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Home My WebLink About185-235Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /~'2_~- ~,.,~_,~ Well History File Identifier Organization (done) ~.~TwoTSided RESCAN DIGITAL DATA ~)I~ Color items: ~.~~rn Diskettes, No. [] Grayscale items: [] Other, No/Type ~ Poor Quality Originals:('~0 , ~.~ ~ ~-----'~"~C..~', ., ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner ,0~Non-Scannable) ~' Logs of various kinds [] Other DATE: /SI Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl ., PAGES: ~ ~ (at the time of scanning) SCANNED BY: BEVERLY ~/INCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wlXl UNSCANNED, OVERSIZED MATERIALS AVAILABLE: I~~ a~ FILE # ~ P~h C~~~ ;~~uc ~, ~~ r ~,~ i a n ~U~ ~ c.~~~( a r~ rU ~-~ (~nP Q ~ G ~ ~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 • MEMORANDUM Toy Jim Regg ~ P.I. Supervisor ~ ~ ' Z I~ I ~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, December O1, 2009 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC A33-11 MGS A33-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~~--- Comm Well Name: MGS A33-11 API Well Number: 50-733-20383-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG091119123903 Permit Number: 185-235-0 Inspection Date: 11/17/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - - -- -- 'I'mo A33 11 T e In•. ~ ~' , Well - ~ -- 7120 ~IA I, 50 ~ ]840 -- 1790 800 ~ ----- ~ ias23so T eTest sPTT- IL Test psi , ~ ~YP ---~ 17ao '~OA 49 X52 - - - - - - -- 52 --- - s2 --- _ _ -- - --- P Interval 4YRTST P~F TUbin 3550 1 3600 ~ g --~- - -- 3600 3600 -- ~--- ---~------ _ _- ---- Notes: Good solid test k `` t ~.~`~tr~'~~~~ ' J I~ i~ ~tr G f~ 1 Tuesday, December O1, 2009 Page 1 of 1 Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: Monday, November 30, 2009 2:20 PM To: 'Barney_Phillips@xtoenergy.com ;Brooks, Phoebe L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com; Cody_Mishler@xtoenergy.com; Steve_Phipps@xtoenergy.com; Jeff_Gasch@xtoenergy.com Subject: RE: XTO Energy MGS Platform A and C -SVS and MIT Reports Barney, Thanks for the information. My comment is in particular with regard to the MIT on A platform. Based on the well file history, it does not appear that the well name and PTD number are correct for the A platform MIT. Although A33-11LS was the last penetration drilled in this "well", since perforations in the original well were retained (above the 4-1/2" liner top) it is not proper to report an MIT using the lateral identity. The name and permit number should be A33-11 and 185-235. I have changed the name and permit number on our copy and suggest you do the same. There is no need to resend the MIT. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Barney_Phillips@xtoenergy.com [mailto:Barney_Phillips@xtoenergy.com] Sent: Monday, November 30, 2009 12:54 PM To: Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com; Cody_Mishler@xtoenergy.com; Steve_Phipps@xtoenergy.com; Jeff_Gasch@xtoenergy.com Subject: XTO Energy MGS Platform A and C - SVS and MIT Reports (See attached file: SVS MGS C Platform 11-16-09.x1s)(See attached file: MIT MGS A 11-17-09.x1s)(See attached file: MIT MGS C 11-16-09.x1s)(See attached file: SVS MGS A Platform 11-17-09.x1s) Hello Phoebe, Please find attached the 180 day SVS tests for MGS Platform A & C as well as MIT reports for MGS C41-23LN and A33-11LS. Should you need any further information or have any questions, please reply to this e-mail or you can reach me at 776-5251 until Wednesday evening. You can reach me on my cell phone after that at 394-2454. Best regards, Barney Phillips barney_phillips@xtoenergy.com Platform A: 907-776-5241 Platform C: 907-776-5251 QE% 2 ~ 2009 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: XTO Energy MGS Platform A 11 /17109 B. Phillips Lou Grimaldi `~~3 J - Packer De th Pretest Initial 15 Min. 30 Min. ell A33-11 T e In~. W TVD 7,120' Tubin 3,550 3,600 3,600 3,600 Interval 4 P. .D. 185-235 T e test P Test si 1780 Casin 50 1,840 1,800 1,790 P/F P Not OA 49 52 52 52 Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T etest Test si Casin PIF Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T test Test si Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 11/27/07 MIT MGS A 11-17-09 (tem-edit).xls MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission OK (. DATE: Tuesday, November 22,2005 TO: Jun Regg -;? i{ -z.,5 05 ." _ _ __f.l.-B.\!P_eLYisPL_l_~1__~ ____ ~uB.!~!.:~t:C~~~lr1te~!1t}' Ie~__ XTO ENERGY INC A33-11 MGS A33-11 FROM: Chuck Scheve Petroleum Inspector ---.p0-.-- .- . ...-..-.- . . \ f6 ç~ Src: Inspector Reviewed By: P.I. Suprv :JBrz-- Comm NON-CONFIDENTIAL Well Name: MGS A33-l1 API Well Number 50-733-20383-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS051121102947 Permit Number: 185-235-0 Inspection Date: 11115/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j A33-11 !Type Inj. j W i TVD I 7118 I IA I 50 ! 2050 I 2025 I 2025 i I I , I P.T. ! 1852350 iTypeTest! SPT! Test psi i 1779.5 lOA! 40 I 40 I 40 ! 40 I I . I ! Interval 4YRTST P/F p Tubing I 3550 I 3550 i 3550 i 3550 ! I Notes Pretest pressures observed and found stable. <;,,;{(J~¡"'~h\·\rËr . ~~q"l:~t:. >itk....> ( " Tuesday, November 22, 2005 Page 1 of 1 -- STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Pull tubing X After casing Plugging Perforate Convert to Repair well Other X Inject ion 2. Name of Operator 3. Address 3000 N. 6~rfield, Ste 175, Midlar~, TX 79705 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface Platform A, Leg 4, Cond 25, 1571'N & 385'W fr~n SE Oorner, Sec. 11, T8N, R13W, S.M. At top of productive interval 7438' 1648'N & 1933'W of Surface location At effective depth 9848' 45'N & 922' W of Surface Location At total depth 9930' 40'N & 897' W of Surface Location 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name 8. Well number 433-11 feet 9. Permit numbedapprov.al,C~L~ber~ .~ 10. APl number 50- 733-20383-61 11. Field/Pool ~ E, F, G Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 1712 ' 6441' 3791' measured 9930 feet 9628 feet 9848 feet 9550 feet Length Size Plugs (measured) Junk (measured) Cemented ~3-3/8" 61# 9-5/8"43.5/47# N/LB0 7" 26/32# NS0/Pl10 Measured depth True vertical depth 710 S~ 1712' 1685' 525 Sx 6441' 6245' 1590 SX 6137-9928' 5948-9627' 7438-9210' truevertical 7235-8946' Tubing(size, grade, and measureddepth) 2-7/8" 7.9#.~S-6 LB0 @ 8190' Packersand SSSV(~peand measureddepth) 7" ~ "SE-3" ~ @ 7322' a 7" Bake= "I]B" ~ ~. A~¥r80~ 13. Stimulation or cement squeeze summary Intervals treated (measured) 8220-9210' Treatment description including volumes used and final pressure Bullhead 48 bbl 10% ~ w/Xlrlene into 4-1/2" slotted liner & 7" ~ casJr~. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation Subsequent to operation 167 100 15 515 80 1949 0 2650 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Paul Figel Title ~r. Operations Enoineer Date 8/7/2002 SUBMIT IN DUPLICATE~ AU8 8 2002 'TO E~N~£ R Gy MGS A33-11 LS Cook Inlet,, Alaska Leg 4, Conductor 25 APl No.: 50-733-20383-61 Spud: Original Hole on 12-5-83 Sidetrack on 1-18-94 24" Conductor Csg @ 370' Surf Csg: 13 3/8" 61# K55. Set @1,712'. Cmt w/660 sx. (50 sx top job) Inter Csg: 9 5/8" 43.5 & 47# N80/L80. Set @ 6,441'. Cmt w/525 sx. Surf - 3,696': 43.5# N80 3,696 - 6,441': 47# L80 Current Completion PLF 8-7-02 KB: 116' Water Depth: Tbg: 2 7/8" 7.9# RTS-6 L80 @ 8,190' Set 12-10-01 Otis R Nipple (2.188" ID) 9Cr @ 332' . Otis R Nipple (2.188" ID) 9Cr @ 7,309' 10' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr X-Over RTS-6 to 2 7/8" EUE @ 7,320' "E" Anchor (80-32) L80 @ 7,321' 7" Baker SB-3 Pkr (84-32) 9Cr @ 7,322' 6' Millout Ext. LTC 14Cr @ 7,326' XO 4.5" LTC Box to 2 7/8" RTS-6 10' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr Otis R Nipple (2.188" ID) 9Cr @ 7,342' 10' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr @ 8,153' Locator 5' Bonded Seals (80-32) @ 8,163' 7" Baker DB Pkr (84-32) LB0 @ 8,164' 4' Sealbore Ext9 Cr @ 8,168' XO Acme Box to 2 7/8" RTS-6 10' Pup Jt. 2 7/8" 7.9# RTS-6 9Cr Otis RN Nipple (2.01" ID) 9Cr @ 8,183' 6' Pup Jt. 2 7/8" 7.9# RTS-6 L80 WL Re-entry Guide @ 8,189' Liner: 7" 26 & 32# N80/P110 @ 9,928'. TOL @ 6,137'. Cmt w/1,500 sx. Sqz TOL w/90 sx. 6,137 - 7,775': 26# N80 7,775 - 9,928': 32# P110 Slotted Liner: 4 1/2" 11.6# N80 @ 11,498'. TOL @ 8,723' MD Hy-FIo2 Hangar @ 8,741' Liner Packer @ 8,736' I I TD: 11,501' MD (9,921' TVD) J J I I I I I I GN-GO: 7438-7465(5/26/94) GR-GS: 7895-7924 (5/26/94) HC-HD: 8220'-8324' HD-HE: 8350'-8370' HE-HF: 8419'-8442' HI-HK: 8540'-8582' HK-HN: 8596'-8740' (40 Holes) HN-HR: 8810'-8990' (40 Holes) HR-HZ: 9050'-9210' (37 Holes) HN-HR & HR-HZ flow thru whipstock Bkr D pkr & Weatherford FIo-Thru Whipstock @ 8,806'. 400' TCP Gun Dropped in Rat Hole PBTD: 9,848' MD, 9,550' TVD TD: 9,930' MD, 9,628' TVD MIDDLE GROUND SHOAL A, WELL #33-11LS AFE %: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/03/01 FIRST REPORT FOR AFE %101391 TO CONVERT WELL TO INJ. Pulled btm GLV @ 7,191' Moving rig fr/MGS All-01 leg %1 to MGS A33- 11 leg %4. DWC: $11,554 CWC: $11,554 AFE ~: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/04/01 Fin skidding rig over to MGS A33-11LS. Rigging up. Repr'd high drum clutch while RU mud lines & top drive. DWC: $18,065 CWC: $29,619 AFE #: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/05/01 Cont'd RU mud lines & flowlines. XTO conducted drug & alcohol search on platform. RU mud line & flowlines. RU to kill well. Killed well w/FIW. Set BPV & ND tree. Set riser & NU BOP. DWC: $18,126 CWC: $47,745 AFE #: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/06/01 Fin NU BOP. Press tstd BOP to 250-5,000 psig, tstd OK. Winton Aubert w/AOGCC waived witnessing of BOP tst. Pulled BPV. Pulled tbg hanger & tbg was free. Pulled & LD 3-1/2", 9.3%, 8rd tbg (checking for 'norm). DWC: $19,457 CWC: $67,202 AFE #: 101391 Objective: Convert Well to Injection 12/07/01 Fin LD 3-1/2", 9.3%, 8rd tbg. RD tbg tongs. FIRST REPORT: 12/3/2001 Set wear ring. PU 6" bit & csg scraper. TIH w/bit to top of 4-1/2" liner ~ 8,723' Circ & ppd dry job. TOH. 'LD 6" bit & scraper. PU 3.8" fish tail bit, string mill & 90 jts of 2-7/8" drill pipe. TIH w/3-1/2" DP to top of 4-1/2" liner. Rotated, washed & reamed trying to get into top of 4- 1/2" liner w/3.8" diam tools, unable to get into liner top. Mixed & ppd dry job. TOH. DWC: $30,926 CWC: $98,128 AFE #: 101391 Objective: Convert Well to Injection 12/08/01 Fin TOH, bit was worn out. FIRST REPORT: 12/3/2001 LD string mill. Rebuilt bit to a tapered 3.30" OD w/Kut-Rite on taper. TtH to top of 4-1/2" liner. Milled & worked on top of liner, may have made 2' (ttl of 5'). Ppd dry job. T0H to 7,930' Slipped & cut drlg line. Fin TOH. LD bit (completely worn). PU tapered mill (2-1/4" to 3-1/2"). TIH to top of 4-1/2" liner @ 8,727' Milled on top of 4-1/2" liner w/tapered mill. Made about 1' (ppd 20 bbl sweep). TOH. Ck'd & tightened pipe on trip out. LD tapered mill. Mill worn dwn to 3-1/8" w/all the Kut- Rite gone. DWC: $30,790 CWC: $128,918 MIDDLE GROUND SHOAL A, WELL #33-11LS AFE #: 101391 Objective: Convert Well to Injection 12/09/01 FIRST REPORT: 12/3/2001 Est inj rate. Press up & broke dwn well ~ 2,775 psig. Inj into fmt @ 3 BPM ~ 2,600 psig. TIH w/2-7/8" DP. LD 2-7/8" DP. PU Baker Model "D" pkr 84-32 & tail pipe (made up in Baker shop). TIH w/btm pkr on 3-1/2" DP. Broke circ. Dropped ball. Set pkr w/2,000 psig. Sheared off pkr w/7,500 lbs of over-pull. LD 3-1/2" DP & Baker running tool. Pulled wear ring. Set tstd plug. Chg'd rams to 2- 7/8" Press tstd BOP body. RU jam unit & 2-7/8" pwr tongs. PU seal assbly & TIH w/2-7/8", 7.9~, L-80, RTS-6 tbg. DWC: $23,113 CWC: $152,031 AFE ~: 101391 0bjective: Convert Well to Injection 12/10/01 FIRST REPORT: 12/3/2001 Ran 259 its of 2-7/8", 7.9%, L-80, RTS-6 tbg. Used Weatherford jam unit for make-up. Stung into pkr ~ 8,163.96' (tbg measurement) and spaced out. Pulled up 40' above seals. RU to pickle tbg. Held pre- job safety mtg. BJ ppd 1,000 gals acid & disp to 500' fr/btm of tbg. Rev circ acid back to holding tnk w/rig pmp. BJ ppd another 1,000 gals of acid to 500' fr/btm of tbg & rev circ acid back to holding tnk w/rig pmp. Disp annulus w/460 bbls of pkr fluid containing 10.gals of NALCO ECll2A + 4 gals NALCO EC1348 biocide per 100 bbls of FIW. Stabbed seal assbly into lwr pkr & landed tbg higher in well head. Dropped prong. Press up & set upper pkr w/4,000 psig, held for 15" Press up on annulus to 1,825 psig, held for 30" (lost 71 psig). Good tst. Completion as follows: Wleg ~ 8,189.32', RN nipple 8 8,182.47', Baker Model "D" pkr 84-32 ~ 8,163.96', R nipple @ 7,341.60', Baker 7" SV-3 pkr ~ 7,321.45', R nipple @ 7,309.20', R nipple @ 331.88', CIW tbg hanger @ 38.50' RU slickline. Pulled slickline prong & sleeve fr/R nipple @ 7,341' DWC: $75,844 CWC: $227,875 AFE #: 101391 Objective: Convert Well to Injection 12/11/01 FIRST REPORT: 12/3/2001 RD slickline unit after pulling prong & plug body fr/"R" nipple. RU BJ for acid job. Conducted pre-job safety mtg. Press tstd lines to 4,000 psig. Bullheaded 2,000 gals acid, chased w/157 bbls FIW. Blew dwn mud lines. Set BPV. ND BOP. Injected spent acid into inj well. Loaded out boat. Std cleaning pits. NU tree & tstd to 5,000 psig, tstd OK. Cleaning pits. DWC: $109,825 CWC: $337,700 AFE #: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/12/01 Fin cleaning pits & slop tnk. Cleaned decks. Removed York mtr fr/generator. Std rigging dwn iron ruff-neck & top drive. Rig released ~ 24:00 (12:00 pm) 12/11/01. Prep to start moving to Platform C. DWC: $27,775 CWC: $365,475 MIDDLE GROUND SHOAL A, WELL #33-11LS AFE #: 101391 FIRST REPORT: 12/3/2001 Objective: Convert Well to Injection 12/13/01 Well inj @ 1,800 BWPD & 1,100 psig. Press is slowly climbing over time. Built 700 psig over last 24 hours. DWC: $0 CWC: $365,475 AFE #: 101391 Objective: Convert Well to Injection 12/14/01 Well inj @ 1,826 BWPD @ 1,250 psi. hour period. FIRST REPORT: 12/3/2001 Press incr 150 psi over last 24 August 7, 2002 XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn:. Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Submission of Forms 10404 for the A33-1 iLS Recompletion in the Middle Ground Shoal Field, Platform A. Dear Ms. Taylor, Please f'md attached the Recompletion Report Forms 10-404 for each well segment (original wellbore A33-11 & sidetrack A33-1 iLS), current wellbore schematic, and daily operations report for the A33-1 ILS well. This will replace the 10-407 form that had been filed on January 4, 2002. This well had been approved for the conversion of a producer to an injection well on Nov 6, 2001. The workover was completed on Dec 13, 2001. Please call me if you have any questions at (915) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc: Doug Schultze Doug Marshall 'Tim Smith List of Attachments: 1. Recompletion Forms 10-404 2. Current Wellbore Diagram 3. Daily Operations Report DUPLICATE TONY KNOWLE$, (~OVEFINOFt August 4, 1999 ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 William Miller Cross Timbers Operating Company HC01 Box 485 Old Wik Road Kenai, AK 99611-9704 Dear Mr. Miller, Re: Administrative Abandonment Action Middle Ground Shoal Wells A33-11 Permit #~ A22-14 Permit # 85-068 A14-O1 Permit # 67-079 Al2-01 Permit # 77-055 A31-11 Permit # 77-031 Al3-01 Permit # 66-015 A41-11 Permit # 85-174 This letter reflects the lateral Well that replaced the original well by well number, permit number and API number: 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. A33-1 ILS (permit # 93-180, API# 50-733-20383-61) permit was approved 11/30/93. A41-11LN (permit # 94-087, API# 50-733-20378-61) permit was approved 6/28/94. 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 abandonmem (SQZED. AOGCC stares) of the originating well bore is appropriate according to current AOGCC procedures for wells where additional permitted laterals are drilled t¥om an existing well bore. Production will be reported to the original APl wellbore (-00. -01 or etc) and not to the lateral API wellbore (-60, -61 or etc). 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 databases require each conductor have only one permit number and APl number. Administrative abandonment of the original permit only eliminates duplication in the databases. Information for the original well and its replacement will be maimained in their respective files until plugged and abandoned according to 20 AAC 25.105. Please notify other cognizant personnel in your organization so that the well will be correctly idemified on subsequem reports and applications submitted to the Commission. ~~Robert N. Chns'~n%on. P.E. Chairman .. -.. Abnd Date · -. · · - . · . . . . Note cas~ size,. '~, aleph, ~t' vol, '&.pro6ed~e. . ' p-~,~ *1,~-q~' ~/'~Oo-s~ + ~Os~Toe : .... - Perf ~te~als - 'tope:: ~ L~ a ~_0~6' ':' Review the well file, and-' comment on plugging, well head status, and lo~ation clear_~_nce - provide loc. clear, code. $ - . . . ~ h~ ~'~ ~ ~o ~ ~ ' ' '- .. _ . well head Cut off: '~ Marker post or plate: ~o- Location-Clearance: N)A Conclusions: Code · . Date o_~Jo%!~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 22, 1994 A1 Foglesong Shell Western E&P Inc. 130 Trading Bay, Suite 310 Kenai, AK 99611 ~Re~ Administrative Abandonment Action Middle Ground Shoal A-33-11 Permit # 85-0235 Dear Mr. Foglesong: With the completion of well A-33-11LS (permit # 93-0180, API# 50-733-20383-61) in March of this year, the file for well A-33-11 (permit #85-0235, API# 50-733-20383-00) has become redundant. Accordingly, we are administratively closing the A-33-11 well file. David W. Johns Chairman ~ printed on recycled paper b y Memorandum State of Alaska Oil and Gas Conservation Commission To~ Well File: A-33-11 Permit # 85-0235 Administrative Abandonment Action Middle Ground Shoal A-33-11 Permit # 85-0235 September 15, 1994 This memo will remain at the front of the subject well file. Well A-33-11 was replaced by A-33-1 ILS (Permit # 93-0180, API# 50-733-20383-61) when the permit was approved November 30, 1994 and operations completed in March 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 from an existing well bore. 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. The operator has been notified of this action. All future correspondence with the AOGCC should reflect the new permit number, API number and well data. Reservoir Engineer Commissioner Statistical Technician Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 June 9,1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemeni SUBJECT: CORRECTED LOCATION COORDINATES MIDDLE GROUND SHOAL A33-11LS (REF.: PERMITNO. 93-180) ~ ~-- ~~.~ Given below are corrected location coordinates for Middle Ground Shoal A33-11LS. These coordinates should replace the well location coordinates which we supplied for the permit to drill application, well completion report, and sundry application to perforate dated November 16, 1993, April 4, 1994 and May 12, 1994, respectively. Location of well at surface: Platf A, Leg 4, Condr 25 1571' FSL & 385' FEL Sll, T8N, R13W, S.M. At top of reservoir, 8220' MD-KB, 8008' TVD-KB: 1660' FSL & 1820' FEL S11, T8N, R13W, S.M. At TD, 11,501' MD-KB, 9923' TVD-KB: 57' FSL & 2782' FEL S11, T8N, R13W, S.M. If you have any questions or wish to discuss, please call Jeff Wahleithner at (713) 544- 3344. Sincerely, A. J. Durrani ' Tech Manager, Asset Administration Western Asset, Continental Division RECEIVED AJD:JMB AJD41581.DOC- I JUN 1 5 1994 Alaska 0il & Gas Cons. Commission Anchorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 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, T8N, 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, T8N, 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. DOC I = ! TgN S.M. ____] [ [ · t ' : ~DI.