Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
191-020
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-12-30_23069_KRU_1A-28_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23069 KRU 1A-28 50-029-22126-00 Caliper Survey w/ Log Data 30-Dec-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 191-002 T39953 1/13/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.13 12:32:27 -09'00' 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Install Coil String w/Jet Pump Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,550 feet 10,198 feet true vertical 9,768 feet 9,754 feet Effective Depth measured 9,754 feet N/A feet true vertical 9,639 feet N/A feet Perforation depth Measured depth 9,085 - 10,133 feet True Vertical depth 8,557 - 9,398 feet 2-7/8" 6.4# / N-80 9,013 MD 8,502 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / N-80 6,457 MD 6,310 TVD 2-3/8" 4.6# / N-80 9,011 MD 8,501 TVD 2" 2.677# / HT95 9,027 MD 8,513 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,130psi2,730psi 907 777-8376 6,330psi 1,584 6,818 9,764 1,584 Conductor Surface 7,020psi 3,810psi 13-3/8" 6,974 Size 136 Production Casing Structural Liner 4,032 Length Intermediate N/A Junk 5. Permit to Drill Number: 0 Granite Point Field / Middle Kenai Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 21 Gas-Mcf 151 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-493 LS - 3440 SS - 72 Authorized Signature with date: Authorized Name: 19 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-020 50-733-20443-01-00 Plugs AL0018742 Granite Pt St 18742 20RD measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data LS - 0 SS - 00 Casing Pressure 7" 6,974 MD 1,584 10,545 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:27 pm, Apr 08, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.04.08 12:51:15 -08'00' Dan Marlowe (1267) RBDMS HEW 4/9/2021 SFD 4/15/2021 DSR-4/12/21 BJM 5/6/21 Updated by: JLL 04/08/21 Bruce Platform Well # Br 20RD-42 Completed: 5/16/93 SCHEMATIC API # 50-733-20443-01 RKB to TBG Head = 44.95’ 1 5 b a 4 2 3 6 c 4 7 8 9 10 PBTD = 10,198’ MD 9,457’ TVD TD = 10,550’ MD 9,768’ TVD A B CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 54.5# J-55 12.615” Surface 1,584’ 9-5/8” 40, 43.5# S-95 & N-80 8.755” Surface *6,974’ 7” Liner 29, 32# N-80 & S-95 6.094” 6,513’ 10,545’ Tubing Long String 2-7/8” 6.4# N-80 Buttress 2.441” 47’ 9,013’ Short String 3-1/2” 9.2# N-80 Buttress 2.992” 48’ 6,457’ 2-3/8” 4.6# N-80 Buttress 1.995” 6,457’ 9,011’ 2” CT 2.677# HT95 Flash Free 1.866” Surf 9,027’ * Note for 9-5/8” Casing – 6,974’ is top of window. JEWELRY DETAIL NO.Depth ID OD Item 44.95’ Tubing Hanger, C.I.W. 5M x 3-1/2” x 10” Dual 1 45.85’ X-Over, 3-1/2” Butt. X 2-7/8” Butt. X 2’, P x P 2 9,013’ 2.441 2.875 X-Over, 2-7/8” Butt. Box x 2-7/8” 8rd. EUE Pin 3 9,013’ 2.250 5.625 Kobe, 2-1/2” ‘Dbl B’, Cavity S/N 93-5-5 4 9,032’ 2.441 2.875 2-7/8” N80, 8rd Pup x 10’ 5 9,043’ 2-7/8” Isolation x 2’ 6 9,045’ X-Over, 2-3/8” X 2-7/8” 8rd P X B 7 9,045’ 1.56 4) 2-3/8” N-80 8rd Pups (33’) w/ no-go 1.56” ID 8 9,078’ 2) Firing Heads 99,082’ Blank 10 9,085’ 4.625 4 – 5/8” O.D. Vann TCP Guns ( 425’) Short String a 45.85’ X-Over, 3-1/2” TDS x 3-1/2” Butt. P x P b 6,457’ 1.995 X-Over, 2-3/8” Butt x 3-1/2” TDS P x B c 9,011’ X-Over, 1-1/4” 10 rd. Pin x 2-3/8” Buttress Box x 1.4’ long Coil Tubing Jet Installation A 0’ 1.866 2.000 Coil Tbg 2”, 0.125” wall 9,012’ CTC X-over B 9,013’ Jet Pump Cavity w/Sealing BHA, 1-1/2” 9,027’ Bottom Seals PERFORATION DETAILS Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8" TCP Guns C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8" TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8" TCP Guns C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Fish NO.Depth (Top)Length Item I 9,754’ 469’ 11/19/99 - Cut off 425’ TCP guns plus tubing, etc. above for total of 469’. Tubing cut @ +/- 9,041’ = 2’ above isolation sub @ 9,043’ up in the 10’ pup joint. Last tag was 2/14/00 @ 9754’ w/ 2” LIB. Rig Start Date End Date CTU 3/6/21 3/10/21 Arrive OSK. Fly to platform. Platform Orientation & PJSM. Wait on M/V Titan to arrive. M/V Titan arrives @ platform. Offload Titan spotting reel, fluid pump, CTU console, CTU power pack, generator & injector, & dog house/toolbox on platform drill deck. Run hydraulic hoses from power pack to console & reel. Run generator line to console. Offload BOP, gooseneck/hose basket, choke manifold, reverse out skid, work window, iron rack, lubricator box, CT hanger head basket, C-pump & cribbing. M/V Titan away from platform. Run hydraulic lines to injector & BOP. Spot reverse out skid and run pump iron from fluid pump to RO skid & CTU reel. MU gooseneck to injector. Stab 2" CT (WT =0.134") in injector. SDFN. Waiting for 2nd boat to deliver flowback tank & treatment fluid. Job in Progress. 03/06/21 - Saturday Simops mtg w/ production. PJSM & permit. Replace FB tank drain manifold 4" - 150 butterfly valve. Test all drain manifold butterfly valves w/ water - PASS. Freeze protect FB tank drain manifold. Function tested work wndow. Removed the 2 work platforms from the work window to reduce pinch point potential and allow 360 degree access to window while standing on well room mezzanine. 1.495" OD teflon swab washers arrive platform. Drift thru CTC. Prep 2" CT & MU 2" slip x 2.375" OD External Grapple CT connector. Pull test, CTC threads fail at 9K attempting to pull test to 15K. CTC grapple cap threads damaged. Call for welder. Cut top threaded section off of EGCTC prepping to weld CTC to 2" CT. Welder arrives platform. Weld 2" CT x 2.375" OD CTC to 2" CT (HT-95-C BlueCoil) per manufacturer specs. Pull test = 15K. Press test = 4200 psi. RDFN. Secure drill deck. SDFN. Job in progress. 03/07/21 - Sunday Simops mtg w/ production crew. PJSM & permit. LS/SS/IA = 0/0/10. Prodution Operator closes Lower LS & SS master valves. Vault WH Tech removes Upper LS & SS master valves. Vault MU CT Hanger tree on LS: 3-1/8" - 5M Flo_tee w/ 2- 1/16" - 5M valve, 3-1/16" - 5M X 2" CT hanger head. Vault MU 3-1/8" - 5M Flo-tee on SS w/ 2-1/16" - 5M blind flange on side outlet and 3-1/16" - 5M ported flange on top w/ gauge. CT crew MU X-over flange, 4-1/16" - 10M work window, 5' riser & 4-1/6" - 10M BOP on LS. Drawing of WHA saved to O drive project file. BOPE Test 250 LO/3500 HI as per sundry. Tested BOPE per AOGCC & Hilcorp standards & requirements. Witness waived by AOGCC (Jim Regg). AOGCC BOPE test report submitted to AOGCC. Copy of test report saved to O drive project file. Yellowjacket Toolhand & WSM drift CT connector (2" CT slips x 1.50" 10rd EUE pin, MIN. ID = 1.55") w/ Prime Pump Solutions CAT-SV (MAX . OD = 1.516"). Attempt to drift CTC w/ PPS Jet Pump. Jet pump packing & body (MAX OD = 1.530") drift CTC. Jet pump teflon swab washers (OD = 1.712") will not drift CTC. Call for 1.495" OD teflon swab washers. All PPS drawings of jet pump equipment saved to O drive project file. M/V Titan arrives platform. Offload 5000 gal. diesel Iso, 100 bbl Flowback tank, gas buster, heater & light plant spotting all on deck. M/V Titan away from platform. MU flowback iron from choke to FB Tank & suction hose from ISO to fluid pump. Drift 2" CT (WT = 0.134" - seemless) w/ 1.561" OD ball & 38 bbl diesel displacement. SDFN. Job in Progress. 03/08/21 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 18742 20RD 50-733-20443-01-00 191-020 BOPE Test 250 LO/3500 HI as Witness waived by AOGCC (Jim Regg). *Sundried procedure called for a 5000 psi PT of the coiled tubing head and master valves connections. These were tested to 3500 psi during the BOP test. The discrepency was self-reported by Hilcorp once it came to the attention of the Katherine O'Conner, Ops Engineer. Maximum surface injection pressure is 3400 psi. See attached e-mail disclosure. bjm Rig Start Date End Date CTU 3/6/21 3/10/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 18742 20RD 50-733-20443-01-00 191-020 03/10/21 - Wednesday Simops w/ production. PJSM & permit. Turnover well to production to bring online. Continue rigging down CTU equipment package prepping all loads for backload to boat. Clean & secure drilling deck. Fly Tool Hand & WH Tech to beach. Waiting on boat. M/V Titan arrives @ platform. Backload complete CTU kit to boat. M/V Titan away from platform. Fly crews to beach. Job Complete. Simops mtg w/ production. PJSM & permit. PU injector & 1 stand of lubricator. Production Operator installs CAT-SV (0.74' L x 1.525" OD) on seat in Jet Pump BHA. MU Jet Pump BHA (14.2 L x 2.322 OD) to CT Connector (0.33" L x 2.375" OD). Move to WH. Press test = 3500 psi. LS/SS/IA/OA = 0/0/8/40. RIH w/ 2" CT @ 40 FPM w/ choke full open to FB tank. No Flow well. TIH to 2750'. Bring fluid pump online w/ diesel @ 0.30 BPM. TIH @ 30 FPM to 8900'. WT CHK = 28K. Continue RIH, RIW = 16K. 9013' KB soft tag @ bottom of KOBE, CTW = 5K . SD pump. PUH, PUW = 33K off bottom, fall back to 28K. PUH to 8975'. RBIH 10 FPM @ 16K RIW. 9000' KB weight set off, continue to 9013' soft tag depth, CTW = 5K. LS/SS = 0/0. 9013' KB bring fluid pump online @ 0.30 BPM CTP = 35 psi & slowly increase pump rate to 0.90 BPM w/ CTP = 125 psi. Watching Short String gauge for communication response. Pump 10 bbl diesel. LS/SS = 0/8. NO FLOW Test Long String for 30 minutes. LS is NO FLOW & STATIC. PUH w/ 2" CT (WT = 0.134" - seemless) to PUW = 27K & hold. Open work window. Vault WH tech MU CT hanger head packoff on 2" CT & pushes packoff into place and seated in CT hanger head & sets hanger head lock down screws. Vault WH Tech MU 2" CT slips on coil & pushes same into place on top of CT hanger head packoff. Slack off on coil to CTW = 0 to set & seat slips in CT hanger head. Hot tap 2" CT & NO FLOW Test CT for 30 minutes. CT is NO FLOW. Cut 2" CT below hot tap port. PUH w/ CT to top of BOP. Close work window. RD BOP & Flow Tee. RD riser, work window & X-over spool. Trim 2" CT to 5.75" stub above CT hanger head top flange. Vault WH Tech MU Flanged Seal Sub & Master Valve to top of CT hanger head. Vault WH Tech continues to MU Dual String Tree on Long string and Short string. SDFN. Job in Progress 03/09/21 - Tuesday MU CT hanger head packoff on 2" CT & pushes packoff into place and seated in CT hanger head & sets hanger head lock down screws. V MU Jet Pump BHA (14.2 L x 2.322 OD) to CT Connector 9000' KB weight set off, continue to 9013' soft tag depth, LS is NO FLOW & STATIC. Slack off on coil to CTW = 0 to set & seat slips in CT hanger head. CT is NO FLOW. Cut 2" CT below hot tap port. Trim 2" CT to 5.75" stub above CT hanger head top flange. MU Flanged Seal Sub & Master Valve to top of CT hanger head. Vault WH Tech continues to MU Dual String Tree on Long string and Short string. S Report is missing pressure test of new Wellhead components and the new completion PT to 3500 psi. 1 Winston, Hugh E (CED) From:Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent:Wednesday, April 7, 2021 3:39 PM To:McLellan, Bryan J (CED) Cc:Juanita Lovett Subject:PTD: 191-280 Sundry: 320-493 BR20RD-24 Coil String Attachments:10-403 Granite Pt St 18742 20RD - Approved - Sundry_320-492_120920.pdf Hello Bryan, This email is to inform to you that we pressure tested coil tubing head and master valves to 3,500 psi during the BOP test. This is not per the sundry of a separate individual test to 5000 psi (step 4). Regrettably, this was just brought to my attention, so I am self‐reporting to AOGCC. The maximum surface pressure this well sees is the power fluid pumped down the long string (where the coil is installed) which has a maximum pressure rating of 3400 psi. If you have any questions or concerns, please don’t hesitate to reach out to me. Thank you Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777‐8376 C: (214) 684‐7400 1 Winston, Hugh E (CED) From:Katherine O'connor <Katherine.Oconnor@hilcorp.com> Sent:Wednesday, May 5, 2021 3:16 PM To:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL] GPS 18742 20RD (PTD 191-020) 10-404 Attachments:Well Report Notes 3-10-21.jpg Hey Bryan Attached are the WSL’s written notes from the day. Pressure test to 3500 psi was executed at 1830. This pressure test tested the short string and the newly installed coil tubing, BHA/jet pump cavity, and the CT hanger & master valve. Thank you Katherine Katherine O’Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777‐8376 C: (214) 684‐7400 From: Katherine O'connor Sent: Wednesday, May 5, 2021 2:49 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] GPS 18742 20RD (PTD 191‐020) 10‐404 Hi Bryan When we closed out the sundry I noticed the discrepancy regarding the pressure tests for the wellhead, I emailed you on the 7th when I looked at the reports (see attached). I also do not see mention of the 3500 psi pressure test after the completion was done, but I do distinctly remember completing that pressure test because I had a long discussion with the WSL and operator about passing criteria and why we were doing the pressure test in the first place. Let me reach out to our WSL and get back to you on this one to see what happened. Thank you Katherine From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, May 5, 2021 10:20 AM To: Katherine O'connor <Katherine.Oconnor@hilcorp.com> Subject: [EXTERNAL] GPS 18742 20RD (PTD 191‐020) 10‐404 Hi Katherine I’m reviewing the 10‐404 for Sundry 320‐493 and it looks like it is missing some information. The report does not include the pressure tests for the new CT wellhead components or the PT of the completion to 3500 psi. Please submit the additional reports and I’ll have them attached to the 10‐404. Thank you 2 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250‐9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Granite Point Field / Middle Kenai Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,550'9,754' Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 3,810 psi Liner 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Install Coil String w/Jet Pump Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 10,198' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 191-020 50-733-20443-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A Granite Pt St 18742 20RD 6.4#, 9.2#, 4.6# / N-80 TVD Burst 9,013; 6,457; 9,011 6,330 psi 8,160 psi Tubing Size: MD 2,730 psi1,584'1,584'13-3/8"1,584' 6,974' Perforation Depth MD (ft): 9,085 - 10,133 6,974' N/A & N/A Tubing Grade:Tubing MD (ft): 8,557 - 9,398 Perforation Depth TVD (ft): Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12/6/2020 2-7/8", 3-1/2" & 2-3/8" Daniel E. Marlowe N/A & N/A 9,768' 9,754' 9,639' 1,424 psi 4,032' 7" 6,818'9-5/8" 10,545' 9,764' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:30 pm, Nov 18, 2020 320-493 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Reason: I am approving this document Date: 2020.11.18 13:52:03 -09'00' Daniel Marlowe 10-404 Install Coil String w/Jet Pump X DLB11/19/2020 DSR-11/18/2020gls 12/7/20 *3500 psi BOPE test (CT) CTU X Comm. ion Required? Yes 12/9/2020 dts 12/7/2020 JLC 12/7/2020 RBDMS HEW 12/9/2020 Well Work Prognosis Well Name: Granite Pt St 18742 20RD API Number: 50-733-20443-01 Current Status: Jet Pump Producer Leg: Leg #1 N Corner Estimated Start Date: Dec 15, 2020 Rig: Coil, SL Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 168-099 First Call Engineer: Katherine O’Connor (907) 776-8376 (O) (214) 684-7400 Second Call Engineer: Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure: 2280 psi @ 8557’ TVD 0.266 lbs/ft Maximum Expected BHP: 2280 psi @ 8557’ TVD 0.266 lbs/ft Maximum Potential Surface Pressure: 1424 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary BR20RD-42 is a jet pump oil producer. The long string had a patch from ~5796’-5950’ MD, and other holes in the tubing causing integrity issues, this patch was pulled during diagnostics in November. The well has been shut in consistently since Oct 2019 but was not producing at max rate due to holes in the tubing before that. Attempts to find and patch the holes were met with minimal success. The short string has integrity based on a passing pressure test 11/6/2020. Max operating pressure of the long string expected to be 3200 psi. Objective of this program is to set a 2” coil velocity string in the long string, from surface to the jet pump cavity in order to reestablish well integrity. Notes: x Barrier to reservoir will be a column of diesel Procedure: 1. Test wellhead 2. Kill well w/ diesel 3. Shut in master valve 4. Install new coil head w/ spacer and test connections to 5000psi against master valves 5. MIRU CTU with 2” velocity string installed x Rig up on long string. 6. Test BOPE to 250 psi low / 3500 psi high x Notify AOGCC 48 hours in advance of test in order to extend witness opportunity 7. Make up BHA including CT connector and jet pump cavity assembly sized for 1.5” Petrolift jet pump 8. RIH to ~9013’ and land BHA in KOBE cavity. x Jet pump cavity BHA has upper and lower seals which seal in the KOBE cavity in order to prevent annular communication 9. Pick up and space out completion 10. Close CT pipe rams 11. Install slips and pack-off on coiled tubing and land out in wellhead. Run in lockpins to energize the seal. Pressure up on back-side of coil above hanger and against pipe rams to test seal integrity to BOP test pressure. 12. Cut coil 13. Dress out coil and install coiled tubing adapter w/ 2’’ secondary sealing bottom 14. Install new 3 1/8 5M 5 bolt master valves on top of coil tubing head and test 15. RD CTU SL Procedure 16. RU SL and PT lubricator to 1500hi/250low 17. Install new standing valve, pressure test completion (jet pump cavity, CT in long string, short string) to 3500 psi. (this will test new LS Master valve flanges also. ) ) Note: can't test LS new master valve lower flange (verify well is dead before pulling lubricator up and cutting coil) gls (s) UPDATED PROCEDURE Well Work Prognosis 18. Pump down jet pump 19. RDMO 20. Turn well over to production Attachments: 1. Well Schematic - Current 2. Well Schematic - Proposed 3. Wellhead Diagram – Current 4. Wellhead Diagram – Proposed 5. Coil Tubing BOP Drawing 6. Coil Layout drawing 7. Sundry Revision Change Form Well Work Prognosis Well Name:Granite Pt St 18742 20RD API Number: 50-733-20443-01 Current Status:Jet Pump Producer Leg:Leg #1 N Corner Estimated Start Date:Dec 6, 2020 Rig:Coil,SL Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:168-099 First Call Engineer:Katherine O’Connor (907) 776-8376 (O) (214) 684-7400 Second Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure: 2280 psi @ 8557’ TVD 0.266 lbs/ft Maximum Expected BHP:2280 psi @ 8557’ TVD 0.266 lbs/ft Maximum Potential Surface Pressure: 1424 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary BR20RD-42 is a jet pump oil producer. The long string had a patch from ~5796’-5950’ MD, and other holes in the tubing causing integrity issues, this patch was pulled during diagnostics in November. The well has been shut in consistently since Oct 2019 but was not producing at max rate due to holes in the tubing before that. Attempts to find and patch the holes were met with minimal success. Objective of this program is to set a 2” coil string in the long string, from surface to the jet pump cavity to regain integrity of the well. The short string has integrity based on a passing pressure test 11/6/2020. Max operating pressure of the long string expected to be 3200 psi. Procedure: 1. Test wellhead seals 2. Kill well w/ diesel 3. MIRU CTU x Test BOPS to 3500 psi/250 psi (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Set 2” coiled tbg w/ jet pump cavity BHA in long string 5. Space out completion and land CT in hangar. 6. Pressure test CT & completion to 3500 psi 7. RD CTU 8. RU SL and PT lubricator to 1500hi/250low 9. Install new standing valve and pump 10. RDMO Attachments: 1. Well Schematic - Current 2. Well Schematic - Proposed 3. Wellhead Diagram – Current 4. Wellhead Diagram – Proposed 5. Coil Tubing BOP Drawing 6. Coil Layout drawing 7. Sundry Revision Change Form ia rate ess. rega ating s diesel 99 14) (90 1 ps fro agnag to ho is pro e short s be 3200 psi. W urr ma rov nta K 22 80 p psi ad a diaa SUPERCEDED Updated by: JLL 11/11/20 Bruce Platform Well # Br 20RD-42 Completed: 5/16/93 SCHEMATIC API # 50-733-20443-01 RKB to TBG Head = 44.95’ 1 5 B A 4 2 3 6 C 4 7 8 9 10 PBTD = 10,198’ MD 9,457’ TVD TD = 10,550’ MD 9,768’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 54.5# J-55 12.615” Surface 1,584’ 9-5/8” 40, 43.5# S-95 & N-80 8.755” Surface *6,974’ 7” Liner 29, 32# N-80 & S-95 6.094” 6,513’ 10,545’ Tubing Long String 2-7/8” 6.4# N-80 Buttress 2.441” 47’ 9,013’ Short String 3-1/2” 9.2# N-80 Buttress 2.992” 48’ 6,457’ 2-3/8” 4.6# N-80 Buttress 1.995” 6,457’ 9,011’ * Note for 9-5/8” Casing – 6,974’ is top of window. JEWELRY DETAIL NO.Depth ID OD Item 44.95’ Tubing Hanger, C.I.W. 5M x 3-1/2” x 10” Dual 1 45.85’ X-Over, 3-1/2” Butt. X 2-7/8” Butt. X 2’, P x P 2 9,013’ 2.441 2.875 X-Over, 2-7/8” Butt. Box x 2-7/8” 8rd. EUE Pin 3 9,013’ 2.250 5.625 Kobe, 2-1/2” ‘Dbl B’, Cavity S/N 93-5-5 4 9,032’ 2.441 2.875 2-7/8” N80, 8rd Pup x 10’ 5 9,043’ 2-7/8” Isolation x 2’ 6 9,045’ X-Over, 2-3/8” X 2-7/8” 8rd P X B 7 9,045’ 1.56 4) 2-3/8” N-80 8rd Pups (33’) w/ no-go 1.56” ID 8 9,078’ 2) Firing Heads 99,082’ Blank 10 9,085’ 4.625 4 – 5/8” O.D. Vann TCP Guns ( 425’) Short String A 45.85’ X-Over, 3-1/2” TDS x 3-1/2” Butt. P x P B 6,457’ 1.995 X-Over, 2-3/8” Butt x 3-1/2” TDS P x B C 9,011’ X-Over, 1-1/4” 10 rd. Pin x 2-3/8” Buttress Box x 1.4’ long PERFORATION DETAILS Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8" TCP Guns C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8" TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8" TCP Guns C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Fish NO.Depth (Top)Length Item I 9,754’ 469’ 11/19/99 - Cut off 425’ TCP guns plus tubing, etc. above for total of 469’. Tubing cut @ +/- 9,041’ = 2’ above isolation sub @ 9,043’ up in the 10’ pup joint. Last tag was 2/14/00 @ 9754’ w/ 2” LIB. SS powerfluid LS Updated by: JLL 11/17/20 Bruce Platform Well # Br 20RD-42 Completed: 5/16/93 PROPOSED API # 50-733-20443-01 RKB to TBG Head = 44.95’ 1 5 b a 4 2 3 6 c 4 7 8 9 10 PBTD = 10,198’ MD 9,457’ TVD TD = 10,550’ MD 9,768’ TVD A B CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 54.5# J-55 12.615” Surface 1,584’ 9-5/8” 40, 43.5# S-95 & N-80 8.755” Surface *6,974’ 7” Liner 29, 32# N-80 & S-95 6.094” 6,513’ 10,545’ Tubing Long String 2-7/8” 6.4# N-80 Buttress 2.441” 47’ 9,013’ Short String 3-1/2” 9.2# N-80 Buttress 2.992” 48’ 6,457’ 2-3/8” 4.6# N-80 Buttress 1.995” 6,457’ 9,011’ * Note for 9-5/8” Casing – 6,974’ is top of window. JEWELRY DETAIL NO.Depth ID OD Item 44.95’ Tubing Hanger, C.I.W. 5M x 3-1/2” x 10” Dual 1 45.85’ X-Over, 3-1/2” Butt. X 2-7/8” Butt. X 2’, P x P 2 9,013’ 2.441 2.875 X-Over, 2-7/8” Butt. Box x 2-7/8” 8rd. EUE Pin 3 9,013’ 2.250 5.625 Kobe, 2-1/2” ‘Dbl B’, Cavity S/N 93-5-5 4 9,032’ 2.441 2.875 2-7/8” N80, 8rd Pup x 10’ 5 9,043’ 2-7/8” Isolation x 2’ 6 9,045’ X-Over, 2-3/8” X 2-7/8” 8rd P X B 7 9,045’ 1.56 4) 2-3/8” N-80 8rd Pups (33’) w/ no-go 1.56” ID 8 9,078’ 2) Firing Heads 9 9,082’ Blank 10 9,085’ 4.625 4 – 5/8” O.D. Vann TCP Guns ( 425’) Short String a 45.85’ X-Over, 3-1/2” TDS x 3-1/2” Butt. P x P b 6,457’ 1.995 X-Over, 2-3/8” Butt x 3-1/2” TDS P x B c 9,011’ X-Over, 1-1/4” 10 rd. Pin x 2-3/8” Buttress Box x 1.4’ long A.±0’ Coil Tbg 2”, 0.125” wall ±9,012’ CTC X-over B.±9,013’ Jet Pump Cavity w/Sealing BHA, 1-1/2” ±9,026’ Bottom Seals PERFORATION DETAILS Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/199 34-5/8" TCP Guns C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/199 34-5/8" TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/199 34-5/8" TCP Guns C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/200 0 2" PowerJet w/ Spec. Phs. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/200 0 2" PowerJet w/ Spec. Phs. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/200 0 2" PowerJet w/ Spec. Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns Fish NO.Depth (Top)Length Item I 9,754’ 469’ 11/19/99 - Cut off 425’ TCP guns plus tubing, etc. above for total of 469’. Tubing cut @ +/- 9,041’ = 2’ above isolation sub @ 9,043’ up in the 10’ pup joint. Last tag was 2/14/00 @ 9754’ w/ 2” LIB. Bruce Platform 20RD-42—proposed coil rev 1 11/30/2020 Coil tubing head, WCI, RH-4, 3 1/8 5M 5 bolt FE X 2 1/16 5M EFO, 2'’ coil tubing slip and seal assy Casing head, OCT-22-BP, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SS0, X-bottom prep, 1 ½ VR profile Tubing hanger, dual, CIW-DCB, 11 X 3 ½ EUE lift X 3 ½ IBT susp, w/ 3'’ type H BPV profile, 5 3/64 centers Bruce Platform BR 20-42 13 3/8 x 9 5/8 x 3 ½ x 2 7/8 x 2 Spacer spool for future coil installation LS SS updated Bruce Platform 20RD-42—Current 10/02/2020 Casing head, OCT-22-BP, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SS0, X-bottom prep, 1 ½ VR profile Tubing hanger, dual, CIW-DCB, 11 X 3 ½ EUE lift X 3 ½ IBT susp, w/ 3'’ type H BPV profile, 5 3/64 centers Bruce Platform BR 20-42 13 3/8 x 9 5/8 x 3 ½ x 2 7/8 Current configuration Bruce Platform 20RD-42—proposed coil 10/02/2020 CIW tbg head adapter 11 5M x 11 5M stdd, prepped for CIW seal pockets on top and bottom, 4 special lock down screws, VGCT coil tubing hanger bowl on both sides, 2 1/16 5M SSO 5 3/64 centers Casing head, OCT-22-BP, 13 5/8 3M X 13 3/8 SOW, w/ 2- 2 1/16 5M EFO Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SS0, X-bottom prep, 1 ½ VR profile Tubing hanger, dual, CIW-DCB, 11 X 3 ½ EUE lift X 3 ½ IBT susp, w/ 3'’ type H BPV profile, 5 3/64 centers Bruce Platform BR 20-42 13 3/8 x 9 5/8 x 3 ½ x 2 7/8 Coil tubing hangers 3'’ nom x 2'’ coil 3'’ GS latch to land New COIL TUBING Head (twin) SUPERCEDED OW, M EF Coiled Tubing BOP SWAB VALVE MASTER VALVE Hilcorp Monopod Rig 56 Flow Diagram Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 18742 20RD (PTD 191-020)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 Carlisle, Samantha J (CED) From:Schwartz, Guy L (CED) Sent:Friday, December 4, 2020 7:57 AM To:Katherine O'connor Cc:Juanita Lovett Subject:RE: [EXTERNAL] GP 18742 20RD (PTD 191-020) Jet pump run on CT Katherine, Thisprogramshouldbefine.IseenowthatyouhavetowaittillSLsetsthestandingvalvetotestthe completion.AssumeyouwilltestthewholesystembypressuringuptheLSandShortstringtogetheragainstthe Standingvalvebeforejetpumpisset. Thereisnocheckvalvein2”CTbutyourmainriskiswhileyouaremakinguptheCThangertothecoilstring.Thereis onlyafluidbarriertoreservoir…makesuretheymonitorwellfor30minutesbeforepullingtherisertomakethat connectionandbereadywithshear/blindsifneeded.(PIPE/SLIPwillbeclosedalready). VerylowriskbasedonBHPhowever. ThenewWellheaddiagrammakesawholelotmoresensetoo. Goodideatofixthiswell…. Goodluck! GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Sent:Wednesday,December2,20204:02PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:JuanitaLovett<jlovett@hilcorp.com> Subject:RE:[EXTERNAL]GP1874220RD(PTD191Ͳ020)JetpumprunonCT HelloGuy, Iattachedtheoldprocedure,updatedprocedureandwellheaddiagram.Astherearenochangestotheprogram,just increaseddetail,Ididn’thighlightanytextinredandIdon’thaveanMOCsundrychangeform,butletmeknowifyou wanteitherofthoseandIcanupdate.Letmeknowifyouhaveanyquestions,thisjetpumpandBHAarefitforpurpose. Thankyou KatherineO’Connor 2 214Ͳ684Ͳ7400 From:Schwartz,GuyL(CED)[mailto:guy.schwartz@alaska.gov] Sent:Monday,November23,202012:47PM To:KatherineO'connor<Katherine.Oconnor@hilcorp.com> Subject:[EXTERNAL]GP1874220RD(PTD191Ͳ020)JetpumprunonCT Katherine, Ilookedatthesundryapplication.Itisabittoobriefaswrittentobeapproved.IwouldchatwithTedonmy expectationsonrunningthistypeofcompletion.Itissimilartoavelocitystring. Forinstance...youneedtodiscussinstallingthenewCThead,anymechanicalbarriersusedthisoperation,howare youplanningontestingtheintegrityofthecompletionetc.,Also,thenewwellheadshowstwoCTstringsinbothSS andLS.IknowyouareonlyrunningCTintheLongstring. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Remove Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,550 feet 10,198 feet true vertical 9,768 feet 9,754 feet Effective Depth measured 9,754 feet N/A feet true vertical 9,639 feet N/A feet Perforation depth Measured depth 9,085 - 10,133 feet True Vertical depth 8,557 - 9,398 feet 2-7/8" 6.4# / N-80 9,013 MD 8,502 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / N-80 6,457 MD 6,310 TVD 2-3/8" 4.6# / N-80 9,011 MD 8,501 TVD Packers and SSSV (type, measured and true vertical depth)N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,130psi2,730psi 907 777-8376 6,330psi 1,584 6,818 9,764 1,584 Conductor Surface 7,020psi 3,810psi 13-3/8" 6,974 Size 67 Production Casing Structural Liner 4,032 Length Intermediate N/A Junk 5. Permit to Drill Number: 0 Granite Point Field / Middle Kenai Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 140 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-020 50-733-20443-01-00 Plugs AL0018742 Granite Pt St 18742 20RD measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 Casing Pressure 7" 6,974 MD 1,584 10,545 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:19 am, Nov 18, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.18 06:41:54 -09'00' Dan Marlowe (1267) RBDMS HEW 11/18/2020 gls 12/10/20 SFD 11/18/2020DSR-11/23/2020 Updated by: JLL 11/11/20 Bruce Platform Well # Br 20RD-42 Completed: 5/16/93 SCHEMATIC API # 50-733-20443-01 RKB to TBG Head = 44.95’ 1 5 B A 4 2 3 6 C 4 7 8 9 10 PBTD = 10,198’ MD 9,457’ TVD TD = 10,550’ MD 9,768’ TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 54.5# J-55 12.615” Surface 1,584’ 9-5/8” 40, 43.5# S-95 & N-80 8.755” Surface *6,974’ 7” Liner 29, 32# N-80 & S-95 6.094” 6,513’ 10,545’ Tubing Long String 2-7/8” 6.4# N-80 Buttress 2.441” 47’ 9,013’ Short String 3-1/2” 9.2# N-80 Buttress 2.992” 48’ 6,457’ 2-3/8” 4.6# N-80 Buttress 1.995” 6,457’ 9,011’ * Note for 9-5/8” Casing – 6,974’ is top of window. JEWELRY DETAIL NO.Depth ID OD Item 44.95’ Tubing Hanger, C.I.W. 5M x 3-1/2” x 10” Dual 1 45.85’ X-Over, 3-1/2” Butt. X 2-7/8” Butt. X 2’, P x P 2 9,013’ 2.441 2.875 X-Over, 2-7/8” Butt. Box x 2-7/8” 8rd. EUE Pin 3 9,013’ 2.250 5.625 Kobe, 2-1/2” ‘Dbl B’, Cavity S/N 93-5-5 4 9,032’ 2.441 2.875 2-7/8” N80, 8rd Pup x 10’ 5 9,043’ 2-7/8” Isolation x 2’ 6 9,045’ X-Over, 2-3/8” X 2-7/8” 8rd P X B 7 9,045’ 1.56 4) 2-3/8” N-80 8rd Pups (33’) w/ no-go 1.56” ID 8 9,078’ 2) Firing Heads 99,082’ Blank 10 9,085’ 4.625 4 – 5/8” O.D. Vann TCP Guns ( 425’) Short String A 45.85’ X-Over, 3-1/2” TDS x 3-1/2” Butt. P x P B 6,457’ 1.995 X-Over, 2-3/8” Butt x 3-1/2” TDS P x B C 9,011’ X-Over, 1-1/4” 10 rd. Pin x 2-3/8” Buttress Box x 1.4’ long PERFORATION DETAILS Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8" TCP Guns C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8" TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8" TCP Guns C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 2" PowerJet w/ Spec. Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Fish NO.Depth (Top)Length Item I 9,754’ 469’ 11/19/99 - Cut off 425’ TCP guns plus tubing, etc. above for total of 469’. Tubing cut @ +/- 9,041’ = 2’ above isolation sub @ 9,043’ up in the 10’ pup joint. Last tag was 2/14/00 @ 9754’ w/ 2” LIB. tubing leaks in LS Rig Start Date End Date Slickline 11/4/20 11/5/20 11/07/20 - Saturday 11/10/20 - Tuesday 11/08/20 - Sunday 11/09/20 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name Granite Pt St 18742 20RD 50-733-20443-01-00 191-020 11/04/20 - Wednesday MORNING MEETING, JSA, PERMIT. P/U LUB, P.T. TO 2500 PSI, TESTS GOOD. RIH W/ 2 7/8 GS TO 5794'KB W/T POOH W/ AA-STOP. RIH W/ SAME TO 5795'KB W/T POOH W/ WEATHERFORD PACK OFF AND SPACER PIPE 26'. RIH W/ SAME TO 5821'KB W/T POOH W/ 21' SPACER. RIH W/ SAME TO 5841'KB W/T POOH W/ 21' SPACER. LUNCH. RIH W/ SAME TO 5851'KB W/T POOH W/ 20' SPACER. RIH W/ SAME TO 5883'KB W/T POOH W/ 20' SPACER. RIH W/ SAME TO 5905'KB W/T POOH W/ 22' SPACER. RIH W/ SAME TO 5928'KB W/T POOH W/ WEATHERFORD PACK OFF AND SPACER 24'. RIH W/ SAME TO 5950'KB W/T POOH W/ WEATHERFORD PACK OFF. RIH W/ SAME TO 5952'KB W/T POOH W/ AD-2 STOP. RIH W/ PUMP PULLING TO BAITED W/ 2'' JUC TO 9049'KB W/T POOH W/ PUMP 17' LONG. LAY DOWN LUB, REHEAD, SECURE WELL FOR NIGHT, LAY DOWN PUMP. FINISHED REHEADING. MORNING MEETING, JSA, PERMIT. P/U LUB. RIH W/ 2 7/8 GS W/ AD-2 STOP TO 9044'KB W/T POOH - AD-2 STOP SET. RIH W/ 2 7/8 GS W/ WEATHERFORD PACK OFF PLUG TO 9040'KB W/T POOH - PLUG SET. RIH W/ 2 7/8 GS W/ AA-STOP TO 9039'KB W/T POOH - AA-STOP SET. STAND BY FOR PRODUCTION TO TEST SHORT STRING - REBUILD PACK OFFS - SHORT STRING AND BHA HOLDS PRESSURE. RIH W/ MOP TO 5950'KB START INJECTING DOWN LONG STRING 600 TO 800 BBL/DAY RATE. RIH SLOW TO 9035'KB POOH SLOW TO 5950'KB, DO NOT DETECT HOLES POOH. RIH W/ PRONG TO 9040'KB W/T SHORT STRING GO ON VAC POOH. RIH W/ 2 7/8 GS TO 9039'KB W/T POOH W/ AA-STOP. RIH W/ SAME TO 9040'KB W/T POOH W/ PACK OFF PLUG. RIH W/ SAME TO 9044'KB W/T POOH W/ AD-2 STOP. LAY DOWN LUB SECURE WELL FOR NIGHT. 11/06/20 - Friday 11/05/20 - Thursday pull tubing patch pressure test SS - good THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 20D Permit to Drill Number: 191-020 Sundry Number: 319-344 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. a ogc c. a la ska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, V;rA�� Daniel T. Seamount, Jr. Commissioner DATEDthis `/day of July, 2019. I MS61 Jill 2 6 2019 ., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shuttdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Cha Jet Pump & 0 • Remove/Reinstall Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • 191-020 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50-733-20443-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑� Granite Pt St 18742 20RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018742 Granite Point Field / Middle Kenai Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,550 . 9,768 9,754 9,639 1,102 psi 10,198 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,085 -10,133 8,557 - 9,398 2-7/8" 6.4# / N-80 9,013 3-1/2'. 9.2# / N-80 6,457 2-3/8" 14.6# / N-80 9,011 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A & N/A N/A & N/A 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Pl' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/1/2019 OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowa hilcor .Com \ Contact Phone: (907) 283-1329 Authorized Signature: W Date: Z2 `� COMMIS ION USIE ONLY Conditions of approval: Notify Commission so that akrepresentative may witness Sundry Number: t 1 L4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ "7 Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ 61019 6 10F ((F4;SWOE3F Spacing Exception Required? Yes ❑ No Subsequent Form Required: //�� Azi" Y THEAPPROVEDBY ^/ Q Approved by: COMMISSIONER THE COMMISSION Date Z"9— � � t/ Submit Form and Form 10-403 Revised 4/201. �` i appliconRIliGMA r= the date of approval. AttacIn is in Duplicate ' I /z� z X11 n 11H. o Ataeka, LLI Well Prognosis Well: Granite Pt St 18742 20RD Well Name: GRANITE PT ST 18742 #20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 North Corner Estimated Start Date: 09/01/19 Rig: N/A Reg. Approval Re 'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Dan Marlowe 907 283-1329 O 907 398-9904 M Second Call Engineer: Stan Golis Office: 907-777-8356 Cell: 281-450-3071 Current Bottom Hole Pressure: 2,000 psi @ 8,977 It TVD 0.223 lbs/ft (4.28 ppg) Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: 2,000 psi @ 8,977 ft TVD 0.223lbs/ft (4.28 ppg) Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface Pressure 1,102 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) (MPSP): Brief Well Summary In order to service the downhole jet pump, the tubing patch must be removed. This job entails pulling the tubing patch, , swapping the downhole jet pump and reinstalling the tubing patch (extending the patch length if required). Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 2. Pull patch at 5,796'-5,950'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re -run standing valve. 6. Re -run Jet pump. 7. Re -run extended patch to +/- 5,795' to +/- 5,955' (WLM). 8. Attempt to pressure test patch against standing valve to 1,000psi. (well is a packerless completion so a small tubing leak will only impact the jet pump performance and not impact well safety) 9. Rig down slick line and lubricator. 10. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic Patch 5,796'- 5,950' WLM CJI 2 3 f12 4 k5 a 6 7 �69 10 C 0 PBTD = 10,198' MD 9,457' TVD TD = 10,550' MD 9,768' TVD Bruce Platform NO. Depth ID OD Item SCHEMATIC 44.95' Tubing Hanger, C.I.W. 5M x 3-1/2" x 30" Dual 1 45.85' X -Over, 3-1/2" Butt. X 2-7/8" Butt. X 2', P x P Well # Br 20RD-42 9,013' 2.441 2.875 X -Over, 2-7/8" Butt. Box x 2-7/8" 8rd. EUE Pin 3 9,013' Completed: 5/16/93 4 Hai".P:u�Ln. LLC 2.441 2.875 2-7/8" N80, 8rd Pup x 30' 5 9,043' 2-7/8" Isolation x 2' CASING AND TUBING DETAIL 9,045' API # 50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 9,082' Blank 10 9,085' 4.625 4-5/8" O.D. Vann TCP Guns (425') 9-5/8" 40,43.5# S-95 & N-80 8.755" Surface *6,974' X -Over, 3-1/2" TDS x 3-1/2" Butt. P x P B 1 1.995 X -Over, 2-3/8" Butt x 3-1/2" TDS P x B C A X -Over, 1-1/4" 30 rd. Pin x 2-3/8" Buttress Box x 1.4' long 7" Liner 29,32# N-80 & 5-95 6.094" 6,513' 10,545' Fish NO. Depth ITopl Length Item 1 Tubing 469' 11/19/99 - Cut off 425' TCP guns plus tubing, etc. above for total of 469'. Tubing cut @+/- 9,041' = 2' above isolation sub @ 9,043' up in the 10' pup joint. Last tag was 2/14/00 @ 9754' w/ Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,457' 9,011' ' Note for 9-5/8" Casing -6,974' is top of window. Patch 5,796'- 5,950' WLM CJI 2 3 f12 4 k5 a 6 7 �69 10 C 0 PBTD = 10,198' MD 9,457' TVD TD = 10,550' MD 9,768' TVD Zone C-5 C-5 C-6 C-7 C-7 C-7 C-7 C-7 C-7 C-7 C-7 C-8 Top (MD) 9,085' 9,170' 9,475' 9,585' 9,632' 9,653' 9,680' 9,713' 9,780' 9,816' 9,837' 10,071' Btm 9,140' 9,236' 9,510' 9,623' 9,640' 9,680' 9,698' 9,731' 9,803' 9,828' 9,875' 10,133' PERFORATION DETAILS Top Btm (TVD) (TVD) Amt SPF 8,557' 8,598' 55' 8,620' 8,668' 66' 8,848' 8,876' 35' 8,936' 8,967' 38' 12 8,974' 8,981' 8' 12 8,992' 9,014' 27' 12 9,014' 9,028' 18' 8 9,041' 9,0561 18' 8 9,096' 9,116' 23' 8 9,127' 9,137' 12' 8 9,144' 9,176' 38' 8 9,344' 9,398' fit' 8 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec, 2/14/2000 Phs. 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/5/1991 TCP Guns Updated by: JILL 07/17/2019 JEWELRY DETAIL NO. Depth ID OD Item 44.95' Tubing Hanger, C.I.W. 5M x 3-1/2" x 30" Dual 1 45.85' X -Over, 3-1/2" Butt. X 2-7/8" Butt. X 2', P x P 2 9,013' 2.441 2.875 X -Over, 2-7/8" Butt. Box x 2-7/8" 8rd. EUE Pin 3 9,013' 2.250 5.625 Kobe, 2-1/2"'Dbl B', Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8" N80, 8rd Pup x 30' 5 9,043' 2-7/8" Isolation x 2' 6 9,045' X -Over, 2-3/8" X 2-7/8" 8rd P X B 7 9,045' 1.56 4) 2-3/8" N-80 8rd Pups (33') w/ no-go 1.56" ID 8 9,078' 2) Firing Heads 9 9,082' Blank 10 9,085' 4.625 4-5/8" O.D. Vann TCP Guns (425') Short String A 45.85' X -Over, 3-1/2" TDS x 3-1/2" Butt. P x P B 6,457' 1.995 X -Over, 2-3/8" Butt x 3-1/2" TDS P x B C 9,011' X -Over, 1-1/4" 30 rd. Pin x 2-3/8" Buttress Box x 1.4' long Fish NO. Depth ITopl Length Item 1 9,754' 469' 11/19/99 - Cut off 425' TCP guns plus tubing, etc. above for total of 469'. Tubing cut @+/- 9,041' = 2' above isolation sub @ 9,043' up in the 10' pup joint. Last tag was 2/14/00 @ 9754' w/ 2" LIB. Zone C-5 C-5 C-6 C-7 C-7 C-7 C-7 C-7 C-7 C-7 C-7 C-8 Top (MD) 9,085' 9,170' 9,475' 9,585' 9,632' 9,653' 9,680' 9,713' 9,780' 9,816' 9,837' 10,071' Btm 9,140' 9,236' 9,510' 9,623' 9,640' 9,680' 9,698' 9,731' 9,803' 9,828' 9,875' 10,133' PERFORATION DETAILS Top Btm (TVD) (TVD) Amt SPF 8,557' 8,598' 55' 8,620' 8,668' 66' 8,848' 8,876' 35' 8,936' 8,967' 38' 12 8,974' 8,981' 8' 12 8,992' 9,014' 27' 12 9,014' 9,028' 18' 8 9,041' 9,0561 18' 8 9,096' 9,116' 23' 8 9,127' 9,137' 12' 8 9,144' 9,176' 38' 8 9,344' 9,398' fit' 8 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec, 2/14/2000 Phs. 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/5/1991 TCP Guns Updated by: JILL 07/17/2019 Bruce Platform PROPOSED Well # Br 20RD-42 MIAkako, LLC Completed: 5/16/93 API# 50-733-20443-01 RKB to TBG Head = 44.95' 1 A Patch 7-5,795'- ±S,955' -5,795'-25,955' WLM 13 MMMMM 3 V. 4 5 6 7 �B9 10 PBTD = 10,198' MD 9,457' TVD TD = 10,550' MD 9,768' TVD 512E WT CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 13-3/8" 54.5# J-55 Tubing Hanger, C.I.W. 5M x 3-1/2" x 10" Dual 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95 & N-80 3 8.755" Surface •6,974' 7" Liner 29, 32# N-80 & 5-95 9,043' 6.094" 6,513' 10,545' Tubing 7 9,045' 1.56 4) 2-3/8" N-80 8rd Pups (33') w/ no-go 1.56" ID 8 9,078' 2) Firing Heads Long String 9,082' Blank 30 9,085' 4.625 4-5/8" O.D. Vann TCP Guns ( 425') 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String C 9,011' X -Over, 1-1/4" 30 rd. Pin x 2-3/8" Buttress Box x 1.4' long 8,981' 8' 12 3-1/2" 9.2# N-80 Buttress 2.992' 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,457' 9,011' . Note for 9-5/8" Casing- 6,974' is top of window Date Comments 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" Powedet w/ Spec. 2/14/2000 Phs. 4/9/1991 TCP Guns 4/9/1991 TO Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/5/1991 TCP Guns Updated by: JLL07/19/2019 JEWELRY DETAIL NO. Depth ID OD Item Top 44.95' Tubing Hanger, C.I.W. 5M x 3-1/2" x 10" Dual 1 45.85' X -Over, 3-1/2' Butt. X 2-7/8" Butt. X 2', P x P 2 9,013' 2.441 2.875 X -Over, 2-7/8" Butt. Box x 2-7/8" 8rd. EUE Pin 3 9,013' 2.250 5.625 Kobe, 2-1/2"'Dbl B', Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8" N80, 8rd Pup x 30' 5 9,043' 2-7/8" Isolation x 2' 6 9,045' X -Over, 2-3/8" X 2-7/8" 8rd P X B 7 9,045' 1.56 4) 2-3/8" N-80 8rd Pups (33') w/ no-go 1.56" ID 8 9,078' 2) Firing Heads 9 9,082' Blank 30 9,085' 4.625 4-5/8" O.D. Vann TCP Guns ( 425') C-7 Short String A 45.85' X -Over, 3-1/2' TDS x 3-1/2" Butt. P x P B 6,457' 1.995 X -Over, 2-3/8" Butt x 3-1/2" TDS P x B C 9,011' X -Over, 1-1/4" 30 rd. Pin x 2-3/8" Buttress Box x 1.4' long 8,981' 8' 12 C-7 9,653' Fish NO. DepthITopl Len h Item I 9,754' 469' 11/19/99 -Cutoff 425'TCP guns plus tubing, etc. above for total 9,698' 9,014' of 469'. Tubing cut @ +/- 9,041' = 2' above isolation sub @ 18' 8 9,043' up in the 10' pup joint. Last tag was 2/14/00 @ 9754' w/ 9,713' 9,731' 2" LIB. Date Comments 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" Powedet w/ Spec. 2/14/2000 Phs. 4/9/1991 TCP Guns 4/9/1991 TO Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/5/1991 TCP Guns Updated by: JLL07/19/2019 PERFORATION DETAILS Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt SPF C-5 9,085' 9,140' 8,557' 8,598' 55' C-5 9,170' 9,236' 8,620' 8,668' 66' C-6 9,475' 9,510' 8,848' 8,876' 35' C-7 9,585' 9,623' 8,936' 8,967' 38' 12 C-7 9,632' 9,640' 8,974' 8,981' 8' 12 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 C-7 9,780' 9,803' 9,096' 9,116' 23' 8 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 C-8 10,071' 10,133' 9,344' 9,398' 62' 8 Date Comments 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" PowerJet w/ Spec. 2/14/2000 Phs. 2" Powedet w/ Spec. 2/14/2000 Phs. 4/9/1991 TCP Guns 4/9/1991 TO Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/9/1991 TCP Guns 4/5/1991 TCP Guns Updated by: JLL07/19/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2 EEGE ED JUL 2 2 9n,g 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Ch'rige:Approved Program ❑ Plug for Redrill Perforate New Pool ❑ ❑ Repair Well Re-enter Susp Well Other: Cha Jet Pumo & J ❑ ❑ Remove/Reinstalled Patch ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 191-020 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20443-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018742 Granite Pt St 18742 20RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field / Middle Kenai Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,754 feet Packer measured N/A feet true vertical 9,639 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation depth Measured depth 9,085 - 10,133 feet True Vertical depth 8,557 - 9,398 feet 2-7/8" 6.4# / N-80 9,013 (MD) 8,502 (TVD) Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / N-80 6,457 (MD) 6,310 (TVD) 2-3/8" 4.6# / N-80 9,011 (MD) 8,501 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 3 5 0 3437 73 Subsequent to operation: 11 7 2 3245 64 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby Certify that the foregoing Is true and Correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-260 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hiloorp.—COM Authorized Signature: t--) Date: 7 2 Z Contact Phone: (907) 283-1329 Form 10-004 Revised 4/2017 71, ?-�v -i"? RBDMSIUL 2 3 2019 AfAll9 Submit Original Only Bruce Platform SCHEMATIC Well # Br 20RD-42 Completed: 5/16/93 Hiles+P Al. -k.. LLC AN # 50-733-20443-01 RKB to TBG Head = 44.95' 1 77 A Patch 5,796' - 5,950' WLM 0 PBTD = 10,198' MD 9,457' TVD TO = 10,550' MD 9,768' TVD CASING AND TUBING DETAIL SIZE WT GRADE CONN ID 13-3/8" 54.5# 1-55 9-5/8" 40,43.5# 5-95 & N-80 7" Liner 29, 32# N-80 & S-95 Tubing 45.85' X -Over, 3-1/2" Butt. X 2-7/8" Butt. X 2', P x P Long String 9,013' 2.441 2.875 X -Over, 2-7/8" Butt. Box x 2-7/8" 8rd. EUE Pin 2-7/8" 6.4# N-80 Buttress Short String 9,032' 2.441 2.875 2-7/8" N80, 8rd Pup x 10' 3-1/2" 9.2# N-80 Buttress 2-3/8" 4.6# N-80 Buttress • Note for 9-5/8" Casing - 6,974' is top of window. TOP BTM. 12.615" Surface 1,584' 8.755" Surface *6,974' 6.094" 6,513' 10,545' 2.441" 47' 9,013' 2.992" 48' 6,457' 1.995" 6,458' 9,011' PERFORATION DETAILS Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8" TCP Guns C-5 9,170' 9,2361 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 2" PowerJet w/ Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2" PowerJet w/ Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Updated by: JU. 07/17/2019 JEWELRY DETAIL NO. Depth ID OD Item 44.95' Tubing Hanger, C.I.W. 5M x 3-1/2" x 10" Dual 1 45.85' X -Over, 3-1/2" Butt. X 2-7/8" Butt. X 2', P x P 2 9,013' 2.441 2.875 X -Over, 2-7/8" Butt. Box x 2-7/8" 8rd. EUE Pin 3 9,013' 2.250 5.625 Kobe, 2-1/2"'Dbl B', Cavity 5/N 93-5-5 4 9,032' 2.441 2.875 2-7/8" N80, 8rd Pup x 10' 5 9,043' 2-7/8" Isolation x 2' 6 9,045' X -Over, 2-3/8" X 2-7/8" 8rd P X B 7 9,045' 1.56 4) 2-3/8" N-80 8rd Pups (33') w/ no-go 1.56" ID 8 9,078' 2) Firing Heads 9 9,082' Blank 30 9,085' 4.625 4-5/8" O.D. Vann TCP Guns (425') Short String A 45.85' X -Over, 3-1/2" TDS x 3-1/2" Butt. P x P B 6,457' 1.995 X -Over, 2-3/8" Butt x 3-1/2" TDS P x B C 9,011' X -Over, 1-1/4" 10 rd. Pin x 2-3/8" Buttress Box x 1.4' long Fish NO. Depth ITOD) Length Item 1 9,754' 469' 11/19/99 -Cut off 425'TCP guns plus tubing, etc. above for total of 469'. Tubing cut @ +/- 9,041' = 2' above isolation sub @ 9,043' up in the 30' pup joint. Last tag was 2/14/00 @ 9754'w/ 2" LIB. PERFORATION DETAILS Top Btm Top Btm Zone (MD) (MD) (TVD) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8" TCP Guns C-5 9,170' 9,2361 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8" TCP Guns 2" PowerJet w/ Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 2" PowerJet w/ Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2" PowerJet w/ Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Updated by: JU. 07/17/2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date Granite Pt St 18742 20RD Slickline 50-733-20443-01 191-020 6/13/19 6/29/19 Daily Operations: 06/13/19 - Thursday ARRIVE PWL SHOP LOAD TOOLS HEAD TO OSK. ARRIVE BRUCE PLATFORM. JSA PERMIT, SPOT EQUIP. WORK ON POWER PACK RIG UP SLICKLINE. P/T LUB. TO 150OPSI GOOD TEST. RIH W/ 2 1/2" GS WORK ON COUNTER CONT. TO 5759' WLM 5789' KB. LATCH W/ TOOL POOH W/AA-STOP. RIH W/ SAME TO 5760'WLM 5790'KB. LATCH W/ TOOL POOH W/ UPPER PACKOFF W/ 22' SPACER PIPE. RIH W/ SAME TO 5785'WLM 5815'KB. LATCH W/ TOOL POOH W/ 20' SPACER PIPE. RIH W/ SAME TO 5807' WLM 5837' KB. LATCH W/ TOOL POOH W/ 20' SPACER PIPE. RIH W/ SAME TO 5827' WLM 5857' KB. LATCH W/ TOOL POOH W/ 20' SPACER PIPE. RIH W/ SAME TO 5850' WLM 5880' KB LATCH W/ TOOL POOH W/ 22' SPACER PIPE. LAY DOWN LUB. CLEAN AREA SECURE WELL FOR NIGHT. 06/14/19 - Friday MORNING MEETING JSA PERMIT. CUT WIRE RE-HEAD CHECK TOOLSTRING. RIH W/ 2 1/2" GS TO 5872' WLM 5902' KB. LATCH W/ TOOL POOH W/ 20' SPACER PIPE. RIH W/ SAME TO 5896' WLM 5924' KB. LATCH W/ TOOL POOH W/ 22' SPACER PIPE & PACKOFF. RIH W/ SAME TO 5918' WLM 5948' KB. LATCH W/ TOOL POOH W/ LOWER PACKOFF. RIH W/ SAME TO 5920' WLM 5950' KB. LATCH W/ TOOL POOH W/ AD-2 STOP. RIH W/ PUMP PULLING TOOL BAITED W/ 2 1/2" JDC TO 9017' WLM 9047' KB. LATCH W/ TOOL POOH. RIH W/ S.V. EQUALIZING PRONG TO 9033' WLM 9063' KB. W/ TOOL POOH - W/ STANDING VALVE (STUCK IN PRONG). RIH W/ 2" JDC W/ D&D HOLEFINDER TO 5760' WLM 5790' KB. SET TOOL STAND BY FOR P/T. GOOD TEST POOH. RIH W/ S.V. RUNNING TOOL W/ S.V. TO 3130' WLM TAG FLUID SHAKE OFF POOH. ASSIST PRODUCTION TO DROP JET PUMP. RIH W/ 2.25" BLIND BOX TO 9017' WLM 9047' KB. TAP JET PUMP IN PLACE POOH. RIH W/ 2 1/2" GS W/ AD-2 STOP TO 5920' WLM 5950' KB. W/ TOOL SET POOH. RIH W/ SAME W/ LOWER PACKOFF TO 5918' WLM 5948' KB. W/ TOOL SET POOH. RIH W/ SAME W/ 20' SPACER PIPE W/ PACKOFF TO 5897' WLM 5927' KB. W/ TOOL SET POOH. LAY DOWN LUB. SECURE WELL FOR NIGHT. 06/15/19 - Saturday MORNING MEETING JSA PERMIT. CUT WIRE RE-HEAD. RIH W/ 2 1/2" GS W/ 20' SPACER PIPE TO 5872' WLM 5902' KB. W/ TOOL SET POOH. RIH W/ SAME 22' SPACER PIPE TO 5850' WLM 5880' KB W/ TOOL SET POOH. RIH W/ SAME 23' SPACER PIPE TO 5827' WLM 5857' KB. W/ TOOL SET POOH. RIH W/ SAME 20' SPACER PIPE TO 5807' WLM 5837' KB W/ TOOL SET POOH. RIH W/ SAME 22' SPACER PIPE TO 5785' WLM 5815' KB W/ TOOL SET POOH. RIH W/ SAME W/ UPPER PACKOFF W/ 23' SPACER PIPE TO 5760' WLM 5790' KB W/ TOOL SET. POOH, RIH W/ SAME W/ AA-STOP TO 5759' WLM 5789' KB W/ TOOL SET POOH. RIG DOWN SLICKLINE CLEAN AREA STOW EQUIP. SECURE WELL FOR PRODUCTION. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 20RD Slickline 50-733-20443-01 1 191-020 6/13/19 6/29/19 Daily Operations: 06/27/19 - Thursday Arrive on platform. PJSM and permit. RU and PT to 1500 psi. O-rings above and below pump in sub fail, replaced. Re- PT to 1500 psi, test good. RIH w/ 2.34" gauge ring to 5797 KB. POOH. RIH w/ 2 1/2" GS to 5797', w/t, POOH w/ slip stop. FL found at 3395'. RIH w/ 2 1/2" GS to 5798', w/t, POOH w/ 25'6" top patch assembly and stand. RIH w/ 2 1/2" GS to 5820', w/t. POOH w/ 21' stand. RIH w/ 2 1/2" GS to 5841', w/t. POOH w/ 21' stand. RIH w/ 2 1/2" GS to 5861', w/t POOH w/ 21' stand. RIH w/ 2 1/1" GS to 5875 w/t, POOH w/ 22' stand. RIH w/ 2 1/2" GS to 5897'. w/t, POOH w/ 22' stand. RIH w/ 2 1/2" GS to 5917', w/t, POOH w/ bottom stand w/ seal assembly; length- 24'6". RIH w/ 2 1/2" GS to 5943' w/t, POOH w/ additional seal assembly; 16". RD and secure well for the night. 06/28/19 - Friday PJSM, Permit, JSA. Cut and wire, re-head, check tool string. RU to well. RIH w/ 2-1/2" GS to 5947' KB, latch and pull AD2 stop. Re-pin JUC w/ steel pin. RIH w/ Pump pulling tool, baited w/ 2 1/2" JUC to 9045' KB. Work tool POOH w/ pump. Asst. Operations w/ pump and removal of riser from tree. Stand by for flush, continue re-building of pack-offs and spacers. RIH w/ 2.4" blind box to 9045'. Tap pump in place several times. POOH. RIH w/ 2-1/2" GS w/ AD2 stop to 5950' KB. Work tool and set AD2 stop. POOH. RIH w/ same to 5948', set lower seal assembly, POOH. RIH w/ same to 5943', set second lower seal assembly w/ 24' spacer. POOH. RIH w/ same to 5921', set 22' spacer, POOH. OOH. Lay lubricator down for the night, secure well, clean area. 06/29/19 - Saturday PJSM, Permit, ISA. Cut and wire, re-head, check tool string. RU to well. RIH w/ 2-1/2" GS and spacer to 5930' KB,work tool, set spacer. POOH,RIH w/ same, w/ 20' spacer to 5880'. Work tool, set spacer. POOH. RIH w/ same w/ 21' spacer to 5855'. Work tool, set spacer. POOH. RIH w/ same w/ 21' spacer to 5834'. Work tool, set spacer. POOH,RIH w/ same w/ upper packoff on 26' spacer to 5816'. Work tool, set spacer and packoff. POOH. RIH w/ same w/ AA stop to 5796'. Work tool. POOH. OOH. Begin RD • • dli,l'',I j7,_7• THE STATE Alaska Oil and Gas 41s-d��- 1:k of/\ T I /� Conservation Commission A SF 'i 333 West Seventh Avenue " `�_ C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 WJE----'or':‘," Main: 907.279.1433 OFA S Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager �' Hilcorp Alaska, LLC SCANNED 3 800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Granite Point Field,Middle Kenai Oil Pool, GPS 18742 2ORD Permit to Drill Number: 191-020 Sundry Number: 317-229 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, fi9P-e—r.44._ Cathy . Foerster Chair DA FED this_day of June,2017. • RBDMS V 'J6(4 - 7 2017 0 • RECEIVED STATE OF ALASKA JUN 0 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 077 G /ell /7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 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 LI Perforate New Pool ❑ Re-enter Susp Well LI Casing E3 Other Chg Pump& Remove/Reinstall Patch 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development 0 • 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.If perforating: '8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0/ Granite Pt St 18742 2ORD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 • Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,550 - 9,768 , 9,754 • ' 9,639 1,102 psi 10,198 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,085-10,133 • 8,557-9,398 2-7/8" 6.4#/N-80 9,013 3-1/2" 9.2#/N-80 6,457 2-3/8" 4.6#/N-80 9,011 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/25/2017 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com /// .,I , Contact Phone:5907)283-1329 Authorized Signature: 1-1 Q`�-� Date: Cor 20t 11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number _ 3r7 - 22i Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Noe Subsequent Form Required: / 0 "'Y©1-1 RBDMS i,L Jbi' - 7 2017 APPROVED BY Approved by: iii "9"...44,014--• COMMISSIONER THE COMMISSION Date: - _t/ ? c (Q./fl- a 'c . 7 -/ 7 7 0 RIF /� Submit Form and Form 10-403 Revised 4/2017 �V�1 I�ti n is valid for 12 months from the date of approval. Attachments in Duplicate •• • Well Prognosis Well: Granite Pt St 18742 2ORD Date:05/30/2017 Hilcorp Alaska,LU Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 North Corner Estimated Start Date: 06/25/2017 Rig: N/A Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) Second Call Engineer: Stan Golis (907) 777-8356(0) Current Bottom Hole Pressure: 2,000 psi @ 8,977 ft TVD 0.223 lbs/ft(4.28 ppg)Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: 2,000 psi @ 8,977 ft TVD 0.223 lbs/ft(4.28 ppg)Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface Pressure(MPSP): 1,102 psi / Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump. I Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 2. Pull patch at 5,741'-5,884'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. w� 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,740'to+1-5,885' (WLM). 8. Attempt to pressure test patch against standing valve to 1,000psi. (well is a packerless completion so small tubing leak will only impact the jet pump performance and not imp'a Well safety) c h14 C 9. Rig down slick line and lubricator. 10. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic • H0 SCHEMATIC • Bruce Platform Well # Br 20RD-42 Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' I *Note for 9-5/8"Casing-6,974'is top of window. L L Patch 5,741- JEWELRY DETAIL 5,884' NO. Depth ID OD Item WLM 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual € 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P i 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"`Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank X 10 9,085' 4.625 4-5/8"0.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P L i ;' , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Topl Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns IMF lilll C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns I=IISII■ 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4Mg 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 w 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. �••: 'S N 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns SIR ,it C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 M C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns * 8 0 * C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns il` * C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns * , 9 + iO * PBTD=10,198'MD 9,457'ND Updated by: JLL 05/30/17 TD= 10,550'MD 9,768'ND 14 • PROPOSED 0 Bruce Platform + Well # Br 20RD-42 Completed: 5/16/93 Hilcora Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' I Tubing fl Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 13-1/2" 9.28 N-80 Buttress 2.992" 48' 6,457 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Patch 1 ±5,740' S JEWELRY DETAIL ±5,885' NO. Depth ID OD Item WLM 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') XIX Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 c Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns MI MORIN C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns Jam'_III 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 --110---. 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. * 2"PowerJet w/Spec. 4 0 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. -" 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns + 6 w 0Illt {M' C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns * 8 -- 0 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns 11 C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns '0 0 9 0 0 10 yr ,� w< PBTD= 10,198'MD 9,457'ND Updated by: JLL 05/30/17 TD=10,550'MD 9,768'TVD STATE OF ALASKA ALL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet❑ Other: Chg Pump& ❑ Remove/Reinstalled Patch 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development [] Exploratory 0 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: EC E I V E ADL0018742 Granite Pt St 18742 2ORD D 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool MAY 31 2017 11.Present Well Condition Summary: CC Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,754 feet Packer measured N/A feet true vertical 9,639 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation depth Measured depth 9,085-10,133 feet True Vertical depth 8,557-9,398 feet 2-7/8"LS 6.4#/N-80 9,013'(MD) 8,502'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2"SS 9.2#/N-80 6,457'(MD) 6,310'(TVD) 2-3/8"SS 4.6#/N-80 9,011'(MD) 8,501'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED _!JN\;, 0 5 2017 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 91 11 14 107 71 Subsequent to operation: 66 7 12 122 72 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [] Exploratory ❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil [] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 316-524 Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: OperationslManager Contact Email: dmarlowetathilcorp.com OpL Authorized Signature: EDDate: 5/1,011,7 Contact Phone: (907)283-1329 Form 10-404 Revised 4/201771``6 -/--/ RBDMS 1/c-/ _ 2017 Submit Original Only ,®6147 0 SCHEMATIC • Bruce Platform . 11Well # Br 20RD-42 Completed: 5/16/93 LLilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' ` Tubing Long String .. 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L J Patch 5,741- JEWELRY DETAIL 5,884' NO. Depth ID OD Item WLM 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual ' 1 ' 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin f 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 ' 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"x2-7/8•• 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads 1111 B 9 9,082' Blank ` ' 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') }. X Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 at mit C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8598' 55' 5/16/1993 4-5/8"TCP Guns tau. C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns IMF MINNIE 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 _--,------s. 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 9,-7: 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • ' 6 C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns * 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns * 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns • 9 I. it 10 PBTD= 10,198'MD 9,457'TVD Updated by: 1LL05/30/17 TD=10,550'MD 9,768'ND • • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD Slickline 50-733-20443-01 191-020 4/18/17 5/14/17 Daily Operations: m` 04/18/2017-Tuesday 6:00arrive at osk 6:30fly to bruce platform 7:00arrive at bruce platform 7:20start job paperwork 8:00rig up s/I 9:30stab on well and p/t to 1500 psi 10:00RIH W PRGS to WLM pull AA stop at 5749wlm 11:30RBIH pull top pack-off and patch 5750 wlm 12:001et element relax and take Iunch,12:30POOH 13:30RBIH pull patch 5775 wlm 14:20RBIH pull patch 5793wlm 14:50RBIH pull patch 5815w1m 15:30RBIH pull patch 5836w1m 16:30RBIH pull patch and bottom pack-off 5859wlm,17:15RBIH pull 2nd pack-off 5858w1m 17:40RBIH pull AD2 stop 5859w1m 18:00RIH W 1 3/8 JDC pull pump at 8984 wlm sheered pooh 19:20RBIH pull pump 20:301ay down for night 20:40redress pack-offs and stops and clean work area • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#20RD Slickline 50-733-20443-01 191-020 4/18/17 5/14/17 Daily Operations: 04/19/2017-Wednesday 6:00 morning meeting. 6:30 morning paperwork jsa,hot work,and permit to work. 7:00 preform equiptment maintenance while production rebuilds pump. 8:00 rih to 8984wlm set pump. 9:10 rih to 5859w1m set ad2 stop. 10:30 rih to 5858wlm set pack-off. 11:10 rih to 5836wlm set pack-off with bottom patch. 11:40 rih to 5815wlm set patch and break for lunch. 12:40 rih to 5793wlm set patch. 13:25 rih to 5775wlm set patch. 14:00 rih to 5750wlm set patch and top pack-off. 14:40 rih to 5749wlm set aa stop. 15:20 lay down and turn over to production to test. 16:30 Operations bundle tested to 1000#, pressure bleeding off slightly. 18:00 Operations attempted to seat and pressure up jet pump. 18:30 Pump would not hold pressure above 600#. 19:00 Slickline rigging up to pull top stop and packoff. 22:00 Shutdown for the night. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD Slickline 50-733-20443-01 191-020 4/18/17 5/14/17 Daily Operations: 04/20/2017-Thursday 6:00 morning meeting and paperwork. 6:45 rih pull patch at 5793wlm. 7:30 rbih pull patch at 5815wlm. 8:00 rbih pull patch and packoff at 5836w1m. let rest for 15 mins. Pooh. 9:10 rbih pull bottom packoff at 5858wlm. 10:15 rih w jdc pull pump at 8984w1m. 11:00 rih w kobe knockout tool to 9001wlm. 12:00 ooh break for lunch. 12:50 rih w standing valve pulling tool to 9001wlm. 13:30 rih shake new standing valve off in fluid at 3750w1m. 14:35 rih w standing valve setting tool to 9001wlm. 15:50 rih w jdc sett pump at 8984w1m. 17:00 rih w prgs set ad2 stop at 5745w1m. Ooh break for dinner. 18:20 rbih set bottom packoff at 5842w1m. 19:00 rbih set bottom packoff and patch at 5822w1m. 19:35 rbih set patch at 5796w1m. 20:00 rbih set patch at 5778w1m. 20:50 rbih set patch at 5756w1m. 21:20 rbih set patch and top packoff at 5731w1m. 22:00 rbih set aa stop at 5730wlm. 22:50 ooh lay down for night secure well and clean work area turm over to production. 04/27/2017-Thursday Arrive at Bruce platform. Start on jsa, permit to work, and hot work permit. Review jsa with all involved. Rig up slickline lubricator and tools. Zero tool string at tubing hanger and stab on well and pt to 1500 psi. RIH W 2 7/8 GS pull AA stop @ 5751 wlm. RBIH pull top pack off and patch at 5752 wlm. Pulled up 10' stop and let element relax. Pooh with pack- off and patch. OOH stand-by for crane operator. RBIH pull patch at 5776 wlm. RBIH pull patch at 5794 wlm. RBIH pull patch at 5816 wlm. RBIH pull bottom pack-off and patch at 5838 wlm. Pulled patch stand-by let element rest. Pooh with pack-off and patch. RBIH pull bottom pack-off at 5858w1m. Stop let element rest. Pooh with pack-off. RBIH pull AD2 stop at 5860w1m. Rih W 1-3/8 JDC to 8984w1m pull pump. OOH pull pump off tool string and lay on deck for production stab back on well and leave hanging for night. Finish daily paperwork and send off reports. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#20RD Slickline 50-733-20443-01 191-020 4/18/17 5/14/17 Daily Operations: 04/28/2017- Friday Morning meeting. Fill out JSA, permit to work, hot work permit. Stand by for production to finish pump. Rih w 1-3/8 JDC to 8984w1m set pump. Rih w 2.313 prgs w AD2 stop to 5864w1m. Pooh tool wouldn't release from AD2 stop. Ooh change tool to 2.313 GS. Rih w 2.313 gs w AD2 stop to 5864w1m and fuel power pack while running in hole. RBIH w bottom pack off to 5863w1m. RBIH w bottom pack off and patch to 5840w1m. RBIH w 20' patch set at 5815w1m. RBIH w 20' patch set at 5794wlm. RIH w 2.313 gs w AD2 stop to 5864w1m and fuel power pack while running in hole. RBIH w bottom pack off to 5863w1m. RBIH w bottom pack off and patch to 5840w1m. RBIH w 20' patch set at 5815w1m. RBIH w 20' patch set at 5794w1m. RBIH pull aa stop at 5739wlm. RBIH beat down 10 times on top pack off. RBIH set AA stop at 5739. Oooh, turn over well to production. Rig down wireline. 05/11/2017-Thursday Arrive at heliport. Fly to Bruce platform. Arrive at Bruce platform. Begin job log,JSA, Hot work permit, and permit to work. Sit down for a prejob safety meeting and talk about Rig up Lubricator,Tool string, equipment, and redress stuffing box. Stand-by for chopper with crane operator. Stab on lubricator and P/T to 1500psi, PASSED. Stand-by for chopper with crane operator. Chopper landed with crane operator, have lunch/Safety meeting with everyone involved to discuss wireline operations. Pop off lubricator attach tools and zero tool string and stab back on. RIH W 2" RB and 2 7/8 D&D hole finder to 5740w1m. POOH hanging up in the tree, check tools hole finder sheared pin. Repin tool and stab back on. RBIH to 5740w1m verify top AA stop, shear pin, pull up to 5700w1m set D&D hole finder stand by for production to finish unloading boat. Fill well and P/T well pumped up to 1000 psi hold for 10 mins w/only 20 lbs. loss, hold. Pump back up to 1000 psi held for 1 hr. call Operations Engineer for next move. Bleed down well to pull out of hole. Pulled up to 5570 wlm tool sheared pooh and re pin. OOH re-pin SB rbih. RBIH to 5570 wlm latch D&D hole finder try to get free started moving but sticky. Came free @ 5200 wlm POOH at a good rate. OOH W D&D but no element. RIH W wire brush to 5740 wlm try to find element. POOH. OOH no element.Talk w/operator and decide to put on a wire scratcher. RIH w wire scratcher 5740 wlm. Sat down on AA stop tap down and pull out of hole. OOH w/o element. Talk w/operator decide to lay down for night and make phone call in morning. Secure well for night and clean work site. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD Slickline 50-733-20443-01 191-020 4/18/17 5/14/17 Daily Operations: 05/12/2017- Friday Attend morning safety meeting. Start JSA, hot work permit, and permit to work and discuss operations. Add 20' lubricator to pull patches. RIH w 2.313 GS to 5740 wlm to pull AA stop. POOH w AA stop. OOH w AA stop found most of the element in the neck of AA stop.Talk w/operations on next move to make, decide to pull rest of the patch. Pump and stand in valve. RBIH to 5741 wlm to pull top pack-off and patch pipe. Pulled patch let element rest for 30 mins. Pull patch out of hole. OOH with packoff and patch. Stand by for crane operator assisting production. Rbih pull 10' patch at 5764 wlm. OOH with patch. Stand by for crane operator who's assisting production. Stabbed back on Break for lunch. RBIH pull patch at 5773 wlm. OOH. RBIH pull patch at 5795 wlm. POOH with patch. RBIH pull patch. Pulled patch let element rest for 30 mins. POOH. OOH w bottom pack off and patch pipe. RBIH pull pack off at 5860 wlm. Pulled pack off let element rest for 30 mins. POOH. RBIH pull AD2 stop at 5863 wlm. POOH. OOH w AD2 stop. Stab back on and break for dinner. RIH w 1 3/8 JDC to 8984 wlm pull pump. Pulled pump at 8984 wlm. OOH. RIH w Kobe knock out tool to 9002 wlm. POOH. OOH, RIH w standing valve pulling tool to 9002 wlm. POOH. OOH. RIH w standing valve to fluid and shake it off. Fluid level at 4120 wlm. RIH w standing valve tap tool to 9002 wlm tap valve in place. POOH. OOH lay down for night. Secure well site and clean work area. Finish job log and send off reports. 05/13/2017-Saturday Morning safety meeting discuss yesterdays progress and todays tasks. Begin filling out JSA, hot work permit, and permit to work. Stand by for chopper with plug bottom. Chopper w parts arrived. RIH w GS w AD2 stop to 8940 wlm. POOH. OOH. RIH w GS w D&D plug to 8939 wlm. Couldn't sheer off plug POOH and change out tools. POOH. OOH. RIH w PRGS w D&D plug to 8939 wlm got set but had to work down hole from 8000wlm-8939 wlm. OOH. RBIH w AA stop to 8937 wlm. Set AA stop. POOH. OOH. Turn over to production to bundle test the short string, stand by. Still standing by for production. Discuss with operations moving forward, decided to pull plug assembly out of well. RIH w PRGS to pull AA stop 8938 wlm. POOH w AA stop at 8938 wlm. OOH w AA stop. RBIH plug at 8939 wlm. POOH w plug. OOH sheered PRGS. RBIH pull plug at 8939 wlm. POOH. OOH w plug. RBIH pull AD2 stop at 8940 wlm. POOH. OOH w AD2 stop. Lay down for night. Secure well site and clean work area. Finish job log and send off reports. 05/14/2017 -Sunday Attend morning safety meeting. Begin filling out JSA, hot work permit, and permit to work. Rig up to well. RIH w 13/8 JDC and pump run down to 8984 wlm. POOH. OOH pump set. RIH w GS and AD2 stop sheer pin at 5900 wlm and sheered GS. POOH. OOH stand by for chopper w extra pipe and tools onboard. Unstab and repin GS. RBIH to 5900 wlm pull AD2 stop up to 5884 wlm, POOH. OOH. RBIH w bottom pack-off to 5883 wlm. POOH. OOH. RBIH w pack-off and 20' patch to 5863 wlm. POOH. OOH. RBIH w 23' patch set at 5840 wlm. POOH. OOH. RBIH w 20' patch to 5820 wlm. POOH set patch. OOH, RBIH w 20' patch to 5800 wlm. POOH. Clamp wireline and fix drum. OOH. RBIH w 20' patch to 5778 wlm. POOH. OOH. RBIH w 20' patch and top pack-off to 5743 wlm. POOH, RBIH w AA stop to 5741 wlm POOH. OOH lay down secure well site.Turn over to production for bundle testing. Finish job paperwork. Stand-by for production. ��o.r �.o J.,� = p w ( 17/-oz�, SCHEMATIC Bruce Platform II Well#Br 2ORD-42 7// Completed: 5/16/93 HiloorP Aiaelce,LLC . -----7. -----7 �/�/// CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' IMP9-5/8" 40,43.5# S-95&N-80 8.755" Surface "6,974' 1 A ? 7"Liner 29,32# N-80&S-95 6.094" 6,51.3' 10,545' - .�y • 4. 1 Tubing s. Long String !1.t. 2-7/8" 6.44 N-80 Buttress 2.441" 47' 9,013' is_ Short String 3-1/2" 9.24 N-80 Buttress 2.992" 48' 6,457' .,, ,, 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. A I. Patch 5,749'- JEWELRY DETAIL 5,859' NO. h jQ OD I "_." WLM 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 1 3 9,013' 2.250 5.625 Kobe,21/2"'Obl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-SO 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') 17: I Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 ` 7 p o 6,457' 1.355 X-Over,2-3/8"Butt x 3-1/2"T05 P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long STIP--.F«- �{s -' ,. , Fish g ( .) c', :' Dearth(Top) Length Nem 1 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 5-'7'17 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LB. PERFORATION DETAILS Top Btm Top Btm 2 Zone (MD) (MD) (WD) (TVD) Amt SPF Date Comments �e� l arts C C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns ")r l p+.,P van�g i r• C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/B"TOP Guns 13 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TOP Guns 41/ ,=Ill III 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 2"Powerlet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. s2"PowerJet w/Spec. 4 40, C-7 9,653' 9,680Y 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 • C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns * C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns M L+ R 6 ,e C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns IOC 7 • C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns t 8 411119 * C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns • C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns * 9 • ri 0 w 10 40 Z114. ,li' ` '.. •. '';'"',N SCONED JUN 4 2 2017 PBTD=10,198'MD 9,457'TVD Updated by: ALL 10/05/16 TO=10,550'MD 9,768'TVD • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent Friday,January 27,2017 1:53 PM To: 'Juanita Lovett' Cc Dan Marlowe;samantha.carlisle@alaska.gov Subject RE:Withdraw Sundry#316-063/PTD:191-020-Granite Pt St 18742 2ORD Juanita, The AOGCC will withdraw sundry 316-063 for well GPS 18742 2ORD as requested. Guy Schwartz Sr. Petroleum Engineer SCANNED JUN ) 52017 AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From:Juanita Lovett[mailto:jlovett@hilcorp.com] Sent:Friday,January 27,2017 10:06 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-063/PTD:191-020-Granite Pt St 18742 2ORD Guy, Please withdraw the above mentioned sundry. The project will not be completed at this tire. Scope of work was to install tubing patch in the short string. Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: ilovett@hilcorp.com 1 RBDMS L'- F'...'3 1 4 2017 yoF ry • • ,(;)��\W7,;* THE STATE Alaska Gil and Gas ������, of Conservation Commission ,'W, _ = r ALAS<:A kiis _- r#=_ = 333 West Seventh Avenue art 11_ Anchorage, Alaska 99501-3572 .�� ., GOVERNOR BILL WALKER 9 Main: 907.279.1433 F 41.A4If Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Scp�NE�1 FEB `? Z01 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, GPS 18742 2ORD Permit to Drill Number: 191-020 Sundry Number: 316-524 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 3-11-j4 Cathy P. Foerster Chair DATED this / day of October, 2016. RBDMS L`—OCT 1 4 2016 • • RECEIVED • STATE OF ALASKA OCT 12 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION Dn / '( i ,/ APPLICATION FOR SUNDRY APPROVALSA GCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ 3 (Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑Other.Cho Pump/Remove-Reinstall Patch 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 191-020 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes 0 No 0 1 Granite Pt St 18742 2ORD b 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Pt Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): • 10,550 • 9,768 , 9,754 , 9,639 -1100 psi 10,198 9,754 Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,085-10,133 • 8,557-9,398 LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapt0 Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/25/2016 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature W Phone (907)777-8356 Date ID III 12011. COMMISSION USE ONLY Conditions of approval: Notify Commi ion so that a representative may witness Sundry Number: 3k(.Q - 6.2 -( Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ j OCTSpacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0+v/ 0 LI RBDMS L� C 1 4 2016 APPROVED BY Approved by: io)12.64,761,....._ COMMISSIONER THE COMMISSION JDate:fa� / /,G 7911196 ID lc cry,6f, fd//l4 r0'',rt/L Submit Form and Form 10-403 Revised 11/20150 Rpf.samtiAsEid i6for 12 onths from the date of approval. Attachments in Duplicate s e Well Prognosis Well: Br 2ORD-42 ffilcorp Alaska,LL Date: 10/05/16 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 10/25/16 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356(0) Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface Pressure -- 1,100 psi 2,000psi-(0.1 "TVD) (MPSP): Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump. 1 Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 2. Pull patch at 5,749'-5,859'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,745'to+/-5,860' (WLM). 8. Pressure test patch against standing valve to 1,000psi. V' r 9. Rig down slick line and lubricator. 10. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 0SCHEMATIC • Bruce Platform Well # Br 20RD-42 Completed: 5/16/93 Hilcora Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# 1-55 12.615" Surface 1,584' I 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 L A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Patch 5,749'- JEWELRY DETAIL 5,859' 1 NO. Depth ID OD Item WLM -"' 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 ji 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' t 5 9,043' 2-7/8"Isolation x 2' 1 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X 10 9,085' 4.625 4-5/8"0.0.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Topl Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments MIER C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns IM C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns =M1■ 2"PowerJet w/Spec. illl C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 -__ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. Jr.7 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns iir 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 408 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns lit C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns Qr 9 10 PBTD= 10,198'MD 9,457'TVD Updated by: JLL 10/05/16 TD=10,550'MD 9,768'TVD • PROPOSED • Bruce Platform ‘ 14Well # Br 20RD-42 Completed: 5/16/93 Hilcora Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# 1-55 12.615" Surface 1,584' 1 \ / 9-5/8" 40,43.S# S-95&N-80 8.755" Surface *6,974' ! A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing l Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Patch ±5,745 i" JEWELRY DETAIL ±5,860 NO. Depth ID OD Item `"nn M "' ' f 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin -' ..' 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads \ / B 9 9,082' Blank X X\ 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. , . B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments 111111111 C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns MIO C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 IMMI C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns MI■ 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 ___ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. t'"- 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns M 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns 0 ,s, 10 A , .. ' : "..., i"IN PBTD= 10,198' MD 9,457'TVD Updated by: ILL 10/05/16 TD= 10,550'MD 9,768'TVD STATE OF ALASKA • AIL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: Chg Pump& C.-1Remove/Reinstalled Patch 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development LI Exploratory❑ 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: ,. ADL0018742 Granite Pt St 18742 20RD C OVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): U L. I 1 1 2016 N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: /""r,GG Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,754 feet Packer measured N/A feet true vertical 9,639 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation depth Measured depth 9,085-10,133 feet True Vertical depth 8,557-9,398 feet ......-- 2-7/8" .2-7/8"LS 6.4#/N-80 9,013'(MD) 8,502'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2"SS 9.2#/N-80 6,457'(MD) 6,310'(ND) 2-3/8"SS 4.6#/N-80 9,011'(MD) 8,501'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: SWAB) FEB 32,01Z Intervals treated(measured): l�R��1l�® k L! N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 63 22 10 78 70 Subsequent to operation: 108 19 16 117 67 14.Attachments(required per 20 AAC 25.070,25.071,&25283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG El GINJ❑ SUSP❑ SPLUG❑ 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: 316-163 Contact Dan Marlowe(907)283-1329 Email dmarloweCa�hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature L3 (7 re4 Phone (907)777-8356 Date %b I 1 1 'Z.O I G j0,1 it r0734 RBDMS L L OCT 1 1 2016 Form 10-404 Revised 5/2015 Submit Original Only • • Bruce Platform SCHEMATIC Well# Br 20RD-42 • II Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ / 1 9-5/8" 40,43.5# 5-95&N-80 8.755" Surface *6,974' / A 7"Liner 29,32# N-80&5-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. 4 Patch 5,749'- JEWELRY DETAIL 5,859' NO. Depth ID OD Item WLM --- 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank V X X-r 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments -- C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns inn SMS C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns MINIM 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 AP-- 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns • 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns • 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns 40 ,,,, 10 ri „ter r PBTD= 10,198'MD 9,457'ND Updated by: JLL 10/05/16 TD=10,550'MD 9,768'ND • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD _ Slickline 50-733-20443-01 191-020 9/21/16 9/27/16 Daily Operations: 09/21/16-Wednesday Fly to Bruce platform. Arrive at Bruce platform sign in and talk with lead. Start jsa, hot work and ticket. Rig Up slickline respot equipment. Pick up lubricator m/u 2.30 gauge ring. Stab on well P/T to 1000psi test good. RIH w/2.30 gauge ring down to 5749 wlm POOH. OOH. RIH w/2 1/2 GS latch and pull AA stop @ 5749w1m POOH. RBIH latch top packoff and 25' spacer pipe @ 5750w1m POOH. RBIH latch 20' spacer pipe @ 5775w1m POOH. RBIH latch 18' spacer pipe @ 5793w1m POOH. RBIH latch 22' spacer pipe @ 5815w1m POOH. RBIH latch 21' bottom packoff and spacer pipe @ 5836w1m POOH. RBIH latch bottom single packoff @ 5858 wlm POOH. RBIH latch AD2 stop @ 5859 wlm POOH. RIH w 1 3/8 jdc latch and pull pump. RIH w/ KOBE punch tool. RIH w/standing valve pulling tool. OOH with S/V lay down lubricator clean up tools SDFN. 09/22/16-Thursday Attend morning meeting. Redress packoffs and pump. RIH W standing valve and shake off in fluid. RIH W standing valve tap in tool. RIH W pump. RIH W AD2 stop set @ 5859 WLM. RIH W pack off set @ 5858 WLM. RIH W pack off and space pipe set @ 5836 WLM. RIH W spacer pipe set @ 5815 WLM. RIH W spacer pipe set @ 5793 WLM. RIH W spacer pipe set @ 5775 WLM. RIH W spacer pipe and top pack off set @ 5750 WLM. RIH W AA stop set @ 5749 WLM. Out of hole lay down and turn over to production for test. Clean tools and work area. 09/27/16-Tuesday Shut-in and used power oil to come up to 1000#on both strings, BOL. • of T8 I////, THE STATE Alaska Oil and Gas pf jL jSlA. Conservation Commission ftri}E2_^_ =_ 333 West Seventh Avenue a ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \r Main: 907.279.1433 ° ALAS*� Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager SCAMP " "r s, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Pt Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Permit to Drill Number: 191-020 Sundry Number: 316-163 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /./;et ",..747)234.., Cathy P oerster � � Chair DATED this`ice-day of March, 2016. RBDMS L-1- MAR 0 4 2016 . • +.Q RECEIVED • STATE OF ALASKA . FEB 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑Other:Chq Pump/Remove-Reinstall Patch 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development 0. 191-020 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Pt St 18742 2ORD • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 Granite Pt Field/Middle Kenai Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,550 - 9,768 - 9,688 9,018 –1100 psi 10.198 - 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,518' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapt0 Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/15/2016 Commencing Operations: OIL 0, WIND ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ Cl Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett@hilcorp.com Printed Name Stan W.GolisTitle Operations Manager Signature •--- £r0+;• Phone (907)777-8356 Date 242.1 I I to COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0—IOL-1 RBDMS LL MAR 0 4 2015 APPROVED BY Approved by: ‘Y,(.7COMMISSIONER THE COMMISSION Date: 3 - _/6 e,._ g-2--a, -1'('a 3PZ)1C- Ati 1 ,6 1 R GittNiAiLar Submn Form ane Form 10-403 Revised 11/2015 �Vpi al 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: Br 2ORD-42 Hi!coil)Alaska.LL Date:02/24/2016 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 03/15/16 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Trudi Hallett (907) 777-8323(0) (907)301-6657(M) Second Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904(M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: -.2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface Pressure — 1,100 psi 2,000psi-(0.1 *TVD) (MPSP): Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump. Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 2. Pull patch at 5,749'-5,859'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,750'to+1-5,860' (WLM). 8. Pressure test patch against standing valve. `— -••- c< . • — 9. Rig down slick line and lubricator. 10. Operations to bundle test system. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic . 0 Bruce Platform SCHEMATIC Well # Br 20RD-42 . li Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.58 J-55 12.615" Surface 1,584' 1 / 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' / A7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' ' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' ?t 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. I Patch 5,749'- JEWELRY DETAIL 5,859' NO. Depth ID OD Item WLM \\N\ -. ,- I 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual \\+_ 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .. .. 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank X 10 9,085' 4.625 4-5/8"0.0.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Topa Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C / Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns iMIMI I;I. C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns ti ■I• 2"PowerJet w/Spec. Allifilit C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 . 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. ir"- 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 ti4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 \4/9/1991 TCP Guns • ] C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 0 $ C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns * 9 w 0 10 �, ' ,f1 PBTD=10,198'MD 9,457'TVD Updated by: JLL 02/12/16 TD= 10,550' MD 9,768'ND • • Bruce Platform PROPOSED Well # Br 20RD-42 . 14 Completed: 5/16/93 Ililcorp Alaska.LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 / 9-5/8" 40,43.58 S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.48 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.28 N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.68 N-SO Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. 4 Patch N ±5,744 JEWELRY DETAIL ±5,855 NO. Depth ID OD Item WLM ' - 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual rv, 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin -, ' 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X /�(y'` . 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns il=l111111M C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns NMa1■ 2"Poweriet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 -__= 2"Poweriet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. .,.\-- C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns • PBTD=10,198'MD 9,457'TVD Updated by: JLL 02/24/16 TD= 10,550' MD 9,768'TVD STATE OF ALASKA • IRSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ElRe-enterSusp Well❑ Other: Chg Pump& El Patch 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development CI Exploratory❑ 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 2ORD RECEIqt ED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool �� 2016 11.Present Well Condition Summary: Total Depth measured 10,550 feet Plugs measured 10,198 feet ; ICj true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,754 feet Packer measured N/A feet true vertical 9,639 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation depth Measured depth See Schemaitc feet True Vertical depth See Schematic feet 2-7/8"LS 6.4#/N-80 9,013'(MD) 8,502'(ND) Tubing(size,grade,measured and true vertical depth) 3-1/2"SS 9.2#/N-80 6,457'(MD) 6,310'(ND) 2-3/8"SS 4.6#/N-80 9,011'(MD) 8,501'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): ��yy(� N/A SCANNED t f, "d Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 55 43 20 64 61 Subsequent to operation: 72 15 12 120 66 14.Attachments(required per 20 AAC 25 070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [] Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil [] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP El SPLUG❑ 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: 316-003 Contact Trudi Hallett(907)777-8323 Email thallettna.hilcoro.com Printed Name Stan W.Golis Title Operations Manager Signature L-3 teb Phone (907)777-8356 Date Z./I5 / ((e Form 10-404 Revised 5/2015 RBDMS Lt— FEB 8 2016 Submit Original Only • • SCHEMATIC Bruce Platform . 11Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ J 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' / A7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing ii ) Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. , L Patch t 5,749'- JEWELRY DETAIL 5,859' WLM NO. Depth ID OD Item --, 44.95' Tubing Hanger,C.I.W. SM x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .. .. 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID \\ 8 9,078' 2)Firing Heads / B 9 9,082' Blank X X r 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. r B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long / Fish e NO. Depth(Top' Length Item /., I I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments NIL C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns I I I■ C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns P■ 2"PowerJet w/Spec. g. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 -__ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"Poweriet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. .!:'"" 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 4* 6 8C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns 8C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns INV 7 r4C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 'Mr 8 ��, C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns �: C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns 9 10 lit § *,. • . ,, .1 N, PBTD= 10,198'MD 9,457'TVD Updated by: JLL 02/12/16 TD=10,550'MD 9,768'TVD • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date • Granite Pt St 18742#20RD Slickline 50-733-20443-01 191-020 1/14/16 2/4/16 Daily Operations: 01/14/16-Thursday Fly out to location.Arrive on location. Fill out JSA and work permit. Spot equipment on deck. Start rigging up equipment. P/T lubricator to 1500 psi. RIH w/GS pulling tool, latch top stop, POOH. OOH. RBIH pull top packoff and spacer pipe. OOH. Redress packoff and build spacer pipe. RIH w/ 10ft of spacer pipe set @ 5,769' wlm. POOH. OOH. RIH set top packoff and 20ft of spacer pipe @ 5,745' wlm. POOH. OOH. RIH set AA stop @ 5,744' wlm. POOH. OOH. R/D equipment. 01/27/16-Wednesday Arrive on platform. Start JSA and work permit. Start rigging up and spotting equipment. P/T lub to 750psi test good. RIH w/2.75 gauge ring down to 6,423' wlm POOH. OOH change tool. RIH w/3.5 D&D hole finder tool sheared at 360' wlm POOH. OOH repin tool. RBIH with same tool, sat down @ 890' wlm POOH. OOH repin tool. RBIH down to 6,423' wlm. Set tool, pressure up tubing, monitor pressure. OOH repin pulling tool with steal pin. RBIH latch hole finder @ 6,400' wlm. Attempt to move up hole, tool sheared. OOH M/U 2.5 JDC. RIH w/JDC latch hole finder move up to 2,000' wlm. Set and pressure up tubing monitoring pressure.Test failed.Tubing still leaking, indicating hole is above 2,000' wlm. POOH. OOH w/tools. Lay down lubricator. Secure well. Clean up work area. 01/28/16-Thursday Fill out JSA and work permit. Attend morning safety meeting. Fuel Equipment. Help Production flange up. P/T lub to 750 psi test good. RIH W/2" GS to 5,741' wlm latch and pull AA Stop. OOH W/AA Stop. RBIH pull top pack off and 20 ft. spacer pipe. OOH. RBIH pull 10 ft spacer pipe. OOH. RBIH pull 20 ft. spacer pipe. OOH. RBIH pull 20 ft. spacer pipe. OOH. RBIH pull lower pack off W/20 ft. spacer pipe. OOH. RBIH pull AD2 Stop at 5,844' WLM. OOH W/AD2 Stop. M/U 1 3/8 JDC. RIH Latch and pull pump at 9,001' wlm. OOH w/pump. M/U Kobe K.O. Tool. RIH Punch out Kobes. POOH. OOH M/U standing valve pulling tool. RIH latch and pull standing valve. OOH w/standing valve. RIH w/ new standing valve shake off in fluid at 4,200' wlm. OOH. M/U blind box. RIH tap on standing valve POOH. OOH. M/U 1 3/8 JDC. RIH W/ pump set in place at 9,001' wlm. OOH. M/U PR GS w/AD2 Stop. RIH set stop at 5,849' WLM. OOH. Lay down lub. Secure well. Clean up work area. 01/29/16- Friday Complete JSA PPWRK. Attend Safety Meeting. RIH W/20ft. Spacer pipe set @ 5,825' wlm POOH. OOH. RIH W/20ft. Spacer pipe, Oil Jars gassed up, could not shear PRGS. OOH take off oil jars. RBIH w/20ft. Spacer pipe set @ 5,805' wlm POOH. OOH. RIH W/20ft. Spacer pipe set @ 5,780' wlm POOH. OOH. RBIH w/ 10 ft. spacer pipe set @ 5,768' wlm POOH. OOH. RIH w/25ft. Spacer pipe set @ 5,750' will) POOH. OOH. RIH W/AA Stop set @ 5,749' wlm Pooh. Fluid Level @ 4,080' wlm. OOH. Lay down lubricator. Wait on production to test well. Well is flowing good. R/D equipment. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD Slickline 50-733-20443-01 191-020 1/14/16 2/4/16 Daily Operations: 01/31/16-Sunday Arrive at the Bruce Platform. Complete JSA PPWRK. Rig up WL. PT lubricator to 800 psi, test is good. RIH w/2" GS. OOH w/25ft. Spacer Pipe. RBIH. OOH w/25ft. Spacer Pipe and 10 ft. Spacer pipe attached to bottom. RBIH. OOH w/20ft. Spacer Pipe. RBIH. OOH w/25ft. Spacer Pipe. RBIH. OOH w/20ft. Spacer Pipe. Redress both upper and lower pack offs. RIH w/20ft. Spacer pipe set @ 5,825' WLM. OOH M/U PRGS pulling tool. RIH w/20ft. Spacer pipe set @ 5,805' WLM. OOH Re-pin tool. RIH w/20ft. Spacer Pipe set @ 5,780' WLM. OOH Re-pin tool. RBIH w/ 10ft. Spacer pipe set @ 5,768' WLM. OOH Re-pin tool. RBIH w/20ft. Spacer Pipe set @ 5,754' WLM. OOH Re-pin tool. RBIH w/AA Stop set @ 5,749' WLM. OOH. Lay down lubricator, secure well, wait on production to test well. 02/03/2016-Wednesday Arrive at Bruce Platform. Fill out JSA paperwork.Attend pre job safety meeting. Rig Up W/L. P/T lubricator to 1000 psi. RIH w/2" GS. Ice plug at stuffing box. POOH slowly. OOH, lay down lubricator, re-head, cut 500ft. of wire. RIH w/same to 5,749'wlm. OOH w/AA stop. RBIH to 5,750' wlm . OOH w/25ft spacer pipe & 10ft. spacer pipe. RBIH to 5,780' wlm. OOH w/20ft. spacer pipe. RBIH to 5,800' wlm. OOH w/20ft. spacer pipe. RBIH to 5,830' wlm. OOH w/20ft. spacer pipe. RBIH to 5,849' wlm. OOH w/AD2 stop . RIH w/ 1 3/8 JDC to 9,001' wlm. OOH w/ pump. Lay down lubricator, secure well. Clean up tools and work area. 02/04/2016-Thusday Fill out JSA paperwork and attend pre job safety meeting. Complete walk around, stand up lubricator, prep tools. RIH w/ 1 3/8 JDC w/pump, set @ 9,001' wlm. OOH. M/U GS w/AD2 stop, set @ 5,859' wlm. OOH, M/U PRGS w/bottom pack off. RIH w/bottom plug, set @ 5,858' wlm. OOH, re-pin tool. RIH w/20ft. Spacer pipe, set @ 5,836' wlm. OOH, re- pin tool. RBIH w/20ft. spacer pipe, set @ 5,815' wlm. OOH, re-pin tool. RBIH w/20ft. spacer pipe, set @ 5,793' wlm. OOH, re-pin tool. RBIH w/20ft. spacer pipe, set @ 5,775' wlm. OOH, re-pin tool. RBIH w/25ft. spacer pipe w/upper pack off, set @ 5,750' wlm. OOH, re-pin tool. RBIH w/AA stop, set @ 5,749' wlm. OOH, Lay down lubricator, wait on production to test well. R/D equipment clean up work area and fill out paperwork. • of T� THE STATE % Alaska Oil and Gas o LJ\ S ���•�.��, f Conservation Commission x-=_ 333 West Seventh Avenue V ,\ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis ` c ' Operations Manager Hilcorp Alaska, LLC 1 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Pt Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Permit to Drill Number: 191-020 Sundry Number: 316-063 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P" vim ' Cathy P Foerster Chair DATED this ?J day of February, 2016. RBDMS LL FEB 0 4 2016 • • • STATE OF ALASKA RECFEBE011IVE2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 12 a'-S Z4 11(/,‘/,‘ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well LJ . Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Patch/Short String 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC - Exploratory ❑ Development E • 191-020 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El6.API Number: Anchorage,AK 99503 50-733-20443-01 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 1 Granite Pt St 18742 2ORD " 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 Granite Pt Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,550 , 9,768 • 9,688 - 9,018 - —1100 psi 10,198 9,754 Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapt❑ Development 0 - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/15/2016 OIL E , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 1/29/2016 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned LI 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thalleWhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature cL- A Phone (907)777-8356 Date -2- ( t I I (O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Cta' Subsequent Form Required: .--/i e { RBDMS t,`- FEB 0 4 1016 AP/PROVED BY Approved by: Y PCOMMISSIONER THE COMMISSION Date: 2... 3 . 0t,,....,41„,_ 1v 4 Submit Form and Form 10-403 Re sed 11/2015 r �r1V'# I oA lid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: Br 2ORD-42 Hilcorp Alaska,LL Date: 02/01/2016 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 2/15/2016 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Trudi Hallett (907) 777-8323(0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904 (M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface — 1,100 psi 2,000psi-(0.1 *TVD) Pressure (MPSP): Brief Well Summary This job entails installing a tubing patch on the short string side to isolate a leak. Procedure: 1. Rig up slick line and pressure test lubricator to 1,500 psi. 2. Make initial drift and tag run w/2.5" GR. POOH. 3. RIH w/+/- 10' tbg patch to +/- 1,000' (WLM). 4. Pressure test patch. 5. Rig down slick line and lubricator. 6. Operations to bundle test system. 7. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic • • Bruce Platform II SCHEMATIC Well # Br 2ORD-42 Hileorp Alaska,1 LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 / 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Patch 5,756' JEWELRY DETAIL 5,845' ) NO. Depth ID OD Item -, - 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 ( 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 4 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads \ / B 9 9,082' Blank X10, 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') /X� Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 N. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments . C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns 111M. C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns NM IIS 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 41 0 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns * 9 . 10 PBTD=9,688'MD 9,018'(TVD) Updated by: JLL 12/09/15 TD=10,550'MD (9,768'ND) • Bruce Platform PROPOSED Well # Br 20RD-42 Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 / 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' ! A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' 1 Tubing t- Long String -, 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L JEWELRY DETAIL NO. Depth ID OD Item 1 \ -. - 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' ); 5 9,043' 2-7/8"Isolation x 2' ' r 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID a 8 9,078' 2)Firing Heads i \ / B 9 9,082' Blank X s 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 6. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 - C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments 1111111. C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns IMMII C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 iMi, C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns iiIM 2"PowerJet w/Spec. Min C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 = 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. •.:";-:- 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 0 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns M 60 C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 0 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns * ,ot 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns +Nr 9 * 10 PBTD=9,688'MD 9,018'(TVD) Updated by: 1LL01/29/16 TD=10,550'MD (9,768'ND) • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday,January 29, 2016 9:16 AM To: 'Trudi Hallett' Cc: Juanita Lovett Subject: RE: Bruce 2ORD-42 (PTD 191-020) Sundry# 316-003 Trudi, I will give you Verbal approval to go ahead and patch the SS as you are already rigged up on the well ..just submit the sundry as soon as you can. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Trudi Hallett [mailto:thallett(ahilcorp.corr Sent: Friday, January 29, 2016 7:09 AM To: Schwartz, Guy L (DOA) Cc: Juanita Lovett Subject: RE: Bruce 2ORD-42 (PTD 191-020) Sundry # 316-003 Good Morning,Guy— At the start of the patch and pump change yesterday on the Bruce 20RD-42,the crew found and isolated a leak on the short string side just above-moo'. It appears to be a single hole that could be repaired with a short patch.With fingers crossed, I was hoping we could do that with the existing sundry or change of approved program. However, I will submit a new sundry addressing the issue and procedure since it is on the SS and the current sundry is for the long string.Thank you for the consideration. Thanks- Tru,di. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, January 22, 2016 11:26 AM To: Trudi Hallett Cc: Juanita Lovett Subject: RE: Bruce 2ORD-42 (PTD 191-020) Sundry # 316-003 1 1 M • • Thanks for checking ...you can use the existing sundry 316-003 to perform the reset of the tubing patch. Report under the same 10-404 report when it's set. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.aov). From: Trudi Hallett [mailto:thallett©hilcorp.com] Sent: Friday, January 22, 2016 11:16 AM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: Bruce 2ORD-42 (PTD 191-020) Sundry # 316-003 Hello,Guy- We performed the patch change-out on the Bruce 2ord-42 on 1/14/2016—However,after a week of production—it appears the patch did not set correctly and we would like to run back in, pull the patch completely out, redress and set a new patch in place under the existing sundry with your approval. Please advise if you would like us to close out the current Sundry#316-003(which "expires"2/1312016)and submit a new one OR if we may proceed with pulling and re-running the patch under the existing sundry.We can move on the well next week. Appreciate the consideration with the above request! Happy Friday! Thanks- Trudi Hallett I Opera' t t ook Inict Oftshorc Asset Tcam ' Hilcorp A Company Built on Energy thallett@hilcorp.com 0: 907.777.83 23 C: 907.301.6657 2 „ OF ,, • • ,w'\-,\I%%s� THE STATE Alaska Oil and Gas • �w -s��—�1 of/\ L /� SKAL Conservation Commission k�...x__._�_= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF '' ` g_' P Main: 907.279.1433 ALAS”' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager S NNEV2 -' � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Permit to Drill Number: 191-020 Sundry Number: 316-003 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, it-t. oerster Chair DATED thisIPday of January, 2016. RBDMSc)AN 12 2016 RECEIVED • • JAN 0/412016 STATE OF ALASKA /4////6 ALASKA OIL AND GAS CONSERVATION COMMISSION O APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing d Chq Pump/Remove-Reinstall Patch , E] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development 0 . 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic LI Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No E]1 Granite Pt St 18742 2ORD 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 Granite Pt Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,550 • 9,768 9,688 • 9,018 1,100 psi 10.198 9.754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,518' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigrapt❑ Development 0 Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/18/2016 OIL 0 ' WINJ Li WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ri 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett(a hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ' `-` ..G (- : Phone (907)777-8356 Date 1/4/2016 COMMISSION USE ONLY Conditions of approval: Notify Com ission so that a representative may witness Sundry Number:3//P (//,Q Plug Integrity ❑ BOP Test [11Mechanical Integrity Test ❑ LiLocation Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No III RBS MS jQ41Z .1" Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /6 Lit a-=• / APPROVED BY Approved by. �(,� COMMISSIONER THE COMMISSION Date: /_/( /,..0( //( -/(so 1)Ki/ 117-11(42 4' /7/'/ Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from efo L Attachments in Duplicate • • Well Prognosis Well: Br 20RD-42 n;k°ru Alaska,LL Date: 01/04/2016 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 1/18/2016 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907)301-6657(M) Second Call Engineer: Dan Marlowe (907)283-1329(0) (907) 398-9904(M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: —2,000 psi ©8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Potential Surface Pressure - 1,100 psi 2,000psi-(0.1 *TVD) (MPSP): Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump / Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 2. Pull patch at 5,756'-5,845'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,750'to+/-5,85St' (WLM). up 8. Pressure test patch against standing valve. 9. Rig down slick line and lubricator. 10. Operations to bundle test system. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic • • Bruce Platform SCHEMATIC Well # Br 20RD-42 ` 14 Mean)Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.58 J-55 12.615" Surface 1,584' 1 J t 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' r *Note for 9-5/8"Casing-6,974'is top of window. Latch 5,756' JEWELRY DETAIL 5,845' NO. Depth ID OD Item ( 1 1. 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over "Butt.Box x 2-7/82-7/8" 8rd.EUE Pin \ ...., -... 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' ' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X X` 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns INNI MUM C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns Ami ala 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 _ _- 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"Powerlet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. - 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns M .8 { C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns • 9 • « 10 PBTD=9,688'MD 9,018'(TVD) Updated by: JLL 12/09/15 TD=10,550'MD (9,768'TVD) ill • Bruce Platform III PROPOSED Well # Br 20RD-42 ` ailcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 ' ir, 1 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.44 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. 4 Patch L ±5,750 JEWELRY DETAIL ±5,850 NO. Depth ID OD Item \ -. ,-- 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .., 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank X X\ ,. 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments .,- C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns IIM MIN C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns 111 2"PowerJet w/Spec. -., C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. 0 C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. .,\11,, j C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns M 6 C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 1M 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 8ist ' C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns 5 C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns * 9 • ,� 10 PBTD=9,688'MD 9,018'(TVD) Updated by: ILL 01/04/16 TD= 10,550'MD (9,768'TVD) STATE OF ALASKA • WSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations.❑ Fracture Stimulate ❑ Pull Tubings❑ Operations shutdown 0 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing)❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well,❑ Other: Chg Pump& ❑ Remove/Reinstalled Patch 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory El 191.020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphie❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 2ORD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet DEC 14 2015 Effective Depth measured 9,688 feet Packer measured N/A feet t'��+/'°� true vertical 9,018 feet true vertical N/A feet (��°/,",+ Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 10,545' 9,764' 8,160 psi 7,020 psi Perforation depth Measured depth See Schemaitc feet True Vertical depth See Schematic feet 2-7/8"LS 6.4#/N-80 9,013'(MD) 8,502'(ND) Tubing(size,grade,measured and true vertical depth) 3-1/2"SS 9.2#/N-80 6,457'(MD) 6,310'(ND) 2-3/8"SS 4.6#/N-80 9,011'(MD) 8,501'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A ;CONK _r C, 0 4 4,.")„)% Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 31 8 18 75 65 Subsequent to operation: 56 47 24 81 68 14.Attachments (required per 20 AAC 25.070,25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Developmentt0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 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: 315-680 Contact Trudi Hallett(907)777-8323 Email thallett@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ��L `'.1 (---/k• Phone (907)777-8356 Date 12-j (`{ S y / 7-Vi-" Ll, RBDMS C a, 212015 Form 10-404 Revised 5/2015 /A ` , /Xi' Submit Original Only • SCHEMATIC Bruce Platform Well# Br 20RD-42 Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# 1-55 12.615" Surface 1,584' 1 f 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 4 A 7"Liner 29,32# N-80&5-95 6.094" 6,513' 10,545' P Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' f *Note for 9-5/8"Casing-6,974'is top of window. i 4 Patch 5,756'- JEWELRY DETAIL 5,845' i NO. Depth ID OD Item 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P ...- s.... ) 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 / 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads \. 1 B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') /' '1 Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. \ B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 IMF mmi C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns !dui. C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns -.'l 2"PowerJet w/Spec. �` C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 Er -_-. 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. * 4 M 2"PowerJet w/Spec. IIC-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. \5\ 5 1 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns \� \ C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns •\ +M \ M C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns \7\ M C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 'iI, �' \8 o 2 'MC-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns \ • C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns ,,,,,,,, ,i0 M ,0 * A ` . PBTD=9,688'MD 9,018'(TVD) Updated by: ILL 12/09/15 TD=10,550'MD (9,768'TVD) • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742#20RD Slickline 50-733-20443-01 191-020 11/19/15 11/20/15 Daily Operations: 11/19/2015-Thursday Morning meeting, discussed job.,Morning meeting. Start jsa, hotwork, and permit to work. Get tools ready, stand- by for production to bleed well. Stab on riser and add on 20' lub. Stab on lubricator and P/T to 1000 psi, pass. RIH W/GS to 5,756' wlm to pull AA stop. Fluid level at 630'. OOH W AA stop. RBIH to pull top pack-off and patch at 5,757' wlm. Fluid level at 1,065'. Pulled pack-off stand-by for element to shrink. POOH.,00H W top pack-off and spacer. Stand-by to eat lunch. Un stab lub. Remove patch. RBIH to pull patch at 5,777' wlm. POOH. OOH stand-by for crane.,RBIH to pull patch at 5,801' wlm. Fluid level at 2,135'. OOH. RBIH to pull bottom patch at 5,823' wlm. Fluid level at 2,275'. Stand-by let element shrink. POOH. OOH stand-by for crane to work boat. Un stab lub. Remove patch. RBIH to 5,845' wlm. Pull AD2 stop__Fluid level at 2,475'. OOH with AD2.,RIH W/ 1 3/8 JDC to 8,982' wlm. Pull pump. POOH. OOH with pump. RIH WI kobe knock out tool. OOH. Lay down for night. Secure well. 11/20/2015- Friday Morning safty meeting. Start jsa hot work and permit to work. Paper work signed. Stab on lubricator. RIH W/stand-in, valve pulling tool to 9,002' wlm. Fluid level at 4,800'. POOH. RIH WI stand-in valve shake off at 5,000' wlm in fluid. OOH. RIH W/ 1.75 blind box to 9,002' wlm seat valve. OOH. RIH WI 1 3/8 JDC and pump jo 8,982'wlm._RIH W/gs and AD@ S,1.- stop to 5,845' wlm. OOH eat lunch .RBIH W/ bottom pack-off to 5,823' wlm. OOH. Stand-by for boat. Unstab lub and Ply attach patch. RBIH WI patch to 5,801' wlm. Fluid level at 4,815'. OOH. RBIH W/patch to 5,777' wlm. OOH. RBIH w/top 4 pack-off to 5,757. wlm. OOH. RBIH W/AA stop to 5,756' wlm. OOH. Lay down and turn over to production. ecrc R • ®F Tk� THE STATE Alaska Oil and Gas of Conservation Commission ALAsKA. iStt; 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 R` Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov iCANSEE► JAN 1 3 2U16 Stan Golis �0 Operations Manager a f O Hilcorp Alaska, LLC I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Sundry Number: 315-680 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this /Z day of November, 2015 Encl. R�oM • • t • STATE OF ALASKA NOV Q ALASKA OIL AND GAS CONSERVATION COMMISSION 2 200 ors ',oz.,/ LS APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 4 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Progra!p ❑ yE7 P•Z'w1f- Plug for Redrill❑ Perforate New Pool ❑ Repair Well L - Re-enter Susp Well ❑ Other Cha Pump 8 Remove/Reinstall Patch L 2.Operator Name: 4.Current Well Gass: 5. Permit to Drill Number. Hilcorp Alaska, LLC , Exploratory ❑ Development D - 191-020 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service CI6.API Number: Anchorage,AK 99503 50-733-20443-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 2 / Granite Pt St 18742 2ORD 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 ' Granite Point Field/Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,550 _ 9,768 9,688 , 9,018 10,198 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365'-9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic • See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development J Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/16/2015 OIL LI • WINJ Cl WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Golis Email sgolis(a)hilcorp.com. Printed Name Stan Golis Title Operations Manager Signature Phone (907)777-8356 Date 11/2/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 COS U Plug Integrity LI BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance CIXU Other: RBDMS� �`QSinv 13 2015 Spacing Exception Required? Yes C1 No d` Subsequent Form Required: l a r a/ a el JO APPROVED BY //_ /Z_/ / Approved by: Y COMMISSIONER THE COMMISSION Date: ! S (l3(S (i•/4 S req' gmlrgaiAlt Submit Form and Fm 10-403 Revised 5/2015 Approved application is vaiiQ f� ap ro al. //—'/ Attachments in Duplicate ���J ���!/ <<(✓ ( /S • • Well Prognosis Well: Br 20RD-42 Hitrorp Alaska,LL Date: 11/02/15 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 11/16/15 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) AFE Number: Current Bottom Hole Pressure: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Anticipated Surface Pressure: - 1,100 psi 2,000psi-(0.1 *TVD) Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump. Procedure: 1. Rig up slick line and pressure test to 1,500 psi. 7/2(44 2. Pull patch at 5,756'-5,842'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,750'-5,845' (WLM). 8. Pressure test patch against standing valve. ,- <' "* - ^ -1 9. Rig down slick line and lubricator. 10. Operations to bundle test system. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic • SCHEMATIC Bruce Platform ' 11 • Well # Br 20RD-42 HilcorpAlaeka,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 / A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' is 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Wireline L patch JEWELRY DETAIL 5,756' NO. Depth ID OD Item 5,842' .. ,- 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X X r 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String f A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long i Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns 1111 1 I i C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 II C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. "::";- 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns * C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns M 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns +M • * 10 A , ,'',N PBTD=9,688'MD 9,018'(TVD) Updated by: JLL 07/23/15 TD=10,550' MD (9,768'TVD) • • PROPOSED Bruce Platform EL Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# 1-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.48 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L JEWELRY DETAIL NO. Depth ID OD Item \ , ,- 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .. '- 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X X\ ' 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P 4 , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total t of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 1 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns IIMEIR amu.. C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 EMI C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns I•I■ 2"Powedet w/Spec. IIMIL C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 -7-._---. 2"Powedet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4287'. 2"Poweriet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. r� 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns lik 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 0 8 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns j C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns I *r 10 PBTD=9,688' MD 9,018'(TVD) Updated by: 1LL 11/02/15 TD= 10,550'MD (9,768'TVD) STATE OF ALASKA . .SKA OIL AND GAS CONSERVATION CG .ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill LI Perforate New Pool❑ Repair Well 0 Re-enter Susp Well❑Other: Chg Pump&Remove/Reinstall Patch 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory❑ 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 RECEIVEL 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 2ORD JUL 2 3 201 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool ACC 11.Present Well Condition Summary: �/��V1J Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,688 feet Packer measured N/A feet true vertical ' 9,018 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365'-9,764' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS-2-7/8" 6.4#/N-80 9,013'(MD) 8,502'(TVD) Tubing(size,grade,measured and true vertical depth) SS-3-1/2"&2-3/8" 9.2#&4.6#/N-80 9,011'(MD) 8,501'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 1Treatment descriptions including volumes used and final pressure: SCANNED AUG 0 201c N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 43 37 5 104 68 Subsequent to operation: 55 0 8 87 70 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 315-390 .r Contact Trudi Hallett Email thallettt hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature ,� � +j1 Phone (907)777-8323 Date 7/23/2015 RBDMS P!_ 2 4 2015 Form 10-404 Revised 5/2015 7 'l S—IS Submit iginal Only SCHEMATIC Bruce Platform . Eli Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ / ' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.44 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.64 N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. Z Wireline patch JEWELRY DETAIL 5,756' 5,842' NO. Depth ID OD Item -, 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .. '. 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads 7 B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (ND) Amt SPF Date Comments C-s 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns li C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 ;N, C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns 1•IMMO1■ 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 - 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 0ist 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. v. 5 \ • C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns M \\ C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • • • ' C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7M C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 0 M 8 l 0 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns 0 C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns U► g M PBTD=9,688' MD 9,018'(TVD) Updated by: JLL 07/23/15 TD= 10,550'MD (9,768'TVD) Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#20RD 50-733-20443-01 191-020 7/3/15 7/9/15 Daily Operations: 07/03/15 - Friday Arrive on platform fill out paperwork and JSA. Start R/U of equipment and tools. Finish rig up. Stab on lubricator P/T lub to 1500 psi, test good. RIH w/GS pull top AA stop @ 5,760' wlm, POOH. RBIH pull top patch @ 5,762' wlm, POOH. RBIH pull spacer pipe @ 5,776' wlm, POOH. RBIH pull spacer pipe @ 5,796' wlm, POOH. RBIH pull bottom packoff @ 5,817' wlm, POOH. RBIH pull AD-2 stop @ 5,837' wlm, POOH. RIH w/ 1 3/8 JDC pull pump @ 8,986' wlm, POOH. RIH w/standing valve equalizing tool punch standing valve. OOH, secure well. Clean up work area, SDFN. 07/04/15-Saturday Attend morning safety meeting. RIH w standing valve pulling tool latch valve @ 9,002' wlm, POOH. OOH, no valve. Spread prong out. RBIH w/valve pulling tool latch and POOH. OOH, no valve. Change out prong. RBIH w/valve pulling tool latch and POOH. OOH w/standing valve. RIH with shake off prong, shake valve off in fluid @ 4,630' POOH. RIH with tap in tool to 9,002' wlm, POOH. OOH, pick up pump. RIH w 1 3/8 JDC and pump set @ 8,986' wlm, POOH. M/u GS and AD-2 stop. RIH set AD-2 @ 5,860', GS sheered, POOH. OOH, repin tool. RBIH pull AD-2 stop set @ 5,837' wlm, POOH. OOH, repin tool. RIH w/bottom packoff and spacer pipe @5,817'wlm. OOH, repin tool. RIH set spacer pipe @ 5,796'. OOH, repin tool. RIH set spacer pipe @ 5,776'. OOH, repin tool. RIH set top packoff @ 5,762' wlm. OOH, repin tool. RIH set AA stop @ 5,760'. OOH, secure well. Clean work area. 07/08/15 -Wednesday Arrive at Bruce Platform. Start JSA, PTW, Hot work. Rig up lubricator and tool string, stand by for boat until 14:30. Stab on lubricator and pressure test to 1000 PSI. RIH W/2.5 GS to 5760' wlm, pull AA stop. OOH with top pack-off. RBIH to 5776' wlm, pull spacer pipe. OOH with spacer pipe. RBIH to 5817' wlm, pull bottom pack-off. OOH with bottom pack-off. RBIH to 5837' wlm, pull AD2 stop. OOH with AD2 stop. RIH w 1 3/8 JDC to 8986' wlm, pull pump. OOH with pump. RIH with kobe kockout tool to 9002' wlm, punch kobes. OOH secure well for night, clean work area. 07/09/15-Thursday Morning meeting. Start JSA, PTW and hot work. RIH w/standing valve pulling tool. OOH with standing valve. RIH with new standing valve, shake off in fluid. OOH. RIH tap standing valve to 9002' wlm. OOH. RIH with pump to 8986' wlm. OOH. RIH with AD2 stop, set at 5842' wlm. OOH. RIH with bottom pack-off set at 5821' wlm. OOH. RBIH with spacer set at 5801' wlm. OOH. RBIH with spacer set at 5781' wlm. OOH.RBIH with top pack off set at 5757' wlm. OOH. RBIH with AA stop at 5756'wlm. OOH. Rig down.Turn well over to production for testing. Finished R/D stand by for production. , VOF TH w\� 4. THE STATE Alaska Oil and Gas of/A LASI( Conservation Commission x= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 tti Main: 907 279 1433 OA, ALAS1°' Fax: 907 276 7542 www aogcc alaska gov SCANNED JUL 0 7 2015 Trudi Hallett a a-° Operations Engineer ' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granit Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Sundry Number: 315-390 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, L.4",_,4./ Cathy P. Foerster Chair DATED thisYay of June, 2015 Encl. JUN222ui`.; STATE OF ALASKA rylS G(2-111S ' ALASKA OIL AND GAS CONSERVATION COMMISSION , eA C;(. APPLICATION FOR SUNDRY APPROVALS ` 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill LI Perforate New Pool ❑ Repair Well 0• Re-enter Susp Well ❑ Other Chit Pump 8 Ramov&Ranstaf Patch Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. tr Nrt0 Hilcorp Alaska,LLC Exploratory ❑ Development 0 ' 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20443-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 1=1•1 Granite Pt St 18742 2ORD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742• Granite Point Field/Middle Kenai Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): - 10,550 • 9,768 • 9,688 , 9,018 10,198 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' ▪ 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' • 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365'-9,764' ▪ 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: 'Tubing MD(ft): See Schematic J See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program LI BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/6/2015 Commencing Operations: OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallettehilcorp.com Printed Name Trudi Hallett Title Operations Engineer ' Signature ttalru1 1 64—(2"14 Phone (907)777-8323 Date 6/22/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315, U w Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance CI Other: Spacing Exception Required? Yes 0 No Subsequent Form Required: 10 -H O"-+ � /° APPROVED BY Approved by: 4 COMMISSIONER THE COMMISSION Date: C — 36 --/.S J ' Cj�.I3 "/-5 Submit Form and Form 10-403 Rsed 5/2o15 Approved ap IlcattttIon is valid in�f�it e�t of approvtdl givi*C"ZAttactwtJsjrt turn 111 ffftnR JUNJ Well Prognosis Well: Br 2ORD-42 Elilcarp Alaska,LL: Date:06/19/15 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 07/06/15 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Trudi Hallett (907)777-8323(0) (907)301-6657(M) Second Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904(M) AFE Number: Current Bottom Hole Pressure: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Anticipated Surface Pressure: - 1,100 psi 2,000psi-(0.1 *TVD) Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump / Procedure: 1. Rig up slick line and pressure test to 1,000 psi. - ) 2. Pull patch at 5,760'-5,837'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,760'-5,837' (WLM). 8. Pressure test patch against standing valve.'' 9. Rig down slick line and lubricator. 10. Operations to bundle test system. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic SCHEMATIC Bruce Platform Well # Br 20RD-42 • 111 ItileurpAlaeka,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.58 J-55 12.615" Surface 1,584' 1 i/ [ 9-5/8" 40,43.58 S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing r Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. 1 L Wireline patch , JEWELRY DETAIL 5,760' NO. Depth ID OD Item 5,837' \ ,- 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual \\i 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 j 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' i 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID / 8 9,078' 2)Firing Heads \ / B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P G , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO._ Depth(Top} Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. I ; PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. Illw 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. • •• C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns ',6, M C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns M C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7\ M C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns ♦ 8 1 0 C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns L.\ • \\\*9 • gig ...,: \ PBTD=9,688'MD 9,018'(TVD) Updated by: JLL 06/19/15 TD=10,550'MD (9,768'ND) . , Proposed Bruce Platform II p Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' r'; 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. • L' Wireline J patch JEWELRY DETAIL , NO. Depth ID OD Item \, 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads I \ / B 9 9,082' Blank k. 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') XX Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P L , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long I. Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns INIIIMI■ C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns ■ 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 _ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 * 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 7.-: 5 is C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns rot C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 0 C-7 9,816' 9,828' 9,127' 9,137' 12 8 4/9/1991 TCP Guns ), 41 40 n---i * C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns Ll 0 C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns ilt PBTD=9,688'MD 9,018'(TVD) Updated by: .ILL 06/19/15 TD= 10,550'MD (9,768'ND) • STATE OF ALASKA !� V - AL .A OIL AND GAS CONSERVATION COM,....,SION JUN2 201:_iREPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing❑ alfi.il(itdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Re-enter Susp Well❑mer Cha Pump&Remove/Reinstall Patch 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 191.020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 2ORD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,550 feet Plugs measured 10,198 feet true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,688 feet Packer measured N/A feet true vertical 9,018 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365'-9,764' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS-2-7/8" 6 4#/N-80 9,013'(MD) 8,502'(ND) Tubing(size,grade,measured and true vertical depth) SS-3-1/2"&2-3/8" 9.2#&4.6#/N-80 9,011'(MD) 8,501'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED i(i[ Q 9 r j i- r Treatment descriptions including volumes used and final pressure: jr; N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 52 34 13 93 72 Subsequent to operation: 27 16 9 91 70 14.Attachments(required per 20 AAC 25 070,25.071,&25.283) ' 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 315-313 Contact Trudi Hallett Email thallettta.hiIcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature --Fit— Phone (907)777-8323 Date 6/22/2015 ` _ ` RBDM ' - 1 2015 Form 10-404 Revised 5/2015 7-6 !S Submit '"'m`it Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #20RD 50-733-20443-01 191-020 5/26/15 5/27/15 Daily Operations: 05/26/15-Tuesday Arrive on platform. Fill out JSA and wait for crew change meeting. Start spotting equipment and rigging up slickline. Stab on lubricator P/T lub to 1500 psi. RIH w/2 1/2 GS pull AA stop @ 5,760' wlm. POOH. RBIH, pull top packoff and spacer pipe @ 5,762'.Jarred for several hours, was able to move up hole 4ft. Sheer off to check wire and tools. OOH, re-pin tool retie rope socket. RBIH, pull top packoff and spacer pipe @ 5,758'.Jarred free, POOH. OOH w/TPO. RBIH pull spacer pipe @ 5,776'. OOH w/Spacer pipe. RBIH, pull spacer pipe @ 5,796'. OOH w/Spacer pipe. RBIH, pull bottom packoff @ 5,817'. OOH w/ BPO. RBIH, pull AD-2 stop @ 5,837'. OOH w/AD-2 stop. RIH w/ 1 3/8 JDC latch pump @ 8,986'. OOH w/ pump. RIH w/ Kobe knockout tool. Punch out KOBE @ 9,002'. OOH. Secure well. SDFN. 05/27/15-Wednesday Fill out JSA and work permits. Attend morning safety meeting. Stab on lubricator P/T lub to 1500 psi. RIH w/standing valve pulling tool latch standing valve @ 9002, wait for well to finish equalizing. OOH w/standing valve. RIH w/new S/V shake off in fluid @ 5030ft. OOH. M/U knock in tool. RIH tap standing valve in place. OOH. M/U 1 3/8 JDC and pump. RIH w/ pump set @ 8986, OOH. M/u GS tool and AD-2 stop. RIH w/AD-2 stop set @ 5837. OOH. RIH w/bottom packoff set @ 5817. OOH. RIH w/spacer pipe set @ 5796. OOH. RIH w/spacer pipe set @ 5776. OOH. RIH w/top packoff set @ 5762. OOH. RIH w/AA stop @ 5760. OOH standby for production to test tubing and patch. Test good waiting for well to flow. Start rigging down slickline. • • ill SCHEMATIC Bruce Platform Well # Br 20RD-42 Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' ITubing I. Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L 'Wireline L patch DETAIL 5'760 , NO. Depth ID OD Item 5,837' \ ,-., -- 44.95' Tubing Hanger,C.I.W. SM x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID / 8 9,078' 2)Firing Heads / B 9 9,082' Blank X 10 9,085' 4.625 4-5/8"0.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P G , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ ff 2"LIB. t PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns li. MIN C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns ENO ENE■I■ 2"PowerJet w/Spec. -. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 i♦ 2"PowerJetw/Spec . C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns �. C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns rilv \ C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns \7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns \.\`�«' \,8\ C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns \\ C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns \\\\\ rlr '10 PBTD=9,688'MD 9,018'(TVD) Updated by: .111 06/19/15 TD=10,550'MD (9,768'ND) O2— OF Ty yw\�I1/7, s THE STATE Alaska Oil and Gas ofALASKA- Conservation Commission 'OM _ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 oMain: 907.279.1433 F ALAS�''P SLOE VM 2 " �hhu�h Fax: 907 276 7542 www.aogcc.alaska.gov Dan Marlowe ( — °49j)Operations Engineer I F Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 2ORD Sundry Number: 315-313 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P4tJe _ Cathy P. oerster Chair DATED this?ay of May, 2015 Encl. �s RECEIVED S-1- ' 1 � • STATE OF ALASKA r/1,, \1� MAY 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well l 1 Re-enter Susp Well ❑ Other:Chg Pump&RemwelRenst ll Patch El- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 ' 191-020 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20443-01' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No I] Granite Pt St 18742 20RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 ' Granite Point Field/Middle Kenai Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,550 . 9,768 • 9,688 • 9,018 10,198 9,754 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365'-9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ' See Schematic LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Os Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/1/2015 Commencing Operations: OIL El' WINJ ❑ WDSPL ❑ Suspended ❑ 1 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe©hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature ff41-11-1(11)n q ryf,Vriti2bitPhone (907)283-1329 Date 5/21/2015 /Vl for Dam riOVV COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' ' _ `3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Qr. Subsequent Form Required: /o— 11 a APPROVED BY Approved by. / COMMISSIONER shills-- APPROVED THE COMMISSION Date: 5-ZZ--/C 7 �, �NALId ��months �'� Submit Form and Form 10-403 Revised 5/2 5 r I for 12 months f m e�te of approval. Attments in Duplicate �� �i RBDMS MAY Z 9 2015 Well Prognosis • Well: Br 2ORD-42 Hiicorp Alaska,LL' Date:05/21/2015 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: 06/01/15 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904(M) Second Call Engineer: Trudi Hallet (907)777-8323 (0) (907)301-6657(M) AFE Number: Current Bottom Hole Pressure: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: —2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Anticipated Surface Pressure: — 1,100 psi 2,000psi-(0.1 *TVD) Brief Well Summary This job entails pulling and reinstalling the tubing patch and swapping the downhole jet pump / Procedure: 1. Rig up slick line and pressure test to 1,000 psi. 2. Pull patch at 5,760'-5,837'. 3. Pull, inspect, rebuild Jet pump as needed. 4. Pull, inspect, rebuild Standing valve as needed. 5. Re-run standing valve. 6. Re-run Jet pump. 7. Re-run extended patch to+/-5,760'-5,837'(WLM). 8. Pressure test patch against standing valve. 9. Rig down slick line and lubricator. 10. Operations to bundle test system. 11. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic SCHEMATIC Bruce Platform Well # Br 20RD-42 aa�rn Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' / A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' 1 Tubing t Long String { 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Wireline patch JEWELRY DETAIL 5,760' NO. Depth ID OD Item 5,837'\ , ..--, ' 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID \ 8 9,078' 2)Firing Heads \ / B 9 9,082' Blank X `X' 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. N. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns PMIS C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns I• 2"PowerJet w/Spec. IIIM C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 _ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. • 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. .\-: A• C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • +t► C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns A C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns , - * C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns 'M C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns • PBTD=9,688' MD 9,018'(TVD) Updated by: JLL 03/06/15 TD= 10,550'MD (9,768'ND) Bruce Platform ProposedWell # Br 20RD-42 . 14 Hilcorp Alaska,LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.511 J-55 12.615" Surface 1,584' 1 \ / - A 9-5/8" 40,43.5# 5-95&N-80 29,32# N-80&S-95 8.755" Surface *6,974' 7"Liner6.094" 6,513' 10,545' ss Tubing Long String 2-7/8" 6.411 N-80 Buttress 2.441" 47' 9,013' • Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' a 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. I Wireline patch JEWELRY DETAIL NO. Depth ID OD Item ,-\ -. 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID �77 8 9,078' 2)Firing Heads i �l \ / B 9 9,082' Blank X X` ' 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P L $ , , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B is C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long I r Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. i PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments It C-5 9,085' 9,140' 8,55T 8,598' 55' 5/16/1993 4-5/8"TCP Guns ; IIIIII C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 Ir C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns Min 2"PowerJet w/Spec. �i II: C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 elear 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. -: 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns • * ,.\\ C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns ,7\ C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns M `8\ C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns kik +09 w ,rr 10 PBTD=9,688'MD 9,018'(TVD) Updated by: 1LL 05/21/15 TD=10,550'MD (9,768'TVD) STATE OF ALASKA • AL-....:A OIL AND GAS CONSERVATION COMIC.__SION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations , Perforate❑ Other 0 Chg Pump/Remove Performed: &Reinstall Patch Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 191-020 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service❑ 6.API Number: Anchorage,AK 99503 50-733-20443-01 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED E C E I\y/CG D ADL0018742 Granite Point ST 18742 2ORD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MAR 0 6 2015 Granite Point Field/Middle Kenai Oil Pool 11.Present Well Condition Summary: AOG^C Total Depth measured 10,550 feet Plugs measured 10,198 feet (� true vertical 9,768 feet Junk measured 9,754 feet Effective Depth measured 9,688 feet Packer measured N/A feet true vertical 9,018 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,365-9,764' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS-2-7/8" 6.4#/N-80 9,013'(MD)8,502'(ND) Tubing(size,grade,measured and true vertical depth) SS-3-1/2" 9.2#/N-80 6,457'(MD)6,310'(ND) SS-2-3/8" 4.6#/N-80 9,011'(MD) 8,501'(ND) Packers and SSSV(type,measured and true vertical depth) N/A&N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED m!-' , :L .3 :J Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 53 41 9 105 69 • Subsequent to operation: 54 33 14 109 68 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 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: 315-011 ' Contact Dan TaylorEmail dtaylor(U�hilcoro.com Printed Name Dan Taylor, Title Operations Engineer Signature ,000"...°..."1/ Phone (907)777-8319 Date 3/6/2015 Form 10-404 Revised 10/2012 J-17- is ubmit Original Only to".3�r/1� RBDMS M�R - 6 2015 SCHEMATIC Bruce Platform II Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 \ / 9-5/8" 40,43.5# 5-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.48 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.68 N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L I//Wireline patch JEWELRY DETAIL 5,760'- �,, t NO. Depth ID OD Item 5,837' ( r)\-, ..- , 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin . 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 / 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads / B 9 9,082' Blank X X 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z. , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish • NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ S2"LIB. t PERFORATION DETAILS i Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-S 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns .is C-S 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 iii C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns MIME 2"Poweriet w/Spec. M. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 -_ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. �." 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns \ \� M 0 8 C-7 9,837 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns � 9 *till 10 PBTD=9,688'MD 9,018'(TVD) Updated by: 1LL 03/06/15 TD= 10,550'MD (9,768'ND) Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date Br2ORD-42 191-020 50-733-20443-01 1/15/15 2/13/15 Daily Operations: 01/15/15-Thursday Arrive at Bruce platform.Start JSA, hot work,and permit to work. Finish ISA, hot work, and permit to work. Prejob meeting with production. R/U spot equipment. R/u tool string and lub.Stand by for production to P/T to 1000 psi, pass. RIH WI 2.34 gauge ring to 5,802' WLM. POOH. RIH W/2.5 GS 5,802' WLM, latch AA stop. POOH with AA stop. RBIH to 5,803'WLM, pull top patch. Pulled up 5'.Stand-by for seal ring to relax. POOH. OOH rubber was washed out. RBIH to 5,816'WLM, pull bottom patch.OOH with bottom section of patch. RBIH to 5,839'WLM. Pull AD2 stop.OOH with AD-2 stop. RIH W/2.34 gauge ring to 8,978'WLM. OOH. RIH W/1.50 SB to 8,978'WLM to pull pump. Latched, pulled up 200'dropped. Ran back down, latched, pulled up 100'dropped could not re-latch. KOBE pump pulling tool threads were gaulded.OOH no pump. 1 dawg on 1.5 SB was shucked.Secure well for night. Clean work area. Finish paperwork. 01/16/15-Friday Start JSA, hot work,and permit to work. Morning safety meeting. Redress bottom Weatherford 2.8 pack-off. (2)225 o-rings for receptacle on patch.Stand up LUB.Attach pulling tool. RIH W/1.5 O'BANON over shot pump pulling tool. Ran baited to a 2"JDC to 8,972'wlm. Production pumped fluid from bottom to help off seat pump.Stand down for hydraulics to cool down. Hydraulics cooled. Continue having production pump oil, held 1200 lbs on wire. POOH w/pump. OOH w/pump, cut 10'wire off. Re-tie rope socket. RIH WI KOBE knock-out 8,992'wlm.OOH. RIH W/stand-in valve pulling tool 8,992'wlm. OOH. RIH W/1.75 blind box to tap in stand-in valve to 8,992'wlm.OOH.Assist production in dropping pump. RIH W 2.5 GS w/AD2 stop to 5,839'wlm. POOH sheared @ 5,900'wlm. RBIH to 5,900'wlm latch AD2 stop, pull up to 5,839'wlm.OOH . Clean work area. Secure well for night. Pull 190'of wire off and re-tie rope socket. Finish paperwork for night. 01/17/15-Saturday Start ISA, hot work,and permit to work. Finish paperwork. Morning meeting.Stand up LUB.Attach pulling setting/pulling tool. RIH W/2.5 GS w/bottom patch set at 5,818'wlm. OOH. RBIH w/top patch set at 5,804'wlm.OOH. RBIH w/AA stop set at 5,803'wlm. OOH. Lay down LUB.Turn well over to production for flow test. Stand by for production. Finish rigging down and stand by for chopper. 01/19/15-Monday Arrive at Bruce platform.Start JSA, hot work and permit to work. Prejob meeting. Rig up lub tools and stab on xo. Finish rig up. P/T to 1000 psi, pass. RIH W/2.5 GS to 5,803'WLM, pull AA stop. OOH. RBIH to 5,804'WLM, pull top patch. Patch pulled.Stand-by and let element relax.OOH w/patch. RBIH to 5,818'WLM, pull bottom patch. Patch pulled.Stand-by and let element relax. OOH w/patch. RBIH to 5,839' WLM to AD2 stop, pull up 5'. OOH. Lay down for night.Secure well. Clean work site. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date Br20RD-42 191-020 50-733-20443-01 1/15/15 2/13/15 Daily Operations: 01/20/15-Tuesday Start JSA, hot work and permit to work. Morning safety meeting. Finish JSA, hot work and permit to work. RIH W/2.5 GS to 5,813'WLM w/bottom patch sat down @ 5,810'WLM. POOH.00H. RBIH to 5,834'WLM pull AA stop. OOH, repin AD2 stop. RBIH to 5,837'to set AD2 stop.Sat down @ 1,700'WLM,sheared GS. POOH. OOH re-tie rope socket. RBIH to 1,700' WLM pull AD2 stop.OOH. RBIH W/AD2 stop to 5,837'WLM.Sat down @ 1,350'WLM. OOH. RIH W/2.25 LIB ran to 6,000' WLM, no marks. OOH. RIH W/2.5 GS w/AD2 stop to 5,837'WLM sat down @ 385' WLM, POOH. OOH repin AD2 stop w/ 3/16 brass. RBIH to 5,837'WLM sat down @ 1,067'WLM. OOH repin w/3/16 brass and added a 2' prong to GS. RBIH W/ AD2 set @ 5,837' WLM. OOH. RBIH W/bottom patch set @ 5,814'WLM.OOH. RBIH WI top patch set @ 5,801'WLM. OOH. RBIH W/AA stop set @ 5,800'WLM. OOH. Turn over to production to bundle test well.Get equipment ready to rig down. Pump failed. Lay down for night.Clean work site. 01/21/15-Wednesday Morning safety meeting. Finish JSA, hot work and permit to work. Re-tie rope socket, redress oil jars. Stab on LUB. RIH WI 2.5 GS to 5,800' WLM. Pull AA stop. OOH WI AA stop. RBIH to 5,801'WLM. Pull top patch.00H WI top patch. RBIH to 5,814'WLM. Pull bottom patch. OOH WI bottom patch. RBIH to 5,837'WLM. Pull AD2 stop. OOH W/AD2 stop. RIH WI O'Bannon pulling tool to 8,972'WLM. OOH WI pump. RIH WI Kobe knock-out to 8,992'WLM. OOH. RIH WI SV valve pulling tool to 8,992'WLM. OOH WI no SV. RBIH WI SV pulling tool to 8,992'WLM. 00H. Pull SV. RIH W/SV setting tool to fluid shake off. OOH, SV is set. RIH WI 1.75 blind box to 8,992'WLM.Tap valve in.OOH. RIH W/1"JDC w/pump run to 8,972'WLM.Tapped down lightly&Sheer off. OOH. Lay down for night. Secure well. Clean work site. Finish closeout paperwork.Send off daily reports. 01/22/15-Thursday JSA, Hot work permits& Morning meeting. Finish paperwork.Stab on Lub. RIH w/GS w/ AD2 stop set @ 5,837'WLM. OOH. RBIH w/bottom patch set @ 5,874'WLM. OOH. Clean GS repin. RBIH w/top patch set @ 5,801'WLM.OOH. Repin GS. RBIH w/AA stop set @ 5,800'WLM. OOH. Lay down Lubricator&turnover to Production for bundle testing long& short string tubing. Stand by and clean up. 02/02/15-Monday Rig up lub and tool string. Stab on lub p/t to 1000 psi. RIH W 2.35 Gauge Ring to 5,800'WLM. OOH. ( F/L @ 3,065' ). RBIH to 5,802'WLM. Pull top patch. Pulled, let relax for 30 min. OOH w top patch. RBIH to 5,817'WLM. Pull bottom patch. Pulled, let relax for 30 min. OOH W bottom patch. RBIH to 5,837'WLM. Pull AD2 stop. OOH w AD2 stop. RBIH to 8,972' WLM pull pump. OOH w pump. Rig down for night. Clean work area. Finish paperwork. 02/03/15-Tuesday Morning safety meeting. Stand up lub and rig up caliper.Stab on lub, run down to 6,300'WLM. Log up to 5,500'WLM. OOH stand-by to analyze data. RIH W Kobe knockout tool to 8,992'WLM. OOH. RIH W standing valve pulling tool to 8,992' WLM.OOH, no valve. RBIH. OOH, no valve. RBIH.OOH, no valve. RIH W 1.5 pump bailer to 8,992'WLM. 00H,some metal and sheared Kobe knockout. RIH W standing valve pulling tool to 8,992'WLM. OOH, no valve. Laydown for night. Clean work area. Finish paperwork. Hilcorp Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date Br2ORD-42 191-020 50-733-20443-01 1/15/15 2/13/15 Daily Operations: 02/04/15-Wednesday JSA, hot work and permit to work. Morning safety meeting.Cut off 20'of wire, re-tie rope socket. RIH W standing valve pulling tool to 8,992'WLM. OOH w valve. RIH w 2.40 brush. OOH let production flush well. RIH W 1.75 blind box. Chase standing valve down to 8,992'WLM.Tap in valve. OOH set. RIH W 1 3/8 JDC w pump to 8,972'WLM.Tap in. OOH set. RIH W 2.5 GS w AD2 stop to 5,837'WLM. OOH set. RBIH to 5,817'WLM, 24' bottom patch. OOH set. RBIH to 5,796'WLM, 21' spacer pipe. OOH set. RBIH to 5,776'WLM, 21'spacer pipe. OOH set. RBIH to 5,762'WLM, 13'top patch. OOH set. RBIH to 5,760'WLM w AA stop.OOH set. Laydown for night. Clean work area. Finish paperwork.Note: patch @ 5,760'WLM to 5,837'WLM. 02/05/15-Thursday JSA hot work and permit to work. Morning safty meeting.Take off 4-bolt XO.Turn well over to production for testing. Stand-by for production. Rig down. Clean work area. 02/11/15-Wednesday Start rigging up equipment. Pick up lubricator M/U 2 1/2 GS stab on well P/T to 1500 psi test good. RIH w/GS pull top AA- stop. OOH retrieve stop. RBIH latch top packoff sheered tool POOH. OOH repin tool. RBIH latch top packoff POOH. OOH retrieve TPO. RBIH pull spacer pipe. OOH retrieve spacer pipe. RBIH pull BPO.OOH retrieve BPO. RBIH pull AD-2 stop. M/U pump pulling tool. RIH w/pump pulling tool pull pump. OOH w/pump M/U Kobe knockout tool. RIH w/Kobe knockout tool. OOH secure well clean up tools SDFN. 02/12/15-Thursday Fill out JSA and work permits. Morning safety meeting. Rebuild and redress packoffs. Pick up lubricator M/U standing valve pulling tool.Stab on well,open well,still on vacuum,wait for well to equal. RIH w/standing valve pulling tool able to latch and over pull but kept slipping off.OOH no valve.Check tool and replace pulling prong. RBIH able to latch and overpull still won't come free,work tool POOH. OOH, no valve. File shoulders on prong spread fingers rerun. RBIH still able to latch and overpull but won't come free keeps slipping off.OOH take off guide prong leaving only pulling prong on re run. RBIH able to latch and overpull still wont come free work tool POOH. OOH M/U 1.75 bailer. RIH work tool POOH. OOH Kobe knockout retrieved and gritty fluid sludge. RIH with standing valve spear. OOH w/standing valve SDFN secure well clean up tools and work area. 02/13/15-Friday Fill out JSA and work permits.Attend morning safety meeting. RIH with standing valve.Shake off in fluid POOH. OOH M/U tap in tool. RIH sat down at 6,350'wlm unable to go down POOH. OOH M/U standing valve pulling tool. RIH latch valve @ 6,350' POOH.OOH M/U 1.75 magnet. RIH down to 9,035'wlm POOH.OOH retrieve metal standing valve guts. RBIH w/ new standing valve shake off in fluid POOH. OOH M/U tap in tool. RIH tap valve in place @ 9,002'wlm POOH. OOH M/U 1 3/8 JDC pick up pump. RIH w/pump set in Kobe cavity POOH. OOH M/U GS. RIH w AD2 stop set @ 5,837 wlm POOH. OOH. RIH w/bottom packoff set @ 5,817'wlm POOH. OOH pick up spacer pipe. RIH w/20 ft spacer pipe set @ 5,796 wlm POOH.OOH pick up spacer pipe. RIH w/20 ft spacer pipe set @ 5,776'wlm POOH. OOH pick up top pack off. RIH w/13 foot top packoff set @ 5,762'wlm POOH. OOH pick up AA stop. RIH w/AA stop set @ 5,760'wlm POOH. OOH secure well clean up tools SDFN. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢/"~_~ File Nu m ber of We il History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED .[3' Logs 'of vadous kinds . n Other COMMENTS: C! Scanned by: Beverly Di~n Lowell , , TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: • I E S.rr r,/ � �� \ /7ji� I �AT st _ 333 VNest Seven h A Enue G0V'E1:\:01-1 ST-.^.N RNF.i(. Anchorage Aloka 99`01 3572 ion ( '9 433 E?j,� u,�a F•e^• F: SCANNED JUL 1 6 203 did Dan Taylor L Operations Engineer "I 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granit Point Field, Middle Kenai Oil Pool, Granite Point ST 18742 2ORD (BR 2ORD-42) Sundry Number: 314-327 Dear Mr. Taylor: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this day of May, 2014. Encl. �C "�\k V • STATE OF ALASKA `SY; ��� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspend 0 Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑ Alter Casing 0 Other. Install Patch/Chg PumD 0• 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory 0 Development 9 • 191-020- 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 0 Service ❑ 6.API Number Anchorage,AK 99503 50-733-20443-01 - 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A / r o.c-`" Will planned perforations require a spacing exception? Yes ❑ No❑ Granite Point ST 18742 20RD•(BR 20RD-42) 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742• Granite Point Field/Middle Kenai Oil Pool, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,550• 9,768* 9,688• 9,018 • 10,198' 9,688 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,584' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,974' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 4,032' 7" 6,513'-10,545' 6,366-9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' See Schematic/ See Schematic SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal 0• 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/2/2014 Oil 0• Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dta for hilcorp.com Printed Name Dan Tam` Title Operations Engineer Signature — .... +— Phone 907 777-8319 Date 5/20/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31i-k.-32-1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No `W Subsequent Form Required: / 0 -- Li 0 y APPROVED BY Approved by: COMMISSIONER THE COMMISSION-rmDate •25:"/L L/� ///� �I�I�� Submit Form and Form 10-403(Revised 10/2012) ApprOy2 deal iNlikt months from the date of approval. ^ D"PVr 2 3 234 Well Prognosis Well: Br 20RD-42 Hileoro Alaska,LU Date:5/20/2014 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: June 2,2014 Rig: N/A Reg.Approval Req'd? N/A Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Daniel Taylor (907) 777-8319(0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907)777-8421 (0) AFE Number: Current Bottom Hole Pressure: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: -2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Max.Allowable Surface Pressure: -358 psi 3,000psi-(0.354*TVD* 1/3+0.1 *TVD" 2/3) Brief Well Summary Druce 20RD-42 was drilled and completed in 1991 as a Tyonek C-7 and C-8 producer. On 5/93 the well was worked over and the Tyonek-C-5 and C-6 intervals were perforated with TCP guns. This work resulted in an increase of mainly water. On 11/19/99 the TCP guns were cut and dropped down hole to allow for a re-perforation of the existing Tyonek intervals. The planned work consists of changing out the pump in tie jet pump cavity. This will entail pulling and reinstalling the patch that is currently set over the interval 5,814 ft to 5,840 ft. Procedure: 1. Rig up slick line unit. 2. Rig up wireline valves, lubricator, pack-off,and line wiper. a. Test lubricator and pack-off to 1,000psi. 3. Rig up 2.5"gauge ring and run in hole to top of patch.' 4. Pull out of hole, rig down gauge ring and rig up pack off latch. • 5. Pick up and run in hole with pack off latch, latch pack off and pipe.. 6. Pull out of hole with latch assembly, pack off and spacer pipe and lay down the same. 7. Pick up and run in hole with latch to retrieve AD-2 stop. 8. Latch bottom AD-2 stop and pull out of hole. 9. Pick up and run in hole with pump latch assembly to+/-9,013 ft. 10. Pull out of hole with jet pump and lay down the same. 11. Pick up and run in hole with standing valve pulling tool. 12. Pull out of hole with standing valve and lay down the same. 13. Pick up and run in hole with rebuilt standing valve and pull out of hole. 14. Pick up and run in hole with rebuilt jet pump and pull out of hole. . 15. Pick up and run in hole with AD-2 stop and set at+/-5,845 ft. 16. Set AD-2 stop and pull out of hole. 17. Pick up and run in hole with pack off and patch pipe. 18. Set pack off at+/-5,814 and pull out of hole. 19. Rig down slick line and lubricator. 20. Operations to bundle test system. 21. Turn well over to production. Attachments: 1. As-built Well Schematic/Proposed Well Schematic(No Change) .. H SCHEMATIC Bruce Platform Well # Br 20RD-42 Hilcorp Alaska.LLC Completed: 5/16/93 CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# 1-55 12.615" Surface 1,584' 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' 1 A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. 4 (Wireline patch JEWELRY DETAIL ssla'- NO. Depth ID OD Item 5,840'\ ' - ? 44.95' Tubing Hanger,C.I.W. SM x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"`Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID i 8 9,078' 2)Firing Heads B 9 9,082' Blank X X 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P L , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"30 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments larC-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns 11E C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns tII 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. ll 4 --_-= 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 2"PowerJet w/Spec. C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns • 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns M 8 gab C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns w 9 no 10 *J+41Y-. ."a'Z7,1i0 PBTD=9,688'MD 9,018'(TVD) Updated by: 1LL 02/24/14 TD=10,550'MD (9,768'TVD) .t • Schwartz. Guy L (DOA) From: Schwartz,Guy L(DOA) Sent Thursday, May 22, 2014 4:15 PM To: 'Daniel Taylor' I`r I Subject: RE: Bruce 2ORD-42 (PTD429-1=020) tubing patch oK... thanks . Could you start putting the Pressure test (bundle test)against SV in the procedure. I was pretty sure you were doing them but they should be mentioned in the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Daniel Taylor [mailto:dtaylor@hilcorp.com] Sent:Thursday, May 22, 2014 4:09 PM To: Schwartz, Guy L(DOA) Subject: RE: Bruce 2ORD-42 (PTD 1291-020)tubing patch Guy, Yes sir. We have attempted to get several bundle tests on the Br 2ORD-42 and have not as of yet been able to. We are unable to produce this well at its full potential due to tubing leaks. The fluid level has not been drawn down to cavity for some time because of this. On the jet pump wells that do not have tubing leaks it is standard to get a bundle test on the standing valve before bringing the well on. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz(aalaska.gov] Sent:Thursday, May 22, 2014 4:03 PM To: Daniel Taylor Subject: Bruce 2ORD-42 (PTD 1291-020) tubing patch Daniel, 1 • j In your procedure to reset the tubing patch is there a way to verify tubing integrity r I would think by closing in the powerfluid side and pressurizing up the production( long string)you could test against the standing valve. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 • ,§'�'\\w 7 THE STATE C e '. Cal (j iv /,_ 77- 1 1 Y -%' �� __ _ lrst� 333 West Seventh Avenue GOVERNOR SEAN PARNEI.[, Anchorage, Alaska 99501 3572 Main 907.2 9 1 433 1J.� no, °V.2 Stan Porhola SCANNED MAY 16 2014 Operations Engineer O Hilcorp Alaska, LLC Q 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point ST 18742 2ORD (BR 2ORD-42) Sundry Number: 314-021 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, p Cathy P oers er Chair DATED this day of January, 2014. Encl. ! . w STATE OF ALASKA ,�,�� �, t • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate El Atter Casing El Other. Install Patch/Chg Pump 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 ^ 191-020 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20443-01 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A &Ruc� et-C4-1 Will planned perforations require a spacing exception? Yes ❑ No ❑ Granite Point ST 18742 2ORD (BR 2ORD-42) t 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742. Granite Point Field/Middle Kenai Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,550. 9,768 . 9,688 • 9,018 • 10,198' 9,688 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,544' 13-3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,936' 9-5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 1,896' 7" 6,513'-10,545' 6,365'-9,764' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): LS 2-7/8" 6.4#/N-80 9,013' SS 3-1/2" 9.2#/N-80 6,457' See Schematic ' See Schematic SS 2-3/8" 4.6#/N-80 9,011' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal 2 4 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/13/2014 Oil 2 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the bes of my knowledge. Contact Dan Taylor Email dtayiorahiicorp.com Printed Name Dan Ta for.----- Title Operations Engineer Signature � Phone 907 777-8319 Date 1/10/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: %\14.— 0 T Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDM' ' ' , AY 09 2014 Spacing Exception Required? Yes ❑ No X Subsequent Form Required: `. Q Ll 1 d — APPROVED BY Approved by: 29177'itt COMMISSIONER THE COMMISSION Date: h/ 7_/ /C � fga t I Submit Form and Form 10-403(Revised 10/2 2) Apprgre�l Rills&INdAtnonths from the date of appurov I. Attachments in Duplicate "1110 �Vv £,;/lam 14 : - Well Prognosis Well: Br 2ORD-42 llilcorp Alaska,LL, Date: 1/10/2014 Well Name: GRANITE PT ST 18742#20RD API Number: 50-733-20443-01 Current Status: Oil Producer Leg: 1 Estimated Start Date: January 13, 2014 Rig: N/A Reg.Approval Reqd? N/A Date Reg. Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-020 First Call Engineer: Dan Taylor (907) 777-8319 (0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: -2,000 psi at 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: - 3,000 psi at 8,977 ft TVD Based on 40°API and fluid level at 400 ft(3/5/2012) and Mid-Pert at 8,977 ft. Max. Allowable Surface -342 psi Based on 2/3 gas filled and 1/3 fluid Pressure: filled well with gradients= 8.825psi/ft and 0.1 psi/ft to Mid-Pert at 8,977 ft. Brief Well Summary Bruce 0RD-42 was drilled and completed in 1991 as a Tyonek C-7 and C-8 producer. On 5/93 the well was worked over and the Tyonek C-5 and C-6 intervals were perforated with TCP guns. This work resulted in an increase of mainly water. On 11/19/99 the TCP guns were cut and dropped down hole to allow for a re- perforation of the existing Tyonek intervals. The planned work consists of changing out the pump in the jet pump cavity. This will entail pulling and reinstalling the patch that is currently set over the interval 5,840 ft to 5,859 ft. Production will test short and long string for integrity. There is a suspected leak in the short string. Should a leak be found, an additional patch will be installed. Procedure: 1. Rig Up Slick line lubricator on well head. a. Pressure test to 2000psi. 2. Run in hole with 2.30in gauge ring to top of AA stop at 5,825 ft. a. Pull out of hole. 3. Run in hole with 2'Ain GS pulling tool and retrieve top AA stop at 5,825 ft. a. Pull out of hole. 4. Run back in hole with 2'Ain GS pulling tool and retrieve top pack off and spacer pipe. a. Pull out of hole. 5. Run back in hole with 2'Ain GS pulling tool and retrieve bottom pack off. a. Pull out of hole. 6. Run back in hole with 2%A GS pulling tool and retrieve AD2 stop at 5,853 ft. a. Pull out of hole. 7. Run in hole with KOBE pump pulling tool and retrieve pump. a. Pull out of hole. 8. Run in hole with KOBE equalizing Prong to SV and equalize. • Well Prognosis • Well: Br 20RD-42 Hiicoru Alaska,LL Date: 1/10/2014 a. Pull out of hole. 9. Run in hole with pulling Prong and pull SV at 9,013 ft. a. Pull out of hole. 10. Run in hole with new SV and set at 9,013 ft. a. Pull out of hole. 11. Run in hole with KOBE Pump. a. Pull out of hole. 12. Run in hole with AD2 stop and set at 5,853 ft. a. Pull out of hole. 13. Run in hole with bottom packoff and set on top of AD2 stop at 5,853 ft. a. Pull out of hole. 14. Run in hole with top packoff and spacer pipe and set. a. Pull out of hole. 15. Run in hole with top AA stop and set in well at 5,825 ft. a. Pull out of hole. 16. Test string with fluid to 1000psi and monitor for leakage to verify patch is holding. 17. If Test is good rig down off well and turn well back over to production. a. If test is bad repeat steps 3-6 and steps 12-15. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic SCHEMATIC Bruce Platform 11 Well # Br 20RD-42 Completed: 5/16/93 Hilcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.55 1-55 12.615" Surface 1,584' 1 / 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' ! A 7"Liner 29,32# N-80&5 95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.45 N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-80 Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Installed patch JEWELRY DETAIL 5,825' NO. Depth ID OD Item 5,853'\-.. , - - 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank X X 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') Short String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P Z , B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Top) Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @+/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns , III I I C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns I 1 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 ram2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. ��" 5 C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C-7 9,713' 9,73V 9,041' 9,056' 18' 8 4/9/1991 TCP Guns 0 C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns . `, • 8 . C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns +N C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns L.` • 9 ., 10 Updated by: JLL 07/25/13 PBTD=9,688'MD 9,018'(TVD) TD=10,550'MD (9,768'TVD) PROPOSED Bruce Platform 11 Well # Br 20RD-42 Completed: 5/16/93 Hilrora Alaska,LLC CASING AND TUBING DETAIL API#50-733-20443-01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head=44.95' 13-3/8" 54.5# J-55 12.615" Surface 1,584' 1 9-5/8" 40,43.5# S-95&N-80 8.755" Surface *6,974' A 7"Liner 29,32# N-80&S-95 6.094" 6,513' 10,545' Tubing Long String 2-7/8" 6.4# N-80 Buttress 2.441" 47' 9,013' Short String 3-1/2" 9.2# N-SO Buttress 2.992" 48' 6,457' 2-3/8" 4.6# N-80 Buttress 1.995" 6,458' 9,011' *Note for 9-5/8"Casing-6,974'is top of window. L Install patch JEWELRY DETAIL 5,825'- NO. Depth ID OD Item 5,853' - - .. 44.95' Tubing Hanger,C.I.W. 5M x 3-1/2"x 10"Dual 1 45.85' X-Over,3-1/2"Butt.X 2-7/8"Butt.X 2',P x P 2 9,013' 2.441 2.875 X-Over,2-7/8"Butt.Box x 2-7/8" 8rd.EUE Pin .. ` 3 9,013' 2.250 5.625 Kobe,2-1/2"'Dbl B',Cavity S/N 93-5-5 4 9,032' 2.441 2.875 2-7/8"N80,8rd Pup x 10' 5 9,043' 2-7/8"Isolation x 2' 6 9,045' X-Over,2-3/8"X 2-7/8" 8rd P X B 7 9,045' 1.56 4)2-3/8"N-80 8rd Pups(33')w/no-go 1.56"ID 8 9,078' 2)Firing Heads B 9 9,082' Blank 10 9,085' 4.625 4-5/8"O.D.Vann TCP Guns(425') VShort String A 45.85' X-Over,3-1/2"TDS x 3-1/2" Butt.P x P L .. B 6,457' 1.995 X-Over,2-3/8"Butt x 3-1/2"TDS P x B C 9,011' X-Over,1-1/4"10 rd.Pin x 2-3/8"Buttress Box x 1.4'long Fish NO. Depth(Tool Length Item I 9,754' 469' 11/19/99-Cut off 425'TCP guns plus tubing,etc.above for total of 469'. Tubing cut @-i-/-9,041'=2'above isolation sub @ 9,043'up in the 10'pup joint. Last tag was 2/14/00 @ 9754'w/ 2"LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (ND) (ND) Amt SPF Date Comments C-5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4-5/8"TCP Guns all=MII C-5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4-5/8"TCP Guns 3 ° ' C-6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4-5/8"TCP Guns U_Iu. 2"PowerJet w/Spec. C-7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 _1_ 2"PowerJet w/Spec. C-7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2"PowerJet w/Spec. 4 C-7 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. C-7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns C-7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C-7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 1 M '.,], C-7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns A 13\ C-7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns \ C-8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns PBTD=9,688'MD 9,018'(TVD) Updated by: JLL 01/10/14 TD=10,550'MD (9,768'TVD) • • OF Zitt / , � s T HE STATE Oil and Gas • i �i Alaska a G ti , ®f KA Conservation Commission s T I GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA, ALAS pv 201 Ancho Alaska 99501 -3572 SCANNED JUN 2 4 Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor O � Operations Engineer 1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point ST 18742 2ORD Sundry Number: 313 -297 Dear Mr. Taylor: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this GI day of June, 2013. Encl. • • `` d r STATE OF ALASKA b 6! 9�/ ALASKA OIL AND GAS CONSERVATION COMMISSION - i ..'; APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ IOther. Install Patch 51 ` 2. Operator Name: 4. Current Well Gass: 5. Permit to DM Number. 4- Hilcorp Alaska, LLC Exploratory El Development p - 191 -020 - _d" 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20443-01 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Granite Point ST 18742 20RD (AKA Br 20RD -42) - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018742 s Granite Point Field / Middle Kenai Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): . 10,550 - 9,768 9,688 9,018 10,198' 9,688 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,544' 13 -3/8" 1,584' 1,584' 2,730 psi 1,130 psi Intermediate Production 6,936' 9 -5/8" 6,974' 6,818' 6,330 psi 3,810 psi Liner 1,896' 7" 6,513'- 10,545' 6,365'- 9,764' 8,160 psi 7,020 psi Perforation Depth MD (ft): • Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): LS 2 -7/8" 6.4# / N -80 9,013' SS 3-1/2" 9.2# / N -80 6,457' See Schematic See Schematic SS 2 -3/8" 4.6# / N -80 9,011' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal 51 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 51- Service ❑ 14. Estimated Date for 6/15/2013 15. Well Status after proposed work: Commencing Operations: Oil 51 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan Taylor -'� Title Operations Engineer Signature <',; �L_,. •'�`/ - P�'� Phone 4 07 777 -8319 Date 6/12/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: A J UN RBDMS 212013 Spacing Exception Required? Yes ❑ No f!d Subsequent Form Required: /D - tidy APPROVED BY Approved by:a i i 3 9 COMMISSIONER THE COMMISSION Date: G -2/ - (3 Submit Form and ') \\ Form 10-403 Revised 10/2012) A v t n i aid r I: months f the d ate a m y � tz4 _pt t8chments in Duplicate 4 � � ( ) pp �� l approval. f7 fT�//'� • • Well Prognosis Well: Br 20RD -42 Hilcorp Alaska, LL Date: 6/12/2013 Well Name: GRANITE PT ST 18742 #20RD API Number: 50- 733 - 20443 -01 Current Status: Oil Producer Leg: 1 Estimated Start Date: June 15, 2013 Rig: N/A Reg. Approval Req'd? N/A Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 191 -020 First Call Engineer: Dan Taylor (907) 777 -8319 (0) (907) 947 -8051 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: Current Bottom Hole Pressure: - 2,000 psi @ 8,977 ft TVD Anticipated reservoir pressure based on surrounding well history. Maximum Expected BHP: - 3,000 psi @ 8,977 ft TVD Based on 40 °API and fluid level @ 400 ft (3/5/2012) and Mid -Perf @ 8,977 ft. Max. Allowable Surface - 2,102 psi Based on gas filled well with Pressure: gradient = 0.1 psi /ft to Mid -Pert @ 8,977 ft. Brief Well Summary Bruce 20RD -42 was drilled and completed in 1991 as a Tyonek C -7 and C -8 producer. On 5/93 the well was worked over and the Tyonek C -5 and C -6 intervals were perforated with TCP guns. This work resulted in an increase of mainly water. On 11/19/99 the TCP guns were cut and dropped down hole to allow for a re- perforation of the existing Tyonek intervals. The planned work consists of changing out the pump in the jet pump cavity. This will entail pulling and reinstalling the patch that is currently set over the interval 5,638 ft to 5,658 ft. Production will test short and long string for integrity. There is a suspected leak in the short string. Should a leak be found, an additional patch will --- be installed. O Procedure: 1. Rig up lubricator onto long string. Pressure test lubricator to 3,000psi. 2. Rig up slick line unit. 3. Rig up 2.5" gauge ring and run in hole to top of patch at +/- 5,638 ft: 4. Pull out of hole, rig down gauge ring and rig up pack off latch. 5. Pick up and run in hole with pack off latch, latch pack off and pipe at +/- 5,638 ft. • 6. Pull out of hole with latch assembly, pack off and spacer pipe and lay down the same. 7. Pick up and run in hole with latch to retrieve AD -2 stop at +/- 5,658 ft: 8. Latch bottom AD -2 stop and pull out of hole. 9. Pick up and run in hole with pump latch assembly to +/- 9,013 ft. 10. Pull out of hole with jet pump and lay down the same. 11. Pick up and run in hole with standing valve pulling tool. 12. Pull out of hole with standing valve and lay down the same. 13. Pick up and run in hole with rebuilt standing valve and pull out of hole. 14. Pick up and run in hole with rebuilt jet pump and pull out of hole. 15. Pick up and run in hole with AD -2 stop to +/- 5,658 ft. 16. Set AD -2 stop and pull out of hole. 17. Pick up and run in hole with pack off and patch pipe. 18. Set patch and pull out of hole. 1E4 • • Well Prognosis Well: Br 2ORD -42 Hilcorp Alaska, LL Date: 6/12/2013 19. Rig down slick line and lubricator. 20. Operations to bundle test system. a. Should bundle test fail slick line will set plugs in both long and short string to identify which string is leaking. b. Upon identifying leaking string slick line will run hole finder. / c. Patch will be installed over compromised section of tubing. V i. Refer to step 15 to 18 for patch installation. 21. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic • • Bruce Platform , , 14 SCHEMATIC Well # Br 20RD -42 Completed: 5/16/93 Hilcorp Alaska, LLC CASING AND TUBING DETAIL API # 50- 733 - 20443 -01 SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 44.95' 13 -3/8" 54.5# 1 -55 12.615" Surface 1,584' 1 / 9 -5/8" 40, 43.58 S -95 & N -80 8.755" Surface *6,974' A 7" Liner 29, 32# N -80 & S-95 6.094" 6,573' 10,545' Tubing Long String 2 -7/8" 6.4# N -80 Buttress 2.441" 47' 9,013' Short String 3 -1/2" 9.28 N -80 Buttress 2.992" 48' 6,457' r, ly 2 -3/8" 4.6# N -80 Buttress 1.995" 6,458' 9,011' !j * Note for 9 -5/8" Casing - 6,974' is top of window. L Tubing Patch JEWELRY DETAIL 5,638' 5,658' NO. Depth ID OD Item \ - . - 44.95' Tubing Hanger, C.I.W. 5M x 3 -1/2" x 10" Dual 1 45.85' X -Over, 3 -1/2" Butt. X 2 -7/8" Butt. X 2', P x P 2 9,013' 2.441 2.875 X -Over, 2 -7/8" Butt. Box x 2 -7/8" 8rd. EUE Pin 3 9,013' 2.250 5.625 Kobe, 2 -1/2" 'Dbl B', Cavity S/N 93 -5 -5 4 9,032' 2.441 2.875 2 -7/8" N80, 8rd Pup x 10' 5 9,043' 2 -7/8" Isolation x 2' 6 9,045' X -Over, 2 -3/8" X 2 -7/8" 8rd P X B 7 9,045' 1.56 4) 2 -3/8" N -80 8rd Pups (33') w/ no -go 1.56" ID ! / 8 9,078' 2) Firing Heads B 9 9,082' Blank IX 1. 10 9,085' 4.625 4 5/8" O.D. Vann TCP Guns ( 425') Short String A 45.85' X -Over, 3 -1/2" TDS x 3 -1/2" Butt. P x P L B 6,457' 1.995 X -Over, 2 - 3/8" Butt x 3 -1/2" TDS P x B C 9,011' X -Over, 1 -1/4" 10 rd. Pin x 2 -3/8" Buttress Box x 1.4' long Fish NO. Depth (Topl Length Item I 9,754' 469' 11/19/99 - Cut off 425' TCP guns plus tubing, etc. above for total of 469'. Tubing cut @ +/- 9,041' = 2' above isolation sub @ 9,043' up in the 10' pup joint. Last tag was 2/14/00 @ 9754' w/ 2" LIB. PERFORATION DETAILS , Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments M, C -5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4 -5/8" TCP Guns ■II1� - ' f C -5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4 -5 /8" TCP Guns 3 � E) ! C -6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4 -5/8" TCP Guns IIN=INM■1■ 2" PowerJet w/ Spec. C -7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 - _ - 2" PowerJet w/ Spec. ei C -7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 4 F 2" PowerJet w/ Spec. C -7 9,653 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 C -7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C -7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns . C -7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 C -7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 'Mt 8 o C -7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C -8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns • 10 A .. 1N Updated by: JLL 06/07/13 PBTD = 9,688' MD 9,018' (TVD) TD = 10,550' MD (9,768' TVD) • • Bruce Platform 11 PROPOSED W ell # Br 20RD -42 a Alaska, Completed: 5/16/93 H core A , c�c CASING AND TUBING DETAIL API # 50 - 733 - 20443 - SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Head = 44.95' 13 -3/8" 54.5# J -55 12.615" Surface 1,584' 1 / 9 -5/8" 40,43.5# S -95 & N -80 8.755" Surface *6,974' A 7" Liner 29, 32# N -80 & S-95 6.094" 6,513' 10,545' Tubing Long String 2 -7/8" 6.4# N -80 Buttress 2.441" 47' 9,013' Short String 3 -1/2" 9.2# N -80 Buttress 2.992" 48' 6,457' 2 -3/8" 4.6# N -80 Buttress 1.995" 6,458' 9,011' * Note for 9 -5/8" Casing - 6,974' is top of window. Reinstall J patch JEWELRY DETAIL ±5,638 - ±5 658' NO. Depth ID OD Item , - 44.95' Tubing Hanger, C.I.W. 5M x 3 -1/2" x 10" Dual I 1 45.85' X -Over, 3 -1/2" Butt. X 2 -7/8" Butt. X 2', P x P �_ 2 9,013' 2.441 2.875 X -Over, 2 -7/8" Butt. Box x 2 -7/8" 8rd. EUE Pin .. .. 3 9,013' 2.250 5.625 Kobe, 2 -1/2" 'Dbl B', Cavity S/N 93 -5 -5 4 9,032' 2.441 2.875 2 -7/8" N80, 8rd Pup x 10' 5 9,043' 2 -7/8" Isolation x 2' 6 9,045' X -Over, 2 -3/8" X 2 -7/8" 8rd P X B 7 9,045' 1.56 4) 2 -3/8" N -80 8rd Pups (33') w/ no -go 1.56" ID 8 9,078' 2) Firing Heads / B 9 9,082' Blank C . _ , ` ' 10 9,085' 4.625 4 - 5/8" O.D. Vann TCP Guns ( 425') X X Short String A 45.85' X -Over, 3 -1/2" TDS x 3 -1/2" Butt. P x P Z. , B 6,457' 1.995 X -Over, 2 -3/8" Butt x 3 -1/2" TDS P x B C 9,011' X -Over, 1 -1/4" 10 rd. Pin x 2 -3/8" Buttress Box x 1.4' long Fish NO. Depth (Top) Length Item I 9,754' 469' 11/19/99 - Cut off 425' TCP guns plus tubing, etc. above for total of 469'. Tubing cut @ +/- 9,041' = 2' above isolation sub @ 9,043' up in the 10' pup joint. Last tag was 2/14/00 @ 9754' w/ 2" LIB. PERFORATION DETAILS Top Btm Top Btm 2 C Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Comments C -5 9,085' 9,140' 8,557' 8,598' 55' 5/16/1993 4 -5/8" TCP Guns ■1111• C -5 9,170' 9,236' 8,620' 8,668' 66' 5/16/1993 4 -5/8" TCP Guns 3 MOW C -6 9,475' 9,510' 8,848' 8,876' 35' 5/16/1993 4 -5/8" TCP Guns MIIIIIIIIIIM■I• 2" PowerJet w/ Spec. C -7 9,585' 9,623' 8,936' 8,967' 38' 12 2/14/2000 Phs. 4 M_ 2" PowerJet w/ Spec. C -7 9,632' 9,640' 8,974' 8,981' 8' 12 2/14/2000 Phs. 2" PowerJet w/ Spec. 4 C - 9,653' 9,680' 8,992' 9,014' 27' 12 2/14/2000 Phs. 5 C -7 9,680' 9,698' 9,014' 9,028' 18' 8 4/9/1991 TCP Guns 6 C -7 9,713' 9,731' 9,041' 9,056' 18' 8 4/9/1991 TCP Guns C -7 9,780' 9,803' 9,096' 9,116' 23' 8 4/9/1991 TCP Guns 7 3 C -7 9,816' 9,828' 9,127' 9,137' 12' 8 4/9/1991 TCP Guns 8 e C -7 9,837' 9,875' 9,144' 9,176' 38' 8 4/9/1991 TCP Guns C -8 10,071' 10,133' 9,344' 9,398' 62' 8 4/5/1991 TCP Guns 9 10 Updated by: JLL 06/07/13 PBTD = 9,688' MD 9,018' (TVD) TD = 10,550' MD (9,768' TVD) 01'4 OR BEFORE .---, STATE OF ALASKA ALASKA OIL.,-,ND GAS CONSERVATION L MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 115' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 2046' FSL, 2019' FWL, Sec. 31, T11N, R1 lW, SM Br 20rd-2 At top of productive interval 9. Permit number/approval number 1972' FNL, 877' FWL, Sec. 31, T11N, R11W, SM 91-20 At effective depth 10. APl number 3144' FSL, 296' FWL, Sec. 31, T11 N, R11 W, SM 50-733-20443-01 At total depth 11. Field/Pool 3169' FSL, 134' FWL, Sec. 31, T11N, R1 lW, SM Granite Point/Middle Kenai 12. Present well condition summary Total depth: measured 10550 feet Plugs (measured) 10198 true vertical 9768 feet ....... Effective depth: measured 10198 feet Junk (measured) 9688 true vertical 9457 .,.. feet Casing Length Size Cemented Measured depth True verti~:b.l'depth Structural Conductor Surface 1544' 13-3/8" 1230 sx 1584' 1584' Intermediate Production 6936' 9-5/8" 475 sx 6974' 6818' Liner 1896' 7" 900 sx 6513'-10545' 6423'-9763' Perforation depth: measured 9085-9140, 9170-9236, 9475-9510, 9585-9623, 9632-9640, 9653-9698, 9713-9731,9780-9803, 9816-9828, 9837-9875 true vertical 8557-8598, 8620-8668, 8848-8875, 8936-8967, 8974-8981,8991-9028, 9041-9056, 9096-9116, 9126-9137, 9144-9176 Tubing (size, grade, and measured depth) LS: 2-7/8", 6.4#, N-80 @ 9078' SS: 3-1/2", 9.2#, L-80 @ 6456'; 2-3/8", 4.6#, N-80 @ 9011' RECEIVED Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary ~P~ Intervals treated (measured) '*"*~%' ii'~' ! ~'~* ~ Treatment description including volumes used and final pressure ~ - ~'- ~c~or~ 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 42 33 7 57 49 Subsequent to operation 90 73 1 68 60 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ,~/~~ ~/~~~.~/~A Title: ~1~./~"~~! Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOr. ALe Dan Williamson Drilling Manager Tuesday, April 04, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Granite Point 18742 Well Br 20rd-2 APl No. 50-733-~34-3~-01 10-404 Perforate 07 bench Dear Mr. Ch ristensen: ~'~1 "" (~~ Please find enclosed in duplicate Form 10-404 for the perforation of the C7 bench in well Br 20rd-2. The following intervals were perforated on 2/14/00: Bench Top Bottom Feet C7 9,585 9,623 38 C7 9,632 9,640 8 C7 9,653 9,680 27 Total: 73 If you have any questions, please contact Ralph Holman at 263-7838. ORI6iNAL RECEIVED 10 2000 Alaska Oil & Gas Cons. Commission Anchorage Sincerely, Dan Williamson Drilling Manager ,~"- .... STATE OF ALASKA ~'~ ALA , OIL AND GAS CONSERVATION COMk 'ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging ~ Perforate X Pull tubing Alter casing Repair well __ Pull tubing __ Other 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 , Location of well at surface 2046' FSL, 2019' FWL, SEC. 31, T11N, SM At top of productive interval TOP C-7 (9585') 3175' FSL, 296' FWL, SEC. 31, T11 N, R1 lW,SM At effective depth (10,1983 3144' FSL, 296' FWL, SEC. 31, T11 N, R1 lW, SM At total depth (10,550~ 3169' FSL, 134' FWL, SEC. 31, T11 N, R1 lW, SM 5. Type of Well: LEG, SLOT5, PLA'rFORM BRUCE 6. Datum elevation (DF or KB) 115' KB feet 7. Unit or Property name GRANITE POINT 18742 8. Well number WELL #20RD 9. Permit number/approval number 91-20 10. APl number ?,~.~...~x/ ~-~/ 11. Field/Pool GRANITE POINT/MIDDLE KENAI 12:- Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 1544' Intermediate Production 6936' Liner 1896' Perforation depth: measured 10,550' feet 9,768' feet 10,198' feet 9,457' feet Size 13-3/8" 9-5/8" 7" SEE A'rrACHED Plugs (measured) CEMENT PLUG 10,1 98' Junk (measured) NONE Cemented Measured depth 1230 SX ~ 1584' 475 SX ~;~,, 6974' 900 SX '( 6513'- 10,545' True vertical depth 1584' 6818' 6423' -9763' 13. true vertical Tubing (size, grade, and measured depth) 2-7/8", N-80, 9548' MD 2-3/8" X 3-1/2", N-80, 9457' MD Packers and SSSV (type and measured depth) N/A Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure REEEiV£D JUN 2 B 199 Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water- Bbl Casing Pressure 42 24 8 69 ~ 36 90 Tubing Pressure 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X_ 16. Status of well classification as: Oil X_ Gas __ Suspended __ Service Signed G. RUSSELL SCHMIDT Title DRILLING MANAGER Form 10-404 Rev 06/15/88 Date JUNE 23, 1993 SUBMIT IN DUPLICATe.. WELL HISTORY BRUCE #20-2 WELL #20, ADL 18742 DAY I (5/12/93) 7" LINER 6573'-10,545 TESTED MUD PUMPS TO 3000 PSI. KILLED WELL WITH #2 DIESEL. INSTALLED BPV'S. REMOVED TREE. BEGAN INSTALLING BOPE. WELL #20, ADL 18742 DAY 2 (5/13/93) 7" LINER 6573'-10,545 INSTALL & TEST BOPE. RIG UP ELEC LINE. CUT SS 2-3/8" TBG @ 9438'. FILL HOLE W/DIESEL POH W/SS. POH W/LS. WELL #20, ADL 18742 DAY 3-5 (5/14-16/93) 7" LINER 6573'-10,545 CONT'D RUNNING AND HYDROTESTING THE DUAL COMPLETION STRING. RIGGED UP ELECTRIC LINE AND CORRELATED GUNS WITH GR. LANDED COMPLETION. RIGGED UP ELECTRIC LINE AND VERIFIED THE GUNS TO BE ON DEPTH. REMOVED BOPE. INSTALLED TREE. INSTALLED PRODUCTION HEADER. DROPPED STANDING VALVE AND JET PUMP. PUMPED WELL UNTIL FLUID LEVEL WAS AT 4423'. FIRED GUNS PERFORATING THE C-5 AND C-6 INTERVALS, 9085'-9140', 9170'-9236', 9475'-9510'. RELEASED THE RIG TO WELL #9, ADL 17586. R'E( EIVED JUN 2 8 1993 Alaska Oil & Gas Cons. Commission', Anchorage BRUCE WELL -fl 20-2 RD LEG 1, SLOT 5 CURRENT 13:3/8', 51.5~, J-55 @ 1584' TOP OF CEMENT AT +/- 725~ g 5/8', 40 AND 4&5~ N-80 @ 6974' TOP OF WINDOW 7', 32# S-95 & 29~ N-80 UNER 6573' - 10,545', CMT'D WITH 900 MAX INCUNATION 45.0 DEG 'ID = 10,55(~ MD 5 K.B. 107 ABOVE MSL LONG STRING 1. ClW 1 O' 5M DUAL HANGER 45' 2_ 2-7/8' X 8-1/2' BUTT XO 47' 3. 2-7/8' BUTt &4# TBG 4. 2-7/8' 8RD X 2-718' BUTT XO 901Z 5. KOBE 2-1/2' TYPE BB CAVITY 9013' & 2-7/8' BUTt X 2-7/8' 8RD XO g045' 7. 2-7/8' &4# N-80 TBG 9078' & 4-fa/8' TCP DROP OFF GUNS SHORT STRING A. 3-1/2' TDS X 3--1/2' BUTt XO 47' B. 3-1/2' L-80 9.2# 'I'DS C. 2-3/8' BuTr X 3-1/2' TDS XO 6456' D. 2-3/8' 4.6~ N-80 TBG E. 1-1/4' lO-RD X 2-3/8' BUTT XO 9011' C-5: C-6: RECEIVED JUN 2 8 3993 9085'-9140' Alaska OJJ & Gas Cons. 9170' - 9236' Anchorage 9475' - 951 O' C-7: 963~ - 9640' 9653' - ~' 9713' - 9731' 9780' - 9803' 9816' - 9828' 9837' - 9875' 41,250~ 20-4O CARBOMTE C-8: 10,071' - 10,133' 44,768# 20-40 CARBOMTE FILL TAGGED AT 10,159' WITH WIREUNE GRB 6/23/93 1. Type of request: Abandon Suspend Alter casing__ Repair well Change approved program -~'-".. STATE OF ALASKA ALA , OIL AND GAS CONSERVATION COME ION ~').F)] APPLICATION FOR SUNDRY APPROVAbSr l Operations shutdown Re-enter suspended well Plugging Time extension Stimulate Pulltubing X Variance __ Perforate X Other 6. Datum elevation (DF or KB) 115' KB 7. Unit or Property name Granite Point 18742 8. Well number Well #20RD 9. Permit number 91-2O 10. APl number 50-883-20012-01 11. Field/Pool feet Granite Pt./Middle Kenai 2. Name of Operator 15. Type of Well: Development Union Oil Company of California (Unocal) Exp~or, to~ 3. Address Stratig raphic P.O. Box 196247 Anchorage, AK 99519 Service 4. Location of well at surface Leg, Slot 5, Platform Bruce 2046' FSL, 2019' FWL, Sec. 31, T11N, SM At top of productive interval Top C- 7 (9585') 3175' FSL, 296' FWL, Sec 31, T11 N, R11W, SM At effective depth (1 0,198) 3144' FSL, 296' FWL, Sec. 31, T11N, R11W, SM At total depth (1 0,550') 3169' FSL, 134' FWL, Sec. 31, T11N, R11W, SM 10,550 feet Plugs (measured) 9,768 feet Cement Plug 10,198 12. Present well condition summary Total depth: measured true vertical 10,198 feet Junk (measured) None 9,457 feet Effective depth: measured true vertical Length 1544' 6936' 1896' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth 13- 3/8" 1230 sx 1584' 1584' 9- 5/8" 475 sx 7" 900 sx See attached 6974' 6818' 6513'- 10,545' 6423'-9763 RE EIV£D true vertical Tubing (size, grade, and measured depth) 2--7/n811, U-80, ~548' MD , 2-3/8 x 3-1/2, N-80, 9457 MD Alaska. 0il & (;as Cons. O0~missi0~ Packers and SSSV (type and measured depth) N/A Anch0rsge 13. Attachments Description summary of proposal __ Detailed operations programX__ BOP sketch X Status of well classification as: 14. Estimated date for commencing operation 115. May 1, 1993 16. If proposal was verbally approved Oil X Gas Name o~approver Date approved Se~/ice 17. I hereby ~rti~re~il~l '~d correct to the best of my knowledge. ~,z~. /~ Signed S. Russell Schmidt Title Drilling Manager Suspended FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test Mechanical Integrity Test Location clearance ~'~bsequent form required ~"~- ~/'.1~/ Original ~'~"ned By ) t, ,....;! David W, Johnston Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE GRANITE POINT BRUCE 20-2 WORKOVER PROCEDURE 1. SKID RIG OVER LEG #1 SLOT #5, PLATFORM BRUCE 2. KILL THE WELL WITH DIESEL. 3. VERIFY THAT THE WELL IS DEAD. 4. INSTALL BPV'S, REMOVE TREE. 5. INSTALL AND TEST THE BOPE TO 3000 PSI. 6. PULL AND STAND BACK THE DUAL STRING COMPLETION. 7. RIH WITH TCP DROP OFF GUNS AND THE DUAL COMPLETION. 8. INSTALL BPV'S, REMOVE BOPE. 9. INSTALL TREE. 10. CIRCULATE HYDRAULIC PUMP INTO PLACE AND ACHIEVE UNDERBALANCE. 11. RECOVER HYDRAULIC PUMP AND STANDING VALVE. 12. TUBING CONVEYED PERFORATE: C-5 FROM 9085'-9140' FROM 9170'-9236' C-6 FROM 9475'-9510' 13. INSTALL THE STANDING VALVE. 13. CIRCULATE THE PUMP TO BOTTOM. 14. RELEASE THE WELL TO PRODUCTION. (55') (66') (35') BRUCE WELL -,-¢ 20-2 RD LEG 1, SLOT 5 CURRENT COMPLETED 4/21/91 13 3/8", 51.5#, J-55 @ 1584' TOP OF CEMENT AT +/- 7250' 5/8", 40 AND 43.5# N-80 6974' TOP OF WINDOW 7', 32# 8-95 & 29~ N-80 UNER 6573' - 10,545', CMI"D WITH 900 8XS MAX INCLINATION 45.0 DEG TD = 10,550' MD '/'//////// L ICB. 107 ABOVE MSL LONG STRING 1.44.95' ClW 1 o" 5M DUAL HANGER 2, 45.85' 2-7/8" X 8-1/2' BUI-I' XO 3. 9459.99456.6' 2-7/8" BU'I-r 6.4# 'FBG 4. 9461.2' 2-7/8' 8RD X 2-7/8' BUTT XO 5. 9482.8 KOBE 2-1/2' TYPE DD CAVITY 6. 9484.0 2-7/8' BUTI' X 2-7/8' 8RD XO 7. 9456.1 2-7/8' 6.4# N-80-I'BG 8. 9547.7 WL RE-ENTRY GUIDE 4.25' SHORT STRING A. 44.95' 3-1/2' TD8 X 3-1/2' BUTT XO B. 6471.95' 3-1/2' L-80 9.2# 1'D8 C. 6472, T 2-3/8" BUTT X 3-1/2' TD8 XO D. 9457.3' 2-3/8' 4.6# N-80 TBG E. 9457.8' 1-1/4' 8RD X 2-3/8" BUTT XO F. 9460.4' 1-1/4" 8RD DOUBLE PIN C-7: 9585' - 96Z3'41,250~ 20-40 CARBOUTE 9632'-9640' 9653' - 9698' 9713' - 9731' 9780' - 98O3' 9837' - 9875' C-8:10,071' - 10,133' 44,768# 20-40 CARBOUTE 2/10/91 BRUCE WELL # 20-2 RD LEG 1, SLOT 5 PROPOSED 13 3/8", 51.5#, J-55 @ 1584' TOP OF CEMENT AT +/- 7250' 9 5/8", 40 AND 43.5# N-80 @ 6974' TOP OF WINDOW 7", 32# S-95 & 29# N-80 LINER 6573' - 10,545', CMT'D WITH 900 SXS MAX INCLINATION 45.0 DEG TD = 10,550' MD K.B. 107 ABOVE MSL LONG STRING 1. CIW 1 O" 5M DUAL HANGER 2. 2-7~8" X S-1/2" BU'I-I' XO 3. 2-7/8" BU'i-r 6.4# TBG 4. 2-7/8" 8RD X 2-7/8" BU'I-r XO 5. KOBE 2-1/2" TYPE DD CAVITY 6. 2-7/8" BU'I-r X 2-7/8" 8RD XO 7. 2-7/8" 6.4# N-80 TBG 8. TCP DROP OFF GUNS SORT STRING A. 3-1/2" TDS X 3-1/2" BUTT XO B. 3-1/2" L-80 9.2# TDS C. 2-3/8" BU'I-r X 3-1/2" TDS XO D. 2-3/8" 4.6# N-80 TBG E. 1-1/4" 8RD X 2-3/8" BUTT XO F. 1-1/4" 8RD DOUBLE PIN C-5: 0-6: 9085' - 9140' 9170' - 9236' 9475' - 951 O' 0-7: 9585'-9623' 9632'-9640' 9653'-9698' 9713'-9731' 9780'-9803' 9816'-9828' 9837'-9875' 41,250# 20-40 CARBOLITE C-8: 10,071' - 10,133' 44,768# 20-40 CARBOLITE FILL TAGGED AT 10,159' WITH WIRELINE RECEIVED GRB 1/22/92 ~task~: Oil &. G,~; Cor~s. Commissior~ A PLATFORM BRUCE .DRILLING STACK PITCHER NIPPLE- 16' ID W/lO' FLOWLINE ANNULAR BOP "NL SHAFFER" 13 5/8' 5000 PSI BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SHAFFER" 13 5/8" 5000 PSI BX-160 ASSY WT. 16,500 LBS. MUD CROSS- 13 5/8' BORE W/4" 5000 PSI VALVES SGL,-GATE BOP "NL SHAFFER" 13 5/8" 5000 PSI BX-160 ASSY WT. 9100 LBS, RISER 18'0D 13 5/8" 5000 FLG LOWER RISER 11' ID W/lO" 5000 PSI FLG (RX-54) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192. PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 3, 1992 Janet Bounds Unocal P O Box 190247 Anchorage, AK 99519-0247 Dear Ms Bounds: As we discussed on the phone October 28, AOGCC will be reassigning APl numbers for the wells listed below. In order to accommodate the revision of Unocal's records, we will not announce these changes to the public until the first week of December, or until you advise me that all the necessary changes are made. Give me a call if you would like to discuss this matter further. Well Name Permit # Old APl Number New APl Number Granite Pt St 17587 #3 66-52 ' 50-883-10031 50-733-20437 Granite Pt St 17587 fl4 89-30 50-883-10032 50-733-20438-90 Granite Pt St 17587 ~6 89-103 50-883-10034 50-733-20439 Granite Pt St 18742 ft8 67-36 50-883-20008 50-733-20440 Granite Pt St 17586 ~ 67-54 50-883-20009 50-733-20441 Granite Pt St 18742 #34 79-17 50-883-20009-01 50-733-20441-01 Granite Pt St 17586 ~1 91-45 50-883-20009-02 50-733-20441-02 Granite Pt St 18742 #14 79-33 50-883-20010 50-733-20442 Granite Pt St 18742 #20 68-16 50-883-20012 50-733-20443 Granite Pt St 18742 #20RD 91-20 50-883-20012-01 50-733-20443-01 Granite Pt St 17587 #5 68-24 50-883-20013 50-733-20444 Pretty Creek Unit #2 79-9 50-283-20022 50-283-20022-90 Nicolai Creek Unit ~ 91-100 50-283-20033 50-283-20033-90 Lewis River D-1 89-72 50-283-20068 50-283-20068-90 Trading Bay Unit G-18DPN 83-135 50-733-20160 50-733-20160-90 Yours truly, Robed P Crandall Sr Petr Geologist /jo · STATE OF ALASKA - " ALASK'~' OIL ANDGASCONSERVATION C~...4MISS¢I~)I~ !~ ~N A I_ ,WELL. COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL [~ GAS [] SUSPENDED [] . ABANDONED [] :2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. Box 190247, Anchorage, AK 99519 Classification of Service Well --_ SERV,CE 7. Permit Number 91-0020 8. APl Number 50- 883-20012-01 4. Location of well at surface Platform Bruce 2050' FSL, 2019' FWL, Sec. 31, TllN, RllW, SM At Top Producing Interval Top C-7 9585' 3175' FSL, 621' FWL, Sec. 31, TllN, RllW, SM At Total Depth 10,550 ' 3169' FSL, 134' FWL, Sec, 31', TllN, RllW, SM COMPL.F. Ti0N ~ 9. Unit or Lease Name Gran±te Pt. 18742 10. Well Number Well ~ 20RD 11. Field and Pool Mid Kenai/Granite Point 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 115' KB J ADL 18742 12. Date Spudded 13. Date I.D. Reached I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 2/27/91 3/29/91 ] 4/19/91 J 62 feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (M,D+TVD)119. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10550' 9768' 10,198', 94;57' ] N/A , J YES [~ NO [] 'N/A feet MD 22. Type Electric or Other Logs Run DIL / SONIC/GR CNL/MSFL/LDT/GR FMS / GR 23. " CASING, LINER AND CEMENTING RECORD CASING SIZE]WT. PER FT. I GRADE ¸ I ',;SETTING DEPTH MD TOP I BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8'' 54.5 J-55 40' 1584' 9-5/8" 40-4%5# S-95/N-80 38' 7" 29-32# N-80/S-95 6573' 8325" 10,545'' 17.5" 1230 sxs None 12.5" 475 sxs Window at 6974' 8.5" 900 sxs None 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number} ... ' . .. .. See attachment "A" ~..; ' ,,,..~. -.. .- 25. TUBING RECORD SIZE I DEPTH SET (MD),IPACKER SET (MD) 2-7/8" 9548' N/A 2-3/8"-3-1/2" 9457' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEP~H~NTERVAL(MD) j AMOUNT& KIND OF MATERIAL USED 9585'-9875' 41250# 20-40 Carbolite 10,071'-10,133' 44768# 20-40 Carbolite 27. PRODUCTION TEST DateFirst Production ..... 41 Date of Test i Hours Tested 4/28/9.1 J .12 Flow Tubing Casing Pressure Press.. · Method of Operation (Flowing, gas lift, etc.) Hydraulic PumP ' PRODUCTION FORIOIL-BBL.,~ [ GAS-MCF .TEST PERIOD I~ 21 17 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE ~ 43 I 34 WATER-BBL WATER-BBL 77 JCHOKESIZE IGAS'OILRATIO - I 790 OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas o¢ water. Submit core chips. None RECEIVED S E P - 9 1991 Alaska 0il & Gas Cons. C0mnlisSt~_ti Anchorage Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate · . 29. ' ' .. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (KOP of RD) 6990 6834 (-6719) 28 Marker 7551 7365 (-7250) 34 Marker Top Granite Pr. Sds (C-l) 8604 8191 (-8076) C-2 Sand 8802 8340 (-8225) C-5 Sand 9085 8557 (-8442) C-7 Sand 9585 8936 (-8442) C-8 Sand 10071 9344 (-9229) · 31. L~ST OF ATTACHMENTS Daily Report of operations, wellbore, diagram, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for'submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection~_observation, injection for in-situ combustion. --.-:--~-----~ .... Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". BRUCE ~FELL #20-£RD LARRY J~cC.4LLIS?EI~ DRILLING FOI~E~ JgARTY LYNCH, DRILLING FOREJL4N & d71.M R ~'ED S EP - 9 1991 &laska Oil & Gas Cons. Commissien Anchorage TFNOCAL PLATFORM BRUCE WELL AFE #311577 DATE MW ETD COMMENTS PAGE 1 02/21/91 8053' 6197' COMMENCED OPERATIONS AT 1800 HRS. SKIDDED RIG OVER 20-2. WORKED ON MUD PITS, GAS BUSTER U-TUBE. WORKED ON THE RETURN LINE. 02/22/91 8O53' CMT CONTINUED TO RIG UP. INSTALLED OUTSIDE STAIRS AND LANDING TO THE SHAKER ROOM. HOOKED UP THE STAND PIPE AND MUD RETURN LINES. PLUMBED AIR AND STEAM. TO THE RIG FLOOR. INSTALLED HOOK. FILLED PITS WITH WATER. PREP TO KILL WELL. SOME GENERAL CLEAN UP AND REORGANIZING. 02/23/91 02/24/91 02/25/91 67 67 67.5 8053' CMT 8053' CMT 8053' CMT CONTINUED WITH GENERAL RIG UP. PLUMBED LINES. WELDED SKIN AROUND THE CHOKE MANIFOLD. LAID NEW BOARDS FOR PIPE RACKING. ATTEMPTED TO HYDROTEST THE CHOKE LINE AND MANIFOLD. SEVERAL SMALL LEAKS WERE REPAIRED. UNLOADED AND MIXED SPUD MUD. INSTALLED LANDING FOR THE DERRICK LADDER. REPAIRED THE PACKING ON A LEAKY VALVE IN THE CHOKE MANIFOLD. HYDRO TESTED THE CHOKE LINE AND MANIFOLD TO 7500 PSI FOR 30 MINUTES, OK. CIRC 67 PCF SPUD MUD DOWN THE LONG STRING TO KILL THE WELL. GOT MUD RETURNS BACK WHEN EXPECTED. WAITED FOR THE WELL TO STOP U-TUBING. INSTALLED OCT BPV'S. REMOVED THE TREE. INSTALLED BOPE. MODIFIED AND INSTALLED THE PITCHER NIPPLE. FINISHED FLOW LINE MODIFICATIONS AND INSTALLED. PULLED OCT BPV'S. INSTALLED OCT 2-WAY PLUG IN THE SS. MADE UP LANDING JOINT AND TESTED S.S. PLUG TO 3000 PSI, OK. MOVED LANDING TO THE L.S. TESTED THE BOPE TO 3000 PSI HIGH 300 PSI LOW, OK. TESTED THE ANNULAR TO 2500 PSI, OK. PULLED THE HANGERS, OCT PLUG. LAID DOWN THE SS. RIH WITH THE L.S. TO 8048'. CIRC BOTTOMS UP. RIGGED UP BJ TITAN. TESTED SURFACE LINES TO 4000 PSI. MIXED AND PUMPED 320 SX CLASS G, 0.15% R-l, I G4S FP-6L. PICKED UP TO 6810'. REVERSE CIRC. GOT 12 BBLS CMT BACK. RIH TO 7200', REVERSE CIR. POOH WITH THE TUBING STRING AND CHECKED FOR HOLES WITH STEAM. NO VISIBLE HOLES, TESTED THE CASING TO 2000 PSI, OK. DATE MW ETD 02/26/91 67.5 PLATFORM BRUCE WELL ~'~'~-2 AFE #311577 PAGE 2 COMMENTS 7312' CMT WLM RIGGED UP WIRELINE. RIH WITH CBL/GR/CCL AND TAGGED CMT AT 7132' WLM. LOGGED FROM 7132'-5000'. RESULTS SHOWED GOOD CEMENT TO 6950'. RIGGED DOWN WlRELINE. REMOVED BOPE. CHANGED OUT OCT SPOOL FOR A CIW DCB SPOOL AND TESTED TO 5000 PSI, OK. INSTALLED BOPE AND TESTED TO 5000 PSI, OK. 02/27/91 68.8 02/28/91 68.8 03/01/91 68.9 03/02/91 68.4 7149' CMT DPM 7149' CMT DPM 7234' CMT DPM 6917' CMT DPM CONT'D W/BOPE TEST. TESTED HYDRIL, UPPER & LOWER PIPE RAMS, BLIND RAMS, CHOKE & KILL LINES, CHOKE MANIFOLD & ALL VALVES 250 LOW- 5000 HIGH. P/U 84 JTS 5" D.P. POOH. MADE UP SECTION MILL. RIH AND TAGGED ABANDONMENT PLUG AT 7149'. REPAIRED THE ROTARY TORQUE GAUGE. MADE CUT IN 9-5/8" 43.5# S-95 CASING AT 6974' DPM. MILLED SECTION TO 6978' AT 2400 HRS. CONTINUED MILLING SECTION FROM 6978'-6997' DPM. SHOOK A BIRD NEST. A3-rEMPTED TO CLOSE THE TOOL TO MAKE A CONNECTION FOR 1 HR. WORKED INTO 9-5/8" SHOE AT 6974'. TOOL PARTIALLY PLUGGED. WORKED UP HOLE. UNPLUGGED AT 6605'. POOH. MILL # 1 SHOWED GOOD cU~rlNG PA3-rERN. PICKED UP SECTION MILL #2. RIH. MILLED FROM 6997'-7042' DPM. TOTAL WINDOW IS 68'. CIRC. FINISH CIRC. WORKED INSIDE CASING STUB TO 7075'. POOH. LAYED DOWN MILL #2. RIH WITH 7-1/2" X 15" TSA LOCK-O-MATIC UNDERREAMER. UNDERREAMED WINDOW TO 15" FROM 6974'- 7042'. CIRC. SPOT'rED HIGH rISC PILL ACROSS THE WINDOW. ATTEMPTED TO RE-ENTER THE CASING STUB AT 7042' NEG. POOH. RIH WITH 3- 1/2" X 20' PERFORATED TUBING PUP AND 3-1/2" TBG. TAGGED ETD AT 7234' WITH 15 K WT. CIRC. FINSIHED CIRC. RIGGED UP CEMENTERS. TESTED LINES TO 3000 PSI. LAID K.O.P. AS FOLLOWS: 25 BBLS FRESH WATER PRE-FLUSH W/170 S-400, 200 CU FT "G", 183 SXS, 16.2 PPF, 04% CD-31, 0.1%, R-l, 1-GHSX FP-6L, WITH 3 BBLS AFTER FLUSH. PULLED UP TO 6660'. REVERSED OUT. POOH. LAYED DOWN 3-1/2" TBG FROM BR 20-2. RIH W/8-1/2" BIT. AT-tEMPTED TO CIRC AT 6688'. I~IT PLUGGED. PULLED TO 6440'. UNPLUGGED BIT. RIH TAGGED CMT AT 6801'. DRL'D CMT FROM 6801'-6917'. ROP. 250-113. CIRC. WOC. DATE 03/03/91 03/04/91 03/05/91 03/06/91 MW 68.4 68.4 67.8 67.8 ETD PLATFORM BRUCE WELL AFE #311577 COMMENTS PAGE 3 7042' CMT DPM 6875' CMT CONTINUED TO WOC. (TOTAL OF 24.5 HRS). DRILLED CEMENT FROM 6917'-6985'. ROP WAS 200-115 FPH. 6985'-7042', VERY RATTY, ROP 80-170 FPH. POOH. RIH WITH 15" UNDERREAMER. UNDERREAMED FROM 6974'-7041'. CIRCULATED. SPOTTED HIGH VISC PILL. POOH. LAID DOWN UNDERREAMER. PICKED UP 3-1/2" PERFORATED TUBING PUP AND 10 JTS 3-1/2" TBG. RIH WITH 3-1/2" TBG AND 5" D.P. UNABLE TO GET DEEPER THAN 7034', CIRC. RIGGED UP CEMENTERS. PUMPED K.O.P. AS FOLLOWS. 90 BBLS PREFLUSH USING FRESH WATER 1% S-400, 120 SXS (125 CU FT) "G" NEAT CMT AT 16.6 PPG, 0.7% CD-31, 1-GPHS FP-6L, 29 BBLS FRESH WATER AFTER FLUSH. DISPLACED WITH MUD. CIP AT 0600 HRS. EST TOC 6875'. 6985' CMT DPM CONT'D TO WAIT ON CEMENT. RIH AND TAGGED CMT AT 6875'. WASHED DOWN TO 6890'. SOFT CMT. WOC. DRILLED CEMENT FROM 6890'-6985', ROP 85 FPH. CIRC. POOH. MADE UP MWD AND MU MOTOR. RIH. 7047' DPM RIH TO 6985'. ORIENTED MUD MOTOR TO TOP SIDE OF THE HOLE. TIME/FOOTAGE DRILLED FROM 6985'-6990'. PUMP PRESSURE DECREASED FROM 1800'-6990', 1460'-1380'. ALL SURFACE EQUIP CHECKED OK. TELECO PULSE GOOD AT 305 GPM. 280 GPM, LOST PULSE AT 234 GPM. POOH FOR POSSIBLE WASH OUT. CHANGED OUT MUD MOTOR AND JARS. RIH AND TIME/FOOTAGE DRILLED FROM 6990'-7047'. CIRC. PREPARED TO PERFORM L.O.T. 03/07/91 03/08/91 03/09/91 03/10/91 03/11/91 68.8 69.1 68.6 68.8 69.2 7225' DPM 7365' DPM 7556' DPM 7672' DPM 7809' DPM CIRC. TESTED THE SURFACE LINES TO 2000 PSI. CLOSED PIPE RAMS. PRESSURED UP AT 0.4 BPM RATE. PRESSURE OF 900 PSI EMW=87.6 PCF. DIR-DRILLED 8-1/2" FROM 7047' TO 7225'. CIRC. BOTTOMS UP. POOH. LAID DOWN D.P. LAID DOWN BIT #2, MUD MOTOR AND LEAD COLLAR. RIH WITH BHA #8 (ROTARY). REAMED FROM 6985'-7225'. DRILLED 8-1/2" HOLE 7225'-7365'. CIRC. POH FOR MUD MOTOR BHA #9. RIH W/SAME. PERFORMED LOT=0.754 PSI/FT (109 PCF E.M.W. ) DRILLED 8-1/2" DIRECTIONAL HOLE 7365'-7556'. DRILLED 8-1/2" DIRECTIONAL HOLE 7556'-7621'. TRIPPED FOR BHA #10. DRILLED 8-1/2" DIRECTIONAL HOLE 7621'-7672'. DRILLED 8-1/2" DIRECTIONAL HOLE 7672'-7751' TRIPPED FOR BHA #11. DRILLED 8-1/2" DIRECTIONAL HOLE 7751'-7809'. DATE o3/12/91 03/13/91 03/14/91 03/15/91 03/16/91 03/17/91 03/18/91 03/19/91 03/20/91 03/21/91 03/22/91 MW 69.6 69.6 71.1 71.8 72.2 71.1 71.8 72.2 72.0 72.9 74.0 ETD PLATFORM BRUCE WELL '-%2 AFE #311577 COMMENTS PAGE 4 7960' DPM DRILLED 8-1/2" DIRECTIONAL HOLE 7809'-7960' WITH MUD MOTOR. DROPPED SINGLE SHOT SURVEY. POH. TEST BOPE. 8066' DPM TEST BOPE-250 PSI LOW, 5000 PSI HIGH. RIH WITH BHA #12 TO 4064'. CBU. RIH TO 7331'. REAMED 8-1/2" HOLE TO 7960'. DRILLED 8-1/2" HOLE TO 8066'. 8405' DRILLED 8-1/2" HOLE 8066'-8306'. MADE WIPER TRIP TO SHOE. SMOOTH TRIP. DRILLED 8-1/2" HOLE 8306'-8405', 8537' DRILLED 8-1/2" HOLE 8405'-8537'. CIRCULATED. POH. RIH WITH BIT #8 ON BHA #13. 8797' 8935' 9254' 9393' 9527' CONT. RIH. REAL TIME LOGGING FEATURE OF TELECO TOOL FAILED DURING TEST. RIH TO 8258'. REAMED 8-1/2" HOLE TO 8537'. DRILLED 8- 1/2" HOLE 8537'-8797'. CONTINUED TO DRILL 8-1/2" HOLE FROM 8797'- 8829'. CIRC AND CONDITIONED MUD. POOH. LAID DOWN BIT #8. P/U BIT #9 ON BHA #14. INITIALIZED THE TELECO TOOL. RIH TO 8829'. DRILLED 8-1/2" HOLE FROM 8829'-8935'. CONTINUED TO DRILL 8-1/2" HOLE FROM 8935'- 9254'. ANGLE BUILDING AT 1.4 DEG/100'. CIRC. CONT'D TO CIRC. POOH. LAID DOWN BIT #9, PICKED UP BIT #10 ON BHA #15. RIH. DRILLED 8- 1/2" HOLE FROM 9254'-9387'. LOST DIRECTIONAL SIGNAL FROM THE MWD TOOL. CIRC. RUN W/L SURVEY. DRILLED 8-1/2" HOLE FROM 9387'-9393'. CONT'D TO DRILL 8-1/2" HOLE FROM 9393'-9447'. LOST #1 MUD PUMP, WASHED OUT THE FLUID ENG. WIRELINE SURVEY. DRILLED FROM 9447'- 9527'. CIRC. POOH. REPAIRED THE #1 MUD PUMP USING BELZONA MOLECULAR METAL COMPOUND. 9698' CONTINUED TO POOH. PULLED WEAR BUSHING. RAN TEST PLUG. RIGGED UP TO TEST BOPE. WELL STARTED FLOWING A GOOD 1" STREAM. RIGGED DOWN TEST EQUIPMENT. MADE UP BHA #16. RIH. RE-SURVEYED WITH TELECO AT 9330' AND, 9426'. SAFETY REAMED 30' TO BOTTOM. DRILLED AND SURVEYED 8-1/2" HOLE FROM ~9426' TO 9698'. 9903' SHORT WIPER TRIP TO 9300'. DRILLED 8-1/2" HOLE FROM 9698' TO 9903'. KNOT AT 9715' ON CONNECTION. CIRC. POOH FOR BIT #12. LAID DOWN 60 JOINTS OF 5" 19.5# X-95 D.P. PLATFORM BRU(3E WELL ~"~0-2 AFE #311577 DATE MW ETD COMMENTS PAGE 5 03/23/91 74.4 DUMPED TELECO MEMORY. PULLED WEAR BUSHING. RAN TEST PLUG. TESTED THE RAMS, CHOKE AND KILL LINES, CHOKE MANIFOLD, ALL VALVES TO 250 PSI LOW AND 5000 PSI HIGH. TESTED THE HYDRIL TO 250 PSI LOW AND 3500 HIGH. MADE UP BIT #12 ON BHA #17. RIH TO 5050'. P.U. 50 JOINTS OF 5" S-135 D.P. PULLED UP AND STOOD THE 5" BACK. RIH AND SAFETY REAMED FROM 9766' TO 9903'. (3IRC BOTTOMS UP. DRILLED 8-1/2" HOLE FROM 9903'-9968'. 03/24/91 76.7 10,177' DRILLED AND SURVEYED FROM 9968'-10,144'. SHORT TRIP, TIGHT AT 9835'. CIRC AND WIPED THE KNOT OUT. REAMED FROM 9720'-9918'. SHORT TRIP FROM 9918'-8980', OK. DRILLED AND SURVEYED 8-1/2" HOLE FROM 10,144' TO 10,177'. STARTED TO BOX CUTTINGS AT 2130 HRS. 03/25/91 76.7 10,280' DRILLED 8-1/2" HOLE FROM 10,177'-10,234'. (31R(3. POOH. DUMPED TELE(30 MEMORY, NO GOOD. LAID DOWN TELECO, AND MONEL D.(3.'S. P/U BHA #18. INSTALLED DRIVE COUPLING ON ENGINE #3. RIH. REAMED FROM 10,174'-10,234'. DRILLED 8- 1/2" HOLE FROM 10,234'-10,280'. 03/26/91 77.8 10,441' CONTINUED TO DRILL 8-1/2" HOLE FROM 10,280' TO 10,379'. WIPER TRIP TO 9414', SMOOTH. DRILLED FROM 10,379' TO 10,441'. CIRC. WIPER TRIP TO 6974'. RIH. CIRC. AND CONDITIONED MUD. POOH. 03/27/91 78 10,441' POOH. RIGGED UP WlRELINE. TESTED LUBRICATOR TO 250 PSI. RAN DIL/SONIC/GR LOG, STOPPED AT 8510', ATTEMPTED TO GET DEEPER, NEG. REDUCED STAND OFFS FROM 8" OD TO 7" OD. RAN DIL/SONIC/GR LOG FROM 10,434'-6974'. RAN CNL/MSFL/LDT/GR FROM 10,434'-6974'. RIH WITH THE FMS/GR LOG. 03/28/91 79 10,540' FINISHED RUNNING THE FMS/GR FROM 10,432' TO 6972'. RIGGED DOWN WlRELINE. MADE UP BIT #14 ON BHA #19. RIH TO 6974'. CIRC. RIH. DRILLED 8-1/2" HOLE FROM 10,441'-10,540'. 03/29/91 8O 10,550' DRILLED FROM 10,540'-10,550'. CIRC. SHORTTRIP TO 6974', OK. SLIPPED AND (3UT DRLG LINE. RIH TO 10,550'. (3IRC AND CONDITION MUD. POOH. RIGGED UP AND RAN 7" LINER. PLATFORM BRUCE WELL -2 AFE #311577 DATE MW ETD PAGE 6 03/30/91 80 10,550' RAN 96 JTS (3972') 7" 32# S-95 & 7" 29# N-80 LINER. EQUIPPED WITH TIW 7"X 9-5/8 .... DTH". SINGLE CONE HYDRO LINER HANGER W/6' TIE BACK STEM TO 10,550'. CIRC & RECIPROCATED W/50' STROKES. CMT'D AS FOLLOWS. 30 BBLS NON-WEIGHTED S-400, 5% KCL. 80 BBLS MCS-2 SPACER AT 12.5 PPG. 900 SXS (1.15 YIELD) CLASS G CMT AT 15.8 PPG W/0.8% FL-28, 0.2% CD-31, 0.15% A-2, 1 GPHS FP-GL. KICKED OUT D.P. DART W/5 BBLS SPACER. DISPLACED WITH 10.6 PPG MUD. PRESSURED UP TO 3000 PSI AND SET HANGER. RELEASED FROM HANGER, SET 40,000# DOWN AND SET THE PACKING ELEMENT. PULLED TO 6294'. REV OUT. POOH. CHANGED TOP RAMS TO 3-1/2" VBR'S. CHANGED OUT BAD CHOKE LINE VALVE. 03/31/91 78.9 10,550' FINISHED CHANGING OUT CHOKE LINE VALVE. COMPLETE BOPE TEST, ALL RAMS, KILL LINES, VALVES AND KELLY VALVES TO 250 PSI LOW AND 5000 PSI HIGH. TESTED THE HYDRIL TO 250 LOW AND 3500 HIGH. LAID DOWN THE 8-1/2" STABILIZERS AND 5" HEAVY WEIGHT D.P. RIH WITH 8-1/2" BIT (BHA #20). WASHED CEMENT FROM 6450' TO 6570' DPM. (T.O.L.). CIRC. POOH AND LAID DOWN 79 JOINTS 5" D.P. MADE UP BIT #15 ON BHA #21. R IH PICKING UP 3-1/2" X-95 D.P. 04/01/91 79.3 10,493' FINISHED PICKING UP THE 3-1/2" D.P. RIH WITH 5" D.P. TO 6555'. CIRC. PRESSURE TESTED THE 7" X 9-5/8" CASING LAP TO 2000 PSI FOR 15 MIN, OK. CONT'D TO RIH. TAGGED CMT AT 10,378' DRILLED FIRM CEMENT AND WIPER PLUGS TO 10,450'. DRILLED LANDING COLLAR AT 10,450' AND CEMENT TO 10,493'. PRESSURE TESTED THE 7" AND 9-5/8" CASING TO 2000 PSI FOR 30 MIN, OK. POOH. 04/02/91 79.3 10,493' RIH WITH 7" CASING SCRAPER AND BHA #22 TO 10,493'. CIRC CLEAN. POOH. RAN TEST PLUG. OPENED TOP SINGLE GATE, INSPECTED 3-1/2" X 5" VBR'S. LOOKED GOOD. REPLACED THE VBR'S WITH A STANDARD 5" RAM. TESTED RAMS TO 250 PSI LOW, 5000 HIGH, OK. PULLED TEST PLUG. RIGGED UP WIRELINE, RAN GYRO SURVEY FROM SURFACE TO 10,493'. RAN CBL/GR FROM 10,482'- 9200'. RE-RAN FROM 10,482'-6370' WITH 1000 PSI. RAN PET/GR LOG FROM 10,482'. 04/03/91 79.3 10,493' CONT'D TO RUN PET/GR LOG. LOGGED TEMP/GR FROM 10,482'-6300'. RIH WITH A PLUGGED F_.ZSV TO 10,435' DPM. DISPLACED WELL WITH INLET WATER. MW PLATFORM BRUCE WELL AFE #311577 PAGE 7 04/04/91 04/05/91 04/06/91 04/07/91 04/08/91 73.2 73.2 72.8 73.1 73.1 10,183' 10,183' 10,183' 10,183' 9943' CONTINUED TO DISPLACE THE WELL WITH INLET WATER. PICKED UP AND SET EZSV AT 10,183'. FLUSHED THE HOLE WITH INLET WATER. MIXED KCL-NABR-NACL BRINE TO 9.6 PPG. PUMPED 100 BBL SPACER FOLLOWED BY NEW BRINE. REVERSE CIRCULATED THE BRINE, DISPLACING THE INLET WATER. FILTERED THE BRINE. NTU READING OF 45 WAS ACHIEVED. POOH. FINISHED POOH. LAID DOWN SE-l-rING TOOL. PICKED UP PERFORATING GUNS AND RIH. CORRELATED THE GUNS WITH GAMMA RAY, RECORRELATED AND FIRED THE GUNS WITH 1750 PSI ANNULUS PRESSURE. PERFORATED THE C-8 WITH 8 SPF FROM 10,071' TO 10,133' DIL, 25 GM CHARGES. RELEASED RTTS AND POOH. LAID DOWN THE GUNS. SOME OIL. RIH WITH FRAC STRING. CONT'D RIH WITH THE FRAC STRING. SET THE PACKER WITH THE TUBING TAIL AT 9676'. PRESSURED UP ON THE ANNULUS 1800 PSI. PUMPED INJECTIVITY TEST, STEP RATE/FLOW BACK TEST, CALIBRATION TEST AT 15 BPM WITH 9,500 PS! MAXIMUM SURFACE PRESSURE. 826 BBLS OF FLUID WAS PUMPED INTO THE FORMATION DURING THESE TESTS. ALLOWED THE CALIBRATION TEST TO BLEED OFF IN ORDER TO GET CLOSURE PRESSURE. RIGGED UP WIRELINE. RAN A TEMP GR LOG FROM 9676'- 10,183'. RIH AND RETRIEVED MSRT-DATA LINK DATA. FINISHED RETRIEVING THE MSRT DATA LINK DATA. RIGGED DOWN WIRELINE. ANALYZED DATA. CHECKED TIE DOWNS. HELD SAFETY MEETING. PRESSURE TESTED THE LINES TO 13,000 PSI, OK. MAINTAINED 1800 PSI ON THE ANNULUS. PERFORMED A FRACTURE STIMULATION USING 40# GEL AND 20-40 CARBOLITE ON THE C-8 SAND. PUMPED AS FOLLOWS: 200 BBL PAD, 15 BBL 2 PPG, 15 BBL 4 PPG, 35 BBL 6 PPG, 45 BBL 8 PPG, 50 BBL 10 PPG, 50 BBL 12 PPG. SANDED OUT THE JOB WITH 44,768# THROUGH THE PERFS. SHUT IN AND MONITORED PRESSURE. BLED OFF AT 1/4 BBL/MIN. HELD 750 PSI ON THE BACK SIDE. RELEASED THE RTrs AND STRIPPED OUT 90'. REVERSE CIRC TWO HOLE VOLUMES. POOH. CONT'D TO POOH. LAID DOWN FRAC ASSEMBLY. RETRIEVED DOWNHOLE DATA. RIH WITH A MULE SHOE. TAGGED SAND AT 9675', REVERSED OUT TO 9943'. CIRC. POOH. PICKED UP TBG CONVEYED PERFORATING GUNS. PLATFORM BRUCE WELL ~'q-2 AFE #311577 DATE 04/09/91 MW 73.O ETD 9943' PAGE 8 COMMENTS RIH WITH TCP GUNS. CORRELATED GUNS WITH GR. SET PACKER. RE-CORRELATED. PRESSURED UP ON THE ANNULUS AND FIRED THE TCP GUNS AT 1650 PSI PERFORATING THE C-7 SANDS WITH 8 SPF. THE WELL LOST THREE BBLS OF FLUID. OPENED THE BYPASS AND REVERSE CIRC SOME OIL. RELEASED RTTS. CIRC. POOH. LAID DOWN PERF ASSEMBLY. RIH WITH THE FRAC ASSEMBLY. SET THE TAIL AT 9502'. PRESSURE TESTED LINES TO 14,800 PSI, OK. PRESSURED THE ANNULUS TO 1800 PSI. PERFORMED INJECTIVlTY TEST, STEP RATE/FLOW BACK, AND CALIBRATION TEST. INJECTED 1050 TOTAL BBLS OF FLUID. RIGGED UP WlRELINE. 04/10/91 73.3 9943' RETRIEVED MSRT DATA. RAN A TEMP/GR FROM 9910' TO 9230'. RIGGED DOWN WlRELINE. ANALYZED DATA. MIXED UP FRAC FLUID. HELD SAFETY MEETING. TESTED ALL SURFACE EQUIPMENT TO 10,600 PSI. PERFORM FRAC ON THE C-7 PERFORATIONS. 41,250 LBS OF 20-40 CARBOLITE THROUGH THE PERFORATIONS. BLED TO 0 PSI IN 45 MINUTES. RIGGED DOWN DOWELL. RELEASED R~-rs. REV CIRC. REDUCED THE MUD WEIGHT FROM 9.7 TO 9.1 PPG. 04/11/91 04/12/91 68 68 10183' 10183' FINISHED REDUCING THE M.W. FROM 9.7 TO 9.1 PPG. MONITORED WELL. WELL STABLE. POOH. PULLED WEAR BUSHING. RAN TEST PLUG AND TESTED BOPE 250 LOW, 5000 HIGH. HYDRIL TO 250 LOW, 3500 HIGH, OK. PULLED THE TEST PLUG. RAN WEAR BUSHING. RIH WITH BURN OVER SHOE. TAGGED SAND AT 9654'. REVERSED OUT SAND FROM 9654' TO 10,183'. LOST 45 BBLS OF FLUID WHILE REVERSING OUT. BURNING OVER EZSV AT 10,183'. CONT'D TO BURN OVER THE EZSV AT 10,183'. CHASED TO 10,492'. CIRC. POOH LAYING DOWN ALL 3-1/2" & 5" D.P. CHANGED TO DUAL RAMS AND TESTED, OK. TESTED KOBE "DD" CAVITY TO 4500 PSI. RUNNING DUAL 2-3/8" X 2-7/8" STRINGS, HYDROTESTING TO 4500 PSI. 04/13/91 ~04/14/91 68 68 10492' 10492' CONT'D RIH W/DUAL HYDRAULIC COMPLETION. CHANGED OVER TO 2-7/8" X 3-1/2" STRINGS. RAN 20 JOINTS OF 3-1/2", FOUND HYDROTEST TOOL WAS NOT FUNCTIONING PROPERLY. STOOD 2-7/8" & 3-1/2" TBG IN THE DERRICK. RIGGED UP HYDROTEST AND RIH TESTING TO 4500 PSI. CONT'D TO RUN DUAL TUBING STRINGS AND TEST TO 4500 PS! WITH THE BPV'S IN PLACE LANDED THE DUAL HANGERS AND TESTED TO 4500 PSI, OK. DATE 04/15/91 04/16/91 04/17/91 04/18/91 MW 68 68.2 ETD PLATFORM BRUCE WELL AFE #311577 COMMENTS PAGE 9 10492' REMOVED PITCHER NIPPLE, FLOW LINE AND BOPE. INSTALLED 10", 5000# DUAL SEAL FLANGE. PRESSURE TESTED THE HANGER/SEAL FLANGE TO 5000 PSI FOR 15 MINUTES. INSTALLED THE DUAL 3-1/8" 5000 PSI FMC AND DUAL 3-1/8" 5000 PSI CIW OFFSET TREE VALVES. PRESSURE TESTED THE TREE TO 5000 PSI FOR 15 MINUTES. PULLED THE 2-WAY CHECKS. BUILT FLOW LINES. 10492' FINISHED INSTALLING PRODUCTION FLOW LINES AND TESTED TO 3400 PSI. CHANGED THE WELL OVER FROM 9.1 PPG BRINE TO POWER OIL TAKING THE BRINE RETURNS TO THE MUD PITS. PUMPED DOWN THE 2-1/2" STANDING VALVE. CIRC WITH POWER OIL. TESTED THE STANDING VALVE AND TUBING TO 2500 PSI. PUMPED DOWN THE "D" PUMP. THE PUMP DID NOT SEAT BUT PRESSURED UP THE LONG STRING. RIGGED UP WIRELINE. TAGGED THE TOP OF THE PUMP AT 9447' WLM (BOTTOM AT 9470'). RETRIEVED THE PUMP, NO INDICATION OF DAMAGE. REMOVED THE CUPS AND PUMPED THE "D" PUMP, SAME RESULT. TAGGED THE PUMP AT 9435' (BO3-rOM AT 9459'). NEITHER PUMP HAD ANY OVERPULL WHEN RETRIEVED. USED 3500 PSI WHEN PUMPING THE PUMPS. 10492' FINISHED POOH WITH THE "D" PUMP. MADE UP A 2-1/2" TYPE "A" PUMP WITH AN UPPER REDUCED ADAPTER 7'-4" X 1.88" OD. O.A. PUMP LENGTH 24.10'. RAN WITHOUT SEAL RINGS, ONLY 1-0-RING ON TOP AND PUMPED DOWN, SAME RESULT. TAGGED THE PUMP TOP AT 9440' (BOTTOM AT 9464'). POOH WITH PUMP, NO MARKS NO DAMAGE. RIH AND RETRIEVED THE STANDING VALVE. RAN A 2.34" GAUGE RING, OK. DISPLACED THE WELL WITH 9.1 PPG BRINE WITH 318 BBLS DISPLACED PRODUCTION COULD NOT TAKE ANY MORE OIL. 6 HRS WAITING TO PROCESS OIL. FINISHED DISPLACING WELL. WELL STABLE. INSTALLED BPV IN L.S. 2 WAY CHECK IN S.S. 10492' REMOVED TREE. INSTALLED BOPE. TESTED DOOR SEALS TO 3000 PSI. PULLED HANGERS. PULLED BPV'S. REMOVED 2.09' PUP FROM L.S. PICKED UP THE L.S. TO 20,000 LBS OVER PULL. EVENED OUT THE HANGERS AND LANDED. DROPPED THE STANDING VALVE. TESTED BOTH STRINGS TO 2500 PSI, OK. DROPPED "D" PUMP AND PUMPED INTO PLACE. PUMP IS STROKING. PULLED PUMP. DROPPED "D" PUMP WITH CUPS. PUMPED DOWN, PUMP STROKING. RETRIEVED PUMP RETRIEVED STANDING VALVE. NOTE: L.S. WAS OVER PULLED BY 20,000 LBS. PLATFORM BRUCE WELL AFE #311577 DATE MW ECrD PAGE 10 04/19/91 04/20/91 68.2 10492' 10492' FINISHED PULLING THE STANDING VALVE. RIGGED DOWN W.L. INSTALLED BPV'S. REMOVED BOPE. INSTALLED AND TESTED TREE TO 5000 PSI, OK. DISPLACED WELL WITH POWER OIL AND TOOK RETURNS TO THE PITS. RELEASED THE WELL AT 0600 HRS. DROPPED THE STANDING VALVE. DROPPED "D" PUMP. WOULD NOT STROKE. WOULD NOT PUMP OUT OF THE HOLE. RIGGED UP OTIS, RIH AND RETRIEVED THE "D" PUMP. IT WAS DETERMINED THAT THE "D" PUMP NEEDS TO BE RE-SPACED OUT FOR THIS CAVITY. CONVERTED BACK TO A "B" PUMP. DROPPED THE "B" PUMP, WORKING. WORKED ON THE ROTARY BACK BREAK, MUD MANIFOLD. PUMPED BRINE FROM PITS TO PRODUCTION. CLEANED PITS. STRINGING NEW DRILLING LINE. 04/21/91 10492' CLEANED PITS. WORKED ON #3 PUMP LINES. INSTALLED ROTARY BACK BREAK. 04/22/91 10492' CONTINUED TO WORK ON THE #3 PUMP LINES. CHANGED OUT THE LINERS IN # 1 AND #2 FROM 5- 1/2" TO 6". WORKED ON EXTENSION FOR MUD BOXES. GLM OUT TO SHIM SKID FOR #3 MUD PUMP. PREP TO INSTALL THE DERRICK ESCAPE LADDER. 04/23/91 1O492' CONT'D TO WORK ON MUD LINES AND LANDING TO THE SHAKER ROOM. BEGAN TO INSTALL THE DERRICK LADDER AND CAGE. X-RAYED MUD LINES. ALIGNED #3 MUD PUMP. RETRIEVED PUMP AND STANDING VALVE. TAGGED SAND AT 10,198' WLM (63' BELOW THE C-8 PERFS. RIH WITH STANDING VALVE. 04/24/91 04/25/91 10198' 10198' WORKED ON STANDPIPE LINE. X-RAYED THE MUD LINES. INSTALLED #3 MUD PUMP POP OFF VALVE. ALL X-RAYS WERE OK. COMPLETED THE DERRICK LADDER CAGE. ADDED 2 BRACES ON THE LEE C. MOORE DERRICK, INSPECTED THE DERRICK GOOD. CONNECTED THE DRIVE COUPLER TO THE #3 MUD PUMP. WORKED ON MOUNTS BELOW SHAKER HOUSE. INSTALLING HANGERS AND BRACKETS FOR #3 MUD PUMP SUCTION AND DISCHARGE LINES. INSTALLING NEW STAIRS AND LANDINGS ON THE RIG. PLATFORM BRUCE WELL AFE #311577 DATE MW ETD COMMENTS PAGE 11 04/26/91 04/27/91 10198' 1O198' CLEANING AND PAINTING IN SUBBASE. CONT'D WITH GENERAL MAINTENANCE. PREPARING UOC RIG #60 FOR COLD WEATHER SHUT DOWN. RIGGED DOWN HYDRAULIC CHOKES. RIGGED DOWN CHOKE CONTROL CONSOLE, E-Z GRANT MUD SAVER, KELLY HOSE AND KELLY SPINNER HOSES. REMOVED ALL RAMS FROM BOPE. REMOVED ALL SUCTION AND DISCHARGE VALVES FROM MUD PUMPS. DRAINED ALL AIR RECEIVERS AND LINES. BLED THE PRECHARGE OFF THE BOPE. BROKE DOWN THE HOPPERS AND SHED. DRAINED ALL MUD LINES AND GREASED ALL VALVES, PUMP LINES, STAND PIPE, CHOKE MANIFOLD, MUD CROSS, BOPE, RISER AND SPOOLS. SERVICED THE DRAWWORKS, PUMP ENGINES. DRAINED THE HYDROMATIC AND ALL WATER LINES. DRAINED ALL STEAM LINES AND HEATERS. DRAINED THE DRAWWORKS FUEL TANK. UNHOOKED PUMP ENGINES FUEL TANK. INSTALLED 3" BLEEDER LINE TO #3 MUD PUMP. SHUT OFF ELECTRICAL BREAKERS. SKIDDED RIG BETWEEN LEG # 1 AND #2. RELEASED ALL CREWS ~ 0800 HRS 4/28/~1, Scientific Drilling International, Inc. 2900 Spinnaker Drive Anchorage, Alaska 99516 Finder Survey for UNOCAL Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Composite Survey 'Interpolated 100' Intervals, 100' Dogleg Severity Site Name : GPF WELL NO. 20-2 RD Site Location : GRANITE POINT FIELD KENAI PENINSULA BOROUGH COOK INLET, ALASKA BRUCE PLATFORM - POOL RIG # 150 Job Number : 45FG0491002 Latitude : 61.000 Survey Date(s) : 02-APR-91 Survey Engineer : R. Picard/ A. Kudrle Calculation Method : Radius-of-curvature Survey Depth Zero : Sensor at RKB RKB to MSL : 115 feet Proposal Direction : S 83.03 W 263.0300 Grid Correction : 0.0 Depth Measured in : feet Comments : * Finder rate gyro survey from surface to 10,493 feet. * Azmuths referenced to true north. * Surveyed 9 5/8" casing from surface to 6573 feet. * Surveyed 7" liner from 6573 feet to 10,493 feet. * Depths confirmed with CCL. * Survey intervals: 100' from surface to 2140'. 10' from 2140' to 8350' 25' from 8350' to 10,493'. RECEIVED MAY 11 t991 Alaska Oil & Gas L;ons. burrtmt~sior~ Anchorage sCIENTIFIC DRILLING INTERNATIONAL, INC. Job number : 45FG0491002 page 1 Date : 02-APR-91 Interpolated Survey, 100 'MD Intervals, uNOCAL Corporation GPF Well No. 20-2RD State Lease 18742 100' Dog-leg Severity Meas ' rd Vert. Vert. Depth Depth Sect' n 0.0 0.00 0.0 100.0 100.00 -0.1 200.0 200.00 -0.5 300.0 300.00 -0.8 Inc Deg 0.00 0.23 0.30 0.26 Azimuth Coordinates Deg Latitude Depart'r 0.00 0.00N 0.00E 62.89 0.16N 0.1E 37.37 0.46N 0.45E 35.01 0.85N 0.74E D-leg /100ft 0.00 0.23 0.14 0.04 400.0 400.00 -0.7 500.0 500.00 -0.3 600.0 599.99 -0.1 700.0 699.99 0.4 800.0 799.99 1.0 0.30 0.37 0.21 0.42 0.62 263.18 1.19N 0.54E 347.31 1.49N 0.10E 302.93 1.90N 0.18W 304.02 2.20N 0.64W 304.14 2.71N 1.39W 0.51 0.45 0.26 0.21 0.20 900.0 899.98 2.0 1000.0 999.97 3.1 1100.0 1099.96 4.2 1200.0 1199.95 5.4 1300.0 1299.94 6.3 0.83 0.73 0.80 0.79 0.59 302.71 3.40N 2.44W 301.46 4.13N 3.59W 296.07 4.77N 4.77W 286.86 5.28N 6.06W 314.58 5.89N 7.08W 0.21 0.10 0.10 0.13 0.38 1400.0 1399.94 7.1 1500.0 1499.93 8.0 1600.0 1599.92 8.9 1700.0 1699.91 9.9 1800.0 1799.90 10.9 0.75 0.62 0.87 0.89 0.93 310.91 6.68N 7.94W 297.51 7.35N 8.93W 310.31 8.07N 10.00W 319.57 9.16N 11.09W 307.57 10.25N 12.24W 0.16 0.20 0.30 0.14 0.19 1900.0 1899.88 12.1 2000.0 1999.86 13.3 2100.0 2099.73 13.6 2200.0 2199.23 11.5 2300.0 2297.92 6.7 0.90 1.67 4.00 7.32 11.09 303.41 11.18N 13.53W 335.87 12.86N 14.97W 2.13 17.67N 15.90W 9.25 27.48N 14.92W 11.71 43.20N 12.01W 0.07 1.03 2.61 3.39 3.79 2400.0 2395.26 -0.7 2500.0 2491.56 -9.6 2600.0 2587.59 -18.5 2700.0 2683.40 -27.3 2800,0 2778.93 -36.3 15.33 15.93 16.46 16.82 17.56 12.25 65.55N 7.27W 12.07 91.89N 1.60W 11.34 119.20N 4.06E 10.60 147.31N 9.51E 10.95 176.34N 15.03E 4.24 0.61 0.56 0.42 0.75 2900.0 2874.13 -45.5 3000.0 2969.11 -54.6 3100.0 3064.02 -63.4 3200.0 3159.07 -71.8 3300.0 3254.38 -79.5 18.09 18.37 18.38 17.81 17.47 10.17 206.43N 20.64E 9.47 237.25N 25.98E 9.18 268.35N 31.08E 8.08 299.05N 35.74E 7.45 329.07N 39.83E 0.58 0.35 0.09 0.66 0.39 3400.0 3349.74 -86.8 3500.0 3445.26 -93.8 3600.0 3541.00 -100.2 17.55 16.88 16.68 6.90 358.92N 43.59E 6.25 388.32N 46.98E 5.59 417 . 04N 49.96E 0.19 0.70 0.28 SCIENTIFIC DRILLING INTERNATIONAL, INC. Job number : 45FG0491002 Interpolated Survey, 100 'MD Intervals, uNoCAL Corporation G~F Well No. 20-2RD State Lease 18742 100' ~eas ' rd Vert. Vert. Inc Azimuth Depth Depth Sect' n Deg Deg 3700.0 3636.89 -106.3 16.32 5.17 3800.0 3733.05 -111.7 15.53 3.77 3900.0 3829.34 -116.6 15.76 3.12 4000.0 3925.63 -121.0 15.56 1.74 4100.0 4022.06 -124.8 15.13 0.63 page 2 Date : 02-APR-91 Dog-leg Severity Coordinates Latitude Depart'r 445.31N .52.62E 472.67N 54.76E 499.59N 56.38E 526.56N 57.53E 553.01N 58.07E D-leg /100ft 0.38 0.88 0.29 0.42 0.52 4200.0 4118.62 -128.0 15.04 359.55 4300.0 4215.23 -130.7 14.88 358.58 4400.0 4311.94 -132.9 14.58 357.61 4500.0 4408.85 -134.7 14.02 356.81 4600.0 4505.95 -136.4 13.61 357.23 579.03N 58.11E 0.29 604.84N 57.69E 0.30 630.25N 56.85E 0.39 654.92N 55.65E 0.59 678.77N 54.41E 0.42 4700.0 4603.22 -137.8 13.24 356.00 4800.0 4700.51 -139.5 13.47 358.29 4900.0 4797.37 -144.1 15.34 9.25 5000.0 4893.73 -152.8 15.67 14.86 5100.0 4990.04 -162.5 15.55 13.21 701.95N 53.03E 0.47 725.02N 51.89E 0.57 749.80N 53.52E 3.30 775.93N 59.10E 1.53 802.03N 65.62E 0.46 5200.0 5086.52 -171.4 14.94 12.41 5300.0 5183.21 -179.7 14.64 11.93 5400.0 5280.01 -187.7 14.40 11.03 5500.0 5376.92 -195.0 14.16 9.48 5600.0 5473.94 -201.4 13.88 7.17 827.67N 71.45E 0.65 852.62N 76.83E 0.32 877.20N 81.83E 0.33 901.47N 86.22E 0.46 925.44N 89.73E 0.62 5700.0 5571.03 -206.9 13.84 5.59 5800.0 5668.23 -211.3 13.34 2.12 5900.0 5765.55 -214.6 13.25 0.33 6000.0 5862.93 -217.2 13.06 359.02 6100.0 5960.44 -219.0 12.53 356.38 949.25N 92.39E 0.38 972.69N 93.97E 0.96 995.69N 94.46E 0.42 1018.44N 94.33E 0.35 1040.57N 93.44E 0.79 6200.0 6058.21 -219.9 11.73 354.34 6300.0 6156.16 -219.9 11.52 351.60 6400.0 6254.15 -218.8 11.51 348.45 6500.0 6352.18 -216.6 11.24 344.84 6600.0 6450.37 -213.2 10.62 340.69 1061.51N 91.74E 0.91 1081.51N 89.28E 0.59 1101.16N 85.82E 0.63 1120.35N 81.27E 0.76 1138.45N 75.65E 1.00 6700.0 6548.71 -208.4 10.29 334.09 6800.0 6647.12 -202.1 10.15 330.72 6900.0 6745.52 -194.7 10.41 326.36 7000.0 6843.80 -184.5 10.86 312.59 7100.0 6941.47 -168.7 13.88 297.59 1155.19N 68.68E 1.24 1170.91N 60.46E 0.61 1186.13N 51.15E 0.82 1200.12N 39.19E 2.57 1212.40N 21.71E 4.39 7200.0 7037.69 -144.6 17.61 282.79 7300.0 7132.46 -114.3 19.62 279.78 7400.0 7226.18 -80.8 21.21 278.36 7500.0 7318.92 -44.4 22.71 274.31 1221.74N 3.69W 5.45 1227.99N 34.99W 2.23 1233.49N 69.43W 1.66 1237.61N 106.58W 2.13 sCIENTIFIC DRILLING _.~TERNATIONAL, Job number : 45FG0491002 INC. page 3 Date : 02-APR-91 Interpolated Survey, 100'MD Intervals, UNOCAL Corporation GPF Well No. 20-2RD State Lease 18742 100' Dog-leg Severity Meas'rd Vert. Vert. Inc Azimuth Depth Depth Sect'n Deg Deg 7600.0 7410.44 -4.9 24.80 274.28 7700.0 7500.03 38.9 27.93 271.07 7800.0 7586.45 88.8 32.43 267.40 7900.0 7668.70 145.6 36.87 264.83 8000.0 7747.23 207.5 39.61 264.18 Coordinates Latitude 1240.63N 1242.70N 1242.03N 1238.18N 1232.25N Depart'r 146.75W 191.10W 241.34W 298.05W 359.65W D-leg /100ft 2.09 3.44 4.86 4.68 2.76 8100.0 7823.66 271.9 40.70 263.75 8200.0 7898.86 337.9 41.78 263.41 8300.0 7972.80 405.2 42.86 263.21 8400.0 8045.48 473.9 43.89 262.73 8500.0 8116.70 544.0 45.28 262.68 1225.48N 1218.10N 1210.26N 1201.85N 1192.94N 423.78W 489.28W 556.15W 624.31W 693.94W 1.13 1.11 i .08 i .08 I .39 8600.0 8188.15 614.0 43.53 263.35 8700.0 8261.96 681.5 41.31 264.04 8800.0 8338.45 745.8 38.88 264.66 8900.0 8415.86 809.1 39.67 264.32 9000.0 8492.41 873.5 40.44 264.01 1184 1177 1170 1164 1158 .43N · 02N · 68N · 60N · 06N 763.38W 830.43W 894.52W 957.53W 1021.54W 1.81 2.26 2.47 0.82 0.80 9100.0 8568.06 938.9 41.25 264 . 18 9200.0 8641.98 1006.2 43.42 264 . 09 9300.0 8714.91 1074 . 6 42 . 92 264.48 9400.0 8789.71 1140.9 40.23 265.20 9500.0 8867.57 1203.6 37.49 265.53 1151 1144 1137 1131 1126 · 33N .44N · 63N · 66N · 59N 1086.60W 1153.58W 1221.66W 1287.74W 1350.27W 0.82 2.17 0.57 2.74 2.74 9600.0 8947.97 1263.0 35 . 48 266.42 9700.0 9029.90 1320.2 34.49 267.03 9800.0 9112.95 1375.7 33.22 267.69 9900.0 9197.08 1429.6 32.22 268.27 10000.0 9282.43 1481.4 30.59 268.76 1122 1119 1116 1114 1113 .42N .14N .58N · 67N · 32N 1409.58W 1466.82W 1522.47W 1576.48W 1628.57W 2.08 1.05 1.32 i .05 I .65 10100.0 9369.25 1530.8 28.89 268.99 10200.0 9457.21 1578· 0 27 . 93 270· 39 10300.0 9545.53 1624.4 28.00 272.48 10400.0 9634.35 1669.7 26.71 272 . 59 10493.0 9717.64 1710·5 26.12 273· 28 Depth Horiz. Displ. Direction 10493.0 2169.705 300.998 1112 1112 1113 1115 1117 .34N · 09N · 26N · 30N · 41N 1678.17W 1725.74W 1772.62W 1818.52W 1859.84W 1.70 1.17 0.98 1.29 0.72 GEOLOGICAL k~ATERiALS iNYENTORY LiST '" check of~ or;li~t data ~S' it is rcceiv~.*list received date for 407, if not req, uired list as NR _~ 407 ] *c//q/~ I. ' drillinQ histo,-v I 'Sur~evl ]'"' i 'well tests ~,,Cq'core descrintio~t~(L] -: " ' 'sis dry ditch intervals ..... digital data cored intervals , core anal ,, ......... 7~ x~, - ~.c, /7'~' 7 ~ Eod_) ...... , nn 'rvnr' ' ' i nl Ik! i Ik!'~cntl*/t" LU~I , I FL ! rll'a'~ll ,lqlLl'~f/'~aLO SCALE HO. , Itu the nearest foot) linch!! i i iiiii i ii ' L S: / ~), , ~s~¢ , / , ~972 -/~ Ri 11] 1 ~ ........ ~q ..................i.......... Memorandum UNOCAL TO: John Boyle LOCATION: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION DOCUMENT TRANSMITTAL May 17, 1991 GEORGE'S COURIER FROM: Dick Stewart LOCATION: Alaska Region P. O. Box 190247 Anchorage AK 99519 Transmitting as Follows: Granite Point 18742-20RD#2 RECEIVED 1 copy of survey M/kY 1 7 1991 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL, . THANK YOU. / RECEIVED FORM 1-0003 (REV. 8-85) PRINTED IN U.S.A. MAY 1 ? t99t Alaska Oil & Gas Cons. Commission Anchorage Memorandum UNOCAL DOCUMENT TRANSMITTAL May 7, 1991 HAND DELIVERED TO= John Boyle LOCATION= 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION FROM= Dick Stewart LOCATION= Alaska Region P. O. Box 19024? Anchorage AK 99519 Transmitting as Follows: Granite Point4~2-#20RD I sepia and i bluellne as follows= Mudlog 2" Phasor Dual Induction log 5" Phasor Dual Induction log Porosity log MSFL 2" LSS 5" LSS LTD Raw Data Dipmeter ACBL GR/TL RWD/TVD RWD/MD &laska Oil & Gas Cu~'~s. t;ommission / Anchorage / Open Hole LIS Tape/Listing .... .. Two (2) boxes of washed and dried well cuttings 7020-8820 8820-10,500 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATEDI FORM I-OC03 (REV, 8-8,5) PRINTED IN U.S.A. Memorandum UNOCAL ) DOCUMENT TRANSMITTAL May 7, 1991 HAND DELIVERED TO: jOhn Boyle FROM: Dick Stewart LOCATION: 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION LOCATION: Alaska Region P. O. Box 190247 Anchorage AK 99519 Transmitting as Follows: Granite Point 18742 #20RD i sepia and I blueline as follows: · Mudlog ~ .2" Phasor Dual Induction log ~ · 5" Phasor Dual Induction log ~ __./~ .Porosity log ~ R EC E IVE D '2" LSS ~ · 5" LSS ~ .LTD Raw Data ~ ~~ ~A Ii/AY ,~ 1991 ~Dipmeter / ~ · ACBL / ,- /aska Oil & Gas Cons. Commission · GR/TL ~ Anchorage · · RWD/MD ~ Open Hole LIS Tape/Listing~ Two (2) boxes of washed and dried well cuttings 7020-8820 8820-10,500 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: DATED: FORM 1-0C03 (REV. 8-85) PRINTED IN U.S.A. FROM ADDRESS GEOR(~i~=-~ ~ ~1~ :COURIER SERVICE l 8292 344-3323 ? -.[::] 24 HOUR · CA~E NO. -' _ COURT DOCUMENTS ' SAME.: DAY $ . 24 HOUR $ ,~ :: OTHER $ TOTAL $ X ALASKA OIL AND GAS cONSERVATION COMMISSION February 15, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Gary S. Bush Regional Drilling Manager Union Oil Company of California P. O. Box 190247 Anchorage, AK 99519 Re: Granite Point Unit Well #20RD Union Oil Company of California Permit No. 91-20 Sur. Loc. 2050'FSL, 2019'FWL, Sec. 31, TllN, RllW, SM Btmhole Loc. 3124'FSL, ll9'FWL, Sec. 31, TllN, RllW, SM Dear Mr. Bush: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The commission will advise you of. those BOPE tests that it wished to witness. Sincerely,_ ~, Chairman Alaska O~and Gas ConServation Commission dlf/enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA :~rL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill ~]1 lb: Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator (UNOCAL) 5. Datum Elevation (DF or KB) 10. F~ll~da~l Po(~l. , Union Oil Company of California 107' RT above MSLfeet e ~enal 3. Address Granite Point P.O. BOX 190247, Anch., AK 99519 6;A~P--e.~,~?~gnati°n ~., 4. Location of well ,~l~c~r~aiCSrm Bruce, 2050' FST_ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2019' FWL, Sec. 31, TllN,RllW, SM Granite Point United Pac. Ins. C At top of productive interv~op C-2 3174' FSL, 8. Well nu.mber Number 1017' FWL, Sec. 31, TllN, RllW SM Well #20 RD U62-9269 At total depth MD=lO, 400' 3124' FSL 9. Approximate spud date Amount 119' ]~WT.. Se~. 31. TllN, RllW, SM Feb. 12, 1991 $200,000 12. Distance t;3 nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 119 ' feet ;reater than 200 feet 5060 10,400 & 9691 feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 72 )ofeet Maximum hole angle 430 Maximum surface 2108PsigAttotaldepth(TVO) 4361PS~g 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ~-~ ,' ~-~ /~ ~ ~ J.~-~ ~-~n 1 ~ z~r) ~n 1BRA 15R4 1230 sxs !2-.!/z 9--K/R an .q-Q~ .q~&~ 7200 3R 38 7200 7Q31 475 sxs a3_.5 N-80 Butt; W..ndow milled at 7200' R-~/; ? 29 N-80 Butt 3200 6900 6737 1040~) 9691 600 sx.s (New) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Cement plug 8053' Present well condition summary Cement retainer 8113' Total depth: measured feet Plugs (measured) true vertical 10085 feet Cement plug 8250' 9880 Cement retainer 8302' Effective depth: measured 8053 feet Junk (measured) 8650' Bad casing true vertical 7869 feet 8656' Tbg fish Casing Length Size Cemented Measured depth True Vertical depth Structural '-1544' 13-3/8" 1230 SX 1584' 1584' Conductor 8291' 9-5/8" 475 SX 8329' 8143'. Surface Intermediate 1896' 7" 450 SX ~' .~l~,,~(~0~7~,fl-% 7995'-9870' Production Liner FEB - 8 1991 Perforation depth: measured See Attachment A true vertical ~lasJG~ Oil & Gas Cons. Commission 20. Attachments Filing fee [] Property plat ~ BOP Sketch [] Diverter Sl,,~R~l~a{J~rilling program ~ Drilling fluid program [~ Time vs depth plot [] Refraction analysis [] Seabed report []- 20 AAC 25.050 requirements [] 21. I hereby certify that/t'~ foregoing is tru(.~nd correct to the best of my knowledge Signed GARY S Title REGIONAL DRILLING MANAGER Date~~G-~ Commission Use Only Permit Number I APInumber IApprovaldate ISeecoverletter ?/'-~P-<~D 50--°c~"3'"JF-"oO/'~-<~ / 07./15/91 for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required [] Yes ~No Hydrogen sulfide measures [] Yes ,,~r'No Directional survey required ~Yes [] No Required working pressure fOr DOPE []2M; [] 3M; ~ EM; [] 10M; [] 15M Other: Approved --- Commissioner the commission Date Form 10-401 Rev. 12-1-85 ~. Subn~ '!pi!cate TOP MD 8420 8690 8760 8995 9030 9355 9380 9458 9530 9570 ATTACHMENT A UNOCAL GRANITE POINT 18742 WELL NO. 20 PLATFORM BRUCE, COOK INLET, ALASKA BOTTOM TVD MD TVD INTERVAL 8233 8420 8233 1 8501 8720 8531 30 8571 8803 8837 9158 9183 9260 9331 9371 8790 8600 30 9005 8812 10 9045 8852 15 9365 9168 10 9420 9222 40 9468 9270 10 9550 9351 20 9620 9420 50 CONDITION SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN RECEIVED FEB - 8 t991 Alaska Oil & Gas Cons. Commission Anchorage BR 20-2 DRILLING PROCEDURE t · · · · · · · 10. 11. 12. 13. SKID RIG AND RIG UP ON LEG 1 SLOT 5. CIRCULATE 67 PCF DRILLING MUD. INSTALL 13-5/8" 5000# BOPE AND TEST TO 5000 PSI. POOH WITH THE EXISTING COMPLE~ION. RIH AND SET A CEMENT RETAINER AT 7500'. LAY A BALANCED CEMENT PLUG FROM 7500' TO 7300'. NOTE: IN APRIL, 1985 SEVERAL ATTEMPTS WERE MADE TO RECOVER THE BHA. THE LOWER SECTION OF THE HOLE WAS ABANDONED PENDING REDRILL OPERATIONS. MILL A WINDOW IN THE 9-5/8" CASING FROM 7200'-7260'. KICK OFF AND DRILL 8-1/2" HOLE TO 10,400' MD, 9691' TVD. RUN AND CEMENT 7" 29# LINER FROM 6900'-10,400'. RUN A CEMENT BOND LOG. CHANGE THE WELL OVER TO CLEAN FILTERED 67 PCF BRINE. PERFORATE THE C-2, C-3, C-5, C-6, C-7 & C-8 SANDS. FRACTURE STIMULATE ALL OF THE PERFORATED SANDS. 14. RUN A DUAL KOBE HYDRAULIC COMPLETION TO + 8500' MD. 15. REMOVE THE BOPE. INSTALL THE PRODUCTION TREE. 16. RELEASE THE WELL TO THE PRODUCTION. ESTIMATED 48 DAYS. P, ECEiVED FEB - 8 199l Alaska.Oil .& Gas Cons. Commission Anchorage LEG BRUCE 1, SLOT 5 13 3/8% 51.5~, J-55 0 1564' 9 5/8% 40 AND 43.5# N-80 · 8329', CUT"D W/ 475 SX I WELL # 20-2 SPUD 02/15/68 1 K.B, 107 ABOVE IdEL COMPLETION: 1. OCT 10" DUN. 3000~ TUBING HANGER · 43' 2. 3 1/2" BUTr TUBING TO 7999' 3. 3 1/2" MULE SHOE AT 8000. 4. 3 1/2" BUTT TUBING TO 108' TOP OF CEMENT AT 805:3' CEMENT RETNNER AT 8113' CEUENT PLUg F/ 8250. - 8302' CEMENT RETAINER AT 8302' 7", 32#, P-105 LINER 8179' - 10075', CM'i"D W/405 SX UAX INCLINATION 18.5 DEG ~ TAGGE~ AT 9871' CEMENT PLUG 10,028' - TD 'rD - 10,085' MD ///////// 8420. 75 SX CUT SQZ COU.APSED CASING AT 8697' C-2: 8690' - 8720' ] SQZ'D W/ 100 $X 8760' - 8790.J THEN RE-PERFORATED C-5: 8995'- 9005' 9030.- 9045' ABANDONED IN THE HOLE: LONG STRING: A. 2 7/8" CUlT 'I'BG F/8856' - 9280. B. 2 1/2" KOBE TYPE "A" CAVITY · 9280. C. 2 3/8" 8RD 'rBG F/8688' - 9280' O. 2 3/8" BUTT TBG F/9285' - 9328' C--7: 9355' - 936~ 9380' - 9420' 945W - 9468' 9530. - 9550. 9570. - 9620. RECEIVED FEB - 8 1991 Alaska Oil & Gas Cons. Commission Anchorage GRB 12/19/90 LEG BRUCE WELL # 20-2 1, SLOT 5 PROPOSED SPUD 02/15/68 ..... · II 1.3 3/8% 51.5#, J-55 O 1584'j 9 5/8", 40 AND 43.5# N-80 e 8.329', CUT'O W/ 475 SX TOP OF CEMENT AT +/- 7300' TOP OF CEMENT AT +/- 7500' TOP OF CEMENT AT 805;3' CEMENT RETAINER AT 811`3' CEMENT RETAINER AT 8.302' MAX INCLINATION 4.:7, DEG 7", `32~, P-105 UNER 8179' - 10075', cur'D W/ 405 SX FU. TAGGED AT 9871' CEMENT PLUG 10,028' - TD 'rD = 10,085' MD ...... K.B. 107 ABOVE USL L NOTE: THE KB OF THE CURRENT RIG IS 115' KOP POINT AT +/- 7200' RECEi FEB - 8 1! Alaska Oil & Gas Cons. Anchorage ED Commission 7", 29#, BUTTRESS LINER FROM 6900' - 10,400' GRB 2/3/91 PLATFORM BRUCE .DRILLING STACK PITCHER NIPPLE- 16' ID W/lO' FLOWLINE ANNULAR BOP 'NL SHAFFER' 13 5/8° 5000 PSI BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP 'NL SHAFFER' 13 5/8' 5000 PSI BX-160 ASSY WT. 16,500 LBS. MUD CROSS- 13 5/8' BORE WI4' 5000 PSI VALVES SGL,. GATE BOP 'NL SHAFFER° 13 5/8' 5000 PSI BX-160 ASSY WT. 9100 LBS. RISER 18°0D 13 5/8'5000 FLG RECEIVED FEB - 8 1991 Alaslm Oil & Gas Cons. CommTss[ot~ Anchorage LOWER RISER 11' ID W/lO' 5000 PSI FLG (RX-54) GRANITE POINT FIELD ADA 18742 WELL #20 REDRILL MUD PROGRAM MUD TYPE: FRESH WATER GEL/POLYMER MUD HOLE SIZE: 8-1/2" HOLE DEPTH: 7200'-10,400' MUD PROPERTIES: WEIGHT (LBS/CU FT) FUNNEL VISCOSITY (SEC/QT) PLASTIC VISCOSITY (CPS) YIELD POINT (#/100 FT2) API FLUID LOSS (CC) HPHT FLUID LOSS (CC) (500 PSI @ 200 DEGREES F) PH MBT (LBS/BSA) DRILLED SOLIDS (LBS/BBL) = 67-70 = 38-50 = 8-15 = 20-30 = 5-8 = 15-17 = 9.0-10.0 < 25 < 50 MILLING/METAL MUNCHING MUD PROGRAM MUD TYPE: LOW SOLIDS/NON DISPERSED/FRESH WATER GEL MUD PROPERTIES WEIGHT ( LBS/CU FT) FUNNEL VISCOSITY (SEC/QT) API FLUID LOSS = 67-70 PCF = 60-200 < 20 CC I E EIVED Alaska Oil & Gas Cons. Commission ; nchorag. BRUCE ADL 18742 WELL NO. 20 REDRILL 1-31-91 ANTICIPATED PRESSURES MAXIMUM SURFACE PRESSURE CALCULATION: MUD WEIGHT = 67 PCF = 0.465 PSI/FT. 9-5/8" WINDOW IS AT 7200' MD, 7031' TVD TOTAL DEPTH IS 10,400' MD, 9691' TVD ESTIMATED FRACTURE GRADIENT (9-5/8" SHOE) = 0.95 PSI/FT. PORE PRESSURE GRADIENT = 0.450 PSI/FT. GAS GRADIENT (ASSUME WORST CASE) = 0.0 PSI/FT. ASSUME 1/2 OF THE WELLBORE VOLUME IS GAS AND 1/2 IS MUD DURING A KICK SITUATION. MAXIMUM SURFACE PRESSURE = BTM HOLE PRESS. - HYDROSTATIC PRESS. MAXIMUM SURFACE PRESSURE = (9691 FT *0.45 PSI/FT) - 0.5 (9691 FT *0.465 PSI/FT) - 0.5 (9691 FT * 0 PSI/FT) = 2108 PSI MAXIMUM PRESSURE AT THE WINDOW: A VERY CONSERVATIVE ESTIMATE OF THE MAXIMUM PRESSURE AT THE SHOE IS THE BOTTOM HOLE PRESSURE OF 4361 PSI. (9691 *0.450 PSI/FT). THE ESTIMATED FRACTURE GRADIENT AT THE SHOE IS: 0.95 PSI/FT * 7031' FT = 6679 PSI/FT. 6679 PSI/FT IS GREATER THAN 4361 PSI/FT SHOWING THE WELLBORE PRESSURES WILL NOT EXCEED THE FRACTURE PRESSURE AT THE 9-5/8" WINDOW. RECEIVED FEB - 8 199t Alaska Oi! & Gas Cons. Commission ;Anchorage F~st B~UCE ~ PIT3 · ii iii I · Desllter Mud return ' '° ..................... · o windows frm btm W d W , Eq' in o e,,,.~, · ~ ~:~" fm~- bt' B~,~ ,nd Trap 8" 156,8 bb~ Blanked off Eq, 52.5 bbl# 57.5 bbl* · .618 bbl/in °6?? bbl/ln F~° riser 1.84 bbl/in Flow Line 6" frm degasser · · · · · · · Opoaau~ Belly gates Rumba Shaker ~ .. . Cuttings TrouAh ~ ..~ BUtterny valve . ~' .'L' ' ' . .' . ' ... Biff~~er~ ;' Pit"t~her ~, ~ ' , ~.... ~. .. -~ .. 2" Reverse out .ine rrm rig fl · · . · · · · · · · 1.9. bbt/tn . 229. bbt · 2 bbl/ln 24O bbt ~ Nud it~ Lurn-Le Top Eq 96"Frm Btu To Top Deck 1. ~4 bbt ,ualizer aM .. uallzec ~" Frn Btm ualizer Bra Eq I0n Frn Bra #2 ~ bbl/tn 240 Re.tt~rn ~rou~hs · ualizer 'Frn' Pit ~ Hud 3htppinS Line- '- ~tl! Fe~y-k't~wa 1..9 bbl/tn 229 bbl 1.5¢ 184 bb~ m Top Frm Bra :turn EIVED -- :.' · FEB' ~ tg~tl , -! Oil & Gas Cons. Commission Nud Retu~ UNOCAL DR'UCE F£~ . 8 lC91 Alaska Oil.& Gas Cons. Commission AnChorage ~ 'If" 40" .......... ~ ......... 11 lO 19 20 21 24 2~ 2& 2~ 31 Itel 1,00 4,00 L00 2,00 2.00 1.00 1.00 1.00 1.00 1,00 1.00 1,00 l.O0 L00 2.00 1,00 1.00 l.O0 1,00 1.00 2.00 1.00 1.00 1,00 2.00 5.00 ~0.00 8.00 4.00 32.00 72,00 8,00 40.00 I.OO 1,00 lescription & uiy block 4X4X~X~X3X2 4' $ll lite valve 3' 5H late valve fllnled tee 4X~ 4 uay block 3' 5d hyd-choke 3' 10Il drilled spacer ~' ~S drilled spacer 3' 51 x 2.188' BSA 3' 5A x ion x DSS 4' 5B X 4.5' OdS ~' 5H X 6.5' target fh.e 3' Sfl spool 3' 5l fig X stud X 7 .75' spool 3' ~HXIOK fl~Xstud spool ~' 5BXlOB flqXflQ ~uffer tlnk 1~' O.B.X tit.ed cross 2' 5B blind fllnse 2' SI 2' 5fl x 2-2' LPT transoitt. 0-6000 psi 1-24 APl rial IX-IS5 APl riB; stud u/2 nuts 7;8X6 1/2 stud u/2 luts I t/IX 7 1/2 stud ul 2 ,ts I 1181 7 stud u12 Ads I U4X 8 stud u Z/Buts I X 7 stud u/2 luts I 1/8 X ront view id¢ view T11N-R12W 2000 FEET _.. 3 AOL 17587 ADL 18742' 4- R E EIVED .& Gas Cons. Anchorage. 8 20.2RD 5RD1 UNOCALO .... ALASKA REGION ORANITE POINT FIELD PLATFORM BRUCE 20-2 REDRILL AFE #311577 TOP 43-44 SAND ' ,.,,...,,.,,o. I !:"; sc,,,, ! II.P. KIEl g'lO 1000' 100' tkd CHECK LIST"FOR NEW WELL PERMITS ITEM APPROVE DATE · - (2 thru 8) (8) (3) Admin//o~ , ~ 9. (9 thru13)' ~ 10. (10 and. 13) , 12. 13. (14 thru 22) (5) BOPE th: 28) '(29 thru 31) (6) Add: /~.~.'~.,qoll-~// Ceol'6gy: Eng~neerin$: rev: 01/30/89 6.011 Company .~/~)~ ~ .../ .... Lease & Well No. ~~ YES NO Is the permit fee attached ~ --- ,,, 2. Is well t~ be located in a defined pool ............................. 3., Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ..... . ...... 6. Is well to be deviated and is wellbore plat included ................ ly ' 7. Is operator the on affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ....................................... Is administrative approval needed .......................... ......... ~-- Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ... ..................................... Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~, Are necessary diagrams and descriptions of 44~ee~-T~ BOPE attached. ~ , Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. .... For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , , o ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTE~ * · ------- SCHLUMBERGER COMPANY NAME WELL NANE FIELD NAME BOROUGH TATE PI N[!~BER REFERENCE NO GRANITE pOINT "B" '18742 #20RD GRANITE POINT KENA! ASASKA 50-883o~00~2-0~ 74473 :hlumberqer A.I~SKa Computinq Center 5.,ABR-ig~~ 20~4g **** REEL HEADER **** S~RVICE NAME : EDiT DATE : 91/04/ 5 O~IGIN :FBI, C REEL NAME. : 74473 CONTINUATION # : PREVIO[]$ REEL : COMMENT : !.INOCAL,G~ANITE pOINT,GRANITg pOINT "B". **** TAPE HEADER **** S~RVICE NAME ~ EDIT DATE : 91/04/ 5 ORIGIN ~ FLIC TAPE.NAME., ~ 7.4473 C~NTINUATIO~ # : I ' PREVIOUS CO~ENT g UNOCAL,GRANITE POINT,GRANITE POINT "B" **** FILE HEADER **** F'L~ NA~E : EDIT .001 $~:~VlCE ~ FLIC V~RSION : 001~06 FILE TYPE I LO LAST FILE : 1B742 1.8742 #20ED,50"BB3-200.12-01 '#20~:D, 5o.883.2°.o 1:2-o ~ PAGE:: ******************************************************************************* ** ** SCHLUMBERGER WELL SERVICES ** ** ******************************************************************************* ******************************************************************************* COMPANY NAME: UNOCAL WELL: GRANITE POINT "B" FIELD: GRANITE POINT BOROUGH: KENAI STATE: ALASKA APl NI,!~BER: 50-883-20012-01 18742 #20RD LOCATION: 2050' FSL & 2019' FWI., SECTION: 31 TOwNsHIP: llN RANGE: 1 1W PER~ANENT DATUM: MSL ELEVATIOn: 0 LOG MEASURED FRO~ KB 115 ABOVE PERMANENT DATUM Tape verification Listing :.hlumber~er Alaska Computing Center 5-APR-1991 20:49 PAGE{ ELEVATIONS DATE LOGG~D~ ~UN C~$I~G I: KB: 115 DF: GL: 27-MAR-1991 ON~ 1044~ 10434,0 g 5/8 e DRILLER DEPTH OF 0 TO 6874 AN:D LOoGER DEPTH OF 0 TO 6875'0 TYPE FLUID IN HOLE: GENERIC #2 DENSITY: 10.3 VISCOSITY: 48 PH: g FLUID bOSSy' 6,4 MUD RESISTIVITY: ~< I.~9 ~ 60 FXLTRATE RESISTIVITY: 1,13 ~ 60 MUD CAKE RESISTIVITY: 1'78 M 60 TI~M CIRCULATION ENDED: ]/~6/!991 MAXIMUM TEMP RECORDED: 163 bOGGING DISTRICT: LOGGING~ENGINEE~: WITNEM$~ NUMBERS: DIS HB !39 SGC SA 553 SbC UA 7O AM~ 954 KENAI HAUGAARD STEWART DIC EB 86 SbS ZA 587 TCC B ! 269 FIELD R~ARKS: KB E EVATION IS B FEET HIGHER NOW THAN IT'WAS ON ORIGINAL bOGS,~ THIS ACCOUNTS FOR THE 8 FOOT DI$CREp~'NCY BETWEEN THESE bOGS AND THE ORIGINAL, THE SFLU AFTER bOG CHECK WAS OUT OF TObER. ANCE FOR RESISTIVITIES GREATER THAN 27 OHMS. THE TOOL WAS THEN RECAbIBRATED AND A SECTION OF THE HOLE WAS REbOGGED, NO DIFFERENCE WAS OBSERVED BETWEEN EITHER THE BEFORE CAbS OR THE SECTION WHICH WAS REbOGGED AND THE MAIN PASS, IT WAS CONCLUDED THAT. THE TOLERANCE ERROR H~D NOT HAD A SIGNIFICANT EFFECT ON THE MAIN LOG, DATE JOB STARTED: ~-APR-91 JOB ~FERENCE NO: 74473 bDP/ANA: $. DEES ****************************************************************************** * FILM - EDIT,O0! * {)MOCAt, rs Tape verification L~stin~ .. lumberaer Alaska ComPuting Center 5-APR-lg9! 20:4g GRANITE POINT GRANITE POINT "B" 18742 #20RD 50-883-20012-01 MAIN PASS LOG DATA FOR DTE & LSS ARE FROM FIELD FILE ~.018 ~AIN PASS LOG DATA FOR LDT, CNL, & MSFL ARE FRO~ FIELD FILE .034 DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED TOOL ~XTENSION TOOL TYPE USED NAME DIT-E ,DTE bDT ,LDT CNT'A/D/H .CNL LSS .bSS MSFb PHASO~ DUAL INDUCTION SFL LITHO DENSITY COMPENSATED NEUTRON bONG SPACED MICRO SPHERICALLY FOCUSED LATERObOG ~0,428 TO 697,5 10432 TO 66~775 10410 TO 5 I0~98 TO 6975 0404 TO 6975 PAGE~ 3 TABLE TYPE : CONS TUNI VALU DEF! TYPE CN WN SECT TOWN COU~ STAT NAT! LATI WITN PDAT EPO ADD EDF EGL T~D TDI, DrT FT FT FT FT FT FT FT FT FT UNOCAL Compan~ Name GRANIT£ POINT Field ~ame 2001~ o Serial Number 2O50' ~SL & 2019' FwL Field notation 31 11N 11W KENAI ALASKA USA STEWART 530755 MSL 0 1!5, ~15. 999.25 -999.25 10441. 10434. 104~8. 6975. GENERIC Section Townshlp Ran e County State or Prov~nce Nation Lat tude ~ono~tude With ss' Name Service Order Number Permanent datum Elevation of Perm. Da o~ Measured From 8 VE PERMANENT DATUM Elevation cZ Kelly Bu Elevation ct Derrlc~ Elevation of Ground L Total DePth - Driller Total DePth - boqqer Bottom bog Interval Top Lo~glnterval ~ Drllli Fluid Type Tape verifY, cation hlstlng :blumberger Alaska ComP~Ittng Center 5-APR-t991 20:'49 PAGES 4 DFPH DFV nFL PFST PCST BHT TUN! VALU DEFI TYPE C/C3 lO.~ Drtllin~ Fluid Densit 9 Drt~iin~ F1 id Ph F3 6 00001 Dr ~ling Loss Resist~vi~Y of ~Ud Sa ~ud~.Sampl .Temperatur OH~ DEGF 60 O~M~ i~3 Resistlvlty of mud fi OEGF 60 · Mud..Filtrate. Sample T oH~ 1,~B Resistivity of MUd Ca DEGF 60 MUd Cake Sample Tempe ~6/199~ Time Circulation Stop DEGF -999,25 surface Temperature DEGF Bottom Nole Tempe~a[u ZONE T~BLE TYPE ~ ZONE TU~i! BDEP TDEP BHT 1 WT O, O, O, TYPE : CURV DEF! DEPT Depth Channel Name. CIDP INDUCTION DEEP PHASOR CONDUCTIVITY IDPH INDUCTION DEEP PHA$OR RESISTIVITY C~P INDUCTION ~EDIUM PHASOR, C~NDUCTIVITY X~PH INDUCTION ~EDIU~ PHASOR RESISTIVITY CTLD Dee~ Induction Standard Processed Conductivity ILO Dee~ Induct~o~ Standard Processed Resistivity CIL~ ~edit]m Induction Standard Processed Conductivity IL~ ~ediu~ Induction Standard Processed Resistivity iFRF Induction Calibrated Frequency IOOF IOOF DEEP INDUCTION OU~LiTY FACTOR INOF I~OF ~ED INDUCTION DUALITY FACTOR IIRD Dee~ Induction Real I~termed~ate Conductivity IIXD Deep Induction Ouad Intermediate Conductivity IIR~ Mediu~ Induction Real Intermediate ConductiV!t¥ IIX" ~edlum Induction Quad Intermediate Conductivity nFL!! SFL Reslst~vitF (unavera~ed) SP Spontaneous Potential GR Gam~a Ray TENS Tension MTE~ ~ud Temperature MRES ~UD Resistivity HTEN Head Tension CAbS Sonic Caliper CaLl Caliper chlU:mberoer Alaska ComPuting <Tenter DEFI ''''''''';;;~'[~;''''G~ ~ .... ''''''''''''"''''''''''''''''''''''' TENS Tension MTEM .ud Temperature ~£$ MUD Resistivltv HTE~ Head Tension ~$F[., MSFL Resistivity SMIN Svnthetlc Micro:Inverse ResistiVity $~NO Svntbet c Micro , Normal Resistivity DPH! Density Porosity RHOB ~ul~ Density D~O Delta RHO PMF photoelectric Factor OI, S 0uallt¥ control of lomo spacing for bDT 085 Oualltv control on short spaclAg for bDT b$ Long Spacing Computed Count Rate (LL+DU/2) LU LongUpper 1,2 Window Count Rate (LUi+LU2) Lb Long bower. Window Count Rate LIT~ L{~thotoo Window Count. Rate $S! Short $6aclng 1 Window Count Rate 882 Short SPacing 2 Window Count Rate L$~¥ LOn~ SPacin~ High Voltage Output SSHV Short spacl, no High Voltage Loop Output SIRM Short Spacing 1~ ~ensitV LSRM bono Spacing RHOB (Uncorrected) LU~w Long UDDer ~HGB CALI Gal!Der GE Gamma Ray T~NS Tension HTEN NPHI RTN~ TNPM TNR~ NPO~ RCNT RCFT CNTC CFTC C~LI Cabs TENS ~TE~ HTE~ DT DTL TT2 TT3 TT4 ~ud Temperature ~[JO Res stivltv Head Tension Neutron Porosity Raw Thermal Neutron Ratio Thermal Neutron PorosltF Calibrated Thermal Neutron Ratio Neutron Porosity OutPut From an ~Ppl~cation Program RC~T ~CFT CNTC CFTC Gamma Rav Caliser SOnic Caliper Tension ~UD ~esistiv~t¥ ~ud Temperature ~ead Tension DELTA-T DEbTA-T bONG SPACING TRANSIT TIME TRANSIT TIME TRANSIT TIME TRANSIT TIME 4 PAGE I 5 Is Tape Yerlficatfon L~st~n~ chlumberger Alask:a Co~puting Center DEFI SP Spontaneous GR Gamma TUNS Tension MTE~ ~ud Temperature 'M~ES MUD Resistivitv HTE~ Head Tension PAGE{ ** DATA FORNAT SPEC]FICA?IO~ RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE. VA~UE ~ 66 0 2 66 0 3 73 336 4 66 5 66 6 73 7 8 68 9 65 . I~ 66 3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT MERV)CE APi APi APl AP] FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 530755 00 C!DP DTE ~MHO 530755 O0 IDPE DTE OHMM 530755 O0 CIMP DT£ M~HO 530755 00 I~P~ DTE O~M. 530755 O0 CYLD DTE M~HO 530755 00 ILO DTE OH~ 530?55 00 fib" DTE ~HO 5]0755 00 IL{ DTE OH{~ 530755 00 IFRE DTE HZ 530755 00 IDOF DTE 530755 00 I~OF DTE 530755 O0 YY~D DTE ~HO 530755 00 000 O0 0 I I I 4 6~ 0000000000 000 O0 0 i I I 4 60 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 00 0 I I I 4 68 0000000000 000 O0 0 ! I I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 i I I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I 1 1 4 68 0000000000 [$ Ta~e veriflcatlon Listina :hlumberger AlasKa Computing Center . . 5-APR.1 g~! 20:49 NAM~ SEPV IT SERVICE .PI AP! APl API E ~U~B NUMB SIZE REPR PROCESS ID ORDER # LOG: TYPE CLASS MOD B SAMP ELEM CODE CHEX] '''''''''"''''''''''''''''''''''''''I,XD D?E MM 5]0755 O 000 ~.O'' '''''''''''''''''''''''''"'''''''''''''''''0 1 1 I 4 6. 0000000000 ~×. u~ ~..o ~)OTSS oo ooo oo o i 1 1 SFb~, UT~ o... ~)O?~S 00 000 00 0 i 1 i S~ U~ ~v ~0~ 00 000 OO 0 I i 1 ~ U~ G~ $~ovss oo ooo oo o 1 1 l TENS DTE LB 530755 00 000 O0 0 1 ! I 4 ~T~ OT~ O~Gr 930755 O0 00o o0 0 1 ! ! 4 ~.~s ~ O.~M S30~SS 00 00o O0 0 1 1 1 4 HT~M DT~ LB 530755 O0 000 00 0 ! ! l. 4 ~ ~sr ~. s~o~ss oo ooo oo o ~ i 1 4 ~ .st ~. ~o?ss oo ooo oo o 1 1 1 4 G~ ~SF GAPI 530755 00 000 O0 0 i I I 4 ?e~s ~sr ~ s~o~ss oo ooo oo o ~ ~ ~ 4 MTE~ ~SF DEGF 530755 00 000 00 0 ! 1 ! 4 .~s .st o... s~oT~s oo ooo oo o ~ ~ ~ 4 .?E. ~sr ~ s~o?ss oo ooo oo o ~ ~ I 4 ~sr~ .st o.~ s~ovss oo ooo oo o i ~ i s.x~ ~sr o.~ s~ovs5 oo ooo oo o i i i s~.o .st 0~ s)0755 oo 000 oo 0 1 I i 4 oP~ ~UT ~u s~o~ss oo ooo oo o ~ ~ i ."OW LDT G/C] 530755 OO 000 00 0 1 ! 1 4 D~o ~T ~/c~ s~o755 oo ooo oo o i 1 1 4 PEF LDT 530755 00 000 O0 0 I 1 I 4 OLS LDT 530755 00 000 00 0 I i I 4 OSS LDT 530755 00 000 00 0 1 I ! 4 LS 5DT CPS 530755 00 000 00 0 ! ! ! 4 LU LDT CPS 530755 00 000 00 0 1 ! 1 4 LL bDT CPS 530755 O0 000 00 0 1 1 I 4 LITH LDT CPS 5]0755 00 000 00 0 1 ! I 4 SSi LDT CPS 530755 00 000 00 0 1 i 1 4 882 LDT CPS 530755 OO 000 00 0 I i I 4 LSHV bDT V 530755 O0 000 00 0 i 1 i 4 SSHV bDT V 530755 00 000 00 0 ~ 1 ! 4 $1RH LDT G/C3 530755 O0 000 00 0 1 1 ! 4 bSRg LDT G/C3 530755 00 000 O0 0 1 1 ~ 4 LU~H LDT G/C3 530755 00 000 00 0 ! ! 1 4 CALl LDT IN 530755 00 000 00 0 ! ! 1 4 GR LDT GAP! 530755 00 000 O0 0 ! ! 1 4 TENS LDT LB 530755 00 000 00 0 ! 1 1 4 ~TEM LDT DEGF 530755 O0 000 O0 0 1 1 I 4 MAES LDT OgMM 530755 O0 000 00 0 ~ ! I 4 HT~N [.,DT L~ 530755 00 000 00 0 1 ! ! 4 NP.! CNL PU 530755 O0 000 00 0 1 1 1 4 RTN~ C~L 530755 00 000 O0 0 1 1 1 4 TNP~ CNL PU 530755 00 000 00 0 ! 1 1 4 TNR~ CNL 530755 O0 000 00 0 ! 1 1 4 NPO~ CNL PU 530755 O0 000 00 0 i 1 ! 4 RCNT CNL CPS 530755 00 000 00 0 1 I 1 4 RCFT CNL CPS 530755 00 000 O0 0 1 1 I 4 CNTC CNL CPS 530755 00 000 00 0 1 ! 1 4 O000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 00000~00000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0O00000000 IS Tame Verification List, ino chlt~mberger Alaska COmput. lnQ Center 5-A. PR-1991 20:49 PA~E~ NAMF [INIT SERVICE API &PI AP API Fl]bE NUMB NUMB SIZE P R PROC" ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 I 1 i 4 68 0000000000 GR CNL GAPI 530755 CibI CNI, IN 530755 O0 Cabs CNL IN 530755 O0 T~N~ CNL LB 530755 O0 ~8 CNL OHM~ 530755 O0 MTE~ CNL DEGF 530755 O0 HT~N CNL LB 530755 O0 DT LS8 US/F 530755 O0 DTb LSG US/F 530755 O0 TT1 LSS lis 530755 O0 TT2 LSS US 530755 O0 TT3 LS$ US 530755 O0 TT4 LSS US 530755 00 8P LSS ~V 530755 O0 G~ LS$ GAPI 530755 O0 TENS LSS LB 530755 O0 MTEM 5SS DEGF 530755 O0 M~S LS8 OHMM 530755 O0 ~TEN LS8 LB 530755 O0 ooo oo o 1 1 ~ ~ t.oooooooooo ooo oo o ~ ~ ~ ~ 6~oooooooooo ooo oo o ~ ~ ~ ~ 6~oooooooooo ooo oo o ~ ~ ~ ~ ~ oooooooooo ooo oo o ~ ~ ~ 4 ~ oooooooooo ooo oo o ~ ~ ~ ~ ~ oooooooooo ooo oo o ~ ~ ~ 4 6~oooooooooo ooo oo o ~ ~ ~ ~ ~ oooooooooo ooo oo o ~ 1 ~.4 ~ oooooooooo 000 O0 0 I ~ ! 4 680000000000 ooo oo o ~ ~ ~ 4 6~oooooooooo ooo oo o ~ ~ ~ 4 ~ oooooooooo ooo oo o ~ ~ ~ ~ ~ oooooooooo ooo oo o ~ 1 i 4 ~ oooooooooo ooo oo o ~ ~ ~ 4 ~ oooooooooo ooo oo o ~ ~ ~ 4 6~oooooooooo ooo oo o ~ ~ ~ 4 ~ oooooooooo 000 O0 0 ~ ! I 4 680000000000 DEPT.. I~PHDT~ Iin~,DT~ SFL .DTE MTE~.DTE CALI,MSF SMNO,MSF PEF,LDT LU.LDT $S~,LDT TENS,bDT NPHI,CNL MPOP.CNL CFTC.CN5 TEN$.CN5 DT LS$ TT3iLSS TENS LSS DEPT. IMP~,DTE ILM*DTE 10504 000 27 859 27 047 281 !62 875 -999 250 -999250 -999 250 -999250 -999 250 -999 250 -999 250 -999,290 -999,250 -999,~50 -999,250 -999,250 7!,250 977,000 3595,000 10500 000 27i859 27 047 25,281 CIDP'DTE CILD,DTE IF~E,DTE IIXD,DTE SP,DTE MRES,DTE G~,MSF ~TEN'MSF DPHI,LDT OL$,LDT LL.LDT LSHV,LDT LURH,b~T ~TE~,LDT RTNR.CNL RCNT.CNL G~'CN5 MRES. CNL DTI, eL$S TT4.LSS MTE~,LSS CIDP.DTE ClLD,DTE IFRE,DTE IIXD.DTE O0 _ 000 '999 50 -999 ~50 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 -999 250 -999 250 -999 250 70 75O 843 500 162 875 26,500 7,797 0.000 -0,307 XDPH, DTE ILD:DTE ID~Fi. DTE GR,DTE HTEN DTE TENS MSF MSFL:MSF RHOB=LDT OSS bDT' LITHLDT SSHV.~bDT CALX,bDT MRES,LDT TNPH,CNL RCFT,CNL CASI.CNb MTEM.CN5 TT1,LSS SP,bSS M~ES,SSS IDPH,DTE ILD,DTE IDOF,DTE IXRM,DTE 37 - 99 m999 '999 '999. -999: -999~ -999: -999: -999 -999- -999 -999 -999 827 0 g6g CXbM.DTE 000 .,1~ 'IMQF,DTE TENS,DTE MTEM,MSF :~50 DRHOi bDT 50 L$~bDT 250 SSl, SDT 250 SlRH bDT 250 GR, bDT 250 MTEN bDT 250 TNRA CNL 25O CNTC CNb 250 CAbS CNb ~50 500 TT2.LS$ ,~72 352 MTEN.LS$ 37.719 ClMP'.DTE 35.969 ClLN,DTE 3'000 IMOF.DTE 35,"125 IIXM.DTE 000 3595 '9992150 '999 250 -999 250 ~999 -999 -999 -999250 -999,250 -999250 -999 250 -999 250 -999 250 -999 250 69{ 000 10 188 -199 750 36,938 2,000 6,723 I'S TaUer~eri~lcatio~ [,istln.ci chlumbe er Alasga ¢omputlnO Center SFLU.DTE MTEM'DTE S~NO.~SF PEF.LDT LU.LDT bSRH.LDT T~N$.LDT NPHI'CN5 NPO~,CNL CFTC,CML T~NS.CNL DT,LS$ TT],LSS TEN$,LSS DEPT, IMPM,DTE SFL?'DTE ~TE~.DTE ~ES,MSF S~O.MSF PEF.LDT SLU LDT LS~.LDT T~NS'LDT NPNI.CNL NPOR CML CFTC[CNb TMNS CNL DT,LS$ TT~,LSS DEPT. IMPM.DT~ {b~.DTE SFLU.DTE MTE~.~TE CALI PEF*LDT bU,LDT $S?.LDT LMmH.LDT TENS.bDT N~WI,CNL 33.781 .!6~,875 .999.250 999,~250 -999,250 -999',.250 -999.~50 -999,250 -999~250 -999~250 :999,~50 999,~50 -999,250 71'250 977'000 4280;000 10400 000 !8 703 44 344 ~3 344 162 875 0 325 4 020 3 885 242500 2~4 750 2 496 7445 000 18 546 18 769 2028 216 7445.000 71..250 977,000 6525.000 10300.000 46:875 9906 0:016 56.938 163,000 8.664 0.328 3,230 2'582 4~4,250 331.750 2,154 7035.000 58.290 SP DTE ~.? M R E$~ D T .~ GE MSF HTE~ .~SF DPHI bDT LL LDT LSHV= LDT LURH~ LDT NTE~ bDT RTNR.CNL RCNT.CNL GR* CNb DTL~SS TT4. LSS ~T~ ~ USS CIDP~ DTE CILD. DTE IFEE DTE IIXD DTE SP DTE MRES DTE G~ HTEN MSF DPHI bDT Lb bDT~ LSHV LDT LURM LDT ~TEM bDT RTNR CNL RCNT ~,CN5 DTb,LSS TT4, bSS MTE~,LSS CIDP,DTE CILD,DTE IiX DIE SP.DTE MRES. DTE GR,MSF DPNI,LDT OLS,LDT bL, LDT bSHV'LDT bUSH, LDT ~TEM LDT RTNR:CNL -22.141 GR"D?E . 0'352 HTEN:~:DTE 999'250 TENS MSF -~99"2~0 EMOB LDT :999,2:50 OS$ ;bDT ',99g'2~0 LXTH : DT 999~0 S~HV.~DT -999,.250 :999'250 999.250 TNPH'¢N5 -999,~50 -999, 50 -999,,}50 NTE~,,CN5 70' 843,150 TTi,LSS' O0 162,875 MRES.bSS 46,531 48~:3!3' ILD:: 20.000 DTE 0 55 3 126 134i 165 t 3843 127 0 7! 842 162 352 438 000 00o 000 2~0 914 937 438 325 000 500 875 HTEN TENS RHOB: OSS 8,141 .000 1.619 7 750 88 0 o 715 0,019 246.750 1343.000 2 172 165i875 4 324 DTE DTE DTE 'bDT :bDT bDT SSHV bDT CAb! bDT MRES bDT': TNPH CML RCF? CNL CAb! CNL MTEM CNL TT! bSS SP GSS MRES bSS IDPH DTE ILD DTE XR~ DTE ,DTE ~,DTE HTE~ DTE TEN~ ~F ~$F~ ~$F ~OB,~DT QSSbDT LXTH bDT SSHV bDT C~L! bDT TNPH,CNL :999"R50 :999'250 SMIN.,~SF 999 250 DRHO'~DT -999 250 bS'LDT -999 2S0 $$1,bDT -999 2S0 .S!RH,bDT 99.~250 .GE.bDT -9 .,250 CNTC.CNL -999.250 CAbS,C~b -999.;250 HTEN,CNb 827.500 -22,i41 GR'bS8 0'352 HTEN,LSS 21 469 88 2g: oo TE 49 625 ZIXM DTE llO:: 38 'TENS DTE 604,~00 C~bS. 7445~000 585 DEMO bDT 0~023 5SSDT 56:688 SSt bDT 1444,000 $1RH bDT ~398 GR bDT 0.325 HTEN bDT 19,588 TNRR.CNL 18~,5~2 CNTC"CNb 8,398 CALS'CNb 165,250 HTEN.CNL 826,500 TT2,LSS 3'~9 GR,LSS 0,352 HTEN,LS8 0 31 606 7035 2! 2 -0 [36 1440 8 0 59 500 CINP'DTE 313 CXLM.DTE 000 IMQF,DTE 781 IIXM.DTE 'A~5 TENS.DTE 0 CALS.NSF 000 160 DRHO~ bDT 021 bS bDT 750 SSi bDT 000 $1RH bDT 664 GR bDT 328 HTEN bDT 455 TNRA CML 2so OoO -999.250 -999250 -999 0 '999: 0 "999 250 :"999250 ':'999 250 -999 250 '999 250 '-999 250 "999 ~ 0 ooo -194 875 52 0 000 65.2~ 289 165 250 2 397 224,250 1055. 0 405496* i36 8 289 1055.000 693 000 1i0 938 604 500 33 406 0 000 2 527 6020 000 8 46i 165 87 t 733 0 O04 453 750 220 000 2 79 750 889 500 4,336 Alaska Computing Center 5-APR-199! 20549 1958 996 CfT.C. CFTC,C....L 436729 GR:CNL 79: 0 CALI CN5 o .ooo TT3.LSS 1349,000 TTb.bSS 1207, O0 T~N$.bS$ 6020.000 ~TEM.LSS 163.000 MRES,LSS 10200 000 22 .~59 24 78 5! 406 26000 162 125 9 617 0 333 6500 4 7~ 25 250 2547 7185 000 16 918 7185 000 65750 948000 5955 000 CIDP.DTE ClLD.DTE IF~E.DTE IIXD DTE SP DTE ~RES DTE GR ~SF HTEN ~SF DP~I 5DT ObS.,bDT Lb. LDT LSHV bDT LURH bDT MTEM bDT ~TNR CNb RCNT CML GR CN5 ~RES CN5 DTL!LSS TT4 LSS ~TEM DEPT. !N'PH.DTE IL~"DTE II~D DT~ ~TE~ DTE SMNO,MSF PEF.LDT SSz bDT LSRH bDT T~N$ bDT NPH! CNL ~POR CNL CFTC TENS CNL DT TT3 [.SS T~NS 10100,000 33,375 32 8 ,2 43 13 8.375 329 2 438 265 500 281.250 2,428 6595,000 16,351 17,027 2715,501 6595.000 70,000 958,500 6135,000 CIDP.DTE CILD'DTE IFPE.DTE I!XD.DTE SP.DTE MRE$.DTE GR,~SF HTEM,MSF DPHI.bDT O~S. LDT LL.LOT LSHV,LDT t..U~H,LDT MTE~,LDT RTN~,CNL RCNT.CNL GR,CN~ MRES.CNL DTL.LSS TTb. LSS NTE~.LSS DEPT. IMPH,DTE YLP,DTE ITRD.DTE SFLU.DTE NTE~ DTE CALi~$F MAES,NSF SMNO.MSF PEW.bDT LU bDT 8S~ bDT LSR~ LDT TENS LDT NP~! CNL NPO~.CNL CFTC.CNL TENS.CNL DT.LSS TT3.LSS TENS'L$S 10000.000 21.547 21156 CIDP.DTE ClLD.DTE IFPE,DTE TIXD.DTE DFPT, IMP!-I. DTE TL~ DTE 50.219 54,~I9 20, ~0 447 3 625 o ~45 62 94 997500 2 263 0,010 1116,438 47'000 2,564 165,000 358A!964393 62 094 0 , 80~,000 162,125 IDPH DTE ILD.DTE IDOF~DTE IIRM:,DTE GR,,DTE HT~N~DTE TENS MMF MSFb MSF RMOB bDT OSS bDT bITH bDT SSHV bDT CALI bDT MRES bDT TNPH CNL RCFT CNb CAb! MTEM MRES,L$$ 3.594 IDPM DTE 20,000 IDOF.DTE 0,733 IIRM*DTE -52.500 GR,.DTE 0 343 45 656 79 II 500 32O 0 1346 000 2 439 164 5 4481097 456)6 0,3 9 70.250 818,000 161,125 HTEN,OTE TENS,MSF MSFh,MSF RHOBbDT OSS:bDT LXTH,bDT SSHV,LDT CALl*bDT MRES DT TNPH:~NL RCFT,CNb CALI,CNb MTEM,CNL TTI,bSS SP,LSS NRES.bSS 44,438 47.031 20,000 2.365 IDPH,DTE ILD,DTE IDOF,DTE IIRM.DTE 437 Oli CNTC CNL 8 664 CAbS CNL 165 875 HTEN CNL 1200 000 TT2 LSS 7250 GR LS8 0 341 HTE~.LSS 19 906 CI~P DTE 18 438 CIb, DTE 0 00:0 INQF DTE 594,000 CAbS NSF 7185 000 N. TEM MSF 107 000 SM'IN NSF 2 613 DRHO bDT 0 037 b8 bDT 47 9.06 8Sl bDT 1444~,000 SIRH bDT 617 GR bDT 18 T'NRA CNL 1680 2~3 CNTC CNL 9 617 CA. LS CNL 165 000 HTEN CNb 806 ,000 TT2 3 625 GR LSS 0345 HTEN 29 734 ClMP,DTE 29 031 ClLM,DTE 0000 IMOF,DTE 29 438 IlXM,DTE 46094 TENS,DTE ooo 65 000 MTEM,MSF 36 875 SMIN,MSF 2 430 DRHO,LDT 0 001 LB,bDT 84 313 881,bDT 1440 000 81RH.bDT 8 375 GR,LDT 0 329 HTEN,LDT 16 772 TNRA.,CNL 2427 CNTC,CNL CALS.C~L ,125 8.375 164.125 HTEN,CNb 817,000 TT2,LSS -5~.500 GR.b$S .343 HTEN.LSS 22.500 CINP.DTE 21,250 CILM.DTE 0.000 IMOF,DTE 44,875 II×M.DTE PAGE { 10 1909 598 8 461 889 5O0 1000 000 77 125 606 000 43 719 41 500 0 000 0oo 165 ~ 475 0 064 O0 226 ~0 214 0 6] 402 O94 997 500 3691 9583 997500 65250O 59 594000 ]9,92~ 0,95 0 000 4 672 6135 000 8 234 164 t~5 5 617 0 OO2 ~ ?$o 2 418 45 656 796500 1 819 4909 380 8 234 796 500 675 500 46 094 615 000 46,~75 , 19 4~,000 6,441 :hlumberqerA. laska ComPutinG Center 8FLU-DTE CAbI,~SF PE~2~T LU'LDT SS~bDT LSRH.~LDT TENS,LDT NPH~.CMb NPOR,CML TENS'CML DT'LS$ TT3,LSS T~NS,LSS IMPM.D"'E IL{iDTE MTE~,DTE MRES,MSF PEF.LDT bU,LDT SS~ LDT LSRH LDT T~NS LDT NPHT CNI, NPO~ CFTC"CNb DT,LSS TT3,LS$ TENM,LSS DEPT, I~PM,DTE ]b~,DTE IIRD,DTE SFLU,DTE MTE~'DTE C~LI,~SF PEF,bDT LU bDT SS~:LDT LSRM.LDT TMN$,LDT NPHI.CNL 26 828 160 500 $ 664 0 333 6 301 3 504 220 000 270 750 257~ 6495 000 23 772 ~3 278 494 689 ,ooo 68.5oo 3 ,,250 . g.ooo 19 891 45 ~9 047 159 500 8 813 0 339 ! 3 3 ~ 14 217 75 273 000 2 566 6645 000 2~.801 '20,727 t787'971 66452000 "59,93~ 277,000 5660,000 9800.000 115.938 !03.563 6.848 118,375 159.250 8.375 0.3.36 2,86) 3.371 199,625 259,250 ~,617 6545.000 13,677 SP,DTE MRES,DTE GR,MSF HTMN,MSF DPHI,LDT QL$,LDT Lb.bDT LS~V,LDT LURH~bDT MTEM,bDT RTNR,CNL RCNT,CNb GR.'CNL ~RES;C~b DTLLS$ TT4:bSM STEM,LMM CiDP.DTE CILD~DTE IFRE DTE IIXD DTE SP DTE NRES DTE GR HTE~ NSF DPHI bDT ~L$ bDT Lb bDT LSMV bDT bURH bDT MTEMLDT RTNR.CNL RCNT CNL GRCNL MRES. CNb DTL,bSS TT4*bSS MTEM.LSS CIDP.DTE CILD,DTE IFRE,DTE IIXD.DTE SP,DTE MRES.DTE GR.MSF HTEN,~SF DPHI.bDT QLS.LDT LL.LDT bSHV,LDT LUSH.bDT MTEM,LDT ~TNR.CNL 96 3 2.~16 -0 038 109 63 ~347 ~00 zs2o ,2 09~ 96 31~ 0 333 68 250 764 000 160 500 46,1}6 49'375 20,000 -0,122 -15.1~8 0.353 89'188 839,000 2,020 '0,006 112,625 !347,000 2,572 162,625 2,148 3508'8{2 89,I88 0,339 67,125 780,000 159,500 7 9 20 000 -0 112 -102 688 o 349 ~0i719 789 000 1,910 0.022 {04.563 ~346.000 2.633 !61.750 1,712 GR,:DTE TENSeMSF NSFL,MSF RHOB.~bDT QMS,bDT LiTH'bDT :SSHV,.LDT CAbI,LDT MRE$'bDT TNPH.CNb ~CFT. CNb CAbI~,CNb STEM CNb TT1 bS$ SP bSS ~EES 5SS IDPR DTE ILD DTE IDQF DTE IIR~ DTE, GR DTE HTEN DTE TENS ~SF MSFL NSF RHOB bDT 0S$ bDT LITH :bDT SSHV LOT CAb! bDT MREM bDT TNPH.CNL RCFT.CNL CALI,,CNL NTEM.CNL TTILSS SP. bSS MRE8 IDPH,DTE ILD,OTE IDQF,DTE IIRM.DTE GR'DTE HTEN.DTE TENS,NSF ~SFL NSF RHOB bDT O$$ bDT LITH bDT SSHV bDT CAb! LDT MRE$ bDT TNPH,CNL .563 TENS 63.~,000 64~.5.000 CAbS ,:594 '61~ 664 DTE NSF LDT bDT /5DT ,LDT 0 2 4 t 412 · 0 MTEN~,bDT TNRA~CNL i:~i CNTC,CNb 664 CA. LS,CNL .875 HTEN.,CNb 52 GR.'tS8 350 HTEN,b$$ 2! 656 ooo 9! ~50 TENS'DTE 584 000 645 000 6 3~ 344 61.7 DRHO,LDT 0 022 ,,LS'LDT 1453 781 $S%,LDT 4~_000 $1RH,BDT 39 HTENBDT 16~1,~14 TNRA,CNb i . CALS,CNb 5 148 GR,LSS 0:3S3 HTBN,LS8 191.625 13~'250 9: 00° 195 579 6545 0 46 1441 8 0 ClMP.DTE CILM,DTE IMOF,DT£ IXXM,DTE 688 TENS.DTE 500 CRBS.~SF 000 MTE~,MSF 250 SMIN.MMF 0 DRHO,LDT ~0 bM,LOT 688 SSi.bDT 000 SIRH.LDT 375 GR.LDT 336 HTEN.LDT 013 TNRA.CNb PAGE{ s. s ooO 8 484 163 875 4 004 0 041 219 000 · 207 000 2 467 9 313 94~ 500 2 338 3687, 860 8 484 948 500 642 500 83 0563 619 O0 45, 5 o.½ o 0:000 3.918 566~ 000 680 162 625 49 ,oo 209 375 2 449 89 188 839 000 ,8 680 839 000 643 500 91 250 584 000 8,617 161 750 1 301 0 012 204 375 ~96 500 2 566 40 719 789 000 1 641 chlumberger Alaska Computing Center CFTC.CN5 3484, ~ T~NS.CNL 6545.000 DT'LSS 62.625 TI3 LSS 87 500 o DEPT, ,DIE SFbU · DIE CAb! ' NSF ~E$, NSF PEF, LDT b U, L D T SS2 ,bDT LSRM. bDT TMNS. bDT N'PH Y. ' CN t. NPOR ~C~-~L CFTC,CN5 · om. USS TT 3, LS5 TENS.LSS DEPT I{PH.:DTE iL~.DTE IIRD.DTE SFL!.!.OTE NTEM.DTE C~LI.~SF M~ES.~SF SMNO.NM? PEF.LDT LU.LDT SSa.bDT 5~RN,LDT T~N$.LDT NPHY.CNL CFTC TEN$.CN5 DT.L$S TT3.LSS T~N$,LSS D~PT. IL~.DTE IIRD.DTE 9700 000 ~. ' 33.969 23.438 15~:500523 0,343 3,342 5,480 2~8,375 28350O 2 533 6335 o00 1778 287 6315 000 70 375 930 000 5720 000 9600000 100000 81438 10992 98563 357625 72;7 0340 2920 8242 542000 396,750 2,000 6395.000 14.757 13.887 3184,930 6395,000 64.$75 902 500 6110:000 950O.0OO 24.953 24 185 35:1~5 RC~T.CNL DTL'LSS TT4,LSS ~T~'hSS CIDP.DTE CILD.DTE IFRE.DTE IIXD,DTE S.P,DTE ~RES,DTE GA*NSF MIEN*NSF DPHI, LDT OLS bDT LL bDT LSHV bDT bURH bDT ~TEN bDT 9TNR CNL RCNT CNL G~ CNL ~RES CNL TT4 LSS MTE~ LSS CID,,DIE CIL .DIE IF~E.DTE iIXD..DTE SP..DTE MRES, DTE GR.NSF HTEN.MSF DPHI,LDT QLS.LDT LI,.LDT LSHV,LDT LURH.LDT NTEM,LDT RTN~.CNL RCNT.CNL GR.CNb MRES.CNb DTL.LSS TT4,LSS ~TEN.LSS CIDP,DTE CILD.DTE IFRE.DTE IIXD.~TE 5-APR-.199! 20:49 ~8!o 0 ~06 62 o 732 500 159250 37 5 20000 '0356 71188 785 500 -! 222 -0034 11481] 1347000 2 539 160 750 333~ 42 71 ~88 o 70 875 79O 000 1575O0 9,648 20,000 ° -'92 8 4~ ~]68 -o o3~ 305 250 !345,000 2.02! 360,500 449~ '66! ,266 45,438 0.340 64,125 767.500 157,625 35,969 38,563 20,000 0,853 RCFT CNL CALl CNL TI'! LSS SP LSS NAgS 5SS IDPH DIE ILD DTE IDOF DIE I.IRN DIE GR DIE HTEN DIE TENS MSF ~SF5 MSF AMOS bDT OSS bDT 5ITH bDT SSHV bDT CALI. bDT MRES~L'DT TNPH CN~ RCFT CNL CALl CNL MTE~ CN5 TTi LSS SP LSS MRES LSS IDPH,DTE IL~,DTE ILO .DIE IlR~..DTE GR,DTE MIEN,DIE TENS.NSF NSFL,MSF RHOB,LDT OSS'LDT LXTH,LDT SSH'V'bDT CALl.bDT MRES,bDT TNPH,CNL RCFT.CNL CAL!.,CNL MTEM,CNL TT1.LSS SP.LSS MRES'LSS IDPH,DTE XLD.DTE IDOF,DTE 3054 43I CNTC CNL 8 375 CAbS CNL ~ 750 ,TEN CNb 000 TT2 LSS -i02688 GR LS8 0349 HTE'N.bSS 27 .~6473 CI~P.DTE CIL~ DT.E 2~ O00 I{OF DIE 42 64 633 o o 160 792 -85 0 TENS DiE 500 CALS NSF 000 M'TEM,MSF 5 SSl..LDT 000 SiRH,LDT 523 GA.bDT 343 MT~N bDT 593 TNRA:CNL 955 CNTC,CN5 523 CALS,CNL ~50 HTEN,C~L O00 TT~,LSS 813 G~,LSS .356 HTEN.LS$ 103 563 CXNP.DTE 84 813 CILM,DTE 000 IMOF.,DTE · 688 II'XM.DIE 438 TENS.DIE 000 CAbS.NSF O00 NTEM,MSF ':375 SMIN.MSF 23 DRHO,LDT i008 LS,LDT 438 SSl.LDT 000 SIRS.BDT ~27 GR.LDT -340 MTEN.LDT 314 TNRA.CNL 509 CNTC.CNL 227 C~LS.CNL 500 HTEN,CNL 000 TT2,LS8 i88 GR.LS8 356 HTEN.LSS 0 4 658 6395 9O .2 -0 94 1439 7 O 13 282~ 160 765 ,,92 0 27.797 CINPoDTE 25,906 ClLM.DTE 0.000 IMOF;DTE 39.281 IIXM.DTE 5397 33 8 02~ 789 000 596 500 41688 579 500 45.625 44344 0 000 -1821 5720000 8 633 160 75O !:961 0.!36 29,000 34'625 785,,~08 0 2;30 3916,49~ 8,633 785,500 656,500 64,22 605.50~ 9 992 !2 273 0.000 -12 602 6210 000 8023 o ~2 263750 ! 8 927000 1 631 4999 624 8023 927 000 63O 500 42 438 658:000 40,03! 41,333 0,000 3,826 r~s ?a~e verificatlon Listinq :hlUmberqer~.lasl<a ComPUti. n~ Center 5-APR-Igg! 20:4g PAnEl 13 SFbU DTE NTE~ OTE CAL! NSF P~F,LDT LU,LDT S~2,LDT TENS,bDT NPH~,CNL NPOR,CNL CFTC,CNL TENS,C~L D?.LSS TT3'LSS TENS~LSS DEPT', I~PM.DTE 6FLU DTE CALT.MSF P~,LDT _(~U. bDT sS~'LDT TENS.LDT NPHI.CNL NPOR'CNL CFTC.C~5 TENS.CNL DT,LSS TT].LSS DEPT. I~P~.DTE IL, DTE IIRD:DTE SFtU.DT~ NTE~.DTE CALI,MSF S~NO.MSF PEF.LDT LU,LDT $S2,LDT LSat.bDT TFNS,LDT NPH~.CNL 30,594 156,500 8.4~4 0 357 9 023 7 01~ 489 000 384 50O 2 066 6590'.000 20,559 .20"!15 ~99~"293 6590,000 953,000 5675,000 9400'000 !7;5 50;2~0 21 000 155 750 8 789 0 356 4 223 5 97~ 412 000 370 250 2 .168 6540 000 ~ 626 26 108 16~0 675 6540~000 70,500 920,000 5455.000 9300.000 17,6~5 16,625 53,500 17.203 155.250 8.523 0,357 4.125 3,895 333,000 326,000 2,285 6000.000 18.458 SP DTE ~RES DTE HT~N ~SF DPHI LDT OL$,LDT LL.LDT L$~V'LDT LUSH LDT ~TE~ LDT RTN'R CNL RCNT ~RE$.,ENB DTL:~LSS TT4.'LSS MTEM,LSS CILD.~DTE IFRE'DTE IIXD~DTE SPDTE MRESDTE G~ HTEN NSF DPHI bDT OLS bDT LL bDT LSHV bDT LURH bDT MTEN bDT RTNR CNL RCNT CNL GR CNL MRE$ CNL DTL,L$S TT4,LSS CIDP'.DTE CILD,DTE IFRE.DTE IIXD,DTE SP,DTE MRES,DTE GR.NSF HTEN,MSF DPHI,LDT OL$.LDT LL.LDT LSHV.LDT bURH bDT MTEM~LDT RTN~.CNL -56,219 938.500 0~9 12~ 250 3 000 2 078 ~59 25O 376~ I!0 179 620 406 357 7~ 625 8! 000 I56 500 GR!"DTE HTEN.,D?E TENS'~SF NSFbMSF RHOB bDT OSS bDT: LITM LDT SSHV bDT CAL] LDT MR~S bDT T~PM CNL ~CFT CNL CALl CNL MT~M,CNb '~LSS MRES,LSS~ 52,344 IDPH'DTE 55'813 ILD'DTE 20'000 IDOF'DTE . 3,512 38,906 GR'DTE: 0'368 HTEN~:DTE 78.938 TENS,NSF 500 NSFb',~SF 678 RHOB, LDT 223 875 5ITH,5DT 1344 000 SSHV~SDT 125 905 17 ,~0 352~ i91099 78 938 0.356 770,250 000 55 906 58 469 2O -61 500 0 48 969 784 000 *4 906 -0 O07 186 125 1344 000 2.299 157,500 1,943 C~LI,LDT MRES'LDT TNPH'CNL' RCFT,CN5 MTEM. TT1.LSS SP,LSS MRES,bSS IDPH.DTE ILD,DTE IDQF.,DTE IIRM.DTE GR,DTE HTEN,DTE TENS,MSF MSFL'MSF ~SS,bDT blTH'LDT SSH¥,LDT CALl,bDT MRES,5DT TNPM,CNL 614.000 CALS,,$ 6590.00 ~0 ~ T E)4, M $ F 25,875 S~IN;MSF 2 - 224 D ~ H 0 ' 5 D T 0,029 LS'LDT 95,000 SSi~*LDT 1439'000 $1RH'LDT 8'484 :0':357 HT~N'LDT 20~1249 TNRA.CNL i774'069 CNTC.CNL 8~:484 CAbS CNL 5 9':250 HTEN CNL 17,000 56'219 OR .bSS 0'$66 HTEN LSS I~ 094 .ClMP DTE 906 C'ILN DTE 0 000 IMOF:~ DTE ~ 094 IiX~'DTE .688 TEN$ 598 6540 18 0 O, 0 094 CILM,DTE 57. 584 6000 12 2 0 80 1438 8 0 17 000 CAL$ ~0 MTEM, 2 SMIN 358 DRHO 04~~ 188 SS1 000 $1~H ~89 356 HTEN 33O 975 CNTC 789 CALS 125 HTEN 000 TT2 9O6 368 HT~N MSF MSF bDT LOT bDT bDT bDT bDT CNL CNb CNL CN5 [,SS 5SS LSS 063 IIXM.DTE 938 TENS.DTE 000 CALS,MSF 000 MTEM,MSF 844 SMIN.MSF 404 D~HO LDT 049 LS LDT 125 SSi LDT 000 S1RH bDT 523 GR bDT 357 HTEN,LDT 986 TNRA,CNL 9,336 7.828 O, ~t 56 ,.ooo t; o00 t, 763 $0o 4070 918 500 55 906 000 ~ :I 72 ~$0~ 000 9 078 905 500 6~8 000 77 688 598 000 56,688 60 0 000 .4 527 5479 000 8 680 257 5O0 2 922 0 {52 500 247 !25 2 049 48 969 784 000 I 972 000' 00S'8E9 OOS'[gL OOS ISL gSO 6 ttO'[08t OOS 980 0 $60 L SSO 6 000 LO[ S 000 0 696 SS ~90~ 000'g99 O0 ,988 OSt,6£g 8T~ ~ 0000 :~9 9~ 000~8~ OOS;TOL O00,~SL 089;8 · ~O'~XlI ~N~'~N& ~Q~'N3&H ~oq OHiO 3&O ~OWI ~gq N3~H qND N3&H 9N~ qND qND ~N~ &O~ N3£H &oq OHaO 3~0 ~OWI 3~0: d~lD qND,N3~ qND,'~q~D qN33[ND 000 98S LL[' 8£6 000 t[f~ 999 69E' gL8 000 o 000 Og 69 00~~ 000 E99 ~L6 0 69- 8 L9£~ 9~ 0 0 SOlO £S 0 8[ 0 Oll- og~ ~L~ 0 8 0 SI99 £69 0 9~ 8~ '0 '~8 3&~'HdOl 9ND'W3~ 9ND'Iq~D qND"HdN~ ~Oq'iqVD ~Oq'H&Iq ~QQ'BOHB 3~q' N3£H q'ND' q qND · oq I. qVD &Oq~AHg~ £0~ H&lq &09 ~Oq BOH~ 3&O N3~H 0' 89 3&O.'HdOI qND EgE') 000!0~ SL~ ~6 SLE E6 O00'SEOI 69E'0 0 6~ 0t0 0- . 906'~S S~I ~99 OSL L~ S~O O= 000 988 ott ¥' ' 0 °OE 9t0'9g OOg [98 LS[ 0 696 8~ 6~:0~ ;66t'~d~-§ 3J.,G :qXI! 3U~I ITL'6 "OqlO 'dQID 000'0006 qND 9NO &oq '~3£~ 000:S9E~ ~q~o 93~W O00'go~9 '~D OL6'~D9~ '~J~h 000 'Hdliq gEE ~ 'AHg9 :qq 0oo'6o~ .~qO 608'E IHSO 99~'8 ~ 69£*0 8D ~L8°8 'd~IO 000 0~6 qND'UOdN qNO*iHdN £Oq*~q ~Oq"M3d 2g~*iqVO 3ZO ~qI 2&O Hd~I '£d3d ~INO 9 ND W~W O00*O£LS ggq 89 ~6g"~19~ qNO :&ND~ ~90' qND "N3Z~ 000'~199 idrl 'H~Aq ggi*~ 'AH~q 00'0~ * 'gqo ~Eg*'£ :'as ,3aMI 69~,L£ ~OqlO 69'~.6E dQID 000 :IH~N * .m'1l "&d~ qNO qNO 9ND W2~ O00*SL~S 93~ 000'0009 ~D ~L~'08S~ £ND8 ~T*B) qND 80dN OUT~STq uoT~eo~)~aA aae£ gl [~ T~e Veri~cat~o~ L~stlnq :hlumberqer aska Comput ng Center SFLU,DTE NTE~.DTE C.AL!,MSF SMNO,MSF PEFiLDT LU,LDT LSRH.LDT TENS,bDT NPHI.CNL NPOR,CNL crT¢.C.5 TENS,CN5 DT'LSS TT3,LSS TENS'LMM DEPT. I~P~'DTE IIRD'DTE SFbU'DTE MTE~DTE CAUI,MSF ~RES,~SF PEF,LDT LU,LDT SS~.bD? SRbDT EN$~LDT NPH! CNL NPOP.CNL CFTC'CML TEN~.CNL DT.LS$ TT~.LS$ TENS.LMM DFPT IL~.DTE IIRD.DTE MFLU.OTE NTE~.DTF C~LI.MSF $~NO ~SF LU.LDT SS~.LDT LSR~,LDT TENS LDT 12 48 0 35~ 3 43~ .4 406 255 750 ]I6 250 2 447 5955 000 ~6681 983. 764 5955 000 83,500 ~29! 000 5325 000 890O 000 30359 29 000 28 281 40 3~3 !52 750 ~0 273 0 369 974 000 21,999 27.747 1540,4~4 6130.000 68.875 946°500 5095.000 8800.000 19,344 18.953 46.531 19,578 151.875 !3.375 0,379 2.459 3.344 283 000 291:5oo 2,3~3 6380,000 16,794 SP.DTE NRES'DTE ~R:',~SF gTEN.MSF DPMI.LDT QLS.bDT Lb,bDT LSHV.'bDT LURH.LDT ~TEM.bDT RTNR.CNL RCNT.,CNb GR,CNb MRES,CNL DTb.,LMM TT4'LS$ MTEM'LSS CIDP'DTE CILD,DTE IFRE~DTE IIXD DTE SP DTE MRE$ DTE GR HTEN ~SF DPHI,LDT QL$,LDT LL.,LDT LSHV.,LDT LURH,LDT STEM,bDT RTNR,CNL RCNT.CNL GR..CML NRES'CNL DTL,L$$ TT4.,L$$ MTEM.LSS CIDP.DTE CILD.DTE IFRE,DTE IlXD,DTE SP.DTE MRE$,DTE GR.MSF HTEN,~SF DP~I, T OLM. LDT Lb.bDT LSMV,LDT bURH.LDT STEM.bDT RTNR.CNL 5-APR-1991 20:49 '54.688 369 10 500 841 000 2 445 o 007 139 250 134] 000 15~ 465 5OO 267~ 753 432 103 500 0 358 g*o 153 750 28, 1 o6o 287 -!1~,o0o 1 747 -000 ~22 1342 000 15~ 520 62.5 2 660 7 375~ 590 75O 0 369 70 750 ooo ! 750 48.875 51.188 20.000 1 0,385 55,313 41:ooo ! 097 1343 000 2 398 153 3 HTEN~DTE TENS~SF RROB,~DT QMS,bDT LITH'bDT SSHV'LDT CAL!,LDT MRE$*LDT TNPH,CNb RCFT,CNb CALI'CNL MTEM'CNL TTi.'LS$ SP,LSS MRES'LSS IDP~,DTE IbD::,DTE IDOF.,DTE lIES DTE GRDTE HTENDTE TENS MSF MSFL MSF RHOB bDT OhS 'LOT LITH bDT SSHV bDT CALl bDT MRES bDT TNPHCNL ~CFT CNb CALI.CNb MTEM~CNb TT1,LSS SP..'LSS MRES'LSS' IDPH,DTE ]~D.DTE IDOF.DTE IIRM'DTE GR,DTE HTEN,DTE TENS,~$F MSFL NSF RHOB bDT QMS bDT kITH LDT SSHV bDT CAb! bDT NRES,LDT TNPH.CNb 102.688 TENS'DTE 632.500 CALS.~SF 5955'~00'0 13'234 SMIN,MSF 2,610 DRHO~LDT 0'046 .Lb. bDT 57.656 $$1.LDT 1438,000 SlRH.:~LDT 10,531' GR~LDT 0,358 HTEN.iLDT 29'378TN~A~.:CNL 934'230 10~531 !55,500 HTEN CNL 1~0'3.:000 TT2 LS$ 0,369 HTEN,LS8 34,875 32.469 o,o0o 32.781 60,031 603,000 6130,000 14,930 2.621 0.053 50,750 1438~000 10'273 0.369 28,000 388'639 10,273 154.625 758,000 115.000 0.383 CI~p DT~ IMOF DTE IIXM:DTE TENSDTE CALM MSF MTEM SNIN NSF DRHO bDT bS LDT ~8i LDT SlRH bDT OR bDT HT~N bDT TNRA.CNL CNTCCNb CALS.CNL HT~N.CNL TT2,LSS GR bSS HTEN bS8 595 O0 C~LS,MSF 6380,000 MTE~,MSF 16.391 SMIN,MSF 2,417 DRHO.bDT 75 250 SS1 bDT 1437i0 000 SIRN bDT 13'375 ~ bDT 1 891 TNRa CNL s) .s ooo 10 258 15~ 500 174 0.162 ooo 248 500 · :2 ~133 5OO ooo 6 10258 841000 · 47 500 ~02 688 632 500 32 938 34 469 o o00 -1 877 5095.: 000 154 I~o~ 57 750 .887 500 35 2 4067 5OO 645 000 6~ 031 60 000 51,688 52.719 0.000 3,703 4965,000 i3,547 ~16 0,034 300,250 217,750 2.289 55 313 945:000 2,109 £S Ta~e verification Listlnq :hlumberoer .Alaska ComputlnQ Center NPO~ CNL CFTC C~ 5 TT3 LSS TENS.LS$ DEPT. I~PH.DTE !IRD.DTE SFSU'DTE PEF~LDT LU*LDT TENS.LDT NPHI.CNL NPO~.CNL CFTC.CNL TENS.CNL DT.LS$ TT3,LSS T~S;LSS DEpT i~PHiDTE !L~.DTE II~D DTE SFLU[DTE ~TE~ DTE CALI.MSF PEF.LDT LU.LDT SSg. LDT LSRN.LDT TEN$.LDT N9HI.CNL NPOR.CNL CFTC.CNL TFNS.CNL DT,LSS TT~.LSS TEN$.LSS DEPT. I~P~.DTE IL,.DTE IIRD.DTE 18 288 1940 231 6380 000 78 000 1058.000 4965,000 ,688 !1i727 0,375 244~!~5 ~87.000 2'496 5640.000 25,544 26;355 1204:;073 5640'000 71"750 1016,000 5070'000 8600.000 41 ,172 '344 !9.64~ 150 5O0 7 941 0 384 ] 469 6 320 397.250 358 000 6060,000 19,277 19.498 2110.858 o.ooo 7.688 977,000 4930.000 8500,000 7.602 7.496 114,938 9CNT.CNL GR.CNL ~ES.CNL DTL'LSS TT4'LSS ~TEM'LSS CILD:iDTE IFRE~DTE IIXD~.DTE SPDTE MRESDTE GR~SF DPHI~SDT ~L$ LDT L~ LDT LSMVLDT LURHLDT ~TEN. LDT RTNR CNL RCNT.CNL G'R'CNL DTL.LSS CIDP'DTE CILD.DTE IF~E,DTE IIXD,DTE SP..DTE MRES.,DTE HTEN.MSF DPHI.LDT OL$,LDT LL,LDT 5S~V'LDT LURH,LDT RTNR,CNL RCNT,CNL GR.CNL ~RE$.CNL DTL.L$$ TT4.L$S MTEM.L$S CIDP.DT£ CILD DTE IFRE:DTE IIXD.DTE 5-APR-1991 20:49 PAGE~ i6 67,706 3655.3t3 0,3'79 78.250 898'500 151,875 75.250 850 oo 774 2774,64 I05,87~ 869,000 151,125 44 281 45 844 2O 000 1 644 -17 188 5~ 390 219 917 000 18 195 -0 013 225 250 1342 000 .195 15 ,500 !.975 15677 3851:219 0,384 '284,750 837,000 150.500 t29.500 31,§75 120, O0 8.523 RCFT,CN5 CALI'CN5 MTEM.CNL .TT1,LSS ~RES,LSS IDP~ DTE IDQF DTE I'IR~DTE · GRDTE MTENDTE TEN$~SF :MSFL NSF RHOB,~DT O$S,,LDT 'SSHV.LDT CALI~bDT' ~RES'LDT TNPH'CNL RCFT,CN5: C~SI.CN5 ~TEM'CN5 'TTI..SSS SP,~SS XDPH,DTE ID~F,DTE IIR);DTE GR'DTE HTEN,DTB T£NS.MSF MSFL,MSF ~O~,~DT ~SS.~DT ~IT~,~DT SSHV.~DT CALI.~DT MRE$.LDT TNPH.CNL RCFT.CN5 CALI.CN5 MTEM.CN5 TTI.LSS SP,L$S ~ES,SSS IDP~.DTE ILD'DTE IDOF.DTE IIRM.DTE 1770'325 13.375 153-875 HTEN.CNL 894.500 -30,.844 . GR.'LSS 0'385 13.28i CI~P DTE ~66 .0,000 .688 .000 12 74 99 605 564~ 0 54 -27, 0 6060 0 78 1437 7 15~ 833 -17 0 C.AL$ 000 MTEM 035 578 DRHO DTE DTE DTE :DTE ~SF ~DT 037 [i$.~LDT 625 SSI,.LDT 000 St~H.~LDT 375 HTEN'LDT 6.92 TNRA'CNL 020 CNTC.'CN~ 727 CALS'CN5 0 TT2..SSS 000 XMeF~DTE 44 XiXM.iDTE ~44 'TENS,DTE 000 000 ,188 35O D~,O 5DT 059 58 LDT 688 SS! bDT 000 S1EH LDT 941 GR LDT 384 HTEN LDT 266 TNRA CNL 78 CNTC,CN5 '44! CALS.CN5 500 HTEN.CNL 000 TT2.LSS 88 GR.LSS 90 HTEN.5SS . 7515 CIMP.DTE . 74 CILM.DTE ~.~00 IMOF.DTE !2 . 38 IIXM.DTE 4037.2~ 13,5 945.'0 ~ 741.5~ 60.3~ 595,0 0 000 6 605 5070 000 I 620 OO8O 246 75 222 ~00 105875 7.74.500 2;649 ]069'676 ~12'211 774'5O0 72~,000 99,3~5 605'000 46906 47188 0000 4 4930000 8086 152500 1808 0 .174 424000 271000 1848 9~'219000 1979 4174355 8 O86 917000 689500 54844 588000 !31.500 13~o375 :ooo . lumberqer laska Computin~ Center C~LI..MSF SPNO.PSF PEF.LDT bU"LDT SS~.LDT LSRH.LDT TENS.bDT NPHI.CNL NPOP.CNL CFTC.CNL TENS.CNL DT.LSS TT]:.LSS TENS.LSS , DEPT YL~,DTM IiRD'DTE SFhU DTE CALX'MSF MRES,MSF PE~.LDT LU.LDT SS2.LDT L$~ LDT TgNS~LDT NPHI,CNL NPOR.CNb CFTC,CNb TENS.CNL ; DT.bSS TT~LSS T~NS:bSS DgPT. I~P~.DTE IL~.DTE IY~D.DTE SFLU.DTE MTE~.DTE S~NO.~SF PE~.LDT b!!.LDT SS~.LDT bMRN.LDT TEN$.LDT NPH~.CNL : 574 14. '875 6 2'838 2'928 245,0O0 2?6'0OO 2'486 5825,00O 14,998 17.50~ 2430'085 582'5,000 69,~50 936,000 4840.000 8400.000 9,969 10633 149 500 12891 0377 2 527 3 959 269 250 306~750 2428 5335 000 27 348 27 665 1160 767 5335 000 71 375 986 000 5035 000 8300 000 !1.797 78.063 11.594 149,125 11.883 0,375 2.686 4.859 246,500 289.250 2 477 oo:ooo ~3,661 N SP'DTE ~RE$.DTE GR.NSF HTEN,MSF DPMI'bDT ~LS.bDT LL,LDT LSHVLDT LURHLDT MTEM bDT RTNR CNL RCNTCNL gR CNb MRES CNb DTL TT4 MTEM.L$$' CILD.,DTE IIXD.DTE SP.DTE MRES'DTE ~T~SF DPHI'LDT OhS'bDT Lb,LDT LSNV'LDT LURH,LDT MTE~.LDT RTNR,CNL RCNT.CNL CR,CNL MRES-CNL DTb. LSS TT4L$S MTEM:LSS CID OTE IFRE,DTE IIXD.DTE SP~DTE MRES.DTE GR.MSF NTEN.MSF DPMI.LDT OLS.LDT LL.LDT LSHVoSDT LU~H.LDT MTE~.LDT ~TN~.CNL 5-APR-19gl 20:49 -15.813 0;392 40,188 940.500 30.003 I 0,500 134~;090 2'492 151.625 ! ,952 · 4261 487 40.188 0:376 69 125 798 500 149 875 GR DTE HTEN DTE TENS ~MOB LDT LITHLDT SSHV~LDT CALI~LDT M~S bDT TNPH NL RCFT CALl CN5 MTE~ CNU TTIL$S SP LBS NRES LSS 103.063 IoPR,.DTE 104.813 ILD D?E 20,000 DTE . 3'994 IIRM DTE 11.,547 .~R DTE 0,394 HTEN DTE 67,2~0 TENS'NSF 819.000 MSFL'MSF 4,599 RHOB'LDT OSS.LDT '0.028 141,000 LITH,LDT 134i.,000 SSHV,'LDT ' 2,430 CALl,bDT 150,625 NRES.,LDT .TNPH,CNL 67 250 0 377 71 875 834 000 149 500 87 88 87 413 20 000 4 0!6 -7 o 74 063 915 000 7.487 -0 005 130 875 134! 000 2 488 150 125 2.576 CALI.,CNb TTI.LSS SP,LSS MRES,LSS IDPH',DTE ILD, DTE IDOF,DTE !IRM,DTE GR,DTE H?EN,DTE TENS,NSF RHOB,~DT 5I?H,bDT SSHV,SDT C~5I,bDT ~ES bDT TNPB:CN5 .36 063 TENS,DTE 574 000 . 5825 000 ~TEN, 8 2 0 65 1436 10 0 8O0 0 CALS MSF 336 SMIN 504 DRHO.LDT 021 LS,LDT 938 SSI,bDT 000 SIRH.LDT i 25 GR.LDT 6 HTE'N*~DT 5 'TNRA CNL 031 CNTC CML 625 CAbS CNL 625 HTEN CNL 00~ TT2 LSS 81 GR LSS 392 HTEN bSS 9 9 0 98 71 685 533~ 59 143'~ 1 0 26 1002 12 150. 815 -ii 0 11 0 80 75 627 5600 15 2 0 695 CIM'P.DTE 531 CZbM;DTE 000 IMOF.,DTE 688 IiXM,DTE :750 TENS.~DTE 000 CALS,MSF 000 MTEM MSF 551 SMIN MS~ 574 DRHO bDT .066 b$ bDT 031 SSi bDT 000 SIRH bDT 891 GR bDT 377 HT£N bDT 895 TNR~ CNL ~8 CNTC CNL 1 CAbS CNL 625 HT~N' CNb 500 TT2 LSS 547 OR bSS 394 HT£N bBS 461 ClMP.DTE 375 CILM.DTE 000 IMOF.DTE 3 IlXM.DTE ] ~0 TENS,DTE 000 CALS,MSF 000 MTEM.MSF 289 SMIN.MSF 526 DRHO.LDT 015 LS,LDT 54,156 SSI,bDT 1437.000 SIRH,LDT 11,883 GR,LDT 0,'375 HT£N.LDT 25,780 TNRA.CNL PAGEt 17 4840 0'00 151,625 2,057 ~ 424 4 , 88 94~ 400 940 56 67 ! 500 ~6 O63 574 000 '5O 100'~1] 104, O, ~00 , )30 )00 24~ 375 819, 0 ~,~00 ,000 87.750 84,750 0,000 6.9{8 5110 000 11 453 150 125 I 490 0 049 254 125 215 500 2 357 74 O63 915 000 2 528 000,0 ~8L.T~ 00~"89S £90"89 000'998 000~£8 000 o . . 906,'~9 ooo.:a69 889~T· 96~,~S6~ 000 0S~99~ OOg LgT 660 6~6" TT O. O0~L[9 ooo: 000,~69 O00,iT6 699 3,(1'I 'W 3&O,dql3 696 09 ~q'~&& OOf 668 N3&H ~g 681,tT ~u;g O00-t~T Tee 00o:~ gq OEO,O OHiO ~3&X O0 Jo.~ &O WqiD ~ L &O 4~lb 9~ L ooo, LC N3&H 98~ ~Qq ~g 6T~~ iOq X~l~ 000 jgW :W2'&W 00( :O~T9 3gN gq~D OOS )$9 3&fl'~XII 889 80t 3&Q'Nql3 ~ 8 · qND:'NI&H SZT::OSt qND'D~D SSL:"sgTT ggq'dg ~ND~Hd~ &oq'g3~W &Oq IqVD £Oq AH~g &Oq aOXU 3&O'N3&H 3$a~XdOi :qND_:HdN~ &O~lqV~ :&Oq~AXgg &aq:'H£lq $Oq":ggO &Oq' tOHa ~O N3~H 3$O~ql 3$QHdQI , S88'T 0'0~ Z:~L'IT 000°8)[ 'TO6 O00,LL 000, t6£ 0 t£O OOt 0[~ 000 OiL 620 0- ~08 LT 000 9E8 8£~ 8 o OOi OOi E8 OOt ~L ~L~ ~69g OOt 6f~ ST~ ~ 000 l~tT~ 000 ~00- 8"T 9T o~o 6£01 SiT L9 ~6l 0 6£8 t- ttO 9 000 OZ Egs ITT oos:6~8 SLE i ~oC .Q 3&O'dOID qND*SD qND'~ND~ £Oq'AHgq &aq'qq soq'gqo £Oq*IHdO 3~0 dOID qNJag :~a 3&q:qqlD qND'BD ISZ'6I 906'S~ 6IL'SS 000'0008 000'S8~ O00°6POi OiL°gL 000'09~ 6SE'T6L 660~£ 000 09~S LiZ'~ OSL~ZSE OOg ~L£ 0~0'9 ~E~'T T6E 0 000 Oig ZTI O16L 000 0018 O00'OtOg 0'[~ O00'O~T9 000,0:I9 O00.~gt ooo~g8£ 6~9'I 98E'0 ~69 8 ELL*8 000~00:8 qND'aOdN qND'IH~N ~$~'iqVD ~0 HdWI .~O~N 3~0 :~qI 000'696 0()0'009S qND,SN3& E6T'~8~T 990'9~ qND'aOdN ia~uo3 ~UT~ndmOj e~sel~' 7abAeqmnlq: bUl'~Sl'i UOT3eOlt'I~a^ oael SI 86L*[ OOg*~f8 00g°96[ 8f;'O OiL TT 000 LtS OT 000 0 8£6 EOT g~T 000:0~9 9iT,g9 000,869 009,808 oos: o OOg~9[ OtO,'8 ooo:o . ooo: e O00;f~6 609,[ T O~[~T6 O00'OggU .~. ~Q~°HBtg 000 &O~"T~ 8it ~Q~'~q i90 3~O'WXIZ 0 g£~T 0 000 gfg 000 ~19 £I8 66 gLE 86 000 0 6g£ 0t :t9 0T 81~'0 0 0 * 60g~'ET f69,~tO gOf~O' O00~g£~I iLO'O 8Lg,T O00~Tfg 9gT:~g9 800 fLE:L~i 8I Ol 06(0 it~ Ol O00gf~T 900:0 ~I~ 8~6,0L ~3&~ 000~0965 &Qq'AHgg 3&a N3~H 3LQ JOaI 3&O HdQZ LL[ ~ O00~O~[t gLS,69T tgO O- 6TT~L 8£6_g0~ ~0~'0 000'0~ OOg'g6 'Iq~D qND'~J3~ &Oq'ggO 3$Q'N3~H 310' &OOi gLS'9~i 000'g98 00~ gig ZE O- TS~' 86E ~ 6~0 L= 69f 6 000 O[ g£8~6 Og~ 06 qN~ q~ O0~'EgL OOi?LOt- 'W35~ 061'0 AHgS &Oq:'~g:O 600,O- &Oq~gOHa gTg,T oo.o: T6 &aq'SqO 3~Q'qXII 3&~'dOl3 8;9'L~ O00'Ogt~ ESE'g 000'£6~ 06g'g ~69 O~ 609 6 889°6 000'008£ qNO'IHdN £Qq'ilq 2~O'~qdS qND;£NDa &aq'aaaq 000!089U 0o0 800T 000 ~L 000 gLT OgTT OOg £~ 000 66T g 00~ 0~£ 000 98£ BOg ~ ~[g 0 ~0~0 609'£t, 8~9,6 000 O06L 'IND:aOdN ~aq flq ~S~ Iq~O qND~ qND,:ND~ ~Oq'AH~q SOq AS~'aD ~'dS 000'0gg~ OOg"~ sBg'E~ 000" 986 6 66~°8 000 0~6~ 6t9 ~ 00~ £6i g 06E 0 00~ 8E~ ~iH~'IHdN jS.'ON~g ~a~uo3 bUT;nd~OD e~$~T~ 2aO.~aqmnlq= ou't3s!q uo~3eoT~l~aA ade~ SI IS Taper~erification i..,ist~ng ~hlumbe er Alaska Computing Center TENS,CNL TENS.L~5 D~PT* IL~DTE ~RD,DT~ SFLU~DTE MR~S,MSF S~NO PE~ bDT LU bDT SS~ bDT LSRM bDT TENS,BDT CFTC,CN6 TENS'CNL DT,LSS TT3,bSS T~NS~bSS DEPT. I~PH.DTE sFLU,DTE MT~.DTE CabI.~SF M~ES.~SF S~NO,MSF PEF,LDT LU,LDT SS~,bDT LSRM.bDT TENS.LDT NPH~.CNL NPOR.CNL CFTC.CNL TEN$.CNb DT.LSS TT3.LSS TENS,bSS DEPT. I"PH.DTE Ib~ DTE IIRD:DTE 28,728 99~.9~9 5450,000 75,625 987'000 46~0'000 7700,000 8 703 8,586 105,250 10,219 145,500 12.094 0.404 0.618 2 36 o'ooo 7 4960,000 71.875 1057,000 4640,000 7600 000 14 242 63.563 18,156 144,750 11.781 0 401 I 010 4 590 324 750 316 500 2 301 5680'000 24.585 25.545 120~,452 5680 000 70:1~5 983.500 4435.000 7500,o00 11.133 10.320 85.4~8 RC~T.CNb GR, CNL . .REo, CNb DTL,LSS TT4 ' MTEM'LSS CIDP,DTE CILD. DTE IFRE' DTE IIXD DTE SP DTE ~4RE$ DTE GR MSF HTEN NSF DPHi bDT OhS bDT Lb bDT LSHV BDT bUR}{ bDT MTEM bDT RTNR CNL RCNT CNb GRi CML MRES:' CNb DTL.. bSS TT4 ' MT~M, LSS CIDP* DTE CILD ~ DTE IFRE.~DTE I IXD. DTE SP*DTE ~.RE$' DTE GR*~SF HTEN. MSF DPHI:LDT OL bDT LSHV. bDT LURH.LDT ~TEM.bDT RTNR.CNL RCNT.CNb GR.CNb ~. RES, CN b DTb. LSS TT4.LSS ~TEM, [.SS CIDP.DTE CILD.DTE IFRE.DTE IIXD.DTE .. 5,,APR-1991 20:49 2548, O, 3 848.000 146'.125 119,375 ! 2 !, 3 ! 3 20,000 . 0,190 "17,391 625 8490, ~ 7 -0 .023 oo 2 346 144 24..0 882 73 0 145 500 63 66 938 000 2~ 467 -18 688 0 416 63406 1078:000 15,008 -0.020 13 ,000 2.314 144,125 2. 80 274g.659 63,406 70. 827,500 144,750 94,938 97,688 20,000 0.708 RC~T,CNL CAL. I,CNb MTEM,CiNb ~?l.,~ss SP.,b$S ~RES'bSS iDPH,DTE ISD,DTE IDQF,DTE i'I~.,D?E HT£N,DTE TENS'~SF ~SFb,~SF RHOB.bDT OSS..,bDT LITH,bDT SSHV,LDT CAL!,hDT ~RES,bDT TNPM,CNL ~CFT,CN5 CALI,CN5 TTI,L$S SP.LSS ~ES.~SS ILD,DTE IDOF.DTE GR"DTE MTEN.DTE TENS'MSF MSFb. MSF RHOB,bDT OSS,bDT LZTH,LDT SSHV bDT CALI:5DT MRES,bDT T~PM.CNL RCFT.CN5 CALI.CNL TTI.LSS SP.~SS IDPH,DTE ILD,DTE ID9F.DTE II~.DTE 905,959 CNTC,CNL 12'!4t C~LS.iCNL !45.125 HTEN.CMb 845'000 TT2.~LSS -19.'484 GR,LSS 0'404 HTEN.LSS 8..:367 CI~P.DTE 8*242 C'iL~*DTE 0'000 2MOF~DTE 110,06~ II×M DT~ 68-375 612'500 CAbS NSF 4960.000 STEM 84! SMIN MSF 496 D~HO bDT 0 029 404 ~TEN'LDT 2~ :919 TNRA,CNB 902 220 CNTC,CNb 890.000 TT2'LSS 'I~.:39t GR,LSS '41i HTEN.~SS CILM.DTE 102000 IMOF.,DTE 66 56~ IIXM.DTE 66 9~ · TENS:,DTE 6!5 000 CASS.~SF 000 568~ ~TEM.MSF 2i7 SMIN 'MSF 2 402 DRMO,LDT O, 054 LS.LDT 64 8t~ SS1,LDT 14~4 000 SIRH'LDT ii 78i ~R,LDT 0 40i HT~N,LDT 25 ~20 TNRA'CNL 1094 718 CNTC,CNL 11 781 CALS,CNL 144 125 NTEN.CNL 826 500 TT2.LSS -18 688 GR.LSS 0 4!6 HTEN.LSS 10,523 CIMP.DTE 10.234 CILM DTE 0.000 91,750 IIXM.DTE PAGE: 20 2754,034 11,750 841'500 99,813 613,000 1t4.875 116'375 o;ooo 14~555 4640'000 11.'8~0 144.S 5 0,772 0,t59 ~20250 6] 027 625 500 2675 167 ii 820 849 500 725 000 68 375 612 500 62, ~00 4435, ~ 8 0 144, O~ 2 092 6~ 406 ~078 000 2 587 3029 718 li 531 1078 000 68i 000 , :goo 89.750 9~,875 .000 7,805 chlumberger Alaska Computino Center SFLU.DTE PEF bDT SS~,LDT LSRH;LDT T~N~:iLDT NPOR"CNL 'CFTC"CNb TENS'CNL DTLSS TT3 TENS,LSS DEPT, IL~'DTE IiRD.DTE SFLU.DT~ ~T~DTE PEF'LDT sLU,LDT .'S~'LDT LSR,.,LDT C~TC,CNb T~NS,CNL DT,LSS TT],LSS TEN$,LSS IMPH DTE IL~iDT~ IIRD DTE SFLU.DTE MTE-'DTE C~LI,MSF MPES,MSF S~NO.~SF PEF,LDT LU.LDT S$2.LDT LSAt.bDT TEN$.LDT NPHI.CNL 13,398 144'1~5 11,273 .404 343;500 2,260 5175000 2969O 3! 252 905314 5175000 76375 983,500 4440,000 7400.0o0. 13,359 62 250 t3 266 !43 500 8 953 0 398 777 ~ 934 28~ 500 286 2 393 4705 000 24 270 24 O38 1464,370 47850O0 82i000 1037000 4430000 7300,000 9.641 9586 89~438 12.039 142,6~5 10164 0:430 2.977 3371 221:500 260.250 2.555 49R0,0o0 30.476 SP'DTE MRES,DTE GR,MSF MTEM,MSF DPHI,LDT 0LS-LDT LL,LDT LSHV'LDT LUSH'bDT MTE~'LDT ~CNT.CNL G~.CNL MRE$.CNh DTL'LS$ TT4,nSS ~TEM,LSS C!DP.DTE CILD,DTE IFRE,DTE IIXD.DT£ M~E$'DTE HTEN MSF DPHIiLDT OLS bDT Lb,LDT 5$HV,LDT LU~H.,LDT ~TEM.,LDT RTNR,CNL RCNT,CNL GR,CNb ~E$.CNL DTL,LSS TT4,LSS CIDP,DTE CILD.DTE IFRE,DTE IIXD'DTE SP,DTE MRES.DTE GRMSF HTE~:~SF DPHI.LDT QLS,LDT Lb,bDT LSH¥.LDT LURH,bDT MTEM,LDT RTNR,CNL 5.,APR'1991 20349 65'125 873.500 15,872 -0,021 192,625 1339':000 2'270 143,875 0,404 76 500 842 000 144~25 7! 375 7! 813 .20000 -4~76t8~ 0428 59O0O 767 500 15560 0 O06 I~5539 875 000 141402 875 59,7 1 ,000 0 398 907,500 143,500 99 000 10~ 938 2 000 3 746 -33781 0.433 105.813 888,500 5,575 -0012 114000 1339000 2561 142125 2'806 GR,DTE HTEN,DTE TENS,NSF ~HOBibDT OSS~LDT LITH~LDT SSHV bDT CAbI bDT MAE8 bDT TNPH. CNL ~CFTiCNL CAbI, CNb ~TEM,~CNb TTI,.LSS SP, bSS MRES,bS$ IDPH:,DTE I~D,DTE IDQF'DTE GR'DTE HTEN'DTE TENS:'MSF NSFL,MSF RHOB bDT O$SLDT bITHi bDT 8SHV bDT CAb'I.. bDT NRE$. bDT TNPH,CNL RCFT.CNb CAbI.CNb NTEN,CNL TTI'LS$ SP,bSS IDPH DTE I~D~DTE IDO~,DTE IIRM DTE GR~DTE HT~N,DTE TENS,NSF MSFb,NSF RMOB,LDT QSS.bDT LITH.LDT SSMV,bDT CALl.bDT MRES,bDT TNPH,CNL 68 11 ~0 63 131'922 CZbN, ,0,000 71'875 IIX~ 61,469 TENS 586.500 CAbS 4785 8, 82: 1434. 8 ' 0 24 125 T£~S.DTE 500 CALS'~SF 000 MTEM.,NSF :262 SM:IN,NSF 388 DRHO'LDT .027 bS,LDT 375 SSl,bD? 000 $!RH,LDT 273 GA,bDT 404 HT£N bDT 681 TNRACNL rbSS DTE DTE DTE DTE DTE NSF bDT: bDT bDT bDT bDT bDT CU 125 143. 906 ,,,49 0 :000 97 SNXN: ]93 DRHO 004 0~0 SS'I $1RH 953 GR 398 HT£N. 08~ TNRA 69 CNTC RTEN,CNb 000 TT2. bS8 ,188 ORibSS 428 HTEN bSS 10 094 CIMP,DTE 9 805 CILM.DTE 97 594 4980 6 0 50 1434 !0 0 33 000 INOF.DT£ 688 IIXM,DTE g50 TENS,DTE O00 CAbS,NSF 000 MTENeMSF 207 SNIN,MSF 558 DRHO bDT 012 LS LDT 188 SSi bDT 000 $1RH bDT 164 GR bDT 430 HTEN.bDT 642 TNRA,CNL PAGE i~ 2 ! 4440000 10789 !43 875 2648 367500 6 1.25 258 95 lO 873500 715 500 6 125 500 75, 50 000 443ili:260 8,~0097 143'875 296,'75~ 767.. ~0 767,500 752,000 500 ~05 688 10~250 0,000 8.547 4350000 10 227 142125 2 902 0 002 224 750 195 2,545 105,8t3 888,500 2,907 000'0 0~"~ O00~6LO~ 00~ O~L O0~,O;L [~9 T 000 8[0 98L 0 000 ~LO~ , £90. O00~tgL 089L'0~ S~6,~ OS '~£~ LT 866:0 089 0; 000 0 OSL ~6 OOS 8 O00~6S OSL;L6 00S,818 00S,888 ~f089~[ 3&G*jO~I 000.0 3&O'W~I3 L[~ 3&~*d~IJ qN3*3&N3 TT~ qN3*~N& ~Gq'H~TS 000 ~ag:~s~ oo~ ~Oq gq ~90 JgW*fllWg EfT JgN W~W 000 ~[a ~ ost ~sa:~o.[ ooo ~&O"dWZD T£O S: Saq:'SD ~86 ~" ': 3gW',W3$~ 000 asN:s~v~ oos 3&.a'~xzz 889 3~a*'JON! 000 o: 3&O*:'d~lD · 9~D*gqVD ~9T.OT q. ND*D~ND 65~ 6EL tT 09~ o ti JOE 0 T T O[gt 89S 0 6t6 0 SL9~ :TgS C6 06 qN3'H3&W qN3'IqV3 qND"&J3~ qND'adN& &oq'lq~D &Oq*H&lq ~Oq'~gO ~W gN3& 3&O*N3&H 3&O'aD ggq~T~ :qND~h3&~ qND. ZqVD' qND~JD~ qNDHdN& ~Oq B:OHU J. gN gN3& 3~O:WSIi 3~O .HdOI ,, qND*~3&W 000'0[ O00*L£~I 000°0£1 8tt*O es~o£ 00o 0 899 006 S9 OOg OTL EgS 0£ EDt o £90 O9- Tg9 0- 000 O~ 906 9t 8£6 6£ 000996 O~~ E.T8 SOT 6f:O[ I66I'adV~f qN3*~D qND'£NDB qND*BN$~ ~Oq'H~flq ~aq*IHda 3&Q,QXII &Oq~AHSq ~Oq~qq &aq:~90 ~Oq Iaaa O0§*80T 08I'8 ES6'L O00'O00L O00*SLO~ O00*T[~I ~LB'6~T 000'0~9~ oLg'60E 0~6'g9 ~9~'~9 000'0~9~ 08S!T oo0 L~E 00o LSTT ~9*G T~T 696'~ O00'O0;L 0oo gB~t 000 9~ 009 ~8 000 ~&9~ 69~ 8E 00'0 OCT ~L9~ OS[ 990 ~ [o~ o ~B60I ~&t 08 8t~ O; /6~TI 000 O0[L 000'086~ ~8L'S~8 rIND'~N2~ ~ND*aOdN qND*IHdN ~Oq*aq ~Gq*&3d ND'SNA$ :aOda ~Qq"SNJ$ ~.Oq[ti qN3,gN. 3~ ND':£N3~ N *~Oda bUT~STq uoT'3e~'[~lJa/k aoe& 93 , IS Ta~e Verification Listing cblumberger AlaSKa ComPutin~ Center SFLU. DIE MTE~'DTE C~I. MSF ~RES, S~MO, MSF bU, bDT SS~, bDT TENS, LDT NPO~. CML CFTC. CML TENS ~ CML DT"LMS TT ~. LSS TENS'LSS 9'078 140']75 0.444 039 539 500 320 750 2010 46~5 000 ~00 358:304' 4625 000 93.50O 1~73 000 4 40,000 MRES.DTE GR, MSF HTEN:MSF DPHI~LDT QLS~LDT LSHV~LDT bU~MLDT STEM bDT RTNR~CNL RCNTCNL GR CNb ~R~$CNb DTLbS$ TT4 LSS MTEM bS$ DEPT, I~PM,DTE ILW'DT£ IIRD,DTE SFLU~DTE MTE~.DTE CALI ~RES ~SF S~NO,MSF 'PEF,LDT LU.LDT $S~.LDT TENS'bDT NPMICNL NPO~iCNb C~T¢ CNb T~NS CNL DT.LSS TT~.LS$ TENS.LSS 6927,000 1950.000 1950..000 70.688 9696'000 {39,625 -999'250 -999.250 -999.,~50 -999.:250 -999.~50 -999,250 -999"250 -999,250 -999.250 -999~250 -999.250 -999.250 54.875 814i000 4020 000 CIDP.DTE CIbD.'DTE IFRE.DTE IIXD~DTE SP,DTE MRES~DTE GR.MSF HTEN MSF DPMILDT ~LSbDT LL bDT LSHViLDT LU~HLDT ~TEM LDT RTNR CNL RCNT CNL GR CNL MREM CNb DTL*LSS TT4 ** END OF DATA ** 5-APR-1991 20:49 3 · 4~ 3 39 80 30~ 0 140 500 :3 ! 3 044.4 500 99. 1014. 140.~0 5 79: 8 20 000 -345 0 0 452 -999 250 :999 999 2~0 -999 2 0 -999 250 -999 250 '999 250 -999 250 -999 250 -999 -999 250 -999 .57 750 704 500 139 625 GR DIg HTEN~DTE TENS MSF MSFL~MSF RHOB bDT OSS bDT LITH bDT SSHV bDT AbI bDT RES bDT TNPH CNL RCFT CNL CALI,CNL MTEM,CNL TTI,bSS SP,LSS MRES'LSS IDPH.~TE ILD, TE IDOF.DTE IIRM,DTE GR:DTE HTEM DIE TENS,MSF MSFL,MSF RHOB,LDT OSS,LDT bITN DT SSHV ~DT CALl bDT ~RES bDT TNPH CNL RCFT CNL CAb! CNL ~TEM,CNL TTi,LSS NRES,LSS PAGE{ 44 969 TENS.DIE 554 000 CRLS.MSF 4625 1 2 0 13 ~0~2 -61 0 000 MTEN.MSF 829 SMiN.NSF 004 DRHO LDT 02.5 LS bDT 375 881 bDT 000 S1RH bDT 828 GR LDT 444 HTEN ~DT 540 TN~A CNL ~1 CNTC CNL 000 TI2 SS 13 GR.LSS 47 HTEN.LSS 12 789 CIMP 12 0 -578 34 553 -999 -999 -999! -999 -999 0 999 250 999 -999 -999 701 -56 0 .D'TE 578 CILM.DTE 000 IMOF DIE 500 llXM DTE 500 TENS DTE 500 CAbS MSF 250 MTEM MSF ~0 S~IN NSF 0 DRHO.LDT 250 LS.LDT SS1 bDT S1RH!LDT GR LDT HTEN.LDT ,250 TNRA.CNL ~250 CNTC.CNL 25O CALS.CNL 250 HTEN.CNb 87~ GR.LSS 45 HTEN.LSS 4140 000 13 047 140 500 0 894 -0 008 2 !25 4~ 04.3 78~ 500 33.6 1~ 047 78 5O0 849 44 969 554 OOO -585 .500 '58~ 500 000 1578 000 402 -99~ 000 250 -999~ 50 -999 ,50 -999 =999 -999 250 -999 250 -999 250 -999 250 -999 250 '999 0 .592 000 553 0 **** FILE TRAILER **** FILE NA~E ; EDIT .001 SERVICE ~ FLIC VERSION ~ OOiA06 DATE { 91/04/ 5 ~X AEC SIZ~ : 1024 FILF TYPE I LO LAST rILE : ~ ~22~ ~OIA2~d : ~dV~ g~OIAM~d q ~u"~sT"i uoT3eoT,~;[aA .ad,j, SI .
