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Home My WebLink About185-174 XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ImaWrOject Well History File Coverege I Organizing Idone) ~IIIIIIIII"III RESCAN DIGITAL DATA :' ~ ~M~ 0 Diskettes, No. ~IIIIIIIIIIIIIIIIIII OVERSIZED (Scannable) ~ ~ I I L <g $- L t ~ Well History File Identifier o Maps: o Grayscale items: o Other, Noffype o Other items scannable by large scanner o Poor Quality Originals: ~ts~w~~~ NOTES: . OVERSIZED (Non-Scannable) ~rious kinds o Other BY: BEVER~CENT SHERYL MARIA WINDY Project Proofing 111II111I1111111111 BY: BEVERL~CENT SHERYL MARIA WINDY Scanning Preparation 3- x 30 = :d7() + ~::¡ = TOTALPAGEsf)?Y- BY: BEVERL~BI~CENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ 7f:- PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: -/- YES _ NO BY: BEVER~R~~VINCENT SHERYL MARIA WINDY DATE:)/~Oð/~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA WERE FOUND: YES NO BV: BEVER LV ROBIN VINCENT SHERVL MARIA DATé>4 Ckl/~ (SCANMMG ,. CO"""'" AT TH,s ""'''' UNCESS ""COAL AITENnON,s ",au,"", ON "" DM,," ,AGE ""S ..' -. - '. 1I1111I111111111111 DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScan ned (individual page [special .ftentloa] £ca,mlng Gompl.,.d] 111111111I111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (dons) 111111111I111111111 12/10/02Rev3NOTScanned.wpd . . MGS FIELD WELLS CHANGE WELL STATUS FOR WELLS WITH LATERALS FEBRUARY 16, 2006 The following wells status was changed from SQZED to I-OIL. These wells had laterals drilled against them and production was assigned to all laterals in Cook Inlet when the wells were first drilled. Since then, AOGCC changed the policy about lateral wells and assigning production against lateral API numbers. This policy is like the lateral wells on the North Slope. Today I notice wells producing in the MGS field with a status not conducive to the well status and changed it to I-OIL. All the wells show oil production over the years. The status date reverted back to the date the well was completed as an oil well. The following wells were corrected: MGS A12-01 MGS A13-01 MGS A14-01 MGS A22-14 MGS A23-01R MGS A31-14 MGS A41-11 PERMIT 177-055 PERMIT 166-015 PERMIT 167-079 PERMIT 185 -068 PERMIT 187 -093 PERMIT 177-031 PERMIT 185-174 '~;¡l' .'~Îi\¡.~',.~It.; '. ~~w "~'\ ~~~~.. t All production has been assigned back to the original well API number, no production is assigned to a lateral well API number. -::> .'''--' ~1 ~1 -' ~". .' I ., . ~~/(A_~_ i . It / .' j'i41<lo { ( TONY KNOWLES. GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 A"~ASIiA OIL A5D GAS CONSERVATION COMMISSION 1999 William Miller Cross Timbers Operating Company 4, August HC01 Box 485 Old Wik Road Kenai, AI< 99611-9704 Permit # 67-079 Mr. Miller, Administrative Abandonment Action Middle Ground Shoal Wells A33-11 Permit A22-14 Permit # 85-068 A14-01 A12-01 Permit A31-11 Permit A13-01 Permit A41-11 Permit # 77-031 ~~ # 85-235 # 77-055 # 66-015 Dear Re: number: letter reflects the lateral well that replaced the original well by well number, permit number and API A12-01LN (permit # 94-120, API # 50-733-10081-62) permit was approved 9/29/94. A13-01LN (permit # 94-105, API # 50-733-10079-61) permit was approved 8/05/94. A14-01LN (permit'# 94-119, API # 50-733-20067-61) permit was approved 9/27/94. A22-14LS (permit # 94-071, API # 50-733-10085-62) permit was approved 5/13/94. A31-14LW (permit # 94-044, API # 50-733-20305-62) permit was approved 3/23/93 A33-11LS (permit # 93-180, API # 50-733-20383-61) permit A41-11LN (permit # 94-087, API # 50-733-20378-61) permit was approved 11/30/93 was approved 6/28/94. This bore. The lateral along with the original hole will be mdicates administrative abandonment (SQZED, AOGCC AOGCC procedures for wells where additional be reponed to the original API wellbore (-00. -0 The replacement well incorporates a lateral with the existing well used for production of hydrocarbons. A review of both well files :'1 status) of the originating well bore is appropriate according to I urrent permitted laterals are drilled from an existing well bore. Producti~ n wil or etc) and not to the lateral API wellbore (-60, -61 or etc) the conductor unless drilled to straighten the AOGCC databases require each conductor original permit only eliminates be maintained in their respective 20 AAC 25.005(e) requires a Permit to Drill for each hole drilled below original hole, sidetrack junk, or correct mechanical difficulties. In addition, have only one permit number and API number. Administrative abandonment of the duplication in the databases. Information for the original well and its replacement will files until plugged and abandoned according to 20 AAC 25.105 be correctly identified on subsequent will Please notify other cognizant personnel in your organization so that the well repons and applications submitted to the Commission. Chairman ! I ¡ I ! I :,i~1 ::::+fi , i,' :',~i ~I" ,. "11'. , . ' , . . { . ,. : . . . .. ( : .;. .~. ... .' . ~ ".... ... . . PLUGGJ:NG &: LOdÂi'3:0N-, . CLEARANCE REPORT State of Alaska' - . o ALASJ,tA C?XL '= GAS °c;œsBRVATXOH cmaassXOH .. . t . . . o 0 .. .. . . - . ~ 0 - . 0 . . ; . .:. .... .... PTÐ No. ß5'- of'~ 4 : Lease A.J)L... l~-:}S:~ . . Kemorandum '1'0.· ~ile·: HZ ~ No ~ :}·3~:. '2..03 -:+ß - 00 Well X_a M{,~ t\ - A\- \ ...l \. ~eratö.ro. . ~. J4É:J..L.. ~.., L LIoJ ~ ¡'p . . Locat.ion ~-~ \.\.~ -To'òN - ~r~V\J . . . . . Ahnd Date b/ 2..& J ~.5 . . -. o. I C!f ii1..1 sS" .,' ~ . .-. . m.: . .' Spud: \oq~_1 ., Complet.ed ~ , . . . . Note casing size" ·wt, dep~, c:mt'vol, ·i:.proåedure. Sfc Csg: 1 ~3/&~' 'bJ ~_.~- . . ¡Q I ß oß' ~I -:J 5'"0. s)(. Long <:sg: ~,S"'IB ,0 ~3.S 14.1- Ñ"ßO' 0" 'o@ ~ Zb -:¡' w/850 5X. . . . Liner: ':},. ./-. þo.\....o : hq~'~~ -10~.-+b ·t}J/.I~~O ~ : Z. $.2--. : P..îlo Perf intervals - . tops:: . ~- ~·1;..d' - ~: ~ lö~·82i··· - Review the well file, and,' ccnDinen·t. on' plugging, well head. st.at.us, and locat.ion cl~arance - provide loc. clear. code. IkFL.. ., ~4ioo" Plugs: P~,,^o ~I"G.L. oPl.I.J(. ~ &..! ~ "~ S" TÞ.~~n· Ç'"-,'&.~ l..M.-r :~ ~ ~T '"'oJ q..qao - . F"'&.ðM· q+.. 01 :u - - - Well head cut off: 'l\) ~ - . - - Harker post or pl~te: ~o - LocatioD'Clearance: - - Conclusions: M .... 4' - \·1 ~ - PI:'f;:t ):;0 W Code Signed 1Ñ Dat.e ð ~~&~Œ @~ &~&~ ~~ (' WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSION ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPV; (907) 276-7542 September 22, 1994 AI Foglesong Shell Western E&P Inc. 130 Trading Bay, Suite 310 \ \ Kenai, AK 99611 Re: Administrative Abandonment Action Middle Ground Shoal A-41-11 Permit # 85-0174 Dear Mr. Foglesong: With the completion of well A41-l1LN (permit # 94-0087, API # 50-733-20378-61) in July of this year, the well file for well A-41-11 (permit # 85-174, API # 50-733-20378-00) has become redundant. Accordingly, we are administratively closing the A-41-11 well file. @ printed on recycled paper by c;a ( State of Alaska Oil and Gas Conservation Commission ( Memorandum 1994 September 20, Permit # 85-0174 Administrative Abandonment Action Middle Ground Shoal A-41-11 Permit # 85-0174 A-41-11 File: Well To Re: file Well A-41-11 was replaced by A41-11LN (permit # 94-0087, API # 50-733-20378-61) when the permit was approved June 28, 1993 and operations completed in July 1994. The replacement well incorporates a lateral with the existing well bore. The lateral along with the original hole will be used for production of hydrocarbons. A review of both well files indicates administrative abandonment of the originating well bore is appropriate according to current AOGCC procedures for wells where additional permitted laterals are drilled ftom an existing well bore. well memo will remain at the front of the subject This 20 AAC 25. 005( e) requires a Permit to Drill for each hole drilled below the conductor unless drilled to straighten the original hole, sidetrack junk, or correct mechanical difficulties. In addition, AOGCC data bases require each conductor have only one permit number and API number. Administrative abandonment of the original permit eliminates duplication in the databases. Information for the original well and its replacement will be maintained in their respective files. All future correspondence with the AOGCC should reflect data. The operator has been notified of this action. the new permit number, API number and well Statistical Technician 'Stiiv-e.,.' Statistical Technician Petroleum Geologis c¡ /"/Þ Reservoir Engineer ¡f,4J:> Commissioner (~ Shell Western E&P Inc. ~ 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 \ 1994 19, April Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 10-407) for SUBJECT: SUBMITTAL OF WELL COMPLETION REPORT (FORM MIDDLE GROUND SHOAL A41-11 REFERENCE: APPROVAL NUMBER 93-334 Further to my telephone discussion with Joan Miller, please find enclosed duplicate copies of the Well Completion Report (Form 10-407) for Middle Ground Shoal A41-11. The daily report summary is attached to the prior correspondence dated April 6, 1994. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, cr.-Q~ RIGE\\J£D Paul Huckabee Staff Production Engineer 1994 ).\aska Qi\ & Gas Cons. Commission Anchorage APR 2 0 ( STATE OF ALASKA ( . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ----- Classification of Service Wel Wel of Status 1. o SERVICE ABANDONED 0 SUSPENDED 0 L LX GAS 0 - - Name of Operator Shell Western I o 2. 7. Permit Number 85-174/93-334 8. API Number 50- 7 3 3 - 2 0 3 7 8 - 0 0 9, Unit or Lease Name Middle Ground 10. Well Number A41-11 11. Field and Pool 99501 31. T8N, Inc 5th Ave Suite 920 Anchorage, AK 4. Location of well at surface P 1 at form II A II , Le g 4, Cond uc tor Conductor @15591FSL & 3881FEL of Section 11, R13W, S.M. At Top Producing Interva 8120 1 & 9501 W of SE T8N . & , E&P W Address 601 3. Shoal @4300 , S.M 'FSL 'TVD ,R13W @4469 corner N G Pools F MGS-E , 11 Section of FEL 1 195 of Section 11, At Total Depth1 0 18 5 1 ''¡'VD T8N. R13W. S.M.", 5. Elevation in feet (indicate KB. DF 1161 KB ions No, of Complet 1 of Permafrost & L Thickness , 15, Water Depth, if offshore 80 feet MSL 20. Depth where SSSV set 2 32 5feet MD , No. Aband. 1 Date Comp., SusP. or 11/28/85 19. Directional Survey YES ex NO 0 Designation and Serial 18754 4. 6, Lease ADL 13. Date T.D. Reached 1 10/19/85 18.Plug Back Depth (MD+TVD 8631+10,114 etc. N/A PCM,DIFL,BHC-AL.CN.CDL.CAL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 17, Total Depth (MD+TVD) 109461 +101971 110, 22, Type Electric or Other Logs Run DILL Acoustic, GR, 23 12, Date Spudded 9/12/85 AMOUNT PULLED .N.tA .N.,LA N/A CEMENTING RECORD 7¡;n Sx RI:)O ~y L390 Sx HOLE SIZE 17 £;11 12 - 25 8 5" BOTTOM lROR' 7?ñ7' 10946' CASING SIZE WT. PER FT, GRADE TOP 13-3 8" ~ 9...= 5 / 8 II . --D..!. 7 II 26- 32# N"8 0 I I? 1":): b, 6980 , TUBING RECORD - - MD PACKER SET (MD 7535' DEPTH SET 7587' 25. SIZE 2 24, Perforations open to Production (MD+TVD of Top and Bottom and nterval, size and number FRACTURE, CEMENT SQUEEZE, ETC, AMOUNT & KIND OF MATERIAL USED 7. 5% HC1/Xylene (75:25) 99BBLS Pad acid MD , II ACID, NTERVAL( -10600 7L8 I , 26. DEPTH 8763 Summary attached Perforation See PRODUCTION TEST Flowing, gas lift. etc. 27, Date First Production 3/07/94 Method of Operation Gas lift PRODUCTION FOR 01 L-BBL TEST PERIOD It 52 CALCULATED ... OIL-BBL 24-HOUR RATE"" 1 0 4 CHOKE SIZE GAS-OIL RATIO 1 2 8 4_50 OIL GRAVITY-API (corr 34.7 WATER-BBL 6 WATER-BBL 12 GAS-MCF 23.5 GAS-MCF 47 CORE DATA dips and presence of oi Hours Tested 12 Casing Pressure 765 Date of Test 3/11/94 F low Tubing Press 100 28. Brief VED I Submit core chips. RECE or wate r gas apparent ithology, porosity, fractures N/A description of 1994 Alaska on & Gas Cons. Commission Anchorage APR 2 0 in duplicate Submit CONTINUED ON REVERSE SIDE Form 10-407 Rev. 7-1-80 -----_._----_._~._._._-. ------r -----~ 30. GEOLOGIC MARKER" F-u,"U\lIA TION TESTS --- _.._---_..._~........ ..-.-.--------- -- ---- ------ NAME I Include in'.'v,1 tested. pee"u'. data. a uids ',",ov.'ed and 9cavitV. I MEA~:'DEPn~--' Il TRUE VERT. DEPTH GOR" and timn of each phase. : II I I N/A I See Attached Marker Summar: ! I ___.._....'___ ..___.._._..,...,.... ~ST OF ATTACHMENTS ......._._--_.__.._-_.._.__..._..~.,-_..__._------.. .. ..G.e. Q .1_Q..g:i_.ç_,,__~ª-;ck_e...r_....S_QmJ.n-ª.r_.¥.._..__._.__._.__.____,_._ true and correct to the best of my knowledge -.--.--..---..-------.---..---------.---. ~__..J?_.e.I..f.Q r a .t.i.o..n.__.S um.ro,ar.y.,.. 32. I hereby c:ertify that the foregoinç¡ Titl.~"---'Iot ~ Da'e~'\.~_ ---- .------.-------- s -ª~-~ . .-- ,..~.._. ._.....,.,.,,-_...-...._----.~._- Signed and log on report completion we NSTRUCTfONS tting a complete and correct General: This form is designed for subm all types of lands and leases in Alaska. salt njection air water injection, steam injection njection for in·situ combustion. of Service Wells: Gas injection supply for injection, observation, tem 1: Classification water disposal. water measurements depth for shown s used as reference (where not otherwise and in any attachments. elevation this form Item 5: Indicate which given in other spaces on well is completed for separate production from more than one interval (multiple item 16, and in item 24 show the producing intervals for only the interval reported separate form for each additional interval to be separately produced, showing the interval. tem 16 and 24: If this completion), so state in in item 27. Submit a data pertinent: to such ) should show the details of any multiple stage cement- Rod Pump, Hydraulic Pump, Submersible. Water In- etc KB OF, G L) or other elevation we 5 tem 23: Attached supplemental records for th ng and the location of the cementing tool. eve whether from ground nd icate tern 2 Lift Operation: F lowing, Gas Shut-in, Other-explain tem 27: Method of ection, Gas Injection none nd icate f no cores taken 28 tem 0-407 , F ( MIDDLE GROUND SHOAL A41-11 PERFORATION SUMMARY ( TVD MD ZONE 7360' 7326 7954' 7920' GN-GO 7814' 7902' 8001' 8125' 7770 7882 7939 8061 8416' 8505' 8605' 8730' 8371' 8484' 8542' 8665' GR-GS GS-HC 8440' 8157 9050' 8763' HC-HD 8536' 8484 9150' 9090' HD-HE 8604' 8795' 8861' 8561 8776 8804 9220' 9420 9490 9176' 9400' 9430' HE-HF HI-HK 9108 9283 9078 9126 9750' 9938' 9718' 9770' HK-HN 9408' 9468 ' 9625' 9728' 9404 9431 9522 9702 10075' 10140' 10315' 10430' 10070' 10100' 10200' 10400' HN-HR VED 9879' 9904' 10040' RECE 9796 9891 9928 10600' 10628' 10782' 10506' 10614' 10656' HR-HZ 1994 Aiaska Oil & Gas Cons. Commission Anchorage 20 APR ( \ GEOLOGIC MARKER SUMMARY GEOLOGI5T: B. 101, DATA ENTRIES BY: TO. SEQUENTIAL NUMBER WELL API NO: : ---------OUTPUT OATA-------- -: HOLE: WELL: CORRECT. :nCORRECTEon: COORDINATES: ANGL: AZM. : FACTORS: TV: TV: TV: FROM SURF. : DEG.: OEG.: TSC: TVC:GAS:Oll: SD: E/-W: N/-S: SECT /TWP/RANGE: API NUMBER: DATA TYPE: UNIQUE WEL 0--) OPERATOR: 5WEPI FiElD: MIDDLE GROUND SHOAL WElL: A41- 11 993 27 AUG UPDATED: COXE CLOS-: URE: (--C AVG:HUD: : SW: WT : SUBSEA: '% : lB/G: DEPTH : 0: 924: 997: 1165: 1473: 1792: 2084: 2111 : 2172: 2287: 2298: 2326: 2335: 2341: 2361: 2378: 2392: 2409: 2418: 2442: 2446: 2457: 2472: 2512: 2585: 2585: 2614: 2622: 2638: 2639: 2726: 2734: 2737: 2740: 2796: 2797: 2798: 2816: 2825: 2832: 2838: 2839: 2841: 2850: 2858: 2855: 2865: 2875: 2882: 2887: o -247 -267 -314 -370 -472 -584 -594 -615 -649 -652 -658 -660 -661 -665 -669 -671 -674 -676 -679 -679 -681 -682 -685 -693 -693 -693 -693 -692 -692 -664 -660 -659 -657 - 611 -608 -605 -563 -538 -509 -482 -474 -466 -416 -366 -383 -315 -235 -146 -49 0 53 53 0 10 10 0 19 19 0 42 42 0 16 16 0 30 30 0 29 29 0 30 30 0 23 23 0 23 23 017081708 020812081 0.····"''''. 0·."'...",. 0-423-423 0-440-440 0"'''''''·.''''''. 0"''''·...'''. 0·"'·....... 0*"'*"''''..... RECEIVED ~~ PR ? 0 190,11. 1-1.. t.... ,} 1 Aiê,ska OJ¡ & Gas Cons. Commission Anchorage 360 1.00 1.00 345 0.85 0.87 344 0.85 0.87 347 0.84 0.87 353 0.81 0.84 338 O. 73 O. 78 341 0.73 0.79 341 0.73 0.79 342 0.74 0.81 346 0.73 0.81 346 0.73 0.81 348 0.73 0.81 348 0,73 0.81 348 0.73 0.81 349 0.73 0.81 349 0.74 0.82 350 0.74 0.82 3510.74 0.82 3510.72 0.82 353 0.69 0.81 353 0.68 0.81 354 0.67 0.80 355 0.65 0.80 355 0.58 0.78 357 O. 43 O. 74 357 0.43 0.74 o O. 43 O. 78 1 O. 43 O. 79 5 0.44 0.83 5 0.44 0.83 28 O. 45 1. 04 29 O. 44 1. 05 30 O. 45 1. 05 30 O. 45 1. 06 62 O. 43 1. 25 63 O. 43 1. 25 63 O. 41 1. 28 70 O. 15 8. 7 1 74 O. 1910. 62 77 0.2026.88 80 0,22*"'*"'* 80 0.23"'*""" 79 O. 1528.27 80-0.25-7.29 81-0.26-7.58 81-0.26-7.40 82-0.28-8.02 84-0.34-9. 85 86-0. 36-8. 88 87-0.40-8.54 O. 0 23. 8 23. 3 22.5 25. 6 27.6 25. 7 25,5 23.9 24, 4 24.4 24. 7 24, 7 24. 6 24. 5 24.3 24, 3 24,2 24. 2 24. 2 24, 1 24.0 23. 5 22.4 19. 9 19. 9 18. 4 18. 0 17.0 17.0 12. 7 12.5 12. 4 12.4 6. 7 6. 7 6. 8 9. 4 11. 2 13.5 15,4 15. 8 16. 1 17. 8 18.4 18. 0 19.2 23. 0 24.3 26.8 o 956 1033 1206 1519 1853 2164 2193 2258 2377 2388 2418 2426 2433 2453 2470 2485 2501 2510 2534 2538 2549 2565 2604 2676 2677 2704 2712 2728 2728 2806 2812 2815 2817 2861 2862 2863 2872 2875 2877 2878 2878 2879 2880 2881 2881 2883 2884 2886 2888 116 -2912 -3088 -3500 -4205 -4884 -5501 -5562 -5700 -5964 -5988 -6053 -6072 -6085 -6130 -6167 -6200 -6237 -6258 - 6311 -6320 -6346 -6382 -6476 -6664 -6666 -6747 -6774 -6824 -6825 -7181 -7218 -7234 -7251 -7653 -7677 -7701 -8041 -8183 -8324 -8430 -8459 -8488 -8654 -8808 -8755 -8962 -9168 -9370 -9572 II II II II II II II II II II II II II II II II II II II II II II , II , II II II II II II II , II II , II , II II II , II II II , II II , II '% ~ '% '% ox '% '% '% 'I '% 39'% % 46'% '% 25% '% % ox 27'% 1 31% '% 39'% % 'X '% '% '% % 1 1 2n 27'% % 251 25% % 22'% 221 '% 281 28'% % 31% 31'% ox 34% 341 38% 381 AVG: PDR: '%: 'X 'X '% 'X '% 'X % ''% % ox 13'% '% 13'% '1. 161 1 'X '% 17X 1 16% % 151 1 1 % 1 '% % % 1 12% 12% % 13% 13'% % 10'% 10'% '% 8. 2% 8.2% 'l. 7. 4'% 7.47- % 7. 1'% 7. 1% 8'% 8'% DATA RES: DIP: DIP: "OBSERVED" : ERV: AWG: AZM:nLOG PAYS" : Ol~ D~G: DEG:GAS:OIL: S~ NPUT NTEREST------- : ---DEPTHS OF MEAS.: MARKER DEPTH: NAME 65: 1~ 23: : 0: 5 5 : : : 0: 20: 20: : : : 0: 38: 38: : : : 0: 28: 28: 0: 28: 28: : : : 0: 18: 18: 0: 18: 18: : : : 0: 196: 196: 0: 196: 196: · . . · . . 0: 39: 39: 0: 39: 39: · , . , . . 0: 58: 58: 0: 58: 58: · . . , , . 0: 212: 212: 0:212:212: 0: 144: 144: 0: 144: 144: 65: 12: 23 0: 0: 0: : 290: 290: 278: 278: 284: 284: 294: 294: 00: 00: 00: 00: 288: 29 21ì: 65: 65: 70: 70: 89: 8q: 90: 90: 8'3: M: r. 3: p~: 55 COMMENTS POSSIBLE FAULT EXTRA SECTION EXTRA SECT ION PDSS. DR I LL I NG POSS. DRILLING WEll: A41- 0: KB 3220:BC 3411: BG 3858:BM 4630: CF 5388: OK 6080:45 6147:A2S 6300: FG 6590: FL 6616: Fl1 - T 6687: Fl1-B 6708: Fl2-T 6723: FL2-B 6772: FP 6813: FP1-T 6849: FP1-B 6890: F S 69 12: F S 1- T 697 1: F S 1 - B 6981: FS2-T 7009: fS2-B 7048: FS3-T 7150: FS3-B 7352:GB 7354:GB1-T 7440:GB1-B 7468:GB2-T 7521:GB2-B 7522: GD 7890:GM 7928:GN 7944:GNMID 7961:GO 8370:GR 8394:GRM10 8419:GS 8762:HC 8906: Hcr.,. 0 9050:HD 9160:HE 9190:HEMID 9220:HF 9394:HI 9556:HI"10 9500: FAUL T 9718:HK 9939:HKMID 10160:HN 10385:HNMID ~O'd ~W~O~ DA~LY REPORT * PLATFORM: A WELL: A41-11 12-Dec-g3 FOREIGN: R.H. SELTZ AFE: ?????? ENGXNEER' P. AUTH:$250,O00 DAILY: $12,100.00 CUMULATIVE: $12,100.00 DA! YTD: .... 0 TR! YTD: .... 0 DAYS & DAYS ESTZHATED: ~.0 OF COI~ENTS: NO ACCIDENTS REPORTED FLUID TYPE: ~EZGHT' 8.5* SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: ?[~E AND SU~t4ARY OF OPERATIONS: RIG ACCEPTED TO A41-11 e 0600 MRS 12-11-93 10.5 HRS - PREPARE RIG FOR HOVE - SKID RIG OVER A41-11 - RIG UP 5.0 HR$ - R/U SLZCKLINE UNIT & TEST LUBRICATOR TO 1000 PS[ - POOH - CHANGE TOOLS - RZH ~/2.30" GUAGE RING TO 8700' - POOH - VALVE OUT OF BOTTOH GLH e 8628' - POOH - R/D ~IRELZNE UNIT & LUBRZDATOR 8,5 HRS - eLEED DOWN TBG- ~NSTALL BPV - N/D FLOWLINE & TREE - N/U ADAPTOR FLANGE ON R[SER- PULL TREE - SET R[SER- N/U BOP& CHANGE RAMS ADGCC WAS NOTIFIED OF UPCOM/NG BOP TEST 12-1~-19~ ~8:14AM FROM Shell Pl&%{o~m A TO ANC OFF]CE · DAILY REPORT .................................. FLATFORM: A WELL: A41-11 13-De~-93 F~RENAN: R.H. SELTZ AFE: ?????? ENGINEER: P. T. HUCKABEE AUTH= $150,000 DA[LY:$12,100.O0 CUMULATIVE: $24,200.00 DAI YTD: .... 0 TEl YTD: .... 0 DAYS & DAYS ESTIMATED: 2.0 OF COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FZ~ WEIGHT ' SPILLS: NO SPILLS RE~RTED RT TO TBG HANGER: $~,90 TOF: ~iHE AND SUMMARY OF OPERATIONS: 3.50 HRS - CHANGE RAHS - FUNCTION TEST BOPS - PREPARE TO TEST BOPS g.OO HRS - TEST DOP~ - H¥DRZL TO 250/3500 PSI - PIPE RAMS & ASSOCIATED EGUZP, TO 260/6000 PSI - HAD TO REBUILD OUTSIDE 2 1/16" SM KILL LiNE VALVE & 3 1/16" 6N CHO~E LINE VALVE, 2.$0 HRB - R/U CHOKE OFF AP SPOOL TO BLEED OFF OAS FROM BAOK$]DE,- PUMP $0 BBL8 DO~/N TEG. - NO RETURNS 1.00 HR~ - PULL BPV - INSTALL 2-~AY OHECK- TEST BLIND R~ 8.00 HRB - R/U CIRC, LiNE & PUMP 2 BBL/HIN FI~ DO~N TBG TO FILL HOLE - AFTER HOLE N~ FULL, MONITOR O~LY RETURN8 & PU~P TO PRODUCTION - OIRC UNTIL RETURNS OLEANED UP, ADDITIONAL CO~NENTS; DRILLS, VISITORS, ~NSPECTOR8 ETC,.. AOGCC REP. WITNESSED BOP TEST RECEIVED Alaska Oil & ~as Con;;. Anchorage * DA~LY RE~T z ~LATFORN: A ~ELL: A41-11 14-0ec-93 ~OR~N= R,H, ~ELTZ z AFE: ?9999? ;NGZNEER: P. T. HUC~BEE * AUTH: $1~0,000 DA~LY:$12,868.00 0UHULATZVE: ~7,904.O0 * * DAI YTD: .... 0 T~ YTD: .... 0 DAYS & DAYS EST~TED: 3.0 OF * C~HENTS: NO ACOZDENT8 RE~RTED FLUID TYPE: F~N ~EZ~ * 2.00 HRS - CIRC. FIW OOWN TBS. TAKING RETURNS TO MUD PITS. , * 7.00 Hfl$ - POOH W/TBS. - LAY DO~N GLN'S, NIPPLE*, & PACKER. , ~ 5.00 HRS - H/U SCRAPER & RIH ~/TBG TO 8476' , * 2.00 HRS - REVERSE CIRC. , * 5.00 HR8 - POOH W/SCRAPER - L/D 24 JTS TBS. * 1.00 HRS - SLIP & CUT DRLG. LINE , * .50 HR8 - SERVICE RIG & TOP DRIVE , * 1.50 HRS - M/U & RIH W/PRODUCTION STRING , * HOLE TAKING APPROX. 40 BBL/HR * , BHA - HUL£ ~HOE, 2 7/B" PUP JT, XO~ XO,7" 05~ SCRAPER, BIT SUB, XO, 2 7/8" TBS * DAILY REPORT * PLATFORH: ~ WELL: A41-11 15-0eo-93 FOREMAN: R,H. $ELTZ * AFE: 253260 ENGINEER: P. T. HUCKABEE * AUTH= 1160,000 DA%LY:$1~,888.00 CUHULAT%YE~ $60~??2.00 *************************************************************************************** * 0AZ YTD: .... 0 TR! YTD: .... 0 DAYS & DAYS ES?ZNATED: ~.O OF , * OONNENTS: NO ACCI~[NTB REPORTED FLUI~ TYPE: FI~ ~EIGHT: * SPILLS: NO SPILLS REPORTED RT TO TBS HAN~ER: 38.90' T · TIME AND SUGARY OF OPERATIONS: ~ G.OO HR* - RIH W/PRODUCTION' ~'rR]NG * * 1.00 HRG - TEST CONTROL TO 5000 PSI - RIH - UNABLE TO GO DO~N PAST 7568' - k~IRK ~ TBS, - NO LUCK * 5,50 HRS - POOH ~/2 7/8" COHPLETION STRING, * 2.00 HR8 - CHANGE BOP RAI48 TO 3 1/2" & TEST , * 5.00 HR* - H/U 6" BULL NOSE ¼ILL & TZH ~/3 1/2" DP TO 7568' - h~qK THROUGH TZGHT * SPOT - RIH TO 8700'. * 4.50 HRS - HIX & PUMP XANVIS 8~EEP - CIRC. : RECEIVEI) , - 7 1994* * ~- 6" MILS. ~IT $08, ($) ~ 3/~" D¢, DN & ~P JARS, 3 1/~" ~ ~""~ ~'"' ~ 6asGons.~ommissio~ z ~nnhnra~e * ************************************************************************************** DAILY REPORT , * PLAT;ORN: A WELL: A41-11 16-Deo-93 PORENAN: R.H. 8ELTZ * AFE: 263260 ENGINEER: P. T. HUCKABEE * AUTH: $150,000 DAILY:$12,aes.00 CUMULATIVE: $§3,040.00 * ** DA! YTD: .... 0 TRI YTO: .... 0 DAYS & DAYS ESTZNATED: 5.0 OF * ** COMNENT$: NO ACGZDENT~ REPORTED FLUID TYPE: F[W flE[~HT' 8.5* * 8PILLS' NO 8PILLS REPORTEO * *******************__********* .............. RT TO TBG HANGER: 38.90' TOF: * T~NE AND SUI4MARY OF OPERAT~ON$: * 1,50 HR* - CIR~. OUT SWEEP * , =.oo HR, - POOH W3 1/2' DP & N~LL * * ~.00 HR* - CHAN*E RAMS TO 2 7/8" & TEST BOP * 4.00 HRB - RIN W/2 7/8" CONPLET~ON STR2N~ - N/U TR$$SV & CONTROL LINE - TEST * 1.50 HRS - TAB TIGHT SPOT t 7568' - WORK TBG UP & DOWN - WH~LE 8~TTZNG DOWN * WEIGHT ON TIGHT SPOT. ~TRZNG WENT DO~N 2' - WAS UNABLE TO CONE UP - * WORKED STRING UP & DOgN - NC~ LUCK - PULL 170,000 & CAJqE FREE (FRO~BLV , * SHAER~D PZI~, BUT UNABLE TO TELL) * 2.00 NRS - P/U & MOVE TR$SSV DO~N STR2NG - M/U CONTROL LINE & TEST - N/U HANGER · z & LAND TBG. z 1.50 HR$ - DROP BALL - R/U'TO PRF. SSUR~ UP ON TaB - PR£$$URE TI~ TO a$O0 PSI - · * RELEAgE PRESSURE a PICK UP TO SEE ~F PACKER SET - NO SET , * S.$O NRE - POOH N/OO~PLETION STRING - L/O PACKER - PAOKER ~A$ SHEAREO- FLEW TO * BEAOH FOR REBUILD. * ~.00 HR8 - WASTE ON PACKER - ESTZIqATEO BACR e 0~00 HR8 * WELL TAKING e BBL FZW/NR * ********************__******* ................. ~44, ~Pr~ ==,=,=,~,==. ................. .'_'_'_' '_ _'~'~~???.* ~ = * * ** = ***********************--*** : DAILY REPORT * , , ~ PLATPORN: A WELL: Aal-~l l?-De¢-g~ FOREMAN: R.H, $£LTZ * ARE' 2B~80 ENaINEER: p. T. HUOKABE£ , **************************************************************************************** ~ ~UTH: $~SO.O00 DA!LY:$30,~T.O0 CU#ULAT~VE: $~4,0a7.00 * **************************************************************************************** * OAI VTO: .... 0 T~! ¥TO: .... 0 OAYB & OAY8 EBTIMATEO: $.00P , ~ COMMENTS: NO ~OC!0ENTg REPORTEO KLUiO TYPE: P~W WEIGHT: B.B* * BPILL8: NO 8PILL8 REPORTED RT TO TBO HANa~R: 38.g0' TO~: **************************************************************************************** * TINE AND 8UHNARY CF OPERATIONS: * A . * 5,50 HR$ - HA[TE ON PACKER TO BE RE-BUILT - HORK ON AND STRAIGHTEN UP R~G , * 7.00 HR8 - fl/U PACKER & RZH W/ OONPLET!ON STRING - N/U HAN~ER & LAND z 2.00 HRS -OROP BALL & ATTEMPT TO SET PAOKER - SUB SHEARED · 800 PSI - PAOKER * NOT SET. * A.O0 HRB - R/U ~LICKLZ~E UNIT & LUBRICATOR - TE&T LUBRICATOR TO 1BO0 PSI - RIH * W/I.gO GUAOE RING TO ??gO' - POOH - RZH ~/PXN PLUG BODY & 8ET - POOH - RZH * WITH PN PLUG & SET , * ~.00 HRS - FILL TBG & PRESSURE UP TO ~800 PSI - PRE$8URE UP TO 3~00 PSZ TO TEST TBG* ~ BLEED OFF TBO TO ~SDO PSI - PESSURE ANNULUS TO 2000 PSI - PA:KER SET & , * HOLDING , * ~.00 HR$ - POOH H/WL & PRONG - R~H ~/WL & PULL PXN BODY - R/D WL & LUBRICATOR , * 2.~0 HRS - R/D LANDING JT - INBTALL BPV - PULL 2 ~/~B" VALVE OFF KILL LINE FOR * * TREE - N/D BOPS *BAKER SOS/WLREG e 7586'. BAKER HB PKR e 7535', OTiS X NIPPLE e7502'. GLH ~6 e 7463' ** , GLN #5 e 7162'. GLH #4 @ 6277'. GL~ ~3 e 6173'. GLN #2 e $632'. GLN #I ! 1871'. , R, ECEI ED * ADDITZQNAL ~I::II~ENTS; DRILLS, VZE~TORS, ZNSPECTORS ETC... .,,~KER I=V-6 TR$$BV e 324' APR -7 1994 uil & Gas Cons, Commis, Anchorage DAILY REPORT PLATFORM: A WELL: A41-11 l~-Oec-9~ FOREMAN: R.H. SELTZ AFE: Z03260 ENOINEER: P. T. HUCKABEE AUTH: $150,000 DAILY:$13,4~l.00 CUMULATIVe: $107,458.00 OAI YTO: .... 0 TRI ¥~: .... 0 DAYS & DAY~ ESTI~TE~: 6.75 OF COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FIW WEIGRT: 8.5Z SPILLS: N0 SPIL.S REPORTE0 RT TO TBa HANGER: 38.gO~ TOF: TIM~ ANO SUMMARY OF OPERATIONS: 18.00 HAS - H/O BOPS - ~NSTALL 2 1/16" SM WING VALVE ON TREE - ~NSTALL TREE & PRODUCT[ON LINES - CLEAN UP WELLHEAD ROOM - PUMP OILY P[T ~ATER IXTdN DISPOSAL NELL - CLEAN PITS &PUNP DOWN DISPOSAL WELL - RIG DOWN AND PREPARE* FOR RIG MOVE TO A33-!~LS RIG REL~.ASED FROM A41-1! ~ 2400 HAS - 12/17/g3 · . OAILY REPORT PLATFORM: A hELL: A41-~1 19-DEC-93 FOREMAN: R.H. 8ELTZ AFE: 203200 ENa~NEER: ~UTH: 1150,000 , DAILY: SO.DO CUMULATIYE: $124,856.00 DAI YTO: .... 0 TRI YTO: .... 