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173-037
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?Beluga River Unit (BRU) 224-13 Yes No 9. Property Designation (Lease Number): 10. Field: Beluga River Undefined Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,000'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate Production 4,430 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See schematic 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, Well Integrity Engineer Contact Email:casey.morse@hilcorp.com Contact Phone: 907-777-8322 Authorized Title: Noel Nocas, Operations Manager, 907-564-5278 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 10,000'3,255' 3,255'See schematic Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 58831 173-037 3800 Centerpoint Drive, Suite 1400, Anchorage, Alaska 99503 50-283-20042-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 65' 65' 9.3 # L-80 TVD Burst 3,013' 8,700 psi MD 1,530 psi 3,090 psi 423' 3,298' 423' 3,298' 6,999'9-5/8" 65' 30" 20" 13-3/8" 423' 3,298' 6,999' Perforation Depth MD (ft): See schematic 6,999' 3.5" kill string Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:28 am, Nov 22, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.21 10:00:29 - 09'00' Noel Nocas (4361) 323-635 None November 22, 2028 DSR-11/22/23SFD 11/27/2023BJM 12/1/23 ($8JLC 12/1/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.01 12:30:27 -09'00'12/01/23 RBDMS JSB 120423 Suspended Well Inspection Data Well: BRU 224-13 Surface Location: 1012’ FSL, 2194’ FWL, Sec. 13, T13N, R10W, SM Permit to Drill: 173-037 API: 50-283-20042-00-00 AOGCC Inspection Date: 11/6/23 AOGCC Inspector: Adam Earl Size Pressure (psi) Tubing 3-1/2” 0 Casing 9-5/8” 0 OA 13-3/8” 4 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Dry hole tree. Good working order. x Condition of Surrounding Surface Location: Good, no trash or dunnage noticed. x Follow Up Actions needed: No This well was suspended July 22, 2014 in good mechanical condition with cement retainer and cement on top of the retainer isolating the completion intervals below. It is proposed that BRU 224-13 be maintained in a suspended status to be utilized as a sidetrack candidate for future development opportunities. Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore Well Schematic Well Sign OA Pressure Gauge IA Pressure Gauge Tubing Pressure Gauge Wellhead Looking North Wellhead Looking East Wellhead Looking South Wellhead Looking West Quarter-mile Buffer Map Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 InspectNo:susAGE231113102151 Well Pressures (psi): Date Inspected:11/5/2023 Inspector:Adam Earl If Verified, How?LAT / LONG Suspension Date:7/22/2014 #314-375 Tubing:0 IA:0 OA:4 Operator:Hilcorp Alaska, LLC Operator Rep:B. Woolley Date AOGCC Notified:11/2/2023 Type of Inspection:Subsequent Well Name:BELUGA RIV UNIT 224-13 Permit Number:1730370 Wellhead Condition Good working order Surrounding Surface Condition First snow about an inch the morning of inspection. Was still able to see. Area looked clean of any trash or debris. Condition of Cellar clean, no water, no oil or sheene, no trash Comments Operator will provide photos. Supervisor Comments Inspection results acceptable despite snow on ground. Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, January 12, 2024 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection 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 10,000 feet 3,250 feet true vertical 10,000 feet 3,450 feet Effective Depth measured 3,250 feet 3,250 feet true vertical 3,250 feet 3,250 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 3,013' MD 3,013' TVD Packers and SSSV (type, measured and true vertical depth)Cmt Ret; N/A 3,250' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 65' 423' 3,298' 0 Oil-Bbl measured true vertical Packer 65' 6,999' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beluga River Field / Undefined Gas PoolN/A measured TVD Tubing Pressure 00 BRU 224-13 N/A ADL 058831 6,999' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 173-037 50-283-20042-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 398' 3,261' 5,974' Conductor Surface Intermediate Production Casing Conductor 30" 20" 13-3/8" 9-5/8" Length 40' 6,870psi 3,090psi Collapse 520psi 1,540psi 4,750psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 1,530psi423' 3,298' t Fra O 6. A G L PG , R n Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:28 pm, Jul 16, 2020 ons Manageons ManageDigitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.07.16 12:19:18 -08'00' Taylor Wellman RBDMS HEW 7/17/2020 DSR-7/16/2020 SFD 7/17/2020 Suspended Well Inspectionn gls 9 /2/20 KEN June 2020 Suspended Well Inspection Data Well: BRU 224-13 Surface Location: 1012’ FSL, 2194’ FWL, Sec. 13, T13N, R10W, SM Permit to Drill: 173-037 API: 50-283-20042-00-00 AOGCC Inspection Date: 06-16-2020 AOGCC Inspector: Lou Laubenstein Size Pressure (psi) Tubing 0 Casing IA 7 OA 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Great x Condition of Surrounding Surface Location: Great x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore x Correspondence/Suspended Well Inspection Report _____________________________________________________________________________________ Updated by DMA 09-07-16 SCHEMATIC Beluga River Unit Well: BRU 224-13 Last Completed: 10/19/2005 PTD: 173-037 API: 50-283-20042-00 30” 13-3/8” 9-5/8” RKB to MSL = 94’ RKB to GL = 25’ TD = 10,000’ / TVD = 10,000’ PBTD = 6,755’ / PBTVD = 6,755’ Max Angle = 2 deg @ 9,695’ Tubing Min ID = 2.47” TOC @3,900” 4 6 7 8 10 11 Sterling Sands A A A Beluga Sands B B C C D E E E E F F F F G G H H I I 20” 12 13 14/15 16 17 18/19 20 21 22 23 P1 P2 P3 1 2 3 5 9 CASING DETAIL Size Type WT Grade Conn ID Btm 30" Conductor 65' 20'' Surface 94# H-40 Butt 19.124'' 423' 13-3/8" Intermediate 61#/65# K-55 Butt 12.515'' 3,298' 9-5/8" Production Casing 43.5# P-110 Butt 8.755'' 2,151' 9-5/8" Production Casing 47# P-110/N-80 8rd LT&C 8.681'' 6,999' TUBING DETAILS 5.5" Production Tubing 15.5# L-80 BTC mod 4.95" 3,110’ 5.5” Production Screens/Blank 15.5# L-80 BTC 5,479’ JEWELRY DETAIL Production String ID. Depth MD (ft.) ID (in.) Description 1 417 5.545 Camco BP-6i Ported Nipple w/ Methanol Inj. Line 2 3,030 4.562 Baker 'SS' CMU Sliding Sleeve, Closed (Open Down) 3 3,109 6 Baker Packer SC-2 96B2-60 4 3,121 5.87 Gravel Pack Sliding Sleeve 190-47, Closed (Open Down) 5 3,102-3,144 2.47 Weatherford Straddle Patch (42’) 6 3,148 5 Model C Iso Protection Sleeve & C-2 KOIV 7 3,490 5 Upper Middle Iso Packer 96A4-60SC1-L 8 3,498 5.87 SS' Closed Gravel Pack 190-47 (Opens Down) 9 3,471-3,526 2.47 Straddle Patch (55’) 10 3,544 4.892 Blast Joint (236’) 11 3,786 4.8 Gas Lift Mandrel 17# L-80 TCII BXP (Dummy Valve) 12 3,809 5 Lower Middle Iso Packer 96A4-60SC1-L 13 3,818 5.87 Gravel Pack Sliding Sleeve 190-47, Closed (Open Down) 14 3,933-4,017 4.892 Excluder 2000 Med. (84’) 15 4,027-4,177 4.892 Excluder 2000 Med. (150’) 16 4,180 5 Lower Iso Packer 96A4-60 SC1-L 17 4,189 5.87 Gravel Pack Sliding Sleeve 190-47, Closed (Open Down) 18 4,255-4,576 4.892 Excluder 2000 Med. (291’) 19 4,555-4,742 4.892 Excluder 2000 Med. (187’) 20 4,743 6 Baker 'F' Permanent Packer (194-60) 21 5,454 4.55 XN Nipple (Plug set 11/02/05) 22 5,465 6 Baker SC-1R Retrievable Sump Packer 23 5,479 6.625 Wireline Entry Guide Plugs/Fish ID. Depth MD (ft.) ID (in.) Description P1 5,653 - 6.5" Junk Mill & X-over 11/12/88 P2 5,660 - Bridge Plug P3 6,914 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,355' 3,482' 3,355' 3,482' 82' 12 Mar-81 Dummied Off B 3,550' 3,683' 3,550' 3,683' 30' 12 10/8/2005 Dummied Off C 3,700' 3,776' 3,700' 3,776' 76' 12 10/8/2005 Dummied Off C 3,755' 3,760' 3,755' 3,760' 5' 4 12/1/1974 Sqz D 3,936' 3,940' 3,936' 3,940' 4' 12 10/8/2005 Open E 4,096' 4,379' 4,096' 4,379' 50' 12 10/8/2005 Open F 4,446' 4,774' 4,446' 4,774' 20' 12 11/18/1988 Open F 4,475' 4,732' 4,475' 4,732' 51' 12 10/8/2005 Open G 4,916' 5,086' 4,916' 5,086' 96 12 11/18/1988 Behind Blank Pipe H 5,398' 5,516' 5,398' 5,516' 72 12 11/15/1988 DST #6 H 5,681' 5,758' 5,681' 5,758' 43 4 12/1/1974 Sqz I 5,820' 5,848' 5,820' 5,848' 28' 4 11/28/1974 DST#4 I 6,026' 6,076' 6,026' 6,076' 44' 4 11/27/1974 DST#3 I 6,117' 6,145' 6,117' 6,145' 35 4 11/23/1974 DST#2 I 6,422' 6,470' 6,422' 6,470' 32 4 11/21/1974 DST#1 ,!YY BRU 224-13 S013N010W BELUGA RIVER UNIT BRU 224-13 BRU M PAD 0 250 500 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 BELUGA RIVER BRU 224-13 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well SymbolYSuspended Suspended Well Inspection Review Report InspectNo: susLOL200620064840 Fluid in Cellar? Date Inspected: 6/16/2020 7' Inspector: Lou Laubenstein Type of Inspection: Subsequent Well Name: BELUGA RIV UNIT 224-13 Date AOGCC Notified: 6/15/2020 Permit Number: 1730370 Operator: Hilcorp Alaska, LLC Suspension Approval: Sundry H 314-375 - Operator Rep: Zachary Rohr Suspension Date: 7/22/2014 Wellbore Diagram Avail? Location Verified? ❑O Photos Taken? ❑� ' If Verified, How? GPS Offshore? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar? D IA: 7' BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead was in good condition and had no signs of leaks or mechanical issues. Condition of Cellar Cellar box was in good condition and free of debris, It was about 50% full of fresh water run-off. Surrounding Surface Condition The surrounding area of the well is boxed in with concrete barriers, beyond that the pad is clear of any trash orsigns of y spillage. Comments This well looks good and also has easy accses to be checked on at anytime. ✓ Supervisor Comments Photos(4) ' Friday, July 17, 2020 h O U X O b O O MI m N,. b STATE OF ALASKA • ALA—..A OIL AND GAS CONSERVATION COM. _SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed Suspend r Perforate r Other Stimulate rAlter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Suspend Well Inspect , 17,• Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I Exploratory r 173-037 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-283-20042-00-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL 58831 BRU 224-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): BELUGA RIVER FIELD/UNDEFINED GAS POOL 11 Present Well Condition Summary: Total Depth measured 10000 feet Plugs(measured) CMT RETAINER-3250' true vertical 10000 feet Junk(measured) ER PACKER FISH-3450' Effective Depth measured 3250 feet Packer(measured) SEE BELOW true vertical 3250 feet (true vertical) SEE BELOW Casing Length Size MD TVD Burst Collapse CONDUCTOR 40 30 65 65 CONDUCTOR 398 20 423 423 1530 520 SURFACE 3261 13 3/8 3298 3298 3090 1540 PRODUCTION 6974 9 5/8 6999 6999 6870 4750 Perforation depth: Measured depth: 3322'-6470' True Vertical Depth: 3322' 6470' S�.A NNED !U L 0 9 Z U 15 E C E D Tubing(size,grade,MD,and TVD) 3 1/2, L-80, 3013' MD, 3013'TVD 4t� .I1_ N 1 0 2015 AOGCC Packers&SSSV(type,MD,and TVD) CEMENT RETAINER-3250' MD, 3250'TVD SSSV-NONE 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25 071,&25 283) 15 Well Class after work: Daily Report of Well Operations (•i Exploratory r Development rv7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16 Well Status after work: Oil 7 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt' N/A Contact Rachel Kautz Email Rachel.Kautz(a�conocophillips.com Printed Name Rachel Kautz Title Well Integrity Engineer Signature / Phone 263-4409 Date //,% / RBDMA �, c 7 IS- JUN 1 1 2015 _ ._ ._ . _ .7. _.__._ i_ •,/..-/._/ ,. . .. . . _ ConocoPhillips RECEIVED Alaska !U N 10 2015 P.O. BOX 100360 OG CC ANCHORAGE,ALASKA 99510-0360 June 10, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Beluga River Unit 224-13 (PTD 173-037) Dear Commissioner Foerster: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Beluga River Unit well 224-13 (PTD 173- 037). This well was suspended July 22, 2014. The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Rachel Kautz at 263-4409 if you have any questions. Sincerely, Rachel Kautz ConocoPhillips Well Integrity Engineer Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: BELUGA RIV UNIT 224-13 Field/Pool: BELUGA RIVER/UNDEFINED Permit# (PTD): 173-037 Sundry 314-429 API Number: 50-283-20042-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 7/22/2014 Surface Location: 1012' FSL, 2194' FWL Section: 13 Township: 13N Range: 10W Nearest active pad or road: K Pad Meridian: SEWARD Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: N/A Surrounding area condition: Good Water/fluids on pad: Rain water Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (#and description): 2 Pictures of Pad and Location Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good, valves operational Cellar description, condition, fluids: Good, rain water in cellar Rat Hole: N/A Wellhouse or protective barriers: Jersey barriers and cones Well identification sign: None Tubing Pressure (or casing if no tubing): Tubing pressure: 0 psi Annulus pressures: IA pressure: 0 psi, OA pressure: 25 psi Wellhead Photos taken (#and description): 4 pictures of wellhead Work Required: Operator Rep (name and signature): Michael Lott AOGCC Inspector: Johnny Hill Other Observers: Rachel Kautz Inspection Date: 6/5/2015 AOGCC Notice Date: 5/26/2015 Time of arrival: 11:00 AM Time of Departure: 11:15 AM Site access method: Vehicle Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: BELUGA RIV UNIT 224-13 Field/Pool: BELUGA RIVER/UNDEFINED Permit#(PTD): 173-037 Sundry 314-429 API Number: 50-283-20042-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 7/22/2014 Surface Location: 1012' FSL, 2194' FWL Section: 13 _ Township: 13N Range: 10W Nearest active pad or road: f3(LU K Pa,() Meridian: SEWARD Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore-diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: -')Q p Pad or location surface: 6-00 p Location cleanup needed: Nj f, Pits condition: (/ Surrounding area condition: (•f 00 d Water/fluids on pad: s/A1i,1L Discoloration, Sheens on pad, pits or water: NO Samples taken: N p or, Access road condition: &-000 Photographs taken (#and description): i G-r v n e S o f CIS 0 4 L O c yk 7/C N Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: y 00P4 VA(.` r 5 eM?'-'n o Nfi(, Cellar description, condition, fluids: (s-oof . fj jN W ATL / Rat Hole: ((// Wellhouse or protective barriers: /--Y' (1-1611- 4 GoNis ' Well identification sign: No �t Tubing Pressure (or casing if no tubing): 4, 'Tt/�I+�Cr, Z5 p4j Annulus pressures: IPI :#j 5 I ' 4)fl ZL, 65: Wellhead Photos taken (#and description): ei( 1 f11C3 ( wCir%-rAD Work Required: y�fJ / Operator Rep(name and signature): .0711 .14.e AOGCC Inspector: 1-cii Other bservers: r' C IZ Alir Inspection Date: 6 5// AOGCC Notice Date: Time of arrival: / nJ Oa I Iv\ Time of Departure: I I : I Site access method: t/Olic (, , • i SAK PROD BRU 224-13 ConocoPhillips u Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cmnrdtullipe 502832004200 BELUGA RIVER UNIT PROD 0.00 0.00 10,000.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date BRU 224-13.3/1220152.21.30 PM SSSV:NIPPLE Last WO: 10/19/2005 18.20 12/16/1974 Vertical schema__(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date IIIIaaY HANGER;212- 1 Last Tag: 4,480.0 11/26/2009 Rev Reason:WORKOVER-WELL SUSPENDED haggea 8/13/2014 s �n.ti CONDUCTOR'25.065.0 1 j w,r Casing Strings SURFACE:25.04233.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 30 29.000 25.0 65.0 65.0 94.00 H-40 WELDED Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CEMENT RETAINER;3,250.0 SURFACE 20 19.124 25.0 423.0 423.0 94.00 H-40 Butt Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE;36.63,297.8 INTERMEDIATE 133/8 12.415 36.8 3,297.8 3,297.8 68.00 K-55 Butt CMT SOZ;3,322.03,323.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread RPERF;3,356.03,361.0 PRODUCTION 95/8 8.861 25.0 6,999.1 6,999.1 47.00 P110 Butt RPERF;3,376.03.396.0 Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread RPERF;3.375.0,3,398.0� OPEN HOLE 8 12 6,999.1 10,000.0 10,000.0 RPERF;3.422.0-3,431.0 r FISH;3.450.01 Tubing Strings PACKER;3,471.0. Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Set Depth(TVD)(...'Wt(lb/ft) Grade Top Connection SEAL BORE;3,491.1 ' '. KILL STRING 31/21 2.9921 21.21 3,013.01 3,013.01 9.301 L-80 'Top 8rd PACKER;3,493.8 PATCH;3.473.0 r Completion Details SEAL BORE;3,497.0 a S ,500.0 r Nominal ID UPPER EXT;3 SLEEVE;3,502.6.„,...g:J Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Corn (m) SEAL BORE;3.507.3 II • 21.2 21.2 0.00 HANGER VETCO GRAY TUBING HANGER 5500 • LOWER EXT;3,510.1 SEAL BORE;3,515.4, • 25.6 25.6 0.00 XO Reducing Crossover 5 1/2"x 3 1/2" 2.992 TUBING XO THREAD;3,518.4 Tubing Description String Ma..ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft. Top Connection PACKER;3,524.0 rGRAVEL PACK 1 6.111 4.8921 3,401.0 4,747.41 4,747.41 1 Grade 1SLHT CMT SOZ;3,525.03,526.0 --- _ Completion Details APERF;3,550.03,570.0 - Nominal ID CMT S02;3.660.03662.0 -- Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) - 3,491.1 3,491.1 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 APERF;3.673.03.683.0 ■ APERF;3,760.03.776.0, _ ■ 3,493.6 3,493.6 0.00 PACKER UPPER MIDDLE ISO PACKER BAKER SC1-L PACKER 5.000 CMT SOZ;3.755.03,760.0 N 3,497.0 3,497.0 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 GAS UFT;3,789.8 s SEAL BORE;3,810.9 SI 3,500.0 3,500.0 0.00 UPPER EXT BAKER 190-47 UPPER EXTENSION 5.750 PACKER;3,813.4 3,502.6 3,502.6 0.00 SLEEVE MODEL-C ISO PROTECTION SLEEVE(OPENS DOWN) 5.870 I SEAL BORE;3,816.81 I,. UPPER EXT;3,819.9 SLEEVE-C;3.822.5 3,507.3 3,507.3 0.00 SEAL BORE BAKER GRAVEL PACK SEAL SBORE 4.750 SEAL BORE;3,827.1, LOWER EXT;3,830.0ii 3,510.1 3,510.1 000 LOWER EXT BAKER 190-47 LOWER EXTENSION 5.870 SEAL BORE;3,835.3 3,515.4 3,515.4 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 APERF;3,936.03,940.0, all3,547.6 3,547.6 0.00 BLAST JOINT 4.892 SCREEN;3,937.3, - APERF;4,096.0-4.102.0 3,665. 3,665.8 0.00 BLAST JOINT 4.892 SCREEN;4,031.2 APERF;4.138.04.148.0 APERF;4,157.04.170.01 - . ' 3,810.9 3,810.9 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 SEAL BORE;4,181.7- al - 3,813.4 3,813.4 0.00 PACKER LOWER MIDDLE ISO PACKER 96A4-6OSC1-L PACKER 5.000 PACKER;4,184.3 SEAL BORE;4,187.7 + UPPER EXT;4,190.7 _= 3,816.8 3,816.8 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 SLEEVE;4,193.3 SEAL BORE;4,198.0 1W-'1 3,819.9 3,819.9 0.00 UPPER EXT BAKER 190-47 UPPER EXTENSION 5.750 LOWER EXT;4200.8, SEAL BORE;4,216.1 3,822.5 3,822.5 0.00 SLEEVE-C 190-47 GRAVEL PACK SLIDING SLEEVE(OPENS 5.870 DOWN) 1 APERF;4,260.04,265.0 - Mr 3,827.1 3,827.1 0.00 SEAL BORE BAKER GRAVEL PACK SEAL BORE 4.750 APERF;4,357.04,303.0 APERF;4348.04,354.0.E 3,830.0 3,830.0 0.00 LOWER EXT BAKER 190-47 LOWER EXTENSION 5.740 RPERF;4,375.04,379.0 SCREEN;4,258.81 - 3,835.3 3,835.3 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 APERF;4,446.04,456.0, a APERF;4,475.04.490.0mg 3,937.3 2937.3 0.00 SCREEN .. EXCLUDER 2000 MED SCREEN 4.892 RPERF;4,475.0-4,490.0,_ RPERF:4,593.04,803.0 4,031.2 4,031.2 0.00 SCREEN - EXCLUDER 2000 MED SCREEN 4.892 APERF:4,693.04,603.0 i APERF;4,624.04,626.0 4,181.7 4,181.7 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 SCREEN;4,558.5 # 4,184.3 4,184.3 0.00 PACKER LOWER ISO PACKER 96A4-60 SC1-L 5.000 APERF;4,676.04,694.0 RPERF;4,676.04,694.0 _. = 4,187.7 4,187.7 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 APERF;/,70-4,742.0 - al PACKER;4,742.0, 4,190.7 4,190.7 0.00 UPPER EXT BAKER 190-47 UPPER EXTENSION 5.750 SNAP LATCH;4,746.5 EXT MILL OUT EXT;4,744.1- 4,193.3 4,193.3 0.00 SLEEVE 190-47 GRAVEL PACK SLIDING SLEEVE(OPENS 5.870 00 TUBING THREAD;4,7536 it DOWN) APERF;4,764.04,774.0 _ 4,198.0 4,198.0 0.00 SEAL BORE BAKER GRAVEL PACK SEAL SBORE 4.750 APERF;4,916.04,924.0 4,200.8 4,200.8 0.00 LOWER EXT BAKER 190-47 LOWER EXTENSION 5.870 RPERF;4,936.04,958.0 4,206.1 4,206.1 0.00 SEAL BORE BAKER 190-47 SEAL BORE 4.750 RPERF;4,966.04,986.0 IPERF;5,0220.5,032.0 4,258.8 4,258.8 0.00 SCREEN EXCLUDER 2000 MED SCREEN 4.892 APERF;5,050.06.056.0 - 4,559.5 4,559.5 0.00 SCREEN EXCLUDER 2000 MED SCREEN 4.892 APERF;5,056.05,086.0 RPERF;5,398.05.448.0 - 4,746.5 4,746.5 0.00 SNAP LATCH BAKER 190-60 SNAP LATCH 4.875 NIPPLE;5,452.9 In Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PLUG;5,452.9 r SUMP PACKER 5 12 4.950 4,742.0 5,479.3 5,479.3 15.50 L-80 BTC SNAP LATCH;5,463,2 ILIA PACKER;5,464.4 Completion Details MILL OUT EXT;5.468.9 1, Nominal ID WLEG;5,478.3 - - 4 To (ftKB) To NO ftKB To I Item Des Com (in) APERF;5.4700-5,528.0 AU P P(TVD)(ftKB) P Incl ) APERF;5,49405,516.0 4,742.0 4,742.0 0.00 PACKER BAKER 197-60'F'PERMANENT PACKER 6.000 FISH;5,577.0 4,744.1 4,744.1 0.00 MILL OUT MILLOUT EXTENSION 4.950 FISH;5.587.0 ttr' EXT FISH;5,654.0 FISH;5,654.5 - 5,452.9 5,452.9 0.00 NIPPLE HES'XN'NIPPLE 6.000 PLUG;5,660.0 5,463.2 5,4632 0.00 SNAP LATCH BAKER SNAP LATCH 6.625 CMT SOZ;5,681.0-5,689.0- 5,464.4 5,464.4 0.00 PACKER BAKER SC-1R RETRIEVABLE SUMP PACKER 6.625 CMT SOZ;5,705.05,725.0 CMT SO2;5,743.05,758.0 - 5,468.9 5,468.9 0.00 MILL OUT MILLOUT EXTENSION 6.625 IPERF;5.827.05,848.0 - EXT IPERF;6626.06.038.0 - 5,478.3 5,478.3 0.00 WLEG WIRELINE ENTRY GUIDE 6.000 (PERF;6,044.5b.076.0 Tubing Description String Ma..ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection IPERF;6.t17.Ob,121.0 TUBING WO 3,110.0) 3,1100 IPERF;6.135.0-6136.0 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IPERF;6,138.06,145.0 IPERF;6,159.06,176.0 - Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) IPERF;6,422.0-6,440.0 - 3,250.0 3,250.0 0.00 CEMENT SET CEMENT RETAINER 7/20/2014 ' 1.000 ' IPERF;6.448.;6454.0 RETAINER IPERF;6,462.0-5470.0 3,450.0 3,450.0 0.00'FISH ER PACKER PUSHED TO 3450'w/CTU 11/17/2009 3.000 ^PRODUCTION;25.0-6999.11 } • • SAK PROD BRU 224-13 ConocoPhillips g Alaska.Inc. Cnarr-Ph,llyn • "• BRU 224-13.3/1212015221:31 PM Vertical schematic(actual) HANGER;21 2- ' W �,�,�CONDUCroa zs.oss.o Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;25.0-423.0 Top(ND) Top Incl Top(RKB) (RKB) (°) Des Com Run Date ID(in) 3,471.0 3,471.0 0.00 PACKER UPPER ER PACKER 4/18/2007 3.000 CEMENT RETAINER;3250.0 3,473.0 3,473.0 0.00 PATCH TUBING PATCH 4/18/2007 3.000 INTERMEDIATE;36.8-3,297.8 >'l 3,524.0 3,524.0 0.00 PACKER LOWER ER PACKER 4/18/2007 3.000 GMT SOZ;3,322.0-3.323.0 5,452.9 5,452.9 0.00 PLUG PXN PLUG SET IN NIPPLE 10/8/2005 0.000 RPERF;3,355.0-3,361.0 RPERF;3,376.0-3.396.0 5,577.0 5,577.0 0.00 FISH Casing Gun 10'Dresser Atlas 12 SPF casing guns 12/1/1988 0.000 RPERF:3.375.03.398.0' (top 10'DNF)pushed to 5577'11/18/88 RPERF;3.FISH;3,431.05,587.0 5,587.0 0.00 FISH CasingGun 10'Dresser Atlas 12 SPF CasingGun 12/1/1988 0.000 FISH;3.450.0-\_.;4.1 w:4 PACKER;3,471.0a 1 (top 10'DNF)pushed to 5577 11/18/88 SEAL BORE;3,491.1 4' PACKER;3,493.6' _ 5,654.0 5,654.0 0.00 FISH X-Over Sub 3.5"reg box by 3.5"IF pin 12/1/1988 3.500 PATCH;3473.0 SEAL BORE;3,487.01 5,654.5 5,654.5 0.00 FISH Junk Mill 12/1/1988 3.500 UPPER EXT;3,500.0 1 5,660.0 5,660.0 0.00 PLUG BRIDGE PLUG SET DURING COMPLETION 1/1/1981 0.000 SLEEVE;3,502.6 { SEAL BORE;3,507.3 `8Is.h LOWER EXT;3,510.11 a� Perforations&Slots SEAL BORE:3,515.4, If((5 TUBING XO THREAD;3,518.4, ••� Shot PACKER;3,524.0 MIT:. Dens CMT SOZ;3,525.03,526.0 - iii.- Top 01K13) Btm(RKB) Top((40(B) (MB) Zone Date (sht'tslf Type Com APERF;3,550.03,5700 11 3,322.0 3,323.0 3,322.0 3,323.0 STRLNG A, 12/12/1974- 4.0 CMT Perfd for squeeze 8 BRU 224.13 SQZ Tested CMT SOZ:3,660.03.662.0 3,355.0 3,361.0 3,355.0 3,361.0 STRING A, 11/20/1988 12.0 RPERF Orig 4 SPF 3/23/81, APERF;3,673.03,683.0 ! BRU 224-13 Reperfd APERF;3,700.03,776.0 CMT SOZ;3,755.0-3,760.0 3,375.0 3,398.0 3,375.0 3,398.0 STRLNG A, 11/20/1988 12.0 RPERF Orig 4 SPF 3/23/81, s BRU 224-13 Reperfd GAS LIFT;37898 3,376.0 3,396.0 3,376.0 3,396.0 STRLNG A, 11/20/1988 12.0 RPERF Orig 4 SPF 3/23/81, SEAL BORE;3,810.9 BRU 224-13 Reperfd PACKER;3.813.41 SEAL BORE,3.810.8 Ors 3,422.0 3,431.0 3,422.0 3,431.0 STRLNG A, 11/20/1988 12.0 RPERF Orig 4 SPF 3/23/81, UPPER EXT,3.8109-, BRU 224-13 Reperfd p[ SLEEVE-C;3,822.5 rail SEAL BORE;3,827.1-, !I I 3,525.0 3,526.0 3,525.0 3,526.0 STRLNG B, 12/10/1974 4.0 CMT Perfd for squeeze& LOWER EXT;3.830.0 BRU 224-13 SQZ Tested SEAL BORE;3,835.3 - 3,550.0 3,570.0 3,550.0 3,570.0 STRLNG B, 10/8/2005 ' 14.0 APERF HES 7'OD Super Hole APERF;3,938.03.9/0.01 '�.I BRU 224-13 Guns SCREEN;3,937.3 3,660.0 3,662.0 3,660.0 3,662.0 STRLNG A, 12/6/1974 4.0 CMT Perfd for squeeze, RPERF;4,096.04,102.0 IMF SCREEN;4,031 q BRU 224-13 SQZ res ueezed&Tested RPERF;4,138.04.148.0, I 3,673.0 3,683.0 3,673.0 3,683.0 STRLNG B, 10/8/2005 14.0 APERF HES 7'OD Super Hole APERF;4,157.04,170.0 SEAL BORE;4.1817'\ BRU 224-13 Guns PACKER;4,187.3 s 3,700.0 3,776.0 3,700.0 3,776.0 STRLNG C, 10/8/2005 14.0 APERF HES 7'OD Super Hole UPPERUPPER EXT;4.197.7 EXT;4,190.7 BRU 224-13 Guns SLEEVE;4.193.3 SEAL BORE;4,198.01 i 3,755.0 3,760.0 3,755.0 3,760.0 STRING C, 12/10/1974 4.0 CMT Squeezed LOWER EXT;4,210.8.E BRU 224-13 SQZ SEAL BORE;4.206.1 3,936.0 3,940.0 3,936.0 3,940.0 BELUGA D, 10/8/2005 14.0 APERF HES 7"OD Super Hole BRU 224-13 Guns APERF;4.260.64.265.0 APERF;4,297.04,303.0, 4,096.0 4,102.0 4,096.0 4,102.0 BELUGA D, 10/8/2005 14.0 APERF HES 7"OD Super Hole APERF;4.340.04,354.01 - BRU 224-13 Guns RPERF;4,375.04,3790 SCREEN;4,258.8-'(-_ 4,138.0 4,148.0 4,138.0 4,148.0 BELUGA E, 10/8/2005 14.0 APERF HES 7"OD Super Hole APERF;4.446.0J,4560-, __ BRU 224-13 Guns APERF;4,475.04,490.0 RPERF;4,475.04,4900,-" 4,157.0 4,170.0 4,157.0 4,170.0 BELUGA E, 10/8/2005 14.0 APERF HES 7"OD Super Hole RPERF;4,593.04,603.0 - BRU 22413 Guns APERF;4,593.04,6030 'I 4,6 APERF;4,824.0280 4,260.0 4,265.0 4,260.0 4,265.0 BELUGA E, 10/8/2005 14.0 APERF HES 7"OD Super Hole SCREEN;4,55951 APERF;4,678.04,694.0 BRU 224-13 Guns RPERF;4,676.04,694.0 '- 4,297.0 4,303.0 4,297.0 4,303.0 BELUGA E, 10/8/2005 14.0 APERF HES 7"OD Super Hole APERF;4728.04,732.0 - BRU 224-13 Guns PACKER;4,742.0-, SNAP LATCH;4,746.5, 4,348.0 4,354.0 4,348.0 4,354.0 BELUGA E, 10/8/2005 14.0 APERF HES 7"OD Super Hole MILL OUT EXT;4,744.1 BRU 224-13 Guns XO TUBING THREAD;4,753.6 APERF;4,764.04,774.0 - - 4,375.0 4,379.0 4,375.0 4,379.0 BELUGA E, 10/8/2005 14.0 APERF HES 7'OD Super Hole BRU 224-13 Guns APERF;4,916.04,924.0 - 4,446.0 4,456.0 4,446.0 4,456.0 BELUGA F, 11/18/1988 12.0 APERF RPERF;4,936.04,958.0 - BRU 224-13 RPERF;4,966.04,986.0 IPERF;5.022.050320 - 4,475.0 4,490.0 4,475.0 4,490.0 BELUGA F, 10/8/2005 14.0 RPERF HES T OD Super Hole APERF;5,050.05,056.0 BRU 224-13 Guns APERF;5056.65,086.0 - - 4,475.0 4,490.0 4,475.0 4,490.0 BELUGA F, 11/18/1988 12.0 APERF RPERF;5,398.05,448.0 - BRU 224-13 NIPPLE;5,452.9 - - - PLUG;5,452.91 - 4,593.0 4,603.0 4,593.0 4,603.0 BELUGA F, 10/8/2005 14.0 RPERF HES 7"OD Super Hole SNAP LATCH;5,463.2 '` BRU 224-13 Guns aw PACKER;546/.41 NI MS MILL OUT EXT;5,468.9 4,593.0 4,603.0 4,593.0 4,603.0 BELUGA F, 11/18/1988 12.0 APERF WLEG;5,478.3, - 4 BRU 22413 APERF;5,470.05,528.0 so APERF;5,494.05,516.0 4,624.0 4,626.0 4,624.0 4,626.0 BELUGA F, 10/8/2005 14.0 APERF HES 7"OD Super Hole BRU 224-13 Guns FISH;5,577.0 FISH;5,587.0 ' 4,676.0 4,694.0 4,676.0 4,694.0 BELUGA F, 10/8/2005 14.0 RPERF HES 7"OD Super Hole H;55,654,05-, BRU 224-13 Guns FISFISH; 654 -- PLUG;5,660.0 WE 4,676.0 4,694.0 4,676.0 4,694.0 BELUGA F, 11/18/1988 12.0 APERF CMT SOZ;5,681.0-5,689.0 - BRU 224-13 CMT SW;5,705.65,725.0 - • 4,728.0 4,732.0 4,728.0 4,732.0 BELUGA F, 10/8/2005 14.0 APERF HES 7"OD Super Hole CMT SOZ;5743.05758.0 - - BRU 224-13 Guns IPERF;5,821.65,848.0 - 4,764.0 4,774.0 4,764.0 4,774.0 BELUGA F, 11/18/1988 12.0 APERF IPERF;6,026.06,038.0 - '- BRU 224-13 IPERF;6044.06,076.0 4,916.0 4,924.0 4,916.0 4,924.0 BEWGA G, 11/18/1988 12.0 APERF IPERF;6,117.06,121.0 - BRU 224-13 IPERF;6.129.06.136.0 IPERF;6,138.68,145.0 - 4,936.0 4,958.0 4,936.0 4,958.0 BELUGA G, 12/4/1974 12.0 RPERF Orig 4 SPF,Reperfd BRU 224-13 IPERF;6.159.06,176.0 IPERF;6,422.66.440.0 4,966.0 4,986.0 4,966.0 4,986.0 BELUGA G, 12/4/1974 12.0 RPERF Orig 4 SPF,Reperfd IPERF;6,448.06,454.0 BRU 224-13 IPERF;6,462.06.4700 - 5,022.0 5,032.0 5,022.0 5,032.0 BELUGA G, 12/4/1974 4.0 IPERF BRU 224-13 PRODUCTION;250-6,999.1, OPEN HOLE;6.999.1-10,000.0 --, SAK PROD BRU 224-13 ConocoPhillips Alaska,Inc. r•.o. irouutn BRU 224-13.3/12/2015 2:21:32 PM Vertical schematic(actual) HANGER;21.2_ ,,AA_CONDUCTOR 25.065.0 . • Perforations&Slots SURFACE;25.0-423.0 Ul Shot Dens Top(ND) Btm(ND) (shotsk CEMENT RETAINER;3,250.0 Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Corn 5,050.0 5,056.0 5,050.0 5,056.0 BELUGAG, 11/18/1988 12.0 APERF BRU 224-13 INTERMEDIATE;36.8-3297.8 CMT SOZ;3,322.0-3,323.0 - 5,056.0 5,086.0 5,056.0 5,086.0 BELUGAG, 11/15/1988 12.0 APERF RPERF;3,355.0-3,361.0 ` BRU 224-13 RPERF;3,378.0-3,396.0 5,398.0 5,448.0 5,398.0 5,448.0 BELUGAH, 12/2/1974 12.0 RPERF Orig 4 SPF,Reperfd, RPERF;3,422.0-3.4431.031.0 RPERF;3,375.0-3. BRU 224-13 Open FISH;3.450.01_ , 5,470.0 5,528.0 5,470.0 5,528.0 BELUGAH, 12/2/1974 12.0 APERF PACKER;3,471.0 SEAL BORE;3,491.1 WI BRU 224-13 ` PACKER;3,493.6 BORE;ORE;3,497.0 5,494.0 5,516.0 5,494.0 5,516.0 BELUGAH, 11/15/1988 12.0 APERF Open _atlIt SEAL PATCH; P 3,497.0 l:r t BRU 22413 UPPER EXT;3.5000 5,681.0 5,689.0 5,681.0 5,689.0 BELUGAH, 11/30/1974 4.0 CMT Squeezed SLEEVE;3,502.6\ rL$, q SEAL BORE;3,507.31 dl j' BRU 224-13 SQZ LOWER EXT;3,510.1, SEAL BORE;3,515.4 5,705.0 5,725.0 5,705.0 5,725.0 BELUGA H, 11/30/1974 4.0 CMT Squeezed TUBING XO THREAD;3.518.4Iri BRU 224-13 SQZ PACKER: 4' CMT SOZ;3,525..03.526.0 *`_ 5,743.0 5,758.0 5,743.0 5,758.0 BELUGAH, 11/30/1974 4.0 CMT Squeezed BRU 224-13 SQZ APERF;3,550.03,570.0 ll 5,820.0 5,848.0 5,820.0 5,848.0 BELUGA I, 11/28/1974 4.0 IPERF Set BP @ 5800' CMT SOZ;3,660.03,662.011! BRU 224-13 APERF;3,673.03.683.0 6,026.6 6,038.0 6,026.0 6,038.0 BELUGA I, 11/26/1974 4.0 IPERF Set BP @ 6000' RPERF;3,700.03,776.0 BRU 224-13 CMT SOZ;3,755.03,760.0 6,044.0 6,076.0 6,044.0 6,076.0 BELUGA I, 11/26/1974 4.0 IPERF a. GAS LIFT;3789.8 9 BRU 22413 SEAL BORE;3,810.9 6,117.0 6,121.0 6,117.0 6,121.0 BRELUGA I,U 224-13 11/23/1974 4.0 IPERF Set BP @ 6145'&6106' BPACKER;3,813.4 -g SEALBORE;3,816.8 == PEI UPPER EXT;3,819.9 6,129.0 6,136.0 6,129.0 6,136.0 BELUGA I, 11/23/1974 4.0 IPERF SLEEVE-C;3,822.5 I� ` BRU 22413 SEAL BORE;3,827.1 11 6,138.0 6,145.0 6,138.0 6,145.0 BELUGA I, 11/23/1974 4.0 IPERF LOWER EXT;3,830.0, _ BRU 224-13 SEAL BORE:3,835.3 APERF;3,936.03,910.0 • 6,159.0 6,176.0 6,159.0 6,176.0 BELUGA I, 11/23/1974 4.0 IPERF •• BRU 224-13 SCREEN;3,937.3 • APERF;4096.0.4,102.0 i 6,422.0 6,440.0 6,422.0 6,440.0 BELUGA I, 11/21/1974 4.0 IPERF Set BP @ 6375' • • SCREEN;4031.2 - UPBRU 224-13 RPERF;4,138.04,148.0, i RPERF;4157.44,170.0 6,448.0 6,454.0 6,448.0 6,454.0 BELUGA I, 11/21/1974 4.0 IPERF SEAL BORE;4,181.71 BRU 224-13 PACKER;4,184.3 SEAL BORE;4187.7 `i UPPER EXT;4,190.7 a . 6,462.0' 6,470.0 6,462.0 6,470.0 BELUGA I, 11/21/1974 4.0 IPERF SLEEVE;4.193.3 iBRU 22413 SEAL BORE;4.198.0-. �, LOWER EXT:4,200.8, _ Cement Squeezes SEAL BORE;4,206.1 l w Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (kKB) (kKB) Des Start Date Corn APERF;4,260.04,265.0 .' 3,253.0 3,471.0 3,253.0 3,471.0 Cement Plug 7/20/2014 16.2 bbls APERF;4.297.0-4,303.0..-_. 3,255.0 3,471.0 3,255.0 3,471.0 Cement Squeeze 7/20/2014 21.4 APERF;4348.0.4,354.0, APERF;4,375.0-4,379.0, a' SCREEN;4,258.8,1 ant 3,160.0 3,253.0 3,160.0 3,253.0 Display Cement 7/20/2014 APERF;4,446.04,456.0 Fill APERF;4475.44,490.0 . 111 -, RPERF;4,475.04.490.04 Notes:General&Safety RPERF;4,593.04,603.0 • End Dale Annotation APERF;4,593.44,603.0 li APERF;4,624.04.6260 . 6/29/1998 NOTE:TAG DATA: SCREEN;4,559.5 APERF;4,676.04.694 0mea String 1: RPERF;4,676.0x,694.01- 4.4.41.4 5/6/91 1.5"bailer,fill at 5507'RKB APERF;4.728.44732.0 6/21/92 1.75'bailer,fill PACKER;4,7420 ilk SNAP LATCH;4746.51 _. 6/29/1998 NOTE:1988 WO-Left in Hole: MILL OUT EXT;4.744.1- , XO TUBING THREAD;4,753.6 s 6.5"OD junk mill&4.75"OD X-over sub at 5654'on 11/12/88 APERF;4,764.04.774.0 $MD _ APERF;4,916.04.924.0 RPERF;4.936.0-4.958.0 RPERF;4,966.0x,986.0 IPERF;5,022.05.032.0 APERF;5,050.05.056.0 APERF;5,056.05,086.0 RPERF;5398.0-5448.0 NIPPLE;5.4529 ' PLUG;5,452.9 . ihip SNAP LATCH;5,463.2 Imo PACKER;5,484.4, se pa MILL OUT EXT;5,468.9 WLEG;5,478.31 P APERF;5,470.45.528.0, APERF;5,494.05,516.0 s t FISH;5,577.0 1 FISH;5.587.0 FISH;5,654.0, FISH;5,654.5 PLUG;5,660.0 CMT SO2;5,681.05.689.0 CMT SOZ;5.705.0-5,725.0 CMT SOZ;5,743.05758.0 IPERF;5.820.45,848.0 - IPERF;6,026.46.038.0 IPERF;6,044.46.076.0 IPERF;6,117.46.121.0 IPERF;6.129.06.136.0 - IPERF;6,138.0.8.145.0 IPERF;6,159.06,176.0 IPERF;6.422.0.8.440.0 IPERF;6,448.05.454.0 IPERF;6,462.08.470.0 PRODUCTION;25.0.6,999.1, OPEN HOLE;6,999.1-10,000.0.„,___,.. , r ,l i { rt :..a. r Air. 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Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 07/22/14 Date AOGCC Notified: 06/01/15 - Sundry No.: 314-429 Type of Inspection: Subsequent_ Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 - OA 25 - � p AUG 1 9 2,05. Condition of Wellhead: good and clean-no well house Condition of Surrounding Surface Location: good and clean Follow Up Actions - Needed: none noted Comments: Attachments: Photos(4) REVIEWED BY: Insp.Supry J r7F--V/51 Comm PLB 06/2014 2015-0605_Suspend BRU_224-13jh.xlsx Suspended Well Inspection— BRU 224-13 PTD 1730370 Photos by AOGCC Inspector J. Hill 6/5/2015 ' �j .t {' s uiiii saspar - ' •~ ..� 6a P. i Illb. #7 •,,,,,,, btat4" 1 _. 4 .e C a . 9 1 r " 1 4 1. . y .. 2015-0605_Suspend_BRU_224-13 photos,j h.do cx Page 1 of 2 , r * * ;17 Y 4yp'y$ A f z s e „g,'A 41 r 3 t .- • f 104 • 4. %1F° f . W f ' \ • ' l< M • 4 @. a ,.. :. .ry ei y r 2015-0605_Suspend_BRU_224-13photos,j h.docx Page 2 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, October 15, 2014 11:53 AM To: 'Huck, Drew' Cc: Brooks, Phoebe L (DOA) Subject: RE: Doyon 1 BOPE test report Attachments: BOP Doyonl 7-10-14.xlsx Revised report attached based on my review of the charts. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 P?P_L� 22447;. PTt> t-7-303 70 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 orjim.regg@alasl<a.gov. From: Huck, Drew [mailto:Andrew.Huck@conocophillips.com] Sent: Tuesday, October 14, 2014 5:28 PM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Heim, Scott D; Dolcater, Randall L (SolstenXP); Herbert, Frederick 0; Whitlock, Guy D (SolstenXP); Mickey, Don (SolstenXP) Subject: RE: Doyon 1 BOPE test report Jim, I've found the original charts so it's a bit easier to see what's going on. See my answers below: - Remarks don't match test results regarding failure (Manual Choke referenced in Remarks; Kill Line Valves shown as FP); is this supposed to be Manual Kill Line Valve instead of Manual Choke? o This appears to be an error. If you look at test #8, it looks like the Manual kill and manual choke were tested together, once before they were greased (which failed) and once after (which passed). In this case, both the Choke Ln. Valves and Kill Lines Valves should both have been marked FP I think. - Charts indicate several questionable tests. Please describe your interpretation of the low and high pressure results for Lower Pipe Rams, Upper IBOP, and Lower IBOP on 7/10/14. o I'm assuming you're referring to #10, #11, and #12. Our interpretation is that the low segments are relatively flat other than the initial decline on #12 and the last segments of the high tests level off. Please let us know if you have further questions. Regards, %A*0 OCT, 2 c.li 4 Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. A TO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 14, 2014 2:12 PM To: Huck, Drew Cc: Brooks, Phoebe L (DOA); Heim, Scott D; Dolcater, Randall L (SolstenXP) Subject: [EXTERNAL]RE: Doyon 1 BOPE test report 7/10/14 MASP is 777psi according to approved Sundry 314-375 Remarks don't match test results regarding failure (Manual Choke referenced in Remarks; Kill Line Valves shown as FP); is this supposed to be Manual Kill Line Valve instead of Manual Choke? Charts indicate several questionable tests. Please describe your interpretation of the low and high pressure results for Lower Pipe Rams, Upper IBOP, and Lower IBOP on 7/10/14. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th 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, arid, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Huck, Drew[ma ilto: Andrew. Huck@conocophillips.com] Sent: Friday, October 10, 2014 1:37 PM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Heim, Scott D; Dolcater, Randall L (SolstenXP) Subject: RE: Doyon 1 BOPE test report Jim, I've found everything but the test chart from 7-10 — I'll find that and send, but I wanted to send these as soon as I could. I apologize for the mix-up. Regards, Pi Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. A TO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Regg, James B (DOA) [mailto:jim.reg_q@)alaska.gov] Sent: Friday, October 10, 2014 10:45 AM To: Huck, Drew Cc: Brooks, Phoebe L (DOA) Subject: [EXTERNAL]FW: Doyon 1 BOPE test report AOGCC has attempted several times to clarify the BOPE test reports performed by Doyon 1 at Beluga River Unit. The reports in question are attached — it appears the report for 7/10/14 was submitted twice (perhaps someone forwarded the wrong attachment). I need someone from CPAI to provide the correct reports for both 7/10/14 along with the test charts for tests on both dates. We would appreciate receiving these reports as soon as possible. Please copy Ms. Brooks when you send the requested reports. Thank you. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th 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 iim.regg@alaska.gov. From: Brooks, Phoebe L (DOA) Sent: Tuesday, October 07, 2014 4:16 PM To: Regg, James B (DOA) Subject: FW: Doyon 1 BOPE test report Hi Jim, I was wondering if you had another point of contact as I have not received a response on this? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 3 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (DOA) Sent: Tuesday, September 30, 2014 9:50 AM To: 'arcticfox@doyondrilling.com' Cc: Regg, James B (DOA) Subject: RE: Doyon 1 BOPE test report I was following up on this email. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 in.formatio.n. '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 Phoebe Brooks at 907-793-1.242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (DOA) Sent: Wednesday, September 24, 2014 2:48 PM To: 'arcticfox@doyondrilling.com' Subject: Doyon 1 BOPE test report I was reviewing July reports and it looks like the 7/10/14 report was submitted twice (on 7/10/14 and on 7/17/14); Jim Regg sent a correction to the MASP on the report, but I was wondering if there should have been a 7/17/14 Weekly Workover report? If so, please forward this. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or 12hoebe.brooks@alaska.gov. n �1E'Cil ScA (V PO%r — STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regg(a�alaska.gov AOGCC.Inspectors(a)alaska.gov Phoebe. brooks(a.alaska.gov Contractor: Doyon Rig No.: 1 DATE: 7/10/14 Rig Rep.: Charles Huntington Rig Phone: 907-263-3012 Operator: Conoco/Phillips Op. Phone: 907-263-3010 Rep.: D.Mickey/G. Whitlock E -Mail afoxcm14a@conocophillips.com Well Name: BRU 224-13 PTD # 1730370 Sundry # 314-375 Operation: Test: Test Pressure (psi): Drilling: Initial: Rams: X 250/3000 Workover: X Explor.: Weekly: Bi -Weekly: Annular: 250/3000 Valves: 250/3000 MASP: 777 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 FP Housekeeping P Rig P Lower Kelly 1 FP PTD On Location P Hazard Sec. NA Ball Type 1 P nding 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 11X5000 P Pit Level Indicators P P #1 Rams 1 51/2 P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 27/8X5 FP 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 31/8x5000 FP Inside Reel valves 0 NA HCR Valves 2 31/8x5000 P Kill Line Valves 2 31/8x5000 FP 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) 1900 P Quantity Test Result 200 psi Attained (sec) 22 P No. Valves 15 P Full Pressure Attained (sec) 112 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (# and psi): 6 @ 2200 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 5 Test Time: 9.0 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 5.5" and 5" test joint, all tests were 250 PSI low and 3000 PSI high. All tests were held for 10 Minutes - stable 5 minutes. Witness of test waived by Jim Regg. Fail -Pass: Lower Pipe Rams, Manual Choke Line Valve, Manual Kill Line Valve, Upper IBOP (high pressure test), Lower IBOP (low pressure test). AOGCC Inspection 24 hr Notice Yes Date/Time 07/06/14 11:30\G` Waived By Jim Regg Test Start Date/Time: 07/0914 16:30 (date) (time) Witness Test Finish Date/Time: 7/10/2014 1:30 Form 10-424 (Revised 06/2014) 2014-0710_BOP_Doyon1_BRU_224-13.xlsx 6pfpf "p'1roAt` RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN AUG 2 0 2014 1a. WeliStatus: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑✓ - 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ - Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ StratigraphicTest❑ 2. Operator Name: 5. Date CompSus 12. Permit to Drill Num�er: ConocoPhillips Alaska, Inc. orAband.: July 22, 2014 173-037 / 314-375 & 314-429 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 September 26, 1974 50-283-20042-00 - 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1012' FSL, 2194' FWL, Sec. 13, T13N, R10W, SM • November 15, 1974 BRU 224-13 - Top of Productive Horizon: 8. KB (ft above MSL): 104' RKB 15. Field/Pool(s): 1012' FSL, 2194' FWL, Sec. 13, T13N, R10W, SM GL (ft above MSL): 75' AMSL Total Depth: 1012' FSL, 2194' FWL, Sec. 13, T13N, R10W, SM Beluga River Undefined Gas Pool - 9. Plug Back Depth (MD + TVD): - 3255' MD / 3255' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-325576 - y- 2636610 . Zone- 4 . 10000' MD / 10000' TVD ADL 58831 . 11. SSSV Depth (MD + TVD): 17. Land Use Permit: TPI: x-325576 y- 2636610 Zone- 4 Total Depth: x-325576 y- 2636610 Zone- 4 none none 18. Directional Survey: Yes ❑ No ❑✓ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-drill/Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 30" - - surf. 65' surf. 65' --- driven 20" 94# H-40 surf. 423' surf. 423' 26" 660 sx Class G 13.375" 61 / 68# K-55 surf. 3298' surf. 3298' 17.5" 2010 sx Class G 9.625" 43.5 / 47# P110 / N-80 surf. 6999' surf. 6999' 1 12.25" 11645 sx Class G 24. Open to production or injection? Yes ❑ No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom, Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4�,' t . z -i• i`f 3.5" kill string 3012' none J - 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6JAl` _Ii ow �'� Was hydraulic fracturing used during completion? Yes No❑ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 3255' 45 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (torr) - Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RSCMS AUG 2 2 201 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only /1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 0 Yes R] No • If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top none none Permafrost - Bottom none none needed, and submit detailed test information per 20 AAC 25.071. Gas Top A 3355' 3355' A-2 Contour 3405' 3405' Top B 3532' 3532' Top C 3692' 3692' Top D - Base Sterling 3852' 3852' Top E 4094' 4094' Top F 4360' 4360' Top G 4830' 4830' Top H 5324' 5324' N/A Formation at total depth: 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.— Contact: Andrew Huck @ 265-6828 Email: Ank conA o hilli s.com drew. Printed Name G. L.Alvord Title: Alaska Drilling Manager r A`'k Signature Phone 265-6120 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: BRU 224-13 Rig Name: DOYON ARCTIC FOX Job Type: RECOMPLETION Rig Accept: 7/8/2014 6:00:00 PM Rig Release: 7/25/2014 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 7/05/2014 24 hr Summary Moving rig: Moved motor, pump and pipe shed modules and staged them on "D" Pad. 12:00 00:00 12.00 MIRU MOVE MOB P RD & move rig f/ BRU 242-04 to BRU 224-13 Moved Motor, Pump and Pipe Shed Modules and staged them at "D" Pad 7/06/2014 Moved rig from BRU 242-04 to BRU 224-13. Spotted sub, water tank and modules. Raised dog house 00:00 06:00 6.00 MIRU MOVE RURD P Unstring blocks, Secure derrick and layover. Prep pits to lower roofs. Lay felt and herculite at M Pad 06:00 12:00 6.00 MIRU MOVE RURD P Lower roofs on mud pits and move to M pad. Secure dog house and lower. Remove derrick board and derrick. Pick sub off of pony subs. Move to M pad and set mats 12:00 14:00 2.00 MIRU MOVE RURD P Spot pony subs. SSV on Xmas tree interfering with placement of sub. Call for operator 14:00 15:30 1.50 MIRU MOVE NUND P Operator removed SSV 15:30 00:00 8.50 MIRU MOVE RURD P Spot sub on pony subs. Spot drawworks and derrick. Spot water tank and pit modules. Spot pump modules, boiler and motor modules. Connect electrical lines. Raise dog house 7/07/2014 Cont. moving & rigging up - raised derrick & string blocks - scope up derrick - set in TD & hook up to blocks - spot gas buster & pipe shed 00:00 06:00 6.00 MIRU MOVE RURD P Cont. prep work to raise derrick - Install drillers console - raise derrick & string blocks - scope derrick & pin - remove bridle line & yoke - Install chemical door in mud pits - assembly pump room & mud pit equipment - Install air & fuel lines 06:00 12:00 6.00 MIRU MOVE RURD P Mob equipment f/ Cottonwood to M pad - Set TD on rig floor & hook up to blocks - Spot gas buster & pipe shed - Install TD service loop - reel house - TD gen. house - Install torque tube and brace - cont. working in pump room & pits - Install torque tube bushing Page 1 of 19 Time Logs Date From To Dur S. De th E. DeiDth Phase Code Subcode T Comment 12:00 18:00 6.00 MIRU MOVE RURD P Cont. RU - Clean & put away tools - Install Handy Berm - Cont. working in pump room & pits - Hook up water lines - Insatll support chains in water tank - hang service loop - Install kelly hose - Change out diaper pins in derrick & crown w/ cotter pins - Install hard lines outside of rig - Put up rig floor lights in derick w/ safety cable - tighten kelly hose union - Rig up cellar pump dump line - Hook up gas buster line, geronimo line - Hookup glycol pump - Hook up Koomey lines to sub 18:00 00:00 6.00 MIRU MOVE RURD P Comt. RU - Put in flags on dog house - Close back door to derrick dog house - Hook up C -O -M & derrick lights - Cont working in pits - Turn on water throughout rig & check for Iaeks - Bring tongs to rig floor & sub rack - Hang rig tongs - Spot office trailor & Enviro Vac - Install 4 1/2" IF saver sub in TD - clean out bolt holees in top of annular for shooting flange - Install hand rails on steps going to DW 7/08/2014 Inspect derrick. Slip drilling line. Change dies in top drive grabber. Adjust kelly hose. Tied back service loop. Change top pipe rams. Test surface lines to 2200 psi. Adjust tong lines. General house keeping. Test BPV to 1000 psi in direction of flow. Monitor well 00:00 06:00 6.00 MIRU MOVE RURD P Hang blocks & slip drill line - Install smaller grabber head dies and bigger bell guide on TD - Cont. work on mud pits equipment 06:00 12:00 6.00 MIRU MOVE RURD P Cont. clean & organize rig - Grease choke manifold, crown & DW - Perform derrick inspection - Take on 6 % KCL to pit 5 & 6 (435 bbls) - Adjusted kelly hose & tied up service loop to pervent f/ catching on anything - Flooded suction lines - Open up boiler # 2 for service 12:00 18:00 6.00 MIRU MOVE RURD P Change top pipe rams. Hook up bleeder line. Connect power to casing test pump. Pressure test lines to 2200psi. Spot Mud Engineer's lab. Move spinner hawks to floor and function -test. Hook power to enviro-vac and company man's office. 18:00 23:00 5.00 MIRU MOVE RURD P Adjust tong lines. Repair hose on mud manifold. Prep mud pumps. General housekeeping 23:00 23:30 0.50 MIRU RPCOM PRTS P Rig up and test BPV to 1000 psi in direction of flow. Rig down 23:30 00:00 0.50 MIRU RPCOM OWFF P Observed well for flow for 30 minutes. Well static Page 2 of 19 Time Logs Date From To Dur S. Denth E. Depth Phase Code Subcode T Comment 7/09/2014 24 hr Summary Nippled down Xmas tree, Nippled up Adapter and BOPE. Rigged up and tested all BOPE components to 250/3000 psi 00:00 01:30 1.50 COMPZ WHDBO NUND P Connect choke line high pressure hose. Prep cellar to N/D Xmas tree and N/U BOPE 01:30 03:00 1.50 COMPZ WHDBO NUND P Terminate control line. Pick up tree and remove from cellar. Install blanking plug 03:00 04:00 1.00 COMPZ RPCOM RURD P Load pipeshed with 5" drillpipe. Blow air through drillpipe and tally 04:00 12:00 8.00 COMPZ WHDBO NUND P Nipple up 11" 3M x 11" 5M DSA, 11" 5M x 11" 5M spacer spool and BOPE. Nipple up bell nipple, flow line and bleeder line. Connect accumulator lines. Continue loading 5" drillpipe in pipeshed 12:00 14:30 2.50 COMPZ WHDBO NUND P Continue nippling up BOPE 14:30 16:00 1.50 COMPZ WHDBO RURD P Rig up to test BOPE 16:00 16:30 0.50 COMPZ WHDBO BOPE P Test Upper Pipe Rams to 250/3000 psi for 5 minutes. 16:30 17:00 0.50 COMPZ WHDBO RGRP T Repair accumulator, replace pressure switch 17:00 23:30 6.50 COMPZ WHDBO BOPE P Test BOPE to 250/3000 psi. Test Upper Pipe Rams and Annular with 5-1/2" tes joint. Test Lower Pipe Rams and annular with 5" test joint. Witness of BOPE test waived by Jim Regg, AOGCC 23:30 00:00 0.50 COMPZ RPCOM SFTY P Pre -spud meeting with both crews to discuss upcoming operations on BRU 224-13 with drilling engineer, Drew Huck 7/10/2014 Finish BOP test - RD - RU for slick line - Pull BPV, Pulled equilizer out of plug at 3058' and started losing returns. Unable to pull plug at 3058' Change drum in slickline to to heavier wire. Lost a total of 1777 bbls of brine. 00:00 01:30 1.50 0 0 COMPZ WHDBO BOPE P Cont. w/ BOP test - Tested annular,lower pipe rams, lower IBOP, TIW to 250 & 3000 psi w/ 5" test jt - Pulled test jt and tested blind rams to 250 & 3000 psi - witnessing of test waived by Jim Regg AOGCC 01:30 02:00 0.50 0 0 COMPZ WHDBO RURD P RD test equipment & pull blanking plug 02:00 04:00 2.00 0 0 COMPZ RPCOM SLKL P ND bell nipple and flow line - NU adaptor flange & shooting flange to top of annular preventer 04:00 07:00 3.00 0 0 COMPZ RPCOM SLKL P Pull BPV - RU slick line equipment & lubicator, Test lubricator to 2000 psi (Good Test) Page 3 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:00 12:00 5.00 0 COMPZ RPCOM SLKL P PJSM - RIH w/ slick line to retreive plug @ 3058'- Work Itool string - GS pulling tool sheared off - POOH & install GR retreval tool - RIH - Observed hole taking fluid -Latch onto plug w/ GS tool work tool string unable to pull plug - POOH & cut line and MU another GR tool to jar up - Pumped away a total of 320 bbls 6% KCL - Pumped & spotted 55 bbls HEC pill & chased w/ 20 bbls 6% KCL - shut down and observed no change in loss rate - RU & pumped down back side & pumped down backside w/ 50 bbls - got returns to surface @ 6 bbls/ min pump rate - Pumped & spotted HEC pill # 2 down backside and chased w/ 83 bbls 6% KCL Lost 725 bbls to hole 12:00 13:30 1.50 COMPZ RPCOM SLKL P RIH w/ GS retrieving tool on slickline. Unable to retrieve plug Losses for the tour = 725 bbls 13:30 14:00 0.50 COMPZ RPCOM SLKL P Rig down slickline 14:00 14:30 0.50 COMPZ RPCOM SLKL T Wait on slickline to change drum to larger wire (0.160") 14:30 15:30 1.00 COMPZ RPCOM SLKL T While waiting on slickline to change drum spotted 54 bbl HEC pill (5 Ip/bbl HEC) at 3 bpm 64 psi 15:30 19:00 3.50 COMPZ RPCOM SLKL T While waiting on slickline to change drum pumped at 3 bpm for 15 minutes (45 bbl) shut down for 15 minutes. Continued for 3 hours. Could pump at 6 bpm with partial returns. Decreased rate at .5 bpm increments and had no returns until rate was down to 3 bpm and had partial returns again. Spotted another 54 bbl 19:00 21:00 2.00 COMPZ RPCOM SLKL T Continue waiting on slickline. Pump at 3 bpm at had slight returns Spot 54 bbl HEC pill 21:00 23:00 2.00 COMPZ RPCOM SLKL T Rig up slickline 23:00 00:00 1.00 COMPZ RPCOM SLKL T RIH to retrieve plug Losses for the tour = 1025 bbl 7/11/2014 Cont. w/ Slick line work. Repaired slickline unit. Latched WRP and pulled free. Pulled plug to BP6i nipple at 407'. Unable to pull plug through nipple. RIH and set down on CMU at 3125'. Shear off of plug and POOH. Rig down slick line and rig up to pull 5-1/2" completion 00:00 02:00 2.00 0 0 COMPZ RPCOM SLKL T PJSM - RIH w/ slick line & pulling tool on 1.60 slick line - latch onto plug - pull on plug 02:00 05:00 3.00 0 0 COMPZ RPCOM SLKL T Repair Pollard wireline unit Page 4 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:00 06:30 1.50 0 0 COMPZ RPCOM SLKL T Cont.to pull on plug 06:30 07:30 1.00 0 0 COMPZ RPCOM SLKL T PJSM - POOH w/ slick line - Change tools f/ GR to GS tool - RIH - Latch onto plug - Pull on plug 07:30 09:30 2.00 0 0 COMPZ RPCOM SLKL T Wireline spool broke (chain) repair chain 09:30 10:30 1.00 0 0 COMPZ RPCOM SLKL T POOH w/ slick line - LD GS tool - No plug 10:30 12:00 1.50 0 0 COMPZ RPCOM SLKL T Repair spool in slick line unit Fill over top w/ hole fill pump @ .8 bbls/min Lost 107 bbls 12:00 13:30 1.50 0 0 COMPZ RPCOM SLKL T Work on slickline unit. Continue filling hole with 3% KCL at .8 bpm 13:30 14:00 0.50 0 0 COMPZ RPCOM OWFF T Shut off hole fill. Make up acoustic fluid shot and take 2 fluid shot readings. Fluid level at approximately 1000' 14:00 15:30 1.50 0 0 COMPZ RPCOM SLKL T Work on slickline unit. Continue filling hole with 3% KCL at .5 bpm 15:30 16:30 1.00 0 0 COMPZ RPCOM SLKL T RIH with BRGS tool on 0.160" slickline while filling hole at 1/2 bpm 16:30 21:00 4.50 0 0 COMPZ RPCOM SLKL T Latch WRP @ 3058'. Jar free and POOH. Noticed top of fluid at 1000'. Plug hung up in BP -6i nipple at 407'. Attempt to work plug through nipple w/o success. RIH with plug and sheared off of plug in CMU @ 3125'. 21:00 22:00 1.00 0 0 COMPZ RPCOM SLKL T POOH and rig down slickline lubricator and sheaves 22:00 23:00 1.00 0 0 COMPZ WHDBO SLKL T Nipple down shooting flange and nipple up riser and flowline 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD P Rig up power tongs to pull 5-1/2" tubing Losses for the tour = 162 bbl 7/12/2014 RU to pull tbg - Pull hanger to floor - Pump HEC pill - Spot calcium carbonate pill - Monitor well - Pull & LD 5 1/2" tbg - Change rams & test - Set WB - MU fishing BHA # 1. RIH picking up 5" drillpipe out of the shed. Engage PBR @ 3085'. Release PBR. POOH 00:00 01:00 1.00 0 0 COMPZ RPCOM RURD P PJSM - RU to pull 5 1/2" tbg 01:00 01:30 0.50 0 0 COMPZ RPCOM PULL P PJSM - MU landing jt to hanger - Back out LDS - Unseat hanger & pull hanger to rig floor - PU wt 70 k 01:30 03:00 1.50 0 0 COMPZ RPCOM CIRC P PJSM - Pumped 100 bbl HEC pill down IA & chase w/ 75 bbls 3% KCL @ 3 bbls/min - Max pressure 180 psi 03:00 03:30 0.50 0 0 COMPZ RPCOM COND P PJSM - Mix calcium carbonate LCM pill 03:30 04:00 0.50 0 0 COMPZ RPCOM CIRC P PJSM - Pumped 54 bbls calcium carbonate pill down tbg & displace w/ 75 bbls 3% KCL to palce pill out of tbg - @ 3 bbls/min @ 94 psi Page 5 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 04:00 04:30 0.50 0 0 COMPZ RPCOM OWFF P PJSM - Monitor well for 30 mins. 04:30 05:00 0.50 0 0 COMPZ RPCOM PULD P Break out & LD landing jt, 05:00 08:30 3.50 0 0 COMPZ RPCOM PULL P PJSM - Pull & LD 5 1/2" tbg - recovered 74 jts 5 1/2" 15.5# tbg - Camco BP -61 ported nipple assembly - Baker CMU sliding sleeve assembly W WRP in top pup jt. of assembly - Baker seal assembly - Vetco -Gray tbg hanger w/ pup jt. - Est top of PBR 3083' Hole took 31.2 bbls while pulling tbg (17,5 bbls calc. fill) 08:30 09:00 0.50 0 0 COMPZ RPCOM RURD P PJSM - RD tongs - elevators & slips f/ pulling 5 1/2" tbg 09:00 10:00 1.00 0 0 COMPZ RPCOM BOPE P PJSM - Close blind rams - Change upper pipe rams f/ 5 1/2" solid bod to 2 7/8" x 5" VBR 10:00 11:00 1.00 0 0 COMPZ RPCOM BOPE P PJSM - Open blind rams - set test plug w/ 5" test jt. - Test upper pipe rams to 250 & 3000 psi for 5 mins. (good test) Pull test plug & set wear bushing w/ 9" ID 11:00 11:30 0.50 0 0 COMPZ RPCOM RURD P PJSM - RU to MU Fishing BHA # 1 11:30 13:00 1.50 0 209 COMPZ RPCOM PULD P PJSm - MU fishing BHA # 1 - Type D spear - XO - Bumper sub - Jars - XO - (6) 6 1/4" DC's - XO Losses from midnight to noon = 467 bbl Wear ring installed I.D. = 9" 13:00 13:30 0.50 209 209 COMPZ RPCOM SVRG P Service top drive and drawworks. Prep floor to pick up drillpipe 13:30 18:30 5.00 209 3,085 COMPZ RPCOM PULD P RIH with BHA #1 picking up drill pipe out of the pipeshed. P/U = 92 kips, S/O = 92 kips Loss rate = 25 bbl/h 18:30 20:00 1.50 3,085 3,085 COMPZ RPCOM FISH P Tag top of PBR @ 3085'. Engage fish and pick up 5 kips over to verify spear engaged. Rotate to the right while picking up 5 kips over string weight to release PBR. 20:00 21:00 1.00 3,085 3,085 COMPZ RPCOM CIRC P Mix HEC pill and spot on bottom. Monitor well 21:00 00:00 3.00 3,085 1,434 COMPZ RPCOM TRIP P POOH to 1434' Losses for the tour = 318 bbl 7/13/2014 POOH - LD fish - MU fish assembly # 2 - RIH - Pump 53 bbls HEC pill - Engage fish (SC -2 packer) @ 3112'. Attempt to jar free without success. Release pulling tool and POOH. Make up 3-1/8" multi -string cutter and 2 - 3-1/8" drill collars. RIH. Locate top of packer with locator on cutter at 3112'. Pick up and start cutting at 3164.5' 00:00 02:30 2.50 1,434 208 COMPZ RPCOM TRIP P Cont. POOH w/ fish assembly # 1 f/ 1434' to 208' (top of fish assembly) PUwt62k Page 6o'19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 02:30 03:30 1.00 208 0 COMPZ RPCOM PULD P LD fishing assembly - Recovered Baker PBR - pup jt - S-22 anchor seal assembly 03:30 04:00 0.50 0 0 COMPZ RPCOM PULD P LD tools f/ BHA # 1 - PU tools for new fishing assembly 04:00 05:00 1.00 0 209 COMPZ RPCOM PULD P MU fishing assembly # 2 - SC -1 pulling tool - XO - Bumper sub - jars - XO - 6 DC's - XO 05:00 05:30 0.50 209 209 COMPZ RPCOM SVRG P Serviec rig - grease TD - DW - spinner hawk - Adjust link tilt 05:30 06:00 0.50 209 209 COMPZ RPCOM OWFF P Monitor well 06:00 09:00 3.00 209 3,042 COMPZ RPCOM TRIP P RIH w/ fishing assembly f/ 209' to 3042' 09:00 10:30 1.50 3,042 3,042 COMPZ RPCOM CIRC P Pumped 53 bbls 3.5 #/bbl HEC + 5 # /bbl calcium carbonate pill & chased w/ 54 bbls 3% KCL 3 bbls/min 10:30 12:00 1.50 3,042 3,112 COMPZ RPCOM FISH P RIH f/ 3042' to 3112' - Engage fish - set down w/ 15 k Observed collette shift in packer - PU & jar on fish - appears chemical cut @ 3213' is not cut Lost 143 bbls last 12 hrs 12:00 13:00 1.00 3,112 3,112 COMPZ RPCOM FISH P Continue jarring on fish. Release from fish and re-engage fish. Continue jarring w/o success. Release pulling tool and monitor well P/U = 95 kips 13:00 16:00 3.00 3,112 210 COMPZ RPCOM TRIP T POOH with packer pulling assembly. P/U = 95 kips. Losses during trip = 8.7 bbl 16:00 17:00 1.00 210 0 COMPZ RPCOM PULD T Rack back 3 stands of drill collars. Lay down jars and packer pulling tool. Clear floor 17:00 19:00 2.00 0 67 COMPZ RPCOM PULD T Make up 3-1/2" multi -string cutter 19:00 22:00 3.00 67 3,165 COMPZ RPCOM TRIP T RIH with cutter to 3179'. Attempt to locate collar with not clear indication of collar. Tag up on top of packer at 3112' with locater. Pick up to make cut at 3164.5' 22:00 22:30 0.50 3,165 3,165 COMPZ RPCOM SVRG P Service rig and top drive. 22:30 23:30 1.00 3,165 3,165 COMPZ RPCOM RGRP T Trouble shoot top drive. Cooling blower not functioning. Found loose electrical connection and repaired same 23:30 00:00 0.50 3,165 3,165 COMPZ RPCOM CUTP T Cut pipe at 3164.5' per Baker Representative Losses for the tour = 63.8 bbl 7/14/2014 Cont. w/ cut - POOH w/ cutter assembly - MU SC -1 pulling assembly - RIH engage fish -jar loose POOH - LD fish - MU wash over assembly. RIH and wash over from 3219' to 3417' 00:00 00:30 0.50 3,165 1 3,164 COMPZ RPCOM CPBO T I Finish making cut w/ cutter @ 3164' Page 7 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:30 01:00 0.50 3,164 3,164 COMPZ RPCOM OWFF T Monitor well for 30 mins. 01:00 03:30 2.50 3,164 67 COMPZ RPCOM TRIP T POOh w/ cutter assembly f/ 3164' to BHA-PUwt85k SOwt85k 03:30 04:30 1.00 67 0 COMPZ RPCOM PULD T LD cutter assembly - monitor well 04:30 05:30 1.00 0 211 COMPZ RPCOM PULD T MU packer pulling BHA - to 211' 05:30 07:30 2.00 211 3,111 COMPZ RPCOM TRIP T RIH w/ BHA f/ 21 1'to 3111' 07:30 08:30 1.00 3,111 3,010 COMPZ RPCOM FISH T Engage fish - Jar on fish - fish came free - PU to 3031' - PU wt 98 k 08:30 09:30 1.00 3,010 3,010 COMPZ RPCOM CIRC T Circ btms up @ 3 bbls/min @ 65 psi - Dumped 50 bbls HEC pill - lose 24 bbls during circulation - No gas @ btms up 09:30 13:30 4.00 3,010 211 COMPZ RPCOM TRIP T POOH w/ fishing assmebly - 13:30 15:00 1.50 211 30 COMPZ RPCOM PULD T Break down & LD fish - Recovered SC -2 packer - mill out extension - seal bore - upper extension - GP sliding sleeve - GP seal bore - lower extension - seal bore - XO sub - pup jt - XO sub - KOVI Iso sleee - C-2 KOIV - XO sub - Pup jt - 1 jt. 5 1/2" SLHT tbg W/ WRP 8.62' down f/ collar - chemical cut jt - Total length of fish -107.57' 15:00 16:00 1.00 30 30 COMPZ RPCOM RURD P Cleared rig floor and prepared to pick up wash pipe 16:00 19:30 3.50 30 555 COMPZ RPCOM PULD P Make up BHA #5 (10 joints of washpipe, jars and drill collars) 19:30 22:00 2.50 555 3,219 COMPZ RPCOM TRIP P RIH with drill pipe out of the derrick to 3219' 22:00 00:00 2.00 3,219 3,417 COMPZ RPCOM FISH P Washover fish from 3219' to 3417' Pump Pressure = 298 psi @ 8 bpm P/U = 103 kips S/O = 101 kips RPM = 20 rpm Torque off = 1000 ft -lbs Torque on = 4000-6000 ft -lbs Losses for the tour = 519 bbls 7/15/2014 Continue to wash over from 3417 -ft to 3,443 -ft MD, monitor well, POOH to BHA #5, stand back DC,s and 2 stands of 8-1/8" Wash pipe found 5-1/2 TBG stub 8 -ft down from connection. Call out pneumatic saw and single out with WP and 5-1/2 Fish to shoe. 00:00 04:00 4.00 3,417 3,443 COMPZ RPCOM WASH P Continue to wash over from 3,417 -ft to 3,443 -ft MD at 210 gpm (5 bpm) @ 150 psi, ROT at 50 rpms, 8k tq, 12k - 15k WOM, 04:00 06:00 2.00 3,443 3,443 COMPZ RIGMNI RGRP T Trouble shoot and repair top drive blower connection Page 8 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 08:30 2.50 3,443 3,443 COMPZ RPCOM FISH P Continue to wash and ream to 3,443 -ft MD at 210 gpm (5 bpm) @ 150 psi, ROT at 50 rpms, 8k tq, 12k - 25k WOM, PU wt 125k, SOW 95k. Observed decrease in torque and penetration rate sloed to nothing. Continue attempts to make more hole, without success. 