The URL can be used to link to this page

Home My WebLink About190-105WELL LOG TRANSMITTAL 4905552758 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log and Tubing Punch Record: 3G-19 Run Date: 3/12/2019 19 01 05 30 73 5 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3G-19 Digital Data in LAS format, Digital Log file 50-103-20136-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: 0�[Nl " d� RECEIVED MAY 0 8 2019 AOGCC Signed: z 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. I (~" [(~ File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: r'l [] Other- Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: DIGITAL DATA [] [] OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by:~ TO RE-SCAN Notes: Bren Vincent Nathan Lowell Re-Scanned by: Bevedy Bren Vincent Nathan Lowell PLUGGt..G & LOCATION CLE..RA/qCE REPORT State of Alaska · ALASKA 0IL & GAS CONSERVATION COM~SSION Mer, crandu_~.. To =~ !e: APi No. Well Name 0uerator Lccation Review the well file, and-cerumen= on plugging, well head suatus~an~ !ocation. c!eara~ce - proMid, e,!oc~!e~ Well head cut off: ' {[~ J .' :Harker ~o~t: or plat:e: % Location Clearanc~: Code PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 August 8, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3G-19 P&A (201-106) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the recent P&A drilling operations on 3G-19. If you have any questions regarding this matter, please contact Brian Noel at 265-6979. Sincerely, Drilling Engineering Supervisor PA1 Drilling CM/skad ORIGINAL R£C£1VED AUG 1 0 2001 Alaska 0ii & Gas COns. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas E] Suspended E] Abandoned [~] Service E] 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 90-105 /301-138 31 Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20136-00 4. Location of well at surface i ~: ~-.~-:~ ~;--:'~-- '.. 9. Unit or Lease Name 2538' FNL, 145' FEL, Sec. 23, T12N, R8E, UM (asp: 498235, 5988561)~' '"~"'*~Ii"LOC'~~I Kuparuk River Unit At Top Producing Interval i · ' ~ 10. Well Number 1754' FNL, 1516' FEL, Sec. 26, T12N, R8E, UM ~. 3G-19 At Total Depth~ 11. Field and Pool 2069' FNL, 1579' FEL, Sec. 26, T12N, R8E, UM (ASP: 496801, 5983750) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 90 feetI ADL 25548 ALK 2662 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions August 7, 1990 August 12, 1990 June 7, 2001 (P&A'd) I N/A feet USE 0 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8200' MD / 6143' TVD 7605' MD / 5729' TVD YES r"l No [~]I 1787' feet MD 1600' (approx) 22. Type Electric or Other Logs Run No new logs 2~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 216 sx AS I 9.625" 36# J-55 Surface 3879' 12.25" 845 sx AS III & 545 sx Class G 7" 26# J-55 Surface 8200' 8.5" 485 sx Class G & 200 sx Class G Tail cement retainer set at 7605' MD, 7" brigde plug @ 7530' WLM 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A · Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 33.3 bbls Class G cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · This 10-407 is subrnitted as directed per the 10-403 form approved (Approval #301-138) RE[EIVED AUG 1 0 2001 ORIGINAL Alaska 0il & Gas Co'ns. Commissi°n Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Summary of 3G-19 Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~_,._~, ~/' Title Ddlling E n,q neerin.q Superv sor C. Mallary ~ Questions? Brian Noel 265-6979 Date Prepared by Sharon A//sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date Comment 3G-19 Event History 06/06/01 SET 2.750" X 1.1 7' CAST-IRON CEMENT RETAINER AT 7605' RKB. WELL FREEZE PROTECTED TO 2500'+. WILL RETURN TOMORROW TO PUMP CEMENT PLUG. [CEMENT-POLY SQUEEZE] 06/07/01 PUMPED 33.3 BBLS 15.8 PPG CLASS "G" CEMENT(9 BBLS IN TBG./CASING, 24.3 BBLS INTO PERFS) UNDER CEMENT RETAINER SET AT 7605' RKB. TUBING ABOVE PLUG CLEANED OUT W/1-1/2# BIO & SEAWATER J313; WASH PASSES MADE ACROSS MANDRELS. TUBING LEFT LOADED W/SEAWATER, 06/08/01 06/09/01 PT AGAINST CEMENT PLUG TO 2500# HELD GOOD, PULLED 1.5" DV @ 7511'RKB, LEFT POCKET OPEN. [PT TBG-CSG] CUT TBG IN FIRST FULL JT ABOVE PKR. Page I of I 7/16/01 Legal Well Name: 3G-19 Common Well Name: 3G-19A Spud Date: 6/7/2001 Event Name: ROT - SIDETRACK Start: 6/9/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 6/11/2001 07:30 - 13:30 6.00 MOVE MOB MOBMIR Move rig from 3J pad to 3G pad (7.5 miles) & spot over well # 19A-Accept rig @ 1330 Hrs. 06/11/2001. 13:30 - 15:30 2.00 ABANDN OTHR ABANDN Spot cutting tank & trash bins-run hard line to kill tank-rig up kill manifold. 15:30 - 18:00 2.50 ABANDN OTHR ABANDN Pull BPV & VR plug-350# on tbg. & annulus. 18:00 - 21:00 3.00 ABANDN CIRC ABANDN PJSM-Displace well w/8.5# seawater @ 4.3 bpm thru choke-monitor well-well dead 21:00 - 00:00 3.00 ABANDN NUND ABANDN Set BPV-Nipple down tree-nipple up bope. 00:00 - ABANDN ABANDN 6/12/2001 00:00 - 02:30 2.50 ABANDN NUND ABANDN Nipple up bope-change door seals in upper pipe rams. 02:30 - 03:30 1.00 ABANDI~ OTHR ABANDN Pull BPV-set 2 way check. 03:30- 06:00 2.50 ABANDI~ OTHR ABANDN Test bope 250-5000# 06:00 - 07:30 1.50 ABANDh OTHR ABANDN Pull 2 way check-install landing jt.-bolds. 07:30 - 08:00 0.50 ABANDh WLHD ABANDN Pull hanger & lay down same-rig up control line spooler. 08:00 - 18:00 10.00 ABANDI~ RTRV ABANDN POH laying down 3.5" tbg-recovered 31 control line bands-243 jts. tbg.-cut off piece-Tbg, had hard crude & scale build up from 5745' to 5847'. 18:00 - 20:30 2.50 ABANDI~ OTHR ABANDN Load out mandrels & misc. tbg. equipment-load 9 steel dc,s-18 hwdp-Clean floor area-PJSM. 20:30 - 00:00 3.50 ABANDI~ OTHR ABANDN Make up bha #1 & run in hole picking up 3.5" dp. 6/13/2001 00:00 - 02:00 2.00 ABANDI~ TRIP ABANDN RIH w/bit & 7" csg. scraper. 02:00 - 06:00 4.00 ABANDF, ClRC ABANDN Break cim.-hook up hot oil truck & pump 60 bbls. hot diesel down annulus to bit-pump down dp & bring diesel back-pump diesel down again & out thru dp. 06:00- 07:00 1.00 ABANDI~ SFTY ABANDN Crew change-service rig & PJSM. 07:00- 12:00 5.00 ABANDN TRIP ABANDN POH w/7" scraper. 12:00- 13:00 1.00 ABANDI~ OTHR ABANDN Lay down bha & clear floor. 13:00 - 17:30 4.50 ABANDN ~LUG ABANDN PJSM-Rig up SWS & rih w/7" bridge plug-set same @ 7530' WLM-poh & rig down sws. 17:30 - 18:00 0.50 ABANDN OTHR ABANDN Test csg. to 3000# 30 mins. OK. 18:00 - 22:00 4.00 ABANDN TRIP ABANDN Make up Whipstock & milling assembly-rih-hit tight spot @ 1639'-bottom of whipstock-tight-work loose-appears to be upper mill w/ 6.151 OD stuck in cement stage collar. 22:00 - 00:00 2.00 ABANDN TRIP ABANDN POH & lay down whipstock. 6/14/2001 00:00 - 02:00 2.00 ABANDh TRIP ABANDN Make up new bha & rih w/same to to 1619. 02:00 - 02:30 0.50 ABANDI~ MILL ABANDN Make up top drive-break circ.-mill thru dv collar. 02:30- 04:00 1.50 ABANDh TRIP ABANDN Finish rih-tag bp @ 7531 DPM. 04:00- 06:00 2.00 ABANDh CIRC ABANDN Make up top drive-displace seawater out w/milling fluid. 06:00- 07:00 1.00 ABANDh OTHR ABANDN Crew change-service rig-Pump dry job. 07:00- 09:30 2.50 ABANDI~ TRIP ABANDN POH for whipstock. 09:30- 10:00 0.50 ABANDI~ SFTY ABANDN Rig assesment meeting. 10:00 - 12:00 2.00 ABAND~ TRIP ABANDN Finish poh for whipstock. 12:00 - 21:00 9.00 ABANDIX TRIP ABANDN Pick up whipstock & rih. 21:00 - 22:00 1.00 ABANDI~ CIRC ABANDN Break circ.-orient & set whipstock 75 deg. right of hi side. 22:00 - 00:00 2.00 ABANDI~ MILL ABANDN Start milling top of window @ 7511'. 6/15/2001 00:00 - 06:00 6.00 WINDO~fSTWP PROD Milling window from 7511 to 7524 & milling new hole from 7524' to 7539'. (recovered 134# metal cuttings.) 06:00 - 08:00 2.00 WINDO~ICIRC PROD Pump sweep & circ. hole clean. 08:00 - 08:30 0.50 DRILL FIT PROD Perform FIT @ 13.2# OK. 08:30 - 12:00 3.50 DRILL TRIP PROD POH for drilling assembly. 12:00 - 14:00 2.00 DRILL PULD PROD Lay down milling bha-make up mud motor & stand back in derrick. 14:00 - 15:30 1.50 DRILL OTHR PROD Make up stack washer-clean metal from bope-clear floor. Printed: 7/16/2001 4:03:49 PM PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May 25, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 3G-19 Application for P&A Dear Ms. Commissioner: As per AOGCC regulations 20AAC25.080, Phillips Alaska, Inc. is submitting this Application for Sundry Approval to P&A the Kuparuk well 3G-19. Also submitted with this application are attachments to meet the requirements to P&A as stipulated by AOGCC. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265-6979. Sincerely, J. lrantham Drilling Engineering Supervisor PAl Drilling JT/skad ORIGINAL RECEIVED MAY 2 5 ZOO1 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _X Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface v/' X/ 2538' FNL, 145' FEL, Sec. 23, T12N, RSE, UM At top of productive interval 1754' FNL, 1516' FEL, Sec. 26, T12N, R8E, UM At effective depth At total depth 2069' FNL, 1579' FEL, Sec. 26, T12N, R8E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service _ 6. Datum elevation (DF or KB feet) RKB 90 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-19 9. Permit number/.~pproval number 90-105 10. APl number 50-103-20136-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3842' Production 8165' Liner 8200' v/ feet Plugs (measured) 6143' ~/' feet 8114' feet Junk (measured) 6083' feet Size Cemented 16" 216 sx AS I 9.625" 845 sx AS III & 545 sx Class G 7" 485 sx Class G & 200 sx Class G' None None Measured Depth 115' 3879' 8200' True vertical Depth 115' 3146' 6143' Perforation depth: measured true vertical Tubing (size, grade, and measured depth 7756'-7770',7800'-7830',7844'-7878' 5835'-5844',5865'-5886',5896'-5920' 3.5", 9.3#,J-55 @ 7678' RECEIVED 5 7.001 Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) Camco HRP-1-SP packer @ 7583', Otis FMX Series 10 SSSV @ 1787' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ Refer to attached morning for LOT test, surface cement details and casing detail sheets, schematic drilling report 14. Estimated date for commencing operation May 31,2001 16. If proposal was verbally approved Name of approver Date approved 15. 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. ~ ~~,-~ ~'~'~,3---,~~=~ Title: Drilling Engineering Supervisor James Trantharn FOR COMMISSION USE ONLY Questions? Brian Noel 265-6979 Date 5-/'~- 5',/c~ t Prepared by Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance· Mechanical Integrity Test_ Subsequent form required 10- Commissioner Approval no. Date Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE KRU 3G-19 SUNDRY OBJECTIVE P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) WELL HISTORY: Well 3G-19 was drilled and cased in August 1990. The rig was unable to pump down the 7" x 9-5/8" annulus for freeze protection. Frozen fluids partially collapsed the 7" and a workover in March 1991 patched a hole in the 9-5/8" surface casing and replaced the 7" down to 1622'. The well was then completed as a 3-1/2" single, gaslift completion producing from the Kuparuk A sands (C4 also perforated but not productive). Another workover in March 1992 patched a second hole in the 9-5/8" casing and ran 7" casing with a stage collar back to 1622'. The surface by production casing annulus was cemented to surface with 360 sx of 14.9 ppg permafrost cement. The 7" casing has since pressure tested successfully. In May 2000 the well began making sand/rocks. Several coiled tubing clean outs attempted to keep the well producing, but it continued to load up with solids and die. The well has been shut in since June 2000 awaiting sidetrack. The 3G-19 proposed sidetrack is a wellbore replacement, moving the well approximately 150' to the southwest to recover the remaining reserves in the pattern. Current Status: Shut in. Last tag on 4/1/01 at 7880' MD RKB (2' below bottom perf). GLV in mandrel #1-5, DV in mandrel #6 & 7. P&A WORK (Pre-Rig): RIH and pull 1" GLV from mandrels #1-5 at 2603', 4510', 5525', 6235' and 6973' MD RKB and run 1" DV in each mandrel. Pressure test the tubing by 7" casing annulus to 3000 psi (chart test). Gauge tubing for running cement retainer below packer. Verify that injection into the perfs is possible. 