0 DAYS & DAYS ESTIMATED: ~.T5 OF COMMENTS: NO ACC2DENTS REPORTED FLUID TYPE: F~N WEIGHT: 8,5, SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: $8.90' TOF: TIME AND SUMMARY OF OPERATIONS: SCHLUMBERGER RIGGED UP & RAN GR/CCL/PERFORAT[NQ DEPTH CONTROL ~0~ PERFORATING WAS DELAYED DUE TO ~ELL PROBLEMS RECEIVED APR - ? ~aska Oil & ga~ Cnn~ C~mml~slp. DAILY REPORT PLATFORM: A WELL; A41-11 Z~'-De~-93 FOREMAa: R,V, WELLS AFE: 2~3317 ENO~NEER' P. T. HUOKABEE · UTH: 5150.000 3ALLY: $4,30§.00 CUHULATIVE: $129,101,00 DA~ YTO: .... 0 TRI YTD: .... ~ DAYS & DAYS E~T~IM~TED! 7.5 OF COMMENT&: NO AOOIDENTB ~EPORTED FLUID TY;E: PRODUCED FLUID NE[GHT: SPILLS: NO 8PILLS REPORTED RT TO TS& HANGER: 38,90~ TOF: TIM~ AND ~U~MA~¥ OF OPERATION~: 'BEGAN OPERATZONS AT 1000 HR5 12/2~/93. 14.0 MRS - R/U SCHLUMBERGER AJ~D RAN OUTFLOfl PRESStJRE SURVEY TOOL C1 11/q6"} TOOL STOPPED GOING ~N HOLE AT 9677'. PULLED TO WITHIN 400 LB~ OF WEAK ~ZNT TO PULL UPHOLE. NO PROBLEH RE-ENTERING T~G TAIL. LOG gURVEV W~TW ~TO=~ AT: 7~48.~', 7500'~ T250J, 6600~, 6600', 4400', 2700~, AflO 1500'. TORE ~N LUBRICATOR PAOKOFF FOR [NSPECTION. W~ OK. RIGGED L~ER8 ASIDE. KEPT WELL FLOWING, .... 12-28-1993 2?:4gAM FROM ~hell Plmt~oem A TO ~NC OFFICE DAILY REPORT PLATFORt4: A WELL: A41-11 28-Dec-95 FOREMAN= R.V. WELLS AFE: 203~1T ENGINEER: P. T. HUCKABEE AUTH: $350,000 DA[LY:$~3,1~I,00 OUMULATIVE: $152,3~a.00 DA! YTD: .... 0 TR! YTD'.,,, 0 OAY8 & DAY8 E~TZMATED: e.5 OF :OMMENTS: NO AGe:DENTS R~PORTED FLUID TYPE' FZW WEZaHT: ~PZLLS: NO SP:LL$ REPORTED RT TO TBG HANOER: 3B.90° TOF: TIHE AND SUMMARY OF OPE~T:ONS: 'BEGAN R~G OPERATZONS AT 1200 HRS 12/27/93. 7.0HR~ R~a UP L~GERS, RAN 2 1/8" SINKER BAR ANO CCL. TAGGED UP AT 90~0~. UNABLE TO WORK PAST RE~TRICTZON. ~H. T~AR ~ LOGGERS. 11.0 HRS RIG ~TEEL LINES F/PROD INJ HEADER TO NELL HEAD. PUT BO BBL8 ~N TBG F~LL ANNULUS W/FI~. RIGGING UP MUD LINES, ~CK HOSE, 4" ~D 6" C~KE LINES. BLEEDING GA8 FR~ ANNULUG TO PROD ~WN TO ZERO PSI AT REP~T~/~ *z~TH[S REPORT IS FOR 18 HRS*** 1~00 HRS 27TH TO 0800 HR8 28TH ~.PR -7 1994 ..,.~. ~a u, & Gas Cons. Commission Anchorage 12-2~-199~ ~8:~A~ ~OM ~ell Platf=~m A TO ., ANC QF~ICE P.01/21 ~ITl¥ RPD~RT ^FE: 2~3317 ~NGINEER: P. T. HUCKABEE AUTH: ~350,000 ~AILY:$~1,984.00 CUHULATIVE: $1~4,306.00 DA! YTD: .... 0 TR[ YTD: .... 0 OAYS & DAYS E~TZNATED: 9.5 CF 3.0 COflHENT$: NO ACCIDENT; REPORTED FLUID TYPE' FZ~ WEIGHT: SPILLS: NO SPILLS REPORTED RT TO TBS HANGER: 38.90' TOF: TIME AND SUMMARY OF OPERATIONS: 5.5 HR*- FINISHED BLEED ANNULUS TO ZERO PSI. PUT F~W DOWN ANNULUS TAKING RETURNS UP TUBING TO PROD HEADER TO GET OIL OUT. HOOK BOTH T~G AND ANNULUS TO THE BACKFLO~ SYSTEH AND BLEED TO ZERO PSI. BOTH SIDES DIED. NO FLOW. 10.0 HRS- SET BPV. PULL TREE. INSTALL AND TEST BOPE. GAS ALARMS HORNS DID NOT BLOW THE LIGHTS WORKED OK. ELECTRICIAN NORKING ON HORNS. 6.$ HR,- RIG TONGS, POH ~/TBG STRING, ~AY ~O~N PACKER FOR RE-DRESSING. 2.0 HRS- CHANGE PIPE RAMS FROM 2 7/8" TO 3 1/2", TESTTNG RAMS AND DOOR SEALS RANG FAILED T/TEST. REPLACING UPPER RAMS SEALS AT RPT T~NE. * AOOITIONAL COMMENTS; DRILLS, VISITORS, INSPECTORS ETC... *HR. BLAIR WONDZELL, OF THE AOGCC, DECLINED TO ~ITNESS BOPE TESTING. *24 HRS NOTICE WAS GIVEN 1427 FIRS ON 12/27/93. DAILY REPORT * PLATPORN: A ~ELL: A41-11 30-De~-93 FORE#AN: R.V. ~ELLS * AgE: 25~17 ENGINEER: P. T. NUCKABEE * AUTH: $350,000 DAZLY:$20,3?D.O0 ~U#ULATIVE: J ~[ ¥1'0: .... 0 TR[ YTD',,,. 0 DAYS & DAYS EST[NATEO: 10.6 OF~, Z COI~IHENTS- ~0 ACCJDE~T$ REPORTED FLUID TYPE: FI~ WEIGHT: * SPILLS: NO SPILLS REPORTED RT TO TBG HA~GER: TIHE AND SUHNAR¥ OF OPERATIONS: * 16 HR*- FINISHED INSTALLING TOP SEALS ON PIPE RAMS. TEST SAME, FAILED, PULLED FROM 1~3P, INSTALLED 3,5" X $" VARIABLE RAMB~ TESTED OK, BUT, THE TEST PLUG FAILED, PULLED TEST PLUG, INSTALLED NE~ SEALS. STILL HAD A LEAK. BEGAN SYSTEMATIC BOPS TEST UNTIL ALL BOPE TESTED OK. SET WEAR BUSHING, BLOW DOWN CHOKE HANIFOLD. GAS DETECTION SYSTEM TESTED PER AOGCC = 3.~ MRS- MAKE UP 6 1/8" M~LL, CS* SCRAPER TZH T/TOP OF LINER. 1.0 HR~- PUMP OOtdM DRILL PIPE TAKING RETURNS TO PRODUCTION HEADER. PUMPED 70 BOLS UNTIL HAD RETURNS AT SURFACE. PUMPED 35 BBLS MORE TO GET OILY MATER OUT OF TOP OF HOLE INTO THE PRODUCTION SYSTEM. * .$ HR-- TIH TO 7566', TIGHT SPOT. HAD H2S ALARH, RESI:~NDED TO ALARM. * 1.5 I'IRS MILL/WORK OUT TIGHT BPOT AT 7666' TO 755B', SMOOTH #0~. 1.5 HR,- TZH T/TO20' N/HILL-SCRAPER ASSHY~ FILL TRIP TANK, POH AT RPT TIME. =FLUID LI3~1' TO HOLE EST: 134 BBLS THZ8 DAY.,,IOg B~LS WHILE FILLJH8 THE HOLE AT.TOP = TOP OF THE LINER AND 2g BBLS WHILE HILLING TIGHT 8POT AT 75eo-oe'. =BHA- 6 1/8" TAPER MILL~ 7" CASING SCRAPER, BIT SUB, §- 4 3/4" STEEL DC'~ JARS U3~8,1E~ ~ ADDITIONAL COMMENTS; DRILLS, V~$~TORS, ~NSPECTORS ETC... KEIC'E I'V-E IJ: APR -7 1994 Alaska Uil & Gas Cons. Commission Anchorage PLATFOF~I: A WELL: k41-11 31-Dec--93 FOREMAN: R.V. WELL;; AFE: 263317 ENGZNEER: P. T. HUC~BEE AUTH: 1350.000 OA~LY: t5,930.00 CUHULAT;VE: tlgO,606.00 DA~ ~O: .... 0 TR~ ~D: .... 0 OAY~ & OAYS ESTIMATED: 11,5 OF COHME~S: NO ACCZDENTS REPORTED FLUID TYPE: FZN WEIGHT: SPILLS: NO SPILLS RE~RTED RT TO TBG HANGER: 38.90' TOF: T[HE AND SUGARY OF OPERAT~ON~: 7.5 HRS- F~NZSH ~H W/6 1/8' HICC ~D SCRAPER. LAY ~N SCRAPER, CHANGE TO A S 3/4" ~LL, T~H TAG TZG~ SPOT AT g~o', 2.Q H~- HILL THRU TI~T S~T AT 9000', CL~N OUT T/g614' 2.5 ~- ~O H2S AL~, EQUIP FAILURE FOUND SEE NOTE BELOW. 1.5 H~- CONTINUE CL~ZNG OUT 7" ~G. MILL THRU T[~ 8~T F/9753' T/9777' ~LE ~LZO BR[OGEO OFF AT g777'~ U~BLE T/HAKE ANY ~LE. ?.S HAg- TRIP F/NEW HILL. 3.0 HAG- N[LL THRU ~IOGE/TZGHT S~TS AT: 9777' TO 97~6' ANOTHER AT g898' TO ANOTHER AT 10042' T/10046'. CONTINUE CLEANZNa OUT AT RPT TIME. N~E: EST FLUID LOSS TODAY AT: 103 ~L~ TOTAL TO DAY, ~3T TOTAL TO DATE. NOTE: CO~ECTED MIS-CODE COST DF $5121 ZNA~ER~LY ~NPUTEO ON YESTERDAYS *M]LLS ~ YESTERDAY SERe'S: 6 1/8" N~ eee~ THE 5 3/4" WAS t8757~. ~BHA: 5.88" NZLL, (SEA ~5243) 6-4 3/4" ~EEL DC'S, JA~, 01617, U328. ADDITIONAL ~E~S; DR2LLS, VIS,ORS, ZNSPEOT~S ~C... ~0 H2S ALA~. NO ACTUAL H2S THO. FOUNO [NOUCT[~ ELECTR[AL CURR~ INTO ~THE H28 A~RM SYSTEH, EFFECTED REPAIRS BY INSTALLING A CAPACZTER ~N L[NE. DAILY REPORT PLA?PORN: A WELL: A41-11 01-Jan-g4 FOREMAN: R.V. WELLS AFE= 263317 ENGINEER= p. T, HUOKABEE AUTH: $3~0,000 DAILY:$~O,771.00 OUMULAT[VE: $Zll,377.00 OA~ YTD: .... 0 TR! YTO: .... 0 DAY5 & DAY& ESTIMATED' COMMENTS: NO ACC[DENTS REPORTED FLUZD TYP~: SPILLS: NO SP~LLS REPORTED RT TO TBG HANGER: 38,g0' TOF: T~ME AND SUMMARY OF OPERATION~: 5.5 HR$- FINISH CLEANING OUT W/E.SS" O0 MILL F/10045' T/10821', BECAME REAL TORQUER= CALLEO THIS NE~ PBTD,..10821'...PU#PEo 28 BBL ZAHV[S S~EEP AROUNO. 1.0 HAS- AT ~ND OF SWEEP HAO LOSS OF 400 PSI PUI~P PRESSURE. CHECKEO OUT SURFACE F. QUZP~ OK. PUMPEO FRAYED SOFT ROPE TO CHECK F/HOLE ~N g,O aRS- ;:OH F/BNA OHANGE ANO LOOK[N~ F/POSSIBLE HOLE HAV~N~ TO PUMP TO PULL PIPE. 2.5 HAS- MZXEO ANO PUMPEO H[-V[$ Sl~EEP TO HELP PIPE PULL FREER. 0.5 HRS- C~NTZNUE POH~ ~T[LL HAO TO PUMP ON O~ P~ws, area'. CONTINUE POH~THOUT PUMP ASSISTANCE. 4.0 HAS- LAY OOWN M[LL~ OC'S ANO JAR8. MAKE UP MULE SHOE~ 1.5 HAS- RIG UP HOWCO F/ACID/ZYLENE WA8H JOB. ESTIMATED FLUID LOST TO HOLE WAS: 94 BBLS TODAY. CULN TOTAL NON 331 BBLS ADDITIONAL OOMMENTG; DRILLS, VISITORS, IN&.~ECTORS ETG... TRIP DR~LL, NORNING TOUR CREW, WELL SECURE IN 2 HZN~. VERY SATIEFACTORY JOB. ~l-o~-lg~a I~:~BPH ;ROPl ~h~ll Pl&?.foem ;I TO ;INC I;IFFICE * DA2LY REPORT , * PLATFORH: A WELL: A4!-11 02-dHn-94 FOREMAN: R,¥. WELL~ = APE: 263317 EHQINEER' P. T. HU~KABEE z AUTH: $~$0,000 DAILY:$11,477.O0 CUMULATIVE: $222,~5A.00 ~ DA! YTD: .... 0 T~! YTD: .... 0 DAYS & DAYS ESTZHATE~: 13.$ OP 3.0 * COHHENTS: NO ACCIDENTS REPO~T~D PLUID TYPE: FIW ~EIGHT: * SPILLS: NO 8PILLS REPORTED RT TO TBO HAN~ER: 38.90' TOF: T~HE ANO SUI,~IARYOF OPERA?~ON~: =1.~ HRE~ FIN~SM~O R~ UP FOR ~YLEKE/A¢~D JOB. NELD ~AFE?¥/PROCEDUR£S HEE?~N~ W/ALL. *4.5 HRS- A5 PART OF THE PRE-JOB PROCEDURE THE H2S DETECTION SYBTEH WA~ CMEOKED FOR PROPER OPERATION AND CALIBRATION. WORKED ON ~Y*TEH AND GOT IT RZ~'(T, ~13.5 HR*- HOD/CO PIJ~ED 5 BBL$ MATER TO FILL LINES. TEST T/2500 PSI, OK. *JOB #1: PUMPED 51BBLS PAD 75~ ACID (7 1/2 ~ HCL) Nlq'H 25~ ZYLENE~ FOLLOWED N~TH *30 BBLS FIN, 11BBL8 ZAN¥IS HI-V~S 8WEEP, 39 BBC* FZ~, 6OAK F/45 HZN$ ON PERP$. *DISPLACE W/F~W, TOOK RETURNS THRU PRODUCTION SYSTEM DURING SPENT ACID/H2* RETURNS. *INJECTED $$Z~ H25 SCAVENGER OURZNG RETURNS T/PROD ALSO. TOOK ZANVIS SWEEP T/PITS. * *JOB #2: PUMPED 48 BBLS, SAME MIXTURE PLUS T BBLS ~ASH UP FLUID FRON ACID TANKS~ * *FOLLOWED ~/50 BBL8 F~W, 7 BBL8 ZANVZ$ SWEEP, 23 BBL8 FZW, 80AK ON PERF$ 30 MINE, ~DZSPLACED W/15 BBL$ RENAMING ZANVZ$ IN P/T AND F/N. TOOK RETURNS AS BEFORE. *PUMPED THRU KILL LINE TO PROD TO D~SPLACE RISER. TOOK ZANVI8 *WEEP8 TO P~T8 TO *COHINGLE ~/O~RTY WATER RETURNS. PUMPED ALL DO'QN DISPOSAL ~ELL, FOLLOWED W/FIN. ~4.$ lIRE- CHANGE ~AVER SUB ON TOPORZVE, OPEN RAMS, CHECK FLOtl, ~ONE, POH ~/#ULE~'IOE. m4OTE: ~1 JOB'S A~ZD VIA$ 45 BGL$ SPENT, LAST & BBLS MAS NOT. ~2, NC)NE SPENT. ~NOTE: A;TER li~ AOZD JOB'G ZT TOOK 10 BBL8 TO I~LL IK)LE AFTER A 1 HR WAIT, , ~ ESTIMATED FLUID LO&T TO HOLE WAG: 124 BBLS TODAY, CULH TOTAL NOW 465 BBL8 * DAILY REPORT , * PLATFORH: A ~ELL: A41-~1 03-Jan-04 FOREMAN: R.V. HELLS , * AFE: 253~17 ENGINEER: P. T. HUCKABEE * ^UTH; $$50,000 OA~L¥:$34,115.00 CUNULAT~VE: $255~0~.00 * COMMENTS: NO AGCZDENTB REPORTED FLU[D TYPE; FIW WEIGHT: 8.$* * SPILLS: NO *PILLS REPORTEO RT TO TaB HANGER: $~,90' TOF' ************************************************************************************** TIHE AND *U#NARY OF OPERATIONS: , 3.5 HRS- CHANGE PIPE RAN* T/2 7/8", PULLED WEAR BUSHING, SET TEST PLUG ANO TEST * · RAMS/DOOR'SEAL8 250 LOW AND ~000 PSi HIGH. FILLED HOLE PR*OR T/RUNNING CONP STRING.* · g.O HRS- TIH W/COMPLETION STRING, STUCK IN TIGHT SPOT AT 757~', UNABLE TO WORK · THRU IT, SHEARED RELEASE P2N8 ZN PACKER PULLING LOOSE FROM TIGHT SPOT, POH. · ~.0 HRS- BLIP/CUT DRILLING LINE 100'. · ~0.5 HR*- LOAD PACKER ON BOAT TO GO TO BAKER OIL TOOL8 FOR REPAIRS. CLEAN z ANO ORGANIZE RIG AREAS, PiTS AREA ANO PUNP ROOM. CLEANED PITS. WORKED ON · DERRICK KLOWLINE CLEANER~. iNSTALLED CORNER SUPPORTS/BRACiNG ON FRESH WATER TANK. * NOTE: AFTER FILLZNO HOLE AT 0900 HR~ FLUID WA8 ONLY ADDED TO REPLACE TUBULARG PULLED FROM THE NELL. THE HOL~ TOOK 33 BBL8 APTER 1~ HRS. THEN, WE F~LLEO THE HOLE * $ HRS LATER AND IT TOOK 30 BBLS. ~ E$'I'ZNATED FLUID LOST T.i 90L~ WAS: ~3 BBL5 TODAY, CUI. Jq TOTAL NOW 548 BBL8 c~l-c~4-1gg,i I~:4'~AM PRnM Shell Platform A Tn ANC QPplC~ DAILY REPORT * PLATFORM: A WELL: A41-!1 04-J&n-94 FORENAN: R.V. WELLS * AFE: 263317 ENGINEER: P. T, HUCKABEE z AUTH: $350.000 DAILY:$1$,$SS.00 CUNULATIVE: $~73,63T.00 * DA! YTD: .... 0 TR! YTD: .... 0 DAYS & DAYS ESTIMATED: 15,5 OF 3.0 z COMMENTS: NO ACCIDENTS ~EPORTED FLUID TYPE: FIW WEIGHT: * SPILLS: NO SPILLS REPORTED RT TO TBS HANGER: 3~.90' * TIME AND BUMMARY OF OPERATIONS: ~ 4.5 HRS- ~HZLE NAITINa ON PACKER; PREP RIG JACK~ F/MOVE, CHANGE OIL ~N SHAKER $¥$TE~ * SGUARE AWAY PIPE RACKS F/HOVE, CLEANING AND ORGANIZING. ~ 4.5 HRS- MAKE UP BAKER "HB" PACKER, TIH. ~ 2.5 MRS- TEST TR$C$$SV, OK. DROP BALL AND SET PACKER AT 753~'. TEAR OUT LINE, * 6.5 INSTALLED BPV, NIPPLE DOWN BOPE, NIPPLE UP TREE. TEST TREE/HANGER T/SO00,, OK. * 6.0 CLEAN OUT WELLHEAO ROOH, TEAR OOWN CHOKE LINES, HOOKED UP 8S8V CONTROL LINE * BEGIN GAS LIFT AT 0200 HR8 01/04/94, TUBING OETA[L: WLREG AT 7586', "XN" NIPPLE 7574', PACKER 7535'. "X" NIPPLE 750~. ELM #6, 7463', ~5 7162', #4 6277'. #3 5173, #2 3S~2', #1 ~871'. *NOTE: W~LLZAM $TALEY. INLET DRILLING ALASKA FLOORMAN, REPORTEOHE FELT SOMETHINg *IN HIS RIGHT EYE TO ME AT ~200 HR$, 01/03/~4. HE DEPARTEO ON THE HELICOPTER AT THAT *T~ME TO ~EE A OO~TOR IN KENAI ALASKA. HR. STALEY R~TURNED TO THEWORK PLACE AT *ABOUT 1630 HR$ 01/03/g4 ABLE TO WORK AT HIS NORMAL DUTIES, HIS WORK SHIFT Z$ ~NIDNZGHT TO NOON 60 HE DID NOT H~$6 ANY WORK TIHE. ~ E$TIHATED FLUID LOST TO HOLE WAS: ~0 BBL8 TOOAY, CULH TOTAL NOW 008 BBL8 OAILY REPORT PLATFORM: A WELL: A~1-11 .O~-dan-g4 FOREMAN: R.V. WELLS ~PE: ~633~7 ENGINeeR: P. T. HUCKABEE **************************************************************************************** AUTH: $350,000 DAILY:S24,371.00 CUMULATIVE: $298,00B.O0 DA1 YTD; .... 0 TR! YTD; .... 0 DAYS & DAY~ EST~HATED: ~ONMENT$: NO ACCIDENTS REPORTED FLUID TYPE: SPILLS: NO 8PILLS REPORTED RT TO TBS HANGER: TIME AND SUMMARY OF OPERATIONS: 6.0 HRS- DRAINED ~RAKE ~LANGE+ DISCONNECTED WATER FRON BAYLOR BRAKE. REMOVED 10" FLOW LINE. CONFIGURED RZG FOR SHORq' TERM WINTER STORAGE. RIG RELEASED AT 1200 HR$ 01/04/94 RECEIVED APR - 7 1994 & Gas Cons. Commission Anchorage ~0'~ ~NOTE: , DAILY REPORT · PLATFORN: A WELL: A41-1~ Og-dan-g4 FOREMAN: R,H. SELTZ , AFE: 263317 ~NQINEER: P. · AbTH: $!~0,000 DAILY: $3.198.00 CUMULATIVE: $305,154 = CLAI YTO: .... 0 T~! YTD: .... 0 DAYS & DAYS ESTIMATED: OF · COMMENTS: NO ACCIEENTS REPORTED FLUID TYPE: PRODUCED WE[G.qT: · SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: · TIME AND GUMMARY OF OPERATIONS: HR8 - R2G UP ~CHLUMBERGER TO PER~ - TE~T LU~RZP-ATOR TO qSO0 PSI - RUN #1 - GUNS HUNG U~ · aea~' - ~NT~NDEO DEPTH WA~ gg2O' COULD NOT GET DOWN - PERFORATED 012g' - gl60~ (ALTER CONSULTZflG RUN #2 - PERFORATE AT 9718' - 9739' RUN #3 - PERFORATE AT 918C' - 9a14~ RUN #4 - RUNNING [N ~OLE AT REPORT TIME - 90eS~ * PERF ~UNS ARE 2 ~/8" RETRIEVABLE ENERJET STRIP aUNS, ~ JSPF, ~00EGREE PHASE = DALLY REPORT · PLATFORM: A WELL: A41-11 lO-Jan-e4 FOREHAN: R.H. = AFE: 263317 ENGINEER: P. T. HUOKABEE · AUTH: $150,000 DAILY: $1,837,00 CUMULATIVE: f305,991 · DA! YTD: .... 0 TEE YTO: .... 0 DAYS & DAYS ESTIMATED: ~T.75 · COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: PRODUCTION WEI~4T: · SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: 38.90' TOF: · TINE AND ~UNNARY OF OPERATIONS: · ~24.G0 HR6 - PERFORATE RUN #4 - COGS' - g1~9~ (HO-HE) · RUN #5 - PERFOP, ATE FROM e930' TO 8962' NOTE; BOTTOM 16' O[O NOT · RUN #e - PERFORATE FROM ease' TO asao' RUN #1 - PERFORATE FROM 8872' TO a89~' (HO-HO) RUN ~8 - PERFORATE FROM ~40' TO 88T2'(HO-HO) RUN fl~ - PERFORATE FROM a947' TO 8971' (HO-HO) RUN #10 - RUNNING IN HOLE AT REPORT TIME - 9~50' TO $~&O' (HI-HK) Gas Cons. Commission Anchorage 04-05-1994 05: 31~'" FROM She ! ! Platform ¢1 j" TO * DALLY REI~RT "--'~ I , , * ~TH:~O,~ OAILY: ~,~.~ ~ATIV~: s3~,~7o.~ ' DAi Y~: .... ; 0 TR! Y~: .... 1 DAYS & DAYS ESTI~TED: 1.~ OF .'. * ~TS: ~A~IDENTS RE~D FLUID TTK: PR~. FLUIDS ~EGHT: * ~iLLS: ~'~ILLS RE~TED RT TO TBG N~R: TOF: t T[~ ~ ~Y OF * 2/,.00 .RS - * * * * * * * * * * * R/UILUIRZCATQR & TEST TO 1500 PS! - HOLD PRE-PERFORATING SAFETY I~.I~fNG W/PLATFm# PERSONNEL - PERFQ~ATE RUII!Irl - 87~' - 8l~,,,' RUNi~ ' 8696' - ~S65~' RUNii5- MOS' - 8S7~' RUIA !At~ - 85&2' - 8571 * I~IN',~ - 8484m * 8505'~"' RUN iIM- 8/4)6' - 84.18" '2 1/8" RETRIEVABLE STRIP PHASED ENERJET GUNS LOADED 6 SPF , i DALLY REPQRT . * PLATF~#: A iMELL: A&I-ll O?-llar-~& FOREHAN; R.H. SELT2 * * AFE: 2~17,~ ENGINEER: P. T. HU~EE AUTR:~O,~., DALLY: ~,~.00 ~LATIVE: ~,~.~ , . * DA! YTD: .... ~ 0 TRZ Y~: .... 1 DAYS & PAYS EST2~TED: 1.~ OF ?? * ' ~NTS~ N~ ACCIDENTS REPUTED FLUID TYPE: PR~, FLUIDS ~ZGHT: ' ~iLLS: NO ~ZLLS RE~TED RT TO TBG HANGER: ~ 2&.~ fiRS - ~RF~TE V/SCHL~ER~R R~ S~R~E & ~ E~I~NT ANC QFFICE P.02/02 R. CEIVED -7 1994 Ataske, L~ & Gas Cons. Gommissim'~ - Anchorage MEMORANDUM TO: David John.~b_.~,~ Chairmar~ THRU: Blair Wondzell ~ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DA TE: December 12, 1993 FILE NO: AV3JKLAD.DOC PHONE NO: 279-1433 SUBJECT: BOP test Shell platform 'W' ~ddre'Groand,,~hoal (~_, PTD # 85-174 .~) Saturday.~ December 11, 1993 1 traveled to Shell's platform 'W' in the Middle Ground Shoal of Cook Inlet to witness the initial BOP test prior to the workover the beginning of workover operations on well # A41-11. Inlet Drilling Alaska Inc. is the drilling contractor operating Shell's Rig. When I arrived the crew was attempting to attach the kill line and it was found to be aligned incorrectly which necessitated the stack to be nippled down and turned one bolt hole. The test began the following day. Sunday, December 12, 1993 The test, once begun, went well with two failures observed. The outside Kill valve and the manual Choke valve had small leaks that eventually required replacing the valves. This operation added much to the test time which would have been two to three hours shorter. I found that Jerome Dodge (Inlet Drilling rep.) provided a proper and systematic test that insured all components of the BOPE were tested and functioned. A additional problem arose when the gas detectors were to be tested. The sample gas was attached the first detector and the bottle promptly ran out of gas. The reserve bottle (which was new) was connected, and, this bottle was found to be also empty. I observed that the rig electrician seemed confident in the rig system and it was obvious to me that he tested the system quite frequently and was the victim of timing. I allowed the rig to proceed on the condition that sample gas be obtained as soon as possible and the detecto.rs be tested. SUMMARY; I witnessed the initial BOP test on Shell platform "A". Test time 8 hours, Two failures. The outside kill valve and the manual choke valve. Attachment:AV3JKLAD.XLS {~. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: 12/12/93 Drlg Contractor: Inlet Drilling Rig No. A PTD # 85-174 Rig Ph.# 776-5756 Operator: Shell Western Rep.: Rick Seltz Well Name: A41-11 Rig Rep.: Jerome Dodge Casing Size: Set {~ Location: Sec. T. R. Meridian Test: Initial X Weekly Other Test MISC. INSPECTIONS: Quan. Pressure P/F Location Gen.: OK Well Sign OK 1 500\5000 P Housekeeping: OK (Gen) Drl. Rig OK 500\5000 P Reserve Pit NV~ 500\5000 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams n~a Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve Test Pressure P/F 250\3500 P 500\5000 500\5000 500\5000 N~A P n~a P F NV~ 500\5000 F 1 500\5000 P 3 500\5000 NV~ MUD SYSTEM: Visual Alarm Trip Tank P NV~ Pit Level Indicators P P Flow Indicator P P Gas Detectors #1 #1 FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP 1 Ball Type 1 Inside BOP 1 500\5000 CHOKE MANIFOLD: No. Valves 13 No. Flanges 32 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure 500\5000 500~000 P/F P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 1 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btrs: 3,000 I P 1,750 P minutes 8 sec. minutes 42 sec. OK Remote: OK Four Bottles 2750 Average Psig. Number of Failures: 2 ~' ,Test Time: 8.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Outside kill line and manual choke valve leaked, replace and retested OK. (#1)No sample gas onboard, acquire and test gas detectors. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 7119) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AV3JLKAD.XLS Louis R Grimaldi < Shell Western E&P In~~I~~ 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 December 8, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO PULL TUBING AND PERFORATE MIDDLE GROUND SHOAL WELL NO. A41-11 Enclosed in triplicate is the Application For Sundry Approval to pull tubing and perforate the "E" and "F" Pools in MGS A41-11. Operations are expected to begin December 11, 1993. If you have any questions or wish to discuss, please call me at (907) 263- 9646. Sincerely, Paul Huckabee Staff Production Engineer Western Asset, Alaska Engineering Enclosures RECEIVED DEC - 8 199,~ Alaska Oil & Gas Cons. Commission Anchorage .,KA OIL AND GAS CONSERVATION COM -~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation shutdown Re-enter suspended well Alter casing __ Repair Well Plugging ~-~e extension Stimulate Change approved program __ Pull'~bing X mVariance Pe-'~"~oorate ~ Othe'~--' 5. lype ct Well: 6. Datum elevation (DF or KB1 2. Name of Operator Shell Western E&P Inc. Development X 105 KB feet 3. Address 601 West 5th Avenue, Suite 810 Explorato~j 7. Unit or Property name Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service 8. Well numOer 4. Location of well at Platform "A", Leg 4, Conductor 31. Conductor @ 1559' FSL & 388' A41-11 sudace FEL of Section 11, TSN, R13W, S.M. 9. Permit number At top of productive @ 8120' TVD. 4300'N & 950'W of SE corner of Section 11, T8N, 85/174 interval R13W, S.M. 10. APl number At effective depth 50-733-20378-00 _~.'1.0,185' TVD, 4469' FSL & 195.2' FEL of Section 11, T8N, R13W, 11. Field/Pool At total depth ~,M- M.G.S.- "G" Pool 12. Present well condition summary Total depth: measured 10,946 feet Plugs (measured) true vertical 10,197 feet Effective depth: measured 10,863 feet Junk (measured) 20' from EnerJet Perf Gun at PBTD true vertical 10,113 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1808' 13-3/8", 61#, K-55 BTC 750 sx "G" 1808' Surface Intermediate 7267' 9-5/8", 43.5&47#, N-80 BTC/LTC 850 sx "G" 7267' Production Liner 3966' 7", 26#&32#, N-80 & P-110 1390 sx "G" 6980' - 10,946' Perforation depth: measured 8763'- 10,782' Seven Intervals true vertical 8156'-10,014'R E¢ E I VE D Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 EUE 8rd @ 8676' P EC - 8 Packers and SSSV (type and measured depth) OTIS XEL Landing Nipple @ 284' Alaska Ull & Gas Cons. Commissi¢ Anchorage 13. Attachments Description summary of proposal __ Detailed operations program x.~ BOP sketch 14. Estimated date for commencing operation 12/U/93 15. Status of well classification as: 16. If proposal was verbally approved ~ Oil~ Gas __ Suspended __ Service Name of approver Date approved 17. I hereby_certify th~ the foregoing is true and correct to the best of my knowledge Signed ~'~.~.._..O ~ ~ Title Staff Production Engineer Date { ?-./O~_../~"~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness JApprova, No~?c~ "~~ Plug integrity BOP Test Location clearance .-- Mechanical ]n~grity Test__ --Subsequent form requ~'~d 10- ~)~ ~pproved Copy. Returned I Z . , , Approved bY order of the Commission~~.~'c/? ~ ~~..~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NIDDLE GROUND SHOAL HELL NO. A41-l! PULL TUBING & PERFORATE "E" & 'F" POOLS Middle Ground Shoal (MGS) A41-11 is currently producing approximately 260 BOPD at 8% water cut from the Hemlock ("G" Pool). We propose pulling the tubing and packer, resetting the packer above the "E" Pool, and perforating the "E" (GN-GO} and "F" (GR-GS & GS-HC) Pools. An estimated incremental oil production of 75 BOPD is expected. PROPOSED OPERATIONS PROCEDURE 1. Prior to shutting well in for rig operations, obtain water sample in clean sample bottle. Label with well number, date sample recovered, and production interval (Hemlock}. Send sample to laboratory for compositional water analysis. Have results sent to P. T. Huckabee in Anchorage office. 2. Prior to RU operations, flood tbg and tbg x csg annulus with FIW. Bleed off any oil and gas. Monitor tbg and annulus pressures to determine kill brine density. Check for oil & gas migration. Slowly bleed qas and oil only to maintain a consistent FIW gradient in the tubing with minimal disturbance to the formation pressure build-up. 3. Skid rig over A41-11 well conductor slot and RU. RU Slickline and pull SSSV. If well control problem is indicated, circulate down tubing through packer communication to kill well if necessary with' NaC1/CaC12 brine. If kill pump rate is unacceptable via packer communication, pull GLV from bottom GLM. 4. Install BPV. ND tree. NU 5000 psi BOPE and test per Shell Oil Company "Safe Practices For Drilling and Well Servicing Operations, Volume 1, Section 4" and AOGCC Regulation 20 AAC 25.285. 5. Release Guiberson UNI-VII packer (set at 8646' MD-KB) with straight pull shear release. POOH with packer, 2-7/8" tubing, GLM's, Nipples, and SSSV. Visually inspect tubulars, GLM's, Nipples, and SSSV for body and thread damage. Acceptable tubing, GLM's, and "X" nipple will be re-run. Lay down any suspect equipment and replace as necessary. (NOTE: OTIS "XO" Sliding Sleeve will not be re-run). NOTE: Contact Ray Graham with Weatherford/Homco @ (907) 776-8148 for contingency plan if packer does not shear release . 6. RIH with bit and scraper and clean out wellbore in preparation of setting BAKER "HB" packer at - 7800' {Consider cleaning out to 20 foot 2-1/8" Enerjet perf strip fish at P[~TD = 10863'; NOTE- Sl ickline tagged at 10800' on 5/10/92; bottom HR-HZ perf is at 10782'}. D:\FILES\PROG\A41-11. PRG RECEIVED D, EC - 8 199:5 Al~k~ UII & (]18 Oorllt. Commimslon Anohomae 7. Run the following equipment on 2-7/8" 6.5# N-80 EUE 8rd tubing: a) Baker Wireline Re-Entry Guide (WLREG) w/ ball drop shear-out plug to shear at 4000 psi. b) 10' pup jt 2-7/8" 6.5# N-80 EUE 8rd tubing (to allow tbg cut in case shear-out plug does not shear). c) OTIS 2-7/8" "XN" nipple (2.205" ID) d) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing e) Baker "HB" packer for 2-7/8" x 7" 26# to set at - 7800' f) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing g) OTIS 2-7/8" "X" nipple (2.313" ID) h) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing i) bottom Gas Lift Mandrel (GLM) j) 2-7/8" 6.5# N-80 EUE 8rd tubing and GLM's per attached proposed wel 1 bore diagram. k) 2-7/8" Baker "FV-6" TRSCSSV w/ 2.313" "X" nipple profile in top & 1/4" SS control line set at - 300'. 8. Install tubing hanger & land tubing so that WLREG is no deeper than 7850' MD. Function test SSSV. Drop ball to set packer at - 7800' MD. Test tubing to 3500 psi. Shear plug from WLREG. Secure hanger in spool. g. ND BOPE/NU Tree and test each tree component to 5000 psi. Skid rig. 10. If weighted kill brine was used for well control, RIH w/ slickline and pull orifice from bottom GLM. Circulate well with FIW to replace kill fluid. RIH and install orifice. RD Slickline. 11. Return well to production via gas lift and test well. Optimize gas lift as necessary to ensure well is lifting efficiently from the orifice in the bottom GLM. PERFORATE "E" & "F" POOLS 12. After production is stabilized, RU Schlumberger Electric Wireline Unit {EWLU} and perform the following operations to perforate the "E" and "F" Pool s. a) Test lubricator'to 1500 psi +. b) Run Perforation Depth Correlation Log (GR/CCL) from 8800' to 7800'. Correlate to Dresser Atlas DUAL INDUCTION FOCUSED LOG / GAMMA RAY log, run #2, dated 10/18/85. Use color coded markers to flag wireline depths as needed to aid depth correlation during perforating operations. c) While continuing to gas lift for underbalanced conditions, perforate with 2-1/8" Retrievable Strip Phased Enerjet guns loaded 6 SPF at the following depths. (NOTE: Reduce gas injection when guns are at or mbove the SSSV nipple to prevent surging guns into the lubricator when RIH and POOH.) D: \FI LES\PROG\A41-11. PRG page 2 RECEIVED DEC Ala~km 0~1 & Om~ Oon.. Comml$~lon 4nohoral~e AOGCC SWEPI POOL ZONE "E" GN- GO "F" GR-GS "F" GS-HC "F" GS-HC "F" GS-HC RD EWLU. Test well and report. DRESSER ATLAS DIL PERFORATION DEPTHS 7920' - 7955' 8:370' - 8418' 8484' - 8505' 8542' - 8605' 8665' - 8730' INTERVAL FOOTAGE 35' 48' 21' 63' 65' 232' D' \F I LES\PROG\A41-11. PRG page 3 RECEIVED DEC - 8 199,t Alaska 0il & Gms Cons. Commission Anchorage 6 12 13 14 COMPLETION EQUIPMENT DETAIL SHEET MGS A41-tl 7/21/87 NO. iTEM 1. OTIS XEL LANDING NIPPLE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL #7 9. GAS LIFT MANDREL #8 10. GAS LIFT MANDREL #9 11. OTIS "XO" SLIDING SLEEVE 12. 