08:30 09:00 0.50 3,443 3,443 COMPZ RPCOM OWFF P Monitor well for flow - (observed fluid dropping) 09:00 10:45 1.75 3,443 555 COMPZ RPCOM TRIP P POOH from 3,443 -ft to 555 -ft to BHA #5. 36 bbls actual hole fill - 13.5 bbls over calc. 10:45 11:15 0.50 555 555 COMPZ RPCOM OWFF P Monitor well at BHA - observed fluid dropping. Static losses at 18 BPH, 11:15 13:15 2.00 555 188 COMPZ RPCOM TRIP P POOH w/ 3 stands of 6-1/8 DC's and 2 stands of 8-1/8" Wash pipe - found 5-1/2 TBG stub 8 -ft from surface connection of washpipe. 13:15 19:15 6.00 188 188 COMPZ RPCOM RURD P RU to lay down wash pipe and 5-1/2 TBG fish - Gather needed equipment for completing task. We had a pneumatic saw sent from the LNG plant. Held PJSM, discussing well ocntrol issues, and procedure to pull and strip 5 1/2" tbg from the 8 1/8'' washpipe. 19:15 23:45 4.50 188 0 COMPZ RPCOM PULD P POOH laying down 8-1/8 wash pipe and strip out 5-1/2 TBG - recovered 180.18' -ft of 5-1/2 TBG and a 1 -ft wide x 7 -ft long slab of 9-5/8 47#, N-80 casing with perf holes. Pictures are uploaded in the S Drive well folder. 23:45 00:00 0.25 0 0 COMPZ RPCOM SVRG P Lubricate rig - fluid loss rate 16 bbls / hr 7/16/2014 Remove fish from shoe - determine 7 -ft of 9-5/8 casing was slabbed. Call out Pollard and EVO down hole video - RU and run video to confirm side track from 3,392 -ft to 3,408 -ft. Clean up from spill in secondary containment. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Continue to remove fish from wash pipe and shoe. 01:00 05:00 4.00 0 0 COMPZ RPCOM OTHR T Discuss findings with town engineers. Move drill collars to the drillers side. 05:00 07:45 2.75 0 3,398 COMPZ RPCOM TRIP T MU 8-1/8" Overshot with no internal components. RIH on 5" DP to 3,399 -ft. Set in slips. When attempting to slowly slack off and get deeper to clean the fluids, we tagged at 3400', and set down 5k, and then 15K. Picked up to set slips with OS Cut lip guide at 3398'. Page 9 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 07:45 11:30 3.75 3,398 3,398 COMPZ RPCOM CIRC T Circulate, while clean and filter fluids to 10 NTU's going in, and 38 coming out. Called out Pollard wireline, spot unit and rig up. Lay out tools for EV Camera run. Install long bales on the top drive to allow for safety valve and pump in sub equipment. 11:30 12:00 0.50 3,398 3,398 COMPZ RPCOM SFTY T Held PJSM with Crew, Pollard, Baker, and EV camera rep. Discuss safety & hazard recognitions issues. Discuss procedure to rig up and run camera run. Crew Change Static fluid losses at 18 BPH 12:00 15:00 3.00 3,398 3,398 COMPZ EVALWE RURD T Continue rig up sheaves and line to rig floor. Rig up EV camera, and check connections. Observed trouble making camea talk to the computer. Continue troubleshoot until set up another computer. Observed pre-test successful. 15:00 17:15 2.25 3,398 3,398 COMPZ EVALWE ELNE T Wireline in hole at 200 ft/minute. Stop and depth check every 1000'. Continue wireline in to bottom. Observed bottom camera had been blinded. and sideview camera enabled a good view. Had trouble initially verifying a corresponding depth with the BHA, even moving the drill string to find it. Finally observed the overshot and corrected depths to DP depth. Continue attempts to gain bottom camera lens, unsuccessful. We circulated at 3 BPM with NTU's at 10 in and 10 out. Pictures good, for what we could see. We never could get good indication that we were looking at casing or tubing. 17:15 21:15 4.00 3,398 3,398 COMPZ EVALWE ELNE T Wire Line out of hole, to pull camera and clean the lenses. Verify rotation motor control functional as well. Run back in the hole to 3,397-ft MD with camera - unsatisfied with shoe depth, pull back in shoe to 3,300-ft and Pull shoe to 3,382-ft Attempt to locate top of window with camera while circulating 43 bbls @ 3 bpm @ 54 psi. Close annular and bull head 227 bbls @ 3 bpm @ 368 psi max pressure, was able to locate top of window in 9-5/8 casing at 3,392-ft and bottom of window at 3,404-ft MD and bottom of the hole at 3,408-ft. Lower shoe back to 3,397-ft. POOH - Loss rate = 37 bph Page 10 of 19 Time Logs Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 21:15 00:00 2.75 3,398 0 COMPZ EVALWE RURD T RD video camera and Pollard Wire Line, change bails over from long to short for tripping. While conducting a Sim ops task at the same time with MI was shipping 3% KCL from Frac tank # 2 to Rig pit #5. During this operation there was a fire that took place in the secondary containment. The fire was extinguished and found to be electrical. The generator was shut down. It was found that a valve at the mixing tank was misaligned and filling the mixing tank at the same time as pit 5 and overflowing into the secondary containment. Security was notified along with the immediate supervisors. Penco was brought to location to assist in the clean up of the spill. 7/17/2014 Held Electrical Safety walk around with crew coming on tour - discuss findings and correct findings. POOH w/ BHA #6, lay down OS. Conduct weekly BOP test - waived by Jim Regg. RIH w/ BHA #7 (Taper Mill) to 3,426 -ft. POOH to 2,518 -ft. 00:00 01:30 1.50 3,999 3,999 COMPZ RPCOM SFTY T PJSM, Held Electrical Safety walk around with crew coming on tour - discuss findings and immediately corrected findings. 01:30 03:30 2.00 3,999 0 COMPZ RPCOM TRIP T PJSM, POOH from 3,999 -ft to surface, lay down Baker overshot 03:30 05:00 1.50 0 0 COMPZ WHDBO RURD T Pull wear ring and install test plug. Grease and service choke manifold. Leave IA open to atmosphere and allow well to remain static. Page 11 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:00 11:30 6.50 0 0 COMPZ WHDBO BOPE T Conduct weekly BOP test at 250 / 3,000 psi for 5 minute straight line. Test w/ 5" test jts. 24 hr notice was given to AOGCC on Monday, July 14, 2014 4:28 PM. Right to witness was waived by Jim Regg Tue 7/15/2014 11:54 AM. Test #1 - 11" 5M Annular, CM valves #5, 9,14 & 15, 4-1/2 IF TIW valve, HCR Kill. Test #2 - UP R's 2-7/8 x 5" VBR's, Dart Valve. Test #3 - CM valves #1,4,8 and Lower IBOP. Test #4 - CM valves 3,7, 13 and Upper IBOP. Test #5 - CM valves - 2,6 & 12. Test #6 - CM valve #11. Test #7 - HCR Choke. Test #8 - Manual Kill and Choke valves. Test #9 - LPR's. Test #10 - Blind Rams, CM valve #10, and Kill line valve on mud line. Accumulator Test - System pressure = 3,000 psi, Pressure after closure = 1,750 psi, 200 psi attained in 22 seconds and full psi attained in 120 seconds. 6 N2 bottles avg = 2,200 psi. All gas alarms were tested. 11:30 12:30 1.00 0 0 COMPZ WHDBO RURD T RD test equipment and pull test plug, install wear ring w/ 9" ID. 12:30 15:00 2.50 0 0 COMPZ RPCOM OTHR T Clean and Service Rig, conduct derrick inspection, Gather tools for next BHA #7 (Taper mill run) 15:00 17:00 2.00 0 254 COMPZ RPCOM PULD T PU, MU and RIH w/ BHA #7 as per Baker Rep. to 254 -ft. 40k up wt. 17:00 20:00 3.00 254 3,335 COMPZ RPCOM TRIP T RIH w/ BHA #7 to 3,335 -ft MD. obtain parameters - 99k up wt, 100k so wt, 102k Rot wt @ 10 rpms w/ 5k OBT. 20:00 22:30 2.50 3,335 3,426 COMPZ RPCOM MILL T Slide in hole to 3,403 -ft and set down 2k, rotate 1 round and dropped off, continue in to 3,408 -ft and set down 2k. Bring pump online at 3 bpm 34 psi, rotate at 10 rpm at 500 ft/lbs torque to 3,409 -ft, pack off, pp increase to 3,200 psi. Kick out pump, bleed pressure and pick up, clear pack off. Work back down to 3,426 -ft, pull back to 3,398 -ft. Rotate back down to 3,398 -ft at 10 rpms circulating at 3 bpm 34 psi, seen pressure increase at 3,413 -ft to 120 psi, increase rpms to 25 and continue in to 3,426 -ft. with 15k WOM. Back ream out to above 3,400 -ft. Slide back to 3,426 -ft. Kick Out rotation, pull back above at 103k w/ slight drag. Slide back in with very little drag. Shut down pump. Page 12 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 3,426 3,426 COMPZ RPCOM OWFF T NFT - slight loss 23:00 00:00 1.00 3,426 2,518 COMPZ RPCOM TRIP T POOH f/ 3426 -ft to 2518 -ft 57k up wt. 7/18/2014 Continue to POOH to Surface, inspect mills. PU and RIH w/ BHA #8 spear w/ 4.805' Nominal Catch. Attempt to engage fish, - failed. POOH. Shucked grapple. PU, MU and RIH w/ BHA #9 and mill down to 3,429 -ft. POOH with BHA. 00:00 01:00 1.00 2,518 254 COMPZ RPCOM TRIP T Continue to POOH from 2,518 -ft to 254 -ft. NFT 01:00 02:30 1.50 254 0 COMPZ RPCOM PULD T POOH w/ BHA #7 and inspect mills 02:30 04:00 1.50 0 283 COMPZ RPCOM PULD P PU, MU and RIH w/ BHA #8 (Spear assy) to 283 -ft. 12k 04:00 05:30 1.50 283 3,367 COMPZ RPCOM TRIP P RIH w/ BHA #8 from 283 -ft to 3,367 -ft MD 100k UP wt, 100k SO wt. Calculated Displ. =31.7 bbls. Actual Displ. = 31.3 05:30 07:00 1.50 3,367 3,412 COMPZ RPCOM FISH P MU up top drive and slide down to 3,412 -ft MD. Tag up and set down 7k, rotate 2 rh turns and observe wt drop off. Attempted several times to engage at 3,412 -ft - unsuccessful. Attempted by circulating @ 3 bpm @ 35 psi, 6 bpm @ 250 psi, rotate and slide at 10 - 25 rpms with 1-2k torque. set down up to 30k several times in last hope - No success. Decision made to POOH. 07:00 07:15 0.25 3,412 3,398 COMPZ RPCOM OWFF P NFT - observed fluid dropping. 07:15 08:30 1.25 3,398 283 COMPZ RPCOM TRIP P POOH f/ 3,398 -ft to 283 -ft. 100k UP wt. Calc. hole fill = 31.7 bbls and actual = 73.7 bbls 08:30 09:30 1.00 283 0 COMPZ RPCOM PULD P POOH w/ BHA #8 and lay down spear - grapple was shucked. 09:30 10:30 1.00 0 248 COMPZ RPCOM PULD T PU, MU and RIH w/ BHA #9 (Taper mill assy) to 248 -ft 10:30 12:30 2.00 248 3,396 COMPZ RPCOM TRIP T RIH w/ BHA #9 from 248 -ft to 3,396 -ft MD 99k up wt, 100k do wt. Page 13 of 19 Time Logs Date From To Dur S. DeiDth E. De th Phase Code Subcode T Comment 12:30 21:00 8.50 3,396 3,429 COMPZ RPCOM MILL T Kelly up and RIH to 3,409 -ft take wt and fell off. Tag up at 3,411-ftw/ 10k dn. Pick up and rotate@ 10 rpms w/ 104k ROT wt. Tag up at 3,411 -ft, begin to circulate @ 3 bpm @ 34 psi. Packed off and pressure up to 1,200 psi. PU and clear bit. Increase PR to 5 bbls @ 120 psi. increase 40 rpm w/ 5k tq. Mill down from 3,409 -ft to 3,418 -ft w/ 2k tq. circulating at 5 bpm @ 190 psi. Stall out 4x's at 3,418.5 -ft at 4.5k torque. Pick up - dragging 10k up to 3,996 -ft. Work back down to 3,403 -ft with no drag and begin milling 3,403 -ft to 3,418 -ft. Seen pressure increase to 600 psi w/ mill at 3,420 -ft and torque increased 3k. Pump pressure spiked to 1,200 psi at 5 bpm with mill at 3,421 -ft. and returned to 800 to 1,100 psi. 3,422 -ft seen formation sand over the shakers - stop milling. PU and tag back down @ 3,422 -ft. CBU and pump 55 bbl HEC pill. Returning sands, metal and frac sand. Continue to mill from 3,422 -ft to 3,424 -ft, seen pressure increase 600 psi at 3.5 bpm; 60 = rpm w/ 4.5k torque @ 3,425 -ft. had pressure increase to 3,200 psi, work up and down - pressure fell off. Continue to mill to 3,432 -ft recovering sand. PU and CBU @ 9 bpm @ 411 psi. Rotate and reciprocate - pull tight and stall at 6k torque from 3,424 -ft to 3,428-ftMD 8-1/2 string mill hanging up. Circulate another 55 bbl HEC pill. PU to 3,396 -ft and slide down with No Pump, No Rotation to 3,429 -ft and set down 20k. Seen 5-10k drag from 3,424 to 3,428 -ft -- work section 3 x's with same results. 21:00 21:15 0.25 3,396 3,396 COMPZ RPCOM OWFF T NFT on trip tank - 12 bph loss rate. 21:15 23:00 1.75 3,396 248 COMPZ RPCOM TRIP T POOH from 3,396 -ft to 248 -ft. 41k UP wt. 23:00 23:15 0.25 248 248 COMPZ RPCOM OWFF T NFT on trip tank - 11 bph loss rate. 23:15 00:00 0.75 248 0 COMPZ RPCOM PULD T POOH w/ BHA # 9, clean string magnet - recovered 30 lbs± of metal shavings. 7/19/2014 Attempt to gather components for milling BHA -not available. RIH with Csg scraper to 3350 -ft and POOH. RIH open ended to 3,380 -ft ±. RU eline and run camera. POOH lay down camera, RD eline. 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD T Continue to break down BHA 01:00 01:30 0.50 0 0 COMPZ RPCOM SVRG T Service rig - grease blocks, crown and draw works along with rig floor equipment. Paye 14 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:30 05:30 4.00 0 0 COMPZ RPCOM OTHR T Monitor well while attempting to locate components for next BHA run. 05:30 06:30 1.00 0 0 COMPZ RPCOM PULD T Breakdown and lay down remaining Milling BHA - unable to locate components needed for desired BHA. 06:30 07:15 0.75 0 210 COMPZ RPCOM PULD T PU, MU and RIH w/ BHA #10 (Csg Scrtaper) to 210-ft 07:15 08:45 1.50 210 3,357 COMPZ RPCOM TRIP T RIH w/ Csg scraper from 210-ft to 3,357-ft 97k up wt, 97k SO wt. Calc. Displ. = 31.4 bbls Actual = -19.1 08:45 11:15 2.50 3,357 210 COMPZ RPCOM TRIP T POOH from 3,357-ft to 210-ft Calc. Hole fill = 28 bbls, Actual 69.5 bbls. 11:15 13:15 2.00 210 0 COMPZ RPCOM PULD T POOH laying down BHA from 210-ft to surface. 13:15 14:30 1.25 0 0 COMPZ RPCOM PULD P Lay down 8-1/8 wash pipe from derrick. Clean and clear floor of BHA tools. 14:30 17:30 3.00 0 3,416 COMPZ RPCOM TRIP T MU and d RIH with open ended drill pipe to 3397-ft, pump 61 bbls @ 5 bpm @ 52 psi. Spot and RU Pollard wire line for DHV evaluation on 5-1/2 and 9-5/8 casing damage at 3,397-ft to estimated side track depth of 3,416-ft. RU associated equipment. 17:30 21:30 4.00 0 0 COMPZ RPCOM ELNE T RIH w/ Camera to 3,398-ft and water was cloudy, close annular and bullhead 3% KCL - water cleared up and picture clarity improved. RIH to 3,408-ft, seen top of 5-1/2 TBG stub at 3,402-ft ±. 5-1/2 was slabbed open past 3,408-ft. Move TBG tail up 10-ft to 3,388-ft in attempt to locate parted 9-5/8 casing - seen multiple areas of damage. Bull headed a total of 410 bbls @ 3 bpm with max pressure of 417 psi. Shut down pump and POOH w/ Camera. 21:30 22:30 1.00 0 0 COMPZ RPCOM ELNE T RD camera and Pollard Wireline service. 22:30 23:00 0.50 0 3,398 COMPZ RPCOM CIRC T Spot 55 bbl HEC pill at 3,398-ft at 5 bpm 23:00 23:30 0.50 3,398 3,398 COMPZ RPCOM OWFF T NFT-24 bph losses 23:30 00:00 0.50 3,398 3,208 COMPZ RPCOM TRIP T POOH from 3,398-ft to 3,208-ft 85k UP wt. 7/20/2014 POOH w/ DP and RU eline set cmt retainer at 3,350-ft. RD Eline, RIH w/ Baker stinger to 3,350-ft and locate Cement retainer. PT treating string and 9-5/8 CSG. RU Baker Pumping services and mix and pump abandonment slurry. POOH laying down DP to 1,500-ft. 00:00 02:00 2.00 3,208 0 COMPZ RPCOM TRIP T Continue to POOH from 3,208-ft to surface. Break off bull nose. 02:00 03:30 1.50 0 0 COMPZ PLUG MPSP X Pull wear ring. RU Pollard Eline and Baker 9-5/8 K-1 cement retainer. Page 15 of 19 C�� Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:30 06:00 2.50 0 3,350 COMPZ PLUG MPSP X RIH w/ Baker K-1 Cement retainer losses at 6 bph) and collar correlate to 9-5-05 Schlumberger USIT log with 700 lbs up wt, 530 lbs do wt. Set CCL @ 3,341.5 w/ top at 3,350-ft and center of element @ 3,349.25-ft. Fire and set in 74 seconds, pick up, New up wt = 480 lbs, SO wt 417 lbs and retag and set 60 lbs down 3,349-ft. POOH with setting tool. Close blind rams and pressure up to _ 1,500 psi for 15 minutes - Good test on chart. RD Eline. 06:00 09:30 3.50 0 3,350 COMPZ PLUG TRIP X PU, MU and RIH w/ K-1 stringer for cmt retainer on 5" DP to 3,340-ft, gather parameters. Install space out drill pipe pups. Sting into cmt retainer and shut sleeve - Pump down drill string establishing an injection rate at 230 PSI - 3 BPM, 15 BBLS away. Pull up and close flapper in retainer. Pump down to verify flapper closed with 900 PSI. 09:30 14:30 5.00 3,350 3,350 COMPZ PLUG RURD X Bring Baker cementing equipment to location, Berm and spot same. Rig up lines. Load pods with clean fresh water and flush tanks, and lines verifying clean. 14:30 15:00 0.50 3,350 3,350 COMPZ PLUG SFTY X Held PJSM with Rig Crew, Baker, and MI reps. Discuss safety and hazard recognition issues. Discuss procedure to line up and pump cementjob. Designate Spill champion 15:00 16:45 1.75 3,350 3,550 COMPZ PLUG CMNT X With Baker Pumping Services, batch mix 50 BBLS of Class G 15.8 PPG cement. Sting into cement retainer, and pump down drill string 10 BBLS Fresh Water, 50.1 BBLS cement and chase with 10 BBLS Fresh water, at 3 BPM - 350 PSI, max. 16:45 18:30 1.75 3,550 3,550 COMPZ PLUG CMNT X Turn over to rig, displace cement observing catching cement with 5.5 BPM after 400 Stks. Continue pumping slowing pumps to 3 BPM, sgeezing 600 PSI and 37.6 BBLS into formation. Pull up and sting out of retainer. Pull back to 3255' ( 95') above top of retainer) and reverse circulate at 6 BPM, 2 DP volumes, observing 4.9 BBLS of cemet return to surface. This left 7.5 BBLS of cement on top of retainer. 18:30 19:00 0.50 3,550 3,097 COMPZ PLUG TRIP _ rea out the reverse cir`cialating assembly. POOH and stand back 4 stands back to 3097-ft. Payr 16 of 19 C�� Time Logs Date From To Dur S. De th E. Denth Phase Code Subcode T Comment 19:00 22:00 3.00 3,097 3,097 COMPZ PLUG CIRC X Make up circulation hose and valve. Install Drill pipe Nerf Ball, and pump down Drill string at 6 BPM to clean the drill pipe. 22:00 00:00 2.00 3,097 1,500 COMPZ PLUG PULD X POOH laying down 5" 19.50# S-135 NC50 D/P from3,097-ft to 1,500-ft 54k up wt. K-1setting tool. 7/21/2014 Continue to POOH from 1,500-ft laying down 5" Drill pipe and K-1 stinger. Prepare to RIH w/ 3-1/2 8rd. Complete well with 3000' of 3 1/2" EUE tbg, open ended. Land with tbg hanger. ND-NU tree. Secure well & release. Begin DEMOB. 00:00 02:45 2.75 1,500 0 COMPZ PLUG PULD X POOH laying down 5" 19.50# S-135 NC50 D/P from 1,500-ft to K-1 setting tool. 02:45 03:15 0.50 0 0 COMPZ PLUG RURD X Clean and Clear rig floor of 5" DP running equipment. 03:15 04:00 0.75 0 0 COMPZ PLUG PRTS X Close Blind rams and pressure test 9-5/8 casing and Cement retainer post squeeze @ 1,650 psi for 30 minutes on chart - good test. 04:00 05:30 1.50 0 0 COMPZ PLUG RURD X RU Weatherford tubing running services equipment for RIH w/ 3-1/2, 9.3#, N-80, EUE 8rd AB Mod R-2 Kill string to 3,000-ft± 05:30 10:00 4.50 0 3,013 COMPZ PLUG RCST X PU„ MU and RIH w/ 3-1/2, 9.3#, N-80, EUE 8rd AB Mod R-2 Open ended Kill string to 2,985-ft±. PU and MU 3-1/2 8rd x 5-1/2 BTC X-O, 5-1/2 x 3-ft BTCM pup jt and Vetco Gray 5-1/2 x 10-3/4 TBG Hanger w/ 5.875" MCA Lifting threads with BPV in place. 48k up wt, 48k do wt. Land. TBG hanger at 3,012.97-ft with IA Open. RILDS. 10:00 10:30 0.50 3,013 3,014 COMPZ PLUG PRTS X RU to IA and pressure test BPV in direction of flow for 10 minutes @ 1,000 psi - Good Test. 10:30 22:00 11.50 3,014 0 COMPZ PLUG NUND X Flush all circulating lines with fresh water. Blow down with air. ND BOPE in component sections and prep ram cavities for storage. 22:00 00:00 2.00 0 0 COMPZ PLUG NUND X Place tree in cellar and hang. Land tree and NU. 7/22/2014 Continue to NU tree. FP for Temporary shut in. Secure well & release rig. Begin DEMOB. 00:00 00:30 0.50 0 0 COMPZ PLUG NUND X Continue to NU Tree 00:30 01:00 0.50 0 0 COMPZ PLUG MPSP X Pull BPV and install TWC 01:00 01:30 0.50 0 0 COMPZ PLUG PRTS X PT void at 3,000 for 30 minutes - good test. PT test tree @ 3,000 for 10 minutes - Good Test. 01:30 01:45 0.25 0 0 COMPZ PLUG MPSP X Pull TWC and RD dry rod. 01:45 03:15 1.50 0 0 COMPZ PLUG FRZP X RU to IA and Tree for freeze protect and well swap. Page 17 of 19 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:15 06:15 3.00 0 0 COMPZ PLUG FRZP X RU and pump 66 bbls of diesel down IA .5 bpm ICP = 0 and FCP = 50 Allow IA x TBG to U-tube and balance out @ 925 -ft.. Secure well. 06:15 00:00 17.75 0 0 DEMOB MOVE RURD P Clean mud pits, rig floor, draw works skid, mezzanine, cellar, and pipe shed. Prep mud pump #3 for rig move. Detach bails and break out savor sub. Detach rig components for removal - torque tube, pumps, pits gas buster etc. Lay over exhaust stacks. 7/23/2014 Scrub, clean, and organize. Prep rig for move (legal highway loads). Tail roll pipe sheds, lay over V door with Crane. Tail roll skate shed. Pull auger box with crane. Remove top drive from rig floor. Pull gas buster out and break down exhaust stack. Slip on drilling line and bridal up blocks. Scope down derrick. Hang and secure blocks. Secure monkey board and flip in derrick dog house. Blow down rig water. Clean out rig water tank. 00:00 06:00 6.00 0 0 DEMOB MOVE RURD P Scrub, clean, and organize choke room, generator 1 & 2 rooms, boiler room, and motorman's lounge. Secure all tools and equipment in pipe shed. Unplug electrical to pipe shed. Coil and secure electrical lines. Prep rig for move (legal highway loads). 06:00 18:00 12.00 0 0 DEMOB MOVE RURD P Tail roll pipe sheds, lay over V door with Crane. Load Top drive cradle on floor. Tail roll skate shed. Pull auger box with crane. Remove top drive from rig floor. Pull gas buster out and break down exhaust stack. Remove service loop off derrick and spool up line in VFD skid. RD skids and prep to move. 18:00 00:00 6.00 0 0 DEMOB MOVE RURD P Slip on drilling line and bridal up blocks. Scope down derrick. Hang and secure blocks. Secure monkey board and flip in derrick dog house. Secure derrick climber. Secure tong and tugger lines. Prep to unstring drilling line. Blow down rig water. Remove chains and binders from tank. Clean out rig water tank. 7/24/2014 Continue to DEMOB the rig 00:00 12:00 12.00 0 0 DEMOB MOVE RURD P Continue to demob rig - remove all ground components to work on substructure and derrick. Lower derrick and on string blocks. Release Doyon Arctic Fox at 12:00 hrs on 7-24-14. 12:00 00:00 12.00 0 0 DEMOB MOVE RURD P Continue to demob rig - disconnect components on substructure and derrick for removal. Remove shakers and possum bellies. Lower roofs on pit modules. Clean up pad of felt and herculite debris. Page 18 of 19 Time Logs Date From To Dur S. Delpth E. Depth Phase Code Subcode T Comment 7/25/2014 24 hr Summary Continue to DEMOB the rig. All rig components off M -pad. 00:00 06:00 6.00 0 DEMOB MOVE RURD P Prep sub base and derrick for disassembly. Clean and prep shop for demob. 06:00 12:00 6.00 DEMOB MOVE RURD P Remove derrick from sub base with cranes. Remove derrick monkey board. Remove draw works skids. Remove sub base from pony subs. Stage pony subs off to the side on M -pad. Mob derrick, derrick board, draw works skid, and sub base to Cottonwood. Page 19 of 19 BRU 224-13 Production Well Actual Amended Abandon & Suspend Conductor (Driven):] 30", @65' MD 'Mile Conductor: 20", 94#, H-40, @423' MD Surface Casina: 13-3/8", 61&68#, K-55, BTC Set @ 3,298' MD / 3,298' TVD Existina A Sand Perf. 3,322'-3,323' (1') (SQZ) 3,355'-3,361' (6) 3,375'-3,398' (23') 3,422'-3,431'(9') 3,435'-3,482' (47') B Sand Peforations 3,525'-3,526' (1') (SQZ) 3,550'-3,570' MD (22') Existing B&C Sand Perf. 3,660'-3,662' (2') (SQZ) 3,673'-3,683' (10') 3,700'-3,776' (76') Comoletion Tubina 5 ''/2", 17# L-80 SLHT D. E Sand Peforations 3,936'-3,940'(4') 4,096-4,102'(U) 4,138'-4,148'(10') 4,157'-4,170' (13') E F Sand Peforations 4,260'-4 265' (6) 4,476'-4,490' (10') 4,297-4,303'(6) 41593'-4,603' (4') 4,348'-4,354' (6') 4,624'-4,628' (4') 4,375'-4,379' (4') 4,676'-4,694' (18') 4,446-4,456' (10') 4,728'-4,732' (4') 4,475'-4,490' (15') F. G. H Sand Perforations (ISOLATED) 4,764'-4,774'(10') 5,046'-5,086' (36') 4,916'-4,936' (8') 5,183'-5,189' (6) SQZ 4,936'-4,958' (22') 5.196'-5,202' (6) SQZ 4,966'-4,986' (20') 5,398'-5,448' (50') 5,022'-5,032' (10') 5,470'-5,528'(58') Fish: 2 10' casing guns, X -over sub & Junk mill @ 5,577' MD Production Casing: 9-5/8", 43.5# P-110 BTC @ 2,154' 47#, N-80, LT&C @ 3,830' 47#, P-110 LT&C @ 7,000' MD / 7,000' TVD Schematic Kill String @ 3,013' VV' EUE-M 8rd L-80 9.3# Huck 8-19-2014 7.5 bbis of cement on top of retainer = -102' to --3,255' Inside 9-5/8" shoe Allows -50' for kickoff in the future below surface shoe Cement Retainer @ --3,350', Tested to 1,500 psi 7120 37.5 bbl Cement Squeezed through retainer into Sterling A 5 %" Tubing parted / chewed @ -3,403+' Casing damage / sidetrack @ -3,392'-3,410' Top ER packer @ 3,471' inside of 5-%" Baker Model 96A4-60 SCI -L Isolation Packer @ 3,494' MD 190-47 GP Sliding Sleeve (Opens Down) @ 3,503' MD Potential Holes around SS. Bottom ER packer @ 3,524' inside of 5'h" Blast Joints 6.050", 3,543'-3,573' MD Formation Sand Fill to -3,722' MD Blast Joints 6.050", 3,662'-3,780' MD 5.5" MMG GLM @ 3,790' MD (for production). DV installed. Baker Model 96A4-60 SC1-L Isolation Packer @ 3,809' MD IBP set @ 3,839' 190-47 GP Sliding Sleeve (Opens Down) @ 3,818' MD Excluder 2000 Med. Screen @3,933'-4,017' MD Stage collar @ 3,830' MD RA tag in "Braden Blank" @ -4,022' MD? Excluder 2000 Med. Screen @4,027'-4,177' MD Baker Model 96A4-60 SC1-L Isolation Packer @ 4,180' MD 190-47 GP Sliding Sleeve (Opens Down) @ 4,189' MD Excluder 2000 Med. Screen @4,255'-4,546' MD RA tag in `Braden Blank" @ -4,550' MD? Excluder 2000 Med. Screen @4,555'-4,743' MD Baker Model F 194-60 Permanent Packer @ 4,743' MD XN Nipple with 4.562" Profile @ 5,454' MD (plug installed 10108105) Baker SC -1 R Sump Packer @ 5,465' MD Tubing tail and WLEG @ 5,479' MD Bridge Plug set @ 5,660' MD. Some perforations isolated below not listed. Openhole interval drilled by Chevron in 1974. PBTD is -5,660' THE STATE of ,/t GOVERNOR SEAN PARNELL Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga Field, Undefined Gas Pool, BRU 244-13 Sundry Number: 314-429 Dear Mr. Huck: A1a:ska Olt and was ICnIce1V?.Ii0 I Cc) -,1n,1 -;Cf:; cc, : 333 west Seventh Avenue Anc orage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 SCp OCT 0 DI 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 n I& DATED this Z7 day of July, 2014. Encl. t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 2.1 2014 ncicc�/ � 1. Type of Request: Abandon - Plug for Redrill r , Perorate New Pool Repair w ell r Change Approved Program ji , Suspendr , Plug Perforations J Perforate Pull Tubing 7-zl ;y 9 Time Extension r Operational Shutdow n r Re-enter Susp. Well r Stimulate r Alter casing {- r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. _ Exploratory (- Development r,; . Stratigraphic j- Service (- 173-037 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20042-00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r BRU 224-13 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 58831 Beluga River Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,0001- 10,000'- 5653' 5653', 5454' 5653' Casing Length Size MD TVD Burst Collapse Conductor 65' 30" 65' 65' Conductor 423' 20" 423' 423' 1,530 psi 520 psi Surface 3,298' 13-%" 3,298' 3,298' 3,090 psi 1,540 psi Production 6,999' 9-%,. 6,999' 6,999' 6,870 psi 4,750 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): from 3,322' to 6,470'; See Attached 3,322'- 6,470' 5-1/2" L-80 3000' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) 1 Baker SC -1 R, 1 Model F, and 3 SC -1 L Isolation Packers 3,494'; 3,809'; 4,180'; 4,743'; 5,465' MD & TVD See Attached 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch j' Exploratory r Stratigraphic r Development r . Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/20/2014 Oil r Gas F WDSPL r Suspended r, WIND r GINJ r WAG r Abandoned r 16. Verbal Approval: Yes Date: 7/19/14 Commission Representative: Guy Schwartz GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Drew Huck @ 265-6828 Email: Andrew.Huck(u)cop.com Printed Name Drew Huck Title: Drilling Engineer Signature -- 2Z Phone: 265-6828 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3K Plug Integrity F_ Test r' Mechanical Integrity Test r" Location Clearance r /BOP Other: �tJi�(s�)rti SvsS��c iti. -I*Hl-�-' 1c /Je-,^ ZC.4A� Spacing Exception Required? Yes ❑ No 62f, Subsequent Form Required:/0% -- yc `� 3i`i• 37� 3i H - Hz5 / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7- 0 - Approve s II v t 1 months j�hs trom tpe date of approval. (,� Form 10-403 (Revis 10/2012) M r' I I / 1 Submit Form and Attachments in Duplicate A- RBOMS JUL 3 0 M,, ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 21 ", 2014 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`b Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED JUL 21 2014 AOGCC ConocoPhillips Alaska, Inc. hereby submits an Application for Changing the Approved Program to workover Beluga River Unit Producer 224-13 (PTD# 173-037, Sundry 314-375). BRU 224-13 was originally drilled, tested & suspended in 1974 and completed as a producer in the Sterling A, Beluga G, and H sands in 1981. It has undergone workovers since, most recently in 2005 to gravel pack the Beluga D, E, and F sands. The goal of this workover was to recomplete the Sterling A -C sands and re-establish Beluga D -F production by. However, during the course of operations, an unintentional sidetrack as a result of casing damage occurred in the vicinity of 3,390'-3,410'. Subsequent attempts to recover the wellbore w,�re unsuccessful and the decision was made to suspend the well and set up for sidetrack operations in the future.,/Verbal approval for the final plan from the AOGCC was received on Saturday, 7/19, with a corresponding email following on the morning of 7/20. The well was cemented on 7/20. If you have any questions or require any further information, please contact me at 265-6828 or Andrew.Huck(&cop.com. Please keep in mind proposed completion depths are approximate and the plan is necessarily rough, especially for fishing the existing completion. Sincerely, ca, �w Drew Huck Drilling Engineer CPAI Drilling and Wells c6"&V/ . / � P l,-Idlf W/O L-YOM10 ii -A-41+ aAa n n �eP� �'�q��e 0-7� BRU 224-13 Rig Workover Suspension: Set retainer, pump cement, run kill string (PTD# 173-037, Sundry 314-375) Current Status: The well has been shut-in since May 2011. Scope of Work: Set a retainer above the Sterling A sand, squeeze cement through and dump cement on top. General Well info: MASP: Max. Reservoir pressures/TVD: Wellhead type/pressure rating: Arctic Fox BOP Configuration: Well Type: Estimated Start Date: Workover Engineer: Completion Engineer: Production Engineer: Completed RWO Procedure: 777 psi (using 0.1 psi/ft gas gradient and Beluga E @ 4, 729' MD) From 6/9/2014 SBHP: Beluga F @ 4,729' MD / TVD = 1,250 psi / 5.1 ppg VetcoGray 3,000 psig Annular / Pipe Rams / Blind Rams / Flow Cross / Pipe Rams Gas Producer July 20'', 2014 Drew Huck (265-6828, Andrew.Huck(&cop.com ) Austin Shields (2634523, Austin.J.Shields@cop.com) Daniel Herrmann (263-4619, JD.Herrmann(a,comcom) 1. MIRU. Pull BPV. 2. Conduct no -flow test. Install two-way check. ND tree. C./ 3. NU BOPE. Function and PT BOPE to 250/3,000 psig. Pull two-way check. 4. POOH w/ 5 '/2" completion. (If the seal assembly will not pull free, cut tubing above the PBR and POOH w/ tubing.) 5. Latch and pull anchor assembly. 6. Release and pull SC -2 packer. Unthread tubing stub from SCI -L packer. • Damage and resulting sidetrack occurred at this point while washing over the 5-1/2" lower completion to prepare to retrieve the SC -1L. Suspension RWO Procedure (Red is complete, black is in prouress): 7. Set retainer @ 3,350', pressure test to 1,500 psi. 8. Sting into retainer, squeeze cement through retainer. Pumped away —37.5 bbls. 9. Sting out of retainer and circulate in cement on top. Left —7.5 bbls on top. 10. Run kill string in well. 11. Set BPV and test, ND BOP, NU tree. Test tree. 12. RDMO. BRU 224-13 Production Well Actual Amended Abandon & Suspend Conductor (Driven): 30", @65' MD Conductor: 20", 94#, H-40, @423' MD Surface Casing: 13-3/8", 61&68#, K-55, BTC Set @ 3,298' MD / 3,298' TVD Existing A Sand Perf. 3,322'-3,323' (1') (SQZ) 3,355'-3,361' (6) 3,375'-3,398' (23') 3,422 ' -3,431'(9') 3,436-3,482 (47') B Sand Peforations 3,525'-3,526' (1') (SQZ) 3,550'-3,570' MD (22') Existino B&C Sand Perf. 3,660'-3,662' (2') (SQZ) 3,673'-3,683' (10') 3,700'-3,776' (76') Completion Tubing 5'/z", 17# L-80 SLHT D. E Sand Peforations 3,936'-3,940' (4') 4,096'-4,102' (6) 4,1138-4,1148'(110') 4,15T-4,170'(13') E. F Sand Peforations 4,260'-4,265' (5') 41476'-4,490' (10') 4,297'-4,303' (6) 4,593'-4,603' (4') 4,348'-4,354' (61) 4,624'-4,628' (4') 4,375'-4,379' (4') 4,676'-4,694' (18') 4,446'-4,456' (10') 4,728'-4,732' (4') 4,475'-4,490' (15') F. G. H Sand Perforations (ISOLATED) 4,764'-4,774' (10') 5,046'-5,086' (36') 4,916'-4,936' (8') 5,183'-5,189'(6-) SQZ 4,936'-4,958' (22') 5.196'-5,202' (6') SQZ 4,966'-4,986' (20') 5,398--5,448'(5U) 5,022'-5,032' (10') 5,470'-5,528'(58') Fish: 2 10' casing guns, X -over sub & Junk mill @ 5,577' MD Production Casing: 9-5/8", 43.5# P-110 BTC @ 2,154' 47#, N-80, LT&C @ 3,830' 47#, P-110 LT&C @ 7,000' MD / 7,000' TVD Schematic i Kill String @ -3,000' 3'/z" EUE-M 8rd L-80 9.3# Huck 7-21-2014 7.5 bbls of cement on top of retainer = -102' to -3,247' Inside 9-5/8" shoe Allows -50' for kickoff in the future below surface shoe Cement Retainer @ -3,350', Tested to 1,500 psi 7/20 37.5 bbl Cement Squeezed through retainer into Sterling A 5'/3" Tubing parted / chewed @ -3,403+' Casing damage / sidetrack @ -3,392' l 3,410' Top ER packer @ 3,471' inside of 5-'/2" Baker Model 96A4-60 SCI -L Isolation Packer @ 3,494' MD 190-47 GP Sliding Sleeve (Opens Down) @ 3,503' MD Potential Holes around SS. Bottom ER packer @ 3,524' inside of 5'/2" Blast Joints 6.050", 3,543'-3,573' MD Formation Sand Fill to -3,722' MD Blast Joints 6.050", 3,662'-3,780' MD 5.5" MMG GLM @ 3,790' MD (for production). DV installed. Baker Model 96A4-60 SCI -L Isolation Packer @ 3,809' MD - IBP set @ 3,839' 190-47 GP Sliding Sleeve (Opens Down) @ 3,818' MD Excluder 2000 Med. Screen @3,933'-4,017' MD Stage collar @ 3,830' MD RA tag in "Braden Blank" @ -4,022' MD? Excluder 2000 Med. Screen @4,027'-4,177' MD Baker Model 96A4-60 SC1-1- Isolation Packer @ 4,180' MD 190-47 GP Sliding Sleeve (Opens Down) @ 4,189' MD Excluder 2000 Med. Screen @4,255'-4,546' MD RA tag in "Braden Blank" @ -4,550' MD? Excluder 2000 Med. Screen @4,555'-4,743' MD Baker Model F 194-60 Permanent Packer @ 4,743' MD XN Nipple with 4.562" Profile @ 5,454' MD (plug installed 10/08/05) Baker SC -1 R Sump Packer @ 5,465' MD Tubing tail and WLEG @ 5,479' MD Bridge Plug set @ 5,660' MD. Some perforations isolated below not listed. Openhole interval drilled by Chevron in 1974. PBTD is -5,660' Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, July 20, 2014 9:43 AM To: Huck, Drew Cc: Arctic Fox Company Man 2014; Allsup -Drake, Sharon K; Shields, Austin J; Herrmann, Daniel D; Buck, Brian R; Packer, J.Brett; Herbert, Frederick O; Roby, David S (DOA) Subject: Re: 224-13 (PTD 173-037) Change of Approved Program Drew, Your new proposal to set retainer deeper and place cement on top is approved as per our phone conversation. Regards, Guy Schwartz Sent from my iPhone On Jul 19, 2014, at 1:38 PM, "Huck, Drew" <Andrew.Huck@conocophillips.com> wrote: G uy, Scott Heim made a fantastic suggestion that would allow us a better chance of salvaging this well and I wanted to run it by you. I've highlighted in red the differences from what we already sent you. In some ways, this actually fits the regulations better anyway. Basically, what we would like to do is set the retainer just above the top Sterling A sand perforations at a set depth of 3,350' instead of above the squeeze perforations from 3,322'-3,323' (shot in 1974). We would then put approximately 6 bbls of cement on top of the retainer, which should give us —50' of coverage above the squeeze perforations as detailed in the schematic. This will give us a 50' window to set a whipstock or section mill and set a plug to kick off instead of a very tight 20' window. In either case, we would be putting a window in the 9-5/8" casing anyway, so the squeeze perforations would become irrelevant. The 50' of cement on top of the squeeze perforations should give us integrity to be able to test the casing to 1,500 psi and we can always dump bail or circulate in with coil more as needed if the decision changed to permanent abandonment. Please let us know if this change meets with your approval. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. A TO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Schwartz, Guy L (DOA)[mailto:guy.schwartz@alaska.gov] Sent: Saturday, July 19, 2014 12:06 AM To: Huck, Drew Cc: Arctic Fox Company Man 2014; Allsup -Drake, Sharon K; Shields, Austin J; Herrmann, Daniel D; Buck, Brian R; Packer, J.Brett; Herbert, Frederick O; Roby, David S (DOA) Subject: [EXTERNAL]Re: 224-13 (PTD 173-037) Change of Approved Program Drew, You have verbal approval to suspend well 224-13 as outlined in your email below. A variance is granted to place retainer within 50 ft of the perforations per 20 AAC 25.112(i). Test casing to 1500 psi after retainer is set for 30 min and submit sundry first thing Monday. Regards, Guy Schwartz AOGCC Sent from my iPhone On Jul 18, 2014, at 3:52 PM, "Huck, Drew"<Andrew.Huck@conocophiIli ps.com> wrote: Guy, As discussed on the phone, we would like approval to set a cement retainer in well 224- 13 and squeeze cement into the Sterling A as a result of loss of access to the wellbore from an unintentional sidetrack due to casing damage in the Sterling A perforations. We would like to try to preserve this well for a future sidetrack option, but abandon everything below us at this point and suspend the well until next year. As a result of this, we need approval for a variance under 20 AAC 25.112(c)(1)(D) to set the cement retainer less than 50' from the top of the squeeze perforations at 3,322'-3,323' and squeeze cement away into the Sterling A sand as detailed in the attached schematic. This may allow us to fit a whipstock and sidetrack just below the 13-3/8" surface casing shoe at 3,298' in the future. We would plan on pressure testing the retainer to 1,500 psi after cement is in place and may dump a little bit of cement on top. There is a high likelihood that we will want to do this late Saturday or on Sunday, as our materials should arrive onsite tomorrow evening. As far as a kill string goes, I have 3,000' in the attached schematic, but we may elect to go with less or more; is there a specific requirement here? I couldn't find one. The 10-403 for this work would be submitted in paper on Monday if we have to go with this option. Please let me know if you have questions or concerns and whether you approve of this work over the weekend. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. A TO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) <BRU 224-13 Abandonment WBS 7-18-14.pdfl <BRU 224-13 Amended Abandonment WBS 7-19-14.pdf> 10 Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re -drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the atria or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed atrici or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. THE NATE GOVERNOR SEAN PARNELL 33 West Seventh Avenue Ancorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 scum `? T r Re: Beluga River Field, Undefined Gas Pool, BRU 224-13 Sundry Number: 314-375 Dear Mr. Huck: 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 L9' d of June, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUN 17 2014 l4- 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend (— Rug Perforations j ` Perforate r Pull Tubing r7o Time Extension (— Operational Shutdow n r Re-enter Susp. Well ( Stimulate r Alter casing r Other: Gravel Pack r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r Stratigraphic r Service r 173-037 • 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20042-00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? cZ0 AA .0 Will planned perforations require spacing exception? Yes r NO r7o / BRU 224-13 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 58831 Beluga River Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,000' 10,000' 5653' 5653' 5454' 5653' Casing Length Size MD TVD Burst Collapse Conductor 65' 30" 65' 65' Surface 423' 20" 423' 423' 1,530 psi 520 psi Intermediate 3,298' 13-%" 3,298' 3,298' 3,090 psi 1,540 psi Production 6,999' 9 %1. 6,999' 6,999' 6,870 psi 4,750 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): from 3,322' to 6,470'; See Attached / 3,322'-6,470' 5-1/2" L-80 5,478' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) 1 Baker SC -2 Production Packer and 5 Isolation Packers 3,110'; 3,494'; 3,813'; 4,184'; 4,742'; 5,464' MD & TVD BP6i Ported Nipple 407' MD / TVD, 12. Attachments: Description Summary of Proposal r7o • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r ' Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/3/2014 Oil r Gas r • WDSPL r Suspended r WINJ r GINJ r WAG r Abandoned (— 16. Verbal Approval: Date: Commission Representative: GSTOR r SPLUG r- 17. 1 hereby certify that the foregoing is true and correct to the best of 17. my knowledge. Contact: Drew Huck @ 265-6828 Email: Andrew.Huck(a)-cop.com Printed Name Drew Huck Title: Drilling Engineer Signature �,..,,__ Phone: 265-6828 Date 117/ 1pl " Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ` -� ?jam Plug Integrity r BOP Test j -Mechanical Integrity Test r Location Clearance r :3060 /3 r /r 'PSI' Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: / - �{ Ct APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: Apprdved p I I o mont s trrom e7 date o approval. �//fir Form 10- (Revise 10/2012) t Submit Form a ,A- `/Tlr n,,&n tin °VW o 20h ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 13'`, 2014 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 70' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: RECEIVED JUN 17 2014 AOGCC ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Beluga River Unit Producer 224-13 (PTD# 173-037). BRU 224-13 was originally drilled, tested & suspended in 1974 and completed as a producer in the Sterling A, Beluga G, and H sands in 1981. It has undergone workovers since, most recently in 2005 to gravel pack the Beluga D, E, and F sands. The purpose of this workover is to re -perforate and gravel pack the Sterling A and C intervals, isolate the Sterling B interval, and keep the existing lower completion to maintain vroduction of the Beluga D E and F To do this, some of the lower completion will first need to be fishedoncluding the top two packers. An isolation string will be added in the lower completion to provide control of the zones in the future. If you have any questions or require any further information, please contact me at 265-6828 or Andrew.Huck(&cop.com. Please keep in mind proposed completion depths are approximate and the plan is necessarily rough, especially for fishing the existing completion. Sincerely, �� ?Z� Drew Huck Drilling Engineer CPAI Drilling and Wells BRU 224-13 Rig Workover: Pull 5-1/2" completion, perforate and gravel pack Sterling A, B, and C, run 3-1/2" completion (PTD# 173-037) Current Status: The well has been shut-in since May 2011. Scope of Work: Pull the upper portions of the existing completion, perforate and gravel pack in 2 separate intervals, and run 3-1/2" gas lift upper completion. General Well info: MASP: 777 psi (using 0.1 psi/ft gas gradient and Beluga E @ 4, 729' MD) Max. Reservoir pressures/TVD: From 6/9/2014 SBHP: Beluga F @ 4,729' MD / TVD = 1,250 psi / 5.1 ppg Wellhead type/pressure rating: VetcoGray 3,000 psig Arctic BOP Configuration: Annular / Pipe Rams / Blind Rams / Flow Cross / Pipe Rams Well Type: Gas Producer Estimated Start Date: July 3td, 2014 Workover Engineer: Drew Huck (265-6828, Andrew.Huck@cop.com ) Completion Engineer: Austin Shields (263-4523, Austin.J.Shieldsacop.com) Production Engineer: Daniel Herrmann (263-4619, JD.Herrmann(acop.com) Proposed Pre -Rig Work: 1. MIRU braided slickline. 2. Fish lost overshot grapple (4490'), upper patch (3097'-3135'), middle patch (3368'-3389'), ER packer fish (3450'), and lower patch (3471'-3524'). 3. MIRU e -line. 4. Set 5-1/2" WRP below the Baker SC -1L packer @ 3809' 5. Cut just above the Baker SC -1L packer @ 3809' 6. Set second 5-1/2" WRP below the Baker SC -2 packer @ 3106' 7. MIRU slickline. Open Baker CMU at 3029'. 8. Circulate water into tubing and IA. 9. Monitor tubing and IA and bleed off any gas. Perform combo -MIT (TxIA) to confirm casing and tubing integrity. 10. Set BPV. 11. Prep site and pad as needed for the rig. Proposed Procedure: 12. MIRU. Pull BPV. A aJ1-c- 13. Conduct no -flow test. Install two-way check. ND tree. 14. NU BOPE. Function and PT BOPE to 250/3,000 psig. Pull two-way check. r t'O '- 15. POOH w/ 5 '/2" completion. (If the seal assemblywill not pull free, cut tubing above the PBR and POOH w/ tubing.) 16. Latch and pull anchor assembly. 17. Release and pull SC -2 packer. Unthread tubing stub from SCI -L packer. 18. Latch and POOH with SCI -L packer. Unthread tubing stub from second SCI -L packer at 3809'. 19. RIH with sump packer and isolation string. 20. Set plug in nipple at base of isolation string. 21. Tubing conveyed perforate target intervals in the Sterling A and C, pumping a fluid loss control pill if necessary. 22. Cleanout debris and perforation burrs to sump packer. 23. RIH with 2 zone gravel pack system and inner string, latch into sump packer and set isolation packers. 24. Pump gravel pack in 2 zones successively. POOH with inner string and workstring. 25. RIH with 3-1/2" upper completion, circulate in CI brine, space out, stab into top packer, and set hanger. 26. PT tubing and IA. (C k'st /15-0 a p s.: / _?') 27. Set two-way check. 28. ND BOP. NU tree. PT tree and tubing hanger packoffs. 29. RDMO. 30. Turn well over to operations. *Red is proposed new equipment Conductor (Driven): 30", @65' MD Conductor: 20", 94#, H-40, @423' MD Surface Casino: 13-3/8", 61&68#, K-55, BTC Set @ 3,298' MD / 3,298' TVD Camco MMG GLM @ -3,200' MD HES X Nipple w/ 2.813" prof. @ -3,230' MD 3,355'-3,361' MD (6) 3,380'-3,397' MD (17') 3.421'-3,431' MD (10') 3,439'-3,495' MD (56' 3,322'-3,323'(1') (SQZ) 3,355'-3,361' (6') 3,435'-3,482' (47') 3,375'-3,398' (23') 3,422'-3,431' (9') B Sand Peforations 3,525'-31526' (1') (SQZ) 3,550'-3,570' 3_660',3,662 (2') (SQZ _ Proposed and Perf. 118 sof) 3,702'-3,714' MD (12') 3,718'-3,740' MD (22') , 3,752'-3,776' MD (24') C, Exi in d P rf. 3,673'-3,683' (10') 3,700'-3,776'(76') D. E Sand Peforations 3,936'-3,940'(4') 4,096'-4,102' (6) 4,138'-4,148' (10') - 4,157'-4,170' (13') Vv E. F Sand Peforations 4,260'-4,265' (5') 41476'-4,490' (10') 4,297'-4,303' (6') 41593'-4,603'(4') 4,624-4,628' (4') Y 4,375'-4,379' (4') 4,676-4,694' (18') 4,446'-4,456'(10') 4,728'-4,732' (4') 4,475'-4,490'(15') F. G. H Sand Perforations (ISOLATED 4,764'-4,774'(10') 5,046'-5,086' (36') _ 4,916'-4,936' (8') 5,183'-5,189' (6) SQZ 4,936'-4,958'(22') 5.196'-5,202' (6) SQZ 4,966'-4,986' (20') 5,398'-5,448' (50') _ 5,022'-5,032' (10') 5,470'-5,528' (58') Fish: 2 10' casing guns, X -over sub & Junk mill @ 5,577' MD Production Casing: 9-5/8", 43.5# P-110 BTC @ 2,154' 47#, N-80, LT&C @ 3,830' 47#, P-110 LT&C @ 7,000' MD / 7,000' TVD DS Nipple w/ 2.875" profile @ -500' MD WO Camco KBMG-LTS CIM @ -3,160' MD w/ 3/8" SIM encapsulated injection line Production Tubing: GL 3'/2", 9.3# L-80, EUE 8rd to 3,263" MD / TVD Superior CSHP-II NR Packer @ 3,264' MD Superior MS Cls Sleeve @ 3,302' MD Superior Screen @ 3,351'-3,502' MD Superior 9637 Isolation Packer @ 3,503' MD Superior 9637 Isolation Packer @ 3,609' MD Superior MS Cls Sleeve @ 3,615' MD Superior Screen @ 3,694'-3,783' MD Superior CSHP-II NR Packer @ 3,792' MD Baker Model 96A4-60 SCI -L Isolation Packer @ 3,813' MD 190-47 GP Sliding Sleeve (Opens Down) @ 3,823' MD 2-7/8" CMU Sliding Sleeve w. 2.313" BX Profile @ -3,820' MD Excluder 2000 Med. Screen @3,937'-4,182' MD Stage collar @ 3,830' MD Baker Model 96A4-60 SC1-L Isolation Packer @ 4,184' MD Seal elements in seal bore of packer @ -4,184' MD 190-47 GP Sliding Sleeve (Opens Down) @ 4,198' MD XN Nipple with 2.205" Profile @ -4,700' MD with plug Excluder 2000 Med. Screen @ 560'-4,747' MD 2-7/8" Tubing tail with WLEG @ -4,745' MD Baker Model F 197-60 Permanent Packer @ 4,742' MD XN Nipple with ??? Profile @ 5,453' MD (plug installed 10/08/05) Baker SC -1 R Sump Packer @ 5,464' MD Tubing tail and WLEG @ 5,478' MD Bridge Plug set @ 5,660' MD. Some perforations isolated below not listed. Openhole interval drilled by Chevron in 1974. PBTD is -5,660' STATE OF ALASKA ALASKI& AND GAS CONSERVATION COMMISO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repairwell r Plug Perforations Stimulate r Other '"°` Alter Casing Pull Tubing f Perforate New Pool Waiver F Time Extension —' Change Approved Program ° Operat. Shutdown r Perforate r Re -enter Suspended Well '-'° 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development T` Exploratory - 173 -037 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service F L 50- 283 - 20042 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 58831 BRU 224 -13 9. Field /Pool(s): Beluga River Unit, Undefined Gas Pool 10. Present Well Condition Summary: Total Depth measured 10000 feet Plugs (measured) 5454' true vertical 10000 feet Junk (measured) 5653' Effective Depth measured 5653' feet Packer (measured) 3109', 3465', 3490', 3809', 4180', 4743' true vertical 5653' feet (true vertucal) 3109', 3465', 3490', 3809', 4180', 4743' Casing Length Size MD TVD Burst Collapse Structural 65' 30" 65' 65 Conductor 423' 20" 423' 423 Surface 3298' 13 -3/8" 3298' 3298 Production 6999' 9 -5/8" 6999' 6999 S� � � Perforation depth: Measured depth: 3355' -5516' NGV 2W co True Vertical Depth: 3355' -5516' - mov 0 9 2010 Tubing (size, grade, MD, and TVD) 5.5 ", L -80, 3110 MD, 3110 TVD r . ��� oil c�t ��as, @ a "3SIOD Packers & SSSV (type, MD, and TVD) 3109', 3465', 3490', 3809', 4180', 4743' MD and TVD MAW* Camco nipple @ 417' MD, 417' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 3355' - 5516' Treatment descriptions including volumes used and final pressure: several stages see attachment 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 3.1 mmscf /d 140 Subsequent to operation 2.6 mmscf /d 150 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory Development Service Stratigraphic 15. Well Status after work: Oil Gas W', WDSPL Daily Report of Well Operations _XXX GSTOR r WINJ WAG GINJ SUSP r SPLUG 16. 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: 310 -157 Contact T. Senden (a) 265 -1544 Printed N e T. Send n Title Wells Engineer Signature Phone: 265 -1544 Date 0 FU RBDMS NOV 0 9 -,, Form 10 -404 Revised 10/2010 Submit Original Only • SAK • BRU 224 -13 Conocc �( " Well Attributes _ _ Max Angle & MD TD Alaska nR Welltlore APVUWI 'Field Name IWeII Status Ind ( °) IMD(ftK8) IAct Bim(ftKB) _ 502832004200 BELUGA RIVER UNI T PROD 1 10.0000 Comment H2S(ppm) 'Date Annotation End Date KB- Grd(ft) Rig Release Date SSSV NIPPLE wen tong egu 22413, rrsRCiG 3;1Z 39 PM, - : Last WO: 10;19/2005 18.20 12/16/1974 _. Sc nematc Acwel.. - Annotation Dep[h IRKS) End Date Annotation Last Mod By IEnd Date Last Tag' 4 480 0 11/26/2009 Rev Reason: Set Capillary String, Packer Imosbor 11/5/2010 HANGER. 25- - -- - "!' C asing Strings NIPPLE, 417- Casing Description String O._'. String ID ... Top (NKB) Set Depth (f... Set Depth(ND)... String W[... String... IS[ring Top Third CONDUCTOR, CONDUCT 20 19.124 25.0 423.0 94.00 H40 Butt 25423 .� _ _ - - SLEEVEO, casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (ND) ... String Wt... String.. String Top Third 3,030 SURFACE 13318 12.515 25.0 3,298.0 61.00 K -55 Butt PACKER, 3,105 ---n casing Description String 0... String ID .. Top (NKB) Sat Depth (f... Set Depth (WD)... String WE. String ._ String Top Thrd -" _ -=-" PRODUCTION 9 5/8 8 755 25.0 6,999.0 43.00 N- 80 /... Butt -_ _-. _ _ -_ -_ SLEEVE -C, _ ' Casing Description String O. -. String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) .. String WI... String String Top Third 3,121 f OPEN HOLE 95/8 6,755.0 10,0000 SLEEVE-C, Stri �s SURFACE, Tubing Descn pti- String .. String ID ... Top (NKB) Sel Depth String Wt... String ... String Top Third 25- 3,298~` 'TUBI NG S2 51/2 4.950 25.0 3,134.3 _ i 1550 L80 EUE -SRD 3,322 _ - ,.__ _.. _... _ __..__. 3.355 -3.361 Co Details ' - � ,' � 1�.._ Top Depth 3,375 - 3,396- - - (TVD) Top Intl Nomi... _. Top (ftKB) (ftKB) C) Item Description comment 3,422- 3.431- - 25.0 HANGER TUBING HANGER 2 -875 3,435 -3,482 - 417.0 NIPPLE CAMCO BPfii PORTED NIPPLE WITH METHANOL INJ LINE 5.545 PACKER, 3,671 - 3,030.0 SLEEVE -C BAKER CMU SLIDING SLEEVE (OPENS UP) 4.562 PACKER, 3,490 3,109.0 PACKER BAKER SC-2 96SU -60 PACKER 6.000 PA SLEEVE - C, 3,121.0 SLEEVE -C 190-47 GRAVEL PACK SLIDING SLEEVE (OPENS DOWN) 5.870 31496 _ _ _-. _. _- _ PACI(ER, 3,526 _ Tubing Des - ption Str rig 0... Str rig ID ... Top (NKB) Set Depth (f... Set Depth (ND) .. String Wt... String -. String Top Thrd 3,525 CAPILLARY 3/8 0.125 250 4,150.0 4.30 N -80 EUE -8RD { Completion Details Top Depth 3,660 -3,662 (ND) Top Irtcl Nomi... DST #6, - To B I B) ( °) Ite Des-iP - Co mment ID (in) 3.755 - 3.760 •,_ - __.... _ _. , 25.0 CAPILLARY 0.125 GAS LIFT, I Tubing Description String 0... Stri g ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 3,786 TUBING SI 512 4.950 3,110.0 5,480.1 15.50 L -80 BTC PACKER, 3,809 -- Coin letion Details I - Top Depth ;. (TVD) Top Inc/ Nunn - i To B (BKS) C) item Description c ID SCREEN, 3,933 - - - - -- 3,148.0 SLEEVE -C MODEL-C ISO PROTECTION SLEEVE (OPENS DOWN) 5.000 SCREEN, 4,027 3,490.0 PACKER UPPER ISO PACKER 96A4 -60 SC1 -L 5.000 3,498.0 SLEEVE -C GRAVEL PACK SLIDING SLEEVE (OPENS DOWN) 5.870 PACKER,4,180 - _ 3,544.0 BLAST JT 4.892 SLEEVE, 4,189 3,809.0 PACKER LOWER MIDDLE ISO PACKER 96A4- 60SC1 -L PACKER 5.870 3,818.0 SLEEVE -C 19047 GRAVEL PACK SLIDING SLEEVE (OPENS DOWN) 5.870 SCREEN, 4.255 - 3,933.5 SCREEN EXCLUDER 2000 MED SCREEN 4 -892 4,4464.456- ----. 00 _ 4,027.3 SCREEN EXCLUDER 2o WED SCREEN 4.892 4,4764,490 - - - { 4,180.0 PACKER LOWER ISO PACKER 96A4.60 SCI -L 5.000 4,189 -1 SLEEVE 19047 GRAVEL PACK SLIDING SLEEVE (OPENS DOWN) 5.870 4,5934,603 - • 4,255.2 SCREEN EXCLUDER 2000 MED SCREEN 4.892 4,556.0 6,6764,694 REEN EXCLUDER 2000 MED SCREEN 4.892 - �:: _ SC- PACKER, 4,743 - -- _ 4,743.0 -- PACKER BAKER 197- 60'F'PERMANENT PACKER 6.000 4,7644,774 ','� 5,454 -2 NIPPLE HES'XN'NIPPLE 4.550 n, 4,916-4,924 1. 5,465.0 PACKER BAKER SCAR RETRIEVABLE SUMP PACKER 6.000 5,479.1 WLEG WIRELINE ENTRY GUIDE 6.625 6.9364,958 DST#7, Other In Hole Wireline retrievable plugs, valves, pumps, fish etc_ 4,9664,986 ` Top Depth (TVD) ToD I�IACK. 5022 - 5,032^° T KB KtK ( °I Comment Run Data ID in 050 - 5,056 t ' 3,471.0 UPPER ER PACKER 11/4/2007 3.000 5,056 - 5,086 DST #6, _ i 1 3,473 -0 PATCH TUBING PATCH 11/412007 3.000 s,396 -s,ua '- _I,__ 3,524.0 PACKER LOWER ER PACKER 11/4/2007 3.000 NIPPLE, 5,454 � PLUG, 5,454 - 5,454.2 PLUG PXN PLUG 112/2005 0.000 5,577.0 - -- FISH Casing Gun 10' Dresser Atlas 12 SPF casing guns (top 10' 12/1/1988 PACKER, 5,465- - DNF) pushed to 5577' 11/18/88 WLEG, 5,478 a 5,587.0 FISH Casing Gun 10' Dresser Atlas 12 SPF CasingGun (top 10' 12/1/1988 DNF) pushed to 5577' 11/18188 5,494 5,654.0 - FISH X Sub 3.5" reg box by 3.5" IF pin 12/1/1988 3.500 FISH.5,5-- 77 - _ _ ._. ____. ___ __-- S 654.5 FISH Junk Mill 12/1/1988 3.500 FISH. S,Sd7 Perforations & Slots v FISH. 5,654 . _.... FISH, 5,655 Shot DST #5, Top (TVD) at. (TV Dons 5,681 - 5,689 Top(ftK6 Btm (face) (ftKB) (ftKB) Zone Dale (sh... Type Comment DST #5 3,322.0 3 3 ,322 -0 12/12/1974 4.0 Perfd for squeeze & Tested 5,705 - 5,725 - - 88 - Dsr#5, 3,355.0 ,361.0 1120119 12.0 Ong 4 SPF 3/23181, Reperfd s,u3 DSST T #f4, " 3,375.0 3,398.0 1120/1988 12.0 Ong 4 SPF 3/23/81, Reperfd , 5,820 - 5,846 3,422.0 3,431.0 11120/1988 12.0 Orig 4 SPF 3/23/81, Reperfd DST #3, 6,026 - 6,038 3,435 - 0 3,482.0 - 7120/1988 72.0 Ong 4 SPF 323!81, Reperttl DST #3, s,oa4 - 6,076 - 3,525.0 3,525 o 12/10/1974 4.0 Perfd for squeeze & Tested DST #2, - 3,660.0 3,662.0 12/6/1974 4.0 Pallid for squeeze, resqueezed& 6,117 -6,121 Tested DST#2, 6,129 -6,136 DST#2, 3,755.0 3,760.0 1219/1974 4.0 DST #8 Squeezed 6,136.6,145 _- "- DST #2, 6, 159-6.176tb DST #1A, Mandrel Details tit _ 6,422-6,4x0 Top Depth Top DST #1A, Pori ( °) 6,4486,454 (TVD) I ci OD vaM Latch Size TRO Run DST#1A, Stn To KB (ftKB) Make Model (in) Sery AS LIFT DWY TYPe Type (i ^) (Psi) Run Date Cam... s,asz s,a7o 1 3 786 0 - G 0.000 0.0 1021/2010 PRODUCTIDN, 25199s OPEN HOLE, 6,755.10,000 TD, 11) • CaKrCi!!kps SAK • BRU 224 -13 (!t) Rig Rekaese Dab 1820 12/1611974 SiNe 'ai _ Aattu HANGER, 25 <„ Perforations & Slots NIPPLE, 417 Shot CONDUCTOR, Top(rVD) Btm (TVD) Dens 25-423 SLEEVE -C, T B1m ft156 M B (ftKB) (ftKB) �_ Zone [late (sh Type Correnent __.. 3,030 4,446.0 4,456.0 11/18/1988 12.0 PACKER,3,109 4,476.0 4,490.0 11/18/1988 12.0 SLEEVE-C, _ 4,593 -0 4,603.0 11/1811988 12.0 3,121 _ T676 ..... _....._..__ .0 4,694.0 11/18!1988 12.0 SLEEVE - C, 3,148 4,764.0 4,774.0 11/1811988 12.0 SURFACE, 25 - 3,298 4,916 - 0 4,924.0 11118/1988 12.0 3,322 4,936.0 4,958.0 12/4/1974 12 3,355 - 3,361 .0 DST #7 Ong 4 SPF, Reperfd - 4,966.0 4,986.0 12/3/1974 12.0 DST #7 Orig 4 SPF, Reperfd 3,375 - 3,398 5,022.0 5,032 -0 121311974 4 -0 DST #7 3,422 -3,631 5,050.0 5,056.0 11/1811988 12.0 3,435 -3.482 - 5,0,56.0 5,066.0 11115/1988 12.0 PACKER, 3,471 5,398.0 5,448.0 L11/27/1974 12.0 DST #6 Orig 4 SPF, Reperld, Open PACKER, 3,aso ---- 5,494.0 5,516.0 12.0 Open PATCH, 3,473 SLEEVE 5,681.0 5,689.0 4.0 DST #5 Squeezed 3,498 PACKER, 3, 52 5,705.0 5,725.0 4.0 DST #5 Squeezed 3,52s -- _ 5 5,758.0 4 -0 DST #5 Squeezed 82 - 5,0.0 5,848A 4.0 DST #4 Set BP @ 5800' 3,660 - 3,662 _ - - ° DST #e. 6.0 6,026.0 6,038.0 1125/1974 4.0 DST #3 Set BP @ 6000' - 3,755 3,760 6,044.0 6,07 1125/7974 4.0 DST #3 GAS LIFT, 6,117.0 6,121.0 1122/1974 4.0 DST #2 Set BP @ 6145' & 6106' 3,786 6,129.0 6,136.0 112211974 4.0 DST #2 PACKER, 3,809 -- - 6,138.0 6,145.0 1122/1974 4.0 DST #2 I 6,159.0 6,176.0 1122/1974 4.0 DST #2 6,422.0 6,440.0 1120/1974 4.0 DST Set BP @ 6375' SCREEN, 3,933 #1A SCREEN, 4,027 6,448.0 6,454.0 112011974 4.0 DST #1A PACKER,4,180 - 6,462.0 6,470 -0 1120/1974 4.0 DST #1A SLEEVE, 6,189 -- Notes: General & Safet SCREEN,4,255 - - - -- End Data Annotation 4.4464.456 6/29/1998 NOTE: 1988 WO - Left in Hole: 4,4764,490 6.5" OD junk mill & 4 -75" OD Xover sub at 5654' on 11/12/88 4,5934,603 - 6129/1998 NOTE: TAG DATA: 4,6764,694 String 1: PACKER, 4,743 -- 5/6191 1.5" bailer, fill at 5507' RKB 6/21/92 1.75' bailer, fill 4,7644,776 - ' 11/52010 NOTE: NO RIG TALLIES AVAILABLE FROM 1974 4,9164,924 - y„ DST , -: 6,936.4,956 DST 97, 4,9664,966 DST #7, 5,022.5,032 lI 5.050 -5.056-- __- ..__ -� i 5,056 -5.086 DST #6, .,.._ 5,398-5,448' -' - -- - NIPPLE, 5,454 PLUG, 5.454 - _ PACKER, 5,465- - filli WLEG, 5,478?. 5,494 -5,516 FISH, 5,577 - - -N FISH, 5,58] - FISH, 5,656 FISH, 5,655 DST#5, 5,881 -5,889 - - DST#5, 5,705 -5,725 - -� DST #5, 5,743 -5,]58 - - DST #4, 5,820 -5,848 DST #3, - 6,028 -6,038 DST #3, 6,044.6,076 DST #2, 6, 17.6,121 DST#2, it 6,129-6,136 DST #2, 6,138 -6,165 - DST #2, 6.159 - 6.1]6 DST #1A, 6,422 -6,440 DST#1A, 6.448 - 6,454_ �. DST #1A, 6,462 -6,470 PRODUCTION, 25 -6,999 OPEN HOLE, 6,756-10,000 TD, 10,000 BRU 224 -13 Well Work Summary DATE SUMMARY 6/10/10 MIRU BJ DYNA COIL EQUIPMEN . PULLED 3/8" CAPILLARY STRING FRO *30' TO SURFACE, NO ISSUES. SECURE WELLHEAD, RDMO DYNA COIL. 6/11/10 MIRU POLLARD W/L UNIT. DRIFT TUBING WITH 2.25" SWAGE TO OBSTRUCTION @ 4,497'RKB. RIH W/ 1.55" BAILER TO 4,775'RKB, NO ISSUES. SECURE WELLHEAD, RDMO POLLARD. STAGE BJ CTU AND EQUIPMENT, JOB IN PROGRESS. 6/12/10 PERFORM INITIAL BOP TEST, MIX APPROXIMATELY 400 BBLS OF 5% HCL, WILL PUMP ACID TREATMENT IN THE MORNING. 6/13/10 PERFORMED ACID TREATMENT WITH 480 BBLS OF 5% HCL THROUGH BJ ROTO -JET @ 1.15 BPM 350 SCFM N2 FROM 4,150'CTM TO 4,600'CTM, MAINTAINED GOOD ACID RETURNS THROUGHOUT, PUMPED NITROGEN @ 1,500 SCFM OUT OF HOLE TO DISPLACE TUBING FLUID. SECURE WELLHEAD, LDFN. 6/14/10 FLOW WELL BACK TO RETURN TANKS, INITIAL WHP 725 PSI, BLEED WELLHEAD TO 350 PSI CHOKE AT SKID HALF OPEN, 8 BPH WATER IN RETURNS. OPEN CHOKE FULLY, WELLHEAD PRESSURE INITIALLY 200 PSI, BUT DROPPING OFF SLOWLY TO 125 PSI, WATER RETURN UP TO 20 BPH OVER 4 HOUR PERIOD. TOTAL VOLUME OF FLOWBACK FLUID 670 BBLS. DECIDE TO SHUTDOWN FLOWBACK AND LET WELL BUILD PRESSURE. RDMO BJ COIL, JOB COMPLETE. 