-i[t754 i : · · LAT. {0°47' 44'808~ ~ /t. tl * co~,. ~¢z¢44.0o~' ~ ~ PLATFOR~f LOC~TIO// ~ · :::'I ............ 3..'.. 15 14 ~ ~ 13 i[~ , t8 , g[~ · ..' . . ............ : . , , ~_ . - ~ ~ , 2t 2~ -' . Z4 19 . . 2~ ~ Z6 ' 2~ 30 .. ... . . . ~ · .- - _ . -- ........ ~4 35 36 ~1 32 ~ : .~. LOCATION OF "-~.(U~ ~ 3 19'~'~] SELF CONTAINED DRILLINO fil~sRa~il& 6asCon~.[:bmmissioa PRODUCINO PLATFORM T 8 N S.M. , gflChOfa~ S H E L L M I D D l E G R OU N D S H _ ~ __ _ : . II !1 ~ T 7N S.M., t ~ . PLATFORM ~ COOK INLET. ALASKA 0 4009 ~000 12000 SCALE IN FIlET APPLICATION BY SHELL OIL'CO~ LOS ANGELES, CALIFORNIA I0 i0 T. 8 N., R.i:5 W., S.M. £ 2 !1 II 14 ADL ! I F 1__8 _ _ I I i I ~ I I I I I I I I I 12 LEG NO. I X = 252,785 Y = 2,485,845 1627' N I~ 4:55'W FROM THE SE COR. OF SEC. II, TBN, RI3W, S M. LEG NQ 2 LEG NO. 3 PLANE X = 232,846 Y = 2,48 5,897 C 00RDINA T£$ X= 2:52,896 Y= 2,485,835 PUBL/C LAND 1681' N ~, 372_' W FROM THE SE COR. OF SEC. II, T8N, RI3W, SM. DESCRIP 7~ION I ~ 2o' N '~ 321' W FROM THE SE COR. OF SEC. II~ TSN~ RISW, SM. LEG NO. 4 X = 232,B33 Y =2,485,783 15G6'N I~ 383'W FROM THE SE COR. OF SEC. II, TSN,RI3W, S.M. GEO DE TIC COOt?DINA TE$ II 0 I II II I LAT.- G0°47'44.839 LAT.-60°47'45.:568'' LAT.- GO 4744.7G8 LAT.- GO°~7'44.2~zi, !i LONG.- 15lO 29'45. il2'', LONG.-I51°29' 43.942" LONG.-I5 l°29' 42.'899" LONG.-15l° 29' 44.154" ,, [~F'.A~,"r'l,! ~;','I-I A. D. I.I ~ SCALE I"= I000' C,.,,,, ~ ;-~,~Y u ~,,~.c,.~) ~.~ ~.,,.,:. u SHELL Of: r-,r.,-.,"--~' Ii ,,,~.~ ,.,~.¥ ,~., ,~.~ ~! . z.- 41 0- 2 I1 LOCATIO~x., OF HIDDLE GROUND SHOAL Platform "A" WELL/CONDUCTOR LOCATIONS Leg 1 - Center of Leg 1 @ 1627'N & 435'W from SE corner of Sec.11, T8N, R13W, S.M. A 12-01 I 1632 A 11-01 2 1632 A 43-11 3 1630 A 34-11 4 1625 A 34-14 RD 5 1622 A 22-14 6 1622 A 12A-01 7 1625 A 13-01 8 N & 437 N&432W N&430W N & 430 W N & 433 W N & 437 W N & 440 W 1630 N & 44O W W from SE corner II II II II II II II II II · II II II II II II II II II II II II Le9 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec. 11, T8N, R13W, S.M. A 42-11 9 1685 A 44-02 10 1685 A 42-14 11 1683 A 41A- 11 12 1678 A 11-12 13 1675 A 11-13 RD 14 1675 A 31-14 15 1678 A 44-11 16 N & 374 N& 370W N & 368 W N & 368W N&371W N&375W N & 378 W 1683 N & 378 W W from SE corner II II II II II II II II II II II II II II II II II II II II II Le9 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 Ca 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 - 1571 A 14-01 26 1571 A 12-12 27 1568 A 24-01 28 1564 A 13-12 29 1561 A 33-14 " 30 1561 A 41-11 31 1559 A 23-01 32 N & 385 N&381W N & 378 W N& 378W N&381W N& 385W N & 388 W 1569 N & 388 W W from SE corner II II II II II II II II !1 II II II II II II :: Jgt' 1 3 1990 t\leska Oil & Gas Cons. commisslo[1 Ancho.rag~ SBBC/mgs A : REFERENCE ' ~ SHE L L' OIL COMPA~ ~' ~' ' TRANSMITTAL OF: the following: Quantity Kind .. Description of Item Please sign and return duplicate copy of this memorandum to: Shell Oil Company P. O. Box 481 Houston, Texas 7700! : L._'. · . ,,' .:.~,.~/-~' Above items received, except as noted: Date Original - Addressee ! st copy - Addressee, for signature and return to sender 2nd copy- Head Office Exploration, Houston ' -~- l,c,; ,~':'"/T ~_'/,~ ,:, )--- D-1~12 (REV. 9-85) STRAIGHT BILL OF LADING-SHORT FORM--ORIGINAL--NOT Ni:GO'i lADLe: RECEIVED, subject to the classifications and tariffs in effect on the date of the issue of this Bill of Lad)hg FROM' fCompanyName) CHELL DEVELOPMENT COMPANY · IDAT r '-lIPPED SHIPPER'S NO. AT 3737 BELLAIRE BLVD. HOUSTON, TEXAS 77025 =RI'L 5,1988 244065 BY FEOERAL EXPRESS 07639127215 CARRIER CONSIGNED TO (Mai/or street address for notification on/y) me property de~criUed below, in apparent good order, except a~ r~ted (contents and Sut~ect to Section 7 of Conditions of condition of contents of backaojes unkhown), marked, consigned, and destined as indicated applicable bill of ladin§, if this ship- below, which said carrier (the word carrier being understood throughout this c=3ntract as merit is to be delivered to the consig- meaning any person or corporation in possession of the property under the contract) agreas nee without recourse on the consignor, to carry to its usual place of delivery at said destination, if on its route, otherwise to deliver the consignor shall sign the following ·,-~ ~H, · tO another carrier on the route to said destination. It is mutually agreed, as to each carrier of statement: ALASKA 0IL & GAS CONSERVATION___, ...[-(,}~v~'/~e a[ ......... id pcoperty ..... I ........ ionofsaid ...... d ...... i ..... d .... each party at any time interested in all or any of ~aid property, that evl~ry service to be Tl'~ carrier shall not make delivery 3 0 01 PO R C U P I N E m R I V ~ .~.~ ~aunder aha,, ~ ,u~ ........ h ........ d cond,,, .... ,the Un,,orm Co- o, ,h,s ah, ..... , ........... , ~'/ me,tic StraiQht Bill of Lading ~et forth (1) in Uniform Freight Classification in effect on freightend all other lawful charges. ANCHORAGE,ALASKA 99501 tr~Eerdate here°f' if this is a raild.ificafiono~ tariff if this ..... is a motoril .... carrierShiP~shipment. ..... (2) in the applicabl ......... Shipper h~reby certifies that he is familiar with all the terms and conditions of the said (Signature of Consignor} bill of lading, including those on the back thereof, sat forth in the clarification or tariff A T T N · J 0 H N B 0 Y L E ~hich go .... th ......... ion of this shi ....... d .... i ........ d conditions are hereby aDreed to by the shipper and accepted for himself and his assigns. ~ P R E PA I D If this document evidences a delivery by shipper's truck .or into consignce's truck, it - '- iS not a bill of lading but consigoee's receipt for the delivery. CO ELECT ROUTE ORDER NO. SHIPPING MEMO PACKAGES HM DESCRIPTION OF MATERIALS, SPECIAL MARKS AND EXCEPTIONS WEIGHT* CLASS TOTAL VALUE Subject to OR OF ITEMS NO. KIND + PLACE "X" IN HM COLUMN IF MATERIAL IS DOT HAZARDOUS correction RATE ..... .! ..... C_A...R TON_ . . 1._.ET .. COR_~_.__.C.._~_!_..P.5_.,,_. SWEP I.,, ....... COOK INLET,AK., INTERVAL.: 9370'-9395'. 19 LBS. · 170-80~62-81 1 CARTOI~ ~ TOTALNO. OFPACKAGES TOTAL WEIGHT ~) 19 LBS. o. , c.o-o. PURCHASE ORDER NO. IINVOICE NO. REASON FOR SHIPMENT APPLYINGTO } I SETTLEMENT BASIS SHIPMENT AUTHORIZED BY E~ CREDIT MEMO [-~ CASH SALE [--] MEMO C. BOY'K I N ISSUE BILLING TO DEBIT ICREDiT I MAIL FREIGHT BILL IN DUPLICATE WITH NO. 3 COPY OF BILL OF LADING TO P.O. BOX 1382, HOUSTON,TEXAS 7725.1-1382 Spill, Leal<. Fire. Exposure or Accident 800-424-9300 MOTOR CARRIER F--] CALL CHEMTREC -DAY OR NIGHT SHIPPER CARRIER · If the shipmeHt moves between two ports by a carrier by water, the law requires that the bill of lading shall state whether it is "carrier's or shipper's weight" 1. The agreed or declared value of the property is hereby specifically stated by the shipper to be not exceeding 150 ~ pe~ pouad wh~ra the rate is dependent on value. 2. Description and gross weight thereof as shown he~ei .... correct, per ^gr~.me.t f.ed w,th We,gh,~ and ~....~t,oo Su..u. Carrier certifies that the container supplied by Carrier for this shipment is a ii applicable, proper container for transportation of the Products as above described. 3. This is to certify that the above named materials are properly classified, d~cribed, packaged, marked and labeled and are in proper condition for transportation accordir~g to the applicable ragulatio'ns of the Department of Transi)ortation. C A R R I E R SHELL DEVELOPMENT,/_CO_MPANY FEDERAL EXPRESS SH I PPE R (Company Name) ~'~~ PER FRANK d . DAV I D~~/"~"'~ PER AGENT I MATERIAL RECEIVED ]DATE RECEIVED TO CONSiG~EE OR AS INSTRUCTF~G I)UESTIONS? CALL 800-238-5355 TOLL FREE. AIRBILL ,~UPHBER 7639127215 Date .~ .~¢~l~t-.~_.~~ '4 / 5 / 8 8 -rom tYouf: Name) PLease Print C. BOYK IN Company 5 i'd.-.. ~,:' Street Address City State Y r Phone Number (Very Important) ) Department/Floor No. IZIP Required For Correct Invoicing .Recipient's Name) Please Print ,JOHN BOYLE PAYMENTr~ E~,,Sender [] B, ill Recipient's FedEx Acct No. [] E~[13rdPar~FedExAcctNo. Recipient's Phone Number ~ery Imporlant) ( ) Company Department/Floor No. ALASKA OIL ~ GAS CONSERVATION C0 DOUR BILLING REFERENCE INFORMATION (FIRST 24 CHARACTERS WILL APPEAR ON INVOICE.) ~ I HOLO FOR PICK-UP AT THIS FEOERAL EXPRESS LOCATION: ~ 17 0 ' 8 0 5 6 2 - 81 ~,s~, A~re~ ~s~ s~,c~ ~ or C~,, ~-~-~, ~ BII Cr~h ~rd ' ICi~' ~ S~te ~~ ~~t,;,,~ Z,,,,Zip~eofStr~tAddre~R~ui,~ CHECK ONJ Y ONE BOX , Exact Street Address [Us~ of P.O. goxes or P.O. ~ Zip Codes Will ~lay D~livery And Result in Extra Charge.] 300'1 PORCUPINE DRZVE City State ~ ZIPStreet Address Zip Require-d ANCHORAGE ,ALASKA I DELIVERY AND SPECIAL HANDLING CHECK SERVICES REI~UIRED [] HOLD FOR PfCK-UP [~ DELIVER WEEKDAY DELIVER SATURDAY ~.~ ~ ~ DANGEROUS GOOOS ~ fiONSTA~T SUAVEILMNCE SERVIfiE [~J ~ 'DRY ICE ~ ~ ~ OT~EA SPECIAL SERVICE ~ L_. .- . > HI' ]PRIORITY I OVERNIGHT OvemicjhtDeliver'/ 6 [] LETTER* U~ng Yo.flr P~:;~ling (O~r Packz~c,g) OVERNIGHT DELIVERY USING OUR PACKAGING BI Courier-Pak Overnight Envelope* 12"x 15W' "~ Overnight Box A [] ~ 12~"x 17~/~"x 3" Overnight Tube 38"x 6"x 6"x 6" · Declared Value limit $100. STANDARD AIR _×J Delivery r, ot fl'~n tared second business day SERVICE COMMITMENT ~t k~;ali~:m.s. I~ may lake hvo O~ ?r, cxe bu~n~ day~ if me PACKAGES l WEIGI~ Total JTotat Received At 1 '.~..¢¢~-16!:::j. uiar Stop % 2 00n-Cal~ Sion 3~3 4~ Drop 8ox B.S.C. Fe-Jeral Express Oorp. Empioye-~. ::-:" :" i:.::;' Se~d~e~Feder~Expres~st~dehvert~isshi~:~e~witr"~1~b~iningadeir~,e.rys`i~r~,~turea~i~ ! DATe/Time Fo: FedJers2 ExOr~--s Use arid ho, id harmles~ Federal E.x,o, res.s froth any claims re~Jt'dng ~e~'etro~. ' - Release ; '" '" ' -': ' / '*'" : ' Signature: -' '~ _j Emp. No. J Date [] Cash Received Fed~eral Express Use E~Se Charoes Received By: x [] Return Shipment [] Third Party~ Ch<j TO Del.[] Chg. To H~ Street Address Ow. er City State Zip · FA~-.=.105001 RE I PRi'~;TED Date/Time Received FedEx Employee Number July 8, 1987 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage,Alaska 99501 SUBJECT- SUBMISSION OF WELL COMPLETION REPORT FOR MIDDLE GROUND SHOAL WELL A33-11 Gentlemen' Enclosed, in duplicate, is the Well Completion Report (Form 10-407) for Middle Ground Shoal well A33-11. If you have any questions, contact Susan Brown at (907) 263-9613. Very truly yours,~'~'. · L. sl and , Managt~,~s}eagul at~ry Affairs glask~ D~v~s~on DLY/SBB/bc 0708/SBBF STATE OF ALASKA ALASKA-~.~',,L AND GAS CONSERVATION C~JMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Shell Western E&P Inc. 85-235 3. Address 8. APt Number 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 5o- 733-20383 4. Loc~i~_.of wr¢ at surface P1 atform "A", Conductor 25, Leg 4. II:~l]'~ 9. Unit or Lease Name ~¢*'~&~from SE corner of Sec. 11, T8N, R13W, S.M. Middl~ C, rn~Jnd Shna] At Top Producing Interval 10. Well Number @ 82201 88o4'N & 1434.6'W of surface locatiom A 33-11 At Total l epth I I lls 13. !1 z 11.FielOanOPool ~'%@ 9930'---48~-~8~-~ ~ Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. "GI; Poo 1 116' KBI ADL 18754 12. Date Spud. deal12/04/85 13. Date T.D. Reached 01/22/86 14. Date C~)m2/,25~ 78 ~r Aba nd. 15. Water Depth, if offshore 80 feet MSL [ 16. No. of Completions single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9930' + 9628.8' 9848' + 9552' YESF~ NO[]I 281 feetMa 0 22. Type Electric or Other Logs Run DA, DIFL/DHC, CDL, CNL, GR, SP, CAL, BHC, LLS, FMT, DIP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# K-55 0 1712' 17L~,72'' 710SX "G" + additives O' 9-5/8" 43.5# N-80 0 3696' 12-1/4" 525sx I'G" + additivas O' 9-5/8" 47# L-80 3696 6441' 12-1/4" O' 7'l 26# N-80 6137 7775' 8-1/2" 1500sx "G" + additives O' 7" 32# P-110 7775' 9928' 8-1/2" 90sx top job O' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) ~.SlZE DEPTH SET (MD) PACKER SET (MD) See Attachment 1 2-7/8"; 6.4~ R1F~4' RI~RI 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,i DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See Attachment 2 .... 27. ' ' PRODUCTION TEsT Date First Production . I Method .of Operation (Flowing, gas lift, etc.) 2/22/86 '~l Gas Lift ..... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCr WATER-BBL CHOKE SIZE IGAS-OILRATIO 2/22/86 24 TEST PERIOD I~. 402 44 17 128/64I 109 · Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 70 600 24-HOUR R~,TE ~ 402 44 17.. 34 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : Development wet 1 . . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . 29. 13o. .~F GEOLOGIC MARKERS FORMATION TESTS , , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST QF ATTACHMENTS ~erforatJons Open to PFoductJon, Fracture Summary, and Xe]] History 32. I hereby certify t~t th~for~going is true and correct to the best of my knowledge Signed j~ ~ ~~ ~_~_~~ Title DiV. ~a~J~S ~. Date ~]~ 13,1~7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (.where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 PERFORATIONS OPEN TO PRODUCTION ZONE HC-HD HD-HE HE-HF HI-HK HK-HN II II II HN-HR II II II HR-HZ II II II II MD 8220 8350 8419 8540 8593 II II II 8772 II II II 9003 II II II II A 33-11 ZONE TOP TVD 7890 8016 8085 8181 8250 II II II 8419 II II II 8637 II II II II PERF. INTERVAL 8220-324 8350-370 8419-442 8540-582 8596-616 8630-650 8670-690 8710-740 8810-830 8850-870 8930-950 8970-990 9050-070 9090-110 9120-140 9160-170 9200-210 ZONE BOTTOM MD 8350 8419 II 8593 8772 II II II 9003 II II II 9280 II II II II TVD 8016 8085 II 8250 8419 II II II 8637 II II II 8896 II II II II ~. '~,-.m.,:.: Qii & Gas 6?.i'is, C.6mmiss~oi~ SBBF/fs FRACTURE SUMMARY A 33-11 DATE 02/05/86 02/08/86 02/11/86 02/24/86 ZONE HR-HZ HN-HR HK-HN HC-HK AMOUNT & KIND OF MATERIAL Frac 759 bbl 40# gel, 50100# 20-40 ISP, Avg. Rate 25, Avg. Press. 7500 psi. Frac 890 bbl 40# gel, 43700# 20-40 ISP, Avg. Rate 23, Avg. Press. 6700 psi. Frac 737 bbl 40# gel, 36400# 20-40 ISP, Avg. Rate 24, Avg. Press. 8000 psi. Drop bar to fire Vann guns, surface indication of firing. SBBF/fs WELL HISTORY A 33-11 11/29-12/13/85 12/13/85 12/14/85 12/14-12/17/85 12/18/85 12/18/85 12/19-12/28/85 12/29/85 12/30-12/31/85 01/01/86 01/02-01/09/86 01/10-01/11/86 01/12-01/22/86 01/23-01/27/86 Cut and pulled casing. Spotted 350 sx cement plug densified w/10% sand and blended w/2% CaC1 and 0.5% D-31. Slurry wt. 16.2 ppg. Kickoff plug. Drilled and surveyed to 1712'. Ran casing; 43 jts of 13-3/8", K-55, 61# BTC. Shoe at 1712'. Cemented casing w/410 sx lead slurry blended w/3% CaC1, 0.1% D-31, and 8% Gel. Pumped tail slurry of 250 sx of "G" w/1% CaC1 and 0.75% D-31. Drilled and surveyed to 6441'. Ran logs (DIFL/BHC, AL/GR/Caliper, CDL/CNL/ GR/Cal iper). Ran casing; 69 jts of 9-5/8", L-80, 47#, 6441'-3969' Ran 91 jts of 9-5/8", N-80, 43.5#, 3696'-0'. Cemented casing w/325 sx Class "G" w/8% Gel, 1% CaC1, 0.15% D-13, and 0.4% R-5. Pumped tail slurry of 200 sx Class "G" w/0.75% D-31 and 0.15% R-5. Tested casing to 2000 psi for 30 min. Tested OK. Performed leakoff test w/9.4 ppg mud ~ 6255'TVD. Formation held 15.0 ppg equivalent mud weight. Drilled and surveyed to 8600'. Cored 8600' -8627'. Recovered 26.5' of 27' core. Drilled and surveyed to 9370'. Cored 9370'-9393'. Drilled and surveyed to 9930'. Logged w/ DIFL/BHC/CAL/GR. Changed tools and ran DIFL/SP/BHC/CAL (9939'-6441'). Changed tools and SBBF/wh 01/28/-01/30/86 01/31/86 02/01-/02/02/86 02/03/86 02/04/86 02/05-02/06/86 02/07/86 02/08-02/11/86 ran. CDL/CNL/SL/CAL. Also ran DLL/MLL and RFT's. Shot sidewall core samples. Ran 7" liner. Used 26#, N-80, LTC from 6137'-7775 and 32#, P-110, LTC from 7775'-9928'. Cemented liner with 1500 sx of Class "G" w 1% D-19 and 0.3% D-31. Slurry wt. 15.9 ppg. Ran liner lap test, no good. Pumped top squeeze of 90 sx of "G" cement w/.6% C-344 and .25% HR-7. Tested casing and drilled out hard cement. Ran Gyro. Survey. Ran tubing (3-1/2" 9.3#, N-80, 8RD) and set at 9848'. Cleaned hole and tested tubing to 4500 psi. Test okay. Perforated HR-HZ with 2-1/8" barkone guns, I JS every other foot. Intervals perforated are 9160-9170', 9120-9140', 9090-9110', and 9050-9070' Fractured intervals with 40#/1000 gal gel with J'347 X-linker, 0.2% F75N surfactant, 0.5#/1000 gal J-218 breaker (1 #/1000 gal added on fly), 3% KC1, 0.05% M76 Bactericide, 0.5% J-451 Hydrocarbon fluid loss additive. Spotted 55sx 20-30 mesh sand, 30 bbls 3# HEC/bbl, 4.36# sand/gal and 5# breaker/lO00 gal. Pumped 2200# additional sand. Perforated HN-HR with 2-1/8" TTHC 1JS/2'. Intervals perforated 8970-8990', 8930-8950', 8850-8870' and 8810-8830'. Fractured intervals with 40#/1000 gal gel with J-347 X-linker, 0.2% F75N surfactant, 0.5#/1000 gal J-218 breaker (1#/1000 gal added on fly), 3% KC1, 0.5% J-451 Hydrocarbon fluid loss additive. Prepared for third set of perforations and fracture job. Set packer @ 8221'. Shot four intervals with 2" HC guns with I JS every other foot. Intervals perforated are 8710-8740', 8670-8690', 8630-8650', and 8596-8616'. Fractured with 40#/1000 gal gel with J-347 X-Linker, 0.2% F75N Surfactant, 0.5#/1000 gal/J-218 breaker (1#/1000 gal added on fly), 3.0% KC1, 0.5% J-451 Hydrocarbon fluid loss additive. SBBF/wh 02/12-02/17/86 Cleaned out sand. Pulled bridge plug. Layed down tubing. Ran 258 joints of 2-7/8", 6.4#, N-80, LTC, 8RD. Perforated with 4/JS/ft the following intervals: 8220-8324', 8350-8370', 8419-8442', 8540-8582'. 02/18-02/19/86 Tested equipment and placed well on production. SBBF/wh E GEOLOGICAL ANALYSIS AND EVALUATION OF GB SANDS SHELL WESTERN EXPLORATION AND PRODUCTION, INC. A43-11 WF. LL (6965-6986 FEET) ~. A33-11 WELL A41-11 WELL (7366-7494 FEET) MIDDLE GROUND SHOAL FIELD, ALASKA il ii : ' ~ i ' i r ii ~1 Prepared for Shell Western Exploration & Production, Inc. Houston, Texas 1151 -C BRITTMORE ROAD · HOUSTON, TEXAS 77043 · CONFIDENTIAL June, 1986 (713) 932-7183 COMPANY PROPRIETARY 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 1 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 t° 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 low 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, succeedingly 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. Senior St~agf 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 GB] 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. GB1 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 microporosity 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. Ail 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 plagioclase 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 intergranutar 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 iow 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: le 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 mineralogicaily. 