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Home My WebLink About185-135Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:31 Township:9N Range:12W Meridian:Seward Drilling Rig:Rig Elevation:Total Depth:9642 ft MD Lease No.:ADL 0017595 Operator Rep:Suspend:X P&A: Conductor:20"O.D. Shoe@ 660 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 3200 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9 5/8"O.D. Shoe@ 7687 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 9630 Feet Csg Cut@ Feet SS Tubing:3 1/2"O.D. Tail@ 7482 Feet Tbg Cut@ Feet LS Tubing:2 7/8"O.D. Tail@ 8998 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Long String Perforation Bridge plug 9300 ft 5301 ft 14ppg Wireline tag Short String Perforation Bridge plug 9300 ft 2027 ft 14ppg Wireline tag Initial 15 min 30 min 45 min Result 1st Attempt Tubing 2240 2149 2092 IA 2240 2149 2092 OA 225 225 225 Initial 15 min 30 min 45 min Result 2nd Attempt Tubing 2240 2160 2112 IA 2240 2160 2112 OA 220 220 220 Remarks: Attachments: Two attempts were made for a passing MIT-IA. During the first attempt, 1.1 bbls were pumped in and 1 bbl came back after testing was completed. For the second attempt 1 bbl was pumped in and 1 bbl came back. The Long String cement tag was at 5301 ft MD and the Short String (velocity string) tag was at 2027 ft MD. Both depths include a 41-foot correction for wireline. Both cement samples showed good cement. August 24, 2025 Guy Cook Well Bore Plug & Abandonment MGS ST 17595 Baker-20 Hilcorp Alaska LLC PTD 1851350; Sundry 324-403 None Test Data: F Casing Removal: Brad Whitten F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0824_Plug_Verification_MGS_State_17595_Baker-20_gc MIT's failed due to pressure loss not demonstrating trend to zero and total pressure loss > 2% -- J. Regg, 12/5/2025                         1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,642 See schematic Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate Production 3,087psi Liner 11,651psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Middle Ground Shoal Middle Ground Shoal Oil N/A 9,270 9,300 8,951 2015 9,300 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 11,827psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 185-135 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20377-00-00 Hilcorp Alaska, LLC MGS ST 17595 20 Length Size Proposed Pools: 266 266 6.4# / N-80 (LS) & 9.2# / N-80 (SS) TVD Burst 8,998 (LS) & 7,482 (SS) 5,745psi MD 2,110psi 3,094psi 660 3,145 660 3,200 7,4189-5/8" 266 30" 20" 13-3/8" 660 3,200 7,687 Perforation Depth MD (ft): 7,429 - 8,970 7,687 7" 7,172 - 8,165 7/26/2024 9,6302,086 2-7/8" (LS) & 3-1/2" (SS) 9,259 See schematic See schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.07.12 16:43:23 - 08'00' Dan Marlowe (1267) 324-403 By Grace Christianson at 8:23 am, Jul 15, 2024 X 7/31/2030 BJM 6/25/25 A.Dewhurst 23JUL24 See attached conditions of approval 10-407 DSR-7/15/24GCW 06/26/2025 6/26/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.26 09:45:06 -08'00' RBDMS JSB 062625 MGS St 17595-20 (PTD 185-135) Suspension Sundry 324-403 Conditions of Approval 1. Variance to 20 AAC 25.112(c)(1)(D) to perform a downsqueeze without a cement retainer or production packer is approved (see email request from Casey Morse dated 6/16/25) with the following conditions: a. Cement retarder should allow for extra time required to bullhead cement into perfs at a low rate. ConƱrm injectivity into perfs prior to performing cement squeeze. Minimum of 50 bbls of cement bullheaded below the KOBE pump is the regulatory minimum. b. Maximum pressure on IA while bullheading cement into perfs, with TOC in IA at 2000’ MD, is 2000 psi. Continue bullheading cement until injection rate is <0.3 bpm @ 2000 psi, or 50 bbls cement is injected below the KOBE pump, whichever comes Ʊrst. Hilcorp should propose alternative injection pressure/rate cutoƯ and obtain approval from AOGCC before cementing. c. Perform CBL on long string to conƱrm TOC in IA after cementing. 2. Provide 48 hrs notice for AOGCC opportunity to witness TOC tag in LS & CT and CMIT LSxSSxIAxCT to 2000 psi. 3. Provide 10 days notice for AOGCC inspection of suspended well within 12 months of completing suspension per 20 AAC 25.110(e). Oil Zone P&A Program Well: Ba-20 Well Name: MGS ST 17595 20 (Ba-20) API Number: 50-733-20377-00-00 Current Status: Shut-In Producer Rig: SL, FB, cement Estimated Start Date: July 2024 Estimated Duration: 2 days Reg. Approval Req’d? Yes Regulatory Contact: Juanita Lovett First Call Engineer: Casey Morse 603-205-3780 (M) Second Call Engineer: Ryan Rupert 907-301-1736 (M) Current Bottom Hole Pressure (est): 2700 psi @ 6850’ TVD (Ca. 2007 SBHPS, EMW: 7.6 ppg) Max. Potential Surface Pressure: 2015 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA): 2/25/3/210/205 psi History Drilled and completed in 1985 and put on production as an oil producer. There have been no rig workovers performed on this well. In 1995 a coiled-tubing retrofit jet-pump completion was run in the short string. The well was SI in 2003. It was then circulated with 9.8 ppg brine and a 60 bbl pill of LCM was pumped down the LS to plug off the perforations. LCM displaced to KOBE cavity w/ 43 bbls 9.8 ppg brine. The LS, SS, and IA were freeze-protected with diesel. 20” Casing set @ 660’ MD. Cemented w/ 860 sacks Class G 3% CaCl2, 8% gel. 0.1% D-31, 2nd 500 Sacks Class G 2% CaCl2 0.5% D-31, 500 sacks circulated to pit, float held, cement to surface. 13-3/8” Casing set @ 3200’ MD. Cemented w/ 2000 sacks Class G; 2% CaCl2, 0.75% Turb Inducer, Liquid sodium silicate 46 gals per 100 sacks. Tail, 500 sacks Class G Neat 2% CaCl2 x .75% Turb Inducer 9-5/8” Casing set @ 7687’ MD. Stage 1, Batch 1: Class G, 1150 Sacks 13.3 PPG slurry. Stage 1, Batch 2, Class G, 450 sacks 15.8 PPG slurry. Lost returns w/ 37 barrels of displacement left. Hole stayed full. Bumped plug, float held. Current Status Shut-in. Perforations are plugged with a Calcium Carbonate LCM pill and the LS, CT, SS, and IA were loaded with 9.8 ppg brine. Pre-P&A Diagnostics Performed 1. Initial pressures (LS/CT/SS/IA/OA/OOA): vac / 0 / 10 / 5 / 185 / 200 psi 2. Pump 9.8 ppg brine: a. Pump down LS up IA, FCP = 500psi / 2 BPM b. Pump down LS up SS CT annulus, FCP 1750psi / 2 BPM c. Pump down LS up CT, FCP 1750psi / 2 BPM d. Pump down CT up IA, FCP 1600psi / 1.7 BPM e. Pump down CT up CT annulus, FCP 400psi / 1 BPM f. Bled down OA to 50 psi, OOA to 0psi, all air, no communication across annuli 3. Inject down LS, pumping at 1/3bpm, pressure climbed to 900psi, broke over to 500psi, increased rate to 1bpm climbed to 1400psi and broke over to 1000psi Oil Zone P&A Program Well: Ba-20 4. RU slickline on LS. a. RIH w/ 2.30” gauge ring to 4128' SLM, tag fish, POOH. Move to short string, m/u tool, RIH w/ 1.25" gauge ring to 7327' SLM tagging KOBE cavity, pooh. Move back to LS. RIH w/ 1.85" LIB to 4128' SLM-W/T, pooh. Triangular shapes on LIB. b. RIH w/ 2.0" magnet to 4128' slm, w/t to 4131', gain 50 lb overpull, slips off, pooh, small shavings and scale on magnet. RIH w/ magnet again, same results. RIH w/ 2"x6' pump bailer to 4131' slm, w/t, pooh, nothing in bailer. c. RIH same pump bailer w/ mule shoe, tag at 4131', w/t, fell to 4283', w/t, fell to 4988', pooh, nothing in bailer. RIH w/ pump bailer and continue working obstruction down to final depth of 7437' slm, pooh, small amount of scale in bailer. d. RIH w/ 2.30' g-ring to 7433', pooh. RIH w/ 2"RB w/ 2-7/8 DD holefinder, set at 7408, pt tubing to 525psi, hold for 5 minutes, good test, pooh. L/d lubricator. 5. RU slickline on CT a. Establish circulation down CT and up SS (CT annulus) at 1 bpm, 400 psi. RIH w/ 1” ponytail while pumping. RIH 60-90 fpm to 7327’ SLM. No indication of hole in CT, continuous flow indicated past set down depth 6. Check pressures (LS/CT/SS/IA/OA/OOA): 0 / 0 / 0 / 0 / 60 / 0 psi a. Bled down OA to 50 psi, no LEL’s Objective Plug and abandon the Middle Ground Shoal Oil Pool perforations and CMIT the casing / tubing to place this well in suspended status. This well will be evaluated for future sidetrack potential or uphole gas recompletion. Procedural steps 1. Fluid pack the tubing strings and IA with 9.8 ppg brine. 2. Pump reservoir abandonment cement plug as follows: ¾ 30 bbls RIW (Raw-Inlet-Water) w/ Surfactant Wash (down LS and out IA) ¾ 445 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down LS and out IA ii. Return 426 bbls from IA (IA cement volume of 374 bbls plus LS volume of 52 bbl) iii. Close IA and swap to taking returns from the SS (CT annulus). Return 34 bbls. iv. Close SS and swap to taking returns up the CT. Return 14 bbls up the CT. ¾ Foam Wiper Ball (drop ball ~16 bbls into taking returns up SSxCT annulus) ¾ 32 bbls of 9.8 ppg brine displacement of cement (puts TOC in LS @ ~5500’, TOC in IA / SS / CT @ ~2000’) ¾ Shut in well and hold ~765 psi on LS to keep plug over-displaced. ¾ LS volume from tubing tail to 5500’: 0.0058 bpf * (8998’-5500’) = 20 bbls ¾ IA volume from tbg tail to 2000’ = 337 bbls o 8998 to 7544: 0.0270 bpf * 1454’ = 39 bbls (tubing tail x liner) o 7544 to 7513: 0.0664 bpf * 31’ = 2 bbls (tubing tail x 40#) o 7513 to 4718: 0.0545 bpf * 2795’ = 152 bbls (LS/SS x 40#) o 4718 to 2557: 0.0533 bpf * 2161’ = 115 bbls (LS/SS x 47#) o 2557 to 2000: 0.0508 bpf * 557’ = 28 bbls (LS/SS x 53.5#) ¾ CT volume from Kobe to 2000: 0.0023 bpf * (7323’-2000’) = 12 bbls ¾ SS volume from Kobe to 2000: 0.0057 bpf * (7323’-2000’) = 30 bbls See revised cement procedure in attached 6/16/25 email from Casey Morse. -bjm The tubing punch in the LS above the KOBE will prevent circulation down to the tubing tail. Need to bullhead cement down into perfs. See revised procedure from Casey Morse 6/16/25 email attached.-bjm Oil Zone P&A Program Well: Ba-20 Total Cement Volume with 10% excess: 445 bbls ¾ LS volume from 5500’ to surface: 0.0058 bpf * 5500’ = 32 bbls ¾ IA volume from 2000’ to surface: 0.0508 bpf * 2000’ = 102 bbls ¾ CT volume from 2000’ to surface: 0.0023 bpf * 2000’ = 5 bbls ¾ SS volume from 2000’ to surface: 0.0057 bpf * 2000’ = 11 bbls Fullbore/Slickline 1. CMIT LSxCTxSSxIA to 1500 psi (AOGCC Witnessed). 2. Tag TOC in LS and CT (AOGCC Witnessed). Cement Tops: x 20” Casing o Annulus volume: 220 bbl 660’ to 266’: 394 ft * 0.2681 bpf = 105 bbl 266 to surf: 266 ft * 0.4284 bpf = 114 bbl o Cement volume: 485 bbl 1000 sx of 12.6 ppg Class G lead (~2.15 cuft/sk) = 2150 cuft, 383 bbl 500 sx of 15.8 ppg Class G tail (1.15 cuft/sk) = 575 cuft, 102 bbl o Cement to surface requires washout < 120% x 13-3/8” Casing o Annulus volume: 516 bbl 3200’ to 660’: 2540 ft * 0.1237 bpf = 396 bbl 660’ to surf: 660 ft * 0.1815 = 120 bbl o Cement volume: 815 bbl 2000 sx of 12.8 ppg Class G lead (~2.0 cuft/sk) = 4000 cuft, 712 bbl 500 sx of 15.8 ppg Class G tail (1.15 cuft/sk) = 575 cuft, 102 bbl Cement to surface requires washout < 58% x 7” and 9-5/8” Casing o CBL from 9-14-85 Bottomhole Pressures x Frac pressure: estimated at 0.9 – 1.1 psi/ft as per AIO 7. TVD of top perf: 7150’ x Full column of 9.8 ppg brine: 3650 psi o Do not exceed 2500 psi with 9.8 ppg brine in well x Full column of 14 ppg cement: 5200 psi x Do not exceed 1500 psi surface pressure with full column of cement. 2000 psi -bjm Offshore Baker Platform Ba-20 N Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal CT Completed in SS 3/8/95 Oil Well C asing & Tubing Size Wt Grade Thread ID Top Btm TOC 30”Surf 266’ 20”94 K-55 Butt 19.124 Surface 660’Surf Calc 13-3/8” 54.5 & 61# K-55, S-80 Butt Surface 3200’ 32º Surf Calc 9-5/8”40, 47 & 53.5#N-80, S-80, S-95 Butt Surface 7687’*2000’CBL 13-3/8 LOT 13.3 ppg EMW, 9-5/8 LOT 12.8 ppg EMW L I N ER 7” 35#S-95 S-95 6.004 7544’9630’7544 CBL Halliburton EZ Drill BP set @ 9300’ T U BING LS 2-7/8” 6.4#N-80 Butt 2.441 30.88998’ SS 3-1/2”9.2#N-80 Butt 2.992 30.87482’ COIL TU BING SS 1.75” 1.915#HS-70 1.532 Surface 7313’ J ewelry Item Depth Length ID Description LONG S TRING 32’ 2.992 Cameron Dual 10” Hanger 1.4.20’2.441 4’ 2-7/8” Pup joint 2.6.37’2.441 6’ 2-7/8” Pup joint 3.7513’ 24.00’2.25 Trico Kobe Pump Cavity 4.8998’.45’2.441 WLEG S H O RT S TRING 32’ 2.992 Cameron Dual 10” Hanger A.7313’4.83’1.502 Baker CT Connector w/ 4’ x 1.90 NU 10rd Pup jt. B.7318’.69’1.149 HES “N” Profile Nipple. C.7319’4.71’1.610 1.90 NU 10rd Pup jt. D. 7323’ 3.48’ NA Trico 1-1/4” Jet Pump Cavity w/o Standing Valve, w/ 1.90” 10 rd BxP E.7327’ 8.59’1.063 Seal Assy w/ MS Guide F.7327’ 10.31 2.38 Upper PBR G.7337’2.83’1.310 HES Repeata Tubing Patch Pkr. H.7482’ 1.08’1.380 Crossover, 3-1/2” x 1-1/4” NU 10rd I.7484’ 10.05’1.380 1-1/4” Tbg Pup Jt. J.7494’24.00’–––––Trico Kobe Pump Cavity Consistent problems w/ tree being slightly cocked, straightening req’d prior to SL/WL operations. (10/10) – Well kill w/9.8 KW brine. SS & CT appear to have plugged after circ complete but unable to freeze protect. (9/08) –1.5” slickline gauges stop @ 4141’ in LS. RIH w/1” slickline tools in SS to 7323’& no tag. (2002)–Had significant issues pulling the CT pumps due to scale buildup just above pump. *CBL 9-14-85: 9-5/8” cement starts at ~2050’ and bond quality is intermittent through 7500’. Good cement bond across surface casing shoe ~2700 –3900’. 7” cement bond excellent throughout. P e rfo ratio n s Zone Top Btm Ft SPF Date Comments F 7,429' 7,435' 6' 4 2/27/95 Atlas 2-1/2" Alpha Jet 60 deg phased gun. Shot in the Short String. G-01 7,738' 8,050' 312' 4 10/12/85 4" TCP Guns G-02 8,100' 8,264' 164' 4 10/12/85 4" TCP Guns G-03 8,560' 8,740' 180' 4 9/19/85 4" TCP Guns G-03 8,784' 8,970' 186' 4 9/19/85 4" TCP Guns G-04 9,390' 9,420' 30' 4 9/18/85 Cmt Sqz'd F i s h x 10/94 – LS has half of a pump with a spear stuck in it. x 11/94- LS has a grapple, from a broke overshot, is on the spear. x Long string & fish was perforated on 2/27/95 x Complete lower pkr assy for CT jet pump (SS) x Kinley perforating Assembly (SS) & packer PBTD = 9300’ TD = 9642’ MAX HOLE ANGLE = 21.45O @ 9530’ 30” 242’ CBL TOC 2050’ G H I J Circ Holes 7360’ - 7365’ Tubing punch 7391’ slm RKB: MSL = 101’ ; RKB to Tbg Hngr = 32.00’ Mudline= 203’ Water Depth= 102’ 9-5/8” 7687’ Open Perfs 7429’ – 7435’ C D E F 1 2 3 4 Stage collar @ 3890’ 20” 660’ 13-3/8” 3200’ 7” 9630’ Drillable BP 9300’ MGS Oil Top 5640’ TOL @ 7544’ Open Perfs 7738’ – 9420’ Base MGS Gas 4695’ B A 9.8 ppg brine Dog Legs 3.96 @ 1000’ 3.21 @ 3300’ 2.98 @ 7800’ ADL: 17595 PTD: 185-135 Leg 2, Slot 3 API: 50-733-20377-00 JN/ARD 12/2010 Offshore Baker Platform Ba-20 N Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal CT Completed in SS 3/8/95 Oil Well C asing & Tubing Size Wt Grade Thread ID Top Btm TOC 30”Surf 266’ 20”94 K-55 Butt 19.124 Surface 660’Surf Calc 13-3/8” 54.5 & 61# K-55, S-80 Butt Surface 3200’ 32º Surf Calc 9-5/8”40, 47 & 53.5#N-80, S-80, S-95 Butt Surface 7687’*2000’CBL 13-3/8 LOT 13.3 ppg EMW, 9-5/8 LOT 12.8 ppg EMW L I N ER 7” 35#S-95 S-95 6.004 7544’9630’7544 CBL Halliburton EZ Drill BP set @ 9300’ T U BING LS 2-7/8” 6.4#N-80 Butt 2.441 30.88998’ SS 3-1/2”9.2#N-80 Butt 2.992 30.87482’ COIL TU BING SS 1.75” 1.915#HS-70 1.532 Surface 7313’ J ewelry Item Depth Length ID Description LONG S TRING 32’ 2.992 Cameron Dual 10” Hanger 1.4.20’2.441 4’ 2-7/8” Pup joint 2.6.37’2.441 6’ 2-7/8” Pup joint 3.7513’ 24.00’2.25 Trico Kobe Pump Cavity 4.8998’.45’2.441 WLEG S H O RT S TRING 32’ 2.992 Cameron Dual 10” Hanger A.7313’4.83’1.502 Baker CT Connector w/ 4’ x 1.90 NU 10rd Pup jt. B.7318’.69’1.149 HES “N” Profile Nipple. C.7319’4.71’1.610 1.90 NU 10rd Pup jt. D. 7323’ 3.48’ NA Trico 1-1/4” Jet Pump Cavity w/o Standing Valve, w/ 1.90” 10 rd BxP E.7327’ 8.59’1.063 Seal Assy w/ MS Guide F.7327’ 10.31 2.38 Upper PBR G.7337’2.83’1.310 HES Repeata Tubing Patch Pkr. H.7482’ 1.08’1.380 Crossover, 3-1/2” x 1-1/4” NU 10rd I.7484’ 10.05’1.380 1-1/4” Tbg Pup Jt. J.7494’24.00’–––––Trico Kobe Pump Cavity Consistent problems w/ tree being slightly cocked, straightening req’d prior to SL/WL operations. (10/10) – Well kill w/9.8 KW brine. SS & CT appear to have plugged after circ complete but unable to freeze protect. (9/08) –1.5” slickline gauges stop @ 4141’ in LS. RIH w/1” slickline tools in SS to 7323’& no tag. (2002)–Had significant issues pulling the CT pumps due to scale buildup just above pump. *CBL 9-14-85: 9-5/8” cement starts at ~2050’ and bond quality is intermittent through 7500’. Good cement bond across surface casing shoe ~2700 –3900’. 7”cement bond excellent throughout. P e rfo ratio n s Zone Top Btm Ft SPF Date Comments F 7,429' 7,435' 6' 4 2/27/95 Atlas 2-1/2" Alpha Jet 60 deg phased gun. Shot in the Short String. G-01 7,738' 8,050' 312' 4 10/12/85 4" TCP Guns G-02 8,100' 8,264' 164' 4 10/12/85 4" TCP Guns G-03 8,560' 8,740' 180' 4 9/19/85 4" TCP Guns G-03 8,784' 8,970' 186' 4 9/19/85 4" TCP Guns G-04 9,390' 9,420' 30' 4 9/18/85 Cmt Sqz'd F i s h x 10/94 – LS has half of a pump with a spear stuck in it. x 11/94- LS has a grapple, from a broke overshot, is on the spear. x Long string & fish was perforated on 2/27/95 x Complete lower pkr assy for CT jet pump (SS) x Kinley perforating Assembly (SS) & packer PBTD = 9300’ TD = 9642’ MAX HOLE ANGLE = 21.45O @ 9530’ 30” 242’ CBL TOC 2050’ G H I J Circ Holes 7360’ - 7365’ Tubing punch 7391’ slm RKB: MSL = 101’ ; RKB to Tbg Hngr = 32.00’ Mudline= 203’ Water Depth= 102’ 9-5/8” 7687’ Open Perfs 7429’ – 7435’ C D E F 1 2 3 4 Stage collar @ 3890’ 20” 660’ 13-3/8” 3200’ 7” 9630’ Drillable BP 9300’ MGS Oil Top 5640’ TOL @ 7544’ Open Perfs 7738’ – 9420’ Base MGS Gas 4695’ 397 bbl cement in LS x IA 48 bbl cement in CT x SS B A 9.8 ppg brine Dog Legs 3.96 @ 1000’ 3.21 @ 3300’ 2.98 @ 7800’ ADL: 17595 PTD: 185-135 Leg 2, Slot 3 API: 50-733-20377-00 JN/ARD 12/2010 1 From:McLellan, Bryan J (OGC) Sent:Tuesday, June 24, 2025 4:14 PM To:Casey Morse Subject:RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, I’m thinking the 3000 psi squeeze max is getting uncomfortably close to burst on the 9-5/8” 40# casing when placed on top of a column of cement at 2000’. What do you think about using IA pressure as the limit with a max of 2000 psi to provide a bit more safety factor for the old casing? Then oƯer a minimum injection rate at that pressure before swapping to take returns up IA. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Thursday, June 19, 2025 10:56 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, The formation frac pressure is estimated at 0.9-1.1 psi/ft (at ~7200’ TVD) would mean the IA could have 1650 psi surface pressure with the TOC at 2000’ before potentially initiating a fracture in the upper perfs. There are 2 options to handle the formation locking up – we could either increase the pump pressure towards the higher end of that frac propagation estimate and potentially push that extra cement into the top perfs, or we could swap to taking returns up the IA with the additional volumes. At the 1.1 psi/ft range, we’ll be close to 3000 psi of surface pressure on either side (LS or IA/SS/CT). I recommend we use 3000 psi as a limit across all the strings during that displacement, and if we can’t get the volumes into the perfs at that pressure, we swap to taking returns up the IA. x At the beginning of the displacement (LS full of cement), 3000 psi on the IA/SS/CT would correspond to 2550 psi on the pump. This would be ~1.1 psi/ft equivalent. x Towards the end of the displacement (LS cement ~5500’), 3000 psi on the pump would correspond with 2225 psi on the IA/SS/CT. This would be ~1.0 psi/ft equivalent. I have a digital copy of the CBL that’s 318 MB, so I don’t think it will go through in email. I’ll have the Geotech submit the Ʊle from their system. 2 Thanks, Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, June 17, 2025 4:13 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, 1. What is the max injection pressure on the IA while bullheading cement into perfs? You should be able to calculate that if you know your TOC is at 2000’ md. It’s a little unclear what is meant be hold 440 psi diƯerential on IA/SS/DT while displacing cement in step 2.v.. 2. What is your plan if the well locks up half way into your cement displacement? 3. Can you send me the CBL for the 9-5/8” casing? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, June 16, 2025 11:21 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, Thank you for taking the time to meet with us on Thursday. Here’s a recap of some context on the subject well: The Ʊsh left in the long string on this well was a jet pump assembly that parted when trying to retrieve it initially. Attempts were made to recover the remaining portion of the jet pump assembly. First, a baited spear was CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 latched inside the jet pump. While jarring up, the spear parted at the threads on the top sub of the spear assembly. Next, an overshot was run to latch the outside of the parted spear. After jarring up, the grapple broke free from inside the overshot and was left on top of the parted spear assembly. At that time, the long string was eƯectively “abandoned,” and a coil tubing jet pump was run inside the short string. With this history, we believe it to be unlikely that we can retrieve the Ʊsh in the long string to gain access to the tubing tail again. Prior to setting the coil jet pump assembly, a six-foot perf interval was added using perf guns inside the short string from 7429 – 7435’. As part of the diagnostics program last year, we circulated a dye pill down the LS up IA with dye returns observed at 434 bbls (calculated volume in LS and IA from surface to 7429’ is 436 bbls.) This suggests that the circulation point for the LS x IA is at the perf holes, and the perforations shot from the SS likely penetrated the LS as well. Forward plans for this well: Hilcorp would like to seek a variance to proceed with the well abandonment work in relation to 20 AAC 25.112(c)(1)(C) and (D). As it pertains to subsection (C), Hilcorp is seeking commission approval to place a cement plug via the displacement method from the top of the Ʊsh in the long string. Access to the tubing tail is restricted, and prior attempts to recover the Ʊsh were unsuccessful. This would place the circulation point at the top of the perforated interval. All open perforations are in the F and G sands. In relation to subsection (D), Hilcorp proposes abandonment of the perforated interval via the downsqueeze method without the use of a cement retainer or production packer. Below is a proposed cement program to achieve the goals of 20 AAC 25.112(c). This would replace Step 2 in the original procedure: 2. Pump reservoir abandonment cement plug as follows: ¾ 20 bbls RIW (Raw-Inlet-Water) w/ Surfactant Wash (down LS and out IA) ¾ 400 bbls 14 ppg Class G cement with retarder to account for estimated job duration of ~4 hours. Record volumes of Ʋuid recovered i. Start pumping down LS and out IA ii. Return 335 bbls from IA (IA cement volume of 291 bbls plus LS volume of 43 bbl) 1. Pressure on SS/CT should be ~1570 psi higher than LS/pump pressure as LS Ʊlls with cement iii. Close IA (pressure on IA should be ~440psi higher than LS pressure). Swap to taking returns from the SS (CT annulus). Return 32 bbls. iv. Close SS and swap to taking returns up the CT. Return 13 bbls up the CT. v. Close CT. Hold ~440psi diƯerential on IA/SS/CT while pumping additional 16 bbl cement squeeze volume down LS (if needed, if no volumes were lost to formation during prior circulations). vi. Keep IA/SS/CT closed while pumping displacement. ¾ Foam Wiper Ball ¾ 32 bbls of 9.8 ppg brine displacement of cement (puts TOC in LS @ ~5500’, TOC in IA / SS / CT @ ~2000’). Pressure should equalize on the IA/SS/CT with the LS pump pressure as displacement pushes TOC deeper in the LS. i. Formation frac pressure estimated at bottomhole pressure of ~6500 psi 1. Full column of 14 ppg cement plus 1200 psi surface pressure 2. TOC at 2000’ with 9.8 ppg brine on IA/SS/CT plus 1650 psi surface pressure 3. TOC at 5500’ with 9.8 ppg brine in LS plus 2400 psi surface pressure ¾ Shut in well and hold ~765 psi diƯerential on LS to keep cement plug over-displaced. Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC 4 (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 9, 2025 5:20 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, This P&A plan will require a variance for approval because the well conƱguration does not easily lend itself to any of the P&A plug techniques outlined in 20 AAC 25.112(c)(1). The variance should include a plan to place cement across the perforations as intended in 20 AAC 25.112(c)(1)(C) or (D). A downsqueeze could be possible if you can conƱrm that some Ʋuid is being injected past the shallowest perfs and the Kobe cavity. Or possibly retrieving Ʊsh from the long string and setting a cement retainer below the Kobe cavity so you can ensure cement is being circulated around the bottom of the tubing tail. Or pull the tubing could be an option. I’m open to other ideas. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, June 4, 2025 3:40 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, It is my understanding that the discussions we’ve had over the past few months and the logs we provided for this well should address the concerns below regarding isolation relative to applicable Pool deƱnitions. What additional information do you need from us to move forward with this Ba-20 sundry? Thanks, Casey Morse Operations Engineer CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 5 Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, October 4, 2024 4:13 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, In order to comply with 20 AAC 25.112(c), I will suggest a couple of options: 1. Recover the Ʊsh in the LS, set a retainer in the long string below the perf holes in the tubing and circulate cement with CT below the retainer and out the tubing tail at 8998’. 2. Recover the tubing strings and then circulate cement in from the top of the drillable bridge plug at 9300’ MD with a jointed workstring. I think the sundry should be resubmitted since this would be such a big change. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, September 30, 2024 3:56 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, We were able to pump a dye pill on the Ba-20 last week down LS and up the IA. The dye returned to surface after 434 bbl, which is the volume of the LS and IA down to the perf holes at 7429’. This conƱrms the circulation point from LS to IA is at the top perf at 7429’. Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 6 (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, September 12, 2024 3:34 PM To: Casey Morse <Casey.Morse@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry We can discuss the plan after you gather more diagnostics. It’s not obvious to me how you can ensure that you will be able to bullhead cement below the holes in the LS tubing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Wednesday, September 11, 2024 7:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, We haven’t had the crew on the platform since July 25, so I don’t have any additional information on this. Casey From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, September 9, 2024 4:19 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, Any progress made on determining where Ʋuid is going? I’m inclined to pull the Ʊsh with CT and perform further diagnostics to conƱrm where the Ʋuid is going. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 7 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, July 29, 2024 7:30 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Bryan, Good catch on that. We weren’t able to get deep enough in the LS to conƱrm if those perfs were open in the LS. The Ʊles show that the “F” Zone perforations from 7429 – 7435’ were shot through the short string before running the coil tubing completion, so it’s likely they would have blasted through the LS as well. It would be good to pump a dyed pill down LS / up IA to conƱrm the circulation point before we proceed with the cementing. If Ʋuid turns the corner at 7429’ I don’t see any issues with placing cement like you suggested below and bullheading it down into the perfs. If we Ʊnd that the Ʋuid is making it to end of tubing, we could place cement as described in the sundry. Thanks, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 26, 2024 3:59 PM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: [EXTERNAL] MSG 17595-20 (PTD 185-135) suspension sundry Casey, I think this plan is workable but will need a slight modiƱcation. The LS is perforated at the top of the Ʊsh according to the wellbore diagram, so the circulation point will not be out the bottom of the tubing tail and across the perfs. After circulating cement up the IA , SS and CT, you’ll need to CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 8 shut-in returns and bullhead cement down to the perfs. Attempt to bullhead the annular volume from the LS tubing punch down to the bottom perf at 8970’ MD plus the volume of the tubing tail below the KOBE pump. Thoughts? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 45_COAL A-1 C E1_ST 44_COAL E G-2_ST F-1 G-3B_ST 50_COAL B-3 D-2 46_COAL G-2_MKR G-3_MKR A-2X F G-3B_MKR_R C-2 D-1 F-2 D-3 E_ST B-1 A-2 F2_ST A A-3 A-1X E-1 F2_BASE B A-4 Top MGS Oil Pool (MGS State 18746-1) B-2 G-1A_ST E-2 47_COAL G-1B_ST C-3 D G-3A_ST F_SAND_TOP C-4 HEMLOCK F_SAND_BASE E1_BASE C-1 Packer Packer Btm 9-5/8" Active Active Active Active WLEG Plug Inactive (9649.2) 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 9200 9225 9250 9275 9300 9325 9350 9375 9400 9425 9450 9475 9500 9525 9550 9575 9600 9625 (9276.8) 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 9200 9225 9250 (9197.8) 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 45_COAL A-1 C E1_ST 44_COAL E G-2_ST F-1 G-3B_ST 50_COAL B-3 D-2 46_COAL G-2_MKR G-3_MKR A-2X F G-3B_MKR_R C-2 D-1 F-2 D-3 E_ST B-1 A-2 F2_ST A A-3 A-1X E-1 F2_BASE B A-4 Top MGS Oil Pool (MGS State 18746-1) B-2 G-1A_ST E-2 47_COAL G-1B_ST C-3 D G-3A_ST F_SAND_TOP C-4 HEMLOCK F_SAND_BASE E1_BASE C-1 BA-20 [SSTVD] Spud date: 07/20/1985 UWI: 507332037700 Completion Date: 11/11/1985 Gas Rate - 10.03.23: Oil Rate - 01.03.23: Water Rate - 01.03.23: Cum. Gas - 10.03.23: Cum. Oil - 01.03.23: Cum. Water - 10.03.23: Max inc: 21.45 deg Petra WSN #: 82 TD (MD): 9642.0 ft MD -69.02 278.31mV SP -2.17 136.32gAPI GR -0.300 0.300ft3/ft3 NPHI_DPHI_265 0.00 1.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 NPHI-DPHI_2.65 CoalLogRHOB <= 1.95 RHOB TVD Perforation_Log Perforation_Log_ShortString SSTVD 1:1000 1.00 100.00ohm.m RESS 1.0000 100.0000ohm.m RESM 1.0000 100.0000ohm.m RESD 1.00 100.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB > 14 ohms < 14 ohms 0.600 0.000ft3/ft3 DPHI_265 0.600 0.000ft3/ft3 SPHI_MJP 0.6000 0.0000ft3/ft3 NPHI 1.65 2.65g/cm3 RHOB 150.00 50.00us/ft DTC 0.00 1.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB SPHI_MJP NPHI/DPHI_2.65 Crossover DPHI_265 >= 0.12 RHOB-NPHI Crossover DTC/NPHI Crossover 1.00 2,000.00STB/lbm TLGS 0.00 1.00 CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 TLGS Proposed Cement David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL T20240719 Log Image Files for the well listed in the table below: Well Name PTD # API # MGS ST 17595 20 185-135 50-733-20377-00-00 SFTP Transfer - Data Folders: Please include current contact information if different from above. 185-135 T39254 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.19 15:40:54 -08'00' ) ) Chevron .. Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October 10, 2005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary " Ii) 'l.'ù'ifjC¡,:C, ~\~~:J: \;.\Q~ f!;i¡\~\~~'V " ., ...,::' :\ì5J\3š"¡""'" \~,~ Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of U nocal' s pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BHP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BHP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BlIP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. \"""\ ~J.n~. '·r U\TE o ,t-·~ ~~; r-\ \ \. ~ ..I..... Union Oil Company of California / A Chevron Company http;f/www.chevron.com ) ') Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker SOland in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263 -7657. Sincerely, -¿:¿¡ c=, A=-7 Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California / A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27-Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7 -Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned .~ Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6·Jul~05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-J u 1-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba-17 Injector No survey Ba-18 Gas No survey ~a-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 - Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Ba-32 Producer No survey ) ') ~=l~¡ :} IÆ~IÆ~~IÆ AT/ASIiA. OIL AlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSK'. GOVERNOR 333 W. -¡TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker l ß [;.",. t'55" Dear Mr. Cole: This letter confirms your conversation with Co!p~rnission EngLlleer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. .;:. Sincer~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SCANNED NOV 2 4 2004 Enel. Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal 1. Type£>f Request: 3. Address: 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 9,642' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7,429' to 9,420' Packers and SSSV Type: 909 West 9th Ave. Anchorage AK 99501 Total Depth TVD (ft): 9,270' Length 266' ) STATE OF ALASKA ') ALASKA 01 L AND GAS CONSERVATION COMMIS:::;ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing D Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other 0 Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: Development Stratigraphic 0 D Exploratory D 1851350 Service D 6. API Number: 50-733-20377-00 9. Well Name and Number: Ba-20 10. Field/Pools(s): MIDDLE GROUND SHOAL PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9,300' 8,951' Size MD 30 266' 600' 600' 20 3,200' 13 3/8" 7,587' 95/8" 2,086' 7 Perforation Depth TVD (ft): 7,249' to 8,893' 16. Verbal Approval: Commission Representative: D 3,144' 7,322' 9,258' Tubing Grade: 3,200' 7,587' / / Junk (measured): Burst Collapse 2,110 psi 520 psi 3,094 psi 1,540 psi 5,745 psi 3,087 psi 11,827 psi 11,651 psi Tubing MD (ft): Trico Kobe Pump Cavity @ 7,513' LS : 2 7/ " LS: 3 1/2" LS : 6.4# N-80 SS : 9.2# N-80 Packers and SSSV MD (ft): LS: 8,998' SS: 7,482' Printed Nam1/. e . "c<!!e Signatur~~¥/I7~ Subsequent Form Required: Approved by: 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: Plug Integrity Other: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Date: 17. I hereby certify that the foregoing is true and correct to e best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that representative may witness BOP Test D . Mechanical Integrity Test D ¥aB Form 10-4e+Revised 12/2003 Location Clearance RBDMS BFL NOV 2 ~~ICA TION RETURNED 11/1 7/04 NOT APPROVED BY COMMISSION 0 RIG I NA ~YORDEROF COMMISSIONER THE COMMISSION 0 Service D Plugged WINJ D D WDSPL Abandoned D D 27-Sep-2004 Sundry Number: 3t:Lf-4~Y D RECEIVED OCT 1 2 2004 à Oil & Gas Cons C '. A . ommlSSlOfJ ncharage Date: Submit in Duplicate ~-- STATE OF ALASKA .... ALASKA OIL~,-~ND GAS CONSERVATION COl~' .... ~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulat__.e Plugging Perforate Pull tubing After casing Repair well Pull tubing Other X 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address , P.O. BOX 196247 ANCHORAGE, AK 99519 Location of well at surface 1993' FNL, 584' FWL, Sec. 31, TDN, R12W, SM At top of productive interval 3859' FNL, 472' FWL, Sec. 31, TDN, R12W, SM At effective depth At total depth 4440' FNL 418' FWL, Sec. 31, TDN, R12W, SM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 79.4" 7. Unit or Property name Baker Platform 8. Well number ADL 17595 #20 9. Permit number 85-135/95-029 10. APl number 50-733-20377 11. Field/Pool Middle Ground ShoaI/EFG feet 12. Present well condition summary Total depth: measured 9642' feet Plugs (measured) Cmt plug 9300' true vertical 9270' feet Effective depth: measured 9300' feet Junk (measured) ~'-"'t !._~ ! true vertical 8951' feet ~-- ~ ! Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 266' 30" Driven 266' ~' il,, .~ I,. I ~' Surface 600' 20" 1360 sx 600' 0CT 2. 0 199, Intermediate 3200' 13-3/8" 2500 sx 3200' Na$!~ Oil & Gas Cons, C( Production 7687' 9-5/8" 2000 sx 7687' ; ~ltJlCh0l"ag8 Liner 2086' 7" 800 sx 7544'-9630' Perforation depth: measured 7429'-7435'; 7738'-8050'; 8100'-8264'; 8560'-8740'; 8784'-8970'; 9390'-9420' true vertical 7249'-7255'; 7561'-7868'; 7910'-8049'; 8287'-8423'; 8456'-8589'; 8826'-8893' 13. Tubing (size, grade, and measured depth) Short string: 3-1/2", 9.3#, N-80 7494' 1-3/4", 1.91# QT-700 Coiled Tubing @ 7335' Packers and SSSV (type and measured depth) Long String: 2-7/8", 6.4#, N-80 @ 8998' 2-1/2" National Pump Cavity (~ 7513'/Halliburton Tb~l Pkr (~ 7337' Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation Oct. 94 142 22 83 70 2100 Subsequent to operation 199 .-- 18 87 70 3125 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operation.% X Oil Gas Suspended Service 17. I hereby certify that the forei)rtini~/..is.tr~,,e(~o'~,e~st of my. . ?