6/16/10 MIRU POLLARD /PDS FOR CALIPER SURVEY. CALIPER TUBING FROM 2,000' TO 4,850'RKB, GOOD DATA, SECURE WELLHEAD, RDMO POLLARD /PDS. 6/23/10 MIRU BJ Capillary String Unit, run 3/8" capillary string w/ 2.0" fluted centrilizer and piston check to mid- entry point for water at 4150' ctmd. Hang string off in WH packoff assembly. Fluid pack coil and verify ability to inject. Set injection to 5 gpd foaming agent and hand well over to production. RDMO. 10/16/10 MIRU BJ capilary string pulling unit, pulled 4150' of 3/8" Dyna coil from well. MIRU BJ CTU, swap equipment for to 1.75" coil. 10/18/10 RIH w/ 2.125" BJ Roto Jet w/ 90 deg jets and acidized scale coated screen interval from 4250' to 4550'w/ 378 bbls of nitrified 5% Hcl. Dropped ball and circulated well out with N2 while POOH. 10/20/10 Ran PDS slim -hole caliper w/ extended fingers accross scaled tubing interval from 4860' wlm to 1823' wlm. Appears scale has been removed from well, clear picture of gravel pack screens with full bore ID pipe. 10/22/10 MIRU BJ Capillary String Unit, run 3/8" capillary string w/ 2.0" fluted centralizer and piston check to mid -entry point for water @ 4150' ctmd. Hung string off in WH packoff assembly. Unable to test pump due to lack of power at pad. RDMO. TRANSMITTAL Be/uga Rives Unit deve%pment we//data FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzer ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7m Ave, Suite 100 Anchorage, Alaska 99501-3539 RE: Beluga River Unit production logging DATE: 08/16/2010 Mail delivery __ Transmitted: Cook Inlet, Alaska BRU224-13 (permit 173-037-0) ~~ ~ ~ ~ -~ Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 8/28/2007 ~?roactive Diagnostic Services, Production profile; 7/18/2008 BRU 211-03 (permit 186-010-0) ~pp~°~ ~ Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 6/4/2008 ~roactive Diagnostic Services, Gas Entry Survey; 6/5/2008 F ~, _~ ~~ ._ r ~ 1?~~ BRU 212-35T (permit 198-161-0) ~d(j ('~. Proactive Diagnostic Services, Production profile; 7/17/2008 BRU 212-24 (permit 172-015-0) ~~~ (P Proactive Diagnostic Services, Multi-finger caliper report and 3D data and viewer; 9/22/2005 BRU 243-34 (permit 208-079-0) ~C34 c~ iA Proactive Diagnostic Services, Production profile; 9/2/2008 ~ U- G./S /-~:~riea! l?ata 'Ian erg o b , ,~/asl~a ~ ~h,° .~G'.~ ~5.~' ; ~'7 Sandra D.LemkeCv~Conocophi/li,~s.mm L~ Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ~ ~ ~. , ~ ~ ~ ~ ~ ~, Anchorage, AK 99510 ~ ~ . `~ ~ ~ 3 Re: Beluga River Field, Undefined Gas Pool, BRU 224-13 Sundry Number: 310-157 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~6day of May, 2010. Encl. ~,p STATE OF ALASKA ~,~' ALASK~L AND GAS CONSERVATION COMMISS• APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 klth- ~EI~s~Z°~Zo,o MAYly2010 1. Type of Request: Abandon ~"' Plug for Redrill r vedPt~~ ~' Perforate New Pool ~ Repair well ~aS~ 1 OO tt ~ tJl' (S E ~l I-- Suspend " Rug Perforations ~~ s~V86~ 7x6 '~~ E x ension "'' t ~ F~rforate ~"` Pull Tubing ~ Operational Shutdown `°" Re-enter Susp. Well Stimulate ~°; • After casing ~ Other: ~` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory `" 173-037 3. Address: Stratigraphic Service " 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-283-20042-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@s No ~ BRU 224-13 , 9. Property Designation: 10. Field/Pool(s): ADL 58831. Beluga River Unit c.(-t~ J~+i..~-~1 •._~~ ~~ .L'S ~ -~r..G= 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effeaive Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10000 10000 5653' 5653' 5454' 5653' Casing Length Size MD ND Burst Collapse Structural 65 30" 65' 65' Conductor 423 20" 423' 423' Surface 3298 13-3/8" 3298' 3298' Production 6999 9-5/8" 6999' 6999 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3355'-5516' 3355'-5516' 5.5" L-80 3110 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Baker and Weathertord packers 3109', 3465', 3490', 3809', 4180', 4743' MD/ND Camco nipple 471' MD / 417' TVD 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ~' BOP Sketch """ Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/8/2010 Oil ~'` Gas WDSPL Suspended "' 16. Verbal Approval: Date: WINJ ~ GINJ ~ WAG ~ Abandoned ~" Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed N e Jim Ennis Title: Wells Engineer ~ Signature ~8 ~~ Phone: 265-1544 Date Cmmi in n Sundry Number: ~' O-`~~ Conditions of appr al: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test Mechanical Integrity Test Location Clearance "°`" Other: ~ ~ S-}• ~ p f ~ 'f't~ ~rJ 0!~ ~S ~ . Subsequent Form Required: ~ p , APPROVED BY ~-~ / ~/Q b Approved by: COMMISSIONER THE COMMISSION Date: ~ RBDMS MAY 2 7 2011~~`~ Form 10-403 Revised 1/2010 r Submit in~Duplicate q ~, -`' • BRU 224-13 • PTD# 173-037 CT Acidize Scale Wells Network: 10281438 The procedure outlined below will utilize BJ's roto-jet nozzle to radially acidize scale in ,,~.-- ,. the gravel pack completion with 20000 gals 5% HCL The scale was i@ntified in August 2007 with attached caliper and a side scan video log. An increment 2 MIVIEFD is expected following this work. _- Reminder: All personnel on location are required to have received Beluga orientation training at the CPAI Kenai LNG Plant within the past year. Procedure• MIRU BJ Dynacoil spooling unit. Unland & remove 3930' capillary string. RDMO. 2. MIRU Pollard slickline. Roundtrip 2.25" drift to 4750' MD to verify adequate ID through scale remains. RD slickline. 3. MIRU BJ 1.75" CTU. Nipple up and test BOP 250/4500 psi as per SOP. Notify AOGCC 24 hours prior to BOP testing. 4. RIH w/ 2.125" Roto-Jet 90 degree discharge nozzle and circ sub to 4600' CTMD. Establish rate w/ 1 bpm 5%HCL w/ additives. Perform up/down passes @ 30 fpm from 4600'-4150' utilizing 20M gals 5%HCL. Launch %2" ball w/ two bbls acid remaining and displace to circ sub w/ N2. Shear circ sub and unload well w/ / N2 @ 1500 scfm. POOH. 5. Flow well for cleanup & turn over to production. 6. MIRU Pollard slickline. RIH w/ PDS memory caliper to 4800' MD. Log caber pass 4800'-3000' MD. POOH w/ caliper. RD slickline. 5/18/2010 BRU 224-13 CT acidize scale 5-18-10.doc Created by jjennis • S aBe Conoe Phillips BRU 224-13 API# 50-283-20042-00 420 a Gravel Packed Gas Producer Annulus Fluid: KCI w/ corrosion inhibitor 9.96 ppg to 3029' Sing/e Comp/etion Max Hole Angle: 2.° @ 9,695' Spud Date 11/20/74 3,030 b } ] [ { Sect. 13, T13N, R10W, SW 1/4 RKB to Ground: 25.' Last Completion 10/19/05 3,051 ASP @ Beluga: 2,636,609; 325,576 RKB to SL: 94.' Schematic Rev. 12/7/09 3,081 CASING & TUBING 2005 RKB to Ground: 21.15' Ho% by Jim Ennis 3,109 c Description OD Btm. Weioht Grade Thread Size Cement 3,121 d ) [I r1 Surface Csg. 20" 423' ~ 94. # H-40 Buttress 26" 660sx "G". 3,148 a Intermediate 13 3/8" 3,298" 61#/65# K-55 Buttress 17 1/2" 2010sx "G". Rtns to surface 3,322 s z Prod. Casing 9 5/8 2,151' 43.5 # P-110 Buftress 12 1/4" SSOsx @shce, bump plug 3,330 e1 Prod. Casing 9 5/8 6,999' ~ 47. # P-110/N-80 8rd LT&C 12 1/4" 500sx @ 3827' collar 3,355 A Open Hole 10,000' 8 1/2" 295sx "G" 3,406 e2 A Prod. Tubing 5 IJ2" 3,110' 15.5# I -$0 BTC rr~ria 3,450 A Screens/Blank 5 1/2" 5,479' i ` I , 3,489 f A 3,498 g ~ [I f1 sq z Lbl. Top JEWELRY& FISH Length ID OD 3,550 h B a 417' Camco BP-6i ported nipple with methanol inj line 2.75' 4.562" 6.65" 3,660 s z b 3,030' SS Closed Baker CMU Sliding Sleeve w/ 4.562 BX profile -opens uo 4.64' 4.562" 6.50" 3,684 B cl 3,093' 4Z' Weatherford packer straddle patch, 2.87"ID, from 3093' to 3135' 42.' 2.87" 4.50" 3,700 C c 3,109' ' PKR Baker SC-2 96B2-60 w/ 7 3/4" 46.1# Hyd 523 Box do 5.24' 6.00" 8.45" 3,786 i C d 3,121' SS Closed 190-47 Gravel Pack Sliding Sleeve -opens down 4.66' 5.87" 7.40" 3,805 e 3,148' f4odel C Iso Protection Sle~=ve & C-2 KOIV, 6.625" SLHT BXP 2.93' 5.00" 8.15" Dy nac oil @ 3930' el 3,364' 2ii' Weatho:fiord pae~er straddle patch., ?.87"ID, from 3364'-3390' 26' 2.87" 4.50" e2 8,465' Weatherford 'ER' pkr sitting on straddle below `e~~;;, ~ ~ 3,809 j fl 3,471' S5' 1'Veather-ford packer stra.1~11e pah_h, LS7"ID, from 3471-3526' 55.' 2.87" 4.50" 3,936 F; I I'. iJ f 3,490' PKR Upper f4iddle Ism Packer 96A4-60 SC3-L Packer 3.38' 5.00" 8.43" 4,096 J,rr f: ; • • ~ g 3,498' SS Closed Gravel Pack Sliding Sleeve 190 47 -opens down 4.66' 5.87" 7.40" 4,157 r{. ;{:}! - h 3,544' Blast Jt. Pipe 5.5" 17 #/ft 236.' 4.892" 6.05" 4,180 n = i 3,786' GLM 5-1/2" 17#/ft L-80 TCII BXP, Special 4.8" ID -DUMMY VALVE 9.14' 4.80" 7.625" 4,189 I j 3,809' PKR .Lower Middle Iso Packer 96A4-60SCi-L Packer 3.38' 5.00" 8.42" 4,297 p q ;•;'~ ~ ~ • 6 k 3,818' SS Closed 190-47 Gravel Pack Sliding Sleeve -Ovens down 4.66' 5.87" 7.40" 4,375 ~'~ ~ ~ ~'~ i i. 3,835' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 98.' 4.892" 6.05" 4,475 ~:~:~.~ I 3,933' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 84.' 4.892" 6.11" 4,593 ~ ___~ 4,017 5.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 9.76' 4.892" 6.05" 4,624 ;;;, = m 4,027' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 150.' 4.892" 6.11" 4,728 ;•;r;: F 4,177' XO Sub 5.5" SLHT Box X 6.625" SLHT pin 0.71' 4.813" 7.41" 4,743 ~ r F ri 4,180' PKR Lower Iso Packer 96A4-60 SCS-L 3.38' 5.00" 8.42" 4,867 T n 4,189' SS Closed 190-47 Gravel Pack Sliding Sleeve -opens down 4.66' 5.87" 7.39" 4,916 a G 4,206' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 49.' 4.892" 6.50" 5,030 ~ G p 4,255' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 291.' 4.892" 6.11" 5,094 ~ G 4,546' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 9.78' 4.892" 6.50" 5,170 ~ q 4,555' SCRN 5.5" 17#Jft L-80 Excluder 2000 Med. SLHT BXP 187.' 4.892" 6.11" 5,246 (~ r 4,743' PKR Baker 1.94-60 "F" Permanent Packer 7.1.8' 6,00" 8.22" 5,398 w H 5,454 ° s H 5 5454' WLM PLUG TBG Nipple w/ 4.562" XN prof, 5.5" BTC-M BXP - PXN PLUG 11/2/05 1.46' 4.55" 6.10" 5,479 u 5,463' 190-60 Model 5-22 SLSA, Special ID, 5.5" SLHT Box 1.27' 4.875" 6.50" 5,353 1 t 5,465' PKR Baker SC-SR Retrievable Sump Pkr, Lower Tubing Tail 3.85' 6.00" 8.44" 5,660 5660 u 5,479' WLEG Wireline entry guide 7 5/8" STC Box 1.00' 6.625" 8.125" 5,771 1 1 5,653' FISH 6.5" junk mill & X-over 11/12/88 6.50" 5,800 5800' Pressure Datum: Sterling 3450' SS: 3,545'MD Beluga 4000' SS : 4,095'MD H PERFORATIONS, FILL & PLUGS Net 6,000 6000' Zone T~ Btm. Status Re-Perf Date SPF Ft. I WSO 3,322' 3,322' Perfd for squeeze & Tested 12/74 4 6,106 6106' v A 3,355' 3,482' Orig. 4 spf -dummied off in GLM 03/81 12 82' 6,145 6145' B 3,550' 3,683' RWO -Dummied Off in GLM 10/05 12 30' C 3,700' 3,776' RWO -Dummied Off in GLM 10/O5 12 76' 6,375 6375' WSO 3,525' 3,525' Perfd for squeeze & Tested 12/74 4 WSO 3,660' 3,662' Perfd for sqz, resgzd & Tested 12/74 4 II C 3,755' 3,760' DST #8, Squeezed 12/74 4 D 3,936' 3,940' RWO -Open 10/05 12 4' 6,755 I E 4,096' 4,379' RWO -Open 10/05 12 50' ~~~a. 678,5 ~ "~`: F 4,446' 4,774' Open 11/88 12 20' ~~ ' ~" .~~~ ~`_~' ~fi$ P s:f ` !/ r r d F 4 475' ~ 4 732' ~ RWO - O n Pe 10/05 12 51' FC `,~~;` ,,~` ~ " ` G 4,916' 5,086' Behind Blank Pipe 11/88 12 96' ~' ° H 5,398' 5,516' DST #6, Orig 4 SPF 11/88 12 130' ~ / PLUG 5,660' BP set at 5660' in 1981 completion H 5,681' 5,758' DST #5, Squeezed 12/74 4 I 5,820' 5,848' DST #4, set BP at 5800' 11/74 4 I 6,026' 6,076' DST #3, set BP at 6000' 11/74 4 I 6,117' 6,145' DST #2, set BP at 6145 & 6106' 11/74 4 I 6,422' 6,470' DST #lA, set BP at 6375' 11/74 4 FC 6,914' Cement PBTD to 6755' Nov 1974 i • PDS Multifinger Caliper 3 D Log Plot Company : ConocoPhillips Alaska, Inc Well : BRU 224-13 Field : Beluga River Unit Date : August 29, 2007 Description : Details of caliper recordings across the areas with heavy scale (4,160' ~ 4,550) .. • • 4280 4285 4290 _.. _ . __ _ - - 4295 4300 Jt.100 _ Gravel - Pack. 4305 _ --- Scale. - _.. _ 4310 _ __ _. 4315 4320 4325 _ _ 4330 Jt. 101 - Gravel 4335 _ -- - -- Pack. - Scale __ _ . 4340 _ . _ __ _ _ - 4345 4350 _. _ - _. 4355 _. _ __ 4360 _._ __ 4365 -... .. __ Jt.102 4370 _ Gravel - - - - - Pack . 4375 l S ca e. ---- --- 4380 4385 _ _. 4390 _.. _ _ _ _ _.. 4395 4400 __ _ _ _. 4405 Jt 103 _. _ __ ----- . 4410 Gravel ........ .. Pack. _.... _ - Scale. 4415 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 9 2010 REPORT OF SUNDRY WELL OPERATIONS ___ „_~,,~~., 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ er TCH Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: .Permit to Drill Number: ConOCOPhillips Alaska, Inc. Development ~ Exploratory ^ 173-037 / 3. Address: Stratigraphic ^ Service ^ API Number: P. O. Box 1.00360, Anchorage, Alaska 99510 50-283-20042 -GC9- D . Property Designation (Lease Number): Well Name and Number: ADL 58831 BRU 224-13 9. Field/Pool(s) ~ ~1'l a1 ~(q . (,~ ~ Beluga River Unit ~ G 10. Present Well Condition Summary: Total Depth measured 10000' feet Plugs (measured) 5454' feet true vertical 10000' feet Junk (measured) 5653' feet Effective Depth measured 5653' feet Packer (measured) 3109', Sass, 3aso', 3809', 4180', 4743' true vertical 5653' feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Structural 65' 30" 65' 65' Conductor 423' 20" 423' 423' Surface 3298' 13-3/8" 3298' 3298' Production 6999' 9-5/8" 6999' 6999' Perforation depth: Measured depth: 3355-5516' &~'e~~~~~~~: ~~~ ~i 2u'C true vertical depth: 3355'-5516' Tubing (size, grade, measured and true vertical depth) 5.5" , L-80 , 3110' Packers & SSSV (type, measured and true vertical depth) Baker, Weatherford pkrs @3109', 3465', 3490', 3809', 4180', x743' MD Camco nipple @ 417' MD / 417' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation r S f -- Subsequent to operation na 3.4 mmscfd 200 -- 350 13. Attachments 4. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^' Service ^ Daily Report of Well Operations _X \. Well Status after work: Oil ^ Gas ^~ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 16. 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: none contact Jim Ennis @ 265-1544 Printed Name i nis Title Wells Engineer Signature Phone: 265-1544 cc]] Date ~ f D Pr aced b aron Al u -Drake 263-4612 Form 10-404 ised 7/2009 ~~~^~./v ~~~ fGD 19 ~~ ~~~'~~"'" ~. Submit Original Only BRU 224-13 Well Events Summary • DATE SUMMARY 6/15/09 WORK STRING DETAIL: (1 11/1 1 1/2" RS, KJ, ABU Tool, 6' Stem, (1 11/16) OJ, Spangs- removed OJ for survey DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Ran 2.25" gauge ring to 4,461' WLM tag fill, ran spinner survey to 4,441' WLM 10/31/09 WORK STRING DETAIL: 1 1/2" RS, KJ, Abut, 1 13/16 x 8' Leaded Stem, 1 3/4" KJ, 1 3/4" OJ, 1 3/4" SSSJ, XO 1 1/2" x 1 3/4" DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Ran spinner survey & tagged fill 11/7/09 MIRU POLLARD B-LINE EQUIPMENT, MAKE UP LUBRICATOR ASSEMBLY, LOWER BOP EQUIPMENT LEAKED DURING INITIAL LUBRICATOR TEST, REMOVE FROM LUBRICATOR ASSEMBLY AND RETEST. RIH W/ 4.525" G-RING TO UPPER STRADDLE PACKER ASSEMBLY @ 3,098'MD NO RESTRICTIONS. POOH. RDFN. 11/8/09 MIRU POLLARD 1/4" B-LINE TO FISH WEATHERFORD PB STRADDLE PACKER ASSEMBLY. RF(`nyFRFD LIPPFR TRADDLE PACKER ASSEMBLY Cad 3 098'MD RECOVERED ALL BUT LOWER PB PACKER ON SUSPECTED LEAKING STRADDLE PACKER ASSEMBLY @ 3,359'MD. SPACER PIPE HAD TWO 2" DIAMETER FLOW CUT HOLES ON OPPOSITE SIDES OF PIPE, APPROXIMATELY 4' ABOVE SNAP LATCH STINGER, NOSE OF STINGER HAD SUFFICIENT FLOW CUT AREA AS WELL, APPEARS SNAP LATCH WAS NOT FULLY ENGAGED. SECURE WELLHEAD, RDFN. 11/9/09 MADE TWO ATTEMPTS TO FISH LOWER PACKER FROM MIDDLE STRADDLE PACKER ASSEMBLY na 3,359'MD. GOT TOTAL OF 40 PLUS 5,200# TO 8,000# OIL JAR LICKS, BEFORE 10,000# WEIGHT INDICATOR DIAPHRAM FAILED, POOH. JOB IN PROGRESS. 11/11/09 ATTEMPTED FISHING RUN USING 1/4" BRAIDED LINE UNIT, LATCHED UP TO FISH WITHOUT PROBLEM, HIT 19 OIL JAR LICKS 6k-7k, PULLED FREE ON 19th HIT, POOH, DISCOVERED CORE AND OUTER BODY OF GS SPEAR MISSING, LAY DOWN FOR THE NIGHT, RESUME IN THE AM. 11/12/09 PERFORMED 3" LIB RUN TO TOP OF FISH, MACHINE SHORT CATCH GRAPPLE AND SKIRT, RIH WITH GRAPPLE (1 7/16")UNABLE TO LATCH FISH, RIH WITH 1 5/16" GRAPPLE, LATCHED AND RECOVERED LOST GS. RDMO SLICKLINE. 11/16/09 Mobe Equipment from barge landing to well site 224-13. Rig up and performed BOP test. (in progress) 11/17/09 ATTEMPTED TO FISH STUCK PACKER AT 3385' CTMD, UNABLE TO JAR FREE AFTER 21 JAR LICKS, FINAL HIT @ 45K (35K OVER STRING WEIGHT) GS PULLED FREE (,, FROM BAIT SUD. MADE ATTEMPT TO RETREIVE ER PULLING TOOL WITH TAPPER TAP AND MOTOR AND PULLED FREE FROM BAIT SUB. MADE SECOND RUN WITH TAPPER TAP AND LOCATED PACKER + - 60' DOWN HOLE, PULLED TO SURFACE, RDMO COIL AND RELEASE FROM SERVICE. 11/18/09 MADE TWO ATTEMPTS TO RECOVER PACKER FROM WELL (UNSUCCESSFUL), MADE GAUGE RUN WITH 2.2 SWAGE TO 3989' SLM AND TAGGED FILL, MADE CALIPER RUN FROM 3439' SLM TO SURFACE USING PDS 40 ARM CALIPER (GOOD DATA). READY FOR E-LINE (IN PROGRESS) 11/19/09 Set Weatherford ER Patch in production tubing first patch set depth 3364.34' ELM (3368.6' - 3389.3' Elem. to Elem. ), Set second Weatherford ER Packer in production tubing at 3135' ELM. Return in the am. (IN PROGRESS) 11/20/09 Set remaining section of upper patch, using slickline and HES DPU setting tool. Top of ptach located at 3093.3 slm (3097.3' - 3135' Elem. to Elem.) .COMPLETE 11/25/09 Made attempt to rig up Pollard for S/L work, both mast trucks had mechanical issues, suspend work till A.M. 11/26/09 MIRU Pollard S/L unit with Peak mast truck. Made two dirft runs to 4,480'RKB, one with 1.75" DD baliler, nothing in bailer. One with 1.98" swage tag fill @ 4,480'RKB. RDMO 11/27/09 OFFLOAD BJ DYNA COIL EQUIPMENT FROM BARGE. TRAVEL TO BRU 224-13, SPOT AND READY EQUIPMENT FOR CAPILLARY STRING RUN IN MORNING. 11/28/09 MIRU BJ DYNA COIL EQUIPMENT. RUN 3/8" CAPILLARY STRING WITH 2" FLUTED CENTRALIZER ON BOTTOM TO 3,930'MD, SECURE STRING IN WELLHEAD. MAKE UP TUBING END TO SURFACTANT INJECTION SKID, FILL STRING. RDMO BJ DYNA COIL. RKB Scale 420 3,030 3,051 3,081 3,109 3,121 3,148 3, 322 3, 330 3,355 3,406 3,450 3,489 3,498 ~~ ConocoPhillips a Gravel Packed Gas Producer Sing/e Comp/etion b } ] [ { Sect. 13, T13N, RSOW, SW 1/4 ASP @ Beluga: 2,636,609; 325,576 CASING & TUBING Description OD Btm. d 1 [I c1 Surface Csg. 20" 423' e Intermediate 13 3/8" 3,298' 5 z Prod. Casing 9 5/8 2,151' e1 Prod. Casing 9 5/8 6,999' A Open Hole 10,000' e2 A Prod. Tubing 5 1/2" 3,110' A Screens/Blank 51/2" 5,479' BRU 224-13 API# 50-283-20042-00 Annulus Fluid: KCI w/ corrosion inhibitor 9.96 ppg to 3029' Max Hole Angle: 2.° @ 9,695' RKB to Ground: 25.' RKB to SL: 94.' 2005 RKB to Ground: 21.15' Ho% Weight Grade Thread Size 94. # H-40 Buttress 26" 61#/65# K-55 Buttress 17 1/2" 43.5 # P-110 Buttress 12 1/4" 47. # P-110/N-80 8rd LT&C 12 1/4" 8 1/2" 15.5# L-80 BTC mod 15.5# L-80 BTC Lbl. Top JEWELRY& FISH Length ID OD 3,550 h B a 417' Camco BP-6i ported nipple with methanol inj line 2.75' 4.562" 6.65" 3,660 s z b 3,030' SS Closed Baker CMU Sliding Sleeve w/ 4.562 BX profile -ocens uo 4.64' 4.562" 6.50" 3,684 B cl 3,093' 42' Weatherford packer straddle patch, 2.87"ID, from 3093' to 3137' 42.' 2.87" 4.50" 3,700 C c 3,109' PKR Baker SC-2 9662-60 w/ 7 3/4" 46.1# Hyd 523 Box do 5.24' 6.00" 8.45" 3,786 i C d 3,121' SS Closed 190-47 Gravel Pack Sliding Sleeve -opens down 4.66' 5.87" 7.40" 3,805 e 3,148' f~1odea C Iso Prot~~rtion Sleeve & C-2 KOIV, 6.625" SLHT BXP 2.93' 5.00" 8.15" Dy nac oil@3930' e1 3,364' 20' W <tlrrford u 4~s~r strad~!ie p~trh 1 `.:/"I[), From 3364'-3390' 26' 2.87" 4.50" e2 3,465' Weathertord'ER' pkr sitting on straddle below ~~ 3,809 j fl 3,471' S' Vtr , _~ ,. r rd L ke; shad ii pai-~_h z = i'Ip, From 3471-3526' S5.' 2.87" 4.50" 3,936 t' 7 [] '", y, D f 3,490' 1 :i< U„^.:,r P7idclle Iso P-ecl:er 96a.=1-CO S~GS-L Packer 3.38' 5.00" 8.43" 4,096 ihX }f xx~' E g 3,498' SS Closed ~iavel Pack Sliding sleeve 190 l -opens down 4.66' 5.87" 7.40" 4,157 ••• • . • . • E h 3,544' Blast ]t. Pipe 5.5" 17 #/ft 236.' 4.892" 6.05" 4,180 r E i 3,786' GLM 5-i/2" 17#/ft L-80 TCII BXP, Special 4.8" ID -DUMMY VALVE 9.14' 4.80" 7.625" 4,189 I I E j 3,809' PKR Lower Middle Iso Packer 96A4-605C1-L Packer 3.38' 5.00" 8.42" 4,297 ~ • ~ E k 3,818' SS Closed 190-47 Gravel Pack Sliding Sleeve -ocens down 4.66' 5.87" 7.40" 4,375 ' tiY °' E 3,835' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 98.' 4.892" 6.05" 4,475 `t• ~ ;:~ F I 3,933' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 84.' 4.892" 6.11" 4,593 ,., r. ; F 4,017 5.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 9.76' 4.892" 6.05" 4,624 •.; ;~ ' ~ F m 4,027 SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 150.' 4.892" 6.11" 4,728 ; ~ ~ ~ ~ ~ ?:~` F 4,177 XO Sub 5.5" SLHT Box X 6.625" SLHT pin 0.71' 4.813" 7.41" 4,743 .s r F n 4,180' PKR Lower Iso Packer 96A4-60 SCl-L 3.38' 5.00" 8.42" 4,867 ? 0 4,189' SS Closed 190-47 Gravel Pack Sliding Sleeve -ocens down 4.66' 5.87" 7.39" 4,916 v" G 4,206' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 49.' 4.892" 6.50" 5,030 ~ G p 4,255' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 291.' 4.892" 6.11" 5,094 ~ G 4,546' S.5" 17#/ft L-80 Braden Blank Pipe, 5.5" SLHT BXP 9.78' 4.892" 6.50" ' " " 5,170 ~ 4.892 6.11 q 4,555' SCRN 5.5" 17#/ft L-80 Excluder 2000 Med. SLHT BXP 187. 5,246 (e1 r 4,743' PKR Baker 194-60 "F" Permanent Packer 2.18' 6.00" 8.22" 5,398 ~ ncn w c .. H u 4,775' S.5" 15 Ib/ft L-80 tubing, BTC-M BXP 673.' 4.95" 6.10" 5,465 t ~ H 5,461' XO Sub 5.5" BTC Box X 5.5" SLHT pin 2.06' 4.892" 6.10" 5,479 a 5,463' 190-60 Model 5-22 SLSA, Special ID, 5.5" SLHT Box 1.27' 4,875" 6.50" 5,353 1 t 5,465' PKR Baker SC-SR Retrievable Sump Pkr, Lower Tubing Tail 3.85' 6.00" 8.44" 5,660 5660 a 5,479' WLEG Wireline entry guide 7 5/8" STC Box 1.00' 6.625" 8.125" 5,771 1 1 5,653' FISH 6.5"junk mill & X-over 11/12(88 6.50" 5,800 5800' Pressure Datum: Sterling 3450' SS: 3,545'MD Beluga 4000' S5 : 4,095'MD H PERFORATIONS, FILL & PLUGS Net 6,000 6000' Zone Top, Btm. Status Re-Perf Datr SPF Ft. I WSO 3,322' 3,322' Perfd for squeeze & Tested 12/74 4 6,106 6106' ® A 3,355' 3,482' Orig. 4 spf -dummied off in GLM 03/81 12 82' 6,145 6145' B 3,550' 3,683' RWO -Dummied Off in GLM 10/05 12 30' C 3,700' 3,776' RWO -Dummied Off in GLM 10/OS 12 76' 6,375 6375' WSO 3,525' 3,525' Perfd for squeeze & Tested 1z/74 4 W50 3,660' 3,662' Perfd for sqz, resgzd & Tested 1z/7a 4 I C 3,755' 3,760' DST #8, Squeezed 12/74 4 I D 3,936' 3,940' RWO -Open i0/05 12 4' 6,755 I ~75~`"`>'-_: E F 4,096' 4,446' 4,379' 4,774' RWO -Open Open 10/05 11/88 12 12 50' 20' FCL ~ q ~~ F G 4,475' 4,916' 4,732' 5,086' RWO -Open Behind Blank Pipe 10/05 11/88 12 12 51' 96' i i H 5,398' 5,516' DST #6, Orig 4 SPF 11/88 12 130' TD 10,000' ~ PLUG 5,660' BP set at 5660' in 1981 completion H 5,681' 5,758' DST #5, Squeezed 12/74 4 I 5,820' 5,848' DST #4, set BP at 5800' 11/74 4 1 6,026' 6,076' DST #3, set BP at 6000' 11/74 4 I 6,117' 6,145' DST #2, set BP at 6145 & 6106' 11/74 4 I 6,422' 6,470' DST #lA, set BP at 6375' 11/74 4 FC 6,914' Cement PBTD to 6755' Nov 1974 Spud Date 11/20/74 Last Completion 10/19/05 Schematic Rev. 12/7/09 by ]im Ennis 660sx "G". 2010sx "G". Rtns to surface 850sx @shoe, bump plug 500sx @ 3827 collar 2955x "G" ~ R~~D STATE OF ALASKA • ~~~ ~+ ~ ~~~~' ALASKA OIL AND GAS CONSERVATION COMMISSION ;' ~ ~~~ Cons. G~iruti~aAian REPORT OF SUNDRY WELL OPERAT~ Anrhnrane 1. Operations Performed: Abandon ^ Repair Well ~ ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhilhps Alaska, InC. Development ~ ' Exploratory ^ 73-037 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20042-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 104' BRU 224-13 8. Property Designation: 10. Field/Pool(s): -, / ~^ ~2~ R i ADL 58831 iver Un t Beluga ~!`~-3 11. Present Well Condition Summary: ~ t•27+0$ Total Depth measured 10000' - feet true vertical 10000' - feet Plugs (measured) Effective Depth measured 5653' feet Junk (measured) true vertical 5653' feet Casing Length Size MD TVD Burst Collapse Structural Structural 65' 30" 65' 65' Conductor 423' 20" 423' 423' Surtace 3298' 13-3/8" 3298' 3298' Production 6999' 9-5/8" 6999' 6999' - Perforation depth: Measured depth: 3355'-5516' true vertical depth: r( ~y C pp ~y r~CC,, ~l:~i'C t~ ~D ~ ~ 2a00 Tubing (size, grade, and measured depth) 5.5", L-80, 3110' MD. Packers &SSSV (type & measured depth) packers: 3107', 3143', 3526' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- -- Subsequent to operation SI -- -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ GasO WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none Contact is @ 265-1544 Printed Nam I .Title Wells Group Engineer s~ 2 ~ Signature Phone Date a d P ared b haron Ilsu Dr ke 263-4612 / ~ ~'~~17 Form 10-4 4 evised 04/2006 ~~), r~-x; ) ~~DB ,~ a/~ (,~ Submit Original Only B 4- RU 22 13 Well Events Summary DATE Summary 4/17/07 Rig up Pollard SL & EL Units. RIH with 4.525" OD gauge ring to 3900' no tight spots detected, indication of fluid level @ 1700'. Rig down SL unit and lubricator, P/U a-line Lubricator with CCL, Baker setting tool, 8~ Weatherford 4.50" ER packer. Started to RIH and noticed top connections of lubricator O-ring leaking. POOH lay down equipment and replace all O-rings. 4/18/07 Performing S.S /Tubing patch total of 7 runs needed. Successful on Runs numbers 1 to 4 today. Bottom ER~acker depth set @ 3526' RKB, tie-in depths of 3030' used with CCL on both E-line runs. Run #4 setting depth @ 3464' RKB vs total BHA in well less than .5 ft difference from initial program depths. Secure well, shut down. 4/19/07 completed patch runs 5, 6 & 7 today. Run #5 using E-line running CCL, 4.46" Baker firing head, 4.50' Weatherford ER packer. Tie in depths same as previous runs 3030' RKB, packer setting depth 3143' RKB. Run #6 using SL, stinging into receptacle @ 3141' WLMD. POOH. Run #7 using E-line running 4.46" stinger, spacer and 4.5" top ER packer. Tie-in 3030', tagged stinger on depth, putting top packer @ 3107' RKB. Set packer, POOH. Rig down and secure well. 4/20!07 Attempt to bring well on 5/11/07 Ran 2" Bailer to 3467' wlm. Return w/ 1/3 bailer full sand. Ran 4.50" centralizer to 3090' wlm tag top patch. No sign of fluid level. Shot level w/ TWM system at 3132' wlm. Broke through bridge to 3802'. Bail down to 3810' wlm 5/13/07 Bailed sand from 3839' wlm to 3893' wlm (several bridges) 5/14/07 Work Being Done: Bail sand 5/15/07 Work Being Done: Bail sand. Bailed from 3857' wlm to 3891' wlm. Work suspended (CTU pending) 6/13/07 Receive all Service equipment from barge @ 03:30hrs. Continue with CCT rig up on location, fluid pack and test CCT string & Sand-vac BHA. Continue rigging up BOP and getting ready to Pressure test. 6/14/07 Complete rig up, function test Sand-vac tool. Pressure test BOP's 400 & 4000 psi -fill coil and p/t to 6100 psi -test in sand vac and well vac mode. RIH to 3700' CTMD tagged sand bridge, getting 1:1 returns, heavy sand concentration (3 - 6 cups per 5 gallon sample). Continue on with program taking 50' bites @ 1-2 ft/min, and 50' wiper trips. Switched to 60' bites & 30' wipers once sand returns lightened @ 3970', (1-2 cups/5 gallons). Total fluid blended so far 490 bbl/6% KCL. 6/15/07 Continue with sand vac cleanout at 1-2 ft/min with 60' bites and 30' wiper trips, better than one for one returns with sand and mud. Recirculating fluids at surface, total est. sand in ,sparge tank 6 yards. WHP - 860 psi, Circ press - 4800psi @ . 5bbbl/min, Disposed of 120 bbl returns, and pre-mixed 100 bbls of 6% KCI in past 24 hours. Total 590 bbls to date. Current depth 5400' CTMD. 6/16/07 FCO to Plug _ 5458' CTMD, sat on bottom for 30 min, getting 1-2 cups of sand/5 gallon sample. Long wiper trip to 3700', getting light to zero sand trace while slowly POOH. RIH to 4450' stop pumping to switch tool to well-vac, good indication getting 2:1 returns. Well- . vac and flow well for water returns. POOH, rig down injector and flow well @ surface. Current well & choke settings as follows:l~VHP 400 psi, choke setting 32%, downstream 120 psi, getting roughly 10 bbls/hour of water with 60°lo gas. Continue to flow well for 12-24 hours. 6/17/07 Slickline tag at 4130' slm -Rig up BJ Concentric Coiled Tbg for cleanout # 2. Cleaned tanks from first CCT run, est. volume of sand 50 bbls. Re-mix fresh KCI fluid total 500 bbls - start FCO. RIH tagged sand bridge @ 3893' CTMD, heavier sand returns starting @ 3950'. Current press. WHP - 860 psi, Circ. press - 4750 psi @ .49 bbl/min, getting 1:1 returns, 11 sec/5 gallon sample, 2-3 cups of sand. BRU 224-13 Well Events Summary 6/18/07 Sand vac sand from 3700' - to top of plug at 5458' CTM -three total passes to bottom - Lost injection pressure within the coil @ 5285' before switching to well vac mode -POOH - the 1" coil inside the 2" had sheared rom the coil connector within the sand vac tool. RIH with SL and tag @ 5450' WLMD. Rig down CCT equipment, keep fluid & LN2 pump on stand-by for camera run. 6/19/07 Continued rig down and move to barge landing -begin cleaning tanks -pumped 63 bbls 6% KCI followed by 35,000 scf of N2 -pressure stabilized at 1200 psi while pumping - rigged up Pollard Eline with APRS personnel and tested down scan and side scan Expro camera -wait until morning to let well stabilize. 6/20/07 Ran Expro downscan and sidescan camera while pumping nitrogen, flowing the well or in static condition -good pictures throughout the well but unable to determine the exact cause of the sand influx 6/21/07 Stand by 8/29/07 Prepare & stage equipment. 8/30/07 RU Pollard slickline. RIH w/ 2" bailer. Tag @ 5455' KB & bail for sample. Collect sand sample & send to John Braden. RIH w/ PDS caliper and run 5445'-3000' KB. Caliper L indicates hole at 3378'. RIH w/ LDL tools to 3000' KB. RU BJ N2 pumper & begin pumper & begin pumping N2 at 1500 scfm @ 900 psi 8~ 97 deg. F. Log LDL passes 3000'-3600' RB up/down @ 80 & 120 fpm. Logged stops @ 3000', 3250', & 3600'. SDFN. 8/31/07 RIH w/ Weathertord test tool on slickline. Sting into top straddle packer C~ 3106' KB. PT tbg & pkr 2000 psi wl N2, OK. Bled tbg to 1000 psi. Sheared off test tool 8~ POOH. Fished test tool on second attempt w/ centralizer. RDMO. 10/8/07 MIRU Pollard braided line. Retrieve top straddle packer assembly. Pull top packer & tag bottom packer w/ 4.530" GR Roundtrip 4.53" gauge ring to 3475' KB. RD braided line. 10/9/07 Load up braided unit for transport to barge landing. Spot eline unit. Fly crew back to Kenai. 10/10/07 RIG UP POLLARD E-LINE UNIT. RIH W/ CCL, BAKER 20 SETTING TOOL AND WEATHERFORD 4.5" ER PACKER, SET MID-ELEMENT @ 3384'MD, POOH. SECURE WELLHEAD, RDFN. 10/11!07 MADE TWO ATTEMPTS TO SET 4.5" WEATHERFORD STRADDLE PACKER ,ASSEMBLY WERE UNSUCCESSFUL. UNABLE TO GET 800# OVER PULL ON SNAP LATCH, E-LINE HEAD PREMATURELY RELEASED, LEAVING E-LINE RS/CCUSETTING TOOL AND PACKER ASSEMBLY IN WELL. SECOND ATTEMPT TO FISH PACKER ASSEMBLY, ASSEMBLY SLIPPED OFF WHILE COMING OUT OF HOLE @ 2500' MD, ATTEMPT TO RELATCH ASSEMBLY UPPER PACKER ASSEMBLY FELL DOWN HOLE AND DISLODGED LOWER PACKER @ 3384' MD, POOH. SECURED WELLHEAD, RDFN. 10/12/07 MADE TWO ATTEMPTS TO FISH LOST PACKER ASSEMBLY BEFORE PARTING _125 WIRE. SPENT REST OF DAY FISHING LOST WIRELINE TOOLSTRING. RECOVERED LOST TOOLSTRING TO 2" JD PULLING TOOL. BAIT SUB/ BELL GUIDE WITH OVERSHOT LATCHED TO LOST PACKER ASSEMBLY LEFT IN HOLE, (2" SECTION OF JDC SKIRT LEFT IN WELL). 10/13/07 jVIOVED OVERSHOT ASSEMBLY UP HOLE FROM 3450' TO 3170' WLM. RECOVERED ONE 4' PIECE OF .125" WIRE FROM WELL BORE, SPENT REST OF DAY ATTEMPTING TO FISH OVERSHOT PIECES ABOVE FISH, 1N PROGRESS. BRU 224-13 Well Events Summary 10/14/07 MADE SEVERAL ATTEMPTS TO FISH OVERSHOT DEBRIS FROM ABOVE PACKER ASSEMBLY @ 3450' WLM WERE UNSUCCESSFUL. LATCHED AND MOVED FISH UP/DOWN HOLE FROM 3450' TO 3380' WLM, UNABLE TO WORK THROUGH TIGHT .SPOT AT 3380' WLM, FISH FELL BACK DOWN HOLE TO 3450' WLM. 10/15/07 Attempt to fish E-line tool string without success, able to latch fish and move up and down hole from 3450' wlm to 3409' wlm. Latched onto fish again with 3" RS with an attached 4.52" BG. Left BG assembly in hole, attemted to fish out without success. 10/16/07 Fished out 4.5" BG assembly from top of E-line TS. Attempt to pull E-line TS but not able to stay latched. (((Left a tooth from wire grab in hole))). 10/17/07 Attempt to fish E-line TS with Braided line unit,parted overshot leaving grapple around E- line rope socket. 10/18/07 Attempt to fish rapple from E-line rope socket, with no success. LDFN wait for CPAI supervisor to arrive in the morning. 10/19/07 Attempt to latch E-line TS w/ Bowen overshot, unable to latch fish due to debris down hole. Marks on overshot bottom indicate that grapple left from prior attempt may still be intact. Will have whicker overshot machined in the morning to attempt to retrieve grapple. 10/20!07 Standby for whicker overshot to arrive, once @ location, RIH w/ 3.25" internal taper whicker overshot to attempt retrieval of lost grapple(s). Marks on bottom of new overshot indicate that grapple may no longer be completely intact. A jagged "zipper" impression was left on overshot bell, with no marks inside at all. LDFN. 10/21/07 Verify E-line CCL can be overshot, beat lost grapples down further on rope socket, latch rope socket with 3.75" Bowen over shot w/ 2.0625" x 1.43" grapple. Pulled on fish with max pull by PW SL unit. Fish did not move, LDFN will resume in the morning with BL unit. 10/22/07 Attempt to fish E-line TS w/ PW BL unit. Retrieved 10.5" of E-line rope socket. RS broke at connection point just above CCL. Had 3.125" Bowen spiral grapple sent from Kenai, will resume in the morning to attempt to bait fish. 10/23/07 Attempt to bait E-ine CCL with 3.75" Baker over shot w/ 3.125" spiral grapple, unable to Jatch fish. Once at surface noticed metal indentation on overshot bottom indicating fish size larger than overshot. Information given by contractor on CCL size was inaccurate, CCL is actually 3.25" OD. No vendors have overshot for this sized tool in Alaska, released PWS. 10/28!07 RIH and bait E-line TS @ CCL w/ 4.38" over-shot and 3.25" Bowen spiral grapple. Attempt to fish TS, working OJ's up to 6600# for one lick before fading. LDFN (((Job in progress))). 10/29/07 STAND BY FOR FISHING JARS FROM KENAI 10/30/07 STAND BY FOR MOST OF DAY WAITING ON CPAI REP ARRIVAL AND 2.125" BOWEN OIL JARS. MADE RUN TO FISH PACKER ASSEMBLY @ 3410' BLM. OG T 32 OIL JAR LICKS UP TO 6800# ON FISH WITH NO MOVEMENT OBSERVED. POOH TO CHECK TOOLSTRING AND GS. RDFN. JOB IN PROGRESS. 10/31/07 MADE FOUR RUNS TO FISH PACKER ASSEMBLY FROM WELLBORE @ 3410'BLM WERE UNSUCCESSFUL, TOTAL OF 120 JAR LICKS USING BOTH DAILY AND BOWEN JARS. PULL WEIGHTS VARIED BETWEEN 6000#- 7500#. NO MOVEMENT WAS OBSERVED, JOB IN PROGRESS. 11/1/07 MADE TWO RUNS TO FISH PACKER ASSEMBLY FROM WELLBORE @ 3410' BLM. GOT ADDITIONAL 60 PLUS JAR LICKS AT BETWEEN 6000#-7000#, WITH NO _MOVEMENT OBSERVED LOST A HALF DAY OF FISHING DUE TO PEAK CRANE MALFUNCTION. JOB IN PROGRESS. BRU 224-13 Well Events Summary 11/2/07 RECOVERED LOST E-LINE CCL/ BAKER 20 SETTING TOOL FROM ABOVE LOST WEATHERFORD ER PACKER ASSEMBLY @ 3410' BLM, RDFN. JOB IN PROGRESS. 11/3/07 RECOVERED LOST UPPER AND LOWER WEATHERFORD ER PACKER _ASSEMBLIES FROM ABOVE LOWEST MOST PACKER ASSEMBLY @ 3475' RKB. DRIFT THROUGH LOWER PACKER ASSEMBLY @ 3475'RKB TO VERIFY NO RESTRICTIONS, TAG DEBRIS FROM LOST OVERSHOT GRAPPLES @ 4423' BLM. RIG DOWN POLLARD. SECURE WEL H AD. 11/13/07 Waited on weather delays for flights. Got SLB equipment & Peak crane warmed up & started. Built SLB lubricator. SDFN. 11/14/07 Finished rig up SLB lubricator on wellhead. PU 'ER' pkr & Baker 20 setting tool. PT lubricator w/ 500 psi tbg pressure, OK. RIH w/ pkr & tag top of btm straddle @ 3475' MD. Pulled CCL strip to 3000' to corrolate collars on caliper log. Set'ER' pkr mid-element @ 3384' MD & tagged to verify. POOH & rebuilt setting tool. RIH w/snap latch seal assy, 15' 3.5" tbg sub & "ER' pkr. Tag first pkr hard & latch in. Overpuil 600# to verify latch., Slack off to neutral weight & set'ER' pkr mid-element C~ 3363' MD. POOH 8~ rebuilt setting tool. RIH w/'ER' pkr & set mid-element @ 3135' MD which is mid joint on 9.5' pup on tally. POOH. RDFN. 11/15/07 Let crew sleep waiting on Pollard flight. RU Pollard slickline. RIH wl snap latch, 14' 3.5" tbg sub & tieback receptacle on 5" GS. Stab into 'ER' pkr @ 3130 & tap down. Overpull 500# to verify latched. Shear GS down 8~ POOH. RD Pollard. RU SLB eline. RIH w/tieback stinger, 14' 3.5" tbg sub & 'ER' pkr. Tag hard into tieback. Overpull 500# to verify latch. Slack off to neutral & set'ER' pkr mid-element @ 3098' MD mid joint on 6' tbg pup on tally. POOH. RD SLB. 11/16/07 Tbg 900 psi. RIH w/ 2.5" bailer w/ 2.78" shoe. Tag @ 4471' SLM. POOH, bailer empty. RIH same, tag @ 4472' SLM. POOH, bailer empty. Scrape marks on 2.78" shoe & several 1"flakes of metallic soda can thin substance stuck to side of bailer. Kept sample of flakes for analysis. RIH w/slick 2.5" bailer. Tag @ 4480' SLM & work down to 4490' SLM, not sticky. POOH, bailer empty. RIH w/ 2" LIB & tag @ 4490' SLM. RDMO. 11/27/07 Drift run/flowing survey 11/28/07 Survey Flowing · . Cor1ocÓPhillips TRANSMITTAL Production Oats FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Librarian/Data Control AOGCC 333W. ih Avenue Anchorage, Alaska 99501 RE: BRU 224-13 DATE: 12/08/05 Hand delivered Transmitted: 173- 031 Beluga River Unit BRU 224-13 Hardcopy Color loa print _ Ultrasonic Imaging Tool, 09/28/2005, run 1 3200-5645 md _ Reservoir Saturation Tool, Sigma 09/29/2005, run 1 3200-5640' md ~ÇANNE[ DE C 2, 2, 2005 Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records. .' To all data recipients: All data is confidential until State of Alaska designated AOGCC release date. Proprietary data may be indefinitelv confidential. Date: 12/JJf15 ConocoPhillips Alaska, Inc. A TIN: S. Lemke, A TO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management 1 ConocoPhillips 1 Anchorage/ Alaska 1 Ph: 907.265.69471 Sandra. D. Lem,ke{âJconocoohillios. com l ... P. Mazzolini Exploration Drilling Team Leader Drilling & Wells ConocóP'hiiii pS P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 November 18, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 2 2 2005 Alaska Oil & Gas Cons. CommiJ.iQn Anchorage Subject: Well Completion Report for BRU 224-13~ø.'~r305-214)'~i! Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Beluga River well BRU 224-13. If you have any questions regarding this matter, please contact me at 263-4603 or Mark Chambers at 265-1319. Sincerely, ?~fY/~ P. Mazzolini Exploration Drilling Team Leader CPAI Drilling and Wells SCANNED DEe [; 82005 PM/skad ~ · , K 1= \..,,1:: I v t:: u NOV 2 2 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Corrmission REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Anchorage o Time Extension 0 Re-enter Suspended Well 0 Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104' 8. Property Designation: ADL 58831 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural Structural Conductor Surface Intermediate Production Perforation depth: Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: ..,·,,~,1'~.14' 6. AÞI Number: 50-283-20042-00 Other 9. Well Name and Number: BRU 224-13 10. Field/Pool(s): Beluga River Unit measured 10000' feet true vertical 10000' feet measured 5653' feet true vertical 5653' feet Length Size MD 30" 65' 20" 423' 13-3/8" 3298' 9-5/8" 6999' Plugs (measured) Junk (measured) TVD Burst Collapse 65' 423' 3298' 6999' Measured depth: old perfs from 3355'-5516'; new perfs from 3550'-4732' (refer to attached schematic) true vertical depth: Tubing (size, grade, and measured depth) 5.5", L-80, 3110' MD. Packers & SSSV (type & measured depth) Baker SC-2 pkr, 3 SC1-l isolation pkrs, "F" sump pkr, SC1 R pkr 3110', 3494', 3814',4185',4747', 5469' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft NOV 22 Z005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation 3.5 MMscfd Subsequent to operation 7.5 MMscfd 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD Gas0 WAG 0 GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mark Chambers @ 265-1319 Paul Mazzolini '~yr¡~ CI Team Leader Title Phone Date Preoared bv Sharon AI/suo-Drake 263-4612 Form 10-404 Revised 04/2004 nR1GINAI Submit Original Only BRU 224-13 Actual Completion Schematic Con(lpctor: 30" Driven to 65' MD II J $l,Irf~ce C¡lsil1~; 20", 94.00#, H-40 BTC @ 423' MD Il'It(!rmediate C¡l~ing: 13-3/8",61.00#, K-55 BTC 13-3/8",68.00#, K-55 BTC @ 3298' MD E){isti"~ PerfQr¡¡tions: New Perforatio!,\s: 3355' - 3361' 3376' - 3396' 3422' - 3431' 3435' 3482' 3550' - 3570' 3673' - 3683' 3700' - 3776' 3936' - 3940' 4096' - 4102' 4138' - 4148' 4157' - 4170' 4446' - 4456' 4476' - 4490' 4593' - 4603' 4676' - 4694' 4260' - 4265' 4297' - 4303' 4348' - 4354' 4375' - 4379' 4475' - 4490' 4593' 4603' 4624' - 4628' 4676' - 4694' 4728' - 4732' 4764' - 4774' 4916' - 4924' 4936' - 4958' 4966' - 4986' 5022' - 5032' 5050' - 5086' 5398' - 5448' 5494' 5516' fis~: TOf @ 5654' MD 6- Vz" OD Junk Mill and XO Sub @ 5654' MD ßridge ftlug: Set @ 5660' During 1981 Completion ProC ,\Jction C¡lsing: 9-5/8",43,50#,1'110, BTC @ 2151' MD 9-5/8",47.00#, P110/N-80, 8rd LT&C @ 6999' MD (MZ Frat: System) IL 1 I i'II!IIIIIÞ I Tubing Hanger: Vetco Gray Hanger wI 5-1/2", 15.5#, L-80, BTC-Mod Pup Joint installed. Spaceout Tubing Pups (as required): 5-1/2", 15.5#, L-80, BTC-Mod Ported Nipple: 5-1/2" Camco 'B-61' Ported Nipple wI DB No-Go Profile and 4.562" Minimum 10. Methanol Injection Line to Surface wI Dual Check Valve Installed @ Nipple. Nipple Set @ +1- 400' MD-RKB. 6' Handling p¡¡PS Installed on Top and Bottom. Tubing (as required): 5-1/2",15.50#, L-80, BTC-Mod Sliding Sleeve: Baker 5-1/2" CMU wI 4.562" X Selective Profile. 6' Hiìndling Pups Installed on Top and Bottom. Tubing (bJoint): 5-1/2", 15.50#, L-80, BTC-Mod Tubing (6' Pup Joint): 5-1/2", 15.50#, L-80, BTC-Mod PBR Seal Assembly: Baker '190-60' pBR Seal Assembly, 15' Length, OD x 4.88" 10) Anchor assembly: Baker Model 'S-22' Anchor Tubing Seal Assembly (7.00" OD x 4.88" 10) Piiicker: Baker SC-2 Packer (96B2-60 I 47# Casing I 8.313" OD x 6.00" 10) and Gp Assembly (as per BOT Completion Schematic) Assembly Includes Mod 'C-2' KOIV wI Protection Sleeve. Packer @ MD-RKB Blank Pipe (as required): 5-1/2",17.00#, L-80, SLHT Piiic!cer: Baker SC1-L Packer (8.125" OD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Top of Packer @ +j- 3494' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT WlJ!I1 Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT BlastJoints: 5-1/2",17.00#, L-80, SLHT (150' Length x 6-1/4" OD) GLM: Schlumberger 5-V2" 'MMG' w/ TCn Conn. 6' Handling Pups Installed on Top and Bottom. Packer: Baker SC1-L Packer (8.125" OD x 6.00" ID) and GP Assembly (as per BOT Completion Schematic) Top Packer @ +/- 3814' MD-RK6 WI,/IIf Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2",17.00#, l-80, SLHT Gravel Pack Screen (as required): 5-V2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" OD x 6.00" ID) and Gp Assembly per BOT Completion Schematic) of Packer (âJ +j- 4185' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SlHT Gravel Pack Screen (as required): 5-V2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker 'F' Permanent Sump Packer (8.220" OD x 6.00" ID) and Lower Isolation Assembly (as per BOT Completion Schematic) Packer @ MD-RKB Packer: Baker 'SC-1R' Retrievable Packer (8.440" OD x 6,00" ID) and Lower Tubing Tail (as BOT Completion Schematic) Packer (âJ +1- MD-RKB BRU 224-13 Schematic v2,0 prepared by Mark Chambers 10/19/05 224-13 MZ Fraq 2 Zone Space Out Sheet Rev 8 10-9-05 .xls Upper Upper Middle Lower Middle Lower Top Gross Bottom Top Gross Bottom Top Gross Bottom Top Gross Bottom 3322.00 160.00 3482.00 3525.00 251.00 3776.00 3936.0 234.00 4170.0 4260.00 472.00 4732.00 Equip Length Depth Equip Length Depth Equip Length Depth Equip Length Depth SC-2 5.24 3106.24 LHSB 2.54 3487.43 LHSB 2.54 3807.27 LHSB 2.54 4178.11 MaE 4.08 3111.48 SC-l L 3.38 3489.97 SC-IL 3.38 3809.81 SC-l L 3.38 4180.65 5.5 SB 3.59 3115.56 Inv SB 3.06 3493.35 Inv SB 3.06 3813.19 Inv SB 3.06 4184.03 VExt 2.61 3119.15 VExt 2.61 3496.41 V Ext 2.61 38]6.25 VExt 2.6] 4187.09 GPSS 4.66 3121.76 GPSS 4.66 3499.02 GPSS 4.66 3818.86 GPSS 4.66 4189.70 GPSB 2.82 3126.42 GPSB 2.82 3503.68 GPSB 2.82 3823.52 GPSB 2.82 4] 94.36 LExt 5.29 3 ]29.24 LExt 5.29 3506.50 LExt 5.29 3826.34 LExt 5.29 4197.18 4"SLHT SB 3.00 3134.53 4"SLHT SB 3.00 35]1.79 4"SLHT SE 3.00 3831.63 4"SLHT SB 3.00 4202.47 Blank 349.90 3137.53 Blank 292.48 3514.79 Blank 99.03 3834.63 Blank 49.66 4205.47 Screen 0.00 3487.43 Screen 0.00 3807.27 Screen 244.45 3933.66 Screen 488.00 4255.13 Total 381.19 Total 3]9.84 Total 370.84 S-22 0.87 4743.13 F-l 2.18 4744.00 Longest GP Port to Top LH 370.84 Total 565.89 Shortest GP Port to Top LH I 319.84 Equip Length Depth Top Blank 3137.53 Stick Down 0.75 3138.28 Top WP 3138.28 Bottom WP 349.42 3487.70 Seal #1 Top 3487.70 Seal # 1 Bottom 25.89 3513.59 Top WP 3513.59 Bot WP 3513.59 Seal #2Top 3513.59 Seal #2 Btm 3513.59 TPWp 3513.59 Bot Wp 664.92 4178.51 RIP to Circulate Circulate to Reverse - Min Circulate to Reverse - Opt. Circ. to Active Hyd Lac Max Reverse Min Circ. Close KOIV from RIP Close KOIV from Last Ind Last Ind to Iso seal top Last Ind to Iso seal btm ] ]/] 8/2005 4.0 4.1 5.0 Snap thru 7.00' Ind @ 6" dn 1609.93 536.64 337.53 364.93 Equip Length Depth MZ X Tool Top 37.43 4]78.5] GP Port Middle 18.45 4196.96 Shift Tool Top 4.75 4201.7] R Port Middle 2.61 4204.32 Hyd Locator 3.28 4207.60 Indcat Tool 3.22 4210.82 Shift Tool 3.29 42]4.11 End XO Tool 1.83 4215.94 WP Top 4215.94 WP Bottom 332.41 4548.35 Port Sub 0.97 4549.32 Top of Seal #3 4549.32 Btm of Seal #3 26.43 4575.75 WP Top 4575.75 WP Bot 168.36 4744.11 Port Sub 4744.11 Top of Seal #4 4744.11 Btm of Seal #4 4744.11 Bottom of MS 3.35 4747.46 ] of2 Page 1 of 26 ConocoPhillips Alaska Operations Summary Report Continue assembling rig components. Positioned and pinned derrick. Unloaded one barge 08:00 containing 3 ea 500 bbl tanks, remaining 4 1/2" drillpipe, 4 1/2" HWDP, 6 1/8" Drill Collars, Pollard grease skid, APRS unit, air compressor, various cleanout equipment, light plant & 2 ea heaters. Second barge sailing cancelled due to weather. This barge is loaded out with mud products, fuel truck, remaining 500 bbl tank and various extras! 24.00 MOVE RURD RIGUP Continue assembling rig components. Raised derrick. Set Swaco injection unit and holding tank. Bermed same. Unloaded one barge 08:00 containing fuel truck, KCI, Sodium Hydroxide, various other mud products, miscellaneous rig supplies and 1 ea 500 bbl tanks I Unloaded second barge at 21 :10 containing KCI and frac sand. 24.00 MOVE RURD RIGUP Continue assembling rig. Raised rig floor into position. Finish rigging up Swaco injection unit - waiting for XlO to tie into tree. Moved material from landing to staging area. Raised telecomm tower. Hooked up and began pumping / filling first water storage tank. Pumped for 2 1/2 hours and filled tank with approx. 200 bbl. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Llc Kuukpik 5 Date Sub Code Code Phase From - To Hours . on. ... . . 8/17/2005 00:00 - 00:00 24.00 MOVE MOB MOVE 8/18/2005 00:00 - 00:00 24.00 MOVE MOB MOVE 8/19/2005 00:00 - 00:00 24.00 MOVE MOB MOVE 8/20/2005 00:00 - 00:00 24.00 MOVE MOB MOVE I 8/21/2005 00:00 - 00:00 24.00 MOVE MOB MOVE I 8/22/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/23/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/24/2005 100:00 - 00:00 8/25/2005 00:00 - 00:00 8/26/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Description of Operations . - . .. .. .,.,,'.. .".. .. .... . . . 2 Kuukpik and 2 Weaver Brothers hands arrive at Beluga. 1st barge arrived at 18:00 hrs. Off load 2 bed trucks w/ office and sleeper modules, 988 loader, 3 pick ups, crew van and 2 floats with rig parts. Stage trailers and modules at location. Off load 04:00 barge. 6 trailers with rig equipment. Off load equipment at location. Stack empty trailers. Off load barge at 18:00 hrs. Sub base on lowboy, 5 trailers with rig equipment and a 128 loader. Back load empty trailers. Stage equipment to location. Off load 05:00 barge. 7 trailers with rig equipment.Back load empty trailers. Off load equipment at location. Stack empty trailers. Off load barge at 18:30 hrs . 6 trailers of rig equipment. Back load empty trailers. Stage equipment to location. Off load 06:30 barge. 6 trailers with rig and service equipment.Back load empty trailers. Off load equipment at location. Stack empty trailers. Off load barge at 18:20 hrs . 4 trailers of rig and service equipment and derrick. Back load empty trailers. Stage equipment to location. Repair broken air line on derrick trailer before attempting to go down 3 mile hill. Stage derrick at airstrip staging area. Prep work barge at 06:30. Barge unable to land on this tide due to 40 knt winds. Layout pad. Lay herculite and matting boards for sub. Spot sub base over well and connect white iron. Offload barge #8 at 18:40 hrs. Vac truck, Peak low boy, 3 pick ups, 2 tiger tanks and 2 trailers w/ MI Swaco equipment including injection skid. Unloaded first barge 10:30 containing baker fishing tools, landing joint, wash pipe, KCI, 3 ea brine return tanks plus various spare parts. Unloaded second barge at 21: 1 0 containing KCI, miscellaneous equipment, pipehandling equipment from GBR, Frac sand, Vetco wellhead equipment, dumpsters & waste containers and first load of 5 1/2" tubing. Completed assembly of rig components. Laid out pipe rack. Begin hooking up rig internally. Printed: 1119/2005 11 :42:55 AM Page 2 of 26 ConocoPhillips Alaska Operations Summary Report Legal Well Name: BRU 224-13 Common Well Name: BRU 224-13 Event Name: WORKOVER/RECOMP Contractor Name: Kuukpik Drilling Llc Rig Name: Kuukpik 5 __._~?rt~...__l From - To e 'lc~:e Phase 8/26/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/27/2005 00:00 - 00:00 24.00 MOVE I RURD RIGUP 8/28/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/29/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/30/2005 00:00 - 00:00 24.00 MOVE RURD RIGUP 8/31/2005 100:00 - 00:00 24.00 MOVE RURD RIGUP 9/1/2005 00:00 - 03:00 3.00 MOVE RURD RIGUP 03:00 - 06:00 3.00 MOVE RURD RIGUP I 06:00 - 08:00 2.00 MOVE RURD RIGUP 08:00 - 10:00 2.00 MOVE RURD RIGUP 10:00 - 12:00 2.00 MOVE RURD RIGUP 12:00 - 18:00 6.00 MOVE RURD RIGUP 18:00 - 21 :00 3.00 WELCT KILL WRKOVR 21 :00 - 00:00 3.00 WELCT KILL WRKOVR 8/17/2005 Spud Date: 9/27/1974 End: 10/23/2005 Group: Sta rt: Rig Release: Rig Number: 5 .. :.·'1f'MrJès:cription of';~pen:l~ions . .·L/L:\' ~ _,__.w~ ....,...".:. . :./ Laid out brine unit & tank farm herculite. Spotted brine filtration equipment and began spotting tanks. Completed filling 500 bbl water storage tank on 214-26. Hooked up second water well (located on BRWD pad) and filled 500 bbl water storage tank. No barges today due to lack of water at high tide. Continue to move equipment from the landing to the staging area and pad. Hooking up rig components. Telescoped derrick up to final height. Filled rig pits with fresh water from storage tanks. Spotted all brine and freshwater tanks at tank farm. Completed berm of tank farm and brine mixing & filtration unit. Manifolded brine & fresh water tanks, began manifolding of MI-Swaco filtration equipment. No barges today due to lack of water at high tide. Continue to move equipment from the landing to the staging area and pad. Moving empty trailers to landing for back loading. Continue rigging up floor, pits, flowlines, Building flowlines to tank farm. Finished hooking up tank farm and brine units. Filled fresh water tanks. Prepared miscellaneous equipment for back load, unload trailers & haul empties to dock. Cleaning location & relocate offices. Telecom rigging up communications, hooking up hoses in tank farm,unloading trailers, haul empty trailers to dock,reberm tank for centrifuge discharge,rigging up mud lines on rig to tank farm. Hold spud meeting wI town personel & do walk thru @ rig. (No Barges Today). Test mud line to 4500 psi. Found bad "0" ring, repair water and steam lines, work on mud pump #2, Re-test mud line-found bad fitting and replaced same, re-test to 4500 psi- OK, Steam clean pits, Shel test on choke manifold to 4500 psi-OK, RU valves on SWACO tank,RU out side discharge lines from centrifuge to outside tank, MU valves on mud cross, wash fluid through mud pumps and centrifugals, set herculite for cuttings boxes. Accept Rig 12:00 hrs 8/30/05 Set tanks under shakers, install vent line in boiler house, change link tilt hoses, tighten flanges and hatch covers on tank farm tanks, flush pits and pumps, MU XO on top of tree, dress shakers & install PVT sensors in outside return tanks, centrifuge wash fluid and haul to injection tank. Suck bottoms out of pits and centriguge Install 2nd annulus valve. Install 2" high pressure circ flange on heater string. RU manifold to kill well through choke and poorboy degaser. Dress trees wI needle valves and gages Wire up 2 PVTs from dirty brine tanks to Payson system. Wire up SWACO transfer pump to pits NU pump in sub to heater string and high pressure hose to annulus Transfer fluids into pits from tank farm Hold PJSM. Open tree valves. Initial pressures =heater string -0- psi, short string920 psi, long string 1445 psi and annulus 570 psi.KiII heater string at 20 SPM 1.5 bpm. initial circ pressure @ 20 spm= Long string 1445 psi,short string 920psi, heater string 28 psi and annulus 608 psi. @ 50 bbls pumped away Long string = 1445 psi, Short string 920 psi, Heater string 1 00 psi, and annulus 623. Shut down pumps and monitor fluids. Final pressures Long string1445 psi, short string 920 psi, Heater Printed: 1119/2005 11 :42:55 AM Page 3 of 26 ConocoPhillips Alaska Operations Summary Report BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Llc Kuukpik 5 : i Sub Hours Code I Code' Phase 3.00 WELCTL KILL WRKOVR Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1'21 :00 - OO:~O 9/1/2005 9/212005 2.00 WELCTL KILL 0.50 WELCTL KILL 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 04:00 0.50 WELCTL KILL 1.00 WELCTL KILL 04:00 - 05:00 1.00 WELCTL KILL 05:00 - 06:00 1.00 WELCTL KILL 06:00 - 07:00 1.00 WELCTL KILL 07:00 - 08:00 1.00 WELCTL KILL 08:00 - 08:30 0.50 WELCTL KILL 108:30 - 09:30 1.00 WELCTL NUND 09:30 - 12:00 2.50 WELCTL NUND 12:00 - 15:00 3.00 WELCTL NUND 15:00 - 18:30 3.50 WELCTL NUND 18:30 - 00:00 5.50 WELCTL NUND 9/3/2005 00:00 - 04:00 4.00 WELCTL BOPE 04:00 - 04:30 0.50 WELCTL BOPE 04:30 - 06:00 1.50 WELCTL BOPE 06:00 - 07:30 1.50 WELCTL BOPE 07:30 - 09:30 2.00 WELCTL BOPE 09:30 - 10:00 0.50 WELCTL BOPE 10:00 - 10:30 0.50 WELCTL BOPE 10:30 - 12:00 1.50 WELCTL BOPE 12:00 -17:30 5.50 WELCTL BOPE 17:30 - 19:30 2.00 WELCTL NUND 19:30 - 21 :00 1.50' WELCTL KILL 21 :00 - 22:30 1.50 WELCTL KILL 8/17/2005 Spud Date: 9/27/1974 End: 10/23/2005 Group: Start: Rig Release: Rig Number: 5 Description of Operations .. . .. .......... string-O-psi , annulus -0- psi Total volume pumped = 122 bbls wt. 8.6 ppg WRKOVR Pre-job safety meeting. Move injection nipple from short string to heater string WRKOVR Initial tubing pressure 920 psi. Start bullhead pumping at 2 bpm. pressure decreased to 50 psi after pumping calculated tubing volume then increased to 320 psi at final calculated volume of 54 bbls. shut dn monitor pressure =zero WRKOVR Move injection from short string to long string WRKOVR Initial tubing pressure 1425 psi Start bullheading at 2-2.5 bpm. pressure decreased to 35 psi after pumping calculated tubing volume then increased to 350 psi at final volume of 75 bbls. shut dn monitor , pressure = zero short string has 25 psi on it at end of bullheading long string WRKOVR monitor tubing pressure. Short string has 25 psi on it. all others at zero WRKOVR RU to bleed short string through choke. Bleed pressure to zero and shut in. Bressure stabilizes at +1- 25 psi in 15 min. Bleed off. liquid returns. shut back in. pressure stabilizes at +1- 25 psi. switched injection nipple from long string to short string bullhead 60 bbls at 2 bbllmin. monitor well. heater string standing full, short string and long string on very slight vacuum. WRKOVR Set BPV's in heater string and long string. Could not get 2.5" BPV past 1 st valve in short string. ND 1 st valve and set BPV. in short string WRKOVR ND tree and remove circ equipment WRKOVR Pull tree. install test darts in all strings. Confirm 4th hole has plug. Paint top of darts. Short string =Yellow( towards beaver slide) Long string=Red (towards pump), heater string= blue (ODS) WRKOVR Stack Hydril, double gate, mud cross, single gate, riser spools WRKOVR NU Hydril,double gae, single gate, riser spools, choke line, kill line, flow line, flow nipple WRKOVR NU BOP. Tighten all flanges & change lower pipe rams to 4-1/2" Start Koomey ,WRKOVR Install rotary table and function test BOPs WRKOVR tighten choke hose WRKOVR test blinds & valves #7,16,&15 to 300 psi 10 + 3000 psi hi-OK WRKOVR test valves 11,6,4,&5 to 300 psi 10 + 3000 psi hi-OK WRKOVR test valves 3,13, & 10 to 300 psi 10 + 3000 psi hi-OK WRKOVR test valves 9,12,&2 to 300 psi 10 + 3000 psi hi-OK WRKOVR work on valves 1 & 8 and outside kill WRKOVR test top pipe rams, outside kill, manual choke, HCR, floor valve, dart valve, choke manifold valves 1,8,14 to 300 psi 10 & 3,000 psi hi -OK test Hydril to 2500 psi hi and 300 psi lo-OK Test gas alarms-OK Test whitnessed by J.Crisp AOGCC WRKOVR Pull test darts from all 3 strings. check BPV's for pressure, No pressure on long string, Pressure on short string. Bleed annulus to zero. annulus fluid packed. WRKOVR MU landing jt.& circ hose to short string build 25 bbl HEC pill at +1- 3 #/bbl. WRKOVR Bullhead down short string at 1 BPM. 200 psi to open BPV. Pump 3 bbls brine followed by 25 bbl pill followed by 27 bbls brine. final pressure 320 psi. Fluid in stack bubbling while bullheading.Bleed off annulus WRKOVR WRKOVR WRKOVR Printed: 11/912005 11:42:55AM ConocoPhillips Alaska Page 4 of 26 Operations Summary Report Legal Well Name: BRU 224-13 Common Well Name: BRU 224-13 Spud Date: 9/27/1974 Event Name: WORKOVER/RECOMP Sta rt: 8/17/2005 End: 10/23/2005 Contractor Name: Kuukpik Drilling Llc Rig Release: Group: Rig Name: Kuukpik 5 Rig Number: 5 Date From - To Hours . Sub: Phase Description of Operations Code · Code! . ... .. . . . . . ..,... .. 9/3/2005 22:30 - 23:30 1.00 WELCTL KILL WRKOVR LD landing jt PU T bar and check for pressure on short string. Short string on vacuum, Open BPV on long string and bleed off pressure to zero. 23:30 - 00:00 0.50 WELCTL OTHR WRKOVR Break out pump in sub on landing joint 9/4/2005 00:00 - 00:30 0.50 WELCTL KILL WRKOVR LD pump in sub- monitor well. Short string bubbeling. PU 'T' bar and find pressure on short string 00:30 - 01 :00 0.50 WELCTL KILL WRKOVR MU landing jt to short string PU safety valve and prep to circulate 01 :00 - 02:30 1.50 WELCTL KILL WRKOVR Build 25 bbls of 3-1/2 #/bbl HEC pill 02:30 - 03:30 1.00 WELCTL KILL WRKOVR Bullhead down short string. Starting press 70 psi. @ 26 bbls away press 395 psi. at 40 bbls away press at 250 psi. at 60 bbls away press at 412 psi. Shut dn press bled to zero 03:30 - 04:00 0.50 WELCTL KILL WRKOVR Monitor well remov.e landing jt PU "T" bar and check for pressure on long string. Long string dead. 04:00 - 05:00 1.00 WELCTL KILL WRKOVR Monitor well - well dead 05:00 - 06:00 1.00 WELLSR SUN WRKOVR pulled BPV on long string and RU Pollard wireline. 06:00 - 09:00 3.00 WELLSR SUN WRKOVR Test lubricator and TIW valve. won't test. Change out TIW. test to 300 WELLS~ SUN low and 1500 psi high. 09:00 - 14:00 5.00 WRKOVR RIH wI slick line and pull G stop, patch. and A stop. Recovered everything. RIH wI 2.28 GR and tag fill @ 5220' 14:00 - 16:30 2.50 WELLSF SUN WRKOVR RD Pollard WL sheaves, tools, lubricator. clear pipe rack. RU APRS e-line, sheaves tools and PO on landing jt. 16:30 - 21 :30 5.00 WELLSF SUN WRKOVR Hold PJSM, laod cutterand RIH to cut tubing. Cut tubing on long string at 5150',3750', & 3320' on 3 runs 21 :30 - 22:30 1.00 WELLSF OTHR WRKOVR Install BPV in long, check pressure in short string and bleed off, pull , WELLSF BPV on heater string 22:30 - 23:00 0.50 OTHR WRKOVR RU to pull 2-3/8" heater string 23:00 - 00:00 1.00 WELLSF KILL WRKOVR Short string bubbleing through BPV, MU pump in sub & landing jt on short string, build HEC pill 9/5/2005 00:00 - 01 :00 1.00 WELCTL KILL WRKOVR Continue build HEC pill. 01 :00 - 02:00 1.00 WELCTL KILL WRKOVR Pump 25 bbl of HEC pill @ 3 #/bbl. Initial pressure 26 psi, final pressure 229 psi. 02:00 - 03:00 1.00 WELCTL EQRP WRKOVR BPV in short string leaking. Pull same, rebuild and replace 03:00 - 09:00 6.00 FISH PULL WRKOVR POOH with heater string, UD 69 joints of 2 3/8" tubing + mandrel hanger 09:00 - 14:00 5.00 WELCTL BOPE WRKOVR Changed out upper pipe rams from 2 3/8" to 2 7/8" - 51/2" variable. PU test joint with donut and tested variable rams against the blind rams to 1500 psi - OK. UD test joint and donut. 14:00 - 14:30 0.50 WELCTL OTHR WRKOVR Picked up "T" bar and M/U to BPV in short string. No pressure trapped below BPV. Retrieved BPV. 14:30 - 16:30 2.00 FISH PULL WRKOVR P/U landing joint and M/U to short string in the tubing hanger. Unseated mandrel hanger and sheared out Baker safety joint at 3007' MD with 29 klbs overpull - Safety joint set for 40 klbs release. Begin lid 2 7/8" short string. 16:30 -18:15 1.75 WELCTL CIRC WRKOVR Brine U-tubing up the short string while attempting to pull same. RIU landing joint & safety valve and circulated short string. No returns. 18:15 - 22:30 4.25 FISH PULL WRKOVR Continue POOH & lid 2 7/8" short string. UD a total of 96 joints + sheared safety joint. 22:30 - 23:00 0.50 WELCTL OTHR WRKOVR Picked up "T" bar and M/U to BPV in long string. Gas trapped below BPV. 23:00 - 00:00 1.00 WELCTL KILL WRKOVR RIU landing joint & safety valve. Closed annular preventer and bullheaded 60 bbls of brine down the long string at 1.5 - 1.2 bpm & 400 psi. I Bled pressure off annulus and opened annular preventer - well dead. I I Printed: 11/912005 11 :42:55 AM ConocoPhillips Alaska Page 5 of 26 Operations Summary Report Legal Well Name: BRU 224-13 Common Well Name: BRU 224-13 Spud Date: 9/27/1974 Event Name: WORKOVER/RECOMP Start: 8/17/2005 End: 10/23/2005 Contractor Name: Kuukpik Drilling Llc Rig Release: Group: Rig Name: Kuukpik 5 Rig Number: 5 . , Sub ; Date . From - To Hours . Code : Code Phase Description of Operations . .. . .. . . , . ... ....... ... ..., 9/6/2005 00:00 - 00:15 0.25 WELCTL KILL WRKOVR Picked up "T" bar and MU to BPV in long string. No pressure trapped below BPV. Retrieved BPV. 00:15 - 00:45 0.50 FISH PULL WRKOVR PU landing joint and MU to long string in the tubing hanger. Unseated I mandrel hanger and worked long string and packer. Released Baker packer "AL-5" dual at 3110' MD with 45 klbs over pull - packer set for release at 40 klbs overpull. 