7" UNI-PACKER VII 13. OTIS "X" NIPPLE 14. GUIBERSON SHEAR OUT SUB CASING APPROXIMATE TVD. MD_~ PS__~I OR 284 284 1640 1698 835 3/16 3134 3335 845 3/16 4402 4719 850 3/16 5415 5856 845 3/16 6276 6805 DUF~4Y 6953 7535 865 1/4 7445 8045 850 1/4 7829 8431 920 1/4 8025 8628 905 1/4 8039 8643 8042 8646 8061 8665 8072 8676 13 3/8", 61#, K-55 @ 1808' w/700 sx 50 sx top job 9 5/8", 43.5#, N-80 @ 0 - 4875' 47#, N-80 @ 4875-7267' w/850 sx 7" 26#, N-80 LINER 6980-8829' 32#, P-110 8829-10994' w/1400 sx short joints @ 8779', 9056' PBTD = 10,863' TO = 10,946' TUBING 2 7/8", 6.5#, N-80 EUE @ 8675' PERFORATED ZONE HC-HD HC-HD HE-HF HI-HK HI-HK HK-HN HK-HN HN-HR HN-HR HN-HR HN-HR HR-HZ HR-HZ HR-HZ G. ROSS .i. NTERVAL NF'P 8763-9050' 9096-9150' 9176-9220' 9400-9420' 943~-9490' 9720-9750' 9770-9938' 10070-10075' 10100-10140' 10200-10315' 10400-i0430' 10506-10600' 10614-10628' 10656-10782' 3 4 X XX < / \ ~= := ~= FISH I< ////////< TD = 10946' MIDDLE GROUND SHOAL A41-11 PROPOSED WELLBORE DIAGRAM - 12/07/93 L 2-7/8" "SJ-FBB" Ext. Seal Neck Tubing Hanger - BAKER "FV-6" TRSCSSV w/ 2.313" "X" @- 300' 24" Conductor Casing @ 370' 13-3/8" 61# K-55 Surface Casing @ 1808' 2-7/8" 6.5# EUE 8rd Tubing GLM MD 1 ' 2 ' 3 ' 4 ' 5 ' 6 ' 7 7730' -TVD PORT Ptro Psc Pso GAS ' 12 984 ' 12 968 ' 12 949 ' 12 936 ' 12 920 ' 12 905 ~' 1/4" ORIFICE Top of 7" Production Liner @ 6980' 9-5/8" 43.5#/47# N-80 Casing @ 7267' GLM #7 @ 7730' MD 1 jt 2-7/8" 6.5# N-80 EUE 8rd tubing ............. OTIS "X" Nipple @ 7769' {2.313" I.D.) 1 jt 2-7/8" 6.5# N-80 EUE 8rd tubing BAKER "HB" Packer @ 7800' *Shear @ psi 1 jt 2-7/8" 6.5# N-80 EUE 8rd tubing OTIS "XN" Profile Nipple @ 7839' {2.205" ID) 10' pup it, 2-7/8" 6.5# N-80 EUE 8rd BAKER Wireline Re-Entry Guide @ 7850' := GN-GO I GR-GS GS-HC 7920'- 7955' MD 8370'- 8418' 8484'- 8505', 8542'- 8605', 8665'- 8730' HC-HD HD-HE HE-HF HI-HK HK-HN HN-HR HR-HZ 8763'- 9050', 9096'- 9150' 9176'- 9220' 9400'- 9420', 9430'- 9490' 9720'- 9750', 9770'- 9938' 10070- 75'/10100-140'/10200-315'/10400-430' 10506- 600', 10614- 628', 10656- 782' 20' 2-1/8" ENERJET Strip Gun FISH PBTD = 10863' 7" 26/32# N-80/P-110.Production Liner @ 10946' D' \FILES\PROG\A41-11. PRG page 4 WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 29, 1992 Paul Huckabee Production Engineer Shell Western E&P Inc. 601 West Fifth Ave., Ste 800 Anchorage, AK 99501 Re: No Flow Verification MGS Well #A 41-11 PTD 85-0174 3001 PORCUPINE DRIVE ANC HO RAG E, ALASKA 99501 -$192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Dear Mr. Huckabee: At your request, on December 22, 1992 our inspector, John Spaulding, witnessed a no-flow test on subject well. He observed the well over a 4 1/2 hour period and concluded that the well was not capable of unassisted flow. The Commission hereby authorizes removal of the subsurface safety valve from MGS well No. A-41-11, on the condition that the Iow pressure sensor and surface safety valve must be maintained in good condition and if for any reason the well again becomes capable of unassisted flow, the subsurface safety valve must be reinstalled and maintained. Sincerely, °! /' I'" ,;i ~ " , ! .. ....... .,. " ,: . ( ..," " :7' LI!~.,, Leigh Griffin Commissioner /dlf xc: Morris Dunkley/Richard Vickerson, Shell · MEMORANDUM STATE OF ALASKA 'ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Griffin Commissioner date: file: December 28, 1992 JOH12221.DOC thru: Blair E Wondzell Sr Petr Engineer from: -~'~ohn Spaulding Petr Inspector subject: No-Flow Test Shell Platform 'W' Middle Ground Shoal Field Well A-41-11 PTD-0174 ~>~'" 1~ Tuesday, December 22, 1992: I traveled to Shell's Platform "A" to witness a no- flow test on Well A-41-11. Upon arrival, I observed the well bled to Zero and open to the test separator, the casing was bled to 62 PSI(~ I monitored the fluid level in the test separator for two and one half hours; no fluids were produced. At this time the wing valve was closed to monitor the tubing pressure on a 0-300 pressure gauge. I monitored tubing pressure for two hours and observed a 4 PSI (gauge) increase. This increase was bled to zero in less than 1 minute. Because Well A-41-11 appear~to be stabl~i?exhibited no fluid productiorl?and had a small amount of gas which was apparently breaking out of solution, I believe this well is a good candidate for a "no-flow" status. SUMMARY: I witnessed a successful "no-flow" test on Shell Well A-41-11 and request that the commission issue a "no-flow" confirmation to Shell. Shell Western E&P In 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 August 7, 1991 Ms. Joan Mil 1 er State of Alaska Alaska 011 & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Dear Ms. Miller: SUBJECT: MONTHLY INJECTION REPORT'FOR THE MIDDLE GROUND SHOAL FIELD (MGS) FOR THE MONTH OF JULY, 1991 The Monthly Injection Report for the Waterflood project at MGS for July is enclosed in duplicate. If you have any questions regarding this report, please call Ms. Susan Murnan at (907) 263-9614. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures \AOGCC\MTHLYINJ.JULY( I~as~Ot~ ik~c,bo'~e OI i i i i . i i ! , i i 0 0 0 0 0 0 0 0 0 0 0 0 C:)Ii.q__/NJ'"" ,- i i i i o o & & & o' ,:,' o' ~ o Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800' Anchorage, Alaska 99501 June !], !990. Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 9950] SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we 'could provide it. Enclosed, for your convenience and use, are the following: 2 location surveys showing the location of Platform A 1 list of conductor/well locations {in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells 1 location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and LOg {10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at {907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190.D0C RECEIVED /tlaska Oil.& Gas Cons. comml~lrorl tlnchoraga ' MIDDLE GROUND SHOAL P1 atform "A" WELL/CONDUCTOR LOCATIONS Levi I - Center of Leg i @ 1627'N & 435'W from SE corner of Sec.11, TSN, R13W, S.M. A 12-01 I 1632'N & 437'W from SE corner A 11-01 2 1632'N & 432'W " " " A 43-11 3 1630'N & 430'W " " " A 34-11 4 16 25 ' N & 430 ' W " " " A 34-14 RD 5 1622'N & 433'W '" " " A 22-14 6 1622'N & 437'W " " " A 12A-01 7 1625'N & 440'W " " " A 13-01 8 1630'N & 440'W " " " ,, Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec. 11, T8N, R13W, S.M. A 42-11 9 1685'N & 374'W from SE corner A 44-02 10 1685'N & 370'W " " " A 42-14 11 1683'N & 368'W " " " A 41A-11 12 1678'N & 368'W " " " A 11-12 13 1675'N & 371'W " " " A 11-13 RD 14 1675'N & 375'W " " " A 31-14 15 1678'N & 378'W " " " A 44-11 16 1683'N & 378'W " " " Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec.11, T8N, R13W, S.M. Leg 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 1571'N & 385'W from SE corner A 14-01 26 1571'N & 381'W " " " A 12-12 27 1568' N & 378'W " " " A 24-01 28 1564'N & 378'W " " " A 13-12 29 1561'N & 381'W " " " A 33-14 30 1561'N & 385'W " " " A 41-11 .~ 31 1559'N & 388'W " A 23-01 32 1569'N & 388'W " ~laska Oil & Gas Cons. Gommission Anchoraga SBBC/mgs A · 't L | TgN S.M. I I 4 3 · · · ,m · · · · · · · · · · · LAT. GO® 47' 44.806' * ' STATE GRID COORD. ~ m 232,839.5 ~ ~ ~ · Y m 2,4eS,B40 · ZON; 4 ~. 1623.5'.~-~ , .'" . 16 15 14 13 ..' ' , ; .' , , . .. , .. ~.. ~ ~ -~-_ . · ,. : - . _ _ _ ,, ........ ~~ ~t~~ . 28 2T Z6 " 25 30 . . 33 34 ~ 3536 }1 32 ,RECEi [i) ., .-.. i : " :;. LOCATION OF . . , ~,lasR;, ~ii & Gas Con~. C ~mmission PRODUC~NO PLATFORM T 8 N S.M. , gllchoraW" SHELL MIDDLE GROUND SHOAL , ~ ~ 7N S.M., t , ,, PLATFORM A" t; COOK IN[ ET. ALAS,,A j- ! 0 ,4000 eooo t;oo0 APPLICATION BY SHELL OIL CO. t,~_~--' ',=~.~.~.~-::= ,~-. _--.X-~::-: ~--*":--~=~----,,~ LOS ANG E I. £ $, CAt.! FORN IA SCALE IN FEET .. Ii I0 I0 II 14 T. 8 N.,R. 3W., S.M. I 1875~ t 2 II 14 ADL LEG NO. I X = 232,78;5 Y = 2,o~85,845 1627' I',1 B 455'W FROM THE SE COR. OF SEC. II,T8N, RISW, SM. LEG NO. 2 LEG NO. PLAN£ COONDIRA ~'~S X= 232,846 X= 232~896 Y = 2,485,897 Y = 2,485,835 POBI../ C LAND 1681' N B. :572' W FROM THE SE COR. OF SEC. II, T8N, RI:SW, SM. D E$ CI~/ P T./ OIV 1620'N 'B :521' W FROM THE SE COR. OF SEC. II, TBN, RI:SW, SM. LEG NO.,~ X = 2, 3,2,8:33 Y = 2,~'85,785 1566'N 8, 38:5'W FROM THE SE COR. OF SEC. II, TSN,RI3W, S.M. GEOD£T/C COO/TD/./VA TE'S LAT.- co0°47'44.839" LAT.-60°47'45.368" LAT.-60047'44.768" LAT.- 60047'44.244" LONG.- 151° 29'45.112'', LONG.-151°29' 43.942" LONG.-151° 29' 42.%99'' LONG.- 151° 29' 44.154" · $'.~ P.~ ~. S .~ i~ ~S Z - 415,q-', ~ Z- 41 0-2 · "" %,a~,.',Ii,ll; J'ti Ni II '. ,.~.~ ,~., ,~-~ . - '''''"''~`'~'''~~'''' ' ' ';'"'~"' ""'"' -- ' ' ' ' ~ ~ I C)C:,ATIC)i'q OF RSH 1655 1151-C BRITTMORE ROAD HOUSTON, TEXAS 77043 (713) 932-7183 TRANSMITTAL LETTER RECORD OF SH I PHENT OF CON~ I DENTIAL INFORMATION TO: Mr. John Boyle FROM: A.O.O.C.C. -.- .. 3001 Porcupine Drive Anehoraffe, Alaska 99501 DATE: G eorl~e W. Bo~er Pro{eet Leader (NAME & TITLE) June 30~ 1986 VI A: ,.u.s. Mail QUANTITY DESCRIPTION CONTENTS 2 eopies: Geologieal Analysis and Evaluation of GB Sands, Shell Western Exploration and Production, Inc., A43-11 Well (6965-6986 Feet), A33-11 IA'ell (7021-7150 Feet), A41-11 Well (7366-7494 Feet), Middle Ground Shoal Field, Alaska. .. =.. INSTRUCTIONS: RECEIVED BY: REMARKS: PLEASE ACKNOWLEDGE RECEIPT PROMPTLY BY SIGNING AND RETURNING DAT£",ff~ / ~~~ ~ ~~D~L O~ 19~ '-' 11S1 - C BRITTMORE ROAD HOUSTON, TEXAS 7704,1 (71~) ~-?IM June 27, 1986 Mr. John Boyle A.O.G.C.C. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear John: The two copies of this report are being provided to the A.O.G.C.C. at no charge to yourself or Shell OiL This material is considered confidential to Shell Oil Company and should be treated as such. Permission was granted to provide these copies by Mr. Clay Williams of Shell. ... G¥;B:mml Sincerely. Enclosures .. '~.~ Oil t, Gas Cons. 1151-C BRITTMORE ROAD HOUSTON, TEXAS 77043 {713) 932-7183 TRANSMITTAL LETTER RECORD OF SHIPMENT OF CONFIDENTIAL INFORMATION TO: Mr. John Boyle State of Alaska Alaska Oil & Gas Conservation Com mission 3001 Porcupine Drive Anchorage, Alaska 99501 QUANTITY DESCRIPTION FROM: James J. Parr , DATE: VIA:. Geologist (NAME & TITLE) CONTENTS 1 Copy: Geological Analysis and Evaluation of GB Sands, Shell Western Exploration and Production, Inc., A43-11 Well (6965-6986 Feet), A33-11 Well (7021-7150 Feet), A41-11 Well (7366-7494___.._Feet), Middle Ground Shoal Field, Alaska. INSTRUCTIONS: qECEIVED BY: ~,EMARKS: PLEASE ACKNOWLEDGE RECEIPT PROMPTLY BY SIGNING AND RETURNING THE YELLOW COPY, DATE: SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTION MAY 20, 1986 SHELL WESTERN E&P INC. MIDDLE GROUND SHOAL FIELD WELL NO. A-41-11 KENAI, ALASKA API NO. 50-733-20378-0000 SAMPLE/DEPTH FEET PYCNOMETER GRAIN DENSITY TOLUENE BRINE g/cc g/cc 6620.65 2.642 2.633 6632.75 2.656 2.650 '.,TE : April 30, 1986 "jOMPANY: Shell Western E&P Inc. WELL NO: A-41-11 API NO : 50-733-20378-0000 FIELD : Middle Ground Shoals STATE : Alaska SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTIO~ STRESS ANALYSIS DATA Grain Sample Lab Depth Density No. No. ft-in gm/cc 5 A-4611 6619-02 2.647 15 A-4612 6632-08 2.663 21 A-4613 6640-02 2.642 25 A-4614 6644-01 2.652 Grain density determined by pycnometer using brine. Brine salinity contained 36,000 ppm NaC1 + 4,000 ppm CaC12. Shell Western E&P Inc. · ~..Subsmdmary ot Shell 0,1 Company P.O. Box 576 Houston, TX 77001 May 28, 1986 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99510 .Attn: John Boyle Dear Mr. Boyle: SUBJECT: DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD, COOK INLET, ALASKA. Well' A. II. II Work Order No: ~.~(~qll Enclosed you will find data pertaining to the Middle Ground Shoal Well 1 isted above. Please return a signed copy of this transmittal letter to acknowledge recei pt. Very tr~ C~Wil 1 lams Alaska Division Shell Western Exploration and Production, Inc. CCW-bj Rec ' d By TEICT8614804 .-"":.',. ~;:'.'v.,'-~'- SECTION FO .!~:,!~5~.TT.:~.~-.::~;!ii.i] R YOUR RECORDS ~.':::i.75.'.%;'::::~;:! R ' - DATE_ 19____._ .. SEPIA SERA RETAIN THIS SECTION FOR YOUR RECORDS '"'~"::'< :~'::~"::; RE t { ':.~....::',: :,~,:,...: 1 SEFqA · ,,. ,~:,;".. :~.'..: '~."'%:.:',":'?~:' SEPIA ,.".~,,,,.-: ,~..,~:~.~,,~ · ':'"'~"~'=~'" NI SEPIA - NEG. SERA ":". '.'?::!~'~"!i.:i Alaska b. ~ ~... -.~ cn .:.:.:..?:.,::..~;:'..- ~'.:"'.~-......._ ,~c~,v~= ,,o~: ',':'"':"7 DRESSER ATLAS SIGNED DATE ,. __ ...... ........ ..... ..... ., .... · ,. ., j .,, .- . ., RE R(,AIN THIS SECTION FOR YOUR RECO(.~S .. A41-1l (O~EN HOLE), All-13RD#2 (PLS) (SHELL) · FMT 5" 1 PRINTS 0 NEG. I~l FI ~-&5" 1 PRINTS 0 NEG. CN/CDL ~ 2&5" ] PRINTS 0 NEG. C-N/¢DL 215'l 1 PRINTS 0 NEG. BHC 2~_5'' 1 PRINTS 0 NEG. PLS 1 PRINTS ~~~ / PRINTS PRINTS NEG. ABOVE RECEIVED FROM: DRESSER ATLA'q3pR 0 9 :].986 JOHN BOYLE ATTENTION . /~ . SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA Alaska OiJ & C,~ Cnn~_ Comml_~.lo~ DATL~¢~ 19~ STATE OF ALASKA ALASK/~" ~AND GAS CONSERVATION .~' "AMISSION WELL COMPLETIO OR RECOMPLETIOi AEPORT AND LOG ~. st,,us of we, Revised 03-26-86 Classification of Service Well OIL I~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator She]] Western E&P Inc. 3. Address 601 West Fifth Avenue_. Suite 810; Anchorage: Alaska 99501 4. Location of well at surface Platform "A", Leg 4, Conductor 31. Conductor @ 1559' FSL & 388" FEL of Sec. 11, T8N, R13W, S.M. B'8'~120' T~/D. 4300'N & 950'W of SE corner of Sec.11,TSN,R13W At Total Depth lc>, @ 10,185' TVD, 4469' FSL & 195.2' FEL of SeC. 11, T8N,R13W 5. Elevation in feet {indicate KB, DF, etc.) 116' KB ADL 18754 2. Date Spudded t I~(° 09/12/85 ~o / 7. Total Depth (~) 18.Plug Back Depth (MD+TVD) 10,946 +,'Q0,-tg-~ 10,863 + 10,114' 6. Lease Designation and Serial No. 13. Date T.D. Reached 10/19/85 7. Permit Number 85-174 8. APl Number so- 733-20378-00 9. Unit or Lease Name Middle Ground Shoa] 10. Well Number A 41-11 11. Field and Pool Middle Ground Shoa ! "G" Pool 11/28/85 I 80 feetMSLI single 19. Directional Survey ! 20. Depth where SSSV set121. Thickness of Permafrost YES [~ NO [][ 284 feet MDI N/A 22. Type Electric or Other Logs Run DIL, Acoustic, GR, PCM, [.o, fl.~" DIFL, BHC-AL, CN, CDL, CAL CASING, LINER AND CEMENTING RECORD CASING SIZE 20" 13~3/8" 9-5/8" 7" WT. PER FT. 94# 61# SEE AT' SEE AT' iGRADE H-40 STC K-55 BTC 'ACHED WOI 'ACHED WOI SETTING DEPTH MD TOP BOTTOM 0 330' 0 : 1808' tKSHEET F3R DETAI ~KSHEET F)R DETAILI HOLE SIZE 26" 17~" CEMENTING RECORD 7355x "G"+ additives 7505x "G"+ additives AMOUNT PULLED ,, 24. Perforations open to Production (MD+TVD of Top and Botto~n and interval, size and number) SEE ATTACHED WORKSHEET 25. TUBING RECORD PACKER SET {MD) SIZE DEPTH SET {MD) _~ 7/R" :6.F~.. N-80 39.8 8~646~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) IAMOUNT & KIND OF MATERIAL USED HR-HZ IFrac 703 bb] 40# ge] .. HN-HR IFrac 754 bb] 40# ae] HK-HR IFrac 765 bbl_ 40# ~e! I 27. PRODUCTION TEST Date First Production 11/09/85 I Date of Test Hours Tested 11/28/85 24 Flow Tubing Casing Pressure Press. 80 750 28. I Method of Operation (Flowing, gas lift, etc.) qas I ift ' IPRODUCTION FOR ~OIL-BBL ] GAS-MCF e 1724 I J24-HOUR RATE ~J 724 J 191 CORE DATA 4 J 128/64 I 264 WATER-BBL JOIL GRAVITY-APl (corr) 4 I 35.0 Brief description of lithology, porosity, fractures, apparent dips a~d presence of oil, gas or water. Submit core chips. ./^ RECEIVED .APR O 11986 Alaska 011 & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate March 17, 1986 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gen tl emen' Attached is the Completion Report for the Middle Ground Shoal well A 41-11. If you have any questions, please contact Susan Brown at (907) 263-9613. V, ,e~truly yours, D. L. Y~s~Tand Sr. Stf~f;r Envi ronmedtal AlaskaLBivision Engineer DLY/kka Attachment SBBC/aogcc.3c " STATE OF ALASKA '" ALASKA{' ,. AND GAS CONSERVATION Cd '~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE J~l ' ~;-..; ....;;~ .... ~ · 2. Name of Operator _ ..~.r,, :....; ~. 7. Permit Number w:~,~i~_~ i 85-174 Shell Western E&P Inc. , 3. Address Surf. 1~. ~ 8. APl Number 601 West Fifth Avenue. Suite 810. Anchoraoe. Ala~k~=B'~~] so- 733-20378-00 4. Location of well at surface " ' ~ 9. Unit or Lease Name Platform "A", Leg 4, Conductor 31. 1559'N & g.~8'W of SE Middle Ground Shoal ~,~)for~o~[ing~n~rval1 1, TGN, R13W. ~o. Well Number @ 8,120' TVD. 4300'N & 950'W of SE corner of Sec.11,T8N,R13W A 41-11 At Total Depth ~1 ~ ~ ~ ~ ~ ~ ~ ~' I~ / ~'j~/--! Sc. et (,!~, ~'~'1~ 11.FieldandPool ............. ,, ~ .... ~, ~ ~,,,er cf ~. ,,,TG;;,R13W Middle Ground Shoal B. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 116' KB ADL 18754 "G" Pool 12. Date Spudded 09/12/85 13. Date T.D. Reached 10/19/85 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 11/28/85 80 feet MSL single 17. TotalDepth (~.~.~)1 18. Plug Back DePth (MD+'rVD)19. DirectionalSurveY10,94~5 +. 10,863 + 10,114' YES[~ NO[] I 20' Depth where SSSV set I 21'Thickness°fPermafr°st284 feetMD N/A 22. Type Electric or Other Log~ Run DTL~ Acoust[c~ GR~ PCM~ DTFL~ BHC-AL~ CN, CDL, CAL 23. CASING, LINER AND CEMENTING RECORD , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 STC 0 330' 26" 735sx "G"+ additive.~ 0 . , 1.3-3/~" 61# K-55 BTC 0 1808' 17V~" 750Ex "G"+ additives 0 g-5/8mm SEE AT'ACHED. WOIIKSHEET 'F3R DETAIl ; 0 7" SEE AT"ACHED WOltKSHEET FUR D~TAILIi 0 24. perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING 'RECORD' intarval~ size and number) SIZE DEPTH SET (MD) PACKER SET (MD) . ~ 7/EU'.6.~.N-~ 39.8 ~,646' SEE ATTACHED WORKSHEET 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED HR-HZ Frac. 703 bb] 40# gel · HN-HR Frac 754 bb] 40# oe] .~ ...... HK-HR Frac 765 bb! 40# ge] 27. PRODUCTION TEST Date First ProduCtion I Method of Operation (Flowing, gas. lift, etc.) 11/09/85I gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S,ZE I GAS-OIL RATIO 11/28/85 24 TESTPERliOD I~. 724 191 4 128/64= 264 . Flow Tubing Casing: Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. 80 750 24-HOUR RATE I~ 724 191 4 35.0' .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. ' ,. N/A .... ~ ...;" ,~'., ~ '' : 'm,'.I ~.' .' ........, ':"''"~"" .... ~ . , . Form 10-407 Submit in duplicate Rev. 7-1.-80 CONTINUED ON REVERSE SIDE 29. 30. NAME GEOLOGIC MARKERS MEAS. DEPTH 31. LIST OF ATTACHMENTS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. Wel 1 Historz,.._._9__5../_.8_'.'_Casjn__q_~rks.h_~.t_~__7" Casinq Worksheet, Perforation Worksheet 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~:":'~ Title Production Superint. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct v~ell completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 WELL HI STORY Middle Ground Shoal A 41-11 09/02/85 09/03-07/85 09/08-10/85 09/10-11/85 09/12-17/85 09/16-17/85 09/17-28/85 09/29/85 09/30/85 10/01/85 10/02-18/85 10/19-20/85 10/20-21/85 10/22-23/85 10/24-11/10/85 Rig up and begin fishing operation on Conductor 31 of Leg 4. Recover fish from Conductor 31 of Leg 4. Total amount recovered: 237'. Drill to 330'. Run 20" casing and cement. Drill and survey to 1,808'. Run 13-3/8" casing and cement. Drill and survey to 7,150'. Logging. Condition hole. Run 9-5/8" casing cement. Drill and survey to 10,900'. Logging. Drill to 10,946' and log. Run 7" liner and cement. Perforate, fracture, and complete well. SBBC/well .0 WORKSHEET FOR MIDDLE GROUND SHOAL A 41 -11 9 5/8" Casing Da1;e of Opera1;ions: Hole size: 12-1/4" 10/02/85 Casing= 47#/f1; 47#/f1; 43.5# Shoe e : 72 66' Amo un 1; N-80 BTC 1943' 47 joJn1;s N-80 LTC 448' 12 joints N-80 LTC 4875' 123 join1;s D~P 1;_._bh 72 66 -53 23 ' 5323-4875' 4875-0 ' Cement= Amount; 350 sx 500 sx Class "G" + 8~ gel + 2% CaC1 + 0.15% D-31 + 0.2~ R-5 Class "G" + 0.75% D-31 + 0.1~% R-5 Casing Tested On: 10/02/85 (Okay) SBBC/wksh.6 WORKSHEET FOR MIDDLE GROUND SHOAL A 41-11 7" Liner Date of Operations: Hole size: 8~" 10/23/85 Liner: 32#/ft 26#/ft 32#/ft 26#/ft Shoe set @ : Cement: Amount 1390 sx A mo un t P-110 2015' 47 joints N-80 118' 3 joints P-110 31' 1 joints N-80 1783' 45 joints 10,944' 10~944-8s929' 8,929-8,811' 8~811-8,780' 8,780-6,997' "G" + 1~ D-19 + 0.1% D-6 + 0.3% D-31 Liner Tested On: 10/23/85 (Okay) SBBC/wksh.7 Date 10/28/85 10/28/85 11/01/85 11/05/85 11/05/85 11/21/85 11/21/85 11/23/85 11/2~/85 11/24/85 11/25/85 11/25/85 11/25/85 11/2~'/85 Z one HR-HZ HR-HZ HN-HR HK-I"N HN-HR HN-HR HR-HZ HN-HR HI-HK HK-I-N HC-HD HE-HF HI-HK HC-HD MD 10~Z~50 10sq. 50 9~999 9~718 9s999 9s999 10~Z~50 9s999 9s39~ 9~718 8~762 9~170 9~394 8~762 TVD WORKSHEET FOR MIDDLE GROUND SHOAL A Z~1-1 1 Perforations Perf. Interval 9s7z~6 9s746 9s338 9~077 9~338 9~338 9s746 9~338 8~770 9~077 8~157 8~555 8~770 8~157 10~506-600' 1 0~656-7 82 ' 10~ 200-315' 9~770-938' 10~070-075' 1 0~1 00-1 40' 10s614-628' 1 0 ~ 4 O0-q- 30 ' 9sz~30-z~90' 9~720-750' 9~096-150' 9~176-220' 9~400-420' 8~763-050' MD 0~830 0~830 0~450 9~999 OsZ~50 O~Z~50 0~830 0~50 9s718 9~999 9~155 9~220 9~718 9~155 TVD 10~081 10s081 9s7z~6 9s338 9s7~.6 9s7z~6 10s081 9s746 9s077 9~338 8~5~1 8~603 9~077 8~5z~1 Gun ~JSPF 4" SOS TC I! !1 II II 50JS ltd entry ~CUS ltd entry 5JS ltd entry &JSPF 2-1/8" TT I! !1 I! II II !1 II II II II II I! !1 II II II I! II Il II II II Il !! SBBC/wksh.9 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 SHELL WESTERN EXPLORATION AND PRODUCTION INC. WELL A-41-11 MIDDLE GROUND SHOAL FIELD RESISTIVITY MEASUREMENTS DRY SIEVE ANALYSIS DATA DECEMBER 1985 FILE 96512 [? .~ C E IV E D ", r'" ,,"~ Al~s,,~ u~ ~ ~as Co~s. CommJgsJo~'~ Anchorage 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 December 12, 1985 Shell Western Exploration & Production Inc. P. O. Box 527 Houston, Texas 77001 Attention: Mr. Brian Tepper Gentlemen: Re: Well A-41-11 Middle Ground Shoal Field Resistivity Measurements Mercury Capillary Pressure File 96512 Enclosed are formation factor, resistivity index, cation exchange capacity and mercury capillary pressure data on core material recovered from your Well A-41-11, Middle Ground Shoal Field, Alaska. The test plugs were dried, saturated with synthetic formation brine and confined at a simulated reservoir stress of 2500 psi for formation factor, porosity and brine permeability measurements. Resistivity index tests were then performed at 2500 psi on samples at 6620.65, 6632.75, 6640.20 and 6644.10 feet~.Cation exchange capacity values were obtained from the sample end butt material using the method outlined by Shell. The reported resistivity data are corrected for clay content using these CEC numbers. Following the resistivity measurements, the' samples were extracted with toluene and then methanol, dried at 180 F and air permeabilities measured. Pore and bulk volume values were determined by the Archimedes method using toluene. Note that these values may differ from the originals due to sample compression. The samples were dried as before and placed in the mercury capillary pressure test apparatus. The air within the equipment was removed by vacuum and the sample surrounded with mercury at 0 psia. Each sample was then subjected to increasing incremental pressures ranging from 1.23 to 1300 psia. The wetting phase saturations were calculated from these data minus the previously determined system calibration. 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 We sincerely appreciate this opportunity to be of service and trust these data prove beneficial in the development of this reservoir. Very truly yours, PETROLEUM TESTING SERVICE, INC. PL:pml Encl. Peter T. Schuy~ President PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. PAGE No. 1 FILE No: 6512 DATE: NOVEMBER 1985 WELL: FIELD: A-41-11 MIDDLE GROUND SHOAL TABLE 1 SYNTHETIC BRINE DATA 1. BRINE RESISTIVITY o Rw = 0.1633 ohm-m @ 25.00 C 2. BRINE DENSITY DATA mmm mmmmmmm o 1.0283 gm/ml @ 21.69 C o 1.0265 gm/ml @ 25.44 C 3. BRINE VISCOSITY DATA -- o 1.061 cp @ 21.11 C o 0.992 cp @ 23.89 C 0 0.928 cp @ 26.67 C 3. BRINE DESCRIPTION COMPOUND SODIUM CHLORIDE CALCIUM CHLORIDE ppm 36000 4000 PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. FILE No: DATE: WELL: FIELD: PAGE No. 2 6512 NOVEMBER 1985 A-41-11 MIDDLE GROUND SHOAL TABLE 2 FORMATION FACTOR DATA AT 2500 psi SIMULATED RESERVOIR STRESS FORMATION CATION '"FACTOR BRINE EXCHANGE POROSITY' @ SRS SAMPLE DEPTH PERMEABILITY CAPACITY percent * NUMBER .'feet mD meq/gm @ SRS Frw (1) 1-6 6620.65 6.88 0.009 13.92 37.37 1-7 6621.90 4.91 0.011 15.00 33.09 1-8 6622.60 15.0 0.009 16.08 29.71 2-1 6628.40 8.40 0.009 16.10 30.13 2-6 6632.75 1.22 0.012 14.13 41.73 2-9 6635.25 0.87 0.012 14.35 '40.87 2-10 6636.10 21.7 0.011 18.18 23.60 3-1 6639.10 0.69 0.007 8.82 78.49 3-2 6640.20 1.04 0.011 10.08 73.03 3-6 6644.10 5.42 0.012 14.89 35.01 (1) Frw and all subsequent values are clay corrected based on the CEC values obtained using the Barium Chloride Titration Method. o REPORTED VALUES CORRECTED TO 25 C PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E SAMPLE DEPTH NUMBER feet mmmmmm PAGE No. 3 & P INC. FILE No: 6512 DATE: NOVEMBER 1985 WELL: FIELD: TABLE 3 CEMENTATION FACTOR DATA A-41-11 MIDDLE GROUND SHOAL ARCHIE'S EQUATION * m 1-6 6620.65 -1.84 1-7 6621.90 -1.84 1-8 6622.60 -1.86 2-1 6628.40 -1.86 2-6 6632.75 -1.91 2-9 6635.25 -1.91 2-10 6636.10 -1.85 3-1 6639.10 -1.80 3-2 6640.20 -1.87 3-6 6644.10 -1.87 COMPOSITE -1.86 WYLLIE'S EQUATION -1.72 1.33 o REPORTED VALUES CORRECTED TO 25 C PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE (::;ROUND SHOAL DATE: NOVEMBER 1985 WELL: A-4-1-11 SAMPLE NO.: 1-6 DEPTH, FT.: 6620.65 m = -1.84 Z lO0 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-4-1 - 11 SAMPLE NO.: 1-7 DEPTH, FT.: 6621.90 Z lO0 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL.~ A-41-11 SAMPLE NO.: 1-8 DEPTH, FT.: 6622.60 rn *-- - 1.86 Z 0 100 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-4-1-11 SAMPLE NO.: 2-1 DEPTH, FT.: 6628.4-0 rn *= - 1.86 Z 100 10' 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-4-1-11 SAMPLE NO.: 2-6 DEPTH, FT.: 6632.75 Z 100 10 m -- -1.gl 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-4.1-11 SAMPLE NO.: 2-9 DEPTH, FT'.: 6635.25 m*= -1.91 Z 100 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: FIELD: WELL: DEPTH, Fr.: SHELL WESTERN E &: P MIDDLE GROUND SHOAL A-4-1-11 6636.10 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: 2-10 rn*= - 1.85 I, Z 100 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CUENT: FIELD: WELL: DEPTH, FT.: SHELL WESTERN E & P MIDDLE GROUND SHOAL A-41-11 6639.10 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: ,3-1 = -1.80 Z 100 10 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR Ys. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: FIELD: WELL: DEPTH, FT.: SHELL WESTERN E & P MIDDLE GROUND SHOAL A-41-11 6640.20 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: 3-2 m -- -1.87 Z 100 10 · i i ii 10 100 POROSITY, PERCENT @ S.R.S. I,., PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO..' CLIENT: FIELD: ...... WELI~ DEPTH, FT.: SHELL WESTERN E &: P MIDDLE GROUND SHOAL A-4.1-11 664-4.10 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: 3-6 Z 100 10 m -- -1.87 10 100 POROSITY, PERCENT @ S.R.S. Z 100 10 PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-41-11 SAMPLE NO.: COMPOSITE m -- -1.86 g. ~ . · 'x \ 10 100 POROSITY, PERCENT @ S.R.S. Z 0 lO0 10 CUENT: FIELD: WELL: PETROLEUM TESTING SERVICE, INC. FORMATION FACTOR vs. POROSITY PERCENT 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: SHELL WESTERN E & P MIDDLE GROUND SHOAL A-41-11 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: COMPOSITE rn =-1.72 o = 1.53 \ · 10 100 POROSITY, PERCENT @ S.R.S. PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. FILE NO: DATE: WELL: FIELD: TABLE 4 RESISTIVITY INDEX DATA AT 2500 psi SIMULATED RESERVOIR STRESS SAMPLE NUMBER * BRINE DEPTH n SATURATION feet VALUE percent 1-6 6620.65 -2.06 2-6 6632.75 -1.82 3-2 6640.20 -2.40 3-6 6644.10 -1.83 80.76 48.00 39.73 77.89 62.38 46.08 79.00 52.34 44.09 76.03 45.38 34.99 o REPORTED VALUES, CORRECTED TO 25 C PAGE No. 16 6512 NOVEMBER 1985 A-41-11 MIDDLE GROUND SHOAL RESISTIVITY INDEX I 1.49 4.32 6.45 1.50 2.18 3.88 1.78 4.81 7.21 1.70 4.28 7.05 PETROLEUM TESTING SERVICE, INC. RESISTIVITY INDEX vs. PERCENT SATURATION 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E &: P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-~-I - 11 SAMPLE NO.: 1-6 DEPTH, FT.: 6620.65 n*: -2.06 X I.,J Z 100 10 10 100 PERCENT SATURATION @ S.R.S. PETROLEUM TESTING SERVICE, INC. RESISTIVITY INDEX vs. PERCENT SATURATION 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WELL: A-41-11 SAMPLE NO.: 2-6 DEPTH, FT.: 6632.75 n*-- -1.82 X 100 10 10 100 PERCENT SATURATION @ S.R.S. PETROLEUM TESTING SERVICE, INC. RESISTIVITY INDEX vs. PERCENT SATURATION 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FILE NO.: 6512 FIELD: MIDDLE GROUND SHOAL DATE: NOVEMBER 1985 WEI_I~ A-¢1-11 SAMPLE NO.: 3-2 DEPTH, Fl'.: 664.0.20 n*= -2.4.0 100 10 X ii 10 100 PERCENT SATURATION @ S.R.S. PETROLEUM TESTING SERVICE, INC. · RESISTIVITY INDEX ¥$. PERCENT SATURATION 2500 psi SIMULATED RESERVOIR STRESS PAGE NO.: FIGURE NO.: CUENT: FIELD: WELL: DEPTH, FT.: SHELL WESTERN E &: P MIDDLE GROUND SHOAL A-4.1-11 6644.10 FILE NO.: 6512 DATE: NOVEMBER 1985 SAMPLE NO.: 5-6 n*= -1.83 X L~J Z 100 10 , 100 PERCENT SATURATION @ S.R.S. PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. PAGE NO. 21 FILE NO: 6512 DATE: NOVEMBER 1985 WELL: FIELD: A-41-11 MIDDLE GROUND SHOAL FORMATION FACTOR AND RESISTIVITY INDEX EQUATION SHEET-CLAY CORRECTED EQUATIONS * Frw = (Ro/Rw)(i+Rw B Qv) * * -m Frw = O * * -m Frw = a 0 1.23 B = 4.0913/(1+0.855 (Rw )) * I = Sw -- (Rt/Ro)( i+Rw B Qv/Sw i+Rw B Qv Qv -- CEC/Vp WAXMAN-SMITS ARCHIE WYLLIE JUHASZ ) WAXMAN-SMITS WAXMAN-SMITS PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. PAGE NO. 22 FILE NO: 6512 DATE: NOVEMBER 1985 WELL: FIELD: A-41-11 MIDDLE GROUND SHOAL FORMATION FACTOR AND RESISTIVITY INDEX EQUATION SHEET-CLAY CORRECTED VARIABLE DEFINITIONS Frw Rt Ro Rw FORMATION FACTOR, CLAY CORRECTED, WITH BRINE RESISTIVITY Rw o RESISTIVITY OF PARTIALLY ohm-m @ 25 c SATURATED CORE o RESISTIVITY OF SATURATED CORE ohm-m @ 25 c o RESISTIVITY OF FORMATION BRINE ohm-m @ 25 c CONSTANT, D~.PENDEN~ UPON POROSITY POROSITY,.FRACTIONAL ., CEMENTATION FACTOR, CLAY CORRECTED -1 -1 -1 O EQUIVALENT CONDUCTANCE ml meq ohm m @ 25 c OF CLAY Qv EFFECTIVE CATION EXCHANGE CONCENTRATION meq/ml CEC Vp Sw CATION EXCHANGE CAPACITY meq/gm UNIT PORE VOLUME ml/gm OF ROCK BRINE SATURATION, FRACTIONAL o @ '25 c SATURATION EXPONENT, CLAY CORRECTED RESISTIVITY INDEX, CLAY CORRECTED PETROLEUM TESTING SERVICE, INC CLIENT: SHELL WESTERN E & P INC. FILE NO.: DATE: WELL: FIELD: SAMPLE NUMBER TABLE 5 MERCURY CAPILLARY PRESSURE SAMPLE PROPERTIES Page No. 23 6512 DECEMBER 1985 A-41-11 MIDDLE GROUND SHOAL 1-6 1-7 1-8 2-1 2-6 2-9 2-10 3-1 3-2 3-6 PORE BULK AIR DEPTH VOLUME VOLUME PERMEABILITY feet cc. cc. mD. 6620.65 2.46 18.79 6621.90 2.77 18.28 6622.60 3.40 18.81 6628.40 2.98 18.67 6632.75 2.66 18.64 6635.25. 2.73 18.84 6636.10 3.26 17.98 6639.10 2.24 19.03 6640.20 2.17 17.95 6644.10 2.75 18.37 45 20 55 29 5.4 4.0 67 5.4 8.2 21 PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. FILE NO.: DATE: WELL: FIELD: TABLE 6 MERCURY CAPILLARY PRESSURE SAMPLE NUMBER Page No. 24 6512 DECEMBER 1985 A-41-11 MIDDLE GROUND S~OAL ABSOLUTE WETTING PHASE DEPTH PRESSURE SATURATION feet (psia) percent 1-6 1-7 1-8 2-1 6620.65 3.45 7.0 20 40 157 1300 00.0 94.1 79.4 64.2 42.4 15.8 6621.90 4.90 100. 10 97. 20 87. 40 71. 157 45. 13.00 17. 6622.60 4.90 10 20 40 157 1300 6628.40 4.90 10 20 40 157 1300 100. 92. 83. 67. 48. 23. 100. 96. 83. 66. 40. 14. PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. FILE NO.: DATE: WELL: FIELD: TABLE 6 MERCURY CAPILLARY PRESSURE SAMPLE NUMBER Page No. 25 6512 DECEMBER 1985 A-4!-ll MIDDLE GROUND SHOAL ABSOLUTE WETTING PHASE DEPTH PRESSURE SATURATION feet (psia) percent 2-6 2-9 2-10 3-1 6632.75 6635.25 6636.10 6639.10 14 30 57 110 315 1300 14 30 57 110 315 1300 3 10 20 40 157 1300 ,14 30 57 110 315 1300 .45 100.0 97.7 79.9 60.7 39.2 19.1 100 97 88 65 42 21 100 91 74 58 33 9 100 95 84 74 57 38 .0 .6 .5 .6 .5 .2 .0 .4 .6 .2 .4 .6 .0 .8 .7 .2 .8 .4 PETROLEUM TESTING SERVICE, INC. CLIENT: SHELL WESTERN E & P INC. FILE No.: DATE: WELL: FIELD: TABLE 6 MERCURY CAPILLARY PRESSURE SAMPLE NUMBER Page No. 26 6512 DECEMBER 1985 A-41-11 MIDDLE GROUND SHOAL ABSOLUTE WETTING PHASE DEPTH' PRESSURE .SATURATION feet (psia) percent 3-2 3-6 6640.20 6644.10 10 20 40 110 315 1300 7 20 30 57 157 1300 .0 100.0 95.7 85.9 72.4 58.4 38.3 100 93 78 60 41 14 .0 .3 .6 .5 .2 .2 , m.m 10000 1000 100 10 1.0 0.1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E &: P FIELD: MIDDLE GROUND SHOAL WELL: A-4-1 - 11 DEPTH, FEET: 6620.65 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.' 1-6 I'1 ABSOLUTE PRESSURE vs. WETTING PHASE SATURATION 3 0 10 20 ~0 40 50 60 70 80 90 100 WElTING PHASE SATURATION, (percent) 10000 IOO0 100 10 1.0 0.1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELl.: A-41 - 11 DEPTH, FEET: 6621.90 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 1-7 I'1 ABSOLUTE PRESSURE vs. WETTING PHASE SATURATION. 0 10 20 50 40 50 60 70 80 90 100 WETTING PHASE SATURATION, (percent) L~ 10000 1000 lO0 10 0.1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELl.: A-41 - 11 DEPTH, FEET: 6622.60 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 1-8 ABSOLUTE PRESSURE vs, WETtiNG PHASE SATURATION 0 10 20 30 40 50 60 70 80 90 100 WETTING PHASE SATURATION, (percent) I' , 1.1.1 10000 1000 100 10 1,0 0,1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELL: A-41 - 11 DEPTH, FEET: 6628.40 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 2-1 E! ABSOLUTE PRESSURE va, WELTING PHASE SATURATION 0 10 20 30 40' 50' 60 70 80 90 100 WETTING PHASE SATURATION, (percent) L~J 10000 1000 1 O0 10 1.0 0.1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WEI.i~ A-41 - 11 DEPTH, FEET: 6652.75 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 2-6 r'l ABSOLUTE PRESSURE vs. WETTING PHASE SATURATION i i i , i i __ , i 0 10 ' 20 30 ¢0 50. 60 70 80 90 100 WETFING PHASE SATURATION, (percent) PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELL: A-41 - 11 DEPTH, FEE'r: 6635.25 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 2-9 I'1 ABSOLUTE PRESSURE vs. WETRNG PHASE SATURATION 10000 1000 lO0 10 1.0 0.1 ,i 0 10 20 30 40 50 60, 70 80 90 100 WETTING PHASE SATURATION, (percent) PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CLIENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELL: A-41-11 DEPTH, FEET: 66,36.10 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 2-10 I. . i,i 10000 1000 lO0 10 1.0 0.1 I'1 ABSOLUTE PRESSURE vs. WETrlNG PHASE SATURATION E] 0 10 20 30 40 50 60 70 80 90 100 WELTING PHASE SATURATION, (percent) I, 1.1.1 10000 1000 lO0 10 1.0 0.1 0 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELL: A-41 - 11 DEPTH, FEET: 6639.10 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 3-1 13 ABSOLUTE PRESSURE vs. WETrlNG PHASE SATURATION 10 20 30 40 50 60 70 80 90 100 WETTING PHASE SATURATION, (percent) 10000 1000 100 10 1,0 0.1 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELI~ A-41 - 11 DEPTH, FEET: 6640.20 FILE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 3-2 r-I ABSOLUTE PRESSURE vs. WETTING PHASE SATURATION 0 10 20 ,30 40 50 60 70 80 90. 100 WETTING PHASE SATURATION, (percent) 10000 1000 lO0 10 1.0 0.1 0 PETROLEUM TESTING SERVICE, INC. MERCURY CAPILLARY PRESSURE PAGE NO.: FIGURE NO.: CUENT: SHELL WESTERN E & P FIELD: MIDDLE GROUND SHOAL WELL: A-41 - 11 DEPTH, FEET: 6644.10 FiLE NO.: 6512 DATE: DECEMBER 1985 SAMPLE NO.: 5-6 I-1 ABSOLUTE PRESSURE vs. WETTING PHASE SATURATION 10 20 50 40 50 60 70 80 90 100 WETTING PHASE SATURATION, (percent) April 3, 1986 Shell Western E&P Inc. A Subsidiary ol Shell Oii Company P.O. Box 576 Houston, TX 77001 Arco Alaska, Inc. ATTN Mr. John Havard P. O. Box 100360 Anchorage, Alaska 99510 Chevron USA, Inc. ATTN Mr. J. L. Weaver' P. O. Box 107839 Anchorage, Alaska 99510 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Mr. John Boyle 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: PETROPHYSICAL ANALYSIS OF CORE FROM MIDDLE GROUND SHOAL WELL A41-11 The Petrophysical Services Laboratory of Shell Development Company has analyzed the core taken from Middle"'Ground Shoal Well A41-11. Core analysis data are attached. Very truly yours, L. A. MacPherson Division Petrophysical Engineer Alaska Division CCW:eb Attachments RECEIVED APR 0 8 1986 Alaska 0il & Gas Cons. CommisSion· Anchorage CRCT86093041 ~HELL DEVELO~NT ~)MPANY PI/TROPHYSICAL SERVICES LABORATORY CATION EXCHANGE CAPACITY FEBRUARY 27, 1986 SHELL MESTERN E&P INC. hELL A-41-11 I~IDDLE GROUND SHOAL FIELD ALASKA AP1 1{ 50-733-20378-0000 SAHPLE NO DEPTH (FEET) 5 6,619' 2" 15 6,632' 8" 21 6,640' 2" 25 6,644' 1" C.E.C. (meq/100S) 1.701 3.252 1.144 1.456 1986 SHELL DEVRLOPNEIqT COMPANY PETROPHYSICAL SERVICES SECTION STRESS ]qdqALYSlS DATA DATE ~ Hatch 14, 1986 COKPANYt Shell Western E&P Inc. WELL NO~ A-41-11 APl NO ; 50-733-20378-0000 FIELD ~ Kiddie Ground Shoals STATE ~ Alaska Drainage 'Cycle Stress StroBe Sample Lab Depth Stress Grain F u Sw ! n Brine perm Oil perm Oil Flow Porosity Density O Sw lO0t O Sw Pressure Ho. Ho. ft-in (%) (gu/cc) (t) (md) (md) (poi) 5 A-4611 6619-02 15.6 2.640 22.06 1.66 42.2 5.26 1.92 3.45 6.00 296 15 A-4612 6632-08 12.9 2.658 35.60 1.74 46.7 3.76 1.74 0.45 0.64 584 21 A-4613 6640-02 8.5 2.643 52.31 1.61 60.9 3.31 2.41 0.40 0.57 610 25 A-4614 6644-01 14.0 2.6S4 27.67 1.69 43.8 4.75 1.89 2.00 2.60 600 All stress measurements vero at an apparent stress of 2500 psi. Brine salinity contained 36,000 ppm NsC1 + 4,000 ppm CaCl2 ( Rw - 0.175 0 23.0 degrees C.) Grain density determined by Archimades prinaiple. SHELL DEVELOPMENT COMPANY (' P£TROPHYSICAL SrRVIC[S SECTI~i STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 2500 PSI · 0 ¢ 1000 · [ . __ · !)! · ,; 100 - . · ' · 0 . , 1 . ' ~FRO 8 lSSG · ~! ,s ;a;, Oi & 6as Co~s. 6ommissi( 1 100 10 1 0.1 MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : MARCH 5,1986 COMPANY= SHELL WESTERN EXPLORATION Jr PRODUCTION INC~ WELL NO: A-41-11 APl NO: FIELD = MIDDLE GROUND SHOAL STATE = KENAI COUNTY, ALASKA SAMPLE NO. : 3 LAB NO. : A-4615 DEPTH (F"r) : 660'.e GRAIN DENSITY : 2.645 GM/'CC ATM. POROSITY : 15.0 ~; STRESS POROSITY : 14.0 Y, ATM. AIR PERMEABIUTY = 14.1 MD LIJ SHELL DEVELOI:'MEHT COMPANY (" e'ETROPHYSICAL SERVICES SECTIOI(' STRESS MERCURY CAPILLARY PRESSURE DATA I0000 1000 STRESS PRESSURE: 2500 PSI 100 10 1 100 90 80 70 60 50 40 50 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : MARCH 5,1986 COMPANY: SHELL WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-735-20&TB-O000 FIELD : MIDDLE GROUND SHOAL STATE : KENAI COUNTY. ALASKA SAMPLE NO. : 3 LAB NO. : A-4&15 DEPTH (Fl') : 6517.$ GRAIN DENSITY : 2.s4a eM/cc ATM. POROSITY : 15.0 · STRESS POROSITY ; 14.0 · ATM. AIR PERMEABILITY: 14.1 MD SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECT( STRESS MERCURY CAPILLARY PRESSURE DATA 10000 STRESS PRESSURE: 2500 PSI 100 10 1 0.1 MERCURY SATUP, ATION - % BULK VOLUME OCCUPIED DATE : MARCH 7,1988' COMPANY: 5HELL WESTERN EXPLORATION Jr PRODUCTION INC. WELL NO: A-41-11 APl NO: so-733-2o378-oooo FIELD : MIDDLE GROUND SHOAL STATE I KENAI COUNTY, ALASKA SAMPLE NO. : B LAB NO. : A-4616 DEPTH (irT) : 8823.8 GRAIN DENSITY : 2.648 GM/CC ATM. POROSITY t 15.3 X; STRESS POROSITY : 14.1 ~g ATM. AIR PERMEABIUTY: 11.0 MD SHELL DEVE].OPMKNT COMPANY ~ PETROPHYSICAL Sr'RVICES SKCTIq~I STRESS MERCURY CAPILLARY PRESSURE DATA 1000' STRESS PRESSURE: 2500 PSI t00' 10' I 100 90 80 70 60 50 40 30 20 10 MERCURY SATURATION - % PORE VOLUME OCCUPIED 0 DATE : MARCH 7',1086 COMPANY: SHELl. WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-733-20&78-0000 FIELD : MIDDLE GROUND SHOAL STATE : KKNAI COUNTY, ALASKA SAMPLE NO. : 8 LAB NO. : A-4618 DEPTH (F"O : 6623.8 GRAIN DKHSITY : 2.648 GM/CC ATM. POROSITY : 15.3 )[ STRESS POROSITY : 14.1 J[ ATM. AIR PERMEABILITY: I1.0 MD SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES Li.I STRESS MERCURY CAPILLARY PRESSURE DATA 10000 STRESS PRESSURE: 2500 PSI 1000' 100 10 10 1 0.1 MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : MARCH 11,1986 COMPANY: SHELL WESTERN r. XPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-733-20378-0000 FIELD : MIDDLE GROUND SHOAL , STATE : KENAI COUNTY, ALASKA SAMPLE NO. ; 14 LAB NO. : A-4617 n£m fiT) : 6831.85 GRAIN DrNSITY : 2.646 GM/CC ATM. POROSITY : 17.4 X STRESS POROSITY : 15.9 ~ ATM. AIR P[RMEABILITY: 37.4 UD SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES SECTI(~" STRESS MERCURY CAPILLARY PRESSURE DATA Li.I STRESS PRESSURE: 2500 PS1 1000 100 10 1 100 90 80 70 60 50 40 50 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : MARCH.11,19B6 COMPANY: SHELL WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-755-20&78-0000 FIELD : MIDDLE GROUND SHOAL STATE : KENAI COUNTY, ALASKA SAMPLE NO. : 14 LAB NO. : A-4517 DEPTH (F'~ : $651.85 GRAIN DENSITY : 2.646 GM/CC ATM. POROSITY : 17.4 ~ STRESS'POROSITY : 15.9 ~ ATM. AIR PERMEABILITY: 37.4 MD IO00E SHELL DEVELOPMENT COIdPAHY ("' PETRO~I~L SERVICES SECT)(' ' STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 2500 PSi 1000 o ,., MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : MARGH 17,1988 COMPANY: SHELL WESTERN EXPLORATION ,ir PRODUCTION INC. WELL NO: A-'.41-11 APl NO: 50-7&$-20&78-O000 FIELD : MIDDLE GROUND SHOAL STATE : KENAI COUNTY, ALASKA SAMPLE NO. : 18 LAB NO. : A-4818 DEPTH (Iq') : 880"7.05 GRAIH DENSITY : 2.856 GH,/CC' ATId. POROSITY ; 17.1% STRESS POROSITY ; 16.2 % ATM. AIR PERMEABILITY: 28.4 lid SHELL DEVE].OPM£NT COMPANY PETROPHYSICAL SERVICES $ECTI(" STRESS MERCURY CAPILLARY PRESSURE: DATA STRESS PRESSURE: 2500 PSI I0000- I00 I0 1 100 90 80 70 60 50 40 30 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : MARCH 17,1986 COMPANY: SHELL V/ESTER# EXPLORATION Jr PRODUCTION INC. WELL NO: A-41-11 APl HO: 50-7;33-20378-0000 FIELD : MIDDLE GROUND SHOAL · I'ATE : KENAI OOUHTY. ALASKA SAMPLE NO. : 18 LAB NO. : A..-461B DEPTH (IRT) : GRAIN DENSITY : 2.6s6 OM/CC ATM. POROSITY ; '17,1 STRESS POROSITY ATM. AIR PERM[ABIMTY: 26.4 laD SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES $[CTI~r''' STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 2500 PSI ] I I . ] I _ -- · _ · 1000- _ , · 1, _ _ . 100 ..... f~ , o .. · . ,, . a ,L_~ _ _. ....... 100 10 1 0.1 MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : MARCH 18.1986 COMPANY= SHELL WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-7&$-203'/'8-0000 FIELD : MIDDLE GROUND SHOAL STATE = KENAI COUNTY, ALASKA SAMPLE NO. : 23 LAB NO. :. A-.4619 DEPTH (F'r) = ~842.10 GRAIN DENSITY : 2.64.4 GM/CC ATM. POROSITY = 14.7 :g STRESS POROSITY : 14.4 ~ ATM. AIR PERMEABILITY: 115 MD STR£s= ,,-._ '~,qL s~~s~ff.~' · .' M~C(j)~¥ CAF'IL' ~T'RESs PRESSURE: 2~qO0 PSI I000. loo go · eo 70 MERCURy SATURso :,~'~ ~ ~. ; ~E '~: ?' , ' , ~ UND ' ~MPLE NO.· ATM. __ ~ po=~_.~ ~ ~ ~ ~ M/CC ': SHELL DEVELOPMENT COMPANY ~'- PETROPHYSI~L SERVICES $[CTIC~" STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 2500 PSI C C ( I~J o :Z) 100 ..... ,, MERCURY SATURATION - % BULK VOLUME OCCUPIED DATE : MARCH 20.19B6 COMPANY: SHELL WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-733-20378-0000 FIELD : MIDDLE GROUND SHOAL STATE : KENAI COUNTY, ALASKA SAMPLE: NO. : 24 LAB NO. : A-4~20 DEPTH (F'I') : 6843.05 GRAIN DENSITY : 2.643 GId/CC ATM. POROSITY : 14.0 X STRESS POROSITY : 15.1 X ATM. AIR PERMEABILITY: SB.7 MD laJ SHELL DEVELOPMENT COMPANY (" PETROPHYSICAL SERVICES SECTIOn" STRESS MERCURY CAPILLARY PRESSURE DATA STRESS PRESSURE: 2500 PSI 1o0 IO 1 100 90 80 70 60 50 40 30 20 10 0 MERCURY SATURATION - % PORE VOLUME OCCUPIED DATE : MARCH 20,1986 COMPANY: SHELL WESTERN EXPLORATION & PRODUCTION INC. WELL NO: A-41-11 APl NO: 50-733-2037B-0000 FIELD : MIDDLE GROUND SHOAL STATE : RENAl COUNTY, ALASKA SAMPLE NO. : ~ LAB NO. : A-4B20 DEPTH (FT) : 6643.05 ORAIN DENSITY : 2,643 OM/CC ATM. POROSITY t 14,0 X; STRESS POROSITY ~ 13,1 X .ATM, AIR PERMEABILITY: 58.7 MD S~ELL D~.VELOP~ PETROPHYSICAt, SERVICVS SECT1_., STRESS ANALYSIS DATA DATE :Hatch 5,1986 COHPANY:Shell Western E~P Inc. FIELD :Hiddle Ground Shoal WELL NO:A-41-11 APl NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL NO.:3 LAB NO.:A-4615 DEPTH :6617.6 ft STRESS :2500 psi POPE VOL. :2.87 cc ~l~IN VOL. :17.616 cc BUIXVOL. :20.486 cc POROSITY :14.0 % GRAIN DEN. :2.648 gm/cc WT. OF SPL :46.656 gm ATH POROSITY:IS.0 % ATM. AIR - PERItEABILITY:14.1 md PSIA PUHP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 14 .1400 .1400 0.0000 0.0000 16 .1430 .1430 0.0000 0.0000 20 .1855 .1450 .0405 .0405 1.41 .20 25 .2820 .1480 .1340 .1340 4.67 .65 30 .4160 .1500 .2660 .2660 9.27 1.30 40 .6255 .1530 .4725 .4725 16.5 2.31 50 .8210 .1580 .6630 .6630 23.1 3.24 75 1.1050 .1880 .9170 .9170 32.0 4.48 100 1.2475 .1930 1.0545 1.0545 36.7 5.15 130 1.3660 .2010 1.1650 1.1650 40.6 5.69 160 1.4775 .2150 1.2625 1.2625 44.0 6.16 200 1.5710 .2200 1.3510 1.3510 47.1 6.59 250 1.6595 .2250 1.4345 1.4345 50.0 7.00 300 1.7525 .2300 1.5225 1.5225 53.0 7.43 400 1.8785 .2450 1.6335 1.6335 56.9 7.97 600 2.0810 .2615 1.8195 1.8195 63.4 8.88 800 2.2085 .2790 1.9295 1.9295 67.2 9.42 1000 2.3130 .3020 2.0110 2.0110 70.1 9.82 1250 2.4060 .3220 2.0840 2.0840 72.6 10.2 1500 2.4945 .3420 2.1525 2.1525 75.0 10.5 1750 2.5690 .3630 2.2060 2.2060 76.9 10.8 2000 2.6280 .3840 2.2440 2.2440 78.2 11.0 Add 1 psi to psia readings for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury filling open spaces around the sample,(between sample and frit,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume might remain constant, or increase with a smaller change in volume. SHELL DEVELOPMENT COMPANY PETROPHYSICAL SERVICES STRESS ANALYSIS DATA DATE :March 7,1986 COMPANY:Shell gestern E&P Inc. FIELD :Middle Ground Shoal ~ELLNO:A-41-11 AP1 NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL NO.:8 LAB NO.:A-4616 DEPTH :6623.6 Et STRESS :2500 psi PORE VOL. :2.85 cc ORAIN VOL. :17.292 cc BULK VOL. :20.142 cc POROSITY :14.1% GRAIN DEN. :2.648 ~m/cc I4T. OF SPL :45.783 ATM POROSITY:15.3 % ATM. AIR - PERMEABILITY:Il.0 md PSIA PUMP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 14 .1400 .1400 0.0000 0.0000 16 .1430 .1430 0.0000 0.0000 20 .1450 .1450 0.0000 0.0000 25 .3320 .1480 .1840 .1840 6.46 .91 30 .5375 .1500 .3875 .3875 13.6 1.92 40 .7870 .1530 .6340 .6340 22.2 3.15 50 .9735 .1580 .8155 .8155 28.6 4.05 75 1.2390 ..1880 1.0510 1.0510 36.9 5.22 100 1.3860 .1930 1.1930 1.1930 41.9 5.92 130 1.5015 .2010 1.3005 1.3005 45.6 6.46 160 1.6065 .2150 1.3915 1.3915 48.8 6.91 200 1.6985 .2200 1.4785 1.4785 51.9 7.34 250 1.7765 .2250 1.5515 1.5515 54.4 7.70 300 1.8585 .2300 1.6285 1.6285 57.1 8.09 400 1.9860 .2450 1.7410 1.7410 61.1 8.64 600 2.1690 .2615 1.9075 1.9075 66.9 9.47 800 2.2935 .2790 2.0145 2.0145 70.7 10.0 1000 2.3975 .3020 2.0955 2.0955 73.5 10.4. 1250 2.4960 .3220 2.1740 2.1740 76.3 10.8 1500 2.5745 .3420 2.2325 2.2325 78.3 11.1 1750 2.6335 .3630 2.2705 2.2705 79.7 11.3 2000 2.6950 .3840 2.3110 2.3110 81.1 11.5 Add 1 psi to psia readings for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury filling open spaces around the sample,(between sample and frit,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume might remain constant, or increase with a smaller change in volume. SHELL DEVELOPMENT COMPANyi~, PETROPHYSICAL SERVICES SECTI. , STRESS ANALYSIS DATA DATE :March 11,1986 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal WELL N0:A-41-11 AP1 NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL N0.:14 LAB N0.:A-4617 DEPTH :6631.85 Et STRESS :2500 psi PORE VOL. :3.19 cc ORAIN VOL. :16.843 cc BUIXVOL. :20.033 cc POROSITY :15.9 % GRAIN DF, lq. :2.646 8m/cc WT, OF SPL :44.572 gm ATM POROSITY:lT.4 % ATH. AIR - PERMEABILITY:37.4 md PSIA PUMP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 10 .1370 .1370 0.0000 0.0000 12 .3530 .1390 .2140 .2140 6.71 1.07 14 .5225 .1400 .3825 .3825 12.0 1.91 16 .6355 .1430 .4925 .4925 15.4 2.46 20 .8840 .1450 .7390 .7390 23.2 3.69 25 1.0660 .1480 .9180 .9180 28.8 4.58 30 1.2410 .1500 1.0910 1.0910 34.2 5.45 40 1.3920 .1530 1.2390 1.2390 38.8 6.18 50 1.5215 .1580 1.3635 1.3635 42.7 6.81 75 1.7460 .1880 1.5580 1.5580 48.8 7.78 100 1.8895 ,1930 1.6965 1.6965 53.2 8.47 130 2.0185 .2010 1.8175 1.8175 57.0 9.07 160 2.1210 .2150 1.9060 1.9060 59.7 9.51 200 2.2350 .2200 2.0150 2.0150 63.2 10.1 250 2.3165 .2250 2,.0915 2.0915 65.5 10.4 300 2.3970 .2300 2.1670 2.1670 67.9 10.8 400 2.5365 .2450 2.2915 2.2915 71.8 11.4 600 2.7090 .2615 2.4475 2.4475 76.7 12.2 800 2.8330 .2790 2.5540 2.5540 80.1 12.7 1000 2.9085 .3020 2.6065 2.6065 81.7 13.0 1250 2.9995 .3220 2.6775 2.6775 83.9 13.4 1500 3.0745 .3420 2.7325 2.7325 85.7 13.6 1750 3.1230 .3630 2.7600 2.7600 86.5 13.8 2000 3.1810 .3840 2.7970 . 2.7970 87.7 14.0 Add 1 psi to psia readings for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury filling open spaces around the sample,(between sample and frit,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume might remain constant, or increase with a smaller change in volume. .. ,, SHELL DEVELOPHI2~ COMPANY/"' PETROPHYSICAL SERVICES SECTI~ . STRESS ANALYSIS DATA DATE :Hatch 17,1986 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal ~EI..LNO:A-41-11 AP1 NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL NO.:18 IABNO.:A-4618 DEPTH :6637.05 ft STRESS :2500 psi PORE VOL. :3.27 cc GRAIN VOL. :16.902 cc BULK VOL. :20.172 cc POROSITY :16.2 % GRAIN DEN. :2.656 ~m/cc I~T. OF SPL :44.885 ~m ATMPOROSITY:17.1% ATH. AIR - PERMEABILITY:26.4 md PSIA ~ BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. 14 .1400 .1400 0.0000 0.0000 17 .2685 .1435 .1250 .1250 3.82 .62 20 .4070 .1450 .2620 .2620 8.01 1.30 25 .6960 .1480 .5480 .5480 16.8 2.72 30 .8840 .1500 .7340 .7340 22.5 3.64 40 1.0775 .1530 .9245 .9245 28.3 4.58 50 1.2360 .1580 1.0780 1.0780 33.0 5.36 75 1.4930 .1880 1.3050 1.3050 39.9 6.47 100 1.6710 .1930 1.4780 1.4780 45.2 7.33 130 1.8235 .2010 1.6225 1.6225 49.6 8.04 160 1.9225 .2150 1.7075 1.7075 52.2 8.47 200 2.0390 .2200 1.8190 1.8190 55.6 9.02 250 2.1425 .2250 1.9175 1.9175 58.6 9.51 300 2.2335 .2300 2.0035 2.0035 61.3 9.93 400 2.3660 .2450 2.1210 2.1210 64.9 10.5 600 2.5450 .2615 2.2835 2.2835 69.8 11.3 800 2.6780 .2790 2.3990 2.3990 73.4 11.9 1000 2.7685 .3020 2.4665 2.4665 75.4 12.2 1250 2.8650 .3220 2.5430 2.5430 77.8 12.6 1500 2.9375 .3420 2.5955 2.5955 79.4 12.9 1750 2.9985 .3630 2.6355 2.6355 80.6 13.1 2000 3.0660 .3840 2.6820 2.6820 82.0 13.3 Add I psi to psta readin§s for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury fillin§ open spaces around the sample,(between sample and frit,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume might remain constant, or increase with a smaller change in volume. SHELL DEVELOPHENT COHPANYi' PETROPHYSICAL SERVICES SECTI%. STRESS ANALYSIS DATA DATE :Harch 18,1986 COHPANY:Shell Western E&P Inc. FIELD :Hiddle Ground Shoal ~ELLNO:A*41-11 AP1 NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL NO.:23 LAB NO.:A-4619 DEPTH :6642.10 ft STRESS :2500 psi PORE VOL. :2.86 cc GRAIN VOL. :17.019 cc BULK VOL. :19.879 cc POROSITY :14.4 % GRAIN DEN. :2.644 &,m/cc %~T. OF SPL :44.999 gm ATM POROSITY:14.7 % ATM. AIR - PERMEABILITY:Il5 md PSIA PUMP BLANK MERCURY CORR. READING INTRUSION VOL. VOL. % PV OCCUPIED OCCUPIED 1 .0915 .0910 .0005 0.0000 2 .1275 .1070 .0205 .0200 .70 3 .1500 .1130 .0370 .0365 1.28 4 .1750 .1210 .0540 .0535 1.87 5 .2165 .1260 .0905 .0900 3.15 6 .2340 .1270 .1070 .1065 3.72 7 .2715 .1310 .1405 .1400 4.90 8 .3680 .1360 .2320 .2315 8.09 10 .5170 .1370 .3800 .3795 13.3 12 .6335 .1390 .4945 .4940 17.3 14 .7135 .1400 .5735 .5730 20.0 17 .7850 .1435 .6420 .6415 22.4 20 .9070 .1450 .7620 .7615 26.6 25 1.0400 .1480 .8920 .8915 31.2 30 1.1295 .1500 .9795 .9790 34.2 40 1.2410 .1530 1.0880 1.0875 38.0 50 1.3640 .1580 1.2060 1.2055 42.2 75 1.5415 .1880 1.3535 1.3530 47.3 100 1.6710 .1930 1.4780 1.4775 51.7 130 1.7655 .2010 1.5645 1.5640 54.7 160 1.8500 .2150 1.6350 1.6345 57.2 200 1.9540 .2200 1.7360 1.7335 60.6 250 2.0095 .2250 1.7845 1.7840 62.4 300 2.0810 .2300 1.8510 1.8505 64.7 400 2.1800 .2450 1.9350 1.9345 67.6 600. 2.3080 .2615 2.0465 2.0460 71.5 800. 