2. RU CTU. RIH with cement retainer on CTU and set retainer at +/- 7605' MD RKB (in 10' pup joint of 3- 1/2" tubing below Camco packer). Squeeze 30 bbls of 15.8 ppg Class G cement below retainer (9 bbl for the tubing and 7" casing volume + 21 bbls into perfs). ~ If needed, use a spotting valve placed immediately above the retainer to displace the cement down coil to desired distance above top of retainer. Close valve and pump cement squeeze below retainer into perfs. Unsting from retainer and circulate any excess cement from well bore. Leave well shut-in with initial tubing pressure on wellhead. RDMO CTU. 4. Bleed annulus pressure to 0 psi. Pressure test tubing above cement retainer to 2500 psi for 30 min (chart test). Slowly bleed tubing pressure to 0 psi and monitor pressure for build-up. 5. RU slickline unit. RIH and pull 1-1/2" DV from mandrel #6 at 7511' MD RKB, leaving an open pocket. 6. RIH and cut (E-line jet cut or CTU mechanical cutter) tubing at +/-7556' MD RKB (=4' from bottom of full joint of 3-1/2" tubing above Camco packer). 7. Set BPV and VR plug. Remove well house and scaffolding. BDN 5/24/01 KRU 3G-19 Producer Proposed P&A PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 9-5/8" 36# J-55 @ 3879' 7" Baker 'Window Master Whipstock' top @ +/-7515' MD Bridge Plug Depth tied in with CBL 3/26/90 7" Baker Bridge Plug set @ +/-7534' MD Tubing cut @ +/-7556' MD, 4' from bottom of full joint 3-1/2" tubing above Camco 'HRP-1-SP' packer. Cement retainer set in 10' pup joint below Camco packer @ +/-7605' MD Squeeze cement below retainer into perfs Abandoned Peds C/B-Sand Peds 7756'-7770' A-Sand Peds 7800'- 7830' 7844'-7878' 7"26#J-55 @ 8200' Tubing tail at 7672' MD Note: Collapsed casing at 7869' (video log Oct. 2000) Last Tag at 7880' MD on 4/01/01 PBTD @ 8114' TD @ 8200' BDN 5/23/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LO~LM.DOC L A T E E T E R IA L HIS M A.R E W UNDER K E R .-~"'..,, - STATE OF ALASKA ALA'~.. OIL AND GAS CONSERVATION COMk. JION REPOR1 OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well ~ Other 2. Name of Operator: 5.' Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development ~ 90' RKB, 54' PAl' 3. Address: Exploratory ___, 7. Unit or Property: P.O. Box 100360 Stratagrapic __~ Anchorage, AK 99510-0360 ... Service ___, Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 145' FEL, Sec 23, T12N, RSE, UM 3G-19 At top of productive interval: 9. Permit number/approval number: 1754' FNL, 1516' FEL, Sec 26, T12N, R8E, UM 90-105 At effective depth: 10. APl number: 2008' FNL, 1568' FEL, Sec 26, T12N, R8E, UM 50-103-2013'6-00 .., At total depth: 11. Field/Pool: 2069' FNL, 1579' FEL, Sec 26, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8200 feet Plugs (measured) None true vertical 6143 feet Effective Depti measured 8114 feet Junk (measured) None true vertical 6083 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 216 Sx AS I 115t 115' Surface 3842' 9-5/8" 845 Sx AS III & 3879' 3146' 545 Sx Class G Production 8165' 7" 485 Sx Class G & 8200' 61 43' 200 Sx Class G Tail Uner Perforation Depth measured 7756'-7770', 7800'-7830', 7844'-7878' true vertical 5835'-5844', 5865'-5886', 5896'-5920' Tubing (size, grade, and measured depth) 3.5", 9.3 lb//t, J-55 @ 7678' Packers and SSSV (type and measured depth) Packer: Camco HRP-1-SP @ 7583'; SSSV: Otis FMX Series 10 @ 1787' '1 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 4/15/98. Intervals treated (measured) 7800'-7830', 7844'~7878' Treatment description including volumes used and final pressure Pumped 105,025 lbs of 16/20 and 12/18 ceramic proppant into formation, fp was 6650 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mc/ Water-Bbl ' Casing Pressure Tubing Pressure Prior to well operation 454 141 212 1247 170 Subsequent to operation 559 155 288 1103 172 ;15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _z~ Oil _X Gas _ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~ . Title: Production Engineering Supervisor Date Form 10-404 Rev d6/"15/~ 8 SUBMIT IN DUPUCATF~ i~s/i--/,~rlt,/l~. [!1 v i=,F! Ii/liB I SERVICE REPORT Kl(3G-19(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-19 FRAC, FRAC SUPPORT 0407981011.3 DATE DAILY WORK UNIT NUMBER 04/15/98 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR s O vo= (.-') .o! ® Yes (~ No DS-YOKUM JOHNS ,,.~ __ FIELD AFC-# CC# DAILY COST ACCUM COST Si~ ~ ~ ~ ESTI MAT E K D2 03 9 230 DS36G L $ 94,600 $163,884 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outei"Ar~n ~ Final (}u~er Ann __ 678 PSI 0 PSI 500 PSI 500 PSIJ 200 PSI I 200 PSI DAILY SUMMARY PUMPED 105,025# PROPPANT TO 9 PPA 12/18 TO PERFS. SCREENED OUT WITH MAX PRESSURE 6655 PSI. LEFT 20,000 I # IN PIPE. ( JOB DESIGNED FOR 205,000#) I · , TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., HOT OIL PUMP AND APC VAC. TRUCK. 08:00 HELD JOB SITE SAFETY MEETING, TALKED ABOUT INJURIES AND SPILL PREVENTION. 08:34 PRESSURE TEST TREATING LINE TO 8400 PSI. 08:36 PUMP DATA FRAC AND FLUSH, TOTAL 100 BBLS 50# X-LINKED GEL AND 83 BBLS SEAWATER FLUSH. 5 TO 15 BPM. AND 5155 PSI. SHUT DOWN FOR ISIP AND CLOSURE CALCULATION. 09:59 PUMPED 655 BBLS X-LINKED GEL AT 5 TO 15 BPM AND 4404 PSI. 10:36 PUMPED 15,439 # OF 16/20 PROPPANT 2 PPA AT 15 BPM AND4317 PSI. ·. 10:49 PUMPED 107,819 # OF 12/18 PROPPANT FROM 2 PPA TO 9 PPA, 15 BPM AND 4300 PSI, SCREENED OUT FRAC WITH MAX. 6650 PSI. LEFT 20,794 # IN PIPE, TOTAL IN PERFS 105,025# TO 9 PPA 12/18. 12:30 RDMO, SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $903.00 APC $1,900.00 $11,350.00 ARCO $400.00 $1,000.00 DOWELL $91,000.00 $137,100.00 HALLIBURTON $0.00 $4,981.00 LITTLE RED $1,300.00 $8,550.00 TOTAL FIELD ESTIMATE $94,600.00 $163,884.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing __ Alter casing Stimulate __ Plugging m Perforate _ Repair well X Other Repair 9-5/6' & 7" csg 2. Name of Operator ..ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 145' FEL, SEC 23, T12N, R8E, UM At top of productive interval 1754' FNL 1516' FEL, SEC 26, T12N, R8E, UM At effective depth 2008' FNL, 1568' FEL, SEC 26, T12, R8E, UM At total depth 2069' FNL, 1579' FEL, SEC 26, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 8200' feet Plugs (measured) 6143' feet 6. Datum elevation (DF or KB) RKB 90', PAD 54' GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-19 9. Permit numbedapproval number 90-105/¢.nr~.~-'v O~'d~.T' 10. APl number 50-103-20136 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 81 14' feet Junk (measured) true vertical 6083' feet Casing Length Size Cemented Structural Conductor 80' 1 6" 216 SX ASI Surface 3842' 9-5/8" 845 SX ASlll & Intermediate 545 SX Class G Production 81 65' 7" 485 SX Class G & Liner 200 SX Class G Tail Perforation depth: measured 7756'-7770', 7800'-7830', 7844' - 7878' MD true vertical 5835'-5844', 5865'-5886', 5896' - 5920' TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 7671' Packers and SSSV (type and measured depth) CAMCO HRP-I-SP RETR PKR @ 7583, OTIS FMX SERIES 10 SSSV @ 1787" Measured depth 115' md 3879' md 8200' md True vertical depth 115' tvd 3146' tvd 6143' tvd RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) J U L - 7 1992 Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure ;Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 17. .,Signed 16. Status of well classification as: Copies of Logs and Surveys run _ Water Injector Daily Report of Well Operations x__ Oil X Gas Suspended I hereby certify~e foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 Service Date SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONa PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3G-19 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20136 90-105 ACCEPT: 03/01/92 04:03 SPUD: RELEASE: 03/12/92 10:03 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 03/01/92 (1) TD: 0 PB: 8114 MOVING F/ 2M TO 3G "@ 8200' MW:ll.8 NaCl/Br MOVE RIG FROM DS 2M TO DS 3G. AT 05:30, RIG IS APPROX 2 MILES FROM DS 2M. 03/02/92 (2) TD: 0 PB: 8114 03/03/92 ( 3) TD: 0 PB: 8114 RU TO PULL COMPLETION "@ 8200' MW: 8.6 NaC1 MOVE RIG FROM 2M PAD TO 3G-19, ACCEPT RIG @ 16:00, 3/1/92, FILL PITS WITH SEAWATER, RU OTIS, TEST LUBE, RIH & PULL DV FROM 1.5" GLM @ 7511', POOH, RD FILL PITS TO 300 BBLS W/SW, HEAT SW TO 130 DEG. W/OIT OIL TRUCK, RU HARDLINE TO PRODUCTION FLOWLINE, CIRC DIESEL OUT OF WELL BY PUMPING SW DOWN TBG SENDING RETURNS TO THE PRODUCTION FACILITY, FREEZE PROT FLOW LINE AFTER GETTING SW RETURNS (111 DEG F) W/25 BBL METHANOL, WELL IS DEAD, RD PUMP LINES, SET BPV, ND TREE, NU BOPS, TEST BOPE TO 3000 PSI RIH W/ RET BRIDGE PLUG "@ 8200' MW: 8.6 NaCl CONT RU FLOOR TO PULL COMPL ASSY. BOLDS. PULL HANGER TO FLOOR AND LD SAME. CIRC HOLE TO ENSURE HOLE IS CLEAN. POH W/3-1/2" COMPL ASSY. RECOVERED 29 SSSV CONTROL LINE BANDS. STRAP, DRIFT AND CHANG OUT SEAL RINGS. LOAD PIPE SHED W/3-1/2" DP AND 4-3/4" DC. STRAP SAME. SET WEAR RING. RIH W/6-1/8" BIT BIT SUB, DC, DP TO 2050'. TEST CSG TO 2500 PSI. INJECTING 1 BPM @ 2500 PSI. 9-5/8" CASING PRESSURE INCR FROM 20 PSI TO 750 PSI. CIRC WELL TO HEAT UP 7" X 9-5/8" ANNULUS. FINAL CIRC TEMP = 130 F IN AND 118 F OUT. RETEST 7" CSG TO 2500 PSI. INJ 1 BPM @ 2500 PSI. POH W/DP. MU BAKER EA RET PACKER ON TOP OF 12 4-3/4" DC. RIH. SET PKR @ 1630' (1641' ON DOYON 14 KB). TEST CSG ABOVE PKR TO 2500 PSI. INJ 1 BPM @ 2500 PSI. TEST CSG BELOW TO 2500 PSI. LOST 40 PSI IN 15 MIN - OK. REL PKR AND PULL UP 30' AND SET PKR @ 1600' (1611' BY DOYON 14 KB). TEST CSG BELOW PKR TO 2500 PSI. INJ @ 1 BPM @ 2500 PSI. TEST CSG ABOVE PKR TO 2500 PSI, LOST 250 PSI IN 15 MIN - OK. SUSPECT CSG IS LEAKING @ SCREW-IN SUB @ 1611' IN 7" CSG. (1622' DOYON 14 KB). POH W/PKR. MU BAKER RET BP AND RIH W 26 STANDS DP. RACK AND TALLY 25 JTS OF DP. PU AND RIH WITH REST OF DP. RECEIVED d U L - 7 1992 Alaska 0il & Gas Cons. Commission Anchorage WELL : 3G-19 OPERATION: RIG : NORDIC 1 PAGE: 2 03/04/92 (4) TD: 0 PB: 8114 03/05/92 (5) TD: 0 PB: 8114 03/06/92 (6) TD: 0 PB: 8114 03/07/92 (7) TD: 0 PB: 8114 03/08/92 (8) TD: 0 PB: 8114 PREPARE TO INSTALL 11" BOP "@ 8200' MW: 8.6 Seawater GIH W/ RBP. CIRC OUT AND POH W/ RBP. RU OTIS SLICKLINE. FISH JUNK OFF OF TUBING PLUG. COULD NOT PULL PLUG. PULL DV F/ GLM BELOW PKR. WELL LOSING @ 16 BPH. RE-INSTALL DV. RD OTIS. MU RBP ON DP AND GIH. SET SAME @ 2496'. DISPLACE HOLE W/ CLEAN SW. SPOT 20' OF SAND ON TOP OF RBP. POH 10 STDS AND ALLOW SAND TO SETTLE. GIH AND TAG SAND PLUG @ 2481'__POH 20 STDS__ PU STORM PKR AND SET @ 240'. POH 4 STDS AND TEST PKR AND CSG TO 1000 PSI. OK. ND 7-1/16" BOP STACK. MI AND THAW 11" BOP STACK. CIRCULATE BRINE "@ 8200' MW:10.7 NaC1/Br ND TBG SPOOL AND REMOVE PO. SPEAR 7" AND PU TO REMOVE SLIPS. NU BOP STACK AND RET STORM PKR. ATT TO PULL 7" CSG W/O SUCCESS. RELEASE SPEAR AND PU HYDRAULIC CUTTER. GIH AND CUT 7" @ 1590'. ATT TO CIRC. PUMPED IN @ 700 PSI AND 1 BPM. WEIGHT UP BRINE TO 10.6 PPG. WELL WAS TRYING TO FLOW. POH AND LD SPEAR. SPEAR 7" CASING AND POH W/ SAME. ONCE ECP'S WERE OUT OF THE HOLE, CIRCULATED AROUND W/ 10.6 PPG BRINE. MU RTTS PACKER "@ 8200' MW: 9.9 NaCl/Br FPOH AND LD 7" CASING. TEST BOP'S. MADE BIT AND SCRAPER RUN TO 7" CASING. CIRCULATE AROUND CLEAN FLUID. RU SWS AND LOG 9-5/8" CASING WITH USIT. RD SWS. MU SPEAR AND GIH. LATCH AND PULL CASING SUB DOWN TO OLD SCREW-IN SUB. PU RTTS AND PREPARE TO GIH. WOC "@ 8200' MW: 9.8 NaCl/Br TEST CASING WITH 9-5/8" RTTS. VERIFIED A HOLE BETWEEN 1516' AND 1520'. GIH W/ 3-1/2" DP TO 2455' AND TAG SAND PLUG. SPOT HI-VIS 16.5 PPG PILL ON SAND PLUG UP INTO 9-5/8" CSG. POH TO 1517' AND CIRCULATE OUT PILL FROM THERE. FPOH. GIH W/ RTTS AND SET @ 1425'. SQZ HOLE W/ 100 SX PERMAFROST 'C'. CIP @ 0220 HRS. SI DP W/ 510 PSI. WOC. GIH W/ RTTS PACKER "@ 8200' MW: 9.8 NaCl/Br FIN WOC. TRIP FOR 8-1/2" BIT. DRILL OUT CMT TO 1521'. TRIP FOR RTTS. ATT TO TEST CASING BELOW 585'. HAD DAMAGED RUBBERS. GIH W/ 8.75" SWAGE. HAD TIGHT SPOT @ 514'. DID NOT ATT TO WORK THROUGH. TRIP FOR NEW RTTS. ATT TO TEST 9-5/8" CASING. RECEIVED ,J U L - i' ]992 Alaska Oil & Gas Oons. Commission Anchorage WELL : 3G-19 OPERATION: RIG : NORDIC 1 PAGE: 3 03/09/92 (9) TD: 0 PB: 8114 03/10/92 (10) TD: 0 PB: 8114 03/11/92 (11) TD: 0 ?B: 8114 MU HOMCO CASING PATCH "@ 8200' MW: 9.8 NaCl/Br TESTED SQZ TO 600 PSI. OK. POH AND LD RTTS. GIH W/ 8.75" SWAGE SWAGE OUT TIGHT SPOTS @ 493', 511', AND 541'_ MADE BIT A~D SCRAPER RUN TO TOP OF 7" CSG @ 1611'. TRIP FOR 7" BTC PIN TAP. LATCH BTC COLLAR AND BACK-OFF TO THE LEFT. POH. REC'D BTC BOX. GIH TO 700' AND CIRC WARM BRINE IN PREPARATION FOR CSG PATCH INSTALLATION. 