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Home My WebLink About190-091CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: MPI-02 (PTD# 1900910) - Well to Remain Shut In Date:Thursday, May 8, 2025 7:40:16 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, May 7, 2025 3:38 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Not Operable: MPI-02 (PTD# 1900910) - Well to Remain Shut In Mr. Wallace – PWI injector MPI-02 (PTD# 1900910) had an injectivity test performed with fullbore on 5/5/25, showing a lack of injectivity to bring the well back on injection. Injection in the well has not commenced since the Operable note below on 2/21/25 therefore no online AOGCC MIT-IA has been performed. The well will now return to Not Operable status until further wellwork is performed to increase well injectivity. Please respond with any questions or concerns. Thank you, Milne / Islands / WNS Well Integrity Engineer 907-564-5005 Ryan Thompson From: Ryan Thompson Sent: Friday, February 21, 2025 8:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable: MPI-02 (PTD# 1900910) - Return to PWI Injection Mr. Wallace – PWI well MPI-02 was made Not Operable after being shut in for its 4 year MIT-IA due in March 2023. We will be returning this well to PWI injection. The well is now re-classified as Operable. Plan forward: 1. POI 2. Perform state witnessed MIT-IA once on stable injection. Please respond with any questions or concerns. Thank you, Ryan Thompson The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable: MPI-02 (PTD# 1900910) - Return to PWI Injection Date:Monday, February 24, 2025 8:57:40 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, February 21, 2025 8:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable: MPI-02 (PTD# 1900910) - Return to PWI Injection Mr. Wallace – PWI well MPI-02 was made Not Operable after being shut in for its 4 year MIT-IA due in March 2023. We will be returning this well to PWI injection. The well is now re-classified as Operable. Plan forward: 1. POI 2. Perform state witnessed MIT-IA once on stable injection. Please respond with any questions or concerns. Thank you, Ryan Thompson The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPI-02 (PTD# 190-091) Missed AOGCC Witness MIT-IA Date:Tuesday, April 4, 2023 9:06:49 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:40 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPI-02 (PTD# 190-091) Missed AOGCC Witness MIT-IA Mr. Wallace, Produced Water Injector MPI-02 (PTD#190-091) is currently shut in and will not be brought online for its scheduled MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg •�7 p� P.I. Supervisor Il —y� 3'ZG,I�C' DATE: Friday, March 22, 2019 SUBJECT: Mechanical Integrity Tests I ' HILCORP ALASKA LLC FROM: Lou Laubenstein Petroleum Inspector I-02 MILNE PT UNIT 402 Sre: Inspector Reviewed By: � P.1. Supry Zluz=� NON -CONFIDENTIAL Comm Well Name MILNH PT UNIT 1-02 API Well Number 50-029-22066-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL190316160852 Permit Number: 190-091-0 Inspection Date: 3/16/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well oz P w 4Ty� San "Tubing 083 oas - oso - oso PTD 900910 ' Type Test sPT 'Test psi soo IA 498 696 1650 1638 BBL Pumped. i BBL Returned OA 4 41- sa - Interval avRTST 'P/F P Notes: Friday, March 22, 2019 Page 1 of I STATE OF ALASKA ALARA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations LI Fracture Stimulate U Pull Tubing Li Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:MBE Treatment 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 190-091 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑✓ 6.API Number: AK 99503 50-029-22066-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB 1-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 6,260 feet Plugs measured 6,138 RECEIVED true vertical 4,308 feet Junk measured 6,133 feet 5,680,5,853& JUL 2 0 2017 Effective Depth measured 6,133 feet Packer measured 5,960 feet 3,875,4,007& AOGCC 'true vertical 4,217 feet true vertical 4,088 feet Casing Length Size MD TVD Burst Collapse Conductor 106' 13-3/8" 106' 106' 3,730psi 1,130psi Surface 2,800' 9-5/8" 2,800' 2,385' 3,520psi 2,020psi Production 6,260' 7" 6,260' 4,312' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-3/8"(Long) 4.6/L-80/IBT 5,984' 4,106' Tubing(size,grade,measured and true vertical depth) 2-3/8"(Short) 4.6/L-80/IBT 5,879' 4,027' GT Dual x(2) Packers and SSSV(type,measured and true vertical depth) &FH N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A C Treatment descriptions including volumes used and final pressure: N/A SCANNED AUG 16 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-408 cle Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilCOrp.COm Authorized Signature: /7"-------------.. Dab 7/20/2017 Contact Phone: 777-8412 Form 10-404 Revised 4/2017 �'"""B/4- 7 St - ] RBDMS t ,L 1 7 2017 Submit Original Only • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-02 Pump Truck 50-029-22066-00-00 190 091 9/23/16 2/6/17 Daily Operations: 9/21/2016-Wednesday No activity to report. c j` 9/22/2016 -Thursday No activity to report. -- 9/23/2016- Friday MIRU Cement Pump Unit and Little Red Pump Unit on Short String. PT lines to 3,500 psi -test OK. Perform injectivity test at 0.40 bpm @ 1,350 psi. Mix and up mp 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/ 12.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 10 bbl of diesel. SD Pumps. Monitor well. Final SITP of 1,300 psi. Move to Long String. RU on Long String. PT lines to 3,500 psi -test OK. Perform injectivity test at 0.60 bpm @ 1,280 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/ 12.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 10 bbl of diesel. SD Pumps. Monitor well. Final SITP of 1,190 psi. RDMO Cement Pump Unit & Little Red Pump Unit. Rig Down. 9/24/2016-Saturday No activity to report. 9/25/2016-Sunday No activity to report. 9/26/2016 - Monday No activity to report. 9/27/2016-Tuesday No activity to report. • S S Hilcorp Alaska, LLC Hilcorp Alaska,LEX Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPI-02 Coil 50-029-22066-00-00 190-091 9/23/2016 2/6/2017 i �a 7-Wen-say Q , 61 rftigtir 0111 No Operations to Report. 2/2/17-Thursday No Operations to Report. 2/3/17-Friday No Operations to Report. 2/4/17-Saturday No Operations to Report. 2/5/17-Sunday Move support equipment from J-24 to I-02.,HES CTU arrive with AMU#1. Hold safety meeting. Discuss job procedure and review JSA. MIRU CTU.,Start BOPE test. Test all rams and valves to 250/3500 psi. Draw down test accumulators. BOPE test complete. Pop off well stack back injector head. Install night cap. 2/6/17-Monday = W Hold safety meeting. Discuss job procedure. Pick inj head. Stab 20' lubricator. Make up dimple coil connector. 1.5"OD,DFCV 1.7",G force Jars 1.69"OD,Disconnect 1.69"OD,Circ Sub 1.69"OD,X treme mudd motor 1.7"OD,Reverse clutch 3 blade Junk mill 1.74"OD, Total BHA length18.14' (PT MHA 250/3500,Pull test connector 25k) Stab on well. PT stack 250/3500 psi.,Bleed down to 500 psi. Open master and swab on short string. Fusible cap installed on SSV. WHP 350 psi. IA=O,OA=0 psi. Bleed down WHP open choke. Returns at surface. RIH, Wt check at 5630'13.8K, RIH wt-600 lbs. 5805'wt check 15k.,5960' Start pumping bottoms up 1 bbl/min 4500 psi. Pumped 12 bbls. Annular Velocity in 2.375"=595'. Shut down pump. RIH at 10 ft/min 5940'stack 5k down.pick up online 1 bbl/min down CT 4000 psi. RIH not indication of motor work. Clean out to Max depth in short string 5961' slight tag on packer. Plck up and re tag dry. Gel sweep at nozzle. Pump bottoms up. Returns look grey and black.,POOH to surface. Tagged up. Pumped 84 bbls for short string FCO. Online down back side with freeze protect at.25 bbls/min 1100 psi. Spoke with engineer. Changed injection rates. Attempted to inject via pressure vs.rate. Shut down pump. Wellhead leveled off at 950 psi.,Short string freeze protected from surface to 2500'. Close master and swab. Blow down stack. Pop off well. Break down tools. Baker tool hand wants to install new motor. Make up new motor and re install mill. Same BHA configuration in description above. Swap tree cap to long string. Stab on well. Low pt stack 250/3500 psi.,RIH, at min rate.4 bbls/min 679 psi. Increase rate 1 bbl/min and FCO to tubing tail. Stacked weight and stalled motor in xn nipple 5976'. Pick up and CIH. pump bottoms up at tubing tail at 5984'. Weight check in tubing tail prior to 7"entry 19K. Small motor work. Doesnt look to be cement. More Gooey than hard. Stacking-7k and motor still spinning. Milled to 6008'and HES stated out of fluid.,Pick up and pump bottoms up. Gel at nozzle. 31k wt check. PU to 5900'and finish bottoms up. Trickle in 60/40 meth. Waiting on Vac truck with more fluid.Fluid tracker on shows pumped 200 bbls of stage volume of 1 KCL.Continue to creep OOH 1.5 ft/min.;Vac truck on location. Pulled 200 bbls off return tank. Should have been at least 260 in return tank. Vac truck pull off upright that was suppose to be out of fluid. pulled 65 bbls. Upright was not out of fluid. Investigate why HES was unable to pull from tank. 1700• 2000 NPT on HES. Vac truck on location with 1%KCL.;Hook up truck circulate KCL to Mill.. RIH attempt dry tag. Clear sailing from 5900-6100'. Plck up to 6000'and start puming 1 bbl/min 4000 psi. Cleanout to 6100'. 10 bbl gel sweep at nozzle. Chase OOH at 20 ft/min in 7". Increase POOH speed in tubing tail to 110 ft/min. 3000'shut donw fluid pump. Circulate 23 bbls of 60/40 in coil for freeze protect. Online down back side for freeze protect of tubing;Tagged up at suface. Close choke. Pump.25 bbls/min injecting at 1073 psi for 3 bbls. Good flat line. Close master swab. Dump SSV. Blow down stack. Rig down injector head,p sub and flowback iron. Unit still spotted up to well. Install tree cap. Location Secure. Crews off location. 2/7/17 ii=4Tuesday . 11 0 • Mime PointMP102 Unit We l SCHEMATIC Last Completed: 10/18/2002 Hileorp Alaska,LLC PTD: 190-091 TREE&WELLHEAD Tree 2-3/8"- 5M Dual Orig.KB Elev.=68.50/Orig.GL Elev.