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Home My WebLink About196-140 STATE OF ALASKA 4 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPIEE. • REPORT AND LOG 1a.Well Status: Oil El Gas ❑ SPLUG ❑ Plugged ❑ Abandoned W/ a ed 012 V. 1b.Well Class: ✓ , E - it 20AAC 25.105' C •'0 Development Exploratory Ill GINJ ❑ WINJ El WAG ❑ WDSPL ❑ Other ❑ No.of Completions: P(b 4 v Service ❑ Stratigraphic Test 2.Operator Name: V 5.Date Comp.,Susp., ✓ 12.Permit to Drill Number: #"" ConocoPhillips Alaska, Inc. or Aband.: March 10,2013 196-140/313-082 3.Address: 6.Date Spudded: ✓ 13.API Number: v P.O.Box 100360,Anchorage,AK 99510-0360 September 1, 1996 50-029-21003-01 4a.Location of Well(Governmental Section): .. 7.Date TD Reached: 0.14.Well Name and Number:V Surface: 386'FSL,793'FWL,Sec.29,T12N,R10E,UM September 6, 1996 1G-10A Top of Productive Horizon: 8.KB(ft above MSL): 94'RKB ✓15.Field/Pool(s): 1132'FSL, 1306'FEL,Sec.29,T12N,R10E,UM GL(ft above MSL): 63'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): ✓ 1015'FSL, 1044'FEL,Sec.29,T12N,R10E,UM 7318'MD/6354'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): y 10.Total Depth(MD+ND): v 16.Property Designation: ✓ Surface: x-540572 y- 5981035 Zone-4 7906 MD/6864'ND • ADL 25640 TPI: x-543746 y- 5981799 Zone-4 11.SSSV Depth(MD+ND): V 17.Land Use Permit: Total Depth: x-544009 y- 5981683 Zone-4 nipple @ 523'MD/523'TVD 2571 18.Directional Survey: Yes ❑ No❑✓ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1668'MD/1599'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD CBL ✓ not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT -• CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 39' 116' 39' 116' 24" 212 sx CS II 10.75" 45.5# K-55 37' 2350' 37' 2185' 13.5" 930 sx AS III,250 sx AS I 7" 26# K-55 35' 6290' 35' 5441' 8.75" 850 sx Class G,250 sx AS I 3.5" 9.2# L-80 6142' 7906' 5305' 6868' 6.125" 396 sx Class G 24.Open to production or injection? Yes ❑ No ❑✓ If Yes,list each ✓25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 6151' 6149'MD/5305'TVD perfs squeezed off: 7318'-7340'MD 6354'-6373'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 7352'-7358'MD 6384'-6389'ND RECEIVED Was hydraulic fracturing used during completion? Yes❑ No Q 7366-7374'MD 6396-6403'ND DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7614'-7644'MD 6613'-6639'ND APR 3 0 2013 7318'-7644' 15 bbls of 15.8#Class G AOGCC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE SCANNED APR 2 3 2014 Form 10-407 Revised 10/2012RBDMS,MAY/^', 8013 gQ TINUED%N%EVEI /7 1 / // 11/40y z. original only z. 29. GEOLOGIC MARKERS(List all formations and m encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1668' 1599' needed,and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kai Starck @ 263-4093 Email: Kai.Starck@conocophillips.com Cr" /1 Printed Name Lamar Gantt Title: Coiled Tubing Drilling Supervisor Signature Arax,> .i I 11'-AA4CA., Phone 263-4021 Date 4/26(/ 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 1G-10A Well Work Summary DATE SUMMARY 1/26/201a TAGGED @ 7765' SLM. MEASURED BHP @ 7300' RKB: 2630 PSI. GAUGED TBG TO 2.79"TO 6141' RKB. DRIFTED WITH 17.3'x 2.625" DUMMY WHIPSTOCK TO 6770' SLM. SET 2.75"CA-2 PLUG @ 6141' RKB; PT TBG AGAINST PLUG & DRAW DOWN TESTED, PASSED. IN PROGRESS. 1/27/2013 SET AVA CATCHER ON PLUG @ 6141' RKB. PULLED GLVs FROM 4755', 3664', &2396' RKB. SET DVs @ SAME. ATTEMPTED PULL OV @ 6095' RKB. IN PROGRESS. 1/28/2013 PULLED OV @ 6095' RKB. LOADED WELL WITH 185 BBL DSL TAKING RETURNS OFF IA TO PRODUCTION. COMBO MITT x IA 2500 PSI, PASSED. SET DV @ 6095' RKB. MIT IA 2500 PSI, PASSED. PULL AVA CATCHER @ 6141' RKB. IN PROGRESS. 1/29/2013 PULLED CA-2 PLUG @ 6141' RKB. READY FOR E-LINE. 1/31/2013 PERFORMED CALIPER SURVEY WITH 24-ARM MIT. LOGGED FROM 7650'TO SURFACE. 2/1/2013 PERFORMED GYRO SURVEY WITH GYRODATA GYRO TOOLS. LOGGED SURVEY FROM 7600'TO SURFACE. 2/15/2013 (PRE-CTD): RIG WORK-T POT(PASSED), T PPPOT(PASSED), IC POT(PASSED), IC PPPOT(PASSED). SV(PASSED), SSV(PASSED), MV(INCONCLUSIVE). IN PROGRESS. 2/16/2013 (PRE-CTD) MITOA(DID NOT CATCH PRESSURE), PT& DDT ON SV(PASSED), SSV (PASSED), MV(PASSED), RE-ENERGIZE OC PO"Y"SEAL 2/17/2013 (PRE-CTD): RIG WORK-SCLD(SUSPECTED TO BE —858') 2/27/2013 SET CATCHER @ 2505'SLM. PULLED DV @ 2396' RKB& REPLACED WITH OV. PULLED CATCHER. READY FOR DHD. 2/28/2013 (PRE-CTD) OA NFT-FAILED WOULD NOT BLEED TO OPSI. 3/1/2013 PERFORMED RADIAL CEMENT BOND LOG AND SBHP WITH PRESSURE MEMORY GAUGE. FOUND GOOD CEMENT BOND OVER ZONE OF INTEREST AT 7300'-7600'. FOUND ESTIMATED TOP OF CEMENT @ 6160'. SBHPS FOUND 2723 PSI AND 160 DEGF AT 7500'. 2682 PSI AND 159 DEGF AT 7386' 3/2/2013 (AC EVAL) OA DD TEST- FAILED ON GAS PASSES W/O GAS 3/3/2013 SET 2.75" D CAT SV @ 6141' RKB. PULLED OV @ 2396' RKB. CIRC'D OUT 85 BBL DSL. SET DV @ 2396' RKB. ATTEMPTED MIT TBG 2500 PSI.. OPERATIONS SUSPENDED FOR HIGH WINDS. IN PROGRESS. 3/4/2013 MIT IA 2500 PSI, PASSED. TESTED TBG AGAINST HOLEFINDER 2500 PSI, PASSED. PULLED CAT SV @ 6141' RKB. READY FOR CTU. 3/7/2013 Pumped 15 bbl 15.8 ppg class"G" neat, squeezed 9 bbls to perfs 7,318-ft to 7,644-ft RKB, achieved 1200 psi squeeze pressure,washed tubing down to 7,240-ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/8/2013 Weather delayed start. Conduct weekly BOP test 250/4,000 psi. Remove snow from surface lines and equipment. Job in progress. 3/9/2013 Milled"D" nipple out to 2.80". Tagged TOC at 7,370-ft CTMD, 52-ft below top perf. Established injection rate of 1,050 psi at.5 bpm. Return in AM for repeat cement job. 3/10/2013 Pumped 10 bbl 15.8 ppg class"G" neat, squeezed '3 bbls to perfs 7,318-ft to 7,370-ft RKB, achieved 1200 psi squeeze pressure, washed tubing down to 7,200-ft, POOH jetting tubing, freeze protect, trapped 500 psi at surface. Stand back CTU for night. 3/11/2013 Milled cement in liner from 7,181-ft to 7,510-ft with 2.7"x 3" Bi-center mill. Test tubing to 1,200 psi. RDMO. Ready for Slickline. 3/12/2013 TAG TOC @ 7503' SLM/—7526' RKB. MITT TO 1475 PSI ( PASS ) . DRIFT TO TAG DEPTH WITH DMY WHIPSTOCK DRIFT. READY FOR E-LINE TO SET WHIPSTOCK. 3/15/2013 Set 3 1/2" Baker Monobore Whipstock with TOWS at 7482' at an orientation of 140 ROHS 3/16/2013 RDMO from 1H-19, move rig to 1G-10 3/17/2013 Mobilize rig from 1H-19 to 1G-10. Spot rig & RU. Start BOPE testing at 12:00pm. State Waived witness by John Crisp. Rig Accept 12:00pm 3/18/2013 PU/MU/RIH BHA 1. Displace well to 9.6ppg used FP. Dry tag TOWS 7481'. Mill window including rat hole down to 7501'. Backream window. POOH 3/19/2013 Finished milling 2.80 OD window, Displace well to 9.5ppg Flo-Pro. POOH. Undeployed 3/20/2013 Finished landing the build section at 8010ft. POOH. Undeployed build PuP, Deployed the B lateral BHA with Rib Stee 'H .. 4 ) s THE STATE or 7,44, Alaska Oil and Gas °f ALAS :A F., _ Conservation Commission GOVERNOR SEAN PARNELL ra 333 West Seventh Avenue Off; Anchorage, Alaska 99501 -3572 ALASY' Main: 907.279.1433 Fax: 907.276.7542 Kai Starck SCANNED MAR 1 2013. CTD Specialist ✓ p ConocoPhillips Alaska, Inc. 6 (� jot P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1G-10A Sundry Number: 313 -082 Dear Mr. Starck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this day of February, 2013. Encl. STATE OF ALASKA RECEIVED ED A OIL AND GAS CONSERVATION COMION 1'i S / V S(t APPLICA TION FOR SUNDRY APPROVALS FEB 15 201r J C--- 20 AAC 25.280 � �1 ,��,ryry,,((//��,, 1. Type of Request: Abandon I"° Rug for Redrill )✓ . Perforate New Pool F 8C 1 Chan tl74 Repair w ell =1 og ram 1... Suspend E Rug Perforations I✓ , Perforate r Pull Tubing 1 - Time Extension r Operational Shutdown E Re -enter Susp. Well (-"° Stimulate I- Alter casing f°" Other: I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development we s, Exploratory r - 196 -140 3. Address: Stratigraphic r Service 1 - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21003 - 01 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes I - No IV 1G-10A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25640. Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): - 7906 6864 7815' 6789' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 • 116' 116' SURFACE 2313 10.75 •2350' 2185' PRODUCTION 6255 7 s 6290' 5441' LINER 1764 3.5 7906' 6868' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7318 -7340, 7352 -7358, 7366 -7374, 7614 -7644 6354 -6373, 6384 -6389, 6396 -6403, 6613 -6639 3.5 L - _ 6151 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER C -2 ZXP LINER PACKER ' MD =6149 TVD =5313 SSSV - CAMCO DS LANDING NIPPLE * MD =523 TVD =523 12. Attachments: Description Sunrrrary of Proposal , I:: 13. Well Class after proposed work: Detailed Operations Program fl BOP Sketch 1 - Exploratory t Stratigraphic E Development W W. Service (` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 Oil 1" Gas 1'" WDSPL E Suspended F. - 16. Verbal Approval: Date: VVINJ I" GINJ r WAG f - Abandoned ( - Commission Representative: GSTOR E SPLUG I- 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kai Starck @ 263 -4093 Email: Kai .Starcktp7.conocophiIIioS.com Printed Name Kai,_ tarck Title: CTD Specialist Signature /, j� � �� A Phone: 263 -4093 Date Commission Use Only Sundry Number: 1 3-W Conditions of approval: Notify Commission so that a representative may witness l c.. Plug Integrity [ BOP Test Mechanical Integrity Test F Location Clearance E Other. DoP /-c-5 t to ¢GOO /75 1 A - l t� rh 4 fc p / (2 y p1 a 6l' a r ki 7 a/) P rO V tc( p er 2 °A -11-C 5.--.,1 /2/(6) . Spacing Exception Required? Yes ❑ No (,lJ Subsequent Form Required: /0- 4-67. RBDMS FEB 2 if APPROVED BY Approved b : - / A papplication is vaFM.Vg the from th IRM val. Date: .2 —25 —2— /3 Form 10 -403 (Revised 10/2012) y � 1 / 3 0R1G1NAL Submit Form and Attachments in Duplicate � • • KRU 1G -10A CTD Summary for Plugging Sundry (10 -403) Summary of Operations Well KRU 1G-10 was originally completed in 1984 as a C1 -sand producer. In 1996 it was sidetracked and 1G -10A was an A -sand producer until 1999 when the C3 and C4 intervals were 'perforated and stimulated with a small fracture treatment. The well continued as an A and C sand dual producer until October 2012 when it was shut in due to low productivity and freezing issues. The C -sand perforations will be cement squeezed with a cement plug left over the A -sand perforations. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 7482' MD. A mechanical whipstock will be placed in the 3W liner at the planned kickoff point. The 1G-10B sidetrack will exit the 3' /Z" casing at 7482' MD and target the A4 sand to the north of the existing well with a 2918' lateral. The hole will be completed with a 2 %" slotted liner to the TD of 10,400' MD with an aluminum billet at 8935' MD. The 1G -10BL1 lateral will kick off from the aluminum billet at 8935' MD and will target the A3 sand north of the existing well with a 1465' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,400' MD with an aluminum billet at 7900' MD. The 1G -10BL2 lateral will kick off from the aluminum billet at 7900' MD and will target the A4 sand southwest of the existing well with a 2200' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,100' MD with a liner top deployment sleeve at 7470' MD, inside the 3 %" liner. y 0,ttvt• froottcr/oA 4c0/ olfere°' 7 0 too d0`.Q Pre - CTD Work r rye Ti 'rk e Ttia p.4J 57vr 14 • i® e 1. MIRU slickline. Dummy all GLMs. 2. MIRU a -line, perform CBL 3. OPTIONAL- Pending results of CBL - MIRU a -line, perforate 3 -1/2" liner at 7480 -7490. To ensure good cement isolation at the window from the C1. 4. Perform injectivity test into open A & C -sand perfs. 5. MIRU coiled tubing. Cement squeeze the open perforations and lay in cement in the 3 -1/2" liner, leaving the cement top in the 3 -1/2" liner at 7290'. 6. Coiled tubing. Mill 2.75" Camco D nipple at 6141' to 2.80" 7. Mill cement from 7290' to 7510' with a bi- center bit. This will leave a cement plug 100' above the A -sand perforations. 8. MIRU slickline. Run whipstock dummy inside 3W liner. p A. )160 HD 9. Prep site for Nabors CDR2 -AC, including setting BPV � 31 3 -0 g2 Rig Work f-z5 t 4"CP s, 9 7 /Vo 1 4-017c6 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. a4 krs ) 1, ad vA Y , c_g 2. 1G-10B Sidetrack (A4 sand, North) a. Set whipstock at 7482' MD with 140 ROHS orientation b. Mill 2.80" window through 3 %" liner c. Drill 2.70" x 3" bi- center lateral to TD of 10,380' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 8930' 3. 1 G -10BL1 Lateral (A3 sand, north) PTO lG — 1 2 ,3 o zl • • a. Kick off of the aluminum billet at 8930' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,400' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7895' MD 4. 1 G -10BL2 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 7895' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,100' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7470' MD inside the 3'/" liner 5. Freeze protect. Set BPV, ND BOPE. 6. RDMO Nabors CRD2 -AC. Post - Rig Work 1. Pull BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production KUP • 1G-10A ConocoPhillips Well Attributes Max Angle & MD TD • Alaska, Inc, Wellbore APW WI Field Name Well Status Incl (°) MD (RKB) Act Btm (ftKB) 500292100301 KUPARUK RIVER UNIT PROD 42.80 3,614.17 7,906.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NIPPLE 65 9/4/2011 Last WO: 9/28/1996 31.18 9/7/1983 Well Conk! - 1G -10A, 3/7/2012 2 5408 PM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,740.0 8/2/2011 Rev Reason: WELL REVIEW osborl 3/7/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 26 CONDUCTOR 16 15.063 39.0 116.0 116.0 62.58 H - 40 WELDED `�„� Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - SURFACE 103/4 9.950 37.1 2,350.3 2,185.4 45.50 K - 55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.1 6,290.0 5,441.1 26.00 K -55 BTC y,, Post Sidetrack Casing Description String 0... String ID ... Top (ftKB) Set Depth (f._ Set Depth (TVD) ... String Wt... String ... String Top Thrd ' LINER 31/2 2.992 6,142.3 7,906.0 6,868.4 9.20 L - 80 ABM - BTC Liner D Top Depth (TVD) Top Inc! Nom'... - -- Top (R 1") stem Description Comment ID (in) iiii 6 5,3 24.50 TIEBACK BAKER TIEBACK SLEEVE 5.250 6,149.2 5 24.45 PACKER BAKER C -2 ZXP LINER PACKER 4.437 CONDUCTOR, 6,155.5 5,318.6 24.40 HANGER BAKER HMC HYDRAULIC LINER HANGER 4.375 39 - 116 6,162.1 5,324.6 24.35 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 NIPPLE, 523.1„ Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 26.0 6,151.1 5,314.7 9.30 J -55 ABM -EUE Completion Details Top Depth (TVD) Top Ind Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 26.0 26.0 -15.64 HANGER CAMERON GEN IV HANGER 3.500 SURFACE, 1 523.0 523.0 0.93 NIPPLE CAMCO DS LANDING NIPPLE 2.812 37 - 2,350 6,141.1 5,305.6 24.51 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT, : 6,148.1 5,312.0 24.46 LOCATOR BAKER GBH -22 LOCATOR SHOULDERS UP ON LINER TIE BACK 3.000 2,396 6,150.2 5,313.8 24.44 SEALS BAKER SEAL ASSEMBLY - SEALS EXTEND INTO LINER SBE (SEALS 3.000 N I 24.5' OAL) GAS LIFT, 1 _ 3.665 Perforations & Slots Shot ` Top (TVD) Btm (TVD) Dens GAS LIFT, 1 Top (ftKB) Btm MB) (ftKB) (RKB) Zone Date Oh- Type Comment 4,242 a 7,318.0 7,330.0 6,353.7 6,364.2 C-4, 1G -10A 4/19/1999 6.0 IPERF 2.5" HC, 31 JUJ alternating w/35 BUP, 60 deg phasing GAS LIFT _ . 