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Home My WebLink About178-055MARATHON • Alaska Asset Team United States Production Operations Marathon Oil Company December 4, 2007 P.O. Box 3128 Houston, TX 77253 Telephone 713-296-2384 t=ax 713-499-$504 FedEx Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 ' RE: Marathon KDU #5 -API 50-133-20319-00 ~ ~ l9 Marathon KBU #41-7 -API 50-133-20327-00 Marathon KBU #31-7RD -API 50-133-20347-01 Marathon BC #9 -API 50-133-20445-00 :~~~~' ~p~ ~ Z~d~ CONFIDENTIAL Dear Mr. Okland: Enclosed is one CD containing confidential core data for the above referenced wells. The Summary of Core Analyses Results document included all the wells in one document. I've included the original. document, and have also saved each well out to a separate document for your files. Sumrnarv of Core Analyses Results: KDUS KBU41-7 KBU31-7RD BC9 Summary_of Core_Analsyis.pdf Separate Documents for each Well of Summary of Core Analyses Results: KDUS_50133203190000_Core_Analsyis_Summ_pdf KBU41-7_50133203270000 Core Analsyis_Summ.pdf KBU3l -7RD 50133203470100 Core Analsyis_Summ.pdf BC9_50133204450000_Core Analsyis_Summ.pdf Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-499-8504. Thank you, Kaynell Zeman Engineering Tech Received b : a Y Date: ~ ~ c,~~~µ-- 01 a ~~ Enclosure 17 8- oss . . MEMO WELLS PRODUCING IN KENAI, STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201-231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X . I 0 'Y'1. -O~ {!!'l-- '"\ \ ;> '" SCANNED JUL 2 7 2007 < . Alaska .eam Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 October 25,2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 3 G .". .-../:. ¡'·~"""¡~Jfì bv~~:; u¡G:.L:: RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, , ,~ Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production from this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X API No. 5011331009001 5011331009101 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 t. . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibele@marathonoil.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Files Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage ( I MEMO TO EACH WELL FILE LISTED BELOW Date January 7, 2004 Two previously undefined intervals, the D 1 sand of the Tyonek Formation and the Beluga Formation in the Kenai Unit of the Kenai Gas Field, have been combined into a single defined pool the Kenai, Beluga/Tyonek Gas Pool, field & pool code number 448571. This change was effective in January 2004. Production from these two intervals had previously been reported to production codes 448569 Kenai, Beluga Undefined Gas and 448570 Kenai, Tyonek Gas. These codes have been deleted from some of the wells listed below. The wells listed below have had their production records modified reflecting this change. 184-109 KBU 23X -06 200-023 KTU 32-07 181-153 KBU 31-07 168-049 KDU 2 195-055 KBU 31-07RD 184-108 KTU 13-05 174-050 KU 14-06RD 199-024 KBU 33-06 178-055 KDU 5 195-054 KTU 43-06XRD 177 -029 KBU 13-08 203-066 KBU 43-07X 185-181 KBU 33-07 199-073 KTU 24-06H 202-043 KTU 32-07H 195-054 KBU 43-06XRD 179-029 KBU 41-07 169-012 KDU 4 184-108 KTU 13-05 179-030 KBU 43-06X 199-024 KBU 33-06 199-025 KBU 42-07 200-188 KBU 24-06 202-025 KBU 41-07X 200-1 79 KBU 44-06 ~)~;AlN1~lËtC. ~]AN 2 @ 2004 1. Type of Request: Abandon OSEXCEL'~,OGCC02.xls STATE OF ALASKA r-- ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 APPLICATION FOR SUNDRY APPROVAL~aska Suspend ~ Operation Shu.own Alter Casing Change Approved Program Repair Well Plugging X Time Extension Slimulate Pull Tubing X Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 692' N & 1720' W of SE Corner of Sec. 36, T5N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective Depth Workover to Allow Flow Up 9-5/8" Casing At Total Depth 715'S & 3051' E of NW Corner of Sec. 36, T5N, RllW, S.M. 6. Datum Elevation (DF or KB) 72.2 feet 7. Unit or Property Name Kenai Deep Unit 8. Well Number KDU #5 g. Permit Number 78-55 10. APl Number 50- 133-20319 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical 10502 feet Plugs (measured) 9695 feet PXN plug @ 5512' MD Cement retainer @ 5828' MD Effective Depth: measured true vertical 5384 feet Junk (measured) 4768 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length Size Cemented Measured Depth 97' 20" Driven 97' 2521' 13-3/8" 2200 sks 2521' 10417' 9-5/8" 2000 sks 10417' A-8: 4054'-4094' MD, A-11'4261'-4267' MD, C-1'5137'-5187' MD True VerticalDepth 97' 2384' 9612' true vertical A-8: 3675' - 3707', A-11' 3844' - 3848', C-1: 4556' - 4598' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS: 3-1/2", 9.2#, N-80 tubing to 5534' MD SS: 3-1/2", 9.2#, N-80 tubing to 4001' MD Baker model A-5 dual packer @ 3986' MD Baker model D packer @ 4353' MD Baker model SAB packer @ 5465' MD ORIGINAL 13. Attachments Description Summary of Proposal Detailed Operations Program X BOP Sketch ~X 14. Estimated Date for Commencing Operation 9/21/00 16. If Proposal was Verbally Approved Name of Approver 17.Signed Y~~t...%l hereby rtiht that the fore lng is true Conditions of Approval: Plug Integrity Mechanical Integrity Test Date Approved 15. Status of Well Classification as: Oil Gas X Service Suspended and correct to the best of my knowledge. Gary Eller- 564-6316 Title Production Engineer FOR COMMISSION USE ONLY Commission so representative may wil~ess BOP Test ' Location Clearance Subsequent Form Required 10- Approved by Order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED'BY D Taylor Seamount Date 8/31/00 IApproval N~~),,... ~,~o~, ¢ Commissioner Date S'~t'bmit in T~plicate WELL KDU 5 - AFE 9204499 KENAI GAS FIELD PULL TUBING, FLOW UP 95/8'' CASING Objective: Perform a workover on well KDU-5 to allow the Sterling C-1 Sand (Pool 6) to produce up the 9%" casing to increase deliverability. Procedure: 1. MIRU slickline on KDU 51. Test lubricator and BOPs to SITP. RIH with shifting tool for 2.750" Otis XA sliding sleeve. Shift the XA sleeve at 3951' into the closed position. POOH. RIH with a PX plug, set PX plug in the XA sliding sleeve at 4398'. POOH, RD slickline. 2. MIRU pump truck on tubing of KDU-51. Load tubing of KDU-51 with 3% KC1 and test to 1000 psig. RD from tubing, RU on annulus. Load casing annulus with water, pressure test to 500 psi. RD from annulus, RU on shortstring tubing. Pump Marcit gel down shortstring to plug perfs (4054' - 4267' gross). RDMO pump truck. 3. RU slickline on KDU-5s. Test lubricator and BOPs to SITP. Set PXN plug at 4130'. POOH, RDMO slickline. 4. MIRU pipe recovery unit on KDU-51. Test lubricator and BOPs. RIH, make chemical cut below dual packer, POOH. RD from longstring, RU on shortstring. RIH, make chemical cut immediately above dual packer, POOH. RDMO. 5. Install BPVs in shortstring and longstring tubing hangers. 6. MIRU workover rig. ND tree, NU BOPs. (Note: Upper pipe rams equipped with single 4" rams, lower pipe rams equipped with dual 3V2" rams.) Fill mud pits with 3% KC1 water for remainder of workover. Pull BPVs, install 2-way checks, test BOPs. Pull two-way checks. 7. MIRU tubing handling equipment for dual 3V2" strings. Attempt to release the Baker model A-5 dual packer on the longstring tubing. If the packer releases, lay down both tubing strings simultaneously. If the packer does not release, verify that the shortstring tubing is free from the dual packer. Circulate down the shortstring tubing to verify no fill is on top of the packer. MIRU pipe recovery unit on the longstring. RIH with chemical cutter for 3¥2" tubing. Tie in with CCL and make a chemical cut on the longstring tubing 20' above the dual packer (leaving adequate 31/2'' tubing to latch with an overshot). POOH, RDMO pipe recovery unit. Lay down all tubing. Well KDU 5 Pull Tubing, Flow Up 9%" Casing Page 2 8. Replace the dual 3½" pipe rams (lower pipe rams) with single 4" pipe rams. Install test plug and retest BOPs. Pull test plug, install wear bushing. PU string of 4" work pipe (14 ppf, S-135, HT-38). 9. If the dual packer is still in the hole, latch it with an overshot and attempt to jar it loose. If needed, burn over and retrieve the dual packer. Also, retrieve the remaining 3½" tubing and blast joints down to the model DB packer at 4353'. 10. PU a packer mill with packer-retrieving tool, two junk basket, and 4%" collars. Mill up the model DB packer at 4353'. Circulate hole clean. TOH. LD packer, mill, etc. Be aware of possible lost returns. 11. Retrieve the remaining tubing down to the model DB packer at 5465'. 12. PU 8½" bit & scraper and TIH to bottom. Clean out fill to 5465' applying HEC gel sweeps as needed to clean the hole. 13. MIRU electric line. RIH with CIBP for 9%", 47 ppf casing. Correlate, set CIBP above model DB packer at 5465'. POOH, RDMO electric line. 14. PU and TIH with 7", 23 ppf, L-80 scab liner to isolate perfs 4050' - 4267'. Set scab liner, TOH laying down work string. Pull wear bushing. 15. PU tubing hanger with one pup joint of 7" tubing. Land hanger and test. Install 6" 2-way check, ND BOPs and NU 7-1/16", 3M tree. Test tree. Note: Minimum ID in the tubing hanger is 5.469" in the BPV profile. 16. RDMO workover rig. Pull 2-way check when the rig is clear. 17. MIRU 1%" coil tubing and nitrogen. Test lubricator and BOPs to 2000 psig. RIH with coil tubing to 5400' CTM. Jet well dry using nitrogen. Reverse out fluid if unable to lift fluids up the 95/8'' casing with 1%" coil tubing. 18. MIRU electric line. Test BOPs and lubricator to 2000 psig. RIH with 4.72", 12 spf hollow carrier guns. Tie in with GR/CCL. Perforate the Sterling C-1 Sand from 5137' - 5187' with maximum underbalance. POOH, RDMO electric line. 19. Flow well KDU 5 as per instructions of Production Foreman. Well KDU 5 Pull Tubing, Flow Up 9%" Casing Page 3 JGE August 30, 2000 C:WlyFiles~DrillingXKDU-5Lk9204499Xprocedur. WPD I FIow Nipple IIFIowLinel 13 5/8" 5M Annular Preventer 113 5/8" 5M Double I I Ram Preventer I 3 1/8" 5M Manually I Operated Valves ,,~ I 113 5/8'' 5M or°ssI I 13 5/8" 5M Single Ram Preventer I Pipe Ram I IBlind RamI I Pipe Ram I I 13 1/8" 5M HydraulicallyI IOperated Valve I , Operated Valve Marathon Oil Company BOP Configuration 3" 5M Valves 2 9/16" 1 OM Swaco Hydraulically Operated Choke 3 1/8" 5M Manually Adjustable Choke Marathon Oil Company Choke Manifold Configuration . I{ ( Static Pressure Gradient Survey Well: KDU 51 Date: 1-Jun-99 Field: Kenai Gas Field Perfs: Sterling C-1 Borough: Kenai MPP: 5,1621 MD 4,571' TVD Slickline Company: Pollard Wireline KB-THF: 27.01 Bomb Type: McAllister quartz Gauge Number: gauge #1 - #2061 Pressure Temperature Depth Depth Pressure Temperature Gradient Grad ient (MD) (TV D) (psia) (deg F) (psi/ft) (Deg/1 00 ft) 01 01 345.11 52.7 N/A N/A 2,0001 1,9361 358.81 57.8 0.007 0.263 4,0001 3,6311 371.42 79.8 0.007 1.298 4,5501 4,0801 374.75 100.6 0.007 4.633 MPP: 5,1621 4,5771 378.44 0.007 Datum: 5,2501 4,6521 378.99 0.007 Calculated Fluid Level: unknown Flowing Pressure Gradient Survey Bottomhole Surface Depth Depth Pressure Pressure Flow Rate Measured (MD) (TVD) (psia) (psia) (MCFD) Delta-P (psi) Annular flow 4,5501 4,080. 359.12 284.71 6,817 15.63 Tubing flow 4,5501 4,0801 364.97 255.61 4,950 9.78 SE,ì~J () ,;') Field: KENAI GAS FIELD Date· Aug 31, 2000 Well' KDU-51 -9-5/8" Casing Flow vs 7" Tubing Flow File' KDU-SL Tit le: POOL 6 INPUT DATA 400.0~ , , , , , , , , , , , , , , , , CORNZSH _ _ DARCY CASED HOLE 6as grav 0.5570 602 0.02 H2S 0.00 _ Hater gray ~.0000 ~ - Cond-gas ratio 0.00 STB/MMCF ~ Wtr-gas ratio 0.~0 STB/MMCF ~ 300.0 ' Meas depth 5,62. feet TVD 4577. feet ~ _ - Abs Rough 0.00,05 in ~ Pwh ~50 psia ~ · ~ Twh 53. Deg F ~ - - Tbh ,02. Deg F ~ - Res Press 370. psia 'Res Temp ,02. Beg F ~ _ Drain radius ~440. ft o yJ Net thickness 40. ft ~ Comp interval 40. ft ~ 200.0 Eff perm J490. md Skin 4.80 ~ Wellbore radius 6., in ~ ~ Shot density 8.00 SPF -~ Tunnel length 7.0 in Perf die 0.33 in - CZ k/Res k 0.400 Turb coef ,.082E+07 ,/ft -- O. ~0000. 20000. 30000. 40000. 50000 Gas Rate, MCFD A A 6.366 inches O O 8.68, inches ~ ~ n,l,i n Ii l, Il i Kenai Gas Field Well KDU//5, Pad 34-31 Marathon Oil Co., Alaska Region RT-GL: 27.00' 692' N &1720' W of SE Corner Sec, 31, T5N, RIlW Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. ,, Anc~orage 20", 94#, H-40 Drive pipe @ 97' 13-3/8", 61#, K-55 Casing @ 2521' Cmt w/2200 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve @ 3976' ID = 2.750" Otis "XN" Nipple @ 4001' ID = 2.635" Shortstring Perfs A-8 4050' - 4052' (Sqzd 11118178) A-8 4052' - 4054' (Sqzd 4/14/82) A-8 4054' - 4094' (4~82) A-II 4261'- 4267' (4/82) Otis "XA" Sliding Sleeve @ 3951' ID = 2,750" Opened 2/19/98 for annular flow Baker A-5 Dual Packer @ 3986' Blast Joints 4049' - 4109' & 4247' - 4287' Otis "XA" Sliding Sleeve @ 4318' ID = 2.750" Longstring Perfs C-1 5133' - 5135' (Sqzd 4/23/82) C-1 5137'- 5187' (4/82) C-1 5189' - 5191' (Sqzd 4/22/82) Fill @ 5395' WLM (5/19/96) Abandoned Longstring Perfs 5520' - 5520' (Sqzd 10117178) 5533'- 5563' 5601'- 5603' (Sqzd 1019178) 5713'- 5715' (Sqzd 10/8/78) 5743' - 5763' 5779' - 5789' 5791' - 5793' (Sqzd 10110178) 5853' - 5863' (Sqzd 4/14/82) 5865' - 5867' (Sqzd 10/7/78) 5875'- 5877' (Sqzd 10/16/78) 6561'- 6571' (Sqzd 11/7/78) 6602'- 6604' (Sqzd 11/5178) 7412' - 7422' (Sqzd 416182) 7424' - 7426' (Sqzd 10/7/78) 7724' - 7726' (Sqzd 10/7/78) 7877'- 7887' (Sqzd 4~6/82) 7907' - 7917' (Sqzd 4~6/82) 7919' - 7921' (Sqzd 1016178) 7974'- 7976' (Sqzd 416182) 8014'- 8024' (Sqzd 416182) 8024'- 8026' (Sqzd 10/6/78) 8127' - 8147' (Sqzd 415182) 8152'- 8154' (Sqzd 1015178) 8460' - 8472' (Sqzd 415182) 8472' - 8474' (Sqzd 10/2/78) 8480'- 8482' (Sqzd 10/5/78) 8545'- 8547' (Sqzd 10/21/78) Baker Model DB Packer @ 4353' Otis "XA" Sliding Sleeve @ 4398' ID = 2.750" Sleeve opened 5~5~82 Otis "XA" Sliding Sleeve @ 5429' ID = 2.750" Sleeve opened 5/5/82 Baker Model DB Packer @ 5465' Otis "XN" Nipple @ 5512' ID = 2.635", PXN Plug set 7/7/82 Baker model E HydroTrip Sub @ 5534' ID = 2.781" Cement retainer @ 5828' Cement retainer @ 6100' Cement retainer @ 8027' 9-5/8", 47#, S-95, BTC Casing @ 10417' Cmt w/2000 sks of Class G Last Rev: JGE, 2/26/98 TD @ 10,502' PROPOSE D Kenai Gas Field Well KDU #5, Pad 34-31 Marathon' Oil Co., Alaska Region RT-GL: 27.00' 692' N &1720' W of SE Corner Sec. 31, T5N, RllW Isolated/Plugged Perfs A-8 4050' - 4052' (Sqzd 11/18/78) A-8 4052' - 4054' (Sqzd 4/14/82) A-8 4054'- 4094' (4~82) A-11 4261'- 4267' (4~82) Active Per~ C-1 5133'-5135' (Sqzd 4/23/82) C-1 5137'-5187' (4/82) C-1 5189'-5191' (Sqzd 4122182) Abandoned Perfs 5520'-5520' 5533'-5563' 5601'-5603' 5713'-5715' 5743'-5763' 5779'-5789' 5791'-5793' 5853'-5863' 5865'-5867' 5875'-5877' 6561'-6571' 6602'-6604' 7412'-7422' 7424'-7426' 7724'-7726' 7877'-7887' 7907'-7917' 7919'-7921' 7974'-7976' 8014'-8024' 8024'-8026' 8127'-8147' 8152'-8154' 8460'-8472' 8472'-8474' 8480'-8482' 8545'-8547' (Sqzd 10/17/78) (Sqzd 10/9/78) (Sqzd 10/8/78) (Sqzd 10/10/78) (Sqzd 4/14/82) (Sqzd 10/7/78) (Sqzd 10/16/78) (Sqzd 11/7/78) (Sqzd 1115178) (Sqzd 4/6/82) (Sqzd 10/7/78) (Sqzd 1017178) (Sqzd 4/6/82) (Sqzd 4/6/82) (Sqzd 10/6/78) (Sqzd 4/6/82) (Sqzd 4/6/82) (Sqzd 10/6/78) (Sqzd 4/5/82) (Sqzd 1015178) (Sqzd 415182) (Sqzd 10/2/78) (Sqzd 1015/78) (Sqzd 10/21/78) Last Rev: JGE, 8/30/00 TD @ 10,502' 20", 94#, H-40 Drive pipe @ 97' 13-3/8", 61#, K-55 Casing @ 2521' Cmt w/2200 sks of Class G 7", 23 ppf, L-80 scab liner 4020' - 4300' CIBP @ 5455' Baker Model DB Packer @ 5465' Otis "XN" Nipple @ 5512' ID = 2,635", PXN Plug set 7~7~82 Baker model E HydroTrip Sub @ 5534' ID = 2,781" Cement retainer @ 5828' Cement retainer @ 6100' Cement retainer @ 8027' 9-5/8% 47#, S-95, BTC Casing @ 10417' Cmt w/2000 sks of Class G ..., I il&o,=„s 1 AA K enai Gas Field W ell KDU #5, Pad 34 -31 MARATHON Marathon Oil Co., Alaska Region RT-OL: 27.00' 692' N &1720' W of SE Comer Sec. 31, TSN, RI 1W 4 ■ 20', 945, H-40 Dm+e pipe @ 97 Shortatrieg Tubing 3-1/r, 9.25, N-80. Butt. A , 13 -3/8', 615, K -S5 Caring ® 2521' CnU w12200 sks o(Class G Lagstrinetking 3 -1/2', 9.25, N-80, Butt. Otis 'kV Sliding Sleeve ® 3976' Otis'XA' Sliding Sleeve @ 3951' ID - 2.750' ID ° 2.750" Opened 2/19/98 for annular flow Otis')O ' Nipple @ 4001' X P BakerA-5 Dual Packer ® 3986' ID •2.635' XN Blast Joints 4049' Q A-8 4050' -4057 (Sqzd I l/I 8/78) — A-8 4052' -4054' (Sgad4/14'82) • () Otis 'XA' Sliding Sleeve @4318' A-8 4054' — ID - 2750' A-11 4261' - 4267' (4/82) >< W Baker Model DB Packer@ 4353' C-I 5133' - 5135' (Sqzd 4123/82) ( Otis'XA' Sliding Sleeve @ 4398' C-1 5137 -5187' (4/82) i ■ ID 2.750' C-I 5189' - 5191' (Sqzd 4/22/82) Sleeve opened 5/5/82 Fill @ 5395' WLM(5/19/96) Otis'XA' Sliding Sleeve @ 5429' [ ID 2750' [ Sleeve opened 5 /5/82 5520' - 5520' (Sqzd 10117 /7) B Model DB Packer @ 5465' 5533' - 5563' !'' ' " ata 5601' - 5603' (Sqzd 10/9/78) 5713' N' 5517 5743' - 5763' 5713' - 5715' (Sqzd 10/8/78) o ID — 2.635', PPXN Plug set 717/82 5779' - 5789' Baker model E HydroTrip Sub @ 5534' 5791' - 5793' (Sqzd 10/10/78) ID - 2.781' 5853' - 5863' (Sqzd 4/14/82) 5865' - 5867 (Sqzd 10/7 /78) 5875' - 587? (Sqzd 10/16/78) 6561' -6571' (Sqzd 1In/78) RN 6602'-6604' (Sqzd 11/5/78) _ S■ 7414-7422' (Sqzd 4/6/82) v �� r on 7424' - (Sqzd 10/7/78) 7724' -7726 (Sgzd ionin) _ Cement retainer (a)5828' 787? -7887' (Sqzd 4/6/82) ■■ 7907 - 7917 (Sqzd 4/6/82) _ 7914 0/6 .7921' (Sqzd 1 /78) L L- .- � r � .■ % 7974' •7976 (Sgzd 416/82) - --.: Cement maim: c 6100' 8014' - 8024' (Sqzd 4/6/82) 8024' - 8026' (Sqzd 10/6/78) MO 8127 -8147 (Sqzd 4/5/82) -- MI 8157 -8154' (Sqzd 10/5 /78) v v �� r 8460'-847? (Sqzd 4/542) 8472' - 8474' (Sqzd 10/1/78) — Cement retainer ®802T 8480' -8482' (Sqzd 10/5/78) 8545' -8547 (Sqzd 10/21/78) MIS C,-, " V1 • A c ' `- 9-5/8', 478, S-95, BTC Casing @ 10417 TD (dl 10502' Cmtw/ 2000 sks of Class G Alaska jion Domestic Production Marathon Oil Company August 31, 2000 P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Reference: Workover of KDU 5, Kenai Gas Field Dear Mr. Wondzell: Attached is an Application for Sundry Approval for a workover of well KDU 5 in the Kenai Gas Field. As part of this workover, Marathon is proposing that the well be equipped to flow up the 9%" production casing. This is the same concept that was performed in well KU 43-6a in April 2000, which increased deliverability in that well from 6.3 MMCFD to 14 MMCFD. A tubingless completion of KDU 5 will economically benefit the Sterling Pool 6 and the Kenai Gas Field in several ways. It postpones the installation of additional compression at the Kenai Gas Field. It lowers the forecasted abandonment pressure of Pool 6, increasing proven gas reserves and field life. On a dollar per MCFD basis, a workover such as this reduces Marathon's cost of developing deliverability by an order of magnitude compared to conventional alternatives. Purpose The objective of this workover is to increase gas deliverability from the Sterling Pool 6 by removing tubulars and completion equipment that are restricting flow. Because the Sterling Pool 6 is depleted to roughly 400 psi bottom-hole pressure, the friction pressure drop in small tubulars is enormous. When well KDU 51 was converted to annular flow in the Sterling Pool 6 in February 1998, the reduction in friction increased gas deliverability from 6.0 to 9.6 MMCFD. Similarly, removal of the remaining restrictions could improve deliverability of KDU 5 to as much as 25 MMCFD. The attached diagram shows the expected deliverability from well KDU 5 if flow occurs up 9%" casing or 7" tubing. As the diagram shows, even 7" tubing presents a significant restriction to flow in well KDU 5. Use of 7" tubing reduces deliverability by 26% compared to flow up the 9%" casing. There is also a cost savings associated with not having to purchase and install 7" tubing, but cost savings is not Marathon's key reason for making this request. This workover is an attempt to increase well deliverability, and Marathon's primary reason for wanting to flow up the 9%" casing is to maximize deliverability. A subsidiary of USX Corporation Environmentally aware for the long run. Workover of Well KDU 5 Kenai Gas Field Page 3 Well Workover & Production Operations The procedure for the workover of well KDU 5 is very similar to well KU 43-6a. Marathon recommends that a 3,000 psig BOPE test is adequate for this well. A diagram of the BOPE configuration is included in the attached Sundry Application. A back-pressure valve profile will be included in the proposed wellhead to make for a safer rig demobilization. A 500-psi casing pressure test will be accomplished prior to mobilization of the workover rig (see step//2 on the attached procedure). During production of the well, there will be no "kill string" in place, but the low bottomhole pressure (1.5 ppg EMW) and high compressibility of the wellbore fluids make it easy to kill by bullheading fresh water. Sand production has historically not been an issue with any of the Sterling Sands in the Kenai Gas Field unless a well also produced a significant volume of water. The Sterling Pool 6 is a volumetric gas reservoir that produces minimal water. Second, as the table below shows, the expected peak flow rate of 25 MMCFD will be well below the calculated erosive threshold. The existing twin 3" flowlines will be replaced with a single 8" flowline, thereby eliminating erosion concerns in the flowline. Concerns Addressed Pressure Containment - The static bottom-hole pressure of the Sterling Pool 6 is approximately 360 psig (1.5 ppg EMW). The proposed wellhead and tree are rated for 3,000 psi. The well will be equipped with surface safety devices that shut in the well automatically in the event of production upset. The wellhead will be equipped with a 6" back-pressure valve profile. Precedent - This workover in KDU 5 is the same concept that was approved and implemented in KU 43-6a in April 2000. Bottom hole pressure, corrosion/erosion potential, and other concerns related to converting well KDU 5 to tubingless flow are very similar to those addressed in well KU 43-6a. Corrosion Potential - Analysis of the produced gas from the Sterling Pool 6 in the Kenai Gas Field confirms that there is virtually no corrosion potential. This is consistent with field observatiOn. The partial pressure of carbon dioxide is 0.4 psi which is substantially below the commonly recognized corrosion threshold. Furthermore, there is no hydrogen sulfide gas produced in the Kenai Gas Field. Erosion Potential - The Sterling Pool 6 does not have a history of sand production. Erosion potential is minimal whether the well is produced up 9%" casing or 7" tubing, and either is an improvement over the current annular flow status. Workover of Well KDU 5 Kenai Gas Field Page 4 9%" Casing 8.681 120 none 106.5 9%" Casing 8.681 120 0.5 82.3 9%" Casing 8.681 120 1.0 58.2 8" Flowline 6.875 120 none 66.8 7" Tubing 6.366 120 none 57.3 Please contact me if you need any further information. Your prompt reply to Marathon's request is greatly appreciated. Please contact me if you need any further information. Sincerely, J.G. Eller Completions Engineer $6'q - 6 :~t6 g:~cmn~drlg~kgf~wells~kdu. SEAogccOl a.xls STATE Of ALASKA ~ ALAS~ OIL AND GAS CONSERVATION bOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate . Plugging__ Perforate._._ Pull Tubing Alter Casing Repair Well Other X 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 692' N & 1720' W of SE Corner of Sec. 36, T5N, R11W, S.M. At top of Productive Interval 5. Type of Well: Development X Exploratory Stratigraphic Service At Effective Depth Convert to Annular Flow At Total Depth 715' S & 3051' E of NW Corner of Sec. 36, T5N, R11W, S.M. 6. Datum Elevation (DF or KB) 72.2 feet 7. Unit or Property Name Kenai Deep Unit 8. Well Number KDU #5L 9. Permit Number 78-55 10. APl Number3 O9 11. Field/Pool Kenai Gas Field, Pool 6 12. Present Well Condition Summary Total Depth: measured true vertical 10502 feet 9695 feet Plugs (measured) PXN plug {~ 5512' MD Cement retainer {~ 5828' MD Effective Depth: measured true vertical 5384 feet 4768 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: Length Size 97' 20" 2521' 13-3/8" 10417. 9-5/8" measured C-1' 5137' - 5187' MD Cemented Driven 2200 sks 2000 sks Measured Depth 97. 2521' 10417. True Vertical Depth 97' 2384' 9612' true vertical C-1' 4556' - 4598' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2~, N-80 tubing to 5534' MD Packers and SSSV (type and measured depth) Baker model A-5 dual packer {~ 3986' MD Baker model D packer (~ 4353' MD Baker model SAB packer @ 5465' MD RECEIVED MAR 19 1998 Alasla 0il & Gas Cons. Commission Anchorage 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) Treatment Description Including Volumes Used and Final Pressure ORIGINAL ¸14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 5600 0 0 100 Subsequent to Operation Test data not yet avilable. 15. Attachments 16. Status of Well Classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil__ Gas X Suspended ~at th .~g Jo true ~t to the best of my knowledge. Signed Form 10-404 Rev. 06~5/88 ~ ~ Service Date 11-Mar-98 Submit in Duplicate Kenai Gas Field Well KDU #5, Pad 34-31 Marathon Oil Co., Alaska Region RT-GL: 27.00' 692'N &1720' W of SE Comer Sec. 31, T5N, R11W Shortstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve ~ 3976' ID = 2.750" Otis "XN" Nipple ~ 4001' ID = 2.635" Shortstring Perfs A-8 4050' - 4052' (Sqzd 11/18/78) A-8 4052' - 4054' (Sqzd 4/14/82) A-8 4054' - 4094' (4/82) A-11 4261' - 4267' (4/82) Longstfing Perfs C-1 5133'-5135' (Sqzd4/23/82) C-1 5137'-5187' (4/82) C-1 5189'- 5191' (Sqzd4/22/82) Fill ~ 5395' WLM (5/19/96) Abandoned Longstring Perfs 5520'-5520' (Sqzd 10/17/78)'~--' 5533'- 5563' 5601'- 5603' (Sqzd 10/9/78-) ..... 5713'- 5715' (Sqzd 10/8/78) 5743'- 5763' 5779'- 5789' 5791'- 5793' (S~78) ...... 5853'- 5863' (Sqzd 4/14/82) 5865'- 5867' (Sqzd 10/7/78) 5875'-5877' (Sqzd 10/16/78) 6561'- 6571' (Sqzd 11/7/78) 6602'- 6604' (Sqzd 11/5/78) 7412'- 7422' (Sqzd 4/6/82) 7424'- 7426' (Sqzd 10/7/78) 7724'- 7726' (Sqzd 10/7/78) 7877'- 7887' (Sqzd 4/6/82) 7907'- 7917' (Sqzd 4/6/82) 7919'- 7921' (Sqzd 10/6/78) 7974'- 7976' (Sqzd 4/6/82) 8014'- 8024' (Sqzd 4/6/82) 8024'- 8026' (Sqzd 10/6/78) 8127'- 8147' (Sqzd 4/5/82) 8152'- 8154' (Sqzd 10/5/78) 8460' - 8472' (Sqzd 4/5/82) 8472'- 8474' (Sqzd 10/2/78) 8480'- 8482' (Sqzd 10/5/78) 8545'- 8547' (Sqzd 10/21/78) Last Rev: JGE, 2/26/98 TD ~ 10,502' 20", 94#, H-40 Drive pipe ~ 97' 13-3/8", 61#, K-55 Casing ~ 2521' Cmt w/2200 sks of Class G Longstring Tubing: 3-1/2", 9.2#, N-80, Butt. Otis "XA" Sliding Sleeve ~ 3951' ID = 2.750" Opened 2/19/98 for annular flow Baker A-5 Dual Packer ~ 3986' Blast Joints 4049' - 4109' & 4247' - 4287' Otis "XA" Sliding Sleeve ~ 4318' ID = 2.750" Baker Model DB Packer ~ 4353' Otis "XA" Sliding Sleeve ~ 4398' ID = 2.750" Sleeve opened 5/5/82 Otis "XA" Sliding Sleeve ~ 5429' ID = 2.750" Sleeve opened 5/5/82 Baker Model DB Packer ~ 5465' Otis "XN" Nipple ~ 5512' ID = 2.635", PXN Plug set 7/7/82 Baker model E HydroTrip Sub ~ 5534' ID = 2.781" Cement retainer ~ 5828' Cement retainer ~ 6100' Cement retainer ~ 8027' 9-5/8", 47#, S-95, BTC Casing ~ 10417' Cmt w/2000 sks of Class G 980225B.XLS MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 2/25/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Pull PX plug FIELD: TUBING: Kenai Gas Field WELL #: KDU-5L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 OTHER: Day #7 & #8, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 2/25/98 RU slickline on KDU-5L. SITP = SICP = 590 psig. Test BOPE and lubricator to SITP. RIH with impression block, tag fluid level at 4326' WLM. POOH. PU JUC pulling tool, RIH to extended neck prong at 4341' WLM. Latch prong, try to pull prong, but sheared off. POOH, repin JUC, and rerun with same results. POOH, secure well, SDFN. 2/26/98 RU slickline. Test lubricator to SITP. RIH with JDC pulling tool. Latch prong, POOH with prong. RIH with GS pulling tool. Latch PX plug body, POOH with plug. RDMO slickline. --- FINAL REPORT--- RECEIVED Naska 0il & Gas Cons, CommiSs! Anchorage Vendor Equipment Daily Cost Cumulative Cost APC Fab. work, vac. trucks, crews $0 $2,500 Dowell Nitrogen, coil tubing $700 $34,050 Misc. Lighting, scaffolding, etc. $500 $2,000 Pollard Wireline Slickline $2,650 $6,900 Udelhoven Crane $0 $1,542 Weaver Bros. Trucking $0 $1,800 DAILY COST: $3,850 CUM: $48,792 REPORTED BY: J.G. Eller MARATHON OIL COMPANY?~. DALLY WELL OPERATIONS RE"-"RT PAGE 1 OF 1 DATE: 02/24/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KDU-5L TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Steding C-1 Use coil tubing to completely remove packer fluid OTHER: Day #6, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 1300 RU Dowell 1.5" coil tubing unit on KDU-5L. Pressure test lines, pipe rams, blind rams, and other BOPE to 1500 psig. SITP = SICP = 650 psig. RIH with coil tubing. Tag PX plug at 4300' CTM. Begin jetting nitrogen at 350 SCF/min while taking returns on tubing. Tubing pressure fell to about 150 psig and held. Recovered approximately 4 bbl of packer fluid almost immediately, then getting straight nitrogen returns. Shut down nitrogen and shut in returns for 30 minutes to let any remaining fluids fall to bottom. Resumed jetting nitrogen at 500 SCF/min, but never saw any more fluid at surface. POOH. RDMO coil tubing. Left well with 500 psig tubing pressure. Note: Yesterday recovered 187 bbls of packer fluid, so total fluid recovery from KDU-5 is 191 bbl. Note: Tomorrow, slickline will pull PX plugs from KU 21-6L and KDU-5L. Coil tubing is moving to well KU 14-32L to shift open the sliding sleeve and jet out any packer fluid. RECEIVE[ 19 1998 Alaska 0il & Gas Cons. Com~ Anchorage ission Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $0 $4,250 Dowell i Nitrogen, coil tubing $15,000 $33,350 Misc. Lighting, scaffolding, etc. $500 $1,500 Weaver Bros. Trucking $0 $1,800 APC Fab. work, vac. trucks, crews $90 $2,500 Udelhoven Crane $1,152 $1,542 ,,, DAILY COST: $16,742 CUM: $44,942 REPORTED BY: J.G. Eller MARATHON OIL COMPANY/'~', DALLY WELL OPERATIONS RE~'"RT PAGE 1 OF 1 DATE: 02/23/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KDU-5L TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 Pump nitrogen to remove packer fluid OTHER: Day #5, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 0700 1700 RU Dowell nitrogen unit on 9-5/8" casing of KDU-5L. SITP = 0 psig, SICP = 200 psig. Pressure test lines to 2000 psig. Pump nitrogen down casing, taking packer fluid returns on tubing. Continue until nitrogen blowing around tubing when casing pressure reached 1300 psig. Bled tubing and casing down to 650 psig. Secure well, SDFN. Note: Tomorrow plan to rig-up coil tubing on KDU-5L to jet out remaining packer fluid from tubing. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $0 $4,250 .... Dowell Nitrogen, coil tubing $7,000 $18,350 Misc. Lighting, scaffolding, etc. $500 $1,000 Weaver Bros. Trucking $1,800 $1,800 APC Fab. work, vac. trucks, crews $340 $2,410 Udelhoven Crane $390 $390 DAILY COST: $10,030 CUM: $28,200 REPORTED BY: J.G. Eller DALLY WELL OPERATIONS RE~'"~T PAGE 1 OF 1 MARATHON OIL COMPANY,,~''', DATE: 02/19/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: Kenai Gas Field WELL #: KDU-5L TUBING: 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 Shift open sliding sleeve OTHER: Day #4, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 080 150 180 190 RU Dowell nitrogen unit on tubing of KDU-5L. SITP = 340 psig, SICP = 0 psig. Pressure test lines to 2500 psig. Pressure test tubing and PX plug to 1800 psig. Plug holding steady; no change in 3ressure on other strings. RD Dowell nitrogen unit, leaving 1800 psig applied on tubing of KDU-5L. MIRU Pollard Wireline. Test BOPE and lubricator to SITP. SITP = 1800 psig, SICP = 0 psig. RIH with "B" shifting tool. Latched "XA" sliding sleeve at 3951' MD. Jar up to open sleeve; tubing 3ressure fell to 1500 psig and casing pressure increased to 200 psig. Continued to jar up. Shifting tool released and could not be re-engaged, indicating full travel of sliding sleeve to open position. POOH, RDMO slickline. Lined up KDU-5L to production system. Blew tubing down to zero psig. Secure well. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $800 $4,250 Dowell Nitrogen, coil tubing $3,800 $11,350 DAILY COST: $4,600 CUM: $18,170 REPORTED BY: J.G. Eller MARATHON OIL COMPANY/-",, DALLY WELL OPERATIONS PAGE 1 OF 1 DATE: 02/18/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Kenai Gas Field WELL #: KDU-5L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 OTHER: Day #3, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 0800 1630 1700 RU slickline on KDU-5L. Test lubricator and BOPE to SITP. RIH with JDC pulling tool. Latch prong, but sheared pulling tool. POOH, redress pulling tool, RIH. Latch prong at 4304' WLM, POOH. RIH with GS pulling tool, latch PX plug body at 4307' WLM, POOH. Inspection of PX plug and prong shows that the bottom packing of the prong is cut. Redress all packings on PX plug and prong. RIH with redressed PX plug on X-line running tool. Set PX plug in X-profile @ 4307' WLM. POOH. RIH with check-set tool, verified that lock is set properly. POOH. RIH with extended neck prong and set in PX plug. POOH, RD slickline. Lined up KDU-5L to production seperator to negative test PX plug. Tubing successfully bled to zero. Left well shut in and secured overnight. Note: Plan to rig up nitrogen unit on KDU-5L in the morning to pressure test the PX plug and tubing to 1800 psig. Slickline will move to KU 21-6L to shift open sliding sleeve. RECEIVEDi Alaska 0il & Gas Cons. Commts~n Anchorage Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,600 $3,450 DAILY COST: $1,600 CUM: $13,570 REPORTED BY: J.G. Eller MARATHON OIL COMPANY~~', DALLY WELL OPERATIONS RE'~"W,T PAGE 1 OF 1 DATE: 02/17/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: FIELD: TUBING: Kenai Gas Field WELL #: KDU-5L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 OTHER: Day #2, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS 8OO 5OO 700 RU Dowell nitrogen pumping equipment on 9-5/8" casing of KDU #5. Test lines to 2000 psig. Initial 3ressures as follows: 9-5/8" casing = 200 psig 13-3/8" casing = 30 psig Iongstring tubing = 350 psig shortstring tubing = 330 psig Pressure test 9-5/8" casing to 1800 psig using nitrogen. The 9-5/8" casing pressured up immediately, other pressures unchanged. Bled 9-5/8" casing to 0 psig. RU nitrogen pump on tubing of KDU-5L and pressure test to 2200 psig. Pump 6500 SCF of nitrogen down tubing, but tubing not ~ressuring up. Holding steady at 350 psig. RD Dowell, move to well KU 21-6. _ine up KDU-5L to the test seperator, attempt to negative test PX plug. Well KDU-5L is flowing as if no PX plug is in place. Shut in KDU-5L. Note: Plan to move slickline to KDU-5L to pull and inspect PX plug. If packings on plug are damaged will try to reset plug; otherwise will look into other methods of plugging the Iongstring tubing. Vendor Equipment Daily Cost Cumulative Cost Dowell Nitrogen, coil tubing $7,550 $7,550 Misc. Lights, etc. $500 $500 DALLY COST: $8,050 CUM: $11,970 REPORTED BY: J.G. Eller MARATHON OIL COMPANY''~ DALLY WELL OPERATIONS RI;'~'~RT PAGE I OF I DATE: 02/16/98 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: Set PX plug. FIELD: TUBING: Kenai Gas Field WELL #: KDU-5L 3-1/2", 9.2#, N-80 CASING: 9-5/8", 47#, N-80, LTC TREE CONDITION: Good BENCHES OPEN: Sterling C-1 OTHER: Day #1, AFE 0480598 - Convert to Annular Flow SUMMARY OF OPERATIONS Conduct safety meeting with Pollard VVireline personnel. MIRU slickline on KDU-5L. Pressure test BOPE and lubricator to SITP. RIH with braided scratcher to 4320' WLM. Work scratcher across nipple profiles at 3938' WLM & 4306' WLM several times to clean. POOH. RIH with PX plug on X- line running tool. Work past nipple at 3938' WLM, attempt to set in nipple at 4306' WLM. POOH. RIH with check set tool, found plug set in nipple at 3938' WLM. POOH, PUGS pulling tool, RIH and retrieve PX plug. Rerun PX plug, could not locate in nipple at 4306' WLM. POOH. Rerun PX plug, can't get past nipple at 3938' WLM. POOH. Upper pin of running tool had sheared. Repin and rerun PX plug. Work past nipple at 3938' WLM, and set PX plug in nipple profile at 4306' WLM. POOH. RIH with check set tool. Vedfied that PX plug is set properly. POOH. RIH with extended-neck prong, set in PX plug at 4306' WLM. POOH, RDMO slickline. RECEIVED Alaska 0il & Gas Cons, Commission Anchorage _.J Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Slickline $1,850 $1,850 APC Fabrication, roustabouts $2,070 $2,070 DAILY COST: $3,920 CUM: $3,920 REPORTED BY: J.G. Eller 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · i _.L ,1. il Abandon 8U6'pelld Operatl0fl ~ll~[doW~ Re. ertter 8 Well Alter Ca=lng Repair Wag__ Plugging._., Time F. xten$1ee Stimulate .. Change Approved Program Name'of 6i~arat°r MARATHON OIL COMPANY Address :: P. O. Box 1,96168, Anohora~e. AK 995t g-el68 location of Well at Surface 692' N & 1720' W of SF_ Cmner of Sec. 36, TSN, R11W, S,M. Al top of Produoth~e Interval Pull Tubing,..,., Varlanoe__ D, OPm X 8tratigraphic 8ervJoe At Effective Depth Convert to Annular Flow At Tot~ Depth 715' ,.q & 30~1' E of NW Corner c~ See. 36, TSN, R1 tW, 8.M. t2. Pre~,er~W'e'lf Condition Sui~imary Total De~h: measured 10502 rem true vertioal g695 rem Plup (measured) PXN pug ~t ~t12' MD Cemefl~ mlalner Q 5~28' MD Effeotive Depth: measured 5384 feet true vertical 4768 feet Junk (measured) Ca,lng Length Size Structural ¢ondu~or 97 20" Surraoe 252r t3-3/8" I~ed~ Pr~uct~ 1~t T ~" ~r P~omtlon Oe~h: m~sur~ C-1: 5t3~ - 518~ MD C,m,nled Meaeured Dep~ /'me Verli~l Driven g7' 97' 2200 sks 2521' 2384' 2000 aka 10417' ~612' true vadleal C-1: 4556' - aS98' TVD Tubi~ (t, lze, grade, and measured depth) 3-1/2". 9.2~, N-80 lublng to 5534~ MD ORIGINAL Packers and S$SV (type and measured depth) Baker model A-5 dual peel<er ~13988' MD Baker model O Fader O 4353' MD a.ker model ~,SAa p.d~ a ..~s' MD la, Mtach~ner~S De~riptlon Summary of Prepeeal__ Detalk~d Operalkm Program ~ ..... t4. E,~timatad'~te for Oomm~cing Operation ...... I$. 6tatul of Will Classllioatl~'~s; .... lr23/98 16, If Proposal w"as Verbally Approved 011 Gas X Name of Approver Dale Approved 8~wvloe i,, ii i .iii 17. I I~reby certify th-LLhe foregoing is true, pnd ~rrec~ ~o ~e best of my knowledge. --' ..... ....... FO. COMa .mUSa0NLY ........ 'lNug~tegrity BOP Tast Location Clearano. MechamaJ Integrity Test Subeequant Fom~ R_equtmd 10-./.( o~, ~'o --- 01'JgJrial $1gneo ~ David W~ Johnston Approved b~ om,er or tl~e Commission ........... I=e.e 10-403 Rev. 03/t5/85 BOP Oa~e 1/20/98 A:pproved' Cupy Alaska Region Domestic Production (.,Marathon Oil Company P.O. Box 196168 Anchorage. AK 99519-6t 66 Telephone 907/,561-5311 January 20, 1998 Mr. Blair Wondzeil Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99,5'13-7599 Reference: Kenai Gas Field, Well KDU #5L Dear Mr. Wondzell: Please find attached a procedure for permitting annular flow in well~DU ~.5L in Kenai Gas Field. The increased flow area of producing up the g'~' casmng and the 3~" tubing simultaneously is expeoted to double the well's gas deliverability. Flow up the 9~ casing will not subject the well to excessive wear from erosion, corrosion, or burst/collapse stresses. This work is expected to commence January 23, 1998. Please contact me if further information is needed. Sincerely, ngineer A subsidiary of USX Corporation RECEIVED JA~4 21 199B Environmentally aware for the long run. Naska 0ii & C~as Cons. Commission Anchorage ~dl~l'l' l~¥:~aFa~;hon O11 Company AnClIOF age'~ WELL KDU-SL- AFE 0480598 KENAI GAS FIELD CONVERT TO ANNULAR FLOW Objective: Allow flow up the tubing-casing annulus in v~l KDU-$L to increase gas deliverability. 1. Shut in both sides of well KDU-5. Pressure test 9%" casing to SITP ofKDU-SL (al~prox.-400- e ~:fi,~ psig). When test is complete, bleed pressure off 9%" casing. 2. MIRU slickline on KDU-SL, Set PX plug in profile of XA sleeve at 4,318' ME). RD slickline. 3, MIRU nitrogen unit on KDU-5L. Pressure test PX plug to i,800 psig. Maintain 1,800 psig pressure on tubing. RD nitrogen. 4. RU slickline. MU tool string with XA shifting tool, spang jars,/ir oil jars. RIH and locate XA sliding sleeve at 3,95 I'M D. Shift open sliding sleeve at 3,95 I'M D while monitoring tubing and casing pressure. POOH. RDMO slieldine. 5. Bleed all nitrogen pressure off of tubing. 6. MIRU 1W' coil tubing and nitrogen unit. Test coil with nitrogen to 500 psig. Line up to take returns to closed-top tank. RIH jetting with nitrogen to top of PX plug at 4,318' MD. Continue to jet until all packer fluid is displaced from tubing. RDMO coil tubing and nitrogen. 7. MIKU slickline on KDU-SL. Pull PX plug at 4,318' MD. RDMO slickline. $. As soon as possible, produce well at maximum flow rate to clear any residual packer fluid from .~'~ wellbore. Put well in test separator, and record flow rate and tubing pressure. 9. Shut in KDU-5L. Install flowline on casing side of KDU-SL. When complete, flow casing side (f~ ~ and tubing side simultaneously to test separator and compare with previous test. When r ·~ ' testing is complete, produce as per instructions of Production Foreman. JGE January 19, 1998 RECEIVED JAN 21 t998 Alaska Oil & Bas Co~a. Commission Anchorage 3E~'I' ~x'~aratnon Ull Lompany ; l-zo-vo ; z;ooF~ ; ; \ I__ III 2 B A-8 Sd. A-Il Sd. C-1 Sd. t4 Eleluga Fa. VI VII VIII,~ WELL KDU ¢5 W.O. CASING & ABANDONMENT DETAIL Io Elevation of Kelly Bushing at 0.0' II, Oameron Dual 3-1/2' Tubing Hanger at 27.40' III. 20', 94~. H-40 Drive Pipe at 97' IV. 13-8/8', 81~, K-55 Oaeing at 2,521' V. Cement Retainer at 5,826' VI. Cement Retainer at 6,100' VII, Oement Retainer at 8,027' VIII. 0-5/8°, 47,*, 8-05 Gaalng at 10,417' TUBING DETAIL LONG STRING: 3-I/2", 9,;Z~ N-80 TUBING 1. Oti, 'XA' Sliding 8leave at 3,951.28' 2. Baker Model "A-6' Duel Paoker at 3,986.21' 3. Baker Blast Joints From 4,049.30' to 4,108.65' 4. Baker Blast Joints From 4,247.28' to 4,288.81' 5, Otis ~XA' Sliding Sleeve at 4,317,55' 6. Locater Sub at 4,351.6T' 7. Baker Model 'D" Packer w110.$' Seal Assembly at 4,363.00' 8. 7'. 28~ Mill Out Ext, 9,42' Long at 4,357,15' g. Bottom of Wirellne Aa-entry Guide a! 4,364.00' 10. X-over 7' x 3-1/2' at 4,366.67' 11, Otis 'XA' Sliding 8leave at 4,398.04' 1~). Otlu "XA' 811ding 8leave at 5,428.53' 13. Locater Sub at 5,463.8T' 14. Baker Model 'aAa' Peeker w/lO.5' Seal Assembly at 5,405.00' 15. 7°, 29~, Mill Out Ext. 8.;32' Long ;t 6,470.29' 10, Bottom of Mule Shoe at 5,476,00' 17, Two X-overs 7' x 4-1/2' x 3-I/2' at 5.479.61' 18. Otis 'XN' Nipple at 5,511.87' 10. Bottom of Baker Shear Out Ball Seat at 5,534,40' SHORT STRING: 3-1/2; 9.2~ N-80 TUBING A, Otis 'XA' Sliding 8leave at 3,876.12' B, Baker Model 'A-5' Dual Packer s! 3,989,64' C. Bottom of Otis 'XN" Nipple at 4°000.79' PERFORATION RECORD DA TE 41181~2 4/25182 4126/82 4/28182 41,27/82 4120/82 INTER VAL CONDITION 5,645'-5,$68' Beluga Fa. Production 4,084'-4,064' A-8 Sd. Production 4,004'-4,0~4' A-8 ~d. Proauction 4,2~I'-4,287' A-11 ,.Rd, Produ~tion 5,137'-8,147' C-1 Sd. Proauction 5,147'-5,187' c-1 Sd. Produetion 4,064'-4,094' A-8 Sd. Production 4,261'-4,267' A-11 ad. Production 5,137'-5,187' C-1 ad. Production " WELL KDU W.O. .. WELL SCHEMATIC bNIO~ OIL COMPS'NY el~ OALI~:ORNIA '-- 6,187'-5,187' C-1 Sd. Production NOTE: For more complete Perforating Record see well history, sPP'D. ~_---. , ,, s~; NONE i, RECEIVED JAN 21 1998 Alaska 0il & Oas Con~. C0mlllistlion SHEET D J. R. Callender District Drilling Superintendent Alaska District union Oil and Gas Di,'~,~on· Western Region Union Oil Company of ~J~!ifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Ouly 1, 1983 Mr. Chat Chatterton AK Oil & Gas Consrv. Comm. 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Please replace the tubing detail and schematics in the KDU #5 Well History for the workover which was completed in 1982 with the attached tubing detail and schematics. The previous material was found to be in error. Sorry for the inconvenience. Please contact $ohn Underhill at 276-7500 if you have any questions. Sincerely, ~im R. Callender 3RC/drm ,~UL '-5 ~ '* Alaska Oil & Gas Cons~ Commission Anchorage J../ /- L~UL,~. ,J~. 1/2" Butt Pup Tbg Hanger CIW ~ 1/2" 8rd Below RT 1.40' 28.40' 29.80' !.00' 27.40' 28.40' 27.40' 0 27.40' UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE A-028142 WELL NO. KDU #5 FIELD SHEET D PAGE NO. Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS SHORT STRING TUBING DETAIL 3TS 43 1 36 1 6 1 3 1 4 1 10 1 2 1 9 1 7 1 6 1 3 1 1 1 DESCRIPTION 3 1/2" Butt Otis XN ~ipple Baker Pkr Model A-5 "Dual" 3 1/2" Butt N-80 9.2# Pup Otis XA Sleeve 3 1/2" N-80 Ors Tbg 3 1/2" Butt Pup 3 1/2" Tbg ors 3 1/2" Butt PUp 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Jts Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt PUp 3 1/2" Butt Jts Tbg 3 1/2" Butt Pup 3 1/2" Butt Jts Tbg 3 1/2" Butt PUp 3 1/2''~ Butt Ors Tbg 3 1/2" Butt Pup 3 1/2" Butt Jts Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Jts Tbg 3 1/2" Butt Pup 3 1/2" Butt Jt Tbg 3 1/2" Butt PUp Tbg Hanger CIW 3 1/2" 8rd Below RT RECEIVED JUL-5 1983 Alaska 0il & Gas Cons. Commission Anchorage LENGTH ./1.00' 10.15 9.55 3.97 1297.70 5.10 ~080.21 4.12' 175.04' 10.12' 83.15' 4.20 118.21 ~ '~4.12 302.96 4.21 58.36 4.07' 273.21' 4.10' 209.20' 4.67' 180.58' 4.98' 84.60' 5.05' 28.36' 1.40' 1.O0' 27.40' TOP 3999.79' 3989.64' 3980.09' 3976.12' 2678.42' 2673.32' 1593.11' 1588.99' 1413.95' 1403.83' 1320.68' 1316.48' 1198.27' 1194.15' 891.19' 886.98' 828.62' 824.55' 551.34' 347.24' 338.04' 152.79 147.81 63.21 58.16 29.80 28.40' 27.40' 0 BTM 4000.79' 3999.79' 3989.64' 3980.09' 3976.12' 2678.42' 2673.32' 1593.11' 1588.99' 1413.95' 1403.83' 1320.68 1316.48 1198.27 1194.15 891.19 886.98 828.62' 824.55' 551.34' 547.24' 338.04' 333.37 152.79 147.81 63.21 58.16 29.80 28.40 2?.40' LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. KDU #5 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS LONG STRING TUBING DETAIL DESCRIPTION Baker Shear Out Ball Seat Pups 10' Long of 3 1/2" 9.2# Butt Tbg Otis "XN" Nipple 3 1/2" 9.2# Buttress Tbg X-over 4 1/2" Butt Box x 3 1/2" Butt Pin X-over 7" 8RD Box x 4 1/2" Butt Pin 7" 29# Mill Out Ext. Baker "SAB" Rkr LENGTH TOP BTM .65' 5533.75' 5534.40' 20.25' 5513.50' 5533.75' 1.63' 5511.87' 5513.50' 30.48' 5481.39' 5511.87' · 91' 5480.48' 5481.39' · 87' 5479.61' 5480.48' 9.32' 5470.29' 5479.61' 5.29' 5465.00' 5470.29' 34 Mule Shoe Seal Assy Locator 3 1/2" Buttress Tbg 9.2# Otis "XA" Sleeve 3 1/2" 9.2# Buttress Tbg Otis "XA" Sleeve 3 1/2" 9.2# Buttress Tbg X-over 7" 8RD Box x 3 1/2" Butt Pin 7" 29# Mill Out Ext. Baker "D" Pkr · 50' 5475.50' 5476.00' 10.50' 5465.00' 5475.50' 1.33' 5463.67' 5465.00' 31.25' 5432.42' 5463.67' 3.89' 5428.53' 5432.42' 1026.60' 4401.93' 5428.53' 3.89' 4398.04' 4401.93' 30.59' 4367.45' 4398.04' · 88' 4366.57' 4367.45' 9.42' 4357.15' 4366.57' 4.15' 4353.00' 4357.15' LEASE A-028142 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. WELL NO. KDU #5 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 48 1 15 25 1 32 OTS LONG STRING TUBING DETAIL DESCRIPTION Wireline Re-entry Guide Seal Assembly Locator 3 1/2" Butt St Tbg 3 1/2" Otis XA Sleeve (Butt) 3 1/2" Butt Ot Tbg Blast Ors (4.5" OD) 3 1/2" Butt Ots Tbg 3 1/2" Butt PUp 3 1/2" Butt PUp Blast Ots 3 1/2" Butt PUp 3 1/2" Butt PUp 3 1/2" Butt Ot Tbg Baker Rkr Model A-5 (Dual) 3 1/2" Butt Ot Tbg 3 1/2" Butt XA Sleeve 3 1/2" Butt Pup 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" BUtt Ots Tbg 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg Tbg Hanger Below PT' LENGTH TOP · 50' 4363.50' 10.50' 4353.00' 1.33' 4351.67' 30.27' 4321.40' 3.85' 4317.55' 30.74' 4286.81' 39.53' 4247.28' 118.85' 4128.43' 9.68' 4118.75' 10.10' 4108.65' 59.26' 4049.39' 10.06' 4039.33' 9.69' 4029.64' 30.60' 3999.04' 12.83' 3986.21' 29.21' 3957.0' 5.74' 3951.26' 4.05' 3947.21' 4.03' 3943.18' 266.17' 3677.01' 9.91' 3667.10' 1440.00' 2227.10' 5.05' 2222.05' 452.58' 1769.47' 759.56' 1009.91' 4.19' 1005.72' 977.35' 28.37' 1.00' 27.37' 27.37' 0 BTM 4364.00' ' 4363.50' 4353.00 4351.67' 4321.40' 4317.55' 4286.81' 4247.28' 4128.43' 4118.75' 4108.65' 4049.39' 4039.33' 4029.64' 3999.04' 3986.21' 3957.0' 3951.26' 3947.21' 3943.18' 3677.01' 3667.10' 2227.10' 2222.05' 1769.47' 1009.91' 1005.72' 28.37' 27.37' TUBING DETAIL LOAIG S THING - ,~ I/~ A. OTIS "XA" SLIDING SLEEVE AT 3951' B. BAKER BLAST JOINTS FROM 4049' TO 4109 C. BAKER BLAST JOINTS FROM 4247' TO 4286' D. OTIS "XA" SLIDING SLEEVE AT 431e' E. BAKER LOCATOR W/lO' SEAL ASSEMBLY AT 4:352' F. 7" LT I~ C X 31/2'' BUTTRESS CROSSOVER AT 4:366' G. OTIS "X/~' SLIDING SLEEVE AT 4398' H. OTIS "XA" SLIDING SLEEVE AT 5428' i. BAKER LOCATOR W/6' SEAL ASSY. I~ MULE SHOE-5464' J. ?"x4~/2" - 4~/2" x 3V2" x-OVER AT 54d0' K. OTIS "XN" NIPPLE AT 5512' L. BAKER MODEL "E" HYDRO TRiP SUB W/21/2" BALL-5554' / SHOH T S THING - ,~ ;/3 I. OTIS "XA" SLIDING SLEEVE AT 3976' 2. OTIS "XN" NIPPLE AT 4000' KDU- 5 K.B. -0' TUBING HANGER - 27.40' 153/8",6r:~,K-55 CASING AT 2,521' 9~8", BAKER MODEL A-5 DUAL PACKER AT 3,986' PERFORATION D, dT'£- //I/7Z-/F//,4Z 4/5/82 8127'- 8147' ' " 8460' - 8472' 4/6/82 8014' - 8024' " 7907'- 7917' " 7877'- 7887' "- 7412' - 7422' 4/7 &4/14/,'82 5853'-5863' 4/8 & 4/17/82 5779'- ,5789' 4/9& " 5743 - 5753' "~ 4/14/82 5533'- 5563' 4/14/82 4052'- 4054' 4/18/82 5543' - 5563' 4/22/82 5189~- 5191' 4/23/82 513;5'- ~135' 4/26,27,29/82 5137'- 5187' 4.,25,26,29/82 4054'- 4094' 4/~6,29/82 4261" 4267' RECORD COND/F/O/I/ SQUEEZED ii ii ii PRCD TEST & SQUEEZED ii . i{t ii A-8 SAND, S~UE_.~D BELJGA ~ 8 H PF C-I SAND, ISOLATION SQZ. C-I SAND, PRODUCTION ii ii 4054~- 4094~ A'8 SAND 426/- 42E ~ A-II SAND 9'~J" BAKER MODEL "DB" PACKER WITH I0' MILLOUT EXTENSION (7"CSG.) AT 43'53' 5157 - 5187~ C: l SAND 9~8" BAKER MODEL "SAD" PACKER WITH 6' MILLOUT EXTENSION (7"CSG) AT 5~465' I ECEIVED / J U L - ~ ]983 LN AJaska Oil & Gas Cons, Commi$,JiOn CEMENT RETAINER AT 5,828' J 554~~- 5565~ EELUGA unl )n ALASKA DISTRICT KDU- 5 WELLSCHEMATIC Js~.d oo,.: jc~. D.,,,' 5/8(82 Field: KENAI GAS JaN. Le~n' 715 8 3~J'E ~ NW ~,~6'.T4N, RIIW. S.M. M' ' .m LO. "Z.635:~ in ~N NIPPLES UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. 1 of 2 , ,. LEASE Kenai Deep Unit FIELD Kenai Gas Field WELL NO. KDU #5 WO LOCATION: 692'N & 1720'W of SE corner, Section 31, T5N, RllW~ SM. START DATE 3/15/82 COMP. DATE 5/4/82 CONTRACTOR Brinkerhoff RIG NO. 59 TYRE UNIT DRILL RIPE DESCRIPTION 3 1/2" & 5" IF PERMIT NO. 78-55 SERIAL NO. A-028142 ID 10502' TVD DEVIATION (BHL) COMPANY ENGINEER Watson, Graham ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL 27" RT TO DRILL DECK RT TO RRODUCTION.~CK CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 94# Drive Pipe H-40 97' Driven 13 3/8" 61# K-55 2521' 2200 sxs cl "G" w/ add. 5/8" 47# S-95 10417 ' 2000 sxs cl "G" w/ add. 3 1/2" 9 2# Butt N-80 4001' SS Dual A-5 3 1/2" Baker pkr 3 1/2" 9.2# Butt N-80 4364' LS " " PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 4/5/82 8127-8147' 8027' (Cmt ret) ~ . Sqz'd w/ 200 sxs "G" cmt " 8450-8472' 8027' _5 " 4/6/82 8024-8014' 6100' Beluqa ~) " 7917-7907' " " " 7887-7877' " " " 7422-7412' " " , 4/7/82 5853-5863' " " Opened to test Sqz'd for permanent abandonment w/ 600 sxs'"G" cmt 4/8/82 5779-5789' " " " 4/9/82 5743-5753' " " " " 5533-5563' " " ~/14/82 5853-5863' 3978' " 4/14/82 5533-5563' 3978' " ,, 'Sq,z'd w/ 250 sxs cl "G" cmt Ret ¢ 5828' ¢¢ ' t~ ;¢ ' /~ '¢ ~¢ Ret $ 5470' 4/14/82 4052-4054' 3978' A-8 sds Sqz'd w/ 200 sxs cl' "6" C'mt 4/17/82 5779-5789' 5828' Belug~ 8 HPF 4/17/82 5743-5753' 5828' " 8 HPF INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 5/5/82 Sterlinq (A-8/A-11) 6800 SS No H20 5/6/82 C-1 Sds 5920 LS 67 BWPD WELL HEAD ASSEMBLY TYPE: CASING HEAD: 20" 2000 x 20" SOW CASING HANGER: 9 5/8. CASING SPOOL: 20" 2000 psi x 13 5/8" 5000 ~ TUBING HEAD: OCT Dual 13 5/8" 3000 psi x 10" 5000 psi TUBING HANGER: Dual OCT 3 1/2" 8rd TUBING HEAD TOP: 3 1/2" 8rd EUE MASTER VALVES: 3 1/16" 5000 psi CHRISTMAS TREE TOP CONN: 3 1/2" 8rd UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. 2 of 2 LEASE WELL NO. FIELD KDU #5 LOCATION: SPUD DATE COMP. DATE CONTRACTOR RIG NO. TYPE UNIT DRILL PIPE DESCRIPTION PERMIT NO. SERIAL NO. l'D TVD DEVIATION (BHL) COMPANY ENGINEER ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS PERFORATING RECORD DATE INTERVAL E.T.D. REASON RRESENT CONDITION 4/18/82 5543-5563' 5828' Beluga 8 HPF 4/22/82 5189-5191' 5163' C-1 Sds Isolation sqz w/ 250 sxs "G" cmt. 4/23/82 5133-5135' 5068' C-1 Sds Isolation sqz w/ 250 sxs "G" cmt. 4/25/82 4054-4064' 5828' A-8 Sds Production 4 HPF 4/26/82 4064-4094' 5189' A-8 Sds Production 4 HPF " 4261-4267' " A-11 Sds " " 5137-5147' " C-1 Sds Production 4 HRF 4/27/82 5147-5167' 5213' C-i~ Sds " '~/29/82 4054-4094' 5828' A-8 Sds Production 8 HPF Total 4261-4267' " A-11 Sds " 5137-5187' " C-1 Sds " 4/29/82 5167-5187' " " Reperfed 8 HPF Production INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYRE: CASING HEAD: CASING SROOL: TUBING HEAD: TUBING HANGER: TUBING HEAD TOR: MASTER VALVES: CHRISTMAS TREE TOP CONN: UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS A 3/16/82 DAILY COST: ACC COST: AFE AMT: 8 3/17/82 DAILY COST: ACC COST: AFE AMT: C 3/18/82 DAILY COST: ACC COST: AFE AMT- O 3/19/82 DAILY COST: ACC COST: AFE AMT: 10,502' TD 10,329' ETD (Junk) 13 3/8" C 2521' 9 5/8" C 10,416 $ 21,302 $ 21,302 $1,215,000 10502' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10416' $ 27,630 $ 48,932 $1,215,000 10,502' TD 10,329' ETD (Junk) 13 3/8" C 2521' 9 5/8" C 10,416' $ 82,107 $ 131,039 $1,215,000 10502' TD 10329' ETD (JUNK) 13 3/8"-C. 2521' 9 5/8" C. 10416' 75 PCF 42 SEC $ 44,438 $ 175,477 $1,215,000 Commenced operations at 00:01 Hrs. 3/16/82. Set in matting boards, subboards, drawworks, and starting legs. Pinned derrick and set in shaker tank, degasser tank, volume tank, centrifugal house, doghouse, motors, pump house and both pumps. Continued general RU. Ail major rig components in place. Raised derrick. Began 24 hr operation © 24:00 hrs, Continued general rig up. Installed wind walls, mud lines, and choke. Rigged up lights and blew down lines. Continued general RU. Accepted rig ~ 06:00 hrs 3/19/82. RU to pull BPV's. Had to pull OCT BPV's w/ Otis WL. Opened "XA" sleeve in SS ® 5317' (appeared to be open already). Pumped water dwn SS - had no returns to annulus. Mixed & pumped 36 sxs pill of safe-seal across Beluga perfs between 5533' & 5863'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 3/20/82 DAILY COST: ACC COST: AFE AMT: 2 3/21/82 10502' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10416' 81PCF 44 SEC $ 53,499 $ '228,976 $1,215,000 10502 ' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10416' DALLY COS.T: $ 32,464 ACC COST: $ 261,440 AFE AMT: $1,215,000 3 3/22/82 DAILY COST: ACC COST: AFE AMT: 4 3/23/82 DAILY COST: ACC COST: AFE AMT: 10502' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10416' 80 PCF 43 SEC $ 29,739 $ 291,179 $1,215,000 10502' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10417' 79 PCF 45 SEC $ 33,769 $ 324,948 $1,215,000 Spotted pill & bled off press in SS- bled to 0 psi & then began to build. Bled LS to 0 psi - then press built slowly. Bled annulus to 0 psi - press built slowly. Vented annulus to flare & RIH in SS w/ GO WL & perfed 4 circ holes ~ 5023'. Displ down SS & up annulus w/ water. HaO 400 psi on SS. Displ down SS & up annulus w/ 75 pcf mud - had 150 psi on SS when totally displ. Checked LS - had 2600 psi on LS. Vented LS to flare - sanded up surf equip in 1 hr. CO surf lines. Mixed & pumped 125 bbls of 110 pcf mud down LS to base of Tyonek perfs. LS was dead. Mixed 81 pcf mud & circ down SS & up 9 5/8" csg. Both sides are dead. RU GO WL & RIH to perf LS - gun stopped ~ 5329'. POOH. RD GO. RU & RIH w/ 1 1/4" tbg. Tagged ob- struction ~ 5329'. Worked thru obstruction in LS ~ 5329' WLM (5318' tbg meas). RIH to 8105' &oirc 4 hrs. POOH & LD 1 1/4" tbg. RU GO WL - RIH & perfed LS for circ f/ 5915' to 5921' w/ 2" guns. Could not gain circ. POOH. RU to run 2nd circ gun. WL jumped sheeve. Perfed LS f/ 5885' to 5887' w/ 2" tbg perf gun - still could not circ. Clrc down SS taking returns out ann thru holes in SS ~ 5023' until clean. Installed BPV's, removed tree, installed DOPE & removed BPV's. RIH w/ 2 1/2" cutter. Cut SS ~ 5039'. Stuck jet cutter after cut. Worked free (sand). RIH w/ 2 1/2" cutter in LS. Could not go below "XA" ~ 5317' - bridged. RD GO Int. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 3/24/82 10502' TD 10329' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 80 PCF 50 SEC DAILY COST: $ 22,597 ACC COST: $ 347,545 AFE ANT: $1,215,000 6 3/25/82 DAILY COST' ACC COST: AFE AMT: 7 3/26/82 10502' TD 10329' ETD (JUNK) 13 3/8" C. 2521' 9 5/8" C. 10417' 80 PCF 51'SEC $ 47,440 $ 394,985 $1,215,000 10502 ' TD 4016' ETD (TOF) 13 3/8" C. 2521' 9 5/8" C. 10417' 80 PCF 48 SEC DALLY COST: $ 29,593 ACC COST: $ 424,578 AFE ANT: $1,215,000 8 3/27/82 DAILY COST: ACC COST: AFE AMT: 9 3/28/82 DAILY COST: ACC COST: 10502' TD 4016' ETD (TOF) 13 3/8" C. 2521' 9 5/8" C. 10417' 80 PCF 49 SEC $ 22,835 $ 447,413 $1,215,000 10502' TD 4016' ETD (TOF) 13 3/8" C. 2521' 9 5/8" C. 10417' 81PCF 48 SEC $ 36,775 $ 484,188 RIH w/ 1 1/4" tbg down LS. Circ thru bridge ~ 5313' & CO to 6118'. Circ clean. ROOH w/ i 1/4" tbg. Ran GO 2 1/2" jet cutter in LS. Cutter stopped ~ 5333'. POOH w/ cutter. Free point LS Stuck ¢ 4020'. Jet cut LS ~ 4011' No cut. Run free point in SS. ~ould not work below 2700'. Circ SS clean. Jet cut LS .4016'. Pulled & LD LS f/ cut ¢ 4016'. Pulled & LD SS f/ cut 8 5039'. LD SS. Changed 1 set of rams to 2 3/8" & one to 5". RIH w/ 2 3/8" & one to 5". RIH w/ 2 3/8" stinger on 5" DP. CO to dual pkr ~ 5381'. Circ clean. POOH. LD 2 3/8" stinger. Tested BOPE. Comp testing BOPE. RIH w/ 5" DP & OS & engauged LS @ 4016'. Could not pull tbg. Ran sinker bar in LS - stopped ¢ 5320'. RD WL. Ran 1 1/4" tbg in LS thru DP to_+5320" Milled thru obstruction ~ +5320' w/ 1 1/4" tbg. RIH to 5882'. Reamed thru obstruction f/ 5882 to 5970' w/ 1 1/4" tbg. RIH to 6040'. Circ clean. Pulled & LD 1 1/4" tbg. Ran 2 5/8" jet cutter & cut LS ~ 5967'. POOH w/ WL. Well started flowing after cut ~ 5967'. AFE AMT' $1,215,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO, LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10 3/29/82 10502' TD 5412' ETD (TOF) 13 3/8" C. 2521' 9 5/8" C. 10417' 83 RCF 46 SEC DAILY COST: $ 33,799 ACC COST: $ 517,987 AFE AMT: $1,215,000 11 3/30/82 10502' TD 5967' ETD (TOF) 13 3/8" C. 2521' 9 5/8" C. 10417' 83 PCF 46.SEC DAILY COST: $ 43,569 ACC COST: $ 561,559 AFE AMT: $1,215,000 12 3/31/82 10502' TD 10329' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 82 RCF 68 SEC DAILY COST: $ 33,773 ACC COST: $ 595,239 AFE AMT: $1,215,000 13 4/1/82 DAILY COST: ACC COST: 10502' TD 8151' ETD (Bad Csg) 13 3/8" C. 2521' 9 5/8" C. 10417' 82 PCF 46 SEC $ 67,947 $ 663,186 Circ & killed well. Cut LS ~ 5412' w/ 2 5/8" cutter. Pulled A-5 pkr loose. Well started flowing. Circ & raised MW to 83 pcf - killed well. ROOH w/ fish. RIH w/ 2 3/8" stinger on 5" DP. CO sd f/ 5860' to 5945'. Cir~ clean. ~ ~,/o ~ _ X POOH. Lost a pce of ' .... -~,, -. o,, 3/4" in hole off of 2 3/8" stinger. RIH w/ OS. .Engauged fish @ 5412'. Pulled loose & POOH. No rec. Re- dressed grapple & RIH. Engauged fish. POOH. pulled & LD 3 1/2" tbg fish & single hydraulic pkr. RIH w/ OS & engauged fish 8 5980'. Pulled seals f/ pkr ~ 8067' & circ out gas. Pulled & LD 3 1/2" tbg fish. Milled on pkr ~ 8067' DIL. Chased pkr down hole to 8134' Milled on pkr to 8149'. ROOH. ~ill worn to 7 3/4" on gauge & appeared to be running in crimped pipe. RIH w/ 8 1/2" watermelon mill & 6 1/4" taper mill. Reamed & milled f/ 8120' to 8151'. AFE AMT: $1,215,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 14 4/3/82 10502' TD 8458' ETD (Collapsed Csg) 13 3/8" C. 2521' 9 5/8" C. 10417' 82 PCF 42 SEC DAILY COST: $ 26,303 ACC COST: $ 689,489 AFE AMT: $1,215,000 15 4/4/82 DAILY COST: ACC COST: AFE AMT: 16 415/82 10502' TD 8458' ETD (Collapsed Csg) 13 3/8" C. 2521' 9 5/8" C. 10417' 82 PCF 40 SEC $ 36,395 $ 725,884 $1,215,000 10502' TD 8458' ElD (Collapsed Csg) 13 3/8" C. 2521' 9 5/8" C. 10417' 81PCF 42 SEC DAILY COST: $ 31,252 ACC COST: $ 757,136 AFE AMT: $1,215,000 17 4/5/82 DAILY COST: ACC COST: AFE AMI: 10502' TD 8027' ETD (CMT RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 81PCF 42 SEC $ 49,024 $ 806,168 $1,215,000 Milled 9 5/8" csg w/ 6" taper mill & 8 1/2" watermelon mill f/ 8151' to 8154'. Trip & redressed mills. Milled f/ 8150' to 8166'. lrip & redressed mills. Milled f/ 8130' to 8170'. Fell free ~ 8170'. RIH to 8452'. Milled f/ 8452' to 8466'. Milled f/ 8466' to 8467'. Circ clean. Trip out. Ran Dialog csg insp log.. Log stopped D 8124'. Logged out f/ 8124'. Csg insp log revealed split in pipe ~ 8124' & numerous pits f/ 8124' to' 5573'. Ran 8 1/2" bit & 9 5/8" csg scrpr to 8150'. Circ clean. Ran 6" X 8 9/16" mills. Milled f/ 8125' to 8160'. Spot milled f/ 8150 to 8160'. POOH. Ran dialog csg insp log - tool stopped ~ 3780'. POOH w/ csg insp tool. Ran 8 1/2" bit to 8321' had no indication of parted pipe. Circ clean &ROOH. Ran csg insp log. Log stopped ~ 8127'. Logged f/ 8127' to surf.