100 DEG RETURNS OBSERVED. POH AND LD DP. MU 9-5/8" CSG PATCH. RU TO CMT 9-5/8" X 7" ANNULUS "@ 8200' MW: 9.7 NaCl/Br PU HOMCO CSG PATCH AND APPLY EPOXY. GIH AND SET PATCH F/ 486' - 546'. PULL PLUNGER THROUGH 60' OF PATCH. FPOH. LD HOMCO TOOLS. GIH OPEN-ENDED AND CIRC WARM BRINE TO CURE EPOXY. RETURN TEMP = 100 DEG. POH AND LD 5" DP. RU AND RUN 7" CSG W/ STAGE CEMENTING COLLAR. SCREW INTO TOP OF 7" STUB (PIN) @ 1612'. INSTALL CIRCULATING HEAD AND CIRCULATE 7" CASING. INSTALL CMT LINE. ND BOP STACK AND INSTALL 7" CASING SLIPS WITH 100K TENSION. RE-CONNECT BOP STACK. RU TO CMT CSG. CIRC BRINE DOWN 7" CSG PRIOR TO CMT JOB. CIRCULATING ON TOP OF RBP "@ 8200' MW: 8.6 Seawater CIRC AND BATCH MIX 360 SX PERMAFROST CMT @ 14.9 PPG. CMT 9-5/8" X 7" ANNULUS THROUGH STAGE COLLAR. PUMPED 700 BBLS SLURRY FOLLOWED BY CLOSING PLUG AND 62 BBLS BRINE. BUMP PLUG AND PRESSURE UP TO 2250 PSI TO CLOSE STAGE COLLAR. RELEASE PRESSURE. STAGE COLLAR HOLDING. REC'D 15 - 18 BBLS SLURRY TO THE SURFACE. PU BOP STACK AND CUT 7". INSTALL PO AND CLEAN CMT OUT OF 11" STACK. INSTALL TBG SPOOL AND TEST PO TO 3000 PSI. NU AND TEST 7-1/16" BOP STACK. GIH W/ BIT AND DRILL OUT STAGE COLLAR. GIH AND TAG SAND PLUG @ 2457'_ TESTED CASING TO 3000 PSI. OK. DISPLACE HOLE TO SW AND WASH SAND OFF OF RBP. TRIP FOR RETRIEVING TOOL. REV CIRC ON TOP OF RBP. RECEIVED d U L - 7 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage WELL : 3G-19 OPERATION: RIG : NORDIC 1 PAGE: 4 03/12/92 (12) TD: 0 PB: 8114 03/13/92 (13) TD: 0 PB: 8114 CLEANING PITS "@ 8200' MW: 7.0 Diesel CIRC DOWN TO RBP. LATCH RBP AND UNSEAT. POH W/ RBP. LD RBP AND LOAD OUT BAKER TOOLS. RIH W/4-3/4" DC AND 3-1/2" DP AND POH TO LD SAME. REMOVE DC AND DP FROM PIPE SHED. PULL BOWL PROTECTOR AND RU TO RUN COMP STRING. RUN 3-1/2" COMPL TBG WITH JEWELRY. RU HOWCO UNIT AND PUMP TOP CMT JOB ON 7" X 9-5/8" ANNULUS. PUMPED 2.5 BBL PERM C CMT @ 15.6 PPG IN VOID AT TOP OF ANN. RD HOWCO. CONTINUE TO RUN IN HOLE W/3-1/2" COMP STRING. MU AND TEST OTIS S$SV/C-LINE TO 5000 PSI. FIN RUNNING TBG. RAN 243 JTS 3-1/2" 9.3 PPF J-55 EUE 8 RD AB MOD IPC TBG AS PER WELL PLAN. MU WKM TBG HAG W/C-LINE. TEST C-LINE TO 5000 PSI FOR 10 MIN - OK. CIRC TBG VOL, LAND TBG, RILDS, TEST 3-1/2" TBG TO 2500 PSI FOR 15 MIN - OK. 20 PSI LOSS. TEST SSSV W 1000 PSI FOR 15 MIN - OK. BLEED OFF ALL PRESSURE. CLOSE SSSV. LD LANDING JT. SET BPV. ND BOPE. NU TREE. TEST TREE TO 5000 PSI - OK. RU TO DISP WELL TO DIESEL. OPEN SSSV. DISPLACE SEAWATER IN WELL WITH DIESEL. BLOW DOWN LINES AND CLEAN CELLAR AND PITS. RAN 32 CL BANDS, UP WT 75 K SLACK WT 38K. "@ 8200' MW: 7.0 Diesel BLOW DOWN LINES, CLEAN PITS, MOVE RIG OFF WELL, CLEAN UP AROUND WELL HEAD AND LOCATION. REL RIG 12-MAR-92 10:00. 03/14/92 (14) TD: 0 PB: 8114 "@ 8200' MW: 7.0 Diesel FINAL REPORT FOR NORDIC PRIOR TO SHUT DOWN OF RIG. RIG REL @ 10:00 12-MAR-92 WITH +- 3400 GAL DIESEL FUEL IN FUEL TANK. ON 12-MAR-92 NORDIC TOOLPUSHER ORDERED AND RECEIVED 2000 GAL ADDITIONAL FUEL FOR FUEL TANK. FUEL WAS DELIVERED BY PEAK FUEL TANKER THAT IS ON CONTRACT TO ARCO DRILLING DEPT. (dril l~e r£ntende~ DATE: RECEIVED ,j U L. - '! 1992 Alaska Oil & Gas Oons. Oommissiol~ Anchorage STATE OF ALASKA A OILAND GAS CONSERVATION COMMIS,51ON ~.-~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing Stimulate ,, Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 145' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1754' FSL, 1516' FEL, Sec. 26, T12N, R8E, UM At effective depth 1754' FSL, 1516' FEL, Sec. 26, T12N, R8E, UM At total depth 2069' FSL, 1579' FEL, Sec. 26, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 8200' feet true vertical 61 4 3' feet Plugs (measured) None 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-19 9. Permit number/approval number 90-105 10. APl number 5o-103-20136 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7754' feet Junk (measured) true vertical 5833' feet None Casing Length Structural Conductor 1 1 5' Surface 3 8 7 9' Intermediate Production 8 2 0 0' Liner Perforation depth: Size Cemented Measured depth 1 6" 214 Sx AS I 1 15' 9-5/8" 845SXAS III & 3879' 545 Sx Class G 7" 485 Sx Class G & 9 62 7' 200 Sx Class G Tail measured 781 0'-7830', 7800'-7810', 7756'-7770' true vertical 5772'-5786', 5865'-5872', 5835'-5835' Tubing (size, grade, and measured depth) 3-1/5" 9.3#, EUE, ABMOD, @7671' Packers and SSSV (type and measured depth) SSSV: FMX Series 10 (1787'), Packer: Camco HRP-1-SP (7583') 13. Stimulation or cement squeeze summary Perforate 7830'-7756' Intervals treated (measured) True vertical depth 115' 3151' 6143' RECEIVED JAN 2 8 t992 Alaska 0il & Gas Cons. ~0mrnissio" Anchorage Treatment description including vOlumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure -1732- -1609- 0- -200- -1504- -1544- 0- -190- Tubing Pressure -153- -154- 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations, ,X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C,l'~' ~ Form 10-404 Rev 09/12/90 Title Operations En~lineer SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Coml~any DIST: ORIG - NSK KOE FILES KOE FILES DS FOREMAN-Moo~ NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WELL NAME: :~- [ ~' EN]~P: /~,4/../ TIED IN WITH: ~.o~~. DATED~-/z-qc, & ~, DATED ~-~-~ COMPLETION DETAILS: . GUN INFO: _ ~ ~ Z y~ ' SPF: ~ ~ PHASING: ~o° , ORIENTATION: ~~~= G~M ~: I!~ , HOLE SIZE ~ :, d dC/.. ~ ~,~ ~ $ I, ~ ~U# PROPOSED 7"P -/o, C," PROPOSED GUN CCL RUN PERFORATIONS PERFORATIONS LENGTH TOTOP NO. (md-~~.. (md'~C~ (fl) SHOT DATE: ?--'Z.'~--~ I SERV. CO & ENG: PERF INTERVAL: SAND A SAND C_ INT SAND INT /~-~=['°~CL TIME SETTING GUN DEPTH COMMENTS SHOT _~_, ?o~Do- 7g/O 7~Zoo-77/0 lo7 /f ' PERFORATION ORIENTING QC FORM WELL: ~t- 1~ DATE' J GUN NO. I SURFACE J DOWNHOLE I IREADING IREADING IDIFFERENCE ICALCULATIONS (Note: Direction Diff is CCW if Ang Dill=+ & CW if -) (DH-SURF) I I ~ ANGLE'= 5 o ~/'Cd~)) , AVG DIFF=(LOWDIFF+HIGH DIFF)/2: LOVV= 30/0 LOW= Z ~' "7~ - 1 ~, J TARGET VALUE=SURF NAV+~AVG DIFF: /7/,,~,"~ HIGH= .1'~52-- HIGH= "'7~/ , --/.~'/ TARGETDIFF=DHNAV-TARGETVALUE: /~/ '~.:-/ ,NAV= '-(?0~ NAY= ~(~ ANGDIFF=TARGETDIFF/28: ~/,,~o , · ' ;ACTUAL ANGLE=SURF ANGLE +~ANGLE DIFF: ANGLE= L~ ~~ L~= ~1~ '/5/ TARGETVALUE=SURFNAV+~VGDIFF:~3~,5 ~~,~ H~ NAV= ~~ NAV= ~~ ANGDIFF=TARGETDiFF/28: /?o ~,~ o ', ANGLE= ~ ° ~/o ¥o ~- 'r/~£ AVG DIFF=(LOWDIFF+HIGH DIF~/2: -/~ ~ ~o~ ~= ~~ -f'~ / TARGETV~UE=SURFNAV+/-AVG DIFF: H~ ~ ~ O H~ ~ ~ ~ [~ ~ TARGET DIFF=DH NAV-TARGET VALUE: NAV= ~ ~ ~ NAV= ~ q 3 ANG DIFF=TARGET DIFF/28: _/~, ~ o ACTUAL ~GLE=SURF ~GLE +/- ANGLE , ,, , [, ANGLE= AVG DIFF=(LOWDIFF+HIGH DIFF)/2: LOW= LOW= TARGET VALUE=SURF NAV+/-AVG DIFF: HIGH= HIGH= TARGET DIFF=DH NAV-TARGET VALUE: NAV= NAV= ANG DIFF=TARGET DIFF/28: ACTUAL ANGLE=SURF ANGLE +/- ANGLE DIFF: ANGLE= AVG DIFF=(LOWDIFF+HIGH DIFF)/2: LOW= LOW=- TARGET VALUE=SURF NAV+/-AVG DIFF: HIGH= HIGH= TARGET DIFF=DH NAV-TARGET VALUE: NAV= NAV= ANG DIFF=TARGET DIFF/28: ACTUAL ANGLE=SURF ANGLE +/- ANGLE DIFF: [ ANGLE= , AVG DIFF=(LOWDIFF+HIGH DIFF)/2: LOW=- LOW= TARGET VALUE=SURF NAV+/-AVG DIFF: HIGH= HIGH= TARGET DIFF=DH NAV-TARGET VALUE: NAV= NAV= ANG DIFF=TARGET DIFF/28: iACTUAL ANGLE=SURF ANGLE +/- ANGLE DIFF: STATE OF ALASKA c. 0 Il' Ir 6 [ WELL COMFy. ETlON OR.RECOMPLETION h~PORT AND LOG O~L ~[] GAS ~ SU~EO ~ ~~D ~ ~RV~E ~ ~;~ of ~ ..... 7 Pe~it N~r ~~, I~ , ~105 ........ ~~ ' 8 APINum~ P'O' ~x 1~, ~r~,AK. ~1~0~0 ~103-~1~ .:~~-~;,~., 9 Unit or Lea~ Na~ 2~8' FNL, 1~' FEL, SEC 23, T12N, RSE, UM ~ ~ ~ - ~ ~ ~ KUPARUK RIVER ~' AtTo~i~~~~~ ~1~[) ~ ~.~~ 11 Fiad and Pool 2~ FNLt 1579' FEL, SEC ~, T12N, ESE, UM ~'~~ KUPARUK RIVER FIELD 5 Eleva~on in f~t (indicts KB, DF, etc.) I 6 L~ D~aon a~ ~1 ~. KUPARUK RIVER OIL POOL RKB ~'~ PAD 54' GL~ ADL 25~8 ALK ~62 12 Date Spud~ 13 ~te T.D. R~ch~ 14 Date Co~., ~. or ~. 15 Water D~, if offshore 116 ~. of Comple~ons 8/07/90. 8/1 ~. 4~1~. NA f~t MSLI 1 17 Toal Dep~ (MD+~D)- '"18 Plug ~ck ~p~ (MD+TVD) lg Di~o~l ~W ~ Dep~ where SSSV ~t 21 Thic~e~ of ~afmst 8200' MD, 6143' TVD 8114' MD, ~' ~D YES ~ NO ~ 1787 f~t MD 1~0' APPROX 22 Ty~ El~ic 'or O~er Logs Run EWR/CN/SFD/DGR/CET/CBUGYRO ~ CASI~, LINER AND CEME~I~ RECORD SE~I~ DE~H MD CASI~ SIZE ~. PER ~. GRADE TOP ~ ~LE SI~ CEME~ING RECORD AMOU~ PULLED 16" 62.5~ H-40 SURF 115' 24" 216 SX ASI .... , .......... . 9-5/8" 36~ J-55 SURF ~' 12-1/4" ~5 SX ASIII~ ~5 SX C~SS G , 7" 26~ J-55 SURF 8~' ~1/2" ~5 SX C~SS G & 2~ SX c~Ss G TAIL . 24 Pe~oraao~ o~n m Pmduc~on (MD+~D of Top a~ ~Eom and 25 ~BI~ RECORD intew~, size and n~r) SI~ DE~ ~ {MD) PACKER S~ ~1/2" 7671' 7~9' ,. 7844'-7878' W/4-1/~ CSG GUN ~4SPF MD ~6'-~' ~D ~ ACID, F~C~, CEME~ ~UEEZE, ~C DE~ I~RVAL {MD) . I AMOU~ & KIND OF MA~RIAL USED SEE A~ACHED ADDENDUM ~ .... ~ ,,, , ,,, 27 PRESTON ~ST Date First Pmducaon [Me~d of O~raa~ (Flowing, ~ li~ etc.) I Date of T~t Ho~s Test~ ~OD~TION FOR OIL-B~ GA~MCF WATER-BBL CH~E SI~ ~ GA~OIL RATIO I ~ST ~RIOD ~ Flow Tubing Ca~ng Pre~e cALCU~TED OIL-B~ GA~MCF WATER-BBL OIL G~V~-API (corr) Press. 24-H~R ~ ~ 28 CORE DATA JUN 1 2 ~,9~ A~aska Oil .