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Home My WebLink About172-033PLUGGING & LOCATION CLEARANCE REPORT State of Alaska .ALASKA OIL & GAS CONSERVATION COMMISSION PTD No. Lease Memorandum To File: API No. Well Name T~ Operator Location Spud: /ZDW/~ TD: '6 7~ ' Completed Note casing size, wt, depth, ~t vol, a procedure. Long CSg: ~ ~V ~ ' ~ II.~ ~/~~~ Liner: Perf inte~als - tops: !e.~ --~-- Review the well file, and comment on plugging, well head status, and location clearance - provide loc. clear, code. Plugs: Well head cut off: Marker post or plate: Location Clearance: Conclusions: Code Date [ alii9 ~- Unocal North Ameri¢~'~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, ~eag~c nS ~~~1 ~rS~l~ i~~g ~an~ager GSB/lew RE""-' V" E,'' APR CONDUCTOR LEG #A-1: LAT: 60°48' 28.272" LONG :151°37' 57.620" DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W "Y" COORD. "X" COORD. WELL # 2,490,836.22 208,461.20 FSL 757.5 1 2 3 4 5 6 7 8 9 l0 ll 12 LEG #A-2: 1 2 3 4 5 6 7 8 9 10 ll 12 LEG #B-l' LAT: 60048, 27.485" LONG :151°37' 57.564" 2,490,836.95 208,454.55 D-27 2,490,840.99 208,456.66 D-28 2,490,842.79 208,460.79 D-29 2,490,841.51 208,465.11. .D-32 · 2,490,837.76 208,467.60 D-4D 2,490,833.28. 208,467.10 D-41 2,490,830.18 208,463.83 D-26 2,490,829.90 208,459.34 D-25 & RD 2,490,832.58 208,455.72 2,490,835.56 208,458.66 D-24 & 34A 2,490,838.66 208,462.17 D-31 & RD 2,490,834.00 208,462.61 D-24A 2,490,835.42 2,490,836.16 2,490,840.19 2,490,842.00 2,490,840.72 2,490,836.97 2,490,832.49 2,490,829.39 2,490,829.11 2,490,831.78 '2,490,834.77 2,490,837.86 2,490,833.21 2,4'90,756.22 208,381.20 208,374.66 208,376.67 208,380.80 208,385.11 208,387.60 208,387.10 208,383.84 208,379.34 208,375.72 208,378.66 208,382.17 208,382.61 208,462.00 758.1 762.1 764.0 762.9 759.2 754.7 751.5 751'.1 753.7 756.8 760.0 755.3 754.7 FWL 1212.0 1205.5 1207.4 1211.5. 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1 2 3 4' 5 6 7 8 9 lO ll 12 LEG #B-2: 2,490,755.48 2,490,751.45 2,490,749.65 2,490,750.92 2,490,754.67 2,490,759.15 2,490,762.25 2,490,762.53 2,490,759.86 2,490,756.87 .2,490,753.78. 2,490,758.43 2,490,755.43 208,468.53 208,466.53 208,462.40 208,458.08 208,455.59 208,456.10 208,459.36 208,463.85 208,467.48 208,464.53 208,461.02 208,460.58 208,382.00 (Reserved for Compressors) 1132.1 D-1 755.3 1125.5 D-17 759.4 1127.4 D-11 761.3 ll31.5 D-7 & RD 760.1 1135.9 D-9 756.4 1138.5 D-19 751.9 1138.1 D-23 748.8 1134.9 D-21 748.4 1130.4 D-5 & RD 750.9 1126.7 D-15 & RD.& 2 754.0 1129.6 D-3. & RD 757.2 1133.0 D-13 752.5 1133.6 677.5 D-8 & RD 677.0 D-6 672.9 D-14 & RD 671.0 D-20 672.1 D-16 675.8 D-22 680.3 D-2 & A & RD 683.5 D-4 683.9 D-lO 681.3 D-12 & RD 678.3 D-18 675.1 D-30 & RD 679.7 674.8 1214.8 1221 .~) 1219.5 1215.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 ?..% --"-,, , - Deri lesearch Center Marathon Oil Company P.O. Box 269 Littleton, Colorado 80160 Telephone 303/794-2601 September 23, 1983 Mr. R. C. Warthen District Development Geologist Alaska District Union Oil Company 909 West 9th Avenue Anchorage, AK 99501 Dear Bob, Please find enclosed duplicate copies of 5 digital well log tapes that you requested recently. They are from the following wells: CTBU D-3 Redrill (Dresser Atlas) ~TBU D-15 Redrill # i & 2 ~ TBU D-25 Redril 1 ~TBU D-34A Deepened W. A. Dulin WAD/vm An Equal Opportunity Employer DEI%~kR'I'~IEN'T OF NATURAl. RESOUIICES D/VISION OF OIL ANO GAS Ol PORCUPINE DRIVE-ANCHORAGE $950I ALASI~ OIL AND GAS CONSERVATION CO~4ISTF~ October 31, 1978 A D M I N I S T RA T I VE A P P ROVAL N O. 80.25 Application of Union Oil Company of California, operator of the Trading Bay Unit, to redrill and complete the Trading Bay Unit D-2___~5 well as the D-25RD well as part of the pressure n~intenance project approved by COnservation Order No. 80. Mr. Wayne Rodges Landman Union Oil Company of California P.O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Rodges: The referenced application which was received on October 30, 1978, stated that the drilling, and completion of the Trading Bay Unit D-25RD well will result in additional ultimate recovery of Hemlock production. The Oil and Gas Conservation Committee hereby authorizes the drilling and completion of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Very truly youzs, Harry W. Kugler / Executive Secretary Alaska Oil & Gas Conservation Commit~e Union Oil and Gas ~ion: Western Region Union Oil Company'of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 279-7681 union January 20, 1976 Mr, Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 RE: TBUS D-7 (].4-33) TBUS D-9 (42-7) TBUS D-ii (14-32) TBUS .D.-25.~'11-8 ) DOLLY VARDEN PLATFORM Dear Mr. Hamilton: Enclosed for your approval and in triplicate are the Sundry Notices & Reports on Wells (Form 10-403) for each of the above capti'oned workovers. very truly yours, ~~~R. Callender District Drlg, Supt, sk cc: Marathon Oil Co. Atlantic Richfield Co, Amoco Production Co, Standard Oil Co. Skelly Oil Co. Phillips Petroleum Co. Mr. Rodney Smith-USGS 1976 Form 10-403 REV. 1-10-Y3 Submi t "1 ntentions" in Triplicate & "Subsequent Reports,' in Duplicate STATE OF ALASKA 0IL AND GAS CONSERVATION COMMITTEE . :': WELL SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Union Oil Company of California * 3. ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchorage, AK 4. LOCATION OF WELL At surface 751' 99501 FSL, 1210' FWL, Sec. 6, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB 106.2' MSL 14. CheCk APpropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 50-133-202,47 · 6. LEASE DESIGNATION ANO SERIAL NO. ADL 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradinq Bay Unit 9. WELL NO. D-25 (11-8) 10, FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 8, T8N, R13W, SM 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO-' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF; WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15, DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates~ Including estimated date of starting any proposed work. 03-06-74 Re-perforate Hemlock Zone as follows- 10,720' - 10,770, (50') 10,970' - 10,990' (20') (70') 3 HPF 3 HPF 3-1/8" Carrier Gun 3-1/8" Carrier Gun 'Prod. Test BOPD Test before Re-perf 2404 Test after Re-perf 2598 BWPD WC MMCF MMCF Lift Sep' Cs9 391 14% 2177 3027 570 18% 2366 3334 1180 psi 1200 psi 16. I hereb/v certify that the fe'~goi~ is t up and correct (This spal~d'for State office use) Tbg 115 psi 167 psi TITLE Dist. Drl~. Supt. DATE,, 1/21/76 APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE ..... DATE * Marathon Oil Company, Sub-Operator See Instructions On Reverse Side 2500 psig in 30 minutes. Reset RTTS at 10,445'. Broke perforations down at 4000 psig at 2 BPM. Reset Howco RTTS at 10,352'. Mixed and pumped 200 sacks class "G" cement. Displaced cement with mud at 3100 psig. Final pressure of 3800 psig. WOC 8 hours. Set RTTS at 10,350'. Pressure tested perforations to 5200', O.K. POOH with RTTS and RIH with 8-1/2" bit and scraper. Tagged cement at 10,590'. Drilled hard cement to 10,610'. POOH. Ran RTTS and set at 10,445'. Pressured squeeze perforations to 4000. Broke formation down, pumped into for- mmtion at 1-3/4 BPM at 4200. Squeezed perforations with 100 sacks class "G" cement. Nosqueeze. Cleared perforations. Reset RTTS at 10,415'. Squeezed perforations with 200 sacks cement. Final squeeze pressure, 4600 psig. Held for one hour. Released RTTS and POOH. Ran 8-1/2" bit and scraper. Drilled hard cement from 10,415-10,605'. Cir- culated hole clean. POOH. Ran RTTS set at 10,568'. Pressured squeeze perforations 10,590-10,593' to 4000 psig for 30 minutes, O.K. Pulled RTTS tool and RIH with bit and cleaned out cement to 11,180'. POOH with bit. Ran 9-5/8" casing scraper to 11,180'. Circulated hole clean. POOH. Rigged up Go-International. Ran cement bond log from 11,615- 9,800', Log indicated very good bonding. Ran dialog high resolution caliper pipe inspection log from 11,170' to.surface. No defects noted. RIH with open ended 3-1/2" drill pipe to 11,180'. Displaced mud with filtered inlet water. 3/12-3/18 Displaced inlet water with 848 barrels of diesel. Pulled and layed down 3-1/2" drill pipe. RIH with one joint, 4-1/2" 12.4# seal lock tubing tail pipe. Shear sub Otis. RH packer. 322 Joints of 4-1/2" 12.4# seal lock tubing with 16 gas lift mandrels~circulating sleeve ~P~~~i~.~. Set packer at 10,489'. ~. ~.. ~l~l~al~v~~..~ ~2'.~.~ . ~..~.~_~. Tested'packer to 1800 psig, O.K'. Installed ba~k pressure valve. Re- moved BOP stack and riser. Installed christmas tree and tested to 5000#. Rigged up Go-International. Ran collar locator, and tubing gauge to 11,174'. Found packer at 11,478' wiraline measurement. POOH. Picked up and ran 10' expendable perforating strip gun. Positioned gun at 11,140-11,150'. Put well on gas lift and began lifting diesel. Per- forated from 11,140-11,150' with two jets per foot in Bench 5 Hemlock under drawdown conditions. Gas lifted 687 barrels of diesel before oil surfaced. Well produced on tests at the rate of 741 barrels of oil per day with 0.3% cut. Ran BHP bomb in hole. The well stabilized. Shut in well for 18 hour buildup at 11 p.m., 3-16-73. Rig crews released at midnight, 3-15-73, and moved to well D-19 for workover. Completed pressure buildup survey. Continued perforating operations under draw- down as follows: 3/19-3/26 Perforated from 11,010-i1,040', 10,980-11,010', 10,965-10,980', 10,914-10,934'. Put well on eight hour production test, pro- ~i~.~dUc~d~36~ba~els~iO~fl~id. Well producing at 1625 barrel per day rate with 12.2% cut. Continued perforating under drawdown con- ditions as follows: 10,850-10,866', 10,808-10,823', 10,748-10,778', 10,715-10,748', 10,670-10,690'. Perforating completed. Rigged down Go-International. Placed well on test at 7 a.m., 3-22-73. Gas lifted well for 24 ~hou= production test. Well produced 3200 barrels of fluid with 2% BS&W in 24 hours GOR 453, gravity 33.60". Three production tests as follows: -2- Date 3-24-73 3-25-73 3-26-73 TOtal Fluid BS&W Gas Lift Gas T.P. C.P. Formation Gas GOR Gravity 3264 0.2% 13.96% 140 1180 1537 472 31.6 3392 0.1% 13.74% 1.40 1180 1505 444 :132'.