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. e 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 authigenic 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 components of framework grains such as argillaceous rock fragments, with consequently less likeli- hood of interaction with fluids in the reservoir. e 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. e Overall, the reservoir potential of the GB1 Sand is judged to be moderately good in the upper 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 Ae Both of the GB Sand intervals in these three ~wells are characterized by moderate porosity, good permeability and high clay content. B$ 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. Ee 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. Detrital chlorite, smectite and illite are part of the framework structure and are not likely to contribute to potential com- pletion problems. Ge 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. Ho 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. 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 Ae Be C. De E. F. 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. The water loss of the cement slurries and spacers should be controlled to 20 cc/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. Perforating underbalanced 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. 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. 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 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 X 7382 X 7410 7475 Insufficient Original Fabric/Sample X X X 7494 X X TABLE 2 ROUTINE CORE ANALYSIS DATA GB~. SAND, A-43-11 WELL (Data supplied by) Shell Western Exploration and Production, Inc. SArvlPLE 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 <5tjclay Minerals ) Sample Depth (Feet) 0 ~ ~D 0 GB ~ Sands A 33-11 Well 7021 A 41-11 Well 7366 GB 2 Sands A 43-11 Well 6965 6986 A 41-11 Well 70% 7% 10% -% 13% 59 6 11 80 6 6 1 7 64 10 11 24 15 51% 17% 17% 15% 47 21 16 16 40 9 42 9 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 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 1 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 Be 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 kaolinite (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 photomicrograph. 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 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 Ae This finer grained sample is comprised of predominantly monocrystalline 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 co~npaction. Muscovite and elongate argillaceous rock fragments show some degree of preferential orientation. Pore space (blue) is common, however, Dore throats appear relatively constricted due to the poor sorting and authigenic clay minerals present. 32X Be 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 ,~ 0.Smm I 0.Smm FIGURE 3 A33-1! WELL (7118 FEET) Ae Be 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 failing in the lower medium sand category. 32X 0.5 mm : FIGURE 4 A41-11 WELL (7366 FEET) Ae Be Co Do 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 A 0.5 mm B 0.5 mm 0.5 mm 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 plate]ets 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 A FIGURE ~i 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. 50X second area F - 250X G - 200X third area H - 1000X 2OO? ! ! ,- , ~'~ 14 FIGURE 6 6986 FEET A large secondary macropore (II) contrasts in size with primary intergranular macropores (arrows). The secondary pore, formed due to leaching, is partially occluded by diagenetic alteration products. Authigenic kaolinite (K) occurs as intergrown masses of booklets and stacked vermicular aggregates. This diagenetic mineral has formed as a pore-filling constituent, forming micropore space in a former macropore space. Photomicrograph C illustrates the morphology of the kaolinite in detail. Elemental data (Photograph D) shows the 1:1 ratio of aluminium and silicon 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 authigenic 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 ~B 20~ FIGURE 8 '/366 FEET 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 7475 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 C - 2500X D - Elemental data FIGURE 10 7494 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 SPECIAL CORE ANALYSIS STUDY FOR Shell Western Exploration and Production Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska File Number: SCAL 305-86011 Special Core Analysis HOLLISTER RD., HOUSTON, TEXJ~ 77040, 7131460-9600 August 25, 1986 CORE LABORATORIES, INC. Special Core Analysis SheI1 Western Exploration and Production Inc. Post O£fice Box 831 Houston, Texas 77001 Attention: Mr. Clay Williams Subject: Special Core Analysis Study A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska File Number: SCAL 505-86011 Gentlemen: In a meeting on February 21, Mr. Clay Williams of Shell Western Exploration and Production Inc. authorized Litton Core Laboratories to perform the following special core analyses on full diameter core material recovered from the subject well: 1) Permeability to Air and Porosity at Corafining Stress 2) Air-Brine Porous Plate Method Capillary Pressure 3) Specific Permeability to Water 4) Formation Resistivity Factor 5) Formation Resistivity Index 6) Cation Exchange Capacity An interim report dated June 11, 1986 provided completed data to date, including permeability to air and porosity at confining stress and air-brine porous plate method capillary pressure test results. The samples used in this study are lithologically described and identified as to sample number and depth on page 1. Sample Selection and Preparation Twenty-three full diameter core segments representing the depth interval 8600.0 to 8625.5 feet (Core No. 1) recovered from the subject well were submitted for use in this study. Eight segments, previously cleaned for conventional analysis, were selected for testing with approval from Mr. Williams. The samples were refaced, attempting to eliminate most of the surface irregularities which were unavoidable during sample trimming. Permeability to Shell Western Expl. and Prod. Inc. A-55-11 Well Page Two air and Boyle's law porosity (using helium as the gaseous medium) at 500 psi and 4000 psi confining stress were measured for the first sample. overburden stress was reduced to 5000 psi for the remaining samples due to sample damage in the first measurement. The results of these measurements are tabulated on page 2 and graphically presented on page 3. Air-Brine Porous Plate Method Capillary Pressure The eight samples were evacuated of air and pressure saturated with a 17,000 parts per million (ppm) sodium chloride brine. Permeability to water measurements were attempted, but due to sample erosion during loading procedures, the testing was halted. The samples were placed in porous plate cells and desaturated using humidified air at the selected pressures indicated on page 4. At each pressure sample saturations were determined gravimetrically. The capillary pressure versus saturation graphical presentations are found on pages 5 through 12. Specific Permeability to Water Following the air-brine porous plate method capillary pressure tests three of the samples not scheduled for further testing were processed for permeability to water measured at 500 psi and 3000 psi confining stress. The results of these measurements are tabulated on page 15. Included with these data are specific permeability to water values for the other five samples. The water permeabilities were measured after the samples were recleaned and saturated wi th th~ brine described on page 14. The flushing required for the se permeability measurements also assured full saturation for the electrical property measurements to follow. Formation Resistivity Factor Five selected samples, saturated as described above, were loaded into core holders and 500 psi confining stress applied. The resistivities of the brine and the brine saturated samples were measured over a period of several days until stable, indicating that ionic equilibrium within each sample was achieved. Using Archie's relationship, with the data on page 15, a cementation exponent, "m", of 1.72 was calculated from the data trend graphed on page 16. The measurements were repeated at 5000 psi confining stress resulting in an "m" of 1.80, as shown on page 17. Formation Resist,ivity Index When formation resistivity factor measurements were stable, the samples were desaturated using a refined mineral oil while remaining under confining stress. The amount of brine displaced was recorded and a volumetric saturation calculated using the pore volume at 3000 psi confining stress for calculation of formation resistivity index. These data are presentedv~__.p~ge 15. The Special Core Analysis i! ,i !:: ! !!__..: ~i;r.~' Shell Western Expl. and Prod. Inc. A-33-11 Well Page Three saturation exponents, "n", ranged from 2.25 to 2.85 as shown on pages 18 thro. ugh 22. A composite plot of the £ormation resistivity indices on page 23 yields an "n" o£ 2.48. Sample 16 showed oil contamination during the later stages o£ testing; consequently, only the £irst saturation point and resistivity was deemed acceptable. _Cation Exchange Capacity A trimmed segment o£ three o£ the samples used in the electrical property measurements and seven irregular core segments from selected depths were analyzed for cation exchange capacity. The procedure used for analysis was the ammonium acetate wet chemical method. The samples were prepared for testing by crushing the entire sample to pass a 10 mesh sieve and cleaning them in a toluene-methanol-toluene sequence. They were then air dried and pulverized to pass a 60 mesh sieve, then split into two equal portions, one to use as the sample and the other to oven dry at 105 degrees Celsius to use as a corrected dry weight. The air dried portion for analysis was then boiled in a 2 normal ammonium chloride solution to remove carbonates, then filtered dry. The sample was then agitated in I normal ammonium acetate (pH neutral) to exchange the cations naturally present on the clays for ammonia. Each sample was then washed with a 70%-/X)% solution of methanol and distilled water to remove the cations not bound to the clays. The ammonia was then distilled from the clays into a 0.1 normal hydrochloric acid solution and the excess acid was titrated with 0.1 normal sodium hydroxide. The cation exchange values calculated are presented on page 24. Thank you for the opportunity to be o£ service to Shell Western Exploration and Production Inc. If we can be of further assistance or if you have any questions about these data, please feel free to contact us. Very truly yours, LITTON CORE LABORATORIES W.K. Hudson Laboratory Supervisor Houston, Texas WKH/grh Special Core Analysis CORE LABORATORIES, INC. Page 1 of 24 Special Core Analysis --~ File SCAL 305-86011 ID~%~I~IFICATION AND LI~DIX}GICAL DESCR/PTION OF SAMP[.~ Shell Western Exploration and Production Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Sample Identification Depth, feet 5 ~605 10 8610 11 8611 13 8613 14 8614 15 8615 16 8616 21 8621 Litholo$ical Description ,, Cgl: wl ind, frac, Mtrx- v f-crs gr, poor srt, slily arg; Clas- subrndd Gran, Pbl,& Cbl (Cht, Fspr, Qtz, & carb) Cgl: wl ind, Frac, Mtrx- v f-crs gr, poor srt, slily arg; Clas- subrndd-subang Gran & Pbl (Cbt, Fspr, Qtz, & carb) Cgl: wl ind, Frac, Mtrx- f-v crs gr, poor srt, slily arg; Clas- subrndd-subang Gran, Pbl, & Cbl (Cbt, Fspr, Qtz, & carb) Cgl: wl ind, Frac, Mtrx- f-v crs gr, poor srt, slily arg; Clas- subrndd-subang Gran & Pbl (Cbt, Fspr, Qtz, & carb) Cgl: wl ind, Mtrx- f-v crs gr, poor srt, slily arg; Clas- subrndd-subang Gran & Pbl (Cbt, Fspr, Qtz, & carb) Cgl: wl ind, Mtrx- v f-v crs gr, v-poor srt, slily arg; Clas-subrndd- subang Gran & Pbl (Cht, Fspr, Qtz, & carb) Cgl: wl ind, Mtrx- v f-crs gr, poor srt, slily arg; Clas- subrndd Gran & Pbl (Cht, Fspr, Qtz, & carb) Cgl: wi ind, Mtrx- v f-crs_gr~ poor srt, slily arg; Clas- subrndd-ang mostly Gran, occ Pbl (Cht, Fspr, Qtz, & carb) This report based on observations and materials supplied by the client is prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE LABORATORIES, INC. Special Core Analysis Page 2 of 24 File SCAL 305-86~11 PERMEABILITY TO AIR AND POROSITY AT OVERBURDEN STRESS Shell Western Exploration and Production Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Overburden Stress, psi: 500 3000 4000 Sample I.D. Depth, feet ,...P.e. rmea. bi.lity to Air, millidarqys 5OO 5 8605 2.6 10 8610 3.6 0.92 11 8611 9.7 2.7 13 8613 2.2 0.66 14 8614 7.2 2.1 15 8615 0.91 0.20 16 8616 2.4 0.44 21 8621 0.53 0.07 0.39 0.83 1.4 3.9 1.1 3.3 0.38 0.86 0.19 Sample I.D. Depth, feet _ Porosity, percent 5 8605 5.1 --- 4.3 10 8610 5.3 4.3 --- 11 8611 6.0 5.0 --- 13 8613 5.3 4.7 --- 14 8614 6.2 5.2 --- 15 8615 4.9 4.3 --- 16 8616 4.8 4.0 --- 21 8621 3.0 2.6 --- 4.7 4.7 5.4 4.9 5.7 4.6 4.4 2.8 This report based on observations and materials supplied by the client Js prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE LABORATORIES. INC. DALLAS. TEXAS Pc~ge 3 of 24 File $ CAL 305- 86011 100 Company Well Field Shell Western E & P Inc. A-33-11 Middle Ground Shoal Formc~tion County State Hemlock Alaska 0.1 2 3 4 5 6 7 Porosity, percent CORE LABORATORIES, INC, Special Core Analysis Page File 4 of 24 SCAL 305-86611 SUMMARY OF CAP I~Z.~RY PRESSURE TEST RESULTS Shell Western E & P Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Fluid System: Test Method: Air-Water Porous-Plate Cell Pressure, psi 2 4 8 15 35 60 Permeability Sample Depth, to Air, Porosity, I.D. feet millidarcys .~eFcent* Brine Saturation, percent pore space 5 8605 2.6 5.1 100 93.9 89.7 81.8 75.2 10 8610 3.6 5.1 100 91.5 80.5 70.8 65.1 11 8611 9.7 6.1 93.1 85.1 73.3 64.2 57.5 13 8613 2.2 5.7 100 93.4 84.9 76.0 69.7 14 8614 7.2 6.5 86.3 78.8 68.4 59.8 53.7 15 8615 0.91 4.9 79.7 77.4 71.3 65.1 59.0 16 8616 2.4 5.0 100 96.9 89.1 80.6 73.2 21 8621 O. 53 3.5 90.8 85.5 75.1 68.3 61.5 73.9 58.6 56.7 67.5 53.6 58.1 66.9 60.8 * liquid resaturation porosity This report based on observations and materials supplied by the client is prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and r~ake no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE: LABORATORI£~. INC. DAI,.LAI. TI'XAI ~=ge. 5 o; 24 FileS CAL 305-86011 Com]:x:~7 Shell Weste.rn E & P Inc. We]) A- 33-11 Field Middle Ground Shoal Formation Hem. 1 ock County State ,, Al~,s~a 100 90-- Sample 5 Permeability to Air: 2.6 md 8O 7O 6O m 5o 3O 2O 10 0 0 Il IIIllllllllill}llllll]!lllllllllllllllllllllllllllllllllll 11 l! 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LI 1.1 i IJ II;lllllllllllllllllllllllllllllllllllllllllllltlllll IIII l..llllllIlllllllllIIllllll [llll[lllllllllllIIllllll IlllJllllllllllllllllllll [lll|lll]llllllllllllllll lllllllll}lll}lllllll}llllllll ,,lllllltlllllllllllll:ll ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ll]lllllllllllltlllllllll II IJ '""'"'"""~'""'~" llllllllllll'"llllllllll;,, lJlllllllllllllllllllllll l]llllllllllllllllllll]ll II!111111111111111111111111111111111111~111]111]111111111111tlI I111111111111111111!II]11 IlllllllllllllllllllllllllJ]lll]lllllll~lllllllllllllllllllllll Illlllllllil]lllll]llllll III Iil111111111111111111111! II I~II1111II!1]111111111]1| Illllllllllllllllllllllllllllllllllllllllllllll]lllllllllllllll I!11111111111111111]11111 ,,,,,,,,,,,,,,,,,,,,,,,,, ,llllllllllllllllllllll|lllllllllllllllll~]'llllllllllllllllllll IllllllllllJlll|llJlllJll IIIIIJlllllllllllllilllllllllllllllllllllllllllllllllllllllllll "~'""'""'""'""~' I!1111111111111111111i111 l~lllllllllllll]lllllllll ~llllll]llllll]llllllllllllllllllllllllllllll'&llllllllllllllllll ,,,,,,,,,,,,,,,,,,,,,,,,, lllllllllllllllllllllll|lllllllllllllilll~ll~,,llllllllllllllll UttlllJllllllllll[lllJll ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,~,,,,,,,,,,,,,,,, 1 ,,,,,,,,,,,,,,,,,,,,,,,,, Jl:llJJllJJl,,~lJlllllllllllll,lllllllJllllllJl,~,llllllllllllJl,,, ,~ ''JJJJJJJJJJJJJJJJJJJJJJJ]JJJJJJJJJJ'~"'JJJJJJJJJj ' I I~V'~ [Jlllllllllll llllli lllJ II i~ ]JJJ]J[]JJ~JJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJ[JJ]J~''. ,,..~JJJJJJJ IJII11111111111111111 llJl :] q II Ii llll|llllllllflll]llllllllllllllllllllllllll]llllllllJJJllJlJ~',,I..J [l]]]]]lJ]JJ]JJ]]J"J[J]J:~ ,,] 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE eL ~42 CORE I. ABORATORIES. INC. DAI. I,..A~, ?EXA~ Page 6 o! 24 F~e SCAL 305-86011 Com;~ny Shell Western E &, .P, Inc. Well A- 33- 11 Field Middle Ground ~ho~al " Formation He,rn, loc,k County Stcrte Alaska 100 90 80 70 6O m 50 m 40 30 2O 10 0 0 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE CL 342 CORE LABORATORIES. INC. DALI.Al, TI:XAt Page. 7 of 24 £fle SCAL 305-86011 Comp:m7 She. Il Western E & P Inc. : ' Field Middle Ground Shoal Formation Hemlock County State Alaska 100 90 Sample 11 Permeability to Air: 9.7 md 8O 7O 6O ~ 5O 30 2O 10 0 0 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE CL GOLPE LABOI~ATORI£S. INC. DALLAI, TEXAI 8. 24 Page _~ of File S .C, AL 305-86011 Core.m7 Shell West.,.ern. E & P Inc,. Well A- 33-11 Field Middle Ground Jho, al Formation H eml o ak County StYe ,. , Alas~ 100 90/ Sample 13 Permeability to Air: 2.2 md 8O 7O 6O 5O /40 3O 2O 10 0 0 II1].llllllJlll~ll[ll]lil i lllll111]]~lill]lIWIIl~llllltllllllllllllll11]lllll ,:"III,,,,,,,, ,,,,~,,,l[ll'llll![!!!llllll[lll. ,,,,,,,,,, ~ l[lll]llllllilllll:illilllllllll~llllllllllilillllt. I1111 II11! I11111111[111111111111[1 . |IIII illlllltlllllllllllllli] Illll llllllllllllllllllllllll II IIIII ~ I1 ,,,,,,,,,,,,,,,,,,,,,,,, '"'"'""'"'"'"'"' " ii ,,,,,,,,,,,,,,,,,,,~,,,, ,,llll,,lllllllllllllllllllllllllllllll ,,,,,, ,,,,,,,,,,,,,,,,,,,,,,,, ! 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[lllll I I1 J,,~ [J ] ]Jllllllllllllllllllll]]llllllll]llllllllllllllll]ll 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE CORE LABORATORIES. INC. DALI. Al, I'I'XAI Page 9 , o! 24 FHeS CAL .305-86011 Comp~nT..She. ll Western E.&., P Inc: Well A- 33-11 i i F~elcl Middle Ground Shoal Form~ion Heml o .c.k C~unty Stye . Al.aska 100 Sample 14 9) Permeability to Air: 7.2 md i ,;;ii' ;;;i;;;~ H :::::::::::::::::::::::: IIIIII, l~l'" lllllll, i l,,,,ll|lllil,.ll,,,,,,,,~,,,,,,,,,,,,,,,,,,,,,~,,,,~" 111111 Il llllllllllll.llllllllll I I 1 [.111111 I 1 ,~I IIIIIIIIIIIIIIIIIII IIIIIIII" llllll 1111 Ilillllllllllllllllll[lll]]]JJJ llllllIllllllllllllllllllllllllllllllllllllllll 7~ IIIII~ II IIIIIIIIIIII,IIIIIIIIIIIIIIII-II"',,.II,," IIIIIIIIII"'~'"'"'"'""'"'" I11111 Il IlllllllI]llillllllllllllllllllllilllllllllll!ll '"~",~,,,~ ~~~~]~~~~~~~.~~~! 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INC. DALI, A1, TI~XAI Page 10 of. 24 F~e SCA~, 305-86011 C~m~m¥, She,il Western .E. & P Inc. We1! A- 33-11 ii i 11 · F~elcl ,M. idJle Ground Shoal Formation Hemlock County StYe Alaska 100 90 80 70 60 m 50 r.o 40 30 20 10 0 0 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE CL ~2 lNG. Poge. il ot. 24 F~le S CAL .305-86011 Come.my Shel..1 Western E & P. Inc, .. Fonm~ion Hemlock W.~. A- ~ ~- 11 .. C~unt¥ ,. F~eld.. Middle Ground ~hoal St~ Alaska iii 100 90-- Sample 16 Permeability to Air: 2.4 md 8O 7O 6O m 50 m 40 3O 2O 10 0 0 IIT~ZllIJIIliJJIilIIIIIItlJlIIJliJ]I]IllilIIlilI[IIII[lilIII[Jl]I]]II]IlIII][ i11111 [ ill ] I llllllllJlllllll]lll]! i Illllllll]lllflllllllllJJJJlJIJJlllJJ ,,,,,""' !1111 llllll! ~]~T~]~]~~~~~~~~~~ I!111 ~~~~~~~~~~~~~~~~~~~~~~]~]]~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ III]11 ]11111111111111111111]11~111111111111~I~111111111111111~11111][11111111111tll I1[I I~I ,,,,,, , ,,I l~illl[lilll~llllll,~l~,lllllllll,,lllll'"l,,, ,,lllllllllllll,,,,,,llllI'"l,, II1]]1 ~~~~~~~~~~~~~~~~]~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~%~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ Illlll ~~~~~~~~~~~~~~~~|~~~~~~~~~~~~~~~~~~]~~~~~~~~~~~~~~~~~~~~~1~~~~~~~~~~~~~~~~~~~~~J~~~~~~~~~ llllll ,,,,,, ~~~~~~~~~~~]~~ l[llll II1111 ~~~]~~~~]~~[~~~~|~|~ " [lilll ]llllllllJill]]lllllll~lllllll]llllllllllllllllllll]lLlllllll%ll H 1t1111111111 llllllll ,,,,,,'"'" llllllllll]lliillllllllllllllllllllllllllll:lll]ll"]]illlll"',, ,,.,IIIIIIIIIIIIII!!! 