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Home My WebLink About182-038 Ima ect Well History File Cover lge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L~..O~_- ~) ~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Project Proofing ~OBIN VINCENT SHERYL MARIA WINDY BY: Scanning Preparation ~ x 30 = BY: BEVERLY ROBIN VINCENT SHERYL~WlNDY Production Scanning Stage '1 BY; Stage 2 BY; (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDI~DUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) c3 Logs of various kinds [] Other III Illllllllll II Ill / ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: y YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES .NO BEVERLY ROBIN VlNCE~ARIA WINDY ReScanned (individuat page [special at~e~tion] .~ca¢~intJ compleX, ed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 12110102Rev3NOTScanned.wpd e ConocJ'Phillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 7, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 H-05 (APD 182-038) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk well 1H-05. This well was abandoned when 1H-105 was drilled in 2004." If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, RT/skad ! "\ I- \.J L.. I V L.. LJ e STATE OF ALASKA e APR 1 0 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil8i Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT ANDAbtÐ'ie 1a. Well Status: Oil 0 Gas U WDSPL 0 No. of Completions _ Plugged U Abandoned l:'J Suspended U 20AAC 25.105 20AAC 25.110 WAG 0 GINJ 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: WINJ 0 P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 528' FNL, 803' FEL, Sec. 33, T12N, R10E, UM . At Top Productive Horizon: not available Total Depth: 631' FNL, 726' FEL, Sec. 27, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549543 ' y- 5980175 y- not available y- 5985382 Zone- 4 Zone- 4 Zone-4 TPI: not available Total Depth: x- 554842 18. Directional Survey: Yes 0 NoD 21. Logs Run: 22. Other - 5. Date Comp., Susp., or Aband: December 6, 2004 6. Date Spudded: April 26, 1982 7. Date TO Reached: May 11,1982 8. KB Elevation (ft): 85' RKB 9. Plug Back Depth (MD + NO): 2230' MD 12077' TVD 10. Total Depth (MD + NO): 10840' MD 17152' TVD 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE 16" 10.75" GRADE H-40 K-55 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH NO TOP BOTTOM TOP BOTTOM Surf. 108' Surf. 108' Surf. 2425' Surf. 2259' wr. PER FT. 62.5# 45.5# 23. Perforations open to Production (MD + NO of Top and Bottom Interval, Size and Number; if none, state "none"): none 26. Date First Production not applicable Date of Test Hours Tested HOLE SIZE 13.5" 24. SIZE none 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: ~ 182-038 1 13. API Number: 50-029-20727-00 14. Well Name and Number: 1 H-05 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25639 17. Land Use Permit: ALK 464 20. Thickness of Permafrost: approximately 2601' MD CEMENTING RECORD AMOUNT PULLED 24" 250 sx AS II 1000 sx ASHI, 250 sx ASH TUBING RECORD DEPTH SET (MD) , PACKER SET 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> Flow Tubing press. psi 27. Casing Pressure GAS-MCF Plugged and Abandoned WATER-BBL CHOKE SIZE GAS-OIL RATIO GAS-MCF WATER-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 10-407 Revised 12/2003 OR\GINAL RBDMS 8Ft AP~! Ä ~i' 7nnli CONTINUED ON REVERSE OIL GRAVITY - API (corr) A!.~~I- : ca':;",ir':.~,·"L:~t- i ì '....," ì ¡ 12- ~~~.~~.¡! :H.\·¿~~~J ý_ »ý. /O.t.. p5\À¡\v.... # 1(;fI(Ø G 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". not available N/A 30. LIST OF ATTACHMENTS 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sharon Allsup-Drake @ 263-4612 Printed Name Randv Thomas Title: Greater KUDaruk Area Drillinq Team Leader '--( /) (ò {, Signature ~~ ....J;!1one 2.65"-' 6, ? :>ù Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 tI" 1<]:1"03<8 ~~~~E :1 !Æ~!Æ~1!Æ AIfASKA. OIL AND GAS CONSERVATION COMMISSION / / / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk 1H-05 Sundry Number: 304-389 Dear Mr. Thomas: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. /' ( sm~r~ ~~onnM ~~ -' BY ORDER OF TIJE COMMISSION DATED this þ-bday of October, 2004 Encl. SCANNED OCT 2 7 2004 STATE OF ALASKA RECEIVE~4()(. ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 f) 2004;:.;?" J 6 APPLICATION FOR SUNDRY APPROVAL ~J.. ~ 20 AAC 25.280 Alaska Oil & Gas Cons. Commission SZ Operation Shutdown D Perforate D vAtik1f¡orai] Annular Disp. D Plug Perforations D Stimulate D Time Extension D Other D Perforate New Pool D Perforation Depth MD (ft): none Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch. D 14. Estimated Date for Commencing Operat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature '~ \ ~ ( , Abandon D Alter casing [J Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Suspend D Repair well D Pull Tubing D 1. Type of Request: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 85' 8. Property Designation: ADL 25639, ALK 464 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 10840' 7152' 2230' Casing Length Size Conductor 78' 16" Surface 2425' 10-3/4" Re-enter Suspended Well 0 4. Current Well Class: Development - D Stratigraphic D 5. Permit to Drill Number: 182-038 6. API Number: Exploratory D Service D 50-029-20727-00 9. Well Name and Number: 1 H-05 10. Field/Pool(s): Kuparuk River Oil Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2077' 5 cement plugs MD TVD Collapse Burst 78' 2425' 78' 2259' Tubing Size: none Tubing MD (ft): Perforation Depth TVD (ft): none Packers and SSSV MD (ft) November 26, 2004 Date: Tubing Grade: no SSSV 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D GasD WAG D GINJ D Service 0 Plugged D WINJ 0 Abandoned D WDSPL D Contact: Mike Greener @ 263-4820 Title: Kuparuk Drilling Team Leader Phone l.,6Ç~'i J ð Date \ c.l'l. '1,(~ '1 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t:J L( "3~r Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Ð,-\\\ \ "So. '(:) ~~ ~\ CJI'- '> ""~ ,,\ \<;t û.:A \.0\'\ ....~ ~~\ ~\ð.- -\0 c.. W\'ò\,}Q \ OCT 2 () l{\O~ \ Approved by: Form 1 0-403 Revised 12/2003 L 0.. D.'.. f\J~..<\~) At SCANNED OCT 2r'~>J 7. 2~4ý I\' . \.:J . ~~ ... -. ORDER OF to ~6 () THE COMMISSION Date: COMMISSIONER INSTRUCTIONS ON REVERSE Submit in Duplicate Well Name: 1 H-05 API # : 5002920727 Surface CasinQ Date set 4/30/1982 Size 10-3/4" in Set at 2425 ft Wt. 45.5 ppf Grade K-55 Hole Size 13-1/2" in Wash Out % Est. T.O.C. 0 ft END OF WELL SCHEMA TIC Spud Date: DNew DUsed Hole angle @ shoe 49-1/2 Degrees Csg Shoe @ 2425 ft Cement PluQ #5 Date cmt'd: 5/17/1982 Plug: 240 sxs Arctic Set I @ 15.7 ppg Top @ 2,200', BUm @ 2,545' Note: Tagged @ 2,200' Cement PluQ #4 Date cmt'd: 5/17/1982 Plug: 240 sxs Arctic Set II @ 15.7 ppg Top @ 2,550', BUm @ 2,715' Note: Tagged @ 2,550' Cement PluQ #3 Date cmt'd: 5/16/1982 Plug: 260 sxs "G" @ 15.8 ppg, 2% CaCL2 + .2% D-46 Top @ 4,160', BUm @ 4,590' Note: Tagged @ 3,979' Cement PluQ #2 Date cmt'd: 5/16/1982 Plug: 290 sxs "G" @ 15.8 ppg, 2% CaCL2 + .2% D-46 Top @ 5,100', BUm @ 5,700' Note: not tagged Cement PluQ #1 Date cmt'd: 5/16/1982 Plug: 225 sxs "G" @ 15.8 ppg, 1 % D-60 + .1 % D-13 + .2% D-46 Top @ 9,825', BUm @ 10,890' Note: not tagged Hole Angle @ TD 52-34 degrees 26-Apr-82 TD @ 10,840 ft Rig Release Date: 18-May-82 Rig RKB (ft): NA ~ Top @ Surface BUm @ 620' Brine 10.5 ppg Brine from 2,200' to 620' SCANNED OCT 2 7 2004 T~\ S o-~~\\J~.~ \ ~ 1. Move on and prepare well for sidetrack. ~ ~ 2. Kick off well using exsisting cement plug at surface casing shoe. \ 3. Drill to planned MD of +/- 8,865'. ~ s:t ,?Q'Iù-~ 4.01- 4. Run casing string of 5-112" x 3-112" casing with seal bore crossover within 150' of the top of the West Sak fonnation. Drill and completion plan for the IH-05 5. Run 3-112" tubing string and sting into seal bore. 6. ND BOP and NU tree for injection service. 7. Move rig off. SCANNED OCT 2 7 2004 RE: Proposed 1H-05 Re-entry '" Subject: RE: Proposed IH-05 Re-entry From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Mon, 25 Oct 2004 08:24:36 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Thanks, will do. Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, October 25, 2004 7:42 AM To: Greener, Mike R. Subject: Re: Proposed 1H-05 Re-entry Thanks Mike. Since this is proposed to be an injector, remember to look at any well that penetrates entry into the West Sak and Call with any questions. Tom Maunder, PE AOGCC the West Sak within 1/4 mile of 1H-05A's along the well path. Greener, Mike R. wrote: Yes there is a permit to drill application coming. The well will be a West Sak well. It will also be an injector. Still accumulating information for the permit to drill application. Mike Greener Senior Drilling Engineer ConocoPhillips Alaska, Inc. 907-263-4820 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, October 22, 2004 11:07 AM . To: Greener, Mike R. Cc: Thomas, Randy L Subject: Proposed 1H-05 Re-entry Mike, This is We have 1H-OS. also a followup to my voice mail message. received your sundry proposing to re-enter suspended well Applying with a 403 is thè appropriate first step. Are you preparing a permit to drill application?? All the steps you propose on the procedure cannot be authorized with a sundry. . Also, will this well be drilled to the Kuparuk or will it be a West Sak well?? It is not clear. I also note that your are planning a tapered completion. Will the well be a producer or an injector?? I look forward to your reply. SCANNED OCT 2 7 2004 10f2 10/26/20048:42 A] ARCO Alaska, Inc.j~ 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, .,.--~,~'mes R. Wine~ '"' /'Senior Landman' / / · // 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 Alask~ 0il & Gas Cons. Commission Anchora '., ARCO Alaska, Inc, Is a Subsidiary of Atlantic Richfield Company ~UPARUK RIVER UNIT (ARCO Contact: Larry Brown 263-1501) Gas Cons. C0~r. Jssion Anch0ra. 