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Home My WebLink About190-036 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(~ ~ ~ 0_~.2 File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~Bren v TO RE-SCAN Notes: Vincent Nathan Lowell Date: 5' ~ ~0~/si ~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LORI~M~LM. DOC E E L E W A T E R IA L U N D E TH IS M A R K ER R PLUGGING & LOC_ATION CLE$-~-~CE, , RE. PORT StaUa of Alaska ALAS~0iL & GAS CL~TSERVATION COMMISSION .,: _.=.-= r~n-Lu_= _- F:: =: APi !,io L¢c~icn "~, we~ ~ -'-' '~" an~' c.~-.~= on ptuqg-i~q, well head .~eV~- eW ~.,e ...... , '' loc. clear, code. t~ Conc£us~ons: 03-9'- ~0~ 7 -0; Code · o PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 June 28, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1L-20 (90-36 / 300-061) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the drilling operations on 1L-20. If you have any questions regarding this matter, please contact me at 265-6120 or William Lloyd at 265-6531. Sincerely, G. C. Alvord Drilling Engineering Supervisor PAI Drilling GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r-1 Gas ~1 Suspended r-] Abandoned ~] Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 90-36 / 300-061 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 '?'r-_ --,,-,,,..__ 50-029-22027-00 , 4. Location of well at surface 9. Unit or Lease Name 104' FSL, 216' FWL, Sec. 29, T11 N, R10E, UM (ASP: 540278, 5949075) , Y_'~ff,~.,,, [ Kuparuk River Unit At Top Producing Interval~i 10. Well Number ~, 1L-20 II At Total Depth 11. Field and Pool 1774' FSL, 1172' FEL, Sec. 28, T11N, R10E, UM (ASP: 549442, 5950789) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 30' feetI ADL 25660 ALK 470 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions April 8, 1990 April 20, 1990 March 24, 2000 (P&A'd) N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11715' MD/6278' TVD 10778' MD/5809' TVD YES ~1 No [~1I N/A feetMD 1500' (approx) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 S u rface 115' 24" 245 sx AS I 9.625" 36# J-55 Surface 6000' 12-1/4" 1400 sx AS III & 600 sx Class G 7" 26# J-55 Surface 10938' 8-1/2" 300 sx Class G set bridge plug @ 6210', HES cement retainer @10730' 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 N/A * Plugged & Abandoned all perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A :~7. 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. RECEIVED N/A ORIGINAL ooo Oil & 6as Cons. Commission Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS M EAS. 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 P&A Abandonment Operations 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Bill Lloyd 265-6531 SignedT,,~~p'. _~. Title Drilling Enqineering Supervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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: 06/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iL-20A STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/23/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22027-01 03/22/00 (D1) TD/TVD: 0/0 SUPV:G.R. WHITLOCK 03/23/00 (D2) TD/TVD: 0/0 SUPV:G.R. WHITLOCK 03/24/00 (D3) TD/TVD: 0/0 SUPV:G.R. WHITLOCK 03/25/00 TD/TVD: 0/0 SUPV:G.R. WHITLOCK MW: 0.0 VISC: 0) N/U BOPE 0 PV/YP: 0/ 0 APIWL: 0.0 Move modules off well and pick up mats and berms. Clean up herculite and cellar. Spot modules over well and set mats. Hook up support lines and build berms for cellar. Hook up elec lines and insulate breezeways. MW: 0.0 VISC: 0 PV/YP: 0/ 0 0) RIH W/ DUMMY MILL ASSEMBLY APIWL: 0.0 N/D tree. Install new tubing spool and test to 3000 psi,Ok. NU BOPE and set test plug and test BOPE to 250/3500 psi. Test casing to 3500 psi, OK. R/U e-line and run CCL tag ~ 6231'. RIH with dummy mill assembly. Tag obstruction ~ 237'. Attempt to rotate past obstruction w/o success. L/D assembly. Top mill showed slight wear, Top mill ~ 224' Run caliper 350' to surface. Obstruction noted at 224' M/U 7" casing scraper. MW: 8.6 VISC: 124 PV/YP: 22/58 0) P/U WHIPSTOCK APIWL: 7.8 Run scraper through restriction ~ 237' w/no problems. M/U dummy milling assembly and clean out restriction ~ 237' w/no problems. RIH w/mills. Hit hard spot at 530' Packed off. Worked pipe and established circ. RIH to 6230' Circ hi-vis sweep. Pump dry job. POOH. RIH w/Baker model "N" CIBP. Set plug at 6210' Setting tool would not release. RIH with overshot and fishing jars. MW: 8.6 VISC: 71 PV/YP: 18/38 0) RIH W/ DRILLING ASSEMBLY APIWL: 6.8 RIH. Latch onto fish. Jar setting tool off of CIBP. POOH. L/D fish and overshot. RIH w/whipstock. Set whipstock. Displace brine w/mud. Mill window +20' hole. Perform FIT to 13.5 ppg. POOH 2 stands. Not taking proper fill. Break circ to clean metal shavings off of pipe. POOH. ARCO Alaska, Inc. Post Office BOx 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, .~ /"~.....J,..~m.es ,R. Wine[~a,.rner, CPL /~""'Senior Lan d~..~n" JRW:hb Enclosures CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATe 1528 LAO 466 ATe 1918 ATe 1420 ATe 1202 ATe 496 ATe 1439 RECEIVED APR 1 4 1995 Alaska Oil & Gas Cons. Commission Anchora '. ARCO Alaska, Inc, is a Subsidiary of Atlantic Richfield Company KUPARUK RIVER UNIT (ARCO Contact: Larry Brown 263-1501) APR ] 4 {995 Alaska 0il & Oas Cons. C0rn~nlssl0n Anchora, ARCO hereby requests extensions of "suspended" status for the following wells. Additionally, an exception to the surface plug requirement of AOGCC 20AAC25.110(c) is requested. All of these wells are located in safe and accessible locations on producing drill sites that are monitored daily. The individual status of each well is detailed below. KRU Well 1H-05, APl # 50-029-20727-00, Permit # 82-0038-0 Well 1H-05 was drilled to TD without setting 7" casing despite encountering 10' of net C1 Sand pay. At the time it was drilled, this pay was considered too marginal to justify completion. This area of the drill site, however, may be economically developed using emerging technologies currently being employed on the North Slope (i.e., slimhole completions, coiled tubing drilling/sidetracks/horizontal sections, etc.). For this reason, Well 1H-05's wellbore (especially the surface hole) is a useful asset to ARCO Alaska and should be maintained in the suspended status. Surface casing (10-3/4") was set and cemented at 2425' MD-RKB. Four cement plugs which were witnessed by an AOGCC representative were set @ 9825'-10,300' (225 sacks Class 'G'), 5100'-5700' (290 sacks Class 'G'), 4160'-4590' (260 sacks Class 'G'), & 2230'-2545' MD-RKB (240 sacks Arctic Set I). Additionally, 10.5 ppg brine was left in the wellbore above the top plug. Based on the above, Well 1H-05 is believed to be in a secure condition with no risk of hydrocarbon migration. KRU Well 1L-20, APl # 50-029-22027-00, Permit # 90-0036-0 Well 1L-20 was suspended due to a drill string fish left in the well @ 11,040' MD-RKB. At the time of the initial suspension, a side-track was planned out of the existing surface hole. Problems developed while trying to pull the 7" casing for the