The URL can be used to link to this page

Home My WebLink About167-017Nolan 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 11 50733200130000 167017 8/17/2025 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' 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. From:McLellan, Bryan J (OGC) To:Juanita Lovett; Casey Morse Subject:RE: MGS ST 17595 11 - PTD: 167-017 - Sundry #"s 324-365 & 325-260 Date:Monday, September 15, 2025 11:02:00 AM Juanita, Yes, Hilcorp can close both sundries with a single 10-407. Please note the Suspension expiration date noted on Sundry 325-260 is 6/1/2030. The Suspension box should have been checked on this sundry. Please indicate the well classification as Suspended on the 10-407. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Juanita Lovett <jlovett@hilcorp.com> Sent: Friday, September 12, 2025 10:45 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Casey Morse <Casey.Morse@hilcorp.com> Subject: MGS ST 17595 11 - PTD: 167-017 - Sundry #'s 324-365 & 325-260 Good morning, Bryan, There are two sundries associated with the work performed on this well. Sundry # 324-365 requires a subsequent 10-404, and sundry # 325-260 requires a subsequent 10-407. Would it be acceptable to close both sundries with a single 10-407? Thank you, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com 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 deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:9543 ft MD Lease No.:ADL 0017595 Operator Rep:Suspend:X P&A: Conductor:20"O.D. Shoe@ 622 Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 2976 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9-5/8"O.D. Shoe@ 9540 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 9474 Feet Csg Cut@ Feet SS Tubing:2-7/8"O.D. Tail@ 7279 Feet Tbg Cut@ Feet LS Tubing:2-7/8"O.D. Tail@ 7340 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Long String Fullbore Bottom 7240 ft See Remarks 9.8 ppg Wireline tag Short String Fullbore Bottom 7240 ft 4443 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result LS Tubing 2555 2476 2437 SS Tubing 2555 2476 2437 IA 2555 2476 2437 OA 24 24 24 OOA 14 14 14 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Brad Whitten Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Due to pump issues when starting cement the LS string cement top is 46 inches from top of wellhead, and was able to see good cement. SS tag was good with good cement sample. MIT pass; 2.25 bbls pumped and 2.1 bbls returned. Well left as Suspended. August 23, 2025 Kam StJohn Well Bore Plug & Abandonment MGS ST 17595 Baker-11 Hilcorp Alaska LLC PTD 1670170; Sundry 325-260 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0823_Plug_Verification_MGS_State_17595_Baker-11_ksj                           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? Yes No 9.Property Designation (Lease Number):10.Field: Middle Ground Shoal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,543 9,041 Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate Production 3,090psi Liner 7,020psi 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: CT, Cementing Middle Ground Shoal Oil N/A 9,273 ~6,193 (SS) ~5,937 (SS) 2511 See schematic 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 8,160psi 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 167-017 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20013-00-00 Hilcorp Alaska, LLC MGS ST 17595 11 Length Size Proposed Pools: 450 450 6.4# / L-80 (LS) & 4.6# / L-80 (SS) TVD Burst 7,340 (LS) & 7,279 (SS) 5,750psi MD 1,530psi 2,730psi 622 2,951 622 2,976 450 30" 20" 13-3/8" 622 2,976 See schematic 9,540 7" See schematic 9,2709-5/8" N/A 6/1/2025 9,4743,762 2-7/8" (LS) & 2-3/8" (SS) 9,204 N/A & N/A N/A & N/A 9,540 Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:25 pm, Apr 25, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.25 13:55:01 - 08'00' Dan Marlowe (1267) 325-260 10-407 A.Dewhurst 23MAY25 DSR-4/29/25 6/1/2030 XX BJM 5/7/25 BOP test to 3000 psi. Run CBL to confirm TOC in IA after cleaning out. Submit CBL to AOGCC and obtain approval before cementing. Provide AOGCC notice for opportunity to witness CMIT LSxSSxIA and TOC tag in LS & SS. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.28 14:41:20 -08'00'5/28/2025 RBDMS JSB 052925 P&A Program Well: Ba-11 Well Name:MGS ST 17595 11 (Ba-11)API Number:50-733-20013-00-00 Current Status:Shut-In Producer Rig:SL, EL, CT, cement Regulatory Contact:Juanita Lovett First Call Engineer:Casey Morse 907-777-8322 603-205-3780 (M) Second Call Engineer:Eric Dickerman 907-564-4061 Current Bottom Hole Pressure (est):2757 psi @ 7045’ TVD (Ca. 2007 SBHPS, EMW: 7.6 ppg) Max. Potential Surface Pressure:2511 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA):vac/vac/vac/30/8 psi History Drilled and completed in 1967 and put on production as an oil producer. Workovers were performed including acidizing, plug-backs, perf adds, squeezes, and recompletes. The well was SI in 2003. It was then circulated with 9.8 ppg brine and a 40 bbl pill of LCM was pumped to plug off the perforations. The LS, SS, and IA were freeze-protected with diesel. 20” Casing set @ 622’ MD. Mixed & pumped 185 sxs (577 cf) Class G w/ 33# diagel D per sx of cmt mixed at 12 ppg. Mixed 1100 sxs (1223 cf) Class G w/ 4% CACL2. Lost returns last 130 sxs. Tagged 32’ down annulus, filled to top with 20 sxs sand and 40 sxs cement. 13-3/8” Casing set @ 2975’ MD. Mixed & pumped 600 sxs (2280 cf) Class G w/ 33# diagel D per sx of cmt 1/4 # /sx flocele mixed at 11.2 ppg. Mixed 2050 sxs (2300 cf) Class G neat mixed at 15.8 ppg. Mixed 600 sxs (690 cf) Class G w/ 2% CACL2, 1/8# /sx Flocele mixed at 15.8 ppg. Lost returns after pumping 65% of neat cement – no returns while pumping plug. Cement did not circulate to surface. 9-5/8” Casing set @ 9543’ MD. Cement: First stage 500 sacks Class G w/ 4% HR-7 and 1% CFR-2, 800 sacks class G w/ 1% CFR-2. Second stage 500 sx class G w/1% CFR-2 and 500 sx class G. CBL TOC 4620’ MD. 9-5/8” Production Casing bowl/patch set at 2522’ and tested to 1500 psi (3/9/83) after well was drilled into while drilling Ba-25. MGS 17595 well 11 (Ba-11) was drilled into while drilling 12-1/4” pilot hole of Ba-25 at 2503’. Drilled through 13-3/8’, 9-5/8” and 3-1/2” tubing on Ba-11. An open hole cement plug was set, plugging back to 1688’ on Ba-25, and sidetracked to surface casing point at 3521’. Current Status On October 1, 2024, the well was bled down and displaced to 9.8 ppg brine. On October 2, 14 ppg cement was pumped down the LS intermittently while fighting pump issues. A total of 247 bbls cement were pumped with partial returns up the IA. 155 bbls of brine were returned from the IA during pumping operations. Ultimately, the pump stopped working. The suction side of the pump had valves stuck to seats. After cleaning and reassembling the suction side of the cement pump, it function-tested successfully and was capable of circulating on itself. Several attempts were made to establish injection down LS, SS, and IA with no success. The SS was pressured up to 2000 psi trying to get returns on IA, then bled down and repeated 15 times with no success. P&A Program Well: Ba-11 The cement top was observed 4’ below the tree on the LS. Based on volumes pumped and circulated, the estimated cement top in the IA should be ~4600’ with 92 bbls squeezed into the perforations. On October 7, slickline made several attempts to acquire a cement tag in the SS. Repeated attempts encountered scale and restricted downward progress beyond 6198’. No cement was encountered, and the tags were unreliable. The decision was made to rig down for the winter prior to conducting witnessed MIT and tags. Pre-P&A Diagnostics Performed 1. Initial pressures (LS/SS/IA/OA/OOA): 282 / 1100 / 1120 / 25 / 10 psi 2. Pump 8.6 ppg FIW: a. Pump down LS up IA, FCP=630psi/2.7 BPM b. Pump down IA up LS, FCP=330psi/2.7 BPM c. Pump down IA up SS, FCP= 900psi/2.7 BPM d. Pump down SS up IA, FCP=1250psi/2 BPM e. Pump down SS up LS, FCP=1400psi/2BPM f. Pump down LS up SS, FCP=1250psi/2 BPM 3. Inject down LS, 1BPM/800psi, 1.5BPM/925psi, 2BPM/1050psi, 2.5 BPM/1225psi 4. RU slickline. RIH w/ 2.3” gauge ring to 7292’ SLM, tag Kobe BHA. POOH 5. RIH w/ 2-7/8” D&D Holefinder to 7250’ SLM, attempt to set, slips won't engage, work up hole in 10' increments until setting at 7171' SLM. Pressure test LS to 570psi, no change in 5 min.-good test. POOH. Objective Plug and abandon the MGS Oil Pool in the Ba-11. Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (D). Hilcorp requests to cement by downsqueeze method using the existing completion in place of a mechanical cement retainer or production packer. The base of the proposed P&A plug will be squeezed into and across the perforations from the end of tubing at 7339’ MD. There is only one Pool between that depth and the top of the lowest open perforations at 7850’ MD, the Middle Ground Shoal Oil Pool as defined in Conservation Order 44 A. Procedural steps Fullbore – Completed Oct 2024 1. Fluid pack the tubing 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 Tbg and out IA) ¾ 194 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down LS and out IA ii. After 163 bbls returned from IA (IA cement volume of 120 bbls plus LS displacement of 43 bbl), close IA and open SS iii. Return 18 bbls from SS, close SS valve iv. Pressure up on LS (max of 1500 psi on LS/SS/IA) and pump remaining cement ¾ Foam Wiper Ball ¾ 27 bbls of 9.8 ppg brine displacement of cement (puts TOC in LS @ ~4600’, equivalent with IA/SS) P&A Program Well: Ba-11 ¾ LS volume from tubing tail to 4600’: 0.0058 bpf * (7340’-4600’) =16 bbls ¾ SS volume from Kobe to 4600’: 0.0039 bpf * (7287’-4600’) =10 bbls ¾ IA volume from punch to 3500 = 108 bbls o 7340 to 7287: 0.0291 bpf * 53’ =1.5 bbls (tubing tail x liner) o 7287 to 5712: 0.0236 bpf * 1575’ =37 bbls (LS/SS x liner) o 5712 to 4600: 0.0623 bpf * 1112’ =69 bbls (LS/SS x 9-5/8) ¾ Liner volume from tubing tail to 8405’: 0.0371 bpf * (8404’-7340’) =40 bbls Total Cement Volume with 10% excess: 194 bbls ¾ LS volume from 4600’ to surface: 0.0058 bpf * 4600’ =27 bbls ¾ SS volume from 4600’ to surface: 0.0039 bpf * 4600’ =18 bbls ¾ IA volume from 4600’ to surface: 0.0623 bpf * 4600’ =287 bbls Coil Tubing 1. MIRU Coiled Tubing and pressure control equipment on short string. 2. PT lubricator to 250 psi low / 3000 psi high 3. MU cleanout BHA and clean scale / debris down to encounter good cement or end of the SS at 7,279’. a. Working fluid will be 9.8 ppg brine b. Take returns to surface up the CT x tubing annulus 4. MU cement nozzle BHA 5. RIH to cleanout depth and tag. PU off bottom ~10’ and confirm circulation. 6. Pump abandonment plug as follows: a.11 bbls 14 ppg cement monitoring return volumes b. Displace cement out coil and pull up above the cement top. Ensure cement is circulated out of coil c.Estimated TOC ~4600’ Fullbore/Slickline 1. CMIT LSxSSxIA to 2350 psi (AOGCC Witnessed). 2. Tag TOC in LS and SS (AOGCC Witnessed). Cement Tops: x 13-3/8” Casing o Annulus volume: 404 bbl 2976’ to 622’: 2354 ft * 0.1237 bpf = 291 bbl 622’ to surf: 622 ft * 0.1815 = 113 bbl o Cement volume: 2280 cf (406 bbl) of 12 ppg 2300 cf (410 bbl) of 15.8 ppg neat (lost returns after 65% of this stage) 690 ft (123 bbl) of 15.8 ppg w/ CaCl2 o 13-3/8” ID volume: 458 bbl 2976’ to 1993’: 983 ft * 0.1522 bpf = 150 bbl 1993’ to 66’: 1927 ft * 0.1546 bpf = 298 bbl 66’ to surf: 66 ft * 0.1522 bpf = 10 bbl o Cement placed into annulus before losing returns: 215 bbl 406 + (65% * 410) = 672 bbl Run CBL to confirm TOC in IA after cleaning out. Submit CBL to AOGCC and obtain approval before cementing. -bjm P&A Program Well: Ba-11 672 – 458 = 215 bbl o Calculated cement top:1398 ft 215 bbl / 0.1237 bpf = 1736 ft 1736 / 110% = 1578 ft 2976’ – 1578’ = 1398 ft x 9-5/8” Casing o CBL on record with AOGCC T# 34808 Attachments: 1.Current Schematic 2.Proposed Schematic 3.Coil Tubing BOP Diagram Updated by: CDM 10/16/24 SCHEMATIC Middle Ground Shoal Well: Ba-11 (MGS ST 17595 #11) Last Completed: 11-4-1997 PTD: 167-017 API: 50-733-20013-00 PBTD =9428’ MD TD = 9543’ MAX HOLE ANGLE = 28.75O @ 3700’MD 30” MGS Oil Top 5730’ Perfs behind 7” casing 5840’ - 6850’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 9540’ TOC CBL 4620’ 9.8 ppg brine 2522’ Casing Bowl Calc TOC 1398’ 20” 622’ 13-3/8” 2976’ 7” 5712’ Fill: 8404’ MGS Gas Base 4779’ Perfs 7850’ - 9050’ Perfs 5740’ - 5780’ Perfs 7105’ - 7115’ 247 bbl cement pumped, Est TOC in IA ~4600’ TOC @ surf in LS TOC >6193’ in SS 9.8 ppg brine Completion Jewelry Detail # Depth ID OD Item Long String 1 31 CIW 11” 5M, DCB Tubing Hanger 2 32 2.438 3.438 Crossover, 3-1/2” Buttress P x 2-7/8” Buttress Pin 3 7,276 2.441 2.875 Crossover Pup, 2-7/8” Buttress B x 2-7/8” 8 Rnd 4 7,287 2.25 5.626 KOBE, 2-1/2” Type B Parallel, Pump Cavity 5 7,306 2.441 3.625 Crossover, 2-7/8” 8Rnd B x 2-7/8” Buttress P 6 7,339 2.437 3.437 WREG, 2-7/8” Buttress B Short String A 31 2.438 3.438 Crossover 3-1/2” Buttress P x 2-3/8 Buttress P B 7,279 1.625 2.7 Crossover, 2-3/8” Buttress B x 1-1/2” 10 Rnd P C 7,280 1.375 1.625 Pup, 1-1/4” 10 Rnd KB: MSL Mean Sea Level Mud Line Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments A 5,740' 5,780' 5,488' 5,527' 40' Cement Sqz'd A,B,C,D 5,840' 6,850' 5,587' 6,589' 1,010' Behind 7" casing E,F,G 7,105' 7,115' 6,841' 6,851' 10' Cement Sqz'd E,F,G 7,415' 7,800' 7,150' 7,533' 385' Cement Sqz'd E,F,G 7,850' 9,050' 7,583' 8,781' 1,200' Cement Sqz'd Fill @ 8,404' Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm 30” Structural 1.0” Wall 29 Surf 450 20” Conductor 94#, H40, Vetco 19.124 Surf 622 13-3/8” Surface 61#, K55, STC 12.515 Surf 66 54.5#, J55, STC 12.615 66 1,993 61#, K55, STC 12.515 1,993 2,976 29.8º 9-5/8” Intermediate 40, S95, BTC 8.835 Surf 2,522 40, N80, BTC 8.835 2,522 5,316 40, S95, STC8RND 8.835 5,316 7,257 43.5,S95,STC8RND 8.755 7,257 9,540 7” Scab Liner 29, L80, BTC 6.184 5,712 9,474 Tubing Detail Long String 2-7/8" Prod Tubing 6.4, L80, BTC-SC 2.411 32 7,276 2-7/8" Tubing Tail 6.4, L80, BTC-SC 2.411 7,340 Short String 2-3/8" Prod Tubing 4.6, L80, BTC-SC 1.995 32 7,279 Notes 10/2024 Fullbore cement to abandon MGS Oil Pool 10/1/2010 Well circulated with 9.8 ppg brine. 8/7/2016 RIH w/2” GR to 8404’ KB, tag fill. Fish Top: 9041’ DPM National Type “V” Cavity and Tail Pipe Assy Updated by: CDM 10/16/24 PROPOSED SCHEMATIC Middle Ground Shoal Well: Ba-11 (MGS ST 17595 #11) Last Completed: 11-4-1997 PTD: 167-017 API: 50-733-20013-00 PBTD =9428’ MD TD = 9543’ MAX HOLE ANGLE = 28.75O @ 3700’MD 30” MGS Oil Top 5730’ Perfs behind 7” casing 5840’ - 6850’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 9540’ TOC CBL 4620’ 9.8 ppg brine 2522’ Casing Bowl Calc TOC 1398’ 20” 622’ 13-3/8” 2976’ 7” 5712’ Fill: 8404’ MGS Gas Base 4779’ Perfs 7850’ - 9050’ Perfs 5740’ - 5780’ Perfs 7105’ - 7115’ 247 bbl cement pumped, Est TOC in IA ~4600’ TOC @ surf in LS TOC ~4600’ in SS 9.8 ppg brine Completion Jewelry Detail # Depth ID OD Item Long String 1 31 CIW 11” 5M, DCB Tubing Hanger 2 32 2.438 3.438 Crossover, 3-1/2” Buttress P x 2-7/8” Buttress Pin 3 7,276 2.441 2.875 Crossover Pup, 2-7/8” Buttress B x 2-7/8” 8 Rnd 4 7,287 2.25 5.626 KOBE, 2-1/2” Type B Parallel, Pump Cavity 5 7,306 2.441 3.625 Crossover, 2-7/8” 8Rnd B x 2-7/8” Buttress P 6 7,339 2.437 3.437 WREG, 2-7/8” Buttress B Short String A 31 2.438 3.438 Crossover 3-1/2” Buttress P x 2-3/8 Buttress P B 7,279 1.625 2.7 Crossover, 2-3/8” Buttress B x 1-1/2” 10 Rnd P C 7,280 1.375 1.625 Pup, 1-1/4” 10 Rnd KB: MSL Mean Sea Level Mud Line Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm 30” Structural 1.0” Wall 29 Surf 450 20” Conductor 94#, H40, Vetco 19.124 Surf 622 13-3/8” Surface 61#, K55, STC 12.515 Surf 66 54.5#, J55, STC 12.615 66 1,993 61#, K55, STC 12.515 1,993 2,976 29.8º 9-5/8” Intermediate 40, S95, BTC 8.835 Surf 2,522 40, N80, BTC 8.835 2,522 5,316 40, S95, STC8RND 8.835 5,316 7,257 43.5,S95,STC8RND 8.755 7,257 9,540 7” Scab Liner 29, L80, BTC 6.184 5,712 9,474 Tubing Detail Long String 2-7/8" Prod Tubing 6.4, L80, BTC-SC 2.411 32 7,276 2-7/8" Tubing Tail 6.4, L80, BTC-SC 2.411 7,340 Short String 2-3/8" Prod Tubing 4.6, L80, BTC-SC 1.995 32 7,279 Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments A 5,740' 5,780' 5,488' 5,527' 40' Cement Sqz'd A,B,C,D 5,840' 6,850' 5,587' 6,589' 1,010' Behind 7" casing E,F,G 7,105' 7,115' 6,841' 6,851' 10' Cement Sqz'd E,F,G 7,415' 7,800' 7,150' 7,533' 385' Cement Sqz'd E,F,G 7,850' 9,050' 7,583' 8,781' 1,200' Cement Sqz'd Fill @ 8,404' Notes 10/2024 Fullbore cement to abandon MGS Oil Pool 10/1/2010 Well circulated with 9.8 ppg brine. 8/7/2016 RIH w/2” GR to 8404’ KB, tag fill. Fish Top: 9041’ DPM National Type “V” Cavity and Tail Pipe Assy KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary Well Name:MGS ST 17595 11 API #:50733200130000 Field:Middle Ground Shoal Permit #:1670170 Sundry #:324-365 10/2/2024 10/7/2024 Weekly Operations Summary Continue displacing well w/ brine holding 500psi back pressure, pumping at 1.2 BPM, getting oil/gas returns. Opened choke after gas is out and increase rate to 2.5 bpm, 310psi, until 9.8 ppg brine returned, total bbls brine circulated around=577. Displace SS w/ brine at 2.3 ďƉŵ͕ϰϰϬƉƐŝ͘ƌŝŶĞĐŝƌĐƵůĂƚĞĚсϯϳďďůƐ͘/ŶũĞĐƚϮϲϯďďůƐǁĞůůďŽƌĞŇƵŝĚĚŽǁŶŝŶũĞĐƟŽŶǁĞůůĂͲϭϲĂƚϭ͘ϲWD͕ϭϰϬϬƉƐŝ͘ Batch up 14 ppg cement and pump down LS taking returns out IA at 3bpm, 10psi. Started losing prime/ability to pump cement, able to get 247 bbls cement pumped w/ 155 bbls brine returned. Open up caps on discharge side of fluid end, nothing apparent with pump issue. Attemt to get pumping again w/ no luck. Go through suction side of fluid end. Found valves stuck to seats. Clean and reassemble. Function test and was able to get pump to circulate on itself. Attempt to break circulation, pressured up to 1500psi. Open up SS and attempt to get returns from SS w/ same results. Open up both SS and IA, pressure up to 2000psi, bleed off and repeat (15 times) w/ no luck. Calculated 112bbls cement in IA, 92bbls squeezed w/ TOC ~4600', w/ LS full, and no cement in SS. Wash up equipment, secure well and SDFN. Rig up on Ba-11 SS, rehead, and change tool string. RIH w/ 1.75"x4' DD bailer, tagging at 6198' slm. Daily Operations: Page 1 of 1 Well Name:MGS ST 17595 11 API #:50733200130000 Field:Middle Ground Shoal Permit #:1670170 Sundry #:324-365 10/1/2024 Daily Operations: Weekly Operations Summary PJSM and PTW. Check well pressures: LS vac, SS 15 psi, IA 860 psi. Hook up circulating hoses. Bleed gas cap off IA, mix 9.8 ppg brine. Start displacing well w/ 9.8 ppg brine, circulating down LS and out IA. Circulated 325 bbls brine. Shut down for night. Page 1 of 1 1 McLellan, Bryan J (OGC) From:Casey Morse <casey.morse@hilcorp.com> Sent:Wednesday, May 7, 2025 2:54 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] MGS ST 17595-11 (PTD 167-017) suspension sundry Attachments:MGS St 17595 11 - Weekly Operations Summary 09-25-24 to 10-01-24.pdf; MGS St 17595 11 - Weekly Operations Summary 10-02-24 to 10-08-24.pdf Bryan, Last month’s reading showed pressures (LS/SS/IA/OA/OOA): 1 / 0 / 6 / 18 / 24 Attached are the weekly summaries of work, and below is the detail from the slickline report on 10/7. Time Operation Details Wireline Valve Size 3.5" 13:30 Rig Up on BA-11 (Short) - Rehead - Change toolstring - Spot up Unit 15:00 RIH w/ 1.75" x 4' DD Bailer to 5793'SLM (5788'KB -5 CF from previous WSR on long string) - W/T - Fall to 5948'SLM - W/T - Fall to 5980'SLM - W/T - Fall to 6040'slm - W/T - fall to 6074'slm - W/T - fall to 6105'slm - W/T - fall to 6136'slm - W/T - fall to 6167'slm - W/T - fall to 6198'slm(6193'KB) - W/T - cannot pass - pull 2 jarlicks come free - POOH - OOH w/ black scally water (Barely any solids mostly water) 18:00 Discuss plan forward - Rig down - Prep for move over to BA- 25RD in the morning 19:00 End of Ticket Casey Morse Operations Engineer Cook Inlet OƯshore Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, May 7, 2025 12:36 PM To: Casey Morse <casey.morse@hilcorp.com> Subject: [EXTERNAL] MGS ST 17595-11 (PTD 167-017) suspension sundry 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. 2 Casey, Can you send me the daily reports from last year’s wellwork activity on this well? Also, what are the current LS/SS/IA/OA/OOA pressures? 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. 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. 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 Other: ___________________ 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? Yes No 9. Property Designation (Lease Number): 10. Field: Middle Ground Shoal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,543 9,041 Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate Production 3,090psi Liner 7,020psi 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 N/A 6/30/2024 9,4743,762 2-7/8" (LS) & 2-3/8" (SS) 9,204 N/A & N/A N/A & N/A 9,540 Perforation Depth MD (ft): 5,740 - 9,050 9,540 7" 5,488 - 8,781 9,2709-5/8" 450 30" 20" 13-3/8" 622 2,976 MD 1,530psi 2,730psi 622 2,951 622 2,976 Length Size Proposed Pools: 450 450 6.4# / L-80 (LS) & 4.6# / L-80 (SS) TVD Burst 7,340 (LS) & 7,279 (SS) 5,750psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 167-017 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20013-00-00 Hilcorp Alaska, LLC MGS ST 17595 11 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager 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 Middle Ground Shoal Oil N/A 9,273 8,404 5,716 2511 N/A Perforate Repair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test No Wellbore schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:33 pm, Jun 21, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.06.21 13:39:09 - 08'00' Dan Marlowe (1267) 324-365 -bjm BJM 9/6/24 -bjm X DSR-6/25/24 10-404 X-bjm X -bjm No cement outside 9-5/8" casing across MGS gas pool. Only the Oil pool P&A is approved as part of this sundry. Provide 48 hrs notice for AOGCC opportunity to witness CMIT TxIA to 2350 psi. A.Dewhurst 09SEP24($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.12 13:18:28 -05'00'09/12/24 RBDMS JSB 091724 P&A Program Well: Ba-11 Well Name: MGS ST 17595 11 (Ba-11) API Number: 50-733-20013-00-00 Current Status: Shut-In Producer Rig: SL, EL, FB, cement Estimated Start Date: June 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): 2757 psi @ 7045’ TVD (Ca. 2007 SBHPS, EMW: 7.6 ppg) Max. Potential Surface Pressure: 2511 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA): vac/vac/vac/30/8 psi History Drilled and completed in 1967 and put on production as an oil producer. Workovers were performed including acidizing, plug-backs, perf adds, squeezes, and recompletes. The well was SI in 2003. It was then circulated with 9.8 ppg brine and a 40 bbl pill of LCM was pumped to plug off the perforations. The LS, SS, and IA were freeze-protected with diesel. 20” Casing set @ 622’ MD. Mixed & pumped 185 sxs (577 cf) Class G w/ 33# diagel D per sx of cmt mixed at 12 ppg. Mixed 1100 sxs (1223 cf) Class G w/ 4% CACL2. Lost returns last 130 sxs. Tagged 32’ down annulus, filled to top with 20 sxs sand and 40 sxs cement. 