&, Csg insp revealed split ~ 8124 15" long hole ~ 6550'. Ran 8 1/2" impression block. IB stopped ~ 8152'. POOH w/ IB. IB re- vealed damaged pipe ~ 8152' w/ 2 slivers of csg stopping IB ~ 8152'. Set cmt ret on WL ® 8027'. Sqz'd perfs f/ 8127' to 8147' & f/ 8460' to 8472' w/ 200 sxs "G" w/ .3% R-5. Initial rate 4 BPM ® 2000 psi, final rate 1/2 BPM ~ 2500 psi. CIP ~ 18:15 hrs. Rev clean. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO.' LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 18 4/6/82 DAILY COST: ACC COST: AFE AMT: 19 4/7/82 DAILY COST: ACC COST: AFE AMT: 2O 4/8/82 10502' TD 6100' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 81 PCF 42 SEC $ 43,661 $ 849,829 $1,215,000 10502' TD 6100' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 78 PCF 45 SEC $ 47,024 $ 896,853 $1,215,000 10502' TD 6100' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 72 PCF 36 SEC DAILY COST: $ 33,100 ACC COST: $ 929,953 AFE AMT' $1,215,000 21 4/9/82 DAILY COST: ACC COST: AFE AMT: 10502' TD 6100' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' '72 PCF 36 SEC $ 30,016 $ 979,969 $1,215,000 Set ret on DP $ 6100'. Ran CBL-VDL- GR-CCL f/ 6100' to TOC. Set RTTS $ 4000' & tested 9 5/8" csg above 4000' to 3000 psi. Picked up 3 1/2" DR for testing. Sqz'd Beluga perfs f/ 8024' to 8014', 7917' to 7907', 7887 to 7877' & f/ 7422' to 7412' for permanent abandonment thru cmt ret ® 6100' w/ 600 sxs "G" w/ .8% D-19, .75% D-31 & .2% D-6. Initial rate 6 1/2 BRM ~ 2200 psi. Final rate 3 BRM ~ 2200 psi. CIR $ 23:05 hrs. Trip for test tools. Set RTTS $ 5817' DIL. Tested test manifold to 3000 psi. Displ DP to 5700' w/ N2. Opened well to test. Well dead. Perfed Beluga f/ 5853' to 5863' DIL w/ 600 psi drawdown e zone. Opened well to test - no entry. Rev DP full - confirmed no entry. Reset RTTS ~ 5650' DIL & tested test mani- fold. Displ DP to 5550' w/ N2. Opened well to test - no entry. RIH & perfed f/ 5779' to 5789'. Lost gun prior to firing on 1st trip. RIH to perf f/ 5743' to 5753' & stuck gun ~ 5379' in DR prior to perfing. Killed well & POOH w/ DP. Rabbit DR on trip out. RIH & set RTTS ~ 5473'. Installed & tested surf equip to 3000 psi. Displ DR w/ N2. Rerfed f/ 5743' to 5753' & 5533' to 5563' w/ 450 psi N2 cushion. Opened well to test. Had very small flame in 2 hrs.' Killed well. Rev clean - had +16 bbls water entry in DP. Displ D-P to bypass. Opened well to test - small flare after 4 hrs. Killed well. Rev clean - had +8 bbls water entry. RIH to x-over. Could not go below 5883' w/ RTTS. POOH. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 22 4/10/82 DAILY COST: ACC COST: AFE AMT: 23 4/11/82 10502' TD ~lo0, ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF 30 SEC $ 42,452 $1,022,421 $1,215,000 10502' TD 6100' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF 30 SEC DAILY COST: $ 21,824 ACC COST: $1,044,245 AFE AMT: $1,215,000 24 4/12/82 10502' TD 6100' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF Brine DALLY COST: $ 33,014 ACC COST: $1,077,259 AFE AMT: $1,215,000 25 4/13/82 DALLY COST: ACC COST: AFE AMT: 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 32,339 $1,109,598 $1,215,000 POOH. RIH w/ 8 1/2" bit. CO bridge $ 5883' RIH to 6043' X-over to 3% KCL ~luid. POOH. ~IH & set RTTS $ 5480'. Displ DR w/ N2. Injected 24 bbls surfactant & 60 bbls N2 into formation. Displ w/ N2. Final pressure 2800 psi. Opened well to test ~ 23:50 hrs. Opened well to test. Lit flare ® 00:25 hrs. Initial CL- 11,000 ppm, 4200 ppm after 24 hrs. Water rate +85 BPD, gas +270 MCFPD ~ 15 psi. Run temp log, BH audio tracer spin- ner surv & radio-active tracer surv across Beluga parrs f/ +_5900' to +5500'. Logs revealed water entry 7oming from perfs ~ 5853' to 5863' & 5533' to 5563'. Killed well. Re- leased RTTS & drop down to 5797'. Hit bridge ~ 5797'. Circ clean & POOH. RIH w/ bit & scrpr. CO bridge ~ 5785'. RIH to 6000' & circ clean. POOH. Ran cmt ret on WL - could not get below 5783' w/ ret. POOH w/ ret. Ran 8 1/2" taper mill & dressed out burr in csg f/ 5783' to 5788'. POOH. Set cmt ret on WL ~ 5828'. RIH w/ DP & engauged ret ~ 5828'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 26 4/14/82 10502' TD 3978' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: ACC COST: $ 82,089 $1,191,687 AFE AMT: $1,215,000 28 4/16/82 DAILY COST: ACC COST: 10502' TD 5470' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 22,303 $1,246,884 Broke down perfs f/ 5853' to 5863' ~ 4 BPM w/ 1600 psi. Form held 250 psi w/ pumps off. Sqz'd perfs w/ 250 sxs "G" w/ 10% silica flour, .75% D-31, .7% D-19, .2% D-6, .2% A-2 & 3% KCL. Final press 2100 psi ~ 2.2 BPM. Form held 2000 psi w/ pumps off. CIP ~ 01:45 hrs. POOH. Set cmt ret on WL ~ 5644'. RIH & set cmt ret on DR ~ 5470'. Broke dwn perfs f/ 5533' to 5563' ~ 3 1/2 BRM w/ 2000 psi. Form held 1000 psi w/ pumps off. Sqz'd perfs f/ 5533' to 5563' w/ 250 SXS "G" w/ 10% silica sd, .75% D-31, .7% D-19, .2% D-6, .2% A-2 & 3% KCL. Final press 2200 psi ~ 1 1/2 BPM. Form held 1200 psi w/ pumps off. CIP ~ 11:10 hrs. POOH. RIH & set RTTS ~ 4900'. Tested 9 5/8" csg f/ 4900' to 5470' to 3000 psi. POOH. Perfed Sterling A-8 sd f/ 4052' to 4054' w/ 4 HPF. Set cmt ret on DP 8 3978'. Broke down perfs w/ 3 BPM ~ 1800 psi. Form held 600 psi w/ pumps off. Sqz'd perfs f/ 4052' to 4054' w/ 200 sxs "G" w/ 10% silica sd, .75% D-31, .7% D-19, .2% D-6, .2% A-2 & 5% KCL. Flnal press 350 psi ~ 3 1/2 BPM. Form held 0 psi w/ pumps off. CIP ~ 23:10 hrs. POOH. Rev clean & POOH. WOC. RIH & drl out ret ~ 3960' CO cmt under ret & RIH to ret ~ 54~0'. Drl on ret ~ 5470'. Trip for bit. AFE AMT: $1,215,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 4/17/82 DAILY COST: ACC COST: AFE AMT: 30 4/18/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 26,631 $1,273,515 $1,215,000 10502' ID 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 40,854 ACC COST: $1,314,369 AFE AMT: $1,215,000 31 4/19/82 DAILY COST: ACC COST: AFE AMT: 32 4/20/82 DAILY COST: ACC COST: AFE AMT: 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 31,918 $1,346,287 $1,215,000 10502 ' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 34,180 $1,380,467 $1,215,000 Drl out ret G 5470'. Drl hrd cmt to ret $ 5644'. Drl out ret $ 5644'. RIH. CO hrd cmt f/ 5763' to 5828'. Circ clean. POOH. RIH w/ 8 1/2" bit & 9 5/8" scrpr to 5600'. POOH. RIH & set RTTS $ 5485'. Displ DP w/ N2. Closed bypass. Perfed Be- luga w/ 700 psi drawdown f/ 5779' to 5789' & 5743' to 5753' W/ 2 1/8" bi-wire guns loaded w/ 4 HPF. (Note: Gun would not come up initially after perfing 5743' to 5753' - worked free in 1 hr). Gun #3 (20') would not go thru surf test manifold. Bleed off N2 & cleared obstruction. Perfed Beluga w/ 700 psi drawdown f/ 5543 to 5563' w/ 4 HPF using 2 1/8" bi-wire guns. Put well on test - dead in 2 hrs. Rev out - rec 23 bbl water. Displ DP w/ N2. Closed bypass. Displ 60 bbls N2 into top perfs. Displ N2 into form. Ann started flowing & had N2 to surf in ann. Killed well &circ clean. POOH. RU new RTTS & bypass. RIH & set RTTS ~ 3900'. Tested ann to 2500 psi. Stood back 17 stds & reset RTTS ~ 3900'. Tested ann to 2500 psi - no leak apparent in DP f/ external test. RIH & set RTTS ~ 5466'. Started displ DP w/ N2 - had leak in DP $ 900 psi w/ N2. Killed well - POOH. Bull plugged DP. RIH testing DP internally to 5000 psi. Tested ail 3 1/2" DP to 5000 psi in- ternally had 3 leaking connections - LD 6 jts. POOH. Removed bull plug. RIH w/ test tools. Set RTTS ~ 5456. Displ DR w/ N2. Closed bypass. Displ 55 bbls N2 into perfs ~_+2800 psi. Ann started flowing. Bled off N2 to flare - ann still flowing. Killed well -circ clean. POOH LD 3 1/2" DR. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 33 4/21/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 37,758 ACC COST: $1,418,225 AFE ANT: $1,215,000 33 4/22/82 DAILY COST: ACC COST: AFE AMT: 35 4/23/82 DAILY COST: ACC COST: AFE AMT: 10502' TD 5163' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 47,281 $1,465,506 $1,215,060 10502' TD 5068' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 53,761 $1,519,267 $1,215,000 RIH w/ 3 1/2" tbg & test tools. Displ tbg w/ N2 & displ 60 bbls N2 lnto Beluga perfs $ 2550 psi. Let N2 soak 20 min. Opened weii to test @ 14:05 hrs. Press bled to 0 in 10 min. Well kicking out water. Left open to flare until 23:00 hrs. Last rate +20 BWPD & very small flare ~ 0 psi-surface. Killed well. Rev out 26 Bbls entry- combination of WO fluid & Res fluid. ROOH. Set cmt ret on WL $ 5213'. Rerf'd base of sterling "C-l" sand for isolation SQZ f/ 5189' to 5191'. Set RET on WL ~ 5163'. RIH w/ 5" DR. broke down perf's f/ 5189' to 5191' w/ 3 BRM G 1600 psi-formation held 0 psi w/ pumps off 3 min. SQZ'D Rerf's f/ 5189 to 5191' w/ 250 SXS "G" w/ 10% Silica Flour, .75% D-31, .7% D-19 .2% A-2, .2% D-6 & 5% KCL. CIR $ 17:20 Hrs. Final rate 3 BRM ~ 2000 psi. Formation held 2000 psi w/ pumps off l0 min. REV Clean. ROOH. RIH w/ perf Gun-Tagged up ~ 5126'. ROOH. RIH w/ 8 1/2" 8IT. CO to 5163' _ POOH. Perfed 4 HPF w/ 4" guns f/ 5133' to 5135'. Set ret on DP ~ 5068'. Broke down parrs f/ 5133' to 5135' w/ 4 BPM ~ 1550 psi, form held 600 psi w/ pumps off. Sqz'd top of Sterling "C-i" thru parrs w/ 250 sxs "G" w/ 10% silica flour, .75% D-31, .7% D-19, .2% A-2, .2% D-6 & 5% KCL. CIP ® 10:15 hrs. Final rate 2 BPM $ 2000 psi, form held 1500 psi w/ pumps off. Rev clean & POOH. RIH & set RTTS ~ 4004' on 3 1/2" tbg. Displ tbg w/ N2 & dry tested perfs f/ 4052' to 4054' to atmosphere - dry. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 11 LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 36 4/24/82 10502 ' TD 5177' ETD (CMT) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 20,000 ACC COST: $1,543,267 AFE AMT: $1,215,000 37 4/25/82 DAILY COST: ACC COST: AFE AMT: 38 4/26/82 DAILY COST: ACC COST: AFE AMT: 39 4/27/82 DAILY COST: ACC COST: AFE AMT: 10502' TD 5828' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 37,225 $1,581,492 $1,215,000 10502' TD 5189' ETD (FILL) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 38,850 $1,640,372 $1,215,000 10502' TD 5213' ETD 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 29,036 $1,669,408 $1,215,000 POOH. RIH w/ 8 1/2" bit. DO ret $ 5068' & cmt to 5163'. Trip for bit. DO ret $ 5163' & CO cmt to 5177'. DO cmt to 5210'. POOH. RIH & set RTTS ~ 5080'. Displ tbg w/ N2 & dry tested perfs f/ 5133' to 5135' & 5189' to 5191' to atmosphere - dry. Released RTTS & RIH to 5200'. X-over to clean 4% KCL fluid. PU & set RTTS ~ 4007'. Displ tbg w/ N2. Inflow perfed Sterling A-8 f/ 4054 to 4064' w/ 2 1/8" biwire guns loaded 4 HPF on 750 psi drawdown. Rate stabilized ~ 7.85 MMCFPD ~ 825 psi. No water. POOH w/ perf gun. Inflow perfed A-8 f/ 4064 to 4094' (2 runs). Flowed well - rate stabilized ~ 8.88 MMCFPD ~ 840 psi. Inflow parred Sterling A-ii f/ 4261' to 4267'. Rate stab- ilized ~ 9.08 MMCFPD ~ 840 psi. No water. Killed well. Released RTTS & RIH. Set RTTS ~ 5057'. Spotted safe-seal pill across Sterling A-8 & A-ii to stop loss tiro (lost 60 bbls into perfs). Displ tbg w/ N2. Parred C-1 f/ 5137' to 5147' w/ 750 psi cushion. (Had fill ~ 5189' prior to shooting). Flowed C-1 perfs f/ 5137 to 5147' to clean up. Shut in & trip for perf gun. Inflow perfed C-1 f/ 5147 to 5167'. Flowed well to clean up. Shut in & attempted to pull gun. Perf gun would not reenter tbg. Pulled out of rope socket. Put well on test. Rate stabilized f/ C-1 perfs ~ 8.71MMCFPD w/ no water w/ 840 psi tbg. Killed well & POOH w/ RTTS. RIH w/ globe JB. Washed over junk f/ 5182' to 5213'. Circ clean & POOH. Recovered bullnose off perf gun & pcs of bi-wire. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO, 12 LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 40 4/28/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 29,867 ACC COST: $1,699,275 AFE AMT: $1,215,000 41 4/29/82 DALLY COST: ACC COST: AFE AMT: 42 4/30/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 47,562 $1,746,837 $1,215 , 000 10502 ' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 28,665 ACC COST: $1,775,502 AFE AMT: $1,215,000 43 5/1/82 DAILY COST: ACC COST: 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 28,578 $1,804,080 RIH & washed over perf gun w/ globe OB. POOH. Rec perf gun. RIH & milled on ret ~ 5213'. Trip for new mill. Milled ret down hole to 5222. Circ out gas bubble under ret. CO to ret ~ 5828'. Circ clean. Spot perf pill across perfs. Perf pill: 15 to 20 ppb safe seal,. 2 ppb HEC & 4% KCL. POOH. Perfed "A-8" f/ 4054 to 4094' A-ii f/ 4261 to 4267' & C-1 f/ 5137' to 5187' w/ 4" csg guns loaded 4 HPF on 120° phasing. Reperfed C-1 f/ 5167 to 5187' (Note: Ail intervals now have total of 8 HPF). Ran 8 1/2 bit & 9 5/8" scraper to 5500'. POOH. Run Baker "SAB" pkr on DP w/ isolation tail & set ~ 5460'. Tested pkr. RIH w/ "DB" pkr w/ tail. Could not stab into pkr ~ 5460' w/ seals. POOH. Lost "DP" pkr off setting tool. RIH & engauged pkr ~ 4355'. Could not pull pkr. Trip for pkr picker. BO & rec pkr f/ 4355'. Pulled & LO fish. RIH w/ seals on DP. Could not stab into pkr ~ 5460. ROOH. RIH w/ 3 1/2" DR stinger w/ mill on 5" DR. Ran right to btm of pkr - no junk. ROOH. RIH w/ pkr picker. Milled over pkr ® 5460'. AFE AMT: $1,215,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 44 5/2/82 DAILY COST: ACC COST: AFE AMT: 45 5/3/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE $ 23,595 $1,827,675 $1,215,000 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 20,493 ACC COST: $1,848,168 AFE AMT: $1,215,000 46 5/4/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' 64 PCF BRINE DAILY COST: $ 160,085 ACC COST: $2,008,253 AFE AMT: $1,215,000 47 5/5/82 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' DAILY COST: ACC COST: AFE AMT: 48 5/6/82 DAILY COST: ACC COST: AFE AMT: $ 22,156 $2,030,409 $1,215,000 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' $ 51,069 $2,081,478 $1,215,000 Pulled & LD pkr (Note: inside of 4 3/4" bore was plastic coated & seal assy would not go into seal bore). RIH w/ 8 1/2" bit & circ clean ® 5828'. Trip out. Set model "DB" pkr w/ isolation tail ® 5465'. RIH w/ seals on DP & tested pkr. Set "DB" pkr ~ 4353' on DP. Tested pkr ~ 4353'. LD 5" DP & 6 1/4" collars. RU to run dual 3 1/2" comp assy. Ran dual 3 1/2" comp tbg. Spaced out & landed tbg. Set XN plug in SS nipple ~ 4001'. Press up on SS to set dual A-5 pkr ~ 3992'. Pulled XN plug & tested pkr - ok. Removed BOPE. Installed tree - would not test. Removed tree - found seal nipple sheared off. Repaired seal neck on tbg hangers ~ tri-state. Installed & tested tree to 5000 psi. Pulled BPV's. Opened XA sleeve ~ 3980' Displ ann above A-5 pkr w/ pkr fluid. Displ SS to sleeve ~ 3980' w/ N2. Closed sleeve ® 3980'. Opened SS to test. 6.8 MMCFPD - no water. Opened XA sleeve in LS ~ 4318' & lifted water out SS. Closed XA ~ 4318'. SI SS. Tested "C-i" & "Beluga" perfs thru LS. Initial rate 5.6 MMCFPD w/ 96 BWRD. Cleaned up to 5.92 MMCFRD w/ 67 BWRD. Water rate still falling & gas increasing. Shut in well. Closed "XA" sleeves opposite "C-l" perfs ~ 5433' & 4407'. Installed BRV's. Released rig to moving rate $ 12:00 hrs 5/6/82. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 14 LEASE A-028142 WELL NO. KDU #5 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 49 5/7/82 10502' TD Rigged down. 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' DAILY COST: $ 21,427 ACC COST: $2,102,905 AFE AMT: $1,975,000 50 5/8/82 DALLY COST: ACC COST: 10502' TD 5828' ETD (RET) 13 3/8" C. 2521' 9 5/8" C. 10417' $ 28,756 $2,131,661 Rigged down. Released rig to KU #24-7 ~ 24:00 hrs 5/8/82. AFE AMT: $1,975,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE A-028142 WELL NO. KDU #5 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 1 9 1 48 1 15 25 1 32 OTS LONG STRING TUBING DETAIL DESCRIPTION Mule Shoe Seal Assembly No-Go 3 1/2" Butt St Tbg 3 1/2" Otis XA Sleeve (Butt) 3 1/2" Butt Jt Tbg Blast Jts (4.5" OD) 3 1/2" Butt ors Tbg 3 1/2" Butt Pup 3 1/2" Butt Pup Blast Jts 3 1/2" Butt Pup 3 1/2" Butt Pup 3 1/2" Butt Jt Tbg Baker Pkr Model A-5 (Dual) 3 1/2" Butt Ot Tbg 3 1/2" Butt XA Sleeve 3 1/2" Butt Pup 3 1/2" Butt Pup 3 1/2" Butt Jts Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg Tbg Hanger Below RT LENGTH TOP .50' 4363.50' 10.50' 4353.00' 1.33' 4351.67' 30.27' 4321.40' 3.85' 4317.55' 30.74' 4286.81' 39.53' 4247.28' 118.85' 4128.43' 9.68' 4118.75' 10.10' 4108.65' 59.26' 4049.39' 10.06' 4039.33' 9.69' 4029.64' 30.60' 3999.04' 12.83' 3986.21' 29.21' 3957.0' 5.74' 3951.26' 4.05' 3947.21' 4.03' 3943.18' 266.17' 3677.01' 9.91' 3667.10' 1440.00' 2227.10' 5.05' 2222.05' 452.58' 1769.47' 759.56' 1009.91' 4.19' 1005.72' 977.35' 28.37' 1.O0' 27.37' 27.37' 0 BTM , 4364.00' 4363.50' 4353.00 4351.67' 4321.40' 4317.55' 4286.81' 4247.28' 4128.43' 4118.75' 4108.65' 4049.39' 4039.33' 4029.64' 3999.04' 3986.21' 3957.0' 3951.26' 3947.21' 3943.18' 3677.01' 3667.]~0' 2227.10' 2222.05' 1769.47' 1009.91' 1005.?2' 28.37' 27.37' LEASE A-028142 SHEET D PAGE NO. UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. KDU #5 FIELD Kenai Gas Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 43 1 36 lO SHORT STRING TUBING DETAIL DESCRIPTION 3 1/2" Butt Otis XN Nipple Baker Rkr Model A-5 "Dual" 3 1/2" Butt N-80 9.2# Pup Otis XA Sleeve 3 1/2" N-80 Ors Tbg 3 1/2" Butt Pup 3 1/2" Tbg Sts 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt Ors Tbg 3 1/2" Butt Pup 3 1/2" Butt Ots Tbg 3 1/2" Butt Pup 3 1/2" Butt ors Tbg 3 1/2" Butt Pup 3 1/2" Butt ors Tbg 3 1/2" Butt Pup 3 1/2" Butt Ot Tbg 3 1/2" Butt Pup Tbg Hanger CIW 3 1/2" 8rd Below RT LENGTH TOP 1.O0' 3999.79' 10.15' 3989.64' 9.55' 3980.09' 3.97' 3976.12' 1297.70' 2678.42' 5.10' 2673.32' 1080.21' 1593.11' 4.12' 1588.99' 175.04' 1413.95' 10.12' 1403.83' 83.15' 1320.68' 4.20' 1316.48' llB.21' 1198.27' 4.12' 1194.15' 302.96' 891.19' 4.21' 886.98' 58.36' 828.62' 4.07' 824.55' 273.21' 551.34' 4.10' 547.24' 209.20' 338.04' 4.67' 333.37' 180.58' 152.79' 4.98' 147.81' 84.60' 63.21' 5.05' 58.16' 28.36' 29.80' 1.40' 28.40' 1.O0' 27.40' 27.40' 0 BTM 4000.79' 3999.79' 3989.64' 3980.09' 3976.12' 2678.42' 2673.32' 1593.11' 1588.99' 1413.95' 1403.83' 1320.68' 1316.48' 1198.27' 1194.15' 891.19' 886.98' 828.62' 824.55' 551.34' 547.24' 338.04' 333.37' 152.79' 147.81' 63.21' 58.16' 29.80' 28.40' 27.40' CONTRACTOR Brinkerhoff Signal Inc. OIL COMPANY Union Oil Company RIG NO. 59 LEASE/WELL NO. BIT RECORD KDU #5 WO COUNTY Kenai STATE Alaska FIELD/TOWN TOOL PUS~H, ER__ RIG MAKE & MODEL ..... DR ....... DR RECORD NO. SEC/TSHIP/ ~ ~ DR ......... RANGE_. ~Se.c~ . ;. _3 6_, ._.T5N. Rj!_W_. SM,.. SHEET TOOL NO. OOINTS MAKE 4 1/2 SIZE TYRE 1F OD 6 1/4" NO. 1 PUMP MAKE & MODEL Emsco F-lO00 Liner 6 1/2 SPUD DATE 3/19/82 UNDER SURF DRILL COLLARS NO 5 OD 6 1/4" ID 2 1/4" LENGTH 151.18' NO. 2 PUMP qAKE & MODEL Oilwell iO00P Liner 6 INTER TD DRILL COLLARS NO OD ID LENGTH RUN SETS 32ND BIT NO_._~SIZE MAKE TYPE I 2 3 ~ER NO. WT DEPTH FOOT- ACCUM 1000 VERT PUMP No 1 No. 2 OUT .r AG_E ..... HOURS HOU_RS LB ...... R_FIq DEV. PRESS $.RM..~LIN _SPM _L. IN_ MUD DULL COND REMARKS WT VIS_ .... T B G (F.,A..I. LURE, E. TC.) Reed 1 8 1/2 SBG$ 917009 2 " " A24002 3 HTC 8 1/2 OSC3AO DK152 4 Reed 8 1/2 S13G$ 164515 5468 ?2 Ret 7 5837 369 5171 129 11 1/2 5220 1 Ret55 13 1/2 FOR CO RUNS Gel 3 2 I Gel 4 3 I Cmt KCL 4 4 I Cmt KCL 3 2 I Cmt TUBING DETAIL ZO/Y¢ I. :5 I/2" OTIS "XA" SLEEVE AT ~951.26' 2, BAKER MODEL A-5 DUAL PACKER AT 3986.21' :5. BLAST JOINTS FROM 4049.;59' TO 4108.65' 4. BLAST JOINTS FROM 4247.78' TO 4286.81' 5. 31/'2" OTIS XA SLEEVE AT 4317.55' 6. NO-GO AT 4;551.67' 7. MODEL "DB" PKR. W/SEAL ASSY. AT 4553.00' 8. MULE SHOE AT 4;563.50' A. ;5 I/2" OTIS "XA" SLEEVE AT :5976.12' B. BAKER MODEL A-5 DUAL PACKER AT 3989.64' C.;51/2" OTIS XN NIPPLE AT :5999.79' PERFORATION RECORD D~TE I#TEAYI~L 4~5~82 8127'- 8147' " 8460' - 8472l 4/6/82 8014'- 8024' " 7907'- 7917' " 7877'- 7887' " 7412'- 7422' 4/78~4/14/82 5855'-586:5' 4/8 a 4/17/82 5779'- ,5789' 4/9 &" 574:5 - 575;5' "& 4/'14/82 553:5'- 556;5' 4/14/82 4052'- 4054' 4/18/82 554:5'- 556:5' 4/22/82 5189'- 5191' 4/2:5/82 513~' - 51:55' 4/26,27,29/82 51:57L 5187' 4/'25,26,29/82 4054'- 4094' 4,/26,29/82 4261'- 4267' COtVDITIOIV SQUEEZED ii II II ii PROD. TEST & SQUEEZED II 11 I, ii 11 II Ii ii ii A-8 SAND, SQUEEZED BELUGA ~ 8 H.P.F C-I SAND~ISOLATION SQZ. II ii ii ii C-I SAND, PRODUCTION A-II KDU- 5 OI 27,40' CEMENT PACKER RETAINER 5.828' s-e c.sl. .T W/PLUG AT 5,465' unl, n KENAI DEEP UNIT WELL SCHEMATIC Well: KDU-5 IField' KENAI GAS County: KENAI IDrofted:2 /4 //83 SpudDote, ;5/16Z'82., Jc°mp Dote 5/4/82 Locat,on, NW of SE Cor. Sec.;51. T5N. RIIW SM. July 1~ 1982 UNION OIL COMPANY OF CALIFORNIA Po O o Box 6247 Anchorage, Alaska 99510 Reference: KDU #5 W/O Gentlemen: This report contains a summary of the drilling mud costs on the well referred to above. The record of drilling mud tests is provided for your information and is representative of the tests made on the mud system during the drilling of the well. The well cost summary and engineering report is filed in our Houston office. Should you require additional information, we will be pleased to furnish it. We look forward to an opportunity to serve your future needs with a complete line of drilling muds and services. Very truly yours, Marketing Administration IMCO SERVICES ~,,00 ,,,,~,,..oo~so,~,~,. ,,.o. ~ox~,~. ~o,~,o,~,-,-~,~ 77027 ~, 713/671-4800. Telex'. 76.2.433 .~ Cabte: ,MCOSERV A Division of HALLIBURTON Company ~" '~~MC~O IMCO Services Houston, Texas 77027 A,'C 713 671-4800 WELL DATA SUMMARY COMPANY UNION OIL COMPANY OF CALIFORNIA ADDRESS Anchorage, Alaska REPORT FOR MR. WELL NAME & NO. KDU #5 W/O STATE Alaska IMCO WAREHOUSE X-KENA I iCOUNTY Kena i CONTRACTOR BRINKERHOFF ADDRESS REPORT FOR MR. FIELD Kenai Gas DESCRIPTION OF LOCATION WE L L DATA HOLE SIZE FROM TO O.D. DATE SPUDDED 3-19-82 TOTAL DEPTH w/o CSG. SIZE FROM 9 5/8 _0__ CSG. SIZE FROM TO =_____~10,41_7 TO HOLE SIZE FROM TO o,a. DATE TD REACHED CSG. SIZE FROM TO HOLE SIZE FROM TO 5-5-82 O.D. TOTAL DAYS CSG. SIZE FROM TO HOLE SIZE FROM TO O.D. 46 _ _ BITS: NUMBER AND SIZE ;~qUD LIP DEPTHS TYPE MUD IMCO GEL/BARITE & 4% t~C1/H20 COMMENTS Please see attached daily reports for details. Dennis R. Lundquist/mn IMCO REPRESENTATIVE FORM .qO9 'OHM 1355 ,I' ,''''T'C IN U.S,A. 5M 1~.81 l ( COST SUMMARY IMCD SERVICES A Division of HALLIBURTON Company 2400 West Loop South, P. O. Box 22605 Houston, Texas 77027 A/C 713 622-5555 ~.. .. I.. . . .~ ~~.~ .;.. ~.; '1 L. : ~ .~. ~. &'.~ I ;: I ~ ;. ! "'.;: TOTAL DEPTH . ..... ~T: ~ . .., .... P d' '~~lJ!"MSY ~ . " ':: J :;", I .' . . 1"1 I:~ . ,.:" " . oJ ," ,; I ".. ~ DATE "/15/62 PRODUCT UNITS SIZE AMOUNT i I I 1 L ¡"" ,: '!" >. , ' '.1,.' ... "" I 1 , . ",'., ' ,-:", .', ...¡ 1 . ...'" 'n ,., nl ,-: ,... ..1" ' 1 T ¡oj, ,"" :' : ' .. (., 1 ~ ~,: 1 1 C-' I :1 i J \ . , ,'"' ~" .. "', ¡, ! !..: ~~ ~ ' . 1'" i' ... T OJ C ,,, .;¡ .L 1 ,. " /' ", r.,¡ C' 7 il3 ';¡! ' .'O ~"; ;, i." ~ I ""'1 '''' J, oJ \1"'i0oi oJ .., ~;;.J!b "I '. . ..~.... I ¡,:; , , r:. ~'~ ' I ",' SO:~I!!:' ",.,., I,~,.' I_vOLt;; 1250:ì!i\') .... I, I', -,,"';'.:',- i... - ~1'.It. PO"'I(.;:.~~:"'.L. I'.:! " i J.'J~1L.d 2':;,',:/Ji~ . - - ," '.. , '" . :... ..., i ' 1 r:i." .., .. ,., . I"' 'I S,., :',.. "'"'' 1 1" 1 ': I' L CJ ~ ~ I! ~I~ ,. fo\ ,~ Co ~ "J ,;, ;:;, ì~ i ':" \0 r' t~ ~ :': ', ~ - t;; .., :ic; '.1 K~! I I,;: n ¡..;;:." ':¡ ¡ ~~' i.'" 1 ',' "; '". ~: L.;J '5 2lA ioil ~ :;) C I~ I. ,...../,;. ¡ I" ., ., , .. I''''' ' I~iC¡"~ ',:r..(, : '~',d..2 '2b,3ir:s0 .. '... 1.... I ..' ,~ , " ", ' ' C '~u ~ ... ': " ~ :'~ ,', ' :..~ ',;) ..' I. t:1 !J 1,?:a ,... t v I ... '" I.., ... " " I ", '" " ", ., -"I J POT ,\ ,-,: ~ ¡' ! ;~", ," " ,! ' '-:" ' ~. ~ ~: I.. d 6:3 31 P 0 ."'I.,"J,''''''' ...;.:,..,..,. I..,.~, -... " D~Fr~"',;:;..L I'~'" ~:)L.~:t 11S~('liOr.~ . ."', I 11 ï";:. -." . .. - '"'I .' TI-'r,.'-.i\C:,' "",'>",1 : ."...¡~ ::;'.H~L ;,J6o.¡i-:lpC',:'I ... .. ." , 1 I... ... ""'.. \; 1 ') , ' .. 1" . ,'.. ~. 'I.;;J. ., TECi'~!'\¡~C!~! ,.,:;.:'~:; i (..~,...v "'.', V '7'HJ;j:ar¡ . :: "I' ': '"" t... ".. .' " 1 ,¡ l( :, ": ,., .' \} -... " : ~ T I:" Î ¡.", ""', ..;: ¡:: " 1 .~'.! ,J '"" ~'" T 108,... Z , 1~1': . .. ... , I. \ . .... t\.. \0,' '.., r~ J i '. J ",' "" "'" ,;) "," t. TRi1II ~:~: ,";:,~r=.'~,~ 1 J..:,¡.(!" 0~V 55'';; t1::I \1 ,... ... ¡.". " ""'" I .'. ¡". : ~. i ."". -- ~'I V .' i .. "'f. J i., :) A Y 4 9 :.;! () J I 1 I 1 I I : 99al~37 * I I' ' I I I 1 I , U i : A Y ..:', ;'; ..;. : ¡ f' r"! ::..' ~ \,I '''"" "" , ,! i ': 1"'\ 1'" ,... I' .,",,' -,: ,., ð:,; 3 ''''''' \..¡', , , ... õ" r:'¡'~ .I.,':" 'I 'I"" 'I': "',¡..",J '".' '.'1 ¡::' "I" \ '..' Ó"7.. . """'" ~ ,,,,,,...""1Ii I ..~ I'" .. t... '.J ~ ,.",\ I I ! 1~OO , 1 I 1 I 1 9.01,."11 I 7:~ .) , ~ I '1 I I I I 1 I I I , , : 9911 ¿:IJ 0 '* * ' 1 I I 1 1 I 1 I 1 I 1 I 1 1 1 I I I I I I 1 I I I 1 I 1 I 1 1 1 1 : 1 1 I I 1 I 1 1 1 1 1 I 1 : 1 1 1 1 1 I 1 1 1 I 1 I 1 I 1 I 1 I I I , I 1 I I ~ ,¡ ¡ -~ I I 1: '., ,I I 'Mea I: : ~'~ ,'- I: : ,~ ' I' 1 -', I I I I I I i I I I ~ SUMMARY OF DRILLING FLUID OPERATIONS PAGE OF TOWNSHIP ~--~-~-~ ......... !MUD TYPE cOaDUcToR SIZE DEPTH -~]IT SIZE Union Oil _ Gel 11.2.~ Bar ~ / ~ ~WELL FIELD SPUD DATE SURFACE A O~*~ o~ ~[eum~ ~m~ CONTRAC-rOR COUNTY/PARISH ~:DT D~'rE INTERMEDIATE ~"' ............... . ...... I~r~,J .... ~S 10417 ENGINEERS ISTATE DAYS TO T.D. LINER{S) .............. ti.~ ~ a~ u is t ........ lkl ~.~ sk.~_ ~ ............ MUD VIS. MUD GELS ] PH APl HT- HP ~ ALKALINITY SALT CALCIUM SAND OIL WATER WT. SEC/ TEMP. '~STRIP FLUID FLUID ] ~ [~ NaCI [[[]PPM % VOL % VOL. % VOL. ~o / ~UMET~ ~OSS ; LOSS ~ I ~C~- ~ON E]PPG. ~T. [] F.L. S~C/ ~ ]'EMP__ CAKE Pf ~ Mf Pm UPPM CEC '[]JCo~Fc / MIN ~ [~ Gr./Gal }il9 5338 75 4~ .... ~, /. :73~'~" I' 1 '10/8xlse/441 I I I,, / I ,,, I I ,I .......... I ! I FZ I I I 1--,1 ..... I 1 ::2./27"1' I ao.s1441 I i ..... !' / I I-~-~-T~Z .... L_ I' I ~ I I , I I "' I" q I,, 1 ...... ~z~' I~o I ~E'~ l,---I I. / I I IE~TET_~ I I" _1 ..... E,, I.. '1 '1 I . .I '"1 1.. '~!2s I ~0417l 80 I, 481 I ,] .... I .... / I ~./26 I 104171 8o I 481 I ! I / I .... 'l-~l .... I ..... I I,, ! , I,, ~ I I .... ! i I I I"~ '3/~7 1.z04~71 ao' I" 4~1 I,, '1 I, / I I" I _.1 I I I I- I I ~-- I "'1 I I L Usi~ 1k" tubing to c~ean out t b~ ~ I ~04~1 80 I 4~'"'1 I "~ ~ ) I. I 1 3/29 !x04~71 8~ I 461 I I I / I I . I L I I I I I I I ..I I I I ~11 flowino sliah~lv, build mud wt to fl3 PCP _ 3/~o lz04zv F ~3-I sb'l I I I / I .I I I I !.... 1. I I I I I I I I L 3/3z IzO4~71 82"! 641 I I I / I I I I I I I I ~7,oool ~6oo4 I I I I I L ~ud ~ontam~n~ted w~th CaC~ from previous oomp~etion ALKALINITY _ Pf Mf Prn · __ IMCO FORM Nc~. 131 (Rev. 1/79] SUMMARY OF DRILLING FLUID OPERATIONS PAGE OF ~~ Union Oil 'l. I G.,e_i/_H2_Oz/KC 1 ~,;;~ IMC0 Sepvices iwE'L ~.,ELD ............ ~.UO ~A~ SURFACE .... ..._ ;__KDU ~5 W.O ........... _K_enai_Gas_l, liald 3/%9/82 10 .... ,~aJ..U.ZONComp~ CONTRACTOR COUNTY/PARISH T.D. DATE INTERMEDIATE ......... ~ ....... _1( anwz ] 95/.8. .... 10417 , ENGINEERS STATE DAYS TO T.D. LINER{S) ....... Hall/Lundquist ~ Alaska ] MUD VIS. MUD GELS . PH i APl HT- HP ALKALINITY ..... ~ SALT CALCIUM SAND OI/ WATER WT. SEC/ TEMP.~n , i~'<~STRIP FLUID FLUID []NaCI [~]PPM %VOL ,%VOL. %VOL. U-]PPG. QT. L-JF.LorU/l~'~" / !L-]METER LOSS i LOSS MCI. ~ION DATE I DEPTH [~ PGF. [_-]SMPL PV I YP 0 TEMP__ CAKEI Pt M! Pm L-fl PPM CEC _._%9di2_ .... gJC°E~Fc / Mm ~ : (::]G,./C,,I ............................................. ........ __~z2 . "to~.].7 '__82" ~' 6 ~ .... 31 g/t2 9 ~.-~ii;121 17000 , l~OO+ ~./3 _[ zO~zT.l ~3 I~0 I -I~ 12~1 g/~o-_], 9 I I ...... L_ -]-_---I .... l----i~J-17000 ~71 I .... r---~, I I 1 "4/4 I ]o 41v i ~1 ! 44 ;' I, [-T-i "'.~ 4"1 ~-}~-[-~- I T---7l-7-7-I-----I-~ F--TJ~ 14oo o. I 1~ oo+ I 'i .. I I I I I -'-~z'5 I zo~71 ,t ],'.l ~ '_l___ 1i~-'1 4~1 3/~._11o,51 12212'.]£_,J2_ I I-~i~i_~.._~._o_o_'z [';'~oo+1 I I I ,,, I I I'-' Sclu .ee ze lo~t~_p~r f s ............. , 7 I 104'1~--~-~--~]'g-]'_7~-_--_I-7' I""'3o"1 4/x2 11o.51 _V_--~-l---I .... q ..... I '--d77__i~-69 ~Fi~6B¥'I'-- I i I I I I - ~7_~ I ~04tvl 72"1 36 I---qT 6' I 71 3/ 110' I I ] I I. I -[ 500-0 I 1480__1 I . I _[ I I I _ _.~d9 I xo~zvl v21~x I I~ 1141 4/7_ I10 I I -I I. I . I' -] .. 5000 1~80 ...I "'1 I I I I ......... , 4/tol z04zTJ 641 I I I .... I / I I I L_ I I ...... I -1 32ooo I I I I I I I 1'"7 ...... ,' .... 4/]_] I 64., I I I / I,, I,,. 1 I ,,, I, I I I 32000 1 I ! ! I I I .V--z__ 4/].2 I I 64 I'" ,I I I I / I I i 1 I I, I I 27500 I I I I I I I _ ~/~_] I i 64 ! I I I I .... / I I I '-I I I I "1 2v'°oo I I I I I I I '1'- - Mill t~aht soot ~n eas~na~ set tel_airier & saueeze, build vol~e ~/~ I ', 1'~ I I ~ I I I / I ' I I I I I I I ~°oo I I I I I ! I f .... 4/k~ I I 64 I I I I '1 / I, I I Ylf I I I '1 2vooo I ',1 I ! I I I i Squeeze top zone, d~nq ce~n~ & ~et~~ne~s. ~~ '" _ IMCO ~'ORM No. 1:31 (Rev. 1/79) SUMMARY OF DRILLING FLUID OPERATIONS OPERATOR _ Union Oil WELL KDU ~5 W.O CONTRACTOR Brinkerh~ff ENGINEERS PAGE OF' ' ~;~l-o-- '~.UD DATE SU".ACE __ . 3/19./_82 [ . IMCO Services l~-o--a~,,,A R,S. T.D. DATE INTERMEDIATE --" ~ ...... ....... . ..... J__Ke.nai ___, ........ //j 95/8 _19417 J J SYATE DAYS YO T.D. LINER(S) .T. I sec, ITEM.. I I '1 'o . IL~S*"'~I~L~'OI"L~'D/ I I I .... nN~, I E~.M I~VOL.~VOL.~VOL.~ ~PPG. QT. E]F.L. ..C/ I[3MET~nl LOSS I LOSS / I I I 4/16 5400 64 27000 I / I I I Dr:.lling cement & retainers ,, ,/z7 s4ss / ~.4 ! .I ' I I ' ! ..~'~-h~~f-~ ' I .... 1 ...... I---~Li~7~-zl I-. .... i I I I '1''1"' . Testinq .. . / ._~.: ..... fi" ........ , ........... ~ ....... 4/iai - I ~ I I I I I / ~ · ~ ~ '1 ..... ! ..... I ..... Z~~-bo I .... ~1 I' I "1 I I' Testing 4/z~l I ~ [ I I I I "~ _1 .... _UJ ...... L ...... L l... I ' 'l~L_X7~oo I . I'_T I I "1 ',1'[ .... Tea~ina ' ~/~n/ '~~ .... I ~,J '7"1./ L7~'ZY]2X~T---IZ~- I I _~-"1~.55_.~I I I ..... ~ . l I I 1 · pn~in~ built new val~tma 4/2il---~' I 6s+ I I I , I I / _..]~YV[U~ I I I I ,,,I , I ,~sAoo I ,,I , J_ I I I I 1,,, 4/'221 ii ! 63 I I I I I / _f_l--__l I _.l I ! I "I '22-o-o~_ I _1 ..... [_ ,1__. 71 I '1 "! Test_ing, fluid contaminated with cement _J_ 4/231 I ~3+ I ', I I I "I "/ 'TZf'__-_]-- I ._1_ . I I , , ,! I 21oo_.o_.1 4_~~/2~ Dlaced hole with fresh KC1/H~O .... ' ] 16a+ ,1 .,1 I , '1 "1 / _1 ii_1. i I I ! I I220@0 I ---]I I I I I ,l ____~L~p_t hole with high vi~ ~EC) pills wh_ile dr_illinq_ret_a_iners. 4/2s1 1~3+1 I / I I / -[ [-----[- [, I ! I I 22000 ! ___[ / I ! I I 1 4/261 i _ 163+1 I . I . ! I / T--/q .... I_, I _1 I I F-~ i~-- 472~~saf7 ~+allpill, fo..r.., lostlcir~ul~tiQ[__lJ.Ql_k_b_l_s)I ' I I ' I 20000 ,---- 4,/281 i 16'3+ !, '1 I I I / I ! I I ! 1 '1 I 21000--[ "'1 I I I I I I 'Mixed 200 ~bls safe seal pill & spotted same _~ppb safe vis x, 15 ppb safe seal) 4/291. 1(;3+ / I ] I I /--F----I I I I I I 1200001 I IMCO FORM No. 131 (Rev. 1/79) SUMMARY OF DRILLING FLUID OPERATIOi'JS ~uv/ce'~i~ IMCO Services jA D~v~lo~ 0l H, ALLI~URTON t~ml;~my 24~Q ~t Loop ,So~a. P 0 8~ ~ ~o~.1~. b~ 7?O27 ~ 713 67~-44GQ DATE 1982 4/30 5/1 J , 5./~ I J MUD !'"ViS. I WT. I SEC/ J ~Pm. j DEPTH J J~PCF. J I 6 +3._~__L OPERATOR Un±on O±] WELL KDU ~t5 W.O ..... CONTRACTOR __B/iinkerho f f ENGINEERS J__Kenai [STATE ~._a ]_,!/Lundqui s_L___ ........... I.__A]..L~ s k_ a MUDI J J .,~sJ ,~. J .,, J,,~..,] --~ALKALINITY T~MP. I I I ,~ ' I~::]~"'PI "~"'" I"~"'~/ / ' "1 ' I gF.L. I J I SEC/ J~ME1'EF~ LOSS J LOSS / I I J ~s~.L/ .v I v" I /~o I / I~U.__l c~E I "~ I ~ I t~CO~F / MIN II,IUD TYPE 4% KC1/HaO 'JS~ 6ATE''' "- - l JT.D. D~TE DAYS TO I'.D. CALCIUM J []PPM 20000 SALT [] N~C~ I~C~- r_~PPM Gr./Gal CONDUCTOR [SIZE , j~5/~ LINfR($) J , IPAGE, OF ' DEPTH IT SIZE 10417 2oooo j I '1" I I I I, i,,, I ~']+ I --1 .... I I .,1 / ...... I ............ I----] ......... !--'1 ' "1 ' I '-I----~-o-6-o-6--I' I I ., i ':],1 ' I I, !',.'.', s/'_~ I , I ~a+ [, __1. I I I ';' .... _LZ.Z_.I_Z_i_-.LT._ ...... I. I · I I I '_~_ao_o__l ..... __L_, i~,1 I i "'1 I I Mixad Na~~LejtiJlr~flnid in grehydral;ign._¢ank._. ......... ~ ........... r----r-=--~-×-~---'~ ......r , -, --n ' , , ,' ..... 5/4 I I 63.+'l _L Ili 'I__z...... Il l....... I ..... I ......... I' t I I..... J___~./_._u__uU__l....... k___ j J l i j J J I Displaced [ ikh_ QII~D ' id_/ j .... i , ~ ~ ~ ~ ~ ~ /--~-_qZ-T;L-Z----_~ ~' "~, ~ ~ ,, ~' ~. "~ ~ ~ ~ ~ .. ~',, [ , I I , I I ! I ./1 .... [~-E___-J I" I I I 1 I '1 I ..... I I I I I_ .. I · I .1 I I I '7.. I 1-----]/_Z_--Ii I '1 ! I I i I "1 I I i. I. I I I I I I / ...I I_ ,_W-C_fl I .I "'l I I I "1 I '! .I I Ii~ I' .1 I . I ! I I / I I I---1 I "i I -1 ~ I I i '1 I I I" I, I I I I' I I./,,I, I I~-I I I I __] I _l. I .... 1 .... L/ I ' I' I I 1,.I-I Ii../ I----l---'F .... F-?'-!i., I" I____l ,.. 1-----I_1 I I, I I I IMCO FORM No. 131 IRev. 1/79) SUMMARY OF MUD MATERIAL USAGE PAGE OF COMPANY LOCATION FI ELD ~ ~'~'; ~ WELL COUNTY STATE WAREHOUSE .............. KDU 5 W.Q. Kenai ....... Alaska ~~D~ers D.Qck cosy cosy ~ · ~ ~ o 1982 m ~ u m ~ ~ ~ ~ ............................. 3/19 5338 12114.3~ 12114 39 400 140 4 ~ .... 3/20 23783.5f ..~97 89 1095 15~ _3/2! 46~Q 40~90 49 181 43 ................ 3/22 ~8~0 43485 89 84 42 . .. 3/23 ......... 651,00 ..44136 89 1Q~ 3/24 2134.70 42271 59 69 20 ................. ~/25 430.00 46701 59 .... 3/26 4753.00 51454 59 20'0 30_ .. 3/27 430.00 51884 59 .. 3/28 [0937.50 62822 09 480 3o ~5 ..... 3/29 3833.80 666~ 89 ]86 3~ 2115.o~ 6R77~ R9 88 ]~ ............ 3/31 1553.20 703~~ 09 40 ~ ...... ..... 4/1 1345.00 71669 o9 5o .............. 4/2 . 1162.oo~ 7283] o9 4~ ........ 4/3 1894_ ~oJ 74725 ~9 4/4 2~33,00~ 77358 09 60 50 ....... 4/5 2805.08~ 80163 17 120 __4 .......... 4/6 1935.50 .82098 67 40 35 .......... 4/7 1042.77 8314~ 44 15 .. '1 4/8 865.97 84007 41 7 1 ._ 4/9 2218,08 86225 49 30 . 4 4/10 6427.60 92653 09 i53 102 ... 4/11 430,00 93083 09 4/1~ 1394.05 94477 14 - ]2 '"3 ... ~/z~ ~000 2~2~.0~ 9~aoz: 2z - z Z~ .... 4/15 430.0Q 98308 IMCO FORM NO. 132 (Rev. 11/79) , , SUMMARY OF MUD MATERIAL USAGE PAGE OF ,., COMPANY LOCATION FIE LD I",~[~OS~IJICSS Unio.n Oil. .... Kenai Gas Field Kenai Ga5 Field A ~,,,~,~ ~ ~,,u. ,~L.U O. C,,,,~ WELL COUNTY STATE WAREHOUSE : ~,,,,,. ' ~~ ~o ~ .... KDU ~ W,O. __ Ken~i _ Alaska ~AI5 DEPTH DALLY CUMULATIV~ COST COST m ~ · · ~ 0 .,. 4/]6 4569 1459.0~ 99767 nl ' 70 .......... 4/] ~ 43n~ 1~8_32 4719 .665.20 101498 01 . . 16 4/20 1047.40 . 102545 41 42 ..... 4/21 430,00 102975 51 4/22 1574.56 104550 07 6 10 4/23 3820,38 108370 35.._ 1 83. 4~ . 4/24 1601.04 109971 39 4/25 4163,80 114135 19 12 230 4/~6 2405.92 116541 11 _ 15 4 1 ~0 4/27 1432.00 117973 11 6~ 4/28 6174,42 124147 53 73 ]8 24 4/29 430.00 124577 53 4/30 430.00 125007 53 5/1 430.00 125437 52 5/2 430. 00 125867 52 ......... 5/3 430.00 126297 52 .. 5/4 430.00 126727 52 .... ,,, .... IMCO FORM NO, 132 (Rev. 11/79) ""' ' *""- ,~ STATE OF ALASKA . ,~--,, ~,/~ ALASKA LAND GAS CONSERVATION C~- :MISSION ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIOn'S 1. Drilling well [] Workover operation [~ 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 78-55 3. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99.502 50- 733-20319 9. Unit or Lease Name KENAI DEEP UNIT 4. Location of Well at surface 692'N & 1720'W of SE corner, Sec. 36, TSN, RllW, SN. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pad 72' MSL A-028142 10. Well No. KDU #5 11. Field and Pool KENAI GAS FIELD For the Month of M,~.y ,19 82 12. D.epth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Ran dual 3 1/2" completion Released rig $ 24:'00 hrs 5/8/82 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None ,16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JUN - 1 982 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certi~that the foregoing is true and correct to the best of my knowledge. SIGNED _ _ IST DRLG SUPT DATE 5/27/82 NOTE-- n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Ga~Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION CC,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 78-55 3. Address PO BOX 6247 ANCHORAGE AK 99502 4, Location of Well 692'N & 1720'W of SE corner, Section 36, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 72.2' Pad above MSL 12. I 6 . Lease Designation and Serial No. A-028142 8. APl Number 50- 133-20319 9. Unit or Lease Name KENAI DEEP UNTT 10. Well Number KDU #5 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 [~ Stimulate [] Abandon [] Stimulation [] Abandonment I'-I Repair Well [] Change Plans [] Repairs Made I~ Other I--I Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · 2. 3. 4. . · . 10. 11. 12. 13. 14. 15. Moved rig #59 over KDU #5. Killed well, removed tree, installed and tested BORE. Fished & recovered existing dual 3 1/2" tubing string. Retrieved production packers and cleaned out to 8458' ETD (discovered collapsed casing below 8126'). Squeezed perfs f/ 8127-8147' and 8460-8472' w/ 200 sxs cmt thru ret ® 8027'. Ran CBL-VDL-GR-CCL logs. Squeezed perfs f/ 8024-8014', 7917-7907', 7887-7877', and 7422-7412' w/ 600 sxs cmt thru ret ~ 6100'. Perfed and tested f/ 5853-5863', 5779-5789', 5743-5753' and 5533-5563'. A. Ran production logs to find water entry. Squeezed perfs f/ 5853 to 5863' w/ 250 sxs cmt and f/ 5533-5563' w/ 250 sxs cmt. Squeezed for isolation above "A-8" sand f/ 4052-4054' w/ 475 sxs cmt & above and below "C-l" f/ 5189-5191' w/ 250 sxs cmt & f/ 5133-5135' w/ 250 sxs cmt. Rerfed and tested Beluga f/ 5779-5789', 5743-5753' & 5543-5563' and Sterling A-8 f/ 4054-4094' A-il f/ 4261-4267' & C-1 f/ 5137-5187' Set "DB" pkrs ® 5465' & 4353'· Ran dual completion and set dual A-5 pkr ~ 3992' . Removed BORE, installed and tested tree to 5000 Psi. Flowed well to clean up & released rig ® 24:00 hrs 5/8/82. 14. I h~ c~rtify that the foregoing is true and correct to the best of my knowledge. Signe(:{/_~,~~/~j~/ ,~ T~tle ~)T~,T DRLG SUPT T h~e below~rCom mission use ~ ~/~~~ ~nditions of App' roval, if any: ~'' ~- - ' ~~~ - RE£EiVE[ MAY 1 ? i982 Alaska 0il & Gas Cons. .Anch0rag9 Date 5/13/82 By Order of Approved by COMMISSIONER the Commission Date ~mJssio~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate -,~'", STATE OF ALASKA ALASKA O,c. AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. UNION 0IL COHPANY OF CALIFORNIA 78-55 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 133-20319 9. Unit or Lease Name KENAI DEEP UNIT 4. Location of Well 692'N & 1720'W of SE corner, Section 36, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 72.2' Pad above HSL 12. I 6 . Lease Designation and Serial No. A-028142 10. Well Number KDU #5 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 [~] Stimulate [] Abandon [] Stimulation [] Abandonment D Repair Well [] Change Plans ~] Repairs Made [] Other D Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to casing damage across the Tyonek Zone and excessive water production in the lower Beluga the wellbore has been abandoned below 5828'. This necessitates changing the completion intervals in KDU #5. It is now proposed to complete the well with the short string producing from the Sterllng A-8 and' A-il sandsfr_om 4054 to 4094' & 4261 to 4267' and the long string from the ~~'~'~0Y'-~89" ~ intervals. The Sterling C-1 sand will also be perforated and isolated with tubing, thus allowing for plugback potential into the C-1 if the Beluga waters out. By isolating the Beluga with plug in "XN" nipple and opening sleeves opposite the C-1 can be put on production in the long string. (See attached completion diagram) S.bsequent Work epo eaAPR 2 ? 1982 Form NO. [~ Dat~ ~--J~~/:_,&~.ska Oil & Gas Cons. Commission Anchoraoo 14. I hereb~tify that the fo~,eJiloij;~J~ true and correct to the best o~my knowledge. ;~oelfO~VpfpOr~vCa~,rr~im:sns;:~ us~- .... Date 4/27/82 Approved by BY LON~'II[ g. S~Ilit COMMISSIONER Approved Copy Returnmd By Order of- the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '- ,,~., STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION C~..AMISSION ~- (../~~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . , 1. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALTFORNTA 78-55 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 733-20319 4. Location of Well 9. Unit or Lease Name at surface KENAT DEEP UNIT 10. Well No. KDU #5 692'N & 1720'W of SE corner, Sec. 36, TSN, RllW, SM. 11. Field and Pool 5. ElevatiOnpadin 72'feet (indicateMSL KB, DF, etc.) I 6. Lease DesignationA_028142and Serial No. KENAI GAS FIELD For the Month of APRIL ,19 -82 r 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Fished & recovered tbg. CO well to 8466'. Determined 9 5/8" casing 'collapsed _o,o~+°"'n' & 8127'. Abandoned Tyonek perfs thru ret $ 8027'. Abandoned lower Beluga perfs thru ret ® 6100'. Abandoned one uPper Beluga per¢ interval thru ret $ 5828'. ETD 5828' MD (Ret) 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run Csg insp log f/ 8124' to surface CBL-VDL-GR-CCL f/ 6100-TOC A!~skaOil Noise, Temp Log & Prod Log f/ 5900' to 5500' .1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed: ~5779-5789' Sqz'd Perfs: 5533-5543' Sqz'd & 8127-8147' 8460-8472' 574~-5763' 4052-4054' abd perfs :8024-8014' 7917-7907' 4054-4094' 4189-5191 ' 7887-7877 ' 7422-7412' 4261-4267 ' 5133-5135 ' 5853-5863 ' 5137-5187 ' 17. I hereby~rtify that the foregoing is true and correct to the best of my knowledge. SIGNED V/,~.~...,~F' ] I /'~/~t'~.~,~'~.,~ ~*iTLE DATE NOTF-~l~.~nrt nn thi_~fnrm is r~.~]uir~.d f~r each~~t~'~th rc. oardl~r'~f th~..~tatu.~ of oac. ration.~ and mu.~t he filed in duplicate with th~ Alagka Oi __Gas Conserva Commission 10-404 F~t'm ~ree~l?i'g- m o nt h, unless otherwise directed. Submit in duplicate STATE OF ALASKA ~ ALASKA O~- AND GAS CONSERVATION CO),,,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 78-55 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 133-20319 4. Location of Well 692'N & 1720'W of SE corner, Section 36, TSN, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) _ 72.2' Pad above MSL 12. 6. Lease Designation and Serial No. A-028142 9. Unit or Lease Name KENAI DEEP UNIT 10. Well Number KDU #5 1 1, 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 Stimulate [] Abandon ~] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Puiling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to excessive water production from the Beluga perfs f/ 5853-5863', they were abandoned by placing a retainer at 5828' and squeezing w/ 250 sxs cmt. CIR ~ 01:45 4/]4/82. .Verbal approval was given by Jim Trimble 4/1~/82. 14. I h~rtify that the~ore~g4~ing is true and correct to the best of my knowledge. S igne~: ~,~~--~~--,~_ J~/~jTitleDTsT b RbG SUPT ~4~e s~ below f~; Commission use Date 4/21/82 ~ditions of Approval, if any: Approved by. BY [ON~iE C. SAflTI! By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · _ STATE OF ALASKA .~ ,/ /"b~l ALASK~-~I L AND GAS CONSERVATION C~. ~IMisSiOu ~JL ~"d. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS/ · Drilling well [] Workover operation [] I '~'I'~ 2. Name of operator 7. Permit No. UNION 0IL COMPANY OF CALIFORNIA 78-55 3, Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 5o- 733-20319 9. Unit or Lease Name KENAI DEEP UNIT Location of Well at surface 692'N & 1720'W of SE corner, Sec. 36, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) Pad 77' MSL 6. Lease DeSignation and Serial No. A-028142 10. Well No. KDU #5 11. Field and Pool KENAI GAS FIELD For the Month of MARCH ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations 06:00 hrs 3/19/82 Fished & recovered tubing to 5980'. 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None I 6. DST data, perforating data, shows of H2S. miscellaneous data None Ab. sku 0il & Gas Cons. Anch0rag0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~S, ~/ ..._,GNED ~/.~- f~)~~/~.~~.,TLE~--rn f r,~' '~'" DIST DRLG SUPT DATE 4/15/82 ~JOTE--I-~porton t is orim isequi ed ,or~,eac cale~th, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and ~as Conservation C~ommission by~~onth, unless otherwise directed. Form 10-404~'~ Submit in duplicate J, i~, UNDERHILL , APR 2 $198~i _~~ ~ ",.,.'.., ,,,.,_ ,,, ~,s ......... :' - ..................................... . -~!a,ka 0ii & Gas Cons. Commission - - , STATE OF ALASKA ALASKA ~,L AND GAS CONSERVATION CO,,,~vllSSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] 2. Name of Operator ON 0IL COHPANY OF CALIFORNIA 3. Address P0 BOX 6247 ANCHORAGE AK 99502 4. Location of Well 692'N & 1720'W of SE corner, Section 36, TSN, RllW, SH. 5. Elevation in feet (indicate KB, DF, etc.) 12. COMPLETED WELL [] A-028142 7. Permit No. 78-55 8. APl Number s0- 133-20319 9. Unit or Lease Name KENAI DEEP UNIT 10. Well Number KDU ~5 11. Field and Pool I 6. Lease Designation and Serial No. 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 Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well bore was abandoned from 8027' to TD. A cement retainer was set at 8027' and 200 sxs cl 'G" cement was squeezed into perfs from 8127-8147' & 8460-8472'. CIR ~ 18:15 hrs 4/5/82. Verbal approval was given by Jim Trimble 4/5/82. A cement retainer was set at '6100' and 600 sxs cl "G" cement was squeezed into perfs from 8014-8024', 7907-7917', 7877 to 7887' , & 7412-7422' . CIP ~ 23:05 hfs 4/6/82. Verbal approval was given by Sim Ti~mmbl~ 4/6/82 (Note: This permanently abandons the weii bore from 6i00' to TD). !ii~[t~ ~ ~l] ~ Subsequer, t Work .Bel~ortecl o,, ~o~-m No. / ~ ~ C~D~t~t ~/~-¢2- 14. I here/~certify that the foregoing is true and correct to the best of my knowledge. Signed ~4~,~ ~//~_~/~,~ .~~ , Title DIST DRUG SePT The s~e below for .~omm issio~n'"~se "--~ ~~ Cofiditions of Appro~aI, if any: - //,~'- ' Date 4/6/82 Approved by By Order of COMMISSIONER the Commission Date F~orm 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate /"~ STATE OF ALASKA ALASKA ,~IL AND GAS CONSERVATION C~,~iIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator UNION 0IL COMPANY -OF CALIFORNIA 3. Address PO BOX .6247, ANCHORAGE AK 99502 4. Location of Well 692'N & 1720'W of SE corner, Section 36, T5N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) 72.2' Pad above MSL 12. 6. Lease DeSignation and Serial No. A-028142 7. Permit No. 78-55 8. APl Number 50- 733-20319 9. Unit or Lease Name KENAI DEEP UNIT 10. Well Number KDU #5 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 IX-] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing tX1 Other IX] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). (See attachment) RECEIVED JUN - 2 1981 Alaska 011 & Gas Cons. Commission Anchorage Sui~sequent Wo[-k Rcpo:'[e~ ' l~p~e belo~ for Commission use ~nditions of A~roval, if an~: Approved Copy Refumed BY [0NI~tl~' C. SMIT~ 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 SUNDRY NOTICE 2 KDU #5 It is proposed to clean out, gravel pack the Upper Tyonek, and return to production as a dual Tyonek-Beluga producer KDU #5, Kenai Gas Field, as follows: 1. Move Rig #59 over KDU #5. 2. Kill well, remove tree, install and test BOPE. 3. Pull and lay down existing dual 3 1/2" tubing string. 4. Retrieve prod. packer and clean out to 10329' ETD. 5. Mill window in 9 5/8" csg across Upper Tyonek zone f/ 8127' to 8147'. 6. Underream hole to 15" f/ 8127' to 8147'. 7. Run and gravel pack 5 1/2" wi re-wrapped liner across Upper Tyonek. 8. SqueeZe Upper Beluga zone to shut off water. 9. Run dual 3 1/2" completion assembly. 10. Remove BOPE, install and test tree. 11. Place well on production. 12. Move rig off location. RECEIVED JUN - 2 1981 Alaska 0il & Gas Cons. Commission Anchorage fo T Hoyle Hamilton State Div. Oil & Gas ~.-~ocument Transmittal on Oil Company of Califorr ! COMM~~ :COM~ union I t ~ ~N~ I R. C. W~~ ~OEO[ u~on Oil co. TRANSMITTING THE FOLLOWING: TELEPHONE NO. 'STAT TE( Kenai Gas Field KDU #5 cc Radius of Curvature cc Tangential Average TBS A-20--2cc Radius of FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. Union Oil and Gas D~sion: Western Region Union Oil Company or California P.O. Box 7600, Kenai, Alaska 99611 Telephone (907) 283-7505 union February 2, 1979 Mr. Ernst W. Mueller State of Alaska Department of Environmental Conservation Pouch 0 Juneau, Alaska 99811 Mr. Hoyle Hamilton Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re- Subsurface Disposal of Kenai Gas Field Produced Water Gentlemen- It has been some time since we have communicated with you concerning our progress in developing an injection well. We hope that with this letter we can .,establish our current status and formally reopen our permit applica- tion. The draft permit' that was sent out in October 1977 reflected our original plans to inject produced water through the annulus of well K~U~.__~4_-3~l at a depth of 1300'. We tested this interval and were unable to inject fluids in this well. · In the fall of 1978, a new gas well, KDU-5, was drilled at the same location as KU 34-31 with the intention of injecting fluids down the annulus. We tested the interval below the 13 3/8" casing shoe set at 2521' and the cementing plug set at 3500'. This interval took the injection water satisfactorily and should meet our requirements for the disposal of produced water. Our latest projection for maximum water produced from the field is 600 barrels per day. This volume should be effective for the life of this permit. We are currently producing in excess of 200 barrels per day. We would like our draft permit revised to cover the change in water rate. At the same time,' the permit should be modified to reflect the well location name change to KDU-5 and the minimum injection depth would start at 2521'. The pumps and filters have been ordered with a delivery date scheduled for some time in March. We sincerely expect to meet the May 31, 1979 cut off date required of us by the E.P.A. Your patience and understanding of the complexity and expense of this seemingly simple project is appreciated. If there are matters that deem clarification to expedite this permit, please feel free to call. Ver~truly yours Dis trot Operation~?nager JDA: nc cc: L. J. Anderson J. D. Amundsen DRA f STATE OF ALASKA DEPART~tENT OF ENVIRONMENTAL CONSERVATION POUCH 0 JUNEAU, ALASKA 99811 WASTE DISPOSAL PEP~fIT No. I~IPC. 77-'!R _ Date This waste disposal permit is issued to Union Oil Company of California 909 West Ninth Avenue, Anchorage, Alaska 99501 for the disposal of liquid industrial waste resulting from gas production. The liquid industrial waste will be disposed of into the ground through Well~'t~--~t located at the Kenai Gas Field (Sec. 31, T5N, RllW, S.M.)o KDO-S This permit is issued under pro=~sions of Alaska Statutes 46.02.100-110, Water, Air and Envirom~.ent:~l Conse~¢atlon, the Alaska Administrative Code as amended or-revised, and other applicable State laws and regulations. This pemit is effective upon issuance and expires October_l, 1982 It may be terminated or modified in accordance with AS 46.03.120. . . . Ernst W. Mueller Co~issioner me LIMITATIONS Page 2 of 5 . o . During the period beginning on the effective date and lasting through the expiration or termination date, the permittee is authorized to dispose of liquid industrial waste by underground injection. . The discharge of liquid industrial waste and/or a flow of water onto the surface of the ground as a result of this underground injection is prohibited. The liquid industrial waste may not be disposed of at a depth of less than~v ~"~ feet beneath the surface. of the ground. 2~! The qUantity of liquid industrial waste disposed of shall not exceed -lO,000 gallons per day. ~ O The liquid industrial waste disposed of shall only consist of produced water from gas production. B~ I~t~NAGm~ENT REQOIR~mNTS 1. Change, in Liquid Industrial Waste Disposed of The disposal of liquid industrial wastes authorized herein shall he'consistent ~ith the terms and conditions of this oermit. ~"me disposal of any pollutant_ identified in this per-_it, or toxic material, including oil, grease or solvents, more frequently than or at a concentration or a limit not authorized shall constitute noncompliance with this permit. Any ., anticipated facility expansion, production increase, process modification, or change in any chemicals' used which will result in a new different, or increased amount of pollutant being disposed of must be reported .by submission of a new waste disposal permit application. If such change will not affect the ability of the permittee to comply with the limitations specified im Section 'A of this permit, the permittee shall submit written notice to the Department sixty (60) days prior to the commencement of such changes. 2. Toxic Pollutants If a toxic pollutant, including oil, grease or solvents, concentration standard is established in accordance with 18 AAC 70 for a pollutant present in this discharge, and such standard is more stringent than the limitation in this permit, this permit may be modified in accordance w.~.th tbc toxic pollutant concentration standard. 3~ ~Oncompliance Notification a. If for any reason the permittee does not comply with or will be unable to comply with any effluent limitation specified in this permit, the Permittee shall report the noncompliance to the Southcemtral Regional Office of the' Department,' }~cKay Building-!2th floor, 338 Denali Street, Anchorage, -Alaska 99501 (274-5527) within 24 hours of becoming aware of such condition by telephone, telegraph, or in the absence of both, by mail. bm A written follow-up report shall be sent to the Department within seven days of the noncompliance event. The written report shall contain but not be limiteR to: (1) times and dates on which the event occurred and, if not corrected, the anticipated time the noncpmp!iance is exTected to continue. (2) a detailed description of the event, including quantities and types of materials involved. (3) details of any damage to the receiving environment. (4) details of actions taken or to be taken to correct the causes of the event. .~(5) details of actions taken or to be taken to correct any damage resulting from the event. .4. Adverse Impact The permittee shall take all necessary neans to ~nimize any adverse impact to thm receiving environment resulting from noncompliance with any limitations specified in this permit, including such monitoring as necessary to deter- mine the nature and impact of the noncomplying discharge° The Department may require the permittee to undertake cleanup activities in the event of an adverse impact resulting from noncompliance. GENERAL 1. ~ight of Ent~ry_ The permittee shall allow the Co~-~nissioner of Environmental Conservation or his authorized representative, upon presentation of credentials: To enter upon the permittee's premises ~.zhere either the waste collection equipment or the discharge well are located at such times and upon such terms as the Department may reasonably require; and At reasonable times, to have access to and to be allowed to copy any records required to be kept under the terms and conditions of this permit and to inspect any monitoring equipment or monitoring method required in this permit. 2. 3, 4~ 5. 6~ 7~ Transfer of ~.mership or Control In the event of any change in control or ownership of facilities fromwhich the authorized discharge emanates, the permittee shall notify the succeeding owner or controller of the existence of this permit 'by letter, a copy of which'shall be forwarded to the Commissioner of Environmental Conservation. Availability of Records Except for information relating to secret processes or methods of manufacture, all records and reports prepared and submitted in accordance with the terms of this permit shall be available for'public inspection at the offices of the Alaska Department of Environmental Conservation. Civil and Criminal Liability Nothing in this permit shall be construed to relieve the permittee, from civil or criminal penalities for noncompliance, whether or not such noncompliance is due to factors beyond his control,-including, but not limited to, accidents, equipment breakdowns, or labor disputes. .Pr op. er ty_ Ri ght~ The issuance of this permit does not convey any property rights in either real or personal property, or any other privileges; nor does it authorize any injury to private property or an invasion of personal rights, nor any infringements of'Federal, State or local laws and ~egulations. .. Severability · The provisions of this permit are severable, and if any provisions of this permit or the application of any provision of this permit to any circumstances is held invalid, the applicatfon of juch provision to Other circumstances and the remainder of this permit shall not be affected thereby. Notwithstanding the above, in the event that such invalidation materially alters the scope or conditions of this permit, the Department shall have the right, at its .sole option, to terminate the permit. State Laws Nothing in this permit shall be construed to preclude the institution of any legal action or relieve the permittee from any responsibilities, liabilities, or penalities established pursuant to any applicable State laws or regulation. J Posting of Permit The permittee shall post a copy of this permit conspicuously at the disposal site and maintain a copy of it in their 'files. k --.~ SUBMIT IN DUI -.~ ~ATE* STATE OF ALASKA <s00 other in- st ructions on reverse side! OIL AND GAS CONSERVATION CO/IIiMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ! I I II ___.. II W ELL W ELL DR ~~ Other b. TYPE OF COMPLE~ON: WELL OVER EN BACK RESVR. Other 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, /~ 99502 4. LOC^TZON oF WELL (Report location clearly and in accordance with any State requirements)* At surface At top prod. interval reported below 406'S & 2657'E of the NW Corner, At total depth Sec. 6, T4N, RllW, S.M. 5. AP1 N~C~%L CODE 50-133Z.2.03.19 6. LE. ASE DF, S,[GNATION AND SERIAL NO. A-028142 ~i IF INDIAN, ALL'OTTEE OR TRIBE NAME 8. UNIT,FAI{~ OR LEASE NAME Kenai Deep Uni~ 9. WE~L NO. KDU #5 ;0. rmLn mD POOL, OR WILDCA.T Kena± Oas F±eld 11. SEC., T., R., M., (BOTTOM HOLE OI~JECTIVE) Sec. 6,.T4N, RllW, S.M. 12. PI~UVIIT NO. 78-55 I'{OW 1ViA_~Y* ROTARY TOOLS CABI,E TOOLS 22, PRODUCING INTERVAL(S), OF THIS COMPLETIOt~TOP, BOTTOM, NAME (MD AND TVD)* 23. WAS DIRECTIONAL !SURVEY MADE (Tyonek) 8127 ' MD-8472 'MD 7346 ' TVD-7710' TVD I 24. TYI~E ELECTRIC AND OTHER LOGS RUN C~SIxNG SIZE .... CASING RECORD (Report all strings set in w~'l'l) W~,~aaT, LB/~T. D~ S~'.T (~ ~OLE SIZE '[" 26. LINER I~EC O1~I1 SIZ~ '[ TOP (A~ID)[ EOTTO~a (I~D) } SACtiS CEMENT*, , 28. PEI~FORATiONS [OPF2N TO PRODUC~Olg' ' [ , (interval, size and number) I CP, MLNTING RECOlq,D ! A, MOUNT PULLED l,, 27. TUBING REC OP~D SCREEN (MD) SIZE DEPTH SET (MD) ] PACKER SET (MD) 29. ACID, SHOT, F,~A,C'I'URE, CF~%IENT SQUE-~ZZ, ETC. See Attac~ent #2 . D~ni iNT~V~ (MD) [ AMOUNT ;~D IC~ND DP MA~P~ US~ IIII I IIII I I I[ I I [ I I I II I DATE FIRST PI%ODUC~ON ~ ~ODUCTION ME'iHO'D (Flowings, gas lifL, pump, s--size and type of pump) [WELL STATUS (Producing or 12/21/78 [ Flowing , ' / Producing n~xz or TEST, [HOURS TEST~ '[CItOXE SiZE {pROD'N FOR OI~BDL. GA~CF. WATE~BBL. GAS.diL I J -- I --, -- F~ow, ~=IN~ lc~s~ ~SSUR~ ICA=~T~ O~L. ~~. W~SL. I ]]70 I ---- ] ~ > I ---- ~ 730n ~ ---- , ..... --~ , ,~-- 31. DISPOSiTiON OF GAS (~0~, ~le~ for ~e4 ~e~ted, cio.) TEST WITNESSRD BY · Sold .... 32. LIST 0F A~kCHM~NTS 33. I hereby ceriJi~that the foregoing and attached information is complete and correct as determined iron{ all-available redordS SIGNED_ TITLE Dist. Drlg, Supt. DATE 1/22~79 *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and teeses ir~ Alaska. Item: 16: Indicate which elevation is used es reference (where not otherwise shown) for depth meesure- ments given in ether speces on this form end in any ettechments. Items 20, and 22:: If this well is completed for separatc, production from more then one interval zone (multiple completion), so state in item 20, and in iteq~ 22 show the prcJucing interval, or interveJs, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a seperate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional date pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAI{Y OF FORMATION T~S'I'S IN('LU[)IN(; INTE[IVAL TESTED. PI~F--~iSUR£ DATA ~'~OV~I~ OF O1~'. GAS, 35. G~GIC MARK~ WA~ AND MUD MEAS. D~ ~U~ V~T. D~ See Page 1 , , 38. CORE DATA, Aq~ACI{ BHIE¢ D~CRIPmONS OF LITHoLoGy, POROSITY, FRA~RB, APP~ DIP$ AND DgTEC~"EI) SHOWS OF O1~, GAS OR XVA~. ,r,.u P---7 ~: / : :' '~STATE OF ALASKA :{:eeotherln- , struct~ons on 5. AP1 N:C~ CODI OIL AND GAS CONSERVATION COMMITTEE reverse ~;d~, 50--133--20319 WELL COMPLETION OR RECOMPLETION REPORT AND LOG* ~.:~:~a:o~ ...... A-028142 --: [-"~-[~ { WELL EN .......... , ~. si~z o~ o~o~ Kenai Deep Union Oil Company of Calif. ,. w~n~o. 3, ,~ss o~ o~z~,ro~ '' ' P O. Box 6247, Anchorase~ ~ 99502 10' Fm~ ~D POOL' OR - 4, LOCatiON O~ wznL'-(Report location clearZ~ and ~ accordance with ~ Mtate requirements)* Ka~ai at~u~ce 692'N & 1720'W of the SE corner, Sec. 31, T5N, n, ssc.,~..a.,~.,(~o~.~ o~m~vm) FILE: RllW, S.M at to~ ~roa. mter~a~ re~ortea~e~o~ 5'N & 382'E of SW corner, Sec. 32, at tota ae~mT5N, RllW, S.M. Sec. 6,T4N, RllW, 715'S & 3051'E of ~ Corner, Sec. 6, T4N, RllW. S.M. ~.e~z~o. 78-55 t I 21. I-IOW ~Y* ROTARY TOOLS 9695 ' TVD, 10,502 ' MI) 2 0 ' -10,502 ' 22. PI~ODUCING INTERVAL(S),OF THIS COMPLETIO~I~TOP,BOTTOM, NAME (MD AND (Beluga) 5533'MD-5863'MD 4902' TVD-5210' TVD 13. DATE SPUDDED ¥4. DATE T.D. iR.F_.A,CHF_,D [15. DATII CO'IVI-P SUSP Ott AtLa-.NI).8/29/78 9/22/78 12/5/78 ]i0. k'J.EVATIONS (DF, RKB, RT, GR, '5'TC)'{17. ELEV. CASINGHEAD72.2, pad above MSL~l TOTAL DEPTH, MD & TVD [9. PLUG, B~%CK MD & TVD]20. IF 1VEULTI~LE COM~L., INTERYALS DRILLED BY CABLE TOOLS 9.3. WAS DIRECTIONAL 24. TYPEELECTEIC AND OTHER LOGS RUN Gyro, W.L. logs .... 25. CASING RECORD (Rep~ort all strings set in well) c~.smc~ size. wEIGaT, nEmm SET (~X>) ~OL~. S~Z~. ?0" ' - C~hILNTING RECO]RJ) SURVEY MADE yes ! A~VIOUNT PULLED 26. LIN~ REC Otq.D 28. PEI{FOiR.AT[ONS OPF2N TO PRODUCTION (interval, size and number) See Attachment #2 SC}%EEN (MD) SIZE TUBING RECORJ) DEPq_W~I SET (MD) ; PACKER SET (MD) 29. ACID, Si:OT, FiIf~C%'URE, CF.,%IENT SQUE~ZF~, ETC. D~I I~TT~V~ (MD) i AMOUNt ;~D I-lIND OF M~TEFA~ US~ 30. PRODUCTION DATE FIRST PI%ODUCTION [ PI%ODUCTION METHOD (Flowi~g, ~a$ lifL pumping--size and type of pump) [V/ELL STATUS (Producing or [ znut-ln) · _~~ 7~8 | Flowine _ I Producin~ I i ITEST P P~TLI O D .., i-. ! ..... ;' I-- I i I -- 'FLO%%;, TUBING- ]CASING PRESSURE [CALCULATED OII.--BBL. QAS--~CF. WA~BBL, [OIL GRAVITY-AP1 I TEST WITNESS[ID BY:} so:a , [. 2 ,,. :' 82. LIsT O~' ATTACHMENTS block squeezes, test intervals, core data, wel]bope schematic 33. I herebY' c~ti~ that the fo~otng/l~nd attached information is complete and correct as determined fro~tv~i~al~e ~$e~r(~'~0i];]i, sm~:~ ~ ~, /~~-~ _~~I~,~, . Dist. Drlg. Supt. ~r: i_/22/79 ~" *(See InstructiOns and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repor! and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in clher spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separato prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item'S6: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item '~8: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TES'I'S INCLUI)IN(; INTERVAD TESTED, PRESSURE DATA A.ND P,.ECOVERIES OF OIL, GAS. 35. G IDOLOG IC M ARK~R~ WATER AND MUD See Attachement ~2 Top Beluga 5~15 ~ ~796~T~ Top Tyonek 8115 ~ 7366~D D Zone -1 9686~ 8893~ See Attachement ~3 ., .,,, ~. Attachment #1 BLOCK SQUEEZES Blk. Sqz. #1 - Through ports in D.V. Tool @6512' csg. meas. 6500' CBL - 6511' DIL - Squeezed w/500 sxs. & ports closed w/RTTS Tool & tested. Blk. Sqz. #2 - 8472-8474 DIL- Sqz. w/ 500 sxs & drilled out. Bl k. Sqz. #3 - 8480-8482 DIL - Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #4 - 8152-8154 DIL Sqz. w/ 500 sxs & drilled ,out. Blk. Sqz. #5 - 8026-8028 DIL- Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #6 - 7919-7921 DIL - Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #7 - 7724-7726 DIL - Sqz. w/ 500 sxs & drilled out. Blk. Sqz-. #8. ~. 7424-7426 DIL - Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #9 - 5865-5867 DIL - Sqz. w/ 500 sxs & drilled outT Blk. Sqz. #10 - 5791-5793 DIL - Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #10 Stage #2 5791-5793 DIL - Resqueeze w/ 500 sxs & drilled out. Blk. Sqz. #11 5713-5715 DII - Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #12 - 5601-5603 DIL - Sqz. W/ 500 sxs & drilled out. Dry Test #1 - 'Dry Test #2 - Dry Test #3 .- Dry Test #4 - 8545-8547 DIL - Perfs open - dry tested & pressure tested. 7974-7976 DIL - Perfs open - dry tested & pressure tested 5875-5877 DIL - Failed to dry test sqz.~as Blk. Sqz. #13. 5520-5522 DIL - Failed to dry test - made same sqz. as Blk. #14. Blk. Sqz. #13 - 5875-5877 DIL - Sqz. w/ 500 sxs & drilled out. Blk Sqz. '-'14 5520-5522 DIL Sqz. w/ 500 sxs & drilled out. Blk. Sqz. #14 Stage #2 5520-5522. Blk Sqz. #t5 6561-6571 -.sqz w/~0- Resqu~ez~e'eV~ o2u5t0 sxs & drilled out - SX.-,, Clrl I i ' Blk Sqz #16 - 6602-6604 - sqz w/ 250 sx .~ drilled out Blk Sqz #17 - 6561-6571.-.sqz .w/ 250 sx. - drilled out " Bl']('Sqz #18 '-'-4050-4052 - sqz w/ 500. sx - drilled, out, ...... , .~ -.. ~ -~- . .. . .~;.~. . .'- -*All perforations 4 - 1/2" HPF Attachment #2 TESTING SUMqAR Y DST NO. 1 48 '6 Note: ZONE Upper Tyonek ~PERFORATED INTERVAL 8127-47, 8460-72 FLOW TIME (HRS) 63 RESULTS 7.9 MMCFPD at 990 psig (Open f~r] Prodactio Beluga 7877-87, 7907-17, 8014-24 6.5 No entry Beluga 7412-22, 7877-87, 4 7907-17, 8014-24 No entry Beluga 6561-71, 7412-22, 4 ?877,87' 79,07-17, 80]4-24 ~30 MCFPD at 40 psig +50 BWPD Beluga 6561-71 13.5 Beluga ~ 5533-63, 5743-53, 81 ~/5779-89, 5853-63 ~ ..... 20-80 MCFPD at 30 psig +50 BWPD 10.4MMCFPD at 1100 psig (Open for productt +60 BWPD ~-----~ ......... ~ .... Beluga 5533-63 12.5 100-300 MCFPD at 90 psig erratic water production Beluga 5'533-63 6 7.0 MMCFPD at 995 psig erratic water and sand production Beluga 5533-63 133 10.8 MMCFPD at 1075 psig +75 BWPD with trace sand All tests were performed through 3 1/2" tubing with 1200-1300 psig gas cushion All perforations 4rl/2" HPF 516 E. 18TH STREET. BAKERSFIELD. CALIFORF~I~ ~JL~ · ~,.,,~r.~,~.,~:~ ~ At tachememt CORE LABORATORIES, INC. October 11, 1978 Union Oil Company of California P. O. Box 6247 Anchorage, AK 99502 Attention: Mr. Bob Wortham Subject: Core-A nalysis Data Kenai Deep Unit #5 Well Keno; Gas Field Kenai, Alaska Gentlemen: Diamond core equipment and water base drilling fluid were used in extracting core from the subject well. These cores were submitted to our Anchorage laboratory for permeability, porosity, grain density, and fluid saturation determinations. The results of these analyses are presented in the accompanYlng, report. FUll diameter analysis was also reqUested and these data are included i'n the above mentioned report. Also requested was a core gamma surface log of the entire depth which is enclosed, We sincerely appreciate this opportunity to serve you.~nd hope these data prove beneficial in the development of this reservoir. Very truly yours, CORE LABORATORIES, INC. ~reiSctA ~aCnUaS~e~r' Cali fornia Professional Engineer P-1176 Enclosures JAC:smc Company Well, Field County. Location. CORE LABOIIATOI{IES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS UNION OIL COMPANY OF CALIFORNIAl:.ormation' BELUGA, & Tyomek KENAI DEEP UNIT NO. 5 Cores. DIAMOND KENAI GAS KENAI State ALA.. S KA Page]- o~ 2 File.. BP-3-490 Drilling Fluid WBM Date Report 9/25 / 78 Elevation Analysts Remarks DEAN-STARK ANALYSIS, & CONVENTIONAL ANALYSIS CORE ANALYSIS RESULTS · (Figures in parentheses refer to footnote remarks) PERM EA BILITY R ESI DUAL MILLIDARCYS SATURATION SAMPLE DEPTH ..... | POROSITY GRAIN ' . ~' ' REMARKS NUMBER FEET Horizontal1 Horizontal Oil ITotal Water Maximum 90° Vertical PERCENT DENSITY % Pore ] % Pore 1 5551 940 29.8 2.72 0.0 74.2 ss,f-cg, v friable 2 52 133 28.2 2.71 0;0 85.4 same 3 53 923 29.7 2.72 0.0 66~6 same 4 54 1734 29.7 2.72 0.0 83.8 same 5 55 615 27.5 2.71 0.0 69.8 same 6 56 1343 30.3 2.70 0.0 59.6 same 7 57 1066 29.1 2.71 0.0 67.5 same 8 58 950 27.7 2.72 0.0 65.0 same 9 59 424 24.9 2.'73 0.0 66.2 same 10 60 252 25.0 2.73 0.0 68.4 same 11 61 2377 27.2 2.71 0.0 54.1 same 12 5562 1157 26.7 2.70 0.0 51.5 same 13 9835 14 36 15 37 16 38 17 39 18 40 19 9841 20 9887 21 88 22 89 23 90 24 91 25 92 26 93 27 94 28 95 29 96 30 9897 205 172 194 .1 2.65 0.0 46.0 ss,m-vcg, cortg · 7 2.64 2.8 50.9 same .8 0.0 43.7 same *Sum. fluids porosity 879 810 193 .2 2.64 0.0 53.0 same .4 .~ 0.0 65.3 same * .2 0.0 56.5 same * ~8~ 0.0 41.1 same * 22 12 1.6 2.1 0.3 0.1 0.2 0.0 0.1 0.0 0.0 18 19 *22 19 '16 *20 '15 18.6 16.6 12.7 13.5 7.7 6.3 6.0 3.2 5.5 3.8 3.7 2.74 0.0 75.9 ss,f-rog, v cly, slty 2.66 0.0 55.8 same 2.63 0.0 63.6 same 2.67 .0.0 64.3 same 2.67 0.0 69.7 same 2.68 0.0 64.9 same 2.68 0.0 66.8 same 2·69 0.0 75.8 same 2.71 0.0 69.4 same 2.70 0.0 62.0 same 2.69 0.0 61.6 same These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for who~ exeh~lve and corffident~l use. this report is made. TI~ interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions ex- cepted); but Core Laborat~r~ Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, propex operation, or profi~bleness of any oil, gas ~r other mineral well or sand in connection with which such report is used or relied upon. COR. E LABORATORIES, 1NC. Pet roleu m Reservoir Engineering DALLAS, TEXAS Company IINTON OTI', COMPANY OV CALTFORNTA Formation Well KENAI DEEP UNIT NO. 5 Cores , Field KENAI GAS Drilling Fluid WBM County M]~ NA]I State ALASKA - Elevation Loca t ion TYONE. K Page 2 · · of_ 2 DIAMOND Fne -.- BP- 3-490 Date Report , 9/25/78 Analysts WSP Remarks. COMVEMTIOIqAT. AlqAT.y.q!$: BOYLES LAW POROSITY CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remarks) PERMEABILITY RESIDUAL MILLIDARCYS SATURATION _-SAMPLE DEPTH I Horizontal 1 POROSITY GRAIN " ' REMARKS NUMBER FEET ' Horizontal -Oil ITotal Water Maximum ! 90°[ Vertical PERCENT DENSITY % Pore } % Pore 31 9898 O.0 32 99 0.1 33 9900 5.5 34 01 6.0 35 02 6.4 36 03 10 37 04 4.7 38 O5 5.2 39 06 1.9 40 07 2.8 41 08 8.5 42 09 2.2 43 10 6.0 -44 11 6.1 45 12 6.6 46 13 3.5 4.1 2.70 0.0 57.0 3.1 2.63 0.0 55.7 15.9 2.67 0.0 58.4 15.9 2.68 0.0' 58.6 16.3 2.67 0.0 59.1 16.9 2.66 0.0 71.7 15.3 2.68 0.0 69.5 15.4 2.67 0.0 70.6 13.3 2.71 0.0 68.9 14.2 2.66 6.0 62.0 16.4 2.66 0.0 58.2 14.5 2.67 0.0 63.6 15.9 2.67 0.0 66.8 15.7 2.67 0.0 70.6 15.4 .2~67 0.0 71.8 13.9 2.66 0.0 72.5 ss,f-ag, v cly, slty s awe s awe same ' '- same s aw e sawe s awe s awe sawe, carb s aw e s awe s awe s awe s amc s awe These analyses, opinions or interpretations are based on observations and materials supplied by the' client to whom. and for whose exclttsive and confidential use, this report is made. The interpretations or opinions e~pressed represent the be~t judgment of Core Laboratories. Inc. (all errors and omtssion$ ex- cepted); but Core Laboratories. Inc.. and its officers and employees, assume no responsibility and make no warranty or representations, ax to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Reservoir Engineering LOCATION COMPANY II'TON C~TI. COHPAI~ O~ ~A1.TF. FIELD. KENA:[ CAS WELL KF~I~IA'[ FIF..F.P l'~NTT MO_ $ ,' ._ COUNTY Y~NA]~ STATE ALAS KA ELEV. _ ._ FILE BP-3-490' DATE 9/2.5/78 VERTICAL SCALE: 5".~ 100' CORE-GAMMA SURFACE LOG (PATENT APPLIED FOIlll GAMMA RAY NAOIATION iNCREASE v COREGRAPH PERMEABILITY x lO POROSITY-- ~ILLID&NCYI PIIrcINT 100 50 10 5 1 k'llllll' IIII L)I IIII IIIL I~Zl II!1 IIII I1~1111 1111 II~TIIII I!]! I!~11111 IIII l]Jl]ll III1 !11,III IIII Ili. llll I111 I111111 lllt II11111 1111 IIIIIII III1 I II11 I1~111 1111 []j]lll Illl IIIl11~ !11! ljjl~l Illl 111~1 IIII II I I IF'P' Illl !11[111 II11 IIIII!1 !111 II11111 11 I111111 II11 Illllll IllI I111111 llll IIIIII1 IIIJL IIIIIII II11 J II11 ilillll i-I LI[ I111111 I111111 i111 II11111 II1! Illllll Ill] IIII IIII111 I111 I,L III1 llll ll~,k IIII111 ilK[ III1'111 I1111 I111111 Illllll. Illl I111111~ i111 IIIIIllC. 1111 it..t~l,~, jjl~ !1 'i 11 !111111 II11 II11111 I111 IJlllll Illl !Ili111 IIII II1 1111 Jill TOTAL WATER- PERCENT TOTAL WAT[I~ 8~0 60 40 20 0 Oil SATURAtiON ....... 20 40 60 80 Attachment #4 · . WELL PROFILE OPERATO. WELL ~ COUNTY ~ NEW TUBING CASING SIZE , .., !?'~'/~' ].. , , *RAOE*'80!..._____.I ~-~!~. I i EQUIPMENT AND SERVICES COMMENTS: TOTAL ESTIMATE PREPARED BY Worksheet No. 523 IOFFICE '{ PHONE SAVE TIME AND MONEY WiTH BA BA~ER OIJ TOOJS, INC. WELL PROFILE ........................... ;.._~ _ OPERATOR WELL COUNTY TUBING '= I ' I~!~~ I I EQUIPMENT AND SERVIC ,o// 0'7-/s COMMENTS: WELL INITIAL FLUIDS FINAL I TOTAL ESTIMATE PREPARED BY IOFFICE I PHONE Worksheet No. 523 SAVE TIME AND MONEY WITH BAKER COMPLETIONS BY BAKER ~A KER O/VIS/ON JA K[/~ OIL ~'00L $, INC. HOUSTON · LOS ANGELES * NEW YORK ,. ','"';''-'" ,, OCT. 5, 1978 CC,,', ~.' u:: liON ?F .... i~' :, R T ~:, - ..... c"' ~,~x~'~ UN~ON O~L Cr~v,°A?~Y .... Of~ C,~L~~:'''''~'''' , o~,~]A ': ...... ~'' Kc,~"'NA~ DEE°, UNIT Ri--Ct)mD OF SU%VEY ~I_L C,.'.,LCULATin'''¢',.,,,.~o Pr:PFOi::~;'"Lg,,,,, ,.~ BY I 2 ELECTr~ORiiC COi',.PUTER TRUE k:EAS. E;q!FT VERTIC/:,,L ,SUB DRIFT TOTAL COORDIKATES C L 0 r' E.'~ T ~.-'., . Ai4GL~::. ~"u E ~. T H ,~', ~"A: D!REC, ~'~ t S T ANC E '~ ,L ,~ ~ ~'' ~..,~; L~~ [;. ~,~ ~ 'Op"-"-' """ DOG LEG S U R ~ S SEVER;TY ANGL~' OEG/LUOFT D ~'.i S ~SE '~ ON r", .* ,' 2.00 -96.00 S74.85E O.C,O S O.OO ~,',' '" r' .I r'~ "i "'""~ 103 '~ 0 z,,,v.O0 4.00 57a..SDE O.,C,,, ":- O.OC, W ' ~ r", S'C, 3 0 .. 300,,,00 2C, 4.00 STa. SPE: 0.:}.00 S 0.00 W A:., ~.. 4'., ,,.,' · ,,.: 0 3":L.C}r'' c74.~5P- ',; .':00 ,. S ,:.. i O.CO r, :,) :.:1,' 0 '50 (..!. r,.:,...,, ,4 U "~ . r~...,. ',,i,' S 7 a.. 35 il: 0 · 00 S 0 ,i 00 &(ii." ' 6 ,'.10 · U t: 504. (.)r; S7/.:. o r-:~ 9 ii 0.00 ,5 {~ '..j ,,., ..... , .... . ...... ,.. "~ . ' 3..36 7C'(') .a a ~v9o93 603 93 S74..~-}5E O.gi S.- ,-~ 800 5 0 799°,53 703.63 S7'3.7gE 3.03 S ..... ' '1'01'~:./2 ~:': ..... c'"'O r. o0 ~,qS '~') 8(')3.~2 ¢72.72-' 5.~2 $ 20.'~1 "' · ' . ,z ., . ',.. · ~ ~ , .,. ,~ - ~ i i ','.} .)-z 3 1 US7 · 8'fi, 1'301 .,Sa Se,.'::' · 0 U ~ 11,.4-2 S 4-1.87 .:" 2.~" 0I u;" ,."" :,'" I '96.7 a 1100.14._ S7r',,~ · 5,-'~ 1~.~':' :~-, .... S 55.,72 ~': ~!,"'"~. ~-.,,.. 1$ 0 129n..73, Ii9.fi1.7°-,.., .58~.63E,.. 25.53 ...q 76.'41 ..... t ', S'--'. "'~ ' i.'-+'d.. .,..-,- 0 1 391.97 1295o°7 ..7. 30.4r:, .5 97.23 E _ -, '~.' .,. ,__ ~ ._ 1500 17 30 !4S. 8.2i 1392,21 586,77E 31,9'2 S 124..%3 E 1600 22 0 iD~2.33 148f-, ~3 5~7,3~r -'~ ........ . ~.~.o5 S Ib~;;.OR.~ ,, 178{i} 2r, 0 167a,";4 z5¥o,0:+ So7,00~ 35 6i S 197,90 .... ,';~ .. 176q · 5_% 1 ' '< -~ .~ .. oo. ,53 $87.59E 37, ~ - igO0 51 0 IS5..q,57 1754,57 S88,00Pi 59,65 S 291,68 200" 31 O Ia~6o2~{! ~840o25 $d~,65H 4~,15 S 543 16 F-' ,z ,,;,. '"': 3 '! ,a _ ,, - -. '- '"'..~; ~O 2021 77 1925,77 $87.60m 42,85 .5 395,01 22n0 ';1 ~ 2107,1.5 20~I,15 S88o35~i a-4,6:~ ~- 447,04 E ~.00 .5 0 0 o w 0.0'30 OoO0 $ (}.00 S 0 O 0 W U.O00 O,CO S u O 0 :,.~ O,OOU O.""c, q 0 0 " u. · C 0 3.~8 ~ 7~ 50 DY E 4.000 1t,33 ,S 74 28 46 i 1.003 21,35 S 73 Da 9 ?'i 1,504 43,97 S 72 58,74 S 71 33 k<~ i 3.Oia 78,66 S 7 101,88 S 72 36 33 5 4,3'90 - i28,36 S 75 36 4 i 3,5ol 151,62 S 77 5n ZOi.O8 S 79 .47 49 E 24.5,39 S 294,36 345,62 S 83 9 38 E 0,335 397,33 S 83 48 Z9 E 0,739 449,27 S .84 17 32 E C,e77 C.O0 C.O0 O.O0 0.00 C, · O0 ,..,. O0 3,q4. i1,2i Zl.14 b2:. iv ,-,3.71 j4~ 10!,20 !2~.50 i95,26 262.56 3~C:.2C :570,25 42'3.5i A L L RECORD OF CA[_CUL_,,~.,TIO,~C, c..~.'RFf:)!~'..,E'r-, ~y · I ',,.. , t_ , v ,.. ~., SURV E Y .. ,,, . .... ONIC COMPUTER 2300 "~0.,~'0.:,' .; 2400 30 0 250,,3 30 30 260(.) 30 0 pTO0 S ~ 3~ 2800 32 15 3000 34 · ', t O0 3'5- 0 3:) ''' ''3'" "'.'] 0 ;) 3 ?~ 0 5400 31 0 350O 32 0 3600 32 15 BY00 3'5 !5 '~.500 25.4 /.,5 3 '-2 C' '?., '35 0 4Ct.,-, ua ,.-,, .., ~. 4300 35 O 4 ~0...~ 4600 35 15 &Tr'~r', %~ a~O0 .SS 0 agO0 SG . · u,,. 36 15 V,:.RT i CAL 2!92,95 2279.96 23~= 2452.13 25~8o0V 2622,99 2707.2! 2790~60 2873.01 2957.35 5130o12 3215.38 330O ,07 338a.].8 3457 · 08 ~549,12 3712,32 3793.86 3875,52. 3957,19 4.0~8,65 4120,64 4201,9~ 4363.73 4464,50 4525,79 SUB DR I FT $ ~':d A D [ R E C 2096,98 $86,60E 2183.36 584,00E 2269,75 S82.!7E 2356.13 S83,,00E 2442.07 S82.72E 2526,9o .. . oo8.55a 2611,21 2694.60 2.777. Ol S87.22E 2861,35 S77,37E 2947.96 568.30E 3034,12 263,68E 51i9,~8 S64,~0E 3204.07 S64.97g 32S8,i7 S65,57E 3371 "" " · vb S03 · p , 3453.].2 ~53q,78 S61.¢5E 3616.~2 56i,34E 3697,86 561,98E 3779,52 3861,19 3942,85 S59,93H 4024,64 S59.77~ 4!05.93 S60.59E 4186,83 S59,85E 4267,73 S61,55E 4429,79 S6!,00~ TOTAL COORS I NATES 46,92 $ 5t,05 5 57,12 S 03,62 S 69,97 S 73.99 S 7 7 s ! u 9, >4 129.~0 6';' 498,31 E 54.8,52 E 598 · 53 E 648.48 E 699.22 E 751,87 E 805.77 E 560 · 68 E 916,97 E 97,0~...2,2 ....... E ...... 974 80 :: ., [ -. t0~. ,v:~ .: i02:; d'"J 1 o~.,'s.p,::,~ i072 24 12 E 55 E 54 E ~7 E 702.7'i S 8a 1'7 ~ E 755,50 S 84 22 45 E 809,25 S $4 39 22 864,4~ $ 84 37 52 ~ 921,11 S 84 34 ~ ~ S Sa 26 35 E 5 L~';j 52 4~ .i $ 03 2 48 E 82 10 3i E 81 23 32 E S 80 4.1 22 n c 79 59 32 Ib33,22 S 79 16 25 E !44.3,54 S 77 53 12 E 1~99,b2 S 77 16 7 6 i55~,13 5 76 41 25 =d 1610,70 $ 76 7 59 [. ib66,'a;~ S 75 35 41 cE 172!.B3 S 75 4 31 ; 177~,!8 S 74 35 34 i i835.!8 S 74 8 14 E i59'2,40 S 73 45 25 E !949,99 S 73 20 49 E 2006,9(} S 72 59 i8 E 500,51 S 84 37 550°89 S 84 40 601,25 S 8~+ 32 651.~0 S 84 23 198,12 222.16 248.13 275.26 302,98 330.46 356.0! 386,04 414,5~ 472,41 501,61 5B0,37 556,81 587.14 S S 1208.50 E i22..63 1258.98 E i270,44 1309 ,'93 [ 1500,~7 E 1411,70 U i~62,65 E 1513,36 E 1563,51 E 1613,99 E 1663,75 E 1714.28 ~ 1765,30 E 1816,56 1868,20 19i9,C9 006 LEG SEVE&ITY DEG/iOOFT 1,182 i.402 !,049 0.652 1.507 5,165 a.810 4.208 7.267 4.p31 0,435 l.Obi 1,~95 0.635 0,777 0,258 0,~7 0.755 O.~O6 0.736 "J.266 U.~89 0,435 ~.999 0.516 !.2~7 SECTIOh 521 .~ 569.' 5i8,22 667.15 7!6,65 766,67 819.07 873.05 924.62 9V4.26 i025.01 1077,23 1130,40 1297,4~ 1355 i700,lb 1618,61 !875,1~ 1933.8b 1'9'~1.90 ALL, C AL.. CLJL;~',t" I ON $ ,.. Or,L) OF P E Fi F 0 R k'i El [) B Y UmVc. ~ ! R M ELECTfRONIC E Oi,'iPUTER EAS, D2, iFT ,'-p .,,,,,~ L~ ~::. TH, AG :'52O0 ~2 15 5qO~ ..... r~ 4 0 n 5500~ 25 5600 .....2 570 n 5gO0 19 5gO0 ~7 0 600(,) 6 ! C.~..~ ~ i ~: 0 6200 ! 6 15 63(~q 16 45 c,~*...,, i6 30 6500 t6 ~ 5 .... 66 {) ..) 1. 670 ') 17 0 6 ~ ',) C 17 0 7r' ~' '''i 7200 !6 33 v'~O0 IV 0 7403 17 30 75' 7600 !T 7 ,u,; !T 7800 !7 7900 16 45 TRUE V if R T Z C A L PEP"' ' a 609 · 06 4.694.66 4782 · 54 4872 · 42 4963 · 78 5056.41 5!5U.3i 5245.4i 5341.'30 5a~-7,4.2 5535.49 5.629.37 5725o19 5821,15 59! 6012 · 6108.59 6204 , .31.+, 63 .C. ':.~ · 2 6395,I! 6491.99 65~7o75 6683,25 6778°49 6g73,80' 6969,23 7064°60 7160 , 17 7255,9g SUB SEA 4513°06 4598.66 a656,54 L..776.42 4867.78 4960 5OrCa 5149 · 41 5245 534.1,a2 54~7 · 49 5533.37 5629.19 5725.1S 9916.96 ~i2,59 6106,34 6204,2~ 63O0, i I 649t,75 6587.25 6682.49 6777.80 6873,2S 6968,6G 7064,11 7159.99 DR I FT DIRE(: $60,48E 859 · 87E $59.25E $58,68E S5.9 · 2 SE S59~45E S58.63E 858.73E S58,80E S58.93E S59.00i S60,OOg S57,95~ S58,67E 55~3, ~OE 558.75~ S60.6OE S60,52E S59,48E 559.43E S59.00E 555.95E S57.93E 557,90E S56,88E TOTAL COORDINATES 614.21 S i967,40 E 63?°92 S 2012,25 664.09 S 2053,39 E 686.45 S 2091.09 El 707.36 .S 2!25.98 E 726,77 S 2158.25 F 744 ...~ 0 S 2187,86 : 760,,,~u .., ~21a 36 E 803.~.:'~' ~ ~'' ~:2~' 8! ~..' ~::~ ~47.S6 5' 2359,'0'8~"E 861.~ S 2353.3,2 E 8,75,~'7 5 2407.97 591,17 S 2~52,8S 906,27 S 2457,43 E 920,9'6, 5 2481.73 E 935,~o r, ~ S 2506,.~2 950'03 S 253,9,54 E 9~4~1~ q 25:5,~4 979,02 S 25gI.32 E 994.51 S 2607,57 !010,01 S 2633,59 i025.~0 S 2659,i5 E 1041.14 S 2684, SO I056,7~ S 2709,75 1072,20 S 2733,85 E C L (;' $ U R E S STANCE ANGLE 2061,05 S 72 39 42 E 2111.55 S 72 21 31 E 215L~.!0 S 't2 ~+ 40 E 2200,88 S 71 49 34 E 2240,57 S 7! 35 47 E 2277.34 S 71 23 22 E 291i.00 S 7i t2 ~2 rZ 22~41.22 S 7! 3 8 E 2968.97 S 70 54 1U E 2395.92 S 70 45 59 ~ 242~,!0 S 70 37 5C ~'"2 2~50,92 .5 70 ~9 4p E 2506,65 S 70 14 32 ~ 2534,19 S 7U 7 67 ~ 2562,32 S 70 0 ~1 E 2590,97 S 69 52 ~ 6 2619.22 S 69 45 24 i 2647,11 S 69 Sb 24 E 2675,01 S 09 3! 32 ~ 27C2.99 S 69 25 2i E 27~i.47 S 69 19 45 .E 2760.74 S 69 15 46 i 2790,79 S 69 7 24 i 2620,62 S 69 1 3 g 2850,03 S 6B 54 4~ E 2879.60 S 68 45 14 g 2908,53 S 68 41 40 E 2936,59 5 68 35 ~ E 2;0'3 LcG~. SEVEi4i ]'Y DEG/!COFT D l S T A~'q C E 2.765 2047.05 2.272 209~. 3.015 2!45. 2.002 t1~9.43 2,023 2229,8i 1.'7~5 2267.19 2.25i 2301,37 2.015 Z~32.0~ i. 000 236v". 22 0.019 23.57.56 U..251 2415.12 C.50O z44.3,3i C.ZSI 247i.70 0.3.77 2499.71 d.OOb 2527.54 0°bO6 2D55,97 3,29d Z5C4.96. (j,P66 261'J,<' '3 · 020 >i ~ 4 ! e .... O.b 14 2o09,5ii 0,525 2698,!1 0°501 27260~0 0.587 2736.30 O,50O 2756.59 0.76! k816,65 0,307 2~7~.I0 O.7~O 290~.26 0.~84 -2953,55 ALt. RECORD OF CALCULATIONS PERF SURVEY ['~ ~,~ '::LF'CTRONIC COMPUTER 9, EAS. D ~2 P T H DRIFT ANGLE 8100 16 0 8200 16 0 8300 16 0 8~.+00 15 30 8500 15 0 S600 15 0 870O 14 15 8800 13 30 8900 la 9000 13 O 9100 13 0 92OO 12 0 930C: 12 0 9400 i ! 30 950O I! g60O 11 30 970(,'. ! t 0 9800 1 1 0 ~00 10 30 lO000 i0100 lO 0 10200 i0 0 10300 lO 0 ~-OaO0 lC 0 10900 10 15 I05,.'2 tu 15 T rD :.,UE VERTICAL DEPTH SUB DRIFT SEA DIREC DEG. 7S52.00 7256.00 S56,84. E 7448,12 7552,12 556,77E 7544,25 7448,25 856.72E 7640,49 7544,49 656,67E 7736.97 7640,97 555.65E 7833.~r ,'~ ~o 7737,55 856,00~ 7930,32 7834,32 S56,52E 8027.41 7931.41 S54,52E 8124,54 8028,94 554.45~ ,.q')21, ~. 7~ .... ~,125.78 ~ ~q5~.43E ., ' ~3!9.2! 8223.21 553.37~ 8416,84 8320.84 S5~.~2E 8514,66 8418.66 552.2gE m612.56 8516.56 S51o25E 8710,56 3614,56 S50,84E 8805,55 ~712,55 S49,30E 8906,63 88!0,63 S50,72E 9004.79 8908,79 S48,70[ 9103,03 9007,03 $46,67E 9201.28 91G5,28 S46,62E 9299,61' 9205,61 S45.59E 9~98,09 9302,09 S43,52E 9A96,57 9400,57 $42,45E 9595,05 9499,05 S42,35E 969B,a9 9597,49 S42.25H 9695,46 9599,46 S42.25E TOTAL CoOx~,~INAT~'S 1087.50 S 2757.28 1102.59 $ 2780.34 1117.70 S 2803.39 1132.61 S 2826,08 1147,26 S 2847,93 1161.79 S 286'9 · 34~ CLOSURES D I STANCE ANGLE D M 1280.98 1293.78 1306.32 1318,68 1331.21 1344.02 t356,66 1369.04 138i.74 1394,56 1407 · 56 1407,~3 ?OTTOX HOL- CLOSURE 3463,87 FEET AT S 66 1 8 E 3031,81 3047.09 3062,04 3076,59 3090.~9 3103.95 31t7,0U 3129.26 3141,10 3152,81 3164,64- 3164.88 2963.99 S 68 28 30 E 29'90.99 S 68 22 6 E 3017.99 S 68 15 46 E 3044.59 S 68 9 37 ~ 3070.32 6 68 3 30 ~ 3095,62 S 67 57 Z5 E 3120,35 S 67 51 46 ~ 3143.78 $ 67 45 !0 E 3166,92 S 67 40 14 =~ 34 16 E 2E 22 i 2~ 45 E 11 ~0 E ~91.32 $ 67 5 42 E J3i0.~9 S ~6 59 3U ~ 5329,05 5 66 53 45 E 3347,28 S 66 47 58 E 33~4,91~ $ b6 41 45 ,..~ 3382.44 S 66 35 13 ~ ~399,52 $ 66 k~ 46 ~: · ~ 34i5,63 S 66 22 14 ~ 3431,57 S 66 i5 gO E 3447.46 S 66 8 20 E 3463.55 S ~6 i 17 E 346D,57 S 66 1 5 t DOG LEG SE'V~.R l TY SLCT t Oi,~ DZG/190FT O i STANCE 0 .~00 296! 0· 0t9 298~' 0 · 0 i~ ~015 0.500 30~2.38 ~,.567 ;06U.30 0.091 3093.78 0.76~ 3118.67 0.890 3142.25 0,500 3165.54 1.028 '31o~.37 0.0i3 5210.33 i,GOo ~23i,45 0.216 3251,69 0,D42 3271.43 O,OU2 D~90,69 0.307 D309.~7 0.572 3325.62 0.385 3~4r ':'4 0.027 5~6~ '0.SOO ~382.2~ i,0i9 3399,39 0,352 34i5.55 0.186 3431,53 0.~17 3447.45 0.251 3463,55 · o D~-:'PTHC~ COORDINATES ANT) CLOSU~' ~. ,., ,-,ES FOR ~I~/gi',l DEPTM$ 'TOTAL COORL~tNATE5 C L O S d R E D [STANCE ANGLE TOP A-8 SD TOP A-9 SD TOP A-10 S TOP A- TOP 8,-1 SD 'TOP ~B-2 SD TOP E:-3 SD TOP 3-4 SD TOP C-1 SD TOP C-2 SD TOP 5 E L ~.,,~ A TOp T y,.") ' ' r: '< T 0 F 8 - 8 C L TC? D ZO:'<,C TOP i'3'-I SD TOP 0-2. SD TOP '7)-"3 SO TOP -:D-4- SD TC',P L'-5 S:5 404.7 3669.1! 4.1.37 3718,03 4143 3747,35 4231 3819,18 4300 3875°52 4404 3960 4472 4015 °99 ~-:>95 4i16,5: 4787 4272 5 !25 45a6,61 5294 4689,52 5415 4796.02 8115 S968 8190.66 9~34 qS41. c','~ 958~ ~ r'~ 9 ~ 90 9809 9013,63 10168 9366,57 !0310 9506 ! :)~:~3 Z 9626,55 10502 9~75 288,29 S !~84o76 E i~14,45 S 78 14 22 E 304.90 S 1415,26 E !447.73 S 7'7 50 31 E 314,79 S 1433, I E i~67,70 S 77 36 55 339,00 S 1478.3'1 E t516,74 358.01 S t5i3,36 E 1555.13 S 76 41 25 E 38~,18 $ 1=65~. .82 E t612,98 S ~6 6 406.5~ S 1599,94 E 1650,~9 S 442,00 S i66!,26 E 1719,06 S 497,81 S i'/58,67 E 1827,77 S 74 11 42 593,9i $ i931,17 E 2020,43 S 72 54 18 3 zoo .5 E S 7Z E 667.45 S i~ 2059,04 E 2i6~,5Z 5 72 2 2Z E 1089,76 S.'~:~ 276C),74 E 2968,04 S 68 27 i212.55 S ~:~ 2942.28 E 3182,34 S 67 36 10 E 12q8.04 S 3052',i8 t 53i6.73 S 66 57 38 1304.56 a 5059,95:'~ 5326,44 S 66 54 1319 7° S ,l' ~3077.,':04,;:,~ ~ : A:'3348 ~7 S 1365.0u" S "' '~, .,i.25.¢6,,~,,," ~ .... .,3410,47 S 66 ~4 19 E 1383,02 S ~! ~.z,~7 E 13':~F~.VZ S 3155,59 E 3452,61 S .66 6 4 E 3573.11 3851,38 3723.t8 3'779.52 3864°46 3919.99 4020.55 ~t76.3i 4450,61 4593,52 4700.0Z 72V0.41 8094,66 8745,90 ~79b.90 9410°42 9530°55 9599.46 Dii?T!4 AND . , OT'"":~mr:.,, DATA FO.'-! EVLFiY i00 FiFT CF SUB SEA DEPTH [.i AS ,r~ D "~ u ,p TH T kdE 'v'E P,T I CAL SUB MD-TVD DEPTH SEA DIFFERENCF VEHT i CAL C 0'"' I' c.- -< R~.CT I ON TOTAL COORDINATES 196 296 596 696 796 997 119° 140a 1598 1725 i o o. 'l I~3 w ,0 _ . , 23O3 253~ 2651 3~ '~7 5~ 27 3477 3595 ~7~q i 96 · 1 C) O · 0 296. 200. 0 396, 300. 0 496. 400 · 0 596. 500. O 696. 600. 0 796. 700. 0 896,, 800. ! 996 · 900 · l ,,96- 1 ~JO0, 2 1196. t100, 1296, 1200. 5 1396, !300, 8 1496. 1400. 12 1596- 15nm ..~ ~ I t 696. 1600, 29 ~ 96. 1-1 O0 · !896, 1~00. 57 ],996. !9tO0. 74 20 g G · 20 n '~ 9 _ ~'~ ~i96. 2100. ].d-I 2,196 , 2200, 123 ~9~ ~ 39 ..,, 4~OO, _ 2495, 2GO0. 155 2595. 2500. 172 2696, 2600, 19i 2796. 2700. 21! 2~96. E 800, 231 2g96. 2900 24° ~.~.~ 6 , 30~0. 254 3196. SECO, 281 ~q6. 3~06. 299 33~6. 3300. 3q96~ 340'0. 339 3595.' ~5~' 0 0 0 0 0 0 0 1 1 1 L..I. ~;., ~"',¢~,~ 6.,:..'/ fx 17' 17 17 2~ ~5 17 21 0.00 C.Ou 0.00 0.00 d.O0 0.8'7 2°95 5.B2 9.52 i15.35 15.54 25.59 30,5! 32.06 33,94 3o. I ,-',. 42 · 34 a4,4.4 52,22 59.39 66.86 72,71 75.16 61,29 89.i5 i09,97 i2i,62 147.50 174.39' 201.55 23!,32 2,53 · 70 0,00 0.00 0.00' 0.00 0o00 3.23 10.64 20,21 50.79 41.67 55.62 74.70 98.36 127.12 164,01 £08.~ 260.83 315.96 440.24 ~iOO.06 558,15 616,©2 674,38 735.t? 798.59 864.37 93!,45 991,53 1045.99 1100,63 1157.05 1215.70 1276,94 1339,17 W w F_ E E E E ~T E E '" q.' LD "' ..... .. T R U V'"'R T I CAL OEP c: U [~4 5 E A ,"..: D- T V D D I F F i::' 'o. [:'i !"'.! ,., .... iV:'."', L':L F't:.'- T 0~: SUix:, SLA VL:: F4 T [ CAL C 051 ?, ii: C T [ t.:: l' (':, T A L. C C) 0 R D i :',i ,-i T rE S 42O3 z.,. 325 a570 ,:+693 a815 ~ 94. 0 5953 fi' ! 8 a 53 32 5526 5 v 42 ....., :.:;95?' 5 .'" 57 6161 5265 · ':54. '7 '4 557S {:5d2 C, 7~7 '? 1:3 ..,') 7515 762.3:, 77 '~ c' 75:3? 3595, 3~ ,'96. 3896. 3996 · 4096. 4i96. 4296, 4396, 4~-96. .. ,., k.., o .'s696. 4796. ~996. 5'096 · 5306. 5496. 5796, 56~6, 599~ ~.J · G196, 62e~. 5396. 65~6 · .5796, 6896, 6996, 7096, o,)0 · 3700. 3800,,, 40 ''~ ~'' 4100. 4200, 4300. 44.00, 4.5 O0. 4600 · 4700, 5O0O, 9 i ('~ 0 · 52OO. ~~300 · 5700, 590f 5100 · . 6500. 6600, 6700 , , , ~ 6800, 6990. 7000 · 5384 407 429 452 ~ 74 497 52O 54,4 567 606 619 630 639 0~,¢. 65 ? 665 609 674 7 C :3 713 717 7~2 727 732 7~7 23 22 23 22 23 23 24 21 i> !I 9 T (. 4 4- 4 4 4 ..,, 297.43 331.18 365.03 399.59 434.74 470,30 500.29 541.73 575.'76 6()9.95 6 4:1), 2 d 69i, ~4 714.11 734. i6 76'7.99 ~;, 2 <}: · 55 54.3,61 65~,27 073.30 >,89.i5 ...4.9~ . 92'.2. ~ 1 9~5 · 67 950,62 969.47 981,09 997,36 ~Ui3,59 1029.82 1401.52 1463,97 1526,0i 1587.6{: 1648,75 1'/10,59 17'73,'$4 18257,19 19()0,44 '!959,82 ,:.~i2,~7 2059 · 0 ':; 2100. i0 2i37,20 2~70,74 2200 · 59 tZk7 · 16 2252.~3 2276,68 2~1,81 2327,32 2352,72 2403 · 60 2429 · 60 2455,29 2480,66 ?~05.99 2531 · 59 2557.~5 2584.83 2612,35 2639 · 54 2666,37 2692 · 99 .) T R U E ,,., E A S U R E t) 'v' E 2 T ~ C A L ,,,.,: P T ;--~ [.':,' E P T H DATA SEA · , FO'":., EV'ZRY ~',' {)- T V O DI FFEREt,~CE ir';?' F L. LT OF' GU!:! SLA VE?.T I CAL COq ,'7 E C T I ON TOT A L DE.P]' COORDINATES 7937 7!e6, 710.0o 74! U042 7296. 7200. 746 814§ 7396, 7300. 750 8250 7496. 7400° 83=/'~,-- 75°6,, 7500. 758.. ,c. 45 S 7696~ 7o00. 856! 7796. 7700. 765 8665 7896, 7800. 769 ~76~: 7006. 7c00. 772 887i ~096. 8090. 775 ~973 81c' " ~G,' olu'O~ 777 ':, 780 9976 c296. ~200~ . 9!79 8396, 8300. 753 9281 8496. 8400, 785 93~3 8596, 850(3, 78 953v ~796. 8700. 79! 96f3'g 8896. 8800. 793 . 97c~1 8996. 8900, 795 o 39 ~ c. C, o. 6, o. 0 0" ~,,.~ · 797 · :,~' ~ ? 5 9196 · 9 ! 00 · T 9 .:, 2"~ 0 · 0 !¢? -~ 9396. 9 Z, O0. 802 3'~97 9496. 9400. 803 Oat" l -;, 5c5. ° 5r"~ co- e 1062,55 b 10'78.57 4 1094.40 6 t110.12 4 1125.72 4 1141.03 .3 1156.14 4 i170,84. 3 1185.00 3 1199. la 2 1213.30 ( ~ 1240 · 52 ~ 2 1253,45 · ... 1266152 ":;:':; 2 - 2 i330.3! I 1556.1~ 2 I~66.77 i i3g1,67 2 159~.69 2718,76 2743.61 2767,84 2791.82 2815,59 2838,6a 2861.0t 2882.59 2903,71 2923,76 2943.32 2962,08 2980.04 2997,15 3013.59 302'9.50 3045,13 3060,42 3075.29 3089.40 3103,22 3!16,60 3129,00 3i4!,03 3152,97_ E g E E E E E -. IO00 .2000 · 50r)~ G ~.q cC, 0 7 r~ v 00 ~-~000 9000 VALUn'c FOc' T'qUE V FF ;" T i, C A 3 c., P '1" H ~., 2 790 3630 &444 5'541 7255 82.21 98U1 SEA 902, 18aO. Z 59 a.. 552.4. 5245, 6204. 7159, 6i25, ~105. FEET T 0 T A L C 0 0 F;; D I N A T E S 9,40 $ 31,05 4!.15 S ?,43.16 275,26 55 1360,67 558,8i S 1868,20 774.96 S 2238,62 920.96 S 2481,73 1072,20 S 2733,~5 ].216,94 S 2948,32 13~+4. Oz. S 3103.95 400 80O 1200 1600 VERTICAL SECTION UNION OIL COMPANY OF CALIFORNIA. SCALE I" = i000' K.D.U. _5 TANGENTIAL AVERAGE ANGLE GYROSCOPIC SURVEY . 2400 $200 ALL DEPTHS SHOWN ARE TVD ,, $600 4000 4400 4800 5200 56OO 6000 6800 7200 7600 8000 8400 9200 9600 VD= 9695' TMD= 10.502' HORIZONTAL VIEW UNION OIL COMPANY OF CALIFORNIA SCALE I" = I000' K.D.U. 5 TANGENTIAL AVERAGE ANGLE GYROSCOPIC SURVEY .. _ . . . . . . ' 7 ..... TVD=9695' ..... TMD= i0~50~' .. ... ..... · : . C©;~PLET ]©N R.£POR T UNION O[~ COf~PANY OF CALIFORNIA GYR. OSCOP i C RADIUS OF CURVATURE HETHOD OF CO~4PUTATION ~ ~4 ~'~ COrqPUTED FOR oDC ~tY F,H~,LI~DSEY AND ASSOCIATES OCT, 5, t978 KENAt D.c~.P U~IT 5 KB ELEV 96 FT, JO~'~]~ I"~O, GY.~q B 072-1i-50 RECORD OF SURVEY ALL. CALCULATIONS PERF'""P~ED,,~,,.,, BY I 8 ~l ELECTRONIC' COMPUTER CONFIDE ITIAL TRUE ~,!EAS, DRIFT VERTICAL, DEPTH ANGLE DEPTH D ~, SU~?, DR I FT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DI STANCE ANGLE D N $ DOG LEG SEVERITY SECTI< DEG/10OFT DiST 0 0 0 0';00 100 0 0 I00,00 200 0 0 200,00 ~00 0 0 300.00 ~00 0 0 400.00 500 0 0 500,00 600 0 O 600.00 700 A ~ 699,91 800 5 0 799.60 900 6 30 899.10 1000 6 15 998.~8 -96 · O0 $7~ · 8 DE 4,00 574,85E 104,00 $74,85E 20~,00 574,85E 304,00 $74.85E ~0~.00 S7~.85E 50~,00 $74,8~E 60~,91 S7~,85E 703,60 57~,78E 80~,10 572,72E 902,48 S70,65E 1100 7 0 1097,81 I001,81 588.60E 1200 10 0 1196,70 1100,70 570,57E 1300 13 O 1294.68 1198,68 568,6BE 1~00 lA O 1391,92 1295,92 587,03E 1500 17 30 1488.15 1392.15 586.77E 1600 22 0 1582,24 1486.24 587.35E 1700 25 0 1673.9~ 1577.94 S87.00E 1800 28 0 1763.47 1667,~2 S87e55E 1900 B1 0 1850,45 1754.45 S88.00[ 2000 31 O 1936,16 1840,16 588,65E 2100 31 30 2021.65 1925.65 S87-60E 2200 31 15 2107.03 2011.03 S38,38E 2300 33 30 2192.~6 2096.86 586.60E 2400 30 0 2279.24 2183.24 $84.00E 0,00 O*i~O o'!i o O, O. O, 5,92 9,40 13,~2 18.58 25.52 30,42 31,89 33,62 35.59 37,71 39,62 41,13 44,65 51.0~ 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 20.51 E 31,05 E 41,86 E 55.72 E 74,40 E 97,12 E 124,22 E 157.96 E 197e78 E 242,34 E 291,54 E 343.03 E 39~.87 E 446.91 E 49~.17 E 548,37 E 0,00 S 0 0 0 w 0.00 S 0 0 0 w 0,00 -$ 0 O 0 w 0.00 S 0 0 0 W O.O0 $ 0 0 0 W 0.00 $ 0 0 0 W 0,00 $ 0 0 0 W 3.48 S 7~ 90 59 E 11.33 S 7~ 28 ~6 E 2A-35 $ 73 5~ 9 ~ 32*44 S 73 8 38 E ~3,96 $ 72 1~ 1~ E 58,73 5 71 33 29 E 78.66 S 71 3 ~3 E 101,78 S 72 36 A5 E 128,25 S 75 35 5~ E 161.50 S 77 58 53 E 200.96 S 79 ~7 52 E 2~5.26 S ~l 9 ~5 E ~9~.~2 S ~2 15 35 E 345.48 S 83 9 44 E 397,19 S ~3 4~ ~4 E 449.13 5 84 17 37 E 500.37 5 ~4 37 17 ~ 550e74 S 84 41 0 & 0,000 0.000 0,000 0.000 0,000 0,000 4.000 1.000 1,500 0,251 0.751 3.00I 3,002 1.~70 3.500 ~.501 3-001 3.002 3.002 0,335 0,576 0,326 0-~79 0.820 0.00 0,00 0,00 0,00 O. O0 ii.21 21.15 52'19 lOl.lO 126,46 A95.17 330.i3 378,19 426,48 W74,23 JNION OIL~CO KDU 5 GYROSCOPIC SURVEY jOB GYF~,& 072-11-50 4, RECORD OF' SURVEY ALL CALCULATIONS PERFOR~IED BY I ~ M ELE]CTRONiC CO~4PUTER TRUE qEA$. DRIFT VERTICAL DEDTH ANGLE DEPTH SUB DRIFT SEA DiREC DEG, 2600 30 0 2A52.01 2356.01 $83.00E 2700 31 S0 253?,95 2441.95 $82,72E 2800 32 15 2622:,87 2526,87 2900 3B 0 2707,09 2611.09 3100 35 0 2872-~9 2776.89 $87.22E 32'00 30 0 2957,20 2861,20 $77,37E 330.0 30 0 3D~3.80 29~7,80 3400 31 0 3129,97 3033.97 3500 32 0 3215,23 31~9~23 3600 32 15 ~299,92 ~20~.92 56~,97E 3700 33 15 3384,02 32~a~02 565,57£ 3800 3~ ~5 3466,92 3370.92 $63.50E ~OOO 35 30 3630,63 3534.63 4100 35 15 3712-16 3616,16 $61-~4E 4200 35 90 B79~,70 3697,70 4900 35 0 ~875,37 B779,37 S61,OOE ~400 35 90 3957.03 3861,C3 S60.87E 4500 35 0 4038.69 3942.69 4600 35 15 4120.48 4024.48 S59.77E 4700 36 0 42(31.77 4105.77 S60.59E 4800 360 4282.67 4186.67 $59.85E 4900 36 O 4363.57 4267.57 S61.55E 5100 35 0 4525,63 4429,63 S61,00[ 5300 ~© 0 4694,~9 4.598.49 $59,87[ TOTAL COORDINATES C L O $ U R E $ DISTANCE ANGLE 69,95 S 699,07 E 73,96 S 751.70 E 75,3a $ 805,60 'E 80,85 $ 860.~6 E 87 5 S 916,71 E 109 )8 $ 1017,60 E 129 702,56 S 84 17 8 [ 755.33 5 8~ 22 ~8 E 809,11 $ 84 ~9 25 E 864.25 $ ~ 37 55 E 920.85 $ 84 ~ 9 E 1023,~3 S 8~ ~2 52 E t071.83 $ 8~ 2 ~2 [ 152. 175, 198. 2 222.09 2 248.06 S 1309.51 275.18 S 1360.46 302.90 $ 1411.28 330,38 S 1462,24 357,93 S 1512.95 385.97 $ 1563.40 414,48 S 1613.5~ 443,37 S 1663.33 ~72.3~ S 1713.87 ~01.53 S ~76~.88 530.30 S 1816,t~ 558,73 $ 1867,78 587.07 S 1918.67 614,1~ 5 1966,98 639,84 $ 2011.~2 1121.3~ S 82 10.34 1224.22 S 80 41 23 1278,02 $ 79 59 32 1332,80 $ 79 i~ 24 1388.01 $ 78 33 52 1499.10 $ 77 16 1554.71 $ 76 ~1 ~2 1610,~ S 76 7 55 1665,96 $ 75 35 38 1721.41 $ 75 4 27 1777.76 S 7~ 35 30 18~.76 S 74 8 10 1891.98 S 73 43 21 1949.56 $ 73 20 ~5 2006.48 $ 72 59 IB 2060.62 S 72 ~9 37 2111.12 $ 72 21 26 DOG LEG £EVERI'TY DEG/iOOFT 0,687 0,5~i 1,502 1,822 0,750 2.84.9 2,577 4,531 1.582 1-01~ 0,609 0.502 0.256 0,802 0,435 0,999 1.252 2.754 2.255 SECTION DISTANCE 667,1~~ 716,87 766,67 ~19,04 ~7~,00 97~,09 I024.8~ 1077,C5 1130,21 12~0,19 1297,29 1~54,86 1412.57 16~2.75 1699,95 1757.90 1874.90 1933, b~ l i ' oiL:co KDu 5 r GYROSCOPIC SURVEY JOB GYMi3 072-1i-5G RfCOt: ~.) OF SURVEY ALL CALCULATIONS PERf. ORF, ED BY I B P~! ELECTRO~'¢IC COMPUTER TRUE 4EA$. DRIFT VERTICAL )EPTH ANGLE DEPTH D H SUB DRIFT SEA DiRE:C DEG. TOTAL COORDINATES C L 0 5 U R E $ D ! STANCE ANGLE 5400 27 0 4782,B6 4686,B6 559.25E 5500 25 0 4872,23 4776,23 559.4~E 5700 21 15 5056,21 4960,21 $59,28[ 5800 I9 O 5150,i0 5054~10 $59.455 5900 17 0 52~5,20 51~9,20 $5~,6~E 6000 16 0 5341,08 5245,08 558,73E 6100 1~ 0 5437.~t 5~41,21 $58,80£ 6200 16 15 5533,28 5437,28 SSB,~SE 6300 i6 45 5629,i6 55~3,16 $58.'9D£ 6400 16 30 5724.98 5628,98 $59,00E 6500 16 15 5820.92 5724.92 560.005 6600 16 15 5916,93 5820~93 560,00E 6700 17 0 6012.75 5916.75 $58,gTE 6800 17 0 6108.38 6012,B8 $57,95[ 6900 16 30 6204,13 6108.13 558.87E 7000 16 30 6300,01 6204,01 558-805 7100 16 30 6395,90 6299,90 $58e75E 7200 16 30 6491,78 6~95e78 $60e60E 7300 17 0 6587e5~ 6491.54 S60,52E 7400 17 30 6683,04 5587.04 $59.48E 7509 18 0 6778.28 6652,28 $59,43E 664,01 5 2052.95 686,36 $ 2090.66 707,27 $ 2125.54 726,68 $ 2157,82 744.21 $ 2187.42 760.ti 5 2213,92 774 ~7 $ 2238,1~ 789 .7 S 22~1,75 ~03 .~ $ 2285.51 2157.67 5 72 b ~5 E 2200,~ 5 71 49 29 E 2240,13 5 71 ~5 42 E 2276,89 $ 71 2~ t7 E 2310,56 $ 7t t2 )7 ~ 2368,52 S 70 54 13 { g~g~e47 $ 70 ~ 54 ~ 2~22,65 $ 70 37 4~ E 2450e47 $ 70 29 ~9 ~ 832. 8,47, 861, 875,78 89i,08 $ 2432.~4 906,17 S 2456.99 920,87 $ 2481,29 9B5,60 $ 2505,5~ 949.93 $ 2530.09 964.10 $ 2555e19 978.93 $ 2580.87 994.42 S 2607.13 2506.20 $ 70 14 26 E 2533,74 S 70 7 41E 561.87 $ 70 0 36 E 2590.~2 $ 69 52 ~0 [ 2618,77 S 69 45 18 E 2646.66 $ 69 3~ 19 E 2674.56 $ 69 31 26 ~ 270Ze55 S 69 25 15 [ 2731.0~ S $9 19 40 h 2760.29 S 69 13 41 5 2790.34 S 69 7 A8 ~ 7600 17 15 6873.58 6777.58 S59.00E 1009.92 S 2633.14 7700 17 3C 6969.02 6873.02 $58.95E 1(325,31 S 2658.73 7800 17 30 706~,39 6968,39 $57.93[ 1041.05 S 2684e35 7900 16 45 7159,96 7063.96 $57,90[ 1056,69 S 2709,30 BOGO 16 30 7255.78 7159.78 556.885 1072.11S 2733e40 8100 16 0 7351,7~ 7255.78 $56.8~5 1087.40 5 2756,83 8200 16 0 7447,91 7351,91 S56.77E 1102.49 $ 2779.90 2820.17 $ 69 0 57 2849.58 S 68 54 40 E 2879.16 S 68 48 9 2908,08 S 68 41 34 293~e14 $ 68 ~5 i E 2963,54 S 68 28 25 2990e54 S 6~ 22 O E DOG L[G SEVER ! TY 5fCT ION DEG/tOOFT DISTANCE ~.000 2,00~ 2229,5~'~ 1,752 2266,90 2.250 2~0~.07 2.00I ~,000 2~59.9~ 0,0t9 2~87.26 0.2~0 2~14,~t 0.500 0,250 2~7t,~9 0,262 2499,40 O,OOO 2527,23 0,755 2555.85 0.298 2~84e63 0.505 2613.20 OeOl~ 2669.5 0.525 2697',', 0.500 0,509 2755-9~ 0,500 2786.25 0-751 0,250 0~307 2875,76 0e750 2904e9i 0-26~ 29~3,19 0.900 2960.82 0,019 2988.03 GYROSCOPIC SURVEY JOB GYN3 0'/2-11-5,0 OCT. 5, 1'978 RECORD OF SURVEY ALL CALCULAT! ~' ~ u~$ PERFORMED DY I ~ ~,~ ELE~CTRONIC COMPUTER TRUE q~ASe DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES DEPTH ANGLE DEPTH SEA DiREC D ~ DEG. 8300 16 0 7544.03 7~8.03 556.72E 1117.~1 5 2802.95 8~0,0 15 30 7640.28 75~.28 556.67E 1132.51 5 2825.63 8500 15 0 7736.76 76a0.76 $55.65E 1147.16 $ 28~7.4a 8600 15 0 73~.35 7737,35 556.005 1161.70 S 8700 14 15 7930.11 7834.11 556.525 11'75.72 S 2889o~9 8800 13 BO 8027~19 7931.19 $54.52E 1189.B0 8900 lq 0 8124.32 8028.32 554.~5E 1203~1 ~ $ 2929-00 9000 13 0 8221.56 8125.56 $53.4~E 1216t 5 ~, $ 2947,87 9200 12 0 8416.62 a320,62 553.32E 1243~!~q 9400 11 30 8612.3~ 8516.34 .551.255 1268'~ 9500 11 30 8710.3~ 861~.3~ $50.845 1280.~ 9~00 11 30 8808.33 8712.33 $49.30E 1293.68' 9700 11 0 8906.4i 8810.41 $50.725 1306.22 S 3061.59 9500 Il 0 9004.57 8908.57 $45.70E 1318.56 $ 3076.14 9900 10 30 9102.81 9006.81 $46.67E 1331.12 $ 3089.94 10000 11 0 9201.06 9105e06 $~6.62E 13~3.92 $ 3103.50 10100 10 0 9299.38 9203.38 $45.55E 1356.56 S 10200 lO 0 9397.86 9301e86 S43e52E 1368.94 S ~128.80 10300 i0 9 9~96.3~ 940.0.3~ $~2e45£ 1381e64 10409 10 O 9594.83 9~g~e83 ,42.3SE 1394.45 10500 lO 15 9693.27 9597.27 542.255 1407.47 $ 10502 lQ 15 9695.24 9599.2~ $42.25E 1407.73 S 3164.&2 BOTTOM HOLE CLOSURE 3463,42 FEET AT S 66 i 3 E C L. O .5 U R ~ $ DISTANCE ANGLf~ D ~ $ }069.$8 5 68 3 25 3095.17 3119.90 314~.33 $ 67 46 4 3189,15 5 67 3210.~7 32'31.96 $ 67 22 40 3252.09 5 67 17 8 E ~271.71 3290.87 5 67 5 37 E 3309,93 S 66 33.28,60 S 66 53 40 33~6,83 $ 66 47 336~,46 33Sl,99 3415.17 5 b6 22 9 E 3431,1~ $ 66 15 14 3~47.01 $ 66 8 14 3463,10 $ 66 1 11 3463.~2 $ 56 i 3 DOG LEG SEVERITY D[G/1.0OFT O-Ol~ 0.500 0.505 0,091 0,751 0.758 0,500 1.001 0,013 1.~00 0.216 0-502 0,082 0.307 0,503 0,385 0.505 0.500 1,001 0.352 0,I86 0,017 0.250 0,000 SECTION DISTANCE 3067,9.~ 3093.40 3165,15 3187,9~ 3209o93 3231.05 3251,29 327~.03 3290.29 3~6.52 3364,22 3381,8- 3431,09 3447.Q0 346~,10 3463-~2 JNION' OIL CO ~OG 5 GYROSCOPIC SURVEY JOD~ ~ ~'~ uY ~.~.~ 072-11-50 OCT,, I NT ER POL ATE ~* ~,~ TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE :ODE MEASURED VERTICAL TOTAL COORDINATES C L 0 $ U R ~A~E DEPTH DEPTH DISTANCE ANGLE SUB SEA FOP A-.8 SD ~0~? 3668,92 288,40 S 1384,29 FOP A-10 $ ~143 37~7,26 31~,95 $ 1~3~,02 FoP A'll $ 42~1 3818,96 339,09 $ 1477,95 lOP B-I SD 4300 3875,~7 357,93 $ 1512,95 FOP ~-2 SD ~0~ 3960.29 387.13 S 1565.~1 tOP B'3 SD ~72 4015,78 407,0t $ 1599,3i tOP 8-4 SD 4595 4116.40 442,62 $ i660,42 TOP B-5 SD 4787 4272.15 498.24 $ 1757.96 TOP C-1 SD 5125 ~5~6,19 593.99 $ 1931,09 lOP C-2 SD 529a 4689.29 638~81 $ 2008.94 TOP ~J, ELUGA 5415 4795,7~+ 667..50 $ 2058.76 TOP TYONEK 8115 7366.20 1089.72 S .26 TOP 8--8 CL 8968 8190.40 1212.62 $ TOP D ZONE 9636 8~41.66 1298.08 S TOP D-1 SD 9686 8892,67 1304.63 S /OD D-2 SD 9809 9013.40 1319.71 $ TOP D-3 SD 10168 9366.35 1365,01 S 3124.88 TOP D-4 SD 10310 9506.19 1382.93 S 314.1.80 TOP D-5 SD 10432 9626.34 1398.61 5 3156.09 TD 10502 9695.24 1407.73 S 316~.42 t~Iz+,02 $ 78 I~ 53 :E 3572,92 t4.67.22 $ 77 36 1516.35 159~. 71 $ 76 161~.57 S 76 ~ ~2 E ~86~,29 t650,29 $ 75 4~ 18 E 39~9,78 1718.41 $ 75 ~ 24 E 4020.~0 1827.20 S 74 10 ~3 E 4176.15 2020,38 $ 72 5g 9 ~ 4~50,19 210~.06 $ 72 21 35 E ~593.29 2164e27 S 72 2967.~8 $ 68 27 2~ [ 7270~20 JNtON O!L'CO KDU 5 GYROSCOPIC 5URYEY .J©B GYN3 072-t1"50 aEASURED DEPTH ANQ OTHER DATA FOR EVERY EVEN 100 FEET OF' 5Uf~ $gA OEPTH, OCT, 5~ TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD IN, ATE& 196 t96. 100 0 296 296, 200 0 396 396, 300 0 · ~96 496, mOO 0 596 596, 500 0 696 696. 600 0 796 796. 700 0 897 896, 800 0 997 996, 900 1098 I096, XOO0 2 1199 1196, 1100 1301 1296, 1200 1~0~ 1396, 1300 8 1508 1496, I~00 12 i6t5 1596, 1500 18 172~ 1696, 1600 28 1837 1796, 1700 1953 1896, 1800 57 2070 1996, 1900 73 2187 2096, 2000 gl 230~ 2196, 2100 108 2~19 2296, 2200 123 2535 2396. 2300 139 2651 2~96, 2~00 15~ 2768 2596, 2500 172 2887 2696, 2600 190 3007 2796, 2700 210 312~ 2896, 2800 232 32~5 2996, 2900 3360 3096. 3000 26~ 3~77 3196. 3100 281 3595 3296. 3200 299 3714 3396. 3300 318 3835 3496. 3~00 339 3957 3596. 3500 361 0 0 0 0 0 0 0 0 16 16 18 17 15 16 15 18 18 20 22 17 15 17 18 19 21 0.00 0,00 0,00 0,00 0.00 0,86 3,04 5,93 9,~2 30,~8 2, o 6 3 ~ · 9 2 :.36.13 *0o57 42,61 4~,85 52,05 59,50 66.85 73.66 75,60 81.~8 88,35 i00.1~ 12t.1~ 147.69 ~7~.78 201.32 231,21 0,00 W 0,00 ~ 0,00 W 0,00 W 3,09 E 10,96 E 20, ~ E 30,70 E ~1,60 E 55,51 E 7~,61 E 98,09 E 126.6 5 E 163,57 E 208,05 g 260.01 E 318,82 E 379,20 E 4~0,1~ E 500,01 E 557.83 E 615,9~ E 673.93 E 736.5b E 79B.~0 E 86~,1~ E 9~2,43 E 991,50 E I156.~0 E 1215.06 ~ 1276,3~ ~ GYROSGOPIC SURVEY JOB GYM3 '072-11-50 ;}EPTH AND OTHER ~' · ,,ATA FOR EVERY EVEN 100 FEET OF SUE~ SEA DEPTH,, OCT, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH :SEA DIFFERENCE CORRECTION TOTAL 4080 3696, 3600 4203 3796. 3700 407 4325 3896, 380.0 429 ~ 3996. 3900 ~570 ~9~, ~000 ~7~ 6693 4196, ~100 ~96 ~816 42'96, ~200 520 ~40 ~396, ~300 5185 ~596. 450,0 589 5302 ~696, ~600 606 5415 4796, 4700 619 ~6 4896, ~800 630 5743 5096, 5000 6~7 58~ 5196. 5100 652 5953 5296, 5200 657 6057 5F96, 5300 661 6161 5496, 5~00 665 6~65 5596, 5500 669 6370 5696, 5600 674 6474 5796, 5700 678 6578 5896, 5800 66~2 5996, 5900 686 6787 6096, 6000 691 6891 6196, 6100 695 6996 6296. 6200 700 7100 6396, 6300 704 7204 6~96, 6400 70~ 7309 6596, 6500 712 7414 6696, 6600 717 7519 6796, 6700 723 7623 6896, 6800 727 7728 699~, 6900 732 7833 7096, 7000 737 23 23 22 22 24 13 297.65 399,90 506,35 54~'78 577,Zl 610.g4 6A0.~8 667.50 691,99 .12 ,20 78~.20 79B,12 813,27 828,70 843e61 858.18 889.~3 90~,20 920.59 935,60 950,50 981,0~ 997,37 1013.45 1~29,79 1046.41 1400,99 1587.~0 1709,89 ~77R,96 1836,b9 1959,76 2012,56 2058,76 2099.97 2137,06 2170.75 2200,~5 2226,~7 2251,50 g276,07 2301,09 2352.34 2377,54 2402.9~ 2428.99 2454.5~ 2480.07 2505.58 2531,08 2557,4~ 258~,38 2638.99 2665,~6 2692.62 ~NION oil '.co KOU 5 GYROSCOPIC SURVEY "~ 2- JO~ GY~] 07 1t-50 ,EASURED DEPTH AND OTHER DATA FuR EVERY VEN lO0 FEET OF SUB SEA D~.PTH, TRUE ~,~EASURED VERT I CAL SUB ND-TVD VERT I CAL DE 'TH DEPTH .SEA DIFFERE. NCE CORRECTION TOTAL COORD INATE~ 793~ 7196, 7100 742 80~2 7296, 7200 746 81~6 7B96, 7300 750 8250 7~96, 7~00 7~& 8~58 7696, 7600 762 8768 79-~'6, 7900 772 887t 8696, 8000 77~ 8976 8196, 8t00 778 9179 8396:, 8300 783 9383 8596, SSOO 787 9a85 8696, ~600 789 9587 8796, 8700 791 9689 8896, 8800 793 2 9791 8996, 8900 795 2 989~ 9096, 9000 797 2 9995 9196, 9100 798 10097 9296, 9200 80I 10198 9396~ 9300 802 lOBO0 9496, 9400 804 2 10401 9596, 9500 805 1062,61 $ 1078,72 $ 1094~, ,49 1110,20 t 125,87 115~,15 $ ltTO,gD 1185,07'5 !199,1~ 5 1227,14 · 62 $ 3,41 5 1305e00 1317,59 1330,~9 S 1~3,39 1356,27 1368,~0 S 1381,69 S 1~94.59 27t8,~5 2767,~4 2791,32 2682,~? 290~,39 2923~20 29~3-00 29&leSB 2979,~8 2996,&7E B013,15 3028,9~ 30~4,56 ~059,87 3074,71 3088,86 3102.65 311~,07 3128,~5 3140.~9 ~152.47 ialON Oi'L,CO K,DU 5 GYROSCOPIC SURVEY .JOB GY~B 072-1i'-'50 iTERPOLATED VALUES FOR EVEN 1000 FEET O:F MEASURED DEPTH, TRUE ~EASU:Rc:D VERTICAL DEPTH DEPTH SEA TOTAL COORD INATE5 1000 998, 902, 2000 1936. 1840. 3000 2790, 2694, ~.000 36 30., 353~- 6000 5B4t, 52~5. 7000 6~00, 6204, 8000 7255, 7159, 9000 8221, 81~5, 10000 9201, 9105, 81.I0 275.60 559,33 775 · 16 921,22 1072 ,/+8 1216,99 OCT, 5, 197~ .... HORiZOi,,TAL ViFW UN~ON O~L COMPANY OF GALIFORNiA .............. . ........... RADIUS OF CURVATURF- _GYROSCOPIC SURVFY ................ . i ..... .--i ........ i'-TF-_-: ~-L-~7'F_--C'7.~Ct" ?1; .... ~''-I-~7'I ..... .7:1 ......... T'-:i'il- . . - . ........... : ........................... F'! .......... ' ........ .2'~.:. _.-.:, .. ....... '- _ ._ . .. . __ . ._ . ........ ' _'- '.- ..... i: . ;~..'L.-.i.)_-i. ...... '..'-'..._-t-'. _.. '_'-.'_. .. _ . · ' ........ '. __L ....... ... ~._o- o~-~ .~ ' · - ......... ~'~ ~ ~ ~ ~ 0 ............. -' --' ]'~------}---} ................................................ ' .......................................... TMD= 10,502' ......... ...... · ............ . ..................... - ...... .................... ............ . , ..................................... ................. ~ ................. , ................................................................... .... ..... ~' ................ .................................... , .................... ' ........................... ALL ARE TvDDEPTHS SHOWN~ ..... _. ................. ........ , ....... . _ .......... ....... .. . .... - ....... ,. .............. , ............. ~ ........... ...... ............ : ....... _ .... ............................... ' ....... . ................................................................... · ............................. .............................. ........... .......... ................. . . ...................... ~ ................ '' - . .................... , ............................ · .......................... ...................................... : . ....... ............. _ . · ' ........; ...... VERTICAL SECTION ! -:'' "..-'-_i .... I '.'-'--i'-'7i i.i._~_]';_.-.-.":.-i ..... i'?i...'-':_ ]_._'~ .... 'i~-;'"..'__ UNION OiL. COh'iPANY OF CALIFORNIA ........................... .......................................... : ........................... . ........... ._; ........... ...................... K.D.U. 5 i .............. 800 -: ~ .~:_: . GYROSCOPIC SURVEY _.._.._-._:~.:_L-;.L_.:~.-_:~-.~.-'d'_.._'-:--:?L-~:~' 2:-_?_rE5 '< 2 .. - :. .L _. ._:_, -:.: ':. ...... ..... ','; ., .-.. ...... ...... i - , : . - ~ .................... ........ , ........ : ...... ~ ............. : .... 8400 ~ . .............. ~ .............. i .............. ' - . ~ ........ ' ..... ~ · ..................... : .... ' -- -' .................................... 8~OO ...... I , .......r ,' ~- ......................................... ' ............' ......................................................... 96 0 0 TVD; 9695' TMD: 10,50a' Union Oil and Ga~"'~ivison: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unl, n Robert T. Anderson District Land Manager ~nuary 19, 1979 Mr. Harry Kugler, Commissioner Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI UNIT State of Alaska Permit to Drill KDU #5 (31-6) Permit No. 78-55 Dear Mr. Kugler: Please be advised that the following information should be included under Item 14. Bonding Informati°n, on the subject drilling permit: Type - Statewide, Surety and No. - United Pacific Insurance Company B-55372, Amount - $100,000 Very truly yours, _ ~,, REV. 3-1-70 ~ "'~ "' :::5 I A I I:: L)I- ALA~SKA ~ ~ ',-,-.; :- ' OIL AND GAS CONSERVATION COMMITTEE s' ~PI' NUMERICAL CODE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. ?. IF INDIAN'ALOTTE£ OR TRIBE NAMI OIL E~ GAS ~ WELL WELL OTHER 2. NAME OF OPERATOR I 8. UNit FARM OR LEASE NAME UgION OIL CO. OF-CALIFOR~I~ KENAI DEEP UNIT 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247. A~CHORAGE. ALASKA 99502 Yd)U #5 4. LOC*TION Or WELL ' 10. fieLD,ND ~OOL, OU WILDCAT f .... ~'~ (; ...... ~----' ~AT CAR ~T~T.n ... 692~ ~ ~~'-'~q~L-~E. Corner o~ Sec. 36, TSR, ~, II. SEC. T.R.M.(BOTTOMHOLE J SEC j ~) ~,., ~' ~= ,~ ~Y ?, ~ OBJECTIVE) CONFER: '' Sec. 6 TSN, RllW,. 78-~5 13. REPO~[O,~6~!~rFH.,;~T (!~,.DSOI~,,N~H~,:_CJ~ANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET KNt~LIg~IEg: USED, P~JRATIOIqS,"Ti~¥S AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIC~',~eHANGES IN HOLE CONDITIONS. 94 95 96 12/1/78 12/2/78 12/3/78 10,502' TD 10,329''ETD 13 3/8" @10,417' 9 5/8" @2521' 10,502' TD 10,329' ETD 13 3/8" @10,417' 9 5/8" @2521' 10,502' TD 10,329' ETD 13 3/8" @10,417' 9 5/8"@2521' Reran 3 1/2" Dual completion assembly. Hydro-Test dropped sinker bars in tubing while changing out test cups. Unable to retrieve tools w/W.L, fishing tools. Lost Myers wireline-fishing tools & 120' of wire in in hole while fishing for Hydro Test Tools. Re-pulled 3 1/2" Dual Completion string to retrieve wireline & tools lost in tubing. Retrieved W.L. & Tools- Re-ran 3 1/2" Dual Completion. Completed running 3 1/2" 9.2# N-80 Butt Dual Completion Strings.' Located on W.L. Packer @8067' DIL & tbg. meas. (above Tyonek Prod. Int.)- Tested W.L. Packer to 500 psi- Held OK. Spaced out & set Baker 3 1/2" X 9 5/8" sgl. Hydraulic Pakcer @5945' (Above Middle Beluga Test Interval) & tested to 500 psi- OK. Set Baker Dual 3 1/2" X 3 1/2" X 9 5/8" Hydraulic Packer @5381' (Above Upper Beluga Prod. Interval) and tested to 500 psi- OK. Removed BOPE & installed & tested OTC 3 1/2" X 3 1/2" Dual x-mas Tree. Opened sleeve in L.S. above Dual Prod. Packer & Disp. L.S. tbg. w/1450 psi- Field Gas Press. ,4. I hereby ce~hat the foreggi~is ta~an,~eFect DIST. DRILLING SUPT. DAT£ 1 / 17 / 7 9 S IGNED~,.,._~ '~.~_ .~ .~_/~/~r_~_Z~_~gT~' NOT/./J~ort on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the '"' oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 97 98 12/4/79 12/5/79 10,502' TD Brought L.S. on w/slow steady increase in 10,329' ETD flare & no fluid to surface. Shut in L.S. (junk) @07:00 Hrs. w/210 psi tbg. press in 55 min. 9 5/8"@10417' Put L.S. back on flare w/slow steady increase 13 3/8"@2521' Started to unload fluid @11:55 Hrs. Installed BPV in L.S. @12:00 Hrs. Released rig to move rate @12:00 Hrs. 12/4/78. 10,502' TD 10,329' ETD 9 5/8"@10417' 13 3/8" @2521' Moving rig f/KDU #5 to KDU #6. Released rig to KDU #6 @24:00 Hrs. 12/5/78. Form No. 10-404 REV. 3,~--? SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL WELL 5. AP! NUMERICAL CODE A-028142 6. LEASE DESIGNATION AND SERIAL NO. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OAS ~ WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME UNION OIL CO. OF CALIFORNIA KENAI DEEP UNIT 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. BOX 6247, ANCHORAGE~ ALASKA 99502 KDU #5 10. FIELD AND POOL, OR WILDCAT KENAI GAS FIELD 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T5N, RllW, S.M. 12. PERMIT NO. 78-55 4. LOCATION OF WELL 692' N & 1720' W of S.E. corner of Sec. 36, T5N, RllW, S.M. 65 66 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 11/1/78 10,502' TD 8035' ETD (BP) 13 3/8"@2521' 9 5/8"@10,417' RECEIVED Continued DST #2 on Lower Beluga Zone perfs. Bleed well down in 40 min. Shut in 1 hour w/no noticable gain in surface pressure. R.U. lubricator & test to 3200 psi. Ran Hewlett Packard recorder to 7850' (F.L. @7700' BHP = 144.7 psi w/well open to atmosphere, increased to 153.8 psi in 1 hr. Shut in. POOH w/ recorder. Close APR. Released RTTS & reset @7352'. Press up on annulus & open APR. R.U. lubricator & test. Press up tbg. w/field gas to +950 psi. Perf'd 4 1/2" HPF w/ 2 1/8" guns f/7412' to 7422'. Bleed well down in 1 hr. Let set 2 hrs. well dead. R.U. & tested lubricator. Press up tb. w/field gas to +950 psi. Reperf'd Upper Beluga 4 1/2" HPF w/ 2 1/8" guns f/7412' to 7422'. Bleed well down in 20 min. - No entry. Unable to close APR valve. ll/2/78 10,502' TD 7215' ETD 13 3/8"@2521' 9 5/8"@10,417' Redressed Howco APR valve. RIH w/test tool checking all joints. Set Howco RTTS Tools @6441'. Perf'd 4 1/2" HPF f/6561' to 6571' DIL. w/+950 psi field gas on tbg. Bleed we down in 35 min. RIH w/Hewlett Packard pressure recorder. Encountered F.L. @950' and rising. POOH w/recorder. Rev. out fluid samples lst-7700 PPM 2nd 8700 PPM Cl. Released RTTS & moved to 6626' & rev. out POOH. RIH w/OEDP to 7304'. Equalized 60 sxs "G" w/2% CACL2 out D.P. @7304'. Pull up to 7210' &.rev. clean. 14. I hereby c~t~ that the fotqgoing~ trl~e~and correct SIGNED W~'/~,-~i~Z~~~~/T,TLE Dist. Drilling Supt. DATE 12/15/78 NOTE~/eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 67 1173/78 11,503' TD 6587' ETD (retainer) 13 3/8"@2521' 9 5/8"@10,417' Perf'd 4 1/2" HPF f/6602' to 6604' DIL w/4" O.D. csg. guns. RIH w/8 1/2" bit to 7500' didn't tag cmt. plug. Circ. clean. POOH. RIH w/B.P, retreiving tool & circ. out sand on top of retr. B.P. @8035' to 8050'. Engauge retr. B.P. @8050' & pull up to 7353' & reset retr. B.P. @7353'. Couldn't lay sand on top of B.P. in three attempts. (B.P. possibly failed) Engauged retr. B.P. & POOH. 68 11/4/78 11,503' TD 6587 ' ETD (retainer) 13 3/8"@2521' 9 5/8"@10,417 RIH w/ 8 1/2" bit & 9 5/8" csg. scraper & tag perm pkr. @8069' DPM. Circ. clean. POOH. RIH w/ Howco retr. B.P. & set @7353'. Dumped 15 sxs sand on top B.P. & tag @7319'. Pulled up to 7308' & equalized 60 sxs of CL. "G" w/2% CACL2. Pulled up to 7152' & rev. clean. POOH. RIH w/ 8 1/2" bit & 9 5/8" csg. scraper & tag cmt. @7162'. Polish off firm cmt. to 7165'. POOH. RIH & set 9 5/8" Howco EZ Drill @6587'. 69 11/5/78 11,502' TD 6587 ' ETD (retainer) 13 3/8"@2521' 9 5/8"@10,417' Sqz'd perfs f/6602' to 6604' w/250 sxs Cl. "G" w/.3% Halad 22A & 5% KCL. Broke down w/1650 psi. Initial press 1500 psi final press 2350 psi. Pull out ret. & rev. clean. POOH. RIH & set Howco EZ drill @6505'. Sqz'd perf's f/6561' to 6571' w/500 sxs Cl. "G" w/.3% Halad 22A & 5% KCL. Broke down w/1700 psi, Initial press 1500 psi final press 2100 psi. Pulled out of ret. & rev. clean. POOH. RIH w/8 1/2" bit & tag cmt. @6503'. C.O. cmt. to EZ drill to 6505'. D.O. EZ Drill @6505' & C.O. cmt. to 6587'. Tested sqz. perfs & csg. to 1650 psi - OK. Circ. clean. POOH. 7O 71 1116178 11/7/78 10,502' TD 6587' ETD (retainer) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 7285' ETD (cmt. plug) 13 3/8"@2521' 9 5/8"@10,417' RIH & set RTTS test pkr. @6442' DIL. Opened APR valve Installed & tested lubricator to 3500 psi. Press up w/field gas to 1275 psi. Perf'd 4 1/2" HPF f/6561' to 6571' DIL w/ 2 1/8" guns. Bleed well down to atmosphere thru 1/2" choke in 30 min. @03:15 hrs. Put thru seperator - rate increased f/16 to 80 MCF. S.I. @10:15 Hrs. SIP built to 325 psi @12:30 Hrs. Opened to seperator @12:30 hrs. 0- rate. Installed & test lubricator @3000 psi. RIH w/Hewlett Packard pressure recorder. Fluid level @+3100'. At 6000' = 1093 psi. POOH w/press, recorder. Released RTTS. POOH w/ test tools RIH w/RTTS. Sqz/ tool for Sqz. #17 of Middle Beluga perfs f/6561' to 6571'. Set RTTS @6480'. Sqz'd Middle Beluga perfs f/6561' to 6571' w/250 sxs CL. "G" w/ .3% Halad 22A & 3% KCL. Perfs broke down w/1950 psi, Initial press 1500 psi, final press 2000 psi. Bleed to 1500 psi in 10 min. Pumped 1/2 bbl & press back to 1900 psi. Held 1900 psi for 2 1/2" hrs. Released RTTS. POOH. RIH w/8 1/2" bit & tagged cmt. @6484'. C.O. cmt. f/6484' to top of EZ drill @6587'. Press tested Middle Beluga perfs, f/6561' to 6571' w/1500 psi. D.O. ret. @6587' and C.O. cement to 6610'. RIH to 7168', top of cmt. plug. Press tested isolation sqz. perfs f/6602' to 6604' w/1500 psi. C.O. cmt. f/7168' to 7229'. POOH. RIH w/ new bit & C.O. cmt. 7229' to 7285'. 72 73 74 75 76 77 11/9/78 11/lO/7S 1111117s 11/12/78 11113178 10,502' TD 6097' ETD(BP) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 7285' ETD(BP) (cmt. plug) 13 3/8"@2521' 9 2/8" @10,417' 10,502' TD 6097' ETD (BP) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 6097' ETD (BP) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 6097' ETD (BP) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 6097' ETD (BP) 13 3/8"@2521' 9 5/8"@10,417' RIH w/ bit #39 & C.O. cement f/7229' to 7319'. Circ. out sand to 7345'. POOH RIH w/Howco Retrieving tool & recover B.P. f/7353'. Pull up hole & reset B.P. @6097'. Dumped 15 sxs of sand on B.P. & tagged top of sand @6067'. POOH. RIH w/ Howco RTTS, APR valve, and test tools on 3 1/2" tbg. Set RTTS @5625'. Install & test lubricator to 3000 psi. RIH w/ 2 1/8" perforator. With tests tools set @5625' perforated BTM interval of Upper Beluga test zone from 5853'-5863' DIL for DST #5 using Go Int. 2 1/8" O.D. Tornado Magnum guns 4-1/2" HPF. Bled off surface surcharge gas pressure of 1250 psi- Initial flow rate 186 mcf/day - Rate Continuously increased to 4.33 mmcf/day @300 spi tbg. press. Making +300 bbls/day water. (Note: Water indicateS W.O. ~iltrate w/120,000 PPM CL.) Continued DST#5 of Upper Beluga perfs f/5853' to 5863'. Rate increased to 4.72 mmcf/day w/200 psi tbg. press. & 28.2 BWPD. Put in field system @12:00 hrs. 11/19/78. Rate Stab. @3.2 mmcf/day w/975 psi on tbg. Installed & tested lUbricator to 3500 psi. Perf'd 4-1/2" HPF f/5779' to 5789' DIL w/ 2 1/8" Guns. Put in system & rate increased f/3.2 to 4.2 mmcf/day & stabilized @3.88 mmcf/day. Produced to flare @2100 hrs. 11/10/78 & rate increased to 6.6 mmcf/day w/280 psi on tbg. Rate increased to 7.64 mmcf/day by 2330 hrs. Put into system @2400 hrs. - Rate stabilized @5.9 mmcf/day 2/975 psi on tbg. &21.5 BWPD. Installed & tested lubricator to 3500 psi. Perf'd 4-1/2" HPF f/5743' to 5753' DIL w/ 2 1/8" guns. Put in system @1105 hrs. 11/11/78. Rate increased f/5.85 mmcf/day to to 7.75 mmcf/day and stabilized @10.2 mmcf/day w/975 psi~tbg, press & 28.8 BWPD. Closed into move tools @21:30 hrs. 11/11/78. Unalbe to close APV valve. Sheared out circ. sleeve. Circ. 70 PCF mud around. Started out of hole & well started to flow. Circ. & cond. mud to 73+ PCF. RIH to 5900' & circ. out gas cut mud. POOH. Red--ressed APR valve & RTTS Pkr. RIH & set RTTS @5410'. Opened APR valve. Put well back on test with perforations open from 5853' to 5863' 5779' to 5789' 5743' to 5753'. Rate stabilized @7.95 mmcf/day. Down 2.25 mmcf/day from 10.2 mmcf/day prior to trip to repair tools. Opened well to flare for 1 1/2 hrs. Rate increased to 11.8 mmcf/day w/550 psi tbg. press. Put well back into Prod. system. Initial rate 10.4 mmcf. Rate @midnite 11.1 mmcf. Rate not stabilized. Will stab. rate & add perfs 5533'- 5563'. Cont. testisng Upper Beluga perfs f/5853' to 5863', 5779'- 5789' 5743' to 5753' RAte stable @9.88 mmcf/day and +24 BWPD. Installed & tested lubricator, to 3500 psi.-- Added perfs f/5563' to 5533'. Rate stable @10.4 mmcf/day w/53 BWPD in system (~975 psi). ClosEd APR valve Shear circ. sub. Circ. & cond. mud. Start out of hole & well began to flow. RI to 5876' & circ. well clean. 78 11/14/78 10,502' TD 5685' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' RIH & set Baker "C" Retr. B.P. @5700'. Spot 15 sxs 10-20 sand on B.P. Tagged sand @5685'. POOH. Instaled & tested lubricator to 3500 psi. Perf'd 4-1/2" HPF f/5533' to 5563' DIL s/ 4 1/8" O.D. casing guns. RIH w/ Baker Retreivamatic Pkr. & stimulation valve on 3 1/2" tbg. Set pkr. @5370'. Opened stimulation vlave for DST #6 and put well on test into flare @20:15 Hrs. Rate unstable. Unloaded 23 bbls of rat hole fluid. Shut well in. Installed & tested lubricator. 79 11/15/78 10,502' TD 5865' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' Ran BHP survey w/stops every 1000'. Rate unstable thru flare @126 mcf/day w/91.2 BWPD & 65 psi tbg. press FBHP 1371 psi, SIBHP 1582 psi in 3 1/2" hrs. P.O. w/BHP survey. Ran tracer survey - Couldn't get thru Baker stimulation valve. Repaired leak in test head. Re-torqued tbg. - stimulation valve still partially closed Established P.I. rate down tbg. 1.5 cfm @1600 psi. Open rev. valve. Circ. out gas cut mud. 80 11/16/78 10,502' TD 5885' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' POOH w/test tools - Laid down Baker Stimulation valve. TIH w/ 9 5/8" Baker Retrievamaric Test Tool & set @5398'. Established injection rate of +--400 BPD water @1600 psi. Ran Go Int. Radioactive Tracer Survey & established that injection water was going into perfs 5533'-5563' (Upper Beluga Zone). Acidized Upper Beluga perfs 5533'-5563' with 3000 gallons of 12% HCL- 3% HF acid. Injected all acid @2.8 CFM rate. Initial pressure 900 psi final pressure 875 psi. Let acid soak 2 hrs. Displaced tubing w/1250 psi field gas pressure. 81 11/17/78 10,502' TD 5885' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' Retested DST #7 perfs in Upper Beluga Zone from 5533'-5563' after acid treatment. Maxmum rate 7.3 mmcf/day @365 psi surface pressure. Making +--200 BWPD (Mostly acid water). Zone making excessive sand. Reduced rate to 1.65 mmcf/day to stop sand production. Unable to release Baker Test Tool - Could come up hole but unable to go down hole, 'therfore unable to circulate below perfs. POOH w/test tools-OK. Ran 8 1/2" bit & circ. out gas cut mud @5586'. POOH - Ran Baker Model "C" 9 5/8" RBP and set @5394' DPM Spotted 25 sxs sand on top RBP. Checked top of sand @5333'. 82 ii/i8/78 10,502' TD 5885' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' ~ R.U. Go Int. & perf top of Sterling interval 4050-4052 DIL for Blk. Sqz. #18 to isolate Sterling gas sands from injection water above. Ran 9 5/8" Howco RTTS Tools & set @3880'. Broke down & pumped perfs 14 CFM @1000 psi. Mixed & pumped 500 sxs class "G" cmt. w/.3% Halad 22-A & 3% KCL. Final pumping pressure 1200 psi. Squeeze held 950 psi w/pumps off. POOH w/9 5/8" Retrievamatic squeeze tool. Ran 8 1/2" bit & casing scraper. Tag cmt. @3965. Drilling firm cmt. to 4098' perfs 4050-4052. Tested 9 5/8" casing to 1000 psi- OK. POOH. Laid down 5" HWDP. 83 11/19/78 10,502' TD 5885' ETD (sand) 13~3/8"@2521' 9 5/8"@10,417' Ran Retreiving tool & picked up Baker RBP @5394'. POOH. Laid down tools. Picked up Hwoco 9 5/8" RTTS Tool & TIH. Set Tool @5460' to perform Hydroxy-Aluminum job on Upper Beluga perfs from 5533-5563. Pumped 139 bbls OH-AC Clay Lok Solution @1 bbl/min. Followed by 140 bbls H20. Initial pumping press 1225 psi. Final pumping press 1495 psi. Displaced water w/1250 psi gas pressure & shut in well for 12 hrs. 84 11/2o/78 10,502' TD 5885' ETD (sand) 13 3/8"@2521' 9 5/8"@10,417' Retested Upper Beluga zone perfs from 5533-5563 after performing Hydrox-Alum. Clay Lok Treatment. Inc. well rate with no sand production until stabilized @7.6 mmcf/day & +150 BWPD into prod. system @1050 psi after 4 Hrs. of st--ab, rate zone starting making sand. Reduced rate continuously in an attempt to stop sand production. 85 11121178 10,502' TD 5685' ETD 13 3/8"@2521' 9 5/8"@10,417' Continued DST #8 on Upper Beluga Zone perfs from 5533- 5563'. Reduced rate from 4.5 mmcf/day 70 BWPD & 3% sand with 1500 psi surface press to 3.5 mmcf/day to put on production without cutting out prod. equipment. Inc. rate in attempt to clean-up sand and produce all injected water. Inc. rate to 6.5 mmcf/day 90 BWPD & 4-5% sand @1300 psi surface press. Well does not appear to be cleaning up. Sand rate constant. 86 87 88 89 90 11/22/78 11123178 11124178 11125178 11/26/78 10,502' TD 8067' ETD (Perm Prod. Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502~ TD 8067' ETD (Perm Prod. Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067' ETD (Perm Prod. Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067' ETD (Perm Prod. Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067' :ETD (Perm Prod. Pkr.) 13 3/8"@2521' 9 5/8"@10,417' Continued DST #8 of Upper Beluga perfs f/5533-5363. Continued DST #8 of Upper Beluga perfs f/5533-5363. Continued DST #8 of Upper Beluga perfs f/5533-5363. Continued DST #8 of Upper Beluga perfs f/5533-5363. Completed DST #8 on Upper Beluga Zone perfs 5533-5363 DIL. Final rate: 10.9 mmcf/day w/1075 psi tbg. press. 60 BWPD w/9000 ppm CL & trace of sand. Shut in test @5:30 PM 11/25/78. POOH w/test tools. Laid down 3 1/2" tubing test string. TIH to retrieve 9 5/8" Baker RBP @5700' Found top of sand @5762' & RBP @5765' (Note: RBP 65' Deep to where set.) POOH w/RBP. Reran tool to retreive Baker 9 5/8" RBP @6097'. Tagged sand @6050' & washed down to RBP @6097'. 91 92 93 94 11/27/78 ll/28/78 11/29/78 11/30/78 10,502' TD 8067' ETD (perm Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067Y ETD (Perm Pkr.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067 ' ETD (Perm Pkr. ) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 8067' ETD (Perm Pkr.) 13 3/8"@2521' 9 5/8"@10,417' POOH w/ BAker 9 5/8" RBP. RIH w/ 4 3/4" seals on drill pipe. Opened flapper & stabbed into perm pkr. @8069' DPM (8067' DIL). Tested pkr. to 300 psi-OK. POOH. Laying down drill pipe. Running 3 1/2" Dual Comp. Assy. Ran 3 1/2" Dual Comp Assy. Stabbed into Perm Pkr. @8067' & spaced out. Installed Dual hanger in OCT tbg. head. RIH w/ blanking plug on Meyers W.L. & set in landing nipple on long string. Attempted to set single hydraulic pkr. @5947' to 5953' w/2000 psi on L.S. Opened c~¢.s~e~ei~nLL$$.@~00~l't~o psi on L.S. Opened circ. sleeve in L.S. @8031' to 8035' & well circulated w/300 psi- PKR. not set. Finished POOH.w/Dual 3 1/2" Comp. Assy. Lay down Otis Pakcers. Redress Seal Assy. RIH w/ Dual 3 1/2" Comp. Assy. w/ Baker Pakcers. Hydro testing @5000 psi. Document Transmittal Union Oil Company of Calif-'~ia unle, n 'DATE SUBMITTED ACCOUNTING MONTH .. I. Dec.. 19, 1978 ... TO FROM Bill Van Allen ' ~ Warthen AT ....... AT " State Div. Oil & Gas Union Oil ,, TELEPHONE NO. TRANSMITTING THE FOLLOWING: Kenai Gas Field, KDU 95 1 Radius of Curvature ..... Please acknc~,ledge receipt · ,, signing ~and .returning copy o] document transmittal. , .... , , .......... , , i i i ii iii ii i i ii i i i FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. From the D~k o~ R. C. WAF'~N ANCHORAGe, ALASKA Document Transmittal Union Oil Company of ",ifornia unlen ~3'ATE SUE~MITTE6 ACC~)b'NTI~'~ ~IONTH Dec. 12, 1978 ¥0 ................... F.o~ .......... H. W. Kugler R.C. Warthen AT .............. AT ...... State. Div. ,, 0i~, &, Gas Anchorage, AK TELEPHONE NO. TRANSMITTING THE FOLLOWING: -- ii i · i i iii i i i i i ii i ii ii i ii i , ii i i ..... l Se.t,, ,~,epi ,a~ ................. 1 Set Blnelines ........... KDU #5, K~ai Gas Field i ...... Please ackn~..c~..1 .e~ge reoeipt by: .... signing and returning copy of ~/-/~/' ....... . , , ......i. do~t transmittal. " ,Date: ...... , ~.~/~ ~//".~,~" ' .... , ./,~z. .... ,,,, ....... .,~.C~. ............. ...... ,~/b,. .... .... ......... ............. .... ~*~i'~ ......... Ii iii I iiii i ii ii iii i i i i i i i i[ ii i i i i i FORM 1-2M02 (REV. ! ~-72)~'PRINTED IN U.S.A. 34 35 36 Fo~rm No. 10-404 ~ SUBMIT 1N DUPLICATE /~ , STATE OF ALASKA s. APINUMEPJCALCODE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPE TIONS 1. 7. IF INDIAN'ALOTTEEOR TRIBE NA~IE ~ ~i ['" WELL ~ELL ~': .... ' ~'~' Kenai Deep Unit Union 0il Co. 0f-California ~ ...... 3. ADDRESS OF O~ERATOR 9. ~ELL NO. ................ P,0. Box 6247. Anchoraoe. Alaska DMsjgQ6O2',:; .::._ ~,. ,.~. ............. KDU ~5 ~ · ................. ,o m. ~o AND ~OO~, O~ W~XT 4. LOCATION OF WELL ,. ~L~-~.,.: 692' N & 1720' W of S.E. Corner of Sec. 36, T5N,' RllW, K~i aa~ Fiold_ .._ I. ...... s~c S.M. ,~. s~c. T. R. M. (BOTTOM ~0~ CONFER: OBJECTIVE) FILE: (~ Sec. 6, T5N, R11W, ~"~]'~-~ ...... ~ 12. PERMIT NO. 78-55 .. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 10/1/78 10,502' TD 10,320' ETD (cmt. plug) 13 3/8"@10,095' 9 5/8"@7055' Drilling out Howco 9 5/8" cmt. ret. @6469' & drilling firm cmt. to 6513'. Finished TIH to plug catcher @10,320' Drilled plugs & C.O. cmt. to 10~350'. POOH R.U. Go. Int. Ran CBL-VDL-GR. Log from 10,350 to 3300'. ~IH w/scientific Drilling Control Gyro Survey on Go. Int. W.L. 10/2/78 1 O, 502' TD 8455' ETD (cmt. ret.) 13 3/8' @10,095' 9 5/8"@7055' Completed running gyro- survey from surface to 10,350' @100' stations. R.U. Go Int. & perf 8472' to 8474' DIL for Blk. Sqz. #2. Ran Howco 9 5/8"@ 'EZ- SV cmt. retainer set @8455' DIL. RIH w/Howco stinger on D.P. tested surface equipment to 5000 psi. Broke down perf 2800 psi @6 cu/ft point. Mixed & pumped 500 sxs Class "G" w/.5% Halad 22A 3% KCL. Surry wt. 118# cu/ft. Final squeeze 3650 psi. FM held 2900 psi after 10 min.. Pulled out of retainer traDed 2900 psi below. Try to reverse, unalt to reverse circ. Pull 1 stand. Broke circ. in reverse pumped 470 strokes D.P. pluged. Rock press back & forth and would not reverse. Circ. out cmt. the long way. 10/3/78 1 O, 502' TD 8358' ETD (top cmt. ) 13 3/8"@10,095' 9 5/8"@7055' Mix mud after displacement w/water. POOH. Found Howco 9 5/8" cmt. retainer mandrial broke above sliding sleeve. RIH w/RTTS on 5" D.P. to close D.V. collar & test ports. Set RTTS below D.V. @6524'. Test below to 2800 psi - OK. - Reset above D.V. Tool & test D.V. Broke down @2200 psi Work up setting RTTS @6" intervals. Located sleeve in D.V. tool and closed ports. Tested to 2800 psi - OK. POOH. Laid down RTTS tools. Picked up BHA #24 @bit #26. RIH. 14. ' hereby c~tif~that the for/~n~g'is~rue~n~ correct // SiGNED~/~~17. ~'f. ~_[~4_.,t~..~/~,..4~.,,~ITLE DIST. DRILLING SUPT. DATE ]]/]7/78 NOT~-J~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the C///oil and gas conservation cOmmittee by the 15th of the succeeding month,unless otherwise directed. 37 38 39 40 41 42 10/4/78 10/5/78 10/6/78 10/7/78 lO/8/ 10/9/78 10,502' TD 8550' ETD (cmt. ret.) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 8100' ETD (cmt. ret.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 5540' ETD (cmt. ret.) 13 3/8"@2521 ' -9 5/8"@10,417' 10,502' TD 5540' ETD cmt. ret. ) 13 3/8"@2521 ' 9 5/8"@ 10,417' 10,502' TD 5540' ETD (cmt. ret.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 5730 ETD (cmt. -ret. ) 13 3/8"@2521 ' 9 5/8"@10,417' RIH w/ BHA #24 & bit #26 & tag cmt. @8358' C.O. cmt. & ret. @8455'. C.O. cmt. to 8459'. ~IH to 8500' & circ. & cond. mud. POOH. Perf'd.4-1/2" HPF.f/8480' to 8482' DIL.' RIH w/ ret. on D.P. & attempted to set @ 8425'. Unable to set. POOH. Found ret. had come off setting tool. POOH w/ setting tool. RIH w/ 8 1/2" bit & tagged ret. @6600'. Pushed ret. to 8550'. Set ret. @8430', sqz'd perf f/8480' to 8482', blk. sqz.#13 Broke down perfs @4750' psi. PI 10 CFM @4750 psi. FM held 4250 psi w/o pumps. Mixed 300 sxs "G" w/ .5% Hal ad 22-A & 3% KCL. Displaced 300 sxs behind perfs to final press of 3400 psi. Perf'd 4-1/2" HPF f/8152' to 8154' for Bl,k. Sqz. ~,4. RIH & set ret. @8100' Sqz'd perfs f/8152 to 815 w/500 sxs "G" w/.3% Haled 22-A .5% CFR-2 & 3% KCL. (Initial press 3200 psi @8 cf/min. Final press 4000 psi.) Perf'd 4-1/2" HPF f/8026' for Blk. Sqz. #5. Set ret. @7975' & sqz'd perfs 8024' to 8026' w/500 sxs "G" w/.3% Halad 22-A 3% KCL & .5% CFR-2 (I.P. 3000 psi, F.P. 3800 psi). Perf'd 4-1/2" HPF f/7919' to 7021' Blk. Sqz. #6. Set EZ drill ret. 7867' & sqz. perfs f/7919 to 7921' w/500 sxs "G" w/ .3% KCL & .5% CFR-2. (Initial press 3400 psi F.P. 3600 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/7724' to 7726' Blk. Sqz. #7. Set EZ drill ret. @7654'. Sqz'd perfs f/7724' to 7726' w/500 sxs "G" w/ .3% Halad 22-A 3% KCL & .5% CFR-2. (I.P. 3000 psi F.P. 2600 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/7424' to 7426' Bl k. Sqz. #18. Set EZ drill ret. @7375' & sqz. perfs f/7424' to 7426' w/500 sxs "G" w/ .3% Halad 22-A 3% CFR-2. (I.P. 2250 psi F.P. 2800 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/5865' to 5867' Blk. Sqz. #9. Attempted to set EZ drill ret. ( Lost ret. on way out of hole). RIH w/ 8 1/2" bit & tag ret. @1596'. Drill out & push ret. tc 6000'. POOH. · Set EZ drill ret. @5810' & sqz. perfs f/5865' to 5867' w/ 500 sxs "G" w/.3% Hal ad 22-A & 3% KCL & (I.P. 2000 psi F.P. 2200 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/5791' to 5793' Bl k. Sqz. #10. Set EZ drill ret. @5740' & szq'd perfs f/5791' to 5793' w/500 sxs "G" w/ .3% Halad 22-A & 3% KCL. (I.P.2350 psi, F.P. 2100 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/5713' to 5715' Blk. Sqz. #11. Set EZ drill ret. @5648' & sqz. perfs f/5713' to 5715' w/500 sxs "G" w/.3% Halad 22-A & 3% KCL. (I.P. 2000 psi, F.P. 2700 psi) Rev. clean. POOH. Perf'd 4-1/2" HPF f/5601. Set EZ drill ret. @5540'. Sqz'd perfs f/5601' to 5603' w/500 sxs "G" .3% Halad 22A & 3% KCL ( I.P. 1800 psi, F.P. 2600 psi) Rev. clean. POOH. RIH w/ 8 1/2" bit & tag ret. @5540'. Tested pipe Rams to 3500 psi - OK. Drilled out retainer @5540' to 5648'. Pressure tested perfs f/5601' to 5603' & 5713' to 5715' @2000 psi - OK. Drilled out ret. @5748' & C.O. to ret. @5810'. Press tested perfs f/5791' to 5793' @2001 psi- Broke down @1300 psi. ' 43 10/10/78 44~ 10/11/78 45 10/12/78 46 10/13/78 4~ 10/14/78 48 10/15/78 10,502' TD 7375' ETD (cmt. ret.) 13 3/8"@10,417' 9 5/8"@7055' 10,502' TD 7654' ETD (cmt. ret.) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 8100' ETD (cmt. ret.) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 8850' ETD (cmt. ret.) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 8850' ETD (cmt. ret.) 13 3/8"@2521' 9 5/8"@10,417' 10,.502' TD 8850' ETD (cmto ret.) 13 3/8"@2521 ' 9 5/8"@10,417' Ran 9 5/8" Howco cmt. ret. on D.P. and set @5730'. Sqz'd perfs f/5791' to 5793' Blk. Sqz. #10 Stage #2, w/500 sxs "G" w/ .3% Halad 22A & 3% KCL ( I.P. 1300 psi F.P. 2500 psi) Rev. clean. POOH. Tested csg. above ret. @5730' to 2000 psi - OK. RIH w/ 8 1/2" bit & D.O. ret. @5730'. Press tested perfs f/5791' to 5793' @2000 psi - OK. D.O. ret. @5810' & test perfs f/5865' to 5867' broke down @1600 psi. ' RIH w/ret. & set @5805'. Press tested perfs from 5865' to 5867' Blk. Sqz. #9 to 4000 psi - OK. Tested above to 2200 psi- OK. POOH. Pumped into 9 5/8" X 13 3/8" annulus @4 BPM & 1000 psi. RIH w/bit & D.O. retainers @ 5805', @6000 & 7375'. C.O. cmt. 7377' to 750%~ RIH to 7650' & test perfs f/7424' to7426' @2000 psi - . D.O. ret. @7654' & C.O. cmt. to 7800'. Tag ret. @7867. Tested perf f/7724' to 7726' @2000 psi - OK. D O. ret @7867' & C.O. cmt. to 7961'. Tag ret. @7975'. Tested .perfs f/7919' to 7921' @2000 psi - OK. D.O. ret. @7975' & C.O. cmt. to 8061'. Tag ret. @8100'. Tested perfs f/8026' to 8028' @2000 psi - OK. Drilled out cmt. retainer @8100'. Drilled out cmt. opposit Blk. Sqz.#3 perfs 8152'-8154'. Fell out of cmt. @8190'. Washed to top of cmt retainer @8430' Tested .Blk. Szq. #3 perfs 8152' to ~154' w/2000 psi i5 mins. - No bleed off. Drilled retainer @8430' & C.O. cement to 8510'. Tested Bl k. Sqz. #3 perfs 8480' to 8482' & Blk. Sqz. #2 Perfs 8472' to 8474' to 2000 psi - Held OK. Pushed cmt. retainer & drilling to 8850'. NOTE: Left cmt. retainer loose @8850. POOH- R.U Go Int. Logging Unit. ' Ran CBL-VDL-GR log from 8560' to BTM. Surface casing @2521'. Ran noise log & Temp. Survey over questionable areas of the bond log..R.D. Go. Int. Ran 12 1/4" bit #31 RK & 9 5/8" casing scraper. C.O. well to ETD @8850'. Circ. & cond. mud. POOH w/bit & scraper. Ran Howco 9 5/8"@ret. bridge plug in tandem with Howco 9 5/8" RTTS Tool with APR valve on Dry drill pipe. Set RBP @8570' and set RTTS tool @8506'. RU GO Int. W.L. lubticator & picked up 2 1/8" O.D. Tornado Magnum Expendable gun. Pressured D.P. with 1325 psi surface pressure with gas. Pressured casinq and opened APR valve in D.P. Perforated 8545' to 8547' ~IL below Lower Beluga test intervals for Dry Test #1. POOH w/gun. Bleed gas press off D.P. & Dtry tested perfs 8545' to 8547' to BTMS. press. 30 mins. with no entry. Released csg. pressure & closed APR valve on D.P. Picked up RBP @8570. Reset RBP @8030' and reset RTTS @7921'. R.U. Go Int. W.L lubricator & P.U. 2 1/8" O.D. Tornado Magnum Exp. Gun. Pressured D.P. with 1325 psi surface pressure with gas. Pressured casing and opened APR valve in D.P. .Perforated 7974' to 7976' DIL (Mid Lower Beluga Zone) For dry test #2. Bled surface Pressure to 0 psi & dry tested perfs 7974' to 7976' DIL w/BTMS, press, for 30 minso with no entry. Closed APR v~lve. ' 49 50 10/16/78 10/17/78 10,502' TD 5570' ETD (BP~ 20"097' 13 3/8"@2521' 9 5/8"@10,417 10,502' TD 5499' ETD (cmt.) 13 3/8"@2521 ' Dry Test #3. Bled down gas press. & blow continued slightly after surface pressure @atmospheric. Closed APR valve & P.U. RBP. Reset Howco 9 5/8" RBP @5595 and reset RTTS Tools @5472' R.U. Go. Int. wireline lubricator & P.U/ 2 1/8" O.D. Tornado Magnum Exp. Gun Pressured D.P. w/llO0 psi gas press. Pressured casing w/2000 psi and opened APR valve in D.P. Perforated 4-1/2" HPF from 5520' to 5522' DIL (above Upper Beluga Test Interval) For Dry Test #4. Attempted to blow well down to BTMS press. WEll continued to blow slightly getting entry from formation- Released csg. pressure after 30 mins. & attempted to P.I.R.B.P. unable to get down to top of RBP due to sand fill. POOH w/RTTS Tool - Recovered 24 bbls of fluid entry in D.P. from 4 Dry Test (Gas Cut Mud) Had approx. 200' of sand fill in D.P. & RTTS tool plugged with sand from Dry Test #4 perfs 5520' to 5522' DIL. Ran retrieving tool on 5" D.P. and tagged sand fill @5582' - Washed down to RBP @5595'. Engauge RBP & POOH. R.U. Go Int. & ran W.L. Gauge Ring & junk to 6000'. Ran Howco 9 5/8" EZ Drill B.P. on W.L. and set @5907'. R.D.W.L. Unit. Picked 9 5/8" Howco EZ Drill cmt. on 5" D.P. and set @5795' to Sqz. off Dry Test perfs #3. Block Sqz. #13 on Dry Test Perf #3, 5875'-5877' DIL. Broke down perfs @2000 psi. Pumped in 1.1.6 CFM @1600 psi. FM held 1200 psi w/o pumps. Mixed 500 sxs Class "G" w/.3% Halad 22-A & 5% KCL. Displaced 480 sxs below retainer to a final pressure of 2200 psi. Reversed out 20 sxs cmt. CIP @8:15 PM POOH w/setting tool- R.U. Go Int. & set 9 5/8" Howco EZ Drill Bridge Plug @5570'. To isolate dry test #4 perfs 5520'- 5522'. POOH. R.D. Go Int. TIH w/ 9 5/8" Howco EZ Drill cmt. ret. on 5" D.P. and set @5458' to squeeze off dry test perfs #4 @ base of Upper Beluga 5520' to 5522'. Broke down perfs @1600 psi- P.I. 12 CFM @1400 psi - Held 1150 psi after 10 mi ns. w/o pump. Mixed 500 sxs Class "G" cement w/.3% Halad 22-A & 5%-KCL. Displace 482 sxs below tool to a final st. anding pressure of 1950 psi. Reversed out 18 sxs cmt. POOH w/ retainer stinger. Tested all BOPE to UOCO Specifications 5000 psi- Held OK. TIH w/ 8 1/2" bit #32 & BHA #27. C:t~. to top of retainer @5358'. Drilling cmt. retainer & firm cement to 5499'. Made trip for new bit. 51 52 53 54 10/18/78 10/19/78 10/20/78 10/21/78 10,502' TD 5800' ETD (DPM cmt. ret.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 5901' ETD DPM (cmt.) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 10,329' ETD (loose junk) 13 3/8"@2521' 9 5/8"[a10,417 ' 10,502' TD 10,329' ETD (loose junk) 13 3/8"@2521' 9 5/8"@10,417' Finished TIH w/ 8 1/2" bit #33, dri.lled firm cement (opposite DrY Test #4 perfs 5520'-5522') From 5499' to 9 5/8" Howco Bridge Plug set #5570' DIL. Attempted to test perfs to 2000 psi - bled off to 1500 psi - Re- pressured to 2000 psi - bled to 1200 psi - 10 mins. POOH w/bit #33. Ran Howco 9 5/8"cmt. ret. on 5" D.P. and set @5429' to resqueeze dry test #4 perfs @top of Upper. Beluga 5520' to 5522'. Unable to break down perfs w/4000 psi. POOH w/retainer stinger. Re-ran 8 1/2" bit #33 on BHA #27. Drilled out cmt. retainer @5429' and C.O. to bridge plug @5570 DIL (5595 DPM) Re-tested dry test #4 perf from 5520' to 5522' DIL to 2000 psi- bled back to 1500 psi - 5 mins. *Located leak in rig's mud line- repaired same & perfs test'ed to 3000 psi - 30 mins. - OK. POOH w/bit #33 RR- TIH w/bit #34 on BHA #27. Drilled bridge plug @5570 & C.O. cmt. ret. @5795'. Drilled out cmt. ret. @5795' DPM. Drilled firm cmt. to 5832' POOH. Left 3 cones off bit in hole. P.U. 8 3/8" fiat btm. junk mill. RIH. Drilled up junk at 5832' and drilled out cmt. to 5901' DPM. Attempted to press, test dry test #3 perfs 5875' to 5877'- Broke down at 2000 psi and bled to 950 psi in 10 mins. TIH w/ 9 5/8"Howco cmt. retainer on 5" D.P: and set @ 5775' DPM Pe,rfs exposed below retainer 5791' to 5793', 5865' to 5867 & 5875' to 5877. Broke down perfs @2000 psi & pumped 3CFM to a total of 21 'CF pumped - perfs tugged up. Increased pressure to 4000 psi - Unable to break down perfs. Pressured 9 5/8" casing annulus above retainer 5713' -5715', 5601' to 5603' and 5520' to 5522'. Isolated leak with RTTS tool to be perfs 5520' to 5522' (Dry test #4. perfs @top of Upper Beluga) R.U. Go Int. W.L. unit & set Howco 9 5/8" EZ Drill cement retainer @5417 DIL. Ran retainer stinger on 5" D.P. - Located on cmt. retainer @5422 DPM'- Note: DPM 13 5' Deep to DIL @5400'. Broke down perfs 5520' to 5522' DIL (Stage #2 Blk. Squeez( #14- Top Upper Beluga) @2000 psi. Pumped in 2.8 CFM @195( psi. FM held 850 psi w/o pumps after 10' mins. Shut in. Mixed 250 sxs Class "G" sement w/.3% Halad 22-A and 3% KCL. Squeezed 205 sxs below tool to a final static squeeze pressure of 2900 psi - Reversed out 45 sxs. cmt. Cement in place @12:45 am. POOH w/ retainer stinger. TIH w/ 8 1/2" bit #35 on BHA #27. Tagged up on cmt. retainer @5422 DPM. Drilled retainer and very firm cmt. to 5434 DPM. POOH. TIH w/ bit #36 on BHA #27. Drilled firm cmt. to 5535 DPM. (5530 DIL) Pressure tested Blk. Sqz. #14 perfs 5520' to 5522' w/1800 psi- Held OK. Drilled through BTM. cmt. @5568 DPM. 56 57 58 · 78 10/23/78 10/24/78 10/25/78 10,502' TD 10,329' ETD (cmt. ret.) 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 10,329' ETD (loose junk) 13 3/8"@2521 ' 9 5/8"@10,417' 10,502' TD 10,329' ETD (loose junk) 13 3/8"@2521 ' 9 5/8@10,417' 10,502' TD 10,329' ETD (loose junk) 13 3/8"@2521' 9 5/8"@10,417' Pushed junk down hole to cement retainer @5775' DPM. Drilled cement retainer & C.O. to cmt. plug @5901 DPM. Drilled firm cement to bridge plug @5907 DIL - 5912 DPH. POOH w/ bit #36- Left 2 cones off bit in hole. Ran 8 3/8" Junk Mill #2 on BHA #28. Drilled up Junk Cones & Bridge Plug @5912 DPM. Pushed Junk & retainer Junk to 10,329' DPM Circ. & Cond. mud. Tested 9 5/8" casing & all squeeze perfs to 1800 psi- Held OK. POOH w/Junk Mill #2. Picked up Howco 9 5/8" RTTS Tool & APR Test Valve on 3 1/2" 9.2# Butt. Tubing test string. To test Tyonek Zone. Completed TIH w/ 9 5/8" Howco RTTS Tools and APR Valve picking up 3 1/2" tubing strings. Set RTTS Tools w/Tbg. Tail @ 8044 DIL or 8062 DPM RU Go Int. W.L. Lubricator & 12' of 2 1/8" O.D. Tornado Magnum Gun. Tested lubricator & surface equipment to 5000 psi -..OK. Pressured 9 5/8"casing annulus w/1500 psi and opened APR valve~ in 3 1/2" tubing. TIH w/ perf gun & posi- tioned to perforate. Pressured 3 1/2" tubing w/1300 psi using field gas- perforated Tyonek Zone from 8460'-8472 DIL - No increase in surface pressure after perforating - Opened well @9'15 AM Bled off charge pressure & well flowed +200 mcf/day rate (Unstable)- No liquids unloaded. Unable to build sufficient pressure on test seperator to determine accurate rate. Shut-in well @ 10'45 am. TIH w/20' of 2 1/8" O.D. Tornado Magnum Gun. Positioned gun to perforate. Charged 3 1/2" tbg. w/1200 psi filed gas. Perforated Tyonek from 8127-8147 D~L. Opened well @l'O0 PM. Bled off charge pressure & well flowed at +300 mcf/day. Continued flow testing Tyonek Zone- Rate increased to 1.6 mmcf/day by midnight- Rate not stabilized & still increasing. B.H.F.P. recorded at top of perfs. 8127-8147 equal 324 psi. Continued flow testing Tyonek Zone perfs 8460-8472 & 8127-8147 DIL. Flow rate increased from 1.6 mmcf/day w/80 psi surface pressure to 4.8 mmcf/day w/210 psi surface pressure @ll:O0 pm. Disontinued flaring. BHFP recorded on H.P. recorder at 690 psi. Put well in to Field Production System @ll:O0 am. Prod. Rate stabilized at 5.2 mmcf/day w/no water cut- Surface pressure at 950 psi - BHFP +1300 psi. Ran Go Int. Spinner - Temperature survey - Determined 10% of entry from perfs 8460-72 & 90% of entry from perfs 8127-47. No indication of gas movement behind 9 5/8" casing below Tyonek Test Interval. POOH w/spinner temp. survey. Rate constant @5.2 mmcf & no water. Final flow rate on Tyonek Zone perfs stabilized @5.2 mmcf/day w/950 surface pressure. BHFP 1821 psi. Shut in well for btm hole static press, build-up. Btm. hole press, built to 3619 psi - final FM press, extrapolated to 3750 psi. CONTINUED: #58 59 10/26/78 60 10/27/78 61 10/28/78 62 10/29/78 63 10/30/78 10,502' TD 10,329' ETD (junk) 20'@97' 13 3/8"@2521' 9 5/8"@10,417' 10,502' TD 10,169' ETD (junk) 13 3/8',@252t' 9 5/8"@10,417' 10,502 TD 10,169' ETD (junk) 13 3/8"@ 2521' 9 5/8"@10,417' 10,502' TD 10,169' ETD (junk) 13 3/8'@2521' 9 5/8"@10,417' 10,502' TD 10,169' ETD (junk) 13 3/8"@2521' 9 5/8"@10,417' Installed positioned @8112 MD, 7364; TVD_+.5 psi/ft. grad. Put well back on flow into production system at 6.2 mmcf/day'@950 psi. RU Go Int. and re-perforated Tyonek Zone 8127'-8147' and 8460'-8472' DIL using 2 1/8" O.D. Tornado Magnum Guns 4-1/2" HPF. No increase in production noted after re-perforating. Put well back on test- rate stabilized @6.36 mmcf/day @965 psi - No sand o~ water. Took well out of production system and vented to flare for 1 hr. @7.5 mmcf/day @220 psi. Put well back into prodution system - rate stabilized @ 7.45 mmcf/day @985 psi - no sand or water. Prod. Test Tyonek perfs @7.45 mmcf/day @985 psi- Rate stable - no sand or water. Put well back to flare 1 hr. & made 7.8 mmcf/day @160 psi - Put well back into Prod. System & made 7.63' mmcf/day @1000 psi. Shut in well @3'30 AM to run bottom hole static pressure build-up survey. Pressures & data correlated w/previous Hewlett Packard Data from initial shut-in. Put well back flow into Prod. System @9'30 am - Max rate 10 mmcf/day- Rate stabilized @8.5 mmcf/day - no sand or water. Shut Shut in to kill well @3'45 pm Displaced tubing string with 76#/cf CACL2 W.O. fluid. (FM press._+73.3 #/cf) Closed APR valve - pumped out shear sub & circ. out 66# mud in casing w/76#/cf W.O. fluid. Released test packer @8039 DIL meas. Well quiet. Pull 3 stds - took correct amount of mud- watched well - no flow. POOH w/ Packer - filled hole every 5 std. & watched well - no flow. Pulled total 48 stds. & well started flowing. P.U. Kelly & circ. out. Mud gas cut on annulus to 52#/cf remained cut to 67#/cf. Raised MW to 80 PCF. RIH & circ. gas cut mud. POOH w/test tools. RIH w/Otis 9 5/8"X 4" Perm Pkr. w/plug in'seal bore on W.L. Go Int. pulled out of rope socket @2170'. POOH w/ W.L. RIH w/ 7 5/8" Guide w/ 3 1/4" grapple. Tagged fish @8144'. Fish fell to 8207'. Engauged fish. POOH. Compl. POOH. Rec. setting tool. RIH w/8 3/8" burn over shoe & pkr. Picker. Tagged Pkr. @8144'. Couldn't stab into pkr. w/Ext. POOH lay down ext. RIH w/ 8 1/4" burn over mill ( w/o pkr. Picker ext.) Tagged Pkr. @8144'. Burn over pkr. to 8152'. POOH. Fouhd mill gauge worn out 1/8" w/no wear on BTM. RIH w/ O.P.D.P. & tagged pkr. @8227'. Pushed pkr. to 8443'. POOH. RIH w/ 7 7/8" Concave Mill & tag pkr. @8439'. Milled pkr. f/8439' to 8442' & fell thru pkr. RIH to 10,165'. Milled on junk to 10,169'. Circ. well celan w/80 PCF CACL2 W.O. fluid. RIH w/ 8 1/2" bit past Burr @8141'. (Went by 3 times 3M# 1st IOM# 2nd 6M# 3rd) Didn't have to rotate. POOH. Set Baker 9 5/8"X 4 3/4" pkr. w/flapper valve on W.L. @8067' DIL. RIH. Retr. B.P. tag pkr. P.U. & set Retr. B.P. @8057' DIL. Spotted 10 sxs sand on retr. B.P. Tagged sand @8039' DIL. POOH. RIH w/ RTTS & test lub. to 5000 psi - OK. KDU #5 Continued- 64 10/31/78 10,502' TD 10,169' ETD (junk) 13 3/8"@ 2521' 9 5/8"@10,417' Unable to wt.:,k perf's gun thru APR valve in test string. R.D. Go. POOH w/test tools. Redressed Howco APR valve. RIH w/Howco RTTS & APR valve on 3 1/2" Butt. Tbg. Set RTTS @7786' Perf'd 4-1/2" HPF f/8014'- 8024', 7907' to 7917', & 78~7' to 7887' DIL. Form No. P-4 REV. 3-1--70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. OIL ~] GAS WELL- WELL ~ OTHER 2. NAME OF OPERATOR UNION OIL COMPANY OF CALIFORNIA 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 4. LOCATION OF WELL 692'N & 1720' W of S.E. SUBMIT IN DUPLICATE 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND S ,R!~L NO. A-028142 7. IF INDIAN'ALO~EE OR 99502 corner of Sec.36, T5N, RllW S.M. 8. UNIT FARM OR LEASENAM! i ' KENAI DEEP UNIT 9. WELL NO. KDU #5 10. FIELD AND POOL, OR WILD4 :AT KENAI GAS FIELD! 11. SEC. T. R. M. (BOTTOM HOLI OBJECTIVE) SEC 6. T5N. 12. PERMIT NO. 78-55 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 8/25/78 8/26/78 8/27/78 8/28/78 RECEIVED 1978 1 5 0ivision e~ 0il & G~ ~on~orvat;o MOVE RIG FROM CLAM GULCH UNIT #1 TO KENAI GAS FIELD, KDU #5, AND RIG UP. CONTINUED RIGGING UP. RIGGED UP & DROVE 20" 1/2" WALL CONDUCTOR WITH DEL MAG D-22 DRIVE HAMMER TO 97' R.K.B. 8/29/78 8/30/78 8/31/78 459' TD 459' Footage 20" @ 97' 66 PCF 63 SEC lO41 ' TD 582' Footage 20" @ 97~ 76 PCF 61 SEC 1607' TD 566 Footage 20" @ 97' 67 PCF 60 SEC. INSTALLED 20" HYDRIL. COMPLETED RIG UP. SPUD @ 16-00 HRS. 8/29/78. DRLG. 17 1/2" HOLE FROM SURFACE TO 459'. DRLG. 17 1/2" HOLE F/459' to 625' KOP. POOH FOR D.D. RUN #1D.D. 17 1/2" HOLE F/625' to 925'. POOH FOR BHA CHG. RIH w/FOLLOW UP ASSEMBLY, BIT #1RR & BHA #3 and DIR. DRILL 17 1/2" HOLE F/925' to 1041'. DRLD. 17 1/2" HOLE TO 1198'. HOLE TURNED RIGHT & DROPPED ANGLE. RAN DYNA-DRILL & ORIENTED FOR LEFT TURN & ANGLE BUILD. DYNA-DRILLED 17 1/2" HOLE 1'0 1607'. HOLE ANGLE 4 DIRECTION AS DESIRED - POOH -. 14. I hereby certify that theefo~g is~e and. correct ~ SIGNED~-'~J~_'~ -'""'~--~~-'~ ' ~-' '' "' TITLEDTgT.DRII I lNG SIIPT. DATE q/ltl/78 NO~' this form is required for ea~ calendar month, regardl~ of the ~atus of operatiom, and mu~ be film in duplicate with the oil and gas conservation committ~ by the 15th of the succ~ing month, unl~ otherwise directS. RI~V. 3q-70~ ",. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR UNION OIL COMPANY. OF CALIFORNIA SUBMIT IN DUPLICATE 5. AP! NUMERICAL CODE A-028142 3. ADDRESS OF OPERATOR P.O. BOX 6247, ANCHORAGE, ALASKA 4. LOCATION OF WELL 34-31 Drilling Pad 415' N & 2100' W of SE corner of Sec. 31, T5N, RllW, S.M. 520' S & 2880' E of NW corner of Sec. 6, T4N, Rl lW, S.M. 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME ~ -.~ K~NAI DEEP UNIT ': 9. WELL NO. . KDU #5 (31-6) · - 10. FIELD AND POOL, OR WILDC.~T . '.. KFNAT GAg FTEL_n . ,:,,,,:.., 1 l. SEC. T. R. M. (BOTTOM HOLE ' _" OBJECTIVE) Sec. 6, T4N, RllW, S.M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISH1NG JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 9/1/78 2536' TD 929' Footage 20"@ 97' 13 3/8"@2521' 9/2/78 2536' TD O' Footage 20" @97' 13 3/8"@2521 ' TIH w/ 17 1/2" Bit #3 on follow-up BHA #7. Drilled 17 1/2" hole from 1607' to 1969'. Hole angle & direction as desired. POOH. Picked up locked BHA #8 & RR bit #3 - TIH. Drlg. 17 1/2" hole from 1969 to 2536'.upCirc. & cond. mud. Made short trip - circ. BTMS - POOH No correction on S.L.M. Depth 2536'. Rigged up to run 13 3/8" 61# K-55 Butt Casing. Completed running 65 its. 13 3/8" 61# K-55 Buttress casing & landed w/shoe @2521'. R.D. csg. tools & crew. Ran Baker stab-in tool on 5" D.P. & located on stab-in collar @2477' Circ. 13 3/8" annulus w/mud - OK. Pumped 50 b~ls water - mixed 2000 sxs. CL "G" cmt. w/2% Prehydrated gel & 2% CACL2 in mixing water. Started mixing cmt. @6:00 A.M. - Got good cmt. returns to surface w/3264 cu. ft. of cmt. slurry pumped. Mixed 200 sxs C1 "G" neat w/ 2% CACL2 & displaced to float collar @2477 w/ 34 bbls of mud. Cmt. mixed @7:20 P.M. 1 hr. 20 min. total mixing time. Cmt. in place @7:30 A.M. Waited on cement 11 hrs. until 6:00 P.M. While cleaning cement out of cellar & mud system. General rig- up operations. Cut off. 20" Conductor & 13 3/8" surface casing. Installed O.T.C. 13 5/8" 5M x S.O.W. 20" casing head spool. Installed 13 5/8" 5M Pipe Rams 13 3/8" 5M . Drilling spool w/ choke & Kill Lines, 13 5/8" 6M Pipe rams & 13 5/8" 5M blind rams plus 13 5/8" 5M annular B.O.P. 14. I hereby c~r~y that the f~s tr~te~and corre~.t SIGNED~/~'~(-~-~-~--~~F'~ TITLE DIST. DRILLING SUPT. DATE 10/20/78 NOT port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. 10 11 12 13 9/3/78 9/4/78 9/5/78 9/6/78 9/7/78 9/8/78 9/9/78 9/10/78 2718' TD 182' Footage 20" @97' 13 3/8"@2521 ' 3345' TD 627' Footage 20" @97' 13 3/8"@2521 ' 5050' TD 1705' ETD 20" @97' 13 3/8"@2521 ' 5562' TD 512' Footage 20" @97' 13 3/8"@2521' 5996' TD 434' Footage 20" @97' 13 3/8"@2521 ' 6699' TD 703' Footage 20" @97' 1 3 3/8"@2521 ' 7331' TD 632' Footage 20" @ 97' 13 3/8"@2521' 7765' TD 434' Footage 20" @97' 13 3/8"@2521' Completed installing 13 5/8" csg. Head. Spool & 13 5/8" BOPE. Tested BOPE - Rams to 3000 psi w/water-annular to 3000 psi - choke & kill lines plus manifold to 5000 psi - all tests witnessed & approved by Ken Baker - USGS rep. Completed testing @ 2:30 P.M. Picked up 12 1/4 bit #4 on BHA #9 - TIH tagged F.C. @2473' DPM (2477 csg. meas.) Tested 13 3/8" csg. & BTM pipe rams to 2500 psi- OK. Drlg. F.C. & firm cmt. to F.S. @2517' DPM C.O. O.H. to 2534 DPM - (Old DPM Meas. 2536) Tested FM & csg. seat w/ 420 psi over 69#/ C.F. fluid w/ equiv, to 93#/ C.F. - held ok. Drilled 12 1/4" directional hole to 2718'. Drilled 12 1/4" directional hole w/bit #4 on BHA #9 from 2718' to 3155'. Hole angle holding as desired not getting any right hand turn as anticipated. POOH. Picked up 12 1/4" bit #5 on Dyna-Drill @ 3155' for maximum right hand turn. Dyna-Drilled from 3155' to 3345' POOH w/ Dyna-Drill run #3 @ 3345'. TIH w/ 12 1}4" bit #6 on BHA #11 (Follow-UP Assy.) Finished TIH w/ Follow-UP Assembly (BHA #11) Drilled 12 1/4" hole from 3345' to 3839' - POOH w/bit #6 TIH w/ bit #7 on packed hole assembly (BHA #12) Drilled 12 1/4" hole from 3839' to 5050'. Drlg. 12 1/4" directional hole w/locked BHA #12 to 5090'. POOH w/ bit #7. Picked up Bit #8 on angle dropping Assembly - BHA #13. TIH. Fanning BTM & Drlg light to drop angle as per program. Drl§ to 5551' - Dropping angle from 36° to 25° - Looking for coring point in top of Beluga Sand - Circ. breaks to surface. POOH @5551' w/ bit #8. Picked up 8 1/2" CDP Diamond Corhead on 6 3/4" core barrel (BHA #14). TIH C.O. to TD @5551' - Started coring 8 1/2" hole @5551' @10:45 P.M. Completed coring from 5551' to 5581'. POOH w/core barrel. RIH w/ 12 1/4" bit #9 on angle dropping BHA #15. Reamed from 5551' to 5581, Drilled to 5996'. Dropped angle from 21 1/2° to 17°. POOH for BHA change. POOH RIH w/ BHA #16 & bit #10. Drld'd 12 1/4" hole f/5996' to 6699'. POOH. RIH BHA #16 & bit #11. Drilled 12 1/4" hole from 6699' to 7331'. Drilled 12 1/4" Hole from 7331' to 7354' POOH RIH w/ BHA #16 bit #12. Drilled from 73~4' to 7765'. 14 15 16 17 18 19 20 21 9/11/78 9/12/78 9/13/78 9/14/78 9/15/78 9/16/78 9/17/78 9/18/78 8190' TD 425' Footage 20" @97' 13 3/8"@2521' 8430' TD 240' Footage 20" @97' 13 3/8"@2521' 8808' TD 378' Footage 13 3/8"@2521 ' 20" @97' 9127' TD 319' Footage 20" @97' 13 3/8"@2521 ' 9479' TD 352' Footage 20" @97' 13 3/8"@2521' 9706' TD 352' Footage 20" @97' 13 3/8"@2521 ' 9835' TD 129' Footage 20" @97' 13 3/8"@2521' 9887' TD 20" @97' 13 3/8"@2521' Drilling 12 1/4" hole f/7765' to 7818'. POOH. Tested BOPE. RIH w/ bit #13 & BHA #17 Drilling 12 1/4" hole f/7818' to 8190'. Drilled 12 1/4" hole w/ bit #13 on BHA #17 ( Angle Dropping Assembly) Normal background gas to unit. Had drilling break in sand 8115' to 8165' gas units increased to 100. Drilling sand & coal stringers. Gas units increased to 600-700 & peaking @1000 units (Saturation on machine) by 8300'. Increased mud wt. to 72#/cf & drilling 8430' - Mud still gas cut & carrying 600 units w/ 72# mud. Inc. mud wt. to 74#/cf mud gas cut to 72#/cf & carrying 450-500 units. Inc. mud wt. to 76#/cf & circ. round. Gas units dropped to 50 units - POOH - Hole cord. good (Survey @8407' - 16° S58E) Picked up bit #14 on BHA #17 & TIH. Completed TIH w/ 12 1/4" bit #14 on BHA #17. (BTMS UP after trip. Gas cut from 78# 12 1/4" hole from 8430' to 8808'. Mud system carrying 75 to 250 units of background gas while drilling. POOH. Picked up 12 1/4" bit #15 on BHA #17 - TIH - Drilled 12 1/4" hole form 8808' to 9127' Background gas 50 to 150 units. Dropped survey & PO0~. Survey @9104' - 13 1/2° S15E. Pikced up 12 1/4" bit #16 on BHA #17. TIH. Drilled 12 1/4" hole from 9127' to 9479'. Dropped Survey & POOH w/bit #15 on BHA #17. Ran 12 1/4" bit #17 on BHA #17. Drilled 12 1/4" hole from 9479'. Survey & POOH w/bit #16 on BHA #17. Ran 12 1/4" bit #18 on BHA #17. Drilled to 9706'. Drilled 12 1/4" hole from 9706' to 9750' POOH. w/ bit #18 on BHA #17. TIH w/ 12 1/4" bit #19 on BHA #17. Drilled & circ. up breaks looking for D-2 sand and coring point. Top of D-2 sand encountered @+9830' Gas units inc. to 400 on BTMS UP. Drilled t~- 9835;. Inc. Mud wt. to 80#/cf to reduce back- ground gas to +130 -150 units. POOH w/ bit #19 on BHA #17. Drilled to 9847' @ Core barrel, POOH. Layed down 12' Core. TIH @BHA #19, Bit #20, washed 100'. Reamed rat hole, drilled to 9887'. Dropped survey & POOH @9'00 P.M. TIH w/8 1/2" CDP corhead on #1 RR #1 on 6 3/4" core barrel on BHA #18. Cored D-2 Sand from 9835' to 9847'. Core barrel jammed @ 9847' - POOH. Recovered 12' of core. 22 23 24 25 26 27 28 9/19/78 9/20/78 9/31/78 9/22/78 9/23/78 9/24/78 9/25/78 9917' TD 9898' ETD 20" @97' 13 3/8"@2521' 10,130' TD 20" @97' 13 3/8"@2512' 10,331 ' TD 20" @97' 1 3 3/8"@2521 ' 10,502' TD 20" @97' 13 3/8"@2521' 10,502' TD 20"@ 97' 13 3/8"@ 2521' 80 PCF 60 SEC 10,502' TD 20" @97' 13 3/8 @2521' 10,502' TD 20" @97' 13 3/8" @2521' POOH @l:O0 A.M. Picked up BHA #20 @ 8 1/2" core bit #1 RR #2 TIH started coring @ 4' 50 A.M. @9887' Cored 30' of D-2 Sands to 9917' @ 3-30 P.M. Coring A~eraged 2.8'/hr. POOH @ 4:00 P.M. P.U. 12 1/4" bit #21 on BHA #21. TIH. Washed & reamed to 9807'. Opened 8 1/2" core hole to 12 1/4"- from 9887' to 9898'. 11'- 2 1/4"hrs. Reamed 8 1/2" core hole to 12 1/4" from 9898' to 9917'. Drilled 12 1/4" hole w/ bit #21 on BHA #21 from 9917' to 10,063'. POOH. PU bit #22 on BHA #21. TIH. Drilled 12 1/4" hole from 10,063' to 10,130'. Drilled 12 1/4" hole from lO,130' to 10,247' - Dropped survey & POOH w/ bit #22 on BHA #21. PU 12 1/4" bit #23 on BHA #21 TIH Drilled 12 1/4" hole from 10,247' to 10,331'. NOTE: Hole condition deteriorating & forming keyseats due to excessive wt. & hang down below angle drop off. Drilled 12 1/4" hole directionally w/ bit #23 on BHA #21 from 10,331' to 10,367' Bit trip - Hole condition good. Drilled 12 1/4" hole w/~it #24 on BHA #21 from 10,367' to below D-5 sand - Final TD of well 10,502'. Reached @8'30 P.M. 9/22/78. Circ. BTMS UP Cond. mud to log well. POOH. Hole cond good. Rigged up Schlumberger - TIH w/ Sonde. Schlumberger checke driller TD of 10,502' @ 10,494' W.L.M. Logged as follows: DIL - S.P.- GR 10,488 -2520 CNL - FDC 10,440' - 2520' BHC - Sonic 10,488' - 2520' Made conditioning trip w/ 12 1/4" bit #24 RR, Prior to running repeat formation tester. Hole condition good. R.U. Schlumberger. RAn repeat formation tester and set tool @ 10,443' to test D-5 sand. Recorded 5352 PSI HYdrostatic head N 80#/C.F. mud - OK. Recorded D-5 sand pressure #2178' PSI - Released tool. Unable to pull tool free. Cut Schlumberger line & stripped. Continued stripping over wireline w/D.P. & overshot drill pipe continously differentially sticking- stripped over wire to 10,114 - Schlumberger unable to keep tension pulled on line w/o parting W.L Schlumberger released brake on W.L. unit & lost location on quick connect. Tied onto W.L. with T-Bar- Pulled maximum on W.L. - Unable to pull tool free - unable to slack off D.P. POOH w/ D.P. & overshot- wireline clamped to D.P. Recovered approx. 10,200' of W.L. in D.P. - left Schlumberger, repeat formation tester and approx. 250' of W.L. in hole. Tested BOPE to UOCO Spec. excepting Hydril & Blind Rams (test pump failed) All test witnessed & Approved by Ken Baker w/ USGS Picked up wireline spear w/ 10" OlD. wireline. Stop on 5" HWDP. 29 3O 31 32 33 9/26/78 9/27/78 9/28/78 9/29/78 9/30/78 10,502' TD 20" @97' 13 3/8"@2521 ' 10,502' TD 20" @97' 13 3/8"@2521 ' 10,502' TD 20" @97' 13 3/8" @2521' 10,502' TD 6512' ETD 20" @97' 13 3/8"@2521 ' 10,502' TD 10,350' ETD 20" @97' 13 3/8"@2521' TIH w/ W.L. spear & 10" spear on DP to bridge @9063'. Unable to wash down or rotate past bridge @9063'. Circ. cond. mud. POOH w/W.L, spear and W.L. stop - no recovery. PU bit #24 RR on 1 std. 8" SDC TIH. Washed & reamed through coal & bridges and hole restriction due to mud cake buildup from 9063' to 9366'. Broke long jaw on B.J. type DB breakout rotary tongs. Recieved tong part from monopod- made repairs to low-drum clutch - Completed rig repairs @5:00 A.M. Washed & reamed bridges in hole from 9366' to 9850'. NOTE: Hole damaged from wireline strip-over operations & not circulated for over 72 hrs. Broke through bridges @9850' - Washed down w/o reaming from 9850' to 10,447'. Unable to work below 10,447- (Wireline & Schlumberger tool below bit). Made 14 std. wiper trip - Hole cond. good - circ. BTMS up & cond. mud . POOH - Made up Howco Shifting Tools. Completed running 9 5/8" casing as per attached casing detail.4,,Landed/ 9 5/8" casing # 10,417'. Circ. 9 5/8" x 12 1 annul us until hole clean. Cemented BTM. stage with 2000 sxs Class "G" w/.75% CFR-2, .5% Halad 22-A & .3% KCL mixed @ll8#/cf. Displaced shut off plug to landing collar @ 10,320' w/757 bbls mud. Bumped plug with 2750 psi- Float equip - held OK. CIP @6:40 P.M. Dropped opening Bomb to open ports in D.V. Tool @6512'. Bomb took 2 hrs. 5 mi ns. to seat. Opened ports in D.V. Tool, circ. 50 bbls fluid out D.V. Tool & lost return circ. @800 psi. Discontinued efforts to cement 2nd stage on 9 5/8" csg. Set Howco RBP @ 937'. Remove 13 5/8" BOPE. Hung off 9 5/8" casing on slips w/200,O00 pounds weight. Installed O.C.T. 13 5/8" 5M x 10" 5M tubing head & tested to 5000 psi. Installed 13 5/8" 5M BOPE & tested to 5000 psi. Retrieved Howco 9 5/8" RBP @937'. TIH w/ 8 1/2" bit & 3-6 1/4" D.C. - Unable to close ports in D.V. Tool @6512' w/ 12 1/4" bit. ? Drilled out D.V. Tool @6512' w/ 12 1/4" bit & C.O. to plug catcher @ 10,320'. Lost returns to D.V. Tool ports. POOH. Ran 9 5/8" Howco cmt. retainer & set @6469' to to squeeze D.V. Tool @6512'. Broke down FM w/lO00 psi @ 12CFM. Mixed 200 sxs gel cmt. followed by 300 sxs "G" w/3% CACL2. Held 1300 psi with out pumps after 10 mins. C.I.P. @ 3'05 P.M. Left 1300 psi trapped below retainer @6469'. Reversed out 4 bbls cmt. POOH. Ran 8 1/2" bit on BHA #23. N.LATITUDE W.LONGITUDE ASP COORDINATES,ZONE 4 Y (NORTHING) . 'X(EASTING). KDU-5 KDU-6 SE COR. · CERTIFICATE 60028, 14" 151 *07 ' 11" OF SURVEY OR.. 60028'20.815'' 151016'31.966" 2,366,837.91 t' 60°28'22.275'' 151°16'32.417'' 2,366,996.'72 269,846.39 269,826.86/: GLO Township Plat .Record S.E. CDr. S36, T5N,RllW I heret~ certify that I am properly regist~_red and licensed to practice land surveying in the .State of Alaska .c-~1 that this plat represents a location survey made by me or under my super~ vision, and that all dimensions and other details . ' July 20t 1978 ~ OF dq.d',~",T,' Divisionof O,l' ,~,~,-1 ~.,~ Cm'~rv-~'"~;_, ' ~0. 953;-$ _-, ~'~' rSCALE: |"l I MILE SHEET I OF AS STAKED a KDU-6' .LOCATED I1%1 SE 114 , $EC. 31 RllW SEWARD .ERIOIAN Surveyed for UNION OIL COMPANY. OF CALIFORNIA Surveyed by Bell, Herring and Associates ENGINEERS AND LAND SURVEYORS 80]. West Fireweed, Suite ].02 ANCHORAGE, ALASKA 99503 Center I/,% Car. Sec. South I/`% Car. Sec. :51 KDU-5 KDU-6 SE COR. N.LATITUDE W.LONGITUDE 60°28'20.815'' 151°16'31.966'' 60028'22.375" 151°16'32.417" East I/4 Cor.~Sec. 31 .....,,,~ ASP COORDINATES, ZONE 4. Y (NORTHING) X(EASTING.) 60°28' 14'' 151 °07' il" 2,366,'837.91 269,846.39 . · 2,366,996.72 269,826.86 GLO Township Plat Record S.E. Cor. S36,TSN,RllW -%¸ KDU-6 PAD ELEV. 72.2 . 1745.0' 1719.8' ~KDU- 5 PAD ELEV. 72.2 .... Eost i$06.47, 'ch I 6 AUG i 8 i978 1606.44' GLO CERTIFICATE OF SURVEYOR.' I hereby certify that I am. properly registered and licensed to practice land surveying in the -State of Alaska and that this 'plat represents a location survey made by me or under my super~ '31. LEGEND GLO Monument Gas Well Location Rebc~r Set, 50' R.P. vision, ar~ that all dimensions .and other details ar.e oorrect. July 20, 1978 SCALE= I"= 500Ft. SHEET 2 OF 2 · . ..... : ~ AS STAKED . ,_~,,~ .,~,. J KD U_L~5 ~5 . K D U - 6' ' ~~'- o ~, ~z'~t m '" '- :LOCATE D IN ~~.' ~ ~'~. .... . ....................... /gW~~. ~~ %~ j UNION OIL COMPANY. ~.*~~~, ~e~..~,5 j . OF CALIFORNIA I ~'~/~:.. ,.L~ J Bell, Herring and Ass~ates 't t'/~';f" ""*'~%~ ~ ENGINEERS AN D ~ND SURVEYORS Robert T. Anderson District Land Manager union August 17, 1978 Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Union Oil and Gas i;~,~ Western Region Union Oil Company ot CalifOrnia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex: 90-25188 i ,~ "-1'--i ..... 1 ....... s~:cL_L_ ...... Attention: Hoyle Hamilton United States Geological Survey P.O. Box 259 Anchorage, Alaska 99501 Attention: Rodney Smith KENAI UNIT State of Alaska~ Drilling Permit{- KDU 5~ KDU 6 Gentlemen: Reference is made to the above Drilling Permits. The location survey plat previously furnished you contained a minor typographical error on sheet 1, referring to TllN, R5W instead of the proper T5N, RllW. We attach 6 corrected copies of said plat for you records. WR/mb enclosures Very truly yours ~ndma~ 78.,55 oil ~ac]~., ~ 99502 ~otlutim of any wa~rs of t~ $~a~ is ~~d by ~S 46, ~ 03, Article 7 and the ~~s ~xumul~a~ thereunder (Title 18, ~/aska a~~crati~ ~, ~ 70) an~ by ~ Fedmml Wa~r Pollutim ~ by a repre~%~ of the ~t of E~vi%~%~l (k~sezTatic~. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska De~ex~t of ~ is being notified of the is~ of this pe~t to drill. ~ed so that a reparative of the Divisic~ may be present to witness ~ of blowout ~ter equipment before surf~ casing shoe is drilled. -2- Ju].y ].2, ].978 Very truly l~oyle H. ~ltcm De%oaztm~t of ~ ~ ~, ~~at Secti(m w/o eric1. Di~ w/o ~. Form 10-401 ' REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TR~ .ATE (Other instructions on reverse side) PERMIT TO DRILL OR DEEPEN DRILL ~ DEEPEN r-'l b. TYPE OF WELL OIL GAS SINGLE WELL [~] WELL [] OTHER ZONE ~-~ MULTIPLE ZONE 2. NAME OF OPERATOR Union: Oil Company of California 3. ADDRESS OF OPERATOR P. O. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL 41~sv~ce& 2100'W of SE corner of Sec. 31, T5N, RllW, S.M. API No. 50-133-20319 6. LEASE DESIGNATION AND SERIAL NO. A-028142 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Kenai Deep Unit 9. WELL NO. KDU #5 (31-6) 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field Af proposed prod. zone 520'S & 2880'E of NW corner of 'Sec. 6, T4N, RllW, S.M. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 14. BOND INFORMATION: TYPE Surety and/or No. Amount 15. DISTANCE FROM PROPOSED * 16. No. OF ACRES IN LEASE 17. NO.ACRES ASSIGNED LOCATION TO NEAREST TO THIS WELL PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T4N, RllW, S.M. 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 19. PROPOSED DEPTH 10,750' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 88' KB above MSL 23. PROPOSED CASING AND CEMENTING PROGRAM 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START duly~ 1978 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 20" 94# H-40 _+lO0' Driven to Refusal 17 1/2" 13 3/8" 61# K-55 +2500' 1380 sx 12 1/4" 9 5/8" 47# N-RO & +10.530' 3460 sx. S-95 See Attached Plan of Procedure IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive 'zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout ~reventer program. (This space for State office use) y CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED I MUD LOG OTHER REQUIREMENTS: [],,~s SXNO [ [] YES .q NO DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE [X~s [] NO 50--133--20319 ~TLE 6/30/78 PERMIT NO. 78-55 APPROVAL DATE APPOVED BY TITLE Chairman *See Instruction On Reverse Side July 12, 1978 DATE July 12, 1978 PERMIT TO DRILL Page 2 PLAN OF PROCEDURE' · 3. 4. 5. 6. 7. 8. 9. Move in and rig up Brinkerhoff Rig #43. Drive 20" casing to refusal @+lO0'. Drill 17 1/2" directional hole to +_2500'. Run and cement 13 3/8" casing @+_2500'. Drill 12 1/4" directional hOle to +__10,530'. Run electric logs. Run and cement 9 5/8" casing @+__10,530'. Test & evaluate Tyonek & Beluga Sands. Complete well as justified by logs and testing. DRILLING AND EVALUATION TIME:~ 82 days KU- 33 - 32 ,.J_, .....,L. TMD 5232 U-M KU- 34-31 . T D 5809 ' .. '"'- ---,. T/BELUGA "-':"%: '-~--"~z 5365' MD ~'"~..."~'"'~"~-,L"~,.~ I ~47~5' v~ '- ~' '~~~ T/D-2 SAN D ":" M '~" o~ ~9705' MD ............. -.. ~ ~. U - '" TMD 4459 "' ~.K U-21-6 ( BHL: TM9 56BZ ~ ~'30' TMD ~ 9,760 TVD " KU- 2_ I - § '~,.' Thio 11,§18.~ · o U-M KDU-! ~...~__ T MD ':~895 0 500 I000 FEET U-M KU-43-6 --~.. T M D 57015 U-M , KU-43-6A !" -~TMD 5300 KENAI GAS FIELD. PROPOSED WELL LOCATION KDU-5 (31 - 6 ) ,_ Alaska District T z~ N 'L 2.0" MSP 2.000 C~ll~r Pa4 L~I ?HECK I~L,VE G~TE OR · Iii _ , M/GL ED t'ILL UP LIf,"E PiPE RA..'dS I · : : - . STANDARD ~_ PREV£:tTER ASSE, C!.~LY · [ - ii i _ , .,""~ ~-~ PIPE ' D,~,~. , . ,~1 ~ . .... +'r~ ....'~ ~-.-~ .... ~-~"o .... ALL CHANGES h~UST HAVE WRITTEN ' " ~%~ tS~ J APPROVAL. BY. THE DISTRICT ~SG 'J DRILLING SUPERINTENDENT. £OSITIVE CHOKE ADdUS T/,£LF CHOKE · · ALL CHANGES MUST HAVE ¥,'RITTEN APPROVAL BY' THE DISTRICT . DRILLING SUPER;hlTENDENT. · .. e. . , ../ l. fl4'll,,/U//, STAKDIRO (HOKE t,!.4I,'IFOLD .4$SEI,!~LY ' · · o' OIAWN ~ D (.AD.. , ~CAt[ None · · · · % CASING STRING ~ ~/8 // ~7~ COUNTY~ /~/~/-~// . STATE /~Z/~/~ ,, DATE' ~-~-'7~ , D~IGN BY ~.~ . _ / 3;. HYD. GR. II psi/ft. :~.S.P. CASING SIZE ~'~% HOLE SIZE /p //5//' ~ WT. I ~~.~ HYD GR. i / ~' ~si/ft. MUD ~T. II v/.g., IFfERVAL LE AI~TH. DESCRIPTION ',~IGHT TENSION 5-~NI. Mb~4 TDF COLLAPSE COLLAPSE CDF BURST !ET£RU~%L W/ BP -top of STRENGT~K PRESS. ~ Bw-SIST. ~ PRESSURE Bottom Top Wt. ' Grade Thread W/O BF~ sectio~ TENSION bottom tensio~ YIELD lbs lbs 1000 lbs psi psi psi psi · PR!~ PER P~. COSl Y=Tensile Lpad/Pipe Yield Strength Formulae: Collapse resistance in tension = X (Collapse pressure ratify) Burst Pressure = }raP + I~p~,h ( ~ya. Or. II --.~) BF (Bouyancy Fac%or) = 1.00 - (o.ol~3 x ~u~ wt. ~) Calculations: '1~ ~$o..o _ Totai Ccst Union Oil and Gas Di,"~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex' 90~25188 union Robert T. Anderson District Land Manager Sune 2.9, 1978 Mr. O. K. Gilbreth Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 KENAI UNIT State'of Alaska Application to Drill KDU #5 and KDU #6, NTL-6 Dear Mr. Gilbreth: Union Oil Company as Operator of the Kenai Unit has made Application for Drilling Permit for KDU #5 and KDU #6 development wells under separate transmittal. In compliance to NTL-6, this is to advise you that both wells will be drilled from the existing KU #34-31 surface location site from existing facilities and no new surface location will be required. Reference is made to our Kenai Unit Facility Map previously furnished you. The KDU #5 bottom hOle target underlies Federal Lease No. A-028142 and the KDU #6 bottom hole target underlies Federal Lease No. A-028055. We respectively request your waiver of the 30 day application approval period and request your approval of. the aforementioned Drilling Permits at your earliest opportunity. WR/sk Enclosures Very truly yours, Robert T. Anderson cc: DMEM, Director Marathon Oil Company-Morrie Lowman RECEIVED ~Jivi~to~ gf Oil ~l~d (~as C'on~orVallon Union Oil and Gas Divi,,""'~: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 Telex: 90-25188 union Robert T. Anderson District Land Manager June 27, 1978 Mr. O. K. Gilbreth Division of Oil and Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 KENAI DEEP UNIT State of Alaska Permits to Drill KDU #5 & #6 Kenai Gas Field' Dear Mr. Gilbreth: Enclosed is our Check No. 18806 in the amount of $200.00 to cover the required filing fees for KDU #5 and KDU #6 Permits to Drill. WR/sk Enclosure cc: Mr. Rodney Smith-U.S.G.S. ~dm~~am~oVery truly ~z~y Union Oil and Gas Di'?%~n: Western Region Union Oil Company of California ~-- P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 Telex: 90-25188 uni n Robert T. Anderson District Land Manager June 23, 1978 Mr. Rodney Smith U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99501 KENAI DEEP UNIT State of Alaska Permits to Drill KDU '#5 & #6 Kenai Gas Field Dear Mr. Smith:. Enclosed for your approval are three (3) copies each of the Permit to Drill Kenai Deep Unit wells #5 and #6. Also enclosed is our Check No. 18806 in the amount of $200.00 to cover the required filing fees. Please return an approved .copy to this office for our further handling. RTA/sk Enclosures . cc: Mr. O. K. Gilbreth/ Very truly yours, RECEIVED JUI £ 8 I 78 l?.':'iSion of Oil ~nd Gas Ail, cl~o~;~;~ C°naervation Forl~a,9-331 C /~'~ SUBMIT IN Tt~CATE* (May 1963) (Other instruct,ohS on ' UNITED STATES reverse side) DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL ~ WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of Calif. DEEPEN I-1 PLUG BACK I-1 ZONE ZONE · 3.ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage, AK 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* ) At surface 415'N & 2100'W of SE corner of Sec. 31, T5N, RllW, S.M. At Proposed prod. zone 520!-S & 2880'E of NW corner of Sec. 6, T4N, Rl lW, S.M. Form approved. Budget Bureau No. 42-R1425. LEASE DESIGNATION AND SERIAL NO. A-028142 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7: UNIT AGREEMENT NAME ,~ Kenai Deep Unit 8. FARM OR LEASE NAME .: 9. WELL NO. KDU #5 (31-6) 10. FIELD AND POOL, OR WILDCAT Kenai Gas Field 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA sec. 6, T4N, Rl lW, S.M. 14.DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. COUNTY OR PARISH I13. STATE 1{~. DISTANCE ]'ROM PROPOSEDs 16.NO.OF ACRES IN LEASE 17.NO. OF ACRES ASSIGNED '. LOCATION TO NEAREST TO THIS WELL - .. PROPERTY OR LEASE LINE, FT. --: ".. .. '~' " " '~- (Also to nearest drlg. unit line, if any} 18. DISTANCE FROM PROPOSED LOCATIONs 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS TO NEAREST WELL, DRILLING, COMPLETED, '- OE APPLIED FOB, ON THIS I~4~SE, FT. l 0,750' Rotary ~'~ 21. ELEVATIONS (Show whether I)F, RT, GR, etc.) I ,22. APPROX. DATE WORK WILL START* 88' KB above MSL ~ '~'I ~ july, .:1978 ''~ 23. PROPOSED CASING AND CEMENTING PROGRAM ~" ~". :-' .: .,,~'-.. ,'"".., :: '~[ ~.'. ,"~ · SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMENT · · +100' ' 17 1/2" 12 1/4" 20" 13 3/8" 9 5/8" 94# 61# 47# See Attached Plan of Procedure +?6NN' +10,530' IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive ~one and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. ,~ .... :: , ', ,~-~- ~! ~. .... _r: .... ' ~.. SIONED LE District Land Mgr, ' ""-DATE : 6/23/78 (This space for Federal or State office use) .'!' " PERMIT NO. APPROVAL DATE . ~' ' ~ DATE ': ' f APPROVED BY TITLE *See Instructions On Reverse Side PERMIT TO DRILL Page 2 PLAN OF PROCEDURE' · 2. 3. 4. 5. 6. 7. 8. 9. Move in and rig up Brinkerhoff Rig #43. Drive 20" casing to refusal @+lO0' Drill 17 1/2" directional hol~ to ~2500'. Run and cement 13 3/8" casing @+2500'. Drill 12 1'/4" directional hole To +10,530'. Run electric logs. Run and cement 9 5/8" casing @+10,530'. Test & evaluate Tyonek & Beluga Sands. Complete well as justified by logs and testing. DRILLING AND EVALUATION TIME' 82 days RECEIVED 2 8 1978 D?,.'isJori of Oil and Gas Conservation Anchorage U-M -~T M D 645~ \. \, \ KU- 33 - 32 TMD 5232 ',,, 32 U-M KU-34-31 ..: T D 5809 ' ' '"'" "~_'t~ ~ T/BELU GA '""~"'~ .~ 5365' MD "'"'~"~.._ I +-4775' VD 'I~:~ "~.~ '~, T/D-2 SAND N . M ~'--. o.~ +9705' MD ~~. U- '"" ~ ~ ;o~,' ,,~ %~ KU- 11-6 "'~ U'~ ' ~=~ ~~MD4459 "-~KU-21-6 -o~0 ~ 5 (31-6) ~" BHL: TMD 5682 t10,530' TMD ~ 9~760' TV D R'lgW U-M KDU-I ~..~.'__ rMD '~895 T 5 U-M ~, KU- 21-5 ~ TMD I 1~518 RECEIVED JU/~ 2 8 U-M · _~:~.KU- 43g~/sion at Oil and Gas TMD 5706 A~ch0rm:i~ I U-M 5300 Alaska District KENAI GAS FIELD. PROPOSED WELL LOCATION KDU-5 (51 - 6 ) · T 4 N T#£ ou '~ H ~ UN ~WD L il 20" /qSP ~0" Z C¢lhr 2.0" 200o p~Z NVdr,'i ,SOU) L~vel JUN 2 8 1978 D;vision of Oil and Gas Conservation Anchor~,~e ! i as' CHECK, ,..,.v ~' : V£ 6~. z C,:? LO-TO£~' · " AI,'GLED FILL UP Lll,"E // ! · o PiPE · · HYDRAULIC O~E~7~TE~ V/, L VE ...... . ....... ,.:. ~, :,-~_ / '- · NGA~ vALVE e _~ .~ ~,-' . -'- ~,~ ..'~,,,x · ' ~~ JU/J 28 ~978 ~_..,,. ,. n:,,,~io, o~ i~ ~ ,,, · ~_~.~ ~ .... _[_~ ',, ~~~ T ~' ~o, ...... '"'~'-'~ ' ~-~ ' · · / ALL CHANGES h~UST HAVE WRITTEN ~k~ t~ ~ APPROVAL BY. THE DISTRICT ~ ,'~ DRILLIMG SUPERINTE~.~DE~T. , O~w~ ~ . ~ zO ~ · · ~'~ H B I. IUX/L IA £Y CHO~£ · · . · . .. ' · 0/7 HOME MA~E ~£GA$$E/~ · . · . · ": . . . . '. . · o.-e,-- · Z..P. VALVE "' L.P. VALVES..._._.... POSI,VVE CHOKE ADJUS?,4£LF CHOKE · e .o. · , · . · . · · : · · · ALL CHANGES MUST HAVE V,1RITTEN APPROVAL BY' THE DISTRICT DRILLING SUPER;NTENDENT, · · · , /.f/fi/1A!U/,! STA/,'D~RD ~HOkT I../XI,'IFOLD · ,i,· CASING AND ~TJBINO DESIGN INTERVAL LEA~TH.. DESCRIPTION ',WIGHT TENSION ~N!-.Mb~4 TDF COLLAPSE COLLAPSE CDF BUPBT !ETERU~AL BDF W/BP _ -top of STItENG~K PRESS. @ P~S!ST. ~ PRESSUltE 1-ff~N~JI~ Bottom Top Wt. Grade Thread W/O BP>( section TEh~ION bottom tensioa YIELD lbs lbs 1000 lbs psi psi psi psi PER .. -~ ~ L. oad/Pipe Yield Y-Gens.lc Strength o, , ,. . :::.:..: ::.:.,~.:..:,:...~:,:::.~,.,..,,:,~.,;i:,-..., , ,~' m I .... , ..':T. ........ . ........ ~"--7~.'T*"T ,..'T'.~-.. ' ... · ,~ ~. , ....... ~.,I.,..,,...~l ...... ,,..I ..... F/',.~ ':':::'~ o ' .2!::::;'::"';":: F:t:",:'":'":::: '::':i:" :!.":.'/~ J;::;i.::';I:';U";' .':,"~ ..... J.,;"' ;~".1' 'i"t L'i.i:..:'~' ............ ,...'~:.~:l'::'.Ji:",'ii,.'.::l,.".l: f'iii':.il I '"'L2~. ........ "1"'"~1 .... -' · '"" V.~_t2.:2.'.4 ~'> '"' ' ,.l.:::,::...,=._!:-:..l::::,.~:::.!,i,..:,:/. 5":'::: ~~,,~ .'.~:',.' ~ ,,~' I':: i:."..l:--::.::::'.l::,:t: :",'.~ m m , I:.:.::'~:;J::'.;:.:::l:.':::..'!i:l:l; ~:t':l'.l;:il:':;I :::., , ~ ,..... ,:::;t.,:,,,,. ,;,..~,--'-*-..-':~.,~-'-~;-,'-:''.~ ' ~" m ,.1:.'.:,::::. :.':::':l: r:l°!::l:':':';(,: ;:r::..l~,:l!:riI ' : · ~ 4) ,.~l ....... I ..... I .... ! ...... ./I''~ ...... '"' .... "' ..,.'' ,.:'-: :.:.-.ir:: ::;'. ;::' .:.'.: .:.:.1. ::, :'-'-r. ........... I .... ,,:,.., *~ .... ~ ~.'-,, ,~, :i.:.:: a,o .or .. ..... ,~..:...,~,:, ...... I ..... ,..:1 .... ! ..... I "e 0 e~ .,., ....... ~.,, ...,..,_. , . ,...i.i .~.1.,. ,.,. I I'~:::!:::.'l.'~:. J .... , ':.:.::: ~1 ~:; 1. i .%',; i.':.,.~.;' :: ,~~ j .' ~ :?. · ..,.*. ~ ..t. · .,, J , ,. [.. ,.~ , ,..~ o.,.;I ~ , .... .~:...., ...... ,, ..... ,.,~.,...,., .... Forraulae: Collapse resistance ~n tension X (Collapse pressure ratir~;) ~u,~st Pressure = ~mP + Depth ( aya. 6r. II --.~) ItF (Bouyancy Fac'tot) = 1.00- (0.0153 X Mud Wt. I) . Calculations: To~.L Cost T 5 N -~~D 27°0 R. II W. U-M K U_ 21X_.=,,'--, ~645 k. KU- 33 - 32 TMD 5232 T 5 N U-M KU-34-31 , T D 5809 ~ -"~--~z~ T/BELUGA ',,~ ",'-.-.~..~.~ ~, ~,~ 5365' MD , , % . ~ ~,.._ I +-4775' VD "~ "'"-..'~-~'~ T/D-2 SAND -,-,.._. o~ +9705' MD U-M '~-- ~ ~ , ~.,. ~u-,,-~ --< ~_~-~t~ v~Du ~TMD 4459 -"~KU-21-6 ~0 BHL: 5 (31-6) TMD 5682 ~10,530' TMD ~ 9,760' T V D KU- 2I- 5't~';~% TMD 11,518 T 4 ULM KBU-I .~...~ TMD' 9895 U- M ~ o 500 ~ooo Ku-,,~-~~~ ' I ---~"i-~-'W- ........ '"%t.~ K U- 21- 7 D Il U-M KU-45-6 --~ T M D 5706 ~ U-M i' 'a~ KU'43'6A ~ T MD 5300 union Alaska District KENAI GAS FIELD PROPOSED WELL LOCATION KDU -5 (31 - 6 ) T 4 N Alaska 99501 J~:y B, 19'7B Mr- J. R. ~ P.O. Box 6~47 CHECK LIST ~XDR NE%q WET~, PEt~ITS C~npan...v. 1. Is the permit fee attached ..................... 2. Is well to be located in a defined pool .............. ~/~K 3. Is a registered survey Plat attached ................ 4. Is well located pro.per distance from property line ....... 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool ..... ~___~ i[) ~!is well to be deviated ....................... 8. Is operator the only affected Party ................ 9. Can permit be apprOved before ten-day x~ait ............. 10, Does operator have a bond in force .' ................ 11. Is a conservation order needed ................... 12. Is administrative approval needed ................. Yes No Remlarks --- __ Lease & Well No. ~ / ~;~'~ ~ ~<- Item. Approve Dat~ - (1) Fee .~Z~.~ .,fl ~- ~ 7~ C2) mc. · .- -- 13. Is conductor string provided 14. Is enough cement used to circulate on conductor and surface .... Yill cement tie in surface and intermediate or production strings . Will cement cover all 'known productive horizons .......... ..~/~ 17. Will surface casing protect freshwater zones ........... ~__~Z2 __ 18. Will all casing give adequate safety in collapse, tension & burst . ~ __ (4) sg. 19. Does BOPE have sufficient pressure rating - Test to J'gPOo psig . A~ 20. Has D~.~ approved Plan of Operation ................ Additional Requirements: Revised 4/14/78