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Home My WebLink About170-011MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, March 5, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC G-33 TRADING BAY UNIT G-33 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/05/2024 G-33 50-733-20212-00-00 170-011-0 N SPT 8504 1700110 2150 0 0 0 0 4 4 4 4 OTHER P Sully Sullivan 1/21/2024 MIT to 2150 per Sundry # 323-678 for workover casing test post packer set. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:TRADING BAY UNIT G-33 Inspection Date: Tubing OA Packer Depth 11 2246 2241 2241IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240123132821 BBL Pumped:1 BBL Returned:1 Tuesday, March 5, 2024 Page 1 of 1            1-Oil producer STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT G-33 JBR 03/04/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 4-1/2" joint Test Results TEST DATA Rig Rep:Whitten/CastagneOperator:Hilcorp Alaska, LLC Operator Rep:Soule/Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:1700110 DATE:1/19/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSAM240122105154 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 1645 Sundry No: 323-678 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 2-7/8"x5-1/2"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 4-1/16"P HCR Valves 1 4-1/16"P Kill Line Valves 3 4-1/16"&2-1/P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P2000 200 PSI Attained P31 Full Pressure Attained P119 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1975 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0      1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replaced ESP 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 10,790 feet N/A feet true vertical 10,252 feet N/A feet Effective Depth measured 10,030 feet N/A feet true vertical 9,562 feet N/A feet Perforation depth Measured depth 9,020 - 10,626 feet True Vertical depth 8,659 - 10,103 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 8,676 (MD) 8,344 (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: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Hemlock Oil, Middle Kenai G Oil, West Foreland Oil 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 79 323-678 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 180 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Casey Morse Casey.Morse@hilcorp.com 907 777-8322Operations Manager N/A 356 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 296 Gas-Mcf MD 356 N/A 81 Size 356 605 7818 81358 204 746096 13-3/8" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 170-011 50-733-20212-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017594 / ADL0018730 McArthur River / Hemlock Oil, Middle Kenai G Oil, West Foreland Oil Trading Bay Unit G-33 Plugs Junk measured Length measured TVD Production Liner 10,090 792 Casing Structural 9,605 7" 10,090 10,754 10,208 605 4,511 605Conductor Surface Intermediate 26" 20" 3,810psi 1,530psi 3,090psi 6,330psi 4,511 4,448 Burst Collapse 520psi 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:16 pm, Feb 20, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.02.19 10:40:16 - 09'00' Dan Marlowe (1267) RBDMS JSB 022824 DSR-2/21/24 _____________________________________________________________________________________ Updated By: JLL 02/13/2024 SCHEMATIC McArthur River Field Well: G-33 Last Completed: 01/25/2024 PTD: 170-011 API: 50-733-20212-00 N PBTD: 10,706‘ TD:10,790’ 20” 7” DV Collar @ 1,003’ 13-3/8” 9-5/8” RKB to MLLW = 110.60’, RKB to Mudline = 235.60’ 1 HK-2 W.F. Zone Tag fill 10,030’ 01/27/22 G Zone 26” CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Surf 356’ 20 94 H-40 8 RND 19.124 Surf 605’ 13-3/8 61 J-55 BTC 12.515 Surf 4,511’ 9-5/8” 43.5 N-80 BTC 8.755 Surf 6,682’ 47 N-80 BTC 8.681 6,682’ 8,478’ 47 P-110 BTC 8.681 8,478’ 10,090’ 7 29 N-80 BTC 6.184 9,962’ 10,754’ TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.958 Surf 8,676' PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-1 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK-1 9,505’ 9,532’ 9,093’ 9,117’ 27’ 05/18/18 Open HK-2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK-2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK-3/4 9,648’ 9,810’ 9,219’ 9,364’ 162’ 05/18/18 Open HK-5 9,826’ 9,942’ 9,378’ 9,482’ 116’ 05/18/18 Open HK-6 9,952’ 10,010’ 9,491’ 9,544’ 58’ 05/18/18 Open WF-1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 Covered WF-1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 Covered WF-1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 Covered WF-1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 Covered WF-1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 Covered WF-1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 Covered WF-2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 Covered WF-2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 Covered WF-3 10,376' 10,407' 9,876' 9,904’ 31’ 12/1987 Covered WF-3A 10,407’ 10,475’ 9,904’ 9,966’ 68’ 12/1987 Covered WF-3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF-4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 43.70’ 43.70’Hanger – CIW-DCB-ESP 11”x4 ½” Lift & Susp w/ 4” Type H BPV Profile 1 8,676' 8,344' N/A 5.130 Discharge Sub 8,678' 8,346' N/A 5.380 Pump (x3) 538 SERIES, 066 STAGE SJ10000 8,749' 8,411' N/A 5.380 INTAKE, SUB-ASSY 8,750' 8,412' N/A 5.130 Upper/Lower Tandem Seals - 513 Series, BPBSBPB 8,773' 8,433' N/A 5.620 Motors (x2) 562 Motor, KMS3LUT 500HP 8,839' 8,494' N/A 5.620 Centralizer / Anode Well Name:MRF G-33 API #:50733202120000 Field:McArthur River Field Start Date:1/16/2024 Permit #:170011 Sundry #:323-678 End Date:1/25/2024 1/16/2024 1/17/2024 1/18/2024 1/19/2024 1/20/2024 1/21/2024 Well Operations Summary Scope up derrick, continue to rig up to test BOPE, shell test 13-5/8 bop's to 250 lo and 2500 psi hi, continue to test BOPE to Hilcorp and AOGCC specs , test witness by AOGCC inspector Austin Meleod, test with 4.5 test joint to 250 lo and 2500 psi ( GOOD) tested GAS and PVT alarms ( Good), rig down test equipment and rig up summit handling tools hang sheeve in derrick. prep to pull esp, pump tbg volume, Bolds, attempt to pull hanger, pick up to 160 hanger came off seat, cont up t/180 with no string movement, , pump lube down annulus, continue to work tbg @ 180k started getting movement , work hanger to floor, lay out same, continue to pooh racking back 4-1/2 super max tbg in derrick spooling up motor lead and capillary line,depth at rpt time 5512' pick up wt at 110k Mobe crews to platform & orientate same. Arrange decks & start R/U 404 rig package. Spotting rig components, pump, pits , pin carrier to beams, insatll derrick and raise same, cut 50 ft drill line, spool line on drum. Continue r/u 404 package, attempt to circulate well, no joy, inject 700 bbls FIW, monitor well on vac, install BPV, nipple down tree, nipple up 13-5/8 5m bope raise derrick & prep to scope up same. Cont. POOH w/ 4 1/2" 12.6# Supermax with ESP completion f/5512', to pump assembly, lay out pump assembly, change out SRL at crown, rigging up slick lne, RIH with 3" bailer, tagging at 9040 ft. slm, worked dwon to 9059 ft. fell through, continue in hole tagging at 9815 slm work bailer, collect samper in bailer, pooh recovered scale. rig down slick line, pick up 9-5/8 JS3 test packer, rig up Gill tongs Daily Operations: RIH with the 9-5/8 JS 3 test packer, on 4-1/2 super max tbg to 8,866', dpm, tagging fill, pick up and set the test packer at 8,858 ft. dpm, fill hole and work air out of annulus took 142 bbls of FIW. pressure up to 2,260 psi on csg & held for 30 minutes good test, (Start pressure 2260 psi, 15-minute reading 2,243 psi, 30-minute reading 2,243 psi, bleed off well & blow down lines, mobe out inspector from beach, test the 9-5/8 csg with JS 3 packer set at 8,858 ft. to 2,246 held 30-minute ( start pressure 2,246 psi, 15-minute reading 2,241 ft. 30-minute reading 2,241 psi,(test witness by AOGCC inspector Sully Sullivan (good test) Bleed off release packer with 130k pooh laying ĚŽǁŶďĂĚϰͲϭͬϮƚďŐ͘ĨƌŽŵϴ͕ϴϱϴŌƚŽϴ͕ϯϮϵŌ͘ƌĞƉĂŝƌƌĂĚŝĂƚŽƌŚŽƐĞŽŶĐƌĂŶĞ͘ Page 1 of 2 Well Name:MRF G-33 API #:50733202120000 Field:McArthur River Field Start Date:1/16/2024 Permit #:170011 Sundry #:323-678 End Date:1/25/2024 1/22/2024 1/23/2024 1/24/2024 1/25/2024 Well Operations Summary Daily Operations: Pooh laying down bad pipe and racking good pipe in derrick, arrange & sort pipe on deck, pick up replacement 4-1/2 tbg,pooh racking tbg in derrick, lay down packer, and brk down same prep floor to pick up remaining replacement 4-1/2 tbg Continue m/u penetrator splice & test good, m/u control line penetrations, land hanger placing assy tail @ 8839', RILD pins. Pull landing joint, set BPV. R/dn floor, lay over derrick, nipple down BOPS, riser, nipple up 11"5m adapter x 4-1/16 5m tree, test void, hanger neck seals and tree body to 5000 psi, ( Good test), Rig down rig and cleaning equipment RIH P/UP 74 Jts 4-1/2,12.6 super max completion tbg, Pooh and rack back same in derrick, rig up Summit ESP handling tools, Pick up, assemble & service ESP pump assembly RIH with ESP pump assembly on 4-1/2, 12.6#, L-80, super max tbg f/ 201 to 6548',Make cable splice & test good, cont. RIH t/ 8805', make hanger penetrator splice. Page 2 of 2 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,790 N/A Casing Collapse Structural Conductor 520psi Surface 1,540psi Intermediate Production 3,810psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Replace ESP 1/2/2024 10,754'792' 4-1/2" 10,208' N/A & N/A N/A & N/A 10,090' Perforation Depth MD (ft): 9,020 - 10,626 10,090' 7" 8,659 - 10,103 9,605'9-5/8" 356' 26" 20" 13-3/8" 605' 4,511' MD 1,530psi 3,090psi 605' 4,448' 605' 4,511' Length Size Proposed Pools: 356' 356' 12.6 TVD Burst 8725 6,330psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 / ADL0018730 170-011 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20212-00-00 Hilcorp Alaska, LLC N/A AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Trading Bay Unit G-33 McArthur River Hemlock Oil, Middle Kenai G Oil, West Foreland Oil Same 10,252 10,030 9,562 1,645psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.12.19 09:01:34 - 09'00' Dan Marlowe (1267) By Grace Christianson at 2:55 pm, Dec 19, 2023 X DSR-12/19/23 Provide AOGCC 48 hrs notice for opportunity to witness MITIA to 2150 psi. SFD 12/20/2023BJM 12/21/23 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.21 11:28:59 -09'00'12/21/23 RBDMS JSB 1222623 Well Work Prognosis Well Name:G-33 API Number:50-733-20212-00-00 Current Status:ESP Producer Leg:Leg #3 (SE corner) Estimated Start Date:January 2, 2024 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:170-011 First Call Engineer:Casey Morse (603) 205-3780 (M) Second Call Engineer:Karson Kozub (907) 570-1801 (M) Current Bottom Hole Pressure:2,495 psi @ 8,500’ TVD 0.293 psi/ft based on ESP Gauge Sept 2023 Maximum Expected BHP:2,495 psi @ 8,500’ TVD 0.293 psi/ft based on ESP Gauge Sept 2023 Maximum Potential Surface Pressure:1,645 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) *** This is a no flow well 03/20/2015 Brief Well Summary G-33 is a comingled G-Zone, Hemlock, West Foreland Producer that was converted to an ESP from a dual string gas-lift completion in March 2015. The current ESP was installed in January 2022. It appears to have failed electrical system causing the motor to short. We plan to pull and replace the current completion. Last Casing Pressure Test: 02/22/2015 - 1,500 psig at 8,955’ and charted for 30 minutes. Procedure: 1. MIRU HAK 404 2. Circulate the well to production. a. Work over fluid will be filtered inlet water. 3. Set BPV, ND tree, NU BOP and test to 250psi Low/2,500psi High/2,500psi Annular. a. Notify AOGCC 48 hours in advance to allow them to witness test. b. BOPs will be closed as needed to circulate the well. 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. L/D all gas lift mandrels and tubing pups above / below each. Plan to P/U 3 additional joints of 4.5” L80 Supermax as replacement to maintain similar pump depth. 7. PU test packer and TIH to ~8,950’. Conduct MIT IA for 30 minutes at 2,150 psi (8,600 ft TVD * 0.25 #/ft). a. If unable to get packer to set, plan to PU work string with bit & scraper. TIH to ~9,000’. TOH and L/D bit and scraper. Attempt to set packer and perform MIT again. 8. TOH and L/D test packer. 9. PU, RIH with new ESP. 10. Land ESP with the bottom of the assembly at ±8,860’. 11. Set BPV, ND BOP, NU tree and test. 12. Turn well over to production. 13. Conduct SVS testing per AOGCC regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. BOP Drawing 5. Fluid/Flow Diagrams 6. RWO Sundry Change Form Provide AOGCC 48 hrs notice for opportunity to witness MITIA to 2150 psi. -bjm _____________________________________________________________________________________ Updated By: JLL 02/11/22 SCHEMATIC McArthur River Field Well: G-33 Last Completed: 01/29/22 PTD: 170-011 API: 50-733-20212-00 PBTD: 10,706‘ TD:10,790’ 20” 7” 1-4 DV Collar @ 1,003’ 13-3/8” 9-5/8” RKB to MLLW = 110.60’, RKB to Mudline = 235.60’ 5 HK-2 W.F. Zone Tag fill 10,030’ 01/27/22 G Zone 26” CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Surf 356’ 20 94 H-40 8 RND 19.124 Surf 605’ 13-3/8 61 J-55 BTC 12.515 Surf 4,511’ 9-5/8” 43.5 N-80 BTC 8.755 Surf 6,682’ 47 N-80 BTC 8.681 6,682’ 8,478’ 47 P-110 BTC 8.681 8,478’ 10,090’ 7 29 N-80 BTC 6.184 9,962’ 10,754’ TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.958 Surf 8,725’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-1 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK-1 9,505’ 9,532’ 9,093’ 9,117’ 27’ 05/18/18 Open HK-2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK-2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK-3/4 9,648’ 9,810’ 9,219’ 9,364’ 162’ 05/18/18 Open HK-5 9,826’ 9,942’ 9,378’ 9,482’ 116’ 05/18/18 Open HK-6 9,952’ 10,010’ 9,491’ 9,544’ 58’ 05/18/18 Open WF-1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 Covered WF-1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 Covered WF-1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 Covered WF-1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 Covered WF-1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 Covered WF-1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 Covered WF-2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 Covered WF-2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 Covered WF-3 10,376' 10,407' 9,876' 9,904’ 31’ 12/1987 Covered WF-3A 10,407’ 10,475’ 9,904’ 9,966’ 68’ 12/1987 Covered WF-3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF-4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 43.70’ 43.70’Hanger – CIW-DCB-ESP 11”x4 ½” Lift & Susp w/ 4” Type H BPV Profile 1 2,184’ 2,184’ 3.833 5.984 GLM #1 - PSPO-1R, 1" 2 3,611’ 3,603’ 3.833 5.984 GLM #2 - PSPO-1R, 1" 3 4,401’ 4,351’ 3.833 5.984 GLM #3 - PSPO-1R, 1" 4 4,934’ 4,852’ 3.833 5.984 GLM #4 - PSPO-1R, 1" 5 8,725’ 8,389’ N/A 5.920 Discharge Sub 8,727’ 8,391’ N/A 6.750 Pumps (2) - 675 Series, SH13000CCW,45S,INC,15,1:1XRO,316 8,771’ 8,431’ N/A 6.750 Gas Separator/Intake 8,772’ 8,432’ N/A 5.130 Upper/Lower Tandem Seals - 513 Series, BPBSBPB 8,795’ 8,453’ N/A 5.620 Motors (2) - 562 Motor, KMS3LUT 500HP / KMS3LT 500HP 8,860’ 8,513’ N/A 5.620 Centralizer / Anode _____________________________________________________________________________________ Updated By: JLL 12/01/23 PROPOSED McArthur River Field Well: G-33 Last Completed: Future PTD: 170-011 API: 50-733-20212-00 PBTD: 10,706‘ TD:10,790’ 20” 7” DV Collar @ 1,003’ 13-3/8” 9-5/8” RKB to MLLW = 110.60’, RKB to Mudline = 235.60’ 1 HK-2 W.F. Zone Tag fill 10,030’ 01/27/22 G Zone 26” CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Surf 356’ 20 94 H-40 8 RND 19.124 Surf 605’ 13-3/8 61 J-55 BTC 12.515 Surf 4,511’ 9-5/8” 43.5 N-80 BTC 8.755 Surf 6,682’ 47 N-80 BTC 8.681 6,682’ 8,478’ 47 P-110 BTC 8.681 8,478’ 10,090’ 7 29 N-80 BTC 6.184 9,962’ 10,754’ TUBING DETAIL 4-1/2” Surf ±8,725’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-1 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK-1 9,505’ 9,532’ 9,093’ 9,117’ 27’ 05/18/18 Open HK-2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK-2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK-3/4 9,648’ 9,810’ 9,219’ 9,364’ 162’ 05/18/18 Open HK-5 9,826’ 9,942’ 9,378’ 9,482’ 116’ 05/18/18 Open HK-6 9,952’ 10,010’ 9,491’ 9,544’ 58’ 05/18/18 Open WF-1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 Covered WF-1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 Covered WF-1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 Covered WF-1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 Covered WF-1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 Covered WF-1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 Covered WF-2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 Covered WF-2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 Covered WF-3 10,376' 10,407' 9,876' 9,904’ 31’ 12/1987 Covered WF-3A 10,407’ 10,475’ 9,904’ 9,966’ 68’ 12/1987 Covered WF-3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF-4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 43.70’ 43.70’Hanger – CIW-DCB-ESP 11”x4 ½” Lift & Susp w/ 4” Type H BPV Profile 1 ±8,725’ ±8,389’ N/A 5.920 Discharge Sub Pump Gas Separator/Intake Upper/Lower Tandem Seals Motors ±8,860’ ±8,513’ N/A 5.620 Centralizer / Anode Grayling Platform G-33 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Grayling Platform G-33 13 3/8 X 9 5/8 X 4 1/2 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom Valve, WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 ¼ ESP neck, 2- ½ npt continuous control line ports Valve, swab, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 4 1/16 5M FE, HWO, T-24 BHTA, Bowen, 4 1/16 5M FE X 4 1/2'’ Bowen Quick Union Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, WKM-M, 3 1/8 5M FE, w/ MA-16 operator Tubing hanger, CIW-DCB-ESP, 11 X 4 ½ IBT lift and susp, w/ 4'’ type H BPV profile, 5 ¼ EN, 4- 3/8 continuous control line ports, prepped for BIW penetrator Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW w/ 2- 2 1/16 5M SSO, CA slips in head Grayling Platform BOP Stack HAK 404 HI L C O R P A L A S K A , L L C Sw a c o Su p e r c h o k e Bl o o e y L i n e To G a s B u s t e r In l e t H i l c o r p A l a s k a , L L C Hi l c o r p A l a s k a , L L C Ch a n g e s t o A p p r o v e d R i g W o r k O v e r S u n d r y P r o c e d u r e Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l G - 3 3 ( P T D 1 7 0 - 0 1 1 ) Su n d r y # : X X X - X X X An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . 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Supry t Z/Z' BOPE Test Report for: TRADING BAY UNIT G-33 - Comm Contractor/Rig No.: Hilcorp 404 Operator: Hilcorp Alaska, LLC Type Operation: WRKOV Sundry No: Type Test: INIT 321-381 ' PTD#: 1700110 — DATE: 1/26/2022' Operator Rep: Soule Test Pressures: Rams: Annular: Valves: MASP: 250/2500 - 250/2500 ' 250/2500 1905 ` TEST DATA Inspector Bob Noble ' Rig Rep: Johnson Insp Source Inspector Inspection No: bopRCN220127134848 Related Insp No: MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Quantity P/F Quantity Visual Alarm P/F Time/Pressure P/F Location Gen.: P Trip Tank NA " NA " System Pressure 3000 " P " Housekeeping: P Pit Level Indicators P - ----------- P Pressure After Closure 1900 - P ' PTD On Location P Flow Indicator NA NA - 200 PSI Attained 20 P - Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 75 P - Well Sign P- H2S Gas Detector P P Blind Switch Covers: All stations " P Dr]. Rig P MS Misc NA NA Nitgn. Bottles (avg): 2025 - P - Hazard Sec. P ACC Mise 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0 NA- Stripper 0 NA No. Valves 11 " P - Lower Kelly 0 NA- Annular Preventer 1 13 5/8" - P Manual Chokes I P Ball Type 2 _" P. #1 Rams 1 27/81' x 5 1/2 -P Hydraulic Chokes I P - Inside BOP 1 P #2 Rams 1 Blinds - P CH Mise 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams NA _-0 #5 Rams _ 0 _ --- - _ — NA _ INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves I - 2 1/16" P-- Quantity P/F HCR Valves 2 "2 1/16" P - Inside Reel Valves __-0- NA Kill Line Valves 2 2 1/16" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 ' Test Results Test Time 3 Remarks: Good test. Ready when I arrived and got right to testing. Closure times, Bag 21 sec, Top rams 6 sec, Kill HCR 3 sec, and Choke HCR 3 sec. W01 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?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Hemlock Oil, Middle Kenai G Oil & West Foreland Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,790'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 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:kkozub@hilcorp.com Contact Phone: (907) 570-1801 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 Authorized Signature: Operations Manager Karson Kozub PRESENT WELL CONDITION SUMMARY Length Size N/A 356' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 / ADL0018730 170-011 50-733-20212-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit G-33 TVD Burst 8,759' 6,330 psi 8,160 psi Tubing Size: MD 1,530 psi 3,090 psi 605' 4,448' 605' 4,511' 356'356' 26" 20" 13-3/8" 605' 4,511' 10,090' Perforation Depth MD (ft): 10,090' N/A & N/A Tubing Grade:Tubing MD (ft): 8,659 - 10,103 Perforation Depth TVD (ft): 10,208' 12.6 / L-80 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. 8/21/2021 4-1/2" Daniel E. Marlowe N/A & N/A 9,020 - 10,626 Other: Replace ESP/ GL Completion 10,252'10,289'9,797'1,905 psi 792'7" 9,605'9-5/8" 10,754' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 8:49 am, Jul 30, 2021 321-381 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.07.30 07:25:30 -08'00' Dan Marlowe (1267) BJM 8/2/21 10-404 X SFD 7/30/2021 BOP test to 2500 psi DSR-8/2/21 No-flow test required if cleanout is performed. dts 8/2/2021 JLC 8/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.02 14:32:12 -08'00' RBDMS HEW 8/3/2021 Well Work Prognosis Well Name:G-33 API Number:50-733-20212-00-00 Current Status:ESP Producer Leg:Leg #3 (SE corner) Estimated Start Date:August 21, 2021 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:170-011 First Call Engineer:Karson Kozub (907) 570-1801 (M) Second Call Engineer:Katherine O’Connor (214) 684-7400 (M) Current Bottom Hole Pressure:2,456 psi @ 8,539’ TVD 0.288 psi/ft based on ESP Gauge July 2021 Maximum Expected BHP:2,758 psi @ 8,539’ TVD 0.323 psi/ft based on ESP Gauge July 2019 Maximum Potential Surface Pressure:1,905 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) *** This is a no flow well 03/20/2015 Brief Well Summary G-33 is a comingled G-Zone, Hemlock, West Foreland Producer that was converted to an ESP from a dual string gas-lift completion in March 2015. The current ESP was installed in 2019. It appears to have broken a pump shaft. We plan to pull and replace the current completion. Last Casing Pressure Test: 02/22/2015 - 1,500 psig at 8,955’ and charted for 30 minutes. Procedure: 1. MIRU HAK 404 2. Circulate the well to production. a. Work over fluid will be filtered inlet water. 3. Set BPV, ND tree, NU BOP and test to 250psi Low/2,500psi High/2,500psi Annular a. Note: Notify AOGCC 48 hours in advance to allow them to witness test 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. RU SL RIH and tag fill 7. * Contingent clean out if fill is tagged high a. RIH with clean out assembly, circulate bottoms up, POOH b. *BOP’s will be closed as needed to circulate the well 8. PU, RIH with ESP/Gas-lift Combo completion. 9. Land ESP with the bottom of the assembly at ±8,885’. 10. Set BPV, ND BOP, NU tree and test. 11. Turn well over to production. 12. Conduct SVS testing per AOGCC regulations. 13. If cleanout is conducted in step #7 - Conduct a no-flow per AOGCC regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. BOP Drawing 5. Fluid/Flow Diagrams 6. Rolling BOP Test Procedures 7. RWO Sundry Change Form If cleanout is conducted in step #7 - Conduct a no-flow per AOGCC regulations. _____________________________________________________________________________________ Updated By: JLL 07/25/2019 SCHEMATIC McArthur River Field Well: G-33 Last Completed: 07/05/2019 PTD: 170-011 API: 50-733-20212-00 PBTD: 10,706‘ TD:10,790’ 20” 7” 2-5 DV Collar @ 1,003’ 13-3/8” 9-5/8” RKB to MLLW = 110.60’, RKB to Mudline = 235.60’ 6 1 HK-2 W.F. Zon e Top of fill 10,289’ 05/16/2018 G Zone 26” CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Surf 356’ 20 94 H-40 8 RND 19.124 Surf 605’ 13-3/8 61 J-55 BTC 12.515 Surf 4,511’ 9-5/8” 43.5 N-80 BTC 8.755 Surf 6,682’ 47 N-80 BTC 8.681 6,682’ 8,478’ 47 P-110 BTC 8.681 8,478’ 10,090’ 7 29 N-80 BTC 6.184 9,962’ 10,754’ TUBING DETAIL 4-1/2” 12.6 L-80 Supermax 3.958 Surf 8,759’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-1 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK-1 9,505’ 9,532’ 9,093’ 9,117’ 27’ 05/18/18 Open HK-2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK-2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK-3/4 9,648’ 9,810’ 9,219’ 9,364’ 162’ 05/18/18 Open HK-5 9,826’ 9,942’ 9,378’ 9,482’ 116’ 05/18/18 Open HK-6 9,952’ 10,010’ 9,491’ 9,544’ 58’ 05/18/18 Open WF-1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF-1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF-1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 WF-1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF-1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF-1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF-2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF-2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF-3 10,376' 10,407' 9,876' 9,904’ 31’ 12/1987 Covered WF-3A 10,407’ 10,475’ 9,904’ 9,966’ 68’ 12/1987 Covered WF-3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF-4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 43.70’ 43.70’ Hanger – CIW-DCB-ESP 11”x4 ½” Lift & Susp w/ 4” Type H BPV Profile 2 2,180’ 2,180’ 3.833 7.063 GLM #1 – SFO-2 w/ RD-2 Dummy valves, RK Latches 3 3,608’ 3,600’ 3.833 7.063 GLM #2 – SFO-2 w/ RD-2 Dummy valves, RK Latches 4 4,398’ 4,349’ 3.833 7.063 GLM #3 – SFO-2 w/ RD-2 Dummy valves, RK Latches 5 4,931’ 4,849’ 3.833 7.063 GLM #4 – SFO-2 w/ RD-2 Dummy valves, RK Latches 6 8,759’ 8,420’ N/A 5.920 Discharge Sub 8,760’ 8,421’ N/A 6.750 Pumps - Tandem Summit 45 Stage SH16000AR 8,799’ 8,457’ N/A 6.750 Gas Separator/Intake 8,800’ 8,457’ N/A 5.130 Seals - Tandem Summit BPBSBPB 8,822’ 8,478’ N/A 5.620 Motors – Tandem Summit KMS 500HP (1000HP/3600V/165.5A) 8,889’ 8,539’ N/A 5.620 Gauge (Zenith E7) / Centralizer / Anode _____________________________________________________________________________________ Updated By: JLL 07/29/2021 PROPOSED McArthur River Field Well: G-33 Last Completed: FUTURE PTD: 170-011 API: 50-733-20212-00 PBTD: 10,706‘ TD:10,790’ 20 ” 7” 1-4 DV Collar @ 1,003’ 13-3/8” 9-5/8” RKB to MLLW = 110.60’, RKB to Mudline = 235.60’ 5 HK-2 W.F. Zone Top of fill 10,289’ 05/16/2018 G Zone 26” CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Surf 356’ 20 94 H-40 8 RND 19.124 Surf 605’ 13-3/8 61 J-55 BTC 12.515 Surf 4,511’ 9-5/8” 43.5 N-80 BTC 8.755 Surf 6,682’ 47 N-80 BTC 8.681 6,682’ 8,478’ 47 P-110 BTC 8.681 8,478’ 10,090’ 7 29 N-80 BTC 6.184 9,962’ 10,754’ TUBING DETAIL 4-1/2” Surf ±8,760’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-1 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK-1 9,505’ 9,532’ 9,093’ 9,117’ 27’ 05/18/18 Open HK-2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK-2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK-3/4 9,648’ 9,810’ 9,219’ 9,364’ 162’ 05/18/18 Open HK-5 9,826’ 9,942’ 9,378’ 9,482’ 116’ 05/18/18 Open HK-6 9,952’ 10,010’ 9,491’ 9,544’ 58’ 05/18/18 Open WF-1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF-1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF-1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 WF-1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF-1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF-1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF-2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF-2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF-3 10,376' 10,407' 9,876' 9,904’ 31’ 12/1987 Covered WF-3A 10,407’ 10,475’ 9,904’ 9,966’ 68’ 12/1987 Covered WF-3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF-4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 43.70’ 43.70’Hanger – CIW-DCB-ESP 11”x4 ½” Lift & Susp w/ 4” Type H BPV Profile 1 ±2,180’ ±2,180’ 3.833 7.063 GLM #1 2 ±3,608’ ±3,600’ 3.833 7.063 GLM #2 3 ±4,398’ ±4,349’ 3.833 7.063 GLM #3 4 ±4,931’ ±4,849’ 3.833 7.063 GLM #4 5 ±8,760’ ±8,421’ N/A 5.920 Discharge Sub ±8,760’ ±8,421’ N/A 6.750 Pumps ±8,799’ ±8,457’ N/A 6.750 Gas Separator/Intake ±8,800’ ±8,457’ N/A 5.130 Seals ±8,822’ ±8,478’ N/A 5.620 Motors ±8,885’ ±8,536’ N/A 5.620 Centralizer / Anode Grayling Platform G-33 Current 02/09/2018 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Grayling Platform G-33 13 3/8 X 9 5/8 X 4 1/2 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom Valve, WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 ¼ ESP neck, 2- ½ npt continuous control line ports Valve, swab, WKM-M, 4 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 4 1/16 5M FE, HWO, T-24 BHTA, Bowen, 4 1/16 5M FE X 4 1/2'’ Bowen Quick Union Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, WKM-M, 3 1/8 5M FE, w/ MA-16 operator Tubing hanger, CIW-DCB-ESP, 11 X 4 ½ IBT lift and susp, w/ 4'’ type H BPV profile, 5 ¼ EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW w/ 2- 2 1/16 5M SSO, CA slips in head Grayling Platform BOP Stack HAK 404 20.00' 1.00' HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Rig 404 BOP Test Procedure Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program – Oil Producers, Gas Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with kill weight fluid. x Note: Fluid level will fall to a depth that balances with reservoir pressure. x Shoot fluid levels as needed. 3) Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) Fill well with KWF if the fluid is not to surface b) ND tree with no BPV Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test) joint to lift-threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Bryan McLellan (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump-in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1 st valve on standpipe manifold (PM1), close valves 8,10 &11 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross (K2), open PM1, close valves 5,7 & 9 on choke manifold, open valve 10 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close manual and super choke / open valves 7 & 9 on choke manifold. Bleed pressure from step b or c recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. e) Close inside valve (K1) / open outside valve on kill side of mud cross (K2), close valves 2,4 & 6 / open valves 5,7 & 9 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. f) Close valves 1 & 3 / open valves 4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close HCR (CL2) open valves 2,4 & 6 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Close inside valve (CL1) / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2-way check in place. Close blind rams and attach test line to valve 11 on choke manifold, close valve 1,2 & 3 / open valve 11 on choke manifold. Test to 250 psi for 5 minutes and xxx psi (see sundry) for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. j) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record “Accumulator Pressure”. It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read “10 bottles at 2,150 psi”). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the electric pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to “Auto”, not “Manual” so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format. Document both the rolling test and the follow up tests. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well G-33 (PTD 170-011)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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r- ri-RECOVED JUL 2 9 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate L Pull Tubing a Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Installed ESP/GL Completion ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 170-011 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20212-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0018730 / ADL0017594 Trading Bay Unit G-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field / Middle Kenai G Oil, Hemlock Oil 8 West Foreland Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,790 feet Plugs measured N/A feet true vertical 10,240 feet Junk measured N/A feet Effective Depth measured 10,289 feet Packer measured N/A feet true vertical 9,797 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 10,090' 9-5/8" 10,090' 9,605' 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation depth Measured depth 9,020 - 10,626 feet True Vertical depth 8,659 - 10,103 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6 / L-80 8,759 (MD) 8,420 (TVD) Packers and SSSV (type, measured and true vertical depth) 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-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 57 34 3443 45 59 Subsequent to operation: 1244 64 9437 75 71 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development ❑a 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 ❑ 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: 319-246 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadowephilooro.com Authorized Signature: Date: 7 Z5 Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 �9 /s -,-i RBDMS-K�''JUL 3 12019 Submit Original Only n Hilcuru Alaska, LLC Maw M1W=11760, N®mf dim= 235.W 13-3/8" G Zone 6 HK -2 35/8' 2-5 W.F. Zone TwC11l1011B9' Qi/16/201B PBTD: 10,706' TD: 10,79(1' SCHEMATIC CASING DETAIL McArthur River Field Well: G-33 Last Completed: 07/05/2019 PTD: 170-011 API: 50-733-20212-00 Size Wt Grade Conn ID Top Btm 26 43.70' Top (TVD) Btm (TVD) Hanger-CIW-DCB-ESP 11"x4 W Lift & Susp w/ 4" Type H BPV Profile Surf 356' 20 94 H-40 8 RND 19.124 Surf 605' 13-3/8 61 J-55 BTC 12.515 Surf 4,511' 7.063 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' 8,789' 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 BTC 6.184 9,962' 10,754' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 1 3.958 Surf 8,759' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' Top (TVD) Btm (TVD) Hanger-CIW-DCB-ESP 11"x4 W Lift & Susp w/ 4" Type H BPV Profile 2 2,180' 2,180' 3.833 7.063 GUM #1-SFO-2w/RD-2 Dummy valves, RK Latches 3 3,608' 3,600' 3.833 7.063 GLM #2 - SFO -2 w/ RD -2 Dummy valves, RK Latches 4 4,398' 4,349' 3.833 7.063 GUM #3-SFO-2w/RD-2 Dummy valves, RK Latches 5 4,931' 4,849' 3.833 7.063 GLM #4 -SFO -2 W/ RD -2 Dummy valves, RK Latches 3/2015 8,759' 8,420' N/A 5.920 Discharge Sub 8,789' 8,760' 8,421' N/A 6.750 Pumps- Tandem Summit 45 Stage SH16000AR 9,164' 8,799' 8,457' N/A 6.750 Gass parator/Intake 6 8,800' 8,457' N/A 5.130 Seals -Tandem Summit BPBSBPB 12/1987 8,822' 8,478' N/A 5.620 Motors -Tandem Summit KMS 500HP (3000HP/3600V/165.5A) 8,855' 8,889' 8,539' N/A 5.620 Gauge (Zenith E7)/Centralizer/Anode Updated By: JU. 07/25/2019 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 1 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 9,505' 9,532' 9,093' 9,117' 27' 05/18/18 Open HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HKA 9,648' 9,810' 9,219' 9,364' 162' 05/18/18 Open HK -5 9,826 9,942' 9,378' 9,482' 116' 05/18/18 Open HK -6 9,952' 10,010' 9,491' 9,544' 58' 05/18/18 Open WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF -1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF -1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 WF -1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF -2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF -2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF -3 10,376' 10,407' 9,876' 9,904' 31' 12/1987 Covered WF -3A 10,407' 10,475' 9,904' 9,966' 68' 12/1987 Covered WF -3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Covered WF -4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered Updated By: JU. 07/25/2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permi[NumEet 5<art nate Entl Date Trading Bay Unit G-33 HAK 404 50-733-20212-00-00 170-011 6/29/19 7/5/19 Daily Operations: 06/29/19 -Saturday Finish securing loads for transfer to boat. Install and pin feet to derrick. Assist crane crew with deck organization and working boat. Pressure wash drill deck. Offload work boat of wireline unit. Load out mast. Remove draw works, walkways and A leg from carrier. Load Boat #1: mast, carrier, base beams. draw works, driller shack, yellow spreaders, carrier walkways, Aframe, gray cones, stairs and landings. 1st boat departed GPP at 1800 hrs. Transfer crews to grayling and get them oriented, PJSM,Unload boat with tool connex, swap cranes and unload boat with base beams, yellow spreader bars, carrier, A frame, derrick and assembled same. Released boat to head back to GPP. Continued assembling rig, walk ways stairs, bolted draw works to carrier. 06/30/19 -Sunday Continue R/U. Bolted up draw works, tightened storm clamps and binders. Install drive line and guard, set dunnage for pits and pumps. Off load boat. Continue unloading boat, R/U line for pits and pumps, choke manifold. R/U high pressure 2" lines. Circulate well with waterflood from production. Fix leak on bingham pump and began circulating again. Continue R/U of 404. N/D wellhead, install VBR's and plumbing onto BOPE stack. N/U riser and adapter spool. 07/01/19 - Monday Cont. stacking up BOPE. Tq. flanges on same, stand mast, install guy lines, spot dog house, install driller consul, install kill line, R/U control line to remote BOPE panel. Cont. R/U lines to driller console, install brake linkage, M/U flange for choke line, install & test PVT system. Spool line on DW & slip 100' of new line. Prep & scope mast & secure same. Install & test gas detection system, R/U load cell for weight indicator. M/U accumulator hoses. Pin drillers doghouse in place. Unchain blocks, M/U bales, install rig floor. Secure and center BOPE stack. Troubleshoot and repair derrick light. Fill pits with FIW. Function tested accumulator and BOPE's. M/U 4-1/2 IBT test joint, Shell test BOPEs. 07/02/19 -Tuesday Cont. prep & shell test BOPE, repair leaks as needed;Test ROPE as per Hilcorp & AOGCC requirements, AOGCC witness was waived by inspector Jim Regg by email, tested w/ 4-1/2" tj, 250/2,500 good. R/D test eq., pulled blanking sub & BPV monitor well good;R/U summit ESP pulling eq. r/u&check annulus, monitor good, work L/D pins;M/U landing joint, PJSM for pulling completion. Pull hanger free @ 1001k, cont. p/u t/130k where we had an issue with ODS brake band dragging. Troubleshoot & repair brake band issue making adjustments as needed. Pull hanger inside riser pump 20 bbls FIW in annulus, monitor good, pull hanger to floor @ 140k, I/d hanger & landing jt. Held bare pipe shut in drill, cont. POOH;Cont. POOH pumping 4 bbl every 5 stands. Troubleshoot issues w/ Summit Spooler. Find water in air hose. Inspect all air hoses on rig. Fill hole every hour w/ 10 bbl FIW. 8 stds OOH. Cont. POOH to GLM If 1= 2,244'. L/D;Cont. POOH to 5,341', @ GLM #2= 3,543'. L/D. 07/03/19 -Wednesday Cont. POOH f/5341't/4487', standing back 41/2" tubing. L/d GLM 43. C/o cable spool. Cont POOH t/ESP assy, standing back 41/2" tubing. Prep & I/d ESP assy, looking for issues, did find Lower tandem motor shaft appeared to have dropped & uncoupled from uppertandem motor. Clean & clearfloor, prep to pick up new ESP assy. Wait on alternate ESP motors from town. Fill hole 10 bbl every hour. P/U ESP assembly and service as per Summit and Karson. Pressure test G/L mandrels -pass. 07/04/19 -Thursday Cont. assemble ESP assy, test same good. RI w/ ESP assy, w/41/2" 12.6# L-80 Supermax tubing as per tally. TO 2900- 3200 FP, Checking cable every 1000', filling hole 30 bbl every hour. Cont. RIH w/ ESP completion. Run GLM per tally. Checking cable every 1000', filling hole 10 bbl every hour. Splice cable @ approximately 2,235' & test same, good. Cont. RI w/ ESP completion t/ 8845', Checking cable every 1000', filling hole 10 bbl every hour. Test cable. P/U and make hanger penetrations, work on penetrator connection/splice. 07/05/19 - Friday Continue make hanger penetrations, test penetrator & cable good. Land hanger, RILD, placing assembly tail @ 8889' slack off weight 102k. Clear floor, r/d Summit Running eq. Pull landing it, install BPV. Cont. clear floor & r/d. Drain pits prep t/scope & I/d mast. R/D rig floor. R/D del ller's shack. Prep to scope mast, scope mast down & lay over. Nipple down ROPE. Prep well head & n/u tree. Pressure test void, 500 low/ 5000 high -good. Pull BPV and set two way check. Clean pits, mud pump, and all associated lines. Cont. N/U tree equip. Pressure test tree 5000 -good. Pull two way check and hand overto production @ midnight. 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 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogcc.a laska.gov Re: McArthur River Field, Middle Kenai G, Hemlock, and West Foreland Oil Pools, TBU G-33 Permit to Drill Number: 170-011 Sundry Number: 319-246 Dear Mr. Golis: 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, 410:�Z� Daniel T. Seamount, Jr. Commissioner 741 DATED this �� Sday of May, 2019. RBDMS�--KAJMAY 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 i V E MAY 13 2019 AtOr, rr 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install ESP/GL Completion -El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 170-011 • 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20212-00-00 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 ❑Q Trading Bay Unit / G-33 9. Property Designation (Lease Number):10. Field/Pool(s): ADL0018730 L 3 3 -- McArthur River Field / Middle Kenai G Oil, Hemlock Oil & West Foreland Oil Pools 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): 10,790 . 10,240 10,289 9,797 2,191 psi NIA N/A Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 1 10,090' 9-5/8" 10,090' 9,605' 1 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,020 - 10,626 8,659 - 10,103 4-1/2" 12.6 / L-80 8,772 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 F41 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: 6/1/2019 OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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 Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe hlloor .Com SContact Phone: (907) 283-1329 q Authorized Signature: .J� I -'Date: 05� t 3 Zo I COMMISSION USE ONLY that a representative may witness Sundry Number: ✓' I /t ' e o,tLf �l Conditions of approval: Notify Commission s�th Plug Integrity ❑ BOP Test �Q Mechanical Integrity Test ❑ Location Clearance ❑/✓-, Other: jE Z Soo eSL /SoP /QS RBDMS4NMIAY 16 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ElNoFYI u Subsequent Form Required: /U — Lr O 1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /�11 F 0-4 3 Rev 4 1 0 �IS�I2� A/� DD A' Approved appl�a R {a i! 4 NA from the date of approval. Submit Form and Aftachments i Duplicate 111111////// ��//�V// 11 `` VVV 1 ' /� fes' 7�% S /= - �� K Ifil .'A6A..,uc Well Work Prognosis Well Name: G-33 API Number: 50-733-20212-00 Current Status: ESP Producer Leg: Leg #3 (SE corner) Estimated Start Date: June 01, 2019 Rig: HAK 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 170-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) (281) 450-3071 (M) Current Bottom Hole Pressure: 3,662 psi @ 8,711' TO 0.351 lbs/ft (6.76 ppg) based on ESP Gauge Maximum Expected BHP: 3,662 psi @ 8,711' TO 0.351 lbs/ft (6.76 ppg) based on ESP Gauge Maximum Potential Surface Pressure: 2,191 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) *** This is a no flow well 03/20/2015 Brief Well Summary G-33 is a comingled G -Zone, Hemlock, West Foreland Producer that was converted to 298ESP from a dual string gas -lift completion in March 2015. The current ESP installed in May 2018 is starting to fail. We plan to pull and replace the current completion. Last Casing Pressure Test: 02/22/2015 at 8,955' at 1,500 psig and charted for 30 minutes. Procedure: 1. MIRUHAK404 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. General note - Work over fluid will be FIW. BOP'S will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. PU, RIH with ESP/Gas-lift Combo completion. 7. Land ESP with the bottom of the assembly at ±8,885'. 8. ND BOP, NU wellhead and test. 9. Turn well over to production. 10. Conduct SVS testing per AOGCC regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current / Proposed Wellhead Diagram (Same) 4. BOP Drawing 5. Fluid/Flow Diagrams 6. Rolling BOP Test Procedures 7. RWO Sundry Change Form !lileurP Alaeke.I.I.0 RKBtoIeG Harger= 93.](Y Rmm rnuw=110 w Mat,rmdime=2u. 1 26° 20' 10 w eix®I 13-3/8" G Zone 10 HK -2 35/8" W.F.Zone Ta-fulo128Y *��01116110:� r PBTD: 10,706' TD: 10,790' SCHEMATIC CASING DFTAII_ McArthur River Field Well: G-33 Last Completed: 05/21/18 PTD: 170-011 API: 50-733-20212-00 Size Wt Grade Conn ID Top Btm 26 43.70' Top (TVD) Btm (TVD) Hanger-CIW-DCB-ESP 11"x4%"Lift&Susp w/4"Type H BPV Profile Surf 356' 20 94 H-40 8RND 19.124 Surf 605' 13-3/8 61 J-55 BTC 12.515 Surf 4,511' 7.063 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' 7 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 I BTC 6.184 1 9,962' 1 10,754' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 1 3.958 Surf 8,772' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' Top (TVD) Btm (TVD) Hanger-CIW-DCB-ESP 11"x4%"Lift&Susp w/4"Type H BPV Profile 2 2,245' 2,245' 3.833 7.063 GUM #1-SFO-2w/RD-2 Dummy valves, RK Latches 3 3,543' 3,537' 3.833 7.063 GLM #2 -SFO -2 W/ RD -2 Dummy valves, RK Latches 4 4,398' 4,349' 3.833 7.063 GUM #3-SFO-2w/RD-2 Dummy valves, RK Latches 5 4,931' 4,849' 3.833 7.063 GLM #4 -SFO-2 w/ RD -2 Dummy valves, RK Latches 6 5,458' 5,343' 3.833 7.063 GUM #5-SFO-2w/RD-2 Dummy valves, RK Latches 7 5,989' 5,841' 3.833 7.063 GLM #6 -SFO -2 w/ RD -2 Dummy valves, RK Latches 8 6,521' 6,341' 3.833 7.063 GLM #7 -SFO -2 w/ RD -2 Dummy valves, RK Latches 9 7,053' 6,840' 3.833 7.063 GLM #8-SFO-2w/RD-2 Dummy valves, RK Latches 12/1987 8,772' 8,432' N/A 5.920 Discharge Sub 8,855' 8,774' 8,434' N/A 6.750 Pumps- Tandem Summit 45 Stage SH16000AR 9,370' 8'812 8.469' N/A 6.750 Gas Separator/Intake 10 8,814' 8,471' N/A 5.130 Seals- Tandem Summit BPBSL 3/2015 8,831' 8,486' N/A 5.620 Motors -Tandem Summit KMS 500HP (1000HP/3600V/165.5A) 9,035' 8,898' 8,547' N/A 5.620 Gauge (Zenith E7)/Centralizer/Anode Updated By: JLL 06/08/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 1 48' 3/2015 H1% -FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 9,505' 9,532' 9,093' 9,117' 27' 05/18/18 Open HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK -3 9,648' 9,810' 9,219' 9,364' 162' 05/18/18 Open HK -5 9,826' 9,942' 9,378' 9,482' 116' 05/18/18 Open HK -6 9,952' 10,010' 9,491' 9,544' 58' 05/18/18 Open WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF -1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF -1 10,100' 10,110' 9,625' 9,634' 30' 3/2015 WF -1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -1 10,127' 10,132' 9,650' 9,654' S. 3/2015 WF -2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF -2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF -3 10,376' 10,407' 9,876' 9,904' 31' 12/1987 Covered NL10,407' 10,475' 9,904' 9,966' 68' 12/1987 Covered WF -3B10,5121 10,544' 9,999' 10,028' 32' 12/1987 Covered WF -4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered Updated By: JLL 06/08/18 }L'lesra Alaska. LLC wmm,eo��=43.ro rao3ronmtw-uara mast.n dl,�, �s sa 1 26 20° wcav® 13-3/9' G Zone 10 HK -2 9-5/8" W.F.Zone Tap d fl[10,2V M/u/2ms r PBTD: 10,706' TD: 10,790' PROPOSED CASING DETAIL McArthur River Field Well: G-33 Last Completed: Future PTD: 170-011 API: 50-733-20212-00 Size Wt Grade Conn ID Top Btm 26 43.70' Btm (MD) Top (TVD) Hanger -CIW-DC&ESP 11"x4 Y." Lift & Susp w/ 4" Type H BPV Profile Surf 356' 20 94 H-40 8RND 19.124 Surf 605' 13-3/8 61 1-55 BTC 12.515 Surf 4,511' 7.063 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' 7 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 BTC 6.184 1 9,962' 1 10,754' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 1 3.958 Surf 18,900' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' Btm (MD) Top (TVD) Hanger -CIW-DC&ESP 11"x4 Y." Lift & Susp w/ 4" Type H BPV Profile 2 ±2,245 ±2,245' 3.833 7.063 GLM#1-SFO-2w/RD-2 Dummy valves, RK Latches 3 ±3,541 ±3,535' 3.833 7.063 GLM #2 -SFO -2 w/ RD -2 Durn my valves, RK Latches 4 ±4,400 ±4,350' 3.833 7.063 GLM#3-SFO-2w/RD- 2 Dummy valves, RK Latches 5 ±4,932 ±4,850' 3.833 7.063 GLM#4-SFC- 2w/RD- 2 Dummy valves, RK Latches 6 ±5,460 ±5,345' 3.833 7.063 GLM#5-SFO-2w/RD-2 Dummy valves, RK Latches 7 ±5,988 ±5,840' 3.833 7.063 GLM#6-SFO-2w/RD-2 Dummy valves, RK Latches 8 ±6,520 ±6,340' 3.833 7.063 GLM #7 -SFO -2 w/ RD -2 Dummy valves, RK Latches 9 ±7,053 ±6,840' 3.833 7.063 GLM #8 -SFO -2 w/ RD -2 Dummy valves, RK Latches 81' ±8,775' ±8,435 N/A 5.920 Discharge Sub 8,818' 8,855' 41' N/A 6.750 Pumps- Tandem Summit 45 Stage SH160DOAR 9,294' 9,370' 8,906' N/A 6.750 Gas Separator/Intake 10 G-5 9,312' N/A 5.130 Seals- Tandem Summit BPBSL 48' 3/2015 N/A 5.620 Motors- Tandem Summit KMS 500HP(1000HP/3600V/165.5A) 9,011' ±8, 900' ±8,549 N/A 5.620 Gauge (Zenith E7) / Centralizer / Anode Updated By: ILL 06/08/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 1 48' 3/2015 H1K-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 9,505' 9,532' 9,093' 9,117' 27' 05/18/18 Open HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK -3 9,648' 9,810' 9,219' 9,364' 162' 05/18/18 Open HK -5 9,826' 9,942' 9,378' 9,482' 116' 05/18/18 Open HK -6 9,952' 10,010' 9,491' 9,544' 58' 05/18/18 Open WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF -1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF -1 10,100' 10,110' 9,625' 9,634' 30' 3/2015 WF -1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF -2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF -2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF -3 10,376' 10,407' 9,876' 9,904' 31' 12/1987 Covered WF -3A 10,407' 10,475' 9,904' 9,966' 68' 12/1987 Covered WF -3B 10,512' 10,544' 9,999 10,028' 32' 12/1987 Covered WF -4 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Covered Updated By: ILL 06/08/18 H Hilnurp Ate..ka. I.M: Grayling Platform G-33 13 3/8 X 9 5/8 X 41/2 BHTA, Bowen, 41/165M FE X 41/2' Bowen Quick Union Valve, swab, WKM-M, 41/165M FE, HWO, T-24 Valve, wing, WKM-M, 21/165M FE, HWO, T-24 Valve, lower master, WKM-M, 41/165M FE, HWO, T-24 Tubing head, CIW-DCB, 135/83M X 115M, w/ 2- 2 1/16 SM SSO, X bottom Casing head, CIW-W F, 13 5/8 3M x 13 3/8 SOW w/ 2- 2 1/16 5M SSO, CA slips In head Grayling Platform G-33 02/09/2018 Tubing hanger, CI W -DCB -ESP, 11 X 4 X IBT lift and cusp, w/ 4" type H BPV profile, 5 Y. EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, WKM-M, 31/85M FE, w/ -� MA -16 operator Adapter, CIW-Toadstool, 11 5M SIM X 4 1/16 5M FE, prepped for 5'/. ESP neck, 2- % npt continuous control line ports Valve, WKM-M, 21/165M FE, HWO, DO �q Qty 2 Valve, CIW-F, 21/165M FE, HWO, AA trim H ki:.k.. LIA: Grayling Platform BOP Stack HAK 404 Il valves M RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR #2 SUPER —1 #9 CHOKE STRIPPER #3 f #5 #7 #�D HERO iF if MUD r#4#3 #2 PUMP STOCK #4 #6 #8 #5 T1 # MANUAL J CHOKE C4 \\ LP t -q 1G , SUCTION VALVE #� cns � LINE eusTer� �, FLUID TANK/PIT Valle Position o/c) Standpipe Pump Manifold 1(PMl) 0 Manifold Pump Manifold 2 (PM2) 0 Pump Manifold 3 (PM3) C Pump Manifold 0 Pump Manifold 5 (PMS) C Mud Kill Line O Cross Kill Line 2 O HCR valve (Choke line l) C Choke Line 0 Choke Choke Manifold 1(CMl) O Manifold Choke Manifold 2ICM2) C Choke Manifold 3ICM3) O Choke Manifold 6ICM0) C Choke Manifold 5 (CMS) O Choke Manifold 6(CM6) C Choke Manifold O Choke Manifold 81CM8) C Choke Manifold 9lCM9f C Choke Manifold 30 (CMlf)) 0 Super Choke C Manual Choke C O Rig Floor Saf Valve RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR #2 SUPER —1 #9 CHOKE STRIPPER #3 f #5 #7 #�D HERO iF if MUD r#4#3 #2 PUMP STOCK #4 #6 #8 #5 T1 # MANUAL J CHOKE C4 \\ LP t -q 1G , SUCTION VALVE #� cns � LINE eusTer� �, FLUID TANK/PIT Valle Position o/c) Standpipe Pump Manifold 1(PMl) 0 Manifold Pump Manifold 2 (PM2) 0 Pump Manifold 3 (PM3) C Pump Manifold 0 Pump Manifold 5 (PMS) C Mud Kill Line O Cross Kill Line 2 O HCR valve (Choke line l) C Choke Line 0 Choke Choke Manifold 1(CMl) O Manifold Choke Manifold 2ICM2) C Choke Manifold 3ICM3) O Choke Manifold 6ICM0) C Choke Manifold 5 (CMS) O Choke Manifold 6(CM6) C Choke Manifold RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN TUBING, UP CASING ANNULAS "THE LONG WAY" STANDPIPE PANIC LINE RIG FLOOR #2 SUPER #9 CHOKE #3 STRIPPER #3 #5 #7 #1O 1I HEAD A MUD #4 q#2 PUMP STOCK #4 #6 ##5 MANUAL CHOKE C `HCR LP VALVE SUCTION #� GAS LINE BUSTER � FLUID TANK/PIT Valve Position 0/C Standpipe Pump Manifold 11PM31 0 Manifold Pump Manifold 2 (PM21 C Pump Manifold 31PM3f 0 Pump Manifold C Pump Manifolds PMSf D Mud Kill Line 0 Cross Kill Line O HCR valve (Choke Line l) C Choke Line 2 0 Choke Choke Manifoltl 1(CM3) 0 Manifold Choke Manifold 21CM2) C Choke Manifold (CM3) 0 Choke Manitold4(CM4) C Choke Manifolds (CMS) 0 Choke Manifoltl6(CM6) C Choke Manifold 0 Choke Manifold8(CMB) C Choke Manifold9(CM9) C Choke Manifold 30 (CM30) O Super Choke C Manual Choke C Rig Floor Safety O RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN TUBING, UP CASING ANNULAS "THE LONG WAY" STANDPIPE PANIC LINE RIG FLOOR #2 SUPER #9 CHOKE #3 STRIPPER #3 #5 #7 #1O 1I HEAD A MUD #4 q#2 PUMP STOCK #4 #6 ##5 MANUAL CHOKE C `HCR LP VALVE SUCTION #� GAS LINE BUSTER � FLUID TANK/PIT Valve Position 0/C Standpipe Pump Manifold 11PM31 0 Manifold Pump Manifold 2 (PM21 C Pump Manifold 31PM3f 0 Pump Manifold C Pump Manifolds PMSf D Mud Kill Line 0 Cross Kill Line O HCR valve (Choke Line l) C Choke Line 2 0 Choke Choke Manifoltl 1(CM3) 0 Manifold Choke Manifold 21CM2) C Choke Manifold (CM3) 0 Choke Manitold4(CM4) C Choke Manifolds (CMS) 0 Choke Manifoltl6(CM6) C Choke Manifold 0 Choke Manifold8(CMB) C Choke Manifold9(CM9) C Choke Manifold 30 (CM30) O Super Choke C Manual Choke C Rig Floor Safety Rig 404 BOP Test Procedure nak,,.i .AI.Aa,u.c Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) H n'il.,p A.A., LLC Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1" valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open 1" valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/ open outside valve on kill side of mud cross, close valves 5 & 6/ open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to ` 1200 psi and bleed off 200 —300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. n Nilro p Akuka, LLC Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2 -way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. I) Test additional floor valves (TI W or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well G-33 (PTD 170-011) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC 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 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date E !'v" STATE OF ALASKA WSKA OIL AND GAS CONSERVATION C(OISSION j U N 11 206 REPORT OF SUNDRY WELL OPERATIONSix 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ti 31l'utcTo—wri ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install ESP/GL Completion 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development E] Exploratory ❑ Stratigraphic ❑ Service ❑ 170-011 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20212-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 Trading Bay Unit G-33 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field / Middle Kenai G Oil, Hemlock Oil & West Foreland Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,790 feet Plugs measured N/A feet true vertical 10,240 feet Junk measured N/A feet Effective Depth measured 10,289 feet Packer measured N/A feet true vertical 9,797 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 356' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 10,090' 9-5/8" 10,090' 9,605' 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation depth Measured depth 9,020 - 10,626 feet p JUN True Vertical depth 8,659 - 10,103 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 8,772 (MD) 8,432 (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: 146 56 7031 73 75 Subsequent to operation: 204 78 9363 74 76 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development(D Service ❑ Stratigraphic Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDS L❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLLIG[--] 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: 1318-060 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadowe hilcor .com ,/ Authorized Signature: L"D Date: r t Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 RBDMS44'-'--` JUN 1 1 2018 6 ;,« 4tdtriit Original Only • • McArthur River Field Well: G-33 SCHEMATIC Completed:Last 05/21/18 PTD: 170-011 I1i[corp Alaska, LLC API: 50-733-20212-00 RKBto TBG Hanger=43.70' RKB to MLLW =110.60' RKB to Mudline = 235.60' 1 13-3/8" G Zone 2-9 10 HK -2 35/8" W.F. Zone Top offill 10,2891 05/16/2018 7 PBTD: 10,706' TD: 10,790' CASING DETAIL Size Wt Grade Conn ID Top Btm 26 43.70' Btm (MD) Top (TVD) Hanger- CIW-DCB-ESP 11"x4 %" Lift & Susp w/ 4" Type H BPV Profile Surf 356' 20 94 H-40 8 RND 19.124 Surf 605' 13-3/8 61 J-55 BTC 12.515 Surf 4,511' 7.063 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' 7 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 BTC 6.184 9,962' 10,754' TUBING DETAIL 4-1/2" 12.6 L-80 Supermax 1 3.958 Surf 8,772' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' Btm (MD) Top (TVD) Hanger- CIW-DCB-ESP 11"x4 %" Lift & Susp w/ 4" Type H BPV Profile 2 2,245' 2,245' 3.833 7.063 GLM #1 -SFO -2 w/ RD -2 Dummy valves, RK Latches 3 3,543' 3,537' 3.833 7.063 GLM #2 - SFO -2 w/ RD -2 Dummy valves, RK Latches 4 4,398' 4,349' 3.833 7.063 GLM #3 - SFO -2 w/ RD -2 Dummy valves, RK Latches 5 4,931' 4,849' 3.833 7.063 GLM #4 -SFO-2 w/ RD -2 Dummy valves, RK Latches 6 5,458' 5,343' 3.833 7.063 GLM #5 -SFO-2 w/ RD -2 Dummy valves, RK Latches 7 5,989' 5,841' 3.833 7.063 GLM #6 -SFO-2 w/ RD -2 Dummy valves, RK Latches 8 6,521' 6,341' 3.833 7.063 GLM #7 -SFO-2 w/ RD -2 Dummy valves, RK Latches 9 7,053' 6,840' 3.833 7.063 GLM #8 -SFO-2 w/ RD -2 Dummy valves, RK Latches 81' 8,772' 8,432' N/A 5.920 Discharge Sub 8,818' 8,774' 8,434' N/A 6.750 Pumps - Tandem Summit 45 Stage SH16000AR 9,294' 8,812' 8,469' N/A 6.750 Gas Separator/Intake 10 8,814' 8,471' N/A 5.130 Seals - Tandem Summit BPBSL 48' 8,831' 8,486' N/A 5.620 Motors -Tandem Summit KMS 500HP (3000HP/3600V/165.5A) 9,011' 8,898' 8,547' N/A 5.620 Gauge (Zenith E7) / Centralizer / Anode Updated By: JLL 06/08/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) atm (TVD) FT Date Stat S G-0 9,020' 9,050' 8,659' 8,686' 30' 12/1987 G-1 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 G-2 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-2 9,159' 9,164' 8,785' 8,789' 5' 3/2015 G-3 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-3 9,196' 9,237' 8,818' 8,855' 41' 3/2015 G-5 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 H1X-FW 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 9,505' 9,532' 9,093' 9,117' 27' 05/18/18 Open HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK -3 9,648' 9,810' 9,219' 9,364' 162' 05/18/18 Ope HK -5 9,826' 9,942' 9,378' 9,482' 116' 05/18/18 Ope HK -6 9,952' 10,010' 9,491' 9,544' 58' 05/18/18 Open WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 WF -1 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF -1 10,100' 10,110' 9,625' 9,634' 10' 3/2015 WF -1 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -1 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -1 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF -2 10,178' 10,180' 9,696' 9,698' 2' 3/2015 WF -2 10,203' 10,286' 9,718' 9,794' 83' 12/1987 WF -3 10,376' 10,407' 9,876' 9,904' 31' 12/1987 Covered WF -3A 10,407' 10,475' 9,904' 9,966' 68' 12/1987 Covered WF -3B 10,512' 10,544' 9,999' 10,028' 32' 12/1987 Cover d WF -4 1 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Cover d Updated By: JLL 06/08/18 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 1 170-011 5/9/18 1 5/21/18 Daily Operations. ''" 05/09/2018 - Wednesday Production previously bled down tb and casing pressure- monitored well and set BPV. Began N/D tree while setting up koomey and choke house. 05/10/2018 - Thursday Continued N/D tree- some difficulty with studded flange and lifting off tb head. 0745 hrs tree off- cleaned hanger threads and M/U 3 1/2" EUE x RHR blanked test sub. Continued moving and setting up accessory equipment as needed. N/U 13 5/8" 5M BOPE: riser w/ 11" DSA on btm, mud cross w/ manual & HRC on each side, double gate w/ blinds & 2 7/8" x 5" VBRs and annular. Scoped out derrick- pinning same and securing all guy lines. Mounted rig floor with supports and wind walls- loaded floor with handling tools and tongs. Continued spotting equipment as needed. Mounted stairs to rig floor- positioned drillers shack. Offloaded Summit pulling equipment from MV Titan. Mounted beaver slide- M/U and landed 3-1/2" test joint- RHR sub on btm, pumpin, SV & IBOP on top. Began cleaning and organizing deck. Fill BOPE system w/ FIW- shell tested to 2500 psi. Performed BOPE pretest to 250 psi low 2500 psi high- found 2- PH6 safety valve that would not pass test- crossed over 4 1/2" valve for use. Test BOPE to 250 psi low 2500 psi high as per Sundry in accordance with Hilcorp and AOGCC requirements- tested w/ 3- 1/2" and 4-1/2" tb. Perform successful koomey draw down test. Witness waived by Mr. Jim Regg/AOGCC 12:45 5/10/18 by email. M/U line from annulus valve to production header in prep for circ. Continued mopping and pressure washing platform top deck. Backed out blanked RHR sub from hanger- B/D test equipment- pulled BPV- presently M/U landing jt in hanger. 05/11/2018 - Friday Finished M/U 3 1/2" landing jt in hanger- NPFT form sent to and received from TB- tied in rig pump and began pumping down tb at 3 bpm 300 psi increasing to 400 psi- blow on casing from fluid rise but no returns in 1 hr (total of 180 bbls pumped). Shut down pump- no blow on annulus. Tied water flood into tb and pumped 188 bbls w/ no returns on annulus. Tied rig pump on casing valve and began flushing annulus w/ FIW at 2.5 bpm 0 psi- pumped 98 bbls with no returns. Backed out lock down pins while flushing annulus. Total Safety checked and calibrated all LEL & 1-12S sensors (6). Tied rig pump onto kill side of mud cross- picked up on completion string and hanger moved off seat at 82k- string moved uphole at 90k- pulled hanger to surface- NOS & Summit worked and L/D hanger. Pulled enough completion pipe to hang Summit sheaves and run cable and flat pack lines to spoolers Began POOH w/ ESP completion string pumping 10 bbls displacement every 40 jts laid down (crane is moving 5 jts at a time to pipe rack). Mixed 80 bbl sized salt pill while POOH with completion string. Reached cable splice- cut cable and changed spools. 118 jts. OOH = 4,044'. Cont. POOH w/ ESP completion string pumping 10 bbls displacement every 40 jts laid down (crane is moving 5 jts at a time to pipe rack). S/D @ 2:30 for approximately 20 minutes to change out crane oil filters (losing oil pressure). Summit began B/D ESP assy. Total of 536 bbls FIW lost to formation in the last 24 hrs. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 170-011 5/9/18 1 5/21/18 Daily Operations: 05/12/2018 - Saturday 260 jts, 134 pipe clamps, 2 splice clamps recovered during completion assy pull. Finished B/D Summit ESP. Backloaded M/V w/ 1- pipe rack w/ 100 jts and 3- bundles of 20 of 3 1/2" SuperMax completion tb. R/D Summit - cleared and cleaned rig floor and top deck. Changed oil and filters and serviced East crane. Summit's explanation of ESP condition on disassembly: The pumps were good. The upper seal was empty. The lower seal had oil in the btm chamber. The motors combined checked grounded but balanced. The motors had good oil. P/U BJs and M/U BHA #1 6" x 2" rock bit, 4 3/4" x 2 1/4" bit sub, 4 3/4" x 2 1/4" B&O jars, 4- 4 3/4" x 2 1/4" DCs, 4 3/4" x 2 5/8" x -over = 144.45'. L/D BJs and R/U Gill tongs. TIH w/ BHA picking up 3 1/2" 12.95# P-110 PH -6 workstring, strapping, drifting and torqueing to 6000 FPT. S01 was generated and sent to Safety Team due to 1/2 gal oil leakage from tb in flying pipe rack to deck of M/V Resolution. 281 jts. in the hole = 8,868'- pump 100 bbls FIW down tb. per operations engineers. No returns. Cont. TIH w/ BHA #1 picking up 3 1/2" 12.95# P-110 PH -6 workstring, strapping, drifting and torqueing to 6000 FPT. 301 jts. in the hole = 9,489'- pump 40 bbl salt pill (9.9 ppg), chased w/ 60 bbl FIW dwn tb. Cont. TIH w/ BHA #1 picking up work string from 9,489' to 9,953' (top of liner at 9,962'). N/U 7 1/16" stripping head w/ adapter. Expected tag is 10,212' (depth of 2015 C/O). 260 bbls FIW lost to formation last 24 hrs (including 40 bbl sized salt pill) = 796 bbls FIW total losses. 0 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 1 170-011 5/9/18 1 5/21/18 Daily Operations: 05/13/2018 - Sunday Finished N/U 7 1/16" stripping head w/ 11" DS adapter on 11" 5M x 13 5/8" 5M spool. R/U power swivel- M/U single #317- installed stripping rubber and M/U to string- landed rubber. Present depth = 9,953'. P/U off slips- lined up LW and began pumping at 3.5 bpm 40 psi to rig tank. Pump pressure increased from 40 psi to 105 psi, oil in returns now (— 30% returns). Shut down pump- contacted TB- received verbal approval to send fluid- sent NPFT form- production lined up returns to header. Began pumping LW to TB at 4 bpm 100 psi- pumped down rig tank in efforts to pump out most of the oil in tank- return rate calculates to be 25 to 30 % returns. Pumped remainder of 80 bbl sized salt pill (40 bbls) and chased with 70 bbls FIW- shutdown and allowed pill to settle. Began building 2nd 80 bbl sized salt pill. Began pumping LW w/ returns going to TB at 3.5 bpm 105 psi- pressure increased to 400 psi then climbed to 610 psi (bringing pill up). Returns cleaned up- routed returns to rig tank- losses running — 50%- decision was made to reverse circ while easing down to tag. CIH from 9,962' to 10,103' w/o tagging reversing at 3 bpm 300 psi 30% losses (82k SOW 100k PUW). Tagged at 10,103' and had to start rotating to make hole- 92k RotW 2000-3000 RT- washed/rotated to EOJ at 10,110'- reversed btms up at 3.5 bpm 300 psi. ROP — 10'/hr. Cont washing/rotating dwn- returns turn to fine sand @ 10,125'. 92k RotW- putting 5k on bit and washing off. Reversed bottoms up @ 10,141 @ 3.2 bpm 233 psi w/ 60 bph losses. Changed screens on shaker- cont. in hole. Started washing easier making 31' in 15 minutes. Reversed btms up at EOJ 3.6 bpm 300 psi, 2000-3000 RT w/ 45 bph losses. Electrician rewired shaker (rotating backwards). Cont washing dwn reversing btms up every joint- 3.6 Bpm 300 psi 2000-3000RT w/ 45 bph losses. Washed dwn single #325 = 10,233' and tagged (21' deeper than 2015 tag). Torque spiking to 4000 FP w/ 3k on bit (bouncing on something hard). Picked up and reversed btms up. Small pieces of metal in returns. Approximately 4 bbls of sand and scale recovered during C/O. Decision made to POOH. L/D Power Swivel, N/D stripping head. POOH kicking out a single and racking back 12 stands = 9,458'. Spotted 40 bbl balanced sized salt pill- chased w/ 60 bbl of FIW. Continue POOH racking back work string- pumping 10 bbl AW every 20 stands. 27 of 161 stands OOH at report time = 8,557'. 1,512' bbls of FIW lost to formation last 24 hrs = 2308 bbls total losses. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 170-011 5/9/18 5/21/18 Daily Operations: 42 05/14/2018 - Monday Finished POOH from 8,557' to BHA racking back work string. 