-' .~. . knowledge. G. Russell Schmidt /,r~,.~ ~'~;--~tle Drilling Manager Date 10/16/95 Signed Form 10-404 Rev06/15/88 ," ' " SUBMIT IN DUPLICATE ~missi0n ADL 11595 Tb~s Head Fin Dep(h 52 O0 Ft ' "~' g,,. I ~ ' ' " ~I, fi, ',t- o 9 :.,,ax. ,.,er. A, Pen°. ,_0 Deg. .) 1~3.O - .)/IJU.IJ' 311UL i544.4- 7554.2' HANGER 7~0 - 7~7.0' SHOE 9~00.0- 9~02.0' BRI£~ PLUG 9/18,/85 ~/.~'- ~]mL.V ~oLIIEN1' DlllpFLUb 9628.6 - 9630,4' ~._'.~I-SHOE P_,OT V 5i.5' HANGER Cameron Dual 1~ Hdnger :~ 1, c. pn~tnvrp 2 7/8" BI'C x 31/2" Rpn OCT 2 0 1995 Oil & Gas Cons. Commission Anchorage 7~9.! - 75!5.2' R¢C National Supply 2 I/2" Pump Cov~ 77~.0 - 8C~.0' PERFS 6-1, 4HPF, Baker 4-" TCP Guns, Phase 90,10/13/85 8100.0: 8264.0' PEI¥S 6:5, 4HPF, Baker 4" TCP Guns, Ph~ 90, 10/13/85 8560.0 - 8740.0' PERFS G-4R, 4HPF, Baker 4" ICP gum, PI~ 90, 9/19/85 8784,0 - 8970.0' PERFS 6-5R, 4HPF, ~ker 4" TCP Guns, Pt~ 90, 9/19/_85. 8997.4 - 8997.8' MULl;SHOE 9~90.0 - 94-20.0' PERFS ~F, ~PF, Baker 4" lCP Guns, PI~ 90, 9/16/85 KB ELEV: 79.'1-' PBTD: 93¢8' ~: 9642' I m~mpmq Oil Weh · I Last W/r'/,,, '~/~/~ --I d!Ul~ SpudOn7/20/8$ I ,,' 14/~1l I- r,- PlnHnrm UFtI\LI \ I ILII. IVilil LB~ k~ UUIIUUGLUI d [vonek" ' JUl J lONG SiRiNG ADL i7595 ,,~,.,,.~, ~na Depth ,;..2.00 Ft. L.'b¥, .,. , 7£JJ J ]£EJ OI IIIil/"FD 6327.0- 7681.0' 9 5/8" OD 55.50i/ft S-95 PROD (;SO 7~.0~ A 7¢07 Al gU,n,[ 9,.i00.0-9,.i02.0' BRi~E PLUG 9/18/85 95]7.0 - 9~2.0' CEEN!'. PI J jO 9628.6 - 9650.,1-' FLOATShu"'E_ BOT V 7~.4-96~.4' 7.000" OD .55.00t/.ft 8-9:5 IJNB. 1~4 I~ t-'~ III III I 4- 4- ¥ ? I 1 I I 4- 7~9.1 - 75132 r~,..',~, ,'btlonal SuppJ)' 2 1 Pump Cmv~ 77~.0 - 8050.0' PEgS (;-1, 4HPF, Baker 4II TCP Guns, Phase 90,10/I,V85 8100,0 - 8264,0' PERFS 0-5, 4HPF, Baker 4-" TCP Guns, Phase 90,10/13/85 8560.0 - 8740.0' PERFS 6-4R, 4Hff, ~ker 4" TCP Guns, Phs 90, 9/19/85 8784.0 - 8970.8' PE,,RFS 6-5R, 4HPF,, Bdker 4" TCP Guns, Phase 90, 9/19/85 8997.4 - 8997.8' MULBHOE . ~ , [,_...,., ,, ~b OCT 2 0 1995 Nas~ Oil & Gas Cons. Commission Anchorage 9390.0 - 94203 P~S ifF, ~F, t~kr 4" TOP Guns, Phs 90, 9/16/85 KB ELEf: 79.4-" PBTD: 9;00' 'ID: 964-2' I I Pumpin90ii Well -tLo t'w/o ~ ~_,,. UUllUUU~UI J T ~ ' ~-'- I _;- AUL "'""~'" i d ;.,-J fha HeoO ';'~''.''', ,, ,,.., Depth ,52.U0 ?',t Ferfs '-' ' hi- I''"" "' · ~ .... ;-;J II ii ti ii I I! ii I I 1ii Iii 7~1~,1 7314.? r'~'~r~° "" ' L,i'..U,X)'u'fLI'.. Bker fbg. Connector - boiled 7ii 0 I,_l!O,I.J - I,_ll().! Z.iJI l,.tLI !J,.illJ tl.I L/'i. lll. lll~,j rilrrLL i~j~!l_~j!tUl! ' ./b FUII~ 7523,4 - 7523,9' 2,!93" OD 1,378" ID CROSSOV~ 1.90" NU lORD B x 1.25"[ 7325,9 - 7326,4' 2,75" OD !.,177" ID H','~RAUUC PUMP frico ~et Pump ~viiy 7526.4 - 7,126,9' 2,75" OD 1.337" ID CROSSO~R 1 1fi4" NU P x 1.9" EU P 7326,9 - 7,327.9' 2,5,~6" OD 1,748" iD SEALS t~Sll ~oi Ijnil 1526,g. - 7jj7,2. z,~.Ju OD 2,380" ID F'BR~.)~'.)¢ 7329.9- 7J~0.8 ,..,,,,,~ OD 1.745" ID SEALS IASN Seal Unit 7552.9 7333.9'"' 77,,, - Z,JJq OD 1.746" ID SEALS NISN ~ol Unit 7334.9 - 73;5,5' 2,5S6" OD 1.06Y ID ~4ULESHOE -777-? ~,IOOj.Z _ -;'7 lf~ fil ! Y'4,]J.g ~. J .J~ ;t '7~T:qil {,J"J"~l'1 1 .~{U'7413Il JLIif'~ ?.r JJ~.¥.F'F-iT'/'t F,~b J'xF_J~. F',i F',liFn nUUIUUlLL~III'II'L' JL.. J~,~JJ('J!j ~.ljF1 .... i. TFiFXjD}$,~ OCT 2 0 1995 Alaska Oil & 6as 6ons. 6ornmission Anchorage Pumping Oil Well Las[ W/O '~/~/r'~ qUF)U Spud On 7/20/85 SHOR[ S~NqNG iii KB E[~f: 79.f PBTD: IL/: lJl:)~r/_' x,=-/,),;,,.v i.~,) OD i ID u~-/uu COILED ,J J,M ., , . 7579.0 - 73,84.8' 2.875" OD FiSH lB ~. Fish x~_ 7489.1'2.875"0D ~on~/H ,n dO,U ~.=~/, N-,~ BO LONG S~IN6 50.8- 7477.0' ~,5~II OD 9,20~/H ~ SHOR~ miNG 7478.5 - 7489.I' 1.250" OD TBG SHORT STRING OCT 2 0 1995 Alaska ui! & 6as Cons. 6ommissior~ Anchorage [ j Pumping Oil Well - -tL t'w/o BAKER 20 COIL TUBING JET PUMP INSTALLATION DAY 1 (02/27/95) R/U ATLAS W.L. RIH TO MAKE GR TIE-IN, TOOL FAILURE FOUND TUBING TALLEY OFF 50' COMPARED TO GR. PERFORATE 7429'- 7435' FLUID LEVEL ROSE 200'. M/U TUBING PACKER ON E-LINE. RIH COULD NOT GET PACKER DEEPER THAN 9' BELOW BOTTOM MASTER VALVE. POOH. N/D SWAB VALVE & CT HANGER DAY 2 (02/28/95) MADE SEVERAL GAUGE RING AND 2.83" OD. DRIFT SLICKLINE RUNS. 2.86" X 15' DRIFT WOULD NOT 2' BELOW HANGER. TREE APPEARS TO BE SLIGHTLY COCKED WHICH WILL NOT ALLOW DRIFT TO PASS. DAY 3 (03/01/95) M/U 2.83" DRIFT 5' LONG TAG AT 2' BELOW HANGER, JAR DOWN PASS TO 7400' ON SLICKLINE. M/U OTIS 2.75" O.D. PACKER ON ARM SLICKLINE RUNNING TOOL, JAR AND WORK THROUGH HANGER. RIH SET DOWN AT 7374' WORK DOWN TO BOTTOM AT 7400'. PICK UP TO 7374' WOULD NOT GO ABOVE THAT DEPTH ATTEMPT TO SET PACKER AT 7374' SETTING TOOL DID NOT WORK. ATTEMPT TO POOH PACKER STUCK AT 7374'. JAR UP TOOL CAME FREE AT GS PULLING TOOL. RIH W/SLICKLINE FISHING ASSY. JAR ON RUNNING TOOL AND PACKER FOR 10 HRS COULD NOT FREE. OCT 2 0 '1995 Ataska u~l & Gas Cons. Commission Anchorage Baker 20 Page 2 DAY 4 (03/02/95) RELEASED SLICKLINE FISHING TOOL AND POOH. WAITED 9 HRS FOR BRAIDED-LINE, WIRELINE UNIT. INSTALLED AND TESTED LUBRICATOR. RAN PULLING TOOL ON BRAIDED LINE AND ENGAGED PACKER SETTING TOOL @ 7340'. JARRED FREE AND RECOVERED PACKER SETTING TOOL, FOUND TOOL HAD APPARENT INTERNAL 0-RING LEAK WHICH PREVENTED SETTING AND RELEASE FUNCTIONS FROM OCCURRING. DECIDED TO AVOID RISK INVOLVED WITH FISHING PACKER #1 BY PUNCHING HOLES IN TUBING ABOVE FISH AND SETTING NEW PACKER. RAN KINNLEY PERFORATOR WI0.5" TUBING PUNCH AND PUNCHED ONE HOLE IN TUBING AT 7391' SLM. POOH. FOUND WEAK POINT SHEARED AND KINNLEY PERFORATOR LEFT IN HOLE. WAITING ON RETRIEVING TOOL TO BE SENT FROM BEACH. DAY 5-7 (03/03-05/95) WAITING ON PULLING TOOL FOR KINLEY PERFORATOR AND ATLAS WlRELINE HANDS. PLATFORM FOGGED IN FOR MOST OF 3~3~95. WAIT 16 HRS. ATTEMPT SEVERAL TIMES TO RETRIEVE KINLEY PERFORATOR AT 7391' SLM W/O SUCCESS. R/U ATLAS ELECTRIC LINE. PERFORATE CIRCULATION HOLES IN SS FROM 7360' TO 7365', WAIT 6 HRS ON HALLIBURTON SETTING EXPLOSIVE FOR PACKER. SET HALLIBURTON TUBING PACKER AT 7340'. N/U COIL TUBING HANGER AND BOP, PRESSURE TEST SAME. PUMP CLEANING BALLS THROUGH COIL. M/U PUMP ASSY. RIH ON 1.75" COIL TUBING. STRING INTO PACKER AT 7340' VERIFY PUMP WORKING TEST SEALS TO 1950 PSI. HANG OFF CT IN HANGER. ATTEMPT TO PRESSURE TEST CT HANGER TO 2500 PSI W/O SUCCESS, LEAKING BADLY. POOH W/COIL TUBING AND PUMP ASSY. OCT 2 0 1995 Alaska 0ii & Gas Cons. Commission Anchorage Baker 20 Page 3 DAY 9 (03/07/95) ATTEMPT TO PUMP-OUT PLUG @ 4300 PSI. DID NOT SHEAR. SHOULD SHEAR-OUT @ 3800 PSI. RU OTIS SLICKLINE UNIT. RIH & PULL JET PUMP FROM CAVITY. ATTEMPT TO SHEAR-OUT PLUG. SHUT DOWN FOR THE NIGHT. PREPARE TO PULL COMPLETION W/DOWELL CTU. DAY 10 (03/08/95) PULLED INNER TUBING STRING & BHA W/DOWELL CTU. REMOVED SHEAR-OUT ASSY FROM BHA AND RE-RAN CTU INNER STRING. STABBED PKR AND SET TBG HGR AND ENERGIZED PACK-OFF. DAY 11 (03~09/95) R/D CTU. PLACED WELL ON PRODUCTION. FINAL REPORT. ,, . 0CT 2 0 1995 A~ask~ 0il & Gas Cons. Commission Anchorage STATE OF ALASKA A~.,3KA OIL AND GAS CONSERVATION COI~,,,,tSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing AJter casing Plugging __ Perforate _X._ Repair well Pull tubing __ Other X_ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Location of well at surface (LEG #2, SLOT #3) 1993' FNL, 584' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 3859' FNL, 472' FWL, Sec. 31, T9N, R12W, SM At effective depth At total depth (9642') 4440' FNL, 478' FWL, Sec. 31, T9N, R12W, SM 5. Type of Well: 6. Datum elevation (DF or KB) 79.4 KB 7. Unit or Property name Baker Platform 8. Well number ADL 17595 #20 feet 9. Permit number/approval number 85 - 135/95-O29 10. APl number 50-733-20377 11. Field/Pool Middle Ground ShoaI/EFG 12. Present well condition summary Total depth: measured 9642' true vertical 9270' Effective depth: measured 9300' true vertical 8951' Casing Length Structural Conductor 266' Surface 600' Intermediate 3200' Production 7687' Liner 2086' Perforation depth: measured feet Plugs (measured) Cmt plug 9300' feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 30" DRIVEN 266' 240' 20" 6360 sx 600' 600' 13-3/8" 2500 sx 3200' 3200' 9-5/8" 2000 sx 7687' 7510' 7" 800 sx 7544'-9630' 7366'-9453' 7429'-7435'; 7738'-8050'; 8100'-8264'; 8560'-8740'; 8784'-8970'; 9390'-9420' true vertical 7251 '-7258'; 7561'-7868'; 7910'-8049'; 8287'-8423'; 8456'-8589'; 8826'-8893' Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 8998' LS 3-1/2" 9.3# N-80 7494'SS 1.75' CT 1.9#, QT-700 7.334' Packers and SSSV (type and measured depth) 2-1/2' National Pump Cavity @ 7513' 2.75 TRICO JET PUMP @ 7323 O C ~'~ I~ ! ~LI I~. I"~ I t\ L~.,LI ¥ I~ ~.,' I 13. Stimulation or cement squeeze summary Intervals treated (measured) None MAY -$1995 Treatment description including volumes used and final pressure None ~Li~ka 0il & Gas Cons. C0mm Anch0ra :~ 14. Prior to well operation Representative Daily Average Production or Injeotion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure'- Shut-in Tubing Pressure Subsequent to operation 106 161 62 80 80 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X_ 16. Status of well classification as: Oil X_ Gas __ Suspended __ Service 17. I hereby certify that the for~o~ il. tiii~d~ the best of my k~wledge. Si?o:e J10_G~. RjSRSeevl10S6:1h~id88t/~,/'~d/-,v,,~,~'~itle DRII-IJ N G MANAGER Date May02~ 1995 SUBMIT IN DUPLICATE sl0n Ci h~OT CTO%if' IL/ii I!g!JU L,'UIJ(II ,,.,/&,...,.J i L, P,-,/:, '1ri n I~qU/",, L/BY. ,q( I ,.¢_.113. £U /,)Zb.'.? ]7fi7 ~ !,J/,).~ 77q7 i JA,%' - i,J'Zt).fl - t JZU.:J - ,r dL;J,J 7~77 - - I,),)/.Z /./:)U'_ UU/.,)OUIU F~I~ u~.L.," 7707 OI ') t/'lTll /~FI 77011 (~ill ~'1 - ~r'~ ......... IJZ().~ Z./U UU I.d'// IL)HIUF.~,ULIb rV/i~ ,JUt 'I/4" y ~u'Ejj 7707;~ a 77L ;~B ! 7IOn Ih ("[,~1 (' iiC'l,l ('..I /dZ/,~' ~,dd(.J UU [ /~_ IU O~,L.3 h'M1 .)uijl UI,I,. m,,~, ~ x~,, r~r~ 1.74.? ID qp,~r. ,c~,~ ~' ~ ~,-;i /d,JV,I) LO.i) VU .... 77~ fi~ 9 7Li' fib i 7AHi Ih c',-~ c' c' , · .'~n~,~..~L Um.., ,, ?~i~ ~,0, ~:x',,., ,,. O~ ir't'?''.b'gJ lO ,,]ULLJH,.Et'I I [':."' 7J.59' 2.7? 73 ..],?" .),.ET,)/.'~.¢..EY.; ."~. '.t' i,i!.)5.()- 7,198.0' PACt'/R Ha!liburtr~n Re?!~] ihq. Patch R E C E IV E O MAY - 8 1995 Oil & Gas Cons. Commission Anchora./' % Id Orl -' / .... /! ',JtJm',J .t l! L ,,J¢ ..',. i: ? ,:%ndudnr 3 i}/one: bo:: JO>J - . . - '., .' O 7 .......,,:,,:...., '. :* *-, - 2522 . XOLLA~ - ............ i ....... iii ............ ,'.->~_v,.. - .h..',,/l ii ~i .3i/,.' i.,'ii ~i iiU~Iii i~ k~J ?h,'iiii V..,'L..',U - il?'-,i i)'!i ~-i/~-:-;" JiiJ :~.i hii~iTi X-!43 VHiii i i I i"i I I i i i iii i i i I~ ' ,: ~1~ ii ii ii ii~ i I i I III!~ i i i i i iiii i ~ ii~ i i ii Ii~ i i ii iii i I t I iii I i~i i ~ ~ ili "iii iii iVO LLLf, ! ,_.,T TF:,,, ii;. La)fi/ RECEIVED MAY -8 1995 Alaska Oil & 6as Cons. Commission Anchora .,- f ...... F""J .... Il LUbl. i'I/U d/ iJi ;',,, .... BAKER 20 COIL TUBING JET PUMP INSTALLATION DAY 1 (02/27/95) R/U ATLAS W.L. RIH TO MAKE GR TIE-IN, TOOL FAILURE FOUND TUBING TALLEY OFF 50' COMPARED TO GR. PERFORATE 7429'- 7435' FLUID LEVEL ROSE 200'. M/U TUBING PACKER ON E-LINE. RIH COULD NOT GET PACKER DEEPER THAN 9' BELOW BOTTOM MASTER VALVE. POOH. N/D SWAB VALVE & CT HANGER BAKER 20 COIL TUBING JET PUMP INSTALLATION DAY 2 (02/28/95) MADE SEVERAL GAUGE RING AND 2.83" OD. DRIFT SLICKLINE RUNS. 2.86" X 15' DRIFT WOULD NOT 2' BELOW HANGER. TREE APPEARS TO BE SLIGHTLY COCKED WHICH WILL NOT ALLOW DRIFT TO PASS. DAY 3 (03/01/95) M/U 2.83" DRIFT 5' LONG TAG AT 2' BELOW HANGER, JAR DOWN PASS TO 7400' ON SLICKLINE. M/U OTIS 2.75" O.D. PACKER ON ARM SLICKLINE RUNNING TOOL, JAR AND WORK THROUGH HANGER. RIH SET DOWN AT 7374' WORK DOWN TO BOTTOM AT 7400'. PICK UP TO 7374' WOULD NOT GO ABOVE THAT DEPTH ATTEMPT TO SET PACKER AT 7374' SETTING TOOL DID NOT WORK. ATTEMPT TO POOH PACKER STUCK AT 7374'. JAR UP TOOL CAME FREE AT GS PULLING TOOL. RIH W/SLICKLINE FISHING ASSY. JAR ON RUNNING TOOL AND PACKER FOR 10 HRS COULD NOT FREE. R£C£1V£D ~A¥ -$ 1995 Alaska 0ii & Gas Cons. Commission Anchora ~' DAY 4 (03/02/95) RELEASED SLICKLINE FISHING TOOL AND POOH. WAITED 9 HRS FOR BRAIDED-LINE, WIRELINE UNIT. INSTALLED AND TESTED LUBRICATOR. RAN PULLING TOOL ON BRAIDED LINE AND ENGAGED PACKER SETTING TOOL @ 7340'. JARRED FREE AND RECOVERED PACKER SETTING TOOL, FOUND TOOL HAD APPARENT INTERNAL 0-RING LEAK WHICH PREVENTED SETTING AND RELEASE FUNCTIONS FROM OCCURRING. DECIDED TO AVOID RISK INVOLVED WITH FISHING PACKER #1 BY PUNCHING HOLES IN TUBING ABOVE FISH AND SETTING NEW PACKER. RAN KINNLEY PERFORATOR W/0.5" TUBING PUNCH AND PUNCHED ONE HOLE IN TUBING AT 7391' SLM. POOH. FOUND WEAK POINT SHEARED AND KINNLEY PERFORATOR LEFT IN HOLE. WAITING ON RETRIEVING TOOL TO BE SENT FROM BEACH. DAY 5-7 (03/03-05/95) WAITING ON PULLING TOOL FOR KINLEY PERFORATOR AND ATLAS WIRELINE HANDS. PLATFORM FOGGED IN FOR MOST OF 3/3/95. WAIT 16 HRS. ATTEMPT SEVERAL TIMES TO RETRIEVE KINLEY PERFORATOR AT 7391' SLM W/O SUCCESS. RJU ATLAS ELECTRIC LINE. PERFORATE CIRCULATION HOLES IN SS FROM 7360' TO 7365', WAIT 6 HRS ON HALLIBURTON SETTING EXPLOSIVE FOR PACKER. SET HALLIBURTON TUBING PACKER AT 7340'. N/U COIL TUBING HANGER AND BOP, PRESSURE TEST SAME. PUMP CLEANING BALLS THROUGH COIL. M/U PUMP ASSY. RIH ON 1.75" COIL TUBING. STRING INTO PACKER AT 7340' VERIFY PUMP WORKING TEST SEALS TO 1950 PSI. HANG OFF CT IN HANGER. ATTEMPT TO PRESSURE TEST CT HANGER TO 2500 PSI W/O SUCCESS, LEAKING BADLY. POOH W/COIL TUBING AND PUMP ASSY. DAY 9 (03/07/95) ATTEMPT TO PUMP-OUT PLUG @ 4300 PSI. DID NOT SHEAR. SHOULD SHEAR-OUT @ 3800 PSI. RU OTIS SLICKLINE UNIT. RIH & PULL JET PUMP FROM CAVITY. ATTEMPT TO SHEAR-OUT PLUG. SHUT DOWN FOR THE NIGHT. PREPARE TO PULL COMPLETION W/DOWELL CTU. RECEIVED MAY -8 1995 Alaska Oil & Gas Cons. Commission DAY 10 (03/08/95) PULLED INNER TUBING STRING & BHA W/DOWELL CTU. REMOVED SHEAR-OUT ASSY FROM BHA AND RE-RAN CTU INNER STRING. STABBED PKR AND SET TBG HGR AND ENERGIZED PACK-OFF. DAY 11 (03/09/95) PJD CtU. PLACED WELL ON PRODUCTION. FINAL REPORT. ,.---. STATE OF ALASKA .--, AL ,KA OIL AND GAS CONSERVATION COl~ '.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Suspend m Opera~Jons shutdown __ Re-enter suspended well__ Alter Gasing__ Repair well __ Plugging __ Time extension m Stimulate __ Change approved program _ _ Pull tubing __ Vadance __ Perforate X_ Other 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 Location of well at surface (LEG #2, SLOT #3) 1993' FNL, 584' FWL, SEC 31,T9N, R12W, SM At top of productive interval (7738') 3859' FNL, 472' FWL, SEC 31, T9N, R12W, SM At effective depth At total depth (9642') 4440' FNL, 418' FWL, SEC. 31, T9N, R12W, SM J5. Type of Well: Development X Exploratory __ Stratigraphic__ Service __ 6. Datum elevation (DF or KB) 79.4' KB 7. Unit or Property name BAKER PLATFORM 8. Well number ADL 17595 #20 9. Permit number I. 5' -- 10. APl number 50-733-20377 11. Field/Pool MIDDLE GROUND SHOAI. JEFG feet 12. Present well condition summary Total depth: measured 9642' true vertical 9270' feet Plugs (measured) feet CEMENT PLUG 9300' Effective depth: measured 9300' true vertical 8951' feet Junk (measured) feet Casing Structural Conductor 266' Surface 20" Intermediate 3200' Production 7687' Liner 2086' Perforation depth: measured Length Size Cemented Measured depth True vertical depth RECEIVED 30' DRIVEN 266' 20' 136o sx 600' FEB 2 1 1995 13-3/8" 2500 SX 3200' ~l~ska 0il & Gas Cons, Commission 9-5/8' 2000' sx 7687' Anchora '~ 7" 800 sx 7544'-9630' 7738'-8050'; 8100'-8264'; 8560'-8740'; 8784'-8970'; 9390'-9420' true vertical 7561'-7868'; 7910'-8049'; 8287'-8423'; 8456'-8589'; 8826'-8893' Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 8998' 3-1/2" 9.3# N-80 7494' Packers and SSSV (type and measured depth) 2-1/2" NATIONAL PUMP CAVITY @ 7513' 13. Attachments Description summary of proposal x _ Detailed operations program__ BOP sketch x 14. Estimated date for commencing operation 2/21/95 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil x Gas Suspended __ Service 17. I hereby certify that the f _~ing(J~tr? ~o the best of my knowledge. Signed G. Russell Schmidt~~,,/~.-v~-"~'"'q'itle Drillinq Manager FOR COMMISSION USE ONLY Date 02/16/95 Conditions of approval: Notify Commission so representative may witness Plug Integrity w BOP Test Location clearance Mechanical Integrity Test_ S--~bsequent form required 1--~- _Z_~z~-/'~f-__ ~Dproved Copy Original Signea By Returned David W. Johnston Approved by the order of the Commission --~jommlssioner - Form 10-403 Rev 06/15/88 IApproval No. SUBMIT IN TRIPLICATE Middle Ground Shoal Field ADL 17595 Baker 20 Coiled Tubing Jet Pump Completion Page: I I. Pre- Coiled Tubing Operations: A. Prep Wellhead for Coiled Tubing work: 1) ND power fluid piping. 2) Blind flange long string and lock master valve closed. (Follow UNOCAL lockout/tagout procedures.) 3) ND towline on short string. 4) NU CT hanger (PEDCOR LARGE BORE SAFESET CT 3-1/8' 5M hanger). 5) Blind flange sideport valve and top of CT hanger. Note: 15 Nitrogen bottles will be needed to blow down coiled tubing after operations. B. Perforate F-Zone and set Packer on E-Line: 1) Before starting job, hold pre-job safety meeting w/all personnel. Stress perforating safety w/all personnel. RU wireline unit on Baker 20 short string. Pressure test lubricator to 3~000 psi for 10 minutes. RIH w/G.IL to 7,474'. (G.R. = d,mmy packer) POOH w/G.1L RIH w/2-1/2" hollow carrier 4 SPF 60° phasing perforating gun and make tie-in pass w/CCL. Perforate 3-1/2" tubing ~ 7,424'-7,470'. b"- ~ ~ ~- ~ - /a a-,-/c o~ /otto,, ~ POOH w/CCL and perf gun RIH w. Halliburton 3-1/2" TBG Retrievable Packer w/10' Seal Bore extension on wireline. Seal Bore extension will be on top of packer. A perforated 4' pup joint (w/plug catcher) 2) 3) 4) 5) 6) 7) Note: 9) ]o) 11) will be on the bottom. Set bottom of packer ~ ~7,410' (WLM). guage ring nm. POOH w/setting tool. RD wireline unit. Set packer between tool joints located during RE¢£1VED FEB 2 1 1995 Alaska Oil & Gas Cons. Commission Anchora -" MWD BA20PRO.DOC 2/17/95 Middle Ground Shoal Field ADL 17595 Baker 20 Coiled Tubing Jet Pump Completion C. CT Completion/Prior to Coiled Tubing Operations: 1) Page: 2 Make up CT Completion and test to 5,000 psi for 10 minutes in shop before being shipped to platform. 2) Lock-Tite will be used on ALL tool ioints in the Completion. 