side-track; therefore, the decision to drill a completely new well (1L-20X) was made. A time extension is requested for this well in order to complete an evaluation of this well's future use as a coiled tubing or conventional side-track candidate. This well's surface hole might be able to be used to drill a much needed water injection well to the north of 1L-20X's bottomhole location. This is a key location for preventing gas migration from the 1C/1D storage area. If this wellbore's suitability for future use is determined to be uneconomic, then the P&A process will be initiated. Well 1L-20 is in a secure condition with 9-5/8" surface casing set and cemented @ 6000' MD-RKB, a 7" long string set and cemented @ 10,938' MD-RKB, a cement retainer set at 10,878' MD with 100' of cement above, and a permanent bridge plug set @ 6657' MD-RKB capped with 75 sx of Class 'G' cement. KRU Well 1L-26, APl # 50-029-22173-00, Permit # 91-0069-0 Well 1L-26 encountered 4' of net A Sand pay. At the time it was drilled, the economics for completing this well were positive, but were considered marginal as stacked against other projects within the KRU; therefore, the well was not perforated nor was tubing run. ALASKA OIL AND GAS CONSERVATION COMMISSION August 19, 1994 WALTER Jo HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 David Sutter, Land Manager ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended wells as shown on the attached lists: ARCO SUSPENDED WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. . Chairman encls c: Blair Wondzell bew/llarsusp ARCO SUSPENDED WELLS PRIOR TO 1980 AS OF AUGUST 1994 PERMIT 00-0242-0 68-0095-0 69-0036-0 73-0027-0 74-0056-0 74-0057-0 76-0013-0 76-0017-0 76-0034-0 78-0017-0 API NLTMBER 029-21821-00 029-20004-00 029-20017-00 179-20004-00 029-20150-00 029-20151-00 029-20195-00 029-20199-00 029-20208-00 029-20278-00 WELL WELL WELL NAME CLASS STATUS PRUDHOE BAY UNIT OWDW-C SER SUSP DELTA ST I EXP SUSP PUT RIV ST I EXP SUSP KAVIK UNIT 3 DEV SUSP DELTA ST 2 EXP SUSP GULL ISST I EXP SUSP GULL ISST 2 EXP SUSP HIGHLAND ST 1 DEV SUSP W BEAC/~ ST 3 HEP SUSP W MIKKELSEN ST I ENP SUSP STATUS DATE 6/23/73 2/27/69 7/01/69 5/02/74 5/17/75 4/01/76 4/22/77 4/12/76 7/26/76 11/11/78 SECT 11 10 07 O8 35 28 24 25 32 TWP 10N 10N 10N 03N llN 12N 12N llN 12N 10N R.NG 014E 016E 014E 023E 016E 01SE 015E 011E 014E 019E MER U U U U U U U U U U ARCO SUSPENDED WELLS SINCE 1980 AS OF AUGUST 1994 PERMIT 60-0041-0 82-0038-0 82-0218-0 83-0181-0 84-0156-0 84-0205-0 86-0056-0 89-0013-0 89-0041-0 90-0036-0 91-0069-0 92-0065-0 93-0174-0 93-0179-0 94-0043-0 API NUMBER 133-10142-00 029-20727-00 029-20888-00 029-21056-00 029-21181-00 029-21221-00 029-20138-01 029-21912-00 029-21937-00 029-22027-00 029-22173-00 029-22261-01 029-22419-00 029-22423-00 029-20614-01 WELL WELL WELL NAME CLASS STATUS SWANSON RIV UNIT 34-15 DEV SUSP KUPARUK RIV LTNIT 1H-05 DEV SUSP P~AVIK ST 1 EXP SUSP HEMI SPRINGS ST I EXP SUSP PRUDHOE BaY UNIT DSlS-11 DEV SUSP PRUDHOE BaY LTNIT DSl1-15 DEV SUSP W BEACH ST 1-a SER SUSP PT MCINTYRE Pl-03 EXP SUSP PT MCINTYRE P3-01 DEV SUSP KUPARUK RIV I/NIT 1L-20 DEV SUSP KUPARUK RIV I/NIT 1L-26 DEV SUSP PT MCINTYRE P2-50A DEV SUSP KUPARUK RIV UNIT 2E-17 DEY SUSP KUPARUK RIV UNIT 2E-05 DEV SUSP PRUDHOE BaY UNIT DS12-13A DEV SUSP STATUS DATE 8/21/91 5/18/82 4/03/83 4/03/84 9/17/84 2/14/91 5/06/86 4/26/89 7/03/89 3/31/91 6/09/91 8/30/92 4/25/94 4/25/94 4/03/94 SECT 15 33 32 12 19 33 25 16 22 29 32 14 36 36 18 T~4P 08N 12N 09N llN llN 12N 12N 11N llN 12N llN 11N 10N RNG 009W 010E 009E 011E 01SE 01SE 014E 014E 014E 010E 010E 014E 009E 009E 015E MER S U U U U U U U U U U U U U U ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~L~ t G i ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS I"--1 SUSPENDED ~ ABANDONED I-"3 SERVICE r-'-I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-36 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22027 , 9 Unitor Lease Name 4 Location of well at surface I~ 104' FSL, 216' FWL, SEC 29, T11N, R10E, UM ~ ........... ~ KUPARUK RIVER f v~ .......... ~ i 10 WellNumber AtTop Producing Interval I ? ?"~Tg , I [ Surf~ N/A i _~_,/__~.~ i 1L-20 At Total Depth I ~IF!EI~ !~.~.,,.~,..__.__.H,~i, 11 Field and Pool 1774' FSL, 1172' FEL, SEC 28, T11N, R10E, UM L~ ,-~c~,~ KUPARUK RIVER FIELD __ 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 122', PAD 86' GLI ADL 25660, ALK 470 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp.jor Ab}and. 15 Water Depth, if offshore 116 No. of Completions 4/08/90. 4/20/90. ~ -~//~'///~:~/ NA feetMSLI 1 17 Total Depth (MD+'I'VD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11,715' MD, 6278' TVD 10,778'* MD, 5809' TVD YES X~--MWD NO O NA feet MD 1500' APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 245 SX ASl 9-5/8" 36# J-55 SURF 6000' 12-1/4" 1400 SX ASIII, 600 SX CLASS G 7" 26# J-55 SURF 10,938' 8-1/2" 300 SX CLASS G 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) NA N/A 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~- 28 CORE DATA 'lOP OF FISH @ 10,77~, EZ 8¥ @10,748', lOG @ 6201' dUN 20 glasl a Oil .& Gas Cons. co.mmlssioa Form 10-407 Submit in duplicate Rev. 7-1-80 CCNTINUED ON REVERSE SIDE NNv~ Include interval tested, pressure data, all fluids recoverd and gravity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP NA KUPARUK C Be'FI'OM KUPARUK A TOP KUPARUK A Bo'FrOM 31. LIST OF ATTACHMENTS MWD, & REPORT OF OPERATIONS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~r/~.~/) ~~ _ Title AREA DRILLING ENGINEEI;[ 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 ir~ item 27. Submit a separate form for each additional interval to be separately produced, showing the ~ata pertinent to such interval. ~em 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. Irem 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ~-Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS WELL: 1L20 PAGE: 1 BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25660 ALK 470 50-029-22027 90-36 AK4630 55.252072 ACCEPT: 03/25/91 SPUD: RELEASE: 03/30/91 OPERATION: Plug & Suspend RIG: AUDI 03/26/91 (26) TD: 0 PB: 0 SUPV:TA 03/27/91 (27) TD: 0 PB:10778 SUPV:KKL 03/28/91 (28) TD: 0 PB:10778 SUPV:WLM 03/29/91 (29) TD: 0 PB:10778 SUPV:WLM NU BOPE 7"@10870' MW:10.0 NaCl/Br MOVE RIG FROM 1L-21 TO 1L-20. RU HARDLINE. ND LOWER TREE AND TBG HEAD. PULL PACKOFF. NU BOP STACK. STACK TO TALL W/ ADDITIONAL SPOOL. ND STACK AND NU DIFFERENT STACK W/ DOUBLE GATE. DAILY:S52,614 CUM:$2,472,316 ETD:S2,472,316 EFC:$1,980,000 7"@10870' MW:10.0 NaCl/Br NU BOPE AND TEST. INSTALL WEAR RING. MU HOWCO PERM BP ON DP AND RIH. SET BP AT 6657'. POH W/ DP. LD HOWCO SETTING TOOL. MU TRI-STATE HYD CSG CUTTER AND RIH. STOP AT 221' AND COULD NOT GO THROUGH. POH. MU 6-1/8" BIT AND RIH. GO THRU TIGHT SPOT AND POH. RIH W/ CUTTER (SAW TIGHT SPOT AT 221' AGAIN). DAILY:S30,460 CUM:$2,502,776 ETD:S2,502,776 EFC:$1,980,000 POH W/ 3-1/2" DP 7"@10870' MW:10.0 NaCl/Br SERVICE RIG. CONT RIH W/ TRI-STATE HYDRAULIC CSG CUTTER ON 3-1/2" DP. CUT CSG AT 6600' MD. POH AND LAY DOWN CSG CUTTER. CHANGE PIPE RAMS TO 7". TEST. RIG UP TO PULL 7" CSG. PU TRI-STATE SPEAR AND PACKOFF. RIH AND ENGAGE 7" CSG. PULL 175K# TO 290K# LBS. ONLY SAW 2" MOVEMENT. RELEASE SPEAR FROM 7" CSG. 