7,330.0 7,340.0 6,364.2 6,373.0 C-4, 1G-10A 12/13/1998 6.0 IPERF 2.5" Hollow Carried, 60 deg phasing 4,756:',': H 7,352.0 7,358.0 6,383.5 6,388.7 C-4, 1G-10A 4/19/1999 6.0 IPERF 2.5" HC, 31 JUJ alternating w/35 ' p BUP, 60 deg phasing 7,366.0 7,374.0 6,395.7 6,402.7 C -3, 1G-10A 4/19/1999 6.0 IPERF 2.5" HC, 31 JUJ alternating w/35 ., BUP, 60 deg phasing GAS LIFT, 6,095 _ 7,614.0 7,64 6,612.8 6,639.2 A -5, A-4, 1G-10A 10/12/1996 4.0 IPERF 2.5" Hollow Carrier IF Notes: General & Safety a r End Date Annotation 9/28/1996 NOTE: WELL SIDETRACKED 8 WORKOVER NIPPLE, 6,141 9/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 LOCATOR, 6.148 SEALS.6.150 s `\ / PRODUCTION Post - Sidetrack, 35 -6,290 IPERF, 7,318 -7,330 IPERF, 7,330 -7,340 IPERF, 7,352-7,358 IER 1111 • IPERF, • 7,386 -7,374 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,396.3 2,224.3 33.97 McMu... FMHO 1 GAS LIFT GLV BK 0.156 1,380.0 8/3/2011 IPERF, ® 2 3,664.8 3,219.7 41.27 McMu... FMHO 1 GAS LIFT GLV BK 0.156 1,357.0 8/3/2011 7,614 -7,644 3 4,242.3 3,694.1 37.58 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/28/1996 4 4,755.6 4,115.4 35.10 McMu... FMHO 1 GAS LIFT GLV BK 0.188 1,375.0 8/3/2011 5 6,095.0 5,263.5 24.87 CAMCO MMM 1 1/2 GAS LIFT OV RK 0.250 0.0 8/3/2011 Q LINER. 6,142 -7,906 TD (10-10A), � 7,906 1G-10A Proposed CTD Sidetrack 3 -1/2" Camco DS nipple @ 523' RKB 16" 62# H-40 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface shoe @ 116' RKB Camco FMHO gas lift mandrels @ 2396', 3665', 4242'. 4756' 10 -3/4" 45.5# J -55 3 -1/2" Camco MMM as lift mandrel @ 6095' RKB shoe @ 2350' MD 3 -1/2" Camco DS landing nipple @ 6141' RKB (2.812" min ID) Baker 3 -1/2" GBH -22 seal assembly @ 6150' RKB (3" ID) L_iner�to Baker ZXP liner top packer (5 6149' RKB 7" 26# K -55 shoe i ` Baker HMC liner hanger @ 6"156' RKB @ 6290' MD — Baker 80 -40 SBE (12 length with 4" ID seal bore) I Z {o 'tee Proposed Cement Plug at 7510' 7-3tp C -sand perfs (sqz'd) = "�- 7,318' 7.374' MD /KOP from 3 -1/2" f / monobore whipstock @ 7482' MD 1G -10BL2 (A4 sourthwest) TD @ 10,100' MD I -, 1G-10B (A4 Northwest) A -sand perfs (sqz'd) TD @ 10,400' MD 7,614' - 7,644' MD �- • 3 -1/2" 9.2# L -80 — — —} shoe @ 7,906' MD _— - 1G -10BL1 (A3 Northwest) TD @ 10,400' MD • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10 :52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS / 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art f or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F:\ Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 ,, ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~v~#~~~~ S~~ ~ ~ 2~~8 Field: Beluga River Unit Well Job # ... Log Description l~a~,~~; ~:il ~~+ ,,~ ;w ;; NO 4852 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD os/2s/os 2W-11 12100437 PROD PROFILE ~ - 08/06/08 1 1 1 F-14 12096521 PROD PROFILE - ~ 08!08/08 1 1 1 Y-05 12096520 LDL J (p ~ ^ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY "~-- a 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~ 08/11/08 1 1 1 G-10A 12097418 PROD PROFILE 08/12/08 1 1 1 L-14 10228963 INJ PROFILE ~ - - (~ 08/12/08 1 1 30-17 11966273 SBHP SURVEY i - 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 __. C7 Schlumberger NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 10/07/05 5ÇANNEl) NO\! 0 2: 2005 Company: Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 ~ 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V -08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02/05 1 1E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: Z,} rJ/jJ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk ,-," Color CD / 7 (\)~Àh r- ¿ ~- t~'b , rp,1~~~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4893' FNL, 4490' FEL, Sec. 29, T12N, R10E, UM At top of productive interval 4139' FNL, 1324' FEL, Sec. 29, T12N, R10E, UM At effective depth At total depth 4263' FNL, 1043' FEL, Sec. 29, T12N, R10E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 540569, 5981035) (asp's 543727, 5981810) (asp's 544010, 5981685) 6. Datum elevation (DF or KB feet) RKB 94 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1G-10A 9. Permit number / approval number 196-140 10. APl number 50-029-21003-01 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 116' SURF CASING 2256' PROD CASING 6192' LINER 1763' 7906 feet Plugs (measured) 6864 feet 7815 feet Junk (measured) 6784 feet Size Cemented 16" 212 SxCS II 10-3/4" 930 SxAS III & 250 AS I 7" 850 Sx G & 250 Sx AS I 3-1/2" 396 Sx G Tagged Fill (11/30/99) @ 7815' MD. Measured Depth 116' 2350' 6286' 79O6' True verticalDepth 116' 2177' 5433' 6864' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7318 - 7340'; 7352 - 7358'; 7366 - 7374'; 7614 - 7644' 6349 - 6368'; 6379 - 6384'; 6391 - 6398'; 6608 - 6634' 3-1/2", 9.3#, J-55 Tbg @ 6151' MD. No Packer. CAMCO 'DS' LANDING @ 523' MD. RECEIVED C F,_B 13 2001 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anchorage 14. OiI-Bbl Prior to well operation 362 Subsequent to operation 850 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 97 12 363 122 Casing Pressure Tubing Pressure - 176 183 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Title: / Date 'Z ",) Prepared by Jot~n Peirce 265-6471 SUBMIT IN DUPLICATE 1G-10A DESCRIPTION OF WORK COMPLETED ROPE STIM STICK & HYDRAULIC FRACTURE TREATMENTS 10/24/99: MIRU & PT equipment. RIH & shot ROPE Stim Stick #1 at 7368- 7372' MD. POOH. RD. 10/25/99: MIRU & PT equipment. RIH & shot ROPE Stim Stick #2 at 7353- 7357' MD. POOH. RIH & shot ROPE Stim Stick #3 at 7324.5- 7333.5' MD. POOH. RD. 11124/99: MIRU & PT equipment. Pumped gelled sand slurry containing 1200 lbs of 20/40 mesh sand, to spot an isolation sand plug across the lowest perforation interval located at: 7614 - 7644' MD 11/25/99: RIH & tagged sand plug top at 7487' MD. 11/28/99: MIRU & PT equipment to 9500 psi. Pumped 'C' Sand Hydraulic Fracture Treatment using 20/40, & 16/20 mesh proppant, through the perforation intervals located above the sand plug at: 7318 - 7340' MD 7352 - 7358' MD 7366 - 7374' MD Pumped Breakdown: a) 50 bbls Linear Gel @ 25 bpm, followed by b) 110 bbls Linear Gel @ 28 bpm through 7.1 bpm stepped down rates, followed by c) Shutdown. ISIP @ 1904. Resumed pumping Data Frac: d) 100 bbls 50# Delayed Crosslinked Gel @ 20 bpm, followed by e) 66 bbls 20# Linear Gel Flush @ 20 bpm, followed by f) Shutdown. ISIP @ 2074. Resumed pumping Frac Treatment: g) 70 bbls Crosslinked Pad @ 20 bpm, followed by h) Slurry stages, w/proppant concentrations ramped up in stages from 2 to 10 ppg, followed by i) 20 bbls Gel & 40 bbls Diesel Flush @ 20 bpm, followed by j) Shutdown. Placed a total of 38,516 lbs of proppant into the formation. Rigged down. 11129199: Performed a CT proppant & isolation sand plug fill cleanout to 7798' MD. 11130199: RIH & tagged fill at 7815' MD. Returned the well to production w/gas lift and obtained a valid well test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X 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 X. 32' RKE 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: 386' FSL, 793' FWL, Sec 29, T12N, R10E, UM 1G-10A At top of productive interval: 9. Permit number/approval number: 1132' FSU 1306' FEL, Sec 29, T12N, R10E, UM 96-0140 At effective depth: 10. APl number: 1023' FSU 1106' FEL, Sec 29, T12N, R10E, UM 50-029-21003-01 At total depth: 11. Field/Pool: 1015' FSU 1044' FEL, Sec 29, T12N, R10E, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 7906 feet Plugs (measured) true vertical 6864 feet Effective Deptl measured 7815 feet Junk (measured) true vertical 6784 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 16" 212 Sx CS II 116' 121' Surface 2168' 10-3/4" 930 Sx AS 111 & 2350' 2176' 250 Sx AS I Production 6254' 7" 850 Sx Class G& 6286' 5433' 250 Sx AS I Liner 1763' 3.5" 396 Sx Class G 6143'-7906 5302'-6864 Perforation Depth measured 7330' TO 7340', 7614'-764~ true vertical 6359'-6368', 6608'-663z ........ · ~ ;!.. ~,~' , Tubing (size, grade, and measured depth) 3-1/2% 9.3#, L-e0, @ 6151' ME: Packers and SSSV (type and measured depth) Baker 80-40 Packer @ 6150' MD; NO SSSV 13. Stimulation or cement squeeze summary PERFORATED C34 SAND FROM 7318'-7330' & 7352'-7358' & 7366'-7374' Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 337 88 8 1113 189 Subsequent to operation 336 115 7 970 188 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil ~X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. !Signed ~~,~~C~' /'~,.~ Title: ~,~ T.~ Date ~/~//~ SUBMIT IN DUPLICATE~ Form 10-404 Rev 06/15/88 ,CO Alaska, Inc. -:- KUPARUK RIVER UNIT · ~ELL SERVICE REPORT 1G-10A(4-1)) WELL JOB SCOPE JOB NUMBER 1G-10A PERFORATIONS-E-LINE 0401991249.1 UNIT NUMBER 8345 DATE 04/19/99 DAY 1 FIELD ESTIMATE DAILY WORK PERF 26'W 2 1/2" HC OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ~ Yes ¢'~ No ~_~ Yes ¢'~ No SWS-STEPHENSON AFC# ICC# I DAILY COST ACCUM COST AK0034 23SG EN41N $14,060 $15,920 InitiaITbg IFinalTbg I lnitiallAI FinallA I lnitialOA IFinalOA ITTLSiz~ 150PSll 1450PSll 100PSll 1400PS~I 0PS~I 0PSll 0.000" SUPERVISOR KOLSTAD Signed IMin ID 2.750" Depth 6141 FT DALLY SUMMARY I PERF 7318''7330' & 7352'-7358' & 7366''7374' W/2 1/2'' Hc 31 JUJ ALTERNATING WITH 35 BUP (DEEP I PENETRATING ALTERNATING WITH BIG HOLE CHARGES)/60 DEG- TAGGED [Per[] TIME LOG ENTRY 07:45 RU SWS - SI WELL - WHP=700 09:00 PU 12' GUN AND RIH 10:00 TAG FILL AT 7636' ELM CORRECTED TO RKB- TIE IN TO MWD LOG DATED 9/6/96 10:30 PERF 7318'-7330' W/ 2 1/2" HC 31 JUJ ALTERNATING WITH 35 BUP (DEEP PENETRATING ALTERNATING WITH BIG HOLE CHARGES) / 60 DEG - SLIGHT TENSION DROP - NO CHANGE IN WHP - POOH 11:15 OOH - ALL SHOTS FIRED 11:20 PU 8' GUN - RIH 12:10 TIE IN 12:20 PERF 7366'-7374' W/2 1/2" HC 31 JUJ ALTERNATING WITH 35 BUP (DEEP PENETRATING ALTERNATING WITH BIG HOLE CHARGES) / 60 DEG - TENSION DROP - NO CHANGE IN WHP - POOH 12:55 OOH - ALL SHOTS FIRED 13:10 PU 6' GUN- RIH 13:40 TIE IN 13:50 PERF 7352'-7358' W/2 1/2" HC 31 JUJ ALTERNATING WITH 35 BUP (DEEP PENETRATING ALTERNATING WITH BIG HOLE CHARGES) / 60 DEG - TENSION DROP - WHP=1500 PSI - NO CHANGE - POOH 14:40 OOH - ALL SHOTS FIRED 15:15 RDMO SWS SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $84.00 APO $500.00 $500.00 HALLIBURTON $0.00 $1,116.00 LITTLE RED $0.00 $660.00 SCHLUMBERGER $13,560.75 $13,560.75 TOTAL FIELD ESTIMATE $14,060.75 $15,920.75 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate Plugging _ Perforate _X Pull tubing Alter casing _ Repair well _ Other _ i2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, inc. Development X. 32' RKE 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: 386' FSL, 793' FWL, Sec 29, T12N, R10E, UM 1G-10A At top of productive interval: 9. Permit number/approval number: 1132' FSU 1306' FEL, Sec 29, T12N, R10E, UM 96-0140 At effective depth: 10. APl number: 1023' FSL, 1106' FEL, Sec 29, T12N, R10E, UM 50-029-21003-01 At total depth: 11. Field/Pool: 1015' FSL, 1044' FEL, Sec 29, T12N, R10E, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 7906 feet Plugs (measured) true vertical 6864 feet Effective Deptt measured 7815 feet Junk (measured) true vertical 6784 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 16" 212 Sx CS II 116' 121' Surface 2168' 10-3/4" 930 Sx AS III & 2350' 2176' 250 Sx AS I Production 6254' 7" 850 Sx Class G& 6286' 5433' 250 Sx AS I Liner 1763' 3.5" 396 Sx Class G 6143'-7906 5302'-6864 Perforation Depth measured 7614'-7644 true vertical 6608'-6634 . Tubing (size, grade, and measured depth) 3-1/2", 9,3#, L-80, @ 6151' ME: ~' ,i.L~ ~t ~. -:~., .~ Packers and SSSV (type and measured depth) _ ,L- '!',~' ~ '; .. E;::.. ~ ".~-'~ Baker 80-40 Packer @ 6150' MD; NO SSSV ......... · .4. 13. Stimulation or cement squeeze summary PERFORATED C34 SAND FROM 7330' TO 7340' Intervals treated (measured) j\ Treatment description including volumes used and final pressure 0i IGIN L 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 243 106 8 1184 187 Subsequent to operation 337 88 8 1113 189 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil _ZX Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~(~ ~ Title: ~z/~ "7-~ Date ~/C~'/~'? Form 10-404 Rev 06/15/88 SUBMIT iN DUPLICATE ,CO Alaska, Inc. ' ' KUPARUK RIVER UNIT vCELL SERVICE REPORT 1G-10A(4-1)) WELL JOB SCOPE JOB NUMBER 1G-10A PERFORATE, PERF SUPPORT 1209980913.2 DATE 12/13/98 DAY 1 FIELD ESTIMATE DALLY WORK PERFORATE C34'SAND OPERATION COMPLETE ISUCCESSFUL~ Yes O No ~ Yes O No IKEYPERSON AFC# ICC# I DALLY COST ACCUM COST KAWWR K 230DSl 0GL $11,345 $13,266 I OA [FinalOA ITTLSize Initial Tbg I FinalTbg I Initial IA Final IA I Initial 1150 PSII 1500 PSII 1400 PSI 1400 PSII 0 PSI 0 PSII 0.000 " UNIT NUMBER 2128 SUPERVISOR LIGENZA Signed IMin ID I Depth 0.000" 0 FT DAILY SUMMARY PERFORATED C34 SAND FROM 7330' TO 7340'. 10' X 2-1/2" HC, DP, 6 SPF, 60 DEG PHASE. [Peri'] TIME LOG ENTRY 07:30 MIRU SWS. TGSM. 09:30 PT LUBE/BOPS TO 3000 PSI. REPLACE O-RING. PRESSURE TEST OKAY. 10:30 RIH W/10' X 2-1/2' HC, DP, 6 SPF. 60 DEGREE PHASE. CCL. 9.5' FROM TOP SHOT TO CCL. 11:10 TIE IN TO SHORT JOINTS AT 7600'. REFERENCE MWD LOG DATED 9/6/96 AND PERF LOG DATED 11/10/96. LOG UP FROM 7636' TO 7300'. 11:50 LOCATE AT 7320.5' TO PUT TOP SHOT AT 7330'. INDICATION SHOTS FIRED. LOG UP. POH. 12:50 ON SURFACE, ALL SHOTS FIRED. RDMO SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $252.00 HALLIBURTON $0.00 $669.00 LITTLE RED $0.00 $1,000.00 SCHLUMBERGER $11,345.50 $11,345.50 TOTAL FIELD ESTIMATE $11,345.50 $13,266.50 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 09/15/98 RUN RECVD 96-140 MWD SRV~ 96-140 MWD SRVY ~RRY 6295-7760 ~-c~5.17-79o6 12/17/96 01/31/97 96-140 DGR/RES-MD 96-140 DGR/RES-TVD 96-140 7922 96-140 MWD SRV~f ~6295-7906 ~L~-5~441-6863 /PERRY GR/RES ~SPERRY 6295-7906 FIN2LL 02/12/97 FINAL 02/12/97 03/12/97 04/09/97 10-407 yCOMPLETION DATE {%/ DAILY WELL OPS /' ~1~1 TO Are dry ditch samples required? yes ~A_nd received? Was the well cored? yes ~~nalysis & description received? Are well tests required? yes ~ Received? Well is in compliance Ini~tial COMMENTS ARCO Alaska, Inc. Post Office Box 1003u0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 8, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1G-10A (Permit No. 96-140) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 1G-10. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA - ALAErxA OIL AND GAS CONSERVATION ,.,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. status of Well ' (~iassification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-140 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-21003-01 4-~-I~ati~n ~fweii at ~-~.~ ..................... .,[~.ii]]~.~[_~i].~]ii - ~~, -91 unit-or E~-se Na~m-e 386, FSL, 793' FWL, Sec. 29, T12N, R10E, UM ~ ~-:.i~;.~,7;?...'!0~ i. .~i~Tl~t~ii , Kuparuk River Unit At top of productive nterva ~ ;?'-~'r~ ~i ~r ~ I IlO. Well Number 1132' FSL, 1306' FEL, Sec. 29, T12N, R10E, UM 'i .---/'-¢~-~/~'- ~ ~i..-~:~.~ ! 1G-10A At total depth , ! ~?~;~ ~ !" ~"i il. Field and Pool __ ! 0! 51FSL! ! 044 ___F'__E_L! Se_c_L29! _T?_2N! R!_°E~ UM ~!...i;~.-v: ~:-.::/~: ~ ~.. ,L ~;-~_~.;, Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Rig RKB 95', Pad Elev. 63'I ADL 25640, ALK 2571 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions ...... 9/1/96 i . . I ..... 9/6/96 I 10/12/96 N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey]20. Depth where SSSV set~21. Thickness of Permafrost 7906 6864 FT] 7815 6789 Fi-ri ~Yes I-1No ~ ........ N/A MD/ 1465' (Approx.) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING I ..... --S -E?D_I_-N--G _- -D-E-P- -T--H-- ...... HoLE SIZEI VVT. PER FT. GRADE ToP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 116' 24" 212sx CS II 10-3/4" 45.5# K-55 Surf. 2350' 13-1/2" 930 sx AS III & 250 sx ASI ....... -?~' ............. 26~0~ ................ ~:~;-5 Surf. 6286' 8-3/4" '~50 sx--Class ~--& 2~O--~X- AS| 3.5" 9.2# L-80 6142' 7906' 6-1/8" 396 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6151' 6150' MD TVD MD TVD ............................................................ 7614'-7644' 6612'-6638' 4 spf 26. ACID, FRACTURE, OEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ..... ~614'-~-~44' - 120,000# to 8.1 ppg, 12/18 proppant On perfs Left 19,000# in pipe. , , ,, 27. PRODUCTION TEST Date First Production iMethod of Operation (Flowing, gas lift, etc.) 10/30/96 i Gas Lift Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOK~ SIZE' ........ i-~;~--~i~'-F~,TTl-~ 4/3/97 i 17.9 TESTPERIOD · 255 368 9 176 ! 0 Fk)V~--~'-~-in-~i(~-~.~-ir~---P-~'eSsureiCALCULATED · OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 1711 1192 ~4-HouR RATE 31 7 513 12 23° i , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 07-01-80 ORIGINAL AP~--t r__ 9 1997 Submit In Duplicate Alaska 0il & Gas 00ns. Commission /~nnhnmOe 29. Geologic M; 30, Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 7313' 6345' Bottom Kuparuk C 7448' 6463' Top Kuparuk A 7607' 6602' Bottom Kuparuk A 7733' 6713' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Prepared By Name/Number: 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 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 Rev. 07-01-80 Date: 11/8/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL: 1G-10A RIG :NORDIC WELL ID: 998466 TYPE: AFC:--998466 AFC EST/UL: $ OM/ OM STATE: ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: 08/28/96 START COMP: 08/23/96 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21003-01 08/23/96 (C 1) TD: 0' PB: 0' SUPV:WSI DAILY:$ 08/24/96 (C 2) TD: 7970' PB: 7863' SUPV:DEB DAILY:$ 08/25/96 (C 3) TD: 7970' PB: 7863' SUPV:DEB DAILY:$ 08/26/96 (C 4) TD: 7970' PB: 7863' SUPV:DEB DAILY:$ 08/27/96 (C 5) TD: 7970' PB: 7863' SUPV: DEB DAILY: $ 08/28/96 (C TD: 7970' PB: 7863' SUPV:DEB 6) DAILY:$ 08/29/96 (C 7) TD: 7970 ' PB: 7863' SUPV: DEB DAILY: $ 08/30/96 (C 8) TD: 6500' PB: 6500' SUPV: DEB DAILY: $ MOVING RIG MW: 0.0 Move camp to 1G pad. Move rig over matting boards. 40,528 CUM:$ 81,056 ETD:$ MOVING RIG Continue to move rig. 0 EFC:$ MW: 0.0 81,056 27,500 CUM:$ 136,056 ETD:$ MOVING RIG Continue moving rig. 0 EFC:$ MW: 0.0 136,056 27,500 CUM:$ 191,056 ETD:$ 0 EFC:$ MOVING RIG MW: 0.0 Continue moving rig on matting boards to 2C pad. 191,056 27,500 CUM:$ 246,056 ETD:$ 0 EFC:$ 246,056 LOADING WELL WITH SEA WAT MW: 8.5 SW Move rig to 1G pad. Accept rig @ 2200 hrs. 8/26/96. Kill well with seawater. 35,883 CUM:$ 317,822 ETD:$ 0 EFC:$ 317,822 NU 13-5/8" BOPE MW:ll.1 LSND Load well with seawater. Shut-in and monitor well. Circulate mud to load tubing. Shut down and monitor well. Well dead. Set BPV. Freeze protect flowline with diesel. NU BOPE. 49,426 CUM:$ 416,674 ETD:$ 0 EFC:$ 416,674 POH LD 3.5" TUBING MW:ll.1 LSND NU 13-5/8" BOPE. Function test BOPE to 300/3000 psi. Pull 3.5" tubing. 34,137 CUM:$ 484,948 ETD:$ 0 EFC:$ 484,948 INJECTING CEMENT THRU RET MW: 0.0 Continue to POH and LD 3.5" tubing and jewelry. Set retainer @ 6500'MD. Pump cement below retainer. 54,414 CUM:$ 593,776 ETD:$ 0 EFC:$ 593,776 RECEIVED Alaska Oil & ~as?ns. r3ommission Date: 11/8/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/31/96 (C TD: 6500' PB: 6500' SUPV:DEB 9) DAILY:$ 09/01/96 (C 10) TD: 6500' PB: 6500' SUPV:DEB DAILY:$ 09/02/96 (C 11) TD: 6286' PB: 6000' SUPV:DEB DAILY:$ 09/03/96 (D 12) TD: 6286'( 0) SUPV:DEB DAILY:$ 09/04/96 (D 13) TD: 6988'(702) SUPV:DLW DAILY: $ 09/05/96 (D 14) TD: 7595'{ 607) SUPV: DLW DAILY: $ 09/06/96 (D 15) TD: 7906' (311) SUPV: DLW DAILY: $ 09/07/96 (D 16) TD: 6286' ( 0) SUPV: DEB DAILY: $ 09/08/96 (D 17) TD: 7906' (1620) SUPV: D LW DAILY: $ RIH WITH SECTION MILL MW: 8.9 UNKN Spot 18 ppg pill as a balanced slug on top of retainer @ 6500' MD. Install new tubing head. Test packoff to 3000 psi, OK. Set test plug. NU BOPE. Function test BOPE to 250/3500 psi. RIH with 3.5" DP. 44,322 CUM:$ 682,420 ETD:$ 0 EFC:$ 682,420 SECTION MILLLING 7" @ 631 MW: 9.6 UNKN RIH with milling BHA #1 on DP. Mill section in 7" casing, make initial cut-out @ 6286' MD. Mill section out of 7" casing from 6386' to 6319' 39,942 CUM:$ 762,304 ETD:$ 0 EFC:$ 762,304 HOLD SQUEEZE ON KICK-OFF MW: 9.6 UNKN Mill section in 7" casing from 6319' to 6336'. Rotate & work pipe in section while circulating hole clean. Pump slug. RIH with open ended DP. Wash last 4 joints down & work muleshoe into 7" at bottom of section. RIH to 6424' No fill. Recovered 40# more metal. Pump cement. Squeeze cement. 54,991CUM:$ 872,286 ETD:$ 0 EFC:$ 872,286 MW: 9.6 VISC: 50 PV/YP: 18/39 APIWL: 6.0 DRILLING CEMENT @ 6279' MD Estimated TOC @ +/-6000' MD. Pump slug. RIH with BHA #1. Tag cement @ 6018'. Drill cement from 6018' to 6279' 147,978 CUM:$ 584,121 ETD:$ 0 EFC:$ 584,121 MW: 10.5 VISC: 43 PV/YP: 18/23 APIWL: 5.5 DRILL A_ND SLIDE Continue to clean out cement from 6279' to 6291'. Continue to slide make 10' new hole to 6346'. Pull up to 7" shoe @ 6336'. Perform FIT to 13.5 ppg EMW. Continue drilling 6.125" hole by sliding for right hand turn from 6346' to 6560'. Drill and slide for correction from 6560' to 6988' 63,624 CUM:$ 647,745 ETD:$ 0 EFC:$ 647,745 MW: 11.0 VISC: 48 PV/YP: 26/19 APIWL: 4.6 DRLG AHEAD W/6.125" HOLE Continue to directional drill 6.125" hole from 6988' to 7595' -- 66,902 CUM:$ 714,647 ETD:$ 0 EFC:$ 714,647 MW: 11.0 VISC: 52 PV/YP: 30/24 APIWL: 4.5 POOH TO RUN 3.5" LINER Continue directional drilling 6.125" hole from 7595' to 7906' TD. 69,353 CUM:$ 784,000 ETD:$ 0 EFC:$ 784,000 MW: 11.0 VISC: 52 PV/YP: 30/24 APIWL: 4.5 R/U TO L/D 3.5" DP Continue to POOH 3.5" DP. Run 3.5" liner to 7906'. Pump cement. CIP @ 0420 hrs. 9/7/96. 63,271 CUM:$ 847,271 ETD:$ 0 EFC:$ 847,271 MW: 11.0 VISC: 52 PV/YP: 30/24 APIWL: 4.5 RUNNING 3.5" TUBING Continue to POOH L/D 3.5" DP to 2000'. Test casing to 3500 psi. Running 3.5" tubing. 31,500 CUM:$ 878,771 ETD:$ 0 EFC:$ 878,771 Date: 11/8/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 09/09/96 (C 18) TD: 7906' PB: 7815 ' SUPV: DLW DAILY: $ RIG RELEASED MW: 8.3 FW Continue to run 3.5" tubing and jewelry. Test casing to 3500 psi for 30 min., OK. Freeze protect well. RD and move off well. Release rig @ 0300 hrs. 9/9/96. 145,910 CUM:$ 1,606,734 ETD:$ 0 EFC:$ 1,606,734 End of WellSummary for Well: 998466 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A KI(1G-10A(W4-6)) WEI I J JOB SCOPE 1G-10A PERFORATE, PERF SUPPORT DATE 1~1~96 DAY 6 DAILY SUM DAILY WORK PERFORATE "A" SAND INTERVAL F/7614 - 7644 FT OPERATION COMPLETE I SUCCESSFUL YES YES Initial Tbg Press I Final Tbg Press ] Initial Inner Ann 0 PSII 1200 PSII 0 PSI .VIARY JOB NUMBER 1001961512.1 UNIT NUMBER KEY PERSON SUPERVISOR SWS-BAILEY BLACK Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI PERFORATED "A" SAND INTERVAL F/7614 - 7644 FI' ( 4 JSPF TOTAL ) TIME LOG ENTRY 02:15 RU SWS ELINE. HOLD SAFETY MTG W/SWS & APC. MU 20' X 2.5" BIG HOLE GUN ASSEMBLY. PT BOPE TO 3500 PSI. 04:00 RIH W/20' X 2.5" ASSEMBLY. TIE INTO MWD LOG. SHOOT 2 JSPF F/7644 - 7624 FI' ELM. NO PRESSURE INCREASE. 05:30 POOH W/20' X 2.5" ASSEMBLY. ALL SHOTS FIRED. MU 10' X 2.5" GUN ASSEMBLY #2. 06:30 07:30 RIH W/GUN ASSEMBLY #2. TIE INTO MWD LOG. SHOOT 2 JSPF F/7624-7614 FT ELM. TOTAL SHOTS FIRED F/BOTH RUNS ( 4 JSPF ). POOH W/ASSEMBLY #2. ALL SHOTS FIRED. RD SWS & APC. 09: 00 OFF LOCATION. ~.~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. Kuparuk River Unit / 1G-10A 500292100301 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/29/97 DATE OF SURVEY: 090596 MWD SURVEY JOB NUMBER: AK-MM-60121 KELLY BUSHING ELEV. = 94.17 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 6295.17 5441.08 5346.91 23 17 N 73.88 E .00 865.14N 2758.63E 6390.00 5528.52 5434.35 22 51 S 81.83 E 9.99 867.74N 2794.96E 6484.00 5613.30 5519.13 28 34 S 64.20 E 10.11 855.33N 2833.35E 6578.00 5695.72 5601.55 28 54 S 63.90 E .38 835.55N 2874.00E 6670.00 5776.31 5682.14 28 45 S 65.80 E 1.01 816.69N 2914.15E VERT. SECT. 2198.68 2231.08 2271.26 2316.41 2360.74 6763.00 5858.07 5763.90 28 10 S 64.60 E .88 798.11N 2954.38E 6858.00 5941.91 5847.74 27 57 S 65.35 E .44 779.21N 2994.87E 6952.00 6025.17 5931.00 27 20 S 65.99 E .72 761.23N 3034.61E 7045.00 6107.90 6013.73 27 2 S 66.14 E .33 743.99N 3073.45E 7140.00 6192.16 6097.99 27 58 S 61.41 E 2.50 724.60N 3112.76E 2405.04 2449.70 2493.30 2535.79 2579.56 7232.00 6273.31 6179.15 28 13 S 64.26 E 1.48 704.83N 3151.30E 7327.00 6356.83 6262.66 28 42 S 64.30 E .52 685.18N 3192.09E 7422.00 6439.88 6345.71 29 23 S 63.50 E .82 664.88N 3233.52E 7516.00 6522.10 6427.94 28 34 S 66.37 E 1.72 645.58N 3274.75E 7612.00 6606.35 6512.18 28 43 S 68.98 E 1.31 628.10N 3317.32E 2622.76 2667.99 2714.05 2759.55 2805.57 7705.00 6687.84 6593.67 28 52 S 66.58 E 1.25 611.16N 3358.79E 7831.00 6798.07 6703.90 29 4 S 66.10 E .24 586.66N 3414.71E 7906.00 6863.61 6769.44 29 4 S 66.10 E .00 571.89N 3448.03E 2850.36 2911.41 2947.85 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3495.14 FEET AT NORTH 80 DEG. 34 MIN. EAST AT MD = 7906 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 113.08 DEG. TIE-IN POINT AT 6,295.17' MD WINDOW POINT AT 6,291.00' MD PROJECTED ·SURVEY AT 7,906.00' MD RECEIVED /~,Io. ska Oil & 8~s O~m~;. t;ommissioi~ SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. Kuparuk River Unit / 1G-10A 500292100301 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/29/97 DATE OF SURVEY: 090596 JOB NUMBER: AK-MM-60121 KELLY BUSHING ELEV. = 94.17 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6295.17 5441.08 5346.91 7295.17 6328.91 6234.74 7906.00 6863.61 6769.44 865.14 N 2758.63 E 854.09 691.81 N 3178.32 E 966.26 112.17 571.89 N 3448.03 E 1042.39 76.13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~_.RY-SL/N DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. Kuparuk River Unit / 1G-10A 500292100301 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/29/97 DATE OF SURVEY: 090596 JOB NUMBER: AK-MM-60121 KELLY BUSHING ELEV. = 94.17 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6295.17 5441.08 5346.91 865.14 N 2758.63 E 854.09 6352.77 5494.17 5400.00 868.55 N 2780.65 E 858.60 4.51 6462.40 5594.17 5500.00 859.38 N 2824.17 E 868.23 9.62 6576.23 5694.17 5600.00 835.92 N 2873.23 E 882.06 13.84 6690.37 5794.17 5700.00 812.68 N 2923.09 E 896.20 14.13 6803.94 5894.17 5800.00 789.83 N 2971.84 E 909.77 13.58 6917.10 5994.17 5900.00 767.76 N 3019.97 E 922.93 13.15 7029.59 6094.17 6000.00 746.83 N 3067.05 E 935.42 12.49 7142.28 6194.17 6100.00 724.09 N 3113.70 E 948.11 12.69 7255.67 6294.17 6200.00 699.97 N 3161.38 E 961.50 13.39 7369.58 6394.17 6300.00 676.30 N 3210.53 E 975.41 13.91 7484.19 6494.17 6400.00 651.68 N 3260.81 E 990.02 14.61 7598.11 6594.17 6500.00 630.50 N 3311.08 E 1003.94 13.92 7712.22 6694.17 6600.00 609.77 N 3361.99 E 1018.05 14.12 7826.54 6794.17 6700.00 587.54 N 3412.72 E 1032.37 14.32 7906.00 6863.61 6769.44 571.89 N 3448.03 E 1042.39 10.02 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS O I~! I I_1_i ~ G S ~:= I:! L/I r' E S WELL LOG TRANSMITTAL To: State of Alaska March 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 300 1 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 1G-10A, AK-MM-60121 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21003-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company CJ F! I I_1-- I IM 13 S ~i I~! ~/I r' ~:: S WELL LOG TRANSMITTAL To: State of Alaska February 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 1 G- 10A, AK-MM-60121 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 1G-IOA: ~ -- {lq ~ 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21003-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21003-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri I::t I I_1_ I I~1 G S E FI~./I I-- E S December 13, 1996 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 1 G- 10A Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 1G-10A Tie in point at 6,295.17' and the last survey 7,760.16'. Please call me at 563-3256 if you have any questions or concerns. station located at Regards, William T. Allen Operations Support Engineer Attachments. F ECEIVED DEC 17 1996 Alaska Oil & Gas C~s. Commi~m~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SP5 ~RCO ALASKA INC. KUPARUK / 1G-10A 5oo2921oo3o1 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 .... IL 'I o '-SUN DRILLING SERVICES PAGE DATE OF SURVEY: 090596 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60125 KELLY BUSHING ELEV. = 94.17 FT. OPEP~ATOR: ARCO ALASKA INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6295.17 5441.08 5346.91 23 12 N 73.88 E .00 865.14N 2758.63E 2198.68 6350.54 5492.40 5398.23 21 17 S 85.39 E 14.51 867.36N 2779.17E 2216.70 6444.21 5578.41 5484.24 25 37 S 67.87 E 8.72 858.35N 2814.95E 2253.15 6536.19 5660.25 5566.08 28 44 S 59.48 E 5.36 839.61N 2852.46E 2295.00 6630.16 5742.67 5648.50 28 40 S 59.38 E .10 816.65N 2891.32E 2339.75 6722.00 5823.34 5729.17 28 26 S 59.83 E .34 794.44N 2929.19E 2383.30 6817.85 5907.79 5813.62 28 0 S 60.25 E .51 771.80N 2968.45E 2428.30 6912.34 5991.39 5897.22 27 34 S 60.47 E .47 750.02N 3006.74E 2472.05 7006.26 6074.84 5980.67 27 2 S 60.99 E .61 728.95N 3044.32E 2514.89 7098.57 6156.75 6062.58 27 51 S 59.62 E 1.11 707.86N 3081.28E 2557.16 7192.55 6239.83 6145.66 27 52 S 58.71 E .45 685.35N 3119.00E 2600.68 7286.78 6322.87 6228.70 28 32 S 58.37 E .73 662.11N 3156.99E 2644.74 7381.91 6406.30 6312.13 28 54 S 58.56 E .40 638.20N 3195.95E 2689.96 7476.63 6488.96 6394.79 29 33 S 59.26 E .78 614.32N 3235.56E 2735.76 7572.14 6572.54 6478.37 28 18 S 63.56 E 2.54 592.20N 3276.08E 2781.71 7664.89 6654.07 6559.90 28 39 S 62.61 E .62 572.18N 3315.52E 2825.83 7705.16 6689.40 6595.23 28 40 S 62.43 E .22 563.26N 3332.65E 2845.09 7760.16 6737.64 6643.47 28 46 S 61.64 E .72 550.87N 3355.99E 2871.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3400.91 FEET AT NORTH 80 DEG. 40 MIN. EAST AT MD = 7760 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 113.08 DEG. TIE-IN SURVEY AT 6,295.17' MD LAST SURVEY STATION AT 7,760.16' MD DEC 1 7 1996 Oil & Gas C ,s, SP5 SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE 2 ARCO ALASKA INC. KUPARUK / 1G-10A 500292100301 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 090596 JOB NUMBER: AK-EI-60125 KELLY BUSHING ELEV. = 94.17 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6295.17 7295.17 7760.16 5441.08 5346.91 6330.24 6236.07 6737.64 6643.47 865.14 N 2758.63 E 854.09 660.01 N 3160.40 E 964.93 110.84 550.87 N 3355.99 E 1022.52 57.60 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPI f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 3 ARCO ALASKA INC. KUPARUK / 1G-10A 500292100301 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/12/96 DATE OF SURVEY: 090596 JOB NUMBER: AK-EI-60125 KELLY BUSHING ELEV. = 94.17 FT. OPEP~ATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6295.17 5441.08 5346.91 865.14 N 2758.63 E 854.09 6352.44 5494.17 5400.00 867.25 N 2779.85 E 858.27 4.18 6461.74 5594.17 5500.00 855.31 N 2822.01 E 867.57 9.30 6574.88 5694.17 5600.00 830.16 N 2868.48 E 880.71 13.14 6688.83 5794.17 5700.00 802.38 N 2915.53 E 894.66 13.95 6802.42 5894.17 5800.00 775.40 N 2962.17 E 908.25 13.60 6915.48 5994.17 5900.00 749.30 N 3008.00 E 921.31 13.06 7027.97 6094.17 6000.00 724.16 N 3052.95 E 933.80 12.49 7140.90 6194.17 6100.00 697.84 N 3098.34 E 946.73 12.93 7254.11 6294.17 6200.00 670.29 N 3143.70 E 959.94 13.21 7368.05 6394.17 6300.00 641.69 N 3190.24 E 973.89 13.95 7482.62 6494.17 6400.00 612.81 N 3238.10 E 988.45 14.57 7596.70 6594.17 6500.00 587.01 N 3286.51 E 1002.53 14.08 7710.59 6694.17 6600.00 562.06 N 3334.96 E 1016.42 13.89 7760.16 6737.64 6643.47 550.87 N 3355.99 E 1022.52 6.10 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS CONSERVATION COMMISSION TONY KIVOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (gO7) 279-1433 FAX: (907) 276-7542 August 14, 1995 Mike Winfi-ee, Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 G- 10A ARCO Alaska, Inc. Permit No. 96-140 Sur. Loc. 386'FSL, 793'FWL, Sec. 29, T12N, K10E, UM Btmnhole Loc. 990'FSL, 1040'FEL, Sec. 29, T12N, R10E, UM Dear Mr. Win_free: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the David W. Jol~ston Xk ~ ~hyai~rnP~ ER OF~COMMISSION" dlf/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · ~TATE OF ALASKA ALASKA OIL AND ~¢,$ CONSERVATION OOMMIS$1ON PERMIT TO DRILL 20 AAO 25.005 la. Type of Work Drill Redrill X lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry E] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 95', Pad 63' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25640, ALK 2571 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 386' FSL, 793' FWL, Sec. 29, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1049' FSL, 1177' FEL, Sec. 29, T12N, R10E, UM 1G-10A #U-630610 At total depth 9. Approximate spud date Amount 990' FSL, 1040' FEL, Sec. 29, T12N, R10E, UM 8/1 7/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and TVD) property line 1G-09 7921' MD 1177' @ Tar~let feet 60' @ surface feet 2560 6891' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 6291' feet Maximum hole angle 27.6° Maximumsudace 2800 psig At total depth ('I-VD) 3500 psig 18. Casing program Settinc~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8' 3-1/2' 9.3# L-80 BTC 1785' 6136' 5436' 7921' 6891' 321 sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7970 feet Plugs (measured) AUG 0 6 1996 true vertical 6889 feet Effective depth: measured 7863 feet Junk (measured) Alaska 0tl & (3as Cons, 60rnrnJssi0r~ true vertica 6797 feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' I 6 ' 212 Sx AS II 116' I 16' Surface 2314' 10-3/4' 930 sx ASIII, 250 sx AS I 2350' 2175' Intermediate Production 7917' 7 ' 850 sx Class G, 250 sx ASI 7953' 6870' Liner Perforation depth: measured 7894'-7946', 7978'-8013' MD ORIGINAL true vertical 6357'-6397', 6405'-6441' TVD 20. Attachments Filing fee X Property plat [-1 BOPSketch X Diverter Sketch ~] Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21 .",~[ hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~~% ~~¢ Title Drill Site Develop. Supv. Date ~/~::~/~.~2) · ~ ¢ '~ '4 Commission Use Only ' Permit Number. I AI~ number ~ . _ , I Approval dale ('~ j~.__~ letter for ~i~'-t/'~/~' 150-0'2-?--- ~/OO~'--4~ [ I '~' ~/~ '"'"] (¢2]seec°ver . other requirements Conditions of approval Samples required [] Yes [] No Mud log required [] Yes '~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ,~ Yes ~ No Required working pressure for BOPE r"] 2M J~ 3M D 5M D 1OM E] 15M Other: Origlrlal David W. Johnston by order of Approved by Commissioner the commission Date Fnrm lf'1-4~1 RP.v 7-24-R.Cl ?-,llhmit n Irinlic. ntn REDRILL PLAN SUMMARY Well 1G-10A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 386' FSL, 793' FWL, SEC 29, T12N, R10E, UM 1049' FSL, 1177' FEL, SEC 29, T12N, R10E, UM 990' FSL, 1040' FEL, SEC 29, T12N, R10E, UM 7921' 6891' Nordic Rig 2 8-17-96 14 Drill Fluids Program- Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Section in 7" casing 9.5 >25 15-35 85-95 20-30 30-40 ._ 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.7 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-IO Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns RECEIVED AU6 0 6 1996 Alaska 011 & Gas Cons, Commi~10n Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/Tbg 3-1/2", 9.3#, L-80, BTC Tubing 3-1/2", 9.3#, L-80, EUE Length Top (MD/DVD) Btm (MD/TVD 1785' 6136,/5436' 7921 '/6891' 6101' 29'/29' 6130'/5431' Cement Calculations: Casino to be cemented: -- 3-1/2" in 6-1/8" open hole Volume = 321 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 47%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,800 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3500 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,800 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards- Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 1G-10A, will kick off out of the 7" casing +/-400' TVD below the K-10 and +/-50' below the K-5 interval. The casing around the kick-off window will be squeezed with cement pdor to drilling out, which should isolate the K-10 and K-5 from the sidetrack operations. Nevertheless, even If not isolated the K-10 and K- 5 intervals should be able to handle the expected mud weights to be used for this sidetrack. Off-set drilling data shows that several wells in the area of 1G-10 were drilled to TD with 12.0 - 12.5 ppg mud without any loses. The kick-off point in 1G-10A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 6291' MD / 5441' TVD 27.6° (in sidetrack portion) No Hazards Page 2 Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: G Fi/CC L Notes: All drill solids generated from the 1G-10A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 1G-10A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH and dummy off all GLMs, leave deepest GLM open. Leave circulation valves in all C Sand mandrels. 2. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down all tubing and jewelry. 5. PU DP and RIH with cement retainer. Set retainer at 6490' MD. Pump cement squeeze below retainer into C Sand perfs filling 7" casing to bottom C Sand perf / top of fill. Unsting from retainer and circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. POOH standing back DP. 6. RIH w/section mill. Cut a 50' section in the 7" casing from 6290' - 6340'. POOH w/mill. 7. RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. POOH. 8. RIH w/6-1/8" bit, mud motor, MWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short tdp to window in casing. POOH. 9. Run 3-1/2" liner to TD w/150' of overlap to top of milled section. 10. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 11. Pressure test casing and liner lap to 3500 psi for state test. 12. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 12 days Expected Case: 14.5 days Upper Limit: 20 days No problems milling section, drilling new hole, or running completion. Difficulties encountered milling section, or drilling new hole. WSI 8/1/96 Page 4 ARCO ALASKA, inc. Structure : Pad 1G Well : I OA Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA .....Poir~ ..... MD Ir~ O;r ~ N m'U'~ Ec~, V. $ e,c;; Deg/100 K~ 8~1.~ 23.20 73.~ ~¢1.08 8~I~ 27~.~ 2i88.7t 0.~ T~ 7~.~ ~.62 11~ ~ 662~ ~11~ 278E.~ 0.~ ~ ~ ~d ~21.2¢ 27.62 113.~ ~14.~ E~.~ 3~ 2843.~ 0.~ T.D. ~ ~d ~ H~d7921.2~ 27.62 113.~ ~91.~ ~.~ S 66.92 DEG E 2936'(T0 TD) East (feel) -> 344~84 2955.93. O.C~ 2600 2700 2800 2900 3000 31 O0 3200 3300 3400 3500 3600 3700 t I I I I I I~ II II II II I I I I I 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 - 6300 - 640O- 6500 - 6600 6700 6800 6900 7 Casing 2,3.17 KOP ~ 2,3.89 DLS: 7.00 d 26.4.0 ~ 16--Jul-96 EOC [ 1049' ESL, 1177' FELl I SEC. 29, T12N, RIOEJ TARGET - T/ UNIT A B/ SHALE WALL TD LOCATION: ] ggo' FSL, 1040' FEL SEC. 29, T12N, RIOE K- 1 MARKER T/ UNIT D T/ UNIT C T/ UNIT B AVERAGE ANGLE 27.62 DEG B/ KUP SNDS TD i i iI i i i ' I I I II I II I I I I I '1 2000 21 O0 2200 2300 2400 2500 2600 2700 2800 2900 3000 Vertical Section (feel) -> Azimuth 113.08 with reference 0.00 S. 0.00 E from slot #10A 11oo lOOO 900 I Z 0 800 --r- 70O --I- 6O0 5OO RECEIVED AU(; 0 6 1996 Alaska Oil & Gas Cons. Oommis~ Anchorage Created by jones ¥or: B Plot Referees is IOA Vernon ~1. J Co~d~ot~ ~e in feet reference spot T~e Ve~l ~ptha ore refer~ RKB (Nor~'c Il).I w _Z ~ ~ ~Z ~ W ~ ~ ~ W ~ ~ ~ w Ow ~ w~ ~W ~ .~ ~ ~w ~ w ~ ~ ~,, ~ ~ ~W ~Z ~WWU~w ~ . w~ ~w 0 ~ > ~ o~ ~ ~ ~ ~ ~- o~ ~< o~ z 0 ~ O~ ~ ~0~ ~w ~ O~ W - Z ~ ~ -- ~ ~ ~ w~ wZ ~z ~ - ~w ~W ~b ~W ~ ~ O~ ~o w~ ~ <> ~ ~ w ~ ~ w~<~o~ ~w~ ~ zO ww=~ ~ ~W OZ~ ~ ~ o~ ~ w ~wO~o ~ ~_~m~ ~._w~ ~u ~ _ ~ ~0 ~ m~ ~00~ ~ ww~~ ~qoOz~ ~> ~< ~ ~ ~w m ~~z ~~W~z ~1-~ 0 zo w~ --O>z ~ ~w~ ~..< ~. v~ < ~Z,~U ~m _m ~w ~ ~ O~wZO~ ~m~zmmm ~-~'z-m~m zo w o~z~ ~~ ~/ ~ w~ ~2~ z~O .~-- >~ ~ ~O~w ~~z~o~ o~ozo o ~.~,~z~O~ ~< --~o ~o~=~ ~z>~ ~,, ~ -~o ~o -~¢ · ~o~wo _~~-w<Z~w~d~;~<~<~ z . ~~..~,~ ~w~<O N~O~t m~m Z~Z~~ o~w~,,,w ~O~w~ ~ w~>~_~ ~z~z~oz~ o~<~om<~ ~ww~O~ww~ L~ ~,,,~Zww ~ow~WWD z~zm~z mm~oo° 888 00~~ NORDIC RIG LEVEL 1 ~ 12' ,4' - 12'-47 28'-6"' 7Y-O" 25'-0' ~'I1RES: 40--57 '' 11 STAIRS _ EMSCO F-goo ; (~1 TRIPLEX MUD , PUMP .. F~4OVABL~ EMSCO F-800 TRIPLEX MUD PUMP SPIRAL , i i' STAIRS CONTROL [CONSOLE 8'-6"- 8'-0' ~ -- 5'-6' NORDIC RIG LEVEL NORDIC RIO LEVEL SPOOL US'TER AIR HEATER WAT'E~ TANK /¢L.¥OOL TANK 15'-6"' 84'.-0" -. STATE OF ALASKA I ~ OILAND GAS CONSERVATION COMM, ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown Re-enter suspended well Plugging X Time extension Stimulate Pull tubing_ Variance_ Perforate _ Other Plugback for × Reddll 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _,~ Exploratory _ Stratigraphic _ Service 4. Location of well at sur/ace 386' FSL, 793' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1347' FSL, 1306' FEL, Sec 29, T12N, R10E, UM At effective depth 1400' FSL, 1000' FEL, Sec. 29, T12N, R10E, UM -_ At total depth 1444' FSL, 923' FEL, Sec. 29, T12N, R10E, UM 6. Datum elevation (DF or KB) RKB 99'. Pad Eley, 60' 7. Unit or Property name Kuparuk River Unit 8. Well number 1G.-10. 9. Permit number ~3-126 10. APl number 5.0-029- 21003 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 7970' 6889' 7863' 6797' feet feet t~eet feet Plugs (measured)DUPLICATE Junk (measured) Blanking plug w/ additional tools on top 7509'-7531' Casing Length Structural Conductor 8 0' Surface 2 314' Intermediate Production 7917' Uner Perforation depth: measured 7894'-7946', true vertical 6357'-6397', Size 16' 10-3/4" 7' 7978'-8013' 6405'-6441' Cemented Measured depth True vertical depth 212 Sx CS II 1 16' 1 16' 930 sx AS III & 2350' 2175' 250 sx AS i 850 sx Class G 7953' 6870' 250 sx AS I Tubing (size, grade, and measured depth) 3-1/2', J-55, @ 7540' MD Packers and SSSV (type and measured depth) Otis 'WD' @ 7513'~ Otis 'RRH' @ 7156', Camco 'TRDP-1A' SSSV @ 1984' Attachments Contact William Isaacson at 263-4622 with an)/questions. 14. Estimated date for commencing operation Auqust 15, 1996 16. If proposal was verbally approved Detailed operation program__ Description summary of proposal I15. Status of well classification as: Oil .. ;X; Gas _ Service Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ~. ~""~,*-,.,.~,~.---..- Title Drillim Enoineer FOR COMMISSION USE ONLY BOP sketch Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test t Location clearance Subsequent form require Mechanical Integrity Test _ Approved by the order of the Commission ~-'~ ~(~Q~ Form 10-403 Rev 06/15/88 10- Commissioner IApprovai No. ~ I SUBMIT IN TRIPLICATE · WELL PERMIT CHECKLIST WELL NAME FIELD&POOL ~?~)~ INITCLASS ~(~/J' ./--z~:,'/ GEOLAREA (~::),~C") PROGRAM: exp 0 de'~red'~serv [] wellbore seg [] ann. disposal para req [] UNIT# ' ///~ ON/OFF SHORE~,,)~ ~DMiNiSTRATiON ................ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................. 4. Well located in a defined pool ................. 5. Well located proper distance from drlg unit boundary ..... 6. Well located proper distance from other wells ......... I.~ 7. Sufficient acreage available in drilling unit. .......... 8. If deviated, is wellbere plat included .............. ~.* 9. Operator only affected party .................. 10. Operator has appropriate bend in force .......... , . ~.~ 11. Permit can be issued without conservation order ...... ~P~ ~,/~,~ 12. Permit can be issued without administrative approval .... x . ~ ..- 13. Can permit be approved before 1'5-day wail ........ U ENGINEERING REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs .......... Y CMT vol adequate to circulate on conductor & surf cog .... Y CMT vol adequate to tie-in long sl~ing to surf csg ...... CMT will cover all known productive hodzons ......... ~ N Casing designs adequate for C, T, B & permafrost. ..... Adequate tankage or reserve pit ................ If a re-drill, has a 10-403 for abndnmnt been approved .... Adequate wellbore separation proposed ............ If diverter required, is it adequate ............... .-' Drilling fluid program schematic & equip list adequate .... BOPEs adequate ............. '~' ' ' BOPE press rating adequate; test to Choke manifold complies w/APl RP-53 (May 84) ....... ( Work will occur without operation shutdown .......... Is presence of H2S gas probable ............... GEOLOGY ,, 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. Y//N ' "'" - ' ' 33. Seabed condition survey (if off-shore) ............ //Y N 34. Contact name/phone for weeid¥ progress, reporl[s, ..... ~. Y N lexp~oramry onn/j / GEOLQ~Y: ENGINEERING: COMMISSION: BE~/~ DWJ ,J~/ JDH _?" JDN Comments/instructions: HOW/l113 - A.%COR~list rev 4/g6 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 'rape Subfile 2 is type: , TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MWD RUN 1 AK-MM- 60121 R. KRELL D. WESTER 1G-10A 500292100301 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 27-FEB-97 386 ~ 79~~t~/~ 31.07 30.32 3.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 6336.0 6.125 7906.0 MWD - EWR4/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. ANNULAR HYDRAULICS WERE CALCULATED USING THE POWER LAW MODEL. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), & ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4) . THIS WELL REACHED A TOTAL DEPTH OF 7906'. PER BILL ISAACSON, NO DEPTH SHIFTS WERE APPLIED. FILE HEADER ' FILE AKIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 6280.0 7846.0 6280.0 7853.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP 1 6295.0 MERGED MAIN PASS. MERGE BASE 7906.0 CN WN FN COUN STAT : ARCO ALASKA, INC. : 1G-10A : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 2 RPX MWD 68 3 RPS MWD 68 4 RPM MWD 68 5 RPD MWD 68 6 FET MWD 68 7 ROP MWD 68 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AAPI 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 HR 4 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 110 · Tape File Start Depth = 7950.000000 Tape File End Depth = 6250.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27209 datums Tape Subfile: 2 190 records... Minimum record length: 62 bytes Maximum record length: 998 bytes 0 0' : (ZI--I) XDN,q'D. OHae:1%:lMa : (i%IT) eleiO(:IN-~,T,E q:OO,T, 000 ' 00' : (MI) NOILDZHNOD Z~OH :XLISNa~ XIHilfl4 :XIHitfI4 qO0£ MOHiCaN 0'99 0'99 O' 0'99 000' ~: Off8 ' Offi ' OOE:'I 008 0'0T 00'II CINS~I 0'9££9 fi[T'9 : (~) HidaG DNIS~D S,~a%%IHG : (MI) aZIS ~I~ a%OH NadO f ' SISa~ ' DI/q40%I.T.D.~I.~ fNMa adA,T, ~IO0,'r, .~GOD ~IO0,T, %tO(~NaA (NO,T.T, Of E O,T, dO&) DNIN.T.S ~lO0,l, I'65 0 0'906£ 0'fi6~9 0'906L £O'fi fdS 88'f 96-daS-90 0'£S8£ 0'9f8£ SIq :~g~ .sT £ siljqns REMARKS: CN WN FN COUN STAT : ARCO ALASKA, INC. : 1G-10A : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 995 99 1 4 90 995 99 1 4 90 640 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 4 90 995 99 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 110 Tape File Start Depth = 7950.000000 Tape File End Depth = 6250.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27209 datums Tape Subfile: 3 175 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 4 is' t~pe: LIS 97/ 2/27 O1 **** REEL TRAILER **** 97/ 2/27 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 27 FEB 97 5:10p Elapsed execution time = 2.42 seconds. SYSTEM RETURN CODE = 0