The URL can be used to link to this page

Home My WebLink About165-038MEMORANDUM 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:11128 ft MD Lease No.:ADL0017595 Operator Rep:Suspend:X P&A: Conductor:20"O.D. Shoe@ 595 Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 2012 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 7565 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 11127 Feet Csg Cut@ Feet SS Tubing:3-1/2"O.D. Tail@ 5831 Feet Tbg Cut@ Feet LS Tubing:3-1/2"O.D. Tail@ 5839 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Long String Fullbore Other 6430 ft 5334 ft 9.8 ppg Wireline tag Short String Fullbore Other 6430'5779 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result LS Tubing 1702 1637 1610 SS Tubing 1702 1637 1610 IA 1702 1637 1610 OA 140 140 138 OOA 135 132 126 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): Cement plug set on D Sump Packer at 6430 ft MD. Good tag in both tubing strings; good samples. Passing MIT - 0.6 bbls pumped and returned. Well left with Suspended status. August 23, 2025 Kam StJohn Well Bore Plug & Abandonment MGS ST 17595 Baker-5 Hilcorp Alaska LLC PTD 1650380; Sundry 324-367 none Test Data: P Casing Removal: rev. 3-24-2022 2025-0823_Plug_Verification_MGS_State_17595_Baker-5_ksj                             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:Casey Morse; Regg, James B (OGC) Cc:Juanita Lovett; Dan Marlowe; Daniel Taylor Subject:RE: Baker P&A Scheduling Date:Monday, June 23, 2025 3:24:00 PM Casey, The answer to both questions in your email below is yes. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Casey Morse <Casey.Morse@hilcorp.com> Sent: Monday, June 23, 2025 2:02 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Daniel Taylor <dtaylor@hilcorp.com> Subject: Baker P&A Scheduling Jim / Bryan, We are solidifying our plans for this year’s campaign of Baker P&A work, and we are hoping to start executing our coil and cement work in early August. It will take us several weeks to prepare the platform for staging equipment and hosting our crews, so that process is underway. Our intent is to conduct coil, eline, and cement work in the first phase. Once cement plugs are set in accordance with the approved sundries, we could place notice for witness of all the tags and MITs to coincide. With that in mind, there are a couple deadlines coming due in July, and I want to be sure we are aligned on work timing and coordinating for the most efficient use of time and resources. Baker-05 (PTD 165-038): Sundry 324-367 includes work scope to tag cement tops and perform a CMIT after providing 48 hours’ notice to AOGCC for opportunity to witness. This work was not completed during last year’s program. The sundry was approved 7/1/24 and has a one year expiration. Could we extend this sundry expiration date to continue work under this sundry and coordinate the tags, MIT’s, and suspended well inspections to coincide with others on the platform before the end of the 2025 work season? Baker-31 (PTD 195-199): Sundry 324-387 placed this well into Suspended status with an approval date of 7/16/24. The Suspended well inspection will be due in July for the 12-month inspection. Could we also push this deadline to coincide with the inspections for the remaining wells at the end of the 2025 work season? We are unable to continue work beyond mid-November due to weather constraints and facility limitations. It is our intent to complete the sundried work with enough time to issue notice and conduct all the witnessed tags and MITs in advance of that time. Thank you, Casey Morse Operations Engineer Cook Inlet Offshore Hilcorp Alaska, LLC (907) 777-8322 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, pleaseimmediately 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. Nolan 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241205 Well API #PTD #Log Date Log Company Log Type AOGCC ESet AN 15(GRANITE PT ST 18742 15) 50733200700000 167082 11/18/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 10/24/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/21/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/30/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 11/8/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 11/12/2024 AK E-LINE Plug/Perf END 2-72 50029237810000 224016 10/16/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 10/18/2024 HALLIBURTON COILFLAG MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL MPU F-109 50029235960000 218014 10/28/2024 READ CaliperSurvey MPU J-02 50029220710000 190096 11/16/2024 READ CaliperSurvey MPU J-47 50029238010000 224120 11/9/2024 READ LeakPointSurvey MPU D-01 50029206640000 181144 10/23/2024 AK E-LINE TubingPunch MPU F-02 50029226730000 196070 11/18/2024 READ CaliperSurvey MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24 MRU M-25 50733203910000 187086 11/15/2024 AK E-LINE Plug NCIU A-21 50883201990000 224086 11/9/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/19/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Plug/Perf PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT PBU H-36A 50029226050100 200025 10/26/2024 HALLIBURTON RBT PCU 02A 50283200220100 224110 11/24/2024 AK E-LINE Perf Please include current contact information if different from above. T39808 T39809 T39810 T39810 T39811 T39812 T39813 T39813 T39814 T39815 T39816 T39817 T39818 T39819 T39820 T39820 T39821 T39822 T39823 T39823 T39823 T39823 T39824 T39825 T39826 T39827 MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.05 14:52:46 -09'00' 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: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,128 N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate 3,090psi Production 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: Cement MGS Oil Pool N/A 6/30/2024 11,1273,788 3-1/2" (LS) & (SS) 10,395 SC-1L Packer & N/A 5,895 (MD) 5,195 (TVD) & N/A Perforation Depth MD (ft): 7,565 6,085 - 6,405 7" 5,374 - 5,686 450 26" 20" 13-3/8" 595 9-5/8"7,565 2,012 MD 5,750psi 1,530psi 3,090psi 595 1,952 6,842 595 2,012 Length Size Proposed Pools: 450 450 9.2# / L-80 (LS) & (SS) TVD Burst 5,839 (LS) 5,831 (SS) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 165-038 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-10071-00-00 Hilcorp Alaska, LLC MGS ST 17595-05 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 Middle Ground Shoal Oil N/A 10,396 6,440 5,721 2196 6,440 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.06.21 13:39:16 - 08'00' Dan Marlowe (1267) By Grace Christianson at 4:37 pm, Jun 24, 2024 324-367 Suspend Run CBL in long string after cementing to verify top of cement in Inner Annulus. 10-407 BJM 6/28/24 Place at least 100' of cement inside 9-5/8" casing and Short string across the 13-3/8" casing shoe. SFD 6/28/2024 Provide 10-days notice for wellsite inspection, to be coordinated with other suspended and P&A'd well inspections on Baker platform after the 2024 P&A season is complete, but before Nov 1, 2024. DSR-6/25/24 X Provide 48 hrs notice for AOGCC witness of 1500 psi CMIT LSxSSxIA and tag of TOC in SS & LS tubing. June 30, 2029 *&: Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.07.01 10:34:39 -08'00'07/01/24 RBDMS JSB 070224 Oil Zone P&A Program Well: Ba-05 Well Name:Ba-05 API Number:50-733-10071-00-00 Current Status:Shut-In Producer Rig:SL, 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):2752 psi @ 5564’ TVD (2005 SBHPS, EMW: 9.5 ppg) Max. Potential Surface Pressure:2196 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA):135/50/200/99/120 psi History Drilled and completed in 1965-1966 and put on production in 1966 as an oil producer. Several workovers were performed including fracs, perf adds, squeezes, and recompletes. The well produced until the platform was SI in 2003. In October 2010 the tubing was punched from 5831 - 5837’ MD. The well was then circulated with 9.8 ppg brine and a 20 bbl pill of LCM was pumped to plug off the perforations. The LS and IA were freeze-protected with diesel, but the SS plugged off during Freeze-protect attempts. 20” Casing set @ 595’ MD. Pumped 798 sxs Class A w/ 2% CaCl2. Lost returns at 798 sxs. Ran 2-3/8” tubing down 20” x 24” annulus to 240’ and cemented with 335 sxs Class G w/ 2% CaCl2. Cement to surface 12/20/65. 13-3/8” Casing set @ 2012’ MD. Pumped 640 sxs Class G Neat followed by 1160 sxs Class G w/ 2% CaCl2. Lost returns during last 100 sxs of displacement – fluid level dropped in annulus. Ran 1-1/4” pipe down 13-3/8” x 20” annulus to 730’, cemented with 154 sxs Class G Neat followed by 330 sxs Class G w/ 2% CaCl2 – lost returns at 384 sxs pumped. Ran 1-1/4” pipe down 13-3/8” x 20” annulus to 480’, cemented with 450 sxs Class G Neat. Good cement returns. CIP at 1800 hours 1/8/66. 9-5/8” Casing set @ 7565’ MD. Pumped 1000 sxs Class G w/ 1% CFR2 followed by 950 sxs Class G neat. Ran CBL 2/15/66 indicating TOC @ 2000’ MD. Current Status Shut-in. LS, SS, and IA were loaded with 8.6 ppg FIW. A CIBP is set at 6490’ MD isolating the lower perforations. Pre-P&A Diagnostics Performed 1. Initial pressures (LS/SS/IA/OA/OOA): 1080 / 755 / 1175 / 185 / 205 psi 2. Circulate FIW: a. Pump down LS up IA @ 1000psi / 2.5 BPM b. Pump down IA up LS @ 1000psi / 2.5 BPM c. Pump down SS up IA. No communication, pressure up to 1500psi w/ 4 bbl d. Pump down IA up SS. No communication, injecting down IA @ 800psi / 2.5 BPM e. Pump down LS up SS @ 1200psi / 2.5 BPM AOGCC cementing specialist verified TOC extends beyond top of CBL logged interval @ 1900' MD. -bjm Oil Zone P&A Program Well: Ba-05 f. Pump down SS up LS. No communication, pressured up to 1500 psi w/ 1.4 bbls 3. Inject down LS @ 1350psi / 1.7 BPM. Pumped 21 bbls, shut down pump, bled down to 800 psi in 5 min 4. Bled down OA to 50 psi, bled OOA to 0 psi. Bleed appeared to be air; no communication across annuli. 5. RU slickline on LS. RIH w/ 2.75” GR to 5873’ SLM. POOH. RIH w/ 3.5” D&D Holefinder to 5840’ SLM. Pressure test LS – fail. Pull up to 5832’ SLM. Pressure test LS – fail. Pull up to 5782’ SLM. Pressure test LS to 750 psi for 5 min – good, no drop in pressure. 6. RU slickline on SS. RIH w/ 2.75” GR to 3844’ SLM, work down to 4140’ SLM. POOH. RIH w/ 2.25” bailer to 5672’ SLM. POOH. Bailer full of iron scale. Objective Plug and abandon the Middle Ground Shoal Oil Pool perforations and CMIT the casing / tubing to place this well in suspended status. This well will be evaluated for future sidetrack potential or uphole gas recompletion. Procedural steps 1. Fluid pack the tubing 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 308 bbls 14 ppg Class G cement. Record volumes of fluid recovered i. Start pumping down LS and out IA ii. After 275 bbls returned from IA (IA cement volume of 223 bbls plus LS volume of 52 bbl), close IA and open SS iii. Return 37 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 46 bbls of 9.8 ppg brine displacement of cement (puts TOC in LS @ ~5200’, TOC in IA/SS @ ~2000’) ¾ Hold 700psi on LS to over-displace cement top down to 5200’. ¾ LS volume from tubing tail to 5200’: 0.0087 bpf * (5910’-5200’) =6 bbls ¾ SS volume from Kobe to 2000’: 0.0087 bpf * (5831’-2000’) =33 bbls ¾ IA volume from tbg tail to 2000: 0.0626 bpf * (5910’-5831’) = 201 bbls o 5910 to 5831: 0.0626 bpf * 79’ =3 bbls (tubing tail x IA) o 5831 to 5499: 0.0507 bpf * 332’ =17 bbls (LS/SS x 43.5#) o 5499 to 2000: 0.0520 bpf * 3499’ =182 bbls (LS/SS x 40#) ¾ Casing volume from tubing tail to 6405’: 0.0745 bpf * 495’ =37 bbls Total Cement Volume with 10% excess: 308 bbls ¾ LS volume from 5200’ to surface: 0.0087 bpf * 5200’ =46 bbls ¾ SS volume from 2000’ to surface: 0.0087 bpf * 2000’ =18 bbls ¾ IA volume from 4600’ to surface: 0.0520 bpf * 2000’ =104 bbls Fullbore/Slickline 1. CMIT LSxSSxIA to 1500 psi (AOGCC Witnessed). 2. Tag TOC in LS and SS (AOGCC Witnessed). Ensure all gas is out of the wellbore and liquid returns to surface on all tubing and IA before pumping cement. -bjm Run CBL in LS to verify TOC in IA. -bjm Adjust cement volume to bring TOC in the SS and IA up to at least 1900' MD, to place at least 100' cement across the casing shoe. -bjm Oil Zone P&A Program Well: Ba-05 Cement Tops: x 9-5/8” Casing: CBL Attachments: 1.Current Schematic 2.Proposed Schematic Updated by: JLL 3/30/16 SCHEMATIC Middle Ground Shoal Well: Ba-05 (MGS ST 17595 #5) Last Completed: 12-28-1990 PTD: 165-038 API: 50-733-10071-00 PBTD =6,440’ TD = 11125’ MAX HOLE ANGLE = 40O @ 4617’MD 26” 450’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 7565’ 7” 11127’ 7339’ 7” TOL Tbg Punch 5871’ - 5877’ 5906’ SC-1 Packer 2000’ TOC CBL 20” 595’ 13-3/8” 2012’ 6430’’ DSump Packer 6440’ EZ-SV w/ bridge plug kit – 11/90 10,200’ CMT Retainer 8677’ CMT Retainer 7648’ Baker “F” Packer w/ 3-1/2” tie in Tbg Punch 5831’ - 5837’ MGS Oil Top 6057 MGS Gas Base 5152 ‘ Perfs @ Intervals 8690 Top 9150 BTM Perfs @ Intervals 6448’ TOP 7125’ BTM Perfs @ Intervals 7730’ Top 8634 BTM 5-1/2” 15.5# J-55 0.012 Wire Wrapped Baker Weld Screen ID: 4.95 Gravel Pack 20—40 Mesh Ottawa Sand RA SV XN XA 8.6 PPG FIW RA SV XN XA 8.6 PPG FIW KB: MSL Mean Sea Level Mud Line Casing Details Size Type Wt/ Grade/ Conn ID Top Btm 26” Structural .5” Wall 25 Surf 450 20” Conductor 94, H40, STC 19.124 Surf 595 13-3/8” Surface 61, K55, STC 12.459 Surf 2,012 21.8º 9-5/8” Intermediate 40, N80, BTC 8.835 Surf 3,496 40, S95, STC8RND 8.835 3,496 5,499 43.5,S95,STC8RND 8.775 5,499 7,565 7”Liner 29, N80, 8 RND 6.184 7,339 10,429 29, S95, 8 Rnd 10429 10,429 11,127 Tubing Long String 3-1/2" Prod Tubing 9.2, N80, TDS w/ SCC 2.992 32.75 5,839 Short String 3-1/2" Prod Tubing 9.2, N80, TDS w/ SCC 2.992 32.75 5,831 Completion Jewelry Detail #DepthID OD Item Long String (Power Fluid) 32' CIW Hanger, (3-1/2” Buttress Down – 3-1/2” EUE 8 Rnd Up) 33' 3.438 Crossover, 3-1/2” Buttress P x 3-1/2” TDS P 2.992 3-1/2” 9.2# N-80 Tubing 5,839' 3.438 Crossover, 3-1/2 TDS B x 3-1/2” EU * Rnd P 5,841' 2.687 KOBE 3” Model “D” BHA (ID SV Removed) Number: ANC1540 Short String (Production) 32' CIW Hanger, Buttress @ 32’ (3-1/2” Buttress Down – 3-1/2” EUE 8 Rnd Up) 33' 3.438 Crossover, 3-1/2” Buttress P x 3-1/2” TDS P 2.992 3-1/2” 9.2# N80 Tubing, TDS w/ SCC 5,831' 1.995 3.438 Crossover, 3-1/2” TDS B x 2-3/8” EU 8 Rnd P 5,833' 1.995 2-3/8” 4.6# N80 Pup EU 8 Rnd Tail Assembly 5,867' 2.813 3-1/2” EU 8Rnd Otis “RA” Sleeve (Open up) 5,870' 2.992 3-1/2” 9.2# N80 8 Rnd Pup 5,875' 2.441 Crossover, 3-1/2” EU 8 Rnd B x 2-7/8” Buttress P 5,876' 2.312 2-7/8” AVA SS Safety Valve Nipple 5,877' 2.813 2-7/8” Buttress, Otis “XA” Sleeve (Open up) 5,881' 2.441 2-7/8” 6.4#, N80, Buttress Pup 5,895' 2.205 2-7/8” Buttress, Otis “XN” Nipple No-Go (Otis XN 2.313 XN 2.205 G) 5,898' 2.87 Seal Assembly w/ 2-7/8 Buttress Box Up ( Seal Assy Locator Sub Landed 18” above SC-1L Packer) 5,910' Mule Shoe Perforation Detail Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments 6,085' 6,405' 5,374' 5,686' 320' Open Open - Gravel Packed 6,448' 7,125' 5,729' 6,403' 677' Sqz'd Sqz'd & Isolated by BP @ 6,440' 7,730' 8,634' 7,007' 7,910' 904' Open Isolated by BP @ 6,440' 8,690' 9,150' 7,966' 8,425' 460' Open Isolated by Cmt Retainer @ 8,677' Notes 10/26/2010 Circ diesel cap for LS and annulus. Attempted SS but appears to be plugged. 10/10/2010 Circ 9.8 ppg brine in LS, SS, and annulus. Pumped 20 bbl LCM pill. Well appears to be dead. 10/5/2010 RIH w/ 1-11/16” tubing punch, punch from 5831’ – 5837’ RKB, 23 shots (no pressure change) 9/30/2010 Attempt to open sleeve unsuccessful. RIH w/ 1-11/16” tubing punch, punch from 5871’ – 5877’ RKB, 23 shots (no pressure change) 8/21/2005 Set W plug at 5834’ KB, MIT LS tubing to 2000 psi – passed. Tubing & casing bundle tested to 1500 psi – good (packer appears to be leaking). 4 Updated by: CDM 6/21/24 SCHEMATIC Middle Ground Shoal Well: Ba-05 (MGS ST 17595 #5) Last Completed: 12-28-1990 PTD: 165-038 API: 50-733-10071-00 PBTD =6,440’ TD = 11125’ MAX HOLE ANGLE = 40O @ 4617’MD 26” 450’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 7565’ 7” 11127’ 7339’ 7” TOL Tbg Punch 5871’ - 5877’ 5906’ SC-1 Packer 2000’ TOC CBL 20” 595’ 13-3/8” 2012’ 6430’’ DSump Packer 6440’ EZ-SV w/ bridge plug kit – 11/90 10,200’ CMT Retainer 8677’ CMT Retainer 7648’ Baker “F” Packer w/ 3-1/2” tie in Tbg Punch 5831’ - 5837’ MGS Oil Top 6057 MGS Gas Base 5152 ‘ 308 bbl cement Squeeze 41 bbls into perfs Over-displace LS to put TOC ~5200’ in LS and TOC ~2000’ in SS/IA Perfs @ Intervals 8690 Top 9150 BTM Perfs @ Intervals 6448’ TOP 7125’ BTM Perfs @ Intervals 7730’ Top 8634 BTM 5-1/2” 15.5# J-55 0.012 Wire Wrapped Baker Weld Screen ID: 4.95 Gravel Pack 20—40 Mesh Ottawa Sand RA SV XN XA 9.8 PPG brine KB: MSL Mean Sea Level Mud Line Casing Details Size Type Wt/ Grade/ Conn ID Top Btm 26” Structural .5” Wall 25 Surf 450 20” Conductor 94, H40, STC 19.124 Surf 595 13-3/8” Surface 61, K55, STC 12.459 Surf 2,012 21.8º 9-5/8” Intermediate 40, N80, BTC 8.835 Surf 3,496 40, S95, STC8RND 8.835 3,496 5,499 43.5,S95,STC8RND 8.775 5,499 7,565 7”Liner 29, N80, 8 RND 6.184 7,339 10,429 29, S95, 8 Rnd 10429 10,429 11,127 Tubing Long String 3-1/2" Prod Tubing 9.2, N80, TDS w/ SCC 2.992 32.75 5,839 Short String 3-1/2" Prod Tubing 9.2, N80, TDS w/ SCC 2.992 32.75 5,831 Completion Jewelry Detail #DepthID OD Item Long String (Power Fluid) 32' CIW Hanger, (3-1/2” Buttress Down – 3-1/2” EUE 8 Rnd Up) 33' 3.438 Crossover, 3-1/2” Buttress P x 3-1/2” TDS P 2.992 3-1/2” 9.2# N-80 Tubing 5,839' 3.438 Crossover, 3-1/2 TDS B x 3-1/2” EU * Rnd P 5,841' 2.687 KOBE 3” Model “D” BHA (ID SV Removed) Number: ANC1540 Short String (Production) 32' CIW Hanger, Buttress @ 32’ (3-1/2” Buttress Down – 3-1/2” EUE 8 Rnd Up) 33' 3.438 Crossover, 3-1/2” Buttress P x 3-1/2” TDS P 2.992 3-1/2” 9.2# N80 Tubing, TDS w/ SCC 5,831' 1.995 3.438 Crossover, 3-1/2” TDS B x 2-3/8” EU 8 Rnd P 5,833' 1.995 2-3/8” 4.6# N80 Pup EU 8 Rnd Tail Assembly 5,867' 2.813 3-1/2” EU 8Rnd Otis “RA” Sleeve (Open up) 5,870' 2.992 3-1/2” 9.2# N80 8 Rnd Pup 5,875' 2.441 Crossover, 3-1/2” EU 8 Rnd B x 2-7/8” Buttress P 5,876' 2.312 2-7/8” AVA SS Safety Valve Nipple 5,877' 2.813 2-7/8” Buttress, Otis “XA” Sleeve (Open up) 5,881' 2.441 2-7/8” 6.4#, N80, Buttress Pup 5,895' 2.205 2-7/8” Buttress, Otis “XN” Nipple No-Go (Otis XN 2.313 XN 2.205 G) 5,898' 2.87 Seal Assembly w/ 2-7/8 Buttress Box Up ( Seal Assy Locator Sub Landed 18” above SC-1L Packer) 5,910' Mule Shoe Perforation Detail Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments 6,085' 6,405' 5,374' 5,686' 320' Open Open - Gravel Packed 6,448' 7,125' 5,729' 6,403' 677' Sqz'd Sqz'd & Isolated by BP @ 6,440' 7,730' 8,634' 7,007' 7,910' 904' Open Isolated by BP @ 6,440' 8,690' 9,150' 7,966' 8,425' 460' Open Isolated by Cmt Retainer @ 8,677' Notes 10/26/2010 Circ diesel cap for LS and annulus. Attempted SS but appears to be plugged. 10/10/2010 Circ 9.8 ppg brine in LS, SS, and annulus. Pumped 20 bbl LCM pill. Well appears to be dead. 10/5/2010 RIH w/ 1-11/16” tubing punch, punch from 5831’ – 5837’ RKB, 23 shots (no pressure change) 9/30/2010 Attempt to open sleeve unsuccessful. RIH w/ 1-11/16” tubing punch, punch from 5871’ – 5877’ RKB, 23 shots (no pressure change) 8/21/2005 Set W plug at 5834’ KB, MIT LS tubing to 2000 psi – passed. Tubing & casing bundle tested to 1500 psi – good (packer appears to be leaking). MGS ST 17595 Ba-5 CBL Log Feb 15, 1966 – Review dated June 26, 2024 ϯ x dŚĞ>ŝƐƵƐĞĚƚŽĮŶĚƚŚĞĐĂƐŝŶŐĐŽůůĂƌƐĂŶĚ͕ůŝŬĞƚŚĞ'ZŝƐƵƐĞĚĨŽƌĐŽƌƌĞůĂƟŽŶƉƵƌƉŽƐĞƐ͘ x dƌĂĐŬϮƚŽƚŚĞƌŝŐŚƚŽĨƚŚĞ>ͬĞƉƚŚƚƌĂĐŬƐŚŽǁƐƚŚĞ amplitude reading between 0 to 100 ŵs;ƚŚĞƵƉƉĞƌůŝŵŝƚŝƐƚŚĞĨƌĞĞƉŝƉĞĂŵƉůŝƚƵĚĞǁŝƚŚůŽǁĞƌǀĂůƵĞƐŝŶĚŝĐĂƟŶŐďĞƩĞƌĐĞŵĞŶƚ ƋƵĂůŝƚǇͿ͘ x As shown in the Main Pass log, - Interval ~ 1900’ – 1940’ – Good bond with amplitude ~ 10 mV - Interval ~ 1940’ – 1990’ – Fair bond with amplitude ~ 15 – 20 mV - Interval ~ 1990’ – 2000’ – Fair bond with amplitude ~ 10 – 15 mV - Interval ~ 2005 – ϯϴϬϬ͛– Good to excellent bond with amplitude ~ 5-ϭϬŵs;EŽƚĞ͗ϭϯϯͬϴ͟ ƐŚŽĞΛϮϬϭϮ͛DͿ - /ŶƚĞƌǀĂůΕϯϴϬϬ͛– 6210’ – ǆĐĞůůĞŶƚďŽŶĚǁŝƚŚĂŵƉůŝƚƵĚĞΕϱŵs - Interval ~ 6210’ – ϲϮϴϬ͛– Good to excellent bond with amplitude ~ 5-10 mV - /ŶƚĞƌǀĂůΕϲϮϴϬ͛– 6420’ – ǆĐĞůůĞŶƚďŽŶĚǁŝƚŚĂŵƉůŝƚƵĚĞΕϱŵs - Interval ~ 6420’ – 6455’ – Good to excellent bond with amplitude ~ 5-10 mV - Interval ~ 6455’ – 6490’ – ǆĐĞůůĞŶƚďŽŶĚǁŝƚŚĂŵƉůŝƚƵĚĞΕϱŵs - Interval ~ 6490’ – 6540’ – Fair bond with amplitude ~ 10-15 mV - Interval ~ 6540’ – 6610’ – ǆĐĞůůĞŶƚďŽŶĚǁŝƚŚĂŵƉůŝƚƵĚĞ ~ 5 mV - Interval ~ 6610’ – 6650’ – Good to excellent bond with amplitude ~ 10 mV - Interval ~ 6650’ – 7490’ – ǆĐĞůůĞŶƚďŽŶĚǁŝƚŚĂŵƉůŝƚƵĚĞΕϱŵs Note ϭ͗dhis assumes that the cement sheath thickness is >/= 0.75 inch and constant cement compressive strength and density is around the casing circumference and throughout the height of the cement column. EŽƚĞϮ͗ There is no VDL to ĂĚĚŵŽƌĞĐůĂƌŝƚǇƚŽŝŶƚĞƌƉƌĞƚĂƟŽŶŽĨƚŚŝƐůŽŐƌƵŶŝŶƚŚĞϭϵϲϬƐ͘ƐǁĞ know CBL ůŽŐƐƌƵŶŝŶƚŚŝƐƟŵĞĨƌĂŵĞŚĂǀĞŵĂŶǇĚĞĮĐŝĞŶĐŝĞƐŝŶŽďƚĂŝŶŝŶŐĂĐůĞĂƌƉŝĐƚƵƌĞŽĨƚhe quality of the cement bond log. EŽƚĞϯ͗ĂƐĞĚŽŶƚŚŝƐůŽŐĂůŽŶĞ͕ŝƚƐŚŽǁƐƚŚĂƚƚŚĞƐĂŶĚƐďĞůŽǁƚŚĞϭϯϯͬϴ͟ƐŚŽĞĂƚϮϬϭϮ͛are ĂĚĞƋƵĂƚĞůǇŝƐŽůĂƚĞĚ;ǁŝƚŚƚŚĞĐĂǀĞĂƚƚŚĂƚƚŚĞƌĞǁĞƌĞůŽƐƚĐŝƌĐƵůĂƟŽŶƉƌŽďůĞŵƐwhile ĐĞŵĞŶƟŶŐďŽƚŚƚŚĞϭϯϯͬϴ͟ĂŶĚϵϱͬϴ͟ĐĂƐŝŶŐƐƚƌŝŶŐƐͿ͘ x dŚĞĂůŝďƌĂƟŽŶWĂƐƐƐŚŽǁƐƚŚĞĨƌĞĞƉŝƉĞƐĞĐƟŽŶ;KйďŽŶĚͿƚŽďĞΕϰϱŵsŝŶƐƚƌĂŝŐŚƚŚŽůĞ ƐĞĐƟŽŶ͘ Summary ŶĂůǇƐŝƐŽĨƚŚĞ>ůŽŐƌƵŶŽŶ&ĞďƌƵĂƌǇ 15, 1966, ŝŶĚŝĐĂƚĞƐƚŚĂƚƚŚĞƌĞŝƐgood to ĞǆĐĞůůĞŶƚďŽŶĚŝŶŐŝŶƚŚĞ interval between ΕϮϬϬϱ͛– ϯϴϬϬ͛;ďĞůŽǁƚŚĞϭϯϯͬϴ͛ƐŚŽĞΛϮϬϭϮ͛DͿĂŶĚĂůƐŽŐŽŽĚƚŽĞǆĐĞůůĞŶƚ ďŽŶĚŝŶŐďĞƚǁĞĞŶΕϯϴϬϬ͛- ΕϳϰϵϬ͛;ďŽƩŽŵůŽŐŐĞĚŝŶƚĞƌǀĂůͿ͘ dĂůŝď^ǇĞĚ͕W͘͘ June 26, 2024 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Casey Morse To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] MSG St 17595-05 (PTD 165-038) question Date:Wednesday, June 26, 2024 12:50:38 PM Bryan, I’m not opposed to bringing cement up higher in the IA / SS to get extra coverage across the surface shoe. I initially just aligned that cement top with the 9-5/8” TOC. As for the pumping sequence, I went back and forth on this. I see value in going with the sequence you described. The way I wrote this up was to target a set amount of return volume from the IA, so it’s likely that we’ll have to pump >275 bbls in to get the 275 desired bbls out of the IA, and that loss will effectively be the downsqueeze. Any remaining volumes beyond the desired displacements would get squeezed at the end of the cement job. To your point, we should see the formation lock up when cement hits that gravel pack, so hopefully that’s the outer limit to the amount of losses we might see. I’m comfortable with either approach. What would you need to see on this sundry to feel comfortable with us moving forward on this well? Thanks, Casey Morse Well Integrity Engineer Hilcorp Alaska, LLC (907) 777-8322 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 26, 2024 9:54 AM To: Casey Morse <Casey.Morse@hilcorp.com> Subject: [EXTERNAL] MSG St 17595-05 (PTD 165-038) question Casey, 1. Is there a reason you don’t want to bring cement a little higher into the surface casing shoe, say 1900’, to ensure you have good cement across the shoe? 2. I suggest adjusting the pumping sequence for the cement job. The issue is that if you don’t cement off the perfs first, you will likely be plagued with lost circulation as the hydrostatic of the cement comes up the backside and the higher pressure will push fluid out the perfs. You’ll lose track of your cement height in the IA and SS. If you start by bullheading cement into the perfs, it will likely bridge off on the screens and then be more likely to hold a column of cement when you circulate it out the annulus and short string. You’ll get a pressure bump when cement hits the screens, then you be more likely to get 1:1 returns and be able to keep track of your cement tops. 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. MGS ST 17595 Ba-5 CBL Log Feb 15, 1966 – Review dated June 26, 2024 1 Review of Middle Ground Shoal MGS Ba-05 CBL Log dated 2/15/1966 Well History: Drilled and completed in 1965-ϭϵϲϲĂŶĚƉƵƚŽŶƉƌŽĚƵĐƟŽŶŝŶϭϵϲϲĂƐĂŶŽŝůƉƌŽĚƵĐĞƌ. Several ǁŽƌŬŽǀĞƌƐ ƉĞƌĨŽƌŵĞĚŝŶĐůƵĚŝŶŐĨƌĂĐƐ͕ƉĞƌĨƐĂĚĚƐ͕ƐƋƵĞĞǌĞƐ ĂŶĚƌĞĐŽŵƉůĞƚĞƐ͘ tĞůůƉƌŽĚƵĐĞĚƵŶƟůƚŚĞWͬ&ǁĂƐ^/ŝŶϮϬϬϯ͘/ŶKĐƚŽďĞƌϮϬϭϬ͕ƉƵŶĐŚĞĚƚƵďŝŶŐĨƌŽŵϱϴϯϭ͛– ϱϴϯϳ͛D, ĐŝƌĐƵůĂƚĞĚǁĞůůǁŝƚŚϵ͘ϴƉƉŐďƌŝŶĞĂŶĚĂϮϬďďů>DƉŝůůǁĂƐƉƵŵƉĞĚƚŽƉůƵŐŽīƚŚĞƉĞƌĨŽƌĂƟŽŶƐ͘ dŚĞ>^ĂŶĚ/ǁĞƌĞĨƌĞĞǌĞ-ƉƌŽƚĞĐƚĞĚǁŝƚŚĚŝĞƐĞů͕ďƵƚƚŚĞ^^ƉůƵŐŐĞĚŽīĚƵƌŝŶŐƚŚĞĨƌĞĞǌĞ-protect ĂƩĞŵƉƚƐ͘ Current status – ^/WƌŽĚƵĐĞƌ. >ŽŶŐ^ƚƌŝŶŐ;>^ͿĂŶĚ^ŚŽƌƚ^ƚƌŝŶŐ;^^ͿdƵďŝŶŐĂŶĚ/ůŽĂĚĞĚǁŝƚŚϴ͘ϲ&/t͘ /WŝƐƐĞƚΛϲϰϵϬ͛DŝƐŽůĂƟŶŐƚŚĞůŽǁĞƌƉĞƌĨŽƌĂƟŽŶƐ͘KƉĞŶƉĞƌĨŽƌĂƟŽŶƐĂƌĞϲϬϴϱ͛– ϲϰϬϱ͛;ϯϮϬ͛Ϳ͘See pre-WΘǁŽƌŬĚŽŶĞŝŶ^ƵŶĚƌǇZĞƉŽƌƚ͘ KďũĞĐƟǀĞ͗ WΘƚŚĞDŝĚĚůĞ'ƌŽƵŶĚ^ŚŽĂůKŝůWŽŽůƉĞƌĨŽƌĂƟŽŶƐĂŶĚD/dƚŚĞĐĂƐŝŶŐͬƚƵďŝŶŐƚŽƉůĂĐĞƚŚŝƐ ǁĞůůŝŶƐƵƐƉĞŶĚĞĚƐƚĂƚƵƐ͘dŚŝƐǁĞůůǁŝůůďĞĞǀĂůƵĂƚĞĚĨŽƌĨƵƚƵƌĞƐŝĚĞƚƌĂĐŬƉŽƚĞŶƟĂůŽƌƵƉŚŽůĞŐĂƐ ƌĞĐŽŵƉůĞƟŽŶ. ^ĞĞƉƌŽƉŽƐĞĚWΘƐƚĞƉƐŝŶ^ƵŶĚƌǇƉƉůŝĐĂƟŽŶ ϯϮϰ-ϯϲϳ͘ Well Details: Well Name: Ba-05(MGS ST 17595-05) W/EŽ͗͘ 50-ϳϯϯ-10071-00-00 Wd͗ 165-Ϭϯϴ ^ƵŶĚƌǇEŽ͗͘ ϯϮϰ-ϯϲϳ Field: DŝĚĚůĞ'ƌŽƵŶĚ^ŚŽĂů Water DeƉƚŚͬDƵĚůŝŶĞ͗ ϭϬϮ͛ͬϮϬϮ͛ Max ƐƟŵĂƚĞĚWƌĞƐƐƵƌĞƐ: 2752 ƉƐŝ;Λϱϱϲϰ͛ds) and 2196 ƉƐŝ;^ƵƌĨĂĐĞͿ ƋƵŝǀĂůĞŶƚMud tĞŝŐŚƚ͗ 9.5 ppg TD: ϭϭϭϮϴ͛ͬϭ0ϯϵϲ͛Dͬds Wd͗ 6440͛Dͬ DĂǆ͘ŶŐůĞ͗ 400 Λϰϲϭϳ͛D ĂƐŝŶŐͬdƵďŝŶŐͬWĂĐŬĞƌ ĞƚĂŝůƐ: 26” Structural ΛϰϱϬ͛ 20” 94# H40 STC Conductor Λϱϵϱ͛D ϭϯϯͬϴ͟ϲϭη<ϱϱ^d^ƵƌĨĂĐĞĂƐŝŶŐΛϮϬϭϮ͛D ϵϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞĂƐŝŶŐϰϬηEϴϬ BTC Surface – ϯϰϵϲ͛DͬϰϬη^ϵϱ^dϴZϯϰϵϲ͛– ϱϰϵϵ͛Dͬϰϯ͘ϱη ^ϵϱ^dϴZϱϰϵϵ͛–ϳϱϲϱ͛D 7” >ŝŶĞƌϮϵηEϴϬϴZϳϯϵϵ͛– ϭϬϰϮϵ͛DĂŶĚϮϵη^ϵϱϴZϭϬϰϮϵ͛– ϭϭϭϮϳ͛D ϯЪ͟ϵ͘ϮηL-ϴϬ>ŽŶŐ^ƚƌŝŶŐĂŶĚ^ŚŽƌƚ^ƚƌŝŶŐ Λϱϴϯϵ͛ͬϱϴϯϭ͛D ǁͬϮ ϳͬϴ͟yKΛϱϴϳϱ͛D Ϯϳͬϴ͟ǆϵϱͬϴ͟^-ϭƉĂĐŬĞƌΛϱϵϬϲ͛D DƵůĞ^ŚŽĞΛϱϵϭϬ͛D ĞŵĞŶƟŶŐĞƚĂŝůƐ͗ ϮϬ͟ĂƐŝŶŐΛϱϵϱ͛D͘WƵŵƉĞĚϳϵϴƐǆůĂƐƐǁͬϮйĂůϮ͘>ŽƐƚƌĞƚƵƌŶƐΛϳϵϴƐǆ͘ZĂŶϮϯͬϴ͟ƚƵďŝŶg MGS ST 17595 Ba-5 CBL Log Feb 15, 1966 – Review dated June 26, 2024 2 ĚŽǁŶϮϬ͟ǆϮϰ͟ĂŶŶƵůƵƐƚŽϮϰϬ͛ĂŶĚĐĞŵĞŶƚĞĚǁŝƚŚϯϯϱƐǆůĂƐƐ'ǁͬϮйĂůϮ͘ĞŵĞŶƚƚŽƐƵƌĨĂĐĞ ϭϮͬϮϬͬϲϱ͘ ϭϯϯͬϴ͟ĐĂƐŝŶŐΛϮϬϭϮ͛D͘WƵŵƉĞĚϲϰϬƐǆůĂƐƐ'EĞĂƚĨŽůůŽǁĞĚďǇϭϭϲϬƐǆůĂƐƐ'ǁͬϮйĂůϮ͘>ŽƐƚ ƌĞƚƵƌŶƐĚƵƌŝŶŐůĂƐƚϭϬϬƐǆŽĨĚŝƐƉůĂĐĞŵĞŶƚ– ŇƵŝĚůĞǀĞůĚƌŽƉƉĞĚŝŶĂŶŶƵůƵƐ͘ZĂŶϭЬ͟ƉŝƉĞĚŽǁŶϭϯϯͬϴ͟ǆ ϮϬ͟ĂŶŶƵůƵƐƚŽϳϯϬ͕͛ĐĞŵĞŶƚĞĚǁŝƚŚϭϱϰƐǆůĂƐƐ'EĞĂƚĨŽůůŽǁĞĚďǇϯϯϬƐǆůĂƐƐ'ǁͬϮйĂůϮ– ůŽƐƚ ƌĞƚƵƌŶƐĂƚϯϴϰƐǆƉƵŵƉĞĚ͘ZĂŶϭЬ͟ƉŝƉĞĚŽǁŶϭϯϯͬϴ͟ǆϮ-͞ĂŶŶƵůƵƐƚŽϰϴϬ͕͛ĐĞŵĞŶƚĞĚǁŝƚŚϰϱϬƐǆůĂƐƐ 'EĞĂƚ͘'ŽŽĚĐĞŵĞŶƚƌĞƚƵƌŶƐ͘/WĂƚϭϴϬϬŚŽƵƌƐŽŶϭͬϴͬϲϲ͘ ϵϱͬϴ͟ĂƐŝŶŐƐĞƚΛϳϱϲϱ͛D͘WƵŵƉĞĚϭϬϬϬƐǆůĂƐƐ'ǁͬϭй&ZϮĨŽůůŽǁĞĚďǇϵϱϬƐǆůĂƐƐ'EĞĂƚ͘ZĂŶ >Ϯͬϭϱͬϲϲ ŝŶĚŝĐĂƟŶŐdKΛϮϬϬϬ͛D͘ WĞƌĨŽƌĂƟŽŶĞƚĂŝůƐ͗ ϲϬϴϱ͛– ϲϰϬϱ͛Dͬϱϯϳϰ͛– ϱϲϴϲ͛ds;ϯϮϬ͛Ϳ– KƉĞŶ ϲϰϰϴ͛– ϳϭϮϱ͛DͬϱϳϮϵ͛– ϲϰϬϯ͛ds;ϲϳϳ͛Ϳ– ^ƋƵĞĞǌĞĚĂŶĚŝƐŽůĂƚĞĚďǇWΛϲϰϰϬ͛ ϳϳϯϬ͛– ϴϲϯϰ͛DͬϳϬϬϳ͛– ϳϵϭϬ͛ds;ϵϬϰ͛) - /ƐŽůĂƚĞĚďǇWΛϲϰϰϬ͛ ϴϲϵϬ͛– ϵϭϱϬ͛Dͬϳϵϲϲ͛– ϴϰϮϱ͛ds;ϰϲϬ͛Ϳ– /ƐŽůĂƚĞĚďǇĞŵĞŶƚZĞƚĂŝŶĞƌΛϴϲϳϳ͛ &ŽƌŵĂƟŽŶdŽƉƐ >ŽƐƚŝƌĐƵůĂƟŽŶWƌŽďůĞŵƐ͗ ,ĂĚ>ŽƐƚŝƌĐƵůĂƟŽŶƉƌŽďůĞŵƐǁŚŝůĞĐĞŵĞŶƟŶŐďŽƚŚƚŚĞϮϬ͟ĐĂƐŝŶŐĂŶĚϭϯϯͬϴ͟ĐĂƐŝŶŐ ;ƐĞĞĐĞŵĞŶƟŶŐ ĚĞƚĂŝůƐŝŶĞĂƌůŝĞƌƐĞĐƟŽŶͿ Review of Schlumberger’s CBL log run on 2/15/1966 x Logged interval from ϯϬϬϬ͛– ϳϰϴϴ͛D;EŽƚĞƚŚĞůŽŐƐŚŽǁƐƚŽƉŽĨƚŚĞůŽŐŐĞĚŝŶƚĞƌǀĂůĂƚΕ1900͛ and not at ΕϯϬϬϬ͛DͿ x Max recorded temp: 1250 F x ĂƐŝŶŐ&ůƵŝĚdǇƉĞ͗Ligno Sulfate Seawater – 10.5 ppg x ƐƚdŽƉŽĨĞŵĞŶƚΛϯϱϬϬ͛D (from CBL ůŽŐŶŽƚĞƐͿ x KďũĞĐƟǀĞŽĨ>ǀĂůƵĂƟŽŶ͗'ĂƐ^ĂŶĚƐďĞůŽǁϭϯϯͬϴ͟ƐƵƌĨĂĐĞĐĂƐŝŶŐΛ2012’ MD are isolated. dŚĞƉƌĞƐĞŶƚĂƟŽŶŽĨ>ůŽŐƐǀĂƌŝĞƐĨƌŽŵĐŽŵƉĂŶǇƚŽĐŽŵƉĂŶǇ͘dŚŝƐŝƐĂŶĞĂƌůǇŐĞŶĞƌĂƟŽŶ>ůŽŐƌƵŶŝŶ ƚŚĞϭϵϲϬƐ͘ x dŚĞĮƌƐƚƚƌĂĐŬ;dƌĂĐŬϭͿĨƌŽŵƚŚĞůĞŌ͕ĐĂůůĞĚƚŚĞĐŽƌƌĞůĂƟŽŶƚƌĂĐŬ͕ƐŚŽǁƐƚŚĞ'ZƌĞĐŽƌĚŝŶŐĨƌŽŵϬ – 100 W/͕ĂŶĚƚŚĞƚƌĂǀĞůƟŵĞ;ĂůƐŽƌĞĨĞƌƌĞĚƚŽĂƐƚŚĞƚƌĂŶƐŝƚƟŵĞͿĨƌŽŵ200 - 400 ђƐĞĐ͘dŚĞddŝƐ ƚŚĞĞůĂƉƐĞĚƟŵĞĨƌŽŵƚŚĞĮƌŝŶŐŽĨƚŚĞƚƌĂŶƐŵŝƩĞƌƵŶƟůƚŚĞĮƌƐƚƐŽƵŶĚŝƐƐĞŶƐĞĚĂƚƚŚĞƌĞĐĞŝǀĞƌ͘ dŚĞ'ZƐŝŐŶĂůŝƐƵƐĞĚĨŽƌĐŽƌƌĞůĂƟŽŶďĞƚǁĞĞŶƚŚĞŽƉĞŶŚŽůĞĂŶĚĐĂƐĞĚŚŽůĞůŽŐƐ͘As shown in the Main Pass log, the TT is fairly consistent and straight at ϯϮϬ ђsec in the interval ~ 2000’ - ~ 7490’ ͕ŝŶĚŝĐĂƟŶŐƚŚĂƚƚŚĞƚŽŽůŝƐĐĞŶƚƌĂůŝǌĞĚŝŶƚŚis interval. David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/24/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240624 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MGS ST 17595 #5 50733100710000 165038 02/16/1966 SCHLUMBERGER CBL MGS ST 17595 #31 ST2 50733204690000 195199 04/28/1996 SCHLUMBERGER CET Scanned Log Images (PDF and TIF FORMAT)gg( ) Please include current contact information if different from above. T39003 T39004 MGS ST 17595 #5 50733100710000 165038 02/16/1966 SCHLUMBERGER CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.24 15:34:52 -08'00' 2011 July's Baker /Dillon Productiell 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 Kos -0 Hi Tom & Jim, 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 ; _, i. AUG 1 F 2011 «Master Well List TIO Report 2011 08 01.xis» 8/9/2011 Plot Pressure & Rate vs Time - Well Ba -05 1400 - •9 5/8" 13 3/8" 20" 1200 Tubing Tubing 2 1000 . 800 F2 3 N N a` 600 400 200 `.41 r J' Y p . CD rn m rn rn CD rn 0, CD CD CD CD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O O O o o O o o N O O ; 8 2 � r t0 r O O N Pi 7 '4 M (Pi N O N O O M O O O M (7 (� N I N N N N N N N N N N N N N N N N N N N N N N N th V s N 8 r W 8 O N N M 3 N 8 r 8 8 O N N 8 3 N O r O O O O O 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 07/19/11 150 200 06/22/11 175 200 Data Sheet 06/01/11 150 200 05/28/11 150 200 05/25/11 150 195 Ba -05 05/24/11 150 200 05/23/11 150 200 05/22/11 150 200 BOT HOLE HYD PUMP 05/21/11 150 200 05/04/11 175 200 04/01/11 150 200 Permit # 1650380 02/03/11 170 200 01/20/11 25 150 200 75 200 12/17/10 25 150 200 80 100 API # 50- 733 - 10071 -00 11/09/10 20 175 200 10 100 10/31/10 19 160 200 0 90 10/30/10 18 75 205 0 80 01/31/2009 to 08/01/2011 10/29/10 16 180 210 10 75 10/28/10 26 90 200 0 52 10/27/10 15 90 210 45 10/26/10 18 185 210 0 40 10/25/10 5 200 200 0 20 10/24/10 10 180 200 0 0 10/23/10 0 175 200 0 15 10/22/10 0 175 200 0 15 10/21/10 0 180 200 0 15 10/20/10 0 175 200 0 15 10/19/10 0 175 200 0 15 10/18/10 0 175 200 0 5 10/17/10 0 150 200 0 85 10/16/10 0 150 200 0 70 10/10/10 0 125 105 10/09/10 125 210 10/08/10 145 205 10/07/10 0 140 200 0 0 10/06/10 1200 150 210 1080 840 8/9/2011 2:36 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 08 01.xIs Ba -05 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 Hi Tom & Jim, ? r "Ig 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» ? (11r 5/16/2011 • Plot Pressure • & Rate vs Time - Well Ba -05 1400 9 5/8" 13 3/8" ••••'-" 20" 1200 — Tubing Tubing 2 1000 - 800 I' m U, N a` 600 400 200 74110 0 I co co co rn co co rn rn rn rn rn rn rn rn rn 0 0 0 jj O 0 0 0 0 O 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 O 03 m c0 r 03 C6 W 1- r co 0 N V • M N V N 0 i:i O O O O O � � � O O O O Date 13 3/8" 20" : u• •. u.' TIO Report 04/01/11 150 200 50 02/03/11 170 200 60 Data Sheet 01/20/11 150 200 75 12/17/10 150 200, 80 11/09/10 175 200 10 Ba -05 10/31/10 160 200 1 10/30/10 75 205 10/29/10 16 180 210 10 75 BOT HOLE HYD PUMP 10/28/10 26 90 200 0 52 10/27/10 15 90 210 45 10/26/10 18 185 210 0 40 Permit # 1650380 10/25/10 5 200 200 0 20 10/24/10 10 180 200 0 0 10/23/10 0 175 200 0 15 API # 50- 733 - 10071 -00 10/22/10 0 175 200 0 15 10/21/10 0 180 200 0 15 10/20/10 0 175 200 0 15 10/30/2008 to 04/30/2011 10/19/10 0 175 200 0 15 10/18/10 0 175 200 0 5 10/17/10 0 150 200 0 85 10/16/10 0 150 200 0 70 10/10/10 0 125 105 10/09/10 125 210 10/08/10 145 205 10/07/10 0 140 200 0 0 10/06/10 1200 150 210 1080 840 10/05/10 1200 145 210 1080 865 10/04/10 1200 145 210 1080 865 10/03/10 1200 140 210 1080 860 10/02/10 1200 140 210 1075 860 10/01/10 1205 150 210 1080 860 09/30/10 1200 140 210 1110 920 09/29/10 1205 150 210 1110 930 09/28/10 1200 145 205 1110 920 09/27/10 1200 150 200 1110 930 09/26/10 1200 150 200 1110 920 5/16/2011 11:09 AM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 04 30 (3).xls Ba -05 \c� — 04 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 0 2009 Cathy Foerster Commissioner Alpsks Oil & Gas com Commigfiinn Alaska Oil & Gas Conservation Commission ,�r ➢�,o 333 W. 7t" Avenue OCT 0 2014 Anchorage, Alaska 99501 SEWED 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, �) "'e,1�ctkl�_ Dale Haines Alaska Area Operations Manager 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 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 1842 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 platforin 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 CurrentlV used as volume bottle for gas abandon at end of platfonn life D-40RD 1820830 Se -Ol 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 -11 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 Di4 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 platform 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 # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg 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 gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 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 4113-9 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 -91 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 no known damage no flow Possible shallow as or as storage 2011-2014 Monopod A-10 1670760 jec-O r-8 Colla sed casin Producin Coal Phase I Abandon abandon at end of latform life Mono od A-23 1720200n-8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life AY,ASKA OIL AND GAS CONSERVATION COMUSSION June 22, 2009 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 SARAH PALIN, GOVERNOR l 333 W. 7th AVENUE, SUITE 100 f ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 S'AW OCT 0 3 2014 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.aubertnalaska.gov. Sincerely, 0'4� 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 41B-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 SC~~EO ~O" I) 8 ZOOS Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 \ bSJ 03<6 ß PI J<5' Re: Baker Platform Pilot Pre-Abandonment Work Summary Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of U nocal' s pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP 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 BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. r'\. ~Jn~ 1\,r r\JC . l-' t ~ l- .~ '¿ ~.... ~.,¡ , Union Oil Company of California I 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 SOland in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. S incerel y, ~ ~-aê- ,2 ~ c-~ /~~ ¿ Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California I 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 .....,.. Sa - 5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7 -Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7-Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned -' Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6-Jul-05 7080 6066 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 Sa -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 11 433 10636 3795 0.357 6.9 Ba-32 Producer No survey ) ~7~~E :J ~~~~~!Æ AI,ASHAOILAND GAS CONSERVATION COMMISSION Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: ) FRANK H. MURKOWSK/, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ro' \ b~t7~ This letter confinns your conversation with Commission 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. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SC"" N' N' i':' ~=- \!.I 0 \. ~2 /i 2 J "" .A ", ~.L~ Ph } ,,r ':t 1 Enel. '\ STATE OF ALASKA ') ALASt,¡.{ OIL AND GAS CONSERVATION COMMlbs'ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate U Waiver U s~~. U Stimulate D Time Extension 0 Other 0 Re-enter Suspended Well Monitor Frequency 5. Permit to ~umber: Exploratory 0 1650380/ Service 0 6. A~mber: ~33-1 0071-00 9. Well Name and NU¿ber: Ba-05 10. Field/Pools(s): MIDDLE GROUND S OAL PRESENT WELL CONDITION SUMM Y ,'" Abandon U Alter casing 0 Change approved program D 2. Operator Name: Union Oil of California aka Unocal Suspend U Repair well D Pull Tubing 0 1. Type of Request: 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 11,128' Casing Structural Total Depth TVD (ft): 10,396' Length Development Stratigraphic 0 0 Effective Depth MD (ft): 6,440' Junk (measured): Size Conductor Surface 20" Intermediate Production 133/8" 95/8" Liner Perforation Depth MD (ft): 7" Perforation Depth TVD (ft): 6085 to 6405; Packers and SSSV Type: 5374 to 5686; 12. Attachments: Description Summary of Prop al ~ Detailed Operations Program D BOP Sk ch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true Printed Namf), ' J<'9 Cole Signatur~vf/~ / Plugs (measured): MD Burst Collapse TVD 594' 1,952' 7,565' 6,842' f 11,127' 10,396' Tu ng Size: Tubing Grade: SS 3 1/2" SS 9.2# N-80 /23/8" 4.6# N-80 LS 3 1/2" LS 9.2# N-80 Packers and SSSV MD (ft): 2,734 psi ITubing MD (ft): I SS 5,833' LS 5,910' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 0 Service D D D Abandoned WDSPL D 0 Plugged WINJ nd correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Phone 27-Sep-2004 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Mechanicallntegr" BOP Test D Other: RBDMS BFL NOV 2 2 2D04 Subsequent Form Required: Approved by: ~ Form 10-404.Revised 12/2003 Sundry Number: 30Lf- <{( (~ APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION :CEIVED :T 1 2 2004 ORIGINAL Alaska Oil & GaB Cons. Commission Anchorage COMMISSIONER BY ORDER OF THE COMMISSION Date: Submit in Duplicate • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Suspend Lj Operation Shutdown Lj Perforate Lj WaiverLi Other Performed: Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Time Extension[] Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re-enter Suspended Well ❑ Shut in & secure 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development Q Exploratory ❑ Stratigraphic❑ Service❑ 1650380 3. Address: 909 West 9th Ave. 6. API Number: Anchorage AK 99501 50-733-10071-00 7. KB Elevation (ft): 9. Well Name and Number: 79 Ba -05 "' >t-' 4` 8. Property Designation: 10. Field/Pool(s): BAKER MIDDLE GROUND SHOAL ,,+ x 11. Present Well Condition Summary: Total Depth measured 11128 feet Plugs (measure true vertical 10396 feet Junk (measured) n Effective Depth measured 6440 feet true vertical 5720 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 20" 595' 594' Intermediate 13 3/8" 2,012' 1,952' Production 95/8" 7,565' 6,842' Liner 7" 11,127' 10,396' Perforation depth: Measured depth: 6085 to 6102; 6108 to 6145; 6192 to 6350; 6395 to 6405; True Vertical depth: 5374 to 5390; 5396 to 5431; 5496 to 5632; 5676 to 5686; Tubing: (size, grade, and measured depth) SS 3 1/2" 9.2# N-80 / 2 3/8" 4.6# N-80 @ 5,833' LS 3 1/2" 9.2# N-80 @ 5,910' Packers and SSSV (type and measured depth) Baker "SC -1" @ 5,906' and 6,430' 12. Stimulation or cement squeeze summary: Intervals treated (measured): scota� J f'► Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 28 39 Subsequent to operation: 0 0 0 680 on 10/05/03 150 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory F] Development Q Service ❑ 16. Well Status after proposed work: Daily Report of Well Operations Oil Gas❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. I,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 Printed Name P. M. Ayer Title Petroleum Engineer Signature Phone 263-7620 Date 07 Jun 2004 Cz Form 10-404 Revised 12/2003rMUMS MAY 29 2012 13-3/8" 54.5# ® 2012' BAKER SC -1 PKR ® 5906' 5-1/2" 15.5# J-5 0.012" WIRE WRAPP BAKER WELD SCREE GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR ® 6430' 9--5/8" 40 do 43.5 ® 7565' 7" 29# 4 11127 • 0 TUBING DETAIL LONG STRING (POWER FLUID) 1) CIW HANGER, BUTTRESS • 32' 2) 3-1/2 BUR PIN x 3-1/2 MS PIN X—DYER O 32.75' 3) 3-1/2. 9.2f N-80 TBG, MS W/ SP CL CPLGS KOBE r MODEL "D" BHA 0 3641' PlN X—OYER • 5839 SHORT STRING (PRODUCTION) A) CIW HANGER, BUTTRESS O 32' B) 3-1/2 BUR PIN x 3-1/2 MS PIN X—OVER O 32.75' C) 3-1/2" 9.2# N-80 TBO. MS W/ SP CL CPLGS D) 3-1/2 MS BOX x 2-3/8 EU ORD PIN X --OVER • 5831' E) 2-3/8- 4.6/ N-80 PUP EU ORD • 5833' TAIL ASSEMBLY 6) 3-1/2" EU SRO OTIS "RA" SLEEVE O S86r 7) 3-1/2" 9.2# N-60 EU 8RD PUP O 3870- 8) 3-1/2 EU ORD BOX x 2-7/8 BUR PIN X—OVER • 587a 9) 2-7/8" AVA SAFETY VALVE NIPPLE • $876' 10) 2-7/8- BUR OTIS "XA- SLEEVE O 5877' 11) 2-7/8- 6.4# N-80 BUR PUP O 5881' 12) 2-7/8- BUTT OTIS -XN" NIPPLE O 5895' 13) SEAL ASSY W/ 2-7/8- BUTT BOX UP ( 10:0' ) • 5898- 14) MULE SHOE AT 5910- "A" ZONE INTERVAL 1 �; 6085'— 6102' 6108'— 6145' 61921— 6350' 6395'— 6405' ,MT RET ® 6440' PERFS F/ 6448'— 7125' 0 INTERVALS A,5,(,b OP OF LINER ® 7339' BAKER MODEL F BP ERFS F/ 7730'— 8634' ® INTERVALS :MT RET ® 8677' ERFS F/ 8690'— 9150' ® INTERVALS �-5 :MT RET ® 10200' ADL 17595 WELL NO. 5 COMPLETION SCHEMATIC DRAWN: DAC - SCALE: NONE UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DATE: 1-15-91 BAKER PLATFORM API # 50-733-20071-00 M G S. ST. 17595 # 5 WELL HISTORY LAST WORK: 4/?/75 0 Well Baker #5 DATE COMPLETED EVENT 1967 6-67 Stimulate EFG x diesel oil -surfactant -N2 Sq. Spear head x 38900 SCF N2. Follow x 155 bbls diesel x 10 gal W26/1000 gal demulsifier x 200 SCFN2 per bbl. 10 bbl plug, 150 bbls diesel - surfactant -N2 mix, 10 bbl plug x 150 bbls dieselOsurf-N2. Displace x diesel x N2. Before: 480 BOPD, TPF 60 psi After: 538 BOPD, TPF 25 psi BCD Zone - Spear head x 40100 SCFN2, follow x three stages of 80 bbl diesel -surf -N2 (in concentrations as above) each. Displace x sand mix x 19.142 SCFN2. Before: 528 BOPD, TPF 55 After: 325 BOPD x 0.2% BS&W, GOR 594 x TPF psi 1975 4-75 Stimulate EFG w/3100 gal 15% HC1/ Very tight, could not matrix acidize EFG. Matrix acidize BCD. Spear head 15% HC1 (3340 gal) followed with 31400 gal 12-6 mud acid containing 0.1 % Dowell J-237 diverter. Before: 186 BOPD x 38 BWPD After: 503 BOPD x 77 BWPD 1998 7/1/03 Shut in well B-5 and reverse circulate pump to surface. Kill well and pull pump as usual. Circulate Well B-5 one tubing volume of 102 bbls. Pull standing valve in B-5. All casing and tubing valves closed; pipe connections removed and blind flanges installed. Gauges installed to monitor pressures. C� Pertinent Data: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 5 Spud Date: SI 7/13/66 due to platform explosion x reactivated 10/26/66. Potential 12/28/66. Surface Location: Slot 6, Leg 1; 1934' FNL, 550' FWL, Sec. 31, T9N, R12W, S.M. Subsurface Location: 725' FSL, 827' FWL, Sec. 30, T9N, R21W, S.M. Elevation: 78.75' RKB MSL TD: 11,128' Plug Back Depth: 10,200' Casing: 20", 79.6# @ 598'x/1 133 sx 13-3/8", 54.5# @ 2012'w/2764 sx 9-5/8" 40 & 43.5# at 7565'w/1 950 sx 7", 29# @ 7339-11,127'w/1400 sx (liner) Initial Potential: BCD: 642 BOPD 0 BWPD x GOR 452 @ 110 FTP EFG: 248 BOPD 0 BWPD x GOR 900 @ 135 FTP Initial Stimulation: Pfs. 10,430-10,563'. Frac w/4000 gals gelled CaC12 wtr w/10-20 SD propant - SWB to 7500', Rec 200 of 340 BLW, NS. Pfs 8710-9102'. Breakdown x 12,000 gal CaC12 wtr. Frac w/4000 gals gelled CaC12 wtr w/2000# 10-20 SD & 8000 gals gelled CaC12 wtr w/2400# 12-20 nutshells; dropped 6 ball sealers and repeated Frac. ISIP 5500 psi. FLW 20 hr. x rec 40 BO x 28 BW x TPF 35 psi. Pfs 8887-9102'. Swb in x FLW 19 BO x 1/4 BW in 2 hrs. Frac w/16,000 gal w/ 1/2 ppg 10-20 SD, 31,700 gal @ 1/3 ppg 12-20 W4. ISIP 3600 psi. Swb down to 7500 x no influx. • MIDDLE GROUND SHOAL ADL 17595 WELL NO. 5 Initial Stimulation: (continued) Pfs 8710-8802'. Frac w/4284 gals wtr w/ 1/4# 10-20 SD per gal. Then 4326 gal wtr w/ 1/21b/gal SD out. ISIP 5800 psi. Swb to 6300' x FL rose 350' in 30 min. Rec 25% oil, 74% wtr, 1% mud. Pfs 8690-8800'. Swb to 5500 x SI for 3-1/2 hrs. FL rose to 4500 x rec 75% oil x 25% load wtr x mud. Frac w/4000 gal wtr & 1000# SD (10-20) x 7600 Gal wtr @ 1/2 Ib/gal. Swb to 7000' x rec 6 BWPH x slight tr. oil. Trt w/546 gal MCA x follow x 19,874 gal crude x 110 W26 demulsifier. Swb to 6400'x 1000' per hr. influx. Pfs. 8478-8634'. Swb down to 7500' x 50 to 100' influx per hr at 50% oil. Kill x CaC12 wtr. ACD w/1000 gals 15% x displace x 500 bbl crude containing 100 gal W26 demulsifier. FWL 59.4 BLO in 7 hrs. at TPF 60 psi. 8634'& 8690' communicated. Pfs. 8478-10,5631. ACD w/1500 gals HC1 x displace x diesel. Swb to 3500 x 80 BF in 6 hrs, diesel, wt x tract oil. Pfs 8040-8430'. ACD w/1500 gals HC1 and displace x diesel. ISIP 3800 psi. Swb 40 BO x 20% BS&W in 4-1/2 hrs. Trtd w/9576 gals diesel x 1% W26 demulsifier. FLW 13.2 BFPH at 6% BS&W. Pfs. 7732 - 57-1/2'. Frac w/11,970 gals wtr w/5300# 10-20 SD & 10,594 gals wtr w/750# nut shells (12-20) Screened out. Pfs 6940-7009'. Frac w/16,000 gals wtr w/8000# 10-20 SD and 32,000 gals wtr w/9600# 12-20 nut shells. SI due to platform explosion 7/13/66. • Perforation Record: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 5 0 Date Zone Interval 5-66 EFG 7675-77'x 8985-87' circ. cmt behind liner. 5-66 EFG 8900-02'& 8160-62'& circ. cmt behind liner. 5-66 EFG 10,562-63', 10,527-28', 10,430-31'x thru tbg gun twice. Later reperf x csg gun in CaC12 wtr. 5-66 EFG 9101-02', 8887-88', 8801-02', 8710-11', x thru tbg gun in CaC12 wtr. 6-66 EFG 8690-8710', 8780-8800' x csg gun in CaC12 wtr. 6-66 EFG 8560-8602', 8620-34', 8478-8540'x thru tbg gun (6 -SPF). Later reperf x csg gun in CaC12 wtr. 6-66 EFG 8710-80', 8800-8935', 9080-9150'x csg gun in CaC12 wtr. 6-66 EFG 8040-8255'(G-1, G-2), 8285-8430'(G-3) x csg gun in aC12 wtr (4SPF). 7-66 EFG 7756 - 57-1/2', 7732 - 33-1/2' x csg gun in CaC12 wtr. 7-66 BCD 6940 - 41-1/2, 6962 - 63-1/2', 7008 - 9-1/2 csg gun in CaC12 wtr. 11-66 BCD 7110-25', 6995-7020', 6935-75', 6875-6915', 6805-55', 6708-23', 6595-6650', 6520-70', 6460-75', 6448-53'x csg gun in CaC12 wtr. 11-66 EFG 7895-7910', 7730-90' x csg gun in CaC12 wtr. 4-23-75 BCDEFG 2 JSPF decentralized 4" Jumbo Jet. 6448-53', 6460-75', 6520-70', 6595-6650', 6708-6723', 6805-55', 6875-15', 6935-75', 6995-7020', 7110-7125, 7730-90', 7885-7910', 8040-8255', 8285'-8430', 8478-8540', 8560-8602', 8620-34'. • Perforation Record: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 5 Date Zone Interval 0 2-13-79 G 4 JSPF with 2" Dresser Atlas at 8040-8050', 8180-8190', 8200-8220', Slimkone retrievable hollow carrier. Perforated in tailpipe. 3-1/79 F 7740-7770', 4 JSPF with 2-1/8" Dresser Atlas. 4-79 EFG 2 JSPF with 2-1/8" decentralized, zero -degree phasing Ener -Jet. 7730-90', 7885-7910', 8040-8255', 8285-8430', 8478-8540', tagged fill @ 8545'. Reservoir Data: Zone Depths: Zone Tops: Cored Intervals: DST Intervals and Results: MIDDLE GROUND SHOAL ADL 17595 WELL NO. 5 (Continued) A zone: 5950-6400' BCD zone: 6400-7465' EFG zone: 7465-11128' G-1: 8040' MD G-2: 8155' MD G-3: 8288' MD G-4: 8470' MD G-5: 8695' MD None None Selective Tests: A zone: None BCD zone: None EFG zone: as given above in initial stimulation Log Inventory: Dual Induction Density Sonic IES Proximity-Microlog Dipmeter CBL Gamma Ray -CCL BAKER CLEANING TASK LOG Task Completed Confirmed BY Date By Tom McCaughey 6/28/2003 Rick Lewis Shutdown Wells and Pull Pumps Note: Pull Kobe pumps now, before source water is circulated. ff 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 6x29/2003 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 bbis 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 7/1003 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 bbis. 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 7/1/2003 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 tubing/casing volume of 480 bbls. There is no standing valve so operating the pump will circulate out any power oil remaining in the well. Turn 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 I 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. E 0 STATE OF ALASKA ALA" , OIL AND GAS CONSERVATION COMMIS~. REPORT OF SUNDRY WELL OPER 'i'IONS 1. Operations performed: Pull tubing __ Alter casing __ Repair well __ Pull tubing __ 2. Name of Opera~::t3N'OCAl', ) I 5. Type of Well: Union Oil Company of California J Devel°pment---~ Exploratory __ 3. Address Stratigraphic __ P. O. BOX 196247, Anch. , AK, 99519 Service__ 4. kocation of well atsurface Leg #1, Conductor #0 Operation shutdown __ Stimulate ~ Plugging __ Perforate __ 1934' FNL & 550' FWL, Sec 31, T9N, R12W, SM m~ ~ ,,~,, Zone at 6225' MD At top of pro~6ttCce~rvaln 581' FSL & 918' FWL, Sec 30, T9N, R12W, SM Ateffectived~P~tainer~Lu at 6440' MD 675' FSL & 932' FWL, Sec 30, T9N, R12W, SM 7~ ~&^'~I~TD AT 11,218' MD 827' FWL, Sec 30, T9N, R12W, SM Other __ 6. Datum elevation (DF or KB) 101' RKB ABOVE MLWeet 7. Unit or Property name MGS STATE 17595 8'Wellnu~Tbeefl NO. 5 9. Per~ nu3r~y~spr~;~l ~ umber 10. APl numl~, 3_10071 50-- 11. Field/l~C_ld. dle Ground She 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 595 ' Conductor Surface 2 012 ' Intermediate Production 7 5 6 5 ' Liner 3 76 ? ' Perforation depth: measured 11,128 ' feet Plugs (measured) 10,396' feet feet Junk (measured) 6,440' feet 5,720' Size Cemented 20" 1133 sxs 13-3/8" 2764 sxs 9-5/8" 1950 SXS 7" 1400 sxs Measureddepth ~ueverticaldepth 595' 595' 2012' 1952' 7565' 7360'-11127' 6842' 6637'-10395' true vertical See attached Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80, TDS; LS @ 5910' SS @ 584 Packers and SSSV (type and measured depth) Baker "D" pkr @ 6430', Baker SC-iL pkr @ 596 AVA SSSV @ 5876' 13. Stimulation or cement squeeze summary Intervals treated (measured) 6085 ' - 64 0 5 ' Treatment description including volumes used and final pressure 3338 gal 7.5% HCL, 4860 psi 14. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation 55 40 80 75 46 84 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas__ Suspended __ - JAN 2 ? 'r'~ I C&¢ I~ VII T,.4 r.4,,~ Anchorage Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~i-~' Gary S. Bus, l:k Regional S!gned ~, o.-.~. ?~. (~0,~k Title Drilling Manager Date ~ -.Z.\ -~ ~., SUBMIT IN DUPLICATE 1' 6' 17595 ~5 ?ERFOtLATION RECORD "A" ZONE 6085'- 6102' MD 6108'- 6145' MD 6192'- 6305' MD 6365'- 6405' MD "=" ZONE * 6448'- 6453' MD * 6460'- 6475' MD ~ 6520'- 6570' MD * 6595'- 6650' MD * 6708'- 6723' MD 5374'- 5390' TVD 5396'- 5432' TVD 5477'- 5587' TVD 5844'- 5686' TVD 5728'- 5733' TVD 5740'- 5755' TVD 5800'- 5849' TVD 5874'- 5929' TVD 5986'- 6001' TVD "C" ZONE 6805'- 6855' MD 6875'- 6915' MD 6935'- 6975' MD 6995'- 7020' MD "D" ZONE 7110'- 7125' MD 6083'- 6133' TVD 6153'- 6193' TVD 6213'- 6253' TVD 6273'- 6298' TVD 6388'- 6403' TVD "F" ZONE 7730'- 7760' MD 7885'- 7910' MD 7007'- 7037' TVD 7162'- 7187' TVD "G" ZONE 8040'- 8255' MD 8285'- 8430' MD 8478'- 8540' MD 8560'- 8602' MD 8620'- 8634' MD 8690'- 8935' MD 9080'- 9150' MD * CEMENT SQUEEZED 7316'- 7531' TVD 7561'- 7706' T~ 7754'- 7816' TVD 7836'- 7878' TVD 7896'- 7910' TVD 7966'- 8210' TVD 8355'- 8425' TVD RECEIVED dAN 2 ? 199 Alaska Oil & (~as Cons. Anchorage BAKER #5 COILED TUBING ACID JOB HISTO~ DATE ETD COMMENTS 12/12/91 6362 ' RIGGED UP ACID TANKS AND MIXED ACID. WAITED ON 3" TYPE "D" DUMMY PUMP ADAPTOR. PULLED THE STANDING VALVE. FILLED THE SHAKER PIT WITH FIW. 12/13/91 6362' RIH WITH 3" DUMMY AND SET AT 5841'. RIGGED UP THE COILED TUBING UNIT AND PRESSURE TESTED LINES TO 3000 PSI. RIH WITH A 1.5" SWIRL NOZZLE ON 1.25" COILED TUBING TO 5895'. DISPLACED THE OIL FROM THE TUBING TO PRODUCTION, RECOVERED SOME VERY FINE SILT. WASHED DOWN TO 6419' ETD. TESTED THE ACID LINES TO 5000 PSI. SPOTTED 26.5 BBLS (1113 GAL) 7.5% HC1 ACID AT 1-BPM WHILE POOH AT 20 FT/MIN, ACID SPOTTED FROM 5900'-6419'. ALLOWED THE ACID TO SOAK FOR 2 HRS. RIH TO 6419' AND SQUEEZED 53 BBLS(2225 GAL) 7.5% HCl ACID AT 1- BPM WHILE POOH AT 10 FT/MIN. POOH. DISPLACED THE COILED TUBING WITH BRINE FOR FREEZE PROTECTION. RIGGED DOWN THE COILED TUBING UNIT. RIGGED UP SLICKLINE AN PULLED THE DUMMY PUMP. RAN THE STANDING VALVE. 12/14/91 6362' FINISHED RUNNING THE STANDING VALVE AND MOVED THE COILED TUBING UNIT TO WELL ~13. RECEIVED J, .N 2 7 '1,992 Alaska Oil & Gas Cons. bommission Anchorage STATE OF ALASKA AL, .AOILANDGASCONSERVATIONCOMMIL ,'.N '" ' '- APPLICATION FOR SUNDRY APPROVALS ..... 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ z. Narpe ot uoe/ator .....I 5. Type of Well: U'nlon O.]_]_ Company o]: q;a_LlI:ornia Development._~_~ Exploratory __ 3. l~d.d~e, ss Box 196247, Anch. , AK, 99519 Stratigraphic __ Service __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance __ Perforate __ Other __ 4. Location of well at surface Leg #1, Conductor #6 1934' FNL & 550' FWL, Sec 31, T9N, R12W, SM At top of productive interval 6225 ' 581f FSL & 918' FWL, Sec 30, T9N, R12W, SM At effective depth 644 0 ' MD 675' FSL & 932' FWL, Sec 30, T9N, R12W, SM At totaldepthTD AT 11,218' MD 725' FSL & 827' FWL, Sec 30, T9N, R12W, SM 11,128' 10,396' 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet feet Junk (measured) feet Cemented 1133 sxs 2764 sxs 1950 SXS 1400 SXS 611~u ~n ~° n~l~E~ ~"-'B) ]4_~ Wf e et 7. U r~t~:~ro~,~l(.~e17595 8. Well number Well No. 5 9. Permit number 65-38 10. APl number 50-- '1.1.33-10071 11. Field/Pool Middle Ground Shoe ECEIVED Effective depth: measured true vertical 6,4 4 0 ' 5,720' Casing Length Size Structural 59 5 ' 20" Conductor Surface 2012 ' 13-3/8" Intermediate Production 7565' 9-5/8" Liner 3767 ' 7" Perforation depth: measured NOV 2 2 !99'! Nasl~a.Oil & Gas Cons. Commissie~ Measured dePt~chOrage''- True vertical depth 595' 595' 2012' 1952' 7565' 6842' 7360'-11127' 6637'-10395' true vertical See attached Tubing (size, grade, and measured depth 1/2" 9 2# N-80 TDS; LS @ 5910 SS @ Baker "D" pkr @ 6430', Baker SC-1L pkr @ Packers and SSSV (type and measured depth) AVA SSSV @ 5876' 5841' 5906' 13. Attachments Description summary of proposal __ Detailed operations program ~_ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: December 4, 1991 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify~t the foregoing is tr?.)and correct to the best of my knowledge, "~f"' L~~~, ~'~,_L~-,,., Title Re lena Signed Gar~/~. ~.~sh ... g 1 Drilling Mana)~l~r FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ zt~,..Li Mechanical Integrity Test_ Subsequent form required 10- - IApproval N o.~,..~, 7/ Approved by order of the Commissioner ORIGINAL SI,:,,~'::D BY LONNt[-.'. C .... ,~,.., Commissioner Date ii' ,~- ~-~ '1 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE >!GS 17595 #5 PERFORATION RECORD "A" ZONE 6085'- 6102' MD 6108'- 6145' MD 6192'- 6305' MD 6365'- 6405' MD "B" ZONE * 6448'- 6453' MD * 6460'- 6475' MD * 6520'- 6570' MD * 6595'- 6650' MD * 6708'- 6723' MD 5374'- 5390' TVD 5396'- 5432' TVD 5477'- 5587' TVD 5844'- 5686' TVD 5728'- 5733' TVD 5740'- 5755' TVD 5800'- 5849' TVD 5874'- 5929' TVD 5986'- 6001' TVD "C" ZONE * 6805'- 6855' MD * 6875'- 6915' MD * 6935'- 6975' MD * 6995'- 7020' MD "D" ZONE * 7110'- 7125' MD "F" ZONE 7730'- 7760' MD 7885'- 7910' MD 6083'- 6133' TVD 6153'- 6193' TVD 6213'- 6253' TVD 6273'- 6298' TVD 6388'- 6403' TVD NOV !991 Gas Cons. 7007'- 7037' TVD 7162'- 7187' TVD "G" ZONE 8040'- 8255' MD 8285'- 8430' MD 8478'- 8540' MD 8560'- 8602' MD 8620'- 8634' MD 8690'- 8935' MD 9080'- 9150' MD 7316'- 7531' TVD 7561'- 7706' TVD 7754'- 7816' TVD 7836'- 7878' TVD 7896'- 7910' TVD 7966'- 8210' TVD 8355'- 8425' TVD * CEMENT SQUEEZED PPOCEDURE ' RECOVER T}IF PUMP BY R. ET/ERSTNC TI{E POWER FLUID~ RECOVER THE STANDING VALVE IN THE E}!A. WITH S,r, IC~ LINE, RECOVER THE SSSV USING SLICK LIME, AVA TO BE PRESENT.~ R. EC-OVER THE "X" PLUG IN THE MA SLEEVE° 6,, PLACE A DUMMY PUMP IN THE BHA TO PROTECT THE SEA[, BORES: 7,, RTG UP COI!,ED TUBING UNIT. 8o RIH WTTfl 1-]/4" COILED TBG .AND SPOT 7~5% INHIBITED HC! FROM 66-30' - 9~ PERP~RM AN 8000 GAl, ACID SQUEEZE TMROUGH THE COILED TI!BTNG, !0, ~ITN THE SSRV O~ ¥ PLUG ON SLICK LINE= 11, RTTM THF STANDING VALVE ON SLICK I, INE~ 19 CTRCII[,ATE TTTE PUMP TNTO PLACE AND RETURN THE WELL TO PRODTTCTION~ RECEiV, [., NOV 2 .~ 199i .Oil & tiaa ~o.~ ..... Ancimmge A KOBE BHA RA SLEEVE SSSV XA SLEEVE -- STANDING __ VALVE RE-ENTRY 10 GUIDE 11 TUBING DETAIL LONG STRING (POWER FLUID) 1) CIW HANGER, BUTTRESS 2) 3-1/2 BU'FI' PIN x 3-1/2 TDS PIN X-OVER 3) 3-1/2' 9.2# N-80 'i-BG, '[DS W/SP CL CPLG$ 4) 3-1/2 'I'DS BOX x 3-1/2 EU &RD PIN X-OVER 5) KOBE 3' MODEL 'D' BHA ~ 5870' TM wrI'H 2.687' ID STANDING VALVE PROFILE 6) 3-1/2 RA SUDING SLEEVE, 2.562' PROFILE 7) 2-7/8' SSSV NIPPLE, 2.313' PROFILE (NO-GO) 8) 2-7/8' XA SUDING SLEEVE, 2.313' PROFILE 9) 2-7/8' XN NIPPLE, 2.205' PROFILE FOR STANDING VALVE 1 O) 2-7/8' WIREI INE RE-ENTRY GUIDE 11 ) 9-5/8' 43.5# PERM PKR W/4" BORE SHORT STRING (PRODUCTION) A) ClW HANGER, BUTI'RESS B) 3-1/2 BU'I-r PIN x 3-1/2 'I'DS PIN X-OVER C) 3-1/2- 9.2# N-80 'fBG, TDS W/SP CL CPLGS D) 3-1/2 'iDS BOX x 2-3/8 EU &RD PIN X-OVER E) 2-3/8" 4.6# N-80 PUP EU 8RD ( 1 O' ) RECEIVED N 0V 2 2 1991 A~as~a Oil & 6as Cons. Commission Anchorage ADL 17595 WELL NO. 5 PROPOSED SSSV INSTALLATION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 11-29-90 13-3/8' 54.5# @ 2012' 1 BAKER SC-1 PKR @ 5906' 5-1/2' 15.5# J-55 0.012" WIRE WRAPPED BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR @ 6430' 9-5/8' 4O & 43.5# 7565' 7" 29# @ 11127' TUBING DETAIL 1 1 A 2 B 3 C KOBE BHA -- -- / ~.':.'::i~:. .............. LONG SmlNG (POWER FLUID) 1 14) MULE SHOE AT 591 O' "A' ZONE INTERVAL 6085'- 61 O2' 6108'- 6145' 6192'- 6350' 6395'- 6405' 1) CIW HANGER, BUTTRESS (~ 32' 2) 3-1/2 BUTT PIN x 3-112 TDS PIN X-OVER 4~ 32.75' [3) 3-1/2- 9.2# N-80 TBG, TDS W/SP CL CPLGS 4) 3-1/2 TDS BOXx 3-1/2 EU aiD PIN X-OVER @ 5839' 5) KOBE 3' MODEL "D" BI'iA (~ 5841' SHORT STRING (PRODUCTION) A) CIW HANGER, BUTTRESS ~ 32' B) 3-1/2 BUTT PIN x 3-1/2 'IDS PIN X-OVER ~ 32.75' C) 3-1/2' 9.2# N.-80 'I'BG, TDS W/SP CL CPLGS D) 3-1/2 TDS BOXx 2-3/8 EU 8RD PIN X-OVER @ 5831' E) 2-3/8" 4.6~ N-80 PUP EU aid ~, 5833' TAIL ASSEMBLY 6) 3-1/2' EU aid OTIS 'RA' SLEEVE @ 5867' 73 3-1/2' 9.2# N.-80 EU 8RD PUP ~ 5870' 8) 3-1/2 EU aid BOX x 2-7/8 BUTT PIN X-OVER @ 5875' 9) 2-7/8" AVA SAFETY VALVE NIPPLE ~, 5876' 6) 2-7/8' BUTT OTIS "XA' SLEEVE ~, 5877' 11) 2-7/8' 6.4# N-80 BUTT PUP ~ 5881' 1 2) 2-7/8' BUTT OTIS 'XN' NIPPLE @ 5895' 1 3) SEAL ASSY W/2-7/8' BUTT BOX UP ( 10.0' ) ~, 5898' CMT RET @ 6440' PERFS F/6448'- 7125' @ INTERVALS TOP OF LINER @ 7339' BAKER MODEL F BP PERES F/7730'- 8634' @ INTERVALS CMT RET @ 8677' PERES F, 8690'-9150'8 INTI~~BFL' IV E D CMT RET @ 10200' NOV ?_ ?- 1991 ,~las~a OiJ & Gas Cons. (;ommiss't~ ~nchorage ADL 17595 WELL NO. 5 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1-15-91 TEXAS TOOLS ~4 TUBING.STRIPPER/PAC~R- S,O00 psi Working Pressure HsS Service 1.00'Series DS322 1.2S!~erles DS32:3- ~asJiaL_ .Oil & 6a~ Cons. k,~JmmiS~l~- ~,nchoraoe " ~:- A .' phone: (71'3') $206 STATE OF ALASKA ALA:L .... OIL AND GAS CONSERVATION COMMIS,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing Stimulate __x Plugging __ Pedorate Repairwell __ Pulltubing :x Other x 2. Name of Operal(oUNOCAL) ~ 5. Type of Well: Union Oil Company of California I Development.z_ Exploratory __ 3. Address Stratigraphic __ P.O. BOX 190247, Anch., AK, 99519 Service__ 4. Location of well at surface Leg #1, Conductor 6 1934' FNL & 550' FWL, Sec 31, T9N, R12W, SM m~ ~¢ ..~,. Zone at 6225' MD At to_p ofpro~lu~e'fffferval~ 581' FSL & 918' FWL, Sec 30, T9N, R12W, SM 8~~¢~f . l~¢tainer at 6440' MD 6,3fr'ectr~z.,p_ 932' FWL, Sec 30, T9N, R12W, SM TD AT 11,218' MD 7~tald~, & 827' FWL, Sec 30, T9N, R12W, SM 12. Present well condition summary Total depth: measured true vertical 11,128 ' feet Plugs (measured) 10,396' feet feet Junk (measured) 6,440' feet 5,720' Size Cemented 20" 1133 sxs 13-3/8" 2764 sxs 9-5/8" 1950 SXS 7" 1400 sxs Effective depth: measured true vertical Casing Length Structural 595 ' Conductor 2012' Surface Intermediate Production 7565 ' Liner 3767 ' Perforation depth: measured 6. Datum elevation (DF or KB) 101 ' RKB ABOVE l~LWeet 7. Unit or Property name MGS STATE 17595 8. Well number Well No. 5 9. Permitnumber/approval number 65-38/90-766 10. APl num~e~ 3_10071 50-- 11. Field/~ddle Ground Shc RECEIV[D Alaska Oil & ~aS COrtS, COBI~i$SjO~ ~achor~e Measured depth ~rue ve~ical depth 595' 595' 2012' 1952' 7565' 6842' 7360'-11127' 6637'-10395' true vertical See attached Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) al 3-1/2", 9.2#, N-80, TDS; LS @ 5910' SS @ 58411 Baker "D" pkr @ 6430', Baker SC-1L pkr @ 59061 AVA SSSV @ 5876' 13. Stimulation or cement squeeze summary Intervals treated (measured) See attached history Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation Shut-in 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil ~ Gas__ Suspended __ Service 17. I hereby cert?.!hat the foregoing is true and correct to the best of my knowledge. Gary /Sit Bush .... . .:..-'~ ~ Regional Drilling Manager Signed ~...~c~"'.k._~'~,~.. ~..~,~-.',*k/'k Title Date~/~.\. l q'k Form 10-404 Rev ~,~6~15/8~ SUBMIT IN DUPLICATEC'~ MGS 17595 #5 PERFORATION RECORD "A" ZONE 6085'- 6102' MD 6108'- 6145' MD 6192'- 6305' MD 6365'- 6405' MD "B" Z ONE * 6448'- 6453' MD * 6460'- 6475' MD * 6520'- 6570' MD * 6595'- 6650' MD * 6708'- 6723' MD 5374'- 5390' TVD 5396'- 5432' TVD 5477'- 5587' TVD 5844'- 5686' TVD 5728'- 5733' TVD 5740'- 5755' TVD 5800'- 5849' TVD 5874'- 5929' TVD 5986'- 6001' TVD "C" ZONE * 6805'- 6855' MD * 6875'- 6915' MD * 6935'- 6975' MD * 6995'- 7020' MD "D" ZONE * 71.10'- 7125' MD 6083'- 6133' TVD 6153'- 6193' TVD 6213'- 6253' TVD 6273'- 6298' TVD 6388'- 6403' TVD "F" ZONE 7730'- 7760' MD 7885'- 7910' MD 7007'- 7037' TVD 7162'- 7187' TVD "G" ZONE 8040'- 8255' MD 8285'- 8430' MD 8478'- 8540' MD 8560'- 8602' MD 8620'- 8634' MD 8690'- 8935' MD 9080'- 9150' MD 7316'- 7531' TVD 7561'- 7706' TVD 7754'- 7816' TVD 7836'- 7878' TVD 7896'- 7910' TVD 7966'- 8210' TVD 8355'- 8425' TVD * CEMENT SQUEEZED UNOCALI, SHEET A ~_~, _.~/ PAGE NO. LEASE MGS State ~75~5 WELL NO. 5 FIELD Middle Ground Shoa% LOCATION: Leg #1, Conductor #6 1954' FNL % 550' FWL, Sec, 31, T9N Rt2W, SM ELEVATIONS: WATER DEPTH 102' PERMIT NO. 65-38 SERIAL NO.50-133-10071 RKB TO OCEAN FLOOR 203' TD 11,%28' TVD 10,396' RKB TO MLW 101' DEVIATION (BHL) 725'FSL & 827'FWLo RKB TO DRILL DECK 25.16 SEC, 30, T9N, R12Wo SM COMPANY ENGINEER CHUD~NOV, HARNESS. RKB TO PRODUCTION DECK MCCAUL ~ SPUD DATE 11-22-90 COMP DATE 12-28-90 CONTRACTOR P,A.~, RIG NO. 6% TYPE UNIT OIME 2000 DRILL PIPE DESCRIPTION 3-1/2" 15.5# 39.%6 CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 20" 79.6# SPIRAL WELD 595' 13-3/8" 54.5# 8RD ST&C J-55 2012' 9-5/8" 40 8RD ST& C S-95 & & 43.5# BUTT N-80 7565' 7" 29# 8RD ST&C S-95 & LT&C N-80 7360'-11127' CMT'D W/1133 SXS CMT'D W/2764 SXS CMT'D W/1950 SXS CMT'D W/1400 SXS PERFORATING RECORD DATE INTERVAL E.T.D. 12/09/90 60~5'-6102' 12/09/90 6108'-6145' 12/02/90 6192'-6305' 6440' 12/02/90 6365'-6405' 6440' REASON PRESENT CONDITION PRODUCTION "A" ZONE-OPEN(GRAVEL PACKED~ PRODUCTION "A" ZONE-OPEN(GRAVEL PACKED) PRODUCTION "A" ZONE-OPEN(GRAVEL PACKED) PRODUCTION "A" ZONE-OPEN(GRAVEL PACKED~ LOWER PERFS ISOLATED BY CMT RETAINER AT 6440' (SEE ATTACHED PERF RECORD) INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS WELL HEAD ASSEMBLY TYPE: CAMERON IRON WORKS/OCT CASING HEAD: 20"SOW X 20" 2M HOUSING w/13-3/8" CSG PREP (OCT 68-130-108) CASING SPOOL: 20" ~M X 12" 3M SPOOL W/9-5/8" csp PREP (OCT 68-130-295) TUBING HEAD: 12" 3M.X 10" 5M DCB SPOOL W/2" 5M OUTLETS (CIW 19047-2-10-10) TUBING HANGER: 3-1/2" NOMINAL DUAL SPLIT HANGERS, BUTT-DOWN, 8RD-UP TUBING HEAD TOP: 10" 5M (RX-54} BLOCK TREE: 3X3 5M DUAL BLOCK TREE w/3-1/8" BoRE MASTER & SWAB VALVES, 5-3/64 CENTERS (cIw 670877-1) CHRISTMAS TREE TOP CONN: 4P,? 26 ]95! Alaska Oil %Gas Co, s. Com~is$io~ anChorag~ PLATFORM BAKER 17595 WELL #5 (BA-5) WELL HISTORY DATE MW ETD COMMENTS 11/22/90 64 PCF 6411' 11/23/90 75 PCF 6411' 11/24/90 75 PCF 6411' COMMENCED OPERATIONS ON WELL ADL 17595 #5, LEG # 1, SLOT #6, BAKER PLATFORM. RIGGED UP LUBRICATOR ON LONG STRING TO CATCH PUMP. HELD 2 HOUR PLATFORM SAFETY ORIENTATION MEETING FOR ALL DRILLING PERSONNEL. REVERSED OUT AND RECOVERED 2- 1/2" X 1-7/16" X 1-1/4" KOBE "A" PUMP, SERIAL #4274. RIGGED DOWN LUBRICATOR. RIG UP WlRELINE AND TEST LUBRICATOR TO 2500 PSI. RAN IN WITH "KO" PRONG TO SHEAR EQUALIZING PLUGS IN STANDING VALVE AT 6014' TM. TRIP FOR RETRIEVING TOOL. PULLED STANDING VALVE. RIGGED DOWN WlRELINE. RIGGED UP AND DISPLACED 78 BBLS (1.5 TBG VOLUMES) 3 % KCL/FIW DOWN SHORT STRING. RIGGED UP TO LONG STRING AND BEGAN DISPLACING WELL WITH 3% KCL/FIW AT 3.75 BPM RATE TAKING RETURNS THRU PRODUCTION TEST SEPARATOR. TUBING AND CASING PRESSURES INCREASED WHEN FLUID REACHED SURFACE. SHUTDOWN TO CHANGE OUT ANNULUS CHOKE ORIFICE PLATES. CHANGED OUT ANNULUS CHOKE ORIFICE PLATES AND COMPLETED CHANGE OVER TO 3% KCL/FIW. WELL FLOWING. SHUT-IN WELL AND PRESSURES EQUALIZED AT 200 PSI. ATTEMPTED TO BLEED WELL DOWN. WELL CONTINUED TO FLOW WATER FROM TUBING AND CASING. DISPLACED 60 BBLS 3% KCL/FIW DOWN SHORT STRING TAKING ANNULUS RETURNS TO PRODUCTION. SHUT-IN WELL FOR 1 HOUR AND PRESSURE EQUALIZED AT 220 PSI. RIGGED UP TO CIRCULATE THROUGH RIG CHOKE SYSTEM AND TANKS TO WEIGHT UP SYSTEM. SECURED RIG AND SHUT DOWN ALL OPERATIONS @ 0639 HOURS DUE TO PRODUCTION FIRE ALARM AND SHUTDOWN. RESUMED OPERATIONS AT 1200 HOURS. INCREASED BRINE WEIGHT IN PITS TO 72 PCF WITH NACL. CHANGED WELL OVER TO 72 PCF BRINE THROUGH RIG CHOKE. LONG STRING AND ANNULUS WAS DEAD, BUT SHORT STRING FLOWED. ATTEMPTED TO EQUALIZE WELL-NO GOOD. INCREASED BRINE WEIGHT TO 74 PCF- WELL DEAD. SET BACK PRESSURE VALVES AND REMOVED PRODUCTION TREE. INSTALLED 11" 5M X 13-5/8" 5M DSA AND 5M RISER. NIPPLE UP BOPE. TESTED BOPE RAM PREVENTERS AND CHOKE MANIFOLD TO 300 PSI (LOW) AND 3000 PSI (HIGH). TESTED ANNULAR PREVENTER TO 300 PSI (LOW) AND 2500 PSI (HIGH). REMOVED SHORT STRING BACK PRESSURE VALVE AND INSTALLED LANDING JOINT. PLATFORM BAKER 17595 WELL #5 (BA-5) WELL HISTORY DATE MW ETD 11/25/90 75 PCF 6411' 11/26/90 75 PCF 6411' 11/27/90 75 PCF 6411' R CE V D A~aska 0ii & t2as Co,ms. Cor~r~issJon Anchorage PAGE 2 COMMENTS OFFLOADED M.V. ALASKA HUSKY. RIGGED UP WIRELINE AND RAN IN WITH A 1-13/16" JET TUBING CUTTER. CUT SHORT STRING IN 2-3/8" PUP JOINT AT 5991' TM (6015'WLM). RIG DOWN WlRELINE UNIT. PULL AND REMOVE SPLIT 3-1/2" TUBING HANGER. CIRCULATE BRINE TO BALANCE THE WELL. PULL AND LAY DOWN 3-1/2" SHORT STRING. PULL 2-WAY CHECK FROM LONG STRING. PULL AND REMOVE SPLIT 3-1/2" TUBING HANGER. CIRCULATE BRINE TO BALANCE THE WELL. PULL AND LAY DOWN 3-1/2" LONG STRING. FINISHED PULLING AND LAYING DOWN 3-1/2" LONG STRING. LAY DOWN KOBE BO~-FOMHOLE ASSEMBLY. SET TEST PLUG AND TEST CSO GATE TO 300 PSI (LOW) AND 3000 PSI (HIGH). RUN IN WITH 8-1/2" BIT PICKING UP 3-1/2" 15.5# DRILL PIPE. RAN TRIP DRILL AND BOPE ACCUMULATOR TEST. ACCUMULATOR FAILED TO PROVIDE ADEQUATE FLUID VOLUME. CHECKED NITROGEN PRECHARGE-OK. CONTINUED IN HOLE TO 6131' DPM PICKING UP DRILL PIPE. CIRCULATED WELL. SHUT WELL IN TO WORK ON ACCUMULATOR. BEGAN REPAIR OF BOPE ACCUMULATOR. CONTINUED REPAIR OF BOPE ACCUMULATOR. REMOVED ALL 16 SEPARATOR BOTTLES TO CLEAN ENTIRE FLUID SYSTEM. REASSEMBLED ACCUMULATOR WITH 13 USEABLE SEPARATOR Bo-Ir'LES (130 GAL CAPACITY, 65 GAL USEABLE). SLIP AND CUT DRILLING LINE. ADJUST DRAWWORKS BRAKES. PERFORM ACCUMULATOR TEST-1250 PSI AFTER CLOSING PREVENTERS. CONTINUED RUNNING IN PICKING UP 3-1/2" DRILL PIPE. TAGGED FILL AT 6256' DP. CLEANED OUT FILL TO CEMENT RETAINER AT 6409' DPM (6411' DIL). DRILLED CEMENT RETAINER AND CIRCULATED BOTTOM UP. CIRCULATED OUT GAS THROUGH THE CHOKE SYSTEMS. 11/28/90 75 PCF 6440' CONTINUED CIRCULATING OUT GAS THROUGH THE CHOKE SYSTEM. PUSHED RETAINER JUNK TO 6683' DPM. CIRCULATED WELL CLEAN. PULLED OUT OF HOLE STRAPPING OUT THE DRILL PIPE. MADE UP AND RAN IN WITH CASING SCRAPER TO 6705' DPM (NO TAG). CIRCULATED WELL CLEAN. TRIP FOR BRIDGE PLUG. RIG UP WlRELINE. RAN GAUGE RING TO 6600' DIL. TRIP WlRELINE FOR HOWCO EZSV WITH BRIDGE PLUG KIT. RAN IN WITH BRIDGE PLUG. TIED IN WITH MULTI-SPACED NEUTRON LOG, 8/11/86 (0' MSL = 5' DIL). SET BRIDGE PLUG AT 6440' DIL. TRIP OUT AND RIG DOWN WlRELINE. DATE 11/29/90 11/30/90 12/01/90 MW 75 PCF 75 PCF 74 PCF PLATFORM BAKER 17595 WELL #5 (BA-5) WELL HISTORY PAGE 3 ETD 6440' COMMENTS 6440' MADE UP RTTS PACKER AND BYPASS ON 3-1/2" DRILLPIPE. RAN IN TO 6375' DPM AND CIRCULATED WELL. SET PACKER AT 6375' DPM AND PRESSURE TESTED BRIDGE PLUG TO 2500 PSI FOR 15 MINUTES TO CONFIRM ISOLATION OF LOWER ZONES. PULLED UP TO 6195' DPM AND RESET PACKER. PRESSURED BACKSIDE AGAINST UPPER PIPE RAMS TO 3000 PSI FOR 30 MINUTES TO TEST CASING. CIRCULATE WELL TO BALANCE MUD. TRIP FOR CASING SCRAPER AND WIRE BRUSH. RUN IN TO 6420' DPM AND CIRCULATED WELL CLEAN. DUMP ACTIVE MUD SYSTEM. CLEAN TANKS AND RIG UP BAKER SAND FILTERING UNIT. BEGAN MIXING 3% KCL/FIW BRINE. MIX NACL WITH 3% KCL/FIW TO WEIGHT ACTIVE SYSTEM TO 75 PCF. HOLE TAKING ABOUT 1 BBL PER HOUR. CHANGED WELL OVER TO FRESH BRINE TAKING RETURNS TO PRODUCTION. CLEANED PITS. CIRCULATED AND FILTERED ACTIVE SYSTEM, INCLUDING THE HOLE VOLUME. RETURNS AT FLOWLINE = 25 NTU. FLUID GOING DOWN HOLE = 5 NTU. PULLED OUT OF HOLE WITH DRILL PIPE. PREPARED TO PICK UP 3-1/2", 9.2#, N-80 TDS TUBING FOR FRACTURE STIMULATION. 6440' RAN IN HOLE PICKING UP 3-1/2", 9.2#, N-80 TDS TUBING FOR FRAC JOB. TAGGED FILL AT 6423' TM (SALT). WASHED DOWN TO 6437' TM AND TAGGED RETAINER. CIRCULATED AND FILTERED BRINE AT 6437' TM. REDUCED BRINE WEIGHT TO 74 PCF. SPOT AND RIGUP ALL FRAC EQUIPMENT. PULL OUT OF HOLE STANDING BACK TUBING. MAKE UP TUBING CONVEYED PERFORATING ASSEMBLY. DATE 12/02/90 12/03/90 MW 74 PCF 74 PCF PLATFORM BAKER 17595 WELL #5 (BA-5) WELL HISTORY PAGE 4 ETD 6440' COMMENTS RUN IN WITH PERFORATING ASSEMBLY ON 3-1/2" DRILL PIPE. TAGGED RETAINER AT 6436' DPM (6440' DIL). PULLED UP AND RIGGED SURFACE LINES FOR PERFORATING. RIGGED UP WlRELINE FOR CORRELATION LOG. PRESSURE TESTED SURFACE EQUIPMENT. FOUND PACKER SET 5' LOW. RESET PACKER AND RAN CONFIRMATION LOG-OK. FOUND R.A. MARKER AT 5852' DIL WITH "A" ZONE PERFORATIONS FROM 6192'-6356' DIL AND 6365'-6405' DIL. PULLED OUT AND RIGGED DOWN WIRELINE. TRANSFERRED FLUID TO BAKER SAND FOR FILTERING. SHOT FLUID LEVEL AT 1100' PRIOR TO OPENING OMNI VALVE. CYCLED OMNI VALVE OPEN-HAD GOOD BLOW. PRESSURED ANNULUS TO 3000 PSI TO FIRE GUNS. DID NOT GET A GOOD SURFACE INDICATION OF THE GUNS FIRING. REPRESSED SEVERAL TIMES-NO GOOD. RIGGED TO DROP FIRING BAR. DROPPED BAR. NO INDICATION OF GUNS FIRING. CYCLED OMNI VALVE TO REVERSING POSITION AND REVERSED OUT OIL. OPENED OMNI VALVE AND PULLED PACKER TO BYPASS POSITION. REVERSED OUT OIL FROM BELOW THE PACKER. CIRCULATED TWO HOLE VOLUMES THE LONG WAY TO BALANCE THE WELL. RIG UP WlRELINE TO RECOVER THE FIRING BAR. MADE THREE TRIPS TRYING TO GET DOWN - TOOLS STOPPED AT 6060' WLM. TRIP FOR GAMMA RAY. RECORRELATED GUNS AND RESET PACKER. RAN IN WITH BAR RETRIEVING TOOL-TOOLS STOPPED AT 6060" WLM. ATTEMPTED TO LATCH BAR-NO GOOD. TRIP TO CHANGE TOOLS. 6440' CONTINUED ATTEMPTING TO FISH FIRING BAR WITH WIRELINE (1-7/16" TOOLS). A~-TEMPT TO LATCH FISH AT 6146' WLM-NO GOOD. RIG UP TO ,REVERSE CIRCULATE. A~-FEMPT TO LATCH FISH WHILE REVERSING-NO GOOD. RIG UP TO CIRCULATE THE LONG WAY. ATTEMPT TO LATCH FISH WHILE CIRCULATING-PICKED UP 80# OF LINE WEIGHT. PULLED OUT OF HOLE SLOW AND TOOLS HUNG UP IN OMNI VALVE AT 6047' WLM. ATTEMPT TO FREE TOOLS-NO GOOD. CIRCULATED THROUGH TOOLS-NO MOVEMENT. RIGGED DOWN SURFACE LINES. CUT WlRELINE AND RIGGED DOWN LUBRICATOR. STRIPPED OVER WlRELINE AND RUN IN AND TAGGED BO~-FOM AT 6437' DPM. SET PACKER WITH BOTTOM OF GUNS AT 6435' DPM. SLACKED OFF 45 K ON TOP OF PACKER AND BACKED OFF GUNS AS FOLLOWS: PUT 6 ROUNDS OF RIGHT HAND TORQUE IN DRILL STRING TO SHEAR RELEASING PINS-NO GOOD; PUT IN 3 MO,RE ,R, OUNDS AND PINS SHEARED; PUT IN 16 MOtRE ROUNDS AND GUNS DID NOT RELEASE; PLATFORM BAKER 17595 WELL #5 (BA-5) WELL HISTORY DATE MW ETD 2/03/90 74 PCF 6440' CONTINUED) 12/04/90 74PCF 6440' PAGE 5 COMMENTS SET GUNS ON BO'I-i'OM WITH 10K AND PUT IN 3 MORE ROUNDS AND GUNS RELEASED. PULLED OUT OF HOLE STRIPPING WIRE OUT OF THE DRILL PIPE. CONTINUED TO PULL OUT HOLE, CUTTING AND STRIPPING OUT WIRELINE. RECOVERED WIRELINE FISHING TOOLS AND BAKER PACKER WITH FLOW TUBE. LEFT TCP PERF GUNS IN HOLE (FISH 242.86'). TOP OF FISH AT 6194' DPM. RIG TO TEST BOPE. TEST TO UNOCAL SPECIFICATIONS. REPAIRED RAT HOLE HINGE PIN. MADE UP OVERSHOT WITH 3-3/4" BASKET GRAPPLE ON FISHING TOOL ASSEMBLY #1. RAN IN TO 6185' DPM AND CIRCULATED WELL CLEAN. RAN IN AND LATCHED FISH AT 6194' DPM. PULLED TCP FISH UP HOLE TO SPACE OUT TOP SHOT AT 6192' DIE RIG UP WlRELINE TO RECOVER FIRING BAR. 12/05/90 73PCF 6440' APR 2 6 99! Alaska 0il & Bas Cons, Commission A~chorage 12/06/90 73 PCF 6440' RIGGED UP SLICKLINE AND RAN IN WITH OVERSHOT TO 6163' WLM. ATTEMPT TO LATCH FIRING BAR-NO GOOD. TRIP FOR 1-1/4" IMPRESSION BLOCK. RAN IMPRESSION BLOCK AND SET DOWN AT 6163' WLM. TRIP TO CHECK TOOLS-APPEARED TO BE SETTING DOWN ON FILL. MADE TWO RUNS WITH A 1-1/4" BAILER-NO RECOVERY. RIGGED DOWN WlRELINE. PULLED AND LAID DOWN TCP GUNS. ALL SHOTS FIRED. RAN IN WITH 8-1/2" BIT AND 9-5/8" CASING SCRAPER. TAGGED FILL AT 6432' DPM. CIRCULATED WELL CLEAN. SLIPPED AND CUT DRILLING LINE 100 INCHES. CIRCULATED, FILTERED AND BUILT FLUID VOLUME. TRIP FOR PRESSURE PACK ASSEMBLY. FINISH TRIP FOR PRESSURE PACK ASSEMBLY. MADE UP 9-5/8" R'I-rS PACKER WITH BYPASS AND 10' TUBING TAIL. RAN IN HOLE ON 3-1/2", 9.2#, TDS TUBING TO 6140' DPM. DISPLACED TUBING WITH FILTERED BRINE. SET PACKER AT 6124' DPM WITH TAIL AT 6140' DPM. TESTED BACK SIDE TO 2500 PSI. RIGGED UP BJ/BAKER PUMPING EQUIPMENT AND PRESSURE TESTED LINES TO 8200 PSI. ESTABLISHED AN INJECTION RATE OF 7.5 BPM AT 2200 PSI WITH 46 BBLS BRINE. ESTABLISHED A SECOND INJECTION RATE OF 15 BPM AT 2800 PSI WITH 60 BBLS BRINE. PUMPED FRAC STIMULATION AS FOLLOWS: 315 BBLS OF 70#/1000 GAL HEC PRE-PAD AT 9.25 BPM WITH 2500 PSI; 146 BBLS OF 70#/1000 GAL HEC WITH 12 PPG 20/40 OTTAWA SAND AT 5.4 BPM WITH 2000 PSI (47,000# SAND); 53 BBLS OF 60#/1000 WELL HISTORY PLATFORM BAKER 17595 WELL #5 (DA-5) DATE MW ETD 12/06/90 73 PCF 6440' (CONTINUED) 12/07/90 73 PCF 6440' 12/08/90 78PCF 6440' 12/09/90 78PCF 6440' PAGE 6 COMMENTS GAL HEC FLUSH 13.25 BPM WITH 2900 PSI. ALL HEC GEL FLUIDS HAD 70 GRAM/BBL BAKER ENZYME BREAKER ADDED BEFORE PUMPING. BASE FLUID FOR PREPAD AND SLURRY WAS 67 PCF 3% KCL/FIW. FLUSH FLUID WAS WEIGHTED TO 73 PCF WITH NACL. FINISHED PUMPING AT 1907 HOURS. SHUT-IN WELL TO MONITOR PRESSURE. WASH UP PUMPING EQUIPMENT. CONTINUE TO MONITOR PACK PRESSURE. ATTEMPT TO BLEED TUBING DOWN-NO GOOD. SHUT-IN TUBING PRESSURE = 425 PSI. RIG UP BJ AND BULLHEAD ONE TUBING VOLUME OF 74 PCF BRINE AT 1 BPM WITH 1500 PSI. SHUT-IN TUBING PRESSURE -- 110 PSI AFTER 4 HOURS. OFFLOAD CACL2 SACK MATERIAL FROM BOAT. MIX 3% KCL/FIW WITH CACL2 TO 78 PCF. SHIP 3% KCL/FIW WITH NACL TO PRODUCTION. CONTINUE TO MIX 3% KCL/FIW WITH CACL2 TO 78 PCF FOR CHANGE OVER. FILTER NEW FLUID TO 110 NTU'S. OPEN PACKER BYPASS AND CHANGE OVER WELL TO 78 PCF BRINE BY PUMPING DOWN THE ANNULUS TAKING RETURNS UP THE TUBING TO PRODUCTION HOLDING 200 PSI BACKPRESSURE. SHUT-IN TUBING PRESSURE PRIOR TO CHANGE OVER = 25 PSi. SHUT-IN WELL WITH 78 PCF BRINE AND OBSERVED PRESSURE FOR 30 MINUTES-WELL DEAD. PULLED AND LAID DOWN FRAC PACKER. RAN IN WITH OEDP AND TAGGED SAND FILL AT 6218' DPM. PULLED TO 6177' DPM TO CIRCULATE AND FILTER FLUID. CONTINUED TO CIRCULATE AND FILTER FLUID TO 35 NTU'S AT 6177' DPM. RIG UP BJ AND SPOT A 16 SACK 20/40 SAND PLUG. WAIT 1 HOUR. TAGGED FILL AT 6186' DPM. SPOT A 3 SACK SAND PLUG AND TRIP FOR PERFORATING ASSEMBLY. MADE UP 7" TCP GUNS AND RAN IN TO 6150' DPM FILLING DRILL PIPE WITH 78 PCF BRINE TO ACHIEVE 500 PSI UNDERBALANCE AT TOP SHOT. RIG UP WlRELINE FOR CORRELATION LOG. LOCATED "RA" TAG AT 5739' DIL, PACKER AT 6044' DIL, AND TOP SHOT AT 6085' DIL. SET PACKER AND RAN CONFIRMATION LOG. RIGGED DOWN WIRELINE. SHOT FLUID LEVEL AT 1281' DPM. TESTED SURFACE EQUIPMENT TO 3000 PSI. CYCLED OMNI VALVE OPEN WITH 1500 PSI AND FIRED GUNS WITH 3000 PSI ANNULAR PRESSURE. PERFORATED UPPER "A" ZONE FROM 6085'-6102' DIL AND 6108'-6145' DIL WITH 8 HPF, 61 GRAM GRAVEL PACK CHARGES. WELL FLOWED AND DIED AFTER A 700' FLUID RISE. OPENED PACKER WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE MW ETD 12/09/90 78PCF 6440' (CONTINUED) 12/10/90 78 PCF 6440' 12/11/90 78 PCF 6440' PAGE 7 COMMENTS BYPASS AND REVERSED TUBING CLEAN. SLIGHT OIL AND GAS SHOWS. CIRCULATED TO BALANCE WELL. RELEASE PACKER AND TRIP FOR BIT AND SCRAPER. FINISH PULLING OUT WITH TCP GUN ASSEMBLY. ALL SHOTS FIRED. MADE UP 8-1/2" BIT AND 9-5/8" CASING SCRAPER AND RAN IN HOLE. TAGGED FILL AT 6177' DPM. CIRCULATED CLEAN FLUID PAST THE PERFORATIONS AND PULLED UP TO 6077' DPM. CIRCULATED AND FILTERED FLUID TO 52 NTU'S. TRIP FOR FRAC PACKER. MADE UP HOWCO 9-5/8" RTTS PACKER WITH BYPASS AND 10' TUBING TAIL. RAN IN TO 6048' DPM AND DISPLACED THE TUBING WITH 40 BBLS 3% KCL/FIW. SET PACKER AT 6030' AND TESTED BACKSIDE TO 2500 PSI. RIG UP BJ PUMPING EQUIPMENT AND TEST LINES TO 6500 PSI. ESTABLISH AN INJECTION RATE OF 15 BPM AT 2900 PSI WITH 45 BBLS OF 3% KCL/FIW. MIX UP FRAC FLUIDS. PUMPED FRAC STIMULATION AS FOLLOWS: 80 BBLS 70#/1000 GAL HEC. PRE-PAD AT 16 BPM WITH 2900 PSI; 40 BBLS 70#/1000 GAL HEC WITH 12 PPG 20-40 OTTAWA SAND (13,000# SAND) AT 11.4 BPM WITH 2600 PSI; AND 52 BBLS 70#/1000 GAL HEC DISPLACEMENT WEIGHTED TO 78 PCF AT 11.4 BPM WITH 2800 PSI. INITIAL SHUT- IN PRESSURE WAS 1100 PSI. PRESSURE BLED TO 70 PSI IN 4 HOURS. OPENED Rq-FS PACKER BYPASS AND REVERSED OUT FRAC FLUSH FLUID TO THE RESERVE PIT HOLDING 200 PSI BACKPRESSURE ON THE WELL. SHUT-IN WELL AND PRESSURE BLED TO 0 PSI IN 30 MINUTES. RELEASED RTTS PACKER AND PULLED OUT OF HOLE. TESTED BOPE AS FOLLOWS: ANNULAR PREVENTER TO 400 PSI (LOW) AND 2500 PSI (HIGH); RAM TYPE PREVENTERS TO 400 PSI (LOW) AND 3000 PSI (HIGH); AND MANIFOLD VALVES TO 400 PSI (LOW) AND 3000 PSI (HIGH), RAN IN WITH AN 8-1/2" BIT AND TAGGED SAND AT 6078' DPM. SINGLED DOWN DRILL PIPE FOR CLEANOUT. CLEANED OUT SAND FROM 6078' DPM TO 6438' DPM (6440' DIL) CIRCULATING CLEAN EVERY 90' OF HOLE. HOLE TAKING 15 BBL/HR DURING THE CLEAN OUT RUN. CIRCULATE OUT SAND AT RETAINER. LOST 160 BBLS FLUID TODAY FOR A TOTAL OF 925 BBLS TO DATE. WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE MW ETD 12/12/90 76 PCF 6440' 12/13/90 76 PCF 6440' PAGE 8 COMMENTS CONTINUED TO CIRCULATE OUT SAND FILL. FILTER FLUID FOR GRAVEL PACK TO 53 NTU'S. TRIP FOR BAKER MODEL "D" SUMP PACKER. RIG UP SURFACE LINES AND SET SUMP PACKER AT 6430' DIL (6427' DPM) WITH 2600 PSI. SHEARED OUT OF PACKER WITH SE'II'lNG TOOL AND CIRCULATED TO BALANCE THE WELL. TRIP FOR GRAVEL PACK LINER. RIG TO PICK UP WIRE WRAP SCREEN. MAKE UP WIRE WRAP LINER AND GRAVEL PACK ASSEMBLY. RAN IN WITH WIRE WRAP LINER AND GRAVEL PACK ASSEMBLY ON 3-1/2" TDS TUBING. STAB INTO BAKER MODEL "D" SUMP PACKER. PULL OUT WITH 30 K OVERPULL TO CONFIRM STAB-IN TO LATCH. SPACE OUT FOR GRAVEL PACK AND STAB BACK INTO THE SUMP PACKER AT 6430' DIL. LINER SE'l-rING DEPTHS AS FOLLOWS: S-22 SEAL ASSEMBLY AND SNAP LATCH AT 6428' DIL; 0.012" WIRE WRAP 5-1/2" LTC 8RD LINER LOWER TELL TAIL SCREEN AT 6418' DIL; O-RING SEAL SUB AT 6417' DIL; 0.012" WIRE WRAP 5-1/2" LTC 8RD LINER AT 6062' DIL (355' SCREEN); 5-1/2" LTC 8RD BLANK CASING AT 5915' DIL; UPPER EXTENSION AT 5910' DIL; BAKER MODEL SC-1 PACKER (#96A4-47) AT 5905' DIE RIGGED UP SURFACE LINES FOR GRAVEL PACK AND TESTED TO 3000 PSI. CIRCULATED TO CONFIRM A CLEAN BALL SEAT AND DROPPED PACKER SETTING BALL. SET SC-1 PACKER WITH 2000 PSI. PRESSURE TESTED THE ANNULUS TO 2000 PSI AGAINST THE UPPER PIPE RAMS. RELEASED RUNNING TOOLS AND LOCATED LOWER CIRCULATING POSITION, UPPER CIRCULATING POSITION, NEUTRAL POSITION, AND REVERSING POSITION OF GRAVEL PACKING TOOLS. ESTABLISHED A CIRCULATING PRESSURE OF 500 PSI AT 3 BPM AND A REVERSING PRESSURE OF 250 PSI AT 3 BPM. MIXED SAND. PUMPED GRAVEL PACK AS FOLLOWS: 15 BBL 350 CPS HEC PREPAD AT 5 BPM; 53 BBL 350 CPS HEC WITH 160 FT3 20-40 OTTAWA GRAVEL; 5 BBL 350 CPS HEC POST PAD; AND 25 BBL COMPLETION FLUID. FINAL PACKOFF PRESSURE WAS 2200 PSI. ALLOWED PRESSURE TO BLEED OFF INTO THE PACK. APPLIED 400 PSI TO THE ANNULUS AND PICKED UP TO THE REVERSING POSITION. CIRCULATING OUT 56 FT3 OF GRAVEL. 104 FT3 OF GRAVEL IN PLACE BEHIND THE SCREEN (107% THEORETICAL). CONTINUED TO REVERSE CIRCULATE THE TUBING WHILE WAITING FOR THE GEL TO BREAK. DROPPED DOWN TO THE CIRCULATING POSITION AND RETESTED THE PACK TO 2000 PSI-SLOW BLEEDOFF. CLOSED PORT WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE MW ETD COMMENTS PAGE 9 12/13/90 (CONT.) 12/14/90 12/15/90 12/16/90 76 PCF 73 PCF 73 PCF 73 PCF 6440' 6440' 6440' 6440' COLLAR AND TESTED SAME TO 2000 PSI. RIGGED DOWN SURFACE LINES AND PULLED OUT WITH GRAVEL PACKING TOOLS. RIGGED UP WlRELINE AND RAN GRAVEL PACK LOG. PACK WAS UNIFORM. RIGGED DOWN WlRELINE. RAN IN HOLE TO LAY DOWN DRILL PIPE. PULLED OUT OF HOLE LAYING DOWN 3-1/2" DRILL PIPE AND TOOLS. RIGGED TO PICK UP 3-1/2" TDS TUBING. RAN IN PICKING UP 162 JOINTS OF 3-1/2" TBS TUBING. FLUID LOSS TO FORMATION INCREASED TO 15 BPH. REDUCED BRINE WEIGHT TO 73 PCF TO REDUCE FLUID LOSSES. MONITOR WELL. CIRCULATED TO BALANCE THE WELL. MONITOR WELL FOR FLOW-NO FLOW OR FLUID LOSS. TRIP FOR COMPLETION. CHANGED TOP PIPE RAMS TO 3-1/2" DUAL BLOCKS AND PRESSURE TESTED THE DOOR SEALS. PICKED UP KOBE PUMP CAVITY AND BO'lq-OM HOLE SSSV JEWELRY (ASSEMBLY HYDROTESTED TO 5000 PSI ON DECK). RIGGED UP DUAL HYDROTEST EQUIPMENT. RAN 3-1/2" TUBING COMPLETION HYDROTESTING BOTH STRINGS TO 5000 PSI. STABBED INTO THE SC-1 PACKER AT 5905' DIL (5902' TM). PRESSURE TESTED THE ANNULUS TO 500 PSI TO CONFIRM SEALS WERE HOLDING IN THE SC-1 PACKER. PICKED UP AND SPACED OUT WITH PUPS TO LAND THE TUBING WITH 10K ON THE PACKER AND 10K MORE WEIGHT ON THE LONG STRING THAT THE SHORT STRING, LANDED COMPLETION AND LOCKED DOWN THE HANGERS. COMPLETION ASSEMBLY AS FOLLOWS; MULESHOE AT 5912' TM; TOP OF SEAL ASSEMBLY AT 5900' TM; TOP OF "XN" NIPPLE AT 5897' TM; TOP OF 2-7/8 .... XA" SLEEVE AT 5879' TM; TOP OF 3-1/2 .... RA" SLEEVE AT 5872' TM; AND TOP OF KOBE BHA AT 5845' TM. RAN IN HOLD DOWN PINS AND PACKED OFF HANGER, PRESSURE TESTED THE ANNULUS TO 1000 PSI AGAINST THE UPPER PIPE RAMS. INSTALLED BACK PRESSURE VALVES, NIPPLE DOWN BOPE. INSTALL TREE AND TEST TO 5000 PSI, RIG UP SLICK LINE AND TEST LUBRICATOR TO 3000 PSI. PULL "AVA" DUMMY SSSV, OPENED 2-7/8 .... XA" SLEEVE AT 5879' TM. SET DUMMY SSSV. CHANGED OVER ANNULUS TO INHIBITED FIW PACKER FLUID. PULLED DUMMY SSSV. CLOSED 2-7/8 .... XA" SLEEVE AT 5879' TM. PRESSURE TESTED ANNULUS TO 1000 PSI. RAN IN WITH SSSV. WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE MW ETD. 12/17/90 64 PCF 6440' 12/18/90 73PCF 6440' REC£i'V[D AlasJ~a Oil & Gas Co~s. Cor~n]ission Anchorage 12/19/90 73 PCF 6440' 12/20/90 73 PCF 6440' PAGE 10 COMMENTS WIRELINE SET SSSV. TRIP FOR STANDING VALVE AND SET SAME. RIGGED UP LUBRICATOR WITH JET PUMP. DISPLACED PUMP INTO KOBE BHA WITH POWER OIL. PRODUCTION WORKING TO TEST THE JET PUMP. PREPARE TO SKID RIG TO WELL 17595 #7, LEG #4, SLOT #4. WORK ON RIG SKID SYSTEM POWER UNIT. WELL #5 JET PUMP NOT PRODUCING PROPERLY-PRODUCTION TRIPPED PUMP 3 TIMES. STAND BY OVER WELL #5 TO VERIFY ON PRODUCTION BEFORE SKIDDING RIG. RIGGED UP SLICKLINE ON WELL #5 AND TEST TO 3000 PSI. RAN IN WITH SLICKLINE AND SET DOWN AT 5820' WLM (26' ABOVE PUMP CAVITY AT 5846' TM). RETRIEVED PUMP WITH WlRELINE. RAN IN 2.313" IMPRESSION BLOCK ON WIRELINE AND TAGGED THE STANDING VALVE IN THE KOBE BHA TO OBTAIN A DEPTH TIE-IN. FLAGGED LINE AND TRIPPED FOR A DUMMY PUMP. DUMMY PUMP SET DOWN 20.5' ABOVE THE STANDING VALVE (FIRST SEAL BORE IS 21.30' ABOVE STANDING VALVE). PULLED DUMMY PUMP. CHANGED OVER TUBING STRINGS TO 73 PCF CACI2 BRINE AGAINST THE STANDING VALVE. SHEAR EQUALIZING PINS AND PULLED STANDING VALVE. RAN IN ON WIRELINE WITH "RA" SHIFTING TOOL AND OPENED SLEEVE AT 5872' TM. PREPARED TO CHANGE OVER ANNULUS TO 73 PCF BRINE. DISPLACED ANNULUS WITH 73 PCF CACL2 BRINE AT 2 BPM CHECKED WELL FOR FLOW. BUILT SURFACE VOLUME AND CIRCULATED WELL TO BALANCED OUT BRINE WEIGHT. INSTALLED BACK PRESSURE VALVES. NIPPLED DOWN AND REMOVED 3-1/2" DUAL TREE. NIPPLE UP BOPE AND RISER. TEST TO UNOCAL SPECIFICATIONS TO 500 PSI (LOW) AND 3000 PSI (HIGH). RIGGED UP SLICK LINE ON LONG STRING AND RAN STANDING VALVE IN KOBE BHA AT 5865' WLM. STANDBY FOR BOAT WITH EQUIPMENT AND PERSONNEL. PULLED OUT OF SC-1 PACKER. OBSERVED WELL- NO FLOW. RESPACED TUBING WITH SEAL LOCATOR SUB 18" ABOVE THE TOP OF THE PACKER Q 5905' DIL. RIGGED UP SLICKLINE AND RAN DUMMY PUMP TO 5861' WLM. PRESSURE TESTED LONG STRING TO 3000 PSI. PRESSURE BLED OFF WITH RETURNS FROM THE SHORT STRING. MADE TWO WlRELINE RUNS TO RECOVER PUMP-NO GOOD. REVERSED POWER OIL AND UNSEATED DUMMY PUMP WITH 3500 PSI. RECOVERED PUMP WITH WlRELINE WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE MW 12/20/90 (CONT.) ETD 12/21/90 73 PCF 6440' 12/22/90 73PCF 6440' PAGE 11 THREE O-RING SEALS MISSING. CIRCULATED TUBING AND RECOVERED O-RINGS. REDRESSED DUMMY AND RAN ON WlRELINE TO 5844' WLM. ATTEMPT TO JAR DOWN WITH NO SUCCESS. ATTEMPT TO PRESSURE TEST LONG STRING-NO GOOD. UNSEATED PUMP WITH POWER OIL. RECOVERED PUMP WITH WlRELINE-FIVE O-RING SEALS MISSING. CIRCULATED TUBING AND RECOVERED FOUR O-RINGS. LOCATED STANDING VALVE IN BHA AT 5865'. WLM. REDRESSED DUMMY WITH SINGLE TOP SEAL AND RAN ON WlRELINE TO 5848' WLM. ATTEMPT TO JAR DOWN WITH NO SUCCESS. ATTEMPT TO PRESSURE TEST-NO GOOD. UNSEATED DUMMY WITH POWER OIL. RECOVERED DUMMY PUMP WITH WlRELINE. PRESSURE TESTED DUMMY PUMP ASSEMBLY AT SURFACE. SMALL LEAK AT CONNECTIONS, BUT VERY SMALL COMPARED TO DOWN HOLE TESTS. EQUALIZED AND RECOVERED STANDING VALVE AT 5865' WLM. UNLOAD TUBING AND PULL SEAL ASSEMBLY OUT OF PERMANENT PACKER AT 5905' DIL. CIRCULATED BRINE TO BALANCE THE WELL. PULLED DUAL 3-1/2" TDS PRODUCTION STRINGS AND KOBE BHA. ATTEMPTED TO INSTALL DUMMY PUMP IN BHA ON DECK-NO GOOD. ATTEMPT TO INSTALL DUMMY PUMP IN REPLACEMENT BHA-NO GOOD. SENT DUMMY PUMP TO MACHINE SHOP. TEST BOPE TO UNOCAL SPECIFICATIONS. INSTALLED SSSV TAIL ASSEMBLY ON NEW BHA. STANDBY FOR REPLACEMENT DUMMY PUMP. ATTEMPT TO TEST REPLACEMENT DUMMY PUMP IN NEW BHA USING SEVERAL DIFFERENT SEAL AND SPACING CONFIGURATIONS-NO GOOD. KOBE REPRESENTATIVE DETERMINED BHA IS NOT FIELD REPAIRABLE. MAKE UP BAKER SEAL ASSEMBLY ON 3-1/2" TDS TUBING AND RAN IN TO 5890' TM. CIRCULATED WELL AND STABBED INTO THE BAKER SC-1 PACKER AT 5901' TM. TESTED SEALS TO 1000 PSI. SECURED WELL WITH BOTTOM PIPE RAMS. RAN IN MANUAL LOCKS ON RAM BLOCKS. INSTALLED TUBING SAFETY VALVE AND 2" PLUG VALVE TO SECURE TUBING STRING. BLEW DOWN ALL LINES AND SECURED RIG. SUSPE.ND. ED OPERATIONS ON WELL ADL 17595 -//-5 AT 2400 HOURS ON 12/22/90. WELL HISTORY PLATFORM BAKER 17595 WELL #5 (BA-5) DATE 12/26/90 12/27/90 12/28/90 MW 73 PCF 73 PCF PCF ETD 6440' 6440' 6440' PAGE 12 RESUMED OPERATIONS ON WELL ADL 17595 #5 AT 1000 HOURS ON 12/26/90. OPENED MANUAL LOCKS ON BOq-TOM PIPE RAMS. CONFIRMED TUBING AND ANNULUS WERE DEAD. UNSTAB TUBING FROM SC-1 PACKER AT 5901' TM. CIRCULATE WELL THROUGH CHOKE TO BALANCE FLUID. WELL STATIC. PULLED AND STAND BACK 3-1/2" TUBING. PRESSURE TEST KOBE BHA WITH DUMMY PUMP TO 5000 PSI-OK. PULLED SSSV AND INSTALLED DUMMY VALVE. MAKE UP BHA AND PLUG TEST SAME TO 5000 PSI. RAN DUAL 3-1/2" TBS PRODUCTION TUBING HYDROTESTING TO 5000 PSI. CONTINUED RUNNING DUAL HYDRAULIC PUMP COMPLETION. SPACED OUT AND LANDED TUBING WITH THE SEAL LOCATOR 18" ABOVE THE SC-1 PACKER AT 5901' TM. PRESSURE TESTED SEALS TO 1000 PSI. RIGGED DOWN HYDROTEST UNIT. RIGGED UP WlRELINE UNIT. RAN KOBE STANDING VALVE AND SET SAME IN BHA AT 5866' TM. TRIP FOR KOBE DUMMY PUMP. TEST TUBING TO 3500 PSI AGAINST THE STANDING VALVE. RAN DUMMY PUMP AND SEATED ON STANDING VALVE. TESTED DUMMY TO 3500 PSI. PULL DUMMY PUMP. PULL KOBE STANDING VALVE. OPEN "RA" SLEEVE AT 5867' TM. RIG DOWN WlRELINE. INSTALL BACK PRESSURE VALVES AND NIPPLE DOWN BOPE. INSTALL AND TEST PRODUCTION TREE TO 5000 PSI. PULLED BACK PRESSURE VALVES. DISPLACE ANNULUS WITH FIW WITH 0.4% NALCO 3900. DISPLACED TUBING STRINGS WITH FIW. RIGGED UP WlRELINE AND CLOSED "RA" SLEEVE AT 5867' TM. PRESSURE TESTED SLEEVE TO 1000 PSI. RAN DUMMY STANDING VALVE AND SET AT 5866' TM. INSTALLED KOBE JET PUMP. CONFIRMED PUMP WAS ON SEAT WITH WlRELINE. ATTEMPT TO CIRCULATE THROUGH JET PUMP-APPEARS TO BE PLUGGED. RIGGED DOWN WlRELINE. CIRCULATED OUT JET PUMP AND RECOVERED SAME IN LUBRICATOR. ORIFICE OF JET PUMP WAS PLUGGED. REPAIRED PUMP AND DISPLACED SAME INTO THE BHA WITH POWER OIL. CONFIRMED PUMP WAS ON SEAT AND PUMPING. REMOVED LUBRICATOR AND INSTALLED TREE CAP. RETURNED WELL TO PRODUCTION. RELEASED RIG FROM WELL ADL 17595 #5 AT 2200 HOURS ON 12/28/90. C: n EQUIPMENT ~ .-'RVICE5 LOCATION: 3P£RATOR FAX// UNOCAL ALASKA REP. PH~ DON CHUDANOV / EVAN HARNESS FIELD WELL NO. MIDDLE GROUND SHOAL B-5 STATE LEA'~" ALA_~KA .Oki)lNG DOCK rdO NAM[ PLATFORM BAKER DATE SUSklllllEO JOB ~ DECEMBER 13. 1990 PR£PARED BY DARRYL SNOW PH~ 563-0885 ~IZE WEIGHT CASING 9 5/8' 43,5 GRADE LINER THREAD J TUBING i WKSTRG 3 1/2' IF N ~. DEPTH 5905,96 5910.70 5915.97 5917,82 5918,57 5940.35 5941,07 597[,37 6001,67 6031,97 8 6062,25 6094,53 6186,88 6159,1.4 ,~191,44 6223,74 6259,03 6288,31 63P0,59 6352.85 6385,14 9 641%48 [0 6418,44 11 6428,75 6430.00 NF!RMATiON: j LENGTH 4,74 5,27 1.85 21.78 ,72 30,30 30,30 30,30 30,88 32.28 3P,P9 32.32 32,20 32.30 32.29 32,E:8 38.28 32,26 32,29 32,28 t,08 [0.31 L,25 3,53 O, D, 8,44 6,63 7,00 7,00 6.63 7.38 5,50 5,50 5,50 6,11 6,11 6,11 6,11 6.11 6,11 6.11 6,11 6,11 6.11 GA1 6,06 6,11 6,00 8,13 4,75 5,75 4,75 4,75 5.75 4.95 4.95 4 4.95 4,95 4,95 4.95 4.95 4.95 4.95 4,95 4,95 4,95 4,95 4.95 4,95 8,87 4,95 3,00 4,75 bOklP. FLUID SEE BELOW SCREEN SIZE 5 I/2' .012 GAGE IBHT t ' .INHIBITOR i COATING AND $1Z£ j 20-40 BAKER LOW FINE l~kX. DEV. IZON£ DEv'. I I DESCRIPTION BAKER MODEL 'SC-i' 96A4-47 GRAVEL PACK PACKER UPPER EXTENSION SLIDING SLEEVE SEAL BORE LOWER EXTENSION CROSSOVER SUB BLANK PIPE BAKERWELD D 1/2' .012 GAGE SCREEN O-RING SEAL SUB BAKERWELD 5 1/2' ,012 GAGE LOWER TELL TAIL SCREEN 'S-22' SNAP LATCH SEAL ASSY ~//2 EXTRA SEAL UNITS BAKER MODEL 'D' SUMP PACKER =t 365-6405 \UNOCAL\gA5 · lanuarv 24. 1991 Baroid Drilling Fluids, Inc. [ir. Don Chudanov Unocal Oil g Gas Divzsion P.O. Box 190247 Anchorage, Alaska 99519-0247 Workover/Completion Fluids Recap Unocal Baker Platform BA-5 Dear Mr. Chudanov: Enclosed is the material usage and cost associated with the above referenced well. Please refer to the recao for specific details .~n reference to the operations involving the completion fluid. The costs are broken down as follows: Calcium Chloride - Potassium Chloride - Sodium Chloride - 99,443.52 18,383.40 29,106.59 Total Salt Cost - $146,933.51 Technical Service - Miscellaneous Cost - $ 13,770.00 $ 2,636.00 Total Well Cost - $163,339.51 We at Baroid would like to express our appreciation of the opportunity of providing the workover and completion fluids on · the Baker Platform. If you have any questions or require any additional information, please do not hesitate to contact me. Sincerely, BAROID DRILLING FLUIDS, INC. T. Jay Olive Technical Sales Representative cc: Bush Neve' File Attachment 2000 West Int'l. Airport Road, Suite A-10 · Anchorage, Alaska 99502 (907) 248-3511 · Fax (907) 248-5390 Drilling Mud Record Baroid Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM inch at ft. WELL Baker DA-5 Workover COUNTY Kenai inch at ft. CONTRACTOR Baker Platform LOCATION Cook Inlet SEC TWP RNG inch at ft. STOCKPOINT Rig Tenders Dock DATE 12/27/90 BAROID ENGINEER Wolfe, Wal lace TOTAL DEPTH ft. DATE DEPTH A/EIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS M/ sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water % Mud Strip - Pm I Pr/ p,/p~ CI CA REMARKS AND TREATMENT 1 9 90 feet C I F oF ~F 10 mi. APl __:F 32.ds % % % me/mt Meter Xj MI ppm ppm (See Operations Sheet) 11-22 64.9 3% <C1/FIW 7.4 J 34000 11-23 74 3% <C1 SATURATED SALT BRINE 7.5I 31000( _ 11-24 74 3% <C1 SATURATED SALT BRINE 7.7 31000( _ 11-25 74.8i:~ 3% <C1 ~ATURATED SALT BRINE 7.7 31000( 11-26 74.83 3% <C1 ~ATURATED SALT BRINE 7.7 31000( 11-27 74+ 3% <C1 ~ATURATED SALI BRINE 7.7 11-28 74+ 3% <C1 ~ATURATED SALT BRINE 7.0 11-29 74+ 3% (C1 ;ATURAT--D SALT BRINE 7.7 11-30 75+ 3% (C1 ~ATURAT--D SALT BRINE 7.5 12-1 73+ 3% (C1 ~ATURAT--D SALT BRINE 7.5 12-2 73+ 3% (C1 ~ATURAT--D SALT BRINE 7.5 12-3 73+ 3% JCl ~ATURAT-_-D SALT BRINE 7.5 12-4 73+ 3% JCl ~ATURATI--D SALT BRINE 7.5 12-5 73+ 3% JCl ~ATURAT--D SALT BRINE 7.5,I 12-6 73+ 3% KC1 ~ATURAT--D SALT BRINE 7.5 3% K]I FIW SYSTEM 7.5 12-7 MIXING tEW CaC 2 3% K]I FIW SYSTEM 7.5 12-8 78 MIXING NEW CaC , 12-9 78 MIXING NEW CaC ~ 3% KC1 FIW SYSTEM 7 5 12-10 78 MIXING NEW CaC ~ 3% KC1 FIW SYSTEM 7.5 12-11 6438 77 NEW CaCl~ 3% K]~F FIW SYSTEMi 7.5 12-12 76+ NEW CACl~ 3% K'I FIW SYSTEM 7.5 12-13 76 NEW CaClo 3% K'I FIW SYSTEM! 7.5 I 12-14 73 NEW CaCI~ 3% K'I FIW SYSTEM 7.5 12-15 73 NEW CaCl~ 3% K'I FIW SYSTEMI 7.5 ! 12-16 CHAqGE ~I~LL OV-R TO FIW 12-17 STA~D B~' TO MO/E RIG CaCl2 3% KS1 F;IW SYSTEq 12-18 73 CaCo 3~ KC1 F[W SYSTEM 7.5 12-19 73 CaC ~ 3% KC1 FiW SYSTEM 7.5 12-20 73 CaC 24 3i% KC1 FIW SYSTEM 7.5 12-21 73 CaCo 3!~ KC1 FIW SYSTEM 7.5 12-22 73 CaC ~ 31~ KC1 FIW SYSTEM 7,5 12-23 73 CaC~ ~ K£1 FIW SYSTEM 7..~ 12-26 73 CaC ~ 3~ KC1 FIW SYSTEM 7.5 12-27 70 CaC 2~ 3~ KC1 FIW SYSTEM 7.5 Unocal Oil & Gas Division Baker BA-5 Material Usage and Cost MATERIAL UNIT USAGE COST/UNIT AMOUNT Calcium Chloride 100 LBS 84 $ 35.04 Calcium Chloride 80 LBS 2,754 $ 35.04 Caustic 50 LBS 1 $ 31.04 Dirt Magnet 500 LBS 1 $1,600.00 Potassium Chloride 100 LBS 630 $ 29.18 Salt 80 LBS 2,663 $ 10.93 SDI Defoamer 50 LBS 2 $ 94.37 TOTAL PRODUCT COST Technical Service Kenai Borough Tax Roundtrip Airfares Roundtrip Airfares Rework Charges 34 $ 405.00 14 $ 10.00 3 $ 50.00 3 $ 111.00 1 $ 193.22 2,943.36 96,500.16 31.04 1,600.00 18,383.40 29,106.59 188.74 $148,753.29 $ 13,770.00 $ 140.00 $ 150.00 $ 333.00 $ 193.22 TOTAL WELL COST $163,339.51 Unocal Oil & Gas Division Baker BA-5 Operations D~[E C~:>ER~T IONS 11-22 11-23 11-24 11-25 11-26 11-27 11-28 11-29 11-30 Mixed 800 bbls of 3% KC1FIW, displaces short string (78 bbls), change over to long string, displaced well monitoring until fluid clean. After circulate 3% KC1FIW around had 300 psi, shut in pressure, weight up to 72 lb/cu, ft. with salt circulated around, until back at short string, weight up to 74 lb/cu, ft., circulated and killed well. After killing well put in back pressure valves, nippled up stack, prepared to shoot off and lay down tubing, Shot tubing, pulling and laying down 3 1/2" 9.5 lbs tubing. Finished pulling and laying down 3 1/2" tubing, pick up BHA and 3 1/2" drill pipe, run in hole, shut down to work on Komie. Completed repairs Komie/B.P. unit, RIH and tag fill/B.P. @ 6256', wash and ream fill to BP @ 6409', drlg up BP, push to 6420', circulate btms up and clean up small gas bubble, RIH and push B.T. ahead to 6683'. Circulate and clean up well, POH, RIH w/bit and scraper, circulate clean, POH, RIH w/W.L., guage ring and junk basket, run B.P. and set @ 6440', RD WL. RIH w/RTTS, circulate Btms up, test casing to 2500' @ 6375', pull up and set packer @ 6190', test annulus to 3000', POH, LD RTTS, RIH w/casing scraper and wire brush, circulate Btms up, clean RTTS, prepare to mix fresh brine. Complete mix fresh brine, mix 85 bbls pill w/brine and 1 drum Dirt Magnet, pump pill and displace well w/fresh brine, all discharge of old brine to production dept. on platform, circulate and filter brine w/backer, objective <100 NTU, final reading <25 NTU. ~(IROID DRILLING FLUIDB, INC. Page 2 Unocal Oil & Gas Division Baker BA-5 Operations DAYE OPERATION8 12-1 12-2 12-3 12-4 12-5 12-6 12-7 12-8 12-09 PU 3 1/2" (9.2#) tubing. Wash 14' fill to top of BP @ 6437' (DP), circulating and filter brine, cut weight to 78-73# while circulate, POH, PUI perf tools, RIH to perf. RIH to perf, no indications of guns firing, reverse circulating tubing, circulate annulus, rig up wireline unit and fish for firing bar. Continue fish for firing bar, stick wireline, back off guns, POH cutting WL every stand. Got out of hole w/wireline, RIH fishing tools, got over the fish w/overshot, rigging up slick line to get sinker bar, will try to get bar then pull guns out of hole, still don't know if the guns have fired. Mixed 160 bbls of additional active brine (weight to 73.6 w/NaC1 3% KC1) added to active system, mixed 509 bbls of 3% KC1FIW to be shipped to baker for frac job, POH to pick up packer. Mixed frac sand 2/3% KC1 water in storage also mixed pre- pad tubing flush, pre-pad was 3% KC1 70 bbls cu. ft., fluix was 3% KCL NaCL to 73.6 lbs/cu, ft. after fracking holding back pressure until tubing pressure bleeds off. Closed in well and observed 400 psi surface pressure after frac, bull headed 72 lb/cu, ft., tail pad into formation filled tubing with 74 lbs NaC1 3% KC1 FIW. Pressure dropped to 140 psi build 650 bbls of 78 lb/cu. ft. (CaCL2 3% KCL FIW) to kill well. Pumped 78 lbs/cu, ft., fluid into well. displaced NaC1 73.6 fluid, sent returns to production killed well, POH with packer, RIH open ended tagged sand at 6218', filtering CaCl2 fluid. Pumped sand to top of perfs tagged sand, POH pickup packer, RIH w/guns shot upper perf's, POH to pick up scraper and bit, filtered 370 KC1 for frac job. BAROID DRILLIN8 FLUID~I, INC. Page 3 Unocal Oil & Gas Division Baker BA-5 Operations DAT~ OPERAT I ON~ 12-10 i2-ii 12-12 12-13 12-14 12-15 12-16 12-17 12-18 i2-i9 Mixed frac fluid and did fraced well, holding back pressure on well then to get taking pressure to bleed off. Complete frac job, POH, test BOP, RIH and tag sand @ 6078, CO sand to 6438' and circulate well to clean up and, while circulating out sand well took 160~ bbls as and in returns reduced, loss reduced, at 2400 had "0" loss from 2300 to 2400'. Complete circulate out sand, filtered brine w/Backer, complete filter, POH, PU mod "0" packer, RIH and set same, POH, PU screen assembly, RIH w/screen assembly. Perform gravel pack, POH, Rig up HLS, run density log, rig down HLS, RIH to LDDP. Complete LDDP, PU 3 1/2" production tubing, RIH to 5057', well taking fluid, circulate well and add FIW to cut weight from 76 pcf to 73 pcf, observed well, flowing slightly, circulate well again to be sure it is dead. Complete circulation, POH, XO rams to 3 1/2" dual, run 3 1/2" dual completion string. Land completion string, N.D. BOP, NU tree, change well over to FIW, catch 500 bbls (~) CaC12 brine @ 72-73 pcf, perform slick line work, prepare to move rig. Complete #5, perform slick line work on #17, stand by to move rig. Mixed 500 bbls of 73 lbs/cu, ft. CaC12 FIW, displaced tubing volume, returns going to production, RIH with wireline, opened circulating. Circulated out tubing volume, returns to surface, sheen tested and dumped 71 bbls of FIW in pits to make room for annulus returns, circulated 73 Bbls/cu. ft. CaC12 around annulus, killed well. Will pull pump out of seat re-spacing to put in tension to see if it will start, Mixed additional volume to have enough to POH. BIAKh; SAN§ C0NIROL A Baker Hughes company 4792 BUSINESS PARK BLVD. BUILDING F, SUITE 3 ANCHORAGE, ALASKA 99503 TELEPHONE (907) 563-0825 FAX NO,(907) 563-0385 Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 January 3, 1991 ATTN: Don Chudanov RE: Completed Gravel Pack Summary Platform Baker's MGS 17595 # B-5 Baker Sand Control is pleased to submit this summary of the completed gravel pack on Platform Baker's MGS 17595 # B-5. Enclosed is a detailed job report with steps and procedures that were implemented on the job. PRE-PACK LOWER 'A' ZONE INTERVAL Perfs: 198' 6192' - 6350'; 6365' - 6405' DIL Guns: 7" OD TCP guns, 8 SPF, 61 gram Gravel Pack Charges at 45° phasing Cement Retainer Depth: 6440' Retrievable Packer Depth: 6160' Volume Placed: 150 bbls Pump Rate: 12 BPM Pump Pressure: 2700 PSI Pre-Pack Sand: 20-40 Baker Low-Fine Gravel PRE-PACK UPPER 'A' ZONE INTERVAL Perfs: 54' 6085' - 6102'; 6108' - 6145' DIL Guns: 7" OD TC? guns, 8 SPF, 61 gram Gravel Pack Charges at 45° phasing Sand Plug Bottom: 6150' Retrievable Packer Depth: 6050' Volume Placed: 40 bbls Pump Rate: 12 BPM Pump Pressure: 3000 PSI Pre-Pack Sand: 20-40 Baker Low-Fine Gravel SINGLE ZONE GRAVEL PACK Perfs: 252' 6085' - 6102'; 6108' - 6145' 6192' - 6350'; 6365' - 6405' Sump Packer: 6430' Model 'D', size 194-47 Lower Tell-Tail: 10' 5-1/2" 0.012 gage Bakerweld Screen Screen Length: 340' 5-1/2" 0.012 gage Bakerweld Screen G.P. Packer: 5905' Calculated Volume: 55 barrels Actual Volume Placed: 57 barrels of 10 ppg slurry at 3 BPM Gravel Pack Sand: 20-40 Baker Low-Fine Gravel Fluids: Filtered with a D.E. press to a 2 micron absolute Polymers: A HEC Baker Clean Gel was mixed to yield a 350 cp viscosity. The gel was then cycled through a hydraulic hydrator to remove any micro-fisheyes. It was then filtered through a 25 Whatman filter paper. 3AKER SAND CONTROL CONCLUSION Overall the Single Zone Gravel Pack with the High Volume Pre-Pack Frac was very successful. By Pre-Pack fraccing the zones separately a larger percentage of excess gravel was placed prior to gravel packing thus increasing the effective inlet area radially over the entire interval. Baker Sand Control would like to thank you for your business and we look forward to providing you with quality service and products in your upcoming gravel packing and perforating completions. Sincerely, Baker Sand Control, a Division of Baker Hughes~Production Tools Inc. Darr¥11,,~now Alaska Sales Re:presentative REC ' VED Alaska 0ii & 8a$ Cons. Commbsio~ Anchorage SAKER SAND CONTROL UNOCAL ALASKA MGS 17595 #B-5 * TOOLS (SALEABLE): TOOLS (RENTAL): FILTERING: PUMPING: PERFORATING: 84,763.63 16,160.15 23,704.08 180,528.10 92,439.70 TOTAL: $397,595.66 * The TOOLS discounted the above quotation. (SALEABLE) cost represented here reflects the price awarded to Unocal for utilizing all of services as outlined in the initial price UNOCAL BAKER B-5 FILTRATION REPORT 11/30/90 NTU'S 160 3% KCL 7'4.6 PPCF 14 0 ............... '-'~ ......... ~' '---:.:-_'-_'-~ ............................................................................................................. 1 ~ 0 ............................................... :;'~"'"'-~:~:-' ...................................................................................... ~ 0 ............................................................................................................... :'::'"'~" .............................. ,.., --.. ",.... 60 ................................................................................................................................ ":'"'-':- ................ ~'~,.... ROLLING HOLE OVER UNTIL RETURNS BELOW 100 NTIJ'S ....... ~".~...~. 40 .................................................................................................................................................. 0 ..................................................................................................................................................... 0 ~ '~'"'" "-'""'"--' ................................. I ................................................. i ........................................ i .......... 1 ...... 1600 170 0 180 0 lO00 20 O0 210 0 TIME IN HOURS --"-- WELL OR PIT RETURNS ..... ~ ........ PRESS DISCHARGE FILTER RUN #1 UNOCAL BAKER B-5 FILTRATION REPORT 12\1\90 3% KCL 74.6 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS NTU'S 160 14 0 ............................ -':.- ....................................................................................................................... 12:0 ........................................... ::':':~'~'-~' ...... :-:< .......................................................................................... --~ 10 0 ............................................................... i'i:':::-:-.-....:.<...:.. ....................................................................... -. -.. 80 ................................................................................... ""'"'< ............................................................ 6o ................................................................................................... "' ...... :'"':-:...:.i.i ...................................... ,4. 0 ................................................................................................................... :':?"- ..... ::.:-:.: ..................... ,_ ..... 2:0 .................................................................................................................................................... ~5"--""'--'TT-_'~:'t'_' ................................ t .................................. i .......................................... t'": ........ .::"'"-"'"' ' ":'~ '~ ............ ~_ ...... 0 0800 0900 1000 1100 12:00 1,.-300 1400 1,500 TIME IN HOURS --'-- WELL OR PIT RETURNS .......... ~ ..... PRESS DISCHARGE FILTER RUN #2 1600 160 NTU'8 UNOCAL BAI<ER B-5 FIL.TRATION REPORT 12\2\90 3% KCL 73.6 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS 140 ......................... - · -- 12 0 ............................................ :":"~:':':.:-.i..i ................................................................................................ 10 0 ......................................................................... '-"-~' 'ti ................................................................... . 8 0 ........................................................................................... '7:':-.-- ........ :-:..Z.]...' ............................................. 40 ............................. , ..................................................................................................... ':'~:': ...... 0200 0300 0400 0500 0600 0700 0800 0900 1000 TIME IN HOURS -'-"- WELL OR PIT RETURN8 ........ l ......... PRES8 DISCHARGE FILTEI~ RUN #8 160 NTU'S UNOCAL BAKER B-5 FILTRATION REPORT 12\3\90 3% KCL 74.2 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS 140 ............... -:-'~'-' ............................................................ 120 ................................................. ':'"' '~.., 100 ............................................................. "-- .~., 0 .................................................................................................................................................... 0 .......................................... J ...................................... ~i ..................................... I .................................... i... l 1500 1600 1700 1800 1900 2000 2100 2200 TIME IN HOURS '--"-- WELL OR PIT RETURN8 ........ ~ ...... PRES8 DISCHARGE FILTEI:! RUN #4 UNOCAL BAKER B-5 FILl'RATION REPORT 12\5\90 NTU'8 160 L ... 14 0 ....... :'"': .... :~. ................................................ , ................................................................................... ~,,.._ 12 0 .......... '-:':~'~," - ~''%'''K''c''L' .............. , ................................................................................... ~'..,.., 73.6 PPCF 100 ................................ '?'x ............................. · .................................................................................... 80 ....................................... :"~"-~ .................... , .................................................................................... '"'",1....., "- FILTERING 8% KCL FOR FRAC 60 ................................................... '"' ........... %. '- 460 BBL GOING TO BLENDERS MAINTAINS 15 NTU WHILE ON LINE 0 ..... "-'~'_-J'-"'"'"'""i"~ .................. i:": .......... :J: ....... -_i._:....::..:::....~ ............... i .................. i .............. i ....... ~" ' i i ..... i ..... ~ ... I... 1800 lg002000 2100 2200280024000100020008000400050006000700080009001000 FILTEI:~ FIUN #6 TIME IN HOURS - WELL OR PIT RETURN8 ...... i ......... PRESS DISCHARGE 160 NTU'8 UNOCAL BAKER B-5 FILTRATION REPORT 12\6\90 3% KCL 741.2 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS 140 .......................... :'~'-~.' .................................................................................................................... . 120 "" ............................................. -:---<..:.~.. ................................................................................................. . --...__ -.... 100 ................................... ............. .._..:_- ..................................................................... ................................. ' .... ' "'""'~...._... 80 ........................................................................ <: .......................................... '"'"'"'.R... .-~_ 60 ....................................................................................................................... '.':';-,'.-..~:..- ...................... . ~.., '"-........ -....... 40 ........................................................................................................................................... :'.-.--.;. ..:-.-:.:.~. 20 ..................................................................................................................................................... 0 .......................... -J' ............................. i ............................................ I' .............................. 1 .................................. i"" ...... ~ ................................ r ............... 0400 0500 0600 0700 0800 0900 1000 1100 1200 TIME IN HOURS --'-- WELL OR PIT RETURNS ......... ~ ......... PRES8 DISCHARGE FILTER RUN #6 2OO NTU'8 UNOCAL BAKER B-5 FIL.TR^TION REPORT 12\7\90 3% KCL 73.6 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS 150 lO0 5O 0 0400 0500 0600 0700 0800 0900 1000 TIME IN HOURS FILTER RUN ~? ---- WELL OR PIT RETURNS ....... ~ ........... PRESS DISCHARGE 2OO NTU'8 UNOCAL BAKER B-5 FILTRATION REPORT 12\8\90 ROLLING CaCL2 FROM PIT #1 TO PIT #5 150 100 50 0 I I I 0600 0700 0800 0900 1000 TIME IN HOURS 1100 1200 1300 WELL OR PIT RETURNS ........... ~ ........ PRESS DISCHARGE FILTER RUN ~8 UNOCAL BAKER B-5 FILl'RATION REPORT 12\9\90 NTU'S 160 ROLLING OVER FROM PIT #1 TO PIT #5 140 ........................................................................ ..r .................................................................................... ,,' 120 ~":.: .................................................................... / ............................................................................ ii'i'":":":.;-,.. CaCl~ 76.3 PPCF/ . 100 .-. i ROLL?NG HOLE OVER 8 0 ................... ':"' ........... ,.": ..... · .............................. 7 ..;- .-....~ ,=. ................... i'. .................. , ................. 40 ..................................................................................................................................................... 2400 .0100 0200 0300 07'00 0800 0900 lOOqt~~ "' i'" ~ ~ 0400 0500 0600 TIME IN HOURS '--'--- WELL OR PIT RETURNS "' "" PRESS DISCHARGE FILTER RUN #g 140 UNOCAL BAKER B-5 FILTRATION REPORT 12\10',,,90 ROLLING CaCl 2OVER UNTIL UNDER 100 NTU RETURNS NTU'S 120 100 80 60 4O 2O 0 0100 ! ] [ I_ j 0200 0300 0400 0500 0600 07'00 TIME IN HOURS ---'-- WELL OR PIT RETURNS "':" PRESS'DISCHARGE FILTER RUN #10 100 NTU'S UNOCAL BAKER B-5 FILTRATION REPORT 12\11\90 ROLLING OVER Cae1 2UNTIL UNDER 100 NTU RETURNS 80 6O 40 20 0 1700 FILTEI:i I~UN #11 I I I j. 1800 1900 2000 2100 2200 TIME IN HOURS --'--- WELL OR PIT RETURNS .... ~ PRESS DISCHARGE 180 UNOCAL BAKER B-5 FILTR^IION REPORT 12\12\00 CaCl276.2 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS NTU'S 160 140 120 100 80 60 40 20 0 02O0 0300 0400 0500 0600 OTO0 0800 0900 1000 TIME IN HOURS --'-- WELL OR PIT RETURNS '"~" PRESiS DISCHARGE FILTEI~ RUN #12 160 UNOCAL BAI<ER b-5 FILTR^TION REPORT 12\13\90 CaCl 276'2 PPCF ROLLING HOLE OVER UNTIL UNDER 100 NTU RETURNS NTU'S 140 120 100 8O 6O 40 20 0 0400 ... '-... ........................................................ ':~-_~:.:_ ....................................................................................... .... "-.,-.....~... -'~... '"-.-_~.. FLUID FOR GRAVEL PACK L 'l_ -1 [ ..................... T-'.~ ......... ::".-t ............................ .-~ ..-].. ..... ~ .I ...~,. ...... ~ ~-..-i: ~_.-_. ..... _.. 0500 0600 0700 0800 0900 1000 1100 1200 TIME IN HOURS f' WELL OR PIT RETURN8 ........ ~ ......... PRES8 DISCHARGE FILTEI~ RUN #13 3-1/2", FROM 5910.46 5898.61 5896.92 5895.56 5880.72 5877.48 5875.68 5875.01 5870.76 5867.44 5841.19 5839.05 5829.00 49.77 39.75 35.75 33.75 32.75 32.00 9.2#, TO 5898 5896 5895 5880 5877 5875 5875 5870 5867 5841 5839 5829 49 39 35 33 32 32 0 TUBING DETAIL BAKER PLT MGS 17595#5 12/28/90 N-80 TDS TUBING WITH SP CL COUPLINGS LONG STRING LENGTH JOINTS DESCRIPTION .61 11.85 BAKER SEAL ASSY W/MULE SHOE .92 1.69 CENT SUB, 3-1/2" x 2-7/8" .56 1.36 OTIS XN, 2.205" NO-GO .72 14.84 PUP 2-7/8" 6.4t N-80 BUTT .48 3.24 2-7/8" OTIS XA SLEEVE .68 1.80 2-7/8" AVA SSSV NIPPLE .01 0.67 3-1/2" EUE x 2-7/8" BUTT XO .76 4.25 PUP 3-1/2" 9.2# N-80 EUE 8RD .44 3.32 3-1/2" OTIS RA SLEEVE .19 26.25 3" KOBE BHA #ANC1540 .05 2.14 3-1/2" TDS x 3-1/2" EUE XO .00 10.05 PUP 3-1/2" 9.2# TDS .77 5779.23 185 3-1/2" 9.2# TDS .75 10.02 PUP 3-1/2" 9.2~ TDS .75 4.00 PUP 3-1/2" 9.2# TDS .75 2.00 PUP 3-1/2" 9.2# TDS .75 1.00 3-1/2" BUTT x 3-1/2" TDS XO .00 0.75 CIW TBG HANGER .00 32.00 LANDED BELOW ZERO FROM 5841.19 5833.09 5831.09 5829.04 49.98 39.94 '35.94 33.94 32.75 32.00 SHORT STRING TO LENGTH JOINTS DESCRIPTION 5833.09 8.10 PUP 2-3/8" 4.6# N-80 EUE 8RD 5831.09 2.00 3-1/2" TDS x 2-3/8" EUE ×O 5829.04 2.05 PUP 3-1/2" 9.2# N-80 TDS 49.98 5779.06 185 3-1/2" 9.2# N-80 TDS 39.94 10.04 PUP 3-1/2" 9.2# N-80 TDS 35.94 4.00 PUP 3-1/2" 9.2# N-80 TDS 33.94 2.00 PUP 3-1/2" 9.2~ N-80 TDS 32.75 1.19 3-1/2" BUTT x 3-1/2" TDS XO 32.00 0.75 CIW TBG HANGER 0.00 32.00 LANDED BELOW ZERO NOTES: LONG STRING MULE SHOE BOTTOM AT 5910.46' TM CIW HANGERS ARE 3-1/2" BUTT-DOWN, 3-1/2" EUE 8RD-UP TOP OF KOBE BHA AT 5841' TM SEAL ASSY LOCATOR SUB LANDED 18" ABOVE SC-1L PKR 2012 ,-_ BAKER SC- 1 PACKER AT 5906 5,5 15,5//J55 ,012" WIRE WRAP LINER GRAVEL PACKED 20-40 MESH OTTAWA SAND BAKER MODEL D SUMP PACKER 64.,50 BRIDGE PLUG AT 644.0 I A TOPS 1 CIW DUAL HN~3 3,5 8rd TOP BUTt BTM 32 2 3.5 BUT~ BY TDS CROSS OVER 3 ,:3.5 9.2i~ N-80 'rDS TUBING 4 3.5 TDS BY ~d CROSS OVER 32.75 33,75 3839 5841 5 3" KOBE "DBD" BI'lA ~,NC 1540 601TS 3,5 8rd RA SLEEVE ~121EA25623 OPEN UP 73,5 9,2~ N-80 8rd PUP 8 3.5 8rd BY 2.875 BUTT CROSS OVER 9 2,875 AVA SSSV NIPPLE 2.312 I.D, IOOTIS 2 7/8 BLrl'r X-A & 121X930874800 OPEN UP! .. 112 7//8 BUTT PUP 120T15 X-N 2,313 X-N 2,205 NG 5895 13CENTRALIZER SUB 3,50,D, 2,5 I,D, 8 3/8 FINS (3) 5896 IcBAKER SEAL ASSEMBLY (MULE SHOE AT 5910) 5898 5867 5870 5875 5876 5877 5881 TOPS A ClW 3.5 DUAL HANGER BUTT BTM 8rd TOP 32 B 3.5" BUTt PIN BY' 8rd PIN CROSS OVER 32.75 C 3.5" 9.2i~ N-80 TDS TUBING 33.9¢ D 3.5" TDS BY 2.375 8rd CROSS OVER 5831 E 2.,375 8rd PUP 5833 DUMMY GUTTED IN KOBE BHA AS OF 12/28/90 WHEN WELL TURNED TO PRODUCTION DRILLING FORMAN EVAN K. HARNESS NOTE IN SSSV NIPPLE STANDING VALVE OVER 2012' BAKER SC-1 PKR O 5906' s- s.s# -5s 0,012" WIRE WRAPPED BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR ~ 6430' TUBING DETAIL LONG STRING (POWER ~UID) 2) 3-1/2 BUTr PIN x 3-1/2 TDS PiN X-OVER · 32,75' 3) 3-1/2" 9.2# N-80 rog, TDS W/ SP CL CPLGS 4) 3-1/2 TDS BOX x ,3-1/2 EU nD PIN X-OVER · 5839' 5) KOBE 3" MODEL "D" BI-IA O 5841' SHORT STRING (PRODUCTION) A) ClW HANGER, BUTTRESS ~ 32' B) 3-1/2 BUTT PIN x 3-1/2 TDS PIN X-OVER · 32.75' C) 3-1/2" 9.2# N-80 Tag, TOS W/ SP CL CPLGS D) 3-1/2 TDS BOX x 2-3/8 EU 8RD PIN X-OVER · 5831' E) 2-3/8" 4.6# N-80 PUP EU nD · 5833' TAIL ASSEMBLY 6) 3-1/2- Eu no ors '~- ~E~ · $8s7' 7) 3-1/2" 9.2# N-aO EU 8RD PUP · 5870' 8) ;3-1/2 EU 8RD BOX x 2-7/8 BUTT PIN X-OVER · 587.' 9) 2-7/8" AVA SAFETY VALVE NIPPLE · 5876' 10) 2-7/8" BUTT OTIS '~,A" SLEEVE O 587? 11) 2-7/8" 6.4# N-80 BUn' PUP · 5881' 12) 2-7/8" BUn' ORS '"XN" NIPPLE · 5895' 13) sm As~ w/2-7/8- Burr BOX UP ( lO.O' ) · 5898' 14) U~E SHOE ~; 5S10' "A" ZONE INTERVAL 6085'- 6102' 6108'- 6145' 6192'- 6350' 6395'- 6405' CUT RET ~ 6440' =a~ Cor~s C, , , 'Z~Cl~ora#e' °r~/SS/on PERFS F/ 6448'- 7125' ~ INTERVALS ~ 7565' '~;~5~ ~ BAKER MODEL f BP 7" 29# ~ 11127' / PERFS F/ 7730'- 8634' ~ INTERVALS CMT RET O 8677' PERFS F/ 8690'- 9150' ~ INTERVALS CMT RET ~ 10200' ADL 17595 WELL NO. 5 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dbe UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1-15-91 -~ 2. 0" ,~I, ooo ocr DOT ~- 15o- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Pluggi.ng __ Time extension __ Stimulate Change approved program __ Pull tubing .i5_ Variance Perforate 2. Name_o.f O. peratoL.., k"T)/~(~e'~U: ~ × 671~aJ;u~v~)(~"°~ onion ul± Company of Californi ! ! Exploratory __ 3'Addre~.o. BOX 190247, Anch., AK, 991519-0~/graphic- 7'~rF~/~a~)e;595 r Service __ feet 4. Location of well at surface Leg #1, Conductor #6 1934' FNL & 550' FWL, Sec. 31, T9N, R12W, SM At top of productive interval Top of "A" zone at 6225' MD 581' FSL & 918' FWL, Sec. 30, T9N, R12W, SM At effective depth Retainer at 6411'MD 671' FSL & 931' FWL, Sec. 30, T9N, R12W, SM At total depth TD at 11,218' MD 725' FSL & 827' FWL, Sec. 30, T9N, R12W, SM 8. Well num~i~ll No. 5 9. Permit number 65-38 10. APl number 50-- 733-10071 11. Field/Pool Mid. Ground Shoal 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 595 ' Conductor 2012 ' Surface 7565' Intermediate Production 3767 ' Liner Perforation depth: measured true vertical ,feet Plugs (measured) 11,128 ,feet 10,396 feet Junk (measured) 6,411 'feet 5,692' Size Cemented 20" 798 SXS 13-3/8" 2764 SXS 9-5/8" 1950 SXS 7" 1400 SXS See attached Tubing (size, grade, and measured depth) 3-1/2" , Packers and SSSV (type and measured depth) 9.2#, N-80 None Measureddepth ~ueve~icaldepth 595' 595' 2012' 1952' 7565' 6842' 7360'-11127' 6637'-10395' RECEIVED Butt; LS @ 6048' SS @ 5995' 13. Attachments Description summary of proposal ..z_ Detailed operations program __ BOP sketch 14. Estimated date_for comm.encing op. eration November 27, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x_._ Gas __ Suspended __ Service 17, I hereby R{'J~ S -~~~-~ .~ ~ ~ certify that thftforegoing is true. and correct to the best of my knowledge. Signed GA ~3S~ Title REGIONAL DRILLING MAN~%a~eER FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-. ,z~, 4. Approved by order of the Commission ORIGINAL SIGNED LONNIE O. SMITH Approved Copy Returned _ JApproval No.~ _ -/~,~, Commissioner Date SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 MGS 17595 #5 PERFORATION RECORD "A" ZONE 6,225'-6,340'MD "B" ZONE .6,448'-6,453'MD .6,460'-6,475'MD .6,520'-6,570'MD .6,595'-6,650'MD .6,708'-6,723'MD "C" ZONE .6,805'-6,855'MD .6,875'-6,915'MD '6,935'-6,975'MD .6,995'-7,020'MD "D" ZONE '7,110'-7,125'MD "F" ZONE 7,730'-7,760'MD 7,885'-7,910'MD "G" ZONE 8,040'-8,255'MD 8,285'-8,430'MD 8,478t-8,540'MD 8,560'-8,602'MD 8,620'-8,634'MD 8,690'-8,935'MD 9,080'-9,150'MD *CEMENT SQUEEZED 5,509'-5,622'TVD 5,728'-5,733'TVD 5,740'-5,755'TVD 5,800'-5,849'TVD 5,874'-5,929'TVD 5,986'-6,001'TVD 6,083'-6,133'TVD 6,153'-6,193'TVD 6,213'-6,253'TVD 6,273'-6,298'TVD 6,388'-6,403'TVD 7,007'-7,037'TVD 7,162'-7,187'TVD 7,316t-7,531'TVD 7,561'-7,706'TVD 7,754'-7,816'TVD 7,836'-7,878'TVD 7,896'-7,910'TVD 7,966'-8,210'TVD 8,355'-8,425'TVD MGS 17595 #5 WORKOVER PROCEDURE (9-12-90) · · ~ ~ ~ ~ · · · 10. 11. 12. 13. 14. 15. 16. MOVE RIG OVER MGS 17595 #5, LEG #1, SLOT #6. KILL WELL WITH COMPLETION FLUID. INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP BOPE. PULL AND LAY DOWN DUAL KOBE PRODUCTION STRING. DRILL CEMENT RETAINER AT 6411' AND PUSH TO BOTTOM. RUN BIT AND SCRAPER TO 7339'. (TOP OF 7" LINER). SET RETAINER AT 6510' TO ISOLATE LOWER COMPLETION. PRESSURE TEST 9-5/8" CASING WITH RTTS PACKER. CHANGE OVER TO CLEAN COMPLETION FLUID. REPERFORATE "A" ZONE UNDERBALANCED WITH TUBING CONVEYED GUNS FROM 6085' TO 6480' AT INTERVALS. FRACTURE STIMULATE "A" ZONE IN THREE STAGES. SET SUMP PACKER AT 6500'. RUN 6" OD GRAVEL PACK LINER ASSEMBLY WITH TOP PACKER. GRAVEL PACK THE ZONE FROM 6085' TO 6480'. RUN DUAL KOBE PRODUCTION STRING WITH PUMP CAVITY AT 6050'. REMOVE BOPE AND INSTALL DUAL TREE. RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 2870 PSI AT 6375' TVD. WORKOVER FLUID WILL BE FILTERED INLET WATER WITH 3% KCL AND NACL AS REQUIRED FOR WELL CONTROL. BELL NIPPLE 5ooo PSi ANNULAR 1 FLOWLINE ! I PIPE RAMS BLIND RAMS I I 1 13-5/8" 3M FLANGE ADAPTER 3M x 5M 13-5/8" 5M FLANGE 3" KILL LINE WITH TWO 3" 5M VALVES I (J; KILL LINE FROM MUD PMP & CEMENT UNIT [ PIPE RAMS I DOUBLE GATE ,SM 15-5/8" 5M FLANGE CHOKE LINE WITH ONE REMOTE 1 MANUAL 4" 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) 15-5/8" 5M FLANGE SINGLE GATE 5M 15-5/8" 5M FLANGE RISER I 10" 5M x 13-5/8" 5M ADAPTER CAMERON 5M SPOOL 1 13-5/8" DOPE 5M STACK BAKER PLATFORM UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE' NONE DATE' 9/12/90 ~-5/8" 54.5#I @ 2012' BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND 9-5/8-40 & 45.5#, @ 7565' / 7" 29# @ 11127' / 2 I KOBE BHA 1 TUBING DETAIL 1/2", 9.2#, N-80 TBG BT&:C. 1) PRODUCTION STRING 2) POWER FLUID STRING 5) WIRELINE REENTRY GUIDE 4) 5-1/2", 15.5#, J-55, 0.012" WIRE WRAPPED SCREEN BAKER SC-1 PKR @ 6000' "A" ZONE INTERVAL 6085'- 6102' 6108'- 6145' 6192'- 6550' 6565'- 6405' 6450'- 6480' BAKER SUMP PKR @ 6500' CMT RET @ 6510' 'L_.~ PERFS F,/ 6520'- 7125' @ INTERVALS "' TOP OF LINER @ 73.59' ~--~~ BAKER MODEL F BP @ 7648' ---_ PERFS F/ 7730'- 8654' @ INTERVALS ~ CMT RET @ 8677' --- PERFS F/ 8690'- 9150' @ INTERVALS CMT RET @ 10200' ADL 17595 WELL NO. 5 PROPOSED WELL SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 8- 14-90 lrdIJal Pot~ntlcd: Initial Stlmufatlofli Cored fntervalm DST fntervafe and Re. ultra MIDDLE GROUND SHOAL ADL 17595 WE:IL. NO. 5 KENAI CONOLOUERATE PLATFORM BAKER 12/17/65 S~ot e, Leg 1, PJatform Bake, 1934' ~ SSO' IrWl. Se& 31, TON, RI2W, 78.75' Iq:KB USL 10200' ...$: · 20% 78.el ~ eet et 8#' Mm 1133 ~. Nment 1:1 3/8% 84.'~t Gbdnl let et 2012' Mth 2?64 m~. oement t S/B'*, 40 md 43.Sd~ Caring IM et 7585' utth 1050 ~. 7-, 2et un,r Nt d 73~t1127. w~h 14oo n, A: e225-.~340' ...O: e448-.845~' I e480.-e475' I 8520-8570' II 8708-0723* I C~ 6803-*8835* 0875-0015' I 6035-8078* ! 8005-7020' *'D: 7110-712~* Irt 7730-7760' 7885-7010' Ot 8040-5255' 8285-8430' 8478-8540' 8580-8602' 8620-8834' 8880-8035' 0080-0150° ~ 642 BiCN~D, 0 BRPD, OC]I~ 45~ · 110 PIP ~ 240 OCX'D, 0 BWlm, O0N ~O0 · 13.1 PTI' See Permit Date M ~pmeter, L 31/2" N-80 Buttroel bJbln! 3. 31/2' N-BO Buttr~# tubing pup 4. 31/2~ 8~2 crud 3 I/2' 8qattr~o XO S. 3" Kob~ type 'A* BHA o/t't 24l O. 31/2'* IkJtbl~O o~d 31/2" 81~2 XO 7. 3 1/2" N-80 Buttr~e tubing O. I, fuleohoe Short Strtngt O. 2 a/O" MD end 3 1/'2' Buttr~l XO D. 2 3/0' 8RD pu~ 3.1' 5087' $ggG' 5007' eO 14' eGiS' 8047. 8048' 37. 8084' 0eSS' 0008' 133,/8" O, CSX 2012' Rebdner et 8411' Brfdg~ plu~ 7848' Retobur Nt · 887'7* PBTO 10200' 11) 1112B* j7:3 8448. 8723' 6805' -- ~p at 733r r91 O' W. G. Smith District Manager August 26, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 File- FEW-113-WF Gentlemen- Subsequent Notice MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Commission Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-56:2-2147 Attached in duplicate is State of Alaska Form lO-404,'Report of Sundry Well Operations to notify you of work recently completed on MGS 17595 Well No. 5. Very truly yours, W. G. Smith District Manager Attachment TWB/dds O05/twb STATE OF ALASKA AL/-, ,,, JIL AND GAS CONSERVATION CO iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown r- Stimulate 51 Plugging ~ Perforate ~ Pull tubing ~X~ Alter Casing __% Other '-~ 2. Name of Operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface 1934' FNL, 550' FWL, Sec. 31, T9N, R12W, S.M. At top of productive interval 5. Datum elevation (DF or KB) 79.4' KB 6. Unit or Property name Middle Ground Shoal 7. Well number 5 8. Approval number 7-432 9. APl number 5O-- 733-10071-00 592' FSL, 921' At effective depth 622' FSL, 929' At total depth 725' FSL, 844' 11. Present well condition summary Total depth: measured 11,128 true vertical 10,396 FWL, Sec. 30, T9N, R12W, S.M. FWL Sec. 30, T9N, R12W, S.M. FWL, Sec. 30 T9N~ R12W, S.M. feet feet 10. Pool HGS "A" Plugs (measured) 6,411'; 8,677'; 10,200' Feet Effective depth: measured 6,411 feet true vertical 5,691 feet Junk (measured) 6,374' Casing Length Structural Conductor Surface 598' Intermediate 2,012 ' Production 7,565' Liner 3,767' Perforation depth: measured Size Cemented Measured depth True Vertical depth 20" 798 sx 598' 598' 13 3/8" 2,764 sx 2,012' 1,950' 9 5/8" 1,950 sx 7,565' 6,842' 7" 1,400 sx 7,360-11,127' 6,637-10,395 6,225-6,340 true vertical 5,507-5,621 Tubing (size, grade and measured depth) Dual 3½" N-80 Buttress at 5,996' with hydraulic pump bottomhole assembly at 5,997' Packers and SSSV (type and measured depth)~'~~ 12. Stimulation or cement squeeze summary None Intervals treated (measured) Treatment description including volumes used and final pressure SEE o '! 1 Gas Cons. Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 70 136 285 '40 300 Tubing Pressure 70 75 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run E] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ned.~,~..~ ,.~. Form 10-404 Rev. 12-1-85 -~',~,' Title Date Submit in Duplicate AMOCO PRODUCTION COMPAf,', .HRONOLO~ICAL REPORT DENVER REGION ~ ANCHORAGE DISTRICT ~ 08/26/87 ~ PAgE 1 ~ dOB INITIATION REPORT' COMPANY OPERATED - REPAIR - OTHER AP1 507331007100 FLAC 985578 MID GROUND SHOAL, MGS STATE 17595, 5, iiENAI O/S STATE, ALASKA OPERATOR' AMOCO PRODUCTION AMOCO W. I. ' 0.6250 AUTH HORIZON ZONE' 03 - MgS STATE 17595, 5 AUTH DATE 07/02/87 DENVER REGION ~ .NCHORAgE DISTRICT ]8/26/87 *** PAGE 07/04/87 MQS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, APl 507331007100, AMOCO W.I. 0.6250 OPERATIONS~ TD li182 FT, PBTD 6411, DISPLACINg WELL W/DSL COSTS~ DAILY WELL $2350, CUM WELL $2350 CHRON TIME DISTRIBUTION (HRS)i 1.00 - MO~ SKID TO LEg 1 3. 50 - OTHER, HO0~ UP SERVICE LINES 1. 50 - CIRC, Rig UP/DISPLACE W/DSL CURRENT WELL ACTIVITY-COMPLT-O&g, DATE 08/25/86 07/05/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS' TD 11182 FT, PBTD 6411, LS-POH W/3-1/~BUTT TBg COSTS: DAILY MUD $25200, CUM MUD $25200, DAILY WELL $36710~ CUM WELL $39060 REMARKS' RELEASED Rig 8 2400 HRS; 7-7-87 CHRON TIME DISTRIBUTION (HRS)' o O0 - CIRC, DISPLACE WELL W/DSL; iNSTALL BPV AFTER C!RC 1.00 - ND, NIPPLE DOWN TREE 9.00 - NUBOP, NIPPLE UP BOPS 2.00 - OTHER, INSTALL RAMS; TST BOPS2500~ REPAIR CHOKE~ AND gASKETS AND RINg gASKETS 1.00 - OTHER, CHANGE RAMS/PULL BPV 1.50 - OTHER, Rig UP ELECTRIC LINE;CUT SS AT 6140 I. 50 - CIRC, REVERSE OIL OUT OF SS 6.00 - PTQ, PULL SS AND PULL LS OUT HOLE 07/06/87 MQS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS~ TD 11182 FT, PBTD 6411, SPACE OUT X LAND TBg COSTS~ CUM MUD $25200, DAILY WELL $17849, CUM WEL~ $56909 REMARES~ DAILY DIESEL - 130 BBLS TOTAL DIESEL - 730 BBLS CHRON TIME DISTRIBUTION (HRS)~ 1.50 - PT~, L.D KOBE BHA; PUMP STUCK 3.50 - TRIP, IN W/8-1/2" BIT ON TBO - 6374 FT. 5.50 - CIRC, HOLE TOOK 11BBLS 2.50 - TRIP, OUT X L/D BIT ASSY DENVER REGION ~. ,NCHORAgE DISTRICT 38/26/87 ~ PAgE 3 1.00 - OTHER, CHANGE TO 3-1/2" DUAL RAMS 10.00 - RTg, DUAL 3-1/2" TBG W/KOBE; BHA ~ 249; HYDRO-TST EA STRINg 4000 PSI- BROACH LONG STRING 07/07/87 M~S STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: DAILY MUD $5460, CUM MUD $30660, DAILY WELL $3D603, CUM WELL. REMARES: RELEASED Rig AT 2400 HRS. CHRON TIME DISTRIBUTION (HRS): 2. 50 - RTg, M/U X TEST TBQ HANGERS -INSTALL BPVS - LAND TBg 3. 50 - NDBOPE 1.50 - N/U, XMAS TREE 1.00 - OTHER, TEST TREE 5000 PSI-OK-PULL BACK PRESS VALVES 6.50 - OTHER, FAB PROD LINES TO 4WAY VALVE 3.00 - OTHER, CRC PO DN BOTH STRGS DROP S.V. TS]" 2500-OK-DROP KBE 3" A PMP 07/08/87 MQS STATE 17595 5, MID GROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS~ FIRST PUMPS RUN WERE NOT OPEN POWER FLUID SYSTEM PUMPS THEY WERE CLOSED POWER FLUID. 5 HR. PRELIM. TEST {SPOT CE ONLY} OPTIMIZINg WELL BF 81.5 AT 8.8% WATER MCF 91~ 5 QOR ~57 F~L. 4657 CHRON TIME DISTRIBUTION (HRS): 8.00 - OTHER, PUMP CHANGES 8.00 - OTHER, PUMPINg - SPOT TESTINg :~.~ 07/09/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 ~ OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS: RAN KOBE 2-1/2 dET PUMP W/SC NOZZLE THROAT CONFIGURATION 4 HR SPOT TEST: BF 67.7 AT 38.4 BS & W;MCF 256;QOR 1024 BPOPD 819 AT 3250 PSI FL 3395 CHRON TIME DISTRIBUTION (HRS): 5. 50 - OTHER, PUMP CHANGE DENVER RE~ION - ~ .~NCHORAQE DISTRICT ' ~8/~6/87 ~ PAgE 4 18. 50 - OTHER, PUMPINg - TESTINg 07/10/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 50733i007100, AMOCO W.I. 0.6250 OPERATIONS~ TD 11182 FT COSTS~ CUM MUD $30660, CUM WELL $92512 REMARKSi 4 HR SPOT CK~ BF 44.3 AT 21.7% WATER~ MCF 201~ QOR 967 BPOPD 779 AT 2900 PSi; FLUID LEVEL 4.600 FT CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg 07/11/87 MGS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONSi TD 11182 FT COSTS: CUM MUD $30660~ CUM WELL $92512 REMARKS~ 4 HR TEST KOBE dET PUMP LIFT BF 41.3 AT 27. 1% WATER MCF 224 QOR 1245 POLO 772 AT 3125 FL 4776 CHRON TIME DISTRIBUTION (HRS)~ 24.00 - OTHER, PUMPINg ~. 07112/87 MQS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 50733.1007100, AIdOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS~ CUM MUD $30660, CUM WELL $92512 REMARKS: 4 HR TEST KOBE dET PUMP LIFT BF 39.8 AT 20.4% WATER MCF 231QOR 1215 POLO 767 AT 3250 PSI FL 4973 CHRON TIME DISTRIBUTION (HRS)~ 24.00 - OTHER~ PUMPINg 07/13/87 MgS STATE 17595 5, MID GROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT DENVER REQION ~ , ,NCHORAQE DISTRICT 8/26/87 *** PAgE COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS: 2 HR SPOT CK; COBE JET PUMP BF 20. 1 AT 24.9% WATER MCF 204 QOR 1130 POLD 853 AT 3300 PSI FL 4973 CHRON TIME DISTRIBUTION (HRS>: 24.00 - OTHER, PUMPINg ~** 07/14/87 *** MgS STATE 17595 5~ MID gROUND SHOAL~ ~ AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS: 2 HR SPOT CK; COBE dET PUMP BF 15 AT 30% WATER NO MCF OR QOR LOggED POLD 880 AT 3250 PSI FL 5052 ANNULUS PRES. 275 PSI CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg *** 07/15/87 MQS STATE 17595 5, MID gROUND SHOAL~ , AMOCO PRODUCTION, FLAC 985578-03-5~ AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS' TD 11182 FT COSTS' CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS)' 9.00 - OTHER, CHANGE 4 WAY VALVE DUE TO O-RINg BLOW OUT AT HIgH PRESSURE CONNECTINg FLANGE ~.00 OTHER, PUMPINg - NO gAUgE 07/16/87 MQS STATE 17595 5, MID gROUND SHOAL~ ~ AMOCO PRODUCTION, ************************************************************************************* FLAC 985578-03-5~ API 507331007100, AMOCO W.I. 0~6250 OPERATIONS~ TD 11182 FT COSTS~ CUM MUD $30660~ CUM WELL $92512 REMARKS~ .4 HR TESTINg OR ~OR MEASURED; BPOPD 815 AT 3350 PSI; FL 4290 CHRON TIME DISTRIBUTION (HRS): 24~00 - OTHER, PUMPINg - TESTINg ~** 07/17/8'7 *** MQS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, DENVER REGION ~ ~ ,NCHORAGE DISTRICT 8/26/87 ~ PAGE FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - NO gAUgE 07/18/87 4.4 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24-.00 - OTHER, PUMPINg - NO GAUGE 07/19/87 MOS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS)~ 24.00 -OTHER, PUMPINg - NO gAUgE .4. 07/20/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS: 6HR TEST; KOBE JET LIFT; BF 71.2 AT 7% WATER; NO gAS MEASUREMENT; BPOPD 745 AT 3350 PSI~ FL. 5400 FT CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - TESTINg 07/21/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, APl 507331007100, AMOCO W.I. 0.6250 D~NVER REGION .~ ,NCHORAgE DISTRICT 8/26/87 *** PAgE OPERATIONS- TD 11182 FT COSTS' CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS)' 24.00 - OTHER, PUMPINg - NO gAUgE *** 07/22/87 *** MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, ********************************************************************************* FLAC 985578-03-5, APl 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - NO gAUgE *** 07/23/87 *** MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPIN~ - NO gAUgE *** 07/24/87 *** MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, ******************************************************************************************** FLAC 985578-03-5, APl 507331007100, AMOCO W.i. O. 6250 OPERATIONS: TD 11182 FT COSTS' CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS)' 24.00 - OTHER, PUMPINg - NO gAUgE *** 07/25/87 *** MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, API 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - NO gAUgE DENVER REGION ,NCHORAQE DISTRICT J8/26/87 ~ PAgE 8 07/26/87 MQS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - NO CAUSE 07/27/87 MgS STATE 17595 5, MID gROUND SHOAL, , AMOCO PRODUCTION, FLAC 985578-03-5, AP1 507331007100, AMOCO W.I. 0.6250 OPERATIONS: TD 11182 FT COSTS: CUM MUD $30660, CUM WELL $92512 REMARKS: 6 HR TEST: 44 BF AT 22.7% WATER CUT~ GRAVITY 35.5 DEC AP1 285 MCFD~ OOR 2097 811BPOPD AT 3350 PSI KOBE dEl' FL 5i32 FT CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPING DENVER REQION ~, NCHORAQE DISTRICT )8/26/87 *** PA~E 9 *** END-OF-dOB SUMMARY: **~ FINALLED dOB INFORMATION: MID gROUND SHOAL, MQS STATE 17595, 5, KENAI O/S STATE, ALASKA OPERATOR~ AMOCO PRODUCTION OPERATIONS COMPLETED DATE 07/~7/87 TOTAL DEPTH 11443 FT. PLUg BACK TOTAL DEPTH 6411 FT CUMULATIVE dOB COST $9251~ CUMULATIVE MUD COST $30660 USELESS FOOTAGE 0 FT END OF REPORT W. G. Smith District Manager June 29, 1987 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' C. V. Chatterton, Chairman File' FEW-O92-WF Gentlemen- Application for Sundry Approval MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Application for Sundry Approval, for mandatory repair work Amoco proposed on MGS 17595 Well No. 5. Presently, the well is shut in with an inoperative pump stuck in the bottomhole assembly. The completion equipment must be pulled and the bottomhole assembly replaced to remove the stuck pump and return the well to production. Well No. 5 was producing 126 BOPD prior to experiencing the pump problem. We expect to achieve the same production rate after repairing the well. We plan to proceed with the repair of this well as soon as we receive your approval. Therefore, we would appreciate your immediate attention to this request. If you have any questions, please call Fred White at 562-2147. Very truly yo.u,~s, ~,.,.' ,,:~ .,Si / ,, W. G. Smith District Manager TWB/db Attachment 319/twb STATE OF ALASKA ALA .~IL AND GAS CONSERVATION COk, ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ;2 Suspend !~7 Operation Shutdown ,r3_ Re-enter suspended well L.'3 Alter casing [] Time extension i~_ Change approved program ~,~I Plugging !~: Stimulate [_~. Puli tubing ~ Amend order E3 Perforate [3 Other 2. Name of Operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, AK 99510 4. Location of wellatsurface 1934'~, 550'~L, Sec. 31, T.9N., R.12W., S.M. Attop ofproductiveinterval 592'FSL, 921'FWL, Sec. 30 T.9N. R.12W. S.M. Ateffective depth ' ' ' 622'FSL, 929':~¢_,, Sec. 30, ?.9N., R.12W., S.M. Attotaldepth 725'FSL, 844'FWL, Sec. 30, T.9N., R.12W., S.M. 5. Datum elevation (DF or KB) 79.4'KB 6. Unit or Property name Middle Ground Shoal 7. Well number 5 8. Permit number 9. APl number 50--733-10071-00 10. Pool M'GS "A" feet 11. Present well condition summary Total depth: measured true vertical 11,128 feet 10,396 feet Plugs (measured) 6,411' ; 8,677' ; 10,200' Effective depth: measured 6,411 feet Junk (measured) true vertical 5,691 feet Casing Length Size Cemented Measured depth Structural Conductor Surface 598' 20" 798 sx 598' Intermediate 2,012' 13 3/8" 2,764 sx 2,012' Production 7,565' 9 5/8" 1,950 sx 7,565' Liner 3,767' 7" 1,400 sx 7,360-11,127' Perforation depth: measured 6,225-6,340 True Vertical depth 598 ' 1,950' 6,842' 6,637-10,395 ' true vertical 5,507-5,621 Tubing (size, grade and measured depth) .. .;",.'~,~:...:.." '" ". ,. :.,. i~il, ,'.:',~: :: :;', ::; ~'. .'_..i; :.!:. :': ';~': :".~ Dual 3 1/2" N-80 Buttress at 6,143' with hydraulic pump bottomhole assembly a~"6,1:44' Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal X Detailed operations program "~ BOP sketch 13. Estimated date for commencing operation July 3, 1987 14. If proposal was verbally approved Name 'of approver Date approved 15. I hereby certify that the f. oregoing is t~:ue and correct to the best of my knowledge .,,,' -~ ¢~,?,.~' ,/,.~> ~ ,./--' , · : ' '" diK' ' .' ,/ C/ Commission Use Only Date Conditions of approval Notify commission, so representative may witness [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 ~,~,t u r,'"t~cl., Commissioner by order of ,~ .~, ~.~/.,i i the commission Date -~' - .,,".~i~, ~.,~ ) Submit in triplicate DETAILED OPERATIONS PROGRAM I · e 4~ m 7, 8. , Circulate the well with dead crude to determine a kill weight. Circulate the well with an appropriate kill fluid. The following fluids will most likely be used: Kill Weight Fluid Less than 7.0 ppg 7.0 ppg - 9.8 ppg Greater than 9.8 ppg Diesel NaC1-KCl in fresh water CaC12 in fresh water The estimated bottomhole static pressure for the well is 2,000 psig and the estimated kill weight is 6.9 ppg. Set back-pressure valves. Nipple down tree, nipple up BOP's and pressure test. Pull back-pressure valves. Pull tubing. Run in hole with tubing to PBTD at 6,411 feet. Reverse circulate any fill to surface. Make a bit and scraper run to bottom of perforations at 6,340 feet. Complete well with dual tubing strings and hydraulic lift bottomhole assembly. Set back-pressure valves. Nipple down BOP's, nipple up tree and pressure test. Pull back-pressure valves. Return well to production. "'-'*-" Amoco Production ENGINEERING CHART · i : D~TI~ eY It/IL ] -.SL-_ i ' f~ ~r-'~ TXFE B~?- ., ! ! J -. i -Ft.) ctloR 1~3.~ RECEIVED J U.L 2 3 !986 Alaska 0ii & Gas Cons. Commission Anch0rage · I -- I SUBJECT . I _ . k)~ ii bore_ Amoco Production Company ENGINEERING CHART /t c.z.z--~ ' · / ~ 3qo : ]/ ~qtl .. : ! ! i . ! ~h~t No. File , ! : I I ; ! : : ! " .~. ,, .. :,.., , , ~ ~ I ! iJ" " ' , ~:,: .,~... i ; i ..: : I ] ! - · ~ , , i i : ; "- I~tUL~..St/qE .: i - i ! :,...~_ i 6ZOl ' I I I ' ' ' : , I I , : ~ I ' ' i J · : , _ . : .; , .l: I I . : ' I . j , : : : i ' ! :__~ ; .s,..~.%',' 'S-,:_~.~d~_l .... ~..j__.! ,-'®i ' : ' ' ' ' ' ' %"~ J ---t I : ' , · ; ..... : · :,~ , i I -~ ! (~1 Sl~ ~!~¢~_ ~ '~,~. io!~,'b_ ~0.' . ! i "i--i !- I 1'- ! .... :-"l- ' ! -:!q,'-:o ~ui~'-';-i' ' I J ,, _.. ~ i: ~ . , i I "-i- ~ I ,:..?....i.::_:.p ; : I' · - I ? .,. ,.%., ~iLB!~I : i I ' :,:~! ! lj i .......... - j : j .; ,,.-.- : r.{,..,:~i l · : i j l:__ i ..... ~_,~ :'.c, qB, .jr,,: , _ · r~ ~ ;u~ ; ,r,~C-', - I i ,,~,,,elt¢~ O\'~ '- =..,.-,~n~ c.'O) ' - · : : i F"~%~:'" l:~,'"{'" ". . - J : . . · : ' ' :- ] i '" ' : - · ] , ' J t :- , -- J--J ~ .... , i ......... ] ' ' ! · I ' ~ i I i J ' , . , , , .! ..... !__ ~ .............. of App. SUBJECT ~" Sheet NO. of Amoco ProductiOn Company ENGINEERING CHART Appn MC-.S 1'7,y'~,y' ~Oe. II AJ~:. 5' ! ! ; . "i: ' i ~ ; - ,.,,,. . j/S,O : ~..~ . i : i : i : ' .: i . -' i .: i I i :. i ] I I I :' : "I ! i : ' i - ' : ' i i I j i : : : i ' ' · ~ ~ : : ' '' ' .... , ! ! ~ ; "- ' I i , i ' · ' ' ' i .. : l._ : ; : : I I : .~ : ' ! :' - : i ~ ~? i c< ' i : : i - : ' : , .-. · l J : i : ..... j J I l ] [ ? ~ ~ ~ '~jJ~~ I / [ I [ ~ .l : .,,, '-I--!- ·. ' S .?: ~ : i I ~' j I : , ®! · 1,, : IO,~b u~ ' ~ ; , ' : ' - I ' ! j ~ I , : : · ~. : ............... ~ t~:.-b' i.*- !; '-'7-:-'.-% ~ ..... 4 , I I ~ · I ' : : .... ' .!_ !...t ..... : ...... , ..... . ' i i · I .... .., '~ ..._q .*.C,~ ~ ~oz.z:~. ~ t , i ~ j : . , 1 i : ' ' i . _.-..! L;' :_--_! :--"--i ' : ..... · ' [ I ' ' i ' .. i : .... : , ~ : - · 1 f : i , · I : I i .:- .- ~ ..1 ..; '--~ -i ......... : -' ' ~ i , j i i i , , ~ : W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 September 22, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File- FEW-237-WF Subsequent Notice MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Report of Sundry Well Operations, to notify you of work recently completed on PiGS 17595 Well No. 5. Very truly yours, ~J. G. Smith District Manager TWB/dds Attachment 014/twb2 STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COM .,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown D Stimulate '~, Plugging ~ Perforate~ Pull tubing · Alter Casing -~ Other ~ 2. Name of Operator Amnc~ Productinn Comoanv 3. Address P.O. Box 100779, Anchoraqe~ Alaska 99510 4. Location of well at surface 1934' FNL, 550' FWL, Sec. 31, T9N, R12W. S.M. At top of productive interval 592' FSL, 921' FWL, Sec 30, T9N, R12W, S.H. At effec~e~t~L, 929' FWL, Sec 30, T9N, R12W, S.M. At total ~)§tt~ FSL, 844' FWL, .Sec 30, TgN, R12W, .S.M. 5. Datum elevation (DF or KB) 79.4' KB 6. Unit or Property name Hiddle Ground Shoal 7. Well number 5 8. Approval number 267 -oo s "A" Feet 11. Present well condition summary Total depth: measured true vertical 11,128 feet Plugs (measured) 10,396 feet 6411'; 8677'; 10200' Effective depth: measured true vertical Casing Length Structural Conductor Surface 598' 2012' Intermediate Production 7565' Liner 3767' Perforation depth: measured true vertical 6,411 feet Junk (measured) 5,691 feet Size Cemented Measured depth True Vertical depth 20" 798 Sx 598' 598' 13 3/8" 2764 Sx 2012' 1950' 9 5/8" 1950 Sx 7565' 6842' 7" 1400 Sx 7360-11127 6637-10395 6,225' - 6,340' 5,507' - 5,621' Tubing (size, grade and measured depth) Dual 3½" N-80 Buttress at 6,143' with hydraulic pump bottom hole assembly at 6,144' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 50 25 58 150 60 782 672 4 1500 60 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title District Manager Date 09/22/86 Submit in Duplicate ~.~fiSC(3 ?RQ£'.'UC, TION C(3M?ANY CHRONOLOG'I C¢~L REPQR-I' DENVER REGION ~.* ANCHORACE DISTRICT .*~.* 09/24/86 ~.~* PAgE I , , T ~-* ..... R~- LET ~-x--:4- Jr,.)'~ !NTTIAT-~ON RE,-d~-,I {Oi'!.?.~'*.h';Y (3PERATED :-_COMP I~,', - DEVELOPNENT AP i = ']'~?? "_ -' ~ ..--~_- -, FLAC c;.,_-, =, ,~,,'o, / ~."!'-'-' MID. GROUND SHOAL, MIDDLE GROUND ,'-ZH(],~L, ~5, KENA]. O/S STATE, ,~LASKA OPERATOR: AMOCO PRODUCTIOf.,I AMOCO W. I.' 50. 0000 AUTH HORIZON ZONE: 03 - MIDDLE (:~ROUND SHOAL, .~5 AUTH DATE 05/06/86: AUTH COST '~.':'~=.,,_.JOOO~} CON'TRAC TOR ( S ) :~.. FIFOR FIA'-[' I O~q."" ' PARI&ER, O152 i6 6-o~]9:~loo~/~o0. DENVER REGION -~'-~-~ ANCHORAGE DiSTRiCT ~*-~ 09.;'24/86 ~.-~* PAGE '-2 .~ 08/09/86 MIDDLE GROUND SHOAL f~5, MID. ~P, OUND SHOAL, PARKER i52, AMOCO PRODUCT iON, -,Ld55.,U-O3-8, API 5u/,:,~ZO07200, AUTH COST $350000: AMOCO W.I. 50. 0000 OPERATIONS' TD 11182 FT, PBTD 8677, N/D XMAS TREE COSTS: DALLY WELL ~&767, CUM WELL $6767 ~,-,~. ,, p,, c, - =,_D RIO OPERATIONS AT 1200 8/8/86 ATTEtdPT CIRC DN S. S. ; PRESS UP 2500 PSi¢ SLOW ~L~EED OFF. ATTEtdPT CIRC DN ' c p ¢ -, ._ , ......; . RscSS UP 2500 PS.I~ SLOW BL~rEn OFF DISPL L.S. W/FRESH WATER {1250 PSI}. DISPL S.S. X ANNULUS {1300 PSI}. OBSERVE WELL- OUT OF BALANCE. D!SPL l_. S. CHRON TIME DISTRIBUTION ~.q O0 - OTHER, TA~ S. S. PUP AT 728i W/OTI '~ O0 - MI SKID RIg TO LE~ 1 WELL 5 3 50 - MI, RIG UP SERVICE LINES ! 50 - PERF, L.S. AT 7630 W/APRS =~' O0 .... OTHER, ATTEMPT C!RC I 50 - PERF, L.. S. AT 7330 W/APRS 5 CO - C IRC, DISPL L.S. X S.S. O. 50 -.. OTHER, SET BACK PRESS VALVES IN BOTH STRINQS 08/10/86 * ~--~. IdlDDLE C~ROUND SHOAL ¢5, MID. O=ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-'8, API s"- "~. ~/331007200, AUTH COST $350000, AMOCO W. I. 50. 0000 O?ERAT!ONS' TD 11182 FT, CiRC L. S. u.:~c:,.. DAILY WE[_L $1520'?, CUM WELL $21974 ~;?-IRON iME DISTRIBUTION (HRS)' 2. O0 --- ND, XMAS 'TREE 5. O0 --- NUBOP 2. O0 - TSTBOP, 3000 PSI. STATE OIL X .~AS WAIVERED WITNESSING. O. 50 - OTHER, INSTALL 3-1/2 SINGLE RAMS I. O0 - OTHER, CUT SS AT 72'79 FT 'W/AF'RS 3. O0 -- C iRC, OIL X GAS BREAKIN~ OUT AT SURFACE~ NO FLOW O. 50 - OTHER,. SHUT IN. NO PRESS BUILDUP ~. ~.,0 - LD, SS TUBING - SCALED 1. 00 - OTHER, ATTEMPT TO PULL LS BPV. PRESS WOULD NO]' BLEED OFF. O. 50 - C IRC, DN LONG STRING ~-~- 08/'11/86 MIDDLE ¢ROUND SHOAL f~5, MID. GROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W. I. 50. 0000 DENVER RECTION ~.~.~ ANCHOR""'-'"- . .._, · ,-,...?~ DISTRICT ~'~ 09/,=.:4/86 -x-~.~ PACE -7 OPERATIONS: TD 11182 FT, CtRC AT TOP OF LINER COSTS' DAILY WELL $14783, CUM WELL $36757 REMARKS: SEAL ASSY PULLED OUT OF PACKER W/150000 LBS. CORROSION ON TBQ STARTING AT ~774 FT. CHRON TIME DISTRIBUTION (HRS)' ¢_...'"" O0 - C IRC: 9. '.DO - PTC~, 1. O0 - TRIP, ,-D. sO - TRIP, F3. O0 - PU, O. ~)0 - CIRC, DN LONG STRING PULL TB~ ]iN Wt ~//4 FT. TBQ IN DERRICH, OUT X L/D REST OF TIH 8. 5 IN. S l'['~ BI']" SUB~ 3 4-5/8 IN. DC X P/U 3-I/2 IN. DP REV AT '7339 F'T; TOP OF 7 IN. LINER MIDDLE GROUND SHOAL ~5, MID. GROUND SHOAL, PARKER i52, AMOCO PRODUCTION, FLAC ~85578-03-8, API 507331007200, AUTH COST $350000, AMI]CO W. t. 50. 0000 O~'E,~A~IONS' TD 11182 FT TiH W/BlT TO CIRC COSTSi DAILY WELL $11207, CUM WELL $47964 RD.M,gK~wJD NELL FLOWINg. RIH 2 S'TDS; PUT IN PRESSURE ~UAeE X CHECK PRESS ~UiL_D UP; 30 PSI rfOTH SIDES. LO~i}IN¢ TOOL FAILED. POH W/TOOL WELL FLDWINCI. STARTED SEFDRE FINISH CHRON TZME DISTRISUTION (HRS)' 2 O0 - CIRC, REVERSE ~ O0 - OTHER, HELL ~ O0 .... OTHER, MIX KCL.) BUTLD,. WT 2 O0 - TRIP, 2 O0 - RBXS, '"~ 50 - CIRC "'~.=. 50 RI]XS, 1 O0- RU, 7 O0 --. LOG OUT RIH W/SCRAPER TO 6430 POH W/SCRAPER RIG UP Io. OG~!NG TOOL 08/13/86 ~. ~-~- MIDDI_E (~ROUND SHOAL ~5, MID. O~ROUND SHOAl_, PARKER 152, AMOCO PRODUCTION, FL~,. 985578-03-8, APl 507331007200, AUTH COST $350000, AlflOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, P/U 3-1/2 IN. BUTT COSTS: DAILY WELL $15711, CUM WELL $63675 CHRON TIME DISTRIBUTION (HRS): 2. O0 - TRIP, IN W/BIT TO C IRC 2. O0 - C iRC, 2. 50 - TRIP, 3. 50 - LO~, 4. O0 - TRIP, WEiO, HT UP TO 8. 5 PP~ RUN COMP. NEUTRON LO~ IN W/BRIDgE PLU~. SET AT 6411. POUR 2 SX SAND ON BP. TST 9-5/8 IN. CS¢ TO 2050 PSI 30 MIN. HELD TI CHT W/NO LEAK~F. DENVER REC~ION ~ ANC.HORAQE DISTRICT .~.*~ 09/'24/86 ~.* PAgE 4 L 50 - TRIP, '?' 50 -- PU, OUT; L/D DRILL PIPE 3-I/'22 IN. BUTT ~-~.-:~- .~- 08/14,'86 ~-~.~ M)'DDLE gROUND SHOAL ~5, MID. ~ROUND SHOAL, PARKER !52, AMOCO PRODUCTION, P': A~ 985578-03-8, APl 5073310 ~'~ C/~_uO, AUTH POST ~350000, AMOCO W.I. 50. 0000 OP--'RAT!ONS- TD Ii!82 FI", FLOWIfq~ WELL ~.~ .,-.. ~. Cu=,i.~ DAILY WELL $!2~864, CUN WELL $186539 ~p, -. REM~.-..KS 10 MtN AFTER FIRINg QUNS FOUND FLOW ON ANNULUS SIDE. MOST CA~E AROUND OR THRU PACKER - SI ANNULUS AND TB~ - BUILD UP 750 PSI ANNULUS X TBQ AFTER 45 MiN S~; Rig UP TO FLOW TO PRODUCTION CHRON T~ME DISTRI~JUTION (HRS)' 10.00 - PU, 3-1/2 TBg FOR LS X SS; MAKE UP STANDS X PUT !N DERRICK 3. O0 - CIRC, DISPLACE WEL~ .... W/DSL 2. O0 - TRIP, OUT W/TBg 2. O0 PU, PERF gUNS 3. 50 - TRIP, IN W/gUNS X 2. O0 - TRIP, IN W/WIRELtNE X. SET ~UNS ON DEPTH 1. O0 .... OTHER, DROP BAR X F'tRE ~UNS ' 50 0 ~HER, --' ~ '~,. h=UW WELL TO ~'~'~*. ~u~, PERFQRA"¢ZQNS' 08/14/86, TOP 62'~ ., FT BOTTOM 6340 FT, TYPE-OPEN, SHOTS/FT. 4, PERF DiAM. O. 500 IN, TOTAL NO. SHOT 460, ~UN-NON-EXPENDABLE, SIZE 5.000 FLUZD Oil_, DENSITY 6. 9 PP~ .~.*e~ 08/15/86 ~..~-~- MIDDf_E (~ROUND SHOAL ~.5, MID. (TROUND SHOAL, PARKER i5~,~ AMOCO PRODUCTION,- ~= ._,,.~C 985578-03-8 AP! ~073,,~007200, AU]'H CO,~ $350000, AMOCO W.I. 50. 0000 OPERATIONS' TD 11182 FT, TST¢ "A" SANDS COSTS' DAILY IdUD $24377, CUM MUD $24377, DAILY WELL $57380, CUM WELL $243919 REMARKS' HELD BOP DRILL WHILE C iRC {SIMULATED}. SOFT SHUT-IN MEN ON STATION IN 3 MIN. FLUID LEVEL IN ANN IS NOT FALLINQ. TEST WAS STARTED AT 0845 DUE TO HIgH PRESS SHUT IN FWKO. AVe TOTAL FLUID PROD = 45. 3 BBL/HR~ AV~ BS&W = TR {SAND STOPPED AFTER 5 HRS}¢ MCF PROD = 29.7. TOTAL CLEAN OIL IN 21 HRS = 945.2 BBLS; TOTAL WATER iN 21 HRS = 6. 3 BBLS; TB~ PRESS 1000- 925 PSI; ANN PRESS 700-530 PSI; gOR 675~ ~RAVITY AT 60 DE~ = 39.6 - 39.9. CHRON TIME DISTRIBUTION (HRS)' 24. O0 -. 'fST¢, FLOW TEST THROUCH TB¢ 08/16/86 DENVER REC.-ION ~.~ ~HORAC;E DISTRICT ~'.~ 09/'24/'86 ~-~-~ PAgE 5 MIDDLE gROUND SHOAL ~5, MID. ~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, API 507331007200, AUTH COST $350000, AMC)C© W.I. 50. 0000 OFEF;~,:',¥~.ONS: TD 11182 FT, PBTD 8677, TST~ "A" SANDS COS-rE' ~'l~M MUD '~'~= .LY , .... ~ ,, DAT WELL $32457 CUM WELL. ~¢"~ ....."' 24 LS - - - R~r,~,,~) HRS -- BB FLUID !072. 8 GTY 3~ 6 AT 60 DEe BS X W TRACE- MCF 7~7 - OCR 668 -'TBg PRESS 925-880 PSI ANN PRESS 540-460 PSI 55680 LBS SODIUIfl CHLORIDE <NACL} 12000 LBS POTASSIUM CHLORIDE <KCL} CHRON TIME DISTRIBUTION (HRS)' ~4. O0 '-TSTg, FLOW TEST THROUGH MiX 660 BBLS 9. 8 PPg KILL. FLUID 08/!7/86 MIDDLE GROUND SHOAL ~D, MID. GROUND SHOAL, PARKER ID2, AMOCO PRODUCTION, FLAg 985578-03-8, ~PI 50733t007200, AUTH COST $350000, ~.'r *~ W. . ~JC, U i. 50 0000 COo].:~. DAILY MUD $5600, CUM MUD $29977, DAILY WELL $9377, CUM WELL $285753 R~,f,~K,:) 24 HOUR TEST- ~BLS FL. UZD ~056. 7- g]'Y 39. ~ AT 60 DEC -BS X W 1 PER CENT - MCF 66D -gOR. 6~9- TBg PRESS 880-870- ANN PRESS 470-4~0- FLUID LEVEL IN ANNULUS IS AT SURF4CE NO ~AS IN ANNULUS CHRON TIME DIS]"RI~UTION (HRS)' 24.00 - TSTg, FLOW TEST 08/18/86 MIDDLE (~ROUND SHOAL ~5, MID. ~ROUND SHOAL, PARKER ~52, AMOCO PRODUCTION, F:'L''/'' ~O,~T $350000, ,'.,,_. 985578-03-8, API 507331007200, AUTH C: ,,':.::HOCO W.I. 50. 0000 OPERATIONS: TD 1t't82 FT, PBTD 8677, TST¢ "A" SANDS COSTS: CUM IdUD $29977, DAILY WELL $3926, CUM WELL $2289679 REMARKS: 24 HOUR TEST - BBLS FLUID 1027. 7 - .~TY 39. 5 AT 60 DE~ - BS X W TRACE - MCF 713 - gOR 693 - TB~ PRESS 845-848 - ANN PRESS 480-400-. CHOKE 16/64 24 HOUR TEST - BBLS FLUID 1022 - gTY 39. 6 AT 60 DE~ - BS X W 1 - MCF 683 - gOR 668 - TB~ PSt 845-830 - ANN PSI 400-480~ AT 480 PSI BLEED 50 PSI OFF ANNULUS.; 390 - 340 WHEN THIS WAS DONE TBg WENT FROM 840 PSI TO 800 PSI - i HR LATER PSI WAS 780 AND ANNULUS 390 PSI.; 2 HRS I_ATER TB~ BACK TO 820 AND ANNULUS WAS 400 PSI - 1ST HOUR AFTER BLEED OFF MADE 41. 0 BBLS X 24 MCF,; 2ND HOUR MADE 44. t BBLS X 26 MCF CHRON TIME DISTRIBUTION (HRS): 24. O0 - TST¢, FLOW TEST 24. O0 - TST¢, FLOW TEST DENVEF! REQION **.~ ANCHORAE¢E DISTRICT .~** 09/_'-?ti./86 *** PAQE 6 MIDDLE GROUND SHOAL ~5, MID. QROUND SI40AL, PARKER i52, AMOCO PRODUCTION, '-"'n',_~,.,*r' 985578-03-8, API 507.:,o~,q07200,_. AUTH COST $350000, ~"~"~'~"'"¢~ b~. i 50. 0000 OPERATIONS' TD 11182 FT, PBTD 8677, TSTg "A" SANDS CO ......... C MUD $29977, DAILY WELL $3926 CUM WELL ~293605 RElSAF~',4. S' 24 HOUR TEST - 983 BOLS FLUID - gTY 39. 6 AT 60 DEG = BS X W . i -' MCF 648 - gOR 659 - TB~ PRESS 830-B18 - ANN PRESS 40 '~ u - CHO~E 16/64 CHRON TiME DiSTRIBUTiON (HRS)' .i~'.~. O0 -' TSTg, FLOW TEST ~* -~- 08/2_i/86 *..* .* MIDDLE QROUND SHOAL f~5, MID. O~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, F'LAC 985578-03-8, API ~ '~"~ ~ '- ,)0~.~0~7~00, AUTH COST $~0000, AMOCO W.I. 50. 0000 OPERATIONS' TD 1it8~ FT, P~TD 8677, TST~ "A" SANDS ~-'~,'-' .',-c..UM -~o ~- St..~ ~ a C MUD $= ¢9 / 7, DAILY WELL ~ .... .~ CUI~ WELL REhJARF, S' 24 H~UR TEST .... BBLS FLUID 984 - ~TY 39. 9 AT ~0 DEG - BS X W 1 - MCF 63~ - ~OR . ~48 - I-Be 815-800 PSI - ANN PRESS 400 - CHOKE 16/~4~ HAD PRODUCTION SI T~¢ PRES IN 15 ~!N WENT T'8 845 PSZ¢ 950 PSI ~;N 30 ~]N - AFTER START UP BACK TO 800 ANNULUS NNET TO 580 PSI AT SAME TIME -' AFl'ER START UP 440 CF'tRJN TINE DISTRIBUTION 24. O0 - TST~, FLSW 'TEST MIDDLE "~' .... ''' (:,,-.bdND SHOAL ~5, MID. (~RUUND SHOAL, PARIAER 152, AMOCO * c PRODUCT ION, FLAC 985578-03-8, API 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATZONS' TD 11182 FT, PBTD 8677, TOH COSTS' CUM MUD $29977, DAILY WELL $28848, CUld WELL $326379 REMARKS' NOTE ~1 - STARTINQ TOg PRESS 800- ENDIN~ 1150~ STARTIN~ ANNULUS PRESS 440 - ENDIN~ 800; NOTE ~2 - RI~ UP OTIS - TEST LUBRICATOR 3000 PSI - RUN PRESS BOMBS 6160 WLM; NOTE ~3 - DILUTE 9. 7 PP~ SALTWATER TO 9. 6 PP~ {KCL X NACL} CHRON TIME DISTRIBUTION (HRS)' 2. O0 - TST~, FLOW TEST SAME 3 O0 '- OTHER SFIUT IN {oEE NOTE ~1} 4. 50 - OTHER, BHP SURVEY {NOTE ~} ~. 50 - WOO, BHP = 2618. 75 PSI 3. 50 - OTHER, MIX KILL FLUID <NOTE ~3} 3. 50 - C IRC, DISPL W/9. 6 PP~ FLUID 'DENVER REGION ~ ANCHORAGE DISTRICT ~.~-~:.~ 09/24/86 ~ PAGE 7 2. 50 - C IRC, CK FLOW - C!RC GAS BUSTER i. 50 - CtRC, BTMS UP - OK O. 25 .- OTHER, SET X TEST PKR - OK RELEASED O. 7'5 -. 'TRIP, OUT W/3-.1/2 IN TBG MIDDLE ~TRDUND SHOAL ~.5, MID. GROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, AP Z 50733i007200, AUTH COST $350000, AMOCO W. I. 50. 0000 OPERATIONS: TD 11182 FT, PB]'D 8677, INSTALL FLOW LINES <PROD} COSTS: CUM MUD $29977, DALLY WELL $!2637, CUM WELL S339016 REMARKS: HYDROTEST 4000 PSI~ BROACH LONQ STRINg. LANDED TB¢ W/15000 LBS EXTRA LON~ STRINg. INSTALL BACK PR ~"~ CHRON TIME DISTRIBUTION (HRS): 3. 50 - TRIF'~ OUT X L/D gUNS ~'~ PACKER 13.00 - RTQ~ CHANGE TO 3-112 IN. DUAL RAMS~ Rig UP X RUN 3-1/~ IN~ DUALS !. ~0 -- RD, R t~ DN TONGS X HYDROTEST 3. 50 - NDBOP ~. O0 -- NU, XMAS TREE O. 50 - OTHER, TEST TREE TO 5000 PSI -'-OK i O0 .... OTHER, PULL BPV AND INSTAL. L PRODUCTION FLOWLINES -~.~-~. 08124/86 -~ MIDDLE GROUND SHOAL. ~f-5, MID. ~.}ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FL. AC 985578-03-8, AP I 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 ~... OPERATION~ TD Ili82 FT, PBTD 8677, PRODUCINg COSTS: CUM MUD $29977, DALLY WELL $17479, CUM WELL $356495 REMARKS: RELEASED RIG AT i800 FIRS 8/23/86. 8 HR TEST: 32.5 BARRELS OF OIL; 17 BARRELS WATER; (~RAVITY 38. 6; MCF 165; QOR 508; TBG PRESS 450-375; CHORE 24/64. CHRON TIME DISTRIBUTION (HRS): 5~ 50 - C iRC~ D ISPL 9. 6 PP~ KiLL FLUID W/POWER OIL 6. 50 - MO, CLEAN MUD PITS; RIO= FLOOR X DECM. OFFLOAD W/O E(~UIP ON BOAT. S¼ID RI~ TO CENTER X HOOF, UP LIGHTS 12.00 - OTHER~ PUMPING - TESTING 08/25/86 ~'~ MIDDLE GROUND SHOAL ~fS, MID. GROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, API 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, PBTD 8677, PRODUCING COSTS: CUM MUD $29977, CUM WELL $356495 DENVER REGION ~.~ /4NCHORAGE DISTRICT ~'~ 09/24/86 ~.-x.- PAGE REMARKS: 12 HR TEST: BARRELS OIL 499; TRACE WATER; GRAVITY 38. 2 AT 60 DEg; MCF 267; gOR 53~,; TBQ PRESS 425 PSI; ANN PRESS 1200 PSI; CHOKE 24/64. 6 HR TEST: BARRELS OIL 270; TRACE WATER; gRAVITY 3S. 8 AT 60 DEg~ MCF !47; GOR 548.~ TB~ PRESS 400 PS!; ANN PRESS 1200-1380 PSI¢ CHOKE 24/64. CHRON TIME DISTRIBUTION (HRS): 24. O0 - OTHER, PUMPING - TESTINE4 24. O0 -. OTHER, PUMPINg - TESTING -~ ~.x.- 08/27/86 ~.~ MIDDLE 6~ROUND SHOAL. ~5, MID. (¢RO!JND SHOAL, PARKER i52., AMOCO PRODUCTION, FLAC 985578-03-8, AP1 50733.i. 007'200, AU]'H COST $350000, AMOCO W.I. 50. 0000 OPERATIONS' TD 11182 FT, PUMPINg COSTS: CUM MUD $29977, CUM WELL $356495 REMARKS' 3 HR TEST' BARRELS OIL 137~ TRACE WATER¢ GRAVITY 39. 8~ MCF 76. 6~ gOR 559¢ TB(¢ PRESS 5.¢(. PSIi ANN PRESS 1490 PSI; CHOKE 2-4-,./64. CHRON TIME DISTRIBUTION (HRS)' ~4 O0 - OTHER PUMPINg -~-~-r ,:.. . , - t=,:::,. INg 08/28/86 MIDDLE GROUND SHOAL ~5, MID. ~ROUND SHOAL, PARKER 152, AMOCO PRODUCT,_ON, FLAC 985578-03-8, API 50733i007200, AUTH COST' $350000, AMOCO W.I. 50. 0000 OPERA]"IONS: TD i1182 FT, PUMP COSTS: CUM MUD $29977, CUM WELL $356495 REMARi&S: 6 HR TEST: BARRELS OIL 27!; TRACE WATER,; gRAVITY 39. 6; MCF !90.8; GOR 704; TB(~ PRESS 55(} PSI,~ ANN PRESS 1650 PSt; CHOKE 24/64. CHRON TIME DISTRIBUTION (HRS): 2_4.00 -.. OTHER, PUMPING - TESTING '~-~ 08/29/86 ~'~. MIDDLE ~ROUND SHOAL ~5, MID. gROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, APl 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, PUMPING COSTS: CUM MUD $29977, CUM WELL $356495 REMARKS: 3 HR TEST: ]BARRELS OIL 132; TRACE WATER; GRAVITY 39. 8; MCF 77. 5; gOR 586; TBG' PRESS 650 PSI; ANN PRESS 1620 PSI; CHOKE 24t64. I)ENVER REGION **.~ ANCHOR:~,gE DISTRICT .~'~ 09/24/86 ~.-~- PAGE 9 CHRON TIME DISTRIBUTION (HRS)' 24. O0 - OTHER, PUMPINg - TESTINg MIDDLE C~ROUND SHOAl._ ,gS, MID. ~ROUND SHOAL, mARKER 15=, AMu,..O PRODUCTION FLAC 985578-03-8, AP1 50733t007200, AUTH COST $350000., A~OCO W.I. 50. 0000 OPERAT]:ONS- TD 11182 FT, PUMPI;NQ COSTS: CUM MUD $29977, CUM Nc. LL $356495 REMAO~c. . . ,~,,~.=, 4 HR 'rEST BARRELS OIL 153. Mcr ~05; gOR 687; TBG' PRESS 625 PSI; ANN PRESS 1660 PSI; CHOKE 24/64. CHRON Tilde DISTRIBUTION (HRS)' 24. O0 - OTHER, PUMPiN~ - TESTINg ~-~ 08/31/86 ~, MIDDLE C~ROUND SHOAL 4¢5, MID. gROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FL_AC 985578-03-8, AP1 507331007200, AUTH COST ,,350000, AMOCO W.i. 50. 0000 OPERATIONS: TD 11182 FT, PUMPIN~ COSTS: CUM IdUD $29977, CUM WELL $356495 REMARKS: 6 HR TEST: BARRELS Oil_ 227~ TRACE WATER; (TRAVITY 40. 1~ Mcr !.59; gOR 700i TBg PRESS 625 PS!; ANN PRESS 16.60 PS!; CHOKE 24/64. CHRON 'T~ME DISTRIBUTION (FIRS): '24, O0 -. OTHER, PUMPINg --- TESTINg ~---:~.,~. 091'01/86 .~- .~.-.x. MIDDLE GROUND SHOAL ~5, MID. ~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, PUMPIN~ COSTS: CUId MUD $29977, CUM WELL. $356495 REMARKS: 6 HR TEST: BARRELS Oil_ 226.2; TRACE WATER~ GRAVITY 40. 2; MCF 161; QOR 712; TBg PRESS 600 PSI; ANN PRESS 1640 PSI; CHOKE 24/64. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, PUMPINg - TESTIN~ 09/02/86 MIDDLE GROUND SHOAL ~5, MID. gROUND SHOAL, PARKER 152, AMOCO PRODUCTION, DENVER RE(;ION ~*~ ANCHORA(;E DISTRICT ~*~ 09,,"24/'86 ~* PA(;E 10 ~' :'~' 9855'?8-03-8, AP1 507331007200, AU]'H COST $350000, AMOCO W. I. 50. 0000 OPERA-Ti~,,,~ TD ii182 FT, PUMP[N~ COSTS~ CUM MUD $~9977, CUM WELL $356495 REMARKS: 6 HR TEST: BARRELS OIL MCF 159; ~OR 710; TBO PRESS 600 PSI; ANN PRESS 1630 PS!; CHORE 24/64. CHRON TIP~E DISTRIBUTION ~4. O0 .- OTHER, PUMPINg - TESTINg ~:..~ ~ 09/03/86 MIDDLE gROUND SHOAL ~5, MID. (;ROUND SHOAL, PARKER i52, AMOCO PRODUCTION, ~...~.~ .~.~ ~..~ ~.~.~. 2.~. ~.~2.~. ~.~. ~.~. ~.~**..~ ~.~ ~. ~2.. ~.,~ ~.~. ~....~ .~.~. ~.~. 2..-.~, ~.~.. ~..~e FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: I'D 11182_ FT, PUMP~NO COSTS: CUM MUD $29977, CUM WELt_ $356495 REMARKS: 6 HR TEST: 13ARREL. S OIL. 2322; BARRELS WATER ~.~ ¢¢RAVITY 38. 9,~ MCF 159; gOR 716.~ TBG PRESS 600 PSI.~ ANN PRESS 1630 PSI; CHOKE 24/64. CHRON ']~]:ME DISTRIBUTION (HRS): ;24. O0 - OTHER, PUMPIN(; - TESTINg 09/04/86 MIDDLE (~RC)UND SHOAL ~,5, MID. ~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, API 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERAT!OhiS: TD 11182 FT, PUMP!N(; COSTS: CUM MUD $29977, CUM WELL $35649'5 REhARMS: 6 HR TEST: BARRELS OIL 216.3~ BARRELS WATER . 65; ORAVITY 39, !~ MCF i31; QOR 606; ]'BO, PRESS 600 PSI; ANN PRESS 1600 PSI; CHOKE 24/64. NOTE: USIN(; OIRFICE METER ]'EST SEP TO MEAS (;AS; NOT TURBINE METER. CHRON TIME DISTRIBUTION (HRS): 24. 00 - OTHER, PUMPINg - TESTINg 09/05/86 MIDDLE (;ROUND SHOAL ~5, MID. (,;ROUND SHOAL, PARKER 152, AMOCO PRODUCT ION, **** **** ~**.~**** ~.*** **-~.. ~.*****~. *******~ ******** ~*** **** ******** ~*** **~. **~** ~..~ FLAC 985578-03-8, APl 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, PUMPINg COSTS: CUM MUD $29977, CUM WELL $356495 REMARKS: 3 HR TEST: BARRELS OIL 105. 1~ BARRELS WATER . 9; ~RAVITY 38.4~ DENVER REGION .~,.- ANCI4ORA6~E DISTRICT .~-x-.~ 09/24/86 .~.~ PAgE 11 MCF 65; O_,OR 618; TBg PRESS 600 PSI; ANN PRESS 1600 PSI.; CHOKE 24/64. CHR[]N TiME DISTRIBUTION (HRS)~ 24. O0 - OTHER, PUMPING - TESTING '~'~'~'~ 09/06/86 ~. ~.-'.--~ MIDDLE: GROUND SHOAL t~5, MID. QROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 9855'78-03-8, APl 507331007200, AUTH COST $350000, AI'!.[)CO W.I. 50. 0000 OPERATIONS' TD t118'2 FT, FI_OWINP= COSTS: CUM MUD $2997'7, CUM WELL $356495 CHRON TIME DISTRIBUTION (HRS): 24, O0 - OTHER, FLOWINg- - NO QUAO~E MIDDLE £~R[]UND SHOAL ~5, MID. ,~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, ~.~. ~.~. ~ .~.. ~..~,~. ~..,~ ~ ~. ~..~....~ ~.~.~ ~ ~.** .~...~,~.. ~..~..~ ~.~ ~.~, ~ ~..~.~ .~**~. ~.~**~. ~.~-~.~..~ ~ .~ ~ FLAC 985578-03-8, APl 50733i007200, AUTH COST' $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182_ FT, FLt]WIN.~. COSTS: CUM MUD $29977, CUM WELL $356495 REMARKS: 3 HR TEST: BARRELS OIL I05; BARRELS WATER .3; CRAVITY 37. 6~ MCF 66. 8.~ (}OR 63~.; TB~ PRESS 600 PSI,; ANN PRESS 1560 PSI.; CHOV, E 24/64. CHRON TiME DISTRIBUTION (HRS): ,=..4. 00 - OTHER, FLOWING' - TESTING +~'~-.'4. 09/08/86 -~.~.~ MIDDLE GR[]UND SHOAL ~f-'5, MID. O. ROUND SHOAL, PARKER i52, AMOCO PRODUCTION, FLAC 985578-03-8, AP I 50733t007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, FLOWtNr9 COSTS: CUM MUD $29977, CUM WELL $356495 REMARKS: 6 HR TEST: BARRELS OIL 207.3; BARRELS WATER-TRACE; ORAVITY 38. 4 MCF 137~ ~OR 661; TB¢ PRESS 560 PSI; ANN 1545 PSI; CHOKE 24/64. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, FLOWING - TESTIN~ *-'~-.~ 09/09/86 MIDDLE OROUND SHOAL ~5, MID. (~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, API 507331007200, AUTH COST $350000, DENVER REGION *** ANCHORAGE DISTRICT -~ 09/"24/86 ~.~ PA~E 1'-2 AMOCO W.I. 50. 0000 OPERATIONS: TD II182 FT, FLOWIN:2 COSTS- CUM MUD $29977, CUM W,-L.L CHRON TiME DISTRIBUTION (HRS): 24. OC., -- OTHER, FLOWINg- N'.] ~]'.UA~E ~-"'*~- 09/10/86 a~.~ IdtDDLE (~ROUND SHOAL ~5, MID. C~'ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, FLAC 985578-03-8, AP1 50733~.007200, AUTH COST $350000, AMOCO W. I. 50. 0000 OPERATIONS: TD 11182 FT, F'LOWIN~ COSTS' CUM MUD $¢~.~77, CUM WEuL $35~495 REMARKS: 4 HR TEST: 135 BARRELS OIL¢ TRACE WATER¢ ~RAVITY 39. 5¢ MCF Ill. 2; GOR 824~ T~ PRESS 550 PSI¢ CHOKE 24/&4; ANNULUS PRESSURE 1500 PSI. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, FLOWINg - TESTINg ~-~.-~.~. 09/11186 ~,~ MIDDLE (~ROUND SHOAL ~5, MID. gROUND SHOAL, PARKER !52, AMOCO PRODUCTION, FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO l.,,I. I. 50. 0000 OPERAT l "'"'W'~' 'TO .I. . ~.¢~,~ . !18= F']"., FLOWINf¢ COSTS: CUM MUD $29977, CUM WELL $356495 CHRON TIME DISTRIBUTION (HRS): 2.4. 00 - OTHER, FLOWINg - NO 09/12/86 MIDDLE gROUND SHOAL ~5, MID. gROUND SHOAL, PARKER I52, AMOCO PRODUCTION, . ***.-~....,,..,-**. ***.. *** **** **~. **%...~.....~*** **~. **** ~ ..~.,'t- .~*** ~*** **..x-. **** **** **** **~-~ FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERA]'IONS: TD 11182 FT, FLOWING COSTS: CUM MUD $29977, CUM WELt_ $356495 REMARKS: 4 HR TEST: 133 BARRELS OIL; TRACE OF WATER~ MCF 120; QOR 902; TBg PRESSURE 540 PSI; CHOKE 24/64; ANNULUS PRESSURE 1500 PSI. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, FLOWINg - TESTINg 09/13/86 MIDDLE C~ROUND SHOAL ~5, MID. gROUND SHOAL, PARKER 152, AMOCO PRODUCTION, DENVER REGION .~.*~- ANCHPR ....... ~ D.i:STRZCT -->.~.~ 09/24/86 ~..~ PAOE 13 FLAC 985578-03-8, APl 50733i007200, AU]-H COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, FLOWING ~rno~c',~.~,..~. CUM MUD $29977, CUM WEL= ~356493 CHRON TIME DISTRIBUTION (HRS): 24. O0 -. OTHER, FLOWIN~ - NO E4UA~E ~.-* -.? 09/i4/86 ~ -.~ ~- MIDDLE ORE,.UND SHOAL 4.t-5, MID. OROUND SHOAL, PARKER !52, AMOCO PRODUCTION, FLAC 9P. EI. 5578-03-8, APl 507~3:n07200,,~ AUTIq C,J~] ..... $350000, ~.,*.0 W I. 50. 0000 OPERATI']n~°'',..,,~ TD 11182 FI', Fi-OWtNO COSTS' r'UM... MUD $29977, CUM WELL $¢364~.~)" REMARKS' 4 HR TEST' 128. 6 BARRELS OIL; . 4 BARRELS WATER; MCF 106; ~OR 824; TBG PRESSURE 520 P,:.,I; ANNULUS PRE=.~URE !450 FSI. C~,NON TIME DISTRIBUTION (HRS)- ~'~,f,. O0 '- OTHER, FLOWINO - TESTING 09/15/86 MIDDLE OROUND SHOAL. ~5, MID. GROUND SHOAL, PARKER 152, AMOCO PRODUCTION, ~..-~..~**.~, .~ .~. ~.~. ~ ~.~ ~-~** ~.. ~ ~. **.~. ~.~. ~**.~ ~.~. ~ .~-. ~..~ ~. ~.~. **** ~**-~ **~..~... **~. ~.**~ FLAC 985578-03-8, AP1 507331007200, AUTH COST $350000., AMOCO W.I. 50. 0000 O,- ,_ ~ A]- ]7 ONS TD !1iS2 fiT, FLOWINO COSTS: CUM NUD $29977, CUM WELL $356495 CHRON TIME DISTRIBUTION (HRS): 24. O0 -OTHER, FLOWiNO- NO OUAOE 09/1.6/86 MIDDLE OROUND SHOAL #5, MID. OROUND SHOAL, PARKER i52, AMOCO PRODUCTION, ~.-~.~.. *** ~.~. **~. **~. ~*** **** **~. ***~. *** ~ *** **** ~ ~.-~ ~. ~.~. **** **~ **** ~** ~ **** ***~ F'LAC 985578-03-8, API 507331007200, AUTH COST $350000, AMOCO W. !. 50. 0000 OPERATIONS' TD 11182 FT, FLOWIN¢ COSTS' CUM MUD $29977, CUM WELL $356495 REMARKS- FLOWINg 4 HR TEST: BARRELS OIL 130.3; .7 BARRELS WATER {¢_4 HR AV~' 747 BOPD; 39 BWPD}; MCF i12; ~OR 861; PRESSURE 550 PSI; CHOKE 24/64; ANN PRESSURE 1450 PSI. CHRON TIME DISTRIBUTION (HRS)- =.~)4.00 - OTHER, FLOWIN~ - TESTINg 09/17/86 MIDDLE GROUND SHOAL #5, MID. O, ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, DENV ER REOION ~..-. ANCHORAQE DISTRICT ~-~ 09 "~ ,,,---,/86 -~.~ PAOE 14 FLAC 985578-03-8, API 507331007200, AUTH COST $350000, Ai"iE~CO W.I. 50. 0000 OPERATI[]hIS' TD 1118~?~_ F'F, FLOW COS'i-S: CUM NUD $29977, CU?I ~E~L ¢356495 CHRON TI. ME DISTRIBUTION ~¢'4. 00. -OTHER, .mLOWING NO .... "-' '"" ' _r~ QRO NtDDLE ¢.~'"';'OUND ;;t"-,UmL ~5, MT.,. UND SHOAL, PARKER i52, AMOCO PRODUCTION, FLAC '.-7'S5578-03-8, APl 50733.t007200, AUTH COST $350000, AMOCO W. ~. 50. 0000 OPERATIF)NS' 'FD 11182 FT, FLOWiNg. COSTS: (..,*,'JM MUD $29977.. CUM WELL $356495 CHR{]N T)[M'E DIS'T'RIBUTION (iqRS)' 24. 00_ - OTHER, FLOWING - NO o,.oUAgC,_ MIDDLE (-)f~OUND SHOAL 4'f. 5, MID. ~ROUND SHOAL, PARKER 152, AMOCO PRODUCTION, F'L_AC 985578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.i. 50. 0000' OPERATT~ONS: TD 11182 FT, FL. OWINO COSTS: CUM MUD $29977, CUM WELL_ $356495 CHRON TIME DISTRIBUTION 24.00 -OTHER, FL. OWINO- NO OUAOE MIDDLE OROUND SHOAL ~:~5, NiD. OROUND SHOAL, PARKER i52, AMOCO PRODUCTION, F'L. RC 9S5578-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 FT, FLO~IN¢ COSTS: CUtd MUD $29977, CUM WELL $356495 REMARKS: 6 HR FLOWIN~ TEST: 182 BBL OIL; TRACE WATER; gRAVITY 39. 1 AT 60 DE¢; MCF 105; ~OR 576; CHOKE 24/64; TBQ PRESS 520 PSi; ANN PRESS 1400 PSI. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, FLOWINg - TESTINQ ~-~-~ 09/21/86 ~ MIDDLE OROUND SHOAL ~5, MID. OROUND SHOAL, PARKER 152, AMOCO PRODUCTION, DEh~VER REGION **-,, ANCHOr~AOE D!CTRiCT._, .**-~ 0~/;'-'"'/86, ~-.'-,. *** PAOE I'=,~. F'LAC 98557S-03-8, AP1 507331007200, AUTH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 1118~ FT, FLOWiN(~ COSTS: CUM MUD $29977, CUM WE;__!._ .$356495 CF!RON TIME DIS~.'RIBUTION (MRS): ~4.00 .- OTHER, FLOWING - NO O~UAOE MIDDLE' GROUND SHOAL ~."4 MT~a n._,-,,-, . ~ , ........ r,~u~UND SHOAL: PARKER 152, AMOCO PRODUCTION ,,...,,.,578-03-8, APl 507331007200, AUTH COST $350000, AMOCO W.I. 50. OOOO OPERATIONS: TD 1118'~ FT, C,_.,::, ~ ~..') .....!flU[) $2997}' '"-t REMARKS- a HR FLOt,,,tlN~ TEST- MCF 95; ~OR 536; ]'BO PRESS 500 PSI¢ ANN PRESS i350 PSI. CHRC~' , - .J¢."i TiME DISTRIBUTION ~HRS) c~,', O0 - OTHER, FLOWiNO TESTINO *** 09123/86 *** MIDDLE OROUND SHOAL ~$5, MID. OROUND SHOAL, PARliER 152, AMOCO PRODUCTION, FLAC 985578-03-8, AP I 507331007200, AU'FH COST $350000, AMOCO W.I. 50. 0000 OPERATIONS: TD 11182 F'T'., FL. OWIN(} COSTS: CUM MUD $29977, CUM WELL $35.6495 CHRON TIME DISTRIBUTION 24. O0 -. OTHER, FLOWINO - NO GUAOE **~ ~--'IN,~L;,._ED dOt~ INFORMATION' Mir', QROUND SHOAL, MIDDLE C4ROU?,.iD SHOAL, :~5: .t' -^ ST .... ~EN.,.-.,,i O/S , ATE, AL.ASKA OPERATOR' AMOCO PRODUCTION ,JOB :[ ..... ~ ....' '"" - ~ .,'--D. I',,.,..,_]:t~--.,_E~E- THE END OF ,.]O~ SUMMARY WILL NO]- BE PRIN''''''i:-- END ;]':F REPORT W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907~ ~t - ~ l q7 July 15, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File' FEW-172-WF Application for Sundry Approval MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Application for Sundry Approval, for work Amoco proposes on MGS 17595 Well No. 5. We plan to temporarily abandon the existing "EFG" horizon produc- tion in the well and run a production test on the "A" horizon. The "EFG" is presently producing 50 BOPD and the "A" is estimated to have an initial production rate of 300 BOPD. Questions concerning this application should be directed to Jeff Blagg at 263-2207. Very truly yours, W. G. Smith Di strict ~qanager JCB/dds Attachments STATE OF ALASKA . ALA~. , OIL AND GAS CONSERVATION coM,,. _,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend LX Operation Shutdown :FZ Re-enter suspended well ..... Alter casing T-: Time extension Change approved program Plugging .... Stimulate r_ Pull tubing ~ Amend order -- Perforate :~ Other 2. Name of Operator Amoco Production Company 3. Address P.0. Box 100779, Anchorage, Alaska 99510 4. Location of well at surface ].934' FNL, 550' FWL, Sec. 31 TgN, R12W. S.M. At top ~P~'~r'°?¢ltiv~j(~%tgrv~L, Sec 30, TgN, R12W, S.M. At effective depth 704' FSL 994' FWL, Sec 30, T9N, R12W, S.M. At total depth 725' FSL, 844' FWL, Sec 30, T9N, R12W, S.M. 5. Datum elevation (DF or KB) 79.4' KB, 6. Unit or Property name Midd'le Ground Shoal feet 7. Well number 5 8. Permit number 65 -38 9. APl number33 50- -1007~-00 10. Pool MGS Hemlock and "A" 11. Present well condition summary Total depth: measured 1]. ,128 feet true vertical 10,396 feet Plugs (measured) 8677'; 10200' Effective depth: measured 8,677 feet Junk (measured) true vertical 7,952 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 598 20" 798 sx 598 598 Intermediate 2012 13 3/8" 2764 sx 2012 1950 Production 7565 9 5/8" 1950 sx 7565 6842 3767 7 1400 sx 7360-11127 6637-10395 Liner Perforation depth: measured 7730 - 9150 ,, true vertical 7006 - 8424 Tubing (size, grade and measured depth) Dual 3½" N-80 Buttress at 7,688' Packers and SSSV (type and measured depth) Baker Mode] "F" Packer at 7,648' 12.Attachments ,-..~ .: :. :,' ?:.--.. Description summary of proposal L~ Detailed operations program J~ BOP sketch 13. Estimated date for commencing operation Ju'ly 28, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certi.fy ~hat tb.e:..-fore.g,cihg is true and ~.~/.," ~' ~', ::,,.,. ~/,~,,~Z..~,~..~ correct to the best of my knowledge Title Di stri ct Manager Commission Use Only Date07/15/86 Conditions of approval Notify commission so representative may witness I Approval No. _-¢-~7 [] Plug integrity [] BOP Test [] Location clearance ~/----'~. ~ "~ ........................ -Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate DESCRIPTION SUMMARY OF PROPOSAL Amoco Production Company proposes temporarily abandoning the existing "EFG" horizon production interval and running an extended "A" horizon pro- duction test in MGS 17595 Well No. 5. The "EFG" horizon is presently pumping at 50 BOPD, 58 BWPD, and 25 MCFD. The "A" horizon is not per- forated and is estimated to have an initial production rate of 300 BOPD. Depending upon actual production rates from the "A" horizon, Amoco may apply for a permit to commingle "A" horizon production with "EFG" horizon production. DETAILED OPERATIONS PROGRAM 1 Circulate the well with dead crude to determine a kill weight. Circulate the well with an appropriate kill fluid. The following fluids will most likely be used- Kill Weight Fluid Less than 7.0 ppg Diesel 7.0 ppg - 8.8 ppg Emulsified Diesel 8.8 ppg - 9.8 ppg NaC1 - kC1 in fresh water Greater than 9.8 ppg CaC12 in fresh water The estimated bottomhole static pressure for the well is 4200 psig and the estimated kill weight is 9.5 ppg. 3. Set back-pressure valves. Nipple down tree, Nipple up BOP's and pressure test. Pull back-pressure valves. 4. Pull tubing. 5. Rig up electric line logging unit. Test lubricator. Run CBL from 5,900 feet - 7,339 feet. 6. Set retrievable bridge plug at 6,410 feet. 7. Perforate 6,225 - 6,340 feet, 4JSPF, with tubing conveyed perforating guns. 8. Complete well with dual tubing string hydraulic pump. 9. Nipple down BOP's, nipple up tree and test. 10. Return well to production. Amoco Production Company ENGINEERING CHART SH E,T.T NO. FIL~ 01.-' UYDRIL ~N NULhP,. BOP / ! 5-0 ~3 r3 , I .SL' I ' Rb, r-'t V~UD .. L.T. 7339' '-~ 9-5/8" set ~ 7565' I MGS 17595 Well No. 5 Wellbore Diagram Casin9 record 20" 79.6# 13-3/8" 54.5# 9-5/8" 40 & 43.5 7" 29# Completion EcLu i l)men t Depth 598' 2012' 7565' 7339 - 1t,127' Depth LS: ] 3-1/2" N-80 Buttress Tubing 2 3-1/2" Buttress Tubing Pup 3 3-1/2" EU 8RD x 3-1/2" Buttress XO Pup 4 Model 'B' Kobe BttA 5 3-1/2" Buttress Tubing 6 Baker 3-1/2" Buttress Locator 4-1/2" OD 3" ID 7 Baker 4" OD Seal Assembly 3" ID 8 1Jt. 3-1/2 "Buttress Tubing 9 Baker Bull Nose Sear Sub SS:lO 3-1/2" Buttress N-80 Tubing 11 2-3/8" BRD x 3-1/2" Buttress XO Pup 7264' 7268' 7273' 7296' 7638' 7639' 7656' 7687' 7688' 7276' 7281' Baker Model 'F' Packer set @ 7648' with 4" Seal Assembly 'B' 'C' 6q48-53' 6805-55' 6460-75' 6875-6915' 5520-70' 6935-75' 6595-7750' 6995-7020' 6708-23' 'D' 7110-25' "EFG" Retainer 'E' Set @ 8677' 4/75 None 10,200' 'F' 7730-60' 7885 -7910' , 'G' 8040-8255' 8285-8430' 8478-8540' 8560-8602' 8620-34' 8690-8935' 9080-9150' SUBJECT ~-'""~0~ 0 SE"./~ Amoco Production Company ENGINEERING CHART U! Sheet File Appn t-:&o,:-.:':o~;:_.5! 'W:6 mp,.r..~ 75~c~ - 1. Of l 1]. W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 January 31, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation CommissiOn 3001 Porcupine Drive Anchorage, Alaska 99501 File- FEW-O32-WF Dear Si r: Subsequent Notice MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in duplicate for your records is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of work recently completed on Well No. 5. Very truly yours, W. G. Smith District Manager Attachment JCB/le 037/JCB1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY ,IOT IC .$ AND RB RTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name ~f Operatox , 7. Permit No. amoco Froauction Company 65-38 8. APl Number ~ 3. Addre~. 0, BOX 100779, Anchorage, Alaska 99510 50- 733-1007,2-00 4. Location of Well Leg 1, Slot 6, MGS, Platform Baker 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75' KB 6. Lease Designation and Serial No. MGS 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 5 1 1. Field and Pool Middle Ground Shoal Hemlock 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). Between January 24, 1986 and January 27, 1986, AMOCO Production Company: . 2, Rigged up a coiled tubing unit w/lubricator and pressure tested to 4,000 psi. Washed fill from 8044 - 8675 feet. Rigged down coiled tubing unit. Returned well to production. 14. I hereby certify that the [zoregoi~g/~S true and correc.,t, to the best of my knowledge. .,/_~/~ ~ · District Manager The space below for Commission use 1/3.1/86 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 January !4, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File- FEW-O15-WF Dear Sir' Notice of Intent ~MGS Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to make the necessary repairs to Well No. 5, Platform Baker. Very truly yours, W. G. Smith Di strict Manager Attachments JCB/dds STATE OF ALASKA ALASK~ . ' AND GAS CONSERVATIONf~, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name ofA~ii($~)or Producti on Company 3. Addressp. O. BOX 100779, Anchorage, Alaska 99510 4'L°cati°~c~Ve~l, Slot 6, MGS, Platform Baker 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. 6. Lea~l~esif~i¢~)andSerial No. 7. Permit6~.- 38 8. AP' N~F~r 1007~-00 50- 9' u nit °~4~e~lN~m~ rou n d Shoal 10. Well Number 5 1 1. FiCdand Pool Mldd]e Ground Shoal Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate} ISubmit 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 January, 1986, Amoco Production Company proposes to: . 2. 3. 4. Rig up coiled tubing unit with lubricator and pressure test. Wash fill from 8,070 to 8,677 feet. Rig down coiled tubing unit. Return well to production. 14. I hereby certify that the foregoing is true alnd correct to the best of my knowledge. Signed . Title District Manager The space below for Commission use Date 0!/!4/86 Conditions of Approval, if any: Approved by COMMISSIONER Appl-oved Copy P,,r,,.~t u r m~l By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent January 15, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-O61-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Report HGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our recent work on MGS 17595 Well No. 5, Platform Baker, Cook Inlet, Alaska. We killed the well, pulled the tubing, cement squeezed the 'BCD' zones, and ran a new bottomhole assembly and tubing with a packer. Yours very truly, ~',;' ,..,' ~..--,~, L. A. Darsow District Superintendent Attachment BFS/klt RECE VE .JAN 1 g ]. 8z A~ch0rage STATE OF ALASKA ALAS'F,,, ,L AND GAS CONSERVATION ~.,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL~ OTHER [] 2. Name of Operator Amoco Production Company 3. AddFess P. O. Box 779, Anchorage, Alaska 99510 4. Location of Well Slot 6, Leg l, Middle Ground Shoal Platform Baker 1934' FNL, 544' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75' RKB 12. 7. Permit No. 65-38 8. APl Number ~ 5o- 733 100 7Z00 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 5 11. Field and Pool I 6. Lease Designation and Serial No. Mi ddl e 6round Shoal MGS 17595 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 L-~ 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). December 2 - December 25, 1981- 1. . . . . Killed well and pulled tubing. Could not establish a pump-in rate in 'D' zone. Cement squeezed 'C' and 'B' zones. Squeezes would not hold pressure; resqueezed. Retested. Set packer at 7650'. Ran dual string 3-1/2" tubing and Kobe Type 'B'.~:~o~t~q~t~¢~q~. assembly. JAN I e ).982 Aiask~ 0~ & ~as 0m~s. Omm~ssl'o~ 14. I hereby certify th,.a(t~he f_or~g_o_~g, is true and correct to the best of my knowledge. Signed .... L.'"'¢' ./.:~--~S~..'¢/~"/L~','~Z?~''~''~'~'-Title District Superintendent The space below for Commission use Conditions of Approval, if any: Date 1/15/82 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 L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 December 2, 1981 File' LAD-1294-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Notice of Intent MGS 17595 Well No. 5 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our plans to cement squeeze the "BCD" zone perforations (Middle Kenai Sands of the Tyonek Formation), which we no longer produce from, and replace the Kobe bottomhole assembly in MGS 17595 Well No. 5. Verbal approval was received by B. F. Smith (Amoco) on this date from Russ Douglass of your office. Yours very truly, L. A. Darsow District Superintendent Attachment BFS/klt EEE ¥ED DEC 0 4 . 981 Alaske 8i~ & 6~s C0~s. C0mmi~sio~ Anchorage STATE OF ALASKA ALASK~ ~. .... AND GAS CONSERVATION CO~-,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL 2. Name of Operator COMPLETED WE LLX-_X OTHER [] Amoco Production Company 3. AddFess P. O. Box 779, Anchorage, Alaska 99510 4. Location of Well Leg l, Slot 6, MGS Platform Baker 1934' FNL, 544' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75' RKB MSL 12. 6. Lease Designation and Serial No. ADL 17595 7. Permit No. 65-38 8. APl Number 50-733-1007100 9. Unit or Lease Name MGS 17595 10. Well Number 5 11. Field and Pool Middle Ground Shoal 'G' Zone Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well NOTICE OF INTENTION TO: (Submit in Triplicate) [] Alter Casing [] [] Abandon [] [~ Change Plans [] Perforations Stimulation Repairs Made SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other Pull Tubing E~ 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). 1. Kill well and pull tubing. . Cement squeeze 'BCD' zone perforations (6448-6453' 6460-6475' 6520-6570' ' , 6595-6650' 6708-6723' 6805-6855' , , , 6875-6915' 6935'6975' 6995-7020' ' , 7110-7125'). ' 3. Run tubing and Kobe bottomhole assembly. 4. Return well to production. Estimated date for work is December 3, 1981. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. DEC 0 z, i 981. Oi~ & Gas 00~s. 60mmtssi A~chora.~e The space below for Commission use ~'~ Conditions of Approval, if any: Approved by. Form 10-403 Title District Superintendent COMMISSIONER Date 12/2/81 ~eturned By Order of the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent August 7, 1980 File- LAD-823,WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Procupine Drive Anchorage, Alaska 99501 Dear Si r' Notice.of Intent Middle Ground Shoal Field State Lease 17595 Well No.. 5 Platform' Baker ', Cook Inlet, iAlaSka Amoco Production Compar~ Post Office Box 779 Anchorage, Alaska 99510 907-272-8471 Attached in triplicate is a State of Alas'ka Form 10-403, Sundry Notices and Reports on Wells. On January .24, 1980 the referenced well was squeezed with a methanol-water mixture to break a suspected water or emulsion block. Yours very truly, ,..;:' ,,,,-,,/C"::'.J ........ ] ..... , ~..~,, .:?...,_..., ~...,;, 'Z,... L. A. Darsow Di stri ct Superintendent Attachment .BFS/llr Form 10-403 Submit "Intentions" in Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF 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 "APPLICATION FOR PERMIT--" for such proposals.) WE.L LAJ'0-I-L' LI V!GAS I I WELL L.--I 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 Slot 6, Leg 1, Platform Baker 1934' FNL, 5441 FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. 78.75' RKB MSL 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. MGS 1 7595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. 5 10. FIELD AND POOL, OR WILDCAT Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, 12. PERMIT NO. 65-38 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data R12W, S.M. NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L.__J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING I I ABANDONMENT* (Other) Met hanD 1 -Wa-t-E-r Squeeze (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 ¢letalls, and give pertinent dates, including estimated date of starting any proposed work. 01/24/80 - Pumped 450 barrels of 20% methanol - 80% water into Hemlock Formation to break a suspected water or oil emulsion block. '/16. I hereby certify that tl)e'foregolng is true and correct "',~ ~-'"~..'"i'i. .... ~-/ /. /" S,GNEO ... District Superintendent TITLE DATE August 7, 1980 /.,(This space for State office use) / ,,, "tPPROVED BY ~3NDITIONS OF APPROVAL, IF ANY: ',~ See Instructions On Reverse Side DATE L. A. Darsow District Superintendent December 7, 1979 Fi 1 e' LAD-1060-WF Amoco Production Comp~any . Anchorage, Alaska 99510 907- 272-8471 . --:: .--,.. ~,-~:~ ,.,. Mr. Hoyle H. Hamilton, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent Middle Ground Shoal Field State Lease 17595 Well No. 5 'P1 atform ' Baker, ' Cook' I nl et, 'Al aska Attached in triplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells. Approval is requested to squeeze a mixture of methanol and water into the Hemlock zone of the referenced well to break a suspected water or emulsion block. Yours very truly, ,'" \.> "~.~.".. ~V' ,'.' ~.,~'~ .... L. A. Darsow Di stri ct Superintendent Attachment YRY/klt Form 10-403 Submit "Intentions" In Triplicate REV. 1-10-73 & "SubseQuent Reports" in Duplicate STATE OF 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 "APPLICATION FOR PERMIT--" for such proposals.) 1. O~L I Yl GAS WELLL~J WELL 2. NAME Of OPERATOR OTHER Amoco Production Company 3, ADDRESS OF OPERATOR P. 0. Box 779, Anchora§e, Alaska 99510 4. LOCATION OF WELL At surface Slot 6, Leg 1, MGS Platform Baker 1930' FNL, 536' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 78.75' MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L----J PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT Or ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Methanol-Water Squeeze 5. APl NUMERICAL CODE None Assiqned 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MGS State 17595 9. WELL NO. 5 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, R12W, S.M. 12. PERMIT NO. 65-38 ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSE'D OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The proposed work is to squeeze 440 barrels of a mixture of 20% methanol and 80% water in the subject well to break a suspected water or oil emulsion block. 16. I hereby certify that the.~!ng Is true and correct TITLE District Superintendent DATE December 7~ 1979 CONDITIONS OF/~PROVAL, IF~NY: TITLE. See Instructions On Reverse Side October 5, 1979 Re: Violation of Regulations Mr. L. A. Darsow District Drilling Superintendent P. O. Box 779 Anchorage, Alaska 99510 Dear Leonard: I ba.ve confirmed this date through my telephone call to Golas, your District Engineer, that a serious fire and tempor- ary abandonment occurred on Platform Baker approximately 'two. weeks ago due to the escape of gas fr°m"Well ~o,' 17595-No.5 during a workover operation. The Commission members were all disappointed to hear of the occurrence of this incid, ent through a third party. This letter is to bring it to your attention that in the State Oil and Gas Regulations there is a regulation in Article 3, 11 AAC 22 205 entitled "Not ' . .ificatlon of Accidental Loss of Oil or ~.,as". Under this regulation the Commission requires and expects to receive notice from operators %~hen any hy~rocarbons are allowed to escape and catch fire. The failure to notify the Commission tL~.ely of this event circumvents the Commission's ability to inspect and verify the cause and nature of an incident and to verify the actions taken whether good or bad. We anticipate that when our new revised regulations are completed, around the first of 'the year, they will better aid you as an operator in understanding and complying with such matters.. To further assist you I'm attaching a copy of our "proposed regula- tion 11 AAC 22.205~'. In addition to the information required under Section (b) of this proposed regulation you might also inform us to what extent there was damage to the platform or rig. ' Sincerely, ,. / .... ~.,I · ,~' Lonnie C. Smith Corem i s s ione r Enclosure LCS .... be 7 8 9 10 11 12 13 14 15 16 19 20 21 22 23 25 26 27 28 29 11 AAC 22.205. NOTIFICATION OF ACCIDENTAL LOSS OF OIL OR GAS. (Substantially revised) (a) The commission must be immediately notified by the opera- tor of any accidental-loss of oil and/or gas from any drilling or producing well. Such notification does not relieve the operator from complying with any other notifi- cation requirements imposed by statute or regulation. (b). Within five days after the accidental loss, the operator shall submit a written report to the commission detailing the following fact~ (1) time of incident; (2) location where incident 'tOQk place; (3) volt~mes of 'oil and/,°r g~'s lost; ,.[2 (4) cause,',, Df the , (5) actions 'taken a.~d planned to prevent further loss; and · {6) equipment or procedural changes, if applicable, to prevent the loss froin recurring. (In effect before 7/28/.59; am 6/20/64, Reg. 3.6; am. 9/30/67, Reg. 25; sec. 2.152 prior to 4/73; sec. 205 from 4/73, Reg. 45 am / /79, Reg. ) Authority: AS 31.05.030 -53- L. A. Darsow District Superintendent May 16, 1979 File: LAD-450-~F Mr. Hoyle H. Hamilton, Cc~issioner Alaska Oil and Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 c ©,,,..,t,'v~ Amoco Production Company- Post Office Box 779 Anchorage, Alaska 99510 907-272-8471 Dear Mr. Hamilton: Notice of Intent MGS 17595 Well No. 5 Platform Baker, CookInlet~Alaska Attached is State of Alaska Form 10-403 in triplicate. On April 2, 1979 the bottcmhole assembly was pulled on MGS Well No. 5 due to scale problems. Production frcm the' Middle Kenai Sands and the Hemlock C0nglcmerate was ~. gled before thiS workover, During the repair a packer was set between the two zones to test the producing rate of only the Hemlock formation. The well was reperforated and acidized due to a low initial produc'.zng rate in the Hemlock formation. The well is currently being tested in only the Hemlock formation. Yours very truly, x L. A. Darsow District Superintendent Attachment DRR: sls Form 10-403 Submit "1 ntentions" in Triplicate REV. 1-:10-73 & "Subsequent Reports" in Duplicate STATE OF 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 "APPLICATION FOR PERMIT---" for such proposals.) o,- ~ GAS I--I WELL~.' WEL~' ' OTHER 2. NAME OF OPERATOR Amoco Production CQmpany 3. ADDRESS OF OPERATOR P. O. BOX 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface $1ot 6, ~e9 1, 1934' FNL, 544' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 78.75 (RT) 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. MGS 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. MGS 17595 Well No. 5 :10. FIELD AND POOL, OR WILDCAT Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30~ T9N, R12W, S.M. 12. PERMIT NO. ~ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1. Pull bottomhole assembly. 2. Clean out to PBTD (8685'). 3. 'Set packer at .7650'. 4. Run bottcmhole assembly. . Perforate Hemlock formation with through tub'.~ng guns, 2 JSPF 0° phasing. . Acidize Hemlock formation through ~tubing with Combination HCl, Mud Acid and Clay Acid. i'. ~ ':,-;: ;,., L,:' 16. I hereby certify that th,e~lng is true and correct . ,, //, ~ -~ ~, /--'-'-' TITLE District Superintendent DATE May 16, 1979 (This space for State office use) , ,,, ,,,, .... ......~ ~, ~:, C,,',,,,,~,~',L,~L;:,~,,(!~:t~,[ See Instructions On Reverse Side DATE Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Super~ntencien[ June 17, 1975 File: GJR-512-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations MGS 17595 Well No. 5 SMGS Unit Well No. 2 Attached herewith are the State of Alaska Forms P-4 furnishing monthly workover operation information for Middle Ground Shoal 17595 Well No. 5 and South Middle Ground Shoal Unit Well No. 2. Yours very truly, George J. Ross Area Superintendent. At tachments DP'/:$~OI'I 'OF OIL AND GAS "~ A ~' AN,~HOR. Gc Form No. P--4 R.L"V. 3-1-70 STATE OF ALASKA SZ;BMrr OIL AND GAS CONSERVATION COMMI'I-[EE AI~! NL'A~ERiCAL CODE 50-133-10071-00 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~ LEASE DESiGN~A?ION A.X-D $E1RIAL NO ADL-17595 1. ~ IF I~DIA~ A~i'~E O~ TRIBE NA~E 0IL ~ GA8 ~ WRLL-- W~LL ~ 0T~R ~. N~ME OF OP~TOR 8. L~IT FA~{ OR LEASE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPhiR 9 WE~ NO P. 0. Box 779, ~chorage,~aska 99510 5 4 ~O~A~ON OF W~ I0 ~iELD ~ND P~L, OR WH~DC&T H~ddle Ground Shoal 1930' FNL, Slot 6, Leg 1, MGS Platform Baker, 536' FWL, Sec. 31, T9N, R12W, S.M. SEC, T.. R. M (Bottom HO~E Sec. 30, T9N, R12W, S.M. 12 PE~,.MIT NO 65-38 REPORT TOTAL DEPTH AT END OF MONTH. CHA. NGES IN HOLE SIZE, CASING AN'D CEA~[ENT!iNG JOBS INCLUDING DEPTH SET AND VOLUMES USED, PER2'ORATIOI~S. ~I-F~TS A/X!T) RESULTS FISHINrG JO~S JIiNK I.N HOLE AND SIDE-~,ACKED ItOLE ~ND ~Y O~R SlGNIFIC~T ~G~ ~' HO~ CO~ITIONS Summary of Operations for May. 1975: May 1-3: Circulated to condition mud and tripped out with 9-5/8" packer and bridge plug. Tripped in open-ended to circulate and con- dition mud. Tripped out and laid down drillpipe. Ran Kobe bottom hole assembly and dual 3-1/2" tubing strings. May 4-6: Landed tubing, nippled down the BOP and nippled up the tree. Displaced mud with power oil and installed K6b~ 4-way valve. Circulated well clean with power oil and ran Kobe pump. Operations completed May, 6, 1975. Production prior to workover: March 5, 1975: 129 BOPD, 2 BWPD, 65 MCFD Production subsequent to workover: May 20, 1975: 503 BOPD, 77 BWPD, 240 MCFD Final Report s~..~~%~-% .~1 f'~ ~.-\kc,~-~", ~T~ Area. Superintendent_ .... n.~ _.June 17_, 1975 .j x ,-' ....... ~-~.-.; .... ~; L ,,1 NOTE --Report on ~is form is required for each cQll~dar ~nth% regardless of Jh~ It~jis ~f o~Iratio~, and must ~ filed in duplicate with the oil and gas conservation commi~ee by the 15~ of the su~c~ding month, u~l~ otherwi~ ~r~cted. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 May 13, 1975 File: GJR-410-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations MGS 17595 Well No. 5 SMGS Unit Well No. 2 Attached herewith are the State of Alaska. Forms P-4 furnishing monthly workover operation information for Middle Ground Shoal 17595 Well No. 5 and South Middle Ground Shoal Unit Well No. 2. Yours very truly~ [/John C. Schillereff Supervisor in Charge Attachments ~r~t-m No. P--4 ~R..~'V, 3-1-70 STATE' ~.,,' ALASKA suBMrr ~ D~P. LmA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~LL ~V~LL OTHER :.NA.MEOFOP~TOR Amoco Production Company ADDRESS OF OPKIIATOR P. O. Box 779, Anchorage.~ Alaska 4 LOCATION OF W~.T.T. 99510 Slot 6, Leg 1, MGS Platform Baker, 1930' FNL, 536' FWL, Sec. 31, T9N, R12W, S.M. AP! N~%ERICAL CODE 50-133-10071-0 g LF. ASE DESiGAK~T'IO:g A%-D SERIAL NO ADL-17595 ? IF INDiA)~T AL/,DTi-~,E Ol~ TRIBE 8 L.~.'IT FARA{ OR LEASE MGS State 17595 WELL 5 I0 FIELD AND POOL. OR WILt)CAT Middla Groun~ Shoal SEC, T., R. M (BOTTOM HOI-.E O~J-P_g~rtr~ Sec. 30, T9N, R12W, S.M. P~]T ~O 65-38 13. REPORT TOTAL DKPTH AT END OF MON~,CPI~NGES IN HOLE SIZE. CASING AN-D CEMF. NT!NG JOBS INCLIiDING DEPTH SET A~ VOL~S USED, P~ORATIONS. ~.STS ~ RESULTS FISHING JO~ JI.~K IN HOLE AND SIDE-~.ACKED HOLE AND ~Y O~R SIGNIFIC~T ~G~S ~ t{O~ CO~ITIONS Summary of Operations for April 1975: April 13-21: Opened mandrels and circulated 8.6 ppg oil base mud to kill the well. Removed the tree and installed BOP. Pulled the dual tubing strings, packer, seal assembly and tailpipe. Milled over packer at 7252', jarred loose and recovered packer. Cleaned out hole to 8700' and tripped out. April 22-24: Ran and set permanent cement retainer at 8677'. Per- forated the following intervals with 2SPF: 6448-6453' 6875-6915' 8170-8255' 6460-6475' 6935-6975' 8285-8430' 6520-6570' 6995-7020' 8478-8540' 6595-6650' 7110-7125' 8560-8602' 6708-6723' 7730-7790' 8620-8634' 6805-6855' 7885-7910' April 25-30: Acidized in three stages as follows: Interval #1 Packer set at 7390' #2 Packer set at 6750' Bridge plug set at 7150' #3 Packer set at 6331' Bridge plug set at 6750' Acid Type Volume 15% HC1 3100 gal. 15% HC1 1790 gal. 12-6 Mud Acid 17,000 gal. 15% HC1 1550 gal. 12-6 Mud Acid 14,244 gal. Total depth 11,128', plug back depth 8677'. 14. I here~ certify thatathe forel~ing is true and correct SrGr~, .',,;,~' 6.,~ ,....~.]','..~.,'/.J-./-.(Y..~ ,,~-:-~ TXTL~ Supervisor in Cha~ eL r~A~..,..._Ma.x] 13, 1975 -...o.o. ,,,. ,o.. ,. ,or .o,, ,o,...o, .o.,,, ,.,,o,.,.. ,,..,.,.. ,,, - , oil and gas coneervation commi~ee by the 15th of the succeeding month unl,~ ~tharwila dar,cted~l]~, Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 March 27, 1975 File: GJR-271-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Sundry Notice for Middle Ground Shoal 17595 Well No. 5 Attached is a State of Alaska Form 10-403 requesting permission for a workover on Middle Ground Shoal 17595 Well No. 5 as described therein. Yours very truly, George J. Ross Area Superintendent Attachment Form 10 -403 REV. ~ - [0-7~ ISmbmtt "Intentions" in Tr/plic~te & "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 p,'oposals to drill or to decpen Use "APP~IC.-k'FION 'FOR [~'EtL~i'F---'" 'for such 'prol~osals.) 1 WELL ~ WELL~ OTHER 2.NAME OF OPEH.ATOR _Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4. LOCATION OF W~.I.L At surface 5. APl NU~LER/CAL CODE None assigned 6. LEASE DET~IGNATION A. ND SERIAL NO. ADL-17595 7. IF INDIA.N, A.LLOT~F_~ OR TRIBE NAM_~ 8. UNIT, FA-R-~ OR LEASE NAME FiGS State 17595 9. WlKLL NO. 5 10. FLEI~D A~ND POOL, OR WILDCAT Slot 6, Leg 1, MGS Platform Baker, 1930' FNL, 536' FWL, Sec. 31, T9N, R12W, S.M. Sec. 30, T9N, R12W, 13, ELEVATIONS (Show whether DF, RT, GR, etc. 12. PEIl2~IT NO. RKB 78.75' MSL 65-38 Check Appropriate Box To In.d}cate Nature of NOtice, Re. 3ort, or Other Data MGS - A, BCD, EFG Pools 11. SEC., T., R,, M,, (BOTTOM HO4E OBJECTIVE) S.M. NOTICE OF INTENTION TO: TEaT WATER aHUT-OFF I [ PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZm ARANDONs REPAIR WELL CHANOE PLANR ~ Other ) RUBaEQUENT REPORT OF : WATER alIUT-0FF REPAIRINO WELL FRACTURE TREATMENT ~OOTING OR ACXDIZXNG ABANDONmEnT' (Other) (NOw~: Report re~ult~ of multiple eomvletion on Completion or Recompletton Report and Log form.) I5. DESCRIBE PROPOaED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The proposed work is to: 1. Remove gas lift equipment and clean out to TD. e Reperforate BCDEF zone with 2JSPF (selected intervals between 6448' and 7910') and G zone with 2JSPF (selected intervals between 8040' and 8634'). Be Acidize the BCD and EFG zone perforations with 40 gallons/ft. 12-6 Ultra Mud Acid in six stages. e Pending State approval, well will be returned to production with hydraulic pumping equipment producing from the BCD and EFG zones commingled. '£, 16. I hereby ce~y that the foregoi~ue and correct TITLE Area Superintendent ~i~ Hatch 27, 1975 (Thia space for State ofll~ce~ uae) CO~DIIIONt Ol~'it~l~15, I~~ ~: TITLE See I,nstructions On Reverse Side April 21, I967 ~¥era-i:,ions f~or 'i:he a'b~ ~'e~e~e.~ed FORM 470 2-57 PAN AME1HCAN PETROLEUM COPPO ION P. O. Box 779 Anchorage, Alaska 99501 April 4, 1967 File: Re: FKK-508-WF Packer Leakage Test MGS State 17595 Well No. 5 '/ Mr. Thomas R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Attached are the original and two copies of a packer leakage test performed on our MGS State 17595 Well No.,fi'on December 29, 1966. As indicated on the charts, the test was conducted by pumping into the tubing strings and casing annulus with a Dowell pumping unit. The test points and the sequence of events are labeled on the charts. Signatures of Dowell and Pan American personnel participating in the test are also shown on the charts. Yours very truly, Attachments FORM 470 2-57 PAN AMEmCAN PETROLEUM C0 ION Po O. Box 779 Anchorage, Alaska 99501 January 26, 1967 File: FKK- 91-WF Re: Form P- 7 Completion Report MGS State 17595 #5 Mr. Thomas iR. Marshall, Jr. State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Enclosed please find two Forms P-7, Completion Report, for the well MGS State 17595 No. 5, with attachments describing the perforations and chronological well history. A sepia of the electric log is also enclosed and a print of this log was previously furnished. A mud log was not run on this development well. Encls. Yours very truly, Ip. K. Krebill Area Superintendent Form P---7 SUt~IT IN D', .~rE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Sl l'll('t JO n,q on reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WEI,I, DRY Oilier 7. UNIT AGItEEMENT NAME b. TYPE OF COMPLE~ON: WEI, L OVER EN BACK IiESVR. Other ~. FARM OR I. EASE NAME 2. NAblE OF OPERATOR MGS State 17595 American Petroleum ~orpora~xon ~. ,~.~ ~o. 3. ADDRESS OF OPERATOR 5 P,O, Box 779, Anchorage, Alaska 99501 x0. 4. LOCATION OF WELL (Re~ort location clearly and in accordance with a~y State requirements) xtsu~aceSlot 6, Leg 1, MGS Platform B; 1930* FNL, 53~~ FWL, Middle Ground Shoal Sec. 31, T9N, R1ZW, S.M. tt top prod. interval reported below 692' FSL, 399' FWL, Sec. 30~ T9N, R12W, S.M. At total dep~ TgN, RlgW, S.M..~::.: 65-38 ~ 1g/13/65 Kena~ Alaska 15. DAT~ SPUDDED [ 16. DAT~ T.D. REACIIEI) [ 17. DATE COMI'J,. (~dy, to prod.) ~ ... 'z/,~' ,-- 1112 8MD 10 837 ~ 11042 DR.~E~ 5. I,EASE DESIGNATION AND SERIAl, NO. , ADI, 17595 6. II-' INDIAN, AI, LOTTEE OR TRIBE NA.ME 11. SEC., T., R., M., OR Ill,OCR AND SURVEY OP. AREA Surface: Sec. 31, T9N, R12W, S. Mo 18. ELEVATIONS (DF, RI~B, RT, GR, ETC.)* 19. EI,EV. CA~INGIIEAD 15 radenhead Outlet RKB 78. 75' MSL 41-1/2' above MSL BACK T.D., MD & TVD llOW MANY* Dual 24. PRODUCING INTERVAL(S), OF Tills COMI'LETION---TOP, ROTTOM, NAME (MD AND 'TVD)* Pools t5, C & D: 6448-7125 Pools E, F & G: 7730-9150 26. TYPE ELECTRIC AND OTHER LOGS RUN 25. WAS DIRECTIONAl, SURVEY MADE Yes ' DIL, Density, 1ES, PML, Dipmeter, CBL, BSL h2tf. WAS WELL CORED tempted, but recoYery no 2s. CASING SIZE WEIGIIT, LB./FT. 20" 13-3/8" 9-5/8" ,29. SIZE 7I1 CASING RECORD (Report all strings set in well) I)EPTII SET-'~'MDj .......... ' ...... :'-li~ijE-S'i~'k ............................. }~}ii'~IE~TING RECORD / AMOUNT rULI,ED - -I' ............................. ~' i~~ -/ ~~ ~cmt w/964 sx TOP (MD) 7360' LINER RECORD nOTTOM (MO) 11127' 31. PERFORATION nECOgO (Intcrval, size and number) 33.* See Attachment A SACKS CEMENT* 1400 SCR~,EN (UP) 30. TUBING nEco~:~See sketch.) ........ S__I_7.,E I DEPTH SET (Mo) PACKER S}:T (MD) , I 605z, "" 3-1/~J--I 9195' 725Z' (Single) 82. ACID, SItOT, FRACTURE, CEMENT SQUEEZE, ETO. DEPTII 'INTERVAL (MD) [ AMOUNT AND KIND OF MATERIAL U~ED DATE FIRST PRODUCTION 6/Z8/66 DATE OF TEST lZ/Z7/66 FLOW. TUBINO PRESS. PRODUCTION L PRODUCTION METHOD (Fl0wing, gas lift, pumping--size and type of pump) [ WELL STATUS (Producing or shut-in ) ~ools E, F & G Flowing Producin~ CASINO I'RESSURE CA I,CUI,ATEI) Oil,---Bill,. (;AS---M CF. WATI,;R--BBL. 24-IIOUR RATE OIL GRAVITY-API (CORR.) 135 0 -' ~ 248 I 223 [ 0 37 5° 34. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ' TEST WITNESSED BY 35. LIST OF ATTACHMENTS Flared "A" (list o£ perfs), Well History, 1ES log, well bore sketch, test data for Pools 15, C,~ 36. I hereby certify that the foregoing and attached information is complete and correct as determined from all available records /' TITLE Area Superintendent VAT~ . l-Z7- 67 *(See Instructions and Spaces [or Additional Data on Reverse Side) PAGE 1 INSTRUCTIONS General: This form is designed for submitting a complete and correct w~-~l completion report and log on all types of lands and lease~ to either a Federal agency or a State agen~y~ or both, pursuant to applicable Federal and/or State laws and X~gulations. Any necessary special instructions concerning the use of this form and the number of copies to J~ submitted, particularly with regard to local, area, or regional proc~Iures and practices, either are shown below or will be issued by, or may be obtained from, the local Feder~ 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, Copi~es of all currently available .logs (drillers, geologists, sample and core analysis, all types elestric, etc.), form~ tion and pressure tests, ~nd directional surveys, should be attached hereto, to the extent required by applicable Federal and/or State laws and regulations. All attachments should be listed on this form, see item 35.' ~ I$~m 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance ~with Federal requirements. Consult local State or Federal office for specific instructions. ~- ~ Item 18: Indicate which elevation is used as 'reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachment~. ~ I~¢ms ~2 ~ ~4: If this ~vell is completed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 show the produciff~-- interval, or intervals, top(s), bottom(s) and name(s) (if any) for only ~he interval reported in item 33. Submit a separate report (page) on thi~ form, ad~luat'ely identiiiq~ for each additional interval to be separately produced, showing th'e additional data pertinent to such interval. : I$em 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. ]~¢m ]3: Submi~ a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) 37. SUMMARY OiV POROUS ZONES: SHOW-: AIoL IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL DRILL-STEM TESTS, INCLUDING 38. GEOLOGIC MARKERS DEPTH INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN, ~LOWING AND SHUT-IN PRESSURES, AND RECOVERIES FORMATION TOP J BOTTO~ DESCRIPTION, CONTENTS, ETC. TOP NAME MEA8. DEPTH TRU~ VERT. DEPTE . ~ (_ . .. .. : .. ~.. m I';--7 / · SUBMIT IN Dt ~ .... " · ATE OF ALASKA ',. .,or ~- OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* W El,l, W ELl, DR Y Ol her b. TYPE OF COMPLETION: WELL OVER EN BACK RE,qV R. 2. NA,,E OF OPERAT~an America,, .~,'.tr,,le,m Cart/, Other 3. ADDRESS OF OPERATOR P, l,-:' ' ' ") /~,I',,K~HO RAG E, ALASKA 9950] 4. LOCATION OF WELL (Report location clearly and it~, accordance with arty State requirements)* At surface Effective: July 1, 1964 5. I,EA,qE DESIGNATION AND SERIAL NO. (~. IF INDIAN, ALI,OTTEE OR TRIflE NASIE 7. UNIT AGREEMENT NAME S. FARM OR LEASE NAME 9. WELL NO. 10.~I~D ~ND POOL, OR WIlDCaT 11. SEC., T., R., M., OR BI.0CK ~ND 8~'ItVEY Ol1 AREA At top prod. Interval reported below At total depth 15. DATE SPUDDED 16. DATE T.D. REACIIED ] 14. PERMIT NO. [ DATE ISSUED 12. BOROUGH 13. STATE 17. DATE COMPL. (Ready to prod.) [ 18. ELEVATIONS (DF, lilt, n, RT, GR, ETC.)* [19. mmv. CASINGIlEAI) 21. PLUG, BACK T.D.. MD & TVD I 22. IF MUI,TIPI,I.] COMPL., 20. TOTAL DEPTH, MD & TVD 23. INTERVAI,S ROTARY TOOLS CABLE TOOL,q. tIOW MANy* 24. PRODUCING INTERVAL(S), OF TI'IlS COMPLETION---.TOP, I10'I.'TOM, NAME (},ID AND 'TVD)* I)IIlLLED BY 25. WAS DIRECTIONAL 26. TYPE ELECTRIC AND OTtlER LOGS RUN SURVEY MADE /27. WAS WELL CORED 28. 29. CASING SIZE WEIGHT, LB./FT. SIZE TOt (~D) CASING RECOI~I) (Report all strings set in well) DEPT. SET (~'i)) .................... liOL~F-',qi~,'k .............. i ................. N~'h'i/'~¥i.q~'-ffE~ ....................... l ....... A,MOIINT PULI,ED LINER RECORD 30. TUBING RECORD SIZE VZrTU SET (~ID) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) 31. PERFORATION RECORD (Interval, size and number) i3.* ATE FIRST PRODUCTION I'ACKI':R SET (SID) PRODUCTION 32. ACID, SttOT FRACTURE, CEMENT SQUEEZE, ETC. DEPTH 'INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED PRODUCTION METItOD (Fl0wing, gas lilt, pumping--size and type o! pump) Pools B, C & D I WELL STATUS (Producing or ~ . shut-in) i,. 11/11/66 Flowing Producin~ DATE OF TEST ~ : 12/18/66 24 5/8'! TEST PERIOD { - > 642 290 0 452 FLOW. TUBING PRES-q. CASING PRESSL'RE CALCULATED OIL---BBl. (;AS--MCF. 1VATER--BBL. OIL GRAVITY-AP1 ( CORR. ) 24-HOUR RATE t-,.,o 0 ~ 642 I 290 I 0 37 6° [14. DISPOSITION OF GAS (,~old, used lot luel, vented, etc.) . ' Flared ~5. LIST OF ATTACHMENTS TEST WITNESSED BY fl6. I hereby certify that the foregoing and attached lnfo,'nlatlon is complete and correct as detennhlcd froln all available records SIGNED TITLE DATE *(See Instructions and Spaces [or Additional Data on Reverse Side) PAGE g INSTRUCTIONS General: This form is designed for submitting a complete and correcl~ well completion report and log on all types of lands and leases to either a Federal agency or a State agency, or both, pursuant to applicable Federal and/or State laws and regulations. Any necessary special 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 lo(mi 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 the extent required by applicable Federal and/or State laws and regulations. All attachments should be listed on this form, see item 35. Ifem 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific instrucCi6ns. Ifem 18: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Ifems 22 and 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 thi~ form, adc~tuately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Ifem 29: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the ~ementing tool. Ifem 33: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) 37. SUMSIARY OF POROUS ZONES: SHOVe' AI, L ISIPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL DRILL-STE%I TESTS, INCLUDING 38. GEOLOGIC ]~IARKERS DEPTH INTERVAL TESTED, CUSHION USED, TI,~E TOOL OPEN, FLO%VING AND SHUT-IN PRESSURES, AND RECOVERIES FOR~IATION J TOP J BOTTO~ J DESCRIPTION, CONTENTS, ETC. TOP I NAME MEA3. DEPTH TRUE VERT. DEPTB : I . · .e...iease Date DM-12 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD Sec .... (31) 3O T. 9N R. 12W S Mer idi an Permit No. 65-38 Issued 12-13-65 OperatorPan American Pet. Corp. Location (Surface) 560'FWL & 1930'FNL, Sec. 31 Lease No, ADL 17595 or Owner MGS State Loc. (Bottom) 600' FSL & 600' F~WL, Se.c. 30 Well No, 5_ Spud Date_ .!2_,17,65 Area M~ddlm C. rnund Shna] Drilling ceased Suspended Abandoned. Completed (F-GL-P2. ~ IP __ Total Depth 11,128' Elevation 7~.!5 '_ MSL B/D, Grav API Cut % Gas __-_ ~= MC~F/D, Bean Casing; Size Depth Sx Cmt 20" 595 ' 798 .1~-3/_8, 2012' 1800 9=5/8" 7565 ' 1950 recmt; . 8900 ' -02 ' Perf: 8900-02 psi, 8160'-62 & recmt'~ [10 ,562 ' -63 ' 10527-28 1~10,430 ' -31' 500 2 ~9101'-02' 8887'-88' [8801'-02' 8710' '11' TP ._. ....... psi Plugs: 11,128.'-1.1,042' GEOLOGIC FORMATIONS Surface Lowest Tested Name PRODUCTIVE HORIZONS Depth Contents . WELL STATUS Year Jan Feb_~. Mar Apr ~.~ May June July Aug Sept Oct Nov Dec ~.....1og indicat~ top~ cmt, .behind 9r5/8 M__3800' -(JO Fract ~W/_.~0.00 gal_water & 2000 lb, sd. (2) Frac~..W/_4000 gal. wa~er & 80QO gal, water w/ 2400# nut hulls,..then wf 4000 gal. water w/ 2000 lb. sd. & 8000 gal. water w/ 2400 lb.. nut hulls. Perf., Frae. & Test (3) 8887'-88'~' & 9101'-02' (4) reperf & test 8710'-11' & 8801'-02' Remark s: (5) 8690"-8710' & 8780'-8800' Acidized 8690'-871i', 8780'-8800' & 8801'-02' ~.(__6)_. 8560'-8602' & 8620'-34' & (reperf. 8478'-8540') 8478'-8540' & reperf 8560'-62' & 8620'-34' (7) 8710'-80', 8800'-8935', 9080'-9150' (8) 8040'-8255' & 8285'-8430' ATTACHMENT A TO P-7 MGS State 17595 No. 5 Pe rfo rations: 5/6/66 8900-8902, 8160-8162 w/4 jspf 5/8 Reperf. 8900-8902, 8160-8162 w/4 jspf 5/16 10562-10563, 10527-10528, 10430-10431w/8 jspf 5/18 Reperf. 10562-10563, 10527-10528, 10430-10431w/8 jspf 5/19 5/24 Reperf. 10562-10563, 10527-10528, 10.430-10431w/8 jspf 9101-9102, 8887-8888, 8801-8802, 8710-8711w/4 jspf 6/7 8690-8710, 8780-8800 6/14 8560-8602, 8620-8634 W/4 jspf 6/15 x8478-8540 w/4 jspf 6/19 8478-8540, 8560-8562, 8620-8634 W/4 jspf 6/Z0 8710-8780, 8800-8935, 9080-9150 W/4 jspf 6/23 7/11 11/2 8040-8255, 8285-8430 w/4 jspf ~6940-6941-1/2,~6962-6963-1/2,~7008-7009-1/2 w/4 jspf ' 6'935'i~5"~'5:/'~g875-691~,- 680S-"6855, '6708-6723, ! 6595-6650, 6520-6570, 6460-6475, 6448-6453, ] w/4-.j-spf ........................................................................ ~ ............... MGS STATE 17595 NO. 5 Chronological Well History 12/17/65 Spudded. 12/19/65 1/ 7/66 Drilled 26" hole to 600 and set 20" casing at 595. Drilled I7-1/2" hole to 2030, logged and set 13-3/8" casing at 2012. 2/14/66 Drilled 12-1/4" hole to 7565, logged and set 9-5/8'! casing at 7565. 3/24/66 3/30/66 Drilled 8-5/8" hole ~o 11,128, logged and set 7" liner from 7360 to _11,127. l~lugged back to 11, 042. 4/ 3/66 Moved off with drilling rig. 4/25/66 5/ 1/66 Moved in with workover rig. Ran gyro surve%displacement at 1.1,042; 2654. 73'N and 290.66'E of surface location. .5/ 5/66 Drilling cement from liner..~BL indicated rece- menting necessary. 5/ 5/ 6/66 8/66 l~erforate 8900-8902, 8160-8162, with 4 jspf. Reperforate 8900-8902, 8160-8162 with 4 jspf. 5/ 9/66 Set retainer 8762, cement liner with 510 sx. 5/13/66 Drill to clean out 7197 to i~BTD. 5/16/66 l~erforate 10562-10563, 10527-10528, 10430-10431 with 8 j spf. 5/18/66 Reperforate 10562-10563, 10527-10528, 10430-10431 with 8 jspf. 5/19/66 Reperforate 10562-10563, 10527-10528, 10430~10431 with 8 jspf. 5/22/66 Packer set at 10295. S~ot 250 gallons 15% acid, frac -. ..... with 4000 gallons treated water with proppant~";-" flush with 108 gallons water. Average injection rate 4.5 '"-. BPM, average pressure 6500 psi. ISIP 5900, 15-minui~-- 5/23/66 5/24/66 5/25/66 5/26/66 5/27/66 5/30/66 5/31/66 SIP 5200. Opened well wi~-~PC 5200 and fell to 0 psi. Flowed small stream in 4 hours. Swab- bed 18 hours to 7500. No show of oil or gas. Re- covered estimated 200 barrels load water, leluid level rising 300' per hour at 7500. ]Estimated load 340 barrels water. Swabbed to 7500. No fluid rise. Pull packer and set retainer at 10200. Perforate 9101-9102, 8887-8888, 8801-8802, 8710-'8711 with 4 jspf. Set packer at 8662, test annulus to 1000 psi. Well open 18 hours, f. lowed pencil-size water stream. Swabbed to 5600, fluid rose to 5000. Recovered 8 barrels water with 3% oil, no gas. Swabbed at 5000 for 14 hours, Swabbed at 5800 for 10 hours, BS&W, 20% oil. 8 BFPH, 60% BS&W. 6-1/2 BFPH, 80% Flowing average 4 BFPH, 25% BS&W with 30 psi on wellhead. Test lines to 8500' psi. Injected 12,000 gallons of water at 8 BPM and breakdown from 4800 to 4400 psi. Frac with 4000 gallons of water with 1/2 ppg 10-20 sand and 8000 gallons water with 0.3 ppg nut hulls with 40 lb/1000 gallons J104 and 1 lb/1000 galt:ons W26. Pressure 4750. to 4300 psi. Dropped 6 ball sealers followed with 5 barrels of water. Stage 1 - 4000 gallons water with Z000 pounds 10-Z0 sand and 8000 gallons with 2400 pounds nut hulls. Rate 6 to 8 BPM at 4500 to 6500 psi. Pressure in- creased steadily to 7200 psi and rate decreased to 1.75 BPM. Shut in and released pressure to drop ball sealers out of casing. Flushed with 80 barrels of water at 1.5 BPM. ISIP 5500, 5-minute SIP 4400, 2-hour SIP 3000. Flowed well 20 hours. Recovered 40 barrels of oil and 28 barrels of water with 30 to 40 psi on wellhead. Shut in for 6-hour bottom hole pressure survey. Lowered packer to 8848. No communication between perforations. Pumped into lower perforations at 6 BPM at 4900 psi. Broke to 4300 psi at 6 BPM. Increased pressure to 5000 psi at 7. 5 BPM. Swabbed 84 barrels of water, fluid'level at 3000 feet before any oil showed up. Now swabbing 75 percent oil and 25 percent BS&W. -2- 6/ 1/66' 6/ z/66 6/ 3/66 6/ 5/66 6/ 6/66 6/ 7/66 Swabbed 3 hours. Well started to ~ow. Flowed open for 2 hours, recovered 19 barrels of oil plus 1/4 barrel of water. Well died. Swabbed 10 hours, fluid level 800 feet, flowed 1-1/4 hours, died. Swabbed 4-1/2 hours, fluid level 2000 feet, reco- vered 18 barrels of oil with trace of water. Frac 8887-8888, 9101-9102 below packer at 8850 with 12,000 gallons treated water pad, 47,700 gal- lons treated water with proppants. ISlP 3600 psi. Shut in 6-1/4 hours, pressure 1900 psi, bled down to 0 in 1 hour. Flowed small stream of water in 8 hours. Shut in 1 hour, in 1/2 hour pressure bled down to 0. Shut in 1 hour, press_ure 820 psi, in 2 hours bled down to 0. Flowed small stream of water, no gas. Shut in 1 hour, pressure 850 psi, 1/2 hour bled down to 0. Swabbed 14-1/2 hours from 0 to 7500'. No buildup between-runs. Killed well and displaced drill pipe with CaC12 water. Ran CI bridge plug. Set at 8850'. Ran packer. Mixed 4 pounds starch and 1 pound gel per barrel of CaC12 water. Water loss 19. Displaced tubing. Broke' down with 3 BPMat 7500 psi. Reperforated 8710' to 8711' and 8801' to 8802' with 4 shots per foot. Broke down and pumped 6 BPM at 6350 psi. Maximum pressure 6600 psi, ISIP 6500. Pumped remainder of 300 bar- rel-'pad at 6 BPM at 6500 psi followed with 102 bar- rels of water with 1/4 pound per gallon 10-20 sand. Pressure increased to 6700. Injection rate decreased to 5 BPM. Followed with 103 barrels of water with 1/2 pound per gallon 10-20 sand. Pressure gradually in- creased to 8500 psi. Shut in. Displaced sand and 5 barrels overflush at 6 BPM at 6500 to 6300 psi. ISIP 58OO. Flowed very small stream for 6 hours. Swabbed to 6300' and shut in for 30 minutes. Fluid rise 350 feet. Fluid 25 percent oil, 74 percent water, and 1 percent mud. Perforated 8690-8710 and 8780-8800. Set packer at 8600'. Swabbed to 5100' and shut in for 5 hours. Pres- sure to 100 psi. Swabbed to 5500' and shut in for 3-1/2 hours. Pressure to 125 psi. Fluid level 4500'. Fluid 75 percent oil and 25 percent load water and mud. ' ...... -3- 6/ 8/66 6/ 9/66 6/10/66 6/lZ/66 6/13/66 6/14/66 6/15/66 6/16/66 6/19/66 CI packer set at 8600'. Injected 4000 gallons pad at 6.25 BPM at 6000 psi. Fracked with 4000 gallons CaC12 water with 1/4 ppg 10-20 sand at 6.9 BI~M at 5100 psi. Increased sand to 1/2 ppg in 7600 gallons CaC12 water. Injected at 6 BPM at 6300 psi. Flushed with 68 barrels at 3 BPM at 6300 psi. Shut in 8 hours. Opened well. Bled to 0 in 30 minutes. Swabbed 13 hours to 7000'. Fluid level 4500' to 6000' and rises intermittently. Recovered 6 BPH water with slight trace of oil. Displaced 3-1/2 drill pipe with sea water and closed packer bypass. Swabbed 10 hours at 4000' andlZ hours at 7100'. Recovered 10 BFPH. Acidized perforations from 8690' to 8710', 8710' to 8711', 8780' to 8800' and 8801' to 8802' with 546 gal- lons MCA at 1 BPM at 4800 psi. Oil treated with 19,874 gallons crude and 110 gallons W26 at 4 BPM at 7500 psi. Flowed back 170 barrels load. Swabbed to 6400', had 1000 feet per hour fluid rise. Recovered estimated 240 barrels of 490-barrel treatment. Drilled out and pushed bridge plug to 10,200.'. Set bridge plug at 8666'. Packer set at 8423' Per- forated 8560'-8602' and 8620'-8634' with 4 SPF using tubing gun. Perforated 8478'-8540' with 4 SPF. Swabbed 10-1/2 hours to 7500', no fluid rise. Swabbed 1Z hours to 7650' at 1 run per hour with 50 to 100 feet of fluid rise. Fluid 50 percent oil and 50 percent water with very small amount of gas. Swabbed 4-1/2 hours at 7800', one run per hour. Re- covered 50 percent oil and 50 percent water. Reverse circulated and added CaC1Z to system. Pulled packer and ran in with casing gun to reperforate. Perforate 8478-8540', 8560-8562', 8620-8634' with 4 jspf. Set bridge plug at 8666', packer at 8392'. Spotted 1000 gallons of 15% acid at packer and displaced with crude. Set packer with 1700 psi on annulus. Pressure 5500 to 7000 psi in 500 psi stages. At 7000 psi, instan- taneous break back to 3000 psi with no change in annu- lus. Injected remainder of 500 barrels of crude and 100 -4- 6/Z0/66 6/Zl/66 6/ZZ/66 6/23/66 6/Z4/66 6/26/66 gallons Dowell W-26 at 4.5 BPM at 5000 psi average. Final pressure 5900 psi. ISIP 5000 psi. Flow tested. Flowed 158 barrels of load oil in 11 hours on 1/4-inch choke with TPF 225 to 200. Flowed 59.4 barrels of load oil in 7 hours on 3/8-inch choke with TPF 60 to 35. Reversed out 59 barrels of load oil and killed well. Tripped out with packer and tripped in with bit. Drilled CI bridge plug and pushed to 10,100'. Circulated and conditioned CaC12 water. Tripped out to perforate. Perforated 8710' to 8780', 8800' to 8935', and 9080' to 9150' with 4 SPF with casing gun. Schlumberger left 23-foot gun in hole with top at approximately 10,080' Set packers at 8642', 8650' and 8673' and checked for communication. Perforations communicated. Set packer at 8418' and spotted 1500 gallons HC1 acid. Injected acid at average of 3. 5 BPM. Maximum pressure 3700, min- imum pressure 3300. ISIP 3600. Bled to 2100 psi in 2-1/2 hours. Flowed 1-1/2 hours on 1/4-inch choke. Re- covered 15 barrels of load oil and pressure dropped from 2100 to 75 psi. Flowed well 9 hours, recovered 32 barrels of load oil. Well died. Swabbed for 3 hours from 0 to 3000', reco- vered 22 barrels of load oil. Swabbed 6 hours from 3000' to 4500', recovered 25 barrels of fluid consisting of diesel, water, spent acid, and trace of oil. Shut in for 2 hours. Swabbed 6 ho.urs from 1500' to 3500'. covered 80 barrels of fluid. Killed well and pulled packer. Perforated 8040-8255' and 8285-8430' with 4 SPF. Bridge plug set at 8450'. Packer set at 7970'. Acidized with 1500 gallons of 15% HC1 acid. Displaced with 62 barrels of diesel. Maxi- mum pressure 4000 psi, minimum 3200 psi. Injection rate 1 BPM. ISIP 3800, 1-hour SIP 2500. Oi0ened 5 minutes, pressure dropped from 2500 to 600 psi. Shut in 30 minutes, pressure increased from 600 to 1950 psi. Opened 5 minutes, dropped to 300 psi. Shut in 30 min- utes. Pressure increased to 1600 psi. Flowed 7-3/4 hours on 1/4-inch choke, TPF 20 psi. Shut in 1 hour, pressure increased to 100 psi. Flowed 6 hours on 1-inch choke, TPF 25. Swabbed Z hours, fluid level 1300 feet. Recovered 62 barrels of load oil plus 26 barrels of acid water with show of crude. Swabbed 4-1/2 hours. Recovered -5- 6/z7/66 6/28/66 6/29/66 6/30/66 7/ 3/66 7/ 4/66 7/ 5/66 estimated 40 barrels of oil with 20 percent BS&W. Treated well with 9576 gallons die s el ~ plus 1% W-26. Displaced with 73 barrels of diesel, pressure 5500 psi, injection rate 5.7 BPM. ISIP 4200, 15-minute SIP 4000, 3-hour SIP 2400. Opened on 1/4-inch choke. Flowed 33 barrels of load oil in 3 hours, TPF. 50 psi.. Changed to 3/4-inch choke. Flowed 73 barrels of load oil in 6 hours, TPF 0. Recovered 115 barrels of load oil, 186 barrels rermining. Some crude and gas breaking through. Flowed 24 hours on 3/4-inch choke and recovered 166 BF. Averaged 6.9 BPH flowing by heads, BS&W 5 percent. Have 20 barrels of load oil y-et to recover. Bridge plug set at 8450' and packer at 7970' with 408 feet tailpipe. Flowed 24 hours by heads on 3/4-inch choke. Reco- vered 220 barrels of fluid, averaged 9.2 BPH, BS&W 4O/o. Fluid was 55 barrels of load oil and 165 barrels of new oil. Completed 8-inch vent system. Flowed 275 barrels of fluid in 24 hours on 3/4-inch choke, FTP 0 to 90 psi, averaged 11.3 barrels of fluid per hour with 4% BS&W. Flowed well 21 hours on 3/4-inch choke. Flowing more steady. Recovered 278 barrels of fluid with BS&W. Averaged 13.2 BPH. Tripped in with packer and set at 7939' with 469' of 2 3/8-inch tail pipe. Displaced water with diesel. Flowed 19-1/2 hours on 3/4-inch choke and recovered 67 barrels of load oil and 6 barrels of new oil. TPF 0 to 50 psi. Shut in 2 hours to relocate separator. Flowed 22 hours and recovered 218 barrels of new fluid with 6 to 8 percent BS&W, TPF 0 to 50 psi. Aver- aged 9.6 BFPH by headings. Set production unit on treater deck and now assembling same. Flowed 24 hours and recovered 293 barrels of new oil, averaged 5% BS&W, TPF 0 to 50 psig, averaged 1Z. 2 BFPH. Pulled packer at 7939'. Perforated from_ 7756-7757-1/2' and 7732-7733-1/2' with 4 SPF with casing~gun. Set bridge plug at 8000' and packer at 7980'. 'Cl~.culated around packer. Set packer at 7635' with 40,000.~pounds. Circulated with 100 psi. Flowed 2-1/2 hours. -ReCovered 15 barrels of new oil. Killed well. -6- 7/ 6/66 7/ 7/66 7/ 8/66 7/10/66 7/11/66 7/12/66 7/13/66 11/ z/66 Bridge plug set at 8000'. Attempted to set Baker Model EA packer at ?665' and 7625' and would not hold. Tripped out with EA packer and tripped in with Baker Model F packer and set at ?665'. Tested pack- er to 1500 psi, held OK. Had 2600 pounds sand pumped into drill pipe when .drill pipe parted at 5487'. Injection rate 6 BPM. Pressure increased from 5800 to 7400 psi when pipe parted. Reversed out estimated 1300 pounds sand. Recovered drill pipe and packer with overshot. ,- Cleaned out sand from 7725' to 7800'. Set packer at 7677' and tested to 1500 psi, OK. Displaced tubing with 1Z, 000 gallons CaC1Z water containing 40 lb/1000 'gallons J140 and 1 gallon/1000 gallons W26. Averaged .injection rate 7.25 BPM. Average pressure 6000 psi. Salt water frac with 11, 970 gallons treated water as above and 5300 pounds 10-Z0 sand. Average injection rate 6 BPM. Average pressure 5900 psi. Followed with 10,594 gallons treated water and 750 pounds 12-20 nuthulls. Average injection rate 6 BPM. Average pres- sure 6500, maximum pressure 7500. Screened out and displaced with 35 barrels of water and locked up. Re- versed out. Explosion in crude oil tank below derrick floor. Cleaned out top of derrick on workover rig. Bled pressure off well. Over weekend - Pulled bridge plug from 8000' and set at 7100'. Perforated 6940-6941-1/2', 6962-6963-1/2', and 7008-7009-1/2' with 4 SPF with casing gun. Prep to pull packer. Working on pumps and electrical system. Frac 7/10/66. Injected 285 barrels CaC12 water, 380 barrels with 1/Z lb/gallon 10-Z0 sand, and 760 barrels with . 3 lb/gallon hulls. Average injection rate 10 BPM, maximum pressure 4500 psi, ISIP 3150. Set CI bridge plug at 6850'. Have removed riser and installed cap on well. Drill pipe laid down and prep to lay down derrick on workover rig. Perforated 7895'-7910', 7730'-7790', 7110'-7125', 6995'- 7020', 6935'-6975', 6875'-6915', 6805'-6855', 6708'- 6723', 6595'-6650', 6520'-6570', 6460'-6475', and 6558'-6453' with 4 jspf. Tripped in to top of liner with ....... bit and scraper. CaC12 water 10.5, water loss 8. -7- 11/ 7/66 11/ 10/66 11/11/66 11/13/66 11/14/66 11/15/66 11/16/66 11/17/66 12/30/66 Ran dual string of 3-1/Z-inclY'tubing and tested each joint to 5000 psi. Landed in dual head with bridge plug valves in place. Conglomerate shut in to test sand. TPC 350 and building up. Sand flowed 2 hours. Recovered 65 barrels of fluid with Ti~F 200 on 5/8-inch choke. Sand flowed Z0 hours and recovered 690 barrels of fluid on 3/4-inch choke with 8 percent BS&W and TPF 125. Conglomerate flowed 6 hours and recover- ed 34 barrels of fluid on 3/8-inch choke with . 20/0 BS&W and TPF 50. Rig released at 12 noon, 11/11/66. Conglomerate in 24 hours tested 120.8 barrels of fluid on 3/8-inch choke with Ti~F 85 and B$'&W 14%. No test on sand. Conglomerate on ZZ-hour test produced 66 barrels of oil. Average 3 barrels of oil per hour with T1~ 275 psi and 6% BS&W on 3/8-inch choke. Sand, on test separator, averaged 47 barrels of oil per hour, tubing pressure 175, on 4Z/64-inch choke with . 3% BS&W. Conglomerate on production sepa- rator on 26/64-inch choke. .. Tested sand 18 hours. 13roduced 530 barrels of oil. Averaged Zg. 4 BOlmI-t on 1/Z-inch choke with 1% BS&W and 200 Ti~F. Conglomerate on ZZ-hour test produced 87 barrels of oil. Averaged 4 BOPH on 26/64-inch choke with TPF 140 and . Z% BS&W. Complete.d 12/28/66. Dual flowing oil well. TD 11,128', Hemlock. i~BTD 11,042'. Top of pays - MGS pools E, F, and G commingled 7710', and MGS pools B. C. and D commingled 6515'. I1~ on ~., Fta~n_cl G 248 BOi~D on 3/8-inch choke with TFP 140 p-~T'(lZ/28/66). IP on .~_~_._G~ and~_~.~..633 BOPD on 5/8-inch choke with TF1~ 125 psi (12/19/66). No limi't on allowable. Dual developmental oil well. -8- FIELD I ............... 1 ................. INCLIN- d.?.. ~.f, i ..... ' 4 ?.. DONE BY: ,/, N W ..... r. .. ............ ,.. -./ ] ./. $ DI!.(:.;_:'flON OF INCLi,,:¥rlON .'..:' ";.';iD----- 0 e'.:.~ ""1 SI--.; E ~- T SU F~\,' [:, ¥ JOB NO. S U [",: ',',.: Y DATE %7' ..t ?'//" , ........... ~'.:..'..,.-.;: ....: ,.' .:., : .',', ,:.'... ..... · .. /-/ ?/ I I CK..BY: ,- '.'"'": ': .................... ""7 '. ....... .'"":'" ".'. ....... 7TM" ." ~'"' '"' "7 ..................... ."'."'"" ................ .'"'":':% 7' .......... "' .;'" ""."'" ~: ....... ' ............. · '. ................ · .............. '.' ......................... ~ ............ ." · - :'":--',:-:'~,::~..,.: . . CUSTOMER .... /.-_'/...: ..' ' YVELL. NO. FIEi.D COr~ F~ ECTED: TIME /54 - z .,,-, DONE BY': "!t CK. BY: ... . .. . N DIRECTI.:';;~ OF INCLINATION .._ OBSERVE{) CO R [~. ECT Et'; ....... . .~ ':~' : SHEET NO. .'.'" . tv !,_.'_ '~/-.. SURVEY ,,c" t ; JO~ ,":0. .': I"?- / ~1...,/.'. ' "' SURVEY D,qTE ......... ~:' ~ .... / " ~';EASUI~FO CC:U~-~,E ?'{$PL.~-,CE',:::.,'I' TOTAL [:... ?l..,' "';Tx'' ' ·f:..)UTH EAST ,,',.'ESTI....1h .... ' ": [::A.S'T' , V,,'[ '"' ' ' '"'-:'i' f-'';''' '" - ........ :;"': ........... ::,'i -':,7..'.<;,.' ";:'::'. :i ..... :: '"'"'~' "' : ' ' "".'L.j.. t. /,' ,- ~ /.., , ~ ...~ ..c~-_; ..... · : .... '...' ":'~::. ' :' "'."7, ;,' ', ....... 1.4 .'~ : ... .....: ........ C.. .! £',EPI CORREC'f L.L' VERTICAL DEPTH l'O'" ;, C:7..,LI RSE TOTAL , -. c?:.? .:!"/ ! / /'?~:"z ~; 4 '" .... -:,..:,,..:..-,.. ..... ... v '1 ~f:..~L. ~'~.~ .'? ,r~T .?. .... :~....:_L:.:...C- L .... ~_'~ 7,_,~.L - '1 DONE BY: CK. BY: ;'" 5..:. !.',C' N DIRECTION OF INCLINATIOIN OBStZI'V~'F.[') CO~-(i'~'. i CORREC1 [. !) SHEET NC.)._ .............. ~..;:_ .,.:.,. · , .. SURVEY JOg NO. -,2 ,'"i.. :.__,.,,.' SU RVL Y ~) A'~ ~: d- -' .:.',~..'....?_.::::..(.,._..,,:7.- ...... M[/',SURED COUR:q£ DISF'LACE~!!;' ' l'O'r/,,L DI:L- ,'.'/',ST i W,' .... I'< '.'CH ' ~,OUTH .. i [ w~,, ,o. _,)_.._._C>._._~_._.__~z:,'.~.~.; ~;...-.. ~-z: 5: ~,' 1~/,.,. ~ ~! - . -~, .. ~.~ FIE.LD 1~1 t t;, C3 L I= (.--.. ,~: .."./. !._-t,_['J_'" · ~l/-. r.~ ! ......... ~ -'~ { -~ ~--" · .:~-' ~_L. z. ~'~._ .... .: MEASLIRED COR,r':EC~ ED DE~"f H VERTICAL DEPTH TIME COURSE TO~ AL ...... 1._ c?/. :. o ~ 7 '1 DONE bY: CK. BY: ' I' I · . W ... .-.'?.i '.e:/.;':'.L ;,,:'" SHEET NC}. SURVEY JOb NO. SURVEY D.ATE DIRECTION OF' INCLINATIO.~.! OL~SLRVED CORREC'i ED ME.t,~:LII~ED COURSE DIS"LACEMENT , TI.4 E: t.. :-" WEST ......... T O'F/-', L DIS?LACEI.4Eh.: NORTH .%OUTH EAST V/EST .2.: ' ~.4 ? ,[ ............. ~ /~'" ~ ." ' .~:':~ 2~];~4..~: ............... ........... ~o:~t.~ ~"/~." t .... :. ,, ~.. ~ ........... ..... , ~ . . , I I" ~",".~"'~,'. ,' ~ l&~.,.~.. . .......... .... ._' ~ ~ ~..:'._, -'r ....... ~ 7.: ...................... // it /, / .~/... '/' ./ .: · .:-4 ~: '". (i ~, .., · .: · --', ii, .... ..... .. :.~..,~ .... . ........ .... :':..::.' . . ,;:-:~.:x:.. l.'' '~ -.,' ' .......... - '.', ,' : ~ , ~ ........... '.:':' '? ~ ,.,~ " ~',,. ,~.,~.~ ..... ,', ."~,.-- ,' :': .............. ,', ~ ;:"?,: ;:":'"' :":" '7' ~ "~ '? ' ~ ' ~.~ ~ ', ...-c: .- .,- .... '-~'....V: ..... ,,,'~.~: . ', -.' .~ .. .,,: .:,.,. ~ ~,,;-.,..:..:.. :' :~..,:.,' ,, ~~':?~?X::~;c~. ' ..: .:~ ..:.,...;.:~.~:~.~.~:;:~;~.,.~...,,,',.';.. ......... ~,....{~,..~.~,~;~t,.::, c,,~.a ;;;'L;~.:-'7 ,}:..7. ................................. . ..... ~ .................. ~ .... ., . ......... , ......... ~,_. . ., . ;. ,., ,-~ .............. ,..~-:~ ............... - .......... , ............... ~. , - .... : .................... - . ,'"r.:.. '"27''~;'a '7 ......................... :'-::~":~'~?::~7~:~':??~'77.':: :'-":~.: ................ :":':~¥'~"~'"' ......' ....... '"Z::L::::::~37:' S:2'.::::' '".....'-".::27:.:(.::- }:" :.:..:.-.:"::.S':~ ': ......... : ....... ~a:'~.:;,~.~,.:,:~,~.: ................. ::7,~.,::}:.~- 77:~::~,~~.,:::.-,..,~ ..... ~?~:Z:::,tT:~..-~t~.~,~ .... ,:.~:~ ............................ :. _~-~:.~..~.,~..,.:~..7,,~,~.: .............. ..,-,,-:~-:-.: .- / / t /,/-'-/- ~'i/ / ,// / ! / / i // FORM 371 2.57 ...~ , AMERIC;AN PI~T~:~OLEUM CO~RP, ENGINEERING CHART ___ ATION I ~H EE-~' NO. FILE APP. .~/h ~,'~,~.._;:_ ' , ..... DATE /? ,. , / / - i · ' ..-"7. '---' ':- ~ ' ~: ,' . ' "~ ..--~. ~ "~ ~.'· ". ~ '~ . ... I 7..-.. '~ " ....... ' ~ .~ :. 1 .... '"'. '""-,7,~ ~ ,,~-%'' ./ , ~,.,, .... . __>~,,~ . \/ '. ,../',. "x. ",~.~ .. · '.,Y ,~., .............. ! . ..~ ./,'. x, - ~ . ..;.~..., .-' . ..,..,~,'.' -...." ' :. ? ,,.~. . ,..,,.,, . . , .',.:,,. ~.: x,> . '-4.,.-. 'N; "x...' ".c..... "N.. ....... ~_ , _ .......... ',,.," ...... · . N ..N.. -_ _-' "~ .-th ............ .-' .: ,; -x-.- :-. ---"~.-~_, ---. . ~j-L.:/' ...... --- /,~.h./ · .. , _ ~.~..: .... ~ - _~- . ....... -'/.~., ,, ,~./. · . ...: '~ '..~.'~ ~,~'_-.?--. -.~--~ ~__~ - - ___ v' ' _ - .... . ,/:,, ~.--< '.. .~ .. '..' ~ ' ~ ~ ' ' "-. ' '~..-~-~' ,.~ ..... "- r"' .'. · _.'" .- 4J '. 'N ~ - - ~ -'"'~- "'- d ' -' " .......... / ' -.--'" ' '- "' ' ---,--7:. ......................... :-- - ':-.,' '-~ ",~..~ ,~, ~ ~'~. .~ ~ ~,- -¥.:-7:- .......... / .... Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1. 1964 LAND o~,=_= Anchorage LE~N,,~E~ APL 17595 ~ =. ~.,~ .~MGS State 17595 ~ell No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operation,s a~d production (inch~dinv. drillin~ and producin~ wells) for the month of ................ __O___c__t_o_._b__e___r_ .......... 19_6__~__ ............................................................................. ~ Pan American Petroleum Corp. .~er~t' s address ............................_B___o__x____7___7__9_. ....................... t;ompany .................................... -~- ...................... Anchorage~ Alaska ............................................................................................... -x~Z:&--_-'~_ :__/__'_ ................. Ph, or~e 2 72- 8471 ~ ....... Area S~l~erintendent ...................................................................................... · /l~ el'L[, S ~,l,~l,e ...................................................... SEC. AND ~4o~ sw 1/4 sw 1/4 Sec. 30 Cu. FT. OF GAS BARRELS OF OIL GR TY (In thousands) 0 0 TD 11, 041 . P~,.rforating. ~,e plugs xd c~ndit'ioned (~ALLONS OF (~ASOLINE RECOVERED Re sum~ hole in t BARRELS OF WATER (If none, so state) :d operaq ~reparat: REMARKS (If drilling, depth; if shut down, oau~e; date and result of test for gaaollno content of gas) None ions 10-26-66. on to perforate XlOF MINES & MINERAL~ ANCHOraGE No No NOTE.--There were ................................................ 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 et' 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. Po O. aox 779 ATY~HTION: Hr. F. E. l~reb~l! A~ea Supez~u~enden~ Enclosed please find ~r eopy of the approved mmdry not,ce ~r~na notice of in~en£1on Co mitSp.le eouplet-e t~e ~tom~ wll. Thomas R. ~11, Jr. Pat~oleum Supervisor Form P--3 ST ~ ALASKA SUB.AT zz~ (Other instructtc.., OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) CE* Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO. ADL- 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NA.RIE 1. 7. UNIT AGREEMENT NA.ME WELL WELL OTHER 2. NAME OF OPERATOR $. FARM OR LEASE NAME Pan :~erican "~ ~ 3oroora~ion -- I[GS Stale 17595 3. ADDRESS OF OPERATOR 9. WELL NO. Box 779 Anchorage, A~ska 99501 5 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* 10. FIELD AND POOL, OR WILDCAT ].-Iiddle Ground Shoal See also space 17 below.) At surface Slo% 6, Leg 1, Pan ~erican HGS ?latfm%~ ......... .,.:~ .... , T 9~T, · '~7 ~ 828' Fl{~', Sec 30 TgN~ il12 Y, S.;~. BT-U~: 723' :: S.o~ ..~ . , , 14. PERMIT NO. [ 15. ELEVATmNS (Show whether ~F, RT, ~R, e~.) 65 38 RKB 7o.7o ~)ove ...... 11. SEC., T., R., M., OR RLK. AND SURVEY OR AREA ........... ~' T 9'".~' J .......":'~aa: .-,,'.~.,;.... 31_, !?.12 If,. S, ).:[. 12. BOROUGH _. '~ 1~. STATE Kenai [ Alaska 16. Check Appropriate Box T° Indicate Nature o~ Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTS (Other) NOTE: Report results of multiple completion on Well ompletlon or Recompletion Report and Log'form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any ' proposed work, If well is dlrecttonally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work,) * ~.i?his Sundry No'rice :'[.s :in addition 'to tha-',~ P-3 da'ted 10-19-66, Notif![c-r~'tion of I~ten~c 'to }~ul'tiple Comple!e the subject well. All steps and i~'ormat:ion l:i_siSd on P-3 da-ted 10-19-65 remain 'the sa.,.:,.."~e add:i"t;ion, .......... ~ 6448 - 6453 and 646,3 -o470 ~ Zt should be noted on '~he well_bore ske'tch which accompanied the 10-19-66 P-3 that 1;he lop perforalion will. now 'be a% ~448'. 18. I hereby certify that the foregoin~ is true and correct NED Are a Su-~e rini:enfe ni 10- 26- 66 TITLE DATE (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, I~ ANY: TITLE DATE *See Instruction, on Rever~e Side Form P--3 STA t: ALASKA SUBMIT IN TRIP. (Other instructions OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL [~ oas [] WELL WELL OTHER 2. NAME OF OPERATOR Pan American Petroleum Corporation 8. ADDRESS OF OPERATOR P. O. Box 779 - Anchorage, Alaska 99501 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surf. ce Slot 6, Leg 1, Pan American MGS Platform 'B'. 1930'FNL, 536'FWL, Sec. 31, T9N, R12W, S.M. BHL 723'FSL, 828'FWL, Sec. 30, T9N, R12W, S.M. rE* Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO. APL 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FAR~! OR LEASE NAME MGS State 17595 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 14. PERMIT NO. ] 15. ELEVATIONS (Show whether DF, RT, GR, et~.) 65-38 J RKB 78.75' above MSL :Lc. Checl~ Appropriate Box l° Indicate Nature of Notice, Report, or Other Data 11, SEC., T., R., M., OR BLK. AND SURVEY OR AREA Surface: Sec. 31, T9N, 1R12W. S.M. 12. BOR,OUGH .-' '1 ill .qTATE KenaiI Alaska NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE. COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF': WATER SHUT-OFF J [ REPAIRING WELL FRACTURE TREATMENT J--I ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENTS (Other) NoTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any l~roposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * This notice sets forth our intent to complete subject well as a dual completion. 7" liner landed at 11,127~. Cemented with 1400 sx, recemented With 600 sx, recemented 2nd time with 510 sx. Top of liner at 7360', top of liner hanger at 7339'. 7~ cast iron bridge plug set at 10,200'. Perforated and production 'inter- vals of the well will be as follows' 9101-02' , 6935-6975' '/8710-80' .... "6962-63-1/2, , 9080-9150' ' 8710-i1' :6815-6915' ~' 7110-7125' "8887- 88' ': 8690- 8710' ' 8285 - 8430' ':6805- 685'5' 8801-02' ,.' 8620-34' ~'8040-8255' ".6995-7020' ~8780-8935' ,. 8560-8602' ':7756-57-1/2' ~,6708-6723' ,..~ 8800-8935' ":8478-8540' '~7732-33-1/Z' '. 6595-6650' '7895-7910' 7730-7790' 7008-09-1/2' :' 6520-6570' (All with 4 j spf. ) As shown on the attached revised well bore sketch, a dual packer will be set at 6070', and a single packer at 7250'. All production below 7250' will be commingled. · ' ...... ,/:/,.~J ,,'/"?(::,'" b:,~,,:,, 18. I hereby certify that ~h/.~oregoin~ is true and correct iI ~ , ,.,"~' -('//~-',/]~ ~"(' ~ .... Area Superintendent 10 19-56 StorED .::..'. '~.?." ....... ." . (' TITLE D~TE - · (This space for Federal or ~tat~ ofllce use) . CONDITIONS OF AI:'PROYAL, IF .ANY: TITLE THOMAS i~. MARSHAl:L, i~xecutive Secr~tar~ Alaska Oil & Gas COnserv~tieti Comrnittf:~ *See In,truction, on Reverse Side 0CI' 2 4 1968 DIVISION OF MINES & /Vl, INJ[RAL~ ANCHORAGE ~;~ oo o ///JO;'-,' · :..-'__-.'.-'.: · .'_,t. J - j'-. J -. . .. , . · , . · .. . · . , · .... , . . · . . . . ..... "-. . . . .. , .", .. · . . .,, ~-m.' O~'.i~ P~.~.--- ~'/'~- 'S4.,~£?'Y,- "lZ "']~ S~r' ~w' 4-0.0 ~ ,, ~,/'~:;,~' ~,~r~0~ '~,~ ': ..- To . ~0~$:~, :- '. .."' .... ' '"'' ' ' · .. -..~". :' ....~.-~..-- - .-. . . . .... .. -. .: , ,' .. . ,. ~ .' . . .. . ~('." - :..., -. ._ . - .. . . . ~ Z/~i~ ~-~/.~'~ ,.-o ~ " · .- ... . I~ ,.~.~ -. . . . ::' - .... ,. :' -~ .. ,. ~o~4 !~ /~.;VC,~'~'~ ~ . "" .:-' ...~...~'~" , ...' . .. ~x~z' /~/~x ~ -- ..."-.,, <..' ~'..... .~.. - :. .... .' . . -. . .- . - -. -, .. - ... .. 5~o " . ~. ~"' '. .. ' . . ssso. ' a~-oo. .. ' :'. ~/~o ' -' ~'~oo. . ' '- ". . , .47o0 ~-~. ~ -~,~-~. . ..... . -: . - . ~...' . , . . ~7~0 '....... ... '. . . . . . -... .. -._.. .; '. - ' . . ~ .'. ., . .' .. .''. . · . . . . . . .. .. : ~ . : : . ,. . . '. ...... ' ' -./...."'5 -.' ' . '. '.'~ ..': .. . . .... .. .... ~ ~. · .... . · ..- . .. · ·,. · -.. .: . .. . .. . .., · i .... :-.. . . .. , . .. . , .. . .. .....;..-.. . . .'j - . . .. ... . . . .. .... . ... . .. . . . :. A z' IO~ ' ' . [ .- .;; · . . . . : · . . · ]~c. 0,~4', ' Form P--3 STAI ALASKA SUBMIT IN TRIP: (Other instructions OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERI, lIT--" for such proposals.) 0IL ~-] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR Pan American Petroleum Corporation ADDRESS OF OPERATOR P. O. Box 779 - Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surfece Slot 6, Leg 1, Pan American MGS Platform 'B'. 1930' FNL, 536' FWL, Sec. 31, T9N, R12W, S.M. BHL 723' FSL, 828' FWL, Sec.3'0, T9N, R1ZW, S.M. 14. PERMIT NO. 65-38 15. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 78.75' above MSL Effective: July t"; 1964 LEASE DESIGNATION AND SERIAL NO. ADL 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME FARM OR LEASE NAME MGS State 17595 9. WELL NO. 5 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., OR BLK. AND SURYEY OR AREA Surface: Sec. 31, T9N, R12W, S.M. 12. BOR,OUGH "' '1 18. STATE KenaiI Alaska 16. Check Appropriate Box T° Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL ORALTER CASING MULTIPLECOMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF': WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Lag'form.) 17. DESCRIBE PROPOSED OR coMpLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directtonally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work,) * This notice sets forth our intent to complete subject well as a dual completion. 7" liner landed at 11,127'. Cemented with 1400 sx, recemented With 600 sx, recemented 2nd time with 510 sx. Top of' liner at 7360', top of liner hanger at 7339'. 7" cast iron bridge plug set at 10,200'. Perforated and production intervals of the well will be as follows: 9101-02' 8710-80' 8285-8430" 9080- 9150' 8710- 11' 8040-8255' 8887-88' 8690-8710' 7756-57-1/2' 8801-02' 8620- 34' 7732- 33-1/2' 8780- 8935' 8560-8602' 7008- 09-1/2' 8800- 8935' 8478- 8540' 6962-63-1/2' 6940-41-1/2,' 6610-6611-1/2' 6879-6881' 6560-6'562' (6'0"~) 2"'69'0'a~'';'':I:' 6531-6533' 7110- 7125' .,: .,.,, 1~6642-16643-1/.2' 6623,24-1/2' (All w/4 jsp .) As shown on the attached revised well bore sketch, a dual packer will be set at 6070', and a single packer at 7250'. Ail production below 7250' will be commingled. 18. I hereby certify that the foregoing is true and correct TITLE A rea Superintendent DATE 10-19-66 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See In,truction~ on Rever, e Side DATE · ,."" ' /g~$ $'r'~'/r--, 75"q5' w'£/-/-. /Vo, ,5" D£PrH $000 /WWNI>££/- Z /IND//V~ DEP ,5'000 9o00 IO0oo T "B~ MooEL K PZ '~ ~ r lO Zoo' I ' [- w~P PAeKa~ 7~W~'O'(7ZfZ) ~~ - ? ~-,,,,. ~-: ?_~.~.. ~o0o 4ooo S'ooO IO0oo I1000 7 "btm6..~ MooF_l. /4' ,4 r lq zoo' t Form No. Effective: July 1, 19(14 STATE OF ALASKA ,_,~No ~-~-,r~- Anchorage ~/~ OIL AND GAS CONSERVATION COMMISSION ~ ~ ~L 17~9~ : ~ ~ ~'~ ~ MGS State 17595 Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS Phone State .......... _A_ _l_~_s. ~_a. .................. L'r, ro,gh ............. _K__e_ ._n_.a._i .......... Field _._ D e x_e__!.o_ p m___e n.__t_ The £ollowi~ is a correct report of operations and prod~etio~ (inchedln6~ drilli~ and prodzecin$' wells) ]'or the month of ........ S___e__p__t__e___m.__b__e_?_ ............. , 19_6__6__ .............................................................................. .4~ent's address .................. __P_:_____O_:__~_o_x__7__7_9_ .................... Company ~__an_Am.e_r_J_c_an_cP_e~_r_oLeu_m__Con: p. ................................................ - -A- - -n- -c- -h- -°- - -r- -a- g-e- -: - - -A- -1- -a- -s- -k- -a- .......... Si~ed .... ~i'~:"/ii~):~(/i'~::~kc_~'/ji~ ........................... ................................... _2__7__2__-___8__4__7__1_ ............................... ~t~e~t's tZtZe ..... __A_ ~__e__a___~_u_ p_e_ r i_a_t_e__n__d___e__n__t_ ........ SEC. AND ANGE WELL D&~ CU. FT. OF GAS GALLONS Or BARRELS O~ REMARKS ~Oi'~ TWP' , NO. ,P ..... BARRELS O;~' OIL GRAY[TI (in thousands) ~GASOLINE WATER (If (If drilling, de~th: if shut d ......... itECOVER, EDnone, so state) date and roault of test for gasoline [ I ....... content of gas) o oo to o T ~ 11 128'[ P~TD ,,042~. Sh~[t i~, 7-10-66 d e to exl~losion o::~ drilling P ~tfc faa 'lB'.l sw 1/4 SW 1/.4 Sec. 30 NOTE.--There were ............... ..N...o. ........................... runs or sales of oil; ..................N..Q ......................... 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 flied in duplicate with the Division of Mines & Minerals by the 6th of the' succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 'ANO ~,~_ Anchorage ., :EASENU~ER ADL 17595 LEAS~ :R ,,~,; ~ MGS State 175~'95 Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS State ...... A l_a__~.ka .................... B~r~,gh ........ _K__.e___n_a__i ........ F/eM D e v e_.!_O p..m__e__n_._t. ......... The followin~ is a correct report of operation, s and productio?~ (incl~dir~ drillir~ and prod~cinoj ~,~el~s) for the mo,~th of .................. __A__u__g_u__s__t_ ........... ~9_~_, ............................................................................. · /l~ent's address .......................... P_ .... Q_._____B_.o.__x___7_7_~_ ............ Company _ _ ?a_ _n_ _ _ _A_ _ _~m_ _e_ _r_ _i_ _c_ ~ _n_ _P__e__t__r._o_le__u___n~_.___C._o_ .................... Anchorage, Alaska S~ne x~, -~:.::::"--'--:::-:::--'---':: ....... Phone ............. 2 7 2 - 8 4 71 ~l~ent s--~'~~title ____A_~_e___a___S__u.p_e___~_i_n__t_e___n_~_n___n_t ........... rp. SEC.~ OrAND],~ Tv~P. RANGE SW 1/4 sw 1/4 TD 11, 12 . BARRELS OF OIL Shut in 7 [TY 6( Cu. F~. OF GAS (In thousands) due to ex GALLONS OF GASOLINE RECOVERED BARRELS OF WATER (If none, so state) .n dr'illir REMARKS (If drilling, del)th; if shut dowu, e~u~e; date ~tud result of test for ga~ollne content of gas) No i1 e g Platform 't5'. ~losion c ; E.CEtV 9 5EP 1 3 1966 ISION OF MINES & MINERALS ANCHORAGE NOTE.--There were ............. ..N....o. ............................ runs or sales of oil; ................. .N..Q ........................ M cu. ft. of gas sold.; ............................... .N...°.. ...................... 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 rr~.ust be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, I9Gl LAND ~F?'~' Anchorage L~As~.,.~.E~ APL 17595 ~ ~ ~"'~ "*~ MGS State 17595 Well No, 5 LESSEE'S MONTHLY REPORT OF OPERATIONS Revised Report 27~e followin~ is a correo~ repor~ of operatio~rs and prod~ctio?~ (incl~dir~ drillir~' and producing' wells) for tI~e month of .......................... ~ ......... 19~_~_ ................................................................................ ~ent' s address .............. ~ .... Q,__~_o~__7_~_9 ........................ Company _.~_~_~X_~_%_~__~_q_~X9_~.~..~_9 rp, Ancho rage, Alaska SZ~,~ed .......................... :~_L~.:~__zz?i~v::.~_~_;~ ........... ........................................................................................... -- ~ ~ .,~,~'~~ __ .............................. .................................... ............. I~EC. AND BARREI~ OF OIL GRAVITY OASOLINE WATER (I[ (If drilling, depth; ii .hut down, oau~e; ~i Or ~ TWP. RANGE WELL DATa CU. FT. Or OAS GALLONS Or BARRE~ or ~E~ARKS No. , PaoDvoao (~ thousands) date and reault o[ ~ECOVERED ~OBO, so state) ....... 1/~ 30 9N LZW 5 1~1/2 *567 36. Z 235 0 9 None I1,128 . P~gTD ll, 04Z', ~hut in 7-10-66 due to exp..osion or Drilling[ Platform " g", 'f. 7, ~56' 7, ~57 '/Z' aind 7, 73Z' - 7, 7~33-1/2' w/4 SPF with casirg gun. 7-5-66. .c w/1Z, 00,) gal CaC1g w~ter conta.ning &0 lbs/100 gallon J-140 and .1% W-Z6, 11, 97C .on treated warier as abozew/5, 30~ lb, .0-20 sand'. 10, 594 gal, treated water and lb 1Z-Z0 nut hi~lls, 7-7-66, Perf. 6,94~)' - 6,941-1/Z', an, l 6,962' - 6,963-1/2', and 08' - 7,00~-1/ [' w, 4 SPF w/casin~ gun Injecte~ 285 bbls CnG12 ~ater, 380 bbls. ./2 lb/~gall,~n lC-20 SN, ' 60 bbls w:.th 0. 3 lb hulls per gallc,n, Test,Sd well during iod, 71-10- 56. ~ . ,~ · · ,.r , J . ' ensured through m~ter ~,hich has ~ot been proved ~Volum{~ subjec~ to correction ~en meter fact( r is esta])lished, j ~ ' :, barrels i:~ 100% P~.n An~erican o~-ned il. J ....... ..4, .................. ~ .............. SW SW Sec TD Perf. Frac ga 750 7,0 * 500 No . NOTE.--There were ................................................ runs or sales of oil; ................................................ Mcu. ft. of gas sold; .................... ..N....o. ................................. runs or sales of gasoline during the monfl~. (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 8th o£ the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 1'"':7~' ~/'~"/~/~ orr,~Anchorage N..~ ADL 17595 o~,.N~ MGS State 1759~ Well No. 5 ~*'~ LESSEE'S MONTHLY REPORT OF OPERATIONS State .......... .A_.!a.__s._k.a_ .............. B~ro,.qh ........... _K___9_n__a_.i_. .......F/eld _ _ Deve. !_ .o__prae_n. t_ ....................... The followin~ is a correct report of operations and productior, (inchedin~ drillin,~ and prod~ecino~' wells) 7'or the month of ............. _J__u__l_y_ ..................... 19_6_.6___, ............................................................................... .4~ent's address ............ P. 0. Box 779 r~,,,,o ....... Pan American Petroleum Cot . ............................................................ ~ .... ~7 ........... ~ ............. -~ ................ ~- .......... ~P- .... Anchorage, Alaska Si~ned ............. .~, ,-' "~-/~-~-~~-" ..-_.~.:=-(-.j:~'(:":~ ............ Phone ........................................... 2J2_-_B_4_7_l ......................... d~e~,t' s t~tle __Ar_em_R0,p_erintendent .............. ~EC. AND ~4 or ~4 BA~RE~.S Or SW 114 SW 114 Sec. 30 TD 11,128'. tut in 7-1( Perf. 7,756 32' - 7,7 w/12,000 ga .ining 40 gallon trea w/5,300 1' 750 lb 12-2, 6. Perf. 7,009~' w/4 Injected 10-20 SN. b hulls p{ GRAVITY ,-66 C 3~' % bs/l( 10-~ 6,94( 285 t r ga] Cu. FT. OF GAS (In thousands) ue to expl /4 SPF wit' 00 gallon 0 sand. 1 ' - 6,941~ bls. CaC12 ion. 7-10 GALLONS OF GASOLINE RECOVERED 0 0 BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; if shut down, oause; date and result of te~t for g~ollne content of gas) None )sion on casing - 140 ant ,594 ga. - 6,96~ water, · 66. Drilling gun. 7 - .1% W-2 treated ' - 6,96 80 bbls. Platform "B". 5-66. Frac 5. 11,970 water and ' - 7 008' 3}~ , - w/~ lb/gallon NOTE.--There were .... No runs or sales of oil' No 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. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, I964 ~ND ~,=_~ Anchorage ~~ ADL 17595 ~ =~.~ ~,-~ MGS State 17595 k~ell No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS State ..........Alas!~a ................ Borough .............. _K__e.~_a_i .... Field .. The followin6~ is a correct report of operation,s and production (includir~ drillin~ and prod~cin~ wells) for the month of ........................ J:4~ ........... 19_~ J~ent' s address ........................ .~ .... ~ ..... ~D~__~2_9_ ................Company ...................................................... ~P~,___~..S~_~_ ........ Si~ea ...... /:I/~:_~: :~~2':?j(q:..~:=~;~ .............. Phone ........................................... ~_~_~_v_~_~7_~ ........................... d~e~t' s title .... ~K~__~PP~_~_~_O_~ .............. SEC. AND CU. FT. OF (]AS ~ OP ~ BARRELS OF OIL (In thousands) SW 1/4 SW 1/4 Sec. 30 TD 11,12 w/12,000 mesh san Reperfor w/102 BW jected 4 7,600 ga 8,711', 110 gall 8,478'-8 w/4 SPF. crude w/'. 9,150' w~ 8,040'-8 diesel° 73 bbls. *Well te 417 o0 58 8,887 8', 9,101' pad, gallons t wa 0.3 lb/gal and 8,801 2' w/4 SpF Swabbe r forate d~ FRAC w/. gallons Ca PPG. Acidized p -8,802' 546 gallon 560'-8~ 8,620'-8, d. Perf( 8,478'-8,5 [ons 15~o ac 8,392' ..an W-26. Tes~ 8,418' an( 1~500 gal ' w/4 SPF Acidized ell with gallons di ~th. (]ALLONS OF GASOLINE ~,,ECOVE RE D None BARRELS OF WATER (If none, so state) ' below .ter w/~ mesh 300 bbls 10', 8,7 w/~ PPC ns 8,690 19,874 SPF. Swa .0'-8,562 '.ed w/cru 80', 8,8 · Tested gal 1 on s 1% W-26 REMARKS (If drilling, depth: if shut dowm, cause; date and result of te~t for ga~ollne content of to 9, 10; reated w~ Ion 12-2( . Pumped ,690'-8, C12 wate ~rforati~ MCA an( 34' w/4 ~0', 8,5( i displa~ 710'-8, .on, aci w/1,500 :scl plu~ r,' None packer at 8,850' lb/gallon 10-20 Tested. . pad followed 80'-8,800'° !n- 10-20 sand and '-8,710.', 8,710'- gallons crude and bbed. Reperforated ', 8,620'-8,634' de. Inject 500 bbl. 00'-8,935', 9,080'- . Perforated 15% acid w/62 bbl. o Displaced with NOTE--There were ............... .4.~.-/ .......................... runs or sales of oil; ........................... .IIQ ............... M cu. ft. of gas sold; ........................... rio ............................ 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 thc succeeding month, unless otherwise directed. Form No. 1~--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE E~fective: July 1, 1964 Anchorage ADL 17595 ~ MGS State 17595 Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS Development The £ollowin~ is a correct report off operations and production (incl~dfn~ drillin~ a~,d prod~cin~~ wells) for the month of ............ ~ ........................ 19_~_, ............................................................................ ~en~'s address ...... ~ ..... 0_.___~_0_~___7_7_9_ .................................. Company Pan American Petroleum Corp. Anchorage, Alaska Si~ed _~:__~~:-~_-~~~::~ ~o~e ...................... ~.~:~J~ ............................................. ~e~' s ~e .... !~?__~_~_P_~_E~_E!~I ............. ~EC. AND ~4 or ~4 sw 114 sw 1/4 Sec. 30 TD 11,128 plus .2 % sax Class w/8 JSPF. 1/2 lb. p at 8662, w .3 Ibp water w/2 / 9N_I 12W/ 5 0 · BT )22~]aD ~1~0 2'. 'G"~/17o[D65 and ?ra~w/41, 00C gal 4oo0 w ~0 ~b. 1D-20~sand BARRELS O~ OIL _ 0 Prepare t¢ Perf 8900- 2% D22. I ~ater w/25 Perf 910] gal. wate 40 lb. J1. and 8000 GRAVITY 0 frac )2 a~ ~ille lb. £ -02, w/~l D and al w/ Cu. FT. o~ GAS (In thousands) 0 . ~ement li~ [ 8160-62 ~ d cement a~ aC1, 40 lb. 8887-88, 8~ 2 lb. per~ 1 lb. W-2( 2400 lb s. (}ALLONS OF GASOLINE RECOVERED ~er thru ~/4 JSPF ~d Perf J140, ;01-02, al 10-2~ per 1,f .ut hull BARRELS OF WATER (If none, so state) ~erfs wi md re-c 0,562-63 lb. W26 710-11 w sand, a 00 gal, . Swab. REMARKS (If drilling, depth: if shut dow~, oause; date and result of test for gasoline content of gas) None ~00 sax Class "G" ~ment liner w/510 10,527-28, 10,430-31 per 1,000 gal. and '4 JSPF. Set packer ~d 8000 gal water :hen w/4000 gal. NOTE--There were ........... ~9. ................................ 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 n]ust be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. ~ro F. ~. KreBtll Area Superintendent Pan American Petrolemu ~orporatio~ ~cx 779 Anchorage, Alaska 99501 Dear Sir: Yours t~uly, ~L~/c jh Eric. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION I ';,'"",, , Effective: .Tuly l, 1964 ~"~" L~ND o~,c~_ Anchorage .. LE~ NUMB~ ADL 17595 ..'~'.'~ ~ =~ ~,~ ~ MGS State 17'59~5'' Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS St,re ........ A.!_a._~.k_.a_ .................... Borr~,gh ......... K_ .e_n__ a_ . '_z_ ......... FieM .. _Deve !op.m._ent_ ........... The followin~ is a correct reporg o£ operations and prodzection (i~,chedin~ drillir~6, and prodzecin~ ~vells) /'or the mo,~tlz of ............ __A__p__r__i__l_: .................. 19_ 66, ~lgen~'s address ..... ~.~.__~_o_,__7_2_9_ ...................................... eompan~ ~.¢_n__A_m__e_~_~_ _a__n:__P_/a_?o leu__m~ Corp. Anchorage, Alaska Si6ned~ _ ........ _~..:'."-'- .......... );'~ ~, .,~' /"~f~'~.~-e'.~JL ~~ ~ z' _/,.. ~ ~~ -~ -~,-[~ ....................... _- .... ~o~e .... ~-~-L-~-~;-{ .............................................. ~ ~ ~ _____A_~___S_~ .......... ~.?__.__a..?__.__~_ ~ OF ~ DA~s (}ASOLINE W.~.R (If (If drilling, depth; if shut down, oause; ~o~ (In thousands) RECOVERED none, so state) date and roault o£ test ~or gasoliae -- -- ~- content of gas) sw 1/4 sw 1/4 Sec. 30 /12W 0 0 0 0 None TD 11,12, IPBT 2' [ Repairin trical equLpment. Operations commenced 1120 4 ~, '.4-66. Mo rkover rig on well for well completion. IRan boI~d log. P~ te 7,375'- ,377' ard 8,985' 8,987' Iw/4 Se[i cement r~ 'r at 8,940 M^Y 1 0 i96E~ Dt\ ISI(.bixi OF MINES & ANCHORAGE NOTE.--There were no ................................................ runs or sales of oil' . ............. ..n..o. ............................. M cu. ft. of gas sold; ................... ~.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 oE the status of operations, and ~. ust be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless other~-ise directed. FORM 4'70 2.57 PAN AMEmCAN PETROLEUM CO ILITION P. O. ]Box 779 Anchorage, Alaska 99501 May 5, 1966 File' FKK- 582-WF Mr. Thomas R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska Re' Form P-3, Intention to Fracture ~AY 6 i966 DIVISION OF MINES & M,NERALo ANCHORAGE Dear Sir' Enclosed please find three copies of our application P-3, Sundry Notice, describing our intention to fracture MGS State 17595 Well No. 5, Permit No. 65-38. Please return one approved copy at your earliest convenience. Yours 'very truly, F. K. Krebill Area Superintendent Enclosures Form ST~ .... ,: ALASKA SUBMIT IN TF (Other instruct OIL AND GAS CONSERVATION COMMISSION verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) re- Effective: July 1, 1964 -~. LEASE DESIGNATION AND SERIAL NO. APL-t7595 t~. IF INDIAN, ALLOTTEE OR TRIBE NASIE 1, OIL [~ GAS ~ 7. UNIT AGREEMENT NAME WELL ~ WELL ~ OTHER $. FARM OR LEASE NAME Pan American Petroleum Corporation MGS State 17595 3. ADDRESS OF OPERATOR 9. WELL NO. Box 779, Anchorage, Alaska 99501 5 4.LOCATION OF WELL (Report location clearly and in accordance with any State requirements., See also space 17 below.) At surface 536' FWL, 1930' FNL, Sec. 31, TgN, R1ZW, S.M. BHL 828' FWL, 723' FSL, Sec. 30, T9N, R12W, S.M. 14. PERMIT NO. 15. ELEVATIONS (Show whether DF. RT, GR, etc.) 65-3~ KB 87' Above MSL 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., ~., OR BLK. AND SURVEY OR AREA Surf. Sec. 3~, T9N, RiZW S.M. 12. BO:ROUGH ... 'J 18. -'~TATE Kenai J Alaska 16. Check Appropriate Box T° Indicate Nature o~ Notic:e, Report, or Other Data SUSSEQUENT REPORT OF: NOTICE OF INTENTION TO; CHANGE PLANS TEST WATER SHUT-OFF PULL OR ALTER CASING I~l WATER SHUT-OFF ~--~~-~ REPAIRING WELL FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ARANDON' I~I SHOOTING OR ACIDIZING ABANDONMENT. REPAIR WELL (Other) I I (Other) (No~E: Report results of multiple ~ell Completion or Recompletion Report an~Log¥o~ f' 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any nentPr°p°sed~ thisW°rk'work,If), well is di~ction~ly drill~, give subs~ace lo~tions and measured and true vertical depths for all markers and zones perti- This 'is to report an intended selective perforating and fracturing program 'in some 15 zones between 10, 561' and ~, 060', using a 60, 000-gallon fracturing treatment in each zone. Operations to commence around May 9, 1965. RECEIVED DIVISION OF MINES & MINERALS ANCHORAGE 18. I hereby certify that th§ foregoing is true and correct SIGNED ,' .,//~_.. g.%~. ,~"-e....¢. c,.d....-~.,, t TITLE Area Superintendent (This space for FederaI or~Stat~ office use) ~ ~ DATE M__~ 5, 1966 CONDITIONS OF APPROYAL, IF ANY: *See In,truc:tion~ on Reverse Side Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION . ,, ICffective: July l. 1964 al"!" LA,o=r~,=~ Anchorage ..'' L~_~ .~,~E~ ADL 17595 L~s~ o~ u,,T ~MGS State 17595 Well Ne. 5 LE$SEE'S MONTHLY REPORT OF OPERATIONS Tlze followi~ is a correct report of operatio?~s and production (i~clz~din~ drilli~v= a~d producible' zvells) for the mop, th of ........ _~_~_h ....................., 19_~_~ .............................................................................. ~ ent$ ' s address ........................ .............................. A~A~_~m~__&~_~_ ........................ · ~'"" ~'>" ~'~ ' ~'~ S~ned .......... e~o~ .................... }2_~_:~_¢_7_}_ .............................................. xz~,'~ ~ztz~ .... _~_r_~__Ss~cr!~5_c~ .......... SEC. AND BARRELS OF OIL ~4 or ~4 sw 1/4 SW 1/;4 Sec. 30 TD 11,1 Prepa~ eno. 11' 7,5 Logs Ran Pr, · 11,127' v sx Clas ~orkove r r well. ~ ] Cu. FT. OF (]AS GALLONS OF RAVITY I GASOLINE (In thousands) RECOVERED 0 / 0 0 lng ti skid rig >£f for ,,533]'- 10, 559 - no re 5'. ]~an Dual i xduct'ion ,, ~6zt' to 7,564' ,x-M~ and Dipn .eter to /616 Isx Class "G" w/l% ~ ,,~,] w/l% o~7, z% .g is ~noved on :or well BARRELS OF WATER (If none, so state) REMARKS (If drilling, depth; ii ~hut down, dgto ~nd result of tost for contont of None orkover :overy. Sonic, ual Indu. 0,573' CFR - Z, ~, z%~: :ompleti rig to complete Ran Dual GE-Density, tion, Density, Set 7" Z% D22R, 46. Final on. · .VISION O~: MIN~S & MINERAI~ ANCHORAGE NOTE.--There were ....... no runs or sales of oil; no 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 rmust be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherw'ise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: ./uly 1, 1964 }'""'" ..... ~ .... ~ Anchorage LEA.~E NU~E~ ADL 17595 ~EA~ O~ ~'~'~ ~MGS State 17595 Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS St,a: ....._i__!_a__s__k_a ..................... B ,,,-r, , g h ......... _K___e__2a__)._ The followin6~ is a correc~ report of operation,s a~d productio~ (i~cl~di~6~ drilli~6~ and prod~cino~ wells) for the month of ....... _~__e__b_?___u__a__r_y_ ................ 19.6._~ ................................................................................ ~/f~t'~ ~r~,~ ........ ~:____O__.____B___q_x___7__7__9_ .............................. Compan~ _ P_ _a _n_ ~ _ _A_ _ _m_ _ _e_ _r_ i. _c_ _a_ _~ _~_ _ P c _t_ ; _o_ ! c u_ _m_ _ . _C_ _o_ r p. · Anchorage: Alaska ..................... · .................................................................................... Area Su erintendent Phone 272 - ~471 d~e~t' s title ...................... 'P_ ................................. SEC. AND SW 1/4 SW 1/4 Sec. 30 TD 9,942' an~ miSmetle r BARRELS OF OIL ,llowing lo )m 7, 568' ~ss "a" w! g. Indical tc tk Cu. FT. OF OAS (In thousands) GALLONS OF GASOLINE ~.ECOV~.RE D o )ual Induc on, Son 012'. Set~-5/~" c CFR-Z a~d 950 sx ~ of ceme~t 3,800' BARRELS OF WATER (If none, so state) ic, Dens · s ing at Class" REMARKS (If drilling, depth; if shut dowry, date and reault of test for co. tent of gas) None ity, ML-Prox-Cal 7, 565' and cemented 3TM Neat. 1Ran NOTE.--There were ............... .n..©. ............................. runs or sales of oil; ............. n..o. .............................. 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 rr~ust be filed in duplicate with the Division of Mines & Minerals by the 6th of. the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1. 1964 o~,=_= Anchorage N,,~BE~ ADL 17595 =~ ~'~ ~MGS State 17595 Well No. 5 LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operation,s arid prodzectio~ (i'nclzedin~ drilli~ and producin~ wells) for the month of .... ~_a___n__u_~_r__~ ...................... , 19__6__6__, _ ........................................................................... ./lger~t's address P. O. Box__7_7_9_ ................................... m Pan American Petroleum Corp. Compa 'j ..................... , ........................ ,,~. · .'""/' .::,~' ~'% ,:.:. /', / ,.:5."" -";-'" ............................. __A_n___c_ _h_ p_ _v_a_ g _e_ .... _.A__!a_s___k_a ......................... &6~ned ..... .,_,.~.?: .... ~:._...:?~r:~.:::~a~:.~c_-d: ................ o n e .................. _Z_ _ 7_ _Z_ . .-.. A 4_ _ 7_1_ _ ................................................ g e t ' s t t Z e .... .......... SEC. AND BARRELS OF OIL SW 1/4 SW 1/4 Sec. 30 TD 5, 520' Log at and 1,160 3/8" casi: "G" with and recel to surfa~ ~( ni Cu. FT. or GAS (In thousands) '. Set 13- s Class "C .m 717' wit ~C1z. Los ~ at 480' ~ an CBL 1, GALLONS OF GASOLINE RECOVERED 3/8" ca ?" plus h 154 sa, t return 4th 450 950' to BARRELS OF WA~ER (If none, so state) ing at Ye GaG1 ks Cla~ during acks 00'. REMARKS (if drilling, depth; if shut down. eau*e; date and result of test for ga~olLao content of gas) None 01Z' with 6'40 ehind. Recemented "G" Neat and last 100 sacks. ~ss "G" Neat. NOTE--There were ........... ..n...o. ............................... runs or sales of oil; ................ ..m..Q .......................... 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 month, unless otherwise directed. Form No. 1~--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION F. ffeetive: July 1. I964 ~ L~ND ar~,:_= Anchorage LEA~ NUM~ ADL 17595 L~E °~ ~N'~ ~A~ MGS State 17595 Well No. 5 LESSEE'$ MONTHLY REPORT OF OPERATIONS Staa: .......... _i...l_a__s__~_a_ ................. B~,r~,,gh ........... _~_e._n.__a._.! ................ F/eld .... D e.y_e _1_0 pm__e___n_ t Th, e followir~ is a correct report of operation,s an, d produ~c~ion, (in, c~zedin~ dri~lin~ and prochecin~* wells) for the month of ____~___e__c__e____m__b___e_x_ ................... 19_~_5__ ............................................................................. .4~e~t' s address ...... _?__:___Q_.____~___o__x____?_7_~_ ............................... Company _p__&_n____A___m___e__~}_c_._~__n___?___e_~_o__l__e_ ~ ::.. ,, ..~. /, . /,. ................................................................................................. Anc ho rage, Alas ka Si6, ned ........ .: P o, e ...................... ........................................... e, t' tZtle __.A___r__e___a__~:_u_p.e___r__i~_t_ _e__n__d_e_--n-_t_ ........... ~EC. AND SW 1/4 SW 1/4 Sec. 30 TD 1,400 DA~S no~uo~ 0 5puc :~ ;ing BARRELS OF OIL (]RAV fled 2000 ur It 595' and ce Cu. F~. OF GAS (In thousands) 12-17-65. ented with (~ALLONS OF GASOLINE I':~,ECOVEEE D 798 sx BARRELS O1~ WA?EE (If none, so state) lass "A REMARKS (If drilling, depth; if shut dowrl, oau~e; date and roault of test for gasoline content of gas) None ' 2 percent CaC1. NOTE--There were ................. .n...o. .......................... runs or sales of oil; ............. .n:...o. .............................. M cu. ft. of gas sold.; ............................. ..I}_..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 ct' 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. FORM 470 2-57 PAN AMEI CAN PETROLEUM COI PO ION P. O. ]Box 779 Anchorage, Alaska 99501 December 10, 1965 File: FKK-472-WF Re: Form P-l, Application For Permit to Drill Mr. T. R. Marshall, Jr. Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Marshall: Enclosed you will find Form P-l, Application for Permit to Drill, MGS State 17595 Well No. 5, 660 feet east and north of the southwest corner of Section 30, Township 9 North, Range 12 West, Seward Meridian. This well, as indicated on Form P-i, will be drilled from Pan American's Middle Ground Shoal Platform B, Leg No. 1. When the well is completed your office will be provided with surveys to define the direction in which the well has been drilled. Also enclosed is a check 'in the amount of $50.00 to cover the permit fee. Yours very truly, F.K.~'Kreb{ll ~ Area Superintendent Enclosures FORM SA-I B ~. 55M I/65 MEMORANDUM State of Alaska TO: i- James A. Eilli~ FROM: DATE : SUBJECT: December 13~ 1965 Applic~.tion fo~ Pera~t to Drill !~ State 17595 ~5 - ~;mloaed is one approved copy o£ the above application. a check in the amount o£ ~50.00 for fillnt fee. Also enclosed k~ Fozl''~. P--1 SUBMIT IN ~. ;ATE' ST~,[E OF ALASKA (Other instruct! ..... on reverse side) OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL [] PLUG BACK [] b. TYPE OF WELL WELL WELL OTHER ZONE ZONE 9.. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska surface O- W ~, ~¥3U'~ OZ iN ~, ~e c.~ir ~%r~t%~] ~xr -eq±';IN--c%±2 vv, S. M. (Conductor No. 6 o£ Leg No. 1, Pan Am MGS Plat£o B" At proposed prod· zone rm ) 600' E & N of the SW Corner, Sec. 30, T9N-R12W 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICES DEEPEN [] 20 Miles NW of Kenai, Alaska Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO. APL 17595 6. IF INDIAN, ALLOTTEE OR TRIBE NAME __ 7. UNIT AGREEMENT NAME -- -- 8. FARM OR LEASE NAME MGS State 17595 9. WELL NO. 5 10. FIELD AN~ POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA Sec. 30, T9N-R12W Ir 12. B.OROUGH SHt 13. STATE Cook Inlet Alaska 1~. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17. NO. OF ACRES ASSIONED LOCATION TO NEAREST 4620' From Lease[ PROPERTY OR LEASE LINE, FT. Line I 5106 (Also to nearest drlg. unit line, if any) ~8. DISTANCE FROM PROPOSED LOCATIONs 19. PROPOSED DEPTH TO NEAREST WELL, DRILLING, COMPLETED, OR APPLIED FOR, ON THIS LEASE, FT. 2 5 0 0! [ i 0, 0 0 0 21. ELEVATIONS (Show whether DF, RT, GR, etc.) TO THis W~LL 16 0 20. ROTARY 'OR CABLE TOOLS Rotary 22: APPROX. DATE WORK WILL START* · 23. Est. RT 85' above MSL December 20, 1965 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 24, t 17-1/2" 12-1/4" ~-5/8" SIZE OF CASING ] 20" 13-3/8" 9-5/8" 7'" Liner WEIGHT PER FOOT 84 lb. 54. 5 lb. Circ SETTING~000!6001 DEPTH QUANTITY OF CEMENT 2000 Sx. 40, 43.5 lb. 8000' 1000 Sx. 23 lb. 7000 - 10,000' 500 Sx. Quantities of cement are approximate and will be determined by caliper logs and the prospective pays to be covered. Directional work will begin just under the 20" casing seat at 600' and will continue using conventional directional drilling equipment until the target area is obtained. · . 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 depths. ' Give blowout preventer program, if any. 24. I herebzeer~ify that the Forego. ing'-i~-'~;~e and Correct. TITLE Area Superintendent DAT~,~; _D..e___C,.e_._m_ be r 9, ~ 6 5 (This space for Federal or State office use) , / ./ff .,,/' .,; APPROVED BY ,~I ( // Z~"' {;'Xt,'"~,-(Ji''C'''C ....... TITLE *See Instructions On Reverse Side TI9 /V I SEWi*~G ME,RI~IAN , ,t~;..A~KA -.£G '.-' ~ LES r':3 2 ~,%T 60° 49' 45.75" LA% 60° 49' 45.22" . ',.CNG 15t°29' O0 95" LONG ~5~~ 29' 00.07" :' = 2~498,069.8 Y = 2~498~014.46 Y = Z~497,96~.55 X = 235, 255.0 X ; 235~29~.30 X = Z55~250-30 F~OM N.W COR. FRO~. NW. COR. FROM N.W. COR. ;~34' SOUTH ~ 1989' SOUTH 8 2041 SOL;TH 544' EAST 588' EAST 5Z2 EAST TgN SCALE I" = I000' I !6 T 8 N LEG N'3 3 I 'LEG NO 4 LAT. GO° 49' 44,70" I ;_AT.60°49' 45.23" LONG 151° 2.~' Gl. 41" J LONG 151° 29' 02.29" Y= Z,4981018.88 X= 235,187.78 FROM N.W. COR. 1987 SOUTH & 478' EAST The locmt:on o¢-, ,- ....... ~ e: .' WQ$ OC¢OFG:Diishsc:. ;~-.' d:.:,i- . U.S.C.8 G.S. monu:,~an:'s -,-'.:.:_ Boulder, and Cos?, ~L!'¥', cc- trol poin?s C~ ~ ;cn~ · Granite P,:,:. n? and tr,angulc?ion s".'ctior,; .... Foreland Light Offset , c.~ .... Arness Dock. 32 COOK INLET CERTIFICATE OF SURVEYOR I I~ereby certify .that I am properly registered ~d I~censed to practice land surveying in the Stere o¢ Alaska and that this plat represents a location survey made'by me or under my supervision and that all dimensions and other details ere correct. LOCATION SURVF_Y OF , A FI RST ORDER CO.','~ :-'~ :,'..,L -POi N';" "PAH" n,, o, ,~T=--::,,.~ ..... v I 'i i ~/-~/, ' '.¢' ,"~ '.'.q SURVEYED PAN AMERI CAN PE-:-~OLEUM C.:,'; ': JPO BOX 779 A,'-:_~.H_'.g.~.~_E.~ A__~__:?:.:.~...'-'.. SU~VEYF'D 8Y F. M. LI ,,:~'"'"EY~, . 8, AS£CC. LAND SURVEYORS & CIVIL 1415 W NORT".dERN LIGHTS ANCNORAGE ~ ALASKA