'POH. MIl MULE SHOE ON 3-1/2" DP AND RIH 550'. CIRC HOT BRINE. RIH TO 1575' AND CIRC HOT BRINE. DAILY:S27,435 CUM:$2,530,211 ETD:S2,530,211 EFC:$1,980,000 POH W/ FREE POINT 7"@10870' MW:10.0 NaCl/Br PU TRI-STATE SPEAR AND RIH. ENGAGE 7" CSG AND PULL UP TO 290K LBS ON 7" CSG. CSG WOULD NOT MOVE. POH AND STAND BACK SPEAR. PU MULESHOE ON 3-1/2" DP. TIH TO 642'. CIRC WARM BRINE. TIH TO 1670'. CIRC HOT BRINE. POH. PU TRI-STATE SPEAR AND ENGAGE 7" CSG. PULL UP 290K LBS. MOVED 7" CSG 6" SLACK OFF WT AND POH W/ SPEAR. PU TRI-STATE CSG CUTTER AND RIH. CUT CSG AT 73'. POH AND LD CSG CUTTER. PU SPEAR AND RIH. SPEAR CSG AND POH AND LD 53' OF 7" CSG. RIH AND ENGAGE 7" CSG W/ SPEAR. PULL WITH 290K LBS. ABLE TO MOVE 7" CSG 36" (SAME DISTANCE STRING FELL TO ONCE FORCE RELIEVED FROM CUT). UNABLE TO MOVE 7" CSG ANY FARTHER. POH W/ SPEAR. RU HLS E-LINE AND APRS FREE POINT. RIH AND ENGAGE 7" CSG. FREE POINT FOUND AT 350' (S~SPECT 7" COLLAR HANGING UP ON 9-5/8" CSG). POH. RIG UP TRI-STATE OVERSHOT ASSY AND APRS STRING SHOT. DAILY:S31,128 CUM:$2,561,339 ETD:S2,561,339 EFC:$1,980,000 WELL: 1L20 OPERATION: Plug & Suspend RIG: AUDI PAGE: 2 03/30/91 (30) TD: 0 PB:10778 SUPV:WLM 03/31/91 (31) TD: 0 PB: 6291 SUPV:WLM REVERSE CIRC TO CLEAN DP 7"@10870' MW:10.0 NaCl/Br PU OVERSHOT AND RIH. LATCH 7" CSG STUB AT 76'. RIH W/ STRING SHOT ON WIRELINE TO COLLAR AT 128'. WORK LEFT HAND TORQUE ON 7" AND FIRE STRING SHOT. BACK OFF 7" CSG. VERIFY BACKOFF POINT WITH CCL. POH W/ 7" CSG (7" CSG COLLAR LOOKING UP). PU AND RUN 7" CSG. TIE IN W/ 12 ROUNDS AND 5500# TORQUE. PU 140K LBS AND SLACK OFF. ROTATE 6 ROUNDS MAINTAINING 5500# TORQUE. PRESS TEST 7" CSG TO 1000 PSI (OK). BLEED PRESS OFF. SLACK OFF AND INSTALL SLIPS. PULL ll0K LBS AND CUT 7" CSG. INSTALL PACKOFF. DRESS OFF 7" CSG STUB AND NU BOPE. TEST SAME. RAMS LEAKED. CHANGE RAMS AND RETEST. INSTALL WEAR BUSHING. RIH W/ 444' OF 2-7/8" TBG CROSSED OVER TO 3-1/2" DP TO BRIDGE PLUG. RIG UP HOWCO AND BATCH MIX CMT. PUMP 5 BBLS H20 AND TEST LINES TO 3000 PSI. PUMP 5 BBLS H20, 14 BBLS CMT AND 2.5 BBLS H20. DISPLACE W/ 42 BBLS 10.0 BIRNE. POH 6 STDS AND CIRC BRINE OUT OF WELL WITH DIESEL. DAILY:S56,459 CUM:$2,617,798 ETD:S2,617,798 EFC:$1,980,000 RIG RELEASED 7"@10870' MW:10.0 NaC1/Br REV CIRC, 1.5 DP VOL @ 4 BPM/500 PSI, POH TO 1000', DISPLACE WELL F/1000' TO SURFACE W/DIESEL (38.5 BBLS), CONT POH, LD DP & TAIL, PULL WEAR BUSHING, ND BOPE, NU TBG SPOOL & DRY HOLE TREE, TEST TO 3000 PSI, RD CELLAR, SECURE WELL SICP=0 PSI, SIAP=0 PSI, RIG RELEASE @ 2200 HRS 3/30/91 DAILY:S48,231 CUM:$2,666,029 ETD:S2,666,029 EFC:$1,980,000 SIGNATURE: DATE: ARCO Alaska Inc. Kuparuk River Field AK-4630 KRU 1L-20 North Slope Alaska SPERRY-SUN DRILLING SERVICES MWD COMPLETION REPORT Anchorage, Alaska (907) 522-3256 Kris Ferguson Senior MWD Engineer JUN 20 ]~9[ · -'~-a~t~'Oil .& Gas Cons. Com~iss[O_~ ~nchorago TABLE OF CONTENTS SECTION I ......................................... RESULTS SECTION II .................................... WELL SUMMARY SECTION III ...................... COMPLETION SUMMARY OF RUNS SECTION IV ............................... . BHA AND BIT DATA SECTION V ........................... DRILLING AND MUD DATA SECTION VI ................................... SURVEY REPORT SERVICE OBJECTIVES AND RESULTS RUN A: Kickoff at 255', build at 3 deg/100' to 57.0 degrees. with direction of N 81.6 E. POOH for BHA change RUN B: Slowly build to 64.5 degrees at 6020' (csg pt)and N 87.9 E. POOH and run 9 5/8 csg. RUN C: Drill to 10965' (csg pt) with Neyrfor turbine, POOH. Run 7" csgo Halliburton finishes the 6" hole. SECTION I WELL SUMMARY JOB NUMBER : RIG / PLATFORM KB ELEVATION : AK-MW-00051 Doyon 14 122' KB REFERENCE : Mean Sea Level SURFACE LOCATION MAGNETIC PARAMETERS 104' FSL, 216' FWL SEC. 29, TllN, R10E UMIAT Meridian NORTH REFERENCE True GRID TYPE Universal Traverse Mercator DECLINATION : 29.92 DEGREES GRID CORRECTION TOTAL CORRECTION 0.00 DEGREES 29.92 DEGREES START AND ENDING IN-HOLE DAYS : START AND ENDING M. D. START COORDINATES (Offset) ( N / S ) : ( E / W ) : 4-12-90 through 4-16-90 115' through 10965' 0.00' North 0.00' East TARGET LOCATION (From Wellhead) MUD MOTOR SIZE / TYPE 1586' North, 9144' East N 80:10 E, 9281' Horizontal Disp 8" NaviDrill II (1 1/4 Deg BH) 7 1/4" Neyrfor Turbine MWD PULSER SUB O.D. 8.00" (#021) 6.75" (#008) ENGINEERS ON LOCATION Kris Ferguson Tony La Belle Allen Sherritt SECTION II OTART DATE/TIME END DATE/TIME RUN RUN OPERATINO BTART END HOU~ MD MI) FOOTAOE DRILLED 541 SURVEY9 DETECTED 15 ::'1 TOOLFP, CES DETECTED 947 ~ECTION III BHfl ~ B~T ~TA MWI) RUNA MWI) RUN i) MWI) RUN C HI BIT/N~IDRIIM. II(~TRI'. )/~ I)EO ~ NI~I'I:)B/I~/NI~/NI~?~/NMI~! XO 3xHWI)P/JAI~/~MHI~ BITtNAUIDRIU. Il (1.~ ~H)/X~ R. OAT/NM PONY INI~TAI)INMI~IHO~ NMI~I~I~I~T~I~I XO 3xHWl~tJARtltlxH~ BITIN~YRFOR TURI)INE/XO/FI. OAT t#.EAI) I NI~ T ~ I NMI~ I HO~ I X O 3 x NMI)C I X O I 3 x HWI)P l J A R~ I ~, , x HWI~ BIT BIT BIT NO. SIZE TYPE I 12 1/4" 3 8 I/E" bith MA1J~ MAIJSI. Hughes ~T FOOTA(3E OIZE OTART ENO 3x14, lx9 a~7 ~ I'FA = O, 54" 6e~e 10970 3~E3 ~iCTI~N IV RECEIVED .,Alaska Oil & Gas Cons, CommissioD Anchorage MM) RUN ~ Mbl) RUN B MWO RUN C 541 541 541 9.3 9.8 Tpa~'t PV 14 YP 11 ? A~O O~I. ORII)liS 900 ~mg/L K:~SO Mil/L 1509 Mg/L PROBE 58.1~ ~CTION V FILE IMPORTED FROM ~-~"~0 PROGRAM .... , Pad 1L 1L-20 15-APR-1990 NORTH REFERENCE : TRUE NORTH MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG LEG DEPTH DEGREE QUADRANT DEPTH FEET FEET SECTION SEVERITY .00 .00 N .00 E .00 .00 N .00 E .00 .00 185.00 .30 N 63.80 W 185.00 .21 N .43 W -.39 .16 367.00 5.70 N 89.30 E 366.68 6.97 N 1.10 E ~.27 3.28 547.00 13.20 S 85.20 E 544.11 5.92 N 30.60 E 31.16 4.19 728.00 18.40 S 87.70 E 718.21 2.87 N 79.76 E 79.08 2.90 908.00 23.20 S 87.50 E 886.43 .19 N 143.61 E 141.53 2.67 1094.00 28.20 S 87.90 E 1053.98 3.04 S 224.18 E 220.37 2.69 1285.00 30.60 N 85.60 E 1220.37 1.16 S 317.87 E 313.00 2.09 1475.00 35.90 N 83.40 E 1379.21 8.82 N 421.52 E 416.83 2.86 1664.00 39.60 N 78.60 E 1528.62 26.91 N 535.75 E 532.47 2.50 1854.00 45.20 N 83.40 E 1668.87 46.94 N 662.20 E 660.49 3.40 2043.00 50.10 N 82.50 E. 1796.16 64.08 N 800.78 E 799.96 2.62 2233.00 55.10 N 82.50 E 1911.52 83.77 N 950.38 E 950.73 2.63 2553.00 55.80 N 80.20 E 2093.00 123.41 N 1210.93 E 1214.21 .63 2868.00 57.60 N 81.60 E 2265.94 165.05 N 1470.87 E 1477.45 .68 3184.00 62.00 N 83.00 E 2424.85 201.63 N 1741.45 E 1750.30 1.44 3501.00 63.00 N 78.80 E 2571.22 246.09 N 2019.03 E 2031.39 , 1.22 3823.00 64.00 N 84.60 E 2714.90 287.67 N 2304.05 E 2319.33 1.64 4166.00 62.80 N 82.80 E 2868.48 321.32 N 2608.88 E 2625.43 .59 4419.00 63.20 N 83.00 E 2983.34 349.19 N 2832.5? E 2850.59 .17 4640.00 64.00 N 86.50 E 3081.60 367.30 N 3029.66 E 3047.88 1.46 4957.00 63.00 N 84.40 E 3~23.04 389.80 N 3312.44 E 3330.35 .67 5336.00 63.10 N 88.10 E 3394.81 411.89 N 3649.50 E 3666.23 .87 5622.00 64.40 N 87.20 E 3521.30 4~2.41 N 