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Stye Alaska ,, 100 90-- Sample 21 Permeability to Air: 0.53 md 8O 7O 6O m 5o m 40 3O 2O 10 0 0 ;:illi" ]iiiiiiiittltltiiiiii I Illll]11111Illlll1111111lll!ll]lll]lllllil]l]llllll I · Il II Illll JlJJJ JJJJJJJJJJJ'JJJJJJJJJJ ~JjJJJJJJJJJJJJJlJJJJJJJJJJJJJJJJJJJJJJJJJJjJJJJJJJ I1111 ]lllJlllllllllllllill L~J,, ,],,[,,,,1,~,,,J,,,J, JJ~JJJJJJJJ"'JJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJ., ,,,,, ,,,,,,,,.11.,,,,.,,,1 , .,,1,,,,,,,,1,1,,11,,,,,,,,,,,,,1,,,,,,, !1111 ] IIIIIIIIIIllllJlllllllllllllllllll jji ~1 IJ II , ,,,,1,'1"" ,,,,J,,,, ,,T,,I JJJJJJJJ"'JJ"J"JJJ.,,, ,, ,JJJJJJJJJJJJJJJJJJJJJJJJJJ, llllll Illllllll]lllllllllll I~! I il I ,JlJ~JJJJJll~JJlJ1, JJJJJJJJJJJ JJJJJJJJJJJJ,,,,,,,,,,,,,,,,,,,,, ,,,,,,,,,,,,,,,JJJJJJJJJJJJJJJJJJJJJJJJJ ,,,,,,']']" JJl,, jjjjjjjjjjj,,, 1 LIIII] illllllll(llll|llllll i l,'-kJlllllllllllllllllllllillllllllllllijj JJJJJJ JJJJJJJJJJJlJJJJJJJJJ i~JJJJ]JJJJJ~JJJJJJJJJJJJJJJJJJJJJJJJJJJlJJJJjJJJJJ 1III11 JlJllllllllll 111111 lllllllllllJlllllllll ,,i,,, L/Ill ,i,, ,,,,,l,,,,,J,,~,,,,,, , ,,,,,, t_]JJlJ ],ITILIIII,IIIIIIT,III 111111 llllllllllllllJlllllll ,,,,,, .lJJJJJJJJJJJJJJJJ~JJJJJ JJJJJJJJJ]JJJJH I11111 II1111111111tl]1111111 1111111111111]1111111111111111111111Illii111111111II .1 Il Il ,,TIIIIIII I , Il Il I ' JJJ ljjj l l~JJJJ ,]1,,, ,,,,]],,[~,i,[~,,,,1,, ,,,,111,,1,,i,1,,1,,,,,11,,,,i,,,,,,,,j~,,,,~,,~,,,, 'JJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJ II11tl llllllllillllllllll]ll 'lJJJJJJJJJJJJJJJJJJJJJJJJJJJJJJiJJJJJJJ [~,,J, ~,,,,]1,]]~],,],,,,,,, '[JJJJJJJJJ|; !! .I I .,JJJJJJJJJJJJJJJJJJJJ'"'JJJJJJJJJJJJJJJ~.[ JJJJJJ J ill JJJJJJ ill J'J J JJJJJJ {ill JJJJJJJJJJ~ JJ JJJJJJJJJ JJJJJJJJJJ JJ JJJJJJJJJJJJJJ JJJJJJ ll[IJl IliXJllll ']l'11 ' ! . 1.11111d 111111 111111]1 I11 111 I "]~'" ~4 '''" L,,,,, t111111111111111'1 1.1]lll [~]lll l[]llll]]llll]llllll] Ji]lllllll]llllll[~lll[llll]ll]llllllllllllll[llllll II1111 lllllllllllllllllll[ll lllllllJlllllllllll'~Jlllllllllllllllllllllllllllllll IlllJl llllll]lllllllll]llJll IIJIlIIIIlIIIlllIII1MIIIIlIIIIlllIIIlIIlIIIlIIIIIII ,Ij~j~jjjjjjjjjjjjjjjjjj~jjjjjjj Ill]Il II11111111lllll]llJ. 11 Illlll ]]JJlllllJlJJlll]lJJ]l Illllll]llllllllll]llll~lll]llllllllllllllllllllllll i,,1,[ lllllllllil'lll]lllill [1]I]1 lllllllllllIll.llllilll L.]]Jll ]llJ]lllll]l]l][Jlllll~ Ill I~1~]] I I111~ i I1]111 Till]Ii jjjj]jjjjjljjjj II II]111 II111111 IIII111[[1111111111111111~1~,11, [11111 ]111 I111111111111111111111111111111]111111]11111111111 H 10 20 30 40 50 60 70 80 90 100 BRINE SATURATION, PERCENT PORE SPACE CL 32+2 CORE LABORATORIES, INC. Special Core Analysis Page File 13 of 24 SCAL 305-86011 SPECIFIC PERMEABILITY TO WATER Shell Western Expl. and Prod. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Inc. Saturant: 17,00.0 ppm NaC1 brine Permeability Sample Depth, to Air, Porosity, I.D. feet millidargys . _.per.cen.t.. 13 8613 2.2 5.3 15 8615 0.91 4.9 21 8621 0.53 3.0 Specific Permeability to Water, millidarcys 500 psi 3000 psi I 2 I 2 0.07 0.07 0.03 0.03 0.03 0.03 0.01 0.01 0.02 0.02 0.01 0.01 Saturant: 4.0_ ,000' .ppm C1- brine Permeability Sample Depth, to Air, Porosity, I.D. feet millidarcys percent specific Permeability to Water, millidarcys 3000 psi I 2 5 8605 3.2 5.7 0.05 0.05 10 8610 4.1 5.5 0.05 0.06 11 8611 20 6.5 0.27 0.26 14 8614 8.3 6.6 0.18 0.18 16 8616 3.6 5.1 ~ 0.03 . 0.03 1) forward direction of flow 2) reverse direction of flow This report based on observations and materials supplied by the client is prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE LABORATORIES, INC. Special Core Analysis Page File 14 o£ 24 SCAL 305-86011 BRINE RECONSTRUCTION Shell Western Expl. and Prod. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Inc. Constituents Concentration, grams · , Sodium Chloride (NaC1) 32.00 Calcium Chloride (CaC12) 4.00 Potassium Chloride (KC1) 4.00 per liter Density- 0.965 g/cm3 at 77.0 degrees Fahrenheit Viscosity- 0.951 centipoise at 77.0 degrees Fahrenheit This report based on observations and materials supplied by the client ~s prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE LABORATORIES, INC. Special Core Analysis Page File 15 of 24 SCAL 305-86011 FORMATI~ R~IS'ITVITY FACTOR AND RESIS'HYITY INDEX S~ell Western Exploration and Production Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Saturant: 40,0OO ppm C1- brine Resistivity of Saturant: 0.1613 ohm-meters at 77.O° F Permeability Sample Depth, to Air, _ I .D. feet millidarcys1 Formation Porosity, Resistivity percent Factor 1 2 I 2 5 8605 3.2 5.7 5.4 142 211 10 8610 4.1 5.5 5.1 164 226 11 8611 20 6.5 5.7 110 162 14 8614 8.3 6.6 5.9 133 180 Brine Saturation, Resistivity percent pore space Index~ 100 1.00 83.0 1.69 68.6 2.42 64.8 2.72 100 1.00 84.2 1.63 64.3 2.83 60.8 3.21 59.9 3.32 63.9 3.14 57.4 4.60 56.8 4.83 65.2 2.59 58.8 3.52 16 8616 3.6 5.1 4.7 169 228 100 1.00 80.6 1.82 1 ) 500 psi confining stress 2) 3000 psi confining stress This report based on observations and materials supplied by the client ~s prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE LABORATORIES. INC. P~m~.um Rg~,'~' E~.~..rmg DALLAS. TEXAS Page 16 o! 24 File SCAL 305-86011 Company Shell Western E & P Inc. Well A-33-11 Field Middle Ground Shoal Formation County State Hemlock Alaska 1000 100 o o 10 O, 0.01 0.1 1.0 Porosity, fraction CL-846 CORE LABORATORIES. DALLAS. TEXAS INC. Page 17 ot 24 File S CAL 30 5- 86011 Comj:x:my Well Field Shell Western E & P Inc. A-33-11 Middle Ground Shoal Formation County State Hemlock 1000 100 o o 10 0 0.01 0.1 1.0 Porosity, fraction CL-846 CORE LABORATORIES, INC. Pa"m~m ~/..~,m~' E.~n~'~.I DALLAS. TEXAS Page 18 _ ot 24 File SCAL 305-86011 Coml:x:my Well Field Shell Western E & P Inc. Formation A- 33-11 County Middle Ground Shoal State Hemlock Alaska Rt 1.00 2.33 Sw 3000 psi Sample 5 Permeability to Air: 3.2 md I 0.01 0.1 1.0 Brine Saturation, Fraction CL 8&7/SCAL 4006 CORE LABORATORIES. INC. DALLAS, TEXAS Page 19 o! 24 File SCAL 305-86011 Compcmy Shell Western E & P Inc. Formation Well A- 33-11 County Field Middle Ground Shoal State Hemlock Alaska ....... · ...... - ....... ~ ~ Sample l0 3000 psi .'-"',:'~'-~ :': ............ - , .... ~ ~- -- .' ; i : ~ i : : ~ : ' -' :' ...... , ; : , ; ;i Iii Il:, 5 ;~i : ' ' : ......... ~ . ~ I ; . . . f .... , ....... : , ' · i , J .... ~ ~ , · - ; -: --' --; - ,,, : ~ : - , , , i %' ' i ' · 'i ~ 1 ............ ' ..... ' " I ~ ? ; I ~' '~ '~ ~ ' ~ ................ , : ' : : ' ' I i' : : ' . i i: ' ~ ' , ' n . : i I ~ ' : ' i: :,,: :::, ,::ii;::::-: :~:: ;::; ':::' :::' : :, :::~ , ' ~ ' ~{~'[~5~ ;~:H!L~i~':i~il~:;t~,~ } . ~ . . : 1 : : ..~.: ,__ , . ~, . , -.,,. : ,, .,:,. 4,,: I i ) I ~ , ~ :.; ' ~1 : :-: -: ~ · ' i - : ''' ~ -: ;:'; - , ~ 1~ I , {Ii 0.01 0.1 1.0 Brine Saturation, Fraction CL 8Z, 7/SCAL /-,006 CORE LABORATORIES. INC. DALLAS, TEXAS Page 20 of 24 File SCAL 305-86011 Compony Shell Western E & P Inc. Well A- 33-11 Field Middle Ground Shoal Formation County State Hemlock Alaska - ~: ~:~ ~J~i ~:.~u~i:.~ ~ J Sample 11 ~f.',~f~f~t'"~ ~ `,~ ~:~u:::~::::;.~.: Pe~eability to Air: 20 md -- ~ : r :~ '::~ ~ :~: .~;: :~:: ~;': ~ ::r-~-~ :: : ~ : 2~ ~'~r~r~r . : _ -~:t -']- ,: ::~::: : ; ~t ;i~~ ',::: :~:~:: , ~ :-:: t~:, .;~: ..... ~ i ] : ' : ~ J '--:~:~::-1' ~: ~'' ::i i~ i - , · :' f'~ 7:. ,, ; ; ~ ~ - ; ,~ :-~ ~r- ' ~ '-' t ' I r · - ~ : -, ; . ~ - -~ ~; ..... ,, I ii' ~ ~; ~;ji~', : i ' ''~ ;; '; i i ~ I ' t ~ ~i : ; ; ;':i- -;:' ~ ] . .2-: ~: ~::: '~ .... '.:/[~. ;!~ ,, . ~, .... : ~ :2~_ :~ ~ . : , .. .... ~ ~ ; : : ~ ] : .~ : : : : d -* ~, -I, :: :; ';:~ .: ] : J ; z t : ~zT: ~:;'= :.~-: .: ii: ;~ :;i - --I ':' : ::: ~ i f '~];:~:[ --~· ::= ;::'; '~' ~ ~: [-~ l::: ::! :~E- ~ = J ~ 1~-:7~ :,~ :: : : ~l! ~ ~: z ~ : i : t : i ; ~ ;_j :,.7 ::~ ] _ :~ : _ _ :., :1. ._,.1. ~ ~ ~ ~ ! ~ i . : ................ I .,l T I Z ~ i I 'J i ' ~ ] : ' ; :']i ~.; % '-' i ] L : . :~: :] ~: ~ ':2 : :i': ::12 2: ]':;:','2] ': :::i ~ ~ ~ ] . . :.]]~ ;;~: ':' ~::: :': : ' : : -:::-~ ~ : ~ i il : :~' i~ '-~- '':' ]- ~' : :' '~ ~i ii' ' ;'~:~: .... :;' ;:'t ~:,: :'~::'::'i~: ] ~ ~ ; ~'' ~,~I' !' ~ li'~ i~~ i-:~ ~:: ';:: :~:,.X" ' " '~'.~' i:~i ~ii'~li] ill!ii!"i , .' 0.01 O. 1 1.0 Brine Saturation, Fraction CL 8&7/SCAL 4006 CORE LABORATORIES. INC. DALI. AS. TEXAS Page 21 of 24 File $CAL 305-86011 Company Well Field Shell Western E & P Inc. A-33-11 Middle Ground Shoal Formation County State Hemlock Alaska Rt 1.00 2.25 3000 psi Sample 14 Permeability to Air: 8.3 md 0.01 0.1 1.0 Brine Saturation, Fraction CL 8~7/SCAL ~006 CORE LABORATORIES. INC. Pa"m~m J~..~.mmr E. zi~'e~.g DALLAS. TEXAS Page ~ o! ? 4 File SCAL 305-86011 Compcmy Shell Western E & P Inc. Well A- 33- 11 Field Middle Ground Shoal Formation County State Hemlock Alaska Rt 1.00 R 2.85 o ' Sw 3000 psi Sample 16 Permeability to Air: 3.6 md 1.0 0.01 0.1 1.0 Brine Saturation, Fraction CL 8/.,7/SCAL ~.006 CORE LABORATORIES. INC. DAL. I.A$. TEXAS Page- 23 o! 24 Fde SCAL 305-86011 Company Shell Western E & P Inc. Well A- 33- 11 Field Middle Ground Shoal Formation County State Hemlock Alaska 0.01 0.1 1.0 Brine Saturation, Fraction CL 8Z, 7/SCAL Z, 006 CORE LABORATORIES, INC. Special Core Analysis .~age 24 of 24 File SCAL 505-86011 CATION EXCHANGE CAPACITY Shell Western Expl, and Prod, A-55-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Inc. Sample Number 15 16 21 Identification Depth, feet Cation Exchange Capacity meq/lOO $* 8615 3,14 8616 2,69 8621 2.56 8603,3 2,85 8604,5 8,16 8609,5 4.76 8610,8 3,02 8620.2 3.61 8621 ,2 2,68 8622.7 9,65 *meq = milliequivalents This report based on observations and materials supplied by the client ]s prepared for the exclusive and confidential use by the client. The analyses, opinions or ~nterpretations contained herein represent the judgement of Core Laboratories, Inc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the productivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may' be used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS CORE ANALYSIS REPORT FOR S.W.E.F'.I. M I DDLE ALASKA 'l'hese analyses, opinions or interpretations are based on observati(ms and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The intermeluti ,ll~ ~r ,.'~p~ni~,n~ expressed represent tile best judgment ,.~f Core Laboratories, thc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with wl'dch such report is used or relied upon. 5295 HOLLISTER, HOUST~)N, TEXAS 77040 · 713/460-9600 CORE LABORATORIES, INC. February 20, 1986 Shell Western E & P Inc. P. O. Box 576 Houston, Texas 77001 Attention: Clay Williams WCK 1131 Re: A-33-11 Middle Ground Shoal Field Alaska File No.: 2202-15289 Dear Mr. Williams: Diamond coring equipment and water base drilling fluid were used to core the subject formation, intervals 8600.0 feet through 8626.5 feet and 9370.0 feet through 9376.0 feet, in the subject well. Recovered cores from these intervals were sampled and transported to Core Laboratories, Inc., in Houston, Texas, where a whole core analysis was performed on core no. 1 (8600 - 26.5 feet) and conventional plug analysis with Boyle's Law porosity was performed on core no. 2 (9370 - 96.0 feet). The results of these analyses are presented in tabular form on pages 1 and 2 of this report. The results are also presented in graphical form on the enclosed Correlation Coregraph. Note: Several streaks of yellow florescence were noted in the bottom of core no. 2. However, no florescence or oil content was found in the plug samples taken. Average core analysis data for the two zones are presented on pages 3 and 4 of this report. Permeability vs porosity plot data, plot, histogram statistics, and histogram for core analyzed from the subject well are presented on pages 5 through 10. The core from the subject well was photographed as requested. Core no. 1 was photographed before analysis and this core was not slabbed. Core no. 2 was analyzed and then slabbed. Photos were taken of the slabbed section of core. Both white light and ultra violet photos were taken of each foot. February 20, 1986 Shell Western E & P Inc. Page .2 The core and plug remnants from the subject well are stored at Core Laboratories, Inc., in Houston, Texas. Please advise of disposition of remnants. It has been a pleasure to be of service. Sincerely, CORE LABORATORIES, INC. Laboratory Manager MEF/pgw enclosure S,W.E,P,I. A-33-11 HIDDI. E GROUHD SHOAL FIELD ALASKA CORE LABORATORIES, INC. Petroleum Reserpoir Engineering DALLAS, TEXAS DATE t 27-JAN-86 FORMATION : DRLG, FLUIDI WATER BASE MUD LOCATION t WHOLE CORE ANALYSIS PAGE 1 FILE NO. t 2202-15289 LABORATORY : HOUSTON, TEXAS APl WELL ELEVATION SAMPLE NUMBER 1 2 4 5 6 7 B 9 10 11 12 14 15 16 17 18 19 20 21 22 23 DEPTH PERM MD PERM MD PERM MD FLD FEET HORIZ Ka 90DEG Ka VERT Ka POR He OIL% WTR% GRAIN POR PORE PORE DEN M DESCRIPTION CORE NO, 1 8600,0-8626.5 8600,0- 1,0 8601,0- 2,0 9.6 8602,0- 3.0 7.1 8603.0- 4.0 10,1 8604.0- 5,0 38. 2,4 2,5 8605,0- 6,0 22, 14. 5,1 8606.0- 7,0 9.3 8607.0- 8.0 7.5 6,3 3,0 8608,0- 9,0 18. 8.9 6,4 8609,0- 9.4 8609,4-10,0 6,8 8610,0-11.0 9,8 7,1 6,5 8611,0-12,0 29. 20. 16. 8612,0-13.0 15. 13, 5.9 8613,0-14.0 11. 9.4 8,2 8614.0-15,0 18, 15. 12, 8615.0-16,0 3,6 2.7 1,8 8616,0-17.0 7.1 5.0 3,6 8617,0-18,0 3,6 2.0 1.6 8618.0-19,0 5.0 3.6 6.9 8619,0-20.0 8620.0-21,0 6.4 4,7 3,2 8621.0-22.0 6.4 4.0 1.1 8622,0-23,0 2.4 1.6 1,4 8623.0-24.0 13. 6,8 5.8 9.3 8,0 43.6 13.3 60.0 11.5 46,0 6.5 13.1 41.8 5.7 10,2 43.2 6,4 56,0 5.6 13.6 54,6 B.2 9,4 51,1 14.6 58.3 6,0 9,2 43,9 6,5 10.9 51.6 5,8 11,8 53,3 6.3 10.0 51,5 6.1 11.6 55.0 6,2 18,7 41,0 5.5 9.8 43.0 5,8 14.5 43.4 5,2 13.6 62,4 16.5 45.8 5,4 6.0 40,6 3.6 15.8 50.5 5.0 13.2 39.7 6.9 15.8 48.5 RUBBLE CONG FG/MG SSLTY MAT EV YL FLU 45 API CONG FG/MG SSLTY MAT EV YL FLU 45 API CONG FG/MG SSLTY MAT EV YL FLU 40 API 2.65 CONG FG/MG SSLTY MAT EV YL FLU 40 APl 2.64 CONG FG/MG SSLTY MAT EV YL FLU 4? API CONG FG/MG SSLTY MAT EV YL FLU 46 APl 2.65 CONG FG/MG SSLTY MAT EV YL FLU 38 API 2.71 CONG FG/MG SS[.TY MAT EV YL FLU 40 APl SAMPLE PICKED IJP BY CLIENT CONG FG/MG SLTY MAT EV YL FLU 38 APl 2,66 CONG FG/HG SLFY MAT EV YL FLU 42 APl 2.65 CONG FG/MG SLTY MAT EV YL FLU 41 APl 2,65 CONG FG/MG SSLTY MAT EV YL FLU 41 APl 2.67 CONG FG/MG SSLTY HAl' EV YL FLU 41 APl 2,66 CONG FG/MG SSLTY MAT EV YL FLU 41 APl 2.68 CONG FG/MG SSLTY MAT EV YL FLU 37 API 2.67 CONG FG/MG SSLTY MAT EV YL FLU 41 APl 2.65 CONG FG/MG SLTY MAT SH/LAM EV YL FLU 36 API 2,65 CONG FG/MG SLTY MAT EV YL FLU 40 API CONG MG/CG SSLTY MAT EV YL FLU 37 APl 2,65 CONG MG/CG SSLTY MAT EV YL FLU 40 API 2.68 CONG MG/CG SSLTY MAT EV YL FLU 2.68 CONG MG/CG SSLTY MAT EV YL FLU 36 AP1 2.66 CONG M~/CG SLTY MAT SH/LAM EV YL FLU 36 APl ]'hese anaiy?,es, opinions or intetprelations are based on observations and materials supplied by the cliellt to whom, and for whose exclusive and confidenlial use, thJs report ~s expre.%ed represent the best judgment ,d' (Tore Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility ami make n(~ warran~ v ,~, representations, as to the productivity, pn~per operations, or profitableness of any oil, gas or other mtner~! well or -and in connection with wl'dch such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE t 27-JAN-86 FORMATION : WHOLE CORE ANALYSIS PAGE 2 FILE NO, ~ 2202-15289 LABORATORY : HOUSION, TEXAS SAMPLE NUMBER 24 25 26 27 28 29 30 31 32 33 34 35 36 37 39 40 41 42 43 44 45 46 47 48 49 DEPTH PERM MD PERM MD PERM MB FLD FEET HORIZ Ka 90BEG Ka VERI Ka POR 8624.0-25.0 3.9 3,6 2.7 8625.0-26,5 He OIL% WTR% GRAIN POR PORE PORE DEN M DESCRIPTION M, 6.6 12.1 51,5 2.66 CONG MG/CG S[.TY MAT SH/LAM EV YL FLU 40 APl RUBBLE CORE NO. 2 9370.0-9396,0 - CONVENTIONAL PLUG /~qALYSIS 9370,0-71.0 0.65 5,4 0.0 84.0 9371,0-72,0 0.98 5,6 0,0 59.3 9372.0-73.0 1,0 5.6 0.0 65.1 9373.0-74,0 0,41 5,0 0.0 83,3 9374o0-75.0 0.46 4.9 0.0 75.0 9375o0-76.0 0.67 5,1 0.0 56.7 9376.0-77.0 0.96 6.5 0,0 80.4 9377.0-78.0 0,67 6.0 0,0 66.0 9378.0-79,0 0.75 6,2 0,0 68,2 9379,0-80.0 0,55 5,7 0,0 81,6 9380,0-81,0 0,84 6.1 0.0 90.6 9381.0-82,0 0,61 5,4 0.0 58.1 9382,0-83,0 0.64 5.4 0.0 74.2 9383.0-84,0 0,67 5,6 0.0 75.0 9384.0-85.0 0.52 5.1 0.0 64°0 9385,0-86.0 0.45 6,0 0.0 76,9 9386.0-87.0 0,57 5.7 0.0 79,1 9387,0-fl8,0 0,59 6,2 0,0 78,7 9388.0-89,0 0.61 6.2 0.0 65,2 9389.0-90.0 0,26 5,4 0,0 60,0 9390o0-91,0 0.23 5.7 0.0 73.0 9391,0-92,0 0,61 5.7 0,0 65.7 9392.0-93.0 0.64 5.8 0,0 64.1 9393,0-94,0 0,58 5,4 0,0 55.0 9394.0-95,0 9395,0-96,0 0.44 5.0 0,0 56,5 2,66 SD FG NO FLU 2,66 SD FG NO FLU 2.66 SD FG NO FLU 2,65 SD FG NO FLU 2.65 SD FG NO FLU 2.64 SD FG NO FLU 2.65 SD FG NO FLU 2.64 SD FG NO FLU 2.65 SD FG NO FLU 2.64 SD FG NO FLU 2.65 SO FG NO FLU 2,65 SO FG NO FLU 2,65 SB FG NO FLU 2,64 SO FG NO FLU 2,66 SO FG NO FLU 2,65 SO F6 NO FLU 2,67 SD FG NO FLU 2,66 SD FG NO FLU 2.65 SO FG NO FLU 2,65 SD FG NO FLU 2.65 SD FG NO FLU 2,65 SD FG NO FI_U 2.65 SD FG NO FLU 2.67 SD FG NO FLU RUBBLE 2.67 SD FG NO FLU These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The imerpretathms or t)pmions expressed represent the best judgment of Core Loboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty {~r representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mtner~i well or sand in connection with which such report is used or relied upon. ~-33-11 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE : 27-JAN-86 FORMATION : *%* CORE SUMMARY AND CALCULATED RECOVERABLE OIL *~% PAGE FILE NO. ANALYSTS : ~n~-15289 ~ LV/SB/AG DEPTH INTERVAL: 8600,0 TO 8628,5 FEET OF CORE ANALYZED : 23.6 F'EET OF CORE -- SAMPLES FALLING WITHIN THE PERMEABILITY HORIZONTAL RANGE (Mil.) FLUID POROSITY RANGE (%) OIL SATURATION RANGE (%) WATER SATURATION RANGE (%) SHALE SAMPLES EXCLUDED FROM AVERAGES. FO INCLUr~ED IN AVERAGES: 18,0 LLOWING RANGES WERE 1.0 l'O 100. 0.0 TO 100,0 0.0 TO 100.0 0.0 TO 100.0 AVERAGED -- (UNCORRECTED FOR SLIPPAGE) ~VERAGE PERMEABILITY (MILLIDARCIES) ARITHMETIC PERMEABILITY ~ 12, GEOMETRIC PERMEABILITY t 9.2 HARMONIC PERMEABILITY : 7.0 i~RODUCTIVE CAPACITY (MILLIDARCY-FEET) ARITHMETIC CAPACITY GEOMETRIC CAPACITY HARMONIC CAPACITY ~VERAGE POROSITY (PERCENT) · 1VERhdE RESIDUAL OIL SATURATION (F'ERCENT OF F'ORE SPACE) 220, 165. 125. 5,9 AVERAGE TOI'AL WATER SATURATION (F'ERCENT OF PORE SF'ACE) ' AVERA~JE CONNATE WATER SATURATION (F'ERCENT OF PORE SPACE) 48.2 ~ (C) 48,').. OIL GRAVITY (AP1) : (M) 40.0 ORIGINAL SOLUTION GAS-OIL RATIO : (E) 1000. (CUBIC FEET PER BARREL) ORIGINAL FORMATION VOLUME FACTOR : (E) 1.57 12,1 (BBI. S SATURATED OIL/STOCK-'rANK BBL) ORIGINAL STOCK-TANK OIL IN PLACE : (C) 153. (BARRELS F'ER ACRE-FOOT) 3ALCULATEB MAXIMUM SOLUTION GAS BRIVE RECOVERY IS 27 BARRELS PER ACRE-FOOT, ASSUMING F'RODUCTION COULD BE CONTINUED UNT. IL RESERVOIR PRESSURE DECLINED TO ZERO PSIG, CALCULATED MAXIMUM WATER DRIVE RECOVERY IS 97 BARRELS PER ACRE-FOOT, ASSUMING FULL MAINTENANCE OF ORIGINAL RESERVOIR PRESSURE 100% AREAL AND VERTICAL COVERAGE, AND CONTINUATION OF PRODUCTION TO 100% WATER CUT, (C) CALCULATED (E) ESTIMATED (M) MEASURED ($) REFER TO ATTACHED LETTER, These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretati.ns or ,~pini(ms expressed represent thc best judgment of Core l_.boratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty {~r representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mlnetal well or s~nd in connection with which such report is used or retied upon. A-33-11 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS "' I DATE ; ~'.7-,. AN-86 FORMATION : CORE SUMMARY AVERAGES FOR 1 ZONE DEPTH INTERVAL: ?370.0 TO 9396.0 FEET OF CORE ANALYZEB ; 25,0 FEEl' OF CORE INCLUDED IN -- SAMPLES FALLING WITHIN THE FOLLOW]lNG RANGES WERE PERMEABILITY HORIZONTAL RANGE HELIUM POROSITY RANGE (%) OIL SATURATION RANGE (%) WATER SATURATION RANGE (%) PAGE 4 FILE NO. :-~)20-~-15~>87~ ~. ANALYSTS : LV/SB/AG AVERAGES: 25,0 AVERAGED .... (MD,) : 0,01 TO 10, (UNCORRECTED FOR SLIPF'AGE) : 1,0 TO 100.0 : 0.0 TO 100,0 : 0.0 TO 100,0 SHALE SAMF'LES EXCLUDED FROM AVERAGES, AVERAGEo FOR DEF'TH INTERVAL: 9370 0 TO 9396 0 AVERAGE PERMEABILITY (MILLIDARCIES) PRODUCTIVE CAPACITY (MILLIDARCY-FEET) ARITHMETIC PERMEABILITY : 0,61 ARITHME:TIC CAPACITY : 15, GEOMETRIC PERMEABILITY '~ 0,58 GEOMETRIC CAPACI'FY : 15, HARMONIC F'ERMEABILII'Y t 0,55 HARMONIC CAPACITY : 14, AVERAGE F'OROSITY (PERCENT) AVERAGE TOI'AL WATER SATURATION : 70,5 (PERCENT OF PORE SPACE) AV,.RAGE RESIDUAL OIL SATURATION ; 0,0 AVERAGE CONNATE WATER SATURATION ~.~. : 70,5 (PERCENT OF PORE SPACE) (PERCENT OF PORE SF'ACE) ESTIMATED FROM TOTAL WATER SATURATION. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive anti confidential use, this report is made. The interpre1:~t i~mx or ,,)pmitms expressed represent thc best judgmeat of Core L~boratories, inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make m) warramy ~,' representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mtneral well or ,and in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TIE XAS STATISTICAL DATA FOR POROSITY AND PERMEABILITY HISTOGRAM PAGE COMPANY: S.W.E.P.I. WELL : A-33-"11 FIELD : MIDDLE GROUND SHOAL FIELD COUNTY, STATE: ALASKA CORE NO, I CONG AIR F'ERMEABILITY : MD. ( HORIZONTAL ) RANGE USED POROSITY t PERCENT ( HELIUM ) RANGE USED 0.000 1'0 38. 0,0 TO 46.0 (F'ERMEABILITY UNCORRECTED FOR SLIPPAGE) DEPTH LIMITS (FEET) FEET ANALYZED IN ZONE 8600,0 - 8626,5 INTERVAL LENGTH 18.0 L. ITHOL. OGY EXCLUDEB NONE 26,5 POROSITY AVERAGE DATA SUMMARY PERMEABILITY AVERAGES ARITHMETIC HARMONIC GEOMEI'R IC 12, 7,0 l'hese analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretuti(ms ~,r ',H~mions expressed represent the best judgmeat of Core Laboratories, inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and empk)yees, assume no responsibility and make no warr:~n~y ~r representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral ~ell or sand in connection with which such report is used or relied upon. COMF'ANY: FIELD t CORE NO. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR F'OROSI'¥Y AND F'ERMEABILITY HISTOGRAM SoWoE.F'olo WELL : A-33.- 11 MIDDLE GROUND SHOAL FIELD COUNTY, STATE: ALASKA I CONG GROUPING BY POROSITY RANGES POROSITY FEET IN AVERAGE AVERAGE PERM, FREQUENCY RANGE RANGE POROSITY (GEOM.) (ARITH) (PERCENT) PAGE 6 CUMUI_ATIVF FREQUENCY (%) 2,0 - 4.0 1.0 3.6 6.4 6.4 5.6 5.6.. 4,0 - 6,0 8,0 5,5 6.8 8,6 44.4 50.0 6.0 - 8.0 8.0 6.4 12, 16, 44.4 94.4 8.0 - 10,0 1.0 8.2 18. 18. 5,6 100,0 TOTAL NUMBER OF FEET = 18.0 These ',lnalysc.~, opn~io;Is or intetprctattons are based on observations ,'tnd materials supplied by the client to whom, and for whose exclusive and conridential use, thi.~ report is made, Fhe ir. erpre~:,! expressed ~eptese,t thc best ,judgme,'~t of (;ore L,~boratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make represent:,tions, as to the productivity, proper operations, o~' profitableness of any oil, gas or other mineral well or sand in connection with wi-Ach such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR F'OROSITY AND PERMEABILITY HISTOGRAM COMF'ANY~ FIELD ~ CORE NO. S.W.E.F'.I, WELL ; A-33-11 MIDDLE GROUHD SHOAL FIELD COUNTY, STATE; AI_ASKA 1 CONG GROUF'ING BY PERMEABILITY RANGES PAGE 7 PERMEABILITY FEET IN AVERAGE PERM, AVERAGE FREQUENCY CUMULATIVE RANGE RANGE (GEOM.) (ARITH) POROSITY (PERCENT) FRE@UENCY (%) 1.250 - 2.500 1.0 2.4. 2.4. '~;~.,0 5,6 5,6 2,500 - 5,000 4,0 4,0 4,0 6,0 22,2 27,8 5.- 10. 5.0 7.3 7,4 5.?. 27.8 55, ,6 10.- 20. 5.0 15. 15, 6,7 27,8 83,S 20,-. 40. :3,0 29, 3;0, 6.2 16.7 100,0 TOTAL NUMBER OF FEET = 18.0 l'hese analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The imerpretations or c,pini(ms expressed represent the best judgment of Core Loboratories, Inc. (all errors and omissions excepted); but Core Iai>oratories, inc. and its officers and employees, assume no responsibility and make no warranty representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or s~nd in connection with which such report is used or relied upon. COMPANY: FIELD : CORE NO. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR POROSITY AND PERMEABILITY HISTOGRAM S,WoE,PoI. WELL. : A-33-11 MIDDLE GROUND SHOAL FIELD COUNTY, STATE: ALASKA 1 CONG F'OROSITY-FEET OF STORAGE PAGE 8 CAPACITY LOST FOR SELECTED F'OROSITY CUT OFF POROSITY FI--ET CAPACITY FEI-- T CAPACITY ARITH CUT OFF LOST LOST (%) REMAINING REMAINING (%) MEAN MEI) I AN 0,0 0.0 0o0 18,0 100,0 5,9 6o0 2,0 0.0 0,0 18.0 100.0 0,0 6,0 4.0 1.0 3°4 17,0 96.6 0o0 6ol 6.0 9,0 44,5 9.0 55.5 0,0 7,1 8.0 17.0 92,3 1.0 7.7 0,0 9.0 10.0 18,0 100,0 0,0 0,0 TOTAL STORAGE CAPACITY IN F'OROSITY-FEET = 106.9 '[hese analyses, opmi~ms or interpretations are based on observatioi~s, and ma;erials supplied by the client to whom. anti for whose e:.::c}usive and confidential use, this report is made. The imerpre~utim~x expressed represent the best judgmeat of Core Laboratories~ I~c. (all errors and o'mis~ons excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make representations, as to the product ivity, proper operations, or profitablenes,s of any oil, gas or other mineral well or mhd in connection with which such report is used or relied upon. COMPANYI FIELD CORE PAGE CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR POROSITY AND PERMEABILITY HISTOGRAM MIDDLE GROUND SHOAL FIELD 1.CONG WELL : A-33-11 COUNTY, S'rATEt ALASKA MILLIDARCY-FEET OF FLOW CAPACITY LOST FOR SELECTED PERMEABILITY CUT OFF' PERMEABILITY FEET CAPACITY CUT OFF LOST LOSI' (%) FEET CAPACITY GEOM REMAINING REMAINING (%) MEAN ME D I AN 0.005 0.0 0,0 18.0 100,0 ?.17 8.71 0,010 0,0 0,0 18.0 100.0 9.17 8.7:[ 0,020 0,0 0,0 18,0 100,0 9,17 8.71 0,039 0,0 0,0 18,0 100.0 9.17 8.71 0,078 0.0 0.0 18,0 100,0 9.17 8,71 0,156 0,0 0.0 18,0 100.0 9.17 8.71 0,S12 0,0 0,0 18,0 100,0 9.17 8.71 0.625 0,0 0~0 18.0 100,0 9,17 8~71 1,250 0.0 0,0 18,0 100,0 9,17 8.71 2.500 1.0 1,1 17.0 98,9 9,94 9.33 5, 5,0 8,4 13,0 91,6 13.17 12,31 10, 10,0 25,3 8,0 74.7 18.99 17.4]. 20, 15,0 59,5 3,0 40,5 28,96 28.28 40. 18,0 100,0 0,0 0.0 TOTAL. FLOW CAPACITY IN MILLIDARCY-FEET(ARITHMETIC) = 220,00 These an~dyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The in~erpret;,tion~ (,~ ,~)p~tdo~s expressed represent the best .iudgme,~t of Core L3boratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warra~tty ~r representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. f Se, I · e.e 4.e 8,e CL-1130 (7520-456) · POROSITY:PERCENT ~1977 · CORE LABORATORIES. iNC. - ALL RIGHTS RESERVED ~00 I I i i I / ! i i ~ i i i iI .......... · 90~- -. 90 80 ~' - 80 ' 70 70 . I.-.- ~wa:: 60-. i! -- 60 ~. mz {3.. ' . ~ 50- 50~ z ,,, 40 - -- 40 >- . 30 ~ 30 20 .- ,~ i ~. 20 10 . 10 0~ ~0 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 ~ POROSITY:PERCENT 100. . lO0 90 90 80 80 .. >' 50 50 ~ .. ! 30 20 .-- 2O ~0 . 10 0 l~l~~~~~ ~0 · 005 .01 .02 .04 .08 .16 .32 .64 1.25 2.5 5 10 20 40 80 160 320 640 1280 2560 512010240 ~O~O~'Jli, PERMEABILITY: MILLIDARCIES ! ~ERMEABILITY AND POROSITY HISTOGRAMS ~-$~-I ! AR~T.M[r~C MEAN ~OROS~TY ........... MEDIAN VALUE ~ CUMULATIVE FREQUENCY .,OR[ ~[~. I ~ CUMULATIVE CAPACITY LOST ....... · ,..~1977 · CCN:~ LA~:)RATORIES. INC · ALL RIC~TS RESERVED · I03gl7177/500 CL- ~L093 (7520-443) CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 12 STATISTICAL DATA FOR POROSITY AND PERMEABILITY HISTOGRAM COMPANY: FIELD : CORE NO, SoWoE,P,I, WELL : A-33-11 MIDBLE GROUND SHOAL FIELD COUNTY, STATE: ALASKA 2 SAND AIR PERMEABILITY : MD, ( HORIZONTAL ) RANGE USED 0,000 TO 1o POROSITY t PERCENT ( HELIUM ) RANGE USE[) 0,0 TO 46,0 (PERMEABILITY UNCORRECTED FOR SLIPPAGE) DEPTH LIMITS (FEET) FEEl' ANALYZED IN ZONE 9370,0 - 9396,0 INTERVAL LENGTH : 26,0 25,0 LITHOL. OBY EXCLUDED ; NONE DATA SUMMARY POROSITY AVERAGE 5,6 PERMEABILITY AVERAGES ARITHMETIC HARMONIC GEOMETRIC 0,61 0,55 0,58 These analyses, op,nions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made, The imerpret:~tions or opinions expressed represent the best judgment of Core l_,boratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no war~ar,~y ,r representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or mhd in connection with which such report is used or relied upon. COMPANY: FIELD : CORE NO, STATISTICAL CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATA FOR POROSITY AND F'ERMEABILITY HISTOGRAM S.W.E.P.I. WELL ; A-33-11 MIDDLE GROUND SHOAL FIELD COUNTY, STATE: ALASKA 2 SAND GROUPING BY POROSITY RANGES PAGE 13 POROSITY FEET IN AVERAGE AVERAGE PERM, FREQUENCY CUMULATIVE RANGE RANGE POROSITY (GEOM.) (ARITH) (F'ERCENT) FREQUENCY (%) 4.0 - 6.0 18.0 5.4 0.549 0.583 72.0 72.0 6.0 - 8,0 7.0 6,2 0,678 0,696 28,0 100,0 TOTAL NUMBER OF FEET = 25.0 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The i;m?rprot:~l.,:~, expressed represent the best judgn~eni .f Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibilily and make representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mtnermi well or mhd in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR POROSITY AND PERMEABILITY HISTOGRAM COMPANY: FIELD : [;ORE NO. S.W.E.F',I, WELL : A-3:3'- 11 MIDDLE GROUND SHOAl. FIELD COUNTY, STATE: ALASKA 2 SAND GROUPING BY PERMEABILITY RANGES F'AGE lq PERMEABILITY FEET IN AVERAGE PERM. AVERAGE FREQUENCY CUMULATIVE RANGE RANGE (GEOM.) (ARITH) POROSITY (F'ERCENT) FREQUENCY (%) 0.156- 0.:312 2.0 0.245 0.,.'~45 5.6 8.0 8.0 0.:312 - O.6~ ~.o 12.0 0.528 0.5:3,3 5 5 .48.0 56.0 0.625 - 10250 11.0 0,758 0.770 5°8 44.0 100.0 TOTAL NUMBER OF FEET = 25.0 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive anti confidential use, this report is made. The imerpret; ti,.m~ or t~pinions expressed represent the best .judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty .r representations, as to the productivity, proper operations, or profitablenexs of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. COMF'ANYI FIELD : CORE NO. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS STATISTICAL DATA FOR POROSITY AND PERHEABILITY HISTOGRAH S.W.E.P.I. MIDDLE GROUND SHOAL FIELD 2 SAND WELL ~ A-33-11 COUNTY, STATE~ ALASKA F'AGE 15 POROSITY-FEEl' OF STORAGE CAPACITY LOST FOR SELECI'ED POROSITY CUT OFF POROSITY FEET CAPACITY FEET CAPACITY ARITH CUT OFF LOST LOST (%) REMAINING REMAINING (%) MEAN MEDIAN 000 0.0 0.0 25.0 100,0 S.6~ ti~. 4 2.0 0.0 0.0 25,0 100,0 0.0 4.0 0.0 0.0 25.0 100.0 0.0 5.4 6,0 18.0 69,3 7.0 30,7 0,0 7,0 8.0 25.0 100.0 0.0 0.0 TOTAL STORAGE CAPACITY IN POROSITY-FEET = 140,7 'l'hcse ~ln~lyscs, opmioas or interpretations are based on obscrvations and materials supplied by the client to whom, and for whose exclusive :md confMen~i:]l t,,se, this report is made~ ',l,e im,~rDrel;~l i{ms o; ,,~l,n~i~m~ exp;essed represent thc best judgment of (lore Laboratories. Inc. (:ill errors and omi.~ions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and m:d:,~' nu wart:mir ~.' ~epresentations, as to the product ivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 16 STATISTICAL. DATA FOR POROSITY AND PERMEABILITY HISTOGRAM COMPANY; FIELD ; CORE NO. S.W.EoF'olo WELL t A-33-.11 MIDDLE GROUND SHOAL FIELD COUNTY, STATE; ALASKA 2 SAND MILLIDARCY-FEET OF FLOW CAF'ACITY LOST FOR SELECTED PERMEABILITY CUT OFF PERMEABILITY FEET CAPACITY FEET CAPACITY GEOM CUT OFF LOST LOST (%) REMAINING REMAINING (%) MEAN MEDIAN 0.005 0.0 0.0 25.0 100.0 0.58 0.57 0.010 0.0 0.0 25.0 100.0 0.58 0.57 0,020 0.0 0.0 25.0 100,0 0,58 0.57 0.039 0.0 0.0 25.0 100.0 0.58 0.57 0.078 0,0 0,0 25.0 100.0 0.58 0.57 0.156 0.0 0.0 25.0 100.0 0.58 0.57 0.312 2.0 3.2 23.0 96.8 0.63 0,61 0.625 14.0 44.9 11.0 55.1 0.76 0.88 1. 25'.0 100.0 0.0 0.0 TOTAL FLOW CAPACITY IN MII_LIDARCY-FEET(ARITHMETIC) = 15.36 'these analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or ,,)pini(ms expressed represent the best judgmeat of (Yore Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty m representations, as to the productivity, proper operations, or profitablene.~ of any oil, gas or other mime;al well or mhd in connection with which such report is used or relied upon. lO0 .100 90 go 80 80 -..I 70 70 ~ 60 6o~ .. >' 50' ,., 40 40 30i 30 · 20 20 10 10 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 ~ POROSITY:PERCENT 100. .100 90 90 70 70 ., ~>' 50 ? ! - 50 ~... m 40- -40 >- · 30 - . 20 ~ 20 ~0 . 0 .005 .01 .02 .04 .08 .'16 .32 .~ 1.25 2.5 5 10 20 40 80 '160 320 640 1280 2560 512010240 ~ PERMEABILITY: MILLIDARCIES PERMEABILITY AND POROSITY HISTOGRAMS J~-~-I I ARITHMETIC MEAN POROSITY ........... ~ ~ ~ m='~U) GEOMETRIC MEAN PERMEABILITY ........... MEDIAN VALUE "-J ~ CUMULATIVE FREQUENCY [,~R[ ~. 2~ ~ CUMULATIVE CAPACITY LOST ....... · (~1977 · CORE LA~,O~RATORIES. INC · ALL RIGHTS RESERVED · '103~/7/77/500 CL-1093 (7520-443) 18. · I · 8.1 PERMEABILITY VS. POROSITY $.W E P.! A-3~-I I HZDDLE GROUI~ SHOAL F.T~ · ALASKA ' CQI~ It0. 8.8 CL-1130 (7520-456) 8.8 12.1 le.l 21.t 24.1 POROSITY:PERCENT o_~. oo.~ ,~,,o.,,~o.,~. =.c · .,~ ,~,~.~s .~s~o CORE LABORATORIES, INC. COMPANY $,~.E.P.I. '~ELL Petroleum Resen,oir Engineering r,EL_O I~DDLE ~ ~ F]:FID r,L_E 2'2~2-1~289 A-33-11 COUNTY~ El ATE 27-gAN- 81t LOCATION STATE ELEV V~I~TICAL SCALE $" --- 100' PERMEABILITY MILLIDARCYS DEPTH FEET TOTAL WATER % PO~E SPACE 80 60 40 2'0 OIL SATURATION °/i P 0 ~'E SP~,CE 2,0 40 GO 80 , -4---- ;,- '+-- ¢ .... ...... t ..... ¢--~ ~ .... ~ - .~_ ~ . _ ~---~--~ - ~ , . -+- ~ i POROSITY PERCENT CORE LABORATORIES, INC. COMPANY S.W.E.P. I, WELL A-33-11 LOCATION Petroleum Reservoir Engineering FIELD MIDDLE GROUND SHOAL FILF 2202-15289 COUNTY. DATE 27-JAN-86 STATE ALASKA ELEV VERTICAL SCALE 5"-- !00' PERMEABILITY MILLIDARCYS TOTAL WATER % POCtE SPACE DEPTH e FEET OILSATURATION °/,,PORE SPACE 20 40 60 80 POROSITY PERCENT A-33-11 ALASKA CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE t 27-JAN-86 FIELD~ MIDDLE GROUHD SHOAL FIELD FILE NOt 2202-15289 ANALYSTt LV/SB/AG COPIES TOt DISTRIBUTION OF FINAL REPORTS cc SHELL WESTERN E&P INC. P. O. BOX 576 HOUSTON, TX 7~001 ATTN: CLAY WILLIAMS WCK 1131 cc SHELL WESTERN E&P INC. 601 W, 5TH SUITE 810 ANCHORAGE, AK 99501 ATTNt TIM PUTNAM 1 CC ATLANTIC RICHFIELD CO. P. O, BOX 360 ANCHORAGE, AK 99501 ATTH: R, K. DOUGHTY ~ cc CHEVRON, USA INC. F'o O. BOX 107839 ANCHORAGE, AK 99510 ATTN: J. Lo WEAVER 1 cc STATE OF' ALASKA ALASKA O~O CONSERVATION COMM 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: JOHN BOYLE These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The ~merp/etaitons or opm tons expressed represent the best judgmeat of Core Laboratories, Inc. (all errors and omissiom excepted); but Cot~ Labor,,torics, inc. and its officers and employees, assume no responsibility and make n- warranty representations, as to the productivity, proper operations, or profitableness of any oil, gas or othe~ malnmal ~ell or ~nd in connection with which such report is used or relied upon. A-33-11 HIDBLE GROUND SHOAL FIELD ALASKA CORE LABORA. DRIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE : 27-JAN-86 FORMATION DRLG. FLUID: WATER BASE MUD LOCATION WHOLE CORE ANALYSIS PAGE 1 FILE NO. : 2202-15289 LABORATORY | HOUSTON~ TEXAS API WELL ELEVATION SAHPLE NUMBER DEPTH FEET PERM MD PERM MB PERM MD FLD HORIZ Ka 90OEO Ka VERT Ka POR He OIL% WTR% GRAIN POR PORE PORE DEN M DESCRIPTION -------- ------------------. CORE NO. 1 8600.0-8626,5 8600.0- 1.0 1 8601.0- 2.0 2 8602.0- 3.0 8603.0- 4,0 4 8604.0- 5,0 5 8605.0- 6.0 6 8606°0- 7,0 7 8607.0- 8°0 8 8608.0- 9,0 8609,0- 9.4 9 8609.4-10,0 10 8610,0-11.0 11 8611,0-12,0 12 8612.0-13.0 8613.0-14.0 8614,0-15,0 15 8615.0-16.0 16. 8616,0-17,0 17 8617.0-18.0 18 8618.0-19,0 19 8619.0-20.0 20 8620,0-21.0 21 8621.0-22.0 22 8622.0-23.0 23 8623.0-24.0 'rhe~ alt~ RECEIVED 9.6 SEP 2 5 1986 7.1 10,1 38, Alaska Oil~ tias Cons. "' .... ~ '~': ...... 22, 14oAnch°rage 5,1 9,3 7.5 6.3 3.0 18. 8,9 6,4 9.8 7,1 6.5 29. 20, 16 d 15. 13. 5.9 11. 9.4 8.Z '18. 15. IL. 3.6 2.7 1.8 7.1 5.0 3.6 3.6 2.0 1.6 6,8 5,0 3,6 6.9 6.4 4.7 3,2 6.4 4.0 1.1 2,4 1.6 1.4 13, 6.8 5.8 9.3 8.0 43.6 13.3 60.0 11,5 46.0 6.5 13,1 41.8 5.7 10.2 43,2 6,4 56,0 5.6 13,6 54,6 8.2 9.4 51,1 14.6 58.3 6.0 9,2 43,9 6.5 10.9 51.6 5.8 11.8 53.3 6.3 10.0 51.5 6.1 11.6 55,0 6.2 18,7 41.0 5.S 9,8 43.0 5.8 14,5 43,4 5.2 13.6 62.4 16.5 45.8 5.4 6,0 40.6 3.6 15.8 50.5 5.0 13,2 39.7 6.9 15.8 48.5 RUBBLE COND FO/HO SSLTY HAT EV YL FLU 45 API CONB FG/MG SSLTY HAT EV YL FLU 45 API CONB FO/MO SSLTY MAT EV YL FLU 40 API 2.65 COND FO/MO SSLTY HAT EV YL FLU 40 APl 2.64 CONB FO/MO SSLTY HAT EV YL FLU 49 API CONB FO/MO SSLTY MAT EV YL FLU 46 API 2.65 CONB FO/MO SSLTY MAT EV YL FLU 38 API 2.71 COND FO~HO SSLTY HAT EV YL FLU 40 APl SAMPLE PICKED UP BY CLIENT COND FO/MO SLTY HAT EV YL FLU 38 APl 2.66 COND FO/MO SLTY HAT EV YL FLU 42 AP! 2.65 COND FO/HO SLTY MAT EV YL FLU 41 AP1 2.65 COND FO/MO SSLTY MAT EV YL FLU 41 API 2.67 COND FO/MO $SLTY HAT EV YL FLU 41 API 2,66 COND FO/MO SSLTY MAT EV YL FLU 41 API 2.68 CONB FO/MO SSLTY HAT EV YL FLU 37 APl 2,67 COND FO/MO SSLTY MAT EV YL FLU 41 APl 2.65 COND FO/HO SLTY HAT SH/LAH EV YL FLU 36 API 2,65 COND FG/MG SLTY MAT EV YL FLU 40 API COND MO/CO SSLTY MAT EV YL FLU 37 API 2.65 COND MO/CO SSLTY MAT EV YL FLU 40 API 2.68 CONB MO/CO SSLTY MAT EV YL FLU 2.68 CONB MO/CO SSLTY MAT EV YL FLU 36 API 2.66 CONB HO/CO SLTY HAT SH/LAH E¥ YL FLU 36 iAPI ~OjJlJJJJ:d on ob~rv:,,,o,, ,,,d ,n~,er~.,s suppl~ed by t~ c~n, ,o whom. and fo, who~ cxcluuve and confidenlul use tMs repo,t is made. Thc ime, pretat.,,n, u, ~Um,i,.,, ~ooratories. inc. (all errors and omi~o~ ex~pted); but Core ~ratories, inc. and its ofl'i~ts and employees, a~ume no ~esponsibih~y and ,nak~ n, war~:m,y ,,~ ~atio,u, or profitabiene~ of any oil, ~s o~ o1~ ~! web m ~d ~ ~cl~n with w~ch such [epo[t ~ u~d or [e~ed u~n. CORE LABOR..TORIES, INC. Petroleum Reservoir Engineering DATE : 27-JAN-86 FORMATION WHOLE CORE ANALYSIS PAGE 2 FILE NO. : 2202-15289 LABORATORY | HOUSTON, TEXAS SAMPLE NUMBER 24 25 26 27 28 29 30 31 32 33 34 35 36 37 40 41 42 43 44 45 46 47 48 49 DEPTH FEET PERM MD PERM MD PERM MD FLD HORIZ Ka 90DEG Em VERT Em POR 8624.0-25.0 3.9 3.6 2,7 8625,0-26,5 He OILZ WTRZ GRAIN POR PORE PORE DEN M DESCRIPTION 6,6 12,1 51,5 2,66 COND MG/CG SLTY MAT SH/LAM EV YL FLU 40 APl RUBBLE CCRE NO, 2 9370.0-9396.0 - CONVENTIOhLAL PLUG AJ~LALYSIS 9370.0-71.0 0.65 5.4 0.0 84.0 9371.0-72.0 0.98 5.6 0.0 9372.0-73.0 1.0 5.6 0.0 65.1 9373;.0-74,0 0,41 5,0 0,0 83,3; 9374,0-75,0 0,46 4,9 0,0 75,0 9375,0-76,0 0.67 5,1 0.0 56,7 9376.0-77,0 0,96 6.5 0,0 80,4 9377.0-78,0 0,67 6,0 0,0 66,0 9378,0-79,0 0,75 6.2 0,0 68.2 9379,0-80,0 0.55 5.7 0,0 81,6 9380,0-81.0 0.84 ~ 6.1 0,0 90,6 9381.0-82.0 0,61 ~ 5,4 0.0 58,1 9382.0-83.0 0,64 ~ 5.4 0,0 74,2 9383.0-84,0 0,67 _o. -~ ~ 5,6 0,0 75,0 9384.0-85,0 0.52 ~ -D m 5,1 0.0 64.0 9385,0-86,0 0.45 .~ Po m 6.0 0,0 76,9 9386.0-87.0 0.57 R~ ~r~ ---, 5.7 0.0 79,1 c..:~ ~, ~_~ ~ 6,2 0,0 78.7 9~87,0-88,0 0.59 ~,:~ ' cc> 9388.0-89.0 0.61 c '-'::cr~ ~ 6,2 0.0 65.2 9389,0-90,0 0,26 ~.~. 5.4 0,0 60,0 9390.0-91,0 0,23 .% 5.7 0,0 73,0 91391,0-92.0 0,61 " 5.7 0,0 65.7 9392,0-93.0 0.64 5.8 0.0 64.1 9393,0-94.0 0,58 5,4 0,0 55,0 9395,0-96.0 0,44 5.0 0,0 56,5 2,66 SD FG NO FLU 2,66 SO FB NO FLU 2,66 SD FG NO FLU 2,65 SD FG NO FLU 2,65 SD FG NO FLU 2,64 SD FG NO FLU 2.65 SD FG NO FLU 2,64 SD FG NO FLU 2,65 SD FG NO FLU 2,64 SD FG NO FLU 2,65 SD FG NO FLU 2,65 SD FB NO FLU 2,65 SD FG NO FLU 2,64 SD F6 NO FLU 2,66 SD FB NO FLU 2,65 SD FG NO FLU 2,67 SD FB NO FLU 2,66 SD FG NO FLU 2.65 SD FG NO FLU 2,65 SD FG NO FLU 2.65 SD FG NO FLU 2,65 SD FG NO FLU 2,65 SD FB NO FLU 2,67 SD FG NO FLU 2,67 SD FG NO FLU 'l~hc~ as~alyses, opinions or inlcrpretalions are based on observations and materials supplied by tl~ client to whom, and for whose exclusive and confidential use, this ;eport is made, The imerp~etal.mx expsessed represent the best judgme,~t of Core L~boratories, Inc. (all errors and omissions .xc~pt.d); h~t C¢~ Lnborntori~s, lac. ~nd its officers and employees, assume no responsibility alid make representauons, as to the productivity, proper operations, or profitableness of any oil, I~S or othcn min~nl ~11 o~ ~nd in connection with which such report is used or relied upon. Gyrod at a CONFIDENTIAL D i r e c t i o n a 1 Survey SHELL WESTERN EXPLORATION & PRODUCTION MIDDLE GROUND SHOAL PLATFORM A, WELL ~A-33-11 Date Run: 1-FEB-86 23:30:0 Job Number: AKO186G034 Surveyor: PAUL J. D'AMICO Calculation Method: RADIUS DF CURVATURE Proposed Well Direction: B 74deg 36Nih Osec W Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference CERTIFIED SURVEY SHELL WESTERN E & P INC. MIDDLE GROUND SHOAL PLATFORM A, WELL NO. A-33-11 MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg 196. 0 0 0 200.0 0 34 300.0 0 40 400. 0 8 9 500,0 4 11 600.0 4 56 700.0 3 55 800.0 6 56 900.0 10 29 1000.0 12 51 1100.0 13 32 1200.0 14 40 1300.0 15 21 1400.0 15 9 1500.0 14 36 1600.0 13 56 1700.0 13 29 1800.0 14 27 1900.0 15 47 2000.0 16 38 2100.0 17 3 2200.0 16 40 2300.0 16 35 2400.0 16 12 2500.0 16 0 N · OE N 1856W N7441 W S 47 37 W B 1748W CONFIDENTIAL VERT VERT DEPTH SECTION ft ft CLOSURE DISTANCE BEARING ft deg min 196.0 0.0 0.0 N 0 0 E ASSUMED VERTICAL TO MUDLINE 200.0 .0 .0 N 18 56 W 300.0 .5 1.0 N 46 19 W 400.0 2.9 3.1 N 86 45 W 499.8 7.0 7.4 8 ~3 36 W S 25 33 W 599.5 11.7 S 66 11 W 699.2 18.4 N 82 25 W 798.7 27.6 N 79 56 W 897.6 41.4 N 82 2 W 995.5 59.8 N 89 7 W 1092.8 81.3 S 86 6 W 1189.8 104.9 S 85 17 W 1286.4 130.3 S 85 44 W 1382.9 156.2 S 86 39 W 1479.5 181.3 S 86 35 W 1576.5 205.4 S 86 57 W 1673.6 228.6 S 86 8 W 1770.7 252.2 S 86 19 W 1867.2 277.7 S 86 30 W 1963.2 305.1 S 86 27 W 2058.9 333.4 S 87 2 W 2154.6 361.8 S 87 30 W 2250.4 389.7 S 88 10 W 2346.4 417.2 S 88 6 W 2442.5 444.1 14.8 S 37 5 W 28.3 S 40 3 W 29.9 S 52 5 W 41.8 S 67 23 W 59.9 S 77 35 W 82.0 S 82 18 W 106.3 S 83 38 W 132.1 S 84 2 W 158.4 S 84 17 W 184.1 S 84 33 W 208.7 S 84 48 W 238.4 S 85 0 W 256.5 S 85 ~ 8 W 282.6 S 85 14 W 310.5 S 85 21 W 339.5 S 85 26 W 368.5 S 85 33 W 397.1 S 85 40 W 425.3 S 85 49 W 453.0 S 85 57 W ~ , ~' ~) ~ .... ,.~ HORI ZONT~L feet .0 N .0 E .0 N .0 W .7 N .8 W .8 N 3.0 W 4.4 B 6.0 W 11.8 S 8.9 W 17.1 S 14.3 W 18.4 S 23.6 W 16.1 S 38.6 W 12.9 S 58.5 W 11. I S 81.3 W 11.8 S 105.6 W 13.7 S 131.4 W 15.8 S 157.6 W 17.5 S 183.2 W 18.9 S 207.8 W 20.5 S 231.5 W 21.~Z S 255.6 W 83.5 S 881.6 W 85.2 S 309.5 W 27.0 S 338.4 W 28.6 S 367.4 W 30.0 S 396.0 W 31.1 S 424.2 W 38.0 S 451.9 W Page DOG-LEG SEVERITY de§/100' 0.00 13.96 .58 1.88 2.55 .98 3.22 4.13 3.57 2.40 1.76 1.62 .71 .83 .60 .65 .46 .97 1.35 .85 .42 .42 .16 .43 .19 SHELL WESTERN E & P INC. MIDDEE GROUND SHOAL PLATFORM A, WELL NO. A-33-11 MEA9 INCL BORE HOLE DEPTH BEARING ft dmg min dmg min 2600.0 15 58 2700.0 15 26 ~.!12800.0 15 28 2900.0 15 8 3000.0 15 9 3100.0 14 45 3200.0 14 30 3300.0 14 19 3400.0 14 8 3500.0 14 17 3600.0 14 25 3700.0 14 2 3800.0 13 57 3900.0 14 40 4000.0 15 41 4100.0 16 25 4200.0 17 4 4300.0 17 27 4400.0 16 59 4500.0 16 16 4600.0 16 19 4700.0 16 21 4800.0 15 53 4900.0 15 39 5000.0 15 16 S8821 W S88 16W S 86 56 W S87 13W S 87 47 W S89 7W S 89 34 W S8951 W N89 7W N 87 32 W N 85 55 W N 84 56 W N 83 36 W N81 55W N 80 24 W N 78 56 W N77 11 W N 76 24 W N 82 44 W S89 13W S 86 40 W S 87 38 W S88 6W S89 13W N8911W VERT DEPTH ft 2538.6 2634.9 2731.2 2827.7 2924.2 3020.8 3117.6 3214.5 3311.4 3408.3 3505.2 3602.1 3699.2 3796.1 3892.6 3988.7 4084.4 4179.9 4275.5 4371.3 4467.3 4563.2 4659.3 4755.5 4851.9 CONFIDENTIAL VERT SECTION ft 470.9 497.2 523.1 548.9 574.4 599.4 623.8 647.8 671.5 695.0 718.4 741.5 764.1 786.9 810.8 835.7 861.3 887,3 914.0 941.0 968.3 995.8 1022.8 1049.2 1074.9 CLOSURE DISTANCE BEARING ft drag mi n 480.5 S 86 5 W 507.6 S 86 12 W 534.2 S 86 16 W 560.5 S 86 19 W 586.7 S 86 22 W 612.5 S 86 27 W 637.7 $ 86 34 W 662.5 S 86 41W 687.0 S 86 49 W 711.5 S 86 59 W 736.1 S 87 12 W 760.5 S 87 26 W 784.4 S 87 41 W 808.8 S 87 59 W 834.6 S 88 19 W 861.6 S 88 42 W 889.7 S 89 7 W 918,5 B 89 34 W 947.6 S 89 55 W 976.1 N 89 59 W 1004.2 S 89 57 W 1032.2 S 89 53 W 1060.0 S 89 49 W 1087.2 S 89 48 W 1113.8 S 89 48 W HORIZONTAL COORD feet 32.8 S 479.4 W 33.6 S 506·4 W 34.7 S 533.0 W 36.1 S 559.4 W 37.2 S 585.5 W 37.9 S 611.3 W 38.2 S 636.5 W . 38.3 S 661.4 W 38.2 S 686.0 W 37.5 S 710.5 W 36.1 S 735.2 W 34.1 S 759.7 W 31.7 S 783.8 W 28.6 S 808.3 W 24.5 S 834.2 W 19.6 S 861.4 W 13.6 S 889.6 W 6.8 B 918.5 W 1.5 S 947.6 W .1 N 976.1 W .9 S 1004.2 W 2.3 S 1032.2 W 3.3 S 1060.0 W 3.9 S 1087.2 W 3.9 S 1113.8 W Page DOB-LEG SEVERITY dmg/100' · 08 .52 .35 .33 .15 · 52 .29 .19 .31 .42 .42 .46 .33 .82 1.09 .84 .82 .44 1.93 2.41 .71 · 28 .48 .39 .57 SHELL WESTERN E & P INC. MIDDLE GROUND SHOAL PLATFORM A, WELL NO. A-33-11 MEAB INCL BORE HOLE VERT VERT DEPTH BEARING DEPTH SECTION ft deg mtn deg min ft ft 5100.0 15 6 N 88 15 W 4948.4 1099.9 5200.0 14 48 N 87 31W 5045.0 1124.5 5300.0 14 49 N 87 5 W 5141.7 1148.9 5400.0 14 49 N 85 34 W 5238.4 1172.9 5500.0 14 47 N 84 29 W 5335.1 1196.9 5600.0 14 20 N 83 2? W 5431.9 12~0.3 5?00.0 14 4 N 82 25 W 5528.8 1243.0 5800.0 14 30 N 81 40 W 5625.7 1265.6 5900.0 14 56 N 80 53 W ~'72~.~ 1288.6 6000.0 15 12 N 79 27 W 5819.1 1311.8 6100.0 15 18 N ?8 35 W 5915.6 1335.4 6200.0 15 11 N 78 0 W 6012.1 1358.8 6300.0 14 43 N 76 12 W 6108.? 1381.5 6400.0 14 53 N 74 37 W 6~05.4 1403.6 CONFIDENTIAL C L 0 S U R E DISTANCE BEARING ft deg min 1140.0 S 89 50 W 1165.8 S 89 53 W 1191.3 S 89 57 W 1216.8 N 89 59 W 1242.2 N 89 53 W 1267.2 N 89 46 W 1291.6 N 89 88 W 1316.1 N 89 29 W 1340.9 N 89 20 W 1366.3 N 89 10 W 1392.2 N 88 58 W 1418.0 N 88 47 W 1443.3 N 88 34 W 1468.2 N 88 21 W HORIZONTAL COORD feet 3.3 S 1140.0 W 2.4 S 1165.8 W 1.2 S 1191.3 W .5 N 1216.8 W 2.7 N 1242.2 W 5.3 N 1267.2 W 8.3 N 1291.6 W 11.? N 1316.0 W 15.6 N 1340.8 W 19.9 N 1366.2 W 25.0 N 1392.0 W 30.3 N 1417.? W 36.1 N 1442.9 W 42.5 N 1467.6 W Page DOG-LEG SEVERITY deg/100' .30 .36 .11 .39 .28 .52 .36 .46 .22 .71 .25 .19 .66 .44 Final Station Closure: 1468.2 feet North 88 deg 20 rain 30 sec West SHELL WESTERN EXPLORATION & PRODUCTION MIDDLE GROUND SHOAL PLATFORM A, WELL #A-33-1! MEAS INCL BORE HOLE DEPTH BEARING 6400.0 14 53 N 74 37 W 6500.0 11 50 N 71 42 W 6600.0 10 29 N 65 22 W 6700.0 8 40 N 74 51 W 6800.0 7 14 N 86 48 W 6900.0 3 44 N 75 31 W 7000.0 2 52 N 68 32 W 7100.0 2 18 N 59 22 W 7.°00.0 1 16 N 13 39 E 7300.0 2 15 N 60 29 E 7400.0 3 24 N 70 16 E 7500.0 4 28 N 77 25 E 7600.0 6 11 N 82 45 E 7700.0 6 59 N 82 40 E 7800.0 7 49 N 82 48 E 7900.0 9 6 N 84 22 E 8000.0 10 41 N 84 14 E 8100.0 11 39 N 86 25 E 8200.0 12 10 S 89 3 E 8300.0 14 20 N 89 37 E 8400.0 15 8 N 88 2 E 8500.0 16 9 N 89 15 E 8600.0 17 48 N 89 25 E 8700.0 18 37 S 89 55 E 8800.0 20 3 S 89 22 E CONFIDENTIAL MERT VERT DEPTH SECTION ft ft CLOSURE DISTANCE BEARING fb deg. ~]i~ 6205.4 1403.6 1468.2 N 88 20 W TIE-IN TO GYRODATA SURVEY NUMBER AKO186G031 86400' 6302.7 1423.2 1490.5 N 88 7 W 6400.8 1438.6 1508.8 N 87 52 W 6499.4 1452.2 1524.6 N 87 4.0 W 6598.4 1464.7 1538.3 N 87 37 W 6698.0 1473.4 6797.8 1478.2 6897.7 1481.6 6997.6 1482.0 7097.6 1479.6 7197.5 1474.8 7897.2 1467.9 7396.8 1458.7 7496.1 1447.3 7595.3 1434.6 7694.2 1420.0 7792.7 1403.1 7890.8 1384.0 7988.7 1364.0 8086.0 1348.0 8182.7 1317.3 8279.0 1291.2 8374.7 1'262.9 8469.6 1232.8 8564.0 1200.9 1547.8 N 87 34 W 1553.3 N 87 31W 1557.4 N 87 27 W 1558.7 N 87 21 W 1557.0 N 87 16 W 1558.6 N 87 11W 1546.1 N 87 6 W 1537.1 N 87 1W 1525.8 N 86 57 W 1513.1 N 86 51 W 1498.6 N 86 46 W 1481.6 N 86 39 W 1462.5 N 86 33 W 1441.9 N 86 29 W 1419.0 N 86 26 W 1393.7 N 86 21 W 1366.8 N 86 15 W 1337.7 N 86 9 W 1306.6 N 86 3 W 1273.5 N 85 58 W H 0 R I Z 0 N T A L DOG-L~!. COORD o ', ~EVE & I 42.5 N 1467.6 W 0.8~ 49.2 N 1489.7 W 3.14. 56.3 N 1507.7 W 1.82 61.9 N 1523.3 W 2.41 64.1 N 1536.9 W 2.18 65.6 N 1546.4 W 3.65 67.4 N 1551.8 W . 69.3 N 1555.9 W .7~! ~72.0 N 1557.0 W '~' 2. 74.4 N 1555.2 W 1. 76.4 N 1550.7 W 1 ,.,~., 78.3 N 1544.1W 1.17 79.9 N 1535.0 W 1.77 81.4 N 1523.6 W 83.0 N 1510.9 W .85 84.7 N 1496.2 W 86.4 N 1479.1 W 1. 88.0 N 1459.8 W 1. 88.4 N 1439.2 W 88.3 N 1416.3 W 2. 88.8 N 1390.9 W .9'~ 89.5 N 1363.9 W 1.0~~ 89.8 N 1334.7 W 1.65 90.0 N 1303.5 W 89.7 N 1270.4 W 1.44 SHELL WESTERN EXPLORATION & PR[]DUCTION MIDDLE GROUND SHOAL PLATFORM A, WELL #A-33-1 1 MEAS INCL BORE HOLE DEPTH BEAR I NG ft deg rain deg r~in 8900.0 21 16 S 89 30 E ', 9000.0 21 38 S 87 12 E ~ 9100.0 21 24 S 84 43 E 9200.0 21 5 S 82 14 E 9300.0 20 12 S 80 46 E 9400·0 19 56 S 80 43 E 9500.0 18 30 S 78 55 E 9600.0 17 2 S 78 6 E 9700.0 17 27 S 78 28 E 9800.0 17 49 S 79 50 E 9880.0 17 59 S 79 25 E Final Station Closure: 931.3 feet CONFIDENTIAL VERT VERT DEPTH SECTION ft ft 8657.6 1167.0 8750.6 1132.1 8843.7 1097.5 8936.9 1063.9 9030.5 1031.6 9124.4 1000.4 9218.8 970.7 9314.0 943.5 9409.5 917·2 9504.9 890.0 9523.9 884.5 CLOSURE DISTANCE BEARING ft deg min 1238.3 N 85 52 W 1201.8 N 85 47 W 1165.1 N 85 47 W 1128.9 N 85 51 W 1093.8 N 86 0 W 1059.6 N 86 10 W 1026.9 N 86 22 W 996.7 N 86 36 W 967.4 N 86 52 W 937.4 N 87 7 W 931.3 N 87 9 W North 87 deg 9 min 27 sec West H'O R I Z 0 N T A L COORD feet 89.4 N 12B5.1W 88.3 N 1198·6 W 85.8 N 1162.0 W 81.6 N 1126.0 W 76.4 N 1091.1 W 70.9 N 1057.2 W 65·1 N 1024.8 W 59.0 N 994.9 W 53·0 N 965·9 W 47.3 N 936.2 W 46.2 N 930.1 W Page DOG-LEG SEVER I TY deg/100' 1.22 .92 · 94 .96 1.01 · 27 1.56 1·49 .43 .56 1.03 SIDEWALL CORE ANALYSIS REPORT 30261011 FOR SHELL WESTERN E&P, INC. ALASKA DIVISION A-33-11 WELL MIDDLE GROUND SHOAL FIELD HEMLOCK FORMATION ALASKA PREPARED BY: NL ERCO/NL INDUSTRI[S HOUSTON, TX 77090 (713) 874-2600 The analyses, interpretations or opinions expressed in this report represent the best judgment of NL Erco, a division of NL Industries, Inc., and it assumes no responsibility, and makes no warranty or representations, as to the productivity, proper operations or profitability of any oil, gas or other mineral well. The analyses, opinions or interpretations are based on observations and materials provided by the client for whom this report is made. SHELL WESTERN E&P INC. CORING CO.: DRESSER-ATLAS FILE: 30261011 A-33-11 ~ELL FORMATION: ANALYST: ROHN MIDDLE GROUND SHOAL FIELD DRLG. FLUID: LABORATORY: HOUSTON ALASKA DATE: 2-18-86 SIDEWALL CORE ANALYSIS ...... SATURATION ...... REC DEPTH PERM POR ---% PV--- (IN) (FT) (MD) (%) OIL W'I'R 0.3 6537 O.O 6544 0.2 6550 0.4 6555 0.4 6560 0.0 6605 0.0 6643 0.0 6651 0.4 6659 0.4 6667 1.0 6686 0.6 6694 0.5 6700 1.1 6707 1.0 6750 0.3 6755 0.3 6760 0.3 6769 0.7 6778 1.1 6802 0.5 15.4 0.0 65.4 0.5 15.8 0.0 73.1 7.0 21.8 9.0 77.5 11.0 16.6 0.0 74.3 )0.01 9.2 0.0 70.1 31.0 10.8 0.0 73.8 18.0 17.1 0.0 58.7 9.6 22.8 0.0 79.5 5.0 12.2 0.0 61.5 3.2 16.6 0.0 55.6 5.0 18.9 0.0 0.0 15.0 28.3 0.O 75.7 4.8 24.2 8.3 49.1 1.0 17.O 0.0 68.9 0.0 0.0 0.0 0.0 8.3 16.3 0.0 51.8 ---~ BV--- PRO8 035 CRIT IrrR OIL GAS PR(X) GAS (Y,) SAMPLE LITHOLOGICAL DESCRIPTION 5.3 (6)~ 0 70 SD LT GRY V FGR SLT SH LAM NO FLUOR NO CUT 0.0 4.3 ~ 0 2 .O 2.9 * 0 0.0 4.3 ~ 0 0.0 2.8 (6)~ 0 O.0 2.8 WTR* 0 0.0 7.1 GAS~ 0 0.0 4.7 (6)* 0 0.0 4.7 (6)~ 0 0.0 7.4 (6)~ 0 0.0 18.9 (6)* 0 0.0 6.9 WTR* 0 2.0 10.3 (6)~ 0 0.0 5.3 (6)* 0 0.0 0.0 0 0 0.0 7.9 (6)* 0 NO RECOVERY 76 SD LT BRN V FGR V SLTY P SRT SPTD YEL FLUOR FR CUT' 71 SD LT BRN V FGR V SLTY P SRT SPTD YEL FLUOR FR CUT (38 DEGREES APl) 59 SD LT BRN V FGR V SLTY P SRT SPTD YEL FLUOR FR CUT NO RECOVERY NO RECOVERY NO RECOVERY 70 SD ~ V FGR V SLTY P SRT CARB SPTD YEL FLUOR FR CUT 44 SD WH V FGR V SLTY P SRT CARB SPTD YEL FLUOR FR CUT 56 SD ~1 V FGR V SLTY NO FLUOR NO CUT 71 SD LT GRY V FGR SLT NO FLUOR NO CUT 57 SD LT GRY V FGR SLT CARB NO FLUOR NO CUT 68 SD LT GRY V FGR SLT CARB NO FLUOR NO CUT 70 SD WH V FCR SLT P SRT NO FLUOR NO CUT 73 SD GRY V FGR V SLTY P SRT NO FLUOR NO CUT 75 SD CRY V FCR V SLTY P SRT NO FLUOR NO CUT 71 SD CRY V FCR V SLTY P SRT NO FLUOR NO CUT 0 SD GRY CRSCR SHATTERED NO FLUOR NO CUT 61 SLTST CRY CARB NO FLUOR NO CUT SHELL ~t~'ESTERN E&P INC. A-33-11 ttIELL M I DDLE GRO(JND SHOAL F I ELD ALASKA CORING CO.: FORMAT I ON: DRLG. FLU ID: DRESSER-ATLAS FILE: 30261011 ANALYST: ROHN LABORATORY: HOUSTON DATE: 2-18-86 REC DEPTH (IN) (FT) 1.1 6809 0.6 6815 0.7 6821 0.7 6850 1.0 6855 0.6 6860 0,2 6867 0.2 6876 O.5 6882 0.7 6888 0.6 6903 O.6 6913 0,5 6920 0.8 7005 0.6 7014 0.6 7021 1.0 7030 0.7 7038 0.2 7047 0,7 7053 SIDEWALL CORE ANALYSIS PERM (MD) (%) OIL tlrrR 8.7 18.3 0,0 65.1 ...... SATURATION ...... ---% PV ...... % BV--- PI:K~ COMB CRIT WTR OIL GAS PRO0 GAS (~) SAMPLE LITHOLOGICAL DESCRIPTION 49.0 25.4 0.0 52.0 15.0 23.2 0.0 76.2 0.4 9.9 0.0 61.7 38.0 22.9 0.0 84.3 26.0 23.9 0.0 58.9 0.57 23.3 0.0 66.7 3.0 24.7 0.0 64.8 0.0 15.0 28.4 0.0 70.7 0.0 0.0 6.4 (6)* 0 (1) 0 (1) o 0.0 12.2 GAS* 0 (2)* 0 (2) 0 (~)* 0 (1) o 0,0 5,5 WTR* 0 0.0 3.8 (6)* 0 0.0 3.6 WTR* 0 0.0 9.8 GAS* 0 (1) 0 0.0 7.8 GAS* 0 0 8.7 (6)* 0 8.3 WTR* 0 0 0 7.1 GAS* 0 18.0 21.5 0.0 67.0 0.0 65 SLTST GRY CARB NO FLUOR NO CUT SD DJ( GRY F GR P SRT MD NO FLUOR NO CUT SD DK GRY MGR P SRT SHATTERED NO FLUOR NO CUT 58 SD GRY V FGR P SRT NO FLUOR NO CUT SD ~ V FGR P SRT NO FLUOR NO CUT SD ~ V FGR P SRT NO FLUOR NO CUT SD GRY V FGR P SRT NO FLUOR NO CUT SD GRY V FGR P SRT NO FLUOR NO CUT 68 SD GRY ~ V SLTY P SRT NO FLUOR NO CUT 78 SD LT BRN FGR V SLTY P SRT NO FLUOR NO CUT 58 SD LT BRN FGR V SLTY P SRT NO FLUOR NO CUT 64 SD LT BRN FGR V SLTY P SRT NO FLUOR NO CUT SD LT BRN FGR V SLTY P SRT SHATTERED NO FLUOR NO CUT 54 SD LT BRN FGR V SLTY P SRT NO FLUOR NO CUT SD LT GRY CRSGR V SLTY SHATTERED NO FLUOR NO CUT 75 SD LT GRY V FGR SLT P SRT NO FLUOR NO CUT 73 SLTST LT GRY P SRT NO FLUOR NO CUT SD LT GRY C:RSGR P SRT SHATTERED NO FLUOR NO CUT SD LT GRY CRSGR P SRT SHATTERED NO FLUOR NO CUT 64 SD LT GRY V FGR P SRT NO FLUOR NO CUT ,:i '~ ~ ,!i i'" "il .... ,'~ .... ~ !;:i' ,I Il ..~ .,~ SHELL ~I~STERN E&P INC. CORING CO.: DRESSER-ATLAS FILE: 30261011 A-33-11 tt~E L L FORMATION: ANALYST: ROHN M I DDLE GROUND SHOAL F I ELD DRLG. FLU I D: LABORATORY: HO(JSTON ALASKA DATE: 2-18-86 SIDEWALL CORE ANALYSIS ...... SATURATION ...... REC DEPTH PERM POR ---~ PV ...... % BV--- PRO8 COMB CRIT WTR (IN) (FT) (MD) (~) OIL ~ OIL GAS PROO GAS (~) SAMPLE LITHOLOGICAL DESCRIPTION 0.6 7075 12.0 19.6 0.0 66.9 0,0 6.5 WTR~ 0 0.6 7083 6.0 17.0 0.0 51,2 0.0 8.3 (6)~ 0 0.6 7095 26.0 21.7 0,0 57.6 0.0 9.2 GAS~ 0 0,5 7106 26,0 21.7 0,0 71,6 0,0 6.2 WTR~ 0 0.5 7118 3.0 23.7 0.0 65.3 0.0 8,2 (6)~ 0 0.5 7130 7.7 22.5 0,0 70.5 0.0 6.6 (6)~ 0 0,0 7140 (1) 0 0.3 7150 0 0,0 7158 0 65 SLTST LT G~Y MIC NO FLUOR NO CUT 65 SLTST LT (~IY MIC NO FLUOR NO CUT 62 SLTST LT GRY MIC NO FLUOR NO CUT 62 SLTST LT GRY MIC NO FLUOR NO CUT 75 SLTST LT GRY MIC NO FLUOR NO CUT 71 sLTsT LT GRY MIC NO FLUOR NO CUT NO RECOVERY SD GRY V FGR V SLTY P SRT NO FLUOR NO CUT NO RECOVERY PROBABLE PRODUCT'[ON SYMBOLS (1) - ALTERED CORE (2) - EXPOSED CORE (3) - INSUFFICIENT SAMPLE (4) - CORE CONTAMINATED BY DRILLING FLUID (5) - REFER TO ATTACHED LETTER (6) - LOW PERMEABILITY (7) - POSSIBLE GAS PRODUCTION (8) - POSSIBLE CONDENSATE PRODUCTION (9) - PROBABLE CONDENSATE PRODUCTION (10) - POSSIBLE OIL PRODUCTION (11) - PROBABLE OIL PRODUCTION (12) - POSSIBLE WATER PRODUCTION (13) - PROBABLE WATER PRODUCTION (14) - ADDITIONAL SAMPLES NEEDED TO CLARIFY MARGINAL FLUID SATURATIONS (15) - PROBABLE GAS PRODUCTION (16) - TRANSITION FROM OIL TO WATER (17) - TRANSITION FROM GAS TO OIL ABD - Abundant AGG - Aggregate AMT - Amount ANG - Angular ANHY - Anhydrite (-icl ARG - Argillaceous ARK - Arkose (-icl ASHY - Ashy BND - Band (-ed) BCM - Become (-in§) BD - Bed (-ed) BlOT - Biotite BLK - Black BL - Blue BL-WH - Blue-White BO - Bleeding BTM - Bottom BRK - Break BRT - Bright BRIT - Brittle BRKN - Broken BRNZ - Bronze BRN - Brown BUR - Burrow (-ed) CALC - Calcite, Calcareous CARB - Carbonaceous CMT - Cement (-ed, -lng) CHK(Y)- Chalk (-y) CHT - Chert (-y) CHLOR - Chlorite (-icl CL - Clay CLN - Clean CRS - Course CRSGR - CourSe-grained CBL - Cobble CGL - Conglomerate (-icl CONS - Considerable CONSOL - Consolidated X-BD - Cross-bedded XL(N) - Crystal (-line) CRPXLN - Cryptocrystalline CTGS - Cuttings DK - Dark DNS - Dense DOL - Dolomite (-icl DOM - Dominant (-ly) STANDARD ABBREVIATIONS FOR LITHOLOGIC DESCRIPTIONS EA EV EX EXTR FNT FR FSPR F~LY) FGR FIS FLUOR FM FOSS FRAC FRAG FR! G GLAUC GLD GD GR GRAN GRY(SH) GN(SH) GYP HD HEM HOR INCL INCR INTBD INTXLN KAO - Earthy - Even - Excellent - Extremely - Faint - Fair - Feldspar - Fine (-ly) - Fine-grained - Fissile - Fluorescence (-ent) - Formation - Fossil (-iferous) - Fracture (-d) - Fragment (-al) - Friable MTRX - Matrix STRK MAX - Maximum STRGR M - Medium SBANG MGR - Medium-grained SBRNDD MIC - Mica (-ceous) MICROXLN - Microcrystalline TN MIN - Minimum TEX _ - Streak (-ed) - Stringer - Subangular - Subrounded MOD - Moderate THK MOTT - Mottled THN MD(ST) - Mud (-stone) TP TR NO - No NO REC - No recovery NUM - Numerous - Gas - Glauconite (-itic) - Gold PKST - Good PA - Grain (-s, -ed) PT - Graunule (-ar) PBL - Grey (-ish) PERM - Green (-ish) P.P. - Gypsum P POSS PYR OCC - Occasional 0 - Oil OOL - Oolite (-icl OR(SH) - Orange (-ish) - Tan - Texture - Thick - Thin - Top - Trace UNCONS - Unconsolidated - Hard - Hematite (-icl - Horizontal QTZ - Inclusion (-ed) QTZT - Increasing - Interbedded REC - Intercrystalline RD(SH) RPL - Kaolin (-itic) RND(D) LAM - Lamina (-tions,-ated) SD(Y) LGE - Large SST LEN - Lens SAT LT - Light SCAT LIG - Lignite (-icl SH LS - Limestone SLT(Y) LIM - Limonite (-icl SLTST LMY - Limy SLI LTL - Little SML LG - Long SRT SPK(LD) SPTD VN - Vein VERT - Vertical V - Very VFNT - Very faint WKST - Packestone WTR - Pale WXY - Part (-ly) WL - Pebble (-ly) WH - Permeability W/ - Pin-point W/O - Poor - Possible (-ly) XL(N) - Pyrite (-icl X-BD - Quartz {-ose) - Quartzite (-icl - Wackestone - Water - Waxy = Well - White - With - Without - Crystal (-line) - Cross-bedded YEL(SH) - Yellow (-ish) - Recovery - Red (-ish) - Ripple - Round (-ed) - Sand (-y) - Sandstone - Saturated (-tion} - Scattered - Shale (-ly) - Silt (-y) - Siltstone - Slight (-ly) - Small - Sorted - Speck (-led) - Spotted Reporting Sequence 1. Major lithology 2. Color 3. Grain-crystal size 4. Matrix impurities (silt, shale, cement, etc.) 5. Fossils and access- ories (pyrite, glauc- onite, mica, etc.) 6. Sedimentary structures- compaction (lamina- tions, inclusions, w~l- consolidated to friable) 7. Cut and fluorescence FINAL REPORT DiSTRiBUTiON 6 - Shell Western E&P Inc. Alaska Division 200 N. Dairy Ashford Houston, TX 77079 Attn: Clay Williams LOCATED IN THE APPENDIX Shell Western E&P Inc. A Subsidiary of Shell Oil Company P.O. Box 576 Houston, TX 77001 June 18, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99510 Attn: John Boyle Dear Mr. Boyle: SUBJECT: DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA Work Order No. Enclosed you will find data pertaining to the Middle Ground Shoal Well listed above. Please return a signed copy of this transmittal letter to acknowledge recei pt. C. C ./~i 11 i ams Alas a~K~Division Shell Western E&P Inc. CCW:mh Enclosure Received by: Aiask¢. 0il & Gas Cons, Commission Anchorage CRCT8701303 SHELL DEVELOPMENT COMPANY F'ETROPHYSICAL SERVICES SEC]'ION DATE : COMPANY : LEASE : WELl_ NO : A-33-11 APl NO : 50-733-2(1.~383-00 FIELD : Middle Ground Shoals SLATE : Kenai ~ Alaska COMMENTS: F'ebruar¥ 5, 1987 Shell Western Exploration i. Samp]. e Lab Depth ....~, F'roducti on, Inc. meq/m]. 0.48 0.55 RECEIVED Oil & Gas Cons. Oommissim~ Anchorage SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 January 27, 1987 ~.E^s; REPLY TO ICHLUMB[RGIrR OFFSHORE Shell Western E&P, Inc. 601W. Fifth Avenue, Suite 810 Anchorage, AK 99501 A~ention' Mr Joe Fram P. O. Box 1001 Kenai, AK 99611 Attention: Shelley Ramsey C~entlemen: Enclosed are 2 BLprintsofthe Production Log (Tracer-Il/21/86) Compony SWEPI ,Well Middle Ground Shoal "A" #34-11 Field. Middle Ground Shoal .,Coun~ Kenai ~tate Alaska on: ., Additionolprintsore beingsentto: 1BL prints, original film Shell Western E&P~ Inc. P. O. Box 527 Houston, TX 77001 Attn: Log Files, WCK 4147 1BL prints, 1 Reverse Folded Sepia State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ,/Anchorage, AK 99501 Attn: H. W. Kugler I BL prints Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 Attn: R. J. Vallejo, WCK 1134 i BL prints Shell Platform "A" c/o Shell Kenai Office North Star Route P. O. Box 485 Wik Road Kenai, AK 99611 1BL prints, 1 Mylar ARCO Alaska~ Inc. P. O. Box 100360 Anchorage, AK 99501 Attn: H. F. Blacker ~prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL. 2 BL prints, 2 Reverse Rolled Sepia Chevron U.S.A., Inc. P. O. Box 107839 Anchorage~ AK 99510 Attn: J. L. Weaver The film is.returned to Shell, Houston. prints We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Roger H. Theis DISTRICT MANAGER January 13, 1987 Shell Western E&P Inc. A Subsidiary of Shell Oil Company P.O. Box 576 Houston, TX 77001 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99510 Attn: John Boyle Dear Mr. Boyle' SUBJECT: DATA TRANSMITTAL FOR MIDDLE GROUND SHOAL FIELD COOK INLET, ALASKA Work Order No. ~(~/~-~1 Enclosed you will find data pertaining to the Middle Ground Shoal Well listed above. Please return a signed copy of this transmittal letter to acknowledge receipt. Ver~ ~trul¢ ~o~s, /i C. ~. Williams Alas~Division Shell Western E&P Inc. CCW'mh Enclosure Gas O0~- CRCT8701303 ADDENDUM NUMBER 1 SPECIAL CORE ANALYSIS STUDY FOR Shell Western Exploration and Production Inc. ~-I-I~ We 11 Hemlock Formation Middle Ground Shoal Field Alaska File Number: SCAL 305-86011 JAN 2 ~ 1987 Oil & C~as Con~, C, ommission CORE LABORATORIES, iNC. $ HOLUSTER RD., HOUSTON, TEXAS 77040, 7131460-9600 .. v December 4, 1986 CORE LABORATORIES, INC. Special Core Analysis Sh~ll Western Exploration and Production Inc. Post Office Box 831 Houston, Texas 77001 Attention: Mr. Clay Williams Subject: Addendum Number 1 Special Core Analysis Study A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska File Number: SCAL ~O5-86011 Gentlemen: Further analyses were requested by Mr. Clay Williams of Shell Western Exploration and Production Inc. to supplement the final report for the subject well issued on August 25, 1986. The requested analyses, residual gas saturation (counter current imbibition), were performed on one full diameter sample segment, sample 10, depth 8610 feet. Permeability to air a~..d Boyle's law porosity (using helium as the gaseous medium) measurements were performed on the cleaned and dried sample. Toluene was used as the wetting fluid in the imbibition displacement. The sample was saturated with th~ toluene and the saturation porosity verified and used in the analysis. Residual (trapped) gas saturations were then determined as a function of initial gas saturations of approximately 100%, 80%, 65%, 50%o, 40¢, and 30¢. The results of this test are tabulated on page I and graphically presented on page 2. We appreciate this opportunity to be of service to Shell western Exploration and Production Inc. Should you have any questions, or if we can be of further assistance, please feel free to contact us. Very truly yours, OORE LABORATORIES, INC. W.K. Hudson Laboratory Supervisor Houston, Texas WKH/grh ECEiVED JAN 2 ].9°87 0il & Gas Cons. Commission Anchorage CORE LABORATORIES, INC. Special Core Analysis '"Page File 1 of 2 SCAL 305-86011 Addendum No. I SUMMARY OF RESIDUAL GAS SATURATION TEST RESULTS Shell Western Exploration and Production Inc. A-33-11 Well Hemlock Formation Middle Ground Shoal Field Alaska Fluid Imbibed: Toluene sample Depth, I .D. feet Permeability to Air, millidarcys Porosity, percen.t 10 8610 1.5 5.2 Gas Saturation, percent pore space Initial Residual 1 O0 40 .-6 81.0 40.1 67.0 40.1 52.1 35.5 43.1 30.1 31 .4 23.4 RE£EIYE[ JAN 2 1987 0it & Gas Cons. uommissiort ~chorage This report based on observations and materials supplied by the client is prepared for the exclusive and confidential use by the client. The analyses, opinions or interpretations contained herein represent the judgement of Core Laboratories, /nc. and its employees assume no responsibility and make no warranties or representations as to the utility of this report to the client or as to the prOductivity, proper operation, or profitableness of any oil, gas or other mineral formation or well in connection with which such report may be used or relied upon. CORE: L&BORATORIEB. INC. DAI. LAI, TEXAI l:~ge 1 . o! 2 FiJe SCAL 305-86011 Addendum No. 1 ~o~¥. She.Il .Western Expl.. & Prod. In,c, Formatto= H ,emloc~, we~ A-33-11 O:~i¥ . i m Field . Middle Ground Shoa, 1 . . , Stme Alike. . 100 9O t~ 8O o 70 h 60 o 50 = 4O ~ 20 10 I! 11 l.l lit! 11 []I~IITll tl ~l 111] 1] Il :J l ', ', ', J Il Il Il III l I't tt "'""""'"'"'"'"' pl ,,,,,,',,,,,,,,,,,,,,,,, S~ o 10 lil I I 1 I I I l! 1.1 ] I I I I I I,! ' I~]11~1~1111] ~IlIllZl IIlT]I]] l~l~lllJll I [] , 1 1 i i I 1 " ity ,,, Pe~eabil to Air: t 5 md Illllllll Jl I]lllJllll Il Illl]~] !11] , ' - !1111 I]11 llll 11 I I 11 II~ lllllillllll]l]llllIllll l]lllll II I!]] 1] 111] 11 ~ , ---. I I1 11 IlllllllllllllJlllll]llll,, ~ , il Il 11 J] llll]lllllll ~111111 llll [],,~i Illlll,]ll,],, l]]T,l,,,lll?ll], ,,l ,,,,l,] 11 ']]'l,I i/~Jll/]J1 Il ,1] Il1 Il Illl, 11 . II , , · i ] ~ l]lll 1111 Ill I I 11 I II11 I1 I1 1] llll]ll I 1 1 I!11~1111 111 11 11111 I1] 11 lJ~]ll~l]lll]ll Iii iii I 11 I111 11 111] 11 I1 I11111111111j1111111111111 { , ,,,,],,,,~,,,,,,,,,,,, ,,,,,,,,,,,,,,,,,,,,,,,,,,~ llllllllllll{{llll I I ' I1 Illllllllllllllllllll it I]lllllllllll 1111111 It1111 II'" [llllllllllllllllllllll] IlllIIlIIIITlqlll I11111111 11 Il II1 i i i1~1{1111 [iii 1 q]! l]lllll~lJlllll]lllll , llllt !1 l]Illllll I Illqlllllll 311111 111 ,~ ,, ,, ,,,,,,,,,,~,,,,,,,,,,,~,~ , 11111 lqql II 1111 Il Il 11 Il 11 Ilj , ,] ~J~LI~I II]llll llllli I Illl 111 I ]1~111 lllii] Ill] Ill . ~]ll I', ',l I Il', ll',ll ', l', l { l',lll ~1 iJ i · · '"I~I~`~~'~jj~.~~`~jj~]j~]~]~`~`~]~]j]]]~]]]~'~~~j~~~ ,,,,~,,,"]'']"J ],,Hj~jjlj],jj,,,, ,.~JlJJ ]]IIl1111111111~II! 1]1111;1 II Iq]II1 Jl I I · I Jl 1111 ]111 i1'1illl I1~11~] 111 11 i1 i1 ,,, ,,,,,,,,,,,,, ,,,,,,,,i,,,,,,,,~,,,,,,,,, ,,]JJl,,Jlil;~,lll',[lllJlJllii'~J] J,,,, ,,~,,,]~,,,JJ J]JJ J' ']JJJJ]'J]]jJ" ,, 1111 ~''''~'~`~'''']~'''`~''''''~]~`''''''~'''''~'~'~,~`''.'~'~j~jjj'`]{{~j'''''~''~'''~]',~ ,,~,~ ,,,,~,,,,,,JJ,~'~]JJJ I j'"~l~,,,,,,_ '"''"'"'~""'""~''''"''"""JlJ~ll~lJJ{~JJllJ" ]IJ ~ . IJ i ~]JlJ~J~'" Il l]ll.]JJlJlJ I] I11 Il]l Jill I1111~! I111111]1]11111111Jllll 1 Iq 1] 111 11 llllllillllllJJJll '"""]""""~"" ["'"'""~'"'"~'"'~'"" ~1111111111] I111~111]]111]111111111111 III 1111111 I Iil 1] 11 11]111111111111]]1 I11 I 1Jl]lJl I I~1 ] I I 11 I1] I I ] I I]11] I I I 1 I 1111 11] I1 lq 1]J I I 11tl I I I !A 1] I 111 llJJJ I I ]J ]111 11 lJ 11 11 I1 ]~ J~J~l I1 I 1 I!1 1 I11 llJl~lJl]]]l~lll [i 11 I 11 I I1~11 I1 11 IJtJIJ I 11 111 111 I ~1~11111] 11111111111111]111111J 1]11 UI II~Jl I1] I I 1111 III t 1111 I1 IJ I1 lJIJ ll]llJl I1 111111I IJll~lJ 11 Jl 111 I11 1111~ ]] 11 11]....... z,...]1...,,,~ ,I1 ~,,,,,,'"""~l,,JJ~ ~',,{I~'' '" '""" " " " IJl 111 I I I 1 I1 lll]lJ1Jl11111 II I111 0 10 20 30 40 50 60 70 80 -90 100 Initial Gas Saturation, Percent Pore Space Shell Western E&P Inc. A Subsidiary of Shell Oil Company P.O. Box 576 Houston, TX 77001 September 19, 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' /~~ ~'~-// Work Order No' ~g~-/// Enclosed you will find data pertaining to the Middle Ground Shoal Well listed above. Please return a signed copy of this transmittal letter to acknowledge receipt. Shell CCW 'bj ll iams 'vision Western Exploration and Production, Inc= -.P25 A~a~k.~ ~" Rec 'd By TEICT8614804 RE RETAIN THIS SECTION FOR YOUR RECORDS MGS A33-11, MGS A 34-11, MGS A22-14 PLS'S 1 PRINTS 0 NEG. I SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA ^BOV~ R~C~'V~D ~OM: D BESS E~]~t~(r rA~['p 0 ATTENTION JOHN BOYLE Alaska 0ii & Gas ~ns. Commissio~ SI G N ED DAT ~.n~or3g~ 19.~ RSH 1655 1151~ BRITTMORE ROAD HOUSTON, TEXAS 77043 (713) 932-7183 TRANSMITTAL LETTER RECORD OF SHIPMENT OF CONFIDENTIAL INFORMATION TO: Mr. John Boyle A.O.G.C.C. 3001 Porcupine Drive Anchorage, Alaska 99501 FROM: DATE: George W. Bolger Project Leader (NAME g, TITLE) June 30, 1986 QUANTITY DESCRIPTION CONTENTS 2 copies: 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: RECEIVED BY: REMARKS: PLEASE ACKNOWLEDGE RECEIPT PROMPTLY BY SIGNING AND RETURNING THE YELLOW COPY, DATE ~j~..~_ 0'~? 1.,9~ -'- 1151-(: BRITTMORE ROAD HOUSTON, TEXAS 77043 (713} 932-7183 TRANSMITTAL LETTER RECORD OF SHIPMENT OF CONFIDENTIAL INFORMATION TO: Mr. John B0y]e FROM: State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive DATE: VIA: James J. Parr Geologist (NAME & TITLE) Anchorage, Alaska 99501 QUANTITY DESCRIPTION CONTENTS I 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, Alaskm INSTRUCTIONS: PLEASE ACKNOWLEDGE RECEIPT PROMPTLY BY SIGNING AND RETURNING THE YELLOW COPY, ~,ECE I VED BY: DATE: ~EMARKS: 11S1 · C BRITTIdORE ROAD HOUSTON, TEXAS 77O43 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. GWB:mml Sincere~ . Enclosures RE~:AIN THIS SECTION FOR YOUR RECOI:[~.-, PRINTS ~) NEG. .,/ PRINTS NEG. PRINTS NEG. PRINTS NEG. PRINTS NEG. PRINTS NEG. SEPIA SEPIA SEPIA SEPIA SEPIA SIGNED Anchorage __ SEPIA March 31, 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 99501 Gentlemen: SUBJECT: GYROSURVEY FOR MGS A 33-11 Enclosed is the Gyrodata Directional Survey for Middle Ground Shoal well A 33-11. The survey was done on February 2, 1986. It shows a measured depth of 9,820' and a total vertical depth of 9,524'. If any further questions arise, contact Susan Brown at (907) 263-9613. Very truly yours, Alaska Division Engineer SBB/kka Enclosure SBBC/aogcc. lal Alaska Oil & Gas C~'ssir~; Ancho,~2[m } ,-,c-FAIN THIS SECTION FOR YOUR RECORUo RE MGS A33-11 (SHELL) PLS I PRINTS 0 NEG. PRINTS NEG. PRINTS NEG. PRINTS NEG. SEPIA SEPIA SEPIA SEPIA ABOVE RECEIVED FROM: ATT' ESS jDoH NR BOY~(~~ SIG. ,.'ED DATE 19 'lease sign and return this card to DRESSER ATLAS THIS IS TO ACKNOWLEDGE RECEIPT OF THE FOLLOWING WELL LOGS AND N EGS: FOR STATE OF AK, AK OIL & GAS CONSERVATION COMMISSION AT MIDDLE GROUND SHAOL 'T',~,-, k ~,.~ WELL A 33-11 & A 44-02 (SHELL) PLS 1 AcBL/v/s SIGNED ATT: JOHN BOYLE PRINTS 0 NEG. 1 SEPIA PRINTS 0 NEG. 1 SEPIA PRINTS'/'~_~ NEG. ,;.-, : ~ SEPIA PRINTS ~~¢~ ~EPIA PRIN(~x" '- cl~:G. 7 ~ 'SEPIA DATE 19: STATE OF ALASKA _ ALASKA L AND GAS CONSERVATION C ~MISSION I ONTHLY REPORTi F DRILLING AND WO OVER OPERATIONS . Drilling well Workover operation [] 2. Name of operator 7. Permit No. Sh~.ll Western .E&P !nc~ 85-235 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810, Anchorage, Alaska 99501 so- 733-20383 4. Location of Well at surface Conductor 25, Leg 4. T8N, R13W. S.M. 1627'N & 435'W from SE corner o.f Sec.11 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 116' KBI ADL 18754 9. Unit or Lease Name Middle Ground Shoal 10. Well No. A 33-11 11. Field and Pool Hiddte Ground Sh0al "A" Pool For the Month of February ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Plugged back to 9,848'. 13. Casing or liner ru.n and quantities of cement, results of pressur9 tests Date' 02/02/86 Ran 3'/2" tubing. Date' 02/17/86 Installed completion equipment. 14. Coring resume and brief description NONE 15. Logs run and depth where run Date' 02/01/86 Ran GR/CBL/CCL from 9,952' to 6,120'. 6. DST data, perforating data, shows of H2S, miscellaneous data Date: 02/04/86 Perforated HR-HZ. Date: 02/04/86 Fractured well. Date: 02/07/86 Perforated. Date: 02/07/86 Fractured well. Date: 02/10/86 Perforated and fractured. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · SIGNE-'~~-~~ ~~~ T-LTLE Production SuperintendentDATE $.-\ 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 February 24, 1986 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 t State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: JANUARY MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Gentlemen' Please find the enclosed subject reports of Drilling and Workover Oper- ations for the month of January. The wells that were worked on during the month of January were the Middle Ground Shoal Wells, A 33-11, C 43-23, and C 44-14. Each enclosed monthly report is submitted in duplicate. Ver~v truly yours -- ~ff Envi rbnmenta Division Engineer SBB/kka Enclosures SBBC/aogcc.2d ' STATE OF ALASKA ~' ALASKA ~ ..... AND GAS CONSERVATION CC._.. MISSION M NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well Workover operation [] 2. Name of operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave, Suite 810, Anchoracje, Alaska 99501 4. Location of Well at surfaceConductor 25, Leg 4. 1627' N & 435' W from SE corner of Sec. 11, T8N, R13W, S.M. 5. Elevation inlf~elt (,~,~icate KB, DF, etc.) 16. L~)s~ D~l~t~rOn and Serial No. 7. Permit No. 8. APl Number so- 733-20383-00 9. Unit or Lease Name Middle Ground Shoal 10. Well No. A 33-11 11. Field and Pool Middle Ground Shoal "A" Pool For the Month of January ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Footage drilled: 3589' Depth @ Month end: 9848' Fishing job: 01-26-86 13. Casing or liner ru.n and quantities of cement, results of pressure tests Ran 7" liner' 01-28-86 (see attached worksheet for details) 14. Coring resume and brief description Sidewall samples taken' Depth' 7158-653.7 ' 01-27-86 15. Logs run and depth where run Date of run' 01~23-86 Logs run' DIFL/BHC/CAL/GR/SP CDL/CNL/SL/CAL 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNfiD NOT[-~eport on this form is required for each ca{endar month, regardless of the status of operations, and must be f duplicate with the Alaska Oil and Gas Conservation Commission by the lSth of the succeeding month, unless otherwise directed~ Form 10404 Submit in duplicate WORKSHEET FOR MIDDLE GROUND SHOAL A 33-11 7" Liner Casing: 7" Amo un t: Depth: Shoe set @: 32#/ft, P-110, LTC 2153' 9928-7775' 9928' Casing: 7" 26#/ft, N-80, LT&C Amount: 1628' Depth: 7775-6137' Cement: Type Amo un t Den si tS Yi el d Class "G" w/1% D-19 + 0.3% D-31 *Class "G" w/0.6% C-344 + 0.25% HR-7 1500 sx 90 sx 15.9 ppg 15.8 ppg 1.14 CF/sx 1.15 CF/sx Pressure tested on: 01-31-86 (okay) * Squeezed this at 6134' on 01-30-86 SBBC/wksh.4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-11433 TO: RE: Receipt of the following material which was transmitted via /4~_7-~ is hereby acknowledged: QUANT I TY DESCRIPTION RECEIVED: DATED' Copy sent YES to sender RE " ~AIN THIS SECTION FOR YOUR RECOR, ; .. MGS A33-~ ~ (SHELL) EPILOG L ITH0-ELASTIC 1 PRINTS 0 NEG. EPILOG CLASS 1 PRINTS 0 NEG. FPII OG FRAC PRESS ] PRINTS 0 NEG. PRINTS NEG. 1 SEPIA. 1 SEPIA 1 SEPIA SEPIA ABOVE RECEIVED FROM' ? .:.~ ~ !: ! ~./ !,r." ;~'.} - DRESSER ATLAS SIGN ED ~ ":~-s~-':2 ~A~' [.;G~o,q MGS A33-11 C 2&5" DIFL C"2 &'5" BHC C'-2 a5~' CN/CDL C "2 ~-~'" CN/CDL~ RETAIN THIS SECTION FOR YOUR RECORDs C=COMPOSITE OF RUN 1 & 2 1 0 1 1 PRINTS 0 NEG. 1 SEPIA 1 PRINTS 0 NEG. 1 SEPIA 1 PRINTS 0 NEG. t SEPIA C~2TM TVD DTFT,~.-~N/CDL¢ 1 PRINTS R2 2&5" COMBO COM4-ARM DIP 1 PRINTS '~5" DIP (RAW DATA) R2 1 PRINTS -~5" SPECTRALOG R2 1 PRINTS "~2&5" COMBO FMT R2 1 PRINTS ~"~5" DLML NEG. 1 SEPIA NEG. 1 SEPIA NEG. 1 SEPIA NEG. 1 SEPIA NEG. 1 SEPIA I ABOVE RECEIVED FR?M~. DRESSER ATLAS . ~,,,--T~E[''xD'A% ~, ~'O ~ SIGNED 19 ' January 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 SUBJECT: DECEMBER 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 December. The wells that were worked on during the month of December were A 33-11, A 14A-01, C 23-26, and C 43-23. Each enclosed monthly report is submitted in duplicate. D.'~/~Y/sland'~ /i Sr. St~a~ff Environmental Engineer Alaska Division SBB/kka Enclosures SBBC/aogcc.2c SI'A1-E Or: ALAtSF, A ALASKA OIL. AND GAS CONSERVATION COMMISSION MONTHLY REPORT (;,. _. DRILLING AND WORi. DVER OPEFU TIONS · [~rilling well ~ Workover operation E] " 2. Name of operator Shell Western E&P Inc. 3. Address 601 West Fifth, Suite 810, Anchorage, Alaska 99501 4. Location of Well at surface Conductor 25, Leg 4, Sec 11, T8N, R13W, SM 1627'N & 435'W from SE corner of 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 116' KB ADL 18754 For the Month of, December ,1985 7. Permit No. 85-235 8. APl Number so733-2083-00 9. Unit or Lease Name Middle Ground Shoal 10. Well No. A 33-11 11. Field and Pool Middle Ground Shoal "A" Pool 12. Depth at end of month, footage drilled, fishing jolm, directional drilling problems, spud date, remarks Beginning Depth- Depth @ end of month- Spud date- 348' 6441' 12-13-85 13. Casing or liner run and quantities of cement, r~ul~ of pressure tests 12-18-85 Casing: 13 3/8"; K-55; 61#/ft; BTC Shoe @: 1712' Cement: 410 sx "G" w/3% CaC1, 0.1% D-31, 8% gel. 250 sx "G" w/1% CaC1, 0.75% D-31 Pressure Tested: 12-19-85 @ 1500 psi · 12-30-85 Casing- 9 5/8" See attached for details. 14. Coring resume and brief description NONE 15. Logs run and depth where run 12-29-85 DIFL/BHC/GR/CALIPER CDL/CNL/GR/CAL I PER 16. DST data, perforating data, shows of H2S, miscellaneous data NONE . I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ /~-~--_~ TITLE Div. Drillina Enaineer SIGNED I ' DATE · ' ' '/ - the Alaska 'f~led in duplicate with NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev 7-1 -RO Submit in duplicate WORKSHEET FOR MIDDLE GROUND SHOAL A 33-11 9 5/8" Casing Date Run' 12-30-85 Casing' 9 5/8". 69 joints of L-80, 47#/ft, LTC 91 joints of N-80, 43.5#/ft, LTC Shoe @ · 6441' Cement' 325 sx "G" w/ 8% gel 1% CaCle, 0.15% D-13, 0.4% R-5 200 sx "G" w/ 0.75% ~-31, 0.1~% R-5 SBBC/wksh. 1 -~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~MMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent YES to send.er~ NO ~ 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 ~ is hereby acknowledged: QUANTITY DESCRIPTION DA TED: Copy sent YES to sender o~d' EP-1034 (Rev. 12-83) DRILLING AND WELL:SERVICING :. BOP, ACCUMULATOR & CHOKE'MANIFOLD' TEST REPORT: (Instructions On Reverse) : r A~ PRESSURE OPER^TE LOCKING - : UNIT APPLIED TIME HELD DID PRESSURE were last valves on choke BLOw OUT BLEED OF.F SCREWS manifold used as a stop? . - : PREVENTER . Hydril t 5""~ ~ ~'"~,*'~' ;~ ~/O ~// Bolts last ,'g~tening ASSEMBLY - ' ' ~ : ~ate ...ssu..~.s~.""""'""~'_~¢~ I~_ ~"~ A [O: .V~~. ~ ~: ~e e~.,o~..'t"~': 0.~..'v",¢~.~..... ~ a.~o.,~'w°: ~/~. ' , - , Locking wheels installed ~Yes ~ No Pipe Rams . . Pipe Rams ~ _ : ' B. KELLY COCK UPPER ~D~ ~~'~ ~/~ Did valves operate easily?· PRESSURE TEST LOWER ~~ ~t~-/ ' ~ = - .... . .... C. Safety valve ~ ~ Left in open position? ~ ~ N0 OTHER ~~ ,~/ :: PRESSURE ~ . . : TESTS Inside Preventer ~ ~,~/ ://~ Std. Pipe~ Swi~ /~ · :: - Mud Line ~/~ . ': : : ::: : L AST--,T~G TOP JOINT ' S~, ,,- ~eigh, "' _.- . CASlNG - I ' PRESSURE TEST ,,~s~r[ on casiqg/casing annulus' ¢ . __. ~ -- TE~T pREssuRE VALVES TESTED VAL~E POSIT-I~'MARKERS USED ~ MANIFOLD VALVE OPERATORS TESTED ACCUMULATOR TESTED AS REBOTE CON. STA. TESTED . BOLTS ON MANIFOLD LAST PRESSURE TEST ~ ~ No .. ~ ~ No 'TIGHT ED HYDRA~~OKE CHECKED ACCUMULATOR /?~ ~Z ~~X /~~ ~-~No ~s ~"o & BOP CONTROL HYDRAULIC PUMPS FLUID OPERATING PRESSURE. AIR INLET PRESSURE - Air s ~ No Electric ~s ~ No OPERATING FLUID LOW PRESSURE NO. OF STATIONS : BLIND RAM coNTRoL GUARD ON ~LADD[R 6R FLOAT I U~ LAST CH[C~[D BY : -'. l CO~TROLS LABELLED cU~E~TLYz Last Checke./~-/~-~ I .' Bat ! _ ~. NUMBER STATIONS I poWER SUPPLY I LOCATION ~ I LABELLED:CURRENTLY IBLIND RAM CONTROL S.T,O. , ~ D NO .' psi D Yes ' : D Yes ~CcUMUL%OR H. Accumulator & Pump Accumulator Only . Pump Only · RECHARGE TIME ACCUMULATOR Pressure : - p~es~ure : ' ": ..... :p~eSSure - : PERFORMANCE Time ' Time : : ~ TEST INITIAL FINAL .Time INITIAL FINAL INITIAL ~'IN~E: 'J ' :: =~ Blind Rams ~ ~ i ~ 1¢~ ~C /~ ~ " . PIT DRILL Top Pipe Rams Z ~ )~-l~ ~2/~ /~' ' .. Middle Rams ' --- _ . D~Hling ' Tripping , : , : Bottom Rams : operated equip, one ~ ~ R~acti°n time: ,osmo. c,on~e. / ~ ~ c~Os,n~ ume . YES NO . : : YES NO ~'~ : ~ : ': : : YEs NO OUIPMENT Circulating head on floor / Flowlinemoni't'or~a~ed.& ~-/' Four-Way valve locks .: CHECK Inside BOP's on floor / Fill uP Li"e.&' Ki,¢ ~ : ~: : wear Bushi"g: :'- :: : ' P t eve ndicator installed & ~ /~ ' ~ stroke~nter ~ ~L : ~ TripTank - . WHERE LEAK OCCURRED - ''~ HO~¢~AIB~'// , : - - : ' , ' I ~¢~ , ,~4 : :'20 c~ : IpIANY REeRESEBTATIVE · 1 - . _ ' ;~: ~- . _ · ~ : - : . HOUSTON - white copy : :: : . RIG - pink copy 12-1/4' HOLE 3000 'Pst STAC~ 19 TOP OF K Y B[JSHI,','G 'rc.,P OF ~P~IC;.~i FLOOR £©TTGt,', OF F, LTAF,'~ 5LAM ¢DRILL ~ .... : LO~-,' LI E FILL UP LINE ANNULAR PREVENTER ~ooo ~, BLIND RAM 5000 PSI PIPE RAM 5000 PSi TOP OF SUBBASE I ,~ ~ l' ///////~, ~ h / ' ...... ~. ,~-~,~. ~ooo ~, ~~ 3000 X 5000 PSI DRILL SPOOL ~' -13-5/8" 3000 PSi FLANGE CASING~ HEAD I I ~mqno PRII I~ WELLHEAD ROOM FLOOR 13-3f8" SOW 'X !3-5/8' 3000 PSI 'W~' HOUSING NOTE: DIMENSIONS INCLUDE 1~2' GAP BETWEEN FLANGES , October 24, 1985 Mr. Brian Kuehne Division Drilling Engineer Shell Western E&P Inc. 601 W. Fifth Street, Suite 810 Anchorage, Alaska 99501-2257 Re: Middle Ground Shoal A %~-I! Shell Western E&P Inc. Permit ~o. 85-235 T8~ RI ~ .7 Sur. Loc ...... 1627'N, 435'W of SE cr Sec 17, , ~, SM. Btmhole Loc. 1450'N, 1320'W of SE cr Sec. '11, T8N, Ri3W, SM. Dear Mr. Kuehne: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 2~ hours prior to commencing installation of the blowout prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere 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. V ~tu~ C. V. Chat~ Chairman of or'ton Alaska Oil and Gas Conservation Commission b~ Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conse~zation w/o encl. Mr. Bill H. Lamor~aux Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 October 15, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT: RESOLUTION OF QUESTIONS RAISED ABOUT THE APD FOR MGS A 33-11 In a recent telephone conversation between Mike Minder (your office) and Susan Brown (our office) several questions were raised concerning the subject APD. The questions involve the following items: 1. The submission of the Plug & Abandon procedure for A 14A-01. 2. The submission of the survey plats. 3. The amount of cement proposed for the 13-3/8" casing string. 4. The presence of Grayling Sands. 5. The wording on the diverter system schematic. In response to these questions, I will address each separate subject. 1. The Plug & Abandonment procedure has been submitted as a Sundry Notice under separate cover. 2. The survey plats are attached. 3. A revised APD form #10-401, that shows that an adequate amount of cement will be used for the 13-3/8" casing string, is attached. 4. There are no Grayling Sands present. =~ 5. The revised diverter system schematic is attached, with wording clarified. SBBC/aogcc. 1 RECEIVED OCT 2 Alaska 0il & Gas Cons. Commissio,q Anchnrm~. STATE OF ALASKA ALASKA O'r~: AND GAS CONSERVATION COk.~,~tlSSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Shell Western E & P Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchoraqe, AK 99501 4. Locationof well at surface Conductor 25, Leg 4. 1627'N & 4351W from SE Corner of Sec. 11, T8N, At toPl~:~rlo~t~p~,~ interval of SE Corner of Sec. 11, T8N, R13 W.! At total depth 1450'N and 1320'W of SE Comer of Sec. 11, T8N, R13W.. 5. Elevation in feet (indicate KB, DF etc.) / 6. Lease designation and~/erial no. 116 ' 1<13 ADL 18754 9. Unit or lease name Middle Ground Shoal 10. Well number A 33-11 11. Field and pool Mi dd le Ground Shoat I'A" Pool 12. Bond information (see 20 AAC 25.025) Statewide - INA Shell 0084 Type oil & gas Surety and/or number 11C 136503 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 17 miles i~ of Kenai miles 22751 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 12,238' (IVD) 11,500' TV[~eet 3746 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 350 feet. MAXIMUM HOLE ANGLE15.4 oI (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program $500,000 Amount $100,000 15. Distance to nearest drilling or completed Well A 43-11 1;100 feet 18. Approximate spud date November 15,1985 _ ! ,6!9 psig@.. L Surface ~psig@10,120 ft. TD (TVD) i SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT ! Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) , 117 1/2" 13 3/8" 54.5~/ft K-55 BTC 1725 0 I 0 1725' I 1700' 660 sx. class ¢~additiv¢_~ !12 1/4" 9 5/8'l57&43.5 #! N-80 LTC 6521 0 I , I 0 6521' 16300' 500 sx. class G+additives i8 1/2" 7" ~_6 & 32#N-80/P11( LTC 4247 6250 , 6062 10497' ~0120' 1800sx. ctass G+additives I I ~ I r I I ~ I 22. Describe proposed program' See attachments for greater detai 1. RECEIVED · Alas~<a 0il & 6as Corm, C0mm~ssion Anchorage 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGN ED %.J~).4 Z_-~.~--~ ~-~-~~-----~-~ TITLE Division Dri l li~ Engineer The space below for Commission use CONDITIONS OF APPROVAL DATE Samples required Mud log required []YES ~NO [~VES [~NO Permit number Approval date Form 10-401 Rev. 7-1-80 Directional Survey required APl number 73.3 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Octobe]: 24, 198.5 by order of the Commission Submit in triplicate ..... DIVERTER ASSEMBLY FLOW LINE I I 20" ANNULAR PREVENTER 2OOO PSI I TO BE CONNECTED SO THAT VALVE IS OPEN WHEN ANNULAR PREVENTER IS CLOSED DIVERTER SPOOL 20 · RISER - ~ 6' LINE IN AN OPEN POSITION UNTIL THE PROPER DIVERTER LINE IS SELECTED AFTER THE ANNULAR PREVENTOR HAS BEEN CLOSED RECEIVED OCT 2 Aiask~ Oil & Gas C~r~s. commission N.T.S. 10/10/85 Resolution of Question Raised About the APD for MGS A 33-11 1.1 If any further questions arise, contact Susan Brown at (907) 263-9613. SBB/kka Very truly yours, For: D. L. Yes land Sr. Staff Environmental Alaska Division Engineer Attachments RECEIVED OCT 2 ~ 1~85 Alaska Oil & Gas Cons. Commission SBBC/aogcc. 1 October 10, 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 99501 Gentlemen' SUBJECT' SUNDRY NOTICE FOR PLUG & ABANDONMENT OF MGS WELL NO. A 14A-01 Enclosed is the Sundry Notice for the plug and abandonment of Middle Ground Shoal Well Number A 14A-01. This is to be done in preparation for the new MGS Well, A 33-11. The work is scheduled to begin on November 1, 1985. The report is submitted in triplicate If there are further questions, please contact me at (907) 263-9613. SBB/kka Very truly yours, Susan Brown SEC Group Alaska Division Enclosure SBBB/aogcc.3 . Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 October 1, 1985 State of Alaska Alaska Oil & Gas Conservation Commission ATTN Betty Jane 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: Enclosed is a check in the amount of $100. As stated on the check, this is for the fee associated with submitting the Application for Permit to Drill A 33-11. SBB/kka Very truly yours, Susan Brown SEC Group Alaska Division Enclosure SBBB/aogcc1.11 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 September 25, 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. A33-11 in the Middle Ground Shoal Field, Cook Inlet, Alaska. A33-11 will be drilled from Shell Western E & P, Inc.'s (SWEPI's) Platform "A", Leg 4, Conductor 25. A permit for drilling as deep as 12,238' (11,500' TVD) is requested although the current prognosis calls for a total depth of only 10,497' (10,120' TVD). The expected spud date is November 1, 1985. Very truly yours, for:D. L. Yesland Sr. Staff Environmental Engineer Alaska Division SBB/kka Attachment SBBB/aogccl. 10 STATE OF ALASKA ALASKA O-,,~ AND GAS CONSERVATION COk~:¢-/ilSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL X~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Shell Western E & P Inc. 3. AddFess 601 West Fifth ^venue,. Suite 810; gnchorage, ~ 99501 )d::uatic3n of,4cel' ¢_.~(~u r/~ac6~t 601 I c~r zb, 55. S & ~.O'E ¢ L~ 1 at 1627 N & 435'W f~ SE ~mer of ~. 1.1, .T8N R13W. ~. l~0~Pflf~H~¢r°~'¢¢~e~er of . 11, mN, R13W. At total depth 1450' N and 1320' W of SE Comer of Sec. 11, T8N, R13W. 5. Elevation in feet (indicate KB, DF etc.) 116' KB I 6 . Lease designation and serial no. ADL 18754 9. Unit or lease name Middle GTound Shoal 10. Well number ^ 33-11 11. Field and pool Middle Ground Shoal 12. Bond information (see 20 AAC 25.025) Statewide - INA shel 1 0084 Type oil & gas Surety and/or number 11C 136503 i $500,00~ Amoun~ ~ $100,000 ~ 13. Distance and direction from nearest town 17 miles NW of Kenai miles 16. Proposed depth (MD & TVD) 12,238' (IVD) 11,500' (TVD) fec. t 14. Distance to nearest property or lease line 2275' feet 17. Number of acres in lease 3746 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 350 feet. MAXIMUM HOLE ANGLE 15-4° I (see 20 AAC-~5.035 (c) (2) 15. Distance to nearest drilli~lfi, or completed welNA 43-11 '1,, 100 feet 18. Approx'(mate spud date NovaT~r 15, lg85 1,619 "~, psig@ ,/ Surface ~psi~ft. TD (TVD) SIZE Proposed Casing, Liner and Cem¢nt,ng Program SETTING DEPTH CASING AND LINER ',Hole 17 1/2" 12 1/4" 8 1/2" Casing 13 3/8" 9 5/8" 11 Weight 54.5#/ft 47&43.5# 26 & 32# 22. Describe proposed program: Grade Coupling Length K-55 I BTC 11725 u-80 / LTC I 6521 N-80/P-1]0LTC "~,,.],,4247~ See attachments for greater detai 1. MD TOP TVD -..0 i 0 0 ~ 0 /--6250., I6062 ~D BOTTOM ,q-VD 1725'' 1700' 652W 6300' 10497 ~ ¢0120' QUANTITY OFIFIF~EMENT ,/ (include stage ~J§ta) ,~ *?"' 410 sx. clas.s/G + ,additives / / // .,/~ /.. // / / / , / / 500 sx. c]~%6 ~+ additives! 1800 sx=.-d~asS G + additives .// .. /- _- 23. I hereby certify that the foregoing is true and correct to the best 9f'my kng(~ledge / ~ TITLE Division Drilling Engineer The space b/el~w for-Commission use DATE 9-25-85 CONDITIONS OF APPROVAL Samples required []YES /~O Permit number Mud log required []YES ~0 Approval date Directional Survey required i /~YES i--iNO APl number 5o- 73~ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE by order of the Commission Form 10-401 Rev. 7-1-80 Submit in triplicate Alaska Oil & Gas Conservation Commission 1 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. SBBB/aodl 30' Core in HC at 8120' TVD o 0 DISFL, GR, BHC, SP/FDC, CNL, GR/ HRD/RFT/SWS DISFL, GR, BHC, SP/ FDC, CNL, GR Catch Samples every 30' for palyo O0 000 0 0 7", 26# & 32#, N-80 & P-110~ 'LTC Kick off at 350' Build Angle 2o/100 to 15.4o in a N87ow direction. Drill ahead to 6400' TVD. Drop angle 2o/100' until hole is vertical (apx 7120' TVD). Build 2o/100' in S73OE direction to upper target at 8120' TVD. Hit target at 20o inclination. Maintain azimuth & inclination to hit lower target at 9620' TVD & TD at 10120' TVD. o Lignosulfonate mud weight and viscosity as required. HTHP fluid loss 10-15cc at 150OF as required. Gel-benex wi th API fluid loss 15-20 Cc. Dispurse only if hole conditions warrant. Gel & water m 0 ,'- ~E I m m ~> Alaska Oil and Gas Conservation Commission August 23, 1985 PROPOSED PROGNOSIS FOR A-33-11 4) Move rig over conductor 25, leg 4 (A-14A-1). Set bridge plug at 780' MD and spot 50' cement plug to 730' MD. Cut and pull 7" casing at 700'. Set bridge plug at 510' MD and spot 50' cement plug to 460' MD. 5) Cut and pull 10-3/4" casing to 450' MD. 6) RIH to 450', spot cement kick-off plug to 300'+. 7) Kick off and directionally drill 17-1/2" hole to 13-3/8" casing point at 1700' TVD (1725' MD). Set 13-3/8" casing and cement to surface. Directionally drill 12-1/4" hole to 9-5/8" casing point at 6300' TVD (6521' MD). 10) Attempt to run the following wireline logs GR, SP, DIL, BHC/GR, FDC, CNL. 11) Set 9-5/8" casing and cement to 1000' above shallowest potentially productive sand. 12) Directionally drill 8-1/2" hole to TD with 30' core in Hemlock zone at 8120' TVD (8350' MD). 13) Run casing caliper to evaluate wear on 9-5/8" casing to determine whether a 7" liner or 7" full string should be run. 14) Attempt to run the following wireline logs' GR, SP, DIL, BHC/GR, FDC, CNL/RFT/HRD. 15) Run 7" liner or full string and cement to 6200' MD. 16) Proceed with production prognosis. JHC/bl RECEIVED Oii &~Gas Cons Commission A-33-11 1 ist/JCH1 -~'T':-T: ~ ~~:-':I~:~:-:-TCT'.:. ~:_C WELL PATH I I ~ . , _ { _ : ..... :.4: ......... ~ .......... ~ ......... &l;~ .......... , ~ . ~ · ~ · ~ ' . .... ........ I ' ' .. SCALE' 1'= 2000' _ - ......... T ;-'j:~ : : ...... .......... ]-~ 0 ~o~ 3~.O'TV~ ' ' ............ - 2 ..... ...... , ......... ~ ........................ T ......]--= ~ .................... ~ .... ::- :: ..... ~_ . ,-- ~ SCALE- 1' = 1000' 4 ~ :]o° i, ............. ~' ' X 200' TARGE .... d--: .......... ~ I TION: ......... : .....~. ~ --- ,'_.___~ ........ :~--4 ..... , 8120'TVD. ~ .......... ~ ::--'-':~--~ ]:-- ~ ~ ~ FEET ~000 - ]: :--: - ]]~_ i -7-7]~ --T : ~ ............ ¢''-¢~150' X 200' TARGET ~ [ ' ' ' ~ ........ ; ..... I-~ F--~~ 9620'TVD ~ :__ .-]_ - ];]]% ~966'MD ' ~- 10- .~~'~'6~6'~D' : ; ' ;':~ . .......... 10497'MD i ;~] ............ ~ .......... ~ ................ t ......... : ' ~ ' ' : ~ ~l ~ ! ........... ~-:-: ....~-2~ -~4~:~. ~ ' ~d---?~~- " ..... ~ - ..... , ' I 'f ~ , , =~ ~-~ .... ' .... ~ ..... ~,~,,, ,'i,~ ,~,,~, '[,,,,, I'1/ Iii I' i .... ri II I)Y'I'I~ SPOOl. ~,'I~L/].~ I~I~V~.~.~It ]$ BOTH I;' IECXA~JCA~ Ir.4L~S I~]tt t _~ I)t'~lf I't)$.Jl~ I~TJL I~tt I~ c~,r,JJv ~ J/fps ?1)' ~AI? S' ALITI:L~TL'I) UAL PI I'Z'll]'[l~ SPOIX SHELL MINIMUM BOP STACK REQUIREMENTS Min. Min. No. Item I.D. Nominal 1 Flowline 7" 2 Fill up Line 2" 3 Drilling Nipple 4 Annular Preventer 5 Two single or one dual hydrualically operated rams 6 Drilling spool with 2" and 3" min. outlets 7 Gate Valve 3 1/8" 8 Gate Valve Power Operated 3-1/8" '" 9' Line to choke manifold 3" , , I10 Gate Valve 2-1/16" , , 11 Check Valve 2-1/16" '1'3 Casing Spool 14 Valves Gate 1-13/16" "1'5 Compound Pressure Gauge connector ~6 Control plu9 or valve 1-13/16" i'~ 7 Kill line to rig mud pump manifold 2" 18 2" X 2" X 2" cross _ 'NOTE: Additional ~pecitications for Air/Gas Service ere given in Shell Well Control Manual, Appendix 6.18. A rotating Ilea~l shill De Provi(]e(] on Air/Gas Service OPTIONAL 12 Wear flange or bore protector 19 Gate valve ,,; 20 Line to roadside connection 21 Rotating blowout preventer ~te valve poWer operated 6" DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE INSTALLATIONS NORMAL AI R/GAS* FOR AIR/GAS DRILLING CONFIGURATION A ANNULAR PREVENTER BLIND RAM PiPE RAM Location optional !:: -' .,.~ ':~ ~o ~ ..'., . , ' ,' ,' ,..,, . · ::~, .::. ,.::,,' ,., ,:,'~ .;. , . ,. loCa~ a.,i. derlned- pooA. ', .... ~'..,..,.. ~ .~,~-.....,, .... ~_ll:~ .lO'~.~t~d':,,..pri~ipelt/diS, fiance :from ~ pr0perty,:,".ltne.~:.. ;..' ,.~'...',. ;... l~C.ated]~/pr,~.p~,~,. di~.tance fro~.: other.~wel'Is...,';'...,..,..% ,..; .' . )perator-~..:the':, Cni~. j~-fed~ted., p'art~ :'..., ;'.', .... "' ; .... i ~ ~'..~,'~.',.F ~-' 'd:~'.: 7' ' . · · ' 'bo a f g ~oporatc orce '(a cOnse~a~i~'n order needed ' ~ · · · · e · e · · · · · e · · · · · · · · · · · e · · · · · · · e · · · · [!'~'i ,approval needed ' 1 ' eeeeeleleeeee®elleeeeeeeeleleeleeee '(i0 and,.:~'l-2)'-'-' 1'2~ l'"the lease number appropriate ... ............................ '.' ..... '. ~ :.'(.13 th'r~ 21') ,,14'~ gh CemePt,.h~'ed.i'to circulate.~ ~~;~ ~ ~~::::::...: ~ "' i'15.~ [l'cement,/tie'.im~:surface and intermediate or production strings .... ~ ;:thru 26).-'.' 16. £1Z cemen6 cover~all known productive horizons ............ , ...... i.Tv/,, s.urface'.caSin~'~iprotect fresh water zones.. ..... . ......... iS;';:,:':;:,,~Will' all casing,:giV~:,'.adequate safety in collaPse'~ 't'enSion,~"~; 'lg;/:'i?i:is this well tO'::be::/kicked off from a.n existing. Wellbore ............ 20, .'IS old Wellbore'ab~ndOnment procedure included on 21 'is adequate wellbO~e separation proposed · · ee®ee~· . . .. 22'; 23. 26. 25." 26. 27. -Is a diverter system required · · .:.Are necessary diagrams of diverter and BOP equipment attached. ~:,~.~,'"~_ 'Does BOPE ha~e:Suf~icient pressure rating - Test' to .~2~~ ~s~g/~.. 2~ Does the choke manifold comply w/API RP-53 (Feb.78)...~9~,~li~o.. Is the presence, of. H2S gas probable ................................. ::Engineering: LCS'! ... :-BE-W- HJH ~ Additional requirements· ' eeleeeeeeeleee~ee·eeeeeeeeeeeee·~e·eeeeeeeeee Addit~al Remarks: JJO;aI a/5 ' , / INITIAL "' GEO. UNIT ON/OFF POOL , CLASS STATUS . .AREA NO. SHORE · Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically - -: · .. organize this category of information. Company Well Field County, State LIBRARY TAPE CURVE SPECIFICATIONS SHELL WESTERN MG$ A 93-]1 MIDDLE GROUND SHOAL KENAI, ALASKA Date 02/10/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale I GRAC I-GAMMA RAY DIFL/AC 0 - 100 I! SP SPONTANEOUS POTENTIAL RFOC RESISTIVITY FOCUSED RILM RESISTIVITY ~[EDIUM -80 20 .2 - 2,000 If !! AC ACOUSTIC ~ " 150 - 50 GN COMPENSATED ~EUTRO~ CN/CDL 60 - 0 DES BULK DENSITY " ~ 2 - 3 GR G~ ~Y " 0 - 100 DENP DENSITY POROSITY " 60'- 0 CO~ CO~CTION " -.25 - .25 K POTASS~ S~ECTALOG 0 - 10 U U~I~'i " 0 - 20 TH THORI~ " 0 - 30 KTH POTASSI~/THORI~ ~TIO " 0 - 100 ....... .. . .. .. .. ~~~ ~ c..' .- - .¢_... ..... _ _{_ ~? .... __ _ .. ___ ~. _.. --_ .... __ ... ..~ .. -_- -,._'_.,,-*X: ':.'}/:,- j....::h" ;.'; -_X.- :. - / ?-- -~%- _ i_",~ ¢ -; -d --- x - - _ ~. , .. ~,. :..%~ ..... :.%..-: _: .-::.: .-;.,..c.- :'w .~ %. ,.:._ .:- - .:'c ,-.-x-*-:'~:-~_::- o '-: .~-'-- *- ~ - ._ .......... _-.c- -';...*:;:.' '. '~7%-..,.': '.' X."::'_~'¢.~-: ', '... ".._ ', .- ' a-%%', <".'.* <' -:--< ; :%x, '-- u- - ~ - 7 ~. . ',.. .* .~ .-'%-_r**:~'.;-{<.x;'v ' .'7 :['--%~:7'/$ ~7-': c:. 3'.".'.'- ' ~.c-:-* ..%.. *...... '{..~. :::,-~-*-... --.~:---% ~. . :.: .X: x-~.-; ::::}::./:-~.-:~?;- .... -..q ~ '. *-". ! H. 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