2.4000 .2790 2.1210 2.1205 74.1 1000 2.4715 .3020 2.1695 2.1690 75.8 1250 2.5360 .3220 2.2140 2.2135 77.4 1500 2.5930 .3420 2.2510 2.2505 78.7 1750 2.6385 .3630 2.2755 2.2750 79.5 2000 2.6785 .3840 2.2945 2.2940 80.2 .10 .18 .27 .45 · 54 .70 1.16 1.91 2.49 2.88 3.23 3.83 4.48 4.92 5.47 6.06 6.81 7.43 7.87 8.22 8.72 8.97 9.31 9.73 10.3 10.7 10.9 11.3 ', ~"" " 11.5 Add 1 psi to psia readin&s for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury fillin§ open spaces around the sample,(between sample and frtt,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume .miEht remain constant, or increase with a smaller chanEe in volume SHELL DEVELOPMENT COMPANY PETItOPHYSICAL SERVICES $ECT~. STRESS ANALYSIS DATA DATE :March 20,1986 COMPANY:Shell Western E&P Inc. FIELD :Middle Ground Shoal WELL N0:A-41-11 AP1 NO :50-733-20378-0000 STATE :Kenai County, Alaska SPL N0.:24 LAB NO.:A-4620 DEPTH :6643.05 ft STRESS :2500 psi PORE VOL. :2.31 cc GRAIN VOL. :15.266 cc BULK VOL. :17.576 cc POROSITY :13.1% GRAIN DEN. :2.643 gm/cc WT. OF SPL :40.349 gm ATM POROSITY:14.0 % ATM. AIR - PERMEABILITY:58.7 md PSIA PUMP BLANK MERCURY CORR. % PV % BV READING INTRUSION VOL. OCCUPIED OCCUPIED VOL. '8 .1360 .1360 0.0000 0.0000 10 .1915 .1370 .0545 .0545 2.36 .31 12 .2340 .1390 .0950 .0950 4.11 .54 14 .2840 .1400 .1440 .1440 6.23 .82 17 .3975 .1435 .2545 .2545 11.0 1.45 20 .5630 .1450 .4180 .4180 18.1 2.38 25 .7015 .1480 .5535 .5535 24.0 3.15 30 .8030 .1500 .6530 .6530 28.3 3.72 40 .9245 .1530 .7715 .7715 33.4 4.39 50 1.0360 .1580 .8780 .8780 38.0 5.00 75 1.2275 .1880 1.0395 1.0395 45.0 5.91 130 1.4455 .2010 1.2445 1.2445 53.9 7.08 160 1.5235 .2150 1.3085 1.3085 56.6 7.44 200 1.6045 .2200 1.3845 1.3845 5'9.9 7.88 250 1.6650 .2250 1.4400 1.4400 62.3 8.19 300 1.7230 .2300 1.4930 1.4930 64.6 8.49 400 1.8055 .2450 1.5605 1.5605 67.6 8.88 600 1.9195 .2615 1.6580 1.6580 71.8 9.43 800 1.9985 .2790 1.7195 1.7195 74.4 9.78 1000 2.0590 .3020 1.7570 1..7570 76.1 10.0 1250 2.1195 .3220 1.7975 1.7975 77.8 10.2 1500 2.1660 .3420 1.8240 1.8240 79.0 10.4 1750 2.2090 .3630 1.8460 1.8460 79.9 10.5 2000 2.2465 .3840 1.8625 1.8625 80.6 10.6 Add 1 psi to psia readings for head pressure. With the initial injection pressures the volume of intrusion mercury will vary. This is due to mercury filling open spaces around the sample,(between sample and frit,and or sample and viton rubber), which can't be taken into account with the blank. As the injection pressure increases, the blank volume will increase while the sample volume might remain constant, or increase with a smaller chanEe in GEOLOGICAL ANALYSIS AND EVALUATION OF GB SANDS SHELL WESTERN EXPLORATION AND PRODUCTION, INC. A43-11 WELL (6965-6986 FEET) A33-11 WELL (709.1-7150 FEET) .... ~ A41-11 WELL (7366-7494 FEET)''''~'., MIDDLE GROUND SHOAL FIELD, ALASKA Prepared for Shell Western Exploration & Production, Inc. Houston, Texas 1151 - C BRITTMORE ROAD · HOUSTON, TEXAS 77043 · CONFIDENTIAL June, 1986 (713) 932-7183 COMPANY PROPRIETA R Y GEOLOGICAL ANALYSIS AND EVALUATION OF GB SANDS SHELL WESTERN EXPLORATION AND PRODUCTION, INC. A43-11 WELL (6965-6986 FEET) A33-11 WELL (7021-7150 FEET) A41-11 WELL (7366--7494 FEET) MIDDLE GROUND SHOAL FIELD; ALASKA INTRODUCTION This report presents the results of a study conducted by Reservoirs, Inc. at the request of Shell Western Exploration and Production, Inc.., Houston, Texas. This study involves the description and characterization of three conventional core samples and seven percussion sidewall core samples'of the GB Sands from three wells in the Middle Ground Shoal Field, Alaska. Four other sidewall samples were submitted, but as insufficient rock material with original fabric was present, no analyses were performed on these samples. Table i lists sample depths and the analyses performed on each sample. The purpose of this study was to determine the geological characteristics of the samples, including the texture, mineralogy, pore space types, pore geometries, and the nature of the pore-filling constituents. Emphasis was to be placed on possible explanations for the minor difference in wireline log resistivity between productive and nonproductive sandstones. In addition, the reservoir quality of these samples was 'to be ascertained, with suggestions made concerning the completion/stimulation procedures to be used in these rocks. To obtain this information, the ten rock samples were analyzed as instructed by Shell Western Exploration and Production, Inc. Routine core analysis data was provided by Shell Western Exploration and Production, Inc. for samples of the GB2 from Shell Western Exploration and Production, Inc. A-43-11 Well. Permeability, porosity and grain density are recorded in Table 2. Prior to. subsampling for geological analysis, the rock samples were extracted using a Soxhlet apparatus in order to remove hydrocarbons and/or other volatile material which interfere with scanning electron microscopy and X-ray diffraction analysis, as well as thin section preparation. X-ray diffraction analysis (XRD) was performed on five of the samples (see Table 1) in order to provide semiquantitative data on the rock composition. X-ray diffraction data for these samples are recorded in Table 3. Each sample was ground to approximately 40 microns in a constant particle size grinder and subjected to a bulk XRD analysis of the total mineral composition. A less than 5 micron fraction was separated from the total sample by using standard XRD particle size separation techniques and subsequently analyzed to identify and quantify clay mineral components. Thin section petrographic analysis was conducted on ten samples (Table 1). Thin sections were prepared by impregna- ting the hydrocarbon extracted samples with blue-dyed epoxy at approximately 1000 psi, followed by grinding to 35 microns. The samples were stained with Alizarin Red-S to aid in distinguishing calcite from other carbonate minerals. A petrographic examination was then conducted to determine the mineral composition of the granular and pore-filling constitu- ents, to characterize the nature of the pore space, and to estimate the grain size and degree of sorting. A modal analysis consisting of a point count of 250 points was conducted on five of the thin sections which were composed of rock material with a natural fabric. These data are presented in Table 4..Two photomicrographs were taken of each sample. Generally, one photomicrograph was taken at a Iow magnifi- cation to show the general rock fabric of the sample, and a second photomicrograph was taken at high magnification to illustrate selected features. Thin section photomicrographs and corresponding descriptions are presented in Figures 1-5. Scanning electron microscopy (SEM) was performed on six of the samples supplied (Table 1). Each sample was examined in order to visually observe and document the general rock fabric, and to provide high magnification photomicrographs illustrating grains, cement types, pore space morphology and occurrence, and the mode and distribution of clay minerals present within the rock pore system. Photomicrographs were taken of three areas of each sample, represented by two separate plates. In the first plate, sueceedingly higher magnifications of 100X, 500X, and 2500X illustrate the general rock fabric as well document the presence and mode of occurrence of diagenetic minerals. In the second plate, low and high magnification photomicrographs of two other areas of the sample are used to illustrate the type and distribution of diagenetic minerals and pore spaces. Additionally, appropriate minerals were analyzed using a EDAX 9140 EDS system in order to provide elemental compositional data on specific minerals and/or particular areas of the general rock material. These data are presented in the form of an atomic percent table. This presentation represents a computer subroutine that semiquantifies the measured X-ray spectrum. Photographs of the atomic percent tables obtained from the EDS spectra are included with the SEM photomicrographs in Figures 6-11. Reservoirs Job Number RSH 1655 was assigned to this study. Any communications regarding this report should refer to this job number. Three copies of this report have been forwarded to Mr. Clay C. Williams, Engineer, Alaska Division, Shell Western Explora- tion and Production, Inc., Houston, Texas. Reservoirs, Inc. retains the original copy for possible future reference in conversations with authorized personnel on specific details of this study. Additional copies of this report may be obtained for reproduction costs by contacting Reservoirs, Inc. Original prints of all photomicrographs presented in this report are on file at Reservoirs, Inc. The SEM samples and thin sections prepared for this study will be retained by Reservoirs, Inc. in referenced storage systems. All data, interpre- tations and other matters related to this study are considered highly confidential and the sole property of Shell Western Exploration and Production, Inc., Houston, Texas. Susan E. Koellner General Projects Supervisor RESERVOIRS, INC. Jam'~s ;J. Parr Geologist RESERVOIRS, INC. Harry L./q-l~rton, P.E. Senior Si~F'f Petroleum Engineer RESERVOIRS, INC. RESULTS AND DISCUSSION The rock properties and reservoir potential of three conventional core samples and seven percussion sidewall core samples of the GB Sands from three wells (A43-11, A33-11, A41-11) in the Middle Ground Shoal Field, Alaska, are discussed in this section of the report. A complete list of wells, samples and analyses performed is given in Table 1. For the purposes of this report, the analysed samples have been subdivided and discussed by sand bodies, GB1 Sand and GB2 Sand, as specified by Shell Western. Depths for the sand intervals in the following table were taken from logs supplied by Shell Western. Well GB1 Sand Interval (Feet) Samples Submitted (Feet) A43-11 6872-6930 A33-11 6996-7060 7021 7038* 7053* A41-11 7350-7438 7366 7382 7410' Well GB2 Sand Interval (Feet) Samples Submitted (Feet) A43-11 6946-7010 6965 6971 6986 A33-11 7064-7160 7083 7118 7150' A41-11 7460-7522 7475 7494 * Denotes insufficient sample to conduct analyses. GB] Sand Three of the samples submitted from this sand body were deemed suitable for analysis (Table 1). The percussion sidewall sample from 7021 feet (A33-11 Well) is extensively fractured and infiltrated by drilling mud with virtually all the original rock fabric destroyed (Figure 2). The largest intact framework grains remaining are in' the coarse sand category (500-1000 microns), however, grain size is skewed towards the finer grain size categories due to the breakage of grains during sidewall coring with many grains having been completely ground to "rock dust". The most common discernable framework constituents present in roughly sub- equal amounts are monocrystalline quartz and metamorphic rock fragments. The metamorphic rock fragments are virtually all polycrystalline quartzite grains, with mica inclusions common. Schistose metamorphic rock fragments are rare, and consist largely of micas and clay minerals with minor quantities of silt-sized quartz. Less abundant framework grains include argillaceous rock fragments, chert, muscovite and biotite mica (Figure 7). Due to the sample destruction, the types and nature of the pore-filling constituents and the pore space cannot be ascertained. The two other percussion sidewall core samples of the GB1 Sand which were examined are from 7366 feet and 7382 feet in the A41-11 Well. They are moderately sorted with framework grains predominantly in the upper fine sand category (177-250 microns). X-ray diffraction analysis (Table 3) of the sample from 7366 feet shows quartz to be the major mineral present (59%). Most of this quartz occurs as monocrystalline framework grains (Table 4), with lesser amounts present as polycrystalline metamorphic rock fragments ("quartzites"), chert and quartz overgrowth cements. Quartz is also the dominant mineral in the sample from 7382 feet. Chert, however, is the major phase present (50%) with subordinate amounts of monocrystalline quartz, quartzite rock fragments, and silica cement (Table 4). Chert grains are sub-rounded (Figure 4), indicating they have been reworked and redeposited rather than having an authigenic origin. The sample from 7366 feet contains abundant feldspar, with XRD showing plagioclase (11%) to be more abundant than potassium feldspar (6%). Approximately 50% of the feldspar present occurs as single detrital grains (Table 4) with the remainder present as constituents of composite rock fragments. Only a trace of feldspar was observed as distinct grains in the sample from 7382 feet. Argillaceous rock fragments are common in the sample from 7366 feet (14%), constituting a large proportion of the total clay (24%) measured by XRD (Table 3). These relatively soft, ductile grains, together with mica, are frequently deformed due to compaction (Figures 2 and 7). Argillaceous rock fragments are less common (7%) in the sample from 7382 feet (Table 4). Minor framework constituents include extrusive igneous rock fragments, mica and opaques. Both of the samples of the GB1 Sand in .the A41-11 Well are well lithified, in particular the sample from 7382 feet (Figure 4). Silica in the form of quartz overgrowths is the main cement (Table 4). The source for the silica is probably the pressure induced solution of quartz framework grains following compaction. Clay minerals probably also act as minor lithifiers. As stated previously, a large portion of the clay present in the GB1 Sand samples from the A41-11 Well is detrital, mainly in the form of argillaceous rock fragments (Table 4). Authigenic clay occurs mainly as diagenetic replacement of unstable framework grains sUch as feldspar and rock fragments, hence, has an isolated, patchy distribution. The dominant species is kaolinite (Table 3), replacing grains and partially occluding large secondary pores (Figure 4). Lesser quantities of illite, smectite and chlorite occur. Thin section petrography shows the sample from 7382 feet to be "cleaner", containing less authigenic and detrital clay than the sample from 7366 feet (Table 4, Figure 4). The framework grain composition has affected the degree to which pore space has been retained. Silica cement has significantly occluded the primary pore space in the sample from 7382 feet, leaving small pore apertures and a poorly connected, tortuous pore network. Leaching of unstable framework components forming large secondary pores has added to the total visible pore space (2%). Minor microporosity associated with the abundant chert grains (Figure 4) will also contribute to the total porosity of the sandstones. In contrast, the abundance of argillaceous (clay-rich) rock fragments has aided in the preserva- tion of primary pore space in the sample from 7366 feet. The presence of these framework grains preserves some of the primary pore space because they cannot nucleate quartz overgrowth crystals (cement). They also frequently undergo alteration in the subsurface, producing secondary intergranular and intragranular pore space. However, this secondary alteration commonly provides material which is reprecipitated as diagenetic clay within the leached grain cavities and throughout the remnant pore system. Abundant intercrystalline mieroporosity is associated with the diagenetic clay minerals. Judging from the logs, the GB1 Sand is thickest in the A41-11 Well (88 feet), thinning in the A33-11 Well (62 feet) and the A43-11 Well (58 feet). Log responses from the A41-11 Well correlate well with the observed characteristics of the rocks. The increase in clay content ("shaliness") towards the top of the zone corresponds to an increase in gamma log response. The increase in deflection of porosity and S.P. toward the top of the interval also correlate with observed porosities. Overall, the reservoir quality of the GB1 Sand is judged to be moderately good in the upper zone, decreasing in quality with depth. GB2 Sand Seven of the samples submitted from the GB2 Sand were analysed (Table 1). Four of the seven samples are percussion sidewall cores, two from the A33-11 Well and two from the A41-11 Well, and the remaining three samples are conventional core pieces from the A43-11 Well. The conventional core samples from the A43-11 Well range from moderately well sorted (6986 feet) to very poorly sorted (6971 feet). Average grain size ranges from upper fine sand (177-250 microns) in the sample from 6986 feet to coarse sand (500-1000 microns) in the samples from 6965 feet and 6971 feet (Figure 1 and 2). Hand specimen investigation shows the coarser samples to contain pebble clasts up to several centimeters in diameter. Framework grains are angular to sub-rounded. All three samples show evidence of bedding on a centimeter scale. The four sidewall core samples contain virtually no original fabric due to process of obtaining percussion sidewall samples. The framework grains are heavily fractured and infiltrated with drilling mud (Figures 2, 3, 9 and 10). The largest surviving framework grains in the samples from A33-11 Well range from upper medium to lower coarse sand (350-750 microns). The samples from the A41-11 Well appear slightly finer-grained, remnant intact grains being in the medium sand category (250-500 microns). Little textural information, however, can be inferred due to the damaged nature of the samples. Silica is the dominant mineral constituent in all of the samples (Table 3), ranging from 62% of the bulk (7475 feet, A41-11 Well) to 80% (6965 feet, A43-11 Well). Petrographic examination reveals monocrystalline quartz and metamorphic fragments (polycrystalline quartzite) present in all of the samples in roughly sub- equal amounts (Table 4, Figures 1-3). These are the dominant framework grains. Silica also occurs as reworked detrital chert, constituting approximately 10% of the samples and as minor quartz overgrowth cement (Table 4). X-ray diffraction analysis shows a total feldspar content ranging from 12% (6965 feet, A43-11 Well) to 21% (6986 feet, A43-11 Well), averaging 16% (Table 3). This value is higher than the 9% average determined petrographically (Table 4) as some of the feldspar detected by XRD is included within the rock fragments. Both plagioelase feldspar and potassium feldspar (dominantly microcline and otho- clase, with minor perthite) are present. The feldspar is commonly diagenetically altered to clay minerals, particularly along cleavage planes (Figure 1). Leaching has given rise to secondary intergranular and intragranular pores. These pores commonly are partially occluded by grain remnants and authigenic clay minerals, particularly kaolinite (Figure 1, 5 and 6). Heavily altered volcanic igneous rock fragments of basaltic origin, argillaceous rock fragments, and both biotite and muscovite mica are present in minor amounts (Table 4). Argillaceous rock fragments average 6% for the GB2 Sand compared to 11% in the GB1 Sand '(Table 4). Opaque minerals (predominantly pyrite) and organic debris are present in trace amounts. Framework grains have a "fitted" texture with some sutured grain contacts due to compaction (Figure 1 and 2). Compaction has resulted in the deformation of relatively "soft" framework grains such as argillaceous rock fragments and cracking in more brittle quartz grains (Figure 1). Quartz overgrowths aid in the lithification .process (Table 4). The source of silica for these overgrowths was probably the pressure induced solution of framework quartz following compact- ion. Minor cements include authigenic clay minerals and rare authigenic dolomite. Clay mineral percentages determined from X-ray diffraction analysis (Table 3) range from a low of 7% (6965 feet, A43-11 Well) to a high of 22% (7475 feet, A41-11 Well). Thin section point count data (Table 4) show clay content to vary from 3% (6965 feet, A43-11 Well) to 6% (6961 feet, A43-11 Well). The lower percentages detected petrographically are due, firstly, to difficulty in seeing the grain-coating and pore-filling authigenic clays that are evenly distributed throughout the rock and, secondly, to the inclusion of the clay in argillaceous rock fragments and other framework components in the total clay mineral category in XRD. X-ray diffraction analysis shows kaolinite as the major clay species in the three samples analysed with smectite also relatively common. Lesser quantities of illite and chlorite were also detected (Table 3). Scanning electron microscopy shows kaolinite as the major authigenic phase present, being widely distributed throughout the samples, often forming as a diagenetic alteration product of unstable feldspar framework grains (.Figures 1, 2, 5 and 6). Well developed booklets and stacks of pseudohexagonal authigenic kaolinite plates and elongated vermiform crystals occur filling pores and lining large pore throats (Figures 5 and 6). Elongate fibers, ribbons and laths of authigenic illite present in pores may be an alteration production of unstable framework grains such as argillaceous rock fragments. Authigenic illite occurs attached to authigenic kaolinite (Figure 6), indicating illite formed at a later stage in the diagenetic history of the rocks than the kaolinite. Both the smectite and · chlorite detected by XRD were not observed in SEM. It is, therefore, probable that these clay minerals occur as constituents of detrital argillaceous rock fragments. Abundant intercrystalline microporosity is associated with the authigenic clay minerals. Routine core analysis data (Table 2) show porosity to range from 16.0 (6986 feet, A43-11 Well) to 18.8% (6971 feet, A43-11 Well), averaging 17.6% for the three samples analysed. Petrographic examination shows both primary intergranular and secondary pore types present, with primary more abundant than secondary (Table 4). Primary pore space has been occluded by compaction, quartz overgrowth cement, and detrital and authigenic clay minerals. Secondary pores are generally large and were formed due to unstable framework grain leaching. Minor intragranular secondary pores are also present. Petrographic examination (Table 4) shows porosity to range from 12% (6986 feet, A43-11 Well) to 15% (6965 feet, 6971 feet, A43-11 Well) averaging 14%. The lower amount of pore space detected visually is due to the difficulty in seeing the abundant microporosity present in all samples which is detected by routine analysis techniques. This microporosity is associated with framework grains including chert, leached feldspar and argillaceous rock fragments (Figures 1 and 5) and with authigenic clay minerals (Figure 5 and 6). Measured permeabilities range from 195 millidarcies (6965 feet, A43-11 Well) to 15.0 millidarcies (6986 feet, A43-11 Well). The sample with the lowest permeability is also the finest grained, hence, has the 'smallest pores and pore throats. Additionally, quartz overgrowths and clay minerals are most abundant in this sample. The components further occlude pore space, decrease pore aperture size and increase the 'tortuosity, hence, decreasing the effectiveness of the pore system. The net impact of finer grain size and greater degree of mineral diagenesis is to produce a rock type with moderate to good porosity and relatively low permeability. The effects of diagenesis are less in the coarser grained samples whose larger pores and pore throats are less significantly occluded with subsequent less reduction in permeability. The logs indicate the GB1 Sand is thickest in the A33-11 Well (86 feet), thinning in the A43-11. Well (64 feet) and A41-11 Well (62 feet). Log responses indicate the best porosity and permeability in the GB2 Sand is towards the top of the zone, which correlates well with the results of the analyses discussed above. Overall, the reservoir quality of the GB2 Sand is judged to be good, particularly in the upper zone, decreasing with depth. Log responses appear similar for the three wells studied in this report. SUMMARY The geological analysis of three conventional core samples and seven percussion sidewall core samples of the GB Sands from three wells (A43-11, A33-11 and A41-11) from the Middle Ground Shoal Field, Alaska, performed for Shell Western Exploration and Production, consisted of thin section petrography, scanning electron microscopy and X-ray diffraction. The results of these analyses lead to the following conclusions: 1. The rocks are very poorly to moderately well sorted sand- stones. Estimated average grain size ranges from upper fine to coarse sand (177-1000 microns), with some samples ranging up to pebble conglomerates. The conventional core pieces show evidence of bedding on a centimeter scale. e Compositionally, the rocks are sub-mature mineralogically. Sub-equal amounts of monocrystalline quartz and metamorphic rock fragments (quartzites) are the dominant framework grains. Subordinate amounts of microporous chert, feldspar, argillaceous and volcanic igneous rock fragments, and mica are also present. Other framework components include organic debris and opaque minerals. m The rocks are moderately competent with compaction and quartz overgrowths'the main lithifiers. Additionally, clay minerals in the form of deformed detrital rock fragments and authigenic clays contribute to grain bonding. e Both authigenic and detrital clay are present. The major a~thigenie phase is kaolinite with lesser amounts of illite. Other clays detected by XRD are smectite and chlorite. These clay minerals were not observed using SEM and are thought to be present as e0mponents of framework grains such as argillaceous rock fragments, with consequently less likeli- hood of interaction with fluids in the reservoir. 5, The effects of mineral diagenesis, comprised predominantly of quartz overgrowths and authigenic clay development has detri- mentally affected the quality of the reservoir rock. The fine- grained, better sorted sandstone samples in particular, have reduced pore space and lowered permeabilities. Additionally, the abundant microporosity associated with framework grains such as chert and argillaceous rock fragments, and authigenic clay minerals may increase immovable water saturations and affect log response. 6, Overall, the reservoir potential of the GB1 Sand is judged to be moderately good in the ~,pper zone, decreasing in quality with depth. Similarly, the GB2 .Sand is judged to be good, particularly in the upper zone, again decreasing in quality with depth. ENGINEERING ANALYSIS AND RECOMMENDATIONS Engineering Analysis Both of the GB Sand intervals in these three wells are characterized by moderate porosity, good permeability and high clay content. Bo Averaging the available data from the three wells indicates a strong similarity between the GB1 Sand and the GB2 Sand. Item GB1 Sand GB2 Sand Gross Height 76 ft. 73 ft. Net Height 60 ft. 57 ft. Hn/Hg ratio 79% 78% Porosity 15% 17% Clay Content 18.5% of bulk 18.5% of bulk Kaolinite 9.0% 8.5% Illite 3.5% 3.0% Chlorite 3.0% 3.0% Smectite 3.0% 4.0% Feldspar Content 17.0% of bulk 18.5% of bulk Ce The highest quality reservoir rock in each zone is located near the top of the zone and the quality decreases with depth in each sand. De Kaolinite and some illite in these samples are authigenic while the chlorite, smectite and some illite appear to be detrital in origin. Eo Both the kaolinite and illite occur as pore-filling materials that are loosely attached to the pore surfaces. The materials are susceptible to dispersion with minimal fluid flow through the pores. Fe Detrital chlorite, smectite and illite are part of the framework structure and are not likely to contribute to potential com- pletion problems. Go Kaolinite is not particularly sensitive to most fluids in normal use. However, a high pH fluid (8 to 10) appears to have a slight stabilizing affect on kaolinite. He Illite is rich in potassium which is easily removed from the crystal structure by fresh water or undersaturated brines. The illite crystals may collapse, into a mushy mass when potassium ions are removed. Ordinary clay stabilization techniques are not effective with illite because of the very slow ion exchange rate of illite. Illite probably will not stabilize in the time frame of a normal clay stabilization treatment. I · II. The low resistivity characteristic of the GB sands, as indicated by the induction logs may be due to excessive invasion of filtrates from the drilling mud, cement slurries and mud spacers. Engineering Recommendations Ao Reducing the water loss of the drilling mud to a range of i to 5 cc/30 min. would help to control filtrate invasion. A high overbalanced hydrostatic pressure would increase the risk of excessive filtrate invasion. A water base drilling mud containing diavalent calcium ions at a pH of 9 to 10 could be considered for these zones. Be The water loss of the cement slurries and spacers should be controlled to 20 et/30 min. or less. Placing the slurries in the annulus in plug flow will reduce the differential pressure from the annulus to the formation which would aid in controlling filtrate invasion. Co Perforating underba]anced will allow the formation pressure to purge the critical area around the well bore. However, a high underbalanced pressure that would allow a fluid surge in the formation may dislodge the kaolinite and create an immediate migrating fines problem. The recommended underbalanced pressure is 1500 to 2000 psi. Use the lower value if the fluid level must be .lowered to obtain the underbalanced pressure. The recommended minimum perforation diameter is 0.375 inches with 10 inches minimum formation penetration. De Testing immediately after perforating with a subsequent pressure build up survey will identify such problems as migrating fines. Migration of fines is indicated when the rate and/or pressure decrease rapidly at the beginning of the test period, then the rate of decline gradually decreases but fails to stabilize during the test period. A matrix treatment to stabilize the clays may be required to control migrating fines. The recommended treating material is fluoboric acid which stabilizes by structual fusion. The recommended volume is 125 gallons per foot of net pay. A spearhead of hydrochloric or hydrochloric-hydrofluoric acid is not recommended for this formation. If subsequent stimula- tion by fracturing is contemplated, a matrix diverting agent or buoyant ball sealers will be required to insure that most of the perforations are open. Fe If fracturing is necessary, a water base fluid with a pH above 8 and containing diavalent calcium ions (1% to 2% calcium chloride brine) would be appropriate. This fluid should also contain an ion exchange type clay stabilizer and a surface tension reducing agent. TABLE I ANALYSES CONDUCTED SAMPLE THIN SCANNING X-RAY DEPTH SECTION ELECTRON DIFFRACTION (FEET) PETROGRAPHY MICROSCOPY ANALYSIS Shell Western Exploration and Production A43-11 Well (Conventional Core Samples) 6965 X X X 6971 X 6986 X X X Shell Western Exploration and Production A33-11 Well (Percussion Sidewall Core Samples) 7021 X X X 7038 7053 7083 Insufficient Original Fabric/Sample Insufficient Original Fabric/Sample X 7118 X 7150 Insufficient Original Fabric/Sample Shell Western Exploration and Production A41-11 Well (Percussion Sidewall Core Samples) 7366 X X 7382 X 7410 Insufficient Original Fabric/Sample 7475 X X 7494 X X X X TABLE 2 ROUTINE CORE ANALYSIS DATA GB~. SAND, A-43-11 WELL (Data supplied by) Shell Western Exploration and Production, Inc. SAMPLE 'POROSITY AIR. GRAIN DEPTH (%) PERMEABILITY DENSITY (FEET) (md) (gm/cc) 6965 18.1 195 2.63 6971 18.8 169 2.63 6986 16.0 15.0 2.65 TABLE 3 X-RAY DIFFRACTION DATA "Bulk" Mineralogy ( ) ( Relative % of <5p clay Minerals ) GB ~ Sands A 33-11 Well 7021 70% 7% 10% -% 13% A 41-11 Well 7366 GB ,2 Sands A 43-11 Well 6965 6986 A 41-11 Well 51% 17% 17% 15% 59 6 11 - 24 47 21 16 16 80 6 6 I 7 40 9 42 9 64 10 11 - 15 46 16 24 14 7475 62 6 10 - 22 46 18 20 16 ' TABLE 4 THIN SECTION POINT COUNT DATA Sample Depth (Feet) Framework Grain Constituents E ) ( Pore-Filling Constituents ( Pore Space ) GB, Sands A 41-11 Well 7366 33% 8% 4% 5% 14% 13% 1% 2% -% 1% 7382 21 50 tr tr 7 9 2 - - tr GB 2 Sand A 43-11 Well 6965 25 11 7 2 4 27 2 2 1 tr 6971 25 9 4 4 4 26 3 2 - tr 6986 25 9 4 5 9 21 2 3 tr 5% 8 1 2 4 -% 1% tr 3% 1 2% tr 5% 1 10 9 8 3% FIGURE 1 A43-11 WELL (6965 FEET) Porosity*: 18.1% Permeability*: 195 md Visible pore Space: 15% Estimated Average Grain Size: Lower Coarse Sand Sorting: Poorly Sorted Ae The wide variety in grain size and composition and the degree of sorting of this sample are evident in this photomicrograph. Metamorphic rock fragments (R) are the dominant framework constituent, generally consisting of polycrystalline quartz grains with minor amounts of mica. Other framework grains present include monocrystalline quartz (Q), chert (C), and argillaceous rock fragments (A). The cracked framework grains (arrows) and deformed argillaceous rock fragments are indicators of compaction, with minor lithifiers including quartz overgrowths, detrital clay and authigenic clay. Pore space (blue) is common. 32X Bo Higher magnification details the nature of the framework grains and pore space. Patchy rhombs of high relief, sparry authigenic dolomite (D) partially replace monocrystalline quartz framework grains (Q). Feldspar grains (F) are commonly diagenetically altered to clay minerals. Leaching and dissolution of unstable framework grain minerals has lead to the development of large, secondary macropores, which are commonly infilled by authigenic kaoli'nite (K). Note the abundant microporosity associated with this clay mineral.'- Primary intergranular macropores are much smaller than the secondary pores (arrow). 128X A43-11 WELL (6971 FEET) Porosity*: 18.8% Permeability*: 169 md Visible Pore Space: 15% Estimated Average Grain Size: Coarse Sand Sorting: Very Poorly Sorted Ce Mineralogical and textural immatUrity is evident in this pl{otomicrograph. Metamorphic rock fragments (R) and monocrystalline quartz (Q) are present in subequal amounts, with lesser quantities of chert (C). Other framework grains include biotite mica (B) and volcanic igneous rock fragments (V). Abundant microporosity is associated with large chert grains. Compaction has resulted in grain deformation (arrow). Intergranular pores are large (blue) and appear to be well interconnected. 32X De This crossed-nicols photomicrograph is the same view as "C" and details the wide range in framework grain composition of this sample. Metamorphic rock fragments (R) appear as coarse, dark and light mottled grains. This is due to the variation in orientation of the individual crystals which comprise these polycrystalline quartz grains ("quartzites"). Other framework grains present include monocrystalline quartz (Q), chert (C) and biotite mica. 32X * Routine core analysis data supplied by Shell Western O.§mm 0.5mm 0.5mm FIGURE 2 A43-11 WELL (6986 FEET) Porosity*: 16.0% Permeability*: 15.0 md Visible Pore Space: 12% Estimated Average Grain Size: Upper Fine Sand Sorting: Moderately Well Sorted This finer grained sample is comprised of predominantly monoerystalline quartz (Q) and metamorphic rock fragments (R), with' lesser quantities of chert (C), feldspar (F), argillaceous rock fragments (A), and muscovite mica (M). Unstable framework grains appear brownish due to partial replacement by authigenic clay minerals. The grains have a "fitted texture", with argillaceous rock fragments deformed due to compaction. Muscovite and elongate argillaceous rock fragments show some degree of preferential orientation. Pore space (blue) is common, however, pore throats appear relatively constricted due to the poor sorting and authigenic clay minerals present. 32X Bt Diagenetic alteration of unstable framework grains has lead to the development of large secondary intergranular macropores (II). These pores often contain remnants of framework grains and are partially occluded by diagenetic alteration products including authigenic kaolinite clay (K). Primary intergranular macropores (I), monocrystalline quartz (Q), and microporous chert (C) are also shown. Quartz overgrowths (arrows) aid in lithifying the sample but are not abundant. 128X A33-11 WELL (7021 FEET) Ce The process of percussion sidewall coring has destroyed all original texture in this sample. Identifiable framework grains include metamorphic rock fragments (R), monocrystalline quartz (Q), argillaceous rock fragments, chert, and mica. Some of these framework grains appear to be in the upper medium/lower coarse sand category. Framework grains are heavily cracked, with original pore space obliterated by rock "dust" and brown and green drilling mud. 32X A33-11 WELL (7083 FEET) De Extensively fractured framework grains and large quantities of drilling mud are evidence of the obliterated original fabric of this percussion sidewall sample. Identifiable grains include monocrystalline quartz (Q), metamorphic rock fragments (R), volcanic igneous rock fragments (V), and chert (C). The larger framework grains visible in this photomicrograph are in the upper medium lower coarse category. 32X A 0.§ mm ~ t B 0.5 mm FIGURE 3 A33-11 WELL (7118 FEET) ie Bm Ce The surviving framework grains in this sample are in the lower coarse sand category. Identifiable grains include metamorphic rock fragments (R), monocrystalline quartz (Q), volcanic igneous rock fragments (V), and microporous chert (C). 32X A41-11 WELL (7475 FEET) The remnant metamorphic rock fragments (R) and microporous chert (C) grains of this sample are in the medium sand category. Monocrystalline quartz is also present. This sample has been intensely cracked and ground to rock powder due to the process of percussion sidewall coring. Note the abundant dark brown drilling mud. 32X A41-11 WELL (7494 FEET) This sample is intensely fractured, with large amounts of dark brown and green drilling mud present. Framework grains include monocrystalline quartz and metamorphic rock fragments, intact grains falling in the lower medium sand category. 32X A ,), B 0.,.% mm ) FIGURE 4 A41-11 WELL (7366 FEET) Ae Bo Ce De Visible Pore Space: 8% Estimated Average Grain Size: Upper Fine Sand Sorting: Moderately Sorted This finer grained sample is well lithified, with quartz overgrowths and detrital clay in the form of deformed argillaceous rock fragments (A) being the main cements. Framework grains include chert (C), monocrystalline quartz, metamorphic rock fragments, argillaceous rock fragments, and feldspars. Both large secondary (II) and smaller primary intergranular macropores are present. 32X High magnification shows white monocrystalline quartz, microporous chert (C), and brownish argillaceous rock fragments (A) present as framework grains. Unstable framework grains including feldspar (F) are commonly intensely leached and diagenetically altered, with authigenic kaolinite (K) a common alteration product. Note the abundant microporosity associated with the unstable framework grains and authigenic clay minerals. Pore space (blue) is further occluded by quartz overgrowths (arrows). 128X A41-11 WELL (7382 FEET) Visible Pore Space: 2% Estimated Average Grain. Size: Upper Fine Sand Sorting: Moderately Sorted This sample is very well lithified with quartz overgrowths being the main cement. Chert (C) is the dominant framework constituent, with lesser quantities of monocrystalline quartz (Q), metamorphic rock fragments (R), and argillaceous rock fragments (A) also present. Pore space is relatively scarce with microporosity (arrow) associated with chert. Large secondary (II) macropores are present, formed due to leaching of unstable framework grains. 32X This photomicrograph shows the same portion of the sample as under crossed nicols and illustrates the abundance of finely speckled chert. Less common monocrystalline quartz and metamorphic rock framents and also evident. 32X 0.§ mm 0.Smm FIGURE 5 6965 FEET The photomicrographs shown on this plate are successively higher magnifications taken of one area of the sandstone sample. The area shown in the white square is seen in the next photomicrograph at higher magnification. The Iow magnification photomicrograph presented in "A" shows the general nature of the rock fabric. Note the coarse-grained nature of this sample. Large primary intergranular macropores (arrows) are common due to the coarse grain size. Feldspar (F) is present as framework grains. Closer investigation (View B) details the diagenetic alteration of feldspar grains. Authigenic kaolinite (K) occurs as a diagenetic replacement mineral, reducing pore space. Greater detail (View C) details the morphology of the kaolinite, which is present as pseudohexagonal platelets stacked face-to-face ("booklets"), and as elongate vermiform crystals. Abundant micropores are present between the individual platelets. An energy dispersive spectrum (EDS) was obtained from the area of the sample shown in Photomicrograph C. This spectrum was converted into a table showing atomic percents and is shown in "D". In the succeeding plates of photomicrographs, the elemental data table will always follow the photomicrograph of the portion of the sample from which the data was obtained. The aluminium and silicon are components of kaolinite and feldspar, with the presence of the cation potassium indicating the feldspar may be potassium rich. The presence of the cations magnesium and iron may indicate the presence of other clay minerals. A - 100X first area B - 500X C - 2500X D - Elemental data 20~ FIGURE 5 Continued) 6965 FEET The photomicrographs found on this plate were taken of two other areas of the sandstone sample. Intergranular macropores (arrows) are large. Closer investigation (Photomicrograph F) shows a feldspar framework grain which has undergone extensive leaching. Preferential dissolution along cleavage planes has resulted in remnant elongate fibers and laths (arrow). Books of authigenic kaolinite (K) occur as diagenetic alteration products of feldspar. Note the associated microporosity and the abundance of fine material which may disperse and migrate, potentially decreasing permeability. The third area photographed (Photomicrographs G and H) shows an intergranular macropore partially occluded by diagenetic minerals. Stacked vermicular aggregates of authigenic kaolinite (K) occur loosely attached to framework grains, partially reducing and occluding pore space. Em 50X second area F - 250X Gm 200X third area H - 1000X FIGURE 6 6986 FEET A large seeondary maeropore (II) eontrasts in size with primary intergranular maeropores (arrows). The seeondary pore, formed due to leaehing, is partially oecluded by diagenetie alteration products. Authigenie kaolinite (K) oeeurs as intergrown masses of booklets and staeked vermieular aggregates. This diagenetie mineral has formed as a pore-filling eonstituent, forming mieropore spaee in a former maeropore spaee. Photomierograph C illustrates the morphology of the kaolinite in detail. Elemental data (Photograph D) shows the 1:1 ratio of aluminihm and silieon in kaolinite. A - 100X first area B - 500X C - 2500X D~ Elemental data FIGURE 6 (Continued) 6986 FEET The second and third areas photographed detail the diagenetic alteration and disintegration of framework grains. Authigenic kaolinite (K) is present as pseudohexagonal platelets, seen tightly stacked to form booklets, replacing the grains and infilling the surrounding pore space. Elongate ribbons of authigenie illite (I) occur growing on authigenic kaolinite (Photomicrograph F), indicating a later stage of diagenesis. E - 250X second area F - 2500X G - 250X third area H - 2500X FIGURE 7 7021 FEET The poor quality of this sample is evident at low magnification (Photomicrograph A). Abundant fine debris and cracked framework grains are a result of the process of taking percussion sidewall cores. Closer investigation (View C) shows a biotite mica framework grain partially.altered, with the edges of the mica grain appearing splayed and abundant authigenic illite clay (I) "growing" on the grain surface. The cations magnesium, potassium and iron are all present in biotite mica, with potassium also present in illite clay. A - 100X B - 500X C - 2500X D - Elemental data FIGURE 8 7366 FEE'I" Framework grains are shattered and generally coated with fine debris in this percussion sidewall sample. Heavily shattered quartz framework grains (arrows) and heavily deformed mica grains are visible in Photomicrograph C. High magnification (View B) details the deformed nature of biotite mica (B) present in this sample. Elemental data shows the high iron content of biotite mica. A - 100X B - 500X C - 2500X D - Elemental data FIGURE 9 */475 FEET Low magnification (View A) shows this sample to be coarse grained, with fine debris surrounding framework grains. Little or no original rock fabric is present. A deformed argillaceous rock fragment (R) is viewed in Photomicrograph B. High magnification (View C) shows the preferential orientation of platey clay minerals present in this argillaceous rock fragment and some associated microporosity. A - 100X B - 500X 2500X Elemental data FIGURE 10 ?494 FEET Identifiable framework grains in this heavily shattered sidewall sample include quartz (Q) and mica (M). Photomicrograph B details a heavily altered argilaceous rock fragment. Authigenic kaolinite (K) and authigenic illitic clay (I) have formed during the diagenetic alteration of this unstable framework grain. Note the abundant microporosity associated with these clay minerals. A - 100X B - 500X C - 2500X D Elemental data PE 2.,,O _Log' o-c 2 Gas COns, commission Anchorage .. GUE~: -' . Shell. Western E&P' Inc. -..Middle Ground 'Shoal A-,I.1-11. -._ ~ -~o lO DATE: PT~ d.O. October 1985 '-~.:! --! . _ ~6512 . :',-~: 0 Permeability. md 0 i I [ I · I ],-~ l' I ! i- l ~ ,, I ! ! I ! I I I ! ! I ! I I ! I I ! I ! ! I I ! ! I ! I ! I I I I ! ! I ! I ! ! I ! ! ! ! ! ! ! ! ! I ! ! ! ! ! ! ! · ! ! ! ! ! ! ! ! ! , ! ! ! ! ! ! ! ! I ! ! ! ! ! ! ! 1 ! ! ! ! ! ! COHPANY SheLL Western E&P Inc. CORE BARREL 6" ALuminum SLeeve MUD TYPE Water Base ARCHIMEDES Air DEPTH POROSITY PermeabiLity O/g FEET PERCENT md. RATIO 6615.6 13.6 2.6 0.15 6616.65 16.6 201. 0.27 6617.6 17.2 23. 0.31 6618.6 17.0 16. 0.53 6619.2 17.0 36. 0.57 6~20.65 15.7 59. 0.60 6621.9 16.2 20. 0.32 6622.6 16.7 66. 0.38 6623.6 15.5 10. 0.67 6626.9 . 15.9 1.7 0.80 6625.9 15.6 6.3 0.38 6627.6 16.9 32. 0.32 6628.4 17.2 28. 0.22 6629.55 13.7 0.9 0.10 6629.9 14.9 2.3 0.66 PETROLEUH TESTING SERVICE, INC. PAGE 1 FILE No. 6512 'DATE October 2, 1985 WELL A-61-11 FIELD MiddLe Ground Shoat COUNTY STATE ALaska PRELIMINARY REPORT CORE ANALYSIS APPARENT SATURATION ~ PORE SPACE SAND GRAIN ....................... DENSITY OIL WATER TOTAL gm/cc 10.5 72.3 82.8 2.65 17.4 64.1 81.5 2.66 21.5 68.5 90.0 2.66 28.6 53.2 81.6 2.65 30.1 52.8 82.9 2.65 23.6 57.8 81.2 2.65 20.1 63.1 83.2 2.65 21.9 57'3 79.2 2.62 33.7 50.3 86.0 2.65 39.2 49.0 88.2 2.69 DESCRIPTION Cgt, S&P, Fsd-gran, Sit, Gd odor, Lt brn stn, Brt yet fluor CgL~ S&P, Fsd-gran, Si[, Gd odor, Lt brn stn, Brt yet fluor CgL, S&P, Fsd-crssd, Sit, Gd odor, Lt brn stn, Brt yeL fluor Cg[, S&P, Fsd-crssd, Si[, Gd odor, Lt brn stn, Brt yet fluor Cg[~ S&P~ Fsd-crssd, Sit, Gd odor, Lt brn stn, Brt yet fluor Cg[, S&P, Fsd-gran, Si[, Gd odor, Lt brn stn, Brt ye[ fluor Cg[w S&P, Fsd-vcrssd, Si[, Gd odor, Lt brn stn, Brt yet fluor Cg[, S&P, Fsd-vcrssd, Si[, Gd odor, Lt brn stn, Brt ye[ fluor Cg[, S&Pw Fsd-vcrssd, Si[, Gd odor, Lt brn stn, Brt yet fluor Cg[, S&P, Fsd-msd, Si[, Gd odor, Lt brn stn, Brt yet fluor 23.8 63.6 87.2 2.65 22.4 69.3 91.7 2.64 17.3 77.5 94.8 2.65 7.8 76.8 84.6 2.66 28.8 63.0 91.8 2.67 Cgt, S&P, Fsd-msd, Sit, Gd odor, Lt brn stn, Brt yet fluor Cg[, S&P, Fsd-crssd, Sit, Gd odor, Lt brn stn, Brt yet fluor Cgt, S&P, Fsd-vcrssd, Sit, Gd odor, Lt brn stn, Brt ye[ fluor Cgt, S&P, Fsd-msd, Sit, Gd odor, Lt brn stn, Brt yet fluor Cg[, S&P, Fsd-crssd, Sit, Gd odor, Lt brn stn, Brt yet fluor RECEIVED OCT ! 6 Alaska Oil & Gas Cons. Commission Anchorage COMPANY SheLL gestern E&P Inc. CORE BARREL 4" ALuminum SLeeve HUD TYPE Water Base ARCHIMEDES Air DEPTH POROSITY PermeabiLity O/W FEET PERCENT lad. RATIO 6630.95 14.8 3.7 0.34 6631.85 17.7 34. 0.26 6632.75 15.6 5.1 0.36 6633.55 14.3 1.4 0.17 6634.55 17.3 24. 0.29 6635.25 15.3 3.9 0.24 6636.1 19.3 61. 0.29 6637.05 17.6 28. 0.31 6638.15 15.8 3.4 0.68 6639.1 10.0 5.4 0.43 6640.2 11.3 7.8 0.22 6641.5 15.0 39. 0.22 6642.1 14.1 80. 0.20 6643.1 14.0 35. 0.26 6644.1 15.9 21. 0.12 PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS APPARENT SATURATION ~ PORE SPACE SAND GRAIN ....................... DENSITY OIL WATER TOTAL gm/cc OESCRIPTION 21.8 64.4 86.2 2.65 Cgt, 20.1 77.7 97.8 2.65 Cg[, 23.1 64.2 87.3 2.66 Cgt, 12.5 7'5.5 86.0 2.67 Cgt, 21.3 74.5 95.8 2.65 Cgt, 17.8 7~.2 91.0 2.66 Cgt, 21.8 74.8 96.6 2.65 Cgt, 23.2 74.3 97.5 2.66 cgt, 37.0 54.5 91.5 2.66 Cgt, 29.1 67.7 96.8 2.66 Cg[, 16.8 76.0 92.8 2.65 Cgt, 15.4 71.3 86.7 2.64 Cgt, 14.8 74.0 88.8 2.65 Cgt, 20.6 78.1 98.7 2.64 Cgt, 9.6 81.9 91.5 2.65 Cgt, WELL A-41-11 FIELD MiddLe Ground Shoal COUNTY STATE ALaska PAGE 2 FILE No. 6512 DATE October 2, 1985 S&P, Fsd-vcrssd, Sit, Gd odor, Lt brn stn, Brt yet fluor S&P, Fsd-vcrssd, SiL, Gd odor, Lt brn stn, Brt yeL fluor S&P, Fsd-msd, Si[, Gd odor, Lt brn stn, Brt yeL fluor S&P, Fsd-msd, Si[, Gd odor, Lt brn stn, Brt yeL f[uor S&P, Fsd-crssd, Si[, Gd odor, Lt brn stn, Brt ye[ fluor S&P, Fsd-crssd, Si[, Gd odor, Lt brn stn, Brt ye[ fluor S&P, Fsd-crssd, Sit, Gd odor, Lt brn stn, Brt ye[ f[uor S&P, Fsd-crssd, SiL, Gd odor, Lt brn stn, Brt ye[ fluor S&P, Fsd-crssd, Si[, Gd odor, Lt brn stn, Brt ye[ fluor S&P, Fsd-peb, Sit, Gd odor, Lt brn stn, Brt ye[ f[uor S&P, Fsd-peb, Sit, Gd odor, Lt brn stn, Brt yet fluor S&P, Fsd-peb, Sit, Gd odor, Lt brn stn, Brt yet fluor S&P, Fsd-peb, Sit, Gd odor, Lt brn stn, Brt yet fluor S&P, Fsd-gran, Sit, Gd odor, Lt brn stn, Brt yet fluor S&P, Fsd-vcrssd, Sit, Gd odor, Lt brn stn, Brt yet fluor · COHPANY SheLL Nestern E&P Inc. CORE BARREL 4" ALuminum SLeeve HUD TYPE Mater Base ARCHIMEDES Air DEPTH POROSITY PermeabiLity O/W FEET PERCENT md. RATIO 66~5.6 13.8 11. 0.47 PETROLEUM TESTXNG SERVICE, INC. NELL A-41-11 FZELD MiddLe Ground Shoal COUNTY STATE ALaska PAGE 3 FILE No. 6512 DATE October 2, 1985 CORE ANALYSIS APPARENT SATURATION ~ PORE SPACE SAND GRAIN ....................... DENSITY OIL MATER TOTAL gm/cc 24.5 52.4 76.9 2.66 DESCRIPTION CgL, S&P, Fsd-vcrssd, Sit, Gd odor, Lt brn stn, Brt yeL fluor Type of Extraction - Dean Stark ToLuene Extraction. Confining Pressure on the Permeameter = 200 psi OiL Gravity Estimated By Visual FLuorescence = 30 These results must be used Nith caution. SideNaL[ core samples are obtained by impact coring. This method can fracture hard formations, thereby possibly increasing the porosity and permeability. In soft formations, impact coring can compact the samples, resulting in decreased porosity and permeability. DriLLing mud may penetrate fractures and soft formations, thereby affecting the porosity, permeability, fluid saturation, grain density and cation exchange capacity results. 1 II ~UB. SURFACE DIRECTIONAL ~URVEY [~UIDANCE ~]ONTINUOUS [~OOL Company SHELL WESTERN E & 'P INC Well Name SHELL A MGS,A-41-11 (S, HEL,,L PL. ATFORM A LEG 4, CONDUCTOR 31) Fleld/Lo~atlon , MIDD, L,E ,,, GROUND SHOAL. KENAI, ALAS,,KA . Jel~ Fleferenae 70929" Loaaad MURTLAND II I II GCT DIRECTION&L SURVEY CUSTOME~ LISTING FOR SHELL WESTERN E~m INC. SHELL ~_ MGS 4-41-11 METHODS OF COMPUT4TION TOOL LOCATION: T&NGENTIAL- INT.ERPOL~TION: LINEAR VERTIC4L Sr-CTION: HORiZ. DIST. MIDOLE GROUND SHO6L KENfiI,4L4SK& SURVEY 94TE: 24-0CT-35 ENGINEER: MUqTLANO ~VER~G:D DEVI4TiON aND PROJECTED ONTO 4 T4RGET AZIMUTH ~ZiMUTH ,OF NO~TH 0 D:G 0 MiN =dST SHELL WESTERN E&P INC. SHELL A MGS A-41-11 MIDOLE GROUNO SHOAL KENAI,ALASKA =_ -. COMMUTATION DATE: '. . .- -, 14-NOV-85 DATE OF SUqVEY: 24-3CT-65 KELLY BUSHING ELEVATI3N: 115.00 ENGINEER: MURTL~NO INTERPOLATED V~LUES- FOR EVEN 100 FEET OF TRUE SUB-SEa MEASURED VERTICAL V=RTICAL DEPTH DEPTH DEPTH MDASURE 0.00 0.00 -116.00 100.00 100.00 -16.00 200.00 199.99 83.99 300.00 299.94 183.94 400.00 399,86 283.86 500,00 499,67 383,67 600,00 599,40 483,40 700,00 699,09 583,09 800,00 798,49 682,49 900,00 897,16 781,16 COURSE VERTICAL DOGLEG RECTAN DEVIATION ~ZIMUTH SECTION SEVERITY NORTH/ OEG MIN DEG MIN FEET DEG/iO0 FEE 1000.00 994.61 878.51 1100.00 1090.53 974.53 1200.00 1185.09 1069.09 1300.00 1277.78 1161.78 1400,00 1368,79 1252,79 1500,00 1459,45 1343,45 1600.00 1550,28 1434,28 1700,00 1641,35 1525,35 1800,00 1732,48 1616,48 1900,00 1823,91 1707,9'1 0 0 N 0 0 E 0,00 0,00 0 11 N 6 15 E 0,30 0,31 1 8 N 56 28 W 0,93 2,39 2 10 N 52 45 W 2.68 0.84 2 26 N 51 3 W 5,23 1,47 4 11 N 66 49 W 7.96 0,62 4 34 N 23 7 W 12,97 2,74 4 51 N 3 42 E 20,68 2,57 7 43 N 9 34 W 31,39 3,84 10 56 N 18 39 W 46,78 3,85 2000.00 1915.12 1799.12 2100.00 2006.28 1890.28 2200.00 2097.16 1981.16 2300.00 2188.25 2072..25 2400.00 2'279.26 2163.26 2500.00 .23t~0~i24 2254.24 2600.00 "..2'~.6.~"~25 2345.25 2700.00-~:~:-~.2 2436.22 2800.00 ~'i"7 2527.27 2900 O0 3000.00 6 2709.76 3100.00 ~28 280~.28 oo.oo 3300.00 -$1 2984.31 3400.00 2,;'15 3076.15 3500,00 3284,12 3168,12 3600.00 3376.24 3260.24 3700.00 3468,27 3352.27 3800.00 3560.16 3444.16 3900,00 3652,37 3536,37 14 55 N 15 2 W 68,09 3,34 17 40 N 13 29 W 95,54 2,55 20 26 N 13 15 W 127.14 3,10 23 25 N 13 46 W -163.59 2,75 24 58 N 14 13 W 203.79 0,30 24 52 N 14 22 W 244,65 0,28 24 31 N 13 54 W 285.22 0.39 24 21 N 13 32 W 325.36 0.11 24 1 N 13 30 W 365,42 1.26 24 6 N 13 56 W 404,74 0,50 24 8 N 14 30 W 444,48 0,28 24 30 N 14 56 W 484.23 0,42 24 33 N 14 57 W 524,54 0,73 24 26 N 15 36 W 56~.35 0.32 24 30 N 15 2~ W 604.27 0,06 24 26 N 15 18 W 644,26 0,43 24 38 N 15 0 W 684.29 0,25 24 24 N 14 53 W 724,40 0,35 24 15 N 14 54 W 764.35 0.20 24 8 N 14 57 W 803.98 0.51 23 59 N 14 59 W 843,43 0,25 '23 37 N 15 13 W 882,35 0.85 23 52 N 15 24 W' 921.22 0.30 23 25 N 16 3 W 960,03 1,14 23 18 N 16 18 W 997,98 0,47 22 54 N 16 20 W 1035,67 0,61 22 58. N 16 13 W 1073,03 0,33 23 4 N 16 4 W 1110.61 0.44 ~3 6 N 14 50 W 1148.59 1.59 22 42 N 12 13 W 1186.22 0.31 B DEPTH GULaR SSUTH T COOROINATES 5fiST/WEST FEET 0.00 N 0.00 E 0.30 N 0.11 E 0.93 N 0.39 W 2.68 N 3.3:~ W 5.23 N 6.29 W 7.96 N 11.64 W 12.97 N 16.66 W 20.68 N 17.63 W 31.39 N 17,73 W 46.73 N 22.37 W 68.0~ N 29.01 W 95.5~ N 35.77 W 127.14 N 43.27 W 153.5S N 52.03 W 203.79 N 62.04 W 244.65 N 72.55 W 285.22 N 82.74 W 325.36 N 92,54 W 365.42 N i02.13 W 404,74 N 111,75 W 444,48 N 121,82 W 484,23 N 132,29 W 524,54 N 1~3,03 W 564,35 N 153,91 W 604,27 N 165,05 W 644.26 N 176,11 W 684.29 N 186,89 W 724.40 N ~97.59 W 764.35 N 208'21 W 803,98 N 218.81 W ~. · 882.3~ N ' 79 W 921.22 N ' 250.50 W 960.03 N 261.33 W 99'7.98 N 272.47 W 1035.67 N 283.51 W 1073.03 N 294.41 W 1110.61 N 305,27 W 1148,59 N 315,97 W 1185.22 N 324,53 W HgRIZ. DIST. FEET 0.00 0.32 1.01 4.29 8.18 14.10 21.11 27.1~ 35.05 51.85 DEPARTURE aZIMUTH OEG MIN N 0 0 E N 19 9 E N 22 43 W N 51 21 W N 50 N 55 37 N 52 6 .'~ N 40 26 W N 29 27 W N 2; 33 W 74.02 N 23 4 W 102.01 N ZO 31 W 134.30 N 18 47 W 171.66 N 17 3~ W 213.02 N 16 55 W 255.18 N 16 31 W 296.98 N 15 10 W 338.27 N 15 52 W 379.42 N 15 36 W 419.8~ N 15 26 W 460.87 501.98 543.69 5~4.96 625.40 667.39 709.35 ?50.87 792.Z0 833.22 874.04 914.35 954,67 994.96 1034.51 1073,78 1112.68 1151.80 1191.26 1229.~9 N 15 19 W N 15 16 W N 15 15 W N 15 15 W N 15 16/~.. N I5 1T N 15 16 , N 15 15 W N 15 14 W N 15 13 w N 15 12 W N i5 I2 W N 15 12 W N 15 13 W N 15 16 W N 15 18 W N 15 20 W N 15 22 W N 15 22 W N 15 18 W SHELL WESTERN E&P INC. SHELL A MGS ~-41-11 MIDDLE GROUND SHOAL KENAI~ALASKA CORPU~TI'ON DATE ..'..i' j ....;.: .,.-.'.. ' .. .. "~2-<'. '~... -. 14-NOV-B5 PAS; 2 DATE Dr SURVEY: 24-0CT-85 KELLY BUSHING ELEVATION: 115.00 ENGINEER: MURTL~ND FT INTERPOLATED VALUES-FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4000.00 3744.49 4100,00 3836,29 4200,00 3927,80 4300,00 4018,90 4400.00 4109,94 4500,00 4200,73 4600,00 4291,14 4700,00 4381,14 4800,00 4471,70 4900,00 4562,16 5000,00 4651,99 5100,00 4741,33 5200,00 4830,22 5300,00 4918,49 5400,00 5006,9? 5500.00 5095.46 5600,00 5184,02 5700.00 5272.93 5800,00 5362,17 5900,00 5451,97 6000.00 5541.96 6100.00 5632.02 6200.00 5722.45 6300.00 581!~. 76 6400.00 '.59.'0..~.79 6500,00 ..-~...99~W.70 6 6 0 0 · 0 0 ~'~0 8'_~ ~-~?"! 6700.00 6900.00 ~j~ .- ..~-~' . ~ 0 0 0 . 00 m 7100.00 ~00.00 .'6. 7300.00 ~t-~ ;93 7400. O0 7500,00 69~7,84 7600,00 7013,69 7700.00 T110.13 TSO0,OO 7~07,17 7900, O0 7304.56 COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 3628.49 3720.29 3811.80 3902.90 3993.94 4084,73 4175,14 4265,14 4355,70 4446,16 23 11 N 12 4 W 23 31 N 11 36 W 24 8 N 11 14 W 24 25 N 10 43 W 24 34 N 10 14 W 24 59 N 9 4 W 25 50 N 8 iT W 25 23 N 9 9 W 2~+ 59 N 14 7 W 25 36 N 20 44 W 4535 4625 4714 4802 4890 4979 5068 5156 5246 5335 ,99 .33 ,22 ,49 ,97 ,46 ,02 .93 ,1T .97 26 25 N 23 19 W 26 51 N 22 58 W 27 47 N 23 14 W 27 58 N 23 11 W 27 37 N 22 32 W 27 49 N 23 3 W 27 27 N-22 0 W 27 4 N 21 14 W 26 32 N ZO 48 W 25 45 N 20 25 W 5425 5516 5606 5697 5788 5879 5970 6061 6152 6243 ,96 .02 .45 ,76 .79 .70 .71 ,65 ,62 ,82 25 59 N 21 7 W 25 30 N 20 1Z W 24 38 N 18 57 W 24 12 N 17 49 W 24 34 N 17 28 W 24 38 N 15 21 W 24 21 N 13 59 W 24 48 N 12 18 W 24 15 N 10 26 W 24 8 N 8 13 W 6335 6427 6519 6612 6706 6801 6897 6994 7091 7188 · 10 23 54 N 5 54 W .04 22 27 N 4 17 W · 68 21 47 N 6 1 W .93 20 26 N 4 27 W · 95 19 10 N I 5 W · 84 17 33 N Z 45 E .69 15 '57 N 11 52 ~ · 13 14 30 N 18. 24 E · 17 1~ 33 N 23 56 E .56 12 42 N 27 57 E EVEN 100 FEET VERTICAL DOGLEG RECT&NG SECTION SEVERITY NORTH/S FEET OEG/IO0 1224.27 0.62 1263.10 0.44 1302.62 0.91 1343.09 0.23 1383.77 0.52 1425,08 0.64 1467.34 1.17 1510.46 1.68 1552.03 2.65 1592.66 Z.73 1633.19 0.88 1674,46 0.71 1716.64 1.03 1759.77 0.60 1802.71 0.29 1~45.66. 0.16 1888.55 0.87 1931.10 0.56 1973.24 0.79 2014.43 0.60 2055.16 0.67 2095.81 0.52 2136.00 2.36 2174.72 0.87 2214.15 0.46 2254.09 0.83 2294.17 0.93 2334.69 0.80 2375.37 0.92 2415.84 1.13 ~4=5 ~8 1.52 2495.56 1.25 2533.05 1.10 2568.95 1.62 2502.96 2.01 2634.50 2.04 2662.73 2.16 2688.17 1.T1 2710.68 1.33 2731.11 1.14 OF MEASURED DEPTH ULAR 'C00RD OUTH E~ST/ FEET FEET 1224.27 N 333.05 W 1263.10 N 34i.I3 W 1302.62 N ~49.11 W i343.09 N 357.00 W 1383.77 N 36~,.55 W I425.05 N 371.61 W 1467.3~+ N 37T.9'9 W i510.46 N 384.34 W 1552.03 N 392.68 W 1592.66 N 405.'49 W 1633.19 N 422.38 W 16'74.46 N 440.15 W 1716.64 N 458.03 W 1759.77 N 476,69 W 1~02,?1 N ~94.78 W 1845.66 N ~12.79 W 1888.55 N 530.64 W 1931.10 N 5~7.a~ W 1973.24 N 563.53 W 2014.43 N 579.05 W 2055.16 N 594.52 W 2095.81 N 609.97 W 2136.00 N 624.38 W 2174.72 N 637.18 W 2214.15 N 649.T1 W 2254.09 N 661.58 W 2294.17 N 672.11 W 2334.69 N 68)..5.2 W 2375.37 N ~_89.77 W 2415.84 N '~9.6,47 W 2456.38 N '0 .,48 24'95.56 N .T:04'67 2533.05 N 708,09 2568.95 N 71'1.86 2602.96 N 713.58 W 2634.50 N 713.29 W 2662.73 N 709.70 W 26~8.17 N 702.69 W 2710.68 N 6~3.99 W 2731.11 N 684.08 W INATES HORIZ. DEPARTURE WEST DIST. AZIMUTH FEET DEG MIN 1268.76 N 15 13 W 1308.35 N 15 6 W 1348.59 N 15 0 W 1389.73 N 14 53 W 1430.9~ N 14 1472.7~ N 14 36 1515.24 N 14 25 1555.59 N 14 16 W 1600.94 N 14 11 W 1643,47 N 14 17 W 1686.)2 N 14 30 W 1731.35 N 14 43 W 1TTS.TO N 14 56 W 1823.19 N 15 9 W 1869.38 N 15 20 W 1915.57 N 15 31 W 1961.68 N 15 41 W 200T.21 N 15 49 W 2052.16 N 15 56 W 2096.00 N 16 2 W 2139.45 N 16 8 W 2132.77 N 16 13 W 2225.35 N 16 17 W 2265.14 N 16 19 W 2307.51 N 16 21 234~.17 N 16 21 2390.50 N 15 19 2432.12 N 15 16 2473.50 N 15 11 W 21514.24 ,q 15 4 W W 2554.5~ N 15 56 W W 2593.14 N 15 46 W W 2630.16 N 15 37 W W 2665.75 N 15 29 W 2599.00 N 15 19 W 2729.35 N 15 8 W 2755.68 N 14 55 W Z77~.50 N 14 38 W 2798.10 N 14 Z1 W 2~15.48 N 14 3 W COMPUTATION DATE: 14-NOV-85 SHELL WESTERN E&P INC. SHELL A MGS A-41-11 MIODLE GROUND SHOAL KENAI~ALASKA INTERPOLATED VALUES FOR TRUE SUB-SCA MEASURED VERTICAL VERTICAL DEPTH DEPTH D;PTH COURSE DEVIATION AZIMUTH DEG MIN. OEG MIN 8000.00 7402.19 7286.13 8100.00 7499.87 7383.87 8200.00 7598.02 7482.02 8300.00 - 7696.69 7580.69 8400.00 7795.90 7679.90 8500.00 7895.17 7779.17 8600.00 7994.32 7878.32 8700,00 8093,35 7977.35 8800.00 8192.09 8076.09 8900.00 8290.41 8174.41 12 25 N 31 4 E 11 53 N 33 28 E 10 22 N 41 0 E 8 13 N 53 35 E 6 42 N 62 8 E 7 10 N 63 40 E 7 46 N 66 13 E $ 18 N 66 37 E 9 53 N 70 1 E 11 5 N 72 50 E 9000.00 8388.32 9100.00 8485.61 9200.00 8582.13 9300.00 8678.07 9400.00 8773.48 9500,00 8868.57 9600.00 8963.53 9700.00 9058.31 9800,'00 9152.43 9900.00 9245.38 8272.32 12 29 8369.61 14 11 8466.13 15 51 8562.07 16 58 8657.45 17 50 8752.57 - 17 59 8847.53 18 37 8942.31 18 54 9036.43 20 39 9129.38 22 30 N 75 34 E N 77 37 5 N 79 9 E N 79 21E N 80 3 E N 80 51 E N 80 32 E N 82 1E N 83 25 N 83 53 E EVEN 100 VERTICAL SECTION FEET 2749.87 2768.07 2783.&5 2794.48 2800.90 2806.36 2811.87 2817.40 2823.29 2829.11 2834.63 2839.90 2845.05 2850.45 2855.76 2860.89 2866.03 2870.83 2875.35 2379.49 ~EET OF DOGLEG SEVERITY DEG/IO0 0.22 2,34 2.88 0.25 0.55 0.52 1.28 1.55 1.32 1.84 1.85 0.83 1.16 0.94 0.69 0.43 1.43 1.88 1.59 10000.00 9337.44 10100.00 9429.26 10200.00 9520.51 10300.00 9611.16 10400.00 97'01-41 10500.00 g791o"18 10600.00 9880.40 10700. O0 :.-9'96~*.23 10800.00 l'90:~:Z~i.~ 7 i 0863.00 '~'~ F'--- ;C .: ~.-": ~-. .. .. .. ..- .- .. 9221.44 23 5 9313.26 23 43 9404.51 24 37 9495.16 25 12 9585.41 25 50 9675.18 26 33 9764.40 26 59 9853.23 27 46 9941.47 28 31 9996.79 2.8 35 N 84 35 : 2883.46 N 35 18 E 2886.87 N 86 14 E 2989.90 N 86 45 : 2392.46 N 86 42 E 2894.80 N 85 46 : 2897.75 N ~6 29 E 2900.~3 N 86 53 = 2903.33 N 86 41 E 2905.95 N ~5 40 5 2907.70 0.71 1.04 1.23 0.55 0.58 1.2.0 0.56 0.81 0.85 0.00 O~GE 3 DATE OF SURVEY: 24-0CT-85 KELLY 3USHING ELEVATIDN: 116.00 ENGINEEr: MURTL~N~ FT M;ASURED DEOTH RECTANGUL&R COORDINATES HORIZ. D;PARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FSET FEET ~SET OEG MIN 2749.87 N 673.30 W 2831.10 N 13 ~5 W 2768.97 N 662.06 W 2845.1 2783.45 N 650.58 W 2~58.47 N 13 9 W 2794.48 N 633.7=~ W 2~66.55 N 1~ 5~_ W 2800.90 N 623.10 W 2~70.45 N 12 38 2806,36 N 617,37 W 2~73.47 N 2811.87 N 605.58 W 2~T$.3~ N 12 9 2817.4~ N $92.~7 W 2979.10 N I1 53 W 2823.29 N 57~.i9 W 2831.~8 N 11 34 W 282~.11 N 560.90 W 28~4.I8 NlI 12 W 2:34.63 N S41.35 W 2385.86 N lO 48 W 2839.90 N 518.84 W 2885.91 N 10 21 W 2845.05 N 4'93.24 W 2,387.49 N 9 50 W 2850.45 N 465.54 W 23~8.22 N 9 16 W 2855.76 N 436.DB W 288a.86 N ~ 40 W 2860.89 N 405.57 W 2889.49 N ~ 4 W 2866.03 N 374.65 W 2890.41 N T 25 W 2870.83 N 343.13 W 2891.26 N 5 48 W 2875.35 N 309.67 W 2891.97 N 5 8 W 2879.49 N 273.03 W 2892.40 N 5 24 W 2883.46 N 234.19 W 2892.'95 N 2886.87 N 194.71 W 2393.43 N 2889.90 N 153.92 W 2893.99 N 2892.46 N 111.78 W 2594.$2 N 2894.80 N 68.77 W 239~.$2 N 2897.75 N' 24.83 W 2397.85 N 2900.83 N 20.26 E 2900.90 N 2903.33 N 66.10 E 2904.08 N 2905.95 _N .113.06 E 2908.15 N 2907.70 N 143.16 E 2911.23 N 4 38 W 3 51 W 3 2 W :- I 21 ~.~,,-. 0 29 ,3 24 t. I 18 E 2 13 E SHELL WESTERN E&P INC, SHELL A MGS A-~1-11 MIDDLE GROUND SHOAL KENAI,ALASKA COMPuTaTiON DATE: ZNTxRPOLATED VALUES TRU~ SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEO MIN DEG MIN 0.00 0.00 -116.00 0 0 N 0 0 E 1000.00 994.61 878.61 14 55 N 1~ 2 W 2000.00 1915.12 1799.12 24 8 N 14 30 W 3000.00 2825.76 2709,76 23 59 N 14 59 W 4000,00 3744.49 3628.49 23 11 N 12 4 W 5000°00 4651.99 4535.99 26 25 N 23 19 W 6000.00 5541.96 5425,96 25 59 N 21 7 W 7000.00 6451.10 6335.10 23 54 N 5 54 W 8000.00 7402.19 7286.19 12 25 N 31 4 E 9000.00 8388.32 8272.32 12 29 N T5 34 E 10000,00 9337.4~ 9221.44 ._~= 5 N 94 3:. _~ 10863,00 10112.79 9996.T9 28 35 N 85 40 E EVEN 14-NOV-g5 1'000 FEET OF VERTiCaL SECTION FEET 0.00 68.09 444.&8 343.43 122~.27 1633.19 2055.16 2456.38 2749.87 2834.63 2~83.46 2907.?0 DOGLEG SEVERITY DEG/IO0 0.00 3.34 0.28 0.25 0.62 0,88 0.67 1.52 0.22 1.8~ 0.71 0.00 OAT~: DF SURVEY: 2,t-ICT-8~ KELLY BUS~IN'$ ELEVATION: 116.00 ENGINEER: MURTLANg MEASURED OEPT RECTANGULAR COOROiN~T~S HORiZ. DEPARTURE NOqTH/SOUTH EAST/W2ST gIST. ~ZIMUTH FEET FEET FEET D5G MIN 0.00 N 0.00 E O.OO N 0 0 E 68.09 N 29.01 W 74.02 N 23 4 W 444.~8 N 121.82 W 450.~7 N 15 19 W 843.43 N 229,31 W 874.04 N 15 12 W 1224.27 N 333.05 W 126~.76 N 15 13 J~. 1633.19 N 422.38 W 1686.92 N 14 30 2055.15 N 594.62 W 2139.45 N 16 8 2456.38 N 701.48 W 2554.58 N 15 56 ~ 2749.87 N 573.30 W 283i. I0 N 1~ 45 W ~ 6~ N :4i 35 W 2835.~6 N 10 4~ W 2853.46 N 234.19 W 2~92.'~5 N 4 38 W 2907.70 N 14).16 E 2911.23 N 2 49 E FT SHELL WESTERN E&P iNC. SHELL A MGS A-41-11 MIDDLE GROUND SHOAL KENAI~ALASKA COMPUTATION DATE: '. . . . .. _ 14-NOV-85 PAG~ 5 DATE OF SURVEY: 24-3CT-85 KELLY BUSHING ELEVATIQN: 116.00 ENGINEER: MURTLAND ~T INTERPOLATED VALUES'FOR EVEN 100 TRUE SUB-SEA COURSE VERTICAL MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION' DEPTH DEPTH DEPTH OEG MIN OEG MIN FEET i 0.00 0.00 -116.00 0 0 N 0 0 ;: 0.00 16.00 16.00 -100.00 0 6 N 15 59 E 0.00 116.00 116.00 0.00 0 13 N 4 9 W 0.36 216.01 216.00 100.00 1 31 N 60 26 W 1.12 316.08 316.00 200.00 2 10 N 50 1 W 3.06 416.16 416.00 300.00 2 41 N 54 42 W 5.67 516.37 ' 516.00 400.00 ~ 5 N 63 6 W 8.44 616.66 616.00 500.00 4 36 N 17 40 W 14.22 · 716.97 716.00 600.00 5 lO N 5 3 E 22.07 ~ 817.70 816.00 700.00 8 14 N 12 28 W 33.84 919.18 916.00 800.00 11 40 N 18 40 W 50.18 1022.20 1016.00 900.00 15 35 N 14 25 W 73.86 1126.77 1116.00 1000.00 18 22 N 13 25 W 103.55 1233.12 1216.00 1100.00 Z1 27 N 13 ~4 W 138.72 1341,84 1316.00 1200.00 24 22 N 13 56 W 180.11 1452.09 1416.00 1300,00 24 56 N 14 26 W 225.10 1562.30 1516.00 1400.00 24 40 N 13 59 W 269.99 1672.18 1616.00 1500.00 24 22 N 13 37 W 314.21 1781.93 1716.00 1600.00 24 9 N 13 29 W 358.20 1891.33 1816.00 1700.00 24 3 N 13 54 W ~01.30 2000.97 2110,69 2220.70 2330,48 2440.38 2550.25 2660.25 2770.10 2879.76 2989.31 3098.61 3207.89 3317.08 3425.97 3534.59 3643.19 3751.92 3860.58 3969.02 4077.88 1916.00 2016,00 2116.00 2216.00 .1316,00 "'241.6~00 25~'6. O'O ~ ~ 6,-~o -Z~ ~-~0 o ~'1~-~'0.0 $-~ 6 0'o 33t ~ ~00 3~16.00 3516.00 3616.00 37~6.00 3816.00 1800.00 24 8 N 14 30 W 444.86 1900.00 24 33 N 14 57 W 488.52 2000.00 24 25 N 15 4 W 532.82 2100.00 24 28 N 15 38 W 576.50 2200.00 24 30 N 15 27 W 520,42 2300,00 24 28 N 15 3 W 564.30 2400.00 24 29 N 14 54 W 705,5? 2500.00 24 22 N 14 53 W 752,50 2600.00 24 10 N 15 0 W 795.99 2700.00 24 1 N 14 57 W ~39.22 2800.00 23 37 N 15 13 W 881.81 2900.00 23 52 N 15 24 W 924.30 3000.00 23 20 N 16 12 W 966.50 3100.00 23 14 N 16 1T W 1007.84 3200.00 22 52 N 16 14 W 1048.55 3300.00 23 2 N 16 5 W 1089.24 3400.00 23 17 N 15 45 W 1130.2& 3500.00 22 38 N 12 43 W 1171.37 3600.00 23 0 N 1Z 14 W 1212,37 3700,00 23 26 N 11 39 W 1254,46 ~EE DOG SEV D:G T OF LEG ERITY /100 0.00 0.00 0.49 2.56 0.49 2.18 2.85 2.35 2.90 3.58 4.18 3.04 2.64 3.05 1.82 0.21 0.41 0.18 0.83 0.61 0.28 0.33 0.72 0.30 0.04 0.40 0.92 0.86 0.57 0.86 0.32 0.80 0.50 0.44 0.30 0.70 0.84 0,69 0.30 SUB-SEA 9£PTH RECTANGULA~ COORDINATES HDRIZ. DEPARTURE NORTH/SOUTH EAST/W~ST CIST. ~ZIMUTW FEET =EET FEET DEG MIN 0.03 N 0.00 E 0.00 N 0 0 E 0.09 N 0.00 = 0.00 N 90 0 E 0.35 N O.11 [ 0,37 N 16 30 E 1.12 N 0.71 W 1.32 N 32 2~ W '3.06 N 3.83 W 4.90 N 51 19 ~k._ 5.6? N 6.~6 W 8.90 N 50 25 8.44 N 12.73 W 15.~7 N 56 27 14.22 N 17.15 W ZZ.2~ N 50 19 ~ 22.07 N 17.48 W 2~.15 N 33 22 W 33.84 N 19.31 W 39.&3 N 28 2~ W 50.15 N 23.55 W 55.43 N 25 8 W 73.~6 N 30.48 W 79.90 N 22 25 W 103.55 N 37.69 W 11~.19 N 20 0 W 138.72 N 45.00 W 145.15 H 1~ 20 W 180.11 N 56.10 W 189.64 N 17 18 W 225.10 N 67.50 W 235.01 N 16 41 W 269.99 N 7~.96 W 281.30 N 16 18 W 314,21 N 89.84 W 326.~0 N 15 57 W 358.20 N 100.40 W 372.00 N 15 39 W 401.30 N 110.~9 W 416.34 N 15 26 W 444.86 N 121.~2 W 4.51.25 N 15 19 W 488.52 N 133,44 W 505.41 N 15 16 W 532.82 N 145.24 W 552.25 N 15 14 W 576.50 N 157.32 W 597.5~ N 15 15 W 620.42 N 169,52 W 643.16 ~ 15 15 j~k,~ 664.30 N 18~.53 W 688.66 ~ 15 17 708.57 N 193.38 W 734.~8 N 15 15 - 752.50 N 205.06 W 77}.~4 N 15 14 W 795.99 N 216.68 W ~24.95 N 15 13 W 839.22 N 228.19 W 369.69 N 15 12 N 881.81 N 'Z~9~65 W 913.79 H 15 12 W 924.30 N .'251~35 W 957.87 N 15 12 W 966.50 N 26~.22 W 1001.70 N 15 14 W 1007.84 N 275.85 W 1044.78 N 15 16 W 1048.55 N 287.28 W 1097.19 N 15 19 W 1089.24 N 299,09 W 112~.56 N 15 21 W 1130.24 N 310,89 W 1172.22 N 15 22 W 1171,37 N 321.58 W 1214.71 N 15 21W 1212.37 N 330.47 W 1256.60 N 15 14 w 1254.46 N 339.35 W 1299.55 N 15 8 W COMPUTATION SHELL WESTERN E&P INC. SHELL A MGS A-41-11 MIDDLE GROUND SHOAL KENAI,AL&SKA INTERPOLATED VALUES FO'R TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 4187.07 3916.00 3800.00 4296.82 4016.00 3900.00 4406.66 4116.00 4000.00 4516.85 ~216.00 4100.00 4627.67 4316.00 4200.00 4738.54 4416.00 4300.00 4848.90 4516.00 4400.00 4959.85 4616.00 4500.00. 5071.62 4716.00 4500.00 5183.94 4816,00 4700.00 24 3 N 11 16 W 24 25 N 10 44 W 24 36 N 10 12 W 25 2 N 8 52 W 26 1 N 8 16 W 25 7 N 10 47 W 25 13 N 'IT 17 W 26 8 N 22 56 W 26 45 N 23 11 W 27 38 N 23 7 W 5297,19 4916,00 4800,00 5410.20 5016.00 4900.00 5523.22 5116.00 5000.00 5636.00 5216.00 5100.00 5748,33 5316,00 5200,00 5860,04 5416,00 5300,00 5971.10 5516,00 5400,00 6082.24 5616.00 5500.00 6192.91 5716.00 5600.00 6302.46 5816.00 5700.00 27 59 N 23 12 W 27 38 N 22 33 W 27 46 N 22 53 W 27 15 N 21 39 W 26 49 N 20 59 W 25 59 N 20 26 W 25 57 N 21 B W 25 34 N 20 20 W 24 47 N 19 4 W 24 1.3 N 17 48 W 6412.33 6522.34 6632.15 6742.23 6851.96 6961.55 7070.72 7178.80 7286.21 7392.64 7498.07 7602.40 7706.05 7809.07 7911.73 8014.14 8116.48 8218.28 8319,51 84-20.23 5916.00 6016.00 6116.00 6216.00 6-3:16;00 ~4.1'6~.00 6.!ii! 6 ~ 0;0 ....~.~ I~.~"--;~.o T~ [6~00 73 ::6i O0 7~16.00 7516.00 7616.00 7715.00 7816.00 5800.00 24 35 N 17 22 W 5900.00 24 34 N 15 2 W 6000.00 24 27 N 13 21 W 6100,00 24 34 N 11 38 W 6200.00 24 14 N 9 24 W 6300.00 24 7 N 6 46 W 6400.00 22 48 N 4 10 W 6500.00 21 57 N 5 39 W 6600.00 20 35 N 5 3 W 6700.00 19 17 N 1 24 W 6800.00 17 35 N 2 38 6900.00 15 56 N 1Z 4 7000,00 14 25 N 18 42 E 7100.00 13 29 N 24 17 E 7200.00 12 38 N 28 27 E 7300,00 12 26 N 31 9 E 7400.00 11 36 N 7500.00 10 1 N 43 11 E 7600,00 7 43' N 56 Z 7700,00 6 45 N 62 30 E DATE: EVEN 14-NOV-B5 100 FEE T OF VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 1297. 1341. 1386, 1432. 1479, 1526, 1571, 1616, 1662. 1709. 1758. 1807. !~55, 1903, 1951. 1998. 2043, 2088. 2133. 2175. 41 80 49 13 36 94 86 70 77 56 08 63 89 55 12 33 64 21 68 05 10 04 39 78 34 21 17 53 gl 38 59 6O 39 87 03 O0 2219. 2263. 2307. 2351. 2396. 2440. 2484. 2525. 2564. 2500. 2633. 2563. 2689. 2712. 2733. 2752. 2770. 2785. 2796. 2802, 1,14 0.24 0,49 0.39 0.20 2.17 3.02 1,02 0.45 1.18 P2G~ ~ D&TE OF SU2VCY: 24-0CT-95 KELLY BUSHING ELEV4TIDN: 115.00 ~NGINEER: MURTL4Ng SUB-SE& DEPTH R=CTANGUL.4R COORDINATES HORIZ. 9EOAqTURE NORTH/SOUTH EAST/WEST DIST. ~ZIMUTH :EET FEET ~=:T 9EG MIN FT 1297.41 N 345,08 W 1343.30 N 15 I W 1341.80 N 356.75 W 1383.42 N 1~ 53 W 1386.~9 N 365.05 W 1433.74 N 14 45 W 1432,13 N ~72,73 W 1479,93 N 14 35 W 1479,36 N 379.74 W 1527.32 N 14 23 ~ 1526.64 N 387.15 W 1--74~ .~6 N 14 13 ' 1571.94 N 393.32 W 1621.62 N 14 13 1516.$6 N 415.37 W .1659.36 N 14 24 ~ 1662.70 N 435.14 W 171~.69 N 14 39 W 1709.77 N 455.08 H !76').30 N 14 54 W 0,62 1758.56 N 475.17 W 1821.~9 N 15 9 W 0,33 1807.08 N 496.59 . 1874.07 N 15 21 W 0.61 1955.63 N 517.03 W 1926.51 N 15 34 W 0,47 1903,89 N 536.75 W 1975,11 N 15 4~ W 0,52 1951,55 N 555.35 W 202~.03 N 15 53 W 0,96 1998.12 N 573.00 W 2078.65 N 16 0 W 0,64 2043.33 N 590.03 W 2126.82 N 16 6 W 0,69 2088.64 N 607.33 W 2175.15 N 16 12 W 2.49 2133.21 N 623.43 W 2222.45 N 16 1T W 0.82 2175.68 N 637.49 W 2267.15 N 16 19 W 0,54 0,72 1.12 1.15 0.84 0.90 1.53 1.07 2.53 2.09 2.92 2.13 1,73 1.19 1.01 0.10 2.59 2.97 3.25 0.55 2219.05 N 651.26 W 2312.65 N 15 21 W 2263.10 N 66~,02 W 2358.50 N 15 Z1 W 2307.04 N 675.25 W 2403.33 N 16 1~ W 2351,98 N 685.20 W 2449.75 N 16 14 W 2396.39 N 693.46 W 2494.71 N 16 8 2440.78 N 699.74 W 2539,10 N 15 59 ' 248~,34 N 703,88 W 2582,13 N 15 49 2525,21 N 707,29 W 2622.40 N 15 38 2564.17 N 711~,50 W 2661.05 N 15 30 W 2600,53 N .7I'"~,~52 W 2696.64 N 15 20 W 2633.91 N":~i.~--I~'.31 W 2728.79 N 15 9 2663.38 N '~"09w57 W 2756.2~ N 14 55 W 2689.59 N 702,20 W 2779.74 N 14 37 W 2712.60 N I 69]),11 W 2799.75 N 14 19 W 2733.38 N 682,86 W 2817.38 N 14 1 W 2752.48 N 671.73 W 2833.26 N 13 42 W 2770.87 N 660,19 W 2'848.44 N 13 24 W 2785.83 N 648.41 W 2550,30 N 13 6 2795.03 N 636.53 W 2867.57 N 1Z 49 W 2802.00 N 626.01 W 2871.98 .N 12 35 W SHELL WESTERN E&P INC. SHELL A MGS A-41-11 MIDDLE GROUND SHOAL KENAI~ALASKA CO P'UtA'tION DATE: ,~;;.-, -?g:::-!-~.: ...... 14-NOV-85 INTEROOLATED VALUES-'~OR"-EVEN 100 TRUE SUB-SEA MEASURED VERTICAL'VERTICAL DEPTH DEPTH OEPTH 8520,99 7916, 8621,89 8016, 8722,90 8116, 8824,29 8216. 8926.09 8316. 9028.38 8416. 9131..39 8516. 9235.23 8616. 9339.71 8716. 9444.71 8816. O0 7800,00 O0 7900,00 O0 8000,00 O0 8100,00 O0 8200,00 O0 8300.00 O0 8400,00 O0 8500.00 O0 86D0.00 O0 8700,00 COURSE VERTICAL DEVIATION AZIMUTH SECTION OEG MIN DEG MIN FEET 7 17 N 64 6 E 28.07,53 7 51 N $5 26 E 2813,06 8 38 N 67 2 E 2818,73 10 13 N 70 44 E 2824,70 11 23 N 73 33 E 2830.57 13 1 N 76 21 E 2836.15 14 49 N 78 14 E 2841.56 16 11 N 78 50 E 2846.90 17 20 N 79 47 E 2852.56 18 3 N 80 23 E 2858.10 9549.88 8916 9655.34 9016 9761.16 9116 9868.25 9216 9976.69 9316 10085.51 9416 10195,04 9516 10305.34 9616 10416.21 9716 10527.79 9816 · 00 8800.00 · 00 8900.00 · 00 9000.00 · 00 9100.00 · 00 9200,00 .00 9300.00 o00 9400.00 · 00 9500.00 · 00 9600.00 .00 9700.00 18 15 N 80 22 E 2863,37 18 29 N 81 29 E 2868,81 19 55 N 82 18 E 2873,62 22 0 N 83 40 E 2878,19 23 6 N 84 18 E 2982.56 23 34 N 8~ 14 E 2886.39 24 34 N 86 12 E 2889.76' 25 14 N 86 47 E 2892.59 25 55 N 86 3& E 2895.20 26 50 N 85 51 5 2898.67 10639.99 9916 10752.92 10016 10863.00 10112 .00 9800.00 .00 9900.00 .79 9996.79 27 12 N 86 53 : 2901.89 28 1 N 86 49 E 2904.71 28 35 N 86 40 ~ 2907.70 =EET DOGL S~VE DEG/ PAGE 7 DaTE Om SURVEY: 24-0CT-85 KELLY BUSHING ELEVATION: 116.00 ENGINEER: MURTLaND OF SUB-SEA O~mTH EG RECTANGULAR COORDINATES HORIZ, RITY NORTH/SOUTH EaST/WEST DIST, 100 :~ET FEET FEET .65 2807.53 N 615.00 W .39 2813.06 N 602.85 W · 74 2~1~.73 N 589.50 W .35 2824.70 N 574.19 W · 20 2830.57 N 556.02 W .07 2836,15 N 535.29 W ,28 2841,56 N 511,16 W .13 2846.90 N 453.70 W .77 2952.56 N ~54.01 W .37 2358.10 N 422,46 W .96 2863.37 N 390.32 .14 2868.81 N 357.24 · 15 2873.62 N 323.03 · 63 2878.19 N 285.00 · 50 2882.56 N 243.27 · 17 2886.39 N 200.52 ,28 2889.76 N 155,~8 .51 2892.59 N 109.51 · 71 2895.20 N 61.71 .06 2898.67 N 12.36 · 94 2901,89 N 38.44 · 83 2904.71 N 90.82 · 00 2907.70 N 143.16 2874,19 2875,93 2f79,78 2882,~7 2~84,57 2886,22 2-~87,17 2887,70 2833.~7 2889.15 W 288').35 W 2590,97 W 2891,72 W 2892,27 W 2892.81 W 2893,35 W 2893,97 W 2894,56 W 2895.86 W 28g~.70 E 2902,14 E 2906,13 E 2911.23 DEPARTURE &ZIMUTH D~G MIN N 12 21 W N 12 5 W N 11 49 W N 11 29 W N 10 41 .N 10 11 ,. 9 38 W N 9 2 W N 8 2& W N 7 &5 W N 7 5 W N 6 24 W N 5 39 W N 4 49 W N 3 58 W N 3 5 W N 2 10 W N I 13 W N 0 14 W N 0 45 E N 1 a7 E N 2 a9 ~ FT SHELL WESTERN E&P iNC. SHELL A MGS A-41-1! MIDDLE GROUND SHOAL KENAI,ALASKA MARKER TD (DRILLER) CDMPUTATI'ON INTERPOLATFD VALUES FOR MEASURED DEPTH BELOW KB 10863.00 DATE: lC-NOV-85 DATE DF SURVEY: 24-0CT-85 KELLY 8USHINS :Lr-V~Ti'2N: 116.00 ENGINEER: .~4URTLAND FT CHOSEN HORIZONS FROM ORIGIN= L&TITIUD: TVD KB SUB-SEa 10112.79 9996.79 SURFACE LOCATION aT 60.7955,SEC 11,TSN,R13W RECTANGULAR COORDINATES NORTH/SOUTH E~ST/WSST 2'907.70 N 1~3.16 E SHELL WESTERN E&P INC. SHELL A MGS A-41-11 MIDDLE GROUND SHOAL KENAI~ALASKA MARKER TD (DRILLER) FINAL MEASURED DEPTH I0863.00 WELL LOC~TION TRUE VERTICAL DEPTH 10112.79 CO/~'PU%ATIDN DATE: . . . 14-NOV-85 P~SE 9 DATE OF SURVEY: Z4-OCT-~5 KELLY 5USHING ELEVATION: 116.00 ~NGINEER: ~URTL4NO MEASURED DEPTH BELOW KB m ORIGZN: LATiTIU~.E TVD FROM KB SUB-SE~ SURFACE LOC&TiON ~T 60.?95B~SEC ll~TON~R13W RECTANGULAR COORDINATES NORTH/SOUTH E~ST/WEST 10863.00 10112.79 9995.T9 2907.70 N 143.16 E AT TD: SUB-SEA VERTIC&L DEPTH 9996.79 HORIZ9NTAL DISTANCE mEET 2911,23 DEPARTURE AZIMUTH OEG MIN N 2 49 FT -SCHLUMBERGER O I RECT I ONAL SURVEY' COMPANY SHELL WESTERN E & P INC. WELL MOS A-41-11 F I ELD M I DOLE GROUND SHOI::>AL COUNTRY USA RUN ONE DATE LOOOED REFERENCE 000070929 WELL NAME: SHELL A MGS A-41-11 SURFACE LOCATION: SHELL PLATFORM A LEG 4 CONDUCTOR 31, Sll, TSN, R13W -600 0 0 SOO ]000 !50(I 2000 VERTICAL PROJECTION PROJECT Z0N ON VERT[CRL PLRNE NORTH - SOUTH SCI:IL. 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H...?...;....4..4...b,...i .-.;.¢~4.......+~-b;.., -~..*...&..~...,-~.*-4-.i....-L.i..i..i......i-~...~...i......i.i ~ ~...~_~_ ~.i.i~ Z& { ~ ~ ' ~: .~ : : ~ : '. ~' "T"T'"T%-"T"'r"T'"T"' ?'T"?T'"'~"'T'"r'T']]'"T"r"t'"~ ,,, ....... : .... , ................ = ,., ..... ........ ?.?.i?i. Li, ............. ....................... I'IT''t'~'I'~I' ''?'t'll''l?- "'?'t"'--t ........ t'''?l?+''' '~''4'"~ ....... t+'i--?' '~"~''~"m' '"~''i'''~''~ll' 'l'i''';'''~.;,.''...i...;l..~.~l..,. ~. '&ll] .. ' --i' ~ . ' ~ ~ i * ' ]. ~ ~ ~ [ 2 : :"~ i : I , ' I ......... [ ' '. : : I ' ' ~ ~i i i ' j i ..... i ' : I "I ] ...... I ....... I Y: : : : ' ' T? .'~''??': -20~ - 1S00 - 1 aaa -S~ O SOO 1 aa0 I SOO ZOOO ~E~ E~ 6C1~L£-- !/~120 XN/FT HORIZONTAL PROJECTION LOCATED IN THE APPENDIX [~ WFL 1~ IPR LOG CALIPER SURVEY [~. VOLAN CURVE DATA [~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER:., Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, 'WEL~ mArnE AND NUMB ~.Rt Reports and Materials to be received by.. /~-~ ~' ~ D&t~ - Required Date Received Remarks , Completion Report ~,~. ~ ~ ..... ~.[__ .~.~ ~R.~7~__. Sample s ~. ~ '? ,.~,. /...., .. _ ~~,"~...f~ dS,' ? "" :':"' ' ' " ' "' ~ ~ ." ~, ~ ~, .,'~> .,., ~....,~ Core uesc~pc~on .., ..... .... .... ...... , ~ " :,' Inclination Survey Directional Survey , ,, , , ,, ,Production Test Reports I Digitized Data SHELL DEVELOPMENT COIdPANY PETROPHYS ICAL SERVICES LABORATORY CATION EXCHANGE CAPACITY FEBRUARY 27, 1986 SHELL NI~STERN E&P INC. WELL A-41-11 MIDDLE GROUND SHOAL FIELD ALASKA API # 50-733-20378-0000 SAMPLE NO DEPTH '( FEET ) 5 6,619' 2" 15 6,632' 8" 21 6,640' 2" 25 6,644' 1" m~-- mm m C.E.C. (meq/1001~) 1.701 3.252 1.144 1.456 RECEIVED MAR 1 8 1986 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the fol lowing material which was transmitted via is hereby acknowledged: QUANT I TY DESCRIPTION DA TED: . -. Copy sent YES to sender · . SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 DECEMBER 20, 1985 SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 ~I..EA~E: REI~Ly TO 500 W.~~'~F6~"~PORT RD. ANCHO~GE, ALAS~ 99518 ATTN' BETH CUZZORT Gentlemen: Enclosed are 1BL nrintsof the PER,, .F~. ATING RECORD Company SHELL WESTI~RN E&P INC. , Well MGS A-4I-I 1 Field MIDDLE GROUND SHOAL , County. KENAI State ALASKA on: Additional prints are being sent to: 1BL -rints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 ATTN: R. J. VAL_LEJO , WCK 1134 / STATE~ OF ALASKA " ALASKA OIL & GAS CONSERVATION~OMM. 3001 PORCUPINE DR. ~ ANCHORAGE, ALASKA 9950.1_---~ ~ ....... 2BL orints SHELl. WESTERN E&P INC. 601W.FIFTH AVE;SUITE 810 ANCHORAGE~ ALASKA q9501 ATTN: JOE FRAM 1MYLAR 1BLorints ARCOALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 9950l ATTN: JOHN C. HAVARD 1BL -rints SHELL"PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NnD'~u STAR. o~.,,,.'~ #I P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~.prints -2RROLLED SEPIA P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN: J. L. WF-~VER prints The film is RETURNED TO SHELL (HOUSTON) . We appreciate the privilege of serving you. RECEIVED BY' DATE' ~,,~.-...-,~ ,,-,~ SCHLUMBE [ / A!aska 0il & Gas Cons. Commission Anchorage n~VlD ~_EBOL DISTRICT MANAG[R December 18, 198 5 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: NOVEMBER MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Gen tl emen: Please find the enclosed subject reports of Drilling and Workover Oper- ations for the month of November. The wells that were worked on during the month of November were A 22-14, A 41-11, A 14A-01 and C 23-26. Each enclosed monthly report is submitted in duplicate. Ver_~v truly yours, r~ Sr. S(~ff Environmental Engineer Alaska Division SBB/kka ,~,~ Enclosures RECEIVED DEC R ~,lgt~ Alaska Oil & Gas Cons. Comrnlsslol~ Anchorage SBBC/aogcc.2b STATE OF ALASKA ' 'ALASKA ~"". AND GAS CONSERVATION C~''~ 'MISSION MONTHLY REPORT i-,i= DRILLING AND WOR, OVER OPERATIONS Drilling well)~ Workover operation I"] 2. Name of operator Shell Western E & P Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 4. Location of Well atsurface Conductor 31 of Leg 4. of Sec. 11, T8N, R13W, S.M. 1559'N & 378'W of SE corner 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. !!6'KB I ADL 18754 7. Permit No. 85-174 8. APl Number so- 733-20378-00 9. Unit or Lease Name Middle Ground 10. Well No. A 41-11 11. Field and Pool Mi dd le Ground "G" Pool Shoal Shoal' For the Month of. November ,19 85 ,12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at months end' 10,863' 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE. 15. Logs run and depth where run NONE ! 6. DST data, perforating data, shows of H2S, miscellaneous data See attached worksheet for details of.the perforating. RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons, C0:tmissi0rl ' Anchorage ;~S,G.ED~~_----~----------~~~ TjT~EPrOOUCtion Superintendent D^TE t~_-/t~lA.~- NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filec~ in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1~0 WORKSHEET FOR MIDDLE GROUND SHOAL A 41-11 MONTHLY REPORT OF DRILLING & WORKOVER OPERATIONS 11/02 - 11/03/85 11/06/85 11/09/85 11/21 - 11/27/85 Fractured the Hemlock producing zone to open perforations in the HN-HR (10,120'-10,401'). Fractured the well to open perforations in the HN-HR and HK-HN (9,770'-10,075'). Ran completion string. Perforated the well at the following intervals: HR-HZ 10,614 HN-HR 10,400 10,100 HK-HN 9,720 HI-HK 9,430 9,400 HC-HD 9,176 9,096 -10,628 -10,430 -10,140 - 9,75O - 9,490 - 9,420 - 9,220 - 9,150 8,804 - 9,050 RECEIVED Alaska Oil & 6as Cons. (;omm~ssior~ A~]chorage ~,,," CHANGE, ___ BELETE DAILY INVENTORY TRANSACTION FORM~/ REQUESTED BY ~?,,.~...-': ~ ...... DATE ._~iz~t_.~_~,' ,, , '''''.__ _=_ ." .'./,' AUTHORIZED PTS HOUSE NUMBER '. ..':.,.'..,:...;: CURRENT JOB ORDER NUMBER _,"..z~!~.Z£'''''.'''c' ___RECEIVED ___SHIPHENT ___DELIVERY ___TR~SFER ___PICK-UP CARRIER REC o DATE .... / ..../ .... CLIENT'S ID, NUMBER (CRC INTERVAL PTS HOUSE NUMBER FROM INTERVAL QTY QTY QTY PLT TO F/M FROM 'fO O/H QTY TRANSACTION DATE LOCATION DESCRIPTION STATUS .... / .... / .... EXPIRATION DATE PTS HOUSE NUMBER 'i:il]'.,.',,.,___~_,_~_..,.,,___..=.,_~,_,,,..:~ .... ~...'=..' ,,"'~.~,' ....~..',..'c,.c. .... ~ .... ,..." .... ," ..... ,,~ .:~, ~ .... .,,~: ~:. .:?. ,.;; ,':.¥ ~;'., ,. INTERVAL INTERVAL QTY ~TY STY PLT FROM TO F/ti .FROM TO O/H QTY TRANSACTION gATE LOCATION DESCRIPTION INTERVAL PTS HOUSE NUMBER FROM ' LOCATION .DESCRIPTION ., STATUS INTERVAL QTY QTY TO . F/M "FROM TO STATUS . , QTY F'LT O/H QI'Y .__/ ..... /___ EXPIRATION DATE TRANSACTION DATE __/ .... / .... EXPIRATION DATE INTERVAL INTERVAL QTY ." .m. QI:~'." QI'Y PTS HOUSE NUMBER FROM TO F/M FROM 'TO O/H , , PL'T TRANSACTION QTY gATE LOCATION DESCRI'PTION .,;.'?' STATUS EXPIRATION gATE / / RECEIVED BY; ,.. DELIVERED' BYt,,., , ~'lm I'll; 'II.''m ..'m.:m''''% .... '''" I.I ' m ' ='' _~. _ .~_.," ,..~" '.~ _~__ -' .... ~_~.,~..~_ ~. ............. ..... ' ' -" "' ~ ' ;:'/ .... .;. ,Z,~.,-. REMARKS: """"' ...... '" '"' ' .......' ,"" DATE .... /_-L]/__.L_ WHITE: Original CANARY: Office PINK: Sample GOLD: File SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOIJ.~T~M. TEXAS 77001 DECEMBER 4,1985 PLEA~If RI'P~Y TO 500 W.'f~'~J~YS~I'L"~[I~PORT RD. ANCHOI~GE, ALASI~ 99518 ATTN: SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 Gentlemen: Enclosed are 1BL prints of the PERFORATING RECORD Company SHELL WESTERN E&P INC. , Well MGS A-41-11 Field. MIDDLE GROUND SHOAL Additionol prints ore being sent to: IBL nrints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 ATTN: R.J.VALLEJO ,WCK 1134 .,County KENAI ~;tat, ALASKA 1~t~3'[.DED SEPIA /'~tBL-nrints "' '" {' STATEr OF ALASKA . A AS A · CAS CONSeCrATe0. CO . ANCH~A~ 9~50-t ...... ATTN' H.~. KUGLER 2BL orints SHELL WESTERN E&P INC. 601 W.FIFTH AVE;SUITE 810 ANCHORAGE~ ALASKA 99501 ATTN' JOE FRAM 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints SHELL r PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE =" P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~prints --2RROLLED SEPIA P.O. BOX 107839 ANCHORAGE, ALASKA 9.9 510 ATTN: J.L. WEAVER prints The film is RETURNED TO SHELL (HOUSTON) We appreciate the privilege of serving you. ~as Cons. Anchorage Very truly yours, SCHLUMBERGER OFFSHORE SERVICES so~-I qS$.A DAVID _REBOL DISTRICT MANAG[R November 26, 1985 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: Gentlemen' OCTOBER MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Please find the enclosed monthly report of Drilling and Workover Oper- ations for our Middle Ground Shoal well. The well that was worked on during the month of October was A41-11. Each report is submitted in duplicate. V~V tru 1 y you rs, Sr. S~f Environmental Engineer Alask~ Division DLY/kka Enclosures RECEIVED ,.. ~.'-'~ 0 .:'~ 1985 Alaska 011 & Gas Cons. CommissioE An,d~orage ........ SBBB/aogccO. 1 STATE OF ALASKA ALASKA(' _AND GAS CONSERVATION C(~"' MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation I--I 2. Name of operator 7. Permit No. Shell Western E&P Inc. 85-174 3. Address 8. APl Number 601 W~st 5th Avenue, Suite 810 Anchorage, AK 99501 50_733-20378 9. Unit or Lease Name W of SE corner of SEC. 11, T8N, Middle Ground Shoal 4. Location of Well at surface 1559 ' N, 378 ' R13W, S. M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 116' KB ADL 18754 10. Well No. A 41-11 11. Field and Pool Midd,l,.e Ground "G" Pool Shoal For the Month of. October ,~9 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Beginning Depth' 7,260' Footage Drilled- 3,603' Ending Depth' 10,863' 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" casing ru.n 7" liner run Date: 10-2-85 Date: # of joints: 182 # of joints: casing type: N-80 BTC type: shoe at: 7,266' shoe at: cement: 850 sx "G" : add.cement: ll~.e]:~r~m~ ~s~me and brief description i 0'- 03 - 85 t e s t'e d: tested to': 2000 psi tested to: 1'0-23-85 95 P-1.10 & 10,946' 1390 sx i0-24-85 2100 psi N-80 "G" + add. CORING RESUME AND BRIEF DESCRIPTION 10-01-85 shot sidewal! cores in F sands 10-21;85 shot sidew.all core samples 15. Logs run and depth where run Date: 10-19-85 Type DIFL/BHC-AL/GE CN/CDL/CAL/GR Depth TD TD ,16. DST data, perforating data, shows of H2S, miscellaneous data none RIECF_iVED 1985 Alaska 0il & Gas Cons. C0mmlssi0m Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. LSIGNED¥-~~ TITLE Div. Dri 11 ing Engr. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with' the Alaska' Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 October 25, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: SEPTEMBER MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Gentlemen: Please find the enclosed monthly report of Drilling and Workover Oper- ations for our Middle Ground Shoal wells. The wells that were worked on during the month of September were A22-14 and A41-11. Each report is submitted in duplicate. Very truly yours, D. L. Y'esland Sr. Staff Environmental Engineer Alaska Division DLY/kka Enclosures RECEIVED NOV 2, 9 !.qB5 A!2sk2 oil & Gas Cons. Comm)ssion Anchorag~ SBBB/aogccS. 1 " STATE OF ALASKA , ' ALASKA'(' _ AND GAS CONSERVATION CQ[."-- .vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [~] Workover operation [] 2. Name of operator 7. Permit No. Shell Western E & P Inc. 85-174 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 50- 733-20378 4. Location of Well atsurface 1559'N & 378'W of SE comer of Sec. 11, TSN, R13W, SM 5. Elevatil~in ~t (indicate KB, DF, etc.) 16. Lease~gL ~)~,~ation and Serial No. 9. Unit or Lease Name Middle Ground Shoal 10. Well No. A 41-11 11. Field and Pool Middle Ground Shoal "G" Pool For the Month of. Septenber ,19 85 ..'12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Fishing Job: 9/2/85 - 9/8/85 Spud Date: 9/9/85 Kick off Depth: 237' 'FOotage Drilled: 7023' Ending Depth: 7260' 13. Casing or liner run and quantities of cement, results of pressure tests Set kick off plug: 9/09/85 (see attached worksheet for details). Set 20" casing: 9/11/85 (see attached worksheet for details). Set plug: 9/14/85 '(see attached worksheet for details). Set 13 3/8" casing: 9/16/85 (see attached worksheet for details). 14. Coring resume and brief description For sidewal 1 core record please see attached. 15. Logs run and depth where run Date Type 9/29/85 DIFL/BHC/GR/SP 9/29/ 5 CN/CDL/GR/C 9/29/85 Flvrr 9129185 Sk5 Depths From 1808' to 7150' · From 1808' to 7150' From 5800' to 71zK)' From 5800' to 7150' :,16. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. AgC~0.~'~[J',~ ....... ,-', .... . SIGNED,~ TITLEDiV;iS:[on Dr~]].~n(] ~K]~rL<L~]P DATE / / {~/,~.% . ~ ~ ~ ~, f ... ~: . NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filea 'in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate WORKSHEET FOR MGS A 41-11 Kick off Plug Date Set: Set At: Cement: Top of Cement: 09/09/85 259* 400 sx Neat + 2~ CaCl2 180' 2o" casing Strlng Date Set: Set At: Casing Type: Cement: Top of Cement: 09/11/85 328* 94 #/ft, H-40 BTC 735 sx *'G" + 2~, CaC12 O* Plug Date Set: Set At: Cement: Top of Cement: 09/14/84 635 * 200 sx "6" + 2~ CaC12 497* 13 3/8" Casing String Date Set: Set At: Casing Type: Cement: Top of Cement: 09/16/85 1808' 61 #/ft, K-55 BTC 700 sx "G' + additives 0* RETAIN THIS SECTION FOR YOUR RECORDS RE MGS A41-11 2" BHC COMPOSITE ,'1. PRINTS PRINTS PRINTS PRINTS ABOVE RECEIVED FROM: DRESSER A.TT: JOHN BOYLE SIGNED Al 0 NEG. 1 SEPIA NEG. SEPIA NEG. SEPIA NEG. SEPIA \ NOV 2 ? 1985 ~')d & (.~s Cons. l~[llffiissiori Anchorage STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via l.e~ /~~ ~_ is hereby acknowledged: QUANTITY DESCRIPTION Copy sent to sender YES NO ~ RE · . RETAIN THIS SECTION FOR YOUR RECORDS ,'..iC~.~D.* I 'OF 2' COM=COMPOSITE OF RUN 1 &'2 OPEN HOLE PARTIAL COMPOSITES MGS A41-11 (S1~ELL~ 5" FMT R. 1 & R. 2___ ___1_ PRINTS _ EL NEG. 5~t-ARM CALIPER RL2 ] PRINTS O NEG. 5'~' DIP RAW DATA R.2 ~ PRINTS __-0- NEG. 2"5"COMP 4-ARM DIP__R. 2_ ]_ PRINTS ___-0- NEG. 0 1 SEPIA !- SERA 1., SEPIA ~ SEPIA 2" C0M DIFL,BHC,CN/CDL~ 1 ,~ c~ ~=~ ....... ABOVE RECEIVED FROM: '%TVDS_ D R ESS E R A~T: JOHN BOYLE ~ ......... · .~ SIGNED .' .... '. , '.,'.~.,'..~ SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 HOUSTON. TEXAS 77001 NOVEMBER 12,1985 P~EASE R[P~Y TO ANCHORAGE, ALASKA 99518 ATTN: BETH CUZZORT Gentlemen: Enclosed ore 1BL prints of the Coml~ny SHELL WESTERN E&P INC. , Well MGS A-4i-11 Field MIDDLE GROUND SHOAL , County KENAI Additionol prints ore being sent to: IBL nrints SHELL. WESTERN E&P INC. P.O. BOX 527 HOUSTON~ TX. 77001 ATTN: R.J. VALLEJO , WCK 113~ C :GYRO WELL SURVEY & TEMP LOG~ ¢2) State__ALASKA /' STATE' OF ALASKA ~ [ ALASKA OIL & GAS CONSERVAT/ION COMM. \ 3001 PORCUPINE DR. ~,,ANCHORAGE. ALASKA ~N.:-_. H. W .... 2BL nrints SHELL WESTERN E&P INC. 601 W.FIFTH AVE;SUITE 810 ANCHORAGE., ALASKA 99501 ATTN- JOE FRAM 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN' JOHN C. HAVARD 1BL nrints' SHELL' PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE #1 P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~.prints 1RROLLED SEPIA ~r~)r~, U.S.A., INC. P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN: J.L. WEAVER prints The film is RETURNED TO SHELL ( HOUSTON ) We appreciate the privilege of serving you. RECEIVED BY ;~ ~ ~/r ~'"1 t ! r r~ Alaska Oil & Gas Cons. Commission Anchorage Very truly yours, SCHLUMBERGER OFFSHORE SERVICES SOS--ISeS-A DAV! O _REBOI, DISTRICT MANAGI'R November 7, 1985 ,F Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT. GYROSURVEY FOR MGS A 41-11 Attached is the Gyrosurvey for the recently drilled Middle Ground Shoal well A41-11 (permit #85-174). If any further questions arise, contact Susan Brown at (907) 263-9613. Very truly yours, ~ for: D. L. Yesland Sr. Staff Environmental Engineer Alaska Division SBB/kka RECEIVED Aleske Oil & Gas Cons, Commission Anchore,qe SBBC/aogcc. la STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted ~ ~ ~ ~/--// is hereby acknowledged: Q,U. ANTITY DESCRIPTION .f DATED: Copy sent to se~de.r YES NO ,~,~ ,, STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: ' ' 1985 CA 90670-2289- I1_ Receipt of the following ma,.,=~. ........ i~ ~; 5 ~ - q /- // ~ ~UANTITY ~---~~ted via is hereby acknowledged: DESCRIPTION RECEIVED: " ' .' ~ DATED. Copy sent to sender YES NO ~ August 28, 1985 Mr. Brian Kuehne Division Drilling Engineer Shell Western E&P !nc. 601 W. Fifth Street, Suite 810 Anchorage, Alaska 99501-2257 Re: Middle Ground Shoal A 41-11 Shell Western E&P Inc. Permit No. 85-174 Sur. Loc. 1559'N, 378'W of SE er Sec. 11, T8N, R13W, SM. Btmhole Loc. 4680'N, 430'W of SE cr Sec. 11, T8N, R13W, SM. Dear Mr. Kuehne: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description· of each core and a one cubic 'inch size chip from each foot of' recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25~050(b)(5). If available, a tape containing the digitized.log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter · surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or' migration.of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office., Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~ commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Brian Kuehne ' Middle Ground Shoal A 41-11 -2- August 28, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission. be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H.' Lamoreaux Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 August 8, 1985 Mr. M. Minder~ State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT- A12A-01 SAMPLES Dear Mr. Minders' In your conversation on August 5, 1985 with Mr. Ed Unger (our office), ditch cutting samples were discussed. Shell Western E&P Inc. (SWEPI) has conducted an investigation in which no ditch cutting samples were found. If there are further questions, please contact Susan Brown of our staff at (907) 263-9613. SBB/kka · t~¥tt t ' "ental Engineer Al ask~ Di vi si on RECEIVED AUG 1 6 ~ Alasl<a 0il & Gas Cons. Commission Anchorage SBBB/aogcc1.5 L STATE Of ALASKA O(I ALASKA ,L AND GAS CONSERVATION C .,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL IZ] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I-1 REDRILL [] DEVELOPMENT OIL[~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Shell'Western E & P Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchorage. AK 99501 ._ 4. Location of well[~t surf&ce 9. Unit or lease name a[Torm A, Leg 4, Conductor 31, 1559'N & 378'W of Middle Ground Shoal At top of proposeSdF-'prgo~l~lgei]~t'ervalSec° 11= T8N, R13W. lO. Well number At 8120' TVD. 4300'N & 950'W of SE Corner. Sec.11 A 41-11 11. Field and pool At total depth At 10,120' TVD. 4680'N & 430'W of SE co~'.R~' L1 Middle Ground Shoal 5. Elevation in feet (india:ate KB, DF etc.) ] 6. Lease designation and serial nde.8''{ , RI3W 116'KBI ADL 18754 "G" Pool 12. Bond information (see2OAAC25.025) Statewide - INA' Shell 0084 $500,000 Type Oil & Gas S,,retvand/or.umber 11C 136503 Amount $100,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or comPleted 17 miles NW of Kenai miles 2'275 feet Well A 11-12 13713 feet 1'6'.' P'roposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 13,656' (11,500' TVD) feet 3746 ___September 7,1985 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures lbl~ ' psig@__ Surface KICK OFF POINT 400 feet. MAXIMUM HOLEANGLE 23 ° I (see 20 AAC 25'035 (c) (2) 5980 psigc~l,500ft. TD(TVD) 21 Proposed Casing, Liner and Cementing Program -- SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT , , --Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 26" 20" 94# H-40 STC 300' 13 I n .300! 300 I 17 1/2 '13 3/8' 61# K-55 BTC 1744' 0 ~ 13 1744't 1700 10545x. class "G"+8% 12 1/4' 9 5/8'43 5/47# N-80 LTC 6583' 0 ~ 13 6538~' 6200 800ex class "G"+ael/ 8 1/2 7" 26# N-80 LTC 5756' 6261' ~5900' 13,656'!11,500'19005x.. class "G" I ~ I 22. Describe proposed program: P1 ease see attachments 'for' detai 1 s. RECEIVED AUG 2 2,1985 Alaska 0il & Gas Cons. Commission Anchorage ..23. I hereby certify that the foregoing is true and correct to the best of my knowledge S,GNE~' ~--~--~"~2~ TITLE Div. Drilling Fng~n... DATE Auqust 21.198 The space below for Commismon use CONDITIONS OF APPROVAL Sampl---es required Mud Icg required Directional Survey Cequired I APl number ~YES F-INO []YES ~'N 0 ,~YES ~0I Permit number Approval date --.- 08/.28./8 APPROVEDBYy/~~---- --// ~'~ ~,~L?. / -- ,,COMMISSIONER DATE ~ ,~r., ~~,~ by order of the Commission el el 10~ Form 10-401 / / Submit in triplicate Rev. 7-1-80 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 August 21, 1985 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Harold Hedlund 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: REVISED APPLICATION FOR PERMIT TO DRILL Per my telephone conversation with Harold Hedlund on August 21, 1985, the revised application for permit to drill is enclosed. The revised form is for the upcoming Middle Ground Shoal well #A41-11. If further information on this subject is required, contact me at (907) 263-9613. SBB/kka Very truly yours, S. B. Brown SEC Department Alaska Division Enclosure SBBB/aogcc7.3 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 August 19, 1985 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Harold Hedlund 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: MIDDLE GROUND SHOAL FIELD WELL A41-11 Please find the attached wellbore for the upcoming Middle Ground Shoal well # A41-11. If there are further questions, please contact me at (907) 263-9613. Very truly yours, S. B. Brown SEC Department Alaska Division SBB/kka Attachment RECEIVED A)a.ska OJ[ & Gas Oons, oommission Anchorage SBBB/aogcc2.3 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 July 29, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT' MIDDLE GROUND SHOAL FIELD WELL A41-11 Gentlemen' In a recent telephone conversation between Harold Hedlund (AOGCC) and myself, several questions arose concerning the upcoming Middle Ground Shoal well # A41-11. Mr. Hedlund asked questions concerning the history of the work and the origin of the fish. He also asked when the BOP's will be hooked up and tested. A concern was also expressed about the proximity of other wells to this one (this will be addressed under separate cover). In answer to these questions, at the time that the MGS field was being developed several conductors were set, to allow for future wells. This particular conductor has not been used to drill any wells. When the conductor was set, the fish was accidentally cemented in place. We plan to wash over it to recover it. (Please see attached diagram for additional information. ) The BOP's will be hooked up when the 12¼" hole is ready to be drilled. The BOP's will be tested to 3000 psi with the exception of the annular preventer, which will be tested to 1500 psi. Additionally, the casing will be tested to 1500 psi. The APD processing fee of $100 for #A41-11 was omitted from the envelope containing the APD. A check for this amount is enclosed. SBBB/aogcc2.2 RECEIVED. .uG o 19l 5 Oil & Gas Cons, Oommission Anchorage Middle Ground Shoal Field Well A41-11 If there are further questions, please contact Susan Brown of our staff at (907) 263-9613. SBB/kka Very tr~uly yours, ~ · D. L. Y~land ~ Sr. St~ff~ Environmental Engineer Pacifi~Frontier Division Enclosure RECEIVED Alaska Oil & Gas Cons. Commission, Anchorage SBBB/aogcc2.2 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 July 12, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen' Attached please find three copies of an Application for Permit to Drill Well No. A41-11 in the Middle Ground Shoal Field, Cook Inlet, Alaska. A41-11 will be drilled from Shell Western E & P, Inc.'s (SWEPI's) Platform "A" Leg 4 Conductor 31 A permit for drilling as deep as 13,656' (11,500' TVD) is requested although the current prognosis calls for a total depth of only 12,017' (10,120' TVD). The expected spud date is August 15, 1985. V er~y trudlY yours, .-, .,, ./~ . ~ ,. ~, .~ ,~' J.~' .... .~ ~,'/...~U .~"~"/'" ~,', v' ,'. .,.~.;~"'' D L. YeT?and , Pacific Frontier ~vJs~on SBB/kka Attachment cc' B. D. Kuehne RECEIVED JUL 1 8 Alaska 0il ,& I~as Cons, Commission Anchorage SBBB/aogccl.1 ALASKA ;L AND GAS CONSERVATION C ,.MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL~ SINGLE ZoNEX~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Shell Western E&P Inc. 3. Address 601 West Fifth Avenue.,__Suite 810; Anchorage, Alaska 99501 4. Location of well at surface 9. Unit or lease name Platform A, Leg 4, Conductor 31, 1559'N & 378'W of SE Middle Ground Shoal At top of proposed producing interval Corner. Sec 11, T8N, R13W lO. Well number At 8120' TVD. 4300'N & 950'W of SE Corner. Sec 11, T8N, A 41-11 At total depth R13W. 11. Field and pool At 10,120' TVD. 4680'N 7 430 W of SE Corner. Sec 11, T81~., R13~:,'. Middle Ground Shoal 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. iIGiI Pool 116' KBI ADL 18754 ~2. Bond ~nformation (see 2O AAc 2S.025) Statewide - INA Shel 1 0084 $500,000 Tvpe__.0il & Gas' Surety and/or number 11C 136503 Amount $100.000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed _[Z__Mil es NW of Kenai miles ??.7.~ feet Well A 1 1 -12 1.'{~r) feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Appro_xim_a_te spud da,~tefl,~-~ .. 12,017' / 10.120 feet 3746 ~. 1985. 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~19 psiS@ _~Surface KICKOFF POINT 400 feet. MAXIMUM HOLEANGLE ~3 °l(see20AAC2B'035 (c) (2) 5262 ' psig@[0,120ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program -~IZE CASING AN ~) LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight ' Grade Coupling Length MD TOp TVD MD BOTTOM TVD ' (include stage data) ?R" ?N" q4~ H-4N ~T£ ~Nr~, N I 0 300' ~, 300' 244~x. 'Cla_~ "A"+8% a~ _ 171/2"1.~ .~/R" ~1~ K-.~E RT£ 174Zt~ O i , 0 1744' ~ 1700' .054ex. Class "G"+8% q( 1.2 1/4" q. ~/e,, [_~ _~/aT~N-80 II TC ~;.~R3'l~..O ~ ~q 6583' 16200" 800ex. "G"+8%gel/100s) R 1/?" 7"- '-~;f"' N-R0 ~IZT~ 5756'~'~,.:. 6261' i ,E~900.,12.017!'10,120 1900ex. "G" 22. Describe proposed program: ~ ,~,.?~/,. ', ',i';",.",," Please see attac "' hments ~',ii~or ~ia'~,'s./ · "' '"i!' ,. p,,ECEIYED ' \', :~, ~;~.';, ,; .t,: ' ' .' ' , / ,..,,' '~':/ ~~..'.' ' " ~J~Jaska 0il & Gas C0~s. 60mmissi0~ ..23. I hereby e~rtify!that the",i~j3r~oing is tj:~e and t to the best of my knowledge I,.,,4/, /' , ,,," .." 7 SIGNED ¢~'" ,"'~'~r'" ,~/)~'~ ,,~f~_~,r, TITLE Sr Staff Environment Er~C. TE Qul V 12 1985 The space 6elJF~v foC'(~om¢ion ~se i' U CONDITIONS OF APPROVAL ~ Saj;npl--es required Mud log required Directional Survey required I APl number ~ ~_~ES ~'NO r-]YES I~-NO J;;~LYES I-]NOI 50- ¢ ~--~'-' Perh3it number Approval date ~/~' --I 7~ SEE COVER LETTER FOR OTHER REQUIREMENTS .... APPROVED BY , ,COMMISSIONER DATE by order of the Commission ,1 !1 .G Form 10-401 ' Submit in triplicate Rev. 7-1-80 Alaska Oil & Gas Conservation Commission July 10, 1985 ATTACHMENT The maximum pressure gradient is expected to be .520 psi/ft. Maximum BHP is expected to be .520 x 10,120 = 5,262 psi. Maximum surface pressure is expected to be 1,619 psi, assuming a full column of .360 psi/ft, oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations issued July, 1981. As noted in the drawing of the diverter, both 6" mechanical valves will be kept in an open position until the preventer is closed. The mechan- ical valves will be wired open and tagged with instructions concerning proper procedures for closing a valve in the event that the preventer is closed. RECEIVED J U L 1 8 1985 Alaska Oil ,& Gas Cons. Commission , ~Anchorage, SBBB/aodl Alaska Oil & Gas Conservation Commission July 10, 1985 A-41-11 1) Move rig over conductor 31, leg 4. 2) Recover shallow fish. 3) Drill 26" hole to 325' or 325 TVD. 4) 5) Set 20" casing and cement to surface. Directionally drill 17-½" hole to 13-3/8" casing point.- /~"'," . 6) Set 13-3/8" casing at 1700' TVD and cement to surface. /.~_c7,~z.}.' E ~.~ ?,~=_. _ ..¢~'. /:y Directionally drill 12-¼" hole to 9-5/8" casing point at 6200' TVD. 8) Attempt to run following wireline logs' DISFL, SP/FOC, GR, BHC, CNL-GR. 9) Set 9-5/8" casing and cement to 1000' above shallowest potentially productive sand. 10) Directionally drill 8-½" hole to TD. 11) Run casing caliper log to evaluate wear on 9-5/8" casing to determine whether a 7" liner or 7" full string should be run. 12) Attempt to run the following wireline logs' DISFL, SP/FDC, GR/BHC, CNL-GR, HRD/RFT. 13) Run 7" liner or full string and cement back to 6200' MD. 14) Proceed with production prognosis. R E C ElY 'JUL. 1 8 Igg5 Oil & Gas Cons Anchorage SBBB/dir ~0" ANNI~AR 10 B£ CC)I~N[CT[D SO VALVE Z$ OPE# AXNUL. AR PR['V(NT£R C:LOS£D DY'/R SPDDL &' LINE IIDTH 6" H[~]~ IrALV[S II']LL lie ,IN AH OPEN leSZTl~ I~l]L IE'LL IS ~LII' ]K AND PP, Z)PER I)]WRTER LllE IS S£LECT£D RECEIVED J U L 1 8 lsd-§ ~Uaska Oil & Gas Cons. Comraission Anchorage D]V[RTER ASS[I~LY 20" Ak'NULAR I;' AUfl:I~IED ITALY[ (w/&' LINE :Il SPIX)I. · - ~rr#~lrAI VAt VI' i ~t4ELL MINIIVlUM BOP ~TAC:K REQUIREMENTS . ,, Min. MI.. No. Item I.D. Nomlnel :2 Fill uP Line , , 3 Driltin~ Nipple 4 Annullr-I~venter ' 5 Two s~nL~le'or one duel ~¥dreultclll¥ Ol~rlted rims 6 Drilling spool with 2" Ind ~ min. outlets 7 G~te V.Ive 3-1/6" ~ Gete ~/ilve - Power Operated 3.~/8" 9 Line to choke menifold ' 3'; t0 Gete I~ '' ' V~lws 2.1/le" 11 Che~k ~/.Ive 2-i/i6" 14 Glte I~ ' Valve 1.13/16" 15 Compound pressure geuge connector. 16 Kill line to rig mud pump mlntfold 2" i i NOTE; Addltlonll mecIflcItlOnl for Sour Sewlce Ind AIr/OIl Sewlct Im glwn In Slqell Well Control Mlnull, Appendix g.1 '1 end S. lg. A rOtltlnt helCl 1hill be Drovlde~l o~ Air/Oil Service. ' OPTI~)NAL o, ;;o,., 17 Pl,n~ed control Dlug or velve 1'13116" ,, i · 18 Rot.tinq heed · '19 Glte wive · Power operltor DRAWING AND CHECK LIST 10'JA SHELL CLA~S 3M gURFACE INSTALLATIONS NORMAL OR ~OUR AIR/GAS * · POll AllllOAI OlllLLINQ CONFIGURATION A AWl. AN Im~V~II~R BLIND RAM MAY 31, 1985 PRC ! F I C D %LL%NG FRONTXER PROGNOS:I:S WEPI INTERES. T 33.33% HELL: A-41-11 LOCATION: Platform "A" OBJECTIVE: Hc - Hz EVALURTION , Leg 4, Conductor 31 GEOLOGY RFE NO: FIELD: MGS EST. ELEVRTION: DRILLING 116' ELEC. MUD CORES SURVEYS LOGGER O z SIGNIFICRNT FORMRTIONS 24" conductor 325- KOP~ 400- Angle built 1454- 13-3/8" csg. 1700- 9-5/8" csg. 6200- GN 7010- Turn right 7310- BC 8120- Complete turn 8260' Build angle Angle built 8490' HZ 9620' 7" liner 10120 NELL DEPTH TVD MD CASING AND CEMENT I "~2 -'400 - 1479 - 6261 - 6282 ' 6497 - 6583 - 7454 -7777 - 8650 - 8802 - 9055 - 11455 12017 HOLE DEV. HOLE RND DIR. SIZE CONTROL J 26" 17-1/2" 12-1/4" 8-1/2" m · %-O%- MUD PROGRAM mi i ~ el--. ~ CZ 0 .l"m 0 0 t]7 I ~ o~ ~o~ MGS PLATFORM A A41-11 {"' DRILLIN (" ATTACHMENT 2 CONSTRUCTION KB TOP OF LEG TOP OF DRILL PiPE MEAN LOW WAT TOTAL ISH ~ 126' 54' .CEMENT · · · · ~,~ o · ~. ,,~'. cHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ,, Fee. -:':-,' ]." .:" (2) "-: ~ cn X._. -.,' - L. Loc ,__.,,,' ,, .... (2 thru 8~)' '7 I,~ .. jr.:',,-. · /,~'._-,./j.~ (3) Admin (..,"-'- ..... ~'-' 9, ('9 thru 12) . lO. ~'"J'~/' ; ' '7~:C~:;,,,'"'., 7,T:~' 11 . '(10 and 1'2) ,' 12. (13 thru 21):' (5) BOPE _.,,,?~,Y,n /,/~.,:','....., '(22 thru;":26) · 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Geology: Eng~neerin~: IIWK _ .~ LCS "7~;'."~,/" 'BEW ~'"' WVA '-~ MTM ~ HJH ~/~ , JAL...:.~j;-~ ....... rev: 03/13/85 6,011. Company Lease & Well No.. 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ........... . 4. Is well located proper distance from other wells .. . 5. Is sufficient undedicated acreage available in this pool ' 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten'day wait ......................... Does operator have a bond in force ................................. Is a.conservation order needed ..... .............................. Is administrative approval needed '''''i'''i.''~'''''''''',~.~'''''' ''' '' ~~222~ ~ Is the lease number appropriate . . . YES NO Is conductor string provided eeee~eeeeeeeeeeeeeeeseeeeeeeee®eeeee,eee Is enough cement used to circulate on conductor and surface ...... ....~i~/ Will cement tie in surface and intermediate or production strings ... '" .... Will 11 k h cement cover a nown productive orizons ....................... Will surface casing protect fresh water zones .... , . Will all'casing give adequate safety in collapse, ;;~;i;~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ' Is ,a diverter system required .. Does BOPE have sufficient pressure rating - Test to .Z,.~,"~,...<> psig . Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of' H2S gas probable., ..................... ,.~ ....... Additional requirements ............................................. Add it ional~ ,, , Remarks:' / REMARKS 0 HO , ,, INITIAL GEO. UNIT ON/OFF .,. POOL CLASS STATUS AREA NO. SHORE .5'z ¥-/i~ Q.~...e 1 ~ :' ! ~ ~'~ o ~,~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. 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C ....~ ~ .~ .. , _ ...... · · · _.. ,._z ......, ..................... /, ............... ..,[..' .................. . : ....... · · , , '. . . .................... . ........................ LIBRARY TAPE CURVE SPECIFICATIONS t4i/¢.S A zt l- // Company SHELL WESTERN E & P Well MGS 41-11 Field MIDDLE GROUND SHOAL County, State KENAI, ALASKA -Date 10/25/85' Curve Name '(Abbrev.) standard Curve Name Logs'Used Scale ' .. .... ... .' ..... cALM" cALIPER ' cN/CDL ' ' 10 "' 20 GRM "GAMMA RAY ., .CN/CDL . · .. 0 · 100.... . · .. DENM BULK. DENSITY -'. · .CN/CDL '2 "' .' 3" · .. .. .. '. . .. ,co.' .~.. ,'..... · · ..... eOR~s~iON.".' '...' "..:'. ".. '..':.'. '...- ....... '". ...... .:.'" · ~leDn'." '""..' ~":'5 '.'"'.'.'......'.:"S ' '. .'... . .. . . '. . . . . .,. . .s~,... . ~'.s~'°~~.ouS""~o~~.' " .."'" ~.~,~./~,c/~c. .o.. ... . ~o..... , , : , · . , .. : .:. · . · . ... . .... . ..' ..' ...- GRIM. · , G~'PAy . , '' : ' ... ' " DIFL/BHc'/Ac', 0':. ..".. "'"' 100" · . . .. . . . . . 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"POROSITY . :' . . · · .. .K I'_ t t I.V. r' U . . .... .:. .. · co~ ,co~c~'~:o~ .'.' .... · .OCT..~ 9.1911~ ' ' · , . · SP' SPONTANEous pTOENTIAL · alasl(a Oil. & Ga~ ConS;'Commisslon · , ' Anc ~O.ra,qo . . PAGE 2 LIBRARY TAPE CURVE SPECIFICATIONS Company SHELL WESTERN E & P Well MGS 41-11 Field MIDDLE GROUND SHOAL County, State KENAI, ALASKA Date 10/25/85 .. Curve Name '(Abbrev.) Standard·,CurVe Name ·Logs,Used Scale REPEAT FILEs ( lCO~T, ) ' I I I I Il . , I I I I . . . . . , .. .... .. · ~ . '. ...... . . . . .... . ..... . : .. . . .. · . '.. . . . . .. . . . . . . . . . · . . . ..... . . . .. . . . . .. ... . . · . .. . . . . . . . .. . . . . . . . .~ ,' . · .. : . . .. : · ~.. .. . . . . . . . .. .. . . .' ' . . . . . . . · .. .~...... . . .. · . . · . . . ..... . .... . . . . . . ..... . ... '.: · .. .. '..' .. . . .~... . .. ' .'. '. ........... . .... .'. ' ... .' .. . . . . .. . . . . .. . . . . . . . .. . .. . 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