00:45 - 01:15 0.50 WELCTL OBSV WRKOVR Monitored well for flow as packer elements are allowed to de-energise. 01:15 - 04:45 3.50 FISH PULL WRKOVR POOH with 2 7/8" long string. Losing 25-30 bbllhr 04:45 - 05:15 0.50 WELCTL OBSV WRKOVR Losses decreased suddenly. Stopped pooh and monitored well. Well still taking fluid but at reduced rate. 05:15 - 05:30 0.25 FISH PULL WRKOVR Continue pooh with 2 7/8" long string while monitoring losses. 05:30 - 06:30 1.00 WELCTL CIRC WRKOVR Losses continue to decrease. Stop pooh. RU circulating head and circulate 108 bbl of 8.6 ppg KCI brine. 06:30 - 09:00 2.50 FISH PULL WRKOVR Continue pooh with 2 7/8" long string. Packer at wellhead under tubing hanger. 09:00 - 12:00 3.00 FISH OTHR WRKOVR Difficulty pulling tubing hanger out of wellhead with the packer. Had to work the hanger out of the wellhead, maximum over pull 40 klbs. 12:00 - 15:30 3.50 FISH PULL WRKOVR RU dual handling equipment & LD baker 'AL-5' dual packer, 2 7/8" long string including GLM, Baker shear out safety joint and 8 ft tubing stub with flared end to 3 1/2", 27/8" short string including GLM, XN nipple and wireline entry guide. 15:30 -16:30 1.00 FISH RURD WRKOVR RD tubular handling equipment & clean rig floor. '16:30 -17:00 0.50 RIGMNT RSRV WRKOVR Serviced topdrive. 17:00 - 19:00 2.00 WELCTL BOPE WRKOVR RU trip tank to annulus for hole fill. PU test equipment and RU to test ! BOPs 19:00 - 00:00 5.00' WELCTL BOPE WRKOVR Test BOPs. Tested variable rams, upper & lower IBOPs to 250 & 3000 psi. Testing choke manifold. 9/7/2005 00:00 - 12:00 12.00 WELCTL BOPE WRKOVR I Finish testing BOPs. Found O-ring on test plug to be "creased". Replaced same. Tested upper & lower kelly, floor valve, upper pipe rams (variable 27/8" - 5 1/2"), lower rams (4 1/2"), blind rams, choke i manifold & Hydril dart valve to 250 & 3000psi. '12:00 -17:00 5.00 FISH PULD WRKOVR PU wash pipe assembly, 8 1/8" drag shoe, 75/8" wash pipe, junk baskets, bumper sub, oil jar & drill collars. 17:00 - 17:30 0.50 RIGMNT RSRV WRKOVR Service topdrive while working on problem with torque gauge 17:30 - 20:00 2.50 FISH PULD WRKOVR Continue RIH with washpipe, picking up drill collars 20:00 - 00:00 4.00 FISH TRIP WRKOVR RIH with wash pipe on 41/2" DP to 2871 ft MD 9/8/2005 00:00 - 01 :00 1.00 FISH TRIP WRKOVR Continue RIH with wash pipe on 4 1/2" DP to 3300 ft MD. 01 :00 - 02:00 1.00 FISH CIRC WRKOVR Made up topdrive and established circulation with 420 gpm @ 765 psi. Took up and down weights, PU 74-76 klbs, SO 74 klbs, Rot weight@ 40 rpm 72 klbs with 1300 ft.lbs. Set top drive torque limit to 9700 ft.lbs 02:00 - 08:00 6.00 RIGMNT RGRP WRKOVR Unable to maintain circulation. Both pumps tripping out. Trouble shoot same. 08:00 - 18:45 10.75 FISH WASH WRKOVR Able to pump with one pump only. Wash over top of fish @ 3320' MD with 8 bpm 630 psi & 45 rpm. Took weight at 3377' MD. Wash over fish to 3411' MD. WOB 8 klbs, RPM 40-45, Torque 6-7 kft.lbs, PU 80 klbs, SO 80 klbs, Rot weight 78 klbs. Pumped one viscous pill - some cement, polymer and very fine metal shavings. Continue to trouble shoot pumps. 18:45 - 19:15 0.50 RIGMNT RGRP WRKOVR Trouble shoot pump problems. 19:15 - 20:15 1.00 FISH WASH WRKOVR Continue attempting to wash over fish. Unable to go beyond 3411' MD. Increased WOB from 8 to 16 klbs, torque remains 6-5 kft.lbs, pressure increasing to 800 psi. Stopped wash over operations. 20:15 - 22:00 1.75 WAlTON ORDR WRKOVR PU off bottom, circulate bottoms up. Discuss path forward with town - Printed: 111912005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 6 of 26 ConocoPhillips Alaska Operations Summary Report BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Llc Kuukpik 5 Date . Sub: From - To Hours' Code. Code ¡ Phase . . 9/8/2005 20:15 - 22:00 22:00 - 23:30 23:30 - 23:45 23:45 - 00:00 9/9/2005 00:00 - 01 :30 01 :30 - 01 :45 01 :45 - 07:30 07:30 - 10:00 10:00 -12:00 12:00 -14:30 14:30 - 17:00 17:00 - 17:30 17:30 - 19:00 19:00 - 19:45 19:45 - 21 :30 21 :30 - 21 :45 21 :45 - 00:00 9/10/2005 00:00 - 00:30 00:30 - 02:45 02:45 - 04:30 04:30 - 08:00 08:00 - 10:00 10:00 -11:15 11:15-12:00 12:00 - 15:00 15:00 -16:30 16:30 -19:00 ,19:00 - 21:15 121:15 - 21:45 121 :45 - 23:00 Communications down at rig location. POOH with washpipe assembly. Performed trip drill. POOH with washpipe assembly to 2064' MD at midnight. Continue POOH with wash pipe assembly to top of drill collars. Monitor well before pulling drill collars through BOP. Conduct Kick While Tripping drill. PULD WRKOVR POOH standing back drill collars, Evidence of slight metal-on-metal scoring on the pin end of the last stand of drill pipe above collars. LD junk baskets & recovered approx. 4 Ibs of sand, cement and very fine metal shavings. LD jar, bumper sub & one joint of 8 1/8" wash pipe. Stood back 7 5/8" washpipe with GBR. LD drag shoe. No evidence of milling casing. Shoe was tapered on the inside and the body was worn on the outside indicating tubing sitting/cemented against the casing wall. WRKOVR Discussing forward options with town while housekeeping on rig. WRKOVR PU outside cutter assembly. WRKOVR Rearrange drill collars in derrick to get acces to drill pipe. WRKOVR RIH with drillpipe in derrick to 2640' MD. WRKOVR Service topdrive. WRKOVR RIH, picking up drillpipe, to 3316' MD (4' above estimated TOF) on DP. WRKOVR Circulate bottoms up, initially at 4 bpm due to HPU problems, then 8 bpm. FISH WRKOVR Took weights, Up 60 klbs, Down 60 klbs, Rot 59 klbs @ 16 rpm & 700 I ftlbs torque. RIH and tagged TOF @ 3332' MD, 12' deeper than I recorded eline cut. Worked over TOF with weight and slow rotation. Worked over fish to 3336' MD but no further progress. Attempted to get deeper with weight (2 - 20 klbs), torque (stalling out at 8000 ft.lbs) and circulation (2.3 & 4.7 bpm) - no go. OTHR WRKOVR Attempted to come off fish, hung up. Worked to free cutting assembly with straight pull. Pipe came free with 32 klbs overpull. Ran back and tagged TOF at 3332' MD. No addition or loss in weight. POOH with cutting assembly to 2485' MD. Trouble shoot HPU. POOH with drillpipe to cutter BHA. LD washover basket - recovered approx. 1/2 Ib of sand and fine metal shavings. Rack back wash pipe. LD lip guide and cutter - marks on guide show fish on the inside. All knives recovered. Knives not engaged on fish. PULD WRKOVR PU overshot assembly and drill collars TRIP WRKOVR RIH to 3330' MD on drill pipe with overshot assembly. FISH WRKOVR Took weights, Up 78 klbs, Down 78 klbs, Rot 80 klbs @ 22 rpm & 1500 ftlbs torque. 93 psi @ 3.4 bpm. RIH and tagged TOF @ 3340' MD, 8' deeper than last time. Start milling over fish. Took 15 minutes to get over TOF. Pressure increased approx. 50 psi indicating fish in pack off. Pulled 30 klbs over pull and indications of fish parting. Circulate bottoms up. POOH with overshot assembly. Rack back drill collars and LD overshot assembly. No fish. MU overshot assembly #2. RIH on drill collars. RIH with overshot assembly #2 on drill pipe to 3284' MD. Trouble shoot problem on pump #1. Replace spring on suction end. Circulate bottoms up 1.75 WAlTON ORDR 1.50 FISH TRIP 0.25 WELCTL SFTY 0.25 FISH TRIP 1.50 FISH TRIP 0.25 WELCTL OBSV WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 5.75 FISH 2.50 WAlTON ORDR 2.00 FISH PULD 2.50 FISH OTHR 2.50 FISH TRIP 0.50 RIGMNT RSRV 1.50 FISH TRIP 0.75 FISH CIRC 1.75 FISH 0.25 FISH 2.25 FISH TRIP 0.50 RIGMNT RGRP 2.25 FISH TRIP 1.75 FISH 1 PULD WRKOVR WRKOVR WRKOVR WRKOVR 3.50 FISH 2.00 FISH 1.25 FISH 0.75 FISH CIRC 3.00 FISH TRIP 1.50 FISH PULD 2.50 FISH PULD 2.25 FISH TRIP 0.50 RIGMNT RGRP 1.251 FISH CIRC I WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Description of Operations ... .. . . .. . ... Printed: 111912005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 9/10/2005 23:00 - 23:45 9/11 /2005 23:45 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 03:00 03:00 - 04: 15 04:15 - 07:30 07:30 - 10:30 10:30 - 11 :00 11 :00 - 13:30 13:30 - 14:00 14:00 - 16:00 16:00 - 17:00 17:00 - 18:30 18:30 - 18:45 18:45 - 19:45 19:45 - 22:00 22:00 - 00:00 9/12/2005 00:00 - 00:45 00:45 - 01 :15 01:15-01:45 01 :45 - 02:15 02: 15 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 09:30 09:30 - 14:00 14:00 - 15:00 0.75 FISH JAR WRKOVR Took weights, Up 78 klbs, Down 78 klbs, Rot 79 klbs @ 15 rpm & 750 ftlbs torque. 73 psi @ 3.2 bpm. RIH and tagged TOF @ 3343' MD, 3' deeper than last time. Worked grapple over fish. Engage fish and work free after 16 jar licks with up to 80 klbs overpull. No noticeable weight increase. Circulate 1 1/2 bottoms up. Finish circulating 1 1/2 bottoms up. POOH to 1900' MD with overshot assembly & fish? Service topdrive. POOH to 400' MD - top of drill collars. POOH drill collars. LD overshot & 19' of fish, all inside fishing assembly. Fish parted at grapple. WRKOVR PU overshot assembly #3 & RIH on drill collars. WRKOVR Work on rig PLC system. WRKOVR RIH with overshot assembly #3 to 3300' MD. WRKOVR Took weights, Up 78 klbs, Down 78 klbs. 40 psi @ 3 bpm. RIH and tagged TOF @ 3332' MD, 11' shallower than last time. Worked 3' over fish, pressure increased to 117 psi. Pulled 20 klbs overpull on fish & set slips. ELlN WRKOVR RU APRS wireline. ELlN WRKOVR RIH with collar locator and 2 1/8" jet cutter. Positioned jet cutter in connection at 3396' MD and fired same. ELlN WRKOVR POOH with eline. RD APRS. JAR WRKOVR Removed slips from drill string - fish not free. Pick up to 80 klbs overpull & wait. No go. Cock jars and pull 80 klbs overpull, free after one blow. Ran back in hole and tagged at 3332' MD. CIRC WRKOVR Circulate bottoms up while rearranging remaining pipe in derrick. TRIP WRKOVR POOH with overshot assembly #3 to 400' MD - top of drill collars. PULD WRKOVR POOH drill collars and LD overshot #3. Recovered 3.6' of fish, all inside grapple. Bottom of recovered fish appears to be part of pin connection. 0.75 WAlTON ORDR WRKOVR Discussing forward options for fishing operations with town. 0.50 FISH PULD WRKOVR LD jar & bumper sub. Clear rig floor and cat walk of Baker fishing tools. Prepare for running wash pipe. PULD WRKOVR GBR tong failure - replace hoses. PULD WRKOVR RU GBR. PULD WRKOVR MU drag shoe and RIH on 7 5/8" wash pipe to 100' MD (Wash pipe assembly #2). PULD WRKOVR Shoe hung up in wellhead and at several places to 100' MD. POOH with wash pipe. Weight indicates dragging something up hole. Pulled table bushings and drained stack. Object visible below wellhead beside wash pipe. Pull object into stack and lose same. Pull wash over shoe to I surface and inspect same. Score mark along the full length of the last I stand and on the shoe. Milling surface not damaged. 1.00 FISH I PULD I WRKOVR Rerun wash pipe to 100' MD. 2.50 FISH PULD IWRKOVR i Run wash pipe assembly #2, lay down GBR, PU junk baskets, bumper I I sub and jar. 4.50 I RIGMNT i RGRP i WRKOVR i While picking up the topdrive after running a stand of drill collars the , I i I tong line was snagged, the tongs were pulled upwards until the snub i ! line caught and the hanging arm broke causing the tongs to fall to the I I floor. MU a stand of drill pipe to the collars and installed the floor safety I I valve. Repaired tongs. Took opportunity of rig down time to repair rig : pump problem. Both rig pumps now functioning. 1.00 FISH ! PULD WRKOVR; RIH with wash pipe assembly #2 on drill collars. I 0.25 FISH CIRC 1.00 FISH CIRC 1.50 FISH TRIP 0.50 RIGMNT RSRV 1.25 FISH TRIP 3.25 FISH PULD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 3.00 FISH PULD 0.50 RIGMNT RGRP 2.50 FISH TRIP 0.50 FISH FISH 2.00 FISH 1.00 FISH 1.50 FISH 0.25 FISH 1.00 FISH 2.25 FISH 2.00 FISH 0.50 FISH 0.50 FISH 0.75 FISH 3.00 FISH Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Start: 8/17/2005 Rig Release: Rig Number: 5 9/12/2005 15:00 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 00:00 9/13/2005 00:00 - 02:00 02:00 - 03:45 03:45 - 06:00 06:00 - 11 :00 11 :00 - 14:00 14:00 - 17:30 17:30 - 19:30 19:30 - 00:00 9/14/2005 00:00 - 09:00 09:00 - 12:00 12:00 - 15:00 15:00 - 00:00 I 9/15/2005 00:00 - 03:15 03:15 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 09:30 09:30 - 10:00 TRIP WRKOVR RIH with wash pipe assembly #2 on DP to 3330' MD. WASH WRKOVR Took weights, Up 78 klbs, Down 80 klbs, Rot 78 klbs, Torque 1200 ft.lbs. Washed over fish to 3411' MD, Torque increased to 4200 ft.lbs. TOF not tagged. 0.50 RIGMNT RSRV WRKOVR Service topdrive. 5.50 FISH WASH WRKOVR Wash/mill over fish from 3411' to 3415' MD. WOB 8 klbs, torque 4-8 kft.lbs. Indications of milling on junk on the outside of fish. Cement & fine steel cuttings to surface. WASH WRKOVR Wash/mill over fish from 3415' to 3416' MD. Torque became constant at 3400 ft.lbs with varying parameters, no progress last hour. CIRC WRKOVR Mix and pump 25 bbl viscous sweep, no change in cuttings to surface. TRIP WRKOVR POOH with wash pipe assembly #2 on drill pipe. PULD WRKOVR POOH with drill collars. LD jar, bumper sub & junk baskets - recovered 4-5 Ibs of fine metal shavings, cement & sand + several large (1 "x1 ") flakes of unidentified metal from baskets. Stand back washpipe & LD drag shoe. Shoe in good condition. 3.00 RIGMNT RURD WRKOVR Install flange on flow line to take acid/caustic returns to dedicated tank. 3.50 FISH PULD WRKOVR MU flat bottom shoe to washpipe & run in hole on wash pipe assembly #3 & drill collars. TRIP WRKOVR RIH with washpipe assembly #3 to 3300' MD on drill pipe. WASH WRKOVR Took weights, Up 78 klbs, Down 79 klbs, Rot 76 klbs, Torque 900 ft.lbs. Washed over fish to 3395' MD where torque increased to 5 kft.lbs. Continue RIH and stalled out at 3399' MD, no increase in WOB. Ream from 3399 to 3400' MD where it broke through. Wash to 3410' MD where torque increased again. Ream from 3410 to 3414' MD (0.5 hours) where it took weight. Wash over fish from 3414 to 3416' MD (1.5 hours) with 8-10 klbs WOB, 50 rpm & 7 bpm. PU to work mill, both overpull & drag experienced. Tag up at 3415' MD while attempting to work to bottom. A lot more torque on surface with pipe rattling in the derrick. Junk above the shoe? Ream back to 3416' MD by midnight (1 hour) . TOF not tagged. WASH WRKOVR Wash over fish from 3416 to 3417' MD. Evidence of junk in the hole- intermittent overpull when picking up and drag when running back to bottom. Have to work back to bottom several times. Vary WOB (8-30 klbs), rpm (40-60) and pump rate (225 - 500 gpm) to get mill to work - no go. TRIP WRKOVR POOH with washpipe assembly #3 to top of collars at 800' MD. PULD WRKOVR POOH with washpipe assembly #3. Rack back drill collars. LD bumper sub, jar and junk baskets (recovered mostly metal with some hard pieces of cement and sand). Rack 3 stands of washpipe, LD 8 joints of washpipe, LD flat bottom shoe - 1.4' worn from end of shoe. 9.00 WELCTL BOPE WRKOVR Pull wearbushing, set test plug. Test BOPs. Test choke manifold, upper & lower IBOP, upper rams (2 7/8" x 51/2" var), lower rams (4 1/2"), blind rams and dart valve to 250/3000 psi. Pull test plug and run wear bushing. PU overshot assembly #4 & RIH on drill collars. PU accelerator. RIH with overshot assembly #4 to 3300' MD. Tag fish & latch same @ 3332'. Pull35K over & hit jars once to verify latch. 1.50 i FISH I FISH II WRKOVR Rig up APRS-hold PJSM-Ioad charge 400gr for backoff. 1.50 I FISH FISH WRKOVR RIH w/ wireline shot & collar locator-log from 3740 to 3416. 0.50! FISH \ CPBO I WRKOVR PJSM-pick up to neutral wt.-put 2 rds. left hand torque 2700-work i torque down-fire charge @ 3416-pick up -fish free. 2.00 FISH 1.00 FISH 2.00 FISH 1.75 FISH 2.25 FISH 5.00 FISH 2.00 FISH 4.50 FISH 9.00 FISH 3.00 FISH 3.00 FISH 3.251 FISH 2.751 FISH 0.50 I FISH I I !PULD ITRIP IFISH WRKOVR WRKOVR I WRKOVR Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: Date 9/15/2005 9/16/2005 9/17/2005 9/18/2005 9/19/2005 BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Sub From - To Hours Code Code Phase Deseription of Operations 10:00 - 11 :00 1.00 FISH FISH WRKOVR POH w/ wireline & rig down APRS. 11 :00 - 15:00 4.00 FISH TRIP WRKOVR POH w/ fish 15:00 - 18:00 3.00 FISH PULD WRKOVR Lay down fish-recovered 81' -4 blast jts. & l' piece. 18:00 - 21 :00 3.00 FISH TRIP WRKOVR Make up jet basket & RIH. 21 :00 - 21 :30 0.50 FISH FISH WRKOVR Work jet basket. 21 :30 - 00:00 2.50 FISH TRIP WRKOVR POH w/ BHA #9. 00:00 - 02:30 2.50 FISH TRIP WRKOVR POH w/ jet basket. 02:30 - 03:30 1.00 FISH PULD WRKOVR Lay down & clean out junk baskets & jet basket-recovered 1/2 gal. iron debrei & 2 chunks of cement. 03:30 - 06:00 2.50 FISH PULD WRKOVR Make up bha #10 w/ 4 jts. wash pipe & shoe. 06:00 - 08:30 2.50 FISH TRIP WRKOVR RIH w/ bha #10. Tag @ 3414'. Possibly top of blast jt. stub. 08:30 - 09:00 0.50 FISH OTHR WRKOVR Service rig. 09:00 - 09:30 0.50 FISH CIRC WRKOVR Clean out over stub & cbu. 09:30 - 19:00 9.50 FISH WASH WRKOVR Washing & milling over fish from 3414 to 3449'. 19:00 - 22:00 3.00 FISH TRIP WRKOVR POH w/ BHA #10. 22:00 - 23:00 1.00 FISH TRIP WRKOVR Lay down junk baskets & stand back washpipe. 23:00 - 00:00 1.00 FISH TRIP WRKOVR Make up junk baskets-washover pipe & shoe. 00:00 - 01 :30 1.50 FISH PULD WRKOVR Continue making up BHA #11-pick up 6 jts. 7 5/8" wash pipe. 01 :30 - 03:30 2.00 FISH TRIP WRKOVR RIH from 756 to 3390'. tight spot @ 3390'. 03:30 - 04:30 1.00 FISH WASH WRKOVR Wash thru tight spot @ 3390' & wash down to 3449'. 04:30 - 13:00 8.50 FISH WASH WRKOVR Washing & milling over fish from 3449 to 3724'. Circulate sweeps around while washing. Getting more sand when sweeps reach surface. 13:00 - 15:00 2.00 FISH MILL WRKOVR Attempt to mill iron above packer. Torque to stall out. No Success. 15:00 - 20:00 5.00 FISH TRIP WRKOVR POH to wash pipe-rig up GBR & stand back washpipe & rig down GBR-Shoe wore out. 20:00 - 21 :00 1.00 FISH OTHR WRKOVR Pull wear ring-clean & Replace. 21 :00 - 00:00 3.00 FISH TRIP WRKOVR Make up BHA #12 & RIH. 00:00 - 02:30 2.50 FISH TRIP WRKOVR RIH w/ overshot to 3414'. 02:30 - 04:30 2.00 FISH FISH WRKOVR Tag fish @ 3414-Attempt to dress top of fish & latch on-chase fish down hole to 3467'-latch on to fish & unseat packer. 04:30 - 05:00 0.50 FISH FISH WRKOVR CBU. 05:00 - 12:00 7.00 FISH TRIP WRKOVR Monitor well-POH slow w/ fish-pulling tight all the way-monitor well @ dc.s-back out lock down screws on bowl protector-stand back dc,s. 12:00 - 15:00 3.00 FISH PULD WRKOVR Lay down fish-recovered blast jts. 2 7/8" tbg. glv,s & packer. 327'. 15:00 - 16:00 1.00 FISH PULD WRKOVR Make up BHA #13. 16:00 - 20:30 4.50 FISH TRIP WRKOVR RIH w/ overshot dressed w/2 7/8" grapple-Latch fish @ 3750-pull seals out. 20:30 - 00:00 3.50 FISH TRIP WRKOVR POH w/ fish. 00:00 - 01 :30 1.50 FISH PULD WRKOVR LD overshot and fish. Recover all fish above packer and seal assembly - 59.72'. 01 :30 - 02:00 0.50 RIGMNT RSRV WRKOVR Serviced topdrive. 02:00 - 04:00 2.00 FISH IpULD WRKOVR PU jet basket assembly #2 & RIH on drill collars. 04:00 - 06:00 2.00 FISH TRIP WRKOVR RIH with jet basket assembly #2 to 3795' MD on drill pipe. 06:00 - 07:30 1.50 FISH OTHR IWRKOVR ¡Tag top of packer at 3795' MD. Circulate at 500 gpm for 30 min. Drop I ! ball for reverse circulation. Circulate at 580 gpm for 60 min. 07:30 - 10:00 , 2.50 FISH TRIP ,WRKOVR I POOH with jet basket assembly #2 to 400' MD on drill pipe. 110:00 - 12:00 I 2.00 FISH i PULD i WRKOVR I Stand back collars, LD junk baskets & jet basket - recovered one large I I ' ! I (9" X 3"), curved sliver of 95/8" casing. I I PULD : WRKOVR i PU jet basket assembly #3 and RIH on drill collars. 112:00 - 15:00 3.00 FISH ì 15:00 - 16:45 1.75 FISH TRIP :WRKOVR i RIH with jet basket assembly #3 on drill pipe. Tag packer at 3795' MD. 116:45 -18:15 1.50 I FISH OTHRWRKOVR I Circulate at +500 gpm & drop ball for reverse circulation. Circulate for ~ I :45 min. I : 18:15 - 20:45 , 2.50 FISH TRIP . WRKOVR i POOH with jet basket assembly #3 on drill pipe to top of drill collars. Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 9/19/2005 20:45 - 23:30 From - To Hours 2.75 FISH Date 9/20/2005 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:30 03:30 - 03:45 03:45 - 04:00 04:00 - 09:30 09:30 - 10:30 10:30 - 13:00 13:00 - 17:00 17:00 - 21 :00 PULD WRKOVR Monitor well at drill collars. Stand back drill collars. LD jet basket - no recovery - junk baskets - several cups of sand and minor metal shavings. PULD WRKOVR PU Packer mill assembly #1 and RIH on drill collars. PULD WRKOVR Continue PU Packer mill assembly #1 and RIH on drill collars. TRIP WRKOVR RIH with packer mill assembly #1 to 3467' where it took weight. OTHR WRKOVR Took weight at 3467' MD - TOF 9/18/05. Work through tight spot (-1 ft) several times with 30 rpm, 5-6 kft.lbs, 2 klbs WOB & 120 gpm. Run past tight spot with no rotation & no pumps - taking negligible weight. Continue RIH. TRIP WRKOVR Continue RIH to top packer at 3795' MD on drill pipe. MILL WRKOVR Held safety meeting. Took weights, Up 84 klbs, Down 88 klbs, Rot 85 klbs @ 30 rpm. Tag top of packer at 3795' MD. Had drag & overpull above packer. Start milling with 4 klbs WOB, 60 rpm @ 2 kft.lbs & 265 gpm @ 685 psi. Milled 1.5 ft of packer to 3796.5' MD, 4 - 10 klbs WOB, 30 - 90 rpm @ 1 - 5 kft.lbs, 170 - 475 gpm @ 625 - 2400 psi. Changing parameters did not dampen surface vibration. 1.00 RIGMNT RGRP WRKOVR Replace hydraulic pump #2 for top drive. 2.50 FISH MILL WRKOVR Milled packer 0.5 ft (total 2 ft) to 3797' MD with 6 - 20 klbs WOB, 70- 75 rpm @ 1.5 - 4 kft.lbs, 200 gpm @ 500 - 1100 psi. 4.00 WELCTL KILL WRKOVR Observed increase in flow from well. Shut well in. 10 bbl pit gain. SICP 18 psi, SIDPP O. Perform 1 circulation across the choke and through the degasser. Shut well in - SICP 124 psi, SIDPP 35 psi. Carried out 3 more circulations across the choke and through the degasser. After second circulation - SICP 124 psi, SIDPP 0, after third circulation, SICP 64, SIDPP O. After final circulation both SICP & SIDPP 0 psi. Open annular and monitor for flow - no flow. MILL WRKOVR Milled packer 3 ft (total 5 ft, 1-2 ft packer sliding downhole) to 3800' MD. Lots of rubber over shakers. Indications (torque & WOB) are that packer is rotating beneath mill. Pump viscous sweep -little increase in cuttings over shakers, a few very thin slivers of metal 3" x 2". 15 klbs overpull when PU from packer but dropped to zero after 5 - 10ft. TRIP WRKOVR Monitor well - ok. POOH slowly with 5 stands (passed through tight spot at 3467' MD with no overpull). Monitor well - ok. Continue POOH with packer mill assembly #1 on drill pipe to 1000' MD. TRIP WRKOVR Continue POOH with packer milling assembly #1 to top of drill collars at 400' MD PULD WRKOVR Monitor well for flow at top of drill collars - ok. Stand back drill collars, LD junk baskets and packer mill - 100% worn. Packer mill extension in good condition. Recovered 10 - 15 Ibs of fine metal shavings, metal lumps and slivers from junk baskets. PULD i WRKOVR PU packer spear assembly #1 (Itco spear with 3.199" grapple) & RIH on I \ drill collars ! TRIP ,WRKOVR II RIH with packer spear assembly #1 to 3316' MD on drill pipe. i OTHR I WRKOVR Slip and cut 97' of drill line i TRIP I' WRKOVR I Continue in hole from 3316 to 3799' ; FISH : WRKOVR . Tag packer at 3799' get inside fish and pull free w/ 25K over ¡ CIRC i WRKOVR ) Circ BU thru tubing and spear to circ valve. Drop ball open circ valve : II I and continue BU. Monitor well. OK 4.00 FISH I TRIP WRKOVR' POOH from 3799 to 429' 2.00 FISH I TRIP WRKOVR Stand back DC's to top of fish. 1.50 FISH ! TRIP WRKOVR Brake down fishing tools. 0.50 FISH 1.50 FISH 2.00 FISH 0.25 FISH 0.25 FISH 5.50 FISH 4.00 FISH 21 :00 - 00:00 3.00 FISH 9/21/2005 00:00 - 00:30 0.50 FISH 00:30 - 02:00 1.50 FISH 02:00 - 04:00 I 04:00 - 06:30 06:30 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 11 :30 ! 11 :30 - 15:30 15:30 - 17:30 17:30 - 19:00 2.00 FISH 2.50 I FISH 2.50 FISH i 1.00 I FISH 0.50 I FISH 1.00 I FISH Sub Code Code Phase Deseription of Operations Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 9/21/2005 17:30 - 19:00 19:00 - 19:30 19:30 - 22:00 9/22/2005 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 04:30 1.50 FISH TRIP 0.50 FISH TRIP 2.50 FISH TRIP 0.50 FISH TRIP 0.50 WELCTL BOPE 1.00 WELCTL BOPE 4.50 WELCTL BOPE 04:30 - 05:00 0.50 WELCTL BOPE 05:00 - 06:00 1.00 WELCTL TRIP 06:00 - 08:00 2.00 CMPL TN TRIP 08:00 -10:30 2.50 WELLSR TRIP 10:30 - 11 :00 0.50 CMPL TN SFTY 11 :00 - 12:00 1.00 WELLSR MILL 12:00 - 14:00 2.00 WELLSR MILL 14:00 - 14:30 0.50 CMPL TN SFTY 14:30 - 17:00 2.50 WELLSR TRIP 17:00 - 18:00 1.00 WELLSR MILL 18:00 - 20:00 2.00 CMPL TN CIRC 20:00 - 00:00 4.00 WELLSR MILL 9/23/2005 00:00 - 00:30 00:30 - 01 :30 01 :30 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 18:00 18:00 - 19:00 19:00 - 00:00 0.50 WELLSR MILL 1.00 WELLSR CIRC 4.50 WELLSR TRIP 3.00 WELLSR TRIP 0.50 WELLS~ OTHR 1.50 WELLSR PULD 1.00 WELLSR PULD 1.00 WELLS~ OTHR 1.00 I WELLSR TRIP 0.50 WELLS~ TRIP 3.50 I WELLS~ TRIP 1.00! WELLSR TRIP I ' I I I 5.00 ~ WELLS~WASH I WRKOVR WRKOVR RU GBR to LD tubing WRKOVR LD 1336' feet of fish & 5.38' of packer. Test choke manifold on way out of hole WRKOVR RD GBR WRKOVR RU trip tank to annulus WRKOVR RU test Jt. pull wear bushing, set test plug, fill stack. WRKOVR Change out choke valve #6, test Hydril, top pipe rams, bottom rams, Blinds, HCR, manual choke, Inside kill, outside kill, dartvalve, floor valve, Hyd IBOP, ManuallBOP, tested to 250 psi low and 3000 high for 10 min - OK, tested koomey WRKOVR Pull test plug, set wear bushing, RILDS, hook trip tank to fill up line WRKOVR PU used jars and make service breaks, LD same WRKOVR PU 8-1/8" flat bottom mill wI 8.51 watermelon mill, 3- Junk bskts bumper sub, new oil jars, pump out sub,l362' of 6-114" DCs and accelerator jars WRKOVR RIH wI CO assy. WRKOVR Safety Stand down-Reviewed recent incident, commitment to safety WRKOVR Took 10 K weight at 3400'. PU rotate dn at 50-60 rpm. started taking weight at 3390' Pumping +1- 4 bpm @ 300 psi. UP wt=85K, DN wt= 85K, Rot wt = 85K, Torq 3K WRKOVR increase rpm to 75, increase weight to 1 OK-16K wI torq increase to 4500 ft-Ibs. work through several times 3390- 3403. shut dn rotary and RIH to 3800' WRKOVR Safety Stand down-Reviewed recent incident, commitment to safety WRKOVR RIH picking up DP to 4997' set dn w/1 OK WRKOVR Reaming tight casing wI 50 rpm, 5K wt and 2500 ft-Ib torq pumping at 50 spm wI 220 psi. getting sand and coal rtns. wI some metal shavings. WRKOVR circ hi visc sweep. getting sand and coal rtns. work pipe circ and clean upwell. WRKOVR Ream from 5014 to 5118 Change screens to 175 and 85. Work pipe circ and clean up well. at 5045 shut dn rotary and wash down 1 jt.w/5 k. circ @ 10 bpm w/11 00 psi. Continue to ream dn. pump high visc sweep. WRKOVR wash and ream from 5118 to 5148. tag top of fish at 5148' WRKOVR Pump sweep and CBU. getting sand and coal returns WRKOVR POOH from 5148 to 430' saw slight drag at 5020' otherwise pulled clean WRKOVR LD accel, jars. stand back collars, break out mill assy and LD same, LD junk bskts WRKOVR RU csg. tongs PU BHA held PJSM for running wash pipe WRKOVR PU shoe, wash pipe wI rolling dog basket. WRKOVR MU jars, junk bskts and RD casing tongs WRKOVR Lube rig and service TD. replace bolts on topdrive guard WRKOVR RIH wI drill collars WRKOVR change out accelerator jars WRKOVR RIH WRKOVR tag top of fish at 5148' slide over top of fish to 5154 wI no problem. pump 450 gpm @ 780 psi wI 20 rpm. Note slightly tight at 5023' approx 5K over WRKOVR Washing over fish to 5420' wI 450 gpm @ 800 psi wI 20 rpm and <5K wt. using hi visc sweeps to clean hole. getting fine sand rtns up wt = 113K, dn wt = 100K, rt wt = 108 K Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 9/24/2005 00:00 - 04:00 4.00 FISH WASH WRKOVR Wash over 2-7/8" tubing from 5420 to 5579'. rot 20-25 rpm w/2-5K torq @ 400 gpm wI 900 psi. Tag at 5579' w/1 OK 04:00 - 06:00 2.00 FISH CIRC WRKOVR Pump 2 high visc sweeps around and CBU. fine sand returns. supersucked +1- 4 bbls out of cuttings bins. 06:00 - 11 :00 5.00 FISH TRIP WRKOVR POOH from 5579 to 778' wI minimal drag (5-15K) 11:00 - 12:00 1.00 FISH TRIP WRKOVR LD accelerators, stand back collars, LD junk bskts. 12:00 - 13:00 1.00 FISH TRIP WRKOVR clean and LD junk bskts. recovered fine sand, cmt and coal. 13:00 - 13:30 0.50 FISH SFTY WRKOVR prejob safety mtg and RU GBR 13:30 - 14:00 0.50 FISH TRIP WRKOVR Brk off 1 st stand of wash pipe. fish too tall to strip over. Make back up and RIH. Brk off single jt of wash pipe and tie on slide 14:00 - 15:00 1.00 FISH TRIP WRKOVR Change tongs RU to LD tubing. while breaking out 2nd jt trapped pressure blew +1- 15 gal of brinel mud over rig floor. Cleaned up and rigged up air drill. 15:00 - 20:00 5.00 FISH TRIP WRKOVR Tubing sanded up. drill 114" hole every jt to relieve pressure. clean out every jt on floor and LD 326.7' of tubing 20:00 - 20:30 0.50 FISH TRIP WRKOVR RD tubing tongs RU WP tongs 20:30 - 00:00 3.50 FISH TRIP WRKOVR LD 7-5/8" WP 9125/2005 00:00 - 02:30 2.50 FISH TRIP WRKOVR PU rotary shoe, 8-1/8" wash pipe, basket, junk baskets, jars & collars 02:30 - 03:00 0.50 FISH OTHR WRKOVR service rig 03:00 - 06:00 3.00 FISH TRIP WRKOVR RIH from469' to 5030' tight from 3390-3440, 10k drag 06:00 - 07:00 1.00 FISH TRIP WRKOVR Tag tigh spot at 5030, rotate 40 rpm w/4k torq, pumping 60 gpm w 30 psi. work pipe. increase pump to 200 gpm wI 175 psi. increase rpm. torq to 8K work to 5034' 07:00 - 09:00 2.00 FISH OTHR WRKOVR Lost rig hydraulic pump. repair same 09:00 - 10:30 1.50 FISH TRIP WRKOVR continue to work thru tight spot wI 200 gpm 175 psi, 50 rpm, torq 4-7 K ft-Ibs, wI 3-5 K wt. 10:30 - 11 :00 0.50 FISH TRIP WRKOVR RIH from 5040 to 5210' 11 :00 - 11 :30 0.50 FISH TRIP WRKOVR RIH picking up DP from 5210 to 5576' 11 :30 - 12:00 0.50 FISH TRIP WRKOVR Tag bottom at 5576' Circ on top of fish 12:00 - 16:00 4.00 FISH WASH WRKOVR Wash over fish from 5576' to 5656' up wt = 116K dn wt = 116K rot wt = 116 K torq = 1000 16:00 - 19:00 3.00 FISH CIRC WRKOVR Circ. pump sweep. rtn sand, coal wI small metal, pump 2nd sweep wI same rtns only less volume. hole clean. 19:00 - 00:00 5.00 FISH TRIP WRKOVR POOH from 5656' to 470. Hole tight 5070 to 5025 w/15 K over. Hole tight 3425 to 3370 wI 20 Kover. up wt =116K, dn wt = 116 K, rt wt = 116K 9/26/2005 00:00 - 05:00 5.00 FISH PULD WRKOVR Lay down accelerator jars,stand back collars, lay down & clean out junk baskets, approx. 1/2 gal. sand & metal cuttings in baskets. Lay down wash pipe. Make up BHA #20. (Overshot assy.) 05:00 - 08:00 3.00 FISH TRIP WRKOVR RIH WI BHA #20 to 5030. 08:00 - 08:30 0.50 FISH IOTHR I WRKOVR I Tag tight spot @ 5030 & work thru same to 5058. 08:30 - 09:00 0.50 FISH I TRIP I WRKOVR RIH to 5636-tag top of fish @ 5636. 09:00 - 09:30 0.50 FISH I CIRC i WRKOVR I CBU 09:30 - 10:00 : 0.50 FISH ¡ FISH I WRKOVR ! Attempt to catch fish w/1 Ok wt. on same. ¡ Unsuccessful. 10:00 - 16:30 . 6.50 FISH ¡TRIP i WRKOVR : POH -tight from 5070 to 5025-1 Ok overpull & tight from3425 to 3380 5k i i overpull. 16:30 -18:30 2.00 FISH PULD I WRKOVR : Stand back DC,s-change bha to milling shoe under overshot. BHA #21. I RIH wI DC,s. 118:30 - 00:00 5.50 ¡ FISH ;TRIP WRKOVR : RIH to 5029-tight spot @ 5029. I i Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 9/27/2005 00:00 - 04:00 4.00 FISH MILL WRKOVR Milling over guns from 5634 to 5652. Indication of guns firing while milling over fish. 04:00 - 04:30 0.50 FISH FISH WRKOVR Service rig.PuIl160k-45k over string wt.-fish came loose.-monitor well for gas. 04:30 - 10:00 5.50 FISH TRIP WRKOVR POH-pulled tight @ 3390 5k over-Let guns depressurize 45 mins. stand back bha. 10:00 - 11 :00 1.00 FISH PULD WRKOVR Lay down fish-recovered 20' guns-guns mostly fired. 11 :00 - 15:30 4.50 FISH PULD WRKOVR Make up bha #23 15:30 - 18:00 2.50 FISH MILL WRKOVR RIH-tight @ 3390'-reamed to 3410. Takes 10K wlo rotation, to pull through or go down through tight spot 18:00 - 21 :00 3.00 FISH TRIP WRKOVR RIH-tight @ 5030-reaming hole from 5030 to 5034'.8000 torque. 21 :00 - 00:00 3.00 FISH TRIP WRKOVR RIH to bottom @ 5653. 9/28/2005 00:00 - 01 :30 1.50 FISH CIRC WRKOVR CBU & Pump sweep @ 10 bpm. 01 :30 - 03:30 2.00 FISH TRIP WRKOVR POH to 3300=1 Ok overpull @ 5030'. 03:30 - 06:00 2.50 FISH OTHR WRKOVR Reaming from 3388 to 3390. Attempting to clean up tight spot.up wt =78K, dn wt = 80K torq1 K 06:00 - 07:30 1.50 FISH TRIP WRKOVR RIH to 5020 Ream hole from 5020 to 5030. up wt 102K, dn wt 104 torq 1K 07:30 - 08:00 0.50 FISH TRIP WRKOVR RIH to 5652. 08:00 - 09:00 1.00 FISH CIRC WRKOVR CBU & pump sweep @ 10 bpm. 09:00 - 14:30 5.50 FISH TRIP WRKOVR POH cautious thru tight spots. Not drag or wt. OK 14:30 - 15:30 1.00 FISH PULD WRKOVR Break & lay down baker tools. Reamer 1/8" under gage 15:30 - 00:00 8.50 FISH OTHR WRKOVR Rig up SOS & run wireline logs. work on top drive. 9/29/2005 00:00 - 05:30 5.50 LOG ELOG WRKOVR Running USIT & RST logs on SOS E line. Both runs completed. Rig Down Same. 05:30 - 09:30 4.00 CMPL TN TRIP WRKOVR Make up Baker retriev-o-matic packer & rih-set same @ 3181. 09:30 - 10:00 0.50 CMPL TN OTHR WRKOVR Test 95/8" 47# csg. above packer to 3000# 5 mins. OK 10:00 - 14:00 4.00 CMPLTN TRIP WRKOVR POH & lay down packer. 14:00 - 19:00 5.00 WELCTL BOPE WRKOVR Test all BOPE to 250=3000#. 19:00 - 20:30 1.50 RIGMNT RSRV WRKOVR Cut & slip Drlg. line. 20:30 - 21 :00 0.50 CMPL TN SFTY WRKOVR Pre job safety meeting prior to picking up scraper magnets & brushes. 21 :00 - 00:00 3.00 CMPL TN TRIP WRKOVR Make up BHA #24 9/30/2005 00:00 - 04:30 4.50 CMPL TN TRIP WRKOVR RIH wI DP magnets, brushes, & scraper to 5652. Work thru tight spot @ 5030. 1 Ok wt 20 rpm idle pump. 04:30 - 06:00 1.50 CMPL TN CIRC WRKOVR CBU clean hole. 8 bpm. 06:00 - 09:30 3.50 CMPL TN TRIP WRKOVR POH to scraper & magnet-clean off magnet full of fine metal, clean junk basket. 09:30 - 10:30 1.00 RIGMNT RSRV WRKOVR Service rig. 10:30 - 13:00 2.50 CMPL TN TRIP WRKOVR RIH to 5652. tight @ 5030 5k went thru with no problem. 13:00 - 16:00 3.00 CMPL TN CIRC WRKOVR CBU clean hole 8 bpm. 16:00 - 22:00 6.00 CMPLTN TRIP WRKOVR POH to magnet & clean same. RIH to 5030-tight took 1 Ok wt. rotate thru without pump, went thru ok. 22:00 - 00:00 2.00 CMPL TN CIRC WRKOVR Circ. clean hole @ 8 bpm. 10/1/2005 00:00 - 12:00 12.00 CMPL TNI CIRC I WRKOVR Circ.-clean hole for caustic wash-acid pickle & run sump packer. Up wt. 94k Down wt. 94k. 12:00 - 00:00 12.00 CMPL TNi OTHR I WRKOVR Clean pits-flushed all lines & bope wI safe surf-Mixing caustic wash & I ' hook up 6" line to bypass on shakers. 101212005 00:00 - 04:30 I 4.50 CMPL TN¡ CIRC I WRKOVR Circ and condition brine. Mix 750 Ib caustic pill with 16 gal ARDS 9140, 1 [ ! 40 gal ARDS 9755 and 1/2 gal ofWD-24 and 75 bbls of 150F brine. 04:30 - 05:30 1.00 CMPL TNi CIRC ¡WRKOVR Pump Caustic wash at 122 spm wI 200 psi. reciprocate pipe @15' min ; WRKOVR and rotate @ 20 rpm 05:30 - 08:30 3.00 CMPL TN: CIRC : Circ at 8 BPM to reduce NTU's Shut down. ,(10 MINUTE INTERVALS) Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/2/2005 05:30 - 08:30 08:30 - 10:30 10:30 -12:45 12:45 - 13:15 13:15 -14:00 14:00 - 16:00 16:00 - 19:00 10/3/2005 19:00 - 00:00 00:00 - 02:30 02:30 - 07:00 ! I 3.00 CMPL TN CIRC WRKOVR NTU OUT 1000++ NTU IN 57 NTU OUT 386 NTU IN 74 NTU OUT 507 NTU IN 53 NTU OUT 504 NTU IN 40 NTU OUT 1000++ NTU IN 25 NTU OUT 1000++ NTU IN 16 NTU OUT 583 NTU IN 17 NTU OUT 190 NTU IN 28 NTU OUT 63 NTU IN 28 STOP CIRCULATING IN ORDER FIX LEAKING VALVE BETWEEN PITS 4 AND 5. RESUME CIRCULATION NTU OUT 84 NTU IN 5 NTU OUT 30 NTU IN 9 NTU OUT 35 NTU IN 7 NTU OUT 37 NTU IN 7 NTU OUT 34 NTU IN 5 NTU OUT 35 NTU IN 5 2.00 CMPL TN CIRC WRKOVR cleanout filteration unit 2.25 CMPL TN CIRC WRKOVR Circ at 8 BPM to reduce NTU's ( 10 MINUTE INTERVALS) NTU OUT 46 NTU IN 15 NTU OUT 23 NTU IN 13 NTU OUT 17 NTU IN 12 NTU OUT 17 NTU IN 15 NTU OUT 14 NTU IN 9 NTU OUT 19 NTU IN 7 0.50 CMPL TN SFTY WRKOVR NTU OUT 12 NTU IN 5 NTU OUT 10 NTU IN 5 NTU OUT 11 NTU IN 2 NTU OUT 11 NTU IN 2 NTU OUT 11 NTU IN 2 NTU OUT 10 NTU IN 2 NTU OUT 8 NTU IN 2 NTU OUT 4 NTU IN 2 Stop circulating Clean wellbore. Pre Job safety meeting and operations discussion about acid and chemical pickle I 0.75 CMPLTNiRURD IWRKOVR I I 2.00 CMPL TN AWSH I WRKOVR 3.00 CMPL TN: CIRC I WRKOVR I 5.00 CMPL TN~ TRIP 2.50 CMPL TNi TRIP 4.50: CMPL TNi PULD I I RU trucks, hoses and chem totes. RU floor and manifold in order to pump acid, and CE-101 down drillpipe and reverse out. Pump 10 bbl high vis pill, 10 bbl CE-101 and 500 gal of 15% HCL , chase with brine to end of drillpipe at 0.5 BPM. Reverse out DP pill train and 2 additional DP volumes at 2 BPM. Take pills back into acid nuetralization pit. Stop reversing. Circulate normal at 8 BPM recording NTU's and allowing to clean up. ¡WRKOVR : POOH, LD brushes, scrapers and magnets. ! WRKOVR ' POOH, LD brushes, scrapers and magnets. 'WRKOVR i PU tailpipe, install plug in XN nipple. PU sump packer and running tool. I Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/3/2005 07:00 - 09:00 09:00 - 12:00 12:00 - 14:30 14:30 - 15:45 15:45 - 16:15 16:15 -17:30 17:30 - 18:00 18:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:45 10/4/2005 23:45 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 04:30 04:30 - 08:00 08:00 - 09:30 09:30 - 10:00 110:00 - 11 :00 11 :00 - 12:30 112:30 - 13:30 I : 13:30 -15:30 I I l 15:30 - 18:00 I 18:00 - 20:00 ¡ 20:00 - 21 :00 2.00 CMPL TN TRIP WRKOVR RIH with sump packer assembly on drill pipe to 1885' MD. At this depth driller opened elevators before setting slips - packer & pipe dropped down hole. 3.00 CMPL TN TRIP WRKOVR Discuss forward options with town while monitoring well & performing rig service.Wait on tools. PULD WRKOVR PU overshot & grapple FISH WRKOVR Tagged TOF @ 50' MD - Packer set @ 1822' MD. Engage fish with grapple. Set down 20K. PU and engage bumper sub. 18" stroke marked. Fish captured. Pick up 25K over. Fish moved slightly. PU again to 25K over, packer hard sets. FISH WRKOVR Pressure up to 1500 psi to verify fully set packer in preparation for milling. Bleed off. PU to 55K slack off to 20K. Packer definitely set. Rotate 14 turns to the right and release setting tool from the packer. PULD WRKOVR POOH with one stand and grapple. Set slips on fish in floor. Work to disengage grapple from the fish. LD grapple. OTHR WRKOVR Pressure up to 3300 psi. (2760 psi to blow ball set in order to not pull wet pipe). Trip pump trips. Reset pump trips and engage test pump. Pressure up to 4500 psi (max) ball did not blow through. TRIP WRKOVR POOH (wet) LD DP. PULD WRKOVR Break out and LD packer setting tools. Prep for barge shipment to redress in BOT Kenai. SUN WRKOVR RU Pollard slickline to retrieve plug set in XN nipple @ 1872' MD. SUN WRKOVR RIH with prong retrieving tool. Tag up on top of packer @ 1822' WLM. Get over lip of packer after several attempts. Latch prong at 1872' WLM & POOH with same. SUN WRKOVR RIH with plug retrieving tool. Tag plug at 1874' WLM. Unable to pull plug free. Inconsistent mechanical jar action - indications of mucklslurry in the hole. Some difficulty in jarring down to release from plug. POOH with plug retrieving tool. SUN WRKOVR RD Pollard SUN WRKOVR RD Pollard wireline PULD WRKOVR PU sump packer milling assembly - 81/2" wash pipe shoe, 1 joint of washpipe & 2 junk baskets and RIH on drill collars to 300' MD. TRIP WRKOVR RIH witth sump packer milling assembly on drill pipe to 1819' MD. Tagged TOF @ 1819' MD with 10 klbs. MILL WRKOVR Took weights, Up 60klbs, Down 60 klbs. Mill sump packer from 1819 to 1822' MD with 40 rpm @ 700-1500 ft.lbs, WOB 2-4 klbs, 328 gpm @ 290 psi. Packer fell away. CIRC WRKOVR RIH 2 stands & circulate well clean. Send brine used for milling to filtration. TRIP WRKOVR RIH with sump packer millng assembly & tag TOF at 2248' MD. Set down 20 klbs. WRKOVR POOH with sump packer milling assembly on drill pipe to 300' MD. WRKOVR I LD sump packer milling BHA. Rack drill collars. I WRKOVR I PU sump packer spear assembly & RIH on drill collars to 270' MD. WRKOVR I RIH with spear assembly on drill pipe to TOF. Tagged TOF @ 2240' I ¡MD. iWRKOVR ; Took weights, Up 61 klbs, Down 61 klbs. Attempted to engage fish. I I Unsuccessful - chased fish down hole to 4150' MD with drill pipe from i i ! the derrick. 2.00 FISH I' FISH i WRKOVR I Attempted to engage fish - chased fish down hole to 5470' MD picking I ! t up singles from pipe rack (drill pipe on fish had been laid down). 1.00 WAlTON' OTHR ! WRKOVR : Trouble shoot telecomms problems - Man on crown working on 2.50 FISH 1.25 FISH 0.50 FISH 1.25 FISH 0.50 FISH 3.00 FISH 0.50 FISH 0.50 FISH 0.50 FISH 1.25 FISH 0.25 FISH 0.50 FISH 2.50 FISH 1.50 FISH 3.50 FISH 1.50 FISH 0.50 FISH 1.00 FISH 1.50 FISH 1.00 FISH 2.00 FISH 2.50 FISH TRIP PULD I¡PULD TRIP I i ¡FISH Printed: 11/9/2005 11:42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/4/2005 20:00 - 21 :00 1.00 WAlTON OTHR WRKOVR communications antenna. 21 :00 - 21 :30 0.50 FISH FISH WRKOVR Take weights, Up 108, Down 108, 3.8 bpm @ 130 psi. Tag fish @ 5597' MD, pressure increase. Set down 30 klbs and PU. Indications of having fish - weight increase 2 klbs, pump pressure with 3.8 bpm @ 154 psi. 21 :30 - 22:45 1.25 FISH CIRC WRKOVR Circulate bottoms up @ 6 bpm. 22:45 - 23:30 0.75 FISH TRIP WRKOVR Attempt to POOH on elevators - negative, hole swabbing. MU top drive, break circulation and work pipe. Pump out of hole to 5438' MD. Increase in drag to 5440' MD. Pipe hung up at 5492' MD - worked free with 10 klbs overpull. 23:30 - 00:00 0.50 FISH TRIP WRKOVR POOH very slowly on elevators monitoring fluid level in bell nipple. No longer swabbing but hung up again @ 5325' MD. Worked free. Intermittent drag indicates junk behind fish. 10/5/2005 00:00 - 05:00 5.00 FISH TRIP WRKOVR POOH with sump packer spear assembly to 270' MD on drill pipe. Slight overpull coming through tight spot at 5030' MD - 6 klbs. 05:00 - 07:30 2.50 FISH PULD WRKOVR Racked drill collars. LD sump packer spear assembly and sump packer fish - recovered packer and tail pipe. 07:30 - 10:00 2.50 FISH PULD WRKOVR RIH with excess drill collars. POOH and LD same. 10:00 - 12:30 2.50 CMPL TN TRIP WRKOVR PU clean out assembly & RIH to 1670' MD. 12:30 - 13:00 0.50 RIGMNT RSRV WRKOVR Service top drive 13:00 - 13:30 0.50 CMPL TN TRIP WRKOVR RIH with clean out assembly to 2200' MD on drill pipe. 13:30 - 15:00 1.50 CMPL TN TRIP WRKOVR PU upper magnet, scraper and brush. 15:00 - 17:00 2.00 CMPLTN TRIP WRKOVR RIH with clean out assembly to 5030' MD on drill pipe. (Took -8 klbs drag running through tight spot at 3390' MO, string mill taking weight). 17:00 - 18:30 1.50 CMPL TN CIRC WRKOVR Clean out assembly tagged up at 5030' MD. Attempt to ream through tight spot - no success. Large quantities of formation over the shakers. Work to keep pipe free with 9 kft.lbs and 50 klbs overpull. Pipe stuck three times, 15-20 minutes to work free each time. 18:30 - 19:30 1.00 CMPLTN CIRC WRKOVR Stand back stand of drill pipe. MU top drive & circulate bottoms up at 6 1/2 bpm (to accomodate filter press - temporary reduced capacity), 20 rpm & 60' reciprocation. 19:30 - 22:00 2.50 CMPL TN TRIP WRKOVR Carry out wiper trip to 2200' MD. Bring upper magnet above rotary table and clean same (-3 Ibs of small metal shavings). See -8 klbs drag coming through tight spot at 3390' MD with string mill. 22:00 - 00:00 2.00 CMPL TN TRIP WRKOVR RIH to 4985' MD. 8klbs drag observed running string mill through tight spot at 3390' MD. 1 0/6/2005 00:00 - 00:30 0.50 CMPL TN CIRC WRKOVR Circulate bottoms up at 8 bpm, 20 rpm & reciprocating 60'. 00:30 - 00:45 0.25 CMPL TN SFTY WRKOVR Held safety meeting with personnel for pumping caustic clean-up pill. 00:45 - 01 :15 0.50 CMPL TN CIRC WRKOVR Trouble shoot MI-Swaco filter unit pump. 01 :15 - 02:00 0.75 CMPLTN CIRC WRKOVR Pump caustic wash at 8 bpm, 20 rpm & 30' reciprocation. Circulate pill to surface. Some debris on shakers with pill. 02:00 - 03:15 1.25 CMPL TN CIRC WRKOVR Circulate 1 1/2 bottoms up at 8 bpm, 20 rpm & 30' reciprocation to reduce NTUs. I NTU Out NTU in (From 02:00 at 10 min intervals) I 9 3 I 27 2 I 10 2 i I 6 1 6 1 5 1 8 1 (Displaced trip tank) 5 1 03: 15 - 05:00 1.75 CMPL TN: TRIP WRKOVR POOH to 2200' MD. Observed -8 klbs overpull when pulling string mill Printed: 11/9/2005 11 :42:55 AM Sub From - To Hours Code Code Phase 03: 15 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 09:30 Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: Date 10/6/2005 09:30 - 14:00 14:00 - 14:30 14:30 - 16:30 16:30 - 20:30 20:30 - 21 :15 21:15-21:45 21 :45 - 22:00 1017/2005 22:00 - 22:15 22:15 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :15 01 :15 - 01 :45 01 :45 - 02:00 02:00 - 02:30 102:30 - 03:00 : I 03:00 - 03:15 , 03:15 - 03:45 i : 03:45 - 04:00 104:00 - 04:45 BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Description of Operations 1.75 CMPLTN TRIP 1.00 CMPL TN TRIP 1.50 CMPL TN TRIP 1.00 CMPL TN TRIP 1.00 CMPL TN OTHR WRKOVR through tight spot at 3390' MD. WRKOVR LD upper junk basket, magnet & scraper. WRKOVR POOH to 130' MD with clean up BHA. WRKOVR LD BHA - lower junk basket, brush, magnet, string mill & junk mill. WRKOVR MU magnet on test joint. Function test all rams & hydril. Wash BOP stack. 4.50 WELCTL BOPE WRKOVR Test BOPE to 250 & 3000 psi. Cleaned out stack of metal particles & junk. 0.50 RIGMNT RSRV WRKOVR Service Top drive 2.00 CMPL TN PULD WRKOVR PU SC1 R packer and tail pipe. 4.00 CMPL TN TRIP WRKOVR RIH with SC1 R packer to tight spot at 5030' MD - did not see tight spot at 3390' MD. 0.75 CMPL TN TRIP WRKOVR Took weights, Up/Down 84 klbs. Tag up at 5030' MD. Made several 1/4 turns to the right, tag up at 5031' MD. Set down 15 klbs - no go. PU, LD single & PU stand. RIH, tag @ 5035' MD, set down 20 klbs, PU ok RIH, tag @ 5034' MD, PU ok RIH, tag @ 5034' MD, PU ok RIH, tag @ 5036' MD, PU with 10 klbs overpull RIH, tag @ 5036.5' MD, PU with 10 klbs overpull RIH, tag @ 5049' MD, PU ok RIH, tag @ 5049' MD, PU ok RIH, tag @ 5050' MD, PU ok RIH, tag @ 5050' MD, PU ok 1/4 turn to the right RIH, tag @ 5054' MD, PU ok RIH, tag @ 5054' MD, PU ok 1/4 turn to the right RIH past tight spot to end of stand at 5090' MD. No circulation through out. 0.50 CMPL TN TRIP WRKOVR RIH with SC1 R packer on drill pipe to 5351' MD. 0.25 CMPL TN TRIP WRKOVR RIH with SC1 R packer picking up drill pipe from the pipe rack to 5498' MD. Safety meeting before RU Schlumberger for packer setting correlation. RU Schlumberger Repair brake on Schlumberger unit. RIH with Schlumberger GRlCCL for packer setting correlation. Continue RIH with Schlumberger GRlCCL to 5450' MD. Perform correlation logging passes with GRlCCL. POOH with GRlCCL. RD Schlumberger Drop 1 7/16" packer setting ball & wait for ball to land. PU drill pipe 15 ft to set packer on depth. 0.50 CMPL TN PCKR WRKOVR I Set packer (top at 5469' MD drill pipe, 5466.5' WLM) by: Pressure up on drill pipe to 1900 psi, hold for 5 min, bleed to zero. Pressure up on drill pipe to 2600 psi, hold for 5 min, bleed to zero. I Pressure up on drill pipe to 3100 psi, hold for 5 min, bleed to zero. 0.25 CMPL TN! PCKR i WRKOVR PU 30 klbs & set down 30 klbs to verify packer is set. PU to neutral ~ ! weight. Turn 21 turns to the right and PU off packer - running tool free. 0.50 CMPL TN! TRIP I WRKOVR POOH wet to 4970' MD. Did not observe any overpull pulling through i ¡ tight spot at 5030' MD. 0.25 CMPL TNI PCKR I WRKOVR MU top drive. Pressure up drill pipe to 3500 psi - sheared ball seat. 0.75 CMPLTNiCIRC IWRKOVR Circulate bottoms up at 8 bpm. I I 0.25 CMPL TN SFTY 0.75 CMPLTN PCKR 0.50 CMPL TN PCKR 0.50 CMPL TN PCKR 0.50 CMPL TN PCKR 0.75 CMPL TN PCKR 0.50 CMPL TN PCKR 0.25 CMPL TN PCKR 0.50 CMPL TN PCKR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR Printed: 11/9/2005 11 :42:55 AM ConocoPhillips Alaska Operations Summary Report Page 18 of 26 Legal Well Name: BRU 224-13 Common Well Name: BRU 224-13 Event Name: WORKOVER/RECOMP Contraetor Name: Kuukpik Drilling Lie Rig Name: Kuukpik 5 Date From - To Hours Code Sub Phase Code 1 0/7/2005 04:45 - 09:00 4.25 CMPL TN TRIP WRKOVR 09:00 - 10:00 1.00 CMPL TN RURD WRKOVR 10:00 - 15:00 5.00 CMPL TN PULD WRKOVR 15:00 -16:15 1.25 CMPL TN TRIP WRKOVR 16:15 - 18:45 2.50 CMPL TN TRIP WRKOVR 18:45 - 20:15 1.50 CMPL TN PCKR WRKOVR 20:15 - 20:45 20:45 - 21 :15 0.50 CMPL TN PCKR WRKOVR 0.50 CMPL TN PCKR WRKOVR 21 :15 - 22:00 0.75 CMPL TN CIRC WRKOVR 22:00 - 00:00 2.00 CMPL TN TRIP WRKOVR 1 0/8/2005 00:00 - 01 :30 1.50 CMPL TN TRIP WRKOVR 01 :30 - 02:00 0.50 CMPL TN SUN WRKOVR 02:00 - 03:00 1.00 CMPL TN SUN WRKOVR 03:00 - 04:00 1.00 CMPL TN SUN WRKOVR 04:00 - 05:00 1.00 CMPL TN SUN WRKOVR 05:00 - 05: 15 0.25 CMPL TN SUN WRKOVR 05: 15 - 05:45 0.50 CMPL TN RURD WRKOVR 05:45 - 06: 15 0.50 CMPL TN SFTY WRKOVR 06:15 - 14:00 7.75 CMPLTN PERF WRKOVR 14:00 - 15:00 1.00 CMPLTN TRIP WRKOVR 15:00 - 16:30 1.50 CMPL TN PERF WRKOVR 16:30 - 19:00 2.50 CMPL TN TRIP WRKOVR 19:00 - 20:00 1.00 CMPL TN TRIP WRKOVR 20:00 - 22:00 2.00 CMPL TN PERF WRKOVR 22:00 - 22:30 I 22:30 - 23:00 ' 0.50 CMPL TN SFTY WRKOVR 0.50 CMPL TN PERF WRKOVR 1.00 CMPLTNiPERF ¡WRKOVR I t ¡ : 123:00 - 00:00 : Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Description of Operations POOH with SC1 R running tool. Rig up GBR to run sump packer PU snap latch, XN, nipple, tubing space out, Baker 194-60 "F" packer - sump packer - and running tool (length = 746.22') RIH with sump packer & tail pipe to 1885' MD on drill pipe. RIH with sump packer & tail pipe to 5469' MD. No sign of tight spot at 3390' MD. Took 4 klbs at 5030' MD. Took weights, Up/Down 90 klbs. Start circulation with 1 bpm & 40 psi. Tag SC1 R packer at 5469' & recorded pressure increase. Shut down pumps. Set down 20 klbs. PU & release from snap latch with 10 klbs over pull. Set down 20 klbs. Verify seting depths. Drop 1 7/16" packer setting ball & wait for ball to land. Set Baker 194-60 "F" packer at 4747' MD (drill pipe measurement): Pressure up drill pipe to 1700 psi. Pull 35 klbs overpull & set down 20 klbs to verify packer is set. PU to neutral weight. Bleed pressure to zero. Turn 15 turns to the right. Pick up - running tool free. Lost 10 klbs weight - packer & tail pipe assembly. Pressure drill pipie up to 2500 psi and shear ball seat. Circulate bottoms up at 8 bpm. POOH with sump packer setting tool to 1540' MD. POOH with sump packer setting asembly. RU Pollard slickline unit. RIH with 51/2" PXN plug and attempt to set it in XN nipple at 5456' MD - negative. POOH. Repin 5 1/2" PXN plug & RIH. Set plug in XN nipple. POOH. MU prong. RIH set prong in PXN plug. POOH. RD Pollard wireline RU to run Halliburton perforating guns. Safety I prejob meeting for running Halliburton perforating guns. MU Baker latch, 7" 14 spf Super Hole Guns, 7" & 4 5/8" Spacer Guns as per instructions. MU safety spacer & time delay pressure firing head. RIH with guns on 6 stands of drill pipe spacer. MU Below Packer Safety Joint, Below Packer Vent Device, 9 5/8" Champ Packer, Above Packer Crossover, jars & RA marker sub. RIH with guns on drill pipe to 3410' MD filling string evry 5 stands. RIH with guns on drill pipe to 4700' MD. No longer filling pipe in order to achieve required underbalance (250 psi) for perforating. Took weights, Up 79 klbs, Down 80 klbs. Tag sump packer @ 4747' MD and set plug. Rearrange stand & PU pup joint to have slick pipe through the annular preventer. PU 7 1/2 ft to perforating depth. Set champ packer with 3 turns to the right. Set down 25 klbs to verify packer is set. PU bail extensions. RU surface lines from drill pipe & pressure test to 2000 psi. Safety I pre job safety meeting for perforating Line up drill pipe to degasser. Line up kill line to pump. Fill annulus & close annular preventer. Pressure annulus up to 2000 psi to initiate firing head. Hold for 5 minutes. Pressure up annulus to 2600 psi and open below packer vent. Bleed annulus pressure to 500 psi. Guns fire - felt at surface. Flow observed from drill pipe. PU and open bypass above packer. Reverse circulate 100 bbls @ 6 bpm until clean brine is observed. Shut down pump & monitor well - ok. Open annular & pull 10 klbs overpull to release Champ packer - pipe free. Fluid level visible from rig floor - well Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: Date From - To 1 0/8/2005 23:00 - 00:00 10/9/2005 00:00 - 00:15 00:15 - 00:30 00:30 - 05:00 05:00 - 10:30 10:30 - 12:15 12:15 -12:30 12:30 - 13:45 13:45 -14:15 14:15 -15:15 15:15 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 20:45 20:45 - 22:00 22:00 - 22:15 22:15-23:15 I I : I I ¡ 23:15 - 23:30 23:30 - 00:00 : BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 H d Sub ours Co e Code Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: Phase Deseription of Operations 1.00 CMPL TN PERF WRKOVR taking fluid. Fill annulus and monitor well on trip tank while RD surface lines from drill pipe. Well taking -30 bbllhr. 0.25 CMPL TN PERF WRKOVR Continue RD surface lines while monitoring well on trip tank. 0.25 WELCTL OBSV WRKOVR Observe flow from well. MU floor safety valve & close annular preventer. Initial SIDPP 19 psi, initial SICP 60 psi. 4.50 WELCTL CIRC WRKOVR MU topdrive & circulate 4 bottoms up through choke & degasser with 8.6 KCI brine @ 3 bpm. Gas continuing to percolate into well. Shut in. Initial SIDPP 27 psi, SICP 130 psi. 5.50 WELCTL OBSV WRKOVR Shut well in and monito while weighing up brine to 8.9 ppg. While weighing up keep drill pipe full by pumping approx. 2 bbls every 10 minutes. Circulate out gas cut fluid at surface as needed. 1.75 WELCTL CIRC WRKOVR Circulate 8.9 ppg brine into the well at 3 bpm. 0.25 WELCTL OBSV WRKOVR Shut well in and monitor. Initial SIDPP 0, SICP 99. Final SIDPP 0, SICP 111. 1.25 WELCTL CIRC WRKOVR Perform 1 complete circulation @ 3 bpm with 8.9 ppg brine. 0.50 WELCTL OBSV WRKOVR Shut well in and monitor. Initial SIDPP 0, SICP 95. Final SIDPP 0, SICP 110. 1.00 WELCTL CIRC WRKOVR Perform 1 complete circulation @ 3 bpm with 8.9 ppg brine. 0.75 WELCTL OBSV WRKOVR Shut well in and monitor. Initial SIDPP 0, SICP 76. Final SIDPP 0, SICP 95 1.00 WELCTL CIRC WRKOVR Perform 1 complete circulation @ 3 bpm with 8.9 ppg brine. 1.00 WELCTL OBSV WRKOVR Shut well in and monitor. Initial SIDPP 0, SICP 78. Final SIDPP 0, SICP 144 1.00 WELCTL CIRC WRKOVR Perform 1 complete circulation @ 3 bpm with 8.9 ppg brine. 1.50 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 91 Shut well in and monitor while weighing up brine to 9.1 ppg. While weighing up keep drill pipe full by pumping brine into drill pipe every 10 minutes. Final SIDPP 0, SICP 202 0.25 WELCTL CIRC WRKOVR Pump 35 bbl down drill pipe to displace gas from under BOPs. Immediate liquid returns. 1.25 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 214 Shut well in and monitor while weighing up brine to 9.1 ppg. While weighing up keep drill pipe full by pumping brine into drill pipe every 10 minutes. Final SIDPP 0, SICP 340 0.25 WELCTL CIRC WRKOVR Pump 32 bbl down drill pipe to displace gas from under BOPs. Pumped I 19 bbl before observing liquid returns. 1.00 WELCTL OBSV IWRKOVR Initial SIDPP 0, SICP 240 I I I Shut well in and monitor while weighing up brine to 9.1 ppg. While I I weighing up keep drill pipe full by pumping brine into drill pipe every 10 I I minutes. : i I Final SIDPP 0, SICP 340 0.25 WELCTL CIRC i WRKOVR ¡ Pump 28 bbl down drill pipe to displace gas from under BOPs. Pumped : 14 bbl before observing liquid returns. 0.50 WELCTU OBSV WRKOVR I Initial SIDPP 0, SICP 230 I Shut well in and monitor while weighing up brine to 9.1 ppg. While : weighing up keep drill pipe full by pumping brine into drill pipe every 10 , minutes. Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 1 0/9/2005 23:30 - 00:00 0.50 WELCTL OBSV WRKOVR At midnight SIDPP 0, SICP 278 Total brine losses for day are 551 bbls. 1 0/1 0/2005 00:00 - 00:45 0.75 WELCTL OBSV WRKOVR At midnight SIDPP 0, SICP 278 Keep well shut in and monitor while weighing up brine to 9.1 ppg. While weighing up keep drill pipe full by pumping brine into drill pipe every 10 minutes. Final SIDPP 0, SICP 340 00:45 - 01 :00 0.25 WELCTL CIRC WRKOVR Pump 28 bbl down drill pipe to displace gas from under BOPs. Pumped 18 bbl before observing liquid returns. 01 :00 - 02:00 1.00 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 228 Keep well shut in and monitor while weighing up brine to 9.1 ppg. While weighing up keep drill pipe full by pumping brine into drill pipe every 10 minutes. Final SIDPP 0, SICP 362 02:00 - 02:15 0.25 WELCTL CIRC WRKOVR Pump 45 bbl down drill pipe to displace gas from under BOPs. Pumped 25 bbl before observing liquid returns. Lost total 34 bbl including the 25 bbl required to get liquid returns. 02:15 - 03:15 1.00 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 255 Keep well shut in and monitor while weighing up brine to 9.1 ppg. While weighing up keep drill pipe full by pumping brine into drill pipe every 10 minutes. Final SIDPP 0, SICP 337 03:15 - 05:45 2.50 WELCTL CIRC WRKOVR Pump 2 full circulations (435 bbl) with 9.1 ppg KCIICaCI2 brine @ 3 bpm & 60% returns. Pumped 15 bbl before observing liquid returns. CP dropped to 50 psi and remains contstant. 05:45 - 06:00 0.25 WELCTL OBSV WRKOVR Shut well in. SIDPP 0, SICP 47. Bleed pressure to zero through choke. Open annular & observe fluid level- level falling, then rising with gas breaking out. Shut well in on annular. Able to move pipe while observing fluid level- pipe free. 06:00 - 08:00 2.00 WELCTL OBSV WRKOVR Monitor weill on trip tank. Approx 60 bph fluid loss to formation. Mix HECpil1. 08:00 - 08:30 0.50 WELCTL CIRC WRKOVR Spot 30 bbls 2.5 ppb HEC-10 pill outside drill pipe at 3136'. 08:30 - 10:30 2.00 WELCTL OBSV WRKOVR Monitor well on trip tank. Initial losses at 60 bph. Losses slowed to 8.4 bph. 10:30 - 13:00 2.50 WELCTL CIRC WRKOVR Well started flowing. Close annular. Circulate out gas with 9.1 brine at 3 bpm. 13:00 - 13:30 0.50 WELCTL OBSV WRKOVR Montor well on trip tank. 13:30 - 15:00 1.50 WELCTL OBSV WRKOVR Pump wI annular open @ 3 bpm for 10 bbls. Noted flow increase, close annular & circ. 3 bpm. Initial Csg. pressure 58# DP 73#. Final csg. 47# DP 80#. Spot 25 bbl. HEC pill on bottom. 15:00 - 19:00 4.00 WELCTL OBSV WRKOVR Monitor losses on trip tank Decreased from 20 bph to 7 bph. 19:00 - 21 :00 2.00 WELCTL OBSV WRKOVR Circ. wI annular open @ 8 bpm-Iosses @ 8 bph. ,21 :00 - 21 :30 0.50 WELCTL OBSV WRKOVR Monitor well on trip tank-losses @ 8 bph. [21 :30 - 00:00 2.50 WELCTL: TRIP WRKOVR POH to 2340 slow. Hole taking average 10 bph. I 0.50 CMPLTN!TRIP Total brine loss for day - 550 bbls. I 10/11/2005 ~ 00:00 - 00:30 WRKOVR POH f/2340' to 2160'. Well started flowing. 100:30 - 02:00 1.50 CMPL TN CIRC WRKOVR Circ out gas cut brine through choke. Gas would not subside. i 02:00 - 06:00 4.00 wELcnJ STRP WRKOVR Strip in hole fl 2160' to 3494' while circ out gas through choke. 106:00 - 06:30 0.50 wELcnJ CIRC WRKOVR CBU through choke. Î 06:30 - 08:00 ! 1.50 WELCTU STRP WRKOVR : Strip in hole fl 3494' to 4383' while circ out gas through choke. SICP I I 181 psi. SIDPP -150 psi. I 108:00 - 08:30 : 0.50 WELCTI.J CIRC WRKOVR ' Circ out gas through choke with 9.1 brine, : 08:30 - 09:30 1.00 WELCT~ OTHR WRKOVR ' Pump out rig pits. Fill system with 9.4 brine. Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/11/2005 09:30 - 11 :00 1.50 WELCTL CIRC WRKOVR Circ well through ported sub at 2825' with 9.4 brine through choke. 11 :00 - 13:00 2.00 WELCTL OBSV WRKOVR Open well. Monitor well on trip tank. Approx 25 bph fluid loss. 13:00 - 15:00 2.00 WELCTL CIRC WRKOVR Circ. @ 3 bpm 46#. 15:00 - 16:00 1.00 WELCTL OBSV WRKOVR Monitor well 20 bph losses. 16:00 - 16:30 0.50 WELCTL CIRC WRKOVR CBU @ 5 bpm 93#. 16:30 - 17:00 0.50 WELCTL OBSV WRKOVR Monitor well 20 bph losses. 17:00 - 17:30 0.50 WELCTL CIRC WRKOVR CBU @ 5 bpm. 17:30 - 18:00 0.50 WELCTL OBSV WRKOVR Monitor well 20 bph losses. 18:00 - 18:30 0.50 WELCTL CIRC WRKOVR Spot 48 bbl. hec pill. 18:30 - 21 :00 2.50 WELCTL OBSV WRKOVR Monitor well 15 bph losses. 21 :00 - 23:30 2.50 WELCTL TRIP WRKOVR POH wI guns to 2400'. losses slowed to 5 bph. 23:30 - 00:00 0.50 WELCTL KILL WRKOVR Increase in flow noted-circ. gas out @ 5 bpm. Gas seems to be coming out of guns. Total down hole losses for today 177 bbls. 10/1 2/2005 00:00 - 00:30 0.50 CMPL TN TRIP WRKOVR Monitor well. POH with 41/2" DP from 2400' to 1971'. Gas to surface. 00:30 - 01 :45 1.25 CMPL TN CIRC WRKOVR Circ out gun gas. 01 :45 - 02:00 0.25 CMPL TN TRIP WRKOVR POH w/2 stds DP. gas to surface. RIH with 2 stds. 02:00 - 02:30 0.50 CMPL TN CIRC WRKOVR Circ out gun gas. 02:30 - 03:15 0.75 CMPLTN TRIP WRKOVR POH from 1971' to 1656'. RIH with 2 stds to 1778'. 03:15 - 04:00 0.75 CMPLTN CIRC WRKOVR Circ out gun gas. 04:00 - 06:00 2.00 CMPL TN PULD WRKOVR POH LD pkr assembly. Vent gun gas from annulus. 06:00 - 07:30 1.50 CMPL TN TRIP WRKOVR POH wI DP from 1656' to top of gus at 1186'. Vent gas on annulus each stand. 07:30 - 07:45 0.25 CMPL TN SFTY WRKOVR PJSM with all hands on LD 7" and 4" guns. 07:45 - 14:30 6.75 CMPLTN PULD WRKOVR POH LD guns. Gas breaking out at surface the entire time guns were being laid down. Monitor well. No gas. Fluid loss - 2 bph. Note: All shots fired. 14:30 - 15:00 0.50 CMPL TN PULD WRKOVR Lay down handling subs & clean floor. 15:00 - 16:00 1.00 CMPL TN PULD WRKOVR Pick up clean out assembly. 16:00 - 19:00 3.00 CMPL TN TRIP WRKOVR RIH to 4734-tight @ 3390 8k under string wt. 19:00 - 22:00 3.00 CMPL TN CIRC WRKOVR Tag fill @ 4734 pick up 5' & circ. to bring down ntu,s. (Gas to surface on bottoms up) 22:00 - 00:00 2.00 CMPLTN OTHR WRKOVR Monitor well on trip tank while cleaning filter press=losses @ approx. 7 bph. Total losses for last 24 hrs - 52 bbls 10/13/2005 00:00 - 03:30 3.50 CMPL TN CIRC WRKOVR Circ and filter brine. Final NTU - 7. 03:30 - 07:00 3.50 CMPL TN TRIP WRKOVR POH fromm 4729' to 520'. 07:00 - 08:00 1.00 CMPL TN PULD WRKOVR POH LD 16 jts 41/2" DP and BHA. 08:00 - 15:00 7.00 CMPL TN TRIP WRKOVR MU and RIH with 41/2" DP and Cavins bailer assembly to 4740'. 15:00 - 15:30 0.50 CMPL TN OTHR WRKOVR Tag @ 4740'-Attempt to latch packer plug-set down 50k. 15:30 - 21 :00 5.50 CMPLTN TRIP WRKOVR POH-Iay down bailer bha-no plug-Clean out perf debris & sand from last 2 jts. dp. Recovered 5-7 gals debris & sand-redress grapple & clean floor. 121 :00 - 00:00 3.00 CMPL TN TRIP WRKOVR Make up bailer bha #2 & rih. 10/14/2005 00:00 - 02:30 02:30 - 08:30 : 08:30 - 13:30 ¡ 13:30 - 17:30 ! 17:30 - 18:00 I I , ! 18:00 - 19:30 , 19:30 - 20:00 , Fluid loss last 24 hrs - 290 bbls 2.50 CMPL TNI TRIP IIWRKOVR RIH wI bailer from 2100 to 4747. Work bailer. No sucess. 6.00 CMPL TN¡ TRIP WRKOVR POH wI bailer & lay down tools. 5.00 CMPL TN: OTHR I¡WRKOVR Test bope to 250-3000#-pull test plug-install wear ring. 4.00 CMPL TN! TRIP I WRKOVR Make up bailer & tools-rih to 2600. 0.50 ¡ CMPL TNI SFTY I WRKOVR While making up stand-jerk chain broke striking floor hand in back-sent 'ii i him to medic & inspected all chains on drill floor. 1.50: CMPL TN: TRIP I WRKOVR : RIH from 2600 to 4744. 0.501 CMPLTNiOTHR 'WRKOVR iTag @ 4744 & work bailer-pick up plug-pull12k over. . i ' Printed: 11/9/2005 11:42:55AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/14/2005 10/15/2005 20:00 - 00:00 00:00 - 02:00 02:00 - 05:30 05:30 - 05:45 05:45 - 18:00 18:00 - 00:00 10/16/2005 00:00 - 01 :30 01 :30 - 03:00 03:00 - 03:30 03:30 - 06:30 06:30 - 07:30 07:30 - 12:30 12:30 - 14:00 14:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 10/17/2005 00:00 - 01:30 01 :30 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 11 :30 11 :30 - 17:00 17:00 - 19:45 19:45 - 20:15 20:15 - 00:00 10/18/2005 00:00 - 00:45 00:45 - 01 :00 01 :00 - 02:45 02:45 - 03:45 03:45 - 04: 15 104:15 - 05:30 I i : 05:30 - 05:45 \ 05:45 - 09:30 :09:30 -10:15 : 4.00 CMPL TN TRIP 2.00 CMPL TN PULD 3.50 CMPL TN RURD 0.25 CMPL TN SFTY 12.25 CMPLTN TRIP 6.00 CMPL TN TRIP WRKOVR POH wI bailer to 535 & lay down part of tools. WRKOVR LD Cavins bailer assembly and Baker plug assembly. WRKOVR Clear floor. Rig up GBR and screen handling equipment. WRKOVR PJSM on picking up screen assembly. WRKOVR RIH wI Baker 51/2" screens and gravel pack assembly. UP wt. 45k. WRKOVR Rig up to run 4" inner string-load pipe racks wI 4" 511 hydril-hold pjsm & run 4" inner string. WRKOVR Finish pick up and RIH wI 4" innerstring. Space out 4". WRKOVR RU and pressure 4" innerstring to 4500 psi. WRKOVR RD 4" equipment and RU 2 7/8" equipment. WRKOVR RIH w/2 7/8" innerstring. Tag up and space out. WRKOVR RU and test 4" x 27/8" to 4500 psi. WRKOVR MU pkr and triple bushing assembly. WRKOVR Attempt to test packer=no communication between annulus & dp. WRKOVR RIH wI DP to 3500=attempt to test=no communication. WRKOVR POH to 1638. WRKOVR Lay down triple string packer. WRKOVR PJSM-rig up & lay down 2 7/8" hydril 511 tbg. WRKOVR Rig up to lay down 4" inner string=trouble shooting plugged tbg. Reverse thru 4" tbg. 1.50 CMPL TN TRIP 1.50 CMPL TN DEOT 0.50 CMPL TN RURD 3.00 CMPLTN TRIP 1.00 CMPL TN DEOT 5.00 CMPL TN PULD 1.50 CMPL TN DEOT 2.00 CMPL TN TRIP 2.00 CMPL TN TRIP 1.00 CMPL TN PULD 3.00 CMPL TN PULD 2.00 CMPL TN OTHR Total fluid loss for last 24 hrs - 167 bbls WRKOVR Reverse circ 4" innerstring. WRKOVR PU and RIH w/2 7/8" innerstring. Rabbit all pipe. WRKOVR RU and test 4" x 2 7/8" annulus to 4500 psi. WRKOVR PU pkr and triple bushing assembly. WRKOVR RD GBR equipment. WRKOVR MU and RIH wI pkr assembly and 1 std DP. WRKOVR Attempt to reverse circ well with no success. WRKOVR Pressure drill pipe to 300 psi to verify ball is on seat. WRKOVR Service rig. WRKOVR RIH w/41/2" DP to 3500' MD. WRKOVR RU line for acid pickle. BJ spotted and rigged up equipment. WRKOVR RIH w/4 1/2" DP to top sump packer at 4747' MD. WRKOVR Hold prejob meeting for packer setting & acid pickle WRKOVR LD single, PU bail extensions, RU BJ floor lines. WRKOVR Continue RU BJ floor lines WRKOVR Safety meeting for packer setting operations WRKOVR Flushed BJ lines. Pressure test same to 6000 psi - ok. Set pop-off valves, annulus 2940 psi, drillpipe 4705 psi. 1.00 CMPL TN PCKR WRKOVR Set SC-2 Gravel Pack Packer at 3106' (pressure up to 1500, 2500, 3500 psi, bleeding off between). 0.50 CMPL TN GRVL WRKOVR Release from SC-2 Gravel Pack Packer with running tool assembly. ! Mark positions on drillpipe for indicating positions. 1.25 II CMPL TNi!' GRVL WRKOVR Pressure Test Standpipe against Ball in MZ tool to 5000 psi. Locate circulating positions and establish baseline pressures for circulating i: i position. Locate reverse position and establish returns. 0.251 CMPL TN: SFTY I WRKOVR : Safety Meeting for Pickle. 3.75, CMPL TN' AWSH I WRKOVR I Rig up and pump 10 BBL Xanvis high vis pill (2.25 Ibs/bbl), 10 BBL I I ¡ I CE-1 01 in brine, 500 galls of 15% HCI 21 inhibitor and 7 Ibs citric acid I ' ! i and reverse out same @ 5 BPM @ 3000 psi. Pump so CE-101 is ¡Ii within 2 BBL of end of drillpipe by following with 9.4 Brine. 0.75 I CMPL TNI RURD I WRKOVR ! Rig up surface lines for gravel pack. i! ! , ! I 1.50 CMPL TN CIRC 3.00 CMPL TN PULD 0.50 CMPL TN DEOT 1.50 CMPLTN PULD 0.50 CMPL TN RURD 0.50 CMPL TN TRIP 0.50 CMPL TN OTHR 0.50 CMPL TN DEOT 0.50 RIGMNT RSRV 2.50 CMPL TN TRIP 5.50 CMPL TN RURD 2.75 CMPL TN TRIP 0.50 CMPL TN SFTY 3.75 CMPL TN RURD 0.75 CMPL TN RURD 0.25 CMPL TN SFTY 1.75 CMPL TN RURD Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/18/2005 10:15 -10:30 10:30 - 11 :00 11 :00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 16:45 16:45 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 20: 15 20:15 - 21 :30 21 :30 - 23:00 23:00 - 00:00 10/19/2005 00:00 - 01 :00 01 :00 - 01 :30 01:30 - 02:15 02:15 - 02:30 02:30 - 03:00 03:00 - 06:30 06:30 - 07:00 07:00 - 09:30 09:30 - 10:45 10:45 -11:15 11:15 -15:00 15:00 -15:15 I 15:15-20:15 0.25 CMPL TN SFTY WRKOVR Safety Meeting for Gravel Pack. 0.50 CMPL TN RURD WRKOVR Rig up surface lines for Gravel Pack. 2.00 CMPL TN GRVL WRKOVR Attempt to set Hydraulic Set down tool 3 times unsuccessfully by pressuring up annulus to 2200 psi, 2900 psi, 3000 psi. After failure establish range for circulating position and mark pipe. 1.00 CMPL TN GRVL WRKOVR Pump High Rate Circulating Gravel Pack. Establish baseline pressures. Pumped 12,245 BBLs sand behind pipe, 60% of design. 14,343 Ibs proppant pumped total. 2100 Ibs proppant left in pipe, 1200 Ibs reversed according to densitometer. 1.00 CMPL TN TRIP WRKOVR POOH to second gravel pack position at 4373' MD. Set tool in closed position while waiting for BJ to fix equipment - pump & silo. 1.00 CMPL TN GRVL WRKOVR Monitor well while waiting on BJ to trouble shoot pump & silo problems. 0.75 CMPL TN PCKR WRKOVR Observe gas boiling in bell nipple and well flowing slightly. Set isolation packer & shut well in. SICP 50 psi, SIDPP O. 1.25 WELCTL CIRC WRKOVR Circulate out gas at 3 bpm keeping back pressure on annulus 1.00 WELCTL OBSV WRKOVR Monitor well while waiting for gravel pack prep to be completed. 1.00 CMPL TN RURD WRKOVR Move work string to packer set position to isolate drill pipe. Replace leaking 3 1/2" valve on BJ rig floor set up. 0.25 CMPL TN SFTY WRKOVR Prejob safety meeting for gravel pack with all hands. 1.25 CMPL TN GRVL WRKOVR Flush lines & pressure test BJ pumping equipment and set tubing popoff to 4660 psi. Leave annulus popoff at 2900 psi. 1.50 CMPL TN GRVL WRKOVR Attempt to set hydraulic set down tool, rig up surface lines, locate for gravel pack. 1.00 CMPL TN GRVL WRKOVR Pump High Rate Circulating Water Pack. 106% Design. 116 pounds proppant per foot perforations. 10,250 Ib behind pipe, 119251b total below surface. 3 BBL flush. 1300 Ibs proppant reversed based on densitometer. 1.00 CMPL TN GRVL WRKOVR Reverse out proppant from circulating pack 0.50 CMPL TN OBSV WRKOVR Monitor Well. Losses decrease from 1.3 BPM to 0.5 BPM in 10 minutes time. 0.75 CMPL TN PCKR WRKOVR LD chicksan, Break Headpin, and pick up to set ISO packer at 3490' with 3000 psi down the drillpipe. 0.25 CMPL TN OBSV WRKOVR Monitor well. Observe well flowing. Shut in. 0.50 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 56. Monitor pressures while preparing to pump. Final SIDPP 9, SICP 159. 3.50 WELCTL CIRC WRKOVR Circulate well at 2 bpm and circulate out gas. 0.50 WELCTL OBSV WRKOVR Open well and monitor - well dead. 2.50 CMPL TN TRIP WRKOVR Pick up above KOIV to 3091. Loss rate went from 68 BBL per hour to 0 when the flapper shut. 1.25 CMPL TN OBSV WRKOVR Monitor Well. Saw first sign of influx at 10:25. At 10:30 losses increased from to 0.5-1.5 BPM. Gained five Barrels. Shut in well. 0.50 WELCTL OBSV WRKOVR Initial SIDPP 0, SICP 51. I Monitor well while prepare to pump. I Final SIDPP 52, SICP 100. 3.75 WELCTY CIRC I WRKOVR I Attempt to circulate gas out of well at 2 BPM. Unable to reduce casing I I I pressure. Casing pressure increased during circulation to 375 psi. Shut I : I well in. 0.25 WELCTL.! OBSV !WRKOVR i Initial SIDPP 0, SICP 319. i I I Monitor pressures. I , I Final SIDPP 130, SICP 440. 5.00 WELCT~ CIRC : WRKOVR i Attempt to circulate gas out of well at 2.4 BPM. Circulating pressure ~ , maintained at 150 psi on drillpipe. Casing pressure built from 360 to ] : 390. Shut in. Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/19/2005 20:15 - 22:00 22:00 - 23:00 23:00 - 00:00 10/20/2005 00:00 - 00: 15 00:15-01:15 01:15 - 02:30 02:30 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 17:30 17:30 - 18:00 18:00 - 18:45 18:45 - 19:30 19:30 - 22:00 1.75 WELCTL OBSV WRKOVR Initial SIDPP 111 SICP 400. Monitor well. Allow gas to separate and come to circulating point/surface. Final SIDPP 328, SICP 634 1.00 WELCTL CIRC WRKOVR Circulate bottoms up while applying additional back pressure at the choke. Pumped 20.5 bbl before observing liquid returns. CP started to closely follow DPP after pumping 26 bbl. Continue circulating for complete bottoms up. Lost 25 bbls total this circulation. Shut well in. 1.00 WELCTL OBSV WRKOVR Initial SIDPP 73, SICP 110. Monitor well. Final SIDPP 64, SICP 101. 0.25 WELCTL OBSV WRKOVR Continue to monitor well. Final SIDPP 61, SICP 98 1.00 WELCTL OBSV WRKOVR Bleed annulus to 36 psi & drill pipe to 14 to see if well is dead. Shut in and monitor. Final SIDPP 94, SICP 159. SIDPP constant last 1/2 hour indicating influx above circulation point. 1.25 WELCTL CIRC WRKOVR Circulate bottoms up (from circulation point at 2510' MD) at 2 bpm. Shut in. 8.50 WELCTL OBSV WRKOVR Initial SIDPP 139, SICP 171 Monitor well while weighing up filtered brine to 9.7 ppg and cleaning out rig pits. Final SIDPP 85, SICP 194 1.00 WELCTL CIRC WRKOVR Circulate 9.7 ppg brine into well at 2 bpm from circulation point at 2510' MD. 9.7 ppg in & out. Shut in. 1.00 WELCTL OBSV WRKOVR Initial SIDPP 200, SICP 253 Monitor well while waiting for 9.4 ppg brine under circulation point to swap over with 9.7 ppg brine above. Final SIDPP 160, SICP 215 1.50 WELCTL CIRC WRKOVR Circulate swapped over 9.4 ppg brine out of annulus at 2 bpm. 9.7 ppg brine in & out. Shut in. 3.00 WELCTL STRP WRKOVR Strip in to KOIV at 3153' MD. Difficult to strip tool joints through bag. Pressure up drill pipe to 500 psi, CP . Tag KOIV with 4 klbs. Attempt to break KOIV with mule shoe - negative. Turned work string one rotation at surface to change orientation of mule shoe. RIH and break KOIV. 0.50 WELCTL OTHR WRKOVR Pressure up drill pipe to 460 psi, casing 580 psi. Tag KOIV with 4 klbs. Attempt to break KOIV with mule shoe - negative. Turned work string one rotation. RIH and break KOIV. DP & casing pressures fall to 185 & 260. 0.75 WELCTL OTHR WRKOVR Start pumping at 2 bpm with annular closed to fill drill pipe and tubing below the KOIV. Increased flow rate at 17:54 to 3 bpm as DPP decreases to 90 psi. As DPP begins to increase (indicating hole is full) decrease flow rate to maintain 180 psi on DP. Flow rate stabilised at 1 "bpm & 180 psi at 18:36. While pumping, casing pressure stabilised at 390 psi. Pumped a total of 80 bbls. Begin displacing gas from annulus by increasing pump rate to 2 bpm and manipulating choke. When reached required pump rate maintained DPP constant while circulating through the choke. Pumped 45 bbl before getting liquid returns at surface. Continue to circulate at 2 bpm & monitor returns - approximately 50% returns. Final circulating DPP 188 ! psi, casing 170 psi. Pumped a total of 93 bbl, lost 63 bbls including hole "fill up. 2.50 WELCTl! OBSV : WRKOVR : Opened choke and shut down pump. Monitor well. Opened annular - I i 0.75 WELCT1JCIRC IWRKOVR I 1 I Printed: 11/9/2005 11 :42:55 AM Legal Well Name: Common Well Name: Event Name: Contraetor Name: Rig Name: BRU 224-13 BRU 224-13 WORKOVER/RECOMP Kuukpik Drilling Lie Kuukpik 5 Start: 8/17/2005 Rig Release: Rig Number: 5 Spud Date: 9/27/1974 End: 10/23/2005 Group: 10/20/2005 19:30 - 22:00 22:00 - 22:45 22:45 - 00:00 10/21/2005 00:00 - 00:45 00:45 - 01 :00 01 :00 - 01 :45 01 :45 - 02:00 02:00 - 04:30 04:30 - 05:30 05:30 - 09:30 09:30 - 11 :00 11 :00 - 15:30 15:30 - 18:00 18:00 - 18:30 18:30 - 21 :00 21 :00 - 00:00 10/22/2005 00:00 - 01 :15 01 :15 - 02:00 02:00 - 07:00 07:00 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 16:00 16:00 - 17:30 17:30 - 19:45 19:45 - 20:15 20:15-21:15 121 :15 - 23:00 I I ! 23:00 - 23:15 ¡ 23:15 - 00:00 10/23/2005 00:00 - 06:00 06:00 - 08:30 08:30 - 11 :30 11 :30 - 12:00 2.50 WELCTL OBSV WRKOVR fluid level 20' below RKB. Fill hole and monitor on trip tank. Steady losses of approximately 40 bph. 0.75 WELCTL OBSV WRKOVR Monitor well while LD floor safety valves & bail extensions. 1.25 CMPL TN TRIP WRKOVR POOH with gravel pack work string to 2280' MD standing back drill pipe. Losses last 24 hours 454 bbl. 0.75 CMPLTN TRIP WRKOVR Continue POOH with gravel pack work string to 1610' MD standing back drill pipe. 0.25 CMPL TN OBSV WRKOVR Monitor well before pulling gravel pack work string through BOP. Losses decreased to 35 bph. LD top module of gravel pack work string. RU GBR to LD 2 7/8" & 4" gravel pack work strings. LD 2 7/8" gravel pack concentric work string. RU to LD 4" gravel pack work string. LD 4" gravel pack work string. RD GBR, clear floor of Baker handling equipment. RIH with 38 stands of drill pipe. POOH LD same. RIH with remaining 36 stands of drill pipe. POOH LD same. Service topdrive Slip & cut drill line. Continue POOH LD drill pipe. LD 1 stand drill collars. Pulled wear ring from wellhead RU GBR for running completion string. MU floor safety valve & crossover to BTC. 5.00 CMPL TN RUNT WRKOVR Run 5 1/2" BTCM completion string to 2660' MD. Removing excess pipe dope and rust from tubulars. 3.50 WAlTON PERS WRKOVR Waiting on Schlumberger hand to MU chemical injection mandrel - unable to fly out yesterday due to weather. 1.50 CMPL TN RUNT WRKOVR MU chemical injection mandrel & injection line. Run in hole to top SC-2 Baker packer at 3110' MD. 2.00 WAlTON EQIP WRKOVR Waiting on Pollard wireline. 2.00 CMPL TN SUN WRKOVR RU Pollard wireline. RIH and open CMU - sliding sleeve valve. POOH. RD Pollard. 1.50 CMPL TN SOHO WRKOVR Take weights, Up 52 klbs, down 54 klbs. Land anchor in SC-2 Baker packer at 3110' MD. PU to verify latch - ok. Shear out of PBR with 25 klbs overpull. PU to leave locator 3' above fully engaged position. Mark pipe. 2.25 CMPL TN SOHO WRKOVR MU space out pup joints. MU hanger. Pass chemical injection through same. Drain stack & land hanger. MU hold down bolts. LD landing joint. Filling pipe through tubing. 0.50 CMPL TN SUN WRKOVR RU Pollard wireline. Draining stack to guide tool string past chemical injection line on tubing hanger both in & out. RIH and close CMU - I sliding sleeve valve. POOH. Filling pipe through tubing. 1.00 CMPL TN OTHR WRKOVR Pressure test annulus to 2500 psi for 30 minutes - ok. Filling pipe . through tubing. 1.751 CMPL TN SUN I WRKOVR RU Pollard wireline. Draining stack to guide tool string past chemical i Ii! injection line on tubing hanger both in & out. RIH and open CMU - i Iii sliding sleeve valve. POOH. RD Pollard. Switch hole fill to the annulus. 0.25· CMPL TN OTHR ! WRKOVR i Drained stack & set BPV in tubing hanger. Filling pipe through annulus. 0.75! WELCTL: NUND i WRKOVR ~ Begin ND BOP stack. Brine loss last 24 hours: 715 bbls. 6.00 WELCTLJ NUND I WRKOVR i Continue ND BOP stack. 2.50 CMPL TN: NUND I WRKOVR I Work on damaged lockdown screw seal. Replace same. 3.00 CMPL TN: NUND i WRKOVR Installed tree valve & test to 3000 psi - ok. 0.50 WELCTL.: NUND ! WRKOVR I Install rotary table. I 0.75 CMPL TN TRIP 0.25 CMPL TN RURD 2.50 CMPL TN TRIP 1.00 CMPL TN RURD 4.00 CMPL TN TRIP 1.50 CMPL TN RURD 4.50 CMPL TN TRIP 2.50 CMPL TN TRIP 0.50 RIGMNT RSRV 2.50 RIGMNT RSRV 3.00 CMPL TN TRIP 1.25 CMPL TN OTHR 0.75 CMPL TN RURD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR Printed: 11/9/2005 11 :42:55 AM ·...! ).':: ::..,..:: .",....... ::.... :: .::......,.... :. ....,.:!.:..: ::< ,.......,..:/>:.,' ........ :1, ':J:: >, .......'...". ".' : :;:' ¡,} . ..:. ...:., .,:' .,..: . :::',.:,: ..:., . ¡~~~ ;~ I~~ Oi. , ...? .(::. ....::: '. .:{ ~ .I~ '~r~ I. i,:.. ::....,. ..:...,.:, .:... ,....: .,.' :,'.,'" 'y Legal Well Name: BRU 224-13 Common Well Name: BRU 224-13 Event Name: WORKOVER/RECOMP Start: Contractor Name: Kuukpik Drilling Lie Rig Release: Rig Name: Kuukpik 5 Rig Number: 5 I.:'..· ..21..' i: :,'.., .'. ': '2:>: '..i:~... :.'1·" '. ( .. .:....... :.: (i· .. ...L; I ,:.....~:ci'~.<.:: ....... ·:,.:.i~,ii!:I .~'::,i ....:.... "/:·,:;:':1_,':. :~~~+¡~L.T: ":'.,:;.:.' ':i:,:, I' 'I.J",~,... .:,:':.:.' .·.ë ,.,..,.,:, ,I' :T""" ,...,..:, "''''0 . .,:.:...: :", ..\",:. ::.', ., .... ~..:..;: 'C:, ,,:"T,"::' :.,:: ,./~~~I.' .: :'¡¡:'::::}~.':,:::U!¡ 1..\:::·','·.:: .>'''>'.:''. ":':::"··:):Y·}:::'I:·,'. ::,':,:"/:.,,..:).,,:..,>....:',,::: :.::.:':,.'.. ',. ~ 10/23/2005 12:00 - 13:30 1.50 CMPL TN SUN WRKOVR RU Pollard wireline with lubricator & pump-in sub. 13:30 - 15:30 2.00 CMPL TN CIRC WRKOVR Pump 130 bbl of corrosion inhibitor down annulus with returns through pump-in sub. 1.00 CMPL TN SUN WRKOVR RIH with Pollard and close CMU - sliding sleeve valve. POOH. Had to stop filling well through annulus in order to be able to run wireline tools in hole. 0.50 CMPL TN OTHR WRKOVR Set BPV in hanger. NO Pollard wireline. 7.00 MOVE RURO WRKOVR Start RO Kuukpik Rig 5 for move to BRU 214-26. Rig released midnight 10/23/2005. Total fluid lost on well: 9189 bbls ,'~:" ·11 '¡¡ïl~""":"':"':":' :::'.',: .....,.:. ,.....:.. (.: Pi : :.,:' : ,:i :.':'~:: .':. : ,:, ,)" ":::' ...: . .¡....., .' 'i¡;~~'/';,· '1 ',; ~~!~~ ..... !J. ¡.,.~,.. ,,< "".. :, ., . <,(j 8/17/2005 Spud Date: 9/27/1974 End: 10/23/2005 Group: 15:30 - 16:30 16:30 - 17:00 17:00 - 00:00 ¡ Printed: 11/9/2005 11 :42:55 AM Re: Beluga BOP Test ) S~i~J~ct:.J.(::~~l~~~~OP!est ..... ... '.. . . ........... .... . ... .. .. . .. .. . .. ..... . Fr~U1:: 1'1i~rµ~s:~(;t\l114eJ;~t()111....i11(;tµnder@~qm.in. state. ak. us> µ:te~æM~;2JOct~OQ513:44:01-080Q.··· ..... ... . .. ... 1'~~: ,:;E\ê~. ' r~~~ Paul, \'\ .~ - a·s '\ We just talked and you confirmed that the BOP is already equipped with the rams required for the 5-1/2" tubing. Since it will not be necessary to change rams, what you propose is acceptable. With the well consistently loosing fluid, it is unlikely that a flow could occur provided the fluid is continuously available. If difficulties are encountered running the completion, you are correct that you should contact us. Good luck with the completion. Tom Maunder, PE ~ANNED NOV 0 2 2005 AOGCC Mazzolini, Paul wrote, On 10/21/2005 9:44 AM: Tom, Kuukpik Rig #5 has just completed a multi-stage gravel pack on BRU #224-13. We have been experiencing intermittent gas bubbles and fluid losses. The brine weight has been increased from 9.4 to 9.7 ppg and has helped to stabilize the well. We have been monitoring the well and are losing about 30 bbls of fluid/hour. The gravel pack equipment has been laid down and we are in the process of laying down drill pipe to run the 5 1/2" completion and finish this well. We are scheduled for a BOP test today but would like to request that it be waived. We have been on this well since Sept 1 st and have completed 8 weeks of BOP tests. Proceeding with the above operations will allow the well to be continually monitored and allow us to have the wellwork completed late Saturday, 10/22 or early Sunday, 10/23. If the situation at the well were to change we would contact the AOGCC to have further discussion concerning the BOP test. Please contact me with your response or any questions. Regards, Paul 1 of 1 10/24/2005 9:07 AM BOPE Test Report ) ) S~;~j¢ct:B()J>ETest~eport.,.. .:'..:.........'.. ....... .. ... ...' .<i>. ..< ...... F,~~~:.·.I'Chan1bers;'¥ark.1\.." ~Þvfark.A.. Chamb~~s@S()l1Qçop~illìps~9p111:> ~a:té:F~?.22"Sep2QO$.J4:48:01...:-0800 ' . ':: ::: :"':':.:".':": : . : ~:. :." : ,}',:re .,.: 5 09 21 Content-Description: BOP-Kuukpik 5 0921 05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 10/24/2005 2:31 PM ) ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .íjm,.J~.gg@adm¡n.state..ªKus aOftQc prudhoe ..bây@ad¡TI;n,state.a.k.µs bob f;eckenste;n@gdmín.stat¡;;.ak.us Rig No.: 5 DATE: 9/21/2005 Rig Phone: 263-3652 Rig Fax: Op. Phone: 263-3651 Op. Fax: 263-3653 3/8/04 Contractor: Kuukpik Rig Rep.: OTTO/DAMBACHER Operator: Conoco/Phillips Alaska Rep.: MIKE WINFREE Field/Unit & Well No.: BRU-224-13 Location: Section: Operation: Drlg: Test: Initial: Test Pressure: Rams: 250/3000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 1 2 1 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P n/a Well Sign Dr!. Rig Hazard Sec. Size 13-5/8 2-7/8 X5-1/2 4-1 /2 13-5/8 3-1/8 3-1 /8 2-1/16 2 1/16 Alarm Test P P P P P PTD # 173-037 Township: n/a Workover: x Weekly: x Annular: 250/3000 TEST DATA Meridian: Range: Explor. : Other: Valves: 250/3000 n/a n/a Test Result P P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P I nside BOP 1 P Test Result P P P P P P P P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 FP Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1400 P 200 psi Attained 30SEC P Full Pressure Attained 2:15SEC P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2500 Test Results Number of Failures: 1 Test Time: § Hours Components tested 32 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Jim regg@admín.state.ak.us Remarks: #6 VALVE on CHOKE MANIFOLD failed, chanqed out valve, shell test t/250/3000psi. re-test #6, passed. 24 HOUR NOTICE GIVEN YES x NO Waived By JIM REGG Date 09/20/05 Time 1030am Witness OTTO/DAMBACHER Test start 1100pm Finish 500am BOP Test (for rigs) BFL 3/8/04 BOP-Kuukpik 5 09 21 05.xls BOPE Test Report ) ) · ..,...............'.......,'.....,...,....·.,.'7.,·.·.·'.·.·,......··,.7. ......... ..... ~.,....f). ...W.Î ". ... ,.. '.. ...'.,.. . .. .'. ..., . . . .. .....". . . . :. I Attached is the Initial BOP Test Report from Kuukpik 5 (09/03/05). If any other information is required please do not hesitate to contact me. Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc. 265-1319 «BOP-Kuukpik 5 09 03 05.xls» Content-Description: BOP-Kuukpik 5 09 03 05.xIs BOP-Kuukpik 509 03 05.xls: Content-Type: application/vnd.ms-excel ,. Content-Encoding: base64 1 of 1 10/24/20052:31 PM ) ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Jkn yegg@admin.state.,ak.us .qQgCG prudhoe b8y@adm;t1.state.ak.u~ bob f;ecken.ste~n@.~dmin.state.,ak.u~ Rig No.: 5 DATE: 9/3/2005 Rig Phone: 263-3652 Rig Fax: 263-3653 Op. Phone: 263-3650 Op. Fax: 263-3653 11/09/04 Contractor: Kuukpik Rig Rep.: Otto / Lynch Operator: ConocoPhillips Alaska Rep.: Mike Winfree Field/Unit & Well No.: BRU 224-13 Operation: Test: Test Pressure: Drlg: Initial: Rams: 250/3000 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 1 2 1 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13 5/8" 2-3/8" 4-1/2" 13-5/8" 3-1/8" 3-1/8" 2-1/16" 2-1/16" Alarm Test P P P P P PTD # 173-037 Workover: X Weekly: X Annular: 250/2500 TEST DATA Test Result P P P Test Result P P NT P P P P NA Explor. : Bi-Weekly Valves: 250/3000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 NT Lower Kelly 1 NT Ball Type 1 P I nside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1400 P 200 psi Attained 00:21 P Full Pressure Attained 02:59 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2450 Test Results Number of Failures: 1 Test Time: 13 Hours Components tested 25 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim regg@admír¡.state.,ak.us Remarks: Choke in flanqe failed. chanqe api rinq-retest-ok-all tests had bleed off-finallv determend that the leakaqe was in the 4 slotted tbq. Hanqer-Iower 4-1/2" rams alonq w/ upper & lower topdrive- valves will be tested when 4-1/2" work strinq is picked up. 24 HOUR NOTICE GIVEN YES x NO Date Test start BOP Test (for rigs) BFL 11/09/04 09/01/05 06:30am Time Finish Waived By Witness John Crisp 16:00pm BOP-Kuukpik 50903 05.xls [Fwd: RE: Beluga BOP Tests] ) Subject: [Fwd: RE: Beluga BOP Tests] From: Thomas Maunder <tom _ maunder@admin.state.ak.Us>,\"./ '?/ ~ 0 ? 7 Date: Tue, 13 Sep 2005 13:04:28 -0800 \, ., To: Mark Chambers <marka.chambers@conocophillips.com> CC: Bob.Fleckenstein <bob_fleckenstein@admin.state.ak.us>, AOGCC North Slope Offige <aogcc -prudhoe _ bay@admin.state.ak.us> Mark, Thanks for the reply. Please be sure that the people at the rig send in copies of the remaining tests that have been done. They should email the excel sheets to Bob Fleckenstein, Jim Regg and AOGCC North Slope as indicated on the heading of sheets. Tom Maunder, PE AOGCC -------- Original Message -------- Subject: RE: Beluga BOP Tests Date: Tue, 13 Sep 2005 10:04:47 -0800 From: Chamb e r s, Ma r k A ,:~.f:1.9.:E.~...:...!.\..~...qÞ.9.:~.e.,~E..~,~?!..~,.?~,?:,~.~,S?p.t~.~,,~..~..~.P'.~...:...~g~.~~. To: Thomas Maunder <tom maunder@admin. ~3tate. ak. us> CC : All sup - Dr ake , sha'ron""'"K"""~'f3Ea';~:(;rl"':'''K'':''ArI';~;:lli)·="Ör.:a::k·e'~~cc:m.oc oph:i.l1 i p ~:¡ " com>, Be I 1.19 a R i ve r C omp an y Man ,=:,.ª.?:.yç.~~P'.~..S?~:!:.?~.S?..P'!?:.~..~,.~~.~'p'!'?'...:".~.,s?'~,.? My apologies. I found a copy of the BOP Test Form (Excel Format) and filled it in for the 09/06 test. I have copied the rig so they can utilize this format in the future and make the appropriate notifications. Call me if you need additional information. Mark Chambers ConocoPhillips Alaska, Inc. -----Original Message----- *From: * Thomas Maunder [ma.:i.lto: tom rnaunder@admi.n" ~3tate. ak" us] *Sent:* Tuesday, September 13, 2005 9:16 AM *To:* Chambers, Mark A *Cc:* Mazzolini, Pauli Jim Regg; AOGCC North Slope Office *Subject:* Re: Beluga BOP Tests Paul and Mark, We had talked with regard to the message below and the early BOP tests on the Beluga workover program. After checking over here, it does not appear that any copies of BOP tests have been submitted from the rig. The testing time requirement for workovers is 7 days. Based on your message, the last test conducted was on 9/6 however we do not have any information to validate this. Regardless of an Inspector being present, normal practice if for a copy of all BOP tests to be submitted by the rig. Email addresses are provided at the top of the test form. Please have the rig submit copies of the tests performed (in the normal excel format). Although you did send a copy of the September 5 report, we cannot import the information from pdf. Please make sure that the rig personnel, both contractor and company, are aware of the need to timely submit testing reports. Call or message with any questions. Tom Maunder, PE AOGCC Chambers, Mark A wrote, On 9/9/2005 3:41 PM: lof2 10/24/2005 9:22 AM [Fwd: RE: Beluga BOP Tests] " Tom: Good afternoon. I spoke w/ Paul Mazzolini and he said you requested some information on the BOP testing at Beluga. As you know, on 09/03/05 we did our initial BOP test and then pulled our 2-3/8" Heater String. On 09/05/05 we changed our 2-3/8" Upper Pipe Rams to a 2-7/8" x 5-1/2" Variable Bore Ram (VBR) and tested the VBR to 1500 psi against the Blind Rams (Tests were witnessed by John Crisp). We continued with our fishing operations until we were in position to re-test the entire BOP. On 09/06/05 we re-tested the BOP (including the 4-1/2" Lower Pipe Rams) to 3000 psi utilizing a test plug. Unfortunately we failed to notify the AOGCC prior to this last test. I have attached a copy of the results for your review. If you need any further information please do not hesitate to call. Thank you. Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc. 907-345-8112 «BOP Test 09 06 05.pdf» BOP-Kuukpik 5 09 06 Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 10/24/2005 9:22 AM ) ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: j¡rD reg.g@admín.state.a~.u$ ,a QgCC:. prudhoe bay@adm;n.stat~..ak.us bob f;ecken.ste~n@admín.state.ak.us Rig No.: 5 DATE: 9/6/2005 Rig Phone: 263-3652 Rig Fax: 263-3653 Op. Phone: 263-3650 Op. Fax: 263-3653 11/09/04 Contractor: Kuukpik Rig Rep.: Otto / Lynch Operator: ConocoPhillips Alaska Rep.: Heim / Hadden Field/Unit & Well No.: BRU 224·13 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 1 2 1 Operation: Test: Test Pressure: Annular Preventer Pipe Rams. Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Drlg: Initial: Rams: 250/3000 Well Sign Dr!. Rig Hazard Sec. Size 13 5/8" 2-7/8"x5-1/2" 4-1/2" 13-5/8" 3-1/8" 3-1/8" 2-1/16" 2-1/16" MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Alarm Test P P P P P PTD # 305-214 ;13-D37 Workover: X Weekly: X Annular: 250/3000 TEST DATA Explor. : Bi-Weekly Valves: 250-3000 Test Result P P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 FP Test Result P P P P P P P P CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1400 P 200 psi Attained 00:31 P Full Pressure Attained 02:15 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2450 Test Results Number of Failures: Q Test Time: 12.00 Hours Components tested 31 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: j¡m re.gg@admín.state.ak.us Remarks: Dart Valve failed, repaired and re-tested BOP Test (for rigs) BFL 11/09/04 24 HOUR NOTICE GIVEN YES NO X Waived By Date 09/05/05 Time Witness Lynch Test start 7:00pm Finish 7:00am BOP-Kuukpik 5 09 06 05.xls Beluga NU / Test Procedure ) Tom: Attached is a revised procedure for your review. Apparently Kuukpik has tested the blinds from above and they will hold to +/- 2500 psi. With this in mind I have reviewed our MASP requirements, prior to perforating any new intervals, and modified our procedure accordingly. Please review our plan and let me know if this meets with your approval. I will be in Beluga today but I will be checking my messages and will call you back if there are any questions. Thanks, Mark Chambers Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1319 «NU Test BOP Procedure AOGCC.doc» .. NU Test BOP Procedure Content-Descnptlon: AOGCC.doc Test BOP Procedure AOGCC.doc Content- Type: Content-Encoding: application/msword base64 I of 1 10/24/2005 9:42 AM ) BRU 224-13 Initial NU I Test Procedure Formation Pressure: Formation Perforations (Existing) Sterling 3355' - 3361' 3376' - 3396' 3422' - 3431' 3435' - 3482' Beluga 4446' - 4456' 4476' - 4490' 4593' - 4603' 4676' - 4694' 4764' - 4774' 4916' - 4924' 4936' - 4958' 4966' - 4986' 5022' - 5032' 5050' - 5086' 5398' - 5448' 5494' - 5516' MASP Calculations (Full Column of Gas): MASP = FPP - (0.11 x D) BHP = Bottom Hole Pressure D = True Vertical Depth to Top Perforation 0.11 = Gas Gradient MASP = 1520 psi - (0.11 x 4446') = 1031 psi Perforations (Proposed) 4138' - 4148' 4157' - 4170' 4297' - 4303' 4446' - 4456' 4476' - 4490' 4593' - 4603' 4676' - 4694' 4767' - 4777' 4916' - 4924' 4936' - 4958' 4966' - 4986' 5022' - 5032' 5047' - 5087' 5398' - 5448' 5494' - 5516' 5621' - 5644' Without addinq any New Perforations, worst case MASP is estimated at 1031 psi. Bottom Hole Pressure (PSI) 1000 1520 ,) ) Proposed NU I Test BOPE Procedure: Annular Double Gate Blind Rams (Bottom) and 2-3/8" Pipe Rams (Top) Mud Cross Single Gate 4-1/2" Pipe Rams Kill well, install BPV's in all three strings. ND Tree, install Test Darts into BPV's, NU (13-5/8", 5K) BOP. Test the Blind Rams (3000 psi). Install a 2-3/8" Test Joint, with a Doughnut, just below the 2-3/8" Pipe Rams. Unable to MU 2-3/8" Test Joint into Heater String with Test Dart in Place. Unable to set a Test Plug until Parent Hanger is removed. Test the 2-3/8" Pipe Rams and Annular (3000 psi). Do not test the 4-1/2" Lower Pipe Rams at this time. The lower ram is not required by AOGCC and we will not be able to use the lower rams until the parent hanger is removed. POOH and LD the 2-3/8" tubing. Plan to use a joint of 2-7/8" tubing with a 2-3/8" XO to pull the 2-3/8" heater string to the rig floor. Change the Upper Pipe Rams to 2-7/8" x 5-1/2" Variable Bore Rams (VBR's). Close the Blind Rams. Install a 2-7/8" Test Joint, with a Doughnut, just below the VBR's. Test the VBR's against the Blind Rams (1500 psi). MASP indicates a 3000 psi test is not required at this time. However, the entire BOP needs to be tested to 3000 psi prior to performing our planned, 3000 psi, casing test and prior to adding any New Perforations. If the Blind Rams will not hold a 1500 psi test from above, plan to PU 4 joints of 2-3/8" Tubing and the 2-3/8" Mandrel Hanger w/ 2-way check installed. RIH, re-Iand the 2-3/8" Mandrel Hanger into the Parent Hanger and attempt to test VBR's. Note: During the next weekly BOP test, plan to test the entire stack, including the 4-1/2" Lower Pipe Rams to 3000 psi. The Parent Hanger should be out of the way so a Test Plug can be utilized. [Fwd: [Fwd: Re: Beluga Workover - NU/Test Procedure]] ) ,) S~þj.e~t:.. ·[F~d:.'E~~d~...~e:..B.~lugawor~o"er..-. N1J/Test.Procedµr~]] Er~m;. ...1~.~111a~....JY{a~r~7f..?t0l11~tnaunder@adnïill.·state·:.åk.u$>. :I:)ª~e:T~~~ 25f\.~~,fQQ5 }~~ 36 :9:I.:~,Ç~9g>,>; ..1...... ... 1""::'" ',....",. ·1· ...' .",,, ..,'......, '1··.." '.."..j)fj...:','...'..' ."",'..",... \t: ',. ~~n~;" :¡~!,.. .':~,~~l~ç~n,~:: Ma z z , I just got off the phone from talking with Mark. He mentioned that he would be talking about this with you. Tom -------- Original Message -------- Subject: Re: Beluga Workover - NU/Test Procedure Date: Thu, 25 Aug 2005 13:07:18 -0800 From: Thomas Maunder <tom maunder@admin.state.ak.us> Organization: State of Alaska To: Chambers, Mark A <.Mark. A. Charnbers@conocophJl1 :i..p~~ . com> References: <:147B02856E10584086F2AC26557A8D38BAD53C@ancexmb1.conoco.net:> ..................................................................................................................................................................................................................................................................................................................."........................................................... Mark, Quite a complicated plan to allow coverage on all the various strings. The one thing that jumped out at me is the plan to test the upper rams against the top of the blind rams. Is that a normal process?? I seem to remember something about the ability of rams to hold in certain directions. When you test your blind rams, the 4-1/2" cavity/block and breaks will be tested. Are you trying to avoid repressuring against the BPVs and darts?? What is your test pressure?? Your wellhead pressure should be "fairly" low. Torn Chambers, Mark A wrote, On 8/25/2005 11:01 AM: Tom: Attached is a procedure we worked up for the 1st Beluga Workover. Since the well is a bit unusual we would appreciate it if you review our plan and make sure it looks ok before we proceed. If you have any questions please give me a call so we can discuss. Thanks. Mark Chambers Sr. Drilling Engineer ConocoPhillips Alaska, Inc. «NU Test BOP Procedure AOGCC.doc» «2 7-8 X 2 3-8 TEST DONUT.xls» 1 of 1 1 0/24/2005 9:22 AM Kuupik 5 @ Beluga ) ) PíÐ.ß:-J73-()?7 .. . "' .. $~þje¢t:·I<:u1+pìk:...~.($I3~lµg~·.· . . .'. . .... ........................ .................................. . ~~Pnl:··.I.1 Jeff.B.·....·J?~es."....1.~ffjones.@~~min.;..ståte;AA..µ;s? J?~~~:..·..~ul1, ··.()9·qp~·.t.9q3.9?:()9:g8··.··.~2§99.......·....,.....,. Î!I:!~.·~;!;'~gi:.~.I~m~~' ·:ªçg,~ij]~i$~ª~~~~ Hi Jim, Don Lutrick (CPAI) called from Kuupik 5 at Beluga to notify us that after perforating last night they were seeing some gas while circulating and so were raising mud weight from 8.6 ppg to 8.9 ppg. Thank s , Jeff ~NEO NO" .~, 7 2005 1 of 1 10/10/2005 8:16 AM .) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Hm Jeg_g@admín_state.ak.us aQg_Qº-"'prudhoe bay@adm;n.state.ak.u$ bob f;eckensìe~n@admín_state.ak.us Rig No.: 5 DATE: 9/14/2005 Rig Phone: 263-3652 Rig Fax: 263-3653 Op. Phone: 263-3650 Op. Fax: 263-3653 11/09/04 Contractor: Kuukpik Rig Rep.: Lynch / Dambacher Operator: ConocoPhillips Alaska Rep.: Heim / Hayden Field/Unit & Well No.: BRU 224-13 Operation: Test: Test Pressure: Drlg: Initial: Rams: 250/3000 Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P Well Sign Dr!. Rig Hazard Sec. Size 13 5/8" 2-7/8"x5-1/2" 4-1/2" 13-5/8" 3-1/8" 3-1/8" 2-1/16" 2-1/16" Alarm Test P P P p P ) PTD # 173-037 Workover: X Weekly: X Annular: 250/3000 TEST DATA Test Result p p p Test Result p p p p p p p p Explor.: Bi-Weekly Valves: 250-3000 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P I nside BOP 1 p CHOKE MANIFOLD: Quantity Test Result No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 p ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2950 P Pressure After Closure 1350 P 200 psi Attained 0:26 P Full Pressure Attained 2:25 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 2450 Test Results Number of Failures: 1 Test Time: Z Hours Components tested 31 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim regg@admín_state.ak.us Remarks: #5 VALVE on choke manifold failed. qreased valve & re-tested/ passed MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 1 2 1 24 HOUR NOTICE GIVEN YES X NO Date Test start BOP Test (for rigs) BFL 11/09/04 09/13/05 5:00pm Time Finish Waived By Jim Regg Witness Lynch/Dambacher 12:00am ·::;;C/\Nl\'E' .s E? ~.,~!. Ci l.I~¡ BOP-Kuukpik 5 09-14-05-1.xls ') ') s~þj-eçt:<~:7~5/8":\yaslli~lpe......... . ............. ... . ... ...... ........... ......... .... ............... ..... ....... .... ............. ]f~.~JIl:..·..."ehan1þers,.·:~~f~...A'I·.···4~~l<·.A..cp~.~l11ge;s®~orºc~p~illíps.:·p.~h1<··· ;:i~ij~~,~q~~~~~~~;*~;*!";··;··i?. ;.,:...., '..0· . '~. . ..:".. . :.. :. ",,::.: . . . .":" ....:. ........ Thank you, J~J-\- \ ~ \,\~-C) S ~ -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Monday, August 22, 2005 7:47 AM To: Chambers, Mark A Cc: Lutrick, Donald C; Mazzolini, Paul Subject: Re: 7-5/8" Wash Pipe Mark, et al: Your understanding and contingency plans are as we had discussed during the latter part of the week. Good luck with the work overs. Tom Maunder, PE AOGCC Chambers, Mark A wrote, On 8/20/2005 2:02 PM: .SGANNED AUG 2 2 ~~005 Tom: As we discussed, we plan to utilize 7-5/8" wash pipe on the upcoming Beluga Workovers and may be required to PU as much as 400' at one time. We consider this a BHA and do not plan to add 7-5/8" rams to our stack for this event. Our plan is to MU a crossover on the bottom of a stand of drill pipe and stand it back in the derrick. In a well control event we would PU the stand from the derrick, MU the stand to the wash pipe utilizing the crossover and RIH below the BOP. We would then MU the TIW valve. If you have any questions please feel free to contact me at any of the numbers below. Regards, Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc 907-265-1319 Office 907 -240-5868 Cell 907 -345-8112 Home 1 of 1 8/22/2005 11:47 AM Re: BRU 212-24 abandon heater string ) sù~ject:~~:~~tr212~~4.abanFR~Featerstrirg.. ... .... FfRltt:Tl1otµa.~~(lull~er'ftom _1I1aun4er@achriip..stªt~.ål(.lÌs:> B~!~:Iu~~16Â;tlg20059~:~7::~?~0800·. . .............................................. ....... .... ........ ..... 1¡~i~:i"~Ðt ølm;~~:~· .':~~Î~~~t~ì?~:.:~;8m~::J Good moves. \'L~-O)l Braden, John C wrote, On 8/16/2005 8:10 AM: ~ ,_ Tom- e 214-26 is plannìng on a SSV and SSSV because of the proximity to the compresso . 224-13 ha a SSV in the plan. John Braden -----Original Message-----Sc:ß~NNEr) {1 ,. G) '" ì: From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] \ . -- ,1UG t: ?J ¿OLb Sent: Friday, August 05, 2005 11:02 AM To: Braden, John C Subject: Re: BRU 212-24 abandon heater string Not a problem. I saw from the proposed workovers that those well will only have 1 larger tubing string installed. are there SSVs "on" the production strings?? I presume so if you had them on the heater strings. As I noted, there is no regulatory requirement to have SSVs, but operationally I think we both can agree that having them makes sense. Tom Braden, John C wrote, On 8/5/2005 10:53 AM: Yes, the manual valves will still be in service. We are removing (abandoning) all surface piping from the heater string, no changes to the tree or below. I just wanted to double-check. Thanks, John Braden -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Friday, August 05, 2005 9:55 AM To: Braden, John C Subject: Re: BRU 212-24 abandon heater string John, There have not been any rules issued that require SSVs in BRU. What do you mean by "abandoning"?? Are you just removing it from service?? I presume that manual valves will be in place to allow access ifneeded. Tom Maunder, PE AOGCC Braden, John C wrote, On 8/5/2005 9:46 AM: lof2 8/22/2005 1: 13 PM Re: BRU 212-24 abandon heater string ) ) Tom- We are abandoning selected heater strings at Beluga River Unit because many wells are below the hydrate point. 212-24 has a surface safety valve attached to the heater string. We are not planning on using it for annular flow. Do we need to notify AOGCC before removing the SSV? Sincerely, John Braden ConocoPhillips Alaska (907) 263-4536 20f2 8/22/2005 1: 13 PM ¡1flì ~ ,11[1 ru ' I l ,I '~!i ) 1/8,», tn )8" 1 Cn,L) m¡ i,l f£'ßi '\ ¡ ni' \, ~" i r i " fl, \ l i" I'~ \ !, '\ " I ' ~ I', [II, / ,\' Iru:,1 " ~, U""'~,/I ' i / \ L..=.ìJ" 1.", I' \:J¡ U \U ) I ¡, FRANK H. MURKOWSKI, GOVERNOR , AlASKA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini CI Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 i 7 ?/,,--(;)?J.'J Re: Beluga River 224-13 Sundry Number: 305-214 SCAi\1NED .l\UG 0 8 2.005 Dear Mr. Mazzolini: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 oliday or weekend. A person may not appeal a Commission decision 0 uperior Court unless rehearing has been requested. \ Encl. cp.:¡. 8 ~2d)5' ~ STATE OF ALASKA ) RECEIVED 5rt) ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 02 Z005 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D ) 1. Type of Request: D D D Suspend D o o Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 104' Pull Tubing 8. Property Designation: ADL 58831 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 10000' 10000' 5670' Casing Length Size Structu ral Conductor Surface Intermediate Production Perforation Depth TVD (ft): 3355'-5516' August 15, 2005 Date: Signature Perforate r:1 ^lasJæ Q-jl Be G,e~ C-r.n....~ Commission ~ Wtñ'Chor~ Other D D Time Extension [j- Stimulate Re-enter Suspended Well D 4. Current Well Class: Development 0 Stratigraphic D 5. Permit to Drill Nymber: 73-037 ,./ 6. API Number: / 50-283-20042-00 V 9. Well Name and Number: BRU 224-13 Exploratory D Service D 30" 65' 20" 423' 13-3/8" 3298' 9-5/8" 6999' Perforation Depth MD (ft): 3355'-5516' Packers and SSSV Type: Baker 'AL-5' pkr, Baker 'HB' pkr, Baker 'DB' pkr no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Paul Mazzolini ?Cù-JJ'1~ 10. Field/Pool(s): Beluga River Unit PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 5670' 5660' MD TVD 65' 423' 3298' 6999' Tubing Size: 2-3/8" /2-7/8" /2-7/8" Packers and SSSV MD (ft) pkrs set @ 3110', 3735', 3805' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil D Gas 0 WAG D GINJ D Contact: Title: Phone: 263-4603 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test¥ Mechanical Integrity Test D Location Clearance D Other: -:}CJC:ú~C;.. ~\~\""~'~ ~OV .~\ r Approved : Form 10403 Revised 11/2004 ~ Junk (measured): 5577',5654' Burst Collapse Tubing Grade: N-80 Tubing MD (ft): ~199'/3134' /5489' Service D Plugged D WINJ D Abandoned D WDSPL D Mark Chambers @ 265-1319 CI Team Leader Date C> 8/0 i / U;lC15 Sundry Number: .søS;--;J, 'f RBDMS BFL AUG 0 4 2005 COMMISSIONER {'î ¡ (""~, ; ¡ ¡ f t -"I. I' .......' ;: ."j' t APPROVED BY THE COMMISSION Date 1z/ð( Submit in Duplicate ) ) ConocoPhillips BRU 224-13 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RU Slick Line Unit. RIH through 2-7/8" Short String and tag TOF. 2. Remove flow line, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Workover Rig. 2. Load pits with 6% KCL, Filtered, Kill Weight Brine (8.5 PPG). 3. Kill well with 6% KCL Filtered Brine. Ensure well is dead. Set BPV's. 4. ND tree. NU 13-3/8", 5M, BOPE with VB rams. Test BOPE. Pull 2-7/8" Long String BPV. 5. RU Slick Line Unit. RIH through 2-7/8" Long String. Pull tubing patch and tag TOF. 6. RU E-line Unit. RIH through 2-7/8" Long String. Make tubing cuts w/ Jet Cutter as outlined below: Cut @ +/- 5150' (Above Tubing Perforations) Cut @ +/- 3750' (Top of 1st Full Joint below Baker Model 'HB' Packer) Cut @ +/- 3320' (Top of 1st Full Joint below Shear Out Safety Joint) Note: Actual location of tubing cuts may vary depending on TOF 7. Pull BPV from 2-3/8" Heater String and 2-7/8" Short String. 8. PU landing joint. Screw into 2-3/8" Heater String. POOH. 9. PU landing joint. Screw into 2-7/8" Short String. Shear safety joint above Baker Model 'AL-5' Dual Packer. POOH. 10. PU landing joint. Screw into 2-7/8" Long String. Release Baker Model 'AL-5' Dual Packer. POOH with the following. Long String from surface to tubing cut at +/- 3320' Short String from Safety Joint to Wire Line Entry Guide Baker Model 'AL-5' Packer Assembly 11. RIH with 7-5/8" Wash Pipe and clean out to top of Baker Model 'HB Retrievable Packer. 12. RIH with Overshot. Latch onto 2-7/8" tubing stub. Release Baker Model 'HB' Packer. POOH with the following: Tubing stub from tubing cut at +/- 3320' to packer Baker Model 'HB' Packer Tubing stub from packer to tubing cut at +/- 3750' Mark A. Chambers Page 1 7/27/2005 ) ) 13. RIH with Overshot. Latch onto 2-7/8" tubing stub. Jar seals free. POOH with the following: Tubing stub from tubing cut at +/- 3750' to seal assembly. 14. RIH with Packer Mill. Mill up Baker Model 'DB' Permanent Packer. 15. RIH with Spear. Latch into Baker Model 'DB' Permanent Packer. POOH with the following: Baker Model 'DB' Permanent Packer Tubing stub from packer to tubing cut at +/- 5150' 16. RIH with 8-1/2" Spiral String Mill to tubing stub at +/- 5150' (potentially damaged / collapsed casing @ +/- 5030') '\ 17. RIH with 7-5/8" Wash Pipe and Rolling Dog. Wash over and latch onto 2-7/8" tubing stub. POOH with the following: Tubing stub from tubing cut at +/- 5150' to shear out sub at +/- 5488'. 18. RIH with 7-5/8" Wash Pipe and Rolling Dog. Wash over and latch onto FISH (5" x 20' Casing Gun). POOH with Fish. 19. RIH with 8-1/2" Junk Mill and cleanout to top of Fish (6-1/2" Junk Mill and XO SUB) at +/- 5654' or as deep as possible for future perforations. POOH. 20. RIH with clean out BHA (Casing Scrappers, Brushes, Magnets, Junk Baskets, Etc). Pump Acid / Pickle. POOH. 21. RU E-line Unit. RIH and log well as required. 22. RIH with RTTS Tool and test 9-5/8" casing above proposed top Gravel Pack Packer location (+/- 3100' MD). POOH 23. RIH with Baker Model 'FB-1' Sump Packer and Lower Tubing Tail. Log on depth and set Sump Packer. POOH. 24. RIH with TCP Guns and Packer Plug. Set Packer Plug. Perforate as required. POOH. 25. RIH with clean out BHA (Spiral String Mill, Junk Baskets, Etc). POOH. 26. RIH with Bailer. Clean-up debris on top of packer. Pull Packer Plug. POOH 27. RIH with Multi Zone Gravel Pack Completion Equipment (as per attached schematic). 28. Latch into Sump Packer. Perform Gravel Pack as required. POOH 29. RIH with 5-1/2" Completion Assembly (as per attached schematic). , 3D. Latch into top Baker Model 'SC-2' Packer. PU and Shear PBR. Space out with tubing pups and land tubing hanger. 31. Pressure test 5-1/2" x 9-5/8" annulus. 32. NO / NU and test. 33. RDMO Mark A. Chambers Page 2 7/27/2005 MD Scale .44 3,007 3,051 3,096 3,140 3,184 3,229 3,273 3,317 3,3621 3,4061 3,450¡ 3,495 i 3,539 3,583 3,628 " b 3,672 I 3,716 3,761 3,805 3,881 3,957 4,032 4,108 4,184 4,260 4,336 4,412 4,487 4,563 4,639 4,715 4,791 4,867 4,942 5,018 5,094 5,170 5,246 5,322 5,397 5,473 5,549 5,625 5,701 5,777 5,852 5,928 6,004 6,080 6,156 6,232 6,307 6,383 6,459 6,535 6,611 6,687 6,762 6,838 6,914 75.8 a HA ¿¿ 2w Ib J~2X , .,' ",7? lc --X ~ l. .d:J].y,z '- 1d le,f 19 1h ~J 11 ~ ""'5Z""" C li 1k ......... ~ lJ. , ~ G ~ "\._~,,-é) r ':' m~~'\) CL ~ ~ '\.\.0- ~ 1L c-þV'- ,}!. 5660'...I,~ 1m,n 5800' 6000' 6106' 6145' -~ 6375' - > œ .~~o FC .~: A ) Conocó'Phillips ~ Gas Producer Dual Compo + Annular Flow Sect. 13, T13N, Rl0W, SW 1/4 ASP @ Beluga: 2,636,609; 325,576 CASING & TUBING ~ Description OD Surface Csg. 20" Intermediate 13 3/8" Prod. Casing 9 5/8 Prod. Casing 9 5/8 Open Hole Prod. Tbg (Htr) Prod. Tbg. 2 Prod. Tbg. 1 Str. Lbl. HA 2w 2x ID 1.751" 2.406" OD 2.719" 3.687" ) BRU 224-13 API# 50-283-20042-00 Annulus Fluid: Gas Max Hole Angle: 2.0 @ 9,695' RKB to Ground: 25.' RKB to SL: 94.' Spud Date 11/20/74 Last Completion 12/3/88 Schematic Rev. 9/22/04 by JDB Hole Size 26" 17 1/2" 12 1/4" 12 1/4" 81/2" Weiaht 94. # 61#/65# 43.5 # 47. # ~z Btm. 423' 3,298' 2,151' 6,999' 10,000' 2,199' 3,134' 5,489' Grade H-40 K-55 P-110 P-llO/N-80 Thread Buttress Buttress Buttress 8rd L T&C Cement 660sx "G". 2010sx "G". Rtns to surface 850sx @shoe, bump plug 500sx @ 3827' collar 295sx "G" A 2 3/8" 2 7/8" 2 7/8" t 4.3 #" \J-80 EUE-8rd 6.5 # N-80 EUE-8rd 6.5 # N-80 EUE-8rd JEWELRY & FISH "X" Nipple, Otis "X" Shear out safety jt, Baker wi 40k# pull release GLM IMandrel, Merla 2-7/8"x1" 'TBPD' wi 28/64" CV BK-2 Latch 12/1/88 3,132' "XN" Nipple, Otis 1.29' 3,134' Wireline Entry Guide, Baker 0.66' Gray Tubing Hanger 2.60' 3,072' GLM IMandrel, Merla 2-7/8"x1" 'TBPD' 6.76' wi Dummy Vlv, BK Latch closed 12/14/96 1 c 3,110' Pkr Packer, Baker 'AL-5' Dual wi 40k# pull release 14.84' 2.406" 8.50" ----Td-------3~3Õg;------------Siiëãr-õüfšã¡ëtÿ-Jf;-Bãkë¡:-wï4Õ¡¿¥puii¡.ëlëãsë------2~5(ji-------2~4Ö6i------j:6ä7i,---· 1 e 3,343' BlastJoints 161.' 2.375" 3.75" 1 f 3348'wlm Patch IDaniels: G-5top, packoff ass., 12' spacer pipe, 38.' 1.10" 2.50" packoff ass., A-Slip stop set 5/4/2004 Re-set 9/16/04 3372'wlm LEAK Hole in tubing PATCHED (see above) 3,627' GLM Mandrel, Merla 2-7/8"x1" 'TBPD' 6.79' wi 1" DV, BK-2 Latch, FULLY in pocket 9/15/04 3,696' GLM Mandrel, Merla 2-7/8"x1" 'TBPD' 6.76' wi Dummy Vlv. BK-2 Latch FULLY in pocket 9/15/04 _____!_L___mJl?_~~~_____f~!___~~s!5.~~!._~~_~~!_~~_ª~!!'l~.:_~~~!.~t.:_~L~Q~~_[>~I!_Q!_____2:.º?~_________~~f!.'~_______ª~?§.!~'___ _____!_L_______~l~_q~~_____f~!___~~s!5.~~!._~_~~!_~º_ª~~~~.:_~L~~:.~§.:~?~_~~~I_~_~~_____~:.~~_________~~?~'~_______ª~g~~'___, 1 k 3,844' '')('' Nipple, Otis 1.32' 2.313" 1 L 5183'-5202' TBG PERFs - could not get WL below sand bridge @ 5430'. 9/15/04 1 m 5,456' "XN" Nipple, Otis 1.30' 2.25" 1 n 5,488' Shear out sub, Brown 0.66' 2 5,577' FISH Perf gun 11/18/88 20.' 1 5,654' FISH 6.5" junk mill & X-over 11/12/88 Pressure Datum: Sterling 3450' SS: 3,545'MD Beluga 4000' S5: 4,095'MD PERFORA TIONS, FILL & PLUGS Net Zone IQQ Btm. Status Date SPF Ft. WSO 3,322' 3,322' Perfd for squeeze & Tested 12/74 4 A 3,355' 3,482' Orig 4 SPF, RWO Reperf 11/88 12 85' WSO 3,525' 3,525' Perfd for squeeze & Tested 12/74 4 _~?.º____~~§~º~_______~~§~~~____J:~!f~_!9!..~_q~!_~~~g~~_~_T~~!~~______________________________m___m_!?l.?.~______.:!_________. C 3,755' 3,760' DST #8, Squeezed 12/74 4 E 4,139' 4,149' Potential Gas Behind Pipe Not Perf'd E 4,157' 4,170' Potential Gas Behind Pipe Not Perf'd E 4,297' 4,304' Potential Gas Behind Pipe Not Perf'd F 4,446' 4,774' Open, String 1 11/88 G 4,916' 5,086' Open, String 1 11/88 TBG 5183' 5189' Tubing Perforations 09/04 TBG 5196' 5202' Tubing Perforations 09/04 H 5,398' 5,516' DST #6, Orig 4 SPF 11/88 PLUG 5,660' BP set at 5660' in 1981 completion H 5,681' 5,758' DST #5, Squeezed I 5,820' 5,848' DST #4, set BP at 5800' I 6,026' 6,076' DST #3, set BP at 6000' I 6,117' 6,145' DST #2, set BP at 6145 & 6106' I 6,422' 6,470' DST #lA, set BP at 6375' FC 6,914' Cement PBTD to 6755' Nov 1974 # :4GS Str 2 9/18/03 3393'RKB unknown StL1 9/24/03 5575'CTM CTU FCO sqz Top 2,165' 3,007' 3,041' Length 0.85' 2.50' 6.79' sqz - 2 Y 2 z All a 1 b 2.25" 2.44" 2.41" 3.668" !] F F F 1 g 1 h m 6.50" 11 I I !] 12 12 4 4 12 62' 96' 6' 6' 72' 12/74 11/74 11/74 11/74 11/74 4 4 4 4 4 Run TDT-P. Find gas in F sands 4476-4694'. Stick PX plug @ 3844' when sand falls in from str. 2. SI in str 1. Find hole in tbg & GLV @3627' is partially out. Cmt hole, push GLV aside, fish PX plug, au FCO to 5575' in str. 1. Set tubing patch in blast joints at 3348'WLM in string 1. Pulled TBG Patch @3348'wlm to clean and re-run DV's in GLMs. DV's replaced, Patch replaced. Could not get below sand bridge @ 5430'. E-line perfed TBG 4spf @ 5183'·5189' & 5196'-5202' wlm. (above and below TBG collar) .RU 224-13 Proposell Completion Schematic ) ConocóPhillipS (MZ Frac System) Conductor: 30" Driven to 65' MD ~ ~ ~ ~ I I ~ I ri ~ I ~ ~ I I ---11 ~ I I ~ I I I I I Surface Casing: 20",94.00#, H-40 BTC @ 423' MD Intermedi~te Casino: 13-3/8", 61.00#, K-55 BTC 13-3/8", 68.00#, K-55 BTC @ 3298' MD ~xisting Perfs: Proposetl Perfs: 3355' - 3361' 3376' - 3396' 3422' - 3431' 3435' - 3482' 4138' - 4148' 4157' - 4170' 4297' - 4303' 4446' - 4456' 4476' - 4490' 4593' - 4603' 4676' - 4694' 4764' - 4774' 4446' - 4456' 4475' - 4490' 4593' - 4603' 4676' - 4694' 4767' - 4777' 4916' - 4924' 4936' - 4958' 4966' - 4986' 5022' - 5032' 5050' - 5086' 5398' - 5448' 5494' - 5516' 4916' - 4924' 4936' - 4958' 4966' - 4986' 5022' - 5032' 5047' - 5087' 5398' - 5448' 5494' - 5516' 5621' - 5644' D~maged C~sing (Tight Spot @ 5030' MD): Opened Casing from 5028' to 5034' w/ 8- W' String Mill. Casing Still Tight w/ Pulled Back Through ~ After Milling. ,,/ C"AU~ · Fish: TOF (ij) 5577' MD 1. Perforation Gun - 20' Length 2. 6-V2" OD Junk Mill and XO Sub @ 5654' MD Bridge Plug: Set @ 5660' During 1981 Completion Production Casing: 9-5/8", 43.50#, Pll0, BTC @ 2151' MD 9-5/8",47.00#, Pll0/N-80, 8rd LT&C @ 6999' MD I fll~1 ~ -.:m- ~ I JJ " ~ ~ I ~ ~ I I ~ I II~L ~ I ~ I ~ ~ ~ ~ ~ Ii I ~ ~ ~ 18; I I ~ ~ ~ I ~ ~ ~ ~ I I m .. i I ~ - I I U&I ~ ~ ~ . I I ~ I} ~ - I ~ +/-3.830'MD ~ ¡~¡¡¡1¡1j:j:~:¡ ~ Ii ............... ~ I ~:~:::::::::::~ ~ ~ illlli ~ i I B P +/-4,310'NO ~ ~ I -- I ~ I I ....... ~ ~ i))) ~ I ~~r~// I ~ ::::::::::~:::~ ! ~ ,~ i ~ +/- 4,788 'NO ~ i ;:;:;:;:;:;:;:; ~ ~ }¡;/~ ~ /' ~ i ~ ~ ~ ~ ~ i ~ ~ ~ ~ .-J +/- 5,5?6' NO ~ ~ ~ ~ ~ I ~ ~ ~ ~ i L .1 Tubing Hanger: Vetco Gray Hanger w/ 5-1/2", 15.5#, L-80, BTC-Mod Pup Joint installed. Spaceout Tubing Pups (as required): 5-1/2", 15.5#, L-80, BTC-Mod Ported Nipple: 5-1/2" Camco 'B-61' Ported Nipple w/ DB No-Go Profile and 4.562" Minimum 10. Methanol Injection Line to Surface w/ Dual Check Valve Installed @ Nipple. Nipple Set @ +/- 400' MD-RKB Tubing (as required): 5-1/2", 15.50#, L-80, BTC-Mod Sliding Sleeve: Baker 5-1/2" CMU Sliding Sleeve w/ 4.562" X Selective Profile. 6' Handling Pups Installed on Top and Bottom. Tubing (l-Joint): 5-1/2", 15.50#, L-80, BTC-Mod Tubing (6' Pup Joint): 5-1/2", 15.50#, L-80, BTC-Mod PBR Seal Assembly: Baker '190-60' PBR Seal Assembly, 15' Length, (7.05" OD x 4.88" 10) Tubing (6' Pup Joint): 5-1/2", 15.50#, L-80, BTC-Mod Anchor assembly: Baker Model 'S-22' Anchor Tubing Seal Assembly (7.00" OD x 4.88" 10) Packer: Baker SC-2 Packer (96B2-60 / 47# Casing / 8.313" OD x 6.00" 10) and GP Assembly (as per BOT Completion Schematic) Assembly Includes Mod 'C-2' KOIV w/ Protection Sleeve. Top Of Packer (â) +/- 3103' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Blast Joints: 5-1/2", 17.00#, L-80, SLHT (150' Length x 6-1/4" OD) Top of Blast Joints (â) +/- 3345' MD-RKB Packer: Baker SC1-L Packer (8.125" OD x 6.00" ID) and GP Assembly (as per BOT Completion Schematic) Top of Packer (â) +/- 3830' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-W', 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" OD x 6.00" ID) and GP Assembly (as per BOT Completion Schematic) Top of Packer (â) +/- 4310' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-V2", 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker SC1-L Packer (8.125" OD x 6.00" ID) and GP Assembly (as per BOT Completion Schematic) Top of Packer (â) +/- 4788' MD-RKB Blank Pipe (as required): 5-1/2", 17.00#, L-80, SLHT Blank Pipe - Braden Pup (as required): 5-1/2", 17.00#, L-80, SLHT Gravel Pack Screen (as required): 5-W', 17.00#, L-80, SLHT- Baker Excluder 2000 Medium 316L Screen Packer: Baker 'FB-l' Permanent Sump Packer (8.280" OD x 6.00" ID) and Lower Tubing Tail (as per BOT Completion Schematic) Top of Packer (â) +/- 5526' MD-RKB BRU 224-13 Schematic vl.0 prepared by Mark Chambers 07/25/05 KIL _~ik Ria !1 Shaffer Type SL 13-5/8" / 5000 PSI/BOP Stack ') L, L 13-5/8" Annular Rams Availahle For ~p.luga Work ~ < Upper Ram (Options): ~ ~ 1.90" 2-3/8" 4-1/2" ~ Þ 7-5/8" 13-5/8" Double Gate 2-7/8" x 2-7/8" Dual 2-7/8" x 3-1/2" Dual ~ Þ Middle Ram: Blind ~ ~ L J L- ~ 13-5/8" Mud Cross S- ~ í l ~ ( ~ ~ lower Ram: 13-5/8" Single Gate VBR (2-7/8" x 5-1/2") ( ~ Mark Chambers 07/19/05 Re: BRU 224-13-1 unloading Subject: Re: BRU 224-13-1 unloading From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 06 Jul2004 14:38:48 -0800 To: "Braden, John C" <John.C.Braden@conocophillips.com> \'\~-o~'\ John, Thanks for the notice. for the patch. Tom Maunder, PE AOGCC Bringing the well in should be covered by the sundry issued Braden, John C wrote: Tom, We are going to swab 224-13-1 to tank in an attempt to unload the well in the next few weeks. This is a well we recently installed a patch in the tubing. According to our discussion, a sundry is not required but you thought an e-mail notice was sufficient. Sincerely, John C Braden Cook Inlet Development (907) 263-4536 phone (907) 265-1441 fax .c.braden@conocophillips.com 1 of 1 7/6/20042:39 PM r----. r"'., STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D 1. Type of Request: Abandon D Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Perforate 0 Stimulate D Suspend D Repair well 0 Pull Tubing D Plug Perforations Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D P. O. Box 100360, Anchorage, Ak 99510-0360 7. KB Elevation (ft): 104' RKB 8. Property Designation: - A-;~ ;'k RECEIVE ') MAY 1 0 2004 ldaskø Oil & ~s C&rtSJ.I<ßiift??~;.Ç).;1 Time Extension Añl:horageOther 0 Re-enter Suspended We D Patch 5. Permit to Drill Number: 73-037 6. API Number: 50-283-20042-00 9. Well Name and Number: BRU 224-13 10. Field/Pools(s): Beluga River Unit PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) 5670' MD ADL 58831 11. Total Depth MD (ft): 10000' Casing Structural Total Depth TVD (ft): Effective Depth MD (It) 10000' 5670' Length Size 30" TVD 65' 423' 3298' 65' 423' 3298' Conductor Surface 20" 13-3/8" Intermediate Production 9-5/8" 6999' 6999' Production Perforation Depth MD (ft): 3355'-5516' Packers and SSSV Type: Junk (measured): Burst Collapse Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 3355'-5516' 2-3/8" /2-7/8" N-8a / N-80 Packers and SSSV MD (ft): Tubing MD (ft): 2199' / 5489' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 5/3/2004 16. Verb!!1 Approval: ~ Date: 5/3/04 Commission Representative: T~;;-M~u,.fuer 17 1 hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Contact Printed Name ~n Braden Title Beluga River Unit Staff Engineer Signature'.l. /pt:f[:J Phone 263-4536 (7' ~\~ ~\\ ~~~~<è..~\\~\\'-J Conditions of approval: Notify Commission so tha' L - \ ~~ ~ - ..... %"{ ~""-X..J~O 'S.,"'-~ a\s Plug Integrity D BOP Test D Mechar T~, s ~~" e \t:3~ "'-.ô..). ~~'Bù~ ~~ ~,\..~.. I~~\~'\ ~l -\-~ ~~~~\ 4-.4 ~~ " K<::\ if'3>;) -d-~ ~~~~c,\æJ -- ~ ~ \ r V r rvr;-r- Other: Approved' Form 10-403 Revised 2/2003 Service D Plugged D WINJD Abandoned D WDSPL D Date 7 (YIo.y Þ'l Sundry Number: 2", 0/-- /7~ ./ ¡ION Dat.1/lf NAY ' 11 2 20uit SUBMIT IN DUPLICATE 68Ft ,--....., r"'., 224-13 Tubing Patch Objective: A caliper log run on well 224-13 on 10 December 2003 revealed a hole at 3,397' MD (tie-in point was a GLM at 3,072 ' MD, drillers depth). The objective of this procedure is to patch the hole at 3,072' MD. Well Specs: 224-13-1 Tubing 2-7/8" 6.4 lb/ft L-80 EUE 8rd, ill = 2.44" Hole: 3,397 MD. Joint above at 3,383, joint below at 3,403 1. Hold PJSM. Rig up slickline. 2. Rill with gauge ring to make sure pack-off can clear restriction. Note depth of any restriction. POOH. 3. Correlate depth with GLM at 3072' MD. Flag the line. 4. Rill with lower packer for anchor. Set around @ 3412'MÐ or 15 ft below the hole. 5. Stack in 30 ft of patch. 6. Rill and set upper packer on top. POOH. 7. Pressure test patch by opening up string #2 to the bleed-down trailer, creating a differential, while monitoring pressure on string #1. r"'., >~ 8t ga River Unit API#: 283-20042-00 Original RKB (Depth Ref): Ground Level: Maximum Hole Angle: Angle at Perforations: ARCO Alaska, Inc. 8RU 224-13 Spud Date: 1 al74 Last Compl: 12/88 Schematic Rev: 9/11/92 ,SW 1/4 Sec.13, T13N, R1aW SM Well Type: Gas Producer Annulus Fluid: Gas Top of Sterling: 3348' ASP: 2636609,325576 Dual w/ Gas heater string 94' 74:8' a a Jewelry DeDth LengthEauipment 1 3072' 6.76' Merla 2 7/8"x1" TGPD GLM w/dum BK-2 latch 2 3110' 14.84' Baker Model AL-5 Dual Pkr. 3 3309' 2.50' Baker Shear Out Safety Jt. 4 3343' 161.00' 27/8"SteeIBlastJts. (161') 5 3628' 6.79' Merla 2 7/8"x1" TGPD GLM w/dum.BK-2Iatch 6 3696' 6.76' Merla 2 7/8"x1" TGPD GLM w/dum.BK-2Iatcb 7 3735' 7.07' Baker HB hyd set retrievable Pkr. 9 5/8"x4 1/2" 8 3804' 8.68' Baker DB perm Pkr. 95/8"x41/2" 9 3844' 1.32' "X" Nipple 1 0 5456' 1 .30' "XN" Nipple 11 5489' .66' 27/8" Brown Shear out sub A 3007' 2.50 'Baker Shear out Safety Jt. B 3040' 6.79' Merla 2 7/8"x1" TGPD GLM w/CV BK-2 latch C 3110' 12.29' Baker Model AL-5 Dual Pkr. 0 3132' 1.29' "XN" Nipple AA 2165' 1.08' "X" Nipple I.D. Q..JL 2.406" 8.50" 2.406" 3.687" 2.375" 3.750" -':-'. ~(1. .. 2.440' 3.250' 2.313'" 2.250" " M 2.406" 3.687" 2.406" 8.50" 2.250. 1.875" / Casing and Tubing DescriDtion Size Weight Grade Thread!..QR Bottom Surface 20" 94# H-40 Butt 0 423' Intermediate 13 3/8" 61 & 65# K-55 Butt 0 3298' < Production Csg. 95/8" 43 & 47# N-80/P-110 Butt 0 6999' Production Tbg. 27/8" 6.5# (1) N-80 EUE-8RD 0 5489.11' Production Tbg. 2 7/8" 6.5# (2) N-80 EUE-8RD 0 3134.29' Heater 23/8" 4.3# (3) N-80 EUE-8RD 0 2198.66' Perforations Net Production Zone DIL Depth Density Footaae Interval Status A 3322' 4 Sqz. Closed 3355'-3482' 12 85' String 2 Open 3525' 4 Sqz. Closed B 3660'-366?' 4 SQ7 Packer Closed C 3755'-3760' 4 SQz. Packer Closed F 4446'04774' 12 62' String 1 Open G 4916'-5086' 12 96' String 1 Open H 5398'-5516' 12 72' String 1 Open 5681 '-5758' 4 Sqz. BP @> 5660' Closed 5820'-6470' 4 139' BP @ 5800' Closed =A :=)B 1:::> e ~2 g:z:.. 3 == D . r--- 4--~ ] /::,11fB' '~ì 5 => . (;t¡":.~t - 6 =, . . . ¡1 ";:'6 ---I' snr¡Y/ 7 ..><- ~f;.fj, ¡II. . 7 . '8' ::~ hóJ~ "p'f, tic..- ,.~~ ---- plrA9, ~11~;¡r)i ~ J II'- 'f. J 10 -. 11 0 PBTD 566(\' .J tQ::.:~:.::.:~::::U:'::':~:'::.t ~"',. ~~~~~~~.' , , , " , , , , - * Note: 1988 WO-- Left in hole: 6.5"00 junk mill & 4.75" 00 X-over sub at 5654' on 11/12/88 (XO wi 3.5" reg box by 3.5" IF pin) 2-10' D.A. 5"/12 SPF csg guns (top 10' DNF) pushed to 5577' on 11/18/88 Tag Data String 2 String 1 5/6/91 2.3" gauge ring XN nipple at 3132' RKB 5/6/91 1.5" bailer, fill at 5507' RKB 7//)/97 I. '11M" ýtlt/./l f 1¡1'}¡ f;/I @ 3'1311' w-U"? 6/21/921.75" bailer, fill at 5506' RKB . MLf /17 1.3' J-/ð fajl.p¿ @ 3'316' wt-/'! ý h../~¡ I' 1/ ,." Çt.f67' * Multiple budge plugs I ( ~ '110 8/10/95 7/1).-/ J7 1 ;;~-" /;cu/f'f € J-j17¡{/ I Toe 6755' 1 J., , , , , , , 'Jio.. ,, ..~..~..~..~,~..~..~.'" ,~~~~~~ ,.'.'.'.'.'.' . ~o 10,000' {/./¿A APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well Alter casing r-I Repair I-1 Plugging I-'l Time extension r'-I Stimulate Change approved program [] Pull tubing [] Vadance [] Perforate Other Squeeze 2. Name of Operator ARCO Alaska, Inc. 3. Address PO Box 100360, Anchorage, AK 99510-0360 Location of well at surface 1012' FSL, 2194' FWL, SEC 13, T13N, R10W, SM 5. Type of Well: Development [] Exploratory [] Stratigraphic [] Service [] Datum elevation (DF or KB) 104' KB feet Unit or Property name Beluga River Unit Well number 224-13 String 1 -At top of productive interval Straight hole, same as surface location At effective depth Straight hole, same as surface location At total depth Straight hole, same as surface location 9. Permit number 73-037 10. APl number 50-283-20042-00 11. Field/Pool Beluga River/ 12. Present well condition summary Total Depth: measured 10,000 true vertical ' 10,000 Effective depth: measured 5,670 true vertical 5,670 Casing Length Size Structural Conductor 65' 30" Surface 423' 20" Intermediate 3298' 13-3/8" Production 6999' 9-5/8" Liner Perforation depth: measured See Attached Schematic true vertical See Attached Schematic Tubing (size, grade, and measured depth See Attached Schematic -; Packers and SSSV (type and measured depth) See Attached Schematic feet Plugs (measured) feet feet Junk (measured) feet Top of Plug @ 5,670' none 0RI$1NAL Cemented driven Cmtd to Surf 2010 sks Class G 1645 sks Class G Measured depth True vertical depth 65' 65' 423' 423' 3298' 3298' 6999' 6999' 13. Attachments Description summary of proposal [] Detailed operation program [] BOP sketch [] 14. 15. Status of well classification as: 16. Estimated date for commencing operation July, 1997 If proposal was verbally approved Name of approver Date approved Oil [] Gas [] Suspended [] Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title Beluga/Kuparuk Staff Manager Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity [] BOP Test ~ Location clearance Mechanical Integrity Test [] Subsequent form require 10- Approved by the order of the Commission ,~;~g~nal Signea By 0avid W. Johnston Commissioner Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Beluga River Unit - Summary of Proposed Operations BRU 224-13 CT Water Shut-off and Recompletion , 2. 3. 4. 5. , , 8. 9. 10. 11. 12. 13. 14. MIRU coiled tubing unit. Clean out sand bridges in tubing and attempt to get well to flow with N2 lift. RDMO coiled tubing. MIRU electric line unit. Run Thermal Decay (TDT-P) and Water Flow Log (WFL) through long string across all perforated intervals with well shut-in and flowing. If log is successful in distinguishing between gas and water bearing intervals, proceed with step 7. Otherwise, RDMO. Perforate long string with tubing punch below bottom packer. RDMO electric line unit. MIRU coiled tubing unit, cement mixer, and pumps. Circulate cement through long string tubing tail and into tubing by casing annular space. RDMO coiled tubing and wait on cement. MIRU electric line unit. Reperforate any gas bearing intervals from 4440-5520' md (as identified in step 6) through the long string tubing. RDMO and put well on production. RCO Alaska Inc. BRU 224-13 Spud Date' 1 0/74 Last Compl: 12/88 Schematic Rev: 9/11/92 SW 1/4 Sec. 13, T13N, R10W SM , River Unit APl#: 283-20042-00 Original RKB (Depth Ref): Ground Level: Maximum Hole Angle: Angle at Pedorations: 94' 74.8' 0 0 Well Type: Gas Producer Annulus Fluid: Gas Top of Sterling: 3348' ASP: 2636609,325576 Dual w/Gas heater stdng Jewelry Depth Lenoth 1 3072' 6.76' - 2 3110' 14.84' 3 3309' 2.50' 4 3343' 161.00' 5 3628' 6.79' 6 3696' 6.76' 7 3735' 7.07' 8 3804' 8.68' 9 3844' 1.32' 10 5456' 1.30' 11 5489' .66' A 3007' 2.50 B 3040' 6.79' C 3110' 12.29' D 3132' 1.29' AA 2165' 1.08' EcluiDment Merla 2 7/8"xl" TGPD GLM w/dum .BK-2 latch Baker Model AL-5 Dual Pkr. Baker Shear Out Safety Jt. 2 7/8" Steel Blast Jts. (161') Merla 2 7/8"x1" TGPD GLM w/dum. BK-2 latch Merla 2 7/8"x1" TGPD GLM w/dum. BK-2 latch Baker HB hyd set retrievable Pkr. 9 5/8"x4 1/2" Baker DB perm Pkr. 9 5/8"x4 1/2" "X" Nipple "XN' Nipple 2 7/8" Brown Shear out sub 'Baker Shear out Safety Jt. Merla 2 7/8"xl" TGPD GLM w/CV BK-2 latch Baker Model AL-5 Dual Pkr. "XN" Nipple "X" Nipple I.D, O.D. 2.406' 8.50" 2.406" 3.687" 2.375" 3.750" 2.440' 3.250' 2.313' 2.250" 2.406" 2.406' 2.250' 1.875" 3.687" 8.50" 10 11 - ~98 .- 5660 Casing and Tubing Desc.riptlQn Size Weiaht Grade Thread ToD Surface 20" 94# Intermediate 13 3/8" 61 & 65# Production Csg. 9 5/8" 43 & 47# Production Tbg. 2 7/8" 6.5# (1) Production Tbg. 2 7/8" 6.5# (2) Heater 2 3/8" 4.3# (3) H-40 Butt 0 K-55 Butt 0 N-80/P-110 Butt 0 N-80 EUE-8RD 0 N-80 EUE-8RD 0 N.80 EUE-8RD 0 Bottom :, 423? 3298' 6999' 5489,11' 3134.29' 2198,66' Perforations Zone DIL Depth Density A 3322' 4 3355'-3482' 12 3525' 4 B 2660'-3662' . . 4 C 3755'-3760' ,, 4 F 4446'-4774' 12 G 4916'-5086' 12 H 5398'-5516° 12 5'681'-5758' ' 4,, , I 5820'-6470' 4 Net Footage Interval Sqz. 85' String 2 Sqz. Soz Packer Sa:,, ,, packer 62" String 1 96' String 1 72' ,,, StrincJ 1 . . Sqz. . BP{'~5660' 139' BP@ 5800' Production Status Closed Open Closed Cldsad _. Closed Open Open.: Open . Closed Closed Note: 1988 WO-- Left in hole: 6.5"OD junk mill & 4.75" OD X-over sub at 5654' on 11/12/88 (XO w/3.5" reg box by 3.5" IF pin) 2-10' D.A. 5"/12 SPF csg guns (top 10' DNF) pushed to 5577' on 11/18/88 Tap Datp String 2 5/6/91 2.3" gauge ring XN nipple at 3132' RKB TD I0,000':: * Multiple bridge plugs String 1 5/6/91 1.5" bailer, fill at 5507' RKB 6/21/92 1.75" bailer, fill at 5506, RKI~ fl ~'~ 8/10/95 COILED TUBING BOPE LUBRICATOR BLIND RAMS SHEAR RAMS SLIP RAMS PIPE RAMS .RISER g-?/8" EUE 8RD TREE CONNECTION Swab Valve Double Master Valves Wellhead E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator F. xtemion Manual. R~s Swab Valve Double Mastez Valves . Wellhead ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR · 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy ~610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the'Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission David W Johnston \ Chairman jo/rpc~z-energy · ' ¢ ' IL AL SK AND GAS CONSERVATION COMMISSION ~r , WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ;~ GAS ,~1 SUSPENDED '~ ABANDONED ~J SERVICE [] 2. Name of Operator 7. Permit Number 73-037 3. Address 8. APl Number p n R,v ~nn~n A,~h ..... AY 9951n-n~n 50- 283-20042 4. Locaii(~ ~f~v-~il a't-s~J'~f'~ .......... =- ' .... 9. Unit or Lease Name 1012' FSL, 2194' FWL~ Sec.13~ T13N~ R10W~ 5N Beluga River Unit At Top Producing lnterval 10, Well Number 1012' FSL~ 2194' FWL~ Sec.13~ T13N~ R10W~ SM BRU 224-13 At Total Depth 11. Field and Pool 1012' FSL, 2194' FWL, Sec.13, T13N, RIOW, SM Beluga River 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 104'I ADL 58831 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 116. No. of Completions 09/26/74 11/15/74 12/1 6/74*I N/A feet MSLI 2 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10,O00'MD/TVD 5670'MD/TVD YES [] NO ~ N/A feet MD N/A ....... 22. Type Electric or Other Logs Run DIL/CNL/BHCS,Micro-loq, Dipmeter~ SWC HFT, CBL, PDK 23. CASING, LINER AND CEMENTING RECORD , .. SETTING DEPTH MD CASINGSIZEIWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT'PULLED ~0tt ......... & t t r'l: RR t .... 13~ ~ ,,,~n ?0,, q&.{3~ H-4O _~,lrf ~.9~, ~,, 660 s× ('_3 ~ r. , , . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , ,, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL uSED See attached ., ....... 27. N/A PRODUCTION TEST ... Date First Production ] Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO TEST PERIOD II~ OIL-BBL GAS-MCF ~ WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. i ECEIVED JAN u 5 19,89 * NOTE: Added. perforations 4/5/81. Workovers performed 9/17/84 and 12/2/88 ..... · ~. ' - Form 10-407 Rev. 7-1-80 WC5/068 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARINERs 'FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · ;,' ,/ (;as Top A 3355~ 3355~ A-2 Contour 3/+05' 3/+05~ Top B ' ' 3532 ~ 3532 ~ , Top C 3692~ 3692' Top D (Base 5re-ling) 3852~ 3852~ Top E ~09~ ~09~ ~ Top F ~360~ ~360~ Top C ~830 ~ ~830 ~ Top H 532~ ~ 532~ .............. . , 31. LIST OF ATTACHMENTS None ............................... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engineer ...... ................ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection'for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". · Form 10-407 WC5/068 WELL COMPLETION OR RECOMPLETION REPORT AND LOG (Continued) BRU-224-13 Item 24 Perforation Depths: MD/TVD 3355'-3361' 3376'-3396' 3422'-3431' 3435'-3482' -4138'~\ 4294,_4304! 4446'-4456'~° 4476'-4490'~ 4593'-4603' 4676'-4694' ~64'-4774' 4936 -4958' 4966 -4986.' 5022_-5032'? -5o86' ~-5448' 5494 -5516' Item 25 Item 26 Tubing Size String #1: 2-7/8", N-80 tb§ w/tail @ 5489' String #2: 2-7/8", N-80 tbg w/tail @ 3134' String #3 (Heater String): 2-3/8", N-80 tbg w/tail @ 2199' Packers and SSSV: String #1: Baker 'AL-5' Dual pkr @ 3110', Baker 'HB' pkr @ 3735', Baker 'DB' pkr @ 3805' String #2: Baker 'AL-5' Dual pkr @ 3110' String #3 (Heater String: None Squeeze Info: 12/2/74 5681 '-5689' 5705'-5725' 5743'-5758' 150 sx Class G 12/7/74 3660'-3662' 368 sx Class G 12/11/74 3755'-3760' 12/12/74 3525' 12/13/74 3322' 150 sx Class G 150 sx Class G 73 sx Class G ARCO Oil and Gas Company Well History- Initial Report- Daily InllnlctiOltl: Prepare and submit the "Initial Recent" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough I , Field ~Lea~ or Unit I ~n~ ~n ~T I ~L: 5883~ Auth. or W.O. no. ~Title AD~n7 J WORKO~R jst. BRU 224-13 iVell no. Operator Spudded./or/~(~(~pTbegun IDate Date and depth Complete record for each day reported as of 8:00 a.m. ROLL'N ~ 5 11/05/88 ( TD: 6999 PB: 5670 SUPV:HRE 11/06/88 ( TD: 6999 PB: 5670 SUPV:HRE 11/07/88 ( TD: 6999 PB: 5670 SUPV:HRE 11/08/88 ( TD: 6999 PB: 5670 SUPV=HRE 11/09/88 ( TD: 6999 PB: 56?0 SUPV:HRE 11/10/88 ( TD: 6999 PB: 5670 SUPV:DL 11/11/88 ( TD: 6999 PB: 5670 SUPV:DL AVI: 50-283-2004~ 11/04/88 JHour 0200 HRS ARCO W.I. 0.ooo0 Prior status if a W,O. ATT TO KILL WELL MW: 8.6 KCL ACCEPT RIG @ 0200 HRS, 11/4/88. ATTEMPT TO KILL WELL. DAILY.' $219,741 CUM.' $219,741 ETD: $219,741 EFC:$1,350,000 NU BOPS MW: 8.6 KILL WELL W/ 8.6 PPG BRINE. ND TREE AND NU BOPE. KCL DAILY:S45,599 C0M:$265,340 ETD:S265,340 EFC=$1,350,000 POH LD STRING #2 MW: 8.6 KCL FIN NU BOPS. FIN RU SUB AND FLOOR. TEST BOPS. POH W/STRING 93 (HEATER STRING). RU ON STRING 92. PULL SAME FREE FROM SAFETY JOINT @ 3081'. POH AND LD STRING %2. DAILY:S20,366 CUM:$285,706 ETD:S285,706 EFC=$1,350,000 SETTING WEAR RING MW: 8.6 KCL FIN. POOH & LD STG %2, PU ON STG %1, SHEAR DUAL PKR & SAFETY JT, CIRC BTMS UP, POOH & LD STG ~1 TO SAFETY JT, CHANGE RAMS TO 3-1/2", TEST RAMS, ANNULAR, AND HCR, SET WEAR RING, PREP TO PO 3-1/2" DP & FISHING ASSEMBLY DAILY=S22,841 CUM:$308,547 ETD=S308,547 EFC:$1,350,000 GIH W/FTA J2 MW: 8.6 KCL GIH W/FTA #1. CATCH FISH @ 3660' AND JAR SAME FREE. CBU . POOH W/FISH. CUT DRILL LINE AND REPAIR RIG. GIH W/FTA %2. DAILY:S19,873 CUM:$328,420 ETD:S328,420 EFC:$1,350,000 POH W/BIT MW: 8.6 KCL FIN GIH W/FTA. CATCH LAST PKR AT 3802'. PULL SAME FREE. CBU. POH W/FISH - FULL RECOVERY. GIH W/BIT. HIT TIGHT SPOT @ 5030' - COULD NOT WORK THRU. CBU AND POH W/BIT. DAILY=S26,779 CUM=$355,199 ETD:S355,199 EFC=$1,350,000 GIH W/ MILLS MW: 8.6 KCL GIH W/6-1/2" BIT - NO RESTRICTION AT 5030'. TAG FILL AT 5407'. CLEAN OUT WELL TO 5660'. CIRC HOLE CLEAN. POH W/BIT. PU 6-1/2" JUNK MILL AND 8-1/2" STRING MILL AND GIH W/SAME. DAILY=S19,611 ~',~'~.?~,810 ETD:S374,810 EFC:$1,350,00g The above is correct For form prepara~ End distributi~ see Procedures ~al, Section Drilling, Pages ~and 87. AR3B-459-1-O Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pedorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnt~rfnt" sheets until tidal completion. Report official or representative test on "Final" form. 1) Submit "lnteriB" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish COOK INLET IstSmAK Lease or U~u 224-13 BELUGA RIVER UNIT Well ho. Date and deptll as of 8:00 a.m. 11/12/88 ( TD: 6999 PB: 5670 SUPV:DL 11/13/88 ( TD: 6999 PB: 5670 SUPV:DL 11/14/88 ( TD: 6999 PB: 5670 SUPV=DL 11/15/88 ( TD: 6999 PB: 5670 SUPV:DL 11/16/88 ( TD: 6999 PB: 5670 SUPV:DL 11/17/88 ( TD: 6999 PB= 5670 SUPV:SS Complete record fOrROLL, NeaCh day ~hi~ drilling or worko~r in progress 3) ¸4) The ab~e~s correct Signa~~.~ FILTER BRINE MW: 8.6 KCL FIN EIH WITH MILLS. REAM CSG FROM 5028-5034. CBU TAG BTM AT 5654. POOH LEFT 6-1/8" JUNK MILL AND XO IN HOLE. CIRC WELL. COULD NOT FILTER BRINE. DISPLACE BRINE WITH NEW FILTERED BRINE. DAILY:S29,194 CUM:$404,004 ETD=S404,004 EFC:$1,350,000 RU DRESSER ATLAS MW: 8.8 KCL FIN DISPLACING WELL WITH FILTERED BRINE.WT UP TO 8.8PPG. RIH W/ 9-5/8" RETV. PKR. SET PI(R AT 3186'. TEST CSG TO 2000 PSI. POOH . RU DRESSER ATLAS. DAILY:S22,061 CUM:$426,065 ETD:S426,065 EFC:$1,350,000 POOH WITH DP MW: 8.8 KCL RU DRESSER ATLAS RIH WITH PDK LOG. LOG FROM 5500'-4800', TOOL MALFUNCTION. POOH. PU NEW PDK TOOL, RIH LOG FROM 4800'-3300'.POOH. RIH WITH CEL, TOOL NOT WORKING.POOH. GAS TO SURFACE. RIH WITH OPEN ENDED DP CIRC GAS OUT. POOH WITH DP. DAILY:S20,616 CUM:$446,681 ETD:S446,681 EFC:$1,350,000 WT UP BRINE TO 8.8 & MIX MW= 8.8 KCL POH W/ DP, RU E-LINE, TEST LUB, RUN CBL, PERF 5494-5515, 5428-5448, 5398-5428, 5056-5086, WELL FLOWING AFTER LAST PERF RUN, RD E-LINE, ATTEMPT TO RIH W/ DP, TO MUCH PRESSURE & FLOW, POH, SWI W/ 2 STANDS IN HOLE, MIX 9.9 BRINE AND LITESAL PILL DAILY:S18,207 CUM:$464,888 ETD:$464,888 EFC:$1,350,000 RIH W/ DP OE MW: 8.8 KCL PUMP 37 BBLS LITESAL PILL, TOP KILL WELL W/ PILL & 166 BBLS 9.9 BRINE, POH, REMOVE DART VALVE, RIH W/ DP OE DAILY:S27,509 CUM:$492,397 ETD:S492,397 EFC:$1,350,000 RU E-LINE MW: 9.4 KCL CONT. RIH W/ DP TO 5597', CIRC. GAS OOH, CIRC. 9.4 PPG BRINE, POH, TEST BOPE, RU E-LINE F/ PERFORATING DAILY:S21,564 CUM:$513,961 ETD:S513,961 EFC:$1,350,000 For form preparat.~'~nd ~is~ution see Procedures ~lanu~l Section 10, Drilling, Pages 8~,~ 87 AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form i$ used during dritling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until completion. Report official or representative test on "Fieel" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil strin~ until completion. District ICounty or Parish IStatL ARCO ALASKA INC. I COO[<: TNLE'r I I Field ILease or Unit BELUGA RIVER UNIT I BRO 224-13 ! Complete record for each day while drilling or workover in progress ROLL'N ~ 5 Date and depth as of 8:00 a.m. 11/18/88 ( TD: 6999 PB: 5670 SUPV:SS 11/19/88 ( TD: 6999 PB: 5670 SUPV:SS 11/20/88 ( TD: 6999 PB: 5670 SUPV:SS 11/21/88 ( TD: 6999 PB: 5670 SUPV:SS 11/22/88 ( TD: 6999 PB: 5670 SUPV:SS 11/23/88 ( TD: 6999 PB: 5670 SUPV:SS 11/24/88 TD: 6999 PB: 5670 SUPV:DL 5) CIRC HOLE CLEAN & BUILD V MW: 9.4 KCL CONT. RU E-LINE, PERF F/ 5050-5056, 4966-4986, 4936-4958, 4916-4924, 4976-4694, 4593-4603, LOST 20' OF GUN IN HOLE ON RUN 94,FIN PERF F/ 4476-4490, 4446-4456, RIH W/ BIT AND JAR GUN TO 5577, CIRC HOLE CLEAN AND BUILD VOLUME. DAILY:S19,812 CUM:$533,773 ETD:S533,773 EFC:$1,350,000 RIH W/ PKR PLUG MW: 9.4 KCL CIRC. HOLE CLEAN, POH W/ DP, RUN 2-7/8" COMPLETION W/ BTM PKR ON DP, RU E-LINE CORRELATE PKR DEPTH, SET PKR AT 3787, CBU, POH, PU PKR PLUG AND RIH DAILY:S20,747 CUM:$554,520 ETD:S554,520 EFC:$1,350,000 W/O FISHING TOOLS MW: 9.4 KCL RIH & SET PKR PLUG, SPOT SAND ON SAME, POH, RU E-LINE, PERF., RIH W/ DP, CIRC. SAND ON TOP OF PLUG, ATTEMPT TO PULL PLUG, POH, NO RECOVERY, WU FISHING TOOLS DAILY:SIS0,163 CUM:$734,683 ETD:S734,683 EFC:$1,350,000 POH W/ BAKER RETR TOOL MW: 9.4 KCL MU FISHING TOOLS (2-5/8" GRAPPLE W/ 5-3/4" OS), RIH, POH, LD OS, RIH W/ 4-11/16" OS, ATTEMPT TO LATCH, NO SUCCESS, POH W/OS, REDRESS OS, RIH, ATTEMPT TO LATCH, NO SUCCESS, POH LD OS, MU BAKER RETR TOOL, RIH, ATTEMPT TO LATCH, NO SUCCESS, POH W/ RETR TOOL DAILY:S19,507 CUM:$754,190 ETD:S754,190 EFC:$1,350,000 RIH W/ 8" MAGNET MW: 9.4 KCL CONT. POH W/ RETR TOOL, NO RECOVERY, RIH W/ MILL, MILL 3' AT 3785, POH, PU & RIH W/ RD OS & JUNK BASKETS, TAG AT 3787, MILL TO 3789, POH, RIH W/ SAME, TAG 3789, MILL TO 3790', POH, RECOVER 12" PIECE OF PLUG, PU & RIH W/ 8" MAGNET DAILY:S19,507 CUM:$773,697 ETD:S773,697 EFC:$1,350,000 RU WIRELINE MW: 9.4 KCL CONT. RIH W/ MAGNET ON DP,'FISH AND POH, NO RECOVERY, RU E-LINE, FISH PIECES OF PKR PLUG W/ MAGNET, INSIDE OF PKR STILL HAS JUNK, RD E-LINE, RU SLICKLINE DAILY:S29,507 CUM:$803,204 ETD:S803,204 EFC:$1,350,000 MILL OVER PACKER MW: 9.4 KCL FIN RU PRECISION WL. FISH FOR JUNK IN PACKER W/2.25" MAGNET. REC'D SMALL PIECES OF SCOOP HEAD ON PACKER. RD WL; BURN OVER PACKER (ON 2ND SHOE AT REPORT TIME). DAILY:$25~664 CUM:$828,868 ETD:$828,868 EFC:$1,350,000 IWell no. The ab.~is correct For form preparg~3'l~ a~{d distributi(~l"-~) ~ see Procedures/Mar~ual Section 10~.--.~" Drilling, Pages 6t~nd 87 IDatel,Z./~ I / AR3B-459-2-B Number all daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Filial" form. 1] Submit "Interim" sheets when filled out but not less frequently than evem7 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District JCounty or Pariah IStat~LK ARCO ALASKA INC, I COOK INLET Field ~Lease or Unit BELUGA RIVER UNIT I BRU 224-13 Date and depth as of 8:00 a.m. 11/25/88 ( 2 TD: 6999 PB: 5670 SUPV:DL 11/26/88 ( TD: 6999 PB: 5670 SUPV:DL 11/27/88 ( TD: 6999 PB: 5670 SUPV:DL 11/28/88 ( TD: 6999 PB: 5670 SUPV:DL 11/29/88 ( TD: 6999 PB: 5670 SUPV:DL 11/30/88 ( TD: 6999 PB: 5670 SUPV:DL Complete rocord for each day while drilling or workover in progress ROLL'N ~ 5 POH W/OS MW: 9.4 KCL BURN OVER PACKER. CBU. GIH W/SHOE 93 AND BURN OVER PACKER. CIRC OUT GAS. POH. GIH W/ OS AND ATT TO CATCH PKR. POH W/ OS. DAILY:S20,469 CUM:$849,337 ETD:S849,337 EFC:$1,350,000 PULL PLUG F/'X' NIPPLE MW: 9.4 KCL POH W/OS - NO RECOVERY. GIH W/SHOE AND CUT OVER PACKER. CBU. POH. PU OS AND GIH. CATCH FISH AND POH. LD PKR. RU PRECISION WL TO PULL PLUG F/'X' NIPPLE IN TAIL PIPE (IN CASE OF TRAPPED GAS). DAILY:S18,607 CUM:$867,944 ETD:S867,944 EFC:$1,350,000 POH W/BIT AND SCRAPER MW: 9.4 KCL UNABLE TO PULL PLUG IN TAIL PIPE W/SLICKLINE. LD i JT 2-7/8" TBG AND PULL EQUIL PRONG. POH W/ 36 JTS TBG - LEFT 17 JTS IN HOLE. GIH W/ OS. CBU AND CATCH FISH. POH - FULL RECOVERY. GIH W/BIT AND SCRAPER TO 4950. CIRC HOLE CLEAN. POH. DAILY:S47,321 CUM:$915,265 ETD:S915,265 EFC:$1,350,000 CHANGE RAMS TO 2-7/8" MW: 9.4 KCL FIN POH W/BIT AND SCRAPER. RO ATLAS WL. RAN GR-JB TO 4950. RIH W/2-7/8" TBG AND MOD 'D' PKE ON 3.5" DP. RU ATLAS WL AND CORRELATE PKR DEPTH TO WLM. RD ATLAS WL. SET PKR @ 3792, EOT @ 5476. POH AND LDDP. CHANGE PIPE RAMS TO 2-7/8". DAILY:S36,992 CUM:$952,257 ETD:S952,257 EFC:$1,350,000 RIH W/ 2-7/8" COMP ASSEMB MW: 9.4 KCL CHANGE RAMS TO 2-7/8", TEST BOPE TO 3000 PSI, RIH W/ 100 JTS 2-7/8", POH & STAND IN DERRICK, RIH W/ 100 JTS 2-7/8", POH & STAND IN DERRICK, CHANGE RAMS TO 2-7/8" DUALS, TEST BOPE TO 3000 PSI, RIH W/ 2-7/8" COMPLETION ASSEMBLY DAILY:S18,881 CUM:$971,138 ETD:S971,138 EFC:$1,350,000 RIH W/ TBG OE MW: 9.4 KCL CONT. RIH W/ DUAL COMPLETION ASSEMBLY, ATTEMPT TO RUN ALLIGNMENT PIN FOR PARENT HGR, SIEZED PIN UP, PULL HGR, DRESS & RERUN HGR, COULD NOT SEAT HGR, POH W/ COMPLETION ASSEMBLY, CHANGE PIPE RAMS TO 2-7/8" SINGLE & TEST BOPE, W/ 2-7/8" TBG DE TO 3000' DAILY:S32,161' CUM:$1,003,299 ETD:S1,003,299 EFC:$1,350,000 Well no. The above is correct For form preparatj~lf'~"~n'd distribution see Procedures I~anu)al Section 10, Drilling, Pages 8~6..j~d 87 AR3B-459-.2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil~ a Gas Company Daily Well History--Interim Inetructioae: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on 'Interim" sheets until final completion. Report official or representative test on "Flail" form. 1) Submit "latlrfllt" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. I County or~ INLET I Stat~.K [ease or t~U 224 13 BELUGA RIVER UNIT IWell no. Date and deptl~ as of 8:00 a.m. 12/01/88 ( TD: 6999 PB: 5670 SUPV:SS 12/02/88 ( TD: 6999 PB: 5670 SUPV:SS Complet ...... d [~b~a~l~ ~ay~vh~e drilling ..... k .... in prog .... ATTEMPT TO ALIGN HGR MW: 9.4 KCL RIH W/ TBG TO 3721', PU STORM PKR & SET 1' BELOW TBG SPL, ND BOPE, REPAIR TBGHD, ATTEMPT TO SET PARENT HGR, NO SUCCESS, ATTEMPT TO SET OLD PARENT HGR, SUCCESSFUL, NU BOPE, POH W/ STORM PKR, CIRC., POH W/ TBG, CHANGE RAMS TO 2-7/8 DUALS, RIH W/ COMPLETION ASSEMBLY TO DUAL PKR, LAND PARENT HGR, ATTEMPT TO ALIGN PARENT HGR DAILY:S25,157 CUM:$1,028,456 ETD:S1,028,456 EFC:$1,350,000 ND BOPE MW: 9.4 KCL CONT. RIH W/ DUAL COMPLETION, SET PKRS & TEST BOTH STRINGS, RIH W/ 2-3/8" HEATER STRING, SET BPVS IN LS & SS, RD FLOOR, LD SUB, ND BOPE STRING #1: BAKER PKRS 'AL-5' DUAL @ 3110', 'HB' @ 3735', & 'DB' @ 3805', & TAIL @ 5489' STRING #2: BAKER 'AL-5' DUAL PKR @ 3110', & TT @ 3134' STRING #3: (HEATER STRING) TT @ 2199' DAILY:S184,962 CUM:$1,213,418 ETD:$1,213,418 EFC:$1,350,000 The above is correct For form prepar{l~ ~nd distribu~gJ~ see Procedures ~a~ual Section 10, Drilling, Pages 8~"~nd 87 IDate AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. JPage no. ARCO Oil and Gas ComPany Daily Well History-Final Report Inetruction$: Prepare and submit the "Final Rel=Ort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Re~ort" form may be used for reporting the entire operation if space is available. Oistrict ICounty or Pariah ARCO ALASKA INC. I COOK INLET Field ~Lease or Unit BELUGA RIVER UNIT I ADL: 58831 Auth. or W.O.AD6307no. ITM WORKOV~R API: 50-283-20042 OperatorARCO IA'R'c°' I~'!'0000 Spudded or W.O. begun I Date ACCEPT I 11/04/88 Date and depth Complete record for each day reported as of 8:00 a.m. ROLL'N # 5 12/03/88 ( 3 TD: 6999 PB: 5670 SUPV:SS IAccounting cost center code Stat~ BRU 224-13 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our 0200 HRS IPrior status if a w.o. I RR MW: 6.9 DIESEL FIN ND BOPE. NU TREE, PACKING ON HEAT STRING DAMAGED,REPLACE PACKING, FIN NU TRIPLE TREE. TEST PACKOFF TO 3000PSI. NOTE: TREE WAS TESTED IN ALASKA TECH SALES SHOP AFTER RECONDITIONING. PULL BPVS. DISPLACE ANN AND ALL 3 TUBING STRINGS TO DIESEL. SHORT STRING SITP=0. LONG STRING SITP=125PSI, HEATER STRING SITP=0. ANNULUS PRESS =0. PLUG IN STRING #1 LEAKING. SET BPV IN STRINGS #1 & ~2. SECURE WELL RELEASE RIG 1800 HRS 12-2-88. DAILY:S52,530 CUM:$1,265,948 ETD:S1,265,948 EFC:$1,350,000 Old TD Released rig New TD PB Depth Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval 0il or gasTest time Production :Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sign at~3-~=~~io~n ~ Date ITitle ~~. ~ _ For form prepar. _ anJdistribution, Drilling, Pages 86 and 87. AR3B~459-3-C Number ell daily well history forms consecutively as they are prepared for each well. iPage no. Division of AtlantlcRl~hfleldCompeny STATE OF ALASKA COM MiS~~' ALA( .~ OIL AND GAS CONSERVATION ~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing ~ Alter casing I Stimulate __ Plugging 2. NameofOperator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Repair well __ Pull tubing 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service Perforate __ Other ~ Wo rkover 6. Datum elevation (DF or KB) ....... RKB 104' 7. Unit or Property name Beluga River Unit 8. Well number 1012' FSL, 2194' FWL, Sec. 13, T13N, At top of productive interval 1012' FSL, 2194' FWL, Sec. 13, T13N, At effective depth Attota~ld2e;tr35L, 2194' FWL, Sec. 13, T13N, 1012' FSL, 2194' FWL, Sec. 13, T13N, 12. Present well condition summary Total depth: measured 10000 'MD true vertical 10000 'TVD R10W, SM R1 OW, SM R1 OW, SM R1 OW, SM BRU 224-13 9. Permit number/approval number 73-037/8-693 10. APl number 50-- 283-20042 il. Field/Pool Beluga River feet Plugs(measured) Top of Plug (~ 5670' feet Effective depth: measured true vertical Casing Length Structural 65 ' Conductor 423' Surface 3298 ' Intermediate 6999 ' Production Liner Perforation depth: measured 5670 'MD 5670'TVD Size 30" 20" 13-3/8" 9-5/8" feet Junk (measured) feet None Cemented Measured depth True vertical depth Dr i ven 65 'MD 65 'TVD 660 sx Cl ass G 423'MD 423'TVD 2010 sx Class G 3298'MD 3298'TVD 1645 sx C1 ass G 6999'MD 6999'MD true vertical See Attached Sheet feet Tubing (size, grade, and measured depth) See Attached Sheet Packers and SSSV (type and measured depth) See Attached Sheet 13. Stimulation or cement squeeze summarY/ N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production 'or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys ruq ~ ! Daily Report of Well Operations~__* Oil~__... Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title * Workover Well Hi story Area Drill ing Engineer Service Date SUBMIT IN DUPLICATE REPORT OF SUNDRY WELL OPERATIONS (Continued) BRU-224-13 Block 12 Perforation Depths' MD/TVD 3355 -3361 3376 -3396 3422 -3431 3435 -3482 4138 -4146 4294 -4304 4446 -4456 4476 -4490 4593 -4603 4676 -4694 4764 -4774 4916 -4924 4936 -4958 4966 -4986 5022 -5032 5050 -5086 5398 -5448 5494 -5516 Tubing Size' String #1' 2-7/8", N-80 tbg w/tail @ 5489', String #2' 2-7/8", N-80 tbg w/tail @ 3134' String #3 (Heater String)- 2-3/8", N-80 tbg w/tail @ 2199' Packers and SSSV' String #1: Baker 'AL-5' Dual pkr @ 3110', Baker 'HB' pkr @ 3735', Baker 'DB' pkr @ 3805' String #2: Baker 'AL-5' Dual pkr @ 3110' String #3: (Heater String): None kEEEIVED Oil & Gas Cons. ' ~ ~cl~orage SW03/077 ARCO ALASKA INC. Cook Inlet~ew Ventures Engineering TRANSMIlWAL #278 TO: Commissioner FROM: Tom Wellman COMPANY: AOGCC DATE: Dec.23, 1988 COMPANY: ARCO Alaska, Inc WELL NAME:Listed below Transmitted herewith are the following IBlue Sepia Sepia Line Folded Rolled Mylar Tape BRU 224-13 · Acoustic CBL 5" 1 1 · PDK-100GRCCL 5" 1 1 , · Collar Log 5" 1 1 · Gamma Ray 5" 1 1 BRU 232-4 ,' Acoustic CBL VDL/Sign/GR 5" 1 1 SCU 41A-9 ~ Production Log 5" 1 1 i ' Receipt Acknowledgement: Return reciept to ARCO ALASKA, Inc. ~ ~~~?~;7: ATFN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510- STATE OF ALASKA M~ AD-, ,A OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ v,/ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugg, j/Qg __ Time extension __ ~n ulate __ Change approved program __ Pull tubing __ Variance __ ,/v~Perforate __ Other 2. Name of Operator ARC..n A 1 ~.~l~a _ Jrl~. 3. Address P. 0. Box 100360~ Anchora~le~ AK 4. Location of well at surface 5. Type of Well: Development v/ Exploratory __ Stratigraphic __ 9951 0 03 60 Service __ 1012' FSL, 2194' FWL, Sec.13, T13N, RIOW, SM At top of productive interval Straight Hole - Same as Above At effective depth Straight Hole - Same as Above At total depth Straight Hole - Same as Above 6. Datum elevation (DF or KB) · RKB 104' 12. Present well condition summary Total depth: measured true vertical IO,O00'MD feet 10,000' TVDfeet Plugs (measured) Effective depth: measured true vertical Casing Length Structural Conductor 65 ' Surface 42:3 ' 3298' Intermediate Production 699 9 ' Liner Perforation depth: measured true vertical 5670 ' M D feet 5670'TVD feet Size Top of Plug ~ 5670' 9-5/8" 1645 sx Class G 6999'MD 6999'TVD 30" 65 'MD 65 'TVD 20" Cmtd to Surf 423 'MD 423'TVD 13-3/8" 2010 sx Class G 3298'MD 3298'TVD Cemented Measured depth True vertical depth See Attached Sheet Tubing (size, grade, and measured depth!.., ,, S e e A t t a c h e d S h e e t l~ '~ ~ 0~ & GSS C0RS. O0~iSS~0~ Packers and SSSV (type and measured ~):~ ~''': ~-:'''/D~-~OE .... ~,.,~.~.,.'~ ~':~:.d'. ...... ,; ...... ~~ ~chofa~8 See Attached Sheet 13. A~achments Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: October 15~ 1988 1'6. If proposal was verbally approved Oil __ Gas '// Suspended Name of approver Date approved . Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,0 ~ ~.,LL~ Title A.ssoci ate Enoineer Date (/ FOR COMMISSION USE ONLY - Conditions of a~pprovah Notify C°mmission so representative ma~'witness ' (J0) $A3/0042 IApprovalNo. ~,.. Plug integrity __ BOP Test ~ Location (Jlearance ~ ~, Mechanical Integrity Test ~ Subsequent form required 10- ,~"O~¢'- ORIGINAL SIGNED BY Approved byorderoftheCommissioner LONNIE C. SMITH Form 10-403 Rev 06/15/88 Approved Copy Returned ~~_~ .,'~ommissioner feet Date SUBMIT IN TRIPLICATE 7. Unit or Property name ,Belucja River Unit 8. Well number BRU 224-13 9. Permit number 7~-n.~7 10. APl number 50-- 283-20042 11. Field/Pool Beluga River Junk (measured) N o n e BRU 224-13 Block 12 Perforation Depths: MD/TVD 3355 -3361 3375 -3398 3422 -3431 3435 -3482 4936 -4958 4966 -4986 5022 -5032 5398 -5448 Tubing Size: 2-3/8", N-80 tbg w/tail @ 2164' 2-7/8", N-80 tbg w/tail @ 3194' 2-7/8", N-80 tbg w/tail @ 3920' Packers and SSSV: Brown 'HS 17-2C' Dual pkr @ 3151' Brown 'HB' pkrs @ 3701' & 3846' RECEIVED SEP 1 ? 1.988 Alsska Oil & Gas Cons. Commission Anchorage SA3/0042.2 General Workover Procedure BRU 224-13 Standard Completion Prior to MIRU 1. RU slickline. Pull tubing plugs at 3863" in string #1 and at 3170' in string #2. Bleed off tubing pressure. 2. Open XA sleeves at 3147' in string #1 and punch hole at 3130' in string #2. (XA sleeve at 3115' will not shift open.) RD slickline. 3. Circulate kill weight brine into annulus and into all tubing strings. Pressure test annulus to 2000 psi. 4. Set BPV's in all tubing strings. Related Work 1. MIRU 2. ND tree. NU BOPE and test. Pull BPV's. An~0rag0 3. Install 2-3/8" rams in BOP*s and POOH with heater string. 4. Install 2-7/8" rams in BOP's and POOH vith short string or string #2. 5. Spear long st-ring or string #1 and rotate to release CC safety joint at 3083!-, POOH with tubing string. 6. PU fishing tools and retrieve three packers from wellbore. 7. PU bit and casing scrapers. Clean out to PBTD at 5670'. POOH. 8. TIH with RBP and set at 3200'±. Test 9-5/8" casing to 2000 psi for 30 minutes. 9. ND BOPE and existing tubing spool. NU new spool and BOPE's. Test. 10. TIH with retrieving tool and pull RBP. 11. RU E-line. Run CET. Squeeze as required. 12. Reperforate required intervals with [2 spf. 13. PU bit and casing scrapers. Hake clean out run. Circulate well, POOH. LDDP. 14. RU and RIH with dual 2-7/8" production tubing and equipment. Space out as required and land tubing. 15. RU and RIH with 2-3/8" heater string and land. 16. Install BPV's in all strings. ND BOPE. NU tree and test. Remove BPV's. 17. Displace well with diesel by pumping down annulus. 18. Set packers hydraulically. Pressure tubing and shear out ball. Test the annulus/packer to 1500 psi for 30 minutes. 19. Install BPV's in all tubing strings. Release rig. 20. Release well to production. ps; ,4'¢ SR/85 ih 11" 5000 PSI BOP STACK BRU 224-13 ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAMS 5 3 1. 13-3/8" SURFACE CASING 2. 9-5/8" CASING HEAD 13-3/8"- 3000 PSI FLANGE 3. 13-3/8"- 3000 PSI X 11"- 3000 PSI TUBING HEAD 4. 11" - 3000 PSI X 11" 5000 PSI CROSS-OVER SPOOL. 5. 11" 5000 PSI BLIND RAMS 6. 11" - 5000 PSI PIPE RAMS 7. 11" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 10. 11. 12. 13. 14. BOP STACK TEST 1 . FILL BOP STACK AND MANIFOLD WITH BRINE. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTRE PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTEST MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE Al WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLI CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEE TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOL AND UNES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PI. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DM 08/31/88 ARCO Alaska, Inc{'~ Post Office '~× f 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Chairman Chatterton' Attached is our Application for Sundry Approval to shut-in BRU 224-13. Recent diagnostic work indicates the packer at 3151' MD is leaking. Our intention is to shut-in the well until arrangements can be made for a workover. You will note that we plan to commence these operations on or about October 13, 1987. Please call C. L.~Crabtree at 265-6298 if there are any questions. H. F. Blac~ke~r~ Regional Engineer HFB:CLC'ch'O065 /Attachment cc' Wellfile 224-13 RECEtVE OCT 1 ~' Alaska 0ii & ~'ch0ra~e ARCO Alaska, InC, is a Subsidiary of AtlanticRichfieldCompany '4 ~' ~ STATE OF ALASKA ~"' AI~ .... , OIL AND GAS CONSERVATION C ..,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing ~ Other Operation shutdown E3 Stimulate [] Plugging ~.. Perforate ,~ Pull tubing 2. Name of Operator 5. ARCO Alaska~ Inc. 3. Address 6. Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 7. 1012' FSL, 2194' FWL, Sec. 13, T13N, RIOW, SM At top of productive interval 8. Straight Hole At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical 5670 feet Plugs (measured) feet Datum elevation (DF or KB) RKB 104 Unit or Property name Belu~la River Unit Well number 224-13 Approval number 9. APl number 50-- 283-20042 10. Pool Be I u~la River Feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Structural 30" Conductor 20" Surface 13-3/8" Intermediate Product ion 9- 5 / 8" Liner Perforation depth: measured Cemented Driven 423'-surf 3298'-surf Measured depth 65' 423' 3298' 6999' up w/ 850 SX 3828' up w/ 500 SX 6999 ' True Vertical depth true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. StimUlation or cement squeeze summary As of November 24, 1987, ARCO Alaska, Inc. has shut-in the subject well with 8 7 ppg brine in both the tub Intervals treated (measured) strings and production casin9. Plugs were set in the Treatment description including volumes used and final pressure xn n i pp les at 3886' i n str lng 1 and 3193' in string 2. The well will be routinely monitored while shut-in. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ S. ~\¢.~ ~ ~;~~~TitleMgr-, Cook Inlet/New Ventur,es.. Engr~¢e Form 10-404 Rev. 12-1-85 Submit in Duplicate~.~, oo · qr O' (I) 0 (2) (3) A L ~jt'''¢ "UBING HANGER ,ANGER 1.0( · RECEIVED ~ : 1.2B' 512.35'--(2) 0TIS XA NIPPLE 1.28 -- 2164.35 ' -- (3) TUBING TAIL 54 JTS Z3~, 4.7~ 1668. I I' EUE SRO -- 3081.80'--(2)BROWN 30M~ ST PULL SAF~ JT -- 3083.06'--(I)BR0~ CC SAFETY JT 1.43' -- 3115.5~' -- (2)OTIS XA SLEEVE 2~8"~E 8RD -- 3147.40'--(I)OTIS XA SLE~E 27/8"EUE 8RD 3.23' -- 3151.46'--(182) BROWN NS 17-2C ~AC PACKER 9,58' -- 3193.50'--~)T~81~G TAlC OTIS XN NIPPCE 2~8'8RD 1.50' 3322* S~E~Z~D 41~"_dHpF 12/74 ~SS'* 33S~ 3375' * 3398* (23'P~RFS.)~ d ~" 34~'- 343t'(0' p~s )r ........ ~* SQUEEZED 4 i/2'~ J~F 12/74 ~'-3662'S~ED 2 I/2" JHPF 12/74 3663.53' -- (I) BROWN 60M~ ST. ~CC SAFETY JT 2.52' -- 3697.32*--(I) O~S XA S~E~ 2~8'EUE 8RD 3.23* 3701J2'-- (I) BROWN H8 PACKE~ 95/8'x 4l/2" ,7.65' -- 3811.66'-- (I) 8RO~ 60M~ ST. PUCC SAFETY JT 2.52* -- 3846~7'-- (I) 8~WN H8 PACKE~ 95/8"x 4~2" 7.65* -- 3886.1~--(I) OTIS XN NI~P~ 2~8' 8RD 1,50' -- 3918.91' -- (I) SHEAR SUB '66' -- 3909.57'-- (I) TUBfNG TAIL 49~6' o 49 S8'( 22' pfrRIrS.)~ ~ 49~'. 4986' (20'p~.) I ! BRU 224-l~ , ~ Y2'* JHPF ~ ~22'-~32' (lO PE~) [ i2/74 CASING ~ TUBING DETAIL -- T~ OF P~ 5670' ' m SEC. 13 T. 13N.,R.IOW. S.M. , REV. 10/84 NP9 , 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. ARCO Alaska, Inc. 3. Address 6. Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 7. 1012' FSL, 2194' FWL, Sec. 13, T13N, RIOW, SM At top of productive interval 8. Datum elevation (DF or KB) RKB 104 feet Unit or Property name Beluga River Unit Well number 224-13 Permit number 9. APl number 50-- 283-20042 At total depth 11. Present well condition summary Total depth: measured 5670 feet Plugs (measured) true vertical feet 10. Pool BP. I,Jgn R i ver Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length SiZe Cemented 30" Driven 20" 423'-surf 13-3/8" 3298'-surf 9-5/8" Measured depth 65' 423' 3298' 6999' up w/850 SX 6999' 3828' up w/500 SX True Vertical depth RECEIVED OC'i' l 1987 Alaska 011 & Gas Cons, ~[[t!!!llt~l AnehoraDa ARCO Alaska, Inc. proposes to shut-in BRU 224-13 while awaiting workover. Diagnostics indicate a leak through the top packer at 3151' MD. AIl Tubing (size, grade and measured depth) tubing, casing and annul i will be left with ki II weight fluids. The well will be routinely Packers and SSSV (type and measured depth) monitored wh i le shut-in. 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 13, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ ~~.l..r.~ Title R,egiona I Engineer Signed Commission Use Only Conditions of approval Notify commission so representative may witness i Approval No. [] Plug integrity [] BOP Test [] Location clearancel Date Approved by ~eturr~¢~ /) - Commissioner Form 10-403 Rev 12-1-85 Dy oraer oT the commission Date Submit in triplicate (I) (2) (3) K.B. ?~' ~'UBING HANGER TUll' .~ANGER 25.0( I.~ --- 494.99'~($) OTIS X NIPPLE ~ 506.18'~ (I) OTIS X NIPPLE --' 512.$5'--(2) 0TIS XA NIPPLE ~ 2164.3S * -- ($) TUBING TAIL 54JTS 25/8"4.?e RUE 8RD $081.80' ~ (2)BROWN $OM# ST PULL SAFETY JT $085.06' ~ (I) BROWN CC SAFETY JT $115.55'~(2)0TiS XA SLEEVE 27/B'EUE 8RD $147.40' ~ (I)OTIS XA SLEEVE 27/8'RUE 8RD $151.46'~(1&2) BROWN HS 17-2C DUAL PACKER ~ 3193.50'~ (2)TUBING TAIL OTIS J~)N.~:~~bBRO 3435* - 3~2'(4?'PERFS~ 3525',SQU[EZED 41/2'~ J~F 12/74 - .~ -3662' s~;~;~ ~ ,/~" ~.P;~ Oil & G~ ~,s. Co~;rSSio, -- ~663.s~'-- (t) BROWN 60Me ST. ~8~ ~T -- 3697.32'-- (I) O~S XA S~[~ 2~8'~U[ $?01 32'-- (I) BROWN HB PACKER 9S/8'x 41/2. -- 3811.66' (I) BROWN 6OM# ST. PULL SAFETY JT --- $846~37'~ {I) BROWN HB PACKER 95/8"x 4~'2" ~ $886.1(Y ~ (I) OTIS XN NIPPLE 27/8" 8RD m 3918.91'~(I) SHEAR SUB ' $919.57' -- (I) TUBING TAIL 1.25 1.28 I .28 1668. I I' 2.52~ I. 4:3 3.23' 3.23' 9.58' I.SO' 2.52' 3,25' .7.65' 2.52' 7.65' 1.50' ~66' 4936'- 49 58'(22' PERFS.q 49~'-4986' (20'I~ERFS.) J I 5022'- 5052' (,0' PERFg Ji~4 ~2 --- TOP OF PLUG 5670' T.D. I0,000' FO~ ADDI..PERI~.BEJ.OW PLUO,~E COMPL. BRU 224-15 CASING 8~ TUBING DETAIL SEC. I$ T. iSN.,R.IOW. S.M. Ri;V. 10/84 NP8 Chevron U,S.A. INC. .. '~? COMPLE*rlON RKPORT- REMKDIAL AREA: Beluga River Field PROPERTY: Beluga River Unit WELL NO: BRU 224-13 ',AND OFFICE: LEASE NO: API NO: Anchorage ADL-58831 50-283-20042-00 LOCATION AT SURFACE: 1012' N & 2194' E of the SW Corner, Section 13, T13N, R10W, S.M. LOCATION AT TOTAL DEPTH: Straight Hole ELEVATION: K.B. 25' SUMMARY TOTAL DEPTH: 10,000' EFFECTIVE DEPTH: 5,660' CASING: 30" Driven to 65' 20" Cemented at 423' 13-3/8" Cemented at 3,298' 9-5/8" Cemented at 6,999' DRILLED BY: Brinkerhoff Signal Inc. #58 DATE COMMENCED WORK: 9/4/84 DATE COMPLETED WORK: 9/17/84 DATE: 12/84 RECEIVED J^ IV 2 1 1985 Alaska Oil & Gas Cons. Commission Anchorage Halliburton Formation Tests HFT it 1 6,422'-6,470' HFT it2 6,117'-6,176' HFT it3 6,026'-6,076' HFT it4 5,820'-5,848' HFT it5 5,681'-5,758' HFT it6 5,398'-5,448' HFT it7 4,936'-5,032' HFT #8 3,755'-3,760' Logs: Schlumberger Dual Induction Log Bottom Hole Compensated Sonic Log Compensated Neutron From. Den. Formation Density Log Proximity Log- Microlog Continuous Dipmeter Cement Bond Log Chevron Geophysical Division Dipmeter-Dip and Azimuth Display Dip and Azimuth Display (selvec) Quality Control Plot Hydrocarbon Anomaly Search Azimuth of Dip vs. Depth Dresser Atlas Log Runs Speetralo~ Multi-Spaced & Compensated Neutron Epilog LAC Analysis Dual Detector Neutrol Lifetime Log 422'-9,982' 422'-9,979' 422'-9,989' 422'-9,988' 3,294'-6,998' 3,294'-9,989' 3,200'-9,989' 3,200'-7,000' 3,200'-7,000' 3,200'-7,000' 3,281'-6,110' 3,200'-7,000' 3,000'-5,660' 3,000'-5,660' 3,000'-5,660' 3,000'-5,646' 2"-5" 5" 5" 5" 5" 5" 5" 2" 2" 1/200 Previous Rig Work: Drilled: Kenai Drilling Company Rig #1 9/27/74-12/16/74 Workover: Brinkerhoff Signal Rig {{58 3/12/81-4/5/81 Runs 4 4 4 4 2 3 1 224-1.3 9/1-9/2/84. Completed moving Brinkerhoff Pig #$8 from BRU 212-25 to BRU 224-13. 9/3-9/4/84 Completed rigging up Brinkerhoff Rig #58. Accepted rig at 8:00 9/4/84. 9/5/84.., 9.9 ppg. Build 3% KCl-saturated NaCI brine for workover fluid. Pulled 2-3/8" X 2-?/8" blanking: plugs. Pumped a 30 bbl. ~'aded NaC1 salt pill followed by 125 bbl. brinewater. Circulation pressure dropped from 2250 psi to 1550 psi. Installed PS plug in Otis Pos. 2 "$" nipple at 3863' in the 2-7/8" tubing. Opened XA sleeve in 2- 7/8" tubing at 3621'. 9/6/84 9.9 ppg. Unsuccessfully attempted to kill well by pumping brinewater down 2-7/8" tubing through XA sleeve at 3621' and up 2-3/8" tubing leak and out annulus.' Pumped brinewater down 2-3/8" tubing and up 2-7/8" tubing through XA sleeve at 3621'. Lost 40 bbls. of brinewater while circulating. Closed XA sleeve at 3621' and opened XA sleeve at 3226'. Pumped 9.9 ppg brine down 2-7/8" tubing. Pumped brine down 2-7/8" tubing and out heater string. Pumped brine down 2-7/8" .tubing through leak at unknown depth. Closed XA sleeve at 3226'. Pumped 2-1/4 bbl. frae gel and t bbl. fresh water 5 SX Cai Seal eement~ and I bbl. fresh water down 1.9" heater string. 9/?/84 9.9 ppg. WOC, tested cement plug in heater string to 500 psi for 5 min. Nippled down Xmas tree Picked up tree and string II (2-3/8") came up with tree. Sat back down. Nippled up tree. String II tubing appears to be parted close to surface. Circulated well dead. Nippled down tree. Set pump through back pressure plugs in 2-7/8", 2- 3/8", and 1.9" tubing strings. Installed 2-7/8", 2-3/8" and 1.9" blanking plugs, nippled up blind rams with rams closed. Elapsed time to N.D. tree and NU BOPE was 35 minutes. 9/8/84 9.9 ppg. Pulled 2-3/8" blanking plug. Pulled string II. String II parted at collar. Recovered 1 jr. and I pup joint of string II. Changed rams to 1.9", pulled and recovered 59 joints of 1.9" heater string (string III). Changed rams to 2-7/8". Rigged up Alaska Pipe Recovery wireline. Cut String I (2-7/8") at 3?9?' 5' below safety joint and at 3200' 5' below safety joint. Recovered 103 joints (3188') of string I tubing. Changed rams .to 2-3/8". 9/9/84 9.9 ppg. RIH with O.S. and engaged string II at 49'. Pulled and recovered all of string II. Changed to 4{" drill pipe. Engaged top of string I at 3192'. Released packer with 100,000# overpull. 9/10/84 9.9 ppg. Circ. out gas bubble. POOH. Recovered Baker 9-$/8" Dual AL-5 packer with 2- 3/8' tubing tail and top of Baker safety joint. Top of fish at 3587'. RIH with overshot. Engaged fish. POOH. Recovered Baker FHL packer, 5 jts. 2-7/8" tubing, 2-7/8" Baker safety jr. and cut-off jr. top of fish at 3797'. RIH with overshot. 9/11/84 9.9 Attempted unsuccessfully to en~a~e fish with overshot. POOH. Hollow mill had concentric 4-~ .,'2" - 5" pattern. RIH with revamped lip-~uide overshot and engaged fish at 3?82'. Pulled 15,000# - slacked off holding 5000# tension. C.A. White RIH with wireline - could not latch PS plug in 'S' nipple at 3863'. Pan bailer and recovered metal chunks, pebbles and metal shavir~s. Alaska Pipe Recovery perforated the tubin~ at 385?'-3859' with 3-0.4" ~un with 500 psi on drill pipe. Pressure dropped to 0 psi. Pumped 10 bbls. brine - pressured up to 1500 psi with slow bleed off to 0 psi on drill pipe. POOH with perforating tools. Released 9-5/8" FH packer with 30,000# overpull. 9/12/84 9.9 ppg. Recovered all of the tubing fish. Made bit and tandum easing scraper run and ta~ged bottom at 5660~. Chan~ed pipe rams to 2-7/8". 9/13/84 Picked up 2-7/8" tubing.~ POOH and stand back 2-7/8" tubing in derrick. Changed rams to dual 2-7/8". Began runnir~ dual 2-7/8" tubing strings in hole hydrotesting to 3000 psi. 9/14/84 Landed dual combination strings of 2-?/8" 8rd (string II) and 2-7/8" buttress (string I) tubing. H~,drotested tubing to 3000 psi. Char~ed rams to single 2-3/8". Ran and landed 69 joints of 2-3/8" 8rd tubing at 2162'. (See attached tubing details.) Nippled up tree. NOTE: 3t" Box on the J latch sub above the dual packer in string 2 will not pass through the parent har~er. Ail tubing measurements are from an origianl 25' K.B. 9/15/s4 Tested tree to 3000 psi. Reverse circulated all tubing strings and the annulus full of diesel fuel. Master ~,-*e on string II did not appear to close. Could not get through valve while attempting to set BRV. Attempted to open valve with wireline swedge. Valve fully closed. Surface pressure of all strings of tubing and the annulus 600 psi. Set the bottom two packers and sheared shear sub. 9/16/84- 9/17/84 Flew in Otis gate valve hot tap machine and drilled gate out of master valve. Set 2-7/8" PXN plug with sliekline in the string IL 2-7/8' XN nipple at 3193'. Set dual packer and tested annulus to 2000 psi. Bled annulus and string II tubing to 0 psi. Repaired defective valve and tested valve to 3000 psi. Retrieved 2-7/8" PXN plug from string II string XN nipple at 3193'. Flowed string I (Beluga Zone) at a rate of 4 MMCF/D with an upstream choke pressure of 1100 psi. Choke was washed out. Shut well in at 5:00 a.m. 9/17/84. String I shut in surface pressure was 2200 psi after cleaning up well. Unloaded diesel fuel from the annulus and heater string using gas from string I. Placed string 1I (Sterling Zone) on production at a final rate of 5 MMCF/D at a surface flowing pressure of 1340 psi. Installed 2-7/8~ Cosaseo BPIPs in strings I and 1I. Release rig at 4:30 p.m. 9/17/84. BRU 224-13 SW t Seer. 13, T.13N, IL.10W, S.M. STRING I K.B. Tt~. Hanger 1 Jt. 2-7/8' EUE 8RD N-80 4.7# XO: 2-7/8" EUE 8RD B x 2-7/8" Butt., P. 2 Put Jts. 2-7/8" Butt. N-80 8 Jts. 2-7/8' 6.4# Butt· N-80 1 Pup Jt. 2-7/8' Butt. 6 Jts. 2-7/8" 6.4# Butt. N-80 Otis X Nipple 2-7/8' Butt. 84 Jts. 2-7/8" Butt. XO: 2-7/8" Butt., B x 2-7/8" EUE 8RD, P. Brown CC Safety Jr. 2 Jts. 2-7/8" N-80 EUE 8RD Otis XA Sleeve 2-7/8" EUE 8RD XO: 3t" 8RD, P x 2-7/8" EUE 8RD, B. Brown HS 17-2C Dual PKR 9-5/8 x XO: 3t", 8RD, B x 2-7/8" EUE 8RD, P. 6 Jts. 2-7/8", N-80, EUE 8RD 8 Blast Joints 5 Jts. 2-7/8" N-80 EUE 8RD BrOwn 60M# Strait Pull Safety Jt. I Jr. 2-7/8" N-80 EUE 8RD Otis XA Sleeve 2-7/8' EUE, 8RD XO: 4t", P x 2-7/8" EUE 8RD, B Brown HB Packer 9-5/8" x 4 t" XO: 2-7/8" EUE 8RD, P x 4t, B 3 Jts. 2-7/8' N-80 EUE 8RD Brown 60M# Strait Pull Safety Jr. i Jr. 2-7/8" N-80 EUE 8RD XO: 41", P x 2-7/8" EUE 8RD, B Brown HB Packer 9-5/8" x XO: 2-7/8" EUE 8RD P x 4~" B I Jr. 2-7/8" N-80 EUE 8RD Otis XN Nipple 2-7/8" 8RD 1 Jr. 2-7/8" N-80 EUE 8RD Shear Sub Tubing Tail LENGTH 1.00' 30.74' .71' 15.20' 244· 59' 5·07' 183.87' 1.28' 2574.78' · 82' 1.43' 62.91' 3.23' · 83' 9.58' .50' 186·22 162· 38' 153.39' 2.52' 31.27' 3.23' · 77' 7.65* .77* 101.92' 2.52' 31.49' .70' 7.65* · 68' 31.40' 1.50' 31.31' .66' DEPTH 25.00' 55.74* 506.18' 3082.24' 3083.06* 3147.40' 3150.63' 3151,46* 3161.04* 3663.53' 3697.32* 3700.55' 3701,32* 3708.97' 3811.66* 3845.67* 3846.37' 3854.02* 3854.70* 3886.10' 3887.60* 3918.91' 3919.57' BRU ~14-13 STR~NG 2 K.Bo i Jt. 2-7/8" EUE 8RD XO: 2-7/8" EUE 8RD, B x 2-7/8" Butt., P 2 2-7/8" Butt. Pup Jr. 14 Jts. 2-7/8*' 6.4# Butt. N-80 Otis XA Nipple 84 Jts. 2-7/8" 6.4# Butt. N-80 XO: 2-7/8", Butt. B, x 2-7/8" 8RD, P Brown 30M# Strait Pull Safety Jt. i Jr. 2-7/8" 6.5# EUE 8RD N-80 Otis XA Sleeve 2-7/8" 8RD I Jr. 2-7/8" EUE 8RD N-80 XO: 2-7/8" EUE 8RD, B x 3{", 8RD, P Brown 3{" J Latch Sub Brown HS 17-2C Dual Packer (9-5/8" x 3{" x 3{") XO.. 2-7/8" EUE 8RD, P x 3{", 8RD, B i Jr. 2-7/8" EUE 8RD Otis XN Nipple 2-7/8" 8RD Tubing Tail LENGTH 31.19' .68' 15.20' 433.58' 1.28' 2574.00' .87' 2.52' 31.21' 3.23' 31.23' · 83' 3.51' 9.58' .62' 31.07' 1.50' DEPTH 25.00' 56.19' 512.35' 3080.93' 3081.80' 3115.89' 3147.12' 3151.46' 3161.04' 3192.00' 31.93.50' BRU HEATER STRING (STRING III) K,Bo 15 Jts. 2-3/8" 4.?# EUE 8RD N-80 Otis X Nipple 54 Jts. 2-3/8' 4.7# EUE 8RD N-80 Tubing Tail LENGTH 469.99~ 1.25~ 1668.11~ DEPTH 25.00' 494.99' 2164.35~ \(~ D ACKNOWLEDGE/tENT OF ItEC - ~o · ~TS~t,,U.,- (~L~A) DATE THE FOLLO~NG IS A LIST OF HATERIAL ENCLOSED HEREIN. FD- Folded - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND Al)VISE IHHEDIATELY. ii [ /, m __ I -- i*' ii II " i i mm RECEIVED ElY _ I i mlli I -m · m i REMARKS ON OTHER SIDE, THIS SHEET N. ~. 6 c A cc,~o~., CHEVltON U.S.A. INC. BOX 7-839 ANCHORAGE, ALASKA 99510 .. 'S~ ~'~ STATE Of ALASKA ALA ~ OILAND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 73-037 3. Address 8. APl Number P.O. Box 107839, Anchorage, Alaska 99510 50-283-20042-00 4. Location of Well 1012' N. & 2194' E. of the SW Corner, Section 13, T. 13 N., R. 10 W.,'S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25' K.B. 6. Lease Designation and Serial No. ADL-58831 9. Unit or Lease Name Beluga River 10. Well Numb~ BRU 224-13 11. Field and Pool Beluga River - Sterling 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate I'-I Abandon [] Stimulation [] Abandonment [] Repair Well [~ Change Plans [~ Repairs Made [] Other [] Pull Tubing [~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any Proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. (This notice is a revision to the notice, approved 6/22/84.) This work will begin on or about 9/4/84. R CEI.¥ D AUG ~ 0 1984 Alaska u:l ~, [-;as Cons. Oommis$iOrl .Anchorage Subsequent Work Reported Signed Title Area Engineer The space below for Commission use Date, Conditions of Approval, if any: ORIGIliAL Slilli£D i! LIIIlilE L Sllll Approved by. COMMISSlON ER Approved Copy By Order of the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Tril~icate and "Subsequent Reports" ir3 Duplicate BRU 224-13 NOTE: Tho Baker lstch-in a~sembly on String 2 (2 3/$')viii not oull through tho parent ~ The I~tch-in n_qqemblv is 3.80" OD nnd crossed over t~tck to ~ 3/S' tubin_f. The n,--imum OD that cnn be oulled thf*oufh tho oa~ent haflfer on tho 2 3/8' side is 1) Prepare the location for the vorkover rig. 2) Move in and rig up the vorkover rig. (Rig up to recover all fluids and cuttings) Mix up 8 clear brine kill fluid conteining 3% KCL and sstursted vith NaCI es per the attached ~ompletion Fluid Program. Mix and spot lev fluid loss pills 8s needed using sized s~lt. Report the d&ily and cumUltive mount of the brine lost to formation on the Pro 562's, 4) 5) Pump 100 Bbls. of' brine dovn String 1. Set 8 PS plug in the Otis 2 7/8"Position 2 '$'nippfe st 3863' and open the 2 7/8' Lq Sleeve st 3621"in String 1,. Kill String 1. String 2, String 3 (Heat st~ing~ and the tubing by 9 5/8"casing annulus by circulating brine dovn each string and up the tubing x 9 5/$": annulus. 6) Plug String 3 vith Halliburton's K-Trol-10Cas foHovs: Mix and pump5 Bbb of 2% KCI brine rater relieved by 150 gsls. of K-TreI-10C solution(mixed in 2 % KCI brine) down String 3. Inject the cstalys~ vhile pumping the K-TroI-10C. Displace vith 1 Bbl. of 2% KCI brine vater plus line volume to lesve the top of the K-TroI-10C st'~ 400'. W~,it & minimum of 4 hours to slier the K-Trol- 10C to set up, (Pumping time of theiK-Trol-10C solution: 30 minutes at 60o F, 40 minutes at 40o F.) 7) Pressure test the K-Trol-10Cplug to ~d)0 l~i.. 8) Set pump through back pressure plugs in Strings I and 2, 9) ND the tree, instefi the 1.5" pump through Cossasco BP v~lve in the he~t string and Gr~y Tool Company's blanking plugs or simil~ equipment in String 1, String 2, the heat string(String 3).NU · 3000 psi. or higher rated Class III BOP. lns~l 1.900" pipe Funs. Test the BOP to 3000 psi.,(Alert both the A0ed~ and the BLM 24 hours. prior to the BOP te~) Remove the'blanking plugs from String I, St;ins 2, and the heat string. Pull the back pressure plugs as needed. ~ ~' I0) Pull and ¼y dovn the heat string (1.900"): l, be Z $/$" tubing is to be used as the be~, string-$~ing 33 Change to 2 3/$" PuU Strin~ 2. Reco?er the pm'eot banger. (Send ~l] the bangers to G~y Tool Company to be redressed and to h~ve tho 1.900" hanger blanked off.) 12) Pick up drift pipe. drill collars, and fishing equipment as needed. Recover tho remaining robing and packers. Remove the plug From the 2 ?/8 Otis position 2 'S' nipple at 3S65' in String I vhen practictl. 13) Pick up an 8 1/2' bit and 9 5/$" 47' tandum casing screpere. RIH and clean out to PBTI) at ~660' or as deep u possible to s maximum oF ~660'. POOH 14) Run the production tubing as sliovn in the attached Proposed Tubing l)etaU. Run the 2 7/$" String I and the 2 7/8" String 2 together, hydrotesting each string to ~)0~. l. and the tubing in the hanger. Blank off the 1.50, hanger with a speciaJ locking buU plug which viii hold the tubing hanger in the pa~ent hanger. 15) Run end land the 2 3/8" heat strin8. 16) Set BP v&lves and ND the BOPs. NU the tree. 17) Circuhte out the brine va~r by circulging diesel down the annulus &nd up all tubing strings. Drop the b~ll and set the psckers. 18) Rig up the test beater and separator to String 1. Flow String I until the veU cleans up. Rig up String 2 to the test heater and sopo. r~or end flow String 2 until it cleans Up. Rig up String 2 to the tubing by 9 5/8" annulus end String3 to the test heator lnd sepaAtor unload the diesel out of the annulus. 19) Set back pressure plugs. Rig down the vorkover rig and move out. 20) Inste/l the production faciUties so that afl or some of String 2 gas is circuhted through the heater, down the tubing by 9 ~}/8" annulus, and up String 21) Return the veU to production as per the Ares Foreman or Anchorgge Engineering. AUG ~ 0 1984 Anci]orao~ 2 Proposed BRU 224- 13 Tubin Detail--B/29/B4 m m String I and 2--One landing joint of 2 7/8" [U[ 8rd v/ 2 7/8' 8rd box x 2 7/8' Butt. pin cross over '500' String 3--2 3/8" Otis X nipple '500' String 2--2 7/8" Otis X nipple '500' String 1--2 7/8" Otis X nipple Siring I and 2--2 7/8" &.4s 1180 Buttress '1500' String 3--2 3/8" Otis XA Sleeve '3090' String 1--2 7/8" Brown CC Safetu ,Jt.Brd w/8rdxButt.X-O '3120' String 2--2 7/8" Otis XA Sleeve 8rd w/8rdx Butt. X-O '3000' String 3--2 3/8" tubing tail '3148' String 1--2 7/8" Otis XA Sleeve '31S0' g 5/8 "x 2 7/8"x 2 7/8" Brown HS 17-2C Dual Packer w/,J Latch '3180' String 2--2 7/8" Otis XN nipple String I and 2--2 7/8' &.5m N80 [U[ 8rd tubing belov the CC Safetll Jr. ia String I and the XA Sleeve in String 2. '3340' String 1--2 7/8" Blast dis. '160' 3355'-336! ' 3375 '-3398' Perforations 3422'-3431 ' 3435 '-3482' '3615' String 1--2 7/8" Brown Straight Pull Safetg Ut. 60PI# '3645' String 1--~2 7/8" Otis XA Sleeve '3650' 9 5/8" x 2 7/8" Brown HB Retrievable Packer '3750' String 1~'-2 7/8" Brown Straight Pull Safet~j Ut. 60PI# Shear Shear 3755' to 3760' Cement Squeezed Perfs. '3800' g 5/8 x 2 7/8" Brown HB Retrievable Packer '3830' String I--2 7/8" Otis XN nipple ....... '3860' string 1--2 7/8 Brown ~ireline Enteru .uuide'W) .... ?F ~ Shear Out Sub 4936'-4958' ---- 4966'-4986 ---- Per~rations 5022'-5032' ,1~ S398'-S448' 5660' PBTD AUG 0 ]984 Alas~(a O~l 6, {~as C3n$. Ccir'.mJss/oiT Anchorage String3--2 3/8' 4.6s N80 EUE 8rd tubing v/T&B Cplgs. ir STATE OF ALASKA ( ..... '"~ ~" AkASfi,,' b,k AND GAS CONSERVATION GOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 73-~7 3. Address 8. APl Number :P.O. Box 107839, Anchorage, AK 99510 50-283-20042-00 4. Location of Well 9. Unit or Lease Name Beluga River 1012' N & 2194' E of the SW cor., Section 13, T.13N, R.10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 25' K.B. 12. I 6. Lease Designation and Serial No. ADL-58831 10. Well Number BRU 224-13 11. Field and Pool Beluga River - Sterling & Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1) Moved in and rigged up Brinkerhoff rig #58. Nippled up BOPE and tested to 3000 psi. 2) Killed well with 9.9 ppg 3% KC1 and saturated NACL brine. Pulled 2 7/8", 2 3/8" and 1.9" production tubing. 3) Ran dual strings of 2 7/8" production tubing with dual packer at 3151', string 2 (Sterling formation) tubing tail at 3194', single packer at 3701', single packer at 3846', and string 1 (Beluga formation) tubing tail at 3920'. 2 3/8" heater string at 2164'. 4) Nippled down BOPE and nippled up tree. 5) Flowed well with a maximum rate of 4MMCFD at 1100 psi in string 1 and a maximum rate of 5MMCFD at 1340 psi in string 2. 6) Rigged down and moved off rig. 7) Installing flow lines. Estimate well will be returned to production 10/1/84. RECEIVED Aia. Ska 0il & Gas Cons. Commission Anchorage ,. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ . ~. ~ Title Area Engineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate an d "Subsequent Reports" i n Duplicate Rolled - Sepia F - Film X'- Xerox Q - Blueline THE FOLLOWING IS A LIST OF ~[ATERIAL' ENCLOSED tlEREIN. . PLEASE CHECK AND ADVISE' II'D[EDIATELY' · · CH2:vitON d.$.z', J.~b. . ""' · , ,, lOX 7~3~ -' 'T'. . . CHEVRON U.S.A. INC. ~,._~D ACKNOI~LEDCEHENT OF' ¢o, ~T~-re oF AL./k~KA ~,~c~= :5Ool Poc.,e__...uPl~dF___._ DC,. Aao ,AIC ~lled Sepia Film ~rox Blue~e THE FOLLO~FING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. ~ukib¢..'.l k~OTIcF_~ ,~.IRF_.POKT"5 Od V~/~· - I~ TP___..IPL..IcATE. ~ OTI CK 13~CUC. TA ,,, E,~'LUGA OF" :T_.d'rF_~T :,, ~ VE~Z,. W'~ vL-- B Rd , 22.4-1.3 2_12. -24 iiii ii ii roll ii _ ii J iii i i iii ii i i~ii ~' -- m'C ' mm -- 1 II,mill I IIIIII RECEIVED 8Y REMARKS ON OTHER SLOE, THIS SHLrET CHEVRON U.$J~ INC. BOX 7.839 'ANCHORAGE, ALASKA 99,510 TRANSHITT(/ CHEVRON' U.S.A. INC. ,D ACKNO~,rLEDGEMENT OF REC~IP<: MATERIAL DATE FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE I10~EDIATELY. -- . Il , Ii -_ i RECEIVED BY Aflchoran~. BOX 7.839 REMARKS ON OTHER SIDE, THiS SHE'E'T 'ANCHORAGE, ALASKA 99510 Page l of [ DAILY PROGRESS OF WELL WORK For all W.L. work, perf. jobs, solvent jobs or other subsurface work other than drilling. Well no. ~V 22~-/~ .,, Field: Object: ~F~,~,,~ ~ v~ ~ All contractors present during work C~, Work detail breakdown: Contractor signature and Company (if detail prepared by Contractors) Results by Company Representative 7; ' ':' ,-,:' "' ,%; 0,,,~, 17E~ / cc: Production Foreman Area Engineer Well File - Original MAY 0 3 1984 Alaska Oil & Gas Cons. Commission Anchorage Company Repr~s~~ive Signature ' -- and Date CqNTROL NO: ENGR. REQUESTING~ PRIORITY' 1 WEEK ANTICIPATED RESULTS: DATE REQUESTED: ~/~f-,,' LOWER GOR LOWER WOR TEST ONLY 1 MONTH OTHER: DETAIL BELOW STATUS OF WELL: G.L. S.I. G. INJ. WTRINJ. DATE OIL WTR GOR GI WI RECENT GAUGE: GLR: PERTINENT DEPTHS: Attach Mech. Cond. Schematic (1) Mandrels~ _~¢ ~ (2) Sleeves ~_ (3) Ldg. Nips. ] ~//~t~/ (4) Other _~ , PROGRAM: . - / ~ . /- - , ......... __ ~ ' .,, ~ . · ~ ', ~ ~ - . - - _ ~ - -, - ,_ ~ '. , , ~.~ ~.~~ ~. - , ,- /,- ,,- . - . .. EC IVED FOREM~N: Please acknowledge work request upon completion. If unable to complete work, please furnish detail. T N 2S OC K.B. TO ANGER - (21 I JT. + Z' I0' & 8' PUPS 2~" TBG. SO. SO' ,. ~ El) 2 JTS. 2~' S.S"(U( SRO N'80 TIG. 76.80~ (2) 2~0 OTIS '~ NIPPLE Position 2 1.44' '°7'8~~(t) 2;0" OTiS '90 NIPPle Position 4 1.58 . - -- (31 59 JTS. 1.9" NU lO THO N.80 L983.86' cp'd j A *'(I) I00 dTS. .... (3) 1.9' TUBING INTAKE (Z) 103 ,JTS. 2~I." 4.7°EU_E 8RO N.80 $17cJ.74' 3191.43'- ' )-- (I) 2~11" 8ROWH CC SAFETY. JT. 3.58 --(I) I. JT. 2~"6.SE EUE N-8OTUBING 31.12 ---3226.13'-- 3229.17' ~--(IJ 2~'1" OTIS XA 'S:EEVE 3.14 3~?.98' --(I) I~,,,I,T. 2~*'8.Si EUE N-8OTUBING , 31.12 x~ifl qo*-~"(2) 2 s OTiS XA SLEEVE. 2.80 ' - , r BORES - ' i4.5! ~Z?s.~; --~(,) ~"X ~; x-o (=t z~'cA~.co'o"mp~~ ~o?' o.~ ... ~ E~ OTiS S NIPPle Position 3 1.5; ~ss:-3--,' '~ I ;T. ~; 6. SSEUE N-e0 TUBING 31.4~ ~4ZZ'-3431' . ~ 8-20 & 2' I0 .BAKER 8~AST JTS. '102.5~ 3~30'- 3482 3586.74"~ 2. JTS.** 2~ 6.~ EUE H.90 TUBING_ -62.9, w~l qK'~ ' ~ ~ ' --3656.97',~ 9%" 8AKER"FHL' PACKER · 7.2t 3664. 25'~ , . -. ]Tss~ 37i~,,~ ,0, i 4 JTS. 2~'~.54EUE 8RD N-80 TUBING 123.li 4,oo. uu~ 2~"BAKER SAFETY JT. 60,000~ SHEAR 3.51 I aT. --3823.76'~ -- 389~.8E~ --~__ 3 897. 36' ~ 3898.3S*.--/ ~ . .1936 i4066 , :,,.,. RECEIVED ~ ~ i'"' MAY o ~ 1984 · Alaska 0il & G~s Oons. fiommis: Anchorage T.~. I O,OOO' I-I a%", 3,'; x.ove. 9~'BAKER "FH" PACKE. ~';' X'OVe. JT. ~" 6.5~ [U[ 8RD N-80 TUBING OTIS "S' NIPPLE Position 2 JT. 2~" 6.5~ (U( SRO H-e0 TUBING BAKER SHEAR-OUT SUB 8ROWN SHEAR 'OUT SUB I. I~ 6.9,' 0.91 30.3E 31.lC I. SC 0.9~. REV. .I2- Il- eS 8. R. U. CASING TUBING DETAIL i°nSECTION I$ T. ISN.,R. IOW. -- 3824.90'.--( ~.. --3831.85'--, --3863.18'-- --3191. --3226.1 3229.17' 3260. · 32 6 I. 3277. 13' 3309.77' 3356' : · 349?' 3586.74' -- 3633.98'| --3656.97'--t -- 3664. 25' 3759' 3760' -- 3788. --38 --3831.85' tiP' .. -- 3895.16' -- 3 897. 36' -- 3898.35' . ' RECEIVED MAY 0 3 ~[~4 .. ~,.,~o,~ R.U. 224 -1:3 CASING TUBING DETAIL SECTION 13 T. 13N.,R. IOW. CHEVRON U.S.A. INC. · ii (r STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION CUMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING wELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchorage, AK. 4. Location of Well 99510 1012' N & 2194' E of the SW Cor., Sec. 13, T13N, R10W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) _. 25' K.B. 12. 6. Lease Designation and Serial No. ADL-58831 7. Permit No. 73-037 8. APl Number 50- 283-20042-00 9. Unit or Lease Name Beluga River 10. Well Number BRU 224-13 11. Field'and Pool Beluga River - Sterling & Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit:in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~] Change Plans J-~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). _ See attached. This work will begin on .or about July 16, 1984 RECEIVED Subsequent Wc~I~ RepozCecl · ~.u~d ~/~~ JUN 2 2 1984 ~homge 14. I hereby certif)~ that the foregoin,g~is true and correct to the best of my knowledge. Signed Title Area Engineer The space below for Commission use Date ConditiOns of Approval, if any: Approved by. Form 10-403 SIGNED Approved Copy Returned By Order of COMMISSIONER the Commission Submit "Intentions" in Trlphcate Rev. 7-1-80 and "Subsequent Reports" in Duplicate WKLLWORK PRGCKDURK SUMMARY WELL: BRU 224-13 1012' l~ & 2194' E of the ~W. Corner LOC.: of See 13 T13N R10W SB&M FIELD*. Beluga River Unit TYPE WELL: Gas Producer OBJECTIVE: Pull 2 3/8" string II, locate and repair leak in tubing, rerun tubing, and return the well to production. WELL DATA:K.B. to Ti)g. Hanger: 25* KB Elev: 93* TD: 10,000' PBTD: 5,660* CASING: 30" to 65* 20" to 423* 13 3/8" to 3,298* 9 5/8" to 6,999* TUBING: String I- 2 ?/8" 6.5# N80 EUE 8rd to 3,898* String 1I- 2 3/8" 4.7# N80 EUE 8rd to 3,307* String HI (Heat) - 1.9" 2.9# N80 10rd to 1,984' 9 5/8" Casing Detail Top 2,153.56' 1.26' 1,674.90' 1.80' 3,084.44, 1.42' 83.05' 1.70' 7,002.13' 3.00' 6,999.13' 51 Jts. 42 Jts. 76 Jts. 2 Jts. 43.5# P-IlO Buttress x-over 47# 8rd N-80 LT&C Stage' Collar (3,829.72') 47# 8rd P-Il0 LT&C - Baker Float Collar 47# 8rd P-110 LT&C Baker Shoe Ab°ve K.B. Casing Landed PERFORATIONS: Sterling A Zone 3355* - 3361', 3375' - 3398' 3422' - 3431', 3435' - 3482' Beluga G Zone 4936' - 4958', 4966' - 4986' 5022* - 5032* Beluga H Zone 5398' - 5448' FORMATION PRESSURES: (Estimated) Sterling A Zone: 1500 psi at surface, 1630 psi ~ 3418' TVD MPP Beluga G-H Zone: 2000 psi at surface, 2270 psi ~ 5192' TVD MPP RECEIVED JUN 2 2 BRU ~14-1:{ WIw.w. WOBK PROCEDU'R~ SUMMARY (COB'PD) Note: A) B) ~ Condition: Cheek with Anehorqe engineering on the current condition of the well prior to moving in the rig beeause additional wireline work and a test program may be eonduoted before the workover is performed. Set a plug in the string 1I 2 3/8" "D" nipple at 3307* if pmmible prior to moving in the rig. C) Cheok out the BP valves - reoords show that the tubing hangers are Gray, but out for Cossaseo plug. Try the plugs in the hangers before moving in the rig, BRU 224-13 WI~HKAD AND TltKK Casing Head: Gray CWCoT w/12" 3,000 psi RS? top flange with two 2" - 3,000 psi flanged outlet -one blanked off and the other with a 2" 3,000 psi valve. Tubing Head: Gray CWC-T w/10" 3000 psi R$3 top flange with two - 2" 3000 psi R31 flanged outlets eaoh with a 3000 psi gate valve. ~ee.. Gray CWC-Q Quad Bonnet~ - 10" 3000 psi R53 down with a 2" 3000 psi R3I flanged outlet out the- side of the 10" flange. The top of the bonnet has three welded outlets eaoh with a 3" 3000 psi master valve. The master valves are welded to a block tee with outlets (flanged) for each string. A swab (crown) valve is flanged to eaoh string above the tee. Only two sides of the triple tree are used. Parent Hangers: Hangers: Gray 10 3/4" x 2 7/8" x 2 7/8" x 2 3/8" x 1 3/4" CWC-Q String I Gray CWC-FA 2 7/8" 8rd Box Top and Btm. out for Coma&moo BPV, String 1I 2 3/8" Gray CWF-FA 2 3/8" 8rd Box Top and Btm. out for Cossasoo BPV, String Iff Gray CWC 1 3/4" D w/2 1/16" eue 8rd BOx Top and Btm. out for Cossasoo Plug Note: One of the 2 7/8" tubing hangers is blanked off and is looked into the parent hanger by a speoial looking bull' plug screwed onto the bottom of the tubing hanger. The looking plug seals the tubing hanger in the parent hanger. The tubing hanger cannot be pulled out of the parent hanger. Position of wellhead and hanger N 3 ,, //~'~~ ~?e"-- STRING / - \ BLANKED OFF '~ ~"~--~'~-~,,~...I.900 STRING S __TOP RECEIVED JUN Alaska Oil & 'Gas Cons. Commissio. Anchorage BRU 224-13 W~ Jtmtlflemtioo Beluga River Unit Well #224-13 b a center of the structure well driXl~l in 1974 and shut-in with drillable cement retainen set above each zone perforated. In 1981, the cement retainers were drilled out and the well was completed. In 1982, surface facilities were installed, but production tests were stopped when the annulus and string II were found to be in communication which made the annulus gas heat system inoperative. In 1983, surface facility changes were made so that high pressure gas from string I could be bled through the heater and into the annulus for heat. This arrangement allowed the well to be placed on production although the well was never a reliable producer due to hydrate plu~ging and the production of mud-silt slugs.~ The cause of the communication is unknown, but possible causes are an open or leaking XA sleeve, the string 1I packer latch-in assembly coming out of the packer, or parted tubing. A leaking or open XA sleeve is the most likely candidate for the communication. Attempts to get down string II with wireUne tools to locate the communication have failed because drilUng mud or formation fines are adhering to the walls of the tubing. This mud sticks the tools at different depths in the well At present (April' 1984), string I is producible, but string Il is plugged off with mud below the point of communication. Our recommendation is to have a two part program. Part one is to clean out string II using a pump truck, wireline truck, and/or coiled tubing. (}nee the tubing is cleaned out, the point of communication may be found and repaired. If the tubing cannot be repaired, part two is to move in a workOVer rig to pull and repair string Il. With string Il repaired, and effective heat available, string I is estimated to be able to produce 4 to 6 MMCF/D and string Il is estimated to be able to produce 5 to 7 MMCF/D. The total cost is estimated to be $750,800 and economics are a 0.284 year payout, 100+ rate of return, and a discounted profit index of 21.4 ~15% based on a conservative total production of 5 MMCF/D at $2.09/MCF for both strings. This workover is needed to help supply gas to Enstar upon completion of their pipeline. Part I 1) Set a pump through back pressure plug in the heater string as follows: (Note: The heat string (string IH) does not have a ,master 'valve to set the BP valve through. Therefore, ,~e~,,,mudptug~.~plugf~dng:off, stringH,:is:.:the:;only through the point of communication in string Il and up the annulus. This BPV should be set in string IH while the mud plug is present.) 'A) Kill the tubing x 9 5/8" annulus and strings II and HI with 9.0 ppg NaC1 brine. s) Remove the 1~" 10rd bull plug above string IH and install a joint of 1,900" O.D. (1~" LD.) 2.9# RUE 10rd N80 pipe with a full opening 3000 psi valve only after the well is known to be dead. RE.CEIVED JUN 2 2 I98 2) 3) 4) 5) C). Set the pump through back pressure plug in string {IL Circulate any mud or sand out of the tubing X 9 5/8" annulus and string by circulating down the annulus and up string IL Make a feeler gauge ring run to 3308' with wireline in string IL If the tubing in string 11 is sound and not parted or in some other way damaged, then set a plug in the Cameo D nipple at 3307' in string IL Bail out or drill out with coiled tubing the mud plug prior to setting the plug in the Cameo D nipple if the mud plug is still present. (Note: Coiled tubing will be needed on BRU 212-25 and ?.12-24, therefore, do not spend a great deal of money bailing on the mud plug if no progress is being made.) .If a plug is set in the Cameo D nipple at 3307', pressure up on the plug to see if it is holding. The most probable point for the communication problem between string 11 and the annulus is the XA sleeve in string II at 3258'. Check position of the XA sleeve. Close if open or open and close if it appears to be closed. Pressure up on either the tubing x 9 5/8" annulus or string II to determine if the communication is still present. If the communication is still present, open the XA sleeve in string 11 at 3258*. Set back pressure plugs in string I and II and prepare the well for the workover rig. If the communication is no longer present and the well is determined to be in reliable condition, pull BPV from string HI and place the well back on production. RECEIVED J UN 2 2 1984 Alaska Oil & 6as Cons. CommissioP Anchorage BRU 224...1.3- WELL WORK PROCKI)URK SUMMARY PROGRAM~ Ps~t II (if needed) 1) 2) 3) Prepare the location for the workover rig. No reserve pit is allowed. Move in and rig up the workover rig. (Rig up to recover all fluids and cuttings.) Mix up a chrome free Lignosulfonate mud with: 10.0 - 10.5 ppg weight 30 - 45 sec/qt viscosity 4 - 6 cc fluid loss (See mud program for more detail.) 4) Circulate mud down string II (2 3/8") through the XA sleeve at 3258' and up the tubing x 9 5/8" annulus until the well is dead. Put a 20 bbl. flush a head of the mud if brine is in the annulus. 5) 6) Set Cossasco pump thru BP valve in all strings. Note: The parent tubing hanger is a quad - Gray CWC-Q 10 3/4" x 2 7/8" x 2 7/8" x 2 3/8" x 1 3/4" with the second 2 7/8" port blanked off. The tree is a triple string, but the 2 7/8" side above the blanked off tubing port is not used. The 1.9" heat string, string'IV, is accessed through a port drilled into the top of the tubing bonnet. ND the tree, install Gray Tool blanking plugs or similar equipment in all the tubing hangers and NU a Class III BOP. Test the BOP to 3000 psi. Alert both the AOGCC and the BLM 24 hours prior to the BOP test. Remove the blanking plug from string II and circulate out any gas trapped below the BPV. 7) Release the string II (2 3/8") latch in assembly from the Baker 9 5/8" x 2 7/8" x 2 3/8" dual packer Model AL-5. (The Baker latch in assembly size 51- B has a 10,000# straight pull release. The 2 3/8" tubing is landed in 4000# compression.) Circulate the well dead. 8) Recover string II, locate and repair the leak in the tubing. Rerun the 2 3/8" tubing with a new Otis 2 3/8" XA sleeve, a 2 3/8" Brown CC safety joint, and a Baker 2 3/8" snap-in right hand rotation release latch-in assembly. Hydrotest the tubing to 3000 psi. 9) Space out the tubing, pick-up and displace the mud out of the annulus. Circulate 50 bbls. of fresh water down the annulus. Circulate diesel down the annulus until diesel returns are seen out string II. Set the 2 3/8" BPV, latch into the dual packer, land the tubing in the parent hangers. N.D, the BOP and N.U. the tree. Test the tree flange to 3000 psi. 11) Pull the plug out of the Camco D nipple at 3307'. 12) Production test the well as directed by Anchorage engineering. R ~ < E {V E D JUN2 219 4 ~,la~ka Oil & (i~'~ C~.'~',~; ~- 1~) 14) · Rig down and move out the rig. Turn the well over to the produetion foreman to plaee on produetion. J. A. CO NN 4/10/84 RECEIVED JUN 2 2 t9~4 Alaska Oil a Gas Cons. {~ommission Anchorage CP~,, (i) (z) , $ K.B. TO TUBI '~ANGER TUBLNG HANGEN (2) I JT.+2'IO' &8'PUPS 2~8' TBG. , I (I} 2 JTS. 2~" $.$~'EUE 8RD N-80 TaG. 76.80~_(?.) 2~" OTIS 'S' NIPPLE Position 2 '87'8u--~(I)'" / 2~8" OTIS "S," NIPPLE Posi.tion 4 · -- (3} 59 JTS. 1.9" NU I0 THO N.80 [983.86' --$191.43-- "(I) I00 JTS. 2~~*6.5~EUE 8RD N.'80 -- ($) 1.9" TUBING INTAKE ... (2) 103 JTS. 2~"4.7=EUE 8RD N-80 - -- 2 =4958 .J4'966 i'~86' i~°~ --5398 TOP PLUG AT iD. I0~000' 50.80' 1.44' 79.74' I 25.00' 1.00' 6'1.80' 1.58' )-- (11 2~e" BROWN CC SAFETY ,IT. (I) I' JT. 2~'e" 6.$~ EUE N-80 TUBING --$226 13'--. -, 2o~9'17, ~(I) 2~ OTIS XA *S~EEV[ ~_'__, [-(I) I JT. 2~" 6.5~ EUE N-SO TUBING 3260, 39'~ (2) 2 e OTLS XA SLEEVE, , 2,88 ~ Z' I,~ 3 ....... ,~(~} 2y~ x3~ X-OVER (2}2%x2~ X.O~E I.~ -- o,o,.ao ~ (I-2)9.~BAKER DUAL AL-5'PKR.w/3~'~2~"..~ C x-o c co' ,*'~ *=~ ~A,~I-2) I JT. Z~" 6.5e {2) I JT. ~ .... ~~ ~ OTiS S NIPPLE Position ~:-3~,' ~ . I ~T. ~' 6.5~EUE N-80 TUBING 3~75'-3398' I ~ ~ 3422' 3431' - i ' 8' 20 ~ 2' I0 ~KE~ ~ST ~TS. ~ 2Ya BAKER S~FET? dT. 60,000~SHEAR ~ dT. 2~"6.~~ EUE 8RD. N-80'T~iNG ~3621 ~ 2~' O~(S "XA' SLEEVE I dT. 2~a" 6.5~EUE 8RD N- 80 TUBING ~ 3655.98'-- ~ ~" x 4~' x- ovg~ ~3656.97'~ , ~ 9-~" BAKER "FHL" PACKER ~ 3664. 25 ~ i,7,5, /~ 4~"x 2Pa" X'OVE" 1~76o' / 4 JTS. 2~8"6 5'~E'U'E 8RD N'80 TUBING '? " -- 3788.58 : 2~"~AKER SAFETY JT. 60,00.0~ SHEAR - ~8~.9o'~ 2~"x ~' x-ov~. , s~" ~=. "~." -~"~s~ ~- ~;' x-ov=. ~8" OTIS "S" NIPPLE Position . I JT. 2~"6.5 ~ EUE eEO N-80 TUBING --~895.8~ _ ~.~.~'~ z~.' ~.ow. s. EAR-OUT sue RECEIVED - . 3.58' 31.12' 3.14' 31.12' 14.59' 0.97' $1.11' I. 57' 31.48' '182.57' 62 3.54' 31. ~7' :3. 16' 31.27' 0.99' · 7.28' I: 15' 12~. 18' 3.51' 31.67' I. 14' 6.95' 0.97' 30.36' I. 58' 31. I0' I. 50 0.99' REV. .12' Ig- 85 B. R.u. :224 ~CASING TUBING DETAIL SECTION 13 T. 13N.,R. IOW. CHEVRON U.S.A. INC. i ALASKA OIL & GAS CONSERVATION COMMISSION Thru: i Hoyle H. Hamilto.n Chairman Commisslo~r.. Lonnie C. Smith~' commissioner Doug Amos ~ Petroleum Inspector March 23, 1981 Witness B.O.P.E. test on ChevronLs~ Sec. 13, T.13N., R.10Wt~. S.B. & M. on Brinkerholl Rig No. 58 Tuesday March 17, 1981: I departed my residence at 7:00 a.m. 'for a 8:00 a.m. fli'~t'"with TroY Air. I arrived Beluga River at 9:30 a.m. ,. Wednesday March ~..8, 1981: 'The B.O.P.E. test commenced at 2.30 a.m. and was concluded at 10:30 a.m. I filled out an A.O.G.C.C.B.O.P.E. test rePort which is attached. In summary, I witnessed the B.O.P.E. test on Chevron's BRU- 224-13 Well, there were three failures all of which were repaired and retested during'~ the course of this test. I filled out an A.O.G.C.C.B.O.P'E. test report, which is attached. DA:dlf /? Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · .Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department March 5, 1982 WELLS 221-23, 224-13, 214-35 OPEN FLOW POTENTIAL TESTS BELUGA RIVER FIELD, ALASKA Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Chatterton, We, as operator of the Beluga River Unit, have recentl~leted Well # 221-23 and will soon complete Wells #. 214-35 and~~or produc- tion. These wells are being completed for use as back-ff~-wells for the existing Beluga River wells and will onty be produced in emergency sit- uations. Pursuant to article 3, section 225 of the AOGCC regulations we request that we, as operators, be allowed to perform the required tests during the upcoming summer months. Please advise us of your approyal on this matter. Very truly yours, T. L. Perryman JBL:fw O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report · Inspector ~4~$ ~z~5 Operator ~/-j~ ~/F~ ~/J Representative Well ~/- 2Z~-/~ Permit # 7~'Z7 Location: Sec /~ T/~J R/~/ M ~t~ ~$/~?/Casing Set @ ~~ ft. Drilling Contractor ~/~J~J~' Rig # ~ Representative Location, General Well Sign General Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM Full Charge Pressure /~f~ psig Pressure After 'Closure ~ psig uu ps~g-~Dove ~r,~cnarge Att~zn~: ,.~ miL /~ sec Full Charge Pressure Attained: ~ miL d~D sec N2 ...Z/~) Z~ /~72~/ /~Z~ /77.~ psig ~- Controls: Master ~/~f Remote ~ Blinds switch cover ~'~-~ BOPE Stack Annular Preventer. Pipe Rams Blind Rams ~Choke Line Valves H.C.R. Valve ~Kill Line Valves Check Valve / Test Pres sure /! Kelly and Floor Safety Valves Upper Kelly. / Test Pressure Lower Kelly / Test Pressure Ball Type Inside BOP / Test Pressure Choke Manifold / Test Pressure No. Valves No. flanges ~ Adjustable Chokes / Hydrauically operated choke / Test Results: Failures , , ~ Test Time ~ hrs ~ Repair or Replacement of failed equipment to be made within /~'//~, days and Inspector/Commission office notified. Remarks: ~ '~'~ ~"/"/0,~"~:~ ~//J~ ~ ~/~ ~/~ ~l/J~ ~V~ Distribution orig. - LO&GCC cc - Operator cc - Supervisor Inspector March 11, 1982 Mr. T. L. Perryman Area,Operations Superintendent .Chevron"U.S.A. Inc. P. O. Box 7-839 Anchorage, Alasha 99§10 Dear Mr. Perryman: We have received your letter of ~.larch 5, 1982 concerning a time for testing of certain wells in the Beluga River Field. Th'is letter will serve to notify you that the~Alaska Oil and Gas Conservation Commissio'n~. pe~ 20 AAC 25 225, approves the testing of wells No. 221-23~2~24-_~3~and No[ 214-35 during the sun'm~er n~onths of 19~'/~:n'e ~-sults of each multi-point back pressure test must be reported 30 days after the test has been comp 1 e t ed. Yours very t ru ly, Barry W. Eugler/ Commi ss ioner BY ORDER OF THE COMMI SS IONER ' Form 10-403 REV. 1-10-~3 Submit "Intentions" in Triplicate [ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE ~..~ 50-283-20042 6. LEASE DESIGNATION ANO SERIAL NO. /' ADL-58831 7. IF INDIAN, ALLOTTEE OR TRIBE NAME SUNDRY NOTICES AND REPORTS ON WELLS · (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL r""l GAs WELLI-._I WELL OTHER 2. NAME OF OPERATOR CHEVRON U.S.A. !N£. 3. ADDRESS OF OPERATOR P. 0. BOX 7-839 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1012' corner of Sec. North and 2194' East from Southwest 13,T13N R1 OW. SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ~3' KB 14. CheCk Appropriate Box To Indicate' Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME BELUGA RIVER UNIT 9. WELL NO. BRU 224-13 10. FIELD AND POOL, OR WILDCAT .BFI..IIC, A R IVFR 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 13. T, 13N. R.1OW.: SB&M 12. PERMIT NO. 73-27 , )ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF [-~ REPAI RING WELL FRAC-~URETREATMENT~.~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Suspension 1~-77-7h (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE~PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1. Move in Rig and install Class III BOPE . 2. Clean out and drill out bridge plugs to 5670' using 75pcf drilling fluid. e 5. , Set bridge plug with top at 5660'. Perforate/'intervals 3355-3361', 3375-3398', 3422-3431' and 3435-3482' with four ½" jet holes per foot. Install· tubing and packers unload well to reserve pit and flare for sufficient time to clear the well of fluids. Shut well in pending installation of surface facilities. RECEJv[D ' JUN 0 Anohura~ 16. I hereby certify that. the foregoing is true and correct ' R. W HAGEE~__~__~,/~4~~E ~t~ En§ineer SIGNED ' {/~ . ~- I I I ~ ~ , DATE (This space for State office.) /~ ~.[~ ' APPROVED BY ~/~~ '~~ TITLE ..... DATE CONDITIONS OF~P~OVAL IF AN~ v ' ' BY ORDER See Instructions On Reverse Side Approved *opy Returned BELUGA RIVER UNIT WELL NO. 224-13 PRESENT STATUS' TOTAL DEPTH' 10,000' PLUG' 6755-7033' cement DRILLABLE BRIDGE PLUGS' 3400', 3708', 4000', 5350', 5626', 5800' 6000'. 6106'. 6145' and 6375' CASING' 30" driven'to 35' 20", 94#, H-40 Buttress thread, casing cemented at 423: 13-3/8" 61 and 68#, K-55 Buttress thread casing cemented at 3298'. 9-5/8" 43.5# and 47# N-80 and P-110 Buttress, L8R thread casing cemented at 6999', cp'd. 3322', 3525', 3755-3760', 5681-5689'. 9-5/8" Casing Reference Collars (E-LOG): 5610 557O 5528 -5487 5446 54O5 5325' 5282' 4996' 3742 5241' 4956' 3704 5200! 4922' 3662 5160' 4887' 3620 5118' 4847' 3580 5071' 4805 3541 5037' 3784 3499 3458 3418 3378 3342 3300 3261 3221 PERFORATIONS' 3'755-3760'*, 4936-4958' 4966'-4986' 5022'-5032' 5398-5448', 5681'-5689'* 5705-5725' 5743-5758'* 5820-5848' 6026-6038' 6044-6076' 6117-6121' 6129-6136' 6138-6145' 6159'-6176' 6422-6440' 6448-6454' 6462-6470' , , , · Four ½" jet holes per foot'· * squeeze with cement' TUBING' 91' of 2-7/8". Plugged with grey tubing plug. Taped and nippled with a valve. HOLE FLUID: Top 100' diesel oil, remaining fluid clay water 76 pcf, 48 sec vis. 20 cps plastic yield, lOcc w. 1., 12% solids, 1% sd., 400 ppm salt, PH 12 measured 12-12-74. B.O.P.E. CONSIDERATION' Maximum recorded pressure was 2624 psi at 5348' 75pcf low solids clay water drilling fluid' will give a 150 psi over balance at 5348'. Use 3000 psi class III B.O.P.E. DATUM' All measurements from K. B. (25' above ground) RECEIVED JUN2 0 1980 BELUGA RIVER UNIT WELL NO. 224-13 PROGR/~M 1. Move in and rig-up drilling equipment. 2 Bleed off and pull 2 7/8" tubing. Install and test class III 300O~psi B O.P.E. 2 Run bit on drill pipe and drill out Halliburton EZ drillable bridge plugs at 3400', 3708' 4000' 5350 and 5626' Clean out to 5670' 2 While on bottom condition drilling fluid to 75 pcf, 40-45 sec. vis.~ and 5-7 cc w. 1. Pull Drill Pipe. 6. Run a drillable bridge plug and set with top at 5660'. 7, Run Dresser Atlat Multi-Spaced and Compensated Neutron Logs from 5660' to 3000' 8. Run Dresser Atlas Dual Detector Neutron Life Time Log from 5660' to 3000'. 9. Install lubricator and test to 1000' psi. Run Dresser Atlas 4" carrier jet perforator and perforate 9-5/8" casing with four 2, jet holes per foot as follows: 3482-3435 47 3431-3422 9 3398-337'5 23 3361-3355 6 TOTAL 85 NOTE' All depths are E-Log depths. 10. Run bit and tandem scrapers. Scrape 9-5/8" casing from 3300' to 5045' and clean out to top of Bridge plug at 5660' Circulate well until clean returns are obtained. 11. Run 2 7/8" tubing and jewelry as per attached mechanical condition'. 12. Using C. A. White equipment set a Baker plug in 2 7/8" D nipple at 3858' +. Pressure tubing and set single packer at 3850' +. Retrieve Baker'from D nipple at 3858'+. 13. Run 2-3/8" tubing and latch into dual packer at 3278'. 14. Run 1½" heater string to 2015'+. 15. Set a Baker plug in 2-3/8" "D" nipple at 3320'+. Pressure tubing and set dual packer. 16. Retrieve Baker plug from D nipple at 3320+. Remove BOPE and install x-mas tree and connect flare lines to flare and reserve pit. 17. Open 2 7/8" XA sleeve at 3244' and displace drilling mud with diesel oil. Close 2 7/8" XA sleeve. 18. Open 2-3/8" XA sleeve at 3275 and displace drilling mud with diesel oil. Close 2-3/8" XA sleeve. 19. Produce 2-3/8" tubing to sump and flare at 2000-3000+ mcf/d rate until clean gas returns are obtained. - 20. Open 2-3/8" XA sleeve at 3275 and produce 1½" heater string. Unload diesel oil to sump then produce to flare at 2000-3000 mcf/d rate until · clean gas returns are obtained. 21. Close 2-3/8" XA at 3275, and bleed off 1½" heater string to assure that dual packer is set and not leaking. NOTE' The Beluga sands will not be perforated and tested until the surface equipment is installed and the well is hooked-up to produce. This will prevent any damage to the sands from leaving the well shut-in. The following intervals will be perforated: INTERVAL FEET 5640-5605 35 5518-5492 26 5448-5398 50 5098-5046 52 5032-5022 10 4990-4966 24 4958-4936 22 4926-4934 8 REPERF REPERF REPERF REPERF Based on the evaluation of the logs ran in this program some of these intervals may be eliminated. 22. Unload 2 7/8" tubing string to sump and attempt to flare the intervals perforated in 1974 at a 2,000-3,000 mcf/d rate until clean gas returns are Obtained. Note' If well will not flow proceed w~th step 23. 23. Shut-in and secure well. 24. Release Rig. DGL' RWM' sjb D. G. REDLINE .CLASS . · · 12'-)000~ 8,0 L.L_ BLD{D ~ -5'7 ~ ~ooo~ 2"-~K)O~. BLIND FL~G~ $CU . CLASS ~ BOP WITH -SHAFFER ROTATING BOP .To 1980 EC/IVED -z COHPLETION REPORT - NEW ~LL ~ , · STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS. INC., OPERATIONS :1 . ~ AREA: Beluga River LAND OFFICE: Anchorage ~ Cook In let -" · i Alaska ...... ' -. ' !PROPERTY: · '.~EASE NO: ADL '58831 ..... iWELL NO: Beluga River 224-1~ APl NO: 50-283-20042 -' .:.---LOCATION AT SURFACE: 1012' North and 2'194' East from Southwest Corner Section 13, Ti3N, R10W, Seward B&M ~?~.~LOCATION AT DEPTH: . 'ELEVATION: 93'KB R. M. McKinley Area Supervisor DRILLED BY: Kenai Drilling ComDany, Rig #1 . DATE COMMENCED DRILLING: September 27, 1974 _ .~ :1% . DATE COMPLETED ". . ......... . December-16, 1974 DATE OF INITIAL PRODUCTION: Abandoned.- December 16, 1974 DEPTH: 10,000' - .~ ::<.PLUGS: ? - 7'033' . :' -,~'~ ' -'"' 7,033'-6,755 ' -.- EFFECTIVE DEPTH: ..... .: ~ "i ·, i~ ::... i:' DRILLABLE ~"BRIDGE PLUGS- -jr'' ..3!_.. CASING: 30" driven .to 65" . ..... . ~.6,'375 6,1.45 ?'- ' -' ' 20" cement at 423' ' """:'<!i'~}!;76'~000~' · 5,800 - ,·,· . ,, .'· ' '. ... --"- 1~ 3/8'.' cement at 3,298'- 5,350 4,000 9 5/8" cement at 6,999' 3,400 LINER: 6,106 ~,626 3,708 ,. SiP b 1975 . D!VlSi°i Perforations: · , , .Four 1/2:' jet holes per foot: 6,470'-6,462' 7 6,454 '-6,448' 6,440'-6,422'3 6,176'-6,159'~ 6,145'-6,138'~ 6,136'-6,129'/ 6 ,-121 ' -6,117 v 6,076'-6~044' ~ 6,038'-6,026' 5,848'-5,820' 5,758'-5,743' squeezed ~ 5,725'-5,705' squeezed 5,689'-5,681' squeezed 5,448'-5,398' squeezed 5,032 ' -5,022 ' i ' 4,986'-4,966' 4,958'-4,936' 3,760'-3,755' squeezed Two 1/2" jet holes per foot 3,662'-3,660' squeezed Perforations squeezed at 3,525', 3,322~. .... BR.-224-13 · 'Cement'Squeeze Jobs Squeeze No. 1 December 2, 1974 Perforations'5,681'-5,689' 5,705'-5,725' and 5,743'-5,758' with squeeze tool set at 5,626', squeezed perforations above with 150 sacks class "G" cement under 3,000 psig final pressure. Squeeze No. 2 December 7, 1974 Perforations 3,660'-3,662'. With squeeze tool at 3,516' squeezed perforations with 368 sacks class "G" cement under 2,500 psig final pressure. Squeeze No. 3 December I1, 1974 Perforations 3,755'-3,760'. With squeeze tool at 3,708' squeezed perforations with 150 sacks of class "G" cement under 1,900 psig final pressure. Squeeze No. 4 December 12, 1974 Perforations at 3,525' With squeeze tool at 3,403' squeezed perfora- tions with 150 sacks of class "G" cement under 1,500 psig final pressure. Squeeze No. 5 December 13, 1974 Perforations at 3,322'. Wfth squeeze tool at 3,190' squeezed perfora- tions at 3,322" with 73 sacks of class "G" cement under 1,500 psig final pressure. Halliburton Formation Tests ~FT #1 6,422'-6,470' HFT #2 6,117'-6,176' HFT #3 6,026' -6,076 ~FT #4 5,820'-5,848' ~FT #5 5,681'-5,758' HFT #6 5,398'-5,448 HFT #7 4,936'-5,032' HFT #8 3,755 ' -3,760 ' Schlumberger Dual 'Induction Log Bottom Hole Ccmpensated Sonic Log Compensated Neutron Form. Den. Formation Density Log Proximity Log - Microlog Continuous Dipmeter Cement Bond Log Chevron Ge6physical Division 422'-9,982' 422'-9,979' 422'-9,989' 422'-9,988' 3,294'-6,998' 3,294'-9,989' 3,200!-9,989' Dipmeter-Dip and Azimuth Display 3,200'-7,000' Dip and Azimuth Display (selveC) 3,200'-7 000' Quality Control Plot ~ 3,200'-7,000' Hydrocarbon Anomaly Search 3,281'-6,110' Azimuth of Dip vs. Depth 3,200'-7,000' 11__511 2"--5" 5" 5" 5Il 5" 5It 5 I! 2" 1/200 Runs 4 4 4 2 3 1 September 26, 1974 , Conductor pipe driven to 65' and rat hole drilled. Spudded in at 12:01 AM. Drilled 17 1/2" .hole .~ !0'-150' (150') -September'27,'1974 Drilled 17 1/2" hole 150'-435' Opened hole up to 26", 90'-436' Circulated hole clean 71 pcf mud 'September'28, 1974 Ran 425' of 20" 94# H-40 Buttress casing and landed it at 423'. Cemented through 5" drill pipe with 660 sacks "G" cement and displaced with 34 cu. ft. ~.ud. Good circulation. Pulled out 5" drill pipe. Septe~..mber 29L. 1974 install 20" Class II BOPE. · · · September, 30, · 1~74 Tested Class II BOPE · '.October '.1 ~ '1974 Drilled out cement from 417'-435' and continued to 703' (286'). 70 pcf mud 'October '2Z ·19.7,~ Drilled 17 1/2" hole 703 '-1,104 ' (401') 74 pcf mud 'October 3,-1974 Drilled 17 1/2" hole 1,I04'-2,106' (1,002') 73 pcf mud October 4, 1974 - ., Drilled 17 1/2" hole 2,106'-2,725' (6~9') 74 pcf mud October 5, 1974 Drilled 17 1/2" hole '2,725 '-3,310' !Circulated and conditioned mud. October 6, 1974 _ (585 ' ) _ 75 pcf mud Ran Schlumberger Dual Induction log 422'-3,301', Formation Density 422'- 3,309', Borehole Compensated Sonic 422'-3,295', Compensated Neutron Formation Density 422'-3,309'. Circulated and conditioned for 13 3/8" ~sin~. 75 pcf mud · 'October '7; ·1974 - , Ran 3,300.48' of 13 3/8", 61# and 68#, K-55, Buttress casing, including shoe (.3.50') as follows: 13 3/8" Casing Detail Top 39.85' 68# Landing joint 1,361.30' 61# K-55 Buttress (35'joints) 1,~68.19' 68# K-55 Buttress (46 joints) 2.60' Duplex collar 25.40' 68# K-55 Buttress (1 joint) ...... 3;50' Shoe 3,300.84' .... 3,00' aboveK.B. 3,297.84' Cemented casing at 3,298" with 2,010 sacks of "G" cement. Good cement returns to surface. 75 pcf mud · 'October 8, '1974 Installed 12", 3,000 psi casing head. 75 pcf mud · 'October "9; '1974 Installed 3,000 psi, Class III BOPE 'October'10, 1974 Pressure tested 13 3/8" casing'with 2,500 psi, leaked. With 12 1/4" bit, fotmd cement at 3,263". Pressure tested casing above packer to 2,500 psi ok.' Pressure tested casing beldw packe~ through 5" drill pipe and found casing shoe leaked. Pressure tested BOPE under 2,500 psi.ok. 75 pcf mud ~October .11.~ ~1974 _ __ With 12 1/4" bit, ~rilled out Duplex collar at 3,266' cleaned out soft .cement to 3,282'. ~Circulated and conditioned mud to 78 pcf. Drilled out '~¢ement from 3,282'--3,298' and drilled out shoe and cement down to 3,310'. Drilled 12 1/4" h~e 3,310 ' -3,715 ~' (405) 75 pcf mud 'October ' 12, '1974 Drilled 12 1/4" ho~e 3,715'-4,283' 'October ' 13, ' 1974 Drilled 12 1/4" hole 4,283'-4 774' October' 14, 1974 Drilled 12 1/4" hole 4,774 '-5,339 ' (568') 78 pcf mud (491') 79 pcf mud (565') 78 pcf mud 'October 15, 1974 Drilled 12 1/4" hole 5,339'-5,601~ '_October '16, '1974 Drilled '12 1/4" hole 5,601 '-5,881 ' (262') 79 pcf mud (280') 78 pcf mud 'October'17'- 18,'1974 Drilled 12 1/4" hole 5,881 '-6,154 ' (273 ' ) Circulated and prepared for Schlumberger log runs. Dual Induction Borehole Sonic Formation Density Compensated Neutron Proximity Microlog Continuous Die, me ter After log runs, drilled from 6,1.54'-6,286' 3,294'-6,096' 3,294'-6,091' 3,294'-6,151' 3,294'-6,151' 3,294'-6,102' 3,294'-6,100' (132 ' ) 79 pcf mud October 19, 1974 Drilled 12 1/4" hole .6,286'-6,560' October 20, 1974 (274 ' ) Drilled 12 1/4" hole 6,560'-6,767 ' (207') · ~ 78 pcf mud 78 pcf mud October 21, 1974 Drilled 12 1/4" hole 6,767'-7,000' ~amed (233') October.-.22., 1974 Circulated and conditioned mud for Schlumberger logging. Dual Induction Borehole Sonic Formation Density Compensated Neutron Continuous Dipmeter Proximity Microlog 6,096'-6,995' 6,091'-6,991' 6,091'-7,000' 6,091'-7,000' 6,091'-6,998' 6,091'-6,998' Prepared to take sidewall samples. October 23, 1974 Shot sidewall samples at: 3,458 4,943 6,351 3,494 5,058 6,430 3,618 5,075 7,089 3,647 5,318 7,427 3,664 5,410 7,887 3,978 5,424 7,912 4,162 5,438 8,000 4,300 5,508 8,140 4,483 5,629 9,090 4,598 5,713 9,099 4,685 5,833 9,194 4,770 6,066 9,627 4,921 6,167 9,797 Rig up to set 9 5/8" casing° 78 pcf mud ..October 24~ 1974 Ran 171 joints of 9 5/8" 47# and 43.5# P-110 and N-80, LT&C and Buttress .casing, cemented at 6,999' with 850 sacks of "G" cement and displaced with . 2,885 cu. fto mud° Good circulation° Opened stage collar at 3,828' and circulated out cement° Cemented through stage collar with 500 sacks "G" cement and displaced with 1,575 CUofto mud. Closed collar, good circula- tion. Installed tUbing head and tested to 3,000 psi and reinstalled 12", 3,000# Class III BOPE° 9 5/8" CASING DETAIL Top 2,153.56' 1.26' 1,674.90' 1.80' 3,084.44' 1.42' 83.05' 1.70' 7,002o13' ..... 3~00' 6,999.13' 51 JtSo 42 Jts. 76 Jtso 2 Jts° 43.5# P-110 Buttress x-over 47# 8rd N-80 LT&C Stage Collar (3,829.72') 47# 8rd P-110 LT&C Baker Float Collar 47# 8rd P-110 LT&C Baker Shoe Above KoBo Casing Landed October 25, 1974 Tested BOPE to 3,000 psi. With 8 5/8" bit, drilled out stage collar at 3;828' and float collar at 6,915'o Drilled out cement and shoe to 6,999'. Circulated and conditioned mud° 79 pcf mud October 26, 1974 Drilled 8 5/8" hole 6,999'-7,150' (151') 79-80 pcf mud October 27, 1974 Drilled 8 1/2" hole (bit change) 7,150'-7,409' (259') 81 pcf mud 'OCtober 28[, !974 Drilled 8 1/2" hole 7,409'-7,557' (148') 81 pcf mud October 29, 1974 Drilled 8 1/2" hole 7,557'-7,730' (173') 81 pcf mud October 30, '1974 ~ ~ -- · Drilled 8 1/2= hole i ?,730'-7,908 ' · ~-q:;ober 31, 1974 ~Drilled 8 1/2" hole · 7,908 '-0,032' ,. ;' November' 1, 1974 Drilled 8 1/2' hole 8,032 ' -8,204 ' November '2 ,,-1974 Drilled 8 1/2' hole 8,204 !-8,288 ' · .ove~. er' ,,3; 1974 1/2# hole 8t288'-8,.$28' ~vamb~ 4, i974 ~ill~d 8 i/2" (178 ' ) (124') (172 ' ) (84 ' ) (240') (172 ' ) ., 81 pcf mud 82 pcf mud 80 pcf mud 80 pcf mud 81 pcf mud 80 pcf mud (180'i 80 pcf mud 8,991 ~:9~088' (114.') (94') 81 pcf mud 81 pcf mud November 9, '1974 Drilled 8 1/2" hole i: 9,088'--9,287' !- : Novombo~' 10, 1974 (99') '~ 81 pcf mud ,Drilled 8 1/2" hole ;9,287'-9,394' (107') 81 pcf mud November 11, 1974 Drille4 8 1/2" hole 9,394 '-9,588' (194 ' ) Had small amount of Gas coming through. 13 3/8" and 20" annulus repaired. 81 pcf mud '~ovembe~. 12;'1974 Drille4 .8 1/2". hole 9,588'-9,670" (82') 81 pcf mud 'November'13; 1974 Drilled 8 1/2" hole 9,670'-9,746' (76') 81 pcf mud November '14, '1974 Drilled 8 1/2" hole 9,746 ' -9,905 ' (159') 82 pcf mud November ' 15, '1974 Drilled 8 1/2" hole 9,905'-10,000' (95') 81 pcf mud November 16, 1974 Ran Schl~erger logs.: Dual IndUction Formation Density Continuous Dipmeter Compensated Neutron 6,991'-9,982' 6,988'-9,988' 6,995'-9,989' 6,000'-9,988' Conditioned mud and prepared to take sidewall samples. No~ember 17, 1974 Shot 19 sidewall samples and recovered 17. Rigged up to run Schlumberger Cement Bond Log. November '18, '1974 ~Ran Cement Bond Log from 3,200'-6,989'. Bridged 8 1/2" hole and 9 5/8" !casing through ~rill pipe hung at 7,200' with 160 sacks of "G" cement. 81 pcf mud November'19;'lg?4 With 8 1/2" bit and casing scrapers circulated and conditioned mud to 78 pcf an~ 37 sec. Fou~cl cement at 7,033'. Rebridged 8 1/2" hole and 9 5/8" casing through 4rill pipe hung 'at 7,033' with 135 sacks of "G" cement. 81 pc f mud November '20, 197,4 With 8 5/8" bi~ and casing scraper went to 6,550' and conditioned mud to 73 ]~cf and 37 sec.., then located top of cement at 6,755'. Installed flange lubricator on 12" 3,000 psi hydrill. 73 pcf mud November '21; ~ 1974 Pressure tested lubricator to 1,500 psi ok. Schlumberger perforated four 1/2" holes/foot ~t 6,470'-6,462', 6,454'-6,448' and 6,440' to 6,422'. Ran in ~hole with 8 5/8" bit and casing scraper to 6,755'. Circulated and conditioned ~sud for formation test. 73 pcf mud N~r '22; 1974 Ran a Halliburto~ Formation Test HFT #1 6,422'--6,440', 6,448'-6,454' and 6,462'-6,470' (11/22/74) Very light blo~ ~throughout 95 minute test. Recovered 270' rise of ~rilling fluid ~ 5" drill pipe° - Reoorder: · H IF FF FSI FH · November 2 3, 1974 Schlumberger perforated 9 5/8" casing with four 1/2" jet holes per foot from 6,176'-6,159', 6,145-6,138', 6,136'-6,129' 0nd 6,121'76,117'. · .73 pcf mud November 24, 1974 Ran Halliburton Formation Test HFT #2 6,117'-6,1'21', 6,129'-6,136' 6,138'-6,145' and 6,159'-6,176' , Strong blow with gas to surface in 68 minutes. Gas rates 55 to 80 mcf/d for balance of 6 hour test° No fluid recovery. 'Recorder ~ '''IH ''IF ''FF '''FSI ''FH .3,098 72 252 2,940 2,975 November 2'5,'1974 Ran 8 5/8" bit and casing scraper to 6,250' 'and circulated and conditioned mud to 76 pcf. Set drillable bridge plug at 6,106' with Go-International equipment. 76 pcf mud November 26, 1974 Installed and tested lubricator. Found bridge plug set at 6,145' so set another plug at 6,106'o Gas flow frOm 13 3/8', and 20" annulus. 1,000 psi on 9 5/8" and 13 3/8" annulus. Bled off in 7 min. at 75 mcf/d diminishing to 6 mcf/do Perforated 9 5/8" casing with four 1/2" jet holes/foot at 6,076'-6,044' and 6,038'-6,026'o 76 pcf mud November 27,'1974 Ran Halliburton Formation Test HFT #3 6,026'-6,038' and 6,044'-6,076' (November 27, 1974) Light blow with Gas to surface in 40 minutes. 6 to 0 mcf/d rate for balance of 105 minute test. Recovered 610' rise of drilling fluid in .5" drill pipe. Recorder: -IH IF 'FF FSI FH 3,194 '37 ' 376' 2,816 3,056 Set drillable bridge plug at 6,000'. Pressure 'tested casing, and bridge plug with 3,000 psi, ok. November 28, 1974 With 8 5/8" bit and casing scraper, circulated and conditioned mud at 5,990'. Raised viscosity to 40 sec., weight is 76 pcf. Installed-and tested lubri- -cator with 1,500 psi, Oko Go-International perforated 9 5/8" casing with four 1/2" jet holes/foot from 5,848' to 5,820'. Ran Halliburton Formation Test. HFT # 4 5,820'-5,848' (November 28, 1974) Strong blow with Gas to surface in 15 minutes. Gas rates 125 - 685 mcf/d , ' ~ for balance of 1,020 minute test. Fluid recovery undetermined. /5~"~ ~corder -IH IF FF FSI FH 5,029 51 ~46 2,716 3,022' 76 pcf mud ''November'29,'1974 Completed casing test. -November. 30, '1974 Set drillable bridge plug at 5,800'· Circulated and conditioned mud. Installed and tested lubricator. God. International perforated 9 5/8" casing with four 1/2" jet holes/foot at 5,758'-5,743' 5,725'-5 705' and 5 689'- _~ 5,681' . · ; 76 pcf mud. ' December 1, 1974 Ran Halliburton Formation Test HFT #5 5,681'-5,689', 5,705'-5,725' and 5,743'-5,758' (12/1/74) Light blow with Gas to surface in 46 minutes. Gas rates 17 - 61 mcf/d for balance of 350 minute test. Recovered 2,744' rise of drilling fluid grading to muddy Water, including 90' of sand on bottom, in 5" drill pipe. 'Recorder 'IH 'IF ''FF 'FSI FH ,l 1~ ~ , 2,960 -44 1,179 2,345 2,957 Circulated and conditioned mud. 76 pcf mud 'December 2,.1974 Set drillable bridge plug at 5,626' and stabbed into it with 5" drill pipe ~m and broke down with 2,500 psi at 20 cu. fto/min.' and pumped in 150 sacks of "G" cement and displaced with 571 cu. fro of mud and squeezed to a final pressure of 3,000 psi. Reversed out mud and cement. Installed lubricator and tested. Go-Internation perforated 9 5/8" casing with four 1/2" holes/foot at 5,398'-5,448'. December '3, 1974 Ran Halliburton Formation Test !HFT % 6 5,398'-5,448' December 3, 1974 Strong blow with Gas to surface in 9 minutes. Gas rates of 1,155'-4,196 ~cf/d for balance of 725 minute test. Recovered 1,254' rise of drilling fluid in 5" drill pipe. Recorder '''IH ''IF ''FF FSI FH 2,799 137 2,145 2,610 2,796 'December 4, '1974 bridge plug at 5,350'. Rigged up ahd tested lubricator. Perforated 9 5/8" casing with four 1/2" holes/foot at 5,032'-5,022' and 4,986'-4 966' , Dropped. gun and collar locator in hole, total of 27.5' fish with top at 5,322 ~ o 76 pcf mud -December~5;'1974 Perforated 9 5/8" casing with four 1/2" holes/foot at 4,958'-4,936' Recovered all of fish° Halliburton Formation Test HFT ~ 7 4,936'-4,958', 4,966'-4,995' and 5,022'-5,032' (December 5, 1974) Strong blow with Gas to surface in 10 minutes. At 1,250 - 2,200 mcf/d rates for balance of 555 minute test. Fluid rise not determined. Recorder ''*IH 'IF FF FSI FH 2~627 51 1','440 2,210 2,500 December * 6, '1974 Ran in with bit to plug at 5,350' and circulated and conditioned mud. .~Set bridge plug at 4,000'0 Installed and tested lubricator. Perforated with two 1/2" holes/foot at 3,660'-3,662'. 76 pcf mud 'December .7, 1974 Set packer at 3,516' and broke dgwn hol~s at 3,662'-3,660' with 2,000 psi at 11 cu. fto/min, and pumped 100 sacks of "G" cement, could not get squeeze pressure. Broke down holes again with 2,000 psi at 8 cu.ft./min, and pumped 10Osacks "G" cement, unable to get squeeze. Broke down holes again with 2,300 psi at 8 cu. ft./mino and pumped 100 sacks "G" cement, unable to ~et squeeze° Broke down holes again with 2,800 psi at 4 cu.ft./min with 100 Decembe_~r 7..: 1,974 con' t sacks "G" cement. Unable to close tool so reversed out cement. Pulled tOO1. '. 76 pcf mud December 8~ 1974 With 8 1/2" bit and casing scraper cleaned out cement stringers from 3,526'- 3,690'. Circulated and conditioned mud and built up mud volume. Set retrievable packer at 3,523'. Broke down holes at 3,660' with 2,500 psi at l0 cu.ft./minute. Used 100 sacks"G" cement and displaced with 387 cu.ft. mud to a final pressure of 2,500 psi. 76 pcf mud · December '9, ' 1974 With 8 1/2" bit, cleaned out cement 3,597'-3,675'° Ran to 4,000' and circulated and conditioned mud° Raised mud weight to 78 pcf. Pressure tested holes at 3,660' to 1,500 psi, ok. 78 pcf mud 'December._ i.~10, '1974_ _ Circulated and conditioned-mud. Perforated 9 5/8" casing with four 1/2" Jet holes/foot at 3,755'-3,760'° Ran Halliburton Formation Test. HFT #8 3,755'-3,760' (December 10., 1974) Strong blow with Gas to surface in 6 minutes declining to 7mcf/d rate at end of 255 minute test. Recovered 3,050' rise of drilling, fluid grading to muddy, sandy Watero Recorder - ' IH ' ' IF ' ' ' FF FSI FH 2,043 384 1,589 1,589 1,991 78 pcf mud D~ember 11, 1974 ~e~ EZ drill bridge plug at 3,708'. Stabbed into plug and broke down holes 3,755'-3,760' with 1,900 psi at 12 cu. ft./minute. Pumped in 150 sacks of ~" cement and displaced with 365 CUoft. mud to 1,900 psi. Tested to 1,500 ~i, ok. Perforated 9 5/8" casing with 4 1/2" holes/foot at 3,525'. 78 pcf mud December 12, 1974 -- Set squeeze tool at 3,403' to squeeze holes at 3,525'. Broke down holes with !,800 psi at 13 cu. fto/minuteo Pumped in 150 sacks "G" cement and displaced ~ith 360 cu. ft. mud to a final pressure of 1,500 psi. 76 pcf mud 'December '13, ' 1974 Gleaned out cement 3,439'-3,527'° Tested holes at 3,525' with 1,500 psi, ok. Set birdge plug at 3,400'. Perforated at 3,322' with four 1/2" holes/foot. Set squeeze tool at 3,190' and broke down holes with 2,400 psi at 7 cu.ft./ minute and pumped 100 sacks "G" cement and displaced with 342 cu. ft. mud to 1,500 psi. 77 pcf mud 'December' 14 ~ '197.4 .Drilled out cement 3,203'-3,326"o Pressure tested holes at 3,322' to 1,500 psi, ok. 77 pcf mud D~cember'15,'1974 Filled 9 5/8" casing with diesel from 100'. Removed BOPE. Ran 91.25' of 2 7/8" tubing° Installed 10" 3,000 psi tubing bonnet and tested to 3,000 psi, oko Installed tubing plug. Dece.mber'16,'1974 Completed installation of Gray well h~ad equipment. Released rig at 9:00 AM December 16, 1974. J. W. Wilson .,~ STATE of ALAS -I(A DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation To: r FROM: MEMO TO FI LES Harry W. Kugler Petroleum Geologist ~A~ : June 13, 1977 SUBJECT: Beluga River Field Dave Courtis, Union Oil Company of California, called this'date to report that there were no mud logs in the State files of the following wells: Socal BRU. //232-4 Completed in 1963 Socal BRU 212-25 Completed in 1962 Socai BRU 233-27 Completed in 1963 .Socal _BRU 212-24 Completed in~1973 '~BRU 224--~13 ~-~ompleted in 1974 He stated that he .believed our regulations are such that we should request Socal (Chevron) submit these logs if they were.run. I reported, after consultation with the Director and staff members, that our interpretation of the regulations were not the same and we would not require the mud logs. Upon heari.ng this, he stated he would .turn the matter over to Union's land department for their interpretation and the land department would 'be in touch with us. Chevron Standard Oil Company of California, Western Operations, inc. P.O. Box L839, Anchorage, AK 99510 . Phone (907) 279-9666 J. L. Rowland Area Supervisor Producing Department September 14, 1976 Application for a Decision Certifying Oil and Gas Leases Capable of Production Beluga River, Alaska State of Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue ~: Anchorage, Alaska 99501 Attention: Gentlemen: Mr. Pedro Denton, Chief Minerals Section The following leases have had gas wells drilled on them which are capable of production as evidenced by data furnished to the State: ADL-58831 - , , ! ,t - Standard Oil Company of California, as Operator, respectfully requests these leases be certified as capable of producing gas J~'~ payin~q...:.~j~ities and that said leases be placed on a m/nimum royalty statusi .... . Will you kindly furnish your decision concerning this request. Very. truly yours, G. Mati~/ / CC: Mr. T. S. Cate Shell Oil ~y 601 West Fifth Avenue, Suite 810 Anchorage,.Alaska 99501 Mr. T. N. Burdette Atlantic Richfieid Cc~--~uany P. O. Box 360 Anchorage, Alaska 99510 0'2-001B ~, STATE ~f ALASKA TO: J--- FROM: O.K. Gilbreth, Directar Division of Oil and Gas File: 3.14 500.41 Pedro Denton tioj~ Chief, Minerals Sec DATE : September 21, 1976 Socal' s ltr. of 9/14/76 SUBJECT: Enclosed is a letter frcm Socal requesting lease ADL's 58820 and 58831 be put on a mininuu royalty payi6g status. Please confirm ~ether the wells identified in the letter are capable of producing in paying quantities. TRANSMITTAL AND AC~' v~EDGMENT OF RECEIPT OF MATERL~ 'ALASKA). TO:__ I b"tateMr' T. of FLAlaskaMarshall ~1~ [ Anchorage, Alaeka 00504 THE FOLLOWING IS ~ LIST OF t4ATERIAL ENCLOSED HEREWITH. PLEASE . . DUAL INDUCTION LATE. flOLOG ............. Z.-.:- BOREHOLE COMPENSATED SONIC ~.~"';' ..1BOREHOLE COMP. SONIC W/caliper . -. - - BOREHOLE COhlR SONIC w/gamma ,-' CONTINUOUS DIPM:ETER HIGH RES. ' ~"~ ." ' CEMENT BOND LOG .......... -:- :~ - CASING COLLAR LOG COMPENSATED FORMATION FORMglION ~N~LYSIS lOG -~ - FORMATioN D~NS~TY LOG F F .. "-":"' FORMATION TESTER .. ...... ' ' :' '- -. GAMMA RAY COLLAR LOG' :. --'..,, ~ MICROLATEROLOG ~ . ~EUT~O~ PROXll, IITY MICROLOG ' ~-.:~ RWA COMPARISON PLOT ':--"":'-. -.. SANDSTONE ANALYSIS .... · ' SIDEWALL NEUTRON POROSITY' . . ' " TEMPERATURE LOG :'::" ''~'' 'T '-- COMPLETION DIRECTIONAL REPORT SURVEY mi BLUE LIN .- . . . . __ o · BR 224-13 SU.~4?-LARY OF FO'..C.~ATION TESTS .... _ ..... _,,~ ~___ ,., - · . Test No. 1-. Perforations. 6422' - 6440' , 6448' - 6454' and 6462' - 6470'. Very light blow throughout 95 minute test. Recovered 270' rise of drilling fluid in 5" drill pipe. -. Pressure Recorder Da~. .. Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostat: · 3286 14 - · 124 2138 3294 .. · . · Test NO. 2: Perforations 6117' - 6121', 61~9' - 6136', 6138' - 6145' and 6159' - "6176'. Strong blow with gas to surface in 68 minutes. Gas rates 55 to 80 mcf/d for balance 6 hour test, No fluid recovery. --:"- Pressure Recorder Data :r":'·'~"'i'~ !'''' '"'>-"'~'.' .... ":-;-~'' ' .... "' .... ....... ...'.' ,. Initial 'Initial .Final Final Final HFdrostatic Flow Flow Shut In HydrostatJ 3098 72 . . 252 2940 2975 .o - · Test No. 3: Perforations 6026' - 6038' and 6044' - 6076'. Light blow with gas to surface in 40 minutes. 6 to 0 mcf/d rate for balance of 105 minutes -. · test~ Recovered 610' rise of drilling fluid in 5" drill pipe. Pressure Recorder Data - . Initial " Initial Final Final Final · · . 'Hydrostatic Flow Flow Shut In HydrostatJ '. 3194 37- ... 376 2816 3056 Test No. 4: Perforations '5820' - 5848'. Strong blow with gas to surface in 15 minutes Gas rates 125 - 685 mcf/d for balance of 1020 minute test. Fluid recovery undetermined. . . . . . " '~, i ~'' "' , -' . ' / ' · . ' ~. ~ ' -.' ', ' ' '~ ~ o."' ·" ~ ~ "~ ' ' · · Pressure Recorder Data ' Initial Initial ~inal Final Final. Hydrostatic Flow , Flow Shut In Hydrostat/ 3029 51'' 246' 2716 3022 · For:It {' - 7 -- ~jl~ i iii iiii Illl III II II ........................ "'' ,,1 III WELL COMPLETION OR RECOMPLETION REPORT AND LO0* i, J -- - i! i jl~ ............ b. TYPE OF COMPLE~ON: NE~ WORK ~ DEEP- FLUG DIFF. WELL OVRR ~ EN D.~CK RESVR. Other J SUBMIT IN CATE STATE OF ALASKA OIL AND GAS CONSERVATIO~ COMMITTEE 50-283-20042 .~L-58831 -'¢&'qE OF UPEE&TOI1 Standard Oil Company of Califqrnia, W0I ~. ADDRES-~ OF OPERATOR "P. O. Box 7-839 Anchorage, Alaska 99510 4. LOCA'~ION OF WELL (Report location clecrl~ a~td in accordance ~cith a.y State requirements)' ~t.~,ce .1012' NO~ a 2194' ..East from Sou~west corner of At total dep~ 8. UNIT,FAJ~%I OR LF~kSE NAME Not in unit 9. WELL NO. BR 224-13 I0. FI.EiZ2) AND POOL, OR WILDC.axT _Beluga Ri. var Fi~!d 11. SEC.. T., R...%1.. (BOTTOM I-{OL,E OISJECTIVE~ Sec. 13; T13N, R10W SB&M 12. PEI~I!T NO. 73~7 .'. 'DI.~L,. ~CS,.FD~C/ CND,-4iPmeter ' 24. TYPE ELECTilIC AND'OTHE~ LOGS RUN SUt%VEY MADE I CASING !~ECORD (Rupurt all strings set in well) CASI~4G SIZE . WEI. GPIT. LBr FT. DEPTH SET (A~; HOLE SiZE 30" ' 20" 94~ 13 9 61 & ~8- 43.5 47 LIN~SR Iq ECOF..D TOP. ( A'ID, 2B. PER. FORATIONS OP~,N. TC EOTTOLI (.%'ID) SACt~S CEMENT* (intcrval, size and number) CEZILNTING RECOPCD i ~C, iOUNT PULLED SC/~ EEUq. ¢5'.D) SIZE None None None cmt. None TUL31NG llEC OFJ-) DEPTH SET (lID~ ~{ PACIkER SET i?,{D) 23. ACID. DIm'~Ttl 1Nq_'ik~VAL ~. - P~OD UCTION DATE I;'I.E~T. PLIoDLrC'tqON [ ~ODUCTION 5tEIiiCyD ;Flowh~c, ~.'~z iii't, p~m,ping--size and type of pump, ~nu~-in)DLL STATUS tProdacing or --- _- ~_ -- . ..[ . .~ : , ........ Suspended 7~-7. :,'...~ ~ .... . ..'. ___. _ .~ . .,,-- 1_. _~-' [ ............... F~OV;,. Tt.'~iNQ {CASa<;G PRES:SURE ICYALCL~T~ ~II~BL GA~{~. ~ATE~--EBL. [OIL GRAVITY-~I (CO~R. ''"'--'~ l-. '."'~" ~ ~ .1 [' ~'1- P~SPOSl'rlON OF GAS .t~ld~ u~ed ~el, t't'nt~d, 'etc.) ~. Lldl' OF AI'TAC~MKNT~ 'SqUeezes, Fo~a~ion Tests, ~qs ~~ hereby certify iba~ ~he fDregolng and ait:~,4 l~ifl>t~itica IS complete and correct as dete~l'~led from ~~ c~:_ _' ...... ~ - ' -= - - '- ~ - -~ ' _ .......... ........................ .. *(See Insttucfion~ and SPaces for Additions{ Data on Reverse Side) Generah This form is 'designed for submitting a complete and correct well completion report and tog on all types of land~'.and leases tn Alaska, Item: 16: indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction, from more than one interval zone (mult. iple completion), so state in item 20, and in item 22 show the p~cdUcing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reporte~l in item 30. Submit a separate report (pa0e) on this for'm, adequately identified, for each additional iht&, vel to be seperately produced, show- ing the ackJitional data pertinent to such interval. "' Item26: "Sacks Cement": Attached supplemental records for this well shoul,:l 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). See attachment No. 2 .... ~,~AS. U~'~ ~UZ'V~n*f O~_ CHEMICAL & GEOLOGICAL LABORATORIES TELEPHONE (907) 279-4014 P'O. BOX 4-I 276 ... ANCHORAGE, ALASKA 99509 OF ALASKA, INC. 2603 ARCTIC BLVD. GAS ANALYSIS REPORT Company Standard Oil Company of California Date December 6~1974 Well No. 224"21 3 ...... Location__ Field Beluga R~ ver Formation - County , Depth DST #6 at 1/2" Choke State ~i aska . Sampling point Line pressurem__mpsig; Sample pressure .... psig; Temperature , .o F; Container number. Remarks NOTE: Muddy _Sample Lab. No.2520-2 Component Oxygen. Nitrogen Carbon dioxide... Hydrogen sulfide.. ~"Methane Ethane and H~ gher Total ....................... ! GPM of pentanes & higher fraction Gross btu,'cu, ft. @60° F.& 14.7 psia (dry basis) ..... Specific gravity (calculated from analysis) ............... Specific gravity (measured) ...................................... Remarks: Mole % or Volume % 0.02 99.98 Trace 100.00 J010 0.554 - ' O. 554 Gallons per MCF ,:A H '~, 7 1975 'CHEMICAL &-'~GEOLOGICAL LABORATORIES TELEPHONE (907) 2'79L4014 P~O. BOX 4-1276 ANCHORAGE, ALASKA 99509 OF ALASKA, INC. ~so~ ~RCT~C ~LVD. Company, Well No.. Field. County. State .... Line pressure__ psig; Sample pressure.__] Remarks GAS ANALYSIS REPORT Standard 0il Company of California Date December 6~ 1974 224-13 Location Bel u,qa Ri ver Formation ,, ' Depth DST ~7 · A1 as ka Sampling point, i psig; Temperature Lab. No.,2520]-1 34° ° F; Container number Male % or Component Volume % Oxygen Nitrogen Carbon dioxide... Hydrogen sulfide.. Methane Ethane and Higher 0.03 .......... 99.97 Trace . Total ..................... 100.00 Gallons per MCF GPM of pentanes & higher fraction Gross btu,'cu, ft. @60° F. & 14.7 psia (dry basis) Specific gravity (calculated from analysis) .......... Specific gravity (measured) ....................................... Remarks: 1010 0.554 0.554 · JAb ~7 197'5 DIVI,iION Otc OIL ~D GAS -': Company ' Well No. -Counh~ ,, .1 State Une .pressure -~Remarks _ _ . . CHEMICAL &.----GEOLOGICAL .LABORATORIES ' ?EL-~PHONE (907) 279-4014 ': ?~0. BOX 4-1276 "' ~:-~NCHORAGE, ALASKA 99509 OF ALASKA., INC. 2603 ARC'/IC BLVD. · -~GAS, ANALYSIS REPO~ Standard Oil Company of California nat. December 6~ 1974 224-13 " @ 11:00 PM. Bel uqa Ri ver -formation ,nsig; Sample pressure ..psig; ~Temperature .... ~.f; Containet~nber. , ,1-b. No.'.2520-3 --,~xygen 'Nitrogen -:~Carbon dioxide .~l, lydrogen, sulfide. -~Methane ~-~-tha~e ,and Higher 0.02 . o Trace -':~C-~M of pemanes & higher fzaclion ............ ~'~'oss btu~cu, ft. ~60° F. & 1,L7 psia (~r~ harris) ..... :.:':Specific gravity (calculated.from arud~) .............. -.~fic gravity (measured) ........................................... :~l~emarks:' · 0.554 I)iVISiON OF O~L 4ND gAS WELL SU!~VEY Pro-312 WELL NO. BRU 224-13 COUNTY OF CiTY OF SECTION MO. 13 TOWNSHIP 13 N. RANGE ]0 W. g~ S.B.]I. & M. TRACT MO. LOTMO. FIELD Beluqa River [] PROPOSED PRELIMINARY 122 FI NAL ~ N.D.B, & N. 1,O12' North of Southwest corner, Section 13, Township 13 LOCATION North, Range 10 West, Seward Pleridian, Alaska, and 2,194' East at right angle. ~a~u,,,, ,.,=~,, Lower Low Water ELEVATION: GROUND 74.8 CONCRETE 14AT DERRICK FLOOR ALTERNATE OR SURVEYED LOCATION LOCAT I ON DES I GN AT I ON LOCAT I ON COORD I NATES MOVE REMARKS Final X = 325..~75.R5 Y : 2.636,610.09 , , NORTH , 6ENCH HARK IS: Top of meta SKETCH OR REHARKS Coordinates are Alaska State Plane, Zone 4. Location is to center of existing well DIVISION OF AND rim o¢ well cellar. Elevation 4.84' STATION BEARING DISTANCE SINE COSINE NORTH 80UTH EAST WEST r C.C. DIV. ENGR, FILE lINTEl IN U,l.X. SURVEYOR C.A. Herschbac~Al#T. FRHN. DATE October 1. 1974 DATE NAINT. SUPT. DATE PR0.312 (2500-CD. 1- 58) .... BR..224-13 .... _C~e_me_n t 'S_quee. ze .' Jobs Attachment No. Squeeze No. 1 Perforations 5681~. - 5689', 5705' - 5725', and 5743' - 5758' with squeeze tool set at $626~, squeezed'Perforations above with'150 sacks class "G" cement under 3000 psig final pressure. Sq%leeze No. 2 '' Perforations 3660' - 3662'. With squeeze tool at 3516' squeezed per- forations with 368 sacks class "G" cement under 2500 Psig final pressure. Squeeze No. 3 Perforations 3755' - 3760'. With squeeze tool at 3708' squeezed perforations with 150 sacks of class "G" cement under 1900 psig final Pressure. Squeeze No. 4 Perforations at 3525'. With squeeze tool at 3403' , squeezed perforations with 150 sacks of class "G" cement under 1500 psig final pressure. Squeeze No. 5 Perforations at 3322 'o with squeeze tool at 3190' squeezed perforations at 3322' with 73 sacks of class "G" cement under 1500 psig final pressure. Attac~ent No. BR 224-13 "'S[~4M_ARY OF FORMATION TESTS , , __ ~ ,..~ , . Test No. 1: Perforations 6422' - 6440', 6448' - 6454' and 6462' - 6470' . Very light blow throughout 95 minute test. Recovered 270' rise of drilling fluid in 5" drill pipe. , Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 3286 14 124 2138 3294 Test No. 2: Perforations 6117' - 6121' 6129' - 6136' 6138' - 6145' and 6159' - 6176'. Strong blow with gas to surface in 68 minutes. Gas rates 55 to 80 mcf/d for balance 6 hour test. No fluid recovery. Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 3098 72 252 2940 2975 Test No. 3: Perforations 6026' - 6038' and 6044' - 6076'. Light blow with gas to surface in 40 minutes. 6 to 0 mcf/d rate for balance of 105 minutes test. Recovered 610' rise of drilling fluid in 5" drill pipe. Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 3194 37 376 2816 3056 Test No. 4: Perforations 5820' - 5848'. Strong blow with gas to surface in 15 minutes Gas rates 125 - 685 mcf/d for balance of 1020 minute test. Fluid recovery undetermined. Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 3029 51 246 2.716 3022 Test No. 5: Perforations 5681' - 5689', 5705' - 5725', and 5743' - 5758'. Light blow with gas to surface in 46 minutes. Gas rates 17 - 61 mcf/d for balance of 350 minute test. Recovered 2744' rise of drilling fluid grading to muddy wated including 90' of sand on bottom, in 5" drill pipe. 1975 - BR 224-13 ~Summary of Formation~ ~ts Attachment No. 2 Pa~ Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 2960 44 1179 2345 2957 Test No. 6: Perforations 5398' - 5448'. Strong blow with gas to surface in 9 minutes. Gas rates of 1155 to 4196 mcf/d for balance of 725 minute test. Recovered 1254' r~Tfi-n~' fluid in 5" drill pipe. Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 2799 137 2145 2610 2796 Test No. 7: Perforations 4936' - 4958', 4966' - 4996', and 5022' - 5032' strong blow with gas to surface in 10 minutes. At 1250 - 2200 mcf/d rates for /~ balance of 555 minute test. Fluid rise not determined. Pressure Recorder Data Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 2627 51 1440 2210 2500 Test No. 8: Perforations 3755' - 3760'. Strong blow with gas to surface in 6 minutes declining to 7mcf/d rate at end of 255 minute test. Recovered 3050' rise of drilling fluid grading to muddy sandy water. Initial Initial Final Final Final Hydrostatic Flow Flow Shut In Hydrostatic 2043 384 1589 1589 1991 No. I C. ENO ~v. 9-30-6: STATE OF ALASKA SUBMrr IN ~mC*~ s..~ ~C~ co~ -~-~;~-~ O~L AND GAS CONSERVATION CO~I~EE 50-283-200~2 ~ONTHLY REPORT OF DRILLi~ ~. ~s~ ~s:~x.~o~ .x~ s~. ~ ~_ AND WORKOVER OPERATIONS ADL-58831 [-5 ENG J .... _ ~: 7. IF INDIAN, A~i lEE OR TRIBE NAXIE~ 0i~ ~ ~,s ~ ~ 2 C~OL ~ .... WELL *~ WELL OTHER : St~dard 0il Coital of California, ~OI ~ot in mit ..... J .... P. O. Box 7-839~ Mchoraqe, Alaska 99510 BR 224-.!~ ~ SEC '~CA~ON O.F W.:T.T_ 10. F~ ~ND P~L. OR WILDC3 1000' North ~d 2200' East from Southwest co~er of _ Beluga ~ver FILE: Sec. 13; T13N, ~0W S.B & M n'S~C',T',a,m..~O~OMHO~ ........ ' · O~) SEC. 13; T13N, ~0W, S. B. & M. 12. P~IT 73-27 REPORT TOTAL DEPTH AT END OF MONTH, CI4_A_NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrM-ES USED, PERFORATIONS, TESTS A/ND R.ESULTS, FISHING JOBS, JUNK IN HOLE AND SIDEJr'R. ACKEDHOLE ~NI) A-NY OTtiER SIGNIFICANT CH-a2qGES IN HOL~ COHDITIONS. November 1974 Drilled 8 1/2" hole form 8032' - 10,000'. Ran DIL, BCS, FDC, CND, land dipmeter logs. Sidewall sampled. Ran CBN log. Bridged hole with 295sacks of class %'G" cement in two stages from 6755' to 7200~. Perforated 9 5/8" casing with four 1/2" jet holes per foot 6422' - 6440', 6448' - 6454', and 6462 - 6470'. F.' T. of perf'd, intervals 6422' -.64~0'. See attached.~rforated 9 5/8' casing , with four 1/2" jet holes per foot 6117' - 6121', 6129' - 6136', 6138' - 6145' and 6159' 6176' , - . F,T. of perf'd, intervals 6117' - 6470'. See' attached, ~et bridge plug at 6106'. Perforated 9 5/8" casing with four 1/2" jet holes per foot from 6026' - 6038' and 6044' - 6076'. F.T. of perf'd intervals 6026' - 6076'. See attached. Set bridge plug at 6000.. Perforated 9 5/8" casing with four 1/2" jet holes per foot 5820' - 5848'. F.T. of perf'd interval 5820' - 5848'. See attached.~et bridge plug at 5800'. Perforated 9 5/8' casing with four 1/2" jet holes per foot 5681' - 5689', 5705' - 5725', and 5743' - 5758'. NOTE--Report on this form/is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the !Sth of the succeeding month, unless otherwise directed. TEANS~~ AND AC~'~L'EDGMENT OF RECEIPT OF HATER~, (ALASKA} ~o~ Mr. T. ~ Ma~hali D~E: /~ .DE~ ~ Dillon of 011 a Gas · -- ":- - .- -' . .:~ Anchorage, Alaska 99504 : ' .... _ _ ' ..._. . 'i' '::; ' .' .. . ] -- j~ ~ ~.~'i' ' ' --.~--"'" .......... ''~ ':~ '-:'" "-%' ...... ' i-.' ;.7.. - ~ . ' ....... i-' ...'~ '' " '" ' '"' - ' --- ' '- .... - ' . ..._- :. ' :'L:' .... ' Ti~ FOLLO~ZING IS ~ LIST OF HATE~ E~CLosED HEREWITH. PLEASE- :~!':"" '~ - ' "': ":::'" CH~CK AND ADVISE .IMMEDIATELY · .-:-.....-- . . .- . . · ..: ,. . . . :-'" .. .- .~., _ ';':":-'- COMPANY ,~~~ -~:-;';i':.'.~.~;-...;:-:?':-'..-.:' 'SC*'E~L.XEROX .;!:~ WELL_ ~,~. ,,~,2~:~_:~~'':~'. ,: ' .- 'SEPIA SLUE , -. ' ::.:~. --" . · .... ~..- . .. -.... . .- ~:~".~'.;.'- RUN · -' ...... ~ ·-. -. ~).. '-. .. . ::. ';.-. i.,-;:.? ~' ,:..~;~ :-~:" ....- '. o' ....,. :'.....-e.- · -.,'.~.j.. : -:.,. ,, . .-- . . OUAL INDUCTION LATEROLOG'.soNIc i'" · _. - ,.,,.,,.,....:' .~... '.'~.. . . '. · :~..";'...~...-' ' · BOREHOLE COMPENSATED' . . .. . ~ -'~' -.-~~-;:..: . .-. ~ . ,7..-~. it- "--'/ ' BOREHOLE COME SONIC w/colip~r .'-':- -- --- ~ ':/-~-.-.---~ ~.'.r='" ; ' . __,." _ '~ ' ' . - . ..... : · BOREHOLE CO~4R SONIC w/gomm~3 ....... ,' .?.-'.- .... · . :'~ - .:.. . ..-- _ __ ~:.:'~-:'~"- -. BOREHOLE TELEVIE~,,,'ER .. "'---" -- -- -' . - .-'.- . . , . _ . .. . .~ ..:... -. -. · . .~:. ... ?:-.-'.- :- -:.-,_ ~ ..~_ CONTINUOUS DIPMETER HIGH RES. ' -'-- --/"~'.'""' "" ' °' _--'----'7 ' - '~'~;~:~:=..._.;...:' '- CDM - POLYWOG PLOT - ' ;:'- '--"~'.... '.' ::.' .'-. - - ' - -. ' ~_ ' ,&;...:_:.. , ........ .;--:. ..... .---; ,;. ~..~-,-.--.. ~ , ,~.-.~..-i/' CEMENT BO~:D LOG .... ' .... · ..... ' ...... ' .... ~'--' '~ .... : -'"" '-~":, : ~' .'7----/' ',r.:?~ _ ~. CASlt;G COLLAR LOG "' ": :' ":'::" :'""'""--'. , ~ -- ' :.~.,:._-~'/-~ 'COMPENSATED FORMATION DEt~: '.'}..~ --- -:' ::!i:.i:?:=.::.-,., .... FORMATION ANALYSIS LOG . "-' '-"&'""". . ..-- ", - ~ '- ~ ' - .,..,.~- · _-. ' FORMAYIO]'~ DENSITY LOG F F '.:" .... ".'-'---'~--'-- ' ,,i, . ... · ~1,4,~.~ . . ' ' ' · ' ~ ~ _-- ... FORMATION TESTER :'-:'~.'..:..:'~:,.':.--'.' ." ':.'~."-' ':.: -. · - .o -'...... ... ~ '-- . · . .. .' - ~,, ~ FO~MATIO;~ .FActOR F R ...... :!:.';:-?. '.'-...;.'--': .... - . ---- -- ':"-"-~ "~ ~'.' ' .... ..,."'-- ,, .............. .... -:._.. : .'--: ~:: :.:.- . .. · .... , .__... ~:','i~-- GAMMA RAY-NEUTRON ':';: ~' ';:: "---"-:'"' -- ' - ,_ .- . ' ' _ 'L '..-.?.~._~ ' ..... -__ ~ .... -' · ,. _ ' GAMMA RAY COLLAR LOG-' ':' ='.-;.~ .,:... ,~._ i, ,1~ ' . i ,. · ,=. ::. :::'.. ' MICRO LOG ' "" ' · "'V ~""""' ~ · . ,, : -:- .':-':::.~',,·~,'..' · .. · · . -- _ .. - . i .. --. , i i ,.? .... _-__ , ]CROLATEROLOG ' : .....;"'.'.'.""-'"'- - ' - . .... .... ,:.".......... ,- '-- : ~. MUD LOG ,: ,~- ...=:'.'~.~:?: '-:-;'"",.;-~-'"..' .... . . "' ' ' -- NEUTRgN LOG :~"-'.;.;:,:'-',-~ -.-- ' -- '' - - .--"' ~. " -- i.i - ' ': ~__:/..-.'2..;, -PEOX:;~ITY MICROLOG . '. L, :"~-.'i".. ' '/~ ',Z "::. ?.' -,--. · PERFORATING RECORD ............ .... ' . ' ~_ - :..:.' ':.___ RWA COt.',PARISON PLOT : ..:'~','-.'"';" --'- -~ -- - ~..'- . SANDSTONE ANALYSIS ' ": ...... --'""~" - ' ~' ~ ~ " - "~ · · · -- I -- ' " - . . .... - - . 'SIDEWALL NEUTRON POROSITY.' -" ~-'- - ' - ' - ~, _ . - . i- J_ . ~ . ':;. _-_- ·SONIC :. .. __ . ...... ....... T£MPERATURE LOG '""!' ~'. '"'- '-' ........... ' ',. .. : .~: '.-:....----. ,...,,,_:' .. ~ . ' .... ~ - .~. ~. - ; ' . , , ,, ,-: . ell,.,,.i ~ . . · --. , i i. :LILL -- , , , · : . I I , , "'" ..... : :""'" COMPLETION REPORT '-" ' '"' ': ~' '--~'-' '' ~. . ' . .' , · .. ;.,-. ::.-,,.. :'. . · . . ~'.;-' ;'-' DIRECTIONAL SURVEY '"'"'"-... " ' · ':~-:' -' . L. ' - · .::" '~. .... ,. , .~-__,_ · ';'". '~ .' '- ..· ~ , ,. -....· . ' · , . · "';: ~*"". ' · ' ' ' · '"' ' '° : ' * · ' · ~' : · · · ' ' ' ' ' · ' " :""'""'"- - · ' :~. :, ,5 '" '/_ * .- . .%~. /~ ~. -. /. / , .. - · ' ' "' ~,---m " 'Z," P~c._ _.' : '"' ; '" · ' ' PLAN OF OPERATION BELUGA RIVER WELL 224-13 BELUGA RIVER AREA, ALASKA 1. Well Site and Setting The proposed location for well 224-13 is approximately 1000' north and 2200' east of the SW corner of Section 13, T13N, R10W, SB & M. A new permanent gravel pad will have to be constructed at the pro- posed site. About 3' to 4' of tundra covers the underlying gravel, and this will be cleared in the area'of the site including the mud waste pit. Excavation material from the pit will be used for a por- tion of the location gravel. Additional gravel will be needed for the pad and will be needed to build approximately 3000'~of a new access road from an existing road. This gravel w£11 be removed from an existing borrow pit located approximately 1.7 miles from the proposed start of the new access road. It is estimated that a total of 20,000 cubic yards of new gravel will be required for pad and road construction. Gravel permits were approved by your office during June of this year (ADL-637!2 and ADL-64108). We intend to utilize gravel under these permits for the road and pad comtemplated. The proposed pad and access road'will be constructed in an open swampy area. 2. Existing Roads and AirstriP Ail roads in this area from the Superior Landing to the south to the Ivan River 44-1 well to the north were built in the 1962-1965 era by Standard Oil Company of California as-operator for the Beluga River Unit as well as during the course of other exploratory activity. ~ The proposed 3000' access road to the proposed BR 224-13 location will be a spur road from one built during 1965 in support of explora- tory.well Ivan River 44-1. The pit proposed as a gravel source for well 224-13 was also used as a source to build the existing road in 1965. The Beluga River Airstrip was constructed during the 1962-63 original - field development. It will also be used in support of our proposed drilling operations at BR 224-13. 3. Water~_Supp!y A new water source well will be drilled at the location to support our drilling operations. 4, Dri.! l_i_ng R_ig- We have negotiated with Kenai Drilling Company for use of Rig No, 1 to drill our proposed well. We anticipate moving to BR 224-13 during the last half of August and after completi~ tubing and packer repair work in BRU 241-34. ~ ~ ~ ~ ~ ~1 ~~~ tt ~ ,It. IL 2 9 974 Plan of Operation Beluga River Well 224-13 Beluga River Area, Alaska -2- 5. Access to Site and Method of Sup~_ly The site is remote and is not connected to the Anchorage area by road. The only access is by one or more of the following: A. BARGING TO THE SUPERIOR LANDING (STATE RESERVED AREA ADL-45327) During most of the year, barging is possible from the Kenai or Anchorage area to the Superior Landing and thence by truck to the proposed wellsite. Use of this landing will definitely be required to drill the proposed well. Most all of the materials and supplies required to drill this well will have to be barged to the Superior Landing. We request continued permission to use the Superior Landing. We estimate operations will continue intermittently to the end of 1974. B. AIR TRANSPORT TO BELUGA AIRSTRIP The Beluga Airstrip can handle Hercules-type airplanes, and we intend using this method to move freight and other items as can be justified economically,-in addition to barging. Since the rig uses diesel fuel, we will probably fly in the fuel. Sufficient hard tankage i~ available to eliminate con- sideration of "bladder" tanks. The rig location will be graded so that any fuel leakage will be conducted to the waste pit. .A 50,000 gallon fuel dump will be established at the Beluga Airstrip at the same location as existing facilit±es installed in 1962. These tanks will be installed in a diked area which will contain any fuel spillage or leakage. 6. Personnel Support A camp capable of housing and feeding approximately 40 men has been installed in an area adjacent to the existing airstrip and will be our base of operations. Personnel will be flown in and out on a scheduled basis of approximately 10 days working and 5 days off. Food and other supplies will be flown in on an "as needed" basis. Sanitation facilities for the camp, consisting of a septic tank and two leach pits, have been constructed with the approval of the Anchorage Office of the Department of Environmental Conservation. A camp water well will be required, and at the time of drilling this well we will °btain bi°l°gical tests and inform DeD~rt~g'"'nt ~F~ ~ ~/ r~ ~U~ plat and lab tests..~..'~ IlI~ !~ ',~ Environmental Conservation with a II~i<~~ ~ ~ · Plan of Operations Beluga River Well 224-13 Beluga River Area, Alaska -3- In addition to the camp, a house trailer has been installed for Standard Oil Company supervisory personnel. 7. Miscellaneous Related D~illing Items A. The waste pit will be located, constructed, and diked as neces- sary to prevent the possibility of any seepage to the surrounding terrain or drainages. Upon completion of drilling activities, the waste pit will be filled, leveled, ~fertilized, and reseeded with natural grasses. B. Sanitary facilities at the rig location will be chemical toilets. These toilets will be emptied periodically and the material hauled and dumped into the camp septic tank. C. The proposed location is approximately 500' from the nearest pond. Our proposed drilling operations should not disturb this area whatsoever. 8. Other Construction on the Site Well BR 224-13 is a development location, and commercial production should be encountered. This well is being drilled to aid in the determination of the field reserves and productive limits. There is no immediate market for the gas volumes expected because our existing wells to the south have the capacity to supply our contractual requirements to Chugach Electric Association. Accordingly, produc- tion facilities will not be immediately installed. When they are installed, the production, dehydration, and metering facilities on- site will be similar to those already installed for six existing producers. Some minor interconnecting line changes may be required. At present we plan to complete the well with three producing strings. 9. General Comments A. No unnecessary surface digging will be allowed. In the past we have restored construction areas and taken measures similar to the rehabilitation methods used at Swanson River. In this case, if sufficient need exists after the proposed work is completed, we intend to fertilize and reseed as necessary with natural grasses. Regrowth in the Beluga Area is rap±d and does not appear from past experience to require much help except fertilizer. B. Solid wastes such as mud sacks, kitchen waste, etc., will be hauled to the central waste pit near the airstrip and buried, while other hard wastes such as drilling bits, etc., will be drillingdiSp°sed Ofis finished.in the waste~Dit when it is close~n~ ~v~e~ ~i~r~!~t f.~ . Attachment - Beluga River Area Map ~t~!~ .... ~ 9 'i~'}~ 16 RIVER U~]iT I /..~ e,~,::,o r' -' I - I /t 1 · ;~14-] I ~- ~, ~ , ~,. SCALE Z" · ! mile DATE 7-22-74 ..1_ BELUGA RIVER UNIT AREA PROF0SED B.R. 224- SHOWING LOCATION AND LEASES Itl AROUND SECTION 13, T. 13 N., RIlOW. STANDARD OIL COMPANY OF CA¼1FORNIA / / Standard 0il Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, Al( 99510 · Phone (907) 279-9666 J. L. Rowland Area Supervisor Producing Department July 26, 1974 State Oil and Gas Lease ADL-58831 Plan of Operation~._for. Drilling Beluga River We~224-13.,. Beluga'River'Area Mr. Homar Burrell, Chairman Alaska Oil and Gas Conservation Committee Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Rodney Smith Regional Oil and Gas Supervisor Alaska Region U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Gentlemen: The attached Plan ~~ions covering the forthcoming drilling of BR We~ ~1~!i is for your files and information. Very truly yours, WCM:dw Attachment ,11!I o 9 Form 10-- 401 REV, I--I--71 (Other instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN IA. TTPB OF WORK DRILL ix] DEEPEN WgLL NAME OF OPEH~TOR API 50-283-20042 5. 6. LEASE D~'~IGNATION A_N'D ~I[,~[/AL NO. ADL 58831 - 7. IF INDIAN, ALLO'i-r~:~: OR TtLI~E NA_M~ 8. UNIT, FARM OR LEASE NAME Not in Unit g. WELL NO. BR 224-13 10.I~IELD AND POOL, OR WILDCAT Beluga 'River Field Standard Oil Company of California, Western Operationst Inc. 3. ADDRESS O~ OPERA~R P. O. Box 7-839o _anchorage, Alaska 99510 4. LOCATION OF WELL At sur~ace 1000 ft. North and 2200 ft. East--from Southwest Corner of Sec' 13 T13N, R10W, S. M. At proposed prod. zone Same as surface location. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 40 miles West of Anchorage SEC., T., R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 13, T13N, R10W, S.M. 14. BOND INFORMATION: TYPE Statewide surety and/or No. #451636 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OH LEASE LINE, FT. ,Also to nearest drig unit ii any) 16. NO. OF ACRES IN LEASE 1000 fto 1,268.57 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 3750' +- from #212-24 21. ELEVATIONS (Show whether DF RT, CH, etc.) 80' +- Gr. l iB. PROPOSED DEPTH 10,000' .,~noun? $100 000. 17. NO. ACRES ASSIGNED TO THiS WELL 6210-F' 20 ROTARY OR CABLE TOOLS Rotary ~9.. APPROX. DATE WORK WILL STAHT* 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT .]~ GRAIDE S~I'rlNG DEPTH quantity of cement 26" I 20" 94 H-40 400' ~' "' ~85"_" sacks ;~'r//t' £'~/ -~,,"fr. S~ ,, ¢~ 17%~'- 13 3/8" 68 K-55 3270' +- 1950 sacks ' ~5')/~.. 3oz'./~:' Z~'f% ~ 8~" / 7" 29 ~-~0 10000~ ! 650 ~acks (L~er ~oe~ ~ 6800.'!~ / We plopose to drill subject well per attached program. PleaSe treat this. well as 'confidential. Pleasktransfer $100.'00 Drilling Permit Fee No. 73-27. filed on__BR~U ~3~1~. ~4, I hereby ce~ify that ~ Poregoins~e ~d Corre~ s,,,m...~/~.~ ~ ~/~~ Area DA~ ~ ~gi-neer ' ' ~~ 'M,, _ Mc~n,:ley // "' (This sDaee ~or S~Ze oHiee u~) CONDI~ONS OF ~V~, ~F A~: SAMPLm AND CORE CHIPS R~U~ I m~'D LO'C ~ DI~ION~ SURVEY R~~ A.P.I. ~C~ COD~ ,'.PPRO',a:D ....... -- Trr~. _ ~ecretary ($~a¢~§ exception §~ante~'J"""~""' Dy u0nservat~0n u~ae~ #]27) · · ! T. 12 N.,R. IOW 2'52-; 4 SOCAL-ARCO SHELL ADL 2'112 ~," #! 212~:~5 ,.L . -° i 3 SOCAL- ~/,/'/7 e,, 13 ~,L -- ARCO -SHELL ADL~ ~8851 PR 224, -I$ 212- 24 ~CO- SHELL ZII28 212-25 ~)CAL-ARCI SHELL AOL 0 RIVER UNIT i AUG 9 I974 BELU6A RIVER UNIT AREA PROPOSE0 B.R. 224-1~3 SHOWING LOCATION AND LEASES AROUND SECTION I$oT. ISN.~RJOW. SM. STANDARD OIL COMPANY OF CALIFORNIA g" ,~ I mile DATE 7-22-7'4 ENeR :£ PW O~lWe..d~_~_~ ~g~t 11, 1974 Re: Beluga River Fteld, BR 224-13 Standard Or1 ~ny of Caltfornta 73-37 Mr. R. g. McKtnley Area Eagtneer Standard Ot I teaparty of Ca1 gestera Oparatleas P. O. B~ 7-83g Anchorage, Alaska 99510 Dear Str: E~closed *ts ~ app~ appltcatton for perett to drt11 the above referenced well, on or about Oc~r 31, 1973, at a lecatton tn Sectton 13, Townsbtp Range Igtt, S.H. ge11 samples, .core chJps, and a mud log are not required. A dJrecUonal survey not requJ-red. I~aRy rtvers tn Alaska ~ 'have been classtfted as taper .t~mt for the spa~Jng or anal' fish. Operattons tn t~ areas are:subject to AS 16.50.870 and the regulattoas preaulgated there- under (Title 5. Alaska Adetntstratlve Code). Prlor to ~Jng operattons you ~ be contacted by the ~bttat Coord~tor's off,Ice, Oepartm~t of Ftsh and Game. Pollutten of aw waters of ~ State Js prohibited by AS ~, Chapter 03, Act, as amended. Prier to cemeactng operattons you may be. contact~ by a represeatatlw of the ~parteent of Entire aec at al Coaser~att'ee. Pursuant te AS 38.40, Local Htre L~der State Leases, the Alaska Department of Laber ts being nottfted of the tssuance of thts perett to. drill. very truly yours, Thorns R. Harsha11, Jr'. Executive Secretary Alaska Oil and Gas Conservation .Coaeittee (Spacing .excepttongrantedby Conservation Order {127) TRN:Jb Enclosure cc: Department of :Fish and Gaee, Habitat Section ~/o eric1. Departaent of Env~romaental Co~ser~atJon w/o eric1. Oepart~nt of Labor, supe~tsot, Labor Law.' Coepltance August 6, 1974 Twelfth Plan of Development and Operation for the Beluga River Unit No. 14-08-.0.001-~1~ · Mr. Rodney A. Smith .... 'Mr,,. F. J.-Keenan, Director Regional Oil and Gas Supervisor ........ Division of Lands Alaska Region ~-..·.Depar~uent of Natural Resources-. U. $. Geological Survey ... ...... State. of~Alaska P. O. Box 259 ~- ........ 323. East Fourth Avenue Anchorage, Alaska 99510 .......... Anchorage,. Alaska 99501 .. Gentlemen~ .................... , ...... .. In our Twelfth Plan of Development and Operatio~fortheBeluga River -. Unit we included the drilling of~w~.,224-13.-~is well is, in fact, outside the existing Beluga River..Unitboundary,,. but.it is our intentiom~-~ to apply for expansion of the Unit Boundaryif well 224-13encounters hydrocarbons in commercial ~antities.~ .. - . WRT,mjs CC: Very truly yours, .... . STANDARD OIL COMPANY OF CALIFORNIA .... ~NI~ OPER~OR . . Mr. J. P. Johnson, ARCO, .Anchorage .......... Mr.-F. H. Richardson, Shell, Houston 16 ~ · /=,7 oi 5 ! · ! · T. 12 N., R. IOW 25~,- 4 /t ! :AL -- ARCO -SHELL 224, '15''~'' 212-24 $OCAL-ARC( SHELL ADL I 0 SOCAL- CO- SHELL · -I/? ADL 2.1128 $0C AL-ARCO~/) SHELL /,/~.-.,.... ADL 21127/J,,'1 ', '-, /11 t · ' '"' // , // */ // '",'// , ,i.;" .¢-/~_ ~8 I2 - 2 s I~ 4? ! , ,/,'.~" I I ' , I i mm m i m · · BELUGI RIVER UMIT , AU6 9 I974 D1¥ISION 0~: OIL AND 212~35 BELUGA RIVER UNIT AREA .1_ SCALE 2"z I mile DATE 7'22-74 ENgR _E PW DRWe. PROPOSED B,.R. 224-13 SHOWING LOCATION AND LEASES IH AROUND SECTION 13, T. 13N.,RJOW. SM, STANDARD OIL COMPANY OF CA~IFORNIA' PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Beluga River Property and Well No: Beluga River 224-13 Location: Approximately 1000' North and 2200' East of the Southwest Corner of Section 13 T13N, R10W, SB & M. Elevation: Estimated 80' Ground and 100' K.B. Blowout Prevention Considerations 1. Potential Problems: a. Gas: _ _ _ The proposed well is a development location on the northerly plunge of a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries into the mud column can cause serious problems. Care must be taken at all times to prevent these entries by either 'swabbing the well when pulling pipe or hydraulicing the formation, with associated lost circulation, on trips. Rapid penetration rates cause an increase in mud weight and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause'serious problems. The beds contain some gas, slough-readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/ or circulate bottoms up. b. Lost Circulation and Water Entries: In recently completed well BRU 212-24 circulation was lost using 70 pcf-mud while the drill pipe was stuck at 927'. From this depth to 3777','some loss in mud was noted. Mud weights varied from 70-75 pcf. No serious losses were recorded, but extreme care must be used in maintaining solids free mud with the properties outlined in the Drilling Fluids Program. Penetration rates will be limited to maintaining optimum drilling fluid properties. c. Precautions Kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. AUG 9 I974 Proposal for Well Operations PRO 316-1 Drilling Program 3. Maximum Anticipated Surface Pressure: 3000 psi; however, the "D" Zone ~an exert a surface pressure of 4500+ psi with a gas column. -4. B~.l_o.~u_t prevention .Equipment: a. 20"-- 2000 psi, Class IIB on 20" casing. b. 12" - 3000 psi, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8". .¢. i0" - 5000 psi, Class III & Shaffer Rotating Blowout Preventer on :the 9 5/8" casing. 5. -Objectives: Sterling, Beluga River, and "D" sands of Tyonek Formation. 1. Drive 30" conductor pipe 60' to 80' below cellar floor. 2. Drill for 20" casing to 400'+. Maintain drilling fluids per attached Drilling Fluid Program. 3. Cement 20", 94#/ft., H-40 Buttress casing at 400' with 485 sacks of 'Class "G" cement premixed with 2.4% Gel, by weight of water. This provides a 50% excess cement volume. If cement does not return to the surface, do a top job through a 1" pipe at 90'+. a. Cement-Gel Properties: Yield: 1.86 cu. ft. slurry per sack cement Slurry Weight: 97-98 pcf Water Required: 1.38 cu. ft. per sack cement Gel Required: 1.5# per cu. ft. water b. Use a duplex shoe with stab-in connector. c. Bakerlock or weld casing to shoe. d. Centralize casing over the entire 400'. Proposal for Well Operations PRO 316-1 Drilling Program 4. Install Class IIB BOPE on the 20" casing per attachment. Nipple up blow and kill lines, and manifold for 3000 psi service. Class III, 12" - 3000 psi BOPE with Chaffer Rotating Blowout Preventer will be installed later. Test BOPE per Operating Instructions D-17. Note: Burst pressure for 20" 94#/ft. H-40.casing is 1530 psi with no safety factor. Do not exceed a 400 psi test. .~ 5. Drill out cement and shoe of 20" casing. Drill ahead in 17 1/2" hole to a dull bit near 3300'. Condition mud and hole for logging. ~ Note: a. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. b. Install Mud Logging Unit at the shoe of the '20" casing and retain to total depth. Specific instructions will be ~provided to the Mudloggers under separate cover. 6. Run and tape the following logs using Schlumberger men and equipment. All logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. Dual indqption_,- Laterolog: 2" = 100' - Arithmetic, 0-50 ohm-meters resistivity and + 10 mv SP scale. 5" = 100' - Logarithmic, 0.2-2000 ohm-meters resistivity and +10 'my SP scale.- -b. Combination Compensated ....... Neutron-Density Log: Density scale 2.0 to 3.0 grams/cc. Neutron scale 0 to +60 sand- stone porosity units. Gamma-ray and caliper curves to~z~~~ ~ ~~ in the left hand track. c. Borehole compensated s0ni~LL?g- with~ntegrator: use 100 to 200 microseconds transit time. DtVISION 0~ d. Have on location a Proximity Log, Dipmeter tool, and sidewal~~{'~A~ sample gun. 7. Drill ahead in 17 1/2" hole to top of the gas productive Sterling sands, depth, equivalent to 3278' in well BRU 212-24. Repeat logs if necessary. 8. Cement approximately 3270' of 13 3/8", 68#/ft., K-55 Buttress casing, in the shale section immediately above the uppermost productive Sterling sands, with 1950 sacks Class "G" cement premlxed with 2.4% prOPosal for Well Operations PRO 316-1 Drilling Program Gel, by weight of water. This provides a 50% excess cement volume and should return cement to the surface. If cement does not return to surface, do a top job through a 1" pipe at 90'+. a. Cement properties as same as Step 3a. Use a float shoe and duplex collar with stab-in connector. c. Bakerlock the bottom five casing joints. d. Use centralizers at and above the casing shoe and collar, and in the 20" casing.. 9. Cut off the 13 3/8" casing to allow top of tubing head to be above ground level upon completion. Install 13 3/8", 12" - 3000 psi top -flange, SOW casing head. Test welds to 3000 psi. 10. Install 12" - 3000 psi Class III BOPE including a Shaffer Rotating Blowout Preventer per attachment and Operating Instructions D-17. Connect blow and kill lines. Pressure test all BOPE to rated pres- sures per Operating Instructions D-17. . 11. Drill out cement in 13 3/8" casing to within 10' of float shoe. Run 'Variable Density Cement Bond Log from effective depth to the 20" casing shoe, Make shut-off tests as required. Pressure test 13 3/8" casing to 3000 psi. 12. Drill out cement and shoe, and drill ahead 'in 12 1/4" hole to 300' below the lowermost gas shows or to dull bit near 7000'. Condition .mud and hole for logging. a. Consideration will be given to spotcoring selective intervals in the Sterling and Beluga River sands. b. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. Circulate out drilling breaks or reduce penetration rate as directed by the Standard Oil Company Drilling Representative. 13. Run and tape the following logs at the effective depth using Schlum- berger men and equipment. All logs are to be run from the total depth to the shoe of the 13 3/8" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. Dual Induction - Laterolog: Same scales as Step 6a. b. Combination Compensated Neutroni~ensi~¥ Log: Same scales as in Step 6B. c. Borehole Compensated Sonic Log with Integrator: Use 50 to 150 microseconds transit time. Caliper and SP curves are to be recorded in the left hand track. SP to have +10 my scale. d. Proximity Log - M~crolog with Caliper_: use logarithmic resis- tivity scale of 0.2 to 2000 ohm-meters; micro normal 2", 0-20 ohm-meters; and micro inverse 1" x 1", 0-20 Ohm-met~ [~ ~ [-~ ~ ~ ~ [~ AUG 9 I974 Proposal for Well Operations PRO 316-1 Drilling Program e. Run four arm HR dipmeter and record using both analog and mag- netic tape. f. Be prepared to take sidewall samples. 14.. Cement approximately 7000' of 9 5/8", 43.5#/ft., N-80 8rd LT & C and Buttress casing on bottom in two stages as follows: a. Use float shoe and float collar. Run one stage collar and place near the base of ~he Sterling sand. b. Bakerlock the bottom five casing joints. ¢. Centralize the casing throughout the productive intervals. d. Cement the 9 5/8" casing ~n two stages as follows: Stage 1 through the shoe using 850 sacks Class G neat cement. Use no excess. Fill calculated from 7000' to 3800'. Stage 2 through stage collar near 3800' with 500 sacks Class G cement. Fill calculated to the 13 3/8" shoe plus 1000' into the 13 3/8" x 9 5/8" casing annulus and includes 38% excess cement on the open hole portion. 15. Land the 9 5/8" casing. Install 12" - 3000 psi x 10" - 3000 psi tubing head and secondary seal assembly. Test secondary seal to 3000 psi. 16. Install 10" - 5000 psi Class III BOPE. Install kill and blow lines per attachment. Test BOPE per Operating Instructions D-17. Test lines to 5000 psi. 17. Drill out cement at stage collar and clean out to top of float collar. Run Variable Density Cement Bond Log from effective depth to shoe of 13 3/8" casing. Establish segregation points as required by squeeze cementing. 18. Drill out casing shoe and drill ahead in 8 1/2" hole to dull bit near 10,000'. 19. Run and tape the following logs using Schlumberger equipment. Ail logs are to be run from total depth to shoe of 9 5/8" casing. Take a 1/2 gallon sample of drilling fluid prior to pulling D.P. for logging. Use same scale as in Step 13 abo~e. a. Dual Induction - Laterolog b. FDC Compensated Neutron with Gamma Ray c. SP - BHC Sonic Log Four Arm High Resolution Dipmeter e. Proximity Log - Microlog with Caliper f. Be prepared to take sidewall samples. AUG 9 I974 20. Based on the formation evaluation analysis, cons±deration will be given to one of the following: Proposal for Well Operations PRO 316-1 Drill '.~ng Program a. Drill ahead to 12,000'~, run suit of logs,.evaluate, and make further recommendation. b. Cement 7" liner at 10,000'~ [or abandon the lower portion of the hole prior to cementing the liner) and complete well for produc- tion. 21. A detailed completion program will be provided after the final log run. The proposed completion for BR 224-13 will be a triple string with the long string to produce the Tyonek, the intermediate string for the Beluga, and the short string for the Sterling. Should the lower horizons turn out to be unproductive, then-the completion program will be revised accordingly. JUL ~6 'r4 RMM ~.B.A. Dakessian/W. D. Sauer DRILLING FLUID PROGRAM BELUGA RIVER 224-13 BELUGA RIVER FIELD Basic System Lightly treated Lignosulfonate mud. Optimum P~0~erties To 13 3/8" Cs~. Point Weight, pcf 73-76 Viscosity, sec/qt, API 40-50 Fluid loss, cc, API 20+ Plastic Viscosity, CPS - Yield Point, lb./100 ft.2 - Gel, lb./100 ft. 2-10 min. - ph - Calcium, ppm - Solids Content, % Volume - Value Range 13 3/8" Csg. Pt. to 9 5/8" ___ Cs_g. Pt. 9 5/8" Csg. Pt. to T.D. 76-80 78-82 40-45 40-45 4-6 4-6 10-15 10-15 5-10 5-10 10 max. 10 max. 8.5-9.0 8.5-9.0 50 max. 50 .max. 8-10 8-10 Remarks: Chemically disperse mud with chrome lignosulfonate. Treat. calcium out as required. Maintain adequate supply of lost circulation material and barite at the location. Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit dry jobs to 10 sacks of barite or as directed by Drilling Foreman. AUG 9 'I974 PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM Field: Beluga River Pr0Pertyand Well No: Beluga River 224-13 Location: Approximately 1000' North and 2200' East of the Southwest Corner of Section 13 T13N, R10W, SB & M. Elevation: Estimated 80' Ground and 100' K.B. Blowout Prevention Considerations 1. Potential Problems: a. Gas: The proposed well is a development location on the northerly plunge of a known gas field. Numerous gas sands w~ll be penetrated during the course of drilling this well to total depth. Gas entries into the mud column can cause serious problems. Care must be taken at all times to prevent these entries by either swabbing the well when pulling pipe or hydraulicing the formation, with associated lost circulation, on trips. Rapid penetration rates cause an increase in mud weight and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain somegas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/ or circulate bottoms up. b. Lost Circulation and Water Entries: In recently completed well BRU 212-24 circulation was lost using 70 pcf-mud while the drill pipe was stuck at 927'. From this depth to 3777', some loss in mud was noted. Mud weights varied from 70-75 pcf. No serious losses were recorded, but extreme care must be used in maintaining solids free mud with the properties outlined in the Drilling Fluids Program. Penetration rates will be limited to maintaining optimum drilling fluid properties. c. Precautions Kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. ~ ~ ~ /~ ~..~/ ~ ~) AUG 9 I974 DIVISION OF OIL AND GAS Proposal for Well Operations PRO 316-1 Drilling Program 3. M~aximum Anticipated Surface Pressure: 3000 psi; however, the "D" Zone can exert a surface pressure of 4500+ psi with a gas column. 4. Blpwout prevention Equipment: a. 20" - 2000 psi, class IIB on 20" casing. b. 12" - 3000 psi, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8". c. 10" - 5000 psi, Class III & Shaffer Rotating Blowout Preventer on the 9 5/8"'casing. 5. ~bjectives: Sterling, Beluga River, and "D" sands of Tyonek Formation. PROGRAM 1. Drive 30" conductor pipe 60' to 80' below cellar floor. 2. Drill for 20" casing to 400'+. Maintain drilling fluids per attached Drilling Fluid Program. 3. Cement 20", 94~/ft., H-40 Buttress casing at 400' with 485 sacks of 'Class "G" cement premixed with 2.4% Gel, by weight of water. This provides a 50% excess cement volume. If cement does not return to the surface, do a top job through a 1" pipe at 90'+. a. Cement-GeI P~0Perti~s: Yield: 1.86 cu. ft. slurry per sack cement Slurry Weight: 97-98 pcf Water Required: 1.38 cu. ft. per sack cement Gel Required: 1.5# per cu. ft. water Use a duplex shoe with stab-in connector. c. Bakerlock or weld casing to shoe. d. Centralize casing over the entire 400'. AUB 9 I974 Di¥1tSION OF OIL AND GAS Proposal for Well Operations PRO 316-1 Drilling Program 4. Install Class IIB BOPE on the 20" casing per attachment. Nipple up blow and kill lines, and manifold for 3000 psi service. Class III, 12" - 3000 psi BOPE with Chaffer Rotating Blowout Preventer will be installed later. Test BOPE per Operating Instructions D-17. Note: Burst pressure for 20" 94#/ft. H-40 casing is 1530 psi with no safety factor. Do not e-xceed a 400 psi test. 5. Drill out cement and shoe of 20" casing. Drill ahead in 17 1/2" hole to a dull bit near 3300'. Condition mud and hole for logging. Note: a. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. b. Install Mud LOgging Unit at the shoe of the 20" casing and retain to total depth. Specific instructions will be -provided to the Mudloggers under separate cover. 6. Run and tape the following logs using Schlumberger men and equipment. All logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. Dual Induction - Laterolo~: 2" = 100' - Arithmetic, 0-50 ohm-meters resistivity and + 10 mv SP scale. 5" = 100' - Logarithmic, 0.2-2000 ohm-meters resistivity and +10 my SP scale. · b. Combination Compensated Neutron-Density Log: Density scale 2.0 to 3.0 grams/cc. Neutron scale 0 to +60 sand- stone porosity units. Gamma-ray and caliper curv~o~r~~ ~ in the left hand track, i~ ~ ~U~ I1\\ C. Borehole Compensated Sonic Log with Integrator: ~" AU8 9 I974 Use 100 to 200 microseconds transit time. DI¥ ION 0~ 0IL AN~ GA~ d. ,ave on location a Proximity Log, Dipmeter tool, and sid~~5 sample gun. 7. Drill ahead in 17 1/2" hole to top of the gas productive Sterling sands, depth equivalent to 3278' in well BRU 212-24. Repeat logs if necessary. 8. Cement approximately 3270' of 13 3/8", 68#/ft.,. K-55 Buttress casing, in the shale section immediately above the uppermost productive Sterling sands, with 1950 sacks Class "G" cement premixed with 2.4% Proposal for Well Operations PRO 316-1 Drilling Program -_ Gel, by weight of water. This provides a 50% excess cement volume and should return cement to the surface. If cement does not return to surface, do a top job through a 1" pipe at 90'~. a. Cement properties as same as Step 3a. Use a float shoe and duplex collar with stab-in connector. c. Bakerlock the bottom five casing joints. d. Use centralizers at and above the casing shoe and collar, and tn the 20" casing.. 9. Cut off the 13 3/8" casing to allow top of tubing head to be above ground level upon completion. Install 13 3/8", 12" - 3000 psi top flange, SOW casing head. Test welds to 3000 psi. 10. Install 12" - 3000 psi Class III BOPE including a Shaffer Rotating Blowout Preventer per attachment and Operating Instructions D-17. Connect' blow and kill lines. Pressure test all BOPE to rated pres- sures per Operating Instructions D-17. 11. Drill out cement in 13 3/8" casing to within 10' of float shoe. Run -Variable Density Cement Bond Log from effective depth to the 20" casing shoe. Make shut-off tests as required. Pressure test-13 3/8" casing to 3000 psi. 12. Drill out cement and shoe, and drill ahead in 12 1/4" hole to 300' below the lowermost gas shows or to dull bit near 7000'. Condition mud and hole for logging. a. Consideration will be given to spot coring selective intervals . · in the Sterling and Beluga River sands. b. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. Circulate out drilling breaks or reduce penetration rate as directed by the Standard Oil Company Drilling Representative. 13. Run and tape the following logs at the effective depth using Schlum- berger men and equipment. All logs are to be run from the total depth to the shoe of the 13 3/8" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. Dual Induction - Laterolog: Same scales as Step 6a. b. Combination Compensated Neutron-Den~itY. Lo~: Same scales as in Step 6B. c. Borehole CompenSated sonic Log with Integrator: Use 50 to 150 microseconds transit time. Caliper and SP curves are to be recorded in the left hand track. SP to have +10 my scale. d. P~oximity Log - Mlcrolog with C~Pe~: use logarithmic resis- tivity scale of 0.2 to 2000 ohm-meters; micro normal 2", 0-20 ohm-meters; and micro inverse 1" x 1", 0-20 Ohlll-meter~ [~ ~ ~ ~ ~ ~ AU6 9 I974 Proposal for Well Operations PRO 316-1 Drilling Program e. Run four arm HR dipmeter and record using both analog and mag- netic tape. f. Be prepared to take sidewall samples. 14. Cement approximately 7000' of 9 5/8", 43.5#/ft., N-80 8rd LT & C and Buttress casing on bottom in two stages as follows: a. Use float shoe and float collar. Run one stage collar and place near the base of %he Sterling sand. b. Bakerlock the bottom five casing joints. ¢. Centralize the casing throughout the productive intervals. d. Cement the 9.5/8" casi.ng in two stages as follows: 1} Stage 1 through the shoe using 850 sacks Class G neat cement. Use no excess. Fill calculated from 7000' to 3800'. 2) Stage 2 through stage collar near 3800' with 500 sacks Class G cement. Fill calculated to the 13 3/8" shoe plus 1000' into the 13 3/8" x 9 5/8" casing annulus and includes 38% excess cement on the open hole portion. 15. Land the 9 5/8" casing. Install 12" - 3000 psi x 10" - 3000 psi tubing head and secondary seal assembly. Test secondary seal to 3000 psi. 16. Install 10" - 5000 psi Class III BOPE. Install kill and blow lines per attachment. Test BOPE per Operating Instructions D-17. Test lines to 5000 psi. · . 17. Drill out cement at stage collar and clean out to top of float collar. Run Variable Density Cement Bond Log from effective depth to shoe of 13 3/8" casing. Establish segregation points as required by squeeze cementing. 18. Drill out casing shoe and drill ahead in 8 1/2" hole to dull bit near 10,000'. 19. Run and tape the following logs using Schlumberger equipment. Ail logs are to be run from total depth to shoe of 9 5/8" casing. Take a 1/2 gallon sample of drilling fluid prior to pulling D.P. for logging. Use same scale as in Step 13 above. a. Dual Induction - Laterolog b. FDC Compensated Neutron with Gamma Ray c. SP - BHC Sonic Log Four Arm High Resolution Dipmeter e. Proximity Log - Microlog with Caliper f. Be prepared to take sidewall sampIes. AU6 9 1974 DI ¥1SION OF OIL AND GAS 20. Based on the formation evaluation analysis, consideration will be given to one of the following: Proposal for Well Operations PRO 316-1 Drilling Program a. Drill ahead to 12,000'~, run suit of logs, evaluate, and make further recommendation. b. Cement 7" liner at 10,000'+ [or abandon the lower portion of the hole prior to cementing the liner)and complete well for produc- tion. 21. A detailed completion program will be provided after the final log run. The proposed completion for BR 224-13 will be a triple string with the long string to produce the Tyonek, the intermediate string for the Beluga, and the short string for the Sterling. Should the lower horizons turn out to be unproductive, then'the completion program will be revised accordingly. JUL ?,,6 'i'4 RMM B. A. Dakessian/W. D. Sauer AU6 9 I974 DRILLING FLUID PROGRAM BELUGA RIVER 224-13 BELUGA RIVER FIELD Basic System Lightly treated Lignosulfonate mud. 9ptimum.. Properties To 13 3/8" Cs~. Point Value Range Weight, pcf 73-76 Viscosity, sec/qt, API 40-50 Fluid loss, cc, API 20+. Plastic Viscosity, CPS - Yield Point, lb./100 ft.2 - Gel, lb./100 ft. 2-10 min. - ph - Calcium, ppm - Solids Content, % Volume - 13 3/8" Csg. Pt. to 9 5/8" __ Cs_g. Pt. 9 5/8" Csg. Pt. to T.D. 76-80 78-82 40-45 40-45 4-6 4-6 10-15 10-15 5-10 5-10 10 max. 10 max. 8.5-9.0 8.5-9.0 50 max. 50 max. 8-10 8-10 Remarks: Chemically disperse mud with chrome lignosulfonate. Treat. calcium out as required. Maintain adequate supply of lost circulation material and barite at the location. Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit drY jobs to 10 sacks of barite or as directed by Drilling Foreman. ~~ 4, 1974 S~ Oil Co., of Califoraia P.O.BoX 7-839 A~, ~ 99510 74-60 Iwa River Unit :~IZ 14-31 O&G ~5I~-33637 J. L. Area 1. Ail .c~atizU are~ shall ~e ~t~ -and upon cc~pl~cic~ of ~ left i~ a ~tfc~ ~t. tsfa~r~ to the D~. 3. A cc~letfo~ ~rt ~! be filea wI~ 15 days of of s~y, F. J. ~~, Director Chief, cc: ADP&G, ~ District Office D-DC Form No. · ~mv. s-3o-r STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE MONTHLY RE:PORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL ~._..2 WELL~ OTHER NA/VlE OF OPI~%ATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION O'F WTM 1~00' North and 2200' East from Southwest corner of Sec. 13, T13N, R10W SB&M. AP1 NL'%~Eiq/CAL CODE 50-283-20042 6. LL~SE DESIGNATION AND SEtlIAL NO. ADL-58831 7, IF INDIAN, ALOTTEE OR TRIBE NAME 8. l/NIT, F.a~tCM OR LEASE N.~ME Not in Unit 9. WELL NO. BR 224-13 10. FIF. I.B AND POOL, OR WILDCAT Beluga River Field 11. SEC., T., R., M.. (BOTTOM HOLE OBJF, C~IV'E ) Sec. 13, T13N, R10W, SB&M 12. PE3:INiIT NO. 73-27 "~3. REPORT TOTAL DEPTH AT END OF MONTH, CI-I-A-NGES IN HOLE SIZE, CASING A_NED CEMENTING JOBS INCLUDING DEPTH SET AND VOLU2VIES USED, PERFORATIONS, TESTS AND RESULTS, nSmNG JOBS. JUNK nv HOLE AND SIDE-TRACKED HOLE AND' A_NY OTItER SIGNIFICANT CHAN~ES IN HOLE CONDITIONS. October, 1974 Drove 30" conductor pipe to 65. September~27, 1974, commenced operations. Drilled 17 1/2" hole from 65' to 435'. Opened 17 1/2" hole to 26" from 65' to 435'. Cemented 20", 94#, H-40, Buttress thread casing at 423' with 660 sacks bf Class "G" cement. Cement returns to surface. Installed Class IIB B©PE and tested to 400 psi. Drilled out cement from 417' to 423'. Drilled 17 1/2" hole from 435' to 3310'. Ran DIL, BHC sonic and Density-Neutron logs. Cemented 13 3/8", 61 and 68#, K-55, buttress thread casing at 3298' with 2010 Sacks of Class G cement. Cement returns to surface, Installed Class III BOPE and tested ~.~. Drilled out cement from 3263' 3298'. Drilled 12 1/4" hole from 3310' 'to 7000". Ran DIL, BHC sonic, neutron-Density, microlog and Dipmeter. Cemented 9 5/8", 43.5 and 47#, N-80 and P-110 LT&C and buttress thread casing at 6999' with 850 sacks Class "G" cement, C.P'd at 3828' with 500 sacks Class "G" cement. Reinstalled Class III BOPE and tested t~.~_0._0_0~?.i. Drilled out cement 6915' to 7000'. Drilled 8 5/8" hole from 7000' to 7150'. Drilled 8 ~/2" hole from 7150' to 8032'. ' Nov c i,: ¢11. AHB Ok5 ANO'IOIIAOE 14. I hereby certify SIGNED Area Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. CHEMICAL .; EOLOGEAL LABOR^TO ( _S OF ALASKA, NC. TEIEPI'K~E {9G7) 279-~O!4 gO. BOX 4-1276 2603 ARC1 lC f~LVD. A~C~O~AGE, ALASKA 99509 . . . .~ o~m~__Standard 0il CompQn~ of Calf. BAT~?L. 19., 197~ ~ l~ NO 256373 _ ... Beluga_ Rj v~r ~o~m~xo~ ...... . '" Li~ ~ co~$xo~...~t Brown_ _ Cloudy Water. . --~ ,r . ~.. ] ~ - ......... _ m, -~ .... _ .... . ~ .-r -'"" __ ~- --' '.'~ -' ' ~:~ . ..... m ...... ' ' ' --- .~ '- ~-- -~ .... -- ..... ~ - . ...... ~ 52.9_ _ 4 ~ ....... 80 ......... 1.66 ......... 34 0.87 ~ ~6Q _ ~.51 ........ ~ 0.05 ~~ TRACE --- '; ..... 4 .~_0-33 m~ . . . ,. . ~292~, 48.02 .... . ~ ....... --- ~. --r H~ ..... - ..... . --- , ..... ~ · _. ~ _ .. ~ ~ ..... ~ t~ ~ . . . .... _54.19 ........... = __8-2_ ~ .... " '. ..... :~' /t ~f i ' - ; . . , - ~ r w w ir- - . , ' Cl :50 Na "~ ..... ' Cl ,co, s c, ,co. - .tCLLrrlrcl(tlltt;tr~ , ~ ,. r, 11 [lillltl i [11 [ i i fll ii 1I t t- * ' LABORATO "A CHEMICAL & ( ~EOLOGICAL. ~SOFALASKA, iNC.. TEIEPI~O~E (9071 279-~01~ P.O. BOX 4-127& 2603 ARCIIC BtVD. ~NC~R~G~, ALASK~ 99509' . , .- . WATER ~~Y818 ~PO~T ortho__Standard Oil Company of Calif. ~~ ~ecember 10, 1974 ' ~ ~0 BR~r224-13 ~~ON ............ . . ~A~~ ...... ~~ ~om~O~ - . . . . _Dark Brown___W_ater: _-~- ...... .~ mbeve .. Fe ...... ' WAT~ JL~J~[,,Y$Ig PATT -~It,.H~ Cl 50 Na HCO~ 5 C~ SO, 5 Mg CO, 5 Fe C1 HCO~ $O.~ COs "A CHEMICAL & ~EOLOGJCAL LABORATO $OFALASKA, iNC.. TEtEPHONE (907)279-4014 EO. BOX 4-1276 2603 ARCTIC bLYP. ANCNORAGE, ALASKA 99509. WATER ANALYSIS ~ & ¢o~c~,u~xO~-~ Mud~ Low W,ater_L_oss:_._Quebrocho Filtrate. i _ -- _ _. .... ~ - ----~ i , ' , i ,,_ ~a~ ....... 1400 60.92 1~ ..... 17 ~.44 ~ ..... 3, __=__0.25 ~ ~15 ~ ~ ~ ~ ii~ _- _ -- ii i ___61 76 - iiii 4045 _ _ .... --- ,, O.1 Cl 50 Na HCO, 5 c~ $0, 5 Mg CO:~ 5 Fe CI HCO.~ CO. TELEFHONE (907) 279 LABORAT "': ES OF ALASKA, IN[L Core,ny Standary Oil Company of California Fielcl- == _ Beluqa River State . A1 aska Line pressur~psig~ ,Sample preSsure_-____psig; Temperature = o ;F; Container numl~er. -. 'ANCHORAGE, ALASKA 99509 ., . . · ~ : ;. · . . .. GAS ANALYSIS REPOP~T ': - Date Decem_ber .12,.._~1974__ _- : _L,b. 14o.___2563-4 Location , . _ Sempl~ng point_. Oxygen. Nitrogen : Certx~ dioxide .... . .... .. . .; - . ~:: ..... f,. ,.,,:~, ,.': . 0.57 TP, ACE E~a,'~ & Higher GPM of pentenes & higher fraction - . 'Gross b~,u,'cu, ft.' @60° F, & 14.7 psia (dry basis). ,Specific gravity (calculated from analysis) .......... $pecific gravity (measured) ................... 1004 0.556 0.55"5 I~r MCF · . Remarks=. , ,.' , L t:ULUUIL, AL LI ,UUt'JAIUI'-JIES OF LASKA IN[,.. ~-~.:,,,~ , .... , .'-' ....-.:, '. ;-'." ANCHORAGE, ALASKA · . "- ': · ' "" ' ' .":.".,i..:.':-'..i'i':' "...-':'.. ': · · . . ... ~ :;.; .; ..... ',',[.. ,. ...... .' . . · .-.' . . .. :..- ~ :.;' . . < ..- . .... .' :. .. . . .... .- ...: . . .-.. · .. .. ~: :.... :....~... . .,..~.. ? ~. .. -. . . · . .... -.. .. .,.. . · ..~ · .. . . ....... . .. ,... .- .- . .- ..-' . · ... .. '. o .°.:... ', y' . ' ,..-..- . ' ': :'o .:- ' . -~ ·. 8: ' ' " "'-".. .~ -: ' :"OAS ANA£¥$1$ REt:'ORT .:'.-.-· ·' o · ~,~t $t*nd'ary--0ii Company of Cal.~forn..ia' . Date: _Dececber 17_, 1974 ........ _:_!.~b. No.'_2~_63-4 ~"'"~""--DST.,_ _ # -8 ~24-'13 ' - - rotation ...... - -- - ....... . ~i'~tl ,~.----~-_ . ' .-.- F~....~oi uqa K~ vet .... ~_,~.F°rm°ti°n ...... _ .... . ..... __ .. _ .... ... ....... · .,em,- - -_ -- .~'""'-A~I aska ........... . ~ampllng point_ ' ~ pre,ute - psig; Sample pre~sure_____psig; Temperature . _- o F; Container number_ · . .._. , , ,i i ii i .... ' - ' - - -- '" ~ i i i 1_ _ - _- ...... _ - _ ....._--._.-~ --., I I · · -- :" -- -- II , -,- - _ ~.--'_ -. · - . · . . · i ~ , ,, · - i ., - _- __ .. '. -. . . - ;.... '~:".. .... . . :- - . ..... ' . . ~ . ~· ...;-...;.,,-:.~:., . :..~. ' ..... ":' "':":"" ~":·""' ~-'~ ': ..... < '". '. ~:':.-"'-".-, ' ... :-,". ';"'-..',,':' :.'..'. '~'"':'.:L. '- ~ '' ..~ .:-~':~/ ." ,....T"-"- '..'-."~:'~ ..' . ~....:' ? ·'-° '-';':'Y , i ,~ :: - :'". · :- -: ': ' ' ' ~:~.i': ~.-~..'.:"/:; i:. ::-' :~...;... '" ...... .:...;.:::;~: ..:."F.':,':~ ...... : ............ . . :- ::. ...... . .... -..' .-........ -- ~.. : - .... ~.'-.': -. Oxygen. Nitrogen :':. -- · Carbon dioxide..... ' . - Hydrogen sulfide... Methane Ethane & Higher · GPM of pentanes & higher fraction .- ........... - _ . · - 'Gross btu/cu, ft. @60° F. & 14.7 psia (dry basis). Specific grevity (calculated from enalysls) ......... Specific gravely (measured).. Remarks: ....... ., . . 1004 ,~, 0.556 0.555 October 31, 1973 Re: Beluga River BRU 223-13 Standard Ol I Co. of Cai ! f., Operator Permit No. 73-37 Mr. J. ~. &tker Standard· 0II Company of California P. O. Box 7-839 Anchorage, A t aska 99510 Dear Str: Enclosed Is the ppproved appl lcaflon for permit to drill the above referenced wel I at a location In Sectlon 13,..Township 13N,. Range ~/ell samples, core chips, a .mud: log and a directional survey .~l~.not required. t~any ~lvers tn Alaska and thel.r drainage systems have been classified as Important for the ;spawning or mlgratlon of anadromous fish. Operations In these areas are subject to AS 16.05.870 and the regulations promulgated there- under (Tttte 5, Alaska Administrative Code). Prior to coamenctng operations· you may be contacted by the Habl'ta't ~rdlnator's offlce~. Department of Fish and Game. Pollution of any waters of the State ts prohibited by AS 46, Chapter 03, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal l~ater Poi lutton Control' Act, as amended. PrlOr to comaenclng operations you may be contacted by a representative of the Department of Environmental Conservation. In the. event of suspension or abandonment please give 'this office adequate advance notiflcation so that we may have a. witness present. Very tru I y Thomas R. Harsha I I, J r. Executi ye Secretary Alaska 01t and Gas Conservatlon Committee TR~;pJ Enc I osure cc: Department of Flsh and Game, Hab. ltat 'Section w/o enct. Department of Environmental ~onservation w/o encl. DRILLING FLUID PROGRAM _BELUGA RIVER UNIT 223-13 BELUGA RIVER FIELD Basic System Lightly treated Lignosulfonate mud. Optimum Properties -Weight, pcf Viscosity, sec/qt, API Fluid loss, cc, API Plastic Viscosity, CPS Yield Point, lbo/100 ft.2 Gel, lb./100 ft.2 -10 min. ph Calcium, ppm Solids. Content, % volume Diesel Content, % volume Value Range To 13 3/8" ~sg. Point 13 3/8" Csg. Pt. to T.D. 73-76 76-80 40-50 40-45 20+ 4-6 - 10-15 - 5-10 - 10 max. - 8.5-9.0 - 50 max. - 8-10 - 6-8 Remarks: Chemically disperse mud with chrome lignosulfonate. 'T~eat calcium out as required. Maintain adequate supply of lost circulation material and barite at the location. Run desander and desilter to keep solids at a minimum while drilling. Increase viscosity while drilling surface hole as required to control gravel. Limit dry jobs to 10 sacks of barite or as directed by Drilling Foreman. // PROPOSAL FOR WELL OPERATIONS PRO 316-1 · DRILLING PROGRAM Field: Beluga River Property and Well No: Beluga River Unit 223-13 Location: Approximately 2200' North and 3000' East of the Southwest Corner of Section 13, T-13N, R-10W, SB & M. Elevation: Estimated 80' Ground and 100' K.B. Blowout Prevention Considerations 1. Potential Problems: a. Gas: D!,i~.$.,iGI~ GF O~t. t..t4D G ANcHORAG~ The proposed well is a development location on the northerly plunge of a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries into the mud column can cause serious problems. Care must be taken at all times to prevent these entries by either swabbing the well when pulling pipe or hydraulicing the formation, with associated lost circulation, on trips. Rapid penetration rates cause an increase in mud weight and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. b. Lost Circulation and Water Entries: In recently completed well BRU 212-24 circulation was lost using 70 pcf- mud while the drill pipe was stuck at 927'. From this depth to 3777' some loss in mud was noted. Mud weights varied from 70-75 pcf. No serious losses were recorded but extreme care must be used in maintain- ing solids free mud with the properties outlined in the Drilling Fluids Program. Penetration rates will be limited to maintaining optimum dril- ling fluid properties. c.- Precautions: Kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. 2. Estimated Depths ~nd Formation Pressures: Zone or Marker Drilled Subsea Est. Press Gradient Depth Depth Psi psi/F~. Top of Sterling "A" Gas Interval Top Beluga River Formation Total Depth 3400' -3300' 1485 .45 3880' -3780' 1815 .48 7000' -6900' 3430 .49 Proposal for Well Operations PRO 316-1 Drilling Program -2- 3. Maximum Anticipated Surface'Pressure: 3000 psi 4. Blowout Prevention Equipment: a. 20" - 2000 psi, Class IIB on 20" casing. b. 12" - 3000 psi, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8". 5. Objectives: Sterling and Beluga River Formations program 1. Drive 30" conductor pipe 60' to 80' below cellar floor. 2. Drill for 20" casing to 400'±. Maintain drilling fluids per attached Drilling Fluid Program. 3. Cement 20", 94#/ft., H-40 Buttress casing at 400' with 485 sacks of Class "G" cement premixed with 2.4% Gel, by weight of water. This provides a 50% excess cement volume. If cement does not return to the surface, do a top job through a 1" pipe at 90'±. a. CementTGel Properties: Yield: 1.86 cu. ft. slurry per sack cement Slurry Weight: 97-98 pcf Water Required: 1.38 cu. ft. per sack cement Gel Required: 1.5# per cu. ft. water b. Use a duplex shoe with stab-in connector. c. Bakerlock or weld casing to shoe. d. Centralize casing over the entire 400'. 4. Install Class IIB BOPE on the 20" casing per attachment. Nipple up blow and kill lines, and manifold for 3000 psi service. Class III, 12" - 3000 psi BOPE with Shaffer Rotating-Blowout Preventer will be installed later. Test BOPE per Operating Instructions D-17. Note: Burst pressure for 20", 94#/ft., H~40 casing is 1530 psi with no safety factor. Do not exceed a 400 psi test. 5. Drill out cement and shoe of 20" casing. Drill ahead in 17 1/2" hole to a dull bit near 3300'. Condition mud and hole for logging. Not~: a. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. b. Install Mud Logging Unit at the shoe of the 20" casing and retain to total depth. Specific instructions will be provided to the Mudl0ggers under separate cover. Proposal for Well Operations PRO 316-1 Drilling Program -3- 6. Run and tape the following logs using SchlUmberger men and equipment. All logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. Dual Induction - Laterolog: 2" = 100' - Arithmetic, 0-50 ohm-meters resistivity and ± 10 mv SP scale. 5" = 100' - Logarithmic, 0.2-2000 ohm-meters resistivity and ±10 mv SP scale. b. Combination Compensated Neutron-Density Log: Density scale 2.0 to 3.0 grams/cc. Neutron scale 0 to +60 sandstone porosity units. Gamma-ray and caliper curves to be recorded in the left hand track. c. BorehQle ~ompensated Sonic Log with Integrator: · Use 100 to 200 microseconds transit time. d. Have on location a Proximity Log, Dipmeter tool and sidewall sample gun. 7. Drill ahead in 17 1/2" hole to top of the gas productive Sterling sands, depth equivalent to 3278' in well BRU 212-24. Repeat logs if necessary. 8. Cement approximately 3270' of 13 3/8", 68#/ft., K-55 Buttress casing, in the shale section immediately above the uppermost productive Sterling sands, with 1950 sacks Class"G"cement premixed with 2.4% Gel, by weight of water. This provides a 50% excess cement volume and should return cement to the surface. If cement does not return to surface, do a top job through a 1" pipe at 90'±. a. Cement properties as same as Step 3a. b. Use a float shoe and duplex collar with stab-in connector. c. Bakerlock the bottom 5 casing joints. d. Use centralizers at and above the casing shoe and collar, and in the 20" casing. 9. Cut off the 13 3/8" casing to allow top of tubing head to be above ground level upon completion. Install 13 3/8",'12"-3000 psi top flange, SOW casing head. Test welds to 3000 psi. 10. Install 12"-3000 psi Class III BOPE including a Shaffer Rotating Blowout Preventer per attachment and Operating Instructions D-17. Connect blow and kill lines. Pressure test all BOPE to rated pressures per Operating Instructions D-17. 11. Drill out cement in 13 3/8" casing to within 10' of float shoe. Run Variable Density Cement Bond .Log from effective depth to the 20" casing shoe. Make shut-off tests as required. Pressure test 13 3/8" casing to 3000 psi. Proposal for Well Operations PRO 316-1 Drilling Program -4- 12. Drill out cement and shoe, and drill ahead in 12 1/4" hole to 300' below the lowermost gas shows or to dull bit near 7000'. Condition mud and hole for logging. a. Consideration will be given to spot coring selective intervals in the Sterling and Beluga River sands. b. Limit penetration rates as necessary to maintain optimum drilling fluid weight and solids content. Circulateout drilling breaks or reduce penetration rate as directed by the Standard Oil Company Drilling Representative. 13. Run and tape the following logs at the effective depth using Schlumberger men and equipment. All logs are to be run from the total depth to the shoe of the 13 3/8" casing. Take a 1/2 gallon sample of drilling fluid immediately prior to pulling drill pipe for logging. a. .Dual Induction - Laterolog: Same scales as Step 6a. b. Combination Compensated Neutron-Density ~0g: Same scales as in Step 6b. c. Borehole Compensated Sonic Log with Integrator: Use 50 to 150 micro- seconds transit time. Caliper and SP curves are to be recorded in the left hand track. SP to have ±10 mv scale. d. Proximity Log - Microlog with Caliper: Use logarithmic resistivity scale of 0.2 to 2000 ohm-meters; micro normal 2", 0-20 ohm-meters; and micro inverse 1" x 1" 0-20 ohm-meters e. Run four arm HR dipmeter and record using both analog and magnetic tape. f. Be prepared to take sidewall samples. 14. Cement approximately 7000' of 9 5/8", 43.5#/ft., N-80 8rd LT & C and Buttress casing on bottom in two stages as follows: a. Use float shoe and float collar. Run one stage collar and place near the base of the Sterling sand. b.' Bakerlock the bottom 5 casing joints. c. Centralize the casing, throughout the productive intervals. d. Cement the 9 5/8" casing in two stages as follows: 1) Stage 1 through the shoe using 850 sacks Class G neat cement. Use no excess. Fill calculated from 7000' to ~8~0~,. 2) Stage 2 through stage collar near 3800' with 500 sacks Class G cement. Fill calculated t° the 13 3/8" shoe plus 1000' into the 13 3/8" x 9 5/8" casing annulus and includes 38% excess cement on the open hole portion. 15. Land the 9 5/8" casing. Install 12"-3000 psi x 10"-3000 psi tubing head and secondary seal assembly. Test secondary seal to 3000 psi. 16. Install 10"-3000 psi Class III BOPE. Install kill and blow lines per attach- .ment. Test BOPE per Operating Instructions D-17. Test lines to 3000 psi. 17. Drill out cement at stage collar and clean out to top of float collar. Run Variable Density Cement Bond Log from effective depth to shoe of 13 3/8" casing. Establish segregation points as required by squeeze cementing. '18. Test, perforating, and completion program will be provided after the total depth logs have been run. Note: A triple completion is planned. : PI<OI--'U..hAL WL:LL ,Ul'kRAliUNb FI( -316-A ( iO biz U tzD Ab A u,-'111) // . , . CASING R (" JiREMENTS AND PRODUCIN(n E UIPMENT /WELL/LOCATION NO BRU 223-13 FIELD Beluga River ~' DATF 10/15/73.-- FORWARD BUYING NO . ESTIMATED SPUD DATF TOTAL DEPTH 7o00' ~METHOD OF PRODUCTIONFl°wing MAX. ESTIMATED SURF. PRESSURF 3000 PSt ESTIMATED G ~30,00~0MCF EQUIP. FOR STEAM No CASING Gross Footage APl Size Weight Grade Conductor 400 ' 20" ' 94 ~ ,Requires: Duplex Shoe (stab-in). 10ea. SurFace ce ntral i zer s. 3400' 13 3/8" 68~ K-55 INJ No . . PRODUCER__Yes Threads Coupling Computer Desk_.', For: Buttress - This Well i-1 20" x 26" Standard Design For Field [] Well No. · I-1 Buttress Max. Dr;ffAngJe . o equires: Water String: Float Shoe, Duplex Collar (stab-in). 20ea. 13 3/8" Designbasedonmuddensity 76 Ibs./cu. ft. andabove max. surf. pressure Bottom 5300' 9 5/8" 43.5~ NL80 8rd LT&C 1 - 9 5/8" N-80 Cros Top 1700' 9 5/8" 43.5~ N-80 Buttress over 8rd - LT&C x Total 7000' Buttress CemenfingAccessories Float Shoe, Float Collar and Stage Collar. 25each., 9 5/8" x 12 1/4" Centralizers. Note: All above floating equipment to be 8rd liner None LT&C. Hanger No n e perforated- None ,, CASING 't. 30 o o UNITIZED)~ HEAD: Top Conn. IZ;.I-+; n,.,~ 1 to, ', ~.Mosh, Rows, .Slots, Centers, ~ MC MUC PS! CWP. Bottom Conn 13 3/8" SOW 12" - 3000 PSI 2 2 - 3000 PSI Valve w/blind flange. 1 - Flanged fla'nge w/bull plug outlets TUBING HEAD 3 ooo PS! CWP. Bottom Corm .TopConn..lO" - 3000 PSI 9 5/'8" secondary Type Suspension TUBING Bottom Next Packers, Total Feet APl Size Weight Grade 10,600 2 7/8" 6.55 N-80 3400' 2 3/8" 4.7# N-80 2000' 2 1/16" 3.4# N-80 safety joints, adjustable union, · Tubing Catcher Packer " type. Csg. Size " "x " .Type with,,. 12" - 3000 PSI 2 2 ,, flanged out!ets _ , , , pack-off, 2-2" 7/~-" & 1 - 2 3/8" & 1 - 2 1/16"" tb~ :st~-i-5 Th reads Type Remarks (Cro[s'-overs, etc.) 8rd EUE 8rd EUE w/beveled collars 10rd Inte . 1.~ , [~ ,~ ~-t~' nipples, & sle~s¢:~.. ~t~c~~ "stroke af ,, >Jr".4Ft~ :~I: ' with ~ wt. Other Fittings. .XMAS TREF Quad ,, tree to be designed.-.- _ Dwg. No. To be designed. Tubing Beans " .Type . " Casing Beans " .Type " Header " Arm PSI CWP. Dwg. No.. S~u~ng Box " ~Type. Polished Rod_ "x PU~P: "x ' Type af RODS: Grede. ' of "' ' of "- ' of PU~P[NG UNIT. APl Size . . Type _~ex. Stroke "Set at. "Stroke end_ Engine ~ofor~ . . HP. Remarks Prepared B/~./~) W. ~/~,~,//~ ~ u e r __ Type _TYpe ' Long !! SPM Drlg. Supervisor,. PR0-$16- A (2~'I-9.06) BRU 223-13 2 7/8" EUE TBG 8 Otis XA Sleeves 1 Otis S Nipple (Pos 1) 1 Otis S Nipple (Pos 2) 1 Otis S Nipple (Pos 3) 1 Otis S Nipple (Pos 4) 3 Camco MMA 2 Camco D Nipple 1 Venturi Shoe 1 Brown CC Safety Jt 6 Brown St. Pull Safety Jt 2 Brown Adj. Union 1 Brown 9 5/8" Triple H~dr. Pkr I Brown 9 5/8" Dual Hydri. Pkr 3 Brown 9 5/8" Single Hydr. Pkr 2, 3/8" EUE TBG 1 Otis XA Sleeve 1 Camco D Nipple 1 Venturi Shoe 1 Brown Adj. Union 16 t5 28 33¢ 24 ! m'm · m~ Im mm. emi I I I · I T. I:> N.~E IOW. ! m -{'" ~4 -~ IIl ~.1.. ?~ ..... ..... .. . I Im I m mm l~ ' '~ PIT ............ ? ....... ;.__ ................. u , ~,. i /.:' , I ELEC lm 27 ' ,' 26 IA$$OC.u ,,,m " il ~ .... ii · ii " '[~ I / / / / / // / __...1 _... ; BELUGA ~ i Iii RIVER UNIT -,- OCT ~ g i~/3 Dl~,..lvh (..F Cll. AND G'A.5 AIx',CHORAGE BELUGA RIVER AREA STANDARD OIL COMPANY OF CALIFORNIA ~CALE OATE IO II .7:~ ENGR W. W: DNi ~HOtLV~I3dO 0_-t1-1~7:D _-10 AN~dNOD -1t0 (]H~C]NViCj ~I3AIB Vglg"I3B :qq3~ OB · l. ! ~o,irI ~ o.I. dOB t:I3=IJYHS H .LI/~ dOB TTT 88~93 "'~£ I ~0~. I, . ~ (INSgB ! ! J dOB ! I~1-1 ! t i I ! t !~i I I I~ r- ¢ I0'-- 401 , I-I--71 SUBMIT IN TRI (Other mstructior~ reverse side) STATE OF ALASKA OIL AND GAS CONSERVATIO'N COMMITTEE PERMIT TO DRILL OR DEEPEN lf[.TTPI~ OJ~ WORK DRILL [] DEEPEN [-'] ~}. TYPI[ O~' W~LL OIL [~] GA8 [] 8INGL, [~ Mt'i.TIPI,~ ~] W~LL WmLL OTH~K ZONI: ZONE 2. NAME OF OPERATOR Standard Oil Company of California, WOI 3. ADDRESS O~ OPERATOR P. O. Box 7-839 Anchorage, Alaska 99510 APl //50-283-20042 ADL 58831 IF INDIAN. ALLO'i-'Fa;~ OR TRLIBE NA2~E '8. UNIT, FARM OR LEASE NAdX4E Beluga River g. WELL NO. BRU 223-13 I0. FIELD AND POOL. OR WILDCAT Beluga River Field 4. LOCATION OF WELL Approximately 2200' North and 3000' East At surfage of the SW corner Section 13, T-13N, R-10W, SB&M U. SEC.,T..R..M.,~BO'rro:~ At proposed prod. zone Approximately 2200 ' North and 3000 ' East HOLE OBS~.CTIVE~ of the SW corner Section 13, T-13N, R-10W, SB&M 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* :~' 12. Approximately 40 miles West of Anchorage, AlaSka 14 ~IU~.' -- ---- .......... ' . . . . ~ Statewide ~451~36 ~v~a~l°nwxa~.~ewa.d/o~o. SL 620586~ ~ ~o~, $150,000 15. DISTANCE FROM PROPOSED' 2200' to Nort~ ]IG. NO. OF AC~ IN LEASE ~ -17. NO. ACR~SASSIGNED LOCATION TO NEAREST * TO ~iS WELL ~N ~ lzne of Beluga [ ~ % , (~s%~%~r~s~r~g~Su%itI, i~ny)' River .On, t 1 [ 1,2802 __~ , 640 18. DISTANCE FROM PROPOSED LOCA~ON* [ [19. PROPOS~ D~ '~ 20. ROTARY ~R CABLE TOOLS TO NEAREST WELL DRILLING CO~LET~, OR APPLIED FOR, ~. ~ ] '[ ~ [ ~ ' 5500'~k ~ i 7000'~ ~ Ro~ary . 21. ELEVATIONS ,Show whethcr DF. RT, CH, ~., ~ ~ x = APPROX DATE WOHK WILL START' ~o'~ ~. ~ / ~ ~_ ~ ' ' ~3' ' ' ~OPOSED CASt~ ANE g~N~G PROGR~ s~z~o~ ~o=z[SlZ~ OFC*S~OlWE~HTP~")~ [,, G" ~E S~ING D~ quant 'y of cement 2e" I 20" l' 9'4~ ~ I H, f40'H 400' . ,, '. ,z2 z ~ 43.s~ teo 70~0' t, zse6 ~ cu. F~. (~o s~age~'~ I Sec. 13,T-13N,R-10W,SB&B We propose to drill subject well per attached drilling program. Please treat this well as Confidential. ~E ~ E ~ ~ E li'!l ~<;,,- o ,--~/,, ,. ,- ,,,' / 2.s-~,- ,-,,~-,,~--:FJ'~.~. cro~..) ~~1~ '~ OCT -o ,--.., ~ /...,-'..,' .... AZ- ,/ ./ ) ,,y-'?t ~7~' ~.,-~ro ~ ABO~PA~ D~B~ ~O~O~ PR~R~: If ~I is to dee~n 'give ~ on present p~u~ve zo~ ~d pro~ ~w preclusive ~he. 3f_~l ~s ~ drlll or ~n ~ec%ionally, glve p~rtm~nt ~' on s~Dsu~a~ ~t~ ~d .meas.~d ~d ~ue w~ieal dept. Give ble~ ~e~e~ter' p~gram. ' - z4. ~ hereby cl~y mat the ~o~ Is ~e .n~ S!GND ' ~ ...-...---.. DA~ ~ Area Supervisor . _ wa~.~a - (This space ~S~te office u~) CONDI~ONS OF ~P~V~, IF A~: SAMPLES AND CORE CHIPS [] YES ]~ NO DIRECTIONAL SURVEY [] YES ~NO MU,D LO'G [] YES '~ NO SEE TRANSMITTAL LETTER A,P.I, NTrNL~I~ICAL CODI: ~o- Z$$- zood z. Executive Secretary October 31, *Se~ Instruction, On Reverse Side 1973