& Gas Cons, gnch0mg0 ,, . Form 10-407 Submit in duplicate Rev. 7-1-80 CQNTINUEDON REVERSESlDE GEOLOGIC MARKERS FORMATION TESTS __ NAIVE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7754' 5833' NA KUPARUK C BO'FI'OM 7768' 5843' KUPARUK A TOP 7782' 5853' KUPARUK A Bo'FrOM 7960' 5976' 31. LiST OF ATTACHMENTS 32. I hereby certify that the for&going i's true and correct to the best of my knowledge Signed ~' ~'~' '~/~~t',c~ Title AREA DRIWNG ENGINFF, Date , / 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 ADDENDUM WELL: 3G-19 Frac KRU "A" sand peris from 7844'-7878' @ 4spf in 11 stages as follows: Stage 1. Pmp 125 bbls YF240 X-linked Gel H20 @ 25 bpm 5410-3430 psi Stage 2 Pmp 75 bbls YF240 Non XL @ 25 bpm 3430-3300 psi Stage 3 Pmp 1200 bbis YF240 XL Pad @ 25 bpm 3700--3700 psi Stage 4 Pmp 119 bbls YF240 XL Pad w/2ppg 16/20 Carbolite @ 25 bpm 3700- 3590 psi Stage 5 Pmp 119 bbls YF240 XL Pad w/4ppg 16/20 Carbolite @ 25 bpm 3590- 3540 psi Stage 6 Prnp 111 bbls YF240 XL Pad w/6ppg 16/20 Carbolite @ 25 bpm 3540- 3590 psi Stage 7 Pmp 103 bbls YF240 XL Pad w/7ppg 16/20 Carbolite @ 25 bpm 3590- 3670 psi Stage 8 Pmp 34 bbls YF240 XL Pad w/8ppg 16/20 Carbolite @ 25 bpm 3670- 3990 psi Prop 51 bbls YF240 XL Pad w/8ppg 12/18 Carbolite @ 25 bpm 3670- 3990 psi Stage 9 Pmp 56 bbls YF240 XL Pad w/10ppg 12/18 Carbolite @ 25 bpm 3990- 4120 psi Stage 10 Pmp 57 bbls YF240 XL Pad w/12ppg 12/18 Carbolite @ 25 bpm 4120- 4320 psi Stage 11 Pmp Pmp Pmp 12 bbls YF240 XL Pad Flush @ 25 bpm 4320-7000 psi 12 bbls YF240 Non XL Flush @ 25-23 bpm 4320-7000 psi 31 bbls Slick Diesel Flush @ 23 bpm 4320-7000 Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 3500 psi 2074 H20, 31 Diesel 98,549# 16/20 Carbolite, 62,2148 12/18 Carbolit( 5,738# 12/18 Carbolite D~:illing Su~'rihtendent DAILY OPERATIONS ARCO ALASKA INC. WELL: 3G-19 PAGE: i BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25548 ALK 2662 50-103-20136 90-105 AK5105 55.252072 ACCEPT: 03/04/91 SPUD: RELEASE: 04/01/91 OPERATION: COMPLETION RIG: NORDIC 03/05/91 (8) TD: 0 PB: 0 SUPV:DB/LA 03/06/91 ( 9) TD: 0 PB: 8114 SUPV:DB/LA 03/07/91 (10) TD: 0 PB: 8114 SUPV:GB/SK 03/08/91 (11) TD: 0 PB: 8114 SUPV:GB/SK 03/09/91 (12) TD: 0 PB: 8114 SUPV:GB/SK RIH W/ 7" CSG CUTTER 7"@ 8200' MW:10.5 NaCl/Br MOVE RIG FORM 3G-12 TO 3G-19, ND WKM LOWER TREE AND TUBING HEAD, PULL PACKOFFS WELD SLIPS TO CSG, NU 11" BOPE, TEST, SLIP AND CUT 50' OF DILLING LINE, MU 2-7/8" PUP AND RIH ON 3-1/2" DP AND TAG OBSTRUCTION AT 502', BUMP DOWN SOLID, COLLAPSED CSG, DISPLACE OUT DIESEL AND MUD WITH BRINE, CIRC TO WARM WELL, POH WITH TUBING AND DRILL PIPE, MU 7" CSG _ CUTTER AND RIH ON 3-1/2" DP DAILY:S90,565 CUM:$890,826 ETD:S890,826 EFC:$1,330,000 VISCOSIFY BRINE TO MILL 7"@ 8200' MW:10.5 NaCl/Br RIH WITH CSG CUTTER AND CUT CSG AT 504', POH, RIH W/ SPEAR, SPEAR CSG AT WELLHEAD, CIRC AND DISPLACE MUD FROM BEHIND 7" CSG, PULL 7" TO FLOOR, RECOVERD SLIPS BY REAISING BOP STACK, MU BOP STACK, TEST BOP, RIH WITH SPEAR ON 5" DP, CIRC HOLE CLEAN AND WARM WELL, SPEAR 7" AND PULL WEIGHT ON SPEAR TO BLIND BACKOFF, POH, RECOVERED 4.9' OF 7" CSG, RIH AND ATTEMPT TO SPEAR 7", CAN'T HOOK CASING DUE TO COLLAPSE, POH, LD SPEAR, BRING IN TRI-STATE MILLING TOOLS, MU MILL AND RIH ON 5" DRILL PIPE, VISCOSIFY BRINE DAILY:S29,107 CUM:$919,933 ETD:S919,933 EFC:$1,330,000 MU 7" CSG SPEAR 7"@ 8200' MW:10.5 NaCl/Br CONT TO VISCOSIFY BRINE SYSTEM, MILL 7" CSG F/ 507'-513', MILL PLUGGED, POH, MU NEW 8-3/4" MILL AND RIH, MILL 7" CSG F/ 513'-523', TORQUE SMOOTHED OUT TO INDICATE TRHU COLLAPSED CSG SECTION, POH, PU SWEDGE AND RIH, TAG OBSTRUCTION AT 1529', CIRC AND HEAT WELL BORE, TOH W/ SWEDGE, MU 7" CSG SPEAR AND RIH TO ATTEMPT BLIND BACKOFF DAILY:S28,579 CUM:$948,512 ETD:S948,512 EFC:$1,330,000 TOH TO RECOVER BACKED OFF CSG 7"@ 8200' MW:10.5 NaCl/Br CONT TIH, SPEAR 7" CSG, WORK UP & DOWN ll0K, PU 37K AND BACK OFF @ 50 AMPS, SERVICE RIG, TOH, WELL SWABBING, RU HEAD PIN, CIRC OUT HEAVY SPOT IN MUD, CONT TOH, RECOVERED MILLED JT & I FULL JT, TOC @ 598', LD & STRAP 7", TIH & SPEAR INTO 7" CSG @ 598', PU 29K & BACK OFF @ 80 AMPS, TOH, RECOVERED 3 JTS, LD & STRAP, TOC 727', RIH & SPEAR 7", BACK OFF @ 80 AMPS, RECOVERED 2 JTS, CONTINUE BACKOFFING FEW JTS AT A TIME @ 06:00 SPEAR INTO 7" @ 1340, PU 29K & BACKOFF @ 150 AMPS, CBU, GELLED UP FLUID RETURNS. DAILY:$28~147 CUM:$976,659 ETD:S976,659 EFC:$1,330,000 ATTEMPT TO FREE 7" SPEAR 7"@ 8200' MW:10.0 NaCl/Br CONT TO CBU, TOH W/ 1 JT 7" CSG, TIH W/ 6-1/8" SWEDGE, TAG OBSTRUCTION AT 1667' INSIDE 7" CSG, PUSH JUNK DOWN TO 1791' CIRC, TEST 9-5/8" CSG, INJ RATE ESTABLISHED AT 3/4 BBLS/MIN AT 400 PSI, POH, TIH AND SPEAR CSG AT 1385', BACK OFF AT 120 AMPS, POH, RECOVERED 1 JT OF 7" CSG, TOP OF 7" AT 1430', TIH W/ SPEAR AND SPEAR 7" CSG, UNABLE TO BACKOFF DUE TO MUCH TORQUE DAILY:S32,263 CUM:$1,008,922 ETD:S1,008,922 EFC:$1,330,000 ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC PAGE: 2 03/10/91 (13) TD: 0 PB: 8114 SUPV:GB/SK 03/11/91 (14) TD: 0 PB: 8114 SUPV:GB/SK 03/12/91 (15) TD: 0 PB: 8114 SUPV:GB/SK 03/13/91 (16) TD: 0 PB: 8114 SUPV:GB/SK 03/14/91 (17) TD: 0 PB: 8114 SUPV:GB/SK RIH W/ WASH PIPE 7"@ 8200' MW:10.1 NaCl/Br CONT TO WORK CSG TO RELEASE SPEAR, RELEASE SPEAR, POH, FOUND 1 JT 7" CSG RECOVERED, TOP OF 7" AT 1474', MU 7" SPEAR AND RIH, SPEAR 7" CSG, ATTEMPT TO BACKOFF, BROKE TOOL JOINT CONNECTION, SCREW BACK INTO TOOL JOINT, RELEASE SPEAR, POH, MU 8-3/16" MILL, RIH AND MILL CSG F/ 1474'-1477', CIRC, POH MU 1 JT WASH PIPE, RIH TO AND PREPARE TO WASH OVER 7" CSG DAILY:S32,539 CUM:$1,041,461 ETD:S1,041,461 EFC:$1,330,000 POH AND CHANGE MILL 7"@ 8200' MW:10.1 NaC1/Br SERVICE RIG, CONT RIH W/ MILL AND WASH PIPE, TAG CSG AT 1475' WASH OVER 7" CSG F/ 1475'-1506' PU AND MAKE , , CONNECTION, UNABLE TO WASH BACK OVER CSG, BREAK OFF JT, REAM BACK TO BOTTOM, MAKE CONNECTION AND WORK BACK TO BTM, CONT WASHING OVER 7" TO 1510' (5' FROM NEXT CSG COLLAR), CIRC BTMS UP, POH, 24.5' OF TWISTED 7" CSG IN WASHPIPE, MU FLAT BTM MILL, RIH AND TAG 7" CSG AT 1505', MILL CSG F/ 1505'-1520' CBU, POH TO CHANGE MILL , DAILY:S23,647 CUM:$1,065,108 ETD:S1,065,108 EFC:$1,330,000 ISOLATE 9-5/8" CSG LEAK 7"@ 8200' MW:10.1 NaCl/Br SERVICE RIG, CONT POH W/ FLAT BTM MILL, CHECK JUNK BASKETS, . RIH W/ FLAT BTM MILL AND MILL CSG F/ 1519'-1557', 5' STUB LEFT ABOVE NEXT CSG COLLAR AT 1562', POH W/ MILL, MU RTTS AND PREPARE TO TEST 9-5/8", ISOLATE LEAK BETWEEN 482' AND 538', CONT ISOLATING AT REPORT TIME DAILY:S39,827 CUM:$1,104,935 ETD:S1,104,935 EFC:$1,330,000 CIRC AND PREPARE TO FILTER 7"@ 8200' MW:10.6 NaCl/Br ISOLATE 9-5/8" CSG LEAK, LEAK ISOLATED BETWEEN 495' AND 531' POH W/ RTTS, PU TRI-STATE CUT LIP GUIDE AND 1 JT WASH PIPE, RIH, WASH OVER 7" CSG TO 1564', POH, MU TAPPERED MILL AND SPEAR, RIH AND SPEAR INTO CSG, BACKOFF CSG AT 100 AMPS, POH, RECOVERED 9' OF 7" CSG LEAVING PIN LOOKING UP, RIH W/ 6-1/8" SWEDGE AND TAG JUNK IN 7" AT 1580', CIRC AND WORK DOWN JUNK TO 1586', UNABLE TO WORK DOWN FURTHER IN 7", POH, RIH OPEN ENDED AND CIRC HOLE CLEAN, PREPARE TO FILTER FLUID CLEAN DAILY:S35,610 CUM:$1,140,545 ETD:S1,140,545 EFC:$1,330,000 CIRC AND FILTER BRINE 7"@ 8200' MW:10.6 NaC1/Br DISPLACE VISCOSIFIED BRINE IN WELL W/ CLEAN BRINE, CIRC AND FILTER BEINE, PULL UP TO 674', CIRC AND FITLTER BRINE, DISPLACE BRINE WITH CLEAR WATER, FINISH POH WITH SCRAPER, RU WA E-LINE, RUN DOWN HOLE CAMERA TO 600', FLUID SEEMS TO BE TOO DIRTY FOR QUALITY PICTURE, POH W/ CAMERA, RIH W/ OPEN ENDED DP TO 806', DIPLACE OUT WATER W/ WEIGHTED CLEAR BRINE, CIRC AND FILTER BRINE, POH, RU WA E-LINE AND RUN DOWN HOLE CAMERA, FAIR PICTURE TO 400', POOR PICTURE FROM 400' TO 500' VERY POOR PICTURE FROM 500 TO 570', DIRTY FLUID SEEMS TO BE COMING IN AT DAMAGED CASING OR MISING UP FORM BELOW, POH W/ CAMERA, MU STORM pACKER, RIH AND SET AT 646', BACK OUT OF PACKER 5' AND CIRC AND FILTER BRINE, FILTER BRINE IN PITS DAILY:S58,726 CUM:$1,199,271 ETD:S1,199,271 EFC:$1,330,000 .Oil & Gas Cons. Ancherage ARCO ALASKA INC. DAILY OPERATIONS WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC 03/15/91 (18) TD: 0 PB: 8114 SUPV:GB/WM 03/16/91 (19) TD: 0 PB: 8114 SUPV:GB/WM 03/17/91 (20) TD: 0 PB: 8114 SUPV:GB/WM PAGE: 3 CIRC WARM BRINE/WAIT ON PATCH 7"@ 8200' MW:10.2 NaCl/Br CIRC AND FILTER BRINE WHILE SERVICING RIG, POH W/ 5" DP, RU ATLAS E-LINE AND RIH W/ CAMERA, ESTABLISH INJECTION TO PUSH DEBRIS INTO CSG HOLE, LOCATE HOLE AT 521' WLM (12.5' BELOW COLLAR), POH AND RIG DOWN E-LINE, PU RTTS RETRIEVING TOOL AND RIH AND LATCH RTTS, POH W/ RTTS, RIH W/ DC'S AND 5" DP TO 1546', POH AND LD SAME, PU HOMCO PATCH TOOLS AND RUN PATCH, WELD 20' AND 30' SECTION TOGETHER WHILE STANDING IN DERRICK, RIH AND SET PATCH (TOP OF PATCH AT 491.5') RKB, POH RIH W/ 3-1/2" DP OPEN ENDED AND CIRC HEATED BRINE AROUND PATCH, LOAD OUT PIPE SHED W/ 7" CSG AND CSG PAKCER DAILY:S49,318 CUM:$1,248,589 ETD:S1,248,589 EFC:$1,330,000 CIRC ARCTIC PACK DOWN ANNULUS 7"@ 8200' MW:10.2 NaC1/Br CONT TO CIRC HEATED BRINE AND WAIT ON CSG PATCH TO CURE, INSTALL SEAL RINGS IN 7" CSG, POH W/ 3-1/2" DP, RD RISER AND FLOW LINE, REMOVE CHUNK OF EPOXY, NU RISER AND FLOW LINE, PULL WEAR RING, SET TEST PLUG, TEST BOPE, BREAKDOWN AND MOVE OUT HOMCO TOOLS, PU FOSTER TONGS, ATTEMPT TO TEST 9-5/8" CSG PATCH, BLIND RAMS LEAKED. CHANGE OUT BLIND RAMS. RETEST PATCH TO 1500 PSI FOR 30 MIN. OK. PU BAKER CSG PKR. RIH ON 7" CSG TO TOP OF 7" COLLAR LOOKING UP. CIRC HOLE CLEAN AT 4 BPM. REVERESE CIRC 23 BBLS BRINE FOLLOWED BY 30 BBLS DIESEL AND ARCTIC PACK. DAILY:S47,924 CUM:$1,296,513 ETD:S1,296,513 EFC:$1,330,000 RIH W/ 7" CASING 7"@ 8200' MW:10.4 NaC1/Br CONT TO CIRC ARCTIC PACK IN PLACE. ATTEMPT TO STAB INTO 7" CSG. NO GO. CIRC OUT ARCTIC PACK AND DIESEL. POH LAYING DOWN CSG. RU TO RUN 3-1/2" DP. PU AND MU 8-3/8" CUT LIP GUIDE, XO BUMPER SUB, OIL JARS ON DP AND RIH. TAG TOP OF CSG AND ATTEMPT TO WORK OVER 7" CSG. NO GO. POH W/ DP AND BHA. MU CUT LIP GUIDE ON 4-3/4" DC'S AND RIH. SLIP AND CUT 50' OF DRILLING LINE. CONT RIH. TAGGED 9-5/8" CSG PATCH AT 491. TRY TO WORK INTO PATCH. NO GO. POH. PU 8-1/2" BIT AND RIH. ATTEMPT TO ROTATE INTO PATCH. NO GO. POH W/ BIT. PU 8-3/8" TRI-STATE MILL AND RIH TO TOP OF PATCH AT 491'. WORK THRU PATCH SEVERAL TIMES. POH AND LD TAPERED MILL. PU CUT LIP GUIDE AND RIH TO 1565'. PU KELLY AND WASH AND ROTATE OVER 7" CSG TO 1568'. CIRC HOLE CLEAN. POH AND STAND BACK 3-1/2" DP AND 4-3/4" DC'S. LD CUT LIP GUIDE. RIG UP TO RUN 7" CSG. PU CUT LIP GUIDE, 1 JT 7" CSG, BAKER CSG PACKER AND RIH W/ 7" CSG. DAILY:S34,361 CUM:$1,330,874 ETD:S1,330,874 EFC:$1,330,000 WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC 03/18/91 (21) TD: 0 PB: 8114 SUPV:GB/WM 03/19/91 (22) TD: 0 PB: 8114 SUPV:GB/WM 03/20/91 (23) TD: 0 PB: 8114 SUPV:GB/WM 03/21/91 (24) TD: 0 ?B: 8114 SUPV:DB POH W/ 7" CSG 7"@ 8200' MW:10.6 NaC1/Br CONT RIH W/ 7" CSG. TAG CSG AT 1566'. REVERSE CIRC 65 BBLS DIESEL/ARCTIC PACK MIX FOLLOWED BY 75 BBLS DIESEL AND 51 BBLS ARCTIC PACK. SCREW INTO 7" CSG. PU 108K LBS AND PRESSURE TEST 7" TO 1000 PSI FOR 15 MIN. OK. RELEASE PRESSURE AND SLACK OFF. PU 108K LBS AND PREESURE UP TO SET PACKER. 7" CSG PARTED AT 2250 PSI. ATTEMPT TO CIRC/REV CIRC. NO GO. ATTEMPT TO WORK PIPE UP/DOWN AND ROTATE. NO GO. ATTEMPT TO SCREW INTO 7". NO GO. ROTATE AND PU PIPE. PU 30K LBS OVER STRING WEIGHT. APPEARS PACKER IS PARTIALLY SET. ROTATE AND WOEK PIPE UP AND DOWN. UNABLE TO WORK FREE. WAIT ON E-LINE. RU HLS E-LINE AND RIH W/ 5-1/2" JET CUTTER. CUT PACKER MANDREL IN MIDDLE OF PACKER RUBBER (1497'). WORK 7" CSG TO RELAX PACKER. ATTEMPT TO CIRC. NO GO. CONT TO ROTATE AND WORK 7" CSG. SLIGHT RETURNS. CONT TO WORK 7" WHILE WAITING ON HLS PERF GUNS. RU AND RIH W/ 1-9/16" PERF GUN, FIRE GUNS AT 1491'-1492' (4 SPF). POH AND RD HLS. REV CIRC DIESEL AND ARCTIC PACK OUT OF WELL. CIRC WELL WITH BRINE. POH W/ 7" CSG. DAILY:S84,958 CUM:$1,415,832 ETD:S1,415,832 EFC:$1,330,000 MILLING 7" CASING 7"@ 8200' MW:10.4 NaC1/Br CONT POH W/ 7" CSG, PUP JT AND 1/2 OF BAKER PKR. SERVICE RIG. PU SPEAR ASSY AND RIH TO FISH AT 1506'. WORK SPEAR INTO FISH. POH SLOWLY. FISH WOULD NOT GO PAST CSG PATCH AT 541'. PULLED 80K LBS. LOST FISH. CONT POH. RECOVERD UPPER PACKER ELEMENT (3"). MU CSG SPEAR ON 1 JT OF 3-1/2" TBG AND RIH TO FISH AT 1506'. WORK DOWN INTO FISH. POH SLOWLY AND RETRIEVE ALL OF FISH. APPEARS CUT LIP GUIDE WAS NOT MADE UP COMPLETELY INTO 7" CASING AND HAD PULLED OUT OF 7" CSG STRING WHEN ATTEMPTING TO SET PACKER. LOAD PIPE SHED W/ 6-1/8" DC'S. PU TRI-STATE 8-1/2" FLAT BTM MILL. RIH ON 6-1/8" DC'S AND 5" DP. TAG TOP OF 7" CSG AT 1567'. PU KELLY. CIRC WELL WITH VISCOSIFIED BRINE. MILL ON 7" CSG F/ 1567'-1582'. DAILY:S49,718 CUM:$1,465,550 ETD:S1,465,550 EFC:$1,330,00 POH W/ DP AND MILL 7"@ 8200' MW:10.0 NaCl/Br CONT MILLING 7" CSG F/ 1582'-1602'. WORK PIPE EVERY 5'. TAG JUNK AT 1592'. MILL F/ 1592'-1595'. POH. PU TRI-STATE CONCCAVE MILL AND ASSY. RIH AND WASH AND REAM FROM 1592'-1600'. POH AND LAY DOWN CONCAVE MILL. PU FLAT BTM MILL. RIH AND WASH AND REAM F/ 1600' TO 1602'. MILL F 1602'-1603'. WORK PIPE AND CIRC HOLE CLEAN. POH. DAILY:S29,541 CUM:$1,495,091 ETD:S1,495,091 EFC:$1,330,000 POH W/ 6" FLAT BTM MILL 7"@ 8200' MW: 9.9 NaC1/Br SERVICE RIG. FINISH POH AND LD MILL. SET WEAR BUSHING. PU CUT LIP GUIDE AND RIH TO TOP OF 7" CSG AT 1603'. WASHOVER 7" STUB TO 1612'. CIRC HOLE CLEAN. POH AND LD CUT LIP GUIDE. MU 8.5" X 7-5/8" CUT LIP GUIDE AND RIH TO COUPLING. WASHOVER COUPLING 1.2'. POH. MU 6-1/8" TAPERED MILL AND RIH ON 3-1/2" DP. TAG TOP OF 7" AT 1603'. MU CIRCULATING HEAD AND TRY TO WORK INTO 7" (NO GO). PU KELLY AND WASH/REAM INTO 7" TO 1607' (SPINNING ON CUTTINGS). POH AND LD MILL. MU FLAT BTM MILL AND RIH. WASH DWON TO 1661' PUSHING CUTTINGS AHEAD. CIRCUALTE. POH W/ MILL. DAILY:S29,667 CUM:$1,524,758 ETD:S1,524,758 EFC:$1,330,000 PAGE: 4 WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC PAGE: 5 03/22/91 (25) TD: 0 PB: 8114 SUPV:DB 03/23/91 (26) TD: 0 PB: 8114 SUPV:DB MILL OUT CSG PATCH 7"@ 8200' MW: 9.9 NaCl/Br SERVICE RIG, FPOH, LD MILL, RIH W/CUT-LIP GUIDE-WO PIPE-WO BOOT BSKT, PU KELLY WO 7" STUB @ 1602 & WASH/REAM PAST 7" CPLG TO 1614', CBU, TEST CSG TO 1500 PSI, LOST 60 PSI IN 30 MIN-OK, BLOW DOWN & STAND BACK KELLY, POH LD BHA, CLEAN OUT BSKT (FULL OF METAL CUTTINGS 2.5-3 GALS), GOT GUIDE SHOE 1' OVER CPLG, RIH W/7" SPEAR, TAG STUB @ 1603', SPEAR 7" STUB , PU 10K# OVER & BLIND BACKOFF 7", POH SLOWLY, CSG DRAGGING SLIGHTLY, AS IF DRAGGING JUNK UPHOLE, TAGGED BOTTOM OF PATCH -@ 541' & PULLED 20K# OVER, WOULD NOT GO BACK DOWN, STUCK 3' IN PATCH, MAX PULL 160K#, NO MOVEMENT AFTER 140K#, CANNOT RELEASE SPEAR, HOLD TORQUE IN IN PIPE & MU TRISTATE SURFACE JARS TO TRIP @ 25-30 K# OVER, TRIP SURFACE JARS 10-12 TIME & BUMPED FISH FREE, LD SURFACE JARS & MU J-JOINT, RIH & SET FISH & J-JOINT ON BOTTOM, RIH W/TAPERED MILL DRESSED TO 8.765" + 1/32" (9-5/8" DRIFT +), TAG PATCH & START MILLING 9-5/8" CSG PATCH F/491'-501' DAILY:S104,055 CUM:$1,628,813 ETD:S1,628,813 EFC:$1,330,000 WORK 5" DP TO ENGAGE J-JOINT 7"@ 8200' MW:10.0 NaCl/Br MILL OUT HOMCO CSG PATCH. CIRC HOLE CLEAN. RIH W/ 5" DP AND TAG J-JOINT FISH. CIRC. POH AND LD TAPERED MILL AND BHA. PULL WAR BUSHING AND SET TEST PLUG. TEST BOPE. PULL TEST PLUG. SET WEAR BUSHING AND LD TEST JOINT. PU AND MU 8-1/2 BIT AND CSG SCRAPER. RIH TO TOP OF FISH AT 1053'. WORKED SCRAPER THRU PATCH AREA. MU CIRC HEAD AND TAG FISH. CIRC HOLE CLEAN. POH AND LD BIT AND SCRAPER. MU J-JOINT AND RIH .' TO FISH. WORK PIPE TO ENGAGE FISH DAILY:S31,095 CUM:$1,659,908 ETD:S1,659,908 EFC:$1,330,000 03/24/91 (27) TD: 0 PB: 8114 SUPV:DB RIH W/ 8-3/8" LEAD IB 7"@ 8200' MW: 9.9 NaCl/Br SERVICE RIG. PU KELLY AND WASH DWON AND ENGAGE J-JOINT. CIRC. STAND BACK KELLY AND POH WITH FISH. LD J-JOINT. MU BIT AND CSG SCRAPER. RIHAND REAM AND WORK SCRAPER IN PATCH AREA. CONT RIH AND TAG COUPLING AT 1612'. CIRC. POH. MU CUT LIP GUIDE AND RIH. WASH DOWN OVER 7" COUPLING TO 1616'. CIRC. 'POH AND LD WASH PIPE AND CUT LIP GUIDE. MU 6-1/8" SWEDGE AND RIH. LIGHTLY TAG 7" CSG AT 1612'. RUN IN 7" CSG TO 1629'. CIRC. POH. MU LEAD IMPRESSIONG BLOCK. RIH TO 7" COUPLING. DAILY:S32,444 CUM:$1,692,352 ETD:S1,692,352 EFC:$1,330,000 03/25/91 (28) TD: 0 PB: 8114 SUPV:DB 03/26/91 (29) TD: 0 PB: 8114 SUPV:DB TEST PACKOFFS 7"@ 8200' MW:10.4 NaCl/Br SET DOWN ON 7" CPLG AT 1612' W/ IB. POH. LD DC'S AND DP. RU TO RUN 7" CSG. PULL WEAR BUSHING. RIH W/ 7" CSG W/ SKIRTED SCREW IN SUB ON BTM JT AND TWO ECL PACKERS. RIH TO 1612' AND CIRC ARCTIC PACK. WCREW INTO 7" CSG. PU 120K# AND PRESS UP TO 1500 PSI ON 7". HOLD FOR 30 MIN (OK). STAGE PRESS UP TO 3500 PSI TO SET ECL PACKERS. BLEED OFF 7" AND TEST 7" X 9-5/8" ANNULSU TO 1000 PSI (OK) ND BOP AND RAISE STACK. SET SLIPS IN CSG HEAD W/ 90K#. DRAIN AND CUT OFF 7" STUB. INSTALL PACKOFF. NU WKM GEN IV TUBING HEAD. TEST PACKOFF TO 3000 PSI. DAILY:S110,625 CUM:$1,802,977 ETD:S1,802,977 EFC:$1,330,000 POH 7"@ 8200' MW:10.5 NaCl/Br MU WKM GEN IV TUBING HEAD. TEST. SERVICE RIG. RIG UP TO RIH W/ 6-1/8" MILL. RIH AND TAG CUTTINGS AT 1784'. BREAK CIRC. MILL PLUGGED. WORK PIPE AND UNPLUG. CIRC AND REAM/WASH TO 1920'. RIH PUSHING JUNK TO BOTTOM. TAG FILL AT 7980'. BREAK CIRC. MILL PLUGGING. WORK PIPE AND REVERSE OUT. FILTER AND CLEAN BRINE AT 7967'. DAILY:S70,563 CUM:$1,873,540 ETD:S1,873,540 EFC:$1,330,000 WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC PAGE: 6 03/27/91 (30) TD: 0 PB: 8114 SUPV:DB POH - LDDP 7"@ 8200' MW:10.5 NaCl/Br SERVICE RIG. FINISH POH LAY DOWN MILL. RU HLS E-LINE. MU CBL AND PET LOGS AND RIH. LOG CBL FROM 7984'-5400'. LOG PET FROM 7958'-5400'. POH. MU GYRO LOG AND RIH. LOG FROM TD TO SURFACE. RD HLS E-LINE. RIH WITH DRILL PIPE AND BHA. POH LAYING DOWN DRILL PIPE AND BHA. DAILY:S52,269 CUM:$1,925,809 ETD:S1,925,809 EFC:$1,330,000 03/28/91 (31) TD: 0 PB: 8114 SUPV:DB 03/29/91 (32) TD: 0 PB: 8114 SUPV:DB 03/30/91 (33) TD: 0 PB: 8114 SUPV:DB 03/31/91 (34) TD: 0 PB: 8114 SUPV:DB NU FLOW NIPPLE 7"@ 8200' MW:10.5 NaCl/Br SERVICE RIG. FINISH POHLDDP, DC'S, AND BHA. RU HLS E-LINE. RIH W/ 6" GAUGE RING AND JUNK BASKET. POH. MU AND RIH W/ PERF GUN #1. PERF 7858'-7878'. POH (ASF). MU GUN #2. ATTEMPT TO PERF 3 TIMES (TOOL FAILURE). RIH FOURTH TIME AND PERF 7844'-7858'. POH (ASF). RD HLS E-LINE UNIT. SET FLOW NIPPPLE ON STACK DAILY:S46,840 CUM:$1,972,649 ETD:S1,972,649 EFC:$1,330,000 TESTING TBG & ANNULUS FOR LEAK 7"@ 8200' MW:10.5 NaCl/Br Nil FLOW NIPPLE. SERVICE RIG. RUN 3-1/2" COMP ASSY. TEST TUBING AND SSSV AND SET PACKER W/ 2500 PSI. TEST TREE AND PACKOFF TO 5000 PSI. TEST ANNULUS TO 2500 PSI (LOST 500 PSI IN 5 MIN). TEST TUBING TO 3000 PSI (OK). REPRESSURE ANNULUS TO 2500 PSI (DROP TO 1450 PSI IN 15 MIN). PRESS UP TBG TO 3800 PSI AND SHEAR OUT BALL. WITH ANNULUS OPEN PRSSURE UP AGAINST FORMATION (SAW SLIGHT INCREASE IN ANNULUS RETURN WHILE PRESSURING UP). SUSPECT PACKER LEAK. RU PUMP-IN SUB. RU OTIS SLICK LINE UNIT. PULL CV FROM GLM AT 7510'. SET DV IN SAME. PRESSURE ANNULSU TO 2500 SPI. MONITOR TBG FOR RETURN TO INDICATE PKR LEAK (FORMATION TAKING FLUID). CONT TO TEST FOR PACKER LEAK. DAILY:S185,690 CUM:$2,158,339 ETD:S2,158,339 EFC:$1,330,000 CLEAR FLOOR AND LOAD 3-1/2" DP 7"@ 8200' MW:10.5 NaCl/Br FINISH TESTING FOR PACKER LEAK. SERVICE RIG. PU STANDING VALVE AND RIH. ATTEMPT TO SET IN XN NIPPLE. DROPPED THRU NIPPLE. POH. FOUND TOOL STRING HAD BACKED OUT BETWEEN OIL JAR AND SPANGS. MU FISHING STRING. RIH AND CATCH FISH A AT 7980'. POH W/ ALL FISH. STANDING VALVE RUN WAS TO SMALL FOR XN NIPPLE. RD OTIS SLICK LINE. SET BPV. ND TREE. NU BOPE. TEST SAME. HAD TO CHANGE OUT ANNULAR PREVENTER RUBBER. RU FOSTER TONGS AND PREPARE TO POH W/ TUBING. BOLDS. PULL 3-1/2" TUBING. LD SEAL ASSMY STINGER. DAILY:S32,757 CUM:$2,191,096 ETD:S2,191,096 EFC:$1,330,000 RIH W/HOWCO TST PKR 7"@ 8200' MW:10.5 NaCl/Br SERVICE RIG, INSTALL WEAR BUSHING, MU CAMCO PKR RET TOOL & RIH, MU CIRC HEAD, REV CIRC 1 DP VOL+ ,85 SPM, 750 PSI, @ 7550', HOLE CLEAN, CIRC HEAVIER BRINE INTO DP, PU SINGLE W/CIRC LINE, LATCH TOP OF PBR @ 7552', PU & RELEASE CAMCO PKR @ 277K# (129 K OVERPULL), POH & LD, ALL 3 PKR ELEMENTS INTACK-NO APPARENT DAMAGE, PU HALLIBURTON CHAMP IV PKR, RIH & SET @ 2024', CLOSE RAMS & TST ABOVE PKR, LEAKING OFF, PU & RESET PKR @ 2021', CLOSE ANNULAR & TEST ABOVE PKR TO 3000 PSI, LOST 140 PSI IN 30 MIN-OK, PU & RESET PKR @ 2085', CLOSE BAG & TST ABOVE PKR TO 3000 PSI, LOST 90 PSI IN 15 MIN ( SAME AS AT 2021')-0K, RELEASE PKR, CONT RIH DAILY:S34,995 CUM:$2,226,091 ETD:S2,226,091 EFC:$1,330,000 WELL: 3G-19 OPERATION: COMPLETION RIG: NORDIC PAGE:~ 04/01/91 (35) TD: 0 PB: 8114 SUPV:DB 04/02/91 (36) TD: 0 PB: 8114 SUPV:DB NU TREE 7"@ 8200' MW:10.5 NaCl/Br SERVICE RIG, CONT RIH W/CHAMP TST PKR, SET PKR @ 7693', TEST 7" ABOVE PKR TO 3000 PSI, LOST 150 PSI IN 30 MIN-OK, RELEASE PKR, POH LD PKR, PULL WB, RERUN COMP ASSY, LAND HGR, RILDS, RAN 244 JTS 3-1/2" 9.3# J-55 EUE-MOD IPC TBG, USED NEW SOS, 4' PUP ON NEW PBR/PKR ASSY TO GIVE PKR A NEW SEAT 6' DEEPER, RAN NEW CL & TESTED TO 5 KSI, 31 SS BANDS, 80K UP, 45 K DOWN PRESS TBG TO 2600PSI SET PKR, HOLD 10 MIN, HOLD TBG & PRESS ANN TO 1000 PSI, HOLD 10 MIN, BO ANN, HELD 1500 PSI ON TBG, PU & SHEAR PBR @ 106K# (26K# OVERPULL), BO TBG, RELAND HGR, RILDS, TEST SSSV W/1000 PSI DIFF, 10 MIN -OK, EQUALIZE & OPEN SSSV, PRESS ANN & TBG TO 2500 PSI, LOST 50 PSI IN 15 MIN-OK, LDLJ, SET BPV, ND FLOW NIPPLE & BOPE, NU 3-1/8" WKM GEN IV TREE RIG RELEASED 7"@ 8200' MW:10.5 NaCl/Br TEST TREE, PACKOFF, AND CL TO 5000 PSI. OPEN SSSV. TEST ANNULUS TO 2500 PSI. PRSSURE UP TBG AND SHEAR OUT BALL AT 3700 PSI. DISPLACE 450' OF BRINE WITH DIESEL IN TBG AND ANNULUS. SECURE WELL AND RD LINES. RELEASE RIG. DAILY:S6,316 CUM:$2,283,114 ETD:S2,283,114 EFC:$1,330,000 OII&IIIAL far "~' " C~!cui~t~ from ~,b!i Head Location Horizontal Coordinates Calculated from Local Horizontal RECEIVED Alaska Oil & Gas Cons. Commiss'~o~ ,A~hOraga ARCO ALASKA ..... KUPARUK RIVER ,m~T :i~!~ ~ ...... NORTH SLOPE r-~n~,n~,:u ai ~:-'~ Job N_.mber~ Ai<95~182!4 Directional i C:0~ 200: 400. 600~ 80:}~ ! 0::}~ 400: 500, 600, 8C:('.~ i .~ <"....'".. -" ..;~; = 260, 78 258, 76 ,~£ i = 90~: 77 i92,2! 193,9! ! 95, 88 200 i 98, 70 198.75 ~o: 37 HORIZONTAL .._.u ....... NAT~.~ feet . O0 ~' ,00- r Depths Are Refe?enced To ~ K B REFERENCED Tn ~, ~:" ~ I00.0 200, 0 40(L-0 500~ 0 599, 9 69% ~ 798.6 896, 7 993= i ~086= ~ ]!77.T 126B= ~ 14~7~7 ~535= 5 !621=7 i 706, 8 ,!7 ~4 .54 W .90 W :.', ii W ,87 S !~40 N 12,12 S 3,:32 N 25,72 S 7,01 W 4.4, '~" q ' ' ~0 ~' ~' '..: !98 105, 23 S 25.32 ?'?A 58 c 60,57 VERT ft .-..,-'q~ : SEVER i TV' "C=F./i :'.¥.,:~ ,06 .1 '7 !~72 :2,09 2, 02 AFSO ~L::4SKA iN-'J.'.- A Syr'odat,i ME~g ZNCL AZIMUTH VERT .[.',EPTH DEPTH ft de~ de9 ft ,, .-,, 36 ?$8,, 5 ~ o~ % 201 i, 2 !96, i2 2(89.6 i%, 06 '.-'~ '~:q 2 2700.9 44.76 199: ~._'.-', 2558.5 4200=0 ~ !3 ~'"'~-,' :,-89 iiz~ 7 440CL 0 4,!, 05 2 i O, 82 3515.0 HOfi ~ ZgNTAL feet 530,39 S 156,86 W 594,~ S ~.-"? !6 W 727,71 S 22i,32 W 798.3~ S 242~29 W i..,'..-'}; ~,~ S ~':" ,¢9 i067~25 S 334,51 i !.Z6, i i S 356.95 ~?"'~ 36 S 57.:, 7-~ W !280.76 S .]90,64 W 1352~,19 S 408,29 W i422.56 S 426, 95 W !565,17 S 467,24 1655~82 S 490.56 !70%79 S 515,35 ?78.22 S 54248 ~846.82 S 575,2! VERT SECTION 552.7 750,2 906.! 977,5 i0.¢7.~ i i 90,, 3 i264.4 i484.3 1556,3 2008.1 208!,1 2i52.1 2220,5 2286.0 d% :' 2~ E:? i ~-., 1:45 = ,0% 3.82 "3, 2, 00 · ARCO A~ASK~ A 6yra'~ ~a~a. MEAS ]NCL AZIMUTH VERT OEF'T~ DEPTH ft d~ deg ft 4%00~ 0 42.45 198.68 3664, ~nn 0 46 95 !96~93 ~= 4800.0 48~ i 5 197.73 5805~ 5100. !} 4~, 3~ i99,72 4007, 5300.0 HORIZONTAL C 0 OR D i NAT E S feet 2222,,'"u...:,_. ~"' 759.. .09 W 2284,78 S 792, 28 W 2422, i~ S 9,E5, 72 ~J ........ S i7W 2562,25 S 881,59 2630.29 S 906.29 2698,36 S 930,81 2766,01 8 954,89 2~ ~ ' 077 O~ 2900,81 S i000,4i 2968,75 S 1022,56 30:7,77 S i045.12 3520~90 S !!17.03 ~391=7~ S ~i32=76 3462=56 S- ii48.74 .553.T,~0 S £!54,£2 3675,04 S L194.04 3747,% S ~20%42 3820,65 S !22.4,79 3893.35 S !240,26 SECTTn~.I 2562,3 2636.5 270%7 2782=0 2854,4 2926.2 3068.4 31i9,? 5212.5 3285,6 335S,5 3503, 7 37i9,S 3791.9 3957,8 4OIL,5 4085~4 SEYER E TY DEPTH DEPTH ~t deg de~ ft 7 ! :,0 ,"~ 47, ::.) i '! ~a ................. 537% ..,z.,,, ..... 4&-,, 5i 'i90.-07 7300,0 i.::, 72 189, ~'-'' 7600,0 45, 28 i92, 70 5725, 8 7700. O "= i 93,90 '~,74 - - 5795,9 CEOr'n'NATES 4458,38 S i361,17 ,6~c, ~,7 S !~7l 77 4598,87 S 139!,25 SECTiOI,~ 4251, 4~(i3. 4374., 444~.,, 4588.3 4.730,6 SEVES'I T.,:' Ja~,'." N 800 - Narke~ Identif ~catton A}~ BJ 9 5/8' CASING CJ P~TD D) EXTRAPOLATED TO E] 7' CASING ARCO ALASKA, INC. ~ H/s 0 ON 0£ 3879 ~.832 S 569 8~,4 4750 S t422 8200 48~t S i434 6200 49~ S ~434 3G-19 API50-~03-20t36 PLAN VIEH CLOSURE ..... : 5020 ft S 16.59 DECLINATION.: 0.00 E SCALE .......: t inch = 800 feet DRAWN .......: 05/08/9t ~eat Land Directional B~illin# 1600 3200- 4600 800 0 600 <-WEST: EAST-> 2400 160O i600 2400 <KB>O- ARCO 3G-19 API50-103-20138 I VERTICAL SECTION VIEN Section at: S ~8.77 ~ TVD Scale.: ! inch = ~000 feet 9ep Scale.; ! inch = iO00 feet Drawn ..... : 05/08/9i GP~t Land OJPectJonalDPJ]]Jn~ Nanker Identification ~ T¥O SECTN INCH A] K8 0 0 0 0,00 8) 9 5/8' CASING 3879 3i§! i918 4B,96 C) PBTD 8i~4 6083 4955 46.16 D) Z" CASING 8200 6t43 50t7 46.16 E} EXTP,,APOLATED TD 8200 6~43 50i7 46.16 T V iO00 I ~000 3000 Section Departure 4000 5000 by GREAT LAND DIRECTIONAL DRILLING, INC. for GyroData Incorported 05/08/91 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : 3G-19 API50-103-20136 Section at: S,18.77,W Engineer..: TOM STODDARD Computation...: RADIUS OF CURVATURE Survey Date...: 03/26/91 RKB Elevation.: 90.00 ft Reference ..... : 0391G214 INTERPOLATED MARKERS REPORT Surface Location: 2538 FNL 145 FEL S23 T12N R8E MARKER IDENTIFICATION KB 9 5/8" CASING KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD EXTRAPOLATED TD 7" CASING MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST BEARING 0 -90 3151 3061 5833 5743 5843 5753 5853 5763 0 0.00 3879 48.96 7754 45.90 7768 45.94 7782 45.98 7960 46.06 5976 5886 8114 46.16 6083 5993 8200 46.16 6143 6053 8200 46.16 6143 6053 DIRECTION REL-COORDINATES FROM-WELLHEAD 0 N 0.00 E 1918 S 25.13 W 4698 S 12.50 W 4708 S 12.37 W 4718 S 12.24 W 0 N 0 E 1832 S 569 W 4496 S 1371 W 4506 S 1373 W 4516 S 1375 W 4845 S 11.08 W 4955 S 11.03 W 5017 S 11.03 W 5017 S 11.03 W 4641 S 1400 W 4750 S 1422 W 4811 S 1434 W 4811 S 1434 W GREAT LAND DIRECTIONAL DRILLING, INC. o5/o8/91 Client · Field · Well ...... : Section at: Engineer..: ARCO ALASKA, INC. KUPARUK RIVER UNIT 3G-19 API50-103-20136 S,18.77,W TOM STODDARD Computation...: Survey Date....- RKB Elevation.: Reference ..... : RADIUS OF CURVATURE 03/26/91 90.00 ft 0391G214 S MEAS INCLN C DEPTH ANGLE 7 100 0.23 7 200 0.24 7 300 0.18 7 400 0.09 7 500 0.56 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DISTNCE DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 100.0 10.0 0.2 S 59.17 W 0.1 S 0.2 W 0.2 S 59.16 W 0.23 200.0 110.0 0.4 S 80.78 W 0.2 S 0.6 W 0.6 S 66.41 W 0.01 300.0 210.0 0.6 S 78.76 W 0.3 S 0.9 W 1.0 S 71.43 W 0.06 400.0 310.0 0.7 S 44.30 W 0.4 S 1.1 W 1.2 S 72.87 W 0.09 500.0 410.0 1.3 S 28.77 W 0.9 S 1.4 W 1.7 S 59.07 W 0.47 7 600 2.84 599.9 509.9 4.2 S 10.46 W 3.6 S 2.4 W 4.4 S 33.57 W 2.28 7 700 7.00 699.6 609.6 12.7 S 12.21 W 12.0 S 4.1 W 12.7 S 18.79 W 4.16 7 800 9.06 798.6 708.6 26.6 S 13.91 W 25.6 S 7.3 W 26.7 S 15.79 W 2.06 7 900 12.98 896.7 806.7 45.6 S 12.35 W 44.3 S 11.6 W 45.8 S 14.68 W 3.92 7 1000 17.72 993.1 903.1 71.9 S 12.31 W 70.1 S 17.2 W 72.2 S 13.82 W 4.74 7 1100 24.54 1086.3 996.3 107.8 S 14.26 W 105.2 S 25.5 W 108.2 S 13.64 W 6.83 7 1200 24.57 1177.3 1087.3 149.2 S 15.13 W 145.4 S 36.1 W 149.8 S 13.93 W 0.15 7 1300 24.95 1268.1 1178.1 191.1 S 15.88 W 185.7 S 47.3 W 191.6 S 14.28 W 0.40 7 1400 25.91 1358.4 1268.4 234.0 S 20.20 W 226.5 S 60.6 W 234.5 S 14.96 W 1.27 7 1500 27.63 1447.7 1357.7 279.0 S 20.20 W 268.8 S 76.1 W 279.4 S 15.81 W 1.72 7 1600 29.51 1535.5 1445.5 326.8 S 18.29 W 314.0 S 91.9 W 327.1 S 16.31 W 1.94 7 1700 31.52 1621.6 1531.6 377.6 S 18.70 W 362.1 S 108.0 W 377.9 S 16.60 W 2.01 7 1800 31.84 1706.7 1616.7 430.1 S 18.75 W 411.9 S 124.8 W 430.4 S 16.86 W 0.32 7 1900 39.21 1788.1 1698.1 488.1 S 13.37 W 467.6 S 140.9 W 488.4 S 16.77 W 7.68 7 2000 41.59 1864.2 1774.2 552.7 S 15.90 W 530.3 S 157.3 W 553.2 S 16.52 W 2.63 7 2100 42.56 1938.5 1848.5 619.7 S 19.36 W 594.2 S 177.6 W 620.1 S 16.64 W 1.86 ^Survey Codes: 7/GYRO (3G19 Bi.21) 3G-19 API50-103-20136 Page 2 05/08/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 2200 44.10 7 2300 48.07 7 2400 46.85 7 2500 45.75 7 2600 44.94 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 2011.2 1921.2 688.3 S 18.96 W 659.0 S 200.1 W 688.7 S 16.89 W 1.55 2080.5 1990.5 760.3 S 16.12 W 727.7 S 221.8 W 760.7 S 16.95 W 4.27 2148.1 2058.1 834.0 S 16.96 W 798.3 S 242.8 W 834.4 S 16.91 W 1.30 2217.2 2127.2 906.2 S 18.63 W 867.1 S 264.9 W 906.7 S 16.98 W 1.39 2287.5 2197.5 977.4 S 18.70 W 934.5 S 287.6 W 977.8 S 17.10 W 0.81 7 2700 44.76 2358.4 2268.4 1047.9 S 19.83 W 1001.1 S 310.9 W 1048.3 S 17.25 W 0.59 7 2800 44.65 2429.5 2339.5 1118.2 S 20.22 W 1067.2 S 335.0 W 1118.5 S 17.42 W 0.22 7 2900 47.81 2498.7 2408.7 1190.4 S 14.67 W 1136.0 S 356.6 W 1190.7 S 17.43 W 4.39 7 3000 48.34 2565.5 2475.5 1264.5 S 12.88 W 1208.3 S 374.3 W 1265.0 S 17.21 W 1.13 7 3100 47.69 2632.4 2542.4 1338.5 S 13.37 W 1280.7 S 391.2 W 1339.1 S 16.98 W 0.70 7 3200 47.07 2700.1 2610.1 1411.8 S 14.40 W 1352.1 S 408.9 W 1412.6 S 16.82 W 0.83 7 3300 46.38 2768.6 2678.6 1484.4 S 15.30 W 1422.5 S 427.5 W 1485.4 S 16.73 W 0.84 7 3400 45.98 2837.9 2747.9 1556.5 S 15.88 W 1492.0 S 446.9 W 1557.5 S 16.67 W 0.50 7 3500 49.73 2905.0 2815.0 1630.5 S 16.85 W 1563.1 S 467.8 W 1631.6 S 16.66 W 3.79 7 3600 49.75 2969.6 2879.6 1706.8 S 18.74 W 1635.8 S 491.1 W 1707.9 S 16.71 W 1.10 7 3700 49.39 3034.4 2944.4 1782.9 S 19.26 W 1707.8 S 515.9 W 1784.0 S 16.81 W 0.47 7 3800 49.33 3099.6 3009.6 1858.7 S 24.29 W 1778.2 S 544.0 W 1859.6 S 17.01 W 2.89 7 3900 48.87 3165.0 3075.0 1933.9 S 25.36 W 1846.8 S 575.8 W 1934.5 S 17.31 W 0.76 7 4000 48.18 3231.3 3141.3 2008.2 S 26.03 W 1914.3 S 608.3 W 2008.6 S 17.63 W 0.78 7 4100 46.64 3298.9 3208.9 2081.2 S 26.32 W 1980.4 S 640.7 W 2081.5 S 17.93 W 1.55 7 4200 45.13 3368.5 3278.5 2152.3 S 27.89 W 2044.3 S 673.4 W 2152.4 S 18.23 W 1.70 7 4300 42.87 3440.5 3350.5 2220.7 S 29.58 W 2105.2 S 706.8 W 2220.7 S 18.56 W 2.39 7 4400 41.05 3514.8 3424.8 2286.2 S 30.82 W 2163.0 S 740.5 W 2286.2 S 18.90 W 1.90 7 4500 41.56 3590.0 3500.0 2351.6 S 21.92 W 2222.1 S 769.8 W 2351.6 S 19.10 W 3.95 7 4600 42.45 3664.3 3574.3 2418.5 S 18.68 W 2284.8 S 793.0 W 2418.5 S 19.14 W 1.72 7 4700 46.95 3735.3 3645.3 2488.8 S 16.93 W 2351.8 S 814.5 W 2488.8 S 19.10 W 4.60 ^Survey Codes: 7/GYRO 3G-19 API50-103-20136 Page 3 05/08/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 4800 48.15 7 4900 47.73 7 5000 46.38 7 5100 46.31 7 5200 46.38 7 5300 45.42 7 5400 45.34 7 5500 45.30 7 5600 45.98 7 5700 47.09 7 5800 46.94 7 5900 46.95 7 6000 47.13 7 6100 46.74 7 6200 46.29 7 6300 46.50 7 6400 46.30 7 6500 46.82 7 6600 47.30 7 6700 47.73 7 6800 48.20 7 6900 47.85 7 7000 46.49 7 7100 47.01 7 7200 46.31 7 7300 46.72 VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 3802.8 3712.8 2562.5 3869.8 3779.8 2636.8 3937.9 3847.9 2709.9 4007.0 3917.0 2782.3 4076.0 3986.0 2854.6 4145.6 4055.6 2926.4 4215.8 4125.8 2997.6 4286.1 4196.1 3068.7 4356.1 4266.1 3140.2 4424.8 4334.8 3212.8 4493.0 4403.0 3285.9 4561.3 4471.3 3358.8 4629.4 4539.4 3431.5 4697.7 4607.7 3504.0 4766.5 4676.5 3576.1 RELATIVE-COORDINATES FROM-WELL-HEAD S 17.73 W 2422.2 S 836.5 W S 17.47 W 2493.0 S 858.9 W S 20.04 W 2562.3 S 882.4 W S 19.72 W 2630.3 S 907.0 W S 19.90 W 2698.4 S 931.6 W S 19.28 W 2766.0 S 955.6 W S 18.53 W 2833.4 S 978.7 W S 18.30 W 2900.8 S 1001.2 W S 17.96 W 2968.8 S 1023.4 W S 18.11 W 3037.8 S 1045.9 W S 17.93 W 3107.4 S 1068.5 W S 12.33 W 3177.9 S 1087.6 W S 11.61 W 3249.5 S 1102.7 W S 12.17 W 3321.0 S 1117.8 W S 12.87 W 3391.8 S 1133.5 W 4835.5 4745.5 3648.1 S 12.62 W 4904.5 4814.5 3720.1 S 12.07 W 4973.2 4883.2 3792.2 S 11.58 W 5041.4 4951.4 3864.8 S 11.98 W 5108.9 5018.9 3938.1 S 12.10 W 5175.9 5085.9 4011.8 S 11.78 W 5242.7 5152.7 4085.7 S 12.24 W 5310.7 5220.7 4158.7 S 14.66 W 5379.2 5289.2 4231.3 S 14.55 W 5447.9 5357.9 4303.6 S 10.07 W S 9.22 W 5516.7 5426.7 4375.2 3462.4 S 1149.5 W 3533.2 S 1165.0 W 3604.2 S 1179.9 W 3675.9 S 1194.8 W 3748.0 S 1210.2 W 3820.7 S 1225.6 W 3893.4 S 1241.0 W 3964.7 S 1258.1 W 4035.2 S 1276.5 W 4106.2 S 1292.0 W 4177.8 S 1304.1 W CLOSURE DL DISTNCE BEARING /100 2562.6 S 19.05 W 1.28 2636.8 S 19.01 W 0.44 2710.0 S 19.00 W 1.91 2782.3 S 19.02 W 0.18 2854.7 S 19.04 W 0.12 2926.5 S 19.06 W 1.01 2997.6 S 19.05 W 0.39 3068.7 S 19.04 W 0.12 3140.2 S 19.02 W 0.70 3212.8 S 19.00 W 1.11 3285.9 S 18.97 W 0.18 3358.8 S 18.89 W 2.99 3431.5 S 18.74 W 0.43 3504.0 S 18.60 W 0.49 3576.2 S 18.48 W 0.58 3648.2 S 18.36 W 0.25 3720.3 S 18.25 W 0.35 3792.4 S 18.12 W 0.58 3865.2 S 18.00 W 0.53 3938.5 S 17.89 W 0.43 4012.4 S 17.78 W 0.50 4086.4 S 17.68 W 0.43 4159.5 S 17.60 W 1.86 4232.3 S 17.55 W 0.52 4304.7 S 17.46 W 2.44 4376.6 S 17.33 W 0.61 ^Survey Codes: 7/GYRO 3G-19 API50-103-20136 Page 4 05/08/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 7400 47.06 7 7500 44.59 7 7600 45.28 7 7700 45.74 7 7800 46.04 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE DIRECTION BEARING 5585.0 5495.0 4447.3 S 9.82 W 5654.7 5564.7 4518.4 S 13.05 W 5725.5 5635.5 4588.6 S 12.70 W 5795.6 5705.6 4659.6 S 13.00 W 5865.2 5775.2 4731.0 S 12.07 W RELATIVE-COORDINATES FROM-WELL-HEAD 4249.8 S 1316.2 W 4320.0 S 1330.4 W 4388.9 S 1346.1 W 4458.4 S 1362.0 W 4528.5 S 1377.6 W CLOSURE DISTNCE BEARING 4448.9 S 17.21 W 4520.3 S 17.11 W 4590.7 S 17.05 W 4661.8 S 16.99 W 4733.4 S 16.92 W /lOO 0.47 2.94 0.71 0.49 0.57 7 7900 45.86 5934.7 5844.7 7 7990 46.16 5997.2 5907.2 X 8200 46.16 6142.7 6052.7 4802.3 4866.4 5016.5 S 11.17 W S 11.03 W S 11.03 W 4598.9 S 1392.1 W 4805.0 S 16.84 W 4662.5 S 1404.5 W 4869.4 S 16.76 W 4811.1 S 1433.5 W 5020.2 S 16.59 W 0.50 0.34 0.00 ^Survey Codes: 7/GYRO X/EXTRAPOLATED 3G-19 API50-103-20136 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/91 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 100 190 0.24 190 0 0 S 78.61 W 0.24 S 0.52 W 200 290 0.19 290 0 0 S 78.96 W 0.30 S 0.88 W 300 390 0.10 390 0 0 S 47.74 W 0.35 S 1.13 W 400 490 0.51 490 0 0 S 30.32 W 0.76 S 1.39 W 500 590 2.61 590 0 0 S 12.28 W 3.18 S 2.29 W 600 690 6.60 690 0 0 S 12.04 W 10.93 S 3.86 W 700 791 8.88 790 1 1 S 13.76 W 24.33 S 6.93 W 800 893 12.71 890 3 2 S 12.46 W 42.77 S 11.26 W 900 997 17.56 990 7 4 S 12.31 W 69.14 S 17.03 W 1000 1104 24.54 1090 14 7 S 14.29 W 106.80 S 25.94 W 1100 1214 24.62 1190 24 10 S 15.23 W 150.99 S 37.59 W 1200 1324 25.18 1290 34 10 S 16.92 W 195.55 S 50.15 W 1300 1435 26.51 1390 45 11 S 20.20 W 241.15 S 65.93 W 1400 1548 28.53 1490 58 13 S 19.28 W 290.06 S 83.73 W 1500 1663 30.77 1590 73 15 S 18.55 W 343.99 S 101.87 W 1600 1780 31.78 1690 90 17 S 18.74 W 402.01 S 1700 1902 39.27 1790 112 22 S 13.43 W 469.16 S 1800 2035 41.92 1890 145 32 S 17.09 W 552.39 S 1900 2171 43.64 1990 181 36 S 19.08 W 639.74 S 2000 2314 47.89 2090 224 44 S 16.24 W 737.75 S 2100 2461 46.18 2190 271 47 S 17.97 W 840.39 S 2200 2604 44.93 2290 314 43 S 18.74 W 936.87 S 2300 2744 44.71 2390 354 41 S 20.00 W 1030.52 S 2400 2887 47.40 2490 397 43 S 15.38 W 1126.89 S 2500 3037 48.10 2590 447 50 S 13.06 W 1235.06 S 121.50 W 141.26 W 163.80 W 193.44 W 224.71 W 256.00 W 288.41 W 321.55 W 354.14 W 380.49 W 2600 3185 47.16 2690 495 48 S 14.25 W 1341.62 S 406.18 W 3G-19 API50-103-20136 Page 6 05/08/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2700 3331 46.25 2790 2800 3477 48.87 2890 2900 3632 49.63 2990 3000 3785 49.34 3090 3100 3938 48.61 3190 541 46 S 15.48 W 1444.08 S 433.46 W 587 46 S 16.63 W 1546.48 S 462.80 W 642 54 S 18.90 W 1658.57 S 498.89 W 695 54 S 23.55 W 1768.03 S 539.53 W 748 53 S 25.61 W 1872.49 S 588.02 W 3200 4087 46.84 3290 3300 4230 44.44 3390 3400 4367 41.65 3490 3500 4500 41.56 3590 3600 4635 44.04 3690 797 49 S 26.28 W 1971.87 S 636.53 W 840 43 S 28.40 W 2063.07 S 683.49 W 877 37 S 30.41 W 2144.17 S 729.34 W 910 33 S 21.92 W 2222.10 S 769.77 W 945 35 S 18.06 W 2307.79 S 800.60 W 3700 4781 47.92 3790 3800 4930 47.32 3890 3900 5075 46.32 3990 4000 5220 46.18 4090 4100 5363 45.37 4190 991 45 S 17.58 W 2408.62 S 832.13 W 1040 49 S 18.24 W 2513.96 S 865.66 W 1085 46 S 19.80 W 2613.59 S 901.03 W 1130 45 S 19.77 W 2712.16 S 936.53 W 1173 43 S 18.80 W 2808.60 S 970.33 W 4200 5505 45.33 4290 4300 5649 46.52 4390 4400 5796 46.94 4490 4500 5942 47.02 4590 4600 6089 46.78 4690 1215 42 S 18.28 W 2904.54 S 1002.38 W 1259 44 S 18.03 W 3002.51 S 1034.36 W 1306 46 S 17.94 W 3104.28 S 1067.51 W 1352 47 S 12.03 W 3207.94 S 1094.06 W 1399 47 S 12.11 W 3312.92 S 1116.07 W 4700 6234 46.36 4790 4800 6379 46.34 4890 4900 6525 46.94 4990 5000 6672 47.61 5090 5100 6821 48.12 5190 1444 45 S 12.78 W 3415.73 S 1138.98 W 1489 45 S 12.18 W 3518.33 S 1161.80 W 1535 45 S 11.68 W 3621.75 S 1183.47 W 1582 47 S 12.07 W 3727.72 S 1205.85 W 1631 49 S 11.88 W 3836.14 S 1228.80 W 5200 6970 46.90 5290 1680 49 S 13.93 W 3943.41 S 1252.65 W 3G-19 API50-103-20136 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/08/91 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5300 7116 46.90 5390 1726 46 S 13.84 W 4046.36 S 5400 