13-3/8” Casing set @ 2975’ MD. Mixed & pumped 600 sxs (2280 cf) Class G w/ 33# diagel D per sx of cmt 1/4 # /sx flocele mixed at 11.2 ppg. Mixed 2050 sxs (2300 cf) Class G neat mixed at 15.8 ppg. Mixed 600 sxs (690 cf) Class G w/ 2% CACL2, 1/8# /sx Flocele mixed at 15.8 ppg. Lost returns after pumping 65% of neat cement – no returns while pumping plug. Cement did not circulate to surface. 9-5/8” Casing set @ 9543’ MD. Cement: First stage 500 sacks Class G w/ 4% HR-7 and 1% CFR-2, 800 sacks class G w/ 1% CFR-2. Second stage 500 sx class G w/1% CFR-2 and 500 sx class G. CBL TOC 4620’ MD. 9-5/8” Production Casing bowl/patch set at 2522’ and tested to 1500 psi (3/9/83) after well was drilled into while drilling Ba-25. MGS 17595 well 11 (Ba-11) was drilled into while drilling 12-1/4” pilot hole of Ba-25 at 2503’. Drilled through 13-3/8’, 9-5/8” and 3-1/2” tubing on Ba-11. An open hole cement plug was set, plugging back to 1688’ on Ba-25, and sidetracked to surface casing point at 3521’. Current Status Shut-in. The well was circulated with 8.6 ppg FIW. Pre-P&A Diagnostics Performed 1. Initial pressures (LS/SS/IA/OA/OOA): 282 / 1100 / 1120 / 25 / 10 psi 2. Pump 8.6 ppg FIW: a. Pump down LS up IA, FCP=630psi/2.7 BPM P&A Program Well: Ba-11 b. Pump down IA up LS, FCP=330psi/2.7 BPM c. Pump down IA up SS, FCP= 900psi/2.7 BPM d. Pump down SS up IA, FCP=1250psi/2 BPM e. Pump down SS up LS, FCP=1400psi/2BPM f. Pump down LS up SS, FCP=1250psi/2 BPM 3. Inject down LS, 1BPM/800psi, 1.5BPM/925psi, 2BPM/1050psi, 2.5 BPM/1225psi 4. RU slickline. RIH w/ 2.3” gauge ring to 7292’ SLM, tag Kobe BHA. POOH 5. RIH w/ 2-7/8” D&D Holefinder to 7250’ SLM, attempt to set, slips won't engage, work up hole in 10' increments until setting at 7171' SLM. Pressure test LS to 570psi, no change in 5 min.-good test. POOH. Objective Plug and abandon the Ba-11. Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (D). Hilcorp requests to cement by downsqueeze method using the existing completion in place of a mechanical cement retainer or production packer. Cement will be circulated from the bottom of the tubing at 7339’ MD and up the IA and SS to a height of 4600’ MD. Once sufficient volumes are displaced out of the IA and SS, Hilcorp will close the IA and SS valves and downsqueeze to attempt to place cement across the lower perforations from 7850’ to the fill depth at 8404’ MD. The base of the proposed P&A plug will be no shallower than the end of tubing at 7339’ MD. There is only one Pool between that depth and the lower perforations at 7850’ MD, the Middle Ground Shoal Oil Pool as defined in Conservation Order 44 A. Hilcorp requests a variance to 20 AAC 25.112 (d) (1). Hilcorp requests that the surface cement plugs extend up to the wellhead and tree valves. This is to ensure the well is properly cemented and to avoid any uncertainty as to the cement top. The platform legs and wells will need to be severed completely at or near the seafloor to remove the legs eventually, and the extra cement in the casing strings should not impede this operation significantly. Procedural steps Fullbore 1. Fluid pack the tubing 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 Tbg and out IA) ¾ 194 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down LS and out IA ii. After 163 bbls returned from IA (IA cement volume of 120 bbls plus LS volume of 43 bbl), close IA and open SS iii. Return 18 bbls from SS, close SS valve iv. Pressure up on LS (max of 1500 psi on LS/SS/IA) and pump remaining cement ¾ Foam Wiper Ball ¾ 27 bbls of 9.8 ppg brine displacement of cement (puts TOC in LS @ ~4600’, equivalent with IA/SS) ¾ LS volume from tubing tail to 4600’: 0.0058 bpf * (7340’-4600’) = 16 bbls ¾ SS volume from Kobe to 4600’: 0.0039 bpf * (7287’-4600’) = 10 bbls ¾ IA volume from punch to 3500 = 108 bbls Surface plug is not approved as part of this sundry. -bjm P&A Program Well: Ba-11 o 7340 to 7287: 0.0291 bpf * 53’ = 1.5 bbls (tubing tail x liner) o 7287 to 5712: 0.0236 bpf * 1575’ = 37 bbls (LS/SS x liner) o 5712 to 4600: 0.0623 bpf * 1112’ = 69 bbls (LS/SS x 9-5/8) ¾ Liner volume from tubing tail to 8405’: 0.0371 bpf * (8404’-7340’) = 40 bbls Total Cement Volume with 10% excess: 194 bbls ¾ LS volume from 4600’ to surface: 0.0058 bpf * 4600’ = 27 bbls ¾ SS volume from 4600’ to surface: 0.0039 bpf * 4600’ = 18 bbls ¾ IA volume from 4600’ to surface: 0.0623 bpf * 4600’ = 287 bbls Fullbore/Slickline 1. CMIT LSxSSxIA to 1500 psi (AOGCC Witnessed). 2. Tag TOC in LS and SS (AOGCC Witnessed). E-line 1. RU perf guns on LS. Perf the tubing and casings @ ~500’ MD. Fullbore 1. Verify circulation down the tubing and out the SS / IA / OA / OOA. 2. Pump LSxSSxIAxOAxOOA cement plug ¾ 30 bbls RIW w/ surfactant wash down tubing ¾ Circulate 2x bottoms up from the OOA, OA, IA, SS (182 bbl, 64 bbl, 62 bbl, 4 bbl) ¾ 178 bbls 14 ppg Class G cement i. Circulate out the OOA until good cement returns are observed at surface, then swap to taking returns from the OA ii. Circulate out the OA until good cement returns are observed at surface, then swap to taking returns from the IA iii. Circulate out the IA until good cement returns are observed at surface, then swap to taking returns from SS iv. Circulate out the SS until good cement returns are observed at surface. ¾ LS volume from 500’ to surf: 0.0058 bpf * 500’ = 3 bbls ¾ OOA volume from 500’ to surf: 0.1815 bpf * 500 = 91 bbl ¾ OA volume from 500’ to 66’: 0.0646 bpf * 434 = 28 bbls (54.5 ppf) ¾ OA volume from 66’ to surf: 0.0622 bpf * 66 = 4 bbls (61 ppf) ¾ IA volume from 500’ to surf: 0.0623 bpf * 500’ = 31 bbls (40 ppf) ¾ SS volume from 500’ to surface: 0.0039 bpf * 500’ = 2 bbls Total Cement Volume with 10% excess: 178 bbls Cement Tops: x 13-3/8” Casing o Annulus volume: 404 bbl 2976’ to 622’: 2354 ft * 0.1237 bpf = 291 bbl 622’ to surf: 622 ft * 0.1815 = 113 bbl o Cement volume: 2280 cf (406 bbl) of 12 ppg 2300 cf (410 bbl) of 15.8 ppg neat (lost returns after 65% of this stage) Verified cement calcs -bjm CMIT to 2350 psi -bjm Surface cement plug is not approved as part of this sundry due to uncemented gas pool. -bjm P&A Program Well: Ba-11 690 ft (123 bbl) of 15.8 ppg w/ CaCl2 o 13-3/8” ID volume: 458 bbl 2976’ to 1993’: 983 ft * 0.1522 bpf = 150 bbl 1993’ to 66’: 1927 ft * 0.1546 bpf = 298 bbl 66’ to surf: 66 ft * 0.1522 bpf = 10 bbl o Cement placed into annulus before losing returns: 215 bbl 406 + (65% * 410) = 672 bbl 672 – 458 = 215 bbl o Calculated cement top: 1398 ft 215 bbl / 0.1237 bpf = 1736 ft 1736 / 110% = 1578 ft 2976’ – 1578’ = 1398 ft x 9-5/8” Casing o CBL on record with AOGCC T# 34808 Attachments: 1. Current Schematic 2. Proposed Schematic Updated by: JLL 3/30/16 SCHEMATIC Middle Ground Shoal Well: Ba-11 (MGS ST 17595 #11) Last Completed: 11-4-1997 PTD: 167-017 API: 50-733-20013-00 PBTD =9428’ MD TD = 9543’ MAX HOLE ANGLE = 28.75O @ 3700’MD 30” MGS Oil Top 5730’ Perfs behind 7” casing 5840’ - 6850’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 9540’ TOC CBL 4620’ 9.8 ppg brine 2522’ Casing Bowl Calc TOC 1398’ 20” 622’ 13-3/8” 2976’ 7” 5712’ Fill: 8404’ MGS Gas Base 4779’ Perfs 7850’ - 9050’ Perfs 5740’ - 5780’ Fill: 8404’ 9.8 ppg brine Perfs 7105’ - 7115’ KB: MSL Mean Sea Level Mud Line Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm 30” Structural 1.0” Wall 29 Surf 450 20” Conductor 94#, H40, Vetco 19.124 Surf 622 13-3/8” Surface 61#, K55, STC 12.515 Surf 66 54.5#, J55, STC 12.615 66 1,993 61#, K55, STC 12.515 1,993 2,976 29.8º 9-5/8” Intermediate 40, S95, BTC 8.835 Surf 2,522 40, N80, BTC 8.835 2,522 5,316 40, S95, STC8RND 8.835 5,316 7,257 43.5,S95,STC8RND 8.755 7,257 9,540 7” Scab Liner 29, L80, BTC 6.184 5,712 9,474 Tubing Detail Long String 2-7/8" Prod Tubing 6.4, L80, BTC-SC 2.411 32 7,276 2-7/8" Tubing Tail 6.4, L80, BTC-SC 2.411 7,340 Short String 2-3/8" Prod Tubing 4.6, L80, BTC-SC 1.995 32 7,279 Completion Jewelry Detail # Depth ID OD Item Long String 1 31 CIW 11” 5M, DCB Tubing Hanger 2 32 2.438 3.438 Crossover, 3-1/2” Buttress P x 2-7/8” Buttress Pin 3 7,276 2.441 2.875 Crossover Pup, 2-7/8” Buttress B x 2-7/8” 8 Rnd 4 7,287 2.25 5.626 KOBE, 2-1/2” Type B Parallel, Pump Cavity 5 7,306 2.441 3.625 Crossover, 2-7/8” 8Rnd B x 2-7/8” Buttress P 6 7,339 2.437 3.437 WREG, 2-7/8” Buttress B Short String A 31 2.438 3.438 Crossover 3-1/2” Buttress P x 2-3/8 Buttress P B 7,279 1.625 2.7 Crossover, 2-3/8” Buttress B x 1-1/2” 10 Rnd P C 7,280 1.375 1.625 Pup, 1-1/4” 10 Rnd Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments A 5,740' 5,780' 5,488' 5,527' 40' Open A,B,C,D 5,840' 6,850' 5,587' 6,589' 1,010' Behind 7" casing E,F,G 7,105' 7,115' 6,841' 6,851' 10' Open E,F,G 7,415' 7,800' 7,150' 7,533' 385' Cement Sqz'd E,F,G 7,850' 9,050' 7,583' 8,781' 1,200' Open Fill @ 8,404' Notes 10/1/2010 Well circulated with 9.8 ppg brine. 8/7/2016 RIH w/2” GR to 8404’ KB, tag fill. 6/24/1905 Issues with scale buildup, made problems pulling SV and getting down through tail. Fish Top: 9041’ DPM National Type “V” Cavity and Tail Pipe Assy Updated by: JLL 3/30/16 SCHEMATIC Middle Ground Shoal Well: Ba-11 (MGS ST 17595 #11) Last Completed: 11-4-1997 PTD: 167-017 API: 50-733-20013-00 PBTD =9428’ MD TD = 9543’ MAX HOLE ANGLE = 28.75O @ 3700’MD 30” MGS Oil Top 5730’ Perfs behind 7” casing 5840’ - 6850’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 9540’ TOC CBL 4620’ 9.8 ppg brine 2522’ Casing Bowl Calc TOC 1398’ 20” 622’ 13-3/8” 2976’ 7” 5712’ Fill: 8404’ MGS Gas Base 4779’ Perf @ 500’ Circ 178 bbl cement to surface Perfs 7850’ - 9050’ Perfs 5740’ - 5780’ 9.8 ppg brine Perfs 7105’ - 7115’ 194 bbl cement Estimated TOC ~4600’ KB: MSL Mean Sea Level Mud Line Casing Detail Size Type Wt/ Grade/ Conn ID Top Btm 30” Structural 1.0” Wall 29 Surf 450 20” Conductor 94#, H40, Vetco 19.124 Surf 622 13-3/8” Surface 61#, K55, STC 12.515 Surf 66 54.5#, J55, STC 12.615 66 1,993 61#, K55, STC 12.515 1,993 2,976 29.8º 9-5/8” Intermediate 40, S95, BTC 8.835 Surf 2,522 40, N80, BTC 8.835 2,522 5,316 40, S95, STC8RND 8.835 5,316 7,257 43.5,S95,STC8RND 8.755 7,257 9,540 7” Scab Liner 29, L80, BTC 6.184 5,712 9,474 Tubing Detail Long String 2-7/8" Prod Tubing 6.4, L80, BTC-SC 2.411 32 7,276 2-7/8" Tubing Tail 6.4, L80, BTC-SC 2.411 7,340 Short String 2-3/8" Prod Tubing 4.6, L80, BTC-SC 1.995 32 7,279 Completion Jewelry Detail # Depth ID OD Item Long String 1 31 CIW 11” 5M, DCB Tubing Hanger 2 32 2.438 3.438 Crossover, 3-1/2” Buttress P x 2-7/8” Buttress Pin 3 7,276 2.441 2.875 Crossover Pup, 2-7/8” Buttress B x 2-7/8” 8 Rnd 4 7,287 2.25 5.626 KOBE, 2-1/2” Type B Parallel, Pump Cavity 5 7,306 2.441 3.625 Crossover, 2-7/8” 8Rnd B x 2-7/8” Buttress P 6 7,339 2.437 3.437 WREG, 2-7/8” Buttress B Short String A 31 2.438 3.438 Crossover 3-1/2” Buttress P x 2-3/8 Buttress P B 7,279 1.625 2.7 Crossover, 2-3/8” Buttress B x 1-1/2” 10 Rnd P C 7,280 1.375 1.625 Pup, 1-1/4” 10 Rnd Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments A 5,740' 5,780' 5,488' 5,527' 40' Open A,B,C,D 5,840' 6,850' 5,587' 6,589' 1,010' Behind 7" casing E,F,G 7,105' 7,115' 6,841' 6,851' 10' Open E,F,G 7,415' 7,800' 7,150' 7,533' 385' Cement Sqz'd E,F,G 7,850' 9,050' 7,583' 8,781' 1,200' Open Fill @ 8,404' Notes 10/1/2010 Well circulated with 9.8 ppg brine. 8/7/2016 RIH w/2” GR to 8404’ KB, tag fill. 6/24/1905 Issues with scale buildup, made problems pulling SV and getting down through tail. Fish Top: 9041’ DPM National Type “V” Cavity and Tail Pipe Assy The surface cement plug is not approved as part of this sundry. -bjm 2011 July's Baker /Dillon Productio>eell Report • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, August 08, 2011 3:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 July's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 08 01.xis Hi Tom &Jim, (0 --0` Here is July's monthly report for the Baker and Dillon monitored production wells. The Ba -25RD continues to show some increasing pressures in one tubing string and the inner casing. The Ba -5 & 11 wells are still showing slowly climbing pressures (one tubing string on Ba -5 and one tubing and the inner casing on Ba -11). The general pattern of stable or slowly rising pressure trends continued this month. Besides the wells mentioned above, the only other pressure anomaly relates to the seasonal trend in pressures apparent in Di -6 & Ba -32 (before it was killed). Larry AI4D AU G. 1 Fi 201'1 «Master Well List TIO Report 2011 08 01.xis» 8/9/2011 • • Plot Pressure & Rate vs Time - Well Ba -11 1200 1000 ■ 1111 V .9 5/8" 800 -- 13 3/8" - -_ •20" Tubing — Tubing 2 ai 3 vi 600 ai a` 400 200 1. I �-1 O, O> W O OD 03 n O> m O 03 O> O O O O O O O O O O O O 000000000000 N O O 2 N N ^.,-- r cD `4 r t0 N N N) f7 N N O N O O M O O O M M M N N N N N N N N N N N N 7 N N N N N N N N N N N M 7 N N 3 R-08 m O N `,,'''83`8`.:3 I8 8 8 O N N 2 8 8 c3 8 O O O O O O O � O O O O � O O O O O O Date 13 3/8" 20" Tubi TIO Report 07/19/11 60 0 7 06/22/11 60 0 610 Data Sheet 06/01/11 60 0 560 05/28/11 60 0 500 05/26/11 500 Ba -11 05/25/11 60 0 500 05/24/11 60 0 500 15 05/23/11 60 0 500 15 BOT HOLE HYD PUMP 05/22/11 60 0 500 15 05/21/11 60 0 500 15 05/04/11 60 0 460 Permit # 1670170 04/01/11 60 0 260 02/16/11 60 0 75 02/03/11 60 0 API # 50- 733 - 20013 -00 01/20/11 475 60 0 0 15 12/17/10 290 60 0 0 15 11/09/10 0 60 0 0 10 01/31/2009 to 08/01/2011 10/31/10 0 65 0 0 13 10/30/10 0 60 0 0 10/29/10 0 65 0 0 12 10/28/10 0 60 0 0 18 10/27/10 0 70 0 0 10 10/26/10 20 65 40 0 0 10/25/10 0 60 0 0 15 10/24/10 0 60 0 0 10 10/23/10 0 60 0 0 10/22/10 0 60 0 10/21/10 0 60 0 0 0 10/20/10 0 60 0 0 0 10/19/10 0 60 0 0 10/18/10 0 60 0 0 0 10/17/10 0 60 0 0 0 10/16/10 0 60 0 0 0 10/10/10 1100 60 0 10/09/10 1095 65 0 10/08/10 1075 60 0 1040 500 8/9/2011 2:36 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 08 01.xIs Ba -11 2011 April's Baker/Dillon Production Well Report Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp ©chevron.com] Sent: Wednesday, May 11, 2011 7:25 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 April's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 04 30.xls ,r� ` Hi Tom &Jim, k WA �r Here is April's monthly report for the Baker and Dillon monitored production wells. The tubing and /or casing pressure increases on the Baker 11 & 25RD wells appear to be continuing and one of the tubing strings on Baker 5 has recently started climbing also. Baker 28 seems to have leveled off, but at a much lower pressure than prior to the well kill operations done last fall. Drilling is aware of these pressures and are making sure the abandonment plans for the Baker wells address any wellbore concerns. The general pattern of stable or slowly rising pressure trends continued this month. Besides the wells mentioned above, the only other pressure anomaly relates to the seasonal trend in pressures apparent in Di -6. Larry «Master Well List TIO Report 2011 04 30.xls» Z01 5,,,A0,45e0 mg 5/16/2011 Plot Pre ssure & Rate vs Time - Well Ba -11 • 1200 - 1000 •"'""•"9 5/8" 13 3/8" - Tubing — Tubing 2 w z vi 600 aw a` ______ 7 400 200 co pp co p, p> p, O CO m m O m W O Oh O O O O O O O O O O O O ,- .- •- N- R 2 W m 2 O 2 a0 r r O N 4 7 7 t N V C' <h N N o o m 7 7 r m W CJ N N N N N N N N N N N N N N N N N N N N N N N ` ` O N N th 8 8 O 8 8 8 O N N 8 8 8 8 n W W O N N 8 8 � O O O O O O O O O � O O O O O O O O O � O O O O Date 133/8° 20" �,.mr~g' u. TIO Report 04/01/11 60 01 260 02/16/11 60 o} 75 Data Sheet 02/03/11 60 0 35 01/20/11 60 0 0 12/17/10 60 0 ` 0 Ba -11 11/09/10 60 0 0 10/31/10 65 0 0 10/30/10 60 0 r ' BOT HOLE HYD PUMP 10/29/10 0 65 0 0 12 10/28/10 0 60 0 0 18 10/27/10 0 70 0 0 10 Permit # 1670170 10/26/10 20 65 40 0 0 10/25/10 0 60 0 0 15 10/24/10 0 60 0 0 10 API # 50- 733 - 20013 -00 10/23/10 0 60 0 0 10/22/10 0 60 0 10/21/10 0 60 0 0 0 10/30/2008 to 04/30/2011 10/20/10 0 60 0 0 0 10/19/10 0 60 0 0 10/18/10 0 60 0 0 0 1 10/17/10 0 60 0 0 0 10/16/10 0 60 0 0 0 10/10/10 1100 60 0 10/09/10 1095 65 0 10/08/10 1075 60 0 1040 500 10/07/10 1065 60 0 1010 500 10/06/10 1070 60 0 1035 500 10/05/10 1080 60 0 1035 500 10/04/10 1080 60 0 1035 500 10/03/10 1090 60 0 1035 500 10/02/10 1100 60 0 1030 500 10/01/10 1075 60 0 1025 500 09/30/10 1075 60 0 500 1025 09/29/10 1075 60 0 500 1025 09/28/10 1080 60 0 1030 500 09/27/10 1080 60 0 1040 500 5/16/2011 11:08 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 04 30 (3).xls Ba -11 2011 March's Baker /Dillon Produce Well Report Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, April 15, 2011 1:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 March's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 03 31.xls Hi Tom &Jim, k(crA_a\,`- Here is March's monthly report for the Baker and Dillon monitored production wells. The pressures on the Baker 11, 25RD & 28 wells continue the unexpected increases mentioned last month. Both 11 & 25RD look to be increasing slowly, but 28 may have leveled off. Drilling is aware of these pressures and are making sure the abandonment plans for the Baker wells address any wellbore concerns. All the other wells are still showing the same general up trend or seasonal trend (like Di -6) in pressures and appear to show no other pressure anomalies. The general pattern of stable or slowly rising pressures for the Dillon wells continued this month and most of the Baker wells have stabilized. Larry «Master Well List TIO Report 2011 03 31.xis» APR i 8 20)1 4/18/2011 • Plot Pressure & Rate vs Time - Well Ba -11 1200 1000 \ V 1111111114 V '9 5/8" 13 3/8" 800 - """'" 20" Tubing Tubing 2 w v) 600 w ot 400 200 0 00 W 00 O O 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0 0 0 0 0 0 0 0 0 0 0 0 N o o 0 0 0 0 0 00 0 0 0 00 0 0 00 0) 0) co r 0) co co N- r- (0 U) N a V (+) N a (+) M N N O O 0) 0) 0-3 N- 0) C) (`) N N N N N N N N N N N N N N N N N N N N N N N N 0) O N N C") V N CO I- a0 0) O N N C') 8 N O 6 8 0) O N N M O ' ' 0 0 O O O O O O O O O O O O O O O O •- O O O Date 13 3/8" 20" TIO Report 04/01/11 60 0 02/16/11 60 0 s '- Data Sheet 02/03/11 60 0 35 01/20/11 60 0 0 ) 12/17/10 60 0 ,! 0 Ba -11 11/09/10 60 0 10/31/10 65 0 0 10/30/10 60 0 0 - BOT HOLE HYD PUMP 10/29/10 65 0 ; 0 10/28/10 60 0 ' 0 10/27/10 70 0 0 Permit # 1670170 10/26/10 65 40 0 - 10/25/10 60 0 0 10/24/10 60 0 0 4 1 API # 50- 733 - 20013 -00 10/23/10 60 0 0 10/22/10 60 0 e 10/21/10 60 0 0 0 09/30/2008 to 04/01/2011 10/20/10 60 0 ' 0 0 10/19/10 60 0 0 10/18/10 60 0 0 0 10/17/10 60 0 0 0 10/16/10 60 0 0 0 10/10/10 60 0 10/09/10 65 0 10/08/10 60 0 1040 500 10/07/10 60 0 1010 500 10/06/10 60 0 1035 500 10/05/10 60 0 1035 500 10/04/10 60 0 1035 500 10/03/10 60 0 1035 5 10/02/10 60 0 1030 10/01/10 60 0 09/30/10 60 0.. 09/29/10 1075 60 0 500 1025 09/28/10 1080 60 0 1030 500 09/27/10 1080 60 0 1040 500 4/18/2011 5:02 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 31 (6).xls Ba -11 \..n -C -,tri - Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009" /AUG q 5 2(109 Cathy Foerster Commissioner figs ,ii Gas Cons, Nirnrnipfir�r, Alaska Oil & Gas Conservation Commission f?nr,hnt, i,ip 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, 1Jctk�_ Dale Haines Alaska Area Operations Manager SEMWOCT 0 3 2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -1 1 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platforrn life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHIJT-IN SCU 21-8 1620190 Aug- parted tb high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow as Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow as 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tb high water Possible shallow as 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Colla sed casing Producing Coal Phase I Abandon abandon at end of platfonn life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life ' t SARAH PALIN, GOVERNOR .�� ALASKA 01j, AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION CO1�Y USSION ANCHORAGE, ALASKA 99501-3539 l:Lvil� il' 111E1 PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 Dale Haines UNOCAL KWED 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(a�alaska.gov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 _ Granite Pt St 18742 14 _ Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 _ Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 _ Trading Bay Unit G-24 _ _ Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD Union Oil Company of California 168-038 Trading Bay Unit K-06RD _ Union Oil Company of California 169-066 _ Trading Bay Unit K-09 _ _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 _ Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 _ MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN Union Oil Company of California 173-014 Trading Bay St A-30 ) ) Chevron III 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. 7th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary §GANNEU NO'~ 0 [} 20mi.;':;:\:: \~7- 01 ~.f';..~. II Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal'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 BHP 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. ~...~Jn~ tf ^TE ~. l-'~,_a :'<...1 M \ Union Oil Company of California / A Chevron Company http://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 501 and in the gas well Baker 32. In light of the Chevron Corporation acquisition of Unocal, 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 platfonns. 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. S incerel y, ~&~'-¿=-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-Jub05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-Jul-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 -1 8 Gas No survey Ba-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 ) -) '~~!Æ~E :} !Æ~!Æ~~~!Æ ATfASIiA. OILAlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. rrn AVENUE, SUITE 100 ANCHORAGE.. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (90~27~7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 tt4",Cd1 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with COl1LT11ission Engineer 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. ,~' SinC1J~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Ene!. SCANNED NOV 2 4 2004 " ) STATE OF ALASKA">' ALASKA OIL AND GAS CONSERVATION COMMI~\:)1oN 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 0 Other 0 Re-enter Suspended Well Monitor Frequency 5. Permit to Dr" Number: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 8. Property Designation: BAKER 11. Ba-11 10. Field/Pools(s): 0 0 Service Exploratory D 0 3. Address: 909 West 9th Ave. Anchorage AK 99501 Development Stratigraphic 7. KB Elevation (ft): 79' 9. Well Name and Number: Total Depth MD (ft): 9,543' Casing Structural Total Depth TVD (ft): 9,275' Length PRESENT WELL CONDITION SUM Effective Depth MD (ft): Plugs (measured): Junk (measured): 9,428' Size MD TVD Burst Collapse Conductor Surface / Intermediate Production 592' 2,943' 9,508' 20" 22' 622' 2,950' 9,255' 2,734 psi 1,128 psi 5,754 psi 3,087 psi 8,160 psi 7,020 psi Tubing MD (ft): LS: 7339' SS: 7279' 13-3/8" 9-5/8" Liner 3,762' 7" Perforation Depth TVD (ft): 5,459'-9,272' Tubing Grade: LS: 2-7/8" SS: 2-3/8" LS: 6.4#, L-80 SS: 4.6#, L-80 Packers and SSSV MD (ft): Perforation Depth MD (ft): 5740' to 9050'; 5487' to 8781'; Packers and SSSV Type: ~ N/A 12, Attachments: Description Summary of Propos I l:!J Detailed Operations Program D BOP Sketc 0 14. Estimated Date for / Commencing Operations: Printed Nam¡ ).'Î .~. COle. Signatur~/7~//,~? ~ 17. I hereby certify that the foregoing is true and orrect to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 0 Service D Plugged WINJ D D Abandoned WDSPL D 0 16. Verbal Approval: Commission Representative: Phone 27 -Sep-2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ÐL/-~~ Plug Integrity D BOP Test 0 Mechanical Integrity Test D Location Clearance 0 liECEIVED OCT I 2 2004 Other: RBDMS BFL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION ;/ & Gas Cons. Commission Anchorage Subsequent Form Required: Approved by: COMMISSIONER BY ORDER OF THE COMMISSION Date: ~ Form 1 O~evised 12/2003 ORIGINAL Submit in Duplicate • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Performed: Alter Casing ❑ Change Approved Program ❑ 2. Operator Union Oil of California Name: aka Unocal 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 79' Suspend Operation Shutdown Perforate Li WaiverLj Other LJ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Time Extension[] Pull Tubing E] Perforate New Pool ❑ Re-enter Suspended Well F1 Shut in & secure 4. Current Well Class: 5. Permit to Drill Number: Development Q Exploratory❑ 1670170 Stratigraphic❑ Service❑ 6. API Number: 50-733-20013-00-- 9. Well Name and Number: Ba -11 8. Property Designation:10. -, Field/Pool(s): - Middle Ground Shoal $��OIL BAKER . 11. Present Well Condition Summary: Total Depth measured 9,543' feet Plugs (measured) true vertical 9,275' feet Junk (measured) SCANNED ` ` `-. �, L Nbn'6 ype "V" cavity and Tail Pipe Assy. @9041' Effective Depth measured 9,428' feet true vertical 9,161' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 592' 20" 622' 622' 2,975' 2,950' 2,734 psi 1,128 psi Intermediate 2,943' 13-3/8" 9,526' 9,255' 5,754 psi 3,087 psi Production 9,508' 9-5/8" 7" 5,712'-9,543' 5,459'-9,272' 8,160 psi 7,020 psi Liner 35762' Perforation depth: Measured depth: 5740' to 5780'; 5840' to 6850'; 7850' to 9050'; True Vertical depth: 5487' to 5526'; 5586' to 6588'; 7582' to 8781'; Tubing: (size, grade, and measured depth) LS: 2-7/8", 6.4#, L-80, 0-7339' SS: 2-3/8", 4.6#, L-80, 0-7279' Packers and SSSV (type and measured depth) N/A 12. Stimulation or cement squeeze summary: r Intervals treated (measured): aCW cons , Treatment descriptions including volumes used and final pressure: Ch/1) 11 Representative Daily Average Production or Injection Data 13 asing Pressure Tubing Pressure Oil -Bbl Gas-Mcf Water -Bbl !4410 Prior to well operation: 129 21 60 80 0 on 10/05/03 0 Subsequent to operation: 0 14. Attachments: 15. Well Class after proposed work: Exploratory[] Development Q Service ❑ Copies of Logs and Surveys Run Daily Report of Well Operations 16. Well Status after proposed work: Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Oil 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Title Petroleum Engineer Printed Name P. M. Ayer Phone 263-7620 Date 09 Jun 2004 Signature BDMS MAY 2 9 2012 ��M Form 10-404 Revised 12/2003 ALASKA �� • V N 0 CAL 76 Depth ID JEWELRY DETAIL OD Item •baker Well No. 11 Actual Completion 11/4/97 Long String 1 CASING AND TUBING DETAIL - - RKB to TBG Head = 31.22' SIZE WT GRADE CONN ID TOP BTM. 1 20" 94 Crossover Pup, 2-7/8" Buttress Box x 2-7/8" 8 rd Pin 19.124 Surface 622' 5.626 13-3/8" 54.5 & 61 7,306' 12.16-12.51 Surface 2,975' 2 a 9-5/8" 40 & 43.5 N-80 & S-95 BTC 8.755 Surface 9,526' 7" 29 L-80 BTC 6.184 5712' 9,543' Tubing Long String 2-7/8" 6.4 L-80 BTC SC 2.411 32' 7,276' Short String 2-3/8"" 4.6 L-80 BTC SC 1.995 32' 7,279' 1 NO. Depth ID JEWELRY DETAIL OD Item Long String 1 31.22' - - CIW, 11", 5M, DCB Tubing Hanger 2 32' 2.438 3.438 Crossover, 3-1/2" Buttress Pin x 2-7/8" Buttress Pin 3 7,276' 2.441 2.875 Crossover Pup, 2-7/8" Buttress Box x 2-7/8" 8 rd Pin 4 7,287' 2.250 5.626 Kobe, 2-1/2", Type `B" Parallel, Pump Cavity 5 7,306' 2.441 3.625 Crossover, 2-7/8" 8 rd Box x 2-7/8" Buttress Pin 6 7,339' 2.437 3.437 WREG, 2-7/8" Buttress Box Short String A 31.22' 2.438 3.438 Crossover, 3-1/2" Buttress Pin x 2-3/8" Buttress Pin B 7,279' 1.625 2.700 Crossover, 2-3/8" Buttress Box x 1-1/2" 10 rd Pin C 7,280' 1.375 1.625 Pup, 1-1/4" lord 3g FISH: C National Type "V" Cavity and Tail Pipe Assy. Top @ 9,041' DPM PERFORATION HISTORY See Attached Sheet for Perforation Data 5740'-5780' 5840'-6850' 7850'-9050' Fill Tagged @ 8,304' 3/8,99 CTM Fill Tagged @ 8,353' 10/30/97 PBTD = 9,428' TD = 9,543' MAX HOLE ANGLE = 28.4° @ 3,700' Baker 11 sch 3-8-99.doc DRAWN BY: tcb BAKER PLATFORM API # 50-733-10013-00 MGS ST. 17595 # 11 WELL HISTORY LAST WORK: 6/15/99 Date Work Performed 1972 1-72 Killed well with mud. Ran 7" liner from top of "A" zone to 9428' PBD. Perf "G" at 7105-9040'. Treated with 26,000 gal. 12-10 MCA, 29,000 gallons 2-1/2% HC1, 2--00# Unibeads x 7000 gallon solvent in 6 equal stages, Convert to Kobe. A & BCD zones shut-in by workover. Prior: 799 BOPD, 0 BWPD, 334 MCFD (EFG Only) After: 1013 BOPD, 13 BOPD, 225 MCFD 5-30-72 Killed well with oil base mud. Replace Type 'B' BHA with Type 'E'. Prior: 1032 BOPD, 2 BWPD, 266 MCFD 1300 BPOPD at 2000 psi - 56 SPM, LSP 1650 psi After: 1012 BOPD, 3 BWPD, 238 MCED 1000 BPOPD at 1650 psi- 27 SPM, LSP 1450 psi 1973 1-73 Perforate additional EEG zone. Hydraulic pump stuck. Pulled BHA and pushed packer to 9420'. Perforated in oil base mud at 2 JSPF using hollow carrier casing guns. Set new packer at 7040'. Prior: 1016 BOPD, 3 BWPD, GOR 305 After: 1642 BOPD, 0 BWPD. GOR 314 1978 8-78 Killed well with diesel. Pulled defective BHA. Ran 3-1/2" tubing and 2-1/2" Type 'E' BHA. Landed at 8569'. Prior: 616 BOPD, 36 BWPD After: 558 BOPD, 65 BWPD 1979 10-23-79 Killed well with diesel. Replaced BHA. Prior: 594 BOPD, 74 BWPD, 155 MCFD After: 612 BOPD, 75 BWPD. 199 MCFD 1980 1-24-80 Tagged fill at 9372' KB. 2-12-80 Killed well with diesel. Replaced BHA. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 (continued) 1990 8-25-90 R/U wireline. Bailed hard fill and sand w/2.55" DD bailer and hydrostatic bailer F/9042' WLM. Equalize and pull STV. Tag fill @ 9060' WLM. 9-7-90 R/U wireline. Equalize and pull STV. Bail fill w/1-3/4" DD and pump bailer F/9056 - 9062' WLM. Bailer stuck @ 9062'. Wireline parted at surface while jarring stuck bailer. Cut wire, fished wire, cutters, and bailer tool string successfully. Tag fill w/1-3/4" DD bailer @ 9063' WLM, worked bailer recovered scale sample. 1991 1-13-91 R/U wireline. Equalize and pull STV @ 9035' WLM. Tag fill @ 9037' WLM. 9-13-91 R/U wireline. Bailed pump cups and sand w/ DD and hydro bailer from 9040' WLM. Equalize and pull STV. Ran gradient survey with 5 min. stops every 1000 ft. 12-4-91 R/U wireline. Tag fill @ 9047' WLM w/2" gauge ring. Bailed sand F/9047' to 9050' WLM w/1-3/4" DD bailer. Continued bailing runs to 9053' WLM. STV seat marks on bailer btm. 12-10-91 R/U wireline. RIH w/1-3/4" DD bailer to 9047' WLM. STV marks on bailer btm. RIH and set 22' Dummy pump @ 9047' WLM. 12-12-91 CTU cleanout to 9190'. Recovered silt and pea gravel. Acidized w/2000 gal acid wash and 10,000 gal squeeze (15% HCI, 20% Xylene). Before - shut-in, After - 65 BOPD @ 40% wcut. 12-17-91 R/U wireline. Equalize and pull STV. Run new STV. 1992 1-5-92 R/U wireline. Pull pump. Equalize and pull STV. 1-7-92 Scale inhibitor squeeze. 8-8-92 R/U wireline. Equalize and pull STV from 9040' WLM. RIH w/1-3/4" DD bailer, set down @ 9041' W LM. Recovered sand. Shut-in well. 1993 1-18-93 R/U wireline. Tag btm @ 9007' W LM w/1.875" gauge ring on 1.5" tool string. 2-1 to 8-93 Killed well w/5% KCI. Unable to pull BHA. Cut tbg 2 9047' and recovered. Ran new tbg and BHA and landed tbg tail @ 7348'. R/U wireline. Tag btm @ 7912' with 2.25" gauge ring. 2-24-93 Perf'd through tubing w/2-1/8" silverjet 4SPF Odeg 7415-7425 7440-7450 7680-7745 0 • 7750-7765 7780-7810 Depths are DIL MD. R/U wireline. RIH w/equaling prong sat down @ 1548' work to 1568' WLM. RIH w/pulling tool, latched STV @ 1568' WLM, POOH w/STV. Ran 2.35" swedge, tagged top of cavity @ 7266' W LM. Ran new STV. 1994 11-6-94 R/U wireline. Pull pump @ 7264' WLM. Equalize and pull STV. Run new STV. 1995 7-23-95 R/U wireline. RIH w/overshot, sat down @ 3900' WLM. Pull pump, tight @ 3960' WLM. Equalize and pull STV. Run new STV. Fluid level @ 1500' WLM. 1996 8-17-96 Changed pump and flow controller. Bundle test to 2500 psi for 5 min. bled down to 700 psi. 9-1-96 Replaced 'A' piston pump w/11 A jet. Piston pump not pulling down FL. 9-29-96 R/U wireline. RIH w/1.8" LIB to 7346' WLM. LIB showed scale. Ran 1-1/4" pump bailer, bailer 1/4 full of scale. Equalize and pull STV. Tag fill @ 8570 WLM. 07/01/03 Shut in well B-11 and reverse circulate pump to surface. Kill well and pull pump as usual. Circulate Well B-11 one tubing volume of 71 bbls. Check for clean returns. Pull standing valve in B-11. All casing and tubing valves closed; pipe connections removed and blind flanges installed. Gauges installed to monitor pressures. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 (continued) 12-01-96 WL - Ran in hole and pulled 2.50" Kobe Pump @ 7331'. Equalized and pulled standing valve @ 7355'. Ran in hole with 2.21" gauge ring to TD @ 8600'. POOH RD. 12-10-96 Shut-in well due to suspected leak in S string. Unable to get complete returns up S string while pumping well. Pump continues to operate normally while S string shut-in with no pressure buildup. 1997 1-2 to 6-97 R/U wireline on S string. Identified leak in S string @ 6503' WLM with 1-1/4" nylon flag tool. Removed scale bridges and opened tubing from 1.4" gauge ring to 1.73" gauge ring to top of cavity. 1.77" gauge ring passed to 5971' WLM, 1.8" gauge ring passed to 5320' W LM. 1-05-97 WL - Chip Scale S. String: Worked 1.60", 1.70", & 1.73" gauge rings thru several bridges (over 5 days) to pump cavity @ 7,282'. RIH W/nylon flag and located leak @ 6,503'. RIH W/1.77" gauge ring to hard spot @ 5,322' and cut very hard scale from 5,322' to 5,971'. 2-05-97 WL - Chip Scale S. String: Worked 1.77" & 1.80" gauge rings 'thru several bridges over 2 days to pump cavity @ 7,282'. Ran 1.825" gage ring through medium scale to hard scale from 5,071'- 6,147', could not get past. 2/28/97 WL - Attempt S String Tbg Patch: 2/25 thru 2/28. Gauged S string to cavity @ 7282' WLM with 1.80" gauge ring. Unable to bundle test L string with dummy pump. Spinner tool showed all fluid leaving the L string through the dummy pump. Attempted to run spinner on S string to confirm suspected leak, spinner set down @ 6120' WLM, POOH. Pulled dummy pump from L string. Descaled S string. Attempt to run spinner on S string pumping through leak and up annulus, S string holding 2000 psi with no returns up annulus. Ran spinner in S string with returns up L string since unable to circ up annulus through leak. Suspended operations 2/28 pm (analyzing data to determine well problem); plan to run pump and attempt to produce. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 (continued) 3/5/97 WO - (S String Tbg Patch Attempt): Job canceled due to severe scale surrounding leak in S string and indications of leaking cavity seal area. Well SI permanently pending rig workover (loss of 60 BOPD). 1998 1999 1/16-19 WL - Pull pump and SV, found pump 1000' above cavity. Found tight spot in tubing @ 5,210' KB. Clean out restrictions at collars, tagged 1' below cavity, hard metal, had metal marks on bailer. RIH w/ 1.75" lead impression block to obstruction @ 7,302' KB, POOH. LIB shows circular marks. Probably scale with an ID of 1.5" or smaller. Unable to clear obstruction @ 7,302' KB, (which is V below where standing valve was pulled). Looks to be a scale build up. RIH w/ 10' of 3/4" stem on bottom of tool string to 7,302' KB, couldn't pass through, not sticky. 1/21-22 AC - Dumped acid on obstruction @ 7,302' KB, continued bailing. Bailed 2 cups of material from obstruction @ 7,302' KB using hydrostatic bailer. 1/23-26 WL - Retrieved 7 BBLS of fluid during swabbing operations & attempted to break through obstruction @ 7,302' KB w/ star bit., Retrieved 5 cups of scale from well, no hole made, fluid level @ 2,240' KB. Continued bailing fill in tail pipe. RIH w/ 2" DD bailer to 7,302' KB, worked tools, POOH w/ bailer empty. Bottom is marked up as if hitting something hard. RIH w/ 1.75" lead impression block to 7,302' KB, POOH, had impression of hard fill. 3/25 TAG — GR - RIH w/ 2.312" gauge ring & tag Kobe cavity @ 7,287' KB, POOH. RIH w/ 2.150"gauge ring & tapped fill @ 8,566' KB, POOH. Depth is correct, no counter problems, 200# difference from coil clean out (deeper). RIH w/ 2 1/2" SV & shake off @ FL @ 2,450' KB. 6/15 TAG - RIH & pulled standing valve @ 7,287' KB, POOH. RIH w/ 2.2 "gauge ring & tagged fill @ 8,551' KB, POOH. RIH to 2,400' KB, shake off standing valve, POOH. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 Pertinent Data: Spud Date: September 5, 1976 Completion Date: 9-7-67 Surface Location: Slot 4, Leg 1, 1940' FNL, 343, FW L, Sec. 31, T9 N, R12W. S. M. Subsurface Location: 1892' FSL, 847' FWL, Sec. 31, T9N, R12W, S.M. Elevation: 79' RKB above MSL Total Depth: 9543' Plug Back Depth: 9428' Casing: 20", 944 @ 622'w/1 345 sx 13-3/8", 54.5 & 61 # @ 2975' w/3250 sx 9-5/8", 40 x 43.5# @ 9541 1 st stage - 1300 sx 2nd stage - 7305' - 1000 sx 7", 29# liner @ 5712-9474'w/700 sx Initial Potential: A zone- 1046 BOPD, GOR 1969 BCDzones - 1515 BOPD, GOR 388 EFG zones - 823 BOPD. GOR 526 Initial Stimulation: None MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 Perforation Record: Date Zone Interval 8-67 A 5840-50', 5895-5905'x csg gun in wtr base mud 8-67 BCD 6105-15', 6180-90', 6210-20', 6255-65', 6297-6307', 6340-50', 6450-60', 6480-90', 6535-45', 6580-90', 6645-55', 6760-70', 6795-6800', 6840-50', x csg gun in wt. base mud. 8-67 EEG 7105-15', 7145-55', 7415-25', 7440-50', 7710-30', 7780-90', 7860-70', 7910-90', 7960-70', 8010-20', 8060-70', 8120-30', 8190-8200', 8255-65', 8365-75', 8430-40', 8520-30', 8615-25', 8685-95', 8760-70', 8810-20', 8860-70', 8935-45', 8990-9000', 9030-40'x csg gun in wt. base mud. 2-72 EFG 7105-15', 7145-55', 7415-25', 7440-50', 7710-30', 7780-90', 7860-70',7910-20', 7960-70', 8010-20', 8060-70', 8120-30', 8190-8200', 8255-65', 8365-75', 8430-40', 8520-30', 8615-25', 8685-95', 8760-70', 8810-20, 8860-70', 8935-45', 8990-9000', 9030-40', csg gun 2 JSPF in oil base mud. 1-73 EFG 7680-7710', 7130-45', 7750-65', 7790-7800', 7870-7910', 7950-60', 7970-8010', 8020-35', 8130-40', 8170-8215', 8240-8310', 8330-65', 8375-8430', 8440-70', 8505-20', 8530-55',8623-80', 8695-8720', 8745-60', 8800-10', 8820-60'8870-8920', 8945-68', 8975-90', 9020-30', 9040-50', x csg gun 2 JSPF in oil base mud. 1 • • MIDDLE GROUND SHOAL ADL 17595 WELL NO. 11 (Continued) Reservoir Data: Zone Depths: A zone - 5590-6040' BCD zones - 6040-7090' EFG zones - 7090-9543' Cored Intervals: EFG zones - 8685-98', 8825 -34 - DST Intervals and Results: None Selective Tests: None Log Inventory: IES, Sonic x Dipmeter 0 BAKER CLEANING TASK LOO Task Completed Confirmed BY Date By Tom McCaughey 6/28/7003 Rick Lewis Shutdown Wells and Pull Pumps Note. Pull Kobe pumps now, before source water is circulated. 9 they are circulated out with water, the wells will be very difficult to put on vacuum. Pull pumps one at a time so oil will be replaced with produced water. Tom McCaughey 6/28/2003 Rick Lewis Shut in well B-13 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-6 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-5 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-11 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-30 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-29 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Shut in well B-28 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Shut in well B-25 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-13 to circulate 125 bbls of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-6 to circulate 125 bbls of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Circulate B-20 by operating the pump with power water for 50+ bbls. Pull CT Jet pump in Well B-20. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-5 one tubing volume of 102 bbls. Pull standing valve in B-5. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-11 one tubing volume of 71 bbls. Check for clean returns. Pull standing valve in B-11. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-28 one tubing volume of 146 bbls. Pull standing valve in B-28. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-30 one tubing volume of 65 bbls. Unable to pull standing valve in B-30. Tom McCaughey 7/1 003 Rick Lewis Circulate Well B-29 one tubing volume of 140 bbls. Pull B-29 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-25 one tubing volume of 134 bbls. Check for clean returns. Pull B-25 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Operate Well #31 while metering power fluid for one complete tubingleasing volume of 480 bbls. There is no standing valve so operating the pump will circulate out any power oil remaining in the well. Tum well over to Wireline to pull pump. Tom McCaughey 7/6/2003 Brett Aldridge Blind Well # 14 gas in Leg Room 1 to isolate it from the LP Dehy. Rick Lewis 8/24/2003 Rick Lewis Blinded Injection Well B-16 after completing final injection and flush. Note that this information was extracted from the overall Baker Cleaning Task Log by Rich Novcaski 6/10/04. ~ STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: X Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 75' RKB MLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: MGS State 1~595 4. Location of well at surface Baker Platform, Leg No. 1, Conductor No. 4 8. Well number 1,940' FNL, 543' FWL, Sec. 31, TgN, R12 W, SM Baker Platform Well No. 11 At top of productive interval 9. Permit number/approval number 67-00017 At effective depth 10. APl number 50- 733-20013 At total depth 11. Field/Pool 1,882' FNL, 837' FWL, Sec. 31, T9N, R12W, SM Middle Ground Shoal 12. Present well condition summary Total depth: measured 9,543' feet Plugs (measured) true vertical 9,275' feet Effective depth: measured 9,428' feet Junk (measured) true vertical 9,161' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 592' 20" 1,345 sx 622' 622' Surface 2,943' 13-3/8" 3,250 sx 2,975' 2,950' Intermediate Production 9,508' 9-5/8" 2,300 sx 9,541' 9,276' Liner 3,762' 7" 700 sx 5,712'-9,474' 5,463'-9,206' Scab Liner Perforation depth: measured (See Attached Perforation Data Sheet) true vertical Tubing (size, grade, and measured depth) L.S.: 2-7/8", 6.4#, L-80, 0-7339' SS: 2-3/8", 4.6#, L-80, 0-7279' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summaryAPR 2 8 3999 Intervals treated (measured)0RI61NALN~ Oil & 6a~ Cons. Comm,ss'o. Treatment description including volumes used and final pressure Al~ch0ra[~t~ 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 Subsequent to operation 4/5/99 128 0 107 80 PSI 3,500 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dan Williamson~ ~t~~! ~itle: Drilling Manager Date: ~'~/2 ~/~ AFE# 134127 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 3/7/99 Baker Well #11 Coil Tubing Cleanout Daily Summary of Operations RU Dowell coil tubing unit on short string. Pressure test BOPs to 4500 psi. rotating nozzle. MU "Scale Blaster" 3/8/99 RIH with nozzle to 7273' CTM while circ at V2 BPM. Tag fill at 7273', increase rate to 1.5 BPM. Clean out fill from 7273' to 7282' CTM. Fell through past tubing tail to 7350'. Full returns up LS. POH to 7200' and wash tbg tail to 7315'. RIH and tag fill at 8304'. Circ BU and POOH. 3/9/99 Rig down coil tubing unit and drop jet pump. Return well to production. Ba- 11 daily summary.doc Page #1 04/22/99 w, '�` , _ � ` - 2 32' Oaker 3.438 3 7,276' 2.441 2.875 4 7,287' 2.250 Well No. 11 5 7,306' 2.441 UNOCAL® 6 7,339' 2.437 3.437 Actual Completion 11/4/97 CASING AND TUBING DETAIL RKB to TBG Head = 31.22' SIZE WT GRADE CONN ID TOP BTM. 1 20" 94 19.124 Surface 622' 13-3/8" 54.5 & 61 12.16-12.51 Surface 2,975' 2 A �� 9-5/8" 40 & 43.5 N-80 & S-95 BTC 8.755 Surface 9,541' r � 7" 29 L-80 BTC 6.184 5712' 9,474' Tubing Long String 2-7/8" 6.4 L-80 BTC SC 2.411 32' 7,276' Short String 2-3/8"" 4.6 L-80 BTC SC 1.995 32' 7,279' JEWELRY DETAIL 1 31.22' - 2 32' 2.438 3.438 3 7,276' 2.441 2.875 4 7,287' 2.250 5.626 5 7,306' 2.441 3.625 6 7,339' 2.437 3.437 Long String C1W, 11", 5M, DCB Tubing Hanger Crossover, 3-1/2" Buttress Pin x 2-7/8" Buttress Pin Crossover Pup, 2-7/8" Buttress Box x 2-7/8" 8 rd Pin Kobe, 2-1/2", Type `B" Parallel, Pump Cavity Crossover, 2-7/8" 8 rd Box x 2-7/8" Buttress Pin WREG, 2-7/8" Buttress Box Short String A 31.22' 2.438 3.438 Crossover, 3-1/2" Buttress Pin x 2-3/8" Buttress Pin B 7,279' 1.625 2.700 Crossover, 2-3/8" Buttress Box x 1-1/2" 10 rd Pin C 7,280' 1.375 1.625 Pup, 1-1/4" lord BF I FISH: C National Type "V" Cavity and Tail Pipe Assy. Top @ 9,041' DPM 0 PERFORATION HISTORY See Attached Sheet for Perforation Data 5740'-5780' 5840'-6850' Fill Tagged (0 8,304' 3/8199 CTM Fill Tagged @ 8,353' 10/30/97 PBTD = 9,428' TD = 9,543' MAX HOLE ANGLE = 28.4° @ 3,700' UNOCALe RKB to TBG Head = 31.22' 1 SIZE 20" 13-3/8" 9-5/8" 7" Tubing Long String 2-7/8" ~aker Well No. 11 Actual Completion CASING AND TUBING DETAIL WT GRADE CONN ID 94 54.5 & 61 40 & 43.5 N-80 & S-95 BTC 29 L-80 BTC 11/4/97 I TOP 6.4 L-80 BTC SC 19.124 12.16-12.51 8.755 6.184 Surface Surface Surface 5712' Short String 2-3/8 .... 4.6 L-80 BTC SC BTM. 622' 2,975' 9,541' 9,474' 2.411 32' 7,276' 1.995 32' 7,279' JEWELRY DETAIL NO. ID OD Item 1 31.22' - 2 32' 2.438 3.438 3 7,276' 2.441 2.875 4 7,2~7' 2.250 5.626 5 7,306' 2.441 3.625 6 7,339' 2.437 3.437 Long String CIW, 11", 5M, DCB Tubing Hanger Crossover, 3-1/2" Buttress Pin x 2-7/8" Buttress Pin Crossover Pup, 2-7/8" Buttress Box x 2-7/8" 8 rd Pin Kobe, 2-1/2", Type "B" Parallel, Pump Cavity Crossover, 2-7/8" 8 rd Box x 2-7/8" Buttress Pin WREG, 2-7/8" Buttress Box Fill Tag~A @ 8304' 3/8/99 CTM Fill Tagged @ 8,353' 10/30/97 A 31.22' 2.438 3.438 B 7,279' 1.625 2.700 C 7,280' 1.375 1.625 Short String Crossover, 3-1/2" Buttress Pin x 2-3/8" Buttress Pin Crossover, 2-3/8" Buttress Box x 1-1/2" 10 rd Pin Pup, 1-1/4" 10rd FISH: National Type "V" Cavity and Tail Pipe Assy. Top @ 9,041' DPM PERFORATION HISTORY See Attached Sheet for Perforation Data 5740'-5780' 5840'-6850' 7850'-9050' PBTD = 9,428' TD = 9,543' MAX HOLE ANGLE = 28.4° @ 3,700' Middle Ground Shoal Field Baker Platform Well No. 11 Actual Perforations 10/30/97 Date Zone Top Interval Btm Amt Accum. spf Present Condition 10/30/97 A 5,740' 10~0/97 A 5,760' 5/14/67 A,B,C,D 5,840' 6/2/85 E,F,G 7,105' 6/2/85 E,F,G 7,415' 6/2/85 E,F,G 7,440' 6/2/85 E,F,G 7,680' 6/2/85 E,F,G 7,750' 6/2/85 E,F,G 7,780' 10/30/97 E,F,G 7,850' 6/2/85 E,F,G 7,860' 10/30/97 E,F,G 7,920' 10/30/97 E,F,G 7,935' 6/2/85 E,F,G 7,950' 6/2/85 E,F,G 8,060' 10/30/97 E,F,G 8,080' 6/2/85 E,F,G 8,120' 6/2/85 E,F,G 8,170' 6/2/85 E,F,G 8,240' 10/30/97 E,F,G 8,310' 10/30/97 E,F,G 8,340' 6/2/85 E,F,G 8,350' 6/2/85 E,F,G 8,505' 6/2/85 E,F,G 8,615' 6/2/85 E,F,G 8,685' 6/2/85 E,F,G 8,740' 6/2/85 E,F,G 8,800' 6/2/85 E,F,G 8,935' 6/2/85 E,F,G 8,975' 6/2/85 E,F,G 9,020' 5,760' 20' 6.00 5,780' 20' 6.00 6,850' 1,010' - 7,115' 10' - 7,425' 10' - 7,450' 10' - 7,745' 65' - 7,765' 15'. - 7,800' 20' - 7,860' 10' 6.00 7,920' 60[ - 7,940' 20' 6.00 7,950' 15' 6.00 8,035' 85' 8,070' 10' 8,090' 10' 6.00 8,140' 20' 8,215' 45' - 8,310' 70' - 8,320' 10' 6.00 8,350' 10' 6.00 8,470' 120' - 8,555' 50' - 8,680' 65' - 8,720' 35' - 8,770' 30' - 8,920' 120' - 8,968' 33' - 9,000' 25' - 9,050' 30' - Total Open: 385' Open Open Behind 7" Casing Open Cement Squeezed Cement Squeezed Cement Squeezed Cement Squeezed Cement Squeezed Open Open Open Open Open Open Open Open Open Open Open Open Covered Covered Covered Covered Covered Covered Covered Covered Covered , , i Illl I UC'I: 4'U/FM UN~ ~UKF, Unocal Corporation P.O. Box lg6247 Telepholle (907) 263.7660 Dale Haines Drilling Manager UNOCALe Friday, October 24, 1997 TO: Blair wondzell AOOCC RE: Baker 11 Workover We are preparing to work over Baker Well No. 11 in the Middle Ground Shoal Field. The well is completed as a packer-less "no flow" completion and is readily killed with filtered inlet water mixed with 3% KCL. The well is completed with a 2,7/8" Long String and a 2-7/8" x 2-3/8" Short String. We intend to pull the first 300' of the completion as a dual, then cut and pull the short string. BOP configuration is to be a 13-5/8, 5M Annular Preventer, 13-5/8" 5M Single Gate with 2-7/8" x 5" Variable Rams, and a Double Gate with 2-7/8" x 2-7/8" Dual Rams in the top cavity and a set of blinds in the bottom cavity (see attached drawing). in order to accommodate all tubing string configurations and to eliminate the need for opening the stack to change rams, we respectfully request that we be allowed to use Annular Preventer for shutting in on the 3,595' of 2-3/8" tubing to be pulled as a single string. I would greatly appreciate an expedient decision in regards to this matter, as the anticipated start date for the project is October 26, 1997. Sincerely, Dale Haines DH/gc Attachment VCt,Z4. 4'UtFM uN~U.~,L. ~uK~. WELL BA- 1 !. HYDRAULIC WORKOVER PLATFORM BAKER" 17.4.8 ,- 27.1~. 2.16 ,,~ 2.2,3 1.7,6 4.20 u 9.66 1.6g J ..' 10.95 3" RLL IXlO, u I ~ y. ~ . ii · · ORIUJNG SPOOL 13 s/a" su x DRILLING SPOOL 13 5/8" GM x 13 5/8" 5M Wn'H ~ 1/16" ~M OUTLE~ ANNULAR PRCVI~q4~R HYORIL Gl<: 13.5/8' 5M SlNC, U~ ~T~ NL 13 5/8" 5M WITH 2 7/8" X DOUBLE CATE NL SHAFT~ 13 5/8" 5M win4 :z 7/8' x 2 7/8' OUAL IN TOP BUND RAMS IN BOTTOM O~ 13 5/8" SM x 11" 31~ Unoeal 909 W. 9th Avenue Anchorage, AK 99501 907-263--7684 Fax 907-263.7884 fax, r a n s m i t t al to: fax number: I1.... I ................ LIJ['i?L:.ZZ~.Z¥;Z ~ .. ................ -_-I date: .. I IJ IIII1! I I I II re: II . iiiiiii i pages: NOTES' · .JJll~ll Il.II I ,,----. STATE OF ALASKA ~-.,~ ALASK/ L AND GAS CONSERVATION CC IISSION REPORT OF SUNDRY WELL OPERATIONS 1. OPerations performed: Operation shutdown __ Stimulate Pull tubing Alter casing__ Plugging __ Perforate Repair well __ Pull tubing X 6. Datum elevation (DF or KE~/ 75' RKB above MLW 7eet 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O; Box 196247, Anchorage, AK 99519-6247 5. Type of Well: Development X Exploratory Stratigraphic Service Location of well at surface Leg #1, Conductor #4 1940' FNL, 543' FWL, Sec 31, T9N, R12W, S.M. At top of productive interval At effective depth At total depth 1882' Fsi, 837' FWL, Sec 31, T9N, R12W, S.M. 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 11 9. Permit number/approval number 67-J~0017/93-011 10. APl number 50-733-20013 11. Field/Pool Kenai/Lower Kenai 12. Present well condition summary Total depth: measured 9543' true vertical 9275' Effective depth: measured 9428' true vertical 9161' feet feet feet feet Casing Length Size Structural Conductor 592' 20" Surface 2943' 13-3/8" Intermediate 9508' 9-5/8" Production Liner 3762' 7" Perforation depth: measured See attached sheet Plugs (measured) Junk (measured) Cement Plug @ 9428 KOBE BHA @ 9041' DPM Cemented Measured depth True verticaldepth 1345 SXS 622" 622' 3250 SXS 2975' 2950' 2300 SXS 9541" 9276' 700 SXS 5712-9474 5463-9206' true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) L.S. 2-7/8", 6.4#, N-80 @ 7348' S.S. 2-7/8", 6.4#, N-80 x 2-3/8" 4.6#,N-80 @ 7297' ECEIVED 13. Stimulation or cement squeeze summary See attached sheet Intervals treated (measured) Treatment description including volumes used and final pressure APR - 5 1993 Alaska Oil & Gas Cons. C0mmiss~o~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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_egoing is tru~ and.correct to_the best of my knowledge. Signed G. RussellSchmidt Reqional Drilling Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE BAKER PLATFORM BA #11 BAKER PLATFORM BA #11 9428' PBTD DAY 1 (02/01/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI MIX 5% KCL WTR & RU TO CIRC WELL. A3-rEMPT TO CIRC DN SS, NEGATIVE. NO ANNULUS PRESS INCR. CIRC SS X LS TAKING RETURNS TO PROD. LUBRICATE ANN W/90 BBLS KCL WTR. OBSERVE WELL. SET BPV & ND TREE. BA #11 9428' PBTD DAY 2 (02/02/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI NU BOPE. CONDUCT ABANDON PLATFORM DRILL. PERFORM BOP TEST. FAILURE ON CHOKE MANIFOLD, REPAIR SAME. CONT BOP TEST. BA #11 9428' PBTD DAY 3 (02/03/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI CMPT BOP TEST, PULL BPV & INSTALL LANDING JTS. RU WL UNIT. TBG PUNCH SS AT 9032' WLM. CIRC SS X ANNULUS TO PROD UNTIL CLEAN. RU & ATTEMPT TO PULL DUAL TBG STRING, NEG. RU WL & RIH W/TBG CUTTER. CUT SS AT 9047' WLM, TBG FREE. POOH, LAY DN 3-1/2" & 2-3/8" TBG. RECEIVED APR - 5 ]993 Alaska Oil & Gas Cons. Commission Anchorage BAKER PLATFORM BA #11 BA #11 9428' PBTD DAY 4 (02/04/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI CONT POOH & LAY DN TBG F/SS SIDE ONLY. A'I-I'EMPT TO PULL LS FREE, NEGATIVE. RU WL & RIH W/TBG CU'I-rER. CUT LS AT 9046' WLM, TBG FREE. POOH, LAY DN 2-7/8" TBG. CHG RAMS TO 3-1/2". BA #11 9041' ETD DAY 5-7 (02/05-07/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI CMPT RAM CHG & TEST SAME, OK. MU 6" BIT W/7" CSG SCRAPER BHA. RIH TO 9041' ETD, CBU. POOH, LAY DN DP. CHG RAMS & TEST SAME. RU & RIH W/DUAL TBG & KOBE COMPLETION, HYDROTEST SAME TO 5000 PSI. BA #11 9041' ETD DAY 8 (02/08/93) 9-5/8" C @ 9541' 7"L F/5712'-9474' 452 PSI LAND DUAL TBG HGR W/LS TBG TAIL 7348'. SET BPV ON SS RU WL UNIT & RIH ON LS W/2.25" GAUGE RING TO 7912' WLM. POOH. ND BOPE. NU TREE & TEST SAME TO 3000 PSI, OK. INSTALL FLOW LINES & MANIFOLD. SKID RIG F/LEG #1 TO LEG #2, BA #27. RELEASE RIG AT 2400 HRS. RECEIVED APR - 5 199; Alaska 0il & Gas Cons. Commiss[ol'~ Anchorage I 20" 94# @ 622' i CEMENTED WITH 1345 SX i A 13 3/8" 54.5 ~ 61# @ 2~75' CEMENTED WITH 3250 SX TUBING DETAIL: LONG STRING: 2-7/8", 6.4.5, N-80 1) CIW 11" 5K DCB HANGER 2) XO 2-7/8" X 2-7/8" (PXB) AT 7297' 3) KOBE 2- 1/2" TYPE "BB" AT 7316' 4) XO 2-7/8" X 2-7/8" (PxP) 73 17' 5) 2-7/8" RE-ENTRY GUIDE AT 7548' 9 5/8" 40, 43.5# @ 9541' ___ -_ SHORT STRING CEMENTED WITH 2500 SX (2 STAGES) __ B -- A) 2-7/8", N-80, 6.4#, BTSC AT 5670' I -- ' ' ~ -- B) 2-5/8", N-80, 4.6#, BTSC AT 7294' --- -- C) XO 1-1/2" lORD x 2-5/8" BUTT (PxB) __ CEMENTED WITH 700 SX --- -- 2 APR - 5 199; ! Alaska Oil & Gas Cons. Commissior~ ! C Anchorage 5 ~~ PERFORATIONS: SEE ATTACHED '4 -- MAX INCLINATION 28.5 DEG FISH' TOP AT 904 1' DPM 5) 2-7/8" BUTT x 2-7/8" 8RD XO AT 9048' 5 E) 6) 2 7/8" 8RD PUP AT 9054' 6 E 7) NATIONAL TYPE "V" CAVITY AT 9075' 7 []~~' 8) 2 7/8" EUE 8RD TAIL PIPE AT 9106' ! i 9) 2 7/8" RE-ENTRY GUIDE AT 9107' 9 ///.///////l/,j ' D) 2 3/8" BUT x 1-1/4" 10 RD X O AT 9048' Z k% E) 1-1/4" 10 RD PUP AT 9058' : __ BAKER # 1 1 DRAWN: CLL COMPLETION SCHEMATIC SCALE: NA UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DATE' 02-22-95 9 '///////// MGS 17595 #11 PERFORATION RECORD TYONEK A POOL BEHIND 7" CASING 5840-5850 5589-5599 BEHIND 7" CASING 5895- 5905 5644-5654 TYONEK B, C, D BEHIND 7" CASING 6105-6115 5753-5763 POOL BEHIND 7" CASING 6180-6190 5927-5937 BEHIND 7" CASING 6210-6220 5957-5967 BEHIND 7" CASING 6225-6265 6003-6013 BEHIND 7" CASING 6297-6307 6043-6053 BEHIND 7" CASING 6340-6350 6086-6096 BEHIND 7" CASING 6450-6460 6195-6205 BEHIND 7" CASING 6480-6490 6225-6235 ~ BEHIND 7" CASING 6535-6545 6279-6289 BEHIND 7" CASING 6580-6590 6324-6334 BEHIND 7" CASING 6645-6655 6388-6398 BEHIND 7" CASING TYONEK E, F, G POOL BEHIND 7" CASING 676O-6770 BEHIND 7" CASING OPEN OPEN CEMENT SQUEEZED CEMENT SQUEEZED CEMENT SQUEEZED CEMENT SQUEEZED CEMENT SQUEEZED OPEN OPEN OPEN OPEN 6795-68OO 684O-685O 7105-7115 7145-7155 7415-7425 7440-7450 7680- 7745 7750- 7765 7780-7800 786O-792O 7950-8035 8060-8070 8120-8140 TYONEK E, F, G POOL 6413-6512 6537-6542 6581-6591 6745-6755 6884-6894 7152-7162 7177-7187 7416-7481 7486-7501 7516-7536 7596-7656 7685-7770 7795-7805 7855- 7875 OPEN 8170-8215 7905- 7950 RECEIVED APR - 5 199~ Alaska 0JJ & Gas Cons. Commissio~ Anchorage MGS 17595 #11 PERFORATION RECORD OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN TYONEK E, F, G OPEN POOL 8240-8310 7975-8045 8350-8470 8085-8205 8505-8555 8240-8290 8615- 8680 8350- 8415 8685-8720 874O-8770 8420-8455 8475-8505 8535-8654 8800-8920 8935-8968 8669-8702 8975-9000 8709-8734 9020- 9050 8754- 8784 RECEIVED APR - Alaska Oil & Bas Cons. Commission: Anchorage UNOCAL TUBULAR DETAIL WELL #: Baker Platform Well BA--11 PAGE 1 o[ 1 DA TH: February 06,1993 AFE NO.; 731404 STRING: Long String; 2--7/8~, 6. 4~, N--80, SC Buttress Tubing: KOBE Completion FOREMAN: 1 2-7/8" Guided Muleshoe 2-7/16 3-7/16 0.8 7347.2 7348 1 Joint 2-7/R', 6.4#, N-80, SC Buttress Tubing 2.441 3.220 30.53 7316.67 7347.2 1 Cross Over, 2-7/8" Buttress Pin x 2-7/8" EUE Pin 2-7/16 3-1/16 0.51 7316.16 7316.67 1 Coupling; 2-7/8" EUE 3-5/8 0.44 7315.72 7316.16 KOBE Assy; 2-1/2" Type B, Parallel DBL w/X/O Body, Ser.# ANC.93-1-11 19 7296.72 7315.72 1 Cross Over, 2-7/8" Buttress Box x 2-7/8" EUE Pin 0.58 7296.14 7296.72 1 Pup Joint; 2-7/8", 6.4#, N-80, SC Buttress 2.441 3.220 8.13 7288.01 7296.14 238 Joints 2-7/R', 6.4#, N-80, SC Buttress Tubing 2.441 3.220 7255.64 32.37 7288.01 1 Cross Over, 2-7/8" Buttress Pin x 3-1/2" Buttress Pin 2-7/16 3-7/16 0.37 32 32.37 1 CIW 11", 5K, DCB Hanger 0.78 31.22 32 KB 31.22 0 31.22 0 0 0 0 o! 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 iD i_"~1" I1t "!"~ o 0 Copy To: Well Files 02/25/93 ~ P8 -- ~ 19S 5 0 Copy To:L. Lohoc£cr A]gl~k~ Clil % fi~.~ [';nn.~. ( un't~i$Sio' 0 Copy To: ~g Ahab oraoe o Copy To: C. Faulkner 0 0 UNOCAL TUBULAR DETAIL WELL ~: Baker Platform, iWcli# BA-11 PAGE 1 o[ 2 DA TH: February 06, 1993 AFE NO.; 731404 sTRING: $1~ort Striag; 2-3/8~, 4.6#, N-80, SC Buttressing.... ~~~ C~fJiou FOREMAN: Don Byrue _ t: ,~e~n.~ 1-1/2 2-3/4 2.33 7294.39 7296.72 1 Cross Over; 1-1/2" 10rd. Pin x 2-3/R' Buttress Box A PR /J iooo 1 1.995 2.7 4.13 7290.26 7294.39 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress T~t~bing 1 Joint 2-3/R', 4.6#, N-80, SC Buttress Tubin~l~i~/(aA! 0i] & Gas (~0t]$. G0ffll~l]$,~ ~995 2.7 27.83 7262.43 7290.26 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing ~[}l~[lot'a~{} 1.995 2.7 8.18 7254.25 7262.43 7 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jts. #2-8} 1.995 2.7 203.82 7050.43 7254.25 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.13 7042.3 7050.43 5 Joints 2-3/87, 4.6#, N-80, SC Buttress Tubing {Jts. #9-13} 1.995 2.7 145.92 6896.38 7042.3 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.16 6888.22 6896.38 3 Joints 2-3/87, 4.6#, N-80, SC Buttress Tubing {Jts. #14-16} 1.995 2.7 86.5 6801.72 6888.22 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.15 6793.57 6801.72 4 Joints 2-3/8~', 4.6#, N-80, SC Buttress Tubing {Jts. #17-20} 1.995 2.7 115.66 6677.91 6793.57 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.1 6669.81 6677.91 5 Joints 2-3/87, 4.6#, N-80, SC Buttress Tubing {Jts. #21-25} 1.995 2.7 147.32 6522.49 6669.81 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.22 6514.27 6522.49 4 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #26-29} 1.995 2.7 114.87 6399.4 6514.27 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.17 6391.23 6399.4 4 Joints 2-3/87, 4.6#, N-80, SC Buttress Tubing {Jts. #30-33} 1.995 2.7 116.39 6274.84 6391.23 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.11 6266.73 6274.84 3 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #34-36} 1.995 2.7 87.97 6178.76 6266.73 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.16 6170.6 6178.76 4 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #37-40} 1.995 2.7 116.45 6054.15 6170.6 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.15 6046 6054.15 4 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #41-44} 1.995 2.7 114.27 5931.73 6046 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.23 5923.5 5931.73 4 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jts. #45-48} 1.995 2.7 118.21 5805.29 5923.5 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.11 5799.18 5805.29 3 Joints 2-3/8~', 4.6#, N-80, SC Buttress Tubing {Jts. #49-51} 1.995 2.7 86.73 5712.45 5799.18 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 8.12 5704.33 5712.45 5 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #52-56} 1.995 2.7 146.24 5558.09 5704.33 ._ 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.22 5551.87 5558.09 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #57-58} 1.995 2.7 57.34 5494.53 5551.87 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.12 5488.41 5494.53 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #59-60} 1.995 2.7 57.33 5431.08 5488.41 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.15 5424.93 5431.08 3 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jts. #61-63} 1.995 2.7 85.41 5339.52 5424.93 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.1 5333.42 5339.52 2 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jts. #64-65} 1.995 2.7 57.79 5275.63 5333.42 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.12 5269.51 5275.63 3 Joints 2-3/~', 4.6#, N-80, SC Buttress Tubing {Jts. #66-68} 1.995 2.7 86.94 5182.57 5269.51 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.14 5177.43 5182.57 3 Joints 2-3/87, 4.6#, N-80, SC Buttress Tubing {Jts. #69-71} 1.995 2.7 87.22 5090.21 5177.43 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.2 5085.01 5090.21 2 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jts. #72-73} 1.995 2.7 57.05 5027.96 5085.01 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.18 5021.78 5027.96 UNOCAL TUBULAR DE s'AIL 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #74-75} 1.995 2.7 56.19 4965.59 5021.78 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.24 4959.35 4965.59 3 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #76-78} 1.995 2.7 86.7 4872.65 4959.35 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.8 4866.85 4872.65 3 Joints 2-3/8", 4.6#, N-80, SC Buttress Tubing {Jla. #79-81} 1.995 2.7 87.49 4779.36 4866.85 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.14 4774.22 4779.36 2 Joints 2-3/8~', 4.6#, N-80, SC Buttress Tubing {Jla. #82-83} 1.995 2.7 57.68 4716.54 4774.22 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.23 4711.31 4716.54 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #84-85} 1.995 2.7 57 4654.31 4711.31 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.16 4649.15 4654.31 6 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #86-91) 1.995 2.7 175.9 4473.25 4649.15 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.08 4468.17 4473.25 3 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #92-94} ~.995 2.7 87.36 4380.81 4468.17 I Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.16 4374.65 4380.81 3 Joints 2-3/8~', 4.6#, N-80, SC Buttress Tubing {Jla. #95-97} 1.995 2.7 87.43 4287.22 4374.65 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.11 4282.11 4287.22 4 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jts. #98-101} 1.995 2.7 116.26 4165.85 4282.11 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.12 4160.73 4165.85 4 Joints 2-3/g', 4.6#, N-80, SC Buttress Tubing {Jla. #102-105} 1.995 2.7 115.78 4044.95 4160.73 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.12 4038.83 4044.95 3 Joints 2-3~', 4.6#, N-80, SC Buttress Tubing {Jla. #106-108} 1.995 2.7 86.74 3952.09 4038.83 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.16 3946.93 3952.09 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #109-110} 1.995 2.7 57.06 3889.87 3946.93 I Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 6.11 3883.76 3889.87 3 Joints 2-3/8~', 4.6#, N-80, SC Buttress Tubing {Jla. #111-113) 1.995 2.7 85.55 3798.21 3883.76 I I Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 5.11 3793.1 3798.21 2 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #114-115) 1.995 2.7 58.05 3735.05 3793.1 1 Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 4.05 3731 3735.05 I Joint 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jt. #116} 1.995 2.7 29.79 3701.21 3731 I Cross Over; 2-3/g' Buttress Pin x 2-7/~' Buttress Pin 2 ~,-13/16 0.4 3700.81 3701.21 I Coupling; 2-7/8" Buttress 3-3/8 0.71 3700.1 3700.81 122 Joints 2-3/R', 4.6#, N-80, SC Buttress Tubing {Jla. #117-238) 1.995 2.7 3669.78 30.32 3700.1 Correction Factor -3.15 33.47 30.32 I Pup Joint; 2-3/8", 4.6#, N-80, SC Buttress Tubing 1.995 2.7 1.1 32.37 33.47 I Cross Over; 2-7/g' Buttress pin x 3-1/2" Buttress Pin 2-7/16 3-7/16 0.37 32 32.37 Hanger 0.78 31.22 32 KB 31.22 0 31.22 i::!:~::::::::i::ii::::i::::i:::::!:::::!i:::::::::::::i:::i::::!:::::::iii:i::i:::i::::~::::::::::i::i::~::i::::::~::i!::::ii::!~~i:~!:~i!~::~!~::~::i::!::i::!::::::!::::::ii::!::~!iii::~::ii~:!ii~::::~!ii::i::!~:::~:~:::!~!::::::i~::?:i~!~i o .-...-.-.-.-:..... :-.-...-...-~. ~. :-:-:-~......-.....-:..-...-.. :..-.-...-.-.-.-...-.-.-.......-....-.-.-.-~-:-...-:-.-~. :..-.-:-.-...-.....-.-.....-.-.-.-.-.-...-.-.-.-...-.-...v.-.-.-.-.-.-.-.-.-...-.-.-.-.-.....-...-.-.......-.-.......-.-.....-.....,.-...... :::::::::::::?...::~.....:...:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.~.::::.:~ .............. ~O~'-l:7:x.:l.'.810~:T~d.~.:FactOt:.:=.:.:~;t:lO-~:.:.:Z ..... Ran:-:l~:.:Well ............ 0 · :.:.:.:.:.:.:...: .: .............~:....... :.: ....... :.....~:...:.........: ... :.: ............... :...:....-......:...................: .....:.....:...:... :.......:. :.:. :. :.: .:...... ..... ...~..............-.~.:...................:.........:.:.......:..........+:+:+: ·:~:~.:.:~:~:~:~~~~~:~:.:~:::.:~:.:::.:.:.:.:.:~:.:~:.:~:~:.:.:.:~:.:~:~~.:.:~:.:.:::.:.:.:::.:~:~:~:.:.:::~:.:.::~~:~:.:~:~:~~.:.~.~:~~:::::.:~.:~:.:~.~...~ ~~~.~...~.~~.~.:.:.:~:.:.:.:.:.:.~.~~:~:.:~~.:.:.:.:.~~:.:.:.:.:.:~:.:~~:::.:.:.:~:.:.:.:.:.:.:.:. ...:.:.:.:.:.:.:.:+:.:.:+:.:.:.:.:.:.:.:.:~:.:.:.~.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.~ ·" '.: ' · :.:.:.:+: · :.:.:+:.:~:.:.:.:.' - '.:.' ...... .:.' -.: '~:- - ..:.:.:.:.:.:.:.:.:~:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:: +:+: :c ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i~ ~ ~ I' ! % # ~" F% 0 Copy To: Wcll Filcs 02/25/93 0 copy to: L. ~oh,,¢[,r ~l:'R - 5 1993 0 Copy To: R/g ~:tele~ fli R, P~e P. nn_~_ {;l]mffli 5$tb'r 0 Copy TO: C. Faulkner ~no. hnr; mn. 0 WELL #: Baker Platform, Well# BA--II PAGE 2 of 2 DATE - February 06, 1993 AFE NO. ' 731404 STRING: Short String; 2-3/8", 4.6#, N-80, SC Buttres~ Tubing, KOBE Completion FOREMAN: Don Byrne UNOCAL~) From the desk of Lee Lohoefer RECEIVED JAN 2 0 1993 Oil & 6as cons. commissior~ :Anchorage r .~-..~ STATE OF ALASKA ALASKA' AND GAS CONSERVATION COIV~SSION APPLICA ilON FOR SUNDRY APPROVALS Abandon __ Suspend Operations shutdown __ Re-enter suspended well__ Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program ~ Pull tubing __ Variance __ Perforate X Other__ 5. Type of Well: 6. Datum elevation (DF or KI~)~ 1. Type of request: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address , P.O. Box 196247, Anchorage, AK 99519-6247 Location of well at surface Leg #1, Conductor #4 1940' FNL, 543' FWL, Sec 31, T9N, R12W, S.M. At top of productive interval 1973' FSL, 847' FWL, Sec 31, T9N, R12W, S.M. At effective depth 1886' FSL, 828' FWL, Sec 31, T9N, R12W, S.M. At total depth 1882' FSL, 837' FWL, Sec 31, T9N, R12W, S.M. Development X 101' RKB above MLW Exploratory Strafigraphio SenAte RECEIVED JAN 0 1993 Alaska 0ii & Gas Cons. OoramissiO~ Anchorage 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 11 9. Permit number 67-00017-0 10. APl number 50-733-20013-00 11. Field/Pool Middle Ground Shoal 12. Present well condition summary Total depth: measured 9543' true vertical 9275' Effective depth: measured 9428' true vertical 9161' feet feet Plugs (measured) Cement Plug @ 9428 feet Junk (measured) feet Casing Length Size Structural Conductor 592' 20" Surface 2943' 13-3/8" Intermediate 9508' 9-5/8" Production Liner 3762' 7" Perforation depth: measured See attached sheet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 1345 SXS 622' 622' 3250 SXS 2975' 2950' 2300 SXS 9541' 9276' 700 SXS 5712'-9474' 5463-9206' 13. Attachments LS: 2-7/8", 6.4#, N-80 @ 9107' SS: 3-1/2", N-80 X 2-3/8" N-80 @ 9050 Description summary of proposal X Detailed operations programX__ BOP sketch X -- 14. Estimated date for commencing operation 16. If proposal was verbally approved Name ~qf approver 17. I here~e~ fo~and Signed G. Russell Schmidt Date approved 5. Status of well classification as: Oil X__ Gas __ Suspended __ Service correct to the best of my knowledge. Title Reqional Drilling Manager FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Location clearance Subsequent form required 10- David W, johnston l Approval No. I "Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ~ x75~5 ZONE CONDITION MEASURED TRUE VERTICAL DEPTH (FT) DEPTH (FT) TYONEK A POOL BEHIND 7" CASING 5840-5850 5589-5599 BEHIND 7" CASING 5895-5905 5644-5654 TYONEK B,C,D BEHIND 7" CASING 6105-6115 5753-5763 POOL BEHIND 7" CASING 6180-6190 5927-5937 BEHIND 7" CASING 6210-6220 5957-5967 BEHIND 7" CASING 6225-6265 6003-6013 BEHIND 7" CASING 6297-6307 6043-6053 BEHIND 7" CASING 6340-6350 6086-6096 BEHIND 7" CASING 6450-6460 6195-6205 BEHIND 7" CASING 6480-6490 6225-6235 BEHIND 7" CASING 6535-6545 6279-6289 BEHIND 7" CASING 6580-6590 6324-6334 BEHIND 7" CASING 6645-6655 6388-6398 BEHIND 7" CASING 6760-6770 6413-6512 BEHIND 7" CASING 6795-6800 6537-6542 BEHIND 7" CASING 6840-6850 6581-6591 TYONEK E,F,G OPEN 7105-7115 6745-6755 POOL OPEN 7145-7155 6884-6894 CEMENT SQUEEZED 7415-7425 7152-7162 CEMENT SQUEEZED 7440-7450 7177-7187 CEMENT SQUEEZED 7680-7745 7416-7481 CEMENT SQUEEZED 7750-7765 7486-7501 CEMENT SQUEEZED 7780-7800 7516-7536 OPEN 7860-7920 7596-7656 OPEN 7950-8035 7685-7770 TYONEK E,F,G OPEN 8060-8070 7795-7805 Poo f I\/1 JAN Alaska Oil & Gas Cons. L;ommissior~ Anchorage MGS X7595 ~IX Perforation Record TYONEK E,F,G OPEN 8120-8140 7855-7875 POOL OPEN 8170-8215 7905-7950 OPEN 8240-8310 7975-8045 OPEN 8350-8470 8085-8205 OPEN 8505-8555 8240-8290 OPEN 8615-8680 8350-8415 OPEN 8685-8720 8420-8455 OPEN 8740-8770 8475-8505 OPEN 8800-8920 8535-8654 OPEN 8935-8968 8669-8702 OPEN 8975-9000 8709-8734 TYONEK E,F,G OPEN 9020-9050 8754-8784 POOL RECE V LD ,,JAN t 0 'bg~ Alaska 0il & Gas gons. Anchorage 17595 #11 WORKOVER BUDGET ESTII~TE PROCEDURE 1. MOVE RIG OVER MGS 17595 #11, LEG #1, SLOT #4. 2. KILL WELL WITH COMPLETION FLUID. 3. INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP BOPE. 4. PULL AND LAY DOWN DUAL KOBE PROD STRING. 5. RUN 7" SCRAPER TO 7100'. 6. SET CEMENT RETAINER AT 7060' TO ISOLATE "EFG". SQUEEZE FOR ABANDONMENT. 7. RUN CASED HOLE LOGS. 8 RUN DUAL KOBE PRODUCTION STRING. 9. INSTALL BPV'S, NIPPLE DOWN BOPE, NIPPLE UP TREE. 10. WIRELINE PERFORATE (THRU TUBING) "ABCD". DAYS 3/4 3/4 1/2 1-3/4 1/2 1-1/2 1-3/4 1/2 10 DAYS RECEIVED Alaska OiJ & Gas Cons. Commission Anchorage BAKER WELL NO. 11 LEG 1, SLOT 4 ADL 17595 SPUD 5/15/67 2 ~ 1/a' BUl'r X 2 7/11 BUTT XO [ 2 ~1, BUTf. N~0 TtJSI~G eOel ~ 2 7/I, BUl'f IKJP fL 2 7/1' BIJTfX 2T/I' IflD XC) g041 & ZT/ll iflD KJP gOSi & 2 7/~ EL~ ~D TM. I~E A. a 1/2' 8UI'T N-e0 t2aP TBG B. 11/2' BUT'f X 2 ~fl' BUTT XC) C, 2 ar~ BUTT N~0 ~LM TB(3 D. 2:~ff BUTTX 1 1141 lORD XD F_t 114' 10 RD IKJ~ 7 FILL-UP KILL LINE ANNULAR BOP 135/s"3000 psi PIPE RAMS 13%"5000 psi BLIND RAMS 13%"5000 psi FLOW I ]DRILLING[ [b--.[~/N-I-' SPOOL --[]"-.. --~:>- ~,~/~.5ooo ps~ C H 0 KE 4" 5000 psi I ~ 4' 5000 psi [ [ PIPE RAMS ] 135/~'6000 psi LINE==~::> RISER 13%" 5000 psi 41aska OJJ & Gas Coas. Commission COOK INLET PLATFORMS BOPE STACK 13 %" 5000 psi TO 10" CROWN VENT BLOW DOWN GAS BUSTER 10" TO SHAKER SWACO CHOKE TO CHOKE PANEL NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. TO BOPE MANUAL SWACO CHOKE ii CHOKE MANIFOLD Unocal PLATFORM RIGS 4-1/16" & 3-1/§", 5M MSP '"~" STATE OF ALASKA -"~' ~ i'ii i b i i~ ~ Al_AC, , OIL AND GAS CONSERVATION COMMtSc ,~1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Pedorate __ Pull tubing m Alter casing __ Repair well __ Pull tubing ~ Other 2. Name of Operat[~I3NOCAL ) Union Oil Company of California 3. Address P.O. BOX 196247, Anch., AK, 99519 4. Location of well at surface Leg # 1, Slot # 4 1940' FNL & 543' FWL, Sec 31, T9N, At top of productive interval 7105 ' 1973' FSL & 847' FWL, Sec 31, 9428' At effective depth 1886' FSL & 828' FWL, Sec 31, 9543' 5. Type of Well: Development Exploratory Stratigraphic __ Service __ R12W, SM T9N, R12W, SM T9N, R12W, SM T9N, R12W, SM 6. Datum elevation (DF or KB) 79 ' feet 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 11 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9,543' 9,275'f~t ~et 9,428' 9,161' feet Plugs (measured) J u nk (measu red) Casing Length Structural Conductor Surface 592 ' 2943' Intermediate 95'08 ' Production 3762 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented 20" 1345 SX 13-3/8" 3250 SX '9-5/8" 2300 SX 7" 700 SX See attachment A LS: 2-7/8", SS: 3-1/2" Packers and SSSV (type and measured depth) None 9. Permit number/approval number & ?--/';' =,, 10. APl number 50-- ?~-..~,~,~/.~, --o o ..~., 11. Fielg~lai/Lower Kenai Measuredde~h ~ueverticaldepth 622' 622' 2975' 2950' 9541' 9273' 5712'-9474' 5463'-9206' 6.4#, N-80 @ 9107' N-80 X 2-3/8" N-80 @ 9050' RECEIVED JAN 2 7' %992 13. Stimulation orcementsqueezesummary See attachment "B" Alaska 0il & Gas Cons. bummiSSJO" Intervalstreated(measured) 2058 gal 7.5% HCL, 2~¢h~l'[igl~ene 8484 gal 7.5% HCL, 1290 psi Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 0 0 0 10 22 133 116' Status of well classification as: Oil ~ Gas_ Suspended __ 15. Attachments Copies of Logs and Surveys run ._.. Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and cOrrect to the best of my knowledge. Title Service Regional Drilling Manager Gary S. ~a~sh F°rm 10'404 Rev 06/15/8~ 6 " Date SUBMIT IN DUPLICATE ATTACHMENT "B" EFG: TREATED INTERVALS (12/17/91) BAKER WELL #11, MIDDLE GROUND SHOALS 17595 MEASURED TRUE DEPTH VERTICAL DEPTH CONDITION 7105-7115 6745-6755 OPEN 7145-7155 6884-6894 OPEN 7860-7920 7596-7656 OPEN 7950-8035 7685-7770 OPEN 8060- 8070 7795- 7805 OPEN 8120-8140 7855-7875 OPEN 8170-8215 7905-7950 OPEN 8240-8310 7975-8045 OPEN 8350-8470 ' 8085-8205 OPEN 8505-8555 8240-8290 OPEN 8615-8680 8350-8415 OPEN 8685-8720 8420-8455 OPEN 8740-8770 8475-8505 OPEN 8800-8920 8535-8654 OPEN 8935-8968 8669-8702 OPEN 8975-9000 8709-8734 OPEN 9020-9050 8754-8784 OPEN RECEIVED JAN 2/' ~992 Alaska 0ii & (Jas Cons. ~,~mmisslo~ Anchorage BAKER #11 COILED TUBING CLEANOUT HISTORY DATE ETD COMMENTS 12/10/91 9047 ' (AFE #311513) FINISHED WELDING GAS BUSTER DERRICK VENT LINE AND WATER LEG RETURN LINE TO THE SHAKERS. RIGGED UP SLICKLINEAND RIH WITH A 1.75" DRIVE DOWN BALER TO 9047'. MARKS ON THE BALER INDICATED THE STANDING VALVE SEAT WAS FREE OF SAND. RIH WITH THE OTIS 22' DUMMY PUMP AND SET IT IN THE NATIONAL BOTTOM HOLE ASSEMBLY. RIGGED DOWN OTIS AND UNLOADED THE COILED TUBING UNIT 12/11/91 9190' RECEIVED JAN 2 ? 3992 Alaska 0tl & ( as Cons, mmissio " Anchorage CONTINUED TO RIG UP COILED TUBING AND SURFACE EQUIPMENT. MIXED 200 BBLS OF 3% KC1. PRESSURE TESTED THE SURFACE EQUIPMENT AND BOPE TO 3500 PSI, OK. RIH WITH A 1.5" OD WASH NOZZLE ON 1.25" COILED TUBING TO 9000'. DISPLACED THE TUBING VOLUME OF OIL TO PRODUCTION. STARTED WASHING DOWN AT 1 BBL/MIN SLOW GOING FROM 9052' -9062'. LOST RETURNS WHILE WORKING THE COILED TUBING AT 9044'. THE 9-5/8" CASING PRESSURE INCREASED FROM 80 PSI TO 825 PSI IN 40 MINUTES FULL RETURNS WERE SEEN. FLUID LEVEL PRIOR TO THE JOB WAS 600' INDICATING A 34 BBL GAS CAP. CONTINUED WASHING FROM 9062' TO 9190'. WASHED FOR 45 MINUTES AT 9190' WITH NO HEADWAY. DURING THE CLEANOUT BRIDGES WERE ENCOUNTERED AT 9080', 9098', 9184', AND 9189'. PUMPED 2.0#/BBL XCD PILLS AT 9120', 9170' AND 9190' FOR A TOTAL OF 30 BBLS OF XCD PUMPED. POOH AND BEGAN RIGGING DOWN THE COILED TUBING UNIT. 12/12/91 9190' UNABLE TO CLOSE MASTER VALVE ON THE TREE. MOITORED WELL, STABLE. RIGGED DOWN THE COILED TUBING INJECTOR HEAD. FOUND NATIONAL DUMMY PUMP IN THE TREE. LAID DOWN THE DUMMY PUMP, SHUT IN THE WELL, RIGGED DOWN COILED TUBING UNIT. 12/17/91 9190' (AFE #311518) RIGGED UP ACID PUMP AND TESTED LINES TO 3500 PSI. PUMPED 49 BBLS (2058 GAL) OF 7.5% HC1 WITH 20% XYLENE. DISPLACED WITH 53 BBLS 3% KCl WHILE TAKING RETURNS TO PRODUCTION. SHUT THE WELL IN FOR 2 HRS. PUMPED 90 BBLS (3780 GAL) OF 7.5% HCl AND THEN SHUT IN THE FLOW LINE TO PRODUCTION. PUMPED AN ADDITIONAL 112 BBLS (4704 GAL) 7.5% HCl. DISPLACED WITH 45 BBLS 3% KCl. FINAL PRESSURE 1290 PSI AND 0.4 BPM. RIGGED DOWN ACID EQUIPMENT. ,-.. STATE OF ALASKA Al,~ '~A OIL AND GAS CONSERVATION COMMIt'-'~." N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator J 5. Tw3e of Well: . Union Oil Company of California (.UN~entX | Exploratory __ 3. P.O. BOX 196247, Anch., AK, 9t519-6~a Address t t~.raphic Service ~ 4. Location of well at sudace Leg #2, Slot. 2, ~Platform Dillon 699' ESL, 1872' YWL, Sec. 35, TSN, R13W, SM At top of productive interval Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension ~ Stimulate __ Perforate ~ Other 2512' FSL, 2537' FWL, Sec. 35, T8N, R13W, SM Ateffectivedepth 2560' FSL, 2482' FWL, Sec. 35, T8N, R13W, SM ~t~aldepth 2578' FSL, 2466 FWL, Sec. 35, T8N, R13W, SM 6. Datum el~t~9 (D~r I~L 7. Unit or Pr%j:~~ 8. Well number 9. Permit number 68-32 10. APl number 50-- 733-20104 11. Field/Pool SMGS/Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10508 ' feet Plugs (measured) 10,325 ' 10170' feet 10,417' Effective depth: measured true vertical Casing Length Structural Conductor 5 6 4 ' Surface 19 6 6 ' Intermediate Production 9 6 4 7 ' 1073' Liner Perforation depth: measured true vertical 10325'fe~ 9996'feet Junk (measured) Size Cemen~d Me~ureddeCh ~uevenicalde~h 20" 1205 SX 605' 605' 13-3/8" 1600 SX 2001' 1975' 9-5/8" 1150 SX 9676' 9356' 7" 210 SX 9429'-10502' 9110'-10164' See attachment Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2#, N-80, Dual @ 9272' 2-7/8", 6.5#, N-80, Single @ 10,128' Baker Model F-1 @ 9,320' Baker Model F-i @ 10,120' ECEIVED 13. Attachments Description summary of proposal __ Detailed operations program .,~ BOP sketch __ DEC - 9 199 14. Estimated date for commencing operation ! 15. Status of well classification as: Alaska OiJ & 6as 60~s. 6ommi~ October 28 t 19 91 ~ Oil __ Gas__ Suspended .~ Anchorage 16. If proposal was verbally approved I Name of approver Date approved ! Service 17. I hereby certify~h~t the foregoing is tru_.ge and correct to the best of my knowledge. Signed ~ARY.-~r. BUSH . Title REGIONAL DRILLING MAWR tt - Conditionsofappro~: ~ FOR COMMISSION USEONLY IApproval No. Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ?/-' -/ Mechanical Integrity Test ~ Subsequent form required 10- ,,~' ,,,,---.:~ -' ORIGINAL SIGNED BY I,,~~ LONNIE C. SMITH ~Commissioner Approved by order of the Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE sion RECEIVED D~C - 9 ~,991 Alaska Oil & Gas Cons. Commission Anchorage Spud Date= Surf=c~ Loc.tlon: Subsurface Locatlom ~oYatlon: TI:): PBD: C=dng: Perforations: InlUal Potential: !nltlal Stimulation: · :. _~_48ervelr Dat.&.'._ Cored Intm'Yals: DST Intlwel~ and R~ulq:~: L,g SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO 11 HEMLOCK COHOLOMERATE PLATFORM DILLON 4/I 7/68 Leg 2, Slot 2. SUOS Platform Dillon 70~' Fsi.. le74' FWt. Sea. :IS. TaN. R13W !o - 2~70' F'st. 24ac' FIK. Se~. 3.5. TBN. n13W 110' KB-MSL 10506' I~D; 10170' 10320' TVD= 10417' 20". 8~ and 0_4~1 Cellng let (st co5' with 1205 ex. cement 13 3/8,54.51F Cedn. g let et 2001' with 1600 Ix. cement 9 ~", 4Q ~and 43.5dl S-SS and N-BO Casing Bt at 9676' with 11S0 Ix. cement ?'. 2.3.4t S--G5 Liner set at 9420-10502' w!~ 210 e~. cement O-3B: 9920-10000' 10010-- 10030' 10050-1008O' 10050-10110' G-4: 10140-10220' 102~0-I03!0' ~573 ~PD. g B~'D. ¢32 UCFO None _C.ompletion Record Long String: 1. Tubing Hanger 8. 3 1/~" Buttmee pups a. :3 1/2" N-BO Buttress tubing 4. Baker Model 'F' Seating Nipple 5. 2 7/B" Butt. XO x :3 1/2" Butt. XO w/collar 5. 2 7/8" Buttrese pup ~. Baker l ge-DA-60 Parallel flowhead 5. Baker 8" S~QI Iocctor sub g. Baker Seal A~sembly 10. 2 7/8" Buttress pup 11. 2 7/8" Buttress pup 12, Baker Model 'ir' Seating Nipple 13. 2 7/8" £UE XO x 2 7/8" pin w/cellar 14. Baker 0--22 Locater (turned to 4" o.d.) 15. Baker Seal A~sembly 16. Shear out sub Short String: A, 3 1/2" Buttress pup Jt~ B. 3 1/2" N-e0 Buttreae tubing C. Baker Model 'Fq Seating Nipple D. 3 1/2" Buttrees pup Jt E. 2 7/8" Y.O and 3 1/2" Buttress w/cellar F. 2 7/8" N-80 pup Jt i! 9739-0756% cut lt, moovemd 19'; g7:iB-g7S3', ~t 25% mcevemd 23.5' gg02-9ltl', o~ 10% No. Nd 18.5'i 6)' 9~1~9g48, ~t 27', ~o~d 25. gge8-gg76',.C~ 26% mc,lind 28'%~ gg76-ggg6', cut 20% mc,lind 14' _ eggO-lO002, ~t 8% NeoveHd S'~,v~ 10002-42', cut 40% ~oove~d 36.5' 10042-54', c~ 12', ~e~md 7'; 12)~ 10064-58% c~ 4% required 2.5' 13 100~8-B7', cut 29% ~eo~d 25'; 1~ 10087-69% cut 12% ~c~d g' 15 10006-126% Gut 27'. ~c~wid 29'T~ 101S6-38', cut 12~ ~e~md 10.5'; TT} 10136-67% ~t 25', ~c~d 25' 18 10167-07% e~ 30', ~o~Nd 30'; 1~)1)10157~216', ~t lg', recited IB' 20 10218-34% ~ 18% N~i~d 13.5'8~ 1~~'. c~ 26'. ~ve~d 24' 22 10255-79% out 2~', ~ewe~d 22' run 1/10/81) Depth 48' 9272' g273' 9306' 9310' 9312' 9312' 9324' 9357' 10104' 10105' 10106' 10107' 10127' 10128' ~1° 9269' 9271' 0307' 5308' 9310' PBTD 10325' TO IO508' ~¢'~& '! ~' 23~ Lher 0020' ~ 10110' I10310' South Middle Ground Shoal ADL 18746 Well No. 1 1 Procedure for suspending and freeze protecting well: 1) Run temperature survey from 9312' to surface. 2) Bullhead power oil down both strings to 100'. Both tubing strings will be protected against freezing by power oil at this point. 3) Run hose to 100' inside 9 5/8" casing X tubing annulus. Circulate power oil into 9 5/8" casing X tubing annulus taking returns up hose. The 9 5/8" casing X tubing annulus will be freeze protected at this point. 4) Install blind flanges on all wellhead outlets. 5) Install gauges on the tubing and 9 5/8" casing X tubing annulus. '--' STATE OF ALASKA '-'" ~ ALA~,.,A oIL AND GAS CONSERVATION coMMIS,...")N APPLICATION FOR SUNDRY APPRO i, I. 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown ~ Re-enter suspended well Alter casing ~ Repair well ~ Plugging ~ Time extension Change approved program __ Pull tubing __ Variance __ Perforate 2. Name of Operator_. _ "" '' fo nJ Union uil company os Call r ,~ ExplOratory 3.Addre~. O. BOX 196247, Anch. , AK, 9 t519- 0 ~t~a~,raphiCservice 4. Location of well at surface Leg #1, Slot 4 1940' FNL, 543' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 7105 ' 1973' FSL, 847' FWL, Sec. 31, T9N, R12W, SM At effective depth 9428 ' 1886' FSL, 828' FWL, Sec. 31, T9N, R12W, SM At total depth 9543 ' 1882' FSL, 837' FWL, Sec. 31, T9N, R12W, SM 6. Datum elevation (DF or KB) 7. Unit or Prop~r~y name IV[G_q St_~_te 17595 8. Well number W(~ll No. 11 9. Permit number feet 10. APl number 50-- 11. Field/Pool Kenai/Lower Kenai 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 592 ' Intermediate 2943 ' 9508' Production 3762' Liner Perforation depth: measured true vertical 9543 ' feet 9275 ' feet 9428 ' feet 9161 ' feet Plugs (measured) Junk (measured) Size Cemented 20" 1345 SX 13-3/8" 3250 SX 9-5/8" 2300 SX 7" 700 SX See attachment A Cement Plug at 9428' None Measured depth RECEIVED NOV 1 2. 1991 True vertical depth Alaska Oil & Gas Cons. Commission Anchorage 622' 622' 2975' 2950' 9541' 9273' 5712'-9474' 5463'-9206' Tubing (size, grade, and measured depth) L.S. 2-7/8", 6.4#, N-80 @ 9107' S S 3-1/2" N-80 X 2-3/8" N-80 @ 9050' Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal __ Detailed operations program .2~ BOP sketch 14. Estimated date for commencing operation November 11, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~__ Gas __ Suspended __ Service 17. I hereby certify thee foregoing is tr[,~.,and correct to the best of m, Signed FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical IntegrityTest __ Subsequent form required 10- '~f+ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 knowledge. REGIONAL DRILLING MAN[~tI~ER J Approval No.¢/..;. ~:~,.~, 11-~6-~1 Commissioner Date II- I 5 - fl I SUBMIT IN TRIPLICATE ORIGIN4L S!GNED BY PERFORATION RECORD BAKER WELL #11, MIDDLE GROUND SHOALS 17595 A: BCD: EFG: MEASURED TRUE DEPTH VERTICAL DEPTH CONDITION 5840-5850 5589-5599 BEHIND 7" CASING 5895-5905 5644-5654 BEHIND 7" CASING 6105-6115 5753-5763 BEHIND 7" CASING 6180-6190 5927-5937 BEHIND 7" CASING 6210-6220 5957-5967 BEHIND 7" CASING 6225-6265 6003-6013 BEHIND 7" CASING 6297-6307 6043-6053 BEHIND 7" CASING 6340-6350 6086-6096 BEHIND 7" CASING 6450-6460 61 95-6205 BEHIND 7" CASING 6480-6490 6225-6235 BEHIND 7" CASING 6535-6545 6279-6289 BEHIND 7" CASING 6580-6590 6324-6334 BEHIND 7" CASING 6645-6655 6388-6398 BEHIND 7" CASING 6760-6770 6413-6512 BEHIND 7" CASING 6795-6800 6537-6542 BEHIND 7" CASING 6840-6650 6581-6591 BEHIND 7" CASING 7105-7115 6745-6755 OPEN 7145-7155 6884-6894 OPEN 7415-7425 7152-7162 CEMENT SQUEEZED 7440-7450 7177-7187 CEMENT SQUEEZED 7680-7745 7416-7 ~481 CEMENT SQUEEZED 7750- 7765 7486- 7501 CEMENT SQUEEZED 7780-7800 7516-7536 CEMENT SQUEEZED 7860- 7920 7596- 7656 OPEN 7950-8035 7685- 7770 OPEN 8060-8070 7795- 7805 OPEN 8120-8140 7855-7875 OPEN 8170-8215 7905-7950 OPEN 8240-8310 7975-8045 OPEN 8350-8470 8085-8205 OPEN 8505-8555 8240-8290 OPEN 8615-8680 8350-8415 OPEN 8685-8720 8420-8455 OPEN 8740-8770 8475-8505 OPEN 8800-8920 8535-8654 OPEN 8935-8968 8669-8702 OPEN 8975- 9000 8709- 8734 OPEN 9020-9050 8754-8784 OPEN RECEIVED t~OV 1 P_ 1991 Alaska 0ii & Gas Cons. Commission Anchorage BAKER WELL NO. 11 LEG 1, SLOT 4 1 ADL 17595 SPUD 5/15/67 20' g4~ @ 822' CEMENTED WITH 1345 SX 13 3/8' 54.5 & 61 # ~ 2975' CEMENTED WITH 3250 SX LONG STRING: DEPTH 1. CAMERON 10" NOM DUAL TUBING HANGER 32 2. 3 1/2' BUTTX 2 7/8" BUTT XO 33 3, 2 7/8' BUTT, N-80 TUBING go40 4. 2 718" BUTT PUP g047 5. 2 7/8" BUTT X 2 7/8" 8RD XO g048 6. 2 7/8" 8 RD PUP g054 7. NATIONAL TYPE "V" CAVITY g075 8. 2 7./8' EUE 8RD TAIL PIPE 9106 9. 2 7/8" GUIDED MULESHOE 9107 SHORT STRING: A. 3 1/2' BUTT N-80 9.2# TBG 5547 B. 3 t/2' BUTT X 2 3/8' BUTT XO 5548 C. 2 3/8' BUTT N-S0 4.6~ TBG 9045 D. 2:3/8" BUTTX 1 1/4" 10 RD XO g048 E. 1 1/4" 10RD PUP g058 (AS RUN 6/3/85) 9 5/8" 40, 43.5~ ~) 9541' CEMENTED WITH ~ SX (2 STAGES) 7", 29~, UNER 5712' - g474' CEMENTED WITH 700 SX 685O 7105 MAX INCUNATION 29.3 DEG SEE ATTACHMENT FOR EXACT PERF INTERVALS A: 5840 - 5905 BCD: 6105 - 6850 EFG: 7780 - g050 7 TD = 9543' 'PVD = 9275' GRB 10/22/91 PROCEDURE: 1. RIH with slickline bailer and bail fill 2' below the Hydraulic BHA. 2. RIH with a standing valve and set in the BHA. 3. Test the short string and long string to 3500 psi. 4. Pull the standing valve. 5. RIH and set a seal bore protection sub in the BHA. 6. MIRU coiled tubing (1-1/4"). Test BOPE to 3000 psi. 7. RIH with coiled tubing and clean the sand out of the long' string tubing tail using 3% KCL and HEC sweeps as needed. Clea~ as far into the 7" casing as possible. 8. Pull the seal bore protection sub. 9. RIH with a standing valve. Test the tubing strings to 3500 psi. 10. RIH with a jet pump. 11. Turn the well over to production. TEXAS @~ TOOLS ~¢T. ,4 TUBING STRIPPER/PAC~~R $,000 psi Working Pressu're ~ H~S Service ~ 1.00'Series DS322 1.25m~erles DS323 p.o. Box 79727 Houston, Texas 77279 - Telex: 790905 TX TOOLS HOU phone: (7' 13) 6206 W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 June 26, 1985 File: TJZ-240-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Noti ce MGS 18746 Well No. 11 Platform Baker, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports On Wells, to notify you of work recently completed on MGS 17595 Well No. 11. Very truly yours, W. R. Halvorson Acting District Manager Attachments JCB/dds RECEIVED JUL 011 5 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLJ~ OTHER [] 2. Name of OperatOr 7. Permit No. Amoco Production Company 67-17 3. Address 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 50- 733-20013 4. Location of Well Leg 1, Slot 4, MGS Platform Baker 1,940' FNL, 543' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 74.4' KB MSL I 6 . Lease DesignatiOn and Serial No. ADL 17595 12. 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 11 11. Field and Pool Middle Ground Shoal Hemlock 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 J~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Between May 20, 1985 and June 3, 1985, Amoco Production Company: 1. Ran Gamma Ray log from 9,057 - 5,700 feet. 2. Circulated and killed well with diesel. 3. Nippled up BOP's and pressure tested. 4. Pulled dual tubing string and BHA. 5. Cement squeezed perforation intervals 7,415 - 7,450 feet and 7,680 - 7,800 feet. 6. Perforated 7,860 - 7,920 feet, 7,990 - 8,035 feet, 8,060 - 8,140 feet, 8,260 - 8,310 feet, 8,400 - 8,720 feet, 8,740 - 8,775 feet. 7. Ran dual tubing string and BHA. Set pump cavity at 9,074 feet. 8. Nippled up tree and pressure tested. 9. Returned well to production. REC[IVED JUL 0 Alasl(a Oil & Gas Cons. 14. I hereby certify t_hat tt}e foregoing is true and correct to the best of my knowledge. S,gned ~/~)(~~ TmeActing District Manager The space below for Commission use Anchorage Dat~6/27/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 Hay 10, 1985 ~-.. File: TJZ-163-WF Mr. C. V. Chatterton, Chairman 'Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent MGS 178595 Well No. 11 Platform Baker, Cook Inlet, Alaska Attached in triplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to repair the bottomhole assembly on Well No. 11. While working on the well, we intend to reperfo- rate the Hemlock pay horizons. Yours very truly, W. G. Smith District Manager Attachments JCB/dds R[CEIVED MAY/~~ Oil & Gas Cons. Commission Anchorage STATE OF ALASKA --"~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of~perator Amoco Pr0duction Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of'Well Leg 1, Slot 4, MGS Platform Baker 1,940' FNL, 543' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4 KB 12. I 6 . Lease Designation and Serial No. ADL 17595 7. Permit No. 67-17 8. APl Number 50- 733-20013-00 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 11. Field and Pool Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In May, 1985, Amoco Production Company proposes to: 1. Run gamma ray log from PBTD to 5,700 feet. 2. Circulate and kill well. 3. Nipple up BOP and pressure test. 4. Pull tubing and bottomhole assembly. 5. Reperforate Hemlock pay horizons. 6. Run tubing and new bottomhole assembly. 7. Nipple up tree and pressure test. 8 ~Return well to production. RECEIVED MAY' i. ],985 Alaska OJt & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~' ~'~ ~(~I /~~ Title Di stri ct Manager The space below for Commissi~n~use" I~_~ Date05/10/85 Conditions of Approval, if any: Approved by Form 10-403 ORIG,It~L SIGN[ii _BY LONNIE C. SMITR COMMISSIONER .>~pproved Co,~' By Order of the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent April 14, 1983 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File- LAD-426-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report MGS 17595 Well No. 11 Platform Baker, Cook Inlet Attached in duplicate is State of Alaska Form 10-403, Sundry Notice and Reports on Wells, outlining the work completed on Middle Ground Shoal 17595 Well No. 11. This well had been damaged at approximately 2503' MD while dyna-drilling MGS 17595 Well No. 25. Any questions concerning this work can be directed to Kevin Smith in our Anchorage office. Your very truly, L. A. Darsow Di stri ct Superintendent Attachments KLS/seh STATE OF ALASKA ~ ALASKA OiL AND GAS CONSERVATION CO,v,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Compan,y 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg I Slot 4, MGS Platform Baker, 1940~ FNL, 543' FWL, Sec 31, T9N, R~2W, S.M. 7. Permit No. i 67-17 8. APl Number 5o- 733-20013-00 9. Unit or Lease Name Middle Ground Shoal .., t0. Well Number 11. Field and Pool Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 79.4 KB I MGS State 17595 12. Check Appropriate Box To indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~] (Note. Report multiple completions on Form 10~407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Operations commenced on March 4, 1983. . Se 4. 5. 6. 7. 8. 9. 10 11 Rigged up BOP. Tested to 2500 psi. Pulled 2500' of parted tubing. Ran overshot and cut tubing at 2715'. Set retrievable bridge plug at 2614'. Cut 9-5/8" casing at 2520', below damaged point. Ran new 9-5/8' casing with patch and tested to 1500 psi. Retrieved bridge plug. Ran overshot and cut tubing at 6977'. Ran wash pipe and cleaned out fill to top of packer at 7039'. Ran overshot to pick up 2-1/2" Type 'E' bottomhole assembly. Circulated water out with diesel. Ran mill to retrieve permanent packer at 7039' Ran casing scraper and cleaned out fill to 941~' 12. Ran 2-1/2" Type 'D' bottomhole assembly on dual ~ubing strings. 13. Set new bottomhole assembly at 9096' MD and returned to production. Rig release on March 18, 1983. ~,.L:,:.~.L,,~ Post-workover production' 326 BOPD, 64 BWPD and 128 MCFD APR 1 9 "¢"~'~ Signedl4' I hereby~,,~certify that th~ing~is true and correct to the beStTitleOf my knowledge. The space below for Commission use District Superintendent Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Dau? __ Form 10-403 Rev. 7-1-80 Subml! "lr~lelltlOnS" itl Triplicate and "Subsequenl Reports" in L)upl~ca~e L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 February 28, 1983 File- LAD-243-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent MGS 17595 Well No. 11 Platform Baker, Cook Inlet, Alaska Attached in triplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to repair MGS 17595 Well No. 11. This well was recently drilled into at approximately 2503' MD while dyna-drilling MGS 17595 Well No. 25. We propose to do one of the following- Cut and retrieve the 9-5/8" csg. below the damaged point and run ne~w 9-5_/8'S_csg~_ w~ith ' s f . '---- 2. Run a 7" liner from existing liner back to surface. 3. Plug and abandon the well. If the casing cannot be repaired, a revised Form 10-403 with an alternative will be re-submitted to your office. Yours very truly, L. A. Darsow District Superintendent Attachment KLS/seh MAR- 1 19 3 Alaska Oil & Gas Cons. Commission Anchorage ~ '~ STATEOF ALASKA ~ ALASKA O~L~AND GAS CONSERVATION CO¥,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 67-17 3. Address 8. APl Number P.0. Box 779, Anchorage, Alaska 99510 50-133-20013 4. Location of Well Leg 1, Slot 4, MGS Platform Baker, 1940' FNL, 543' FWL, Sec 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4 KB 12. I 6 . Lease Designation and Serial No. MGS State 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 11. Field and Pool Middle Ground Shoal 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 D[ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Estimated Starting Date: March 2, 1983 1. Rig up BOP and test to 2500 psi. 2. 3. 4. 5. 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 2'0" ~ ~ 7" Cu~ ~nd pu]] 9-5/8" csg.~o~ ~un liner ~o surface. Pul]land run new bo~o~ho]e assembly. Return to production. R E C E ! V E D O[ :~0 °~r°u~' , ~ ~it/~ MAR- i 'I~B3 Alaska Oil & Gas ConsL Cummissior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~..'~ ~C~'~oC.)k-~---~, Title District Superintendent .... ~ ~r-,¢-%. The space below TOr uomm~ss~on use Date Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SCHLUMBERGER OFf:SH©F¢'~_-' SERVICES ,~'~x Division of Schlumberger Limited HOUSTON, TEXAS 77001 pL Ir A la Ir IR £PLY 500 ~ INTERNATIONAL Ai~?O~T ~OAD ANCHORAGE, A~SKA ~502 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3OO1 PORCUPINE DRIVE ANCHORAGE, ALASKA Attention: 99501 Gentlemen: 1 RFOLDED SEPIA ' Cam on AMOCO PROD-'UCT 10N C0 Well S - 1 5' D- 3 D- , D 8 RD, S ' Fie'Idp- ~OUTH MIDE~LE GROUND SHOAk~CountY NAI State ALA~ZA _ ., Additional prints are being sent to: prints prints prints prints prints prints prints prints The film is RETURNED TO AMOCO We appreciate the privilege of serving you. ,.- /~ECEIVED Very truly yours, i 'i ~. ..,,,,'' .SCHLUMBERGER OFFSHORE SERVICEs' March 14, 1973. File: WMJ-137-WF Mr. Homer L. Burrell,· Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Sundry Notice - Subsequent Report on MGS 17595 Well No. 11 The attached State of Alaska Form P-3 is the subsequent notice of work performed on Middle Ground Shoal 17595 Well No. 11. The work- over commenced on January 27, 1973and was completed on February 7, 1973. Yours very truly, W. M. Jones District Production Superintendent Attachment Form P--3 ~ Smbrnit "Intentions" in Triplicate REV. 9-30-69 & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'EH~iT-~' 'for such 'p~o~osals~) 5. API NUMERICAL CODE 50-133-20013 6. LF_,A~E DESIGNATION A-ND SERIAL NO. ADL 17595 , 1. i?. IF INDIA.N, ALLO'i~r~:s: OR TRIBE NA2ViE OIL ~ OAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FArM OR LEASE NAME Amoco Production Company MOS State 17595 99510 . 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 4. LOCATION OF WELL At su~'~ace Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. Check Appropriate Box To I,ncii,cate Niat'ure of N~ti'ce, Re 13. ELEVATIONS (Show whether DF, RT, GR, etc. RDB 79' above MSL 14. 9. WELL NO. 11 ' 10. FLI~L,D A~D POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOL~E OBJECTIVE) Sec. 31~ T9N~ R12W, S.M. 12. PE~VIIT 1~O. 67-17 tort, or Other D~ta ' NOTICE OF ~NTENTION TO: TEST WATER 8HUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPL~ COMPI,ETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS tOther) ! ,, SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZINO ~ ABANDONMEIqT$ (Other) (NOTE: 'Report results of multiple completion on Well Completion or Recompletion Report and Log form,) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The Kobe pUmp in this well failed and could not be. retrieved by conventional methods.' Operations commenCed' on 1-27-73 to' pull the well. The tubing and Kobe'. bottom hole assembly were pulled. The permanent packer that was set at 7050' was milled loose and pushed to 9420'. 'The following intervals were then perforated at 2JSPF using hollow carrier casing guns in oil base mud: 7680-7710'; 7730-7745'; 7750-7765'; 7790-7800'; 7870-7910'; 7950-7960'; 7970-8010'; 8020-8035'; 8130-8140'; 8170-8215'; 8240-8310'; 8350-8365'; 8375-8430'; 8440-8470'; 8505-8520'; 8530-8555'; 8625-8680'; 8695-8720'; 8745-8760'; 8800-8810'; 8820-8860'; 8870-8920'; 8945-8968'; 8975-8990'; 9020-9030'; and 9040-9050'. A permanent production packer was set at 7040' on wireline. A Kobe bottom hole assembly and tubing were then rerun and the well returned to production. Production prior to the workover on 1-14-73 was 1016 BOPD, 3 BWPD, and 305 MCFD. Production after the workover on 2-7-73 was 1642 BOPD, 0 BWPD, and 314 MCFD. Operations were complete on 2-7-73. MAR DIV[SIbI'-4 '~ i.. ~tL ~ND GAS ANCHORAGE. ]6. I hereby certify that the ~--nd correct SIGNED ~"~" ~":~'~"~' TITLE District Production Supt. DATE 3-14-73 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See I,nstrucfions On Reverse Side Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 February 12, 1973~ File: WMJ-081-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001Porcupine Drive Anchorage, Alaska 99504. Dear Sir: Re: MonthlY Report of Drilling and Workover Operations MGS 17595 Well No. 11 Transmitted herewith' is a State of Alaska Form P-4 reporting operations on MGS ~17595 Well No. 11 during January 1973. Yo s very., y, W. M. Jon District ~r~uctiOn Superintendent Attachment FEB 1 3 lg73 DIVISION ~,-F (.;IL AND OAee ANCHORAGE l~orm N*o. P--.4 REV. STATE OI- ALASKA SUBMIT ~ DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. N~ OF oPine?od Amoco Production Company 3. ADbRESS OF OPERATOR P. 0. Box 779~ Anchorage~ Alaska 4. LOCA~ON OF W~ 99510 Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec 31, T9N, R12W, S.M. APl NUAIER/CAL CODE 50-133-20013 LEASE DESIGNATION A.X'D SERIAL NO, ADL 17595 7 IF INDIA)~, ALOTIEa, O1~ TRIBE NAME 8. L.~IT. FARM OR LEASE NA.ME MGS State 17595 WELL NO 11 10. FIELD A.ND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., Ii,. (BOITOM HOLE om,mm-mrs) Sec. 31, T9N, R12W, S.M. 12, PERMIT NO. 67-17 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEi~'rH SET AND VOLI/MES USED. PERFOH. ATIOBTS, TESTS A_ND HESULTS FISHING JOI~S SLINK L~T HOLE AND SIDE-T'RACKED HOLE AND ANY OTHER SIGNIFICANT CliANG~ IN HOLE CONDITIONS. Summary of Operations During January 1973 January 27.- 28 January 29.- 30 January 31 Rig up, kill well with oil base mud, and remove wellhead. Install and pressure test BOP. Pull tubing and faulty Kobe equipment. Lay down bottom hole assembly. Pick up drillpipe and drill collars to clean out. 14. I hereby certi s~sx~ //_)-7~%~-~/f-~', ~_~ Dist. Production Su~t. mA~ Februar7 12, 1973 .o~.-...o,, ../,,. ~...,,., ,o, ...~ .,...~, ~,,, ,.,,,,,.,, o, ,,. ,,~,., o, o..,.,,......, ..,,. ,,,., ~..u,,,.,..,,, ,,. oil m,d g~s c~n,ervatlon commi~ee bythe 15~ of the ~uoc~ding ~n~.~le~ Otherwise directed. January 29, 1973 File: WMJ-058-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504. Amooo Produotion Corn P. O. Box 779 Anchorage, Alaska Dear Sir: Re: Sundry Notice of Intent MGS 17595 Well No. 11 Attached is the State of Alaska Form P-3 advising your office of our intent to perforate MGS 17595 Well No. 11. The proposed work on Well No. i1 was discussed in a telephone conversation between Mr. O. K. Gilbreth and Mr. B. R. Allard on January 26, 1973. Y~frs very//~ru~, D±str±ct ?~luction Super±ntendent Attachment jAN F~rm F--3 REV. 9-30-6 9 STATE OF ALA~SKA Smbrntt "Intentions" in Trtplicat~ & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR f~'ERfV~I'£-L" 'for such 'p~o/mosal~.) WELL WELL OTHER 2. NAME OF OPERATOR Amoco Production C0mpan_v 3. ADDRESS OF OPERATOR P. 0. Box 779, .Anchora~;e, Alaska 99510 . 4. LOCATION OF WF~LL At sur£ace Leg 1, Slot 4,.MGS Platform Baker, 1934'~ FNL, 544' FWL, Sec' 31, T9N, R12Wi, S.M' 13. ELEVATIONS (Show- whether DF, RT, OR, etc. RDB 79' above MSL 14. 5. APl NUMF_JUCAL CODE 50-133-20013 6.LEASE D~S~IGNATION A.ND SERIAL NO. /~L-17595 7. IF IIVDIA.N, ALLO~ OR TRIBE NA1VL~ 8. UNIT, FARM OR LEASE NAME MGS State 17595 11 10. F~ A~ID FOOL, OR WILDCAT Middle Ground Shoal I1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 8et.. 31} Tg~ R12W, S.M. I~. PER.MIT BrO. 67-17 .. Cl, eck Aj3propriate Box To [nd, icate Niature of N~tice, Re ~ort, or Other Data NOTICE OF INTENTION TO: TEST ~'ATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT [ I MULTIPLE COMPI,ETE S~OOT OR ACIDIZ~ ARANV0N* nEPAIR WELL CHANOE PLANS ~ Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT -- ALTERING CASINO SHOOTING OR ACIDIZINO ABANDONMEN'T$ (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) !5. DEMCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The' Kobe pump in this well failed and cannot be retrieved by. conventional methods. We Plan to pull the tubing and bottom hole assembly to replace the faulty pumping equipment. With the tubing out of the well, we' plan to retrieve the permanent packer at 7050', clean out to at least 9200' and perforate as follows at 2JSPF: 7680-7710', 7730-7745', 7750-7765', 7790-7800', 7870-7910', 7950-7960', 7970-8010', 8020-8035' , 8130-8140' , 8170-8215', 8240-8310' , 8350-8365' , 8375-8430' , 8440-8470' , 8505-8520' , 8530-8555' , 8625-8680' , 8695-8720' , 8745-'8760' , 8800-8810' , 8820-8860' , 8870-8920' , 8945-8968' , 8975-8990' , 9020-9030', 9040-9050'. After perforating, a permanent packer will be. set at approximately 7040'. Kobe pumping equipment will be rerun and the well returned to production. (This space for State ~.effYO(~~~ CONDITION8 OF APPR YAL, IF N~f: ] JAN 3 i 1973 ,,'¢' I, l- (ell AND GA% DI, ,.IL.- ,.- ANCHORAGE TITLE Dist. Production Supt. DATE January 29, 1973 ~l~_roved Cop~ See i,nstrucfions On Reverse Side Novemb er 15, 19 72 File: ASH-237-WF Mr. Leland Franz Skelly Oil Company 1088 Lincoln Tower Building 1860 Lincoln Street Denver, Colorado 80203 Dear Mr. Franz: Re: Middle Ground Shoal Field 17595 Well No. 11 Amoco Production Corn P. O. Box 779 Anchorage, Alaska 9951 Regarding your inquiry dated 11'7-72, a revie~,g of our recor¢]s indicates that our Middle Gro~md Shoal Well No. ll is being reported in error as a gas lif~ well on' State of Ala---ska Form~ 10-405. ~iiddle Ground Shoal Well No. ll's conversion to Kobe was finalized March 13~ 19_72, and our records have been corrected to indicate h_ydraulic pump as current method of lift for this well. A further review of our records indicates that due to a transposition error, Granite Point_State 1_ 874.2~ Well No. 5, has been carried as . hydraulic---~.umping ~ell on Form 10-~405 since 9. ctober~ 197~. Please cor- rect your records to reflect this well as a f]~.owin$ well. Very truly yours ~ Original Sig~ by A. s. HAI. ¥ A. S. Haley Area Administrative Supervisor l~rm No. 1:'--4 lq~EV, a- 1-70 STATE Or-ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER Water Injection NAME OF OPERATOR SUBMIT IN DUPLICA~ ~ApI NUMERICAL CODE ,5-0-:.133-20104 ~A ~"DESIGNAT~ON AND ADL%~I~'746 I ~-,~ '~', SMGS Unit ,/,i~'fi~,~ ~ ~ .....,,; ! Amoco Production Company LEASE NAME 3. ADDRESS OF OPEI{ATOR g WELL .NO 11 P. O. Box 779, Anchorage, Alaska 99510 '4. LOCkT~ON OF WELL . Surface: Leg 2, Slot 2, SMGS Platform "D" 699' FSL, 1872' FWL, Sec. 35, T8N, R13W, S.M. 10. FIELD A_ND POOL, OR WILDCAT South Middle Ground Shoal I! SEC. T., R., M.. (BO~TOM HOI-~ OBJECT~ Sec. 35, T8N, R13W, S.M. 12. PI~R~MIT NO 68-32 13. REPORT TOTAL DE~I AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CE~iENTING JOBS INCLUDING DEPTH SET A~rD VOL~ USED, PERVO.RATIONS. TESTS A/XrD RESULTS FISHING JOBS JLr~K IN HOLE AND SIDE-TR~CKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Summary of Operations Du.ring April 1972: April 1-8, 1972 April. 8-14, 19 72 PBTD 10,445'. Shut well in and prepared to pull and repair leak in tubing. Kill well. Nipple up and test BOP. Pull tubing. Found collar washed out 277 joints down. Rerun 3-1/2 in. tubing and hydrotest. Load annulus with inhibited water. Land tubing, nipple up and test wellhead. Resumed water injections. Final Report. 14. I hereby ~rtify tltat the.~oregoix~ is true and correct smmmC~,sfl,.~ (~.. ~~1~~ =~ Supervisor in Charge u,~ May 12, 1972 .................... // - _ . ~f/ - , , - _ N~E -- Report off this fo~ il required for-eO~ Galendar ~th% regardless of the itotu~ of operations, and must ~ flied in duplicate with the oil and Oas conservation commiflee bytho 15~ of the suec~ding mn~, ~leM otherwise directed. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 April 7, 1972 ~ File: JCS-206-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Re: Sundry Notice MGS 17595 Well No. 11 A Sundry Notice and Report on'Wells, State of Alaska Form P-3, trans- mitting our ~ubsequent report of repairing MGS 17595 Well No. 11 is attached. Yours very truly, John C. Schillereff Supervisor in Charge Attachment Form REV. 9-30-6 9 STATE O'F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COAAMIY[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use -APPLICATION'FOR [~ERfViiT-~' 'for such 'pi;o~osal~.) . . . 1. OIL ~ GAS [] WELL WELL OTHER 2. NAME OF OPERATOR Amoco Production ComPany 3. ADDRESS OF OPERATOR 0. Box 779, Anchorage, Alaska 99510_ 4.LOCATION At su,-mce Leg 1, Slot 4, MOS Platfo~ i~e~ 1934' ~L, 544' ~L, Sec. 31~N, . ' 13. ELEVATIONS (Show whether DF,,RT, OR, etc. D[~/iStON RKB 79'.abOve MSL Ch~ck .a4~propriate Box To [ndlcate Niat'ure of N~tice, Re, 5. APl NUMERICAL CODE 50-133-20013 6.LEAME DE~dGNATION A-ND SERIAL NO. ADL-17595 7. IF INDIA_N, ,~J.J.,OTTF_J~ OR TRIBE NAME 8. UNIT, FARAI OR LEASE NAME MGS State 17595 9. WELL NO. ~ 11 ooL, wi cAT ~iddle Ground Shoal m~, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) · .Sec. 31, T9N, R12W, S.M. PER/W_IT NO. 67-17 ~o., or Other Da~a ' NOTICE OF INTENTION TO: --I SHOOT 0R ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS iOther) SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT 8HoOTIN0 OR ACIDIZINO -~-- REPAIRING WELL ALTERIN0 CASINO ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including-estimated date of starting any proposed work. Production data showed that the "A" and "BCD" zones were no longer commercially productive in this well. Thus, the primary purpose of the workover was to isolate the "A" and "BCD" zones behind a 7 in. liner, rePerforate the "EFG" zone and re- turn the well to production using downhole hydraulic lift equipment. The well was shut in January 14 and 'the workover began the same day. After the existing gas lift equipment was removed from the wellbore, the well was cleaned out to 9474' and the casing above 5800' was successfully pressure 'tested. Next a 7 in. 29 lb/ft N-80 liner was installed from 5712' to 9474' and cemented in place. The well was cleaned out to 9428' and the "EFG" zone reperforated as shown on the attached perforations list. A permanent packer was set at 7050' and downhole hydraulic pump and related bottom hole equipment was installed. However, the well failed to respond as anticipated and appeared to be suffering from formation damage. The well was acidized with 26,000 gallons of 12-10 mud acid, 29,000 gallons 2.5% HCL, 2500 OS-90 Unibeads and 7,000 gallons solvent in six stages down the tubing. After pump testing, the well was returned to production on March 13, 1972. Production rate before the workover was 799 BOPD, 0 BWPD, 33_4 MCFD..._.__On March 12, 1972, after t D. Final Report. ~ ~=~"~'~"~' ................. ~ 16. I hereby certify that the forg~oin~ i. true and correct _ - , - (This s'lface for State offiee use) APPROVED B~ CONDITION~ OF tPPR0¥IL, IF ANY: TITLE Supervisor in Charge DATE TITLE DATE April 7, 1972 See Instructions On Reverse Side PERFORATIONS LIST MGS 17595 Well No. 11 Reference: IES Log Dated 8-5-67 Used Dresser Atlas 4 in. Casing Gun and Goldenjet charges on February 3, 1972. Ail Intervals 2 JSPF 7105 -'7115 7145 - 7155 7415 - 7425 7440 - 7450 7710 - 7730 7780 - 7790 7860 - 787'0 7910- 7920 7960- 7970 8010 - 8020 8060 - 8070 8120 - 8130 8365 - 8375 8430 - 8440 - 8615 - 8625 8685 - 8695 8760 - 8770 8810 - 8820 8860 - 8870 8935 - 8945 8990 - 9000 9030 - 9040 8190 - 8200 Totals: 8255 - 8265 25 Intervals 260 Feet 520 Shots APR I 0 1972 DIVISION OF OIL ANi:) F~rm ~o. STATE OF AJ.A.SKA SUBMIT I1~ DUPLICATE OIL AND GAS CONSERVATION CO,~,/LMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL ~'~ GA~I [] 0TI/~E~ WKLL Wl~LL . '~. ~.,~,: or oPm?oR Amoco Production Cgmpany' .... ~. ~ss O~"6P~R' ' g. O. Box 779, Anchorage;.. Alaska 4. LocAT~ON OF WF2~L ,, 99510 Surface: Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. %, Ai~x N~Emc~ CODE 50--133--20013 ~FUkSE DESIGNATION AXD SERIAL NO. ADL-17595 ? IF INDIAN, ALO] i~E 0]~ TRIBE ~: "C'.~'i~ r~' ow~^sE w~m' - MGS State 17595 11 10. F~T.T~ A.ND POOL, OH WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. ~BOTTOM HO= o~ Sec. 31, T9N, R12W, S.M. _ , ,, 1~. P~IT NO. 68-29 · , , REPO~" TOTA~ DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING A~ C~NG JOBS INCLUDING DEP~ SET ~ VOL~ USED. P~O~TIONS, ~TS ~ ~SULTS FISHING JO~ J~K ~ HOLE ~D SIDE-~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. Summary o..f. Operations During February 1972 February 1 - 2, 1972 Drilled out cement and retainers and pressure tested cement squeezed perforations. Cleaned out well to 9428'. February 3, 1972 Perforated intervals shown on attached perfora- tions list. February 4 - 6, 1972 Set permanent packer at 7050'. Installed down- hole hydraulic pump and related bottom hole equipment. February 7 - 24, 1972 - Pump tested well. February 25 - 28, 1972 Acidized well with 26,000 gallons 12-10 Mud Acid, 29,000 gallons 2.5% HCL, 2500 lbs. 0S-90 Unibeads, and 7000 gallons solvent in 6 stages down the tubing. Average injection rate was 5.0 BPM at 1500 psi. February 29, 1972 8 1972 Pump tested well. mG~ ~} ~~~ =~ _Sucervisor in Charge .... .~ ~_ ~rch 7, 1972 ' // .... '- , ~ H~ ~ · ............ ~ j ~ ~ ~ ~ ......... N0~ --RepOrt on this f~m is tt{uired for ~ COlehd0r ~t~ regardless 0f the ~totuS of oper0tions, °nd must ~ flitd i. dupliCOtt wit~ PERFORATIONS LIST MGS 17595 Well No. 11 Reference: IES Log Dated 8-5-67 · · Used Dresser Atlas 4 in. Casing Gun and Goldenjet charges on February 3, 1972. Ail Intervals 2 JSPF 7105 - 7115 7145- 7155 7415 - 7425 7440 - 7450 7710 - 7730 7780 - 7790 7860 - 7870 7910 - 7920 7960 - 7970 8010 - 8020 8060 - 8070 8120 - 8130 8365 - 8375 8430 - 8440 8520 - 8530' 8615 - 8625 8685 - 8695 8760 - 8770 8810 - 8820 8860 - 8870 8935 - 8945 8990 - 9000 9030 - 9040 8190 - 8200 Totals: 8255 - 8265 25 Intervals 260 Feet 520 Shots MAR 8 1972 Amoco Production Company P. O. Box 779 Anchorage, Alaska February 14, 1972 File: JCS-096-WF Re: MGS 17595 Well No. 11 Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir- Attached for your approval are copies of Form P-3, Sundry Notice and Report on Wells, concerning a mud acid stimulation we plan to perform on MGS 17595 Well No. 11 in the near future. 99510 c. 5 ENG .......... 2 G:~OL 3 GEOL REV ~RXF~ .......... s~C CONFER: FILE: Yours very truly, ~n C. Schillereff Supervisor in Charge Attachments ~rrn ~V. 9-30-69 Smbrnit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR ~'EB-~iT-~' 'for such 'p~o~)osal~) OIL ~ OAS ~-] WELL WELL OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage~ Alaska 99510 4. LOCATION OF WELL At surface Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 79' above MSL 5. AP1 N~CAL CODE 50-133-20013 6. LEASE DESIGNATION AND SERIAL NO. ADL-17595 7. IF INDIA_N, ALLO'r'ri~E OR TRIBE NAiVIE 8. UNIT, FAi~Vi OR LEASE NAME MGS State 17595 9. %VELL NO. 11 10. FLEL,D A~ND POOL, OR WILDCAT l~ddle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TgN, R12W, S.M. 12. PEI~uM/T 1%10. 67-17 Check Appropriate Box To [ndkate Nature of NOtice, Reimorl', or Other D~ta NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS ~Other) SUBSEQUENT R~PORT OF: WATER SHUT-OFF -- REPAIRING WELL FRACTURE TREATMENT -- ALTERING CASING . SHOOTING 0n *CIDIZINO ABAND0NMENT$ (Other) (NOTE: Report results of multiple completion on Well Cornpletion or Reeompletion Report and Log form.) !5. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONa (Clearly state all pertinent details, and g'ive pertinent dates, including estimated date of starting an)' proposed work. After the work proposed on our Sundry Notice of January 14, 1972 was completed, the well produced only about 550 BOPD, whereas before the workover it made 800 BOPD. To return the well to its original productivity, we plan to acidize the "EFG" zone with 26,000 gallons of 12-10 mud acid in six stages. Temporary diverting agents will be injected between each stage ~to insure the entire interval is treated. It will not be necessary to pull the well to perform the workover. 16. I hereby ,c~tffy that the _fore~olu~Ji! true and correct (Thts spree for State CONDITIONS OF APPROVAL, IF TITLE Supervisor in Charge DATE February 14, 1972 See Instructions On Reverse Side Approved Copy Returned Amoco Production Company P. O. Box 779 Anchorage, Alaska February 10~ .1972 File: JCS-088-WF Re: Monthly Report of Workover Operations Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Attached are the necessary copies of the State of Alaska Form P-4, furnishing you monthly workover operation information, for the month of January on Middle Ground Shoal Wells Nos. 11 and 12 and Granite Point 18742 Well No. 6. Yours very truly, Y' .. , ~ John C. Schillereff Supervisor in Charge 99510 DI R I /" C. C; ~,'DL C. 1 ENG 2 ENG 3 r,. ~ .--. .... ~ C.:-OL . 2 G !;:0 L 3GF_OL REV DRAFT sec CONFER: FILE: Attachments DIViSiON FORM SA MEMORANDUM TO: r O. K. Gilbreth, Jr. Chief Petroleum Engineer FROM: Karl L. VonderAhe Petro Ieum Engineer State of Alaska DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS DATE : SUBJECT: January 28, 19 72 John Ea~on called 1/26/72 regarding ADL 1'7595 No. 11. Said lost circulation during cementing job. Temperature survey indicated top of cement about 6,850'. Top of liner is 5,712' - bottom 4,474' Top '~" pool - 5,800' + Top "E" pool - 7,090' Plans call for blank-off of "A" and "B,C,D" pools and reperforating "E,F & G." Now have packer at top of liner but is ~ot set. If set would leave "A" in communication with "B,C,D." Discussed possibilities. I approved plan to perforate liner just above "B,C,~" pool and with packer set above these perfs in liner, break circulation and cement with excess of cement to fill annulus around liner to its top, thereby sealing off '~" from "B,C, & D." If circulation is lost, and assuming cement goes down, will then be plugging "B,C,D" and isolating it from '~". l~rm No. P--4 ]~'~, 5-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICAT~ AP1 NU'MEP./CA.L CODE 50-133-20013 6 LEASE DESIGNATION AXD SE1RIAL NO. ADL-17595 ? IF INDIA]~, ALOTTEE O1~ TRIBE NAME 0IL ~'~ 0&8 [~ WELL WELL OTHER NAME OF OPERATOR Amoco Production Company ADDRESS ~ P. 0. Box 779, Anchorage, Alaska 4. ~ocA=oN OF Wm.t Surface: 99510 Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S .M. 8. L.~IT FARM OR LEASE NAME MGS State 17595 !t WELL NO 11 l0 ' ~1~ A.ND POOL, OR WILDCAT ~Middle Ground Shoal I1 SEC., T., R., M,. (BOCCI'OM HOI..~ om~,C-'Tn,~ Sec. 31, T9N, R12W, S.M. 1~.. PERMIT NO. 68-29 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, P~OiR~kTIONS. TESTS AND RESULTS FISHING JOB~ JUI~K LN HOLE AND SIDE-TI~ACKED HOLE A2q'D ANY O~HER SIGNIFICANT CI-IANGES IN HOI~ CONDITIONS. Sqmmary.. of pperations During January 1972: January 14, 1972 - Well shut in. January 15 - 17, 1972 - Pulled gas lift valves with wireline unit. January 18 - 24, 1972 - January 25, 1972 - Removed existing equipment from wellbore. Cleaned out wellbore to 9474' and pressure tested casing above 5800' and held okay. January 26, 1972 Ran 7 in. 29 lb/ft N-80 liner from 5712' to 9474' and cemented with 700 sacks Class G cement. Had poor returns during cement job. January 27, 1972 Ran temperature log from 5500' to 9400' and found cement top 6850' to 6900'. January 28 - 31, 1972 Perforated four holes at 7105' and no communication to the annulus. Perforated four holes at 6700' and 5810'. Cemented interval 6700' to 5810' with 275 sacks of Class. G cement. Cleaned out and pressure tested perforations at 5810'. Cement squeezed perforations at--581~' ~'a~'! of Class G FEB i DIVISION OF OIL 14. I hereb~/'~ertif~ that AT~ Ioreg~ ~ tree ~ ~ ' A'MCM[I~' f' 1972 ~TE -- Report off this fo~ il required fbr -ea~ calendar ~th~ regardless of fas status of opera/lens, ofld must ~ flied Jo duplicele with fao oil and gas conservatbn commiflee bythe 15~ of the suec~diflg mn~, ~le~ otherwise directed. Amoco Production Company P. O. Box 779 Anchorage, Alaska January 14, 1972 File: JCS-014-WF Re: Sundry Notice MGS 17595 Well No. 11 Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: A Sundry Notice and Report on Wells, State of Alaska Form P-3, advising you of our intent to repair MGS 17595 Well No. 11 is attached for your approval. Yours very truly, John C. Schillereff Supervisor in Charge At t a chmen t s Form P--3 REV. 9-30-6 9 St~bmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO, N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen Us~ "APP-I.ICATION 'FOR ~ERfV~iT-f-~' 'for such'pi:o~osal~.) . 1 OIL ~.~ GAS O WELL WELL OTHER 2.NAME OF OPERATOR Amoco Production Company 3.ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4 LOCATION OF WELL At surface Leg 1, Slot 4, MGS Platform Baker, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 79.' above MSL 14. 5. AP1 ND-B/LE~C~ CODE 50-133-20013 6. LEASE DESIGNATION A2qD SERIAL NO. ADL-17595 ?. IF INDIA.N, A. LLO~ OR TRIBE NA1V~ 8. UNIT, Fa OR LEASE NAME MGS State 17595 9, WELL NO. 11 10. FIELD A~ID POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) Sec. 31~ T9N~ R12W, S.M. 12. P EB2VLI T §7-17 Check Appropriate Box To I,ndJcate Niature of N~ti'ce, Rel~rt, or Other Date NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS , . , Other) SUBSEQUENT RI~PORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEN'T* (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) !5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. We propose to workover the well as follows: me o o 5~ Pull existing tubing, packers, and gas lift equipment. Clean out well to plug back depth. Run a 7 in. casing liner from 5750 to 9'450 and cement in place. Reperforate "EFG" zone in all previously perforated intervals. Return the well to production from the "EFG" zone only. The "A" and "BCD" zone perforations are no longer commercially productive, as shown by attached tabulation of well tests. The "BCD" and "EFG" zones are incapable of flowing production. We plan to begin this workover on about 1-17-72. 16. I hereby~that the APPROVED BY. . CONDITIONS OF APPROVAL, IF ANY: TITLE Supervisor in Charge DiT~ 1-14-72 ,, -- See Instructions On Reverse Side Approved Copy Returned MGS 17595 Well No. 11 "A" Zone Date Tested BOPD BWPD MCFD 9-24-67' 1-24-68 871 1350 175 551 2060 2701 1-28-69 1-27-70 583 450 250 192 758 248 9-24-70 30 22 38 10-24-70 28 11-25-70 92 1.0 72 4-14-71 19 12 "BCD" Zone Date Tes ted BOPD BWPD MCFD 9-23-67 1351 164 779 8-10-68 948 237 898 1- 1-69 722 372 1055 2-15-71 157 671 165 3-10-71 239 680 285 4- 7-71 222 666 193 5-16-71 199 649 229 7-25-71 11 527 8- 7-71 12 584 17 9- 5-71 173 31 10- 4-71 0 142 20 4?0 2-57 PAN AMERICAN PETROLEUM CORPORATION P. O. Box 779 Anchorage, Alaska 99501 January 7, 1969 File: FKK-21-WF Re: Use of Dual Flow Choke MGS i7595 Well No. I1 Middle Ground Shoal Field Mr. Homer L. Burrell, Director Division of Oil and Gas State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: RECEIVED J/ N 9 1969 DIVISION OF OIL AND GAS ANCHORAGE Our letter of May 21, 1968, explained the problems encountered when we attempted to perform the testing on MGS 17595 Well No. i1 required by Rule i of Conservation Order No. 56, dated January 3, i968. · Testing operations were resumed after completion of operations on Well No. 14, with continued poor' success. On July I2, 1968, during testing operations, the Otis dual flow choke check valve assembly was pulled from the intermediate tubing string of Well No. Ii for inspection. After re-rUnning the check valve assembly, the A zone could not be made to flow through the intermediate tubing string, and swabbing yielded only water. The check valve was again retrieved and the A zone sliding sleeve in the intermediate tubing string closed. T~ A zone was then returned to prOductiOn through the short tubing string, and has continued to flow to the present time, with varying water cuts. On July 21, a string of gas lift valves were installed in the inter- mediate tubing string of Well No. i1, and the ]BCD zone placed on gas lift. Results were satisfactory, and we have continued to gas lift production from this zone. Production from the EFG zone is also being gas-lifted through the long tubing string in this triple completion. Mr. Homer L. Bur. il, Director File-. FKK-21-WF January 7, 1969 Page 2 On the basis of the above experience, and continuing water production from the A zone, we conclude the A zone is an erratic and undependable source of energy at this location, and is not suitable for a dual flow choke application. Please be advised we now plan no further use of the dual flow choke at Well No. I1. Very truly yours, F. K. Krebill Area Superintendent jAN 9 FORM 470 2-S7 XCAN PETnOLEUM COP ON P. O Box 779 Anchorage, Alaska 99501 May 21, 1968 RECEIVED File: FKK-643-986.511 MAY 2 1968 oiv~s~oN oF M~N~S & M~NE~.S ANCHO~O~ Re: Testing of Dual Flow Choke - Middle Ground Shoal 17595 Well No. 11 Mr. Thomas R. Marshall, Jr. State Petroleum SupervisOr Division of Mines and. Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Conservation Order No. 56, dated January 3, 1968, approved Pan Amer- ican's application for exception to the commingling provisions of Conservation Orders 44 and 53. A provision of this order required testing of Middle Ground Shoal State 17595 Well No. 11. A report on this testing was required within three months after the initial downhole commingling. Initially, the start of the testing was delayed due to the drilling of Well No. 14 from the same platform leg as Well No. 11. Following the completion of Well No. 14, an attempt was made to begin the testing of this well. However, mechanical problems caused a further delay of this testing. It became necessary to manufacture teflon coated O-rings for the downhole choke assembly to prevent gas from permeating the rubber O-rings which were initially provided with the assembly. The teflon O-rings have now been received; however, a further delay has be~n incurred due to the necessary recompletion of Middle Ground Shoal 17595 Well~No. 14. Following the work on Well No. 14, we plan to begin the testing~of the dual flow choke in Well No. 11. We anticipate beginning this work in the very near future. The tests will be performed in accordance with Rule 1 (b) of Conser- vation Order No. 56, except for the required 24 hour flow test of the B-C-D (intermediate) zone. This portion of the testing was waived by your letter of January 18, 1968. The intermediate zone is still dead, and we will be unable to conduct any production tests on this zone. Your letter of January 18, 1968, also requested information on contact made with Shell Oil Gompany on this matter. It is our understanding that the Mr. Thomas R. Marsha~, Jr. May 21,. 1968 - Page 2 public hearing on this matter held December 21, 1968, and the subsequent hearing on commingling of Well No. 4 on March 14, 1968, constituted contact with Shell Oil Company on this subject. Please advise if this interpretation is incorrect. Yours very truly, F. K. Krebill Area Superintendent FOII~M 4'70 2.57 PANAMEPACAN PETROLEUM CORPOP. ATION P. O. Box 779 Anchorage, Alaska 99501 February 2, 1968 File: FKK-161-443 Mr. T. R. Marshall, Jr. Division of Mines & Minerals Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska Re: Packer Leakage Tests, MGS 17595 Well No. 11 Dear Sir: The required packer leakage tests on the subject triple comple- tion at Middle Ground Shoal have been completed and a curve showing pressures vs. time for each string during the test is attached. Al- so attached for your information is a sketch of the equipment cur- rently in the well. This data shows that all three of the packers are properly set, and there is no communication between any of the three zones. This set of tests was run during the period January 8 - 21, 1968. A previous set of packer leakage tests was run during the period Sep- tember 29-October 4, 1967, when the well was initially completed. The first series of tests were difficult to evaluate due to the fact that the intermediate and short strings were heading during the early test- ing period of this well. This necessitated the second set of tests. A curve showing the data from the first tests is also attached. The most recent tests were run as follows: 1. Calibrated pressure recording charts were attached to each string and to the tubing-casing annulus. 2. The well was flowed at stabilized rate for 8 hours, at the end of which the long string was Shut in for a 24-hour build-up. 3. The long string was then opened to flow; however, the remainder of the test was delayed for several days due to the necessity to test MGS Well No. 4. Well No. 11 was shut in from January 12 until January 15. The pressure recordings during this period were maintained; however, the accompanying data was incomplete, so this period is not plotted on the attached chart. FEB 1968 DIVISION O[; MINES & MINERALt AN~HO~GE Mr. T. R. Marshall, Jr. Page Two February 2, 1968 4. On January 15 all strings were re-opened to flow, and flowed with minor choke adjustments until January 17, when a flowing pressure gradient survey was taken. This data and the sub- sequent 24-hour pressure build-up data is also attached. 5. On January 18 the short string was Shut in for 24 hours, then returned to flowing on January 19. Ail three strzngs flowed at a stabilized rate until the end of the test on January 21. You will note that we did not obtain a build-up on the intermediate zone during these tests. This was because we feel the first set of testsi satisfactorily proved that the intermediate zone was isolated and no com-[ munications existed between it and the upper or lower zones. The variations in the casing-tubing annulus pressure can be explained by changes in wellbore temperature, brought about by changimg fluid rates through the tubing. The annulus was filled with diesel, and a small varia- tion in the temperature of the annulus fluid results in a large change in pressure due to the relative incompressibility of the diesel. This letter and accompanying data are supplied to fulfill the re- quirements of Section 2153 of the State Oil and Gas Conservation regula- tions. We are also submitting for your file, copies of all pressure re- cording charts obtained during the test period. Yours very truly, F. I(. Krebill Area Superintendent Attachments RECEIVED FEB 5 1968 DI¥181ON OF MINES & MINERAI,,B ANCHORAGE m~ am-m m fa ~ ~ FOR~ 4?0 2-57 PAN AME1HCAN PETI OLEUM COtILlION P. O. Box 779 Anchorage, Alaska 99501 January 16, 1968 File: FKK- 986. 511-400.1 Mr. Thomas R. Marshall, Jr. State Petroleum Supervisor Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Testing Procedure to Establish Zone Producing Rates Using Dual Flow Choke at Middle Ground Shoal No. 11, Platform "B" MGS Field, Cook Inlet, Alaska DIVISION OF MINES & MINERALS ANCHOP, AG~ Dear Sir: This will confirm an informal discussion between O. K. G±lbreth and J. R. Eaton regarding the tests which will be required to establish State '~" zone and State "B-C-D" zone production from the subject well upon the installation of the dual flow choke. This choke was approved for use as a result of the hearing of Case No. 56. Attachment No. 1 is a sketch of the downhole equipment installed in this well. Attachment No. 2 is the step wise test procedure proposed for Middle Ground Shoal No. 11. This testing will provide data for a set of curves similar to those shown as Figure 2 of the paper entitled '~rtificial Lift as Applied to the Multiple Completion Choke Assembly," by Karl N. Tunstall with Otis Engineering Company. Am Upper (State '~") zone curve and a total production curve will be obtained with the Lower (State "B-C-D" zone) curve being obtained by subtraction of the Upper zone ~urve from the total production curve. For your convenience a copy of the referenced Figure 2 from the Otis paper is attached; however, the paper was introduced as evidence at the hearing. A waiver from Shell Oil Company, the offset operator, is being obtained to permit installation of the dual flow choke in Middle Ground Shoal No. 4. A request for administrative approval of this installation was presented in our letter of January 6, 1968, File: FKK-4-986.511. As mentioned by Mr. Gilbreth, this waiver, or a 15 day waiting period after evidence of contact, is required under article 2154 of the State- wide rules. Yours very truly, F. K. Krebill Area Superintendent Attachments 470 2-5'7 PAN AMERICAN PETIIOLEUM CORPOP. ATION la. O. Box 779 - Anchorage, Alaska 99501 October 31, 1967 · ME.MORAND UM .To: J.W. Ferguson P~e: Packer Leakage Test - Middle Ground Shoal Well No. 11 ' During the period September 29 to October 4, 1967, we attempted to obtain tests on the subject well to determine whether or not we had any communications between the three zones which are segregated in this well. The pressure charts were received by this office and the data plotted up on a pressure vs time curve. This curve indicated some irregularities occurring at the time that the long string was shut in. However, there was insufficient information supplied with the chart, concerning surface manipulations, to say for certain that we do/do not have a packer leak. Therefore, we request that the final portion of the test be re-run as per the following procedure. Also, because of the declining gas rate and the varying BS & W cuts in the short string of thiS well, we request that a 24-hour pressure build-up be obtained immediately following the packer leakage test. P. lease use the following procedure: 1. Hook up pressure recording charts to each of the three strings, and to the annulus, be sure that the recorders are properly zeroed, and note the time that the charts are installed. It is important that all pertinent data is noted on each chart. This includes time on/off, any changes in surface chokes-, time when any. string is shut in or opened, and ~nything unusual which occurs during the tests. 2. Put the short string on a 24/64 choke to attempt to reduce heading. Allow all three strings to flow at a stabilized rate for approximately 8 hours, making no surface changes. 3. Shut in the long string after the flow period, and leave shut in for 24 hours. Make no unnecessary changes in the flowing status of the other two strings during this period. 4. Open the long string to flow. After the long string has been flowing for about 8 hours, run a pressure bomb into the short string. Take benches every 1000' from surf to 5000', and every 100' from 5000' to 5600'. Locate the bomb at 5600' (RDB). Do not run the bomb out of the tubing. Bottom of the tubing is located at 5619' RDB. Let the short string flow for several hours to stabilize after running the bomb, and then shut in .the short string. (Maximum BH? expected is about 2360 psi.) ''5. .Obtain a 24-hour build-up, then pull the bomb, and re-open the short strin§ to flo~.~~ on a normal choke. 6. Maintain the flow rate on all strings for at least 8 hours after re- opening the short string, and th~n consider the tests concluded. 7. Forward the BHP data, and all of the charts, to this office as soon · as practical. /' i' i /i / / ., I !/ N · // P~ n forn THE FOXSORO, U.S.A.~ / / · ./ /. ./ / / / ! t t /// :' '/ / ,// / , / / 7 /. \ .\ /' / / .o .~_ / / i ?'OXBO~O CO~ PAN¥ 3A..M. FOX~O!R.O,: HA~ S. ! J. HgIN 12 NOON / .; // : ,. ,, / :PLO00 WIO0 g // J / ,// [OS 4::. C~/ifor:~ia ,,, \- *. / / 04./~L · ~,'/,, // t / / / ? / / ? ,,,. O. · .0 A%rt- 1,4.M · Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 .,~V~6, LAND~r~,~E Anchorage LEA~ NUMBS. ADL - 17595 ~ ~ ~ ~'~ ~ ~GS State 17595 LESSEE'S MONTHLY REPORT OF OPERATIONS State ............ _~_l_~fi__k__a__ ............... Borough ............. _K.__e___n..~'_x_ ................. Field .... __D_e_~_e_.l___°.._P_m__~.n._.t_ .......................................... Tt~e followi~ is a correot report of operatior~s and prod~etior~ (i~elz~dir~ drillin~ an, d prod~ei~ wells) fortI, e rnontI~ of ............... _S_._e_p__t__emhe._r_ ...... 19__6__7__, _ ........................................................................... ffl~ent's address P.O. Box 779 Corr,-an' Pan~~___z~~American Petroleum Corp. Ancho ra e, Alaska ~i~r~ed ...... ~/-t~__.__.,~__~, __._ ....................... e~o,,e ..................................... _z_7__z_-__8_.4_Z! ............................. .~e,,~' s ~Ze __A___s_~_'_t__'__A~__?___~_d__m__~:.__s_..u._P_f ~: SEC. AND TWP. RANGE WELL D*xs BARRELS Or OIL GRAVITY CU. F~. oF GAS GALLONS o~ BARRELS o~ REMARKS GASO~NE WATER (If (If &lHin~, d~th; If shut down, ~ o~ ~ No. P~o~o,v (h'tho~) RECOVERED none, so state) date ~d r~ult of t~t for ~o~e oo~ o[ ~) ~ 0 Middle Kenai Sa ~ 31 9N lgW 11 0 Produced from 11~/~~0 ~~~~ 0 Produced from I Units, Middle Sand 0 0 roauce om ~. ......... Units Kenai San // ' ~~ ~ G Unit Conglom ...... . --"'9/' _ ~'BTI) 948~', com~ted a wing we / 9/ _ 9/7 - PBTD 9484', se dple tu~m~g string flow te~,t, ~ ' an(t move off ~ rig. .. BHL: NW SW Unit, ,nd ,C&D nai &F mhd rate See Pa e 1 No NOTE.--There were ..................... .g ........................ runs or sales of oil; ................................................ M cu. ft. of gas sold; ....................... ..N...o.. .............................. runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. OCT 9 01¥t$10N OF MINES Page 2 of 3 STATE OF ALASKA OIL AN~ GAS CONSERVATION coMMIsSION WELL COMPLETION C~ R~C .C~_ LETION REJ~ORT AND LOG la. TYPE OF WELL: OIL ~ ~;~ ~1 _S~ ~ wEI~ ~ELL DRY ~ Other b TYPE OF COMPLE~ON' ~ ~ WELL .~ OVER ~ EN '~ ~ BACK~ RESVR. ~ Other 2 NAME OF OPERATOR ~ '~ ~ } Pan American Pe~ol~m~?rporation 3. A~DRESS OF OPERATOR ~ ' o. - 4. L~CATION OF WELL (~OF~ ~ocation~earl~ an~ in:-accordance w~tk a~ ~tate requirements) xt ~c~ Leg 1, Slot 4, MGS Platform B; 1934'~FNL, 544' FWL, Sec. 31, T9N, R12W, S.M .... : ~t top prod. tnte~ reported below xt tota a ~' FSL, g~8' FWL, Sec. 31, T9~,:R12W, S.M. '.1892'FSL, 847'FWL, Sec. 31, ._.TgN, R~ZW, S,.M, .....:I 67-~7 ~ 5/6/67 SUBMIT IN DUPLI~ · (See °~her structions on reverse side) * 7. UNIT AGREEMENT NAME Effective: July 1, 1964 ~ · 5. LEASE ',DESIGNATION AND SERIAL', NO.,9~ ./~' ADL - 17595 ~'~'~'j~, $. FARM OR. LEASE NAME MGS State 17595 9. WELL NO. 11 10. FIELD AND FOOL, OR WILDCAT Middle Ground Shoal :11. SEC., T., R., M;, OR BLOCK AND SURVEY OR. AREA BHL: Sec. 31, T9N, R1ZW, S.M. Ke. nai .. Alaska 15. DiTE SPUDDED ]16. DATE T.D. REACHED ]'i7. DATECO~PL. (ReadY to~rod.)5/14/ 67 8/6/67 9/7/67 18. ELEVATIONS (DF, RR:B, gTi GR, ETC.)s [ 19. ELEVr CASlNOHEAD RKB 79' above MSL .lB'head 4!-t/2' MSL 20.TOTAL DEPTH, MD & TVD 21. PLUG, BA~ ll.D., MD & ~ I22.IF MULTIPLE COMPL., 23.INTERVALS ,,, ~' [ HOW MANY-* DRILLED BY 9543 MD 94 84-~MD Three 24. PRODUCING INTERVAL(S), OF THIS COMPLE~iON~---TOP, BOTTOM, NAME (MD lAND TVD)* : 5840' MD - 9040"MD, Middle and l~ower Kenai .. 26.. TYPE ELECTRIC AND OTHER LOGS RUN ROTARY TOOLS CABLE TOOLS O~TD I ...... ~5. WAS DIRECTIONAL SURVEY MADE Yes 27. WAS WELL-'CORED Yes 1ES, GR-Sonic, ~ipmeter, CBL 28. 29, 'CASING RECORD (Repor~_al~ strings Set in well) 20" 85# & 94# '~ /1622' i Y/8"1 54.5# & 61#1'~~; SIZE TOP (MD) HOLE-'SIZE ]. CEMENTING RECORD 26r~- I 1285 sx w/accelerator 17:~1/2" 3250 sx w/accelerat, or 12:;1/4'" 1300 s'x w/retardant LINER :RECORD . BOTTOmrY....... (MD) I SACKS CEMENT* 30. TUBING RECORD SCREEN (MD) SIZE SeJe AMOUNT PULLED DEPTH SET (MD) rACKER 'SE? (MD) Attachmer~t 31. PERFORATION RECORD (lntervaI:~, size and number) l~32' see Attached Perforation Record 33.* . PRODUCTION' ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH ~INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED DATE FIRST_ PRODUCTION.. [PRODUCTION METHOD (.FlOwing, gas lift, p~mping--size and type o! pump) ]WELLsh~t.in)STATUS (Pro5uoi~ or 9 / 4 / 67 Flowing ProduCing. See Attac~ed Test;[Reclord F~W. ~N~ ~8. CASING PRESSURE CALCUL~-~ED OIL BBL. GAS~MCF. WAYBR BBL. OIL ORAVI~-API (CORR.) 24-HOUR ' RATE 84. DISPOSITION ,OF GAS (~Old, ~sed for f~[ ~e~t~d, e~o.) TEST WITNESSED BY Flared 35. LIST OF ATTACHMENTS 1ES, Perforation re~ord, We~l history, Tubing record and Test Data 36. I hereby certify that the foregoing and a, tta~lYed information is. co,~ple~ and correct as determined from all avatla~b!e records SIGNED'~' ' ~' ,;i /t' ' · ..... -.DATE ~ ~,,~X~'"~~ TITLE AsS,t. Area Adm,n. Supvr. t0/6/~7 INSTRUCTIONS -:. . General: This form is designed for submitting a complete .and Correct well completion rePort and log on alt types of. ian~s a,,d leases to either a :Federa! agency or a State agency, or both, pursuant to applicable :Federal and/or .State laws and regulations. ~ny'necessary speeia! instructions concerning the use of this form and the number of copies to be submitted, particularly with regard to local, .area, or regional :procedures and :practices, either are shown below or will be issued by, or may be obtained from, the loca! :.Federal and/or State office. See instructions on items 22 and 24, and 33, below regarding separate reports for separate completions. - If not filed prior to the time this summary record is submitted, copies of all currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.)~ forma- tion and pressure tests, and directional surveys, should be attached hereto, to th~ extent required by applicable Federal and/or State laws and regulations. All attachments should be listed on this form, see item 35. " ~$¢m 4: If there are no applicable State requirements, locati°ns on Federal or Indian land should be described in accordance with Federal requirements.' Consult local State or Federal office for specific instructions. · I~¢m. ]8: Indicate which elevation is used as reference (where not otl~erwise shown) for depth measurements given in other spaces on this form and in any attachments. I~¢ms 22 a~d 24: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 33. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. I~¢m 2~: "Sacks Cement": Attached supplemental records for this~well should show the details of any multiple stage cementing and the location of the cementing tool i~¢m ~]: SubmP a separate comPletion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) ........ · · . ~7. SUMMARY OF POROUS ZONES: ...... ' - ~ ( .... SHOW ALL IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL DRILL-STEM TESTS, INCLUDING 38. ~EoLoGIC MARKERS · DEPTH INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN, ]~LOWING AND-SHUT-IN PRESSURES, AND RECOVERIES . . FORMATION TOP I ~ BOTTOH DESCRIPTION, CONTENTS, ETC. ' TOP : NAME ..... · . MEA~. DEPTh TRUE YERT. DEPTB MGS Sand 5612' ..... Not , SS, VF'M, F srt, F por, silty, Sli arg MGS Sand_ , 561'2' 5349' Member Reached '' '.. ' ~'' ·. Member ::" .. · ' ' -, E.£EIX/ E,D .:Core #1' 6240' . 6265' ' SS, VF-CG,. cgl, 'P-F SEt, P-G por ?. .: ' ?" ..... ' .... dk igneous grains, chty, sli~carb, "uuT 9 19S7.'-' ' ¥" ' -~ ~' ' a r ~ :'"' - .... ' ': ' ' · .~ .... , .. · .. - ~ -' C'ore #2 " 6447'· 55' Sar~eas above . - · c~,,- ~ ..-~ . , · ; · · ,, ~hronological Well History MGS State 17595 No, 11 5/14/67 Spud from Leg 1, Slot 4, MGS Platform 5/18/67 Drilled to 627' and set Z0'' casing at 622' with 1285 sx, 6/04/67 - "8'~ casing at 29i5' with Drilled to 3025' and set 13 3z 3250 sx, 6/6~,30/67 7/1-30/67 Temporarily susPended, Switched to drilling rig and drilled from 3025' to 8834' 7/31/67 Cores No, 1 and No, 2, 8/1-8/67 8/11/67 Drilled from 8834' to 9543'; logged and set 9-5/8" casing at 9535'. Stage collar at 7305'; cemented first stage with 1300 sx, second stage with 1000 sx. PBTD 9484', logged and perforated selected intervals from 9040' to 7960'. 8/14/67 Circulated, recovered gas cut mud and raised mud weight. 8/15/67 Perforated selected intervals from 7920' to 5840'. 8/16/67 to 9/01/67 Run triple string tubin~ and install tubing hangers. 9/5-7/67 - Flow te sting. 9/07/67 - Drilling rig released and well completed. Perforation Record "~ ~l.' -'- MGS State 17595 No. 11 (Section 31. ) 8/11/67 - 8/15/67 - Perforated 9030-40', 8990- 900', 8935-45', 8860-70', 8810-20', 8760- 70', 8685-95', 8615-25', 8520-30', 8430-40', 8365-75', 8255-65', 8190- 8200', 8120-30', 8060-70', 8010-8020', and 7960-70'. Perforated 7910-20', 7860-70', 7780- 90', 7710-30', 7440-50', 7415-25', 7145-55', 7105-15', 6840-50', 6795- 6800', 6760-70', 6645-55', 6580-90', 6535-45', 6480-90', 6450-60', 6340- 50', 6297-6307', 6255-65', 6210-20', 6180- 90', 6105-15', 5895-5905', 5840-50'. FORM 47,,0 2-~7 PACKER LEAKAGE TEST MIDDLE GROUND SHOAL STATE 17595 WELL NO. ll-S FLOW GRADIENT AND BUILD-UP ELEMENT 4215-N 6000 PSI TIME DE PTH 10:30 0 11:40 1000 12:30 2000 1:20 3000 2:10 4000~ 3:00 5000 3:45 5100 4:30 5200 5:15 5300 6:00 5400 6:45 5500 7:30 5600 10 Hrs. 30 Minutes Shut-in Well 6:00 A.M. (Hour(s)) 6 8 10 12 14 16 18 20 22 24 5600 DEFLECTION · 287 · 387 · 453 · 526 · 602 .612 .620 .629 .637 · 646 · 654 · 654 · 748 .761 · 765 · 768 · 770 · 771 · 771 · 773 · 774 · 774 · 775 · 775 · 775 · 775 PRESSURE GRADIENT 851 1149 1346 1563 1.791 1821 1845 1871 1895 1922 '1946 1946 · 100 ·197 .217 · '228 · 300 · 240 , . 260 ' · 240 · 270 · 240 Gradient not Corrected to True Vertical Depth 2228 2267 2279 2288 2294 2297 2297 2303 2306 2306 2309 2309 2309 2309 CX-~ C~ -~ cy,-g ~0 y,c) X ,,, ?_gL 4,ogO × LN C% ATTACtR~ENT NO. 2 DUAL FLOW CHOKE INSTALLATION MIDDLE GROUND SHOAL NO. 11 10. 11. 12. 1. Set plug in "N" nipple at 6074 ft. in intermediate string. 2. Open "XO" sliding sleeve at 5993 ft. in intermediate string. 3. Set dual flow choke in "XO" sleeve at 5993 ft. in intermediate string. 4. Run BHP bomb in intermediate string and hang at about 5975 ft. Use 72 hour clock and 4000 psi element. 5. Run a series of production tests on "A" zone, using various surface choke settings. Testing should begin after well stabilizes on new choke setting. Suggest testing on 124/64", 64/64", 32/64", and 16/64" chokes. Record all pertinent data such as: Oil rate, gas rate, BS & W%, TPF, choke, length of test, etc. Pull pressure bomb 7. Pull dual flow choke 8. Pull plug from "N" nipple 9. Re-run dual flow choke and set in "XO" sliding sleeve at 5993 ft. Run BHP bomb as in (4) above. Run new stabilized tests as in (5) above. Place well on production through dual flow choke. FIGU'RE ~ 2 PRODUCTION DISTRIBUTION CURVE · , PRODUCTION VS, TIP · · · .~, · . . 240~ ~~.~. ' ' \ 2ZO , · [VALi DATINO POINT · ' ALLOCATION ~ · ~6o. . 167 BOPD z~O' o ~1~0' o 80' ' .~~~UPPER ZONE so' ~ . ,' 67 BOPD ~ ~0' I ~-~-TUBING INLET PRESSURE ~o. ~OO . . TUBING INLET PRESSURE (PSIXIOt) i, i i , , i i , (Section 33o) Long Intermediate Short Test Hrs. Date Tested 9./i9/67 16 (Calculated) 24 9/24/67 24 9/24/67 24 TEST RECORD MGS State 17595 No. 11 .,. , ~.. .,. ;g Bbls MCF Bbls Choke Oil Gas Water 124.5/64 823 433 8 1234 650 12 124.5/64 1515 779 164 24/64 1046 ~ 175 GOR 526 514 1969 Flow Tbg. Pressure 150 90 1175 . . Casing ,.~.. ~ 1~I Pressure Gravity (Section 30.) Long Intermediate Short TUBING' RECORD MGS State 17595 No. 11 * ..... -,- , * * * -'- , Size Depth Set (MD) 2-7/8" 9123' Z-7/8" 6081' 2-3/8" 5620' Packer Set (MD) 7065' Single 6061' Dual 5605' Triple /,/Is ~ /o.¢ ,, /oo.oo /of/. ...~..,u3_.¢_- .... ~'u /,~. oo ? (,, - t o.sfi ,'=/ 8, o, 3 3 _. ¢~,~? ~9.'~ '/ 12~. ~S/ ~ 75'~, 0',~I 0,./~ ,~ 2osO I, 9'.2 i."o ? 2,/,5" 2./1. 0 1,7~ /,~2 o,~fz O, 25 0.27 0./7 /,?~ 0.'71 2.0,9.. 1,7~ 1,0~ o~- 77' "5.2 ~ 0.1~1 0.5'1 /5.6,5' ~ ~.- PAN AMERICAN PETROLEUM CORPORATION · Direction ' Depth ..~.~..~.~ ~ ,,iDef. .~-~--.-~ DIRECTIONAL CONTROL D~v. ~Cor. ~ ,. , Cou. r, se Factpr. . TVD Factor Factor __~ N z~ S ~ E ~ W ~ ~ . ~. .~~~ z/.~ .~' . ~. o.~_ , ~,~z ~, so . ~.'~ ~~~~~~~~~__ ~ z.e~_ . . 1 ,/~+* ~,zc_ . · '.'..'.. :~~ .. ~ ~ ~~~ ~ ~m~ ~- ~ ..... " ~"'- ' , ~, L _, ~ ..., ~~~~~~~~~ ~- ~;'~ ~ 7~~ ~1 ~ - ~- ~s,7.r~ ~ i~ ..... a~s E~ ~z/~ 77. ~.70 7Z ~ ~~7~ .~.~ IZ. ~ ZA~ ~~ /~~ Z=~Z ' ~.~7 ..) Me Pm~ ~~N ,,:~T~O~a~ cotu~o~T~oN L~t. Def. Direction Depth ~ ' Course' Factor TVD Factor Factor N S DIRECTIONAL CONTROL E W PAN AMERICAN PETROLEUM CORPORATIONDIRECTIONAL COIqTROL ~'~' Direction De~th La~!.. Def M.D. Dev. ~C,o,r. ~ Course Factor /% TVD TVD Fac~0,r Factor /~ N ~A~ S J?A E /l W N S E W Dog LegL ~,//~ .:~F_ ' ' ' ~~ ' ' " ' ' · - ' I' , . ' I , . .~u~e~ l~,. zo~ ~.-xl~P~Z ~ lqgf' ~~ ~ ~'~ ,~w& X~<. ~:. ToN' ,Je);:~ ~ , ,, .,[ , ,.,, , .. , 11 - i_ . ~ . _ .. . ..... i i ·, ,:, ii ~ I i ' iii ii i I : i ii i i i .... i i i i i ~ IIII ~,~:~ ....... - - ___=- ~= ~l ... ~. . . ~:~_~ ~ ~ ~ ~_----· ~ , .,,,~ ,. _ ~' , ,,," , , ~ ,., i , -- , : · ~,. n ii ':": , , . .... ~ ~" ~ ,, .. ~ , ~ ~ ..... ~ . · . ,, h. ~ ~ ~',~, .. .. ,,, , ~,., · ,,. . '. , ~ i . ~ ... , ~ ,, ~ , i , , ,, i ~ i i ~ ' ,1' ~ il i i i i ii i i i i i , ~ ......... , ,,., ~ . ., L .~ , . ., ~ . .... . ~ . , , .. . , , ,, ~i- -'~ , ~ ~ .......... , .... ....... j,, .... , , , ,~ il Il I i I I I i ii i' i ,~ ~ , i i :~,v , , , ' ,,~ , , , ~ , , .~ I I I I ' , ~ ,= '" ' A ~'~,1. C0DE_L..;!O_:!$3-20013 Release Date,,.lO_-7~69 .: Operator, ~_ ,a!!.., Amer;_ Pet. _ ~.r~. Lease No. Al)L- 17595 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Pet roleum Branch INDIVIDUAL WELL RECORD Sec. ~ ~!,, T. 9N R. 12 W , , S Meridian Permit No., .... 61;1_7 Issued .... 5-6-6__7 .. _ Leg 1. ~1o~ 4 Location (Surface) !9.~ ~ & 5~'.,.,~ ~. 3~ or Owner MgS State 17595 Loc. We I 1 No. 11 Area Middle Orou~d Shoal . ,,t.l_ .~ ~ ;' _ _ .7 :~c z - __ _. z - ~_ :_ · ~ _ "-: _ ± _ ' '~-: .... "_"' Spud Oate_:_5...14t67 D'~i 1 1 lng Ceased , (Bottom)__ 1,8,~2 ESL_ &'8_~7' .,_1~, _~e¢? 31_ .... _ ,. -, ~ "' , ..... Pg~ 9,489' * Total Depth ! Suspended Abandoned Elevation 78.75 ldSL Coaplet~d (~-~L-P)9-;-67 2~-' .... (~}~~.._ ~/0. ~rav APl Cut Casing: Size Depth SxCmt 20" 622' t285 9 5/8" 9535 ' 1800 pe r,f?:, _see. b.;a~.;k_.;.o!_ sheet_ :;-_P I,~ugs_ :._ ~ ;..g~89 ......... ' -- 9~84' GEOLOGIC FORHATI ONS PRODUCTIVE HORIZONS Surface LOWest Tested Name Depth Contents WELL STATUS Year Jan ~F~b , Mar ._Apr, ,. May June July Aug. Se~t , '--; ~:_:~.~;';-;:~_;_:__~--~ ~-....._.~.;_.~.~ ~-, - ~_ -, .;~ ~.~,_~.~.~..~ '~-':-.. , _~.~. ~ ;~ :~_v.. ' ~'~ ,? ,~'~:~ ~ '. -: ~. '-~'-u ,... '~ ~ -~ ,',~ '; ~ .Oct Nov Dec Remarks: ~ontr: Readin~ & Bates on' M.O.s. Platfora "B" - _: .._ .~ _ ..._=. ~.. 7- _ _ ....~ - ! ~ ~'"L _ · _ _ ~._..~ . .~ -. - -~ · .: '=: :_: ....... ' - , ___ . L ' .... J~ _,. ~ .... 1, _' - Perforation Record - . , .... · ,:.~.* .............. -'"'/ ~:' .................. MGS State 17595 N(~. 11' (Section .3.!., )_. ......... . ............... .... 8/1'1..I 6.7 8/.,1.,5t 67 _. .... per f.o r..a.te, d.. 9030-'40', 8,990 :- 900', · 8935-45', 8860-70', 8810-20', '8760 ....... ............ .70', ..8685.-95', 8615-2'5',' 8'520-30', 8430-"~'0;, 83,"6'~-':7.5i', 8255-65', '819'0': ................. ........... 'Szob', '811o.-:~o',...8Q.6. o-'7.0..f, .8OLO-8OZO',,., ........ '-.....'' .-'~ and 79.60-70'. · . . . , . '_ . Perforated 791'0-~0.',-'7.860'-'~);'; 7?80- ' ": ............ 9'0"'; ~'77't'0~"30'"'?'''~~'~8- 50~'""i;'7:'~15'"'2'5"!";' ''~ . 7145-55', 7105-15', 6840-50', 6?95- '"'6'80'0"; "6-"f'80'-?'0' ,-"6'645--5'5' *"",' 65.80,..,90!, ............... 6535-'45', 6480-90', 6450-60', 6340- ............ -~*0-~.-;--'-629 ? z 630.7,.-;---..6.Z 5...5_ 6~';-. 62&0',-.20'-,. 618.0 ........... 90', 6105o15', 5895-5905', 5840-50'. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 ADL - 17595 LEA~E NUMBER LEAs-- OR U.,~ .AM~ MGS State [7595 A2[ 50-[3~-Z00[~ LESSEE'S MONTHLY REPORT OF OPERATIONS State .............. _A_ __l_ _a_s__ .k_ _ a_ .............. Borough .............. _ _K_e__ A_a_ _i- ................ Field ........ _D_ _ ._e y_ _ e. l_o__p.m_ .e_ __n. _t_ ...................................... Tke followinff is a oorreot report of operations and prod~etio~ (incl~dir&~ drillir~ a~.,d prod~einff wells) for tke montk of ................. ..A__~g_u__s__t_ ........... 19_6__7__, ............................................................................ .4~ent's address ..................... _-P--'____~.-___--~--°--x----7--7---c)- ................ Company____ __~___~_~~----------Pan Amc ri can Petroleum Co rp. Pipette ..................................... ~_7__~__-___8_.4__7__~_. ............................ .Xl~e~t' s title ..... ........ Or. F~. o~ OAS SEC. AND BAREELS OF OIL ~ or ~4 (In'thousands) BHL: Sec. 31 NW of SW 0 0 ning tubin I/1 / 6 7. sx Class G ' runnin /6, TD9 500 sx GL .4% c: CFR-2 a .g for trip] (~ALLONS 0~' OASOLINE RECOVERED ~43', sel ~ss G pit FR-Z; nd 500 s e compl, BARREL~ OF WX~EE (If none, so state) REMARKS (If drilling, depth: If shut down, oauae; date and result of test for content o! 9-5/8" ~s . 4% H .~mented x Glass .~tion of :asing at R- 7 and second ~ cement. veil. NOTE.--There were ............. ..N..©. ............................. runs or sales of oil; .................. ..N.0.. ....................... M cu. ft. of gas sold; No runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th of the succeeding montt~u[~le~ ~h[rvf~. directed. L ! VI,[ DI¥I$ION OF MINES & MINERAL~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE LESSEE'S MONTHLY REPORT OF OPERATIONS Effective: July 1, 1964 LAN° o~,=~ Anchorage LEASEN''MS~ ADL -- 17595 LE^S~ OR ~'~ ~GS State 17595 API ~50-133-20013 State ............ A!a__s_ka ................ Borough .........._.K_e_D_a_.i. .................... Field ............ D__e._y_.e.]_9_p.__m.__e_.n__t_. Tire followi~ is a eorreot report of operatio~zs and production (i~el~dir~ drillir~ff and produeir~ff wells) for the month of .................. ~__u_!¥_ ................ 19_6__7__, ............................................................................ .4~e~t's address P.O. Bo-x--__7__7_~_ .................... Core, an, Pan~ -_~America'-n' Petroleum _C_.9_rp. ............................................ A _n___c__h_o__r_ .a_g _e_,___A3_a_~__k__a_ ........... Si~,~ed ........ ~~ ........ Phor~e 272 - 8471 ~,~,,~,,o ,~z..~Area Suffe rintendent ................................................................................... W.L~'~ u ~,v~.v~ ................................................. SEC. X~D :BAauZm ov On. 3/o= 34 BHL: Sec. 31 NW / 4 SW/4 ahead on ..aning out 3035', dr 13' and re 3/' ho iVITY ./61 vez Cu. F~. OF GAS (In thousands) 0 7/5, TD ahead. 7 ed 7~; Co (~ALLONS OF (~ASOLINE RECOVERED 025', m 31, TD e #2 882 BARRELS OF WA~R (If none, so state) illing jul 834' -34'. REMARKS (If drilling, del>th; If shut down, oause; date and result of teet for gmm[ine content of ~) Lk )re NOTE.--There were ............. .N....O. ............................ runs or sales of oil; .................. ..N.._.0 ....................... M cu. ft. of gas sold- No runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must directed.be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month,~nl~ss.~otherwisek_ C E [ V E D AU~ 1 0 1987 DIVISION OF MINES & MINERALS Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 .~No orr,c~ Anchorage L~A~E N,,MsE~ADL - 17595 LE^~E =~ =~'~ ~ MGS State 17595 AP1 50-133- 20013 LESSEE'S MONTHLY REPORT OF OPERATIONS The followir~ is a corree~ repor~ of operatior~s and prodz~c~ior~ (ir~cl~dir~ drillir~ and prod~ei~ wells) for the mo~th of ................ 3u~ ...................19__~_, ............................................................................ ~ee~'s aaares~ r. 0, .Box 779 Company ............................... ............................ ..... .............. Phone .................... ~r_~2~ ............................................... d~ent' s title .._~_~UP_~_~_~~~ ' ' ' ' ............. , , SEC. AND BARRELS OF OIL GRAVITY (~ASOLINR WATER (If (If drilling, depth; if shut down, oause; ~ OF ~ TWP. RANGE WELL DAnte CU. FT. OF GAS GALLONS OF BAEEELS o~ REMARKS No. P~om~c~. (In' thousands) RECOVERED none, so state) date and r~ult o! te~t for content o! ga~) :. 31 '~ S~/& 9N 12~ 11 0 0 0 0 0 0 TD 3025' , operations tel~porarily ~,luspended 6-30-67 On 6-5-(7 TD 3025i' /8" , , set 13-3 (:asing at 2975', ..emented wil~h 60( sx Class G plu~ 33~ per ~x of Dia~el D pl~s ce..lopha.ne flakes per si~ and 2,05( sx Class G and ~00 sx Cl~.ss G plus 2% CaC12 a~.~d ~ cell~,phane fl~kes per sx. 6- i-67, TD 3025' , operations temp¢,rarily s~spended BHL Sec NOTE--There were ...........................N..O.. ................. runs or sales of oil; ................... N...0 ........................ M cu, ft. of gas sold; No runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines& Minerals by the 6th of the succeeding mo~h,~,,,un~es~ o. th~er, wi~e__ directed. Kk~/ V ~ ~' JUL l 1,19E;? DIVISION OF MINES & MiNERAI~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 D - ~rr,~.E Anchorage l.~,~,.,-~ '~ NuMBs. ADL - 17595 ~ ~0~ a~ ~'~ ~ MGS State 17595 LESSEE'S MONTHLY REPORT OF OPERATIONS State .......... _A___l__a___s___k_a_s2 .............. Borough ........ ,K___e___n_._a_i ...................... Field ........ D._e_v. el_Qp_ment_ ...................................... Tl~e followir~ is a eorreo~ repor~ of operations and prod~etior~ (ineh~di.r~ff drillin~ an, d prodt~ein~ wells) for tl~e rnontl~ of ....................... __M__;a_y_ ........... 19~___7___, ............................................................................ .4~er~t's address ..........................._P__;__~_O__:____~__q_x___7__7__9_ ........... CompanF _P__a_n___A_me_= £c.arr.., ,.. ~/ ~ ,.~ ,q .P.~t,~ ole_~m.C o_r p. ..................................................... __A__n_c_h_o_r_ag_e_,__~kla.s_ka_ Si ffr~ed., .......... ~~__ PAor~e .......................................... _2___7__2__-___8_.4__7__1_ ....................... ~/~er~, s title ..........." Area~ ' ' '}__a.~_!_n__t_e___n__d__e___n.t. ......... . . SEC. AND BARRELS OF OIL (]RAVITY (]ASOLINE WATER (If (It drlllinz, depth; if shut down, oauae; ~,~ OF ~ TWP. RANGE WELL D~rs CU. FT. OF (]AS(]ALLON8 OF BARRELS o~ REMARKS NO. Pao~oo,v (In thousands) RECOVERED none, so state) date and result o! test for eontent of gsa) iL: , W/4 9N 12W 11 0 0 0 0 0 0 TD ~025t'. Re~ming at ~1280~. Spu~[ at )1~0 ~,n 5/1.4/67, 5/17/67, TD ~27'; set 20" cas:~ng at 6~2' S.nd ¢~imented w:th 18!~ sx Class G with ~# sx D~acel D a~d 11)0 sx Class G plus 4~f0 CaC12. 5/19/67, TD 62~ ; ~ep~i~img DC genezatozs and pzepazing to d~ll ahead. B Se NW/4 S NOTE.--There were ................ .N...°.. ......................... runs or sales of oil; ............. .N..0.. ............................ M cu. ft. of gas sold; ........................... ..N...o. ........................... runs or sales of gaSoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 0th of the succeeding rn_onth, unless otherwise directed. RE CEIVED JUN 919e7 DIVISION OF MINES FORM 470 2-57 PAN AMERICAN PETROLEUM CORPORATION P. O. Box 779 Anchorage, Alaska 99501 May ZZ, 1967 File: FKK- 731-WF Re: MGS State 17595 #11 Mr. Thomas R. Marshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: This is to advise you that the surface location of MGS State 17595 Well No. 11 has been changed from the location reported on the Form P-1 filed with your office May 3, 1967. The change is from the intended location of Leg Z, Slot 1, which is 1989' FNL and 588' FWL, to the current drilling location in Leg 1, Slot 4, which is 1934' FNL and 544' FWL. Please adjust your records accordingly. Yours very truly, F. K. Krebill Area Superintendent REC I:'IV E: I) ~'~Y 2 9 1967 OIVl$1Ohl OF MINE,S & NtlNERAL~ FORM 470 2.5'7 PAN EmCAN · CORPORATION Anchorage, Alaska 99501 May 16, 1967 File: FKK- 703-WF Re: Spud New Well - MGS State 17595 ~tl, #AP1 50-133-20013 Director Division of I~nds Department of Natural Resources 344 Sixth Avenue Anchorage, A la s ka Dear Sir: Thi~ is to notify you that the subject well was ~pudded on State Lease ADL-17595 at 0130 hours on May 14, 1967. The sur- tace location of this well is at SW/4 NW/4, Section 31, TgN, Rt2W, S.M. We plan to drill this well directionally to a bottom hole lo- cation of 1770' F~L, 1070' FWL, Section 31, TgN, IA1ZW, S. lVl. Yours very truly, Origin~ Signed ~y: F. K. KBEBILL F. K. Krebill Area Superintendent c/c: Mr. Thomas R. Marshall Division of Mines & Minerals Iii &Iirf, e,m Peim'oleI Cu~,ee'atbm i'. O. IoI ~ FORM SA 50M 1/67 !?!?~-_- MEMORANDUM TO: J-- FROM: State of Alaska DATE FORM SA 50M 1/67 iii!iiiiii!i--" ': MEMORAN!DUM TO: J-- FROM: State of Alaska DATE : SUBJECT~ SUBMIT IN TR1 JATE* : STA-TE OF ALASKA : (Other t"~tructi0'm~ on reverse side) OIL AND GAS CONSERVATION COMMITTEE APl 50-133-20013 Effective: JulY, 1, 1964 5. LEASE DESIGNATION AND SERIAL NO APPLICATION FOR PERMIT TO,-!DRILL, DEEPEN, OR PLUG- BACK ~R. T,P'O, WO~,'~..DRiLL:~ ......., -,- :DEEPEN Fl:. PLUG BACK"I'] b. Tn;ii'o~'w~L~, ' -~'-": .... '~ OIL [] OAS D SINGLE ~ MULTIPLE[] WELL WELL OTHER ZONE ZONE 2. NAM~OF' OPERATOR ' :u'z..;· ~ . ~" .: Pan American Petroleum Corporation ~ '- o. 779: A o 0r% , ' 4. LOCATION OF WELL /Report location clei~rly and in accordance with any State requirements.*) .~A,~' <~: ~FNL, ~ FWL, Sec: 3..!, T9N, R1ZW, S.M. e~ / ,At s~'rfaee '/a-~4 , ' ' ; *'4 ~; ............ ' ........ " ':: ': ' / At proposed prod. zone See Attached 14.DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 20 miles NW of Kenai l~. DISTANCE ,aO~ PaO~OSED' 1770'from AD~-18~/54 I ~6. No. OF ACRES IN LEASE LOCATION TO NEAREST ~ I PaoPEaTY sa LEASE LINE, FT. Sc~CAL a~l°"tic t (Also to nearest drlg. unit line, i~an~~ , ~H~ ,. [ 5106 I8. ~lgYi~c~ ~aO~ ~aOPOS~D ~OCtYIO~* ~//1~ ~..l..r . [ 19. ~~-- · o ~ta~S~ w~ ~i~, CO~,?OO ~ ill ~ [q.[ o~ ~m~ ~o~, o~ ,am ~., .. MGS State 17595 ~7 10,000' 21. EleVATIONS (Show whether DF, RT, GR, ets.) 78.75' above MSL ADL -' 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME MGS State !7.595 ~),~ WELL NO. 11 10. FIELD A,~'~ POOL, ~a wILDcAT · Middle Ground Shoal 11. SEC., T., R,, M., OR BL~. ,. AND SURVEY QR. AREA BHL: Sec. 31, T9N, R12W, 12. BDROUGH SH] 13. STATE Kenai[ Alaska 17.NO. OF ACRES ASSIONED TO THIS WELL 160 20. ROTARY OR CABI,E TOOL8 Rotary 22.' APPROx. DATE WORK WILL START* May 12, 1967 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMEN~ 17'-1/2" 13-3/8" 54, 5~ 2000' Circulate to surface 12-1/4" 9-5/8" 40# & 43# 10000' Cement to cover zones A,B, C, D, E and i~,G ADL-17595 Well #7 has been drilled on the SW/4, Section 31, T9N, R12W and dually completed in MGS Pools B, C and D, and in Pools E, F and G. Performance of this well indicates that MGS Pools E, F and G contribute little, if any, to the total oil produced from the well. Efforts to stimulate production from these pools in the well have been unsatisfactory. The primary purpose of ADL-17595 #11 is to establish satisfactory production from MGS Pools E, F and G on the SW/4, Section 31, T9N, R1ZW. MGS Pool A'will be tested; and if it is found productive of oil, the well may also be completed in this pool. Adequate precautions will be taken to in- sure that bothADL-17595 #7 andADL-17595 #11 are completed, operated and pro- duced in accordance with the rules, regulations and orders of the Oil and Gas Con- servation Committee. BOP arrangement attached. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proPosal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depth-s. Give blowout preventer program, if any. 24. I hereby ce, r~at.t~ Foregoing is True and Correct. SXGN~D ~' :..~~--~-~-~..~ TITLE Area Superintendent DATE 5/3/67 (This space for Federal or State office use) PERMIT NO. CONDITIONS OF APPROVAL, IF ANY: TITLE APPROVAL DATE THOMAS R. MARSHALL, JR. .Executive Secretary Alaska Oil & Gas Con..~rva,fion Committee *See InstrUctions On Reverse Side RECEIVED 1961 DIVt$1ON OF MINES MGS STATE 17595 No. 11 Attachment to Item No. 4: We anticipate encountering the following production zones at the locations as shown below - A Zone 2170' FSL, 930' FWL, Section 31, T9N, 1R12W, S.M. E Zone 1970' FSL, 1000' FWL, Section 31, T9N, 1R12W, S.M. Bottom Hole Location - 1770' FSL, 1070' FWL, Section 31, T9N, 1R12W, S.M. RECEIVED I. AY 3.1967 DIVISION OF MINES & MINERAI~ ANCHORAGE Flow line ~ ~ i , h- RECEIVED I,iAY 3,1967 DIVISION OF MINES & MINE~ ~-~,,e~-~ Rams ................................ j J .- 4,, ~iu,..~ or? ..~ , 2" Check Valve Spool~ ~gaue valve J ' ~):ud Gauge o~, plug valve~ . ~ ~' olug valve 2"Plu Valve 4" piug vcive 0" 2" ~"* 4" line w/shop ~4" tarn -~o or Gate .Valve ' made swae~ w/no tine more ~han~45© bend ~ gtank rams ~~ 2" plug valve 1-2" Plug Valve on side ou~i'e~ ~~2" line Equipmen~ below ~his poin~ fu~ished by Pan f~n. / ~ choke . . .- . i.'All preventor~s to be hydraulically ope.rated from an accumulator which will open and 'close hydril a~ ~e'as~ nhree ~imes-'without 2. All equipment thru which 'bit must pass to have at !eas~ as large iD as casing being dr~ lied ' ' . - ~. gnrougn 3 KelIy cock Co bo on KaS~y irom ~ime o~ spud. 4. Drill pipe safe~y valve equivalen~ to Shaffer~ Mod. 55 or 0MSC0, wi~h proper connections, .to be on rig floor at ail ~imes. 5. Ail equipmen~ mentioned abovo eo bo 5000~~ WP or 6 All connections to be flanged. 7. Operaging ~r~nifold ~o be in'easy reach of drillers ~ation w/% romo[c operating : s~agion. .. RECEIVED Dl¥1~lON Of MINES & MINEP, AL~ ANCHORAGE ~9o~ 70o 400