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Home My WebLink About180-069 Ima ~roject Well History File Cover ge 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. j ~_- ~__~ ~ Well History File Identifier RESC.~.N DIGITAL DATA ~ C~plor items: "~,, [] Diskettes, No. ~ Grayscale items'~l~ ~ [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BEVERLY ROBIN VINC~ MARIA WINDY Project Proofing BY: ~OBIN VINCENT SHERYL MARI,~ WINDY Scanning Preparation x 30 = BY: BEVERLY R~HERYL MARIA WINDY OVERSIZED (Scannable) [] Maps: ~] ~r items scannable by large scanner OVERSIZED (Non-Scannable) [] ..~s of various kinds ~~Other /~ -- TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~.~~'~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND-- ~/C YES NO Ill IIIIIIIIIII II III ReScanned (i~dividuat pa~ ~;~pec~ai ,~ft~.nf~tj ~c~nin~ c~mp~ezed) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd ALASKA OIL AND GAS CONSERVATION CO~I~IISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Jerry Booth, Vice Pres Energy & Minerals ..~k Inlet Region, Inc. 2525 C Street Anchorage, AK 99503 Re: Location Clearance, Simasko Production Company wells SIMPCO E MOQUAWKIE #1 and ~CO KALDACHABUNA #1. Dear Mr. Booth: Researching our files discloses that we should have issued "Location Clearance" letters to Simasko Production Company for the subject wells. Since CIRI owns the subsurface estate, we are issuing the location clearance to you. The SIMPCO KALDACHABUNA #1 location was inspected by our petroleum inspector Ben LeNorman on August 8, 1983. He found the location to be in good condition, and recommended location clearance. The SIMPCO E MOQUAWKIE #1 location was inspected by our petroelum inspector Harold R. Hawkins on October 17, 1984. He found the location to be in good condition, and recommended location clearance. Location clearance for Simasko Production Company wells SIMPCO E MOQUAWKIE #1 (PTD 79-020) and SIMPCO KALDACHABUNA #1 (PT~~ is hereby approved. Chairman c: Blair Wondzell bew/lsimasko r.~ printed on recycled paper b y C rt M MORA'NDUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION CO~MISSION TO C.V. Chatterton DATE Chairman FILE NO Thru: Lonnie C. Sm/th ?0~ Cc~missioner TEJ,..~PH ON E NO FROM ]~I~ n Le~or~aD ~ SUBJECT Petroleum Inspector August 9, 1983 108B:Cl Inspect Simasko t s Surface Abandonment of Simpco Kaldachabuna #1, Sec. 17,TllR,RllW,SM. Monday August .8~ 1983= I departed my home at 7=45 am for an 8:15 a~ "s'~ow~p and'8 ='3'0 am departure via Simasko chartered King Air for Tyonek airstrip arriving at 9.'00 am. Others in the party were Simasko President Bill Stewart, Tyonek Native Corporation Representative Carols El lerbee and Brinkerhoff Drilling Company Tool pusher Leonard DuDham. Surface abandonment report and pictures are attached. Inspection of Sirocco Kaloa #1 ~as concluded, the subject of a separate report. I departed Tyonek airstrip at 11=45 am, arriving in Anchorage at 12=[0 pm an~ at my home at 12:40 pm .... I summary, I inspected Si~askots Simpco Kaldachabuna #1 for surface abandonment. Attachment s A ,LA~,Kk OIL AND GAS C~,NSERVATION COMM~SSION SURFACE ABAN])ONMENT REPORT FILE INFORMATION: Opera,or Address Surface Location of W~I' ~ 7~ Ft. F~L,/ /~ Ft. F~L, Sec. /7 , T~__, R// ~, ~M. Date Downhole P & A 20 AAC 25.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) _~z,z Height Above Final Grade Level (4' Min.i Top of Marker Pipe Closed with: Cement Plug Screw Cap Set: On Well Head ~"~, On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level ~/ Ft. in. Side Outlets: All Valves and Nipples Removed ~ All Openings Closed ~"~, With Blinds ~ , With Cement Permit No. ~..~ AP1 No. 50-~'~- ~~ Unit or Lease Name ~~~ ~_~.~~~ Wel 1 No. t Field & Pool /~f~/~_~? Length (10' Min.) f · Welds , Other INFORMATION BEADWELDED DIRECT~LY TO MARKER POST: (List Where Different from File Information) Operator Unit or Lease Name Well Number , Surface Location of Well: Ft. F L, Ft., F L, Sec , T , R , M 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ~, Liners Removed or Buried , Debris Removed SURFACE OF PAD AND/OR LOCAj~_ION: Rough , Smooth W~, Contoured Other Flat ~, Compacted CLEAN UP OF PAD AND/OR LOCATION: Clean ~, Pipe Scrap , Iron Scrap Paper , Other , Wood , Mud Cement SURROUNDING AREA: Wooded 1,~~'r , Brush Sand , Other , Tundra , Grass , Dirt , Gravel CONDITION. SU~iOUNDING AREA: Clean ....... ~, TraSh from Site Other __, Trees and/or Brush from Clearing Site__ ACCESS ROAD: Dirt , Gravel ~', Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean ~, Rough , Smooth ~, Trash from Operations , Trees 'and/or Brush from Clearing Road , Spoil from Clearing Road Other REMAINING TO BE DONE: RECOMMEND APPRO~F AB~NMENT:~ Yes ~/~, ~' INSPECTED BY ~.~,~/ ?ii_, ~~_~_~ 05/26/81 No Final Inspection DATE _~-- ~"~ ,, ' STATE OF ALASKA ALASKA ((' AND GAS CONSERVATION C~ MISSION WELL COMPLETION OR RECOMPLETION'hEPORT AND LOG 1. Status of Well Class,f~cat~on of Serwce Well OIL I-1 ' GAS 1-'1 SUSPENDED [-] ABANDONED [] SERVICE [] NA 2. Name of Operator 7 Permit Number Simasko Production Company 80-69 3. Address P.O. Box 101515, Anchoraqe, AK 99510 4 Locatipn of well at surface 3579''FNL, 1505' FWL, Sec. 17, TllN, RI-IW, S~ At Top Producmng Interval NA At Total Depth 4397' FNL, 1875' FWL, Sec. 17, TllN, RllW, SM 5 Lie'/at,on in feet (indicate KB. DF, etc.) I 6 Lease Des,gnat,on and Ser,al No. 131.72' KB; 114.92' GR I None 12. Date Spudded i 13 Date T.D. Reached 14. Date Comp., Susp. or Aband. 5/01/80 ! 9/27/80 Abandoned 7/16/83 1,~.~.~pth (MD+TVD)/18 Plug Back Depth (MD+TVD 19. Directional Survey ~,97~:;D ;12,980'~w Surface YES ~ NO U I ~ectric or Other Logs Run 23. CASING SIZE WT. PER FT. · 8. APl Number 50- 283-20066 9. Unit or Lease Name SIMPCO Kaldachabuna 10. Well Number 11. F,eld and Pool Wildcat 15 Water Depth. tf offshore 116 No. of Completions NA feet MS L! NA Depth where SSSV set 1 21. Thickness of Permafrost NA feet MDI NA DIL~ BHC Sonic, FDC-CNL, Diplog, Spectra Loq, VDL-CBL, Mud Loq, Gyro Surve~ CASING, LINER AND CEMENTING RECORD GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 'See For~ SETTING DEPTH MD TOP / BOTTOM P-7 filtd 12/31/8 24 Perforations open to Production (MD+TVD of Top and Bottom and ~nterval; size and number)' None o) 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) , None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED (See Form P-7 Filed 12/31/80) 27. ' PRODUCTION TEST Date F~rst Product,on NA Date of Test Flow T.ubing Press. 28. Hours Tested Casing Pressure IMethod of Operat,on (Flowing, gas I,ft, etc.) (See Form P-7 filed *12/31/80) PRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GASoMCF WATER-BBL WATER-BBL CORE DATA ICHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) Br,ef descr,ption of Ihhology, poros,ty, fractures, apparent dips and presence of oil. gas or water. Subm,t core chips. No cores taken. RECEIVED AU$ 4 1983 I 29 30. GEOLOGIC MARKERS FORMA'[ ION TESTS · NAME . Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,,. (See form P 7 filed 12/31/~0) · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge /, / ~/ ~~ President .August 4 Signed ~- --~ .....-.~ T,tle Date ...~ 1 983 ,., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21 :' Indicatewheth~r 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". STATE OF ALASKA ALASKA( ,L AND GAS CONSERVATION (~ vlMISSION SUNDRY NOTICES AUD REPORTS ON WELLS L,// 1. DRILLING WELL I-1 COMPLETED WELL OTHER [] 2. Name of Operator Simasko Production Company 3. Address P.O. Box 101515, Anchorage, AK 99510 4. Location of Well (Surf) 3579' FNL, 1505' FWF, Sec. 17, TJ1N, RllW, SM (TD) 4397' FNL, 1875' FWL, Sec. 17, TllN; RllW, SM 5. Elevation in feet {,ndicate KB, DF. etc.) 131.72' KB; 114.92' GR 12. Lease Designation and Serial No. None 7. Permit No. 80-69 8. APl Number 5o-283-20066 9. Unit or Lease Name SIMPCO Kaldachabuna 10. Well Number 11 F~eld and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triphcate) Perforate I-] Alter Cas,ng r'] Perforations St,mulate [~] Abandon [] Stimulation Repair Well i-1 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.) (Submit in Duphcate) [] Altering Cas,ng [] Abandonment [] Other 13. Qescr~be 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). This well was suspended on November 30, 1980, at which time the drilling rig was rigged down and moved. Preliminary clean-up work was done in May, 1981. The well was abandoned and dry hole marker installed on July 16, 1983. The reserve pit has been filled and the location recontoured. Wellsite is ready for final inspection. Completed Form 10-407 to follow. 14. I hereby~~~s true S~gned ~ /' ,' ,--~/~ The space below for Commmssion use and correct to the best of my knowledge. Title President Conditions of Approval. if any: Date July 25, 1983 KL ivcu Approved by COMMISSIONER AUG 4 1983 By O,der of . . - & Gas Con5 b0~.missi0n the comm,ss,onNas~ 0ii i~.__~.ke~aae ....... Form 10-403 Rev. 7-1-80 Subrmt "Intentions" in Tr~phcate and "Subsequent Reports" ~n Dupl,cate Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) OiL l---1 GAS I---I WELLI m WELLm m OTHER E×ploratory--Suspended 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR ?. O. Box 1515, Anchorage, AK. 99510 5. APl NUMERICAL CODE 50-283-20056 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 19. WELL NO. 1 4. LOCATION OF WELL 10. Atsu,ace 3579' FNL, 1505' FWL, Section 17, T11N, R11W, Seward Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR) 14. Check Appropriate Box To Indicate Nature of Notice, Re! FIELD AND POOL, OR WILDCAT Wiidcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17, T11N, R11W, SM. 12. PERMIT NO. ~9-69 3crt, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-O~ ~ puLL OR ALTER CAS,NG FRACTURE TREAT ~ MULT,P-ECOMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (other) Time Ez~e~lon ~o~ Fl~al [~pec~lb~Xl SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well COml)letion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includ~ng estimated date of starting any proposed work. This well was suspended on November 30, 1980, at which time the drilling rig was rigged down and moved. Preliminary clean-up work was done in May, 1981. The operator plans to complete the location clean-up when earthmoving equip- ment is available late this fall following the construction work for a new drilling location proposed in the lease area. It is anticipated that the final clean-up might not be completed until mid-December. Consequently, final inspection would likely not be practical until the following spring when the snow cover is gone. The operator hereby requests a time extension for the final inspection of the wellsite until July 1, 1982. The plans and timing of the final clean-up work has been discussed with the surface owner, Tyonek Native Corporation, and has received their concurrence. RECEIVED Subsequent Work Reported Alaska Oil & Gas Cons. Commission Anchorage 16. I hereby cephF ,o~~an~rect SIGNED .i~/~ · ~-- ~ __ TITLE District Engineer DATE August 31, 1981 (This space for State of,lc. ~,~INA[ SIGNEt APPROVED BY ~ , '"' · CONDITIONS OF APPROVAL, IF ANY= ,C. OMhlI$$ZOX'-'~' See Instructions On Reverse Side DATE Approved opy Returned II ___ June 4, 1981 Simasko Production Company P. O. Box 1515 Anchorage, Alaska 99510 Alaska Oil and Cas Conservation Commission Regulations Article 2, ABANDON~4ENT A~D PLUGC-ING, 20 AAC 25.120 WELL ABANDONMENT MARI.'E~ and 20 AAC 25.170 LOCATION CLEAN UP. Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of %.;ells which, according to our records, have not received a final location inspection and approval of clean up. In compliance with 20 AAC 25.170 Section (a), "Within one year of suspension or abandonment of an on- shore well", all clean up work is to }~ finished. Section (b) provides the means for an extension of time if a valid reason exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells. Many of these are now more than one year old and are not in compliance with regulations. Others should have the final inspection completed this summer while weather permits. This list covers the years 1975 to date. There may .be some earlier wells that also need inspec- tion. If you have any earlier wells to be inspected this summer please inform us. Therefore, we are requesting a schedule from you for this summer when our field inspectors can accompany your representa- tives to these sites for the final clean up inspection. Yours truly,~ Lonnie C. Smith Commissioner LCS/JKT: be SIMASKO PRODUCTION COMPANY SIMPCO Kaldachabuna #1 SIMPCO Kaloa %1 SUSPENDED PLUGGED & ABANDONED SIMPCO E. Moquawkie Ivi shak Unit Simasko Production Company P O. BOX 1515 · ANCHORAGE, ALASKA 99510 ° (907) 277-5932 ° 274-4591 · TELEX 26-338 December 31, 1980 Re: Project 79-3 SIMPCO Kaldachabuna #1 Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Transmitted herewith are the following materials relating to the SIMPCO Kaldachabuna #1, located in Section 17, TllN, RllW, S.M.: Item Depth No. Pieces I COM~ i ~. REs ENG-~ 4 ENO i-OEOi. 1 ~ 3 GEOL / ___ I ] ,STAT TEC ]~- STAT TE~-- ! FILF~· Mud Log Dual Induction- DIL (5") Dual Induction- DIL (2") Acoustilog (2") Acoustilog (5") Densilog - Neutron Densilog CBL 350-12,976' 337-12,973' 337-12,973' 337-12,963' 337-12,963' 2470-12,964' 2470-12,964' 8330-12,874' 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia 1 & 1 Sepia _iorary Tape gs - DIFL, AC, CN/CDL 300-12,000' 1 ~ Please acknowledge receipt by signing and returning one copy of this letter. Sincerel~ ' ~e~'~ ~h ~W .--~i ~ ~ r wood District Engineer /jm Enclosures: As noted b ~. Received y _ .z~,x~ _ _Da te: Simasko Production Company P.O. BOX1515.ANCHORAGE, ALASKA99510.(907) 277-5932o274-4591-TELEX26-338 December 31, 1980 Re: Project 79-3 SIMPCO Kaldachabuna ~1 Alaska Oil & Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Transmitted herewith are the following materials relating to the SIMPCO Kaldachabuna #1, located in Section 17, TllN, RllW, S.M'.: Item Depth No. Pieces Mud Log 350-12,976' 1 & 1 Sepia Dual Induction- DIL (5") 337-12,973' 1 & 1 Sepia Dual Induction - DIL (2") 337-12,973' 1 & 1 Sepia Acous.tilog (2") 337-12,963' 1 & 1 Sepia Acoustilog (5") 337-12,963' 1 & 1 Sepia Densilog - Neutron 2470-12,964' 1 & 1 Sepia Densilog 2470-12,964' 1 & 1 Sepia CBL 8330-12,874' 1 & 1 Sepia /p L~~rary Tape gs - DIFL, AC, CN/CDL 300-12,000' 1 ase acknowledge receipt by signing and returning one copy of this letter. i Sincerelv .... ~ District Engineer 8,,. /jm 1-7- 1 Enclosures: As noted Form P--7 . SUBMIT IN DUPLi. STATE OF ALASKA (see other In- structions on el L AND GAS CONSERVATION COMMITTEE reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRY[~ Other b TYPE OF COMPLETION NEW I---I WORK I---! DEEP-I~i PLUG DIFF Suspended WELLI I OVER I I EN I I BACKO RESER I--'1 Other 2 NAME OF OPERATOR Simasko Production Company 3 ADDRESS OF OPERATOR P.O. Box 1515. Anchorage. AK 99510 4 LOCATION OF WELL (Report Ideation clearly and in accordance with any State requirements)* Atsurface 3579' FNL, 1505' FWL, Sec 17, TllN, At top prod .nterval reported below At total depth 4397' FNL, 1875' FWL, Sec 17, TllN, RllW, S.M. 13 DATE SPUDDED 114 DATETD REACHED 5/1/80 I 9/27/80 18 TOTAL DEPTH, MD & TVD 119 PLUG BACK MD & TVDI20 DEPTH HOW MANY* 12976 'MD; 12890'TVDI Surface I N/A 22 PRODUCING INTERVAL(S), OF THIS COMPLETION - TOP, BOTTOM, NAME (MD & TVD)* None RllW, S. 5 APl NUMERICAL CODE 50-283-20066 6 LEASE DESIGNATION AND SERIAL NO None IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region, UNIT FARM OR LEASE NAME SIMPCO Kaldachabuna 9 WELL NO / 1 10 FIELD AND POOL. OR WILDCAT Wildcat 11SEC,T,R,M,(BOTTOMHOLE OBJECTIVE) Inc. Sec. 17, TllN, RllW, SM 12 PERMIT NO 80-69 11/30/80 131.72' KB; 114.92'G~ IF MULTIPLECOMPL, 12~-1 ROTARY TOOLS INTERVALS DRILLED BY I CABLE TOOLS ~urf to 12,976' I None 123 WAS DIRECTIONAL SURVEY MADE Yes 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL. BHC Sonic. FDC-CNL.p~plgq,~p~c~raloq, VDL-CBL,Mud Loq, 25 CASING RECORD {Report all strings set In well) CASING SIZE WEIGHT, LB/FT DEPTH SET (MD) HOLE SIZE CEMENTING RECORD 20" 94 334 26" 0 sx w/2% CaCl2 GYro Survey AMOUNT PULLED None 26 SIZE LINER RECORD 27 TUBING RECORD TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 28 PERF( None ~0 DATE FIRST PRODUCTION _IPRODUCTION METHOD (Flowing, gas lift. pumping--size and type of I)ump) N/A - See Dril1 Stem Stem Test Record (Attachment No. OPEN TO PRODUCTION (Interval, size and number) 129 ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC I DEPTH INTERVAL (MD)/AMOUNT AND KIND OF MATERIAL USED PRODUCTION IWELL STATUS (Producing or 3 ) I shut-,n)~ ~ S_u_sPended DATE OF TEST FLOW TUBING PR ESS HOURS TESTED :CASING PRESSURE CHOKE SIZE I PROD'N FOR OIL-BBL ITEST PERIOD I 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) 32 LIST OF ATTACHMENTS GAS-MCF WATER-BBL S- L I TEST WITNESSED BY '1 Alaska 0i~ & b .... ~ ..... .ss~on Liner record, p.e~o~tion record, DST record, 33 ,her.byc. rt,~t~~e/,i//~' -'f~ In~ormat,on is co~plete and correct as ~et.r~,n.d ,rom al, daily well history, wellbore available records, program, Directional Svy. SIGNED ~' /' TITLE President DATE 12/31/80 __ W.R. (Stewart · *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: Th~s form ~s designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on this form and in any attachments. Items 20, and 22: If th~s well is completed for separate production from more than one ~nterval zone (multiple com- pletion), so state in item 20, and ~n item 22 show the producing interval, or ~ntervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on th~s form, adequately identified, for each additional interval to be separately produced, showing the additIonal data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cement,rig tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35 GEOLOGIC MARKERS NAME MEAS DEPTH TRUEVERT DEPT See Attachment No. 3 Surface gravel 0 0 Beluga Fmtn. 300' 300' Tyonek Fmtn. 5045' 5045' MGS "A" 7800' 7795' MGS "C" [0068' 1'0049' Hemlock Cngl. [2393' 10330' 36 CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS W. Foreland AND DETECTED SHOWS OF OIL, GAS OR WATER. Fmtn. / 2 9 3 0 ' 1 2 8 4 6 ' NO CORES TAKEN II Attachment No. 1 State of Alaska Form 10-407 SIMPCO Kaldachabuna Well No. 1 Part 26: Liner Record S i ze We ight Grade TOP-MD Bottom-MD 7" 26 lb/ft S-95 8330' 11,647' Cemented with: 900 sacks Class "G" containing 0.04 gal/sk D81; 0.2 gal/sk D108; and 0.17 gal/sk D80 around shoe. Squeezed liner lap with 200 sacks of Class "G" with same additives. ~" 181b/ft N-80 11,547 ' 12,961' (a/s FL4S) Cemented with: 250 sacks Class "G" containing 0.17 gal/sk D80; 0.2 gal/sk D108; and 0.04 gal/sk D81 around shoe. Squeezed liner lap with 75 sacks of Class "G". ATTACHMENT No. 2 STATE OF ALASKA FORM 10-407 SIMPCO Kaldachabuna No. 1 Part 29: Perforated Intervals Original Plug Back Depth (before testing); 12,877' Perforation Depth (by test interval) 12,813-12,823' 12,798-12,808' 12,782-12,792' 12,724-12,734' 12,668-12,688' 12,625-12,635' 12,440-12,450' 12,395-12,415' 11,950-11,960' 11,917-11,927' 11,838-11,848' 11,570-11,630' 11,462-11,522' 11,352-11,442' 11,075-11,105' 10,710-10,740' (1) Ail bridge plugs Bridge Plug Depth(1) (zone isolation) Cement Plug Depth 12,763' None 12,651' None 12,553' None 12,306' None Spotted 50 sx in casing from 12,305' to 12,000' 11,716 None 11,545' None 11,158' Squeezed w/50 sx below retainer @11,158' 10,942' 10,537' None Plug No. 1: Spotted 40 sx in casing from 10,535' to 10,250'. CIP @1020 hrs 11/29/80. Plug No. 2: Spotted 60 sx in casing from 8445' to 8225' CIP @1306 hrs, 11/2~/80. Plug No. 3: Spotted 50 sx in casing from 120' to surface. CIP @0415 hrs, 11/30/80. cement retainers. Attachment No. 3 State of Alaska Form 10-407 SIMPCO Kaldachabuna No. 1 Part 34: Drillstem Test Record A. DST No. 1 Hemlock 11/4/80 PBD: 12,877' MD Casing size: 5", 18 lb/ft Perforated Intervals: 12,813-12,823'; 12,798-12,808'; 12,782-12,792' Water Cushion: 4600' of fresh water: Mud weight: 10.9 ppg Packer depth: 12,740' MD; BHT: 200OF Initial Flow Period: 120 minutes Initial Shut in Period: 240 minutes Final Flow and Final Shut-in Periods eliminated due to weak formation response. Description of test: Opened tool at 2240 hrs, 11-3-80. Weak blow increasing slowly to 11 inches of water (bucket) in 10 minutes. Blow was then steady for 1 hour, 20 minutes then decreased to 8 inches of water at the end of the 2 hour flow period. Shut in at 0040 hrs, 11-4-80. No gas or fluid to surface. Recovery: Reversed out estimated 14 barrels of slightly gas and oil cut drilling mud heavily contaminated with formation water. Chlorides measured 7000-9000 ppm by field titrations. The lab measurement was 13,200 ppm with a resistivity of 0.33 ohm-meters at 68°F. Conclusion: Formation very tight and water productive. There appears to be little to no formation damage near the wellbore. Static formation pressure appears to exceed hydrostatic pressure. There was an apparent leak in the Dual CIP during the latter part of shut-in period. Pressure Data: Guage No. 2859 @12,724' MD (48 hr) ( ins ide ) Guage No. 2855 @12,754' MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP FHP 7288 psi 1823 psi 2563 psi 7219 psi 7245 psi 7309 psi 1843 psi 2589 psi 7269 psi;~ L'~ ~ ~. B. DST No. 2 Hemlock 11/5/80 PBD.. 12,760' MD Casing Size: 5", 18 lb/ft Perforated Intervals: 12,724-12,734'; 12,668-12,688' Water Cushion: 4300' of fresh water; Mud weight: 11 ppg Packer Depth: 12,614' MD; BHT: 190°F Inital Flow Period: 120 minutes Initial Shut-in Period: 240 minutes Final Flow and Final Shut-in Perods eliminated due to weak formation response. Description of Test: Opened tool at 1410 hrs, 11-5-80. Weak blow increasing slightly to 5 inches of water (bucket) then decreased slightly near the end of the 2-hour flow period. Shut in at 1610 hrs. 11-5-80. No gas or fluid to surface. Recovery: Reversed out an estimated 4.6 barrels of mud cut water, slightly gas cut. Tight-hole sample chamber contained +7 gallons of slightly gas and oil cut drilling fluid (heavily water cut). Chlorides measured 8000 ppm with a resistivity of 0.42 ohm- meters at 68°F. Conclusion: Formation very tight and water productive. Appears to be no formation damage near the wellbore. Static formation pressure exceeds the hydrostatic pressure. Possible supercharging while setting packer. Pressure Data: Guage No. 2858 @ 12,598'MD (24 hr) ( ins ide ) Guage No. 2855 @ 12,618'MD (48 hr) (outside) IHP 7254 psi 7267 psi 1st IFP 1833 psi 1899 psi 1st FFP 2083 psi 2114 psi ISIP 7822 psi 7821 psi FHP 7249 psi 7267 psi C. DST No. 3 Hemlock 11/6/80 PBD. 12,650' MD Casing Size: 5" 18 lb/ft Perforated Interval: 12,625 - 12,635' Water Cushion: 4300' of fresh wateri Mud Weight: Packer Depth: 12,588' MD; BHT: 196VF Initial Flow Period: 30 minutes Initial Shut-in Period: 60 minutes Final Flow Period: 120 minutes Final Shut- in Period: 240 minutes ( Description of Test: Opened tool at 2018 hrs, 11-6-80. Started with a weak blow increasing to moderate blow (bottom of bucket) in 11 minutes. Shut-in at 2048 hrs for 1 hour. Opened tool for final flow at 2148 hrs with a weak blow increasing to a moderate blow in 25 minutes. Slight increase in blow throughout the 2-hour period. Shut in at 2348 hrs. No gas or fluid to surface. Recovery: Reversed out 16.9 bbls of slightly gas and mud cut salt water with a trace of oil. Tight-hole chamber contained +6 gallons of mud cut water. Chlorides ranged from 8700 ppm to 10,800 ppm. There was approximately 5 gallons of sand in the drill pipe above the dual CIP which confirms water production. Conclusion: Formation is very tight and water productive. Appears to be no formation damage near the wellbore. Static formation pressure, estimated at 7400 psi from extrapolated Horner Plot, exceeds the hydrostatic pressure. This is supported by indications of a slight water flow into the wellbore while drilling this particular interval. Pressure Data: Guage No. 2859 @12,572'MD (48 hr) ( ins ide ) Guage No. 2855 @12,602'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP 2nd IFP 2nd FFP FSIP FHP 7261 psi 1575 psi 2251 psi 6606 psi 2272 psi 2560 psi 6648 psi 7266 psi 7289 psi 1736 psi 2269 psi 6618 psi 2315 psi 2584 psi 6673 psi 7294 psi Calculated Reservoir Parameters: p* @12,572' MD = 7501 psi Fluid Gradient = 0.6 psi/ft p* @MPP (12,630' MD; 12,558' TVD) = 7,535 psi kh = 6.88 md-ft k=0.69 md Skin factor = -2.86 (indicates no wellbore damage) MPP = mid-point perforation depth D. DST No. 4 Hemlock 11/10/80 PBD: 12,553' MD Casing Size: 5", 18 lb/ft Perforated Intervals: 12,395-12,415'; 12,440-12,450'; Water Cushion: 4000' of fresh water; Mud Weight: Packer Depth: 12,335'; BHT: 194°F Initial Flow Period: 30 minutes Inital Shut-in Period: 60 minutes Final Flow Period: 120 minutes Final Shut in Period: 240 minutes Description of Test: Opened tool at 1240 hrs, 11-10-80. Weak blow increasing to moderate blow (bottom of bucket) in 12 minutes. Shut in at 1310 hrs. Opened for final flow at 1410 hrs with a weak blow slowly increasing to a moderate blow in 35 minutes. Blow then slowly decreased the last 30 minutes. There was evidence on the BHP charts that some tool plugging occurred during the early parts of each flow period. Shut in at 1610 hrs. No gas or fluid to surface. Recovery: Reversed out an estimated 13 barrels of slightly gas cut mud and formation water. Chlorides in the reversed recovery measured 9000 ppm. A water sample from the tight-hole sample chamber measured 13,200 ppm chlorides and 0.31 ohm-meter resistivity at 68°F. The formation water recovered was dark straw colored. Conclusion: Formation was very tight and water productive. From pressure build-up performance, there appears to be no wellbore damage. Pressure Data: Guage No. 2858 @12,319'MD (24 hr) ( ins ide ) Guage No. 2855 @12,349'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP 2nd IFP 2nd FFP FSIP FHP 7103 psi 1677 psi 2128 psi 6142 psi 2118 ps~ 2480 ps~ 6196 ps~ 7083 ps~ 7124 psi 1726 ps~ 2152 ps~ 6156 psi 2173 ps~ 2503 ps~ 6216 ps~ 7100 ps~ Calculated Reservoir Parameters: p* (@ 12,319' MD; 12,258' TVD) = 6954 psi. Fluid Gradient = 0.57 psi/ft p* (@ MPP 12,443' MD; 12,378' TVD) = 7,022 psi kh = 5.87 md-ft k = 0.2 md skin factor = -2.37 (indicates no wellbore damage) ~ "'~ i~ E. DST NO. 5 MGS "C" & "D" 11/13/80 Dr~,.~r.-, ~9~ PBD: 12,000' Casing Size: 5" 18 lb/ft ~t,,,~, Perforated Intervals: 11,838-11,848', 11,917-11,92~a~.'. ~ ~, 11,950-11,960 ' ~ ~ . ~' ~n;,,~isst~ Water Cushion: 3300' of fresh water; Mud Weight: 10.9 ppg Packer Depth: 11,777'; BHT: 182°F Initial Flow Period: 120 minutes Initial Shut-in Period: 240 minutes Final Flow Perod: 15 minutes (to check initial response) Final Shut-in: Eliminated due to short final flow period Description of Test: Opened tool at 1430 hrs, 11-13-80. Opened with an immediate blow slowly increasing to a moderate blow in 15 minutes. It appeared that some plugging occurred during the flow period evidenced by flow heading at the surface. Blow remained steady with some surging throughout the flow period. Plugging was confirmed by the BHP charts. Shut in at 1630 hrs. Opened again at 2030 hrs for 15 minutes to check initial flow response following the shut-in period. After no indication of flow, closed and re-opened hydrospring in an effort to create a possible surge to re-establish flow but without success. No gas or fluid to surface. Recovery: Reversed out 6 1/2 barrels of slightly gas cut and heavily salt water cut drilling mud. Chlorides in the sample from the tight-hole chamber measured 4000 ppm. Conclusion: Formation was very tight and water productive. Analysis of pressure build-up performance confirms low permeabilities and indicates that there is no wellbore damage. Pressure Data: Guage No. 2858 @ll,761'MD (24 hr) ( ins ide ) Guage No. 2855 @11,787'MD (48 hr) (outside) IHP 6677 psi 6709 psi 1st IFP 1304 psi 1538 psi 1st FFP 1863 psi 1899 psi ISIP 5057 psi 5071 psi FHP 6681 psi 6694 psi Calculated Reservoir Parameters: p* (@ll,761'MD; ll,716'TVD) = 5683 psi; Fluid Gradient=0.49 psi/ft p* (@MPP, 11,899' MD; 11,850' TVD) = 5749 psi kh = 3.17 md-ft k = 0.11 md skin factor = -2.35 (indicates no wellbore damage) F. DST No. 6 MGS "C" PBD: 11,716' Casing Size: 5", 18 lb/ft Perforated Interval: 11,588 - 11,604' Water Cushion: 2200' of fresh water; Mud Weight: Packer Depth: 11,496' (in 7" casing); BHT: 177°F Initial Flow Peroid: 30 minutes Initial Shut-in Period: 60 minutes Final Flow Period: 180 minutes Final Shut-in Period: 360 minutes 11/15/80 10 ppg Description of Test: Opened tool at 0647 hrs, 11-15-80, with a weak blow after 4 minutes slowly increasing to a moderate blow in 10 minutes. Shut-in at 0717 hrs then re-opened for final flow at 0817 hrs. Immediate blow increasing to moderate blow in 18 minutes then strong blow after 1 hour. Blow continued to increase throughout 3-hour flow period. Surface pressure increased to 1/2 psi with all flow through the blow hose. Shut in at 1117 hrs. No gas or fluid to surface. Charts indicated slight plugging during the flow period. Recovery: Reversed out approximately 22 barrels of gas and oil cut drilling mud. There was approximately 1 gallon of free oil on top of the water cushion. There was an accumulation of gas immediately on top of the oil. Chlorides measured 900 to 1000 ppm which is equivalent to the mud filtrate. Dual CIP sample chamber contained 7% oil and 93% water cut mud. Concl us ion: Formation very tight. Due to the recovery of a measurable amount of oil, the zone will be retested after perforating additional section. Pressure Data: Guage No. 2858 @ll,480'MD (24 hr) ( ins ide ) Guage No. 2855 @11,510'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP 2nd IFP 2nd FFP FSIP FHP 6103 psi 1049 psi 1338 psi 5125 psi 1353 ps~ 1878 ps~ 5391 ps1 6069 psi 6121 psi 1066 ps~ 1371 psi 5131 psi 1381 psi 1888 psi 5404 ps~ 6086 psi Calculated Reservoir Parameters: p* (@11,480' MD; ll,439'TVD) = 5822 psi; Fluid Gradient=0.51 psi/ft p* (@MPP, 11,596'MD; ll,553'TVD) = 5880 psi kh = 11.65 md-ft; k = 0.73 md Skin factor = -2.34 (no apparent skin damage) G. DST No. 6B MGS "C" 11/16/80 PBD: 11,716' Casing Size: 5", 18 lb/ft Perforated Interval: 11,570-11,630' Water Cushion: 1000' of fresh water; Mud Weight: 10 ppg Packer Depth: 11,468' (in 7" casing); BHT:178°F Initial Flow Period: 360 minutes Initial Shut-in Period: 570 minutes The final flow and shut-in periods were eliminated since this was a retested interval. Description of Test: Opened tool at 1653 hrs, 11-16-80, with a weak blow increasing to a moderate blow in 16 minutes and strong blow in 1 hour. Gas to surface occurred after 5 hours and 40 minutes. Maximum surface pressure recorded was 3 1/2 psi with all flow through the surface blow hose. Measured gas gravity with Ranarex instrument was 0.746 (air=l.0). Shut in at 2253 hrs for 9 1/2 hours. No fluid to surface. Recovery: Reversed out 23 barrels of fluid of which 2 1/2 barrels of oil was recovered on top of the water cushion. The remaining 20 1/2 barrels was slightly gas and oil cut drilling mud. Chlorides measured 1050 ppm in the reversed recovery. Chlorides in the Dual CIP sample chamber measured 1700 ppm. The Dual CIP sample chamber contained water cut drilling mud and 4% oil. The tight hole sample chamber contained 100% oil. Measured oil gravity was 42°API at 62°F. Conclusion: The formation was very tight yet from pressure build-up analysis no wellbore damage is evident. This zone is very marginal due to low productivity. This test confirmed test No. 6. Only a small portion of the perforated interval contributed to production indicated by similar kh values between tests 6 and 6B. Pressure Data: Guage No 2858 @11,449' MD (24 hr) ( ins ide ) Guage No 2855 @11,478'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP FHP 5926 psi 626 psi 1608 psi 5445 psi 5907 psi 5955 psi 657 psi ~~ 1640 psi ~ ~ ~,~;~ 5470 psi r~ i~ ~ Calculated Reservoir Parameters: p* (@11,449'MD; ll,409'TVD) = 5798 psi; Fluid Gradient=0.51 psi/ft p* (@MPP, ll,600'MD; ll,557'TVD)= 5873 psi kh = 9.26 md-ft k = 0.15 md skin factor = -1.26 (no indicated wellbore damage) H. DST No. 7 MGS "C" 11/20/80 PBD: 11,545' Casing Size: 7", 26 lb/ft Perforated Interval: 11,462 - 11,522' Water Cushion: 1000' of fresh water Mud System and Weight: Calcium Chloride; 10 ppg Packer Depth: 11,407'; BHT: 180°F Initial Flow Period: 60 minutes Initial Shut-in Period: 60 minutes Final Flow Period: 360 minutes Final Shut-in Period: 630 minutes Description of Test: Opened tool at 0827 hrs, 11-20-80, with an immediate blow increasing slowly to moderate blow in 43 minutes. Plugging indicated by surging during the initial flow period; however, the BHP charts indicated nearly complete tool plugging during this flow period. Shut in at 0927 hrs. Opened for final flow at 1027 hrs with an immediate blow increasing to moderate blow in 48 minutes. Blow slowly increased throughout entire 6 hour flow period. Maximum surface pressure was 1.4 psi. Shut in at 1627 hrs for 10 1/2 hrs. No gas or fluid to surface. Recovery: Reversed out approximately 26 barrels of fluid of which the first 15 barrels were gas and oil cut drilling mud followed by 11 barrels of salt water contaminated with completion fluid. Chlorides in the reversed fluids measured 3600 ppm with 0.9 ohm-meters resistivity at 68°F. The Dual CIP sampler contained 1850 cc of fluid of which 8% was oil, 2% mud, and 90% formation water (chlorides = 3500 ppm). The tight-hole sample chamber (between the Dual CIP and the Hydrospring) contained 4 68 gallons of fluid, all oil The oil measured 42©API at ~0°F with a gas/oil ratio of i67:1. The Dual CIP sample chamber contained a more representative sample of the wellbore stream than the tight-hole chamber. During the shut-in period, only the Dual CIP (above the tight-hole sample chamber) was closed. The conventional Hydrospring (below the tight-hole sample chamber) remained open allowing any oil or light liquids and gas in the rat hole to percolate upward and collect in the tight-hole chamber thus resulting in a non- representative fluid sample. All tests following this test employed an indexing Hydrospring which was closed when the Dual CIP was closed for pressure build-up. This action~,~ eliminated the problem of disparity of sample data. Conclusion: From pressure build-up analysis and flow response, the formation exhibits very low permeability and produces with a high water cut (+8 to 10%). No wellbore damage was evident. Pressure Data: Guage No. 2855 @11,395'MD (48 hr) ( ins ide ) Guage No. 2847 @ll,419'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP 2nd IFP 2nd FFP FSIP FHP 5919 psi 768 psi 4909 psi (plugged) 4879 psi 1056 psi 1894 ps~ 5308 ps~ 5899 ps~ 5928 psi 783 psi 4901 psi (plugged) 4870 psi 1065 ps~ 1899 ps~ 5301 psi 5912 ps~ Calculated Reservoir Parameters: p* (@11,395'MD; ll,355'TVD) = 5771 psi; Fluid Gradient=0.51 psi/ft p* (@MPP, 11,492' MD; ll,451'TVD) = 5820 psi. kh = 5.53 md-ft; k = 0.09 md skin factor = -1.14 (indicates no wellbore damage) I. DST No. 8 MGS "C" 11/22/80 PBD: 11,455' Casing Size: 7", 26 lb/ft Perforated Interval: 11,352 - 11,442' Water Cushion: 1000' of fresh water Mud System and Weight: Calcium Chloride, 10 ~pg Packer Depth: 11,289'; BHT: 178VF Initial Flow Period: 30 minutes Initial Shut-in Period: 63 minutes Final Flow Period: 360 minutes Final Shut-in Period: 643 minutes Description of Test: Opened tool at 0528 hrs, 11-22-80, with an immediate weak blow increasing rapidly to strong blow in 4 minutes. Shut in at 0558 hrs for 1 hour. Opened tool for final flow at 0701 hrs with an immediate blow increasing to strong blow in 4 minutes. Blow continued to increase until the surface pressure reached 6.3 psi. Gas-to-surface occurred 2 hours, 50 minutes into the final flow period. Put well stream through the 1/4" surface choke and to the flare line. Flow rate was too small to measure; however, yielded a 4-foot flame at the flare line. Shut in at 1301 hrs. No fluid to surface. Recovery: Reversed out 36 barrels of fluid of which 14 barrels was oil (44©API at 65°F) on top of the water cushion. The remaining 22 barrels, below the water cushion was oil, gas, and mud cut water. The Dual CIP samRle chamber contained 0.252 cu. ft. of gas, 350 cc oil (44v API@ 65°F) and 1550 cc of water (chlorides = 9000 ppm). The tight-hole sample chamber contained 15.69 cu. ft. of gas, 0.97 gallons oil (42©API @ 65°F), and 4.62 gallons of water (chlorides = 8900 ppm). The water cuts in the sample chambers were quite similar (82 and 83% water). Conclusion: The formation was very tight; however, since the water cut was lower from this zone than any zone tested earlier, a retest with a longer flow period was performed. This retest was designated as No. 8B. Pressure Data: Guage No. 2858 @ 11,274' MD (24 hr) ( ins ide ) Guage No. 2847 @ 11,303'MD (48 hr) (outside) IHP 5828 psi 5850 psi 1st IFP 749 psi 768 psi 1st FFP 1093 psi 1107 psi ISIP 4209 psi 4221 psi 2nd IFP 1123 psi 1154 psi 2nd FFP 1814 psi 1841 psi FSIP 5125 psi 5145 psi FHP Clock Expired 5834 psi Calculated Reservoir Parameters: p* (@ 11,274'MD; ll,235'TVD) = 5626 psi; Fluid Gradient = 0.50 psi/ft p* (@MPP, 11397' MD; 11,357'TVD) = 5687 psi kh - 9.21 md-ft; k = 0.14 md Skin factor = -1.67 (indicates no wellbore damage) J. DST No. 8B MGS "C" 11/23~> ~i?~. PBD: 11,455'; Casing Size: 7", 26 lb/ft ~ Perforated Interval: 11,352-11,442' (Retested) ~ Water Cushion: None Mud System and Weight: Calcium Chloride; 10 ppg Packer Depth: 11,292'; BHT: 182°F Initial Flow Period: 1440 minutes (24 hrs) Initial Shut-in Period: 992 minutes (16 hfs, 32 minutes) Final Flow and Shut-in Periods were eliminated. Description of Test: Opened tool at 1745 hrs, 11-23-80, with an immediate blow increasing to strong blow in 4 minutes. Opened to flare line on 1/4" choke in 15 minutes. Surface pressure increased to a maximum of 6.5 psi after 45 minutes then slowly decreased to 2.2 psi at the end of the 24-hour flow period. Gas-to-surface occurred in 50 minutes. Shut in at 1745 hrs on 11-24-80. No fluid to surface. BHP charts showed slight plugging during early part of the flow period. Recovery: Reversed out 54.6 barrels of fluid of which the first 15 barrels was oil (42°API @ 60°F). The remaining 39.6 barrels was oil and gas cut water (chlorides measured 9000 ppm). The tight-hole sample chamber contained 14.96 cu. ft. of gas, 1.02 gallons of oil, and 5.63 gallons of water. The resultant GOR was 618. The oil gravity measured 41.5°API at 60°F and the chlorides in the water were 4700 ppm which is representative of the formation water. The water cut was 85%. Conclusion: This retest confirmed the results from DST No. 8. The formation is very tight (low permeability) and produces with an excessive water cut for this low productivity. There is no apparent wellbore damage; however, the magnitude of the negative skin factor changed between tests 8 and 8B indicating a slight reduction in permeability near the wellbore on the retest. Pressure Data: Guage No. 2855 @ll,281'MD (48 hr) ( ins ide ) Guage No. 2847 @11,306'MD (48 hr) (outside) IHP 5833 psi 5855 psi 1st IFP 429 psi 449 psi 1st FFP 2320 psi 2320 psi ISIP 5086 psi 5099 psi FHP 5828 psi 5845 psi Calculated Reservoir Parameters: p* (@ll,281'MD; ll,242'TVD) = 5599 psi; Fluid Gradient= 0.50 psi/ft p* (@MPP, 11,397'MD; ll,357'TVD) = 5657 psi kh = 6.93 md-ft; k = 0.10 md Skin factor = -1.13 (indicates no wellbore damage) K. DST No. 9 MGS "C" 11/27/80 PBD: 11,158' Casing Size: 7", 26 lb/ft Perforated Interval: 11,075-11,105' Water Cushion: 1000' of fresh water Mud System and Weight: Calcium Chloride, 10.0 ppg Packer Depth: 11,040' BHT: 175°F Initial Flow Period: 30 minutes Initial Shut-in Period: 60 minutes Final Flow Period: 120 minutes Final Shut-in Period: 229 minutes Description of Test: Opened tool at 2132 hfs, 11-27-80, with a weak blow slowly increasing to a moderate blow in 22 minutes. Shut in at 2202 hrs. Reopened at 2302 hrs with a very weak blow. Well was dead in 40 minutes. Left tool open for 2 hours. Shut in at 0102 hrs, 11-28-80. No fluid or gas to surface. BHP charts indicated some plugging occurred during the flow periods. The formation flow potential was very low. Some leakage occurred in the Dual CIP during the shut-in periods causing erratic build-up curves. The leakage ceased the last two hours of the final build-up period allowing sufficent data for pressure build-up analysis to confirm very poor reservoir qual i ty. Recovery: Reversed out 9.1 barrels of slightly gas cut drilling fluid with a trace of oil. Chlorides measured from 6900 to 15,000 ppm. The samples in the Dual CIP and tight-hole chambers were filled with calcium contaminated drilling mud and very clabbored. The fluid was slightly gas cut with a trace of oil. Conclusion: The formation was very tight and essentially non-productive. Pressure Data: Guage No. 2858 @11,025'MD (24 hr) ( ins ide ) Guage No. 2859 @11,054'MD (48 hr) (outside) IHP 1st IFP 1st FFP ISIP 2nd IFP 2nd FFP FSIP FHP 5705 psi 695 psi 783 psi 2559 ps~ 818 ps~ 980 psi 3993 ps~ 5695 psi 5741 psi 746 psi 811 psi 2571 psi 854 psi 1016 psi 4021 psi 5725 psi Calculated Reservoir Parameters: p* (@11,025'MD, 10,990'TVD) = 5425 psi; Fluid Gradient=0.49 psi/ft p* (@MPP, ll,090'MD; ll,054'TVD)= 5456 psi kh= 2.43 md-ft; k - 0.08 md Skin factor = -1.93 (indicates no wellbore damage) L. DST No. 10 MGS "C" 11/28/80 PBD: 10,950' Casing Size: 7", 26 lb/ft Perforated Interval: 10,710 - 10,740' Water Cushion: 1000' of fresh water Mud system and Weight: Calcium Chloride, 10 ppg. Packer Depth: 10,666'; BHT: 173°F Initial Flow Period: 240 minutes Initial Shut-in Period: 434 minutes The Final Flow and Shut-in periods were eliminated due to poor formation response. Description of Test: Opened tool at 0856 hrs, 11-28-80, with an immediate blow slowly increasing to a moderate blow in 30 minutes. Blow. remained steady and moderate throughout the 4 hour flow period. There was evidence of plugging during the first hour. Shut in at 1256 hrs. No fluid or gas to surface. Recovery: Reversed out 14.4 barrels of slightly gas cut and heavily mud cut formation water. The fluids in the Dual CIP and tight-hole sample chambers were just slightly gas cut with a trace of oil. The chlorides measured 2750 ppm. Conclusions: The formation was very tight and water productive. Pressure Data: Guage No. 2858 @10,650'MD (24 hr) ( ins ide ) Guage No. 2855 @10,683'MD (72 hr) (outside) IHP 5494 psi 5520 psi 1st IFP 626 psi 647 psi 1st FFP 1142 psi 1163 psi ISIP 4480 psi 4494 psi FHP 5479 psi 5480 psi Calculated Reservoir Parameters: p* (@10,650'MD;10,620'TVD) = 5092 psi; Fluid Gradient=0.48 psi/ft p* (@MPP, 10,725'MD; 10,694'TVD) = 5128 psi kh = 4.53 md-ft; k = 0.15 md Skin Factor = -2.07 (indicates no wellbore damage) Attachment No. 4 State of Alaska Form 10-407 SIMPCO Kaldachabuna No. 1 Daily Drilling Summary 4/1-4/3: Finalize preparation to barge construction equipment 4/4: Barged construction equipment to job site. 4/5-4/8: Completed snow removal on road and drillsite in preparation for gravel haul. 4/9-4/25: Construction of access road and drillsite. Repaired existing road. 4/26-4/29: Move in and rig-up Brinkerhoff Signal Rig No. 58. 4/30: Complete rig-up and drive 30" conductor pipe to 73' KB. LD drive hammer and make final preparation to spud. 5/1: Complete hook up on 30" conductor. Spud @ 2:00 p.m. Drill 17 1/2" hole. 5/2: Drill 17 1/2" hole to 339'. Open hole to 26" to 339'. Condition hole and ran 20", 94#/ft, H-40, buttress casing and landed at 334' KB. Circulate and prepare to cement. 5/3: Cement 20" casing with 720 sacks Class "G" with 2% calcium chloride. CIP at 9:00 a.m. Full returns throughout with good cement to surface. Install 20" casing head and nipple up 20" hydril and diverter system. 5/4: Completed diverter nipple up. Clean out and drill out w/12 1/4" bit. 5/5: Drill to 2228'. 5/6: Drill to 2485'. Condition hole and short trip. Prepare to log. Ran DIL. 5/7: Log. Ran DIL-SP and dipmeter-GR. Start opening hole to 17 1/2". 5/8-5/9: Open hole to 17 1/2" to 2485'. Condition hole to run casing. Ran 13 3/8", 689/ft, N-80, BTC casing ~"~ ~.~ ~ ,? ~ from 2476-1072', 13 3/8", 68~/ft, K-55, BTC casing ~ ~ %~ from 1072' to 888', and 13 3/8" 61#/ft K-55 BTC '~ ~ casing from 888' to surface. Landed at 2476'. Break ~}~ ~ ~' ~ circulation. 5/10: 5/11: 5/12: 5/13: 5/14 5/15: 5/16: 5/17: 5/18: 5/19: 5/20: 5/21: 5/22: 5/23: 5/24: 5/25: 5/26: 5/27: 5/28: Cemented 13 3/8" casing to surface with 1000 sacks Class "G" with 4% gel followed by 750 sacks Class "G" with 2% calcium chloride. CIP at 1:30 a.m. Full returns throughout with good cement to surface. PU BOP and cut off 20" casing head. Weld on 13 3/8" casing head. Nipple up BOP and test. PU drilling assembly. Clean out and tested casing to 1500 psi. Drill out shoe and drill 12 1/4" hole to 2495'. Conducted formation integrity test to equivalent gradient of 11.6 ppg with no bleed-off. Drill ahead. Drill to 3548' and trip for bit. Drilling at 3922'. Drill to 4078' and trip for bit. Drilling at 4318'. Drill to 4499' and trip for bit. Reaming back to bottom with stiff BHA. Ream to bottom with BHA. Drill to 4840' and trip for bit. Drill to 5224 and trip for bit. Drill to 5482 and trip for bit. Drill to 5685 and trip for bit. Drilling at 5770'. Drill to 5960'. Test BOP. Trip for bit. Drilling at 6194'. Drill to 6224' and trip for bit. Test BOP. Drilling at 6348 ' . Drill to 6450' and make short trip. Drilling at 6541' . Drill to 6671' and short trip. Drilling at 6733'. Drill to 6887' and trip for bit. Drilling at 6906'. Drill to 7083' and trip to change BHA. Repair rig. Drill to 7187' and short trip. Drill to 7240' and trip for bit. .~ .... Drilling at 7444'. '~ f 5/29: 5/30: 5/31: 6/1: 6/2: 6/3: 6/4: 6/5: 6/6: 6/7: 6/8: 6/9: 6/10: 6/11: Drill to 7474' and trip. Test BOP. Change BHA. Drilling at 7509'. Drill to 7630' and trip for bit. Trip in and run survey. Short trip to retrieve survey. Drilling at 7832'. Short trip and drill ahead at 7979'. Drill to 8068' and short trip for survey. Drilling at 8130' . Drilling at 8338'. Drill to 8340' and short trip for survey. Drilling at 8511' . Drill to 8530' and short trip for survey. Drill to 8675' and strap out. Test BOP. Circulate and condition hole to log. Ran DIL, Dipmeter, Density-Neutron, Gamma Ray- Caliper and Compensated Sonic Logs. Ran magnetic multi-shot and gyro surveys. Rig up to run casing. Ran 64 jts 9 5/8", 43.5 lb/ft, S-95, LT&C from 8671' to 5900'; 116 jts, 9 5/8", 43.5 lb/ft, N-80, LT&C, from 5900 to 1548' 41 jts, 9 5/8", 40 lb/ft, N-80, LT&C from 1548 to surface. Cemented casing with 700 sx Class "G" containing 0.17 gal/sk D80 (TIC), 0.04 gal/sk D81R, and 0.2 gal/sk D108 (FLAC). Displaced plug with mud and bumped at 2500 psi. Full returns throughout. CIP at 10:55 p.m. Landed casing in slips. Nipple up casing head and BOP. Tested BOP. PU drilling assembly. Drilled float and cement to 8633'. Tested casing to 2500 psi. Drilled shoe and formation to 8685'. Conducted formation integrity test to equivalent gradient of 12.1 ppg at the shoe. No bleed-off. Drilled ahead with 8 1/2" hole @ 8752' . 6/12: 6/13: 6/14: 6/15: 6/16: 6/17: 6/18: 6/19: 6/20: 6/21: 6/22: 6/23: 6/24: 6/25: 6/26: 6/27: 6/28: 6/29: Drill to 8813' and trip to change BHA. Install casing protector rubbers on drill pipe. Drilling at 8868' . Drill to 8913' and trip for bit. Drilling at 8944'. Drill to 8998' and trip for bit. Drill to 9076'. Trip for bit and repair rotary table Complete rotary table repair. Drilling at 9146'. Drill to 9158' and trip for bit. Drilling at 9242'. Drill to 9276'. Trip for bit and test BOP. Drilling at 9312'. Drill to 9338'. Trip for bit and change BHA. Drilling at 9390'. Submitted new "Application for Permit to Drill" for a deviated hole. Permit No. 80-69 was approved and issued by the Alaska Oil & Gas Conservation Commission on 6/19/80. Drill to 9461' and trip for bit. Drilling at 9500'. Drill to 9626' and trip for bit. Drilling at 9648'. Drill to 9757' and trip for bit. Drilling at 9801'. Drill to 9872' and trip for bit. Drilling at 9935'. Trip for bit. Drilling at 10,050'. Drill to 10,120' and short trip for survey. Drilling at 10,210'. Drill to 10,270' and short trip. Drilling at 10,360' . Drill to 10,431' and short trip for survey. Drilling at 10,521'. Drill to 10,544' and trip for bit. Test BOP. Drilling at 10,600'. Drill to 10,692' and short trip. Drilling at 10,745' . 6/30: 7/1: 7/2: 7/3: 7/4-7/5: 7/6: 7/7-7/8: 7/9-7/10: 7/11-7/12: 7/13-7/14: 7/15: 7/16-7/17: 7/18: 7/19: 7/20-7/21: 7/22: Drill to 10,765' and trip for bit. Change BHA. Drilling at 10,815 Drill to 10,868'. Stuck pipe at 10,868'. Spot SFT pill. Backed off at 10,722'. fishing tools. Jar on fish. RIH with Fishing. Recovered 3 drill collars and 2 stabilizers. Top of fish at 10,822'. Fishing and wash over. No success. Spot 50 sacks Class "G" neat cement plug with 8% sand from 10,821' to 10,727'. WOC. RIH with Dyna Drill. Test BOP (7/9). Washed off c eme n t plug. POH. Spotted 65 sacks Class "G" cement plug with 8% sand from 10,775' to 10,688'. WOC. Dressed plug to 10,712'. Run Dyna Drill. 10,770'. Kick off at 10,712'. Drill to Drill to 10,880'. Stuck pipe on bottom. Spotted SFT pill. Ran free point and backed off at 10,852'. RIH with fishing tools. Could not jar loose. Backed off at 10,852'. Ran wash pipe and washed over to 10,874'. Twisted off washover shoe. Made attempt to jar fish loose with no success. Spotted 95 sacks Class "G" neat cement plug with 8% sand from 10,849' to 10,575'. WOC. Test BOP. Dressed off cement plug to 10,772'. Ran Dyna Drill and kicked off at 10,772. Drilled to 10,837'. LD Dyna Drill. Ream to bottom at 10,837'. and siltstones. Hole tight. circulate hole clean. Drill alternating coals Drill to 10,890' and 7/23: 7/24: 7/25: 7/26: 7/27: 7/28: 7/29: 7/30: 7/31: 8/1: 8/2: 8/3: 8/4: 8/5: 8/6: 8/7: 8/8: 8/9-8/10: Trip for bit. Ream to bottom and drilling at 10,937' . Drill to 10,941 and trip for bit. Hole tight. Left one cone and spindle in hole. Run mill and junk sub. Mill on junk. Mill on junk. Partial recovery. Mill on junk. Ran reverse circulating junk basket. Dropped ball and recover more junk. Trip in and ream to bottom. Drilling at 11,006'. Trip for bit and ream to bottom. Drilling at 11,055'. Drill to 11,083'. Trp for bit. at 11,084'. Drill to 11,112'. Trip for bit. Drilling at 11,116'. Test BOP. Drilling Hole tight. Drill to 11,147' and trip for bit. Change BHA. Ream to bottom. Drill to 11,191' and trip for bit. Ream to bottom. Drill to 11,246' and trip for bit. Change BHA. Ream to bottom. Drilling at 11,292'. Drilled to 11,303'. POH. Stuck pipe at 9263'. Backed off at 9106'. PU fishing tools. RIH and screw into fish and jar loose. POH. Lost fish. Clean out to top of fish at 10,933'. Trip out. Stuck pipe at 9195'. Spotted SFT pill. Work stuck pipe. Backed off at 8630'. RIH with fishing tools. Screw into fish and backed off 9085'. POH with part of fish. Fishing with no success. Wash over fish. 8/11: 8/12: 8/13: 8/14-8/15 8/16: 8/17: 8/18-8/19: 8/20: 8/21: 8/22: 8/23: 8/24: 8/25: 8/26: 8/27: 8/28: LD wash pipe. Clean out to top of fish. RIH with fishing tools. Screw into fish and jar loose. POH. LD fish. Clean out to top of first fish. RIH with fishing tools. Could not engage fish. Clean out to top of fish. RIH with overshot and engage fish. Pulled fish up the hole 110' and overshot released. RIH with smaller overshot. Engage fish. Attempt to back off. Overshot released. Ran overshot extension and over over fish. Backed off at 11,003'. POH and LD part of fish. RIH with fishing tools and screw into fish and jar loose. POH. Condition hole to log. Logging. Ran DIL, FDC/CNL, BHC Sonic, and Dipmeter. RIH with reverse circulating junk basket. Wash to bottom. Cut 2' core to recover junk. No recovery. RIH with mill. Mill on junk. RIH with bit and drill ahead to 11,325' . Drill to 11,327'. Trip for bit and change BHA. Drilling at 11,372. Drill to 11,439'. Trip for bit. Hole tight. Drilling at 11,507'. Drill to 11,542' and trip for bit. Ream to bottom. Drilling at 11,591'. Drill to 11,644'. Trip for bit. Hole tight. pipe. Stuck Worked stuck pipe. Spotted SFT pill and soaking. Jarred on stuck pipe. Backed off at 9192'. fishing tools, engage fish, and jar loose. with fish. Condition hole. ' ........ ~ ~, ~,~ J Ran Trip out ( 8/29-8/31: 9/1: 9/2: Logging. Ran DIL, FDC/CNL, BHC Sonic and Dipmeter. Milled on junk from 11,644' to 11,654'. Partial recovery. Condition hole to run 7" liner. Ran 79 jts. 7", 26 lb/ft, S-95, LT&C liner with BOT Boll Weevil mechanical set hanger. 9/3-9/4: 9/5-9/9: 9/10: 9/11: 9/12: 9/13: 9/14: 9/15: 9/16: Hung liner with top at 8330' and shoe at 11,647'. Cemented with 900 sacks Class "G" cement and additives. Displaced with mud and bump plug with 3000 psi. CIP at 0720, 9/3/80. Ran RTTS packer and cement squeezed liner lap with 100 sacks Class "G" plus additives. WOC 24 hours and cleaned out to liner top. Test BOP. Pressure tested liner lap to 1000 psi. Would not hold pressure. Set cement retainer at 8267'. Cement squeeze liner lap with 100 sacks Class "G" cement with additives. WOC 24 hours and drilled out retainer and cement. Pressure tested liner lap to 2000 psi for 30 minutes, OK. Cleaned out to 11,618'. Pressure tested liner pipe and lap to 2000 psi, OK. Ran gyrosurvey. Drilled out shoe and formation to 11,664'. Tested formation to equivalent gradient of 0.65 psi/ft with no leak-off. Trip in with 6" bit and drilling assembly. Repair rig. Drilling at 11,748'. Trip for bit and change BHA. Drilling at 11,799'. Drill to 11,811' and trip for bit. Change BHA. Ream to bottom. Drilling at 11,844'. Drill to 11,852'. Trip for bit. Ream out-of-guage hole. Drill to 11,869' and trip for bit. Drilling ahead at 11,981'. Drill to 11,988' and short trip for survey. Drilling at 12,060'. Drill to 12,095' and trip for bit. Repair rig. Trip in. Could not get proper pump pre~s.~u~e..Lost nozzle in bit ..... 9/17: 9/18: 9/19: Trip in. Drilling at 12,194'. Drill to 12,214' and trip for bit. Test BOP. Ream to bottom. Drilling at 12,216'. Drill to 12,250' and short trip. Drilling at 12,303' . 9/20: 9/21: 9/22: 9/23: 9/24: 9/25: 9/26: 9/27: 9/28: 9/29-9/30: 10/1: 10/2: Drill to 12,319' and short trip for survey. Hole sloughing. Drilling at 12,355'. Drill to 12,408' and trip for bit. Hole sloughing. Wash and ream. Wash and ream to bottom. Drilling at 12,456'. Drill to 12,559' and short trip for survey. Drilling at 12,568' Drill to 12,601' and trip for bit. Drilling at 12,655' . Drill to 12,756' and short trip for survey. Drilling at 12,796'. Drill to 12,855' and trip for bit. String up new drilling line. Drilling at 12,857'. Drill to 12,976'. Short trip and condition hole for logs. Logging tools would not go to bottom. Ran bit and clean out. Logging. Ran DIL-SP/GR, BHC Sonic-GR. Could not get density log to bottom. Ran bit and cleaned out. Test BOP. Complete logging. Ran FDC-CNL/GR. Trip in and condition hole for casing. Trip out. RU and ran 33 jts 5", 17.93 lb/ft, N-80 Atlas Bradford FL4S liner on BOT multicone hydraulic set liner hanger w/6' tie-back sleeve. Set hanger w/shoe at 12,961' and liner top at 11,547'. Condition hole and prepare to cement. 10/3: 10/4: 10/5: 10/6: 10/7: 10/8: 10/9-10-25: 10/25-10/27: 10/28-10/29: 10/30: 10/31: Pumped 20 bbls Dowell's Spacer-1000 mixed to 11.5 ppg. Mixed and pumped 250 sacks Class "G" containing 0.17 gal/sk D80, 0.4 gal/sk D108, and 0.04 gal/sk D81R. Displaced with mud. Overdisplaced by 2 bbls and did not bump plug. Released from hanger and reverse out . CIP at 0200 hrs. WOC 24 hrs and tested liner hanger to 2000 psi with packer on drill pipe. Bled down to 1900 psi in 30 minutes. Tripped out and ran cement retainer and set at 11,477'. Pumped in water spacer at 3000 psi. Could not establish formation breakdown. Milled out cement retainer. Ran packer and 5 stand tailpipe and drill pipe. With tailpipe at the 5" liner top, spotted 75 sacks of Class "G" cement. Picked up 150' and reversed out excess cement. Picked up 30' and set packer. Squeezed cement around liner at 3000 psi. Held pressure on squeeze for 12 hours. Bled off pressure. Released packer. Could not pull loose. Could not pump through drill pipe. Backed off between packer and by-pass. Left packer and tailpipe in hole. Weather down. Wait on tools. Wait on tools. Weather down. Fishing for packer. Milled over packer. Recovered packer in three separate sections. Washed over drill pipe and recovered same. Drilled out hard cement from 11,362' to liner top at 11,547'. Cleaned out inside 5" liner. Ran liner tie-back dressing tool in 9 5/8" x 7" hanger. Ran casing scrapers in 7" liner and 5" liner. Ran VDL-CBL/GR and Spectralog. Running gyro survey at 2400 hrs. 11/1: Completed running gyro survey. Ran and set RTTS at 11,500'. Pressure tst 5" liner lap to 3250 psi for 30 minutes with no bleed-off. Test BOP. Cleaned out in 5" liner to 12,877' PBTD. 11/2-1/3: Perforated 12,813-12,823'; 12,798-12,808'; and 12,782-12,792' at 4 JSPF with casing guns. Ran DST No. 1 with packer at 12,740. Reversed out recovery. 11/4: Pull DST No. 1. Ran cement retainer and set at 12,763'. Attempt to break down formation for cement squeeze. Pumped in est. 1/16 BPM at 4000 psi. Did not squeeze. 11/5: Perforated 12,724-12,734' and 12,668-12,688' at 4 JSPF with casing guns. Ran DST No. 2 with packer set at 12,614'. Reversed out recovery. 11/6: Pulled DST NO. 2. Ran cement retainer and set at 12,651'. Could not pump into formation at 4000 psi. Perforated 12,625-12,635' at 4 JSPF with casing guns. Ran DST No. 3 with packer set at 12,588'. Reversed out recovery. 11/7-11/9: Pulled DST No. 3. Rig compound sprocket failed. Wait on parts and repaired compound. Completed trip out. Ran cement retainer and set at 12,553'. 11/10: Perforated 12,440-12,450' and 12,395-12,415' at 4 JSPF with casing guns. Ran DST No. 4 with packer at 12,335'. Reversed out and pulled packer loose. Trip out. 11/11-11/12: Ran cement retainer and set at 12,306'. Could not pump into formation at 4000 psi. Spotted 50 sacks of Class G cement from 12,305 to 11,934'. Pulled 3 stands and could not reverse out. Pulled out and layed down 44 joints of drill pipe (cemented). Clean out to 5" liner top with 6" bit and 7" casing scraper. Cleaned out inside 5" liner and tag cement at 11,934'. Drill cement to 12,000'. Ran 5" casing scraper. 11/13: Perforated 11,950-11,960; 11,917-11,927; and 11,838-11,848' at 4 JSPF with casing guns. Ran DST No. 5 with packer set at 11,777'. Reversed out and pulled packer loose. Trip out. 11/14: Ran cement retainer and set at 11,716'. Pressured up on formation with rig pump to 2400 psi with negligible fluid entry. Reduce mud weight from 10.9 ppg to 10.0 ppg. 11/15: Perforated 11,588 to 11,604' at 4 JSPF with casing guns. Ran DST No. 6 with packer set at 11,495'. Reversed out recovery and pulled packer loose. Trip out. 11/16: Trip in and clean out. Perforated 11,600-11,630' and 11,570-11,590' at 4 JSPF with casing guns. Ran DST No. 6B with packer set at 11,468'. 11/17-11/19: Completed DST No. 6B. Reversed out recovery and pulled tools. Ran cement retainer and set at 11,545'. Change over from conventional drilling mud to Calcium Chloride completion fluid. Made clean out trips with 9 5/8" and 7" casing scrapers. 11/20: Perforated 11,462-11,522' at 4 JSPF with casing guns. Ran DST No. 7 with packer set at 11,406'. Reversed out recovery. 11/21: Pulled DST tools. Ran retrievable bridge plug and set at 11,455'. Perforated 11,352-11,442' at 4 JSPF with casing guns. 11/22: Ran DST No. 8 with packer set at 11,289'. Reversed out recovery. 11/23-11/25: Pull packer loose and trip out. Reran DST tools. Set packer at 11,292 and retested interval as DST No. 8B with an extended flow period. Reversed out recovery, pulled packer and trip out. Released retrievable bridge plug. 11/26: Bridge plug stuck at 11,359'. Worked free and trip out. Ran cement retainer and set at 11,158'. ', ~ Establish injection rate into formation and cement ~.~' squeeze below the retainer with 50 sacks of Class G ~ ' ?~w~ith additives. CIP 81100 hrs. Final squeeze '~,-.., ~' ~pre~.ssure was 3750 psi at 1/4 BPM Perforated ~'~/~,~ 11',,~)75-11,105 at 4 JSPF with casing guns' Ran DST --'~.., ~';~No. 9 with packer set at 11,040'. 11/27: 11/28: 11/29: 11/30: Reversed out recovery and pulled packer loose. Ran cement retainer and set at 10,942'. Perforated 10,710-10,740 at 4 JSPF with casing guns. Ran DST No. 10 with packer set at 10,666'. Reversed out recovery and pulled packer loose. Ran cement retainer and set at 10,537'. Spotted a 40 sack Class G cement plug on top of the retainer. CIP at 1020 hrs. Picked up to 10,250' and reversed out excess cement. Picked up to 8445' and spotted plug No. 2 (60 sacks Class G) from 8445 to 8225' across the 7" liner top at 8330'. CIP at 1305 hrs. Laying down drill pipe. Complete laying down drill pipe and collars. Spotted a viscous gel pill from 185' to surface. Pick up to 120' and spotted a 50 sack cement plug to surface. CIP at 0415 hrs. Wash cement out of top 10' of casing. Fill with glycol and water. Nipple down BOP and install suspens'ion wellhead. Released rig. Well suspended. 20" casing set ~334 ' 13 3/8" casing set @2476 ' 7" liner top ~8330 ' 9 5/8" casing set @8671 ' 5" liner top ~11, ~47 ' 7" liner set ~11, ~47 ' 5" liner set @12,961 TD 012,976 MD ATTACHMENT ' "~' Well bore Diagram'~SIMPcO Kaldachbuna #1 - Status~"~ 11/30/80 Suspended Status Plug No. 3 10.0 ppg Ca 1 ci um Chloride FI ui d P1 ug -Bottom of top plug ~120' Top of plug ~8225' Bottom of plug ~8445' Top of plug ~10,250' Retainer ~10,537' Perf interval: 10,710-10,740' Retainer at 10,942' Perf interval: 11,075-11,105' ~Retainer ~11,158' 50 sx cement below retainer to 11,352' Perf intervals: 11,462-11,522' Top of cement . Retainer ~12,306' . Perf intervals Retainer 012,553' ~ Perf interval 12,625-12,635' --Retainer 012,651' Retainer ~11,545' Perf interval: 11,570-11,630' Retainer 011,716' Perf intervals ; 11,352-11,442' :11,950-11,960; 11,917-11,927; 11,838-11,848' plug ~12,000' : 12,440-12,450'..12,395-12,415', ~. Perf intervals: 12,724--12,734; 12,668-12,688' .... Retainer 012,763' ~ ~ Perf intervals: 12,813-12,823; 12,798-12,808; 12,782-12,79; ' ~ ~. ~' PBTD ~12,877' ~" needle valve ~'~-~---- 2 9/16",5000 psi RJ companion ...... flange w/tapped bull plug ......., , . 4~sk,l 2 9/16",5000 psi RJ gate valve SUSPENSION WELLHEAD SIMPCO Kaldachabuna #1 9/16", 5000'ps~ x 11", 5000 psi RJ adapter flange . ' ~' 9 5/8' casing spool (11", 5000 x 13 5/8", 5000) .~.··.~ ~ ~ 2 1/16", 5000 ps~ RJ gate valve ATTACHMENT "B" Well bor~ biaqram %SIMPCO Kaldachbuna ~1 - Status ~ 11/30/80 Suspended Status 20" casing set @334' 13 3/8" casing set ~2476' 7" liner top ~8330' 9 5/8" casing set ~8671' 5" liner top 011 , 547 ' --~ 7" liner set ~11 , 647 ' Plug _ - No. 3 10.0 ppg Cal ci um ~ Ch 1 ori de Fluid '~ P1 ug No. 1 --Bottom of top plug 8120' Top of plug ~8225' Bottom of plug @8445' Top of plug @10,250' Retainer @10,537' Perf interval: 10,710-10,740' Retainer at 10,942' Perf interval: 11,075-11,105' ~Retainer @11,158' 50 sx cement below retainer to 11,352' Perf intervals: 11,462-11,522'; 11,352-11,442' Retainer @11,545' Perf interval: 11,570-11,630' Retainer ~11,716' Perf intervals:il,950-11,960; 11,917-11,927; 11,838-11,848' Top of cement plug @12,000' Retainer @12,306' Perf intervals: 12,440-12,450'; 12,395-12,415' Retainer 812,553' Perf interval 12,625-12,635' Retainer @12,651' Perf intervals: 12,724--12,734; 12,668-12,688' Retainer 812,763' . Perf intervals: 12,813-12,823; 12,798-12,808; 12,782-12,79~ 5" liner set @12,961 /~ TD ~12,976 MD - PBTD ~12,877' SUSPENSION WELLHEAD SIMPCO Kaldachabuna #1 r/ ~" needle valve RECEIVED 2 9/16",5000 psi RJ companion flange w/tapped bull plug OEC l 0 19~ 2 9/16.,5ooo psi RJ gate valvea~ Anchorag~ · '2 9/16", 5000 psi x 11", 5000 psi RJ adapter flange 9 5/8" casing spool (11", 5000 x 13 5/8", 5000) 2 1/16", 5000 psi RJ gate valve 13 3/8" cdsJng head (13 5/8", 5000 psi) Simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 ° (907) 277-5932 ° 274-4591 ° TELEX 26-338 January 7, 1981 Alaska Oil & Gas Conservation Commission Attn: William Van Alen 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Bill: Enclosed is the Directional Survey for Kaldachabuna No.1 well. All other well data were previously transmitted to your office. Very truly yours, KWC/nk Enclosure l Eastrnan · Whipstock l A PETROLANE CO~PA~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY Simasko Production CO, COMPANY Kaldachabuna #1 ,' WELL NAME Tyonek Field, Cook Inlet, Alaska LOCATION JOB NUMBER Al180GO086 SURVEY BY Max Lund TYPE OF SURVEY Gyro Multi Shot RECEIVED JAN- 8 1~'~,~ Alaska 0il & Gas Cons. Commissior~ Anchorage OFFICE Alaska DATE ]_o/3:z/8o Eastm. an Whipstock A PET ~ROLAt~E CO/.~PANY P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 TWX 910-881-5066/Cable. EASTCO o. November 3, 1980 Simasko Production Co. P.O. Box 1515 Anchorage, Alaska 99510 Well Number: Kaldachabuna #1 Location: Tyonek Field, Cook Inlet, Alaska Type o£ Survey: Gyro Multi Shot Date: October 31, 1980 Method o£ Computation: Radius o£ Curvature Surveyor: Max Lund Job Number: AllSOGO086 ATTN: Brit Allard Dear Mr. Allard, I am enclosing the original and one copy o£ the Gyro Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, ~~rna g~~e~ District Operations Manager Alaska District JT/cfw O~rt..N:t~onal Ordlers Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide -S]7. ~4ASKO' F'.RODUCT l KAL[~ACHA[~U~A NO. 1 TYONEi~ FIELD, ALASKA ~G~S, -O~-24'OOMT~- GYRO M~S, 2506-867oM[I, 17 DEG A/UI ~2~A, CAMERA NO~ 1488 DATE RUN JUNE 8, 1980 -SURVEYOR; MAX I_UND GMS, 8600-11600MD, SURVEYOR~ R WOMAK G~S, 11700-12850 ~D, SURVEYOR; ~ LUND, DATE RUN ~1-0CT-80 VERTICAL SPCTION CALCULATED DIRECTION: S 20 DEG. RECORD OF SURVEY ....................... RA~.~IUS OF CURVATURE METHOD · IMASKO F'RODUCTION COMPANY ALDACHABUNA NO· 1 .... ~ONEK FIELD,'ALASKA tI=ASURED DRIF-T DRIFT DEPTH ANGI, E f-~IRECTI ON FEET Fi M -- I) COMF'IDTATI ON T-I ~iE ' DATE- 09 ,' 35: 27 .05-NOV-80 PAGE .NO · I COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E LENGTH DEPTH SECTION C 0 0 R D I N A T E S DISTANCE DIRECTION FFF. T - FEET .... FEET --- F'EE-T -- F.:-E E-T- [p---M---- ]DOGLEG SEVF_' RiTY DG/iOOF-T- O. 0 0 0 - 100. 0--0 0 200. 0 0 0 300. 0 30 N 85 400. 0 0 .... 0 O. 0.00 0.00 0.00 0o00 0.00 0 0 0 -~00. ...... 100.-00 ......... 0.00 ........... 0,00 ......... 0.00 ........... 0,00 ....... 0--0 0 100, 200.00 0.00 0.00 0.00 0.00 0 0 0 100. 300.00 0.11 0.04 N 0.43 W 0.44 N 85 0 W 0 100. -400.00 ........ 0.23 O-,08-N~---O.87--W ........ O,-87--N-SS--O--W----O ,00 ,-00 -- - .00 . ,..JO ~'g'~O0. 0 30 S 79 -600-. .... 0--30 .... S 85 700. 0 30 S 25 800. 0 0 0 ---~00~ ....... 0--30-~-8--20 1000. 0 30 S ~2 -1100· 0 45 S- 6 i200. 0 30 S 10 1300. 0 30 S 20 t400· 0 45 S 50 W 100. 500.00 0.45 0.01S 1.30 W -W ...... 100. ....... 599.99 ........ 0.86 ............. 0-.13--S .... Z.-16-W W 100, 699,99 1,54 0,61 S 2.84 W 100, 799.99 1,98 1,00 S 3,03 W -W ....... 100· .... 899-~99 ........ --2,4J.~ ....... 1',-41--S ....... 3,18-W W 100, W '100. W iO0, 1199.97 W 100· 1299,97 W 100., .... '1399A~96 1500. 0 45 S 56 W I600. -II0-30 IS 28--W- -- 1700. 0 30 N 87 W BO0. 1 0 S 70 W ]~'~'~O0~-------q)--45----S--~6--W 100. 1499,95 -100. --- 1599,95-- - 100. 1699,94 100, 1799,93 100~~1~99T92--~ ~1-1~g0 8.43 6.81S 5. 9.43 ...... 7.61-S ....... 6. 10.06 8.02 S 7. 10.68 8.21S 8. 8~8--S-------t~0o 1.30 S 89 41W 0.50 -2-.-17---S--86--36--W~0-.05- 2.91 S 77 58 W 0·50 3.19 S 71 42 W 0.50 3,48--S--66---2-W ..... 0.50 4·18 S 58 20 W 0.10 5.06--S--50-$4-W .... 0.37 5.91 S 43 24 W 0·25 6,69 S 39 51 W 0.0~ 7·77---S--39-11--W ..... 0,40 95 W 9.04 S 41 10 W 0 67-W ..... 10-.-12---S 41 15-W-~ 0 39 W 10,91 S 42 41 W 0 68 W 11,95 S 46 35 W 0 09--W :-13~38~8--48--59-W~0 .08 ,-39 - - .57 2000. 0 45 S 66 W -2100. ..... 0-45 ..... S--45-W 2200. 0 45 S 71W 2300. 0 45 S 58 W 2400. 0 S0 - -S 46-W 100. 1999,91 100,----2099-,90 .... 100. 2199.90 100· 2299,89 --100, .... 2399,88 12.61 9·31S 11. 13.67 .... 10.05-S ..........12. 14.70 10.74 S 13. 15.63 11.30 S 14. 16.55- - 11·97 S .... 15. 29 W 14.63 S 50 29 W 0 36-W ..........1-5~-93 .... S-50-53'W ....... 0 46 W 17.22 S 51 25 W 0 64 W 18.50 S 52 20 W 0 50-W ......... 19,58 .... S--52-19-W ..... 0 .00 ,27 .... .34 .!7 ,28 - qMS 2506-8675HD 2506. 0 30 2600. 0 45 ---2693~-- -1--0 2~87. i o S 33 W 106. 2505.88 S 50 W ,, 94, 2599,87 S-JS-W ....... 93-.-- -2692.86 ....... S 31 W 94, 2786,85 17.42 18,37 19,73 ...... 21.37 12.68 S 16.09 W 20.48 S 51 45 W 0.1! 13.45 S 16.76 W ,~1.49 S 51 16 'J,' 0.33 16.].3 S 18.15 W 24 ~o . · ~,~ S 48 2m W 0·30 · '~HASKO PRODUCTION COHPAN¥ · ~t-DACHA[~UNA- NO ,---1 '*¥ONEK FIELD, 'ALASKA ,, :EASURED DRIFT DRIFT COURSE .3EF'TH ANGLE OIRECTION LENGTH FEET -- - D H ..... D ..... FEET · COH.F'L~T. AT I ON T I ~E ....... D ¢PT-E 09135 ~ 27 O5-NOV-80 PAGE ~ TRU5 VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG J. [EFTH SECTION C 0 0 R D I N A T E S DISTANCE OlRECTION SEVER TY F'EET--~ FEE-T- FEE-T- FE-E-T 0 .. t'4 , DG/100F-T- 5688. 2 15 S 23 W --5782,-----~--25-~S--15-W 5876. 2 0 S 22 W 5969, 2 0 S 20 W - 6063. ----2--~0 .... S ll-W 93, 5686,79 95,99 81,24 S 57,45 W 99,50 S 35 16 W 0,36 "' 74-~ '5780'T7~ 99~-&7~84~2-S'- -58~-65--W------103,~.4-~S--34-,4~--W :: 94. 5874.66 103.15 88.03 S 59,76 W 106,39 S 34 10 W 0,38 93. 5967,60 :106,40 91.06 S 60,92 W 109.55 S 33 47 W 0,08 -- 94, ....... &061-,53----z-'110-*07--: ~4¢&1--S ~1-,-90--W~11~-,-06 ..... S--3~--12--W : 6'"""]¢56, 2 30 S 15 W ~6950~ ...... 2--45-~-S-14--W 6344. 3 0 S 11W 6437. 3 0 S 8 W --6~3t. ~O~S~7-W-- 6624. 3 45 S 6 W --67i8~ ...... 4- O----S----5-W 6812. 4 0 S 8 W 6905. 4 15 S 2 W 6999. ...... 4--0-----S~5 W 7092, 3 45 S 3 W -7186,- -~3--30 ~S ..... 4-W-~ 7279, 3 15 S 3 E '~73. 3 30 S 3 E ~46-7. ~ 3--30----S----J.--E 93, 6154,44 114,10 98,56 S 62,82 W 94, .... 6248,-34 .... 118-,-39 ...... 1-02,-73--S . .~63-r89--W 94. 6342.,,,,,,.'"'"" 123 . 06 107 · 33 S 64.91 W 93, 6435,10 127,84 112 · 13 S 65,72 W 94-,~6528,-94 ~1-33-, 05 ~ '-1-1-7¥4 t- S~66--,-4 fk~'~'j'. 66&'~6,~,,,-,,~L~381~ 77~ ~'-~,1.,"23. o6 S 67.08 W 94. 671~.~4':, ~ _~'~.;~144'9~~, .. ..~_:~,~.. 129,~8~~67.6~ . ~ W 94. 68b~9-;S~l&~ ~gl.2'9' 136.09 S ~ 68.43~ W 116,87 S 32 31 W 0.19 1-20-,~8---S-3-1--53-W .... 125.43 S 31 10 W 0.31 129,97 S 30 22 W 0,i7 ~-34~-90 S-29--30-W '" 0~-54~ 140,33 S 28 33 W 0.28 146,19--S-27-35-W ....... 0.28~ 152,33 S 26 42 W 0,22 158,56 S 25 48 W 0,54 164,84 .... S--24--55-W ...... 0~5 93. 7088.62 170,27 155.77 S 69.86 W 170.72 S 24 9 W 0.31 -~94. ..... 7182~43 175-.97 ........ 161.70-S ..... 70.23--W--'~17-~.-29---S-~3-29--W~O-.-27 ..... 93, 7275,27 181,13 167.17 S 70,27 W 181,34 S 22 48 W 0,52 94, 7369,10 186,22 172.70 S 69,98 W 186,34 S 22 4 W 0.27 94:"' 746~:93~~1~'i:54 "1-78:-43--S~69'~78--W ' 1-~-60---S--?i---?2--W "~rt-3:: 7560. 3 45 S I E -7654~ ..... 4-- 0 .... S---4--E 7748. 4 30 S 6 E 7841. 4 45 S 6 E -7935. ...... 5-15-~S'---6--E 8028. 5 30 S 10 E ~8'J. g2 . --5"-J. 5 ~S-'-14- E 8216. 5 45 S 6 E 8309. 6 0 S 7 E ---8405-, -6~J. 5 .... S- 6 --E 93, 7555,74 197,03 184,31S 69,68 W 197,05 S 20 43 W 0,27 --94. .... 7649~53 .... 202-.90 ....... 190.66-S--~69.41--W .... 202-~9~--S-20----0--W---~0,34~- 94, 7743.27 209.21 197.60 S 68.80 W 209.23 S 19 12 W 0.55 93, 7835,97 215.95 205,06 S 68.01W 216.04 S 18 21W 0,27 94, .... 7929,~61 ..... 223,32 ..... 213,20-S ...... 67,16-W ..... 223,-53--S--1-7--29-W-- -0.53--- 93, 8022,20 231,01 221,83 S 65,95 W 231,42 S 16 33 W 0.48 .. , 55 W 247 34 S 14 39 W 0 97 94. 8.`:.,`:.,09.35 246.27 239 30 S 62. 93. 8301,87 254.78 248.76 S 61.48 W 256.24 S 13 53 W 0.29 94. ......8395-i~33~--~ 263.76 ..... 258.73-'-S~-~6~4-W~265-~67~--£S-- 8-W- ~0-.29'" ,IMASKO F'RODUCTION COMPANY 4LDAC'~ABUNA NO. 1 ¥ONEE FIELD, .ALASKA :EASUREfJ DRIFT ORIFT r, EF'TH ANGLE DIRECTION F E E T D M --- - D ......... TRUE COURSE VERTICAL VERTICAL R E C T A N G U L A R PAGE NO. - 2 CLOSURE LE:NGTH FEE] DEF'TH SECTION FEET ..... FEET-' C 0 0 R 0 I N A T E S DISTANCE F 8 E-T-~ ...... FEET DOGLEG DIRECTION SEVERITY Ir---M--- --DO/100PT- 2880. I 15 S 43 W '2974; ----1---0 ..... S'-25--W 3068. i 15 S 23 W 316].. 1 0 S 18 W -3255. - - 1 15 S 29'-W 93. 2879.83 2J.11 17.59 S 19.25 W 94 .---- 2973~.-81 .... :--24~. 89 ..... 1--9-~11--9~20 .--28-W 94. 3067.79 26.74 20.80 S 21.03: W 93. 3160.77 28.56 22.51 S 21.67 W 94. ...... 3254.76 ...... -30-. 40 ........... ~-,°~-.-~~--°~ ~.~~~ ~ . -.~ 26.07 S 47 ;35 W 0.37 ....... 27¥86---S--4-6--42-W ..... 0 · 46 29.58 S 45 19 W 0.27 31.24 S 43 55 W 0.29 32-~-98--S--4...'2--48-W----O ~- 35 .... J5"48. 1 15 S, 30 W --3442. ..... 1':0 ...... S-21--W 3536. I 30 S 47 W 3629. I 15 $ 21W 3816. I 15 S 16 W 3910. -1-15---S--24-W 4004. 1 0 S 30 W 4097. I 30 S 24 W 4191. I 30 S 32 W 4284. 1 30 S 27 W -4378-. ..... 1 -30 ---S-40-W 4472. 1 45 S 42 W 565. 1 45 S 41 W --~r~59. i ~'0---s-~s-w 93. 3347.73 32.40 ,_'"5.97 S 23.40 W 34.96 S 42 --'~ W 0.02 94.--- 3441-~-71- ........ 34 65 ....... 28 O0-S .... 24-~57-W~37~-l-2~-S-4-1--2--W~-0.3..,~ · ~' ~= ~ 72 94. ~,~oo.67 37.01 30.02 S~.74 W 39.54 S 40 36 W O. 93.~ 3628.65 39.16 31.85 S 26.97 W 41.74 S 40 15 W 0.71 94~~5722¥63 '41w2i = -33-. 78-S ..... 27.6-~W ...... 43 r67---S 59-1-9-W --0 ~ 05--- ~o~o ~o".~ ~=:~,'~,o .... *~J~ '~? . 4~, .:,~.~ -.- ~4, 4003,56,-, .¢. ,.';47'12 39. ,29 S ~ 29,82, W ',,.93~ 4096.54 /r,~ 49) 1~*~41'?0975~=, ,:~, ~ 30.74 W 94'~24190~'51 ~ 51..oo, .... 43,,26...S'~¢%~ 31.90 W 93. 4283.48 53.96 45.38 S 33.10 W 94. .... 4377.-44 ..... 56¥35 .... 47.43-S~ 34.45--W-~- 94. 4471.41 58.84 49.44 S 36.20 W 93. 4564.36 61.48 51.57 S 38.08 W 9~'7-~4'658]~2 6~r;'02 53%-67~-S- '$9~72--t,,d-- 45.56 S 38 23 W 0.07 47.51~S--37-36-W~--0-~19 .... 49.32 S 37 L2 ~ 0.29 5i.32 S 36 48 W 0.56 53.75~S-36--24-W ..... 0.22 56.17 S 36 6 W 0.14 58-'¢62~S-36 .... 0--W----0.~6-- 61.28 S 36 13 W 0.27 64.11 S 36 27 W 0.03 6-6-~-77---S--3-6--30--W~' 4752. I 45 S 34 W --4846. 1--45~--32-W 4940. 1 45 S 34 W 5033. 1 30 S 32 W 5127. -1'-45 ~S-44--W 93. 4751.29 94~----4845~-24'-- 94. 4939.20 93. 5032.16 94(----5126.12- 66.57 55.84 S 41.22 W 69.41 S 36 26 W 0.27 '69s57 58v25-S~42'~/-8--W-~ 72~-2-7~S--36--~8-W-~0~06-- 72.16 60.66 S 44.34 W 75.14 S 36 10 W 0.06 74.73 62.87 S 45.78 W 77.77 S 36 4 W 0.28 77.-27 ...... 64.97--S ..... 47.42-W ...... 80~43~S--36--8-W ..... 0.-45~- 5220. 1 45 S 36 W -5~1-4~ 2---0---S-32-W S408. 2 0 S 31W 55~1. 2 o s 30 w ---5595. ' 2- O- 9~. 5219.08 79.93 ---94.--53-13(03 ..... 82~92-- 94. 5406.97 86.13 93. 5499.92 89.32 94~ .... 5593,86 ..... 92.56 67.14 S 49.24 W 83.26 S 36 15 W 0.26 69~59--S~ 50~6--W '---86,~4~S-36--]rl'-W .... 72.49 S 52.68 W 89.61 S 36 0 W 0.04 75.28 S 54.32 W 92.84 S 35 49 ~ 0.04 78.14--S~--55¥94--W .... 96~-t0---S--35--36-W-----0.~4 i'[.HASKO PRODUCTION COMPANY xALDACFIABUNA NO'.- I 'YONEK FIELD,.ALASKA <..-CASURED DRIFT DRIFT DEPTH ANGLE DIRECTION 8496. 6 30 S 5 i · COMF'L~TATION F'AGE NO. 4 " I~ME ........ DA?P- .... 09~'35:27 O5-NOV-80 _ tRUE " COURSE VERTICAL VERTICAL R E C T A N G U L A R C L 0 S U R E DOGLEG LENGTH DEF'TH SECTION C 0 0 R r_l I N A T E S DISTANCE DIRECTION SEVERITY F IS El-- F IK E'T .... PE'B'T--' F'~ "FE~.'-T - m I:r---~----D G-/1.-00 F T- 93. 8487.75 273.08 269.00 S 59.35 W 275.47 S 12 27 W 0.29 -8590. ~--O-----S'---6--E 3600 - TIE IN POINT OF E r )0. 8 0 S 2 E ~"8"00. 8 15 S 0 E - -- 8900-. ........ ~'O~-'-<.S---O- E /W 9- .4:----- 85 81 .-7-1-0~'---2. 8~05------280 :-0 O-S~5 ~.29- W'--~ 286 .-XYI--'-S--i-1--4 6--W~O-. 55--- GYRO MS 110. 8690.].6 296.17 294.32 S 57.29 W 299.85 S 11 1W 1.03 100. 8789.16 309.36 308.45 S 57.04 W 313.68 S 10 29 W 0.38 iO0-.~8888.d.~:~~--~4~-322'.59-S~-5~7s-.O~--W~ ~..~ '3~7~59~S--1-0---?-W~ ' ~.-25~ 9000. 7 30 S 1W --91~0:---'-'-6--~;5~S----1--W 9200. 5 30 S 2 W 9300. 5 45 S 3 W --9400, .......... -6-O~-'S~2-W 9500. 6 9600. ........ 7 9700. 7 9800. 7 -~900~ ...... 7 45 S I W --'O--S --2-E 15 S 6 E 30 S 6 E ~O-'--S---9-E ...... 100.--'- 100. 8987.24 335.35 336.07 S 57.16 W 340.90 S 9 39 W 0.52 ].00~- 9086~47~~4~;'08-~348.47--S~--5~38--W------353-~6~S'---9--21--W-~O~75 - ~00. 9185~89 357 20 359 14 S 57 66 ~/100. 928~4~4~L,l~'16'6~':55~,,,~368.93 S - 58.08 100. 9682.78 409.38 A t,~ rf414,60,¢S~N~ 57.85 100. 9781.95 420.92 427.36 S 56.51 9881¥09 ......... 432.49 .... 440.30-S ..... 363.74 S 9 7 W 1.25 373.48 S 8 57 W 0.27 383.65---S---8--47-W~-- 0.27--- W 394.67 S 8 34 W 0.76 W 406.49--S~8--18-'W~0~44 W 418.61 S 7 57 W 0.56 W 431.08 S 7 32 W 0.25 54881--W ....... 443-'(70~S-'-~--6-W .... 0-.-39--- 100. 9980.18 444.29 453.62 S 52.70 W 456.67 S 6 38 W 0.50 1-00.-~0-0'~'4~--45~.78 ~6-'/.-7~~5'--W .... 470~4~S---'6~-~W 100. ~0177.91 470.25 483.15 S 47.48 W 485.48 S 5 37 W 1.01 100. 10276.50 484.43 499.50 S 44.00 W 501.44 S 5 2 W 0.42 1'00~----"'10374~98 ..... 498vgl~516-~'-39-S------39~95--W----51~.-~9-3--S---4-~5--W---O¥53 10500 10600 10700 10800 10900 · . 11 0 S 13 E o- --- 11--45 ~8 -1-1-E . 12 15 S 14 E . '10 45 S 26 E .------8--30 ~-S -37-E zlobo. 8 15 s 39 E ---I-T-I-O0~ .... 8--45 ~-g--35--E-- 11200. 8 30 S 41 E 100. 10473.27 514.29 534.32 S 35.64 W 535.51 S 3 49 W 0.77 '100.~-10571v30-~--53I-~01~553.6~ $~--31w54--W 354v51----S~3--'i-6--W~'O¥85-~ 100. 10669.12 548.54 573.90 S 27.04 W 574.54 S 2 42 W 0.80 100. 10767.11 563.79 592.60 S 20.24 W 592.95 S 1 57 W 2.82 -100~1~865¥69~574-~-18 : -:606~84-S ..... t-i-~-S:"--W~606-(95---S~I~5-W .... 100. 10964.63 581.90 618.31S 2.55 W 618.32 S 0 14 W i-O0v----lI~6~.--SJ~58-9"v95 : 63Ovl'~-2--~~34--E .... 6SOv-J:5,~<3---O--35--E'~' 100. 11162.40 597.89 641.93 S 15.57 E 642.12 S 1 23 E 0.38 0~77~ 0.93 · · ~IMASKO F'RODUCTION COMPANY ,ALDACHABUNA-NO.-1-- ¥ONEK FIELD,'ALASKA EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION FEET- D--M-- D-- FEE-T ..... FEET-~FEE~ 11300. 7 45 S 44 E L1400.----8--45-----S--48--E 11500. 10 30 S 52 E 11600. 11 0 S 51 E !1< ~ MD IS TIE-IN POINT 11-700 o-- - 10--15---S- 54-E 11800, 12 0 S 55 E i-t-~ 00-~---~.-1--45-' S--55-E 12000. 12 45 S 55 E 12100. ].3 30 S 59 E 12200.----14-15 ..... 12300. 15 0 S 66 E 12400. ....... 15-15~-S-70-E i2500. 15 45 S 73 E 12600. 16 0 S 73 E t2700. .... 16-15 ..... S--75-E .... · COM;'LrTATION T~E ' · rtCtTE 09:35:27 05-NOV-80 PAGE NO, 5 300. 16 30 S 76 E --;'I"Z850~ - t9----'0--'---S--7'8: E R E C T A N G U L A R C L 0 S U R E DOGLEG C 0 0 R D I N A T E $ DISTANCE DIRECTION SEVERITY -FEET F BE-T ,D H . DC-/-i00~T- 100. 11261.39 604.41 100, .... ~13&0-.-36 .... 610-~25 100. 11458.95 ,615.97 100. 11557.19 621.88 FROM PREVIOUS E/W GMS 652.35 S 673.06 S 684.67 S 25.12 E 652.83 S 2 12 E 0.86 -'35~44--E .... 663-.'~&~S~~4--E ..... ~-1-5~ 48.24 E 674.78 S 4 6 E 1.87 62.84 E 687.55 S 5 15 E 0.5~ ,, 100 . -1t-&55-,48 .... &27--.-43 .......&~'5 . 8~--S --~7-7 · 47 E -700-,-1-~-~S --&--2-1--E -0 .-~3 .... 100. 11753.59 632.58 707.09 S 93.17 E 713.21 S 7 30 E 1.76 1'00-~ 1-1-85 l-r45~&37-*-91 .... -718° 90--S-----1-10~.-0'Tx-E- -727~-27 S ..... 8--42--E 0-,2 5 ~ 100. 1194,9~,.~i8 643.40 7~1.07 S 127.41 E 742.09 S 9 5~ E 1.00 ~'00'. 12046~,6~e.~6'48;.~1~~7,47.43 S i46.45 E 757.72 S 11 ~ E 1.18 %6~~~6~4 ~-~6,5~5~~5~'20~'"A21~-'~0 E 804.78--S-15-2-7-E .... 1,07-- 100. 124~.20 654.~Aplri~,OA~'_%8}V~WY 2~9.74 E 820.00 S 17 0 E 0.94 100. 1~-. 49 653.46 --100,'" 12625.-55 ....... 651-.52~-- 792.17 S 265.90 E 799.8~-S .... 292.59--E-~ 100. 1~7~1.50 648.82 806.89 S 319.89 E O-t-<Y,-t:$--S-------3S3Tg~--E ' 8S5.61 S 18 3S E 0.._~ 851~,&?-~-S-.--20-~6--E~O,~i~- 847.98 S 21 38 E 0.38 ,876~25----S--22--24--E :~ t~53 ~-FINAL--CLOSURE-----DIREO-T-tON-;'" S--22--DEGS--24-HINS--E DISTANCEI 876.25 FEET ( Check Form for timely compliance with our regulations. Operator, Wel 1 Name and Number Reports and Materials to be received by: Date Completion Report Wel 1 History Samples I~ ~ ~D~u~re~ i Date Received Yes Yes Mud Log Remarks ,/,~-3)- gO Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes /-__7- gl CURVE DATA LOCATED IN THE APPENDIX , t ii AMERICAN S?RATIGRAPHIC P O BOX 2127 * ANCHORAGE. ALASKA · TRANSMITTAL COMPANY co,'~,^ ~ COMM RE3 ENG 1 ENG 2-'E~G 3 ENG 4ENG 1 GEOL 30 -- STAT TEC -- STAT TEC CONFER: FILF: Dear Sir: We have transmitted this date via ~o-o~/ -- _samples from the: ~~lease acknowledge receipt by returning one copy of this transmittal, R e c eipt acknowled ged Remarks: Very truly yours, American Stratigra'phic Co. RECEIVED DE¢29 Alaska 011 & {~as bullS. [,ommission Anohorage Form I f0-403 REV, ] 10~73 , Submit "1 ntentlons" in Triplicate j & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L I--1 GAS I'--I WELLL-.J WELL L-J OTHER Explo~ato~r 2. NAME OF OPERATOR Simasko Production Ccmpany 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 1515, Anchorage, AK 99510 1 4. LOCATION OF WELL At surface 3579' FNL, 1505' FWL, Sec. 17, TllN, RllW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re L 10. FIELD AND POOL, OR WILDCAT Wildcat · 21. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) Suspension n (NOTEh Report results of multiple completion on Well C~flpletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state &Il Dertlnent detlll~, and give pertinent dates, Including estimated date of starting any proposed work. The operator has ccmpleted an extensive testing program on this well. It has been determined frcm the testing that hydrocarbons in cc~ercial quantities could not be produced from the existing wellbore due to low permeabilities and low structural position. The operator plans to maintain this well on a suspended status for possible future re-entry and sidetracking to improve structural position. The viability of this situation will be determined~ following the interpretations of a seismic program scheduled during the next few months. Attachment "A" is a tabulation listing all perforating depths as well as bridge plugs and cement plugs used for zone isolation and suspension. Attachment "B" is a wellbore diagram showing the location of perforations and suspension plugs. The procedure for suspending the well was discussed with and yer.ball¥ approved by Mr. Bill Van Alen on November 29, 1_980. The surface c~nent plug-(f~i~ 120~ to' '~ur~c~')' %fa~ ih ~t~ce at 0415 hrs 'o~ November 30, 1980. Alaska Oil & Gas Cons, Cornmissmn Anchorago 16. I hereby cert~ that the foregoing is true~/I correct (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY: ,, TmTLE.....District Enqineer TITLE. . DATE 12/9/80 DATE See Instructions On Reverse Side ATTACHMENT "A" STATE OF ALASKA FORM Subsequent Notice of Well 12-8-80 10-403 Suspension Original Plug Back Depth (before testing); 12,877' Perforat _(by test ion Depth interval) Bridge Plug Depth (1) (zone isolation) Cement Plug Depth 12,813-12,823' 12,798-12,808' 12,782-12,792' 12,724-12,734' 12,668-12,688' 12,763' 12,651' None None (2) (2) 12,625-12,635' 12,440-12,450' 12,395-12,415' 11,950-11,960' 11,917-11,927' 11,838-11,848' 12,553' 12,306' 11,716 None None (2) Spotted 50 sx from 12,305' None (3) in casing to 12,000' 11,570-11,630' 11,462-11,522' 11,352-11,442' 11,545' 11,158' None Squeezed w/50 below retainer SX @11,158' 11,075-11,105' 10,710-10,740' (1) (2) (3) 10,942' 10,537' Ail bridge plugs are Halliburton Could not pump into formation at Could not pump into formation at None Plug No. 1: Spotted 40 sx in casing from 10,535' to 10,250'. CIP @1020 hfs 11/29/80. Plug No. 2: Spotted 60 sx in casing from 8445' to 8225'. CIP @1305 hrs, 11/29/80. Plug No. 3: Spotted 50 sx in casing from 120' to surface. CIP at 0415 hrs, 11/30/80. EZ SV drillable cement retainers. 4000 psi. 2400 psi. 1 1,5' ,¥ C.., ci lo 14//~, 1, Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. WELL WELL OTHER~"~q ~'"'*"'~ora~z 2. NAME OF OPERATOR Simasko Production Ccmpany 5. AP! NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. None 7 IF INDIAN'ALOTTEE OR TRIBE NAME Cook Inlet Region, Inc. 8 UNIT FARM OR LEASE NAME S~ Kaldachabuna #1 3. ADDRESS OF OPERATOR 9 WELL NO. P.O. BOX 1515, Anchorage, AK 99510 1 4. LOCATION OF WELL 3579' FNL, 1505' FWL, Sec. 17, TllN, RllW, S.M. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC. T R. M. (BOTTOM HOLE OBJECTIVE) Sec. 17, TllN, RllW, S.M. 12. PERMIT NO 80-69 13. REPORT TOTAL DEFFH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. SEE AT~ACHED SF~T RECEIVED DEC=91tt Oil & Gas Cons, TITLE District Enqineer DATE 12/9/80 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duphcate with the oil and gas conservation commfttee by the 15th of the succeeding month,unless otherwise directed. ll/l: Completed running gyro survey. Ran and set RTTS at 11,500'. Pressure tst 5" liner lap to 3250 psi for 30 minutes with no bleed-off. Test BOP. Cleaned out in 5" liner to 12,877' PBTD. 11/2-1/3: Perforated 12,813-12,823'; 12,798-12,808'; and 12,782-12,792' at 4 JSPF with casing guns. Ran DST No. 1 with packer at 12,740. Reversed out recovery. 11/4: Pull DST No. 1. Ran cement retainer and set at 12,763'. Attempt to break down formation for cement squeeze. Pumped in est. 1/16 BPM at 4000 psi. Did not squeeze. 11/5: Perforated 12,724-12,734' and 12,668-12,688' at 4 JSPF with casing guns. Ran DST No. 2 with packer set at 12,614'. Reversed out recovery. 11/6: Pulled DST No. 2. Ran cement retainer and set at 12,651'. Could not pump into formation at 4000 psi. Perforated 12,625-12,635' at 4 JSPF with casing guns. Ran DST No. 3 with packer set at 12,588'. Reversed out recovery. 11/7-11/9:: Pulled DST No. 3. Rig compound sprocket failed. Wait on parts and repaired compound. Completed trip out. Ran cement retainer and set at 12,553'. 11/10: Perforated 12,440-12,450' and 12,395-12,415' at 4 JSPF with casing guns. Ran DST No. 4 with packer at 12,335'. Reversed out and pulled packer loose. Trip out. 11/11-11/12: Ran cement retainer and set at 12,306'. Could not pump into formation at 4000 psi. Spotted 50 sacks of Class G cement from 12,305 to 11,934'. Pulled 3 stands and could not reverse out. Pulled out and layed down 44 joints of drill pipe (cemented). Clean out to 5" liner top with 6" bit and 7" casing scraper. Cleaned out inside 5" liner and tag cement at 11,934'. Drill cement to 12,000'. Ran 5" casing scraper. RECEIVED DEg-9 lgl j Gas Cons, ~,or. ml~sloll f f 11/13: Perforated 11,950-11,960; 11,917-11,927; and 11,838-11,848' at 4 JSPF with casing guns. Ran DST No. 5 with packer set at 11,777'. Reversed out and pulled packer loose. Trip out. 11/14: Ran cement retainer and set at 11,716'. Pressured up on formation with rig pump to 2400 psi with negligible fluid entry. Reduce mud weight from 10.9 ppg to 10.0 ppg. 11/15: Perforated 11,588 to 11,604' at 4 JSPF with casing guns. Ran DST No. 6 with packer set at 11,495'. Reversed out recovery and pulled packer loose. Trip out. 11/16: Trip in and clean out. Perforated 11,600-11,630' and 11,570-11,590' at 4 JSPF with casing guns. Ran DST No. 6B with packer set at 11,468'. 11/17-11/19: Completed DST No. 6B. Reversed out recovery and pulled tools. Ran cement retainer and set at 11,545'. Change over from conventional drilling mud to Calcium Chloride completion fluid. Made clean out trips with 9 5/8" and 7" casing scrapers. 11/20: Perforated 11,462-11,522' at 4 JSPF with casing guns. Ran DST No. 7 with packer set at 11,406'. Reversed out recovery. 11/21: Pulled DST tools. Ran retrievable bridge plug and set at 11,455'. Perforated 11,352-11,442' at 4 JSPF with casing guns. 11/22: Ran DST No. 8 with packer set at 11,289'. Reversed out recovery. 11/23-11/25: Pull packer loose and trip out. Reran DST tools. Set packer at 11,292 and retested interval as DST No. 8B with an extended flow period. Reversed out recovery, pulled packer and trip out. Released retrievable bridge plug. 11/26: Bridge plug stuck at 11,359'. Worked free and trip out. Ran cement retainer and set at 11,158'. Establish injection rate into formation and cement squeeze below the retainer with 50 sacks of Class G with additives. CIP @1100 hrs. Final squeeze pressure was 3750 psi at 1/4 BPM. Perforated 11,075-11,105 at 4 JSPF with casing guns. Ran ~~V~ No. 9 with packer set at 11,040'. DEC-9 1980 Alaska Oil & Gas Cons. Commission Anchorage ( (' 11/27: 11/28: 11/29: 11/30: Reversed out recovery and pulled packer loose. Ran cement retainer and set at 10,942'. Perforated 10,710-10,740 at 4 JSPF with casing guns. Ran DST No. 10 with packer set at 10,666'. Reversed out recovery and pulled packer loose. Ran cement retainer and set at 10,537'. Spotted a 40 sack Class G cement plug on top of the retainer. CIP at 1020 hrs. Picked up to 10,250' and reversed out excess cement. Picked up to 8445' and spotted plug No. 2 (60 sacks Class G) from 8445 to 8225' across the 7" liner top at 8330'. CIP at 1305 hrs. Laying down drill pipe. Complete laying down drill pipe and collars. Spotted a viscous gel pill from 185' to surface. Pick up to 120' and spotted a 50 sack cement plug to surface. CIP at 0415 hrs. Wash cement out of top 10' of casing. Fill with glycol and water. Nipple down BOP and instal~-~spension wellhead. Released rig.,~ Well suspended~.~.~ DEC - 9 Alaska 0il & Gas Cons. C0~mfss~0n Anchorage Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5 AP! NUMERICAL CODE 50-283-20066 6 LEASE DESIGNATION AND SERIAL NO. None 1. 7. IF INDIAN-ALOTTEE OR TRIBE NAME OIL [] GAS [] Exploratory Cook Inlet Region, Inc. WELL WELL OTHER 2. NAME OF OPERATOR 8.UNIT FARM OR LEASE NAME Simasko Production Company SIMPCO Kaldachabuna 3 ADDRESS OF OPERATOR 9.WELL NO P.O. Box 1515, Anchorage, AK 99510 1 4. LOCATION OF WELL 3579' FNL, 1505' FWL, Sec 17, TllN, RllW, S.M. 10. FIELD AND POOL, OR WILDCAT Wildcat 11 SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 10/1: Complete logging. Ran FDC-CNL/GR. Trip in and condition hole for casing. 10/2: Trip out. Rigged up and ran 33 jts 5", 17.93 lb/ft, N-80 Atlas Bradford FL4S liner on BeT multicone hydraulic set liner hanqer w/6'~ tie-back sleeve. Set hanger w/shoe at 12,961' and liner top at 11~5~7~. Condi%ion hQle and prepare to cement. 10/3: Pumped 20 bbls Dowell's Spacer-1000 mixed to 11.5 ppg. Mixed and pumped 250 sacks Class G containing 0.17 gal/sk D80, 0.4 gal/sk D108, and 0.04 gal/sk D81R. Displaced with mud. Overdisplaced by 2 bbls and did not bump plug. Released from hanger and reverse out. CIP at 0200 hrs. 10/4: WOC 24 hrs and tested liner hanger to 2000 psi with packer on drill pipe. Bled down to 1900 psi in 30 minutes. Tripped out and ran cement retainer and set at 11,477'. Pumped in water spacer at 3000 psi. Could not establish formation breakdown. 10/5: Milled out cement retainer. 10/6: Ran packer and 5 stand tailpipe on drill pipe. With tailpipe at the 5" liner top, spotted 75 sacks of Class G cement. Picked up 150' and reversed out excess cement. Picked up 30' and set packer. Squeezed cement around liner at 3000 psi. Held pressure on squeeze for 12 hours. 10/7: Bled off pressure. Released packer. Could not pull loose. Could not pump through drill pipe. Backed off between packer and by-pass. Left packer and tailpipe in hole. Weather down. Wait on tools. 10/8: Wait on tools. Weather down. 10/9-10~25: Fishing for packer. Milled over packer. Recovered packer %n three separate sections. 10/25-10/27: Washed over drill pipe and recovered same. 10/28-10/29: Drilled out hard cement from 11,362 to liner top at 11,547'. Cleaned out inside 5" liner. 10/30: Ran li~er/i~ack dressing tool in 9 5/8" x 7" hanqer. Ran casinq / /;~z~ / (SEC ATTACHED SHEET) SIGNED ... ~ ~ .' ! //~"-~- TITLE President 11/10/80 ~ o ~. ~ ~ ~iF1'' DATE , ~ ...... ~ ~ ~ NOTE--Report on this form is required for each calendar month, regardle~ of the .atu, of operations, and mu. be filed in d~lg~ ~lhg~ U oil and gas conservatmn committ~ by the 15th of the succeeding month.unl~ otherwise directS. Alaska Oil & Gas Cons. Commission A~,~;~o ~e ( Form 10-404 Monthly Report of Drilling & Workover Operations Month of October, 1980 SIMPCO Kaldachabuna #1 scrapers in 7" liner and 5" liner. 10/31: Ran VDL-CBL/GR and Spectralog. Running gryro survey at 2400 hrs. Alaska Oil & C.~s Cons. Co~rnissior~ Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Oo not use this form for prol~osals to drill or to deel~en 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I.--.I OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchoraqe, AK 99510 4. LOCATION OF WELL At surface 3579-FNL, 1505' FWL, Section 17, TllN, RllW S.M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re None 7. IF INDIAN, ALLO~EE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 9. WELL NO. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 15. SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Otb.r) Runninq & Cmntinq 5" Liner (NOTEt Report results of multiple completion on Well CemlHetlon or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent details, anti give pertinent dates, including estimated date of starting any proposed work. A 6" hole was drilled to 12,976' (MD), 12890' (TVD) and logged. Ran 33 its of 5", 18 lb/ft, N-80, A/B FL-4S liner with a BeT MC hydraulic set liner hanger. Hung liner with the top at 11,547' and the shoe at 12,961' MD. Cemented around the shoe with 250 sacks Class G cement containing 0.17 gal/sk Dowell's D-80, 0.04 gal/sack D-81R, and 0.4 gal/sack D-108. Displaced plug with mud, 2 bbls over calculated value to seat plug but did not bump. CIP at 0200, 10/3/80. Tested liner lap with packer after 24 hr WOC. Slight leak-off at 2000 psi. Spotted 75 sacks of Class G cement on top of liner hanger and squeezed with 3000 psi on 10/6/80. Cemented packer in the hole. Fished out packer and tail pipe. Clean out excess cement to the liner hanger. Tested liner lap to 3000 psi for 30 minutes with no leak-off. Last lap test was conducted on 11/1/80. Delay was due to fishing operations. 16. I hereby certif~h~l~~ru,e and correct SIGNED~ Subsequent Work Repor~e~ TITLE President DATE 11/3/80 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side I Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE ( STAT OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL WELL 2 NAME OF OPERATOR 3 ADDRESS OF OPERATOR OTHER Exploratory 5. APl NUMERICAL CODE 50-283-20066 ~ 6 LEASE DESIGNATION AND SERIAL NO. · None ~~. 7. IF INDIAN-ALOTTEE OR TRIBE NAME Cook Inlet Reqion 8. UNIT FARM OR LEASE NAME SIMPCO Kaldachabuna Simasko Production Company P.O. Box 1515, Anchorage, AK 99510 4. L~ATION OF WELL 3579' FNL, 1505' FWL, Section 17, TllN, RllW, Seward Meridian 9. WELL NO. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11 SEC. T. R M. (BOTTOM HOLE OBJECTIVE) Sec. 17, TllN, RllW, S.M. 12 PERMIT NO. 80-69 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 9/1 Milled on junk from 11,644' to 11,654'. Partial recovery. 9/2 Condition hole to run 7" liner. Ran 79 jts. 7", 26 lb/ft, S-95, LT&C liner with BOT Boll Weevil mechanical set hanger. 9/3-9/4 Hung liner with top at 8330' and shoe at 11,647'. Cemented with 900 sacks Class "G" cement and additives. Displaced with mud and bump plug with 3000 psi. CIP at 0720, 9/3/80. Ran RTTS packer and cement squeezed liner lap with 100 sacks Class "G" plus additives. WOC 24 hours and cleaned out to liner top. 9/5-9/9 Pressure tested liner lap to 1000 psi. Would not hold pressure. Set cement retainer at 8267'. Cement squeeze liner lap with 100 sacks Class "G" cement with additives. WOC 24 hours and drilled out retainer and cement. Pressure tested liner lap to 2000psi for 30 minutes, OK. Cleaned out to 11,618'. Pressure tested liner pipe and lap to 2000 psi, OK. Ran gyrosurvey. Drilled out shoe and formation to 11,664'. Tested formation to equivalent gradient of 0.65 psi/ft, with no leak-off. 9/10-9/27 Drill 6" hole to 12,976'. Circ and condition hole for logs. 9/28 Logging tools would not go to bottom. Ran bit and clean out. 9/29-9/30 Logging. Ran DIL-SP/GR, BHC Sonic-~R. Could not get density log to bottom. Ran bit and cleaned out. Making 14 stand short trip at 2400 hrs 9/30/80. 00T1 1980 Ancho~a~j~ -- 14. I hereby c~~yjZ~/d co.ect SIGNED_ ~ f~ L~QC~' ~ ' ~ ~ ~ ~ - _. TITLE ' r ' ' DATE ~ MOTE-Re~o~ on th~s form is reqmred for each calendar month, eeoardle~ of the ~atus of o~erations, and mu~ be file~ oil and oas gonservation ¢ommitt~ by the 1~th of the sue~m~ month,unl~ otherwise directS. Form No 10-404 REV 3-1-70 ( ~ SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. WELL WELL OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchoraqe,, ~ 99510 4 LOCATION OF WELL 3579' FNL, 1505' FWL, Section 17, TllN, RllW, Seward Meridian 5. AP! NUMERICAL CODE 50-283-2006 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN'ALOTTEE OR TRIBE NAME Cook Inlet Region, Inc. ~, 8 UNIT FARM OR LEASE NAME SIMPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M 12. PERMIT NO 80-69 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 8/1-8/3 8/4 8/5 8/6 8/7 8/8 8/9-8/10 8/11 8/12 8/13 8/14-8/15 8/16 8/17 8/18-8/19 8/20 8/21 8/22-8/25 8/26-8/27 8/28 8/29-8/31 Drill to 11,292'. Drilled to 11,303'. POH. Stuck pipe at 9263'. Backed off at 9106'. PU fishing tools. RIH and screw into fish and jar loose. POH. Lost fish. Clean out to top of fish at 10,933'. Trip out. Stuck pipe at 9195'. Spotted SFT pill. Work stuck pipe. Backed off at 8630'. ~H with fishing tools. Screw into fish and backed off 9085'. POH with part of fish. Fishing with no success. Wash over fish. LD wash pipe. Clean out to top of fish. RIH with fishing tools. Screw into fish and jar loose. POH. ;L~D fish. Clean out to top of first fish. RIH with fishing tools. Could not engage fish. Clean out to top of fish. RIH with overshot and engage fish. Pulled fish up the hole 110' and overshot released. RIH with smaller overshot. Engage fish. Attempt to back off. Overshot released. Ran overshot extension and work over fish. Backed off at 11,003'. POH and LD part of fish. RIH with fishing tools and screw into fish and jar loose. POH. Condition hole to log. Logging. Ran DIL, FDC/CNL, BHC Sonic, and dipmeter. RIH with reverse circulating junk basket. Wash to bottom. Cut 2' core to recover junk. No recovery. RIH with mill. Mill on junk. RIH with bit and drill ahead to 11,325'. Drilled to 11,644. POH. Stuck pipe at 9230'. Spot SFT pill. Work stuck pipe. Backed off at 9192'. Screw into fish & jar loose. POH. Condition Hole Logging. Ran DIL,FDC/DNL,BHC Sonic, & dipmeter. RIH wlmill & 14 lherebycert~that~fo~o],n~,strue.~d;o.~t- junk basket at,2400 hrs 8/31/80 SIGNED ( . .n.n.n.n.n.n.n.n¥~, . .'~ - ~~ TITLE District Engineer DATE 9/15/80 NOTE-Reportonth,sform~' K' ~isrequirZoreachcalendar month, regardl'e, of the status of operations, and mu. oil and gas conservation commKt~ by the 15th of the succ~ing mo.th.unl~ otherwise dir~t~. o..P ! 5 AlasKa 0Il & ~as ~o,:o. ~rS,,J.~,. ~ Form 10-403 REV. 1-10-73 Submit "1 ntentlons' In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-283-2006 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) z. O,L [--] GAS ~ Exploratory WELLL.2 WELL L--J OTHER 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WELL At su dace 3579' FNL, 1505' FWL, Section 17, TllN, RllW, Sewart Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72 (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re None 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region~ Inc 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 9. WELL NO. 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF B REPAI RING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SNOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ill I~rtlnent detllll~ Ind give pertinent dates, Including estimated date of starting any proposed work. The origihal drilling plan called for 7" liner to be run to the proposed TD of 12,500'. Due to hole problems, it was necessary to run 7" liner to a shallower depth of 11,647'. Additional drilling to the original proposed TD will be with a 6" bit and drilling assembly. This was discussed with Mr. Russell Douglass on August 22, 1980. If pipe is to be run in the 6" hole, the operator plans to run 5", 18 lb/ft, N-80, FL4S Atlas Bradford, as a liner with a minimum of 100' liner lap. Cementing would be done with 60 sacks of Class "G" cement and appropriate retarders, fluid loss additives and turbulence inducers. (Includes 30% excess) It is anticipated that all drilling below the 7" liner will be done with 9.8 to 10.2 ppg mud weights. 16. I hereby certify that the foregoing Is true and correct 'T"is space '°r Statt~°.~' use)' /~'( ,/` / COMMISSIONER , DATE C) /1 ~ /RO · . See Instructions On Reverse Side DATE . ! Ret~rn~ d · Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proDosals to ~lrill or to ~leepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. WELLL__.IOIL I I WELLGAS [~ OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchorager AK 99510 4. LOCATION OF WELL At surface 3579' FNL, 1505' FWL, Section 17, TllN, RllW, Seward Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L.__J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 50-283-2006 6. LEASE DESIGNATION AND SERIAl NO. J None 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LE~E NAME SIMPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. ].2. PERMIT NO. 80-69 3ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (om.r) Running & Cmntnq 7" liner (NOTEI Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all laertlnent detall~, and give pertinent dates, including estimated date of starting any proposed work. Due to hole problems, the operator elected to run the 7" liner shallower than originally planned. An 8%" hole was drilled to 11,654' and hole was logged. Ran 79 joints of 7", 26 lb/ft, S-95, LT&C and Brown Oil Tool Boll Weevil mechanical set hanger (OAL 3317.55') and landed at 11,647' with liner top at 8330'. Cemented around shoe with 900 sacks Class "G" cement containing 0.04 gal/sk D81, 0.2 gal/sk D108, and 0.17 gal/sk D80. Displaced with mud. Bumped plug with 3000 psi. CIP at 0720, 9/3/80. Cement squeeze liner top with 100 sacks Class "G" with same additives as primary job. WOC 24 hours and pressure tested liner lap. Test failed. Resqueezed with 100 sacks of Class "G" as above below a retainer at 8267'. CIP at 2125 hrs 9/5/80. WOC 24 hrs. Drill out retainer and pressure tested liner lap with 2000 psi for 30 minutes - OK. RECEIVED Subsequent Work Reported on Form No. ------ Dated ---/--/-- !980 AlasKa 0~1 & Ga~ (~ons, C~mmiss 16. I hereby certif~hat the foregoing is true and corre,ct SIGNED B · R; Allard / ~ , TITLE T~ .~_r~ ~.t Enq~neer (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE 9 / 1.5 / 80 DATE See Instructions On Reverse Side -- - THE OIL DAILY. THURSDAY, SEPTEMBER 11. 1980 3 ?rati~n Update / Le rge Alaska Fi VANCOUVER -- Warrior Re- sources Ltd and Double Eagle Energy and Resources Ltd say they have made a large oil find in south- by .nd ern Alaska The two affiliated companies said it is' onshore _we_st of Cook Inlet v~ill yield hydro- carbonS for prgduct, ioh Previous- attempts to find oil in the region failed, they said Trading in the companies' stock was halted in London, Vancouver and on the over-the-counter market in the U S. after sharp rises in the price of the companies' stock. The well is cased and lined to 11,647 feet, allowing drilling to 12.500 feet, and is safe after prob- lems which endangered the well and added substantially to costs, said the firms More tests ofthe well are expected to take two Unit Dz~lling Well Flows TULSA, Okla -- Unit Drilling and Exploration Co's Beck No 1 well in Hansford County, Texas, flowed 9 49 mihon cubic feet of gas a day with perforations from 7,596 to 7,600 feet The company said the well, a Chester gas discovery in Section 80, Block 't6 of the H and TC survey, flowed through a 35/64-inch choke with 1,013 pounds per square inch flowing tubing pressure Unit Drllhng, the operator, and the Unit 1980 Oil and Gas Program hold a 100 percent working interest in the well and In the 1,440-acre Two Firms Halts Trading in Their Stocks Kearney No. 1-Well Keeps Drilling DRILLING CONTINUES on Resources Investment Corp.'s Kear- ney No. I well zn the Bayou Carhn Fzeld, East Cote Blanche Bay, in St. Mary Parish, La. The posted drzlling barge Goldrus Marine I, owned by Goldrus Marzne Drzlhng Co of Houston, spudded the well July 6. The well is scheduled to reach its total depth of 18,200 Petroleum Carp, It added. The well is selling gas to Tennessee Gas Pipeline Co at the rate of 350,000 cubic feet dally at a price of $2 46 per ~nilhon BTUs, the company said Firms Hit Turkish Oil TORONTO- Gulfstream Re- sources Canada Ltd., North South Resources Ltd and Eurocan Ven- tures Ltd say their joint well in southeast Turkey discovered oil in the Raman Formation - A 12-hour test on Sept 5 and a 17-hour test Sept 6 yielded be- tween 14 and 16 barrels of oil per hour, indicating potential rates of 336 to 384 barrels of oil a day, the companies said ' The well has been shut in pend- ing arrangement for production storage facilities, truck transport and crude sales contract The companies said they plan to move the rig and begin a well known as Mollacabir No 1 Crown Central Well Hits MIDLAND, Texas -- Crown Cen- tral Petroleum Corp. has a 1207 percent interest m a Pottawatomm County, Okla, well that tested 840 barrels of oil daily from two zones, Estoril Producing Carp said Estoril said its EPC 1980-1 LTD drilling program owns about 46 per- cent of the Clyde Coleman No. 1 well, while the rest is held by Rowe Group, Estoril and other private in- terests. gas, Verdens Gang newspaper said Tuesday. The first well drilled by the Norsk Hydro Co no]"~h of the parallel earlier thJs qummer ga, no sign of oil or gas But a second well drJlled by the Statoll platfm m Ross Rlgg indicates there may be some oil some 3.500 3 ards below the ocean floor, the paper smd Ross Rigg dlsrovercd hydrocar- bons some 9,000 feet below the sea bed, and there were other Indica- tions there may be off further do\vn the paper said Statofl refi~sed com- ment on the reporl InterNorth Ptan Backed WASHINGTON -- The Depart- ment of Enel~' has authorlTCd In- terNorth Inc. to import as much as 200 milhon cubic feet of natural gas a day from Canada for the seven years InterNorth was allowed to purch- ase the gas at $447 per mlll~on BTUs, which is thc prevailing bor- der price for gas imported from Canada While approwng the ~mports, the department ordered further pro- ceedings to determine ~hcthcr conditions should be placed on the approval to prevent undue reh,~nce by InterNorth on tngh-prlced Cana- dian gas. The Department found Inter- North needed the gas to help re- duce curtailments of services and to permit the company to provide more rehable service. O'~o O - z.- DO0 v'- /~O q Form No 10-404 REV. 3-1-70 ' . SUBMIT IN DUTLICATE STATE(" ALASKA AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTH~ Exploratory NAME OF OPERATOR Simasko Production Company ADDR~ OF OPERATOR P.O. BOX 1515, Anchorage, AK 99510 4. LOCATION OF WELL 3579' FNL, 1505' F~, Section 17, TllN, RllW, S.M. , APl NUMERICAL CODE 50-2R3-20~66 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN-ALOTTEE OR TRIBE NAME Cook Inlet Region: 8. UNIT FARM OR LEASE NAME SIMPCO Kaldachabun~ 9. WELL NO. 1 10. FIELD AND POOL, OR WILDCAT Wildcat i !. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 17, TllN, . 12. PERMIT NO. Ro-Rq 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. RllW, S.N See attached R CElVED Alaska 0il & Gas C.~,,,... ,',~.~.-, -- An~ilor~ SIGNED ~'~'~--~' 'k~'-'-~v.,~ .... ~'~ TITLE District Engineer DATE 8/14/80 _ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ( 7/1: 7/2: 7/3: 7/4-7/5: 7/6: 7/7-7/8: 7/9-7/10: 7/11-7/12: 7/13-7/14: 7/15: 7/16-7/17: 7/18: 7/19: 7/20-7/21: 7/22-7/24: 7/25: 7/26-7/31: Drill to 10,868'. Stuck pipe at 10,868'. Spot SFT pill. Backed off at 10,722'. RIH with fishing tools. Jar on fish. Fishing. Recovered 3 drill collars and 2 stabilizers. Top of fish at 10,822'. Fishing and wash over. No success. Spot 50 sacks Class "G" neat cement plug with 8 % sand from 10,821' to 10,727'. WOC. RIH with Dyna Drill. Washed off cement plug. POH. Spotted 65 sacks Class "G" cement plug with 8% sand from 10,775' to 10,688'. WOC. Dressed plug to 10,712'. Run Dyna Drill. Kick off at 10,712'. Drill to 10,770'. Drill to 10,880'. Stuck pipe on bottom. Spotted SFT pill. Ran free point and backed off at 10,852'. RIH with fishing tools. Could not jar loose. Backed off at 10,852'. Ran wash pipe and washed over to 10,874'. Twisted off washover shoe. Made attempt to jar fish loose with no success. Spotted 95 sacks Class "G" neat cement plug with 8% sand from 10,849' to 10,575'. WOC. Dressed off cement plug to 10,772'. Ran Dyna Drill and kicked off at 10,772. Drilled to 10,837'. Lay down Dyna Drill. Drilled to 10,941'. Spindle failed on bit leaving cone in hole. Ran mill to drill up junk. Milled on junk. Partial recovery on junk. Drilled to 11,147'. (midnight 7/31/80) Alaska Oil & (~as Oo~o. Anchorage · , Form 10-403 REV. 1-10~73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for prol~osal$ to drill or to deepen Use "APPLICATION FOR PERMIT--*' for such proposals.) O,L I--1 GAS r-I WELL l I WELL! ! OTHER Exploratory NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchoraqe, 4. LOCATION OF WELL At su trace AK 99510 3579' FNL, 1505' FWL, Section 17, TllN RllW~ S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN, ALLO~EE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT I"'-"-"1 SHOOTING OR ACIDIZING (Other) Sidetracki-n-~ REPAIRING WELL ALTERING CASING ABANDONMENT* Fish (NOTEt Report results of multiple completion on Well C~mpleth~, or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state Ill I~ertlnent dltllll, and give pertinent dates, including estimated date of starting any proposed work. On July 14, 1980, the bottomhole drilling assembly stuck while drilling at 10,880'. Fishing efforts were not successful and a bit, junk sub and monel drill collar were left in the hole. The hole was plugged back from 10,849' (top of fish at 10,852') to 10,575' with 95 sacks of class "G" cement containing 8% sand. The cement plug was dressed off to 10,772'. Using a downhole mud motor, the fish was successfully sidetracked from the kick-off point at 10,772'. RECEIVED Alaska 011 & An~llor=~ 16. I hereby certify that the foregoing is true and .cgrrect TITLE District Engineer DATE 8/14/80 (This space for State office use) APPROVED BY.. CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE Form '10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~, for such proposals.) WELL I--_J OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box i515, Anchorage, AK 99510 4. LOCATION OF WELL At surface 3579' FNL, i505' FWL, Section 17, TllN, RllW, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) /14.92' (GR); 131.72 (KB) 14. 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. None ,F ,.D,A.. ALLO Ei Cook Inlet Region, Inc. ~. U--"""~,~OR LEAS NAM S IMPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat -ll. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. 12. PERMIT NO. 80-69 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO= SUBSEC~UENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ~ ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTINGI OR AClDIZING ~ ABANDONMENT* REPAIRWELL CHANGE PLANS (Other)Sidetracking fish (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnellt gletlll'~"en¢l give pertinent dates, including estimated date of starting any proposed work. While drilling at 10,868' on July 1, 1980, the bottom hole drilling assembly became stuck. Efforts to retrieve the drilling tools were not successful and it was necessary to leave a monel drillcollar, two RWP stabilizers, and an 8[" bit in the hole. The hole was plugged back from 10,822' (top of fish) to i0,688' with 115 sacks of Class "G" cement containing 8% sand. The cement plug was dressed off to 10,712'. Using a downhole mud motor, the sidetracked hole was successfully kicked off at 10,712!. JUL 1 ? 19 0 SIGN~- (This space for State office use) Alaska 011 & ~as Gu,,~, Anchorage TITLE District Engineer 7/17/80 ------,-- DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form No 10-404 REV 3-1-70 STATE UF ALASKA OIL AND GAS CONSERVATION COMMIT' MONTHLY REPORT OF DRILl AND WORKOVER OPE WELL WELL OTHER gxp j COMMM¢; J COMM I RES ENG - 'J~ EJ 1 ENG '~) s ^PI NUMEmC^L CODE 50--283--20066 '- J O I::!~"'~ (~ ~~ 6. LEASE D~IGNATION AND SERIAL N0. ~IN~G L ~ ~o~e J ,STAT TE~ ~TAT TEC-- S ]~CO K~dachabuna ~ J ~. WELL~O. CO~ER~ FILF: ~o. FIELD A~D ~OL, OR WIL~T S. H. Sec ~7~ T~N~ R~ S. 2. NAME OF OPERATOR Simasko Production Company' 3. ADDRESS OF OPERATOR P.O. tsox 1515, Anchorage, 99510 4. LOCATION OF WELL 3579' FNL, 1505' FWL, Section 17, Ti .M. 12. PERMIT NO. 80-69 13. REPORT TOTAL DElrI'H AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING .lOBS JUNK IN HOLE AND SIDE.TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 6/1 - 6/5/80' 6/6' 6/7' 6~8' 6/9' 6/10- 6/11' 6/12- 6/17/80' 6/i8 - 6/30/80' Drill 12¼" hole from 7832' to 8675' Test BOP. Circulate and condition hole to log. Ran DIL, Dipmeter, Density-Ne~+ao~./Gamma Ray-Caliper and Compensated Sonic Logs. Ran magn. etic multi-shot and gyro surveys. Rig up to run cas lng. Ran 64 its ~, 43.5 lb/ft, S-95, LT&C from 8671 to 5900'; 116 3ns, w 5/8", 43.5 lb/ft, N-80, LT&C, from 5900 to 1548'; 41 its, 9 578", 40 lb/ft, N-80, LT&C from 1548 to surface. Cemented casing with 700 sx Class "G" containing 0.17 gal/sk D80 (TIC), 0.04 gal/sk_ D81R, and 0.2 gal/sk D108 (FLAC). Displaced plug with mud and bumped at 2500 psi. Full returns throughout.-CIP at 10:55 p.m. Landed casing in slips. Nipple up casing head and BOP. Tested BOP. PU drillin$ assembly. Drilled float and cement to 8633'. Tested caszng to 2500 psi. Drilled shoe and formation to 8685'. Conducted formation integrity test to equivalent gradient of 12.1 ppg at the shoe. No b~leed-off. Drilled ahead with 8~" hole @8752. Dkilled 8~" hole from 8752 to 9242' Submitted new "Application for Permit to Drill" f~r deviated hole. Permit No. 80-69 approved and issued by the Alaska Oil and Gas Conservatiori Commission on 6/19/80. Drilling 8~" hole from 9242' to 10815' at midnight 6/30/80 RECErVED 14. ! hereby ~er~h~t~ f~.~omg ~ true and co~t ' NOTE~~ ~ t~orm is required for each calendar month, r~ardle~ of the matus of operatiom, and mu~ be filed in duplicate with the , oil and ~s conse~ation committ~ by the 15th of the succ~ing month, unl~ othe~ise dir~t~. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilt~-o~~r Chairman/Commiss Thru: Lonnie C. Smith ~~ Commissioner Harold R. Hawkins Petroleum Inspector June 23, 1980 B.O.P.E test Simpco Kaldachabuna No. 1 Simasko Prod. Co., Sec. 17-TllN-R 11 W-S. PERMIT NO. 80-4 June 10, 1980, I left my house at 3:30 pm for a check in at Anchorage Air Service, for a flight at 4 pm to Tyonek. The flight was delayed for two hours and 45 minutes, as the controls on the tail section of the Titan airplane were froze up, and would not operate. I left Anchorage at 6~45 pm and arrived at Tyonek at 7 pm. I arrived at Simasko Drill site at 7:15 pm; the B.O.P.E test started at 7:30 pm on Simpco Kaldachabuna No. 1. I filled out an A.O.&.G.C.C, B.O.P.E Inspection Report, copy attached. In Summary: I witnessed a 5000 P.S.I.G test on the B.O.P.E for Simasko Production Company. There were no failures. Test was satis- factory. HRH/mm 0&G #4 4/80 (" ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report I n spe c t o r ~.~. ~L//f/~;3' Date ~--/~'- ~8 Wel 1 /6/~ / Operator -5/ /2~-Jj~Z9 Well J/.? / Location: Sec / ? T//~/ Drilling Contractor Location, General Well Sign_ _~Q ~' General Housekeeping ~,~ Reserve pi t .~ Rig ~9 /~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure Representative Permit # Representatlveo ACCUMULATOR SYSTEM Full Charge Pressure /J~c3 psig Pressure After Closure ./~d~ psig 200 psig Above Precharge Attained: ,/,~ min~ Full Charge Pressure Attazned: ,~-- min__s Control s~: Master /~/~ -- , , Remote_~_~____Bllnds swiach cover Kelly and Floor Safety Valves Upper Kelly. Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. flanges Test Pressure Test Pressure Test Pressure ,/~///~ Test Pressure Test Results: Failures ~ Repair or Replacement of failed equipment to be made within '-----days and Inspector/Commission office notified. Adjustable Chokes _~/~ ~Hydraulcally operated choke. Test Time '--_~_'- hrs. /~. Distribution orig. - AC&GCC cc - Operator cc - Supervisor $~maako Pr~uo~~n Company P. O. Box 1515 Anchorage, Alaska 99520 Simasko Production Conpeny · ermit No. 80-69 BottomholeLoc't 4370'fNL, 14808FWL, See. 27, TXX,, R22#, SM. Dear Mr. Allard ~ Enclosed is the approved application for permit to drill the above r~£eFenced well. Well *auplea, sore chips and a mud log are requ~ed. A directional, survey is required. If available, a tape contain- tag ~ digitized log information on all logs shall be sub- n~Ltted for copying except experi~ental logs, velocity surveys and d~pme~er surveys, Many rivers in Alaska and their drainage systems have been clasal£ied as important for the spawning or migration of anadrcuovs fish. Operations in these areas are subject to AS 16.$0.870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any ~aters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 28, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. B. R. &l lard SINPCO ~aldachabuna 1~o. 1. -2- June 19, 1980 coemmnc~ng op~rationa you may be contacted by a.representative of the Department of 2nvironsmntal Conservation Pursuant to ~ 38.40,/Local Bite Under State Leases, the alaska Depar~smnt of Labor i& bain9 not~£ied of the issuance of this lmZ~lt to drill. To aid us in schedulinq ££eld work, we ~uld a~r~ate not~y~nq th~ off~ w~th~n 48 hours a~ter ~e well ~d~. We would al~ l~ke ~ ~ ~t~f~ ~ that a repre- sentative o~ b amisli~ may ~ ~esent to vLtnes8 testing o~ bl~ut pr~enter ~u~pent ~fore surface casing ~oe drilled. In ~e ~ent of ~s~ns~on or ~ndo~ent,please g~ve office ad~ua~ advance ~tifioatl~ so ~at ~ may ha~ vaz~ ~'u. ly ~ s, Lonnie C. ~t~h C~ission~ o~ BY ORDER OF THE CO~;~,flSSlON Alash Oil i Gas ~nOe~atton Co~iosion Enclosure cc: Department o£ Fish & Came, Habitat Section v/o encl. Department o£ Bnvironment~l Conservation w/o/enol. Department Of Labor; Supervisor, Labor Law Compliance Division w/o encl. ( Supplemental Data Sheet for Application for Permit to Drill (Deviated Well) SIMPCO Kaldachabuna Well No. 1 June 17, 1980 I. Deviation Plan The purpose of this application is to change the wellbore location from a "straight hole" as per the original application for permit to drill to a location established by the operator as the maximum limit of horizontal displacement along an established directional course of natural trend. The well was drilled to 8675' MD. Single-shot deviation surveys were run while drilling. Below 7500', the deviation angle began to increase naturally and single-shot directional surveys were then run. At 8675', a magnetic multi-shot survey was run back to the shoe of 13 3/8" surface casing at 2476'. A gyroscopic survey was then run to surface to establish the bottom hole location. The 9 5/8" casing was run and landed at 8671'. The casing was cemented as per the original drilling plan. Drilling has continued with single-shot directional surveys taken approximately every 100'. The established natural trend of the wellbore course is approximately SO4°E. The operator proposes to drill ahead along the natural trend without special efforts to control the deviation and direction by the use of downhole mud motors or whipstocks. The only proposed controls will be in the bottom hole drilling assembly (i.e. "angle dropping" pendulum assembly, and "packed hole" assembly to minimize wellbore deflection, primarily for deviation control). A target point at +9950' TVD of 4370' FNL, 1480' FWL, Sec. 17, TllN, RllW, S.M. has been established by the operator to represent the maximum limit of horizontal displacement at the top of the proposed producing zone. This point falls within the "500-foot" lease line limit. A letter of non-objection from the only affected operator is attached. The wellbore course is not expected to change significantly as drilling progresses. Similarly, the wellbore deviation is not expected to increase rapidly. Consequently, the actual wellbore location at the top of the proposed producing zone will likely be closer to the surface location than the proposed target point. Single-shot directional surveys will be run and when TD is reached, a magnetic multi-shot survey will be run in the open hole section. This data will be tied in to the existing survey data to fix the bottom hole location. Supplemental Data Sheet Application for Permit to Drill SIMPCO Kaldachabuna 91 June 17, 1980 Page Two II. Casing Program 7" 26 lb/ft, S-95, LT&C: Liner from 8400' to 12,500' III. Cementing Program The 7" liner will be cemented with 290 sacks of Class "G" with fluid loss, turbulence inducer, and retarder additives followed by a 100 sack Class G down-squeeze at the liner top for a total of 390 sacks. The down-squeeze slurry will contain appropriate additives for squeeze cementing. The open-hole volume should result in a 2000' cement column (includes 30% excess). The cement slurry will be preceeded by a water spacer containing clay stabilizing additives. Actual volumes will be calculated from open-hole caliper data on electric logs. IV. Drilling Fluid Program 8671' to 12,500 TD - Inhibited Polymer System V. Anticipated Geolog~ 4350-11,900' 11,900-12,500' Tyonek Formation Hemlock Formation VI. Formation Evaluation A. Standard mudlogging equipment was installed prior to drilling below the 20" OD deep conductor at 334'. B. It is anticipated that one or more full-size cores will be taken at points to be determined by wellsite geologist. C. Wireline logs will be run including dual induction laterolog, sonic log, density log, and dipmeter survey. I;55/B" 5000 psi SRRA BOP ARRANGEMENT Top of cellar DNRILLING IPPLE {iIFiLL I I I I I ~ ANNULAR PREVENTER ~,5000 psi 1~13 ~,~', 5000psi~ J 'i DOUBLE GATE RAMS (BLIND)~ I I (PIPE)+ 135/;', 5000psi LINE ~0", 5000 psi I0'; 5000 psi TUBING SPOOL ORDER OF RAMS OPTIONAL CASING CHOKE MANIFOLD SCHEMATIC TYPICAL: 5000psi Working Pressure SCALE: None ~ KILL LINE VALVES DRILLING SPOOL REMOTE OPERATED HYDRAULIC CHOKE HCR VALVE ~.//$" NOMINAL PRESSURE GUAGE MANUAL ,, t'-t "r" __ .4- ADJUSTABLE ALL VALVES TO BE 5000PSI RATED' Z ~~_~ Z ALL VALVES TO BE RING-JOINT TO TO DEGASSER RESERVE DEGASSER AND PIT AND MUD MUD TANKS TANKS Simasko Production Company ANCHORAGE DENVER SIMPGO KALDACHABUNA NO. BOPE for 8~;~' ROLE ! SCALE NONE DR. AMS DATE dUNE 1980 CK'D. B.A ( Simasko Production Company P 0 BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 June 18, 1980 Re: SIMPCO Kaldachabuna 91 Application for Permit to Drill (Deviated Well) State of Alaska Department of Natural Resources Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Hoyle Hamilton Commissioner Gentlemen: Submitted herewith is an Application for Permit to Drill an onshore deviated well in accordance with 20 AAC 25.050 (b) (1). Drilling is in progress under an approved drilling permit, No. 80-4 for a straight hole. The well unintentionally deviated to a point where the wellbore will cross the "500-foot" lease line spacing unit before intersecting the proposed producing zone. The only affected operator of the adjacent lease, Amoco Production Company, has been advised of the condition and their letter of non-objection is attached. Details of the deviation plan and related deviation history are in the supplemental data sheet. Enclosed in triplicate are the following: (A) Completed and executed Form 10-401, "Application for Permit to Drill or Deepen. (B) Supplemental Data Sheet for the permit application detailing information on the deviation plan, casing program, cementing program, drilling fluids, anticipated geology, and formation evaluation for the remaining portion of the well to be drilled. (C) As-built survey plat prepared by F. M.A~3..;?~ C,~, & G,~,~ ,. , .... ;.~..~ Lindsay and Associates. A~?,~,,~ (D) Lease boundary map showing the other affected operator. The proposed location of the wellbore intersection with the proposed producing zone is also displayed. State of Alaska June 18, 1980 Page Two (E) Plat of proposed wellbore course prepared by Eastman Whipstock, Inc. (F) Letter of Non-Objection from the only affected operator, Amoco Production Company. (G) Blowout Preventor Equipment drawing for 8 1/2" hole. Also enclosed is the required filing fee of $100.00, payable to the State of Alaska, Department of Revenue. The lease and surface use agreement with Cook Inlet Region, Inc. and Tyonek Native Corporation, respectively, apply as under the original application for permit to drill and the approved Permit No. 80-4, dated February 11, 1980. At the time of this writing, drilling is in progress at 8 1/2" hole at 9269'. The last survey at 9158' MD (9144.62' TVD) showed the bottom hole coordinates to be 350.91' south and 55.33' west of the surface location. Survey calculation techniques employ the "radius of curvature" method. Since drilling is in progress and the wellbore is rapidly approaching the "500-foot" lease line, we would certainly appreciate your immediate attention and review of this application. Approval as soon as possible will allow drilling to continue without delay. Sincerely, Bret R. Allard District Engineer BRA/jm Enclosures: As noted above Form 10-401 REV. 9-1-78 Ia TYPE OF WORK reverse rode) STATE OF ALASKA ,, ALASKA OIL AND GAS CONSERVATION coMMISSION PERMIT TO DRILL OR DEEPEN DRILL ~] GAS WELL D SINGLE OTHER Exploratory ~E b TYPE OF WELL OIL WELL g 2 NAME OF OPERATOR Simasko Production Company 3 ADDRESS OF OPERATOR P.O. Box 1515, .~mchoraqe, AK 99510 4 LOCATION OF WELL At surface 3579' FNL, 1505' FWL, Section 17, TllN, At proposed prod zone (as-built) 4370' FNL, 1480' FWL, Section 17, TllN, 13 DISTANCE IN MILES AND DI~ON FROM NEAREST TOWN OR POST OFFICE* Approx. 5 mi. WSW from Village of Tyon~k 14 BOND ImOR~TION nE Blanket surety and/or No RllW, S.M. RllW, S.M. Safeco Insurance Co. of America 92209296 API # 50-282-20066 5 Fee Land 6 LEASE DESIGNA~ON Am SERIAL NO None 7 IF I~IAN, ALLOTTEE OR T~BE NAME l~Cook Inlet Region, 8 ~ff FARM OR LEASE NAME SIMPCO Kaldachabuna 9 WELL NO. 1 10 FIELD AND POOL, OR WILDCAT Wildcat 11 SEC, T , R., M , (BOTTOM HOLE OBJECTIVE) Inc. Sec 17, TllN, RllW, S.M. 12 Kenai Borough ~ount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest dng, umt, ff any) 882' from shoreline 16 No OF ACRES IN LEASE 8785 19 PROPOSED DEPTH ~2,500'MD -'12,430 TVD) 18 DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, 7 51 ' f rom OR APPLIED FOR, FT Amoco Tyonek St. 21 ELEVATIONS (Show whether DF, RT, CR, etc.) 114.92 (GR) 131.72' (KB) (as-built) 17 NO ACRES ASSIGNED TO THIS WELL 640 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX DATE WORK WILL START Drilling Currently in 23 PROPOSED CASING AND CEMENTING PROGRAM P rog r e s s SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 8½" 7" (liner) 26 lb/ft S-95 8400-12500' 390 sx Class G w/additives The operator proposes to change the wellbore location from a "straight hole" as per the original application for permit to drill to the location shown above at the proposed producing zone. See the attached supplemental data sheet for details. Other attachments are: (1) As-built survey plat; (2) lease boundary map; (3) plat of proposed wellbore course; (4) Letter of "non-objection" from Amoco, et al, and (5) BOP diagram. BOP Program: From 8671' (9 5/8" casing shoe) to TD - 13 5/8", 5000 psi, SRRA assembly with 5000 psi choke and kill system. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal is to deepen g~ve data on present productive zone and proposed new producUve zone. If proposal is to drill or deepen chrect~onally, g~ve pertinent data on subsurface locations and measured and true vertacal depths. G~ve ~.blOwout preventer program. 24. I hereby cert~ thgt.-tlpe Fg~go~g IF)True and .C~r/ct SIGNED ~~<~ ~~"'~/~ DATE 6/17/80 mLE ,District Engineer R_ R. A~.]ard (Tim space for State office use) CONDITIONS OF APPROVAL, IF ANY SAMPLES AND CORE CHIPS REQUIRED I MUD LOG ~YES [] NO [ ~YES[] NO DIRECTIONAL SURVEY REQUIRED ~YES [] NO OTHER REQUIREMENTS A P I NUMERICAL CODE ~o -- 2 g.,~ - ,goo PERMIT NO. gO,~-- ~,. ~0 ~/~70~~~ ~~,~ ~ APPROVAL DATE APPROVED BY (~ TITLE ~~O~ DATE "~ ~ *See Instruction On Reverse Side June 19, 1980 06/19/80 18 24 i,, I 8 I I i I I ii' 23 ~ I ~ I I / I StMPCO KAL. DACH~.BUNA No. I LAT = 61 °02:' P-9.46" LONG = 151 o 16' 19 · 80" X: 274,486 ELEV.: ~4.92' I SCALE I": i MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice lend surveying in the State of Alasko and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. Dote Sur vej~o~ Note. Revised to As-Bultt May 19, 1980 0,1=4 I I ii illl i ii i ii i iii AS-BUILT SIMPCO KALDACHABUNA No. I Located in SW ~ PROTRJICTF..D SEC, I?.T, tI~I..R,_IIW.. IEWARD MERI:)IAN, AIL Surveyed for '~IMASKO PRODUCTION CO: III II III . I .Jill II I I . I II. I I II I1.! . Surveyed by EM. LINDSEY & ASSOC. LAND 6 HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Beuleverd Box 4-0~i Anc.h orage Ataek~ II . ~' IIIIII II II LIJ .,, I._ j -~-~ I T li IIIIII ..I ' 135/a" 5000 psi SRRA BOP ARRANGEMENT Top of cellar DNRIL. LING IPPLE I ,, I ,I IFILL LINE ( · I I I I ANNULAR PREVENTER 13~;', 5000 psi DOUBLE GATE RAMS (BLIND)+ I 1 (PIPE)+ 1354;', 5000 psi I0", 5000 psi I0'~ 5000 psi I SPOOL ORDER OF RAMS OPTIONAL CASING CHOKE MANIFOLD SCHEMATIC TYPICAL: 5000psi Working Pressure SCALE: None I, KILL LINE VALVES ,,i DRILLING SPOOL REMOTE OPERATED HCR VALVE X] L 3 '~ 90e PRESSURE GUAGE NOMINAL HYDRAULIC CHOKE MANUAL %q,~ t"l "'" __~ --I- ADJUSTABLE ALL VALVES TO BE RING-JOINT TO TO DEGASSER RESERVE DEGASSER AND PIT AND MUD MUD TANKS TANKS ['|mpC°~ Simasko Production Company ANCHORAGE DENVER __ $1MPCO KALDAGHABUNA NO. 1 for 8~'.~' HOLE BOPE __ , SCALE NONE DR. AMS '- DATE dUNE 1980 CK'D. BA. __ AMOCO PRODUCTION COMPANY 1670 Broadway Denver, Colorado 80202 June 17, 1980 Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Harry Kugler, Commissioner Re: SIMPCO Kaldachabuna ~1 Drilling Permit ~80-4 API Code 52-283-20066 Gentlemen: On April 1, 1980 Amoco Production Company, Getty Oil Company, Phillips Petroleum Company, Atlantic Richfield Company and Chevron U.S.A., Inc. entered into an agreement with Simasko Production Company by means which said companies will contribute a 100% working interest in that portion of State of Alaska lease ADL17587 lying within Section 17, Township 11 N, Range 11 W,S.M. to Simasko Production Company as encouragement for Simasko Production Company to drill an exploratory oil well within said Section 17. Simasko Production Company commenced the drilling of the Simpco Kaldachabuna ~1 well referenced above in a timely manner and is continuing drilling operations with the terms of the agreement. In accordance with State of Alaska Oil and Gas Operating Regu- lations 20 AAC 25.055. (a) (1), the surface location of an explo- ratory well must not be located closer than 500 feet to any pro- perty line of the lease on which the well is located, nor may any hydrocarbon reservoir be opened to the well bore closer than 500 feet to any property line of the lease on which the well is loca- ted. We are advised by Simasko Production Company that the above captioned well bore is drifting naturally in a southerly direc- tion from its surface location and may ultimately lie closer than 500 feet from the common boundary between the lease on which it Alaska Oil and Gas Conservation Commission June 17, 1980 Page 2 is being drilled and the lease ADL17587. Notwithstanding the fact that Amoco Production Company and its partners will retain only an overriding royalty interest in that portion of Section 17,Township 11 N, Range 11 W,S.M. located within State lease ADL17587 and Simasko Production Company will own 100% of the working interest in each lease on either side of the common lease line, this letter is to advise that Amoco Production Company, as Operator for itself, Getty Oil Company, Phillips Petroleum Company, Atlantic Richfield Company, and Chevron, U.S.A., Inc. has no objection to the location of the well bore of the captioned exploratory well ultimately being located closer than 500 feet from the common lease line between the lease on which the well is being drilled and the State of Alaska lease ADL17587. Very truly yours, AMOCO PRODUCTION COMPANY W. R. Francis Form ! 0-403 REV. 1-10-73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. None 1. OIL r~ GAS ~ 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELLL._3 WELL OTHER Exploratory Cook Inlet Region, Inc. 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Simasko Production Company SI~LPCO Kaldachabuna 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WELL At surface 9. WELL NO. y 1 10. FIELD AND POOL, OR WILDCAT Wildcat 3579' FNL, 1505' FWL, Section 17, TllN, RilW, Seward Meridian 13` ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) 14. Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, TllN, RllW, S.M. 12. PERMIT NO. 80-4 )ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIOIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (otb.r) Rng & Cmntng.. 9 5/8" csng . (NOTE1 Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertinent detlll~ and give pertinent dates, including estimated date of starting any proposed work. The 12¼" hole was drilled to 8675' and logged. One June 9, 1980 221 ~oints of 9 5/8I' casing was fun and landed at 8671'. The casing was run zn the following order: 9 5/8", 43.5#/ft, S-95, LT&C from 8671' to 5900'; 9 5/8", 43.5#/ft, N-80, LT&C, from 5900 to 1548; 9 5/8", 40#/ft, N-80, LT&C from 1548' to surface. The casing was cemented with 700 sacks of Class G containing 0.17 gal/sack D-80(TIC), 0.04 gal/sack D-81R, and 0.2 gal/sack D-108(FLAC). Displaced plug with mud and bumped at 2500 psi. Full returns throughont:job. CiP @10:55 6/9/80. HunS casing and set wellhead spool. Tested the packoff to 2250 psi. Nzppled up BOP equipment. RECEIVED JUN Z 2 1980 16. I hereby certify that the foregoln[t is true and cg~ect __ DATE- (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE. . DATE See Instructions On Reverse Side Form No 10-404 REV 3-1-70 f( SUBMIT IN DUPLICATE ( ! STAT&E OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NL MERICAL CODE 50-283-20066 6 LEASE DESIGNATION AND SI*RIAL NO. None I. ?- OIL[] GAS [] WELL WELL OTitER Exp lor atory 2. NAME OF OPERATOR Simasko Production Company 3 ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, Alaska 99510 Section 17, TilN, RllW, Seward Meridian 4 LOCATION OF WELL 3579' FNL, 1505' FWL, IF INDIAN ALOTTEE OR TRIBE NAME Cook Inlet Region, Inc. S IMPCO Kaldachabuna/ WELL NO. I0 FIELD AND POOL, OR ~,ILDCAT Wildcat I! SEC. T R M (BOTTOM HOLE OBJECTIVE) Sec 17, TllN, RllW, S.M. 12 PERMIT NO. 80-4 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISItING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 5/1' 57z' ., 5/3' 5/._Aa' 5/5-5/6,: 5/7' 5/8'-5/9' 5/10- 5/ii.: 5/12' Complete hook up on 30" conductor. Spud @2:00 p.m..Drill 17~" hole. Drill 17~" hole to 339' Open hole to 26" to 339'. Condition hole and ran 20" 94#/f~ H-40, buttress casing and landed at 334' KB. Circulate and prepare to cement. Cement 20" casing with 720 sacks Class G with 2% calcium chloride. CIP at 9:00 a.m. Full returns throughout with good cement to surface. Install 20" casing head and nipple up 20" hydril and diver ter system. Completed diverter nipple up. Clean out and drill out w/12¼" bit. Drill 12¼" hole to 2485'. Condition hole. Rig up Dresser Atlas to log. Log Ran DIL-SP and dipmeter-GR Start opening hole to 17~" · · 2 · Open hole to 17~" to 24854. Condition hole to run casing. Ran 13 3/8", 68#/ft, N-80, BTC casing from 2476-1072', 13 3/8", 68#/ft, K-55, BTC casing from 1072' to 888', an~d 13 3/8", 61#/ft, K-55, BTC casing from 888'to surface. Landed at 2476'. Break circulation. Cemented 13 3/8" casing to surface with' 1000 sacks Class G with 4% gel followed by 750 sacks Class G with 2% calcium chloride. CIP at 1:30 a.m. Full returns throug, hout with good cement to surface. PU BOP and cut off 20" caszng head. Weld on 13 3/8" casing head. Nipple up BOP and test. Pick up drillin, g assembly. Clean out and tested casing to 1500 psz. Drill out shoe and drill i2¼" hole to 2495' Conducted formation integrity test to equivalent gradient o~ 11.6 ppg.with no bleed-off. Drill ahead. 5/13-5/3i' Drill 12¼" hole from 2495' to 7832' at midnight, ~3_1/80. V_ D JUN 1, :! 1980 ' BV H. -A I ! ~T'CY - '-- TITLE strict Engineer DATE 6 / ! 0 / 8--0an'~h°rag~' NOTE-Report on th,s form is required for each calendar month, regardless of the status of operations, and must be filed in duphcate w~th the oil and gas conservation comm,ttee by the 15th of the succeeding mo~th,unless otherwise d~rected. Form ! 0-403 REV. 1-10-73 Submit "IntentionS'" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (OD not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-283-20066 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 6. LEASE DESIGNATION AND SERIAL NO. None WELLI--J WELL~''d OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, AK 99510 4. COCAT.ON OF WELL At surface 3579' FNL, 1505' FWL, Section 17, TllN, RllW, Seward Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 114.92' (GR); 131.72' (KB) Check Appropriate Box To Indicate Nature of Notice, Re 14. Cook Inlet Region, Inc. ~ 8. UNIT, FARM OR LEASE NAME · SIMPCO Kaldachabuna 9. WELL NO. Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 17, TllN, RllW, S.M. 12. PERMIT NO. 80-4 ~ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR AClDIZlNG L~ ABANDONMENT* (Other) Final As-Bul±~ Location Svy. (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent (letlllt, and give pertinent dates, Including estimated date of starting any proposed work. The final As-Built survey has been completed. The final surface location and elevations are shown above. A copy of the As-Built location plat is attached. RECEIV,CD JUN 4 I980 Alaska 0il & uas uu,,~. U0mmtss;, Anch0ra~e 16. I hereby certlf~that.t.he foregoing Is true anj;Pjcorrect '"1~_ '~_ 'l"[~'r'd . x,,,, (This space for State office use) ~ APPROVED BY CONDITIONS OF APPROVAL, IF ANY= TiTLE District Engineer DATE 6/2/80 TITLE DATE See Instructions On Reverse Side CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct Date - Surveyor Note- Reviled to Al-Built May 19, 1980 RECEIVED JUN- I Alaslm Oil & ~ s , Aflel~uraite _ I IIIIII J I II I I ~11 I IIIIIIII I II . $1MPCO KALDACHABUNA No. I Located In SW I/4. PROTR&OT!~ ~¢,17,?, II#,R,_IiW.. Surveyed fo~ SIMASKO PRODUCTION CO. ! I I n [ . I I II I . II I II I I I I I. ILI I SUrveyed by F.M. LINDSEY 81 ASSOC. LAND 8~ HYDROGRAPHIC SURVEYORS 2502 West Nor~ern L,Ight$ Boulevord Box 4-0~ Ancl~ora,ge AIaM~ Form 10-403 REV. 1-10~73 Submit "1 ntentlont" In Trlpllc&t~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for pro~os&l$ to drtll or to deepen Use "APPLICATION FOR PERMIT-'~* for such proposals.) WELLU OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515~ Anchorage, AK 99510 4. LOCATION OF WELL 10. At surface 2200' FNL, 2200' FWL, Sec. 17, TllN,-R-11~ ~1. Seward Meridian -. 13. ELEVATIONS (Show whether DF, AT, GA, etc.) 14. +150' GR (est); +168' KB.(e. st) Check Appropriate Box To Indicate Nature of Notice, Re None 7. IF INDIAN, ALLOTTEE OR TRIBE NAI~ Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME , S IMPCO Kaldachabuna 9. WELL NO. 1 FIELD AND POOL, OR WILDCAT Wildcat SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17, TllN, RllW, S.M. 12. PERMIT NO. 80-4 )ort, or Other Data TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO.' ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF !~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) Rug & Cmtg 3/8" csg , (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state &Il i~ertlnent detallf~ and give pertinent dates, Including estimated ciate of starting any proposed work. On May 9, i980, 63 joints of 13 3/8" casing were run and landed with the shoe at 2476' KB, and the float collar at 2438' KB. The casing was run as follows: 13 3/8", 68'lbs/ft, N-80, BTC from 2476' up to 1072'; 13 3/8", 68 lb/ft, K-55, BTC from 1072' up to 888'; 13 3/8", 61 lb/ft, K-55, BTC from 888' up to 156'; and 13 3/8", 61 lb/ft, K-55, ST&C from 156' to surface. A duplex stinger was run on 44" drillpipe and stabbed into the duplex float collar. The hole was circulated clean and the 13 3/8" casing was cemented to surface with 1000 sacks of Class "G" cement containing 4% dryblend gel followed by 750 sacks of Class "G" cement containing 2% calcium chloride. CIP at 1:30 a.m., 5/10/80. Good returns throughout job with 14ppg cement returns to surface. Cement set before slips could be set,therefore cut off 20" starter head and 13 3/8" casing. Welded on 13 3/8" S. O. x 13 5/8", 5000 psi starter'he~d and nippled up BOP equipment. R~!~ ' '1 5 1980 Alaska 01I & ~s t~u~,~. ~ommmm Anti, or&ge 16. I hereby certify that the fo_regolng is true a.i~ correct SIGNED ~~~ _ ~~lf~ _ TITLE District Engineer DATE 5/14/80 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE See Instructions On Reverse Side DATE Form.10-403 REV. Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OiL r-I GAS I--'1 WELL I,~.J WELL I..--I OTHER Exp 1or atory 2. NAME OF OPERATOR Simasko Production Company ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WELL At surface , 5. APl NUMERICAL CODE 50-283-20066 6. LEASE DESI(~NATION AND SERIAL NO. None 7. IF INDIAN, ALLOIIEE OR TRIBE NAME Cook Inlet Region, Inc. 8. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat 2200' FNL, 2200' FWL, Sec. 17, TllN, RllW, Seward Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) +_150' GR (est.); -+168KB (est.) 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 11. SEC.. T., R., M., (BOTTOM HOLE OBJECTIVE) Section 17, ~llN, RllW, S.M. 12. PERMIT NO. 80-4 3orr, or Other Data SUBSEQUENT REPORT OF: REPAIRING WELL ALTERING CASING ABANDONMENT* WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Runninq & Cmntnq 20" c sQ. (NOTEt Report results of multiple completion on Well C~PliIon or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent Itltllll, iln~l give pertinent dates, including estimated date of starting any proposed work. On May 2, 1980, a total of 335' of 20", 94 lb/ft, H-40, BTC was run and landed at 334' KB. (TD of 26" hole was 339' KB.) A duplex stinger was run on 4%" drillpipe and stabbed into the 20" duplex shoe. Circulated hole clean and cemented 20" casing to surface with 720 sacks of Class "G" cement containing 2% calcium chloride. (15.8 ppg slurry weight). Good returns throughout job with good cement to surface. CIP at 9 A.M., 5/3/80. 16. I hereby certify that_the foregoing is true/~ correct SIGN ~ret Allard - -~ (This space for State office use) RECEIVFn MAY 1980 Alaska 011 & (:ia, S bom~, ~,omrniss Anchorage APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE District Engineer ,,, DATE 5/9/80 TITLE See Instructions On Reverse Side DATE Al~d~a Oil and Ga~ Conservation Camnission May13, 1980 To Witness.' HJPE Test SimRco, Kal~ Well No. 1 Wildcat Cook Inlet Region Inc. Sec. 17-T11N-R11W-~.M. Pan~t 8O-4 May !lr 198.0 - I left Anchor~ at 9=15 AM by a Cessna 404, an airplane ~ by C.I.R.~nc., fr~ Ar~hor~j~ airways. Mere1 Long, SuRervisor for Simpoo, picked me up at the Granite Point Kalao Airstrip and trar~Rorted me by pickup to the ~rilling site. Sen I arr~ived, Br~f ~as still nipp~ up. ~ I toured the locat/on and found that Md and cement and jell mix h~d run ~ff 'the pad and into the ~0oded area, on the backside of location. I informed Lor~e S~th, and he discussed the situat~on with Britt Allard, Manager for I filled out an A.O.& G.C.C.B.O.P.E. Inspection Report, copy attached. May 13, !980 - I cal~ed Britt Al!a~d, Manager for Shq~o, and info~ him 'tha~' a ~raulic~ly ~ated valve must be i~sta/led on the choke line, direct/y off the ~, Britt ~ on this. Lonnie Smith also talked to Britt Allard ~ the chcke manifold not being API for a 5000 psi test, and that another valve shall be installed on ~.he dowT~tream side of the inlet on the manifold. I talked again to Britt Allard and told h/m, that ~hen the 9 5/8 casing is run, to notify A.O.& G.C.C., so that a State. ~~tive may witness the BOPE test. 1 In ~~ I witnessed the B.O.P.E. test on Simpoo, Kaldachabuna Well No.1. The BO~ test was ~tisfactory with the =c~/o~s noted above on this ~1 on the A.O. & G.C.C.B.O.P.E. Ins~q~on O&G #4 4/80 ( STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well ~ /~P Location: Sec / Drilling Contracto Date ~-/// /~ Well _/-'~9 _ / ( ~/~ZPZ-~9 ~-) Representative /~_ ~r/?/Zt ~ ~ ~- Permit # ? d -- ~ /~A/Caslng Set @ ~ ~/~ ft. Rig # ,_~' ~' Repre sentat ivp ~. _~..~ ~Tz~ P//~3/~/-' ~ Location, General Well Sign General Housekeepzng Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams / Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure /3-~f~.~ .. psig Pressure After Closure ?() Z;~ pszg 200 psig Above Precharge Attained: / mit ~ sc Full Charge Pressure Attained:_ ~ rain -- sc N2 )~'~, /~ /F.~,~, ~ ~ psig Controls: Master ~/~ Remote ~/ff Blinds switch cove~..~ Kelly and Floor Safety Valves Upper Kelly.~FOZ~ Test Pressure ~~ Lower Kelly Test Pressure $~~ Ball Type Test Pressure ~ Inside BOP Test Pres~re ~/~ Choke Manifold Test Pressure ~~ No. Valves ~ No. flanges /~ ~~LE ~ J/ ~gc Adjustable Choke~/ ~ ~ Hydrau~cally operated choke 5~AC~ -~ ~ ~M~ Test Results: Failures / Test Tithe Repair or Replacement of failed equipment to be made within ~ days Ins~ctor/Com~ssion office notified.. ~//~ff / ~X/fgc~ R~arks: ~/f~ ~/~ /j ~7 ~ ~;~ D~~F~ o~, orig. - AO&~C ~ ~51~ ~ I ~ cc - Operator cc - Supervisor Inspector Form 10-403 REV. 1-10~'3 Submit "1 ntentlon~" In Triplicate /,' A "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to clrlll or to ~leepen Use "APPLICATION FOR PERMIT-'" for such proposals,) ~' o,L r~ GAS r~ Exploratory WELLL-J WELL I---J OTHER 2. NAME OF OPERATOR 8. Simasko Production Company &, ADDRESS OF OPERATOR 9. P.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WELL At surface 2200' FNL, 2200' FWL, Sec. 17, TllN, RllW, Seward Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc.) '~150 GR (est.); +_168' KB (est.) 5. APl NUMERICAL CODE 50-283-20066 LEASE DESIGNATION AND SERIAL NO. None IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Tnlet Region, Tnc. UNIT, FARM OR LEASE NAME SIMPCO Kaldachabuna WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat L 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 17, TllN, RllW,S.M. 12. PERMIT NO. 80-4 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TOt SUBSE(~UENT REPORT OF: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING ~ WATER SHUT-OFF ~ MULTIPLE COMPLETE FRACTURE TREATMENT ABANDON* SHOOTING OR ACIDIZING CHANGE PLANS (Other) Spud Date _ (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) REPAIRING WELL ALTERING CASING ABANDONMENT* 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent det&ll~ and give pertinent dates, including estlmatecl date of starting any proposed work. This notice confirms the telephone conversation on May 1, 1980 between Mr. Lonnie Smith and Mr. B. R. Allard regarding notification of spud date. Official spud time and date is 2:00 p.m., 5/1/80. 16. I hereby certl~ correct SIGNED W. R. S[ewart RECEIVED MAY - 8 1980 Alastia 011 & Cias L,u,~. L, OmlIll$$1or Anchorage TITLE Vice President DATE 5/5/80 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANYI COMMISSIONElq ~Y ORD'-~'I!IT~:¢ THE COMUISS[ON DATE See Instructions On Reverse Side Form No 10-404 jr' SUBMIT IN DUPLICATE 1 REV 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE APl NUMERICAL CODE 50-283-20066 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS None 1o OIL O GAS [--i Exploratory WELL WELL OTHER 2. NAME OF OPERATOR 8. $±masko ?roduction Compan7 3 ADDRESS OF OPERATOR 9 WELL NO. ?.O. Box 1515, /~chorage, hK 99510 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT 2200' FNL, 2200' FWL, Sec 17, TllN, RllW, Seward Meridian LEASE DESIGNATION AND SERIAL NO. IF INDIAN ALOTTEE OR TRIBE NAME Cook Inlet Region, UNIT FARM OR LEASE NAME SlMPCO Kaldachabuna Wildcat 11 SEC T R. M (BOTTOM HOLE OBSECTIVE) Sec 17, TllN, 12. PERMIT NO 80-4 RllW, SoMo 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 4/1-4/3: Finalize preparation to barge construction equipment 4/4 : Barged construction equipment to job site. 4/5-4/8: Completed snow removal on road and drillsite in preparation for gravel haul. 4/9-4/25: Construction of access road and drillsite. Repaired existing road. 4/26-4/29: 4/30: Move in and rig-up Brinkerhoff Signal Rig No. 58 Complete rig-up and drive 30" conducutor pipe to 73' drive hammer and make final preparation to spud. KB. LD I\LL. LI V I_L/ V cer~~correct TITL~ V±¢e President DATE 5/5/80 W. K. ...l~!t31 .--.~ on this form is required for each calendar month, regardless of the status of operations, and must be T,.eo m (~up.ca~e w~tn the as conservation comm,ttee by the 15th of the succeeding month.unless otherwise d~rected. Alaska Oil & Gas G0ns. ~0mmiss~ Anchorage Alaska Oil and Gas Conservation Cannission Hoyle H. H~milton Chainmn of the Ccmni ss toner May 6, 1980 Harold R. Hawkins Petroletm Inspector To Inspect: Diverter System SIMP(I) Kal dachahma Wel 1 No. 1 Cook Inlet Re~ion, Inc. Sec. 17-T1 IN-R11W-S.M. Permit No. 80-4 ~ 4~ 1980 - I left Anchorage at 7:00 AM by a Cessna 404, a plane chartered by 'C,'i.R. inc., from Anchorage Airways. l~hen I arrived at Granite Point Kalao Airstrip, I met Merel Lont/, Supervisor for S~. klm-el took me directly to the location, v/aere I inspected the Dtverter S~tem. I found that th~ Diverter System was beir~ installed v/aen I arrived. ~h~ Divart®r line was a 13 $/8m ~ir~ to the pit with a 13 S/Sm imtterfly valve at th stack, this valve is to be hooked up and operated remotely by the driller with a wireline. I irdorm~ l~rel LonE that the 18 $/8m was fine but there had to be another line m~d t~ n~re valves hooked up, to divert ~as or fluid in alternate directions, if needed. The schamtic Merel Lor~ had, sho~ed only one line. I also informed him that the diverter valve on the 13 3/8m line should be autamtic. I called Lonnie Suith were accordir~ to our r~l Yerel Lon~ invediately the second line to the dive May 5, 1980 - I, ~ie ~ the Di~rt-er ~t~. ~ he informed me that I was right, that tv~ lines ~tions and was not waived by the State. lined up the valves and pipe and was connecting ,ter system ~hen I departed the location. Blair had a disc~assion about the regulations on Blair ~zell called Britt Allard, Supervisor for SIMH33 and clarified our rel~lations. In ~~ I inspected the Diverter System on the SIMPiX) Kaldachahma Wel 1 No. 1' I found that the diverter system did not meet our requirements fully, but with mir proposed modifications it would be substantially in compliance. ( Simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX April 29, 1980 ~/r Re: SIMPCO-Kaldachabuna Casing Data Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 smG I 1 ENG, ~l'-I aEaL'-- J STAT TEC CONFER: FILF: . Attn: Mr. Hoyle Hamilton Commissioner Gentlemen: Availability of casing has been quite critical causing certain modifications to the original casing program for the captioned well. We have just received final footage confirmation on our casing purchases. The 20", 13 3/8", and 9 5/8" strings were modified. In every case, the revised program meets or exceeds the strength criteria of the original design. The attached table lists the original design and revised program. The items underlined in the revised program are where changes occur. We are currently in the rig-up phase of the operation and anticipate spudding on April 30, 1980, barring any unforeseen difficulty. Sincerely, Bret Allard District Engineer BRA/jm Attachment Casing Size Original Design Revised Design Setting Depth iI l Setting ~epth orI ~ ' or Weight Grade Coupling Amount Changeover Point i Weight Grade Couplingi' Amount I Changeover Point 20" 94#/ft H-40 ST&C 300' 300' I 94#/ft H-40 BTC ~ 300' il 300' ' ' I i "' 13 3/8" 61#/ft K-55 ST&C 2500' ~ 2500' 61#/ft I K-55 BTC 700' 700' 68#/ft i K-55 BTC 440' 1140' 68#/ft N-80 BT¢ 1360' 2500' ......... ! 9 5/8" 40#/ft N-80 BT&C 4200' 4200' 40#/ft N-80 BT&¢ 2100' 2100' 43.5#/ft N-SO BT&C 2200' 6400' 43.5#/ft !N-S0 BT&C 4300' 6400' 40#/ft S-95 BT&C 900' 7300' 43.5#/ft 8-95 BT&C 2600' 9000' 43 5#/ft S-95 LT&C 1700' 9000' ~Qfm No 1~404 REV. 3-1-70 SUBMIT IN DUPLICATE · STATE OF ALASKA Gl L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLIN AND WORKOVER OPERATIONS L OIL I--I GAS I-"] Exploratory WELL WELL OTHER 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR Y.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WELL 2200' FNL, 2200' FWL Sec. 17, TllN, RilW. S.M. $. APl NUMERICAL CODE 50-283-20066 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN'ALOTTEE OR TRIBE NAME Cook Inlet Region, 8. UNIT FARM OR LEASE NAME S It-LPCO Kaldachabuna 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 17, Ti!N, RllW, S.M. 12. PERMIT NO. 80-4 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. March 10 Mobilized initial construction equipment March i 1 Pioneered access road to wellsite location. Cleared wellsite location and prepared same for drillpad construction. March i2 Located gravel sources. March i3-31 Obtained approval of gravel extraction site from surface owner. Commenced mobilization of primary construction equipment by barge. APR !, ! !980 Alaska Oil & Ga'.; u ...... , ......... Anchorzge TITLE Vice President DATE April 11, 1980 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. / l~eb~uary i! ~ M~. W. R. Stewart Vies Preaidont Anobora~, Alaska 9~Sl0 gnolooed ia the approved application £or permit to drill the above re£erenoed vel 1. Well samples, core chips and a mud log are required. A d~rec- tional surv~ ts not required. Xf available, a tape contain~ng the digitized log iaformation on all logs shall be submitted for copying except experimental logs, velocity surveys and dipme~er sUrVeys. Nany rivers in Alaska and their drainage systems have been olassi£ied aa ~mportant for the spawning or migration of anadromoua £iah. Operations ~n thox areas are subject to AS 16.S0.870 and the regulations prmuulgated theremnder (Title Alaska Administrative Code). Prior to commencing operations ym2 may he contacted by the Habitat Coordinator's o££tee, Department off Fish and ~ame. Pollution of any waters of ~he State is prohibited by AS 46, Chapter 3, Article ? and tP~ regulations ~omulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as a~ended. Prior to ~Lr. W. R. Stewart SXHPCO Ealdaohabuna -2- February 1!~ 1980 commeno~ng operations you nay be oontacted by a.repFesentative the Department of Environmental Conservation Pursuant Ho AS $8,40, Local Hire Under SHare Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dril 1. TO aid us in 8ohodul£ng field ~ork, ~e would appreciate your notifying this o£fice within 48 hours after the well is spudded. We would also like to be noti£ied so that a repre- sentative of tho ccuuiission may be p~esent to witness testing of blowout preventer equipment be£oEe suEface casing shoe is drilled, i In the event of suspension o~ abandonment, please give this off,ce adequaHe advance notification so that we may have a Very truly yours, lamil ton C)~i~ Of BY ORDi;a OF T~ COM~SSlgN Alae~ Oil ~ Gas ~nSe~ation C~tsst~ Enclosure oc~ Departnent of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supe~visor, Labor Law Compliance Division w/o encl. Simasko Production Company P O. BOX1515 · ANCHORAGE, ALASKA99510 · (907) 277-5932 · (907) 274-4591 · TELEX26-338 January 22, 1980 Re: SIMPCO Kaldachabuna Application for Permit to Drill Supplemental Data HAND DELIVERED Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Hoyle Hamilton Commissioner Gentlemen: In response to a telephone conversation between Mr. Blair Wondzell and myself, we are furnishing a copy of the revised schematic of the choke manifold proposed for the drilling of the captioned well. The attached schematic is typical for the intended choke manifold to be used following the running and cementing of 13 3/8" surface casing. The choke manifold will be 5000 psi rated and consistent with API RP53 recommendations. This is to include double, full- opening valves upstream of each choke, as well as the bypass line. The schematic previously submitted was the type used for earlier, shallow, low-pressure operations and was inadvertently included with our original Application for Permit to Drill dated January 7, 1980. In keeping with established Company policy, drilling and production practices will meet or exceed the minimum API recommendations. If you have further questions, please do not hesitate to contact Mr. W. R. Stewart, Vice President of Simasko Production Company, or the undersigned. BA/jm Enclosure: As noted Sincerely, Bret Allard SIMPCO Engineer ¢ APPLICATION FOR PERMIT TO DRILL SUPPLEMENTAL DATA SIMPCO Kaldachabuna Well No. 1 Choke Manifold Schematic Typical: 5000 psi Working Pressure Scale: None; January 21, 1980 jk~22 ~980 KILL LINE 3" DRILLING SPOOL REMOTE OPERATED HYDRAULIC CHOKE _~ 1. ALL VALVES TO BE FULL-OPENING. 2. ALL VALVES TO BE 5000 PSI RATED. 3. ALL VALVES TO BE RING-JOINT FLANGED. HCR VALVE 3" -.,~.-' 45° ELLS ,% LONG RADIUS 90° ELLS 3" NOMINAL PRESSURE GAGE - _ . . ADJUSTABLE TO TO DEGASSER DEGASSER AND AND J MUD MUD TANKS TANKS TO RESERVE PIT Simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 January 7, 1980 Re: SIMPCO Kaldachabuna Application for Permit to Drill Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Hoyle Hamilton Commies loner Gentlemen: Simasko Production Company hereby makes application for a permit to drill an onshore exploratory well on the west side of Cook Inlet at a location in Section 17, TllN, RllW, S.M. Enclosed in triplicate are the following: (1) Completed and executed Form 10-401, "Applica- tion for Permit to Drill or Deepen". (2) Supplemental Data Sheet attached to the Permit form providing detailed information on casing program, cementing program, drilling fluids, anticipated geology, and formation evaluation. (3) Proposed Location Plat prepared by F. M. Lindsey & Associates. (4) Blowout Preventor Equipment Drawings for 17 1/2" surface hole and for 12 1/4" and 8 1/2" hole. (5) Surface Facilities Map upon which existing facilities are indicated together with lease boundaries. Also enclosed is the required fee in the amount of $100.00, payable to the State of Alaska, Department of Revenue. This wellsite is located on a fee lease which has been into by and between Cook Inlet Region, Inc., as Lessor, and Simasko Production Company, as Lessee. The wellsite lease Alaska Oil and Gas Conservation Commission January 7, 1980 Page Two contains 8,785 acres and is indicated as "Area II" on the Surface Facilities Map. A Surface Use Agreement has been entered into with Tyonek Native Corporation, owner of the surface estate, covering all surface activities including extraction of gravel and construction of drillpads, roads, and airstrips. As indicated on the executed application form, Simasko Production Company maintains a $100,000 Blanket Bond from Safeco Insurance Company of America bearing Bond No. 2209296. This bond was submitted to your office on November 21, 1977, to cover any wells drilled by Simasko Production Company on the adjacent "Area I" lease. As discussed recently with Mr. Harry Kugler of your offices, we are in the process of amending this bond in order to extend coverage to the "Area II" wellsite lease. We will provide you with appropriate documentation in the near future. We are targeting for a March 1, 1980 spud date on this test and will appreciate your early attention to review of this appl icat ion. W. R. Stewart Vice President WRS/jm Enclosures: As noted RECEIVED _Anchorage Fm'm 10401 REV. 9'1'78 STATE OF ALASKA la. TYPE OF WORK SUBMIT IN TRIPL~TE ALASKA OIL AND GAS CONSERVATION COMiY~(S~I~~ PERMIT TO DRILL OR DRILL r~l DEEPEN F-] b. TYPE OF WELL OIL GAS w~ ~] WE~ ~] milER Exploratory SINGLE ZONE ....... 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchorage, AK 99510 MULTIPLE 4. LOCATION OF WELL At surface 2200' FNL, 2200' FWL, Section 17, TllN, RllW, At proposed prod. zone S · M. Same (Straight hole) 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approx 5 miles WSW from Village of T¥onek 14 BOND INFORMATION Safeco Insurance Company of America ~n~ Blanket Sure~,nd/orNo. #2209296 A~ou.t APT 50-2Rq-20066 .. Fee Land 6. LEASE DESIGNATION AND SERIAL NO. None 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Cook Inlet Region, 8. UNIT FARM OR LEASE NAME SIMPCO Kaldachabuna ,9 WELL NO. 1 10 FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T, R., M., (BO'II'OM HOLE OBJECTIVE) Sec 17, TllN, RllW, Kenai Borough $100,000 Inc. S.M 15. DISTANCE FROM PROPOSED ' LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest dng, umt, ~f any) ±2,100' from shoreline 18 DISTANCE FROM PROPOSED LOCATION ~' 0 0 0 TO NEAREST WELL DRILLING, COMPLETED, __ 2, OR APPLIED FOR, FT from PanAm Tyonek State 21. ELEVATIONS (Show whether DF, RT, CE, etc.) -+150 ' GR #1 16 No OF ACRES IN LEASE 8,785 19. PROPOSED DEPTH 12,500'TMD & TVD (Estimate from USGS Tope Sheet) 17. NO ACRES ASSIGNED TO THIS WELL 640 20 ROTARY OR CABLE TOOLS Rotary 22 APPROX. DATE WORK WILL START March 1, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantfly of cement N/A 30' Conductor. ±80 ' Driven-no cement 26",, 20" 94# H-40 -+300' To surf.:600sx C1.G w/2%CaC 17% 13 3/8" 61~ K-55 ±2500' To surf.:1000sx w/Gel+750sx 5/8" . ~9000' · · .. 12%" 9 40&43.5# [80&S9~ 700sx Cl G w/Add w 8%" 7" (liner 26# S-95 8700-12,500 390sx C1.G w/Add. 12 /Cae1 Proposed Surface Location Plat enclosed. As-Built Survey Plat to be submitted after setting conductor. See attached Supplemental Data Sheet. See attached Surface Facilities Map with Lease Boundaries. BOP Program: From 300' to 2500' - 20", 2000 psi, SA diverter assembly From 2500' to TD - 13 5/8", 5000 psi, SRRA assembly w/5000 psi choke & kill system. (See attached drawing) IN ABOVE SPACE DEScR_rBEPROPOSED PROGRAM if proposal ~s to deepen g~ve data on present productive zone and proposed new producUve zon~ proposal ~s to dali or deepen duecUonaUy, g~ve perttnent data on substuface iocat,ons and measured and true v,:t~~Fblowout preventer propam. SIGNED ' /~7~- DATE January 7, 1980 ~TLEViCe President W. R_ ~_e,...,_=M'~i- - (Tim space for State office use) SAMPLES AND CORE CHIPS REQUIRED MUD LOG ~..YES [-] NO ] ~LYES DIR~'rIONAL S~V~Y REQUIRED O~ ~o CONDITIONS OF APPROVAL, IF ANY OTHER REQUIREMENTS [] NO A.P.! NUMERICAL CODE PERMIT NO. ~ 0 - ¥ APPROVAL DATE APPROVED BY TITLE ---~,..-' ~- - - *See Instruction On Reverse Side DY v~.~ ~DF THE COMMISSION DATE SUPPLEMENTAL DATA SHEET For APPLICATION FOR PERMIT TO DRILL SIMPCO Kaldachabuna #1 January 7, 1980 I. Casing Program 20", 94 lb/ft, H-40, ST&C 13 3/8", 61 lb/ft, K-55, ST&C t'9 5/8", 40 lb/ft, N-80, LT&C ~/~'~9 5/8", 43.5 lb/ft, N-go, LT&C 9 5/8", 40 lb/ft, 8-95, LT&C 9 5/8", 43.5 lb/ft, S-95, LT&C 7", 26 lb/ft, S-95, LT&C 30" conductor pipe driven to +80'. : : : · . : : : Surface to +300'. Surface to +2500'. Surface to 4200' 4200' to 6400' 6400' to 7300' 7300 to 9000'~>.,,~ v28~ ~0o 900 Liner from 8700' to 12,500' The above casing weights and grades are preferred. At the time of purchase, h6wever, it may be necessary to vary slightly due to availability. In any case, the performance properties for the final casing selected will meet or exceed those for the casing listed above. II. Cementing Program A. The 20" shallow surface casing will be cemented to surface around a duplex shoe with +600 sacks of Class G cement with 2% Calcium Chloride. (Includes 50% excess) 7' FIll ': ~4 ~ ' . sT-"~ ~,~ B. The 13 3/8" surface casing will be cemented to surface Ce with 1000 sacks of Class G with 4% dry blend gel (includes 40% excess) followed by 750 sacks of Class G with 2% Calcium Chloride (includes 30% excess). A duplex cementing technique will be employed. The 9 5/8" intermediate casing string will be cemented with 700 sacks of Class G cement containing fluid loss and turbulence inducer additives and appropriate retarder. This should result in a 2000' cement column (includes 30% excess). If potentially productive horizons are encountered above the cement top, a second stage will be performed through a DV collar,,a~[.~. ~.~. ~- ~I~, appropriate. T. ~,'/; = ~&, Supplemental Data Sheet SIMPCO Kaldachabuna 91 Page 2 De The 7" liner will be cemented with 290 sacks of Class "G" with fluid loss, turbulence inducer, and retarder additives followed by a 100 sack Class G down-squeeze at the liner top for a total of 390 sacks. The down- squeeze slurry will contain appropriate additives for squeeze cementing. The open-hole volume should result in a 2000' cement column (includes 30% excess ). z~ s~, ~,~e~ F. ~//~ - ~~' Each cement slurry below the surface casing will be preceeded by a water spacer containing clay stabilizing additives. Actual volumes will be calculated from open-hole caliper data on electric logs. III. Drilling Fluid Program Surface to 2500' - 2500' to 12,500'TD - Benex-gel/fresh water Inhibited Polymer System IV. Anticipated Geology 0 - 200' 200 - 4350' 4350- 11,900' 11,900 - 12,500' Gravel Beluga Formation Tyonek Format ion Hemlock Formation V. Formation Evaluation A. Standard mudlogging equipment will be installed prior to drilling below the 20" OD deep conductor +300'. B. It is anticipated that one or more full-size cores will be taken at points to be determined by wellsite g eolog ist. C. Wireline logs will be run including dual induction laterolog, sonic log, density log, and dipmeter survey. SCALE I"-- I MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct Date Surveyor PRoPosED SIMPCO KALDACHABUNA No. I Locoted in NWl/4 PROTRACTED SEC I7~T lIN.iR IIW., SEWARDMERIDtAN. AI~ Surveyed for SIMASKO PRODUCTION CO. I I II Surveyed by EM. LINDSEY 8~ ASSOC. LAND 5 HYDROGRAPHIC SURVEYORS 2502 West Northern L~ghts Boulevard Box 4-08t Anchorage Alaska II I II I I II I I i I I Fill- up Line ~ 20" OD Drill lng Spool I 8' Long 20" Starter He~d SURFACE HOLE BOPE ARRANGEMENT 20"-2000 MSP HYDRIL ~,.,~-.- Ki I I Line 500 psi WP FO Valve Weld - O- Let Remote Operated Shut-off Valve Notes: I. Hydraulic Control System for Diverter 8' (~) Hydraulic Valves to include Accumulator 8, Reservo;r with 80 Gal, capacity each with 1500 psi operating pressure. 2. Hydraulic Control Lines MUST be connected so that Shut-Off Valves OPEN before Diverter CLO~ES, ~ must include both rig floor & Remote Control Stations. 4. Provisions will be made to prevent freezing of fluids in either the Hydra~, Control System or the Relief Lines. 5. Pressure Gauge with Remote Readout on Rig Floor will be Installed to show casing pressure. tar Line fo Slope Toward the Reserve Pit to Prevent Plugging. Cellar Wall ~,,..-/ ressure,,. I:~e" Dlverter Line To Reserve ,, Simasko Production Company ^NC.O~^OE OENV~. , Simpco K~ld~ch~bun~ Well No.I BOPE For 17J/2" Surface Hole . ${~[~ None 0~. AMS DRILLING NIPPLE ANNULAR PREVENTER I! ISS/. , 5000 J Est 14° to q Rotary I - I Beams q (PIPE),, I~ ~ 5000ps: DOUBLE GATE RAMS (BLIND) I i I 1 .*29" CASING SPOOL ! I I'above cellar floor 20'; 2000 i CASING BOWL Weld "CASING , 5000 psi SRRA BOP ARRANGEMENT (WHILE DRILLING 121/4 ',~ HOLE) (WHILE DRILLING HOLE) ~DRILLING ! ANNULAR PREVETER ~3%'; ~oo~, I DOUBLE GATE RAMS (BLIND) I q (PIPE) ~ 13~': 5000 psi I I' ~3%': 5000 Est. to I Topof / Cellar/ ~ I IO'; 5000 '0' 000 +-~" TUBING i' I ,3%';5ooo CASING SPOOL $.29" g20" CASING I 20'~ 2000 above cellar flool~I ) CHOKE MANIFOLD SCHEMATIC (TYPICAL-DRILLING ~2v$' a 8~/~' HOLES) Kill Line Pressure Guoge From Pumps HCR Drll Ii ng Spool Valve :,", 5ooop~i~ To Degasser and Mud Pits Remote Operated i[~ Hydraulic Choke ManualAdjustablechoke ~ixxqi''- '~' T'~Mr-,1'" AdjustableManual _L 'v'~Z~Ch°k* -r- -1- -r Discharge Header To Reserve I. All Valves and Flanges in II Choke Manifold are 2, 5000 psi Rated. 2II 2. Piping in Manifold is except for Discharge Header which is 4'.' ,,, Simasko Production Company ANCHORAGE DENV[R Simpco Kaldachabuna Well No. I BOPE for 12~/4'. t~ 8~/~' Hole SCALE None DR. AMS DATE Dec:. 1979 CK'D. BA Item Approve Date Yes No Remarks (1) Fee .w~m~., ~-If-~o 1. Is the permit fee attached .......................................... 2. Is w~ll to be located in a defined pool ............................. ~ 3. Is a registered survey plat attached ................................ ~m~ (2) Loc. ~K ~-/~-~ 4. Is well located proper distance frcm property line .................. ~ 5. Is well located proper distance frcm other wells .................... /~2~ , 6. Is sufficient undedicated acreage available in this pool ............ ;~0C 7. Is w~ll to be deviated .............................................. ~ 8 Is operator the only affected party /' (3) kflmin. ;L~/~)~'. 9. Can permit be approved before ten-day wait .......................... 10. Does operator have a bond in force .................................. ;~ . . 11. Is a conservation order needed ...... : ......... ' ......... - ...... - ..... 12. Is administrative apuroval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... ~/~O 15. Will c~nent tie in surface and intermediate or production strings ...~? 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect freshwater zones ....................... A~ (5) BOPE ~/~b~ 18. Will all casing give adequate safety in collapse, tension and burst.-~kJ~ 19. IX>os BOPE have sufficient pressure rating - Test to .~'~ Approval Reccmmended: Additional Requirements: Geology: HWK JAL Engin~e~ring: rev: 03/05/80 7. E' / 8: Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait ......................... .~..~ Does operato~ have a bond in force .................. '!. Is a conservation order needed ...................................... CHECK LIST FOR NEW %~LL PERMITS Oompany Is the permit fee attached .......................................... ~ No .). Is ~all to be located in a defined pool ............................. / 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frc~ property line . ~/~/ 5. Is well located proper distance frcm other wells__ .................. 6. Is sufficient undedicated acreage available in this pool ............ Is well to be deviated .............................................. ]0. 12. 13. 14. Is administrative approval needed ................................... Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ 15. Will cement tie in surface and intermediate or production strings ... ~ 1~ Jill cement cover all known productive horizons ..................... d~ Remarks Lease & Well No.~.?c~ Item Approve Date (1) Fee (2) Loc. ~~'/< ,, 17. Will surface casing protect fresh ~ater zones ....................... ~ .... ~8. Will all casing give adequate safety in collapse, tension and burst.. 19. Does BOPE have sufficient pressure rating - Test to j--o0 o psig .. Approval Reccmmended: Engin~K-~g :_ LCS ,/~' BEW ~ rev: 12/12/79 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically .. organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Simasko Production Co. Well - Kaldachabuna #1 Fie ld Wi] dcat County,State Kenai, Alaska Date 12-5-80 __ Curve Name (Abbreviated) Standard Curve Name Logs Used Scale SP Spontaneous Potential DIFL 0-100 _GRI Gamma Ray .... DIFL 0-]00 RXO Shallow Focus Log DIFL .2-2000 - _RILM Indoct~o__n L,0§ ~edi~m DIFL .2-2000 RILD Indoct]on Log Deep DIFL .2-2000 COND DIFL 500-0 Conductivity ~GRA Gamma Ray BNC/AC 0-100 ]ALA Caliper BBC/AC 6-16 Z Acoustic BHC/AC 150-50 Formation Factor BHC/AC 2-20000 ~D Gamma Ray CDL/CN 0-]00 ~LD Caliper CDL/CN 6-16 iN '~]k Density CDL/CN 1.65-+2.65 - + RR Correct~on CDL/CN -.15 Compensated Neutron CDL/CN 60-0 P Density Porosity CDL/CN 60-0 Long Space Neutron CDL/CN 0-2000 _Short Space Neutron CDL/CN 0-2000 RECEIVED LIBRARY TAPE CURVE SPECIFICATIONS Company Simasko Production Co. Well Kaldachabuna #1 Fie Id Wildcat County,State Kenai, Alaska Date 12-5-80 __ Curve Name (Abbreviated) Standard Curve Name Logs Used Scale ,,, SP Spontaneous Potential DIFL 0-100 CRI Gamma Ray DIFL 0-]00 _ RXO , , Shallow Focus Log ,, DIFL .2-2000 _R..ILM Induction Log %Jedi~m DIFL .2-2000 RILD Induction Log Deep DIFL .2-2000 ---- ._ COND Conductivity DIFL 500- 0 -- GRA Gamma Ray BBC/AC 0-100 CALA Caliper I BBC/AC 6-16 AC Acoustic BHC/AC 150- 50 F Formation Factor BHC/AC 2-20000 ('~D Gamma Ray CDL/CN 0-100 CALD Caliper CDL/CN 6- 16 _ DEN B~]k Density CDL/CN 1.65-+2.65 f'OKR Correction CDL/CN -+. 1S CN Compensated Neutron CDL/CN 60-0 -- , -- ~IENP Density Porosity CDL/CN 60-0 LS Long Space Neutron CDL/CN 0-2000 _ _~_S____ ..... Short Space Neutron .. CDL/CN ~_~!,~p 0-2000 ..... , ...~/~,,~ ~ -~-~ ~ S~SSSRSS S~ SS ) s~ S~SSSSS ~SSSSSS ) SS S~SSSSSS ) ~SSSSS o000000 OOO00000 On 000 ) on o0oo O..q OHO00 O0 ) onoo oo · odo oo oonoooooo ) ooonooooo OO 11 11111111 O0 0 BRBBBBBB BB BB BB BB BBBBBBB BRBBBBB BB BB BB BB BBBBBBBB BBBBBBB 99999 99999999 99 99 99 99 99999999 9999999 99 99 9999999 99999 222222 22222222 222 22 222 222 222 222 222 22222222 22222222 55555555 55555555 55 5555555 55555555 55 55 55 555 55 55555555 555555 // O0 /// 000000000 /// 000000000 /// O0 000 /// O0 0000 /// O0 00000 )// ooooo oo /// 0000 O0 2/) ooo oo /// ooooooooo /// ooooooooo // O0 666666 66666666 66 66 66 66~6666 66666666 66 66 66 66 66666666 666666 55555555 55555555 55 5555555 55555555 55 55 55 555 55 55~'55555 555555 ., III II/ II/ III II // /// 888888 /// 88888888 -I /// 88 88 I/1I 88 88 ~/f 888888 /// 888888 88 88 88 88 88888888 888888 3333333 3333333 333 333 33333 33 33 33 33 33333333 ~33333 O0 000000000 000000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 £~'C NUP~BE~ 11~.1o00 SI~ASKO PRODUCTION CO, .... KALD~CHABUNA ~l WI~'DCA~ .... KENAI~ALASKA P~R~ CaLD hEN CORR CN OENP L~ SS FR~4 .2.600~00 TO 2800,00 LEi~EL RPAC?NG 0,5000 1~5, ~AMPi'ES PER RECOR~ PAGE 1 SIMASKO PRODUCT?ON WILDCAT---=KENAI,ALASKA DATA Ei~RY I SAMPI_ES SRD C4LO DmN 260~.00 50.86 16.55 2.30 2601,00 53.79 16.62 2~35 ~601.50 52.69 16.66 2.36 .26Q2.0_0 50.73 16.67 2.36 260p.50 5t.22 16.66 2.35 p60~.oo 54.03 16.54 ~.33 26~3.50 55.99 ~6.12 2.31 e60~,O0 57,09 15.84 2.31 26o~.5o 5?.%6 15.~ 2605,00 57.33 15.98 ~60S.50 56.%8 15.88 2.37 260~.00 53,91 15.78 2.38 a6o6,sQ 51.10 15.52 26o7,oo 51.59 15.~o 2.39 2607.50 52.08 15.20 2.39 2608,00 50.12 15.15 2.~9 260~.50 50.~9 15.16 2.40 ~GOg. O0 50.12 15.23 ~G09~50 5~,57 15.26 2.38 2610.00 51,83 15.16 2.37 ~610.50 53.55 15.16 2~36 _~.61.!~00 5~77 15.~3 2.35 ~61~.50 5%.03 15.24 2.33 2612.00 5%,89 15.28 2~30 2612.50 57.33 15.37 2.26 261~.00 57.33 15.56 2~2~ ~61~.50 57.09 15.60 2126 2614,00 55.50 15.63 261~.50 52.32 15.76 2137 261S.00 5~.81 15.82 261S.50 5~.93 15.93 2.35 261~.00 53.67 16.06 2.33 261R.50 57.82 16.20 ~617.00 60.~7 15.90 9517.50 61.00 15.60 ~19 ~61~.00 59.90 15.5% 2.17 ~61~.50 58.80 15.43 2~20 ~619.00 60.02 15.45 2.27 ~61g.50 6~.22 15.6~ 213~ 26~0.00 59.90 15.8% 2~33 ~6~.50 55.62 15.93 2.3~ 2621.00 53.18 15.9~ 2.33 P621.50 55,50 15.99 - ~G~P,O0 5%,16 15.95 2.27 ~6~,50 5%.28 15.91 2.19 ~6~3,00 55.99 15.9% ~.10 ~693.50 57.70 16.01 2.03 2G~U.O0 55.67 16.06 ~.01 262~.50 %7.31 16.13 2.06 2625.00 %%.01 16.02 2.21 CO. .... KALDACHABUNA ff~ CORR Cg OENP 0.09 39.56 21.09 0.10 %0.%0 19.97 0.11 40.4% 1~.20 0.11 ~0.04 0.11 39.01 17.72 0.11 38.90 1~.27 0.11 39.52 19.12 0.10 39.38 20.42 0,11 37,88 20.38 0.12 36.82 19.16 0.13 36,60 18.12 0.1% 36.23 17.~0 0,1% 35,87 16.%9 0,1% 35,94 15.94 0.13 35.9~ 15.46 0.1~ 35.65 15.%9 0.11 35,54 15.75 0.11 35,28 15.23 0.10 35.54 15.9% 0.09 35.68 16.6~ 0.09 35,46 16.75 0,09 36,56 17.31 0.09 38.2% 1~.31 0.09 39.23 19.57 0.10 39,82 20.98 0.09 40.51 23.42 0.08 40,59 24.7~ 0.08 %0.07 23.%6 0,10 39,71 19.01 0.11 39.3% 16.83 0.10 38,72 17.4a 0,11 38,68 18.38 0.11 40,00 19.35 0.11 %0.40 21,94 0.10 39.85 ~5.~7 0.09 3~.le 2~.12 0,10 39,12 28,94 0.11 39.7~ a7.57 0.13 40.62 2~.98 0.14 40.~8 20.05 0,15 39,96 lg,53 0.15 40.07 18.90 0,14 %0,22 19.38 0.13 ~0.37 20.83 0.13 %0.33 22.98 0.10 %1.13 27.90 0.07 %2.38 33.13 0.05 %2,89 37.46 0.0% %3.04 5~.79 0.05 42.34 35.94 0.09 ~0.91 ~6.57 LS 3%0.20 342.65 350.00 350.00 3%6.32 3%7.55 352.45 357.35 361.03 365.93 373.28 376.96 378.19 384.31 383.09 383.09 37~,19 375.7% 367,16 356.13 3%7.55 3%2.65 338.97 3~0.20 345.10 350.00 352.%5 356.13 354.90 345.10 342.65 3%1.42 3%3.87 3~3.87 - 343.87 3%6.32 351.23 35~.90 357.35 358.58 356.13 353.68 342.65 33~.07 332.8% 335.29 341.42 353.68 365.95 372.06 SS 426.99 %29.45 431.90 431.90 %30.67 42,9.45 %31.90 436.81 %42.94 %51.53 %57.67 %61,35 ~62.5~ %62.5~ 455.21 43.6.81 . 438.04 %36.81 431.90 %26.99 %55.21 ~5~.76 %34.36 426.99 4R5.77 %33.13 %53.99 457.67 ~58.90 PAGE p SI~ASKO PRODUCTTON WILDCAT .... KENA[,ALASKA DATA EVERY I SAMPLES SRO CALO ~625.50 44.38 16.01 2.35 ~2~,50 4~.62 16.27 ~627.00 ~5,72 16.~G 2.35 2627,50 ~6.~! 16.51 2.35 ~G2R,O0 45°72 16.50 2.34 ?62R.50 49.1! 16,6~ 2~34 ~629,00 ~5.84 16,61 2~35 ~629,50 44.25 16,56 2.36 2630,00 43.28 16.63 2.~6 2630,50 ~5.60 ~6.73 2~3q ~631.00 4~.72 16.73 2~33 ~631,,50 45,97 1~,~7 2.31 ~6~,00 47.~8 [~.~ 2.29 253~.50 ~6o2! ~6.~5 2.23 ~.00 ~7.80 16.6~ 2~18 2633,50 50.37 16.62 2,[7 2634.00 57.93 16.G1 2.19 ~63~.50 5~.44 1G.GO 2~21 ~63~,00 5~,69 16,65 263~,50 53.18 16.66 2~28 263~,00 50,86 16.63 2.28 ~637.00 46,9~ 16.73 2.28 ~G$7.50 47.92 16.6~ 2.28 26~8,~0 48,,~4 I6.G~ 2~27 ~63~.50 48.41 16.67 2.26 2634.00 ~8.17 16.5~ 2728 263q.50 49,76 16.46 2.31 2~40.00 50.61 16.~4 2.31 2640.50 50.12 16.3~ 2.31 ~64],,00 50,12 16,35 2,32 26~1.50 50.73 16,35 2~33 264~.00 48.66 16.39 2.34 264~,50 48,53 16.44 2,34 ~6~.00 ~7.07 16.3~ 2~35 2643.50 45.72 16.3~ 2~35 ~6~,00 4R.70 I6.37 2.35 ~6~5,50 51,59 16.33 ~$4~.00 52.32 16.~0 2.35 ?~.50 51.47 16.~3 2.34 2~47.00 50.37 16.37 26~7.50 46.9~ 16.2R 2.33 ~64~.00 47.56 16.37 2.34 ~&48.50 50.12 16.35 ~&4~,O0 57.08 16.33 2.34 264q.50 51.71 16.29 2.36 ~650.00 50,73 16.?G 2.37 ~&50.50 51.83 16.26 2.37 CO, .... KALDACHABUNA N1 CORR C~ OENP 0.11 38.83 1~.20 0,10 37.~7 1~.75 0.10 36.27 18.G0 O.lO 35.94 1~.46 0,10 35,68 18.38 0.10 36.41 1R.79 0.10 36.45 1R.75 0.11 3a.82 18,05 0,11 37,99 17,6~ 0.11 38.87 17,86 0,10 38.~8 18.72 0.09 ~8.61 19.6~ 0.08 38.72 20.~6 0,08 39.60 21.94 0.07 40,37 25.27 0.06 41.90 2A.24 0,07 43,29 29,01 0,08 43.15 ~8.09 0,09 42.20 2~.46 0,10 41,35 ~4,61 0.1! 40.48 2~.68 O.lO 40.04 22.12 0.~0 40,04 2Z.20 0.10 40,22 22.27 0,09 40,22 22.49 0,09 40,40 23.31 0.09 40.66 23.61 0.10 40.37 2~.68 0,11 40,15 20.53 0.10 39,74 20.31 0.10 39,16 20.72 0.09 38.83 20.27 0.09 38.50 19.16 0.09 38.10 18.90 0,08 37.37 18,83 0.09 37.33 1R.46 0,09 37.80 18,09 0,09 38,32 17.94 0,10 38,02 17,57 0.10 38,24 17.~6 0.11 38.87 17.~6 0.11 39.56 1R.20 0,11 3g,GO 18.72 0,11 39.23 19.05 0.11 38.94 19.12 0.11 38,87 19.09 0.11 39.01 19,05 0.11 39.05 1R.64 0.11 38.~6 17.53 0.12 37.84 17.05 0.12 37.15 16.97 Lg 375.74 375,74 376.96 373.28 370.83 368.38 364.71 363,~ 36~.71 365.93 363.48 357.35 348.77 332.8~ 331.62 336.52 3~1.42 345.10 348,77 350.00 350,00 3~8,77 346.32 345.10 3~6.32 350.00 352.45 357.35 361.03 365.93 369.61 372.06 373.28 372.05 369,61 372.06 368.38 365.93 359.80 359.80 361.03 359.80 358,58 358.58 359.80 362.25 364.71 367.16 370,83 369.61 456. ~ 21 451.53 '~SJ, 53 ~.5.7.67 ~8.90 ~5B,90 ~9.0~ ~26,99 ~36,81 ~3~, 26 ~0. ~e 435.58 44..4. ~ 7 451,53 45.6, ~ ~.6~. 35 ~6~.35 V6g · 58 V60.12 ~60.12 ~58.90 451.55 ~51.55 ~7.85 ~50.~1 ~50.~1 ~1,7~ t22 124 PACE ~ SI~ASKO PRODUCTTON WILDCAT .... KENAI,ALASKA DATA EVERY ! SAMPLES ~RO C~LO DFN 265] ,00 5P,93 16.26 2,37 ~,50 ~...~. !~.~ 2.36 265~.00 53.18 16.3~ 2~35 265}.50 53,79 16.45 2~33 2653.00 57,58 16.45 8.30 265~.50 56.60 1~,41 2.26 ~65~,00 54,03 16.15 2.18 ~s~.so 55,ol 16.16 265S.00 55.99 16.26 2,03 2655,50 ~9,39 16.35 1.92 2656,00 43.~8 I6.30 1~80 265A,50 ~3.52 16.39 1.76 2657.00 47.~0 16.41 _~.7.,~.0 ~5,87 16.51 2,11 265~.00 59,90 16.59 2.23 ~65~.50 60.39 16.5~ 8~23 2659.00 61.00 16.55 2~23 ~659o50 61.00 16.57 2.27 ?660.00 57,~3 16.52 2.34 ~66~_, 50 ~4.03 16~62 2~3~ 8661.00 5~.08 16.65 ~661.50 53,~2 16.63 2~32 266~.~0 51.3~ 16.67 ~66~.50 Vq.39 16.65 2.31 266~.00 42.78 16.67 2.29 ~6~.50 50.00 16.70 2.27 ~6~.oo 50.98 16.s~ ~.26 ~66~.50 V9.39 26.57 2~28 ~665~00 V9.27 16.57 2~30 266~.50 50.~7 16.56 ~.33 ~6~.00 52.57 16.57 2.36 p6~.ob ~.29 16.60 2667.50 ~7.19 16.6~ 2.34 2668.00 51.10 16.59 2~32 ~66~.50 53.67 16.61 ~6~.oo 5~.42 16.~ ~'.27 ~6e,5o 5~.42 16.4o 2.2~ ~7~,oo 5~,57 16.4o 2[~o ~67o,~o 51,~6 ~6.3~ 2.29 ~671.00 5t.59 16.35 2~27 ~67~.50 5~.32 16.37 ~7~.00 52.08 16.~7 2.21 ~$7~.50 51.10 16.~1 2.17 2673.00 5~.71 16,4V 2~17 ~7~.50 5~.08 16.41 2~21 ~74.00 50.61 16.41 2.30 ?~7~.50 48.53 16.44 2.34 ~67~.00 4~.27 16.30 2~33 ~675.50 4q.76 16.32 2,32 ~67R.00 ~7.92 16.23 2.31 CO. .... KALOACHABUNA ~1 CORR C~ 0,12 36,80 I~.R~ 0.11 35,87 17,54 0.11 36.49 1B.23 0.11 37,48 19.12 O,ll 38.94 21.23 0,12 40,88 0.11 43.26 28.35 0.11 45.~9 3~.57 0.09 47.72 37.83 0.06 49.22 44.17 0.03 49,26 51.50 0.02 48,93 5~.0~ 0.05 47.24 0.09 45.45 3~.98 0,09 ~4,13 25.3~ 0.08 ~3.~2 25.2~ 0.07 42.82 25.31 0.08 41.90 2~.75 0.10 40.91 0.10 39.60 18.S3 0,10 37,99 19.46 0.10 36.56 20.20 O.IO 36,23 20.53 0.10 36.41 0.09 36.23 21.~3 0.08 36.20 22.98 0.08 36.49 23.6~ 0.10 37.37 22.57 0.11 38.65 21.12 0.11 39.20 19.12 0.12 39.20 17.53 0.11 38.68 17.72 0.11 37,84 17.9~ 0,11 37.26 1B.53 0.11 37.26 20.20 0.10 37.33 0.10 38.06 2~.~6 O.ll 38.57 2~.~7 0.11 39,05 21.12 0.10 39,3~ 21.6~ 0.09 39,20 0.08 38.50 0.07 38.9~ 26.87 0.07 t9.85 29.09 0,07 ~0.~ 29.8~ 0.08 40.66 26.61 0.10 ~0.11 20.98 0.09 39,09 19.01 0.08 17.59 19.53 0.08 36.38 0.09 36.09 20.53 tS SS 362.25 354.90 ~30.67 345.10 ~4.5~ 334.07 ~15,95 321,81 314.~6 ~07.36 305.88 ~04.91 300.98 .~02.~5 30~.66 ~06.13 307,11 ~13.50 315.69 .~22.09 ~26.72 ~30.67 332,84 436.81 33.7.75 .,.~39.2/, 3~0.20 ~0.~9 345.10 ~ff5.40 352.~5 ,9V9.08 356.13 ~50.31 362.25 367.16 367.16 365.93 ~2.9~ 365,93 36~.71 4~1.72 36~.71 #40.49 361.03 357.35 358,58 , 363.4,8 .j_57.67 367.16 460.12 369.61 ~58.90 369.61 ~55.21 368.58 ~51,53 365.93 ~50.31 362.25 #~.17 361.03 ~49.05 361.03 ~53.99 362.25 362.~5 ~55.21 365.93 361.03 356.13 50.31 353.65 ~9.0B 354.90 452.76 358.58 ~56.4~ 363.48 458.90 372.06 458.90 376.96 376.96 460.12 37~.25 455.21 370.53 ~53,99 PAGE q SIMASKO PRODUCTTON CO. .... KALDACHABUNA WILDCAT .... KENAI,ALASKA D~TA EVERY 1 SAMPLES ffl GRO CALO DFN CORR 267~.50 ~9.0~ 16.30 2~$1 0.10 36.q5 2577,50 52.32 16.30 2,32 0.11 36,93 267~.00 53.55 16.2~ 2~32 0,11 37.29 2678.50 51.83 1~.24 2~30 0.11 38.28 2679,00 49.~3 16.Pl 2.27 0.11 39,01 2679,50 50.12 16.22 2,20 0.11 39.78 2~0.~0 ~.~.1~ 16.2~ 2.12 0.!0 ~0.33 2680,5'0 53,67 16.22 2.03 0.08 41,35 2681,00 51,71 16.2V 1.92 0.05 42.89 26~1,50 . ~8,0~ 16.22 1.82 0,02 ~V,76 . · ?6BP.50 V~.30 16.1~ 1.83 0.03 268~.00 ~1,,93 16.i3 1.95 0.05 42.63 268~.50 45.84 16.13 2.16 0.10 ~1.65 268~.00 50.00 16.30 2~31 0.12 ~0,62 ~6~,50 51,22 16.VV 2~35 0,12 38.83 ~685.00 53,30 16.37 2.3V 0.10 37,70 ~685,50 53,06 16.30 ~.33 0,09 37,77 PGBG,00 52,20 16.34 ~.33 0,09 38,~3 ~68~.50 5~,08 16.32 2~$3 0.09 38.87 ~687,00 52.08 16.32 2~5~ 0.10 39.38 2687,50 50,37 16.35 2,33 0,09 ~0,11 268R.00 ~B.66 16.2~ 2.29 0.08 V0.37 P68R,50 ~R,29 16,25 2~2q 0,06 39,~5 268q.00 ~R,90 16.2~ 2.18 0.06 38.65 ~68q,50 49.02 16,15 2.11 0.06 38,61 2690.00 ~9.51 16.12 2.04 0.05 39.~1 g690.50 51,B3 16.06 ~.05 0.06 ~0.15 ~691.00 5~.0~ 16.0S A.O4 0.06 ~0.51 2691.50 51.B3 16.07 ~.0~ 0.05 ~0.26 ~69~.00 48.90 16.10 2.01 0.0~ 39.q5 P692.50 46.82 16.06 2.05 0.05 38.~6 ~69].00 ~7,07 15.99 2~12 0,08 37.80 2693.50 50.00 16.0~ 2.$0 0.11 36,63 ~69~.00 52,08 16.16 2.32 0.09 35,72 ~69~,50 5~,~0 16.17 2.50 0,09 35,90 ~$9~.00 53.30 16.11 ~30 0,09 36.27 ~69~.50 5~,57 16.1~ 2.30 0,09 36.52 269A.00 56.97 16.13 2.30 0.09 36.52 2~9~.50 5~,65 16.15 ~$2 0.10 56,~5 ~697.00 51.71 16.0~ 2.33 0.10 36.52 P~97.50 4q.39 16.06 2,35 0.11 36.~5 P69R,O0 ~8,66 16.07 2~37 0,!3 36,7~ ~69~.50 49,02 16.07 2.36 0.13 37.07 ?$99.00 48.78 16.05 2,30 0.12 37.40 2699.50 47,31 15.99 2~21 0.09 39,01 ,'3ENP LS SS 20.31 369.61 )oo oo 5o.~0 ~l.s1 ~5.95 ~9.76 338.97 .~33.13 29.98 356,13 ;{gl 72 eO,6~ 361.03 ~,~6 359,80 ~2,9~ ~8,8~ 357,35 19,g2 3~8,77 ~36,81 19.05 3~5.10 '~33,13 19,~8 3~5,10 ~l.6B 3~2.65 ~19,63 2~.~6 335.29 11~~0~ 3R.72 330.39 11 O~ 37.16 332.8~ 13 50 37.09 3~2,65 23 31 37.2~ 350.00 ~31 90 38.61 357.35 ~36~81 37.~7 36~.71 40 ~9 31.90 368.38 ~1.7~ ~1.~3 369.61 ~9.0B 21.3R 373.28 ~53.99 21,12 376.96 ~q61,35 20,98 378.19 j~63,80 19.1~ 378.19 1B.16 369.61 ~52.76 17.75 3~7.55 ~26,99 ~0,9~ 529.1~ '~15.50 2~.90 ~15.69 V01,2~