3905.78 E 3920.54 .54 5950.00 64.50 N 87.90 E 3662.77 435.06 N 4201.44 E 4214.01 .19 6183.00 63.90 N 87.60 E 3764.18 443.30 N 4411.05 E 4421.95 .28 6562.00 63.60 N 79.60 E 3931.80 481.15 N 4748.57 E 4760.98 1.89 6847.00 60.60 N 77.50 E 4065.15 531.15 N 4995.39 E 5012.71 1.24 7193.00 64.20 N 76.30 E 4225.42 600.63 N 5293.98 E 5318.78 1.08 7445.00 64.00 N 75.60 E 4335.50 655.66 N 5513.88 E 5544.86 .26 7696.00 63.70 N 74.90 E '4446.12 713.03 N 5731.77 E 5769.33 .28 8012.00 63.50 N 75.70 E 4586.62 784.85 N 6005.54 E 6051.36 .24 8264.00 64.20 N 75.90 E 4697.69 840.34 N 62~4.84 E 6276.90 .29 8581.00 65.00 N 74.30 E 4833.66 913.97 N 6501.55 E 6562.13 .52 8896.00 64.80 N 76.70 E 4967.28 985.39 N 6777.70 E 6846.42 .69 9246.00 64.00 N 75.00 E 5118.51 1062.55 N 7083.75 E 7161.15 .49 9561.00 63.80 N 75.00 E 5257.09 1135.76 N 7356.99 E 7442.88 .06 9877.00 64.40 N 71.40 E 5395.12 1217.91 N 7629.07 E 7724.99 1.04 10100.00 63.30 N 76.40 E 5493.40 1273.40 N 7821.33 E 7923.90 2.07 10353.00 64.50 N 77.00 E 5604.70 13~5.67 N 8042.44 E 8150.68 .52 FILE IMPORTED FROM ~ro PROGRAM 1L-20 Pad 1L 15-APR-1990 NORTH REFERENCE ~ TRUE NORTH MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG LEG DEPTH DEGREE QUADRANT DEPTH FEET FEET SECTION SEVERITY 10607.00 60.50 N 73.10 E 5721.96 1383.77 N 8260.02 E 8375.00 10878.00 59.30 N 72.~0 E 5857.87 1453.68 N 8483.81 E 8607.43 2.08 · 53 RADIUS OF CURVATURE CALCULATION METHOD HORIZONTAL DISPLACEMENT AT BOTTOM HOLE IS 860?'45 FEET ALONG N 80 DEG 16 MIN E RELATIVE TO WELL HEAD VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 80.17 DEG AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ct~ - ~ WELL NAME ~~k COMPLETION DATE ~ / ~ , ] ~t I CO. CONTACT '__ "'check off or list data as it 14~ reCei¥~d?list received date for 407. if not re~JuirCd list as Nil '.4.O~l*~/~loLi drillin_qhistOry, V/ SurvegJ Iwel, t'ests ,,j,~oredescrip'tiod- cored In,terra,Ii ,,C,°re analysis d~,ditCh,, in,tCrvals ,,,d, igital data i lllllll I I Il I I Il I Il I I Il I I ~ L I II I I I I II I I III I I III II I I II I I I I I I I I II II I I I III I I I I I III I I I I . I I I I I I IIIII I LOG 'PY'PE RUN INTERVALS .... SCALE' ........... N0. . (to the nearest foot) (inch/1. 00'] '~! j~ek~: ..... f/- .............. . 3) ~ ~ ,7 ~_~ ~ ..... ............ ................ ii ii i i L I 6) i,, i i , , i , , ,kl,_~. '""" ,, , , , , i , i ,, , i i ,, , , ,,, 9) i'6) ................................................. ,, ~, , , , , i i i ii ii i,,i i iiiii 11) i2) .................. i'4) ............................... ' , ,, i i u , . ,,i i~1 L ii i i i~11,, i i6) .................... ,11 i1,1 i i ,,111 , Ull, i, 1~) i~. , ,,,,, ,,,,,,~1 i i i i i ,- ,, ,, , 18) i, , ii i ,11, lU,,ll,, i ,1111,1 , ,, , ,, ,,,,i ii i i i u i · , , Ab. A OILAND GAS CONSERVATION COMM,.. ON ~ ~../.. APPLICATION FOR SUNDRY APPROVALS :~ ~:' ' 1. Type of Request: Abandon_ Suspend ~ Operation Shutdown _ Re-enter suspended well,,,~ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing Variance _ Perforate _ Other ~ ~4 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 104' FSL, 216' FWL, Sec. 29, T11N, RIOE, UM At top of productive interval 3,590' FNL, 1,200' FEL, Sec. 28, T11N, RI OE, UM At effective depth 3,590' FNL, 1,200' FEL, Sec. 28, T11N, RI OE, UM At total depth 3,541' FNL, 920' FEL, Sec 28, T11N, RI OE, UM 12. Present well condition summary Total Depth: measured true vertical 11,715 feet Plugs (measured) 6. Datum elevation(DF or KB) RKB 112 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-20 9. Permit number 90-36 10. APl number 50-029-22027 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 6,295 feet Cement: 11,040' - 10,778' Effective depth: measured true vertical Casing Length Structural Conductor 8 O' Surface 5,984' Intermediate Production 10,983' Liner Perforation depth: measured Size 16" 9 5/8" 7" feet feet Junk (measured) TOP OF FISH @ 11,040' Cemented Measured depth 250 Sx AS I 1,500 Sx AS III & 600 Sx Class G 300 SX Class G 115' 6,000' 11,040' True vertical depth 115' 3,675' 5,920' true vertical RECEIVED Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal Plug back to redrill hole to avoid fish lost in hole. ~,~;~ 2 ~. 1991 ~!Jas _~..Oil .& Gas Cons. C0m~issio~ "." ~, i Anchora~a Detailed operation program X BOP sketch _ 14. Estimated date for commencing operation March 24, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;~ Gas __ Suspended Service 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 Date 3-21-91 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test~ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 10- /?c~ Commissioner Approved Copy Returned IApproval o Date (~- ~,~,- ~/ SUBMIT IN TRIPLICATE , . , , . . . . KUPARUK RIVER UNIT Well 1 L-20 Preparation for Sidetrack Procedure MIRU Audi #4. Fill pits with 10.0 ppg brine. Make sure no pressure is on 7" casing or 7" x 9-5/8" annulus. Nipple down McEvoy lower tree unit and 7-1/16" 5K psi x 11" 3K psi tubing head. Back out primary packoff screws and pull 7" x 9-5/8" packoffs. Prepare area around wellhead for safe welding operations. Tack weld slip segments to 7" casing and tie segements together with tack welded straps. Do not weld slips to hanger bowl. Nipple up 13-5/8" BOPE (13-5/8" 5K psi x 11" 3K psi double studded adapter needed) and flow nipple. Test blind rams and choke manifold to 3000 psi. Test annular to 3000 psi. (Notify AOGCC 24 hrs prior to nippling up BOPE). MU and RIH with a permanent bridge plug. Set BP at _+6650' MD. POH. PU Tri-State 5-1/2" hydrualic multiple string casing cutter on 3-1/2" DP. RIH and cut 7" casing at 6600' MD. POH. PU 7" casing spear with packoff on 3-1/2" DP. RIH and spear 7" casing at wellhead. PU 5' and break circulation. Circulate down 7" casing displasing diesel out of 7" x 9- 5/8" annulus. Circulate until clean brine returns. POH with 7" casing, 7" slips and hanger bowl. LD same. RU to spot cement above BP. RIH with 3-1/2" DP and place +300 ft3 of cement in a balanced plug above BP at ___6650' (see Attached Schematic). POH. Recommended Cement blends: Halliburton 0.3% CFR-3, 0.15% HR-5, 0.085 gal/sak Halad-344L Dowell 0.4% D-59, 0.4% D-65, 0.2% D-46, 5% KCL BJ 0.3% D-31, 0.8% D-28, 0.1 % D-6 Notes: a)mix with batch mixer. b)desired fluid loss is 130-150 cc c)desired pump time of +3hrs ml~. . CE, ~ED d)ensure field tests are run on ce ~ ~/ RIH with 8-1/2" drill bit on 3-1/2" DP to 200' above cement. Dress cement down to _+5800'. Circulate. POH. Oil & 6as Cons . 10. 11. ND BOP stack. NU tubing head and lower tree assembly. Secure well. Release rig. Current Status of Well 1L-20 3/20/91 9-5/8" 36# J-55 ['::~'~(~'-'_i 6000' MD ~ Fish: 20-Steel Drill Collars Steel Stab 4 Monel Drill Collars Float Sub Pulser Sub MWD Collar Gamma Ray Sub Monel Lead Collar Double Pin Sub NM Stab Turbine Bit 10.0 ppg Brine 7" 26# J-55 ~'[-:'i 10,938' MD .~:::.::::...:.~ ~: ::..': .'.