0830 hrs R/D Gill tongs R/U McCoy tongs- Gill tongs unable to break connections without running into it (not putting out enough torque). P/U BJs and B/D BHA #1 M/U BHA #2 (6" x 2 1/4" 4- bladed X -bar mill, 4 3/4" x 2 1/4" B&O jars, 4- 4 3/4" x 2 1/4" DCs, 4 3/4" x 2 5/8" x -over = 146.10'. P/U Gill tongs and TIH w/ BHA #2 running 3 1/2" 12.95# P-110 PH -6 workstring out of derrick to 10,204'. N/U stripping head- P/U swivel- M/U single #325- installed rubber- M/U to string and landed rubber. Broke circ SW at 2.4 bpm 320 psi (72 bbls to get returns)- established parameters: PUW 105k, SOW 87k, RotW 93k, Tq 3500 FPS, 60 RPMs - eased down and tagged at 10,233'. Pressured up while trying to mill SW- turned fluid around LW (3.3 bpm 470 psi) and began milling on obstruction- loss rate at 16 bph. Milled to EOJ at 10,236'- P/U off btm and rev 180 bbls to flush hole clean from liner top. M/U 10' pup in string and broke circ in rev- rotated down to tag and began losing returns - turned fluid around LW (3.25 bpm 450 psi) and began milling on obstruction at 10,236' Milled to EOP @ 10,246'. Rev. 180 bbls to flush hole clean. Small metal shavings on magnet. M/U 6' pup in string. Circ. LW @ 3.2 bpm, 430 psi, 60 RPM Tq 3500 FPS spiking to 6000 FPS. Made 1'= 10,247'. No new hole made in over an hour. Discussed events and plan forward with Ops Eng- P/U off btm to reverse hole clean. Circulating hole clean (SW) @ 4 bpm 490 psi. Fluid losses (SW) = 24 bph. — 1 gal of fine metal shaving w/ 1/3 bbl of sand and scale recovered in returns during 14' of hole made. Total fluid losses last 24 hrs = 320 bbls for total losses of 2628 bbls FIW. 05/15/2018 -Tuesday Finished circulating hole volume around. B/0 S/B swivel and N/D stripping head. B/0 L/D 6' & 10' pup. POOH to BHA #2 racking back workstring- pumping 10 bbls displacement every 20 stands. P/U BJs and B/D BHA #2 M/U BHA #3 (5 3/4" x 2 1/4" 4 -bladed X -Bar mill, 2- 5" x 11/2" Boot Basket, 4 3/4" x 2 1/4" B&O Jars, 4- 4 3/4" x2 1/4" Dcs, 4 3/4" x 2 5/8" x-over=155.66') TIH w/ BHA #3 running 3 1/2" 12.95# P-110 PH -6 workstring out of derrick- 10 stands= 477'. R/D McCoy tongs and R/U Gill tongs, (issues w/ pancake on McCoys) Cont. TIH w/ BHA #3 running 3 1/2" 12.95# P-110 PH - 6 workstring out of derrick to 120 stands= 7,606' . Adjust rollers on draw works brakes. Cont. TIH w/ BHA #3- 158 stands = 9,964'. Eased down and tagged liner top @ 9,973' (PM) (11' deeper than schematic.)- P/U and rotated thru TOL w/ tongs. CIH to 10,214'. N/U stripping head- P/U swivel- M/U single #325- installed rubber- M/U to string and landed rubber. Began circ SW at 3.5 bpm 0 psi increasing to 320 psi- took 85 bbls to get full returns- estb parameters: PUW 105k, SOW 87k, RotW 93k, Tq 3000 @ 60 RPMs. Eased down to EOJ @ 10,245'- shutdown and M/U 10' pup - reestablished circ (SW) and eased down tagging at 10,247'. Began milling on obstruction- could not maintain rev circ due to pressure- turned fluid around- 3 bpm 500 psi on btm. 1' of new hole made at report time. 210 bbls of FIW lost past 24 hrs for a total of 2838 bbls FIW lost during W/O. Losses running 16 bph. C Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 1 170-011 5/9/18 1 5/21/18 Daily'Operations: 05/16/2018- Wednesday Continued milling on obstruction from 10,248', circ LW at 3 bpm 500 psi - milled down to EOPup at 10,255'- P/U off btm and reversed btms up +. Shut down pump- B/0 pup and M/U #326- milled down to EOJ at 10,276' circ LW- P/U off btm and reversed btms up +. Shutdown pump and M/U 10' pup- milled down to EOP at 10,286' circ LW- P/U off btm and reversed btms up +. Shutdown pump and M/U #327- milled down to 10,289' circ LW- unable to make additional hole in 2 hrs- mill would torque but not cut. Judging by quantity of sand & scale returns ID is mostly open - recovered — 1- gallon of metal cuttings and 5- gallons of 90% scale and sand. Conferred with Ops Eng- ceased C/O operation. P/U off btm. Lined up and reversed hole clean at 3.5 bpm 400 PSI pumping 24,000 strokes = 857 bbls FIW (figuring 20% losses). B/D and L/0 power swivel- B/O x -over sub and safety valve. N/D stripping head- separate DSA and Hall's head. R/D GIII Tongs and P/U McCoy Tongs. Cleared and cleaned rig floor. Kick out single -jt 327. POOH w/ BHA #3 racking back 15 stands of 3 1/2" 12.95# P-110 PH -6 workstring for TCP run= 932.05'. Cont. POOH L/D work string, pumping 10 bbl FIW every 40 jts. 175 of 327 jts OOH = 4,876' at report time. 288 bbls of FIW lost to formation last 24 hrs f/ a total losses of 3126 bbls FIW. Total recovery during C/O = 2 gals of metal fines & — 20 gals of 90% scale and sand. 05/17/2018 -Thursday Continued POOH from 4,876' to BHA laying down 3 1/2" PH6 workstring, pumping 10 bbls FIW every 40 jts. B/D BHA #3 completely (thru w/ C/O operation). 5 3/4" bladed mill 90% worn, heavily damaged- 70% of one blade broken off - emptied boot baskets and recovered 11/2 gal of mostly scale and sand- handful of 1" x 1/2" chunks of steel that resemble pkr slips and thin/flat metal- pics in 'O' drive of all. Cleared floor and prepped for TCP M/U. Held PJSM w/ Tripoint, crane and rig crew, expeditor, WSM plus prod foreman and lead op. Assembled TCP guns per Tripoint. ( 4 1/2" Bull Blug, 4 1/2" 6 SPF SDP TCP Assembly= 505', 4 1/2" Safety Spacer, 3 3/4" Firing Head, 4- 2 7/8" 6.5# L-80 EUE Pup joints, 2 7/8" ported sub/ debris barrier, 3 1/2" PH -6 box x 2 7/8" EUE Pin, 3- 3 1/2" PH -6 P-110 WS, 3 1/2" PH6 BxP RA Tag Sub)= 642.84' in hole. M/U R/I remaining 13 1/2 stands (839.13') of 3 1/2" 12.95# P-110 PH -6 work string, dropping rabbit = 1,481' in hole. M/U 3 1/2" PH -6 x 4 1/2" Supermax xover. M/U 4 1/2" supermax xover on btm of safety valve. Cont. RIH P/U 4 1/2" 12.6# L-80 Supermax tubing- strapping, drifting, and torqueing to 3200 FPs. Depth at report time is 6,772'- target depth is 10,011'. 80 bbls FIW lost to formation last 24 hrs- total losses during W/O operation is 3206 bbls FIW. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig LPI Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 170-011 5/9/18 5/21/18 Daily Operations: ft 05/18/2018 - Friday Continued RIH from 6,772' picking up 4 1/2" 12.6# L-80 Supermax tb, strapping, drifting, torqueing to diamond (3200 FPT). Ran in to 10,060' (267 jts Supermax)- SOW 86k PUW 101k- laid out #267 to put btm shot at 10,027' (pre - correlation). Secured well. Spotted Pollard Eline- R/U w/ pumpin & packoff on top of safety valve. M/U 111/16" Gamma Ray/CCL tool w/ 5' weight bar- TIH and tagged at 9,497'- pulled correlation pass and emailed same to Ops and Resv Engs- decision was made to P/U 5' and fire TCP guns. POOH w/ Eline and rigged to side. P/U string 5' (101k) and dropped bar- guns detonated in — 3 mins- slight puff on tb. Checked P/U- S/O to M/U hose. R/D E/L. Perfed intervals are: 9,505'- 9,532' HK2, 9,648'- 9,810' HK3, 9,826'- 9,942' HK5 & 9,952'- 10,010' HK6 (6SPF). Lined up and pumped 285 bbls FIW (SW) around to purge gun gas @ 3.25 bpm 140 psi- took 125 bbls to get returns, fluid losses running 21 bph. Shutdown pump and well settled. Pulled 10 stands of 4 1/2" 12.6# L-80 Supermax tb. = 644.69' - (puts EOTs above perfs). M/U DCB test plug in string (w/ needed xovers) using jt of 3 1/2" tb- landed test plug. M/U Pumpin, Safey Valve and IBOP. Filled system w/ FIW and shell tested to 3000 psi. Test BOPE to 250 psi low 3000 psi high as directed in accordance with Hilcorp and AOGCC requirements- tested w/ 3- 1/2" tb. Perform successful koomey draw down test. Witness waived by Mr. Jim Regg/AOGCC 08:59 5/18/18 by email. Began changing out brakes on rig. Total Safety came onboard (earlier) and tested LEL & H2S gas alarms and sensors- documented same. Operation S/D due to high winds (unable to crane 4 1/2" IBT test jt to floor)- 60 mph gusts. Finished replacing brake pads on draw works drum, facility cleanup. Changed out to 4 1/2" test jt- continued testing BOPE to 250 psi low 3000 psi high as directed in accordance with Hilcorp and AOGCC requirements. 155 bbls FIW lost to formation last 24 hrs f/ total losses of 3361 bbls. 05/19/2018 - Saturday Finished BOPE test (witness waived)- 250 psi low 3000 psi high as directed in accordance to Hilcorp and AOGCC requirements. Witness waived by Mr. Jim Regg/AOGCC. B/D test equipment, POOH racking back 4 1/2" Supermax completion string pumping 10 bbls every 20 stands. 133 stands in derrick. Changed handling equipment to 3 1/2" - lined up and pumped 30 bbls FIW down tb and 50 bbls down casing to flush pipe before laying it down- shutdown pump. Laid out 30 jts of 3 1/2" PH6 workstring. B/D TCP assy. All shots fired. Cleared and cleaned rig floor. Spotted Summit equipment. Hung sheaves in derrick. Ran cable and flat pack to rig floor.,M/U centralizer/anode, Zenith, 2 - motors 562 series kmslt 500 hp, 2- lower tandem seals 513 series, gas separator/intake, 2- pumps 45 stg SH 16000, discharge, bolt on ported pressure sub, xo to SuperMax, tubing handling joint. Serviced components and wired as needed. Began draining rig tank. Started RIH w/ ESP/SPM assy on 4 1/2" 12.60# L-80 Supermax tubing (MUT 3200 FP) adding SPMs as directed. 14 stands in hole at report time = 1,062'. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-33 I Moncla 404 50-733-20212-00 1 170-011 5/9/18 1 5/21/18 Daily Operations: 05/20/2018 -Sunday Continued running in hole w/ Summit ESP/SPM assy on 4 1/2" 12.6# L-80 Supermax tb from derrick- installing clamps and SPM as directed. Checking cable every 1000'. Stopped at 6,447' (96 stands in hole)- changed out cable spool and made electrical splice- checked good. Cable splice @ 6,588'. Continued running in hole as before. 1820 hrs 113 stands in hole = 7,560', out of canon clamps- got assistance from dock to receive needed clamps. Received clamps at 1910 hrs- finished running in hole. M/U hanger w/ 4 1/2" Supermax pin x IBT box pup and 4 1/2" IBT landing joint. Plumbed electrical cable and flat pack thru hanger and tested same. Landed hanger on seat- SOW was 84K- EOT = 8,898'- NOS rep ran in lock down pins while landing jt was B/O L/D. R/D Summit equipment. NOS rep set BPV. B/D all crossovers in prep for rig demobe- cleared and cleaned rig floor- R/D McCoy tongs and handling tools- dismounted rig floor- disconnected all BOPE lines. Scoped down and laid over derrick. Began pressure washing and cleaning equipment in prep to be moved to beach. N/D BOPE- presently at double gate on N/D. 05/21/2018 - Monday Finished N/D 13 5/8" 5M BOPE. Washed components as they were broken down. Continued prepping equipment to be transferred off Grayling. Quadco dismantled PVT, pump and pulling unit sensors. Lowered tree thru deck and landed same on tb head- torqued flanged. Summit tested connector- good. NOS tested void to 500 psi/5 mins 5000 psi/15 mins- good. Continued bolting on new tree components- hooked up flow lines. NOS pulled BPV & set 2WC- shell tested tree to 5000 psi/15 mins- good. Pulled 2WC and turned well over to production at 1530 hrs. Raised derrick to half mast and spooled off old drill line- spooled on new drill line. Separated equipment bound f/ Moncla, Monopod, Weatherford & CIFO. NPFT form sent and received from TB- began pumping out rig tank to TB. Total Safety dismantled LEL & 1-12S gas detection system. Cont. separating equipment. Removed solids from rig tank. L/D derrick and secured all lines for transportation to beach. Loaded equipment onto M/V Resolution. Continued pressure washing and organizing equipment in preparation to be put backloaded. • Re• •, James B (DOA) From: Michael Quick <mquick@hilcorp.com> Sent: Monday, May 14, 2018 10:13 AM � 6/ 17118 -/ 1Zl(, , To: Regg,James B (DOA); Daniel Duckworth - (C) Cc: Dan Marlowe; Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); Stan Golis Subject: RE: G-33 BOPE Test Report Moncla 404 11May18 All future BOPE testing for this G-33 workover will be to the 3000 psi (2500 psi annular) test pressure per discussions with Jim Regg and Guy Schwartz, per the copy of the sundry Mr. Regg emailed on 5/11/18. Regards, Mike From: Michael Quick Sent: Friday, May 11, 2018 12:24 PM To: 'Regg,James B (DOA)' <jim.regg@alaska.gov>; Daniel Duckworth -(C) <dduckworth@hilcorp.com> Cc: Dan Marlowe<dmarlowe@hilcorp.com>; 'Brooks, Phoebe L(DOA)' <phoebe.brooks@alaska.gov>; 'DOA AOGCC Prudhoe Bay' <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: G-33 BOPE Test Report Moncla 404 11May18 Mr. Regg— After reviewing the mark ups on the "Original" sundry copy you provided, we have found a typo on our submission. On the Well Work Prognosis, under Current Bottom Hole Pressure,we listed 3662 psi @ 8771'TVD. This 3662 was a typo, and should be 3062 psi, which is the correct pressure for the 0.351 psi/ft gradient listed. With the typo correcte., the Max Potential Surface Pressure is correct as listed at 2,191 psi. Regards, Mike SCANNED JUN 0.1 NIB From: Michael Quick Sent: Friday, May 11, 2018 12:09 PM To: 'Regg,James B (DOA)' <iim.regg@alaska.gov>; Daniel Duckworth -(C) <dduckworth@hilcorp.com> Cc: Dan Marlowe<dmarlowe@hilcorp.com>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: G-33 BOPE Test Report Moncla 404 11May18 Mr. Regg— Attached is the copy of the sundry that Hilcorp received for this well. Note there are no markups on either the 10-403 form or the procedure. I will give you a call to discuss. Thanks, Mike 1 • • From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 11, 2018 12:04 PM To: Daniel Duckworth - (C) <dduckworth@hilcorp.com> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Michael Quick<mquick@hilcorp.com>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: G-33 BOPE Test Report Moncla 404 11May18 Sundry required test to 3000psi. Please send test charts for my review. Jim Regg Supervisor, Inspections AOGCC 333 With Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Daniel Duckworth - (C) [mailto:dduckworth@hilcorp.com] Sent: Friday, May 11, 2018 11:48 AM To: Regg, James B (DOA) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Michael Quick<mquick@hilcorp.com>; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov> Subject: G-33 BOPE Test Report Moncla 404 11May18 D ouvuly D W5M(C) @ Hilcorp Alaska/CIO dduckworth@hilcorp.com 907-776-6754 601-323-8099 2 0STATE OF ALASKA • OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *AII BOPE reports are due to the agency within 5 days of testing* Submit to:jim.reqq a(�,alaska.gov;AOGCC.InspectorsAalaska.gov; phoebe.brookst7a alaska.gov Contractor: Moncla Rig No.: 404 DATE: 5/11/18 Rig Rep.: Anthony Edmond Rig Phone: 907-776-6754 Operator: Hilcorp Alaska Op. Phone: 907-776-6754 Rep.: Danny Duckworth E-Mail dduckworth@hilcorp.com Well Name: TBU G-33 PTD# 1700110 Sundry# 318060 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250-2500 Annular: 250-2500 Valves: 250-2500 MASP: 2191 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13 5/8"5M P Pit Level Indicators P P #1 Rams 1 2 7/8"x 5"VBR P Flow Indicator NA NA #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 2 1/16" P Inside Reel valves 0 NA HCR Valves 2 2 1/16" P Kill Line Valves 1 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 P CHOKE MANIFOLD: Pressure After Closure(psi) 1550 P Quantity Test Result 200 psi Attained (sec) 38 P _ No.Valves 10 P Full Pressure Attained (sec) 192 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles#&psi(Avg.): 6@1700 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 4.0 Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested w/3 1/2"&4 1/2"tb. Total Safety tested(and calibrated)LEL&H2S gas sensors-6 total, 2 each at rig tank, BOP cellar&rig floor. Pit level indicators checked good. AOGCC Inspection 24 hr Notice Yes Date/Time 5/9/18 11:15 AM Waived By Jim Regg Test Start Date/Time: 5/11/2018 1:00 (date) (time) Witness Test Finish Date/Time: 5/11/2018 5:00 Form 10-424(Revised 04/2018) 2018-0511_BOP_Moncla404_TBU_G-33 60to e_b // .7- _',(-:,,:"---T-:---------.--A-000--------r7-7--------------__ .-.74-,. '--,... -,, \ ,:i-z __500, ,io. :Ft:: 1.1,:: 1,.... _____._:.---___;...„..___:,:.„2:::-.22,, -.., --„,,, ..„,,, "))c' ,I . r NI„,,..---- 7------, '---- /4' . 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OO s 91, _ _ : _ 005• / Op �� _ _0pV ��. -- ,. ``�-- 000 .`' ` / . --__ 009 --•:------ ��J/' 5 £1 • f _ • - w� THE STATE 01ALASKA GOVERNOR BILL WALKER Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: McArthur River Field, Middle Kenai G Oil, Hemlock Oil & West Foreland Oil Pools, TBU G-33 Permit to Drill Number: 170-011 Sundry Number: 318-060 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, Hollis S. French Chair DATED this 2 t day of February, 2018. REDII•S L ° L 6 2[18 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25260 RECOVED FEB 13 2018 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate [] - Other Stimulate ❑ Pull Tubing B Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Install ESPIGL Completion PI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 170-011 3. Address: 3800 Cenlerpoint Drive, Suite 1400 6. API Number. Anchorage, AK 99503 50-733-20212-00 - 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A ` Will planned perforations require a spacing exception? Yes ❑ No -' Trading Bay Unit / G-33 ' 9. Property Designation (Lease Number):10. Field/Pool(s): ADL0018730 McArthur River Field/ Middle Kenai G Oil, Hemlock Oil & West Foreland Oil Pools it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,790 - 10,240 10,212 9,727 2,191 psi NIA NIA Casing Length Size MD TVD Burst Collapse Structural 356' 26" 356' 360' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 10,090' 9-5/81, 1 10,090' 9,605' 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,020-10,626 r 8,659 - 10,103 3-1/2" 9.2 / L-80 8,732 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A & N/A N/A & N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development E] ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work. Commencing Operations: 3/25/2018 OIL Ej • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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 Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com Authorized Signature: M.� Date: %-1 13 /1 8 Contact Phone: 907 283-1329 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. I — 0 ` _! // Plug Integrity ❑ BOP Test [,r Mechanical Integrity Test ElElIiA/'/l9Location Clearance Other: 3ooa PSI ea P TEST �c 7dtL.5 6oP775TGYe-LE Post Initial Injection MIT Req'd? Yes ❑ No RRD11S v F_p 2 6 H18 No N Subsequent Form Required: Spacing Exception Required? Yes ❑ L G/ Subsequent APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z Z t I rol t Form 10-403 Revised 4/2017 Approved applicati i v ill Q11 o Aso he date of approval. Submit Form and Attachments in Duplicate n Hi" Alaska, Uk Well Work Prognosis Well Name: G-33 API Number: 50-733-20212-00 Current Status: ESP Producer Leg: Leg #3 (SE corner) Estimated Start Date: March 25, 2018 Rig: Moncla 404 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: 8. Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 170-011 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: 3,662 psi @ 8,711' TO 0.351 lbs/ft (6.76 ppg) based on ESP Gauge Maximum Expected BHP: 3,662 si @ 8,711' TVD 0.351 lbs/ft (6.76 ppg) based on ESP Gauge Maximum Potential Surface Pressure: 2 psi 2'79 1 P s t Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) *** This is a no flow well 03/20/2015 Brief Well Summary G-33 is a comingled G -Zone, Hemlock, West Foreland Producer that was converted to and ESP from a dual string gas -lift completion in March 2015. The current ESP is starting to fail. We plan to pull the current ESP completion and replace with a combination ESP / Gas lift completion. Last Casing Pressure Test: 02/22/2015 at 8,955' at 1,500 psig and charted for 30 minutes. Procedure: 1. MIRU Moncla 404 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. General note - Work over fluid will be FIW. BOP'S will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/2 psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). -5oor i mMR ✓!ar -if& ZX&Oe! 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with ESP completion. 6. RIH with cleanout assembly, Circulate bottoms up, POOH. 7. PU TCP guns, RIH and perforate per the Perf recommendation. 8. After detonation, circulate perf gas, confirm well is static, POOH. 9. PU, RIH with ESP/Gas-lift Combo completion. 10. Land ESP with the bottom of the assembly at ±8,885'. 11. ND BOP, NU wellhead and test. 12. Turn well over to production. 13. Conduct SVS testing per AOGCC regulations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing 6. Fluid/Flow Diagrams 7. Rolling BOP Test Procedures 8. RWO Sundry Change Form K HileorP Alaska, LLC RKBto TBG Hngr=43.70' 1 Ze' 2Y' w1W tan' 133/8" G Zone HK -2 35/8' W.F. Zone Top o", 10,212 PBTD: 10,706' SCHEMATIC CASING DETAIL McArthur River Field Well: G-33 Last Completed: 03/11/15 PTD: 170-011 API: 50-733-20212-00 Size Wt Grade Conn ID Top Btm 26 Btm (MD) Hanger 8,732' 8,395' Surf 356' 20 94 H-40 8 RND 19.124 Surf 605' 13-3/8 61 J-55 BTC 12.515 Surf 4,511' 5.13 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' 9,159' 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 BTC 6.184 9,962' 10,754' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax 2.992 Surf 8,732' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' To (MD) Btm (MD) Hanger 8,732' 8,395' N/A 5.13 Discharge Balt -On 8,733' 8,396' N/A 5.13 Pump (x3)- 513 Series 68 Stage SG7300 8,798' 8,456' N/A 5.13 Intake 2 8,799' 8,457' N/A 5.13 Seals (x2) 8,817' 8,473' N/A 5.62 Motor (x2) 562 Series 340HP/1900V/107A 8,883' 1 8,534' 1 N/A 1 5.62 1 Gauge/Centralizer/Anode Updated By: JLL 02/09/18 PERFORATION DETAIL Zone To (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status "G" Zone 9,020' 9,050' 8,659' 8,686' 30' 12/1987 "G"Zone 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 "G" Zone 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-3 9,159' 9,164' 8,785' 8,789' 5' 3/2015 "G" Zone 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-4 9,196' 9,237' 8,818' 8,855' 41' 3/2015 "G" Zone 9,294' 9,370' 8,906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 1 48' 3/2015 "G" Zone 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 West Foreland 10,086' 10,092' 9,612' 9,618' 6' 12/1987 WF -2 10,100' 10,110' 9,625' 9,634' 30' 3/2015 West Foreland 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -2 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -2 10,127' 10,132' 1 9,650' 9,654' 5' 3/2015 WF -3 10,178' 10,180' 9,696' 9,698' 2' 3/2015 West Foreland 10,203' 10,286' 9,718' 9,794' 83' 12/1987 West Foreland 10,376' 10,475' 9,876' 9,966' 99' 12/1987 West Foreland 10,512' 10,544' 9,999' 10,028' 32' 12/1987 West Foreland 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Updated By: JLL 02/09/18 McArthur River Field Well: p PROPOSED Last PTD: 70 om-011 eted: FUTURE Hiloorn Alaska, LLC API: 50-733-20212-00 PBTD: 10,706' TD: 10,790' CASING DETAIL Size Wt Grade Conn ID Top Btm 26 Btm (MD) Hanger 2 ±2,250' Surf 356' 20 94 H40 8 RND 19.124 Surf 605' 13-3/8 61 J-55 BTC 12.515 Surf 4,511' 9,077' 43.5 N-80 BTC 8.755 Surf 6,682' 9-5/8" 47 N-80 BTC 8.681 6,682' 8,478' ±6,350' 47 P-110 BTC 8.681 8,478' 10,090' 7 29 N-80 BTC 6.184 9,962' 10,754' TUBING DETAIL 4-1/2" 12.6 L-80 Superman 1 3.958 Surf ±8,730' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.70' 43.70' Btm (MD) Hanger 2 ±2,250' ±2,250' "G" Zone GLM#1 3 ±3,556' ±3,550' 30' GLM #2 4 ±4,400' ±4,350' 8,704' GLM #3 5 ±4,932' ±4,850' 9,077' GLM #4 6 ±5,465' ±5,350' 3/2015 GLM #5 7 ±5,998' ±5,850' 8,789' GLM #6 8 ±6,531' ±6,350' 9,164' GLM #7 9 ±7,064' ±6,850' "G" Zone GLM #8 9,250' ±8,730' ±8,393' N/A Discharge Bolt -On G-4 9,196' 9,237' 8,818' Pum 41' 3/2015 "G" Zone 9,294' Intake 10 8,973' 76' 12/1987 Seals 9,312' 9,360' 8,922' 8,965' Motor 3/2015 ±8,885' ±8,536' N/A Gauge/Centralizer/Anode Updated By: ILL 02/12/18 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status "G" Zone 9,020' 9,050' 8,659' 8,686' 30' 12/1987 "G" Zone 9,070' 9,094' 8,704' 8,726' 24' 12/1987 G-2 9,077' 9,091' 8,711' 8,724' 14' 3/2015 "G" Zone 9,132' 9,164' 8,761' 8,789' 32' 12/1987 G-3 9,159' 9,164' 8,785' 8,789' S. 3/2015 "G" Zone 9,169' 9,250' 8,794' 8,866' 81' 12/1987 G-4 9,196' 9,237' 8,818' 8,855' 41' 3/2015 "G" Zone 9,294' 9,370' 81906' 8,973' 76' 12/1987 G-5 9,312' 9,360' 8,922' 8,965' 48' 3/2015 "G" Zone 9,412' 9,440' 9,011' 9,035' 28' 12/1987 HK -2 ±9,505' ±9,532' ±9,093' ±9,117' ±27' Future HK -2 9,553' 9,594' 9,135' 9,172' 41' 3/2015 HK -2 9,603' 9,649' 9,180' 9,220' 46' 3/2015 HK -3 ±9,648' ±9,810' ±9,219' ±9,364' ±162' Future HK -5 ±9,826' ±9,942' ±9,378' ±9,482' ±116' Future HK -6 ±9,952' ±10,010' ±9,491' ±9,544' ±58' Future WF -1 10,084' 10,088' 9,611' 9,614' 4' 3/2015 West Foreland 10,086' 10,092' 9,612' p 9,618' 6' 12/1987 WF -2 10,100' 10,110' 9,625' 9,634' 10' 3/2015 West Foreland 10,105' 10,132' 9,630' 9,654' 27' 12/1987 WF -2 10,116' 10,119' 9,640' 9,642' 3' 3/2015 WF -2 10,127' 10,132' 9,650' 9,654' 5' 3/2015 WF -3 10,178' 10,180' 9,696' 9,698' 2' 3/2015 West Foreland 10,203' 10,286' 9,718' 9,794' 83' 12/1987 West Foreland 10,376' 10,475' 9,876' 9,966' 99' 12/1987 West Foreland 10,512'10,544' 9,999' 10,028' 32' 12/1987 West Foreland 10,593' 10,626' 10,073' 10,103' 33' 12/1987 Updated By: ILL 02/12/18 .0 nil.,rp Alu.kx. LId: Grayling Platform G-33 13 3/8 X 9 5/8 X 31/2 Valve, swa 3 1/8 5M T Valve, wing, WD 21/16 5M FE, H T-24 Valve, lower mas 31/8 SM FE, I Tubing head, CIW-DCB 135/83M X 115M, w, 2- 21/16 SM 550, X bottom Casing head, CIW-WF, 135/83M x 133/8 SOW, 2- 2 1/16 5M SSO, CA slip: head Grayling Platform G-33 ESP Tubing hanger, CIW-DCB-ESP, 11 X 3 % EUE lift and susp, w/ 3" type H BPV profile, 5 Y, EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator BHTA, Bowen, 3 1/8 5M FE X 3" Bowen quick Union WKM-M, 3 1/8 SM FE, w/ MA -16 operator "oadstool, 11 5M I FE, prepped for -'/1 npt continuous ine ports WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 IW -F, 2 1/16 3M FE, WO, AA trim . H Hilnnrp Alxxka, LIA: Grayling Platform G-33 13 3/8 X 9 5/8 X 41/2 BHTA, Bowen, 41/165M FE X 41/2" Bowen Quick Union Valve, swab, WKM-M, 41/16 5M FE, HWO, T-24 Valve, wing, WKM-M, 21/16 SM FE, HWO, T-24 Valve, lower master, WKM-M, 41/16 SM FE, HWO, T-24 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 21/16 5M 550, X bottom Casing head, CIW-W F, 13 5/8 3M x 13 3/8 SOW w/ 2- 21/16 SM 55O, CA slips in head Grayling Platform G-33 Proposed 02/09/2018 Tubing hanger, CIW-DCB-ESP, 11 X 4 N IBT lift and susp, w/ 4" type H BPV profile, 5 Y EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, WKM-M, 3 1/8 SM FE, w/ , MA -16 operator Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 %ESP neck, 2- %npt continuous control line ports Valve, WKM-M, 21/165M FE, �y HWO, DD Qty 2 Valve, CIW-F, 21/16 5M FE, - _HWO,AAtrim .H RII.,,p Alwko, 1,11: Grayling Platform 2016 BOP Stack Moncla 05/13/2016 n�me: M MONCLA RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR #z SUPER #9 CHOKE #3 f STRIPPER #3 #5 #7 #10 MUD #4 #2 UMP STOCK #4 1j #S #8 #5 MANUAL) CHOKE LP HC. SUCTION VALVE #� cnsR LINE BUSTER � FLUID TANKIPIT Valve Position 0/CI Standpipe Pump Manifold 1(PMl) 0 Manifoltl Pump Manifold O Pump Manifold 3 (PM3) C Pump Manifolds (PMO) 0 Pump Manifold 5 (PMS) C Mud Kill Linei 0 Crass Kill Line 0 HCR valve (Choke Line l) C Choke Line 0 Choke Choke Mangold l(CM31 0 Manifold Choke Mangold 2(CM2) C Choke Mangold (CM3) 0 Choke Manifold C Choke Manifolds (CMS( O Choke Mangold C Choke Manifold ] (CM]I O Choke Manifold C Choke Manifold C Choke Manifold l0 (CM30) O Super Choke C Manual Choke Safety Valve C Rig Floor 0 MONCLA RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" STANDPIPE PANIC LINE RIG FLOOR #z SUPER #9 CHOKE #3 f STRIPPER #3 #5 #7 #10 MUD #4 #2 UMP STOCK #4 1j #S #8 #5 MANUAL) CHOKE LP HC. SUCTION VALVE #� cnsR LINE BUSTER � FLUID TANKIPIT Valve Position 0/CI Standpipe Pump Manifold 1(PMl) 0 Manifoltl Pump Manifold O Pump Manifold 3 (PM3) C Pump Manifolds (PMO) 0 Pump Manifold 5 (PMS) C Mud Kill Linei 0 Crass Kill Line 0 HCR valve (Choke Line l) C Choke Line 0 Choke Choke Mangold l(CM31 0 Manifold Choke Mangold 2(CM2) C Choke Mangold (CM3) 0 Choke Manifold C Choke Manifolds (CMS( O Choke Mangold C Choke Manifold ] (CM]I O Choke Manifold C Choke Manifold MONCLA RIG #404 FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN TUBING, UP CASING ANNULAS "THE LONG WAY" #4 #1 GAS — 6USTER FLUID TANKIPIT 9 MUD PUMP LP SUCTION LINE STANDPIPE -HCR VALVE # Valve Poshion O/C Standpipe Pump Manifold I (PM3) 0 Manifoltl Pump Manifold 21 PM2) C Pump Manifold 3 (PM3) D Pump Manifold 4(PM4) C Pump Manifold 5 PM5) 0 Mud Kill Line 1 0 Cross Kill Line2 O HCR valve Line 1) C Choke Line2 O Choke Choke Manifold 1(CM1) O Manifold Choke Manifold 2 (CM2) C Choke Manifold 3 (CM3) 0 Choke Manifold 4(CM4) C Choke Manifold 5(CM5) D Choke Manifold 6(CM6) C PANIC Choke Manifold 2(CM]) 0 LINE Choke Manifold 6(CMR) C Choke Mani fold 91CM9) C RIG FLOOR Jlz Choke Manifold 10 (CM10) 0 Illi Super Choke C Manual Choke C SUPER y #9 Rill Floor Safe Valve 0 CHOKE �STHEAD #3 tt #S #% #i0 HEAD if STOCK #4 #6 #6 MANUAL 71 CHOKE -HCR VALVE # H Hil.q AI.Ak , LLC Attachment #1 Moncla Rig 404 BOP Test Procedure Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) H Hil.,p Alaska, LLC Moncla Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BODE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety valve and IBOP in testjoint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1" valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on testjoint, close outside valve on kill side of mud cross, open 1" valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5 & 6 /open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to — 1200 psi and bleed off 200-300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. H Ril mrp Alaska, LLC Moncla Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug / 2 -way check in place. Close blind rams and attach test line to valve 10 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/ -3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "30 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto', not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well G-33 (PTD 170-011) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC 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 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date • • Brooks, Phoebe L (DOA) ?TI?$k(7001;0 From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Friday, April 08, 2016 11:04 AM To: Brooks, Phoebe L (DOA) Subject: FW: Grayling G-33 - PTD: 170-011 - Revised Schematic Attachments: G-33 Schematic 2016-04-08.pdf Hi Phoebe Found that we had sent an incorrect schematic (wrong depth listed)with the 10-404 perforating report last year. Attached is the corrected schematic. Would you please get this into your well files?? Thank you SCAMP ='h: 2 $ LUIS Larry From: Juanita Lovett Sent: Friday, April 08, 2016 10:59 AM To: Larry Greenstein Cc: Subject: Grayling G-33 - PTD: 170-011 - Revised Schematic Larry, Attached you will find the revised schematic for G-33. The 10-404 submitted for this well last March listed an incorrect perforation depth. The interval was listed as 10,178—10,192 when it should have been 10,178—10,180. Thank you, 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 • ! 11 McArthur River Field,TBU SCHEMATIC Well:G-33 Completed: 03/11/15 Il➢tearp Alaskar,LLC CASING DETAIL RKB to TBG Hngr=43.70' SIZE(in) HS(in) WT(#/ft) GRADE CONN ID(in) TOP(ft) BTM(ft) Cmnt 20 26 94 H-40 8 RND 18.936 43 605 No Rtrns Surf 13.3/8 17.5 61 1-55 BTC 12.515 43 4,511 Rtrns srf;fix leak @ 999ft 8.681 2ksx G.>40%Unbnd 9.5/8 12.25 47,43.5 P110,N80 BTC 8 625 41 10,090 >8 900ft.TOC:8,910ft r 7 8.5 29 N-80 BTC 6.059 9,962 10,754 200 sxs G.Bump plug. TUBING DETAIL 3.5 - 9.2 L-80 Su permax 2.867 Surf 8732' Tubing Detail No. Depth(ft) Item t, 43 Hanger 1 8,732' Discharge Bolt-On '.. 2 8,733' Pump(x2)-513 Series 068 Stage 3 8,798' Intake T o-c 4 8,817' Motor-562 Series 340 HP S 8,883' Anode 1i PERFORATION DETAIL Top(ft) Btm(ft) Date Zone 9,020 9,050 12/1987''G"Zone t 9,070 9,094 12/1987"G"Zone 9,077 9,091 3/2015 0-2 mom'_ 1 2 9,132 9,164 12/1987"0"Zone 9,159 9,164 3/2015 G-3 9,169 9,250 12/1987"G"Zone 9,196 9,237 3/2015 0-4 5. 5 9,294 9,370 12/1987"G"Zone �e 9,312 9,360 3/2015 0-5 9,412 9,440 12/1987"G"Zone 9,553 9,594 3/2015 HK-2 °0 Zone 9,603 9,649 3/2015 HK-2 10,084 10,088 3/2015 WF-1 10,086 10,092 12/1987 West Foreland 10,100 10,110 3/2015 WF-2 10,105 10,132 12/1987 West Foreland 10,116 10,119 3/2015 WF-2 10,127 10,132 3/2015 WF-2 - - 10,178 10,180 3/2015 WF-3 10,203 10,286 12/1987 West Foreland 10,376 10,475 12/1987 West Foreland L 10,512 10,544 12/1987 West Foreland 10,593 10,626 12/1987 West Foreland W.F.Zone Top of fill --p a"" 10,212' 74.17.440,14, TD a 10,790ft STATE OF ALASKA ' AL,,.,r<A OIL AND GAS CONSERVATION COME` MON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate 0 Other El Install ESP Performed: Alter Casing El Pull Tubing❑ Stimulate-Frac El Waiver ❑ Time Extension❑ Change Approved Program El Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ p,,,a tX.I4. 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number C-,,,,•-ri'. Name: Hilcorp Alaska,LLC Development El Exploratory❑ 170-011 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: RECEIVED Anchorage,AK 99503 50-733-20212-00 7.Property Designation(Lease Number): 8.Well Name and Number: APR 1 3 Z015 ADL0018730 Trading Bay Unit/G-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): F c3CC McArthur River Field/Middle Kenai G Oil&West oreland Oil Pools 11.Present Well Condition Summary: Total Depth measured 10,790 feet Plugs measured N/A feet true vertical 10,240 feet Junk measured N/A feet Effective Depth measured 10,212 feet Packer measured N/A feet true vertical 9,727 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 360' 26" 360' 360' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 10,090' 9-5/8" 10,090' 9,605' 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation depth Measured depth 9,020-10,626 feet True Vertical depth 8,659-10,103 feet SCANNED APR 2 4 2015 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 8,732'(MD) 8,395'(ND) Packers and SSSV(type,measured and true vertical depth) 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: 123 32 1216 1108 1060 Subsequent to operation: 233 82 5953 192 182 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 El WAG ❑ GINJ El 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: 315-019 Contact Dan Taylor Email dtaylort hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature 971„ - ,,, �1et"- Phone (907)777-8319 Date 4/10/2015 47/.