~4 3363 0.3% 13.60% 140 1180 1463 436 32.2 Well completed 3-26-73. Producing on gas lift at the rate of 3363 barrels fluid per day 'with 0.3% BR&W, 1310 Mcf per day lift gas with gas oil ratio of 436. Tubing pressure 140#, casing pressure 1180#, gravity 32.2°. *Marathon Oil Sub-Operator Producing Hours 22-1/2 24 24 -3- Union Oil and Gas ~ion: Western Region Union Oil Company'oT California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl. n .April 13, 1973 Mr. Homer Burrell State of Alaska Division of Oil ~ Gas 3001 Porcupine Drive Anchorage, Alaska 99504 WELL D-25 WELL HI STORY (2) EASTMAN SURVEY REPORT (2) Dear Mr. Burrell- Enclosed please find two (2) copies of the well history and two (2) copies of the Bastman survey report for the above captioned well, both of which were prepared upon completion of the well. Jim R. Callender District Drilling Supt. JRC/sk Enclosures APR 8 973 A~CHOR~GE ..... SUBMIT IN D~ STATE OF ALASKA ',Seoother m- st ructions on reverse side; 5. AP1 N~CAL OIL AND GAS CONSERVATION COMMITTEE 50-133-20247 ii ii i i WELL COMPLETION OR RECO~PLETION REPORT AND LOG* i · i i ii~ WELL W~LL DRY Other b. TYP~ OF COMPL~ON: WELL OVeR rS nXCK RESVR. Other ~ 8. UNIT,F~ OR L~SE NAME 2. ~ o~ o,~o~ .... Trading Bay Unit · Union O~1 Company of California ~.WmL~O. a. ~o~ o~ o~o~ ' .... D-25 (11- 8) 909 West N~nth Avenue, Anchorage, Alaska 99501 4. LOC~rmN 0¥ W~LC-(Re~ort location c~early and in accordance with any State requirem~nts)* xt~u~ 75~~ FSL & 1210' FWL, Sec. 6~ TSN~ Ri3W~ SH n.s~c.,T.,a.,~..(~owo~ao~ Leg ~t Conductor 8 om~v~, At top prod. interval ~d below At total dep~ 806' F~L & 1092' F~L~ Sec. 8~ TSN~ R13W~ S~ ~.Pm~T~O. 72-33 11,350 MD 10,000T~ 11'180 MD ~owmu~Y. ROTARY T00L.~ ~2; PRODUCING INTERVAL(S), OF TI-IlS COMPI.2gTIOiNI--TOP, BOTTOM, NAME (MD ANDTV'D)* Homlock-Bonches 1-5 TOP 10,668 MD 9415 TVD · B21Vl 11,236 MD 9905 TVD 6. LF-d~E DESIGNATION AND SERIAL NO. ADL-18729 7. IF INDIAN, AJ~LOTTEE OR TRIBE NAME 10. FLEI.I) A2qD POOL, OR WILDC~.T McArthur River Field Sec. 8, T8N, R13W, SM INTSRVALS DRILLED BY X [ c^~.s TOm. S 23. WAS DIRECTIONAL SUt~VEY MADE ~ Yes CkSI24G SIZE 3/8 "5/8 24. T%'PE ELECTRIC AND OTHER LOGS RUN DIL, FDC-GR, BHC S(INIC-SP, CBL-VD, HiDh Resolution CSG. Inspection Log Zfi. CASING RECORD (Report all Strings set in well) 47# ' 11,3,,,37. 12 LiNET[ RJgCO~ None SIZ~ TOP (IA'ID) EOTTONI (MD) SACKS 27. TUBING RECOP~D (MD) SIZE DEPTH SET (MD) " ~528 28. PERYORATiONS OPF/N TO See Attachment 92 (interval, size and number) 29. i ADOUNT PULLED ~ PACKER SET (_,'VID) 528 ACID, Si!OT, FiIAC2URE, CEk, IENT SQU~'zE ETC. AMOUNt ~'~ND I-;HND OF MA~I~F~IAL USED See Attactm~t #1 30. DATE FIRST PI~ODUCTION 3-14-73 DATE OF T[ST, HOURS TESTED '[CI-tOIiE SiZE [PF~OD'N FOR 4-5-73, 24 ' lOpen tT~'~'~? ~--~, TUBING CA~'b ~RESSURE ICALCLI-I-~A;FED OIL--B~L. ~24-HOUI{ RA~ ~ '~ssl60 1200 I ~ [ 3771 31. ms?osn'"loN or oas (8o[d~ used lot ]ue~, vented, etc.) ' [WELL STATUS (Producing or ] ~,:~t-i~ Producinq oIL--~BBL. G.~YS--~ICF. V~£fI'EIA--BBL. [ GAS-OIL ILkTIO 3771 11423 I 15 I 377 GA~MCF. W~BBL. ] OIL GRAVITY-~I (CO~.) I TEST WITNESSED BY Sold to Parathon-Union Gas GatherLrzj System J/m Hoover 32. LIST OF ATTACHMENTS 1. Cementing_~Record 2. perforatin9 Record 3. Directional $ _urvoy Record .ga. I hereby c~tily that the/b~ego.~ and'attached information ~,S complete and correct aS determined from all--available records SIgNED~'~~TITL~, Dist. Drilling Sul:~int~dOnt~,T,sApX'__,rrl 9 1975 ~im R. Call~-nrlm- - , . ,, - - ~ - *(See Instructions and Spaces [or Additional Data on Reverse Side) * Marath)n Oil Oaupany - Sub0Perator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion reF, ort ~nd log on all types af lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, production from more than one ~nterval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucing 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 seperatel.y produceJ, show- ing the ad~,Jitional data 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 i'tems 20 and 22 above). ,, ,, 24. SU1MMAIL¥ Ol,' [~'OH. MA'I"ION 'I'E~'I'S 1N('I,UI)IN¢; IN'I'HI~VAL T~'FEI3. I>II~UI{E DATA ~'~COVEI~I~ OF OIL. GAS, 35. G~GIC MA~K~ WAT~ AND MUD No Formation Tests Taken G-Zone 9r778 8,652 Hemlock 10,668 9,415 36. CORE DATA, Aq~'ACI[ ~RI~ D~~ONS OF LITIIOLOGY, POR~ITY, FRA~R~, A~~ ~ ~N~ I~q~C~'EI) SHOWS OF OIL, G~S ~ %VAil. No Coros Taken ATTACHMENT #1 TBUS D-25 Cementing Record 13 3/8" Casing 9 5/8" Casing (lst Stage) D. V. Stage (2nd Stage) 1600 Sacks - Class "G" 1/2ft3/Sk Pearlite, 4% Gel, 1% D-31 400 Sacks - Class "G", 2% Calcium Chloride 800 Sacks - Class "G", 4% Gel, 1/2ft3/Sk Pearlite, .5% R-5, 8% D-31 550 Sacks - Class "G" .8% D-31 1% D-19 5% R-5 Tool @ 7150' 800 Sacks - Class "G" 4% Gel 1/2ft3/Sk Pearlite, 5% R-5, 8% D-31 550 Sacks - Class "G" 8% D-31 1% D-19 5% R-5 Squeeze Cementing 9 5/8" Casings{ Shoe (11,337') Perforations 11,080'-11,200' Perforations 10,590'-10,593' 300 Sacks - Class "G" 1% D-19 .5% R-5 150 Sacks - Class "G" 1% D-19 5% R-5 150 Sacks - Class "G" 1% D-10 .5% R-5 100 Sacks - Class "G" 1% D-19 5% R-5 150 Sacks - Class "G", 1% D-19, .5% R-5 200 Sacks - Class "G", 1% D-19 100 Sacks - Class "G", 1% D-19 200 Sacks - Class "G", 1% D-19 ATTACHMENT #2 TBUS D-25 Perforating Record Hemlock Bench 1 Bench 2 Bench 3 Bench 4 Bench 5 10,670' - 10,690' 10,715' - 10,778' 10,808' - 10,823' 10,850' - 10,866' 10,884' - 10,894' 10,914' - 10,934' 10,965' - 11,040' 11,080' - 11,150' FORM ,484 REV. 3--63 DATE March Z6, 1973 HISTORY OF OIL OR GAS WELL FIELD McArthur River WELL NO, STATE MEASUREMENTS TAKEN FROM D-25 Alaska LEASE /ToP Of Oil STRING__ .toP OF ROTARY TABLE~ BLOCK Trading Bay Unit SEC. 6 TWP 8N r 13W PARISH COUNTY. Kenai Peninsula Borough o6. oo' ELEV ..... HISTORY PREPARED ~"J'.~ YetlS'se~, Jr. ' E ~ ELEV. ~ TITLE AnaAyst GRD. OR MATi ELEV._ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 lZ/17 ]2/18 12/19 lZ/ZO 1z/z1 12/22 1z/z3 12/24 TD 410' - Moved rig over Conductor 8 and completed rigging up. Picked up drilling assembly and cleaned out 33" conductor to 405'. Spudded @ 3:00 AM 12/17/72. Drilled 5' new hole to 410'. Running Sperry Sun Gyro of Conductor 8. TD 614' - ComPleted running Sperry Sun Gyro on conductor. Ran in hole and drilled 12Q' hole from 410' to 533'. Could not get survey due to fill up in hole. Circu- lated and mixed mud and conditioned hole. Drilled from 533' to 614'. TD 1,201' - Drilled 12Q' hole from 614' to 1,201'. Tripped for turbodrill #1. ' Orienting turbodrill. TD 2, 101'.- Oriented turbodrill #1 and drilled 12~' hole from 1,201' to 1,375' Tripped for drilling assembly and drilled from 1, 375' to 2, 101'. TD 2,521' , Drilled 1Z~" hole 2,101-2, Z36' and tripped for turbodrill. Turbodrilled 2,236-2,284' and tripped for drilling assembly. Drilled from 2,284' to 2,521'. Tripped for 17~r hole opener and opened 12~' hole from'410' to 600'. TD 2, 521' - Opened 12~' hole from 600' to 1,930'. Tripped for hole opener and opened 12Q'r hole from 1,930' to 2,085'. TD 2,5Z1' - Opened 1Z~' hole to 17~' from 2,085' to 2,520'. Circulated bottoms up and made wiper trip. ~Circulated 1 hr and POH. Rigged up and ran 64 jts t(-55, 61# buttress 13-3/8r' casing to 2, 514'. Pumped mud into casing @ 800 psi to shear ball out of float equipment and casing parted. Weight indicator showed loss of 35,000#. Picked up landing jt and tagged casing setting on bottom. Rotated and got ~' drop. Attempted [o screw into fish. Rotated 6 turns. Circulated and pressure indicated circulation around shoe. Picked up and casing parted again. POHw/casing. TD 2,521" -Pulled 33 jts 13-3/8" casing, found pipe parted @ bad thread. Ran Tri-State casing spear on 5" DP and caught fish. Pulled 5" DP and tools. Made gauge run w/12Q' bit and 5" DP into bottom 31 jts, OK. Tagged float collar. Pulled joint which parted. Replaced 2 jts and reran 33 jts (total 64 its) and set @ 2,514'. Circulated 1 hr and cemented w/1,600 sax Class G w/1½CF/sack Perlite, 4% gel, 1% D-31, 'followed by 400 sax Class G w/Z% CaC12. Plug down to 2,473' @ 3:30 AM 12-24-72. Circulated 15 BBLS cement. Float equipment holding. W.O.C. 13-3/8" Casing Detail KB to top of casing 63 jts 13-3/8", 61#, K-55 Buttress csg Baker Flexiflow float collar jt 13-3/8", 61#, K-55, Buttress csg Baker Flexiflow float shoe Eff. From To -0- 4. 00' 2,472.78' 4.00' 2,472. 78' 1.65' 2,472. 78' 2,474.43' 41.62' 2,474.43' 2, 516. 05' 2. 10' 2, 516.05' 2,518. 15' Total overall 2,518. 15' ~'ORM 484 DATE REV. 3--63 ~IV~.!RAT'HON OIL COMI~NY HISTORY OF OIL OR GAS WELL Page Z FIELD McArthur River WELL NO D-25 LEASE STATE Alaska BLOCK Trading Bay Unit SEC. PARISH COUNTY Kenai Peninsula Borough __ El£V. TWP. R. I ToP of OIL STRINg__ EIEV.-- HISTORY PRePareD BY MEASUREmENtS LTOP Of ROTARY TABLE ~ ELEV. TITLE TAKEN FrOM I GRD. OR MAT ELEV. k It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1972 lZ/25 lZ/26 lZ/27 12/28 12/29 12/30 12/31 1973 ~/1 1/z 1/3 1/4 1/5 1/6 1/7 PBTD 2,473' - Shut down for Christmas @ 12:00 Noon 12/24/72. PBTD 2,473' - Shut down for Christmas. Resume operations 12:00 Noon 12/26/72. PBTD 2, 473' - Removed 13-3/8" landing jr. Nippled down 20r' Hydril and riser. Cut 13-3/8rr casing off. Installed weld-on Cameron casinghead housing and tested to 5,000#, OK. Now nippling up 13-3/8r' riser and BOPs. TD 2, 521' - Installed BOPs and 13-3/8r' riser. Tested BOPs, riser, kill and choke manifold to 3,000 psi, OK. Tested Hydril and 13-3/8" casing to 1,500 psi for 30 min., OK. Installed wear bushing. Going in hole to drill out below 13-3/8" casing. TD 3, 100' - Tagged top of cement @ 2,458', float collar @ 2,473'. 2,503' and tested 13-3/8" casing to 1,500# for 30 min., OK. @ 2, 514' and new hole to 2,539' l~OH for drilling assembly. 3, 100'. Drilled out to Drilled shoe Drilled 2,539- TD 3,966' - Drilled and surveyed 12~' hole 3,100-3,477'. POH for bit change. Ran Sperry-Sun Gyro on 13-3/8" surface' casing to 2,500'. Ran in with drilling assembly and drilled 1Z~' hole 3,477-3,966'. TD 4,840' - Drilled and surveyed 1Z~r hole 3,966-4,405'. POH for new bit. up remote control for BOPs, slipped drilling line. tLan in w/new bit and drilled and surveyed 4,405-4,840'. Hooked TD 5, 101' - Drilled and surveyed 4,840-4,984' and hole continued to turn right· POH. Ran in w/turbodrill #3 w/2° kick sub and drilled 4,984-5,025'. POH. Ran in w/drilling setup and drilled 5,025 5 101' Survey: 29° S73°E -- , · , · POH to change drilling setup to build angle· TD 5,436' - Changed drilling setup, ran in and drilled and surveyed 5, 101-5,352'. l~OH and changed bit and drilling setup. Ran in and drilled 5,352-5,436'. TD 6,062' - Drilled and surveyed 5,436-5,889'. POH for bit change. Hole in good condition. Drilled 5,889-6,062'. TD 6,572' - Drilled and surveyed 6,062-6,367' and tripped for bit change. Ran in and hit tight spot @ 5,938'. Conditioned mud for 3 hrs and washed to bottom. Drilled 6, 367-6, 572'. TD 6,900' - Drilled and surveyed 6,572-6,637'. Unable to retrieve survey. POH. Ran in and found some bridges last 11 stands. Drilled and surveyed 6,637- 6,900'. TD 7, 188' - Tripped for bit change--had tight spot 180' off bottom. Drilled & surveyed 6,900-7, 188'. TD 7,470' - Ran in w/new bit & drilled 7, 188-7,470'. Ran sand line survey. Dropped survey. POH for turbodrill. Fo~ 484 DATE REV, 3--63 M*,'RATHON OIL COMg .4NY HISTORY OF OIL OR GAS WELL Page 3 FI ELD!~kcA rthu r Rive r WELL NO D-25 STATE MEASUREMENTS TAKEN FROM BLOCK LEASE Trading Bay Unit SEC. TWP. r. PARISH COUNTY __ ELEV._ ftoP OF O~L STRiNg ELEV.__ hiSTORY PREPARED BY tOP OF ROTARY TABLE ,i ELEV. __ TitlE GrD. OR Mat, ELEV._ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all testS, all completion operations and procedure, etc. DATE 1973 1/9 1/lO 1/11 1/lZ 1/13 1/14 1/15 1/16 1/17 1/18 1/19 1/20 1/Zl TD 7, 545' - Ran in w/turbodrill #4 & drilled 7,470-7, 501'. Tripped for bit. Opened 9-7/8" hole to 12~r from 7,470' to 7,501'. Drilled 7,501-7,545'. TD 7,793' - Drilled 7,545-7,59Z' & POH. Stripped guards off drawworks and installed key in brake assembly (4 hrs). Brake is in good condition. Ran in & drilled and surveyed 7,592-7,793'. TD 7,990' - Drilled 7,793-7,855' & tripped for bit. Drilled and surveyed 7,855- 7,990'. HOle in good condition. TD 8,235' - Drilled 7,990-8, 168' and dropped survey. Tripped for new bit. Drilled 1Z~' hole 8, 168-8,235'. Hole in good condition. TD 8,510' - Drilled 12~' hole 8,235-8,330' & tripped for bit change. Had 60,000# drag ~ 7,200'. Drilled 8,330-8,510' & POH for bit change. Hole in good condition this trip. Rigged up to pressure test BOPs. TD 8,676' - Pulled wear bushing & ran test plug. Tested riser & pipe rams to 3,000 psig & Hydril to 1,000 psig, OK. Down 9½hrs repairing DC panel. Replaced 2 contactors in panel. RIH & drilled 8,510-8,676'. Hole in good condition. TD 8,916' - Drilled & surveyed 12~' hole 8,676-8,735'. POH for new bit. Hole in good condition. Drilled 8,735-8,870', when rotary chain failed. Replaced rotary chain & drilled 8,870-8,916'. Started POH for bit change. TD 9, 074' - Continued POH. Changed bit, RIH & drilled 8,916-9,074'. POH for bit change. Had tight spot @ 8,690'. RIH & cleaned out bridge @ 8,690'. TD 9,380- Drilled 12~' hole 9,074-9,313' & tripped for bit #~8. dition. Drilled 9,313-9, 380'. Hole in good con- TD 9, 580' - Drilled 9,380-9,470' & POH for bit change. Measured out of'hole-- made +11' correction. Checked BOPs & crownomatic, OK. Changed BI-lA & RIH. Drilled 9,470-9,580'. Hole in good condition. TD 9, 845' - Drilled 9,580-9,676' & tripped for new bit. Drilled 9,676-9,845'. Hole in good condition. TD 10,018' change. change. Drilled 12~' hole 9,845-9,879' & dropped survey. Tripped for bit Drilled 9,879-10,018' & dropped survey. Preparing to POH for bit TD 10, 170' - Tripped for bit #32 ~ 10,018'. Found bottom 150' tight on trip in hole. Reamed & washed to bottom. Drilled 12~' hole 10,018-10,170'. Started POH for bit change. TD 10,311' - Completed POH for bit change ~ 10, 170'. Survey no good. RIH & drilled 10, 170-10,311'. POH for bit change--some drag pulling off bottom, remainder of hole in good condition. Started in hole w/new bit. FORM 484 DATE REV. 3--63 ~'~, .~.~ MARATHON OIL COMI~ANY HISTORY OF OIL OR GAS WELL Page 4 FIELD McArthur River WELL NO D- 25 LEASE STATE' MEASUREMENTS TAKEN FROM 'ToP OF OIL STRING __ .TOP OF ROTARY TablE__ GRD. or MAT Trading Bay .,Unit PARISH COUNTY BLOCK SEC. TWP R. __ ELEV._ ELEV.i I HISTORY PREPARED BY, ELEV. __ TITLE ELEV. __ It is of the greatest importance to hove a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 1/22 1/23 1/24 1/25 1/26 l/Z7 1/Z8 1/29 1/30 1/31 2/1 2/2 2/3 TD 10,386' - Completed trip in hole. Drilled 12~' hole 10,311-10,386'. POH for bit change. Rigged up & tested riser to 3, 000 psi, O141. Testing BOPs. TD 10,510' - Tested pipe rams to 3,000 psig, Hydril to 2,900 psig, OI&. drilled 10,386-10,488'. Tripped for new bit; hole in good condition. 10,488-10,510'. RIH & Drilled TD 10,653' - Drilled 12~' hole 10,510-10,617' & tripped for new bit. Hole in good condition. Drilled 10,617-10,653'. TD 10,734' -Drilled 12~' hole 10,653-10, 10,663-10,735' & POH for bit change. in hole. 663' & tripped for bit change. Drilled Hole in good condition. Started back TD 10,815' - Completed trip in hole. Drilled 10,734-10,800' & tripped for new bit. Hole in good condition. Drilled 10,800-10,815'. TD 10,873' - Drilled 10,815-10,832' & tripped for new bit. Hole in good con- dition. Drilled 10,832-10,873'. TD 10,978' - Drilled 10,873-10,892' & made 10-stand wiper trip. Hole in good.. condition. Drilled 10,892-10,963' & made 10-stand wiper trip--hole OK. Drilled 10,963-10,978'. · TD 11,046' - Drilled 10,978-11,037' & dropped survey. Tripped for bit change. Reamed & washed 10,847-11,037'. Drilled 11',037-11,046'. TD 11, 145' - Drilled 11,046-11,085' & lost 700 psi circulating pressure. Checked surface system & pumps--all OI&. POH & found washout in slip area of 66th stand of 5" Grade E drill pipe. Replaced bad jt and RIH to bottom. Drilled 11,085-11, 145'. TD 11,292' -Drilled 12~' hole 11, 145-11,292' & made 14-standwiper trip--hole in good condition. Drilled 11, 175-11,292'. TD 11,350' - Drilled 11,292-11,296' & tripped for bit change. Drilled from 11,296' 1 to Total Depth of 11,350' @ 12 Midnight 1/31/73. Circulated ihr and made short trip. Ran back-to bottom & circulated for 3 hrs to condition mUd .and clean up hole preparatory to logging. Started TD 11,350' - Completed trip out of hole. Rigged up Schlumberger & ran DIL-SP, BHC-Sonic-SI~, & FDC-GR from 11, 350' to 2,514'. Had misrun on FDC Log. Ran back w/new tool & ran repeat section OI~. Dropped back to TD @ 11,328' & started to log. Tool became stuck @ 11,320'. Attempting to free FDC logging tool. TD 11,350' - Freed Density tool & completed logging w/run of Density/Caliper/ Gamma Ray from 11,319' to 2,516'. RIHw/bit & drilling assembly to 6,000' .& broke circulation. Completed trip to bottom & conditioned hole & mud for 3 hrs. POH & laid down bottom hole assembly. Rigged up to run 9-5/8" casing. Started running casing. FORM 484 DATE REV. 3--63 M#.~RATHON OIL COM~,ANY HISTORY OF OIL OR GAS WELL Page 5 FIELD McArthur River WELL NO. D-25 STATE LEASF Trading Bay Unit PARISH COUNTY BLOCK SEC. __ ELEV._ ToP Of OIL STRING.~ ELEV:__ HISTORY PREPARED BY MEASUREMENTS ~ToP Of ROTARY TAblE ELEV. TITI~E TAKEN FROM/ -- -- [GRD. OR MAT. ELEV._ .... TWP R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE ]973 2/4 z/5 2/6 PBTD 11,252' - Completed running 9-5/8" casing. Ran 279 jts 9-5/8", 47~, P-110 · 1 Buttress casing to 11, 337' Broke circulation & circulated for lyhrs. Rigged up B-J Services & cemented casing in two stages: FIRST STAGE: Mixed & pumped 800 sacks Class "G" cement w/4%0 gel, ~/cu ft Perlite, 0.5% R-5, 0.8% D-31, followed by 550 sacks Class "G" Neat cement w/0.8% D-31, 1% D-19, & 0.5% 1t-5. Pumped 10 BBLS mud sweep ahead of cement & 10 BBLS water b'ehind slurry. Slurry weight 12.5#/gal--gel cement & 15# /gal Neat cement. Displaced slurryw/824 BBLS mud w/rig pump. Bumped plug w/2,000 psig. Released pressure & plug held. CIP ~ 10:00 PM 2/3/73. Dropped D-V bomb & opened D-V collar 1 w/1,200 psig. Circulated lyhrs. Circulated approx. 60 BBLS cement from 1 st stage. SECOND STAGE: Mixed & pumped 800 sacks Class "G" cement w/4% gel, ¥#/cu ft Perlite, 0.5% 1t-5, 0.8% D-31, followed by 550 sacks Class "G"Neat cement w/0.80/o D-31, 1% D-19, & 0.50/0 1t-5. l~umped 10 BBLS mud sweep ahead of slurry & 10 BBLS water behind slurry. Slurry weight 12.5~/gal gel cement & 15# /gal Neat cement. Displaced slurryw/523 BBLS mud w/rig pump. Bumped plug w/3,000 psig. Released pressure & plug held. CIP 2:30 AM 2/4/73. Had cement returns to surface w/15 BBLS excess cement. Set casing in slips & began installing 9-5/8" tubing spool. Rigged down Services. 9-5/8" Casing Detail Eff. From To KB to top of casing 174 jts 9-5/8", 47#, Pl l0, Buttress 7, 108.37' 1 Baker DV Collar 1.75' 102 jts 9-5/8", 47#, Pl l0, Buttress 4, 101.94' 1 Baker Float Collar 1.98' 2jts 9-5/8", 47#, Pll0, Buttress 79.72' 1 Baker Float Shoe 2.55' Total Overall 11,296. 40.80' 40.80' 7, 149. 17' 7, 149. 17' 7, !50.92' 7, 150.92' 11,252.86' 11,252.86' 11,254.84' 11,254.84' 11,334.56' 11, 334.56' 11,337. 11' PBTD 11;252' - Cut off casing & installed tubing head, tested to 3,000 psi, OK. Nippled up BOE on tubing head & tested, OK. Ran in w/8~' bit & drilled out DV collar @ 7, 150'. Ran to bottom & tagged float collar. Circulated hole clean. POH to 5,000' & closed rams. Now pressure testing casing w/3,000 psi. I~BTD 11,252' - Pressured 9-5/8" casing to Z, 700 psi--bled off to Z, 200 psi in 15 minutes, i°OH & ran casing scraper to bottom. Measured out of hole--1 stand (94') off. No cement in shoe jts. Rigged up Schlumberger & ran CBL & GR Log to bottom of 9-5/8" casing @ 11,337'. Indicated poor bond. Rigged up & ran Howco EZ drill retainer on wireline &set @ 11,262' WLM. POH & rigged down Schlumberger. I~ressure tested 9-5/8" casing to 2,600 psi-- holding OK. Tested to 3,000 psi--dropped 20# in 30 minutes, OK. FORM 484 DATE REV. 3--63 Mt-~RATHON OIL COMi~.tNY HISTORY OF OIL OR GAS WELL Page 6 FIELD McArthur River WELL NO.. STATE D-25 LEASE Trading Bay Unit PARISH COUNTY [LEV. __ BLOCK SEC. TWP. R. top Of OIL STRING.-- ELEV.- HISTORY PREPARED BY MEASUREMENTS I TOP Of F~OTArY TABLE ELEV. TITLE TAKEN FROM ' [GRD. OR MAT ELEV. It is of the greatest importance to have a complete history of the well.' Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size' and number of bits, complete description of casing, cementing, fishing or drilling difficulties, sUrveys, all tests, all completion operations and procedure, etc. DATE 1973 Z/7 2/8 2/9 2/10 Z/Il Z/lZ 2/13 PBTD 11,262' - Ran in w/Howco stinger & circulated above retainer. Set into retainer @ 11,262' WLM & broke formation down @ 3,400 psi @ 5 - 5½ BPM. Pressure tested surface lines to 5,000 psi, OK. B-J Services mixed & pumped 300 sax Class r'G" cement w/l% D-19 & 0.5% R-5. Spotted cement w/25 BBLS water ahead. Pressure increased slowly from 3,400 psi to 5,000 psi final pressure. Pulled out of retainer & reversed out 10-15 BBLS cement & approx. 5 BBLS water. Slurry wt - 15½ - 16 ppg. Estimate 200 sax cement behind pipe. CIP @ 8:00 PM 2/6/73. POH & laid down HW drill pipe. Picked up BHA & 5" DP & R_IH, measuring in hole. PBTD 11,270' - Tagged top cement @ 11,270' DPM--2' cement on top of retainer. Circulated hole clean & POH to run Bond Log. Rigged up Schlumberger & ran Cement Bond Log w/Variable Density Log. PBTD 11,243' - Ran 8~' bit & 9-5/8" casing scraper to 11,268'. Conditioned mud while WOC. POH w/bit & scraper. Rigged up Schlumberger & perforated 11,251-11,252' w/4 Hyper jets/ft. Ran Baker Model "'K" cement retainer on wireline & set @ 11,230' WLM, 11,243' DPM. B-J spotted 20 BBLS water, stabbed into retainer & attempted to break down perforations @ 11,251-11,252' w/5,000 psi. Pressure bled back to 4,500 psi. Repressured to 5,000 psi-- bled back to 4, 500 psi in 15 minutes. Unable to break formation down. Pulled out of retainer. Reversed mud out of hole w/filtered Inlet water. Started laying down drill pipe. PBTD ll, 243' - Completed laying down 5*' drill pipe. Rigged up to run tubing. Started running 4~', 12.6# Seal Lock tubing w/Otis 9-5/8" RH-1 packer & gas lift valve s. PBTD 11,243' - Finished running 4~' production tubing string w/Otis gas lift valves & Otis RH-1 packer. RIH w/packer @ 11,237' & displaced water w/560 BBLS diesel. Lacked Z00 BBLS displacement volume when diesel came to surface. Pulled & laid down extra .tubing. Installed ball valve control line & .landed tubing with packer @ 10,515'. Dropped ball & attempting to set packer. PBTD 11,243' - Pumped ball thru packer up to 1,400 psi. Broke over & circulated. Packer failed to set. Rigged up Otis wireline unit & ran test plug. Pressured up to 2,000 psi, bled off pressure. RIHw/Otis wireline to retrieve test plug. Plug stuck @ 5,700'. Jarred retrieving neck off plug. Ordered out fishing tools & rigged up to run. Wireline unit broke down. Repaired unit & to retrieve plug. Could not latch onto plug ~ 5,700'. Chased plug to bottom & retrieved. Attempted to pressure test packer--hole circulated. Packer not set. Started out of hole to replace packer. PBTD 11,243' - Finished POHw/packer--all rubbers torn off packer. Rigged up Schlumberger & made 3 runs w/gauge ring & junk basket. Recov'd approx. 85% of packer rubber, ball from shear sub, & cement @ 11,227' WLM. RIH open-ended w/tubing, leaving out gas lift mandrels. Circulated out 310 BBLS mud, water, & cement. Circulated for 1 complete circulation @ 11,220', tubing measurement. Started out of hole w/tubing. FORM 484 DATE RI'V. 3--63 M?'I=IATHON .OIL COM~NY HISTORY OF OIL OR GAS WELL FIELD Page 7 McArthur River WELL NO. D-25 STATE MEASUREMENTS TAKEN FROM LEASE 'ToP Of Oil STRING __ .ToP OF ROTARY TABLE~ GRD. OR MAT, Trading. Bay Unit PARISH couNTY __ ELEV. ELEV .... ELEV. __ ELEV. __ bLOCK SEC. TWP. R. HISTORY PREPARED BY._ TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 2/14 Z/15 Z/16 Z/17 2/18 2/19 PBTD 11,243' - Finished POH w/tubing. Ran Otis gauging plug thru tubing. Picked up Otis 9-5/8" RH-1 packer & gas lift mandrels. RIH w/4~' tubing, broke circulation, set packer @ 10,526'. Sheared out setting ball @ 1,700 psi. Pressured up tubing to 2,000 psi--bled off to 1,400 psi in 20 min. Ran Otis tubing plug k set in N landing nipple @ 10,563'. Pressure tested tubing to Z, 000 psi for 30 min. , holding. Pulled tubing plug k pressure tested tubing to 2,000 psi for 30 min., holding. Nippled down BOPs & installing tree. PBTD 11,243' - Finished installing X-mas tree. Installed flowline & gas lift line. Rigged up Schlumberger & installed & pressure tested lubricator. R.IH w/30' expendable type perforating gun k gun stuck @ 10,560'. Pulled loose k POH. Found perforating gun had parted 6' below top swivel jr. Rigged up Otis wireline unit & RIHw/wireline grapple, oil jars, spang jars, & 2 sinker bars. Latched onto fish k pulled up hole 60' to 10,500'. Top of fish @ 10,470'. Pulled loose k now POH to inspect fishing tool. PBTD 11,243' - Ran Otis fishing tools. Made 5 runs w/inside spear to attempt recovery of perforating strip gun. Recov'd approx. 3' of gun strip. Rigged down Otis & rigged up Schlumberger. Ran collar locator log to determine top of fish--found top ~ 10,515'. Bled pressure off casing. Pulled tree & nippled up BOPs. Rigged up Otis & RIHto open circulating sleeve. Preparing to displace gas from annulus. PBTD 11,243' - Unable to open circulating sleeve. annulus w/diesel. Rigged up to pull packer. wt of string ). Packer would not shear. Pulled to 270, 00 string wi) & packer, sheared. POHw/packer. Found 20' gun hanging out of tail pipe. Gun was stuck by broken jet POH w/shifting tool. Filled Pulled 210,000# (60,000# over 0# (120,000# over of perforating strip charges. RIH w/wireline gauge ring & junk basket to 11,220' & recov'd debris from strip gun & pieces of seal from hanger. RIH w/Baker Model"D" 9-5/8" x 6" perma- nent packer'on Schlumberger wireline. Packer started sticking @ 2,700'. POH & ran 8~' gauge ring & junk basket. POH. RIH w/packer & set packer ~ 10, 514' WLM & 10,528' casing measurement. Picked up seal assy & prepared to go in hole w/tubing. PBTD ll, 243' - 1KIH w/Baker seal assy, Otis gas lift mandrels, & ball valve on 4~' 12.6#, Seal Lock tubing. Spaced out tubing string. Installed ball valve control line & stabbed into packer. Set 6,000# on packer. Tested tubing & packer to 1,500 Psi, OK. Nippled down BOPs k installed X-tree. Tested tree to 5,000 psi, OK. RIH w/gauging plug to 10,700'. Go-International ran 30' x 2-1/8" perforating strip gun to 11,200' to perforate interval 11, 170-11,200'. Began gas lifting diesel down to first 'gas lift valve prior to perforating. PBTD 11,243' - Gas lifted 198 BBLS diesel prior to perforating from 11, 170' to 11,20( (30') w/2 jets/ft, by Go-International. Flowed well until oil surfaced. Produced 451' BBLS. Continued. perforating. Made run #2 & perforated from 11, 140' to Il, 170' (30') w/2 jets/ft. Lowered gun below perforations & produced well for 1 hr to clean up perfs. Shut well in & pulled gun ~'2. R_IH w/gun #3, resumed gas lift & perforated from 11, i10' to 11, 140'. Produced well for 1 hr to clean up. Shut well in k pulled gun #3. RIH w/gun #4, resumed gas lift prepatory to perforating. M~'-I=IATHON OIL COM~._~NY HISTORY OF OIL OR GAS WELL WELL NO. D-25 STATE LEASE Trading Bay Unit PARISH COUNTY BLOCK SEC. __ ELEV. ~ MEASUREMENTS TAKEN FROM f ToP OF Oil STRING ~ ELEV._ TOP OF ROTARY TABLE__ ELEV. GRD. OR MAT EIEV. HISTORY PREPARED BY TITLE Page 8 FIELD McArthur River TWP. R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 z/z0 Z/Zl 2/22 2/23 Z/Z4 Z/Z5 Z/Z6 2/27 PBTD 11,243' - Continued to perforate under drawdown. Total interval shot (Bench 5, Hemlock) - 11,080-11,200' {120'), 240 holes. Checked sample of produced fluid--high water cut. Placed well on test @ 12:00 Noon 2/19/73. PBTD 11,243' -.Continued testing well, gas lifting w/1,450 Mcf--flow rate inter- mittent. Produced 647 BBLS past 24 hrs, average water cut 50%. Rigged up Go-International & ran Differential Temperature & R-A Tracer Logs to determine fluid source. Logs indicate water flowing from sands above Hemlock. Hole full of mud from PBTD to 11, 180'. Hooking up casing blowdown line preparatory to killing well. PBTD 11,243' - Rigged up blowdown line & bled gas off armulus. Rigged up Otis & pressure tested lubricator to 3,500 psi, OK. RIH w/wireline shifting tool & opened XO circulating sleeve @ 10,488'. Hooked up rig pump to tubing & annulus to production header. Displacedhole w/mud, holding 700 psi back pressure. Circulated mud for 1 hr. Shut down. Installing tubing back pressure valve. PBTD 11,243' - Rigged down flowline, removed X-tree, & nippledup BOPs & riser. Pressure tested riser & pipe rams to 3,000 psi, OK, & hydril to 1,800 psi, OK. Rigged up & pulled stinger out of packer @ 10,528'. POH w/tubing, laying down gas lift mandrels. Picked up 8-3/8" x 7" mill shoe & 6Q' DCs. Started picking up 3~' drill pipe. PBTD 11,243' - Completed RIHw/mill & packer retrieving tool. Tagged packer @ 10,528'. Circulated bottoms up prior to stabbing into packer. Mud gas-cut to 8.8#/gal. Conditioned mud to 9.8 ppg. Milled over packer & pulled packer loose & out of hole. l~acker dragging thru collars coming out of hole. Recov'd packer mandrel, left cone & slips in hole. PBTD 11,243'- RIHw/oz-/Q~'' bit & cleaned out fill to ll,220'--running on junk. POH. Rigged up Go-International & ran gauge ring & junk basket on wireline to 11, 125' POH & ran Baker Model "IK" cement retainer & set @ 11,060'. Started out of hole. PBTD 11,243' - Completed POHw/wireline. RIHw/3~' DP w/retainer stinger & stabbed into retainer @ 11,060'. Pressured up annulus to check retainer-- would not hold pressure. Retainer slipped down hole 8'. Pressured up under retainer to Z, 000 psi--recorded 2,0.00 psi on annulus. Bled off pressure & picked up drill pipe to close sleeve in retainer. Pressured drill pipe to 1,000 psi, OK. POH w/3~' drill pipe. RIH w/bit & drilled up retainer & remainder of Baker Model "F" packer. Cleaned out hole to 11,.230'. Circulating hole clean. PBTD 11,243' - POHw/3~' DP. Ran junk pusher & gauge ring on wireline to 11,231'. Set Baker Model"K" cement retainer onwireline @ 11,020'. POH. RIH w/stinger on 3~' drill pipe, broke circulation & stabbed into retainer. Presmred casing to 1, 500 psi & drill pipe to 5,000 psi, no breakdown. Pressured casing to 2,000 psi, drill pipe to 6,000 psi for 5 min., broke back to 2, 500 psi. Pumped into formation @ 2 BPM @ 4,400 psi. Pulled out of retainer. Spotted 25 BBLS water in DP & stabbed into retainer. Pumped 11 BBLS water @ 3½BPM @ 1,000- FORM 404 DATE REV. 3--63 M~ .I::IATHON OIL. COMF""~NY HISTORY OF OIL OR GAS WELL FIELD Page 9 McArthur River WELL NO. D-Z5 LEASE STATE Trading Bay Unit PARISH COUNTY, IToP OF OIL STRING MEASUREMENTS TOP OF ROTARY TablE~ TAKEN FROM [GRD. OR MAT BLOCK SEC. TWP R. ~ ELEV. ~ ELEV.-- HISTORY PREPARED BY ELEV.~ TITLE ELEV. It is of the greateet importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 z/z7 (Cont'd) Z/Z8 3/1 3/2 3/3 & pressured casing to 2,500 psi, held OK. Stabbed into retainer & circulated out annulus. POH & found inner mandrel of retainer still on stinger. PBTD 11 243' RIH ' /R~' bit & BHA on 3{' DP & drilled up Baker Model "K" cement , -- w/~2 retainer @ 11,020'. Cleaned out to 11, 230'. POH. Ran junk basket & gauge. ring to 11,223'. Ran & set Howco EZSV retainer @ 11,028'. POH. RIH w/Howco stinger on 3~' DP & stabbed into retainer. Picked up, spotted 20 BBLS water & stabbed into retainer. Pumped into formation @ 2½ BPM rate @ 4600#--no apparent breakdown pressure while pumping 8½BBLS. Casing pressure increased from 1,000 psi to 1,700 psi. Bled off casing pressure & opened Hydril. Circulated down DP and out casing. Closed Hydril & pumped down casing @ 2,000 psi & circulated out DP. Shut down pump--casing pressure bled from 2,000 to 1,000 psi in 3 min. Pulled out of retainer. Closed rams & pressured casing to Z, 500 psi--pressure bled to 2, 000 psi. Opened rams & preparing to POH. PBTD 11,243' - POH w/retainer stinger. RiHw/RTTS & set @ 10,014'. Pressured below RTTS to 3,000 psi--bled to 1,000 psi in one min. Casing pressure 1 remained @ 1,200 psi. Pumped by retainer @ 12BPM rate @ 2,500 psi. Reset RTTS @ 11, 0Z0' & pressured DP to 2,800 psi--bled to 1,600 psi in one min. Pressured casing to 2,400 psi for 5 min., OK. Drill pipe continued to bleed off to 800 psi. POH w/RTTS. Picked up 8~' bit & BHA & RIH on 3~' DP. Drilled up Howco retainer @ 11,028' in 3 hrs. Cleaned out to 11,226'. Circu- lating & conditioning mud. PBTD 11,243' - POH w/bit & ran gauge ring on wireline to 11,220'. POH. RIH w/RTTS & set @ 11,070' Pressured up annulus & circulated out DP. Reset @ 11,063, 11,048', 11,0;8', & ll,024'--allcirculated. Reset @ ll,010'-- casing held 2,500 psi. Reset @ 10,920'--casing held 3,000 psi. Broke down formation @ 2 BPM @ 3,400 psi, pumped 20 BBLS water, 150 sax cement. (Class "G" w/l%-D-19, 0.5% R-5), 5 BBLS water, & 25 BBLS mud. Started mixing cement @ 2330 hrs. Pumped cement into formation @ 2 BPM @ 4,000 psi. Cleared tool--shutdown pressure 1,600 psi. Pumped remainder of cement away in 8 stages. Maximum shutdown pressure 2,500 psi @ 0200 hrs. Flushed perforations w/5 BBLS water & 10 BBLS mud..Reversed out--no cement. 1 , Pulled 2 stands, reversedyhr. Shut down to 0600 hrs. Set RTTS @ 10 918' & tested casing to 3,000 psi. Preparing to break down. Note: Hole in casing below 11,010' and above 11,024'. PBTD 11,243' - Breakdown of formation for 2nd squeeze below RTTS @ 10,918'. Pumped 2 BPM @ 3,900 psi. Pumped 20 BBLS water, 150 sax Class "G" cement w/l% D-19 & 0. 5°'/0 R-5, 20 BBLS water, & 10 BBLS mud. Closed tool. Displaced w/mud. Unable to obtain squeeze. Maximum shutdown pressure 3,900 psi. Flushed perfs 11,080-11,200' w/20 BBLS water. Re- leased RTTS & reversed out--no cement returns. Pulled 2 stands & reversed again. Shut down 4hrs. Reset RTTS @ 10,918' & pumped into formation @ 2 BPM @ 3800 psi. Opened tool & pumped 20 BBLS water, 100 sax Class "G" cement w/l% D-19 & 0. 5~0 R-5, 20 BBLS water, & 22 BBLS mud. Closed ~ool. Squeezed in 5 stages w/final build to 5,000 psi, held 30 min. Released pressure to 2,000 psi. Repressured to 5,000 psi, holding OI~. Reversed out. Pulled 2 stands & reversed again. WOC 4hrs. Tested squeeze to 4800 psi, OK. POH. DATE REV. 3--63 M' .I::IATHON OIL. COIViI: ~NY HISTORY OF OIL OR GAS WELL FIELD Page 1 0 WELL NO. D- 2,5 STATE BLOCK LEASE Trading Bay Unit SEC. PARISH COUNTY. __ ELEV..~ I ToP OF OIL STRING __ ElEV..i HISTORY PREPARED BY. MEASUREMENTS ' TOP OF ROTARY TABLE ELEV. __ TITLE TAKEN FROM -- I, GRD. OR MAT. ELEV._ Ii TWP R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the' dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 3/3 (Cont' d) 3/4 3/5 3/6 3/7 3/8 Rigged up Go-International & perforated 2 HPF 10, 590-10,593'. Laid down 7 stands (Z1 jts) of cement coated 3~' DP. Made up RTTS tool & preparing to RIH. 1 PBTD 11,243' - RIH w/RTTS to 10,445' & reverse circulated ~ hr. Set RTTS & broke down formation thru perfs 10,590-10,593' w/2900 psi. Pumped 2 BPM @ 2800 psi--bled pressure back to 2Z00 psi. Tested casing to 2600 psi, OK. Squeezed to 4,000 psi w/150 sax Class rrGr' cement w/l% D-19 & 0.5°/0 R-5. Pressure on casing increased from 1,200 to 1,400 psi. Released pressure. Increased wt on RTTS & repressured casing to 1000 psi. Pressured DP to 4500 psi. Pressure on casing increa'sed to 1050 psi. Released RTTS & reverse circulated--no cement returns. Pulled 5 stands & reversed for 30 min. POH w/RTTS. Made up BILk on 8~' bit & RIH to 10,400' & circulated while WOC. PBTD 11,243' - Circulated & WOC to 10:00 AM. Closed rams & pressured casing to 3,000 psi, OK. Tagged cement @ 10,455'. Crilled cement to 10,617' in 3½ hrs. Closed rams & pressured casing to 3,000 psi--bled to 2,750 psi in Z0 min. Pressured surface lines to 3,000 psi, OK. Repressured casing to 3,000 psi--bled to 2,800 psi in 30 min. RIH & tagged cement @ 10,~669'. Circulated & conditioned mud. POH. RIHw/RTTS & set @ 10,630'. Pressured casing to 3,000 psi--bled to 2, 600 psi in 15 min. Pressured DP to 4, 000 psi--lost 25 psi in 30 min. Casing continued to bleed to 2,500 psi in 30 min. Pulled up & set RTTS @ 10,445'. Pressured up to 4,000 psi & perfs broke down @ Z BPM. Shut down pressure 2,700 psi. Pumped 10 BBLS @ 2½BPM ~ 3,800 psi. PBTD 11,243' - Set Howco RTTS packer @ 10,352' & broke down perfs @ 10,590- 10, 593' @ 3400 psi. Pumped into formation @ 3 BPM @ 3400 psi. Pumped 20 BBLS water ahead of 200 sax Class r'Gr' cement w/l% D-19. Spotted cement & closed tool. Displaced cement @ 3, 100 psi, final pressure 3800 psi. WOC 8 hrs. Set RTTS @ 10,350' & pressure tested squeezed perfs to 5,200 psi, OK. POH. RIHw/bit & scraper & tagged cement @ 10, 590'. Drilling out. PBTD 11,243' - Drilled hard cement to 10,610' & POH. Ran RTTS tool on 3~' DP & set @ 10,445'. Pressured annulus to 2,000 psi. Pressured up on' squeezed perfs to 4,000 psi & formation broke down. Pumped into formation @ 1-3/4 BPM @ 4200 psi. Squeezed perfs 10,590-10,593' w/ 100 sax Class "G" cement w/l% D-19. Started cement @ 10:15 PM. Initial pumping pressure 3900 psi-- no builduP. Displaced perfs w/ 10 BBLS mud. Waited 1½ hrs- -bled off & reversed out. Reset RTTS @ 10,415' & broke down formation w/4300 psi. Squeezed perfs w/200 sax Class G cement w/l~0 D-19--initial pressure 3400 psi, final squeeze pressure 4600 psi held for 1 hr. Released RTTS & reversed out. Started POH w/RTTS. PBTD 11,243' - Finished POHw/RTTS tool. RIHw/bit & scraper & tagged cement ~ 10,415'. Drilled hard cement to 10,605'. Circulated hole clean & POH. RIHw/RTTS & set @ 10,568'. Pressured up on squeezed perfs 10,590-10,593' to 4000 psi, holding pressure w/no bleed-off in 30 min. ,. FORM 484 DATE REV. :$--63 M/-~RATHON OIL COMP"~NY HISTORY OF OIL OR GAS WELL Page 11 FIELD McArthur River WELL NO. STATE D-Z5 LEASE Trading Bay Unit 'PARISH COUNTY ELEV. ~ bLOCK SEC. TWP R. I TOP OF OiL STRING . ElEV.~ HISTORY PREPARED BY MEASUREMENTS ~TOP OF ROTARY TABLE~ELEV.~ TITLE TAKEN FrOM ! [GRD. OR MAT, ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereOf, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 3/9 3/10 3/11 3/12 3/13 3/14 3/15 3/16 PBTD ll, 180' - POHw/RTTS tool. RIH w/bit and drilled as follows: 10,605- 10,674' - hard cement, 10,674-10,914' - no cement, 10,914-11,064' - hard cement, 11,064-11,0'71"- Soft cement, 11,071-11, 180' - hard cement. Circulated hole clean & POHW/bit, strapping out drill pipe. Pressure tested casing to 3, 000 psi. for- 30 min., no bleed off. PBTD 11, 180' - POH w/bit. Measured out of hole--+ll' difference. Made no correction at this time. Started inhole w/9-5/8" casing scraper, ran 40 stands when 8" x 3/4" stop bolt on power slips came loose & fell in hole. POH & picked up riser in attempt to recover bolt. Bolt slipped past scraper & fell downhole. Reconnected riser & tested stack to 3,000 psi, OK. Ran in w/bit & scraper to 11, 180'. Circulated hole clean & POH. Rigged up Go- International & ran in w/Cement Bond Log. PBTD 11, 180' - Completed running CBL-Signature Log 11, 165-9,800'--indicated good bonding. Dia-Log rigged up & ran High Resolution Caliper Pipe Inspection Log from 11, 170' to surface--no defects noted. Ran in w/open-ended 3~' DP & reversed out fill on bottom. B-J rigged up & displaced hole w/filtered Inlet water (874 BBLS). Displacing water w/diesel. PBTD 11, 180' - Circulated until clean diesel surfaced (848 BBLS). POH & laid down 3~' DP. Ran in w/4~', 12.4#, S.L. tubing, Otis RH packer, 322 jts tubing, 1 jt tail pipe, 16 gas lift mandrels. Packer set @ 10,489'. Tested ball valve line to 5 000 psi OK. Ball.~ve set @ 302' Dropped bali to set packer. PBTD 11, 180' - Set & tested packer to 1,800 psi, OK. Installed back pressure valve & removed BOP stack & riser. Installed X-tree & tested to 5,000 psi. Rigged up Go-International & ran collar locator & tubing gauge to 11, 174'. Ran Collar Log & found packer @ 11,478' (WLM). Logged sqzd perforations @ 11, 174' to 11,080'. POH. Picked up 10-ft expendable perforating strip gun, ran in & positioned gun @ 11, 140-11, 150'. Put well on gas .lift & began lifting .diesel. Produced '183 BBLS @ 7:00 AM 3/13/73. PBTD 11, 180' - Perforated 11, 140-11, 150'.w/2 JPF in Bench 5, Hemlock zone, under drawdown conditions. Gas lifted 687 BBLS diesel before oil surfaced. Well producing on gas lift @ 408 BPD rate (17 BPH), 0.3% BS&W, TP 160 psi, CP 1140 psi, total gas volume 2, 207 Mcf, lift gas 1,539 Mcf, formation gas 668 Mcf, GOR 1,723. Lifting from 16th valve @ 10,410'. PBTD 11, 180' - Tested well on gas lift to ll:00AM 3/14/73. Produced 227 BBLS w/avg cut of 0.4% BS&W. Resumed perforating Bench 5, Hemlock, under draw- down il, 140-11,110' & 11, 110-11,080' w/2 JPFw/expendable strip perforating gun. Put well back on production test. Well producing @ rate of 720 BPD, 0. 1% BS&W, TP 140 psi, CP 1120 psi, GOR 509, lift gas l, 581 Mcf, formation gas 366 Mcf. PBTD 1t, 180' - Production testing. Produced on test: 741 BOPD w/3.0% cut, 30. 1° AP1 gravity, 1440 MCFD lift gas, 830 MCFD formation gas, GOR 1, 123, GLR 1,943, TP 140#, CP 1110#. FORM ,48,4 DATE REV. 3--63 M"--~ATHON OIL COMI=_:NY HISTORY OF OIL OR GAS WELL Page 12 FIELD McArthur River WELL NO, STATE M EAS U R EM ENTS TAKEN FROM BLOCK D-25 LEASE .Trading Bay Unit SEC. TWP R._ PARISH COUNTY, EIEV. f ToP of Oil STRING ELEV.- HISTORY PREPARED BY ToP OF ROTARY TabLE~ ELEV. TITLE GRD. OR MAT. . ELEV._ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casiflg, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1973 3/17 3/18 3/19 3/20 3/Zl 3/22 3/23 3/24- 3/26 PBTD 11, 180' - Produced well on gas lift until ll:00AM. Ran gradient survey, found well lifting off valve #13 @ 9,490'. Ran bottom hole pressure bomb. Shut in well for 18-hr BHP @ 11:00 PM, 3/16/73. Released rig crews from TBUS D-25 @ 12:00 PM, 3/15/73 to Well TBUS D-19 for workover. PBTD 11, 180' - Completed 18-hr B.HP build-up survey @ 5:00 PM 3/17/73-- 3,261 psi. Ran in w/30' perforating gun. Stabilized well flow @ 736 BOPD. Perforated Bench #4 w/2 HPF 11,010-11,040'. Produced well 1½hrs. Reran 30' perforating gun & positioned from 10,980' to 11,010'. Wellheading & making2 - 20% cut. (Discovered water to be coming from water injection system used to pressure WL lubricator. ) PBTD 11, 180' - Flowed well after correcting water source--no cut. Perforated Bench #4 10,980-11,010'. Produced 138 BBLS @ 0.3% cut. Perforated Bench #4 10,965-10,980' w/2 HPF. PBTD 11, 180' - Put well on test of Benches 4 & 5: Gas lifted 365 BBLS fluid in 5-3/4 hfs (1,544 B/D rate w/1,072 MCFD lift gas). Perforated remainder of Bench 4 from 10,914' to 10,934' w/2 HPF. Gas liftedwell 8 hrs--produced 536 BBLS fluid @ 1,625 B/D rate w/0.2% cut, 1,375 MCFD lift gas. Perfo- rated Bench 3 from 10,884' to 10,894' w/2 HPF. Gas liftedwell for 1½hrs & produced 130 BBLS. Perforated Bench 3 from 10,850' to 10,866' (16') w/2 HPF. PBTD 11, 180' - Completed perforating Bench #3 from 10,808' to 10,823'. POH. Put well on test (Benches 3, 4, & 5) & produced 526 BBLS fluid @ 2, 104 B/D rate w/0.2% cut. Perforated Bench #2 from 10,748' to 10,778' and from 10,715' to 10,748'. Put well on test (Benches ~2, 3, 4, & 5) & produced 747 BBLS fluid @ 2,988 B/D. rate w/0.3%0 cut, 1,554 MCFD lift 'gas. PBTD 11, 180' - Perforated Hemlock Bench #1 from 10,670' to 10,690' w/2 HPF. All perforating completed. Put well on test & producing @ 137 BFPH @ 7:00 AM (3,288 BPD) w/0. 2% cut--emulsion & water. PBTD 11, 180' - Gas lifted well for 24hrs & produced 3,200 BFw/2.0% BS&W (0.5% water & 1.5% emulsion), total gas 2,773 Mcf, formation gas 1,420 Mcf, GOR 453, gravity 33.6°. PBTD 11, 1 Date 80' - Gas lift wellw/g4-hour rates as follows from Hemlock Benches 1-5: Finn GL BFPD BS&W Gray. Gas Gas GOR TP CP Test Period 3/24 3,264 0.2% 31.6° 1537 1396 472 140 1180 2Z½hrs 3/25 3, 392 0. 1% 32.4° 1505 1374 444 140 1180 24hrs 3/26 3, 363 0. 3% 32.2° 1463 1310 436 140 1180 24 hrs Well completed March 26, 1973. SYM60L OF SERVICE REPORT SUB-SURFACE DIRECTIONAL SURVEY ,'~RATHON OIL CON[PA~'~ - COMPANY WELL ~D-25 LEG A-1 SLOT 8 ~FELL NAME COOK .L;,LET DOLLY VARDEN LOCATION JOB NUMBER A~12-1172 TYPE OF SURVEY SINGLE SHOT DATE SURYEY BY GENE THIBODEAUX 075 AiASKA DIRECTIONAL SURVEY TANGENTIAL IqETHO0 NARATHON OIL COMPANY 0-25 LEG a-I SLOT 8 ~/IG. CECL. HEASURED 0 E V-I"A T [" O-N DEPTH ANGLE DIRECTION TVO SUB SEA TOTAL COORDINATES C LATITUDE DEPARTURE D[ST ORIGIN LOCATED AT HO = .... .TS 0 24" N 17E 100 0 13" S 4SW t 0 15" N 25W ..~O 0 14' N 18H 17'~ .... 0 12' N 28H 200 0 13" N 34H 225' 0 25" N 21W "'2~0 .... 0 20" ...... 275 0 20" N 49W ]00 0 ~4~ N 77W - ~5 '-0 ~6''~ ....... N"73H 350 0 48" N 79W ~60 0 4T~ S ~00 0 20· -N ~45'0 0 20" N ~E ~00 0 ~0' N ~6E 0,00~ TVD = ~9.99 7~.99 '99.99 124.99 1~9.99 I74 299 199.99 22~.99 274.99 299.99 3~9.99 359.99 499.98 0.00' 'LATITUDE -56.20 -31.20 '-6.20 18.7g 68.7g 93.79 118.7q 143.79 168.79 193.79 ........ 3~3.78 393.78 O.llS O.05N 0.015 O.08N 0.17N 0.25N 0.33N 0.50N O.71N 0.76N " 0.84N 0.90N I.OON 1.28N 1.36N 600 0 20" '50 0 10' JO - 0 ?$0' 0 800 0 15* 900 0 10" ggO 0 10~ 1000 0 5~ 105'0 0 11-00 0 15' - i-i-~O ............ 1200 I O' N 14E 599.q8 4~3.78 N 87W 64g.98 ~43.78 N O~ 749.98 643.78 N 7~ Tg9.98 693.78 'N .... OW .......... 849,~8' 743.78 .... S ~9k 899.98 793.78 S 59N 949.98 843.78 N' 87W ' 99g."g8 8q3.78 N OM 1049.98 943.78 S 60W 1099.98 993.78 S 45E 1199.97 1093-77 '1.62N 1.91N 1.91N 2.001~ 2,00N 2.06N '2.06N 1.98N 1.91N 1 .gin 1.91N 1.80N 1.33N = 0.00, DE O.16E 0.21E O.ISE O. IOE O.07E O.03E O.OZW O.CSW O. lTW 0.28W 0.52~ O. 77W 1.12k l .25W 1.46W 1.37N 1.25k 1.38k I.]IW 1. ~ 5t,,l 1.57k 1.57k 1.78k l .78W 1 2.03~ 2.10W 2.10W 2.29k 2.32w 1.70W PAGE 2/, DEG. 02/08/73 L 13 S U R E S DOG L EC ANCE ANGLE SEVERITY PARTURE = 0.00 " 0.20 S 55.00E 0.000 0.22 N 77.04E 2.086 0.15 S 83.67E 2. 399 0.13 N 51.93E 1,530 0.19 N 22.30E 0.135 0.25 N 7.22E 0.201 0.33 N 3.q9~ 0.109 0.51 N 9.63W 0.845 0.64 N 16.01W 0.573 0.76 N 21,92W 0,232 0.93 N 34.49W 1.256 1.14 N 42'.66W- 0.210 '- 1.44 N 50.88W 0.850 1.55 N. 54.13W 1.663 1.78 a 55.55W 1.263 1.88 N 47.03W O.883 1.85 N ~2.65W 0.453 2.13 N 40.28W 0.697 2.31 N 34.43W 0.445 2.40 N 37.18W 0.800 2.54 N 38.07W O. 2.54 N 38.07W 0.333 2.72 N 40.83W 0.500 2.72 hi 40.83W 0.500 2.75 N 43.$1W 0.333 2.79 N 46.72W 0.000 2.84 N 47.67W 0.216 2.84 N 47.67W 0.166 2.92 N 51.75N 0.500 3.0~ N 4cJ.96W 2.16 N 51.96W 2.283 SECTI DISTAN O. -0. -0. -0. -0. -0. -0. ""' t -- -lc -1- -1. -1. -1. ~*1. -1,. -,~. -2. -`2. -2. -,2. -.3. -2. -,2. '2. -2e TANGENTZAL HETHO0 O I R E C T I ONA L MARATHON OIL COMPANY D-25 LEG A-I SURVEY SLOT 8 HAG. _. DECL. 24 OEG. 02/08/73 PAGE NEA'SUREO 0 E V 1 A T -i'D N DEPTH ANGLE O[RECTION TOTAL TVD SUB SEA LATZTUOE COCROZNATES PEPARTURE CLOSURES DISTANCE ANGLE SE LEG SECT! VERZTY OISTAN "-1'~50 3 '-Or -- S-~tSE 1300 4 55' S 59E ISSQ 6 45' S T3E 14~ '-9 -5' S ~E I ~ g 0e S 79E t~uO 9 ~S* S TeE ~:;~600 It ~S' S 76E 16t0 12 45" S 76E X 2z~'9 *'gO-'- L1':~3';70" ' 0.41S 1299.T2 1193.52 2.62S 1349.~7 1243.1T 4.34S X396.68 t'2~2'.6e s.g2s 1448.26 1342.06 7.41S 1497.54 1391.34 ~.ITS ~-.-6-~ ...... I~U~'-. ;iF6- ........... 1 I-; 27 $ 1644.38 1~38.18 16o40S 17~,~.26 1635.06 23.23S 1"/8'9.30 1683. t0 27.28S I-8~ ...........1730. g2 3 1884.63 1TT6.43 1931083 1825063 40.67S i'~ T6,T'~ 1812' 54 .... 45, 73S 2025.32 1919.12 51.04S 20.7L.43 1969.23 56.TOS ~~ ...... 20lO.gO 6a;~2S 2162.69 20S6.49 68.64S 2208.10 2101.90 -'~; &'i ~7;2I ................. 77'*02S 2298.26 2192.06 81.2~S 2400 27 30' '$ '/SE 2342.61 2236.41 2500 29 4~J' $ ?SE R~l 30 O' S ale ' ~'/6-0 ..... bO- .... -({' '-$ 'T/E- ...... · ~971 ~JO O" $ 79E · __~oe 2'9 4~S, S e2E 86. 2429.85 2323.65 96. 2448.04 2341.84 97. ze,2.e5 2136.T5 t4g. 3112.V6 3006.16 166. 4'.'-00 z+ - 4.109 4.619 10. 2.858 -' IT.' 1.926 29. 1.~534 33. Z'-031 2.037 2.000 2.666 2.231 LO2. '113,04;E" I17-;3-6' $ "T~;~'gE ...... [-.-'833 ........ 128.02E 132.95 S 74.35E 2.410 1;+3.79E 149.43 S 74.20E 2.259 1.48, 160.33E 166.73 S 74.08E 2'000 " !77.73E 18q.92 S 73.97E 2.166 183. 196.22E 204.29 S 73.88E 2.833 203. 215';-3TE- 22a,-3-8 'S TT.~ '* -2-;.150 ...... 223-°. 23'J.30E 245.11 S 73.73E 2,2/8 243. 255.78E 265.9q S 74.07E 3.370 264. 276.92E 287.05 S 74.43E O.eJ'?EI' 298.23E 309.10 S 74.76E 2.499 306. 04S 320.81E 332.1~i S 7qogSE 2.658 329. 13'~5 ....3a4.34E' 356'-['T S TS;IB'E .... 2.499 .... 20S 368.61E 380.95 S 75.37E 2.000 377. 64S 378. qBE 391.40 S 75.*J2E 7.21~ 36.7. 725 495.4IE 510.87 S TS.86E 0',836 .... SOS. 43S 60I.g2E 619.24 S 76.41E 0.460 905 754.74E 772.98 S 77.53E 0.487 76~. TANGENT[&L METHOD OIRECT - MARATHON OIL COMPANY I 0 N A L D-25 LE SURVEY A-t $LCT 8 MAG. NEASURED 0 E V ! A T ! DEPTH ANGLE DIRECT ION TVD SUB SEA TOTAL COCRD[NATES LATITUOE OEPARTURE 3996 30 Oe , 3 3l 510l 29 0~ Stgg 30 O' ~3SR 31 O' ~S~3 31 15' 588g Il ]0' ,,.6t06 tl 30' 6a6T 31 30e 66~7 32 67~'1 32 "' 6 ~0 .....32' T~70 30 4~' .,92 31 O' 7716 32 0t 3456.30 $350. tO 3726.50 3620.30 225.575 3997.21 3891o01 269.965 4078.21' 39'72,0I 281.50S 4206.T8 4100.S8 305.385 4367.5l 4261.31 337.13S 4~6.~4 4420.~' ~2.835 ~673.62 ~56~.~2 396.g3S 4757.03 4650.83 411,45S ~891.61 4785.~t 5054.89 4948.6g 46~.36S 5349.9t 5243.Tt 527.279 553~.93 5428.73 5757.4T 565i.2T 607.06S 5985.82 5879.62 653.975 6069.32 5959.[2 66g.47S 6~8T.80 638[.60 763.865 6626.6~ 6590.~ 822.[95 67~7.73 66~I*-S3 - 83~.71S 6.80t.73 6695.53 846.39S 6206.89 6800.69 868.8TS SaOE S 8IE S 74E 5'76E S 71E S 696 S ?3E S 72E S 74E S 72E S "70E .... S 69E S ?3E S 70E S S 72E .... S 7dE' S 68E S 62E S 676' S 678 S TOE S S 6'/E S 6"/E 'S 66E S 65E S 63E . , 702[,' 44 6-gi5.24 7132.70 7026.50 7281;13 7174.93 7418.14 7311,q4 757'0.76 7464.56 7765.49 7659.29 YSSS' "34 '30' TggO 34 30' 816e 33 30' .... 8330 22' 15' 8509 31 30' 0735 30 30' '-'~'i'& ........ 3'~' -i"~ ....... S"-~i~ ............. ~".~ 928.245 966.625 'lOOt.?SS 1041.31S 1093.385 l t PAGE 3 OECL. 24 OEO. 02/08/73 C L 0 S U R E S OOG LEG SECT i Ol STANCE ANGLE SEVERITY DISTAN q49.05E g70.13 S TB. O3E 0.I17 1103.13E 1125.q5 S '/8.44E 0.160 1106. 1257.~5E 1286.59 S 77.88E 1.148 1267. 1304.24E t334.2"/ S 77.82E l.ll5 1314. 1377.71E 1411.15 S 77.50E 1.403 11191° 1469.93E 1508.09 S 77.08E 0.305 1488. 1562.23E 1606.7q S 76.58E 0.685 1~88. 1641.75E 1689.05 S 76.40E 2.129 1670. 1686.45E 1735.92 S 76.28E 1.185 t717, 1734.97E 1786.35 S 16.22~ i.453 L767. 1764.18E 1816.72 S 76.18E 0.000 1797, 1858.42E 1915,55 S 75.97E 0,556 1896. 1966.43E 2029'~)'1 S '/5.63E 0.-4~6 2Oil. 2027.8gE 2095.32 S 75.42E 0o414 20T?, 2136.32E 2208.61 S 75.30E 0.262 2190. 2264.47E 2344.43 S 74.99E 0.600 2326, 2400.70E 2488.18 S T4.76E 0.339 2470° 2448.40E 2538.28 S 74.70E 0.567 2520. 2533.14E 2628.17 S 74.54'E' 0.631 2610. 2690.43E 2796.77 S 74.14E 0.443 2780. 2800.13E 2918.34 S 73.63E 1.287 2903. 2827.2~E 2947.65 S 73.~7E 4.468 2933. 2857o15E 2979.89 S 73.49E 1.587 2965. 2918.gOE 3045.48 S 73.42E 1.499 3031o 2991.90E 3123.86 S 73.28E 1,g63 {110. 3062.29E 3199.88 S '/3.13E 0.419 3186o 3152.72E 3297.58 S 72.95E 0o561 3284° 3231.69E 3383-40 S 72.77E 0.841 3371. 3316.46E 3476.09 S 72.56E 0.512 3464. 3418.66E 3589.25 S 72.26E 0.635 397e. 3503' [~E' 3684.02 S TANGENTIAL METHOD 0 ! R E C T I ON A L SU R VE Y HARATHON OiL COMPANY 0-25 LEG A-! SLOT 8 MAG. OECLo 24 OEG. 02/08/73 PAGE MEASURED DEPTH ANGLE DIRECT IOIN TVO SUB SEA TOTAL COORDINATES C L 0 S U R E S DOC) LEG; SECT'IO LATITUDE I~EPARTbRE DISTANCE ,aNGLE SEVERITY DISTANC 80-51 · 82 82§4.51 8388.37 8564.48 8738.4g 8859.43 -gI"I'!'; 67 9172.84 9371.59 10003.86 8148.31 6262.17 6~58.2g 663Z.2g 6753.23 I'180.065 35'/8.09E 1241.47$ 3688.86E 1282.485 3759.90E *133g.llS 38S0.5]E 1396.065 3938,22E 1435.505 3996.69E 9066.64 [53T.gOS 4148.51E 9265.39 16090835 4251.24E 9897.66 1842,665 4539.31E 3767.66 S 71.74E 3892.16 S 7!.3qE .!972.61 S 71,16E 4076.74 S 70,82E 4178.34 S 70.48E 4246.67 S 70.24E ~35'g:39 S 6g,77E 4424.40 S 69.65E 4545.83 S 69.25E 4640.11 S-'68.g4E 4899.05 S"67,90E 0'g374 37~.2i 0,305 3884.g, 0,462 3966.1 0,519 0,282 4174,1. 0.647 Og"O00 0.352 4422.~ 0.T76 4544.5 0.29i 0,588 CLOSURE 4899,05 :$ 67- 54' E 0 [ R EC T I ONAL S UR VE Y .......... I~tTERPOEATEO'""~AE[TE$'"'FOR-,~-I01~ OF 'SUB SE~ DEPTH LEG .4-1 SLOT 8 HAG. TOTAl. COOROINATES SUB ,SEA LATZTUDE DEPARTURE #GASUREO DEPTH TVO 206 206.20 100.00 O.3TN -0.03# ~06 306.20 200.00 O.TSN -O.$Sg ~ .................. 4-0-6~ 2-0 ............. 30-0',-01~ .................. 1-' ~06 ~06.20 400.00 1.39N ..... ~0~ 606.20 50-0.00 1.91N -1.32~ ~ 706: 20 ~g~ 806 806.20 700.00 2.06N 906 ~06-20 800.00 t1Oe 1t0~.20 tO00.O0 1.82N 1206 1~06.20 1100.00 I.IIN -1.46~ 1407 1~06.20 1300.00 -6.1~S "[aTl- 18t8 1506.2o 1400.00 -9o5~S, 33.9~E I606",2-0 .... 1500'*00 ............ l'~;ll"$ ........ 1706.20 1600.00 -20.64S T6.TSE le06.2O 1700.00 -28.79S 190-6%20 ..... --[~O'O~.~O -3BT'OES'~'--I]Sg'ZZE ....... - !48 2~-73 2704 3050 2006.20 1900.00 -48.86S ITO. SgE 2t06.20 2000.00 -61.435 2IO.?TE '2206'~20 .... '210-0-. O0 .......... =72-' 6 I"S ......2'5'4-,-g2 E~ 2306.20 2200.00 -82. lOS 302.27E 2406.20 2300.00 -93.3gS 355.3ee ..... 21JE~' 2 0 '-2 40-0~ O~ ---[05-~ ~ ..... ~'I:'6"~E -' 2606.20 2500.00 -118.38S 461. gSE 2706.20 2600.00 -130.36S 524o42E 2806.20 '2TO0.O0 -141.~85 5111o09E 2906°20 2800.00 -t50.465 637.72E 3006.20 290~.00 -158.41S 694.32E OECLo 2~ DEG. 02/0 . I, IO-TVD VER OIFFERENCE COR 0 0 0- 0 0 0 0 0 1 3 8 t2 23 6 32 9 42 lO 67 82 98 ti3 t5 129 t6 144 tS 159 15 PAGE I 8/73 TANGENTIAL METHOI: TICAL RECTION 0 0 2' 3 O [ R E C T [ ONAL S UR ¥ E .... INTERPOLATED'VALUES'FOR'EVEN 100 FEET OF SUB MARAThCN J~IL::COI~P,aNY 0-25 LEG A-I SLOT 8 NAG. DE MEASURED TOTAL COORDINATES DEPTH TVD SUe SEA LATITUDE DEPARTURE 3393 3206.20 3100o00 3~ &-I, 3306.20 3200.00 36~6 - 3406.20 3300;00 ~-"/4Z 3506°20 3400.00 ,~T ~606.20 3S00.00 - 3973 ~OSg . 3806.20 3700.00 ~20~ 3906.20 3800.00 44]8 4106.20 4~4 4206.20 47.89 4907' ~1486 g603 '?2'0 _.d38 666X 4/S06.20 4300.00 4S06.20 4400.00 4606o~0 4500.00 4706.20 4600.00 4806°20 4700.00 ........ :4g'06.'20 ~eO0.O0 5Q06.20 4'900.00 S106020 §OOO.O0 ....... 52-0-6-:'-20' ' SIO0.O0 §306.20 g200.O0 5406.20 5300.00 ..... ~ 06;20 ..... ~:~0--0, O0 5606020 5~00.00 5706.20 5600.00 5806.20 5700.00 5906.20 5800°00 6006°20 5gO0oO0 ........ -61-O&-;2'~-' -345.79S -368.19S -385.685 -402.38S -419.5gS -43&.485 -45~.23S -475.11S -4q&.07S -517,67S -537.35S 555,-2T5 -57S.35S -596.31S -617;OTS -637o61S -657.g4S 21 2177.36E 2234.94E 2293.54E 2353.20E 24&2.g]E -~lr8; 2-q$-- 2472.64E Y SEA DEPTH CL. 24 DEG. 02/08/73 MD-TVD VERT DIFFERENCE CORR 18q 15 205 16 220 236 16 2.51 15 267 '16 283 16 2q9 16 3t5 16 332 .17 348 16 3&S 17- 383 18 401 18 416 15 430 14 446 16 463 17 480 17 497 17 514 t7 532 18 549 17 566 17 584 18 601 17 619 18 637 18 655 18 673 t8 PAGE [CAL ECTION TANGENTIAL METHOD O I R E C T I ON A L S U R VE Y ]NTERPOLATEC VALUES FOR EVEN I00 FEET OF SUB SEA DEPTH 14ARATt~ON OIL COMPANY 0-25 LEG A-1 SLOT 8 MAG. OECL. 2'~ DEG. MEASURED DEPTH 6898 701~5 7~48 7597 7715 78:~6 " ~7 9 ~ 8 8o7e 83~6 843~ 8666 87e3 8901 9020 9138 *~$6 9~1 960~ 9841 TOTAL COORDINATES HO-TVD TVD SUB SEA LAT[TUOE OEPARTURE OIFFERENCE 6206.20 6100.00 -699.87S 2531.93E 692 6306.20 6200.00 -722.58S 2588.2SE 709 6406.20 6300.00 -745.31S 2644.52E 726 6g06.20 6400.00 -769.00S 2700.09E 742 6606.20 6:500.00 -796.93S 2792.62E 759 6'706:20 6'60'0-°00 .......-824.3':45 ......... 2'8'0S; ~E 775 6806.20 6'/00.00 -847.35S 2899.78E 791 6906.20 6800.00 -868.72S 2918.49E 809 7-006.~,0 "6~'O-O.OO ;894'43'5 ..... 2~9-8-2, X~~ 8~0 7106.20 7000.00 -921-12S 3045oS2E 852 '/206.20 7100.00 -947.24S 3107.06E 872 "7~-O&. 20 7'20'0 ;'O'*O- .... -9 7~. 0'6 S .....~,'ITE 892 7406.20 7300.00 -998.72S 3224.81E 910 7506.20 7400.00 -1024.59S 3280.60E 927 · 760'6'20 7500.00 -1050.79S 3335.05E 944 7706.20 7600.00 -1077.53S 3387.S4E 960 7806.20 7700.00 -1105.84S 3441. IZE 977 7'~0&,'20 7800;00 - 113&'*-~2S .... 3':~q'6" 3 IE 995 8006.20 7900.00 -1166.42S 3552.42E 1014 8106.20 8000.00 -1196.54S 3607.80E !032 8206.20 8100,00 -1226.83S 3662.46E 1050 8306.20 82.00.00 -1257.30S 3716o29E 1068 8406.20 8300.00 -1286.21S 3769.07E 1085 '8~J06.20 8400;~'0 ; I3''20'375 * --382~,'~E 1102 8606.20 8500.00 -1352.76S 3871.5~JE 111.9 8706.20 8600.00 -1385.49S 3921o94E 1135 8806.20 8700.00 -1418.14S 3970.95E llSl 8906.20 8800.00 -1450.75S 401g.30E !167 9006.20 8900.00 -1483o36S 4067.6~E 1183 PAGE 3 02/08/73 TANGENTIAL VERTICAL CORRECTION 19 17 17 16 16 16 18 22 ~0 20 18 17 17 16 17 19 18 l~I 18 17 17 17 16 16 16 16 HETHO0 MEASUREO DEPTH 0 I R E CT I ON AL S U R VE Y INTERPOLATED V'ALUE5 FOR EVEN 100 FEET OF SUe SEA DEPTH MARATHI]N ail COMPANY 0-25 LEG A-I SLOT 8 I~AG. OECL. 24 DEG., 02/08/73 PAGE 4 TOTAL COORO [NATES HO-TVD VERTICAL TVD SUB SEA LATITUDE DEPARTURE DI FFEREI~CE CORRECTION 10421 9206.20 10540 9306.20 1065e 9406.20 J. nT76 9506.20 ,92 9606.20 X'xoo? ...... 11122 9806°20 1215 16 1234 19 t252 t8 t270 18 1286 L6 t301 15 1316 t5 1331 15 - TANGENTIAL NETHO0 NEASUREO DEPTH . .. 1000 2000 ~'000 ~000 DO0 7000 6000 ~OoO 10000 11000 O IR EC[ I ONAL S UR INTERPOLATED VALUES' FOR EVEN I'000 FEET OF V E ~ HEASURED (]EPTH NARATHON OIL COMPANY 0-25 LEG A-1 SLOT 8 NAG,, {]ECL. 24 DEG. 02108/73 TOTAL COORDINATES TV(] SUB SEA LATITUOE OEPARTURE 893,,78 1.91N -2olOW 1872o5~ -~5.735 160o33E 3623.7, -226.13S IIOS.09E 6187.53 -719.7~$ 7034.84 -930.395 ~067.31E 7ee3.2i ~IleI.4O'S ' 8736.81 -1~30.145 ~eee. TS~ 9~93.79 -1731.02s 999,,98 1978 286'2.9 t 372q.9~ 6293,,73 7141.04 T989.4 88q3.01 9699 PAGE NI~-TVC OI FFERENCE VERTICAL CORRECflON 0 0 21 21 137 It6 2?0 133 ~12 1~2 55'5 143 706 151 858 152 1010 152 1156 tzt6 1300 144 TANGENTIAL NETHOD 1 Union Oil and Gas O,'~,,4~ion: Western Region Union Oil Company ot California 909 W. 9th Avenue, Anchorage, Alaska 99501 TelephOne: (907) 279-7681 April 10, 1973 Mr. Homer Burrell State of Alaska Division of Oil 5 Gas 5001 Porcupine Drive Anchorage, Alaska 99504 1RE: WBLL D-25 (11-8) WELL D-19 Dear Mr. Burrell: orr of Drilling and Workover ~---~ the Monthly Rep ....... and the Sundry Enclosed please ~nun~_'~ ubmitted in cup~c~= duplicate Operations for %~ell ~ --, s Well D-19 submitted in ' Notice for the completion of ' Very truly yours, C/Jim R. Callender District Drilling Supt. JRC/sk Enclosures F~rm No. I=--4 REV. 9-~9-67 STATE OF`ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLIC.~TE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS AP1 NUA{ERICA.L ~ODE 50-133-20247 LEASE DESIGNATION AND SE1RIAL NO, ADL - 18729 1. 7.IF INDIA]~', ALOTTEE OR TRIBE NAME OIL [~ GAS ~-~ WELL WELL 0THEE 2. NAME OF OP'~R. ATOR *Union Oil Company of California 3, ADDRESS OF OP~TOR 909 West Ninth Avenue~ Anchorage, Alaska 99501 LOCAT/ON OF WF-J.,~ At Surface: 751' FSL & 1210' FWL, Sec. 6, T8N, R13W, SM, Leg A-1 Conductor 8. Total Depth: 806' FWL & 1092' FNL, Sec. 8, T8N, R13W, SM. 10,004 TVD, 11,350' TMD 8. U'NIT,F.~RA~ OR LEASE NAME Tr~H~n~, B~v lTnjt 9, WELL NQ" ' D-25 {'11-8) 10. FIEI.,D A_ND POOl.. Oil. WILDCA.T McArthur River Field 11. SEC., T., R., Ri., (BOI'I'OM HOLE OB,mCTrV~ Sec. 8, T8N, R13W, SM l~-. PI~/IIT NO. 72-33 ~3. REPORT TOTAL DKPTH AT END oF MONTH, CI-IA~NGES IN HOLE SIZE, CASING ANT) CEiVIENTING JOBS INCLUDING DEPTH SET A/ND VOLI/ME~ USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE ANT) ANY OTHER SIGNIFICANT CI-{A/NiGF. S IN HOL~ CONDITIONS. TRADING BAY UNIT D-25 -- March~ 1973 Operations from March 1 through March 26 are as follows: 3/1 - 3/4 RIH with Howco RTTS tool & set at 10,014'. Pressured below RTTS to 3000 psig. Bled to 1000 psig in one minUte. Casing pressure remained constant at 1200 psig. Reset RTTS at 11,020'. Pressure annulus to 2400 psig, O.K. Pressure below RTTS bled off from 2800 psig to 800 psig. POOH with RTTS. RIH with 8-1/2" bit and BHA on 3-1/2" drill pipe, drilled up Howco E-ZSV retainer at 11,028'. Cleaned out to 11,226'. RIH and set RTTS tool at 10,920'. Broke formation down with 3400 psig at 2 BPM. Cement squeezed perforations 11,080-11,200' with 150 sacks cement. Maximum shutin pressure during squeeze 2500 psig. No squeeze obtained, cleared perforations. Reset RTTS at 10,918'. Tested casing to 3000 psi. Mixed and pumped 150 sacks class "G" cement displaced with mud, unable to obtain squeeze. Maximum shut in pressure during squeeze 3900 psig. Cleared perforations. Reset RTTS at 10,918', mixed and pumped 100 sacks cement. Displaced cement with mud. Squeezed in ~ve stages with final buildup to 5000-psig. Held pressure for 30 minutes, released pressure held O.K. Reversed out no cement returns. POOH rigged up Go-International. Perforated two holes per foot from 10,590- 10,593'. RIH and set RTTS at 10,445'. Cement squeezed perforations with 150 sacks cement, squeezed to 4000.psig. Pressure on casing increased from 1200 to 1400 psig.during squeeze. Increased weight on RTTS, repres- sured casing to 1000#. Pressured drill pipe 4500 psig. Pressure increased on casing to 1050 psig. Released RTTS POOH made up 8-1/2" bit and BHA and RIH to 10,400'. WOC. 3/5 -3/11 Closed BOPs. Pressure tested casing to 3000 psig, O.K. Tagged cement at 10,455'. Drilled cement to 10,617'. Pressured casing to 3000 psig. Pres- sure bled to 2750' in 20 minutes. POOH. Picked up RTTS and RIH. Set RTTS at 10,630'. Pressure tested squeeze perforations at 4000 psig. Bled to th for oing is true mild correct' ....'" ~ Drilling Supt ..... / / il~lJ 'lita with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. ILJJ D~ument TranSmit~ Un'irJn Oil Company of C.' 'nia ,. unlan DATE SUBMITTED I'AC'COUN'TING '~VlON T I~-I 4/11/73 , , · TO FROM Hr. John Levorson Division of Oil § Gas llarry C. Lee AT AT State of Al~ka Southe~ AZ~ka District TELEPHONE NO. TRANSMITTING THE FOLLOWING: logs on Trading Bay Unit, 14~th~ l{ivi~r CiAl~ ~11 n_25:, 2" 6 5" . 2'~ ~. ~'~ 2" ~ 5" BHC 5" Cement Bond ,(variable density) 5" Gement Bond (Gm ~) . . , . ......... · ....- .: .... - ....... DisfHat 909 WEST ¢'T~-! ,~V~:}i'~U~, 57H FLOOt ANCiqC)a,:,.G~, ALASKA 99,501 ....... / FORM 369 (REV 2/70) PRINTED IN U.S.A. ,: WELL wELL OTHER 2. NA2dE OF OPEI~ATOR *Union 0il Company of California 3. ADDRESS OF OPI~TOR 909 West Ninth Avenue, Anchorage, Alaska 99S01 4. LOCA/~iON OF %V~LT. At Surface: 751' FSL ~ 1210' FWL, Sec. 6, T8N, R13W, SM, leg A-l, Conductor 8 At Total Depth: 806' FWL ~ 1092' FNL, Sec. 8, T8N, R13W, SM 10,004 TVD, 11,350' TMD 8. T3q%'IT,F~{ OR LEASE NA3~E Tradin~ Bay Unit 9. WET.T. NO, D-2.q (11-8) 10. FIF_J~D A_ND POOL: OR WILDCAT .McArthur River Field 11. SEC.. T.. R., M.. (BO~I'OM HOLE OB.mCTIVE) Sec. 8, T8N, R1SW, SM 1~.. PERMIT NO. 72-55 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IJLN'GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/q-D VOLUNiES .USED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS, JUNK LN HOLE AND SIDE-TRACKED HOLE A2qD A~Y O'iw~IER SIGNIFIC~A~NT CI-I~GES IN HOL]~ CONDITIONS. TRADING BAY UNIT D-25 FEBRUARY, 1975 Operations from February 1 through February 28 are as follows' 2/1-3 Drilled & surveyed 12-1/4" hole from 11,292' to 11,350' T.D. Ran Schlumberger open hole logs (DIL, FDC-GR & BHC-SONIC-SP logs) from 11,350' to 2,514'. Circulated hole clean. 2/4-7 Rigged up ~ ran 279 joints, 9-5/8" 47# P-Il0 Buttress casing , , , · Landed casing at 11,337' & cemented in two stages as follows' ls..% Stage 13,557' - 7,150' Cemented with 800 sacks class "G" cement with 4% gel, 1/2#/cu. ft. per lite, 0.$% R-$ ~ 0.8% D-51 followed by 550 sacks class "G" neat cement with 0.8% D-51, 1% D-19 ~ 0.5% R-5 pumped 10 BBLS mud sweep followed by 10 BBLS water ahead of cement slurry. Bumped plug with 2,000 psig, held O.K. Dropped DV bomb and opened stage collar at 7,150', circulate 1-1/2 hrs. Approxi- mately 60 BBLS cement returns from first stage. 2nd Stage Cement volumes same as first: stage. Pumped 10 BBLS mud sweep ~ 10 BBLS water ahead of slurry. Bumped plug with 3,000 psig, O.K. Approximately 15 BBLS cement returns to surface. Landed casing in slips, cut off casing ~ installed tubing head:i& tested to 5,000 psig, O.K. R1H with bit & cleaned out. Ran Schlumberger cement bond log from 11,557' to 2,500' Log indicated poor bonding. Set cement retainer at 11,26½' & cement squeezed around shoe with 500 sacks class "G" cement with 1% D-19 ~ 0.5% R-S final squeeze pressure 5,000 psig, est. 200 sacks cement behind ipe.I hereby c~tif, t~t the fo .~[~~'rrec~ // .Jim g. : . · A'f NOTE--Report on this form is required for each calendar month, regardless of the status of operation& and must ~ filed in duplicate with the Division of Mines & Minerals by the 15th ~ the succeedin9 month, ~less othe~ise directed. 2/8..1 Reran Bond log, still indicated poor bonding. Perforated from 11,2S1'-it,2S2'. Set retainer at'il,250'. Attempted to cement squeeze, no breakdown at S,000 psi. Closed re- tainer. Displaced mud with filtered inlet water. Layed down S" drill pipe. -Picked up ~ ran 4-1/2", 12.6# seal lock tubing, Otis 9-S/8" retrievabie hydraulic packer, Otis gas lift valves ~ ball valve. Displaced water with diesel. Unable to set packer. P.O.O.H. Reran tubing string with new Otis R. H. packer. Set packer at 10,S26', nipple down BOPs, installed x-tree ~ tested to $,000 psig, O.K. Rigged up to perforate - RIH with expendable strip perforating gun ~ stuck gun at 10,$60'. Fished for perforating gun - unsuccessful. Removed x-tree, installed ~ tested BOPS. Pulled out of hole with tubing ~ packer. Recovered perfor- ating gun in tubing. 2/17-21 RIH ~ set Baker, model F, 9-5/8" x 6" bore permanent packer at 10,528' Reran 4-1/2" production tubing string ~ stabbed into packe~. Rigged down BOPs ~ installed x-tree. Tested tree to 5,000 psi. Rigged up Go-International ~ perforated Hemlock Bench #5 from 11,200' to 11,080' under drawdown conditions. Began gas lifting well. Samples indicated well producing at high water cut. Placed well on produc- tion test at 12 noon, 2-19-73. Produced 647 BF in 24 hrs. S0% water Cut. Ran temperature differential ~ R.A. tracer logs to determine fluid entry. Logs indicate fluid entry from above Hemlock ~ from water bearing bench #6 in HemloCk. 2/22-28 Rigged up blow-down line ~ bled gas off of:annulus. Opened x-o circulating sleeve at 10,488' ~ displaced hole with drilling mud. Removed x-tree, installed ~ tested BOPs. P.O.O.H.'with tubing. Milled over ~ retrieved Baker per- manent packer. RIH with 8-1/2" bit, ~ BHA on 5-1/2" B.P. ~ cleaned out to 11,220' Ran .gauge ring ~ junk basket to 11,12S' Set Baker, ~odel K, cement retainer at 11,060' with wire iine. RIH with 3-1/2':~'~drill pipe. Stabbed into retainer, pressured up under retainer to 2,000 recorded 2,000 psig on annulus. Closed sleeve in retainer & pressure test C.P. to 1,000 psi, O.K. POH. RIH with bit ~ drilled up retainer. Cleaned out to 11,230'. Ran junk basket & gauge ring to 11,231'. Set Baker, mOd~l K, cement retainer at 11,020'. RIH with stinger on 3-1/2 D.P. pressured drill pipe to 5,000 psig, no break down. Pressured annulus to 2,000 psig. Increased pressure in drill pipe to 6,000 psig, obtained break down, pumped into formation at 2 BPM at 4,400 psi. Pulled out of retainer & spotted 25 BBLS water. Stabbed back into retainer. Pumped 11 BBLS water at 3-1/2 BBLS/min. at 3,000 psig. Pressure increased an annulus from 1800 to 2500 psig indicating communication. P.O.O.H. found inner mandrel of retainer on stinger. RIH with bit ~ drilling assembly & drilled up retainer. Cleaned out to 11,230'. Ran junk basket & gauge ring. Ran & set Howco 9-5/8 c~ment retainer at 11,028'. Ran stinger & stabbed into retainer. Pumped into formation at 2-1/2 BBLS/ min. rate at 4600 psig pressure increased in annulus from 1000 psig tO ~il.21Q~) indicating communication around retainer. P.O.O.H. with stinger. Marathon Oil Company - Sub-Operator OIL AND GAS CONSERVATION COMMITTEE 50-133-20247 o ............. S. LEASE DESIGNAT20N ~..N'g MONTHLY REPORT O:F DRILLING AND WOR'KOVER OPERATIONS ~L - 18729 i.- ..... ; ¢. Ir I~i'~, A~T~E OR T~I~E .~ ~--~'":~0-'~ , WELL, ~ ~ WELL Union 0il Co~v of Caliio~ia T~ad.~~ ~y ~it ...... 3, ADDRESS OF OP~OR 9. WE~ NO , 909 ~est 9th Avenue, ~ch0ra~e Ala3.ka 99501 ~15 (11-8) H~r~hur River F Conductor 8- 751 I FSL, 1~10.3~ Section 6: T8N' R13W, S.M. ~'~ o~~ Section 8' TgN, R13W, S. M. I2. P~IT ~O. "' 72-~g , , ,, , ~,, , .... 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~'GES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PERFORATIOI~S, TESTS AND RESULTS. FISHING JOBS JUNK IN HOLE A_ND SIDE-TRACKED HOLE AND ANY 07~ER SIGNIFICANT CHA~ IN HOLE CObTDITIONS. Spudded TBUS Well #D-25 at 3:00 am, 12/16/72. Operations from the 1st of ~2r~r~ th~ the-51s-t'6fJanuarya'~e as follOWs' Drilled 12 1/4" hole from 5101' to 7470'. Pooh. Ran 9 7/8" turbodrill and drilled from 7470' to 7501'. Pooh w/ turbodrill. TIH w/ 12 1/4" bit and opened 9 7/8" hole to 12 1/4" from 7470' to 7501'. Continued drilling 12 1/4" hole to 11,292'. Now: Drilling at 11,29Z'. FF.. B 15 g?3 DIV::~IObl GP OIL AHD GAS ANCHORAGE Marathon Oil Company- Sub-Operator. hereby ~Z~: the ~)~s~ s~o~-sn .a-z;ze'_'_'_'_'_'_~' ~.. ~~~ m ~t~ ~t ~1 o S~mt_ ~ ,, 2/12/73 ...... v NOTE.~eport %~'t,i~o~-r%~refl for each calendar month, regardless of the status of operations, an~ must ~ file, in duplicate with the Division of Mines & Minerals by t~ 15th of the succeeding month, unless othemise directed. Form 1~o. REV. 9-30-~7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O:F 'DRILLING AND WORKOVER OPERATIONS 2.NAME OF OPEi~TOR Union 0il Company of California 3~ AD~R~.SS OF OPm~TOR ' 909 West 9th Avenue; Anchorn~a_ Alnck~ 4. LOCA~ON OF WFJ~L ~' ' .... Conductor 8' 751.1 FSL, 1210.5' Section 6: T8N, R15W, S. 54. SUBMIT IN DUPLICATE %. API NLrMERIC~kL ~ODE ,, Trading 99501 ,0D;~ s (]1-~3 ~rthur R~ver n. szc., T., R., ~.. (SO~O~ HO~ Section 8: TgN, R15W, S. 54. 12. PICRMIT NO. 13. REPORT TOTAL DEPTH AT F-,ND OF MONTH, CHANGES IN HOLE SIZE, CASING ~ CEMENTING JOBS INCLUDING DEPTH SET ~ VOLI/IVi~ USED, PF~Oi~TIONS, T~TS ~ RESULTS, FISI{ING JOE~, JLrNK IN HOLE ~%ND SIDE-/q~ACKED HOLE A~TD A_NY OTHZER SIGNIFICANT CI-IANGIC~ IN HOL]~ CONDITIONS. Installed 20" hydril and riser. Spudded TBUS Well #D-25 at 5:00 am_,!2/!6/7Z. Drilled 12 1/4" hole to 2521'. Opened 12' 'i/4'"-hole tb 17 1/2" to 2521'. Ran 64 joints 15 5/8" K-S5 61# buttress casing to 2514'. Cemented w/ 1600 sx class "G" cement light slurry and 400 sx of class "G" neat. Removed 20" hydril and riser. Installed 15 5/8" BOPF, and riser. Tested to 5000#. Tested 15 5/8" casing to 1500 psi-ok. Drilled 12 1/4" hole to 5101'. Survey: 5101 'MD 29° S75E. s~a~m~/ JLm R. Callcndcr =~ District Drilling Supt. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, an~l must be filecl in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. 909 ~ 9th Ave .Inclosed is ~ ~!:~d ~l~pttcetton ~ pe~mlf ~o drill the ~tt, durl~ h ~ of l)t.i)lr, t972, from h ~tly Vef~le~ pl~, tn ~ event of suspension or atilt plea. give thts office adqquate advance notlft~tt~ ~o that ~e ~ ha~e a .ltnes~ prgent. Very. truly ~, cc: ~"t~t of Fish a~ ~, ilab-lht Section ~/o enct. union Union Oil and Gas P~'~Lsion: Western Region Union Oil Company of California 909W. 9th Avenue, Anchorage, Alaska Telephone: (907) 279-7681 ._?.N% ! _ l -~ 4 ~N~ I ! I ~ ~o~ 'December 8, 1972 J ~EV J I D.~,T ~ SEC I C~F~, , State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of Alaska Well Tradi,ng Bay Unit D-25 Gentlemen: Enclosed i's an Application for Permit to Drill the subject Trading Bay Unit Well along with Union's '$100.00 check as a filing fee. In compliance with Rule 5 Conservation Order No. 80, Union Oil Company of California, as Unit Operator, requests approval of the application. The Trading Bay Unit participants, who are the only affected parties, have been notified of the location of this well. Very truly yours, UNION OIL COMPANY OF CALIFORNIA Un i t Operat. o¢-' . WSM:jb Enclosures cc: Management Committee Trading Bay Unit, w/encl. F~rm P~I HEY. SUBMIT IN TRIPE (Other instructions reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK"' 11~, TYPE OF WORK DRILL [] DEEPEN [] PLUG BACK [-I b. TYPEOF WELL OIL [] OAS ~-~ SINGLE[] MULTIPL~ ~_] WELL WELL OTHER ZONE ZONE 2. NAME OF OPER/[TOR Union 0il Company of California* 3. ADDRESS O~ OPERATOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCATIOA1'OFWELLAt s.r£ace Leg A-1 Cond. 8, 751.1' FSL, 1210.3'PWL, Sec.6, 1.8 N,'R.13 W,'SM. APl #50-133-20247 5. 6. LEA~E DESIGNATION AND SERIAL NO. ADL-18729 I. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO, D-25 (11-8) 10. FIELD AND POOL, OR WILDCAT McArthur River 11. SEC.-, T., R., M., (BOTTOiVI ^t proposed prod. zonelOp of Hemlock - 600'FWL, 800'FNL, Sec. 8, T.8 N, R.13 W, SM. DISTANCE IN MILES AND DIRECTI~N:)F-IOM NE~ES~ TOV~N OR,POST OFFICE* .... 21 miles northwest Of Kenai~ Alaska 14. BoN~ INFO,~A=ON: Uni~ted-Pacif.~ic Insurance Co Statewide - ' TYPE . Surety ?nd/or. No~B-55502 . . -. m LOCATION TO NEAR~ST "' " !' '3085.00 P.OP~TY O, ~"AS~ ~'"~, ~. 4'680' (Also to nearest drig, unit, if any) 1 ~. DISTANCE FROM P~OPOSED L~A~O~* ~ ~ " 119- P~OPOS~ D~ · o .....~ ~. ~,~o. ~o~,~. ~ /- MD -~ ll ,300' O~ APPLI~ FO~, ~. ' 1,800' from-B-17 ~ ~-m TVB -.9,936' 21. ELEVATIONS (Show whether DF, ,RT,._GR, etc.) 106.00 RT MSL 23. ' '~ " ~OPOS~ CASING ~D ~EN~NG PROG~ HOLE OBJECTIVE) Sec. 8, T.8 N, R.13 W, SM _ *~°'~.t $100,000.00 17. NO. ACRES ASSIGNED TO THIS WELL 80 20. ROTARY OR CABLE TOOLS rotary 22. APPROX. DATE WORK WILL START* December 1;5, 1972 SAMPLES AND CORE CHIPS REQUll{ED iDIHECTIONAL SURVEY YES [] NO tOq"HER REQUIREMENTS: A.P.I. NUMEHICAL CODE See Transmittal Letter APPROVED BV ...... 'TITLE.. Cha i rman *See InstructiOns On Reverse Side December II, 1972 December II, 1972 DATE ,[ [] ~z~s )~.o Plan .to install 20" riser and 20,' hy-drill on 33" Piling, drill 17-1/2" hole to approx. 2500' Run appr0x 2500'..~of"61~ii!j3-§/8, casing and cement to surface rW/2000 sacks of cement. Install 13-5/8" B.0.P..and 13-5/8" hy-drill test to 3000#. Drill a 12-1/4" hole to approx. 11 ~-300' ~ .-r?~9~S/8','...casing and cement w/2500 sacks ce~e~~ ~o~1 ~~ a producing wel 1~, : ~ ': :~-..-.:'-.~? ~ - ' Bottom hole location - 950 FN[-,-970 ~L, Sec. 8, T. 8 N., R. 1 DECO 1972 * ~rathon 0il C~pany - Sub,Operator - ~lly Varden Platform DIVIS~N DP OIL A~ ~AS - ~ ABO~ SP~ D~BE ~OPOS~ P~OGR~: If ~1 ts W dee~n or plug ~ck, give ~ on present~~d propos~ ~w produ~ive zoo. If Pr~ ~ to ~ill or d~n d~e~Lo~ly, give pe~ent ~ on subs~face ~~ ~~d ~ue venial d~. Gi~ blo~ut preventer/~rogra.m. 24. I her~i~at the F~g '~; ~ue ~ ~ ' .~~/~.~~/~j~~ .... ~x~., December 8, 1972 =~ L~ndm~n (This space for S~te office ~) ~ CONDIGNS OF ~P~V~ IF ~' ,, SIZE OF HOLE SIZE OF 'C~SiNG ~ WEIGHT pER FO6T GRADE ~ sETTING DEpTH ' QUANTIT! OF , .,, 17-1/2 13-3/8 ..... :_61#.-. K-55 2500 2000 sks ~r~.-..-, ~.~:,,';-'~ ~.~:., 12-1/4 9-5/8, .: 47~ . ,,. N,80.. I1.300 . - ..: . -..;,_ /.. ,_ ..':' . ..... .. . UNIO N-MA RATHON DOLLY' ,32 D-II (14-52) · ' $4' "8 D-32 ' )-31 (12X-5) (~,a-6) .~_.-----~ ~..~._.____._,_.~ !,/el' ,-~ a2-5) (42-6) .5 (24-5) 'MD 'VD D-f7 (44 - 6') -~. T/HEM TMD TVD 9581 D~9 (42-7) D-24~ D-14 (44-7) ( 2- U-M ADL'18729 PPSS D-8 (24-8) ADL 17579 ,, G-14A T9N R 13W I NI;R. I -'"'--"'--' -'T"- %~,, ~TSN RISW ~ 8 TD 11,281' ~ D-19 ~ (22-4) '-0 D-lO (44 -5) D-££ (33x-18) J¥ (12X-17) D-21 ' ,' ,//~ (24X-17) , -scALE: I": 2000' * UNION WELL LOCATION MAP MARATHON SUB-OPERATOR · TRADING BAY STATE UNrF,,D~5 (il- 8) o 2o°° Company Lease & Well CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1. Is well to be located in a defined pool ................. ~ 2. Do s tatewi de ru 1 es apply ............. ........... 3. Is a registered survey plat attached .................. 4. Is well located pre~er distance from property line ........... ~ 5.(,~' Is well located pre~er distance from other wells ...... . . . . . . ~< 6. Is sufficient und~icated acreage available in this pool ........ x X 7. Is well to be deviated ......................... ~< 8. Is operator the only affected party ................... g. Can permit be appreved before ten-day wait ............... 10. Does operator have a bond in fOrce ...... ~ . .~ .......... r Is conductor strin~ provided ll .,, o ..................... 12. Is enough cement used to circulate on conductor and surface ...... 13,.i~ '~ill cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ........... 15. Will surface casing cover all fresh water zones ............ 16. Will surface csg. ieternal burst equal .5 psi/ft, to next string .... 17. Will all casing gi'ye adequate safety in collapse and tension ....... 18. Does BOPE have sufficient pressure rating ............... .<~ Additional Requirements: Approval Recon~ended: TRM , ,, I KLV ~l~l~. i LCS Jcx