-.:: ~ ¥2.:::.::t Esamated Top of Cement 8,538' MD Top of Cement 10,778' Top of Retainer 10,910' Top of fish 11,040' Top of Kuparuk 'C' Sand 11,020' Top of Kuparuk 'B' Sand 11,252' Top of Kuparuk 'A' Sand :::::::::::::::::::::: :::::::::::::::::::::: 11,325' :::::::::::::::::::::: 11.8 TD 11,715 MD DSS 3/20/91 Side Track Preperation Plans Well 1L-20 3/20/91 16" Conductor 115' MD ~,::::.:::.: :;:.;:;:.;::i i'E:i-';.;'.'. '~'-':-:'"'-':] Top of Cement ['.:' ::' :::! :~" "~'..'- ~`::~`::~`::l~------------------------------------------------------------------~-[~::~::~::~ 5700' MD 9-5/8" 36# J-55 [' :':'.i :'."._: ; ~.'.'.'.'.'.'.'.'.'l ..'i'."..'~'."-:~ 7'6600'Pulled MD to -'-~ ~ To~;~0R, o~;nor Estimated ToP of Cement 7" 26# J-55 10,938' MD 10.0 ppg r,'.",." Brine 7..?.'3 -~ I.'.'.'.' ,.....j r... v.r.'.'.'.~~''''''''''' i~---::: :::::- ' '::;' "~ '::' · ;{" Estimated Top of Cement 8,538' MD Top of Cement 10,778' MD Top of Retainer 10,910' MD Top of fish 11,040' MD Top of Kuparuk 'C' Sand 11,020' Top of Kuparuk 'B' Sand 11 252' Top of Kuparuk 'A' Sand :::::::::::::::::::::: :::::::::::::::::::::: 11,325' :::::::::::::::::::::: 11.8 TD 11,715 MD DSS 3/20/gl STATE OFALASKA COMMISSION0 RIG IN/ i. ALASKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown ~X Pull tubing Alter casing Stimulate __ Plugging X Repair well Other Perforate 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 surface 104' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 3590' FNL, 1200' FEL, Sec. 28, T11N, R10E, UM (approx) At effective depth 3590' FNL, 1200' FEL, Sec.28, T11N, R10E, UM (approx) 6. Datum elevation (DF or KB) 112' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1L-20 9. Permit number/approval number 90-36/90-303 10. APl number 50-029-22027 At total depth 3541' FNL, 920' FEL, Sec. 28,T11N, R10E, UM 12. Present well condition summary Total Depth: measured (approx.) true vertical (approx) 1 1 71 5' feet 6295' feet Effective depth: measured 1 0778' (approx.) true vertical 5858' 11, Field/Pool Kuparuk River Oil Pool feet feet Plugs (measured) Junk (measured) Top of 100 sx Class G @ 10,778' EZSV @ 10,878' Top of 175 sx Class G @ 10,951' Top of fish @ 11,040' Casing Length Size Structural 8 0' 1 6" Conductor Surface 5963' 9 5/8" Intermediate Production 1 0903' 7" Liner Perforation depth: measured None Cemented 200 Sx AS II 1400 Sx AS III & 600 Sx Class G 300 Sx Class G Measured depth True vertical depth 115' md 115' tvd 6000' 3675 (approx) 1 0938' 5920' (approx) true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED OCT u _t .]990 OjJ .& Gas Cons. ,, r~ch0ra~je ' 14. Prior to well operation Subsequent to operation ReDre8eptative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run 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 ~D~[~/~'~.~,~A~t' i! ~:~~.~~ Title Area Drilling Engineer Form '10-404 -Rev 05/17/~' ~ ~ Date SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or wed(over operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W,O. no. AK4630 County, parish or borough NORTH SLOPE ~Lease or Unit ADL: 25660 ALK: 470 JTifle DRILLING IState AK Well no. Operator ARCO Spudded or W.O. begun IDate IHour SPUD 04/08/90 22: 30 Date and depth as of 8:00 a.m. 04/09/90 ( 1) TD: 1069' ( 10( SUPV:CTD Complete record for each day reposed DOYON 14 Prior status if a W.O. 04/10/90 TD: 3957' SUPV:CTD 04/11/90 TD: 6020' SUPV:CTD 04/12/90 TD: 6020' SUPV:TAB 04/13/90 TD: 6713' SUPV:TAB 04/14/90 TD: 9584' SUPV:TAB 04/15/90 TD:10365' SUPV:TAB 04/16/90 TD:10965' SUPV:TAB 04/17/90 TD:10965' SUPV:TAB 2) 28e8) 3 20 3) O) 5 6! 3) 6) 28~ ) 7) 781) 8) 6C0) 9) O) DRLG MW: 9.3 VIS: 55 MOVE RIG FROM 1L-9,NU DIVERTER, CO KELLY, PU BHA, TEST DIVERTER, DRLG FROM 115 DAILY: $74, 319 CUM: $74,319 ETD:S74,319 EFC:$1, 980, 000 DRILLING MW:10.0 VIS: 47 DRLG 1069 TO 1460. CIRC OUT GAS, MUD CUT 10 0 TO 9.5 PPG. DRLG TO 2397'. CIRC & MIX SLUG, DROP SINGLE SHOT. TRIP F/B!{A & BIT, DRLG AHEAD. DAILY:S69,694 CUM:$144,013 ETD:S144,013 EFC:$1,9~0, ~O'~ CIRC MW:10 0 VIS: 47 ;i:'~LG 3957-6020,CIRC AND CONDITION HOLE. DAILY:S55,402 CUM:$199,415 ETD:S199,415 EFC:$1,980,000 CEMENTING MW:10 1 VIS: 45 CIRC, SHORT TRIP,CIRC,DRO? SURVVEY, POH, RUN 9.625" CASING,CIRC, RIG UP TO CMT. DAILY:S55,182 CUM:$254,597 ETD:S254,597 EFC:$1,980,000 DRLG MW: 9 0 VIS: 36 FINISH CMT, NU BOPE,RIH, DRLG 10' NEW FORMATION, TEST SHOE TO 12.5PPG, DRLG. DAILY:S279,197 CUM:$533,794 ETD:S533,794 EFC:$1,980,0~>~ MW: 9 4 VIS: 35 DRLG DRLG FROM 6713 TO 9584. DAILY:S60,621 CUM:$594,415 ETD:S594,415 EFC:$1,980,000 DRLG MW: 9 5 VIS: 36 DRLG,PUMP PILL,DRLG, POOH, RIH W/ NEW BIT,CUT DRLG LINE, DRLG. DAILY:S61,164 CUM:$655,579 ETD:S655,579 EFC:$1,980,000 POH, LDDP MW: 9 8 VIS: 36 DRLG, CIRC.,WIPER TRIP,REAM AND WORK HOLE,CIRC, POH LDDP. DAILY:S63,736 CUM:$719,315 ETD:S719,315 EFC:$1,980,000 ND BO?E 7"@10870' MW: 9.8 VIS: 37 LD DP AND BHA, RUN 7"CSG,ATTEMPT TO CIRC,DAMAGED LAST JT WHILE RUNNING CASING, REPLACED JT,RU D/S AND ATTEMPT TO CIRC,PUMP CEMENT W/ PARTIAL RETURNS,WELL FLOWING, WAIT BEFORE ND BOPE.PREPARE TO CUT 7"CSG. DAILY:S213,548 CUM:$932,863 ETD:S932,863 EFC:$1,980,000 The above is correct For form'rn p eparat on/~preparation d distribution., see ProcedruresMian~, Section 10, Drilling, Pages 86 and 87, AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no, ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out bul nol tess frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25660 ALK: 470 JStale AK IWell no. KRU ' L-.] ' KUPARUK RIVER UNIT Date and depth as of 8:00 a.m, 04/18/90 ( 1 TD:10928' ( SUPV:TAB 04/19/90 TD:ll186' SUPV:CTD 04/20/90 TD:11555' SUPV:CTD 04/21/90 TD:l1715' SUPV:CTD 0'4/22/90 TD:l1715' SUPV:CTD 04/23/90 TD:l1715' SUPV:CTD 04/24/90 TD:llT15' SUPV:CTD Complete record for each day while drilling or workover in progress DOYON 14 ~) o) .) ~58) :) ~69) ~) L60) ) O) ) O) ' DRILLING CMT & FLOAT COLLAR 7"@10870' MW: 9.5 VIS: 36 ND BOPE, SET 7" CSG SLIPS, CUT LDG JT, NU TBG SPOOL, TEST ?O 3000 PSI, OK, NU BOP, CHANGE RAMS TO 3-1/2", CHANGE OUT KELLY, TEST BOPE TO 3000 PSI, SET WEAR BUSHING, PU BHA, TEST TURBINE, ORIENT MWD, RIH W/3-1/2" DP, TAG FLOAT COLLAR, TEST CSG TO 3500 PSI, DRILL FLOAT COLLAR AND CEMENT TO 10928' RETEST CSG, OK DAILY:S66,954 CUM:$999,817 ETD:S999,817 EFC:$1 980,000 DRLG 7"@10870' MW:12 0 VIS: 41 DRLG FLOAT EQUIP,CIRC AND COND,TEST FORMATION, OK,CIRC AND INCREASE MUD TO 12, DRLG. DAILY:S91,475 CUM:$1,091,292 ETD:S1,091,292 EFC:$1 980,000 DRLG DRLG F/ 11186 T/ 11555 7"@10870' MW:ll 9 VIS: 43 DAILY:S65,944 CUM:$1,157,236 ETD:S1,157,236 EFC:$1,980,000 WORK STUCK PIPE 7"@10870' MW:ii 8 VIS: 42 DRLG 11555 TO ll715,RIG DRAWWORKS BROKE, STUCK PIPE, SPOT LUBE, JAR ON STUCK PIPE DAILY:S57,439 CUM:$1,214,675 ETD:S1,214,675 EFC:$1 980,030 REPAIR RIG 7"@10870' MW:ii 8 VIS: 45 JAR ON STUCK PIPE,ATTEMPT TO BACK OFF. DAILY:S59,156 CUM:$1,273,831 ETD:S1,273,831 EFC:$1 ATTEMPT TO BACK OFF 7"@10870' MW:ii 6 VIS: 46 REPAIR RIG, SPOT LUBE, R/U HLS FREEPOINT, RUN TO 10878',WORK 13 ROUNDS BACK TORQUE. DAILY:S59,689 CUM:$1,333,520 ETD:S1,333,520 EFC:$1 980,000 JARRING ON STUCK FISH 7"@10870' MW:ii 5 VIS: 45 FIRE STRING SHOT F/BACKUP, MISFIRE. POOH W/STRING SHOT, MU RIH W/STRINGSHOT #2 500 GR/FT, FIRE CHARGE @ 10878', BACKED