3) CT Completion: 1.75" Coiled Tubing Connector -- Baker Oil Tools 4' Pup Joint 1-1/4" 10RD Threads--Tuboscope 1.25" N-Nipple -- Halliburton 4' Pup Joint 1-1/4" 10RD Threads--Tuboscope 2' Jet Pump Cavity w/1.03" Jet Pump in place. No standing valve in cavity. -- TRICO 10' Seal Assembly -- Halliburton Pump-out plug - Haliburton Mule Shoe Guide - Halliburton a) b) c) d) e) f) g) h) 4) Run jet pump in place with slickline setting tool; and verify jet pump can be retrieved before completion is sent to the dock. II. Coiled Tubina Operations: Note: 1) 3) 4) Note: 5) 6) Complete shear test before mobilizing. Verify tree/CT BOP connections before moving CTU to the Baker Platform. (Thread: 3-1/2" 8rd; Flange: 3-1/8" R25 5M psi) Hold safety meeting and discuss procedure w/coiled tubing personnel and production personnel before starting job. Fill out CT pre-job checklist. Verify CT history and integrity. A "COILCADE" shall be placed in well file. MIRU Dowell CTU, pump skid, choke line, double choke manifold, and kill line. Prepare 75 BBLS of kill fluid for Baker 20. Brine will be 3% KCi using FIXV. NU BOP on Baker 20 Short String using flange connections below BOP. Pressure test BOP, 1-3/4" CT, and all surface lines to 5,000 psi for 10 minutes. Use FIW for pressure test--weather permitting. Complete BOP Inspection Perform pull test. MU saddle to jet pump port. MU completion to coil tubing connector and test to 250 psi and 3~500 psi for 10 minutes. Take off saddle. 7) 8) 9) 10) 11) MWD BA20PRO.DOC 2/17/95 ~2) 13) 14) 15) 16) 17) lS) 1~) 20) 21) Note: 23) 24) 25) 26) 27) 2s) 29) 30) 31) Page: 3 Middle Ground Shoal Field ADL 17595 Baker 20 Coiled Tubing Jet Pump Completion Pump 75 BBLS of 3% KCL (FIW) down short string taking returns through CSG vent line and to production. RIH w/1.75" CT and CT Completion. Do not exceed 80 FPM while Rill. Land Seal Assembly into Seal Bore. Set down w/1500 lbs. down weight. Activate CT Hanger Slips. Confirm equal slip positioning. (PEDCOR rep. will be on site.) Rotate injector in-hole and push down with a force of approximately 2000 lbs. Stop injector. Confirm silos are holding tubing weight. Vent trapped pressure between hanger top and below injector stripper. Verify hanger seal has been effected. Slowly release injector skate or gripper pressure completely releasing tubing grip. Retighten release screws. Test Completion: A) Test Coiled Tubing X 3-1/2" Tubing annulus to 500 psi for 10 minutes. Test to Power Fluid Manifold Pressure ~. 3~500 psi for 10 minutes. Increase annulus pressure slowly. Coiled tubing pressure will have to be maintained; other wise the jet pump will unseat at a differential pressure of 1,000 psi. Burst = 5200 psi ~ 7500' & Collapse = 4200 psi ~ surface. B) Test Hanger from above to Power Fluid Manifold Pressure ~ 5~000 psi for 10 minutes. Disconnect BOP from hanger. Cut coiled tubing. Dowell will supply proper tools to cut and dress end of coiled tubing. Dress end of Coiled Tubing and MII wireline re-entry guide on end. NU swab valve. Close swab valve. Lock open master valve on short string following UNOCAL lockoutJtagout procedures. NU power fluid and towlines. Hydro-Test all lines and completion to 5,000 psi. Pressure up to 4,000 psi and shear out plug. RD Dowell CTU. Demob after well is on line. Turn well over to production. MWD BA20PRO.DOC 2/17/95 Baker 20 Coiled Tubing Hanger Completion Wellhead Diagram 3-1/8" 5M R-35 API Studded PEDCOR XO Spool w/Sideport 3-1/8" 5M R-25 API Studded Swab Valve 18.5" PEDCOR 1.75" iled Tubing Hanger 34 Sideport 2-1/16" 5 R-24 API Studded U-Bolt Short String Master Valve Long String Master Valve Side View: Not to Scale MWD A26WHDG.DOC 2/17/95 Middle Ground Shoal Field ADL 17595 Baker 20 Proposed Coiled Tubing Jet Pump Completion Page: I KB = 79.4' 20" CSG @ 600' 13-3/8" CSG ~ 3200' Long String: 2-7/8" Butt 6.4// 0'-7513' Short String: 3-1/2' Butt 9.3 # 0'-7484' Coiled Tubing: OD = 1.75" ID = 1.532" QT-700 Coiled Tubing Connoctor 1.25" Otis N-Nipple w/C-Pump Thru Plug 1-1/4" 10rd Pup Joint 2.20" Trico Jet Pump Cavity WI 1.03" Jet Pump 1.66" EUE X 1.25" 10rd XO 2-7/8" 8rd TBG Pup JT ~ 8997' Mule shoe ~ 8998' 7" Liner Top ~ 7544' Mule Shoe ~ 8998' 9-$/8" CSO (~ 7687' Peri's: 7738'-8050' Perfs: 8100'-8264' Perfs: 8560'-8740' Perfs: 8784'-8970 Squeezed Perfs: 9390'-9420' Not To ~ Halliburton 3-1/2" TBG Packer @ 7,410' Halliburton 10' Seal Bor~ Extension w/Mule Shoe Guid~ F-zone P~fa: 7424'-7481' 3-1/2" X 1-1/4" XO (~ 7484' 3-1/2" Butt X 1-1/4" 10rd XO (~ 7484' 2-1/2" National Pump Cavity ~ 7513' PBTD:9300' TD: 9642' MWD B,a.20'vVBD.D~D~ 2/17/95 Section 310.1 t ~ Pacje 2 of 38 March 1992 COILED TUBI'-'" ~ OPERATORS MAr~UAL The following components me identified in F'~gurs I m~ 2. T'ne BOP commonty found on Oow~# Schlumberger co~e~ tubing unR~ (CTU$) is manufactured Toots (TOT}. This is available in a range of ~izes ~ ramgs snct a~ (ee., H~S, Nc~ or Stanaam · I~P Body · Shear Ram~ 'l'ne model most commonly used is the 3-ira, t0,00~ Working Pressure. H~S service Quaai BOP. It is this on wttich the dlagraxl~ and text in this section are basea. Saxl-Up Flar~e To~ Connecfion~ · 81~ Rams · Pipe Rsms Pressure Port Bland-Ram Eclumizlng VaNe Manual Lo<:~ Ham:lie ,.~ear Ram~ r~..,,~ , Side Port (Kill Pon) .~------ s~ Rsms p1~ Rame (eamm.4) with Ram Pe~ltton ImJ~J~ Bottom Ptn an~ ~ ?~ t~mm~ crl m qumd BOP--lmm v~. · MEMORANb,.., State ,.,, Alaska Alaska Oil and Gas Conservation Commission TO: David Joh rj.~, Chairman"~P' DATE: April 9, 1994 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector 9VEJDHBD.DOC No Flow Ven cat on Wells #D-20,12,27,28,&25 Marathon Dolly Varden platform Middle Ground Shoal Field Friday, April 8. 1994: I traveled to Marathon's Dolly Varden platform in the Middle Ground Shoal field of Cook Inlet to verify the No Flow status of five wells. When I arrived the wells had already had their gas lift shut in and the tubing flowed down to the group separator, These were then flowed to the well clean system which has approximately .5 psi back pressure on it. The wells tubing was then routed to open top containers with water in them. All wells bled only gas and died off quickly with the exception of well #D-25 which kept flowing gas and would build up to 160 psi rather quickly, this may have been residual gas in the annulus coming through a leaky gas lift valve. The platform needed this well back for production and we did not attempt any fudher tests on other wells. Recommendations: Wells # D-20, D-12, D-27, and, D-28 exhibited a inability to flow from the formation without the assistance of artificial lift and met the criteria for No Flow status. Well # D-25 would not die off and should be maintained as a flowing well. Summary: I verified the no flow status of 4 wells on Marathon's Dolly Varden platform. cc: Don Lacour (Production Superintendent) ATLAS WIRELINE SERVICES W~tern Atlas International 5600 B Street, Suite 201 Anchorage, AK 99518 TO: ~0 BE PICKED UP BY/ CURTIS KING OF AMOCO PROD. CO. 1 LIS, 1600 BPI TAPE ~IADE FOR ST OF AK O&G COM. PLUS 1 COPY OF LISTER (VERIFICATION LIST POSTMASTER: RETURN POSTAGE GUARANTEED iNG) W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 January 8, 1988 Frances L. Jones State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 File' WEN-OO1-WF Middle Ground Shoal State 17595 #20 Dear Ms. Jones' In response to your letter to Arnold F. Walker, dated December 16, 1987, enclosed is the information we have available from 10/31/85 - 11/11/85. The digitized tapes and verification listings you requested are being located in Denver. Some time will be needed to locate and copy them. You will be receiving these at a later date, due to the date of the tapes. If you have any questions please contact Joyce Burnett at 562-2147 (ext. 240). Very truly yours, W. G. Smith Di stri ct Manager FJB/db Attachments O01/FJB RECEIVED JAN 1 1 19~8 pdasl~ 0il & Gas Cons~ Commissl0n /~Jmrage W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 December 12, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine DriVe Anchorage, Alaska 99501 File' FEW-O33-WF Gentlemen: Well Completion Report Middle Ground Shoal 17595 Well No. 20 Platform Baker, Cook Inlet, Alaska Attached in d~p~ki-~ate is a State of Alaska Form 10-407, Well Completion or Recompletion Report and Log for the subject well. A directional survey and a well history are also attached for your information. Very truly yours, W. G. Smith District Manager Attachments KLS/dds 014/kls RECEIVED ou & Gas Cong. Comm[ss/or~ Anchorage Middle Ground Shoal 17595 Well No. 20, Platform Baker 07/20/85 07/21/85 07/22/85 07/23/85 07/24/85 07/25/85 07/26/85 07/27/85 07/28/85 07/29/85 07/30/85 07/31/85 Spud well and clean out 30-inch slot. Drill 17½-inch hole to 660 feet. Open hole to 26 inches and run 20-inch casing. Cement with 860 sx Class 'G' lead and 500 sx Class 'G' tail. Nipple up lO-inch diverter lines and drill to 684 feet. Drill to 750 feet. Mud motor to 926 feet. Mud motor to 1,124 feet and drill to 1,417 feet. Mud motor to 1,755 feet. Mud motor 1,755 - 1,824 feet. Drill to 2,479 feet. Drill to 3,200 feet and condition hole for casing. Run 13 3/8-inch casing. Cement 13 3/8-inch casing with 2,000 sx Class 'G' lead and 500 sx Class 'G' tail. RECE'IV 'D Alaska Oil & Gas Cons. Commission Anchorage MGS 17595 Well No. 20 22. Type Electric or Other Logs Run: Mud Log 1,110 - 9,634 feet 08-20-85 Dual Induction Compensated Neutron - Density Diplog 7,694 - 3,200 feet 7,694 - 6,000 feet 09-07-85 Dual Induction Sonic, Gamma Ray Compensated Neutron - Density Diplog 9,641 - 7,687 feet 09-14-85 Cement Bond Log 9,500 - 900 feet 24. Perforations open to production (MD + TVD of top and bottom and interval, size and number) MD (Feet) TVD (Feet) Net Feet Size 7,738 - 8,050 7,466 - 7,763 312 0.25 8,100 - 9,264 7,811 - 7,968 164 0.25 8,560 - 8,740 8,251 - 8,421 180 0.25 8,784 - 8,970 8,463 - 8,640 186 0.25 TOTAL = 842 NUMBER - 4 JSPF Each Interval RECEIVED OJJ & Gas Cons. CoF, lmJssJor~ ~.nchora~e 08-01-85 08-02-85 08-03-85 08-04-85 to 08-17-85 08-17-85 08-18-85 08-19-85 08-20-85 08-21-85 08-22-85 to 08-25-85 08-26 -85 08-27-85 08-28-85 08-29-85 08-30-85 08-31-85 MGS 17595_ Well No 20 Test BOP stack - prepare to drill out of 13 3/8-inch casing at 3,200 feet. Run leak-off test at 3,211 MD to 13.3 EMW. Mud motor 3,211 - 3,359 feet. Stuck stabilizer in 13 3/8-inch casing shoe. Drill 3,359 - 7,516 feet. Mud motoring 7,516 - 7,522 feet. Drill 7,522 - 7,568 feet. ' · Mud motoring 7,568 - 7,583 feet. Drill 7,583 - 7,694 feet. Log DIL/GR, CNL-CDL-GR, Dimpeter from TD to surface casing. Run 9 5/8-inch casing to 7,687 feet and cement with 1150 sx Class "G" lead and 450 sx Class "G" tail. Run Gyro survey. TeSt casing to 1,500 psi. Drill out 9 5/8-inch shoe to 7,698 and test formation to 12.8 ppg EMW. Drill 7,698 - 7,830 feet; mud motor 7,830 - 7,962 feet. Mud motor 7,962 - 8,304 feet. Drill 8,304 - 8,354 feet. Mud motof drill 8,354 - 8,655 feet. MGS 17595 Well No. 20 09-01-85 09-02-85 09-03-85 to 09-04-85 09-04-85 to 09 -05-85 09-06-85 09-07-85 to 09 -09 -85 09-10-85 to 09-11-85 09-12-85 to 09-14-85 to 09-15-85 09-16-85 to 09-17-85 09-18-85 09-19-85 .09-20-85 to 09-23-85 09-22-85 09-23-85 to 09-30-85 Mud Motor 8,655 - 8,749 feet Ream and drill 8,749 - 8,752 feet Mud motor 8,752 - 9,089 feet Ream and drill 9,089- 9,127 i~eet Drill 9,127 - 9,642 feet Log DIL/GR, BHC Log CNL/CDL/GR Log Dipmeter 9,641 - 7,687 feet 9,641 - 7,687 feet 9,641 - 7,687 feet Run 7-inch liner from 7,544 - 9,630 feet and cement with 800 sxs Class "G" Cement through 9 5/8-inch "FO" tool at 3,890 feet with 400 sx Class "G" and close "FO" tool. Drill out excess cement to top of liner at 17,544 feet. Pressure test casing to 1,500 psi. Clean out 7-inch liner and test liner lap to 1,500 psi. Run CBL log from 9,500 - 900 feet. Run DST on West Foreland sand from 9,390 - 9,420 feet. No flow - no recovery. Set bridge plug at 9,300 feet Perforate 8,560 - 8,740 feet, 8,784 - 8,970 feet w/4 JSPF Run hydraulic pumping equipment Place well on hydraulic pump, release rig and test well. Pumping and Testing Well MGS 17595 Well No. 20 10-01-85 to 10-10-85 10-11-85 to 10-12-85 10-13-85 10-14-85 to 10-15-85 10-16-85 to 10-23 -85 10-24-85 to 10-27 -85 Pump testing perforation intervals 8,560 - 8,740 and 8,784 - 8,970 feet. Pull hydraulic pump equipment. Set Bridge Plug at 8,410 feet. Perforate 7,738 - 8,050 and 8,100 - 8,264 with 4 JSPF. Run Hydraulic pumping equipment. Place well on test. Pumping and testing well. Pull hydraulic pump equipment. Retrieve bridge plug at 8,410 feet. Run hydraulic pumping equipment. 10-28-85 to 10-31-85 Pumping and testing welt. DST DATA- 9,390 - 9,420 feet Depth of Gauge: 9,339 feet Pressure Data: Initial Hydrostatic IOP: Start 2134 psi ISIP: Start 2134 psi FOP: Start 2142 psi FSIP: Start 2147 psi FHP: 3330 psi 3315.5 psig End 2134 psi End 2583 psi End 2147 psi End 2579 psi Test Times: IO: ISI: Final Flow: Final SI: 17 minutes 65 mi nutes 131 minutes 141 minutes Note: No Recovery Telecopy No. (907) 276-7542 December 16, 1987 Arnold F Walter Sr Staff Exploration T.ech Amoco Production Company 1670 Broadway, Amoco Bldg Denver, CO 80202 Subject: Middle Ground Shoal State ]7595 #20 Dear Mr Walter: Our records indicate that the latest daily drilling report for the subject well only goes to October 31, 1985, and was received in this office December 16, 1985. We need information from t0/31/85 through 1!/11/85, the completion date shown on our form 10-407 report. We also need any~digitized tapes and verification listings~ Please call me at (907) 279-1433 if there is a problem providing this material. Sincerely, Frances L Jones M±cro£±!m Equ±p Op !! jo/E.FJ.2 ' ' STATE OF ALASKA ...... · . ALASKA ~,.~ AND GAS CONSERVATION C~,.,:.-../IlSSION ~I - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Weli .~ OILJ~ GAS[-I sUSPENDED [] ' ABANDONED F-~ . SERVICE [] - 7. Permit Number 85-135 2. Name of Operator Amncn P~'nrl,m't"~nn r'nmn~.n.y 3. Address ' P.0. Box 100779 4. Location of well at surface Leg 2, Slot 3, MGS Platform Baker 1,993' FNL, 584' FWL, Section 31 TgN R12W S.M. At Top Producing lnterval 6-1 sand at 7,738' MD; 7,466'TVD 3,859' FNL, 472' FWL, Sec 31'T9N R12W S.M. AtTotal Depth 9,642 MD, 9270' TVD ' ' ' 4,440' FNL, 418' FWL, Sec 31, T9N, R12W, S.M. 8. APl Number 50- 733-20377 - 9. Unit or Lease Name Middle Ground Shoal gtatP 1 10. Well Number 20 17. Total Depth (MD+TVD) 9,642, 9270 TVD 22. Type Electric or Other Logs Run See attached list 11. Field and Pool Middle Ground Shoal Field Lower Kenai Conglomerate 5. Eievation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 79.4" KB I ADL 17595 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp; or Aband. I 15. Water Depth, if offshore · 116. No. of Completions 7 ~20-85 09-07-85 ] 11-11-85 ] 102 feet MSL ] 17 I where SSSV set I 21. Thickness of Permafrost 18.Plug Back Depth (MEH-TVD)~ 19. Directional Survey 20. Depth 9,300', 8,95.1 'T~D'Es~ : NO I--] N/A feet MD J 0 23. CASING, LINER AND SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP ! BOTTOM' ~0" 320# -- 0 i 266' 20" 94 K-55 -0 600' "54.5,61# J-55 0 . 3200' 3,47, 53.5##-~0/-~ ~'0 17687' 35# ' S-95 7,544' 9630' 24. Perforations open to Production (MD+TVD of Top and Bottom and .. - interval, size and number) See attached list 13 3/8 9 5/8" 4 27. :EMENTING RECORD HOLE SiZE CEMENTING RECORD -- Driven Conductor 26" ;360 'sx lead, 500sx tail 17..~" :h30(3 '~× lead: 500s×ta ! 1'2.25" .150sx lead.450sx tai 8.5" ;,OOsx Class 'G' 25. TUBING RECORD SIZE I DEPTH SET (MD) PACKER SET (MD) Dual 3.5"I 7,513 N/A -. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. AMOUNT PULLED ;400sxOF0tool ¢38' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None PRODUCTION TEST Date. First Production . .. i 0.9222_85" Date of Test I Hours Tested 11-08-85 I ~ 4. F Iow Tubing Casing Pressure Press.. 'i00 · 100 28. ' 1 Me~th°d of'Operation !F!owing, gas li.f~, etc.) I HyH~,~,,1 ~c Lift IPRODUCTION FOI~IO~E-~6L I GAS-MCF I ~/24-H°uRRATE~-I :~22 --I 't64 CORE DATA WATER-BBL · . ICHOKESIZE I GAS-OILRATIO I 314 IOI I"~R'AVITY-API (corr) · 4'' WATER-BBL . . 24 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED i 6 · Alaska Oil. & Gas Cons. Commission . Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. · . · ':' - : _'~' :: ~:::~:-GEoLOGIcMARKERS~: ~-i~ ' ' : :. :.'; ::.~' ~ '"' ' .':i-: '""'-' ;' .~i~O~'M~TioNTESTs ' :~ ' . . NAME InclUde interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek ,'A" 5,502 - 5,324 See Attachment Middle "B" 6,043 5,846 .. Kenai !'C" 6,327 6,113 : Sands "D" 6,651 6',425 ..E.. 7,039 6,798 -"F" 7,422 7,165 · . Lower "G-I" 7,734 7,463 . · . Kenai "G-2" 7,890 7,611 Con- "G-3" 8,100 7,811 glo- "G~4'' 8,270 7,974 merate . Fault G-4R 8,542 8,234 G-5R 8,773 8,453 West - . Forel and 9,002 8,669 31. LIST OF ATTACHMENTS Lo.qs, perforation summary~chronologicaI wP-11 hi~f_nry a. nH Directional Sur,:ey~ 32. I hereby certify that the foregoing is tr~,ue and correct %o the best of my knowledge Formati on. Test :.. ~ Signed Title District Manager Date 12/ /R.~ 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 Sera, ice Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, Water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production :from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ' ~'- Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". A ~yrodata Directional Survey Date Runl 1-AUGUST-85 '~:-22:'50:0 ., Job Number: CAO785G082 · Surveyor: D'AMICO ,Calculation Method: RADIUS OF CURVATURE "' Proposed Well Direction: 'Vertical Section Calculated ~rom Well Head Location "~, sure Calculated {rom Well Head Location , Horizontal Coordinates Re£erenced to Well Head AMOCO PRODUCTION CO. MIDDLE GROUND SHOAL PLATFORM BAKER, WELL#20 CONFIDENTIAL' CEgTIFIED SURVEY AMOCO PRODUCTION CO. MIDDLE GROUND SHOAL PLATFORM BAKER,~WELL#20 CONFIDENTIAL Page MEAS INCL BORE HOLE DEPTH BEARING £t de9 min deg min 0.0 0 0 200.0 0 17 300,0 0 8 400.0 0 10 500.0 0 8 600.0 0 7 700.0 0 5 800.0 0 42, 900.0 3 3 1000.0 7 0 ' 11oo.o 9 1200.0 10 58' 1300.0 11 27 1400.0 11 50 ,1500.0 12 19 1600.0 11 42 1700.0 12 40 ' 1800.0 14 51 1900.0 14 17 2000.0 13 45 2100.0 13 0 2200.0 13 25 2300.0 13 46 2400.0 12 57 , 2500.0 12 18 N 00E N 1257E S 52 1S E N 70 46 E S 58 29 E S49 6E S 21 13 W S 0 2E $ 719W S 3 9W S 035W S 127E S 043E , $ 0 9W '$ 048W S 314W S 528W S 423W O19W 023E S 055E S 1 15W S 547W S 6 2W S 659W VERT DEPTH ft 0.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 899.9 999.5 1098.4 1196.8 1294.9 1392.8 1490.6 1588.4 i1686.2 1783.3 1880.1 1977.1 2074.4 2171.8 2269.0 2366.2 2463.8 VERT SECTION ft 0.0 -.4 .4 3.6 12.4 27.0 45.0 64.4 84.6 105.5 126.3 147.4 171.1 196.3 220.5 243.6 266.4 289.9 313.0 334.8 CLOSURE DISTANCE BEARING ft deg min 0.0 N 0 0 E .5 N 12 57 E .7 N 34 3 E .9 N 49 49 E 1.1 N 60 20 E HORIZONTAL COORD feet .0 N .0 E .5N .1 E .6 N .4 E .6 N .7 E .5 N .9 E DOG-LEG SEVERITY deB/lO0' 0.00 .14 .36 .15 .14 1.2 N 70 17 E .4 N 1.1 E .03 1.2 N 77 11 E .3 N 1.1 E .11 1.1 S 68 6 E .4 S 1.0 E .63 3.8 $ 12 25 E 3.7 S .8 E 2.36 12.4 S 0 3 E 12.4 S .0 E 3.96 27.0 S 0 59 W ,45.1 S 0 25 W 64.5 S 0 2 E 84.7 S 0 6 E 105.6 S 0 i W 27.0 S .5 W 45.0 S .3 W 64.5 S .0 E 84'.7 $ .I E 105.6 S .0 W 126.4 147.4 171.1 196.2 220.4 .8 W 2.4W 4.4 W 5.4W 5.4W 243.6 S 26,6.4 S 289.9 S 312.95 334.6 $ 5.2W 5.2W 6.7W 9.0 W 11.5 W 126.4 $ 0 21W 147.4 S 0 55 W 171.1 $ 1 29 W ' 196.3 S 1 35 W 220.5 S 1 25 W 243.6 S i 13 W 266.5 S 1 7 W 290.0 $ 1 19 W 313.0 $ 1 39 W 334.8 S 1 58 W 2.84 1.21 .49 .42 .50 .79 1.07 2.21 1.17 .56 .76 .65 1.12 .83 .68 CONFIOENTII L AMOCO PRODUCTION CO. MIDDLE GROUND SHOAL PLATFORM BAKER, WELL#20 Page MEAS INCL BORE HOLE VERT VERT DEPTH BEARING DEPTH SECTION ft deg mtn deg mtn ft £t 2600.0 12 34 S 12 54 W 2561.5 356.1 2700.0 12 35 S 19 16 W 2659.1 377.2 2800.0 13 2 S 19 6 W 2756.6 398.5 2900.0 13 54 S 17 27 W 2853.8 420.9 3000.0 14 14 S 15 9 W 2950.8 444.5 3100.0 14 15 $ 13 56 W 3047.8 468.5 CLOSURE DISTANCE BEARING ft deg min 356.1 S 2 27 W 377.3 S 3 14 W 398.6 S 4 6 W 421.3 S 4 53 W 445.1 S 5 30 W 469.4 S 5 58 W HORIZONTAL COORD feet 355.8 S 15.2 W 376.7 S 21.3 W 397.6 S 28.5 W 419.7 S 35.8 W 443.1 S 42.7 W 466.9 S 48.8 W DOG-LEG SEVERITY deg/lO0' 1.30 1.39 .45 .95 .65 .3O Final Station Closure: 469.4 feet South 5 deg 58 min 17 sec West AMOCO PRODUCTION CO. )~IDDLE GROUND SHOAL PLATFORM BAKER, WELL~ 20 .( MEAS INCL BORE HOLE DEPTH BEARING ft deg r,~in deg rnin 3000.0 3100.0 328.0.0 3300.0 3400.0 3500.0 3800.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 43~.0.0 4400.0 4500.0 4600.0 4700.0 4800.0 4900.0 5000.0 5100.0 5200.0 5300.0 · 5400.0 14 14 14 14 15 0 I7 34 18 59 19 28 19 26 19 8 18 41 18 30 17 46 17 23 17 32~ 17 56 18 8 18 9 18 10 18 59 20 9 20 83 80 4 19 37 19 81 19 8 18 28 S15 9W S 15 18 W S12 5W S 5 6W S 838W S 212W S 2 8W S 2 5W S 1 39W S 130W S 1 4 W S 1 40W ~ I88W S 1 0 W ~S 1 85W 111W S 2 1W S 339W S 348W S 350W S 4 37W S 582W S 6 6W S 654W S 711W VERT DEPTH ft 8950.8 3047.7 3144.5 3240.5 3335.4 3429.8 3524.1 3618.5 3713.1 3807.9 3908.9 3998.3 4093.7 4188.9 4884.0 4379.0 4474.1 4568.8 4663.1 4756.9 4858.7 4944.8 5039.0 5133.5 5828.2 VERT SECTION ft 444.3 468.3 493.0 520.8 558.8 585.1 618.4 651.4 683.8 715.7 746.8 777.0 807.0 837.4 868.4 899.5 930.7 968.5 996.0 1030.6 1065.2 1099.1 1132.4 1165.1 1197.2 CONFIDENTIAL HO R I Z ONTAL CLOS U RE C 0 0 R D DISTANCE BEARING feet ft deg r,li ri 443.1 S 42.7 W 466.8 S 49.2 W 491.3 S 55.1 W 519.0 S 59.3 W 550.3 S 61.4 W 583.8 S 68.8 W 616.5 S 64.1 W 649.5 S 65.3 W 681.9 S 66.3 W 713.8 S 67.2 W 744.9 S 67.9 W 775.1 S 68.6. W 805.0 S 69.4 W 835·5 S 70.1 W 866.4 S 70.7 W 897.6 S 71.4 W 988.7 S 72.3 W 960.5 S 73.9 W 993.9 S 76.1 W 1088.5 S 78.4 W '1063.0 S 80.9 W 1096.8 S 83.9 W 1130.0 S 87.8 W 1162.7 S 90.9 W 1194.6 S 94.8 W 445.2 S 5 30 W 469.4 S 6 1 W 494.4 S 6 24 W 522.4 S 6 31 W 553.7 .S 6 28 W 586.6 S 6 9 W 619.8 S 5 56 W 658.8 S 5 44 W 685.1 S 5 33 W 716.9 S 5 83 W 748.0 S 5 13 W 778.1 S 5 4 W 808.0 S 4 56 W 838.~4 S 4 48 W' 869.3 S 4 40 W 900.4 S 4 33 W 931.5 S 4 27 W 963.4 S 4 24 W 996.9 S 4 23 W 1031.5 S 4 81 W 1066.1 S 4 81W 1100.0 S 4 22 W 1133.3 S 4 25 W 1166.2 S 4 28 W 1198.5 S 4 32 W Page 1 DOG-LEG SEVERITY deg/100' 0.00 .04 1.12 3.21 1.68 .50 .04 · 30 .48 · 80 .74 .43 .17 .48 .'24 · 08 .86 .95 1.18 .84 ,48 .51 .37 .40 · 57 AMOCO PRODUCTION CO. ~IDDLE GROUND SHOAL PLATFORM BAKER, WELL# 20 CO FIDEN'I'I L Page MEAS INCL BORE HOLE DEPTH BEARING ft deg r~in deg VERT VERT DE;'TH SECTION ft ft HO R I Z 0 NTAL CLOSURE C 0 0 R D DISTANCE BEARING feet ft deg 5500.0 17 44 5600.8 17 45 5700.0 17 15 5880.0 I7 22 5900.0 17 32 ~,S T 13 W 5323.2 1228.1 1825.4 S 98.7 W S 7 2 W 5418.5 1258.5 1255.7 S 102.5 W S ? 9 W 5513.9 1288.5 1285.5 S 106.2 W S 7 49 W 5609.3 1318.1 1315.0 S 110.1 W S 8 42 W 5704.7 1347.9 1344.7 S 114.4 W 6080.0 17 33 6180.0 16 46 6200.8 16 29 6300.0 16 5 6400.0 15 59 S 7 31 W 5800.1 1377.9 1374.5 S 118.7 W S 6 35 W 5895.6 1407.3 1403.8 S 128.3 W S 5 5 W 5991.4 1435.8 1432.3 S 185.2 W S 3 50 W 6087.4 1463.8 1460.2 S 187.4 W S 2 38 W 6183.5 1491.4 1487.8 S 188.9 W 6500. o 15 5o 6600.0 16 15 6700.0 16 9 6800.0 15 46 6900.0 15 24 B 084W S 025E S 0 8E S 0 SE 'S 118E 6879.7 1518.8 , 1515.8 S 189.7 W . 6375.8 1546.4 1548.8 S 129.7, W 6471.8 1574.3 1570.7 S ' 129.5 W 6568.0 1601.8 1598.8 S 129.5 W 6664.3 1628.6 1625.1 S 189.8 W 7000.0 15 32 7100.0 16 14 7200.0 16 44 7300.0 17 11 7400.8 17 32 S 218E S 249E S 425E B 549E S 6 1 E 6760.7 1655.2 1651.7 S 128.3 W 6856.9 1682.5 1679.1 S !87.1 W 6952.8 1710.7 1707.4 S 125.3 W 7048.4 1739.7 1736.4 S 188.7 W 7143.9 I769.8 1766.1 S 119.7 W 7500.0 18 5 S 6 26 E 7600.0 17 14 S 5 9 E 7660.0 16 58 S 5 1 E 7239.1 i799.5 '1796,5 S 116.3 W 7334,4 1829.6 1826,7 S 113.3 W 7391.7 1847.1 1844.3 S 111.7 W Final Station Closure: 1847.? feet South 3 deg 27 min 58 sec West' 1229.4 S 4 36 W 1259.9 S 4 40 W 1289.9 S 4 43 W 1319.6 S 4 47 W 1349.6 S 4 52 W 1379.? S 4 56 W 1409.1 S 4 59 W 1437.7 S 5 0 W 1465.8 S 4 59 W 1493.4 S 4 57 W 1520.7 S 4 53 W 1548.3 S 4 48 W 1576.1 ',S 4 43 W ,1603.5 S 4 38 W 1630.2 ,S 4 33 W 1656.7 S 4 27 W 1683.9 S 4 20 W 1712.0 S 4 12 W 1740.8 S 4 3 W 1770.2 S 3 53 W 1800.3 S 3 42 W 1830.2 S 3 33 W 1847,7 S B 28 W DOG-LEG SEVERITY deg/100' · 73 .06 .51 .23 .31 · 36 .83 .51 .53 .35 · 63 .48 .13 .39 · 50 · 30 .73 · 67 .61 · 56 .56 .45 MIDDLE GROUND SHOAL PLATFOR~ BAKER, WELL #20 CO ,IFIDE ]TI tL Page MEAS INCL DEPTH it de9 min BORE HOLE VERT VERT BEARING DEPTH SECTION deg min £t ft CLOSURE DISTANCE BEARING £t de9 min 7660.0 16 58 7700.0 16 27 7800.0 18 1 7900.0 18 37 8000.0 18 35 S 5 1 E 7391.7 1847.1 1847.7 S 3 28 W TIE-IN TO GYRODATA SURVEY JOB NUMBER CAO885G086 @7660' $ 7 56 E 7430.0 1858.5 1859.0 S 3 24 W S 16 30 E 7525.5 1887.2 1887.5 S 3 10 W S 18 46 E 7620.S 1916.8 1916.9 S 2 50 W S 18 53 E 7715.2 1946.6 1946.6 5 2 29 W 8100.0 16 35 8200.0 16 6 8300.0 16 13 8400.0 17 25 8500.0 17 58 S 13 25 E 7810.6 S 7 58 E 7906.5 S 2 31E 8002.6 S 7 17 E 8098.3 S 4 17 E 8193.6 1975.2 2002.7 2030.3 2059.0 2089.1 1975.3 S 2 12 W, 2002.7 S 2 1W 2030.3 S 1 55 W 2059.0 S 1 50 W 2089.1 S i 43 W 8600.0 18 11 8700.0 18 37 8BO0.O lB 36 8900.0 17 47 9000.0 18 31 9100.0 18 48 9200.0 20 0 9300.0 20 31 9400.0 21 22 9500.0 21 21 S 0 49 E 8288.6 2120.0 S 2 4 W 8383.5 2151.6 S 3 53 W 8478.3 2183.5 $ 656 W 8573.3 2214.6 S 11 5~ W .~8668.3 2245.5 · , S 20 12 W 8763.0 2276.5 S 23 54 W 8857.3 2307.7 S 26 26 W 8951.2 2339.6 S 28 29 W 9044.5 2371.8 S 28 31 W ' 9137.7 2404.5 2120.1 S 1 39 W 2151.6 S 1 38 W 2183.5 S 1 40 W 2214.7 S 1 43 W 2245.5 S 1 49 W 2276.5 S 2 1W 2307.7 S 2 18 W 2339.7. S 2 38 W 2372.2 S 2 59 W 2405.1 S 3 22 W 9528.0 21 27 S 27 59 W 9163.8 2413.6 2414.4 S 3 28 W Final station Closure: 2414.4 feet South 3 deg 28 2 sec West · HORIZONTAL COORD feet 1844.3 S 111.7 W 1855.7 S 110.4 1884.7 S 104.1 1914.6 S 94.6 1944.8 S 84.3 1973.8 S 2001.4 S 2029.1S 2057.9 S 2088.2 S 75.9 70.7 68.2 65.7 62.6 2119.2 2150.7 2182.6 2213.7 2244.4 61.2 61.6 63.2 66.2 71.3 2275.1 2305.9 2337.2 2368.9 2401.0 80.1W 92.6 W 107.3 W 123.8 W 141.2 W 2410.0 S ,146.0 W DOG-LEG SEVERITY de9/lO0' 0.00 2.46 2.98 .93 .05 2.60 1.61 1.52 1.83 1.07 1.09 1.0I .58 1.26 1.71 2.67 1.72 1.02 1,12 .02 .78 F I LENAME' WELLIOA TRADITIONAL UNITS RADIUS OF CURVATURE P. ETHOD 198~-06-10 13' i7 VERTICAL SECTION OR CLOSURE DiP~CTION..: iS MEAS. DEPTH 7 .... O0 0 O0 S 2. 42W 853. O0 1. 50 S 2. 42W 953. O0 3. O0 S 2. 42W 1053. O0 4. 50 S 2. 42W 1153. O0 6.00 S 2. 42W 1253. O0 7. 50 S 2. 42W 1353. O0 9. O0 S 2.42W 1453. O0 10. 50 S 2. 421,4 1553. O0 12. O0 S 1653. O0 13. 50 S 2. 42W 1753. O0 1=~.. O0 S 2.-42W 1853. O0 16. 50 S 2 42W ~-- "]1 i 1886. O0 17. O0 1986. O0 17. O0 S 2. 42W 2100. O0 I7.00 S 2. 42W 2200. O0 17. O0 S 2. 42W ~o,~r, O0 17. O0 S 2. 4~W 2400. O0 17. O0 S 2. 42W 2500. O0 17. O0 S 2. 42W 2600. O0 17. O0 S 2. 42W ~ ¢, . 7.;0. O0 17 O0 S :=.. 42W 2800. O0 17. O0 S 2. ~--'~,,,, 2900. O0 17. O0 S 2. 42W 3000. O0 17. O0 S 2. 42W 3100. O0 17. O0 S 2. -..?,...-,¢.,*'~' 3200. O0 1?, .. O0 S 2. ~.,-,,~'~" 3300. O0 17. O0 S ~. 42W 3400. O0 17. O0 S 2. 42W 3500. O0 !7. O0 S 2. 42W 3600. O0 17. O0 S 2. 42W 3700. O0 17. O0 S 2. 42W 3800. O0 17. O0 S 2. 42W 3900. O0 17. O0 S 2. 42W 4000. O0 t7. O0 S 2. 42';,4 4100. O0 17. O0 S 2. 42W 4200. O0 17. O0 S 2. l~,-~... ,,..., 4300. O0 17. O0 S 2. 421,4 4400. O0 17. O0 S 2. 42W . 4~W 4500. O0 17 O0 S 4600. O0 17. O0 S 2. 42W 4700. O0 17. O0 S 2. 42W 4800. O0 17, O0 S 2. 42W 4900. O0 17. O0 S 2. 42W 5000. O0 17. O0 S 2. 42W 5100. O0 17. O0 S 5200. O0 17. O0 S 2. 42W 5300. O0 17. O0 S 2. 42W 5400. O0 17. O0 S 2. 42W 5500. O0 17. O0 S 2. 421,4 5600. O0 17. O0 S 2. 42W 5700. O0 17. O0 S 2. 42W 5800. O0 17. O0 S 2: 42W 5900. O0 17. O0 S 2. 42W 6000. O0 17. O0 S 2. 42W 6100. O0 i7. O0 S 2.42W 6200. O0 17. O0 S 2. 42W 6300. O0 17. O0 S 2. 42W 6400. O0 17. O0 S 2. 42W 6500. O0 17. O0 S 2. 42W 6600. O0 !7. O0 S 2. SURVEY DEP TH INCL. DIP. (TVD) 182. 42 DEGREES NORTH ~ EAST VERT. CLOSURE -SOUTH -WEST ..... ,ON DIS ~. DIP ~.o -1993.00 753.00 -1993.00 852.99 -1994.31 952.91 -1998.23 1052.69 -2004.76 1152.27 -20!3.91 125!.57 -2025.65 1350.53 -2039.98 1449. 09 -2056. 90 ! .5-~7. ~.,_.~. -2076. 40 1644. 69 -2098. 44 1741. 6i -2123. 04 !~37. 86 -2150. I 1869. 46 -2159. 66 i~'~.~ O~ -2i'~¢- ,~,. , ~. 87 2074. il -2~. 17 ,_ , '2~1.33 2265 37 -2280. 59 236i O0 -2309. 80 2456 63 -2339. O1 =55= 28 -2368.22 ~647 89 -~397. 44 ~P:~ 1 ~ -2455. 8A 2934 78 -24S5. 07 3030.4t -25~ '~ 3&~6. 04 -2543. 49 3221. 67 -2D72. 70 ~o~ 30 -260~ 91 3508. 56 ~' ='* 3604. ~9 -2689. 54 36~9. 82 -27t8. 76 3795. 4~ -2747. 97 38~ &. 08 ~. -~, /, ~8 3986. 7~ -2806. 39 4082. 34 -2835.'60 4~77. 97 -~4. 8 4273. 60 -2894. 4464 86 ~='~ 4560. 49 -298~. 65 4656. i2 -3010. 86 4751. 75 -3040. 08 4847. 37 -3069. 29 4963. O0 -3098. 5038. 63 -~I~ ~,,. 7~ 5134. 26 -3~56. 92 5229. 89 -3i~o.'~' i~- 5~o~ =2 -~2'5.34 5421. 15 55Z6. 78 --3273. 56i~. ~! --3302. 97 5708. 04 --3332. 19 5803. 66 -3361. 40 5899. 29 -3390. 61 5994. 92 --3419. 6090. ~ --3~49. 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OE 3116 SlOE 3173 SlOE 3202 S 10E 3230 S!OE 3259 S 9E 3288 S 9E ~316 S ~E 3~45 S 9E 3374 S 9E 3402 S 9E 3431 S 9E 34~C' ~ YE 3488 S ~E 3517 S 9E 354~ S 8E 357= ~ DOG LE9 0.0 i 5 i 5 1 5 i 5 1 5 1 5 1 5 1.5 i.5 1.5 !.5 i.5 0.0 0.0 C;.0 O. 0 0.0 0.0 0.0 0.0 0.0 ,--. ',J.O 0.0 0.0 0.0 O. 0 0.0 0.0 '0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0. 0 0.0 O. 0 6700.00 17.00 S &800. O0 17.00 S 69Q0. O0 17.00 S 7000 O0 17 O0 ~ 7100.00 17,. 00~ ~ 7200.00 I7.00 S 7300.00 t7,00 ~ 7400.00 17.00 S 7500.00 17.00 S 7600.00 17.00 S 7700.00 17.00 S 7800.00 17.00 S 7900.00 17.00 S 8000.00 17 O0 S 8118.00 I7.00 S 8218.00 18.49 S . 83!8.00 !9.99 S 84!8.00 :.,.~ O0 S 8518. O0 ~v.~ O0 S 8600.00 20.00 ~ 8700 O0 ~0 O0 ~ 8800.00 20.00 S 8900.00 20.00 S 9000.00 2,3.00 S 9100.00 20.00 S 9200.00 20.00 S 9300.00 ~0.00 S 9400.00 20.00 S 9500.00 20.00 S 9584.00 '~n~. O0 ~= 2. 42W 2. 4~W-- ~ 4~W . 2. 42W 2. 42W 2. 42W 2 4"'" W 2. ¢ "-'-~.t ,z--,. - · -'.42W 2. 42W 2 42W ,2~. ;5 .,-~1,t 2. ~.2W '-' 42W _--. 2. OOW · .'"", "'"" 4 i ..., u~ O. OOW 8206 O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW O. OOW 6473.07 -3565.87 6568.70 --3595. O~ 666~ 67~9 95 --3653. 5~ 6855 58 -3682.72 6951 21 -3711.93 7046 84 -374!.14 7142 47 o~n 35 7~3~ 10 -3799. 5~ 7333.73 -3828.77 7429~3~ -3857.98 752~. 98 -3887. !9 7620.61 -39i6.40 7716.24 -3945.61 7829.09 -3980.0~ 7924.32 -4010.53 80i8 ~3 81!~.72 -4077.~4 69 -4i!!.84 8283 74 -4139.89 8377 71 -4174.09 847]. 68 -4208.29 8565 65 ~'~'~ 86~? 62 87~3 59 -43!0.8~ 88~7 55 -4345. ~0 ~035 4~ -4413.50 9 ~ 4~ -4~7.70 9208 39 -4476.43 517.51 .~16.28 ~I~ o~ ~12.5~ ~i~ 34 ~0.11 ~n~ 87 507. 64 ,?uo. 40 505.17 503.93 ~'~° 70 501.46 ~00.01 498.72- 49.7.45 496.~0 4~5.96 495.96 ~ 95 4~ 95 495.95 495.95 4~5.95 495 9~ 3540. S4 3570.07 3~57.78 3~87.02 3716.26 3745.49 377~.73 3803.~7 38~i.&8 ~ ~". ~9~0.92 395D 3985 89 4018 84 4053 04 4087 22 4115 25 4149 4!83 59 4217 76 4~51 93 4286 4320 27 4388 61 4422 79 4451 49 3603 S ~E O. 0 ~,~- S 8E O. 0 3&,~9 S SE O. 0 3718 S 8E O. 0 3747 S 8E O. 0 3776 S 8= O. n 3805 S SE O. 0 3833 S BE O. 0 3862 S 8E O. 0 3891 S 7E O. 0 3920 . S 7E O. 0 3949 S 7E O. 0 3977 S 7E O. 0 4011 S 7E O. 0 4041 S 7E I. s 4074 S 7E l. 5 4108 R 7E n ~ 4] 42 S 7E O. 5 ' 4169 S 7E O, 0 420~ S 7E o. 0 4237 S .7E O. 0 4'~I S 7E O: 0 4305 S 7E O. 0 4339 S 7E 0. 0 4373 S 7E O. 0 4407 ¢= 6E O. 0 4441 S ' ~ O. n 4475 S 6E O. 0 4504 S 6E O. 0 (W)ELL (M)ETHOD (V)ERT!CAL SECTION (C)REATE A FILE (T)RUE VERTICAL DEPTH (P)LOT (A)LTERNATE FORMAT (O)UTPUT UNITS (E)XTRAPOLATE TO TARQET (S)TOP (DEFAULT) PLEASE ENTER SUBSEA CORRECTIOi~ DEPTH {FT) 79 DO YOU WISH TO RUN ~A,.D TOP r):p~u¢ ONLY PLEASF F'NTER rNiTIAL TRUE VERTICAL DEPTH AND DEPTH INCREMENT (FT). 7829,1380 .-..RECEivED '? F-ILENAME: WELL20A TRADITIONAL ..... ~m~ '-.~ i'4 ~. · ---~ 19~-06-10 TRUE VERTTCAL DE~TH ....... 13' %7 TRADITIONA- dNITS 1985-06-12 18'15 R~DIUS OF CURVATURE METHOD TRUE VERTICAL DEPTH NO. I(WELL20A NORTH EAST -SOUTH -WEST -0.00 -1993.00 584.00 5000.00 -3115.91 536.53 5100.00 -3146.45 535.24 5200.00 -3177.00 533.95 5300.00 -3207.55 532.66 54-00.00 -3238.09 531.37 5500.00 -3268.64 530.08 5600.00 -3299.18 528.79 5700.00 -3329.73 527.50 ~800.00 -3360.28 526 ql 5900.00 -3390.82 524.91 6000.00 -3421.37 523.62 6100.00 -3451.92 522.33 6200.00 -3482.46 521.04 6300.00 -3~13.01 519.75 6400.00 -3543.55 518.46 6500.00 -3574.10 517.17 6600.00 -3604.65 515.88 6700.00 -3635.19 514.58 6800.00 -3665.74 513.29 6900.00 -3696.28 512.00 7000.00 -3726.83 510.71 7100.00 -3757.38 509.42 7200.00 -3787.92 508.13 7300.00 -3818.47 506.84 7400.00 -3849.02 505.55 7500.00 -3879.56 504.26 7600.00 -3910.11 502.96 7700.00 -3940.65 501.67 7800.00 -3971.20 500.38 7900.00 -4002.76 499.05 8000.00 -4036.93 497.70 8100.00 -4073.02 496.54 8200.00 --4109.41 495.99 8300.00 -4145.80 495.96 8400.00 -4182.20 495.96 8500.00 -4218.60 495.96 8600.00 -4254.99 495.96 8700.00 -4291.39 495.95 8800.00 -4327.79 495.95 8900.00 -4364.18 495.95 9000.00' -4400.58 495.95 9100.00 -4436.98 495.95 9200.00 -4473.37 495.95 TO(MQS7 ) FROM NO. 1 FT DIR. 106 O0 535 64 576 36 615 21 654 79 694 97 735.67 768.64 783.07 797.71 812.55 827.5~ 837.71 829.32 821.06 812.93 804.92 794.70 782.44 770.33 758.05 745.50 733.12 719.64 706.18 692.95 678.8~ 664.26 649.73 634.52 617.34 597.71 577.33 558.12 539.45 TO ( MOS 12-SS ) FROM NO. 1 FT DIR. ---- TO(MOSll-SS) FROM NO. 1 FT DIR. Ngow 5.39 S68E 67.01 N38W S12W 1847.70 S33E 288.33 N75E S 9W 1855.62 533E 302.36 N76E S 7W 1863.54 S33E 315.62 N75E S 6W 1871.46 S33E 327.71 N73E S 4W 1879.40 S33E 338.76 N71E S 2W 1887.33 S33E 349.92 N69E S 1W 189~.27 S33E 361.04 N66E S OW 1903.21 S33E 372.27 N64E · S 1E 1906.89 S33E 383.66 N62E S 2E I903. 12 S33E '395.43 N59E 'S 2E 1899.36 S32E 407.05 N57E S 3E 1895.60 S32E 419. 16 N55E S 4E 1891.84 S32E 4'30.00 N54E S 5E 1888.09 S32E 440.94 NO2E S 5E 1884.33 S32E 451.53 NSOE S 6E 1880.58 S32E 462. 13 N49E S 7E 1876.82 S32E 472.87 N47E S 8E 1873.07 S32E 483.36 N45E S 9E 1862. 14 S32E 493.80 N43E S 9E 1848.2~ S32E 505. 19 N41E SlOE 1834.31 S32E 518.55 N39E SllE 1820.42 S31E 533.20 N37E S12E 1806.55 S31E 549.4~ N35E S13E 1792.71 S31E 567.22 N33E S14E 1778.88 S31E 586.99 N31E S15E 1765.07 531E 608.~D N~gE S16E 1751.29 S30E 630.29 N28E S18E 1737.53 S30E 653.34 N26E S20E 1710.75 S30E 677.87 N25E S22E 1679.34 S30E 704.36 N24E S24E 1645.73 S29E 733.78 N22E S26E 1610.40 529E 76D. 48 N~IE SRgE 1574.57 S29E 797.54 N21E Alaska Oil & Gas Cons. Oommission Anchorage 521.86 S35E 1502.55 S28E 862.96 N19E 507.26 S39E 1466.64 S27E 895.78 N19E 496. 14 S43E 1430.80 S27E 928.56 N18E 488.47 S47EP 1389.72 S27E 961.34 N18E 483.90 S51EP 1346.00 S26E 994.08 N18E 482.28 S56EP 1302.38 S26EP 1026.90 N18E 483.64 S60EP 1259.43 S25EP 1059.89 N18E 487.97 S65EP 1216.54 S25EP 1093.01 N18E 495.17 S69EP 1173.72 S20EP 1126.10 N18E TRADITIONA~"~NITS 1985-06-12 '-")'15 TRUE VERTICAL DEPTH 0.00 100.00 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 RADIUS OF CURVATURE METHOD NO. I(WELL20A ) NORTH -SOUTH -1993.00 -1"993.00 -1993.00 -1993.00 -1993.00 -1993.00 -1993.00 -1993.00 -1993.61 -1996.15 -2001.31 -2009.11 -2019.55 -2032.66 -2048.48 -2067.02 -2088.34 -2112.48 -2139.49 -2168.99 -2199.53 -~30.08 -2260.62 -2291.17 -2321.72 -2352.26 -2382.81 -2413.35 -2443.90 -2474.44 -2504.99 -2535.54 -2.566.08 -2596.63 -2627.17 -2657.72 -2688.26 -2718.81 -2749.36 -2779.90 -2810.45 -2840.99 -2871.54 -2902.08 -2932.63 -2963.18 -2993.72 -3024.27 -3054.82 -3085.36 -3115.91 . .- EAST -WEST 584.00 584.00 584.00 584.00 584.00 584.00 584.00 584.00 583.97 583.87 583.65 583 32 582 88 582 32 581 65 580 87 579 97 578, 95 577.81 576.56 575.27 573.98 572.69 571 40 570 10 568 81 567.52 566.23 564.94 563.65 562.36 561.07 559.78 558.48 557.1.9 555.90 554.61 553.32 552.03 550.74 549.45 548.16 546.86 545.57 544.28 542.99 541.70 540.41 539.1~ 537.83 536.53 · TO ( MGS7 FROM NO. 1 FT DIR. TO ( MGS 12-SS ) FROM NO. 1 FT DIR. 106.00 N90W 106.01Ngow 105.79 sgow 103.54 S89W 101. 19 S87W 97.37 S86W 92.95 S83W 88.77 S81W 83.49 S79W 74.33 S79W 62.93 S84W 53.23 N84W 48.57 N63W 51.70 N40W 63.48 N~3W 81.00 N14W 100.64 N 6W 119.11N OW 137.69 N 3E 155.91N 3E 170.39 N 2E 181.93 N OW 190.38 N 2W 195.78 N OW 199.62 N 7W 201.01 NllW 197. 12 N15W 192.65 N20W 182.81N26W 174.21N32W 165.'54 N40W 158.94 N46W 154.06 NO3W 146.44 N61W 141.09 N71W 139.97 N81W 144.50 S86W 157.62 S73W 176.38 S61W 200.72 ~5=W 228.71 S45W 257.65 S40W 288.25 S36W 317.92 S32W 345.87 S30W 374.02 S27W 399.50 S24W 428.44 S21W 461.14 S18W 495.44 S15W 535.6~ S12W 39 S68E 35 S68E 16 S67E 83 S71E 12 S79E 21 S83E 7.80 S84E 10.35 S82E 16.42 S65E 27.18 S49E '41.30 S40E 58.73 S34E 77.01S31E 98.30 S29E 124.88 527E 158.57 S26E 19B. 16 S27E 239.87 S29E 287.84 S30E 340.84 S31E 397.91 S32E 464.38 S32E 531.61 S32E 593.69 S32E 651.27 S32E 705.50 S33E 759.00 S33E 815.69 S33E 874.85 S33E 934. 11 S33E 991.03 S33E 1048.17 S33E 1107.99 S33E 1169.43 S34E 1230.77 S34E 1286.64 S34E 1342.52 S34E 1398.39 S34E 1454.26 S34E 1510. 14 S34E 1562.85 S34E 1596.27 S34E 1629.70 S34E 1663. 13 S34E 1696.56 534E 1729.99 S34E 1763.43 S33E 1796.86 S33E 1830.29 $33E 1839.79 S33E 18~7.70 S33E TO ( MGS 11-SS ) FROM NO. 1 FT DIR. 67.01N38W 66.75 N38W 66.49 N38W 66.23 N38W 65.97 N38W 65.71N38W 65.42 N38W 64.98 N37W 64.76 N37W 66.45 N36W .70.84 N33W ' 77.90 N30W 87.97 N26W 100.53 N22W 1'15.87 N18W 133.70 N14W 153.98 NllW 177.48 N 9W 204.21N 7W 233.28 N 5W 263.53 N 4W 292.69 N 3W 316.72 N 3W 335.45 N 3W 350.77 N 4W 363.03 N 4W 372.07 N 4W 380.64 N 4W 383.15 N 2W 377.73 N OW 365.41N 2E 352.86 N 4E 341.36 N 7E 328.84 N 9E 314.97 N12E 3O0.64 N15E 285.02 N19E 270. 12 N24E 256.86 N28E 246.79 N33E 239.44 N38E 233.91N43E ==9.99 N47E 227.84 N53E 227.76 NDSE 231.30 N62E 237.74 N67E 248.97 N70E 262.11N73E 274.72 N74E 288.33 N75E Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPE~TOR, WELL N~ ~D NU~ER Reports and Materials to be received by. !~--A..~ II'- ~_.~ Date Required Date Received Remarks . s-~amPiles ~,- < Core Chips C6r~ 'Description Registered Survey Plat Directional Survey Drill Stem Test Reports Production Tes L.FJ.04 W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99.510 907-272-8471 November 15, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-OO6-WF Gentlemen: Monthly Report of Operations Middle Ground Shoal 17595 Well No 20 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for Middle Ground Shoal 17595 Well No. 20, reporting October 1985 activities. Very truly yours, W. G. Smith District Manager Attachment JCB/dds E~ I/ED Con° '~rlOhorag.~~' C°mr..q!ssior~ · ~. ~-- STATE OF ALASKA -~-~ ALASKA O,,_ AND GAS CONSERVATION CO~,.MISSION 'MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of ol~erator 7. Permit No. ~moco Production Company 85-135 3. Address p. 0 BOX 100779, Anchorage, Alaska 99510 8'AP~Nu'~§r3-20377 · 50- 9. Unit or Lease Name MGS 17595 4. Location of Well at surface Leg 2, Slot 3, 1,993' FNL, 584' R12W, S.M. Platform Baker FWL, Sec. 31, T9N, 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease Designation and Serial No. 79.4' KB 'I AD[ 17595 10. Well No. 20 11. Field and Pool Middle Ground Shoal Hem10c k For the Month of ~¢_Dtm_mh~r ,19 R~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 9,642 feet Footage drilled - 0 feet 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data Perforated 7,738-8,050 and 8,100 - 8,264 w/4 JSPF, 0.25 inch holes. Pump testing well (See Attachment). 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate MGS 17595 Well No. 20 10-01-85 to 10-10-85 10-11-85 to 10-12-85 10-13-85 10-14-85 to 10-15-85 10-16-85 to 10-23-85 10-24-85 to 10-27 -85 Pump testing perforation intervals 8,560 - 8,740 and 8,784 - 8,970 feet. Pull hydraulic pump equipment. Set Bridge Plug at 8,410 feet. Perforate 7,738 - 8,050 and 8,100 - 8,264 with 4 JSPF. Run Hydraulic pumpi'ng equipment. Place well on test. Pumping and testing well. Pull hydraulic pump equipment. Retrieve bridge plug at 8,410 feet. Run hydraulic pumping equipment. 10-28-85 to 10-31-85 Pumping and testing well. MEMORANL)UM TO: T~RU: FROM: State of Alaska Cha ir~a--' · / ..-: Lonnie C. Smith q''~'' (~ COmmiss loner TELEPHONE NO: Edgar W. $±pple, .Jr ~ Petroleum Inspector DATE: November 15, 1985 FILE NO: D. EWS. 56 SUBJECT: BOP Test /~¢~ Amoco's Well 20 Permit No. 85-135 NMGSU Tuesday, July 30., 1985: i traveled this date from Anchorage via ~iaska Aeronah~'i~al-~0 Kenai. I drove to Amoco's Heliport and went to Baker Rig 152, to witness a BOPE test. The drilling contractor was in the process of nippling up. Wednesday, July 31, 1985: The BOPE test commenced at 4:30 am and was h0n~ci'~ded a~'8::Io am'. T~ere were three failures. All failure's were replaced or repaired and tested to 3000 pounds satisfactorily. See list of failures in Remark Section on BOPE inspection report. I filled out the AOGCC BOPE inspection report which is attached to this report. In sux~mary, i witnessed the BOPE test on Amoco's, Baker Rig 152. Attachment 02-00IA(Rev. 10/79) . "-Operator. ~ 0 ~ - '- ': ' · ' RePresentative ~/Lr~ ~. /40 ~~ .... - Location: Sec' ~/ Tq~~/~M ' " /3~Cas-ing Set 8 31~ . ft. ~Z~ Drillin~ Contractor ' ~'~% Ri~ #/~Z Representative ~ ~/_ ~~ Location~ General ~ Well Sigq O~ H AOO~ATOR SYST~ Oene=~ ~ouse~e~p~ ~ ~g ~~ ~~" C~=ge ~ressure ~Z~ ps~ ~~ Reserve Pit- ~ '- HPressure After Closure/~ psig ~/~ ~,u~ ~wt~ms~ - V~ua~ Audio. ~um~ ~n~r. ~o~. ~re~. ~00 p~ ..~ ~n.g~ ~e=. ~~ ~ H-Full Charge Pressure Attained: 3 min~V sec. . - ": temote ~/~i Blinds switch cover f~g ' 7 Kelly and Floor Safety Valves BOPE S taCk ~~.r Preventer~ P~'pe Rams ~p~ Blind~Rams . / C~o~e Line Valves Test Results: Failures Test 'Pressure ~o o ~0oo 3 ooo Upper Kelly O~ ~'Test Pressure -Lower Kelly ~/~ ~est Pressure Ball Type ~l~est Pressure m~e ~0~ ~M~t ~r~r~ Choke Manifold '0~ Test Pressbre ~o. v~:w~ ~ No. flanges2~ Adjustable Chokes /-A ~.~-- Hvdrauically'operated choke . 7000 3~o o 2 · Repair or Replacement of failed equipment to be made within ~/~ days and Inspector/ / Commission ~ffice notified. ' - . ' Distribution orig. - AO&GCC cc - Operator cc - Supervisor h'.-c:,:=: t --"'--'-c:",5, _..,-, ';."', 741 'r~ (::P--OU;:'4D .qFi."3AL ,~N['iCC_.,' ~-~F~.~,_F3.,:..~..:;:F~.4~.~ 4x.-.~ ;.< ~ .:-~-2~ :-~-,~-:-c-:~-~ ~--~--m-~.~:-:~4.:..:<-~:.~,-,a- -'-..: -~ -,._ ~ ~.-.:.' - k'.-~-:--'.-S SF-~-':;~,-'~· .. -. :~ .. :~ ~ ~ ~ ,.' ~. ~ ................ :--- ~-?'-- x- -~-~c--~.- t. ~:--,¥ P-~-.- '~: -:-'~-¢i-.;?~~ '.~; 5. ~:~ ~' '.~. q'. ¢c ';' 4~ :.~ q:~ 'h'-h--;.: '~ -.'-.. -~i '~ ::' ':.' -~;'~ ~:' :~ a~ ~",--'4~ : ........ , · ..... '? ,...: -.._: ....... A."":,':-.b~O W. ! S-:'~,. E! F' F_-:_ i'::. ,'::cc }~ =~:~,:':'-" -rD 9.64~ ~-"-q" ,.:-.~i ~-~-...',~, iNO k_-'-t'-,.C?, ..... !" ~., !' ,.t; i~ (':J]Fi]- '-:' k]~'~ ~--iij?, ....... ,'::s-~.-:: ..... ,,,= ......... ::.,. C ......- <~"~:- :' ~"~ CUff b.-iEL L. -4~ ,~,- .......... F-.'.l-qh'.i/:d:~k~S 4 ~ 'n, ~.; - _ ......... '- . .... "' .... 7?2 _ ' ,du'-,:s -FL=:.ST N,a;T%ONAL ,.'.FT L. ~::: v ~:- t. [-1! (jii"i ;..-~' Or-._. 2496:., NCPD; ..... ,.~Lx-'-..~ i:.~-'7"7--'5 "-:, "' r; ,"!, I - .'-i.,a.--,.,,' ~,,,g.:DiS--!-o 'r~.-:,,~ ti-iON HRS ) · ~..,~.-.~:.'..-~ Ti ..... ,-...._ :_, ,.. , f. · ?_'4 0() - qT.~dF';:e, F'UMP }. i,-';'. - L=,'T h-,,--,F- :.i ';'-5c-, =- 20, i'~)' D ~,":? DUND e:.a'nAi ... .......... · _, ............... AMOCO PRODUCT:[ ..... ¢i--~-: >.-- ~. '~, ,., ~ ~. F ............. ~ ,-, ,., ;,,- UT-H- ',-r: c;;=:o,_ :_'., :-:..:s.-'-'_, '"· 9642 '='~ p~. ;?ip · "", ,':"T~'- ,,--~ .'.~-~-~ .,-.,~.~ l~ $2284'7~, C:UN W,':J.!. I 4~ S:! ~ /' c-'' ° '' '' '=' · ._-: .-' ~.: ; ._'D. -...-'-.'~ : ; p.--~ .... *._-r.,., '..-,,-; ........... - ............... ~.,--s: .... I,.,,_., . .. ; q , .. ,.. : i :73 '7 __. -"--"-' ~ :(:-~Pi3P- _ _ . '" . F,~ f'-IC, lzl-,': (4.'L,r~. i4.; .L) Z:O-q~! AT 3:;2.0(') PL-:il ..... ...................... & . ~_,, .-) _] ~- , . · - .._- TC.; ~' ....... .::.,~. ",ii(:) - (J.'"Tt-":::c'', ,,._::, PO~il-'! !',16.; .: ..... i ,~-7',... ,¢-'-c'-, ... [:~,,, x_ -:, --,.~ -,.,.._, ~_, ,.:.. -, .... o1_. .... 0,. :-,/'P:[ fsO :7 ~.'_~S? 0 L-~ 7'7(? F~. ..... .,~ U '}"F4]- r"~9.7-.;(:"::'.-4 , ~-~ ,i -'F I--I. C E~ ~:~-i'-_ , ~", ':., ,-c:-"-z.. ,: ,_., ..~ . L-'iP_ET.,r-~"'rTFIi~S- -T'T) ~-647 FT - I-1. I ...- ............ 7 1 -'.- _ 1 · --r-,c., 'i S-.' C.'.. ,~hi hltjD --~"~'-,c,z].78 -" ':,~ (,u,,: WE. Lt. ::'~ENAF.:K.?-:' 4 : "- ....... '-" ........ :' :-:, :o- T[£ST: N,~,Ti:'~'t'':/'' 'r ....... :_ ,.',[Eft' PUMP i iF':T. &,~-':,<?l.~.U~..~,' .¢(} ['..;I.,:~r: ~'",o ........... . , ~_. " ~-,i:-' ,:-?, r-, Fi'-" 275 l F 'f' i',! . 34 :-S~ ,'-;,-!- 4,0 !)EO.:. ...,_.-; ,._, i;:-!!~_5 -,~t_;~ ; L i :.;,2!0~ A".,- ~.;,S. 5 ~:':.:.;,i. ~5 L_ !.J'ir'~_ ,.. ;, .... '~:~' '''''v:: i,- ~-~ .¢ ,..-i"r-iO0h"--=',. ~-:'t:; C;:?., :. ,_,: EJ .,"~ i-, -'--,-' %, C.;--iF-i--';._)hl 'i ]'F-,':-~fl ?'i~.:;Tr~'7;S,U-i'!'F~''-t ...... A, ~_,I ~ ~ ' ~ .......... 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Z ~'~ '~' AMOCL~ PRODUC~.'I ~ ~ %.~.4.?~?..,:?.I,.!.~7%%~.~.;.~ ..~__~;_.~._~_,,_.~.%.:-_~..~.,,~%%%%.~..~,=~...-,_.~.~.~.~_,: ~ ,, ^ ,, ,, . ~ . ~ ~ =..-..-. ~ .-. , ~._~_ ,,..~r. -~--,-:-.~,. ×. .~- -:-'!--~[-~--~-f'::~' /"'= ..... -' " --'. · ~_ ,~ f-.~ ~ T ; ._, ....... : :' .... , ..................... : ................ ,~ .............. 4~4 ~' ~.', i~ [:-.; ..... , ....... ,.. ?4. 0:~ - n'n--~F~' ~.:~o - TEE:TINg .... L, ,: ,_::r~., : ..... I NO ;~=-.:: i 7~:,c:'5 :70, p!~-~ ~:...~oi ,~-, i~ >~L, , OC:O ..... - ...... ., i;.%~i~.~-.i!.~(->~-~-IF~.%~.E::..iS~?i~-~-i~f~-.~t~.~f~-~?~ ~ iL-~ t--~ ii-~-~5-!~ ~--~-iF % ~"~' i: i::i. ,::~C c ..... 5>4 --(-~ 1 ,:}, AP T .... -":i:¥::'F)'T':;VO0, F-~.~ , n Tn o ' ...... A~'.iL';:(; (3 iJ T ? 5_ OO(30 t_H ' i:7 ?/~"i- :(-"-~ (:iNS:' Ti') .... :'/-,:~[:? :~'"'"~, PtJ~q'-', . t- i.. r~i~._ -,.i" - ...... H-. ~-i :--. -~-' C~._,.~:~4 ~ii ~:~ ..... ~ ~:5.:qd Zl-" ....../:5,~ t.. ~ !P'!~' ' "-':~h~. 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' 24. o-':'], .... __ ._,¢*-rL~P,,, .... ,, PUHP l N,q._ - -i-EST , :'-~Gc: 3.-"=~'5 20, f~in,_, GROUND -~'- -,,:' T,'"~ ". ' .:' '~' ',- r. ............. ~; ..... O, 3~:'->z~'3-7?,.. - ma'( iT~ Tr). -_ c2 5(~A , ¢~.)"['H ..... - .... ."}&'~:iT'~),O() ,.. A'''''hr''-' bi. v 25. OOOO C(Kf;-fS CU!'fi ~-~t~i3 ~4";"~:q.,~'/S, r ..... ' ' '"'-'~*~ TEST' NATi ........... 1 ...... ...... t; :~r-iJr-_ J .... -,, AT 2SC50 PS ~; .......... - .... ' ..... CHRON T' ]. f'iE._r)iSTR iB!jT iDN. ( u~ c,~ ,,, ,..~ ~.:. .~n< - .x. xx_.~: ~~x45 ~c-~-~ -~ '~ ×x Aid£gCD W. }.'. 7? ,'5. OOOO ~'*.:~. L-- f?/,.-,-' 'r ON:---.;-' Ti/; ~-'/-" ''~ - ......... : _. ~,_,--!-~_ f"-i", PUP!P I'NO ...... , ...... ., ~,. ,.~ ,"_ :.,., ,~. r:; ,,~' c:- - (5 :'710Li R . ; ',,..~ 'n'":"~ ~' ! '-)'-~'.--D -'" -i' p/',e"() PC2 i .; :.~;l')?i 54. ~7j f_}-..,r I~} ................ i [::t":'~:.k.. '7-9"%/-),, }.'' }i((,,.r.,.i. {3{3 1 :' :,.:, r-'.:;":_:.,.~.~,,-. ,~. .......... ' ,.-.7.' i ! 51:, ~" a £'- -- ,~i.-.iR, r,~,, -[ i.,'4F-: i-'~,iCY° ink)-'- Tc~-~:, , _,. ~_,,~. { M~;':S~'. %./. ~: .~_._li-~. I : ;?..?;,. ,', .',,-':.> -- ~_j -I HER , P W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 14, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TJZ-353-WF Gentlemen- Monthly Report of Operations Granite Point 18742 Well No 35, Platform Anna, and Middle Ground Shoal 17595 Well No. 20, Platform Baker, Cook Inlet, Alaska Attached in duplicate are the State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced wells, reporting September 1985 activities. Very truly yours, W. G. Smith District Manager Attachment KLS/dds oct ~mska Oi~ & Gas Cons. Cornm'~ssion Anchorage STATE OF ALASKA ----.. ALASKA t. __ AND GAS CONSERVATION CO,..MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of o~erator 7. Per~:~L~o35 ~moco Production Company 3. Address p O. BOX 100779, Anchorage, Alaska 99510 8'AP~Nu~-20377 · 50- 4. Location of Well atsurfaceL~g 2, Slot 3, Platform Baker 1,993' FNL, 584' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (J~ic. a4e~ K~(~BDF, etc.) I 6. Lease ~)s~na~¢~d Serial No. 10. Well No. 20 1 1. ,F,i~l~J ,a~nd Po,.ol r~ac~e ~round Shoal Hem1 oc k For the Month of September ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 9,642 feet Footage drilled - 987 feet 13. Casing or liner ru.n and quantities of cement, results of pressure tests 7-inch liner set from 7,544 - 9,630 feet and cement with 400 sx Class "G" pressure test liner and liner lap to 1,500 psi, 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHC/GR CNL-CDL-GR DIPLOG CBL Run 09/07/85 from 9,641 - 7,687 feet Run 09/07/85 from 9,641 - 7,687 feet Run 09/07/85 from 9,641 - 7,687 feet Run 09/14/85 from 9,500 - 900 feet 16. DST data, perforating data, shows of H2S, miscellaneous data DST ran on perforations 9,390 - 9,420 feet (See attachment) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. District Manager SIGNED. TITLE DATE 10/ /85 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. Fnrm 10-4i34 F;uhmit in duolicate MGS 17595 Well No. 20 09-01-85 09-02-85 09-03-85 to 09-04-85 09-04-85 to 09-05-85 09-06-85 09-07-85 to 09-09-85 09-10-85 to 09-11-85 09-12-85 to 09-14-85 to 09-15-85 09-16-85 to 09-17-85 09-18-85 09-19-85 09-20-85 to 09-23-85 09-22-85 09-23-85 to 09-30-85 Mud Motor 8,655 - 8,749 feet Ream and drill 8,749 - 8,752 feet Mud motor 8,752 - 9,089 feet Ream and drill 9,089 - 9,127 feet Drill 9,127 - 9,642 feet Log DIL/GR, BHC Log CNL/CDL/GR Log Dipmeter 9,641 - 7,687 feet 9,641 - 7,687 feet 9,641 - 7,687 feet Run 7-inch liner from 7,544 - 9,630 feet and cement with 800 sxs Class "G" Cement through 9 5/8-inch "FO" tool at 3,890 feet with 400 sx Class "G" and close "FO" tool. Drill out excess cement to top of liner at 17,544 feet. Pressure test casing to 1,500 psi. Clean out 7-inch liner and test liner lap to 1,500 psi. Run CBL log from 9,500 - 900 feet. Run DST on West Foreland sand from 9,390 - 9,420 feet. No flow - no recovery. Set bridge plug at 9,300 feet Perforate 8,560 - 8,740 feet, 8,784 - 8,970 feet w/4 JSPF Run hydraulic pumping equipment Place well on hydraulic pump, release rig and test well. Pumping and Testing Well DST DATA - 9,390 - 9,420 feet Depth of Gauge- 9,339 feet Pressure Data' Initial Hydrostatic IOP: Start 2134 psi ISIP: Start 2134 psi FOP: Start 2142 psi FSIP: Start 2147 psi FHP: 3330 psi 3315.5 psig End 2134 psi End 2583 psi End 2147 psi End 2579 psi Test Times- IO: ISI: Final Flow: Final SI: 17 minutes 65 minutes 131 minutes 141 minutes Note' No Recovery 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 ~'~ ¢-~ 7q.4~ is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy YES sent to sender __ N0~k_ W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 September 26, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage., Alaska 99501 File: TJZ-339-WF Washed and Unwashed Cuttings Samples MGS 17595 Well No. 20 Platform Baker, Cook Inlet, Alaska Amoco requests the return of the subject well's cutting samples. These samples were forwarded to your office by mistake, and we apologize for any inconvenience this may have caused. We are analyzing the cuttings for future drill mud inhibition and require the samples for testing. Very truly yours, W. G. Smith Di strict Manager KLS/dds O01/kls RECEIVED OCT 0 219 Alaska 0il & Gas 0OHS. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive ~ Anchorage, Alaska 99501 (907) 279-1433 Receipt of the fOllowing 'material which was transmitted via . ~{L ~~~ A~L~ is her eby ackr~owl edged: QpANTITY ' DES CRI PT ION Copy sent to sender YES ~ NO Amoco production company ..Post Office Box 100779 'AnchOrage, Alaska 99510 907,272-8471 W. G. Smith ' District j~JBrlSg~l' September ?_0, 1985 File: TjZ-336-WF terton ', Chairman Mr. C. ~. Chat~ ~ c.n servation Co~ission AlaSka oil and ~ v_n . orcUpine Drive 3001 P ~ka 99501 Anchorage, n' ~ ..... ~ Gentl emen'- 0 erationS -~-thlY Rep°rt.°~f~oP Well No 35_.and~n m.~,~., point ~_u,~,~q Well No. Gron}te ..... .~ hoal ~.~_5 Middle bru~,,~ S Alaska Form 10-~04 rm Anna,-'C°°k lnle~ ' , MonthlY' plat{o - --e the state O~.onS, for the above referenced --~-d in duplica%%~orkover . Attac-: illing anu...: =~tivities. Report of .~., August well, repor~,,'~ ~e~y truly yourS, W. G. smith District Manager Attachment Y, LS/dds RECEIVED SEP2 5 Alaska 0il & Ga~ ConS. Commission Anchorage STATE OF ALASKA ' ALASKA' .LAND GAS CONSERVATION C, iMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. /~,oco Production Company 85-135 3. Address 8. APl Number P. 0. BoX 100779, Anchorage, Alaska 99510 so- 733-20377 4. Location of Well at surface Leg 2, Slot 3, Platform Baker 1,993' FNL, 584' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. 79.4' KB ADL 1759.5 9. Unit or Lease Name HGS 17595 10. Well No. 20 11. Field and Pool Middle Ground Shoal Heml oc k For the Month of August ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month - 8,655 feet Footage drilled - 5,455 feet 13. Casing or liner run and quantities of cement, results of pressure tests 9 5/8-inch casing run to 3,200 feet. Cemented with 1150 sx Class "G" lead and 450 sx Class "G" tail. Pressure tested 9 5/8-inch casing to 1,500 psi. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR run August 20, 1985 7,694 - 3,200 feet CNL-CDL-GR run August 20, 1985 7,994 - 3,200 feet DIPLOG run August 20, 1985 7,695 - 3,200 feet 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED Alaska Oil & Gas Cons. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE DATE Anchorage 09/~/85 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 08-01-85 08-02-85 08-03-85 08-04-85 to 08-17-85 08-17-85 08-18-85 08-19-85 08-20-85 08-21-85 08-22-85 to 08-25-85 08-26-85 08-27-85 08-28-85 08-29-85 08-30-85 08-31-85 MGS 17595 Well No. 20 Test BOP stack - prepare to drill out of 13 3/8-inch casing at 3,200 feet.- Run leak-off test at 3,211 MD to 13.3 EMW. Mud motor 3,211 - 3,359 feet. Stuck stabilizer in 13 3/8-inch casing shoe. Drill 3,359 - 7,516 feet. Mud motoring 7,516 - 7,522 feet. Dritl 7,522 - 7,568 feet. Mud motoring 7,568 - 7,583 feet. Drill 7,583 - 7,694 feet. Log DIL/GR, CNL-CDL-GR, Dimpeter from TD to surface casing. Run 9 5/8-inch casing to 7,687 feet and cement with 1150 sx Class "G" lead and 450 sx Class "G" tail. Run Gyro survey. Test casing to 1,500 psi. Drill out 9 5/8-inch shoe to 7,698 and test formation to 12.8 ppg EMW. Drill 7,698 - 7,830 feet; mud motor 7,830 - 7,962 feet. Mud motor 7,962 - 8,304 feet. Drill 8,304 - 8,354 feet. Mud motor drill 8,354 - 8,655 feet. [ ECEiVED Alaska Oil & Gas Cons. Commission Anchorage W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 27, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 File' TJZ-308-WF Dear Sir: Subsequent Notice Middle Ground Shoal 17595, Well No. 20 Platform Baker, Cook Inlet, Alaska Attached in duplicate Reports on Wells, for Any questions concerning Anchorage office. Very truly yours, W. G. Smith District Manager Attachments KLS/dds is a State of Alaska Form 10-403, Sundry Notices and the subject well. the project may be directed to Kevin Smith in our Alaska Oil & Gas Cons. Commission Anchorao,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SU RY .P RTS ON W .iLLS 1. DRILLING WELL'~ COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Amoco Production Compan.v 85-135 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 s0- 733-20377 9. Unit or Lease Name Middle Ground Shoal 4. Location of Well Leg 2, Slot 3, MGS Platform Baker 1993' FNL, 584' FWL, Sec. 31, TgN, R12W, S.M. 5. Elevation in feet (indicate KB. DF, etc.) 79.4' KB, 12. I 6 . Lease Designation and Serial No. ADL 17595 10. Well Number 20 11. Field and Pool Middle Ground Shoal Fi eld Lower Kenai Conglomerate , Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~J~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105:170). Verbal approval was received from Russ Douglas on August 16, 1985, to run a Haliburton "FO" stage cementing tool in 9 5/8-inch casing at 3,900 feet, and leave this second stage uncemented until the completion of the well. This gives Amoco an option of cutting and pulling the majority of the 9 5/8-inch casing if the bottomhole pay objective is not penetrated. A gas sand exists at approximatley 3,800 feet, and this sand will be covered with cement prior to completion of the well. The 9 5/8-inch casing was run on August 23, 1985, to 7,687 feet MD and the "FO" tool is at 3,890 feet. RECEiV .D Alaska Oil 8, Gas Cons. Cor,'untss~on Anchoraoe The space below for Commission use to the best of my knowledge. District Manager Title D~b/27/85 Conditions of Approval, if any: Approved by COMMISSIONER Approved By Order of the Commission Form 10-403 Submit "Intentions" in Triplicate W. G. Smith District Manager Amoco Production Company (USA) P.O. Box 100779 Anchorage, Alaska 99510 August 19, 1985 File: TJZ-299-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Granite Point 18742, Well No 35 and Middle Ground Shoal 17595 Well No. 20 Platform Anna, Cook Inlet, Alaska Attached in duplicate are the State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting July 1985 activities. Very truly yours, W. G. Smith District Manager Attachment KLS/dds RECEIVED AIJG 2 2 198,5 Alaska Oil & Gas Cons. commission Anchorag~ .... STATE OF ALASKA ~- ALASKA L__ AND GAS CONSERVATION CO,..MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well-J~ Workover operation [] 2. Name of o~)erator 7. Per~t .NLO35 Amoco Production Company - 3. Address p. 0 Box 100779, Anchorage, Alaska 99510 8'APINur~.~-20377 ° 50- 9. Un~ Lef~esN~e 4. Location of Well atsurfaceLeg 2, Slot 3, 1,993' FNL, 584' R12W, S.M. P1 atform Baker FWL, Sec. 31, T9N, 5. Elevation in feet (i~c.a~e.K~BDF, etc.). I 6. Lease ~na~d Serial No. 10. Well No. 2O 11..F,i~ld, a,[~d Po..ol , Mlaa/e urouna Sh0al Hemlock For the Month of. July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 0-7/20/85 Depth at end of month - 3,200 feet MD Footage drilled - 3,200 feet 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20 inch casing set at 660 feet KB, cemented with B60 sx Class 'G' lead and 500 sx Class 'G' tail. 13 3/8" casing set at 3,200 feet KB, cemented with 2,000 sx Class 'G' lead and..500 sx Clas~_'G'. tail;',.'Pre~sure~.tested-'to 1,90'.'? .~si. '-Run leak-off te~t i~0 13.3'"PPG' MWE. ' ' 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None Alaska 0il & Gas (.;~;~;s. Cornf~']~ss~o~) Anchor~0e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~.,~¢~. ~ District Manager SIGNED ,- ~ _ ..... TITLE DATE 08/20'/85 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 Middle Ground Shoal 17595 Well No. 20, Platform Baker 07/20/85 07/21/85 07/22/85 07/23/85 07/24/85 07/25/85 07/26/85 07/27/85 07/28/85 07/29/85 07/30/85 07/31/85 Spud well and clean out 30-inch slot. Drill 17½-inch hole to 660 feet. Open hole to 26 inches and run 20-inch casing. Cement with 860 sx Class 'G' lead and 500 sx Class 'G' tail. Nipple up lO-inch diverter lines and drill to 684 feet. Drill to 750 feet. Mud motor to 926 feet. Mud motor to 1,124 feet and drill to 1,417 feet. Mud motor to 1,755 feet. Mud motor 1,755 - 1,824 feet. Drill to 2,479 feet. Drill to 3,200 feet and condition hole for casing. Run 13 3/8-inch casing. Cement 13 3/8-inch casing with 2,000 sx Class 'G' lead and 500 sx Class 'G' tail. MEMORANDUM Stat of Alaska ;L ....... -' FILE NO:D. BD~. 60 THRU: Lonnie C. Smith --~f' ~ Comm± s s ioner FROM: Bobby Fo s t er', '-._;~,~ SUBJECT: Petroleum Inspector TELEPHONE NO: Diverter Inspection Amoco M.G.S. ~20 Permit #85-135 Tuesday, July 23, 1985. I traveled this date to Amoco's Baker Platform and inspected the diverter system being used on Well #20. Attached to this report are pictures and a schematic of the diverter lines and valves. In summary, I inspected the diverter system on Amoco's M.G.S. Well. #20. 02-00IA(Rev. 10i79) It3 June 26, 1985 W. G. Smith District Manager Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510-0779 Re: Middle Ground Shoal 17595 No. 20 Amoco Production Company Permit No. 85-135 Sur. Loc. 1993'F~, 584'FWL, Sec. 31, T9N, R12W, SM. Btmhole Loc. 800'FSL, 500'F~.~, Sec. 31, T9N, R12W, SM. Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. IS coring is conducted, a brie= _ z description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified'as important for the spa~ing or migration of anadromous'fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. W. G. Smith -2- Middle Ground Shoal 17595 No. 20 June 26, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. '-Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ~~tru!y yours, / ~ /J C. V. CRatte.Ctdn Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~SSION be Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 June 13, 1985 File: TJZ-214-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Application for Permit to Drill Middle Ground Shoal 17595 Well No. 20 Platform Baker, Cook Inlet, Alaska Attached in triplicate is a State of Alaska, Form 10-401, Application for Permit to Drill for Middle Ground Shoal 17595 Well No. 20. We propose to directionally drill this well from Middle Ground Shoal Platform Baker, utilizing Leg 2, Slot 3, to a target location at the top of the Lower Kenai Conglomerate G-1 zone, - 7,750 feet subsea, 1,300 feet FSL, 500 feet FWL, Section 31, T9N, R12W, Seward Meridian. This well is to be completed as a producing well to recover reserves from the west flank of the Middle Ground Shoal field. Also attached is our company draft No. 306518 dated June 3, 1985, for $100.00 to cover the filing fee. Two plats showing the location of the well in relation to the Middle Ground Shoal structure, and a Platform Baker survey plat are attached, along with sketches of the BOP equipment to be used. Our computer program, "DEVPLAN," is included which calculates the horizontal distance between the proposed wellpath and offset Well Nos. 7, 11, and 12. A leg diagram shows our proposed kickoff in relation to the surrounding wells. Since this will be the seventh well completed in the southwest quarter of Section 31, we also wish to obtain an exception to the provisions of Conservation Order No. 76 (dated September 12, 1969) of the Alaska Oil and Gas Conservation Commission. The other wells completed in this quarter section are' RECEIVED Alaska 0ii ,~', G:ut, C,,. ,} :-,.; (.';ui~lmJssJor, C. V. Chatterton, Chairman TJZ-214-WF June 12, 1985 Page 2 MGS 17595 Well No. 7 - Producer MGS 17595 Well No. 8RD - Injector MGS 17595 Well No. 11 - Producer MGS 17595 Well No. 15RD - Producer MGS 17595 Well No. 12S & 12L - Lease Line Injector MGS 17595 Well No. 23 - Producer Drilling of the subject well is estimated to start on June 24, 1985. Please contact Kevin Smith in our Anchorage office if you have any questions concerning this application. Very truly yours, W. G. Smith District Manager Attachments KLS/dds STATE OF ALASKA ALASKA ~ ,L AND GAS CONSERVATION CO,, ,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] RE•RILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface Leg 2, Slot 3, MGS Platform Baker 1,993' FNL, 584' FWL, Section 31, T9N, R12W, S.M. At top of proposed producing interva~ G-1 sand at 7,750' Subsea, 1,300' FSL 500' FWL, Section 31 T9N,-R12W, S.M. Attota~depth800' FSL, 50[l" FW[, 9,130' Subsea, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF etc.) 79.4' KB 6. Lease designation and serial no. ADL 17595 9. Unit or lease name Middle Ground Shoal 10. Well number , 20 11. Field and pool Middle Ground Shoal F]eld Lower Kenai Conglomerate 12. Bond information (see 20 AAC 25.025) Type Blanket Suretyand/or number Surety - 599481 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 20 miles NW of Kenai, AKmues 800' FSL of ADL 17595 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease i9,584, MD 9,209' TVD feet 5,106 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 750' feet. MAXIMUM HOLE ANGLE 20° (see 20AA025.035(c) (2) 21 Amount $500,000 15. Distance ,o nearest drilling :~D~.~I~ ~Up or c pte A #7 wel~ is 643' S 19°E feet 18. Approximate spud date ur~u ~4 lnST5 1.- 3~ ~ psig~ 0 Surface 3,391 psige~,800 ft. ~(TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight m 1 7½" 17¼"9 !" 30Il 1 _R 7" 22. Describe propose~ ]20¢/f.t 94# ~7., 53.5 35# program: CASING AND LINER MD 1 SETTING DEPTH Grade Couplingl Length - 1 266' K-B~ R~tt I 600' J- .SJaOButtl 500' N-80~SJSOButt 8100' HC-9~ Butt 11684' TOP TVD O' 0' - :0_'.-' ~1~0' 7900' [7621' MD BOTTOM TVD 266 I 266 600 _~_£00 8100' ~7812, 9584' 9209 QUANTITY OF CEMENT (include stage data) Driven conductor Class "G" to Surface Class "G" to Surface Cover A sand plus 500 Cover. entire liner Amoco proposes to directionally drill Shoal Platform Baker, to a Lower Kenai 500' FWL, Sec 31, T9N R12W, S.M. Tota after adequate penetration of .the G-5 be perforated, and the well placed on Well No. 20 from Conglomerate G-1 1 depth is estima zone. After log hydraulic lift. Leg 2, Slot 3, Middle.Ground target at 7,750' SS, 1,300' FSL, ted to be at 9,584' MD, 9,209' TVD evaluations, zones of interest will There are no affected operators. A location plat and BOPE sketches are attached. NOTE' Casing design safety factors of 1.125, 1.0 and 1.8 will be used for collapse, burst and tensile strengths respectively. Estimated maximum mud weight is 11.25 ppg. RECE/V D 23. ' hereby certify that the foregoing is tJ;~e and correct to the best of my knowledge JUN i J~ ~Q ~ SIGNED TITLE Distri~ql~sk)~aqer%$ ~_ D~ATE 06/13/85 The space below for Commission use ...... ~JUll,S. u0mmIssJ0rl ' Anchorage CONDITIONS OF APPROVAL Samples required i Mud log required []YES ~NO [ I--lYES I~O Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Approval date 6 85 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ._Tune 26, 1985 . by order of the Commission Submit in triplicate -) ,~r~oco) SUBJECT. Amoco Production Compa ENGINEERING CHART Sheet No. Of File Appn ~ _* TOP* ! : 12Q0'. 3O o . 31 LEGEND · OiL PROOUCER ,~ '~TER INJECTOR X PROPOC*.ED LOCATtOI~ '~ CmS SUPPLY JUN'i ~' ~oor, ska Oil & Gas Cons. Commission Anchorage ~ R/2W DOLE GROUND SHOAL G- 1 $.TRIJCT. URE :- LEG ¢:C. I LONG 151°29' O0 gsT _ Y = 2,498,059.8 . X = 2:$5, 255.0 5~4" E~Sf . SEW/4~'~, ~.'ERI~I~,,"J , AFAsKA _ .. .LEG NO 2 .I LA-". 60° 49' 45. ZZ" LONG'ISI° 29' 00.07" Y : 2,498,014.46 · X : 235. 297. 30 ' FROM N_W. COR. 1989' SOUTH Bi 588' EAST LAT. 60° 49' 44.70" LONG ~51-0 29' Ct. 41" . Y = 2,4g·7',9~5.55 X '=- 235,2 30-30 . FROI'4 ft.w. COR.' 2041 SOUTH a . 522 EAST : .- _ . · . · I hur~by licensed Alaska s.urv,ey, that ail ... -.. .. . ~i~s~a 0/i d Gas ' - , 'Cons ' CERTIFICATE OF SURVEYOR . AnChorage' C°mmi~ .cerf~¢y that I om properly registered o~d' to practice toad surveying in the State 'of and that this plot represents a location mad~ by me or Under my sUpe~isi~n and dimensions and other details ore correcL . · ' .- 'T9N _ -. . - _~-~,= : .. · 'LEG Nd 5 --... J .LEG N0. : ';' .' .. L~T. 50° 49' 45.2'3". - "LOrt~ !5~° 29' 02:'Z~" ' Y- ~_,4981'018.$8 : · 'X: 235, 187.7~ '': . FROMM N.W. COR. ' · 1987 sOuTH.. Bi .'' . 4T8' EAST . · - . . NOTE The location of platform legs was accomplished by using U.S.C.8 G.S. monument's Tad, Boulder, and Cost, BLM c~)h- trol points CET lO,and Granite Point Native Hub, and triangulation stations East Foreland Light Offset, and Arness DooR. - --. CO0,'< I,NLE. T CO~RECTIO,"I LINE .. · . .'- .. -. · .' : .,,.~,-....-1%'~-_'%....~ . . .t .t_ : k_~l ~,: ' ' ~ '~ -, _<..,...../. . f. -,,-~fi #* :;-.-- . 1'~ $ N _.. ,! 53-5,; . . ~, ~,." ,. ~. ' -~ '.. l_ .. ~ ~'~-',-- .~ . ~ ~n... . ..... LOCATION SURVEY OF sj~nFIRST ORDER CONTROL POINT "PA H" ON PLATFORM "B" ! .O~3,'tT[O ,{'4 3,~,/4,',I~/ I/4, PRGT~$T~S S~S 31,T9~:,~ ~'.V,~ SU~V[YED FOR PAN AMERICAN PETROLEUM OCR: · . ,,' PO BOX 779 Af~CHO~AGE, ALADKA · SURVEYED BY' .. F. N!. LII'.,~DSEY 8, ASSOC. LAND SURVEYORS 8~'ClVl~ ENGINEERS' . C ~,T.~.~ Amoco Production Compa, ~ /~il/10C0, ENGINEERING CHART SUBJECT SHEET NO. FILE OF APPN I . NYDRIL / A~ NL.)L.aR BOP) L///~' I LXA/3 ! ' t~/'.,r,~ R,.LJ i',lg ~',AmS~ .SHA FF EF,, (,¥%i r~ '~A,'n'-,~ -I RECEIVED Alaska Oil & Gas Certs, Co~,,~imss~or, Anchorage ~T~, Amoco Production Compal,t :,AMOCO ~ I ~1~" ENGINEERING CHART SUBJECT :U // ~/~-J/~/0 ~/~-- /~i~i~~//7~-77 -- /----~/~V/~-~/~-'~ SHEET NO. FILE OF APPN I -j · ~.o ~,-,,,,,,. el', I~, a'laska (Jil ~ Gas' COrls, Commissio~ Anchorage .. . '7256 MOCO ET ., FOR F~ AL PLA T ' o . 3W AMOCO ET AL -7326: / / / ';.-7328 .B-12 0 o 0 O, 3W 754 SHELL ET AL RI3-O! U°!SS!U]I'U°O 'Su°O Se9 ~ !!0 -q I I ! I O'~ ~ -rr~ ~ 0 0 I 6~ .JUM lV ~:d3 RMOCO FROD. WEST PROD. DENVER CO · · Anchorage Subject: Zubula= Goons &llocatio~ ~iddle Ground Shoals No. 20 ~£ddle Ground Shoals Cook Ialet, Alaska 8q6525-~ P. 001 Listed below as the casia9 de~i~n/allocat£oa ~or the a£o£eaeat£oae~ · 600* 20.000" 9~.001 K-55 BTC Keaa£ Sthae DTH )80 ' 13.3 75" 61.00~ J- 55 1500' 13. 375" 54.50# J-55 1120' !3. 375" 61,00# 3-55 2000' 7. j~ ~1 ~!~Sk~ Off d:~, &-~.s. Cons, '-;nc4.-,..., ~ge 'Con?m/SS/on cc= T. ~cKaY G. ~lieage - A~c~qrag~ Wes[ Div2~ion we~l F~e - A. 8- ~oo~ i539 Comments:The above qasing d.e~2i, ga_.i.s .based 4pea.a. 9-5#/9~L. mud wg~ght for the surface c~szng, aaa ~]-~/gai. maa ~eight ~or ~e in~ecaed~ate stc~9. script file reference: mg~m20 JUN 10 03:23 AMOCO PROD. WEST PROD. DEMVER CO ., P. 001 Sub ject: ~ubula~ Gooas &llocation ~iddle Ground Shoals ~iddle G~ouad Shoals Sq6525-q 2O Listed the az oreaea t~oae ~ 600' 20.000" 9q. O0t K-55 BTC Keaa& 13. 375" 1120' 13. 375. 61.OO~ J-55 BTC .5_o.a~ ~ -_ above Gasiag d. egi_ga.i.s ~ased upoa a. g~5t/g~, mum ue~qh[ .Alaska Oil 8, Gas Cons. (jolnir].ss{or,'" ' ~" ' Anchorage : , _., · i · CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /~43 ITEM APPROVE DATE thru (3) Aamin (.9/ thru ,12) [10 a~d 12) (13 thru 2'1) (22 thru 26) (6) Add: ~.~.~/~ o/g-~°_f' Geology: En~ineerin~: rev: 03/13/85 6.011 e 10. 11 12 YES NO ,, 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ............... ,,/~_ 4. Is well located proper distance from other wells ....... i° i° i~/~..~ ."~F__.~ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is 'wellbore plat included .. . 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ............................... Is the lease number appropriate .. .i..i . i ........ '~-~ 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. REMARKS 27. Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... /~. Will cement tie in surface and intermediate or production strings ... iJ~ Will cement cover all known productive, horizons ..................... ~,f Will surface casing protect fresh water zones ....................... dd~ __ Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. ~d Is old wellbore abandonment procedure included on 10-403 ............ ---- Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ,7000 psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~ IN ITIAL GEO. UNI~" '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 APPENDIX. No special effod has been made to chronologically organize this category of information. ** REEL HEADER ** RE=L NAME : DATE : ORIGIN : FSYS SERVICE NAME: BiTL!S REEL CCNTINU~T ~O~- NUMbeR: 01 PREVIOUS REEL N~NE : COMMENTS: DRESSER ATLAS LIS CUSTOMER LENGTH: t]2 BYTES ** TA.:E HEADER T.aPE NAME : ~,ATE ORIGIN : F-SY~ S=RVICE NAME: MAiN TAPE CONTINUATION NUY~B~R: .01 PREVIOUS TAPE NAME COMMENTS: LENGTH: 132 BYTES CREATED BY SCS PROGRAM ~: 2,0 ** FILE H~DER # t ** FiLE NAME: N~ZN .001 SERVICE NAME: VERSION # : D~T~: ~5/11 MAX RECO~D LENGTh: FIL~ TYPE: LC PREVIOUS'FILE NAME: ** INFORmATiON RECORDS ** MNEM CONTENTS APZN : ~0733203~8 CN : AMOCO PRODUCTION CO. WN :MGS 17595 NO 20 ~N : ~IDDLE GROUND SHOAL COUN : KENAZ ST~T : ALASKA LCC : I:~ ~u. CO ** ~ORMAT UNITS TYP= $ 11 0 DATUM ENTRY BLOCKS =NTRY CESCRtPTION I OEPTHS DECREASE 6C,0 FRAME SPACING ,lin FRAFE SPACING UNITS 18 ~XiMUM FR~S/RECORD TERMINATOR -~ 50Q L=V~L sm~rINC cP=r~r~'C~TEON 2LOCKq CURVE REPR N~ME CODE SiZE S~MPLE UNITS GR 6~ ~ 1 ~i L, URVc R--PR SIZE S;~MPLE 1 UNITS APl CENP 68 RF~r kS RiL~ 68 FORMAT 4 1 4 t USIF 4 1 0HMM SP ~_8 4 1 .,v.v CN ~8 4 1 ~i~ M 6~ 4 1 CHMM ENTRY, =LO~' S. ~K TYPE F--NTRY C=~SCRiPTION i iii m m i ! lmmiI mi I III 4. 1 DEPTHS BECREASE $ ~r 0 FRANF SPACING 9 lin r--RA~'~ ~P~CING UNITS 11 18 NAXINUM ;RAMES/RECORD 0 TERMINATOR -0,500 LEVEL SPACING DATUM SoEC=~iCATTCN, z- ,_ , ~LOCKS,~ CURVE REmR NAME CO~Eu SIZE SAMPL~ LNITS GR 68 4 I APl CORR 68 4 I 3/C3 CALl 68 ~ I IN OEN~ 68 4 I ,~C 68 4 I US/F RF~vu 68 4 I C~M~., RiLD 68 4 1 CHM~ ** DATA ** CR -~9o9 COO GR1 -99¢9 CCG ~ ~ . . ~ · CALl -9999.C00 DEN -9999.000 ~C -9999.000 CN -9990.000 RILD -9999.000 DEPTH o60O.COO FT 2926.0860 M GR 92.683 GR1 CALl 8.3t0 DEN AC 70.983 CN RILO 45.998 6~.291 ?.~6~ 17.863 OEPTH, 9500 . COn~ :T~ 2~95~ .606C. GR 6! .937 GR1 ~L1 8.872 DeN AC 70.592 CN RILO 30.C60 N 2.460 1~.~2~ OEPT~ 0400 CCO =T ?865 125C M , , . . : ~ ~ m OR 48.509 GR1 CALl 7.410 DEN ~ 87.522 CN RILD Z, 6.515 2.470 t3.978 DEPTM 9'~00 rr.c I=T 2834.6460 M ~ m ~m, i CURV: REPR NAMF CCr~ SI7~ --i--i ~--i! GR1 68 4 CAL 68 4 ~N 6~~ 4 SP ~8 4 CN 65 ~ RILM 68 4 ~ORR DENP RFOC CORR ~END R~OC CORR U '"' NP CORR uENP RFOC -9999.0CC -9ggg.oCC -9999.0CC C.3cC !7.103 40.175 C.175 11.53C 2~.573 C.CSC :IC.3aC SAMPLE 1 1 1 1 1 1 CAL SP RILN CAL SP RILM CSL S P RIL~~ CAL SP RIL~ UNITS IN G/C3 CHMM -9999 r, ,", -~ -9999.0C0 1 -34.goe, 5~ 12.9¢7 AC 6Q.839 CN RZLD 22.210 30.237 DEPTH Q200.CCO ~T 2804.166C M GR 117.364 GR1 C~L1 8.693 DEN dC 64.420 CN R!LD 38.831 106· C8~ 2.492 27.486 DEPTH 9100.GCO FT 2773.686C M GR 1t2.326 GR1 CALl 9.083 DEN AC 67.4t8 CN RiLD 22.902 109.622 2.5~6 3 ~ u,479 DEPTH, 90nn..u.cg~v ~T 2743.~m6Gu M GR 116.585 GRt CALl 9.202 DEN AC 68.609 CN RILD 27.62t 103.253 2.a27 24.421 DEmTH ~900 ¢ ' , , ..... ~O0 -T 2712.7260 M GR 48,121 GR1 CALl 7.,.~16 D~N ~C 81.749 CN RILD 51.14~ 44,t2~ ~ .495 10.663 DEPTH 8800.CC0 FT 2682.245C M GR 51.t77 OR1 CALt 7.456 DEN ~C 78.2~1 CN RILD 78.852 ~3.522 2.495 12.8Z7 DEPTH 8700.CC0 ~T C~L1 8,316 ~&C 69.C24 RILC 79.831 26~1,765C ~ D=N CN 44.~55. ~ 2.5~$ 10.697 DEPTH $600.6C0 :T 2621.235C M GR 38.972 GR1 CALl ..~.23z_ ¢ O=N~ AC 74.895 CN RZLD 69.330 37.488 2.51~ !1.C60 DEPTH 8500.000 FT 2590.80~C ~ eR.= _~0 ,566 CALl 8,825 DEN ~C 86,c-, 62 CN RiLD 19.~r 46,~1'~ 2.432 DEPTH 840n ~,~ ~ uu FT 25AU.325C M GR 56.763 GR1 C~L1 10.C88 DEN ~e 86 4~8 CN 49,874 2.463 lC,391 u. ORR DSNP RFOC CORR DENP U~OC rnRR ,~.~, DENP ~FO~ CORR ~n ENP CORR DENP RFOC CORR DENP RFOC ,,.¢RR J ENP RFOC CORR !7,834 0.15C 9.577 35.129 0.202 ;1.611 9.415 71.6C9 -u .0.,( 9.3,c3 lC5.031 C.039 6.3~C C.045 8.007 ~2.2~C 0 13,239 24.947 C .03C 11,3t5 15,27~ C/~L SP RILP C~L SP RIL~ CAL SP RiLN CAL SP RiLF~ CAL SP RILP CAL SP RiLF C$L SP RrLiv C&L SP RIL~' C~L SF' RILF 22.715 11.1~? -5~.779 33.9Z~ 1 2.5,~0 -63.490 1 C. 360 -71 .321 75. ]$2 9.Z39 9.141 57,166 9.545 -=4 151 57.59? 9.5=2 -=7.007 5 ~ ~ ..... ,41 11.1o,S -91, ~37 ?.1 ,m66 11 .S6z~ -99, %, 15.321 8300'000. eT 2529.8450 GR 45.050 GRt CALl 9.C86 DEN AC ?3.652 CN RILD 22.825 46,453 2,506 13,656 DEPTH 8200.000 FT 2499.3650 OR 52.722 GR1 CALl 8.021 DEN AC 76.505 CN qiLD 62,364 M 43,167 2.461 I 4,$3! "=PT~- 8100.CGr FT 746.~.~-~C M cm 52 ~61 GRt C&L! 8.101 DEN AC 72,347 CN RiLO 52,C~9 46.706 12,832 DEPTH 8COO.C'CO FT 2438.4056 GR 44.427 GR1 CALl 8.507 DEN AC 78.081 CN RiLD 96.210 43.45[ p 50; 12.2~1 DEPTH 7900,C06 FT 2407.925C M O~ 56.457 GR1 52,576 CALl 9,E62 DEN 2,375 AC 68,238 CN 24't37 RILD 62.982 u~=PTH. , 7800 . C'*Ou FT 2377 .4450 M --~mmmemmmmmllemmimmmimmmIIimm-- GR 42.772 G~! 44.222 C~L1 ~.~. ~4~ DEN 2 · 44~ AC 82,767 CN 14,899 R!L~u 40 ,134 DEPTH 77C0.000 ST 2346.985C P Gm,~ 77 .081 GR1 8=~._n26 CAL! 9.497 DEN 2.188 AC 82.553 CN 42.639 R=~ 38 4~5 DEPTH 7600.000 FT m316.485C M mmmmmmmImIimm~immmmmmmmmmmmm~m G~ 73,~7 ~R1 6A 275 CA!,1 O.~C~. ~ ,~ D~N 2.5Z9 AC 0 C~3 CN ~ ~ ~6.CF~ RILD 9.6~ D:mTH 75C0.0C0 FT 2286.005C M GR 51 .999 GR1 C.~L1 O,CO0 DEN ~C O.uu~' ., RiLD 14.5F5 41 ;' m 40.257 D= .... '~ FT ~'55,525C *.~ .~T~ 740u, C ~;-.~ _~ · rO~,R D=NP CORR DENm R=CC CORR DENP RFCC ~ORR DENP RFOC ~ORR RFOC ~ORR DEN? ~FOC ~rORR DEN~ RFOC CO~ R~OC '-.3 0.2!3 5.0~ ~'4 7~ 2 C.01~ 11.482 91,873 C .07~ ~.153 60 ,t7=, ,.0-4 8.57g 1C7,273 C.198 16,687 C.121 12.544 62 C.171 25.097 ~..751 E .734 21 .~ CAL SP RiLM CSL SP RiLN CAL SP RiLN CAL S° RILN C~L SP RILN C~L CAL SP CAL RILN C~L RILN 11 .75! 24..~,~1 9.162 -~2.161 41 .107 ~. 871 41 .739 57.1334 1C.e69 -19~ ,f31 X~ lC.2~4 -102.d43 41 ,372 I C. :::. 74 -143,370 3C. I~'.9 14.203 -9 ~-',. 647 10. '~'4f 16.2'45 -,5 *. 740 ?~ 47~ ,~aL1 U ,COn 'EN ~C O,C00 CN RTLD 2.4~4 20, ~ 79 SR 43.453 CALl O.O00 DEN AC 0. COn ~ CN RiLD 7.~25 . · .~.~ iii~Ii~iiiiiII--iii-- CALl O.C00 DEN RTLD 8 M 49.0C3 2.384 7100 . CCC FT 2164.. GR 55.842 GR1 C~-L1 O.CO0 '.DEN &C O.GO0 CN RILD 12.470 54,164 2,591 2,~. 740 DEPTH 7COO.CO0 ¢-T 2133.6040 M GR 45.584 GR1 CaLl O.C'"Ou O=. -~N AC ~ '~ u. O0u CN ~!LO 6,861 43.344 2 '457 23.1~ Cr-PTH 6900.C00 FT 2103.1240 GR 55.064 GR1 CALl O,COO DEN AC 0.0OO CN RILD ~ 4~4 58.316 2.557 30.038 n ,, ~C:n FT 2077.6440 M uEPTH 6R00.u ~, , _ GR 41.2~1 GR1 CALl O.CO0 DEN AC 0.C00 CN R!LD 25.C82 4! .733 2,517 t4.404 ~'V. DTk 670n COO FT 204'2 t640 M GR 47.477 GR1 CALl O.CO0 DEN ~C n o~n CN RILD 19,730 44,577 2.392 21 .~19 u~¢mTH_, 6600, .CCC FT, 2011.~AR4~... u M 02 42.5t8 GR1 CALl 0.000 DEN AC 0.GO0 CN RiLD 11.235 37,317 I ,833 45,728 u"-'F-'PTH,_ . 6500.C00 FT 1981.~04C_ ,,M GR 39.308 GR1 CALt O. C':O0 DEN - - - 37.5(::6 nEN~ ~.FOC CORR RFOC CORR ~..~NP CORR D~NP R.=OC CORR DENP RFOC CORR ~'~NP RFOC CORR '35NP RFOC CORR OENP CORR DENP R¢OC CORR OEND ,_.OC~,. !1 .~55 5.676 0.103 3.562 10.17E C .072 11.681 5.52a C.0!5 ~ 607 7.940 -C.OCI ~.0~1 2C.~7C C.013 1 ~ 62d 13.019 -C .0~;.. 9,297 u · 02',9 15.55,2 . . SD CAL SP CAt SP RIL~ CAL SD RILF C 4 L SP CAL SP RILM C~L RIL~ CAL S~ RILM CSL S~ RILW CaL SP -S5 7.:10 15.527 -92 . 7. 469 1~.4~0 -87.267 7.547 1 ~ .2&O -70.319 16.009 -77,903 6,939 16.082 16.468 11.487 22.006 16.I92 -9.331 14,967 17.313 -57.=79 10.319 21 . ~ F.,S 15,753 BFPTH_ 6400 . r"o0_ FT. 195n,..,. 7240 GR &1.222 GR! CALl 0.600 DEN aC O.CO0 CN RiLD 17.548 2.355 24.457 OEPTH 6'~O0.CCC CT I,~20 P440" GR 66.579 GR1 CALl O.O00 DEN AC 0.000 CN RILD 7.~74 66.735 2.62~ 31.210 -~EPTH 6200.000 FT 1889.70-40 M GR 34.510 GR1 CALl u.~ CO0 DEN AC O.CCO CN RILD 30.532 2 I 21.872 OEPTM ~10~ COO I='T 1859 2~&C M ~ ,,¢ -. ii , - · ~., - GR 37.656 CALl O-CO0 DEN ~C 0.000 CN ~iLO 1t.764 41.920 2.~4~ 2C,392 D:PTH 6000.000 FT !828.8040 M GR 48.206 GR1 CALl O.CO0 DEN AC O.O00 ON RiLO 7.698 41.403 2.475 24.46t ~EPT~ 5900 GOO ~T 1798 GR 39.664 Gq1 CALl 0.000 DEN ~r 0 O~ CN RILD 10.~g9 35,673 2.~3t c~.527 ~EPTH 58'"' '"' '- .- vO. ,,., C O. rT 1 7'"; 7., .,,..,,¢,44C ,v, GR 40. 4~n_u GR1 CALt O.CO0 DEN aC O.CO0 CN RILD 12.841 42.m~I¢~ 2.3Z7 ~4 C5~ nEPT~ 5?nO CO~ F~ 17x7 x640 u~R ~7.603 GRt AC O-CO0 CN RZLD 31.086 M 34,223 2.452 19.625 DEPTH 5600.CC0 FT 1706.8840 GR 59.790 GR1 CALl O.O00 DEN aC O.O00 CN RiLmu 6.7~1~ 57.530 2.567 26.674 CORR D_=NP RFOC CORR DENP- ~¢OC DENP RFOC CORR DENP RFOC CORR DEN? RFOC CORR DENP RFOC CORR DENP RFOC CORR D RF--OC CORR DENP RmOC 17.967 C .053 I .5C6 7 0.12; 17.255 16.436 -C.034 16.1C4 E.4Cg C 10.532 5,o4e -O .074 IC.35~ 8.572 C.07.~ 12.008 21 .147 C.144 5.0 5.814 CAL RILR C~L SP RILF CAL S P RILff CAL SP ~iLY C&L SP RiLR C~L SP RiLW CAL SD RiLF CAL SP RILl¢ CAL SP RIL~ 17.129 1. z, 2,3 !5.17,3 17./-,19 -66.~ '$ 7.254 20.722 32.204 1~.64m -21.4~4 11 -O"z ~3 7.C:9~ 17.7_67 -75.797 10.034 17.157 -70'.640 11 .71e 14.286 -4~.739 18.72~ 1~.454 -10P.631 51294 GR 80.503 CALl O.OO0 DEN AC 0.000 CN R!LD 6.316 82,496 2.6C6 27,427 DEPTH 5400.C00 FT 1645.9234 M GR 62.313 OR1 CALt O.CO0 DEN $.C O.O00 CN RILD 13.331 65.335 2.490 25,742 DEPTH 5300,000 FT 1615.4430 M GR 49.4~3 GR1 50.506 C.&L1 O.CCO DEN 2.412 dC O.CO0 CN 25.899 RILD 9,195 DEPTH 5200.CCC FT 1584.9630 M ! I I i GR 28,690 GR1 27,529 CALl O.CO0 DEN 1.580 AC 0.000 CN 59.418 RILD 33.C42 OEPTH 5!00.CC0 FT 1554.483C M -- uR ~6,~48 GR1 CALl 0.000 D~N dC 0.000 CN RiLD !4.530 32,461 2.4t7 19,402 OF-PTH. 5r~O0,.. . COp~ PT 1524. · 0030 OR 89.231 GR1 CALl 0.000 DEN AC 0 '- '"- ~ · ',.,, u u CN ~ILO 7.873 ~9,066 2.526 33,371 DEPTH 4~On ~ ~ .... uuu FT GR 48 a18 CALl AC O.CO0 RILO 8.~27 t493.5230 N GR1 DEN CN 49,003 2 3~3 24,799 ~ uv FT 1463 ~EDTH 4800 Cmn SR 33.782 GR1 CALl O.CO0 DEN dC O.C~ uu CN R!LD 9.'34~ 311049 2,346 22,225 ~$DTH 4700 C GR 60. C~L1 O. ~C O. RILD 9. O0 FT 1432.5630 419 GR1 COO DEN COO CN 72O 55.52~ 2.074 ~5 ~84 DEPT~ 4600 CO~ ~T 14~2 083C ~ .- . ~ ~ I CORR DEND , - CORR DEND RFCC CORR DENP RFOC CORR DENP R:OC CORR DEN~ RFOC CORR DENP R~OC r~RR DEND RFOC CO~R D ENP R~OC CO~R O=ND RFOC 0.035 2.664 7.116 C .051 Q .722 1C.232 0.072 1~.421 7.615 -C.137 ~4.8~C 22.67C 14,107 9.0~5 0.1C6 7.49,c a.103 19,232 6.621 -C.021 1~.43~ 7,~C~ C,04E 34.93E 6,?C7 C~L S~ RILM CAL SP RILN C~L RILN C~L SP RILM C ,& L SP RILM CAL SD RILN CAL SP RILN C .zl L SP RILK CAL SP RILiv 15.154 -137.465 A . 16.001 -68.115 11 .699 15.755 -131 .211 8.109 1~,~6 -~1.892 28.2~6 16.16~ -110.414 14.412 17.031 -14~.285 7.212 17,653 -131 .637 7,675 15.54~ -14.3. 577 ,S.;~ 5 16,507 -144.502 8,117 GR 57.030 GR1 54,864 CORR -C.124 C~,L 10.744 RILD 6.99t OEPTH. 4~00. .~n~ FT. t371.6n30~ M GR 5~.750 GR1 CALl 0 C60 nc AC O,O00 CN RILD 14,995 49.t39 2.392 27.455 uEPT~ 4400 CCC FT 1341 12'~r M GR 43.451 GR1 CALl O.O00 DEN AC O.CO0 CN RiLD 7.0!6 40.779 2.457 23.503 ,DEPTH 4300.000 FT 1310.643C ~4 GR 38,907 GR1 CALl O,CO0 DEN AC O,CO0 CN R!LD 7,776 39.'::~ 6 2.538 19.720 -~,.~'F-PTH ",mO0,~ .CO0 FT l m80,~ .1630 ,.,,'4 OR 33.985 GR1 CALl O,Cvu D~N ac O,CO0 CN R!L9 9.0!5 32.123 p.~z7 18.753 BEPTW. ., 4100.~¢00 FT 1249. .683C M GR 61,176 GR1 CALl O,CO0 DEN ~¢.~ O,O00 CN. RILD 9,900 ~? 14~ 2.529 3~.5~~ OF-PTH 4000, COO FT t 21 9. 202C ¢~ GR 89.388 GR1 CALl C. CCO ~EN ~C O.O00 CN RILD 9.883 2~ 614 2,492 32,72~ DEmTH 3900,000 FT 1188,72~C N GR '~7, 2~1 GR1 ~ ~41 CALl O,CO0 DEN 2,561 AC O,CO0 CN 33.560 RILD 7.C92 OEPTH 3~O0.CO0 FT 1158,242C M GR 49.838 GR1 5!.9C2 CALl O.CO0 DEN 2.449 ~C ~ CO0 rN 23 2e7 ~IL~ 19.950 ~=PTH ~700 rcc FT 1127 762C u GR 51,900 GR1 CALl O,CO0 DEN AC O,CCO CN RILD 6,C89 S1.686 ~ ¢87 CORR DEN. P RFOC CORR OENm RFOC CORR OENP RmOC ~ORR 9ENP RFCC CORR DENP R'FOC CORR mENP R~OC CORR DENP CORR R~O~ ., ~ CORR DENP 15.A'~c 9.125 C.05C 11.681 5.294 C .052 6.794 6.729 C 6.848 C .0'~'~ 7.351 ~ .9~:'~ C.054 9.5~7 ~ 6¢6 ~.036 5.419 5 .$6c, C,OC3 12.152 1C,231 C .038 3.817 5.727 CAL S° RILY CAL SP RILN CAL RILM ~L SP RILN RILN C~L Sm RILM CAL SP RILN C~L SP r~ iLN CAL SP RIL~' 15.042 -120.535 12,479 17.$07 -17_1 .!331 6.6!6 !5.540 -101.731 8. C34 1 5 "'Ol -114.11~ 10.111 17.158 -09.612 9.380 18.408 -133.614 9.2~9 17.759 -161.46.5 d.b57 15.222 -13C,284 15.$34 1.~.116 -13C.776 GR CALl AC RiLD 67.322 GR1 O.COO DEN O.CO0 CN 7.~55 · ~ 66.464 2.454 28.795 DENP RFOC DEPTH GR CALl AC RILD CCC ~T ln66.~020 N 59.401 GR1 56.119 0.000 DEN 1.967 O.O00 CN 48.347 26,922 CORR DENP R=OC DEPTH 3400,C00 FT 1036.322C M GR 65.938 GR1 64,00~ CALl O.CO0 D=N 2.447 AC O.CO0 CN 32.979 RILD !0.504 CORR DENP RFOC gEPTH 3300 ~ ~ .~0n FT 100:5.8420 GR 70.630 GR1 C4L1 O.CO0 DEN AC O.COO CN RILD 8.327 63.849 2.394 40.594 CORR D~NP RFOC DEPTH 3200.C00 mT 975.3621 M GR 47.02! GR1 C&L1 0.000 DEN AC 0 nnO CN RILD !L.190 ~6.047 2.029 36.750 CORR DENP RFOC CEPTM 318~.500 FT 970.0281 M GR 40.81 8 GR1 CALl 0.000 DEN AC O.C:O0 CN RILD lCO00.CO0 37.755 CORR 2.524 DENP 21.494 RFOC STARTING DEPTH = 9662.000 FT ENDING DEPTH : 3182.500 FT 2~44 9~40 ,v, 970.0281 M ** mILE TRAILER FILE NAME: MAIN .001 SERVICE NAME: VERSION # : :1t DATE: 85/1t/ MAXIMUM LENGTH: 1024 FiLE TYPE: LO NEXT FiLE NANE: ** FiLE HE~OER FILE NAME: REP SERVICE N~ME: VERSION ~ : 1 DATE: 85/11/2e MAX RECORD LENGTH: FiLE TYPE: LC PREVIOUS FILE NA~E: # 2 ** I ,002 1024 ~YTES . 6.038 1C.063 5.835 0.043 41 .38~ 16,382 £ .OZ! 12.31~ 7.948 0.111 15.543 7.873 -C.0~4 37.638 7.39C · ., .071 7.627 16 · 01/-,, CAL SP RIL~' CAL SP RiLN CAL SP RILR CAL SP RIL~ CAL SP RILM CAL SP RILM 18.031 -197.792 7.3~3 16.268 -188.586 t6.689 15.2,31 -20E 36z . !5.454 -232.7£5 7.530 14.651 -245.167 6.149 13.620 -249.~21 11 .7o0 MNEM APIN : CN : WN : FN : COUN : STAT : L,.,~ : CONTENTS AMOCO PRODUCTION CO. MGS 17595 NO 20 MIDDLE GROUND SHOAL KEN.&I ALASKA ** FORMAT bt -~ NiT~ Im~ mmmm ENTRY BLOCKS TYPE ENTRY CESCRiPT!ON 4 I DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 13 ~AXIMUM FRAMeS/RECORD O TERMINATOR -0.5C0 LEVEL SPACING DATUM SPECI:IC4TION BLOCKS CURVE REPR NAME CODE SIZE SAMPL SSD 88 4 t CAL 68 4 1 LSN 68 4 1 TTEN 68 4 1 SPO 68 4 1 CORR 68 4 1 SP 68 4 1 C~L1 68 4 1 R!LM 68 4 1 E UNITS CPS IN CPS F/MN G/C3 MV iN OMMM ** FORMAT ** CURVE NAME LSD SSN GR TEN DEN CN GR1 RiLD REPR CODE d8 SIZE 4 4 SSMPLE 1 1 1 1 1 1 1 1 1 UNITS C~S CmS G/CZ C CHMM FNTPY :LOrK¢ TYPE 4 1 8 6C.0 9 .I!N 11 13 0 -0.500 DATUM ENTRY ~ESCRiPTiON DEPTHS DECREASE F R A~, E SPACING ~AN~_ ,. SPACTNG. UN~'TS M~XIMUM F-R~MES/RECORD TERMINATOR LEVEL SPACING SPECIFICATION BLOCKS CURVE REPR NAME COOE SIZE S4MPLE UNITS sso 68 4 1 cps CAL 68 4 1 IN LSN 68 4 I CPS TTEN 68 4 1 SPD 68 4 I :/MN CURVE NAME LSD SSN GR TEN DEN REPR CCC:~ 4 4 4 SAMPLE 1 1 1 1 1 UNITS CPS CPS APZ L%F G/CS CALl 68 4 I iN RIL.H 68 4 I C ~'-iH mFOC RIL~' DATA ** DEPTH 7,~9~, ...CC":u FT. 2x46~.¢'~5-~C,, M :SD 40Q g5~ LSD s~ 974 LSN 197.980 GR 40.788 SPD 10.9¢9 ~EN 2,3E? ~D ~,,0.80~ G~I ~.~ hOC RZLM 999o~ O~ ,,. ~ RILO 46~96.000 C&L TTEN ? ~ORR CALl DEPT~ 7600.C:OO FT 2316.4850 M SSn ~48,466 LSD 199 12~ LSN 145.735 GR 63.46~ S~D~ 24,056 D~N SP 96.317 GR1 56.u~, RILM 9. 196 RILD 8.37 CAL TT ~hi CORR CALl O~PTH 7500,000 FT 2286,0050 M SSD 467.475 LSD LSN 73.315 GR SPD ~4.196 DEN SP 59.~42 G~I RILM. 36.77~_.~ RTLD~ 397.S63 23.883 1.819 34.168 1,3.903 CAL TTEN CORR CAL! O'PTH 7400 .CC'" FT ~P~5... SS3 33o,9~g LSD LSN 216,79~ GR SmD. .m4. 609 3EM ~D ~4 C~2 G~-I RiLM 7.380 RILE: "" A TT2N "nR F4' C .~ L 1 C=~TH~.. 7x78.~''n. ¢ _. ~ ,_, FT -m~4~.o?IC. , ,.," SSD 336.963 LSN ~! 6 7~~ SP $4. PiLM 7.300 LSD DEN ~i'L~ 795 CAL Ir.'O TT~N 2.5C7 CC.~R .~94 CaLl 7.27C ~T&~TTN& DE~Th = 7498 nG0 FT ENDING DEPTH = 7378.500 FT 2346.355:0 M 2248.97!0 M 1! .,36~_ 2342.1~5 C.147 C.OCC t4.342 3229.841 ,C~1, C.173 16.1C( 3246.4~4 -0.053 C.1~I C,05¢ C.183 1L.450 3123.297 C.1Fj3 SSN TEN CN RFOC S SN TEN CN RFOC SSN TEN CN RFOC S SN TEN CN RFOC S SN TEN CN RFOC 307.95~ ~4 251 2C.751 9c999. 2~3 5~ -137.262 25. '?,5~ 7.046 1R3.359 -14.070 5C.J2~ ~.775 3 37. - c 1 -gC.Sq3 ~r, 75~ 6.~7~ ?~'7 ,241 -J C. 5 ~ ~ 20 7'~ . .J ,._ 8.,472 ** FILE TRAILER ** FiLE NAME: REP I .002 SERVICE NAMe* VERSION ~ : 1 D&T~: 85/t!/ MAXIMUM LENGTH: 1024 =ILE TYPE: LO NEXT ~ILE NA~E: ** FTLF-.,. M:ADI:::R_ FILE NAME: REP SERVICE NAME: VERSION ~ : 1 DATE: 85/11/20 # 3 ** 2 .003 PREVIOUS FILE NA~E: . ** iNFORMATION RECORDS ** MNEN CONTENTS APIN : 50733 CN : AMOCO WN : MOS 1 FN : MiDDL COUN : KEN~I STAT : ~LASK LCC : 1 PRODUCTION CO, 7595 NO 20 ; GROUND SHOAL 50.00 ** FORMAT UNITS ENTRY BLOCKS TYPE ENTRY 4 1 8 6C,0 9 ,tIN 11 19 0 -0.500 CATUM SPECI CURVE NAME DESCRIPTION CILD GR TTEN SOD RILM ~EDTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM ~RAMES/RECCRD TERMINATCR L~VEL SPACING FIXATION ~ v . ~LOCKS REPR COD: SIZE SAMPLE ~NZTS 6~''~ ~ I MMHC,, 68 4 I API 68 4 I F/:PN 68 4 I US/F 68 4 1 OHMM ** FORMAT ** CURVE NAME SP CAL TEN ACC R:OC RILD REPR CC~-= I I I t 6~ SIZE 4 4 SAMPLE 1 1 1 1 1 1 UNITS PV LgF- L~ C~MM GriMM ENTRY BLOCKS DATUM..qP:CTFIC-~T'rON-~ .. . BLOCKS CURVE ~EPR CURVE R~PR NAME CODE SiZE SAMPLE UNITS NAME COlE SIZE SAMPLE UNITS i I I I i I I I III I I III CILD 68 :4 I MMHC SP 68 4 1 MV GR 6g 4 I API CAL 68 4 1 IN TTEN 68 4 I LBF TEN 68 4 1 L~F S~D 68 4 t F/MN ACQ ~ 8 4 1 Z I TYPE ENTRY DESCRIPTION 4 1 D:OTHS~, DECREASE~ 8 60.0 FR4ME SPACING 9 ,I!N FRAME SPACING UNITS 11 19 MAXIMUM FRAMES/RECORC 0 TERMINATOR -0,5C0 LEVEL SP~CZNG DEPTH 9655.C00'FT .2942.85CC M CILD 0.CO0 SP 0,CCO TTEN 0-C00 TSN C.CO0 AC 0.000 RFOC 0.000 DEPTH 9600,000 FT 2926.0860 M CILD 19.371 S~ 2 TTEN 4479.637 TEN 77 AC 89.510 RFCC 4 9.170 9.644 3 D~PTH 9c0n n~O FT 2895 606C M ClLD 33.740 S° 36 TTEN 4278.730 TEN 58 AC 70.478 RFOC 26 '~95 .184 ,807 DEPTH 9400.C:C0 FT 2865.1260 N CILD 38.246 SP 10 TTEN 4271.789 TEN -10 AC 88.703 RFOC 35 .427 .8~+3 DEOTH 9~00 ~ , .... u~CO ~T 2834,6~60 ~ CILD 44.219 SP 56 TTEN. 4219.5o0, T~N -~!~ AC 70.C95 RFOC 18 .914 .1~,~ .~21 DEPTH 9200.000 FT 2804,166C M CILD O.O00 SP TTEN 0.000 TEN 'AC O.CCO RFOC 0 .CCO 0 ,CCC DEPTH 9100.~u0 FT 2773.6~,~C ~ CILD O.CO0 SP u ~ · TTEN, 0.000 TEN u.."* no0 AC O.CO0 RFOC O.OOO DEPTH 9000.000 FT 2743.2060 M CILD O.OO0 Sm O.C0O TT:N :0.CO0 T~N O.CO0 ~C 0.000 RFOC O.CCO DEPTH 8900.000 FT 2712,7260 M CILD n~. COO S® TTEN O.OO0 TEN AC O.~nO0 RFOC C. DEPTH 8800.C00 =T 2682.2450 M CILD O.CO0 SP TT;N 0.O00 T=N ~C O.COO RFOC C.O00 O.O0*~ O.CCO CEPTH 8700,C00 FT 2651.7550 M GR SPD RILM ~R SPD RILM SPD RILM GR SPD RiLM GR SPD RiLM GR SmD R~LM GR SPD RZLM GR SPB RILM GR RiLM GR SPD R ILM C,OCC C .oeo ~,.OCC 64.666 4! .29E ~ 6~9 59.87C 48.505 24.73C 46.140 47.973 24.742 1C7.07C 49.142 22.6~2 C.OCC ~.OCC 8.0CC C ,OCC C.O~C C.OCC C.OCC O.OCC C .OtC C.OCC C.OCC nCC C ~..0CC C.OCC C~L ~C~ RiLD C~L ACG RIL~ C4L RILD CfL ~ C ,~ RILB C~L RILC C~L ACQ RIL~ CSL ACQ RILG C,4L ACQ ~ILC C~L RiLC C~L ~C~ RILD O.OOO 8.072 ~1 624 8.~25 C.O00 29.6~8 7.~76~ 0 26.147 8.692 .~.000 22,615 C.O00 C.~nO C.O00 C.OO'J C.OOrj O.OOC 0.300 0.000 C,O00 0.000 C.OO0 C ,Or,r` u. TTEN O,C00 TEN 0,000 ~C 0,000 R;OC 0,00O ~ILD 0.0~0 Sm 0 TT~N O.CO0 TEN 0,CCC AC O,CO0 RFOC O,0O0 0EPTH 8500,000 FT 2590,805~ M CZLD 0.000 SP TTEN 0.000 TEN AC 0.000 RFOC 0EOTH ~400 0C0 =T 2550 3250 M CILD O.CO0 SP 0 TTEN O,CC0 TEN O ~C 0,C00 R~OC 0 OEPTM 8300,000 FT 2529,8450 ~ CILD O.CO0 SP O TT N 0 ~0u TEN 0 ~C 0,000 RFOC 0 O:~TH ~200 mm0 ~T 2499 365C M CZLD 0.000 S~ 0 TTEN 0,000 TEN AC 0 C~ · uu RFO~ 0 DEPTH 8100,000 FT 2468,8850 M CILD O,mn uuO Sm n TTEN O.C00 Tr-N 0 ~C O.CO0 Rr-OC 0 DEPTH 8000,000 FT 2438,4050 M CILD O.CO0 Sm 0 TTmN m hmo TEN 0 ~C 0 0nn . wu RFOC 0 ¢ ' ~¢ FT P407.9250 u ~EPTH 7900.U~,. . ,, CZLO O.O00 SP 0 TTEN O.CO0 TEN 0 AC O.CO0 RFOC 0 DEPTH 7800.000 FT 2377.4450 mm~ml~em CZLD 0.000 SP TTEN 0.C00 TEN AC 0.000 RFOC OEPT~ 7700,000 FT 2346,9650.M mmmmm mmmmm mmmm mmm m ~mmmmmmmmmmm m CILD 0,000 SD 0 TTEN 0.000 TEN 0 ~C O.C00 ~FOC 0 0=PTH 7~0O,0C-0 FT 2516.4850 M 0,C~0~ u,OOC' ,OO0 .COO .Oar' ,00O ,C00 ,000 · ,000 · 6. 0""u .CO0 .L. UU ,O00 ,COO ,0O0 .0C0 ,COO · L, OO SPD RILM GR SDD RILM SPD R..,.T L M GR SPD RILM OR RILM GP RiLM SPD RILM GR SmD 2 iLM OR SPC RILM SPD RILM GR Sp~ RiLM C ~r, C.OCC C .OOC ~ 0~ C..0CC C.OCC C.OCC C.OCC C.OCC C 0m F'. O~'C,. C.OCC r OOC C · OC6 C.OCC C.OCC C C.CCC C.OCC ~.uCC C.OCC C.OCC C.OCC '.OCC C.OCC C.OOC O.OCC C.OCC C.OOC C .OCC C.000 C.OCC RIL5 CAL &CQ ~TL~ C/~L &CQ RILD CAL AC~ RiLD CAL RILC C~L RILC C~L ~!LO C~L RILO CAL ACQ RILD CAL ~C~ RILD CAL ACQ RiLD 0,000 C 0 0.000 '~ OOO C.CCO O,000 0.000 O,000 0.300 r. 0 ~ '~ C.OOg ~.CO0 C.COC C.OOO COO .O0O C "nO ;.GOO C.OO0 C.OCC C.CO0 C.OOO O.CO© 0.000 ~.UOG C. C.O00 C ,000 TTEN 0.000 TEN AC 0.000 RFOC SPD RIL~ DEPTH 7575.5C0 FT 2309.017C_M ii CiLO O.COO SP O.O00 TTEN 0 000 Tm` ... ~N O CO0 AC 0.000 RFOC O.OCO GR SPO R!LM STARTING DEPTH = 9655.000 FT ENDING DEPTH : 7575.500 ~T 2942.8500 2309.0170 ** FILE TRAILER FILE NAME: REP SERVICE NAME: VERSION # : 1 ,'5-'-ATE: 85/11/ MAXIMUM LENGTH: FTL: TYPF: LO NEXT FILE NAME: 2 .003 1024 ** FILE HEADER # 4 ** mILE NAME: CH GR .004 S:RVICE NAME: VERSION # : 1 DATE: 85/11 ~AX RECORD LENGTh: FILE TYPE: LO PREVIOUS FILE NAME: 1024 BYTES ** INFORMATICN RECOROS ** MNEM CONTENTS APIN : 5073320388 CN : AMOCO PRODUCTION CO, WN : MGS 17595 NO 20 FN : MIDDLE GROUND SHOAL C OUN: KENaI STAT : ALASKA LCC : 150.00 ** ~ORMAT ** UNITS TYPE 4 9 11 0 DATUM CURVE NAME ENTRY BLOCKS ENTRY EESCRIPTiON 1 DEPTHS DECREASE 6~.0 FRAME SPACING .lIN FRAME SPACING UNITS 127 M~XIMUM FRAMES/RECORD TERMINATOR 500 LEVEL SPACING SPECIFICATION BLOCKS REPR CODE SIZE Imm/ m~II SAMPLE bNiTS C.OCC C.CCC C .OCC £.0CC C .gCC ACQ RILB ~AL AC.Q RILC 0.000 C.OOC C.OOC C.O00 ** FORMA:T ** ENTRY BL TYPe ENTRY m imm ~ 6r' 0 9 .lIN 1t 127 0 --OI 500 OCKS DESCRIPTION DEPTHS mErREAqr- ~ RA~.~ E SPACING FRAME SPACING UNITS N~XIMUM I=RAM:S/RF-COR · ,_ TERMINATOR LEVEL S~CING GATUM SPECIFIC CURVE REPR NAME CODE ** DaTA ** ATION BLOCKS SZZE SAMPLE UNITS 4 I AP1 DEPTH 3300.000 :T 1005.842C M GR 54.140 3~PTH 3~0~ _ u.C:O0 FT 075. 3621 GR 47.651 DEPTH 3!00.C00 FT 944,8818 GR 31.121 ~PTH~ 30OO.mO0.. ~T 914.4019 M GR 22.913 OEPTH 2900.000 FT 883.9219 M GR z3.ao2 DEPTW 28~J.CC0 FT 85.3 441f r, GR 19.128 DEPTH. 27C0.CCC,:- FT 822.Q6t7 M GR 15.859 DmPTH. 2600.0mm~u mT: 792.q8t7 M '~R 31 144 DEPTH 2500.0G0 CT 762.0015 M GR 22.389 DEPTH 2~00.000 FT 731.5215 GR 29.368 ~PTH 2~00~ .C00 ~T 701.0415 M OR =7 DEPTH 2000.000 FT 509.601~ M GR 28,125 CEPTH 19GO,CCO FT 579,1211 M i I i il i i i ~ i iii i ii ! i i l~i GR 27,458 C-; PTH. 1 ~00 . COO ~T. ,-~4~,~.~'~411 M GR 12.293 DEPTH 1700.6'00 FT 518.1'61t M 28.811 · '""EPT~ 1~C000n FT 487 5809 "."' ,i,.i GR 28.768 DEPTH 1500.CC0 FT 457.2009 M ~ ii! GR 22.104 ;...,; ~_. : , ,, . . -_ :T 4P0.72~c M GR 26.549 CEPT~ 13GO.COO 396.2437 GR CEPT~,, 120Lq,.C""'"u:~' FT. . 36S.7507, , CEmTH 1!GO.COO 2S.4~7 DEPTH 900,COO =T 27z,.3206 M GR 31.047 DEPTH ~OO.COO FT GR 24.946 DEPTH TOO.COO FT 243,8405 M 213.3604. M 3n.887 6R 13.190 DEPTH 500.CCC FT 152.4003 I.,I GR !8.160 ~EPT~; 400.OEO FT iiIi i i liII ! ill ! ! I ii I I i I i GR 15.898 D=pTM ~n CCC ~T 121 c2~ mi .4402 GR 16.029 DEPTH 200.CC0 FT e0.9601 GR DEPTH DEPTH 13.6q3 100.CC0 FT 30.4801 14.704 8~.50n. 25.7556 GR 14.507 STARTING DEPTH = 3300,000 ENDING DEPTH = 84.500 FT FT 1005.8410 ~= 7556 ~I . ** FILE TRAILER ** FiLE NAME: CP GR .004 SERVICE N&~E: VERSION # : 1 DATE: 85/1t/ MAXIMUM LENGTH: 1024 FiLE TYPE: LO NEXT FILE NAME: ** TAPE TRAILER ** TAPE NAME: SERViC¢ NAME: CH GR DATE: ...... ORIGIN OF DATA: =SYS TA~E CONTINUATION # NEXT T~PE NA~E: COMMENTS: : 01 ** REEL TR~IL~R ~* REEL NAME: SERVICE NAME: BITLIS DATE : ...... ORIGIN O~ DAT~: FSYS REEL CONTINUATION # : 01 NEXT REEL N~NE: COMMENTS: ORE$SER ATLAS LIS CUSTOMER REEL HEADER - 1 TAPE HEA~ER - 1 FIL~ HEADER - 4 INFORMATION - 4 FORMAT - ~ CRE~TEC SDS PROGRAM 2.0 FZLE TRAILER - 4 TAPE TRAILER - 1 REEL TRAILER - I TOTAL RECORDS: 1068