7261 46.56 5490 1771 45 S 9.55 W 4149.88 S 5500 7407 46.88 5590 1817 46 S 10.05 W 4255.01 S 5600 7550 44.93 5690 1860 42 S 12.88 W 4354.15 S 5700 7692 45.70 5790 1902 42 S 12.98 W 4452.88 S 5800 7836 45.97 5890 1946 44 S 11.75 W 4553.69 S 5900 7980 46.12 5990 1990 44 S 11.05 W 4655.10 S 6000 8124 46.16 6090 2034 44 S 11.03 W 4757.31 S 1279.28 W 1299.50 W 1317.10 W 1338.25 W 1360.72 W 1382.89 W 1403.09 W 1423.02 W 3G-19 API50-103-20136 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/08/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 17.72 993 903 72 S 12.31 W 70 S 2000 41.59 1864 1774 553 S 15.90 W 530 S 3000 48.34 2565 2475 1264 S 12.88 W 1208 S 4000 48.18 3231 3141 2008 S 26.03 W 1914 S 5000 46.38 3938 3848 2710 S 20.04 W 2562 S 17 W 72 S 13.82 W 4.7 157 W 553 S 16.52 W 2.6 374 W 1265 S 17.21 W 1.1 608 W 2009 S 17.63 W 0.8 882 W 2710 S 19.00 W 1.9 6000 47.13 4629 4539 3431 S 11.61 W 3249 S 7000 46.49 5311 5221 4159 S 14.66 W 3965 S 8000 46.16 6004 5914 4874 S 11.03 W 4670 S 1103 W 3431 S 18.74 W 0.4 1258 W 4160 S 17.60 W 1.9 1406 W 4877 S 16.75 W 0.0 AOGCC GEOLOGICAL MAI'El-rIALS INVENTORY LIST FOR DEVELOPMENTAL WELLS COMPLETION DATE :nU~ -'" :" NO. :'l iNTERvALS I I, ~/,,~ - i I I I ISCALE I I I I I I I I I i 1 i I I t I I ARCO Alaska, Inc. Date: May 31 1991 Transmittal Ct: 8116 RETURN TO: ' ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. ~[--I0 1L-1 1L-1 1L-1 0o--151 ~I- 0~_ ,,,..1A-2 Cl{ -0~ -,4 A-2 Ol t-e3-"-,1A-2 "~I,A-2 "~1A-2 X,l,A-2 · ~,3 G- 1 4 4 4 7 9 Cement Bond Icg Geochem~l Log Cement Evaluation Log Acoustic Cement Bond Log After Squeeze Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Please acknowledge receipt and return one 5-12-91 5300-6327 5-12-91 5100-6330 5-12-91 5300-6349 4-24-91 4800-8400 3-2-91 4981-7880 3-2-91 5276-7379 1-25-91 7000-9914 3-26-91 5400-7984 3-3-91 5330-7380 3-2-91 5625-7860 1 -25-91 7000-9894 3-26-91 5000-7958 Receipt Drilling . State of Ala~a(+sepia) Date' REc£1V£D jUN 0 ~rage STATE OF ALASKA ~,.. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown __X_ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 145' FWL, Sec. 23, T12N, RSE, UM At top of productive interval 1715' FNL, 1660' FEL, Sec. 26, T12N, R8E, UM At effective depth NA At total depth 1906' FNL, 1725' FEL, Sec. 26, T12N, R8E, UM 5. Type of Well: Development Exploratory Stratigraphic Service (approx) (approx) 12. Present well condition summary Total Depth: measured 8200' feet (approx) true vertical 6163' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) None Junk (measured) None 6. Datum elevation (DF or KB) RKB 9O' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-1 9 9. Permit number 90-105 10. APl number 50-103-20136 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3842' 9 5/8" Intermediate Production 81 65' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth (approx) 115' 115' 845 Sx AS III & 3879' 3146' 545 Sx Class G 485 Sx Class G 8200' 61 63' & 200 Sx Class G tail RECEIVED Oil & Gas Cons. 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation J 15. November. 1990 I Oil ;K Gas 16. If proposal was verbally approved Name of approver Date approved Se rvi ce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance Mechanical Integrity Test_ Subsequent form require 10-//6¢'~ · Status of well classification as:, __ Suspended _ Date IApproval NO. Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Cooy ,~eturnpd SUBMIT IN TRIPLICATE ARCO Oil ano Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~lt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough ARCO ALASKA INC. I NORTH SLOPE Field ILease or ~nit KUPARUK ' J ADL: 25548 Auth. or W.O. no. ~Title AK5105 j DRILLING ALK: 2662 IState AK 31~ell no. --~9 Operator ARCO SpuddedsPuDor W.O. begun ]Date 08/07/90]Hour Date and depth as of 8:00 a.m, 08/08/90 (1) TD: 1480' (1480) SUPV:JCP 08/09/90 (2) TD: 3890'(2410) SUPV:KSP 08/10/90 (3) TD: 4047'( 157) SUPV:KSP 08/11/90 (4) TD: 5960'(1913) SUPV:KSP 08/12/90 (5) TD: 8025'(2065) SUPV:KSP 08/13/90 ( TD: 8200' ( SUPV: KSP Complete record for each day reported DOYON 14 IARCO W.I. 55.25207 Prior status if a W.O. 19:30 DRLG AT 1480' 9-5/8"@ 3879' MW: 9.1 VIS: 59 MOVE RIG FROM 3G-10 TO 3G-19, N/U DIVERTER, STRAP AND CALIBRATE BHA, TEST DIVERTER, SPUT AT 115' AND KOP AT 600' DRILL W/ DAVI-DRILL TO 1480'. ADT-6.6 DAILY:S78,013 CUM:$78,013 ETD:S78,013 EFC:$1,330 R/U TO RUN 9-5/8" CSG 9-5/8"@ 3879' MW: 9.7 VIS: 43 DRLG 1481' TO 3890', CIRC HOLE. MADE 29 STD WIPER TRIP, CIRC HOLE. POOH TO RUN 9-5/8" SURFACE, L/D BHA AND RU TO RUN 9-5/8". DAILY:S53,157 CUM:$131,170 ETD:S131,170 EFC:$1,330 DRLG AT 4047' 9-5/8"@ 3879' MW: 9.4 VIS: 39 RUN 9-5/8" CSG, SHOE AT 3879', CIR I CSG VOLUME. CMT CSG, PLUG HELD, LOST RETURNS W/ 70 BBL OF DISPLACEMENT STILL TO PUMP. N/D DIVERTER, RUN TOP JOB. N/U AND TEST HOPE. M/U BHA, RIH. DRLG FC, CMT TO 15' OF SHOE, TEST CSG, OK. DRLG CMT, SHOE AND 10' OF FORMATION, DISPLACE HOLE W/ NEW 9.SPPG MUD. RUN LEAKOFF TEST TO 12.5 PPG, NO LEAK. DRLG 3890' TO 4047' DAILY:S155,725 CUM:$286,895 ETD:$286,895 EFC:$1,330 DRLG 9-5/8"@ 3879' MW: 9.6 VIS: 39 DPJ~G ~Q.47' TO 4394'. POH FOR BHA CHANGE. CHANGE OUT BHA ~ O~'E~ TOOLS. TIH WITH TURBINE AND PDC BITo DRILLED TO DAILY: $77,803 CUM.' $364,698 ETD: $364,698 EFC: $1,330 DRLG 9-5/8"@ 3879' MW:10.6 VIS: 40 DRLG 5960' TO 7295'. POH FOR WASHOUT IN G GRADE DP 32 JTS DOWN. DRLG TO 7400 CIRC AND COND MUD. RAISE MW TO 10.4. 6) 175) POH TO CSG SHOE. LEAK OFF. TIH. DAILY:S58,974 TEST FORMATION TO 11.3 PPG EMW WITH NO DRLG 7400' TO 8025'. CUM=$423,672 ETD:S423,672 EFC:$1,330 CIRC W/ 7" CSG 7"@ 8200' MW:10.7 VIS: 41 DRLG 8025' TO 8200'. CIRC HOLE CLEAN. SHORT TRIP TO CSG SHOE. CIRC HOLE CLEAN. DROP SS SURVEY. SPOT DIESEL PILL. LDDP. REMOVE SOURCES, READ TOOLS, LD TURBINE AND BHA. PULL WEAR BUSHING. RU TO RUN 7" CSG. RUN 193 JTS 7" CSG TO 8200'. CIRC CSG VOLUME. DAILY:S168,192 CUM:$591,864 ETD:S591,864 EFC:$1,330 The above is correct For for~ prePa~t~ ~nd distributlo~,3, see Procedure~[j~'anual, Section 10, Drilling. Pages 8'8 and 87. I Data / " AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO (~, Iand Gas Company ~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Repolf" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish ARCO ALASKA INC. I NORTH SLOPE Field JLease or Unit KUPARUK I ADL: 25548 I Auth. or W.O. no. JTitle AK5105 I DRILLING Accounting cost center code State ALK; 2662 3~el~ no. - 9 Operator I A.R.Co. W.I. ,a~CO J 55. 25207 I Spudded or W.O. begun ~Date SPUD I 08/07/90 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON '14 08/14/90 (7) TD: 8200' ( 0) SUPV: KSP I otal number of wells (active or inactive) on this pst center prior to plugging and I bandonment of this well J our ~ Prior status if a W.O. 19:30 J FINAL REPORT REL RIG 7"@ 8200' MW: 0.0 VIS: 0 CIRC CSG VOL. CMT WITH DOWELL. PUMPED 485 SX LEAD CL G CMT W/2% D79 + 0.2% D47 + 1.3% D800. 12.5 PPG (182 BBL). TAILED IN WITH 200 SX CL G W/3% KCL + 0.050 GAL/SX D047 + .25% BWOW D065 + .8% BWOW D127 + .05% GAL/SX D135 + .2% BWOW D800. 15.8 PPG (41 BBL). DISP W/ 311 BBL BRINE. BUMPED PLUG, FLOATS HELD. CLOSE HYDRIL, PUMPED 30 BBL MUD DOWN ANNULUS. BROKE DOWN @ 800 PSI. BLED BACK 16 BBL. ND BOP SET SLIPS, CUT CSG. INSTALL HGR AND TREE VALVE. TEST FLANGE TO 3000 PSI. ATTEMPT TO PUMP DIESEL DOWN ANNULUS, UNABLE TO BREAK DOWN ANNULUS WITH 3000 PSI. REL'RIG TO MOVE @ 1430 HR. DAILY:S208,397 CUM:$800,261 ETD:S800,261 EFC:$1,330 P CEIV£D S ~. P - ? 1990 Alaska Oil a Gas Cons. ~om.~t~'., Old TD J New TD I Released rig J Date I Classifications (oiJ, gas, etc.) PB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oi'l on test Gas per day Pump size, SPM X length 'CI,io~e~-~i~(t' '~ ~ .I T.'~.' -' C.~, Water % GOR Gravity Aliowable Eff'ective date corrected ,, ,, Drilling, Pages 88 and 87. AR3B-459o3-C INumber all daily well history forms consecutively as they are prepared for each well, iPage no, Dlvlllon of AtlsntlcfllehfleldCompaeY ARCO Alaska, Inc. Date: August 31, 1990 Transmittal #: 7874 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. J 3 G- 19 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density / ,,/3G-19 Dual Gamma Ray Electrmagnetic Wave Resistivity ~f 3 G o 14 Dual Gamma Ray Compensated Neutron Porosity Simultaneous Formation Density V~ 3 G- 14 Dual Gamma Ray Electrmagnetic 8 - 2 5 - 9 0 Wave Resistivity Formation Exposure Time ~ 3 G- 16 Dual Gamma Ray Compensated 8 - 2 0 - 9 0 Neutron Porosity Simultaneous Formation Density ,~' 3 G- 16 Dual Gamma Ray Electrmagnetic 8 - 2 0 - 9 0 Wave Resistivity 8-12-90 8-12-90 8-25-90 Please acknowledge 3798-8200 3798-8200 3160-7040 3160-7040 4370-9653 4370-9653 Receipt Acknowledged' DISTRIBUTION: ~~'1...~... Date' REEEIVED .... ~EF - 4 1990 Ala~l~.Oil & Gas Cons. Commissior Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK ARCO Alaska, Inc. Date: August 31, 1990 Transmittal #: 7873 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the OPEN HOLE following items. receipt and return one signed copy of this transmittal. '~' 3G-19 ~/3G-14 v3G-16 Receipt LIS Tape and Listing 8 - 9 - 9 0 LIS Tape and Listing 8 - 2 9 - 9 0 LIS Tape and Listing 8 - 2 9 - 9 0 Acknowledged: ~ ...... DI,~TRIBUTION: Please acknowledge 900830 900834 900832,.~~~l'~0 Date' - ......... SEP Lynn Goettinger State of Alaska August t, 1990 Telecopy.. (907)276-7542 A. WaNe McBride Area Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 KuparUk ~ver Unit 3G- 19 ARCO Alaska, Inc. Permit No. 90-105 Sur. Loc. 2538'F~L, 145'FEL, Sec. 23, T12N, RSE, UM. Btmhole Loc. !906'F[UL, 172§'F~, Sec. 26, T12N, R8E, UM. Dear Mr. McBride: Enclosed. is the approved applicat~.on for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional emtts required by law from oth~r governmental agencies, and~ oes not a~thorize conducting drilling operations until all other required pe~tttlng dete~inations are made. The Commission wilt advise you of those BOPE tests that it wishes to witness. Very truly y~o~-rs, Co~tsst~er of Alaska Oil amd Gas Conservation Co~tssion BY O~ER OF nE CO~ISSiON dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse~ation w/o encl. LAS:~;A STATE OF ALASKA ' A "- OILAND GAS CONSERVATION COMMISo~ON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone X Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 90', pad 53' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage,,AK 99510-0360 ADL 25548 ALK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 145' FEL, Sec. 23, T12N, R8E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1715' FNL, 1660' FEL, Sec. 26, T12N, R8E, UM 3(3-19. #U630610 At total depth 9. Approximate spud date Amount 1906' FNL, 1725' FEL, Sec 26, T12N, R8.E, UM 03-AUG-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property i'5. proposed depth (~D"and TVD) property line 3G-12 8151' MD 1906' @ TD feet 240' at SURFACE feet 2560 6157' TVD feet 16. To be completed for deViated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 600 feet Maximum hole an~le 46° Maximum surface 1860 psig At total depth (TVD) 6157' 3250 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~ Weight Grade Couplin~ Length IVD TVD IVD TVD (include sta~e data/ . , . !24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115, ±200 Cu. Ft. , ,, 12.25 9.625 36.0# J-55 BTC 3776' 35' 35' 3811 3140 1650 Cu. Ft. AS III & , , HF-ERW 625 Cu. Ft. Class G , 8.'5 7" 26.0# J-55 BTC 8116' 35' 35' 81 51' 61 57 195Cu. Ft. ClassG , HF-~.RW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. i .ECEIVED Surface Cu. R .... Intermediate Production Liner J ,!L £ ' Perforation depth: measured :;' true vertical / ch0ra6, ? i 20. Attachments Filing fee ~ Property plat ~ BOP Sketch _.~ Diverter Sketch X Drilling program X !Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I 'hereby certify that the foregoing is lrue and correct tO the best ~)f my knoWledge Si~ned ,/~//~~'t~ Title Area Drilling Engineer Date v Commission 'Use Only ",/ /'~', Permit Number APl number Approval date 08 / 01 / 9 ~:['"') '- ,/d'~ ~ 50- /C3,,~'-- -~<:3/~,~ ~' other rec~uire, ments Condi'{ions c~f approval Samples required ~Y e s ,~ N o Mud Icg required ~ Y e No Hydrogen sulfide measures __ Yes ~1~ No Directional survey required ,~Yes ~ N ~ O Required working pressure for BOPE~ ~2M; ~ 3M; ~ 5M; ~ 10M; ~ 15M Approved by , ~"~-" , Commissioner the commission Da,,te, Form 10-401 Rev. 7-24-8c,' Submit in triplicate DRILLING FLUID PROGRAM (3G-19) Spud to 9-5/8" Drill out to Weight up surface casing wei_oht up to TD Density 8.6-10.0 8.6-9.3 1 1.0 PV 15-35 5-15 10-1 8 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4 - 8 4 - 8 APl Filtrate 10-1 2 8- 10 4- 5 pH 9-1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators i?EC£tVED 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 1860 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-19 is 3G-12. As designed, the minimum distance between the two wells would be 240' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, !ne, Pad 30, Nell No, 19 Kuparuk Field, Nor'th Proposed SI ope, Al asks 0 _ RKB ELEVAT[ON' 90' 1000_ 20O0 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ KOP 9 15 21 2T TVD=600 TMD=600 DEP=O BUILD 3 OEO PER !00 FT B/ PERMAFROST TVD=I605 TMD=1658 DEP=286 T/ UGNU SNDS TVD=I720 TMD=1797 DEP=36:3 39 45 EOC TVD=I97:3 TMD=21:32 DEP=582 T/ 14 SAK SNDS TVD=2455 TMD=2826 DEP=I081 B/ 14 SAK SNDS TVD=2940 TMD=3523 DEP=1582 9 5/8" CSO PT TVD=:3140 TMD=3811 DEP=1789 K-lO TVD=3280 TMB=4012 BEP=1934 AVERAOE ANOLE 45 DEO 58 HI N K-5 T/ ZONE C/A TARGET CNTR B/ KUP SNDS TD (LOG PT) TVD=4460 TMD=5710 DEP=:3154 TVD=5905 TMD=7789 DEP=4649 TVD=5962 TMD=7871 DEP=4707 TVD=6018 TMD=7951 DEP=4765 TVD=6157 THD=8151 DEP=4909 I I I I I 1000 2000 3000 4000 5000 VERTICAL SECTION 245O 2500 2550 26OO 2650 2700 275O 200 I 150 I 100 I 50 I 200 # 300 / / ! 900 / / 1100 / / / / / / /' 1 30O I 150 I 100 "~3oo 500 \ ' roo '~ 900 \ 11100 \ \ \ ! 0 50 100 I 150 200 / / ,, i ,// 1 700 I 100 I 150 i 2O0 245O 2500 255O 26O0 2650 _ 27O0 _ 2750 HORIZONTAL SCALE 1 IN. PROJECTION = ! 000 FEET z 0 -,4 I TARGET LOCATION~ 1715' FNL, 1660' FEL SEC. 26, TI2N, RSE TD LOCATION 1~t06' FNL, lT25' FEL SEC. 1000 1000 2000 ,3000 4000 5000 ARCO ALASKA, lnG. Pad 30. Well No= 19 Propoaed Kuparuk FI · I d. North SI ope, Al aaka WEST-EAST 2000 1000 0 I I 1000 I ( ) SURF.ACE SURFACE LOCATION, 2538' FNL, 145' FEL SEC. 23, TI2N. RSE TARGET CENTER TYD=$962 THD-?S?I DEP-4?O? SOUTH 445? WEST 1515 S 18 DEG 46 MI N t4 4707' (TO TARGET) GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point 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. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. Ku~PARUK RIVER UNIT 20" DIVERTER SCHEMATIC 5 6 4 3 DO NOT SHUT IH WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HF. AD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ,6 , I I 13 5/8" 5000 PL. 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. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" ~ 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 VICINITY NO. Y 6 ~900~800.00 490,6P4.?0 70°PR'47.~R4" 13 8~980,660.46 490, 384.86 ?O°P~' 07. pPO" EW.I.. 0.$. 855' 40.9 55.9 1~5' 40. P 84.0 170' 47.8 NO. ~' X I. A ~ L ONO. /4 8, p00,$60. 83 490,389,?P ?O°P~ 4?.9R8" I~0o00,~0.0~ / , I0 8,900~b~0. 81 4~0, 334.00 ?~PP' 47.9P0" 150°00'40.7~0" F.N.L. P.K.L. 0.$. Pb$O'°' Po' 4?,P 65.1 P050''/ 70' 46.9 §$.1 £030'-- 95' 46.0 ~$.0 P050'~ /PO' 46.6 Pb3O' ~ /70' 46.4 ~P.9 R~O' RPO ' 46.8 I If£1?~OY CffRTIFY TI~AY I AM ~NO SU~VffPlN~ IN YH~ 9rAT~ O~ AND ~AT ?Hl~ ~LAp N~PR~N~ MAOff ~ M~ ~ UN~R MV O/O~P ( ~ T~T A~L 01~1~ AND ORIL /- $I Y£ 3, ~ CONDUCTORS 8-22 AB BOlL T LOCATION I I ii iii I I I [OI3NSBIJA' & ASSOCIATES./ 't (1) (8) (3) Admin/f~_ ~/~) 9. '(9 thru 13) 10. (10 ~d 13) 12. 13. (14 ~h~ 22) (5) BOPE (23 thru 28) Company _/~//'r-.~'5 Lease & Well No. /7~g YES NO Is the permit fee attached .......................................... ~ -- · 2. Is well to' be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~_ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is we!lbore plat included ................ 7. Is operator the oniy affected party ......... ; ....................... 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~-- Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is cdnductor string provided ....... ................................ Wi!i surface casing protect ail zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate.~ Are necessary diagrm~ and descriptions of dive:re: and BOPE attached. Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. , ,, Is the presence of H2S gas probable ............................. ~... (6) 0TIIER (6) Add: Geology. DWJ .~ (29 thru 31) Engineering: LCS BEW rev: 01/30/89 6.011. · For 29. 30. 31. 32. e~ploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON 1 OFF POOL CLASS STATUS AREA NO. SHORE 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. T° 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 APPENDIXi No special 'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/08/20 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/08/20 ORIGIN OF DATA: 3G19 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G19.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/08/20 MAX. RECORD LENGTH: 1024 FILE TYPE: PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-19// API#: 50-103-20136// DATE: 12 AUG 90 LOCATION: 2538' FNL & 145' FEL, SEC. 23, TWP 12N, RANGE 8E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, U.S.A.// RIG; DOYON 14// CO. REP.: KEN PRICE RLL ENG: HANIK & BROWN ** COMMENTS **> NEUTRON & DENSITY LOGS ARE CALIPER CORRECTED. NUCLEAR PROCESSING ASSUMES A SANDSTONE MATRIX AT 2.65 G/C3, FLUID DENSITY @ 1.0 G/C3, FORMATION WATER SALINITY 14,545 PPM CL-, MUD WT. 9.4-10.6 MUD SALINITY 800 - 1100 PPM, NO TOOL WEAR FACTORS, NO TOOL MOTION CORRECTION, AND NO CHANGES IN PRE VS POST JOB CALIBRATION FACTORS. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 NFO MWD CTS 0 0 0 0 1 4 0 1 68 NFl MWD CTS 0 0 0 0 1 4 0 1 68 NN0 MWD CTS 0 0 0 0 1 4 0 1 68 NN1 MWD CTS 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 GRC MWD API 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0, 0 0 0 1 4 0 1 68 NPS C MWD P. U. 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT EWR MWD NFO MWD NFl MWD NN0 MWD NN1 MWD FXE MWD ROP MWD GRC MWD CAL MWD NPSC MWD CAL MWD RHOB MWD FT 0 0 0 0 OI-[D~ 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 HOUR 0 0 0 0 FT/H 0 0 0 0 API 0 0 0 0 INCH 0 0 0 0 P.U. 0 0 0 0 INCH 0 0 0 0 G/C3 0 0 0 0 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 ** DATA VERIFICATION DEPT ROP 3650.000 -999.250 3700.000 -999.250 3800.000 141.064 3900.000 82.106 4000.000 75.220 4100.000 69.387 4200.000 62.757 4300.000 72.879 4400.000 343.455 4500.000 180.761 4600.000 298.242 4700.000 45.392 4800.000 203.027 4900.000 158.891 5000.000 271.080 5100.000 243.750 5200.000 243.633 5300.000 223.035 5400.000 266.143 5500.000 243.516 EWR GRC -999.250 -999.250 -999.250 -999.250 30.019 46.331 2.889 72.935 7.037 84.614 3.822 92.152 4.336 86.914 3.981 94.208 3.731 90.211 3.437 95.124 3.331 106.604 3.512 100.908 3.405 88.532 4.448 60.670 3.114 113.566 3.390 110.808 3.532 115.125 3.572 89.316 4.948 179.502 3.163 129.017 (every 100 FT) ** NF0 CAL -999.250 -999.250 -999.250 8.350 416.000 8.710 447.475 8.570 555.247 8.610 562.946 8.400 542.859 8.430 544.413 8.660 519.000 9.110 594.163 8.670 607.000 8.480 543.000 8.810 496.819 8.740 635.759 8.590 543.000 8.550 591.000 8.970 607.000 8.940 622.490 8.560 663.000 8.890 617.821 8.710 NFl NPSC -999.250 -892.230 -999.250 -892.230 469.000 51.786 456.798 49.666 572.380 37.333 529.256 43.010 520.650 42.333 533.014 43.090 485.000 43.917 604.432 36.835 607.000 37.188 591.000 39.152 511.651 40.297 603.456 30.568 607.000 37.253 591.000 34.114 631.000 33.687 623.510 34.497 687.000 35.103 595.232 39.284 NN0 CAL -999.250 -999.250 -999.250 8.350 2312.000 8.710 2407.076 8.570 2629.421 8.610 2471.971 8.400 2567.003 8.430 2478.913 8.660 2392.000 9.110 2606.326 8.670 2616.000 8.480 2584.000 8.810 2611.978 8.740 3010.126 8.590 2696.000 8.550 2840.000 8.970 2728.000 8.940 2786.327 8.560 2552.000 8.890 2498.357 8.710 NN1 RHOB -999.250 -999.250 -999.250 .615 2232.000 2.487 2338.583 2.332 2692.129 2.492 2482.637 2.462 2499.745 2.477 2404.149 2.480 2472.000 2.109 2664.000 2.273 2696.000 2.345 2552.000 2.306 2679.970 2.332 2950.582 2.519 2728.000 2.364 2632.000 2.518 2696.000 2.490 2699.058 2.274 2616.000 2.500 2530.357 2.700 FXE -999.250 -999.250 .389 1.521 .843 .893 .829 .790 1.054 .695 .913 .755 .931 .681 .631 .487 .701 .660 .598 .645 5600.000 232.690 5700.000 310.107 5800.000 331.587 5900.000 148.197 6000.000 315.631 6100.000 185.889 6200.000 370.439 6300.000 280.844 6400.000 265.681 6500.000 265.932 6600.000 344.851 6700.000 261.161 6800.000 351.243 6900.000 344.851 7000.000 162.997 7100.000 207.031 7200.000 237.195 7300.000 304.688 7400.000 281.250 7500.000 203.125 7600.000 121.875 7700.000 165.445 7800.000 199.414 3.110 141.480 3.529 153.843 2. 125 133.172 3.690 154.180 4.246 135.697 4.240 141.418 3.657 129.925 3.243 105.324 4.086 94.487 3.352 105.025 3.516 112.525 4.373 100.933 4.761 87.724 5.474 107.475 3.204 133.184 6. 128 88.507 3.902 136.430 4.402 175.286 3.280 209.391 3.207 115.519 2. 639 112. 657 2.238 105.871 7.769 72.284 655.000 9.120 676.936 9.070 543.000 8.740 633.936 8.840 623.000 8.440 575.000 8.510 583.000 8.430 561.286 8.440 639.000 8.720 655.000 8.620 615.000 8.670 623.000 8.570 583.000 8.700 599.000 8.470 589.198 8.430 608.305 8.910 623.000 8.850 623.000 8.890 743.000 8.930 554.707 8.630 521.384 8.560 527.000 8.590 575.000 8.640 623.000 33.477 697.516 32.781 535.000 42.329 643.734 37.571 599.000 40.242 631.000 39.298 615.000 38.154 571.571 40.799 623.000 33.742 607.000 35.789 591.000 34.857 663.000 34.029 559.000 35.674 607.000 34.699 638.874 36.262 629.695 31.168 615.000 38.038 655.000 35.419 791.000 35.789 536.268 43.580 507.541 45.267 503.000 47.455 575.000 34.334 2648.000 9.120 2664.904 9.070 2472.000 8.740 2590.532 8.840 2536.000 8.440 2536.000 8.510 2648.000 8.430 2554.286 8.440 2744.000 8.720 2680.000 8.620 2760.000 8.670 2696.000 8.570 2808.000 8.700 2776.000 8.470 2683.099 8.430 2823.241 8.910 2568.000 8.850 2680.000 8.890 2424.000 8.930 2472.000 8.630 2498.356 8.560 2408.000 8.590 2856.000 8.640 2664.000 2.752 2606.840 2.738 2536.000 2.592 2488.661 2.639 2504.000 2.540 2584.000 2.484 2648.000 2.530 2588.571 2.557 2728.000 2.407 2616.000 2.346 2712.000 2.351 2760.000 2.336 2680.000 2.408 2840.000 2.327 2731.099 2.439 2814.315 2. 196 2520.000 2.335 2584.000 2.438 2456.000 2.207 2441.171 2.396 2405.837 2.377 2296.000 2.373 2776.000 2.366 .544 .586 .814 .468 .596 .479 .490 .584 .504 .715 .576 .573 .729 .722 .826 .849 .719 .477 2.827 .836 .895 1.049 .751 7900.000 174.275 7.466 615.000 575.000 2664.000 86.854 8.480 35.826 8.480 3.213 543.000 543.000 2616.000 90.272 8.710 39.328 8.710 2.750 535.668 537.858 2513.294 91.227 8.670 42.127 8.670 -999.250 -999.250 -999.250 -999.250 -999.250 8.350 -892.230 8.350 ** 485 DATA RECORDS ** FROM 3650.00 TO 8000.000 107.588 8100.000 148.992 8200.000 -999.250 ** FILE TRAILER** FILE NAME: 3G19.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/08/20 MAX. RECORD LENGTH: FILE TYPE: NEXT FILE NAME: 1024 ********** END OF FILE (EOF 2808.000 2.378 2632.000 2.440 2500.340 2.411 -999.250 -999.250 8250.00 FT # 2) ********** .855 1.465 1.985 -999.250 ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/08/20 ORIGIN OF DATA: 3G19 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/08/20 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT