB) Btm(ftKB) Date St./Treat Fluid (bbl) Vol Slurry(bbl) 1 14,302 0 14,378.0 12/9/2002 Mandrel Inserts st NIPPLE;14,152.9 ati eTop(ND) Valve Latch Port Size TRO Run N lop(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 3,341.5 2,503.2 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,349.0 12/15/2014 (( 2 7,553.9 3,707.5 CAMCO KBMG 1 GAS LIFT OV BK 0.188 0.0 12/15/2014 OVERSHOT;14,205.4 f: 3 10,757.4' 4,606.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/28/2014 EXTE NDE 1. D SEAL ASSY;14,225.5 4 12,955.0 5,251.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/30/2014 ' '.0 PACKER;14,226.7 5 14,017.9 5,669.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/30/2014 Notes:General&Safety IF End Date Annotation NIPPLE;14,242.0 - 6/1/2008 NOTE.TUBING PUNCH BETWEEN SAB-3 PACKER 8 CA-2 PLUG IN TUBING STUB,9 SHOTS A w/ENTRANCE HOLE OF 0.19 11/9/2008 NOTE:View Schematic w/Alaska Schematic9.0 111 11/5/2014 NOTE:2.81"DS N.P.@14152'RKP MAY BE DAMAGED FROM PULLING PLUG ON 11 5 14 WLEG;14,2627 • APERF;14,302.0-14,317.0 APERF;14,330.0-14,346.0 FRAC;14,302.0 _ IPERF;14,352.0-14,378.0 I PRODUCTION;38.3-14,787.0 1111 Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend"boxes are also checked, cross out that erroneous entry and f initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer j The drilling engineers will serve as quality control for steps 1 and 2. (QC) 0 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 1 ~~_~~~ File Number of Well History File PAGES TO DELETE Complete RESCAN ^ Color items -Pages: ^ Grayscale, halftones, pictures, graphs, charts - Pages: ^ Poor Quality Original -Pages: ^ Other -Pages: DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type OVERSIZED ^ Logs of various kinds ^ Other COMMENTS: ~ ~ ~ ~ . _, ~~ Scanned by: Beverly ^ TO RE-SCAN Notes: Nathan Lowell Date: ~ -I /s/ ~~ Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /s/ STATE OF ALASKA ~i JUN ~ Q LAC S ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIi~tSas'~ ~ ~~~ ~~~°~~ ~+c:3ri+" ,.,:;~`i 1. O erations Performed: Abandon ~'~` '` "°' p ^ Repair Well Q Plug Perforations ^ Stimulate ^ Ot ~ d Alter Casing ^ Pull Tubing ^~ Pertorate 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: COnOCOPhIIIIPS Alaska, InC. Development ~ Exploratory ^ 195-068 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20221-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 94' - 2A-22 • 8. Property Designation: 10. Field/Pool(s): ADL 25571 BALK 2669 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14797' • feet true vertical 6144' feet Plugs (measured) 14242' Effective Depth measured 14314' feet Junk (measured) 14242' true vertical 5842' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURF CASING 4887' 9-5/8" 4928' 2937' PROD CASING 14657' 7" 14698' 6082' Perforation depth: Measured depth: 14302'-14317', 14330'-14348', 14352'-14378' t e3 Q ~ `~ 2008 ' ~~~~~ ~UL ' ' ' ' ' true vertical depth: 5835 -5844 , 5852 -5864 , 5866 -5882 ' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 14265' MD. Packers & SSSV (type 8 measured depth) pkr-- BAKER'FHL' RETRIEV.; BAKER'SAB-3' pkr- 14185', 14227' Camco DS nipple @ 501' 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 117 1645 1931 - 206 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: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Jim Ennis @ 265-1544 Printed Name Jirry~fnis Title Wells Group Engineer /~ Signature ~'`~~~ Phone Date lp ~`~ Dg~.~~4 O~j ~ Pre n 11 u Drake 263-461 ~^- Form 10-404 Revised 04/2006 Submit Original Only ~~. ~~.--F/ r~ • Cono~oPhi[lips Time Log & Summary WelN7ew Web Reporting Report Well Name: 2A-22 Rig Name: NABOBS 3S Job Type: RECOMPLETION Rig Accept: 12/15/2007 12:00:00 PM Rig Release: 12/29/2007 6:00:00 AM Time Logs i Date From To Dur S. De th E De th Phase Code 5ubcode T Comment 12/14/2007 2a hr Summary Finish up on 2D-15 18:00 00:00 6.00 COMPZ MOVE RURD P Scope down and lay derrick over. Disconnect steam and electricit . 12/15/2007 Move to 2A-22 MIRU and accept rig. Accepted rig @ 12:00 hrs. Verify well killed and ND tree and NU BOPE. Witnessin of BOPE Test waived b John Cris 19:00 hrs on 12-15-07. 00:00 03:00 3.00 COMPZ MOVE RURD P Finish preparing for rig. Back trucks under equipment modules and pull off well. 03:00 05:00 2.00 COMPZ MOVE MOB P Move rig off of 2D Pad to 2A Pad 05:00 12:00 7.00 COMPZ MOVE RURD P Spot Equipment and Rig Up. 12:00 16:30 4.50 COMPZ RPCOM OTHR P Spot & set Tiger tank. Rig up lines for well circulation. 16:30 18:30 2.00 COMPZ WELCTL OTHR P RU Lubricator and lubricate out BPV 0 si. RD lubricator 18:30 00:00 5.50 COMPZ RPCOM NUND P ND Tree and NU Bope. Function test and fill stack. 12/16/2007 Test BOPE @ 250/2500 psi, Witnessing of BOPE Test waived by John Crisp @ 19:00 hrs on 12-15-07. Unland tbg hanger @ 40k and work up to 20' out of the hole @ 175k. Call out for tbg cut and fishing. Pump in hole w/ 2.5" OD Jet cutter from 3000' to 5770' 3.5 b m 670 si. 00:00 05:00 5.00 COMPZ WELCTL BOPE P Install test jt. Conduct BOPE Installation test 250!2500 psi. Witnessing of Test was waived by John Crisp w/ AOGCC @ 19:00 hrs on 12-15-07. Remove test jt and pull test lu and BPV. 05:00 06:00 1.00 COMPZ RPCOM RCST P Attempted to pull the completion with 175k#. Hanger pulled up ~ 20ft. Landed han er back down 25k#. 06:00 09:00 3.00 COMPZ RPCOM CIRC P Circulated hole volume 375 bbl with 9.6 brine. 2b m 1200 si. 09:00 14:00 5.00 COMPZ FISH WOEO XP Waiting on SWS for chemical cut. 14:00 21:30 7.50 COMPZ FISH ELNE P Rigging up SWS with 2.5" jet cutter. Set completion in 100k# tension. Held PJSM w/all involved. MU 2.5 Jet Cutter assy (23' long @ 290 Ibs overall wt.) and Rih to 3000' w/ 75 degree hole angle, was not able to work past. Beain to pump wireline down and found flow line to rigs pits to be froze. 21:30 22:30 1.00 COMPZ FISH OTHR T Clean up overflow. Remove and thaw out frozen flow line P~g~ 1 of 9 • ~ Time Logs I D From To Dur 5 De th E. De th Ph e Code Subcode T Comment I 22:30 00:00 1.50 COMPZ FISH ELNE P Continue to pump 2.5" OD Jet cutter down from 3000' to 5770' +/- Run collar log 5770' to 4735'. Discuss further logistics -Make call to En ineer 12/17/2007 Pooh w/ hole w/ jet cutter and Rih to retrieve valve from GLM @ 13,426'. RD HES and RU SWS and Pump in hole w/ 2.5" OD 'et cutter to 13,256.0' and ick u to 13,223' and cut i e. Pooh and RD SWS 00:00 03:00 3.00 COMPZ FISH ELNE X Review status w/engineer and decided that well needed to have valve removed from GLM # 7 prior to cutting for future existing pipe recovery runs during work over. Pump in the @ 3.5 bpm @ 670 psi and same distance was made. Pooh and dis arm 2.5" OD 'et cutter. RD SWS and ull to side of location. 03:00 04:30 1.50 COMPZ RPCOM SLKL XP Wait for HES slick line to become available 04:30 08:30 4.00 COMPZ RPCOM SLKL P Spot and RU HES Slick line 08:30 12:30 4.00 COMPZ RPCOM SLKL P RIH with HES. Able to run down to the GLM #7 at 14172'. Unable to latch on r Iota L .Pulled up to GLM #6 at 13426', located and latched onto the GLV. POOH with 12:30 00:00 11.50 COMPZ RPCOM RURD P RD HES slickline unit. RU SWS unit with 2.5"jet cutter was able to get to down and cut 13 223'. Pumping w/I down @ 4 bpm @ 430 psi w/ 2.5" OD Power Jet Cutter. Made cut & Pooh hang back W/L equip. PU on string and move string w/ 82k UP wt. Load out SWS 12/18/2007 Break out and lay down landing jt and TIW Valve. Break out hanger. Reverse circulate 463 bbls, Pooh w/ 3.5" Production tbg. Monitor well for flow, well static. POOH standing back the top 90 jts and laying down the remainder of the 3-1/2" tubing. RIH to be able to POOH laying down the 90 jts. due to needing the extra room in the derrick. Pulled 415 jts + cut joint 17.18'. Well static. 00:00 00:30 0.50 COMPZ FISH ELNE P Continue to Load SWS 00:30 01:00 0.50 COMPZ RPCOM PULD P Break out and lay down landing jt and TIW Valve. Break out han er. 01:00 05:30 4.50 COMPZ RPCOM CIRC P RU to Reverse Circulate, Reverse circ 463 bbls 3.5 360 si. 05:30 06:00 0.50 COMPZ RPCOM OWFF P Monitor well for flow, well static. 06:00 00:00 18.00 COMPZ RPCOM RCST P POOH standing back the top 90 jts and laying down the remainder of the 3-1/2" RIH to be able to POOH laying down the 90 jts. due to needing the extra room in the derrick. Pulled 415 'ts + cut 'oint 17.18'. Page 2 €~f 9 I Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 2/19/2007 2a hr summary Continued to RIH w/ 45 stands(90 jts), POOH laying down to clear the derrick. Load and strap drill pipe into pipe shed. PU BHA for fishing 3.5" tubing stub. Drifted all tools to 2 1/8". Had trouble with some of Drill Collars drifting. Scale build up or drilling mud from last run. Picking up drill pipe and RIH.. Load and strap drill i e into i e shed. 00:00 05:00 5.00 COMPZ RPCOM RCST P Continued to RIH w/ 45 stands(90 jts), POOH laying down to clear the derrick. 05:00 11:00 6.00 COMPZ FISH PULD P Load and strap drill pipe into pipe shed. 11:00 14:30 3.50 0 250 COMPZ FISH PULD P PU BHA for fishing 3.5" tubing stub. Drifted all tools to 21/8". Had trouble with some of Drill Collars drifting. Scale build up or drilling mud from last run. 14:30 23:30 9.00 250 6,634 COMPZ FISH PULD P Picking up drill pipe and RIH. 23:30 00:00 0.50 6,634 6,634 COMPZ FISH PULD P Load and strap drill pipe into pipe shed. 12/20/2007 Continue to load and strap drillpipe into the pipe shed. Cut and slip drill line while loading pipe shed. PU and RIH w/drill pipe. Electrical problems with pipe skate. Blown relay in control panel. Replace relay. Shut down for Safety Awareness meeting. Discussed support and commitment to doing all jobs safely and in an evironmental responsible manner. Reviewed serious incidents that have occurred recently with ConocoPhillips, Nabors Drilling and proper pre-work, planning and preparation for preventing incidents. Continue to clean drill pipe free of snow and ice and RIH. RU Kelly and test. Kelly froze up, work on thawing Kell . 00:00 03:30 3.50 6,634 6,634 COMPZ FISH OTHR P Continue to load and strap drillpipe into the pipe shed. Cut and slip drill line while loadin i e shed. 03:30 07:00 3.50 6,634 9,147 COMPZ FISH PULD P PU and RIH w/drill pipe. 07:00 08:00 1.00 9,147 9,147 COMPZ RIGMNT RGRP T Electrical problems with pipe skate. Blown relay in control panel. Replace rela . 08:00 08:30 0.50 9,147 9,147 COMPZ RPCOM SFTY P Shut down for Safety Awareness meeting. Discussed support and commitment to doing all jobs safely and in an evironmental responsible manner. Reviewed serious incidents that have occurred recently with ConocoPhillips, Nabors Drilling and proper pre-work, planning and re aration for reventin incidents. 08:30 14:30 6.00 9,147 13,192 COMPZ RPCOM PULD P Continue to clean drill pipe free of snow and ice and RIH. 14:30 00:00 9.50 13,192 13,192 COMPZ RPCOM RURD P RU Kelly and test. Kelly froze up while above the wind walls during testin , be in work on thawin Kell . F'~r~~ 3 e~f 9 ' Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12/21/2007 2a hrSummarv Continue to thaw and test Kelly. Shut down for Safety Awareness meeting. Discussed support and commitment to doing all jobs safely and in an evironmental responsible manner. Reviewed serious incidents that have occurred recently with ConocoPhillips, Nabors Drilling and proper pre-work, planning and preparation for preventing incidents. PU & MU space out pups and Kelly. Dressed off tubing stub. Up wt. 155K and down wt. 52K Rotate over tubing stub while pumping at 2 8PM @ 300 psi. Lowered 13' and engaged fish with overshot. PU to 200K set jars off with 45K over. PU to 220K and came free. Up wt 165K, gained 10K and dragging. Monitor well for flow. Stand back Kelly. Pulled 20 space out pup. Blow down all lines. Install head pin. Circulate bottoms up 3.5 BPM W/850 psi. Blow down lines. POOH standing back12,000' of 3-1/2"drill pipe, laying down 1200'. OOH w/ no fish. Some wear and chips on shoe, grapple had some marks on the bottom but did not look like it had latched up. Swapped to a 5 3/4" hollow mill container w! 3112" insert, dro ed the lower extension, and installed a new ra le in the overshot. PU BHA and RIH. 00:00 02:30 2.50 13,192 COMPZ RPCOM RURD NP Continue to thaw and test Kelly. 02:30 03:00 0.50 COMPZ RPCOM SFTY P Shut down for Safety Awareness meeting. Discussed support and commitment to doing all jobs safely and in an evironmental responsible manner. Reviewed serious incidents that have occurred recently with ConocoPhillips, Nabors Drilling and proper pre-work, planning and re aration for reventin incidents. 03:00 05:00 2.00 COMPZ FISH PULD P PU & MU space out pups and Kelly. 05:00 07:00 2.00 COMPZ FISH FISH P Dressed off tubin stub. Up wt. 155K and down wt. 52K Rotate over tubing stub while pumping at 2 BPM @ 300 psi. Lowered 13' and engaged fish with overshot. PU to 200K set jars off with 45K over. PU to 220K and came free. Up wt 165K, gained 10K and dragging. Monitor well for flow. Stand back Kelly. Pulled 20 space out pup. Blow down all lines. Install head in. 07:00 10:30 3.50 13,192 13,192 COMPZ FISH CIRC P Circulate bottoms up 3.5 BPM W/850 si. Blow down lines. 10:30 22:00 11.50 13,192 0 COMPZ FISH PULD P POOH standing back12,000' of 3-1/2"drill i e, la in down 1200'. 22:00 23:00 1.00 0 0 COMPZ FISH PULD P OOH w/ no fish. Some wear and chips on shoe, grapple had some marks on the bottom but did not look like it had latched up. Swapped to a 5 3/4" hollow mill container w/ 3 1/2" insert, dropped the lower extension, and installed a new grapple in the overshot. 23:00 00:00 1.00 0 1,000 COMPZ FISH TRIP P PU BHA and RIH. 12/22/2007 Continue to RIH. Establish circualtion 3 BPM W/560 psi. Up wt 160K Dwn wt 45. Engaged fish in same spot 13,192'. Worked and jarred @ 250K pulling up to 275K for 1 hr with no movement. Attempted to unsrew the KBH-22 Ancbhor Seal Assy. for 1 hr with no progress. Released overshot and prepared for Eline them cut. Circulate Safe-Cube around for lubrication while rigging up SWS Eline. Held PJSM, arm and test chemical cutter. RIH w! chemical cutter began pumping SWS down the hole @ 3,000'. Pump rate 2.5 BPM @ 420 PSI. SWS unit broke down. Reduced um rate to 1 BPM 90 PSI while workin on SWS unit. 00:00 08:30 8.50 1,000 13,192 COMPZ FISH TRIP P Continue to RIH. ~'~ge 4 of 9 • Time Logs Da e From To Dur S De th E. De th Ph se Code Subco e T Comment 08:30 12:00 3.50 13,192 13,192 COMPZ FISH JAR P Establish circualtion 3 BPM W/560 psi. Up wt 160K Dwn wt 45. Engaged fish in same s of 13,192'. Worked and jarred @ 250K pulling up to 275K for 1 hr with no movement. Attempted to unsrew the KBH-22 Ancbhor Seal Assy. for 1 hr with no progress. Released overshot and re ared for Eline 12:00 18:00 6.00 13,192 13,192 COMPZ FISH ELNE P Circulate Safe-Cube around for lubrication while rigging up SWS Eline. 18:00 20:30 2.50 13,192 13,192 COMPZ FISH ELNE P Held PJSM, arm and test chemical cutter. 20:30 23:30 3.00 13,192 13,192 COMPZ FISH ELNE P RIH w/ chemical cutter began pumping SWS down the hole @ 3,000'. Pump rate 2.5 BPM @ 420 PSI. 23:30 00:00 0.50 13,192 13,192 COMPZ FISH ELNE T SWS unit broke down. Reduced pump rate to 1 BPM @ 90 PSI while workin on SWS unit. 12/23/2007 Continue to circulate at 1 BPM @ 90 PSI while still working on the SWS unit. Continue to RIH w/SWS while puming at 1 BPM. Shut down pump and blew down lines prior to tie in and cut. No indications of previous cut with CTU. Cut made @ 14,207, good confirmation in logging unit and on the rig floor. Tubing was set in slips w/ 10K over pull. POOH with eline and chem. cut tools. Stuck when coming off bottom. Set off jars once. Pulled up to 13,200' stuck again, pressured up tubing/IA to 1500 psi to help relax gun anchors. Worked through the BHA and no further problems, bleed off pressure and continue to POOH. Set all SWS equipment aside on rig floor. Latch onto drillpipe and PU. Staight pull up, everything appeared to be loose. Up wt 120K Dwn wt 62K. LD two 20' pups. Complete RD of SWS equipment. POOH standing back 12,000' drillpipe, laying down 1200'. Pulling smooth, no drag. OOH w/ workstring, continue to POOH laying down fish. OOH w/ fish, 1 cut jt., 28 full jts, and bottom cut jt. 19.24'. Clean cut. Prepare for and begin BOPE test. State witnessed test waived b Chuck Sheve 07:00 12!22!07 er hone conversation. 00:00 02:30 2.50 13,192 131,392 COMPZ FISH ELNE NP Continue to circulate at 1 BPM @ 90 PSI while still working on the SWS unit. 02:30 04:00 1.50 13,192 13,192 COMPZ FISH ELNE P Continue to RIH w/SWS while puming at 1 BPM. Shut down pump and blew down lines prior to tie in and cut. No indications of previous cut with CTU. Cut made ~ 14.207. good confirmation in logging unit and on the rig floor. Tubing was set in sli s w/ 10K over ull. 04:00 08:00 4.00 13,192 14,207 COMPZ FISH ELNE P POOH with eline and chem. cut tools. Stuck when coming off bottom. Set offjars once. Pulled up to 13,200' stuck again, pressured up tubing/IA to 1500 psi to help relax gun anchors. Worked through the BHA and no further problems, bleed off ressure and continue to POOH. 08:00 09:00 1.00 14,207 14,207 COMPZ FISH PULL P Set all SWS equipment aside on rig floor. Latch onto drillpipe and PU. Staight pull up, eve thin a eared to be loose. Up wt 120K Dwn wt 62K. LD two 20' pups. Complete RD of SWS a ui ment. ~~r~e 5 t~f 9 Time Logs Date From To Dur S. De th E. D th Phase Code Subcode T Comment 09:00 23:00 14.00 14,207 0 COMPZ FISH PULL P POOH standing back 12,000' drillpipe, laying down 1200'. Pulling smooth, no drag. OOH w/ workstring, continue to POOH laying down fish. OOH w/ fish, 1 cut jt., 28 full jts, and bottom cut jt. 19.24'. Clean cut. 23:00 00:00 1.00 COMPZ WELCTL BOPE P Prepare for and begin BOPE test. State witnessed test waived by Chuck Shevey @ 07:0012/22/07 per hone conversation. 12/24/2007 Continue BOPE test. State witnessed test waived by Chuck Shevey @ 07:00 12/22/07 per phone conversation. Continue BOPE test. State witnessed test waived by Chuck Shevey @ 07:00 12/22/07 per phone conversation. Held PJSM, PU completion BHA and RIH on 3 1/2" drill pipe. Locate tubing stub. Install head pin. Spot CI brine (1% by volume Baker Petrolite CRW-132) by pumping 35 bbls and follow with 105 bbls to get on spot. Set and spaced out 1', drop ball & rod, attemted to pump it down, no success. Pump rate 2.5 BPM @ 480 psi. Ball & Rod is 6' long, w/ 1.38" fish neck, 1 5/16" ball on bottom w/ 2 sets of fins w/ 1.5" OD. 00:00 03:30 3.50 COMPZ WELCTL ROPE P Continue ROPE test. State witnessed test waived by Chuck Shevey @ 07:00 12/22/07 per phone conversation. 03:30 19:30 16.00 0 14,173 COMPZ RPCOM RCST P Held PJSM, PU completion BHA an RI 19:30 22:00 2.50 14,173 14,206 COMPZ RPCOM CIRC P Locate tubin stub. Install head pin. Spot CI brine (1 % by volume Baker Petrolite CRW 132) by pumping 35 bbls and follow with 105 bbls to get on s ot. 22:00 00:00 2.00 COMPZ RPCOM PACK P Set and spaced out 1', drop ball & rod, attemted to pump it down, no success. Pump rate 2.5 BPM @ 480 psi. Ball & Rod is 6' long, w/ 1.38" fish neck, 1 5/16" ball on bottom w/ 2 sets of fins w/ 1.5" OD. 12/25/2007 Could not pump ball & rod down to set packer. Stand by for HES slickline unit to push it to bottom. Held PJSM, RU and RIH w/ HES. Tag fish @ 9320' WLM and pushed to bottom @ 14,173' WLM. Ran 20' of 1 1/2" roller stem w/ knuckle every 5', oil jars, long stroke spanges, and 2" LIB. LIB had good impression of the ball & rod fish neck., POOH. Finished rigging down HES while setting packer. Pressured up to 2500 psi and held for 10 minutes. Good test, sheared PBR @ 170K, 44K over. Center of packer elements is 14,190'. POOH laying down drill pipe, laid down Kelly. Up wt. 126K. Ball & Rod is 6' long, w/ 1.38" fish neck, 1 5/16" ball on bottom w/ 2 sets of fins w/ 1.5" OD. 00:00 03:30 3.50 COMPZ RPCOM SLKL T Could not um ball & rod down to set packer. Stand by for HES slickline unit to push it to bottom. Ball & Rod is 6' long, w/ 1.38" fish neck, 1 5/16" ball on bottom w/ 2 sets of fins w/ 1.5" OD. 03:30 11:00 7.50 COMPZ RPCOM SLKL T Held PJSM, RU and RIH w/ HES. Tag fish @ 9320' WLM and pushed _ to bottom an. 14,173' WLM.. Ran 20' of 1 1/2" roller stem w/ knuckle every 5', oil jars, long stroke spanges, and 2" LIB. LIB had good impression of the ball & rod fish neck., POOH. Page 8 of 9 • • Time Lois _ D e_ From To Dur 5 De th E. De th Ph e Code Sub T Comment code 11:00 12:00 1.00 COMPZ RPCOM _ _ PACK _ P Finished rigging down HES while setting packer. Pressured up to 2500 si and held for 10 minu Good test, sheared PBR @ 170K, 44K over. Center of packer elements is -14,190'. 12:00 00:00 12.00 COMPZ RPCOM PULD P POOH la in down drill i e laid down Kell . U wt. 126K. 12/26!2007 Continue to POOH laying down drill pipe. OOH w/ SBR. Pull wear ring, take Kelly apart and lay down, prepare to run new completion. PU and run new completion string. At 12:00 100 JTS in hole. Up WT = 32K displacement normal. 18:00 Joint 250 well conditions stable. Load, strap, and drift the last 150 jts of tubing 21:00- 22:30. Continue to RIH w/ com letion. 00:00 08:00 8.00 COMPZ RPCOM PULD P Continue to POOH laying down drill pipe. OOH w/ PBR Seal ASSY. Pull wear ring, take Kelly apart and lay down, prepare to run new com letion. 08:00 00:00 16.00 COMPZ RPCOM PULD P PU and run new completion string. At 12:00 100 JTS in hole. Up WT = 32K displacement normal. 18:00 Joint 250 well conditions stable. Load, strap, and drift the last 150 jts of tubing. Continue to RIH w/ com letion. 12/27/2007 Continue to RIH w/ new completion string. Tag PBR and rotate in. Spaced out 2', installed 10.01 pup, and tubing FMC tubing hanger. Spot 35 BBL inhibited 9.6# brine.(1 % by volume Baker Petrolite CRW 132) Land tubing with some difficulty. Having to set 15-20K down to sting into PBR. Unable to test tubing to 2,500 PSI with success. Combo MIT is good to 2,500 PSI. Tubing leak off is linear with returns to surface. Attemp to flush PBR with 300 PSI on tubing while PUH after ROLDS. Re-engage PBR \RILDS and test tubing to 2,500 PSI. Upon re-entry to PBR no down WT needed. Slid right in. Still have linear leak off. Call for wireline unit to assist in trouble shootin .Held PJSM, PU and RIH w/HES slickline with a standin valve. 00:00 04:00 4.00 COMPZ RPCOM RCST P Continue to RIH w/ new completion strip . 04:00 07:00 3.00 COMPZ RPCOM HOSO P Tag PBR and rotate in. Spaced out 2' installed 10.01 pup, and tubing FMC tubin hap er. 07:00 09:00 2.00 COMPZ RPCOM CIRC P Spot 35 BBL inhibited 9.6# brine.(1% b volume Baker Petrolite CRW-132 09:00 18:00 9.00 COMPZ RPCOM HOSO T Land tubin with some difficulty. Having to set 15-20K down to sting into PBR. Unable to test tubing to 2 500 PSI with success. Combo MIT is good to 2,500 PSI. Tubin leak off is linear with returns to surface. Attemp to flush PBR with 300 PSI on tubing while PUH after ROLDS. Re-engage PBR \RILDS and test tubing to 2,500 PSI. Upon re-entry to PBR no down WT needed. Slid ri ht in. Still have linear leak off. Call for wireline unit to assist in trouble shootin . 18:00 00:00 6.00 COMPZ RPCOM SLKL T Held PJSM, PU and RIH w/HES slickline with a standin valve. ~ ~ Page 7 of 9 • Time Logs ' _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment _ 12/28/2007 2a hr summary Continue to RIH wl HES slickline, running a standing valve for a pressure test. Set standing valve in the DS nipple, pressured tested tubing to 2,500 psi and held for 15 mins., held solid. POOH w/ standing valve and pressure tested tubing again to 2,500 psi, would not hold. RIH @ 05:00 w/HES slickline w/ LIB to tag and drift to seal assembly/PBR section. No marks on LIB. Rig down HES prepare to pull hanger to floor. Pull hanger to floor. Remove hanger replace with 10' pup for working room. Pick up landing joint and work seals several times. Confirm seal bore length by pressuring tubing to 700 PSI / PUH for pressure bleed off. Note pressure fall off after 11.5'. Sting back into seals compress with 20K WT. Pressure test tubing 2,500 PSI. Not charted but witnessed to bleed off 20 PSI 15 Min. Bleed off pressure leave 700 PSI while PUH to purge seals again. Sting back into PBR and perform space out. Space out measurements same as initial. Stand back landing joint, lay down 10' pup, install hanger. Land tubing as initial. Pressure test tubing to 2,500 PSI. Passed! Bleed pressure to 1,750 PSI, pressure test IA to 2,500 PSI. Passed! Shear SOV. Install BPV, ni le down BOPE. 00:00 09:00 9.00 COMPZ RPCOM SLKL T Continue to RIH w/HES slickline, running a standing valve for a pressure test. Set standing valve in the DS ni le ressured tested tubing to 2,~50~si, and held for 15 mins., held solid. POOH w/ standing valve and pressure tested tubing again to 2,500 psi, would not hold. RIH @ 05:00 w/HES slickline w/ LIB to tag and drift to seal assembly/PBR section. No marks on LIB. Rig down HES prepare to ull han er to floor. 09:00 14:00 5.00 COMPZ RPCOM HOSO T Pull han er to floor. Remove hanger replace with 10' pup for working room. Pick up landing joint and work seals several times. Confirm seal bore len th b ressurin tubi 700 PSI /PUH for ressure bleed off. Note pressure fall off after 11.5'. Sting back into seals compress with 20K WT. Pressure test tubing 2,500 PSI. Not charted but witnessed to bleed off 20 PSI 15 Min. Bleed off pressure leave 700 PSI while PUH to purge seals again. Sting back into PBR and perform space out. Space out measurements same as initial. Stand back landing joint, lay down 10' pup, install hanger. Land tubing as initial. Pressure test tubing to 2,500 PSI. Passed! Bleed pressure to 1 750 PSI ressure test IA to 2 500 PSI. Passed! Shear SOV. 14:00 15:00 1.00 COMPZ RPCOM NUND P Install BPV nipple down ROPE. 12/29/2007 Continue to ND BOPE's, NU tree, pull BPV, and install test plug. Tested tree and packoffs to 5,000 psi. All pressure tests were good. Pulled test plug and installed BPV. Wrapped tree w/ visqueen and put a heater on it. Released ri 06:00 on 12/29/07. Page 8 of 9 • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 COMPZ RPCOM NUND P Continue to ND BOPE's, NU tree, pull BPV, and install test plug. Tested tree and packoffs to 5,000 psi. All pressure tests were good. Pulled test plug and installed BPV. Wrapped tree w/ visqueen and put a heater on it. Released ng Ccil 06:00 on 12/29/07. Page 9 crt 3 2A-22 Well Events Summary . DATE SUMMARY 11/13/07 Perform logging run prior to tubing chemical cut. RIH to tag @ 14198 CTMD, Corrected depth, Flagged pipe @ 14201 RKB. Logged tubing from tag to 13000 RKB. Well freeze protected. Will return in A.M. for tubing cut. 11/14/07 COIL TUBING DEPLOYED CHEMICAL CUT 14201'. ~~ r` 11/14/07 Perform tubing chemical cut Cad 14201 RKB, Performed successful CMIT, displaced tubing & IA with 540 bbls 9.6 bine. Freeze protected tree. 2/2/08 GAUGED TBG TO 2.75" & TAGGED FILL IN TBG ~ 14127' WLM. PULLED SHEARED SOV @ 12961' RKB. IN PROGRESS. 2/3/08 DISPLACED CSG &TBG WITH 460 BBL DSL. SET DV @ 12961' RKB. MIT IA, PASSED. ~~~~~ ~ IN PROGRESS. 2/4/08 BAILED FILL ON BALL & ROD FROM 14125' TO 14136' WLM. IN PROGRESS. 2/5/08 BAILED FILL ON BALL & ROD FROM 14134' TO 14140' WLM. IN PROGRESS. 2/6/08 BAILED FILL ON BALL & ROD FROM 14137' TO 14140' WLM. IN PROGRESS. 2/7/08 SET SLIPSTOP CATCHER ~ 14110' WLM. REPLACED DV WITH OV @ 14115' RKB. IN yPROGRESS. 2/8/08 PULLED DVs @ 12961', 10741', 7522' RKB. SET GLV @ 12961' RKB. IN PROGRESS. 2/9/08 SET GLVs @ 10741', 7522' & 3646' RKB. ATTEMPTED PULL CATCHER. IN PROGRESS. 2/10/08 PULLED SLIPSTOP CATCHER _ 14110' WLM. READY FOR CTU. 2/11/08 Perform Mud Cleanout, Jetted down to tag of 14168 CTMD. Well is displaced with diesel. Turned over to slickline. 2/12/08 PULLED BALL & ROD Cc~ 14147' WLM. IN PROGRESS 2/13/08 BAILING ON RHC PLUG BODY @ 14196' RKB. IN PROGRESS 2/14/08 BAILING ON RHC PLUG BODY @ 14196' RKB. IN PROGRESS 2/15/08 BAILED ON & PULLED RHC PLUG BODY. IN PROGRESS 2/16/08 BAILED TRASH & FILL ON CA-2 BLANKING PLUG @ 14242' RKB, IN PROGRESS 2/21/08 PERFORM REVERSE FCO DOWN TO TOP OF BLANKING PLUG @ 14215' CTMD / 14238' RKB.HAD GOOD 1 FOR 1 RETURN WITH HEAVY SOLIDS IN RETURNS.LEFT WELL SHUT IN AND LOADED WITH DIESEL FOR SLICKLINE TO PULL CA-2 PLUG.JOB COMPLETE. 2/23/08 BAIL FROM 14,181' SLM TO 14,213' SLM. MARKS ON BAILER INDICATING WE'RE POSSIBLY AT PLUG. IN PROGRESS. 2/24/08 ATTEMPT TO PULL CA-2 PLUG @ 14,242' RKB. UNABLE TO GET PULLING TOOL INTO TUBING STUB @ 14,179' SLM. IN PROGRESS. 2/25/08 MADE ATTEMPT TO ENTER TOP OF STUB W/ 2.75/2.50 DECENTRALIZED MULESHOE, UNABLE TO ENTER STUB. RAN BLB & VERIFIED NIPPLE DEPTH FOR CORRECTION. RAN 2.70" LIB TO 14,178' SLM; RATTY IMPRINT OF DEBRIS OR POSSIBLE TUBING STUB. IN PROGRESS. 2/26/08 TAGGED DS NIPPLE @ 14162' RKB, 14117' SLM. RAN 2.70" LIB TO 14178' SLM, APPARENT TBG STUB. LOGGED PDS CALIPER FROM 14178' SLM TO 13700' SLM; DATA GOOD. JOB SUSPENDED. 3/18/08 RUN DEPTH AND JEWELRY DETERMINATION LOG. RESULTS: TAGGED AT 14218'. THIS IS 8' OUTSIDE THE POOR BOY OVERSHOT. 3/20/08 RAN A MULTI FINGER CALIPER -PMIT-A. TOOLS SAT DOWN AT 14251'. LOGGED PMIT FROM 14245' TO 14040'. FOUND AN 8' GAP BETWEEN THE POOR BOY OVERSHOT AND THE TBG STUB. 4/23/08 TAGGED CA-2 BLANKING PLUG @ 14242' RKB WITH 1-3/4" SAMPLE BAILER. TAGGED TBG STUB @ 14161' SLM AND EQUALIZING PRONG @ 14198' SLM WITH 1-3/4" LIB. ATTEMPTED PULL PRONG. SET DOWN 1' HIGH WITH MOD P/T; SET DOWN 6' HIGH WITH BOWEN SPEAR. IN PROGRESS. 4/24/08 ATTEMPTED PULL CA-2 PLUG @ 14242' RKB; UNSUCCESSFUL. TAGGED PLUG WITH 1-3/4" SAMPLE BAILER. UNABLE TO ENTER TBG STUB WITH PULLING TOOL. IN PROGRESS. 4/25/08 CONTINUED ATTEMPT TO PULL CA-2 @ 14242' RKB. IN PROGRESS. 4/26/08 CONTINUED ATTEMPT TO PULL CA-2 @ 14242 RKB. IN PROGRESS. . 2A-22 Well Events Summary • 4/27/08 CONTINUED ATTEMPT TO PULL CA-2 @ 14242' RKB. PULLED BIND ON EQ-PRONG WITH SPEAR LOST 1.06" OD GRAPPLE FROM SPEAR. IN PROGRESS. 5/23/08 ATTEMPTED TO PERFORATE TUBING JOINT ABOVE CA-2 PLUG WITH HES RCT TUBING PUNCH. UNABLE TO ENTER TOP OF TUBING STUB, TAGGING CONTINUALLY AT 14229'. PLAN FORWARD INCLUDES MODIFICATION OF BHA TO INCLUDE BOW-SPRING CENTRALIZER AND SPEAR. ((IN PROGRESS)) 5/26/08 ATTEMPTED AGAIN TO PERFORATE TUBING JOINT ABOVE CA-2 PLUG WITH HES RCT TUBING PUNCH MODIFIED TO ACCOMODATE BOW-SPRING CENTRALIZER AND SPEAR. STILL UNABLE TO ENTER TOP OF TUBING STUB, TAGGING CONTINUALLY AT 14229'. CURRENTLY EVALUATING ADDITIONAL TOOL AND CENTRALIZATION OPTIONS. 5/31/08 ATTEMPTED TO PUNCH TUBING, COULD NOT WORK TOOLS PAST 12,300', TOOLS BACK AT SURFACE COVERED IN METAL SHAVINGS -PLAN FORWARD INCLUDES MODIFYING TOOLSTRING, RE-ATTEMPT IN THE A.M. 6/1/08 TUBING PUNCH BETWEEN SAB-3 PACKER AND CA-2 PLUG IN TUBING STUB, 9 SHOTS WITH ENTRANCE HOLE OF 0.19", WHP: BEFORE 700 PSI /AFTER 950 PSI, IA: .BEFORE 430 PSI /AFTER 450 PSI ABLE TO GET INTO TUBING STUB WITH OUT A PROBLEM ~ /~~* KRU 2A-22 ( Ct~nt~~pPhillip~ 1~las~ca, (rr. -- 2A-22 _ _ - - API: 501 t1320`l21 W Well T e: PROD An le d~ TS: 5`L de a) 14257 TuewG SSSV Type: NIPPLE Orig 6/11/1995 Angle @ TD: 51 deg @ 14797 (o-141ss, oD:3.5o0, Com letion: ID:zssz) ~ Annular Fluid: Last W/O: 12/29/2007 Rev Reason: WORKOVER NIP ~ 'I~# :14196-14198, OD:4.520) SEAL ~ ~ - "t ;14226-14227, TUBING ;14198-14265, - OD:3.500, ID:2.992) sos lazsa-142ss, OD:3.500) ~--- Perf X14302-14317) ~~ FRAC ;14302-14378) , Perf X14330-14348) PROD CASING (0.14698, OD:7.000, Wk26.00) Perf ,14352-14378) Reference Lo .Ref Lo Date: Last U date: 12/29/2007 LastTa 14314'RKB TD: 14797ftK6 Last Tag Date: 5/21/2005 Max Hole Angle• 76 deg fad 4190 Casing String -ALL STRINGS Descrl tlon Slze To Bottom TVD V1It Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SURF CASING 9.652 0 4928 2937 40.00 L-80 PROD CASING 7.000 0 14698 6082 26.00 L-80 Tubing String-TUBING Slze To Bottom TVD VUt Grade Thread 3.500 0 14198 5772 9.30 L-80 8RD EUE ABM 3.500 - 14198 14265 5812 9.30 L-80 8RD EUE ABM _ _ Perforations Summary _ Interval TVD Zone Status Ft SPF Date T Comment 14302 - 14317 5835- 5844 C-4 15 4 6/28/2000 APERF 2 1/2" HSD DP, 180 de h 14330 - 14348 5852 - 5864 C-4 18 4 8/17/2001 APERF 2.5" HSD Alternating BH/PJ, 180 de hase 14352 - 14378 5866- 5882 A-3 26 4 6/12/1995 IPERF SWS TCP Type BH UP; 180 deg ph; oriented 90 - ---- _ - CCW flhighside SUrrtulatiuns & Treatments ~, Interval __ Date T e - - _. Comment 14302 - 14378 12/9/2002 FRAC A/C SAND FRAC W/221,728# OF 16/20 PROPPANT _._ _ _ - -- BEHIND PIPE W/10 PPA ON PERFS_ Gas Lift MandrelsNalves I ~ I MD TVD --- Man Mfr I Man Type I V _ --- - Mfr I V Type I V OD I Latch I Port I TRO I Date Run i Vlv 5 1141151 _ 57231 CAMCO I KBMG_ I _ I DMY I 1.0 I BK-5 10.000 10 112/28/20071_ )ther (pl-ups, equip., etc.).- COMPLETION ~e h TVD T e Descn tlon ID 501 501 NIP CAMCO DS LANDING NIPPLE 12/28/2007 2.875 14162 5750 NIP CAMCO DS NIPPLE 12/28/2007 2.813 14168 5754 SEAL BAKER PBR 80-40 SEAL ASSEMBLY 12/28/2007 2.970 14185 5764 PACKER BAKER'FHL' RETRIEVEABLE PACKER 12/28/2007 2.970 14196 5771 NIP HALLIBURTON'X' NIPPLEw/RHC PLUG-BALUROD 12/28/2007 2.813 14264 5812 SOS SWS'SXAR' 2.992 14265 5812 TTL ELMD (a7 14258' ON SWS PERF 8/17/2001 2.992 Osneral Notes ~~i~~~ill~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~. ~P~ ~ ~~ ~~ Log Description ~~ ~i NO. 4650 Company: Alaska Oit & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04!08/08 1A-19 12031469 LEE TOOL PROD PROFILE 03/21/08 1 iF-07 12031470 PROD PROFILE r ~'~-'~ 03/22/08 1 3A-09 11980648 PROD PROFILE ~ ~4 03/22/08 1 2q-22 11970645 MULTI-FINGER CALIPER _ 03/20/08 1 iF-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 iG-09 11996613 INJECTION PROFILE V = 04/05/08 1 iJ-159 11994646 GLS (o- 04/06/08 1 2W-15 11996615 PRODUCTION PROFILE --a 04107/08 1 1L-08 11996616 PRODUCTION PROFILE L 04!08/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • /~ 1/~~~L Lo ~~. ProActive Diagnostic 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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1) Caliper Report 2) 26-Fe1r08 2A 22 1 Report / EDE 50-1 03-2022 1-00 ~~~ ~~ ~ ~ ~Q~~ Signed Print Name: 1 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907245-88952 E-MAIL : ~dsancS~orage(a~memorylog.com WEBSITE : www.memorvfoq corn C:\Documen6 and SetEngs\Owne~\Desktop\Tmnsmit_Conow.doc • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-22 Log Date: February 26, 2008 field: Kuparuk Log No.: 8865 State: Alaska Run No.: 2 API No.: 50-103-20221-00 Pipet Desc.: 3.5" 9.3 !b. L-80 Top Log Intvl1.: 13,739 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 14,190 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This log is tied into the bottom of the Camco DS Nipple @ 14,162' (Driller's Depth). This log was run to assess the condition of the bottom of the 3.5" tubing with respect to corrosive and mechanical damages. This is the second time a PDS caliper has been run in this well and the first time this interval of 3.5" tubing has been logged. The interval of 3.5" tubing fogged appears to be in good condition, with no significant wall penetrations (> 11%} recorded. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the interval of 3.5" tubing logged. A detailed 3-D log plot of the interval logged is included in this report. A tool hang up in GLM 7 resulted in a loss of coverage of the pup joint above the mandrel. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 11°~} are recorded throughout the 3,5" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significan# I.D. restrictions are recorded throughout the 3.5" tubing logged. Field Engineer: K. Miller Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. J 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 I~ 5 -~~ ~ ~~ G~ • PDS Multifinger Caliper 3D Log Plot ~ .~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-22 Date : February 26, 2008 Description : Detail of Caliper Recordings From 13,800' To 14,247' • 13890 13900 Joint 439 13910 13920 13930 Joint 440 13940 13950 13960 Joint 441 13970 13980 13990 Joint 442 14000 14010 14020 Joint 443 14030 14040 14050 • PDS Report Overview ~~, S. Body Region Analysis Wefl: 2A-22 Survey Date: February 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 ppf L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body metal loss body 20 10 0 0 to 1 to 10 to 20 ro 40 ro over 1% 1D% 20% 40% 85% 85% Number of 'oints anal sed total = 14 pene. 0 11 3 0 0 0 loss 2 12 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 434 444 GLM 5 u'~~ Bottom of Survey = 446.5 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 2A-22 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 26, 2008 Joint No. jt. Depth (Ft.) I'en. Utx~t (In.) Pen. Body (Ins.) I'c~n. °i~> Vle~t,~l I oss `;~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 434 13739 (~ 0.02 6 u 0.00 43 13762 O 0.02 `~ 1 U 2.96 436 13793 t) 0.0 I I ~ 2.96 437 13824 !) 0.03 I U t, 2.95 438 13856 U 0.02 ~) ') 2.9 439 13887 O 0.02 ~) (~ 2.94 440 13919 a 0.02 7 1 U 2.94 441 13950 U 0.03 11 6 .97 442 13981 U 0.03 I1 l 2.96 443 14013 ~) 0.02 t3 ~~ 2.95 444 14045 Q 0.02 9 r, 2.95 445 14076 l) 0.02 7 - 2.97 445.1 14108 to 0 U ~) N A PUP-Han U 44 .2 14115 u 0 t) ~ ~ N A LM 5 Latch ~ 12:30 445.3 14121 t_i 0.01 5 I 2.89 PUP 446 14130 U 0.02 ~ c ~ 95 446.1 14161 U 0 l) i! 2.81 Camc DS Ni le 446.2 14163 l) 0. 1 5 U 2.95 PUP 446.3 14168 ' ~ 0 U i ~ 2. 7 Seal Assemb -Han U 446.4 14174 i ~ 0 U i ~ 4.03 PBR 80-40 446.5 14188 ! ~ 0 0 ~ ~ 2.97 Packer Penetration Body Metal Loss Body Page 1 ConacoPhillips Alaska, Inc. KRU 2A-22 za n API: 501032022100 Well T : PROD An le TS: 52 d 14297 TUBING 1a1a19s, oD:3 5o0 SSSV Type: NIPPLE Orig Com k:tion: 6/11!1995 Angle @ TD: 51 deg @ 14797 . . ID:2.ss2) Annular Fluid: Last W/O: 1229/2007 Rev Reason: GLV GO Reference L Ref L Date: Last U ate: 2212008 Last Ta : 14314' RKB TD: 14797 ftK6 Lest Ta Date: 5/212005 Max Hole An le: 76 d 4190 Cesin Stri - ALL S RI GS eccri lion S' a To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SURF CASING 9.652 0 4928 2937 40.00 L-80 PROD CASING 7.000 0 14698 6082 26.00 L-80 Tubin Strin -TUBING Size To Bottom ND Wt Grade Threed 3.500 0 14198 5772 9.30 L-80 8RD EUE ABM 3.500 14198 14265 5812 9.30 L-80 8RD EUE ABM Perforations Summa n erval TVD Z ne Statua Ft SPF Date T e Comment 14302 - 14317 5835 - 5844 C-4 15 4 6/28/2000 APERF 2 12" HSD DP 180 d h 14330 - 14348 5852 - 5864 C-4 18 4 8/172001 APERF 2.5" HSD Alternating BH/PJ, 180 d hale 14352 - 14378 5866 - 5882 A-3 26 4 6/12/1995 IPERF SWS TCP Type BH UP; 180 deg ph; oriented 9D CCW f/hi hside ~ I Stimulations & Treatments Interval Date T Comment 14302 - 14378 12/9/2002 FRAC A/C SAND FRAC W/221,728# OF 16/20 PROPPANT BEHIND PIPE W/10 PPA ON PERFS Ga s Lift M andr elsNaly 9t MD ND Man Mfr Men Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3646 2583 CAMCO KBMG GLV 1.0 BK-5 0.125 1275 2/92008 2 7522 3698 CAMCO KBMG GLV 1.0 BK-5 0.156 1294 2/9/2008 3 10741 4601 CAMCO KBMG GLV 1.0 BK-5 0.156 1278 2/9/2008 4 12961 5255 CAMCO KBMG GLV 1.0 BK-5 0.188 1296 2/82008 5 141 15 5723 CAMCO KBMG OV 1.0 BK-5 0.188 0 2/7/2008 Oth er s ui .et c. -COMP TION De th TVD T Descri Lion ID 501 501 NIP CAMCO DS LANDING NIPPLE 12/28/2007 2.875 14162 5750 NIP CAMCO DS NIPPLE 12/282007 2.813 NIP 14168 5754 SEAL BAKER PBR 80-40 SEAL ASSEMBLY 12/28/2007 2.970 14196-14198, aD:a s2a) 14185 5764 PACKER BAKER 'FHL' RETRIEVEABLE PACKER 12/28/2007 2.970 . 14196 5771 NIP HALLIBURTON 'X' NIPPLE w/RHC PLUG-BALL/ROD 12282007 2.813 14198 5772 Poor Boy OVOrSfIOt BAKER POOR BOY OVERSHOT 12282007 2.992 SEAL ta2zs-14227 14226 5789 SEAL Baker'KBH-22' Anchor Seal Assembl 2.984 oD:3.5ta) 14227 5789 PKR Baker'SAB-3' 3.250 14242 5798 NIP Camco'D' Landin 2.750 TUBING 14242 5798 PLUG CA-2 BLANKING PLUG set 6/42006 0.000 1a1sa1a2s5, 14264 5812 SOS SWS'SXAR' 2.992 oD:3.soo, ID 2 992 14265 5812 TTL ELMD 14258' ON SWS PERF 8/172001 2.992 : . ) Gen r al Note s S Dete Note ia2sa-i z~ 2281 200 NOTE: ***WARNING*** CHEMICAL CUTTER DEBRIS ON TOP OF PLUG 14242' C0:3.500) Pert 14302-14317) FRAC 143014378) /, Pert 14330-14348) PROD CASING ta1a69a, oD:7.oo0, wt:2s.oo> Pert 14352-14378) ~~ I ~ i ~ • ~_._ ~ .-.~~ ~- ~ . ~- ~~1 'ter Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~ ti ~~~ ~ ~ ~~.~ Dear Mr. Maunder: • Enclosed please find a spreadsheet with a Iist of well's"from the`Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant ~ op-off Report of Sundry Operations (10-404) Date Kuparuk Field V1/ell Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-01 184-057 SF na SF na 1.5 12/14!2007 2A-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12/14/2007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-OF~7 SF na SF na 5 12/5/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12/14/2007 2A-08 185-248 SF na SF na 3 1215/2007 2A-09 186-001 SF na SF na 1..75 12/14/2007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12!5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12/14/2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12/14/2007 2A-21 193-133 5' 0.7 18" 9/24/2007 3 12/5/2007 2A-22 195-U6$. 39" na 39" na 7.5 12/14/2Q07 2A-23 193-142 SF na SF na 2 12/5/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 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) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) 2A - 22 20-Oct~6 Caliper Report ¡0-S- -o0~ -:t 14(31) f..); --', (:.;' ,;.-L (2jL C,h rì-<.-M IA;:7 Ih Q f¡z M kl2 0 Signed: Print Name: ~~ (')\ ¡ -ì ¿1 '.\ ;.,,--";,/'~ JUO Date : PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~ -,=còA ';;J:'.~c,3,=C'D.¡i;:i'.,i·"\"··"_.·.·3,::::".: WEBSITE: '''l·i\r,1J,·.i;:i:':;2·fL:>;~.:>:] 0;\00_ POSANC-2006\Z _ W ord\Distribution\Trnnsuùttal_ Sheets\Trnnsuùt_ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 20, 2006 8065 1 3.5" 9.3 lb. L-80 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 2A-22 Kuparuk Alaska 50-103-20221-00 Surface 10,220 Ft. (MD) Inspection Type: COMMENTS: Co"osive & Mechanical Damage Inspection This log is tied into the top of gas lift mandrel station 4 @ 9,912' (Driller's Depth). This log was run to assess the condition of the casing with respect to corrosive and mechanical damages. The 3.5" tubing appears to be in good to poor condition. A possible hole is recorded in joint 182 (5,800'). Wall penetrations from 20% to 84% are recorded from 4,000' to -8,200'. The damage appears in the form of lines of corrosion and bands of general corrosion on the low side. No significant areas of cross-sectional ' wall loss or 1.0. restrictions are recorded throughout the 3.5" tubing logged. Cross-sectional drawings of the most significant damage are included in this report. A temporary tool malfunction from 6,734' to 7, 261'resulted in a loss of interpretable data over this interval. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole! Corrosion Line Corrosion Line Corrosion Line Corrosion ( 90%) ( 84%) ( 83%) ( 75%) ( 72%) Jt. Jt. Jt. Jt. Jt. 182 @ 181 @ 189 @ 180 @ 194 @ 5,800 Ft. (MD) 5,765 Ft. (MD) 6,013 Ft. (MD) 5,734 Ft. (MD) 6,177Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 12%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the 3.5" tubing logged. I Field Engineer: R. A. Richey Analyst: M. Lawrence Witness: C. Fitzpatrick I PDSi(jTne:nOry¡o,],cRE C E IVE 0 Iq5--()(o~ 1f: 1'-1;)3"ð NOV 1 4 Z006 Alaska 011 & Gas Cons. eommission Anchorage I I I I I I I I I I I I I I I I I I ---------------- - ----------- Pipe 1 GlM 2 4776 '- QJ ..D .:t E :::¡ c z 6341 ..c ...., Q. c QJ 0 0 GlM 3 7953 Correlation of Recorded Damage to Borehole Profile 3.5 in (10.7' - 10209.4') Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA October 20, 2006 Approx. Tool Deviation Approx. Borehole Profile GLM 1 GlM 4 50 Damage Profile (% wall) I Tool Deviation (degrees) Bottom of Su rvey 321 14 1580 3180 9525 10209 100 I I I Well: Field: Company: Coun try: 2A-22 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread l-80 I Penetration ami Metal loss ('Yo wall) I penetration body metal loss body I 300 250 200 150 100 50 o 10 to 20 to 40 to over 20% 40% 85% 85% I o to 1% 1 to 10% I I 1 o pene. loss I Damage Configuration ( body) 80 I 60 40 I 20 o I isolated general line ring hole / poss pitting corrosion corrosion corrosion ¡ble hole I I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.992 ins October 20, 2006 UW MFC 24 No. 212330 1.69 24 M. Lawrence Nom. Upset 3.5 ins Upper len. 12.0 ins lower len. 12.0 ins Damage Profile ('Yo wall) penetration body o o GlM 1 GlM2 GlM 3 GLM 4 metal loss body 50 100 Bottom of Survey 0.1 Analysis Overview page 2 I I I PDS REPORT JOINT TABULATION I Pipe: Body Wall: Upset Waif: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Compa ny: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA October 20, 2006 I I I Joint Jt. Depth Pen Pen. Pen ;\k:¡;~T Min. Damag e Profile No. (Ft.) Body ID. Comments (% wall) ) (Ins.) (Ins.) 0 50 100 .1 11 0 0.02 B : 3.00 PUP ~ 1 14 0 0.D1 6 ] 2.96 II 1.1 45 0 0.01 4 0 2.95 PUP P 1.2 54 0.D1 ') 11 2.95 PUP \I 2 63 0.02 7 : 2.96 3 95 0.02 ;; 2.97 4 126 0.02 , 2.97 5 159 0 0.02 2.98 6 189 0 0.02 2.96 7 223 0 0.02 2.96 8 255 11 0.02 9 I :) q¡; 9 287 11 0.02 7 j 2.97 10 318 0 0.02 7 2.97 11 350 11 0.03 II 2.96 12 382 0 0.02 2.97 13 413 0 0.02 2.97 14 445 0 0.02 2.97 14.1 475 0 0 ¡ 2.81 DS LANDING NIPPLE 15 47H 0 0.D1 2 2.98 16 510 0 0.02 7 ¿J 2.96 17 542 () 0.02 B ::; 2.96 18 573 0 0.02 4 2.97 19 60S 0 0.02 2.97 20 637 0 0.02 1\ 2.97 21 668 0 0.02 C) 2.96 22 700 0 0.02 ß 2.97 23 731 0 0.02 2.98 24 763 0 0.02 ) 2.97 25 795 0.02 FI ( 2.97 26 826 I 0.02 2.98 27 856 I 0.02 2.97 28 887 ( 0.02 2.98 29 921 0 0.02 2.97 30 953 0 0.02 2.97 31 984 () 0.02 2.96 32 1015 0 0.02 B 2.98 33 1047 () 0.02 2.97 34 1078 (I 0.02 2.97 35 1109 (I 0.02 2.96 36 1141 (I 0.02 2.97 37 1172 0 0.02 2.95 38 1203 0 0.01 6 S 2.98 39 1234 i 0.D1 S 2.96 40 1266 I 0.D1 ri 2.97 41 1297 I 0.02 , 2.96 42 1329 ( 0.02 2.97 43 1360 I 0.02 2.97 44 1391 () 0.02 7 2.97 45 1423 0 0.02 ß 2.97 46 1454 (I 0.02 7 'i 2.97 I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA October 20,2006 I Joint Jt. Depth Pen Pen. Pee ·\/lI1'!al Min. Damag e Profile No. (Ft.) Body .01..1.. I.D. Comments (% wall) (ins) (Ins.) (Ins.) 0 50 100 47 1486 0 0.Q2 3 2.97 48 1517 IJ 0.02 4 2.98 49 1548 0 0.01 " 2.97 50 1580 ( 0.02 2.97 51 1612 I 0.02 7 2.98 52 1643 0.Q2 7 2.96 53 1675 0.02 7 2.98 54 1706 0 0.02 2.97 55 1738 ( 0.02 5 2.97 56 1769 0 0.Q2 2.96 57 1801 0 0.01 2.96 58 1832 0 0.02 2.96 59 1864 0 0.02 7 2.95 60 1895 0 0.D3 10 2.96 60.1 1927 0 om 2 I 2.95 PUP 60.2 1933 0 0 Ii N!A GLM 1 (Latch @ 3:30) 60.3 1941 0 0.02 0 2.93 PUP FE! 61 1947 0 0.02 4 2.96 62 1978 0 0.02 ! 2.97 63 2010 0 0.02 ;> 2.97 64 2042 0 0.02 ) 2.97 65 2073 ( 0.02 9 ¡ 2.96 66 2105 ( 0.02 4 2.97 67 2137 I 0.02 :2 2.97 68 2168 0.Q2 7 2.98 69 2200 0.02 5 2.97 70 2231 ( 0.02 ~.,.' 4 2.97 ! 71 2263 0 0.02 9 ;> 2.95 72 2294 0 0.02 7 4 2.96 73 2326 0 om 4 2.96 74 2357 0 0.02 I' 2.96 75 2389 0 om J 2.97 76 2421 0 0.02 3 2.97 77 2452 0 0.02 :2 2.97 78 2484 0 0.02 2.97 79 2515 0 0.02 7 2.97 80 2547 0 0.02 it 2.96 81 2579 0 0.02 7 ( 2.97 82 2610 0 0.02 7 2.96 83 2641 0 0.02 0 2.97 84 2673 0 0.Q2 4 2.96 85 2704 0 0.02 2.96 86 2736 ( 0.02 2.97 87 2768 ( 0.02 2.97 88 2799 0.02 n 2.96 89 2830 I 0.02 7 2.96 90 2862 ( 0.02 9 2.96 91 2894 0 0.02 7 2.91 U. Deoosits. 92 2925 0 0.D3 12 ( 2.97 93 2957 (j 0.03 1 J ¡ 2.96 Shallow oittin2. I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA October 20, 2006 I I I Joint Jt. Depth Pc Pen. Perr 11 Min. Damag e Profile No. (Ft.) 'I Body 1.0. Comments (% wall) ..) (Ins.) (Ins.) 0 50 100 94 2989 0 0.ü3 13 7 2.96 Shallow oitúnQ. I 95 3021 0 0.02 7 2.97 96 3052 () 0.02 q I 2.95 97 3084 () 0.03 n 7 2.96 Shallow corrosion. 98 3116 0 0.03 1 'j I 2.95 99 3147 () 0.02 9 ) 2.96 100 3180 0 0.02 7 , 2.96 ¡ 101 3211 0 0.ü3 12 I 2.97 1m 3242 0 0.02 a ") 2.97 103 3274 0 0.ü3 13 i 2.97 Shallow oitúnQ. 104 3306 0 0.03 11 1 2.94 105 3338 0 0.02 7 2.97 106 3369 'i 0.04 14 2.93 Shallow oitúng:. fIi 107 3401 0 0.ü3 17 2.97 Pitting: in uoset. 108 3432 ( 0.01 6 2 q<; 109 34M 0.06 0.02 fj 2.97 Pittino in unçet. 110 3495 0 0.03 10 ,i 2.9! Pi ttinQ. 111 3526 0.05 19 7 2.89 Shallow corrosion. 112 3559 I 0.03 11 I 2.96 ¡ . 113 3590 ( 0.ü3 17 2.95 114 3622 ( 0.02 2.95 115 3653 0 0.ü3 11 2.94 ~ 116 3684 0 0.04 15 2.98 Shallow oittinQ. 117 3715 0 0.02 7 2.96 . 118 3746 0 0.04 17 2.94 Shallow oittinQ. 119 3777 0 0.02 a 2.97 120 3808 ow; 0.03 II 2.93 Pitting: in uoset. 121 3840 0 0.02 9 2.90 Lt. Deaosits. 122 3871 0 0.ü3 I 2.95 123 3903 0 0.ü3 ¡ 2.96 Shallow oittino. 124 3935 0 0.ü3 10 2.97 i 125 3965 0 0.04 16 (¡ 2.96 Shallow corrosion. 126 3998 : 0.02 f 2.96 127 4029 0.ü3 ¡ 2.96 Shallow aittinQ. 128 4060 0.06 2.97 Isolated aittin2. 129 4092 ( 0.07 2.97 Isolated aittin2. 130 4124 ( 0.06 2.96 Isolated nittino 131 4156 0 0.05 '0 2.95 Shallow nittinQ. 132 4188 0 0.05 19 2.96 Shallow nittinQ. 133 4219 0 0.04 7 2.95 Shallow nittimJ. 134 4251 0 0.04 1 I 2.96 Shallow nittinQ. 135 4281 0 0.04 fj 2.96 Shallow corrosion. 136 4314 0 0.05 2.96 Isolated nittin2. 137 4345 0 0.04 2.96 Shallow aitúm!. 138 4376 I 0.07 2.96 Corrosion. 139 4409 0.0'; 0.07 2.97 Isolated nittinQ. 140 4440 007 0.06 2.' " 2.96 Isolated nittim>:. 141 4471 0 0.04 1 9 2.95 Shallow oitting:. 142 4504 0 0.07 I: il 2.97 Isolated nittinll:. 143 4535 0 0.05 2( n 2.96 Isolated nittino I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT TABUlATION I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA October 20, 2006 I Joint Jt Depth f\'I¡ Pen. Pen. 1 ;\,1('11 Min. Damage Pro file No. (Ft.) ('I Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 144 4567 0 0.04 15 r~ 2.95 Shallow nittin"'. 145 4599 010 0.06 22 2 2.95 Isolated nittin'" 146 4629 nil 0.05 21 h 2.95 Isolated nittin<> 147 4661 0 0.05 19 'j 2.96 Line shallow corrosion. 148 4693 n I': 0.Q3 f1 2 2.96 Shallow nittin<>. 149 4724 n 0.05 21 2.96 Corrosion. 149.1 4756 0 0.Q3 10 2.93 PUP 149.2 4762 0 0 ( N/A GLM 2 (Latch @ 3:30) 149.3 4770 0 0.03 1 2.94 PUP 150 4776 O.On 0.11 42 2.97 Line c.orrosion. 151 4808 P II 0.10 m ¡¡ 2.95 Line corrosion. 152 4840 nOI\ 0.10 S 2.96 Line corrosion. 153 4870 00(. 0.12 7 2.96 Line corrosion. Lt. Deoosits. 154 4901 001{ 0.13 10 2.94 Line corrosion. Lt. Deoosits. 155 4935 012 0.13 If 2.97 Line corrosion. 156 4965 IJO(, 0.15 11 2~ Line corrosion. 157 4998 011 0.13 n 2. Corrosion. Lt. De oosits. 158 5029 n 0.14 f, 2.96 Line corrosion. 159 5060 0:: 0.14 55 .'() 2.96 Line corrosion. 160 5091 0 0.11 15 2.96 Line corrosion. 161 5122 014 0.08 I ;f¡ Line corrosion. 162 5153 OO\., 0.09 :h Line corrosion. 163 5186 0.11 0.12 19 Line corrosion. 164 5217 007 0.12 46 h 2.97 Line corrosion. 165 5249 011'1 0.10 I) II 2.96 Line corrosion. 166 5281 12 0.09 0 2.96 Line corrosion. Lt. Denosits. 167 5311 . Of, 0.14 , 7 2.90 Line corrosion. Lt. Deoosits. 168 5344 lOb 0.09 6 2.96 Line corrosion. 169 5375 IS 0.11 14 ~¡ 'I 2.95 Line corrosion. 17D 5407 OOn 0.09 1(, () 2.97 Line corrosion. 171 5438 0.f2 0.10 0 I: 2.97 Line corrosion. U. DeDosits. 172 5469 0 0.11 42 9 2.96 Corrosion. 173 5502 Of4 0.08 32 (, 2.96 Corrosion. 174 5533 Of 3 0.09 34 ,) T 2.96 Line corrosion. 175 5565 o liil 008 1 2.97 Line corrosion. 176 5597 007 0.10 2.96 Líne corrosion. 177 5628 007 0.12 2.96 Líne corrosion. 178 5660 00(, 0.15 2.95 Line corrosion. 179 5692 Of6 0.13 2.97 Line corrosion. 180 5723 Off 0.19 75 q 2.96 Line cor rosio n. 181 5755 010 0.21 7 2.96 Corrosion. 182 5787 017 0.23 ') 2.96 Possible Hole! 183 5818 OW 0.16 I', 2.97 Corrosion. 184 5849 lilO 0.18 ¡ 2.96 Corrosion. 185 5881 0~0.12 q 2.97 Corrosion. 186 5912 o 0.14 'I 1 2.96 Líne corrosion. 187 5944 I 0.18 q 2.96 Line corrosion. U. Denosits. 188 5976 l'On 0.13 0 2.96 Line corrosion. 189 6007 I I'') 0.21 ! 2.96 Líne corrosion. U. Deoosits. 190 6038 110 0.16 I 11 2.97 Line corrosion. I I I I I I I I I I I I I Penetration Body Metal Loss Body Page 4 I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Ine. USA October 20, 2006 I I Joint ]t. Depth Pc·, Pen. Pen. i ,Vlet;11 Min. Damage P rofile No. (Ft.) Body I.D. Comments (%wall) ns.) (Ins.) (Ins.) 0 50 100 191 6071 010 O.B 50 () 2.96 Line corrosion. Lt. Deoosits. 192 6102 o on 0.11 2.96 Line cor rosio n. 193 6134 OJ 0.12 2.96 Line corrosion. Lt. Deoosits. bE 6163 001 0.18 2.95 Line corrosion. 6184 01 0.14 2.95 Line corrosion. Lt. Denosits. 196 6214 OJH 0.10 2.96 Line corrosion. Lt. Deoosits. 197 6246 009 0.10 2.97 Line corrosion. Lt. Denosits. 198 6278 0.07 0.13 h 2.96 Line corrosion. 199 6310 0.09 0.12 46 h 2.96 line corrosion. 200 6341 017 0.09 35 q 2.96 line corrosio n. 201 6373 I} 1 'i 0.10 )q 2.97 Line corrosion. 202 64D4 0 0.10 40 2.95 Corrosion. 203 6437 DOh 0.08 0' 2.96 line corrosion. , 204 6468 OW, 0.08 31 2.95 Isolated nininO' 205 6499 0 0.11 44 1 2.97 Line corrosion. 206 6530 0.05 0.05 10 2.97 Line c.orrosion. 207 6563 001, 0.07 16 2.97 Corrosion. 208 6593 IW7 0.09 r7 , 2.96 Corrosion. 209 6625 0.1)7 0.08 I 2.96 Isolated niHiml. 210 6658 0.06 0.07 >g 2.96 Isolated oittimL 211 6689 00') 0.09 )6 ¡ ~I 2.97 Corrosion. 212 6722 006 0.10 09 -; 2.96 Corrosion. 213 6752 0 0 7i NA No Data 214 6784 0 0 NA No Data 215 6816 0 I NA No Data 216 6848 0 ( NA No Data 217 6881 0 ( NA No Data 218 6914 I 0 NA No Data 219 6945 I 0 NA No Data 220 6978 0 0 0 () NA No Data 221 7012 0 0 0 n ~tt No Data 222 7044 0 0 0 No Data 223 7077 0 0 0 ( No Data 224 7110 0 0 o I No Data 225 7140 0 0 0 NA No Data 226 7174 0 0 0 NA No Data 227 7210 0 0 0 !) NA No Data 228 7241 012 0.04 16 2.98 Line shallow corrosion. ~ 229 7272 i 0.04 17 Ii 2.97 Shallow nittina. 230 7302 ( 0.04 ') 2.97 Shallow oittinQ. 231 7333 I 0.05 0 ~ Shallow oitlinQ. 231.1 7365 ( 0.ü1 PUP I 231.2 7372 ( 0 ( N A GlM 3 (latch @ 3:00\ 231.3 7380 0 0 . 0 7) 2.99 PUP 232 7385 J( 0.10 ¡n 2.97 Line corrosion. 233 7416 11 0.09 " 2.95 line corrosion. 234 7449 11 0.07 h 2.97 Corrosion. 235 7480 U 0.09 (., 2.93 Line corrosion. 236 7512 1.04 0.07 {, 2.97 Corrosion. Lt. Denosits. 237 7542 0 0.07 26 'i 2.90 Corrosion. I I I I I I I I I I I I Penetration Body Meta! loss Body Page 5 I I I REPORT JOINT ULATION SH I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Ine. USA October 20, 2006 I Joint Jt. Depth Pen. Pen. Pen. !v\cl;¡1 Min. Damage Profile No. (Ft) 'j Body !.D. Comments (%w all) (Ins.) (Ins.) (Ins.) 0 50 100 238 7575 I) 11 0.12 46 c¡ 2.98 Line corrosion. I 239 7606 íì il"1 0.08 ill 7 2.97 Corrosion. 240 7637 0 0.07 r. 2.95 Isolated nittinIL 241 ~I) 0.07 26 2.96 I ine corrosion. 242 7 (1)(, 0.09 !7 2.97 Corrosion. 243 7732 0 0.06 22 2.95 Isolated nittin<>. 244 7764 ()JF 0.05 20 2.96 Line shallow corrosion. 245 7794 0.06 )5 f 2.94 line corrosion. 246 7827 0 h 0.04 2.96 Shallow nittinQ. 247 7858 I) 'S 0.05 2.97 Shallow nit1inQ. 248 7889 0 ;g 0.04 ¡ 2.93 Shallow nittina. 249 7921 011 0.04 1 2.90 Shallow nittina. Lt. DeDosits. 250 7953 0 0.03 1 2.97 251 7983 0 0.04 ¡ 2.96 Shallow nittin<>. -ili-+ 8015 0 0.05 21 2.97 Isolated nitting. 8047 o O'S 0.02 2.98 Pitting in un<;et. 254 8078 011 0.02 2.97 PittinQ in ur)<;et. 255 8109 0 0.05 2.92 Isolated oittinlL 256 8142 019 0.03 1 2.95 Pittin<> in un<:et. 257 8173 0 0.03 13 l 2.96 Shallow nit1ir¡o. 258 8203 o 2 0.05 21 g 2.96 Isolated nittin'" 259 8234 OOB 0.06 22 g 2.96 Isolated niuin<> 260 8268 0 0.03 13 ] 2.95 Shallow nitting. 261 8298 0 0.04 1· '7 2.94 Shallow oittinQ. 262 8331 0 0.04 ¡ I 2.96 Shallow oittinQ. 263 8362 014 0.04 1 j 2.96 Shallow nittinQ. 264 8393 0 0.04 1 7 2.95 Shallow corrosion. fill 265 8426 O.Og 0.02 9 7 2.96 Pitting in uoset. 266 8457 0 0.03 1.: 1 2.96 267 8488 017 0.03 10 ') 2.96 Pitting in unset. 268 8519 0 0.03 3 7 2.95 Shallow nit1ing. 269 8552 0.03 1 2.94 270 8584 I 0.03 11 2.96 Shallow oittinQ. 271 8615 1 0.02 B 2.97 272 8646 0.03 !'! 2.96 273 8677 0 ~ 12 2.96 274 8709 J c¡ ~ 2.98 275 8741 0 3 7 2.96 Shallow nittinQ. 276 8772 01 .; 0.03 1 2.95 Pitting in ur)<;et. 277 8803 014 0.05 h 2.98 Shallow nittiml. 278 8835 0 0.03 2.96 Shallow nittiml. 279 8867 0 0.03 ill 280 8898 01} 0.03 Pittirw in un<:et. 281 8930 0 0.03 13 2.97 Shallow nittim<. 282 8960 0 0.04 14 2.92 Shallow nit1in"'. 283 8992 0 0.03 13 l' 2.94 Shallow nitúng. 284 9024 0 0.03 ,) 2.96 285 9054 0 0.03 1 2.96 286 9087 0 0.02 B 2.96 287 9117 0 0.03 ,3 2.93 Shallow nittin"'. I I I I I I I I I I I I I Penetration Body Me1a1 Loss Body Page 6 I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2A-22 Kuparuk ConocoPhillips Alaska, Ine. USA October 20, 2006 I I I I Joint Jt. Depth l'el1 Pen. Pel1. Met:! Min. Damage Profile No. (Ft.) !. Jpse] Body ;s 1.0. Comments (%w all) (Ins.) (Ins.) 0 50 100 288 9148 P! 0.02 9 Y -?Ci7 289 9180 () 0.02 -;, 2.97 290 9210 () 0.02 J 2.96 291 9243 () 0.02 2.96 292 9274 () 0.ü3 2.95 I 293 9304 U 0.04 1 2.93 Shallow corrosion. 294 9338 0 0.02 2.95 295 9369 0 0.02 9 2.97 296 94D0 0 0.ü3 10 ;, 2.96 297 9431 0 0.01 2.96 298 9462 () 0.04 2.89 Shallow oitlinlZ. 299 9492 () 0.03 f 2.94 300 9525 010 0.05 2.94 Isolated oittinlZ. 301 9557 0 0.02 1 2.96 302 9589 ()15 0.02 7 2.96 Pittirw in un<:et 303 9621 0 0.02 9 1 2.96 304 9653 () 0.ü3 12 6 2.94 305 9685 () () c; 0.12 4i 7 2.95 Corrosion. 306 9716 () 0.03 1 1 2.95 Shallow oitnnlZ. 307 9746 Ii ()i) 0.ü3 ;, 2.96 Shallow corrosion. 308 9778 () 0.03 1 2.Q¡;; III 309 9809 () 0.02 q 2.96 ¡ill! 310 9841 0 0.04 1 2.94 Shallow corrosion. pill 311 9875 0 0.02 1 2.94 311.1 9905 0 001 I) 2.92 PUP 311.2 9912 () 0 i N/A GLM 4 (Latch @ 11 :30\ 311.3 9921 () 0.03 10 ? q3 PUP 312 9926 () 0.02 ( 2.96 313 9958 U 0.02 ( 2.96 314 9989 U 0.02 ß 1 2.95 315 10021 Ii 0.02 ±j ~. 7.95 316 10053 0 0.02 2qr:, 317 10085 () 0.02 2.95 , 318 1011 6 () 0.02 I 2.95 319 10146 () 0.02 i 2.96 320 10179 U 0.02 ) 2.95 III 321 10209 () 0.02 I 2.95 III I I I I I I I I I I I I I Body Metal Loss Body Page 7 .. .. .. .. .. .. .. .. .. .. .. - .. .. .. .. P S Report Cross Sections Well: Field: Company: Country: Tubin : 2M2 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9,3 f L-80 Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: October 20,2006 UW MFC 24 No. 212330 1,69 24 M, Lawrence Cross Section for Joint 182 at depth 5800.11 ft Tool speed 43 NominallD 2.992 Nominal 00 3.500 Remaining wall area = 94 % Tool deviation = 79 0 Finger 1 7 Penetration = 0,228 ins Possible Hole! 0.23 ins = 90% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. - .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. .. .. PDS Report Cross Sections 2A-22 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 Survey Date: Tool Type: Tool Size: i'lO. of Fingers: Anal st: October 20, 2006 UW MFC 24 No. 212330 1.69 24 M. Lawrence Cross Section for Joint 181 at depth 5764.79 ft Tool speed = 43 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 84 0 Finger 18 Penetration 0.214 ins Corrosion 0.21 ins = 84% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. .. .. I I .- -. ... A. KRU 2A-22 . 12A·22 API: 501032022100 Well Tvpe: PROD Anole @ TS: 52 dea @ 14297 NIP (494-495, SSSV Tvpe: NIPPLE Orio ComDletion: 6/11/1995 Anole Iâ> TD: 51 deo Iâ> 14797 OD3.500) Annular Fluid: Last W/O: Rev Reason: SET PLUG, GLV C/O, LEAK DETECT Reference Log: Ref Loa Date: Last UDdate: 10/4/2006 Last Tag: 14314' RKB TD: 14797 ftKB GasLiff ~~~/2005 M 6 cleg @4190 MandreWaIve 1 (1947-1948, Size TOD Bottom TVD wt Grade Thread DD,6.018) DescriDtion CONDUCTOR 16.000 0 121 121 62.58 H-40 SURF CASING 9.652 0 4928 2937 40.00 L-80 GasLiff PROD CASING 7.000 0 14698 6082 26.00 L-80 MandreWaIve ....~... 2 (4772-4773, ~ I Bottom I TVD I wt I Grade I Thread OD6.018) I 14265 I 5812 I 9.30 I L-80 I 8RD EUE ABM GasLiff Interval TVD Zone Status Ft SPF Date Type Comment MandrêWalve 14302 -14317 5835 - 5844 C-4 15 4 6/28/2000 APERF 21/2" HSD DP 1$0 dea ph 3 (7377-7378, 14330 - 14348 5852 - 5864 C-4 18 4 8/17/2001 APERF 2.5" HSD Alternating BH/PJ, 006.018) 180 cleo phase 14352 -14378 5866 - 5882 A-3 26 4 6/12/1995 IPERF SWS TCP Type BH UP; 180 deg ph; oriented 90 CCW f/hiahside Interval Date Type Comment 14302 14348 12/912002 FRAC AlC SAND FRAC W/221 ,728# OF 16/20 PROPPANT BEHIND PIPE W/10 PPA ON PERFS Ga: St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt 1 1947 1838 Cameo MMG GLV 1.5 RK 0.188 1299 10/1/2006 2 4772 2889 Cameo MMG GLV 1.5 RK 0.250 1337 9116/2006 :3 7377 3657 Cameo MMG GLV 1.5 RK 0.250 1330 10/3/2006 -.-£ I ~ 9912 4367 Cameo MMG DMY 1.5 1=20.000 0 1 0/3/2006 2 4903 Cameo MMG GLV 1.5 10.250 1318 10/1/2006 6 5407 Cameo MMG DMY 1.5 0.000 0 10/1/2006 (1) 7 14172 5756 Cameo MMG OV 1.5 RK 0.188 0 7/7/2006 ~~èQUh).,"'fI "' ;Tlfll\l DeïJth TVD Type DescriDtion ID 494 494 NIP Cameo 'DS' Landino 2.813 14218 5784 NIP Cameo 'W-1' Selective 2.813 NIP 14226 5789 SEAL Baker 'KBH-22' Anchor Seal Assembly 2.984 (14218-14219, 14227 5789 PKR Baker 'SAB-3' 3.250 OD,3500) 14242 5798 NIP Cameo 'D' Landino 2.750 14242 5798 PLUG UG set 6/4/2006 0.000 ~5S12 Tn I 2.992 SEAL 5812 SOS ISWS'SXAR' 2.992 (1422&-14227, NôtèS' OD3.500) Note 6/15/2006 A LEAK DETECT WITH PMIT WAS PERFORMED. LEAKS WERE FOUND @ GLM #4 (9912), 5741' AND GLM#2 (4772') PLUG (14242-14243, OD 2. 750) TUBING (0-14265, OD,3.500, ID,2992) FRAC .~ (14302-14348) Perf (14302-14317) Perf ì (14352-14378) - - --- ~ - - I I I I I I I I I I I I I I I I 10/25/06 Sc~lIIIIIbepgel' NO. 4020 C)¡ (.~ (:;} ~, Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N""^"'" Ct·/\.', ~~P"'~¡ ':Z:\;1h.) '~,,~...... ',,, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ICJS-00o -' Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R-27 11415636 LDL 10/04/06 1 2A-22 11445111 LDL 10/11/06 1 1J-115 11445116 US IT 10/17/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . RECE\\/ED 06/13/06 dUN 1 4 2006 Sc~lulDbepgep r,O<O ,¡ \c¡~ NO. 3850 .l\læka Oil &, Gas Cal1!t Cf)mmi!:lsiOn Anchof~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ....~ . "...,ìto,'.'\;,:\.' . "!i'd, ,,'iI',', '¡¡,..,' ' '3~,,"'¡ ,~ ~ Field: Kuparuk Well Job# Log Description Date BL Color CD h'- 3J-16 11249908 INJECTION PROFILE 06103106 1 1R-08 11249909 INJECTION PROFILE 06104106 1 3H-11 ' 11213760 PRODUCTION PROFILE WIDEFT 05131/06 1 1R-07 11249912 PRODUCTION PROFILE 06107106 1 1 F-12 11320981 PRODUCTION PROFILE WIDEFT 06106106 1 3G-20 11249911 INJECTION PROFILE 06106106 1 2A-16 11213754 PRODUCTION PROFILE WIDEFT 05125106 1 2A-22 11213756 LDL 05127106 1 1Y-04 11320980 LDL 06103106 1 2Z-02 REDO 11235362 INJECTION PROFILE 05128106 1 1 H-19 REDO 11320975 INJECTION PROFILE 05129106 1 2A-13 REDO 11320976 LDL 05130106 1 3J-09 11320977 INJECTION PROFILE 05131106 1 1 F-17 11249913 PRODUCTION PROFILE WIDEFT 06/08/06 1 1J-170 11320983 US IT 06111/06 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (N / -{Jf/",--. 0 / 1'1 (()6 e e Conoco hillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Janua~ 14,2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2A-22 (195-068) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2A-22. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Moori'ey Wells Team Leader CPAI Drilling MM/skad RECEIVED JAN .50 200,.5 Alaska 0ii & Gas Cons. Commission Anchorage SGANNED FEB 0 4 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _XX Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 4521' FNL, 5054' FEL, Sec. 13, T11N, R8E, UM At top of productive interval 1745' FNL, 1013' FEL, Sec. 16, T11N, R8E, UM At effective depth At total depth 1669' FNL, 1367' FEL, Sec. 16, T11N, R8E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service__ (asp's 498619, 5960178) (asp's 486818, 5962969) (asp's 486465, 5963041) 6. Datum elevation (DF or KB feet) RKB 135 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-22 9. Permit number / approval number 195-068 / 10. APl number 50-103-20221 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 14797 feet Plugs (measured) 6144 feet Effective depth: measured 14520 feet Junk (measured) true vertical 5971 feet Casing Length Size Cemented CONDUCTOR 121' 16" 250 sxAS 1 SURF CASING 4793' 9-5/8" 820 sx AS III, 890 sx Class G PROD CASING 14563' 7" 260 sx Class G Measured Depth 121' 4928' 14698' True ve~icalDepth 121' 2937' 6082' Perforation depth: measured 14302' - 14317', 14330' - 14348', 14352' - 14378' true vertical 5835' - 5844', 5852' - 5864', 5866' - 5882' 'ubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 14265' MD. Packers & SSSV (type & measured depth) BAKER 'SAB-3' @ 14227' MD. CAMCO 'DS' LANDING @ 494' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) 14302' - 14348' MD Treatment description including volumes used and final pressure 221,278# of 16/20 ceramic proppant behind pipe 14. OiI-Bbl Prior to well operation 296 Subsequent to operation 340 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 873 443 1006 1085 Casing Pressure Tubing Pressure 243 274 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Oil_ X Gas_ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~' Michael Mooney Title: Wells Te~'~ Leader Date Prepared b~, Sharon Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · gDMS BFL ' ', SUBMIT IN DUPLICATE Date Comment 2A-22 Event History 11/30/02 12/01/02 12/02/02 12/03/02 1 2/04/02 12/05/02 12/06/02 TAGGED @ 14345' SLM (VERY MUSHY) EST. 33' FILL. IN PROGRESS. [TAG] RETAGGED @ 14352' RKB, EST. 26' FILL. PULLED GLV (NO SCALE) & SET DV @ 9912' RKB. PULLED OV (GOOD SHAPE, NO SCALE) @ 14172' RKB. IN PROGRESS. [TAG, GLV] SET DV'S @ 4772', 7377' & 14172' RKB. POCKET OPEN @ 13426' RKB. IN PROGRESS. [GLV] SET DV'S @ 11700' & 13426' RKB. EMPTY VALVE CATCHER PULLED @ 14242' RKB. IN PROGRESS. [GLV, PT TBG-CSG] SET 2.75" CAT SV @ 14242' RKB. P/T TBG, GOOD. PULLED DV @ 14172' RKB & LOADED IA W/311 BBLS SEAWATER. UNABLE TO SET DV @ 14171' RKB DUE TO UNKNOWN OBSTRUCTION @ 7581' SLM. [GLV, PT TBG-CSG] ATrEMPT SET DV @ 14172' RKB, TOOLS NOT FALLING, PUMP ASSIST INADEQUATE. TOOLS TO MAX DEPTH OF 8840'. IN PROGRESS. [PT TBG-CSG] LOADED IA W/311 BBLS SW. A-I-tEMPT SET DV @ 14172' RKB. IN PROGRESS. [GLV, PT TBG-CSG] 12/07/02 12/09/02 SET DV @ 14172' RKB. P/T TBG 3000 PSI, GOOD. P/T IA 3500 PSI, GOOD. CAT SV PULLED @ 14242' RKB. READY FOR FRAC. [GLV, PT TBG-CSG] PUMPED FRACTURE TREATMENT OF NC SANDS. PLACED 221,728# OF 16/20 CERAMIC PROPPANT BEHIND PIPE WITH 10 PPA ON PERFS. PUMPED JOB AT 20 BPM USING 50# DELAYED X-LINK GEL, REDUCING TO 40# DELAYED X-LINK GEL TOWARD END OF JOB TO REDUCE FRICTION PRESSURE. SCREENED OUT LEAVING 38,000# OF PROPPANT IN PIPE. RECOVERED ALL TREESAVER CUPS. 12/10/02 12/1 2/02 12/15/02 12/16/02 12/17/02 12/18/02 12/19/02 12/20/02 12/23/02 12/24/02 SPOOL PIPE. CURRENT PIPE ON BOARD MILED OUT. [MAINTENANCE] PERFORMED A FCC TO 14,559' CTMD. ALL INDICATIONS OF A GOOD FCC. SLIGHT THIEF ZONE @ 14,360' CAUSING DIFFERENTIAL STICKING. DIESEL IN WELL BORE TO THE PERFS. USED 1400 BBLS DURING FCC. WASHED ALL MANDRELS ON THE WAY TO SURFACE. SUGGEST THAT IF 14,559' CTMD IS NOT DEEP ENOUGH THEN FCC IS NEEDED WITH A VORTECH NZL. TAGGED FILL @ 14520' RKB EST. 142' RAT HOLE, SET CATCHER @ 14242' RKB, PULLED DV F/14172' RKB, SET OV 3/16" PORT @ 14172' RKB, IN PROGRESS. [FRAC-REFRAC] PULLED DV'S,F/13426', 9912', 4772', RKB, SET ONE GLV @ 13426' RKB, LEFT STN 2, & 4 OPEN, VALVE CATCHER @ 14242' RKB JOB IN PROGRESS, [FRAC-REFRAC] DISPL TBG 85 BBL DSL, UNSUCCESSFUL SETTING GLV'S @ STN 2 & 4, DUE TO POOR TOOL ACTION. JOB IN PROGRESS. [FRAC-REFRAC] SET 1.5" GLV @ 4772' RKB. MADE SEVERAL A~-FEMPTS BUT WAS UNABLE TO SET 1.5" GLV @ 9912' RKB DUE TO POOR ACTION.IN PROGRESS. [GLV] SET 1.5" GLV @ 9912' RKB. CHECK STN # 2 @ 4772' RKB W/PINNED R/T & CONFIMED VALVE IS IN POCKET. IA WILL NOT BLEED DOWN INDICATING STN # 4, 6, OR 7 COULD BE OUT OF POCKET. IN PROGRESS. FOUND POCKET TO BE OPEN @ 9912' RKB.PULLED VALVE CATCHER @ 14242' RKB & RECOVERED STN # 4 GLV. RE-SET VALVE CATCHER @ 14242' RKB. MADE ONE ATTEMPT TO SET GLV @ 9912' RKB BUT BROUGHT VALVE BACK. IN PROGESS. [GLV] RAN LIB TO STN # 4 @ 9912' RKB & CONFIRMED VALVE IS IN THE POCKET. SET 1.5" GLV @ 13426' RKB. CHECK SET VALVE @ 14172' RKB & CONFIRMED VALVE IN POCKET.WELL STILL HAS TBG X IA COMMUNICATION. JOB IN PROGRESS. [GLV] CHECK SET STN # 6 @ 13426' RKB & 9912' RKB.IA & TBG STILL TRACKING.PULL EMPTY CATCHER SUB @ 14242' RKB. IN PROGRESS. SET 2.75" CAT STANDING VALVE @ 14242' RKB.PUMP DOWN TBG SEE IA TRACK BUT AFTER 2.5 BBLS TBG PRESSURED UP TO 2500 PSI W/500 PSI ON IA.WATCH FOR 15 MINUTES & HELD SOLID.PULL CAT STANDING VALVE @ 14242' RKB. [GLV, PT TBG-CSG] SCANNED FEB 0 A 2003 Page 1 of I 1/13/2003 Pf _LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 September 7, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 .'],i,xska 0il & Gas Cons...(;o~ Subject: Report of Sundry Well Operations 2A-22 (195-068) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2A-22. If there are any questionsl please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4521' FNL, 5054' FEL, Sec. 13, T11 N, R8E, UM At top of productive interval 1745' FNL, 1013' FEL, Sec. 16, T11 N, R8E, UM At effective depth At total depth 1669' FNL, 1367' FEL, Sec. 16, T11 N, R8E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service__ (asp's 498619, 5960178) (as/o's 486818, 5962969) (asp's 486465, 5963041) 6. Datum elevation (DF or KB feet) RKB 135 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-22 9. Permit number / approval number 195-068 / 10. APl number 50-103-20221 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SURF CASING 4793' PROD CASING 1 4563' 14797 feet Plugs (measured) 6144 feet 14375 feet Junk (measured) 5880 feet Size Cemented Measured Depth True vertical Depth 16" 250 sx AS 1 121' 121' 9-5/8" 820 sx AS II1,890 sx Class G 4928' 2937' 7" 260 sx C~ass G 14698' 6082' Perforation depth: Tubing (size, grade, and measured depth) oEP ! 4 2i~r)l Alaska Oil & Gas Cons. Commission ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:::::::~:::::::: ::::::::::::::::::::: .::: JJ::J::: ::J:: 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes ............................................................................................................................................................................ used and final pressure 14. Prior to well operation Subsequent to operation Representative Da y Avera,qe Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure !.i i.i i.i i.i.i.!~ i!_!. !.!.. i.!_ !. !.! !. !i.i i.i :,.! i.'. i~.. !.!. !. !.!. !.!.!. !i.i i.i i.:, :J. i.i.'..~. i.. :~. i.. i i.. i.!..;.i. !.. !;.:.~. ;J........;.. '.... :;...J. ~i !:! ii i:ii :;ii: ?ii 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~~-'~ /~'~,,r.¢~ Michael Mooney Form 10-404 Rev 06/15/88 · Title: Wells Team Leader Questions? Call Mike Mooney 263-4574 ORIGINAL SUBMIT IN DUPLICATE Date Comment 2A-22 Event History 08/1 O/01 08/17/01 TAGGED FILL @ 14375' RKB. EST.3' FILL. DRIFTED TBG W/23' X 2.565' DUMMY GUN W/PETROLINE ROLLERS TOP & BTM TO TD. TOOLS FALL SMOOTHLY @ 3 BPM. [TAG] RIH W/2.5" HSD,BH,PJ, 4 SPF, 180 PHASED TO 3600', PUMPED 15 BBL DEISEL THEN SW @ 3 BPM, DECEND TO TD @ 14367', LOGGED TIE IN , LOGGED INTO POSITION, SHOT (14330'-14348'), POOH, PUMP 20 MOPRE BBL DEISEL DN TUBE AND 20 BBL DEISEL DN FLOW LINE FOR F.P., LE Page 1 of 1 9/7/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 756' FSL, 227' FWL, Sec. 13, T11 N, RSE, UM At top of productive interval 1745' FNL, 1013' FEL, Sec.16, T11 N, R8E, UM At effective depth At total depth 1676' FNL, 1368' FEL, Sec. 16, T11 N, RSE, UM Perforate _X Other__ 5. Type of Well: Development __X Exploratory__ Stratigraphic___ Service__ (asp's 498620, 5960179) (asp's 486818, 5962969) (asp's 486464, 5963039) 6. Datum elevation (DF or KB feet) RKB 135 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2A-22 9. Permit number / approval number 195-068 10. APl number 50-103-20221 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 14797 feet 6144 feet Effective depth: measured 14532 feet true vertical 5978 feet Plugs (measured) Casing Length CONDUCTOR 121' SURF CASING 4793' PROD CASING 14563' Junk (measured) Size Cemented 16" 250 Sx AS I 9-5/8" 820 Sx AS III, 890 Sx G 7" 260 Sx Class G Fill Cleanout (9/21/00) to 14532' MD. Measured Depth TrueverticalDepth 121' 121' 4928' 2937' 14698' 6O82' Perforation depth: measured true vertical tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 14302 - 14317'; 14352 - 14378' 5835-5844';5866-5882' 3.5", 9.3#, L-80, Tubing@ 14265' MD. Baker 'SAB-3' Packer @ 14227' MD. Camco 'DS' Landing Nipple @ 494' MD. RECEIVED FEB I 6 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Oil-Bbl Prior to well operation 145 Subsequent to operation 227 Representative Daily Avera.qe Production or Injection Data Gas-Md Water-Bbl 311 395 417 444 Casing Pressure Tubing Pressure - 207 252 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2A-22 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 6/27~00: RIH w/CT & performed a fill cleanout to 14435' MD. 6/28/00: MIRU & PT equipment. RIH w/CT conveyed perforating guns & shot 15' of perforations in the 'C4' sand as follows: Added perforations: 14302 - 14317' MD Used 2-1/2" carriers & shot the perfs at 4 spf at 180 degree phasing. 9/21/00: RIH w/CT & performed a fill cleanout to 14532' MD. POOH w/guns. RD. Returned the well to production w/lift gas & obtained a valid well test. RECEIVED FEB 1 6 7_001 Alaska Oil & Gas Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, 2~'"'"" DATE' CommissiOner THRU: Tom Maunder,/-j-~ P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum. InspectOr January 4, 2001 Safety Valve Tests Kuparuk River Unit -2A Pad Thursday' January 4, 2001' I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2A Pad. As the attached AOGCC Safety Valve SyStem Test Report indicates I witnessed the testing of 12 wells and 24 Components with one failure observed. The Surface Safety Valve on Well 2A-12 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. Earnie Barndt cOnducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhoUses entered at this location were clean and all related equipment apPeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2A Pad in the Kuparuk River Field. KRU 2A Pad, 12 wells, 24 components, 21 wellhouse inspections 1. failure 4.1% failure rate AttaChment: SVS KRU 2A Pad 1-4-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2A Pad 1-4-01 CS.doc Alaska Oil and Gas ConserVation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve . Submitted By: Chuck Scheve Date: Field/Unit/Pad: .Kuparuk / KRU / 2A Pad Separator psi: LPS 96 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i · 2A-01A 1840570 . 2A-02 1840500 2A-03 1840510 2A-04 1840530 2A-05 ' 1840670 2A-06 1840640 2A-07 1840650 2A-08 1852480 2A-09 1860010 96 70 ~0 P P OIL 2A-10 1860020 96 70 55'P P OIL 2A-11 1860030 96 70 50 P P OIL 2A-12 1860040 96 70 70 P 4 OIL 2A-13 1851440 96 70 50 P P OIL I 2A-14 1851450 96 70' 70 -P P OIL 2A-15 1851460 96 70. 70 P P OIL 2A-16 1851470 96 70! 70 P P OIL 2A-17 1931400 96 70! 50 P P OIL ,I 2A-18 1950590 96 70 60: P P OIL , 2A-19 1931520 2A-20. 1931510 ,, 2A-21 1931330 2A-22 1950680 96 70 70 e e OIL 2A-24 1931440 96 70 60 e e OIL 2A-25 1960620 ' , Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.1°A Elg0 Day Remarks: Surface Safety on 2A-12 had slow leak, valve to be serviced and retested 1/9/01 Page 1 of 1 SVS KRU 2A Pad 1-4-01 CS.xls ARCO Alaska, Inc. Post Office Bo), ,d0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #1 below 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1 C- 15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously reported volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the volume required to flush and freeze protect the annulus during initial drilling operations, not a volutne of disposal fluids injected prior to the receipt of authorization for annular injection. Total Volume: into Annuli for which Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume ~ Injected Status of Annulus 1C-12 34995 100 0 I 35095 Open, Freeze Protected 1C-13 26800 100 0 I 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO' s, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume Injected Annulus 2A-22 16749 100 0 16849 Open, Freeze Protected 2F-19 20725 100 0 20825 Open, Freeze Protected 3K-27 I 37173 100 0 37273 Open, Freeze Protected 3K-26 33970 100 0 34070 Open, Freeze Protected 1E-31 33645 100 0 33745 Open, Freeze Protected 1E-32 45205 100 0 45305 Open, Freeze Protected 3Q-22 6245 100 0 6345 Open, Freeze Protected 1Q-24 23158 100 0 23258 Open, Freeze Protected 1Q-26 I 25931 , 100 I 0 26031 I Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files STATE OF ALASKA Ab.,oKA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 756' FSL, 227' FEL, Sec. 13, TllN, At top of productive interval 1745' FNL, 1013' FEL, Sec. 16, Tll At effective depth 1690' FNL, 1292' FEL, Sec. 16, Tll At total depth 1676' FNL, 1368' FEL, Sec. 16, Tll 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R8E, UM N, R8E, UM N, R8E, UM N, R8E, UM 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 2A-22 9. Permit number/approval number 95-68 10. APl number 5o-103-20221-00 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 1 4797 feet true vertical 61 44 feet Effective depth: measured 14698 feet true vertical 6082 feet Plugs (measured) None Junk (measured) None ORIG feet NAL Casing Length Size Structural Conductor 8 0' 1 6" Surface 4 8 90' 9 - 5 / 8" Intermediate Production 14741' 7" Liner Perforation depth: measured 14352'-14378' true vertical 5866'-5883' Cemented Measured depth 250 Sx AS I 121 ' 820 Sx AS III & 4928' 890 Sx Class G 260 Sx Class G 14787' Tubing Pressure True vertical depth 121 2937 6138' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 14265' Packers and SSSV (type and measured depth) Pkr: Baker SAB-3 @ 14227'; SSSV: None, nipple @ 494' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 10/3/97. Intervals treated (measured) 14352'-14378' Treatment description including volumes used and final pressure Pumped 185 M lbs of 16/20 and 12/18 ceramic proppant into formation, fp was 9234 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 646 1372 89 1360 28O Subsequent to operation 1 4 7 3 2219 334 1400 299 15. Attachments Copies of Logs and Surveys run I Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Signed ~)~~ '~A~.~ Form /1,~-gO~ -0~'~15¢8~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT K1(2A-22(W4-6)) WELL JOB SCOPE JOB NUMBER 2A-22 FRAC, FRAC SUPPORT 0921 971552.2 DATE DAILY WORK UNIT NUMBER 10/03/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 (~ Yes O NoI (~) Yes O No DS-YOKUM JOHNS ESTIMATE KD1643 230DS28AL $1 46,357 $163,241 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Anh I Final fD'uter Ann 1 1 00 PSI 1200 PSI 836 PSI 500 PSII 390 PSII 600 PSI DAILY SUMMARY I PUMPED "A" SANDS REFRAC WITH 185,000# OF UP TO 10 PPA 12/18 PROPPANT IN PERFS. LEFT 47,453# PROP. IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, LI'I-rLE RED PUMP AND APC VAC TRUCK. 08:30 HELD SAFETY MEETING, WATCH FOR SLICK CONDITIONS ON PAD. 08:50 PRESSURE TEST TREATING LINE TO 10,900 PSI. 09:00 INITIAL WHP 1100 PSI, PUMP BREAKDOWN TO 25 BPM AND 8900 TO 7013 PSI. 08:58 09:09 10:17 12:39 13:38 13:48 14:48 PUMP 1 AND 2 PPA SCOUR STAGES 15 9PM 5900 PSI. FLUSH TUBING AND SHUf' DOWN FO~ iSIP 1955 PSI. PUMP DATA FRAC AND FLUSH, 15 BPM AND 5448 PSI. SHUT DOWN FOR ISIP AND CLOSURE CALCULATIONS. PUMP 475 BBLS PAD, 15 BPM AND 5968 PSI. PUMP 11579# 2PPA (16/20) PROPPANT , 15 BPM AND 4930 PSI. PUMP 211,453# 2 TO 10 PPA 12/18 PROPPANT 15 BPM AND SCREENED OUT WITH 185,000# IN PERFS AND LEFT 47,453# IN PIPE. SHUT DOWN AND RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $2,068.00 APC $7,400.00 $7,400.00 ARCO $400.00 $400.00 DOWELL $136,557.00 $136,557.00 HALLI BU RTO N $0.00 $7,646.00 LI-I-I'LE RED $2,000.00 $9,170.00 TOTAL FIELD ESTIMATE $1 46,357.00 $1 63,241.00 'h'~. lc[ 2c/.? Geoio?j'icai Hater'~a'i s Znver',!:¢;,r'y P E iR H I T D A T A T D A T ,-"~,_~P !.... IJ '5 J.)a!'.e~ 0:.:~/"J9//97 95'---068 CDN 95 .... 068 9B .... O68 95 068 CDE-: / 689 (..1 i 'i 0/' i 9/Si) 5 J '10/ i 9,,"95 i 08 / 29/' 95 'i I C) / i 9/' 9 !5 10--h 07 R ;$Oi'4PLET];ON [.'.'ATE ¢; /'(I b/;,IL.¥ WELL O-PS R 5/~q ,,/¢~-/ TO 6/'/A./'~/)-/" ~/' ?d/'" W? A r'.e ,..':.t r"y Wa s '~ h e samples r'equ'ir"ed? yes ~ And w e i 'i c c; r" e d ? y e s ~_. A n a 'i y s 'i s E. d e s c r" 'i p t: 'i: o r", /'-.,r"e we'11 !:ests r'equ~'red? ,yes ,I ~,,,!e 'i 'i ~ s 'f n c o rn p i -i a n c eI n~ t '"i~"~'~'.: -. ,~'1- C 0 H H E N T S r' ,.'.s c e '¥ v e d ? ~.~',' e s n<~_ r"E: c e '} v ,:.:i: c:J~ y ~.5 s ~~ e c e ~' v e d ? ,~ ARCO Alaska, Inc. Date: January 18, 1996 TRANSMI-I-FAL #9322 RETURN TO: ARCO Alaska, Inc. Attn: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following pressure items. receipt and return one signed copy of this transmittal. Please acknowledge ~',~-. II ~ 2X-04 ~'5'- 1 ~-~-2B-14 q 5-'~g 2A-22 9 ~-'7° 2M-28 Well Pressure Report 10/24/95 Well Pressure Report 01/03/96 Well Pressure Report 01/08/96 Well Pressure Report 01/08/96 Receipt Acknowleged' ~~/¢~.. DISTRIBUTION: AMERADA AMERADA AMERADA ~' AMERADA RECEIVED Date' jAN 2 2 Oil & Gas 6ons. Oommisskm A~ct~orage Petrotechnical Data Center BP Exploration (Alaska) Inc. MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Holly Fuller c/o Chevron U.S.A., Inc P.O. Box 1635, Rm 3008 Houston, TX 77251 Barbara Sullivan Mobil Oil Corporation 12450 Greenspoint Drive Houston, TX 77060 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Debra Childers UNOCAL P.O. Box 196247 Anchorage, AK 99519-6247 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 10/16/95 NO. 9809 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape · / 2A-22 ~. ~./,,(.,)(.~ 0 CDN 950528 I 1 2A-22 [ "/ 95218 CDR/CDN 950528 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA -'~ .,,:' ALASKA OIL AND GAS CONSERVATION COIVi,v~iSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well C~wlce Well 2 N~e of ~mtor 7 AR~ Alas~, Inc 3 Aadre~ 8 ~lNum~r P.O. ~x 100~0, A~hom~e~ AK ~51~0~0 5¢103-2~21 4L~tionofwellatsuda~ : . .- _ .... ~, 9 Unltor~e~me ...... ~ ~ r Ku~uk River 7~' FSL, 227' ~L, ~c 13, T11N, R8E, UM~~=~ ~~-~~, lO We llNum~r At Top Producing Intewal 1745' ~ 1013' FE~ ~. 16, T11N, R8E, UM .... ~:~;~ 2A-22 AtTot~p~ - . r.~ 11 ~old~dPool 1676' ~L, 1368' FE~ ~c. 16, T11N, R8E, UM ~ KUPARUK RIVER 5 Elevation In f~t (Indl~te ~, DF, etc.) 6 ~e ~gnation ~d ~dal ~. KUPARUK RIVER RKB 41' Pad 94' ADL 25571 ALK 2669 12 Date S~dd.~ 13 ~ T.D. R~h, 14 ~te ~mp., Susp. or A~d. I, 5 Water ~pth, If o~hore [10 No. of ~pletlons 1 ~May-95 27-May-95 6/11/1 ~5 (~d) NA f~t MSL 1 17 Tot~ ~pth (M~) 18 PI~ B~ ~h (M~) 19 DIr~ ~wey ~ ~p~ w~re S~V set 21 Thins of ~a~st 14797'MD &61~'~D 146~'MD &6082'~D YES ~ NO ~~ NA feetMD APPROX 22 Ty~ El~c ~ ~her L~s Run 1: G~C~C~ 23 C~ING, UNER AND CEMENTI~ RE.RD SE~G DEP~ MD CASI~ S~E ~ GR~ T~ ~ H~E S~E 16' 62.5" ~0 Sud. 121' 24' 2~ sx AS I 9.625" 40" L-80 Sud. 4~8' 12.25" 820 sx AS III Lead, 890 ~ Class G Tail 7' 26' L-80 Sud. 14787' 8.5' 2~ sx CI~ G 24 Pedom~ons o~n to P~uc~on (M~ of Top ~d ~om ~d 25 TUBING RE~D intew~, size ~d numar) SI~ DEP~ SET (MD} 3ACKER SET 3-1/2' 14~5' 14~7' 14352' - 14378' MD 5866' - 5~3' ~D 4 spf ~ ACID, ~CTURE, ~MENT S~E~E, ETC DEP~ INTERVAL (MD) ~NT & KIND ~ ~TER~L ~ED 14~2' - 14378' 10M~ ~/40, 176M~ 1~18 11M~ 10/14 27 PR~UCTI~ ~ST Date Fimt Pr~u~lon lMet~ of ~mtion (FIo~, g~ li~, etc.) ~5~ FLOWING Da~ of Test ~um T~ PR~UCT~N F~ OIL-BBL GA~MCF WATER-BBL CH~ES~E ~ GA~ ~TIO 7~ 20 H~ TEST PER~ ~ 1322 1282 40 176~ 970 FIowTu~ng C~ing Pre.ute C~CU~D OIL-BBL GA~MCF WATER-BBL OILG~VI~-~I (~) Press 271 1~ 2~UR ~TE~ 1586 15~ 48 24.~ 2~ ~E DATA Bdef d~cdption of lithology, ~i~, ~ur~, ~ent di~ ~d ~en~ of oil, g~ or ~r.~u~i~m~h~ ~ AUG 0 ]995 ~s~ 0il & Gas Cons. Commission ~ ~chorage Form 10-407 Rev. 7-1-80 Submit In duplicate 30. GEOLOGIC MAR(ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS ~ TRL.~ VERT. DE]=TI--I GOR, and time of each phase. Top Kuparuk C 14297' 5832' Base Kuparuk C 14352' 5866' Top Kuparuk A 14352' 5866' Base Kuparuk A 14537' 5981' 31. LIST OF ATrACHMENTS Daily Drillin~ History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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- ing 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 ,CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 4, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2A-22 (Permit No. 95-68) Well Completion Report Dear Mr. Commissioner: Enclosed is a revised well completion report for KRU 2A-22. The date completed in block 14 has been changed to reflect the date the well was perforated. Production data is included in block 27. A revised drilling history summary is also attached which includes the perforation activity. If there are any questions, please call 265-6206. Sincerely, Kuparuk Drill Site Development Supervisor AUG 1 0 1995 & Gas Cons. Commission Anchorage MZ/skad Date: 06/28/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2A-22 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8213 AFE: AK8213 TYPE:DEV AFE EST:$ 1951M/ 2540M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20221 FIELD: KUPARUK SPUD:05/19/95 START COMP: FINAL: 05/19/95 (1) TD: 121'(121) SUPV:JT 05/20/95 (2) TD: 3338' (3217) SUPV: OT 05/21/95 (3) TD: 4937'(1599) SUPV:JT 05/22/95 (4) TD: 4937' ( 0) SUPV: OT 05/23/95 (5) TD: 9183' (4246) SUPV: JT 05/~24/95 (6) TD: 11632 ' (2449) SUPV: RLM 05/25/95 (7) TD:12582' (950) SUPV: RLM 05/26/95 (8) TD: 14021 ' (1439) SUPV: RLM 05/27/95 (9) TD:14764' (743) SUPV: RLM MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 SPUD WELL Move rig from 2A-18 to 2A-22. Test diverter. Spud well @ 0600 hrs. 5/19/95. DAILY:S47,507 CUM:$47,507 MW: 10.0 DRILLING Drill from 121' to 3338'. DAILY:S89,030 CUM:$136,537 ETD:SO PV/YP: 33/22 EFC:$1,998,207 ~I~: 5.6 ETD:SO PV/YP: 52/21 EFC:$2,087,237 ~I~: 5.2 MW: 10.0 RUNNING 9-5/8" CASING Drilled from 3338' to 4937'. Run 9-5/8" casing. DAILY: $92,742 CUM: $229,279 ETD:SO EFC: $2,179,979 MW: 10.1 PV/YP: 50/24 APIWL: 5.6 PRESSURE TEST CASING Run 9-5/8" casing. Cement. Lost returns. Test BOPE. Prepare to pressure test. DAILY:S225,467 CUM:$454,746 ~ ETD:SO EFC:$2,405,446 MW: 9.2 DRILLING Drilled from 4937' to 9183'. DAILY: $77,308 CUM: $532,054 PV/YP: 9/ 7 ETD:SO APIWL: 7.2 EFC: $2,482,754 MW: 9.6 PV/YP: 11/ 7 APIWL: 7.4 CIRCULATE FOR TRIP Directional drill 8.5" hole from 9183' to 11632' . DAILY:S81,821 CUM:$613,875 ETD:SO EFC:$2,564,575 MW: 9.5 PV/YP: 10/ 7 APIWL: 7.4 DRILLING Mad pass through the K-10 with GR and CDR. Directional drill 8.5" hole from 11632' to 12582'. DAILY:S74,023 CUM:$687,898 ETD:SO EFC:$2,638,598 MW: 9.7 PV/YP: 15/12 APIWL: 5.6 DRILLING Directional drill 8.5" hole from 12582' to 14021'. DAILY:S85,393 CUM:$773,291 ETD:SO EFC:$2,723,991 MW: 10.6 PV/YP: 23/11 APIWL: 4.2 DRILLING Directional drill 8.5" hole from 14021' to 14764' . DAILY: $95,802 CUM: $869,093 ETD:SO EFC: $2,819,793 AUG 1 0 1995 Oil & Gas Cons. Commission ~choraDe Date: 06/28/95 Page: 2 05/28/95 (10) TD:14797' ( 33) SUPV: RLM 05/29/95 (11) TD:14797'( 0) SUPV:RLM 05/30/95 (12) TD:14797' ( 0) SUPV: RLM 05/31/95 (13) TD:14797' ( 0) SUPV: JT ARCO Alaska Inc. DAILY DRILLING REPORT MW: 10.6 PV/YP: 18/ 7 APIWL: 4.5 POOH Directional drill 8.5" hole from 14764' to 14797'. Circulate and condition mud for 7" casing. DAILY: $76,370 CUM: $945,463 ETD:SO EFC: $2,896,163 MW: 10.6 PV/YP: 17/ 8 APIWL: 4.6 CIRCULATE CASING Run 7" casing to 6412'. Hi clutch overheated, cause not yet determined. Run 7" casing to 14787'. DAILY:S213,392 CUM:$1,158,855 ETD:SO EFC:$3,109,555 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LAY DOWN DRILL PIPE Cement casing~ CIP at 1027 hrs. 5/19/95. Freeze protect 7" x 9-5/8" annulus. DAILY:S122,453 CUM:$1,281,308 ETD:SO EFC:$3,232,008 MW: 0.0 PV/YP: 0/ 0 MOVING RIG TO 2T Release rig 1900 hrs 5/30/95. Move to 2T-29. DAILY:SO CUM:$1,281,308 ETD:SO APIWL: 0.0 EFC: $3,232,008 Date: 06/28/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: 2A-22 WELLID: AK8213 AREA/CNTY: FIELD: SPUD: AFE: AK8213 START COMP: RIG:PARKER 245 WI: 0% SECURITY:0 TYPE:DEV AFE EST:$ 1951M/ 2540M STATE: API NUMBER: FINAL: 06/07/95 (14) TD:14787' PB:14698' SUPV:DCB 06/08/95 (15) TD:14787' PB:14698' SUPV:DCB 06/09/95 (16) TD: 14787 ' PB: 14698 ' SUPV:DCB 06/10/95 (17) TD: 14787 ' PB: 14698 ' SUPV: DCB 06/11/95 ( 189 TD:14787' PB:14698' SUPV:DCB 06/12/95 (19) TD:14787' PB:14698' SUPV:DCB RACK TUBING MW: 8.4 SEAWATER Move rig. Accept rig @ 1900 hrs 6/6/95. Test BOPE. DAILY: $43,025 CUM:$1,324,333 ETD:S0 EFC:$3,275,033 RUN COMPLETION TUBING MW: 8.4 SEAWATER Rack, drift and tally 3-1/2" tbg. Held safety meeting. Service rig, RIH with TCP guns, spaced out as per plan, tail pipe and SAB-3 packer on 3-1/2" L80 9.3# AB mod tbg. Safety meeting on TCP guns. Run completion tubing. DAILY:S33,345 CUM:$1,357,678 ETD:SO EFC:$3,308,378 RIH W/STANDING VALVE MW: 8.4 SEAWATER Continue to RIH w/3-1/2" completion string and SAB-3 pkr with TCP guns. Space out to calculated depth with gun top shot at 14353'(vs.352). RU Schlumberger WL and RIH w/ 1-11/16" GR/CCL, pump down @ 1-3/4 bpm. Tie in w/MWD as per plan. 5' shallow at packer. POH w/SWS and space out tubing. RIH w/SWS ccl/gr and confirm packer/gun depths. Packer approx. 1' deep, ok on spaceout. POH R/D SWS. Set BPV. DAILY: $176,197 CUM: $1,533,875 ETD:S0 EFC: $3,484,575 RIH W/STANDING VALVE MW: 0.0 Set CAT standing valve. Set SAB-3 packer. Pressure testing on tubing/annulus indicates communication. DAILY: $30,700 CUM:$1,564,575 ETD: $0 EFC: $3,515,275 SHEAR DUMP KILL VALVE @ 1 MW: 0.0 Continue to have problems with communication between tubing and annulus. Hold safety meeting; pressure annulus to 1500 psi, pressure tubing to 4000 psi to fire TCP guns. Hold pressure, gun response in 5 min 36 sec., good drop in pressure to 2800 psi, then slow bleedoff afterwards. Acts like fairly tight formation. DAILY:S146,830 CUM:$1,711,405 ETD:SO EFC:$3,662,105 RIG STACKOUT @ 2B PAD MW: 8.4 SEAWATER Freeze protect annulus.. Secure well. Release rig @ 1600 hrs 6/11/95. DAILY: $12,750 CUM:$1,724,155 ETD: $0 EFC: $3,674,855 End of WellSummary for Well:AK8213 ******************************************************** ~S~ED DEPTH TRUE '~" ~ ,ml i:',~ ! ~ · · DnPARiu~/-W) 0,00 0,00 0,00 283.70 MEqSbL~D P~.TKR-'JAL U~giC':,i TAF,~E? ~ATiON AZIMUTH DE:TH :"F.:'"" ' f..-. ft ft f~ de~ i2i,'JO 0,0 iSi,CQ 0.00 0,00 O,OO · ' ~ " 46v.~3 348.~ -¢.!.,:,z. 2,23 0,73 281,5'3 56!.37 .~ ,.~.: 4,.. 2,06 ~6.55 65!.14 ""' '" " ;v,v. 5,25 293,fl6 74i.;'2 '..--"0.~ 740.98 21.13 8,88 288,12 920:2B 1010.69 ~.;.u~o2.4. 1287.56 !475 = ,~4 !662,60 2223.99 2600,99 2~4,48 2977,~0 307~,45 90,4 t001,2l 87,02 18,05 · 90,6 1174.73 146,19 19.89 287,22 2~2..77/ 285.!7 286,15 288.50 93.5 1262.17 179.27 21.65 286,~8 2~4,% 23.12 286,35 93,7 ~'~ :l " ~ 94,2 1435,21 252,58' 24,02 285,52 9~ o+! i519.6~ 2~1.78 25.99 290,71 93.? 1~03,l.i 3~,59 28,50 286.84 92,3 17~,'28 95,0 94,0 1972,57 380.!'5 3!,86 288,37 431.45 35.94 288,25 489,46 39,60 287;10 552,06 42,62 287,74 617.47 45,60 286,63 ~50.70 4!6%53 4472.30 2A-22 4752,3! 5032,01 · 5577,i2 93.9 2¢~6.:0 ~8o.~ 48.82 94,0 2096,~2 758,40 51.54 94.? .~5o,o~ 834,26 54,74 93,0 2204.~ 911.62 57,93 95.1 pf. 53,4L 992,41 60,67 LATITUDE ft ft ft 0,0¢ 0.00 3~46 ,,. o -:,1, 2.~ I..~ -4,23 4,43 3.72 -9,43 !0.,14 7,59 ,!9.89 21,29 · · 12.77 -36,24 18.4C -)7.62 24,86 ~: -8~,~1 ~2.75 '111,64 41,71 -140,30 DK~AR.%.~. D!SP!.AC~IiT at 38+42 60,4? 87.i3. 116,34 146.37 51,6~ -171.93 61.80 -206.16 72.14 -242,39 84.42 -279,74 98,2C -320.4) 179,53 215,22 252.90. 2?2.20 325,16 95,2 ~c~,~. 1162,86 66,59 93,4 ~"~ '~ ~4~ 94.2 2404.4~ 1~7J2 71,59 94,1 243L36 !4~?,7i 75,22 2q9,3 2505,7! 169&88 73,8? J7~.9 2579.]5 ~96~.¥: 75.57 2~1.2 2653,D 2237.27 73+95 278J 2726~31 2506.14 75,59 2~.8_ ' ~.aa~.~..~2778,~4 73.47 .. 2~.0 26~2.61 3046.68 72,94 Y3,7 zVl~.~ 3130,U~ 185,9 297I+2B 321!,81 70,02 2o.,6 3¢J66,09 3581,37 , ,23 279.2 3!~63 2845.45 70,77 287,93 285,85 .284,2! 283,79 112.04 :-363,97 128.21 '-412..83 ,' 145.84 -.468,24 164,62 -528,10 183.97. -590.7I 2C4..48 -656,56 2~ ~ -725,66 2~5,64 -798.8I 265,16 2~,4,~ -953.04 380,82 432;28 4?0,43 553,16 618,69 687,67 75%87 8~,73 913.03 994,72 284,40 30~. i4 '1023,41 1077.52 284,&6 326,&6 -1117,23 1164;06 284,45 348.53' - 1200.69 1250.25 285,25 371+21 .-1286.!9 !338,69 284,24 394,16 -1373,43 1428,87 0.00 281.'f~ 287.46 291,56 290.87 289.41 287.70 286,58 286,35 .2~6,56 286.73 286,69 '286,57 286,79 287,04 287,!t 287,25 287.31 287,30 287.26 287.09 286,&8 286,65 286,45 286,31 266,19 286,10 286,01 283,69 459,I¢ -1~4,65 1697,90 285,69 283,53 522.40 -18%,18 1966,&2 285,40 283,15 5~5.~ -2!60,18 22~,'99 285. 284,17 '648,50 -2421,~ 2506,78 283.!5 712,~ -2686.~ ~9,~ 2~.86 282,26 771,85 -2947,74 304.7,12 282.25 790,&2 .-3035.10 3i36,44 281,95 827.66 -3207.03 3212,1i 283,15 ~6,26 -3470,20 3581,58 283,26 946.57 -37Z7,31 384.5.63 284,67 284.60 284,47 284.33 284.~ D~ ..4 .,-j m ' I~t 0.00 3.56 4.07 4.47 .0.82 1.52 1.57 3,17 3+27 3,79 4.43 3,92 3,20- 2,48 3,37 3,35 3,44 3.52 3(83 2.52 1,80 3,62 4,00 0,51 0',60 10,69 0.82 0,36 ~ ~7 1,10 0.58 · 0,17 .. 3 ~EASbR~, iNT~VAL~RTICAL T~G~ STATION A!iMbTH DEPTH 5~'TH S~3TiON INCLH, f~ fr ft ft deq deg 57~A.98 187.~ 3216.0! 4022.79 72,64 282,60 6252.31 281,4 32~42,2~ 4473.24 73,~ 2~3.94 6527.56 275.2 3423,01 4736.87 72.67 2~3,54 6606,~2 281,4 350i+23 5007.12 75...05 284,05 7090,26 736~,06 7649.2~ 792!.62 9611,I5 9889,59' 1O168.95 10449,54 I0721,~7 11253.70 11466,27 11678.65 28t.3 ~575,00 527~,33 74,12 278,8 36~,.Jf ~45,64 72,87 280,2 ~32.75 5814,90 74.99 · 252.3 36~,35 . &087,45 74.78 ~9,0 2~8~,39 6356.41 74,45 279.6 3~S5,77 ~525.31 73,84 282,0 4036,?1 6895,68 '73+14 285,1 4119,65 7168.45' 73,10 271,5 '4!99,18 7428.06 72.85 282+4 4282,]7 7697,70 72,55 278,4 2'/9,4 280,6 282+3 2,77,1 274,8 182,7 212,3 273~4 272,3 283,69 283.44 284,02 284.51 284,4i ~TiTUDt: DEPARTI.Kd~ DISPb~C~ at 12e5,75 -5119.46 13¢~.47 -5379,32 1412,~ -5640,8~ 1479.55 -5905.04 1546,7! -6165,5~ 5278,46 5545,76 5815,01 6087.58 6355.55 ~Z!~TH 284.~o 284.16 284,15 284,12 284.11 284,10 284,07 284,07 284,08 12498.68 27;.3 12773.2? 274.6 13047.3i 274.0 !~23i07 2~4.05 283,37 283,26 283,2~ 283,65 !612.81 -6426.17 1676,6~ -6688,82 I7~.71 -6954,28 1799,22 -7206,9~ 1862,1~ -7~9,18 6625,47 7428,17 7697,81 284,09 284.07 '284.05 284,02 284,00 · 13418,i2' 95,0 ,SSv6,vO 13597,35 91,3 1~88.44 ?i,I 13760,50 ?2,4 426t,35 7964,91 74,84 4&37.'0I '8233.79 73.74 · 451.5,71 8502,76 73,26 4598,5~ 8772.?1 73.03 46.'63.16 ~036,55 71,43 7'71.72. 9296,56 .70[97 4c?,0,82 944,9,41 7!,28 46%.65 671,20 72.58 SO ,,l 1019S.40 74,14 5[23,54' 10459,14 73,97 51~,:! 10722,89 73,96 52E0,13 10984,29 71,78 53~.95 11160,48 70,78 S370,05'11244,53' 69,87 282.&1 282,51 282;59 .282,43 280.8~ 283.95 284.56 284.08 283.16 I"~3.~ 1982,2~. '2040,7C. 209%22 2152,52 -7729.31 -7Wl,69 -8254,2~-8518,08 · -8776,45. 220~.46 -?030,44 2250.~ .-9198,20 22~,66 '93~3.82 2'~.4,~ -9647.7& 2426.16 -~02,52. 7965,00 8223184 8502,81 8772.~ 9296,5:6 9469,41 .9671,2! 9922.28 10195,4! 2~.'.97 283.93 12~,89 282,84 283.78 283.74 282,75 283,76 283,77 283.77 5'~3,~ 11~3.'21 68.43 5437,44 II4!4,~ 66,67 5474,42 11497,68 65,57 ~12,39 11580,36 65.I6 5~52,07 11.~3,57 63,95 ~/~.~ 9!,5 ~94.24 I1744,53 61.17 !3962.81 90,5 5639.7~ 11822,52 58.40 14051.78" 89.2 ~67.57 1!877,70 56,78 i~i44.~5 93,0 57~,04 11974,33 54,50 .!426&.47 !21.5 5--8.13,06 12071.38 51,64 282.~ 280,84 279.9? 280.51 280,70 280.43 280.28 .280,69 '. 280.4? 279,02 280.61 280,64 280o90 281,36 2~4~ -10159.74 2537,86 -I0418,23 25.95,1~ -I0675,77 2616,53 -10849,4& 2622,0! -10~22,20 · . 264~.30 -11019,5! 2~2,~ -110~,41 26~,32 -11262,D2 2707,~2 -11345,10 . . 2720,34 -11425,31 2733.65 -11502~34 U47,~ -11576,~ 2761.87 -11651.72 27E0+61 -t1747,03 10459,14 10722;89 10~84,31 111&0.51 11244,57 11223,27 11414,37. 11497,78 11580,47 1Ib63,71 11744,70' !189.2+72 11897,92 11974,58 12071.64 282,74 283,69 282,61 283.55 283,54 203,51 283.49 282.47 2&3.45 283,42. 283.39 283.37 283.35 283.34 283.32 ,,.a. . 0,33 0.48 0.87 0,46 0,78 .0,18 0,!2 0.25 0,34 0,04 0,09 0.16 0,41 0~17 O,.lO. 0°78' 1.07 0,17 0.68 .0.34 0;26 0,56 !,04 1,54 !.28 0.48. 1,87 3.04 3,42. 2~47 2.37' ft ~t ~t 14777,00 84,5 6!~3.90 ARCO Alaska, Inc. Date: August 25, 1995 Transmittal #: 9291 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATe-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed co~y of this transmittal. 2A-18~ Directiona[Survey ~~'~__~,-22~ ~'- O (~(~ Directional Survey ~ ' Directional Survey . Directional Survey _ Directional Survey Directional Survey Receipt Please acknowledge receipt and 5/18/95 AK7621 5/19/95 AK8213 6/23/95 AK8173 6/9/95 AK8237 7/2/95 AK9229 5/31/95 AK8157 Directional Survey Direftional~~/,//~ .Sur~ey ~/~~Dat7~~e tg5'~. 7/11/95 ........ AK8181 AK8253 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 :>:.:l~rry Grant (2 copies)=. 3001 Porcupine Dr. Anchorage, AK 99501 .6, 1°O~,~o 9'39P5~~ ARCO i. LASKA Ii-IC iso, ALA" '~' OIL AND ~ ~ERVA~ APPLIC~FION FOR SUNDRY APPh~VALS I, Type of Request: Abandon _ Su~end_ Operation 3hutdown _ Re-enter suspended well_ I Alter ¢~slng _ Repair wall _ Plugging _ Time extension _ Stimulate .... Ci~ange approve0 program ~ Pull tubing _ Vsrlsn~e _ Perforate ._ Other ~;-'~ame of Operalor " 5. Type of Well: ..... 6. Datum ~evatkm' (DF or K~)' ' Oavetopmeni ~ ARCD Alaska. InC, ....... Exploratory _ RKB ~,_l.'_Pad_level 94' feet 3. Address Stratigraphi¢ _ 7. Unit or Property n~me P, O, Box 100360, Anchorage, AK 99510 s .aT,,[.~' _ Kuparuk River Unit 4. Lo¢~tien o! well-~t surface ~. Well number 756' FSL, 227' FWL, Sac. 1:3, T11N, RSE, UM 2A.22 At top of productive interval 9, Permit number 1634' FNL, 1071' FEL, Sec, 18, T11N, R8E, UM 95-68 . At effective depth 10. APl number ___~.103-2q221 At total depth 11. FieldtPooi Kuparuk River Field ~.~.~.~' I=NL, 1278' FEL, Sec. 16,_ ..T, 11N, RSE, UM KBp.~r~.k._Riv_e.r. Oil Pool ~'2. 'Present we!l condition summary Tol~I Depth' measured 14861' teat Plugs (estimated: still drlliln~l well) true verticaJ 6 1 7 8' Effective depth: measured 14861' I~eet Junk (estimated; still drilling well) true vertl~l 61 7 6' [sat Casing Length Size Cemented Measured depth True vertic~l depth Structural Conductor 8 0' I 6" 250 Sx AS I 1 21' 1 21' Sur~ac~ 4807' 9-5/8" 878 sx AS Iil & 4928' Intermediate 890 sx Class G Production L[ner P~rf~ru[i~n depth, measured None true vertical Tubing (SiZe, grade, and rneasursd depth Pa~er$ and $~3SV (type and measured depth) _-. 13. "A~chment~ Description ~t, mm~ry ~ pmlm.~i _ Detailed operation program X_ ~oP ~,ketch _ · ., '14. Estim~i'ii~[ date for commenolng ~'~oretio~ JS. Status of wall ¢l~si]ication ~;[27/~i ~ , , Oil ~ Gas _ $usBended _ '1~, if propoeaJ ws~ varball'y--a~'prov~.d Name of ap,prover Date approwd Service -{~'-," ;~ereby cer~j~ that the foregoing is' true and corre~ to the best o! my knowledge. -~nd[tions el approval: cfi Commiss-i~ so representative may witness IApprov~ No. _ . Plug integrity j~ BOP Teat._. Lo~tton ~learance~ .L_, Ma~anical integrity Test -,,-- Subsequent form require 10- .~_roved Copy / (Jriginal Signe0 By Returned A~pro..ved b~ ,ha order el~ the Co .nl~ll.s.,io~ David W. Johnston, , ,. ..... &/.L~,~.~'~._..,.,,,,,,,..,,.,, ,., -Date Form 10-403 Hey 0u/15/88 5LIBMIT IN TRIPLICATE RECEIVED t~L~¥ ?- 6 '~995 Oil & Gas Cons. Anchorage .6, I~g5 2'40P14 ARcO ~.LA~I£A !i'!C ~,u, ~.,.o~ ~, KRU 2A-22 P & A 8-1/2" Production Hole Kuparuk River Unit Well ZA-22 is being drilled to the planned Kuparuk Target location ~,d TD is estimated to occur on 5/27/95. In the event that the open hole logs indica~te fire well is not economic as a ro~u]~ of a ~hin pay interval, ARCO Alaska, Inc. requests approval to plug and abandon the 8-1/2" production hole. Tlte surface hole of Llxe well will be used to sidetrack the well to ~ alternate Kupamk target location. The detailed proeedttre for plugging the 84/2" ~on nf 'tho. wo.ll will be. So.hr in if the P & A is required. In summary, a cement plug will be placed from TD (I~,,861' estimated MD) to a minimum of 100' ~bove the top of the Kuparuk Formation (14,448' estimated top, MD; 14348' top of cement). A ~econd plug wilI be set in the 8-I/2" open hole from 5500' MD to 4800' MD (I30' inside 9-5/8" surface casing shoe). This plug will b~ used to kick off the well to the alternate location. Kill weight mud (10.6 ppg estimated) will be left in the open hole in between the two plugs. Approval to side track the well to the alternate location will be requested via a Permit ~:o Drill Form. If you have any questions or comments rega.tding the attached procedure, please con~act myself at 263-6206 or the Drilling Engineer, Denise l~etra~h at 263-4183. ARCO Alaska, Inc. I FACSIMILE TRANSMISSION Phone: · I Location: II Location: FAX #: Phone #: i Il Il I El Ii I] · II I! I II II I] · I! III I II II I I iiii ~11 i I I..,. ,, ,, .I lb Il II I Il Il 11 i III l! I II Il Il II Il Ill I Il Il Il I~I II I II II II · [I II I II II II · II II · II II · [~ Il II I II H III H II II I II 14 III Il II II I H II U I II II II I II II IIII ,!! !! !! ! !! IIfil,~ liiiiiiiii ii iII I! II II I II II II II I II II II II I Ii II II II I "" !' "' "!! ![!.~l Kuparul( Drill ~lte IJevelopment P, O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATO-12O9 Copies To: -- I II Subject: i- , Comments: Alaska 0il & (~as Cons. Anchorage ~6, ~99,5 KUPARUK i,.,ER UNIT WELL #2A-22 WEL~._.ORE DIAGRAM 16" CONDUCTOR AT 121' CEMENTED TO SURFACE 9-5/8", 40#. L80 W/SHOE AT 4928' Cemented with 878 sx AS anti s90 sx Class G to sur/ace Planned Kick Off Point: 5000' Depths are estimated only; still drilling original well ila . EuL. Tup Kuparuk; 14450' Est. Base Kuparuk: 14660' 17,0 PPG Cement · ~.~.~.~.~.~.~.~.~. ~ ,~ 10.6 PPG t5.8 PPG Cement Est. TD 14861' Cement plug for kick off: 280 sx Class G 5500' - 4800' 8-1/2" OPEN HOLE Cement Plug; 15.8 ppg, Class G 14350' - 14861' (175 sx) ARCO Alaska, lac. KRU 2A-22 RECEJV g !-~:~,Y £ 6 t.995 ~as.ka 0it .& (;as Cons. uotnmisSlu" Anchorage DKP 5/26Ig5 ALASI~A OIL AND GAS ! CONSERVATION COMMISSION TONY KNOWLE$, (~OVEI~NOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 15, 1995 Michael Zanghi Drill Site Development Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2A-22 ARCO Alaska, Inc. Permit No:~ 95-68 Sur. Loc. 756'FSL, 227'FWL, Sec. 13, TllN, R8E, UM Btmhole Loc. 1559'FNL, 1378'FEL, Sec. 16, TllN, R8E, UM Dear Mr. Zanghi:' 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 law 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 below 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. Sincerely, Russell A. Doug~ Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CCl Department of Fish & Game, Habitat Section w/o encl. Department~of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,,.,N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-~ lb Type of Well Exploratory [-1 Stratigraphic Test r-] Development Oil X Re-Entry r~ Deepen E] Service r~ Development Gas E] 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 94' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25571, ALK 2669 4. Location of well at surface 7. Unit or property Name 1 1, Type Bond (see 2O AAC 25.O25) 756' FSL, 227' FWL, Sec. 13, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1634' FNL, 1071' FEL, Sec. 16, T11N, R8E, UM 2A-22 #U-630610 At total depth 9, Approximate spud date Amount 1559'FNL, 1378'FEL, Sec. 16, T11N, RSE, UM 5/1 6/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15, Proposed depth (MD and TVD) property tine 2A-1 8 14861' MD 1559 @ TD feet 20' @ 580' MD feet 2560 6176' TVD feet 16, To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 580' feet Maximum hole angle 73.28° Maximurnsurface 1 708 psig At total depth (TVD) 31 00 pslg 18, Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD {include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 4636' 41' 41' 4677' 2885' 820 Sx Arcticset III & HF-ERW 820 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 14820 41' 41' 14861' 6176' 220SxClassG HF-ERW Top 500' above Kuparuk 1' 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°~dacUeCt°r R E C ~ IV ~ D Intermediate Production Liner [¥1~V 1 0 Perforation depth: measured true ,,ertica~ Alaska 0ii & Gas Cons. Commission /~ch0ra 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis g] Seabed report I-'] 20 AAC 25.050 requirements X 21. I hereby certify,that the foreg91ng is true and correct to the best of my knowledge Signed ' Title Drill Site Develop. Supv. Date ,. Permit_Number C I A'"~number Commission Use Only .~,~-'~ ~" ~'~0-/~7)~,~ - .~..4:~:' <?- ,;~_- ~/ I Approval da~t~~//~ ~ [ See cover letter fOr/other requirements Conditions of approval Samples required E] Yes [[~ No Mud Icg required E] Yes ~ No Hydrogen sulfide measures [~ Yes r-] No Directional survey required [] Yes r~ No Required working pressure forBOPE [--] 2M [~ 3M E] 5M [-] 10M E] 15M Other: Approved by RUSSELL A. DOUGLASS Commissioner the commission Date Form 10-401 Rev. 7-24-89 S{ tri[~licate o . . 10. 11. 12 13 14 15 16 17 GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2A-22 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,677')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (14,861') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if cased hole logging planned), or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM Well 2A-22 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,708 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2A-22 is 2A-18. As designed, the minimum distance between the two wells would be 20' @ 580' MD. Incidental fluids developed 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. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2A-22 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Risks in the 2A-22 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. R E £ E IV E D fvlAY t 0 1995 Al~sk~ 0il & Gas Cons. Commission Anchors. ? TD LOCATION : 1559' FNL, 1578' FEL A C0 ALASKA, Inc. Structure : Pod 2A Well : 22 Field : Kuporuk River Unit Location : North Slope, Alaska Created by : jones For: D PETRASH Date plotted : 13-Apr-95 Plot Reference is 22 Version #5. Coordinates ore in feet reference slot #22. True Vertical Depths ore reference wellhead. SEC. 16, T11N, RSE ¢ ~ West Scale 1- 575.00 12750 12000 ! 1250 10500 9750 gooo 8250 7500 6750 6000 5250 4500 3750 5000 2250 1500 750 o 750 L 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 TARGET LOCATION: 1654' FNL, 1071' FEL SEC. 16, T11N, RSE TARGET TVD=5910 TMD=I 4448 DEP=12205 NORTH 2890 WEST 11858 3750 750 _ m 750 _ ~L 1500_ - 2250_ (D 3000. 3750_ 4500_ V N 76.3 DEG W ,~,o'~ lZZ05' (TO TARGET)R ,o~ ECEiVED 5250 _3000 _2250 j - I _1500 Z - 0 _ 750 ~ -- ., 750 g 6000_ 6750. RKB ELEVATION: 135' MAY 1 0 199,~ KOP TVD=580 TMD=580 DEP:O ~'%% Alaska 0il & Gas Cons. Commission · BUILD 3 DEG / 100' . ~,,8.oo Anchora ? SF~'FACE LOCATION: ~,27.00 B/ PERMAFROST TVD=1515 TMD=1557 DEP=245 I k36.o0 T/ UGNU SNDS TVD=1560 TMD=1609 DEP=271 J /ob' I 756' FSL 227' FWL co ""~'~%.00 T/ W SAK SNDS TVD=2274 TMD=2665 DEP=1028 '"'---Z_2.00 - EOC ~/D=2409 TMD=3023 DEP=1560 ~-"'"--~- B/ W SAK SNDS TVD=2685 TMD=5982 DEP=2279 ~..~._ 9 5//8'' CSG PT ~¢D=2885 TMD=4677 DEP=2945 ~K-IO TVD=5145 TMD:5581 DEP=5810 MAXIMUM ANGLE ~~ 73.28 DEG K-5 TVD=4545 TMD=10448 DEP=8471 BEGIN ANGLE DR P TV 1 l 0 D=536 MD=13284 OEP=Ill88 --=,. ~,-, '~ 72.0~0~,00 B/ HRZ TVD=5662 TMD=14023 DEP:11861 ~ 60'%0400 TARGET - T/ ZONE C (EOD) TVD=5910 TMD=14448 DEP=lgg05 ~ ' TARGET ANGLE v ZONE A TVD=Sg32 TMD=14482 DEP=12231~"~k""'~ 50 DEG T// A3 SNDS TVD=5972 TMD:14544 DEP=12279 ¥' B/ KUP SNDS TVD=6047 TMD=14661 DEP=12368 TD / 7" CSG PT TVD=6176 TMD=I4861 DEP=12522 750 0 750 1500 2250 ,3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 Scale 1 : 575.00 Vertical Section on 285.70 azimuth with reference 0,00 N, 0.00 E from slot #22 ARCO ALASKA, Inc. Structure : Pad 2A Well : 22 Field : Kuparuk River Unit Location : Nor-ih Slope, Alaska Created by : jones :For: D PETRASH Date plotted : 13-Apr-95 Plot Reference is 22 Version #5. Coordinates are in feet reference slot #22. True Vertical Depths are reference wellhead. A I I o o o .. 280 . 24O 200. 160 120 80 80 120 160 20O 560 520 480 440 400 560 140C 3100 Z700 ~800 1300 1700 560 520 480 440 400 360 <~- Wesf 520 280 240 200 1400 800 520 < 28O 240 Scale 1 · 20.00 160 120 80 40 0 40 80 I I I I I I I I [ I ] I I RECEIVED Alaska Oil.& Gas Cons. Commission Anchors. ,' 200 160 Wesf 2200~ 1800 120 80 40 28O _ 240 _ 2OO 160 _ 120 _ 80 _ 40 600 -t 120 %,%29 O0 160 I~ I 200 o 0 40 80 Scale 1 : 20.00 8O I I Z 0 KUPARUK RIVER UNI1 20" DIVERTER SCHEMATIC 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) _Al~s~ Oil & Gas Con~ C~m:~i';rJon ,. '__Anchor:,~ 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. DKP 11~4 ! i 3 2 13 518" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ 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 LOWI;R EMIT IS45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRE~.~IRF_ BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT All HOLI~DOWN SCREWS ARE FULLY RETFIACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELlhEAD. RUN IN LCX~K-DOWN SCREWS IN HEAD. :~ CLOSE AM~ULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALLCOMPONENTS TO 250 PSI AND HOLD FOFI 3 MINUTES. INCREASE PRESSURE TO ~_'2z300__ PSi AND HOLD FOR 3 MINLITES. BLEED TO ZERO PSI. 5. OPEN AMqULAR PREVENTOR AND MANUAL KILLAND CHOK~ MNE VALVE& & CtJ3SE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE MNI;~ 7. TESTTO 250 PSI AND 30(X) PSI AS IN STEP 4. CX3NTINUE TE~ ALL VALVES, MNES, AND CHOKES WITH A250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING PosrrlVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PiPE RAMS. TEST BoI'rOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS, BACKOFF RUI~IING JT AND PULL OUT OF HOL~ CLOSE BUND RAMS AND TESTTO 3(X)0 PSI FOR 3 MINUTES. BI m=nTO ZERO PSI. 10. OPEN BENO RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL ANO ALL VALVES ARE SET IN THE DRILUNG Posm(~. 11. TEST STANOPIPE VALVESTO 3000 PSI FOR 3 MINUTES. 1Z TEST KELLY ~AND INSIDE BOP TO 3000 PSi WITH KOCML~ PUMP. 1:~ RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TESTONCE A WEEK AND FUNCTI~Y OPERATE BOPE DAILY. 1. 16' - 2000 PSI STARTING HEAD 11'. 3000 PSI CASING HEAD 11'. 3000 PSi X 13-5~'- 50(X) PSI SPACER SPOOL 4. 13~8'. 5000 P~ PIPE RAMS 13~:~/8' - 5(XX) PSI DRLG SPOOL W/ 13~/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13~/8' - 5(XX) PSI ANNULAR 'WELL PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA UNIT# PROGRAM: exp [] .///Jo dev~ redrll [] serv [] ON/OFF SHORE O~ ADMINISTRATION ENGINEERING GEOLOGY APPR DATE 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ...... N 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ......... N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. N 12. N 13. N Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... -~ .,~_ 26. BOPE press rating adequate; test to ~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown. . . 29. Is presence of H2S gas probable ............ 31. 32. 33. 34. Permit can be issued w/o hydrogen sulfide measures .... Y Data presented on potential overpressure zones .. .... Y//~ Seismic analysis 9f shallow gas zones .......... ~ N Seabed condition survey (if off-shore) ........ /Y N Contact name/phone for weekly progress reports /. Y N [exploratory only] ' ' ' ~ ' GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ C~mments/Instructions: HOW/jo - A:%,'=ORMS%cheklist rev 03/94 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 NAME : ARCO ALASKA INC. WELL NAME : 2A-22 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032022100 REFERENCE NO : 95218 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-0CT-1995 16:22 **** REEL HEADER ,4,, SERVICE NAME : EDIT DATE : 95/10/12 ORIGIN : FLIC REEL NAME : 95218 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2A-22, API #50-103-20221-00 PAGE: 44** TAPE HEADER ,4** SERVICE NAME : EDIT DATE 95/10/12 ORIGIN : FLIC TAPE NAME : 95218 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2A-22, API #50-103-20221-00 TAPE HEADER KUPARUK RIVER 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: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD BIT RUN 1 95218 ST. AMOUR MORRISON 2A-22 501032022100 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 12-0CT-95 1ST STRING 2ND STRING BIT RUN 2 BIT RUN 3 13 11N 8E 756 227 135.00 94.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. oo LIS Tape Verification Listing Schlumoerger Alaska Computing Center 12-0CT-1995 16:22 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LOGGING WHILE DRILLING DATA OF CDR RESISTIVITY AND CDN DENSITY/NEUTRON TOOLS. $ **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves~ all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 5459.0 14797.0 CDN 11512.0 14797.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH MERGED DATA SOURCE LDWG TOOL CODE CDR CDR $ CDR CDR CDN BIT RUN NO. MERGE TOP i 11572.0 MERGE BASE 5712.0 14797.0 REMARKS: THIS FILE CONTAINS THE EDITED DATA OF DRILLING PASS 1 CDN FROM 11512' TO 14797'. MAD PASS #1 OF THE CDR (5459' TO 5712') WAS MERGED WITH THE DRILLING PASS 1 OF THE CDR (11572' TO 14797). NO CDR/CDN DATA WAS ~ ACQUIRED OVER THE INTERVAL FROM 5712' TO 11512'. THIS DATA HAS NOT BEEN DEPTH CORRECTED AT ARCOs REQUEST. $ LIS FORMAT DATA LIS Tape Verification Li~ting' Schlumberger Alaska Computing Center 12-0¢T-1995 16:22 PAGE: 3 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN KUPARUK RIVER Field Name WN 2A-22 Well Name APIN 501032022100 API Serial Number FL 0756' FSL 0227 FWL Field Location SECT 13 Section TOWN 11N Township RANG 8E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LATI 70 18 08.755 N Latitude LONG 150 O0 40.217 W Longitude WITN MORRISON Witness Name SON 57001 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF DRILL FLOOR Log Measured From APD FT 135. Above Permanent Datum EDF FT 135. Elevation of Derrick Floor EGL FT 94.3 Elevation of Ground Level TDD FT 14797. Total Depth - Driller TDL FT 14797. Total Depth - Logger BLI FT 14797. Bottom Log Interval TLI FT 5459. Top Log Interval DFT LSND Drilling Fluid Type DFD G/¢3 10.2 Drilling Fluid Density RMS OHMM 1.813 Resistivity of Mud Sample MST DEGF 73. Mud Sample Temperature RMFS OHMM 1.676 Resistivity of Mud Filtrate S MFST DEGF 73. Mud Filtrate Sample Temperatu BHT DEGF 150. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA RP VRA VRP DER ROP GR ~ FET RHOB DRHO PEF CDR ATTN RESISTIVITY CDR PHSF RESISTIVITY QRO VERY ENHANCED AMPLITUDE RESISTIVITY QRO VERY ENHANCED PHASE RESISITIVTY DIELECTRIC RESISITIVTY RATE OF PENETRATION Gamma Ray TIME AFTER BIT Bulk Density Delta RHO PhotoElectric Factor LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-0CT-1995 16:22 DEFI CALN NUCLEAR CALIPER NPHI Thermal Neutron Porosity PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** 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 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57001 O0 000 O0 0 1 1 I 4 68 0000000000 O0 000 O0 0 i I 1 4 RA MWD OHMM 57001 68 0000000000 RP MWD OHMM 57001 O0 000 O0 0 I I 1 4 68 0000000000 VRA HWD OHMM 57001 O0 000 O0 0 1 i i 4 68 0000000000 VRP HWD OHMM 57001 O0 000 O0 0 I I i 4 68 0000000000 DER MWD OHMM 57001 O0 000 O0 0 1 i 1 4 68 0000000000 ROP MWD FPHR 57001 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 57001 O0 000 O0 0 I I I 4 68 0000000000 FET MWD HR 57001 O0 000 O0 0 1 i 1 4 68 0000000000 RHOB MWD G/C3 57001 O0 000 O0 0 1 i 1 4 68 0000000000 DRHO MWD G/C3 57001 O0 000 O0 0 I i 1 4 68 0000000000 PEF MWD BN/E 57001 O0 000 O0 0 i i i 4 68 0000000000 CALN MWD IN 57001 O0 000 O0 0 1 i 1 4 68 0000000000 NPHI MWD PU-S 57001 O0 000 O0 0 i i I 4 68 0000000000 LIS Tape Verification Listing Schlumoerger Alaska Computing Center ** DATA ** DEPT. 14797.000 RA.MWD VRP.MWD -999.250 DER.HWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 14700.000 RA.MWD VRP.MWD 3.195 DER.MWD FET.MWD 0.826 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 14600.000 RA.MWD VRP.MWD 3.097 DER.MWD FET.MWD 1.178 RHOB.MWD CALN.MWD 9.122 NPHI.MWD DEPT. 14500.000 RA.MWD VRP.MWD 3.920 DER.MWD FET.MWD 1.378 RHOB.MWD CALN.MWD 9.245 NPHI.MWD DEPT. 14400.000 RA.MWD VRP.MWD 7.446 DER.MWD FET.MWD 1.270 RHOB.MWD CALN.MWD 9.077 NPHI.MWD DEPT. 14300.000 RA.MWD VRP.MWD 46.416 DER.MWD FET.MWD 2.088 RHOB.MWD CALN.MWD 9.445 NPHI.MWD DEPT. 14200.000 RA.MWD VRP.MWD 2.385 DER.MWD FET.MWD 1.183 RHOB.MWD CALN.MWD 8.995 NPHI.MWD DEPT. 14100.000 RA.HWD VRP.MWD 3.241 DER.MWD FET.MWD 6.689 RHOB.MWD CALN.MWD 9.520 NPHI.MWD DEPT. 14000.000 RA.MWD VRP.MWD 7.747 DER.MWD FET.MWD 0.954 RHOB.MWD CALN.MWD 8.500 NPHI.MWD DEPT. 13900.000 RA.MWD VRP.MWD 4.205 DER.MWD FET.MWD 0.758 RHOB.MWD CALN.MWD 8.500 NPHI.MWD 12-0CT-1995 16:22 -999.250 RP.MWD -999.250 -999.250 ROP.MWD 38.822 -999.250 DRHO.MWD -999.250 -999.250 2.825 RP.MWD 3.142 3.013 ROP.MWD 82.911 -999.250 DRHO.MWD -999.250 -999.250 2.756 RP.MWD 2.934 ROP.MWD 2.531 DRHO.MWD 37.100 3.425 RP.MWD 3.739 ROP.MWD 2.497 DRHO.MWD 36.800 6.485 RP.MWD 6.858 ROP.MWD 2.502 DRHO.MWD 27.800 11.851 RP.MWD 19.422 ROP.MWD 2.844 DRHO.MWD 29.200 1.708 RP.MWD 1.987 ROP.MWD 2.402 DRHO.MWD 43.200 2.700 RP.MWD 3.000 ROP.MWD 2.343 DRHO.MWD 44.900 4.501 RP.MWD 6.435 ROP.MWD 2.380 DRHO.MWD 41.500 2.716 RP.MWD 3.300 ROP.MWD 2.166 DRHO.MWD 43.000 3.056 47.733 0.175 3.954 41.545 0.130 7.005 56.784 0.127 21.570 109.460 0.036 2.306 32.967 0.045 3.238 199.970 0.055 7.324 148.382 0.086 3.962 46.430 0.093 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.HWD GR.HWD PEF.MWD PAGE: -999.250 -999.250 -999.250 2.953 102.952 -999.250 2.737 101.650 3.807 3.507 101.676 4.131 7.131 82.318 3.579 43.790 61.336 7.O59 1.806 115.128 4.084 2.707 124.365 4.824 4.972 210.976 4.517 2.854 298.520 2.711 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 13800.000 RA.MWD VRP.HWD 5.409 DER.MWD FET.HWD 1.598 RHOB.MWD CALN.MWD 9.784 NPHI.MWD DEPT. 13700.000 RA.MWD VRP.MWD 5.279 DER.MWD FET.MWD 1.658 RHOB.HWD CALN.MWD 8.500 NPHI.MWD DEPT. 13600.000 RA.MWD VRP.MWD 4.918 DER.MWD FET.MWD 1.492 RHOB.MWD CALN.MWD 8.500 NPHI.MWD DEPT. 13500.000 RA.MWD VRP.MWD 5.236 DER.MWD FET.MWD 1.115 RHOB.MWD CALN.MWD 9.215 NPHI.MWD DEPT. 13400.000 RA.MWD VRP.MWD 8.047 DER.MWD FET.MWD 0.956 RHOB.MWD CALN.MWD 9.009 NPHI.MWD DEPT. 13300.000 RA.MWD VRP.MWD 4.447 DER.MWD FET.MWD 0.953 RHOB.MWD CALN.MWD 9.515 NPHI.MWD DEPT. 13200.000 RA.MWD VRP.MWD 11.188 DER.MWD FET.MWD 0.500 RHOB.MWD CALN.MWD 9.484 NPHI.MWD DEPT. 13100.000 RA.MWD VRP.MWD 4.235 DER.MWD FET.HWD 0.456 RHOB.MWD CALN.MWD 9.125 NPHI.MWD DEPT. 13000.000 RA.MWD VRP.MWD 3.939 DER.MWD FET.MWD 0.506 RHOB.HWD CALN.MWD 9.026 NPHI.MWD DEPT. 12900.000 RA.MWD VRP.MWD 7.246 DER.MWD FET.MWD 0.921 RHOB.MWD CALN.MWD 9.115 NPHI.MWD DEPT.' 12800.000 RA.HWD VRP.MWD 6.812 DER.HWD FET.MWD 0.259 RHOB.MWD CALN.MWD 8.500 NPHI.MWD 12-0CT-1995 16:22 3.904 RP.MWD 5.291 ROP.MWD 2.273 DRHO.MWD 43.700 4.234 RP.MWD 5.005 ROP.MWD 2.289 DRHO.MWD 43.200 4.409 RP.MWD 4.657 ROP.MWD 2.316 DRHO.MWD 34.900 3.762 RP.MWD 4.893 ROP.MWD 2.398 DRHO.MWD 36.300 5.073 RP.MWD 6.761 ROP.MWD 2.415 DRHO.MWD 38.300 4.539 RP.MWD 4.646 ROP.MWD 2.662 DRHO.MWD 35.100 10.802 RP.MWD 14.210 ROP.MWD 2.480 DRHO.MWD 32.300 4.906 RP.MWD 4.655 ROP.MWD 2.489 DRHO.MWD 32.100 4.696 RP.MWD 4.323 ROP.MWD 2.478 DRHO.MWD 33.000 7.003 RP.MWD 7.203 ROP.MWD 2.407 DRHO.MWD 25.500 7.346 RP.MWD 6.822 ROP.HWD 2.375 DRHO.MWD 31.900 5.786 95.615 0.046 5.261 348.965 0.201 4.794 252.934 0.103 6.370 152.756 0.080 8.752 103.433 0.046 4.699 79.496 0.061 14.958 223.568 0.042 4.556 168.746 0.034 4.183 176.858 0.035 7.283 74.584 0.039 6.618 258.977 0.095 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR. MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.HWD PEF.MWD PAGE: 3.609 219.928 2.916 3,912 142.378 2.773 4.408 104.789 2.991 3.873 164.631 2.777 4.739 113.393 3.426 4.157 101.437 3.301 8.376 104.186 3.284 4.077 113.461 3.129 4.144 85.485 3.257 7.190 64.188 2.916 7.446 99.845 2.861 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 12700.000 RA.MWD VRP.MWD 4.942 DER.MWD FET.HWD 0.183 RHOB.MWD CALN.MWD 8.859 NPHI.MWD DEPT. 12600.000 RA.MWD VRP.HWD 4.908 DER.MWD FET.MWD 0.209 RHOB.MWD CALN.MWD 8.892 NPHI.MWD DEPT. 12500.000 RA.MWD VRP.MWD 3.434 DER.MWD FET.MWD 0.292 RHOB.MWD CALN.MWD 8.836 NPHI.MWD DEPT. 12400.000 RA.MWD VRP.MWD 5.512 DER.MWD FET.MWD 0.369 RHOB.MWD CALN.MWD 8.832 NPHI.MWD DEPT. 12300.000 RA.MWD VRP.HWD 7.324 DER.MWD FET.MWD 0.556 RHOB.MWD CALN.MWD 8.748 NPHI.MWD DEPT. 12200.000 RA.MWD VRP.MWD 5.744 DER.MWD FET.MWD 0.283 RHOB.MWD CALN.MWD 8.849 NPHI.MWD DEPT. 12100.000 RA.HWD VRP.MWD 2.594 DER.MWD FET.MWD 0.454 RHOB.MWD CALN.MWD 8.843 NPHI.MWD DEPT. 12000.000 RA.MWD VRP.MWD 4.024 DER.MWD FET.MWD 0.394 RHOB.MWD CALN.MWD 8.972 NPHI.MWD DEPT. 11900.000 RA.MWD VRP.MWD 4.459 DER.MWD FET.MWD 1.360 RHOB.MWD CALN.MWD 9.602 NPHI.MWD DEPT. 11800.000 RA.MWD VRP.MWD 4.987 DER.MWD FET.MWD 0.252 RHOB.MWD CALN.~WD 8.500 NPHI.MWD DEPT. 11700.000 RA.HWD VRP.MWD 3.594 DER.MWD FET.MWD 0.163 RHOB.MWD CALN.MWD 8.911 NPHI.MWD 12-0CT-1995 16:22 4.664 RP.MWD 4.788 ROP.MWD 2.479 DRHO.MWD 31.400 4.391 RP.HWD 4.586 ROP.MWD 2.504 DRHO.MWD 33.000 3.273 RP.MWD 3.492 ROP.MWD 2.473 DRHO.MWD 30.200 3.361 RP.MWD 4.137 ROP.MWD 2.433 DRHO.MWD 37.100 4.217 RP.MWD 5.859 ROP.MWD 2.400 DRHO.MWD 41.300 4.501 RP.MWD 5.377 ROP.HWD 2.517 DRHO.MWD 33.100 2.551 RP.MWD 2.598 ROP.MWD 2.437 DRHO.MWD 34.200 3.846 RP.MWD 3.986 ROP.MWD 2.502 DRHO.MWD 39.000 4.024 RP.MWD 4.317 ROP.MWD 2.375 DRHO.MWD 41.300 4.616 RP.MWD 4.991 ROP.MWD 2.354 DRHO.MWD 35.200 3.963 RP.MWD 3.759 ROP.MWD 2.423 DRHO.MWD 36.600 4.850 240.025 0.027 4.690 210.920 0.034 3.634 223.207 0.024 4.969 216.775 0.043 8.802 96.851 0.011 5.680 258.848 0.032 2.626 175.384 0.017 4.063 202.301 0.034 4.493 238.763 O.O54 5.132 255,253 0.052 3.671 317.812 0.025 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD PAGE: 4.782 111.711 3.062 4.741 98.114 3.101 3.057 113.947 3.014 3.961 111.821 3.321 4.349 109.786 3.916 4.652 132.780 3.421 2.484 101.360 3.454 3.525 131.419 3.434 3.855 132.836 2.992 4.730 107.739 3.160 3.587 100.517 3.192 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 11600.000 RA.MWD VRP.MWD 3.279 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD 10.424 NPHI.MWD DEPT. 11500.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 11400.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 11300.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 11200.000 RA.MWD VRP.HWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 11100.000 RA.MWD VRP,MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 11000.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10900.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10800.000 RA.MWD VRP.HWD -999.250 DER.MWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 10700.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10600.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 12-0CT-1995 3.251 3.258 2.110 36.400 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16:22 RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.HWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.HWD DRHO.MWD RP.HWD ROP.MWD DRHO.MWD 3.262 -999.250 -0.021 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 VRA.HWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.HWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD PAGE: 3.220 94.485 2.916 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumoerger Alaska Computing Center 12-0CT-1995 16:22 PAGE: DEPT. 10500.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10400.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10300.000 RA.MWD VRP.HWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10200.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10100.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 10000.000 RA.MWD VRP.HWD -999.250 DER.HWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9900.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 9800.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9700.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 9600.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9500.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RP.HWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.HWD -999.250 -999.250 ROP.HWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.HWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.HWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 9400.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.HWD -999.250 NPHI.MWD DEPT. 9300.000 RA.MWD VRP.MWD -999.250 DER.HWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9200.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9100.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 9000.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8900.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8800.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8700.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8600.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8500.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8400.000 RA.HWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 12-0CT-1995 16:22 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.HWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD .250 ROP.HWD .250 DRHO.MWD .250 .250 RP.MWD .250 ROP.MWD .250 DRHO.MWD .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.HWD PEF.MWD VRA.HWD GR.HWD PEF.MWD VRA.MWD GR.MWD PEF.MWD PAGE: 10 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 8300.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 8200.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 8100.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 8000.000 RA.MWD -999 VRP.MWD -999.250 DER.HWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7900.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.HWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7800.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7700.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.HWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7600.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7500.000 RA.HWD -999 VRP.MWD -999.250 DER.MWD -999 FET.HWD -999.250 RHOB.MWD -999 CALN.HWD -999.250 NPHI.MWD -999 DEPT. 7400.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.HWD -999 CALN.MWD -999.250 NPHI.MWD -999 DEPT. 7300.000 RA.MWD -999 VRP.MWD -999.250 DER.MWD -999 FET.MWD -999.250 RHOB.MWD -999 CALN.MWD -999.250 NPHI.MWD -999 12-0CT-1995 16:22 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.HWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 .250 RP.MWD -999.250 .250 ROP.MWD -999.250 .250 DRHO.MWD -999.250 .250 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.HWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 11 LIS Tape Verification Listing Schlumoerger Alaska Computing Center DEPT. 7200.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 7100.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 7000.000 RA.HWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6900.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6800.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6700.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6600.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6500.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.HWD CALN.MWD -999.250 NPHI.MWD DEPT. 6400.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6300.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6200.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD 12-0CT-1995 16:22 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.HWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.HWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.HWD VRA.HWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.HWD PEF.MWD VRA.HWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD PAGE: 12 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tare Verification Listing Schlumberger Alaska Computing Center 12-0¢T-1995 16:22 PAGE: 13 DEPT. 6100.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 6000.000 RA.MWD VRP.HWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5900.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5800.000 RA.MWD VRP.HWD -999.250 DER.MWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5700.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5600.000 RA.MWD VRP.MWD 6.394 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5500.000 RA.MWD VRP.MWD 2.884 DER.MWD FET.HWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 5459.000 RA.MWD VRP.MWD -999.250 DER.MWD FET.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHt.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7.003 6.475 -999.250 -999.250 3.431 3.169 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD RP.MWD ROP.MWD DRHO.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 234.787 -999.250 6.265 163.642 -999.250 3.058 -999.250 -999.250 -999.250 -999.250 -999.250 VRA.MWD GR.HWD PEF.MWD VRA.MWD GR.HWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD VRA.MWD GR.MWD PEF.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7.549 91.309 -999.250 3.195 99.761 -999.250 -999.250 97.897 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001¢01 DATEi : 95/10/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/10/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 12-0CT-1995 16:22 PAGE: 14 FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves~ all MAD runs merged using earliest passes. 0.5000 DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE CDR $ MERGED DATA SOURCE LDWG TOOL CODE $ START DEPTH STOP DEPTH ..... MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE REMARKS: THIS FILE CONTAINS HAD PASS #1 CDR DATA. NO CDN DATA WAS ACQUIRED. NO DEPTH CORRECTIONS HAVE BEEN APPLIED AT ARCOs REQUEST. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA INC. Company Name FN KUPARUK RIVER Field Name WN 2A-22 Well Name APIN 501032022100 API Serial Number FL 0756' FSL 0227 FWL Field Location SECT 13 Section TOWN 11N Township RANG 8E Range COUN NORTH SLOPE County STAT ' ALASKA State or Province NATI USA Nation LATI 70 18 08.755 N Latitude LONG 150 O0 40.217 W Longitude WITN MORRISON Witness Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-0CT-1995 16:22 PAGE: 15 TUNI VALU DEFI SON 57001 Service Order Number PDAT MSL EPD FT O. LMF DRILL FLOOR APD FT 135. EDF FT 135. EGL FT 94.3 TDD FT 14797. TDL FT 14797. BLI FT 14797. TLI FT 5459. DFT LSND DFD G/C3 10.2 RMS OHMM 1.813 MST DEGF 73. RMFS OHMM 1.676 MFST DEGF 73. BHT DEGF 150. Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Total Depth - Logger Bottom Log Interval Top Log Interval Drilling Fluid Type Drilling Fluid Density Resistivity of Mud Sample Mud Sample Temperature Resistivity of Mud Filtrate S Mud Filtrate Sample Temperatu Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth RA CDR ATTN RESISTIVITY RP CDR PHSF RESISTIVITY VRA QRO VERY ENHANCED AMPLITUDE RESISTIVITY VRP QRO VERY ENHANCED PHASE RESISITIVTY DER DIELECTRIC RESISITIVTY ROP RATE OF PENETRATION GR Gamma Ray ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-0CT-1995 16:22 PAGE: 16 -TYPE REPR CODE VALUE 11 66 32 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 P~ESS ID ORDER # LOG TYPE CLASS MOD NUMB SAHP ELEM CODE (HEX) DEPT FT 57001 O0 000 O0 0 2 i 1 4 68 -~$~--- O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OHHM 57001 RP MAD OHMM 57001 O0 000 O0 0 2 1 I 4 68 0000000000 VRA HAD OHMM 57001 O0 000 O0 0 2 i 1 4 68 0000000000 VRP MAD OHMM 57001 O0 000 O0 0 2 1 i 4 68 0000000000 DER MAD OHMM 57001 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 57001 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 57001 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5712.500 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 209.669 GR.MAD DEPT. 5700.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 234.787 GR.MAD DEPT. 5600.000 RA.MAD 7.003 RP.MAD 6.265 VRA.MAD VRP.MAD 6.394 DER.MAD 6.475 ROP.MAD 163.642 GR.MAD DEPT. 5500.000 RA.MAD 3.431 RP.MAD 3.058 VRA.MAD VRP.MAD 2.884 DER.MAD 3.169 ROP.MAD -999.250 GR.MAD DEPT. 5459.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 GR.HAD -999.250 -999.250 -999.250 -999.250 7.549 91.309 3.195 99.761 -999.250 97.897 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-0CT-1995 16:22 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001¢01 DATE : 95/10/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/10/12 ORIGIN : FLIC TAPE NAME : 95218 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2A-22, API #50-103-20221-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/10/12 ORIGIN : FLIC REEL NAME : 95218 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2A-22, API #50-103-20221-00 PAGE: 17