OFF, POOH W/WIRELINE, RD HALLIBURTON, POOH W/DP-BREAK EVERY CONNECTION, CHECK F/BAD BOX F/60 STDS, LD 7 BAD JTS, TOP OF FISH @ 10864' DPM, LD 2 DC & 4-3/4 DAILY DRILLING JARS, MU FA #1, TIH CUT DRLG LINE, TAG FISH @ 10864' DPM SCREW INTO FISH, WORK TORQUE TO BOTTOM, JAR ON STUCK FISH, NO MOVEMENT. DAILY:S72,203 CUM:$1,405,723 ETD:S1,405,723 EFC:$1,980,000 The above is correct S~gnat For form preparatiq~nd distributionS"; see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all dally well history forms conseculively as they are preparod for each well. IPage rio ARCO Oil a~,,, Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show Iormation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set, Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25660 ALK: 470 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 04/25/90 TD:l1715' SUPV:CTD 04/26/90 TD:l1715' SUPV:JCP 04/27/90 TD:llT15' SUPV:JCP 04/28/90 2 TD:l1715' SUPV:JCP 04/29/90 2] TD:ll040' SUPV:JCP 04/30/90 2~ TD:10951' SUPV:JCP 05/01/90 ( 22 TD:10948' ( SUPV:JCP 1 1.) O) O) O) 0) ) O) ) O) DOYON 14 0) AK Well no. KP.b' LL-2~ CIRC 7"@10870' HW:10.8 VIS: 55 JAR ON STUCK PIPE,ATTEMPT TO CIRC,COULD NOT, PUMP FREE?OINT DOWN TO 11300' 100% STUCK AT l1024(TOP OF C),CIRC AND REDUCE HUD WEIGHT. DAILY:S55,152 CUM:$1,460,875 ETD:S1,460,875 EFC:$1,980,000 CIRC GAS 7"@10870' MW:ll.2 VIS: 51 CIRC AND CONDITION MUD,DROP MUD WT,CIRC AND JAR ON FISH, LOST CIRC,GAINED 41 BBLS, SICP=1000,SIDP=0,LUBRICATE WELL, RIH WITH SEVERING TOOL,CUT DRL COLLAR AT ll040',PU PIPE SEVERED OK, CIRC OUT GAS,RD ATLAS WIRELINE,INCREASE HUD TO ll.2,POOH, SWABBING WELL,CIRC OUT GAS,WASH BACK TO i1000. DAILY:S77,247 CUM:$1,538,122 ETD:S1,538,122 EFC:$1,980,000 POH 7"@10870' HW:ll.5 VIS: 50 PULL INTO CASING SHOE,CIRC OUT GAS,OBSERVE WELL NO FLOW, CBU, POOH SWABBING, TIH,CIRC OUT GAS,RIG UP TO PUHP OUT OF THE HOLE,POH SLOWLY WHILE PUMPING INTO THE HOLE DAILY:S60,211 CUM:$1,598,333 ETD:S1,598,333 EFC:$1,980,000 REAMING 7"@10870' PrW:ll.5 VIS: 50 PU HILL AND RIH,CUT AND SLIP DRLG LINE,CBU, CONT.RIH,REAH 10938-10975,HOLE PACKING OFF,CBU,POH,CHANGE BHA, RIH,REAH 10938-11011. DAILY:S429,624 CUH:$2,027,957 ETD:S2,027,957 EFC:$1,950,000 TEST BOPE 7"@10870' MW:ll.5 VIS: 45 WASH AND REAM, CIRC,POH, RIH W MULESHOE,WASH TIGHT HOLE,HIX AND PUMP BALANCED CEMENT PLUG, POH 10 STANDS,REV CIRC CEMENT,POH, LAY DOWN TBG,TEST BOPE. DAILY:S101,323 CUM:$2,129,280 ETD:S2,129,280 EFC:$1,980,000 RIH W/KO ASSY 7"@10870' HW:ll.4 VIS: 47 FINISH TESTING BOPE,MU BHA, RIH,CIRC BU, RIH,CIRC, RIH,TAG CHT AT 10700,DRILL CMT 10700-10792,CBU, TEST CSG, DRILL CHT TO 10951,CBU, POH,MU BHA W/BENT SUB, RIH. DAILY:S62,209 CUM:$2,191,489 ETD:S2,191,489 EFC:$1,980,000 POH 7"@10870' MW:ll.3 VIS: 46 WASH AND REAM TO 10941,HOLE PACKED OFF,PULLED UP INTO CSG,WHILE PULLING STRING IT PARTED IN TWO, WAIT ON FISHING EQUIP,MU OVERSHOT,RIH, LATCH ON TO FISH,CBU, PULL OUT HOLE INSPECTING DRILL STRING, LAY DOWN 9 JTS DP,CUT SLIP DRLG LINE, RIH W/ SLICK ASSY, WASH AND REAM TO 10948,HOLE CONTINUES TO PACKOFF, PUMP PILL TO POH TO PLUG. DAILY:S58,736 CUM:$2,250,225 ETD:S2,250,225 EFC:$1,980,000 The above is correct ,, For form preparation and distribution.---" see Procedures 19~nual Section 10, Drilling. Pages 86 and 87 AR3B-459-2-B Number all daily well hislory forms consecutively as they are prepared for each well Page no ARCO Oil ar, u Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and forlowing setting ol oil string until completion. District ARCO ALASKA INC. ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25660 ALK: 470 ]~'~ate AK IWel[ no KRU 1L-2 ? Field KUPARUK RIVER UNIT Date and depth as of 8:00 a.m. 05/02/90 ( 2 TD:10778' ( SUPV:JCP IComplete record for each day while drilling or workover in progress DOYON 14 CIRC 7"@10870' MW:ll.2 VIS: 43 POH,LDBHA, PU EZSV, RIH, SET EZSV, CIRC, PUMP CMT,PULL 5 STDS,REVERSE CIRC, POOH, MU BHA, RIH,TAG CMT @ 10748,PRESS.TEST TO 3500PSI,OK, DRILL HARD CMT TO 10778, CBU, REVERSE CIRC W/ H20. DAILY:S78,804 CUM:$2,329,029 ETD:S2,329,029 EFC:$1,980,000 The above is correct Signature ~//~ For form preparation aC'dj distribution see Procedures Manualk,,Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number ali daily well history forms consecutively IPage no as hey are prepared for each well ARCO 6 and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" 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 Jn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish /State ARCO ALASKA' INC. NORTH SLOPE AK Field Lease or Unit IWell no, KUPARUK RIVER UNIT ADL: 25660 ALK: 470 K~!: :L-.:. Auth. or W.O. no. ~Title AK4630 I DRILLING Operator A.R.Co. W.I. ARCO 56. 8533 Spudded or W.O. begun Date SPUD 04/08/90 Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 05/03/90 ( 251 TD:10778' ( SUPV:TA Iotal number of wells (active or inactive) on this pst center prior to plugging and I bandonment of this well our I Prior status if a W.O. 22:30 I 0) RIG RELEASED 7"@10870' MW:10.0 ViS: 0 DISP HOLE WITH H20,DISP HOLE WITH BRINE,TEST CASING TO 3500PSI,POH LDDP, BREAK KELLY, LDDP,LDDC,PULL WEAR BUSHING, CO RAMS,ND BOPE, RELEASE RIG AT MIDNIGHT ON THE 2HD OF MAY. DAILY:S90,673 CUM:$2,419,702 ETD:S2,419,702 EFC:$~,980,~00 Old TD New TD Released rig Date PB Depth K nd of rig Classifications (oil, gas, etc.) 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 Oil on test Gas per day ~ump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .... The above is correct Signature ~.~,. /~~ For form preparation an~istribution, see Procedures Manual~...~ection 10, Drilling, Pages 86 and 87. Date AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. DlviNon of AtlantlcRIchfieldCompany ~"'$KA OIL AND GAS CONSERVATION COk 3SION AppLiUATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend -~ Operation Shutdown ~'" Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time` extension _ Stimulate M Change approved program_ Pull tubing _ Variance _ Perforate _ Other_ 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 surface 104' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 3590' FNL, 1200' FEL, Sec. 28 , T11N, R10E, UM At effective depth 3590' FNL, 1200' FEL, Sec. 28, T11N, R10E, UM At total depth 3541' FNL, 920' FEL, Sec 28, TllN, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) Effective depth: measured true vertical RKB 11g 7. Unit or Property name Kuparuk River Unit Casing Length Structural Conductor 8 0' Surface 5 9 8 4' Intermediate Production 1 0 9 8 3' Liner Perforation depth: measured 8. Well number 1L-20 9. Permit number 90-36 1 1 715' feet Plugs (measured) 6295' feet Cement: 10750'-12045' feet feet 10. APl number 50-029-22027 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool - i'~',,, ~i--' Size Cemented Measured depth 16" 250 Sx AS I 1 15' 9 5/8" 1500 Sx AS III & 5984' 600 Sx Class G 7" 300 Sx Class G 1 0 9 8 3' .. ~qch.o, raFa True veruca~oepm 115' 3675' 5920' true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) EZSV @ 10880'MD WITH TOC @ 10780'MD 13. Attachments Description summary of proposal _ Detailed operation program X~ BOP sketch 14. Estimated date for commencing operation 15. 01 -MAY-90 Oil 16. If proposal was verbally approved Name of approver M. MINDER 31-APR-90 Date approved Service _ 17. I her/e~by certify that the foregoing is true and correct to the best of my knowledge. S,,ned y~-~-~ ~..'' .~ ~¢_.~ Title Status of well classification as: Gas Suspended X FOR COMMISSION USE ONLY Date ~c-'//2,//¢~_~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance ~ Mechanical Integrity Test_ Subsequent form require 10-_~4;~, Original-3i:'~r, ed By Approved by the order of the Commission David W, Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1 L-20' CONFIGURATK::)N 5/01/90 NOT TO SCALE 7" csg TOC 10780'MD CEMENT RETAINER 10880'MD 7" CSG POINT 10938' md I 1 040md TOP OF FISH 1 STEEL DRILL COLLAR STEELSTAB 8 STEEL DRILL COLLARS STEEL STAB (3) 6 STEEL DRILL COLLARS 4 MONEL DRILL COLLARS MWD TURBINE BIT 11715'MD (6295 TVD) JA' SUSPENSION Of OPERATIONS ON 11_-20 The following is the procedure for the suspension of operations of 1L-20. 10. 11. 1. RIH with a EZSV cement retainer and set at 10880' md. a)Break circulation at the setting depth to clean the side wall. b)Stop circulating and PU to setting depth. c)Turn 35 turns to the right. d)Pick up 30K# in 10K# increments to shear tension sleeve. e)Set down the amount of shear weight on the tool, setting the retainer. 2. Pick up 10 feet. Turn 20 times to the right. 3. Break circulation. Sting back into the retainer to check for pump in rate. Do not exceed 3500 psi. 4. Release stinger. Displace drillpipe volume with 10 bbls slurry. Use choke manifold to impede cement freefall. 5. Sting back into retainer once cement is within 10 bbls of being displaced out of the drillpipe. Bullhead up to 5 bbls slurry below retainer. 6 Release stinger and displace remaining slurry above retainer. 7. POOH 5 stands and reverse out drillpipe volume plus 10 bbls. 8. Finish POOH. PU BHA (casing scraper/bit) and RIH to dress off cement leaving 100' cement above retainer. WOC 8 hours before tagging cement. 9. Circulate out cement cuttings. Reverse circulate hole volume with 350 bbls. fresh water followed by 10.1 ppg brine. Pressure test casing and plug to 3500 psi. POOH LDDP and BHA. Blow top 100' of hole dry. Rig down, release rig and move to 1L-11. Use same blend of cement slurry as used on the production liner casing. TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND/.GAS CONSERVATION COM~ISSION Lonnie C. Smit~>~/ DATE: April 18, 1990 Commissioner ~j' ~) FILE NO: 3T. BF. 418.2 TELEPHONE NO: Bobby D. Foste Petroleum Inspector SUBJECT: BOP Test AAI KRU 1L-20 Permit No 90-36 Kuparuk Rv Field Thursday April 12, 1990: The tests on Doyon rig 14 began at 3:00 p.m. an--~~e cone ue~--~ :00 p.m. As the attached BOPE test report shows, there were no failures. In summary, I witnessed the BOP Test on AAI's KRU 1L-20. Attachment 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA AL~,SKA 01 l AND GAS CONSERVAT 1 ON COMM ISS 1 ON BOPE Inspection Report InspectOr t ~- .... i" '/ : ' Location (general) Well sign General housekeeping L~.i Rig Reserve pit ~.Y" Visual Trip .tank Pit gauge F1 ow moni tar Gas detectors Audio MUD SYSTEMS: DATE ft ACCUMULATOR SYSTEM: ' Full charge pressure . r~ ~O (~) psig Press after closure _. /~ ~ psig Pump incr clos press 200 psig ,-- min /~..~ sec ,, Ful 1 charge press attai ned .~,:.: rain N~ , ~ r.~ ~-- ~)~ O ']J' psig Control S: Master L~J ~_ 1 Remo~e ~d~) ~ B1 ind switch cover,,, i~:: :' ~"' i KELLY AND FLOOR SAFETY VALVES: Upper Kelly ) Test pressure~/~U " BOPE STACK: ' Lower Kelly Test Pressure Annular preventer__~O~ .:' ~ ~,:'~ .cb Ball type ! Pi pe rams ~ ~,~ i ,, .:., ,, , q~:)D Inside BOP / Blind rams 30g~./'~-::O Choke manifold ~oke line valves ~) / '~' ,? ~:'"~Tb Number valves HCR valve ~9 ~" ~ '~":'~ Number fl anges . Kill line v~lve~ , .~),// ~~ ~dju~g~ble ehoke~ Check valve Hydraulically operated choke Test pressure Test pressure Test pressure TEST RESULTS: Failures Test time .... ,~' hrs Repair or replacement of failed equipment to be made within ~-- ' days , and Inspector/Commission office notified. Remarks: Distribution: orig - AOGCC c - 0pera=or c - Supervisor C.004 (rev 03/17/89) Al' 'iA OIL AND GAS CONSERVATION COMk ~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other_ 6. Datum elevation (DF or KB) Alter casing ~ Repair well Change approved program _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 2. Name of Operator ARCO Ala~,ka. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 4. Location of well at surface 104' FSL, 216' FWL, Sec. 29, T11N, R10E, UM At top of productive interval 3590' FNL, 1200' FEL, Sec. 28 , T11N, R10E, UM At effective depth 3590' FNL, 1200' FEL, Sec. 28 , T11N, R10E, UM At total depth 3541' FNL, 920' FEL, Sec 28, T11N, R10E, UM Present well condition summary Total Depth: measured true vertical RKB 112 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-20 9. Permit number 90-36 10. APl number 5~-029-22027 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 1 2045' feet Plugs (measured) 6342' feet Cement: 10750'-12045' Effective depth: measured true vertical feet feet Casing Length Size Structural Conductor 80' 1 6" Surface 5984' 9 5/8" Intermediate Production 11050' 7" Liner 12045' 5" Perforation depth: measured Cemented Measured depth True vertical depth 250 Sx AS I 1 15' 1 15' 1500 Sx AS III & 5984' 3675' 600 Sx Class G 200 Sx Class G 1 1 0 5 0' 5 9 0 0' 125Sx AS I 12045' 6342' true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) RE£E VED ,~PR 1 ! 19~0 .,i':'!:~,s~ ,0ii & ~as C0ns~ Commission Detailed operation program .~rlCtlora~:)p sketch _ 12. 13. Attachments Description summary of proposal _ 14. Estimated date for commencing operation 08-APR-90 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil m Gas m Suspended Service Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S igned"~ ~ A~.~~ Title ~ ~~jC~,~f~. ~ ~ ~ _~R COMMISSION USE ONIL.~ Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test __ Mechanical Integrity Test_ require IApproval No. _ Location clearance ¢¢ ~! /-2/ Subsequent form 10-~-~ -"'re~/ec~ O~O'"d~' t ~ ' / ~P~ ~o~ - C missioner Date ~'-/j" 2~ ~nNNIE C. gM~TH SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 DRILLING PROCEDURE KUPARUK RIVER FIELD 1L -20 . , , . 5, . , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 casing point according to directional plan, Run and cement 7" casing. Pressure test to 3500 psi. Drill 6" hole to TD. Run open hole evaluation logs. Run and cement 5" casing liner. 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. March 7, 1990 Telecopy No. (907) 276-7542 P J Archey Area Drilling Engineer ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit iL-20 ' ARCO Alaska' Inc Permit # 90-36 Surf Loc 104'FSL, 216'FWL, Sec 29, TllN, R10E, UM Btmhole Loc 3541'FNL, 920'FEL, Sec 28, TllN, R10E, UM Dear Mr Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dete~inations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ry tru%~ YOUrs C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY OP~DER OF THE CO~LMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl " ' STATE OFALASKA ALA~,,,A OIL AND GAS CONSERVATION COMMEx.,ON PERMIT TO DRILL 20 AAC 25.005 I 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 12;~, Pad 86' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~]e, AK 99510-0360 ADL 25660 ALK 470 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 104' FSL, 216' FWL, Sec. 29, T11N, R10E, UM Kuparuk River Unit A t top of productive interval (TARGET) 8. Well number Number 3590' FNL, 1200' FEL, Sec. 28 , T11N, R10E, UM 1L-20 #U630610 At total depth 9. Approximate spud date Amount 3541' FNL, 920' FEL, Sec 28, T11N, R10E, UM 03-18-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and TVD) -- ~%~ '~'r~ '~. / properly line 1L'~'81oS~-'/~' ~"';~ t~'~ 12045 MD 3541'@ TD feet 60' at RFC 2560 6342TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300 feet Maximum hole angle 64° Maximum surface 217551g At total depth (TVD) 6342' 3495 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD {include stage data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 5894' 35' 35' 5894' 3675 1500 Sx AS III & ~'-~,Rw 600 Sx Class G 8.5 7" 26.0# J-55 BTC 12045 35' 35' 10245 6342 250SxClassG ~'-~.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 vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural sC:,~da~ect°rRECEIVED Intermediate Production Liner MAR - 2 1990 Perforation depth: measuredAlaska Oil & Gas Cons, true vertical Anchorage 20. Attachments Filing fee ~ Property plat __ BOP Sketch _X_.. Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot 4 Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,~ ~' ~/~ Title Area Drillin~ En~]ineer Date Commission Use Only Permit Number I APl number I Approval date I See cover letter for 50- - z o 0 3 / 0 7 / 9 0other requirements Conditions of approval Samples required ~Y e s ~ N o Mud log required ~ Ye s~.. N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~ Yes ~ N o Required working pres~.l~e for BOPE ~2M; .z~3M_' ~ 5M' ~ 10M' ~ 15M Other: ............. by order of Form 10-401 R~ // J in triplicate DRILLING FLUID PROGRAM (1L-20) Spud to 9-5/8" Drill out to surface casino weioht UD Density 9.0-9.6 8.6-9.4 PV 15-30 8-10 YP 20-40 5-8 Viscosity 70-80* 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 APl Filtrate 10-1 5 7- 9 pH 9- 1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 10.6 10-16 7-12 35-50 4-8 5-12 4-5 8.5-9.5 <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 Notes' RECEIVED MAR - 2 1990 Naslfa 0ii & Gas Cons. Commissl(~!~ Anchorage - 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 2175 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. ~o ' '"' '~ - The nearest well to 1L-20 is 1L-e,8. As designed, the minimum distance between the two wells would be 60' 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. 400 _ 350 _ :5OO 250 2OO 150 ? 1 50 200 250 ~00 ~..~ 50' 400 450 500 550 ........ I I I I l I I I .... ~ 40O I .~ /900 / -'" I / o ..- ~ ~~oo × ...' ~oo / ~1 I -~oo ~ I.I- ~o oo '~ !~/I J 150 ._ ._ ._ -- -- "-J :~oo , , I ' ._.... --. --' ri 0%-' J I ..- --- -"~o-' =_ _ _~-o~'''''~'°-b ...... J loo 150 200 250 :~00 550 400 450 .500 550 ARCO ALASKA. I~c. Ped IL. Well Not 20 Proposed Kuperuk Field. No~th Slope. Aleeke 0 RKB ELEVATION, ~25' 1000 2000 :3000 4000 5000 KOP ?VD-300 TMD-300 DEP-O BUILD 2.5 ! 5 PER t O0 FT 20 30 B/ PERMAFROST TVD-15~$ THO-1604 DEP-361 35 40 55 T/ TVD-2445 ?MD-SOS6 DEP-1464 T/ 14 SAK SNDS TVD-2975 TMD'-4279 DEP-2566 , K-lO ?VD-3935 TMD-6494 DEP-4562 AVERAGE ANGLE 64 DEG 19 8/ g SAK sNas TVD-3475 TMD-5432iDEP-3605 9 5/8'.~S0 PT . ' TVD ~67~ TI~ $89~ DEP-40~! i K-5 ?VD-5150 THO-9296 DEP-?087 6000 7000 1 1 o0o I 2000 T/ ZONE C TVD-6000 THD=II2$? DEP-8854 T/ ZONE A TVD=6155 THD-11615 DEP=9177 TAROET CNTR TVD-6205 TMD-Ii?30 DEP'9281 B/ KUP SNDS TVD-6255 TMD-Ii845 DEP-9384 TD (LOG' PT) TVD-6342 TMD-12045 DEP-9565 3000 1 I i 4000 5000 6000 VERTICAL SECT[ON 7OOO I 8000 90O0 I 10000 HORIZONTAL PROJEC[ION SCALE 1 IN. =: 1000 FEET ARCO ALASKA, Inc. Pmd 1L. Well No, 20 Kuperuk Field, NorEh Slope. 2000 z 1000 I ~ 0 I000 1000 O 1000 2000 I I I SURFACE ~'~*~/ SURFACE LOCATION, 104' F~--'L., 218' FWL SEC. 29, TI1N. RI OE 6000 7000 8000 9000 I 00(' I I I i I TO LOCATION, ~I' FNL, 920' FEL Sl~C. 28. TIlN. RI OE WEST-EAST 3000 4000 5000 I I TARGET CENTER TVD-~205 TMD=II?30 DEP-0281 NORTH TARG~T LOCATION, 35~0' FNL. 1200' FEL SEC. 28. TIlN. RIOE N 80 DEG 10 HI N E 9281' (TO TARGET) I 13 5/8" 5000 F,.,I BOP STACK 7 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 PREVENTORAND MANUAL KILLAND 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 3(X)0 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO'FI-OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF 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 RECEIVED MAR -2 1990 0il & Gas Cons. comm[SSi¢ Anchorage SRE 8/22/89 DOYON 14 KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC r 6 DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~:3N WELD STARTING HEAD 3. FMC DNERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL WI10' OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PRE~ VALVES CAN BE REMOTELY CONTROl I;_n TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 3 1. 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. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES RECEIVED MAR - 2 1990 Alasle Oil & Gas Cons. CommtSSiO~ Anchorage JG 4/26/88 GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 1 L PAD . . . . . . . . , lO 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. note: The surface casing for all wells will be set deeper than the field rules of 3000' to cover the West Sak formation. 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. 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. RECEIVED MAR - 2 1990 Alaska Oil & Gas Cons. Com~liSSiO.[~ Anchorage CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ( 1 ) Fee /~/D~,~ _g//~/z~,-3 1. / , , (2) Loc (~hru 8~ (s) (3) Admin ~/~ ~/~~ 9. '(9 ~hru~ 10. (10 and 13) 12. 13. (4) Casg'/~.~,,¢9~ 3-&-¢0 (14 thru 22) (23 thru 28) Company Lease & Well No. /~Z~ YES NO ,,, Is the permit fee attached .......................................... 2. Is well t~ 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 wellbore plat included ................ 7. Is operator the only 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 conductor string provided ........................................ Will surface casing protect all 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 diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~Oo~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OIS{ER ,(,~ th~u (6) Add: f~'~.~/. ~-~'~ GeologM, Engi;~eerin~: .... rev: 01/30/89 6.011 For 29. 30. 31. exploratory 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 32. Additional requirements ............................................. ~,~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE o ~z ~o