--,2c -15' RBDMggiOI l 2015 Form 10-404 Revised 10/2012 / u t ri McArthur River Field,TBU SCHEMATIC Well:G-33 Completed: 03/11/15 Hileorp Alaska,LLC CASING DETAIL RKB to TBG Hngr=43.70' SIZE(in) HS(in) WT(#/ft) GRADE CONN ID(in) TOP(ft) 8TM(ft) Cmnt 20 26 94 H-40 8 RND 18.936 43 605 No Rtrns Surf 13.3/8 17.5 61 1-55 BTC 12.515 43 4,511 Rtrns srf;fix leak @ 999ft 9.5/8 12.25 47,43.5 P110,N80 BTC 8.681 41 10,090 2ksx G.>40%Unbnd 8.625 >8,900ft.TOC:8,910ft 7 8.5 29 N-80 BTC 6.059 9,962 10,754 200 sxs G.Bump plug. TUBING DETAIL 3.5 - 9.2 L-80 Supermax 2.867 Surf 8732' ✓+ Tubing Detail No. Depth(ft) Item a 43 Hanger 1 8,732' Discharge Bolt-On 2 8,733' Pump(x2)-513 Series 068 Stage 3 8,798' Intake 4 8,817' Motor-562 Series 340 HP 5 8,883' Anode R Top(ft) BtmPE(ft)FORATION DETAIL Date 9,050 12/1987"G"Zone Zone 9,020 9,070 9,094 12/1987"G"Zone 9,091 3/2015 G-2 9,164 12/1987"G"Zone 9,164 3/2015 0-3 9,250 12/1987"G"Zone 1 9,077 2 9,132 9,159 3 9,169 4 9,196 9,237 3/2015 0-4 5 9,294 9,370 12/1987"0"Zone 9,312 9,360 3/2015 0-5 9,412 9,440 12/1987"G"Zone 9,553 9,594 3/2015 HK-2 "G"Zone 9,603 9,649 3/2015 HK-2 10,084 10,088 3/2015 WF-1 10,086 10,092 12/1987 West Foreland 10,100 10,110 3/2015 WF-2 10,105 10,132 12/1987 West Foreland 10,116 10,119 3/2015 WF-2 10,127 10,132 3/2015 WF-2 10,178 10,192 3/2015 WF-3 10,203 10,286 12/1987 West Foreland L 10,376 10,475 12/1987 West Foreland 10,512 10,544 12/1987 West Foreland 10,593 10,626 12/1987 West Foreland W.F.Zone Top of fill 10,212' : .. TD=10,790ft Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 02/10/15-Tuesday HOLD JSA SAFETY MEETING. CHANGE OUT 2 HOLD DOWN PINS ON WELLHEAD. RE-TEST OK. N/D FLANGES ON TOP OF TREE AND INSTALL BPV'S. N/D FLOWLINES. N/U RISER AND SINGLE PIPE RAM. M/U ACCUMLATOR HOSES AND N/U BOP STACK.WHILE R/U SCAFFOLDING AROUND BOPS CLEAN SUCTION SCREEN ON ACCUMULATOR. HOLD JSA SAFETY MEETING.TORQUE UP DOOR BOLTS OF BTM SAFETY RAMS. RID LIFT PLATE ON ANNULAR. FINISH BUILDING SCAFFOLDS AROUND BOPS. R/U BELL NIPPLE AND FLOW LINE SENSOR. R/U DRIP PAN. GET ELEVATION MEASURMENTS. R/U BELL NIPPLE EXTENSION AND DRESSER SLEEVE. M/U FOSV, IBOP ON TEST JOINTS. BEGIN TESTING CHOKE MANIFOLD.TESTED VALVES 1-11 250 LOW-3000 PSI HIGH. MAKE UP TEST JOINTS AND FILL STACK.ATTEMPT TO TEST DUAL RAMS. PRESSURE DROPPING ON HIGH SIDE. RE-PACK HANGER. STILL LEAKING. PULL BACK PRESSURE VALVE. R/U ON SHORT STRING CIRC LONG WAY TO GET GAS OUT OF ANNULAR. R/U TO DO ROLLING TEST. MR BOB NOBLE W/AOGCC WILL COME OUT TO WITNESS TEST. 02/11/15-Wednesday HOLD JSA SAFETY MEETING.CHANGE OUT SHEARED PIN ON STEM CASING VALVE. INSTALL FLOOR AND RIG UP ON SHORT STRING SIDE TAKING RETURNS UP ANNULUS. 189 BBLS PUMPED TO GET RETURNS,TOTAL PUMPED 500 BBLS DUE TO GAS COMING OUT OF CASING VALVE. TEST CHOKE MANIFOLD. BLOW LINES DRY. RIG UP LINE CASING, FILL ANNULUS WITH C PUMP. PULL BPV ON LONG STRING SIDE. HOLE TAKING 5 1/2 BBLS PER HR. SPACE OUT LANDING JOINT DUE TO DUAL BLOCK SLIPS HEIGHT. INSTALL SLIPS.START PULLING ON DUAL STRING FROM 240K-260K. @ 250K. HANGER PULLED FREE FROM BOWL.WORK TUBING FROM 240K-260K,4.5 'OF STRETCH NO TUBING MOVEMENT. R/U ELINE TO CUT TUBING. R/U ON LONG STRING AND PUMPED 87 BBLS DOWN LONG STRING GOT RETURNS IN ANNULUS. PUMPED TOTAL OF 160 BBLS DOWN LONG STRING. 02/12/15-Thursday Cont. R/u a-line on short string. M/U 2" RCT. RIH cut @ 7,307'wlm, pulled 9001b over to come free, POOH. R/U e-line on long string. M/u 1 11/16 tubing punch, RIH punch holes f/8,940'-8,943'wlm. POOH. M/U 2.5 jet cutter, RIH correlate& cut @ 8,906'wlm. POOH. Pump down long string taking returns up annulus @ 3bpm,427 bbls total pump. Small amount of scale in returns. P/u s/s to 110k. R/u eline,TIH with 2.5"jet cutter to 6,019'WLM.Try to work through, no go, having over pull, pooh. M/u 2" RCT cutter and TIH to 7,306'fire tool, POOH,cutter fired. M/U 2" RCT, RIH correlate&cut @ 8,865'wlm, POOH. R/d e-line. R/U& pull on duals, p/u t/210 had movement cont p/u t/260k&work making 8.5'total. R/u dual slips, pull short string t/160&work no movement, pull on long string movement @ 120k. R/d eline. R/u and pull s/s pick up to 170k,wk no movement. R/U& RIH with 2.5"jet cutter to 6,004'wlm 15'above GLV#6 make cut, all indication show cut tubing POOH. R/d eline and r/u on s/s and I/s pick up pulling free at 152,000#pull hangers to floor and lay down same. 02/13/15-Friday PTSM. L/d hangers,set long string in dual slips. Start pooh with short string,tallying while pooh. 180 joint out with 5 GLM. PTSM with night crew. Continue pooh. L/d 14 joints and cut jt.Total joints out 194 joints, 13.89'cut joint, 5 GLM with pups- 5,974' pipe measurements. P/u on long string r/d dual slips and control panel. POOH with long string 85k-105k off btm. L/D L/S SSV nipple,control line w/14-Stainless Steel bands. Continue pooh with 3 1/2 butt completion tubing. L/d 266 jts, 9 glm,sssv nipple=8,194'total. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 02/14/15-Saturday PTSM.Cont. L/d 3 1/2 production tubing. L/d total from L/S-286 jts, 10 GLM, 1 sliding sleeve, 1-sssv nipple, 1-13.16'cut jt =8,829.24'.Clear floor. Clean floor,cellar, pipe rack&walkways. Set test plug.C/O upper rams to 2 7/8"x 5"variables& lower rams to 3'/:". R/u 3 1/2 tj. Fill stack&surface eq w/water,shell test 250&3000,good. Test BOPE as per Hilcorp& AOGCC regulations,witness waived by AOGCC inspector Bob Noble @ 14: 30.Tested w/3 1/2 test jt,250 low,3000 high, annular 250 low, 2500 high.All good. PTSM. Install wear bushing. M/u BHA assembly. 8-1/8" Mill Guide,Overshot,x-over, bumper/oil jars,6-4-3/4"drill collars,acc jars,x-over=230.90'. 17 bbls to fill hole.TIH with 3-1/2 PH-6 workstring torqueing every connection to 8000 ft/#. Shut down to fix radiator hose. Continue TIH with 3-1/2 PH-6 workstring torqueing every connection to 8000 ft/#.Tag fish @ 6,025' DPM.90k p/u 86k s/o. R/u power swivel. Start pumping 2.25 bbls/min rotating 120 rpm @ 4000 ft/lbs slack off and start milling over fish 6"stop rotating s/o 5'and latch fish p/u 20k over,s/o and r/d swivel. 02/15/15-Sunday R/U e-line. M/u 1 11/16"tubing punch. RIH t/6,024'wlm, unable to pass, POOH r/d e-line. Jar on string starting @ 140 working up t/180 string came free w/13k added wt. L/d pup jts,c/o elevators. POOH up wt off btm 104. McCoy's started scarring tubing,c/o dies w/same results.C/O McCoy tongs for BJ's. Cont. POOH. Overshot at rig floor fish pulling wet. R/U foster tongs,cont pooh. L/D fish,41jts, 2 GLM's, 2 pups&2 cut jts, total= 1,292.85'recovered.Completion has 1/4" build up of scale in the id of the tubing. Cleaned&cleared rig floor. Prep BHA unable to shuck fish from overshot. M/u BHA- oversize mill guide dressed for 3-1/2",top extension,overshot,bumper/oil jars,6-4-3/4"drill collars,acc jars,x-over= 231.30'.TIH with 3-1/2" PH-6 workstring to 6,453.92'. 02/16/15-Monday Cont.TIH t/7,267', up wt 110,dn wt 98k. P/U swivel. Get parameters, up wt 112,dn wt 104,free tq 1k,engage fish @ 7,310'. P/u on short string t/127k work 6 rounds in to the left working string f/127-160 tq fell off.Appeared higher connection may have broke. Rotate to right to re-tq 24 turns,tq 4k,tq fell off p/u 128k,string coming free. L/D swivel. POOH wet up wt 124k. L/d BHA. Continue pooh. L/D fish. Hot tap as needed due to trap pressure. Recovered remaining short string to packer backing out left hand anchor sub. L/D 50 jts,3 GLM w/pups=1,576.72'. Clear and clean rig floor, pipe rack while fixing leak on radiator and circulating head for draw works. P/U BHA#3-Oversize mill guide 8"OD,Top Extension,Overshot, Bumper/Oil Jars,6-4-3/4" Drill Collars,Acc Jar,X-Over=231.30'.TIH w/3-1/2" 12.95#work string t/ 1,352'. 02/17/15-Tuesday PTSM.Service rig and change oil in rig motor. Continue tih with workstring to 8,879' 131k p/u weight/110k s/o weight. Latch fish @ 8,879'p/u to 140k let jars bleed down.Continue p/u to 220k no go.Start jarring at 200k 4x pulled free. Having 30 k drag,continue pooh. PTSM.Continue pooh to BHA. L/d jars,overshot and dual packer assembly. P/u overshot and shuck top pup joint. Clean and clear rig floor. Re-dress overshot and m/u BHA#4 Oversize mill guide,top extension, overshot, Bumper/oil Jars,6-4-3/4" Drill Collars,Acc Jars,X-over=231.30 to workstring-3-1/2" 12.95#PH-6.TIH t/8,903'. M/u swivel and pup joint. 134k p/u weight, 114k s/o weight.Start rotating over fish 100 RPM,3000 ft/lbs torque 2 bbls/min 89 psi to 8,919', latch pressure came up to 150 psi.Shut down pump. P/u to 220k letting jars go off and s/o to 90k. R/d swivel. R/u pump in sub start pumping 1.8 bbls/min @ 233. Cont.jarring, nogo. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 02/18/15-Wednesday Cont.jarring on fish @220k, pump at 2bbls/min 250 psi. R/u s/line. M/u 2.15 swage and TIH to 9,980'wlm. Pooh,r/u eline. M/u tubing punch 10 shots and TIH and space punch for 9,924'-9,926'wlm. Fire punch, no indication of fired. Pooh. Punch didn't fire.Cut 75'off of eline and rehead. M/u tubing punch and TIH with same. Place punch 9,924'-9,926'wlm,fire punch. Pooh. L/d punch. P/u tubing to 160k. M/u and TIH with 2" RCT to 9,914'WLM. Fire cutter, no indication of cut. Pooh. L/d eline. M/u 1 joint and s/o to 90k. Reset jars. P/u workstring to 220k multiple times while pumping 3.5 bpm @ 950 PSI. Fish not free. L/d joint and r/u eline.TIH with 2" RCT to 9,478'WLM. Fire cutter, no indication of cut. Pooh. R/u 1 joint and continue jarring on fish @ 220k s/o to 90k to reset jars. Fish not free. R/u swivel and rotate with 6000 ft/#. Continue working fish by torqueing and overpull string, unable to rotate.Start pumping 3bpm @200 psi with returns, lost return after 30 bbls.String unable to rotate. R/u swivel. R/u eline and TIH with RCT cutter while mixing 20 bbls NW-50 pill. P/u work string to 150k cut fish at 9,000'. Good indication of cut,weight fell off to 140k. Pooh. Ooh with eline and r/d. P/u workstring free pulling 146k. Pump 20 bbls NW-50 pill followed by 63 bbls FIW. Pooh 3 stds 140k. P/u while filling annulus 02/19/15-Thursday Hold JSA safety meeting.Service rig and equipment. Fill hole and monitor for loses. POOH with workstring, p/u weight 140k. L/d BHA. Recovered 95.02'=2 joints of tubing and 2 cut joints.Clean and clear rig floor. M/u BHA#5-Wave bottom shoe,6-joints 8-1/8"washpipe,top bushing,x-over, bumper/oil jars,6-4-3/4"drill collars,Acc jars,x-over= 415.40'. TIW with 3-1/2" PH-6 workstring to 8,520'. Install Halls Head Rubber. Continue TIH saw top of fish @ 9,014'. Continue s/o and tag @ 9,028'. R/u swivel,wash down to 9,060'3bbls/min 290 psi,getting scale in returns. 02/20/15-Friday Cont.wash over fish f/9,060'to 9,190',circ 3 bpm, 260 psi, rot tq 2600 off,4500 on. CBU x2 clean, @ 3BPM,260 psi. R/d swivel. Pull halls head. POOH. L/d wash pipe BHA. Clean and clear rig floor. M/u BHA#6-Overshot,top extension, bumper/oil jars,6-4-3/4"drill collars, acc jars,x-over=230.85'. R/u McCoy tongs to load cell and check torque.TIH with 3- 1/2" PH-6 workstring to 8,748', up wt 128,do 110. 02/21/15-Saturday P/U 9 5/8 RTTS w/circ.valve. M/u connections. RIH &set @ 118'.Test t/1500 psi,good._Back out running tool&POOH. Pull wear bushing. M/u 3 1/2 test jt.Set test plug,fill stack&CM.Shell test t/2500 good. Service rig&housekeeping while transporting AOGCC inspector. PJSM w/all involved.Test BOPE as per Hilcorp&AOGCC regulations.Witnessed by AOGCC inspector,Jeff Jones.Tested w/3 1/2 test jt, 250 low,3000 high,annular 250 low,2500 high.All good. Had drip on CMV #10 stem, packed stem good, had small leak on nipple t/lower ram 4-way valve,repaired good. Pull test plug. Install wear bushing. M/u top sub for circ valve.TIH and M/u into RTTS. P/u, pooh and L/d RTTS.TIH to 9,000', 134k p/u 114k s/o. TIH engage fish@ 9,014'. P/u w/10k over free, up wt 143k, POOH. Tongs slipping on joint,change out tong dies. Continue pooh. L/d BHA. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 02/22/15-Sunday Continue L/d fish-475.73'.Total recovered=21 blast joints,2 cut jts. New TOF @ 9,489'.Clean and clear rig floor. R/d McCoy tongs and r/u Fosters tongs. M/u Tripoint 9 5/8"test packer.TIH with 3-1/2" PH-6 workstring to 8,955', 126k p/u weight, 108k s/o weight,set packer,set 28k down on packer. Test annulus to 1500 psi for 30 mins charted,good. Unset packer,pooh 126k p/u weight. L/d packer.Clear and clean rig floor. M/u BHA#7-Overshot,Top Extension, Bumper/Oil jars,6-4-3/4"drill collars,Acc jars,x-over=230.85'. TIH with 3-1/2" PH-6 workstring. 136k p/u weight, 116k s/o weight 298 joints.Tag top of fish@ 9,490'. R/u pump in sub. 02/23/15-Monday 136k p/u weight, 116k s/o weight. Engage fish @ 9,490'p/u to 210k on fish,pulled free. POOH w/4k extra wt. LID BHA& fish recovered-13 joints 2-cut pieces, 1-sliding sleeve=436'.Clean and clear rig floor. M/u BHA#8- shoe 8 1/8,1 jt washpipe 8 1/8 HT,Top Bushing,X-over, Bumper/Oil Jar,6-4-3/4" Drill Collars,ACC Jar,X-over=265.22'.TIW w/3-1/2" PH- 6 workstring.Work each stand f/9,030't/Tag @ 9,859'dpm. M/u Halls Head rubber and power swivel. Reverse circulating @ 3bpm @ 340 psi, rotating 132 RPM.tq off 2800,on 5200.Wash down to 9,941' DPM.CBU 3X. POOH t/2,439'. 02/24/15-Tuesday Cont. POOH. L/d BHA-8 1/2"shoe in gauge. M/u BHA#10-5-3/4"Overshot,Top Extension, Bumper/Oil Jars,6-4-3/4" drill collars,Acc Jars,x-over=230.85'.TIH to 9,926' DPM. 140k p/u weight, 120k s/o weight. Latch fish and set 10k down. P/u to 180k. Fish moving up hole.Weight fell to 140k. Cont Pooh. L/d BHA and fish= 14.41'cut piece, 10.70 Seal Assembly. M/u BHA#11-Spear assy,circ sub, mill head 8.5"OD, bushing,x-over,double pin, mud motor, magnet,double pin, boot basket, boot basket,double box, bumper/oil jars,6-4-3/4"drill collars,Acc jars,x-over=276.45'.Surface test motor 2 bpm @ 300 psi. TIH w/3-1/2" PH-6 workstring to 1,646', 22 stds. POOH. 02/25/15-Wednesday Cont.TIH f/1,646' t/9,280'.Tagged up. Up wt 135,do 118. Wk string. Unable to wk through. P/u swivel. Rot wt 130,tq 4- 6k,circ 3 bpm,420 psi.Attempt to wash&ream through hanging at same depth. L/d swivel. POOH. L/d Pioneer packer milling assembly.Clean and clear rig floor. M/u BHA#11-Tapered Mill 8.5 OD, Double Box,x-over, 1-4-3/4"drill collar,x- over,8.5 OD string mill,x-over, bumper/oil jars,6-4-3/4"drill collars,Acc Jars,X-over=277.46'.TIH w 3-1/2" PH-6 Workstring. 126k p/u weight, 110k s/o weight.Tag 8,534'won't work through. R/u swivel,work through tight spot 8,534'- 8,610'4x 4-6 k torque 3bpm @ 270 psi. Cont.TIH to 9,280',tag. R/u swivel 4-6k torque,3bpm@ 300 psi.Tight spots: 8,534',9,280',9,303'.Continue TIH to 9,941'Top packer. L/d swivel. ii. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 02/26/15-Thursday POOH f/9,941't/2,335'. Cont. POOH L/D 8 1/2 string&taper mil assembly.Clear floor. P/U BHA#12- Spear assy,circ sub, mill head 8.5"OD, bushing,x-over,double pin, mud motor, magnet,double pin, boot basket, boot basket,double box, bumper/oil jars,6-4-3/4"drill collars,Acc jars,x-over=276.45'. P/U swivel, up wt 144,dn 124, rot wt 130 tq 4700-4800. TIH tag w/spear @ 9,940, pump 4 bpm,910 psi, RIH t/9,942' unable to get spear down to engage mill head, no tq. increase or diff pressure,p/u w/op of 15k.Cont.try to wk down no go. P/u 35k,over pull free.Attempt to wk back down w/same results. L/D swivel. POOH t/2,017'. Service rig.Clear fuel line. Respond to fire drill,shut in well, meet at muster area. Proceed to escape capsule for abandon platform drill. TIH t/9,918'up wt 144,dn 122. 02/27/15-Friday Cont. POOH f/2,017'. L/d BHA. Last 1'of spear had been sheared off,no wear on mill,grapple had signs of movement half way up mandrel. P/U BHA#13-8 1/2 burn shoe,top bushing,xo, bumper sub,oil jar,6-4 3/4 DC,acc jar,xo=234.04'. TIH t/9,938', up wt 144k,dn 122k. Install Halls head bushing&power swivel. Change out air dryer on rig pump. Circ @ 3 bpm,305 psi, rot wt 130,tq,4900-5000.Tag top of packer @ 9,940'. Burn over 2.5'packer,moved down 2',stopped,cont. burn. Gas units came up t/7,215 units. Flow check, no flow, lined up on gas buster cbux2 @ 3bpm,gas units down. Cont. burn on shoe moving down hole.Chase t/9,955'. CBUx2 L/d swivel. Pull Halls head bushing. POOH. L/D BHA. 02/28/15-Saturday Clear floor. M/u 3 1/2 TJ. Pull wear bushing.Set test plug. Fill stack&surface eq. PJSM w/all involved.Test BOPE as per Hilcorp&AOGCC regulations.Witness waived by AOGCC,Jim Regg @ 9: 32 on 2-26-15. Tested w/3 1/2 test jt, 250 low, hi,‘P 3000 high,annular 250 low, 2500 high.All good. Pull test jt. Install wear bushing. Break down test jt. P/U BHA#14-short ;5� catch overshot w/6.5 grapple,xo, bumper sub,oil jar,6-4 3/4" DC,ACC.jar,xo=229.53'. C/O failed Foster tongs. TIH t/ 9,933', up wt 140, dn 120. Cont RIH t/engage fish @ 9,962'stack 20k dn. P/u no show on wt repeat process. L//d 2 jts. POOH L/d BHA, no recovery. Had a 1/2"x11" piece of metal inside grapple. Discuss options.Wk on cutting down guide on overshot for next run. 03/01/15-Sunday Prep&P/U BHA#15- overshot w/6 grapple,xo, bumper sub,oil jar,6-4 3/4" DC,ACC.jar,xo=230.17'. TIH t/9,954' up wt 140 dn 122. P/U swivel, up wt 144,dn 124, pump 2 bpm 170 psi. RIH engage fish @ 9,962',set down 20k p/u had 8k op,fell off,cycled 5x. Last attempt had over pull. Pulled 60k over,jarred 3x @ 70k over,came free. R/D swivel. POOH. L/d BHA, no recovery. Break down overshot, had 6.25"marking on top bushing&grapple was spread&dull. Clear floor. R/u W/L. RIH w/3"magnet. Run#1 recover packer slip&small metal pieces. 2nd run recover packer slip&1//2"x 6 metal strap on the way out with 3rd run. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 03/02/15-Monday Cont.W/L, running 3" magnet, recover 3/4" metal piece&fines. RIH w/8" LIB, brought back half moon impression TOF. R/D W/L. P/U BHA#16-short catch overshot w/6 1/8"grapple,xo, bumper sub,oil jar,6-4 3/4" DC,acc.jar,xo=229.53'. TIH t/9,954'up wt 140k,dn 120k. RIH t/9,962'engage fish,set down 20 k, p/u t/20k over, bled jars off p/u t/200k(60k over)no movement.Set down p/u t/40 over jarred&came free w/no wt show,set down x2 set 20k dn. P/u no o/p. POOH t/9,619'had over pull 4x worked through. Hang Blocks,cut drill line 120'.Service rig. POOH slow t/4,024'hanging up @ casing collars w/fish, having to wk through. 03/03/15-Tuesday Cont. POOH f/4,024'w/fish. 3,027'was the last time we saw any o/p at casing collars. OOH had recovered 28"of packer mandrel,w/broken spear from Pioneer tool. Service rig.Wait on boat to deliver W/L hands. R/U W/L. RIH w/3" magnet t/ 9,920'wlm. P/u w/50#op dropped off.OOH recovered part of slip die. P/u 2" magnet painted bow spring cent. RIH t/ 9,928' p/u had op hit spang's several x to free. POOH recovered part of slip die, bow springs had paint removed top& bottom down t/4.5-5"collapse. R/d W/L. P/U BHA 16-Spear w/4.8 grapple,xo, bumper sub,oil jar,6-4 3/4" DC, acc.jar, xo=228.07'.TIH t/9,958', up wt 144,dn wt 122. R/U circulate 2 bpm,230 psi. Engage fish @ 9,964',set dn20k,p/u no op or wt gain, repeat process same results. POOH t/9,866'. 03/04/15-Wednesday Cont. POOH t/9,710'. R/d Foster tongs. R/u Hawkjaw.Train hands in operation. POOH changing break in work string. L/d BHA, no recovery. No identifiable markings. R/U W/L. RIH w/3" magnet,appear to have fallen through obstruction w/bow spring t/9,920'wlm. POOH recover fines. RIH w/5" LIB t/9,913'wlm. POOH,showing fish top 1/3 impression. R/d W/L. R/d Hawkjaw. P/u Foster tongs. P/U BHA#18-Spear w/4.8 grapple,xo,xo 3 1/2 if x 4 1/2 if,xo 4 1/2 if x 3 1/2 if, bumper sub,oil jar,6-4 3/4" DC,acc.jar,xo=234.00'. TIH t/7,758', up wt 116k,dn wt 100k. 03/05/15-Thursday Cont.TIH t/9,964' DPM,tag TOF.Set down 10k fell through t/9,967'. P/u no wt show or drag. POOH. RECOVERED MILL OUT EXTENSION,X-O, PUP JT,OTIS X NIPPLE,ONE JT TBG, MULE SHOE. LAY DOWN SAME. CONTINUE BREAKING TOOLS DOWN FOR SHIPMENT. PICK UP 6"OD REVERSE MILL, BUMPER JAR,OIL JAR,6 4 3/4" DC,ACC JARS AND X-O,TIH 156 STDS. P/U 9 JTS 3 1/2//PH6 TAGGED UP @10,208'. R/U POWER SWIVEL, MILL 4' POWER SWIVEL STALLING OUT TO 10,212'. COULD NOT GET ANY DEEPER. REVERSE OUT ONE TBG VOLUME SAND AND OIL BACK. 03/06/15-Friday POOH WITH WORKSTRING. L/D BHA. CLEAN RIG FLOOR. REMOVE ALL TOOLS. TRIP IN HOLE WITH 3 1/2" MULE SHOE ON WORKSTRING TO 10,212' DPM,TAGGED UP. RIGGED UP TO REVERSE OUT TO TRADING BAY. REVERSE OUT ONE HOLE VOLUME 800 BBLS PUMPING @3 BBLS PER/MIN. RIG DOWN LINES. POOH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-33 50-733-20212-00 170-011 2/10/15 Future Daily Operations: 03/07/15-Saturday FINISH POOH WITH 3 1/2" PH6 WORK STRING. L/D MULE SHOE. PULL WEAR BUSHING. R/U TO TEST BOP'S. TEST BOP'S AS PER HILCORP AND AOGCC SPECS TO 250 LOW 3000 HIGH.ALL TEST GOOD.WITNESS WAIVED BY JIM REGG,AOGCC MARCH 5, 2015 10:56 AM. RIG DOWN TEST EQUIPMENT AND SET BACK WEAR BUSHING. HELD SAFETY MEETING AND JSA WITH BOTH CREWS AND HALIBURTON ON PICKING UP 4 5/8" PERF GUNS, 5 SPF. CONTINUE PICKING UP TOTAL 1,113'. TRIP IN HOLE WITH 3 1/2"WORKSTRING DRIFT SAME OUT OF DERRICK. DEPTH AT 6 AM 7,000'. 03/08/15-Sunday TRIP IN HOLE TO 10,160'SPACE OUT PLACING END OF GUNS @ 10,190'. R/U E-LINE. P/U 1 1/16"GAMMA RAY TOOL.TEST LUB TO 1500 PSI. RIH AND LOG.SHOWING 25'TO HIGH. POOH LAY TO SIDE. P/U SINGLE RIH TO 10,215'.TAG BAD CSG. PICK UP TO 10,195' PIPE MEASURMENTS.TEST LUB. RUN BACK IN HOLE. LOG UP SHOWING NEEDED TO P/U 3'TO PUT P GUNS ON DEPTH. POOH RIG DOWN E-LINE. PICK UP 3' PLACING GUNS @ 9,077 TOP AND 10,192' BOTTOM. FILL PIPE AND ANNULUS WITH FLIUD. DROP BAR,WAIT 5 MIN, GUNS FIRED. PERF WELL 9,077'-10,192'WITH 4 5/8" 5 SPF GUNS. OPEN UP TIW.WELL ON SLIGHT VAC. OPEN BACKSIDE, FILL HOLE 18 BBLS. MONITOR WELL. HOLE SLOWED DOWN TO 4 BBLS PER/HR. PULL SLOWLY ABOVE PERFS. R/U AND REVERSE OUT TBG VOLUME. GAS BACK AT SURFACE 300 UNITS. POOH LAYING DOWN 1301TS 3 1/2"TBG TO MAKE ROOM FOR ESP OPERATIONS. FINISH POOH RACKING BACK WORKSTRING IN DERRICK. LAY DOWN 4 5/8" PERF GUNS"NOTE GUNS ALL FIRED". HELD JSA AND SAFETY MEETING WITH CREW AND SUMMIT ON PICKING UP ESP ASSY. 03/09/15-Monday FINISH LAYING DOWN PERF GUNS. BACK LOAD ALL HALIBURTON EQUIPMENT TO WORK BOAT. SPOT SUMMIT REELS IN PLACE. HANG SHEAVES IN DRK. RUN CABLE THROUGH,SPREAD OUT MOTORS AND PUMPS IN ORDER. BEGAN PICKING UP ESP ASSY FILLING WITH OIL AND HOOKING UP CONTROL LINES. TEST SAME,TEST GOOD. BEGAN PICKING UP 3 1/2"SUPER MAX 9.2#L-80 PRODUCTION TBG,STRAPPING ON CAT WALK. DEPTH AT 6 AM 1,650'. 03/10/15-Tuesday CONTIUNE RIH WITH 3 1/2"9.2#L-80 SUPERMAX PRODUCTION TUBING, PLACING CANNON CLAMPS EVERY OTHER JT. STOPPING EVERY 1,000'AND CHECK CONTINUITY. MAKE SPLICE @ 5,323' MEG GOOD.CONTINUE GOING IN HOLE WITH 3 1/2" 9.2#L-80 SUPERMAX PRODUCTION TUBING PLACING CANNON CLAMPS EVERY OTHER JT,TOTAL 261 JTS. PICKING UP HANGER MAKE SPLICE IN CABLE. 03/11/15-Wednesday FINISH MAKING SLICE AND INSTALL PENETRATOR THROUGH HANGER. LAND HANGER. RUN IN HOLE DOWN PINS. PACKOFF AND TEST TO 5000 PSI, GOOD. L/D LANDING JT. REMOVE SHEAVES OUT OF DERRICK. NIPPLE DOWN BOP'S. REMOVE EXTRA SET RAMS. CLEAN HANGER. INSTALL TREE AND WING VALVES. INSTALL FLOW LINE HAVING TO REFAB FLOW LINE. CHECK PRESSURES ON ACCUMULATOR BOTTLES.CLEANED OUT FLUID IN RESERVOIR.ADDED NEW FLUID. PREP RIG TO SKID. HOOKED UP BOTTOM JACKS. REMOVE BEAVER SLIDE AND HAND RAILS. DISCONNECT HOSES. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -2,1z51k, �� 7 DATE: March 21, 2015 l P. I. Supervisor l FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit G-33 • Hilcorp 170-011 Friday, March 20, 2015: I witnessed the verification of No-Flow conditions for Hilcorp's Trading Bay Unit well # G-33 on the Grayling Platform in Cook Inlet. I arrived this morning to find the test equipment rigged up properly and the subject wells Tubing and Inner Annulus in communication and flowing a slight amount of gas to a barrel outside of the wellhead room. Mounted in proper configuration was a 0-30 psi test - gage with 0.2 psi subdivisions and an "Erdco Armor Flo meter" capable of measuring 180-1800 scf methane. Both instruments had current calibration certificates (copies - attached). Lead Operator Zach Rolph performed very well today in making sure everything was rigged correctly and having all pertinent paperwork/documentation ready for me. The following table shows test details: Time (Start Pressures' Flow Rate Remarks 08:30) (psi) Gas - scf/hr Liquid - gal/hr 0:00 0.1/0/14. <180 0 Barely bubbling in barrel 0:15 0.1/0/14 <180/--- - 0 Shut-in Tubing/IA 0:30 0.2/0/14 - ---/600 - 0 Tubing-IA Shut-in/Open well to barrel 0:35 0.1/0/14 - <180 • 0 Barely bubbling in barrel 0:45 0.1/0/14 <180/0 - 0 Barely bubbling in barrel/SI 1:15 0.4/0/14 --- • 0 Tubing-IA Shut-in 1:45 0.5/0/14 ---/1500 0 Tubing-IA Shut-in/Open well to barrel 1:50 0.1/0/14 <180 - 0 Barely bubbling in barrel 2:20 0.1/0/14 <180 - 0 Barely bubbling in barrel 3:00 0.1/0/14 - <180 • 0 Conclude Test 1 Pressures are T/IA/OA Summary: TBU G-33 appears to meet the criteria to be granted "No-Flow" status. Attachments: Test equipment calibration certificates (3) SCANNED )1/IL;, 2015-0320_2015-0320 No-F1ow_TBU_G-33_1g.docx Teck-33 HILCORP CALIBRATION CERTIFICATE Test Equipment"Traceable to NIST 71 Gauge type: 1� t11fx C ' ‘-rEfLSS Pressure range: J 1.D. number: Date: TEST PRESSURE INDICATION - -- C2LA 1 Calibrated by: (7 Test equipment S/N: This certificate expires in 90 days on 3 For recertification, contact Gina Bogart or Cathy Marshall at KGF 776-6825. HilcorpAlaska 3123 Calibration Certificate Technical Information Manfacture: PERMA-CAL Face Diameter: 4" Serial Number: 130405002-01-002 Connection type: BOTTOM Range: 0-300 PSIG Connection Size: 1/2" NPT Test Equipment Traceable to NIST Test Equipment: ASHCROFT DWT Serial Number: 1MA-38647 Calibrated By: Jeff Wright Calibration Date: 3/19/2015 * This certificate expires in 90 days of calibration date Gauge Response Test PSI Rising Falling 0 0 0% 0 75 75 25% 75 150 150 50% 150 225 225 75% 225 300 300 100% 300 Comments: • bCD LI c_5 pct G-33 Akria, , 3z3�5 CERTIFICATE OF CALIBRATION Part Name: Armor-Flo Meter Model Number: 3461-03T0-13 Serial Number: 031189 ERDCO Order#: 7216 Calibration Date: This is to certify that this instrument has been calibrated for the fluid conditions specified on the purchase order and embossed on the nameplate. • Technician Date ERDCCY ERDCO Engineering Corporation 721 Custer Avenue,Evanston,IL 60202-2200 • tel 847 328.0550 • fax 847 328.3535 mail PO Box 6318,Evanston, IL 60204-6318 • email info@erdco.com tiOF T� �w\ 4. THE STATE Alaska Oil and Gas ofALASI(;A Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh Main: 907.279.1433 OFALASY'P Fax. 907.276.7542 www.aogcc.alaska.gov March 24, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit G-33 PTD 1700110 pp Dear Mr. Golis: On March 20, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit G-33 located on the Grayling Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit G-33 prior to the test. The well performance was monitored for three hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit G-33 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Grayling Platform. Sincerely, Ze-Ic James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors 161,06;• Rd) (7c ON c Regg, James B (DOA) From: Harold Soule - (C) <hsoule@hilcorp.com> 116II`, Sent: Sunday, February 15, 2015 12:43 PM Lj' To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, hoebe L (DOA) Subject: Moncla 301, 2-14-15 BOPE Test Report Attachments: Charts 2-14-15.pdf; Moncla 301 2-14-15.xlsx Harold Soule 907-776-6754 • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq(cD,alaska.gov AOGCC.Inspectors aC�alaska.gov phoebe.brooksCa�alaska.gov Contractor: Moncla Rig No• 301 DATE: 2/14/15 Rig Rep.: Jerry Guidry Rig Phone: 776-6754 Operator Hilcorp Op. Phone: 776-6754 Rep.: Harold Soule E-Mail hsoule@hilcorp.com Well Name. TBU G-33 PTD# 1700110 - Sundry# 315-019 - Operation. Drilling: Workover X Explor.: Test. Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 - Annular: 250/2500 • Valves. 250/3000 MASP: 2565 ' MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P . Well Sign P - Upper Kelly 0 NA Housekeeping P - Rig P Lower Kelly 0 NA PTD On Location P • Hazard Sec. NA Ball Type 1 P Standing Order Posted P _ Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P - Annular Preventer 1 13 5/8" P - Pit Level Indicators P P #1 Rams 1 2 718x5"var. P • Flow Indicator P P #2 Rams 1 Blind P - Meth Gas Detector P P ' #3 Rams 1 • 3 1/2" P • H2S Gas Detector P P . #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 • 3 1/8 P - Inside Reel valves 0 NA HCR Valves 2 - 3 1/8 P Kill Line Valves 2 3 1/8 2 1/16 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2950 . P - CHOKE MANIFOLD: Pressure After Closure(psi) 1850 • P Quantity Test Result 200 psi Attained(sec) 34 . P No.Valves 11 • P Full Pressure Attained(sec) 166 • P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 • P - Nitgn. Bottles Avg. (#and psi' 4@2150 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 3.5 ' Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested with 3'/2'test jt. This test follows rolling test procedure approved in sundry 315-019 conducted prior to this test due to hanger leaking on 2-11-15 Tested 250 low,t/3000 high pumping at 10 gpm,testing dual upper 3 1/2 rams. Tested w/3 1/2tj-2 7/8 x 5"variable lower rams&annular no surface leaks. Gas detection system tested on 7-15-1 results rpnnrriprt nn this form AOGCC Inspection 24 hr Notice Yes Date/Time 2/13/2015-15:00 Waived By Bob Noble Test Start Date/Time: 2/14/2015 14:30 (date) (time) Witness Test Finish Date/Time. 2/14/2015 1800 hrs Te5d—Cltc�; ti ctee/ Form 10-424(Revised 06/2014) 2015-0214_BOP_Moncla301_TBU_G-33.xlsx --gu. - 3 (?r) i ioo") c(a 3o1 aperrirsi- _5 - __ /0 - ____-.---------_._;___ z�i4��S • _----`"------ -----___--450p _„_. ___-- - - - 3500 f __ __,----- '7,--_'� --3000 ICS },3 / / -P500 ` , .—fix = rJ -- 2000K,, / _..- / -r -.]500 ,;____L-,--- O 00 � *. .1, • ' 111111% , . h00 2 00 -500 f.' i / 2 • O co, p o p O OO • 00 .� � 000 p0 0 44I*• O J7 O O \� �S \ 66p0 O lai \ • f o /�Q, ,oF ,c)- •�,Ff i or� ai. : 1111 ) l P� 0 `t 0, 4, ti 'V $$>r.' A6, ''-t:S! . .• • ' . i O pp � G0.- nP$ 00 67, O ..:' . :' -V oma 11/0/ .. ,\\.. , 41144111411111111 001 OP. 01 I I I/0 00� %Itiotitioliasii411141.110144188,81 .OOOZ:. 1 11111111.1111 1111.°lig 00 r� OOSZ- 0 • 000'-- 01..00/00/0010,6 ,,, / a , i 052 _ ' • Nisss.......sisi...:........:N.,, ob- ____ _ - Oir S� . - • 60 0 kimak 30t 3ore,--Tecr- . ., OO . . -. , . . . ' 1 - . . hp00 . ------- , D , , . . ' . • . . • . • - . , -„„: • .5$00 . ------.2--..._ . '. . . .---rI ••-- , .,:.----L. , i ---`---... OC•'`,,_, ''''',.., '100 1 r‘t , . • . 1.5000 . • /0 X0 • , • ... ''. 2,..563 00 • . ..-...--,- , . , •, • 1 ,2N L'%6‘0 •.. .. '.. ri 00° 1 e; ., • . ': : ; :: i ---------.A, -----...„..... , . . ' ,/ i ''...., ....,, ''.•,,\C)•. vommr, : :it,' 1000 .•,,, / --.......... k • ... '..r. ;:-.• ,--, .- U) R \ CC) CI 0 CU ' .53 . 8 0#01.0,,,R- to. - - /-----,.. 2. 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L o0 'so 0 . • . ?\.0",' mo:, ------.-- .it _ . 1 - NO MO MP-50 Does-ti"i r \. 5 oo GHP1 rte. �.. o 3,0' 3 I cn '�.. 11111:11' ER S PKEN OFf M o f . o oosioi, 111;�A��eN G o 0 REMPRI Jam'.. 00' p,g S O . / O00 ` , ! .! : 000 )l 111,, • , -4 -. ' ' ' iallil (O. '. '. ' . 40,j r oos�. 002 o • °oma t �2 0 l 0 0 DOOM ppp� \.. N .,,. .,,,„ .., s pp5n - P5 /3 Regg, James B (DOA) From: Harold Soule - (C) <hsoule@hilcorp.com> Sent: Thursday, February 12, 2015 10:06 AM To: Regg, James B (DOA) Subject: Moncla 301, G-33 rolling test charts Attachments: Scan0038.pdf Hello Mr. Regg Here are the charts from the rolling test. Harold Soule 907-776-6754 1 I • , k 301 6oP ._ _._ zi ,.�' ..---- '3500 — 1 1 _,, _----3000 -___ fir' '�" :`"� "•-�.`�� '� / 1.i / t --r j• ` ip'4 \ n // 71'y� -/. -' Ayr's) _�.� / i , •\ +'-� 6,0 q.......-\-\\ \ \ \ \ \ ,/�/ l fl ta , Rolutv 't ' ; , \ / tf G `3 Ts1 k i CHART0 i ef! I UT Gil .,, , , : ' 1'.'I. I I I. -...- ..4, \ ' ''' '') . 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' oa, I ......------<- -\' 2� . } \ ' ` \ ,LVJ C �,� N 4 - :, : ter_ \ : .- —y" - -. rad \\ T r THE STATE � 0 1 a 454p 1041 M164' U01A GOVERNOR BILL WALKER Dan Taylor Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 k -lo- o It Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Re: McArthur River Field, Middle Kenai G and West Foreland Oil Pools, TBU G-33 Sundry Number: 315-019 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 eday of January, 2015 Encl. SCANNED JAN 15 2015' STATE OF ALASKA D-Tt-'\ ALASKA OIL AND GAS CONSERVATION COMMISSION 11)3115 APPLICATION FOR SUNDRY APPROVALS 20 AAQ 95 980 DECEIVED JAN 0 9 2015 00's .111-61 IS /` OGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing Q Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install ESP Ell 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development [] Stratigraphic ❑ Service ❑ 170-011 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20212-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No ❑ y Trading Bay Unit / G-33 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 0018730 McArthur River Field / Middle Kenai G Oil & West Foreland Oil Pools . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MID (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,790 10,240 10,706 - 10,165 N/A 10,664 Casing Length Size MD TVD Burst Collapse Structural 360' 26" 360' 360' Conductor 605' 20" 605' 605' 1,530 psi 520 psi Surface 4,511' 13-3/8" 4,511' 4,448' 3,090 psi 1,540 psi Intermediate Production 10,090' 9-5/8" 10,090' 9,605' 6,330 psi 3,810 psi Liner 792' 7" 10,754' 10,208' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,020' - 10,626' 8,659' - 10,103' 3-1/2" 9.2# / N-80 8,915' & 9,977' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See Schematic See Schematic, 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/18/2015 Oil F • Gas ❑ WDSPL ❑ Suspended ❑ WINJ ElGINJ ElWAG ElAbandoned ElCommission 16. Verbal Approval: Date: Representative: GSTOR ❑ SPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dta for hilcor .com Printed Name Dan .T J Title Operations Engineer Signature _ _ Phone 907 777-8319 Date 1/9/2015 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: 'i�f 3�� Si. �DY es I 1CcS� Z S 6 �jOSv) e -A Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / l Q l APPROVED BY 1 COMMISSIONER THE COMMISSION Date: !