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 Well1 H-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. ARCO Alaska, I~., ': ....... Post Oft~ ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 26, 1993. Russell A. Douglass, Commissioner A~[ska O,I and Gas Conservation Commission Re' Third Quarter 1993 Kuparuk River Field Injection · Dear Mr. DouglasS: Attached are injection surveys consisting of separate zone tests and cased-' hole logs pedormed or analyzed bY ARCO Alaska as operator of the Kuparuk River Field during the third quarter of 1993. These surveys are pedormed on wells with both A and C Sand injection as required by Rule 4 of Conservation Order No. 198. Blue'.tine~"and sepia'copies of. all logs are included..:,~ If you have any questions concerning these injection profiles, please call me at 263-4241. Sincerely, P. S. White ' Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska. Inc. is a Subsidiary of AtlanticRIchlilldCompany Alaska Oil Gas Consc~,ation Commission 300i Porcupine Drive Anchorage, Atask~ 99.~01-3192 9{]7-279-1433 To: Permit following data is hereby acknowledged as being received: CoPy sen~to sende.r: Ycs~ No ~' ALASKA OIL AND GAS CONSERVATION COMMISSION August 19, 1994 WALTER J. 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 sUs?ENDED 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 SINCe- 1980 AS OF AUGUST 1994 PERMIT 60-0041-0 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 SWAi~SON RIVUNIT 34-15 DEV SUSP ~ARUK RIV 'UNIT IH:'~ DEV SUSP P.~VXK sT I ~xP susP PRu~om mAY U~mT D818-11 omv susP PRUDHOE BAY ~IT DSl1-15 DEV SUSP PT ~CINTYRE P1-03 EXP SUSP PT MCINTYRE P3-01 DEV SUSP ~PARUK RIV ~IT 1L-20 DEV SUSP NPARUK RIV~IT 1L-26 DEV SUSP PT MCINTYRE P2-50A OEV SUSP KUP~UK RIV~IT 2E-17 DEV SUSP ~PARUK RIV~IT 2E-05 DEV SUSP PR~HOE BAY ~IT DS12-13A DEV SUSP STATUS DATE 8/21/91 5/lS/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 TWP 08N 12N 09N 10N 11N 11N 12N 12N 12N 11N 11N 12N 11N 11N 10N 009W 010E 009E 011E 015E 015E 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 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 NUMBER 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 IS ST I EXP SUSP GULL IS ST 2 EXP SUSP HIGHLAND ST I DEV SUSP W BEACH ST 3 ~XP SUSP W MIKKELSEN ST I EXP SUSP STATUS DATE 6/23/73 2/27/69 7/01/69 5102/74 5/17/75 4/01/76 4/22/77 4/12/76 7/26/76 11/11/78 SECT 11 10 07 08 35 28 28 24 25 32 TWP 10N 10N 10N 03N 11N 12N 12N 11N 12N 10N 014E 016E 014E 023E 016E 015E 015E 011E 014E 019E U U U U U U U U U APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend~. Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension"~Change approved program [] Plugging [] Stimulate ~ Pull tubing .rq, Amend order [] Perforate [] Other~ 2. N {~n..e~of.Q per.ator /~KL, U A1 asKa, I nc 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 528' FNL, 803' FEL, $eco33, T12N, RIOE, UN 5. Datum elevation (DF or KB) RKB 85 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 1H-5 8. Permit number 82 -28 feet At top of productive interval N/A At effective depth N/A At total depth 57/+ ' FNL, 775' FEL, Sec.27, T12N, RIOE~ UM 9. APInumber 50-- 029-20727 lO. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical 10840'MD .7152'TVD Effective depth: measured 2230 'MD true vertical 2077'TVD Casing Length Size Conductor 1 6" Surface 1 0-3/4" feet Plugs (measured)2230, -2545 ' feet 9825'-1 0300' 5100'-5700' feet Junk (measured) 41 60 ' -4590 ' feet ' N/A Cemented Measured depth 240 sx AS I , 225 sx Class G 290 sx Class G 260 sx Class G Wue Verticaldepth 250 sx AS il 78'MD 1000 sx AS II I & 2425'MD 250 sx AS II 78'TVD 2259'TVD Perforation depth: measured None RECEIVED true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Alaska Oil & Gas Cons. Commission Anchorage Description summary of proposal ~ Detailed operations program [] BOP sketch C 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~LJ,,,L~- TitleAssociate [ng~ne~r Commission Use Only ( J G ) Conditions of approval Approved by Date SA2/65 I Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI by order of ; ?,~ ~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 1H-5 APPLICATION FOR SUNDRY APPROVALS ARCO Alaska, Inc., requests an extension of "suspended" status for Kuparuk Well 1H-5. Evaluations are currently in progress to determine the future use potential of the well. ARCO Alaska, Inc., also requests an exception to the surface plug require- ment of 20AAC25.110(C). The well was drilled to TD without setting 7" casing. The 10-3/4" casing was set at 2425'. There is a plug at 2230' and no perforations in the well. SA2/65a 06/24/87 LE~ENO & NOTES 54 a I S, F~OTRACTED SECTION CORNER. FUTURE WELL LOCATIONS. PE~rMANENT S~RVIry LOCATION ~UMENTS EXISTING WELLHE~ F~ND THiS AS*BuILT S~T ~LEVATI~. PAD OIM(NSIONS S~WN A~E MEA~S TAKEN AS-~ILT SURVEY ~TES. ELevATIONS I~WN ~ REPRESENTATIVE ELEV- ATIONS TAKEN F~OM AS-BUILT SURVEY NOTES. ELEVATIONS ARE BASEO ~ S~IO-~ VERTICAL DATUM. a~ C~ROINATES ~N ~E ~ASKA ST4TE C~OINATE SYSTEM, ZONE 4. SECTI~ C~NER~ S~WN ARE BASED ~ ~ASKA P~OTRACTIOH SYSTEM, THE ENTI~E A~A LIES WITHI~ TI2N, ~10~, UM;AT MERIDIAN, ~ASKA. ALL AZI~TH ~N A~E ALASKA STATE ~ANE GRID AZIMUTH ALL DISTANC[ ~N ARE T~E ~STA~ES -/N~%sel,]e~.sea J I ----1 ~' 5, Bel 330 44ol ' ~.E_, S4e~90,:e6e /.)~..~"~ ~..[YOfl~ CE~T~ATE K~AR~ P~JECT '- AS-BUILT DRILL SITE "I-H" las a. Ine. I --I"''r'"~'/-= AZ ITS'47'S$#-1750.0 TRUE m ! ~___._..._.~ ':_.- .... : I t I I ~ CONDUCTOR HOLE LOCATIOHS WITHIN SECTION I I I ARCTIC SURVEYING, INC. I I I I ENGI#EE nl fL A#NEII$ I II0"" -'".'-' I'c'". "'-' ,- --. ~-.,".,I '/',/" I'"l°''"" '" "' I c...o .,. · - I '"' I;;I 0" ' HSK- 3 2 t-~ I! ,.-,. o.. GEODETIC CO'JRDItIATE9 LAVlTUUE LONGITUDE · ,_o: ,. ""'-'l-,4,. ,s' :_o: f!: ..4]..,' ~s"~,.~',' ~0- si' 21.4;6] i4.. ss' 70- ~1' 20 ~99:1 149" :35' ~01B~'B" 70' 21' 20.0G4"~ 149' ~' STAT~PLANE YLNI S.tBO, 174.54 5,990 ,US4 .OS S,S 79,95S. I $ 5,979,B I 5.46 SoS FO,re?.20 S,BBO, J4e. I0 x~EI ,. ~49,s4s.27 ~49 ,~)si .~o S49,560.55 .549,569.18 549,2 lO 20 . 549 t201.04 54.9,192. I0 549, Ia 3.14 FNL . FE L 528 I'803 648 I 796 lee I O I I I 114O ~91 I 114e B/'1 I ' 1156 .2 I ,64 ',3, June 10, 1987 . Telecopy No, (907) 276-7542 Randy Ruedrich Manager Drilling ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-.0360 Re .' Application for suspended well status: ARCO operated wells SCU 13-3, KRU 1H-5~ PBU DS 4-23, PBU DS 4-29, PBU DS 15-22, Dear Mr. Ruedrich: A review of our records shows the above referenced wells as suspended prior to April, 1986. In April, 1986 the Alaska Oil and Gas Conservation Commission (AOGCC) revised its regulations concerning suspended well status. Suspension of these wells has~ not been applied for under current AOGCC regulations, Following is a brief summary of the status of each well, derived from AOGCC files. Soldotna creek Unit 13-3 Our records show a completion report with suspended status dated 1/28/76. This well was originally operated by ChevrOn, and has only recently been operated by ARCO.. A letter to Chevron dated 6/4/81 requesting a status update was never answered. ~..Kuparuk River Unit 1H-5 (formerly IH-I) Our records show a completion report with suspended status dated 8/9/82 No suspension status extensions were ever received Prudhoe Bay Unit DS 4-23 Our records show a completion report with suspended status dated 2/13/86, A sundry approval to perforate was approved 5/16/86, but no subsequent report has been received. Our records indicate the well has not produced. Mr. Randy Ruedrich June 10, 1987 Page 2 Prudhoe Bay Unit DS 4-29 Our records show a completion report with suspended status dated 2/12/86. A sundry approval to perforate was.approved 6/2/86, but no subsequent report has been received. Our records indicate the well has not produced. .P. rudhoe Bay Unit DS 15-22 Our records show a completion report with suspended status dated 4/21/81. A sundry approval to complete was approved 7/31/85, but no subsequent report has been received. Our records indicate the well has not produced. By this letter the AOGCC is requesting you to submit Form 10-403, Application for Sundry Approval, with justification for classifying these wells as suspended per 20 AAC 25.110. Please call Russ Douglass at 279-1433 if you have any questions. Sincerely, -/ , :02-" Lonnie C. Smith Commissioner Jo/A.RAD.38 ALASKA OIL AND GAS CONSERVATION COMMISSION Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;..3192 TELEPHONE (907) 279--1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject Well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman AR C O Alaska, I nc['~ Post Office ~Ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As,Built Location Wells 1-8 Dear Elaine' Enclosed is an as-built location plat If you have any questions, please call Sincerely, Plat - 1H-Pad for the subject wells. me at 263-4944. . Gruber Associate Engineer JG6/L20'tw .Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office ux 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1983 Mr. Lonnie Smith State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Re: Subsequent ReDorts, Sundry Notices, Your Letter 10-12-83 Dear Mr. Smith: I have researched the wells you asked about and the status is as follows: Well ARCO Date Comments Kuparuk l-B1 1-8-83 Kuparuk 1-H1 Kuparuk 1-E28 4-21-82 9-23-82 A change notice was prepared. Copy dated 1-8-83 is attached. The clean out attempt was never done. This well number was changed to 1H-5. See attached not ices for 1-H1 and 1-H5. Subsequent notice was prepared 4-5-83. See attached copy. Kuparuk WSW-1 8-5-82 I am collecting the injection dates and volumes. I will submit the subsequent notice within two weeks. Please call me at 263-4527 if you Charles K. House Kuparuk Operations Coordinator CKH/kmc have any questions. Attachments cc: W.L. Crandall/M.D. Schall R. S. MaY R. A. Ruedrich ALASKA OIL AND GAS CONSERVATION COMMISSION October 12, 1983 Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE (907) 279.'-1433 Mr. Charles House Kuparuk Operations Coordinator ARCO Alaska, Inc. P. O. Box t00360 Anchorage, Alaska 99510 Re: Subsequent Reports, Sundry Notices and Reports on Wells (Form 10-403) Dear Mr. House: For the following list of "Notice of Intention To:" Sundry Notices and Reports on Wells (form 10-403) this office does not have on record the "Subsequent Report of:" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. Wel 1 '~ Kuparuk 1-Bi 10-22-82 ~uparuk W~W-1 08-05-82 0~~~KKuparuk 1E-28 09-23-82 ~0~ ~ 1H-1 1-82 uparuk/~, ~?~H...~04-2 sincerely, commis s ione r ARCO Date LCS/HJH :lc: 105:D1 OCT 2, 0 Brief Description Of Intention Clean out' wellbore with coiled tubing unit. Inject water. Change kick-off depth. Change surface casing setting depth. August 9, 198.2 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr Chatterton' Enclosed are monthly reports for July on these drill sites' 2-25 13-25 18-3 2-26 13-30 1E-15 6-17 13-33 1H-3 6-18 14-21 1H-4 6-19 18-2 Also enclosed are three subsequent sundry reports for Kuparuk 1H-5 and completion reports for' 13-21 15-1~ 13-24 18-1 13-26 1E-14 14-17 :~1H-5 14-22 The gyroscopic survey for DS 2-22 needs to be reran; a com- pletion report for this well will be submitted when the approved survey is received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:sm Enclosures GRU1/L61 ,a./aska 0il & Gas Cons. ARCO Alaska. Inc. i~ a subsidiary of AllanlicRichheldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20727 4. Location of Well Surface: 528'FNL,803'FEL, Sec. 33, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 6. Lease Designation and Serial No. ADL 25639 ALK 464 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-5 11. Field and Pool Kuparuk RiverField Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., has officially changed the well number designation from IH-1 to IH-5 as proposed in our Sundry Notice dated 04/26/82. 14. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Si§ned C~ ~: Title Senior Dri 11 ing Engineer The space ~¢ow for C,~ission use Conditi°nsVof Appr°v~1, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~80 GRU1/S10 Sub.mit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~l STATE OF ALASKA & ALASKA L AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator DRILLING WELL [] COMPLETED WELL [] OTHER[~JX ARCO Alaska, Inc. 3. Address P, 0, Box 360, Anchorage, AK 99510 4. Location of Well Surface: 528'FNL,803'FEL, Sec. 33, T12N, RIOE, UN 5. Elevationinfeet(indicate KB, DF, etc.) 85' RKB 12. I 6. Lease Designation and Serial No. ADL 25639 ALK 464 7. Permit No. 82-38 8. APl Number 50- 029-20727 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-5 11. Field and Pool Kuparuk RiverFiel d Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing ~[~ Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · In our Sundry Notice, dated 05/10/82, we proposed a]tering the 7" casing program for the subject well. Subsequently, we drilled to TD without setting 7" casing. The 10-3/4" surface casing has been suspended for future use. J ECEIVED UG 1 ¢ J982 Gas Cons. Co~rnission AnChorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b/. w f~?m~/~io'n use -~-~-~ti°ns of APprOVal ~ Title Senior Drilling Engineer Date Approved by.. Form I0-403 By Order of COMMISSIONER the Commission Date Rev. 7-1-80 GRU1/S9 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA O~v ALASKA LANDGASGONSERVATIONG ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER IZP( 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20727 4. Location of Well Surface: 528'FNL,803'FEL, Sec. 33, T12N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 6. Lease Designation and Serial No. ADL 25639 ALK 464 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-5 11. Field and Pool Kupa ruk RiverFiel d Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The well was spudded on 04/26/82. The 13-1/2" hole was drilled to 2443'. 10-3/4" casing was ran, cemented and tested with shoe at 2425'. '~,.qO ~1,?$/0# 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~J/~~/ TitleSeniOr Drilling Engineer ~.. ~- r~m/'- ~ The space b~/w ~r Co.f_.. ission use Condition~/'of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/S11 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA( '-AND GAS CONSERVATION C~r IMISSION WELL COMPLETI i I OR RECOMPLETIOK riEPORT AND LOG 1. Status of Well Classifiqation of Service Well OIL [] GAS [] SUSPENDED ~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20727 4. Location of well at surface 9. Unit or Lease Name 528' FNL, 803' FEL, Sec. 33, T12N, R10E, UM ~LOCATIONSI Kuparuk River Unit -- tl VEPdFiED L 10. Well Number At Top Producing Interval r-_ . N/A i Surf.---~-~l 1 lt-5 . At Total DepthlB' H.~ 11. Field and Pool -- 574' FNL, 775' FEL, Sec. 27, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKBI ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 04/26/82 05/11/82 05/18/82I N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10840'HD,7152'TVD 2230'ND, 2077'TVD YES IX-I NO []I N/A feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/BHC/GR/SP, FDC/CNL/Cal, FDC/CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 78' 24" 250sx AS II 10-3/4" 45.5# (-55 Surf 2425' 13-1/2" 1000sx AS III A 250 sx AS II 24. Per~orations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None .... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9825'-10300' 225 sx Class G plug 5100'-5700' 290 sx Class G pluq 4160'-4590' 260 sx Class G plug 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD I~ ........... Flow Tubing Casing Pressure CALCULATEDal~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ', I GPU 1/WC20 Form 10,407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~'~' ~g:7" NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ! N/A 31. LIST OF ATTACHMENTS Dri 11 i ng Hi story ~ Di recti onal Si ngl e-Shot Survey (2 copi es ) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -1 £- /- , /,/ 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 injectio0, water injection, steam injection, air injection, Salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevatiOn is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 ~and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the Cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 1H-5 DRILLING HISTORY NU hydril & diverter. Spudded well @ 1130 hrs, 04/26/82. Drld 13-1/2" hole to 2443'. Ran 59 jts 10-3/4", 45.5#/ft, K-55 csg w/shoe @ 2425'. Cmtd 10-3/4" csg w/lO00 sx Arctic Set III & 250 sx Arctic Set II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. POH; bit tore up. TIH w/impression block - tag bottom @ 2452'. TOH - no · impression. TIH w/mill & milled 5' - no junk. TOH w/mill & LD same. Drld 8-3/4" hole to 9327'. RIH w/survey tool; overshot unlatched & jammed open. POH w/overshot & reworked. RIH w/overshot; latch onto survey tool & recovered. Cont drlg 8-3/4" hole to 10840' TD (05/11/82). Ran DIL/BHC/GR/SP f/7950'-2350'. TIH to 10840'-40' fill on btm. Pumped Hi-Vis pill. Worked pipe-tight hole. Circ & cond mud. Ran BHC/DIL/GR/SP & FDC/CNL/Cal. Ran FDC/CNL/GR- log unable to get past 10200'. TIH w/600', 3-1/2" stinger & 5" HWDP & DP to set cmt plugs. Circ & cond hole for cmt. Pipe set @ 10300'. Pumped 225 sx Class G cmt balanced plug #1 w/top @ 9825' & btm @ 10300'. Pulled 6 stds & attempted to rev circ. TOH to 5700'; placed balanced cmt plug #2 w/290 sx Class G cmt~ - top @ 5'100' & btm @ 5700'. TOH to 4590' pumped 260 sx Class G cmt balanced plug #3 w/top @ 3979' & btm @ 4590'. Circ hole clean. TOH & LD DP & HWDP. Circ & clean out cmt from DP. TIH; tagged cmt plug @ 3979'. Broke circ & TOH. LD 5" HWDP to 2715'. Pumped 240 sx AS I. Balanced plug - ok. Reverse out - LD 5" DP. TIH to tag cmt; tripped to 2363' no cmt. Circ & cond mud. TIH to · 2550'; tagged soft cmt. TOH; TIH; tagged cmt @ 2570'. Pulled up to 2545' & CBU. Pumped 240 sx AS I; balanced plug - ok. TIH. Tagged cmt @ 2230' PBTD. Pulled up to 2200' & circ out contaminated mud - reverse circ H20 wash followed by 10.5# brine displacement for freeze protection. Displace top 620' of hole w/diesel. ND BOPE. NU suspended wellhead. Released rig @ 0100, 05/18/82. RECEIVED JG:llm 08/06/82 GRU1/DH32 AUG 1 ~ 1982 A~.ska Oil & Gas Cons. Commission Anchorage ARCO A[;AS~K'¢e, INC + PAD H, WEI..L. NO,*4,~" DSS ............... ~..~.p_A_~_y.~_ F'__~E_:k ~_Z~ ....... !.~_OJ~])_~ ..... ~ L 0 F'.E, A~.. ~.S~-~ A JOB NO DSS, 0-10065 MD, DRIL. L. ER~ R F'ANCHER RIG: F'ARKER 141 I)ECL. INATIONI 30 1/2 DEG. EAST ' ...... ~ ~ · . ...... : ........................................................ ....... ,-~ ..... ~ ....... ~ ....................................... RECORD OF: SURVEY ....................../~, ' ~ ~ ~ ..-"', ! RA]OIUS OF CURVAI'URE MEI'HOD [L.IF'ARUK FIELD, NORI'H SL.C~F:'E, AI..ASKA COHF:'UTATI~N PAGE NO. 1 ~0482D0309 TINE [ ~-, l'E 15:45:05 13-'HAY-82 iEASLIRED DRIFT DRIFT COURSE DEPTH ANGI...E DIREC'I'ION LENGTH '-FEET .................. 17.i ............... N ...................... -D ........... -h- ........... WEE"I ..... T-~-LJE VERTICAL VERTICAL SUBSEA DEF'TH SECTION TVD FEET ........FEET FEET RECT COOR A N G U D I N A FEET L A R C L.O S U R E I';OGL[:'~ T E S I_'; I STANCE DIRECTION SEVERI FEET lq M [;G/ldO! O. 0 0 0 0 O. 0.00 0.00 -85.00 500"; ........... 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COMPUTATION I-~lGE NO, '2 'AD H, WELL."NO: '5 DSS JOB NO~ A0482DOSO~ TIME DATE 'UF'ARUK FIELD, NORTH SLOF'E, ALASKA 15;45;05 13-MAY-82 TRUE iEASURED TiRIF'T DRIFT L. uUKoE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L O S U R E DOGLE(_ I)EF'TH ANGLE DIRECTION LENGTH DEF'I'H SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI'~ 6654 50 15 N 29 30 E 471 4567,56 ~' , , . 4~,~_1.,88 4482.56 2860.41 N 3105 5~' E 4222 16 N 47 21 E 0.32 48 ............... ...... ......... ..... .... ......... ..... 7-1~6. 49 45 N SO SO E 278, 5076,S4 4791.18 4991.S4 SS7S.75 N ~404.08 E 4792.70 N 45 15 E 7690. 51 45 N 34 0 E 254. 52S7,04 4981.61 5152~04 3540.07 N ~509.02 E 4984.51' N 44 45 E 8415. ~.~ 45 N Z, 7 0 E: 47~. ~';6:'~,0~' 5~':'45,91 559~.09 4008 51 N 4~ ........~. oo ~.95 E ~o3.08 N 43 48 E 0.50 ,. ~ ,~ -~ .... ~?~ .... :~ : ..... "z .... ', , -Z~: ~. ~.,~ ~: ~.~, ' ~-R=: ...... ~ ................ ~q~'~-~:'-~ ........... '~'""~' .... ~/' . ~:' 880~, ~.~, 4.~ N 4~. 9277. 52 .0 N 4S SO E 474. 619S.59 62SS.99 6108.55' 4521.J~S N 4S05.16 E 62'1S.14 N 4S S6 E 0,S7 9592. 51. 45 N 50 SO E 515, 6S88.07 6481.62- 6SOS.07 4~,90.2"~ N 4486,27 E 6490.S6 N 43 44 E 1.75 10065. 52 45 N 62 S0 E 47S. 6677,65 6849.48 6592.65 4896.26 N 4797.56 E 6854.9~ N 44 ~ ~ ~,~-. F1N*.~L CLOSURE - DIRECTION · N 4 .... . ~ , , , : ~ : ! ~ ~ ~ ': i ~ ~ ii i : ~ I t i i ! '. , i / ' · ! i ; : ~ i : I~ I ~ I I i , ' ~ ~ ~ i ' ! ~ , , ' ...... ¢- -': ................. *-% .... 4 ........ !" d'--f ......... t--'r ....... r ...... r-1 .............. 4 .......... ~ ......... r ...... . .... ~ .... ~ ~ ....... : '--r--~ · ' ~ ; .... t~i .... ¢ ' -h-! - i: .... "'? C ~-'hi ...... ',-'--t-"~- t ..... r'-~I-'i ........ ;1' ~ - ~--:--1-4%-? ..... ~--~---t--~ ....... F'-*'-~-'f'":-!- r .... ~ ...... 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IT ' ..... ........ ~_l~ ......... ~ ...1,._.~_.,: ~ : ..... _~__ _ .~ _~ ....... i..--4..1.1111 ....... ~--~ t"-+ .... ~--+- ~I ~ : iI i [~ ~ i i ~ L - ...... ~-~--4--~ .... ~.~-~- ~T ..... · '~-'":--7::_: ................ : ............... ~ ................................. Suggested foTM to be inserted in each "Active" well folder to d~eck for timely compliance with ~ur regulations. Operator~ We~l N~ a~d ' ' Reports and Materials to be received by: Required Date Received Remarks Ccmpletion Report Yes Wel 1 .History Yes · · Mud Log ............. · , .. Core Description ,, ,, ........... ,~ . ...... . ...... ,, .... ......... ~. ,....f- ,, Inclination Survey 4/'.~,. , ,. . , ,, , , ,,,, , Drill St~ Test Re~s ' , ., ~/'~/~., ..... , __ :.,..,..~'~ ~,, Pr~u~on T~g Re~s , . ~ , . _ ~ . ,. ~. · ,.. .... , , . .. , ,, ~ . . · ....... wUP~RU~ ENGiNEERiNG TO: D. W. Bose/Lorie L. Johnson DATE: ,~ ~ WELL NAME: ~~Transmitted herewith are the following: PLEASE NOTE' Y - - ~ I ~ F - FILM, T - TAPE RECEIVED DATE: JUL 1 2 1982 PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. Alaska Oil & Gas Cons. Commissior ATTN: LORiE L. JOHNSON - AFA/~'~_[ P. O. BOX 360 ANCHORAGE, AK 9'9510 KUPARUK ENGINEERING TRANSMITTAL TO: ~. ~~ FROM: D. DATE: &///~.. WELLNAME: Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, W. Bose/Ann Simonsen F - FILM,~ TAPE RECEIVED JUN - 2 ~982 RECEIPT ACKNOWLE ' ~ l_ .SEt RETURN RECEIPT TO: ARCO.ALASKA,. !NC.. , ATTN: ANN SIMONSEN AFA/311 P. O. BOX 360.. ANCHORAGE, AK 99510 Alaska Oil & Gas Cons. Commissior DATE: Anchorage, ARCO Alaska, Inc. Teiepi~one 907 277 5637 May 26, 1982 Hr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: StaLe Reports - Kuparuk Dear Mr. Chatterton: Enclosed are well completion reports for the following drillsites: 1A-16A (Sidetrack) 1E-9 1E-10 Also enclosed are monthly reports for April on these wells: 1E-11 11H-5:~ Sincerely, P.A. Van Dusen Regional Drilling Engineer PAV/JG: 11m Enclosures GRUC/B4 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82- 38 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o- 029-20727 4. Location of Well at surface 528' FNL, 803' FEL, Sec. 33, T12N, R10E, L~4 (Approx.) 5. Elevation in feet (indicate KB, DF, etc.) I 6,J_ease Desionationand Serial No. 815' RKB I ADL 25639, ALK 464 9. Unit or Lease Name Kuparuk River Field 10. Well No. 1H-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of April ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1130 hrs, 04/26/82. Drld 13-1/2" hole to 2443'; ran, cmtd & tstd 10-3/~" csg. Drld FC, cmt, FS & 10' new form. as of 04/30/82 See DrillingHistory 13. Casing or liner run and quantities of cement, results of pressur9 tests 10-3/4", 45.5#/ft, K-55 csgw/shoe @ 2425'. Cmtd w/1000 sx AS III & 250 sx AS II. See Drilling History 14. Coring resume and brief description N/^ 15. Logs run and depth where run None to date RECEIVED 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A MAY 2 6 i982 ' Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~t~, ~~ Sr Drilling Engineer __ TITLE ' DATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with t'he Alaska' Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 1H-5 Drilling History NU hydril & diverter. Spudded well ~ 1130 hfs, 04/26/82. Drld 13-1/2" hole to 2443'. Ran 59 its 10-3/4", 45.5#/ft, K-55 esg w/shoe ~ 2425'. Cmtd 10-3/4" csg w/lO00 sx Arctic Set III & 250 sx Arctic Set II. ND hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BORE & tstd to 3000 psi - ok. Tstd esg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok, as of 04/30/82. 3G:llm RECEIVED o5/2o/ 2 GRU6/A28 MAY 2 1982 Alaska Oil & Gas Cons, Commission Anchorag~ MEMORAi,DUM Stm of Alaska TO: Chat ~h~t~t~rtmn ,. DATE: May 24, Chai~ ~~ FILE NO: 108A/Q THRU: Lonnie C. Smith Commissioner TELEPHONE NO: F,OM: Bobby FoSter~~[, Petroleum Inspector 1982 SUBJECT: Witness Cement Plug Setting on ARCO's 1 H-5 for Well Bore Suspension Sec. 33, T12N, R10E, UM Permit #82-83 May. !5, 16,.ii_7..,_. 1982 - I went to ARCO's 1 H-5 after being contacted bY Mike Minder concerning the ce~nt plug setting at this well. The first cement plug conSisted of a 225 sack slurry - 15.8 ppg - class G cement set from 10,300" to 9,825'. The D.P. was then pulled up to 5700' and a 290 sk. slurry - 15.8 ppg - plug was set to 5100'. The D.P. was then pulled up to 4550' and a third plug consisting of a 260 sk. slurry - 15.8 ppg - Class G cement was set. This plug is just above the West Sak sand and below the Ugnu sand. After ~aiting on cemnt 9 hours this plug .was tagged at 3979' with opened D.P. With 10,000 lbs. of D.P. weight. The nest plug conSisted of 240 sks of Arctic Set I ~15.7 ppg slurry- from 2,725 to 1981. After w.o.c, for eight hours we tagged the cemnt at 2,550'. This is 126' below the 10 3/4" casing shoe. Another plug ~as then set from 2,544' to 2,230' using 240 sks of Arctic Set I 15.7 ppg slurry. After waiting on cement eight hours this plug was tagged at 2,230 with 6,000 lbs of weight with open end D.P. In summary I witnessed the cement plug setting on ARCO's 1 ARCO Alaska, Inc.t ~"~ Post Office BOx 3~u Anchora§e, Alaska 99510 Telephone 907 277 5637 May 19, 1982 Hr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK 99501 SUB3ECT: Sundry Notice for DS 1H-5 Dear Mr..Chatterton: Enclosed is our Sundry Notice of intent to suspend the 10-3/4" surface casing for future use. This matter has been discussed with Mike Hinder, AOGCC. Sincerely, Senior Drilling Engineer OBK: OG/llm Enclosures GRUS/AiO ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany RECEIVED MAY 2 1982 Alaska 0il & Gas Cons. Commission Anchorage A~ ...... STATE Of ALASKA (~' ¢ ...... ALASK ''~ ~ND GAS CONSERVATION C ''~''''SSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER>E] 2. Name of Operator 7. Permit No. &RC0 Alaska, ;[nc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50-029-20727 4. Location of Well Surface: 528' FNL, 803'FEL, Sec. 33, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 85' RKB 54.5' Pad ADL 25639 ALK 464 12. 9. Unit or Lease Name Kuparuk River Field 10. Well Number 1H-5 11. Field and Pool Kuparuk R±ver Field Kuparuk River 0il Pool (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other tm Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). As proposed 05/15/82, to Mike Hinder of AOGCC, ARCO Alaska, Inc., has plugged back the 1H-5 wellbore drilled to the permitted bottomhole location. ARCO Alaska, Inc., intends to suspend the 10-3/4" surface casing for future use. Cement plugs were spotted as follows: Plug ttl 225 sx "G" 10300~ to 9825' Plug 1t2 290 sx "G" 5700' to 5100' Plug tt3 260 sx "G" 4590' to 3979' Plug 114 240 sx ASI 2715' to 2570' Plug 1t5 240 sx ASI 2545' to 2230' Kuparuk Plug West Sak Plug UGNU Plug Kickoff Plug Surface Casing Plug The 10-3/4" shoe is set at 2425' MD. 10.5 ppg brine was left from 2200' to 620'. Diesel was left from 620' to surface. The well was left with a 16-3/4" x 11" crossover, an adapter bonnet, and a 3" valve as a wellhead. REEEIVED MAY 2 1982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify_that the foregoing is true and correct to the best of my knowledge. Signed 6/~.~~u~ ./~, ~ Title Sr. D~lg. Engineer The space be f Com sion use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate THRU ' MEMOR/-,NDUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Cha/~te/rton~ D^IE: May 13, 1982 Ch~Jf~ n~/ --~,/' FILE NO: 108A/N Lonnie C. Smith ~~ Commissioner TELEPHONE NO: FROM:Edgar W. Sipple, J:~~- Petroleum Inspecto: SUBJECT:witness BOPE Test on ARCO 's~_i-H5~ Pad Parker Rig 141 Sec. 27, T12N, R10E, MUM Permit No. 82-38 Check Diverter System on Nabor's Rigs 27E and Rig. '17 on Conoco's Milne Point Wednesda.y, April 28, 1982 - I left Anchorge for Prudhoe Bay via 'alaska'" ~ir'lines a%" 2-'05 ~.m. arriving at Prudhoe Bay-at 3::45 p.m. Upon arrival at ARCO's Pad l-H-5; Parker Drilling Company's Rig 141 was in the process of running casing. At 11:00 p.m. they were stuck with the casing until 4:30 a.m. Thursday, April 29, 1982 - I left Parker Drilling Rig 141 and ~nt' tO N~:'s Dril~ng Rig 27E and Rig 17 and Conoco's Milne Point to check out the diverter systems. They were in compliance with APi RP53 and State of Alaska regulations' I returned to Parker Rig 141 at 5:00 p.m to conduct the BOPE test. F~rida¥_, April. 30, 1982- The BOPE test commenced at 10:00 a.m. and was concluded at 12:00 p.m. this date. There ~re no failures, the drilling rig was exceptionally clean. I filled out the A.O.G.C.C. report which is attached. In summary, I witnessed the diverter systems on Nabor's Drilling Rig 17 and 27E and at Conoco's Milne Point. I also witnessed the BOPE test on ARCO's l-H5 pad, Parker Drilling Rig 141, in which there ~re no failures. I left Parker Rig 141 and went to Rowan's~ Rig 29 to a BOPE test. , ~ ~TA%% OF ALASK,t "ALASKA OIL% fAS CID~%ERVATif)~~. C~i~tlSSION B.O.P.E. Inspection Rclx~rt _. erator ~ ~ C ~ ,ii /- /4 .f' cation: Sec_~? T_/,gtJ il ]inq Contracto~ Representative ~A e ~ ~",//¢"7'"'7;'"'~ Permit'# CZ-- J'~'. /~2Sasing Set @ ~2~z~2¢ ft. Rig # 7 q/--Representative 4 I /~,,,~3/Vk As.~ cation, Ceneral ~ /< 11 Sign ~F~ neral Housekeeping__~lK serve pit d ~ TeSt Pressure /.goo 3000 _~o00 ACCL?~UIATOR SYSTEM Full Charge Pressure ~ 0 · Pressure After Closure_/~3-~> Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: psig psig / mined sec. ~emote o~ Blinds switch cover Kelly and Floor Safety Valves - Upper Kelly / Test Pressure Lower Kelly. / Test Pressure Ball Type '" Test Pressure Inside BOP u-" Test Pressure ~J / A Choke, Manifold.. b-"- Test Pressure ~ooo No. Val~ms ¢ No. flanges. Adjustable Chokes (12 ~$ ~fdrauically operated choke st Results: Failures Test Time' ~..hrs.., 0 /~ ~/~ oair or Replacement of failed equipment to he made within---~ ~days and spector/Conmi~sion office notified. stribut ion ig. - AO&4CC - Operator - Supervisor Post Office .360 Anchorage, Alaska 99510 Telephone 907 277 5637 Hay 11, 1982 Mr. C. V. Chatterton Commissioner State of Alaska AIaska Oii & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBOECT: Sundry Notice for DS 1H-5 Dear Mr. Chatterton: Enclosed is our Sundry Notice of intent to alter the casing program on well 1H-5. Since we estimate starting this proposed work on May 11, 1982, your earliest approval will be appreciated. Sincerely, 3. B. Kewin Senior Drilling Engineer JBK:OG/hrl Enclosures GRUS/A11 RE£EigE ) MAY 1 t 1982 0il & Gas Cons. C0mmissi0~ ~chorag= ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS ,L AND GAS CONSERVATION C .dMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER~[] 2. Name of Operator 7. Permit No. ARCO Alaska, [nc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50_029-20727 4. Location of Well Surface: 528' FNL, 803' FEL, Sec. 33, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 83' RKB 5/~,5' Pad' 12. I 6 . Lease Designation and Serial No. ADL 25639 ALK Z~6Z~ 9. Unit or Lease Name Kuparuk [liver Field 10. Well Number 1H-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing ' [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes altering the easing program for the sUbject well as follows: 7" 26#/ft L-80 easing will be ran from 28' MD to 4500' MD in place of 7" 26#/ft, K-55 7" 26#/ft K-55 will be ran from 4500' MD to TD This program was discussed with and approved by Blair Wondzell on 05/10/82 at 3 p.m. Estimated start: May 11, 1982 RECEIVED MAY t 1 82 Subsequent Work ~,e9o~tec~ ~/~.~/~. ~laska Oil & Gas Cons. Commission ' __ ~ No. ~ Da~ Anch0rag0 14. I hereby certify that the foregoing is true and ~rrect to the best of my knowledge. SignedfZ~~ ~,~~~ Title Senior Drilling Engineer The space below for Commission use Conditions of Approval, if any:, Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 GRUS/AIO Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B Anchorage, Alaska 99510 Telephone 907 277 5637 April 26, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBOECT: 1H-1 Sundry Notice Dear Mr. Chatterton: Enclosed is our Sundry Notice of intent to change the well number designation of 1H-1 to 1H-5. If you have any questions, please call me at 263-4970. Sincerely, Sr. Drilling Engineer 3BK: 3G/hrl Enclosures GRU4/AIO RECEIVED. APR 2 61982 A~aska 0il & Gas Cons. Comm{ssi0rl Anchorage ARCO Alaska, inc. is a subsidiary of AtlanticRichfieldCompany O(L STATE OF ALASKA ALASKA AND GAS CONSERVATION CO. ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, ;[nc. 82-38 3. Address 8. APl Number P. 0. Box 360, Anchorage,. AK 99510 50-029-20727 4. Location of Well Surface: 528' FNL, 803' FEL, Sec. 33, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 54,5' Pad I6. Lease Designation and Serial No. ADL 25639 ALK 464 9. Unit or Lease Name Kuparuk River Field 10. Well Number 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). - ARCO Alaska, Inc., proposes changing the well number designation from 1H-1 to 1H-5. This matter was discussed with and appr.oved by 3im Trimble, AOGCC, on 0/4/23/82. Kuparuk well 1H-5 was spudded on 04/26/82. RECEIVED · ,AP 2 i982 Alaska Anchorage 0)~ & Gas Cons° Comrnisslon Date 14. I hereby cer/t~y that the foregoing is true and correct to the best of my knowledge. Signed//~____.Z/Zz~¢'¢/'~ ~~~'~_.- Title Senior Drillinq Enqineer The spac~lo~ ~mmi~si~n~se ConditiOns of Approval, if any: ~p~OW~.~ '.Cp~ ~eturned BY teN'tiE C. SMITfl .v Order of Approved bv COMMISSIONER the Commission Dete~ Form t0-403 GRU4/A1 1 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate Post Office .~ $60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 21, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi s si on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Sundry Notice for Kuparuk-~44-~t Dear Mr. Chatterton- Enclosed is our Sundry of Notice of intent to change the 10-3/4" casing setting depth from 2625' MD to 2550' MD. Since we estimate spudding the well April 26, 1982, your earliest approval would be appreciated. Sincerely, ~ ~B~xKe_wi n ~ Senior Drilling ~ngineer JBK'GRU/hrl Enclosures GRU4/B7 t 19Bt Gas Cons. commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCon~pany STATE OF ALASKA ALASKA LAND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHERxC] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-38 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o-029-20727 4. Location of Well Surface' 528' TD: 1059' FNL, 803' FEL, Sec. 33, T12N, RIOE, UM FNL, 991' FEL, Sec. 27, T12N, RiOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 54.5' Pad I6. Lease Designation and Serial No. ADL 25639 ALK 464 9. Unit or Lease Name Kuparuk River Field 10. Well Number 11. Field and Pool Kuparuk R~ver 0~1 Field Kuparuk R~ver 0~1 ?ool 12. (Submit in Triplicate) Perforate [] Alter Casing [~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or ComPleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes changing the permitted 10-3/4" surface casing setting depth from 2625' MD (2250' TVD) to 2550' MD (2205' TVD). This will ensure that the surface casing shoe is not set deeper than 700' TVD below permafrost (estimated @ 1535' TVD). Estimated spud' April 26, 1982. RECEIVED APR 1 1982 A~aska Oil & Gas Oons. ¢ommissio~ Anchorage J14. I hereby certif~,y that the fOregoing is true and correct to the best of my knowledge. Signed//~/~~~,.~~/.-.~.~' _/ Title Senior D ri l ling E ngi neer ace~o~o r~i us~" ,, The,,sp ConditiOns of Appr~l, if any: Date Date Form 10-403 GRU3/B30 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate April 9, 1982 Mr. Jeffrey B. liewin Senior Drilling lingineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Kuparuk River Fi eld ~ /H",~' ARCO Alaska, Inc. Permi t l~o. 8Z--38 Sur, Loc. 528'FNL, 803*ImEL, Sec 33, TI2N, RIOE, L~, Btmhole Loc. 1059'FNL, 991*FEL, Sec 2?, TII~N, l~10E, UM. Dear Mr, liewi n ~ Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a umd log are not required. A continuous directional survey is required as 'per Ii0 AAC 25,050(b)(5). If available, $ tape containing the dt~fiti.zed log .information shall be submitted on all logs for copying except experimental IotIs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drai.nage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16'.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). .Prior to c~ncing operations, you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to c~neing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would al so like to be notified so that a representative of the Co~ission may be present to witness ~r. Jeffrey B. 14ewin guparuk River Field lB-11 -2- April 9, 1982 testing of blowout preventer equipment before surface casint~ shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Ve~-y truly yours, C. V. Chat tert~)n Chatr~nan of f~Y 0~ O~ THE COM~SS~O'N Alaska Oil and Gas ~nservatton Co, lesion [~epartment of Fish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o encl. ARCO Alaska, InC. B{' Post Office $60 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1982 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Mr. Trimble- We are enclosing the appropriate diverter and 13-5/8" BOP stack diagrams for Kuparuk ~ per our telephone conversation of 4/6/82. If we can be of any additional assistance, please feel free to contact us at 263-4969. Very truly yours, ~To~m~!,assfl O' APR 0 8 ]982 ~cl~ora-g~ C°~[S=lon ARCO Alaska, ~nc. is a subsidiary of AtlanticRichfieidCompany 3-5/8" 5000 PSI RSRRA BOP STACK.~, · 1. 16" Bradenhead 2. 16" 2000 PSI x lC" 3000 PSI casing head 3. lC" 3000 PSI tubing head 4. lC" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill. lines 7. 13-5/8" 5000 PSI pipe rams 8. 13-5/8" 5000 PSI blind rams 9. 13-5/8" 5000 PSI annular . ACC~IULATOR CAPACITY TEST 1. ,CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACC~IULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TINE THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE RB4AIN- ING AFTER ALL UNITS ARE CLOSED WITH C~iARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. - le e I-" z_, '"'1 . ' .,:. IVED' 14. I ' ' ! ' APR08]982 'is. ~ Alaska 0il & Gas Cons. Commission16.. · Anohorag~ 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. .PREDETE~,IINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RU~ IN LOCK DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. TEST ALL C~,IPONENTS TO 250 PSI AND HOLD FOR lO MINUTES. INCREXSE PRESSURE TO 1SO0 PSI AND .OLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. ~',~.~, INCREASE PRESSURE T,O<'3000 PS/I~AND HOLD FOR 10 MINUTES. ~ CLOSE VALVES, DIRECTL~rl]PSTREAM OF CHOKES. BLEED D~NSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI D~NSTREAM. BLEED SYSTEM TO ZERO PSI. - ' OPEN TOP SET OF PIP£ PAMS AND CLOSE BOTTOM SET OF PIPE RAMS. ' INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN BOTTOM" SET OF PIPE I;LAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAI~AND TEST TO 3000 PSI FOR l0 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAHS AND RECOVER TEST PLUG.. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI[;G POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS A&4D INSIDE BOP TO 3000 PSI WITH KOO~Y PUMP. RECORD TEST INFO~MATION ON BLOWOUT PREVENTER TEST FORM SIGN ArID SEND TO DRILLING SUPER- VISOR. ' PERFO~4 C~IPLETE DOPE TEST ONCE A WEEK AND FUNCTIOt~LLY OPERATE DOPE DAILY. . Surface Dive~': ~r System LI 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pi t. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. ~20" bell 2ipple. P, ECEIVED 'APR 'Anchorage 16" Conductor Maintenance & Operation ~ . 1. Upon initial installation c'l~se annular ! preventer and verify that bal!l valves ! have opened properly. .. - I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours, ' t 3. Close annular preventer in i:he event that gas or fluid flow to surface is detected. If necessary, man'~ally over- ride and close ball valve to apwind rI' diverter line. Do not shut in well under any circumstances. ARCO Alaska, Inc. Post Office B~>~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 17, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS ~ Permit to Drill Dear Sir: Enclosed find the Application for Permit to Drill DS 1H-1 and the required $100.00 filing fee. Attachments 'include the following: a drawing of the proposed well bore, a drawing and description of both the surface hole diverter system and the BOP equipment including anticipated reservoir pressures. Since no wells are within 200' of the proposed well bore a proximity map has been excluded. In add~ition, please note that his well's bottom hole location will require letters of Non-objection from BP Alaska Exploration, Inc. and Sohio Alaska Petroleum Company. A copy of the replies from affected operators will be forwarded to your office as soon as possible. If you should have any questions, please do not hesitate to contact me at 263-4970 Sincerely yours, ~r ~~~g Engi neer JBK: AAC: 1 tc Enclosures RECEIYEi) MAR 2 2 ]982 Alaska 0il & Gas Cons. Commission A~chorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfietdCornpar~y [, STATE Of ALASKA (~,i ALASKA LAND GAS CONSERVATION C IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~[ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, AK 99510 4. Location of well at surface 9. Unit or lease name 528' FNL, 803' FEL, Sec. 33, T12N, R10E, UM (approx.) Kuparuk River Field At top of proposed producing interval 10. Well number 1443' FNL, 1403' FEL, Sec. 27, T12N, RIOE, UM ~ At total depth 11. Field and pool 1059' FNL, 991' FEL, Sec. 27, T12N, R10E, UM Kuparuk River 0il Field 5. Elevation in feet (indicate KB, DFetc.) ~LE. Lease designation and seria~ no. Kuparuk River 0il Pool 85' RKB 54.5' Pad D 25639 ALK 464 12. Bond information (see ~0 AAC 25.025) Federal Insurance Co. Type Statewide Surety and/or number 8088-26-27 Amount $500,000 ~ 13. Distance and direction from nearest town 14. Distance to nearest property or lease line '1 15. Distance to nearest drilling or completed 30 mi. NW Deadhorse miles @ surface 528 feet 0-7 well 11,375 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate Spud date 10280'MD, 7100' TVD feet 2560 05/07/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~.~.l::;j psig@ . Surface KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 51 oI (see 20 AAC 25.035 (c) (2) ~80 psig@E&55 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER ~ SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length! MD TOP TVD MD BOTTOM TVD (include stage data) 24 16 65# H-40 Welded 7~'~ ~'32' ~32' 110'I 110' 200sx P.F. ' i31' 2625" 13-1/2 10-3/4~ 45.5# ~K-55 BTC £5~4':.:"31 ~ 12250' 1000sx Fondu & 2'50sX ' I AS II 8-3/4 7 26# K-55 BTC 10250' 30' ~30' 10280'17100' 1100sx Class G cement i 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field, Kuparuk River 0il Pool deVelop- ment well to approximately 10280' MD, 7100' TVD. Selected intervals will be logged. A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole'. A 13-5/8", 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig.~' Ex- ~ected maximum surface pressure will be 2749 psig based on cooling of a gas bubble rising at constant" volume. The well will be completed with 3-1/2", 9.2#, J-55 buttress tubing. Non-freez!'/ng fluids will be left in uncemented annuli thru the permafrost interval. Selected intervals Will be perforated within the Kuparuk formation and reported on subse- quent reports. A downhole safety valve will be installed and tested upon conclusion of 23. I hereby c 'e~,j~ tha~'th~oregoing is true and-cforrec'~ to the best of my knov~ledge~' ' S,GNED L/J~ B~,~/ T,TLE Senior Drl(~. E naineer DATE , The space beyw f~ ~omfission us~ -- ~ " / -- CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required AP.I number r--lYES ~NO []YES ~NO /~.yES [-1NO 50- O ~-- , Permit number Approval date O~:r~-''~ ~ ~,,~r'"-T"-"~l~_q/~1~~. /'L_.---~ J SEE COVER LETTER FOR OTHER REQUIREMENTS. APPROVED BY ,COMMISSIONER DATE An~"{ 1 -q _ 1 .q~9. by order of the Commission Form 10401 Bev. 7-1-80 e,~,~ ~/~q Submit in triplicate ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3280 psig from RFT and pressure build-up data. This pressure @ 6370' SS = 6455' TVD will be balanced by 9.77 ppg mud weight. Normal drilling practice calls for 10.3 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 175 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2855 psi during drilling operations. Derivation assumes a gas kick at reser- voir temperature and pressure (160°F, 3280 psi), gas migration to the surface without expansion, and cooling to 80°F cellar temperature. This is well below the 5000 psi§ BOPE working pressure and less than the 3000 psi weekly test pressure. Pi ='pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf : volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion. Pi = Pf Pi~Tf Then Pf - "Ti" T--~ _ (3295 psia)(80°F + 460) Ti (160.~F @ 460) Pf = 2870 psia = 2855 psig CLC'hrl 03/19/82 CRA1/A20 SURFACE HOLE D IVERTER ARCO ALASKA SYSTEM INd. SCHEMATIC ~ IO" HYD. OPR. BALL VALVE ~ ~ WE,L,L BORE (SEE BETAIL) .,,," f..-..---- I0' NY?. OPR. BALL VAL,,VE /" ,/'-/" I ALL 90 TURNS ARE "TEE' ~ I CUSHION ~'~. ~1 I sue BASE--,, I _ I I I I I' I I V~LL (~) BORE , I I RESERVE PIT AREA FLOWL INE _ DR ILL ING RISER "'b 20" 20OO PSI WP ANNULAR PREVENTOR 20" CONDUCTOR PIPE "D ETA I L" 2026010203 ANNULAR PREVENTER BLIND RAMS PIPE RAMS ING SPOOL PIPE RAMS ' MAR222982 Alaska Oil & Bas Oons, Cornrnissior~ Anchorage 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a~250 psi low pressure test for a minimum of 3. minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. . 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to ze~o. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/I3/81 cHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITeM APPROVE DATE YES NO REMARKS (1) Fee - 1. Is e permit fee attached ................................ ' .......... __ (2 thru 8) 2. Is well to be located in a defined pool ...... - ..................... -... ~K · 3. Is well located proper distance from property line ................. ' /v~ 4. Is well located proper distance from other wells .................... f~ 5. Is sufficient .undedicated acreage available in this pool .~ ........... Ah~K , 6. Is well to be deviated and is well bore plat included ............... kho( 7 Is operator the only affected party - · ********************************* 8. Can permit be approved before ten-day wait .......................... (.3) Admin ~0K o~-Z~-g2~ 9. (9 thru 11) 10. 11. (4) CaSg~u..~- ZT'f~/2 '20) 13. 14. 15. 16. 17. 18. 19. 20. ~(21 thrfi 24) 22. 23. 24. (6) Add~ 5-zB~g~ 25. Does operator have a bond in force .................................. ~O~ Is a conservation order needed ...................................... Is administrative approval needed ................................... conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production string's ... Will cement cover all known productive horizons .... . Will sUrface casing protect fresh water zones ..... ~.~.... 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 well bore separation proposed .......................... Is a diverter system required ... ' ....... .~. Are necessary d~agrams of diverte[' ~' ~;~'equi;~e~[Test ~o°a;;~g~ed'ps ~~oii Does BOPE have sufficient pressure rating- to '.~'-"-~~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ' Additional Remarks: Geology: Engin~ing: uwr WVA~/ JK~~AD '----- J AL MT~ ~-~--~ rev: 01/13/82 INITIAL GEO. UNIT ON/~FF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. 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 APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. ~mm~mmmm~mmmmmm#mmmm~ ~ .... BCHLUMBERGER---'~ LIS TAPE VERIFICATION LISTING LYP OIO,HO1 VERIFICATION LISTING PAGE ** REEL HEADER ** SERVICE NAME :$ERVIC DATE :82105126 ORIGIN : REEL NAME :REEL ID CONTINUATION # :01 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/05/26 ORIGIN :6511 TAPE NAME CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER FILE NAME :SERVIC.O0! SERVICE N~ME : VERSION # : DATE : MAXIMUM LENGTH : i024 FILE TYPE PREVIOUS FILE : INFORMATION RECORDS ** MNEM CONTE~4TS CN WN : FN : RANG: TOWN: SECT: COUN: STAT: CTRY: MNEM ATLANTIC RICHFIELD COMPANY 1H 5 KUPARUK IOE 12N 33 NORTH SLOPE ALASKA U.S.A. CONTENTS PRES: DILOOIE RECORD TYPE 047 ** UNIT TYPE CATE SiZE CODE o00 000 026 065 000 000 004 065 000 000 008 065 000 000 00] 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP 010.H0! VERIFICATION bISTING PAGE ~ RECORD TYPE 047 · ~ RECORD TYPE 047 ~* COMMENTS *~ SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY = ATLANTIC RICMFIELD COMPANY WELL : iH 5 FIELD = KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 10707,65114 RUN #1, DATE LOGGED: 12 MAY 82 BOTTOM DEPTH = i0817 FT. TOP DEPTH = 2418 FT. CASING = 10.75 IN. BIT SIZE = 8.7'5 IN. TYPE FLUID = XC POLYMER DENSITY = 1.0.5 LB/G VISCOSITY = 48.0 S FT, 5VP 010.HO1 VERIFICATION LISTING PAGE PH = 9.0 FLUID LOSS = 5.5 C3 RM = 2 9 0 68 DF RMF = 2~9 ~ 68 DF RMC = 2.2 ~ 68 DF RM AT BHT = 1.44 g 145 DF MATRIX SANDSTONE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 4 1 66 1 8 4 73 60 9 4 65 .lIN 0 1 66 0 DATUM SPECIFICATION BLOCKS , MNEM SERVICE SERVICE UNIT API API APl AP1 FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 4 SFLU DILr OMM~ 7 0 0 0 0 4 ILM DIL OHM~ 7 0 0 0 0 4 ILD DIL OH~M 7 12 46 0 0 4 SP DIL ~V 7 1 0 0 0 4 GR DIL GAPI 7 3! 32 0 0 4 NPHI FDN~ PU 42 68 2 0 0 4 DPHI FDN PU 42 0 0 0 0 4 RHOB FDN~ G/C3 42 35 1 0 0 4 GR FDN GAPI 42 3t 32 0 0 4 CALI FDN~ IN 42 28 3 0 0 4 DRHO FDN G/C3 42 44 0 0 0 4 NRAT FDN 42 42 t 0 0 4 NCNL FDN 42 34 92 0 0 4 FCNL FDN 42 34 93 0 0 4 DT BMC--'~ US/F 60 52 32 0 0 4 GR BMC ~ GAPI 60 31 32 0 0 4 LEYE5 CODE 0 1 68 0 ! 68 0 I 68 0 I 68 0 ! 68 0 1 68 0 1 68 0 I 68 0 1 68 0 I 68 0 I 68 0 ! 68 0 ~ 68 0 - I 68 0 1 68 0 i 68 0 I 68 bVP OlO.HOl VERIFICATION LISTING PAGE 4 ** DATA DEPT 11858.0000 SFLU SP~--~ -43,5'313 GR RHOB 999,2500 GR NRAT 999,2500 NCNb G~-~- 77.0o00 DEPT 10800.0000 SFLU SP -48.5938 GR RHOB :999,2500 GR NRAT 99912500 NCNb GR 76"7500 DEPT 10700,0000 SFLU SP -9.8984 GR RHOB ~999 2500 GR NRAT -999:2500 NCNb GR 88.6875 DEPT 10600.0000 SFLU SP -20,8906 GR RHOB -999,2500 GR NRAT -999,2500 NCNb GR 75.8125 DEPT 10500 0000 SFLU SP -25:2656 GR RHOB -999,2500 GR NRAT -999 2500 NCNb GR 79:5000 DEPT 10400 oooo SFbU RHOB ............. 999,2500 GR NRAT -999.2500 NCNb GR 65.3i25 DEPT I0300 0000 SFLU SP -3t:1250 GR RHUB -999,2500 GR NRAT -999,2500 NCNb GR 64,0000 DEPT 10200 0000 SFLU 8P -21:4375 GR RHOB -999.2500 GR NRAT -999,2500 NCNb GR 96.1875 DEPT iOlO0 0000 SFLU SP -20:1250 GR RHOB -999 2500 GR NRAT -999:2§00 NCNb 2 6934 77:0000 -999,2500 -999.2500 2.8047 76.7500 -999 2500 -999:2500 2.8340 88.6875 -999.2500 -999,2500 3.9180 75.8125 -999.2500 -999.2500 4 8555 79:5000 -999.2500 -999.2500 5.1914 -999 500 -999.2500 5 0000 64;0000 -999 2500 -999,"2500 2,6836 96.1875 -999 2500 -999:2500 3.3516 57,8125 -999 2500 -999:2500 IbM -f' 2.6758 NPHI -999.2500 DPHI CALI -999,2500 DRHO FCNL -999,2500 DT~~' !bM 2.7305 NPHI -999.2500 DPMI CALI -999,2500 DRHO FCNL -999.2500 DT Ib~ 2.4746 NPMI -999.2500 DPHI CALl -999,2500 DRHO FCNL -999.2500 DT IbM 3.9238 ILD NPHI -999,2500 DPHI CAbI -999.2500 DRHO FCNL -999.2500 DT IbM 4.2148 IbD N?HI -999.2500 DPHI CA~! -999.2500 OReO FCNL -999.2500 DT IbM 4.5664 NPH! .............. 999.2500 CALI .............:999,2500 FCNL 999,9500 2 ~563 -999! 500 -999 2500 98 3750 -99.9 500 -999 2500 98:3750 2,3574 -999.2500 -999 2500 I01:0000 · 3,7832 -999.2500 -999 2500 90~0000 4 999:~703 - 500 -999.2500 87,5625 ILD 4 4375 DPHI -999i2500 DRHO~-~-.,999 2500 DT 86.~875 IL~ 4,5781 ILD NPHI -999.2500 DPHI CAbI -999 2500 DRHO FCNL -999:2500 DT IL~ 2.9668 NPHI -999'2500 DPHI CAbI -999,2500 DRHO FCNL -999.2500 DT ILN 3.4258 ILD NPHI -999.2500 DPHI CAbI -999,2500 DRHO FCNL -999'2500 DT 4.5078 -999.2500 -999.2500 89.5625 2 9160 -999i2500 -999 2500 91 0000 3 3379 '99912500 -999 2500 9~ 7500 LVP 010.H01 VERIFICATION LISTING PAGE 5 57,8125 DEPT 10000 0000 SFLU sp -528711 RHOB -999.2500 GR NRAT -999.2500 NCNb GR 112,8750 DEPT SP RHOB NRAT DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT 9900.0000 8FLU -1.1230 GR -999,2500 GR -999.2500 NCNb 106,1250 9800 0000 SFLU -2216719 GR -999,2500 GE -999.2500 NCNb 116.0000 97~0.0000 SFI~U 0,5000 GR -999.2500 GR -999.2500 NCNb 109,6250 9.600 0000 SFbU 2614531 GR -999.2500 GR -999.2500 NCNb 103,1250 9500 -29 -999 -999 2 203 6 0000 SFLU 9219 GR 2500 GR 500 NCNb 25O 9400 0000 SFbU -27:5469 GR -999 2500 GR -999!2500 NCNb 219 2500 oo.oooo ; o.oooo ' 9,2500 GR '999,2500 NCNb 135.6250 00.0000 SFLU 9~46.1250 GR -999.2500 GR -999,2500 NCNb 2 6758 -999 2500 -999~2500 2 0098 106i1250 -999 2500 -999.2500 1.8213 116.0000 -999 2500 -99912500 109 50 -999 2500 -999 2500 I 5352 103~1250 -999 2500 -999:2500 3.6367 203.6250 -999.2500 -999.2500 1,8379 219.2500 -999.2500 -999.2500 3 3340 135i6250 -999 2500 -999 2500 3.7402 111.3125 -999.2500 -999.2500 ILM NPHI CALl FCNL NPHI CAbI FCNL NPHI CALI FCNL IbM NPHI CAbI FCNL IbM NPHI CAbI FCNL IbM NPHI CAbI FCNL IbM NPHI CALl FCNL IbM NPHI CALI FCNL NPHI CADI FCNL 2.9375 -999,2500 DPHI -999.2500 DRHO -999.2500 DT 2.0410 -999.2500 DPHI -999.2500 DRHO -999.2500 DT 1,8291 DIbD :999,2500 PHI 999,2500 DRHO -999.2500 DT 2.1152 -999.2500 DPHI -999.2500 DRHO -999.2500 DT .99~,.7109 .2500 DPHI -999 ~500 DRMO -999:500 DT 3,3t84 'IbD -999,2500 DPHI -999.2500 DRHO -999'2500 DT 1,6758 ILD -999;2500 DPHI .-999.2500 DRHO 999.2500 DT 3.2461 ILD -999'2500 DPHI -999.2500 DRMO -999.2500 DT .3,5000 -999.2500 DPHI -999,2500 DRHO '999,2500 DT 2 8789 -99912500 -999 2500 9715625 1.9844 -999 2500 -999!2500 I09 1875 .gg91,7549 .2500 -999 2500 .9992 0566 2500 -999 2500 I O5, 0000 1,6611 -999,2500 -999,2500 7500 3,2480 -999,2500 -999.2500 108.7500 1.6572 -999,2500 -999,2500 I08.7500 . 3,1562 .999,2500 -999.2500 I07~1875 3 4863 -999:25oo -999.25OO !00.3750 I~VP GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR OIO.H01 VERIFICATION 111.3125 9i00 -40 -999 -999 119 0000 SFLU 8437 GR 2500 GR 2500 NCNb 9375 9000 -49 -999 -999 89 0000 SFLU 2813 GR 2500 GR 2500 NCNb 5000 DEPT 8900,0000 SFLU SP -44.2500 GR RHOB -999 2500 GR NRAT -999!2500 NCNb GR 98 4375 DEPT SP NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT RHOB NRAT 8800 -40 -999 -999 i15 0000 SFLU 2500 NCNb 4375 8700.0000 SFbU -41,5000 GR -999.2500 GR -999,2500 NCNb i02.8125 8600 0000 SFLU -53!25OO GR -999 2500 GR -999.2500 NCNb 131.5000 8.500 0000 SFLU 65:1250 GR -999 2500 GR -999!2500 NCNL 125 0000 8400 -3 -999 -999 155 0000 SFBU 4492 GR 2500 GR 2500 NCNb 2500 83=00.0000 SFLU . 9,2578 GR i999,2500 GR 999,2500 NCNb LISTING 2,1582 119.9375 -999.2500 -999,2500 3,9238 89,5000 -999.2500 -999.2500 3,4863 98,4375 -999.2500 -999,2500 !8828 11 4375 -999 2500 -999.2500 2 8379 99:2500 3 5273 131:5000 -999,2500 -999,2500 3 2656 125~0000 -999,2500 -999,2500 3,1523 155, 500 '-999,2500 -999.2500 1 2344 19.2:0625 -999,2500 -999.2500 FCNL NPHI CAbI FCNL IBM CA~I FCNL IBM NPHI CA6I FCNL FCNL NPH! CALl FCNB NPHI CALI FCNL NPHI CAbI FCNL NPHI CALl FCNL . 2. 7773 :999*2500 DPHI 999.2500 DRHO -999,2500 DT 3.9609 -999.2500 DPHI -999,2500 DRHO -999,2500 DT 2,9180 ILD '999.2500 DPHI -999,2500 DRHO '999,2500 DT 2,4180 ~999.2500 DPHI .999,2500 DRHO 9'99,2500 DT 2 4219 -999:2500 DPHI -999.2500 DRHO -999,2500 DT 3,3555 IbD -999,2500 DP}J! -999 500 DRHO o, 3.3574 -999.2500 DPHI -999,2500 DRHO '999,2500 DT 2,3496 '999.2500 DPHI -999.2500 DRHO -999.2500 DT 1,5586 -999.2500 DPHI -999,2500 DRHO -999.2500 DT PAGE 2,8340 -999,2500 -999.2500 102.3750 3 9434 -999i2500 -999 2500 96,7500 2.8984 -999.2500 -999,2500 103,7500 2 3398 '99912500 -999 2500 106 0000 2 3594 -999:2500 -999.2500 100.1875 3,3555 -999,2500 '999,2500 104.5625 3 500 -999 250O 109:5625 2 4434 -999:2500 -999 2500 113~0000 1,255293 '999, 500 '999,2500 104.1875 6 bYP OI0oH01 VERIFICATION LISTING PAGE 7 GR DEPT SP RHO8 NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT GR DEPT RHOB NRAT DEPT RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT 122,0625 @2~0 0000 SFLU 9:6016 GR -999.2500 GR -999,2500 NCNL 130,6250 8100.0000 SFLU -9 500 GR -9 500 NCNL 1 6 2500 0000 SFLU -999,2500 GR 2 oo .CN 7900,0000 SFLU -9,2266 GR 99,2500 GR 85,2500 0,0000 SFLU 78~9.7266 GR -999,2500 GR -999 2500 NCNL 87:7500 7700 0000 SFLU -516055 GR -999 2500 GR -999 2500 NCNb 93,6875 00,0000 SFLU 15,3828 GR 999.2500 GR -999 2500 NCNb 110:6250 7500,0000 SFLU -t3.2266 GR -999,2500 GR -999,2500 NCNb 96.8125 7400,0000 SFLU -6,3320 GR -999,2500 GR -999.2500 NCNb 130 250 -999 2500 -999 2500 2 0605 136i2500 -999 2500 -999 2500 2 5703 84:1875 -999.2500 -999.2500 2,4004 85,2500 -999,2500 -999,2500 2.9238 87,7500 2soo 999:2500 2 ! 328 -999.2500 -999.2500 3 0586 i o: : 9o -999,2500 -999,2500 2.4570 96i8125 -999 2500 -999.2500 2,9180 91.8750 '999.2500 -999.2500 NPHI CALI FCNL NPHI CALI FCNL NPHI CAbI FCNL IbM NPHI CALI FCN5 NPHI CALI FCNb NPHI CALI FCNL IbM NPHI CALl FCNL IbM NPMI CALl FCNL IbM NPHI CALI FCNL 2,0469 -999,2500 DPHI '999,2500 DRHO -999,2500 DT 1.8027 -999,2500 DPHI "999.2'500 DRHO '999.2500 DT 2.9570 ILD -999,2500 DPHI .-999,2500 DRHO 999'2500 DT 2,4785 -999.2500 DPHI -999 2500 DRHO -999:2500 DT 3,0195 ILD -999.2500 DPHI -999,2500 DRHO -999,2500 DT 2,0996 1LD -999,2500 DPHI -999,2500 DRHO -999.2500 DT 3,4258 -999,2500 DPHI -999.2500 DRHO -999.2500 DT 2,5938 -999,2500 DPHI -999..2500 DRHO -999,2500 DT 3,0996 ILD -999.2500 DPHI -999,2500 DRHO -999.2500 DT 2500 -999,2500 99,1875 25O0 -999,2500 110,7500 2.9961 -999,2500 -999,2500 98,3750 2,5137 -999;2500 -999,2500 102.0000 2 9707 -999:2500 -999,2500 96,3750 2.12i! -999,2500 -999 72500 :{,04: 500 5OOO -999~2500 -999.2500 105.0000 2 6309 -999i2500 -999 2500 I05,1875 . 3,1406 .999,2500 999,2500 99'7500 GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT RHOB NRAT GR DEPT RHOO NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT RHOB NRAT OtO,HO1 VERIFICATION 91.8750 7300 -8 :999 999 93 7200 -999 -999 94 7100 -4 -999 -999 87 7000 -7 -999 -999 92 6900 -7 -999 -999 95 6800 -7 -999 -999 99 -999 -999 106 .0000 SFLU .i250 GR ,2`500 GR ,2500 NCNb .2500 0000 SFLU 9297 GR 2500 GR .2500 NCNL .1250 .~000 SFLU .3594 GR ,2500 GR .2500 NCNb .5625 .0000 SFLU .3555 GR 2500 GR .8125 :0000 SFLU 9883 GR .2500 GR 2500 NCNb .0000 SFLU .2500 GR ,2500 GR .2500 NCNb 0000 SFLU :1094 GR 2500 GR i 2500 NCNL 0625 6600 0000 SFLU -7i9844 GR -999 2500 GR -999 2500 NCNb 94.3750 -999 -999 .0000 SFLU .8047 GR 2500 GR '2500 NCNb LISTING 2 6406 -999.2500 -999.2500 3.2852 94 1250 -999i2500 -999 2500 87!5625 -999 2500 -999,2500 3 0996 92!8125 -999 2500 -999 2500 2 8145 95 3125 -999 2500 -999 2500 2 707,0 99'.1875 -999.2500 -999.2500 2 0137 106~0625 -999.2500 -999,2500 2 8340 94:3750 -999.2500 -999.2500 2 26 750 -999 2500 -999:2500 NPHI CAb/ FCNL NPHI CALI FCNL ILM NPHI CALI FCNL IbM NPHI CAb! FCNL IbM CALI FCNL NPMI CALI FCNL IL~ NPMI CALI FCNL IbM NPHI CALI FCNL IL~ NPHI CALl FCNL 2, 301 '999,~ 500 DPH -999.2500 DRHO -999.2500 DT 3.6289 ILD -999.2500 DPHI -999,2`500 DRHO -999.2500 DT 0449 IbD -999.2500 DT 3.4707 ILD -999.2500 DPHI -999 2500 DRHO -999:2500 DT 3,5547 ILD =999'2500 DPHI -999.2500 DRHO -999,2500 DT 2.7754 -9 99,2500 DPHI -99g,2500 DT 3 ~055 -999: 500 DPHI -999,2500 DRHO -999'2500 DT 3,i680 IbD '999 2500 DPHI '999!2500 DRHO -999 2500 DT DP I ~999,2500 .999,2500 DRHO 999.2500 DT PAGE 2 8672 -999:2500 -999 2500 oo.'`5625 3,6816 '999.2500 '999 2500 o4:oooo 3 0859 2999i250o 999 2500 96.7500 3.5078 -999.2500 -999.2500 97.7500 3.7051 -999.2500 -999.2500 103.7500 2 8379 -999:2500 -999 2500 106:187,5 3.1'875 -999 2500 -999:2500 109.5625 3.2695 .-999.2500 999,2500 110.1875 92,5938 -99 . 2500 -999 2500 110:1875 bVP OlO,HO1 YERIFICATION LISTING PAGE 9 DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT SP NRAT DEPT SP RHOB NRAT GR 96.8750 6400 0000 SFbU -6:8437 GR -999.2500 GR -999.2500 NCNL 106,4375 6300.0000 SFLU -5.5938 GR -999 2500 GR -999:2500 NCNL 90.6875 6200 -8 -999 -999 79 0000 SFLU 1172 GR 2500 GR 2500 NCNL 0000 0000/ SFLU -999,2500 GR -999,2500 NCNL 89.5625 6000.0000 SFLU -13.4766 GR -999.2500 GR -999.2500 NCNL 69,8125 DEPT ~9.00i0000 SFLU SP 12 1094 GR RHOB 999 2500 GR NRAT -999.2500 NCNL GR 93.3125 DEPT 58~0.0000 SFLU SP 9.1094 GR RHOB -999.2500 GR NRAT -999.2500 NCNL GR 75.5000 DEPT SP RMOB NRAT GR DEPT SP RHOB NRAT 5700.0000 SFLU -9.8672 GR -999.2500 GE -999.2500 NCNb 76.6875 O0 0000 SFLU -999.2500 GR -999.2500 NCNL 2.9687 106 4375 NPHI -999:2500 CALI -999.2500 FCNL 2 4492 Ib~ 90:6875 NPHI 999.2500 CALI -'999.2500 FCNL 2.7402 IbM 79.0000 NPHI -999 2500 CALI -999:2500 FCNL 4.22 7/IL~ 89.56 5--NPHI -999.2500 CALI -999.2500 FCNL 6.4180 ILM 69.8125 NPHI -999.2500 CALl -999.2500 FCNL 4 5703 ILM 93i3125 NPHI -999 2500 CALI -999 2500 FCNL 3 3809 ILM 75:5000 NPHI -999.2500 CALI -999.2500 FCNL 4 1602 IL~ 76i6875 NPHI -999 2500 CALI -999.2500 FCNL 29.1719 Ib~ 57.3125 NPHI -999.2500 CALI -999.2500 FCNL 3 ~363 -999! 500 DPHI -999~2500 -999.2500 DT 2.7148 ILD -999.2500 DPHI -999.2500 -999,2500 DT 3.18~6 ILD -999.2500 DPHI -999,2500 DRMO -999,2500 DT . 4,6094/ ILD 999.2500 DPHI -999.2500 DRRO -999.2500 DT 6.9023 ILD -999.2500 DPHI -999.2500 DRHO -999.2500 DT . 4.6B36 DPHI 2500 999.2500 DT 3 6543 ILD -999:2500 DPHI -999.2500 DRHO -999.2500 DT 4 4922 ILD -999:2500 DPHI -999.2500 DRHO -999'2500 DT . 26.5000 iLD 999~2500 DPHI -999.2500 DRMO -999.2500 DT .99~'2930 ;2500 -999,2500 114.5625 2,8613 '999,2500 '999,2500 114,5625 3 3105 -999:2500 '999,2500 i17.5625 -999i2500 500 -999 21 109. 875/ 7.6367 -999,2500 -999,2500 115,3750 4.6094 -999.2500 -999,2500 ~07,1875 3.8418 -999,2500 -999.2500 I14,3750 5.1562 -999.2500 -999.2500 ~2,5625 29,2969 '999'2500 '999.2500 134.0000 LVP GR D~PT SP RHOB NRAT DBPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT GR DEPT SP RHOB N~AT GR DEPT SP RHOB NRAT GR DEPT Sp RHOB NRAT OiO,MO1 VERIFICATION 57.3125 5500 0000 SFbU -15:6094 GR -999.2500 GR soo oooo -999.2500 GR -999.2500 NCNb 59.2813 53O0 0000 SFbU -23:8750 GR -999.2500 GR -999 2500 NCNb 64:3125 520O 2 3 83 0000 SFLU 2187 GR 2969 GR 3750 NCNb 5000 5.1.00 0000 SrbU : 5oo 2 2793 GR 1:7578 NCNb 63.7500 5000.0000 SFLU -42.2500 GR 2.1113 GR 3.5645 NCNb 52.5625 4900.0000 SFLU -27.0625 GR 2,2266 GR 6 8125 4.800.0000 SFLU 55.0938 GR 2,1230 GR 2.!641 NCNb 52.9062 4700 0000 SFLU -23:7344 GR 4355 NCNb LISTING 71 8750 '999,2500 '999.2500 17 6406 -999 2500 9.4922 64.3125 -999.2500 -999.2500 5,8203 83.5000 90.2500 2388.0000 5.4883 63,7500 65.0625 2248.0000 8.6172 52 ~625 47:500 2488.0000 6.1133 64.8125 60 3750 2214:0000 12.6250 52 9062 56!9687 2666 0000 8,0547 82.6250 76.2500 1997.0000 IbM NPHI CAbI FCNb IbM NPHI CAbI FCNL IbM NPHI CALl FCNL NPHI CAbI FCNL IbM CALI FCNL IbM NPHI CALI FCNL IbM NPHI CALI FCNL NPHI CALI FCNb IbM NPHI CADI FCNL 6,4609 -999i2500 DPHI -999,2500 DRHO -999.2500 DT 18.5156 ILD -999.2500 DPHI -999,2500 DRMO -999.2500 DT .9~19.1328 IbD .2500 DPHI -999.2500 DRHO -999,2500 DT 6 ~96'1 IbD 34:168 DPHI 17.6250 DRHO 611.0000 DT 6.4922 11.2305 DPHI 14.0234 DRHO 1235.0000 DT 13.1797 41.1621 DPHI 171 21087 DRHO 6O : 5 O0 6.7852 IbD 30.1758 DPHI t2 8359 DRHO 514:5000 DT 11.4063 18.3594 DP~{I 10~,4688 DRHO .0000 DT bD 8.0156 ~PHI 38.2813 12.3594 ORHO 536.0000 DT PAGE 7 0898 -999.'2500 -999.2500 t20.0000 20.3281 -999.2500 -999,2500 121.0000 12 3359 -999:2500 -999.2500 124.5625 7.3867 24.1211 0,0269 114.7500 6.6367 25.1465 0.0332 118'3750 12 9062 35:0098 0,0151 126,1875 6.7813 28.2227 0 0063 115:3750 ~.7031 .2773 0,0059 126.1875 8.7500 26,1719 0,0391 119,1875 10 bVP 010,H01 VERIFICATION LISTING PAGE GR DEPT RHOB NRAT GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP RHOB NRAT GR DEPT SP NRAT GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT 460 -4 3 43 2.6250 0000 srbu 6563 GR 1523 GR 5352 NCNL 7188 4500,0000 SFLU -28.4375 GR 461 GR . , 64.8125 4400 -49 2 3 43 0000 &FLU 1875 GR 0996 GR 4297 NCNL 2813 4300.0000 SFLU -30.9687 GR 2.2520 GR 3 3105 NCNL 57:6875 4.200 0000 SFLU 12:8672 GR 2,1895 GR 3.9629 NCNL 79,0000 4100,0000 SFLU -26.6250 GR 2. 2012 GR 65'1250 O0 0000 SFLU 4'040:8437 GR 2 1035 GR 3i3184 NCNL 45 0313 3900,0000 SFLU -15.5078 GR 2,1504 GR 4,1523 NCNL 67.8125 3800.0000 SFLU -22.2969 GR 2 2539 GR 3:1914 NCNL 18,8125 43.7185 43.6875 2666.0000 8 8359 6418125 74 6250 2496 0000 13,3594 43.2813 46,3125 2584.0000 9 5000 57:6875 68.0000 2326.0000 6.3203 79.0000 88 2500 1918:oooo 7.3711 65 1250 66i6250 2166 0000 9.6484 45.0313 45.2813 2708.0000 9.4766 67.8125 68.9375 1760.0000 5 50OO 47:2813 51.9375 2536,0000 IbM NPMI CALI FCNL IbM NPHI CAbI FCNL IbM NPHI CALI FCNL IbM NPHI CALI FCNL NPHI CALI FCNL NPHI CALI FCNL IbM NPHI CALI FCNL IbM NPHI CALI FCNL NPHI CALl FCNL 23.9219 IbD 40'4297 DPHI 11.6484 DRHO 646.0000 DT 10.2578 45.5566 DPHI 10,8437 DRHO 563,0000 DT 11,7031 II.,D 40,1367 DPHI 9219 DRHG 68 : 0000 DT 10,2344 IUD 36,6699 DPHI 11.0547 DRHO 644.5000 DT 7,8047 48.0469 DPHI 11.8594 DRHO 450.2500 DT 9.6094 ILD 45.4102 DPHI 10.2109 DRHO 510.2500 DT 9.7734 37.1582 DPHI 10.5703 DRHO 706.5000 DT 12.4688 51.5625 DPHI 11 5547 DRHO 400:2500 DT 6 5625 ILD 32:6660 DPHI 14.2344 DRHO 752.5000 DT 24.31.25 32.5684 0,0020 132.0000 10,7656 27.0996 0 0142 122:i875 11 .-! 406 35.6934 0 0073 135:5000 10 9141 26 7578 0 0454 I22 7500 8,5859 30,4199 0.0239 128.5000 9 6641 29i7363 0 0220 125 7500 9.5391 35,4492 0,0112 136.1250 14.3438 32.7148 0.0283 118.7500 6.8711 26,6602 O,030B I1210000 LVP 010.H01 GR 47 VERIFICATION LISTING .2813 DEPT 3700 0000 SFLU SP -3819687 GR RMOB 2,1172 GR NRAT 3.7383 NCNb GR 41.8750 DEPT SP RHOB NRAT GR 3600.0000 SFLU -29.5781 GR 2,2852 GR 2,8008 NCNb 41,2500 DEPT SP RMOB NRAT GR 350 -2 4 DEPT SP RMOB NRAT GR 0000 SFLU 8281 GR 1035 GR 4336 NCNb 8125 DEPT SP RHOB NRAT GR 3400.0000 SFLU -3~,0000 GR ,0879 GR 3.4746 NCNb 45.0313 3300 -32 2 3 52 0000 SFLU 5000 GR 1t91 GR 5469 NCNb 7188 DEPT 3200 0000 SFLU BP -3916875 GR RHOB 2 0684 GR NRAT.. 3:5508 N~CNL' GR 43,1250 DEPT RMOB NRAT 3100.0000 SFLU -36.9687 GR 2 0762 GR 3!4258 NCNb 53 7813 3000 0000 SFLU -1813125 GR 2.1562 GR 3.9375 NCNb 71.8125 DEPT SP RHOB NRAT GR 29O -1 DEPT $P RHOB NRAT 0 0000 SFLU 613281 GR 2 1309 GR 3 4590 NCNb 8 5859 4118750 47.1875 2442.0000 16.5781 41.2500 56.2187 2066.0000 8 3438 48:8125 53 5625 2728:0000 tl.2969 45.0313 41.7813 2542.0000 10,8828 52,7188 55.9687 2762.0000 10.4i41 43,1250 48,3438 2738.0000 11 7 813 57 0313 2530~0000 6.5039 71 8125 77i0000 1822 000o 5,7227 56,5625 69,1250 2270.0000 NPHI CALI FCN5 NPHI CALI FCNL IbM NPHI CALl FCNL IbM NPHI CALI FCNL IbM NPHI CALI NPHI CALI FCNb NPMI CALl FCNb IbM NPHI FCNL NPHI CALI FCNL 8.953i 44.1406 1i,5547 621.0000 13.3359 27.6855 12.0625 658.0O00 8.3516 38,8672 t1.1641 7t5.5000 1!.3516 39,4531 11.4688 656.5000 10.1641 41.5039 10.4141 667.0000 9.4063 42,4~I6 9.8 37 710.5000 1i.6406 40.332O 9.7109 637.0000 7 6563 47:9980 10,9141 414.5000 7.3906 40.2832 10.i719 586.0000 DPHI DRHO DT ILD DPHI DRHO DT DPHI DRHO DT DPHI DRMO DT DPHI DRHO DT DPHI DRHO DT ILD DPHI DRHO DT DPHI DRHO DT DPHI DRHO DT 8 7109 3416191 -0.0020 143,3750 12 3594 2418047 0 0488 10711875 8 2969 3514492 -0.0059 126,7500 11 0078 36."3770 -0 0039 13410000 10,2969 34,5215 0.0083 127.5625 9 6563 3715000 -0.0029 146.3750 12 0313 3720605 0.0122 133.Z250 8.5938 O, 42 101.5625 8 1 §:oo2o 5000 12 LVP OiO,H01 YERIFICATION LISTING PAGE 13 GR 56,5625 DEPT 2800 0000 SFLU SP -3B:1250 GR RHOB 2,1133 GR NRAT 3 3496 NCNb GR 57:2500 4922 51,9062 2536,0000 NPHI CALI FCN5 DEPT 2700,0000 SFLU SP -20,7969 GR RHOB ! 9961 GR NRAT 4:5625 NCNL GR 78.4375 10 3750 78:4375 70.4375 1786.0000 IbM CALl FCNL DEPT 2600.0000 SFLU SP -26,2500 GR RHOB 2 1270 GR NRAT 4:1953 NCNL GR 62.3438 7 8906 IbM 62!3438 NPH! 73 8125 CALl 2268.0000 FCNL DEPT 2500 0000 SFLU SP -42i3750 GR RHOB 2 0742 GR NRAT 3 5449 NCNb GR 50.0313 13,4531 50.0313 51.2187 241~,0000 NPHI CALI FCNL DEPT 2400.0000 SFLU SP -50,1875 GR RHOB 1,9824 GR NRAT 4,2852 NCNb GR 41,4063 5,4414 41,4063 45.03i3 1353.0000 NPHI CALl FCNL DEPT 2388,5000 SFLU SP -53,6250 GR RHOB -999,2500 GR NRAT -999.2500 NCNb GR 39,7813 33 4063 -999 500 -999,2500 IbM NPHI CALl FCNL ** FILE TRAILER ** FILE NAME :SERVIC,O01 SERVICE NAME : VERSION # l DATE l MAXIMUM LENGTH : 1024 FILE TYPE ~ NEXT FILE NAME : ********** EOF ** TAPE TRAILER SERVICE NAME DATE :82/05/26 ** ISERVIC 37:5000 DPHI 10,7266 DRHO 686.0000 DT 2109 5 1 6250 DRHO 4½:oooo 1t.4063 52,7344 DPHI 10,7813 DRMO 499.2500 DT 14,4688 ILD 40.6250 DPHI 11.6250 DRHO 630,0000 DT 2000.0000 55.3223 DPHI 10,0859 DRMO 253.6250 DT 2000,0000 ILD -999,2500 DPHI -999,2500 DRHO -999,2500 DT 8633 1~0.0015 7.3750 15 4609 7480 4~ 0010 156 7500 11 7578 34:0820 0000 15,0078 37,1582 -0,0063 I59.-1250 11.4766 42'5293 -0,5605 43.7813 . i0,7344 .999,2500 -999,2500 66,1875 LVP 010,H01 VERIFICATION LISTING ORIGIN :651! TAPE NAME : CONTINUATION ~ :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS DATE ~82/05/26 ORIGIN : REEL NAME ~REEL ID CONTINUATION # :0! NEXT REEL NAME : COMMENTS :REEL COMmeNTS EOF EOF PAGE 14