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Home My WebLink About160-031 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 11/19/98 PERMIT DATA T DATA PLUS RUN RECVD 60-031 BLUELINE L Ri 01/20/93 60-031 SPEC L 01/27/93 60-031 TEMP L 01/20/93 60-031 TEMP L 01/27/93 60-031 TEMP/GR L 3000-4222 07/12/93 60-031 COMP 8/22/96 L 708-950 1 10/07/96 10-407 R COMPLETION DATE ,,,/ / / / / / DAILY WELL OPS R / / / TO / / / / / / Are dry ditch samples required? yes no And received? yes no Was the well cored? yes no Analysis & description received? yes no Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 15, 1996 Land Department J. Brock Riddle, Mgr. Marathon Oil Company PO Box 196601 Anchorage, Alaska 99519-6601 Re: Location Clearance Kenai Unit Well #14-4 Dear Mr. Riddle: On July 26, 1996 our inspector, Louis Grimaldi, witnessed the surface abandonment of your well Kenai Unit #14-4, PTD 60-031. He concluded that subject well meets the requirements for Location Clearance. Final Location Clearance is hereby approved for the Kenai Unit Well #14-4. The Commission will require no additional work on subject well; however, Marathon remains liable if problems with the wells occur in the future. Chairman CC: Blair Wondzell Lance Lamons Icma I ciw MEMORANDUM TO: THRU: David Jo~n, Chairman Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 26, 1996 FILE NO: OQ9JGYDD.DOC FROM' Lou G rimald i,'~',.,. SUBJECT: Petroleum Inspector Surface plug Marathon well #14-4 Kenai Gasfield (Gaswell rd) Friday, July 26, 1996: I traveled to Marathons KU 14-4 to verify placement of the Surface cement plug in the abandonment of this well. This well had 200' of tubing pulled, perforated and cement circulated to surface prior to rfiy arrival. There was well cured cement observed in all casings and a 1/2" plate was welded to the 20" drive pipe in my presence. A 4" pole was welded on this plate with the proper well information bead welded onto it. I noticed that the casing was cut off at approximately ground level. I discussed this with Lance Lamons (Marathon Oil rep.) who pointed out the ground water level was very high in this area and they could not dig any deeper without flooding the cellar area. I advised Lance that our reg's require a minimum ~ of 3 feet below grade for final abandonment and may require a additional cut on this (_casing once the pad is removed. This location is on.CIRI land and falls under BLM jurisdiction A plan for final abandonment may be in place with them SUMMARY: i verified the placement of the Surface cement plug in Marathons KU 14-4 in the abandonment of this well. Attachments: OQ9JGYDD.XLS cc; Terry Kovasovich (Marathon Anchorage) NON-CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2. ) FILE INFORMATION: I Permit not on Operator:. Address: [Location Surface Location: F L, F L Section ,T ,R ,M Well Name: PTD No.: AP! No. 50- Unit or Lease Name: Field and Pool: Downhole P&A Date: Inspection Date: I 20 AAC 25.125 - ABANDONMENT MARKER: I Approval Date: Steel Post OD: (4" rain) 4 "Length (10' min.) 12 ft. Height Above Final Grade Level (4' min.) ~ Top of Marker Post Closed With: Welded 0Nelded, Cmt., Cap), Set: Casing (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ~ ft. Side Outlets: All valves and nipples removed ? Yes All openings closed ? Yes With N/A Marker Plate Diameter: 20" Marker Plate Attached To: Wellhead "Thickness: 1/2" "Distance Below Final Grade Level: ? ft. Cutoff Csg Yes Other ,, Information Beadwelded Directly to Marker Post or Blind Marker Plate: ( Note wl~en different from file information) Operator:. Marathon Oil Unit/Lease Name: FED Lease# A-028047 Well Name: KU 14-4 Remarks: "Physical location as follows"; Surface Location: 1177' N 4489' W SE Comer F L, F L Section 4 ,T 4N ,R 11W ,M S Inspection Date: PITS: 20 AAC 25.170 - LOCATION CLEANUP'. I Approval Date: Filled In: Yes Liners Removed or Buded: Debris Removed: SURFACE CONDITION OF PAD AND / OR LOCATION · Smooth ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: NO Type & Quan. of Debris if any remaining on pad and / or location: Equipment, Pipe, Wellhouse Fence TYPE AND CONDITION OF SURROUNDING AREA' Grass ( Wooded,Tundra,Grass, Brust~,Dirt, Gravei,Sand) Clean: Yes Type & Quan. of Debds if any remaining on surrounding area · TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: Gravel ( Dirt, Gravel, Ice, Other) Clean: Yes Type & Quan. of Debds if any remaining on access road or surrounding area · CLEANUP WORK REMAINING TO BE DONE' Fill in cellar, Remove remnants of operations, Remove pad (if neccessa~/) NOTE; Federal lease (Native land) BLM should be consulted on their allowances for leaving the pad and cleanup required. RECOMMENDED FOR APPROVAL OF ABANDONMENT: 'T' Yes /~. No ~ ( If "No" See Reason ) r Dis~bul~on: Reason: Casing cut off at ground level (may be OK with 8L/VI), Pad has not been removed. odg - Well file c - Operator FINAL INSPECTION: Yes No X c - Database c- Inspector INSPECTED BY: Louis R. Gdmaldi DATE: 7/26/96 FI-O00 (Rev. 3~3) OQgJGYDD.XLS PLUGGI~"& LOCATION CLE~CE REPORT State of Alaska .ALAS.~OIL & GAS CONSERVATION COMMISSION .. Memorandum To File: Note casing size, wt, S fc Csg: ~O Perf inte~als - tops: Review the well file, and' c~ent on plugging, well head status, and.location clearance .- p~oxid_e&l~Q~ clear. code. . - ~/~ 7,s.'~,o. '/~.. l ' Well hea~ cut off: Code ' *' i..~, ..~ ;-.~, STATE OF ALASKA .,~,~ ~ iSKA OIL AND GAS CONSERVATION CC ]ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Weli 'i;- Classification of Service Well OIL[~ GAS~"~' SUSPENDEDD ABANDONEDF~ SERVICEO . 2. Nbme of Operator .~ · 7. Permit Number MARATHON el L COMPANY ~-~. 60-31 , 3. Address 8. APl Number P. O. Box 196168,Anchorage, AK 99519-6168 50- 733-10087 4. Location of Well at Surface 9. Unit or Lease Name 1177' N and 4489' W from SE Corner, Sec. 4, T4N, R1 lW, S.M. Kenai Unit At top of Producing Intewal 10. Well Number Straight Hole ! ~1~ KU 14-4 At Total Depth : -'~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.). ~6. ,!Lease Designation and Serial No. Shallow Sterling 104.6 KB ~!'~ A-028047 Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12..Date Spudded 13. Date T.D. Reached 14. 7-26,9-- I I October 1960 ~ feet MSL ~17;~Totat DePth ('MD+TVD), 18. PlUg BackDepth (MD+TVD) ,: ~ ........... ~ ~ 19, Directional Survey Yes[~"lNo r~,,,, 120' Depth where SSsv set feet MD 121' Thickness °f Permafr°st 22. '~ype Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 6' Driven 2' 11-3/4" 40 H-40 1069' 1205 SX 3' 7" 23 & 26 J-55 5102' 800 SX 4' 24. Perforations open to Production (MD+TVD ~f Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 4158' 4148' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27:' PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR , OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD ~ I Fiery Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL o Form 10-407 Rev. 7-1-80 O:\EXCEL\144COM PL.XLS (nrs) CONTINUED ON REVERSE SIDE Submit in Triplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered NAME MEAS. DEPTH TRUE VERT. DEPTH and gravity, GOR, and time of each phase. 31. LIST OF A'I-I'ACHMENTS Operation Reports, Procedure, Wellbore Diagram 32. I hereby certify that the foregoing is tru=e and correct to the best of my knowledge Signed ~;~~ Title ~ ~~ ~ Date '~"' V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other. explain. Item 28: If no cores taken, indicate "none". Form 10-407 O:\EXCEL\144COMP.XLS (nrs) ~_AI%ATHO~ OIL COMPANY DAILY WELL OPERATIONS (As of 0700 hrs.) DATE Y -~ -- ~ R-- ORT TD (MD) ~ 690/?~O PBTD PRODUCTION CASING SiZE/DEPTH DATE LAST WL WORK WORK DONE WR ~ ~/F-d~ WELL NO. /C&; /~'~ ~ILL DEPTH/DATE 7'' TUBING SiZE/DEPTH TREE CONDITION BENCHES OPEN PRESENT OPERATION ~00 ~_~ HOURS 0700- SUM~RY OF OPERATIONS 07oo--/~o REC: VED PAGE 1 of PAGE(S) WELL TESTS BFPD %WC BOPD LG GOR TP CP BEFORE AFTER COMMENTS: DAILY COSTS DATE ., CUM: /..,~) 4&--~ REPORTED BY: M_AP~ATHON OIL COMPANY DAILY WELL OPERATIONS (As of 0700 hrs.) DATE Y" 2 ~ ~ ~ R=~ORT FIELD TD (MD) ~d~9 / fsi) PBTD PRODUCTZON CASING SiZE/DEPTH AFE'-" WR ..... FILL DEPTH/DATE TUBING SIZE/DEPTH DATE LAST WL WORK TREE CONDITION WORK DONE BENCHES OPEN PRESENT OPERATION HOURS 0700- SUM~.ARY OF OPERATIONS ' I PAGE ! of PAGE(S) WELL ~STS BFPD %WC BOPD LG GOR TP CP DATE BEFORE AFTER DAILY COSTS ¢7/40 CUM: &Z~/~O~-- REPORTED BY: ~'~_AFuXTHON OIL COMPANY DAILY WELL OPERATIONS (As of 0700 hrs.) DATE TD (MD) PRODUCTION CASING DATE LAST WL WORK R_2ORT FIELD AFE,--~, WR PBTD SiZE/DEPTH ~ ''/ FILL DEPTH/DATE TUBING SIZEIDEPTH TREE CONDITION WORK DONE PRESENT OPERATION HOURS 0700- BENCHES OPEN SUM~RY OF' OPERATIONS /o~ -tz~ PAGE ! of PAGE(S) WELL ~STS BFPD %WC BOPD LG GOR TP CP DATE BEFORE AFTER DAILY COSTS W77 D cuM: REPORTED BY: ] , · Y_A'~LATHON OIL COMPANY DAILY WELL OPERATIONS (AS of 0700 hrs.) FIELD TD (MD) O PBTD FILL DEPTH/DATE PRODUCTION CASING SiZE/DEPTH TUBING SIZE/DEPTH DATE LAST WL WORK TREE CONDITION WORK DONE BENCHES OPEN PRESENT OPERATION HOURS O700- SUM~RY OF OPERATIONS PAGE ! of PAGE(S) WELL TESTS BFPD %WC BOPD LG GOR TP CP DATE BEFORE AFTER COMMENTS: costs 3 8-o REPORTED BY: LA/~A;m'~N..% 'M-ARATHON OIL COMPANY DAILY WELL OPERATIONS (As of 0700 hrs.) DATE .7-~- ~ TD (MD) k_ P 0 RT FIELD PBTD AF F~-'~ WR FILL DEPTH/DATE PRODUCTXON CASING SiZE/DEPTH TUBING SIZE/DEPTH DATE LAST WL WORK TREE CONDITION WORK DONE BENCHES OPEN PRESENT OPERATION ~Z-~ P~:4e/>~,,~-~/~///iz"/_~/ ,~~~,~t/~,~ -- ~/,~/,~ ~/~ ;7- HOURS O700- SUM~RY OF OPERATIONS i Err-!v n PAGE 1 of PAGE(S) WELL TESTS BFPD BEFORE AFTER COMMENTS: %WC BOPD LG GOR TP CP DATE DAILY COSTS '~~9 CUM: REPORTED BY: Z/~~~V~ 20" @ 6' KU 14-4 CI~!qT 7-26-96 120 sx cel~ent plug in 7" & 7" x 11-$/~, annulus to surq Perf 7" 164-165' Cut & pulled TBG @ 222' WSO 4180' SOZD PE~ 4194'-250' TOP OF ~l_f_ 4289' PE~ 4295' PE~ 4311 '-20' TOC 4322' PERF 4315'-27' PERF 4344' CEMENT RET~R 4500' PERF4825' PERF4827' PERF4838'-40' TOC4850' PERF4885'-gg' PE~4894'-97' 155 sx cement plug in TBG & both annul ii Est T0C 500' ,Derf'd 2-7/8" & 7" 850'-852' T~ IN TUBING I~26' (~VlRELI1N'E TAG} TUBING PERF 162{'-1630' SQUEEZED W/80 aX TOC I~ TUBING ~'~ 2,703' (WIREI2NE TAG) PE~ 4194'-2S0' SQUE~-~ W/?S aX ~ ~" CEME~ PE~ 4900'-08' PE~ 4916'-26' WSO 4949' PB~ 5043' ,'"'@~to2' Well KU 14-4 Abandonment Procedure Pull Wellhouse off prior to starting work 1. RIU Dowell and test 2 7/8" Tubing to 1500 psi. Test 2 7/8" X 7" annulus to 1500 psi. 2. RJU E-Line. RIH and perforate 2 7/8" tubing and 7" casing from 850' to 852' with 4 spf. 3. R/U Dowell and establish circulation down 2 7/8" tubing, up 7" X 11 3/4" annulus. Establish circulation down 2 7/8" tubing, up 2 7/8" X 7" annulus. (Note: If unable to establish circulation up 7" X 11 3/4" annulus, then establish injection rate down 7" X 11 3/4" annulus.) 4. Mix and pump 27 bbls cement down 2 7/8" tubing. Circulate or squeeze (based on results in step 3) 18 bbls cement into the 7" X 11 3/4" annulus. Circulate 7.5 bbls of cement into the 2 7/8" X 7" annulus. Displace cement with 3 bbls of water, leaving 1.5 bbls of cement in tubing. (TOC 600' ). 5. W.O.C, Test 2 7/8" tubing, 2 7/8" X 7" annulus, and ?" X 11 3/4" annulus to 1500 psi. 6. R/U wireline. RIH and cut tubing at 200°. R/D wlreline. 7. N/D Tree. 8. Pull tubing out of hole. 9. Perf. casing at +/- l~i0'. 10. Establish circulatio~l down 7" casing and up 7" X 11 3/4" annulus. 11. Mix and pump 19 bbls of cement down 7" caaing and up 7" X 11 3/4" annulus, to within 5' of natural grade. 12. Remove cellar and excavate to 5' below natural grade. 13. Cut 20", 11 3/4", and 7" easing to 5' below natural grade. 14. Weld abandonment cap with Well info ..0..n casing stubs' · · .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: ¢~,bandon X Suspend __ Operation shuhlown -- Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Vanance __ Pedorate __ Other __ 2. Name of Operator ! 5. lype of Well: Marathon Oil Company i Development__ Exploratory __ 3. Address L Stratigraph~c P.O. Box 196168, Anchorage, AK 99519-616~ Serv,ce-X- 4. Location of well at surface 1177' N & 4489' At top of productive interval At effective depth At total depth W from SE corner, Sec. 4, T4N, R11W, SM ORIGINAL 6. Datum elevation (DF or KB) 104.6 7. U n~t or Property name Kenai Unit 8. Well number KU 14-4 9. Permit number 60-31 10. APl number 5o- 733-10087 11. Field/Pool Shallow Sterling feet 12. Present well condition summary Total depth: measured true vertical EFfective depth: measured true vertical Casing Length Structural 6 ' Conductor Sudace 1069' Intermediate Production 5102.' Liner Perforation depth: measured 5,12 5 feet 5,12 5 feet feet 4,289 feet 4,289 Size 20" I 'lugs (measured) 2-7/8" tubing @ 1226' 2-7/8" X 7" annulus @ 1430' 7" X 11-3/4" annulus @ 1430 Junk (measured) Ct ~mented Measured depth True vertical depth Driven 6' 6' true vertical Tubing (size, grade, and measured depth) 11-3/4" 1205 sx 1069' 1069' 7" 800 sx 5102' 5102' Buttress @ 4158' 4194' - 4250' 2-7/8" 6.4# N-~O est. est. Packers and SSSV (type and measured depth) Baker model "D' packer @ 4148' C :,) OCT 0 z 199:5 Alask~ Uil & Gas Cons. Commission , ~chorage !3. Attachments Description summary of proposal ~ I)etailed operations program __ BOP sketch __ 14. Estimated date for commencing operation October 9, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~F~C~L~;~., ~/I~~ Title Drill ing Superintendent M. F. SincTair FOR COMMISSION USE ONLY Conditions of approval: Notify_Commission so representative may witness Plug integrity ..~- BOP Test __ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission original Signed By David W. Johnston I Approval No. &pproved Copy Returned Commissioner Date Form 10-403 Rev 06/15~88 SUBMIT IN TRIPLICATE .a~'c L~ ~d,~ararl~on UII Gompany · ;itl-a-Ut5 ;10:52A1~1 ; Anchorage-, 907 276 7542;# 2/ 3 KU 14'4 ABANDONMENT PROCEDURE CURRENT WELL STATUS SHOWN ON SCHEMATIC LABELED CURRENT 1. RETEST 2 7/8" TUBING TO 1500 PSI. RETEST 2 7/8" x 7' ANNULUS TO 1500 PSI. 2. PERFORATE 2 718" TUBING AND 7" CASING FROM 850' TO 852' WITH SPF. 3. ESTABLISH CIRCULATION PUMPING DOWN 2 7/8" TUBING THRU PERFS AT 850' TAKING RETURNS UP THE 7" x 11 3/4" ANNULUS. ESTABLISH CIRCULATION PUMPING DOWN 2 7/8" TUBING THRU PERFS AT 850' TAKING RETURNS UP 2 7/8" x 7" ANNULUS. (NOTE: IF UNABLE TO ESTABLISH CIRCULATION UP 7" x 11 3/4' ANNULUS, THEN ESTABLISH INJECTION RATE PUMPING DOWN 2 7/8" TUBING THRU PERFS AT 850' AND INTO 7" x 11 3/4" ANNULUS.) 4. MIX AND PUMP 27 BBLS CEMENT DOWN 2 7/8' TUBING. CIRCULATE OR SQUEEZE (BASED oN RESULTS IN STEP 3) 18 BBLS INTO THE 7" x 11 3/4" ANNULUS. CIRCULATE 7,5 BBLS INTO THE 2 7/8" x 7" ANNULUS. DISPLACE CEMENT WITH 3 BBLS OF WATER LEAVING 1.5 BBLS OF CEMENT IN THE TUBING. 5. WOC. TEST 2 7/8" TUBING, 2 7/8" x 7" ANNULUS, AND 7" x 11 3/4' ANNULUS TO 1500 PSI. 6. WIRELINE CUT TUBING AT +/~ 200'. WITH A CRANE. N/D TREE. PULL TUBING OUT OF HOLE 7, WIRELINE SET 7" RETAINER AT +/- 160'. 8. CUT 7" CASING AT +/- 80' WITH A MECHANICAL CUTTER USING POWER TONGS FOR ROTATIONAL CAPABILITY. Iod {I ~7;~ 9. RIH WITH TUBING TO RETAINER AT 160'. LAY 13 BBL CEMENT PLUG FROM RETAINER TO SURFACE. WASH OUT CEMENT TO 5' BELOW NATURAL GRADE. 10. REMOVE CELLAR AND EXCAVATE. 11. CUT 11 3/4" AND 20" CASING 5' BELOW NATURAL GRADE. WELD CAP TO 20" CASING. SEE SCHEMATIC LABELED PROPOSED OCI 0 Z '~995 6as Cons. Commisston Anchorage KU 14-4 CURRE~ 12/~/94 11-3/4" 42#, H-40 ~ 1069' TOC IN 2-7/8" X ?" AND 7" X 11-3/4' ANNULUS (~ I,,L30' 2-7/8" 6.4g N-80 TUBINO BAKER TYPE "L' SLID~G SLEEVE (~ 4111' BAKER MODEL"O-22" LOCATOR AND SEAL ASSEMBLY BAKER MULE SHOE ~ 4158' WSO 4180' SQZD PERFS 4194'-250' TOP OF ~UNK/FILL 4289' PERF 4295' PERF 431 I'-20' TOC 4322' PERF 4315'-27' PERF 4344' CEMENT RETAINER 4500' PERF 4825' PERF 4827' PERF 4838'-40' TOC 4850' PERF 4885'-88' PERF 4894'-9'7' PERF 4900'-08' PERF 4916'-26' WSO 4949' PBTD ~043' ?"@5~o2' TOC I~ TUBING 1,226' (WIRELINE TAG) TUBING PERF 162r-1630' SQUEE2~D WI 80 8X ~ "G" CTaMENY TOC IN TUBING (~ 2,703' (WIRELINE TAG) PERFS 4194'-250' SQUEEZED WI 7~ SX ~ aG" CEMENT .,J~l~tS~:;~lar~athon 011 Company ;10-3-IJ5 ;lO:82AAI ; Anchor age-~ 907 276 7542;# KU 14~ PROPOSED 9-29-95 Note: Cement may be placed in 7' x 11 3/4' from 85Q' to 1 100' If unable to clrc 2.?/r s.4~ N-tO TUBU~O B,~K.ER 'rY.'L- SI. JDI~O SIZ~ ~ 4111' BAiiF~ MU[,~ SHOE I~. 41 ~S' Pro~oeed oemen! plug from' 160' to 6' ProPbled 7' out & recovery at Propoled 7' retainer at Proposed tbg cut & ret:ovsry mt 200' Proposed TOe at 600' In'both ItnnulJl & tho Proposed tho & 7' perfm st 850' TO(~ ~'1'U~I~{~. lA2&' (WmEU2~TA~ sQUEE2:I:D w/~ fx CLAmI.,~ Cl2,,IENT 'T~ 43~' P£P.~ 4] l J'-27" PERi* PERI" 482:~' P£R.'r 4827' P ERF 483r-4~' PEPJF 4R,i.4r I, EPJ~ PEP,~ 4900%4)1' PERP 4914'.~$' WSO 494~' PBTD J043' OCT 0 2 1995 ~,~aska Oil & Gas Cons. Commission ^ncl~oraoo Marathon Oil Company September 29, 1995 Alaska on Domesh,. ,-'roduction P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: KU 14-4 Abandonment Dear Mr. Wondzell: In November, 1994, Unocal commenced abandonment operations on the referenced well in the Kenai Gas Field. Due to severe cold weather, Unocal suspended abandonment operations on 12-1-94. Since that time Marathon became operator at the field. Marathon proposes to complete the abandonment as per the attached sundry. For your reference, attached are sundries submitted by Unocal as well as morning reports for the work Unocal completed. Sincerely, M. F. Sinclair Drilling Superintendent /nrs H:\WP\DRILL95\MFS9291 Enclosure OCT 0~ ,-]995 Alas~ .Oil .& Gas Cons. ComrnJsslorl 'Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. ABCIIOF age-, 'dU'/ 7./13 Alaska Region Domestic Production Marathon OilCompany RO. 6ox 190168 Anchorage. AK 99519-0168 Telephone 9071561-5311 FAX COVER LEITER PLEASE DELIVER i THE FOLLOWING DOCUMENTS TO: Department/Location Facsimile Number · Number of pages (including this cover page) FROM: Department/Extension ~ ~"d ~x~'~O ---. _:-__ ,- ....... ,1,., I, ,I .... _ ........ , ......... L ....... :.: . . ...... . .............. Facsimile Number ............ (907) ~64-6489 .__ NOTE: T 0 9 1995 .,, Anchorage If transmi~ion is not complete, p/ease ca//(~07) 561-531L A subsidiary of USX Corporation Form 3160- 5 U._ , ED STATES (JUNE 1990) DEPARTMENT OF THE INTERIOR ~ BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to clrill or to cleepen or reentry to a aifferent reservoir. Use 'APPLICATION FOR PERMIT-' for sucl~ proDosals ,.5'UBMIT IN TFiI?LI(.;A TE 1. Type of Welt Oil Gas ~ Well _-- 'Nell ~: Other Disposal Well 2. Name ot Operator Union Oil Company of California (UNOCAL) 3. Address anD Telepl3one P.O. Box 196247 Anchoraqe, AK 99519-6247 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) 1177' N & 4489' W of SE corner of Sec. 4, T4N, R11W, SM FORM APPROVED Budget Bureau No. 1004-0135 Expires: Marct~ 31, 1993 5. Lease Designation and Serial No. A-028047 6. If Indian, ,,Uiottee or Tribe Name 7. If Unit or CA, Agreement Designation Kenal Unit 8. Well Name and No. KU 14-4 9. APl Well No. 50-733-10087 10. Field and Pool, or Explorato~/Area Kenal Gas Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE. REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent .'-3, Subseauent Report\ ,,-..I Final Abanclonment [~ Aban0onment i-'] Change of Plans I-] Recompletion see other j-'] New Construction I-] Plugging Back [-'] Non-Routine Fracturing [-] Casing Repair r-'] water Shut-Off I-'] Altering Casing [] Conversion to InjeclJon I-'! Other_" 1'"1 Dispose Water (NorD: Report re, ufa o~ multiple eonmplmioa on Well Completion or Reoomplet~m Report and Log form.) 13. Describe Proposea or Completed Opemtion~ (Ciearty etate ail pertinent ctem~, and give i)~lment datee, including estimated date ot starling any _prop,~__ed work. If well is direcaonally drilled, give subsurface Iocations,,nd measured a~cl ITUe vertical delXtm for ail markem and zone pertinent to his wo~.)* See Attacl~ea aescri.Dtion of Abandonment 0CT 0 z !995 ~s~ Dil & Gas Cons. C__ommiss~n .... ~ ~c~omge ' 14. I heret~y certity ff~ar ~e toreg~ ~)l~u, an~.~0t.~ Signed G. Russmi Schmidt ~l,~~~~e Driling Manager Date October 17. 1994 (This space for Feoeral and State office use) Approved by Conditions of approval, if any: Title Date Title 18 U.S.C. Section 1001. makes it a crime for any pemon knowingly and willfully to make to any deparlment or egell~f of he United State~ arty hlJlt, fictitious or fraudulent statemenls or representations as to am,/matter within its iurbdi~Jon. *See Instruction on Reverse Side STATE OF ALASKA ~ AL '~KA OIL AND GAS CONSERVATION CC i$SION APPLICATION FOR SUNDRY APPROVALS 1. '~'/pe of request: Abandon X__ suspena __ Opermiorm .hutdown __ Re-enter luspended well__ Alter casing__ Repair welt __ Time extension __ Stimulate __ Change approved program Perforate Other 2. Name ot Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Aclaress P,O. BOX 196247 ANCHORAGE, AK 99519 Plugging __ Pull tubing Vm~anoe 5. Type of Well: Location of well at surface 1177'N & 4489' Wfrom SE CORNER, Sec. 4, T4N, R11W, SM At top of productive interval At effective depth At total depth 12. Present well condition summary Total depth: measured 5,125 feet true vertical 5,125 feet 6. Datum elevation (DF or KB) 104.6 7. Unit or Property name Kenai Unit 8. Well number KU 14-4 9. Permit number 60-31 10. APl numl3er 50-733-10087 11. Field/Pool Shallow Sterling Plugs (measurea) feet Effective depth: measured 4,289' feet true vertical 4,289' feet Junk (measurea) Casing Length Size Cemented Structural 6' 20' Driven Conductor Surface 1069' 11-3/4' 1205 sx Intermecliate Production 5102' 7' 800 sx Liner Perforation depth: measured 4194'-4250' Measured depth 6' 5102' OCT 0z iss true vertical ^las~ 0il & Gas Cons, C0mmissi0r~ Tubing (size, grade, and measured aleph) 2-7/8' 6.4# N-80 Buttress @ 4/t~l~0rage Packers and SSSV (type ancl measured deptt~) Baker model 'D' packer @ 4148' ' - ' '3. Attachments Description summary of proposal X_ True vertical depth 6' 1069' 5102' !VED ,. - ~nc~cr: Detailed operations program_ _ BOP sketctt 14. Estimated clate for commencing operation 115. ASAP 16. If proposal was verloally approved Oil _ _ Gas __ Name of approver Date approved Service Inlector 17. I hereby certify that the f_~oi7 is. t.r~~.~.to the best of my knowleclge. Si.qnea G. Russell Schmldt/1%.~1e Drillincj Man~_ner FOR COMMISSION USE ONLY Status of well classification as: Suspended Date October 18, 1994 Canaitions of approval: Notify Commission so representative may witness j Appr~3val. N/9.:" Plug Integrity ~ BOP Test Location clearance ,,~r~ ~ Mechanical Int __ . Approved by the order of the Commission Commissioner Date I//~1'7/~ Form 10-403 Rev 06/15/88 ---\-- ~ SUBMIT I1~ T~Ii61~I~,ATE ' NOV- 17-~4 , THU - RNUHUNRU~ rN~ mu, r, Ut'/ PKEPARE LOCATION. WORKOVER FROCEDURE KU 14-4 11/16/94 ':"~.'~.~ .: t,. 2. PRESSURE TEST 2-7/8" X 7" ANIWUL~ TO 1,500 PSI. 3. ESTABLISH IN/ECTION RATE AND PRESS~ DOV~T 2418" TUBING. M/X 15 BBLS OF CEMENT. DISPLACI~ 13 BBLS CEMENT BELOW PA~ AT 4,148' AND LEAVE 2 BBL~ ~ IN TUBING. TOC IN TUBING AT +/- 3,803'. 20 AAC 2~.10~ 0l)(1)~), 4. WOC. PP, ESSUKE TEST CEMENT PLUG IN TUBING TO 1,$00 PSI_ VERIFY TOP OF ~ IN TUBINO BY TAGGING W1TH SLICK LIN~. 5. FERFORATjE 2-7/8" TUBIN{3 AND 7" CASING AT 1,630' wrI'H 1-11/16" 12 GRAM CHARGE. ESTABLISH RATB AND PRESSURE TO 7" X 11-3/4" ANNIR,US. SHALE AT 1,630'. 5. ,'MIX 80 BBLS CEMENI', DISPLACE ~0 BBLS CEMENT THROUGH CASING PERFS (TOC=$00' ASSUMING 20% WASHOUT). SHUT ll'q 7" X I1-3/4" ANNULUS AND OPEN 2.7/~" X 7" A_NNI~U$. DISPLAC~ 30 BBLS CBMBNT THROUGH TUBING PERFS (T~'). :10 AAC 7. WOC. PRESSURE TEST 7" X 11-3/4" ANNULUS, 2-7/g" X 7" ANNULUS, AND 2-7/~" T[~INO 1~ 1,500 PSI. S, ~'B C~Yr 2-7/8" TUBING (~ +/- 200'. ND TREE. POOH. RECOVER TUBING WITH A~. 9. FIlLIP'ORATE 7" CASING ~ A 2 GRAM CIP. CULATION CHARGE (~l +/- 165'. 10. P.,U TO PUMP ON ?" CASING. 11. CIKCULATE 19 BBL CEMENT DOWN T' AND UP 11-3/4~ X T' ANNULUS. 20 AAC 2S.~OS ~;(~). 12. CUTT", I1-3/4" AND20" CASING3' BELOW NATURAL GRADE. 20AAC 2~.120(I). 13. EqST~ ABANDONMENr PLATE. 20 AAC 1.~120 (d). 14. REMOVE _~'.t,AR AND BACKFILL. NOTE: DUE TO THE URIGLES$" NATURE OF TH~ ABANDONM~KT, A VARIANCE OF 20 AAC 2~.10S 0) IS REQUITED. IT IS PROPOSED TO TEST THE INTEGRITY OF THE PLUGS BY APPLYING HYDRAULIC PRESSURE IN Ir.ail OF PHYSICALLY TAC, G~G, OCT l)it & Gas Cons. Commissiot~ .-~-, ~chorage KU 14-4 CURRENT SPUD OCT 1960 -314' 42#. H-80 1069' Shatter tumncj nsncjer 18' 2-718' 6.4~ N.SO tuDa'tg Otis °X1 TOC ;n annutus 3560' i'Temo4 Pelf 4827' - P~f 4838-40' ~ 4850' 4885-88' 4894-87' 4900-O8' 4916-26' WSO 4949' @ 5102' TD 5125' Baker Type 'L' sliding sleeve 4111' Baker Moeel 'G.22' I~ an= ama aaeamtW Baker mule ~toe 4158' OCT Oz ~5 .Oil .& Gas Cons, CommissJo_n .... , ~mchorage EC !VED : ~,.,. ~ ~: ..';. u~,,,. Commission ~nchor' GRB 9-14-.84 irlu UNUUP* KiT 14-4 PROPOS~..D ABANDO~ WU ~",~ F~4 P, 03/03 I~OI~O~ED CMT PLUG 1~S' TO 3' B~LOW NATTJl~/, GRADE LEVEL 11-3/4" 42#, H-40 (=~ 1069' PROPOSED 7" CASING PUI~CR ~ 16~' PROPOffF, D TUBING Ct.'T I~ROPOSED TO~ ~ ~N)' IN BOTH 2-?/g" 6,4# N-II0 TUBING BAKER ~ "L" SLIDINO SLEEVE (~ 4111' BAIO~R MODEL "0-22" LOCATOR AND SEAL AS-~BMBL¥ B,a,K~R ~ SHOE ~ 415~' wso ~lS0' OPEN PERI~ TOP OF ~ l~Rlr 4295' PERF 4311'-20' PERP 4315'-27' PER~ 4344' CEMENT ~'I'ALN~R 4500' PERF 482~' PEI~F 4~7' TO~ PI~RF 4894'-~7' FERF 4900'-0g' PERP 4916'-26' W,.~O 4949' PROPOItlRD :FRRF 1630' PROPOSED TOC IN TUBING 4-/. 3803' i'.. ..,i,,.t . OCT Oa 1995 Gas Cons. Commission ^I_A.~'~ DRP · JNO MORNINO lalq~'OlL'l" !. ii, Trip AV IX: : BHA N u at ~.~,~ L~:~se Wt,.,.- ':)rit!"-~ Wt. Drillin! Wt. DrfllMI Wt. R PM: BHA Numeee: Lentte Wt.: · DALLY CO~-[' BRF~tKDOWN Driiline & WO Fluid= Fuel · Water: Fisbi~ ,i 1 ',l · OCT OZ 1~95 ,, - Oil.& Gas Cons. Commission ...... , ~chorage Drilla t Timen: I II I PAO~ I Stm Liner SPM pt- ...... ~-" ~'".; ! .. Brr$ No. , Size ~ Make Type Jet Si_'_-"_ Seriet No. D~I~ &m Oelstll Out : Footage Hou~ i C. asmdMm~, Bi-lA Number: L~- .~_-, WE- Orillim~ Wt. RPM: BHA Numbs': Lg$~ WI_- Drillk~ Wt. P. PM: BHA Number: Lenttl~ W~.: .r)rilli~l Wt. R PM: . ~. DALLY COST BR~_AKDOWN Locat~: ~/'|ftllje · L, Olgll)~| Rig Char~reK Cofltgl~ L&_~_r:. Prod~0~e~ Orilliae & WO Fluid: Fuel dr Wate~. :1 CO_U"~l/T~ (UNOe_4L. OKIt~-tqO ONLY~ I* r.. ,..l.... I v k. OCT OZ 199~ A~n__ska Oil & Ga~ Rnno n,,-..-.:--,-- "'--~ ~cho,ra~o, , Orili~ I Timm; Pump ~ Mc~ Type St _r~_-_ Liner SPM Pr ___,~,e~__SIo~ 8PM $! I #Z i · Well No.: ALASKA DRll J-lNG MORNING REPORT Slot I Report ! AFE · AFE gAnount Dail.vAnoum , Cum Amount ~udT~e Mu~ Wm~t ~ T~ Forage ETD T'VD D ars: H ^V DP AV DC A('X3T, AK. lq~(~!t..~i' 1 Conductoc Surim gs$., Intern#me , ?rodu~t~ Lin~' Top BITS "t g Serial No. Oeptll in De~ln O~t Footage Hou~ No. , Size ~ M~I Typ~ Jet_~ BHA Numbs: LengtO: Wt.: Drilling Wt. RPM: BHA Numbe~: Lcntm: Wt.: Drilling WL RPM: BHA Numbs: LenttB: Wt.: Drillint Wt. RPM~ DALLY CO~ BRE~DOWN R it Cbartea: Contra~ Labor:. ~__ Produ-,mn EquipmL'm: i Drillint ~. WO Fluid: Fuel & Water:. C ~,inc Trananol~atmo-~e _~_o~e_~: t~ ~ Com~/tl~ R apa~ D ireci~G~a: Stimuialm ~& Tntifll.' REMARKS COMMKN'r~ (UNO~AL, DRILLING ONLY3 Walkaix)uw Alaska IJil & Gas Con~, Commi~sio. Drilh / Time~: I Pure. , Mod~ rTpe Strote #1 I :1 Liner gPM Pr~e'_'_q $1o~$1)M j SlowP~ssueu .,, #Z ! pOIll~ ! IV. 1t1141 Ai-ASKA DRII_J_-_IN(] MORNINO REPORT ~ud T~e Mud W~ ~ T ~o~.~e ETD T'VD Since $oud D a~: H ours: Drlg Hrs. Do~ t~rs. , Trip l-ira. 'F oral ~PM ~ AV DP Sur{ae~ CaS. ~ tnt~ed~ate i Production No. ~ Size , Make Type Jet :!!_~_ ,i Loca.on: Wireime & LGelKm$: Superw~mn: Drillinl~ & WO Fluid: Fuel A Wate~. Fishing: REMARI~q FROM '=__~Z~_ to ~-"~- Hits COMMBN'I~ (UNO~AI. DRII=I---INO ONLY1 ~!~__SKA DRIIJANG MORNINO REPORT Mud T~e ~ Mud W~M t T~ Fo~n~e ETD D ;i ~.i: H -- BITS Lin~' Top Boltl No. : Size , Make Type Jet S~__:_--_S~-ial No. Deett~ Ia Oe~b Out Foo~IWe Hem1 zl Bits: E quipm~nt Rental: Drillint a WO Fluid: Fuel a Cement & ' : O i£ecI IOflIl: COMMP-NI~ fUNOCAL. DRILLING ONLY] V'/a lit _- _":--_"_: -' --- I DriII~ I Times: t Model Type Strote Lin~ SPM #Z PAGB 1 D Ho~ Drl$ Hr~ : Do~ Mil- Trip HrL Total GPM APf'.T AK Ri-;¢~l,' ..., I i Condugu~ No. Size , Make BHA Nu-,~_--~. ben;tin: Wt: Dril!in~ WL R PM: BHA Nu-----b=-~: ben~tb: Wt.: Drillin~ WL RPM: BHA Number: ben~tb: Wt.: Orillinl Wt. RPM: DALLY COST BREAKDOWN i REMARICS Oc~ - k%oo XO00 - \ ~ $0- \%50 #Z I uCT OZ i995 " Alas_ga, Oil.& Gas Cons. Commission '. imcnomg~. Slo~ SPM I SIo~ Pmnum Lin~ Driit~ I Time~:, Pump I Model T,vpe Strolte #1 I STATE OF ALASKA ~-~ A SKA OIL AND GAS CONSERVATION COL ~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon X Suspend I Operations shutdown __ Re-enter suspended well__ Alter casingI Repair wellI Plugging __ Time extension I Stimulate __ Change approved program I Pull tubing __ Variance _ _ Perforate __ Other_ _ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 , 5. Type of Well: Devaopment _ _ Exploratory I Slmtigraphic I Service X Location of well at surface 1177'N & 4489' W from SE CORNER, Sec. 4, T4N, R11W, SM At top of productive interval At effective depth At total depth 6. Datum elevation (DF or KB) 104.6 7. Unit or Property name Kenai Unit 8. Well number KU 14-4 9. Permit number 60-31 10. APl number 50-733-10087 11. Field/Pool Shallow Sterling feet 12. Present well condition summary Total depth: measured 5,125 feet true vertical 5,125 feet Effective depth: measured 4,289' feet true vertical 4,289' feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural 6' 20" Driven Conductor Surface 1069' 11-3/4' 1205 sx Intermediate Production 5102' 7" 800 sx Liner Perforation depth: measured true vertical 4194'-4250' Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 Buttress (iD 4158' Packers and SSSV (type and measured depth) Baker model "D" packer @ 4148' ORIGINAL Measured depth 6' True vertical depth 6' 1069' 1069' 5102' 5102' 't 0 1994 Gas Cons. ~0m~[~t¢~ ~ch0~e 13. Attachments Description summary of proposal X_ Detailed operations program_ _ BOP sketch _ _ 14. Estimated date for commencing operation ASAP 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil _ _ Gas I Suspended I Service Iniector 17. I hereby certify that the f.o~oinj~ is. t.r.~1 Signed G. Russell Schmidt,_A~o~ ~~to the best of my knowledge. ~itle Drilling Manager FOR COMMISSION USE ONLY Date October 18, 1994 Conditions of approval: Notify Commission so representative may witness ] Appr~a~o.~ Plug Integrity ~ BOP Test Location clearance i Mechanical Integrity Test__ ~-~bsequent fOrm reqTM ~-~- Original Signed By Approved by the order of the Commission .... . ...... ..... ,/.....~ ~,eh'~rffissioner Date ~, '~'~,/- r ~/--,, Form 10-403 Rev 06/15/88 HUV-J l-~q - l-ll~lbrlUn. Hur.. rna nu, ,, ~, .... IMU · , WOI~OVF. R I~OCF. DU1U~ KU 14-4 11116194 P~AI~ LOCATION. PRF~SURIt TEST 2-7/8" X 7" ANNI~US TO 1,500 PSI. RECEIVED ESTABLISH IN.I~CTION I:b~TE AND PRESSURE DO'~Tq 2-7/8" TUBING. MIX 15 BBLS OF CF_2dENT. DISPLACI~ 1~ BBLS CEMENT BELOW PACKER AT 4,148' AND LEAVE 2 BBLS CEMENT IN TUBING.. TOC IN TUBING AT +l- 3,80~'. 20 AAC 4. WOC. PRI~S~ TEST CEME~ PLUG IN TUBING TO 1,500 PSL VERIFY TOP OF C;EM]E~NT IN TUBING BY TAGGING WITH SLICK LI1V~. 5, PERFORATIg 2-7/8" TUBING AND 7" CASING AT 1,630' WITH 1-11/16' 12 GRAM CHARG!i. ESTABLISH RATB AND PR~SURETO 7" X 11-3/4" ANNULUS. SHALE AT 1,6~0'. 5. MIX 80 BBLS CEMI~NT, DIIPLlC~ S0 ]~L$ CEM]~I?I' TItROUGH CASINO PliES (TOC=800' ASSUIvfiNO 20% WASHOUT). SHUT IN 7' X 11-3/4" ANNULUS AND OPEN 2-7/6" X 7" ANNULUS. DISPLACB 30 BBLS CI~Mi~NT ltIROUGH TUBING PERFS (T~00'). 20 AAC 2s. los (0(2). 7. WOC. PP.d~SSURIg TEST T' X 11-3/4" AHNI~US, 2-7/8' X 7" ANNULUS, AND 2-7/8" TUBING TO 1,500 PSI. 8, WIRELINE CUT 2-7/8" TUBING (~ +/- 200'. ND TP-'F~'.. POOH, RECOVER TUBING WITH A CRANF.. 9~ 10. 11. PERFORATE 7" CASING WITH A 2 GRAM CIRCULATION CHARGE ~1 +/- 165'. AU TO PUMP ON ?" CASINO. CIRCULAT~ 19 BBL CF, MENT DOWN 7" AND UP ] t-3/4" X 7" ANNULUS. 20 AAC is. los (i)O). 12. 13. 14. ci. rr T', 11-3/4" AND 20" CASING 3' BELOW NATURAL GRADE. 20 AAC 25.120 ("9- INSTALL ABANDONMENT PLATE. 20 AAC 25.120 (d). REMOVE CELLAR AND BACKFILL. NOTE: DUE TO THE "RIGLESS" NATURE OF THIS ABANDONMENT, A VARIANCE OF 20 AAC 2~.10S (1) IS REQUESTED. IT IS PROPOSED TO TEST THE INTEGRITY OF THI~, PLUGS BY APPLYING HYDRAULIC PRESSURE IN LIEU OF PHYSICALLY TAGGING. KU 14-4 GURRENT SPUD 001' 196O 11-3/4' 42#, H-80 1069' TOC in annulus 3560' (Temp.) Baker model "D' packer 4148' WSO 4180~qz'd Open peril 4194-250' Top of junk/fill 4289' P®rf 4285' Pelf 4311-20' Pelf 4315.27' Perf 4344' Pelf 4825' Pelf 4827' Pelf 4838.40' TOC 4850' Perf 4885-88' Perf 4894-97' Perf 4900-08' Perf 4916-26' WSO 4949' PBTD 5043' 7' @ 5102' 'rD 5125' Shaffer tubing hanger 18' 2-7/8' 6.4~ N-80 tubing Otis "X" profile 41' Baker Type 'L' sliding sleeve 4111' Baker Model 'G.22' Iocator and seal assembly Baker mule shoe 4158' REEEIVED NOV 10 1994 Alaska Oil & Gas Cons. Commission Anchor&.,e GRB 9-14-94 111 IVl i~l,,/i~.ll'~lt-- KU 14-4 PROPOSF. D .ABA]'~O~ OU i~..UO IOOq 1", UO/UO 11-3/4" 42#, H-40 ~ PROPOSED CMl' PI~UO IgC' TO 3' BELOW NATURAI~ GRADE I~IIOI~$ED ?" CASING PUNCH ~ 1~' I~ROPOSED TUBING CUT AITD ~VERY ~ 200' PROPOSED TOC (~ 800' IN BOTH ANI~ULI PROPOSED PRRF 1~0' FROPOSED TOC IN TUBING ,L/- 38(Lt~ -~',, ~ATE OFALASKA ' ?"~ A ~KA OIL AND GAS CONSERVATION COMM ,ON APPLICATION FOR SUNDRY APPROVAL8 Type of Request: A, bandon .._. SuSpend .._. Operation shutdown __ R~.~nte~ ~=penclec/~1~ ~ ~ter casl~ __ He~ai~we~ Pluggi~ ~ ~me ~ension ~ Stimulate ~ Change appr~d program ~ ~ Pull tubing __ Varlan~ ~ Per[orate ~ Other Name of Operator Un,on 0~1Co~pany o~ California (UNOCAL) S. Aaaress P.O. Box 196247 Anchorage, AK 99519-6247 4, ~caUon~wellatsur!ace 11.77.03~ N. & 4489,35~ W, of G.E. Cu~ue£ ~p~productivei~er~; i. i' Type o~ Well; Development __. $1raUgraphic , . Service ~ - ,.. too 14-4 - 9, Perm;t number At elfective deplh Al Iolal depth 12. Present well condition summary Total depth, measures Irue verbcal (Cla~ II Disposal Well) ., feet Plugs (measured) feet 60-31 10. APl nur~b~'- .... '11. ~ield/Po;31 ' Eenai Cas Field .. .. · .. fee~ Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor 8udace Intermediate Production Liner Perforation depth: mca~urcd true vertical Tubing (size, grade, and measured depth) Pack~sr~ and SSSV (~ype and measured depth) ~ize Cemented Measured depth True ver0cal depth (See original Sundry Approval) RECEIVED JUN - 3 1993 Alaska 0ii & Gas Cons, Comrnissi°'~ Anchorage 13. Attachments Oe~ription summaq Detailed operations program ._... BOP sketch A4d diesel to oil ba~,~d muds and cuttings to slurry for injection, 14. isUmated date ,or cT~~ O.~ationl~3 [1E Sram, of ~11 cl.slficaUon ! Oil ~ Gas ~ SusDend~ __ Date approval Class II m _ m 16. If proposal was verbally approved Name of approver Service I hereby certify thahh6)or_ egpifl~ js true and correct to ~he best Of ~ knowledga sig,~,,,? Bruce S~ Pierre ?~e Environmen~al Coozdinator ' FOR CO_'MMIS$10N USE ONLY " Conditlo~ ~ u~' approval'_ ; Noafy Comml~0n so re pr esenlative may with e ss Plug mtegr~(y --. BOP Test __ Location clearance .._,.,,. Mechanical lnteority Te..~t _._ Subsequent form required t0- q{:~'~- .. Date 6-2-93 Approved Oy order of the Commissioner Form 10-403 Rev 06/1E88 ORIGINAL SIGNED BY " RUSSELL A. DOUGLASS ,~UBM~T IN TRIPLICATE Alaska Oil Gas Conservation Commission 3001 Porcupine Drive. Anchora§e, Alaska 9§S01-31 §2 907-279-1433 Permit The following data is hereby acknowledged as being received: Received by: , ~ Oared: '7/17~3 CopyscnttosendeN Ycs~ No ~' MEMORANDUM S TA TE O~ A LA SKA ALASKA OIL AND GAS CONSER VA TION COMMISSION TO: David Johnston..~?.<. Chairman DA TE: June 16, 1993 FILE NO: GLZEFPAA. DOC THRU: ' Blair Wondzell -~ ~/~ P.I. Supervisor ¢ ~.~._.~ · FROM: Ddug Amos Petroleum Inspector PItONE NO.: 279-1433 SUBJECT: Mech. Inegrity Test Union KGF 14-4 Kenai Gas Field Wednesday June 16, 1993: After inspectin, g the BOPE and Diverter systems on the Gilbert Rowe :~ Jack-up/Lou and I traveled to Union's KGF disposal well 14-4 to witness the annual Mech. Integrity Test. The well passed the test which was conducted in accordance with all applicable AOGCC regulations and Area Injection Orders Lou filled out an,;; AOGCC Mech. Integrity Test Form which is attached to his report, file number GLZGFPAA. INSUMMARY, witnessed the MIT on Union's KGF disposal well 14-4. Attachment None ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 27, 1993 Bruce St. Pierre Environmental Coordinator Unocal Corporation P. O. Box 190247 Anchorage, Alaska 99519-0247 Re: NORM disposal Dear Mr. St. Pierre: The Commission has reviewed your request to inject naturally occurring radioactive materials (NORM) into Ii~l~illl~l~ass II disposal well. The Comrpission concurs that pipe scale contaminated with NORM is "brought to the surface" in conjunction with oil and gas production and therefore is a Class II substance and eligible for injection into a -'Class II disposal well. ' Since the substance in question is Class II, Commission approval for injection in the Kenai Unit 14-4 well is given in Disposal Injection Order No. 2. The Commission supports deep well injection of NORM contaminated Class II wastes as the best disposal option when it is available. Should you have further questions regarding this matter please do not hesitate to contact US. Sincerely, Chairman r~ printed on recycled paper b y Environmental Affairs Alaska Region Unocal North Amer~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL May 18, 1993 Mr. David W. Johnston Chairman, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3i92 dOMM ~ COMM I COMM RES ENG ~- SR ENG SR ENG EN'(~-~SSTI ENG ASST 1 SR G E O~L-~ GEOL AS'S'f' ~_ GEOL ~f,l~ STAT TECH! FILE Dear Mr. Johnston: Disposal of Naturally Occurring Radioactive Material (NORM) Unocal hereby request permission to dispose of Naturally Occurring Radioactive Material (NORM) into our permitted Class II disposal well at the Ke~.~..i Gas Field 14-4 location. Uno_,cal is currently operating an injection p, rogram to dispose of drill muds and cuttings via slurry injection. The project is approximately half completed and this summer we plan to finish the program. The NORM waste has been generated from a variety of drilling operations in the Cook Inlet. All of the NORM waste is classified as exempt Exploration and Production waste with respect to RCRA, subtitle C. Unocal uses a radioactive survey instrument to detect NORM levels. Unocal's threshold limit for NORM classification is 50 uR/hr. To date we have seen a range from 50 to 1,000 uR/hr in the NORM waste we've generated. None of this waste has exceeded the NRC regulatory concern level. The start-up date for the KGF 14-4 injection program is slated for May 22, 1993. Upon your approval we would iike to incorporate the NORM material as soon as possible after this date. Thank you for you consideration on this matter. Respectfully, ~ 'r Bruce St. ~ Environmental Coordinator BWS/ CC: J. Beitia/File 0NDI 14-4) C. Partridge, BSP Reading File RECEIVED MAY 2 4 t99;~ Alaska 0il & Gas Cons. Commissio~ Anchorage MEMORANDUM TO: David John?.~~ Chairman,,>"- THRU: Blair Wondzell P.I. Supervisor FROM; ~ou Grimaldi Petroleum Inspector $ TA TE LA SKA ALASKA OIL AND GAS CONSER VA TION COMMISSION DA TE: , 1993 FILE NO: GLZGFPAA. DOC PHONE NO.: 279-1433 SUBJECT: Mechanical Integrity test Unoc~ll #14-4 Kenai gas field WEDNESDAY 6-16-93 I witnessed the yearly mechanical integrity test on UNOCAL's disposal well 14-4 in the Kenai gas field. This well is used to dispose of the ground up cutting's from the Kenai Gas field's reclaimed reserve pit's holding'.s.,Doug Amos (AOGCC Petroleum Inspector) was also present for the test. The well took approximately one barrel to bring its annulus pressure to 1614 PSI and lost 9 PSI over the 30 minute observation time. I passed the well for injection SUMMARY; I witnessed the yearly Mechanical Integrity test on UNOCAL'S well #14-4 in the Kenai Gas field. Attachment: GLZGFPAA. XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: UNOCAL FIELD I UNIT I PAD: KENAI GAS FIELD DATE: 6/16/93 4,147 340 300 310 260 14-4 W N WATER 7" 29~ N-80 3.5 1500 1532 X 4,147 580 1,614 1,605 1,605 COMMENTS: COMMENTS: COMMENTS: ~ COMMENTS: COMMENTS: *TUBING INJECTION FLUID: P = PRODUCED WATER INJ. S = SALT WATER INJ M -- MISCIBLE INJ. I = INJECTION N = NOT INJECTING Distdbution: orig - Well File c - Operator c- Database c - Tdp Rpt File c - Inspector ANNULAR FLUID: GRADIENT: WELL TEST: DIESEL . Initial GLYCOL 4 - Year SALT WATER Workover DRILLING MUD Other 1 YEAR OTHER 4.33 AOGCC REP SIGNATURE OPERATOR REP SIGNATURE GLZGFPAA.XLT LOUIS R. GRIMALDI FI-051 (Rev. 3/93) Unocal North Americi Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL January 22, 1993 TO: Larry Grant. FROM: 3001 Porcupine Drive Anchorage AK 99501 M. ASKA OIL & GAS CONSERVATION COMMISSION Ralph Holman P 0 Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Swanson River Unit 1 - Sub-Surface Directional Survey- SCU 33A-8 Kenai Gas Field- KU14-4 & 0" 3 1 2 - Temperature Log Gamma Ray 1 - Spectral Analysis PLEASE ACKNOWLEDGE RECEIPT OF THIS DOCUMENT TRANSMITTAL BY RECEIVED BY: ~'~_g,,~SIGNING AND. RETURNING//~~ONE COPY. THANK YOU. DATED: : Unocal North Americ Oil & Gas Division Unocal Corporation P,O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL~ Alaska Region DOCUMENT TRANSMITTAL January 18, 1993 TO: Larry Grant LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM' Quinn Aikens LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS KENAI GAS FIELD KU 14-4 1 blueline Temperature Log Gamma Ray THIS DOCUMENT TRANSMITTAL. THANK YOU ~¢~IV~I, ~: ~_! V E D DATED: JAN 2 0 1993 Naska Oil & G~s Cons. Commission Anchorage Unocal North American· 'Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Affairs Alaska Region Joe Dygas BLM, Division of Minerals (984) 222 W. 7th Ave., Box 13 Anchorage, AK 99513-7599 November 10, 1992 Blair Wondzell AOGCC 3001 Porcupine Rd. Anchorage, AK 99501 Don Seagren ADEC, Kenai District 35390 Kalifornsky Beach Rd. Soldotna, AK 99669 Kellie Litzen DNR, Division of Water P.O. Box 107005 Anchorage, AK 99510-7005 Ladies and Gentlemen: MONTHLY REPORT FOR OCTOBER, 1992 KENAI GAS FIELD OPEN RESERVE · PIT INJECTION PROGRAM The following is an end-of-month status report for the injection program currently suspended at Unocal's Kenai Gas Field 14-4 Pad. The project was suspended on October 7, 1992 and will resume operations in the Spring of 1993. As of October 7, 1992 the following volumes have been injected: Dry Mud Product Processed Water Mud Slurry Flush Water 10,902 yd3 97,092 BBL (Max. of 2,948 BBL/day) 141,195 BBL 8,779 BBL (Max. of 420 BBL/day) Amount of oversized material segregated (not injected): Oversize material 5,890 yd3 The list below represents the dates that specific reserve pits were excavated. 7/06/92- 9/04/92 9/06/92- 9/09/92 Project start-up & KGF 34-31 reserve pit excavated. KGF 33-30 reserve pit excavated. (continued) ~ E ~ E IV E D N 0V 1 2 1992 AJaska 0il & Gas Cons, t;0mmissi0 Anch0rag~ page 2 9/09/92 - 9/14/92 9/15/92- 9/24/92 9/25/92- 10/7/92 · . KGF 41-18 reserve pit excavated. Also began processing boxes of mud and drill cuttings located at KGF 14-6 Pad. Boxed material is from KGF 33-7 well. KGF 14-6 reserve pit excavated. 299 Boxes processed to date. KGF 43-32 reserve pit excavated. 678 Boxes processed to date. Project suspended for the winter. Plan to resume in May of 1993. If you have any questions related to this project, please call me at 263-7615. BWS/ CC: J. Beitia C. Partridge A. Graveley Bruce Cox (Marathon Oil) John Dowling (Chevron) file Bruce St. Pierre Environmental Coordinator RECEIVED N 0V 1 2 1992 Alaska Oil & Gas Cons. (;ommissi0n Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR .~. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 2'/9-1433 TELECOPY: (907) 276-7542 October 7, 1992 John T. Beitia, Regional Mgr Safety/Environmental Protection Alaska Region UNOCAL Corporation · P O Box 190247 Anchorage, AK 99519-0247 Re: KU 14-4 Disposal Project Dear Mr. Beitia: Thank you for the comprehensive summary of Unocal's KU 14~4 Disposal Project (correspondence 9-16-92). The Commission appreciates being kept up to date with your pit closeout operations. Data you provided in our meeting on September 8, 1992 in conjunction with the aforementioned report provide evidence to support continued operation of the project. Production logging analysis, step rate tests, fracture simulation and actual history data show that fracturing through the confining zone is not occurring and current operations are in accord with Class II, UIC requirements. Therefore, the Commission approveS continued operation of the KU 14-4 Disposal Project with pressure/rate monitoring and periodic logging. David W. Joh~ton Chairman John T. Beitia Regional Manager Safety/ Environmental Protection Alaska Region ,.. COMM Unocal North Ameri_.,7~n Oil & Gas Division ..... '" .~'" .... ;.~OMM Unocal Corporation f- "~ ~,,~x,,~,~ (.~% COMM " 909 West 9th Avenu~ ' RD. Box 190247 ~-~% RES ENG Anchorage, Alaska 99519-0247 Telephone (907) 263-7682/276-7600 Fax 263-7698 UNOCAL September 16, 1992 SR ENG SR ENG ENG ASST ~ ! ENG ASST · SR GEOL. GEOL ASST! GEOL ASSTI: STAT TECH' iSTAT TECHI David Johnston . Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 KO 14-4 DISPOSAL PROJECT Dear Mr. Johnston, As of September 15, 1992, KU 14-4 has taken 6117 cubic yards of dry mud material in 83,710 barrels: of slurry. 6091 barrels of flush water and 3912 barrels of fluid from other sources also have been injected--mostly, surface water from the pits. From a downhole standpoint, the project is proceeding very well with fairly steady rates and surface pressures. There is no indication of any mechanical problem other than fill partially covering the perforations. If things continue as they are, the well can accept the entire planned volume of cuttings with the possibility of a coiled tubing cleanout becoming necessary if the fill builds up Past the top perforation. While the well does not appear to be acting differently than expected, some evidence exists that fracturing may be occurring-- perhaps intermittently. This evidence is mostly theoretical and can be explained as simply normal injection behavior. The same evidence that suggests that fracturing may be occurring also indicates that such fracturing could not be occurring into or through the confining zone at 2900 feet below the surface. This being the case, the fresh water aquifers above 1500' are being protected. Loqqing PrQgram To monitor the progress of the injection program, temperature and radioactive tracer (RA) logs are run periodically. So far these logs have been run prior to start-up (July 8), at 1134 bbls cumulative injection (July 17), at 5200 bbls (August 8), and at 64,879 bbls (September 5). In each case, the logs have shown that all fluid is exiting through the perforations between 4194' 'and RECEIVED S EP 2 2 1992 · Ala'sffa 13il & Gas finns. ~nmmissl0n Mr. David Johnston KU 14-4 Disposal Project Page 2 4,250'--although the most recent log showed fill below 4230'. On August 8th, the RA log indicated that most if not all of the fluid was being injected between 4200' and 4210' just prior to logging-- possibly due to plugged perforations below 4210'. None of the logs run to date give any indication of fracture height growth above the top of the B-1 sand at 4190'. This is not conclusive since the fracture would have to be co-planar with the wellbore to be detected. Because the well is vertical, a classic vertical fracture woUld line up with the well. The logs are definitive in showing that no communication is occurring as a result of channelling. The plans is to continue running logs after at least every 100,000 barrels of injection. Other Surveillance Daily injection reports are being used to monitor the injection behavior of the well These reports have shown fairly constant injection pressures between 1150 and 1400 psig since the step rate test on August 7 (Figure 1). No unusual changes in pressure or injection rate have been noted. The well still has much greater capacity for injection of the slurry than the surface facilities can deliver. As a result, no daily runs longer than 22 hours have been achieved. This intermittent injection has not been detrimental to the injectivity as evidenced by the consistent injection pressure over time. The pressure history of the well is being plotted as a Hall plot (Figure 2). Changes in the slope of this plot can be interpreted as indications of damage (upward break), fracing (downward break), and reservoir fill-up (gradual concave up). This technique was developed for waterflood injection into oil reservoirs and may not provide much information in a watered-out gas zone such as the Sterling B1/B2 sands. So far, the plot is reasonably straight indicating no appreciable changes in reservoir conditions. Bottom-hole Pressures can not be measured directly due to the difficult environmental conditions during injection. Calculations of BHP are in error due to lack of rheological data on the slurry. Three samples of slurry have been sent to MI Drilling Fluids for laboratory analysis. The results will help to more accurately estimate bottom hole pressures. St~p Rate Test The step rate test performed on August 7 was designed to test the Mr. David Johnston KU 14-4 Disposal Project Page 3 feasibility of cuttings slurry injection into KU 14-4, and to determine if and at what rate fracturing would occur. The test went well and'proved that up to 5 bbl/min could be injected into the well at less than 1500 psi surface pressure. The character of the surface pressure vs. time is exactly what would be expected for a normal injectivity test (Figure 3) with increasing pressures corresponding to increases in injection rate. The previously mentioned difficulty in estimating bottom-hole pressure makes analysis hard, but it shows a fairly constant slope between 2 and 5 barrels per minute, leading to a conclusion that the fracture gradient in the well is greater than 0.77 psi/ft which is consistent with the 1987 step rate test using water. Small changes in assumed slurry rheology can change this conclusion so the step rate test will be reexamined when the mud lab tests are completed. Evidence of poSsible Fracturinq The evidence of fracturing is threefold. None of it is a result of direct field measurements. First, the step rate test can be construed as not showing increasing bottom-hole pressure with increasing rate--depending on the propertieS you assign to the mud. This is the conclusion reached by Bob Baree of Marathon Oil Co. in his analysis of the data. Once we receive the results of the lab work, we will recalculate the bottom-hole pressures. Even then, the pressures will only be estimates, and a high permeability formation--like the Sterling--may not show enough change in pressure to be conclusive. Second, a lab test with a slurry designed to be similar to the actual injection slurry injected into a Berea sandstone core resulted in fracturing. The problem with extrapolating this result to field conditions lies mainly in the fact that Berea sandstone and Sterling sandstone are very different rocks. The Sterling has higher porosities, permeabilities, and grain size than Berea. All these qualities would make fracing less likely in the Sterling than in Berea. Also, the Sterling is highly variable in these values from point to point, while Berea cores are extremely consistent which is why they are used in lab work. This means that even if average Sterling permeability and grain size measurements would suggest that fracturing is likely, high permeability streaks within the Mr. David Johnston KU 14-4 Disposal Project Page 4 reservoir could easily take the slurry without fracturing. Third, a model study was performed to investigate the possible range of outcomes if fracturing were to occur. The model is based on conventional fracturing which differs from our injection program in that frac jobs are usually short duration procedures utilizing a Newtonian carrier fluid with sand-size proppant following a pad containing no proppant. Injection is assumed to be continuous. At KU 14-4, the disposal fluid is non-Newtonian, the solids are mostly clay-size, injection takes place over a very long period, and injection is very discontinuous. The slurry essentially is the pad. These differences make it unlikely that the model would accurately predict fracture geometry. However, Bill Minner of Unocal Science and Technology Division in Brea feel that the results of a model study would be useful.in providing an "upper bound" of frac height, growth, and length. He feels that the model would provide "worst case, unrealistic results for height growth." The model study was performed by Marathon Oil personnel and reviewed by Bill Minner. Three cases were simulated: totally confined fracturing in the injection zone, unlimited height growth, and a "most likely" case that took into account calculated rock properties based on the wireline logs from the well. In reality, the last case should be called "more possible" since all three cases presuppose that fracturing will occur and that it will result'in a single vertical fracture. The first case, well confined fracturing, is shown in figures 4 and 5. It predicts that fracturing in this mode would quickly result in surface pressures exceeding 4000 psi which would have caused injection to be stopped soon after it began. This is obviously not what actually occurred. The opposite extreme, unlimited height growth, is presented in figures 6 and 7. The model predicts that in this mode, within one day--1440 minutes, surface injection pressures would drop to less than 500 psi, and stay there. This is also not possible considering the actual field data. The last case, which can be called moderate height growth, is shown in figures 8 and 9. In this case, generally constant pressures are expected--except for one 200 psi drop--as the fracture grows up and out. Final geometry is extrapolated to be approximately 800 feet of height (not all upwards) and about 1500 Mr. David Johnston KU 14-4 Disposal Project Page 5 foot half length. Figure 9 can be compared to the observed pressure history of the well as shown in figure 1. These pressures are similar to the model case. Fairly constant injection pressures would be expected in the case of normal, non- fractured injection, however, the actual pressure data should not be viewed as a validation of the model. The intermittent nature of the injection operation makes me doubt that daily reinitiation of a single, long fracture would be very likely. According to fracture theory, the pressure necessary to do so would get higher each time. This has not been the case. It is likely that a series of short fractures, radiating away from the well in a fan shape, Would be created. Approval From AOGCC Injection operations at KU 14-4 are going well and are expected to continue without significant downhole.problems. Pressure monitoring and periodic logging have shown that injection is being confined to the permitted injection zones and presents no threat to fresh water aquifers. Based on the information presented and the results to date, Unocal requests that the Alaska Oil and Gas Conservation Commission approve the continued injection of muds and cuttings into KU 14-4. Pressures and rates will continue to be closely monitored and periodic logging will be conducted. SKB:JTB:nk _~~ truly yours '~hn T. Beiti~~' Attachments KU 14-4 Disposal Project 100 1000 10000 Elapsed pumpimg time, minutes 100000 Surface injection pressure ~ Calc. BlIP 80 6O = 30 10 KU 14-4 disposal project Hall plot 10 20 30 40 50 60 70 80 90 Thousands cumualtive bbls injected 100 KU 14-4 INJECTION TEST ,..../92 STAGE BBLS 1 20 2 120 3 360 4 500 5 1200 6 1800 TOTAL 4000 CALC. BBLS/MIN TBG PRESSDENSITY FRICTION HYDROSTATIC BHP I 750 9.4 31 2045 2764 2 850 10.35 110 2251 2991 3 990 10.5 230 2284 3044 4 1175 10.7 395 2327 3107 5 1450 10.6 605 2306 3151 4.5 1300 10.6 480 2306 3126 ASSUMES FLUID HAS WATER VISCOSITY PSI/FT 0.67 0.73 0.74 0.76 0.77 0.76 13O0 1400 1300 1200 1100 lO00 ?00 0 I 2 3 4 5 6 INJECTION RATE, BBL PER MINUTE 3300 3200 3100 3OO0 2900 28OO 2700 2600 23O0 0 0 -< 3~ 0 Z C C Kenai KU 14-4 So l)~~ts~ .~.Jo~S. sa I Project Pumping Time, ilHe l'ght AvgHa I f ¥!Length- I~x. Wldth .~. ~,th .... o C Kena i KU 14-4 Sol i ds Disposal Calculated Treat ln~j Pressures i, Project Iii I II JBHP - , .... M-IP o - - . 1 ~30 Pump in9 Time, mir] -I -r 0 Z ID Keno i KU :!.4--4 ~ol ids Dis I Proj ec t ed Fr octure Gene // 10(30 Pump i r,9 Time, tght I- Ho lf Length ] Mox. Width I_Avg. ~/tdth 16)000 c Kenai KU 14-4 Sol ids Disposal Colculoted Treot In9 Pressures Project ! 84) 1 ol3o 10006) Pumpin9 l'ime, m in C 0_ Kenai KU 1 4-4 Sol i ds Disposal CalCulated Fracture Geometry Project 1 O0 ~ o00 --]Hal f Length /Hax. I/tdth _.. IAvg' Wldth Pump ing Time, mi ~l C ID; Kenai KU 14-4 Sol ids ¢~ ! cu I u ~ ed Disposal Tr eot Ing Pr essur es Project BHP ~ Pumpin9 Time, rnin 1 E1E~O0 Unocal North American, Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Gas Division UNOCAL ) Environmental Affairs Alaska Region Joe Dygas BLM, Division of Minerals (984) 222 W. 7th Ave., Box 13 Anchorage, AK 99513-7599 Don Seagren ADEC, Kenai District 35390 Kalifornsky Beach Rd. Soldotna, AK 99669 September 3, 1992 Blair Wondzell AOGCC 3001 Porcupine Rd. Anchorage, AK 99501 Kellie Litzen DNR, Division of Water P.O. Box 107005 Anchorage, AK 99510-7005 MONTHLY REPORT FOR AUGUST, 1992 KENAI GAS FIELD OPEN RESERVE PIT INJECTION PROGRAM Ladies and Gentlemen: The following is an end-of-month status report for the injection program currently underway at Unocal's Kenai Gas Field 14-4 Pad. As of August 30, 1992 the following volumes have been injected: Dry Mud Product 4,412 yd3 Processed water 28,080 BBL (Max. of 2203 BBL/day) Mud Slurry 40,232 BBL Flush Water 3,666 BBL (Max. of 240 BBL/day) Amount of oversized material segregated (not injected): Oversize material 11'42 yd3 The mud injected has all come from the reserve pit located at the Kenai Gas Field 34-31 Pad. Unocal expects to have this pit excavated out by September 6, 1992. RECEIVED s E P - 41( 9 . Alaska 0il & Gas Cons. (;0mm'tss'to~ Anchorage Page 2 If you have any questions related to this project, please call me at 263-7615. Respectfully, Bruce St. Pierre Environmental Coordinator BWS/ cc: J. Beitia C. Partridge A. Graveley file ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR .. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 17, 1992 John T Beitia Regional Manager Safety/ Environmental Protection Alaska Region Unocal Corporation P O Box 190247 Anchorage, AK 99519-0247 Dear Mr. Beitia: Re: Cutting Injection Program - Kenai Gas Field Disposal Injection Well KU 14-4 We have received your May 7, 1992 letter (attached) requesting approval to inject approximately 31,000 cubic yards of drilling mud with cuttings and exempt wastes from.wells previously drilled in the Kenai Gas Field, Kenai Unit and Cannery Loop Unit into the KU 14-4 disposal well. We have also received the letters of June 5, 1992 'and June 15, 1992 concerning inventory and explanation of the materials to be injected following telephone discussions of the project with Mr. Dan Graham. It is the Commission's understanding that all of the items listed on the inventories and proposed for injection have been "brought to the surface in connection . . . with conventional oil or natural gas produc- tion . . ." and therefore, qualify as Class II fluids which are hereby approved for disposal. Please provide an addendum to the monthly injection report (10-406) indicating the source and volumes of all materials injected from this project. When Unocal is ready to commence the step-rate test in the KU 14-4 well, please notify Blair Wondzell of'this office (279-1433) so that a petroleum inspector can have the opportunity to witness the test and any of the subsequent disposal operations. Also, please submit a copy of the step-rate test data and'your analyses for the KU 14-4 well file. Sincerely, Lonnie C. /Sm£~4~ Commissioner Attachment Unocal North Americar,~"-... Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL ) Environmental Affairs Alaska Region June 15, 1992 Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99503 ADDITIONAL INFORMATION CUTTING INJECTION PROGRAM KENAI GAS FIELD INJECTION WELL KU 14-4 Mr. Smith: Based upon our recent telephone conversation, I am providing you with additional information on the materials we propose to inject at KU 14-4. I have hand-delivered a detailed inventory of the waste materials to be injected during the program. I failed to provide the following information, namely that Unocal certifies that to the best of our knowledge, all of the materials to be injected are from exempt sources, primarily materials directly recovered from wells. Additionally, Unocal has a waste inventory, manifesting and tracking system in place that allows us to provide the exact source of the materials to be injected. Should any questions arise over particular sources or manifests, I am at your disposal to provide answers. RECEIVED d U N 1 5 1992 Alaska 0il & (~as Cons. C0mmissi0~ Anchorage Respectfully, !a nie~l~ ~,~G raha m/~//~-, Senior Environmental Coordinator Unocal North Amerirmr~''-'', Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL Environmental Affairs Alaska Region June 5, 1992 Mr. Lonnie Smith Alaska Oil and Gas Conservation Commission HAND DELIVERED COMPLETE INVENTORY CUTTING INJECTION PROGRAM KENAI GAS FIELD INJECTION WELL KU 14-4 Mr. Smith: I have attached several sheets that show the complete inventory of wastes that will be injected during the project. The vast volume of the materials comes from the reserve pits at the Kenai Gas Field and Cannerl Loop Units. I have noted on the container inventory those items that will either be inspected and separated (such as oily plastic from sand) and handled by disposal other than injection (washing and landfill, incineration, etc.). If you need further information or have any additional questions, please call me at 263-7679. Respectfully, Daniel J. ~raham Senior Environmental Coordinator Attachments No Scale SITE VICINITY MAP )ldotnl KENAI PROJECT LOCATIOH iewlrd GULF . CANNE~~Y LOOP ~.- 2:.":. ;, ;:. -. KENAI 'GAS FIE · / ;' !/~// ;. , . / ! ! . ..',; ! OF ALASKA PROJECT LOCATION MAP O!" "' ' · ~.' ~/~ · ~C?LE IN MILES / DRAWN Harding Lawson Associates Engineers, Geologists & Geophysicists JOB NUMBER .00382,031 08 · / Site Location Map UNOCAL Kenai Reserve Pits Kenai Gas Field/Cannery Loop Unit Kenai, Alaska APPROVED DATE REVISED 7c. 2186 DATE PLATE INTRODUCTZON This reports presents alternatives and estimated construction and monitoring costs for storing drilling mud in reserve pits at the Kenat Gas Field (KGF) and Cannery Loop Unit (CLU) in Kenai, Alaskm. The CLU gas field is south of the city of Kenai; the KGF is immediately south of the CLU and east of Kalifonsky Beach Road. Reserve pits are used for storing drilling mud as waste at seven drill sites within these gas fields. Table 1 summarizes conditions at each of the seven reserve pits. Table 1. Sun,nary of Reserve Pit Conditions* Primary Secondary Drinking Drinking Year Located Muds Water Water Surface Mud Available Con- Land in Below High Standards Standards A~'qp Volk~m Voh~pe Site structed Status Wetlands Groundwater Exceeded Exceeded (ft~) (yeP) (yd°) KGF 33-30 1960 X N N N Y 14,000 1,700 2,600 43-32 1965 X Y N N Y 77,000 8,300 8,500 14-6 1959 X Y N Y Y 42,000 4,400 1,600 41-18 1972 X Y Y Y Y 18,000 2,700 1,700 34-31 1959 X Y Y Y Y 37,000 5,000 2,800 CL__U CLU-1 1979 U N Y N Y 59,000 3,500 16,500 CLU-3 1981 U N Y N Y 28.000 1.400 5,400 Totals X - surface rights not owned by Unocal U = Unocal owns surface rights N=no Y - yes 275,000 27,000 * See attached bibliography for sources of reserve pit conditions. OSOOR I 'e~ee KGF - PAD 43-32 RECEIV£D JUN - 5 1992 Alaska Oil & Gas Cons. commiss'~on ~Anchorage LEGEND 43 - 3B PAD SnIL BAGS 1/2 S[]IL BAGS .STEEL DRUH PLASTIC DRUH 4X4X4 b/DF]D BgX SANPLED BERN EDGE ~ eeee ~. eeee ~ eee ~ eeee 0 000 ' '"'~ FACILITY: KENAI GAS FIELD. 43-32 .PAD SURVEYOR: BRUCE ST. PIERRE DATE 06105/91 UNOCAL CORPORATION WASTE SURVEY CONTAINER MANIFES1 WASTE HIGHEST DA' ~,~, ,- ~vr~ ~/.',lPi~-I1 ~V~lJI I IUN MANII-I-~ I ATTACHEI LOCATION uRem/hr INVENTORY _! GEN PT DESCRIPTION OF WASTE STORED 'IYPE ~i:;? KGF::::i~~c-~n-~oS~'d-Of c~i;i-taminate'd:~a~d,' "ra~tel: a~~ ...... __~_____p____ '~N°' J~[:! ..... ':':.'~- AT SITE ~~RADIATION No. ~~i~--~~~COMMENTS ' ::KGF:.'-: :.' .' :;::'..'.:.;::: ...... :.:_.: - . : ..... :.... _ .;~: ~ : ~ .'. : WOod BOxes ' · (~ ~ ~'~!W~i: bO~'::(4x~.~):':: ........ ...... '.:. :: .:':' .... Used oily rags .... ~J~iJ~¥'Di~m'Drum ' G'G .' 8-1989..:: ,": . "~N ..... :.. :No:.i~ii:!!ii:!i!iiiii::!i::iii:.:::i'::::i????:i: :: : :..: :i:': '::': :: .. :.:... 8[~[ Dram : G : KL96 ~ '. · ,~il~i~j~i:i.::i!::.::i :.:i..'..:. .' ': ::i.':i :..:: '.' ----..P6iY ..... Dj, Urn ' : G .... ~ -' .... i~"l~i?..ii' i..'i. :i.: ·. ': .... .... .:.::: ~.:::: .. ...'.. .. · ~ ~~-"---'-'"~-'- , ~.::.:~':.i::. :\~: '. .... : ' ..... _ ~ ., .~~~~~lDi~um. 'G .KL120. N ~ :: ..::. : ,..~.:.':./:: .:.sam.:le~.:::!:!i..i:i?.:......i... : .:.... :. : ..: : _ . . · . ~.P:~::::i~i '::"':. .... : ...... . . ~DrUm .: G ::: KL48:! N '. :.':::" '. ' . .: ... " , ......... ' .... .. ' '.~:~p~i.~::.'... ' ' .: ... ........... 8tM'Drum · G K8115 N '.': .i:i:i:i:ii!:ii:i::::ii:i:i:i::'::: i :"'".' :': · · ·" = · ': - ..... . 8reel:;.,::,:: .Drum. G. ' KL76':. N. : ':: · : ..... "8ai~P~i :':: !"i "': :: '._~ ........ '.' ' ___ ....... ~ Drum G KL35 N i ......... i:i.il.i:::' ............. ' ::' :' ;C~o.~,~,~ Lu~e; h draulic ~ui~ i~bel: !.::: .!~'~:::::.=:':::! ':::· ".. Oi!i:':!~v~d:!: '::i i:?:'::' =: ?: ~ ~.~ :;'=: ::=: '":: '~:::: ~: : i :'::.~.. 'i . ." .. ~ ~~~~8~ Di, tiim G : KLi02' N ...... i:i:i:!:!:!:i:i:i:i:i:!:i ...... '.:!:..'!:::. :-. :::.. : · :. ~': ~ -.~'. ' ~ ·uSed oil a~d filters ~=: ' .:.:~::'~i:::"~'-~:~:-':~:~¥':e.':- ~' ~ ~ ~ ~:::ii~i:i~?:~i:~:??:?::!:'::::!?':i!' :: ~::' '. .... ::, ~, ': ~i-~ii-:-ii~:ii':~::' · :::. :: ?::.::': ':::'::::i:: '::.-! ": i:i i:: :: :'~. '-* ','.':':-: :-:::::-: .... ::-::'::- :: ~ ~':':':" .'.':':':':':, GEN PT DESCRIPTION OF WASTE DATE STORED CONTAINER 'I'YPE CONTAINER CONDITION MANIFEST No. MANIFES'i' WASTE ATTACHE[ LOCATION AT SITE HIGHEST uRem/hr RADIATION INVENTORY No. COMMENTS atet '~BERM IS 1,5' TEl ,,~ RHINO-HIDE IN ~' HIGH LINES__ W/6ML VERY Pr'1FIR CFINDITIFIN / / / / / / / / 677 SRXES (4x4x4) CUTTINGS STACKED 2 HIGH 4 STEEL DRUMS K~3 ~Hf~TY 4x4x4 ~009 eOX ~,NUlPLL~D KGF PAD 14-6 FACILITY: KENAI GAS FIELD, 14-6 PAD SURVEYOR: BRUCE ST. PIERRE DATE 06/05/91 UNOCAL CO RPO RATIO N WASTE SURVEY GEN PT DESCRIPTION OF WASTE 677 Wood boxes of water based!curtain 33;7"Well CONTAINER MANIFES'[ WASTE HIGHEST DATE CONTAINER CONDITION MANIFEST ATTACHE[ LOCATION uP, em/hr INVENTORY STORED TYPE No.__=. ~ RADIATION No. COMMENTS KL86 : ': BERM FROM CLU 1II 640 BOXES ~/ET MUD (OIL BASE) 119 BOXES VET & DRY 127 ! CLU 3 ANK FROM CLU~4 440 BOXES (OIL BASE) 150 KGF 79 SAND CUTTINGS 336 DRUMS SLUDGE KGF PAD 41-7 FROM CLU ~ Trip HOLE 408 (4x4x4) BOXES (~/ATER BASE) OILY SaIL 175 TOTAL COUNT, 3141 BOXES 379 DRUMS m i 'm m""'t' i EMPTY I I I,I] i~] BOXES -~43 DRUMS 192 SPILL DIRT -~SPILL DIRT 156 CONTAM. DIRTI ,-tllF ACCESS RBAD NORTH ! FACILITY: KENN GAS FIELD, 41-Z PAD SURVEYOR: BRUCE ST. PIERRE DATE 06/05/91 :~ GEN PT DESCFIlPTION OF WASTE i stee! 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"':-:~ i !~d::im:d M :: i':::':?i.::':: " :::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: x.: :.:!i!i!ilili!!ifili!ii!i!!iii!ii:i:!:!:i:!:!:iji:ili!i ,.. ...... : i:i!i:!!': :: :::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::: ....... ::::::::::::::::::::::::::::::::::: ::::::::::.:::::::: ...... .. :! i::!! ':': :!: :i!::.' :!::i::::.:ii:!:!; "!:::::: ============================= , · . WS:~:::WeM~ide'~enemtedw~:~l~tum~n~ LeWi~i~C United States Department of the Interior BUREAU OF LAND MANAGEMENT ALASKA STATE OFFICE 222 W. 7th Avenue, #13 ANCHORAGE, ALAS KA 99513-7599 Mr. Daniel J. Graham UNOCAL P.O. Box 190247 Anchorage, Alaska 99519-0247 Dear Mr. Graham- COMM COMM COMM RES ENG SR ENG SR ENG ENG ASST 1992 SR GEOL GEOL ASSTI GEOL ASSTI 'TAT TECHI ::TAT TECHI 3160(984) We have received and reviewed your May 7, 1992, letter notifying our office of the injection of muds and exempt wastes in Kenai Unit Well No. 14-4. The Bureau of Land Management (BLM) approves the method chosen for disposal. All operations are to be conducted in accordance with BLM, Alaska Oil and Gas Conservation, and Alaska Department of Environmental Conservation regulations and requirements. Please provide our office with a monthly summary of the operations associated with this disposal project. This report shall include the source of muds and/or exempt wastes removed during the month, the volume injected each month, and a representative analyses of the material injected during the month. A summary of all disposal activities, including the injection of muds and exempt wastes, is required in the annual Kenai Unit Plan of Development and Summary of Operations. This plan and summary is to be submitted to this office by December 15th of each year. We appreciate UNOCAL's efforts in reclaiming the reserve pits and removing the boxed exempt wastes within the Cannery Loop and Kenai Units. We look forward to working with you in the implementation of this project. Sinc. Tel~, -- Chief, Branch of Lease Operations Division of Mineral Resources cc- Mr. David W Johnston, Chairman Alaska Oil and Gas Conservation Commission JUN - 51992 .Oil & Gas Cons. ~.m. ~i~!~ John T. Beitia Regional Manager Safety/ Environmental Protection Alaska Region UNOCAL ) Unocal North American ¢"'~'Gas Division Unocal Corporation 909 West 9th Avenue E O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 263-7682/276-7600 Fax 263-7698 May 7, 1992 COMM RES ENG SE ENG SR ENG ~ENG ASST 'ENG ASST SR GEOL GEOL ASST GEOL ASST STAT TECH FILE REEEIV£D MAY 1 1 1992 Alaska 0il & Gas Cons. 00mmissio~ Anchorage Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99503 REQUEST FOR APPROVAL CUTTING INJECTION PROGRAM KENAI GAS FIELD INJECTION WELL KU 14-4 Mr. Johnston: Unocal requests your concurrence on our proposed program to inject the exempt wastes currently stored at various locations at the Kenai Gas Field and in the Cannery Loop Unit. The materials to be injected consist of the contents of the open reserve pits located at KGF and CLU, specifically at KGF pads 33-30, 43-32, 34-31, 14-6 and 41-18 and at CLU #1 and CLU #4. Also included are the contents of the approximately 4,000 boxes of exempt wastes stored on the pads at KGF. The total volume of material to be injected is approximately 31,000 cubic yards. Unocal will begin the program about July 1, 1992. The program may extend into 1993. At the start of the program, Unocal will perform a Step rate injection test using representative materials. Through this test, we will establish the formation fracture pressure, and will then proceed with the injection program staying below formation fracture pressure. During the execution of the program, should we require fracture stimulation of the well in order to continue injection, we will apply for permission and provide additional information as required at that time. Mr. David Johnston May 6, 1992 Page 2 Please indicate your concurrence by signing where indicated below and returning a copy to me. If you have any questions or require additional information, please call me at 263- 7682. Thank you for your positive consideration. David Johnston Commissioner Respectfully, '-'-J'o~ Beitia P,.~g~nal Manager ~afety and Environmental Protection Environmental Affairs Alaska Region Unocal North Americar~-''-. Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL ) April 24, "~(~iM-------- ~' ~~ COMa 1.,"'"",¢~('"'" ~e~ ~ ,-ENG ~S~ ~ ~,;~ ~ ~EOL ASS~ 1992 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99503 REQUEST FOR APPROVAL KU 14-4 FRACTURE TREATMENT PLAN ~ENA! GAS F'rELD TN~ECT'TO. WELL [U 14-4 6/~ -- ~ / Mr. Johnston: This letter is to request approval of the attached fracture treatment program for the previously submitted muds injection program (reference letter of December 4, 1991). This fracture treatment of the well would be~~ .qn~ly ~.~e..~_q~.9~ ~o maintain injection of the mud volumes The program ensures that %-~~ i~'~l~~ the non-exempt aquifer (above 1300 ft) and does not allow fracturing of the confining zones above the permitted injection zone (2900 ft). cc: Kurt Bair John Beitia Respectfully, Daniel J. Graham Senior Environmental Coordinator RECEIVED APR 2 4 1992 Alaska 0il & Gas Cons. uumm~ss~o, Anchorage Mr. David Johnston April 24, 1992 Page 2 KU ~4-L4 FI~CTURE TREATHENT PLAN Unocal proposes the following procedure to monitor the possible fracturing of the formation during disposal operations in well KU- 14-4. 1. Fill the casing-tubing annulus with fresh water and maintain 700 psig on annulus· 2. Establish injection of disposal slurry at 3 barrels per minute, ~ ~i~n~t~n p~~e to 3009~psi at the surface· Monitor~ rate, t%~i~ng and casin~--~re~ures, and slurry density continuously· · After observing stable injection pressure at 3 bpm, increase rate to 4 bpm. After 30 minutes, increase to 5 bpm for 30 minutes, then increase to 6 bpm. Rate vs pressure data will be plotted to determine parting pressure. · Increase pump rate to maximum capacity, keeping surface pressure below 3000 psi. Monitor pressures, rate, etc. Continuously. Terminate job if tubing pressure exceeds 3000 psi or casing pressure increases suddenly. · Stop pumping at cumulative injection volumes of 10,000 bbl, 100,000 bbl, 250,000 bbl, and 500,000 bbl and perform temperature/ra tracer logs to determine extent of fracture height growth, if any. Run logs every 500,000 bbl for remainder of job. · Terminate project if logs or other data indicate that fracturing is occurring above 2900' depth. This is the top of the alternate injection zone and is well below the deepest protected aquifer. RECEIVED APR 2 4 1992 Alaska Oil & Gas Cons. Commissior~ Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTEFI J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3193 PHONE: (907) TELECOPY: (907) 278-7542 March 11, 1992 John T Beitia, Regional Mgr. Safety/Environmental Protection Alaska Region Unocal Corporation P O Box 190247 Anchorage, AK 99§19-0247 Dear Mr Beitia: ~o-?/ This is in response to your December 4, 1991 request for modification to Disposal Injection Order No.2 (DIO2), Kenai Gas Field, injectior~ well KU 14-4 and additior~al information dated February 21, 1992. The Commission finds your proposal to dispose of accumulated drilling mud and cuttings by injection into the authorized disposal zone of the KU14-4 well to be consistent with the existing terms and conditions of DIO2. The Underground Injection Control program is specifically designed and implemented to protect underground sources of drinking wat. er. Although the aquifers in this area are exempted below 1300 feet unexempted aquifers exist above this depth. The Commission believes unlimited fracturing of the injection zones specified in DI02 may jeopardize unexempted aquifers. Therefore your request for modification of DIO2 to allow extended hydraulic fracturing of the injection zones cannot be approved. This does not preclude any approved fracture treatment of the well. If you have any questions or concerns regarding this decision, please contact this office. Chairman )hn~n Environmental Affairs Alaska Region Unocal North America,~-% Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL ) February 21, 1992 RES Elq61 "'.~ ~~SST~ Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99503 ADDITIONAL INFORMATION REQUEST FOR MODIFICATION DISPOSAL INJECTION ORDER NO. 2 KENAI GAS FIELD INJECTION WELL KU 14-4 Dear Bob: The additional information that you requested in order to properly evaluate our request of December 4 for a modification to the existing injection order at Kenai Gas Field well KU 14-4 is contained below. Permanent Injection Order Modification Unocal is requesting a permanent modification to the injection order. The first injection of solids will consist of accumulated boxes of drilling muds and cuttings and other exempt wastes and the contents of the open reserve pits at the Kenai Gas Field. All materials that will be injected into KU 14-4 are classified as exempt exploration and production wastes. Unocal is also requesting a permanent modification to the injection order to allow us to fracture the formation within the primary and alternative injection zones. In order to inject reasonable volumes of solids at reasonable rates, it is likely that some intermittent or continuous fracturing of the formation may occur. RECEIVED FEB 2 1 1992 Alaska 0il & Gas Cons. Commission Anchorage Mr. Bob Crandall February 21, 1992 Page 2 Specific Injection Zones Unocal would like to use the existing perforations in KU 14-4 as the primary solids injection zone. These perforations are from 4194' to 4250', within the Sterling Formation B-2 sand. We would also like to use the Sterling #1 through #5 sands as alternative injection zones. These sands consist of various thicknesses of sands between 3150' and 3450'. The alternative zones would be used in case injection within the primary zone fails. Volume to be Injected The initial volume of solids to be injected will consist of approximately 150,000 barrels of solids. Although the actual solids/fluid mixture will be determined during the injection process, using a conservative solids-loading factor of 2 ppg means that the initial total volume will be 1.5 million barrels or less. Any significant increase in the solids loading abOve 2 ppg will significantly reduce the injected volume. Even a moderate increase to 3 ppg will reduce the volume to less than I million total barrels. The only reason that a large volume will be initially injected is that significant volumes of materials have accumulated since production began at the Kenai Gas Field. The decline in reservoir pressure from an original 1850 psi to 1220 psi at shut-in, indicates a voidage of tens of millions of barrels. It is unlikely that the total injection volume over the foreseeable operation of the injection well would exceed ten million barrels. Fracture Geometry and Volumes, Maximum Surface Pressures Because of the subject zone's excellent porosity (30-35%) and related high fluid leakoff characteristic (as evidenced by a high rate injection test in 1987), it is probable that most of the injected slurry will leakoff much as in a waterflood, and no related fracturing of the formation will occur. However, plugging of pore throats with cuttings will likely lead to the occurrence of some degree of high leakoff fracturing. Fractures would be expected to be vertically oriented at the well bore, and extend as two wings outward and split by the well bore. These fracture wings are expected to be contained by the upper and lower confining strata. If no fracturing were to occur, the entire 1.5MMB slurry could be contained in a 400' radius cylinder out from the well bore. With some fracturing, fluid may be placed some multiples of this radius away from the wellbore dependent on the plugging characteristics of the slurry and leakoff capacity of the formation. However, fractures would be expected to remain vertically confined and running on-strike with the well's penetration. Thus, no other sands or productive acreage of the interval is expected to be affected by the proposed injection. Mr. Bob Crandall February 21, 1992 Page 3 It is intended to inject 50 mesh and smaller particles, with the majority of the cuttings placed being in.the 80 mesh and smaller size range. Thus, fracturing is envisioned as a natural resolution of pore plugging as injection progresses. Maximum anticipated surface tubing pressure to foreseeable working scenarios is 4000 psi. accomplish the injection under Very truly yours, Daniel J. Graham Senior Environmental Coordinator KGF WELL 14-4 INJECTION ENGINEERING CONSIDERATIONS The injection of Unocal's stockpiled 150,000 bbls of drilled solids into KU 14-4 is feasible. The well had produced 38.3 bcf prior to conversion as an injector. Reservoir pressure declined from an original 1850 psi to 1220 psi at shut-in, indicating potential voidage of tens of millions of barrels. Based on Cook Inlet experience, a 2 ppg (cuttings added to gelled water) solids loading should be injectable for a long duration without significant pressure increases. A step rate test run on the subject well suggests that a 2000 psi wellhead pressure would handle such a slurry at 3 bpm. If the disposal material is assumed to be loosely packed and to have a specific gravity of 2 relative to water, a 3 bpm program of 2 ppg slurry would exhaust the cuttings in less than ten months of on-time with total injection of 1.25MM bbls. A cuttings washer (essentially a spray bar over a shale shaker) will typically wash out 90- 95% of cuttings. ARCO has used 50 mesh screen for this purpose. Thus, grinding of cuttings can be postponed until a later date after injection of 50 mesh and smaller particles has taken place, or performed as generated only on the volumes that exceed 50 mesh in size. ARCO employs a 10% solids loading, in line with the 2 ppg estimate Unocal made through analogy with well stimulation work. BP approaches a 20% solids loading. The key is to have a homogenous slurry, sometimes facilitated by addition of a gelling agent of about one sack of XCD (dispersed XC polymer, a non-hazardous material) per 400 bbls of water for use in the cuttings slurry. 2-7/8" tubing has apparently been successful in providing adequate turbulence at 3 bpm. RECEIVED FEB 2 1 1992 Alaska 0il & Gas Cons. c0mm%sS'~o~ Anchorage John T. Beitia Regional Manager Safety/ Environmental Protection Alaska Region Unocal North American ' ' Gas Division Unocal Corporation 909 West 9th Avenue P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 263-7682/276-7600 Fax 263-7698 UNOCAL ) December 4, 1991 COMM RES ENG ~ SR ENG SR ENG ENG ASST ! ENG ASST J G E_O ':~TAT TECH1 · Messrs. Johnston, Smith and Douglass Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99503 REQUEST FOR MODIFICATION DISPOSAL INJECTION ORDER NO. 2 KENAI GAS FIELD INJECTION WELL KU 14-4 ,~.~_ .~/ Gentlemen: This letter is to request a modification of our existing Disposal Injection Order No. 2 for injection at Kenai Gas Field Well KU 14-4. Under Disposal Injection Order No. 2, issued February 18, 1987 (attached), Union Oil Company of California (Unocal) is authorized to inject non-hazardous waste fluids generated by normal drilling and production operations. Unocal requests permission to inject both solid and fluid wastes, generated directly from normal drilling and production operations, in KU 14-4. The vast majority of the wastes that have accumulated for the initial injection efforts are some 150,000 bbls of drilling muds and cuttings from the Kenai Gas Field and Cannery Loop units. Addition of this capability will allow Unocal to accomplish permanent disposal of accumulated wastes and to close the reserve pits at the KGF and Canne~ Loop. The described injection activity takes advantage of state-of-the-art techniques deV~eloped by ARCO and BP. Operation of a facility permitted to inject solids will simplify~,~aste handling for all of Unocal's .operations on the Kenai Peninsula using proven,~ safe and permanent disposal techniques. Unocal also requests a modification to paragraph 4 of the FINDINGS section in Disposal Injection Order No. 2. Although the step-rate test data from well KU 14-4 (attached) suggests that the formation will accept materials at pressures less than the formation REEEIVED DEC - ,5 1991 Alasl~a Oil & Gas Cons. Commiss'tet~ Anchorage Mr. David Johnston December 4, 1991 Page 2 fracture pressure in the injection zones, the consistency of the fluids and the relatively Iow formation strengths involved may eventually require that the injection zone be hydraulically fractured. There would be no risk of contamination of fresh water aquifers, as shown by the geological information submitted with the original permit application. Attached is a description of the confining strata, and Plate 1, highlighting the numerous confining strata above 2900 feet in well KU 14-4 that will prevent upward movement of the injected materials into non-exempt freshwater aquifers. Attached are several documents that outline our plan of injection operations for injection of solids and liquids. KU 14-4 passed a Mechanical Integrity Test (MIT) in June of 1989, and is scheduled for another MIT in the first quarter of 1992, prior to the beginning of the proposed solids injection. Unocal will provide the results of the MIT to AOGCC prior to beginning injection of solids in KU 14-4. If you have any technical questions on this request, please contact Dan Graham of my staff at 263-7679. Very truly yours, Re/Oi~nal Manager S~ty and Environmental Protection Attachments RECEIVED DEC - 5 1991 Alaska Oil & Gas Cons. commission Anchorage KGF WELL 14-4 INJECTION ENGINEERING CONSIDERATIONS The injection of Unocal's stockpiled 150,000 bbls of drilled solids into KU 14-4 is feasible. The well had produced 38.3 bcf prior to conversion as an injector. Reservoir pressure declined from an original 1850 psi to 1220 psi at shut-in, indicating potential voidage of tens of millions of barrels. Based on Cook Inlet experience, a 2 ppg (cuffings added to gelled water) solids loading should be injectable for a long duration without~p~e__ssure increases. A step rate test run on the subject well suggests that a 2000 psi _w~e!!_h_e~ad pressure Would handle such a slurry at 3 bpm. If the disposal material-is'~as~s'u-i:ned to be loosely packed and to have a spebEi-c~g~a~ity of 2 relative to water, a 3 bpm program of 2 ppg slurry would exhaust the cuttings in less than ten months of on-time with total injection 1.25MM bbls. A cuttings washer (essentially a spray bar over a shale shaker) will typically wash out 90- 95% of cuttings. ARCO has used 50 mesh screen for this purpose. Thus, grinding of cuttings can be postponed until a later date after injection of 50 mesh and smaller particles has taken place, or Performed as generated only on the volumes that exceed 50 mesh in size. ARCO employs a 10% solids loading, in line with the 2 ppg estimate Unocal made through analogy with well stimulation work. The key is to have a homogenous slurry, facilitated by addition of a gelling agent of about one sack of XCD (dispersed XC polymer, a non-hazardous material) per 400 bbls of water for use in the cuttings slurry. 2-7/8" tubing has apparently been successful in providing adequate turbulence at 3 bpm. RECEIVED DEC - 5 1991 Alaska 0JJ & Gas Cons. Commission Anchorage PREFERRED SURFACE MATERIALS HANDLING SCENARIO Excavation A 4 inch sand pad with a liner will be set up at the edge of the reserve pit where muds will be removed. The liner will be large enough to set a dump truck with a bed-liner on it, with enough overlap so when back hoe loads the truck any spillage would be contained on the liner. The operation would move around the reserve pit and/or a bulldozer would be placed inside of the reserve pit to push the material to the back hoe until all material is removed. The operation would then move to the next location. Confirmation methods to demonstrate the completion of excavation will be determined later. Injection The truck would drive to the 14-4 site where it would dump its contents into an underground hopper covered by a steel grizzly. All items 1" in diameter and larger would be removed by the grizzly and dumped on a lined area to one side of the hopper. A high pressure water cannon will be mounted on one corner of the hopper to work the items collected on the grizzly. A vibrator may also be required. A screw auger mounted in the hopper will move the material out of the hopper into the shale shakers equipped with a 50 mesh screen and a cutting washer. It is estimated that 90-95% of all cuttings will paSs through the 50 mesh screen. The shale shaker will be moUnted on top of a two-compartment slurry tank equipped with mixing motors. The shale shaker discharge will be set up to be able to discharge its contents into either tank compartment. One sack of dispersed XC polymer per 400 bbls of water will be added to stabilized the slurry. A high-pressure triplex pump will take suction off of one of the slurry tanks and pump the slurry down the well. Material that is discharged from the shale shaker will be washed while being shaken. It can then be ground up and returned to the hopper for recycling. GEOLOGIC FORMATION SUMMARY KENAI UNIT WELL 14-4, KENAI GAS FIELD, ALASKA A subsurface evaluation was conducted to determine the stratigraphic relationship of the freshwater aquifers and the dispOsal well sands in the Kenai Gas Field. Results and Conclusions: Plate 1 is an east-west geologic cross-section showing the lateral continuity of the impermeable shale intervals. These shale intervals act as upper and lower confining impermeable units in the sand-rich Sterling Formation. The shales vary in thickness from three to 40 feet. The data available is conclusive that the shales are widespread and prevent vertical fluid communication between sandstones. Plate I also shows the stratigraphic relationship of the freshwater aquifers and impermeable claystone intervals in the Pleistocene strata overlying the Sterling Formation. The freshwater aquifers are generally fluvial channel sands bounded by lacustrine claystones. A major unconformity lies at the base of the Pleistocene strata (Top Pliocene Sterling Formation). This unconformity also acts as a barrier between the freshwater zone and the more highly saline Sterling Formation sands. The sediments below the base of the glacial deposits are in the upper and middle part of the Sterling Formation. These sediments are sands, siltstones, shales and occasional thin-bedded coals. The sands are highly unconsolidated and generally uncemented. Shaded intervals on the Type Log indicate impermeable shale zones. Waste water is currently being injected in these Sterling Formation sands at the base of the wellbore from 3030'-3160', 3178'-3193', and 3235'-3250'. Geologic Summary: The Sterling Formation of Pliocene Age is currently the disposal interval for the injected fluids in the Kenai Gas Field. This formation is over 3500 feet thick in the area with the lower _ 1100 feet containing commercial gas producing reservoirs. The Sterling Formation is made up of a thick sequence of massive sandstones and conglomeratic sandstones with impermeable interbeds of mudstone, siltstones and thin coals. This sequence was deposited by moderately large, meandering streams which were part of the main drainage system of the Cook Inlet Basin. These moderately large stream courses deposited point bar sands and flood plain silts and muds. The point bar sands are typically fining upward sequences of significant thickness and lateral continuity as are the interbeds of mudstone and siltstones. A Iow angle unconformity occurs at the base of the Pleistocene strata (Quaternary glacial deposits), thus separating these deposits from the top of the Pliocene Sterling Formation. The glacial deposits consist of poorly to moderately consolidated fluvial channel sands and gravels with interbeds of glacio-lacustrine claystones. CUTTINGS GRINDING and INSECTION Unocal's request of Dec 4, 1991 to grind up reserve pit solids and a small quantity of pad material, mix with drilling mud and/or gelled water for disposal into well KU-14-4. After reviewing ARCO's and BPX's cuttings grinding operations at Prudhoe and at Kuparuk, and reviewing the data of subject well and well KU-WD-1, I can make the following conclusions: Material ground to 50 mesh and mixed with drilling or gelled water can be injected into shallow formations such as below 3000' in subject well. Pressure increases have not occurred at the Kuparuk and Prudhoe operations. Cuttings ground to 50 mesh and mixed with a gelled liquid can be injected in large quantities at surface pressures below the fracture pressure in KU-14-4. Solids ground to 50 mesh and mixed with a gelled fluid are covered by Disposal Injection Order No.2. The step-rate test conducted in KU-14-4 on March 30, 1987 did not locate fracture pressure. To provide information should fracturing of the near- wellbore formation become necessary, a step-rate test should be conducted once stabilized injection conditions have been achieved. The test should locate the fracture pressure or should be conducted to test the maximum possible Pump injection rate or pressure. I recommend that we send a letter to Unocal telling them that this proposed operation is covered by the DIO, however, we would like the step-rate test as outlined above. DATA FOR SIEVES (Continued) TYLER STANDARD SCREEN SCALE SIEVES In the following table the Tyler Standard Screen Scale Sieves Series has been expanded to include intermediate sieves for closer sizing which gives a ratio of the fourth root of two or I. 189 between openings in successive sieves~ Tyler Standard Screen Scale Sieves and U. S. Sieves can be used inter- changeably. Tyler Standard Screen Scale Opening in Inches 3 2 1.5 1.050 · 742 · 525 .371 .263 For Closer Sizing Ratio 4 Opening in Inches 1.050 .883 .742 .624 .525 .441 .371 .312 Mesh eeeeeeee. Diameter of Wire, Decimal of an Inch · 207 · 192 · 162 148 135 135 120 105 105 · 092 · 088 U. S. Series Eq ui v alen ts (Fine Series) MICRON Designa- tion eeeeeeee Numbe~ e·.eeeee ieee.eel .eec.cee eeeeeeee eeee·®ee cee.Ieee leeeeee~ eeeee~em '".'iii" · 093 '".'ddg" '".'ddd" " '.'Sii ' · 0082 .263 .221 · 185 · 156 .131 .I10 · 093 .078 · 065 .055 · 046 · 03!)0 · 0328 .0276 .0232 .0195 .0164 .0138 .0116 · 0097 · OO82 3 6 7 8 9 10 12 14 16 20 24 28 32 35 42 48 60 65 .O70 ·065 ·065 .044 .036 .0328 .032 .033 .O35 ·028 .O25 .0235 0172 0141 0125 0118 0122 0100 0092 0070 0072 5660 4760 4000 3360 2830 2380 2000 1680 1410 119O 1000 810 710 5:)0 5OO 420 350 ~_ 2~.7_~. 250 210 eeeellee 0 8 10 12 14 10 18 20 30 35 4O ~0 O0 7O .0058 · 0041 eee· · · · · · .0029 · 0021 .0015 ·0058 .0049 .0041 ·0035 .0029 .0024 .0021 .0017 .0015 100 115 150 170 20O 25O 270 325 40O 0042 0038 0026 0024 0021 0016 0016 0014 ool .1Z7 149 125 105 88 74 62 53 44 100 120 140 170 ~00 230 270 325 40O · 0 2800 260O .2403 R200 2000 1800 1600 1400 1200 4.0 KENAI GAS FIELD WELL KU 14-4 STEP RATE TEST March 301h. 1987 I I I ! 6.0 7.0 8.0 9.0 5.0 WATER INJECTION RATE (BPM) W 1200 1100 1000 9O0 800 700 KENAI GAS FIELD WELL WD- 1 STEP RATE TEST' December 18th - 19th, 1986 I 1.0 2.0 ESTIMA TED FRACTURE PRESSURE 3.0 4.0 5.0 1,090psi 1 6.0 I WATER INJECTION RATE (BPM) Environmental Affairs Alaska Region Uno~,al North Americar''-'~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL ) May 16, 1991 Commissioner Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Lane Anchorage, AK 99501 DISPOSAL OF PRODUCED WATER FROM t~iLLON PLATFORM IN KENAI GAS FIELD WELL #KU 14-4 ~o - ~t Dear Commissioner Johnston: This is to advise that Unocal did not dispose of any water from the Dillon Platform into Kenai Gas Field Well #14-4 as requested on May 8, 1991. The total volume of excess water shipped from the platform was approximately 50 barrels and was caused by an operating error. There was no pipeline leak as originally suspected. The excess water was handled at the East Forelands Delivery Facility. Thank you for your assistance and prompt response. Sincerely, Faye W. Sullivan Environmental Coordinator CC: Anton Chaplin Joe McAdara Russell Peterson Robert Province RE£EIV£D MAY 2 0 t991 Alaska 0il & 6as Cons. C0mmiss't0t~ Anchorage Environmental Affairs Alaska Region Unocal North Americ/-''~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone: (907) 276-7600 UNOCAL May 13, 1991 Ct Commissioner Dave Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Lane Anchorage, AK 99501 Dear Commissioner Johnston: DISPOSAL OF PRODUCED WATER FROM DILLON PLATFORM IN KENAI GAS FIELD WELL #KU 14-4 ~-~1 This is to confirm our conversation of Wednesday, May 8 wherein Unocal requested and was granted permission to inject approximately 500 barrels of produced water from the Dillon Platform into Kenai Gas Field Well #14-4 pursuant to Disposal Injection Order #2. We will advise you of the volume and reason for the excess water as soon as possible. Thank you for your assistance. Sincerely, · Faye W. SulliVan Environmental Coordinator CC: Anton Chaplin Joe McAdara Russell Peterson Robert Province RECEIVED MAY 1 4 t991 Alaska 0il & (~as Cons. Commission Anchorage l~.e: Rel;eSt~ o[ UI:C wells Deal.- 14.1:- l)el}ll: .,:... .~. .In add.l,t, lon to retestti]g the Gcan-tte POlllt UIC wells for mecl!,-tt~tjca! :[l}t:egrt. t¥, the f'ollowin~l wells, also l]eer,:t bo.be I:e te.s ted tl'l 'l, ~.'.~ 9 .l, . Ga,:, l¢.t.c....l.dlwell 14-4. .. , · } ,, , lq[¢.:Arthi~{;' River Fleld~ : ": DOlly Vi~l[(]¢,9ll WSl].t: OR, 9R, 14R, .15R2, 24A'l& 29R: (}£'ayl..J. llg wells IZR, 14A, ~ .. · l;].oase Co{~t:o,:t ].,ol~r~te Smith at 279-1433 for schedull.g So that we ca~l {lave.. an t~lspector wit:ness ~o~e o[ the ,tests,'" , . , , o. STATE OF ALASKA / ...... · r'.. ;~, A~ OIL AND GAS CONSERVATION COM MI.°'~'~N' REPOR'I OF SUNDRY WELL OPEt- TIONS 0 I! 1. Operations pedormed: Operation Shutdown __ Stimulate __ Plugging __..~orate __ . . Puli tubing __ A.~er casing- Repai! well_ ~/"'r Pull tubing¥'~ Other ,~,_ 2. Name of Operator ! 5. Type of Well.'~----'~''---'''- 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAl) Development__ KB 104.6 ,, .... ,! Exploratory ~ -- ~. ~oaress | Stratigraphic 7. Unit or Property name P.O. BOX 190247, Anch, Ak. , 99519-0247I Se~ice~ Kenai..Unit 4. Location of well at surface 8. Well number 1177' N & 4489' W of SE Corner, Sect. 4, T4N, RllW, SM Kg 14-4 At top of productive interval At effective depth Straight Hole At total depth -- -- number 9. Permit number/apProval ~-3!/9-525 10. APl number 50-- 133-10087 11. Field/Pool Shallow Sterlinq feet 12. Present well condition summary Total depth: measured true vertical 5,125' 5,125' Effective depth: measured 4,292 · true vertical 4,292 · measured Length 6' 1069' 5102' Casing Structural Conductor Sudace Intermediate Production Liner Pedoration depth: feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" D riven 11-3/4" 1205 sxs 7" 800 sxs 4,194; - 4,250 Measured depth 6' 1069' 5,102 ' True vertical depth 6' 1069' 5,102' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Straight Hole 2-7/8" 6.4#, N-80 Buttress @ 4158' Baker Model "D" Packer @ 4148' RECEIVED 13. StimulatiOn or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0il & Gas Cons. Commission Anchorage 1'4. Prior to well operation Representative Daily Average Production or Injection Data Oil. Bbl Gas-Md Water-Bbl Casing Pressure 165 -0- Tubing Pressure 1000 Subsequent to operation 3 3 - 0- 15, Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Oil ~ Gas __ Suspended __ 17. I hereby certify that the ioregoing istrue and correct to the best of my knowledge. Signed ., D, p,-,h,--r~ = Title For~(31021~3¢ I~v 06/15/88 Service 1000 Inject ion Date7 / 2 6 / 8 9 SUBMIT IN DUPLICATE SUMMARY OF MECHANICAL INTEGRITY TEST KENAI GAS FIELD, WELL KU 14-4 JUNE 20, 1989 1) 2) 3.) 4) 5) ~) RU Arctic Recoil to well. Tubing pressure prior to Mechanical Integrity Test was 840 psi. Approval received fro~ Mike Minder (AOGCC), to pressure up annulus to 1900 psi. Observed pressure for 30 minutes. Witnessed by Mike Minder. Pressure held. Bled off pressure and injected annular volume of water into well Rig down and returned well to injection. 1. Type of Request: ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other .~X 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface 1177' N & 4489' W of At top of productive interval At effective depth SE Corner, Sect. 4, Straight Hole At total depth 5,125' 5,125' 12. Present well condition summary Total depth: meaSu red true vertical Effective depth: measured 4,292 · true vertical 4,292 ' Size 20" 11-3/4- 7" feet feet feet feet Casing Length Structural 6 · Conductor Surface 1069' Intermediate Production 5102 · Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-7/8" 6.4#, Baker Model Description summary of proposal 13. Attachments 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X__ T4N, RllW, SM Plugs (measured) Junk (measured) Cemented Driven 6 ' 1205 sxs 1069' 800 sxs 5,102' 4,194' - 4,250 Straight Hole N-80 Buttress @ "D" Packer @ 4148' Detailed operations program X__ 15. Status of well classification as: 14. Estimated date for commencing operation I June 20, 1989 16. If proposal was verbally approved Name of approver Date approved Service Disposed Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 6. Datum elevation (DF or KB) KB 104.6 feet 7. Unit or Property name Kenai Unit 8. Well number KU 14-4 9. Permit number 60-31 10. APl number 50-- 133-10087 11. Field/Pool Shallow Sterling Measured depth True vertical depth 6' 1069' 5,102' RECEIVED LIUN 1 tgS9 41 S 8,jlija~k~ Oil & Gas Cons, C0mllllsslOIt Anchorage BOP sketch Oil __ Gas __ Suspended Date 6/12/89 I Approval No. ~::~_. ~-~.--- · .~pproved Copy Returned commissioner.`. E~ate SUBMIT IN TRIPLICATE Signed /~¢¢_¢~.,/~. /,¢~~ Title W. nviron~,ntal Enqineer %~'~' D. P.o~3ortc(' ~//..,/ FOR COMMISSION USE ONLY Conditions of approval: Notify ComJ'p. issi'on so representative may witness Plug integrity ~ BO~/Test __ Location clearance g Mechanical Integrity Test ~ Subsequent form required 10-, , ~P ADp_roved by order of the Commission F(~r~n"l~);~0~ Rev 06/15/88 ORIGINAL SIGNED BY LUNNiE O. 3;'v1!TH MECHANICAL INTEGRITY TEST KENAI GAS FIELD - WELL KU 14-4 me e 3e e Se e 7e Rig up pumping unit over KU 14-4 casing/tubing annulus Pressure test lines to 2500 psi. Bleed off pressure and start Mechanical Integrity Test Pressure up to 1500 psi. Observe pressure for 30 minutes. Bleed off pressure Rig down pumping unit and demob equipment. RECEiV£D ~JUH I z, ~_9~9 Gas Cons. Commission Anchorage TU~IN~. ~c-A:L,., INTERVAL C 0 N D' -' "'" "' Trueteo W/ I I,C~:D ~'nl. ,,." 3~ O~-AL (5-I KU 14-~ l RECEIVED ~UN 1'~ 1989 Rlaska 011 & Gas Cons; Commission ~ Anchorage i Environmental Department Alaska District Unocal Oil & Gas Di'~n Unocal Corporation Rd. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) March 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Mr. Joseph A Dygas, Chief Branch of Lease Operations Bureau of Land Management 6881 Abbott Loop Road Anchorage, AK 99507 Unocal Operated KU 14-4 Kenai Gas Field Gentlemen: As we recently discussed, Unocal anticipates injecting non-unit produced fluids from the Pretty Creek Unit into KU 14-4 in the Kenai Gas Field. As you are aware, Unocal submitted a request for an injection order to convert Lewis River Well No. D-1 from a plugged and abandoned gas well to a Class II disposal well to handle disposal of produced water from ti~e Lewis River, Pretty Creek, Ivan River and Stump Lake gas wells. Until Unocal receives approval to convert Lewis River D-1 well to a Class II disposal well, it will be necessary to dispose of the Westside produced water into the Kenai Gas Field Well KU 14-4. - , ShoutO you have any questions, please contact me at the number listed aOove. Very truly yours, /ff Candace Lockwood~Y Environmental Analyst CWL~cgso03/22/89 CC' Kevin Tabler - Unocal 0013n/34 RECE'tVED STATE OF ALASKA ALAS, OILAND GAS CONSERVATION COMMISSI, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing __ Other 2. Name of Operator UNION OIL CO, OF CA.TL~IFOR.~IA 3. Address P.O. BOX 190247, ANCHORAGE AK 99519-024] 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1177' N & 4489' W FROM SE COR, At top of productive interval At effective depth At total depth 5125' 5125' SEC 4, T4N, RllW, S.M. 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet 6. Datum elevation (DF or KB) KB 104.6 7. Unit or ProDertv name KENAI UNIT 8. Well number KU 14-4 9. P~rmit numbedappr~val number , 60-31 , 8-7~2 lO. APl number 50-- 733-10087 11. Field/Pool SHALLOW STERLING Effective depth: measured 4292 ' true vertical 4292 ' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 6' Size Cemented Measured depth True vertical depth 20" DRIVEN 6 ' 6 ' 1069' 11-3/4" 5102' 7" measured 4194'-4250' 1205 SXS 1069' 800 SXS 5102' 1069' 5102' feet true vertical Tubing (size, grade, and measured depth) 2-7/8" 6.4~/, N-80 BUTTRESS @ 4158' Packers and SSSV (type and measured depth) BAKER MODEL "D" PACKER @ 4148' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re, presentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 65O lOOO Subsequentto operation 650 15. Attachments 116. ~tatus of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations ~ Oil ~ Gas ~ Suspended ~ , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned fY Rog D. ROberts . Title Environmm_ntal Enoinemr Form 10-404 Rev 06/15/88 1000 Service INJECTOR Date///¢/(~' SUBMIT 'I~U~oATE UNION OIL CO. OF CALIFORNIA DRILLING RECORD PAGE NO. 1 Kenai Unit LEASE WELL NO.14-4 Shallow Sterling FIELD DATE 10/16/88 10/17/88 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4,292' 4,292' MIRU Otis 1-1/4" coiled tubing unit and B.$. N2 equipment. Test BOPE to 1500 psi - ok. Ran in hole with 1.75" down jet hydro-blast nozzle to fill at 4228' Cleaned out fill with water, 4228'-4238' and foam 4238'-4292'. Could no~ clean out deeper. Pulled out of hole. Secured well. Suspended ops at 1630 hours. Commenced ops at 0800 hours. Ran in hole with 2-1/2" flat bottom mill on 1-3/4" Navi-drill. Could not work past 4292'. Appears to be running on metal. Rulled out of hole. Rig down all equipment. Suspended ops at 1330 hours. 2/8O ' ' ,'"-" STATE OF ALASKA AL,-..,,(A OIL AND GAS CONSERVATION COMMI,., APPLICATION FOR SUNDRY APPROVALS Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance ~ Perforate ~ Other 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program 2. Name of Operator Union Oil Company of California (UNOCAl)' 3. Address P.O. BOX 190247, Anch, Ak., .99519-0247!. 4. Location of well at surface 5. Type of'Well: Development __ Exploratory __ Stratigraphic ._.../ Service ..~ 1177.03' N & 4489.35' W from SE Cot. Sec. 4, T4N, RllW, SH At top of productive interval 5125 ' feet Plugs (measured) 5125 ' feet At effective depth At total depth "i'2. Present well condition summary Total depth: measured true vertical Effective depth: measured 4235 ' 4235 ' feet Junk (measured) true vertical feet measured true vertical 6. Datumelevation(DForKB) KB 104.6 z unitorProPedynam¢ Kenaz Unlt 8. Well number Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: KU 14-4 9. Permit number 60-31 10. APl numl~er 5o_733~10087 11. Field/Pool Shallow Sterling ~ngth Size Cemented Measureddepth 6' 20" Driven 6' 1069' 11-3/4" 1205 sxs 1069' 5102' 7" 800 sxs 5102' feet Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) True vertical depth 6~ 1069' 13. Attachments 5102' BOP Sketch __ 14. Estimated date for commencing ~l~erati0n ' 115. Status of well classification as: I 16. If proposal was verballY approved ..... I Oil ._.. Gas __ Suspended Lonnie Smith 10/14/88 I Name of approver , Date approvedl Service Disposal "~. I hereby c~'ifv that t~e foregoir~'g is true and correct t~'ih® best of'mY knowledge. ~,.~ FOR COMMISSION usE'ONLY 'COnditions of approval': Notify Commission'sOrepresentative' may .... witness Plug integrity __ BOP Test __ Location clearance __ /, .¢, Mechanical Integrity Test ~ Subsequent form required 10- z¢¢~ Approved Copy Returned ORIGINAL..,SIGNED BY ,/42 -¢¢~-~ Approved by order of the Commissionflr. ON~ll~ .~.. SJ~TH Form 10-403 Rev 06/15/88 I Approval No. ~-,.....~:~_ Commissioner Date/0 SUBMIT IN TRIPLICATE~/~; DescriptiOn Summary of ProPosal __ Detailed operations program Baker Model D packer $ 4148' 10/14/88 2-7/8" 6 4#, N-80 Buttress $ 4158' KENAI UNIT KU 14-4 PROCEDURE 1. Move in and rig up coiled tubing and Nitrogen units on KU 14-4. 2. Function test coiled tubing BOPE. Test surface lines to 1500 PSI. Slowly RIH with 1-1/4" coiled tubing and jet washing tool thru 2-7/8" tubing to fill in 7" casing at + 4221'. Tubing tail is at 4158'. (See Attached Schematic) - 4. Clean out fill inside 7" casing from 4221' to ETD at 4500'. (+ 279' of fill). Use Nitrified foam. Make short trips as necessary to ensure fill removal. Switch over to a small mud motor and mills if the fill can not be effectively removed by washing. When clean returns are established, shut down N2 and foam. PO~H. 7. Return well to production. Reperforating to be accomplished at a later date as directed by Reservoir. DURATION: 2 Days KU 14-4 RERERFORATING RROCEDURE (IF REQUIRED) 1. R.U. Gearhart W/L over KU 14-4. 2. RIH w/ l-Il/16" guns 4/HRF 0° phased. 3. Locate across 4194' - 4250'. 4. Reperforate zones overbalanced. 5. ROOH w/guns. 6. Return well to disposal status. trf TUBING DETAIL KU 14-4 Oti~ X-Nipple al 4 4147. g2~ wltn Coment Retainer Bt 4500' Cement Retainer at 5043' PERFORATION RECORD INTERVAL CONDZTION 41~4~-4~S0~ TruateO W/ 1~,000 g~l. O,3M OH-AL (~-1 Sand} 7" C,3=ing at 4221 KU 14-4 WELL SCHEM.~TIC ;',,'.ti KU $4,-~ I F~i,l KENAI GAS .. UNOCAL~ Alaska District Hr. C.V. Chatterton, Chairman Ak. Oil & Gas Consv. Comm. 3001 Rorcupine Drive Anchorage, Ak. 99501 Unocal Oil & Gas Divisio, Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Oune 8, 1988 Mr. Ooseph A. Dygas Chief, Branch of Lease Operations Bureau of Land Management 6881 Abbott Loop Road Anchorage, Ak. 99507 Gentlemen: Unocal Operated KU 14-4 Kenai Gas Field Unocal operates the above injection well under Disposal Injection Order No. 2 issued on February 18, 1987 by the Alaska Oil and Gas Conservation Commission This letter is to inform you that Unocal will be injecting non-hazardous waste fluids from the Rretty Creek and Lewis River Units into KU 14-4 beginning the week of Sune 13, i988., Disposal activities within the Kenai Gas Field are in compliance with Alaska Oil and Gas Conservation Commission Regulations and the Bureau of Land Management. All necessary reports will be filed in accordance with applicable State and Federal Regulations. 6/~/~'(' Should you have any questions regarding this matter, please contact me. If__ ~CO ~[~e~ ~ ~~ ~' ~ n Candace Lockwood) ~'~-- -. dT _ ~ ~T, J, ~ ~ Environmental Department _cw~~,~ ~~ ?RECEIVE ~/~ ~ ~ ~ ,.__, ~ AWs~ 0il & Gas Cons. Commi~ion ~h0rage Telecopy No. (907) 276-7542 March 22, 1988 Mary Bell Ronald Bell P 0 Box 3863 Soldotna, AK 99669 Dear Mary & Ronald Be]'l: This is to rel~~o~B~mgeting of March 11, 1988 at Union's disposal well,~~which is located off the end of Wendy Lane, Kenai are~%~-C0ncerns expressed by you and others were the large number of vacuum' trucks traveling Wendy Lane to KU 14-4; Union's authority to dispose of the fluids being hauled; and the safety of the disposal operation. On March il, 1988 I flew to Kenai and met Kevin Tablet and Bob Smith, both with Union, whom I had asked to meet with me to answer questions. At the well site about 1:30 p.m., Mr. Johnny Wilson arriVed accompanied by a neighbor. A brief time later, Mr. Monte Barnett of the Kenai Borough arrived. Near the end of our meeting Mr. Billy Gilbert, an area resident, drove up. Mr. Wilson handed me your letter. As we discussed, the truck traffic was from various sources such as Beaver Creek, Poppy Lane Pit, and the drilling rig. It was expected to decrease in about.a week. As of this date, only occasional use is being made of. KU 14-4; therefore, vacuum truck traffic on Wendy Lane has dropped significantly. Class II wells may be Used for hydrocarbon storage, enhanced recovery, and for the disposal of non-hazardous oil and gas field wastes. Hazardous wastes are listed in 40 CFR Part 261 Identification and Listing of Hazardous Wastes. The EPA considers drilling muds to be non-hazardous and has provided specific authority to dispose of Poppy Lane fluids into a Kenai Gas Field disposal well. This is a rather long explanation to say yes, the fluids being disposed into KU ]4-4 are approved by EPA and AOGCC. Mary & Ronald Bell March 22, 1988 Page 2 Regarding the safety of the disposal interval, EPA regulations state, at 40 CFR PART 147 - STATE b~NDERGROUND INJECTION CONTROL PROGRAMS, Subpart C - Alaska at 147.102 (b): "(b) %"ne following aquifers are exempted in accordance with the provisions of ¶¶144.7(b) and 146.4 of this chapter for Class II injection activities: "(1) The portions of aquifers in the Kenai Peninsula, greater than.the indicated depths below the ground surface, and described by a k mile area beyond and lying directly below the following oil and gas producing fields: (i) Swanson River Field - 1700 feet. (ii) Beaver Creek Field - 1650 feet. (iii) Kenai Gas Field - 1300 feet." The EPA is obligated by Congress to protect water fresher than 10,000 ppm; therefore, the formation water at the above respective depths is presumably greater than 10,000 ppm. Regarding the disposal interval, the disposal is through perforations at 4194' to 4250' below the surface. (The shallower gas sands in the Kenai Gas Field are 3700' below the surface.) The 7" casing has been cemented with a total of 1150 sx (1345 cubic feet) of cement slurry. There are adequate impervious confining zones above the injection interval to preclude the disposal fluid from migrating upward into the freshwater sands. Based on the above considerations, known geologic conditions, and a review of the file data, the disposal zone is sufficiently below the.freshwater sands and appears to be adequately cased and cemented to confine disposal fluids to the perforated sands so that the shallower freswater sands will not be contaminated. If you have additional questions, please contact me by letter or telephone (279-1433). Sincerely, Blair E Wondzell Sr Petroleum Engineer j o/A. BEW. 87 March 17, 1988 Telecopy No. (907) 276-7542 G A Graham District Operations Mgr Unocal P O Box 190247 Anchorage, AK 99519-0247 Re: CBL's requirements for injection wells Dear Mr Graham: Recent analysis of your Kenai Field disposal wells -- KU WD-1 and KU 14-4 -- disclosed that on KU WD-1 a CBL was run, but we do not have a copy; and that on KU 14-4 a CBL was not run. Since these are required per 20 AAC 25.030(g)(3) -- "...for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 9-5/8 inches or less in diameter..." -- please furnish us with a copy of the CBL on KU WD-1 as soon as convenient; and plan to run cement evaluation logs in KU 14-4 early this summer. If you have questions, please contact me at 279-1433. Sincerely, Blair E Wondzell Sr Petroleum Engineer jo/A.BEW.85 CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. 5633 B Street Anchorage, Alaska 99518 TELEPHONE (907) 562-2343 OPERATC ,::{ UNOCAL WELL NO. 14 FIELD CANNEF~ LOOP COUNTY STATE ALASKA WATER ANALYSIS REPORT · DATE I $ --! 3-87 LAB NO. 8447. ! LOCATION FORMATION. ', INTERVAl 1ST S/~{PLE-45 BBL INJECTED SAMPLE FROM PRODUCED WATER INJECTED DO'~;~i 14-4 REMARK:S & CONCLUSIONS: bARIUM, MG/L.. STRO~TIU~:¶~ MGi/L 4Z l RoN, MG/L .D( O. ! ) .'4CC/ C~-.':;3ns mgll Sodium .............. zs19 109o59 Potassium ........... 140 3,58 Calcium ............. Z360 117.76 Magnesium .......... o. 09 o. 07 · Iron ................. Total Cations ......... z31. oo meq/i Anions mg/I meq/i Sulfate .............. · z I 0 Chloride ............. 7320 Carbonate ........... ! 3 z Bicarbonate ......... 965 Hydroxide ........... 4,37 206.40 4.40 15.83 Total Anions .......... 231 .oo Total dissc'ved solids, mg/! .......... NaCI equi','alent, mg/! Observed F H ....................... I3,157 Specific resistance ~, 68* F.: 755 Observed .......... o.. 52 ohm.meters o, a Calculated ......... o, ss ohm.meters Na Ca Mg Fe _--.ample above described WATER ANALYSIS PATTERN Scale MEQ per Unit SO, ~ Mg SO, COs ! Fe COs (Na value in above graphs includes Na, K, and'l~l-~ NOTE: Mgtl = Milligrams per liter Meqll = Milligrams equivalent per liter Sodium Chloride equivalent = by Dunlap & Hawthorne calculation from components CHEMICAL & GEOLOGICAL LABO~O~E$ OF ALASKA, INC. · ~'X ~-~ ,: FEDERAL TAX ID. 92-0040440 A~LYS!~ ~0~ BY oA~LE CI i en t PO{f : VERBAL CIient 8mpl ID: DRILLING FLUID .... Sample Rec'd : JUN 15 87 Ordered By : CANDY LOCKWOOD Send Reports To: UNOCAL ATTNACCTS PAYABLE P 0 B~×7600 LOS ANGELES, CA. 90051 Special ,~MATRIX = DRILLINGFLUIDS Instruct: Req #: ChemlabRef #: 6578 Lab Smpl ID: I ParameterTested Work Order No..~' : 1107 Client Account : UNOCALP .... D~te Report Printed: JUL 1 87 g 15:4i ReleasedBy : SCE,~C~.~~ Reports Address #2 Matrix: See SamPle Remarks Result/Units Method Allowable Limits SODIUM POTASSIUM MAGNESIUM IRON (TOTAL) CALCI~I .CHLORIDE CARBOIqATE BICARBONATE L~D ARSENIC BARIUM CADMIUM CHROM I ~ (TOTAL) CYANIDE RESIDUE: (TDS) FI LTEP, ABLE pH SULFATE 1 i00 mg/t 38 mg/l 0.2 rog/1 1.0 rog/1 58 ~g/] 360 rog/1 360 120 ND (0.05) mg/l 0.007 mg/l 0.05 mg/l ND (0.01) mg/l 4.7 rog/1 ND (0.01) rog/1 3260 mg/l 11 units 1300 m~/l ICP ICP ICP ICP ICP ICP AA ICP ICP ICP Samp 1 e Remarks: .17 Tests Performed ND= None Detected NA= Not Analyzed * See Special InstructionsAbove ** See SampleRezarksAbove LT=LessThan, GT=Greater?nan 1986 /~~!'~-'.'X ' P.O. BOX 4-1276 ' TELEPHONE ANCHORAGE INDUSTRIAL CENTER ,~"';, .......... "'~' ' Anchorage, Alaska 99509 (907) 562-2343 5633 B Street WATER 'ANALYSis REPORT ,:..., · OPERATOR UN~ DATE '"~'~r~,e_..q: I ~'(o LAB NO. WELL NO. WD-i LOCATION . 'FIELD. Kena± Gas B£e'ld FORMATION COUNTY INTERVAL STATE AZask~. · SAMPLE FROM 3250 REMARKS & CONCLUSIONS: Barium, mg/1 0.91 Strontium, mg/i 0.71 Iron', mg/1 1.4 ~.,: Cations sOdium - Potassium'. .......... Calcium ............. Magnesium .......... Iron ................ mg/1 megll Anions mgtl meg/1 Sulfate .............. 4.1 0.09 Chloride ............. 300 8.46 Carbonate ........... 0 0 Bicarbonate ......... 720 11.81 Hydroxide ........... 0 0 375 65 40 4.0 Total Cations ......... 16.32 1.66 2.00 0j38 20.36 Total Anions .......... ~ Total dissolved solids, mg/1 .......... NaCl equivalent, mg/1 . .. Observea pJ-'j .............. ~ ........ 1143 982 7.5 Specific resistance ® 68° F.: Observed .......... Calculated ......... 6.53 ohm.meters 6.5 ohm.meters Z~VOICE #38155 WATER ANALYSIS PATTER;,; Scale MEQ 'per Unit value in above graphs includes Na, K, and L1) ..... ~!!igrams per bier Meq/1 = Milligram equiv~,lr,,:t per liter · . ..... '...., nl,.l~ ,~. I-~.~l:lth,,.~rl~n .ell¢-.,! ............. DATE: MEMO TO: FROM: June 9, 1987 File File: KU WD-1 KU 14-4 FLUID DISPOSAL FROM POPPY LANE PIT, KENAI Operated by Union Oil Company On June 4, 1987, at about 2:30 p.m., Elaine Johnson received a call from Mr. Charles Dickson, Soldotna, requesting the location of Union's two disposal wells. Elaine provided the information by section, township, and range. He said that was not useable by him. He then asked Elaine questions about the legality of Union removing liquids from the Poppy Land gravel pit and disposing of them into the injection wells. .Elaine asked me to talk to him. I picked up the phone and introduced myself. Mr. Dickson asked if Union had approval from us to inject waste fluids into the Kenai Gas Field disposal wells. I said, "Yes, non-hazardous oilfield wastes." He responded that the contaminated fluids in the pit were hazardous because DEC analyses showed large quantities of... -- here he named various substances, including benzene, toluene, barium, arsenic, and chromium. He also said they were removing the fluids to decontaminate the pit, since the soil contained considerable hazardous materials because it had been Union's dump site; and that it was a candidate for "superfunds". I asked if he had contacted DEC personnel about this. He said he had, and gave the following names: Bill Lamoreaux, Bruce Erickson, Bob Cannone, Mike Lucky, Colleen Berg, Governor Sheffield, Governor Cowper, Kelso, Carl Reller, and others. When asked how long this situation had been going on Mr. Dickson said it started in 1981, and the file at the AG's oflice is 3' thick. He said EPA did a preliminary inspection in 1985 or 1986 (July), and Debra Flood in Seattle was the EPA contact. In response to further questions, he said the Poppy Lane gravel pit covered 45 acres, and his place is on the edge of it. He stated (in other words) that the DEC analyses were not accurate -- they didn't show much as far as bad contamination -- and the water table was about 6' deep. He said he had no tests on his well, but would have shortly, as he had sent in a water sample to be analyzed and it would cost $1,500. When asked about effects on the vegetation, Mr. Dickson said it was not growing much in the pit. I said that was to be expected, and asked about the vegetation near his house. He said it was spruce and cottonwood, they had spruce beetles, so not much there. I asked about shrubbery, and he said his wife was having a hard time growing flowers. I asked about browning of natural vegetation. He said no, but two of his dogs drank from the pit and one died, the other was sick. This situation was discussed with the Commissioners. The concurrence was that removal of fluids from the pit for disposal in the injection wells was most probably in accordance with DEC/EPA approval. I was asked to see if Union had supplied the data requested by Robert Burd, EPA, in his November 14, 1986 letter to Union; and if so, to get a copy for us. They also asked that I write a letter to the file concerning the citizen complaint. Mr. Burd's letter (EPA) to G. A. Graham, Union, dated November 14, 1986, gave approval to inject fluids from shallow aquifers into the disposal wells as long as the fluids were "equivalent to produced water." This procedure was recognized as a means to clean up the shallow aquifers which were contaminated by "produced water placed on the land." In his letter, Mr. Burd asked for backup information to provide a history, analytical data demonstrating that cleanup waters are "equivalent to pro- duced water", and a plan to locate the source of contamination. The requested data was supplied by Union on February 3, 1987. Samples of produced water from well KU 41-7 and water from the Poppy Lane pit were analyzed for aromatic hydrocarbon content by Chemical & Geological Laboratories of Alaska, Inc. during November, 1986 with results as follows: . - 2 - Hydrocarbon KU 41-7 Produced Water-PPB Poppy Lane Gravel Pit Water-PPB Benzene 82 0.86 Toluene 280 19.7 Ethylbenzene 146 68.8 Chlorobenzene ND(I) ND(i) p-Xylene ) ) m-Xylene ) 403 )416 o-Xylene 98 122 1,4 Dichlorobenzene ND(I) ND(I) 1,3 Dichlorobenzene ND(I) ND(I) 1,2 Dichlorobenzene ND(I) ND(I) ND = none detected-- detection limits in () Since the water from the Poppy Lane pit is similar (equivalent) to produced water, EPA has given Union approval to inject this fluid into the Kenai Unit disposal wells: KU WD-1 and KU 14-4. The Alaska 0il and Gas Conservation Commission concurs in that decision. - 3 - Unocal Oil & Gas Di' ' Unocal Corporation ; Rd. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska District April 8, 1987 TO: S.A. 'Lambert FROM: M. R. Starzer ~ RE: KU 14-4 STEP RATE TEST AND TEMPERATURE SURVEY MARCH 30~ 1987 A step rate test and injection temperature surveys have been run on KU 14-4 in preparation for disposal service. KU 14-4 is currently open in the pool 4, 'B-1 Sand with 56' of perforated interval from 4194' to 4250' (NO). Prior to/injection, fill was tagged at 4235' leaving 41' of the perforated interval open. The following stabilized injection rates ano pressures were recordeO. Rate Bottomhole Injection Pressure ~ BPM " ~' Pre-Test Temperature Survey 5 1891 PSIG 6 1962 7 2019 8 2260 9 2466 2 o Post-Test Temperature Survey o Static Temperature Survey Three temperature surveys were performed· The survey designated Run #1 was taken prior to the injectivity test at a rate of 5 BPM and 500 psig surface injection pressure. Run #2 is the post-test survey taken 20 minutes after the maximum sustainable injection rate of 9 BPM. Run #3 is the post-test static survey. Anomalies in Run #1 near tile packer and locator are due to the 't' sleeve at 4111' being open allowing cool water on the backside The sliding sleeve was closed after_the, statics, Kb 14-4 Step Rate Test and Temperature Survey - Harcn 30, 1987 April 8, 1~87 Page Two survey in preparation for the mechanical integrity test. All surveys Oemonstrate injection occurring within the 8-1 sand of Pool 4 and no ci~anneling behind casing. Ther~ is no indication of injection above the confining shale intervals into possiOle sources of fresn water. The B-l sana witi~in the Kenai Gas Field is under-pressureO Oue to depletion from the gas pool. A fluio level taken in 14-4 prior to the step rate test indicates a localized B-1 formation pressure of approximately 1220 psig. Losses across the perforations and sandface approach 650 psi at an injection rate of 5 8P~l, increasing linearly to i250 psi at 9 BPM. No indication of formation breakdown occurreO up to 1900 psig in~ection pressure. The fracture gradient for the 8-1 sand in '14-4 is in excess of .89 psi/ft. Applying a multiple rate transient analysis to the test yields a permeability, to tI~e in3ection fluids of approximately 75 ~D with a stimulated skin, comparaole to transients analyzed eise~ere within the field. Attact~ed is the step rate test Hall plot and temperature survey log. MRS:vlf-O41~r cc: C. Lockwood R. D. Rooerts 8. C. Smith - Field Well File KU 14-4 Well File ~'- L~~ STATE 'OF ALASKA ~ A ' OIL AND GAS CONSERVATION CON iSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [~ Mechanical Integrit~v test & step rate test 2. Name of Operator Union 0il Company of Californ±a (UNOCAL) 3. Addre~.0. Box 190247, Anch, Ak., 99519-0247 4. Location of well at surface 1177.03' N & 4489.35' W from SE cot., Sec. 4, 5. Datum elevation (DF or KB) Feet 6. Unit or Property nar~nai Unit 7. Well number KU 14-4 8. Approval number 7-195 9. APl 50-- number733-10087 10. Pool Kenai Gas Field TN 1W At top ~o~ pt~O~L~Lc']t',v~ inSt~v'a' At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical 5125 ' 5125 ' feet feet Plugs (measured) Effective depth: measured true vertical 4235' 4235' feet feet Junk (measured) Casing Length Structural 6' Conductor ].069 Surface Intermediate 5102 Production Liner Perforation depth: measured true vertical Size Cemented Measured depth 20" Driven 6 ' ll 3/4" 1205 sxs 1089' 7" 800 sxs 5102 ' 4194 ' -4250 ' ~ue Verticaldepth 1069' 5102' Tubing (size, grade and measured depth.) 2 7~8",.~6.4#, N-80 Buttress $ 4158' Packers and SSSV (type and measured depth) Baker Model-D pkr ~ 4148' 12. Stimulation or cement squeeze summary i\EtEI VEL) Intervals treated (measured) Treatment description including volumes used and final pressure Alaska OiJ & Gas Cons. Comm,~oL 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Well shutin Tubing Pressure Subsequent to operation 14. Attachments Daily Report of Well Operations [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Roy Roberts Copies of Logs and Surveys Run [] Title Environmental £nglneer Da,...- 5-8-87 Signed Form 10-404 Rev. 12-1-85 Submit in Duplicate MECHANICAL INTEGRITY TEST KENAI GAS FIELD ~ WELL KU 14-4 MARCH 31, 1987 . . . 5~ e Rig up Dowell over KU 14-4 casing/tubing annulus Pressure tested lines to 2500 psi. Tested OK 8leo off pressure and started Mechanical Integrity ]'est Pressured up to 1500 psi Observed pressure for 30 minutes. (Doug Amos, AOGCC witnessed) Bled off pressure Rig down Dowell and demob equipment RECEIVED Alaska Oil & Gas Cons. 6ommissio,q Anchorage 2800 2600 ,2403 2200 2000 18oo 'i- 1600 0 '" ~ O' oo · :.: . . ~-,,.~ cO ,,,~ ii' i i"i .:.-, C t ' '! · .. . :.; ': i 1400 1200 4,0 KENAI GAS FIELD WELL KU 14-4 STEP RATE TEST March 30th, 1987 5.0 6.0 7.0 8.0 9.0 WATER INJECTION RATE (BPM) Unocal Oil & Gas Di~, ;t Unocal Corporation RO. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Environmental Group Alaska District ,qay 15, 198'7 Dear Hr. Chatterton: Mr. C.V. Chatterton, Chairman Alaska 0il & Gas Conservation Comm. 3001 Rorcupine Drive Anchorage, Ak. 99501 Temperature Survey and step Rate Test - Well KU 14-4 Kenai Gas Field Attached is Unocal's report of Sundry Well Operations (Form 10-404) for the Step Rate Test and Mechanical Integrity Test recently performed on the above well. Also included is a memo to S.A. Lambert - Unocal from H.R. Starzer relative to the tests. Based on the ,information provided, Unocal requests a surface injection pressure of 2,000 psi for .well KU 1.4-4.~ ~~ ·~_ ~_~.~~/ Very truly yours, ~) <~'~ \ RoFO. Roberts w~)--_. ~r~. ~C ~ Environmental Engineer ~.'-~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re.. REQUEST BY UNOCAL COMPANY ) to dispose of non- ) hazardous oil field wastes) by underground injection ) in well KU 14-4, Kenai Gas) Field ) Disposal Injection Order No. 2 Kenai Unit' Kenai Gas Field February 18, 1987 IT APPEARING THAT: · Unocal Company (Unocal) requested on January 20, 1987 the Alaska Oil and Gas Conservation Commission to authorize the use of well KU 14-4 as a disposal well in the Kenai Unit, Kena± Gas Field. Unocal will inject non-hazardous waste fluids generated by normal drilling and production operations. · Notice of an opportunity for a public hearing on March 11, 1987 was published in the Anchorage Daily News on January 30, 1987. · No protest or request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. 12. · ~ Ail aquifers-below 1300 feet within the Kenai Gas Field Boundary, and one-quarter (k) mile beyond, are exempted under 40 CFR 147.102(b)(1)(C) for Class II injection activities. Permeable strata, that will accept injected fluids, are present below 2900 feet in well KU 14-4. A series of confining strata are present above 2900 feet in well KU 14'4 that will prevent upward movement of the injected waste fluids into non-exempt aquifers. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. Disposal Injecticr--xOrder No. 2 February 18, 198', Page 2 · To .ensure that waste fluids are cOnfined to injection strata, the mechanical integrity of KU 14-4 will be demonstrated periodically and monitored routinely for disclosure of possible 'abnormalities in operating conditions. KU 14-4 is constructed in conformance with the requirements of 20 AAC 25.412. CONCLUSIONS: The~ geologic sequence present at the well site and maintenance of the mechanical integrity of KU 14-4 will prevent movement of injected fluids into non-exempt aquifers. NOW, THEREFORE, IT IS ORDERED THAT: Non-hazardous oil field waste fluids may be injected in conformance with Alaska Administrative Code Title 20, Chapter 25, for the purpose of disposal into the Sterling formation below the measured depth of 2900 feet in well KU 14-4. DONE at Anchorage, Alaska, and-dated February 18, 1987. C~V. C ,~hatte~~rto~.rf, C~ai~man Alaska Oil and Gas Conservation Commission Lonhie C Smith, Commissioner Alaska Oil and Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission ,'~'", STATE OF ALASKA ~ ALAS,,.~ OIL AND GAS CONSERVATION COMI,,,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approVed program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Union 0±1 Company of Californ±a (UNOCAL) 304.6 ~ feet 3. Address 6. Unit or Property naK~nai Unit P.O. Box 190247, Anch, Ak., 99519-0247 7. Well number 4. Location of well at surface 1177.03' N & 4489.35' W from SE cDr., Sec. 4, T4N. RllW, S.M. At top of froductive interval At effective depth At total depth KU 14-4 8. Permit number 60-31 9. APl number/33_10087 50-- 10. Pool Kenai Gas Field 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5125' 5125' 4280' 4280 feet feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size 6! 1069 ' 20" 11 3/4" 5102' Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth Driven 6' 6' 1205 sxs 1069' 1069' 7" 800 sxs 5102' 5102' 4194 ' -4250 ' true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 2 7/8", 6.4#, N-80 Buttress $ 4158' Baker Model-D pkr $ 4148' 12.Attachments Description summary of proposal I;2: Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March 30, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Roy Roberts/~.~_.~¢///¢_~:~. Title Environmental Engineer Commission Use Only Date 03/26/87 Conditions of approval Approved by 6~J I~t~Ht[ ~;. SLIT] Form 10-403 Rev 12-1-85 _Nptify commission so representative may witness I Approval No. /~Plug integrity [] BOP Test [] Location clearanceI ., _ :.::.::, ................ by order of Commissioner the commission Submit in triplicate KENAI GAS FIELD KU 14-4 STEP RATE TEST Unocal proposes to perform a step rate test aha mechanical i~tegrity test following t~e proceoures outlineo below' l. Rig up Gearhart and Doweli anO run flowing temperature survey (maintaining ~eliheaO injection pressure below 1000 psi' .67 psi/f't.). Perform step rate test, varying injection rate from 0.5 8PM to 6 8PM, recording injection rate ano stabilized wellhead pressure· Determine at least six points confirming breakover. ~taintain injection pressure above parting pressure for at least five hours· Run flowing temperature survey while injecting above parting pressure· 4. Shut well in ano rig down· · . MECHANICAL iNTEGRITY TEST RU Dowell pump over KU 14-4 annulus. Pressure up annulus to !500 psi and hold for~ mins. (AOGCC inspector to witness pressure test). BleeO pressure off annulus and RD Doweli. UNION OIL CO. OF CALIFORNIA ""':'.".' ' '-- '" - - REPAIR RECORD ' LEASE Kenai unit .WELL NO 14-4 CONTRACTOR- Brinkerhoff Riq FIELD Kenai Gas Field TYPE UNIT :.EG~: 6/10/81 COMPLETED: 6/22/81 ELEVATIONS: GROUND 6o-3 CASZNG HEAD ~ERMIT NO. .S~L NO. ~! STAT :OMPANY EN~NEE' '.~h -' Pharr- _, _ / TUBING HEAD -~PPROVED ~~~~'~~~~' ROTARY DRIVE BU~ " /-- // '" LZ 3/4" 1069' 42~ ~. 'H-80 [ See previous history 7" 5~02' ._ 23~, 26.~ ~S-95.._&-5.~ see previous history .. - . ...... 2 7/8" 4159' 6.4g ~-80 ~kr Set at 4148' ~' , PERFORATTNG RECORD DAT~. INTERVAL E.T.D. REASON PRESENT coNDITION . , ~/17/81 4194'-4250 '4289 ' prOduction Treated· w/ll, 000 gal', :-O..'3M. OH-AL· (B~.i' snd) ' ." . · - , ."..,: · . " Sanded up, currently S..I ;' ' r . . · · · . · · · . ~IAL PRODU( DATE I INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR BEMARKI~ · . . ' . . · . . · .. · ., --'" ~:." ' ';": i' .. '".~'::'?:'..?' "':~)[":::7:?i ."....':(..::if ..-.'i i.'..';.~ ' ~...,.':.:.- .;' .'?':':.':".'.'.. ' ,.' .:i: ':. :(..':': ./::: i ¢:. i'-'? /..'' :' i: i i :' .' i .i" . ' ' : . '" '''~''' . '." ' ;'2' ;"' . ':.' ,'~:/.' ',:s: , . . . ' " : " '.?':i : '..).";.' '~' '"~ ' '" ~"'"":'"~" :" .... ' '" : : . · , .... - : .... . ,, · ,,. . , ., ,.',~, : ::-.. .... · ':- 7% ' _'ii'-'' .-.',:' ,.i',"... ~- ". · : '.'.., :. ..'.' ' ' ':.: ,.,',:::.~,, ' .. ',,:-."...;.;. ~. ' · . ':-'" '.J.~:?i'~':'i ' · ': .:J:"~:'/ · ' ~'.L.' : d, -:'j::,:'~, '.": '" ': .'. · '';L ,'' . · ' '., ~,.',' '-"': ?.'; ",-r,...;~:.' '. '' - ' . !:.":,"Jif ~" .':'"!'")": 7. [ ~D:.," ':';' ;',". '. ;', . . ' ' .'":/,:. '.u.,. i -¢>'.,'"."'-. :.,'.~,':.';~ '~,~.' :. :.'~:.';::![j/~?.f.'¢.?.:,.; '.. · ' ,-' ', : · ;.;.... · ',.... (,, ,,b .." .~ ~, ::'~[':~: "":")~ ¢;:"'-~ .'~ :' - -,~:' ;';';')!':' * ;' ??"-"i: :: Y* ,, '" "." ":¢ ~ ~' ' .' · - . .-, ' . .".' i , ! ; ' ' ..: ...,:,,:.;..-..'"":"':": ......;;:':'"."?::?":';":"~':;'::*"'-,.:...,...,,: .,;,~, ..:......,.~ ."~'; ...... .- -- "-': '-:-' '- WELL HISTORY PRIOR TO REPAIR ' '""' ..... "'" ' "" ..... ...... .. , ,.. -., .....:..,~ .... :',~..,..: ...,..:,~:.;..: ..~..... , ;.~.,..:...':,...- .... :?-< .... '.,..~...,- .. . ......... ~..: ........ -.. , ~.-,..-..._. .... ...~,.:~:;:,,..:'.:~.!.?,:.:.~;;..k,~.fi.!;/:;:,!/.~- ~. : : . . .~ .. ., ;OMPLETION DATE: B-1 Sand 4194.% -4250 ' - ...-.; ,- ...... . ..... '. '., ..... ' ........'"' "-~.' ...... ' ..... ;'"':'~::"' ?RODUCING ZNTERVAL: . "... -. .~ · . ., ~: -.. :NITIAL PRODUCTION' ., ', . ..:,, : ..; , , , ,,- · ,- · ,~.. , ,:,: ~ .....;. (-f .?.f,! '_ ,._ -.'-. f .." .. . '-F'.' ': , :. '. . LAST REGULAR PROD. & DATE: ........ ' ....... '":?""¥:'""' .......... ~ ,:. ~[ ~;-:,-,-., . ., . ~ .~ . :-,..,~ ~,~? .7.:.-<.¢ . -1-~, ~,.,.. ,- ~ -.. ,~,' :f:-,. . . ~UMULATIVE PRODUCTION: ' ' "' .{EASON FOR REPAIR: Clean out sand, reperf B-1 sand & treat W_fOH-AL U[1IOI.I OIL Ca;PAra' OF C LIFORJ.iIA ~ELL RECORD S~:EET D PAGE ilO, LEASE A 0~.80~7 DATE ETD NEll l~lO, 14-4 FIELD Kenai Ga~ Field .DETAILS OF OPEP~TIO[IS, DESCRIPTIQ;,!S ,& RESULTS Frc~ 4159.34 4158.32 4147.92 '4146.86 4146.05 4114.22 · 4111.31 43.04 41.31 19.05 18.05 4158.32 4147.92 41~6.86 4146.05 4114.22 4111.31 43.04 41.31 19.05 18.05 1.02 %10.40 1~06 .81 '31.83 .2.91 4068.27 1.73 22.26 1.00 ~ing Detail '. JT~s Description Baker Mule Shoe Baker Model "D" Pkr. & Seal Assy. Baker Model "G-22" Tbg. Locator XO '1 2 7/8" 6.4~ N-80 Butt. .. Baker "L" Sliding Sleeve 133 2 7/8" 6.4# N-80 Butt. Otis "X" Nipple 5 2 7/8" 6.4# N-80 Butt. Pups Shaffer Tbg. Hngr. (8rd pin x Butt. Pin XO) Landed Below K.B. UiiIOI-I OIL Ca?/ F CF CALIFOPJ.iIA ELL RECORD LEASE DATE 6/10/81 DAILY COST: ACC COST: AFE AMT' 2 6/11/81 DAILY COST- ACC COST: AFE AMT- 3 6/12/81 DAILY COST: ACC COST: AFE AMT- 4 6/13/81 DAILY COST: ACC COST- AFE AMT- 5 6/14/8l DAILY COST: ACC COST: AFE AMT- ' A-028047 ETD 125' TD 322' TED (Cmt) 1 3/4" C. 1069' "C. 5102' .16,424 16,424 460,000 5125' TD 4322' ETD (Cmt) ll 3/4" C. 1069' 7" C. 51 O2' 68 PCF 30 SEC $ 27,842 $ 44,26~ $ 460,000 5125' TD 4216' ETD · (Pkr) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 50,439 $ 97,489 -.. $ 460,000 - 5125' TD 4216' ETD (Pkr) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 16,720 $ 114,209 $ 460,00O 5125' TD 4216' ETD (Pkr) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 16,720 $ 130,929 $ 460,000 ~LI_ NO, KU #14-4 FIELD KENAI GAS FIELD DETAILS OF OPERAT/_OIIS, DESCRIPTIO_~!S &,RESULT, S Commenced operations @ 00:01 HRS. 6/10/81. Moved rig to Kt) #14-4 location. KU# 33-1 well .. test' 6.9 MMCFPD @ 950 PSI tubing. Rigged up, mixed 5% KCL WO fluid. Killed well, spotted 50 bbl pill of 2 ppb "xc" & 20 ppb bara- carb.across perfs to stop lost circ. Installed 10" 5M BOPE on 12" 3M x 6" 3M tbg spool. Tested BOPE to 3M psi (Note: 24 hrs testing & repairing BOPE). Pulled · lOM# over tbg wt & set slips. Rotated seal assy out of pkr. Pulled & laid down 2 7/8" tbg. RIH w/ 6" PRT mill w/ 3 1/4" PRT grapple. Tagged pkr @ 4187' & attempt to sting into pkr w/ PRT grapple - could not enter pkr. POOH. Found PRT g. rapple fouled w/ sand. RIH w/ 6" x 4 3/4" BO shoe #1. Milled on pkr @ 4187'. Pkr moved down hole to 4196' POOH. RIH w/ BO shoe #2 w/ 3 1/4" ~RT grapple. Pushed pkr down hole to 4216'. Milled on pkr. · o Ui'IIOI.l OIL C[I'?A h' 'CALIFORHIA ELL SI.:EE7 D PAaE ih, --- z LEASE A-028047 DATE 6 6/15/81 DAILY COST' ACC COST' AFE AMT' 7 6/16/81 DAILY COST- ACC COST: AFE AMT: 8 6/17/81 DAILY COST: ACC COST: AFE AMT: 6/18/81 DAILY COST' ACC COST' AFE AMT: 10 6/19/81 DAILY COST' ACC COST' AFE AMT- ETD 5125' TD · 4225' ETD (Fill) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 39,838 $ 167,983 $ 460,000 5125' TD 4289' ETD (Junk) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC .$ 20,623 $ 188,606 $ 460,000 5125' TD 4289' ETD (Junk) 11 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 44,982 $ 233,588 $ 460,000 5125' TD 4289' ETD (Junk) ll 3/4" C. 1069' 7" C. 5102' 68 PCF 30 SEC $ 57,089 $ 290,677 $ 460,000 ,. 5125' TD 4289 ETD (Junk) ll 3/4" C. 1069' 7" C. 5102' $ 69,740 $ '343,697 $ 460,000 ~LL [~0, KU #14-4 FIELD KENAI GAS FIELD DETAILS ..OF OPERATIOItS, DESCRIPTIO~!S &RESULTS · POOH. Recovered top p~r mandrel on PRT spear. RIH w/ BO shoe #3.' Milled'on pkr @ 4216' Pkr moved down hole to 4225'. Swept hole w/ ~0 bbl 80 sec pill. POOH. No recovery. RIH w/ PRT mill w/ PRT spear dressed with 3 1/4" grapple. Circ into pkr @ 4225'. Pulled pkr loose w/ 35M# over PU wt. POOH. Rec entire pkr. RIH w/ 6" bit & 7" scrpr. CO fill f/ 4250' to 4289'. Trip for junk mill. Mill up junk @ 4289'. POOH. Ran Schlumberger FDC-CNL-GR f/ 4287' WLTD to 3000'. Perfed the B-1 sand F/ 4194' to 4250' W/ Schlumberger 4" carriers W/ 4 HPF. RIH & set RTTS @ 4134' W/ tail to 4234'. Tested all lines to 3M psi. Dowell pumped 1000 gal. 5% HCL, 350 gal. 5% KCL, 11000 gal..3 molar OH-AL & 12000 gal. fresh water. Displ.aced 11000 gal. of last stage out tool. Pumped all stages @ 2 BPM, had 1400 psi on first stage, all other stages pumped @ lO00 psi. NOW- Shut in for 24 hours. Wait on OH-AL treatment. Released tool & spot 25 bbl, suspended salt pill on btm. Set Baker model "D" pkr on DP @ 4150'. X-over above pkr to pkr fluid. Laid down DP. Ran 2 7/8" prod string. Landed tbg w/ MS @ 4159', "L" sleeve @ 4111' & "X" nipple @ 41'. Ran tbg dry w/ equalizing plugs in both the "L" & "X". Tested annulus between tbg hanger & pkr to 2000 psi. U[IIOIt OIL CO[?A~h' OF CALIFOR~.~IA ELL RECORD S~;~--T D 'PAGE ;b. -" 3 LEASE A-028047 DATE 11 6/20/81 DAILY COST: ACC COST- AFE AMT' 12 6/21/81 DAILY COST' ACC COST: AFE AMT' -13 6/22/81 DAILY COST- ACC COST- AFE AMT' ETD 5125' TD 4289 ETD (Junk) ll 3/4" C. 1069' 7" C. 5102' $ 19,182 $ 362,879 $ 460,000 5125' TD 4289 ETD (Junk) ll 3/4" C. 1069' 7" C. 5102' $ 21,012 $ 383,89! $ 460,000 5125' TD 4280' ' ETD~ (Junk) ll 3/4" C. 1069' 7" C. 5102' $ 16,192 $ 416,803 $ 460,000 1.ELL NO. ~,, ~.-4 FIELD KE~AI GAS FTFLD OF OPERATIO[tS, DESCRIpTIOI!S ~ RESULTS Removed BOPE, installed &-tested tree to 3000 psi. Pulled plugs f/ "X" @ 41' & "L'! @ 4111'. Swabbed well f/~140' to 1000' & fluid level remained @ 1000' & fluid level remained @ 1000' during last 16 hrs of swabbing. Total' rec 130 bbls (i.e. 100 bbls producer thru perfs). Note: Annulus remained full during swabbing. Rigged down Otis swabbing unit. Rigged down rig. Rigged down rig & moved to KU #21-5. Released rig to KU #21-5 AFE #311106 @ 24'00 hrs 6/22/81. , % _1 ~11 ii i iii III I / , I 14'4 1 41' Otis "X" Nipple 1069' 11 3/4" c. 4111' Baker "L" Sliding Sleeve 4147 ' Locator Sub 4148' Baker Model "D" Pkr. w/Seal Ass'y' 4159 ' Mule Shoe cmt ret 4500' cmt ret 5043' 5102' 7" c. ....... _ m I' I Il mi' _ .Well~ Schematic 14-4 Kenai Gas Field ii m~l u ii I Il UNION OIL. COMPANY OF. CALIFOt',NIA i AtI~'D. SC, ALE 0^~ 6-22-81 .... Il I I I II SHEETS i ii i i i i i iiiii ii i i · - Sq'ATE OF ALASKA --"~ ALASKA ~,L AND GAS CONSERVATION C'_.,iMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] "~ DRILLING WELL [] · 2. Name of Operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 COMPLETED WELL Location of Well 1177.03'N & 4489.35'W from the SE corner, Sec. 4, T4N, RllW, SM. 7. Permit No. 60-31 8. APl Number 50- 733-I 0087 9, Unit or Lease Name KENAI UNIT 10. Well Number KU 14-4 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. __ KB !04~6-' A-028047 KENAI GAS FIELD 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ;-- NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations X~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made X~ Other [] Pull Tubing [] Other [] Pulling Tubing X~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In order to pull tubing, clean out sand, treat with OH-AL and recomplete well KU #14-4, it was necessary to perform the following work' (See attached) Sig e DIST. DRLG, SUPT. elow for Commission use ~,.n~tio ns ~ ~ ~- ~ RECEIVED JUL 0 2 1981 Alaska 011 & Gas Cons. Comm. iadt)ll DStel 7/1/8l By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ENHANCED RECOVERY ENDICOTT FIELD ENDICOTT POOL FIELD TOTAL GRANITE POINT FIELD MIDDLE KENAI POOL FIELD TOTAL KUPARUK RIVER FIELD KUPARUK RIVER POOL FIELD TOTAL MCARTHUR RIVER FIELD HEMLOOK POOL MIDDLE KENAI G POOL WEST FORELAND POOL FIELD TOTAL MIDDLE GROUND SHOAL FIELD B C AND D POOL E F AND G POOL FIELD TOTAL PRUDHOE BAY FIELD LISBURNE POOL PRUDHOE POOL FIELD TOTAL SWANSON RIVER FIELD HEMLOCK POOL FIELD TOTAL TOTAL ACTIVE FIELDS DAILY AVERAGE ALASKA ENHANCED RECOVERY AND DISPOSAL PROJECTS FOR DECEMBER, 1987 OIL WATER GAS INJ. CUM OIL (BBL) mmm(BBL) (MCF) WELLS (BBL) 2,604,268 2 21,036 2,604,268 2 21,036# 329,013 12 329,013 12 21,114,202 8,401,557 208 21,114,202 8,401,557 208 2,318,603 16 116,002 q 9,q70 1 2,h4q,075 21 57,152 2 390,546 15 447,698 17 6,551,831 3 35,193,412 108,227,590 133 13,012,875 35,193,412 11h,779,421 136 13,012,875' 7,726,429 7 _ 7.726.4~9 7 59,528,q00 133,511,675 403 13,033,911* 1,920,270 4,306,828 INACTIVE O ALL FIELDS 13,033,911' DISPOSAL PROJECTS ENDICOTT FIELD UNDEFINED ZONE FIELD TOTAL KENAI FIELD UNDEFINED ZONE ,.. I~JD STERLING 4 POOL ~- FIELD TOTAL KUPARUK RIVER FIELD CRETACIOUS UNDEF ZONE FIELD TOTAL PRUDHOE BAY FIELD UNDEFINED ZONE FIELD TOTAL SWANSON RIVER FIELD UNDEFINED ZONE FIELD TOTAL TOTAL ACTIVE FIELDS DAILY AVERAGE CUM WATER , {BBL) · 1 1 129,337,612 129,337,612 370,269,607 370,269,607 856,803,607 31,220,482 9,47O 888,033,559 26,123,728 226,182,695 258,102,362 337,626 1,505,896,682 1,506,234,308 8,337,995 8.337.995 3,160,315,444 127.512.325 3,287,827,769 FLUIDS DISP. CUM FLUIDS ...(BBL) WELLS (B~L) 127,197 2 127,197 2 2,009~ ~x 1 11,917 -- ~,~, 1 13,926 2 21,397 2 21,397 2 2,044,516 9 2,044,516 9 ~ eFLUIDS RETURNED TO RESERVOIR, NOT ENHANCED RECOVERY 322,691 322,691 210,696 79,191 289,887 2,494,817 2,494,817 124,500,796 124,500,796 200,752 4 1,744,452 200,7~2 q 1..74q.452 2,407,788 19 129,352.643 77,670 INACTIVE 43,475 ALL FIELDS 129,396,118 CUM OAS , (MCF), 5,615,130 5,615,130 369,578,116 369,578,116 56,741,269 6,962,065,416 7,018,806,685 2,014,875,361 2.014.875.361 9,408,875,292 74~,~88 9,409,619,280 ill + LEASE NO. IDISPOSAL PROJECT COHP.DATE ALASKA INDIVIDUAL HELL PRODUCTION FOR 1987 YEAR STATUS PRODUCT JAN FEB MAR ~~ KENAI, STERLING 4 --- UNION OIL CO OF CALIFORNIA KENAI UNIT 14-4 API UNIT051120 OIL 11/21/60 FLDS HDSPL GAS APR MAY 155-10087-00 JUN JUL AUG SEP OCT NOV DEC TOTAL 27757 5890 9452 7045 8079 11095 11917 79191 CUM. 79191 OPERATOR TOTALS UNION OIL CO OF CALIFORNIA FLUIDS 27,757 9,452 8,079 11,917 5,890 7,045 11,095 79,191 POOL KENAI, STERLING TOTALS FLUIDS 27,7~7 3,890 9,452 8,079 11,917 79,191 7,045 11,095 79,191 FIELD KENAI TOTALS FLUIDS 18,0q8 19,912 52,102 11,006 18,259 19,685 56,197 7,515 9,906 15,926 8,617 15,558 208,707 289,887 iii LEASE NO. IDISPOSAL PROJECT I ~COHL. DATE + ~ STATUS PRODUCT JAN FEB NAR ALASKA INDIVIDUAL HELL PRODUCTION FOR 1987 APR HAY JUN JUL AUG SEP OCT NOV DEC YEAR TOTAL CUM. ~~ KENAI, UNDEFINED UNION OIL CO OF CALIFORNIA KENAI UNIT HO I API 133-20345-00 UNIT051120 OIL 08/22/82 FLDS 18259 18048 19685 19912 56197 HDSPL GAS 4365 3623 1574 1574 1827 2465 2009 129516 210696 OPERATOR TOTALS UNION OIL CO OF CALIFORNIA FLUIDS 18,048 19,912 365 1,574 1,827 2,009 5,625 1,574 2,465 18,239 19,683 36,197 129,516 POOL TOTALS KENAI, UNDEFINED FLUIDS 18,048 19,912 18,239 19,685 36,197 4,565 1,574 1,827 2,009 210,696 3,623 1,574 2,465 129,516 III Sundry Notice 2 KU 14-4 PROCEDURE: 1. Move rig over KU #14-4 and rig up. 2. Kill well, install BPV, remove tree, install and test BOPE. 3. Pull and lay down existing 2 7/8" tubing. 4. Mill over and recover Baker model "N" pkr @ 4182'. 5. ~Clean out to +4289' ETD w/ 6', bit & 7" csg scraper. 6. Run FDC-CNL-GR w/ CCL log f/ ETD to +_3000'. 7. Reperf the B-1 sand w/ 4" csg guns. 8. Treat B-1 perfs w/ OH-AL thru RTTS @ 4200'. 9. Set Baker model "D" packer @ 4170'. 10. Run single 2 7/8" completion tubing assembly to 4180'. Displace annulus w/ packer fluid prior to landing tubing. 11. Remove BOPE, install and test tree. 12. Place well on produCtion and move out. RECEIVED J U L 0 2 1981 Oil & G~ Cons. CommL~,/ml Al~horage ~ STATE OF ALASKA ~ ALASK; )IL AND GAS CONSERVATION C ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] C.OMPLETED WELL [] OTHER [] 2. Name of Operator UNTON 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well 1177.03'N & 4489.35'W from the SE corner, Sec. 4, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) KB 104.6' I 6 . Lease Designation and Serial No. A-028047 12. 7, Permit No. 60-31 8. APl Number 5°-133-1 0087 .. 9. Unit or Lease Name KENAI UNIT 10. Well Number KU 14-4 11. Field and Pool KENAI GAS FIELD Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing E] Stimulate [] Abandon [] Stimulation [] Abandonment I-~ Repair Welt ~ Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 3. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170).. In order to pull tubing, clean out sand, treat with OH-AL and recomplete well KU #14-4, it will be necessary to perform the following work' (See attached) RECEIVED MAy 2 1 1981 A/aska Oil & Gas Cons. Commission AnChorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed h'L~ ~., 0~)0~:~,~,. ~ (~Sg Title Dist. Drlg. Supt. The space~elow for Commission use ~' (] Date 5/20/8] Conditions of Approval, if any: Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Sundry Notice 2 KU 14-4 PROCEDURE: 1. Move rig over KU #14-4 and rig up. 2. Kill well, install BPV, remove tree, install and test BOPE. 3. Pull and lay down existing 2 7/8" tubing. 4. Mill over and recover Baker model "N" pkr @ 4182'. 5. Clean out to +4322' ETD w/ 6" bit & 7" csg scraper. 6. Treat B-3 perfs w/ OH-AL thru RTTS @ 4200'. 7. Set Baker model "D" packer @ 4170'. 8. Run single 2 7/8" completion tubing assembly to 4180'. Displace annulus w/ packer fluid prior to landing tubing. 9. Remove BOPE, install and test tree. 10. Reperf the B-3 sand w/ 2 1/8" Enerjet guns. 11. Place well on 'production and move out. RECEIVED MAY 2 1 Naska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~.~, AND GAS CONSERVATION COMMITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT )lultt-POINT T'EST Test Inl,i-'*l D Annual D Special Field I Reservoir Kenai Gas Field Pool 4 iTes: Date .,5,27-76 Oporator I Lease Union 0il C.om. pany of California A-028047 cuun:r I Loc,ti,,n 1177' N & 4489' W from SE Corner, Kenai ! Sec. 4, T4N, Rl lW, S.M. Completion 1-21-60 %%'~11 No. KU 14-4 Total Depth J T/Pay 51 55 ! 62 T.o. I cso. Tcmptr~.ture Tcrnpe;~ture X 9~ 'F 56 '~ 7" 23 2 7/8" 6.4~ 2.875 · 2.441 & 26// 6.366&6.27 5102' Oa~.Liq,,td H~dr:¢ar~e,~ I Gri~',",' of R:,tio MfF per Bbl.i Llqu:d ,ipi~ , Pipeline Connection Kenai - Nikiski Pipeline Multiple Completion (Dual or Tripl~) __ Single jType Taps Flanqe Type production front each zone Gas OBSERVED DA. TA Flow Data Time j (Prover) of Flow I (Line) Hours J Size (Choke) (Orifice) Size J 3.826 Press. DiflL h psig w sT , j t 2.5 3.826 ! ~.826 t Tubing Press. psig 1175 , ,, .,]]75 t J 1.96 ~ i 5.76 i 1i50 J 2.5 j , 10.8~ j 1125 .j 2.5 I I 29'16 -J 1075 ,,J FLOW CALCULATIONS Casing i Flowin.~ Press. Temp. pslg I 'F 70° 70o 700 70° J Coel~I- 1~o. cient · (24 Hr.) ~. I 34. 147 · ~. ! 3..4. !47 , 4. J 3,,4,.147. , 48.29 81.922. 111.42 178.28 I Pressure Factor Factor Factor psla F. 'F F t . g pv 11~0 i' ..9905 I 1.3423 J 1.0921 1165. ! .9905 . ! 1.3423 I 1.0902 1140 J .9905 J 1.3423. J 1.0884 J .9905 J 1.34.2} Rate of Flow Q 3ICF D 2184 3698._~ 5022 1090 J 1.0846 8007. PRE.'~$t'HE CALCULATIONS w Ca 1. w 'I, - (psla) P: F Q (F q): (F Q): X 1-e's P: P~ -- P= ' P ' t c c e w ~ W w P ! ¢ Ahs-lute Potential 2}.,200. .~w~','p ! ' .5863 CZRTI~ICAtE: I. ,he ,nders~ed. st,,,e that : ~m ,a, engineer o~ m, gnion 0i 1 Company (company). and ~at I am au~or~ed by said comply to make ~ls report: and ~at this report was pre. . pared under my su~rvision and direction and that ~e fac~ stated th~e~ are true, correct ~d complete to ~e best of my ~owledge. _~ ~ ~~ S~ature "Gary/E. Carlson .o GA?"~-..:LL OPEN FLOW POTENTIAL TEST R"-'""~RT · PRESSURE C^LCULAT IONS (Supplement to Alaska'O & GCC Form No. G-I) Field Reservol. r Tesl ~ato Kenai Gas Field Pool 4 5-27-7 ~Operator Lease Well Union Oil .Company of California A-028047 ..... KU 14-4 (I) (2) (3) (4) Test ps Pf (Ps2- Pr2) Q No. Dsia ~sia X I04 !'.'~C~/D _ · 1 1190 1190 -O-,, ., 2184 2 1190 1165 5.89 3698 '3 11~0 1140 11.65 5022 , 4 1190 1090 22.80 8007 L Sub-Surface Test Data [---] Subsurface pressures measured. 1----] S~bsurface pressures computed: 'Cullender-Smith :.~ethod of ICCC. (I) (2) (3) (4) Test Pws 0 ' (Pws2-pw~2) Q No. nsia psia X 10-4 ¥CF/O _ ,. · ., ! · Nomenc I ature: Ps = Static surface pressure '~f~.= Flowing surface pressure . Pws ='Static bottom-hole pressure (mid-point of perforations) Pwf = Flowing bottom-hole pressure (mid-point of perforations) Q = Flow rate, MCF per day'at 60°F and 14.65 psia 1-70 , Kenai Gas Field Back Pr~'~~. Tests Well: Pool: Survey Date: 5-27-76 1.0 f · 02 ; : //. .! 10 20 50 GAS FLOW RATE ~.~CF/D UNION OIL CO. OF CAI, IFORNIA ALASKA DISTRICT Transmittal TO: Tom Marshall DATE: FROM: E.H. East WELL NAME: Transmitted herewith are the following: Run No. Sepia Blue Scale Induction Electrical Log Dual Induction Laterolog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/ Caliper/Gamma Ray Log Formation Sonic Log (Fs) Density-Gamma Log -~ Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) CDM or ttigh Resolution Dipmeter CDM Safety Print CDbl or Printout CD~4 or Polywog Plot CDM Polar'.-Plots Proximity-~icrolog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log --I-'~a. --- M~dlog Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Core Chips Sample Cut Drill Stem Test Directional Surveys April 1, 1969 KU 14-4; KU 34-31 RECEIVED APR 1969 DIVISION OF OIL AND Receipt a~kno~,ledg~d: .g-/-f~-~.) ?_~. - Date' ~ .... ,~",:~ q; Return receip2 to: Union Oil Co. of California, 280.5 Denal. i St.. Anchorage, Alaska Rochelle Cattton 99503 Form ST.6~ DF ALASKA S~B~ZT ZN ~mf ~* (Other in~tructio, ~n r~ OIL AND GAS CONSERVATION COMMISSIONverse side) - SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) O,L [2 oas ~] WELL WELL OTHER 2. NAME OF OPZaiT0a Unq n,~ O~'t .C, nm~n~'~r . 2809 Denali Street Anchorage ~ Alaska LOCATION OF WELL (Report location clearly and in accordance with any State requirements? See also space 17 below,) At surface 1177'N hh89'w from SE corner sec h, T~N, RllW, SM 14. PERMIT NO. 15. E~VATZONS (Show whether ~)~,' RT, OR, et~) RT 10~.1~ above S.L. 16. 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREE,MENT NAbIE Yan~i ITnit s. FAR.~I ca LEA~E NA~E WELL NO, --~-0. FIELD AND POOL~ OR WILDCAT _Kenai Gas Field~ 11. SEC,, T., a., M., 011 RLX. AND SVav~e O~ Sec. I~,T[iN, RllW.SM 12. BOROUGH .. 'J 18. STATE Kensi Penn.J Alaska Check Appropriate Box TO Indicate .Nature o1: Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE. COMPLETE SHOOT OR ACIDIZE ABANDON* REPAZR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* (Other) Production NoTE: Report results of multiple completion on ~ell ompletlon or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Cle~,rly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionall¥ drilled, l~ive subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * ~ .- Kenai Unit lh-h waS^placed on full time production in May, 1966. It is presently producing at 8-10 MzCF/D into the gas rental line delivering to the Swanson River Field. · SZO~D',/ fi(__../X'",v/-//J~[//f/-~."~ .... _.) TZTL~ Production Engineer D~T~ 8/29/66 (This space for Federal o~ Sta~e ofl~ce use) CONDITIONS O~/AI~[~R6VAL, IF ANY: *See Instruction, on Rever, e Side C. A. WIRE LA'VE WELL SERVICE 2~.~5-- PHONE~-5264 CASPER. WYOMING P. O, BOX 1.56 Operator Company Union Oil Co~any Location Lease Kenai Gas well No. 14--¢ Field County Kenai State K.U. !g-4 File Kenai Gas A!ask& Formation Kenai Date of test July 13-!5~ [i966 FLOWING BOTTOM HOLE PRESSURE TEST Depth j Pressure Grc~lient feetj PSi, ga. PSl/ft ..... Flow 4228 1844 1/2 bt". 1841 1 hr. i Rat( 1834 2 " 2 " 1831 3" 3" 1822 4 " 4 " 1810 6 " 5 " !, i Shut In ! 4228 ! 184! i hr. I 1841 2 " 1841 4 " 1843 6 " 1848 12" 1850 18" !850 24" 1850 30 '" 1850 36" i850 gl½ hr. 4282 Plug 4178 Otis "S" Nipple 4166 Otis Sid ~door I REC '.IVED : 1 2 1966 OiViSlO~ o~ M'~ ~S & MINa~,LS Summary . March 19 66 On variable Choke Well flowing since Rate _ b/d ~,-8 ],,~,( cu ft/d Casing pressure 1667 P¢I Tubing pressure 1667 .PSI Flowing temperature I ' 98 OF at ]<228 feet Meosuremenfs Reference point for measurements N.B. 121 Zero level: Grd ( ) DF ( ) Tby hd gate ( ) Other (If) KB Distance from reference point to zero plus ( ) minus ( ) Pressures are (x) are not ( ) corrected to zero level Elev'. Grd DF DB Other KB-104 Completion details Casing set 5102 feet Size 7 inches perf. 4200t to ~2~6t Liner -- Tubing set feet Size 2 ?/8 inches BH Ch. Packer 4182' P'in-p'lug -- Last flowing pressure -- Last rate · - b/d Last productivity index Last open flow potential History PSi at ' -- on - cu Ft/d - b/d/P'SI _ cu ft/d Produc t ivl ty Static pressure used PSI at ft Flowing pressure PSI at ft Pressure drop Rate b/d cu I:t/d Productivity index '"b/d/PS I Open flow potentia't 8?tO00t000cu ft/d ,. Reservoir Data Name of pay zone Module 4.B-~an~epths 4200 to 4262 Gravity of produced fluid __'~ °API--- Gravity of produced gas 0.557 Remarks Type Instrurnont Kuster No. /¢904-N , Run by Kuster Calculated by Kuster Lost calibration data Chocked by Kuster 3 3 4 5 6 7 8 9~0 AUG ! DIVISION OF MINES & MIINI~I~AL~ - ANCHORAGE 2O 30 40 5O 6O 70 8097.OLC0 4 5 6 7 8 9102..' GAS ~LL OPEN FLOW POTENTIAL TEST, ORT 4-POINT TEST Test Initial ~ Annual D Special Field Reservoir Set @ ~,. SLOP,' oas o~.av!t~ Ave. Prod, j '~' "{ '2355 Test Date 1T,'ell No. Total Depth [ T/Pay { Producing $lSS' 6~' I Sl' o_men Gas-Liquid H).drocarbon Gravity of Ratio MCF per Bbl. Liquid (Apt) , ,, Multiple Completion (Dual or Triple) l Type production from each zone ..... o ~ si~,i~vE ~:ij×~:,,_ ....... Time (Prover) (Choke) Press, . . ' · Diff, · T.ubing Casing Flowing No. of Flow (Line) (Orifice) ' h Press, Press. Temp. Hours Size Size Psig w psig - psig -~ ·F s, 1~6 ,.. ~,..-. a-s-'.-~:" ~' -e.o~' "' ~z~'*~ .,i'~. 'l~f FLOIV CALCULATIONS . . Coeffi- ' Flow Temp. Gravity Compress. ' cient ----~/h p Pressure Factor Factor Factor Rate of Flow (24 Hr.)V w m PsJa Ft Fg ,' Fpw · Q MCF/D, · O~.~. ' ts,'.~' i~~ i.~I, t.a~, ~ 'z..~a~ 4,~t ~,la ~.~m t~ ',.~' x.,mm :~--,' t.~~- .m+m~ PRESSURE CALCULtTIONS ~ ~ ~' _ w 1~ F Q (F Q): (F Q)2 X 1-e's p2 pa _ p, Cal. w p (Psia) :t c c c %v o w P . - ,, w P t c , 2. 4. , , C'ERT FICATE: T, the undersigned, state that l' 'am th . company tO make this report; and that/tgls report was pre- (company), and that I am authorized by said pared under my supervision .and direction and that the f.a.cts stated theft;e/ii/are transect and complete to Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4.Po/hr Test) Form No. G-1 Authorized by Order No. 1 Effective October 1, 1958 Field Operator County Location GAS "ELL OPEN FLOW POTENTIAL TEST , ~)RT 4-POINT TEST Test Initial [~] Annual [~] Special Reservoir Lease Completion Date .. Total Depth Test Date JWell Xo, 'T~Pay Producing Interval Producin~ Thru [ Reservoir ] Wellhead! CSG. Size [ %Vt/Ft. [ LD, JSet@ TBG. [ CSG. Temperature · Temperature TBG.' Size ~Wt/Ft. J O.D. I.D. Set ~ ~as Gravity Avg, Prod. - ' - - (-Separator) Length [ GL [ Gas-Liquid H~.drocarbon Ratio Mcr per Bbl. Gravity of Liquid (Apt) o pipeline Connection [ Type Taps ..... . · , . -': ~, 'ii;i; , ~ _;__ . [ Multiple Completion (Dual or Triple) [ Type production from each zone ' ' ' OBS~RYED ~A~-~' '" Time (Prover) (Choke) ,~ - Press. ~. Diff-, , -Tubing Casing . Flowing .~o. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig w '-'pslg -' PstlI *F SI 3. ' ' ~ '' .... ; , FLOIV CALCULATIONS Coeffi- Flow Temp.- Gravity Compress. --=-X /h p Pressure Factor Factor Factor Rate of Flow 1~1o. (24cientHn)~w m psia Ft Fg . F. pv Q MCF/D. · , · ~ . . , : '. ¥ · . .. ..,. [.. . ,' . · . ~ · 4. .. . , , ~.,,.,.~. u ..... ~ _-",i. PRESST:RE CALCULATIONS ~ *~ P Cal. 'w p= F Q (F Q)' (F Q)2 X 1-e-s P2 pn -- ps p .p ., (psla) :t c c c ~v . e -. ,w . w t ,., 1. ;" ' '~" ' ' ' ': " 2. , _ 4. ! Absolute Potential I n CERTIFICATE: Z, ~e ~dersi~ed, stat~ ~at I ~ the~~ of ~e (eomp~), ~d ~at I am auto.ed by said comply to m~e ~s ~o~; ~d~at ~ repo~ was pre- p~ed ~der my super~sion ~d direc~°n ~d ~~ that me facts stated t are e~-~~mplete to ~e best of my ~owle~e. "~~~ ~ !966 plV~S~ON OF M~N~S & MIN5~ ANcHO~GE Alaska Off and Gas Conservation Commission Gas Well Open Flow Potential :Pest Report (4.Po/at :I'est) Form No. G-1 Authorized, by Order No. I Effective October 1, 1958 FORM SA-1 B 100M 9/65 MEMORANDUM TO: [Thomas &. ~larsha11, Jrt7 Petroleum Supervisor FROM.O,, I(. gilbreth, Jr. Petroleum Engineer State of Alaska DIVISION OF MINES AND HIN~S DATE : SUBJECT: July 14, 1966 Field Trip Report, Kenai Unit Well #14-4 On Wednesday, July 13, 1966, I flew to Soldotna by Cordova Airlines and met ~lr. Elmer Kendall, Field Foreman for Union Oil. We drove to the Kenat Oas Field then to the dehydration unit for well #14-4. The meter run is located approximately two miles from the well across a swamp. Telephone communication was established and the subject well opened up at 11:30 a.m. at a rate of approximately 2 ~tCF per day. The following data were observed. Ti~_. Different.iai Static Temp. e~ature Field Est Q . 11:30 2.05 9.0 56° ' 2 12:24 2.98 8.85 56° 4 1:15 3.95 8.72 56° 6 2:06 4.85 8.68 56° 8 3:20 5.85 8.40 57° 10 We went to the office to await return of the dead-weight tester data as these measurements had been taken at the well head. While waiting, we were advised by phone that Cordova Airlines had canceled my return flight to 'Anchorage. We immediately left and went'to Kenai where I returned to Anchorage by PNA. Mr. Kendall will furnish the dead-wight tes~data by mail. Form P--3 (Do no Unic ~. ~DDR~J GL o thi~ ZUB~IT IN TF~'~'w%~.ATE, C"~her instruct. ~n r~- aide) .~:LLS proposals '~o dr~l or :o ,~cepen or plug bacL: c.> ._ different reservoir. "APPLICATIO!~ FO~: PER~iiT--" for such propo~::l~.) . .'%L "~ OTHER 3R Di).ffo. of Calif., Operator .... ena__~. St., Anchorage, Alaska 99503 .LL (i'~c~:org location clearly and in accordance with any State requirements.· 'l ~ .... 1 .7 below.) 1177.03'N and 4489.35' W from SE corner Sec. 4, T4N, RllW, SM. 14. PERMIT NO. 31 15. ELEVATIONS (Show whether DF, BT, RT 103. l' aoove S~ Kc ..... ~n 8. ~' xSE . 12. . "13. STz'~ K-::n ~: ~nn. Alaska 16. Appropriate Box T° ]ncica'~c .Naa'ute o~ Notice, Reporb or O~her ' . i<GTIC= OP INTENTION TO; MULTIPLE. COMPI,ETB ABANDON~ CHANGE PLANS SUBSEQUENT REPORT C.. WATER SHUT-OFF i;.2~IRINO WELL FRACTURE TREATMENT ._i'ERING CASING ._ SHOOTING OR ACIDIZING ~,..XDONM~NT* } X (otheO Gomgletion "~ NoT~: Report results or m:':. ''7 91etl,. ,, 97ell ompletion or Recomplet~on '-cl.,. Lo~ LCLIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent datc~, Incluuin.z . ,~ .ted da~e of star~inz ~roposed work. If well is directionally drilled, give subsurface loaations and measured and true vertical depths zo. _.. markers and zones nent to this work.) · . 2. 3. 4. · . :~oved in and rigged up. ::3hanged over from water to 75.5% mud. Removed Christmas tree. .[nstaiied and tested BOE. ~ul~_ed 2-7/8" tubing. .'et :~:erforated four 3/8" holes .per foot in the interval 4200-4210' Aah ~n and set 'Baker Model N-1 production packer at 4182'. Ghange over mud to fresh water. · Swabbed in well and unloaded tubing and annulus of water.. Shut well in. Rigged down and moved off. '~ E C ~J '!~.. ..,. \,/ '~'~ r, 4214-4256'. DIVISION C)/- Mtb.!E5 & M;N~.RAL$ ANCHORAGE 18. I hereby certz, that ~ foregoing ts true and corregt ~iG.NED ' ~' ' --' ~ '" /~'" ' ~' TITL~ Drillinq Engineer DATE April 28, 1965 APPROVED .. ~ ·---w , . TITLE ~ DATW, COZ~DITION~ ~ A:?::~OVAL, ~ A~Z: - ~NOT~..: Well will be tested aha put on producz~on when-fatalities a' July, 1965. instaliea Form P--3 STAT ;F ALASKA SVEMIT IN TRIP' rE* (Other instruction~ · re- OIL AND GAS CONSERVATION 'COMMISSION verse ~lde) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dieeerent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) E£fective: July 1, 1964 LEA8m DESIGNATION AND SERIAL NO. Fed. Lease ~A-028047 6. IF INDIAN, ALLOTTEE OR TRZBS NAME 1. 7. UNIT AGREEMENT NAME OIL [--~ GAS WELL k--] OT.ER Kenai Unit WELL 8. FARM OR rLEASE NAME 2, NAME OF OPERATOR Union Oil Co. of California 3. ADDRESS OF OPERATOR 2805 Denali St,., Anchorage, Alaska 99503 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece 1177.03' N and 4489.35' W from SE corner of Section 4, T4N, Ri1W, SM 15. ELEVATIONS (Show whether DF,-RT, GE, .et~) RT 103.1' above S.L. 14. PERMIT NO. 31 9. WELL NO, -' Kenai Unit 1~-4 10. FIELI~-AND POOL~ OR WILDCAT Ke, nai Gas Field 11. SEC., ~., B., M., OB BLE. AND SURYE~ OR' AREA Sec; 4, T4N, RllW, SM 12. BOROUGH -- '1 18. STATE KenaiI Alaska 16. Check Appropriate Box T° Indicate .Nature of Notice, Report, or .Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE. COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS (Other)Complete x SUBSEQUENT REPOR~ OF': WATER SHUT-OFF ~ REPAIRING. WELL' FRACTURE TREATMENT ALTERIN0 CASING SHOOTING OR ~CIDIZING ARANDON~ENT* (Other) NOTE:.Report results of multiple eomRleti0n on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including e~timated date or.starting any proposed work, If well is directionally drilled, ~ive subsurface locations and measured and true vertical depths for all markers aha zones perti- nent to this work.) * 1. Move in work-over rig and rig up. 2. Change over from water to 66-67% mud. 3. Remove Christmas tree and install ROE. 4. Pull 2- 7/8" EU tubing. ~ ~ ~ ! r~ - 5. Jet perforate interval from 4200-4260'. 6. Run in production packer on 2-7/8" EU tubing. 7. Change over mud to water and swab in production. * 8. Rig down and move off location. [21'¢!.:,I:Ui'-,~ OF .M!r'..:i [. ~.: ANCHOI~AGE Estimated starting date: 4-15-65. *Note: Well will be left standing idle until production facilities ar~ installed in July, 1.965. 3-Div. M&M, Anch., 1-USGS, Anch., 1-Standard, Anch., 1-Richfield, Anch., 1-File 2-Marathon, Anch. 1-RCH \ (This space for Federal or ~tate office TITLE Drilling Engineer DA~E March 10, 1965 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: ... TITLE DATE *See Inductions on Reverse Side Form 9-881~ (Feb. 1951) ~ .....~ '~ .... (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R358.4. Fozm Approved. SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO CHANGE.PLANS ............................. II SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING ..................... NOTICE OF INTENTION TO TEST WATER SHUT-OFF .............. I ......II SUBSEQUENT REPORT OF ALTERING CASING ....................... I'~{~" ,OT,= O~'N~N~'ON ~O,~N~O* *~. ...................... I ...... II ........................................................................ I ...... (INDICATE ABOVE: BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) ........................................................................ ~(.~.,, ,,. , .~~.:~,'* ~, ~1'~.,.'~ ~ ~~/~. frol~ine 4 - ~* ~0 ~e~]~*l~lO] ~: ~Z~ _ ~ .......... 15 IOCa[C~I , sec,. __U_:__LT_~. from__ lgl]ine and of ............ .................................................................................................................... ,18~o No.) . (Meridf~n) (Field). ~ . _ ...... (Oounty or Subdivision) (8tato or Territory) The elevation of the ~'~rl~'~a~ve sea level i$ ............ [.t~ ~. DETAILS OF 'WORK (State names of and expected depths to objective sands~ show sizes, weifhts~end ien&~he of proposed cadnp~ indicate mudding jobs, cement- ing points, and all other important proposed work) ~. ~~. "RECEIVED~ Divklon of Mines and Minerals ~dmko Dept. of Natural Resourc~ ! understand~ that this plan of Work must receive &pprov~i in writing b~ tho Geological ~urvey before operations may be commenced. Company ............................................................................................................................................... Ad&~s ___..~..' L~,~_~ .................... ~_..__~__.~__._/~_._~. .............. '~~:_~ .................... By ................... GPO 9 14974 l~or~t ~-881a (Feb. 1951) (SUBMIT. IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~'~'~ ,udder Bureau No. 42-R358.4. Fo~m Approved. JUNVI8 1962 SUNDRY NOTICES AND REPORTS ON WELJ~.m O~t~qn of Mtngs and Minerals NOTICE OF INTENTION TO DRILL ................................. J ...... SUBSEQUENT REPORT OF WAI'F_R ~.1~CI DI~J' O~ Natural- Re 0urr.4~ NOTICE OF INTENTION TO CHANGE.PLANS ....................... J ...... SUBSEQ'UENT REPOR; O-; SHOOT-------;N-~ OR AC-' -'' ,'l~;~;~.-_'_'.'_~j~ NOTlC£ or InTENT,ON TO TEST W^TER S.UT-O, .............. J ...... SUesE~ENT .£,ORT OF ALT~mNG C~NS ..................... ._J. NOT,C£ OF '.T~TION TO R~DmLL OR Ra'^m wm. ......... J__Z_ SU,SEQUENT R£mRT OF m'.-DRiU.,N~ OR R~P^,R .............. ..J. ..... NOTICE OF INTENTION TO SHOOT OR ACIDIZE .................. J ...... SUBSEQUENT REPORT OF ABANDONMENT ........................ ..J_ ..... NOTICE OF INTENTION TO PULL OR ALl'ER CASING .............. J_ ..... SUPPLEMENTARY WELL HISTORY ................................. ._J_ ..... NOTICE OF INTENTION TO ABANDON WELL ...................... J~ ..... (INDICATE: ABOVE BY CHECK MARK NATURE OF REPORT. NOTICE, OR OTHER DATA) /~ . ........................ ~_? ................................... ~9____".. ~-~~. V~.,~~-~ ..... ,~ ............ -~-t!~'- .......... ~m'~ .......... ........... ............ _ ...................... .............. The elewtion of the ~~:~bove ~ea level i~ __!~___ ft. DETAILS OF WORK ~ ~ ~. iii, · lng polnt~, and aH other important propoaed work) " p ' ~ rout rece~ve~E~p~'o~al In w~tl~ar' I~ the Goolofical ..urvoy before °peratl~ may be co~nmeneed. ~,~ ._F~-~~,~:~,-~.~ ........................................................................... .... .................. ................. A~qilIIIIB~il~,__, .............. By .................... Title __~_~ ................... GPO 914974 OPERA?OR. ~ELD. WELL _ . LOCATION ELEVATION DRILLING CONTRACTOR _ DRILUNG TOO.I~_ COMMENCED DRILLING STATUS C,OMPLET!O~ _REPORT_ Union Oil Company of .California, Operator Kenai Gas Held, Kenai Peninsula, ~aska Kenai Unit 14-4 / 1177. 03' North and 4489.34' West from the Southeast corner Section 4, T 4 N, R 11%V, SM 103. 1 R. T. 90.6 Ground LAND,, ,,,OFnC Anchorage 0 Alaska Federal Lease A-028047 Kenai Unit Coastal Drilling Company, Bakersfield, California Rotary - Erasco G$00 October 18, 1960 Shut In gas well COMPLETED -DRILLING Jl rI i . I [ November 21, 1960 Signed Title ........... Divl.~ion Geolooist ...... TOTAL DEPT.H,, CASIN, G, TUBING _ PLUGS SUMMARY . 5125' 20" conductor pipe at 6' 11-3/4" cemented at 1069' 7" cemented at 5102' 2-7/8" hung at 4296' 43'22'-4500' 5043'-5125' 2-1/2" holes per foot 4311-4320' ~LL. HISTORY Union Oil Company of California, Operator Kenai Unit 14-4 Section4, T4N, R 11 W, SM Page 2 October.;.18, ::1960 Spudded 1 A, M, Drilled 17-1/2" hole 0-124' with Smith 3-point hole opener, Drilled 12-1/4" hole 124-405'. Lost cirCulation around cement floor in cellar and between cellar walls. ~/Vaited on cement truck 8 hours. Octo~ber 19o..19.6.0 Pluq._No?.. 1 Welded plate over conductor pipe and cemented through conduc- tor pipe with 93 sacks Permanente cement, ' Good returns to cellar, Halli- burton, Stood cemented 5 hours, Pluq NO,._2. Cemented through conductor pipe with 35 sacks construction cement. C, I, P, 9 A, M, Halliburton, Felt top of plug 1 P, M,, O, K, Cleaned out, .Drilled 12-1/4" hole 405-468', Lost 5 hours fighting running gravel 3 75-460,, OCtOber 20. 1960~ Drilled 12-1/4" hole 468-1519', Opened 12-1/4" hole to 17-1/2" 124-'398' with Smith 3-point bit. October 21o_ 19~0 Opened 12-1/4" hole to 17-1/2" 398-1080'. Mud 844f, vis. 80. Pan 11-3/4" 42~f"H-40 8 rd. casing, cemented through Halliburton guide shoe at 1069' (13.8' below rotary table) with Halliburton float collar at 1031', using 1205 sax construction cement. Co I. P. 8:45 P.M. Halliburton. (Approximately 50 barrels of lost circulation during cementing). Casinq Detail I jt 2 7 its HOWCO guide shoe 42~ H-40 8 rd ST&C casing HOWCO Super Seal float collar 42~f H-40 8 rd 8T&C casing 1.00' 36, 25' 1, 66' 101.67...4,q' 1055, 31' l~enai Unit 14-4 Well History Page 3 October 22. 1960 Stood cemented, Installed BOE, tested BOP. and kelly cock with 1250% for 10 min., 'O.K. Drilled out float collar at 1031' , guide shoe at 1069' cement to 1170% October 23-October 26, 1960 . ~illed 9-7/8" hole 1519-4209', Circulated for core. Mud 76%-92%, vis. 50. .Core. No:.. jl 8-I/2" Reese drag head. 4209-4238°. Cut 29', recovered 0. 5' sandstone. October 2 7. 1960 Opened 8-1/2" hole to 9-7/8" 4209-4238'. Drilled 9-7/8" hole 4238-4335'. Circulated for core. Mud 95%, vis. 55, w. 1. 6. 2 c.c. Core No. 2 8-1/2" Reese rock head, 4335-4362'. 21' of sandstone, siltstone and lignite. Cored 27' recovered Dips 5o. Opened 8-1/2" hole to 9-7/8" 4335-4362'. Drilled 9'7/8" hole 4362-4380'. Circulated for core. October 28. 1960 CoreNo. ..... 3 8-1/2" Reese rock head. 4380-4395', cored 15' , recovered 15' . . _ sandstone. Ope.ed 8-1/2" hole to 9-7/8" 4380-4395'. Drilled 9-7/8" hole 4395-4456'. Circulated for core. Mud 959, vis. 60, w.l. 6.2 cc. Core No. 4 8-1/2" Reese rock head. 4456-4471', cored 15', recovered 13' · - ' ~ sandstone. Opened 8-1/2" hole to 9-7/8" 4456-4471% Drilled 9-7/8" hole 4471-4637'. Mud 95~f, vis. 50, w.l. 6 c.c. October 29_. 1960 Drilled 9-7/8" hole 4637-4842'. Circulated for core. Core No' 5 8-1/2" ~eese rock head. 4842-4857'. Cored 15', recovered 14' sandstone, siltstone and lignite. Dips 0-10°. Opened 8-1/2" hole to 9-7/8, 4842-485?% Drilled 9-7/8" hole to 4959% Kenai Unit 14-4 'Well Histor~ Page 4 Drilled 9-7/8" hole 4959-51'25'. Mud 95~, vis. 60, w.l. 5.1] c.c. Circulated for electric log. Measured out, ran Schlumberger Induction- Electrical Log, fa led to go below 4330'. Pulled out, cleaned out bridges 4240-4260' and 4325-4360'. Conditioned mud. Ran Schlumberger Induction- Electrical Log 5123-1071', Sonic Log 5123-1071'. November. 1. 1960 Ran Schlumberger Microlog 5123-3500', Continuous Dipmeter 5123-1071', and took 36 sidewall samples. Ran in with 3-point reamer and reamed tight hole, conditioned mud, !aid down 4-1/2" drill pipe add drill collars. Ran 5102' 7" 23# and 26~ S-95, N-80 and 1-55 casing. Had lost circula- tion while attempting to circulate casing. Cemented with 800 sacks Permanente construction cement. Had no returns during mixing or displacing cement. 7" casing was stuck during entire cement Job. Theoretical dis- placement 1108 cu. ft., actual displacement 1142 cu. ft. at 2100 psi. Cement in place 2:05 P.M. ,.. Nov. 1, 1960. HOWCO. Installed tubing head and landed casing' c'a' sin.~ Detail casing cemented at 5102' Baker Flexiflow shoe 1 it. 2 itS. 3 its. 13 itS. 31 its. 81 its. 1 it. 26~ S-95 8 rd ST&C casing Baker Flexlflow collar 26~ S-95 8 rd. ST&C casing 26~ N-80 8 rd. LT&C casing 26t~ 1-55 8 rd LT&C casing 26~ 1-55 8 rd ST&C casing 23~ 1-55 8 rd ST&C casing 26~ 1-55 8 rd ST&C casing , 12.8' below rotary table. 1.72' 48. 1.50' 70.10' 118.62' 520.48' 1326.30' 2984° 61 _ _ 17. 15 5102.03' Ran Schlumberger Temperature Survey, indicated top cement 3560'. Checked Flexlflow collar at 5050'. NQve...mbe.r.. 2. !960 Ran Schlumberger Neutron-Collar Log 5048-3000'. Ran in with 6" Smith Ii2P bit and scraper on 2-7/8" tubing, found top of cement at 5043~, Conditioned mud, made up tester, ran in for Kenai Unit 14-4 -a~ell history Page 5 November 3._ 1960 ~0 Test at,.,,4949' Ran HOWCO combination gun-tester with 5/8" bean on dry 2-7/8" 6.5~ 1-55 tubing. Shot 4-1/2" holes at 4949'. Set packer at 4899' With tail to 4922'. Opened tester 2:26 a.m. for 1 hour test. ~Areak blow for 9 min., then dead for remainder of test. Recovered 20' drilling fluid. Charts showed tester open throughout test. ~A~SO O. Il. I, H. !,. F, F, F, F. H, ToP Chart 3225 12 10 3225 Bottom Chart 3234 30 30 3234 Test Ran HOWCO combination gun-tester with 5/8" bean on dry 2-?/8" 6.5~ 1-55 tubing. Shot 4-1/2" holes at 4825" Set packer at 4768', tail to 4791'. Opened tester at 11:09 a.m. Had strong blow to dead in 15 min., indicating tester plugged. Opened bypass at ll~42a, m. Reopened tester 11:47 a.m., had medium blow for remainder of test. Gas to surface 12:15 p.m. Pulled tester loose 12:30 p.m. Recovered 2?0' drilling fluid and 2130' of 79 G/G water. ~..~NSO. I, H. I, F. F, F, F, H, Top Chart 3106 57 1196 2925 Bottom Chart 3209 54 1206 2931 Set Halliburton DM Bridge Plug at 4875'. November 4. _1960.. Set Halliburton DM retainer at 4625". Squeezed perforations at 4825'. Broke down formation with 13 cu. ft./min, at 1800 psi. Pumped in 40 cu. ft. water followed by 150 sacks Permanente construction cement. Closed tool on 20 cu. ft. water in and out. Followed cement with 20 cu. ft. water and 120 cu. ft. mud. Stage displaced to a total of 172 cu. ft. at final pressure of 4000 psi. Cemant in place 5:30 a.m. HOWCO. Stood cemented, made up tester for WSO at 4344'. Kenai Unit ?Veil 14-4 'We 11 H_,.' s tory Ran ~Ialliburfon ¢Ombin~:e~t Cur~--'tester wi~ $/8" bean on dry 2-7/8" 6.5 J-55 tubing. ShOt 4 - l/1t ~,.%es at 4344'. $¢t packer at 4290' with tail to -4315'. O[~ened tSster 1:41 p~ m; Light bj~w for 15 min., dead remainder of te~t. gecOvere& 35'~rflli.~l Fiui¢to C~arts indicated tester open through- out ter, L HOWCO~ :~,,;SO Oo K. TOp Chart 2674 26 26 2574 Bottom Chart 2691 40 40 2640 i Ran Ha;lliburton combination gUn-tester with 5/8', bean on dry 2-7/8" 6. J-55 tubing, ~ Shot 4 - 1~2". holes at 4180'. Set packer at 4131' with tail to 4154'. Strong blow~i Gas to surface in 3 min. Pressure continued to build to 1100 psi through 1/4" bean in 25 mins., rate 1650 MC¥/D. Press- tire' Still building up when tester closed. No water in evidence at any time during test. Charts showed test O.K. H. OWCO. Tool open 25 minutes. ,H. !. F. F.F. F.H. Top Chart 2578 41 1290 2560 Bottom Chart 2591 52 1294 2561 _November 5, 1960 Ran in with 6" Smith K2P bit and scraper, circulated and conditioned mud. Ran in and set Halliburton DM Bridge Plug at 4300'. Set Halliburton DM aretainer at 4054'. Broke down formation with 22 cu. ft. per min. at 2000 psi. PUmped in 30 cu. fro water, followed by 100 sacks 118~ slurry Perm- anente construction cement. Closed tool with 30 cu. ft. water inside tubing. Followed cement with 10 cu. ft. water and 100 cu. ft. mud. Stage displaced 20 cu. ft. with slow pump. Staged 5 cu. ft. in 15 min. Total displacement 135 cu. ft. to a final pressure of 4000 spi. Cement in place 6:30 p.m. HOWCO. Novemb..er 6, 1.9,,..60 Made up 2 7/8" drill pipe, .4-5/8" drill collars. Drilled out retainer at 4054', drilled hard cement 4060-4183'. Pressure tested casing with 2000~, Page 7 Oo K.~ C~.cu.a~d and cond'.~i.oa~t mue~ Ran ~a wfth tion gun-t~ster'to Shoo~ ?:r~d',uci*oa test 4Z$4--z/25~" Made up new gun ang tcs~'~ Halliburton combina- Gun did not fire, ~ove_ ~_b~r 7, 196__0-- R.a./t/q&lliburton comkimntion gun-tester with 1/4"-3/8" bean on .2-7/8" Hltd'~il g~ill .pi~o Shot 4 - 1/2" holes 4254-4256', Set packer at 4194' with t.~dl t-o 4217', Took 20 mino I8I, Opened ~ester 10:00 a,m, for 8 hr 6 min, flaw ::~st.. Gas to surfaco in 2 min.- Tester B~an Surface Bean Duration Pressure Rate .... (psi) .. /4 !)4 1/4 i/4 3/8 i/4 ode a/e Closed tester 6:28 p.m. 14 min, 1425 600 .16 mir~, 1390 2065 10 mira 840 ~907 8 mih' 590 3787 1~1 mih, 1600 2374 10 min. 1150 3961 6 hrs. 44 min. 890 5665 5 min. (line froze) 8 min. 1560 2315 I. H, I, S.I. I.F.: F, F. F. 8. I. F: H. Top Chart 2715 1822 Bottom Chart 2730 1845 1754 1456 Chart Time Expired 1794 1631 Chart Time Expired Note: Formation solids were produced with 3/8-1/2" combina- tion. Solids ceased when surface bean changed to 1/4". N_gxgmber 8, 1960. Set Halliburton DM retainer at 4087' and broke down formation at 10 cu. ft. per min. with 2800 psi. Pumped in 40 cu. ft. of water followed by 60 sacks Permanente construction cement. Closed tool followed by 40 sacks con- struction cemaqto Displaced with 110 cu. ft. mud. Stage displaced to a total of 120 cu, ft. and a final pressure of 4500 psi, Cement in place 1:05 a.m. HOWCO. Stood cemented. Drilled out retainer at 4087', drilled cement 4162-4200'. Pressure tested holes 4180' with 2000 psi. O.K. Page 8 Drilled out cement to Pressure tested b. ele~, at 4254-'--~26~' with 2000 psi. O.K. ';~'~~ out bridge pl~.~ a~ 43~0"~ Ran in to 4625' drilled out retainer at 4623'._ Drilled cement ~ ~82~'. Pressure ~ste~ holes 4825' with 2250 psi. O. ~ Circulated to Ran Malliburton combination gun-tester with 5/8" bean on dry 2-7/8" !0.40~ Hydr'~l drill pipe. Shot 4 - 1/2" holes at 4827'. Set packer at 4771' with tail to 4794'. Opened t~ster 3:30 a. m, geak blow for 10 minutes, dead for remainder of t~st. Recovered 30' of drilling fluid. Charts showed tester open throughout test. VdSO O.K. HOWCO. I.H. !.,., F. F.F., F. H: Top Chart 3035 16 16 2981 Bottom Chart 3025 40 160 3018 Made up production tester, ran in for production test 4838-4840'. Unable to make packer hold. Slips jammed with pieces Of retainer, Ran 6" Smith K2P bit and 7" casing scraper. Cti'culated and conditioned mud. Ran in with tester for test 4838-4840'. _Produc_.t, io,n, Test. 4838-.,4840' Ran Halliburton combination gun-tester with 1/4" to 3/8" adjustable bean on dry 2-7/8" 10.409 Hydril drill piPe. Shot 4-1/2" holes 4838-4840'. Set packer at 4771' with tail to 4794'. Opened tester 10:30 p.m. for 15 min. !. S.I. Opened tester with 1/4" bean at' 10:43 p.m. Light blow for 10 min. Opened bypass 10:53 p.m. Reopened tester 10:58 plm. At 11:28 p.m. increased bean in tester to 3/8". Light diminishing blow to almost dead. Closed tester 11:58 p.m. for 30 min. F. S. I, Recovered 120' drilling fluid. Charts showed tester was open throughodt test. O.K. HOWCO. Top Chart 3009 false 106 106 107 3009 Bottom Chart 3056 false 105 106 110 3056- Kenai Uni'~. '/'/e~l 14-4 Well Eli s*''?'~ Page 9 November 10. 1960 OriI.~d out bridge plug at 4878'.. clean,~d nut to 5041'. Circulated, Ran Scb].u.mberger 3-$/8" $~pe&~-charge capsules an, d perforated 2-1/2" holes per foot at folloWing intervaJ, s: 4885-4888', 4894-4897'~ 4900-4908', 4916-492~'. Proct'ucti. on Test 4885 '~':q' Raa I~llibu~ton tester witi: 1/4-3/8" adjustable bean on dry 2'7/8" 10. [4/dril dr/Il pipe. Set packer 4855' with tail to 4874'. Opened tester 4:24 p'~ f~:~ 1~' min. initial shut in. Opened tester 4:34 p.m. with 1/4" bean in t,~ster. Weak-diminishing blow for 15 min. Opened bypass. Reopened tester 4:57 p, m. with 1/4'" bean in tester. '~reak-diminishing blow for minuteS. Opened bypass. Reopened tester 5:35-5:42 p.m. with 1/4" bean. Medium blow. Increased bean to 3/8" 5:42-6:13. Gas to surface 5:45 p.m. Very small flare. No recordable pressure. Took final shut in 6:13-6:43. Recoversd 230' drilling fluid, I230' formation water, salinity 92 G/G, 90' very fine silty sand. HOWCO. I.H. !.S.!~. I.F.* F.F. ,F?.$,.I. F.H. Top Chart 3136 2041 478 807 1920 3108 Bottom Chart 3141 2060 493 814 1931 3126 * initial flow taken after third reopening of tester. November I !,, .1960 Ran Halliburton cast.iron drillable bridge plug, set at 4500'. Pressure- tested casing after setting BP with 2050 psi, O.K. Ran Schlumberger 3-5/8" shaped-charge capsules and perforated 2-1/2" holes per foot 4315-4327'. Ran in with 6" Smith K2P bit and 7" Baker casing scraper to 4500', Condi- tioned mud. Laid down 2-7/8" drill pipe. Ran 4284' 2-7/8" 6.5~% 1-55 tubing, hung at 4296' and landed 12.8' below zero. Removed BOE. November 12, 198,0,,, Flanged up Xmas tree. Laid flow lines to sump. Changed mud to water, circulated water intermittently, starting at 11:00 a.m. Started swabbing 10 p.m. Fluid level 750' at midnight. Kenai Unit Well Page 10 November 13 - November ] 4, ~ ~ti'~ Continued swabbing 'wetl~ ?l~-~a lev~! at 1650' ~t 4:00* a. m~,, fluid level !2~n-'~,, at 6'00. a.m. W~¢I! lc..i~k~d over 6f15 a.m. Nov. 13, blowing water with l'/.tt].e ~as. FI0w~J ~ell t~,aI 22 hours 57 minutes. ............... ~e, .: .... .~.jtom~_Pre_~sur__e Casing_Pressure ~;1~ ~-'~ m~ --12:03 P.m. 3/8 750 700 ~Z:O~ - 4:00 ~/~ 750 1350 ~:~ - 8:11 1/4 1370 1620 8:1[ '~:~,, m. -1:5 la. m, 3/16 1350 1655 1:5i - 3:14 Shut in, thawing frozen flow lines. ~:14 - 6:50 3/8 1225 1520 ~CF/D 2000-245~ 4000-478~:~ 2030 1090 4~230-4276 Produced gas and water vapor with intermittent slugs of water except from 8:15 p.m. to 9:25 p.m., when well produced dry gas. YVell would only intermittently sustain a flame. Shut well in. Mixed mud and killed well, N0v.ember 15,: 1960 Back-scuttled, tore out Xmas tree, installed BOE, made up 2-7/8" tubing and ran to 4499'. Cemented with 20 sacks Permanente construction cement, 6 barrels of water ahead and displaced with 1 barrel water and 24 barrels mud. Pulled up to 4406', back-scuttled a trace of cement. Cement in place 1:30 p.m. HOWGO. Made up tester for VffSO test at 4345, Ran HalliburtOn combination gun-tester with 5/8" bean on 2-7/8" dry 6.59 J-55 tubing. Shot 4 - 1/2" holes at 4345'. Set packer at 4340' with tail to 4362'. Opened tester 11:42 p.m. for 1 hour test. Weak blow for 9 min- utes, dead for remainder of test. Recovered 30' drilling fluid. Charts · showed tester open. ~NSO O. K. I.H, I.F. F.F. Top Chart 2853 14 14 2853 Bottom Chart 2890 45 45 2875 November_ 16, 1960 Production Test 4315-4327' Ran Halliburton tester on dry 2-7/8" 6.5~ J-55 tubing. Set packer at 4265' Keuei Unit We!! ~ 4-4 Page 11 .. with tail to 4284', OPened cest-ee '~:43 aom. for initial shut in. Opened tester 7:59 a.m. for l~rOductien test~ wi~ 1/4' bean in te~t~r and 3/8" W~llis be~n. Gas to surface in 4: minufes. Flow increased steadily to 4 p, m,, at $ich time 790 psi and 2'/37 MCF/D rate. Installed blow trap to gauqe water volume, Started 30 minute final shut in at 5:37 p.m. . Teste~ 8,an Willis Beau 1/'4 .~ ./~ hurl -' ~ ~-re.~s, MCF/D Water Water Salinity .::. ...... :' .. .... . B/D B/MMCF G/_G 3/8 800 2771 225 123 65 1/2 575 3693 300 123 65 3/3 ~ 965 .3332 288 116 63 1/2 700 ~4476 328 136 65 Top Chart 2772 1835 1021 1533 1849 2772 Bottom Chart 2766 1851 1086 1572 1865 2766 Set Halliburton DM bridge plug at 4300'. November, 17.~, 1960 Made up tester for 'WSO. _WSO Test4295' Ran Halliburton combination gun-tester with 5/8" bean on dry 2-7/8" 6.5$ tubing. Shot 4 - 1/2" holes at 4295'. Set packer at 4264' with tail to 4287'. Opened tester $:16 a.m. for 1 hr. test. Had very faint blow for 15 minutes, dead remainder of test. Recovered 15' drilling fluid. Charts showed tester open throughout test. WSO O. K. Top Chart 2783 32 40 2767 Bottom Chart 2806 57 68 2806 Drilled out bridge plUg at 4300'0 clem ed out to 4363'. November 18~. 1960, Set Halliburton DM retainer at 4187' broke down formation with 28 cu. ft. per minute at 2200 psi. Pumped in 10 barrels of water followed by 67 sacks Unit .~!! !4-4 Page 12 Permanente constrtlctton ce~en~ C~ose;d~eei and continued to mix cement to a total of 157 sacks. Displaced wi'th £3-1/2 barrels of mud to a final pressu~.e of 5000 l~Si. Ger~.Kt in place 1:45 a.m. HOVffCO. (Back- scuttled appro~4imately' o~e barrel of cement --cement flashed.) Drilled out retainer at 4187'~. drilled out cement to 4322' (in cement at 4322'). Condi- tione, cl ~1. NOvember ~/~.. i960 Ran ~chlUmb~rger 3~5/8" ' ~ .' ' shaped-charge capsules. Perforated 2 holes per foot a311'-4320'! Ran 6" smith K2P. bit,and 7' Casing scraper to 4320'. Circulated debris. Ran in for prodiicti6n test. Produ.ction..Test 4311-432__0' Ran Halliburton tester on dry 2-7/8" 6.59 J-55 tubing. Set paCker at 4266' with tail to 4285'. Opened tester at 11:15 a.m. for 15 minute shut in. Opened tester for production test at 11:30 a.m. with 1/4" bean in tester and 3/8" ~Villis bean. Gas to surface in 5 minutes. Produced well for 8 hours at following rates and pressures: Time T. B, W, .B. Pre,~.. MCF/D V¢~ter. B/D -;~rater,B/M,.MCF ~alinity · , 12:35 1/4 3/8 525 7:00 3/8 1/2 700 7:30 3/8 3/8 950 1836 206 112 - 4476 257 57* 63 G/G 3281 220 66 63 producing some very fine sand Closed tester at 7:30 p.m. for 30 minute final shut in. I..H.I.S.L !.F, F.~. ~,F,. S. L F.H. Top Chart 2703 1866 839 1564 1863 2690 Bottom Chart 2765 1871 992 1592 1865 2726 _Ngv,~mber 20. 1960.. Ran 4284' 2-7/8" 6.5% 1-55 tubing. Hung at 4296', landed 12.8' below zero. Removed BOE, installed Xmas tree, rigged up to displace mud to water.' Started swabbing 1 p.m. ~Vell started flowing 3:15 p.m. Flowed well 9 hours 45 minutes at following pressures and rates: Kenai Unit We!l I4-4 'tYell H~story T__im~e Casinq: Tubing.. t~rrels ;rater Page 13 Barrels .arater _Der MMCF 5 pom. 300 1125 ~/~ 2~78 6 6',,~, 1150 3/'8 396,1 7 700 1150 $/8 3961 8 922 115~ ~,/~ 9 !075 1175 10 1175 1150 3/8 396i 11 1275 1125 3/8 3876 12 Mid, 1325 1200 3/8 4131 I a.m. 1450 1375 1/4 204~ 277 6~ 72 35** Well not entireiy clean UntiI midnight, therefore waterlnot gauged. ,Yell blew considerable ice On ~/4" bean. /Cater gauge may or may not be reliable. Nov.___ember 2.1. 196.0,, Shut well in 1:00 a.m. Released contractor. ~URVEYS De~th Deviation 1685 0° 15' - 1870 0 30 2050 0 30 2254 1 2327 0 30 3102 0 15 3294 0 15 3490 0 30 3926 0 45 4126 0 30 4456 0 30 4842 0 45 5125 0 35 Kenai Unit -/Veil 14-4 Litholo9Jc Log Page 14 1515-1630 1630-2610 2610-2680 2690-3775 3775-3880 39~,.:-39 75 3975-4940 ~940-5125 Sandy ~,-cnql. omef~te and silt~tone Sandstone and silt~tond.~, minor conglomeratic sandstone Sands~:o~e. and ~fltst~ne, some lignite Siitztone and sandstone, occasional lignite Sandstone a::d s.tltstcne Lignite, sil. ts~one and sandstone Sandstone e. nd slitS'tone, occasional lignite Siltstone and sandstone, occasional lignite '~" ........ ~'~ "~ .......... "~' ....... OPERATIONS State ......... ~~ ............ ao~ty __~~--~~ ...... Fiela ........ ~..~.~ ....................................... Tke follo~ is a correct report of operations a~d prod~otio~ (i~ol~i~ drilli~ a~ prod~oi~ wells) for ~e ........................... .... I ' GALLONS OF [ BARRELS Or REMARKS RANO~ ~"_ELL DA~S I BARRELS OF Om GRAVITY GU. FT. OF OAS SEC. AND . GASOLINE[ WATER (~ (If drilling, depth; if shut down, ~ECOVERED _ ~one, so state) date ~d r~ult of t~t ~or ~ OF ~ TWP. ~O.~l P~o.uc~ ~ (In thausan~) con~nt of ~ ~'"4 N l lW 14~ [NO~: W~ ~~rly desl~maMd ~ts~d SW 1/4 ~ i U~n ~ ~ ¢,f ~~, O~n ~3~ and 26~ 8-95 SW 1/4 ~~ U~t ~13-1. .__ q~0 and 1-55 (~men~d at 5102' '~/800 s.~ ~nsim~n ~aen~ ~st~led (~g ~ad, lan~, ~as~g, ~ ~:em~ ~y and Ne~,~n-Collar 1~- I m bit ~i~ s~a~r, c~~ c~t t~ 504:3', i ()~ned WSC[ at ~1 ~S~ at ,~25', ~t D~ ~e ~ a'~ 4875' ~ sqzd ~,~ ~SO at 43.44'~ flo~ 161 ~0 M(~F~ ra~ t ~ I/4~ ~ ~g W80 ~st ~ llo~ 5~65 ,ICF~) ra~ ~ ~2' ~ ~n on 4 - ~'2" ho~s at 42S4-56' - sqzd loles w~90 sl~ ~sb ~t, ~le~[ ~ to 48'~5~, ~S~ ~sl~ ~s at 4180 4254..56' ~d ~i825' - ~ld O~ O~~ed ~C at 4827~, ~~~~t~st48311~0'-~.lnoen~.~~121~'~~.lfl~d. c~~dmS041. st ~,~ I1 - ~/2' h1~f 4885~8 ~I~4~'. 45~0~8'~ 4~S16-t$', ~ ~}$~: ~ ~ {~ p~.~d ~t~ fl~ of g~s. 1550' ~ ~ incl. 1230' ~. v~l. ~It D~ ~e plug at J~t ~,~1 - 1~2" hl)f .4315-27'. Ht~ z-7/8" ~ at 4926', mm~d ~E, ~' zmas ~e, ~mg~ ~ m~ :o wa~rt sw~b~ ~H fm ~o~d 6667 MCF~ me r eM C ~ ~ ~" b,~, ,ome we~. J t~sM1 ~ ~ (~ p~ ~ ~bss at i315-27'~ fl~d m~ ram 'of 4476 cut ~ 43~3'. ~d l~s 431S.-27' v~S7 ~ c~s~ ~ ~,,d out M 4322'. · ~H ~ ~owed m~ ~ 4130 ~(:F~, 270 ~ ~~ ~ 3/~ ~ ~. Shut ~ ~oba~ ~n~a~E 1:00 ~--~, N~~ 21, [9~. ~~ ~.~ d oleamd d~be~ in. No No NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ................. 1~__0 ....................... runs or sales of gasoline during ~he month. (Write "no" where applicable.) 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 supervisor by the 6th.of the succeeding month, unless otherwise directed by the supervisor. Form 9-3~9 1~5766-8 U.S. GOVERNMENT pRINTING OFFICE (January 1950) · Form 9-381a (Feb. 1~51) i i ! I I . I I I I I '1 ..... ..I ...... I ...... ! I i ! I -[---. I ..... i ...... ! , , ' i I I (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR Budget Bureau No. 42-R~18.4. Approval expires 12-31-60. o~. ~~-"-~_o_ ...... ~...o..__A_~_.QO__4_.~ ........ ........ ~_n_..a~._ ............... GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DRILL .................................... :__ NOTICE OF INTENTION TO CHANGE.PLANS .............. L ........ I ...... NOTICE OF INTENTION TO TEST WATER SHUT-OFF .............. ] ...... NOTICE OF INTENTION TO RE-DRILL OR REPAIR WELL ......... [ ...... NOTICE OF INTENTION TO SHOOT OR ACIDIZE .................. I ...... NOTICE OF INTENTION TO PULL oR ALTER CASING__' ........ J-I' ..... NOTICE OF INTENTION TO ~ANDON WELL ...................... / ...... SUBSEQUENT REPORT OF WATER SHUT.OFF ............................ SUBSEQUENT'REpORT OF SHOOTING OR ACIDIZING ...................... SUBSEQUENT REPORT OF ALTERING CASING ............................ SUBSEQUENT REPORT OF RE-DRILLING OR REPAIR ................ [ ..... SUBSEQUENT REPORT OF ABANDONMENT .......................... I ..... SUPPLEMENTARY WELL HISTORY ................................... I ..... ~~_!~_~R_~__~~__~L .l__ (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) Well No, __~J~:4~: ...... is located~?_~,__0_~, from__~iine ancl4_~_~P_.___$_~, fro~,t~cline of sec ..... _4_ _~:_~._4_ ........ ~,__4._ ............... _.4:~_ ........... .!L_w___ .... (~ Bec. an5 Bec. No.) (Twp.) (Range) .......... ~I'e-~li~')- .......... .......... ~ ......................... ~~_~ ........................... A~~. .......................... ' (Field) ( Ounty or SUbdivision) --- (State or Territory) The elevation of the~ above sea level is 10_$_,_l__ ft. DETAILS OF WORK (State names of and expected depths to objective sands; show size.s, weightsgand lengths o~ proposed casings; indicate mudding jobs, cement;= ~ lng points, and all other important proposed work) NOV 10 1960 (, · .~ Division o[ rx::J~:cs :md M/nc;at.s .... r~e~t, o[: Natural Besources~: I understand that this plan of work must receive approval in writing by the Geological ?-urvey before operations may be commenced. Company ..... Y~J~_Otl~_~__:Of_~~~.__'Oll~l~clF ............................................................... Title ...... M_~_.a. _~. _ r___o__f.._~..a..~....o~...s.. ......... Alaska Dtvlsl0n GPO 8 62040 G~OLO~ ICAL S U ~V'E Y LESSEE'S MONTHLY REPORT OF OPERATIONS The followinff is a correct report of operations and prodz, ction (incl~diT,¢ drilliT~ and prod~ci~5 wells) for the mo~th of ....... _~_~[Q~[ ................... , 19_~_ ................... .............................................................. ~en~' s address ...... 2~_0_5__DenaH_$~ee_t ......................... Company _~0~ .0~_ ................................. ~_o~hor_m~e._hlmzka .......................... ~iff~e~ ................................................................. Phone .................... B_~n~g~y_B_rfi25_L ............................. deent' s title SEC. AND ~or ~ Sec. 4 NW 1/4 sw 3 U.S. 1 -File 1 - Ohio 1 - Ohio, 1 - Div. TwP. t RANGE1 4NI 1 l'~:g S. , ~c] rag~ & ?~ I I WELL ] Da~s ' _ or~ e tn. i Anchorage,' I Cu. FT. 0F OAS GALLONS OF [ BARriErS or RE1V~ARKS BARRELS OF OIL GRAVITY ! (In thousands) GASOLINE ] WATER (If (If drilling, depth; if shut down, cause; lq. ECOVERED 110118, SO state) date and result of ~t for g~ol~e eon~nt of -. -~ -i ~ - I Gpudded 1:00 A. M. , ~ ~ . [ I i , ] 10-18-60. Drilled 11-3/4" ,12~ H-80 casin9[to 1068',cemented with 1205~ con- stmaion ceme:~t. ] ' ] / ~nte~aIs: Cor,~ ~I, 4Z09~38'; Cc.~ ~, 4~35-6~'; Core 93, 4380-95' Cor~ ~'4, 4456~72'; Cc,re ¢5, 4842-57'. Ran Schl~ mberger IRS and Dtpmeter land !btatned 36 2earned h le~ ~:ondittone~ ~onic 1o Sidewall mud. i ;s, M'ic~olog, Continuous Sample~ between 3545-5076'. ow running 7" casing, NoT~.--There were .......... ~'?0- ...................... runs or sales of oil; .......... ~O .................................. M cu. ft. of gas sold' ............... ~ .........................runs or sales of gasoline during the month. (Write "no" where applicable.) NowE.---"tl~port on this form is required for each calendar month, regardless of the s~atus of operations, and must be filed in duplicate with the supervisor by the 6th of the sueeeedi,hg month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766-8 U. $. ¢OYVR~M[N? ,RINTIN¢ OlrF~C[ ~ow,~ ~ ~ ~ , , 4 I LO~ ~ GL.X'S'r,4o4"r... ~% 'q,L APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK .... ,..:. . APPLICATION. TO DRILL NAME OF C~)~I~ANy OR OPERATOR ' ....... DANCE Address :: ~ -~ ~ . - - ~ ' City Stat~ ..... ~ - -- ' ' D~SCRIP~IO~-OF WEL~~ AND LEASE ~'~ ' ' ~ ' " ' -'~ [~Veli number ' [Elevation (ground) Name of lease f-_ .~ -.. . . :.. -. :~ . . . -_... . . Well location (give footage from section lines) Section--townshilp~ang~~~& s~r~,ey Fie~d~ reservoir (If wild:cat~:so state) ~_ . Distance, in miles, and direction from nearest town or vost office Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: Proposed depth: [ Ro~ry or ¢able tools Approx. date work will start Number of acres in l~se: Number of wells on lease, including this well. eomDleted in or drilling to thta r~ervoir: iSS8. 10 fee t If lease, purchased with one or more wells drilled, from whom purchased: Name Address status of bond N&tion~ Oil & (Lt, Bond No. 222337, dated 8-3-S8 for $1S0,000, ~tod by producing zone and expected new producing zone) 4. [~~h ~O'~ a~ ~~~. ~EP 10 1960 Oil & Gas Sccdon Division o[ M.i~es a~d Minerals ~aska Dept. o~ Natural Resource~ Top of wodu~vo oend o~d &t 48S0' ~. BOP Eq~lpmoM tn~ udes: 8hfbr ~ ram BOIP, Hydfll 'OK' ~, 12' b~lom 900 ~ttn~_ hoad flaM- ~o, and 13-1./l= iand~~ CERTIFICA~: I, the ~dersi~ed, state that I am th~ of ~e ~ (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are tru~.~orrect and complete to the best of my knowledge. ~,~~~.~ Signature 31 Permit Number: Approval Date: Apl~l~ov~c] ~SF~ .1 2.. 19~D~ ........ ',~ k . Alaska De~t. of iN~oA;ura]~ ~esource~ -- 5ce lns~ructlorl, on ~everse ~lcle O! ~'orm Alaska Off and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 ; -cZ8C55 Chic Uil Cc,. 2,.324.67A 54 UNION OHIO Ervin 2560.00Ac. 9 .., lO 0 HI 0 OIL CO. ,-o~o~ T 4 N -R II W U N ION- OHIO REEEIVED Oil & Gas Sccti~ · Division of Mines a:~c! i' Alaska Dept. of N~tu~:a] : , i": ZOO0' 9- 6 '60 NOTICE The following well logs and oversized documents have been placed in offsite storage. To view these documents, please contact the AOGCC librarian. AOGCC 2/16/2005 , r ~~,~'. -~', ell c:::a UJ t- -== ,t- '0 :z: :z: -== ..,. u.J I-- c:t: ~ .....I c... .A ,~ ,U 11. a3TI11R9 ,ear";!,;), I,/..e "'AO'! t 1oC>~ ~\ , .'- '" '" '" " " " " '" '" " " '" " "- RUN No. di'i t: Date I i,..1,..: J \J- b V First Reading") J ? (' Last Reading I u7 I Feet Measured 11 ~~)6 C5g. Schlum. I u-¡' I Csg. Driller f u6 h Depth Reached J ¡ ¿ b Bottom Driller :,) ! ? J Depth Datum U f' ----- --_. ----- Mud Nat. '.-:':l Dens. : Vise. 'J ~ .. TP:.:-~n______-¡- Mud Resist. I (I Ar@",",IF,@',OF J.,L}-n lJ ,j -- ,- Res. BHT <1.. 6@ ! ~~ /1 °f- @ OF Rmf L..:ù..~~-~! @ cF R m~- /~ . G @ t ¿ if ~ @ ° f pH I; J . ~,@ Of --@ OF Wtr. loss:), -""CC 30 min. Cç 30 min. Bit Size 1J t.> Spcgs.- AM I ( ,. - ", If. , f MN ,j6.: IND. f: ~- ~- ~. U Opr. Rig Time! .,; ; I ;' I'~ . Truck No. -' J~, i..:~ ~ecorded By t t/ It." . ¥itne5$ ! I: ~ i \.-, .. "';1' \....... ":.. .'~- r . .' '. ~, J ~" .f , I ',' '..,.j .~.. '..~' ,'p Z ,~: >- 0'" t-""'- Ot- ZO<{-J ::)-JU-J OUJOUJ uU:-J~ c.c CC'.) ......... Q 'P-' ..q- , v lL" -) --'~ '.' , Location of V ----.-. 1._... :~ ,~) WELL KENAI UNIT =#= 14œ4 , :; -- J 'ì ,;'''..'1 ~) . ~ FIELD iJ;~¡ T ~~ L ~ r~ r ,,'\ : , -, .- . LOCATION-4-4N- i t.',¡ oJ!': ~.:~ ;~ :) :. (. ~: J uj II , Elevation: D.F.: K.B.:- or G.l.: >- Z <{ 0- :E 0 U . -~--_.-- ¡,~ ¡ ! ;.'\ ¡ ) ¡ , \ ;' ,', \~,.. "~ I~ '-, ¡ COUNTY_, 5T A TE -- 1'.1.. ,.~) -.: i '. FILING No.__- _._-- - -.--------.- -..--- ---.--.- ----------.---.----- 1'--------------'------ I ! @ OF @ OF @ of @ of @ of @ of @ QF @ of @ cF @ of CC 30 min. CC 30 min, @ @ (ûJ @ @ CC _._-------- -. --- .._--_. - - - . -.-- - _._~--- I t ----------,~ ¡J,,'¡ - --- ¡~-~;f' .. <:~è ~J \" ": ~ } I . tJ- :::: '';J, ,~t')~J ,-:¿ (; F' '.~¡-\L J r:,) k ¡~ I k. lJ rJ I.:l,¡.d" OR t-.. '- ',. :- , -' . '-r' Z ,:) c;; fj WELL KENI-H UN I T ¡~O. 14-4 (-' ~ .:~~, ~.~ U ..:J ::3 r;:::-: Z -. 0- ..~~ ~:>. z -..,. FIELn KEN/\! Ui~ ¡ T ,~, w... C)- ::: ,~:J LOCATION 4-4N- ¡ 1 ~¿ Sf~1 "'- -1:, r. '~;~ )', ~ ',' ,-.} ('j /, ~,~ <'\) >- ". ' \( Ji) ~ COUNTY KEN¡:¡¡ PR{(;I~~CT ~ 8 STATE , ; / /:~~c til '.( J: :::: Z z--- l.1J ~.u '1: ,.,. ,,; -')I' ...~- ...... J//:'" z~.u >- O~ t-Io..- Ot- zo<..... ::J.....u"'" OwOw uü:.....3: RUN No. , Date First Reading Last Reading . Feet Measured Csg. Schlum. Csg. Driller Depth Reached Bottom Driller Qepth Datum Mud Not. Dens. I Vise. Mud Resist. " Res. BHT Rmf Rmc " pH " Wtr. Loss Bit Size Spcgs.- AM , MN IND. Opr. Rig Time Truck No. Recorded By Witness COMPANY UN I UN 0 ~ L 0vll1r) ,nN Y Other Surveys 5¿L'~ ¡.,~ L..... :.l ~- - \.~ J t,,'1- \.o~; T Location of Well ,'. - ... , R T : I u3 II ~ ( Elevation: D.F.: ' K.B.: or G.L.: ALnS K /J. FILING No. ONE I U-3 u-6l) ~1?7 I u11 4 U::>6 I u11 I u68 :>128 ~12~ uF GEL 9~ I ~.J 9.A6@ (.d;/f 4 .. 6@ I;? 4 QF 6.~1@ 64°F 4. 8@ 12 4°F H . ~@ of ~ J UCC 30 min. ';18 ICÏ4 34-}-) . 6 f- f-4 U 13 H{S. ~t.> U~ M I LLL:R LrON , C~¡DENNr1Äl I I I I @ OF @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of CC 30 min. CC30min. CC30min. CC 30 min. ,~ COMPANyUNI ON . OIL COMP MN Y ¡ ~ ~ ~ OF\';í-\L I FORN I~. OP ER~ TOR ~ ML-5L-CÙM~~S T i ~ - . ~, ~ , , ' " Location of Well t. % . O~ WELL KENAI UNIT NO.I,4~4~< j;. - C!..) [1J ' ;¡ , (,,) to- Z ,~ . ¡~ LJJ - 0 ':,i,:' ~ Z t-. ::.' 'r\ 0- ':=>- o. i¡ ~'~ FIELn KENAI UN I T l.; - - ::; z u- ti . ,~" .~ 0" HiIX"%- ' -...J LOCATION 4-4N...lfW SM [j 'w, ,W '~': ,%'4: if ~::,'~z ':)(~' r1" ..-~ ,,'''zU;¡' >- :1 >-',' 'ow "z ' '1""'(5- ',< ' KENAI PRE'C ,IN, ,CT [\z';6"'~,,~' ,...'" "",~,.",,_ÇOUNTY ¡ i"J "', ,::::>.....u -' ',. -"<c', ,: ,,: ",'-' ' ' , Il~Q~~:~~~:~',?~~T:6cALASKA tt~. _First Reading '~1?7 '" ¡~ ..~~~~~~:;~~ed 18l1. . L,.',',~¡': ""CSQ",::S,C,,' ~Ivm,"" ,~' '"f, °, ",7 'I f " 'Csg. Draller" I Ü6A f,'.' .' ( ',' \ Depth Reached:> , 28 fy;, Bottom Driller ~] ;> ~ ~c':': Depth' Datum OF r:A'<~:J Mud Nat. Gf;Jn 0L:'~Dens.1 Vise. 9ó, I t)3 ~ ~~d:::~SiHT ~: 19::~ ~ :~: ~:~:IU:: rf "pHE}, 5@ OF ~ "Wtr. loss 5 ~lncc 30 min~ l~ Bit Size 98'" ¡,~ Spcgs.-AM I 6 It ;f~ MN J4-J;4 :t: IND. 6FF40 ;~¡ Opr. Rig Time ~ J ~ RS . itj Truck No. 3~ Ol \'~ Recorded By MILLER ~~' Witness LYON 1'¡' / (., / .:~. ~( ~~':¡';~m-r..."I'.~IW..~"".;.o.- ~,-----'.,...---,..-- . D r:rr:!.'/r::D' b ",. i'." I,," ,:" :t' L ~ , 't .1 ~,;. )4 ',I' 1 . .' J/ÀN 5 1961 on E~ C8S Section Diì'isir;p cF ¡',';¡r'~'s nnd I\Iillcr 1.:J' AI,wRT'."", t' 0 JI.'t'lr"l 1'("'0" ,., ,U"'. ¡;"""."1:t., \. , -.' 0. \\,.00) (,.10 ","" Elevation: D.F.: K.B.: orG.l.: FILING No. -1 ~ f¡ Ji , -I¥\t\I, "" '.',' " '" ..,~,'L' "J~,', ''-\Al,...... t;U1,rIV;:I', .. .'. .1,. .~. ' I I I I @ OF @ of @ of . .@ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ of @ OF @ of @ of @ of CC30min. CC 30 min. CC 30 min. 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' ,,' . ,~~:.,., , '..'t ,^,cstern~tlas ~ r'AMMA' "'R, AY~::- :::,:r' : internatIonal ~ l:J II \':' ','~, ~' .' .l . : I.' :. ,,:.; .,' '."~; " :;.. 1 : tilL NO. Î () tv! I . , " . UI\¡VlvnL:~""'..,,... ':~' ',' ':i K U I L1 - i' ' . ".:;: . ;. J I , ",~: ' ; j ¡ ~PI NO, ¡' I [ iJ) I\ENA 1 GAS FIELD': :., '. ,',:,<:.~~,::'.., . "';'j[. ¡ C:ÜlJtHi KENA I ~)rnl+ALAiKAI : I U~I\ 1 I' ~H ~~ 'T"p~~~rï ()~¡, . - ---.. - ----- r¡O;HER 5E~}C(Sjt);>1 ¡ ü.:: :~;\', :~ \i\ h \. "..ù ¡ . .I'~' ... ......; 'r: ~t;<} ! ," u,.- ",lc.¡,:.r~, .iÞ \.'.\f\~,\~'"'' iWf.) At-.) ¡)(~,"F ¡ 1'1 !.,":":,' ., ',-'., : 'Î.. ,"'\',":',,'\ '::~ .>. ( " ..':" Lt. , ... r I', ,,\ .' V~ t: " ,,:r' ! '". . r ¡; RMnNf N [ iWt¡}JI-1,~: r,'J()¡¡~\!~~)~~(h I - -, - - .ii r ~ n ; 1 W - N I;' ~ L': ',,::~ Èm)AT 1 ONS>CI:¡ ! : ¡Db M[n:)U~?E[) f ~OM KB IB.Ø ¡-r, n¡¡Ol)[' PLl~~H'¡N[Nl DnlUN ¡'~t5 ~~~' <:'{ ,:", ':"::'i' J I)R I I L ~11 At.' l ¡)()11 KI ~ 1,1.-,,, , ',' '~'r" : ': 'I : . , ' . I 1.~1.) ~ ~ ." ,-~ 1_. -'- ,,- .,. -" '-, -' -_.."--~.... '~, ~¡, r~ fA" ~,:"'''''' '..:..'~,' . ¡ Dn r I.. 1 (/H/~37 i' ':'., ..~ :,,-':'.' ; I.~ ¡J~:i: C¡)b~.~~).~ ~...... .- - .. .... :.: .:....~i~ ~i~-.-...~. ..... ...:.:.... ......... .. ..... .. .... .. . .. . .: t . ....-...._.__.';:-)Ë--F¿;~i . ¡ i30fl0M I O(;,li[ l) INifRUflL ,. 11263" ". - ",.. r -:..n'____~"~"---':-~~"'":-:'-".T~--f ¡ : .~~:fL ~f~ \ X : ~!:!:j~t----~:_. f-~~1¡- fLDI.jr.lfi~:-- -:. .1. -:_~ .=====-i~+:;:i . . ; <~(ìIUn¡Y )!>¡"1 Ct. - -,- - ',':',", ,~", ~"-".-,~'!' ¡ 11.; ~ ~ 0~:1 (I: Y il: 1::: rd. i)[ G . ...1 ... .:~J~LI ... . ..... . - .. ... - .. .. - :.f :.--~-?E~~-=j;=~:~:I~ lW"R: R Ilj 'I j 11L ." -, --~pb'l~ 17)ÜLF'" MAS (- -- [(~-l}ï-¡~:'NQ.. ï LOC_nrl.oN 7,f.Ù~-¡-t3'f;¡f9':""-r'KINÃI RECORDED 8Y W.R, BAkK 'w' ï 'rt~f'-S' :;'r'D BY -- -f¡( . 1'¡OCM--ÇIÑ-----. '.."_..,,.. """-- . BOREl-IOU R(~CORb' "- FROM i '-' \/1 11./ rll\J Y j hJ F l I.. ¡-'NUMB! R OIT 1- "-'-~'~--- .- .-.--. _.._.~--- -.-. ..',-- --'.. .---... ---" ----.-_..- .-._- -- 0'__- --- -." -- . - '--'--'- - --- .--.,.- ----- ..,.. .--.---- '--'-~'." ~"..__.__._--. I !.-. ,¡ .. ~ 1! C(( 'I, ."":. ,.'-..o(o~'" "~' ~'. /I/J~I , " ," , , ' , " ,', " ", i ";"r-, :...~~. }~T>:'" '--¡r¡c:-~:-'.:' ;,:l 1,:\ \~:/¿Ø;'Jt':,i,~1. ~,:~~:~~ðJ ,fi'., ,rLA, ~," ";,,"i,, ,,~I """ D.t r,', ",r,E&, ¡"e,.,n ~, '."./i." ("J ~',', I ''''<~,~~,~v~j~1f:~~~il~ W, " IR" EL, BI\1iE, , .1 '-'r""r";,:-,,',,rv,,~,' ',r=>,', ,E- ,[), ' ,""K, ,-r, '," t ,~fjí~~"~~!~){~~J~\$ERV]CE~1 'I " ,"CilE _. rll~r,r ~ .1 :'::;~~~~~Î 'i"'!". .. .1. GAMM¡~ ;".".,.,".'.,..,;,r,.,~,,',',',F!~,~,.]:, . ,,'.,:,r,'-,;;,,:,'.':';'" M,'.', ;"t,i,'"".,,N,., ':\~Ü'~,.'~,Õ'C-,.,~,A,.~,{-," ,,'.,' ',,' ',",'" x '-,""'" """"",,,,,,"",..j ",:1,'" ", " .' " '!\'~;i',:;';;:,\,,""<" /" U' ¡ ¡'ð !,- 4' , t '," n¡ C"í.~l- ' , 'J ,.. ! "" .. ' " ',' , ' , ' '" . !iAP1NO, . ..; ,'.. ." i.. E~Ar.GAS F I ELf) . . . ,"Î, C'(}UN J ,KE ~JAI ! f)1 bi:),"'\" S' .;,~ .. ,', ~"t/. - ~'~\' ..~. . .,. ~ i:C,1),1Ly,\:> J.}~:,:.-;:;;t l)LA F:,J'!,vf-:l !,:.'; ; ,', '.. i I . t"""".,,';',"~',;",:, : ,"", ,',..~.,';,!',:'R.tf,'t", £I;,',...\I',';',.'~,!D::::"';:'~ , " '~,:,:,."".,' , "" " ¡,~,~ "i r:':~ ,~<' ;,:(' ~".i''''I:'' ",C' . ;" ), '~i IF INA", F'Rb~~~c 4 .... . .1WP 4N ,RGLI I: , ,HOTTOM:LOGGBOIN1FRI.Ji1L."4Zt)]'" ' , .!,\, ,',' , ',', ,12:);;' ! .. .,. r~;~:l n;:{I¡~ ~:~l:¡:j(~X'~,~1:1;;~; ~1;I'O:'-~ ~ ï~~;'-~:~_: :-i~!j ~;:J¡Ji .lì--,-,~~.~-,~l, !", ~,:,;,';,~i,'~,i,'~,,~,',L,ë,t,(¡,:,V,,':,'.',,~,.~, 'P~~~~,'~,-"-, =:j~~~===~, -F':,: -~'--:,=~;~, ~,'~~;,~, -..t;"';,,,,','-: I --:-'...., .. ";""-'~" ,...0."' .....,...~- r'~""''''''''\''';:Io....~,:""..I''~.'''-'~:;:'''''-'''''''''''''' .':""r'''-'~';''''~'''''' ,_...~-.,....:-:._.. ~,..;,.--..~,~.-......."".""",,,,,,,.:-,:--_~,_._- ---;_.........-_."-- .".,-.----..-. "'---.;" 1 , LEUEl ' ";,': .' """','" FULL," ,'i;" FUrL, i ...~~Fl~-;:f~E7'QIf,_E=1f,tm'~;=MA~~r-~=~:.=~~~ r~,!;;! ffi1~:-,[,~,...~Î\f,~.~,~,',Z1,:'~,-~,~Ð,~f,:,~~~,',':-;jr]~,~,L1~,.,~~iJ~~~~,~,=~,:~~~~)~1 iWrTNE~>SE!) BY:,; ," R. H()LMAt~ ~', I ", lR. HD¡ n ,,~~"_.I!c' -":)~~',~'\":<:\<~ :";~'~~~ ~"...,.'\ ,y.,I.., v, nÒRElIOir'RÉ'h),~rf' ... - '. ,--- -.,'-. ""1 [~~~ii;'~j;~~~~~=-:=~ê~~=tR~~-~:_;=_~_-~-i;-~1-~ , I ! ' " , , L:~=,~,.~~~ ~~,-=t',::;~:'-=~~'~~,','=-r-~1'-'~'_-'~~~---'-"-.-'-~-,-~~,~-,.~_..~~,-,._----t:~-~~~-=~ I \ j ! i ._.Jih._-,-_.. -.. ,- -....-._I,J ~~~~~~~.C"~~~f¿¥':"~~~":~~"~¡I'~'~}¿'Vt'-' ._...~'"'[~'!;~~. I f ~ /'~ /" , "- l q¡ :,." VVestern Atlas ¡ International : F] LE NO. foo - 1 . ATLAS WIRELINE SERVICES Differential TEMPERATURE LOG GAMMA RAY j i I: ! ' FIELD COUNTY UNOCAL KU 14 - 4 KENAI GAS FIELD KENAI STAT[ ALASKA COMPANY WELL. : API NO, I . COMPOSITE~ I . . LOG LOCATION: OTHER SERUICES FINAL PRINT SEC 4 PERMANENT DATUM GROUNO LEVEL LOG!MEASURED FROM KB DRI LL. ME AS ,~FROM KB DATE 'RUN 'SERUICE ORDER .DEPTH-DRILLER ;DEPTH-LOGGER ,'¡BOTTOM LOGGED INTERUAL , ,TOP LOGGED I NTERlJAL 'TYPE FLUID IN HOLE SALINITY PPM CL. ~NSITY LB/GAL. ! LEVEL , ;: MAX. REC. TEMP. DEG. F ¡OPR. RIG TIME II~ :;EQUIP. NO. I LOCATION ¡: RECORDED BY '¡'WITNESSED BY NUMBER. B]T , ' I '. ,¡- '. TWP 4N RGE I I W ELEVATION N/A FT. ELEUATIONS 18. ø FT. ABOVE PERMANENT DATUM ~~ ~; ~ GL N I A Ø5-SEP-92 3 79715 429Ø' 423Ø' 423Ø' 4Ø54' WATER 17-JUL-92 2 79712 4290' 4266' 4255' 0.0' .IN FIELD WATER FULL 93 PORTABLE HAST HSL B649 I. KENA I CAIN R. HOLMAN BOREHOLE RECORD FROM FULL 77 PORTABLE MAST HSL 8649 I KENAI D. CAIN R. HOLMAN I I ! i ! ~ ~) ~ u! . :::II , cl , ë! , LJ 'J( TO Þ (;/í (¡JO - 3\ .'- ._, "'"-~...---........~ ~.~~...(¡.,.-..........,.\". .,;,\,....... ,~... """""-'~--r~'''---~' - ~- '...-. -'~"- .-. , ~1~:GNE I T EMF) [ RAT U R E ,^,esternAtla~ SEr:1\fICES t G A t\1 M A- D A Y International I ' I \ f ] ¡ f ~m, ~- ..-0 - ~.--~_...,... ... -.,."... .,.. 'It'~-'~-"-'-- .....iI..,.,.,.'_..'''~-' .."~'" ì .....--....-.--... -. - .-.,.' _.- ...,-_.. \ ~-_... ~P! NO. : c:orvjfin"'JY UNOCAL ; i t,~f I! KU I Ll--4 , ¿ f ¡ II t) K E NA 1 GAS FIE L D I I .COIH\jjY KENAI ¡TOr~()-i 1 ÒN-:- -- -, -. --~. ~)I nr f ALASKA I 01 Hf R ~)fRl)] Cf S ~;! C ,1 Il~f) /j t\J f'~ l~ ¡ I I ~,J . -.w -.-, .- ""'" --. PI fmnNf N I I)nl un Kf! lOCi HI n~;lJf~[ D f kOM HKB . DRIll, M[ (ìS. I ROM HKB I 1---' " I [) n I [ ¡IWI~ I ~;f RU] Cf ORDf R IIH f)l H [)f~ II LI R D r f) "1 H I 0 () () f R HOTf OM I OGGl D ¡ NIIIWn¡ 101' I ()(J()f [) I NI L Rl)nL r ) .p f fLU 1 D ] N H 0 L I ,~;~L1NIIY PPM CL, D F N~; IIY I BIG f¡ I - I f IJ L I MfìX. fÜC. lIMP. DLC. f () P R, R 1 G '11M I ¡GUlf>. NO. IlOCfìTION I~ I C () I~ ) I!) I ¡y !.~JlINf_~;~;I[) In I I 1------------,-----,-- I NUMB f R H II I \.. ". I I I ¡ ¡ I r- -----' ,.,,-, --,., ,--....-., - -,'----,.-...-...,.-, I I (1 () ! I f un ¡ or~ WI ¡ I . 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