— 3 -/j Approved by: /- /z -lS -rA6 * / Form 10-403 10-403 (Revised0/2012) Approved application is 19 R11 flt fate of approval. Submit Form and Attachmg`niin Duplicate Cinr1■■A \Y1 I. Ll • I nn.r Hilcorp Alaska, LL, Well Prognosis Well: G-33 Date: 1/8/2015 Well Name: G-33 API Number: 50-733-20212-00 Current Status: Producer Leg: 3 Estimated Start Date: January 18, 2015 Rig: Moncla 301 Reg. Approval Re 'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 170-011 First Call Engineer: Dan Taylor 907 777-8319 O 907 947-8051 M Second Call Engineer: James Young 907 777-8421 O AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary 3,500 psi @ 9,354ft TVD / 9,800ft MD 3,500 psi @ 9,354ft TVD / 9,800ft MD 2,565 psi 0.37 psi/ft at mid-perf, Based on surrounding well data 0.37 psi/ft at mid -pert, Based on surrounding well data 3,500psi - 9,354ft (TVD) * 0.1 psi/ft Grayling G-33 is a dual string oil producing "G" Zone / West Foreland completion currently on gas lift. G-33 is producing up the long string at 1,400bpd and 160bopd. Both the long and the short string have inner obstructions that hamper production and do not allow for tools to pass. This program outlines the procedure of removing the current dual gas lift completion, adding perforations, and re -completing the well with an ESP. )(-- Procedure: 1. Bleed off well. 2. Identify fluid level. 3. Rig up a -line line on short string. 4. Run in hole and punch tubing above obstruction at +/-6,700ft. a. Rig down a -line. 5. Circulate until clean returns down short string (-337bbls csg capacity) until well is dead. a. Work over fluid will be filtered inlet water unless well conditions dictate heavier brine is required. 6. Nipple down tree and nipple up BOP. —? 5* -It lArt/ s 7. Perform BOP test in accordance with AOGCC regulations. a. Note: Dual 3.5in GL completion and 3.5in work string. b. If back pressure valve will not set with tree on notify AOGCC and refer to attached rolling test procedure. 8. Utilize casing jacks to pick up on long string tubing and unseat upper packer with lower 10ft seal assembly in lower packer. a. Upper Packer: Baker A-5 Dual String Retrievable b. 3.5in N-80 BTC tubing joint and body yield: 207,200lbs c. Total Weight: "��-- '• i. Long String: 91 klbs + 28% friction = 125k1bs ii. Short String: 82klbs + 28% friction = 104klbs iii. Total dry weight: 230kibs iv. Total buoyant: 209klbs v. Packer over pull & seal assembly: —50klbs • vi. Total PU Weight: 260klbs 9. If packer does not work free rig down casing jacks. 10. Pick up on short string hanger. 11. Rig up a -line and run in hole for deepest possible cut on short string +/-6,700ft. a. Run in hole for cut above number 2 GLM at +/-3,150ft. i. Dry weight = 29klbs 12. Pull out of hole with fish. 13. Rig down off of short string. 14. Pick up on long string hanger. 15. Rig up a -line on long string. a. Run in hole for deepest cut possible (+/-2,150ft) provided good fishing neck exists. Hilcorp Alaska, LL Well Prognosis Well: G-33 Date: 1/8/2015 b. Dry weight = 20klbs c. Pull out of hole with fish. 16. Run in hole with fishing assembly to remove obstruction in long string. 17. Run in hole with overshot and engage long string. a. Rig up a -line and run in hole for deepest possible cut though overshot above upper packer +/-8,800ft. b. Run in hole for cut at +/-6,750ft. c. Pull out of hole with long and short string to cuts at +/-6,750ft and +/-6,700ft. 18. Continue making necessary cuts on short and long string while attempting to latch with overshot until upper and lower packer release with overpull. 19. Once upper packer is pulled run in hole with test packer to +/-9,000ft and test 1 500Dsi and chart 30min. K 20. Pick up packer plucker and run in hole. a. Burn over and retrieve lower packer, seal assembly, and mule shoe. 21. Pick up and run in hole with 9-5/8in X lin clean out assembly. a. Clean out to +/-10,650ft 22. Pick u TCP assembly ands ace out over the following intervals: Top MD (ft) Btm. MD (ft) Feet MD (ft) Top TVD (ft) Btm. TVD (ft) I Feet TVD (ft) 9,077 9,091 14 8,711 8,724 13 9,159 9,164 5 8,785 8,789 4 9,196 9,237 41 8,818 8,855 37 9,312 9,360 48 8,922 8,965 43 9,553 9,594 41 9,135 9,172 37 9,603 9,649 46 9,180 9,220 40 10,084 10,088 4 9,611 9,6141 3 10,100 10,110 10 9,625 9,634 9 10,116 10,119 3 9,640 9,642 2 10,127 10,132 5 9,650 9,654 4 10,178 10,180 2 9,696 9,698 2 10,203 10,207 4 9,718 9,722 4 10,220 10,223 3 9,734 1 9,737 3 10,229 10,234 5 9,742 9,747 5 10,241 10,249 8 9,753 9,760 7 10,284 10,289 5 9,792 9,797 5 10,296 10,298 2 9,803 9,805 2 10,376 1 10,4031 27 9,876 9,900 24 10,593 1 10,6091 16 10,073 10,087 14 10,615 1 10,627 1 121 10,093 1 10,104 11 23. Close annular and circulate out gun gas ensuring well is static. 24. Pull out of hole laying down TCP assembly ensuring all shots fired. 25. Pick up and run in hole with completion: a. ESP b. Cable c. Capillary Tubing d. Set ESP Intake at +/-8,930ft MD. 26. Land Hanger and test. 27. Turn well over to production. 28. Complete a surface safety valve test and `no flow' test in compliance with AOGCC regulations. a. See 20 AAC 25.265. Well safety valve systems. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. Current Well Head 4. BOP Stack 5. Rolling Test Procedure 2 tib F/�'w c I I K Hileorp Alaska, LLC �l2 VV RKB to TBG Hngr = 43.70' TD =10790' ,BS31 SCHEMATIC CASING DETAII McArthur River Field, TBU Well: G-33 As Completed: 10/21/1988 SIZE (in) HS (in) WT (It/ft) GRADE CONN TOP (ft) BTM (ft) Cmnt 20 26 94 H-40 8 RIND 43 605 No Rtrns Surf 13.3/8 17.5 61 J-55 BTC 42.6 4511 Rtrns surf; lea @ 999ft; fxed 9.5/8 12.25 47,43.5 P110, N80 BTC,BTC 40.6 10090 2ksxs G. >40% Unbonded>8,900ft. TOC-8,910ft 7 8.5 29 N-80 BTC 9962 10754 200 sxs G. Bump plug. TUBING DETAIL A LS: 3-1/2 - 9.2 N-80 Butt 3173.57' 3997.88' 4778.34' S5:3-1/2 - 9.2 N-80 Butt 8628.11' C 8848.54' LONG STRING JEWELRY DETAIL No. Depth Item 1 328.41' Otis Ball Valve Nipple 2 2178.48' Camco K -bug GLM's 3284.77' 4139.26' 4882.61' 5562.95' 6151.78' 6794.07' 7442.93' 8097.55' 8748.17' 3 8816.82' Otis "XA" Sliding Sleeve 4, 0 8883.59' Baker Model A-5 Dual Packer i.{ 9015.69'- 9463.75' Baker Blast Joints f- S 9892.56' Otis "XA" Sliding Sleeve iT L 9929.66' Baker Perm Packer w/ No -Go Locator ,s 7 9946.73' Otis "X" Nipple R Q 9977.24' Bottom of Mule Shoe Collar SHORT STRING JEWELRY DETAIL A 297.46' Otis Ball Valve Nipple B 2096.79' Camco K -bug GLM's CAI -C, 3173.57' 3997.88' 4778.34' 5397.16' 6019.82' 6701.00' 7322.94' 7975.28' 8628.11' C 8848.54' Otis "XA" Sliding Sleeve D 8883.59' Baker Model A-5 Dual Packer E 8914.02' Otis 3-1/2" "XN" Nipple F 8916.06' Bottom of Mule Shoe Collar PERFORATION DETAIL Top Btm Date Zone 10086' 10092' 12/24/1987 ✓ West Foreland Production 10105' 10132' 10203' 10286' 10376' 10475' 10512' 10544' 10593' 10626' 9020' 9050' 12/25/1987 "G" Zone Production 9070' 9094' 9132' 9164' 9169' 9250' 9294' 9370' 9412' 9440' McArthur River Field, Proposed TBU Well: G-33 Hileorp .4ta.ka. ILLC "G" Zone W.F. Zone RKB to TBG Hngr = 43.70' TD=10,790ft CASING DETAIL SIZE (in) HS (in) WT (#/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) Cmnt 20 26 94 H-40 8 RND 18.936 43 605 No Rtrns Surf 13.3/8 17.5 61 3-55 BTC 12.515 43 4,511 Rtrns srf; fix leak @ 999ft 9.5/8 12.25 47,43.5 P110, N80 BTC 8.681 8.625 41 10,090 > 2ksx G. 40%Unbnd >8,900ft. TOC:8,910ft 7 8.5 29 N-80 BTC 6.059 9,962 10,754 200 sxs G. Bump plug. TUBING DETAIL 3.5 - 9.2 L-80 Supermax 1 2.867 1 43 Tubing Detail No. Depth (ft) Item 1 43 Hanger 2 8,883 ESP PO t .4 /V(e C001141141,y 10di Vi 4,74a r"`' _ " 7 �y co �23Y1� PERFORATION DETAIL Top (ft) Btm (ft) Date Zone 9,020 9,050 12/1987 "G" Zone 9,070 9,094 12/1987 "G" Zone 9,077 9,091 Future G-2 9,132 9,164 12/1987 "G" Zone 9,159 9,164 Future G-3 9,169 9,250 12/1987 "G" Zone 9,196 9,237 Future G-4 9,294 9,370 12/1987 "G" Zone 9,312 9,360 Future G-5 9,412 9,440 12/1987 "G" Zone 9,553 9,594 Future HK -2 9,603 9,649 Future HK -2 10,084 10,088 Future WF -1 10,086 10,092 12/1987 West Foreland 10,100 10,110 Future WF-, 10,105 10,132 12/1987 West Foreland 10,116 10,119 Future WF -2 10,127 10,132 Future WF -2 10,178 10,180 Future WF -3 10,203 10,286 12/1987 West Foreland 10,203 10,207 Future WF -3 10,220 10,223 Future WF -3 10,229 10,234 Future WF -3 10,241 10,249 Future WF -3 10,284 10,289 Future WF -3 10,296 10,298 Future WF -3 10,376 10,475 12/1987 West Foreland 10,376 10,403 Future WF -4 10,512 10,544 12/1987 West Foreland 10,5931 10,626 12/1987 West Foreland 10,5931 10,609 Future WF -7 10,615 10,627 Future WF -7 PO t .4 /V(e C001141141,y 10di Vi 4,74a r"`' _ " 7 �y co �23Y1� Grayling G-33 133/8X95/8X31/2X 31/2 Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X -bottom prep, R seal installed in head Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW w/ 2- 2 1/16 5M SSO, CA slips in head Grayling Platform G-33 Current 10/28/2014 Tubing hanger, dual, CIW- DCB, 11 5M X 3 Y2 EUE 8rd lift X 3 Y. IBT bottom, w/ 3" type H BPV profile, 1/8 non cont control line ports in hangers Tree assy, dual block, CIW-F, 11 5M X 3 1/8 5M X 3 1/8 5M, prepped on 5 3/64 center, 3" CIW seal pockets, %: npt control line exits Valve, CIW-F, 2 1/16 5M FE, HWO, AA Valve, CIW-F, 2 1/16 3M FE, HWO, AA trim Rilrnrp ,Ilssrkn. JJA; Grayling Platform G-33 133/8X95/8X31/2 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Tubing head, CIW-DCB 135/83MX115M,w, 2- 2 1/16 5M SSO, X bottom Casing head, CIW-WF, 13 5/8 3M x 13 3/8 SOW 2- 2 1/16 5M SSO, CA slip, head BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union Grayling Platform G-33 Proposed ESP 10/28/2014 Tubing hanger, CIW-DCB-ESP, 11 X 3 Y/ EUE lift and susp, w/ 3" type H BPV profile, 5 X EN, 2- 3/8 continuous control line ports, prepped for BIW penetrator Valve, WKM-M, 3 1/8 5M FE, w/ MA -16 operator oadstool, 11 5M FE, prepped for '/2 npt continuous ine ports WKM-M, 2 1/16 5M FE, HWO, DD Qty 2 IW -F, 2 1/16 3M FE, WO, AA trim Grayling Platform BOP Stack (Moncla 301) x 3-1/2 X 3-1/2 Hileorp Alaska, LLC Attachment #1 Moncla 301 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. Contact Mr. Guy Schwartz and Mr. Jim Regg with the AOGCC prior to rolling test. AOGCC may elect to send inspector. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) Hileorp Alaska, LLC Moncla 301 BOP Test Procedure Attachment #1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 12, 2015 2:05 PM To: 'Daniel Taylor' Subject: RE: G-33 RWO (PTD 170-0110 Thanks... makes sense. The way the procedure read it looked like you were only latching the long string to pull packer loose. You need to be pulling on both strings as per below. 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 rmailto:dtaylor@hilcorp.com] Sent: Monday, January 12, 2015 1:02 PM To: Schwartz, Guy L (DOA) Subject: RE: G-33 RWO (PTD 170-0110 Guy, Please see answers to your questions below sir. Thank you. Regards, Daniel Taylor Operations Engineer Hilcorp Alaska, LLC. O: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L (DOA)[mailto:guy.schwartzcd)alaska.gov] Sent: Monday, January 12, 2015 11:54 AM To: Daniel Taylor Subject: G-33 RWO (PTD 170-0110 Dan, Couple of questions: 1. What are the nature of the obstructions in both of the tubing strings.? Long String: 2-1/8in 21ft damaged strip guns with charges. Stuck in 1995 at 2,151ft. Wireline in well in July of 2014 and recovered metal and charges new TOF at 2,250ft. Short String: 2.5in scratcher stuck in hole in 1994 at 6,700ft. 2. In step 5 are you planning on circulating or bullheading into the Long string too? Once the gas is shut off to the long string fluid level is expected to drop to +/-2000ft. We will fill the tubing and monitor loss rate. Once static fluid level is observed we will proceed. 3. In step 8 are you planning on using casing jacks.. how exactly are you latched into the long string with these? We will pick up on both sides of the split hanger with two landing joints. The casing jacks have upper and lower slips. The upper slips will pick up while lower slips hold the pipe for the next bite. Is jack flange mounted? It is flange mounted on top of the BOP. 4. What is your max pull limit ? ^200klbs. The casing jacks are only an option for working the pipe at 180-200klbs. This will relieve the DW of strain. Our preferred method of removing the current completion is staggering our tubing cuts from long to short string until we reach the upper packer. 5. What type of pipe are you using for a work string? We will be using 3.5in P110 with PH6 connections. 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 (Guv.schwartz@alaska.gov). XHVZE Image~oject Well History File Cover PO ! This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing RESCAN [] [] [] [] Other: NOTES: Color items: Grayscale items: Poor Quality Originals: BY: BEVERLY ROBIN DIGITAL DATA [] Diskettes, No. o Other, No/Type VINCENT SHERYL MARI~WI'ND~ Project proofing BY: BEVERLY ROBIN VINCENT SHERYL'~WINDY Scaqning Preparation c~ x30= (~)(,~ + BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: OVERSIZED (Scannable) [] Maps: ' Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [3 Other DATE:{-"( ~.~ ~.~IsI ~-. III IIIIIIIIIII II III I0 = TOTAL PAGES---'~ b PAGE COU.T MATC.ES .UMBE. ,. SCA..,"G PREPARAT,O.: YES BEVERLY~ VINCENT SHERYL MARIA WINDY DATE:)~/7-~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: NO BY: BEVERLY ROBIN VINCEN~ARIA WINDY DATE:/ '/' ~.~/ ~ IS REQUIRED ON AN INDIVIDUAL PAGE BASIS ///?/0 ? I RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is/ Quality Checked 12~?102Rev3NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~' ~a ~i~/ FILE # ~- ~~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~-333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 kFax (907) 276-7542 Facility No Flows Regg, James B (DOA) Page 1 of 1 From: Johnson, Wayne E [johnsonw@chevron.com] ~ Sent: Friday, February 06, 2009 3:11 PM `Q~ I To: Regg, James B (DOA) Cc: Santiago, Johnny T; Greenstein, Larry P; Bartolowits, Paul D; Lovett, Juanita L Subject: Facility No Flows Attachments: G-33 8-95.doc; A-22dwg comp11-9-79.DOC; G-1Schm9-17-97.doc; G-31Schm9-10-89.doc; G-32 Schematic 5-13-08.DOC ,, «G-33 8-95.doc» «A-22dwg comp11-9-79.DOC» «G-1Schm9-17-97.doc» «G-31Schm9-10-89.doc» «G-32 Schematic 5-13-08.DOC» ~ Jim, Here is your well schematics. '~A-22s: Shut In ~ STD I ~ b ~: 3 /A-22L: No flow on May 27, 2004 +~1s: Shutln ~rn I`t(- i3`~ ~G-1 L: No flow May 27, 2004 ~G-31 s: No flow November 23, 200 P~ i'(~q _ U2 Z „.6l~31 L: Shut In 'c~-32: No flow April 21, 2003 ---~ P~ ~~~f - ~~ -33s: Shut In ~ IZC~-> oi( -33L: No flow November 23, 2004 '~i ~ ~i~.~ Wayne E. Johnson Operations Supervisor MidContinent/Alaska Business Unit Chevron North America Exploration and Production Grayling 907-776-6632 King Salmon 907-776-6692 Monopod 907-776-6672 Mobile 907-398-9942 2/6/2009 ~ • 1 r r « ; , I 111 2 ~: -y ~ ` S 1~1 7 3V ~11 X12 ~~~ rrr.rr ~: f~` ~ +~ i~ 1~,. L Vi ~~'... - L'i ~~l ~ ~ ~ 2v~~~ ~ ,,~ . t C~SI~ZG & >~3AhJQN},~~i~T D~TIL 1. Landed below zero `; '~-T-'~'-r-^-""'^- 1(. Cameron Dua! Tubing fianoer Q 44.70' '? ~,'''~) ~ ~ !?:. 20" 94~ h-40 Cosinc O 805' 1 i'''"1 A t~'. .3-4/E" 81ii J-55 casing O 4511' \,t,; V. Tap 7^` 29~ N--B0 Liner O 9962' \~ ;.,i.1 ~"~' $ V!. 9-5j8" 44.5 8t 47~ N-80 do P-110 Q 10090` .. VIl. Bottom of T 29 f 80 Liner O 101,754' ~`~ c TUB;~'G D~7>~lL c:~ D LONG SING: 3- i~2" 9.2~' N--$G1 Bu~~. ~~!A!v^ "~ 1. Otis Batl Vofve Nipple O 428.41' G..u, E 2-11 Cameo K-bug GL#J,'s e: 2)?178.48' 3)3284,77' ~~ G:JJ ~ ~ 4}4139.26' 5)4882.61' 6)5562.95' 7)6151.7E' s :a.! ~'"~ acj678~.07' 9)7~-42.93` 10)8097.55' 11)8748.1T ~:.-~ ~ ~ - i Z. ~s "X~" Sliding Siaeve +8 8816.82' ;~ I~r k: ~ ;,~ ; 4, $oker Model ~°5 Dual Packer O 8883.59` r "~ G_J~A ~ ~ ~ 14. baker 81aet Jointr From 9095.89' tp 9463.?S' G:~l ~ 15: Otis "):1," Sliding Sie~ave Q 9892.56' "'~'' I 9 E. 5aker Farm Focker WjNo-^vo Locator !~ 9929.66' G.fM1 '17 Otis "X" Nip !e ,Q[m99,4~6.73` 4 i,.ld ~„.. ~ 4F " 18 `bottom fat, ~ , le 5i90~e Collar O 9917.24' F f ;a.ws ~~ ~ SH©f?T S73?ING:.i--- 7r2" 9.2~' N--80 Buft. TU3/NG A. Otis fiotl VnMe Kpple O 297.48` ~ , ~ ~` ~' 6°K Cameo K-nug GUJ's ii $)2fj9b.79' 0)4174..5?' f ~, ~ },1, D)3997.86' E~4778.34' x')5397.1 s' G)8019.82' l 1 xh ~, ~ N)f7al.aa' 1)7322.94' ~797:.ze' K}ss~8.11' `-'-'~ 0 L. Otis "X~." Sliding Sleeve O 6848.54' # ~ 4 ~ -!. bokar Model ~-5 Duol Docker Q 8683.59' ~ 1 N. Otis 3-1 j2" "XN" Nipple +ii 6914.02' _ _- ., ~ '15 ~ 0. Battam o` Mule Shoe Collor ~ 8916.03' _ ~,, ~~Rr 0R1~;710~ R~CQr2Q _; _,- 'J~~~ It~i-R1/r! C£1N~e?lJ' N F x 17 ~ , 1 oass-1 Doss - _ - ~ ~ ~ ~ a~ , ~ ~ r ~ t 70105-10132 10203-10?86 ~ - ,r .. t , . t , , d _ ~ ~ F . 1$ 10376-10475 ~~w~ FOR~h~ ;2j24j67 70512 10544 PR0DL-CTIat1 t3~_r ,~ 1as9~-10s2s ~: _ - ~_ 9o2o-saso - r n~~f T` _ 9G70,-~J094 ~0t~" 12j?.5jE7 ~ 9132~91~64 ' ~t~0~U~T1~fk ~ d 4E'16c-9..5~~ , o2ca947G ~. 9412-9440 r(- .._ ._ ;~ ~ r .. ... t Drown: 10 f 21 /88 B/.W %' ~ Page 1 of 1 Regg, James B (DOA) __ From: Regg, James B (DOA) Sent: Friday, February 06, 2009 8:50 AM ' l~G~ Z'~~~ U~ ~/ To: 'myersc@chevron.com' Cc: Fleckenstein, Robert J (DOA) Subject: No Flow Determinations We've just completed an update/review of AOGCC "no flow wells" database and found a few dual completions that are not clear if the no flow determinations were on long string or short string. Wells in question are: > Trading Bay State (Monopod) A-22; PTD 170-031 > Trading Bay Unit (Grayling) G-01 RD; PTD 191-139 > Trading Bay Unit (Grayling) G-31; PTD 169-072 > Trading Bay Unit (Grayling) G-32; PTD 169-086 > Trading Bay Unit (Grayling) G-33; PTD 170-011 I would appreciate it if you could provide: 1) current well schematic for the listed wells; 2) current status of the LS and SS completions; 3) Union's understanding of which string the no flow determination applies to and why. Call if you have any questions about this request. Thank you in advance. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 2/6/2009 l' ') ~~!Æ~! :F fÆ~~~~~!Æ A.I,A.SKA. OIL AlVD.GAS CONSERVATION COMMISSION December 10, 2004 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: Safety Valve System Inspections No Flow Tests Trading Bay Unit, Grayling Platform Dear Mr. Johnson: ) FRANK H. MURKOWSKI, GOVERNOR ~!~()ft~:j()f.f 333 W. TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 On November 23, 2004 the Alaska Oil and Gas Conservation Commission ("AOGCC") inspectedUnocal's Grayling platform, Trading Bay Unit. The Commission's inspection included witnessing semi-annual safety valve system ("SVS") tests, no-flow tests on four. wells, and general platform safety inspections. The platform was found to be clean, orderly, and in good condition. The SVS associated with thirteen of the platform's wells were tested. Eleven wells were not tested during the November 23 inspection - four wells were shut in for no-flow testing, two wells were not tested at the request of the platform supervisorl, and five wells were not tested due to their "long term shut in" status. Unocal must provide a schedule for completing the semi-annual testing of the six wells2 that would normally be in operation, and provide the Commission with sufficient notice when SVS testing will be conducted so these tests can be witnessed. The Grayling platform production wells utilize artificial lift gas to produce hydrocarbons. It is unclear if a catastrophic failure of a well or flowline component will automatically shutdown artificial lift gas, or if the well will flow for several hours until it depressures. Unocal is requested to provide an explanation and relevant supporting flow schematics with sufficient detail to demonstrate the emergency shutdown system and its control over the artificial lift gas. 1 TBU G-14 (PTD 168-080) and TBU G-18DPN (pTD 183-135); reason for not testing was concern about disrupting the platform's fuel gas supply 2 TBU G-12 RD3, G-14, G-18DPN, G-21, G-31, and G-33 SCANNED DEC 1 4 20D4 ) ) Dwight Johnson December 9, 2004 Page 2 of2 We also note that safety valve system test results at Grayling are not routinely provided to the Commission. Unocal should begin reporting all safety valve system tests to the Commission, particularly those tests that are not witnessed by a Commission inspector. Please contact Mr. Bob Fleckenstein at 793-1242 to get the proper reporting format. No Flow Tests Wells G-12RD3, G-21, G-31, and G-33 were no-flow tested on November 23 to determine if they qualify for removal of the subsurface safety valve. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored for 3 hours. Gas flow rates less than 180 SCF per hour, and total liquid recovery less than Y2 gallon during the 3-hour monitoring period were determined for each well tested. Based on the results of no flow tests, the subsurface safety valve may be removed from service in Wells G-12RD3, G-21, G-31, and G-33. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be . maintained in proper working condition in each well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, S~~~ JmnesB.Regg ~ Petroleum Inspection Supervisor cc: Bob Fleckenstein File: TBU G-12RD3 (PTD 202-055) TBU G-21RD (pTD 198-064) TBU G-31 (pTD 169-072) TBU G-33 (PTD 170-011) ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ç A ~ P.I. Supervisor rV1Q FROM: Jeff Jones Petroleum Inspector \Z,} 3\ Obr DATE: November 23, 2004 SUBJECT: No-Flow Test Unocall Grayling PL T G-33 S/L PTD 1700110 McArthur River Fieldl TBU November 23, 2004: I traveled to the Grayling Platform in Cook Inlet to witness a No-Flow Test on Unocal's McArthur River Field well G-33 S/L. Unocal representative Darrel Bruce performed the test today in a safe and proficient manner. Well G-33 S/L was lined up from the production tubing through a 1" hose terminating in an open top drum. Gas flow from this well was such that it was below the amount measurable (180 SCFH) with the Armor-flow model 3461-03TO flow meter usually used for No-Flow Tests. This well utilizes artificial lift gas to produce hydrocarbons, which was shut in at least 12 hours previous to the test, and the well was allowed to depressure into the test separator. This artificial lift gas may not be automatically shut off in the event of a catastrophic failure of well head or flow line components, depending on the nature of the failure. In the event of such a failure, it may be necessary to block in the lift gas manually, and in any case the well may flow for several hours unassisted until it depressures. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the well during the test did not exceed the maximum permissible 900 SCF hourly flow rate and no significant amount of fluid was produced. ' Summary: I witnessed a successful No-Flow Test on Unocal's McArthur River Field well G-33 S/L on the Grayling Platform in Cook Inlet. Attachments: none ÇÇ¡ Dwight Johnson I J.C. Watski (Unocal) . . " . - " -. . Well No-Flow Test Dåtà; . ~ '-.: "'~\~\~Ei,{', ~~; ;: '. . . - Unocal Darrell Bruce Jeff Jones MRFffBU Gra lin PLT Date 11/23/2004 11:45 AM 12:15 PM 12:45 PM 1: 15 PM 1:45 PM 2: 15 PM 2:45 PM Gas <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH <180 SCFH Liquid < 1 cup <1 cup <1 cup <1 cup <1 cup < 1 cup <1 cup Start Test End Test Produced to open top container. T otalliquid produced: < 1/2 gallon SCANNED DEC 1 4 2004 RJF 09/19/02 Page 1 of 1 NO-FLOW Grayling PLT G-33 S-L 11-23-04 JJ.xls ~KA OIL AND GAS CONSERVATION REPO OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing __ Alter casing__ Repair well __ Pull tubing __ OtherX 2. Name of Operator 5. Type of Well: 6. Datum elevalion (DF or KB) Development X UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory __ RT 103' MSL feet 3. Address Stratigraphic __ 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 se~ TRADING BAY UNIT 4. Location of well at surface Leg #3, Conductor #11 8. Well number 1409' W & 1806' N f/SE Corner, Sec. 29, TDN, R13W, SM G-33 At top of productive interval 9. Per_mit number/~pproval number 2004' E & 146' S, f/Surface Location '7~" At effective depth 10. APl number 2654' E & 496' S f/Surface Location 50-733-20212-0 At total depth 11. Field/Pool 2683' E & 516' S f/Surface Location MCARTHUR RIVER FIELD 12. Present well condition summary Total depth: measured 10790' feet Plugs (measured) true vertical 10241' feet Effective depth: measured 10706' feet Junk (measured) 10664' true vertical ~. 10165' feet f. Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" Driven 360' 360' Conductor ~" 605' 20" 2215 sx 605' 605' Surface 4511' 13-3/8" 2650 sx 4511' 4448' Intermediate Production 10090' 9-5/8" 2000 sx 10090' 9605' Liner 792' 7" 200 sx 9962'- 10754' 9489'- 10208' Perforation depth: measUred See attachment ~ true vertical Tubing (size, grade, and measured depth) SS: 3-1/2", 9.2#, N-80 LS: 3-1/2", 9.2#, N-80 Packers and SSSV (type and measured depth) Baker perm, PKR @ 9930', Baker A-5 dual PKR @ 8.884, Otis 3-1/2" ball valve @ 328' & 297' 13. Stimulation or cement squeeze summaryR E ¢ E IV E D intervals treated (measured) N/A , FEB 2 4 ]995 Treatment description including volumes used and final pressure N/A Alaska 0il & Gas Cons. Commission , 14. i Representative Daily Average ProdUction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation N/A 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X_ Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the fo~a~goi~g is~t ~lJe/~r){:l co, r~t to the best of my knowledge. Signed G. Russell Schmidt .J~_,l~,k~W~;~,~v~ Title Drilling Manager Date 1/11/95 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE APl 50-733-20212-0Q Grayling Platform Leg 2, Conductor 11 Trading Boy Unit McArthur River Field LONG STRING ,~ RKB Elev. 103 FT. lb~,,~.od Flcl Depth 4-3.70 Ft. Mid-Peri Deviation 28 Deg. 681.7 - 8476.7' 9.625" OD 8.681" ID 47.~/fl N-80 PROD CSG 16.7-10090.0' 9.625" OD 8.681" ID 47.00t/ft P-110 PROD CS(; 10221.0-10286.0' PERFS ~/F-3 1/9/95 10,376.0-I0:~9~.0' PERFS ~/F-5 ]/9/95 10407.0-10475.0' PERFS ~IF-5 1/9/95 10512.0-10544.0' PERF$ WF-6 1/9/95 10593.0-10626.0' PERFS ~F-7 1/9/95 10664.0-10705.7' FiLL 1/7/95 GTCO fill~ 10664 WLM 9962,4 - 10754.1' 7,00" OD 29.~ff/ft N-80 LINER KB ELL¥: 103' PBTD: 10706' TD: 10790' 4,~.7 - 8915.,Y 3.5" OD 2.88" ID TBG SHORT STRNG 9070.0 91,],2.0 9196.0 9294.0 9416.0 888,~.6 - 8890.8' RETRY. PACKER Baker Mod. A-5 Dual Pie 43.7 - 9946.7' ~.50" OD 2.992" ID 9.20J/fi N-80 TBG LONG S'I'RIN(; 9020.0-9050.(~ PERFS (;-1, Prod, 4HPF, ,~/17/70, 12/25/87 -9094fl PERB (;-2, Prod, 4HPF, 3/17/70, 1)_/25/87 -9164.0' PERFS g-3, Prod, 4HPF, 3/ff/70, 12/25/87 -0250.0' PERFS (;-4, Pro(I, 4HPF, ,3/17/70, 12/25/87 -95623 PERFS G-5, Prod, 4HPF, ,~/17/70, 12/25/87 -94~4.0' PERFS (;-6, Pr~, 4HFT', 5/17/70, 12/25/87 9946,7 - 9948,0' LANDING NIPPLE Otis ,b 1/2" 9929.7- 99,],,].7' PACKER Baker 9 5/8" Perm. Pkr 9946.7 - 9976.5' ,!,.50" OD 2.992" ID N-80 'IBC LONG STRING 10086.0 - 10091.0' PERFS ~-2, Prod, 4HPF, 1 11/16" Pivot (;un, 1970, 87, gl, 10105.0 - 101:~2.0' PERFS WF-2, Prod., 4HPF, 1 11/1¢ Pivot (;un, 1970,87,91, 10203.0 - 10286.0' PERFS WF-3, Prod,, 4HPF, 1970, 87, 1/,30/91 10376.0 - 10475.0' PERFS WF-5, Prod., 4HPF, 1970, 87, 1/,30/91 10512.0-10544.0' PERFS WF-5, 4HPF, 1970, 1987, 1/80/91 1059~.0 - 10625.0' PERFS WF-7, Prod, 4HPF, 1970, 1987,1/30/91 JOil We l J RECEIVED FEB 2 4 1995 Alaska Oil & Gas Cons. Commission Anchora ,~ APl ,50-72;~-20212-00 Grayling Platform Leg 2, ConducEor 11 45.0- ~60,0' 26.00" OD 1" ~/all CSC; 42,6- 605.1' 20.00" OD 94,00t/ff H-~ CSG / / J 4.2.6-4511,4' 1,].375" OD 12,415" ID 61.00t/fi J-55 SURF C:SG 4-0,6 - 6681,? 9.625" OD 8.715" ID 43.50t/fl N-80 PROD CSG 681,7 - 8476,7' 9.625" OD 8.681" ID 47.00t/fl N-80 PROD CSG f6,7-10090.0' 9.625" OD 8.681" ID 47.00~/f[ P-110 PROD CSG 10664.0- 10705.7' FLL 1/7/95 C]'CO ri ~ ]0664 WLM 9962,4- 10754,1' 7,00" OD 29.OOt/ft N-80 LINER 'l-r~din9 Bay Unit Mckthur River Field LONG STRING KB ELD/: 103' PB'rD: 10706' TD: 10790' LL ~. RKB Elev. 105 FT. Tb~-,,ec]d Fig Del)th 63.70 Ft. Mid-Peri: Devia[ion 28 Deg. 2151.0- 2161.0' GUN FISH 2-1/§II ENERJET S1R1P 43.7 - 8915.~' 3.5II OD 2.88" ID TBG SHORT STRING 43.7- 991.6.? b.50" OD 2,992" ID 9.20t/f[ N-80 'rBG LONG STRING 8883.6 - 8890.8' RErRV. PACKER Baker Mc, d. A-5 Dual Pkr 888,~.6 - 8890.8' RETRV, PACKER Baker Mod. A-5 Dual Pkr 9946.7- 9948.0' LANDNG NIPPLE OLisb 1/2" 9946.7 - 9976.5' ,3.50" OD 2,992" ID N-80 ~ LONG STRING 9929.7- 9963.7' PACKER Baker 9 5/8" Perm, Pkr RECEIVED FEB 2 4 1995 Well Anchora: ?, G-33 UNOCAL DAY 1 (12/30/94) 9-5/8" @ 10,090' 7" @ 9962'-10,754' TBG TAIL @ 9977' RIG UP ON G.33 LONG. FUNCTION TEST RAM & TEST TO 3000 PSI (OK). RIH W/1.5" WASH NOZZLE & DUAL CHECK VALVES & STRAIGHT BAR & CRIMP CONNECT. CIRC FIW @ .25 BPM TO 5000'. BLEW DOWN COIL CLOSE PIPE RAMS & SLIPS SHUT DOWN FOR NIGHT. DAY 2 (12/31/94) 9-5/8' @ 10,090' 7" @ 9962'-10,754' TBG TAIL @ 9977' UNLOCK RAMS. RIH CIRC. FIW TO TBG TAIL. START PUMPING N2. TAG @ 10188' (HARD). POOH W/NOZZEL. RIH W/2-1/4" MILL & 2-1/8" MOTOR. SURFACE TEST MTR (OK). TEST LUB TO 3000 PSI (OK). RIH TO 9000'. SHUT DOWN FOR THE NIGHT. DAY 3 (01/03/95) 9-5/8" @ 10,090' 7" @ 9962'-10,754' TBG TAIL @ 9977' ACCEPT C.T.U. 12/30/94 @ 06:00. RIH W/2.25" BIT & 2-1/8' MTR. PUMP FIW. WASH DWN TO 10,521'. BEGIN PUMPING FIW & N2. UNABLE TO CLEANOUT PAST 10,521'. POOH. LEFT MILL, MOTOR, BAKER DISCONNECT IN HOLE. RIH W/2.725" OVERSHOT ON BRAIDED WIRELINE. RECOVERED MOTOR FISH W/BRAIDED LINE. RU 1/2" COIL TUBING. RIH W/2.7" BIT ON MUD MOTOR. TAGGED AT 10521'. CLEAN OUT WITH MOTOR TO 10,530'. PLATFORM HAVING PROBLEMS SUPPLYING GAS LIFT TO WELL. POOH TO 9998'. SECURE WELL FOR NIGHT. RECEIVED FEB 2 4 1995 Aiaska Ojj & Gas Cons. Commission Anchor~ : ~ DAY 4 (01/04/95) 9-5/8" @ 10,090' 7" @ 9962'-10,754' TBG TAIL @ 9977' RIH W/COIL TBG AND CLEANED-OUT W/MOTOR 10,521'-10,636' - ENCOUNTERING SUSPECTED PERFORATING DEBRIS. INJECT N2 & FIW AND CIRCULATE CLEAN. POH. R/U SLICKLINE &RAN 2.5" GAUGE RING AND 2" SINKER BAR AND TAGGED AT 10,664' WLM. RIGGED DOWN VVIRELINE. RELEASE C.T.U. 1/4/95 @ 16:00 HRS. RECEIVED FEB 2 4 1995 A~ska Oil & Gas Cons. Commission Anchor~':~ G-33 Long String Perforations Existing Perfs: 10,086'- 10,091' WF2 10,105' - 10,132' W-F2 Perforated 1/9/95: 10,221'-10,286' WF3 10,376'- 10,394' WF5 10,407'- 10,475' WF5 10,512'- 10,544' WF6 10,593'- 10,626' WF7 RECEIVED FEB 2 4 1995 Aiaska Oil & Gas Cons. Commission G-33 UNOCAL DAY 1-3 (1/29-31/95) 1/29 TRAVEL TO GRAYLING UNLOAD BOAT 1/30 RU DOWELL 1.75" C.T. TEST BOP TO 3000 PSI. PERFORM PULL TEST TO 16,000# (OK). TEST PIPE RAMS (NO TEST). PIPE & SLIP RAMS CLOSED ON TBG CONNECTOR. REDO PULL TEST (OK). PU 2-3/8" MOTOR & 2-11/16" WASHPIPE. ATTEMPT TO WASHOVER FISH. CANNOT PASS 2144'. POOH. RECOVERED6" PIECE. SHUT DOWN FOR NIGHT. CIRC. FIW FOR FREEZE PROTECTION. 1/31 MU 2-3/8" MTR & 2-11/10" WASHPIPE. TEST LUB TO 3000 PSI, (OK). RIH CIRC .57 BPM FIW. WASHOVER FISH @ 2153.5'. STALLED MTR (MADE SEVERAL ATTEMPTS). KEPT STALLING (~ 2153.5'. FLAG PIPE. POOH. NO RECOVERY. RIH W/SAME BHA. ~ TAG @ 2148,6' & FLAGGED PIPE. MADE SEVERAL ATTEMPTS TO WASHOVER. POOH. RU BRAIDED LINE. RIH W/2-5/16" O-SHOT W/1-9/16" SPIRAL GRAPPLE. TAG @ 2151' (WLM), CATCH FISH WORK O-SHOT. POOH SOME MARKS ON OUTSIDE OF O-SHOT. MU 2.25 I.B. RIH TAG @ 2151'. POOH LOOKS LIKE FISH IS OFF TO SIDE. PROBABLY IN BELLY OF GLM. MU KICK-OVER TOOL W/2-5/16" O- SHOT. RIH @ 06:00 HRS. ~s~ O~t & Gss C~o~s. ~omm'~ss'to~ STATE OF ALASKA ' · ALASK/~m,~IL AND GAS CONSERVATION CO~MISSION · APPLIC/I ION FOR SUNDRY AR,ROVALS 1. Type of request: Abandon __ Suspend __ Operatlons shutdown __ Re-enter suspended Well__ Alter casing__ Repair well Plugging __ Time extension Stimulate Change approved program __ Pull tubing __ Vadance ~ Perforate X_ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Oevek)pment X_ KB: 103' ~o~y . . feet 3. Address S~.gaphb ~ 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 sense __ Trading Bay Unit 4. Location of well at surface Leg #3, Conductor #11 8. Well number 1409' W and 1806' N fr. SE cor., Sec 29, T9N, R13W, SMI ECEIVED At top of productive Interval 9. Permit number',-)'~ 2004' E and 146' S fr. Surface Location S EP 2 3 1994 7-791 At effective depth 10. APl number 2654' E and 496' S fr, Surface Location Alaska 0il & Gas Cons. Commission 50-733-20212-00 At total depth Anch0ra~e 11. Field/Pool 2683' E and 516' S fr, Surface Location McArthur River/G, West Forelands 12, Present well condition summary Total depth: measured 10790 feet Plugs (measured) true vertical 10241 feet i,,i true vertical 10165 feet Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26' Driven 360' 360' Conductor 605' 20" 2215 sx 605' 605' Surface 4511' 13 3/8' 2650 sx 4511' 4448' Intermediate Production 10090' 9 5/8' 2000 sx 10090' 9605' Uner 792' 7' 200 sx 9962'- 10754' 9489'- 10208' Perforation depth: measured See Attached true vertical Tubing (size, grade, and measured depth) SS: 3 1/2', 9.2#, N-80 LS: 3 1/2', 9.2#, N-80 Packers and SSSV (type and measured depth) Baker 9 5/8' perm. packer @ 9930', Baker 9 5/8' A-5 dual packer @ 8884', Otis 3 1/2' ball valve nipple @ 328' and 297' ....... , 13. Attachments Description summary of proposal ~ Detailed operations prograrn~__ BOP sketch ~ Questions? Call Hal Martin @ 263-7675 or Ralph Holman (~ 263-7838 i4. Estimated date for commencing operation 15. Status of well classification as: October 26, 1994 16. If proposal was verbally approved Oil X_ Gas __ Suspended __ Name of approver Date approved Service i7. i herebY/e~ rtify t,l:~t the fo, r4~!;lRing~is/t/ve an~c~rrect to t~e best of my knowledge. ' FOR COMMISSION USE ONLY conditions of approval: Notify Commission so representative may witness I Approval No. Plug Integrity _ BOP Test Location clearanceI Mechanical Integrity Test__ S"-~bsequent form required 1"~- 4 O4 ? '/'?- ' Original Signe(i By Approved by the order of the Commission David W. Johnston Commissioner Date ~//~, &;?~'(f · Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRII Trading Bay Unit G-33 Perforation Record 9/20/94 "G" Zone TOP 9020 9070 9132 9196 9294 9412 BOTTOM 9050 9094 9164 9250 ....... 9370 9440 TOP 8649 8694 8750 8807 8893 8997 BOTTOM 8676 8716 8778 8854 8960 9021 West Foreland ToP 10086 10105 10203 10376 10512 10593 BOTTOM 10092 10132 10286 10475 10544 10625 TOP~ 9601 9619 9707 9864 9988 10061 TVD BOTTOM 9607 9643 9782 9954 10017 10091 SF_.P 23 1994 ~asga Oil & Gas Cons. Commission Anchor~e Ralph P. Holman Engineer Technician Unocal P.O. Box 196247 Anchorage, Alaska 99519-6247 September 20, 1994 Mr. Russ Douglas Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglas: This is to inform you of Unocal's intent, upon your approval, to perforate the following intervals in well G-33 (API# 50-733-20212-00) on the Grayling platform. ..,BENCH TOP (MD) ,.BOTTOM (MD) FEET (32 9070 9092 22 (33 9134 9164 3O (34 9200 9230 30 (35 9300 9330 30 HBI 9506 9534 28 WF2 10086 10092 6 WF2 10105 10132 27 WF3 10203 10286 83 WF5 10376 10475 99 WF6 10512 10544 32 WI=r/ 1O593 10626 33 TOTAL 420' SEP 25 1994 Alaska Oil & Gas Cons. Commission Anchor~ September 20, 1994 Grayling Platform, Well Cr-33 perforating .Proc~ur~ . . . . e . e Hold safety meeting. Rig up electric line unit. Pressure test lubricator as directed by Unocal wimess for five minutes. Note: A pump-in sub with a valve is required. Shut down all welding and radio transmissions. Run in hole and perforate intervals as instructed by Unocal wire.ss. (When gun is 200' below surface, welding and radio transmissions may resume.) Pull out of hole. (When gun is 200' below surface, shut down all welding and radio transmissions.) Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL. FEET G2 9070-9092 22 G3 9134-9164 30 G4 9200-9230 30 G5 9300-9330 30 HB1 9506-9534 28 WF2 10086-10O92 6 WF2 10105-10132 27 WF3 10203-10286 83 WF5 10376-10475 99 WF6 10512-10544 32 WF7 10593-10626 33 TOTAL: 420 SEP 23 1994 A~asV, a Oil & Gas Cons. Commis~'ton AnchoraUe STATE OF ALASKA ALAS~" OIL AND GAS CONSERVATION C~-",':-~MISSION '" ' REPOR OF SUNDRY WELL O1[., RATIONS 1. Opel;ations Performed: Operation Shutdown __ Stimulate __ Plugging __ Perforate" X_ Pull tubing __ Alter casing__ Repair well__ Pull tubing __ Other__ -//¢/ 2. Name of OPerator 5. TYPe of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Devek~ment X_ KB: 103'l~ L Explomto~/__ ..: fe e~ 3. AddreSs ..... Stm~gmph~ __ 7. Unit or ProPerty name P.O. Box 196247, Anchorage, Alaska 99519-6247 Serace __ Trading Bay Unit 4. Location of well at sLrface Grayling platform, Leg #3, Conductor #11 8. Well number 1409'W and 1806' N from SE Cor., Sec. 29, T9N, R13W, SM G-33 At top of productive interval 9. Permit number/approval nUmber- 2004' E and 146'S from Surface Location ~ '7 0 -- ~. ~ At effective depth 10. APl number 2654' E and 496' S from Surface Location 50-733-20212-0 At total depth "11. Field/Pool 2683' E and 516' S from Surface Location McArthur River/West Foreland , 12. Present well Condition summary Total depth: measured 10,790 feet Plugs (measured) true vertical 10241' feet .. Effective depth: measured .10,706 feet ._ Junk (measured) , Casing Length SiZe Cemented Measured depth True vertical depth Structural 360' 26" Driven 360' 360' Conductor 605' 20" 2215 sx 605' 605' Surface 4511' 13 3/8" 2650 sx 4511' 4448' Intermediate Production 10,090' 9 5/8" 2000 sx 10,090' 9605' Liner 792' 7' 200 sx 9962'-10,754' 9489'-10,208' Perforation depth: measured See Attached true vertical Tubing (size, grade, and measured depth) SS: 3 1/2", 9.2#, N-80 LS: 3 1/2", 9.2#, N--80 Packers and SSSV (type and measured depth) Baker 9 5/8" perm. pkr. @ 9930', Baker 9 5/8" A-5 dual pkr. @ 8884' Otis 3 1/2" BV (~ 328' and 297' ~ ~ ~ ~ ! % I ~= r~ 1'3. StimUlation or cement squeeze summary ~, E ~ E ! V r... [~ Intervals treated (measured)MAR 0 199; Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons, 14. Representative Daily Average Production or Injecti°n Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 287 377 809 1265 140 Subsequent to operation 211 0 746 1280 200 t5. Attachments 16. Status of Wel! classification as: Copies of Logs and Surveys run Dally Report of Well Operations Oil X Gas Suspended Service ....Signed~r"[,//~,.~~. Title '~.LL,I,~G, ~'~A,~/~(.~,-. Date 2~.~/~{L. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Trading Bay Unit G-33 Perforation Record TOP, 9,020 9,070 9,132 9,196 9,294 9,412 MD BOTTOM 9,050 9,094 9,164 9,250 9,370 9,440 ZONE TVD TOP 8,649 8,694 8,750 8,807 8,893 8,997 BOTTOM 8,676 8,716 8,778 8,854 8,960 9,021 WEST FORE~ ToP, 10,086 10,105 10,203 10,376 10,512 10,593 BOTTOM, 10,092 10,132 10,286 10,475 10,544 10,625 TVD TO~ BO~T02 9,601 9,607 9,619 9,643 9,707 9,782 9,864 9,954 9,988 10,017 10,061 10,091 Unocal North Amerioa~.:~~ Oil & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region DOCUMENT TRANSMITTAL March 23, 1993 TO: Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT 1 blueline and 1 sepia TST-P Log in TBU G-33 RECEIVED MAR 2 4 1995 Alaska Oil & Gas Cons. Commission Anchorage PLEASE ACKNOWLEDGE RECE~ BY SIGNING AND RE~G ONE COPY OF RECEIVED BY: - ' 0 ' -- ' ~" DATED: STATE OF ALASKA , ALASK~,OIL AND GAS CONSERVATION CO.b!MISSION · APPLICI 'ION FOR SUNDRY A( "ROVALS 1. Type of request: Abandon__ Suspend __ . Operations shutdown Re-enter suspended well__ ' Alter casing__ Repair well __ Plugging __ ~me extension ~ Stimulate Change approved program Perforate X_ Ot~er ~'"~,~ . __ Pull tubing Variance 2. Name of Operator 15. Type of Well: 6. Datum ,e, levation (DF Union Oil Company of California (Unocal) I Development X KB: 103 Exploratory --- ~,"~eet 3. Address Sbatigraphic 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519-6247 Sense ~ Trading Bay Unit 4. Location of well at surface Leg #3, Conductor #11 8. Well number 1409' W and 1806' N fr. SE cor., Sec 29, T9N, R13W, SMRE .EIYEO G-33 -~- (3~, ~ At top of productive interval 9. Permit number ' 2004' E and 146' S fr. Surface Location 7-791 At effective depth ~P~ 1 1 '~049~ 10. APl number 2654' E and 496' S fr. Surface Location At total depth Alaska 0il & Gas Cons. I;;om 50-733-2O212-0 11. Field/Pool 2683' E and 516' S fr. Sudace Location ~llCtiOl'ag8 McArthur River/G, West Forelands 10790 feet Plugs (measured) 10241 feet 12. Present well condition summary Total depth: measured true vertical Effective depth: -measured · 10706 feet Junk (measured) · true vertical 10165 feet Casing Length Size Cemented Measured depth True vertical depth Structural 360' 26" Driven 360' 360' Conductor 605' 20" 2215 sx 605' 605' Surface 4511' 13 3/8" 2650 sx 4511' 4448' Intermediate 2000 sx 10090' 9605' 200 sx 9962'- 10754' 9489'- 10208' Production 10090' 9 5/8" Liner 792' 7" Perforation depth: measured See Attached true vertical Tubing (size, grade, and measured depth) $8:31/2", 9.2#, N-80 LS: 3 1/2", 9.2#, N-80 Packers and SSSV (type and measured depth) Baker 9 5/8" perm. packer (~) 9930', Baker 9 5/8" A-5 dual packer ~ 8884', Otis 3 1/2" ball valve nipple @ 328' and 297' 13. Attachments Description summary of proposal__ Detailed operations programX__ BOP sketch Status of well classification as: Suspended 14. Estimated date for commencing operation ~15. March, 1993 r 16. If proposal was verbally approved Oil X_ Gas __ Name of approver Date approved Sen/ice 7. I hereby/'c~r, tif~that~th~r{F'e~, true and correct to the best of my knowledge. Signed ,~~~ Title FOR COMMISSION USE ONLY IApproval N~;) Conditions of approval: Notify Commission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required 10- Origina.! $~gned By David W. johnston Commissioner SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 TOP 9,020 9,070 9,132 9,196 9,294 9,412 Trading Bay Unit G-33 Perforation Record 5/2/89 "G" ZONE BOTTOM 9,050 9,094 9,164 9,250 9,370 9,440 TVD TOP~ BOTTOM 8,649 8,676 8,694 8,716 8,750 8,778 8,807 8,854 8,893 8,960 8,997 9,021 TOP 10,086 10,105 10,203 10,376 10,512 10,593 BOTTOM 10,092 10,132 10,286' 10,475 10,544 10,625 WEST FORELAND TVD TOp 9,601 9,619 9,707 9,864 9,988 10,061 BOTTOM 9,607 9,643 9,782 9,954 10,017 10,091 Alaska Oil & Gas Cons. Commission Anchorage March 3, 1993 Gra lin Well G-33L erforatin rocedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all,welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume.) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURE~ TRUE VERTICAl_ WF2 10,086'-10,092' 9601'-9607' WF2 10,105'-10,132' 9619'-9643' TOTAL: TOTAL FEET -- 6' 27_2 33' ' " F STATE OF ALASKA ALI A OIL AND GAS CONSERVATION COMMI(' )N REPORT OF SUNDRY WELL ~,,-~r~.,,.,,,o"'""~' ~'"'~"~ 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate ~ Pull tubing _... Alter casing __ Repair well __ Pull tubing ~ Other __ 2. Name of Operator ! 5. Type of Well: 6. Datum elevation (DF or KB) Development / Union Oil Co. of Calif. (UNOCAL) i] Ex~oratory~ RT to MSL 99' 3. Address PCB 190247, Anch, AK., 99519-0247 4. Location of well at surface 1409' W & 1806' N of SE Cor., Sec. 29, At top of productive interval 2004' E & 146' S of Surface Location At effective depth 2654' E & 496' S of Surface Location At total depth 2683' E & 516' S of Surface Location Stratigraphic __ Service __ T9N, R13W, SM ZUnitorPrope~name Trading Bay Unit 8. Well number C~-qq 9. Permit number/approval number 7-791 10. APl number 50-"73 3 -2 0212 -00 12. Present well condition summary Total depth: measured 10 true vertical 10 ,7 9 0 ' feet Plugs (measured) ,241 ' feet Effective depth : measured 10,706 ' feet Junk(measured) true vertical 10,165 ' feet feet _ 11. Field/Pool McArthur Rr./Hemlock Casing ~ngth Size Cemen~d Measumdde~h ~ueverticalde~h stru~uml 360' 26" DA[V~ 360' 360' Condu~or 605' 20" 2,215 sx 605' 605' Sudace 4,511' 13 3/8" 2,650 sx 4,511' 4,448' Intermediate Production 10,090' 9 5/8" 2,000 sx 10,090' 9,605' Liner 792' 7" 200 SX 9962'-10,754' 9489'-10,208' Pedor~ionde~h: measured 10,086'-10,092' 10 105'-10 132' 10 203'-10 286' I I I , , 10,376'-10,475' 10,512'-10,544' 10 593'-10 625' ! , I trueve~ical 9,601'-9,607' 9 619'-9 643' 9 707'-9 782' , I I I I ! 9,869'-9,954' 9 988'-10 017' 10 062'-10 091' I I I I I ~ng(siz~grad~andmeasumddepth) 3 1/2", 9.2#, N-80 @ 9,977' @ 9,930'; Baker 9 5/8" Packers and SSSV (type and measured depth) Baker 9 A-5 Dual PKR. @ 8,884'; Otis 3 1/2" 13. Stimulation or cement squeeze summary ' 14. Intervals treated (measured) Treatment description including volumes used and final pressure Tubing Pressure 5/8" PERM. PKR. BV @ 328' 125 Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mol Water-Bbl Casing Pressure 100 265 291 600 1450 330 82 660 1360 Subsequent to operation 15: Attachments ' 116. Status of well classification as: Copies of Logs and Surveys run -- ! Daily Report of Well Operations __ Oil ~v/ Gas __ Suspended __ Service 1Z I hereby certify tha~'~e foregoing is true and correct to the best of my knowledge. Signed Gary ~ B~h T~l~egional Drilling Manager Form 10-404 Rev 06/15/88 Date ~ - \ -~ \ SUBMIT IN DUPLICATE'-...,.~ ., . STATE OF ALASKA 0 ~ · AI..~' , OIL AND GAS CONSERVATION COMMI(~ N APPLI I'ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown_.. Re-enter suspended well ~ Alter casing __ Repair well __ Plugging __.. Time extension ~ Stimulate __ Change approved program ~ Pull tubing .__ Variance ~ Perforat{ x Other ...._ 2. Name of Operator ! 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal)l Oev~opment~ RT 99' Above MSL 3. Address / Exploratory ~ Stratigraphic __ 7. Unit or Property name P.O. Box 190247, Anchorage, AK 99519-024r Ser~ce~ Trading Bay Unit 4. Location of well at sudace 1409' W & 1806' N fr. SE Cor., Sec. At top of productive interval 2004' E & 146' D fr. Surface Loc. At effective depth 2654' 'E & 496' S fr. Surface Loc. At total depth 2683' E & 516' S. fr. Surface Loc. 12. Present well condition summary Total depth: measured true vertical 29, T9N, R13W' SM 10,790' ~a Plugs(measured) 10,241' ~et 8. Well number ¢-33 9. Permit number 7-791 10. APl number 50--133-20212-00 11. Field/Pool MdArthur River/Hemlock RECEIVED Effective depth: measured 10,706' feet Junk(measured) JAN 1 0 1991 true ve~cal 10,165' feet ~a,~31 ~, &-~...8~. ~~B~ Casing Length Size Cemented Measured depth ~V~l~~r{ical depth Structural 360 ' 26" Driven 360 ' 360 ' Conductor 605 ' 20" 22].5 sx 605 ' 605' Surface 4511' 13 3/8" 2650 s× 4511' 4448' Intermediate feet Production 10,'090' 9 5/8" 2000 sx 10,090' 9605' Un~ "792' 7" 200 sx~ 9962'-10,754' 9489'-10,208' Pe~oo?t~on depth: measured 3 10,086 -10,092'; 10,105'-10,1 2'; 10,203'-10,286'; 10,376'-10,475'; 10,512'-10,544'; 10,593'-10,625' true vertical 9601'-9607'; 9619'-9643'; 9707'-9782'; 9869'-9954'; 9988'-10,017'; 10,062'-10,091 Tubing (size. grade, and measured depth) 3½", 9.2tI, N-80 @ 9977' PackersandSSSV(typeandmeasureddepth)Baker~'9 5/8" PERM. P.KR. @ _9930[..4 Baker 9 5/8" .A-~DUAL · PKR. @ ,~8~.,4,.';, ~:".'OTIS 3½" BV~ @ 328'_':' '"' 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch x 14. Estimated date for commencing operation Status of well classification as: On Approval 16. If proposal was verbally approved Oil ..2[ Gas __ Suspended __ Name of approver Date approved Service 1Z I hereby ceAfy that the foregoing is true and correct to the best of my knowledge. Signed ~,,~~ ~ ~-~,.,~,, ' Title Regional Drilling Manager Date t-9-~ _ ~ ~- ' FOR COMMISSION U ;E ON Conditions of. ap~. ~: Notify Commission so representative may witness I Approval No. ~qug imegrity ~ BOP Test ~ Location clearance /, . z, ' (~ 9 Mechanical lntegrity Test __ Subsequent form required 1'~'- "t~T Approved COPY* BetUrned - BY LONNIE C. SMITH Approved by order of the Commission Commissioner Date / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE December 28, 1990 RE: G-33 perforating procedure 1. RU slick line, run gauge and tag bottom. 2. Hold safety meeting. 3. RU electric line unit. 4. Pressure test lubricator to 2500 psi for five minutes. 5. Shut down all welding and radio transmissions. 6. RIH and perforate intervals as instructed by Unocal representative. (When gun is 200' below surface, welding and radio transmissions may resume.) 7. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 8. Repeat steps 5, 6 and 7 as needed to perforate the following intervals: BENCH MEASURED WF1 10,086 - 10,092 WF1 10,105- 10132 WF2 10,203 - 10,286 WF4 10,376- 10,475 WF5 10,512- 10,544 WF6 10,593 - 10,625 TRUE VERTICAL 9,601 - 9 6O7 9,619 - 9.643 9,707- 9 782 9,864- 9,954 9,988 - 10,017 10,062 - 10 091 TOTAL FT. 6 27 83 99 32 32 TOTAL 279 Alaska R ecj~o~ April 16, 1990 Alaska Oil & Gas Conservation Commission 300! Porcupine Dr. A~ckorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. JohnSon: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, GSB/lew Unocal Oil & Gas Di ~n Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Department Alaska District May 2, 1989 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Report of Sundry Well Operations Grayling Platform - Well G-33 Dear Mr. Chatterton: Attached is a corrected Report of Sundry Well Operations for perforations done during workover operations on Well G-33 in December, 1987. The Report of Sundry Well Operations dated 4/22/88 included proposed perforations for West Foreland and not the actual perforations. Please replace the Sundry Report you currently have on file with the attached. Please telephone me if you have any questions regarding the attached revision. .. Very truly y.our~, cc: Gary Bush D. Wotring K. Kiloh Carol Moudy Marathon ARCO 0013n/55 RECEIVED TBUS G-33 PERFORATION RECORD M__D 9020' - 9050' 9070' - 9094' 9132' - 9164' 9196' - 9250' 9294' - 9370' 9412' - 9440' "G" Zone TVD 8649' - 8676' 8694' - 8716' 8750' - 8778' 8807' - 8854' 8893' - 8960' 8997' - 9021' West Foreland 10,086' - 10,092' 10,105' - 10,132' 10,203' - 10,286' 10,376' - 10,475' 10,512' - 10,544' 10,593' - 10,625' 9,601' - 9,607' 9,619' - 9,643' 9,707' - 9,782' 9,864' - 9,954' 9,988' - 10,017' 10,061' - 10,091' 0013n/56 STATE OFALASKA .... 0 ~'i FIEPOF OF SUNDRY WELL OPEi:: TIONS 1. Operations performed: Operation shutdown __ Pull tubing m Alter casing Stimulate __ Plugging __ Perforate __ Repair well ~ Pull tubing __ Other 2'UNnz&%en°foO~pfra~mPany of Calfforn.ia (UNOCAL,! 3'~.~r.e~ox 100247, Anoh, Ak., 99519-0247 I 4. Location of well at suflace 1409' W & 1806' N F/SE Co., Sec 29, T9n, At top of productive interval 2004' E & 146' S F/Surface Location At effective depth 2654' E & 496' S F/ Surface Location At total depth 2683' E & 516' S F/Surface Location 5. Type of Well: Development Exploratory Stratigraphic Service R13W' S.M. 6. Datum elevation (DF or KB) 99- RT above MSL 7. ~rar~ng ~aym~nit U it or rop_e na 8. Well number G-33 9. Permit number/approval number 7-791 10. APl number 50-- 133-20212 11. Field/Pool West Foreland Pool 12. Present well condition summary Total depth: measured true vertical 10,790' feet Plugs (measured) 10,241 ' feet Effective depth: measured 10,706 ' feet Junk (measured) true vertical 10,165' feet Casing Length Size Cemented Measured depth True vertical depth Structural 360 ' 26" Driven 360' 360' Conductor 605' 20" 2215sxs 605 ' 605' Sudace 4,511' 13-3/8" 2,650sxs 4,511' 4,448' Intermediate Production 10,090' 9-5/8" 2,000sxs 10,090' 9,605' Liner 792 7 # 200sxs 9,962-10,754' 9,489-10,208 Perforation depth: measured true vertical See Attached Tubing (size. grade, and measured depth) (LS & SS) 3-1/2", 9,2,9, N-80, LS @ 9977', SS @ 8914' Packers and SSSV (type and measured depth) a- e 9 5 '8" . erin Pa k Dual Packer @ 8884', Ot...is 3rl/2~ ~a[1 ?.~e ~z~le ~ ~8~ ~9~.~, Baker 9-5/8# A-5 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation SS LS SS LS RECEIVED MAY Representatiye Daily Average ProduCtion or Injection Data ~~ ~ffl..~~ ~i.~,~,.~ Shut-in Oil-Bbl Gas-Md Water-Bbl Casing- ""~'"'~-'"~"' P~ressure ..... ~ut)rng ressure. 442 22 425 860 psi 200 psi 140 159 735 1250 psi 110 psi 586 230 661 1250 psi 140 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil x__ Gas m Suspended Service 17. I hereby,certif,/~hat the forego/tills true and correct to the best of my knowledge. oy D~ ] obe~ts ~ . Title Environmental Engineer Si~ned Form 10-404 Rev 06/15/88 feet Date 5/02/89 _ SUBMIT IN DUPLICATE K( STATE OF ALASKA rv~~ ALAS .)IL AND GAS CONSERVATION CO'M 51ON REPORT OF. SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate E~ Pull tubing Alter Casing [] Other [~ 2. Name of Operator 5. Datum elevation(DF or KB) Union Oil Company of California 99' RT to MSL 3. Address 6. Unit or Property name P. O. Box 1'90247 Anchorage, AK. 99519-0247 Trading Bay Unit 4. Location of well at surface 1409'W & 1806'N F/ SE Co., Sec 29, TAn, R~13W.S,M. 7. Well number G-33 Attop ofproductiveinterval 2004'E & ~:.46'S F/ Surface Location Ateffective depth 2654'E & 496'S F/ Surface Location Attotaldepth 2683'E & 516'S F/ Surface Location 8. Approval number 7-791 9. APl number 50-- 133-20212 10. Pool West Foreland Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,790 feet !0,241 feet ~0,706 feet 10,165 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural 360' 26" Driven Conductor 605 ' 20" 2215 sx Surface 4511' 13-3/8" 2650 sx ,. Intermediate Production 10,090' 9-5/8" 2000 sx Liner 792' 7" 200 sx Perforation depth: measured See Attached Measured depth ~ueVerticaldepth 360' 360' 605' 605' 4511' 4448' 10,090 9605 V£D9489-10'208' true vertical ~lasl(a Oil & 8as Cons. Commission Tubing (size, grade and measured depth) (LS & SS) 3-1/2", 9.2¢, N-80, LS e 9977', SS e 8914' Anchora¢ Baker 9-5/8" Perm Packer ~ 9930', Baker 9-5/8" A-5 Packers and SSSV 6ype_ and measured depth) Dual Packer ~ 8884', Otis 3-1/2'r Ball Valve Nipple ~ 328' & 297' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 14. Attachments SS Shut-in LS 442. 22 425 860 psi SS 140 159 735 1250 psi ~S 586 230 661 1250 psi Tubing Pressure 200 psi 110 psi 140 psi Daily Report of Well oPerations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢¢~~. ~~ itle ~p.v:i.~e~ta] Enqineer Form i0-404 I~ev. 12-1-85 Roy D. Roberts / Feet Date 4/22/88 "Submit in Duplicate TBUS G-33 PERFORATION RECORD "G" Zone 9020-9050' 9070-9094' 9132-9164' 9196-9250' 9294-9370' 9412-9440' 8649-8676' 8694-8716' 8750-8778' 8807-8854' 8893-8960' 8997-9021' West Foreland 10,086-10,092' 10,105-10,146' 10,175-10,190' 10,200-10,290' 10,371-10,480' 10,505-10,554' 10,588-10,630' 9,601- 9, 9,619- 9, 9,682- 9, 9,704- 9, 9,860- 9, 9,981-10, 10,057-10, 607' 656' 695' 786' 959' 026' 095' 0447N(5) APR 2 Alaska Oit & G~s Oons, Oommissio~ A~cfiora~ GRAYLING PLATFORM TRADING BAY UNIT G-35 20" C. @ 605'MD z~ 13-3/8" C. @ 4511'MD Z BAKER 9-5/8" A-5 DUAL PKR @ 8884'MD BAKER 9-5/8" PERM. PKR. @ 9930'MD 7" LINER F/ 9962'- 10754-' SS: 3-1/2" 9.2# N-80 SEAL LOCK @ 8914-'MD "G" ZONE 9020'-9050' (50') 9070'-9094-' (24-') 9152'-9164-' (32') 9196'-9250' (54-') 9294'-9370' (76') 94-12'-94-40' (28') LS: 3-1/2" 9.2# N-80 SEAL LOCK @ 9977'MB WEST FORELAND 10086'-10092' (6') 10105'-1014-6' (4-1') 10175'-10190' (15') 10200'-10290' (90') 10,571'-10480' (109') 10505'- 10554-' (49') 10588'-10650' (4-2') ETD 10706'MD STATE OF ALASKA ALASK. , OIL AND GAS CONSERVATION COMN.,JSION REPORT OF. SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ~ Other Lr~Z Plugging E] Perfora~,e '.? 2. Name of Operator Union Oil Company of California 3. Address P. O. Box 1'90247 Anchorage, AK. 99519-0247 4. Location of well at surface 1409'W & 1806'N F/ SE Co., At top of productive interval Sec 29, T9n, R13W.S.M. 5. Datum elevation (DF or KB) 99' RT to MSL Feet 6. Unit or Property name ~ ~ ~,,~,-~..~ .o,. ~, · . 2004'E & ~.46'S F/ Surface Location At effective depth 265~'!?'E & 496'S F/ Surface Location At total depth . 2683'E & 516'S F/ Surface Location , 7. Well number ~33.~. __ ~,'~f.~: ~" - 8. Approval number 7-791 9. APl number 50-- 133-20212 10. Pool ~:~' West Foreland Pool 11. Present well condition summary Total depth: measured true vertical 10,790 10,241 feet Plugs (measured) feet feet '; Junk (meaSured) feet Size Cemented Measured depth '~ True Vertical depth 26" Driven 360 ' 360 ~ 2'0" 2215 sx 605' '~ 605' 13-3/8". ~' 2650 sx 4511' .~4448' / Effective depth: measured 10,706 true vertical 10,165 Casing Length Structural 360' Conductor 605' SUrface 4511 ' Intermediate Production Liner Perforation depth: 10,090' 9-5/8" 2000 sx 10,090 9605 792' 7" 200 sx 9962-10,754' 9489-10,208' measured See Attached true vertical Tubing (size, grade and measured depth) (LS & SS) 3-1/2", 9.2#, N-80, LS @ 9977', SS @ 8914' Packers and S$$V (type_ and measured depth) Baker 9-5/8" Perm Packer @ 9930', Baker 9,5/8" A-5 Dual Packer @ 8884', Otis 3-1/2'rBall Valve Nipple @ 328' & 297' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment dcscript on including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Averag~ Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure' ~bing Pressure SS Shut,in LS 442 22 425 860 psi 200 psi SS 140 159 , 735 1250 psi 110 psi - 14. Attachments LS 586 230 Daily Report of Well Operations [] 661 1250 psi 140 psi Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~4~Title Envirnnmen~ 1 Enqineer Signed Form 10-404 Bev. 12-1-8'5 Roy D. Roberts Date 4/22/88 Submit in Duplicate TBUS G-33 PERFORATION RECORD "G" Zone 9026-9050 9070-9094 9132-9164 9196-9250 9294-9370 9412-9440 8649-8676' 8694-8716' 8750-8778' 8807-8854' 8893-8960' 8997-9021' West Foreland 10,086-10,092' 10,105-10,146' 10,175-10,190' 10,200-10,290' 10,371-10,480' 10,505-10,554' 10,588-10,630' 9,601- 9,607' 9,619- 9,656' 9,682- 9,695' 9,704- 9,786' 9,860- 9,959' 9,981-10,026' 10,057-10,095' 0447N(5) GRAYLING PLATFORM TRADING BAY UNIT 0-55 20" C. @ 605'MD /I 13-3/8" 'C. @ 4511'MD BAKER 9-5/8" A-5 DUAL PKR @ 8884'MD BAKER 9-5//8'' PERM. PKR. @ 9930'MD 9-5/8" C. @ IO090'MD 1 7" LINER F/ ,~ 9962'-10754' '- - I SS' ,.3-1/2" 9.2# N-80 SEAL LOCK @ 8914'MD "0" ZONE 9020'-9050' (50') 9070'-9094' (24?) 91,32'-9164' (52') 9196'-9250' (54') 9294'-9570' (76') 9412'-9440' (28') LS: 3-1/2" 9.2# N-80 SEAL LOCK @ 9977'MD wEsT FORELAND 10086'-10092' (6') 10105'-10146' (41') 10175'-10190' (15') 10200'-10290' (90') 10571'-10480' (109') 10505'-10554' (49') 10588'-10630' (Zl-2') ETD 10706'MD UNION 01[~'~ :0. OF CALIFORNIA Dt% ~ING RECORD PAGE N~ ·LEASE T~S DATE E.T.D. 12-17 12-18 12-19 12-20 12'21 12-22 12-23 12-24 12-25 12-26 12-27 12-28 9,920 10,706 G-33 McArthur River Field WELL NO. FIELD .... DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Trip for washover shoe 93. Milled 10" on 9-5/8" single hydraulic packer @ 9920' POOH. RIH with jar assembly and attempt to jar packer free - no good[ Trip for washover shoe #3. Milled additional 5" on packer. Milled over packer assembly and began moving packer down hole. Engaged fish with overshot and packer came free with 210,000# overputl. POOH with complete recovery. Left packer rubbers in hole. RIH with barbed junk catcher to fish rubbers - no recovery. Ran 9-5/8" scraper to 7" liner top. CBU at top of liner. RIH with RTTS and tested 9-5/8" casing above 9000' to 2500 psi. POOH. RIH with 7" scraper to 10,307'. Wash fill 10,507' to ETD of 10,706'. Began displacing well to FIW. Continue to displace well to clean FIW + 6% KCL. POOH. Performed weekly BOPE test to UOC specifications. Made up and RIH with Baker 4" tubing conveyed guns. Located across WestForelands at intervals. Began to rig up surface equipment. Continue to rig up surface equipment. Tested same. Began displacing with field gas and was unable to obtain sufficient drawdown (FP=2900 psi; Wanted to shoot @ 2400 psi). Pull to +4650' and installed Omnie valve. RIH with dry pipe above Omnie tool. Located guns across West Foreland benches 1, 2, 4 & 6. Opened omnie tool and dropped bar to fireBaker tubing conveyed guns - Guns did not fire. Reversed out. Rigged up wireline and fished bar. Rigged down surface equipment. Prep to POOH to check guns. Circulated bottoms up and retrieved guns. Baker mistakenly installed a bar catcher sub above the bar drop firing head. Re-ranguns with Omni tool at 4625'. POOH and placed Omni tool 180' above packer. RIH filling drill pipe with 6% KCL fluid at 2400 hours. Continued to RIH filling drill pipe. Correlated guns on depth with garmma ray. Set packer with fluid level in tubing at 4602'. Pressured up annulus and opened omni tool. Dropped bar and fired guns. Had 979' of fluid rise inless than one hour. Reversed out and POOH with guns. All shots fired. RIH and set 7" retrievable bridge plug at 10,050'. Pulled up and spotted sand to top of 7" liner at 9962'. Tripped for Baker 5" guns with annular pressure firing head at 2400 hours. Continued to RIH with guns. Correlated guns with gamma ray and positioned guns across "G" zone. Set packer and opened by-pass. Displaced fluid in drill pipe to 2300' with field gas. Fired guns with 2000 psi on the annulus. Fluid rose 270' Pulled packer loose and reversed out. POOH and laid down guns. ~11 shots fired. RIH and circulated out sand. Retrieved RBP from 10,050'. RIH with dual 7" and 9-5/8" scrapers at 2400 hours. Tagged fill at 10,676'. Washed down to 10,704'. POOH and laid down 3-1/2" drill pipe. TestedBOPE. RIH and set 9-5/8" perm packer at 9930' with mule shoe at 9977'. RIH and tested packer at 1500 psi, OK. POOH and laid down 5" drillpipe at 2400 hours. Continued laying down 5" drill pipe. Installed 3-1/2" dual rams and tested. RIH with dual 3-1/2" completion assembly at 2400 hours. Continued running dual production equipment. Misplaced GLM ~5 on short string. Pulled up 63 joints and replaced mandrel. After running packer to 7074', could not go deeper. Worked free and POOH at 2400 hours. LEASE TBUS UNION OI F CALIFORNIA DR~_~.ING RECORD PAGE N G-33 McArthur River Field WELL NO. FIELD 12-06 12-07 12-08 12-09 12-10 12-11 12-12 12-13 i2-14 12-15 12-16 E.T.D. 10,706 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Skidded rig over G-33 and rigged up. Rigged up wireline to short string. Pulled ball valve at 313'. Pulled GLV at 2446'. Recovered only retrieving sleeve from GLV92. Rigged up over long string. Recovered ball valve at 325' and GLV from 2446; at 2400 hours. Continued running 2.735" gauge ring and pulling gas lift valves. Pulled valves 5-10 and pushed valve #11 out the bottom of the long string. Closed all mandrel ports except at 8671'. Rigged up on short string and ran gauge scratcher to 2446'. Flowed short string to recover gas lift valve ~2 at 2400 hours. · Continued pulling gas lift valves #3 - 99 in short string. RIH to pull valve #10 at 2400 hours. Pulled gas lift valve #10 at 8575'. Could not latch onto gas lift valve ~ll. at 8643'. Pushed valve to Q nipple at 8721' with impression block. Closed all cx mandrels except for 911. Rigged down wireline. Circulated short string with 90 barrels of 6% KCL. Circulated long String. Installed BPV's. Nippled down tree and nippled up BOPE at 2400 hours. Nippled up and tested B OPE. Rigged up APRS. RIH with 2.70" jet cutter, unable to get past 8687'. Ran gauge ring to 8798' no problem. Ran 2.59" jet cutter and cut~3-1/2" long string at 8769', 49' below dual packer. Pumped 75 barrels of 6% KCL down short string. Circulated down long string taking returns to production. Spotted 25 barrel sized salt pill. Unseated dual hanger, short string free at dual packer. Jet cut long string 18' above dual packer. POOH and laid down dual strings at 2400 hours. Continued laying down dual 3-1/2" production strings. Recovered all of the short string. Top of long string fish at 8691', 18' above dual packer. Installed and tested 3-1/2" X 5 VBR. Picking up fishing assemblY and.5" drill pipe at 2400 hours. RIH picking up 5" drill pipe. Engaged top of fish and jarred packer free. RecoVered tubing stubs and packer. Top of fish at 8775'. Re-ran fishing assembly and engaged top of fish at 8775'. Jarred on fish, overshot released from fish. POOH at 2400 hours. POOH and had no recovery. 3-1/2" grapple was packed with carbon and scale. RIH with fishing assembly 92 and engaged fish at 8775'. Ran free point, 100% stuck from 9504' - 9253', 9153' had 90% movement. Attempted backoff at 9146' DPM, POOH and recovered 2 joints and 1 stUb. TOp of fish at 8842'. RIH with fishing assembly #3. Washed out fill from 8818' - 8842'. Engaged fish and rigged up to cut tubing. Made first cut at 9900' and second at 9150' Worked and separated tubing. POOH at 2400 hours. POOH and recovered 312' of 3-1/2" tubing. RIH with 8-1/2" bit and scraper and cleaned out from 8915'- 9150'. Pumped 30 barrel hi-vis slug and changed system to clean 6% KCL. POOH. Performed BOPE test, changed out API ring. RIH with fishing assembly at 2400 hours. RIH with wash over pipe. Washed over 3-1/2" tubing from 9155' - 9335'. Pumped hi-vis sweep and circulated clean. Tripped for fishing assembly. Caught fish at 9155'. Worked fish freee and circulated bottoms up. POOH and recovered 23 joints and 2 tubing stubs. Top of fish at 9900'. RIH with 8-1/2" bit and scraper and cleaned out fill from 9318' - 9895'. Circulated bottoms up at 2400 hours. POOH with bit and scraper. RIH and wash down from 9895' - 9920' (top of packer). Tripped for overShot. Engaged fish at 9900'. Could not release packer after 1-1/2 hours jarring. Grapple pulled loose. POOH at 2400 hours. UNION Oljjf!s. '0. OF. CALIFORNIA D FF, _,..lNG RECORD PAGE LEASE TBUS G-33 McArthur River Field WELL NO. FIELD DATE E.T.D. 12-29 12/30 0447N 10,706 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Continued toP O OH. Found shear ring sheared in Baker packer. Replaced packer and ran dual 3-1/2" production equipment. Installed ball valve nipples in both strings and tested control lines. Stabbed into perm packer at 9930' and tested seals at 1500 psi. Landed tubing on dual hangers. Long string mule shoe at 9977', short string mule shoe at 8916'. Dual packer at 8884'. Pulled dummy valve in short string. RIH with tubing plug at 2400 hours. Set plug in XN nipple at 8915'. Pressured tubing to 2000 psi to set packer. Pulled plug. Tested packer to 1500 psi, OK. Nippled down BOPE and removed from under rig. Installed prodUction tree and flowlines. Pulled dummy valves out of ball valve nipples and installed live valves. Turned well over to production. Released rig. at 2400 hours, 12/30/87. 3-1/2", 9.29, N-80, Buttress Lqqg. St. ring Tubing Detail. From To Length. J.t.s. Decription 9977.24 9976.53 9948.03 9946.73 9941.00 9940.15 9933.70 9926.66 9928.83 9896.54 9892.56 9463.75 9015.69 8892.89 8890.84 8883.59 8880.09 8820.80 8816.82 8754.72 8748.17 8104.10 8097.55 '7449.48 7442.93 7019.93 7014.82 6800.62 6794.07 6158.33 6151.78 6029.25 6025.05 5569.50 5562.95 5231.37 5227.18 5221.09 4889.16 4882.61 4211.59 4205.46 4145.81 9976.53 9948.03 9946.73 9941.00 9940.15 9933.70 9929.66 9928.83 9896.54 9892.56 9463.75 9015.69 8892.89 8890.84 8883,59 8880,09 8820.80 8816.82 8754.72 8748.17 8104.10 8097.55 7449.48 7442.93 7019.93 7014.82 6800.62 6794.07 6158.33 6151.78 6029.25 6025.05 5569.50 5562.95 5231.37 5227.18 5221.09 4889.16 4882.61 4211.59 4205.46 4145.81 4139.26 .71 28.50 1 1.30 5.73 .85 6.45 4.04 .83 32.29 1 3.98 428.81 14 448.06 21 122.80 4 2.05 7.25 3.50 59.29 2 3.98- 62.10 2 6.55 · 644.07 21 6.55 648.07 21 6.55 423.00 14 5.11 214.20 7 6.55 635.74 21 6.55 122.53 4 4.20 455.55 15 6.55 331.58 11 4.19 6.09 331.93 11 6.55 671.02 22 6.13 59.65 2 6.55 3-1/2" Mule Shoe Collar 3-1/2" 9.29 N-80 Butt. Tbg 3-1/2" Otis X Nipple 3-1/2" 9.29 N-80 Butt Tbg Pup Jt. X-Over Baker Mill-Out Extension Baker 9-5/8" Perm. Pcker Baker Locator (No-Go) 3-1/2" 9.29 N-80 Butt. Tbg. Otis 3-1/2" XA Sliding Sleeve 3-1/2" 9.29 N-80 Butt. Tbg. Baker 4-1/2" Blast Jts. 3-1/2" 9.29 N,80 Butt Tbg. .Baker Packer Mandrel Baker 9-5/8" A-5 Dual Packer Baker Pkr Mandrel 3-1/2" 9.2# N-80 Butt. Tbg. Otis 3-1/2" XA Sliding Sleeve 3-1/2" 9.2# N-80 Butt Tbg. Camco K-Bug GLM. 3-1/2" 9.2# N-80 Butt. Tbg. Camco K-BugGLM. 3-1/2" 9.2~ N-80 Butt Tbg. Camco K-Bug GLM. 3-1/2" 9.29 N-80 Butt. Tbg. 3-1/2" 9.2# N-80 Butt. Tbg. Pup Jt. 3-1/2" 9.2~ N-80 Butt. Tbg. Camco K-Bug GLM. 3-1/2" 9.2~ N-80 Butt. Tbg. Camco K-Bug Glm. 3-1/2" 9.2~ N-80 Butt. Tbg. 3-1/2" 9.2# N-80 Butt. Tbg. Pup Jt. 3-1/2" 9.29 N-80 Butt. Tbg. Camco K-Bug GLM. 3-1/2" 9.2# N-80 Butt. Tbg. 3-1/2" 9.2# N-80 Butt. Tbg. Pup Jt. 3-1/2" 9.2# N-80 Butt. Tbg. Pup Jt. 3-1/2" 9.2# N-80 Butt. Tbg. Camco K-Bug GLM. 3-1/2" 9.2# N-80 Butt. Tbg. 3-1/2" 9.2# N-80 Butt. Tbg. Pup Jt. 3-1/2" 9.2# N-80 Butt. Tbg. Camco K-Bug G~. UNION OI O. OF CALIFORNIA D R~.._ING RECORD TBUS G-33 LEASE .WELL NO. FIELD PAGE N McArthur River Field DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3-1/2", 9.2~, N-80, Buttress Lonq String Tubing Detail (Continued) From To Leqg~ J~s Decription 4139.26 .4019.17 120.09 4 3-1/2" 9.2# N-80 4019.17 4014.08 5.09 3-1/2" 9.2# N~80 4014.08 3985.09 28.99 1 3-1/2" 9.2# N-80 3985.09 3978.91 6.18 3-1/2" 9.2# N-80 3987.91 3291.32 687.59 23 3-1/2" 9.2# N-80 3291.32 3284.77 6.55 Camco K-Bug GLM. 3284.77 2372.34 912.43 30 3-1/2" 9.2~ N-80 2372.34 2368.27 4.07 3-1/2" 9.2# N-80 2368.27 2185.03 183.24 6 3-1/2" 9.2# N-80 2185.03 .2178.48 6.55 Camco K-Bug GLM. 2178.48 1903.68 274.80 9 3-1/2" 9.2# N-80 1903.68 1898.60 5.08 3-1/2" 9.2# N-80 1898.60 330.91 1567.69 52 3-1/2" 9.2~ N-80 330.91 328.41 2.50 Otis 3-1/2"Ball 328.41 115.94 212.47 7 3-1/2" 9.2# N-80 115.94 110.72 5.22 3-1/2" 9.2# N-80 110.72 50.19 60.53 2 3-1/2" 9.2# N-80 50.19 47.76 2.43 3-1/2" 9.2# N-80 47.76 44.56 3.20 3-1/2" 9.2% N-80 44.56 43.70 .86 Camron Dual Tbg. 43.70 0 43.70 Landed Below Butt. Tbg. Butt. Tbg. Pup Jt. Butt. Tbg. Butt. Tbg. Pup Jr. Butt. Tbg. Butt. Tbg. Butt. Tbg. Pup Jt. Butt. Tbg. Butt. Tbg. Butt. Tbg. Pup Jr. Butt. Tbg. Valve Nipple Butt. Tbg.' Butt. Tbg. Pup Jt. Butt. Tbg. Butt. Tbg. Pup Jt. Butt. Tbg. Pup Jt. Hanger 3-1/2", 9.2#, N-80, Buttress Short String T.u~.~. 8916.03 8915.32 8914.02 8894.27 8890.84 8883.59 8883.32 8852.52 8848.54 8634.66 8628.11 7981.83 7975.28 7855.72 7850.63 7701.63 7696.53 7329.49 7322.94 6895.99 6890.90 6799.83 6794.80 6707.55 6701.00 6184.50 6178.40 6026.37 6019.82 5593.89 5587.99 5558.34 5554.16 5403.71 8915.32 8914.02 8894.27 8890~84 8883.59 8883132 8852~52 8848.54 8634.66 8628.11 7981.83 7975..28 7855.72 7850.63 7701.63 7696.53 7329.49 7322.94 6895.99 6890.90 6799.83 6794.80 6707.55 6701.00 6184.50 6178.40 6026.37 6019.82 5593.89 5587.99 5558~34 5554.16 5403.71 5397.16 .71 1.30 19.75 3.43 7.25 .27 30.80 1 3.98 213.88 7 6.55 646.28 21 6.55 119.56 4 5.09 149.00 5 5.10 367.04 12 6.55 426.95 14 5.09 91.07 3 5.03 87.25 3 6.55 516.50 17 6.10 152.03 5 6.55 425.93 14 5.90 29.65 1 4.18 150.45 5 6.55 3-1/2" Mule Shoe Collar Otis 3-1/2" "XN" Nipple 3-1/2" 9.2~ N-80 Butt Tbg Pup Jt Baker Packer Mandrel Baker'9-5/8" Dual Packer Baker Left Hand Sub-Welded in Place 3-1/2" 9.2~ N-80 Butt Tbg Otis 3-1/2" "XA" Sliding Sleeve 3-1/2" 9.2# N-80 Butt Tbg Camco K-Bug GLM 3-1/2" 9.2~ N-80 Butt Tbg. Camco K-Bug GLM 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2# N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2~ N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. Camco K-Bug GLM 3-1/2" 9.2% N-80 Butt Tbg. 3-1/2" 9.2# N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2% N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. Camco K-Bug GLM 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2% N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. Camco K-Bug GLM 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2% N-80 Butt Tbg Pup Jt. 3-1/2" 9.2# N-80 Butt Tbg. 3-1/2" 9.2% N-80 Butt Tbg Pup Jt. 3-1/2" 9.2% N-80 Butt Tbg. Camco K-Bug GLM LEASE TBUS UNION O! O. OF CALIFORNIA O _lNG RECORD PAGE N~.: ,, G-33 McArthur River Field .WELL NO, FIELD DATE 0447N (1. E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3-1/2", 9.29, N-80, Buttress Short S.tri.n~ Tubing Detail (Continued) From To Length ~ Decription 5397.16 .4784.89 612.27 20 3-1/2" 9.2# N-80 4784.89 4778.34 6.55 Camco K-Bug GLM 4778.34 4384.29 394.05 13 3-1/2" 9.2# N-80 4384.29 4378.21 6.08 3-1/2" 9.2# N-80 4378.21 4164.05 214.16 7 3-1/2" 9.2# N-80 4164.05 4157.67 6.38 3-1/2" 9.29 N-80 4157.67 4004.43 153.24 5 3-1/2" 9.29 N-80 4004.43 3997.88 6.55 Camco K-Bug GLM 3997.88 3276.36 721.52 24 3-1/2" 9.2~ N-80 3276.36 3271.21 5.15 3-1/2" 9.29 N-80 3271.21 3180.12 91.09 3 3-1/2" 9.2# N-80 3180.12 3173.57 6.55 Camco K-Bug GLM 3173.57 2103.34 1070.23 35 3-1/2" 9.2# N-80 2103.34 2096.79 6.55 Camco K-Bug GLM 2096.79 299.96 1796.83 59 3-1/2" 9.29 N-80 299.96 297.46 2.50 Otis 3-1/2" Ball 297.46 50.19 247.27 8 3-1/2" 9.29 N-80 50.19 47.76 2.43 3-1/2" 9.29 N-80 47.76 44.56 3.20 3-1/2" 9.2# N-80 44.56 43.70 .86 Camron Dual Tbg. 43.70 0 43.70 Landed Below Zero Butt Tbg. Butt Tbg. Butt Tbg Pup Jt. Butt Tbg. Butt Tbg Pup Jt. Butt Tbg. Butt Tbg. Butt Tbg Pup Jt. Butt Tbg. Butt Tbg. Butt Tbg Valve Nipple Butt Tbg. Butt Tbg Pup Jt. Butt Tbg Pup Jt. Hanger ,(' STATE OF ALASKA O( AL .~A OIL AND GAS CONSERVATION C ..VlISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [~ Other 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California 99'RT above MSL feet 3. Address 6. Unit or Proper, ty nam_e P. O. Box 190247 Anchorage, AK. 99519-0247 Traalng ~ay Field 4. Location of well at surface 1409'W & 1806'N F/ SE Cor. At top of productive interval , T29N, R9W, RBW,S.M. 7. Well number 8. Permit number Location Location effec~v02~;p~h& 147'S F/ Surface At 2654'E & 496'E F/ Surface At total depth 2683'R ~ 516'.q ~/ .q~]rt:am.~_ 11. Present well condition summary Total depth: measured 10,790feet Plugs (measured) true vertical 10,241feet Effective depth: measured feet Junk (measured) 10,706 ,,,.,, true vertical 10,165f~' Casing Length Size Cemented Measured depth Structural 360' 26" Driven 360' Conductor 605' 20" 2215SX 605' 9. APl number 133 ' 501 1 ,~'3 -~',~'~'~ ,~ ~ qO. Pool Mc~thur River Fiel~ Surface 4511' 13-3/8" 2650 sx 4511' Intermediate Product[b~,090 ' 9-5/8" 2000 sx 10,090 ' Liner 792' 7" 200 SX 9962'-10,754' Perforation depth: measured SEE ATTACHED true vertical True Vertical depth RE£EI /EI) t98'7 Tubing (size, grade and measured depth) AlaSkS. 0il & GasCons. Coral1 (LS & SS) 3-1/2", 9.2#, N-80, LS @ 9985", SS @ 8722' Anchorage Packers and SSSV (type and measured depth) Otis RH Packer @ 9916', Guiberson Dual Hyd. Packer @ 8711'. Otis Ball Valves @ 313' & 325'. 12.Attachments Description summary of proposal ~1 Detailed operations program [] BOP sketch ID~ 13. Estimated date for commencing operation Nevem_~er ! ~ 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true an(~ COlirec_~t"to the best of my knowledge Signed /z~/'~ ~ ~ q~tle Environmental Engineer Date //Y/RQy D. Ro~rts ) Commission Use Only ~ Plug integrity ~ BOP Test ~ Location clearance ~ ' ~ I Approved by Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date/~ Submit in trip. licate~, TBUS G-33 Perforation Record MD 9026' - 9046' 9073' - 9090' 9138' - 9164' 9196' - 9250' 9294' - 9362' 9416' - 9434' "G' ZONE 8654' - 8672' 8697' - 8712' 8755' - 8778' 8806' - 8854' 8893' - 8953' 9000' - 9016' 10,086- - 10,092 ' 10,105' - 10,132' 10,203' - 10,286' 10,376' - 10,475' 10,512' - 10,544' 10,593' - 10,625' WEST FORELAND 9601' - 9607' 9619' - 9643' 9707' - 9782' 9864' - 9955' 9988' - 10,017' 10,062' - 10,091' 0391N RECEIVED OC'[' ~ 2 A/aska 0ii & ~as Cons. Cornrnissior~ ~chorage TBUS G-33 PROCEDURE: 1. Rig up over TBUS G-33, leg #3, slot 911. 2. Kill well. 3. Remove tree, install and test BOPE. 4. Pull and lay down existing dual 3-1/2" completion equipment. 5. Clean out fill to 11,345'. 6. Reperforate West Foreland sands from 10,086' - 10,625' at intervals. 7. Reperforate "G" zone from 9026' - 9434' at intervals. 8. Run new 3-1/2" dual completion equipment with chemical injection strings. 9. Remove BOPE and install production tree. 10. Return well to production. TIME: · ,,, , 16 days ~0390N Unocal Oil & Gas DivisNIf:' Unocal Corporation%'~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Environmental Group Alaska District July 18, 1986 Ms. Elaine Johnson AK. Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ns. Johnson: Listed below is the information you recently requested on the status of the following wells: : GPS ll-13 Hemlock zone'shut in, not abandoned, The well is still producing from the Granite POint Sands. TBS A-lO & A-16 Sundry notice to abandon.A-lO & A-16 submitted Harch, 1984. The abandonment was never performed. TBS A-23. A-23S shut in since September, 1983. A-23L has just been shut in. This well is not abandoned. G-23RD, G-33 & G-34 Dualstring producer. Hiddle Kenai "G" shut in Harch, 1984. K-21RD Dual string producer shut in July, 1983. The well is not abandoned. K-30 Dual string producer, Hiddle Kenai shut in July, 1982. The well is not abandoned. If you have any further questions, give me a call. Very truly yours, Candace LockwOod 00280 RECEIVED J U L 2 1 ]986 Alaska 0~1 & Gas Cons. Commisslo. Anchorage UNION OIL & GAS DIVISION WESTERN REGION AN C}IO RAG E D I S T R i CT TO' State of Alaska FRObl- G. H. Laughbaum, Jr. TP~ANSblI TTAL DATE' May 14, 1970 WELL NAME' TBU G-33 (13-28) Transmitted herewith are the following' Run No. Final Sepia Blue Scale I I Induction Electrica. 1 Log ---2n- Dual Induction Laterlog BHC Sonic/Caliper Log BHC Sonic/Gamma Ray BUC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDH Safety Print CDH or Printout CDM or Polywog Plot CDH Polar Plots Proximity Microlog/Caliper Log Gamma Ray-Neutron Log Ganuna Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut RECEI PT ACKNOWLEDGED' RETURN RECEIPT TO' ~/~--____ DATE'___ "ff-/~'"'" 70 Union Oil & Gas Division - Western Region Anchorage District P. O. Box 6247, Airport Annex Anchorage, Alaska. 99503 ATTN: ROCHELLE CARLTON l~orm No. 1:'--4 , STATE OF ALASKA OIL AND OAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPEi%ATOR Union Oil Company of California 3~ADbRESSOFOPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. LOCATION OF WELL Conductor #11, Leg #3, Grayling Platform, 1806'N & 1409'W from SE corner Section 29, T9N, R13W, SM. ~ ~ HLB ........ TRM ~. APl NUA{EE/CA/~ CODE KLV 50-133-20212 HWK_ ~___ 8. g-NIT F.~RA~ OR LEASE NAME Trading Bay Unit 9. WELL NO. State G-33 (13-28) 10. FiF_J~D A.ND POOL. OR.%~;I~DC_~LT K ' "-" ...... pll~ale enal ~ Mcartnur xlver-west Foreland 11. SEC., T., R., 1%{., (BO'I'I'OM HOLE OBJECr~) Sec. 28, T9N, R13W, SM. 12, PERMIT NO. 70-11 13. REPORT TOTAL D~/~{ AT E/~D OF MONTH, CIiA~NG~.S IN ~OLE SIZE, CASING ~ C~TING JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~O~TIONS, ~TS ~S~L~S~.,-.FISHIN~<~O~,cJ~K ~ HO~ ~D SIDE.~C~D HOLE AND ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~IT~ONS~ ,,, [~,~, ,.[7 '~[ '~[~'~' ........ T~ING BAY UNIT ,S,~TATE G-33, March_ 1~970 Continued drlg 12-1/4" hole from 9484' to 10,070'. Ran Schlum DIL, Sonic, density, and SNP logs.- Drld 12-1/4" hole 10,070' to 10,090'. Ran 9-5/8" 43.5# & 47# N-80 & P-110 csg. Hung w/shoe @ 10,090' & cmtd w/1750 sx Class "G" w/l% CFR-2 followed by 250 sx Class "G". ~CIP %2:30 Pm 3/8/70. Landed csg. Instld tbg head. Reinstld BOE. Tstd OK. RI w/da. Drld out shoe. Drld 8-1/2" hole from 10,090' to 10,790'TD. Ran Schlum DIL, FDC, BHC sonic & SNP Logs. Ran & cmtd 18 jts 29# N-80 buttress liner. Liner hanger @ 9962', shoe @ 10,754', landing collar @ 10,706' . Cmtd w/200 sx Class "G" w/l% CFR-2. Bumped plug w/3000#. Floats held OK. CIP 10:30 Dm 3/12/70. Ran 8-1/2" bit & scraper. CO cmt to top of liner @ 9962'. ~k~ W/~"~ bit & 7" Scraper. CO to 10,706'ETD. Ran Dresser-Atlas corr. log & CBL. Set EZ drill BP @ 9650'. Perfd @ top of Hemlock @ 9470' for block sqz. Set cmt retainer @ 9430'. S9z cmtd in 2 stages total 225 sx cmt. Max press 4000#. Final CI~ 9:00 Dm 3/%5/70. woc. DO cmt retainer @ 9430 & cmt 9432'-9475'. DO BP @ 9650'. CO to 10,706'ETD. Spotted 157 bbls Invermul. Dresser-Atlas perfd "G" & West Foreland using 4" thru csg guns 4 hpf: 9026-9046, 9073-9090, 9138-9156, 9158-9164, 9196-9250, 9294-9362, 9416-9434, 10086-10092, 10105-10111,'10117-10121,10126-10132, 10203-10206, 10210-10212, 10219-10223, 10231- 10235, 10242-10250, 10269-10276, 10282-10286, 10376-10402, 10414-10428, 10434-10475, 10512-10528, 10532-10544, 10593-1062.5. Ran & t~nded dual strings 3-1/2" buttress tbg w/tail @ 9985', btm single hyd pkr @ 9916' & top dual hyd pkr @ 8911. Long string 321 its & short string 280 jts. Instld & tstd Cameron 18 "S" 1500 tree. Disp mud w/diesel. Set & tstd pkrs OK. Long string flowing fm West Foreland zone & short string flowing fm Middle Kenai"G" Zone. RIG RELEASED @ 12:00 Midnight 3/18/70. with the Division 5f Mines &~inerals by the 15th of the succeeding month, unless otherwise directed. STATE OF ALASKA OIL AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG* \v EI.L Xv E[,L ~ DRY Other b TYPE OF COM?LET]ON: WEll. ¢)\'ER ~ EX ~ BACK ! .' RESVR. Other __ ~ NAME OF OPIrRATOR Union Oil Company of California 3. .~.r/DR£S.R OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. ~.OC.*TI:)N OF w£!,L (Report location clearly and in accordance with a,y State requirements)* A! traceConductor l~,~Leg 3 1806'N & 1409'W from SE corner Sec ~8, T9N, R13W-o~v~. '.:.::: Xt :, p prod. interval reported below SOU:~'h From surface location: 355' & 2434'East :~t total dep~ From surface location: 515' South & 2682'East ~'. D.-YTE SPUDDED 114. DATE T.D. R~CHED [15. DA~ COMP SUSP OR ABAD. 2/5/70 [ 3/11/70 [ 3/18/70 10790 & 10240'I10706MD& 101631% aowM~. ~. PRODUCING [N~RVAL(S). OF ~.IS COMP~TIO.N~O,P, BOSOM. NAME fMD A~D ~)~ West Foreland 10,086'MD & 9599'~D -- 10,625'MD & 10,089'~D ., TI~M SUBMIT IN DUPLICATE' ~ ~ · ..s~. .... ~h~,- LONG STPT~'.T~C: COMMITT[[ ADL 18730 7.iF 1NDI~. 8.UNIT,F~ OR L~kSE ~adin9 Bay Unit State 9. W~L NO. G-33 (13-28) 10. F~ ~D POOL, OR WI~CAT McA Rjr-West Foreland 11. SEC.,T.,R.,~.,(BOTTOM HOLE ...... ;'~ Sec.28, T9N, R13W, SM. . 12. P~'IW NO. 70-11 t 16. ~EVATIONS ~DF, RKB, RT, GR, ~TC)' ~17. E~V. CASINGHEAD RT 99' above MSL I 59' above MSL INTER~:}ALS DRILLED BY CABI,E TOOLS 0 ,23. WAS DIRECTIONAL ~ SURVEY MADE I yes : 24. Tx.'PE ELRCT[:IC AND OTHER .LOGS RUN . DIL', FDC-GR, BHO'SONIC, SNP,& CBL 2,51 'I~ ~ ' CASING RECORD (Report all strings set in well) SIZE 0086-10092 0105-10111 0117-10121 0126-10132 0203-1020~ 30. WEIGI~T, LB,FT. ~ "GP~ADE I DEPI~I SE~" 61g 1J-55 ] 45'11' ' 9-5/8" .~3.5 & 47g IN&Pll~ 10690'' i 1 26 LINER R~CO~ 7" ~¢b2~' 10'/5~' 28. PERFORATIONS OPeN TO PRODU~ON (D~terval, size and number) 10210-10212 10282-10286 10219-10223 10376-10402 10231-10235 10414-10428:10532-1 10242-10250: 10434-10475 10593-1 PRODUCTION . DATE F'iR5T PN.ODUCTION [ P~ODUCTION MEIHOD ~FIo~'.~}iPg. K:.:3 lift, p~mp[ng.'size and type of pump, 3/21/7 [ flgwing ~ DATZ OF T~ST, ~URS 2'ES'I'~ "ICI!OXE SIZE [Pf%OD'N FOR Oi~BDL. .... 3/21/70 1.2 [ I1873 I 363 FLOW. TURIN(> CASI. NGP~ESSUR~ [CALC~ OII~BBL. GAS---A~CF, "~s~ 30 0 t'~-a°u~ ~*vz [ 3746 '1 726 3] DlSPt, sl'rlox OF CAS (Sold, uaed lor /ue4 vented, etc.) 32. i. IMT OF ATTACHMENT8 ' HOLE SIZEI Cr'.U\5 EN TI N G RECOP~D i ~k?.I©UNT PULLED 26" I ZOO0 sx + 65 sx top job ii, none 17:'1/2"[ 2000 sx prlt ¢ 1000 sx "q' nor:~f 12-1/4"1 2000 sx "a,' w/l% CPR-2t no"ne SCREEN (3**D~ SIZe. DEPTH SET t3fiD~ i PACKER SET 3-1 2" : ~85' ' ~16' ACID. Si:CT, F2A~ O'~E, C~,iE~ 8.Q.U~Z~, ETC. D~-'/Ii IN'!~V.~ (MD) AMOUNt 2~,~I'i~D~,OF A~AIEP~A~-US~ 544 kT/A : . :.) ,,, . [625 . IV, ELL STATUS (Pr0duci.~g; or proaucing WATER--BBL. [ GAS-OI[~ IIATIO I 16 j 194 WATER--BBL. [ OIL GRA. VITYo A.PI (CORR.) 32 I 31 tTEST WITNESSED B~ T. K. :'~:'~ uir :I,. I horeby certify that the for~golgg/$nd attach.ed tj~t)rmation is complete and correct as determined from all-lvatlable records '/ ,~ //( /' SICNEI,' . TITLE .Dis t, _Drl¢_S up_t D^T~:: 3/2_4. ~_7.._O *(See Instructions and Spaces for Additional Data on Reverse Side) General: This form is designed for subrnitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr0:~:or depth measure- men~s given in cther spaces on this .form and in any attachments. Items 20, ar~cl 112:: If this well is completed for separatc production from more than one interval zone (multiple completion), so state in item 20, ,-~nd in item 22' show the p~cJucing .intcrx,~! or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit .,,%}eparate report (page) on this form, adequately identified, for each additional interval to be seperatel~:produce<J, show- ing the ackiitional ~ata'pertinent to such interval. . It~,m26: :"Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. It.m 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ~4. SUMMARY OF FORM^~bN ~ES'I'S :IN¢'LUm~; '~NTERVAL T~TED, PH.~URE DAT'k ~ ~OV~I~ OF OIL, GAS. ,-c. 35, G~GIC MARK~ WAT~ AND MUD ,,, ~:,~ NONE Middle Kenai "G" 87 20 83 H e m 1 o ck 9 5 0 7 9 () West Foreland 10020 ~:~ . : .: . ). . AND~EII~CTEI) SIIOWS OF OIL. ~S. Otl ;.: . : NONE , i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* SUBMIT IN DUPLICATE* STATE OF ALASKA (s ...... th~,-~--'~~(??" /./~.'i,":r:~'"~-~ OIL AND GAS CONSERVATION C(:;i:~M,: .... ~-~:., ADL 18730 \v ELI. vv ELL DR ¥ Other b. TYPE OF' COMPLETION. \vE[.i. , .' OVER ~_~_Ex' ~ BACK P. ESVR. ()thor_ 2. NAME OF 0P£RATOR Union ©il Company of California ADDRESS OF OPERATOR 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 4. Lo¢.~r~o.x oF n'£LC '(Re~or~ tocation c~ear~y and in accordance with any State requirements)* ~t~Conductor 11, Leg 3, 1806'N & 1409'Wfm SE cor Sec.2 7. IF INDIAN. ALLOTTEE OR TRIBE NAJVI~ 8. UNIT,FAI~I OR LF~kSE N&ME Trading Bay Unit 9. WELL NO. State G-33 (13-28) 10.FIELD AND POOL, OR WILDC.,kT McA Riv- Mid Kena i "G" T9N, R13W, SM. At top prod. interval reported From surfa ce...location: At total depth From surface location: bel o w 148'South & 2008":~ast . $15'South .& 2682'East OkLJ Ec~'I'] V E) Sec. 28, T9N, R13W,oM'::"" ELEVATIONS ~DF, RRB. R.T, OR, ~TCJ'tlV. ELEV. CASINGttEAD RT 99' above 'MSL I 59' above MSL INTER'CAI.$ DRILLED BY:. 'i .:~A BI,E0 TOOLS 23. %VAS D!I~ECTIONAL SURVEY 1Y~A DE ye s 1Z. D.~TE SPUDDF_,D114. DATE T.D. RF.~CHED [15. DATE COMP SUSP OR ABAND. 2/5/70 [ 3/11/70 I 3/18/70 ltj. TOTAL DEPTH. NLD& TVD[19. PLUG. BA.C'K MD "~ T%rD~0. I.F MULTIPLE COM.PL.. In. / ! HOW I~IA.NY'I ROTARY TOOLS 10790' & 10240' I}0706'MD & l'0163.~rVD 2 0-10790' Z2. PRODUCING I.~T'ERVAL(S), OF TI-IlS CO.MPLETIO~--TO~P, BOTTOM. NAME (MD AND TV'I)), Middle Kenai "G" 9026'MD & 8652'TVD -- 9434'MD & 9015'TVD 24. TYPE EL,ECTRIC AND OTHEI{ LOGS RUN DIL, FDCXGR, BHC-S©NIC &'CBL __ ! , CASING RECORD (Report all strings set in well) CASI~4G SIZE I WEIGHT, LB, FT 20" 94% ' LINEX 1R~E C O I:LD SIZE [ TOP 7" [ 9962' fGI{ADE IH-40 ' l l-SS IN&PllC ! EOT'I'O~/i t MD ~ ! 10,754' DEPTH SET (M.D) i 28. PER. FORATiONS OPV. ZN TO PRODUCTION' (interval. size and 'r.u/mbef~] 9026-9046 9196-9250 9073-9090 9294-9362 9138-9156 9416-9434 9158-9164 : 30. P R. OD UCTION HOLE SIZE [ CEhM[LNTING RECO~LD [ fO.qOU.,~'T PULLED 605' 26" 120.00 sx + 65 sx top.job I none 45~1' [17-1/2"12000 sxorlt+ 1000 sx.'.'G"~ t0,090' [!2-,!/4"[2000'sx-Gw/l% CFR-2 t none 27. . TUBING RECO;~ DEPTH SET ~'iD~ ~ PACKER SET SACKS CE).iEXT* SCii~ t~D~ SIZE , . '29. " ffCID, Si!OT. Fi~AC2 O'RE, C~,I/XT SQUEEZE, ETC ~ D~I~i II{T~V.~ (MD) AMOUNt ~k~D !'2!ND OF MATEPJAL US~ , , ,9470-71 325 sx "G" w/l% CFR-2 Sqz standing press 4000 psi ,..[ ,,,', i, ii i DATE FiEST P!~[©DUCTION [ FrP~ODUCT1ON ME/HOD ~Flov.'h~g. Faz !if(. pumping--size and type ofj~pump'* 3/21/70 .~.. flowing , ,,,~ ,~ ~,~, ~ou [cnoxEs,Z~,: ]T~~? I 814 l ~%k,'. TUEING CASU~O PRESSURE [CALCL~T~ 'O~I~BBL. GA~-~. ~1. D~SPOSI'rION OF GAS (SOld~ used f~r fuel, vvntvd, etc.) 32. LiST 0t ATTACHMENTS I l'. ELI, STATUS (Producing or unu~-in) · .~ produCinq ~?~'JI'ER--BBL. [ GAS;OIL~ IL%TIO 2SS ] 12-1/2I '313 WA_TE1R.--EBL. [OILGRAVITY-APl (COlq. F..) ] 25 I 31.5 -~ ..... ITEST WITNESSED BY T.K. Muir , hereby certify thatCe foreg~,in~a,~¢l attached lnf4~matlon is complete and correct as determined from alFavatlable records ......... . ---- TITLEDiSt.Tall SlC,.~:~, Drlq. SU__pt m~'rl:: 3 2 70 , *(See Instructions and Spaces for Additional Data on Reverse Side) I i'~! ~ I Kuq., I . General: This.form is designed for subr'nittin~ a complete ar'~d correct well completion re~o~ and log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, an~l 22:: If this well is completed for separato production from more than one interval zone (multiple completion), so state i.n item 20, and ir'~ iter~:~. 22 show the p,c. Juci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Subrri:i? a separate report (page.) on this form, adequately identified, for each additional inte, val to be seperately produced, show- ing the ackJitional data pertinent to'such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. -. Item 28: Submit a separate completion report on this fOrm for each interval to be separately produced. (See instruction for items 20 and 22 above). ..... ~4. SUMM~RY O1~ I~O~VIATi~N TF~S'I'S INcLui~iN(; 'INTE~VA~ T~E~'. p,~URE DA~ ~J~ovERI~ Or"0i~ 8AS.- .... WAT~ AND MUD MEAS. NONE Middle Kena. i .. ,,G,, 8720, : Hemlock 9507' . . --/ i i i i ii iii i ill iii ii- i i i i i J ii ri' 3~. COB.E DATA, A]~'ACl[ ~RIEF D~R~P~NS OF LI.TI.IOLOGY, PORO~TY. FRAFW~. A~~ ~' '. : AND D~I) SIlOWS OF OIL. GAS OR XVA~. NONE , , .......... UNion. oil co. of DRILLING F~ECOlqD SHEET A PAGE NO... FLEA.qE TBU State ' V~ELL NO G-33 'E';~D McArthur River ' '' --- L.._7 ..... Leg 3, Conductor 11 rom orne , TgN, R13W, SM; PERMIT N~. 70-11 T.D. 10790 DEVIATION (B.H.L.) COMPed%Ur ENGINEER SERIAL NO.~ 50-133-20212 T.V.D. ;t~ ~ ~ o. Ash, Boykin SPUD DATE 2/5/70 COMP. DATE 3/18/70 CONTRACTOR WODEC0 ' RIG NO. 54 TYPE UNIT National 1320 UE Rotary DRILL PIPE DESCRIPTION 5" 19.50E with 4-1/2'I.F. ELEVATIONS: WATER DEPTH IL T. TO OCEAN FLOOR IL T. TO MLLW II. T. TO DRILL DECK ILT. TO B.E. Talley) · : BIT RECORD ..... MUD ~/EL:' DEPTH & DEVIATION ~IT JET DEPTH] VERTICAL DATE DEPTH NO. SIZE MAKE TYPE SIZE OUT FEET HOURS ANN. · JET DIRECTIONAL ~ _ 2/6/70 630 irr I5" HTC OSC-3J 3-24/3:: 630 630 8 i50 300 Drid conductor hoie 7 630 HO1 26" servco Expndb:. HO 630 260 3 Opened 'hoei for 20"csg. 9 2465 2 i2-i/4". HTC 0SC3A3 3-i8/3:~ 2465 I845 23-i/;:I60 380 T-5 'B-2 9 ' 2961 3 .... " " 296I 496 7-I/2 i60 380 T-5 B-2 ~ lO 3173 4 " Reed STIAG3 3-24/3: '3173 212 5' DDric T.2 B-i (520 gpm) lO 3S3~ 5 ,, Giobe ST3G'3 3-i6/3:.. 3838 665 9 120 346 T-7 B-4 IN ... ' ll 3985 ~6 " Reed STIAG-~ 3-24/3: 3985 147 6 DDrid T-7 B-2 IN 11 4500 7 " -' Globe ~;T36-J 3-16/3: 4500 515 5 160 380 T-5 B-4 IN 12' 3040 HO2 17-1/2" Smith 6 pt - 3040 2435 22 60 - opening surf hole II II I' 13. 4520 Ho3 " Smith 6 pt - 4520 1480 19 60 '- 15 4520 18 12-1/4" Globe ST3G 3-15 486.0 340 7-1/2 120 377 T-8 B-7 1/8" out 17 4860 9 " Globe ST3G " 5460 600 9 118 371 T-5 B-4 ~ 18 5460 10 "' Globe ST3G " 5764 304 7 118. 371 T-5 B-3 18 5764 11 " Globe ST3G " 6137 373 7 105 330 T-5 B-5 - 19 6470 12 " Globe ST3G " 6470 333 7 103 330 ~T=6 B-4 19 6688 13 " " " " 6688 218 5 105 330 ~-7 B-5 1/4"-out "l 20 6969 14 " ,, ,, ,, 6969 281 7 105 330 T-6 B-3 1/8" out -' 20- ' 7198 15 " " " " 7198 229 6 105 330 F-6 B-m.,..l~_'_~_OUt 21 ' · 7565"16 " '~' "' " 7565 367 10 103 330 T-6 B-5 1/4" out 22 76'27 17 ,, Reed ST1AGJ 3-24 7627 62 9-1/2 DDrld T-4 B-4 . 2'2 7890 1~ ,' Globe ST3G 3-15 7890 272 9 105 330' T-6 B-3 OK 23 8089 19 ,' Globe ST3G 3-15 8089 199 7-1/2 105 330 T-3 B-5 OK ' 24 8313' 20 " ~Globe ST3G " 8313 224 8-1/2 105 330 T-6 B-6 1/8" . 24 '' 8476 21 " Globe ST3G . " 8476 163 6-1/2 105 330 T-6 B'-4 1/8" '"25 8626 22. " Globe ST3G " 8626 150 7-1/2 105 330 T-5 B-5 OK 25 8626 23 " " " " 8720 94 6 105 330 T-6 B-3 OK 26 ' 8720 24 " Smith DGH " 8851 131 8 1105 328 T-7 B-3 OK ~ , 26 8851 25 " ,, K2H " 8978 127 5 105 328. T-5 B-4 ' ' 27 8978 26 " " " " 9118 140 8 105 328 T-4 B-5 ~ 27 9118 27 " " " " " 9252 134 8' 105 328 T-8 B-5 28 9252 28 " " DGH "' 9381 129 7 105 328 T-6 B-4 28 9181 29-' ]-~ " " " '" 9499 118 7-1/2 105 328' T-4 B03 3/1/70 9499 t3''0 ,, ,,' K2H ,, 9561 62 9-1/2 105 328 r-6 B-4 1/8" 1 9561131 " HTC XD7 ". 9623 62 110-1/2 105 328 T-4' B-2 OK 2 '" 9623 32 I '~ Smith K2H " 9678 55 7 105 328 T-6 B02 1/4" 2 9678 33 " " V2H " 9728 50 6-1/2 105 328. ~-7 B-4 1/8" 3 '" 9728 34 " " 4JS 3-16 9833' 105 19 105 288 r-8 BL3 ]./8" ~ '4' I 9833 35 " " ' 5JSRB " 9838 5 3 105' 288 r-1 B-1 would not drl '' 4 9838 36 " HTC XD7 " 9910 72 9-1/2 105 288 r-5 B-2 1/8" ,, 5 9992 37 " " " " 9992 82 9-1/2 105 288 ~-6 B-1 OK '' 6 1004(38 " " " " 10046 54' 9 105 288 r26 B-2 OK " 7 10070 39 " Smith 'K2H " '. 10070 24 2-1/2 105 288 r-3 B02 OK .' 7.. 10090 40 " ,,. U2H " 10090 20 ! 2 105 28'8 r-1 B-1 ..~ Ran 9-.5/8" c~sing " 9 10194 41 8-1/2" Globe MT3G 3-12 10194 104 6-1/2 215 ~00 r-6 B-3 i/8" 9 " 10382 42 " Globe " " 10382' 188 7 !15 400 T-8 B-8 1/4" 10 10492 %3 " Sec. SHTG " L0492. li0' 6 215 400 T-8 B-5 1/8" 10 10618 ~4 "' Sec. S4T. G " 10618. 126 7-1/2 215 400 T-7 BL4 OK .... 11 10681 %5 " Sec. d4NG " 10'681 65 8· 215 400 T-4 B-4 OK , .... 11 10790 %6 I ' ' ;lobe ST3G " ' %0790 109 7.. 215 400 ....... -13 10790 $7 ,, ]lobe nt3G ;-16 ~62 CLEANED OUT ~MT ..... T~13 10906 ~8 'l6 .~TC DWV Reg L0706 CLEANZD OUT s~r , , , . ,,. .., . 125.00 235.60 110.60 19.30 . .i 60 U IN. t k. Jl~ · · . f"", MUD RECORD o . Tra~ing' Bay Unit State ,. ~ASE, I..o~ 8olids Lignobulf0nat~ WELL'NO~ G-33 ~PE PAgE NO FIEbD McArthur Rive~"~ield -. P.P.1. DISTRIBUTOR ~ WEIGHTJ PH SALT ' OIL SAND SOLIDS REMARKS '63 .65 Inlet Water 'Gel Drld & opened 2~" 6Ondu~t°r· hole '-8 2121 77 44' ' 1-3 8' '113000'.I' - ~ 7 ' Drld ~rf.hole ~ 9 J -- .3093 76 J 4'1 ......12. 0 9 13000 --' 3 8 ~- 11 4500 ' 75 " 42 I 6.8 " ,9.5 11300'0 , 0 III3 8 ' F'ini'.~h~..d isurf hole ' I I I I I · - 1-.2 45000 79 4J 6.2 9.5 13000 0 3 '9 'Opened.,-,h.0!,,,e ~ i3 4520 75' ' 45-- "4.6 9.0-/13000 j' 0 3 9L Conditioned for 1.~-3/8" csg '14 ~520 -- ) 5 I ' 45 4..6 .9.0, '113000 .0 3 9 · 17' 52~0 : 72. 45 ' I 6.2 I 10' 5 12000 '0 2 6 . "i8 ' -I5975 73'' 51 6.~I 10' 120-00 b- 1 ' ~ 8 ~ i9 6688 I I 75 47 ' 6.2 J J 9'5 112000 0 i 10 ' II I 'I j ~:20 7198 7J 46. ! 5~0 ] 9.5 112000 ' "O ~' 9 "21 7593 75 45 -5.2' 9.0 '12000' -0 ' 1 9 --22' 7890 75 45 4.8 9..0 12000 0 1/2' ' '23 81'32' 75' 47 " 5.'2 " 9.0 12000 0 ' 1/2 9 ...... · ...... · 24' ' 8515 75 i 49 4.6 · "9.0 12000 0 I 1/2 9 - 25 ·8750 75.5i 50 ' '4;6 9.0 12000 0 ' ~/4 10" I ....... " ' ~: 26 8970 ' 77' 45 .... ] 4.7' 9.0 12000 0 2' I' if i DIesander dbwn. to~' rprs ' I -28t 943.5 76 :46 } j '4.8 9~0 12000 , 0 ' 3/4 1117q 9570" 77J' 54 ..... j"4.'9' 9-;'0 '12000 j 0 j.1,-i/4 J.l .. . . ........ Z 9~58 j '75 I 45" II" 4.8' 19.0 ...... 12000 j '0", _ j_3/4., i0 -- ~ ~ '''872mm ~ 75 : 5~ '~ 6 ~ 4 . ~ ~ ~. 0' i 2000 ~ I 0' j3/4 10 j ~ -- .... 5" 99'92I ~'76.51 45 j 4.8 19.5 Ir2-OoO j 'o il/2 9' ~ J ~ .... :o07o"1 75 j 48 j"4.6 ~.0 il2000 j 0I ~ ' 1 /2 9 j Logged .... 9 10382 75~I 147 4'9 19.5 ~2000 ....j 0 Z /2 10 J 10638 7.5'. 4'7'. '4.8 9.5 ".j12ooo 'l .... 0 j Z /z "' 11 10790 '''75 :47 '4';8 9'5' 12'OO0 ' ----0 '11/2 ~ jbogged ....... . ...... 12 10790 .... 75 j 48' 5.0 9 12000 I I L0 ' l/Z . 9 I II ~ Ran &'Icmtd 7" liner 13 10790 '70'[' 36 ' ".1'~.8 ..... , ...' bwrd'wt prio~ to'"spotting i~'Vermul _.. 16 107'90 ..73'.5' '~. 0 I .' ..... I ' '] i'nve.rmul " 'j . · · . · · __ .._ _ ............ · .... . ......... .. ..... .. . . · · · i · .... · · , ............. . . . _ - . · · , · . , · I UNIOI ,r' DIL CO, OF CALIFOk,.:IA DRILLING RECORD SHEET D 4 PAGE NO, · LEASE. DATE 2/5/70 · Trading Bay Unit State E. T. D. 446' 620( 620' 2121' 3093' 3902' 4500' 4500' 10 . : '14' -' : . -.. · 4520'- ~V~. LL NO. G-33 FiELD.i.McArthur River Field DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS 4511' ~U Woden@ Rig #54 on Conductor #11, Leg #3. Landed riser assy on 36" wellhead flange. PU B.H.A. & RIH to cmt @ 321'. Drld out of cmt below conductor 6 365'. Drld 15" hole to, 620'.-P~ 24" mill & worked thru shoe fm 295-365'. RIH w/26" Servco ex~andible HO & opened 15" hole to 26" fm shoe @ 26" conductor @ 360' to 620'. Disp high vis gel mud into hole & poh.. RU to run 20" csg. Ran 14 its 20" 94# 8rd csg w/Howco stab in cmtng shoe & landed in Cameron 24" landing hub @ 43' (shoe @ 20" @ 605'). RIH w/5" dp & Stabbed into cmtng shoe. Lost returns while breaking circ. Mixed 1000 sx "G" w/3% CaC12. & 650 sx "G" neat. Mixing & pumping time 2 hfs & no returns' tO surf while .cmtng. CIP @ 11:30 pm22/6/70. POH w/5" dp. Le~t 30' ft3 cmt in csg. 2.70 555.42 4.70 26.45 18.35 607.62 - 2.50 605.12 , 20" CasinR Detail '-' ' .. ...... . . 20" Howco Stab in type cmtng '~hoe i4 j.ts · 20" 94# H-40 8rd csg 24" Cameron csg hngr + 20"'csg Nipple 20" Landing Jt + Left Hand thread rng tool 20" LandinR ~oint Landed above rotary Setting Depth StriPped 26" riser assy off 20" landing j't. Backed off rng tool & pulled 20" landing jtS~ Spotted 65 sx Class "G" w/!% CFR-2 in top of annulus with 3/4" tbg. NU 20" riser ~ssy w/rng tool & 20" 3000# Hydril. RIH with 12-1/~" bit & found no ,cmt above-shoe. POH. PU stab in sub. RI & stabbed into shoe @ 605'. Cmtd w/500 sx Class "G!' w/l% CFR-2. CIP @ 12:30 pm 2/7/70. ~U B.H.A. & RIH & circ & conditioned mud while WOC.12 hrs. Tagged top of firm cmt @ 590'. Tstd csg& Hydrii w/750#. Drld 15" firm cmt below float shoe. First Sperry Sun Gyroscope Survey @ 646'. Drld & surveyed 12-1/4" hole 620-2121'. . · . D & S 12-1/4" hole-2121' to 296!' w/trip for new bit.'@ 2465'. Trip for DDrl @ 2961'. ' ,.- · - . Completed kick off ~/DDrl @ 3173' RIH w/building ~SSy. Hole walked right in ~65'. Trpd for DDrl to ~°rred for-right .hand turn. _ . Ran DDrl 3838'-3985' to correct direction. Drld to 1~-3/8" csg point. Picked up 17-1/2"'HO~· ' -'-. · . . Opened 12-1/4" surf hole to 17-1/2". Trpd for new HO @ 3040'. . Finshed opening 12-1/4" hole to ~7-1/2". Circ .btms up & made wiper 'trip. SLM out of hole & corrected + 20'. RU to run 13-3/8" csg. .. .. . · Ran 113 its 13-3/8" 61# J-55 cst. Landed same w/cameron 18-3/4" OD boi~ Weevil hanger in 17-5/8" ID landing hub @ 42.60'. Cmtd w/2000 sx Class "G" w/6% gel, 1% D-3.1 & 16 ft3 / sk perlite + 650 Sx Class "G" CFR-2 Did not open DV since we did not lose returns while ¢irc or cm~ng. Disp ~mt w/.3&20 fi3 mud & bumped plug w/2000#.' Cmt"r~ts to surf. CIP @ 1:30 pm 2/15/70. ND 20" Hydril & 20" riser assy. Cut off 13-3/8" cst & made up Gamexon "WF" cst.-12" 3000# x 13-3/8" slip on weld with 32" landing base. UNIOF OIL CO. OF CALIFOk,:IIA DRILLING RECORD ,, SHEET D PAGE NO. 5 · LEASE Trading Bay Unit State %%,qgLL NO.L G-33 FIELD McArthur River Field DATE E.T.D. 2/15/7o 4511ETi 4520' 18 19 2-1 5340- 6012' 6688' 71.4 8' 7593' 789O' :. 8132' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS H°wco "Reg" cmt float shoe-self fill 14-1/2" OD x 2-1/2" ID 13-3/8" 61# J-55 buttress csg. Howco "E" cmt fioat collar-self fi11-14-1/2" OD x 2-1/2" ID 13-3/8" 61# J-55 buttress csg. Howco "DV" multistage cmtng collar 15-1/2!' OD x 10-1/2" ID 13-3/8" 61# J-55 buttregs csg. Cameron Bowl-weevil csg hgt. 18-3/8" OD x 12-5/8" ID D£stance from'csg hngr to Rotary · Setting Depth -33.73 1-.75 3471.49 2.30 ' :-: ' 13-3/8" Casing De ail Zj. . '. , 88 its ' ' .. . 956.56 1.00 42,60 4511.39 NOTE: 24 its · Ran three centralizers on bottom joints and one centralizer each side of DV collar~ Ran. metal pedal basket 1 jt below "DV" collar. Fnshd instlngweld on 1323/8"'csg head. Tstd w/1500t~. NU 13-3/8" riser assy, I2" series 900 dual Shaffer BOP's & 12" Hydril. Tstd blind rams & csg w/2000t~. RIH to D.V. @ 999'. Closed D.V. w/pipe weight & DO same. RIH to FC @ 4477'. Attempted to ~est pipe rams but had leak in csg. Trpd to PU 13-3/8" RTTS tool. Located leak in "DV" @ 999'. Tested Hydril & pipe rams w/1500~t. Set RTTS @ 937'. Mixed 800 sx Class "G" w/10% sand &..disP w/250 ft3 Inlet wtr to clear hole. Max & final press 400~. CIP 9:00 pm 2/15/70 .- WOC. . · WOG 6 hrs. Broke down w/400t~. Mixed 200 sx Cla~s "G" 'neat cmt w/2% CaC12 1.0%'sand. Disp w/250 ft3 Inletwtr to clear perfs.,,.CIP@ 4:00 am 2/16/70. WOC 6 'hrs. Broke down w/200~ Mixed 300 sx Class "G" w/3%' CaC12. Di'sp w/134 ft3 Inlet wtr, leaving 55 ft. cmt in-c'sg'. Max stand.ing press 500~o CIP@ ll:30 am 2/16/70. -WOC 10..h~s. Drld firm cmt 964'- t040'. --... D & S 12-'1/4" ho le to: 5340' D & S 12-1/4" hole to 60.1.2'. Some sloughing c0al while drlg @ ~510'. -. D & S'12-1/4" hole to 6688!' Hole in good Condition. . D & S 12-i/4" hole to 7198'- . : ' . ' D & 'S 12-1/4" hole to 7565'. PU DDrl to correct r~g.ht turn. ' . . . Made 62' with DDrI. Trpd for new B..H'Ai Drld & surveyed 12"-1f4'' hole. to 7890'/ . '. '.-.. ..... . ...... - - -. . . . Fnshd .trip for bit. Drld two hrs. Made Short trip into csg to work on fast coupling on ro~:ary'for 6~hrs. Trpd for bit @ 8089 Down 1 hr forA.C, pwr _______failurm. -' ' ' . . . ' LEASE UNIOi "OIL CO. OF CALIFO-?.,,qlA DRILLING RECORD SHEET D PA~ NO. 6 Trading Bay Unit State ~rfgLL NO. G-3-3 FIELD .McArthur River Field DATE 3/1/70 E.T. D, ... 8515' . 8743' . .8978' · 9208 9484 9571 9678 98O3 9871 9992 10,070' 10,090' 10,090' 'DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS D & S 12-1/4" .hole to 8515'. "..: - . D & S 12'1/4" hole to 8743'' ' - ::':' "i"',-- · ' Drld to 885'1. PO for NB. Set cameron test plug.~ hyd "fail open" valve would not open. 'Remvd same from choke 'line. Recharged n{tr°gen tanks on Koomey Unit. Press tstd riser, .BOP,. kill & choke lines w/2000 psi OK. Drld 12-1/4" hole to. 8-978'. :. ' D & S 12-1/4" hole to 9208'. D & S 12-1/4" hole t6 9494' . D & S i2-1/4': hol'e-to 9571'. D & S 12-1/4 " . hole' to 9678'. D & S 12-1/4" hole to 9803'. Press tstd 'BQE. Shaffer D & S 12-1/4" hole to 9871' Drld 12-1/4" hol& to 9992'. Drld 12-1/4." hole to 10,070' S.L.M. out bf hol~' No correction. -. . Girc.& cond mud to log. · tian Sch!um-DIL4500' - 10,045'. W..L.M. Ran B.H.C.S. 10,048' - 868.7" Ran F.D.L2 10,048' - 4500'. Ran S.N.P i0,048' - 8677'. RIH w/NB. .. S.L.M.'in hole. .Noticed slight bridge @'10,050'. Drld to'10,090' as per geological orders. Circ btms up & POH to run:csg. .. · RU & ran 259 its new 9-5/8" 47~:& 43.5g P-il0. & N-80 csg. Landed same W/float st~oe @ 10,090'. Gmtd'W/1750 sx Class "G" w/1To CFR-2 mixed to llS~/ft3 W/fresh,wtr & tailed'w/250 sx Cias~ "G" neat cml mixed to -llS~/ft3 ~;/fresh wtr. Mixing time 50 min. "D$'sp w/4200 ft3 mud. Disp time 30 min. Bumped plug w/2000ff, CI'P-@ 1.2.30 pm 3/8/70. Released press & ND riser a. ssy. Landed 9-5/8" w/250,0.00~ in KiJameron type "CA" hngr. Instld "R" seal & NU Cameron "rDG.-B" tbg hd 12" x 10" ,5000~.. Instld 12" S 900 BOE.. Tstd tbg hd w/2500~ OK. Made up B.H.A. & RIH to FC @ 10,005'. Tstd rams w/2000~ & Hydril w/I500J~ OK. · · ": " '- .' ","'{:.: '. ':'"'i ':"" ..... ' ": .. .- . . . · LEASE. . Trading Bay UNIOl,,, Unit 'State OIL CO. OF CALIFOI (NIA DRILLING RECORD SHEET D PAGE NO., 7 WELL'NO G-33 FIELD_ McArthur River Field DATE 3~9/70 10 11 12 E. T. D. 10,.382' 10,638' 10,790 10,790' 10,706' 10,706' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2 it8 . . 2 40 its 2 46 its 7 lf0 its · 1 Jt - §-~,.5./8" Casing Detail . '9-5/8" Baker "G" 9-.5/8" 47~ P-110 .. 9-5/8" Baker "G" 9-578" 4'7~ P-Il0 . 9'5/8" 47~ N-80 buttress csg. . "9,5/8" 43.5~ N-80 buttress csg. - 2.5 76.0 .1.8 1795.0 6606.7 34.42 40.;60~ . 10090.04 · . _ Drld 76' firm cmt & float shoe.@ 10;090' to 10,382.'. · -.. :. D & S'8,1/2" hole'to 10,638'. . Diff fill float sh°e 10-3/4"OD buttre s s csg. Diff fillFC 10-5/8" OD M&F buttress csg.- .9-5/8" 43.5~ N-80 buttress cut off lndng Ct. Distance from csg"head to'rotary Setting Depth -. : . . Drld"& Surveyed 8-1 ./2" 'h°le D & S 8-1/2" hole to 10;790. Circbottoms up & POH to log. RU Schlum & ran DIL 10,772' - 10,070'. Ran B.H.C. Sonic 10,776' --10,010'. Ran FDG 10,778' - 10,070'~ Ran S'N.P. 10,775' - 10,070'..PU enough 5" dp to run liner and RIHto 10,740' and circbtms . Tight hole 10,715'-10,770'. Ran & cmtd 18 jts 7" 29~ N-80 csg (see detail). Cmtd w/200 sx Class "G" w/l% CFR-2. Bumped plug w/3000 psi. Floats held OK..CIP 10.30 pm. . .,- · 7" Casing Detail . . 7" TIW'Shoe 2.42 1 jt 7" 298 N-80 butt. csg w/spl, clr collars 43.'13 7" Baker Mod "G" FC ' i-.80 7" TIW Landing Collar 'l',10 17 its 7" 29~ N-80.butt. - csg. '.'- ' ' ',' '722.80 7"x9-5/8" ~'IW ln'r 'hgr 20.46 Landed Below Zero : 9962.39 . . ., 10,751'. 68 1..0,708.55 :10,706,75 10/705.65 -.- 9,982.85 · 9;962.39 · .. . lO ,754.10 RIH with 8-1/2" bit &. csg scraper. Drld '& CO cmt 9878' to top of liner o hanger@ 9962'. Ran 6" bit & csg scrpr. Drld & CO 60' of cmt on top df 7" liner float collar @ 10,706'. RU Dresser-Atlas and ran GRN correlation log. - . . . , . Cont rng correlation & CBL'logs.. Set "EZ"..Drill BP 6.9650'. Perfd'csg @ 9470' w/four 1/2,.hpf. Set RTTS @ 9550" & tstd BPw/5000~; Reset RTTS @ 9300'. Broke' down formation"w/4900 psi. 'Pumped into formation' @rate of. 10 ft3/min @ 3900psi. Mixed 150 sx Class "G" w/1% CFR-2. Sqzd 150 sx into formation. Unable to obtain more than 3000 psi standing press, cleared peris w/an over displacement of 15 ft3' Due to flow back . held press 1-1./2 hrs. Unable to pump thru peris w/5500 psi. Laid down RTTS tool. ' LEASE_ UNION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D PAgE NO. 8 Trading Bay Unit S{ate " WELL NO G-33 FIELD McArthur Ri~er Field · DATE 3/15/70 16 .17 18 E. T. D. 0,706' 10,706' 10,706' DETAILS Of OPERATIONS, DEscRIPTIONS & RESULTS Drld cmt 9464' to 9470'.,- Set RTTS @ 9300'. Sqz job broke down @4100 psi. Pumped 4 ft3/min @ 4600' psi. Would-bleed off to 2900~ in 10 mins. Mixed i00 sx "G" w/l% CFR-2. RTTS failed before cmt'reached formation. Reversed out cmt. Perfd csg 9471-72' w/two 1/2" holes. Set cmt retainer @ 9430'. Mixed 75 sx' "G" w/l% CFR-2. Sqzd 63 sx thru perfs- 9470-72'. Max sqz press 5500 psi. Final standing press 4000 psi. CIP 9:00 pm. Drld cmtretainer@ 9430' & firm cmt to 9475'. Drld out BP@ 9650' & CO to 9962'. RIH w/6" bit & csg scrpr. Drld thru junk on top of liner @ 9962' LCleaned out to 10,706'. SPotted 175. bbls Invermul pill on bottom. Dresser-Atlas perfd "G" & West Foreland Zones with 4" thru csg g'uns 4 hpf. (See Perforating Record). RU Weatherford dual tubing tools. 'Changed rams in BOP & started rng dual 3-1,/2" tbg strings. Ran & landed dual string 3-1/2" N-S 9.20g buttress tbg @ 9985'. LONG STRING 3'21 its (9843.36) w/Guiberson dual hyd pkr @ 8711 and Otis type RH single hyd pkr @ 9916'. SHORT STRING 280 its (8604') left 12,000~. weight of short string on dual pkr. SEE TUBING DETAIL. ND BOE. Instld & tstd Cameron tree. Disp mud w/diesel. Down annulus out ss and then out ls. Dropped ball & set pkrs. Sheared out @ 3700~. Tested pkrs OK. RD Howco lines. 'RIG RELEASED 12'00 Midnight,,3/!,8/70. t J [ FIELr~=%~,!E.~ .... WELL NAME ' ~ COUNTY ~ NEW i ~ WEIGET . GRADE THREAD DEPTH SIZE WEIGHT GRADE THREAD DEPTH ~ ~ SAFETY EQUIPMENT ~ GAS LIFT EQUIPMENT ~PACKERS AND ACCESSORIES -O COMPLETION EQUIPMENT O POST COMPLETION EQUIPMENT s,z~ I ~*1 ~*1 D~sc.,.T,O~ o~ ~QU,.~. ~D s~.V,C~S ~S.,~AT~ THREAD !:- 7 ,. ( x ~..~,¢ 1 ~ 73. . . 4-: _ 2 it .7~" n~t/ ¢~/,M 62.// .... ~7~.~ --+---~- ~2., DL~ 4,,.- c.~ ~.~.m./ '- s. ...~....5 .... 3~ i¢. 3t'. /3~ L/.;z //~/.z~ "i ' ~ :~f' 4.0o. ." _. '°_ ci L,.O I ~*c,'" ~:~,~ ' " ' ' 0 -- -- TELEPHONE '-~' PREPARED BYI OFFICE I -4.-..4 ..... ~ , ~ .~ 1 ~ . ~ ~. I WELL NAME COUNTY ,STATE ~ NEW [ ] ]COMPLETION · .1,4,.,. ~.~ ~.~,,, .4~C wo~ov. SIZE wEIGHT ·GRADE THREAD DEPTH c"'s'"'~"l ~" l'-/7" I I ,SIZE WEIGHT GRADE THREAD DEP~.~ '-'""~'~ I 7" . I ~'~ ' I I I sAFETY EQUIPMENT i~)GAS LIFT EQUIPMENT · (~)PACKERS AND ACCESSOR4ES OcOMpLETION EQUIPMENT O POST COMPLETION EQUIPMENT DESCRIPTION OF EQUIPMENT AND SERVICES ESTIMATE ~ 3 ?Zz.r 7.3 77~ 7. 23' ..¢', COMPLETION PROCEDURE ,I. TOTAL ESTIMATE · .OFFICE TELEPHONE LEASE~ Trading Bay Unit State WELL RECORD PAGE NO WELL NO....G-33 FIELD McArthur River Field CASING & TUBING RECORD SIZE WEIGHT '''~ THREAD 'G R__A'_.D E DEPTH . I~EMARKS .-----~- 94t! 8rd- . it_40 605' Cmtd w/2000 sx + 65 sx top 'job -- 13-3/8" 61{! 'butt, J-55 4511" Cmtd w/2000 sx prlt gel & 1000i. sx "G" w'/2% 'CFR--~-- .9-5/8" 47 & 43. butt. P-il0, N-80 10090' Cmtd w/1750 sx "G" w/l% CFR-2 + 250 sx "G":neat 2:: Ant. 2Ui/ bUtt. · i i; . .N_80 10754, ~mtd w/200 sx "G" w/l%' CFR-2 -- · . ~ . · PERFORATING RECORD 0 INToERVAL E.T.D. , tlE~ · P_I~_~SENT CONDITION ., . 9026-9046 '" production , 9073-90-90 ' " -' 9138_9156. ,, ..... - ~ 9158_9164 ,' -- 9196-9250 " " 9294-93'62' " 9416-9434 " .. .'100'86-10092 10282-10286 ,, . 10117-10121 10414-10428 ,, , . 10126-10132 10434-10475 " · 'I10203._10~6 10512-10528 " 10210-10212 10532-10544 " · 10219-10223 10'593-10625. " 10231_1023~ " · 10242-10290- " " · 10269_10276 " . -. INITIAL PRODUCTION , , DATE INTERVAL' NET OIL CUT GRAV. C.P. T.P. CHO_KE ~C~ GOR . . , . ,, . - . · ...... · · · ,., ,,, · ,, , , , · _ .... , , · ,, WELL H~AD A.$~%E_MBLY TYPE: Cameron CASING HEAD'"WF'" 12",3000# x 13-3/8'' OD slipon weld btm w/two 2" 5000t; w.p. flgd n,,t!ors · CASING HANGER: Type "C3[" 12" x 9-5/8" slips & seal assy w/type .R15123-4 seal assy. . . CASING SPOOL: TUBING HEAD: Type "DC-B" i2" x 10" 5000# wp w/two 2" 5000# wp stud outletS:"F'' gate valve 2" x__ 2-1/16" 3000#. TUBING HANGER:Dual DCB 10" nominal with 3-1/2" x 3-1/2" butt. on 5-3/64" centers TUBING HEAD TOP. 10" 5000# MASTER .......... VALVP.~- Cameron tyPe "F'i, Gate dual string solid block log tree w/2-3-'1/8" bore Master Valves w/2-3-1/8' bore wing valves CHRISTMAS TREE TOP CONN.: 3-1/2" 8rd EUE GRAYLING DISTANCE &.DIRECTIONS FROM SE CORNER SEC. 29, TgN, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL LEG #3: LAT : 60o50, 22.569" LONG :151°36' 46.519" 2,502,352.30 212,272.70 1804 FEL 1409 1 2,502,346.65 212,269.32 G-22 1789 1413 2 2,502,350.14 212,266.48 G-21 1802 1415 3 2,502,354.64 212,266.55 G-26 1806 1415 4 2,502,358.05 212,269.49 G-25 1810 1412 5 2,502,358.77 212,273.94' G-24 lB10 1408 6 2,502,356.46 212,277.80 G-20 1808 1404 7 2,502,352.20 212,279.28 1804 1402 8 2,502,347.99 212,277.68 G- 36 1800 1'4 04 9 2,502,345.80 212,273.75 G-34 & RD 179'8 1408 l0 2,502,350.83 212,270.89 G-23 & RD 1803 1411 11 2,502,354.60 212,272.33 G-33 1806 1409 12 2,502,351.47 212,274.88 G-27 & 28 1803 1407 1831 LEG #4: LAT = 60050, 22.832" LONG :151°36' 48.042" 2,502,380.80 212,197.90 13 14. 15 16 17 18 19 20 21 22 23 24 2,502,374.34 212,196.66 G- 14A 1825 2,502,376.65 212,192.79 G-1 9 1827 2,502,380.90 212,191.32 G-1 3 1831 2,502,385.11 212,192.92 G- 15 1835 2,502,387.30 21 2,196.85 G- 5 1838 2,502,386.45 212,201.28 1837 2,502,382, 96 212,204.12 G-3 1833 2,502,378.46 212,204.05 G- 2 1829 2,502,375.05 212,201.11 G-11 1825 2,502,378.50 212,198.27 G-lO 1829 2,502,381.63 212,195.72 G-17 & RD 1832 2,502,382.27 212,199.71 G-7 1832 , 455.60 212,226.40 1906 LEG #1: 2,502 · LAT: 60050, 23.575" LONG :151°36' 4Z. 505" ' 2,502,427. l0 (Reserved for Compressors) LEG #2: LAT: 60050, 23. 313" LONG :151°36' 45.982" 2,502,421. 2,502,424. 2.502,429. 2,502,432. 2,502,433. 2,502,431. 2.502,427. 2,502,422. 2,502,420. 2,502,425. 2,502,429. 2,502,426. 212,301.20 1880 45 212,297.82 G-12, RD & 2 1874 94 212,294.98 G-31 1878 45 212,295.05 G-4 1882 85 212,297.99 G-1 1886 57 212,302.44 G-9 1886 26 212,306.31 G-18 1884 O0 212,307.78 G- 14 1880 37 38 39 40 41 42 43 44 45-- 46 47 48 80 212,306.18 G.-30 ........... 1876 60 .............. 2'12,'302.25 ................... G-8 & RD 1874 63 212,299.39 G-6 1879 40 212,300.83 G-32 1882 27 212,303.38 G-16 1879 1486 1487 1491 1493 1491 1487 1483 1480 1480 1486 1483 1488 1484 1458 1383 " 1386 1 389 1389 1386 1382 1378 1376 ....... 1378 1382 1 385 1 383 1381 ~..o.0 ..&:z ./: .' ,../o.0 I A T I 0 N DIRECTION TV OP. LGIN L. OC>.TED tT M · 560 £: O, .... S 346 .._ C 30 ~ S _-.'g62 ....... 0.25 ~ S -1104 0 20' 1350 ._. o 15 ' 1504 ............. 0 .25 ' ].812 .......... 0 0" ?.L 0 2 ~33 ........... 0 2 z743 0 296i C 5 3055 ...... 3 1 3126 5 32-~ '7 ~ C . 34?6 ...... ~ 1 3 '714 17 ~ ~(~ a 19 4 ,>., :~ 7 ,';' 2 O '1 6,388 20 6969 2(} 1 7198 21 3 .. 7890 2! 4 OE 53E 12E 37W 58E O6 2~ ~7~ 61 E 85E 8'7 E 86E . 85E S 81E S '79E S_ 73E S 78E O0 36 64 !!0 134 150 181 212 243 274 296 3OO 306 3!2 3~7 3'78 4O5 47 4 597 7~0 760 CONPANY G~.33 WELL CC~PLET!ON REPORT PREPARED BY SCS OJ/lc. 7U ................ ............................................ TOTAL COORDINATES .SUB Sa~ .... LATITUDE DEPARTURE ..... C L 0''S 'U R E S .... DO~ LEG_i--SECT!uN DISTANCE ANGLE SEVERII¥_. DISTANCE VD : .... O.o0,._ LATITUDE : 0..00 .... 261.00 ................ 0o00 ............. O,CC ................ 0,00 5,98 ........ 546,98 ................... 1.88S ..............1,63E ................2.49 I~98 ......... 762.98 2.82S ................... 2.89E ................. 4.04- 3,97 1004.97 ............ 1 ' 4 5S ...........3,18E ......... 3,49 9.97 1250.97 .............. 0,59S ......... 2,53E ..... 2,60 3.97 _ - 1404,97 .......................... O.OOS .......... 3.48E ...... 3.48 1,97 .... 1712.97 .................... O.OOS ........... 3o48E ........ 3,.48 0.96 ..... 2021.96 ......................... 1.79S ............ 3o58E ........... 4.00 0o00, ..... DEPARTURE = _.C.O0 O.O0 ...... 0.000 ........... 0.00 S 41.OOE ..... 0.174 ............ 1.96 S 45,63E __ 0,058 ............... 3,37 S 65o49E __ 0,262 .......... 3,40 S.76,81E .~ 0,103 ................. 2,60 S 89.98E 0.327 3.42 S 89.98E 0.135 ..................... 3.42 S 63.36E . 0,107 ............. 3,85 2,95 ...... 2333.95 .................. 0.20N ............. 2.51E ................2.52 N 85.29E 2.94 _ 2643.94 ................... 1.60S ..... 5,10E ..... 5,34 S 72,55E 0,92 2861,92 ........... 4,13S .... 7.O1E 8,13 S 59,46E 2.90 2903,90 .....................3.55S ..... 8,15E ......... 8,89 S 66,45E 4.80 2965.80 ................... 1.84S .... 11,22E ......... 11,37 S 80.64E 5.56 . 3026.56 .............. O,03S .... 16.22E ..... 16.22 S 89,89E 6.18 3177.18 ............... 5.96N ._ 35.82E ............ 36.31 N 80o55E 9.80 . 3390.80 ............. 13.50N ' 78.62E ... 79,77 N 80,255 8,27 3599,27 .............. 19.06N 142,12E 143,39 N 82,35E 6~74. 36a7o74 .............. 20o72N ...... 1'73,84E .... 175,07 N 8.51 __. 3959.51 ............ 43o04N 263.35E ..... 266.84 N 80.7!E 7.87 ._. 43~8,87 ................ 70,10N _. 402,58E. .:408~64 N 80.12E 7.47 .... 46~8,47 .................. 86.00N .515.69E .. 522,81 N 80,53E 9.27 4970.27 .............. 98,41N 633o75E 641.35 N 81,17E 8.53 5239.53 ........... 107.07N 732.715 740.49 N 81.68E 3.28 5524.28 .......... 110.78N 839.11E _. 846.39 N 82.475 3,78 _. 587~78 ................ 1C8o56N - 966.665 .... 972.74 N 83.595 6,20 .... 6187o20 ........... 100.5~N 1081.64E 1086.30 N 84.69E 1.05 ...... 6392.05 ................. 94.02N .1155.92E... 1159.73 N 85o3~E 4.69 _.6655.69 ............... 78,80N _..1251.98E 1254,46 N 8.6,39E .. 0,234 ................. 2,43 0,313 ........... 5.31 0.152 _._ 7.66 4.292 8.67 2.423 ......... 11.37 3,050 ............. 15,93 1.821 ............ 34,05 1,798 ...... 74,67 2,583 ........ 135,98 .. 3,001 .......... 166,81 . 1,308 ......... 250,5~ 0,498 ....... 382,15 0,325 ..... 490,23 . 0,201 .... 603,84 0,120 699~0 0,35B 803,1~ 0,308 _ . 928,87 0,318 ..... 1043,31 0,195 .......... 0,497 _ 1214.68 7.75 ._. 6868.75 ................. 62,79N...1334,B6E _ 1335.84 N 87.30E .... 0.628 ..... 1298.61 6,20 ........ 7207,20 21,2.9N ....... 1470,09E ...... 1470,24 N 89,16E ........ 0,703 ....... 1439,72 8..06 ..75.09o06 .................. 3.74S _1587.89E ....... 1587.89...5_._89.86E 0,658 ......... 1560.13 ................................................................................................... RECE, ¥[.D PAGE CNZCN OIL COMPANY 6-3?, WELL CC~;:PLETION REPORT PREPARED BY SCS 03/16/70 "; :" 7 ~.~ ;":, ;'. ' [. E .r.] I R E C T I r? N ................................. TOTAL COORDINATES . C L 0 S U R E S . . 006 LEG._SECTION TVD gU8 SEA LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTANCE 9 i 18 2": 93.51 .... 2 a 15 ~ S 75E !5'~ _. S 73E 0 ¢ S 72E 15 I . S 70E C" S 69E 15 ~ S 68E 0 ~ S 66E !.5 ~' S 66E C '~ S 64E ~2E 6CE 58E 55E 7793.53 '7694.53 ............. 22.40S 1657 8000.85 ....... 7901~85 ............ 47.20S. 1738 8150.89 _.. 8051.89 .................. 66.88S_ 1799 8288.71 .......... 8189.71 .............. 87.135. 1854. 8495.83 8396.83 ......... 118,64S 1936 8737.32 8638,32 ......... 161.30S 2042 8969,53 _ . 8870,53 ............ 211,52S 2155 9072.60 89'73~60 .......... 234.05S 2205 9250.80 .... 9151.80 .............. 273.85S_ 2287 9430.56 9331.56 .................315.01$ ...... 2364 9~C4.57 9505.57 ............. 355.58S ¢ 2435 9699.01 9600.01 ............. 377,35S 2472 9969,64 ..9870,6~ .......... 443.47S 2578 10240.81. 1014.1.81 ............... 514o35S ...... 2679 .55E .66E.._ 1739.30 .24E _ 1800.48 · 88E 1856.92 o95E 1940.58 .55E¥. 20q8.91 · 35E 2165.70 .94. E 2218.32 · 55E / 2303.88 .96E' 2385.85 .-23E ~ 2461.06 .gqE 2501.56 .74E 2616.60 .97E ~ 2728.88._S .... 79.'13E . . 165'7.70 S 89.22E .. 0.606 ........ 1632.07 S 88.44E ...... 0.555 ...... 1716.40 S 87.87E ........ 0.517 ........ 1779.59 S 87.31E ....... 0.549 ........ 1838.05 S 86.49E 0,206 . 1924.60 S 85,48E 0,856 2036,35 S 84,39E 1.099 2156.59 S 83o94E ._ 0.213 2210.52 S 83.17E .... 0.778 ..... 2298.16 S 82,415 ........ 0,670 ...... 2381,95 S 81.69E 0.687 2458.61 S 81.32E 0,240 2499,74 .S 80.24E 0._280 .......... 2616.11 0.fi27 ........... 2728.88 ............. CL 'SURE 2728.88 _ S 79- ..... 8' "£ I R E C T i ~ N A L ~ U K v ~ Y VA,_U~S FOR. F':";~=iV- ~nn F~ET OF..SUB SEA DEPTH OIL CC,.~,P^NY G-33 WELL CO. MP-LETIQN REPoRT~.iPREPARED BY. SCS O3/I6/?O.'.__TANGENTiA[..Li_M'ETHOD-._. SUB SEA 399 .......................... 399,.00 -. ....... 300 O0 400 O0 ...........500 O0 6O0 OO 700 CO 800 O0 900 CO lOOO O0 !100 ,',3 1200 O0 1300 o00 2200 o00 2300 .00 2400 .GO 25OO cO0 .... 2600 .00 2700 .00 ........2800 .CO ..... 2900 .OO .... 3000 ~00 _3100 .OO ............. 3200 .... 499 ..................... 499 ........ 599 .... 699 ........................ 699 ........ 79c~ ........................... i'99 ........ £;99 ' 899 ....... 999 ..................... 999 'L 2'-'" .. 1S99 .................... l.b~9 . izi-99 ............................... 1499 - -1599 ........................ !599 .... !699 .................. 1699 ...... i79~ ...................... 1799 . ..209~ .......................... 2c99 .... 2199 ....................... 2!99 .,-22¢~9 .................. 2299 ... 239c; ..................... 2~99 ' :2/,9e 2499 .................. .~.~9 ............................. 2(99 ........ 2799 -2899 ....................... 2899 ~ {'i .3 2'"'" ~ 199 .... ,~ ~ ................. O0 1400 O0 .-. 1500 O0 .1600 00.. 1700 OO 1800 O0 1900 OO 2000 O0 2100 ......... TOTAL COORDINATES ................ ~D-TVD .......... VERTICAL LATITUDE ..... DEPARTURE ................. DIFFERENCE'_ ........ CORRECTION .00 ................ -0.25S .0.22E ....................... 0 ................................. 0 .OO .00 ............. -1.575 ......... 1.36E 0 0 .CO ........ -2.liS I 94~- 0 ' 0 .00 ......... -2.55S .00 ....... -2,,51S ................ 2.93E ............................... 0 ...................................... 0 o00 .CO .......... -1o48S 3 o IL'TE ............................... 0 ............................... 0 .CO .00 o00 .CO ............. -0.02S __3.45E 0 ........................... 0 .00 .......... -O.OOS ................3.48E .......................... 0 .............................. 0 _.. .00 ,,00 .................. -O.OOS :3.48E 0 0 .00 O0 -1.08S ':', ~aE 0 0 .00 ................... -1.66S 3.57E 0 .......................................... 0 .CO .00 ............. -0.65S 2.97E .CO ..............-O.C1S 2.63E O ................................... 0 .CO .CO ....... 0 ?aS ................. ~ 90E 0 0 .CO -!.34S .00 ............ -2.25S .............. 5.59E .......................... 0 .................................... 0 .CO ..................... -3o41S 6.46E 0 o00 .................... -3.60S ............ 8.04E 0 0 ,,00 ,nO .00 '" .76N z,n ~o= 2 I !~4EASL~EO ..... DEPTk. .................. TVD ,, -. 3506 .......................... 3499, 36!r' -. 37~5 3821 ............. 3799, 3527 138 x.'~52 ~55" ..-4672 ............ 4599. 54! 6 ........... 5299. O0 OO OO O0 O0 OC O0 CO O0 . CO 00 OO O0 O0 O0 O0 O0 CO CO O0 O0 oe 00 O0 oo oo oo oo ~ ~:;..... ............................ ...,, ,,~ ,~, 56 '32 5 .q 9 9, 57,.'"38 ...... 5599. 5C57 ............ 5899. 6!64 ................. 5~'99. 637 7 ........... 6199. SEA DEPTH CO~PAN'Y G-33 WELL CONPLETI£N REPORI_..PREPARED BY,.SCS 03/16/70_ TANGENTIAL__,METHOD SUB S 3300. 3400. 35OO° 3600. 3700. 3900. ~000. 4100. 4200° 4300. 4400. 4500. 4800. 4700. 4800, 4900. 5000. 5100. 5200. 5300. 5400. 5500. 5600. 5't00. 5800. 5900. 6000. 6100. 6200. ...... 'TOTAL COOROINSTES ................. ND-TVD ...............VERTICAL ................. E~ ........ L~TITUDE .........CEP~R'FU~E .............. DIFFERENCE .............. CORRECTION O0 .............. lO.30N ..........60.43E CO ............ 13.75N ............. 81 00 .............. 16.41N ....... !t! CO ........ !9o07N ........ 142 O0 ...... 21,73N ..........1'77 CO ........... 29.94N ........ 210 CO ........ 38.15N ............. 243 O0 ........... 45o93N ............ 27~ CO .... 60.20N ...........351 O0 ..... 67.~3N ......... ~88 O0 ........ 73.2~N ...... ~2~ O0 78.38N ......... 461 O0 .........83.51N .......... 4~7 O0 .......... 87.99N ......... 534 O0 ........... 91.8~N ....... 571 O0 95o70N ....... 607 O0 ...... 99.36N .......... 544 O0 .... 102o58N ....... 681 O0 105.80N ..........718 O0 ..... 107.86N ................. 755 O0 109o16N ......... 792 O0 . 110.46N ..........830 O0 ...... 110o30NA .........866 O0 :09obTN ..........903 O0 109o03N ....... 939 O0 ...... 107o91N ..........975 O0 :05o3~N.. 1012 O0 ..... 102.75N .......... 1049 O0 ........ 100.1~N ........... 1088 4 2 .42E ................... 7 .£8~ 11 · °38E ................... 16 .87E .......................... 22 ................................... 6 ' · .SIE. 28 ......................................... 6 .2rE ...................... 39 ................................. 6 .91E ................................. 46 ................................... 7 - .6IE .............................. 5~ ...................................... '7 ~lE 60 .$'IE .................. 66 .............................. 6 o98E ........................ 79 .59E .......................... 86 ......................................... 7 o28E ..................... 9] .68E ...................... 106 .43E .................. 112 .1SE .................119 ' 7 · 30E ............................ 126 .~TE ....... 133 .66E ..................... 146 ............................................ 7 .06E .................152 o45E ....................... 158 .94E ................ 165 ............................................ 7 .?4E .......... 172 =SE .................. 178 ................................. 6 o~ o28E ........................ 186 .............................................. 7 LN!Oh} OIL CO,~iP~NY ~];. F P TH .._ TVD 6590 ................... ~,~ ggo 00 7017 .............. ~Tgg. O0 7i24 ~q C ....................... 76:99. O0 .-,. 7665 ......... 7399.00 .7773 ...................7499~00 7~aO ................ 7599.00 7988 ...................... 7699.00 a095 ......................... 779g.00 8209 ............ 83il ............. 7ggg.oo 842C ................. 8699.00 8¢;2~ 8'~ 99 O0 8637 .......... 8299.00 8'7'~. 6 .................. 8sgg~o0 835~ .... 8499.00 S95;5 ..... 8~fgg~o0 qS~~ ' 8~99.00 9qZq - . ................ 8999.00 9~>" gog9.O0 --9640 ................. 9 199~ O0 .9 7 52 ........................ 9299. O0 SLJB S .. 6300. 6400,,. 6500 ,. 6600,,,00 ...... 82,,, 6700.00 ....... 75,,. 6800.00 ......... 67. 6900.00 ............. 58. ?CO0. O0 ....... 46 o 7200.C0 ..... 22. 7.300. O0 ..... 13 o . 7400.00 ............ 5, 7500.00 ...... -2. 7600.60 .......... -12, ... 7700.00 ......... -23, 7800.00 -35° 7900.00 _. -46, 8000°00 ........ -60 o 8100.00 -73, 8200.00 -88, 8300.00 ..... -103, 8400,00 _ -119, 8500,00 ..... -136. 8600.C0 ..... -154. 8700. O0 _.-17~. 8800~ 890O. 9000 ~ 9100. 9200. VALUES FOR EVEN 100 FEET CF SUB G-33 HELL COMPLETION REPORT_ PR TOTAL CCORCtN~TES ........... EA . LAT~fUBE 6EPARTURE ......... D CO .............. 9a~gqN ...........1122 O0 ............ 93 " 'I '- O0 ............... 87.79N ....... 1195 02N ..... 1231 47N .... 1269 96N ........1307 96N ....... 1346 7Cr~' ....... 1386 44N ........1427 1SR._ 1467 60N .... 1506 30N ......... 1545 98S ....... 1584 89S ....... 1622 06S ........1659 02S ....... 1698 98S ....... 1-737 07S ......... 1778 9tiS .. 1818 70S ._ 1858 91S ....... 1898 20S .... 19~8 87S .......... 1982 fi3S ...... 2025 64 S .......2072 SEA DEPTH EPARED BY SCS 03/16/70__ TANGEi~,~T_];AL_ NETHOD_ ff,.'.O-TVO _ VERTICAL I FFERENCE ......... CORRECT ION o.54E ................... !91 .................................... 6 ,, 3. 1E ........................ 197 ........................................ 6 .25E 204 ................................... 7 .69E ........................ 211 ................................. 7 · lie ........................ 218 ....................................... 7 .78E ................... 225 ...................................... .~7 .89E ...................... 233 ....................................... 8 .99E .............. 241 .............................. 8 .IOE _ 250 9 ,,,205 .......................... 2.58 ........................................ 8 ............................................................... o30E ...................... 266 ........................................ 8 .32E - 274 .............................. 8 .35E ....................... 28.1 ...................................... -7 .04E ......................... 289 .................................... 8 ................. ' o BgE ........................ 296 ....................................... 7 .81E ............................ 304 ........................................ 8 o94E ................ 312 ........................................ 8 .28E ., 321 .................................... 9 .66E ............. 329 .............................. 8 ................ .95E .....................338 ............................. 9 ,58E .....................347 ....................................... 9 .345 ................ 356 ..........................9 .C7E ......................... 366 ..........................lO °?95 ................... 377 ............................. 11 .5tE ...................... 389 ....................................... 12_ CO ........ -196.27S ....... 2121.C9E .................. 402 O0 ........ -217o96S ........ 216g.°81E .......................... 415 ............................................... 13 O0 -239.95S ........ 2218.C3E ..................... zl2g ..........................14 O0 .... .262,,28S ........... 2263.83E ................... 441 ..................................... 12 0 O ............. ~284 ,, 8_9S____2 ~ 08.30E .......................... 453 ........................................ 12 ' . _ DJ[RE ............. !NTER~CLATED VALUES C T I C "' A L:, S U R V E Y FOR EVEN 10C FEET OF SUB SEA DEPTH ............ PAGE ................... ~.,aION OIL Cui~PA~Y 6-33 WELL._ .C''~ ~.KPLETI£N REPORT__. PREPARED BY_SCS 03/16/70 ........ TANGENT_IAL._METHOD ..~ D~PT~ TVD SUB ........ TOTAL .CCORD INJ!.TES ................. MD-TVD ............ VERTICAL ........................................... SEA ........ LATITUDE ........ DEPARTURE ..... DIFFERENCE ........... CORRECTION ~- 9863 ...................... 929 9974 .................. 949 .... !00~4 ................... 959 .-tO!g4 .................... 969 ~0304 ...................... 979 -10414 ................. 989 ]0524 ......................... '9¢9 '~53.~ ....................... '1009 9.00 9.00 9.00 9.00 9.00 ...... 9300.00 ...... -307o79S ..... 2351o37E 464 ............................. I1 _ giCO.CO ..... -330.97S ........ 2392.t0E ......................... 475 ...........................!1 "' 9500.00 ........ ~354o2'9S ........ 2432.98E 485 ........................ 10 9600.00 ......... -377.35S ...... 2472..93E ................ 495 .............................. 10 ...................................................... 9700.00 .... -401o78S ......... 2512.03E ...................... 505 .............................. 10 ....................................................... 9.06_ 9800°00 ........... -4-26o21S ...... 2551.i2F 515 ............................... 10 9.00 9900°00 ........ -45!o14S ..... 2589.70E ............... 525 10. 9~00 !O00C.CO ............ -477.25S .......... 2627.03E ........................ 53.5 10 9o00 l. OlO0.O0 ........... r503,..t2S ........ 2.66A.36E ........... 5~5 10 i ~v T E i~. P 13 L A T E D tC~T . ....... . ,_ ,,-- I-'-'. ............ 1'VD · !OOC .....................S99.98 ;.- 200C ..................... 1¢99.96 ;300C ........................... 2c~99o'90 .-. 4000 ...................... 3968o55 5000 SUB SEA 900 1900 . 2900 -. 3869 4807 6000 ................... 5845.04 5746 7000 ...................... 6783°53 . 6684 "O00 ......................... 7710.58 7611 .......................... ~ 59 ,,.8531 !.00O~ ................. g523.00 .- 9424 Z R .E C T._.I__C N...A. L .......... S ..U..R...V E Y ............................... PAGE .......... VALUES._ FOR_EVEN .... !000 .... F. EET'.OF..NEASURED ...DEPTH · G-33 WELL CONPLETIEN R'EPORI PREPARED.BY._SCS 03/!.6/70 ...... TANGEN_IIAL_METHOD TOTAL COORDINATES ............... MD-TVD ........... VERTICAL LATITUDE ........... D EP~.?,TURE ............ DIFFERENCE ........... CORRECTION ..........04 109.37N' ......... 919.'81E ............................ 154 ........................................ 61 .53 ........ 76.63N .......... 1263.13E ..................... 216 ................................ 62 .58 ....... -14..055 ........... 1626.39E ..........................289 .......................... 23 .59 -142.t55 ........ !995.88E ........................... 369 .................................. 80 .00 ......... =336.5_75 ........ 2_402.2.9E ...................... 476 ............................. 307 UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT TRANSHI TTAL TO' State of Alaska FROM- _ _g. _H._ _Laughb_a_Um~_ Jr ......... DATL' _ March 23~_!970 WELL NAHE' __TItlJ G-~3 Transmitted herewith are the following' Run No. Sepia Blue Scale RECEIPT ACKNO~ LEDGED · RETURN RECEIPT TO' Induction Electrical Log Dual Induction Laterlog BHC SOnic/Caliper Log BHC Sonic/Ganuna Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (}tDT) CDM Safety Print , CDM or Printout CDM or Polywog Plot CDM Polar Plots Proximity Hicrolog/Caliper Log Gamma Ray-Neutron Log Gamma. Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut RECEIVED 2 4 1 70 DWI$10N OF OIL ,AND ANCHORAGE DATE' Union Oil & Gas Division - Western ~egion Anchorage District P. O. Box 6247~ Airport Annex Anchorage, Alaska 99503 ATTN: Rochelle Carlton REV. 9-3O-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT EN DUPLICATE MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPE:RATIONS 3. ADbRESS OF OPEI{ATOR 507 W. Northern Lights Blvd., Anchora~e~ Alaska 99503 4. LOCATION OF WEJ~L 1. 7. IF INDIA]q, ALO'i'I~ OR 0IL ~ GAB J~J OTHER FILE WELL ~ELL 2. NAME OF OPEP..A. TOR 8. U'NIT,F.~:~/I OR LEASE NAME Union Oil Company of California Trading Bay Unit g. WELL NO, State G-33 (13-28) Conductor #11, Leg #3, Grayling Platform, 1806'N & 1409'W from SE corner Section 29, T9N, R13W, SM. 10. I,~LELD AND POOL, OR.%¥~Lp~T .,,. . ~.~! .,. a~.aa.te ~,ena~ u McArthur ~mver--West Foreland 11. SEC., T.. R., M.. (BO%'~OM HOL,E Sec. 28, T9N, R13W, SM. 12. PEI~IVIIT N'O. 70-11 REPORT TOTAL DEP~ AT F_2qD oF MONq~-I, CHA~NGES IN HOLE SIZE, CASING A2~ C]~F_2~TING JOBS INCLUDING DEPTH SET ~ VOLLrATES USED, PERFOlq. ATIOI~S, TESTS A/XII) RESULTS, FISHING JOB~, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHA/~GES IN HOL]~ CONDITIONS. T.~ding Bay Unit State G, 33. February 1970 Spudded @ 6:.qQ. pm 2/5/70. Drld 15" hole to 620'. Opened to 26". Ran 24" mill. Milled:conductor'shoe from 295'-365' Ran 14 its 20" 94# H-40 csg w/Halliburton duplex shoe. Landed in Cameron hub ~/shoe @ 605'. Cmt w/1650 sx Class "G" cmt. Lost circ. CIP @ 11:30 pm 2~6/70. Removed 26" riser. Cmtd 20" annulus from top w/60 sx Class "G". RI~, found no cmt in 20" csg. Recmtd thru shoe w/500 sx Class "G" w/l% CFR-2. CIP 12:30 pm...2/.7/70, woc. Tstd csg OK. Drld shoe & cmt, drld & DDrld 12-1/4" hole 620' - 4520'. Opened 12-1/4" hole to 17-1/2" hole to 4520'. Ran 113 its 61# J-55 buttress csg. Hung w~shoe @ 4511' & DV @ 999'. Cmtd thru shoe w/2000 sx Class "G" mixed with 1/2 ft° perlite per sk., followed by 650 sx Class "G". CIP 1:30 pm 2/14[~0. Good returns to surface. Did not open DV. Inst~d 12" 3000# csg head, BOE & riser assem. DO DV @ 999'. Press tstd & DV leaked. RI with 13-3/8" sqz tool. Set pkr @ 837' Sqz DV w/200 sx Class "G" w/10% sand. CIP 9:00 pm .2/15/70. WOC. Resqzd DV w/20~ sx Class "G". Max press 500#. CIP 4:00 am 2/16/70. WOC. Resqzd DV w/300 sx Class "G" cmt. Max press 1000#. Held OK. CIP 11:20 am 2/16/70. WOC. RI w/da & drld 12-1/4" hole 4520' - 9484'. Now drilling. ' NOTE~ei~rt on this form ~reqUired for each calendar month, regardless of the status of operations, anO must ~ file~ in duplicate ' with the Division of Mines & Min~als by the 15th of the succeeding month, unless othe~ise directed. OIL ~ ,GM ~ COMMt~t~ SUBMIT IN TRIPLIC~ , (Other instructions on reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL~ DEEPEN~ OR PLUG BACK l&. TYPI OF WORK DRILL [] DEEPEN [-1 PLUG BACK [] b. TYPR OF W~LL WgLL WItLL O~rHl~R ZONe! ZONE 2. NAME OF OPE~CLATOR Union 0il Company of California 3. ADDRESS ~ OPF-~I~TOR 2805 Denali Street, Anchorage, Alaska 99503 4.LOCATION OF WELL Atsurface Conductor #11, Leg #3, Grayling Platform- 1806'N & 1409' W from SE corner Sec. 29, TgN, R13W, S.M. Atpr°p°sedpr°d'z°nd'G" Zone: 1803'N & 500'E SW cor. Sec. 28, TgN,R13W,SI West Foreland Zone: 1803IN & 10931E SW cor. Sec. 28, TgN, R13W,Sl 13. DISTANCE IN MILES AND DIRECT!ON F1OM NEAREST TOWN OR POST OFFICE* 23 air mi les NW of Kenai, Alaska 14. BOND INFORIV[ATION: TYPE Statewide Surety and/or No. Uni ted Pacific Insurance Co. B-55372 18. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, (Also to nearest drig, unit. i£ any) DISTANCE FROM PROPOSED LOCATION* 500' t16. NO. OF ACRES IN LEASE 3,840 19'. PROPOSED DEPTH 10,775'MD & IO,200'VD TO NEAREST WELL DRILLING. COMPLETED, OR APPLIED FOR, lwr. 1 , 500 ' 5 0-13 3 -2'0 212 6. I.,E~SE DI!:SIGNATION A.N'D -~]~IAL NO. ?. IF IN'DIAN. ~'r'rE~ OR TI~IBE NA_M~ 8. UNIT~FARM OR LEASE NAME Trading Bay 9. WELL NO. G-33 (13-28) 10. FIELD AND POOL, OR WILpCAT ...... M I dd] e Ken a i Mcarcnur Kiver I~G,~ & West 11. SEC.. T.. R.. M.. (BOTTOM Fo r e I a nd HOLE OBJECTIVE~ Sec. 28, TgN, R13W, S.M. A~no=t $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 160 ~0. ROTARY OR CABLE TOOLS Rot a ry 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) ~. APPROX. DATE WORK WILL START* 99' RT above MSL February 15, 1970 23. PI~OPOSED CASING AND (;iglV[ENTiNG PROGRAM SIZE OF HOL~ SIZE 0F CASING :WEIGHT PER FOOT, GRAD~ [ SETTING DEPTH QUANTIT! OF ,, , ~ ~.~ ~,,:~: 26" 20II 94~ 'H 600 1,550 sacks 17~" 13-3/8'l 61~ J 4500 3 400 Ti ~ ,/ 9-5/8' 43 5# ~ 47~ N & P 10075 1,'200 ~'~'~% ~ F '~ 7" ~' '2 q ~ "' N 10 7 7 5 16 5 "~', ~ Cement 20" ca~ing in 26" hole at:600', nstall 20TM Hydril. Drill 12¼" directional hole to 4,500'. Open to 17½'l and cement 13-3/8I' casing at 4,500'. I.nstall BOE and drill 12¼" directional hole to 10,075' (Top West Foreland). Run electric logs. Cement 9-5/8" casing at 10,075'. Drill 8½" directional hole to 10,775' TD. Run E logs, cement 7" liner 10,000' to 10,775'. Block squeeze above and below Hemlock for zone segregation. Perforate "G" and West Foreland sands and complete for production thru dUal '3½" tubing strings. Bottom hole location - 1,803'N and 1418'E of SW corner Section 28, TgN, R13W, S.M. IN ABOVE SPACE DESCRIBE i~ROPOSE'D PRCK~RAM: If l~Ol~Sal is to dee~n or plug ~, give ~ on present p~u~ive zo~ ~d pro~ ~w produ~ive ~. If propel ~ W drill or d~n d~eetLo~lly,, give pert~ent ~ on subsu~a~ ~t~ ~d meas~d ~d ~ue venial dept. Give bio--ut preventer p~gram. 24. I hereby ce~tfy tha~o~g Is ~ ~ ~re~ (This space for' State office use) ~aNDITIONS O~' AppROvAL, IF ANY: I SAMPLES ANiCORE CHIPS R.EQTJn~.~I) OTH]~ P,~-'QU~: [] YES NO See TransmittalLETTER DIRECTIONAL SURVEY RE~ A.P.I. ~CAL COD~ PERMIT NO_ APPROVED ~Y ..... Oh rm n ' ¥ - *See ~lnmuctio., On Reve.4 Side Ta,nuary 29, 1970 January 29, 1970 DAT~ ..J G-5 K-9 K-5 -- i(21-28) G- I G-18 K-7 G-I IHL ,~"~~45- 281 10,775 TVD I O, ~300 · -PrOp T/WF .~. ~ TMD 10,075 ~ TVD 9575 ~,~'" G 6 7 (14-28) G-II / (.~2- 3,7-) '~" (12-55) D-I -. D-7 D-II AD]-- 17514//// [ YON- rl3W D-3 · (34-33) UNIOK MAR A TH,F~q ADL IOT~C I \~(3G-14 Z-34) ~I._MI~ION OF OIL AND UNION OIL COMPANY OF CALIFORNIA· ALASKA DISTRICT WELL LOCATION MAP UNION OIL CO. OPERATOR UNION TRADING BAY STATE UNIT 6-33 Company L Unio~_O.i I _Co.__Q.f__~;aLL.~ ..... ADL 18730 Lease & Well No. Tradi.n_g~B~._¥_G_.-_3~3________ CHECK LIST FOR NEW WELL PERMITS Yes No Remarks Is well to be located in a defined pool ................. .~/c .. 2. Do statewide rules apply ........................ ~ ~__L~ 3. Is a registered survey plat attached .................. ~ ~2z' ~o~L~ee~.~.r~ 4,~,~~, Is well located proper distance from property line ........... ~.ao~ 5.~'~.~Is well located proper distance from other wells · · ........ //~4~ ' 6. Is sufficient undedicated acreage available in this pool ........ ~' Is well to be deviated ......................... ~ ~ I operator ti ly affected party ~_LC' s ~e on ................... __-_ 9. Can permit be approved before ten-day wait ............... ¢~__~ ~ 10. Does operator have a bond in force ................... ll. Is conductor string provided ...................... 12. 'Is enough cement used to circulate on conductor and surface ...... l~L...~,Will cement tie in surface and intermediate or production strings 14. Will cement cover all possible productive horizons ........... 15. Will surface casing cover all'fresh water zones ............ ]6. Will surface csg. internal burst equal .5 Psi/ft. to next string 17. Will all casing give adequate safety in collapse and tension ...... 18. Does BOPE have sufficient pressure rating ............... Additional Requirements: