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Home My WebLink About194-1121. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: 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 9,740 feet 300, 2,477 feet true vertical 9,649 feet NA feet Effective Depth measured 144 feet NA feet true vertical 144 feet NA feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) None Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: None TVD NA 2,470psi5,210psi Slotted Liner 30"130' 2,743' Casing 10-3/4" ENDICOTT / ENDICOTT OIL Conductor 2,743'Surface Burst NA Collapse Intermediate Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 DUCK IS UNIT MPI 1-53 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-112 50-029-22501-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 000 0 00 0 0 N/A measured true vertical Packer MD 130' Size 130' 2,722' Length Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 NA PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:40 am, Jul 08, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.07.07 14:41:50 -08'00' Justus Hinks (3691) RBDMS JSB 071025 JJL 7/21/25 DSR-7/21/25 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email:steve.soroka@hilcorp.com If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA N/A OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified by Pad map and sign. WBS Pictures Area map Yes Yes Onshore 05/27/25 Subsequent No Well House. Tree is weathered, all valves function smoothly. No IA on Wellhead. No leaks. Casing valve open to gauge. The gravel and grating area are clean. The cellar has clean gravel. The front of the well head has dunage and delineators. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Kam St. John 06/08/25 Yes Steve SorokaDUCK IS UNIT MPI 1-53 907-830-8976 Follow Up Actions Needed: Hilcorp Alaska, LLC 194-112 Condition of Surrounding Surface Location: 09/30/94 321-004 REVIEWED BY: Other (specify in comments) PLB 12/2014 END MPI 1-53 Suspended Well Inspection Form 2025 Photo 1. Front of END 1-53 well Photo 2. END 1-53 well sign close up. Photo 3. Front left of well END 1-53. Photo 4. Front right of well END 1-53. Photo 5. Back of well END 1-53. Photo 6. Back right of well END 1-53. Photo 7. Back left of well END 1-53. Photo 8. Back view of well cellar END 1-53. Photo 9. View of cellar left of well END 1-53. Photo 10. View of cellar right of well END 1-53. Photo 11. Tubing gauge of well END 1-53. Photo 12. OA gauge of well END 1-53. Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 InspectNo:susKPS250608122215 Well Pressures (psi): Date Inspected:6/8/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:11/14/1994 Tubing:0 IA: OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:5/27/2025 Type of Inspection:Subsequent Well Name:DUCK IS UNIT MPI 1-53 Permit Number:1941120 Wellhead Condition No wellhouse. Area around well was clean and no debris. All lines capped with new gauges. No IA Surrounding Surface Condition Area was clean Condition of Cellar Celler was dry with no visable sheen Comments Supervisor Comments Photos (1) Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, July 25, 2025         2025-0608_Suspend_DIU_MPI_1-53_photo_ksj Page 1 of 1 Suspended Well Inspection – Duck Island Unit (Endicott) MPI 1-53 PTD 1941120 AOGCC Inspection Rpt # susKPS250608122215 Photos by AOGCC Inspector K. 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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: inspect well Hilcorp Alaska 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 9,740 feet 300 feet true vertical 9,648 feet N/A feet Effective Depth measured 300 feet N/A feet true vertical 300 feet N/A feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,470psi N/A Burst N/A 5,210psi 30" 10-3/4" 2,722' Liner Length 130' 2,743'Surface Intermediate N/A measured Production Production Casing Conductor Size DUCK IS UNIT MPI 1-53 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 194-1120 50-029-22501-00-00 Plugs ADL0312828 5. Permit to Drill Number: ENDICOTT / ENDICOTT OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Oil-Bbl measured true vertical Packer WDSP2 WAG Water-Bbl MD 130' 2,743' TVD 130' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:44 pm, Jul 17, 2020 Chad A Helgeson 2020.07.17 15:15:10 -08'00' ADL 034633 194-112 RBDMS HEW 7/20/2020 SFD 7/20/2020 SFD 7/20/2020 SFD 7/20/2020DSR-7/20/2020MGR21JUL2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Suspension Date: Sundry No.: Well Pressures (psi): Tubing 0 IA N/A OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm Follow Up Actions Needed: Hilcorp Alaska, LLC Photos Taken? 194-112 Condition of Surrounding Surface Location: 09/30/94 94-273 REVIEWED BY: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date AOGCC Notified: Bob Noble 06/14/20 Yes Other (specify in comments) WilfHylandMPI 1-53 1- Wellbore Schematic Wellbore Diagram Avail.? 1 - Photo of wellhead 1 - Pad Map Yes Weathered, valves operate good. No IA on wellhead. No signs of leaks. All lines blinded and open to gauge. Yes Gravel and floor grating are clean. Cellar has some clean snowmelt . Well protected with dunage in front and well houses on each side . Offshore None Map on location 659-6530 whyland@hilcorp.com 06/13/20 SubsequentType of Inspection: PLB 12/2014 Suspended Well Inspection 06-14-2020 MPI 1-53 ENDEAVOR ISLAND ENDICOTT MAIN PRODUCTION ISLAND (MPI) MPI 1-53 MPI 1-59 U012N016E Sec. 36 DUCK ISLAND UNIT 147°57'0"W147°57'30"W147°58'0"W 70°21'15"N70°21'15"N70°21'0"N70°21'0"NMap Date: 9/8/2015 Duck Island Unit Endicott MPI Well Rows Facility Map - Figure 1 0 500 1,000 Feet 0 100 200 Meters Alaska StatePlane Zone 3 NAD 1983 (Feet) Legend Well Rows Existing Pipeline (Above Ground) Oil and Gas Unit Boundary Suspended Well Inspection Review Report InspectNo: susRCN200614160018 Date Inspected: 6/14/2020 Inspector: Bob Noble Well Name: DUCK IS UNIT MPI 1-53 Permit Number: 1941120 - Suspension Approval: Completion Report Suspension Date: 11/14/1994 Location Verified? r❑ If Verified, How? Other (specify in comments) Offshore?❑ Type of Inspection: Subsequent I Date AOGCC Notified: 6/13/2020 Operator: Hilcorp Alaska, LLC Operator Rep: Wilf Hyland Wellbore Diagram Avail?❑ Photos Taken? ❑D Well Pressures (psi): Tubing: 0 Fluid in Cellar?❑ ' IA: BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition No wellhouse. Wellhead is weathered but operated good. Wellhead protected with other wellhouses on the sides and dunnage in front. All lines were capped with good gauges. No IA Condition of Cellar Small amout of melt water in lined cellar. Surrounding Surface Condition Good clean gravel ✓ Comments Location was verified with a pad map. Supervisor Comments Photos (1) ZgIZ- 61Iq(2"'2v Friday, June 19, 2020 Suspended — DIU 1-53 (PTD 1941120) AOGCC Inspection #susRCN200614160018 Photos by AOGCC Inspector B. Noble 6/14/2020 2020-0614_Suspend_DIU_1-53_photos_bn.docx Page 1 of 1 STATE OF • R ED ALA OIL AND GAS CONSERVATION COM.SION ECr REPORT OF SUNDRY WELL OPERATIONS SEP 0 8 2015 1.Operations Abandon U Plug Perforations LJ Fracture Stimulate U Pull Tubing U A G'Cown U Performed: Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Inspect Well ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Developments Exploratory ❑ 194-112 3.Address: Stratigraphic❑ Service ❑ 6.API Number.: i. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22501-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 ' DUCK IS UNIT MPI 1-53/Q20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ ENDICOTT OIL 11.Present Well Condition Summary: Total Depth measured ' 9,740 feet Plugs measured 300 feet true vertical . 9,648 feet Junk measured N/A feet Effective Depth measured 300 feet Packer measured N/A feet true vertical 300 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 130' 30" 130' 130' "' Surface 2,743' 10-3/4" 2,743' 2,722' 5,210psi 2,470psi Intermediate Production Liner Perforation depth Measured depth See Attached Schematic feet � � "Yk� True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2Exploratory❑ Developments 4 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ • SUSP s SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Taylor Wellman Email twellman(a�hilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature Phone • 777-8449 Date 9/8/2015 VTC 9/i1 /S Form 10-404 Revised 5/2015 y RBDMt'� Qpi�y Submit Original Only ,j 7y0,rt1 IN rJ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/21/15 Inspector: Lou Grimaldi Operator: Hilcorp Alaska,LLC Well Name: MPI 1-53 Oper.Rep: Larry Mc Bride PTD No.: 194-112 Oper.Phone: 659-6530 Location Verified? Yes Oper.Email: Imcbride@hilcoro.com If Verified,How? Other(specify in comments) Onshore/Offshore: Offshore Suspension Date: 09/30/94 Date AOGCC Notified: 08/17/15 Sundry No.: 94-273 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA N/A OA 0 Condition of Wellhead: Weathered,valves operate good.No IA on wellhead. Condition of Surrounding Surface Location: Gravel and floor grating are clean. Follow Up Actions Needed: None Comments: Map on location Attachments: 1-Photo of wellhead REVIEWED BY: 1-Pad Map Insp.Supry 1-Wellbore Schematic Comm PLB 12/2014 Suspended Well Inspection Form MPI 1-53 TREE= _WELLHEAD • SAF NOTES:H25 READINGS AVERAGE 230 - ACTUATOR= ....._____ 260 PPM ON A/L& GAS INJECTORS. KB.ELEV= BF.ELEV= T EN I:)1 5 3 MaX Angle= i Strc.{,a, Datum MD= Datum 1VD= SUSPENDED 30"CONDUCTOR H 130' l *1' 1 1N!1�1` 144' -300' —110-314"CEMENT PLUG#6 1111111111111111 11Ii11NN11111*11 300' H10-3/4"CIBP 111111111111111 2383' -2477' 10-3/4"CEMENT PLUG#5 s111111l1111111111111111111*11i 2477' —10-3/4"EZSV 0� ♦1` IMii•�O 2477' -2737' H10-3/4"CEMENT PLUG#5 1111111111111111111111111111111 111111111111111111111 • 1111111111 1111111111!1111 1�1�1�1�1�1�1111111111l11111111 TOP OF DRILL PIPE 2526' %• * *I S r4 *. 1111 !1SS111111111 11 10-3/4"CSG,45.5#,NT-80, ID=9.950" H 2743' tii " 2743` -2972' —�10-3/4'"CEMENT PLUG#4 /1111111111+11111 2972' --SEVERED DP 111111111 **Oft5365' -6601' H10-3/4"CEMENT PLUG#3 111 11/14 1111 11 11111111111 PERFORATION SUMMARY 111111111/1•/111111111111111 REF LOG 111•••••• 1N1 6601' -SEVERED DP ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2515-2517 S ��►s• ♦��s 8042' -8541' H10-3/4"CEMENT PLUG#2 11•�11111111�►11111'111111111�1� 11111.1/111111 •••••••• •4 1111/1/�111i11+1111 111111111 111111 8541' H SEV ERED DP 9615' -9740' 10-3/4"CEMENT PLUG#1 00001 11111 1111111111►11�11e111111111/1 1111111111i*►11111S1111111111! TD— 9740' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 11/14/94 SUSPENDED WELL: 1-53/0-20 05/04/11 MB/JMD CONVERT TO CANVAS PERMIT Nb:'1941120 08/12/11 DW/JMD ADDED H2S SAFETY NOTE Aft Nb: 50-029-22501-00 SEC 36,T12N,R16E,2172'FNL&2185'FEL v r g i,,, ,. i, ;7 ,44,;,,,,:1.7 - f- .,, ., .�. - -; -.: lit . ::.l.,,,f - '''''': ' ,,..4 x � fir . a 1c ' r • fix` « i ie,dn+ " a nWp tx tf kr .. ...arn• .�,-...:.a.., .www , t 1, ' , 4, .- -, - .,,, - ',,,,lik 'id- tr. r 1 g_.4114001,t, .,,or ['.,••1`,,:i,,,,‘ +fir rza t , . ,, „!. ; Ftp si.T.i.' ,: 5.. `-s '' ? , •` ., •, it !t3 y �'{fg'} I e ?''in ry2q p ' I 5' $ :'�C• N X(J1 3` �f •E�� "� 1 I :yam _;,,,pl. ii.;a444 ,:.1 ; . , ;.!„;;,•;%.: ;,, . frit : B e 4, €,a 4 ( .i.' , ti, kc y W -tea e s ' Z R ,-., ..,.- ire, '°,a L ,, A ✓ P Cz x i.r . •,•;,...,...,;:-;,'" ' A-44' ' , a }IVIr' t t3. � 1 { t ) W` i` Y ':nr "�"•-.a+nr«.»'n'-$,hnf Im,: f ; - "- d`3. # x. 147°' 147°57'30"W 0 147°57'0'W '4 DUCK ISLAND ---- ENDEAVOR UNIT ISLAND 1 �m e ENDICOTT MAIN PRODUCTION ISLAND ' ,' (MPI) .. . _` . 0 q Z 1111 o N III '' } o ) 1 • ��1 i -' a $r N Sec!36 ti i I(ft \ C:-// U01.2401 E �. MPI 1-53 /\ '.- \ MPI 1-59 \ \ \\--,----- /-9 ---1 ;: a � -� f z o n O / N ,� O ♦. \ o i Legend • Well Rowe -Existing Pipeline(Above Ground( ®Nand Gas Una Boundary I I . fl Duck Island Unit Endicott MPI 0 AlaskaStatePlaneZone 3NAD 1983(Feet) 100 200 (N) IIAO .bwkn.I,.c Well Rows Meters Map Date:9/8/2015 Facility Map - Figure 1 o 500 1,�Feet • • BE N E Post Office Box 244027 JUL3 0 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U 201 ` 3800 Centerpoint Drive Suite 100 A^IV\^i`••+1 C Anchorage,AK 99503 (\•/"' Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster SCANNED AUG 2016 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 q ' Anchorage, AK 99501 3 1 ' 5 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig New API_WeIINo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/I17 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 7 50029225010000 1941120 DUCK IS UNIT MPI 1-53/020 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/116 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 X50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/20/15 Inspector: Chuck Scheve Operator: Hillcorp Well Name: Endicott 1-53 Oper. Rep: Larry McBride - PTD No.: 1941120 Oper. Phone: 907-659-6700 Location Verified? Yes Oper.Email: Imcbrideahilcorp.com • If Verified,How? Other(specify in comments) ' Onshore/Offshore: Offshore Suspension Date: 11/14/94 - Date AOGCC Notified: 08/18/15 Sundry No.: 194-273 Type of Inspection: Subsequent Wellbore Diagram Avail.? yes Well Pressures(psi): Tubing Photos Taken? No IA 0 OA 0 Condition of Wellhead: Manual valve only Condition of Surrounding Surface Location: Good Follow Up Actions Needed: Comments: Location verified by location map SCANNED SEP 0 7 2016 Attachments: none REVIEWED BY: / Insp.Supry �C "t '5 Comm PLB 06/2014 2015-0820_Suspend_DIU_1-53_cs.xlsx • • bp BP Exploration (Alaska) Inc _ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 ! I Mr. Jim Regg t I Alaska Oil and Gas Conservation Commission 1 333 West 7 Avenue ° Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 1 A Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 / 1 -18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0 -23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 /0 -20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 • • ~~Q~C~ 0~ Q~u~~~tQ ia~.o.w.E..~a....~ Gary Preble Data Management Engineer BP Exploration (Alaska), Inc. .~ P.O. Box 196612 ~. Anchorage, AK 99519-6612 4` Re: Endicott Field, Endicott Oil Pool, 1-53/Q-20 Sundry Number: 310-265 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair ti DATED this ~' day of September, 2010. Encl. • STATE OF ALASKA • ~ ~~?L ALASKA OIL AND GAS CONSERVATION COMMISSION I ~ APPLICATION FOR SUNDRY APPROVALS ~~ on eer+ ~~ man 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Aiter Casing ^ RENEW SUSPENSION 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development O Exploratory ^ 194-1120 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22501-00-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^ 1-53/0-20 No Spacing Exception Required? Yes 9. Property Designation (Lease Number): 10. Field/Pool(s): - ADLO-312828 - ENDICOTT Field / ENDICOTT Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9740 - 9648.79 - 300 300 300' NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 90 30" SURFACE 130 SURFACE 130 Surface 2700 10-3/4" 45.5# NT80 SURFACE 2743 SURFACE 2722 5210 2480 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE Packers and SSSV Tvoe: NONE Packers and SSSV MD and ND (ft): 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ WDSPL ^ -Suspended Q 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 Gary Preble Printed Name a Preble Title Data Management Engineer Signature Phone Date /} ~ Q'~ ~ 4 4944 v 564-4944 - Prepared by Gary Preble 56 COMMISSION USE ONLY .. ~ "'" "~~ ~ ~ Conditions of approval: Notify Commission so that a representative may witness Sundry Numb er: - Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: Nan ~ a~T `f'nis ''rn-`' - APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: ~ ~ j i nauly~5 SEP 0 2 ~ ~-~ r , ~,~--. 9~/% ~ q'~t'/v Form 10-403 Revised 1/2010 ~ ,l ! ~~ ~ $ ~ ~ ~~ /._.y ~ Submit in Duplicate ~'~ ~ • Duck Island Unit well 1-53/Q20 Technical Justification for Application for Renewal of Suspension Status August 24, 2010 Well Status Duck Island Unit well MPI 1-53/Q20 was plugged and suspended on 11/14/94 after a well control incident. Multiple cement plugs secure the well. A waiver was requested to allow the use of a retrievable bridge plug in lieu of a surface plug. The retrievable bridge plug would facilitate in reentry and provide the reuse of surface casing and well slot which are limited at the Main Production Island at Endicott. The plugging of MPI 1-53/Q20 included pumping 11 bbls of Class G cement from TD to 9615', conducting a pressure test to 1000 psi for 30 minutes without any bleed off. A second cement plug consisting of 44 bbls of 15.8 ppg Class G cement was placed from 8541' to 8042' MD. A third cement plug consisting of 109 bbls of of 15.8 ppg cement was placed from 6601' to 5365'. Drillpipe was cut at 2972' and a 251 bbls of 15.6 ppg slurry of Type "C" Permafrost was pumped from 2972' to 2743'. The drillpipe was backed off at 2526', the casing was perforated at 2515' and an EZ drill cement retainer was run to 2477'. Following a pressure test, 25 bbls of Type "C" permafrost cement was squeezed from 2737' to 2477' followed by 9 bbls of cement placed on top of the retainer to 2383'. Abridge plug was set at 300' with 15 bbls of Type "C" permafrost cement placed on top to 144' MD. The well is mechanically sound as indicated by a passing pressure tests performed during the plugging operations. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Duck Island Unit well MPI 1-53/Q20 is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 0/0/NA. Request BPXA requests approval for renewal of the existing suspension status for MPI 1- 53/Q20. BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 24, 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Duck Island Unit MPI 1-53/Q20 (PTD # 1941120) Suspended Well Inspection Report (10-404) Application for Renewal of Existing Suspension (10-403) Dear Mr. Seamount, by BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Duck Island Unit well MPI 1-53/Q20 on 8/3/10. Enclosed is a Report of Sundry Well Operations (10-404) with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore sketch illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location • Photograph showing the condition of the wellhead and the surrounding location Duck Island Unit well MPI 1-53/Q20 was suspended on 11/14/94. It is located on a pad with active wells and/or service wells. Based on this information, BPXA requests ap, removal for renewal_ of the~exstin~, suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Duck Island Unit well MPI 1-53/Q20 is mechanically sound and secure and will meet the requirements for renewal of suspended status. r: C If you require any additional information, please contact me at 564-5637, Torin Roschinger/Jerry Murphy at 659-5102 or Chris Stone 564-5518. Sincerely, R. Steven Rossberg BPXA, Wells Operations Manager Attachments: Report of Sundry Operations (Form 10-404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Picture of wellhead and location Application for Sundry Approval (Form 10-403) with attachment: Technical Justification Cc: Roschinger/Murphy Harry Engel Mike Bill Chris Stone Jennifer McLeod Gary Preble STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q INSPECT Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ WELL Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ ~ 194-1120 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 '150-029-22501-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~, ADLO-312828 1-53/Q-20 10. Field/Pool(s): ` ENDICOTT FIELD / ENDICOTT POOL 11. Present Well Condition Summary: Total Depth measured 9740 feet Plugs (measured) 300' feet true vertical 9648.79 feet Junk (measured) None feet Effective Depth measured 300 feet Packer (measured) true vertical 300 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 90 30" SURFACE - 130 SURFACE - 130 Surface 2700 10-3/4" 45.5# NT80 SURFACE - 2743 SURFACE - 2722 5210 2480 Intermediate ~,jti ~,g Production + ~,; ~' , Liner Liner Perforation depth: Measured depth: NONE - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) NONE 0 Packers and SSSV (type, measured and true vertical depth) NONE ~(y~+^~~`r~ pR/rp ~ ,~~,,,•,yAR ~Y'l4 mj + ^; 12. Stimulation or cement squeeze summary: Intervals treated (measured): . ""$ ~' "' ~~„ ~t^N~tiISSiOft ... ..~ ~'a~a >~y'it:lz)~s~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after wo[k: ~, Copies of Logs and Surveys Run Exploratory^ ~ elopment Q Service ^ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~~ .Phone 564-4944 Date ~~/"2- ,1~ r~~ i i i i vwvw ~cviacu r icvva R~UAAS AUG ~ 5 ~ 1010 ~ ~- ~ q ~ ~"~ ~~, • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: DUCK IS UNIT MPI 1-53/Q20 Field/Pool: ENDICOTT 1 ENDICOTT OIL Permit # (PTD): 1941120 API Number: 50029225010000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/14/1994 Surface Location: Section: 36 Twsp: 12N Range: 16E Nearest active pad or road: Endicott Island Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location !Aerial photos Wellbore diagram showing downhole condition Site clearance documentation 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: Clean Pad or location surface: Clean, dry and level Location cleanup needed: No Pits condition: No pit Surrounding area condition: Clean Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): None 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: FMC single casing head w/ MV and otis cap Cellar description, condition, fluids: 1' of water in cellar Rat Hoie: No Wellhouse or protective barriers: 2 12"x12" timbers Well identification sign: None Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA: 0 psi Wellhead Photos taken (# and description): 1 -wellhead. Work Required: Ordered wellhouse sign. Operator Rep (name and signature): AOGCC Inspector: Chuck Scheve Inspection Date: 8/3/2010 Time of arrival: 1:00 PM Other Observers: AOGCC Notice Da Time of Departure: Ryan Holt 7/27/2010 1:15 PM Site access method: Access road. • • ~ ~~~~~ -53/Q-20 FINAL STA'R-~~: ~/ ~~.~ a CIBP ~a 300' w/cmt cap c 0 cu E 0 c~ c as c~ c~ Perf Sqz holes above DP 2743' sooo~ ---- -------- -cc a~ .~ a~ o - U 0 a~ U [~ .... i U _ s1oo~ PLUG #6 PLUG #5 °s ~ ' BO C~ 2526' Pipe stuck ~ 2541' PLUG #4 Severed DP @ 2972' 3~s PLUG #3 Severed DP @ 6601' N2 PLUG #2 Severed DP @' .ssY~ :(~ ~ PLUG #1 LCU/Top Kekiktuk ~ 9714' TD 9740' MD ~~~~~~E ~iasi;a uii & Gas LonS. Comrnissian Anchor bs14495a3.dgn :_M ~% ~~ ,~~, - ` ,~ Rm ~ e . ~.e j f •~ ~ejR ~ ` ~~ :yam k. t ~t a ~'M M~\Yi s `~ ~ ~ x~ `' ,: ~ } y' ,+ ~ i 'i T';~ ~' ~~: PI 8 Endeavor Is. ~ly 13, 2009 Approximate Scale: 1 "=300' 2009-18c-1-13 AFRO-Ii1~TRl~ .I i Endicott (DIU) 1- 53/Q20, PTD 1941120 Page 1 of /4 • • _. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 18, 2010 11:44 AM To: Schwartz, Guy L (DOA) Cc: Regg, James B (DOA) Subject: RE: Endicott (DIU) 1- 53/Q20, PTD 1941120 The file for this well is interesting. This was the Endicott "blowout well ". The event occurred in mid September 1994. The release was underground, but flows were reported through conductor by surface casing of other wells and at other locations on the main production island. Page 18 of the well file has a diagram of how this well is plugged. Only surface casing was set. DP apparently was stuck in the hole and was severed at several depths in order to allow plugs to be set. The plugging that was accomplished appears to fully meet the suspended well regulations. Hard to believe they would reenter this well, but I guess you never know. The outcome of this event were crew BOP training requirements, hazards section in the PTD application, requirement to post the PTD and standing orders. Tom From: Schwartz, Guy L (DOA) Sent: Wednesday, August 18, 2010 10:34 AM To: McMains, Stephen E (DOA) Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: Endicott (DIU) 1- 53/Q20, PTD 1941120 Steve, This well is listed in RBDMS as P & A status. Since the wellhead is not cut off it should be changed back to "Suspended" . I am going to have BP submit a 404 for the inspection that was done. f Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bill, Michael L (Natchiq) [mailto:Michael.Bill @bp.com] Sent: Tuesday, August 17, 2010 4:48 PM To: Schwartz, Guy L (DOA) Cc: Stone, Christopher; Engel, Harry R Subject: Endicott (DIU) 1- 53/Q20, PTD 1941120 Guy, As we discussed, according to the database, Endicott (DIU) 1- 53/Q20 was P &A 11/14/94. BP requested the well be classified as abandoned but left with the wellhead in place. Enclosed is a recent photo of the "tree" for the well. A note in the AOGCC online file indicates the well should be considered suspended since the tree is still in place. A Suspended Well inspection was performed on 8/3/10 with Chuck Scheve as a witness. Please advise as to the best way to handle the paperwork on this well. 3/24/2011 Endicott (DIU) 1-53/Q20, PTD 1941120 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, August 18, 2010 10:54 AM To: 'Bill, Michael L (Natchiq}' Cc: Stone, Christopher; Engel, Harry R; McMains, Stephen E (DOA) Subject: RE: Endicott (DIU) 1-53/Q20, PTD 1941120 Page 1 of 1 Mike, Thanks for catching that. We had it listed in our database as " P & A " . We have changed it to "Suspended" . Please submit a 404 report on the inspection that was done and point forward treat it as a suspended well. I have a record in our file of 6 cement plugs set in the wellbore. The upper most cement plug appears to be 150' of cement (14bbls) with a bridge plug as a base. The plug depth is listed as 150-300' md. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Bill, Michael L (Natchiq) [mailto:Michael.Bill@bp.com] Sent: Tuesday, August 17, 2010 4:48 PM To: Schwartz, Guy L (DOA) ,.a 4J Cc: Stone, Christopher; Engel, Harry R ~'~ f. ~~~ ~ ~~~ ~ ~~ ~ ~~ ' ~` c, ~~ ~ (~ i~ Subject: Endicott (DIU) 1-53/Q20, PTD 1941120 Guy, As we discussed, according to the database, Endicott (DIU) 1-53/Q20 was P&A 11/14/94. BP requested the well be classified as abandoned but left with the wellhead in place. Enclosed is a recent photo of the "tree" for the well. A note in the AOGCC online file indicates the well should be considered suspended since the tree is still in place. A Suspended Well inspection was performed on 8/3/10 with Chuck Scheve as a witness. Please advise as to the best way to handle the paperwork on this well. «END1-53 wellhead.ZlP» Mike Bill Well Integrity Group Drilling & Completions 907-564-4692 OfFce 907-564-5510 Fax 8/18/2010 ON OR BEFORE ",.OGCC "t" Iiq~..'l v:iau,:~ -' i ',,,,!e 'J (.;.e,.x,,og'i:c,~'i i','la?er'5~a'i s Inventor'y PERk,IZT DATA T DATA_,F'LUS T 8950-- 10074. ,,?,N/'SBT/GR L 24.0~'-8563 L 10600-11300 1 L SIJRFACE~-94.50 1 L SURFACE-94.4.8 1 9~-,.-'112 ~-Z'EMP/PRESS/GR/CL L S~JRFA,3E-9~50 1 RUN E,A'f'E....R ECVD 1 10/12/96 O3/3 1/'95 t0/'l 2i94. 10/05/9t~ 10/'05/9~- Ar'e dr'y ditch samp'ies r'equ')'r'ed? yes r~__~nd r'ecei'ved? yes ~,,,tas 1:.ne we'i 't eot'ed? yes n~a'i ys~'s & ' ...... " ' d~Cl ipl:')'orl r'ece~ yes no Ar'e we'll tests r'equ~'r'ed? l~eS ¢ Recei'ved? y~ ~4e 'l 'i 'i' s '~' n cornp i ~' a rice I n i' t ~" ' "a'i ,COF~M ENTS PLUGGING & LOCATION CLEARANCE REPORT State of Alaska .~LASKA OIL & GAS CONSERVATION COMMISSION -. A_bnd Date Completed Long Csq: ~ C~ Liner: Perf in=ez~zais - tops Review the well file, and-comment on plugging, well head st. at'as, and location clearance - provide loc. clear, code. Well head cut off: ~ ~. " ~ ~ *x ~arker post or plate: ~. ~ Location Clear~ce: ~ ~,, ~ ~/ ~ Conc!usio ~ I ~ ~ -~i ~ t "-v ~ I Signed Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) March 30, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The-following data of the _.8_.LJJ~_l_G_.B for well -_I.=.6J.L(~,~, Job # * Please note: no depth shifts per Brent Voorhees. Alaska Oil & Gas Cons. Commission Anchorage 95097 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 2 Blueline 1 Film Arco Alaska Inc. Attn: Dede Schwartz, ATO-1336 Anchorage, Alaska 99510-0360 · . ............ ~ta'te of Alaska ~ .... Alaska Oil & Gas Conservation Cornm "~ / ,/ / Attn: Larry Grant ~ 3001 Porcupine Drive _ · "".-.... Anchorage, Alaska 99501 E×xon Company-;15'S-A .... Alaska Interest Organization Attn: Susan Nisbet 800 Bell St., EB3083 Houston, Texas 77002-7420 1 OH LIS Tape 1 RRolled Sepia '-., ,~-d'~ ~ 1 OH LIS Tape '----~.. 1 Blueline. '-~..,~ RFolded Sepia 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 905 127 800 UNOCAL Attn: Debra Childers 909 W. 9th Ave. Arlchorage, Alaska 99519-0247 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Amoco Production Company Attn: Shirley A, Kuhr 18506 Osprey Circle Anchorage, Alaska 99516 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 905 127 802 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION~ (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 ~r. hh ]mharr~r (~_nl IrJ~r' Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA/.~99518-1199 Received By. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 6 January 1995 Transmittal of Data ECC #: 6336.01 Sent by: MAIL Data: LDWG Dear Sir/Madam, Reference: ENDICOTT ~~ ? NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIST Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 · Anchorage, AK 99518 /~ y~/~~ Or F,AX to (907)563-7803 '~'~ ~%~O&,~ ~~u~/~,,/~ Received b ~ate. ~, ~" /~ ~/) Memorandum ALASKA OIL AND GAS CONSERVATION COMMISSION State of Alaska , To: David W Johnston Chairman Blair E Wondzell Sr. Pet. Engr. Date: Nov. 29, 1994 Sub: Final Report, Endicott Incident 9/21/94 Kick, Well 1-53/Q-20 Doyon Drilling Rig #15 This is a final report of the well control incident "kick" that occurred at the Endicott well 1-53/Q-20 on September 21, 1994. Data is 'from BPX briefings, Bobby Foster's onsite reports during the incident, discussions with the inspectors, file information, and BPX's "Endicott Well 1-53/Q-20 Final Investigation Report - Follow up". The purpose of investigating an incident is to identify the primary contributing factors and adopt or modify procedures which can prevent future recurrence of similar incidents. Its obvious the kick occurred because the mud weight was too low. The germane questions are: why was the mud weight too low and why did a minor influx turn into a major event. Incidents !. Rig personnel were not warned that the well would enter the Kekiktuk gas cap, the~were therefore not prepared for high pressure formation gas. The PTD application contained this statement - "No 'abnormal pressures are expected in the 9-7/8" hole section." 2. Upon encountering a significant drilling break, the driller did not check for well flow. This was a mistake in procedure, but probably did not,~contribute to the occurrence of the kick. 3. After pulling 3.5 stands and observing the well flowing and an 8 bbl pit gain, the driller ran back to bottom without shutting the well in; this was a mistake in procedure that was significant. When they got to bottom and shut the well in, the driller reported.~O sidpp, 200 psi sicp and a 25 bbl gain; at this point the kick was readily controllable, but it was still not treated as a serious~event. 4. The driller started a slow circulation with non-kill-weight mud; this procedure strung the gas bubble up the hole while allowing additional influx of gas. In a relatively short time gas was strung from the formation to the surface. Significant mistakes A) Why was the mud weight too low? The rig was not apprised they would drill into the gas cap - had the fluid been water or oil there would have been no "event". B) Why did a small (8 bbl) gas influx turn into a major influx? By not shutting in the well prior to running back to bottom, the driller violated the basic principles of well control, including BPX's well control policies as set forth in their Well Control Manual. C) Why did a moderate (25-33 bbl) gas influx turn into a major wel~ . control situation? After reaching bottom and taking shut-in readings, the driller again ignored well control procedures, including those in BPX's Well Control Manual, when he started to slowly circulate the well instead of keeping it shut-in until kill procedures could be initiated. D) Why did the two Doyon rig 15 drillers, one on each of the two shifts, not follow basic well control procedure? Two of our inspectors told me it was rumored that North Slope drillers where told not to shut-in wells, only the toolpusher and company man could make that decision. Areas for Improvement: a) A Drilling Hazard section in the Permit To Drill.(~TD) application and a copy of the PTD on the rig would help ensure that rig personnel know of the drilling hazards uncovered during preparation of the PTD. ' This is being required in my draft of the regs. ARCO and BPX are irregularly including a Hazard section in their North Slope drilling programs. We are revising the BOPE Test Report form to include a "check- off" for a-copy of the PTD on location, especially the Hazard Section. b) The standing orders posted on the rig have been revised by Prudhoe Bay Drilling to re~lect good shut-in procedure while drilling and while tripping; this statement is at the bottom of the Well Shut In Procedure Under No circu~nstances will pipe be run to bottom with the annular open and the well flowing! Two subsequent (11/29/94) submittals from Scott Sigurdson of BPX. KEY RESPONSIBILITY The DRILLER is RESPONSIBLE and AUTHORIZED to. "SHUT THE WELL IN" on HIS OWN RECOGNITION. WELL CONTROL PROCESS THE DRILLER, IF IN ANY DOUBT THE WELL IS FLOWING, WILL: * CLOSE THE WELL IN AS QUICKLY AS POSSIBLE; * NOTIFY THE TOOLPUSHERAND COMPANY REP; * TOOLPUSHER AND COMPANY REP WILL ASSESS THE SITUATION; * RESPONSIBILITY FOR OPENING THE WELL LIES WITH THE COMPANY REP: ~t * THE TOOLPUSHER WILL DESIGNATE TASKS TO SPECIFIC INDIVIDUALS; * THE COMPANY REP WILL INITIATE THE EMERGENCY RESPONSE PROCEDURE. To my questions, Scott stated "The 'Driller' is the person on the brake". Copies of the above three documents are attached. c) The responsible drilling personnel need to have minimum well control training. Upon returning from the November 18 well control refresher class, Bobby reported that some Doyon drilling personnel - Toolpusher, Driller, Derrickman, and Motorman - were in the refresher class. In my draft of the regs, under 25.035(d) (2), I've proposed that MMS certified well control training be required for key members of the rig crew. Implementation of the above "improvements" could reduce the occurrence of similar and related well control incidents. WELL SHUT IN PROCEDURE.," Harc~ Shut In iii i WHILE DRILLING WHILE TRIPPING 1. Drilling Eh'~ak 2, In~,~a~.ed Re(urns Ftowmtg 3. Pit Gab 4. Change In P(~ Spe~ or P~.~sure 6, Su~an Change h Mua 1. Pick Up T~',~I .J~m! Above Rclary Tabk, 2, Shut [~wn Purno8 ,.'3 r. lowchec.,~ Well If Nu,;e~ary the Well Fbwin YES ,. NO Notify P[3D Representative Proceed as Directed 1. Hole Nnt T~k~ng Correct Volume 2. W~II ~ Fbwing.. Line Valve (HCR) 2. CJos~ Annular Prever~ter 3. Che~k Well is Shul In 4. Record DP & Csg Pressure .5, Notify PgD Rupre.'mmatlve 6. Proceed as Directed Under bLo circumstances will pipe be run to bottom with the annular open and the well flowing! ~p! 14, lgg4 2, Inslut~ Open DP Safe~y Valve 3, CIose DP Safer)/Valve 4, Open Choke Lins Valve (HCR) 5, Close Annular Proven[er 6. Check Well Is Shul In 7. Nntify PBD Representative 8. lns[atl Kelly 9, Of:un DP ~afety Valve 10, ReCOr0 DP & Csg Pre?.sure 11. Proceed as cfirected KEY RESPONSIBILITY __ __ __ - I-- Il . - - .mi _ I __. Il . Il _ --~ ~ I _. II The DRILLER RESPONSI.BLE and AUTHORIZED to "SHUT THE WELL IN" On RECEIVED NOV 29 ]994 ',~laska 0ii & Gas Cons. CommtSstu" Anchorage WELL CONTROL PRO'CESS _.T. HE DRILLER,iF.. i.N ANY DQ._UBT THE WELL. IS FLO .WING, WILL; CLOSE THE WELL IN AS QUICKLY AS POSSIBLE; · NOTIFY THE TOOLPUSHER AND COMPANY REP; -' ~ , . TOOLPUSHER AND COMPANY REP WILL ASSI:::SS THE SITUATION; ' ·RESPONSIE~iLITY FOR_OPENIN..G THE WELL LIES WITH THE COMPANY REP; ·THE TOOLPUSHER WILL DESIGNATE TASKS TO SPECIFIC INDIVIDUALS; · THE COMPANy REP WILL INITIATE THE EMERGENCY RESPONSE PROCEDURE. ' RECEIVED i~.OV 29 1994 kla~k~ Oil & Gas L;ons. ~" STATE OF ALASKA -" Al_~,~.,~ G,_ ,-~ND gas CONSERVATION COMMIS~._N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging x Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development /~ Exploratory 3. Address Stratigraphic 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service 4. Location of well at surface 8. 3108' NSL, 2185' WEL, SEC. 36, 12N, R16E At top of productive interval N/A At effective depth At total depth 11. 2387' NSL, 1131' WEL, SEC. 36, T12N, R16E 12. Present well condition summary Total depth: measured true vertical 9740 feet Plugs (measured) 9650 feet Datum elevation (DF or KB) KBE=56 feet Unit or Property name Duck Island Unit/Endicott Well number 1-53/Q-20 9. Permit number/approval number 94-112 10. APl number 50- 029-22501 Field/Pool Endicott Field/Endicott Pool Please see attached Effective depth' measured true vertical Surface feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 90' 2700' measured None true vertical Size Cemented 30" Driven 10-3/4" 617 sx PF "E"/375 sx "G" Measured depth BKB 130' 2743' ORIGINAL RECEIVED True ve~l depth 130' 2723' Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Atask~ u, c, ua.,-, b~.,~ ,.,ummissJo_fl Anchor,;; .,,~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well gperations x Oil Gas Suspended 17. I hereby certify that~__~,e~te, r~o~g is true a~,~d correct to the best of my knowledge. Signed / A ~-/("~',~,~ '~,,., Title Driilin.q En.qineer Supervisor Form 10-404 Rev 06/lJ~/88 Service S Datejj/J~lq~'.. UBMIT IN DUI?LICA~I'E 1-53/Q-20 Abandonment After discussion with Blair Wondzell on 11/15/94 we are requesting that well 1-53/Q-20 be classified as an abandoned well whilst maintaining the 1-53 surface location slot for future development. RECEIVED 1-53 Ce~'ent .. ' ....... i.53/20 Cement Plu_gs .. Plug Number 'Cement (bbl's) Bottom, M.D Top MD ..... '" TYPe 1 11 9740 9615 Premium ............ 2 44 8541 8042 Premium 3 109 6601 5365 Premium 4~ 251 ., 2972 2743 "C" Permafrost ........... I. 5 25 2737 2477 EZSV at 2477', "C';' PermafrOSt cement below EZ~V ................. 5 9 2477 23831 EZSV at 2477', "C" Permafrost cement above EZSV ,, 6 1 5 3.0. 0 144 Bridge Plug set at 300',."C" Permafrost Cement on top .... Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COlvlMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] ,SUSI:~d~)ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number iBP Exploration 94-112 13. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22501 4. Location of well at sudace.c. ,--~ ......... , : .6' ;.., _:2,,?~,~,,~.~. 9. Unit or Lease Name 3108'NSL, 2185' WEL, SEC. 36, T12N, R16E ........ i.:... _: ........... ~ ..~ Duck Island Unit/Endicott At Top ProduciQg Interval ! ~/~.?~_~ i :~i:ik~. 10. Well Number N/A -~ ~:_. 1-53/Q-20 ~!. ! 11. Field and Pool At Total Depth ~- - ..... '{?-' '~ Endicott Fie/d/Endicott Pool 2387' NSL, 1131' WEL, SEC. 36, T12N, R16E ~-- ~'~ ...... "~ 5. Elevation in feet (indicate KB, DF, etc.) ~. Lease Designation and Serial No. KBE = 56' ! ADL 312828 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 9/12/94 9/21/94 9/30/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set ~21. Thickness of Permafrost 9740' MD 300' MD/300' TVD YES [] NO []I None feet MD ~1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' 30" Drive 10-3/4" 45.5~ NT-80 43' 2743' 13-1/2" 617 sx PF "E"/375 sx "G" 24. Perorations open to Production (MD+TVD of Top and Bottom and ;~5. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) None None None I ' D {'--,.~ /;._~ I :~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. [.~ [_ \ i ~? i~{ '-~''~i ,~ , ~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Please see attached 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lilt, etc.) Not on production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence et oil, gas or water. Submit core chips. RECEIVED ~.~a Oil & Gas Cons. Cammiaaion Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOG~ MARKERS ~-~RMATION TESTS NAME Include interval tested, pressure data. all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea K-7 5960' 5851' Top West Sak 6860' 6742' Top Kekiktuk 9700' 9553' RECEIVED .OV 31. LIST OF ATTACHMENTS AJb[SJ/~ 0JJ & CaS C0RS. -' ,-, ~P'orrJ~s$=or~ 32. I hereby certify th~tt the foregoing is true and correct to the best of my knowledge ~uuuor: Signed Title Drilin.q Engineer Supervisor 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. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1-53 Cement 1-53/20 cement Plugs Plug Number Cement (bbls) Bottom MD Top MD Type 1 1 1 9740 961 51 Premium 2 44 8541 8042 Premium 3 109 6601 5365 Premium 4 251 2972 2743 "C" Permafrost I 5 25 2737 2477 EZSV at 2477', "C" Permafrost cement below EZSV 5 9 2477 2383 EZSV at 2477', "C" Permafrost cement above EZSV 6 1 5 300 1 44 Bridge Plug set at 300', "C" Permafrost Cement on top -- .... Page 1 ; ~--'-"t - S 3/0.-2 0 FINAL CIBP @ 300' w/cmt cap Perf $qz holes above DP 2743' 6000' o o 8100' PLUG #6 PLUG//5 BO @ 2526' Pipe stuck @ 2541' PLUG #4 Severed DP @'2972' PLUG #3 Severed DP ~ 6601' ! PLUG #2 Severed DP @ I PLUG #1 LCU/Top Kekiktuk @ 9714' TD 9740' MD RECEIVEb BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPI 1-53/Q-20 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/12/94 03:00 SPUD: RELEASE: 10/12/94 06:00 OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 09/08/94 (1) TD: 0 PB: 0 09/09/94 (2) TD: 0 PB: 0 09/10/94 ( 3) TD: 0 PB: 0 09/11/94 ( 4) TD: 0 PB: 0 09/12/94 ( 5) TD: 0 PB: 0 09/13/94 (6) TD: 1313' ( 0) 09/14/94 ( 7) TD: 2752' (1439) RIG MAINTENANCE MW: 8.5 Seawater MOVE RIG OFF WELL & REMOVE THE BOP STACK. MOVE THE RIG T/MPI. SPOT @ END OF CELLAR. BLOCK PITS UP F/WELDERS T/REINSULATE UNDER #1 MUD PIT. LOWER SUPPORT LEGS, SKID FLOOR. REMOVE DRAWWORKS B MOTOR. CLEAN BOP'S, BODY & PARTS. YEARLY RIG MAINTENANCE MW: 8.5 Seawater REINSULATE & PLATE MUD PIT #1. REMOVE, REPAIR & MODIFY VARIOUS EQUIPMENT. CLEAN THE RIG. RIG MAINTENANCE MW: 8.5 Seawater YEARLY MAINTENANCE SCHEDULE FOR RIG. REPAIR, REPLACE &/OR MODIFY RIG COMPONENTS, INSPECT BOP & NU BOP. YEARLY MAINTENANCE MW: 8.5 Seawater YEARLY RIG MAINTENANCE. REPAIR, REPLACE OR MODIFY VARIOUS RIG COMPONENTS. LAY MATTING BOARDS ON WELL LOCATION T/MORU OPERATIONS. ACCEPT RIG MW: 0.0 Seawater YEARLY RIG MAINTENANCE. REPAIR, REPALCE OR MODIFY VARIOUS RIG COMPONANTS. MIRU ON 1-53/Q-20. SKID WFLOOR OVER WELL. RU & FILL PITS W/WATER. MIX SPUD MUD, STND DC BACK IN DERRICK F/BHA. ACCEPT RIG @ 3:00 HRS. DRILLING MW: 8.8 VIS:195 MIX SPUD MUD, RU ROCK WASHER, INSTALL INJECT LINE T/l-51. PU 41 STNDS OF 5" DP & STND BACK. PU 9 HWDP. RU ATLAS WL. MU BHA & ORIENT. RIH TAG BTTM @110'. SPUD @ 20:00 HRS. DRILL & SURV. W/MWD T/1313. RIH W/10.75" CSG MW: 9.2 VIS:130 DRILLING & SURV. W/MWD 1313 T/1325. SHORT TRIP, 10 STNDS. DRLG T/2752 W/MWD. SHRT TRIP 10 STNDS. CBU. TRIP OUT LD BHA. CLEAR FLOOR. RU & RIH W/10.75" CASG. Armhor: . ' WELL : MPI 1-53 OPERATION: RIG : DOYON 15 PAGE: 2 09/15/94 ( 8) TD: 2752' ( 0) 09/16/94 ( 9) TD: 4606' (1854) 09/17/94 (10) TD: 5845' (1239) 09/18/94 (11) TD: 7464' ( 1619) 09/19/94 (12) TD: 7763' ( 299) 09/20/94 (13) TD: 9000' (1237) RIH W/BHA MW: 9.2 VIS: 46 LAND 10.75" CASG. BEGIN CIRCULATING. ENCOUNTERED A COMMUNICATION PROBLEM W/THE ANNUL. INJECTION ON 1-51. SWITCHED INJECTION T/2-24. CMT'D CSG, BUMPED PLUG W/2000 PSI. FLTS. HELD. CLEAR FLOOR. ND RISER & TEST. NU BOP'S & TEST 500/5000. NOTIFIED AOGCC ON TEST BUT NO ONE SHOWED UP T/WITNESS. INSTALL WEAR RING. PU NEW BHA & RIH. POOH F/BIT CHANGE MW: 9.2 VIS: 81 RIH. TAG FLT COLLAR/TEST CSG T/3000/30 MIN. DRILL SHOE TRACK + 10' OF NEW HOLE. CBU. LOT: 900 PSI PSURF W/9.1 PPG MUD = 15.4 PPG EMW. DRILL T/3745. PUMP SWEEP. SHORT TRIP OK. DRILL T/4606, ROP SLOWED. CBU. POOH F/NEW BIT. DRLG MW: 9.4 VIS: 72 POOH. SWABBED 1ST TEN STANDS BEFORE HOLE WOULD FILL CORRECTLY. DRY JOB @ SHOE. (PROBLEM TIME WORKING TIGHT HOLE WHILE POOH). M/U NEW BHA; SERVICE RIG, ORIENT TOOLS. P/U NEW BIT & MOTOR. P/U 69 JT'S DP WHILE RIH & TEST MWD TOOL @ SHOE. RIH. HAD TO REAM BACK THROUGH CLAYS @ 3500'-TD. (PROBLEM TIME WORKING BACK THROUGH TIGHT HOLE WHILE RIH). DRLG 4606-5750'; READY TO BEGIN TURN. SHORT TRIP. HAD TO BACKREAM 5466-4130' HOLE ULLED NORMAL TO 3903'. RIH W/NO HOLE PROBLEMS; APPEARS TO BE WIPED OUT OK. DRLG 5750-5845'. GETTING GOOD TOOL SETS ON TURN, TURN PROCEEDING WELL. DRLG MW: 9.4 VIS: 70 DRLG 5845-6701'. SHORT TRIP 12 STANDS - NO PROBLEMS. DRLG 6701-7464. ROP SLOWING TO <50 FPH; WILL PROBABLE TRIP THIS MORNING - PLAN TO RUN USED PDC FROM THIS INTERVAL THROUGH TOP OF TUFFS (PREDICTED @ 8900') DRLG MW: 9.4 VIS: 65 DRLG TO 7445'; CONSISTENT 35-40 FPH. CBU UNTIL SHAKERS CLEANED UP GOOD FROM HI-VIS SWEEP. POOH; PULLED TIGHT @ 3800-3600', AND AGAIN @ 3200. M/U NEW ASSY & RIH, PICKING UP SOME NEW DP. REMOVE PIPE HANDLER FROM TOP DRIVE FOR REPAIR ON SOME SHEARED BOLTS AND IBOP ACTUATOR SYSTEM. CUT DRLG LINE. REPAIR TOP DRIVE. RIH, TESTED MWD @ SHOE, RIH TO BOTTOM. NO TIGHT SPOTS SEEN ON THE WAY TO TD. DRLG 7445-7763. DRILLING MW: 9.5 VIS: 62 DRILLING F/7763 T/8810. SHORT TRIP THIS SECTION BEFORE ENTERING TUFFS, NO PROBLEM DURING SHORT TRIP. DRLG F/8810 T/9000. EST TOP OF TUFFS @ 8958.MD. i',,.".OV - '~,' 'i',-;'?"-~ Anchor: WELL : MPI 1-53 OPERATION: RIG : DOYON 15 PAGE: 3 09/21/94 (14) TD: 9311' ( 311) 09/22/94 (15) TD: 9311' ( 0) 09/23/94 (16) TD: 9740' ( 429) 09/24/94 (17) TD: 9740' ( 0) 09/25/94 (18) TD: 9740' ( 0) 09/26/94 (19) TD: 9740' ( 0) 09/27/94 (20) TD: 9740' ( 0) DRILLING MW: 9.5 VIS: 65 DRLG F/9000 T/9082. SAW THE SAME MARKERS IN TUFFS FORMATION THAT HAD BEEN SEEN BEFORE WHILE TRY T/LOCATE PULL POINT-DRILLED FURTHER T/SEE IF BIT COULD DRILL T/HRZ. ROP SLOWED T/<15 FPH. SO DECIDED T/PULL BIT. FINISH CIRC SWEEP AROUND. POOH OK. RIH PU ROTATING ASSY & EXTRA HWDP IN PREPARATION F/BUILDING SECTION UP ON NEXT TRIP. DRILLING F/9082 T/9311. WELL PROBLEM MW: 9.5 VIS: 0 WE ARE EXPERIENCING A WELL CONTROL PROBLEM AT PRESENT. A LIMITED AMOUNT OF GAS WAS RELEASED EARLY THIS MORNING. THE WELL WAS SHUT IN & IS NOW UNDER CONTROL. NO FURTHER GAS IS BEING RELEASED INTO THE ATMOSPHERE. THERE HAVE BEEN NO INJURIES & EMERGENCY RESPONSE PROCEDURES HAVE BEEN INITIATED. APPROPRIATE AGENCIES ARE BEING NOTIFIED. STAGING BJ EQUIP. MW:10.0 ViS: 58 WELL FLOWING THROUGH THE ANNULI @ THE RATE OF 9 MILLION CF OF GAS & 6000 BBLS LIQ. PER DAY @ 1050-1150 PSI INTO THE FACILITY THRU WELLS 1-63, 1-39 & 1-41. PUMPING DOWN THE DP .5 BPM T/INSURE DP STAYS OPEN. PERCULATION OF GAS INTO ADJACENT CELLARS IN WELLS 1-41, 1-43, 1-55 & 1-69 THROUGHOUT THE NIGHT STEADLY DECLINED & @5:00 AM HAD ALMOST STOPPED COMPLETELY. ATLAS RAN PDK/TEMP LOG. SFTY BOSS ARRIVED ON LOCATION @3:45AM ON 9/23. @06:00 HRS, BJ BEGAN STAGING PUMP UNITS ETC. IN PREPARATION F/A DYNAMIC WELL KILL. PREPARING T/KILL WELL MW:IO.O VIS: 0 SAFETY BOSS ON SITE. PREPAIRING T/ KILL WELL W/HEAVY MUDS. EVAL. WELL KILL MW:10.0 VIS: 0 WELL KILL APPEARS SUCCESSFUL. CURRENTLY EVALUATING FOLLOW-UP PROCEDURES. EVALUATING WELL KILL MW:iO.O VIS: 0 EVALUATING WELL KILL. TRYING T/DETERMINE WHETHER T/P&A OR TEMP. SUSPEND. EVALUATING WELL KILL MW:10.0 VIS: 0 CURRENTLY APPLYING FOR A TEMP. SUSPENSION PERMIT. FOR WHAT APPEARS T/BE A SUCCESSFUL WELL KILL. WELL : MPI 1-53 OPERATION: RIG : DOYON 15 PAGE: 4 09/28/94 (21) TD: 9740' ( 0) 09/29/94 (22) TD: 9740' ( 0) 09/30/94 (23) TD: 9740' ( 0) 10/01/94 (24) TD: 9740' ( 0) WASHING IN HOLE. MW:10.0 VIS: 0 WORK PIPE/NO RETURNS. INJECTION TEST:500PSI @ 5BPM. PRESS TEST ANNUL. T/1000. RU HOWCO & PUMP 145 BBLS PERMAFROST C @ 15.6PPG & 106 BBLS COLDSET 111 @ 15 PPG. DISPLACE W/RIG PUMPS, ETOC 2700'. SHUT IN W/450PSI SQZ PRESS. WOC. PRESS DECLINED T/200PSI. RU AWS & RIH W/APR STRING SHOT. TAGGED @ 2830' BACKED OFF DP @ 2526 ELM. POOH & RD AWS. RU TOP DRIVE & CIRC @1500 PSI @.5 BPM, INTERMITTENT RETURNS FELL T/0. COULDN'T MOVE PIPE W/O HIGH DRAG, (350-400K) UNLESS ASSISTED W/CIRC PRESS OF 300-400PSI. HAD T/PUMP EA. STND OUT OF HOLE-NO RETURNS, BUT A LOT OF GAS BUBBLING UP AROUND PACKED OFF AREA. POOH VERY SLOWLY WHILE HYDRAULICING UPWARDS. NO DOWNWARD MOVEMENT POSSIBLE, ALLOWING FREE GAS T/PERCOLATE OUT AFTER PULLING EA. STAND. WHEN #24 WAS PULLED, WE BEGAN T/SEE CIRCULATION WITH LOTS OF GAS @ SURFACE. PLUGGED THE FLOWLINE W/VERY CLEAN FINE SAND. PU BIT, CASG SCRAPER & HWDP. WASHING IN HOLE, 1" THICK SAND ON THE SHAKERS. ND BOP MW:10.5 VIS: 82 WASH T/BTTM @2544 W/BIT & SCRAPER. CBU. POOH LD BHA. RU WL, RIH W/2-5/8" PERF GUN/SHOT 4 SPF F/2515'=17' POOH & RD WL. GOT INJECTION RATE 5BPM @950 PSI. MU HOWCO EZSV & RIH. SET EZSV,~2477._~_PRESS TEST CASG T/1000. RU HOWCO & SQUEEZE CMT THRU PEq~-~lqOLE @2515. PUMP 5BLS H20 @800PSI. SHUT DOWN/TESTED EZSV @1000. WITNESSED BY B.FOSTER W/AOGCC. PUMP 33 BBLS 200 SX C CMT W'TED T/15.6 PPG, FOLLOW W/2 BBLS H20. DISPLACE W/30 BBLS MUD, 4 BPM, 500 PSI, PLACED 50 SX CMT ON TOP OF EZSV, EST. TOC @2383. PULL 3 STNDS. CIRC 42 BBLS T/CLEAN DP_ POOH & AD DP & TOOLS. RIM & SET EZSV @300', TEST BP W/1000. PLACE 15~' CMT ON TOP OF BRIDGE PLUG. PULL T/125', CIRC 20 BBLS. POOH & LD DP & TOOLS. PULL BOWL PROTECTOR TEST BOP & CHOKE MANIFOLD. CLEAR FLOOR & ND BOP. RIG REPAIR W/C DAMAGE MW:10.5 VIS: 0 ND BOP & TBG SPOOL. NU 13-5/8" DRY HOLE FLANGE & 4" VALVE. TEST T/1000. CLEAN PITS & WELL HOUSE. DEACTIVATE EMERGENCY SHUT DOWN SYSTEM. MOVE RIG OFF WELL & RU T/RIG REPAIR @ END OF WELL ROLL. REMOVE SEATS, PADDLES F/CHOKE MANIFOLD F/INSPECTION. ND BOP, REMOVE OUTSIDE & INSIDE SHOCK HOSES, AND RAM BLOCKS F/INSPECTION. INSPECT WC DAMAGE WORK ON CHOKE MANIFOLD & BOP STACK. MW:10.5 VIS: 0 10/02/94 (25) TD: 9740' ( 0) WORK ON BOP WORK ON BOP STACK & CHOKE MANIFOLD. MW:lO.5 VIS: 0 .. ~,,. ijiJ &. i3a~ t;onq, (;ommission WELL ' MPI 1-53 OPERATION: RIG : DOYON 15 PAGE: 5 10/03/94 (26) TD: 9740' ( 0) WORKING ON WC DAMAGE WORK ON BOP STACK & CHOKE MANIFOLD. MW:10.5 VIS: 0 10/04/94 (27) TD: 9740' ( 0) 10/05/94 (28) TD: 9740' ( 0) 10/06/94 (29) TD: 9740' ( 0) 10/07/94 (30) TD: 9740' ( 0) 10/08/94 (31) TD: 9740' ( 0) 10/09/94 (32) TD: 9740' ( 0) 10/10/94 (33) TD: 9740' ( 0) WORKING ON WC DAMAGE MW:10.5 VIS: 0 REBUILT VALVES IN PUMP ROOM, SERVICE TO DRIVE, EX-RAY OVERBOARD & GAS BUSTER LINES. INSTALL NEW GAS BUSTER, REBUILT CHOKE MANIFOLD VALVES, HEAT TAPE & INSULATE OVERBOARD LINES. FINISH WORKING ON BOP IN MAINT BLDG, MOVE BOP TO RIG, CLEAN SHOP WORKING AREA. WORKING ON WC DAMAGE MW:10.5 VIS: 0 REBUILD VALVES ON CHOKE MANIFOLD, PLUMB LINES FOR GAS BUSTER, WELD NEW FLANGES ON SPACES FOR CHOKE MANIFOLD, HEATTAPE AND INSULATE OVERBOARD LINE, WORK ON GAS BUSTER. WORKING ON WC DAMAGE MW:10.5 VIS: 0 REBUILD GAS BUSTER LINES & WORK ON DEGASSER. WORK ON SPACES F/CHOKE MANIFOLD. WORK ON WC DAMAGE MW:10.5 VIS: 0 WORK ON GAS BUSTER, CLEAN RIG & BOP PARTS WHILE WAIT ON CHOKE PARTS FROM ANCHORAGE. WORK ON WC DAMAGE MW:10.5 VIS: 0 REBUILD CHOKE MANIFOLD, WORK ON GAS BUSTER, WAIT ON PARTS F/MECH SHOP. WORK ON WC DAMAGE MW:10.5 VIS: 0 WORK ON WC DAMAGE: REPAIRING STANDPIPE, N/U BOP'S, INSTALL PORTION OF CHOKE MANIFOLD, FLES HOSE & FLANGES. WORK ON WC DAMAGE MW:10.5 VIS: 0 WORK ON WC DAMAGE: M/U CHOKE MANIFOLD. 10/11/94 (34) TD: 9740' ( 0) 10/12/94 (35) TD: 9740' ( 0) 10/13/94 (36) TD: 9740' ( 0) WORKING ON WC DAMAGE. MW:10.5 VIS: 0 NU CHOKE MANIFOLD & WORK ON GAS BUSTER. WC DAMAGE REPAIR MW:10.5 VIS: 0 WELD & INSTALL GAS BUSTER & CHOKE MANIFOLD LINES. RIG RELEASED MW:10.5 VIS: 0 WELDING ON CHOKE LINES & GAS BUSTER. SKID THE RIG. PREPARING FOR THE MOVE T/1-57/R-23 WORKOVER WELL. RELEASE RIG FROM 1-53 ON 10/12 @ 18:00 HRS. RECEIVED Gas CoI~. Commission Anchor: AZII,LrFH ~ ROTARY T~ TO T~ET IS TIE IN POI~(TIP): I'IEA_qURED I)EI:9'H857.00 TRUE VtAT DEPTH II'~IHATIOH AZIMUTH 12~.70 LATITUDE(I,V-S) -10,00 DEPARTURE(El-W) 17.00 DEP(E/-W) o. MICROI:ILMED ORISINAL ~ CAU3ULA?IONS ~ I~ VtU~TICAL TARGEI STATION DEPTH DEPTH 8)~TION I~, f% f% fr ft 8~.~ 0,0 ~.~ 19,~ 6,~ 979,26 1~,3 9~.~ ~.~ '9.~ 1143.~ 1~.7 11~.~ ~,67 1261,64 116,6 1~,15 79.~ 9,02 1~.62 94.2 1~9.~ 94.~ 10.~ A/I~UTH LATITUDE deg ft 126.70 -10.00 128.07 -19.75 132.80 -36.21 130.30 -48,3~ 125.30 -57.91 ))EPAR1IJRE DISPLACLCI~EHI at AZIMUTH EY-W ft ft deg 17,00 19,72 120,47 29,70 35.67 123,63 49.04 60.96 126,44 62.79 79.27 127.62 75,12 94.85 127.63 lOOft 0,00 2,50 0.47 0.37 1,39 1449,81 1545.06 1615.00 1735.76 1832,58 94.0 1441,68 110.36 9,39 95,2 1535.60 126,21 9.78 69.9 1604,55 137.91 9.50 120+8 1723.83 156,77 8.49 96,8 1819.59 171,07 8,53 130.00 -67.57 87,68 110,70 127.62 1,0~ 129.40 -77,70 99,88 126,55 127,68 0,43 128.60 -85.08 108,98 138.26 127,98 0.45 134+29 -97.52 123,16 157+09 128.37 1,11 136.79 -107,75 133.19 171.32 128,97 0,38 1927,84 2119,47 2196.00 2402.99 95.3 1913.90 104.41 7,60 ~5.6 2008,68 197.16 7,74 96.0 2103.80 210.11 7,77 76,5 2179,67 220+14 7,3O 207,0 2304.68 247,07 7,71 129.02 -116,87 131,24 -1~,09 122.63 -133.75 128.10 -t40,~S 126,52 -1~.63 142,93 104,63 129,27 1,50 152,68 197,38 129,33 0,34 162.32 210,32 129,49 0,20 169.~ 220,35 129,53 0.99 191,46 247.36 129,29 0,22 2489.® ~91.~ 86,0 2470,10 258.72 7,89 107.0 2576.08 273,41 7.68 95,8 2671,01 286.&2 7,99 lOS.O 2775.06 300.98 7.76 94.5 2&~8,69 313,~ 7.90 131,40 -163,97 200,53 259,03 133,08 -173,04 211,40 273,69 128,37 -182,46 221,42 127.74 -191,~ 232.75 301.30 126,47 -1~9.10 243.01 314,16 129.27 129,43 129.49 129,42 129,33 0.80 0,21 0.69 0.23 0.23 29~,29 3001,81 3177,39 3271,13 3368,02 3462,04 3559.42 365'3.~ 3749,53 3845.12 94.9 2962.72 326,62 7.71 95,5 3057,37 33%41 7.74 ~.6 3152,11 351.97 7.42 ~3.7 3245.04 264.27 7,69 96.9 3341.08 377,08 7.51 94.8 3435,09 389,~ 7,49 96,6 35...30.83 402.13 7,60 94,1 3624,~ 415,15 8,35 _ .. 96.0 3718.94 42'9',~ 8,93 95.6 3813.38 444.22 8,82 126,65 -206.77 127.54 -214,51 127,09 -222,15 130,85 -~;~'o91 130,63 -238,27 253,36 263.60 -273.62 283,19 292.90 131,~ _-246,41 302.~ 128,35 -254.55 311,94 127,43 -262;57 322,25 127,38 -271.33 333,70 128.53 -280.39 ~5.22 389.9~ 402,62 415,68 430.09 444.82 129,22 129.14 129,~ 129,13 129.19 129,22 12%17 129.11 129.08 0.20 0,13 0,34 0.60 0,18 0,14 0,46 -0.81 0.60 0,22 ~40.~ 4036,37 4131.21 4227.76 4323.35 95,7 3908,01 458,59 8+47 i5,5 4002,46 473,00 8,88 94.8 40%,21 487,32 8,51 96,6 4191.69 501,&4 8,5'7 95.6 4286.Zt 515,89 8,59 131,04 -289,b5' 356,38 459.20 133,33 -~,27 367°05 473,59 134.63 -309,22 377,36 487,87 131,48 -319,00 387,83 502.17 128,15 -328,12 3~8,78 516,42 129,10 129,19 129,33 12~,44 129,45 0,~ 0.% 0,44 0.4? 0.52' 4418,49 4512.00 4607.30 4703.12 4796,74 ~,1 4380,28 530,08 8,61 ~,5 4472,73 544,~ 8,68 f~,3 4566,96 558,33 8,53 95,8' 4661.74 572.38 -8,3~ 93.6 4754.39 585.77 127,54 -33~,85 410,02 . 530,65 t27,~ -345,46 421,13 544,70 131,01 -354,52 432,13 b'58,74 129.06 -363.57 442.89 573,01 131,54 -372,~2 453,11 .~,40 0.10 0,10 0.~ 0.35 0,47 MEASLREO INT~VAL VERTICAL OEPTH {)EPTH ft ft ft 4890.90 94.2 4847,63 4990,76 99.9 4946.52 5086.86 96.1 5041.68 5180.91 94.1 5134.79 52T7.63 96,7 5230,~ SEL'~ION I~LN, H/-S ft deg d~ ft 598.93 7.98 133.27 -381.10 612.78 7.99 128.46 -390.17 626.15 8,07 125.42 -398,23 639.34 8,13 126.79 -406,05 652.94 8,10 127.78 -414,32 i "Q-20 ~ATION ~ LATITUDE )EPAR~ DIBPIJ~iI~ENT at AZIPUII.I ft ft deg 462.83 5~.54 129.47 473.31 613.~ 129.~ . 484,04 626.~ 129.45 494.~ 640,04 129.9 505,61 653.68 129.33 DIS lOOft 0,29 0.67 0.45 0.22 0.15 5372.82 5468,60 5564.14 5656,55 57~1.% 95.2 5324,80 95,8 5419.65 95.5 5514.27 92,4 5605.81 95.4 5700.33 666.25 8.02 126.98 -422.42 67%46 7.92 1~,69 -430,47 692,65 7,97 128,62 -438.63 7~.29 7.81 126.7~ -446.38 718.20 7,82 126.49 -454.12 516.22 667,02 129.29 0.14 57.6,78' 680,29 12%26 0,15 537.16 693,49 129,23 0.14 547.19 706,17 12%21 0.33 557.60 719.12 129.16 0.03 .~7.46 5942.69 6037.98 6131.39 6227.05 95.5 5794.95 731.00 95,2 5889.29 743,71 95.3 5983,70 756,27 93,4 6076,27 768,47 95,7 6171,06 '781,00 7,79 120,36 -461,25 .%8.40 732,01 129.06 7.90 11%53 -467.74 579.67 744.84 . 128,90 7,65 118,45 -473,99 590,94 757,55 128,73 7,78 119,19 -480.03 601.93 769,90 128.57 7,64 i~,11 -486.38 613,08 782.57 128,43 0.87 0.16 0,30 0,17 0,20 6322,52 6417.25 6514,47 6607,02 6703,61 95,5 6265,69 793,38 94.7 6359,56 805.66 97,2 6455.89 818,47 92,5 6547.55 830.88 96,6 ~)43,17 844,O3 7.66 '"117.89 -492.53 7,~ 116,83 -498,37 · . 7,88 118,54 -504,52 7,98 t18.37 -510.60 8,2! 116.27 -516,84 624,19 795.11 128,?.8 0,31 635.47 807,59 128.11 048 647,17 820,59 127,94 0,27 6S8,40 83348 1Z7,79 0,12 670.48 846,~6 127,63 0,39 68(X),74 6896.05 6991,14 7084,37 7181.29 97,1 6739.~ 857,45 95.3 6833,54 871,06 95,1 6927,54 884.97 93,2 7019,71 898,68 96,9 7115,51 912,85 8,34 115,55 -522,94 8,75 116,19 -529,13 8,&6 118,30 -535,71 8,73 11%02 -~2,47 8,54 118,55 -549,48 _683,05 860.25 127,44 695,80 874,14 127,Z~ 708,60 .? 888.31 127.09 720.97 902.26 126,96 733,72 916,66 126,&3 048 0,44 0,35 0,14 0,21 7276.74 7373,65 746941 7565,75 7660,18 95;5 96,9 7305,80 95.5 7400,24 96,6 7495.83 94,4 7589,22 926,52 ' 940.30 953.84 967,67 981,28 8.40 118,74 -556,22 8,36 120,13 -563.16 8,39 11840 -569,92 8,53 119.09 -576,73 8,48 11%05 -583.51 746,06 930.58 126,71 0,14 758.35 944,59 1~,~0 0,21 -770.49 958.37 126.49 0,31 782,97 972,45 126,Z7 0,21 795.18 986,31 126,27 0,05 7753,17 7847,21 7942,73 0037,56 8131.80 93,0 7681,17 994,72 94,0 7774,16 i008,26 ~,5 78~.65 1021,91 94,8 7962,46 10~,38 94,2 805'5,68 1048,83 8,65 117.09 -5~0,03 8,46 117,89 -596,49 8,45 118,~ -603,18 8,37 117,57 -609,75 -8,51 119.55 -616.36 807,40 1000,02 126.16 819,82 1013,86 126.04 832,17 1027.78 125,94 844,38 1041,52 125.83 856,53 1055.24 '- 125,74 0.37 0,24 0,17 0,23 0,34 827_7,68 8~,13 8419,75 8515,20 8611,M 95,9 8150,51 1062.56 94,5 8243,96 1075,96 97,6 8340,55 1089,8i 95,5 84~.00 1103,30 96,2 8530,25 1116,74 8.41 118~91 -623,20 868.86 1069.25 125,65 8,32 120,15 -629,93 880.83 1082.90 t25.57 8,36 11%86 -637,01 893,1d 1097,00 125,50 8,25 120,~9 -643,92 90%03 1110,73 125,43 8.17 119,99 -650,82 916,91 1124,41 0,19.. 0,27 0.06 0,14 0,09 I~AGE ~, 4 D£PTH ft ft ft ~704.7~ 93.3 8622.63 8~1.69 96.9 ~71~.63 6~96.18 94.5 8~12.14 9016,27 120,1 8930.96 9049.~ 33.3 ~963.91 SURVEY ~J~J3UI.ATIONS ,)ew~ CIRCULAR ARC TARGET ~ATI~ S~I~ ~. W-S ~/-W ft ~ ~ ft ft 11~,~ 8,10 119,03 -6~.~ ~.~ 1142,74 7,~ 116,75 .-~,~ 9~,19 11~.~ 8.~ 117,12 -~0.14 ~2,11 '1172,~9 8,15 1~,~ -~,~ 9~.~ LATITUDE D~T~E DI~LACE~ENT at ft 1137,~4 11~0,92 1164.30 I181,53 1186.16 AZIMUTH de~ 125,30 125,22 125,14 125,01 124,97 lOOft 0,16 0.25 0,78 0,42 0.54 9152,15 102.6 9065.51 1190.~ 7.98 116,86 -686,25 964,80 9247.02 94.9 9159,47 1203.41 7.84 114,79 -691,94 996,55 9341,11 94,1 9252.70 1215,56 7,69 115,12 -697,30 1008,07 . . . _ 9442.32 101,2 9353,04 122B,17 7,34 113,34 -702,74 1020,14 9~,96 94,6 9446,91 123~,67 7,33 115,18 -707,70. 1031,16 1213;'21 122~,74 1238,76 1250,65 124,B7 124,77 124.67 124,56 124.46 0,11 0.34 0,16 0.41 0.25 9633,31 96,3 9542,50 1251,24 7,05 115,98 -712,91 1042,(M 1262,b'7 124,38 0,30. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 3 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 3/Q-20 MPI 1-53/Q-20 MPI DESCRIPTION 1 COLLAR/PERF FINAL BL 1 COLLAR/PERF RF SEPIA 1 DTEMP/CCL FINAL BL 1 DTEMP/CCL RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6276.02 6276.01 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 September 1994 RE: , Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-19/R-28 SDI 1-53/Q-20 MPI DESCRIPTION 1 PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA TEMP/PRES FINAL BL GR/CCL FINAL BL P/PRES RF SEPIA GR/CCL RF SEPIA ECC No. Run # 1 5709.03 Run # 1 Run # 1 Run # 1 6185.07 Run # 1 6217.06 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6276.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 /1 Anchorage, AK 99518 ~ At~/~_ ey D. Paulson Received by/ /~ /~// / /~~ Date: STATE OF ALASKA AIJ-,SKA OIL AND GAS CONSERVATION COMMISS~L,N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend X Operation Shutdown__ Re-enter suspended well__ Alter casing ~ Repair well __ Plugging ~ Time extension __ Stimulate __ Change approved program__ Pull tubing_ Variance__ Perforate Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3108'NSL, 2185' WEL, SEC. 36, 12N, R16E At top of productive interval At effective depth At total depth 2387'NSL, 1131'WEL, SEC. 36, T12N, R16E 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE=56 7. Unit or Property name Duck/s/and Unit/Endicott 8. Well number 1-53/Q -20 9. Permit number 94-112 10. APl number 50- 029-22501 11. Field/Pool Endicott Field/Endicott Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 90' Surface 2700' Intermediate Production Liner Perforation depth: measured None 9740 feet Plugs (measured) 9650 feet feet Junk (measured) feet Size Cemented 30" Driven 10-3/4" 617 sx PF "E"/375 sx "G" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Measured cl~ Tr u/~/~/~rtical depth 130' 130' 2743' 2723' RECEIVED S EP 2 7 ]994 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 9/27/94 16. If proposal was verbally approved Name of approver B. Wondzell 9/26/94 Date approved 15. Status of well classification as: Oil × Gas~ Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~t.~¢ ~'~ Title Drilling En,gineer Supervisor FOR COMMISSION USE ONLY Date ~-Z¢ I/¢ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance~ Mechanical Integrity Test ~ Subsequent form required 10- q, 6)'7' Approved by order of the Commission Original Signed By David W. ,lr)hn.~tnn Form 10-403 Rev 06/15/88 IApproval No.~, (¢ ' 7. 7 ~ Commissioner Approved Copy Returned SUBMIT/IN T~IPI'ICATE Suspension Request Endicott well 1-53/Q-20 As a result of the well control incident of 9/24/94, we request this well to be suspended while further evaluation may be conducted. A waiver is requested to allow the use of a retrievable bridge plug in lieu of a surface plug in accordance with the attached procedure. The retrievable bridge plug would facilitate reentry and provide reuse of the surface casing and well slot which are limited at the Main Production Island at Endicott. SEP 27 Gas Cons. Commission Anchorage 1-53/Q-20 Suspension procedures PLEASE FOLLOW THE FOLLOWING STEPS' 1. R/U Halliburton. Test lines to 3000 psi. Pump bottom cement plug as follows: a. 5 bbls of NSC1 spacer mixed at 11.5 ppg 11 bbls of cement slurry mixed at 15.8 ppg followed with 5" wiper dart. 8 bbls of spacer NSC1 mixed at 11.5 ppg Displace dart to @ 9480' MD as per enclosed clia~am. Calculated displacement volume is 147.5 bbls. Close in on surface. Do not bleed off pressure. WOC for 4 hfs only if there is back flow. . RAJ Arias E-Line. a. Test lubricator to 3000 psi. bo Pressure test cement plug inside the drill pipe to 1000 psi. ( Note: This test needs to be witnessed by AOGCC representative ) c. P/U and RIH with 2" severing tool. d. IH with 2" severing tool to @ 8641'MD ( @ f'u'st full joint of HWDP ) eo Sever 5" HWDP. Record pressures on DP accurately. Bleed off pressure very slowly and record flow back volume. Monitor situation. POOH with wireline. R/D lubricator. f. Latch elevators on pipe and attempt to work string. ( Alternatively screw in top drive if easier for pump capability ). Do not pull more then 500K on the weight indicator and do not attempt to rotate drill pipe. NOTE: If the pipe is freed after the sever the plugs will be laid balanced and if it is not the plugs will be squeezed. RECEIVED SEP 2 7 1994 Alaska Oil & Gas Cons. Commissior,' Anchor~!?. o Have Halliburton to pump the second plug as follows: a. 20 bbls of NSC1 spacer mixed at 11.5 ppg b, 44 bbls of cement slurry mixed at 15.8 ppg with the following additives' .4% Halad 344 /.2% CFR-2 /.3% HR-5 / @ 1.15 cuft/sk / 5.0 gal of water/sk / 3 hrs thickening time at the water loss of 60. c. 5 bbls of spacer NSC1 mixed at 11.5 ppg followed with 5" wiper dart. Displace slurry with 138 bbls, ( including 131 bbls of 10.5 mud, 5 bbls of spacer and 2 bbls of 'test' water ) by using displace and hold method. Do not attempt to build squeeze pressure. Hold pressure for 4 hrs. ( Be aware of any possible surface leaks ) Top of slurry should be @ 8070' and bottom should be @ 8570' MD. . o . R/U Atlas E-Line. a. Test lubricator to 3000 psi. b. P/U and RIH with 2" severing tool. Tag top of cement plug inside of DP. c. Position 2" severing tool @ 6600' Sever 5" DP. Record pressures on DP accurately. Bleed off pressure very slowly and record flow back volume. Monitor situation. POOH with wireline. R/D lubricator. e, Latch elevators on pipe and attempt to work string. ( Alternatively screw in top drive if easier for pump capability ) NOTE: If the pipe is freed after the sever the plugs will be laid balanced and if it is not the plugs will be squeezed. RECEIVED Have Halliburton to pump the third plug as follows: a. SEP 2 7 1996 20 bbls of NSC1 spacer mixed at 11.5 ppg Aiaska 0it & Gas Cons. Commission Anch0raue 109 bbls of cement slurry mixed at 15.8 ppg with the following additives: .4% Halad 344 /.2% CFR-2 /.3% HR-5 / @ 1.15 cuft/sk / 5.0 gal of water/sk / 3 hrs thickning time at the water loss of 60. c. 5 bbls of spacer NSC1 mixed at 11.5 ppg followed with 5" wiper dart. Displace slurry with 92 bbls of mud by using displace and hold method. Do not attempt to build squeeze pressure. Hold pressure for 4 hrs. Top of the slurry should. be @ 5350' MD and the bottom of the slurry should be @ 6600' MD. R/U free piont. RIH and tag top of third plug. Determine stuck point. ( We are going to assume that the drill pipe is stuck @ 10-3/4" shoe which is @ 2743' MD. . Cut 5" drill pipe at @ 100' below 10-3/4" shoe. Cut should be made within the drill pipe tool joint. Just before severing work in left hand torque to 50% of the original M/U torque. This is to ensure backoff in case that severing tool does not work. Be aware of any U-Tubing. Gas also may be trapped below shoe. 8. Break circulation. Attempt to recover DP to sever ( backedoff ) point. . If the drill pipe is not recovered RIH with string shot and back it off based on where the free point was found. ( make sure that it is backed off inside of 10-3/4" csg where it is easier to fish ) Note: Fishing program will be discussed and reviewed prior to commencing of fishing operations. 10. P/U and RIH with 10-3/4" EZSV on 5" DP. Set EZSV @ 2668' MD which is @ 75' above the 10-3/4" shoe @ 2743' MD. P/U off of EZSV and test 10-3/4" csg and EZSV to 1000 psi. After the pressure test please follow the folowing steps: a. Sting into the EZSV and establish injection rate. bo Pump either 1000 sks ( 204 bbls ) of cement slurry with the following additives: .4% Halad 344 /.2% CFR-2 /.3% HR-5 / @ 1.15 cuft/sk / 5.0 gal of water/sk / 3 hfs thickning time at the water loss of 60, or until the slurry is observed back to surface. Co If no returns are observed to surface attempt to build squeeze final pressure by using hesitation method. NOTE' Consider shutting down if there are any signs of flow around the adjacent well conductors. d, Unsting from EZSV and spot balanced cement plug to @ 200' on the top of EZSV. 11 12. POOH and L/D 5" DP to @ 2000'. Reverse circulate hole clean. Re-test casing to 1000 psi. Displace well to diesel for F/P purposes.~.PQ~)H.. .. RIH and set RBP @ 100' below ground level. Spot 10' of sand on the top of RBP. 13. N/D BOP as Well as tbg spool. N/U 13-5/8" 5M dry hole flange and valve. Test to 1000 psi. Release rig. Note: Obtain AOGCC waiver for top surface plug. RECEIVED S EP 2 7 1994 Alaska Oil & Gas Cons. Commission Anchoraue 1-53/Q-20 ABANDONMENT DIAGRAM _9/25/94 - O0:40h rs Set EZSV retainer @ 2668' 2nd cut in 5" DP is @ 6600' MD Cut above HWDP @ 8586" Bit at @ 9702' TD @ 9740' . RBP @ 1 00' w/1 0' sand Cement above EZSV 2468'- 2668' 10 3/4" casing shoe @ 2743' RECEIVED Ai~ska 0il & Gas Cons. (;ommission 5350' Anchora:.~e ~ Cretaceous plug Set in 2 stages 6600' 8070' MD 857O' MD 2nd Cmt plug Bak~rr N1 plug @ 8595' MD (just inside of HWDP ) Top of drill collars @ 94:81' MD Bottom Cmt plug 9702' - 9502' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston,~q~._~ DATE: Chairma~ THRU: Blair Wondzell, ~'~.~ FILE NO: P. I. Supervisor ~'~]~.~),~ FROM: Bobby Fost~'~ .~,,~ SUBJECT: Petroleum Insl~ector September 22, 1994 GKHIIVBD.doc Investigation - Gas Kick BPX - DIU - MPI - 1-53/Q-20 Endicott Field T..h..ursdaY, September 22, 1994: ! traveled this date to Prudhoe Bay and at 9:30 AM I received a phone call at the AOGCC office from Blair Wondzell informing me that BPX had a well problem at the Endicott Field and directed me to go to the location and investigate the problem. ! went to the Endicott drilling office and met with Steve Walls and James Carlies, both PBD drilling foreman. Steve informed James and I, whom arrived when I did, at approximately 10:40 AM, that the previous night at about 7:00 PM as the drill crew started to come out of the hole to change bottom hole assembly, they noticed that the well was flowing on the fourth stand. The crew was instructed by the toolpusher to go back to bottom, which they did. While going back to bottom, they gained 25bbls. of mud in the pits. The annular preventer was closed and the well was shut-in. The casing pressure was 200psig and the DP pressure was 0 psig. Steve told the. crew to bleed a couple of barrels of mud from the casing and record the pressure.~Steve arrived at the rig and the toolpusher told him that they had bled of 2 bbls. o~the casing and the pressure was at 400psig and climbing very quickly. The pressure rose to between 1100 and 1200psig. Then mud, gas and water began to blow out around the 10.750" casing. The crew put on their gas mask and went under the floor to tie the line from the rig choke manifold into the producing well next to them since the rig degasser would not handle the large amount of gas. After making the tie-in, the flow was diverted to the production faculities. The crew then tied another valve off the casing into another well's flow line and opened the casing up thru the production choke to the production faculities test seperator. The casing pressure stayed at 1140 psig with both chokes fully open. Steve said the well was producing between 8-10 mm/cu/ft of gas and 8-10 thousand bbls. of mud and water. This was the conditions at the time arrived on location. I contacted Blair Wondzell, PI Supervisor, and reported to him what I knew. I left the location to take care of another job and was gone 3 hours. When I got back to the location, I received a call from Blair instructing me to stay on location as much as I deemed necessary and to keep him informed as to plans and progress. Friday, September 23., 1994: BPX drilling reps. arrived on location and began setting up the Incident Command Control center. Equipment began arriv)~ing on the location, joining the cementing equipment already on location. Two other rigs stopped their operations and began mixing 10.51b/gal mud to be used in the Dynamic kill operation. The adjacent wells were being mointered as they had been since gas began escap¢ing around the casing on Q-20. All the wells in rows 1 and 2 were checked every hour all during the complete operation. Attached to this report is some of the data gathered and is marked as CELLER DATA. Water and gas bubbles were noted in 5 of the hereby cellers, includ¢ing one with only the conductor pipe set. At 10:00PM, I spoke with Steve Horton, drilling manager, about evacuating the island. He told me that all non-essential personal had been removed and that I should also leave. Since I could be of no help, agreed with him, but I would stay on the roadway close to the MPi, which I did, approximately with-in 200 yards. By midnight, the crews were all in place with all personal equipped with radios and safety equipment. They then went through a "mock" kill procedure until everyone was sure of his job when the real operation began. Saturday, September 24, 1994: At 6:00AM they began pumping mud down the drill pipe and bleeding the casing as fast as possible. About half way through the operation one of the dump lines in the faculity began to stop up. The crews made a change and began dumping the TRICO Seperator out through a 3" line previously laid in case this happened, to a pit which had been dug on the island. A short time later the line in the faculity was cleared and the dump line was closed. The casing pressure began to decrease and after pumping approximately 1600 bbls. of 10.5 lbs./gal mud ( BJ pump rates are attached to this report marked pump rates) the casing was beginning to pack off at the casing shoe. Another 230 bbls. of mud was pumped and by 10:30 AM the well was dead. Ail of the gas, mud and water had ceased to appear in all the well cellars except for three, and they were very weak. Sunday, September 25, 1994: Beginning plug and abandonment operations. The bottom cement plug, consisting of 11 bbls. of class G cement, was pumped down the DP leaving the TOC at 9,520'. The DP depth was at 9,702'. After waiting on cement for 4 hours, the cement was tagged using sinker bars on the wire line. At this time an attempt was made to run 3" a CIBP with the wire line unit. Due to a stabilizer up hole having a smaller ID than the plug this could not be accomplished. It was then decided to run an inflatable packer and set it in the DP. After getting the packer in the hole, it failed to set due to the viscous fluid in the DP. The packer was pulled out and the bottom plug was pressure tested to 1,000psig With my approval. The pressure held for 30 minutes with no bleed off. A 2" severing tool was then run to 8,541' ELM ( 8,570 MD) and the DP was cut off. An attempt was made to free the DP by pulling 500,000 pounds on it. The DP was still not free. Another cement plug, consisting of 44 bbls. of 15.8lbs./gal. class G cement, was placed from 8,579' to 8,070' MD. WOC four hours and tagged same with wire line tools. Tagged OK. The DP was again severed at 6,600'MD and a cement plug consisting of 109 bbls. of 15.8 lbs./gal, was placed from 6,600' to 5,350'. WOC four hours. This plug was tagged approximately 60' Iow, which still gave good coverage. A "free point" was then run and the DP was found to be free at 2,541'. The DP was cut at 2,972' and a cement slurry consisting of 1,500 sacks of Type "C" Permafrost (252bbls.) at 15.6lbs./gal. was pumped into the formation leaving the TOC 100' below the free point of the DP at 2,541'. in the last stages of this operation the pump rate was slowed down and a final injection pressure of 500 psig was left on the DP. This pressure bleed to 200 psig in approximately 20 minutes and seemed to stabilize. The DP was then backed off at 2,541' and was pulled out of the hole. The DP had to be pumped out of the hole due to the sand and clay on the wall of the casing. After getting the DP out of the hole a bit and scraper was run in to clean up the casing. After the casing was cleaned up and the hole circulated good a perforating gun was run in the casing and the casing was perforated at 2,515'. A EZ Drill cement retainer was run on the DP and set at 2,485'. After setting the retainer and unstinging from it, the casing was pressure tested to 1,000 psig for 30 minutes. Test OK. The setting tool was then stung in and 150 sks. (25 bbls.) Type "C" permafrost cement was squeezed in to the formation. The DP was unstung from the retainer and 50 sks. (9 bbls.) was placed on top of the retainer. I departed the location at this time. The BP rep. told me that another retainer would be set at 300' and 89 sks. (15 bbls.) of cement would be placed on top of it and from 125' to surface would be water and a dry hole tree would be placed on the casing. Summary: I investigated the "gas kick" situation at BPX's Endicott well 1-53/Q-20 and the plug and abandonment of same. Attachment: BJ SERVICES TREATMENT REPORT Ticket No. Date L~ ~ -) Company /~j'~/ Lease E ~t~ County/Parish Loc at i on District Format ion / Rig Weii No. /-~ ~ State /~/( Field Job Type I'~ ~ ~ \ WELL DATA: Total Tubing: Size Depth Casing: Size Depth Liner: Size Depth Annul us: Size Depth Capacity Total: Packer Type: Bridge Plug Type: Depth/P1 ugbac k Weight Weight Weight Weight Factor Vol ume Factor Vol ume Factor Vol ume Factor Vol ume bplf bplf bplf bplf Set At Set At PERFORATIONS ZONE I SIZE I SPF FROM ', TO I FROM TREATMENT INSTRUCTIONS TREAT DOWN TBG. ANNULUS I PRESSURE LIMIT TBG. & I TBG PSI CSG ANNULUS I CSG PSI MATERIALS AND CONCENTRATION COMPANY REPRESENTATIVE TREATER AVG PRESS PSI MAX PRESS PSI AUG RATF ;]PM lAW RATF ;]PM MAX DATF ;)PM DATE: 24-SEP-94 CUSTOMEF.'.: BP X RIG/WELL: F-iD S E Fi.: V :[ (-: E F':(] M F' A I,,I Y: B J ~T El B T I IE:K E l: 00"$ 9 8 4 SEI('.V I TIME: 05: 15:28 C!JSTOME-F..: REF': K. SM]lIN JOB TYF'E : DATA FEiAC SEI;.iVICE REP: J. ~z:UI_F'EF'F'I!-_-1.-4'. TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 05:15:28 313 ~TAF..T JOB 05:16:13 304 05:16:58 1596 05:17:43 2194 05:18:28 3232 05:19:13 4143 05:19:59 4848 05:20:44 5122 05:21:29 5093 05:22:14 5064 05:22:59 5034 05:23:44 5015 05:24:29 5005 05:25:14 4995 05:25:59 4985 05:26:44 4976 05:27:29 4'966 05:28:15 4956 05:'29:00 3105 05:29:45 754 05:30:30 774 05:21:15 774 05:~;.~°' 00.. 764 ~.,J 744 05:33:30 7~ 05:34:15 725 o5:35:o0 7~ (;5:35:45 725 o5:36:30 7,~ 05:37:16 715 05;38:01 705 05:38:46 705 05:39:31 695 05:40:16 695 05:41:02 686 05:41:47 676 05:42:~ 676 05:43:17 666 05:43:~ ~ 666 0.0 50.8 50.8 0.0 0 0.0 -1.0 0.0 50.8 50.8 0.0 0 0.8 0.1 50.9 50.9 0.0 0 1.5 0.0 50.9 50.9 0.0 0 2.3 0,0 50.9 50,9 0,0 0 3,0 0.0 50.9 50,9 0.0 0 3,8 0.0 50,9 50,9 0,0 0 4,5 0.0 50.9 50.9 0.0 0 5.2 0.0 50,9 50,9 0,0 0 6.0 0,0 50,9 50.9 0.0 0 6.7 O. 0 50.9 50.9 O, 0 0 7.5 0.0 50,9 50,9 0.0 -10 8.2 0.0 50.9 50.9 0.0 0 9.0 0,0 50.9 50.9 0,0 0 9.7 0,0 50.9 50,9 0.0 0 10,5 0.0 50.9 50.9 0.0 0 11.2 0.0 50,9 50,9 0,0 0 12.0 0.0 50.9 50.9 0.0 0 12.7 0.0 50,9 50.9 0,0 0 13.5 0.0 50.9 50.9 0.0 -10 14.2 O. 0 50,9 50,9 O, 0 0 15.0 0.0 50.9 50.9 0,0 0 15.7 0,0 50.9 50.9 0.0 0 16.5 O. 0 50, 9 50,9 O. 0 0 17.2 O. 0 50,9 50.9 O. 0 -10 18.0 0.0 50,9 50.9 0.0 -I0 18.7 0.0 50.9 50.9 0.0 1047 19.5 0.0 50.9 50.9 0.0 999 20.2 0.0 50.9 50.9 0.0 999 21.0 0.0 50.9 50.9 0.0 989 21.7 O, 0 50.9 50, 9 0.0 999 22,5 0.0 50.9 50.9 0.0 999 23.2 0.0 50.9 50.9 0.0 999 24.0 0.0 50.9 50.9 0.0 1018 24.7 0.0 50.9 50.9 0.0 1028 25.5 O. 0 50.9 50.9 O. 0 1028 26.2 O. 0 50.9 50.9 O. 0 1028 27.0 0.0 50.9 50.9 0.0 1028 27.7 0.0 50.9 0,0 0.0 1028 28.4 -i.0 -1.0 -I.0 -I.0 -1.0 -I.0 -1.0 -1.0 -1.0 -1.0 -i.0 -1.0 -1,0 -1.0 -1.0 -I, o -1.0 -1.0 -1.0 -1.0 -I.0 -1.0 -1.0 -1.0 -1,0 -1.0 -1.0 -I.0 -1.0 -I,0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 F. iESET STA~BES DATE: 24-SEP-94 CUSTOMER: BP X RIG/WELL: F-19 SERVIE:E COMF'ANY: BJ JOB TICKET: 004984 SERV ICES TIME: O5:43:56 CUSTOMER REF': K.SMITH JOB TYPE : DATA FRAC SERVICE REF': J.CULF'EF'PER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 05:43:56 666 RESET TOTAL 05:44:41 656 05:45:26 656 05:46:11 646 05:46:56 646 05:47:42 637 05:48:27 637 05:49:12 39 05:49:57 29 05:50:42 29 05:51:27 29 05:52:12 59 05:52:57 39 05:53:42 39 05:54:27 39 05:55:13 49 05:55:58 49 05:56:43 39 05:57:28 49 05:58:13 39 05:58:58 39 05:59:43 39 06:00:28 39 06:01:13 39 06:01:58 69 06:02:44 69 06:03:29 78 06:04:14 69 06:04:59 78 06:05:44 78 06:06:29 78 06:07:14 176 06:07:59 98 06:08:44 98 06:09:29 98 06:10:15 108 06:11:00 98 06:11:45 98 06:12:30 98 06:13:15 235 06:14:00 460 O. 0 O. 0 O. 0 O. 0 1028 28.4 - 1.0 0.0 0.0 0.0 0.0 1028 29.1 0.0 0.0 0.0 0.0 1038 29.9 0,0 0,0 0,0 0,0 1047 30.6 0.0 0,0 0.0 0.0 1047 31.4 0.0 0,0 0.0 0.0 1057 32.1 0.0 0.0 0.0 0.0 1057 32.9 O. 0 O. 0 O. 0 0.0 I(.')67 33.6 0.0 0.2 0.2 0.0 1067 34,4 3.4 1.3 1.3 0.0 1067 35.1 0.0 2.8 2.8 0.0 1067 35.9 10.2 7.9 7.9 0.0 1067 36.6 6.0 13.4 13.4 0.0 1057 37.4 5.7 17,8 17.8 0.0 1057 38. 5.6 22.0 22.0 0.0 1047 38.8 5.4 ,.6. ~. 26.2 O. 0 I(])38 39.6 5.4 30.3 30.3 O. 0 1008 40.3 5.4 34.4 34.4 0.0 979 41. i 5.5 38.6 38.6 0.0 ')59 41.8 5.5 42.7 42.7 0.0 950 42.6 5.4 46.8 46.8 O. 0 930 43.3 5.5 50.9 50.9 0.0 910 44.1 5.4 55.0 55.0 O. 0 891 44.8 5.4 59.1 59.1 0.0 871 45.6 8.5 65.0 65.0 0.0 871 46.3 8.7 71.4 71.4 0.0 861 47.1 9,7 78.6 78.6 0.0 861 47.8 9.8 86.0 86.0 O. 0 842 48.6 10.2 93.6 93, 6 O. 0 852 49.3 10.0 101.3 101.3 0.0 B52 50.1 10.2 108.9 108.9 0.0 852 50.8 12.1 117.3 117.3 0.0 852 51.6 12.8 126.8 126.8 0.0 861 ~'~ · J~., 3 12.9 136.5 136.5 0.0 861 53.1 12.9 146.2 146.2 0.0 861 53.8 12.9 155.9 155.9 0.0 871 54.6 12.'Q_ 165.6 165.6 0.0 881 ~.~ 3 12.9 175.3 175.3 0.0 881 56.1 13.0 185.0 185,0 0.0 881 56.8 12.7 194.7 194.7 0.0 891 57.6 12.7 204.3 204.3 O. 0 901 58.3 -I,0 -I.0 -1.0 -I.0 -I.0 -I.0 -1.0 -I.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -i.0 -I.0 -1,0 -1 0 -1 0 -1 0 -1 0 -i 0 -1 0 -1 0 -1 0 -1 0 -1.0 -1.0 -1.0 -1.0 -I,0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 DATE: 24--SEP-94 CUSTOMEE'.: BP X ~iIG/WELL: F-19 SEE'.VICE COMF'ANY: BJ JOB TICKET: 00,4984 SERV ICES TIME: (:)6:1,4:45 CUSTOMER REF': K.SMITH JOB TYPE : DATA FRAC SERVICE REP: J.CULF'EPF'EF~i 06:14:46 284 06:!5:31 411 06:16:16 881 06:17:01 1048 06:17:46 1430 06:18:31 1469 06:19:17 1528 06:20:02 1557 06:20:47 1557 06:21:32 1567 06:22:17 1577 06:23:02 1606 06:23:47 1636 06:24:32 1665 06:25:17 1685 06:26:02 1704 06:26:47 1724 06:27:33 1724 06:28:18 1743 06:29:03 1753 06:29:48 1773 06:30:33 1802 06:31:18 1792 06:32:03 1802 06:32:48 1802 06:33:34 1792 06:34:19 1792 06:35:04 1802 06:35:49 1812 06:36:34 1822 06:37:19 1812 06:38:04 1802 06:38:49 1812 06:39:34 1802 06:40:19 1792 06:41:04 1783 06:41:50 1802 06:42:35 1802 06:43:20 1812 06:44:05 1822 06:44:50 1812 06:45:35 1822 06:46:20 1832 06:47:05 1861 11.6 213.4 213.4 0.0 910 59.1 -1.0 12.2 222.4 222.4 0.0 910 59.8 -1.0 14.4 232.1 232.1 0.0 920 60.6 -1.0 14.4 243.0 243.0 0.0 920 61.3 -1.0 15.7 254.7 254.7 0.0 940 62.1 -1.0 15.7 266.6 266.6 0.0 940 62.8 -1.0 15.6 278.4 278.4 0.0 950 63.6 -I.0 15.6 290.2 290.2 0.0 950 64.3 -1.0 15.7 301.9 301.9 0.0 950 65.1 -1.0 15.7 313.6 313.6 0.0 959 65.8 -1.0 15.6 325.5 325.5 0.0 959 66.6 -1.0 15.7 337.2 337.2 0.0 959 67.3 -1.0 15.6 349.0 349.0 0.0 959 68.1 -I.0 15.7 360.8 360.8 0.0 969 68.8 -1.0 15.6 372.6 372.6 0.0 969 69.6 -1.0 15.7 384.4 384.4 0.0 969 70.3 -1.0 15.7 396.1 396.1 0.0 969 71.1 -1.0 15.6 407.9 407.9 0.0 979 71.8 -1.0 15.7 419.6 419.6 0.0 969 72.6 -1.0 15.7 431.5 431.5 0.0 979 73.3 -1.0 15.7 443.2 443.2 0.0 969 74.1 -1.0 15.6 455.0 455.0 0.0 979 74.8 -I.0 15.6 466.9 466.9 0.0 969 75.6 -1.0 15.7 478.7 478.7 0.0 969 76.3 -1.0 15.7 490.4 490.4 0.0 969 77.1 -I.0 15.6 502.2 502.2 0.0 969 77.8 -I.0 15.7 514.0 514.0 0.0 959 78.6 -I.0 15.6 525.8 525.8 0.0 959 79.3 -1.0 15.7 537.6 537.6 0.0 950 80.1 -1.0 15.7 549.4 549,4 0.0 950 80.8 -1.0 15.7 561.2 581.2 0.0 950 81.6 -1.0 15.8 573.0 573.0 0.0 950 82.3 -1.0 15.7 584.8 584.8 0.0 940 83.1 -1.0 15.7 596.6 596.6 0.0 940 83.8 -1.0 15.7 608.5 608.5 0.0 930 84.6 -1.0 15.7 620.2 620.2 0.0 920 85.3 -1.0 15.7 632.1 632.1 0.0 910 86.1 -I.0 15.7 643.8 643.8 0.0 910 86.8 -1.0 15.7 655.7 655.7 0.0 901 87.6 -1.0 15.7 667.4 667.4 0.0 891 88.3 -1.0 15.7 679.2 679.2 0.0 891 89.1 -i.0 15.7 691.0 691.0 0.0 881 89.8 -I.0 15.7 702.8 702.8 0.0 881 90.5 -i,0 15.7 714.7 714.7 0.0 881 91.3 -1.0 TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES 88L/MIN DATE: 24-SEP-94 RUSTOMER: BPX RIA/WELL: F-19 SERVICE COMPANY: BJ JOB TICKET: 004984 SERV ICES TIME: 06:47:50 CUSTOMER REP: K.SMITH JOB TYPE : DATA FRAe: SERVICE REF': J. CUI_F'EF'F'ER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 06:47:50 1871 06:48:35 1881 06:49:20 1881 06:50:06 1048 06:50:51 1038 06:51:36 1038 06:52:21 1038 06:53:06 1048 06:53:51 1048 06:54:36 1058 06:55:21 1058 06:56:06 1058 06:56:52 1058 06:57:37 1058 06:58:22 1068 06:59:07 1077 06:59:52 1077 07:00:37 1087 07:01:22 1087 07:02:07 1087 07:02:52 744 07:03:37 715 07:04:22 715 07:05:08 715 07:05:53 725 07:06:38 725 07:07:23 735 07:08:08 627 07:08:53 627 07:09:38 637 07:10:23 637 07:1!:09 646 07:11:54 646 07:12:39 656 07:13:24 666 07:14:09 676 07:14:54 686 07:15:40 705 07:16:25 715 07:17:10 725 07:17:55 725 07:18:40 735 07:19:25 735 07:20:10 744 15.7 726.4 726.4 0.0 871 92.0 -1.0 15,7 738.3 738,3 0.0 861 92,8 -1.0 15.7 750.1 750.1 0.0 87! 93.5 -1.0 12.4 759.8 759.8 0.0 861 94.3 -1.0 12.4 769.1 769.1 0.0 861 95.0 -1.0 12.4 778.4 778.4 0.0 861 95.8 -I.0 12.4 787.7 787.7 0.0 852 96.5 -1.0 12.3 797.0 797.0 0.0 842 97.3 -1.0 12.4 806.3 806.3 0.0 832 98.0 -I.0 12.4 815.6 815.6 0.0 832 98,8 -1.(I 12.3 824.8 824.8 0.0 813 99.5 -1.0 12.4 834.0 834.0 0,0 813 100.3 -1.0 12,3 843,3 843,3 0.0 803 101.0 -1.0 12.3 852.5 852.5 0.0 803 101.8 -1.0 12.2 861.8 861.8 0.0 793 102.5 -1.0 12.3 871.1 871.1 0.0 793 103.3 -1.0 12.4 880.3 880.3 0.0 783 104.0 -1.0 12.4 889.6 889.6 0.0 773 104.8 -1.0 12.3 898.8 898.8 0.0 754 105.5 -1.0 12.3 908.0 908.0 0.0 734 106.3 -I.0 i0.8 916.7 916.7 0,0 715 107.0 -1,0 10.7 924.8 924.8 0.0 685 107,8 -1,0 10.7 932.8 932.8 0.0 656 108.5 -1.0 10.7 940.9 940.9 0.0 636 109.3 -1.0 10.7 948.9 948.9 0.0 587 110.0 -1.0 10.7 956.9 956.9 0.0 578 110.8 -1.0 10.7 964.9 964.9 0.0 568 111.5 -1.0 10.1 972.7 972.7 0.0 529 112.3 -1.0 10.1 980.3 980.3 0.0 509 113.0 -I.0 10. I 987.9 987.9 0.0 480 113.8 -!.0 10.2 995.5 995.5 0.0 470 114.5 -1.0 10.0 1003.1 1003, I 0,0 450 115.3 -1.0 10.1 1010.7 1010.7 0.0 431 116.0 -1.0 10,2 1018.3 1018.3 0.0 421 116.8 -1.0 I0.1 1025.9 1025.9 0.0 401 117.5 -1.0 10.0 1033,4 1033.4 0,0 392 118.3 -1.0 10.0 1041.0 1041,0 0.0 372 119.0 -1.0 10. I 1048.5 1048,5 0.0 343 119.8 -1.0 iO,O 1056.2 1056.2 0.0 323 120.5 -i.O 10.0 1063.6 1063.6 0.0 294 121.3 -1.0 I0.0 1071.2 1071.2 0.0 255 1~ o -1.0 9.9 1078.7 1078.7 0,0 215 122.8 -1.0 10.0 1086.2 1086.2 0.0 196 123.5 -1.0 9.9 1093.6 1093.6 0.0 166 124.3 -1.0 DATE: 24-SEP-94 CUSTOMER: BPX RIG/WELL: F-19 SERVICE COMPANY: BJ JOB TICKET: 004984 SERV ICES TIME: 07:20:55 CUSTOMER REP: K. SMITH JOB TYPE : DATA FRAC SERVIE:E F.:EF': J. r-:ULF'EI--'F'EF.'. TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 07:20:55 764 07:21:40 774 07:22:25 784 07:23:11 784 07:23:56 803 07:24:41 813 07:25:26 823 07:26:11 852 07:26:56 862 07:27:41 872 07:28:26 881 07:29:11 891 07:29:56 901 07:30:42 930 07:31:27 930 07:32:12 940 07:32:57 950 07:33:42 979 07:34:27 999 07:35:12 1019 07:35:57 1038 07:36:42 1048 07:37:28 1048 07:38:13 1068 07:38:58 1087 07:39:43 1097 07:40:28 1107 07:41:13 1126 07:41:58 1156 07:42:43 1175 07:43:28 1175 07:44:14 1185 07:44:59 1166 07:45:44 1185 07:46:29 1195 07:47:14 1224 07:47:59 1254 07:48:44 1254 07:49:29 1273 07:50:14 1283 07:50:59 1303 07:51:44 1322 07:52:30 1303 07:53:15 1303 9.9 I0.0 9.9 I0.0 10.0 10.0 I0.0 10.0 10.0 I0.0 9.9 9.8 9.8 9.8 9.9 9.7 9.8 9.7 9.7 9.7 9.7 9.7 9.7 9.7 9.7 9.7 9.7 9.7 9.6 9.6 9.7 9.6 9.6 9.6 9.6 9.6 9.6 9.6 9.5 9.5 9.4 9.5 9.5 1101.1 1108.5 1116.0 1123.5 1131.0 1138.5 1145.9 1153.4 1160.8 1168.3 1175.7 1183.2 1190.6 1198.0 1205.4 1212.7 1220.1 1227.4 1234.7 1242.0 1249.3 1256.6 1263.9 1271.2 1278.4 1285.7 1293.0 1300.3 1307.5 1314.7 13~.0 1329.3 1336.5 1343.8 1351.0 1358.2 1365.4 1372.6 1379.7 1386.9 1394.0 1401.1 1408.3 1415.4 I101.1 0.0 166 125.0 1108.5 0.0 157 125.8 1116.0 0.0 147 126.5 1123.5 0.0 127 127.3 1131.0 0.0 117 128.0 1138.5 0.0 108 128.8 1145.9 0.0 108 129.5 1153.4 0.0 98 130.3 1160.8 0.0 78 131.0 1168.3 0.0 78 131.8 1175.7 0.0 69 132.5 1183.2 0.0 59 133.3 1190.6 0.0 49 134.0 1198.0 0.0 39 134.8 1205.4 0.0 29 135.5 1212.7 0.0 29 136.3 1220.1 0.0 20 137.0 1227.4 0.0 20 137.8 1234.7 0.0 10 138.5 1242.0 0.0 20 139.3 1249.3 0.0 10 140.0 1256.6 0.0 10 140.8 1263.9 0.0 10 141.5 1271.2 0.0 20 142.3 1278.4 0.0 10 143.0 1285.7 0.0 I0 143.8 1293.0 0.0 10 144.5 1300.3 0.0 10 145.3 1307.5 0.0 I0 146.0 1314.7 0.0 10 146.8 1322.0 0.0 0 147.5 1329.3 0.0 10 148.3 1336.5 0.0 0 149.0 1343.8 0.0 0 149.8 1351.0 0.0 0 150.5 1358.2 0.0 0 151.3 1365.4 0.0 0 152.0 1372.6 0.0 0 152.8 1379.7 0.0 10 153.5 1386.9 0.0 0 154.3 1394.0 0.0 0 155.0 1401.1 0.0 0 155.8 1408.3 0.0 0 156.5 1415.4 0.0 0 157.3 -1.0 -1.0 -1 0 -1 0 -1 0 -1 0 -1 0 -1 0 -I.0 -I.0 -1.0 -1.0 -1.0 -I.0 -I.0 -1.0 -1.0 -1.0 -1.0 -I.0 -1.0 -I.0 -I.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -I.0 -I.0 -1.0 -1.0 -1.0 -I.0 -1.0 -1.0 -i.0 -I.0 -I.0 -1.0 DATE: 24-SEP-94 CUSTOMER: BPX RIG/WELL: F-19 SERVICE COMPANY: BJ JOB TICKET: 004984 SEF.:V ICES TIME: 07:54:00 CUSTOMER REF': K.SMITH JOB TYPE : DATA FF.:AC SERVICE REP: J.CULF'EPPER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 07:54:00 1303 07:54:45 1342 07:55:30 1361 07:56:15 1352 07:57:00 1283 07:57:45 1254 07:58:30 1254 07:59:15 1273 08:00:00 735 08:00:45 735 08:01:30 735 08:02:I6 744 08:03:01 754 08:03:46 764 08:04:31 774 08:05:16 784 08:06:01 784 08:06:46 784 08:07:31 637 08:08:16 793 08:09:02 793 08:09:47 803 08:10:32 813 08:11:17 813 08:12:02 823 08:12:47 833 08:13:32 833 08:14:17 842 08:15:02 842 08:15:47 852 08:16:32 852 08:17:17 852 08:18:02 862 08:18:47 862 08:19:33 872 08:20:18 872 08:21:03 872 08:21:48 881 08:22:33 881 08:23:18 891 08:24:03 891 08:24:49 901 08:25:34 891 08:26:19 911 9.5 9.4 9.5 9.4 9.4 9.6 9.5 9.5 5.1 5.1 5.1 5.1 5.1 5.1 5.1 5.1 5.0 5.0 3.4 5. I 5. I 5.2 5.1 5.2 5.1 5.1 5. I 5.2 5.1 5.1 5. I 5. I 5.1 5.2 5.1 5.1 5.1 5.1 5. I 5.1 5.! 5. I 5.0 5.1 1422.5 1429.6 1436.6 1443.7 1450.8 1458.0 1465.1 1472.2 1477.3 1481.1 1484.9 1488.7 1492.5 1496.3 1500.2 1504.0 1507.8 1511.6 1514.9 1518.5 1522.4 1526.3 1530.2 1534.0 1537.9 1541.8 1545.6 1549.5 1553.4 1557.2 1561.1 1564.9 1568.8 1572.6 1576.5 1580.3 1584.2 1588.0 1591.8 1595.7 1599.5 1603.3 1607.1 1610.9 1422.5 0.0 10 158.0 1429.6 0.0 0 158.7 1436.6 0.0 0 159.5 1443.7 0.0 0 160.2 1450.8 0.0 0 161.0 1458.0 0.0 0 161.7 1465.1 0.0 0 162.5 1472.2 0.0 0 163.2 1477.3 0.0 0 164.0 1481.1 0.0 0 164.7 1484.9 0.0 10 165.5 1488.7 0.0 0 166.2 1492.5 0.0 0 167.0 1496.3 0.0 0 167.7 1500,2 0.0 0 168.5 1504.0 0.0 0 169.2 1507.8 0.0 10 170.0 1511.6 0.0 0 170.7 1514.9 0.0 0 171.5 1518.5 0.0 0 172.2 1522.4 0.0 0 173.0 1526.3 0.0 0 173.7 1530.2 0.0 0 174.5 1534.0 0.0 -10 175.2 1537.9 0.0 0 176.0 1541.8 0.0 -10 178.7 1545.6 0.0 0 177.5 1549,5 0.0 -10 178.2 1553.4 0,0 -10 179.0 1557,2 0,0 -10 179.7 1561.1 0.0 0 180.5 1564.9 0,0 0 181.2 1568.8 0.0 0 182.0 1572,6 0.0 -I0 182,7 1576.5 0.0 0 183.5 1580.3 0.0 0 184.2 1584.2 0.0 0 185.0 1588.0 0.0 0 185.7 1591.8 0.0 0 186.5 1595.7 0.0 0 187.2 1599.5 0.0 0 188.0 1603.3 0.0 0 188.7 1607.1 0.0 0 189.5 1610.9 0.0 0 190.2 -1 0 -1 0 -1 0 -1 0 -1 0 -1 0 -I.0 -1.0 -1.0 -1.0 -I.0 -I.0 -1.0 -1.0 -i.0 -1.0 -1.0 -I.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -1.0 -I.0 -1.0 -I.0 -I.0 -1.0 -1.0 -1,0 -1.0 -1.0 -I.0 -I.0 -1.0 -I.0 -I.0 -1.0 -1.0 -1.0 DATE: 24-SEP-94 CUSTOMER: BP X RIG/WELL: F-19 SERVICE COMPANY: BJ JOB TICKET: 004984 SERV ICES TIME: (])8:27:0'~ CUSTOMER REP: K.SMITH JOB TYPE : DATA FRAC SERVICE REP: J.CULPEPPER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:HM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 08:27:04 911 08:27:49 921 08:28:34 930 08:29:19 930 08:30:04 940 08:30:49 940 08:31:34 940 08:32:19 940 08:33:05 950 08:33:50 960 08:34:35 950 08:35:20 950 08:36:05 960 08:36:50 970 08:37:35 970 08:38:20 979 08:39:05 979 08:39:51 989 08:40:36 999 08:41:21 999 08:42:06 1009 08:42:51 1009 08:43:36 1019 08:44:21 989 08:45:06 979 08:45:51 970 08:46:36 940 08:47:22 950 08:48:07 950 08:48:52 950 08:49:37 940 08:50:22 940 08:51:07 940 08:51:53 940 08:52:38 940 08:53:23 940 08:54:08 940 08:54:53 940 08:55:38 940 08:56:23 940 08:57:08 940 08:57:53 950 08:58:38 950 08:59:23 852 5.1 5.0 5.1 5.1 5,1 5.1 5.1 5.0 5.0 5.0 5.0 5.0 5.0 5.0 4.9 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 4,9 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 3.6 1614.8 1618.6 1622.4 1626.2 1630.0 1633.8 1637.6 1641.3 1645,1 1648.9 1652.6 1656.4 1660.1 1663.9 1667.6 1671.4 1675.2 1678.9 1682,6 1686.4 1690.1 1693.9 1697.6 1701.3 1705. I 1708.8 1712.5 1716.3 1720.0 1723.8 1727.5 1731.2 1735.0 1738.7 1742.5 1746.2 1750.0 1753.7 1757.5 1761.2 1764.9 1768.7 1772.4 1775.8 1614.8 0.0 -10 191.0 -1.0 1618.6 0.0 -10 191.7 -I,0 1622.4 0.0 -10 192.5 -1.0 1626.2 0.0 0 193.2 -1.0 1630.0 0.0 -I0 194.0 -1,0 1633.8 0.0 0 194.7 -1.0 I637.6 0.0 0 195.5 -1.0 1641.3 0.0 0 196.2 -1.0 I645.1 0.0 0 197.0 -1.0 1648.9 0.0 0 197.7 -1.0 1652.6 0.0 0 198.5 -1.0 1656.4 0.0 0 199.2 -1.0 1660.1 0.0 0 200.0 -1.0 1663.9 0.0 0 200.7 -1.0 1667.6 0.0 -10 201.5 -1.0 1671.4 0.0 0 202.2 -1.0 1675.2 0.0 0 203.0 -1.0 1678.9 0.0 -I0 203.7 -I.0 1682.6 0.0 0 204.5 -1.0 1686.4 0.0 0 205.2 -1.0 1690.1 0.0 0 206.0 -1.0 1693.9 0.0 -10 206.7 -1.0 1697.6 0.0 0 207.5 -1.0 1701.3 0.0 0 208,2 -1.0 1705. I 0.0 -10 209.0 -1.0 1708.8 0.0 0 209.7 -1.0 1712.5 0.0 -10 210.5 -1.0 1716.3 0.0 -10 211.2 -1.0 1720.0 0.0 -10 212.0 -1.0 1723.8 0.0 0 212.7 -1.0 1727.5 0.0 -10 213.5 -1.0 1731.2 0.0 -10 214.2 -1.0 1735.0 0.0 0 215.0 -1.0 1738.7 0.0 0 215.7 -1,0 1742.5 0.0 -10 216.5 -1.0 1746,2 0.0 0 217.2 -1.0 1750.0 0.0 0 218.0 -1.0 I753,7 0.0 -10 218.7 -1.0 1757.5 0.0 0 219.5 -1.0 1761,2 0.0 0 220.2 -1.0 1764,9 0.0 0 221.0 -I.0 1768.7 0.0 0 221.7 -I.0 1772.4 0.0 0 222.5 -1.0 1775.8 0.0 0 223.2 -i.0 DATE: 24-SEP-94 ~]~USTOMER: BPX RIG/WELL: F-19 SERVICE COMPANY: BJ JOB TI~Z:KET: 004984 SERV ICES TIME: 09:00:09 ~]:USTOMER REF': I-::]. SMI ]"H JOB TYPE : DATA FRAC SERVIE:E REP: J.CULF'EPF'ER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 09:00:09 842 09:00:54 852 09:01:39 842 09:02:24 852 09:03:09 852 09:03:54 852 09:04:39 852 09:05:24 852 09:06:09 852 09:06:54 852 09:07:40 852 09:08:25 862 09:09:10 862 09:09:55 852 09:10:40 764 09:11:25 764 09:12:10 774 09:12:56 764 09:13:41 774 09:14:26 774 09:15:11 764 09:15:56 764 09:16:41 764 09:17:26 774 09:18:11 725 09:18:57 715 09:19:42 705 09:20:27 705 09:21:12 509 09:21:57 509 09:~'43~. 500 09:23:28 480 09:24:13 470 09:24:58 470 09:25:43 470 09:26:28 451 09:27:13 431 09:27:58 421 09:28:43 421 09:29:28 411 09:30:13 392 09:30:59 372 09:31:44 353 09:32:29 343 3.6 3.6 3.6 3.6 3.6 3.6 3.7 3.7 3.7 3.7 3.6 3.7 3.7 3.7 2.4 2.5 2.4 2.5 2.5 2.6 2.6 2.5 2.5 2.6 0.4 0.1 0.2 0.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1778.6 1781.3 1784.0 1788.8 1789.5 1792.2 1794.9 1797.7 1800.4 1803.2 1805.9 1808.7 1811.4 1814.2 1816.2 1818.0 1819.9 1821.8 1823.7 1825.6 1827.5 1829.3 1831.2 1833.1 1833.6 1833.7 1833.9 1834.0 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1834.1 1778.6 0.0 0 224.0 -1.0 1781.3 0.0 0 224.7 -I.0 1784.0 0.0 0 225.5 -1.0 1786.8 0.0 0 226.2 -1.0 1789.5 0.0 0 227.0 -1.0 1792.2 0.0 0 227,7 -1.0 1794.9 0.0 0 228.5 -1.0 1797.7 0.0 0 229.2 -1,0 1800.4 0.0 0 230.0 -1.0 1803.2 0.0 0 230.7 -I.0 1805.9 0.0 0 231.5 -1.0 1808.7 0.0 0 232.2 -1.0 1811.4 0.0 0 233.0 -1.0 1814.2 0.0 0 233.7 -1.0 1816.2 0.0 0 234.5 -1.0 1818.0 0.0 0 235.2 -1.0 1819.9 0.0 0 236.0 -1.0 1821.8 0.0 0 236,7 -1.0 1823.7 0.0 0 237.5 -1.0 1825.6 0.0 0 238.2 -1.0 1827.5 0.0 10 239.0 -1.0 I829.3 0.0 803 239,7 -1.0 1831.2 0.0 881 240.5 -1.0 1833.1 0.0 -10 241.2 -I.0 1833.6 0,0 0 242.0 -1.0 1833.7 0.0 0 242.7 -1.0 1833.9 0.0 0 243.5 -1.0 1834.0 0.0 0 244.2 -1.0 1834.1 0.0 10 245.0 -1.0 1834.1 0.0 0 245.7 -1.0 1834.1 0.0 0 246.5 -1.0 1834.1 0.0 -10 247.2 -1.0 1834.1 0.0 0 248.0 -1.0 1834.1 0.0 0 248.7 -1.0 1834.1 0.0 10 249.5 -1.0 1834.1 0.0 10 250.2 -1.0 1834.1 0.0 i0 251.0 -1.0 1834.1 0.0 10 251.7 -1.0 1834.1 0.0 20 252.5 -1.0 1834.1 0.0 10 253.2 -1.0 1834.1 0.0 39 254.0 -1.0 1834.1 0.0 49 254.7 -1.0 1834.1 0.0 59 255.5 -1.0 1834.1 0.0 78 256.2 -1.0 DATE: 24-SEP-94 CUSTOMER: BPX RIG/WELL: F-19 SERVIC:E COMF'ANY: BJ JOB TICKET: 004984 SERV ICES TIME: 09: 33:14 CUSTOMER REP: K.SMITH JOB TYPE : DATA FRAC SERVIE:E REP: J.E:ULPEPPER TIME PRESSURE RATE TOTAL STAGE SAND CONC ANNULUS E TIME CLEAN SID HH:MM:SS PSI BBL/MIN BARRELS BARRELS PPA PSI MINUTES BBL/MIN 09:33:14 323 09:33:59 313 09:34:44 304 09:35:30 284 09:36:15 264 09:37:00 255 09:37:45 235 09:38:30 235 09:39:15 225 09:40:00 215 09:40:45 196 09:41:30 245 09:42:15 245 09:43:01 245 09:43:46 245 09:44:31 245 09:45:16 235 09:46:01 235 09:46:46 558 09:47:31 548 09:48:16 313 09:49:01 10 09:49:46 0 09:50:31 0 09:51:17 0 09:52:02 10 09:52:47 10 09:53:32 29 09:54:17 29 09:55:02 20 09:55:47 20 0.0 0.0 0.0 0.0. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 10.5 10.2 9.9 10,0 9.8 1834.1 1834.1 1834.1 1834.1 1834.1 1834.2 1834.2 1834.2 1834.2 1834.2 1834.2 1834.2 1834.2 1834.2 1834.2 I834.2 1834.2 1834.2 1834.2 1834.2 1834.2 1834.5 1834,5 1834.5 1834.5 1834.5 1836.9 1844.5 1852.1 1859.7 1866.8 1834.1 0.0 78 257.0 -1.0 1834.1 0.0 88 257.7 -I.0 1834.1 0.0 88 258.5 -1.0 1834. I 0.0 98 259,2 -I.0 1834.1 0.0 98 260.0 -1.0 1834.2 0.0 98 260,7 -I.0 1834.2 0.0 108 261.5 -I.0 1834.2 0.0 98 262.2 -1.0 1834.2 0.0 117 263.0 -1.0 1834.2 0.0 108 263.7 -1.0 1834.2 0.0 108 264.5 -1.0 1834.2 0.0 108 265.2 -I.0 1834.2 0.0 117 266.0 -1.0 1834.2 0,0 127 266.7 -I.0 1834.2 0.0 127 267.5 -1.0 1834.2 0.0 147 268.2 -1.0 1834.2 0.0 147 269.0 -1.0 1834.2 0.0 117 269.7 -1,0 1834.2 0.0 88 270.5 -I,0 1834.2 0.0 108 271.2 -1.0 1834.2 0.0 108 272.0 -1.0 1834.5 0.0 108 272.7 -1.0 1834.5 0.0 98 273.4 -I.0 1834.5 0.0 98 274.2 -1.0 1834.5 0.0 98 274.9 -1.0 1834.5 0.0 88 275.7 -I.0 1836.9 0.0 78 276.4 -1.0 1844.5 0.0 98 277.2 -1.0 1852.1 0.0 49 277.9 -1.0 1859,7 0.0 49 278.7 -1.0 1866.8 0.0 69 279.4 -1.0 ~CONSERVATION COMMISSION ~'~~ ~ ~,~ ~ ~ ~ ~ ..WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS 300, ~'ORCU~NE [~R~VE ANCHORAGE, ALASKA 99501-3192 PHONE: (907} 279-'1433 TELECOPY: (907) 276-7542 September 2, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Duck Island Unit/Endicott 1-53/Q-20 BP Exploration (Alaska), Inc. Permit No: 94-112 Sur. Loc. 3108'NSL, 2185'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 1481'NSL, 95'WEL, Sec. 36, T12N, R16E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chai~ma~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryl-! Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-'Ii Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25,025) 3108' NSL, 2185' WEL, SEC. 36, T12N, R16E Duck/s/and Unit/Endicott At top of productive interval 8. Well number Number 2106' NSL, 688' WEL, SEC. 36, T12N, R16E 1-53/Q-20 2S100302630-277 At total depth 9. Approximate spud date Amount 1481' NSL, 95' WEL, SEC. 36, T12N, R16E 9/1/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 34633-95' feet 1-51/V-20-13.2'@ 900' feet: 11421'MD/10135' TVD feet 116. To be completed for deviated wells 17. Anticipated pressure (s,,e 2o AAC 25.035 (e)(2)) Kickott depth 500 feet Maximum hole angle 92.8~ Maximum surface 3900 psig At total depth (TVD) 10000'/4890 psig 118. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" Struct. Drive Pipe 90' 40' 40' 130' 130' Drive 13.1/2' 10-3/4" 45.5# NT80 BTC 2723' 37' 37' 2750' 2730' 467sxPF"E"/375sx'G"/150sx"E" 9-7/8" 7-5/8" 29.7# NT95HS NSCC 10543' 37' 37' 10580' 10175' 296 sx Class "G" 6-3/4" 4-1/2" 12.6# L-80 NSCC 950 10471' 10162' 11421' 10136' Uncemented 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production AU(~ 1 9 1994 Liner Alaska 0il & Gas Cons. Commission Perforation depth: measured Anchora.~j~ true vertical ' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program E'l/~ime vs depth pict [] Refraction analysis F-I Seabed reportFI 20 AAC 25.050 requirements[] 21.1 hereby certify t.~h/~e~f~r,~g ~,'~? is t,~'e and correct to the best of my knowledge ,'"/,Signe~, , ,~/ ~ k~..(./..,(/~~/~(, Title Drillin~l EnginoorSuporvisor Date ¢~'.~'~¢- ~..,/ ~' ..... Commission Use Only Permit Ndm'lSer lAP' number IApprov~, date ISee cover letter ? ~,,_,/,/.%, 150. o ~ ? - ~- ~ .¢'~ f~ ~ ...~.. ¢/-f lfor other requirements Conditions of approval Samples required [] Yes [~ No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~recl ];3] Yes [] No Required working pressure for DOPE []2M; []3M; [-15M; I-I10M; F-I15M; Other: by order of Approved by Commissioner me commmsion Date Form 10-401 Rev. 12-1-85 Submit in triplicate ['Well Name: 1-53/Q-20 Well Plan Summary Type of Well (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 3108 FSL, 2185 FEL, S36 T12N R16E UM 2106 FSL, 688 FEL, S36 T12N R16E UM 1481 FSL, 95 FEL, S36 T12N R16E UM I AFE Number: 1717492 I Rig: I Doyon 15 I Estimated Start Date: I 9/1/94 I I Operating days to complete: 1 29 I MD: I11421 I ITVD: I10080' SSI IKBE: 155'85 Well Design (conventional, slimhole, etc.)' I Slimhole, longstring, horizontal Formation Markers: Formation Tops MD (BKB) TVD (BKB) Tuffs 8926 8846 HRZ 9451 9366 Put R. 9712 9624 Kekiktuk 9719 9631 Target 10621 10176 TI) 11421 10135 RE£ VED /x,~.~ka Oil & Gas Cons. Commi~ Anchoraqo sion Casing/Tubing: Program: Wt/Ft Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD Driven 30" Stmct. WLD GL Preset 131/2'' 103/4'' 45.5# NT-80 BTC 2723' 37'/37' 2750'/2730' 97/8'' 75/8'' 29.7# NT-95HS NSCC 10543' 37'/37' 10580'/10175' 63/4'' 41/2'' 12.6g L-80 NSCC 950' 10471'/10162' 11421'/10136' TBG 41/2'' 12.6# L-80 NSCT 10463' 37'/37' 10500'/10169' Well Plan Summary KSB 1-53/Q-20 Page 1 Logging Prog ] Open Hole Logs: Surface Intermediate Production I Cased Hole Logs: ram · Directional (MWD and Gyro) LWD - CDR/CDN, MWD Directional MWD Directional/Gamma Ray Mud Program: I Special design considerations I FloPro mud in horizontal Surface Mud ProPerties: [ FW S'>ud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 100 +30 15 20 9.0 20 to to to to to to to 9.4 200 sec/qt 20 30 9.5 15 Intermediate Mud Properties: [FW Gel - Polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 40 +_20 12 25 9.0 8 to to to to to to to 10.4 100 15 30 9.56 6 Production' Mud Properties: I Flo-Pro Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 80 +40 10 18 9.5 8 to to to to to to to 10.0 100 15 22 10 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. RECEIVED Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I S00' Mr> I I Maximum Hole Angle: [ 92.86° Close Approach Well: 1-51/V-20:13.2 @ 900' MD in 1-53/Q-20 The above listed wells will be secured during the close approach. AUG 1 9 1994 Oil & Gas Cons. Commission Anchor%e Well Plan Summary KSB 1-53/Q-20 Page 2 Well 1-53/O-20 (MPB _ Pr0p0$~d Drilling and Completion Program Objective Well 1-53/Q-20 will be directionally drilled from the Endicott MPI to produce reserves from the Kekiktuk formation. This well will be completed with 41/2'' L-80 tubing. Operation Execute a rig move and rig-up. Directionally drill the surface hole with 8.8-9.4 ppg mud to the proposed depth. Run and cement 103/4'' 45.5 LB/ft NT-80 buttress casing to surface. Pressure test casing. Install BOPE. Drill out casing and five feet of new hole and conduct a formation leak-off test. Directionally drill 97/8" hole with a 9.2-10.4 ppg mud system to the Kekiktuk formation. Set 75/8'' 29.7 LB/ft NT-95HS, NSCC intermediate casing. No abnormal pressures are expected in the 97/8 hole section. Drill the 63/4'' hole to TD. Run slotted 41/2'' liner. Clean out liner and displace to brine. Pressure test casing. Complete with 41/2" L-80 NSCT tubing. Install a sub- surface safety valve below the base of permafrost. Nipple up tree and release rig. Fluids incidental to the drilling of the well will be pumped down the 103/4'' by 75/8" annulus of an approved offset well. The 103/4" by 75/8" annulus will be freeze protected with a non-freezing fluid down to 1500 feet once the rig is released. RECEIVED AUG I 9 i994 A!~sk~ Oi~ & Gas Cons, Commission Anchor~ ~,. Well Plan Summary KSB 1-53/0-20 Page 3 CEMENT PROGRAM-HALLIBURTON 10-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx APPROX. SACKS: 467 THICKENING TIME: 5+ hrs MIX WATER: 11.63 gps TAIL CEMENT TYPE; Premium - ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. SACKS: 375 THICKENING TIME: 4 hrs MIX WATER: 5.00 gps TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gps APPROX. SACKS: 150 SPACER: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME 1. Lead slurry + 375 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 150 sx. 7 5/8" INTERMEDIATE CASING CASING SIZE: 7 5/8", 29.7# CIRC, TEMP 135°F TAIL CEMENT TYPE; Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 296 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix lead slurry. Batch mix tail slurry. Displace at 12-15 bpm with rig pumps. CEMENT VOLUME Tail Slurry to 1000' above shoe w/50% excess + 80 ft. shoe. <KB> ' ' PRUDHOE BAY BRI_LING UR"OUP ....... /a-2o (p o) ,~ ~-- ,' ........ i ! VERTICAL SECTION VIEW' '-- ii -' i' "' I Section at: 232.06 , i i TVO $¢81e.' ~ inch = 1200 feet i'- ' } i i Oep Scale. 1 inch = ~200 {eet ' '; ~ ~ I Drawn · 08/15/94 '-~ ~:' ~ ...... i ~ /nadr ~ ] ] Schlumberger :' ~ [ NapK~r Ident~{ica[iOn ~D BKB SECTN !NCU/,I ~ " ~ i Al KB 0 0 0 O:dO 8] g~ILD t.5/t00 500 ~00 0 0.00 C) END 1.5/~00 BUILD 1039 1037 38 8.08 li~ J I D) lURK LEFT 2/100 5857 5807 714 8]08 ~ i ~ El END 2/t00 TURN 5937 5886 725 8,08 I1 TD ttd21 10136 '2643 92.86 . I . · : . ......... ~ ................ i .... . . . , ,, i Crrll:! ' ~ j.A~ska, bi~ [& Gas Co m. Commission · ~a~~~ ____ -- -,-----~:-::~ .......~ , ~ ¢-~¢ - - -----~----- , . - ~~ ~-~ .~, ,...._. ........ ~t .... ~ = .F ...... , I I I I -!200 -60,6 0 600 i200 1800 2400 3000 3600 4200 4800 5400 6000 6500 7200 ! Sec-t ion Departure ........................... ,. .__. ..... i : · : ' ~', ' ~':I'~: -'. :" ]'::'- . PRU'OHOa M~rk~r id:n~Ificatlon ~) KB B) BUILD 1;5/'.,00 C) 6ND ~.5/~.00 BUILD D) TURN LEFT E/lO0 E) END 2/1Q0 TURN F) CURVE lO/JO0 G) ....... SARGET ....... H) END }0/~00 BUILD il lO BAY'" DR]] --II II .. I MD N/S 0 0 500 o 1039 24 5857 450 5337 456 9770 7O6 10621 ~092 10621 ~092 1~421 i E/N 1042 !497 i~g7 209~ --Ill _ I I I _LING GROUP II, I , III :t-53/0-20 (P ~ 0) PLAN VIEW i .__ii i i ....... i i1 iii i __ CLOSURE ' 2650 feet at Azimuth 127.90 DECLINATION.' 29. 919 E SCALE ' ~. inch = 400 feet DRAWN ' 08/:15/94 D t ~ '~ I ........ I i " ........................ ! ~ -- . ~ · =, , ' 1,, ' , ii ~ ' i [' ' '~i ! i ' I ! ' : .................... i .................. ; ~ .-, : ....... ~.~_.., , , 200 O i 200 400- 600 800 lO00 1200 1400 1600 1800 2000 2200 2400 2500 <- WEST '~ EAST -> t_ .. m mm .. m .. i _ · ;~ ~ ~.~.;: ...... ::., ~ .-.: -'~:.~'~'.. ~ :. .... : :~:..:;..~, :..:~. ;:..$ 'i:... : ~,..,. ~i~:~.. ..-~ BP EXPLOR,;g'ION August 22, 1994 BI= Exploration (Alaaka) Inc, 900 East P. enaon I~lo~le~ard P,O. B~x 1~12 Anchorage, Alaska .99519.6612 (907) 561-511'1 Rober~ R. CrandaJl Alaska O[I and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Endicott Well 1-53/Q-20 Spacing Dear Bob: Enclosed please find a map which shows that the proposed Subzone 2B Endicott Well 1-53/Q-20, is outside of the drainage areas of the adiacent producing Subzone 2B wells 1-41 ancl 2-28, There is no conflict with the AOGCC rule regarding well penetrations within 1000' for production from a comparable subzone. Well 1-49/P-21 is within 1000' of well 1-53/Q-20, however this well is a Subzone 3A well and has no potential for production from the 2B. Please contact me at 564-4613 if you wish to discuss this matter in further detail. Sincerely, rrm Enclosures Well Location Map Endicott Type Log 1-53/Q-_0 Wellfile Kleppin, D. Chester, D. Suttles, D, '.-z~ Z^ JG ~P' ' ~J4 P'. 4./4 04:50PF1 BPX EhtDICOTT DEVP ~,. ENDICOTT TYPE LOG i__ mi ..... _, ..... LOW-. ~. ~. ~ ~ ~HRZ SHAL~ ITKILYARIAK FM "-- -. ,,-.) .) FRANKLINIAN BASEMENT Sequence 3A4 not present in this well 23- 3~ Alaska Oil & 6a~ uu;ls. Anchorage SANDSTONES SHAI,~S, SILTSTONES, AND TIGHT ~AND~I'ONE~ LCU ' LOWER CRETACEOUS UNCONFORMITY WELL PERMIT CHECKLIST FIELD & POOL ~O/O~_~ WELL NAME UZ~'~ / --s3/P -~-~ PROGRAM, exp [] devy redrll [] serv a GEOL ~ ~? C~ UN~T# /0 .r~.GO ON/OFF SHOP. E ~ ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. tY 5. Well located proper distance from drlg unit boundary., tY 6. Well located proper distance from other wells ...... '7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... tY 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ........ N N N N N N N N N N N ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USOWs ........ 16. CMT vol adequate to circulate on conductor & surf 17. CMT vol adequate to tie-in long string to surf csg 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved.'.~----R%~/~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate -~ N ~ ~ 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............. GEOLOGY APPR D 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./. · Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW~o - A:~FORMS~cheklist rev 03/94