=35.00 11"x 2-3/8"5M FMC Dual w/2.375"IBT T&B Thread Wellhead FMC Tubing Hanger 2.0"CIW"H"BPV Profile 13-3/8"At:, 1 OPEN HOLE/CEMENT DETAIL 13-3/8" 500 sx Permafrost C in a 30"Hole 9-5/8" 938 sx PF'E',254 sx'E',in a 12-1/4"Hole 7" 391 sx Class`G'in a 8-1/2" WELL INCLINATION DETAIL KOP @ 500' Max hole angle=69 deg.at 4,023'MD Hole angle thru perfs=41 deg at 6,100'MD 9-5/8" ag 1 ii CASING DETAIL A Size Type Wt/Grade/Conn ID Drift Top Btm BPF 13-3/8" Conductor 54.5/K-55/N/A 12.615" 12.459" Surface 106' 0.1545 9-5/8" Surface 36/K-55/BTC 8.921" 8.765" Surface 2,800' 0.0773 7" Production 26/L-80/BTC 6.276" 6.151" Surface 6,260' 0.0383 TUBING DETAIL 2-3/8" Tubing(Long) 4.6/L-80/IBT 1.995" 1.901" Surf 5,984' 0.0039 2-3/8" Tubing(Short) 4.6/L-80/IBT 1.995" 1.901" Surf 5,879' 0.0039 TUBING DETAIL No Top Depth Item LONG STRING 1 2,278' HES 2-3/8"'X'Nipple,ID=1.875" 2 5,660' HES 2-3/8"'X'Nipple,ID=1.875" TOC:4,000 3 5,680' Baker Model'GT'Retrievable Dual Packer 40K Shear 4 5,853' Baker Model'GT'Retrievable Dual Packer 40K Shear 5 5,960' Baker FH Packer 40K ROT Release .4 RA Tag: 5036' 6 5,976' 2-3/8"'XN'Nipple 1.795"No Go 7 5,984' 2-3/8"Cut Tubing TOC 5,450 8 6,130' Dropped Baker Model'E'Hydro-Trip Sub/Mule Shoe USIT 10/16/02 SHORT STRING (No log above) B Y� 2 . A 2,281' HES 2-3/8"'X'Nipple,ID=1.875" B 5,659' HES 2-3/8"'X'Nipple,ID=1.875" C 5,680' Baker Model'GT'Retrievable Dual Packer 40K Shear C ( ?w 3 D 5,853' Baker Model'GT'Retrievable Dual Packer 40K Shear Z. -� 'yam E 5,867' 2-3/8"'XN'Nipple 1.795"No Go N Sands F 5,868' 2-3/8"WLEG—Bottom @ 5,879' D 4 PERFORATION DETAIL MnimumlD ELII Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status 1.795"@5,867' 5,710' 5,722' 3,896' 3,905' 12 12 3.5" 2/15/1991 Open F ONG STRING 5,742' 5,758' 3,920' 3,932' 16 12 3.5" 2/15/1991 Open "op of Cement N OA Sands X6,100'CTM 5,775' 5,782' 3,945' 3,951' 7 12 3.5" 2/15/1991 Open Milled 2/06/17 5,803' 5,826' 3,955' 3,973' 23 12 3.5" 2/15/1991 Open OA 5,898' 5,940' 4,038' 4,069' 42 5 5.0" 2/01/1991 Open 5 Minimum ID= ` =' i OB 5,982' 6,018' 4,101' 4,129' 36 5 5.0" 2/01/1991 Open 1.795"@5,976 Ref Log:SLB GCT—1/30/1991—Perf Guns 5.0"/37 gram 5 spf;Perf Guns 3.5"/24 gram 12 spf 6 �a ) , a OB Sands ` ' "' 7 ' , GENERAL WELL INFO -ish:Tubing Tail API:50-029-22066-00-00 STIMULATION DETAIL X6,133' Drilled&Cased by Nabors 27E—11/05/1990 OA/OB:Frac w/82,72644 16/20 Carbolite Fish:1.75"Ball Frac Pack ESP Completion by EWS Rig—2/18/1991 @6,138' a 8 Pull&Replace ESP by EWS Rig-12/21/1991 NOTE: 7 '0lir- 1 ,, . Pull&Run ESPCP by Nabors 4ES—3/08/1995 7"Casing Repaired in 2002. • Pull&Replace ESPCP by Polar 1—6/23/1996 TD(MD)=6,260'/ TD(TVD)=4,308' Pull&Run ESP by Nabors 5S—3/16/1998 PBTD(MD)=6,138'/PBTD(TVD)=4,293' Pull&Replace ESP by Nabors 4ES—4/06/2001 Convert to Injector by Nabors 4ES—10/18/2002 Cut long-string tubing tail—8/19/2009 Revised By:STP 7/20/2017 � OFTJi • • • re I'/7;4.ct THE STATE Alaska Oil and Gas ; Of TAS Conservation Commission � � AL }# 333 West Seventh Avenue Anchorage, Alaska 99501-3572 rR., GOVERNOR BILL WALKER g Main: 907.279.1433 O4'ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Area Operations Manager Hilcorp Alaska, Inc. SCANNED JAN 1 3 2017 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-02 Permit to Drill Number: 190-091 Sundry Number: 316-408 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A Cathy P oerster Chair DATED this /6137 of August, 2016. RBDMS'I,L/ AUG 1 5 2016 e • RECEIVED • STATE OF ALASKA AUGALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ars $//' 6 20 AAC 25.280 O 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: MBE Treatment❑., / 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC • Exploratory ❑ Development 0 190-091 I 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic 0 Service 0, 6.API Number. Anchorage Alaska 99503 50-029-22066-00-00 ' 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT SBI-02 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 " MILNE POINT/SCHRADER BLUFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,260' 4,308' 6,133' 4,217' 3,500 6,138' 6,133' , Casing Length Size MD TVD Burst Collapse Conductor 106' 13-3/8" 106' 106' 3,730psi 1,130psi Surface 2,800' 9-5/8" 2,800' 2,385' 3,520psi 2,020psi Production 6,260' 7" 6,260' 4,312' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-3/8"(Long) 4.6/L-80/IBT 5,984' See Attached Schematic / See Attached Schematic 2-3/8"(Short) 4.6/L-80/IBT 5,879' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): i GT Dual Pkr,GT Dual Pkr&FH Pkr and N/A 5,680(MD)/3,875(TVD),5,853(MD)/4,007(TVD)&5,960(MDY 4,088(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory 0 Stratigraphic ❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: 8/20/2016 Commencing Operations: OIL ❑ WINJ Q v WDSPL 0 Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola SIP Email sDorholat hilcorp.com Printed Name Bo York Title Operations Manager Signature A Phone 777-8345 Date 8/2/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number.Ce: I ` V Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Location Clearance ❑ / Other: 3560 p S 4 ,•' 'd--)10 °T5 f- EC:r4' 111 ) Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /4 / 0: Li it' I� 1 t� L.:_ 5 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g -/ -J D4cJ � Submit Form and .F.fC"SY„ t Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU 1-02 Hibor!Alaska,LI) Date:8/01/2016 Well Name: MPU 1-02 API Number: 50-029-22066-00 Current Status: SI Dual Water Injector Pad: Milne Point I-Pad Estimated Start Date: August 20th, 2016 Rig: N/A Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-091 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure: 2,793 psi @ 4,000' TVD (Last BHP measured 3/25/2014) Maximum Expected BHP: 2,793 psi @ 4,000' TVD (No new perfs being added, EMW= 13.43 ppg) MPSP: 3,500 psi (Based on maximum surface injection pressure) Brief Well Summary: MPU 1-02 was drilled with Nabors #27E in 1990 as a deviated producer in the Schrader Bluff NA, NB, NC, NE, OA, and OB sands. The well was first brought online using an ESP in March 1991. The ESP was changed out using EWS #4 in December 1991, Nabors 4ES in March 1995, Polar #1 in June 1996, Nabors 5S in March 1998, and Nabors 4ES in April 2001. The well was converted to a dual string injector using Nabors 4ES in October 2002. A hole was found in the 7" production casing during the workover and the casing was cut at 476' and recovered the cut joint and backed off and recovered the cut joint. New 7" casing was ran and made up to the existing casing and tested to 3,000 psi.The tubing tail of the long-string was cut in August 2009. The well provides support in hydraulic unit 3 for the OA sand (Short-string) and the OB sand (Long- string) for offset producers MPU H-16 (PTD 204-190), MPU I-04A (PTD 201-092), and MPU 1-15 (PTD 202-152). Notes Regarding Wellbore Condition • Dual String Injector(Short-string= OA sand; Long-string = OB sand). • Well is a deviated dual-string water injector (max hole angle 69.5° @ 4,000'). • Last MIT-IA to 1,500 psi on 3/12/2015. • Shut-in water injection due to diagnosed MBE (Matrix Bypass Event). • Confirmed MBE between MPU H-16 (ESP Oil Producer) based on dye tests in the OA and OB sands. Objective: The purpose of this work/sundry is to pump MBE treatments (down both the Long String [OB sand] and the Short String(OA sand])and place the well back on water injection for both strings. Brief Procedure: // j$ (a,/tr f °a Pumping Procedure (STEPS#1-#30 to be completed for both Long&Short Strings): 1. Production to SI offset producers up to 5 days prior to treatment (H-16, I-04A, 1-15). 2. Production to SI offset injectors up to 2 days prior to treatment (H-04& H-15). 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 3,500 psi. [TREATMENT#1] • • Well Prognosis Well: MPU 1-02 Hilcorp Alaska,LLQ Date:8/01/2016 a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5. Mix and bullhead the following fluids with the Cementing Unit: a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/- 12.0 bbl of 1% KCL water. b. +/- 10.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST#1] 11. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 3,500 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. / c. RIH and bail cement. POOH. d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours(to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BOPE to 3,500 psi Hi 250 psi Low, 10 min each test. i. Notify AOGCC 24 hrs. ii. Test using 60/40 methanol or 8.5 ppg seawater. iii. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 psi Low to confirm no leaks. c. RIH w/1.50" coil w/1.50" wash nozzle to cement top.Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to+/-5,960' MD(SS-Pkr)or+/- 6,133' MD (LS-Fish). e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/1.75" OD mill, 1-11/16" motor, and oil jars and cleanout cement to+/-5,960' MD (SS-Pkr)or +/-6,133' MD(LS-Fish). b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/ 1.75" wash nozzle to+/-5,960' MD (SS-Pkr)or+/-6,133' MD (LS-Fish). . 13 • • Well Prognosis Well: MPU 1-02 Hikcorp Alaska,LU Date:8/01/2016 b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 3,500 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 3,500 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. 20. Fluid-pack and maintain tubing pressure on offset well saffected by MBE (H-16/I-04A/I-15). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/- 12.0 bbl of 1% KCL water. b. +/- 10.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (H-16/I-04A/I-15). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes(same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing • 4) Milne Well: Point MP 1-02Unit SCHEMATIC Last Completed: 10/18/2002 flacon)Ala k��,f,t�. PTD: 190-091 TREE&WELLHEAD Tree 2-3/8"- 5M Dual Orig.KB Elev.=68.50/Orig.GL Elev.=35.00 11"x 2-3/8"5M FMC Dual w/2.375"IBT T&B Thread Wellhead FMC Tubing Hanger 2.0"CIW"H"BPV Profile 13-3/8 ` -'. OPEN HOLE/CEMENT DETAIL 13-3/8" 500 sx Permafrost C in a 30"Hole 9-5/8" 938 sx PF`E',254 sx'E',in a 12-1/4"Hole 7" 391 sx Class'G'in a 8-1/2" WELL INCLINATION DETAIL KOP @ 500' Max hole angle=69 deg.at 4,023'MD Hole angle thru penis=41 deg at 6,100'MD 9-5/8" ,, ii' CASING DETAIL .<1 A' Size Type Wt/Grade/Conn ID Drift Top Btm BPF 13-3/8" Conductor 54.5/K-55/N/A 12.615" 12.459" Surface 106' 0.1545 9-5/8" Surface 36/K-55/BTC 8.921" 8.765" Surface 2,800' 0.0773 7" Production 26/L-80/BTC 6.276" 6.151" Surface 6,260' 0.0383 TUBING DETAIL 2-3/8" Tubing(Long) 4.6/L-80/IBT 1.995" 1.901" Surf 5,984' 0.0039 2-3/8" Tubing(Short) 4.6/L-80/IBT 1.995" 1.901" Surf 5,879' 0.0039 TUBING DETAIL No Top Depth Item LONG STRING ) 1 2,278' HES 2-3/8"'X'Nipple 2 5,660' HES 2-3/8"'X'Nipple TOC:4,000 = 3 5,680' Baker Model'GT'Retrievable Dual Packer 40K Shear (Estlrraterq - 4 5,853' Baker Model'GT'Retrievable Dual Packer 40K Shear 5 5,960' Baker FH Packer 40K ROT Release CE 6 5,976' 2-3/8"'XN'Nipple 1.795"No Go 7 5,984' 2-3/8"Cut Tubing TOO 5,450' r 8 6,130' Dropped Baker Model'E'Hydro-Trip Sub/Mule Shoe USlT10/16/02 .' SHORT STRING I (tel'g ) 4 B'' - 2Y*)., A 2,281' HES 2-3/8"'X'Nipple B 5,659' HES 2-3/8"'X'Nipple =0? C 5,680' Baker Model'GT'Retrievable Dual Packer 40KShear C` — D 5,853' Baker Model'Gr Retrievable Dual Packer 40K Shear s ,3 E 5,867' 2-3/8"'XN'Nipple 1.795"No Go N Sands F 5,868' 2-3/8"WLEG—Bottom @ 5,879' D °'4 PERFORATION DETAIL ' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status MnimumlD= �` E ` /�1/(� 1.795"@5,867 �; 'i' ,„=+ i�" 5,710' 5,722' 3,896' 3,905' 12 12 3.5" 2/15/1991 Open F �� N 5,742' 5,758' 3,920' 3,932' 16 12 3.5" 2/15/1991 Open Sands tit4 (4 5,775' 5,782' 3,945' 3,951' 7 12 3.5" 2/15/1991 Open PA5,803' 5,826' 3,955' 3,973' , 23 12 3.5" 2/15/1991 Open OA 5,898' 5,940' 4,038' 4,069' 42 5 5.0" 2/01/1991 Open Mnimumllk 5l OB 5,982' 6,018' 4,101' 4,129' 36 5 5.0" 2/01/1991 Open 1.795"@5,976' � iRef Log:SLB GCT—1/30/1991—Perf Guns 5.0"/37 gram 5 spf;Perf Guns 3.5"/24 gram 12 spf It 6 f.iii OB Sands 7 ; GENERAL WELL INFO -F Feh Tubing Tail API:50-029-22066-00-00 STIMULATION DETAIL @6,133 Drilled&Cased by Nabors 27E—11/05/1990 OA/OB:Frac w/82,7264 16/20 Carbolite Fish:1.75"Ball ': -%, , Frac Pack ESP Completion by EWS Rig—2/18/1991 @6,138' i. 8 Pull&Replace ESP by EWS Rig—12/21/1991 ,' NOTE: Y j , Pull&Run ESPCP by Nabors 4ES-3/08/1995 7 • Pull&Replace ESPCP by Polar 1-6/23/1996 7"Casing Repaired in 2002. TD(MD)=6,260'/ TD(TVD)=4,308' Pull&Run ESP by Nabors 5S—3/16/1998 PBTD(MD)=6,138'/PBTD(TVD)=4,293' Pull&Replace ESP by Nabors 4ES—4/06/2001 Convert to Injector by Nabors 4E5—10/18/2002 Cut long-string tubing tail-8/19/2009 Revised By:STP 8/01/2016 • • , IIMilne Point Unit COIL BOPE MPU I-02 7/21/2016 fIhM1p.Ala4a.LU, MPU 1-02 13% X 9% X 7 X 2%(Dual) 1 's Coil Tubing BOP Lubricator to injection head , 0 al l 1,______J 1.50"Single Stripper I I 1J•��I Blind/Shear ®`1/16 10 —Blind/Shear, 7 '.LLIBIind/Shearr -Nisi =4 Blind/Shear 44 ,O0 —__ Slip Slip ,�,'. sm "`1 1'•'.',) Pipe =— Pipe 1111471 �s - Crossover spool e_ 4 1/16 10M X4 1/16 5M iimi St vi Pump-In Sub 41/16 5M I ' ;: IIIiffl 1502 Union A i i Manual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X2 3/8 5M 6 4 1 ` p= Alai i' —lig Valve,Swab,WKM-M, ' , .�, 2 3/8 5M FE(Long-String) � � h � ,,/ Valve,Swab,WKM-M, III I.11 2 3/8 5M FE(Short-String) °'roc\ .�1=IIII II _-'c' S a5ailI....1i,,,e,‘,1\,.. (11 om - I: 'L''\ illnino Valve,Upper Master,Baker, iplik OO Valve,Upper Master,Baker, 2 3/8 5M FE,w/Hydraulic •IF s • 2 3/8 5M FE,w/Hydraulic (Long-String) El' (Short-String) Valve,Lower Master,WKM-M, ON 2 3/8 5M FE(long String) (.i, \*/''' � Valve, Lower Master,WKM-M, �� ' " 2 3/8 5M FE(Short-String) .w. w4 CrIJ 11.a�wwr. air Tubing Adapter,11 x 7 lit�iMMOMMININIM psi x23/8dual 5M --= S 0 1 I- I2 re S- m .3- • • Ti a ok 0 ..:::•••. E "'",, --'" O a r=4 0 -,; E 7,1 et E • :or 2 gc ' :•:::•••• R Lucc w= .: '' 1 i I 16 r ....._ — IIXZZO Loi ...... i-- IN 4.,,,,j ..,.... .-- te)-. .”, no. ... .. 0 I ,..-•• z ....: < --; ez • .-, > m ••• Z 0 ..."'' ;,,, ¢ .... < :".% L,'_, •- `>' u 2 --g 5 • : : a... _ •,,.. -: > cD 0:1 c.: a. 45-0-141/111 —101..; f ; o -si f I 4 g 1, .' ..,.. Mill IIIIN, ,• 7 A .E a. 4 4 . 1 u u 5 a i•77 .-- ,.'J- ___ in gm ini mi ,-----i--- = AI E....-7 :71 I 11 mum* 0 /liwiim .4- 41.011i -4101 a _f_ •''' 1111 III IIII IIII DODO 1 i i w NJ Z ,.. 9 iLI! < i ..... :-. ..-. .. Ce 0. U. I- 0 o 0 0 0 . 7 4 d 2 2 co 8 LA 04 4 e- I. 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg31?-01\ 15 DATE: Tuesday,March 17,2015 P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests s l-IILCORP ALASKA LLC 1-02 FROM: Bob Noble MILNE PT UNIT SB I-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB 1-02 API Well Number 50-029-22066-00-00 Inspector Name: Bob Noble Permit Number: 190-091-0 Inspection Date: 3/12/2015 Insp Num: mitRCN150312160654 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-02 Type Inj W• TVD 4001 • Tubing 759 763 • 766 - 766 PTD 1900910 - Type Test SPT Test psi 1500 IA 104 1815 1748 - 1745 Interval!4YRTST IP/F l P '' OA � 12 17- 18 18 - Notes: I`i��1rt 3 .t sopa Tuesday,March 17,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i qO ~' I~ [ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~ Bren Vincent Nathan Lowell D TO RE-SCAN Date:~c ~' 02 Is' ~ Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 14, 2011 TO: Jim Regg 251 11 P.I. Supervisor C SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I -02 FROM: Jeff Jones MILNE PT UNIT SB 1 -02 Petroleum Inspector Src: Inspector Reviewed B; P.I. Supry J NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB 1 -02 , API Well Number: 50- 029 - 22066 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ110314070613 Permit Number: 190 -091 -0 Inspection Date: 3/12/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1-02 Type Inj. W 1 TVD 3873 ' IA 60 1790 ' 1760 1750 ' P.T.DI 1900910 , TypeTest SPT Test psi 1500 , OA 30 30 30 Interval 4YRTST - p/Ii P - Tubing 900 900 900 900 Notes: 1.2 BBLS methanol pumped. 1 well inspected; no exceptions noted. _, , MAR 0 MI Monday, March 14, 2011 Page 1 of 1 ~ ~ ~`$ ~ ~ ~=y~ ~ ~ . ~ ~ , ~ ~ ~~`~~ ~ ~~`~.~ ~ ,~i" a.~ ~ °, ~ ~ ~ ~; ~ ~ ~ ~ ~ ~~~ ~ ~ 4'~ ~~~ ~ ~ ~ ~ ~ ~ ~ ~~~ ~~ ~ ~ SEAN PARNELL, GOVERNOR ~~e ~ ~ ~..~ ~ ~.~:,~ ~ ~ a a t ~ a ., , , ~~ ~ ~ fi ~~,~ ~~s~ ~ H ~~ ~~ „~n ~ } ~ R ~ ~ a=A~i~. `~~ ~„Y F.~ _ ~ ~ ~ ALAS~ Du A1~TD ~S ~ COI~TSERQATIOI~T CO1~II~IISSIOI~T ~~ 333 W. 7th AVENUE, SUITE 100 ~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 ; FAX (907) 276-7542 Mr. Keith Lopez Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~o~l ~~b Re: Milne Point, Schrader Bluff Oil Pool MPI-02 Sundry Number: 309-328 °, „*::~~ ~ ^~tzr;r~ ~ n ,__ ._ r~ , Dear Mr. Lopez: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair h DATED this 2Zday of September 2009 Encl. STATE OF ALASKA ALAS L AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS ~n nnr ~~ ~nn 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Re-enter Suspertded Well ^' Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate Q. Other ^ S~Cify: Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 190-0910 ~ 3. Address: P.O. Box 196612 5tratigraphic ~ Service ~. 6. API Number: Anchorage, AK 99519-6612 50-029-22066-00-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: /,,p MPI-02 ~~+ Jo ~ Spacing Exception Required? Yes ^ No ^ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-025906 • MILNE POINT Field / SCHRADER BLUFF OIL Pooi • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Totai Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6260 ' 4312.35 ~ 6221 4283 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 71 13-3/8" 54.4# K-55 SURFACE 106 SURFACE 106 2730 1130 Surtace Intermediate 2765 9-5/8" 36# K-55 SURFACE 2800 SURFACE 2384 3520 2020 Production 6186 7" 26# L-80 SURFACE 6221 SURFACE 4283 7240 5410 Liner Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2-7/8" 6.5# L-80 SURFACE - 5424' Packers and SSSV Tvpe: 7" OTIS AWD SUMP PKR Packers and SSSV MD and ND (ftl: 5863' 4015' 7" OTIS VST VERSA-TRIEVE 5517' 3751' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ~ Service ^~ r 14. Estimated Date for 15. Weli Status after proposed work: Commencing Operations: 9/21/2009 Oil ^ Gas ^ WDSPL ~ Plugged ^ 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 KEITH LOPEZ Printed Name EITH LOPEZ Title WELL ENGINEER Signature Phone Date 564-5718 9/15/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~9J~ f~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: ~ O " APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z 2 "~~F ~~? ~~~.. ~ ~a~ ~j~ t3~ ~ ~. /G-~ i ~- ~ ~ - ~=~~~~ ~ R ~ G I !~ A L ~~ ~ ,1~, ~~~~~ Form 10-403 Revised 07/2009 ~~ ~/~~~ Submit in Duplicate M PI-02 190-091 PFRF oTT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI-02 2/19/91 PER 5,710. 5,722. 3,898.4 3,907.55 MPI-02 2/19/91 PER 5,742. 5,758. 3,922.78 3,934.96 MPI-02 2/19/91 PER 5,775. 5,782. 3,947.89 3,953.21 MPI-02 2/19/91 PER 5,803. 5,826. 3,969.16 3,986.6 MPI-02 2/19/91 PER 5,898. 5,940. 4,041.02 4,072.64 MPI-02 2/19/91 PER 5,982. 6,018. 4,104.21 4,131.22 MPI-02 10/17/02 STC 5,677. 5,849. 3,873.22 4,004.02 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • , . • • ~~ To: From: BP Exploration Alaska Milne Point Jerry Sharp/Mark O'Malley MPU Well Operations Supervisor Keith Lopez Tract 14 Engineer Subject: MPI-02LS Acid 5timulation Date: 9/ 14/09 IOR: 50 bopd AFE: MSIPDWL02 COST: $ l OK Cate ory Ste Descri tion F 1 Pum Acid Job WELL INFO: 1. Well status: Both strings on water injection. 2. Minimum I.D.: a. SS: 1.791".at 5867'MD - 2-3/8" HES XN nipple b. LS: 1.791" at 5976'MD - 2-3/8" HES XN nipple c. LS: Fish (tubing tail) @ 6007' MD 3. Pressure: a. LS: 2135 psi @ 4000' TVDss (3/16/07) b. SS: 2056 psi @ 4000'TVDss (3/15/07) 4. Maximum wellbore angle through tubing is 69 deg at 4023'MD 5. Hole angle through perfs: 41 deg 6. Last downhole ops: LS tag after tubing tail cut @ 6007' MD on 8/19/09 7. Last PBTD tag: LS 6007' on 8/19/09 OBJECTIVES: Pump acid down the LS to stimulate the OB zone and increase injectivity. . BACKGROUND MPI-02 is a dual string Schrader Bluff injector. The well was converted from a commingled producer to an injector in 2002. The well has had a breakthrough event with MPI-15 and it is • unknown whether the breakthrough was in the OA or OB. String communication has been .~ • . suspected since 02' and was verified with a pulse test in 03'. The communication seems to be stronger from LS to SS but there is evidence that there is some pressure connection SS to LS. It is suspected that the cause of the communication is either a tubing leak in the LS or a packer failure (packer @ 5960'). LS A TD tag was attempted in the LS on 4/11/09 but could not get past 5974' SLM. An LIB recovered a semicircular impression thought to be a bent collette finger in the Baker `E' Hydro Trip Sub @ 5984'. A XN plug was then run and set in the XN nipple after some difficulty getting down and a brush and flush. An attempt to MIT the tubing failed as it pressured up to 2500 psig pumping at 0.2 bpm and bled off to 1300 psig in 4 minutes. A Schmoo-be-gone treatment was conducted on 6/8/09 with little increase in injectivity observed. The LS tubing tail was cut off (below the XN nipple) on 8/18/09. A tag was made and found the severed tubing tail @ 6007' MD estimating 11' of fill above the bottom perf leaving 25' of OB perfs open. The plan forward is pump a HCL acid pill down the LS while keeping the SS on injection. , DETAILED PROGRAM: MPI-025S Keep the SS on injection at 1050 psig throughout this procedure (this is to discourage the fluid pumped in the LS from communicating across to the SS) FB - MPI-02LS 1. MIRU pump truck to MPI-02LS 2. Pump 5 bbls MEOH spacer. Pump 30 bbls of 12°Io HCl DAD acid @ 0.5 bpm without exceeding 1500 psig tubing pressure. Pump 5 bbls MEOH spacer. 3. Allow LS to soak for 90 minutes. 4. Return LS to injection for 10 bbls without exceeding 1050 psig 5. Allow LS to soak for 90 minutes. 6. Return LS to injection targeting 500 bwpd with m~imum wellhead pressure of 1050 psig. Please contact Keith Lopez at 564-5718(w) or 903-5432(c) with any questions. Tree: CiW 2-3/8" 5M Dual siring 7 Weilhead:ll" x 2 3t8" 5M FMC dual sfring Hanger thread 2 3/8° 18T top and 6ottom 2" CIW-H 8~'V profile 13-3/8",5a.5 #fft, K-55 Weld Set 166' ~ P U'~42 f Orig. DF EEev. = 68.5 (27 E} . .: Orig. GL Elev. = 35.0 (27 E) Shdr# Strm9 2-318` HES X-Nlpple (1.875" pkg. bore} 2,28t' 9-5l8". 36 #IR K-55 Buft 2800` KOP @ 500' Max. hole angie = 69 deg @ 4023` Hole angle tF-ru perEs = 41 DEG. 7" 26#. 1-80. 67RC Casing (drift id = 6.15t, cep.= .09g3 bP~ 2-3/8". 4.7 #!ft L-80.18'C iubing {drift id = 1.90i, cap.=.OQ3$7 bPfl 2-3t8" HES X Nipple {9.875" pkg. bore) 5,659' N-Sands Stradd3ed Size Spf fntervaf Tvd 92 5,714' - 5,722' 3,896' - 3,905' 12 5,742' - 5,758' 3,920` - 3,932' 12 5.775` - 5,782' 3,945` - 3,951' 12 5,$03' - 5,826' 3,955' - 3,973' 2-3l8" HES XN-Nippte (1,875" pkg. bore} ~ 8fi7' No-Go t.79i" Tubing tail / WLEG 6,879` 5ize Spf lntervat Tvd 5 OA sands 5,888' - 5,940' bB sands 4,038' - 4,069' 5 5,982'-6,01$' 4,101`-4,728' 7° Halli~urton float shoe 6,221` T° Halliburfon F'loat Cotiar P6Tf3 6,260' 1.15" bafl. 2-3/8" HES X Nippls {1.875° pkg. bore) 2.278' i 2-318" HES X-Nepple (i.875° pkg. bore) 5,~4' 7" x 2-3/8° Baker "GT" Rei. dual pkr. 5,677` 1.945° ID. 7" x 2-3(8" Baker "Gl'° Ret. duaE pkr, 5,849' 1.845"ID. 7" x 2-3/8" Baker "FH" Rei, pkr. ~~ggp~ 2-3l8" i1ES XN-Nipple (1.875" pkg. bare) g.976' NaGo i.79i° 2-3l8" Baker `E' Hydro Trip Sub 5,384' (2.00" pk8- bore) ~ Tubing tail / 1/Y[.Et3 5>g89' QATE REV. SY COMMENTS MILNE POINT UNiT 10/17/02 MDO Cornerted from ESP to Dual tnjector 4-ES {~yELL No.' 1-0Zi API : 50-029 22066-00 BP EXPLORATION (AKj • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, September 17, 2009 9:10 AM ~~~~ ~~ To: 'Lopez, Keith' Subject: RE: MPI-02i acid stim (PTD- 190-091) Keith, Thanks for the reply. Was just making sure we are confident that the acid will stay out of the IA during the job. L-.fS7 /~t- / T - ~i4 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Lopez, Keith [mailto:lopek3@BP.com] Sent: Wednesday, September 16, 2009 4:57 PM To: Schwar~, Guy L (DOA) Subject: RE: MPI-02i acid stim (PTD- 190-091) 3-31- zoo7 Yes, to the best of my knowledge the IA is not in communication with either tubing strings. There was no response in the IA pressure during the pressure test of the LS. The IA halds a substantial pressure differential from the two strings (+/- 700 psig). Keith Lopez Wells & Subsurface Engineer Milne Point - Alaska BP Explorcrtion A/aska, lnc. Offite (907)-564-5718 Cell (907)-903-5432 . .,. . R~; ... _ . , . _ _ __ _ _ _ _ _ From: Schwariz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, September 16, 2009 3:49 PM To: Lopez, Keith Subject: MPI-02i acid stim (P'TD- 190-091) Keith, I am reviewing the sundry application to acid stim MPI-02. 1 saw you pressure tested the LS tubing with a plug in the XN tubing tail. Did IA respond at all? ~an I assume the IA has integrity? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 9/17/2009 • , Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, August 31, 2009 3:44 PM To: Maunder, Thomas E (DOA) Subject: Emailing: MPI-02 TUBING-PACKER ATTACHMENT.doc Attachments: MPI-02 TUBING-PACKER ATTACHMENT.doc ~~ MPI-02 ~R~G~ ~S ~ ~ ~ ~ ~ G-PACKER ATTACHI ~'tiC t1 C~ t~^~,~ ~ The message is ready to be sent with the following file or link attachments: MPI-02 TUBING-PACKER ATTACHMENT.doc Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «MPI-02 TUBING-PACKER ATTACHMENT.doc» Page 1 of 1 ~.}.~ "4~~,'`~u ii_.~ .E ~d~~'. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 31, 2009 2:28 PM To: 'Preble, Gary B (SAIC)' Subject: MPI-02 (190-091) Gary, I am reviewing the 404 recently submitted for cutting off the tail pipe on the long string. There is only one tubing string listed on the 404 and neither the depth given for it or the packers do not match the last drawing in the file. Looking closely at the 403, the packer depths don't match there either. Could you reconcile? Thanks, Tom Maunder, PE AOGCC ~~m~ ~ ~~~~~ ~ STATE OF ALASKA ALAS~L AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Pertorations ~ Stimulate~ Other Q~j~T~1f,~~IG TAIL PerFormed: "^`'~-T Alter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver~ Time Extension~ Change Approved Program ~ Operat. Shutdown ~ Pertorate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~!i 19o-oslo • 3. Address: P.O. Box 196612 ,+ • Stratigraphic ~ Service 6. API Number: Anchora e, AK 99519-6612 g 50-029-22066-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 70 KB • MPI-02 • 8. Property Designation: 10. Field/Pool(s): ADLO-025906 MILNE POINT Field/ SCHRADER BLUFF OIL Pool . 11. Present Well Condition Summary: Total Depth measured 6260 ' feet Plugs (measured) None true vertical 4312.35 . feet Junk (measured) None Effective Depth measured 6221 feet true vertical 4283 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 71 13-3/8"54.5# K-55 SURFACE - 106 SURFACE - 106 2730 1130 INTERMEDIATE 2765 9-5/8" 36# K-55 SURFACE - 2800 SURFACE - 2384 3520 2020 PRODUCTION 6186 7" 26# L-80 SURFACE - 6221 SURFACE - 4283 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 S E- 5424' ('1 ~~0 0 C ~~ ~ SE,E. ''V Packers and SSSV (type and measured depth) 7" otis awd sump pkr 5863' ~~,, ~ 7" otis vst versa-trie 5517' ~ ` 0 ~~ ~ 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 447 1375 Subsequent to operation: 585 1091 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment T° Senrice ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG r GINJ ~ WINJ ~' ' WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-239 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 8/26/2009 ~`1~J~ 2 'm "1_~G3 '~'~ ~. K v ~:I h ~~C~E~ ~ Q' 7 ~'~~~ Form 10-404 R vised 04/2006 ~" R" ,.- ~ ~~Submit Original Only v ~/ . .~.~ ~~. ,~~ fD ~ ?!J(t~~ ~~ „/~~C(~ ~7~~, • • MPI-02 1: SO-091 TUBING AND PACKER ATTACHMENIT Tubing size grade and measured depth: Dual Tubing: 2-3/8" 4.7# L80 tubing to 5879' 2-3/8" 4.7# L80 tubing to 5989' Packers and SSSV type and measured depth: 7 x2-3/8" Baker GT Ret Dual Packer at 5677' and at 5849' 7 x2-3/8" Baler FH Ret Packer at 5960' ~'P@~~- Q4c~ ~ ~~~~~ ~ M PI-02 190-091 PFRF ATTO(:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI-02 2/19/91 PER 5,710. 5,722. 3,898.4 3,907.55 MPI-02 2/19/91 PER 5,742. 5,758. 3,922.78 3,934.96 MPI-02 2/19/91 PER 5,775. 5,782. 3,947.89 3,953.21 MPI-02 2/19/91 PER 5,803. 5,826. 3,969.16 3,986.6 MPI-02 2/19/91 PER 5,898. 5,940. 4,041.02 4,072.64 MPI-02 2/19/91 PER 5,982. 6,018. 4,104.21 4,131.22 MPI-02 10/17/02 STC 5,677. 5,849. 3,873.22 4,004.02 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • ~ ~ MPI-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/18/2009!***WELL (LS) SHUT-IN ON ARRIVAL""" (E-LINE: JETCUTTER) ~ INITIAL T/I/O: 750/0/0 PSI j CUT TUBING @ 5984' AS PER PROGRAM. ~ CCL TO CUTTER: 4.2' CCL STOP DEPTH: 5979.8' ~ FINAL T/I/O: 1000/0/0 PSI. NOTIFY PAD OP. RDMO I"*"LS STRING SHUT-IN ON DEPARTURE**" 8/19/2009~***WELL S/I ON ARRIVAL"''* (LONG STRING) i RAN 3' X 1.5" STEM, 1.75" CENTRALIZER, SAMPLE BAILER TO 5974' ~SLM ( SETTING DOWN IN XN NIPPLE) ~ RAN 3' X 1.5" STEM, 1.75" LIB TO 5998' SLM (IMPRESSION OF COLLET iIN HYROTRIP) ;TAKING CORRECTION OFF OF PREVIOUS TAG OF XN NIPPLE. iCUTOFF TAILPIPE ASSEMBLY IS AT 6002' MD + 5' FOR TUBING TAIL = i6007' MD FOR TOP OF FILL. ESTIMATE 11' OF FILL OVER BOTTOM ~ PERF. ~ ~ ~ ~~~ j*""JOB COMPLETE, RDMO""* FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL • • ~ ~ ~ ~~ ~~ / ~ ~ ~ SARAH PALIN, GOVERNOR t ~ ~ ~ Mr. Chidiebere Igbokwe Petroleum Engineer BP Exploration (Alaska) Inc. , j ,, ~~ a~ c~ P.O. Box I96612 ~'~~~~~~"~ J ~ ~' % ~`i Anchorage, Alaska 99516-6612 Re: Milne Point Field, Schrader Bluff Pool, Milne Point Unit I-02 Sundry Number: 309-239 ~ " ~ ~ Dear Mr. Igbokwe: ~ 1 ~ 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. When providing notice for a representative of the Ccmmission to witness any required test, contact the Comrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, withuz 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 Comrriission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30. PM on the 23rd day following the date of this letter, or the ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ DATED this ~ day of July, 2009 Encl. Daniel T. Seamount, Jr. Chair O~ V~ ;~~t~ ~ STATE OF ALASKA ~ ~~ ALAS~OIL AND GAS CONSERVATION COMM~ON ~,1~ APPLICATION FOR SUNDRY APPROVALS ~ 20 AAC 25.280 ~Gt~/~I 4/ ~~ ~ ,.~~~ ~. ~ ~Ll~~ ~~~ , : . _ n:! 4. C_ae ('e-C!~ ~.~iY§1'~~~'~a~~Sa 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ ` aiver ~~~~~~,~~~~~,Other Alter casing ~ Repair well ~ Plug Perforations ~ Stimulate ^ Time Extension ~ CUT TUBING TAIL Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ r/.~.i 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 190-0910 • 3. Address: P.O. Box 196612 Stratigraphic ~ Service Q~ 6. API Number: Anchorage, AK 99519-6612 50-029-22066-00-00 ~ 7. If perforating, closest approach in pooi(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ ~~ ~~'~~ ~' ~~'-~ ~ ~~ /~ ~ Spacing Exception Required? Yes ^ No ^ ~/ ~ 7i ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~, ` ADLO-025906 ~ 70 KB ° Milne Point Field / Schrader Bluff Pooi . 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6260 ' 4312.35 ~ 6221 4283 NONE NONE Casing Length Size MD ND Burst Collapse Structurai Conductor 71 13-3/8" 54.5 # K-55 SURFACE 106 SURFACE 106 2730 1130 Surface Intermediate 2765 9-5/8" 36# K-55 SURFACE 2800 SURFACE 2384 3520 2020 Production 6186 7" 26# L-80 SURFACE 6221 SURFACE 4283 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 2-7/8" 6.5# L-80 SURFACE - 5424' Packers and SSSV Type: 7" OTIS AWD SUMP PKR Packers and SSSV MD (ft): 5863' 7" OTIS VST VERSA-TRIEVE 5517' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ^ Service Q~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/24/2009 , Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ Q• WDSPI ^ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Giovanna Boccardo Printed Name ~ Chidiebere I b k e Title Petroleum Engineer Signature t}~, ~% Phone Date t `~;: a, ~ ti " '~ ~ ~ >' ~ ` 564-4795 7/10l2009 °"~. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ y~ a~ ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~-~~ CCj,~~~ CLC v`'i e i~-'~~J~..'t~ `~. GCL~ ~~( Pv ~C., a-S . c~ b~ l- Subsequent Form Required: '~^`oy ~~~~ i~~° ,~U~- ~ ~3 ~~~~ l ~ APPROVED BY ---- ~~ ~ ~ / ~/ ~/ ~ i Approved by: COMMISSIONER THE COMMISSION Date: / ~ ~~~ ~, ~ U~IUiNAL ~~ ~,~~~ Form 10-403 Revis 06/2006 Submit in upiicate -~-r//v/GlY MPI-02 190-091 PFRF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPI-02 2/19/91 PER 5,710. 5,722. 3,898.4 3,907.55 MPI-02 2/19/91 PER 5,742. 5,758. 3,922.78 3,934.96 MPI-02 2/19/91 PER 5,775. 5,782. 3,947.89 3,953.21 MPI-02 2/19/91 PER 5,803. 5,826. 3,969.16 3,986.6 MPI-02 2/19/91 PER 5,898. 5,940. 4,041.02 4,072.64 MPI-02 2/19/91 PER 5,982. 6,018. 4,104.21 4,131.22 MPI-02 10/17/02 STC 5,677. 5,849. 3,873.22 4,004.02 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . • ~~ To: From: BP Exploration Alaska Milne Point C. Olsen/J. Bixby ADW Wells Ops Supervisor Jerry Sharp/Mark O'Malley MPU Well Operations Supervisor Keith Lopez Schrader Bluff Production Engineer Subject: MPI-02LS Cut Tubing Tail Date: 6/24/09 IOR: 100 bopd A~; MSIPDWL02 COST: $30K Cate o Ste Descri tion S 1 Drift for 1.68" Jet Cutter E 2 Cut off tubin tail at 5984' ELMD S 3 Ta TD WELL INFO: 1. Well status: Both strings on water injection. 2. Minimum I.D.: a. LS: 1.791" at 5976'MD - 2-3/8" HES XN nipple b. SS: 1.791".at 5867'MD - 2-3/8" HES XN nipple c. Obstruction @ 5984' 3. Pressure: a. LS: 2135 psi @ 4000' TVDss (3/16/0'n b. SS: 2056 psi @ 4000'TVDss (3/15/0'n 4. Maximum wellbore angle through tubing is 69 deg at 4023'MD 5. Hole angle through perfs: 41 deg 6. Last downhole ops: LS MIT on 6/5/09 7. Last PBTD tag: LS 6104' on 9/13/06 OBJECTIVES: Use an E-line deployed jet cutter to cut the LS tubing tail and allow it to fall to the bottom of ' wellbore. This will allow access to the mainbore. SL will then perform a TD tag. " ~ ~ BACKGROUND MPI-02 is a dual string Schrader Bluff injector. The well was converted from a commingled producer to an injector in 2002. The well has had a brea.kthrough event with MPI-15 and it is unknown whether the breakthrough was in the OA or OB. String communication has been suspected since 02' and was verified with a pulse test in 03'. The communication seems to be stronger from LS to SS but there is evidence that there is some pressure connection SS to LS. It is suspected that the cause of the communication is either a tubing leak in the LS or a packer failure (packer @ 5960'). LS A TD tag was attempted in the LS on 4/11/09 but could not get past 5974' SLM. An LIB recovered a semicircular impression thought to be a bent collette finger in the Baker `E' Hydro Trip Sub @ 5984'. A XN plug was then run and set in the XN nipple after some difficulty getting down and a brush and flush. An attempt to MIT the tubing failed as it pressured up to 2500 psig pumping at 0.2 bpm and bled off to 1300 psig in 4 minutes. Plan forward is to cut the tubing tail using a jet cutter and allow it to fall to the bottom of the mainbore. SL will then move in and perform a TD tag to determine if a CT FCO is necessary to increase injection into the LS. DETAILED PROGRAM: Slickline: Drift LS to 5984' MD for 1.68" Jet Cutter a. Note: there is an obstruction in the Baker `E' Hydro trip sub at 5984' MD. E-line• Jet cut 2-3/8" tubing at 5984' ELMD. Tie-in Log: SLB Depth Correlation log Tie-in Injection String 18-October-2002 Slickline• 1. Drift LS and Tag. Please contact Keith Lopez at 564-5718(w) or 903-5432(c) with any questions. Tree: CIW 2-3/8" SM Dual strin Wellhead:11" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" tBT top and bottom 2" CIW-M BPV profile 13-3/8",54.5 #/ft, K-55 Weld Set 106' ~hort Strina 2-3/8" HES X-Nipple (1.875" pkg. bore) 2,251 9-5/8", 36 #/ft K-55 Butt 2800' 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpfl 2-3/8", 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bp~ 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,659' N-Sands Straddied Size Spf Interval Tvd 12 5,710' - 5,722' 3,896' - 3,905' 12 5,742' - 5,758' 3,920' - 3,932' 12 5,775` - 5,782' 3,945' - 3,951' 12 5,803' - 5,826' 3,955' - 3,973' 2-3/8" HES XN-Nipple (1.875" pkg. bore) 5,867' No-Go 1.791" Tubing tail / WLEG 5,879' Size Spf Interval Tvd 5 OA sands 5,898' - 5,940' OB sands 4,038' - 4,069' 5 5,982' - 6,018' 4,101`- 4,129' 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,849' 1.945" ID. 7" x 2-3/8" Baker "FH" Ret. pkr. 5,960' 2-3/8" HES XN-Nipple (1.875" pkg. bore) 5,976' No-Go 1.791" 2-3/8" Baker'E' Hydro Trip Sub 5,984' (2.00" pkg. bore) ~ Tubing tail / WLEG 5,989' 7" Halliburton float shoe 6,221' ~ 7" Halliburton Float Collar PBTD 6,260' DATE REV. BY COMMENTS 10/17/02 MDO Converted from ESP to Dual Injector 4-ES MILNE POINT UNIT WELL No.: I-02i API : 50-029-22066-00 BP EXPLORATION (AK) 3/8" HES X-Nipple (1.875" pkg. bore) 2,278' I 2-3/8" HES X-Nipple (1.875" pkg. bore) 5,660' 7" x 2-3/8" Baker "GT" Ret. dual pkr. 5,677` 1.945" ID. M P U I~~2 ~ i9• DF Elev. = 68.5 (27 E) Orig. GL Elev. = 35.0 (27 E) [Fwd: 1-02i 7" casing failure] Subject: [Fwd: 1-02i 7" casing failure] Date: Sat, 23 Nov 2002 08:03:09 -0900 From: "Jeff B. Jones" <jeff_jones@admin.state.ak.us> Organization: AOGCC To: Tom Maunder <tom_maunder@admin.state.ak.us> Hi Tom, Here is some more info on the 1-02 7" casing failure regarding the electric cabling removed from the well. Thanks, Jeff Subject: RE: 1-02i 7" casing failure Date: Sat, 23 Nov 2002 10:35:40 -0600 From: "Hasebe, Brant M" <HasebeBM@BP.com> To: "Jeff Jones (E-mail)" <jeffjones@admin.state.ak.us> CC: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> Jeff, Apologies for the delay in response. For some reason I had this sitting in my "Drafts" box and just now realized it... Our Centrilift crew takes good notes during workover operations and pay particular attention to potential cable failures and the like. During the pull in question, the heat trace cable was found to be good and balanced phase to phase and phase to ground with no indication of compromise. The ESP cable had a few armor blowouts the last 1000' to the ESP, but this didn't result in an electrical compromise and also is far below the location of the casing leak. It should be noted that this well had been worked over with new equipment after the Paratrol heating system in question was replaced. Let me know if you have any other questions and we'll keep you appraised of any changes in the existing wells. Regards, -Brant ..... Original Message ..... From: Jeff B. Jones [mailto:ieff iones@admin.state.ak.us] Sent: Sunday, November 03, 2002 2:33 PM To: MPU, Wells ESP Coord Cc: Tom Maunder Subject: Re: 1-02i 7" casing failure Hello Brant, thanks for the information regarding MPU well 1-02 and the other wells which were operated with this type ( Paratrol ) of system that you and Jack Merrifield have provided. I do have one question: what is the condition of the ESP/heat trace cabling ( in the area relative to the depth of the hole in the 1-02 7" casing ) that was removed from well 1-02 during the recent injector conversion? Has this cabling been checked for damage? The increased surveillance you described of these wells appears warranted and please keep the AOGCC informed of any problems that arise in the future regarding this topic. Thanks again for the information, Jeff Jones AOGCC I of 3 11/25/2002 4:46 PM C3 ~ I LL. C3 ~ C3 C3 a.. "- "- co I t- I ~ " If l .-li. I e I:) .... I.L e tU ....,. CQ "- ~ ~ ~ I CÐ I ...... u C> STATE OF ALA~t\A ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanlcallntegrlty Test E-MaU to~ Tom_Maunder@admln.state.ak.us and Bob_Fleckenstein@admln.state.ak.us OPERATOR:BP F'ELD / UNIT I PAO~ .MiLNE POfNT UNiT DATE: October 18J 2002 1Jv'GI( ~!"., " PERMit 'l' ';~ :,:~; ',:. :" r·}i. ~:. <;' y. i;,.l· ¡ ::'/ ,,;:; ,"{.~" ';> ·r,'· ":'r:: i'.· :i ":' : ....:.j: .:\ ,\., .;<. ,~. :' :'. '. ~:-t': ,. ~ ;i ·P..~tEst: : ·.~T AR1;:;;tM'I~ ;;;Ç~3If"'(I'e; ;'¡," ">" ~: . :y¡ : ":::y ~·.'.~~~~~~~'~¡i ~ 1: . /.~ 'WEµ :·l.(~ 'r.I:.Ulp~'.,: 1 ,I P=ï: ;: .:~ F.L:Olu.~ : ~,r\"::<'~D'~ 1~6. ~~. 81...e JWT·::,G~OJ2.,;,~·;.slZ~ ': ~~P8ESS-J ~." PRESS! " ~; . i C$G I . " 7::. 'ÇSG:-· ::-~ '::,': ÇSG',:-. ~ , : ~tIME:'-'-~:1 :. :+~: ..~.~.,,', '{~~;,~~·,~}NtíM.ËR~.~~~\·: :~~?<": ·~.-~~{{~:f;:.~ ';,"?()' ~ ::' "'~'¡~;~):'~~':,:~'..,:,:"::,:". :"~~·::~::'~:·~'/":~·::":-;:'=t·Z:..::';:.~~.:~,~.':;: ~:~~T;;}~:: ..~.:::~ .?~.:::..;':/:.~.~-r;.':~':.~~:~:j:..;:: j~: ÞRÊ$$,~ ;:~·P.RE·~,S,.~··¡:~· PR'ESS~: ?;~:··~:?~?::.:I:;: ?;n,:::~t): I -- - -". N M' BRINE, 411 DO 7P126tlL80 : 2..318/' : 3J 000 3) 000 . 3.000 . 3,000 X . Wen,: MPI-02 'i P1ESEL 5)675 4.7 ; 1025 2,000 2.060 ~ooo 2)000 COMMENTS: MJT TeST WAS PERFORMED IN 1WO STEPS TBG. TO 3000 SET PKRS & MONITOR 3D-MINUTES /BLEED TBG & PRESSURE ANNULUS TO 2000 & MONiTOR, . PTD: ' i. . . '¡ Well #: COMMENTS: MPI-02 API. ~ 5()"~9-22086 PERMJT # 190-091 SHARDER INJECTOR OA & DB SANDS. PTD: ' Well #: COMMENTS: PTC: Wen #: . COMMENTS: PTD: WeU #: COMMENTS: TBG. INJ.. FLUID CODES F = FRESH WATER 'NJ. G = GAS INJ. S = SAlT WATER lNJ. N = NOT iNJECTING TEST TYPE: M = ANNULUS MONtTORING P = STO ANNULUS PRESSURE TeST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST Q = D1FFERENTtAL TEMPERATURE TEST ANNULAR FLU'D: P,P .G. Grad. D1ESEl 6.5 0.34 GLYCOL SALTWATER '10.2 0.53 ORIU..ING MUD OTHER WELL TEST: Initial X 4 w Year Workover Other D161ribut'lDn: 0'"'9 - weO F~'& c - Operalor c - Database Sheet revised by L&!.-Q9flle c - Ins.pector LARRY MYERS . AOGCC REP SIGNATURE: OPERATOR REP SJGNA TURE: CHUCK SHéVE (WA'VEDl ". REeerVED OCT 2 1 2002 - Alàska Oil· & Gas Qons. CommlllJon '-: Anchorage rl . qD'" ()~\~~ \ ...C~ Copy of MP B..Q2 M~T 10'1912002. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill, ~'~ Commissioner THRU: Tom Maunder, P. ,. Supervisorp'~ '\~,~'~_ FROM: Jeff Jones, Petroleum Inspector DATE: October 11, 2002 SUBJECT: Investigation 7" casing failure Well UPI-02 BPXA Milne Point Field/MPU October 11, 2002: I traveled to BPXA's Milne Point Field well MPI-02 to investigate a 7" casing failure. On my arrival at Nabors rig 4ES to witness a BOPE test, I met and discussed the rig work over (RWO) with BPXA representative Larry Myers, who was in charge of the operation. Well MPI-02 was an Electric Submersible Pump (ESP) completionbeing converted to a multi-zone injection well. During the RWO, a casing integri~test determined that the 7" buttress casing was leaking. A drill pipe conveyed packer (RTTS) was used to identify the location of the leak: a 15' section of casing at a depth of between 407' MD and 422" MD. A leak rate of approximately 1.5 BBL/min. @ 1500 PSI was noted. The upper approx. 500' of 7" casing was cut & removed, and new 7" buttress casing was installed to surface and set on emergency slips at the wellhead. A new emergency pack-off was installed with a "B condition" tubing spool and tested successfully. Well MPI- 02 was re-completed as a dual injector. I inspected the damaged 7" buttress casing and noted a circular hole in the caSing that measured approx. ¼" diameter on the outer surface and approx. %" diameter on the inner surface. The hole, in my opinion, appeared to be "burned" or "melted" in the casing rather than a split or fracture of the pipe. I spoke with BPXA Milne Point Field Supervisors Mike Hefley and Jack Merrifield regarding the casing failure and requested that the cause be investigated and reported to the AOGCC. I also requested that the shielded ESP electric and heat trace lines removed from well MPI-02 be inspected for damage in the area that corresponds to the depth of the 7" casing damage. BPXA MPU Artificial Lift Coordinator Matt Linder investigated this item but was unable to find any damaged cabling. He indicated that if there was damaged cabling it was probably removed from the well during one of several RWO's that were performed between 1991 and 2002 and is not available for inspection at this time. Photographs of the 7" casing and the affected area is attached for reference. MPI-02 7 inch Casing Failure 1 O-11-02 JJ.doc Summary: I inspected a 7" casing failure that occurred on BPXA's Milne Point Field well MPI-02. Attachments: MPI-02 7" casing photographs (2) Mpu Lead Tech J. Merrifield Report (3) v/' MPI-02 Well & Wellhead Schematics & RWO History (18) BPXA Daily Operations Reports (3) E-mail from Brant Hasebe BPXA MPU ALC (2) NON-CONFIDENTIAL cc: MPI-02 7 inch Casing Failure 1 O-11-02 JJ.doc Tests performed on the original insulating doughnuts installed in the two failed applications, determined that the doughnuts had some conductive properties and may have help cause the failures. So the manufacturer was contacted and a different material was used to mold replacements. The 1-02 well was the first to have these replacement insulators installed. The 1-02 Well was unlanded and raised and it was found that the E-SUB had failed and arced across the inlet and outlet. The E-SUB was replaced. Since the workover rig was in place it was decided to replace the insulating doughnuts that fitted between each joint of tubing. A Time Delay Reflectometer (TDR) had been rented and brought on site to investigate the failures. A TDR will inject a signal and reflect back the distance to where the short occurred. However, a TDR is primarily used on insulated wire with known capacitance values. Since the capacitance values of the system were not known, the exact distance to the shorts were never determined. As the 1-02 ESP and tubing was run in the hole, the electrical characteristics were monitored on the insulated tubing. Each time the tubing was in the wellbore to about 500-700 feet the tubing went shorted to ground and the process was stopped and the tubing pulled. Repeated attempts and different torque values were done on the tubing joints to insure the doughnuts were compressed to seal them. Eventually even though the tubing was shorted it was determined to land the completion. The reason we continued to indicate a shorted condition was unknown and after 8 days of work over it was determined to just run the completion and hope it would work under current. After the surface hook up was reinstalled the Paratrol system was activated and it tripped the breaker. It was determined to indeed be shorted and pulled about 1300 amps at 186 VAC single-phase. The Well ESP was never started. After a week of additional troubleshooting and investigation it was determined to utilize a ESP variable speed drive to limit the power to the Paratrol system to the current that was being pulled by the J-05 and 1-01 wells which had successful Paratrol installations. This connection was made and the 1-02 Paratrol system was activated at the VSD limitations of 241 amps. The voltage I remember was in about the 20 VAC range. The ESP was started but the well froze up after several days of operation. Additional attempts were made to install the Paratrol systems on the I-4 and J-4 wells but also never met with success. All failed at a TDR reading of 500-800 feet down hole. The 1-01 and J-05 never shorted and ran until their ESP's failed and required work-overs. The Paratrol systems were replaced on those wells with the present UL approved heat trace systems for downhole applications. The J-05 well Paratrol system operated in excess of 44,000 hours. The concept was not continued in 1993 due to the poor overall success rate. Of the 8 attempts to utilize this system, only 2-of the systems ever operated successfully (I-01 and J-05). 1-01, 1-02, 1-04, J-05, J-07, and J-04 all had a Paratrol System installed for either operation or an attempt at operation. Of all the systems installed the current limit operation was only performed on the 1-02 as I remember. Results: The failed systems were eventually removed and discarded; it is believed that the doughnut actually held the seal to the wrap on the upper and lower side of the two joints as intended. However the well was under work over operation and was killed with water, seawater, or brine. As the Tubing was lowered into the well bore the pressure on the outside of the seal far exceeded the interior pressure on the inner ID of the doughnut. Once adequate head caused a sufficient-over balance condition, the kill fluid-penetrated the doughnut seal surface and made a conductive path to the tubing. The paths that occurred near the inner surface of the inner annulus provided an early current path before the current reached the contactor at 3500 feet where the well would have adequate distance for the applied voltage. Looking at the failed casing that was removed from 1-02 it is my opinion that when the Paratrol system was operated in current limit at the Iow voltage, the casing was under a continual arcing condition. The surface of the metal was heated and material was lost. Either at that time or sometime since then the integrity failed at that point and was not detected. As of now, no Paratrol systems are in operation on any Milne Point Well. I do not know of any additional wells that have ever had this issue. It is unlikely in my oPinion that the ESP cable could ever fail and cause a similar failure on a well casing. Jack S. Merrifield Jr. MPU Field Lead Tech 907-670-3359 • • Maunder, Thomas E (DOA) From: Jeff B. Jones [jeffjones @admin.state.ak.us] Sent: Wednesday, October 16, 2002 10:49 AM To: Maunder, Thomas E (DOA) Subject: CGF gas release report and MPI -02 7'casing photos Attachments: Hydrocarbon Release CGF LTS3GLX 10 -12 -02 JJ.doc; CGF GTLX Train3.2.JPG; CGF GTLX Train 3.4.JPG; CGF GTLX Train 3.JPG; CGF GTLX Train 3.3.JPG; MPI -02 7in.csg.JPG; MPI -02 7in.csg.3.JPG; MPI -02 7in.csg.2.JPG Hydrocar. ,n CGF G CGF GT rain CGF GTLX in CGF GTLX in MPI -02 7in.csg.JPG MPI -02 elease CGF LT ,GL. Train3.2. G 3.4.JPG 3.JPG 3.3.JPG 7in.csg.3.JPG o hti , MPI -02 7in.csg.2.JPG Hello Tom, attached is a report on the gas release at CGF and some photos of the hole in the 7" casing that 4ES removed from well MPI -02. The hole in the casing is approx. 1" diameter on the inside and approx. 1/4" diameter on the outside. The folks at Milne Point Facility suspect that either the ESP power cable or the heat trace cable was arcing (480 V) against the casing and caused the failure. I have some attachments and supporting documents that I will bring to town for your review. Chuck just called and the AA Prudhoe flight for this morning was cancelled due to a mechanical problem. He said they scheduled one for this evening. I don't know how that will work for the performance review meeting we had planned, but we'll work it out. Thanks, Jeff 1 s MPU SB I -02 (190 -091) 7" casing hole October 16, 2002 ,, s . �� 4, .. F '._ h 4.$'Yk� aM iq �� ,, "a -^ * Vii% �" • ,:' � AA�R - _ $ t4 '45 a "v u' . i . z u ? . x q E , ; mss;, ;, y , t 13 . PM MPU SB I -02 (190 -091) 7" casing hole October 16, 2002 ' ''i:', .A'•':•''•1 -'<- ' ••. ,•••• -, ,•-• •--: • ,......- . -.' - • , -.,- , , ....,.- -,,,,,,... -.., ..., z'-'. ,.. ,.. , . .„ .... , . , . )44i4.-.. 4 , ' ... .. ,„ ..., . „ , . . - ,,... , ,.. ‘ ,-. ,., ) ' . . ; ' 1,.,4t" .,. ..= .- MPU SB 1-02 (190-091) 7" casing hole October 16, 2002 Re: 1-02i 7" casing failure ~-'" '-'" Subject: Re: 1-02i 7" casing failure Date: Sun, 03 Nov 2002 14:33:17 -0900 From: "Jeff B. Jones" <jeff_jones@admin.state.ak.us> Organization:-AOGCC To: "MPU, Wells ESP Coord" <MPUWelIsESPCoord@BP.com> CC: Tom Maunder <tom_maunder@admin.state.ak.us> Hello Brant, thanks for the information regarding MPU well 1-02 and the other wells which were operated with this type ( Paratrol ) of system that you and Jack Merrifield have provided. I do have one question: what is the condition of the ESP/heat trace cabling ( in the area relative to the depth of the hole in the 1-02 7" casing ) that was removed from well 1-02 during the recent injector conversion? Has this cabling been · checked for damage? The increased surveillance you described of these wells appears warranted and please keep the AOGCC informed of any problems that arise in the future regarding this topic. Thanks again for the information, Jeff Jones AOGCC. "MPU, Wells ESP Coord" wrote: > Jeff, > Enclosed below is a document written by Jack Merrifield, MPU Lead > Production Operator, on the Paratrol'heating system we believe is > responsible for the compromised casing we found in 1.02. I belive he > spoke to you in depth about this last week. if you have any further > questions, please do not hesitate to call - though if you have specific > questions about the history of Para'roi systems I suggest you call Jack > specifically. He is on R&R right now and will be back in a week. You may have questions about other wells at MPU that have in the past had Paratrol systems in place at one time. The wells that had this system were 1.01, 1.02, 1.04, J-04, J-05, and J-07. 1.02 was the only well where a VSD was utilized to maintain a constant current despite a downhole short situation, which we feel was resonsible for the wall loss. As you know, we recently worked over 1.02 and replaced the casing. It should be said up front that the reason, for the recent discovery of the compromise in the casing was spurred by the decision to convert 1.02 from a producer to an injector. None of the producers inquestion, including.l-02, have ever exhibited inner or outer annulus pressures in excess of #2000 or #1500 (respectively), whiCh are.our threshold pressures to identify the need for further troubleshooting. These threshold > pressures we use at MPU are in line with-Alaska Administrative Code > 20AAC25.412. In the life of these wells, the highestpressures seen are > as follows: IA .OA 1-01 - 1840 1160 1-02 1750 850 1-04 5O0 460 1-04A 480 370 J-04 800 720 J-05 975 950 J-07 480 450 The 1-01 and J-05 systems were successful 1-01's last ESP failed in December of 1998 and was not replaced. We continue to monitor the IA and OA pressures and have not seen any indication of communication. J-05 has been worked over once in October 2000 since the initial installation in December of t991 and is currently producing. Again, there is no evidence of IA x OA communication. We have instigated daily tracking of the OA and IA pressures on the remaining three wells, 1-04A (sidetracked from 1.04 on 7/23/01), J-04 ' - 11/R/2002 10:46 AM I~e: 1-02i 7" casing failure > (currently shut in), and J-07, because there is indication that the IA and > OA are tracking eachother. Again, none of these wells have pressures > anywhere close to threshold values, we are simply increasing our > surveillance of these wells because of the potential situation brought to > light by 1-02's conversion. FY/, the wellhead packoffs were checked on > all these wells and verified good. > One of the qUestions alluded to in Jack's document is the possiblity > of ESP cable causing a similar situation. Cable faults occur due to > blowouts in the protective metal armor caused by expansion of the gas > trapped in the insulating material. This allows entrance of we//bore > fluids and results in a short. When this happens, the ESP immediately > shuts down due to an instantaneous overload trip detected by the variable. > speed controller. The situation of constant current application to a > shorted system, as that employed with 1-02's Paratrol system, would not be > possible. During the next RWO of the above mentioned wells a determination > will be made whether or not to run a packer to check out the top 3000' of > casing. All factors of casing integrity will be considered when making > this decision. > Again, please feel free to call if you have any further questions or > concerns. > Regards, > -Brant Hasebe > <<021017 MP/-02 Damaged Casing Explanation3. doc>> > ps - please feel free to forward this email to other appropriate > personnel. > Brant M. Hasebe > Artificial Lift Coordinator > Mi/ne Point > * Internal: BPX Mi/ne Point L-I, P.O. Box 196612 > * Externah 1000 Mi/ne Point Road, Prudhoe Bay, AK 99734 > * Work (907) 670-3333 > * Fax (907) 670-3390 > * hasebebm@BP, com Name: 021017 MPi-02 Damaged Casing Explanation3. doc 027017 MPi-02 Damaged Casing Explanation&doc Type: WINWORD File (application/msword) Encoding: base64 itt. t/ J.O 2~ N ' To: ,Jim From; ~ Linde( __ __ I~J~! Dar 4/6/2001 flOP Dele: 4/9/2001 Fall C)~e: 414/2D02 RurilJme: 360 _. , Date: Monday, May 27, 2002 i · I ; : i I q . I , I i! I i i Sl[Bli~ 8Uwa¥: ' 4/~11~G6 8~fl~ ~ H-1 li. I~Si i P~: 1~ E~o~ ~HP: 1150 9ohfader Bluff N/O; i-02 £9P was ImdaN f'e~l wide shut da~'~ p4~npmam'o PHD f~ i III II · i ~d afl 4aM:)1 end over i~s life required mJmeroLlS $1icldlne bumps 1o remtmt.. A cK~ured off 12/7/01. Upon re~ld, the unit son until 12/9t01 when I'he Bed oral 3 houm liner ~e unit shut down. Cenlililt was ~Ned to ctmck downhole esCX:N'ded weak plliSe lo graund buL good pkB~e tO pl'mse. On 414102 b'le uJ~ 7t29J1994 3/3,/1996 3/20/lgg6 Wlg/IOO~ 10/2011990 9/22/1997 1/9/1990 2/2d/1998 10tl,2000 Waif c~wn for ~ tu~, ~ pr~ ~. lZ~ ~ 4~ ~n ~ ~m ~ ~, ~ ~18~, ~ ~e~ul ~ ~ ~ ~ ~k~. Pe~: 14~ ~ RWO ~ N~. R m ~ E~P ~ ~n~ Heat : 3/2:8/2001 RWO Pul! PCl~ar¢l replace ~ 21~ FCNPSH/FC.,650'~ ...... J Rue- I Pump Pu~p Pump Mot~' I~lailed l~rst Pr¢~ Fgiture Dgm days ; Type ~ ~ $1,.g~ ~ ~ ~ HP V Amps .__ ' F'PINTHP-2 [~ .65__~_2~..~ VSC KVA Xfmer KVA I Xfme~ Ra~io V$C ~rn Ximer ~fl i ! ; O~ T~ 8~ ~t ~GY ~ ' ~ s~, ~ r~ the B~y ~p, Dom BOPO ~ FOrm. Rate Gas TGLR GOR Amps Hz PiP WHP WHT Tree: CIW 2-3f8' 5M i:kml abing Wollltead: 11'xZ 3/8' 5M FMC ~al ~ Hanger th~eed 2 3/8' IBT top and boltT~n 2' CIW. H BPV profile MPU 1-02i DI-A-Iil]iLINIL ! VIllI'-' I I, Orig, DF Elev. = 68.6 (27 E) Orlg, GL EIo¥. = 35,0 (27 E) 13-3/6",54.5 #/ft, K-,55WIdd Set ~ 2-3/8' HES X-Nil~le (1.675" pkg. bore) 2.-3/r HES X-N~p~ (~.875' p~. kxxe) ~ D.5/r, 36 ~ K-55 ~lu(t ~ KOP ~500' Max. hole a~gle = 69 <leg @ 4023' Hole angle 1bm perf$ = 41 OEO. (ddtt id = 6, t5~. cap." .03e~ bpf) 2-3/8'. 4.7 ff./it L-EI~, IBT tubin9 (drR id -- 1.901, r, ep.=.01)387' bpi) 2-3/r HE$ X-Nipple (1.67D" l-'&g, bore) ~ N-,,'~nds ~lraddled 2-3~ HFS XN-~ (1.8'i'$* pkg. bore) ldo.Go 1.791" Tubing ~ I WLEG 2-3/6" I-lES X-Nipple (1.675" pkg. Ix~) ~ 7' x 2-3/a' E.,ker'Gr' ~t ~ .u. I ~:~7' ] ~.945" ID. 7' x 2-3/9" Baker ~T" ReL dual pkr, ~ 1.945' ID. Size Spt In~rval Tvd . 6 5,89~'- 5.940' 4.038' - 4,~' 5 B,~' - 6.018' ;,,4.101'-4.t~' 7' HMll)urmrt Ik~at shoe ~ 7' Halh~urtm Float Collar PBTO ~ 7' X 2,3/8" I~aker 'FH' Ret. pkr. 2-s~' HES X~-~pp~ No-Go 1.791' 2-3/B' Baker 1~' Hydro Trip (2.00"pkg. bore} 1.75" ball. DATE 10117/02 COMMEN'~ Conver~ed'fiTmi'E~P ~ I~ Inje0~or 4.E~S ii M!~NE POINT UN~_ WELL No.: 1-02i BP EXPLORATION (AK) 000c3 IdV .,I ~ 000~ (3ALVA Idly3) ~£'L~ I o00c. ]dY .9~/ 000~ IdV ~L 't' i I /O'c~g gO'gOt g~ OT /O ..I I -T~t~g J~mf essy. 11" SM s 11~ SM wI ~ 1116" ~ (pa. 441734) 7-1.~-89 TF,.GT FI T'I'i NI~ LI:X~ N'F.~"T FITTIN~ ,~4...i"4& I.~i ,LTl. 'CAMEliON FIELD SERVICE[ ORDER & WEU,HEAD - J~l.,v .~ u-'----, tV-J.,.3 I"'. : I Il [ f) ;t~t1¥1C~. rdl{|}I It ~,~, ,, !LAND : OTHER I ~ED. WAT. F~[I~HT ; VIA L~A i'~l~ LL ~ ~1~ I CA~IEn ' ~ TO ~ S/~ · W,~. ., , : .q,'N PAkl NO. i),, .-- PRIC~' DI~- COUNT · ! ..... ;.... ~,. ] I ' 'TOTAL P~R'I'~ ~ · · ---,m.a~ I Jori 'l'Ypi~ · Wc;H~ROVi' i :. 8LIP,c, 13.OM PLi-': ,,, LL/IJ.I IK'A ? .t M Lqlr,/l' f.'(tr.I I I t¢?1: ~'~.-~i~ ' ............~~ ' -" .~ .... .,,,,,~,: ,.~' ' . .-,.. ~., I · ~.!11 _11 . i __ m , I 2 ISi~bkrO ............... : lGa~r .~ , '1 i -l' --' , -' _ ,. ; ~0 'd ZT:OT gO, g iiii .... -- [ ~^'1 I. I 11" WKM "TDU" Dual tubing t~nger 2 3/8" IBT 'Ibp & BTM 2" Type'"H" back pressure valv~ prep Bore 1.935" Assembly PN: 2221517-01-01 Assembly SN: 11043128~ r ~-,L ,I, / LO 6.'19 5.47' "t 4.16 3.44 ~1 000 A01 2:11.351S-~~. 1.ao ~ ?Q20&2-04. i4 S. Off ~I'-IN, i D] ,CII-A-LV]I-N.A_, ~/ ,tO I WELLHEAD: 11" 5M WEll w/i! -~,~L Orig, KB · GL" 35' {NABORS 271: 2-711t" Brd TREE 'l'OP OONNE~TIMN 2.1/2' "H' P(~le. : I i K-F~ Wek:l ~l ~ · : Camoo 2 718" x 1" '-: ...... sk:lepo~ket KBMM KOP ~11500' i GLM M~x I.fl31e Angle; 69' ~ 40~' MD ) I K-55 Butt ' -.. ) · i r, idepocket KBMM 2L?/8' 6.,~ L.80 EUE ~ ,~. GLM .0o~79 bbl,~. , ,~3 ~, 2 718" XN Nipple : ID 2.25' [ 5411' . ~n~ff 204 ~g PC ~-~2~' I ; ~0 and 21 ~g FCNPSH ~ 1:1 ~D 3~5' : iC~n~iX~ ~ndem seal . S~D ~E~~ ~M~Y Cen~l~ 57 HP KMH ~ZE SPF I~E~ ~D rotated fr~ 50 HP 12 S710'~722' ~'~'-3~5' KME-I l~50v/2~A 12 5742'~758' 3[ 20'~932' ~nt~lifl Hi~ Load PHD I ~74' I 12 ' S775'~Ta2' 3(45'-3~1' w~ ~x Fin Centralizer I 12 ~'~6' 3~55'~973' ~ 7' OTI~ W~T" VERSA-TRIEVE · ~ ~ ~-S 3-1~ ~ ~ (154 lUU,, s~ sPI ~.~.. ~vo ·. o-.~ s= Bom(z. TS'~D) I . (lt. zoo') 5 5~2'~18 41~1'412~~ ~ OTIS'AW~ S~p ~r 3.~' X N~E (2.~13"1D) 4 ~ PBTDI 0221' I : ii ~TE ~V. a~ : ,. , ' .... MILNE POINT UNIT ~ ...~BR RWy. INSTALL ESPCP. WELL 1~2 0~23198 M.LI~m ,,.~o ~rs-s .. ,, ~~ ~, ~ R~O.~ ~s B~, ~PLO~TIqN tA~' Tree Cap Gate Valve Handvhee! Operated Blind Flange ,Z-9/16# SN C~ons Studded 2-9/16" r:~stmas742 Tree ~embl~ /,41232 x 2-9/!6 t&41232 Gate Velve 2-9t16" HaIJdvheel Op~ · 746 ~feldneck Flange 2-9/16" 5N Oa~e Valve ~dapted for Ac Baker Actuator v/ Do.et Gate Valve 2-9/1b" Hand~hee£ Operated TubJ. ng Head Adapter TubTng Head I &~173.5 { Oumpanion FlanBe { ~1736 r~41734 SuI1PIu8 ~'~' 4~17~9 ~ubing Hd. A~mbly/'veZve ' Plu~ { ~ { 441616 ~stn8 Ilead ~ 441619 Bull Plu8 ' "161~d ~ Assembl "· ~ 441617.~panion ~an' t ~1230 Grace Valv~ 441359 Gate ~1617 COmpanion F~an{ ~1750 rtut~! I -B/8° TT-~. ' . ~'~17~ l)iverter Head FLOW CONTROL = . ,[ 6(--OOZO , l_ W*Kdd PFt~ I · il · rt~T FI~TIf',,G I P,~d~KOIT ~ ~.~ lNG HEAD I CAS 1 NG · I .... .--iLl FILE NO. I ' I r II =UeJJI~T SHGETIOP ~,hl, N/A $,1 co.,- .~-,., CALCULATIONS ~ .. '/.ZP- ' __ i COT-'~M~.- H CALCULATIONS l o-octl Milne Point Unit, AK. TO: Hefley / Bixby FROM: Jack Merrifield Well Name: IMP I-O2 Main Category: I Information Only Sub Category: I Operation Date: IOctober 17, 2002 Date: ]October 17, 2002 Purpose: This well is being converted as a new Dual injector. During the demobe process and RWO preparation the well was found to have communication between the inner and outer annulus. The workover plan was continued and the program was modified to repair the well and return to use as the planned dual injector. The Casing was recovered where the failure had occurred. The AOGCC has requested a clarification as to the cause of the failure. This Telex is to provide that information and is based on my memory of the well. The exact dates are not known but will be stated based on what l remember. Sequence of Events: 11/01/92 to 03/30/93 The shallow oil sands of the Schrader Bluff reservoirs repeatedly hydrated and froze off the tubing during production operations. The 1-02 well was equipped with an ESP and the ESP pump failed prematurely due to no flow conditions causing the motor to overheat when the tubing froze. Conoco Corporate engineering developed a concept to use a Heated Tubing System called Paratrol to attempt to prevent plugs from occurring in the tubing. The Paratrol system was developed and dep!oyed in the lower 48 to clear paraffin and asphaltine deposit from the interior walls of production tubing in wells that had build up problems. In those wells the tubing was installed in strait bore shallow wells primarily. The concept was to suspend the tubing from the tubing hanger by utilizing an E-SUB. This device provided electrical insulation from the wellhead. A heavy cable was run in to the well casing and attached to the lower portion of. the E-SUB. To provide insulation qualities from the well bore, the tubing was wrapped with a corrosion wrap and that wrap was non conductive. 4 Paratrol Systems were purchased and the surface equipment was installed and the workovers planned. Wells 1-01, 1-02, J-05, and J-07 were worked over and a Paratrol system was installed with each. Upon activation the J-7 and the 1-02 Paratrol systems failed and were found shorted to ground. The J-7 well ESP was started and the well produced adequate water production to warm the tubing and prevented hydrates from forming. No attempt was made to repair this system. STATE OF ALASKA ALASKA' OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to Dual Injector 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service '4. Location of well at surface 8. Well Number 2948' SNL, 3756' WEL, SEC. 33, T13N, R10E, UM MPI-02 At top of productive interval 9. Permit Number / Approval No. 190-091 / 302-292 & 302-315 1569' SNL, 482' WEL, SEC. 33, T13N, R10E, UM 10. APl Number At effective depth 50-029-22066-00 1515' SNL, 151' WEL, SEC. 33, T13N, R10E, UM 11. Field and Pool At total depth Milne Poir~t Unit 1511' SNL, 125' WEL, SEC. 33, T13N, R10E, UM -C=,ands----'~' 12. Present well condition summary Total depth: measured 6260 feet Plugs (measured) true vertical 4312 feet Effective depth: measured 6221 feet Junk (measured) true vertical 4283 feet Casing Length Size Cemented MD TVD Structural Conductor 71' 13-3/8" 500 sx Parma Frost 'C' 106' 106' Surface Intermediate 2765' 9-5/8" 938 sx Parma Frost 'E', 254 sx 'E' 2800' 2384' Production 6186' 7" 391 sx Class 'G' 6221' 4283' Liner Perforation depth: measured Isolated: 5710'- 5722', 5742' - 5758', 5775'- 5782', 5803'- 5826', 5898'- 5940', 5982' - 6018' true vertical Isolated: 3898'- 3908', 3923' - 3934', 3948' - 3953', 3969' - 3987', 4041'- 4073', 5004' - 5131' Tubing (size, grade, and measured depth) Dual Tubing - 2-3/8", 4.7#, L-80 tubing to 5879' and 2-3/8", 4.7#, L-80 tubing to 5989'. Packers and SSSV (type and measured depth) 7' x 2-3/8" Baker GT Ret. Dual Packer at 5677' and at 5849'; 7" x 2-3/8" Baler FH Ret Packer at 5_960'. ,, ...... 13. Stimulation or cement squeeze summary Intervals treated (measured) NOV 0 8 ~00~ Treatment description including volumes used and final pressure Alaska 0il & Gas ~ns. Commission Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [][] CopieSDaily Report°f Logsof Welland SurveySoperationsrUn ~il [] Gas [] Suspended Service Water Injection X 17. I hereby certi~ for~ggoing is true and correct to the best of my knowledge So Stewm Title Technical Assistant Date Signed ~% ~ ~ ~% ~_ ~,~ ~ ~ ~ Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 R B D M $ El F L NOV I 5 ~0,,_~ubmit In Duplicate · BP EXPLORATION Page I of 4 Operations Summary Report Legal Well Name: MPI-02 Common Well Name: MPI-02 Spud Date: 10/27/1990 Event Name: RECOMPLETION Start: 9/25/2002 End: 10/18/2002 Contractor Name: Rig Release: Rig Name: Rig Number: Date From-To Hours Task t Codel NPT Phase Description of Operations 9/23/2002 06:00 - 14:00 8.00 MOB P PRE MI/RU & SAFE OUT EQUIPMENT. 14:00 - 15:30 1.50 KILL P DECOMP RIG LINES TO TREE & TIGER TANK 15:30 - 16:00 0.50 WHSUR P DECOMP RIG LUB & PULL BPV 16:00 - 18:30 2.50 KILL P DECOMP CIRC WELL BORE INFLUX OUT OF WELL WITH HOT SEAWATER & GET SITP & SICP & DISPLACE WELL WITH 10.2 PPG. BRINE. 18:30 - 19:00 0.50 WHSUR P DECOMP SET TWC 119:00 20:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 20:00 - 22:00 2.00 BOPSUI~P DECOMP NIPPLE UP BOP 22:00 - 22:30 0.50 BOPSURrP DECOMP SAFETY MEETING WITH BP REPS FROM ANCHORAGE. 22:30 - 00:00 1.50 BOPSUR~P DECOMP BODY TEST & FUNCTION BOP TO 250~3500 (TEST WAIVED ! BY JEFF JONES WITH AOGC) - WHSURIP DECOMP PULL TWC 9/24/2002 00:00 00:30 0.50 00:30 - 14:00 13.50 PULL!P DECOMP POOH WITH ESP COMPLETION LAYING DN TBG. & ESP EVAL N ASSY. & HEAT TRACE TAPE. 14:00 - 19:00 5.00 DFAL DECOMP RIH WITH HES PLUG & SET IN 7" VERS RETRIEVE PKR @ 5520' & PRESSURE UP TO VERIFY PLUG IN PLACE & INTEGRITY. (NOTE:CSG. LEAK ABOVE PREVENTED POSITIVE TEST AT THIS TIME) 19:00 - 21:00 2.00 EVAL N DFAL DECOMP POOH & LAY DN SETTING TOOL 21:00 - 22:30 1.50 EVAL N DFAL DECOMP RIH WITH HES CHAMP PACKER & SET @ 1025' & PSI DOWN TO 5520' VERSA-RETRIEVE PLUG @ 2000 PSI. GOOD INTEGRITY. 22:30 - 00:00 1.50 EVAL N DFAL DECOMP POOH TESTING & ISOLATED LEAK IN 7" BETWEEN 285' & 463' & HAD POSSIBLE BY LEAK ON CHAMP PKR. 9~25~2002 00:00 - 07:00 7.00 EVAL N DFAL DECOMP RUN CHAMP & ISOLATE INTEGRITY FAILURE BETWEEN 285' & 463' PAKER WAS LEAKING BY VALVE, POOH& CHG. TO 7" CHAMP PKR & ISOLATE INTEGRITY FAILURE OF CSG. TO BE BETWEEN 407' & 422' POOH & LAY DN RTTS. 07:00 - 09:30 2.50 CHEM N DFAL ABAN RIH WITH 3.5" DP TO 5500' & MU & SET R-I-rS @ 55' 4ES KB 09:30 - 15:00 5.50 CHEM N DFAL ABAN REVERSE CIRC IN 65- BBL. DIESEL & U-TUBE TO DP. & HAB&R RIG UP & FREEZE PROTECT 7" X 9-5/8" ANNULUS DOWN TO LEAK VIA DP & U-TUBE FLUID AGAIN IN DP TO ENSURE DP FREEZE PROTECTION OK(NOTE :WE WERE UNABLE TO BULL ANY DIESEL DN 7" X 9-5~8" ANNULUS BELOW THE LEAK. 15:00 - 18:00 3.00 TA N DFAL ABAN PREP RIG FOR WARM STACK 18:00 - 00:00 6.00 TA N ABAN STD. BY WITH CREWS. 10/11/2002 12:00 - 14:00 2.00 MOB N PRE START UP RIG FROM WARM STACK 14:00 - 23:00 9.00 BOPSUF.N DECOMP TEST BOP 250/2500 PSI. WITNESSED BY JEFF JONES WITH AOGC (NOTE :HAD EXCESSIVE PROBLEMS GETTING TEST PLUG TO MAKE SEAL. HAD TO RE-INSTALL TBG. HANGER & TEST AGAINST IT BY ENEGERIZER THE SEALS TO GET A POSITIVE SEAL. 23:00 - 23:30 0.50 DHEQP N DECOMP MU RET. TOOL & OPEN VALVE ON RTTS @ 50' & CHECK PRESSURES & PULL RTTS TO FLOOR & LAY DN SAME. 23:30 - 00:00 0.50 CASE N DECOMP CIRC FREEZE PROTECTION DIESEL OUT WITH 10.2 PPG. BRINE 10/12/2002 00:00 - 01:00 1.00 CASE N DECOMP ClRC FREEZE PROTECTION OUT OF WELL BORE. 01:00 - 03:00 2.00 CASE N DECOMP POOH WITH 3.5" DP. 03:00 - 04:30 1.50 FISH N DECOMP MU BAKER HYD. CUTTER & RIH & LOCATE CONNECTION Printed: 11/5/2002 12:04:22 PM ' '" ' : ON Page 2 of 4 : ...... mmarY Report Legal Well Name: MPI-02 Common Well Name: MPI-02 Spud Date: 10/27/1990 Event Name: RECOMPLETION Start: 9~25~2002 End: 10/1812002 Contractor Name: Rig Release: Rig Name: Ri9 Number: : Date: ' :From~TOlHours TaSk code' NpT ' Phase Description of Operations 10/12/2002 103-00. - 04:30 1.50 FISH N DECOMP @ 499' & PULL UP & CUT CSG. @ 476' 04:30 05:00 0.50 FISH N DECOMP POOH & LAY DN CUTTER 05:00 08:00 3.00 FISH iN DECOMP RIG CENTER SPEAR & LATCH CSG. & BOLDS & ATTEMPT ,J ,TO PULL CUT CSG. WAS NOT SUCCESSFUL I 10:00 1.00 FISH N DECOMP CIRC HOT FLUID TO MELT POSSIBLE ICE PLUG IN OUTER ANNULUS. 10:00 - 10:30 0.50 FISH N DECOMP PULL CUTTER TO 476' & RE-CUT CSG. ALL INDICATIONS i WERE THAT CSG. ALREADY CUT i10:30 - 11:30 1.00i FISH N DECOMP POOH & LAY DN CUTTER & MU CENTER SPEAR & LATCH I : SAME. IN 7" & PIPE FREE. 11:30 - 12:30 1.00! FISH N DECOMP LAY DN 7" CSG. HOLE WAS FOUND IN JT. NO. 10 3-FT. , ABOVE PIN ROUND ABOUT THE SIZE OF A LEAD PENCIL I i i& ANALYZATION WAS MORE LIKE A ARCED SPOT FROM I I ESP CABLE. (POSSIBLE) 12:30- 19:00 6.50i FISH N DECOMP MU BAKER BACKOFF TOOL & RIH & BACK OF STUB i 6-ROUNDS & RELEASE BACKOFF TOOL & TOH & LAY DN I BACK OFF TOOL & MU SPEAR & TIH TO CONNECTION @ 499' & MU KELLY & BACK OUT CONNECTION & POOH & ' i RECOVER REMAINING CUT WITH PIN END. 19:00 - 20:00 I 1.00 FISHI N DECOMP RIH WITH BAKER MODEL G-LOCK PACKER & SET @ 561' 00 & POOH. 20:00 - 21:00 ! 1. CASE N DECOMP MU & RIH WITH 11-JTS. 7" 26~ L-80 BUTTRESS CSG. TO 499' 21:00 - 22:00 1.00 CASE N DECOMP FREEZE PROTECT OUT ANNULUS WITH 40- BBL. DIESEL 22:00 - 23:00~ 1.00 CASE N DECOMP MU CSG. CONNECTION @ 499' & TEST SAME TO 3000 PSI. 23:00 - 23:30 I 0.50 CASE N DECOMP RIG DN CSG. TOOLS 23:30 - 00:00 I 0.50 CASE N : DECOMP NIPPLE DN BOP'S FOR PICK UP TO SET SLIPS. WITH 60K 10/13/2002 00:00 - 02:30I 2.50 CASE N DECOMP PU BOP'S & SET SLIPS WITH 60K & CUT 7" & i DRESS.STUB. 02:30 - 04:30 2.00 CASE N DECOMP INSTALL PACKOFF & INSTALL TBG. SPOOL & TEST TO 5000 PSI. 04:30 - 06:30 2.00 BOPSUF~ N DECOMP NIPPLE UP BOP'S & TEST SAME TO 3500 PSI. 06:30 - 08:00 1.50 PULL N DECOMP RIH & TO BAKER BRIDGE PLUG & CIRC DIESEL OUT 561' , & PULL PLUG & LAY DN. 08:00 - 12:00 4.00 PULL N DECOMP RIH WITH HFS VST PLUG RETRIEVEABLE TOOL & LATCH I & RELEASE PLUG @ 5513' (NOTE:CHG. OUT UPPER II KELLY VALVE & TESTED TO 3500 PSI. ON TIH. 12:00 - 16:30 4.501 KILL N DECOMP CIRC OUT INFLUX & RAISE BRINE WT. TO 10.5 PPG. & I, MONITOR SAME. 16:30 - 19:00 2.501 PULL N DECOMP POOH WITH HFS VST PLUG & LAY DN SAME. 19:00 - 22:30 3.50 FISH P DECOMP RIG SWS & RIH WITH STRING SHOT TO CLEAN SCALE I 50 FROM 3.5" BLANK PIPE- & GET ON DEPTH & FIRE @ 5688' 22:30 - 00:00 . FISH P DECOMP MU SWS 2-5~8" CHEMICAL CUTTER 10/14/2002 00:00 - 02:00 2.00 FISH P DECOMP RIH WITH SWS 2-5/8" CU'I-I'ER & CUT 3.5" BLANK PIPE IN SCREEN ASSY @ 5688' POOH & RIG DN SWS. 02:00 - 03:30 1.50 FISH P DECOMP MU HFS VERSA-RET. TOOL & RIH TO PKR @ 5513' 03:30 - 04:30 1.00 FISH P DECOMP LATCH PKR. WITH RET. TOOL & UNABLE TO RELEASE PKR & RELEASE TOOL. 04:30 - 06:30 2.00 FISH P DECOMP POOH WITH HFS RET. TOOL & DISCOVER TOOL HAD I , BACKED OFF AT 2-3/8" CONNECTION. 06:30 - 11:00 4.50 FISH P DECOMP RIH WITH HFS VERS-RET. TOOL +BUMPER Printed: 1115/2002 12:04:22 PM Page 3 of 4 ;: :; :: ::oPerati°ns summary Report : i :: : :: : : ::: : i ii: : : : i ::: :: : Legal Well Name: MPI-02 Common Well Name: MPI-02 Spud Date: 10/27/1990 Event Name: RECOMPLETION Start: 9/25/2002 End: 10/18/2002 Contractor Name: Rig Release: Rig Name: Rig Number: :ii:Date: l:Fr°m; TO IHOurS : TaSk l:Code NPT :1 Phase Description of Operations ' 10/14/2002 06:30 - 11:00 4.50 FISH P DECOMP SUB+JARS+9-DC & MAKE SCREW IN & JAR ON PKR & RELEASE SAME 11:00 - 14:30 3.50 FISH P DECOMP POOH WITH VERSA PKR & LAY DN SAME & 143' OFF BLANK 3.5" PIPE. (HAD GOOD CHEMICAL CUT ) 14:30 - 18:30 4.00 FISH DECOMP MU BAKER FTA OVER SHOT+RATTLER TOOL+BUMPER , SUB+JARS+ 9-DC & RIH WITH SAME & LATCH 3.5" BLANK i PIPE 18:30 - 22:30 4.00! FISH P DECOMP WORK RATTLER TOOL @ ALL POSITION & JAR ETC. ; UNABLE TO RELEASE SCREEN ASSY. 22:30 - 00:00 , 1.50 FISH P DECOMP RELEASE OVERSHOT & POOH & LAY DN FTA. RATTLING I I TOOL. 10/15/2002 00:00 - 02:00 ! 2.00 FISH P DECOMP MU FTA SHOE+6-JTS. WASHPIPE+BUMPER I SUB+JARS+9-DC'S 02:00 - 05:00 3.00 FISH P DECOMP RIH & TAG FISH @ 5688' 05:00 - 06:00 1.00 FISH !P DECOMP WASH OVER SCREEN ASSY 5688' TO 5839' SUMP PACKER & CIRC OUT SAND. 06:00 - 08:30 2.50 FISH I P DECOMP POOH & LAY DN WASH PIPE & CLEAN FLOOR 08:30 - 10:30 2.00 FISH P DECOMP MU OVERSHOT+BUMPER SUB+JARS+9-DC'S & RIH TO 15681' 10:30 - 11:00' I 0.50 FISH P DECOMP LATCH SCREEN ASSY & WORK FREE. 11:00 - 12:00 1.00 FISH P DECOMP POOH WITH FISH TO 3300' & GAS BUBBLE WORKED UP DP. 12:00 - 13:00 1.00 FISH P DECOMP ClRC INFLUX OUT OF DP & MONITOR WELL (STATIC & TAKING FLUID) 13:00 - 15:30 2.50 FISH P DECOMP POOH & LAY DN RECOVERED SCREEN ASSY. 15:30- 16:30 1.00 FISH P DECOMP MU FTA PACKER MILL W/PRT+ 3-BOOT BASKETS+BUMPER SUB+JARS+9-DC'S 16:30- 18:30 2.00 FISH P DECOMP RIH & ENGAGE PKR. 18:30 - 19:30 1.00 FISH P DECOMP MILL PACKER @ 5843' 19:30 - 20:30 1.00 FISH P DECOMP CIRC. BOTTOMS UP & MONITOR WELL BORE. 20:30 - 23:30 3.00 FISH P DECOMP POOH & LAY DN RECOVERED PKR. & MILLING FTA. 23:30 - 00:00 0.50 CLEAN P DECOMP MU CLEAN OUT ASSY. BIT+7" CSG SCRAPER 10/16/2002 00:00 - 01:30 1.50: CLEAN P DECOMP RIH WITH BIT+SCRAPER+3-BOOT BASKETS+9-DC TO 5987' 01:30 - 03:00 1.50 CLEAN P DECOMP WASH DOWN TO 6107' i03:00-04:30 1.50 CLEAN iP DECOMP REVERSE WELL CLN TO 10.3 PPG. BRINE. i 04:30 - 07:30 ' 3.00 CLEAN P DECOMP POOH & LAY DN CLN-OUTASSY. 07:30 - 14:00 6.50 EVAL P DECOMP RIG SWS & RUN USlT LOG & FROM 6107' TO 5450' & POOH & RIG DN SWS 14:00-21:30I 7.50 EVAL ~ DECOMP RIGHESCHAMPPACKER&RIHWlTHSAME&SET@ 5960' & ESTABLISH INJECTION RATE INTO "CA" SAND @ ' 3-BBL. BPM 1100 PSI. SEEN NO COMMUNICATION INTO "OB" SAND, RESET PKR @ 5850' & ESTABLISH INJECTION RATE INTO "OB" SAND AT 3-BPM 900 PSI. SEEN NO COMMUNICATIONS INTO "N" SANDS (GOOD INTEGRITY) CIRC WELL BORE TO CLN-FLUID &POOH & LAY 3.5" DP & PACKER. 21:30 - 22:30 1.00 BOPSUR P COMP SET TEST PLUG & CHG RAMS TO 2-3~8" & TEST BREAK TO 250~3500 22:30 - 00:00 1.50 RUNCOItF' COMP RIG TBG. TOOLS & RIH WITH LONG STRING OF 2-3/8" TBG. 10/17/2002 00:00 - 04:00 4.00 RUNCOr P COMP PU & RIH WITH 180-JT. 2-3/8" TBG. 04:00 - 07:00 3.00! PULL P COMP POOH WITH 180-JTS. 2-3~8" TBG. AND STAND IN DERRICK Printed: 111512002 12:04:22 PM ::: .... ::: i~: ::~ i i~ i : BP:EXPLORATION Page4of4 : : : ii:: : :i: : OPerations :Summary Report : : :: : i : : : : : : Legal Well Name: MPI-02 Common Well Name: MPI-02 Spud Date: 10/27/1990 Event Name: RECOMPLETION Start: 9~25~2002 End: 10/18~2002 Contractor Name: Rig Release: Rig Name: Rig Number: ~01~712002 04:00 - 07:00 I 3.00 ~ULL P COM~ IN PRFP TO RUN DUAL GOMPLI=TION 07:00 - ~ 1:00 I 4.00 RurqGoI~ COM~ PICK LIP 180- J-rS. 2-3/8" IBG. FRO~ PI~F SHFD 8, Rll-I 11 00 - 12:00I 1.00 PULL P COMP SLIP & CUT DRLG. LINE 12:00 14:00 2.00 PULL P COMP POOH WITH 180- JTS. 2-318" TBG. & STAND IN DERRICK IN I~REP FOR DUAL COMPLETION. 14:00 - 15:30 1.50 BOPSURo~~i~ IcOMP 250/3500CHG' RAMS IN BOP TO DUAL 2-3/8" & TEST SAME TO 15:30 23:30 8.00 RUNC ~COMP RIG GR&R DUAL TBG. TOOLS & MU TRIPLE PACKER DUAL {SOMPLETION & RIH TO 5975' 23:30 - 00:00 0.50 RUNCO~Pj .COMP RIG SWS 10/18/2002 00:00 02:00 2.00 RUNCOI~P COMP RUN SWS GR/CCL & CORRELATE IN PKRS. & RIG DOWN I SWS. 102:00 - 03:30 1.50~ RUNCOIVP COMP SPACE OUT & MU HANGER & LAND & RILDS & TEST i SAME TO 5000 PSI. ~03:30 - 04:00 0.50: RUNCOr COMP RIG DOWN GB&R DUAL STRING TBG. TOOLS. 04:00 - 06:00 2.00 BOPSUF:P J COMP SET TWC'S & NIPPLE DOWN BOP & CHG. RAMS TO 2-7/8" 06:00 - 10:00 4.00 WHSUR PI COMP NIPPLE UP TREE & TEST SAME TO 5000 PSI. & RIG LUB & PULL TWC'S 10:00 - 12:30 i 2.50 RUNCOI~I~ COMP ~REVERSE IN TREATED BRINE WITH COREXIT 100 BBL. & i.~ FOLLOW WITH 90- BBL. DIESEL& U-TUBE TO BOTH TBS. I Jl~ STRINGS. 112:30 - 16:00 3.50 RUNCO COMP DROP BALL IN LONG STRING & PUMP TO SEAT & TEST i SAME TO 3000 PSI. FOR 30-MIN & SHEAR HYDRO-SUB @ I 3500 PSI. & BLEED TBG. PRESSURE & PRESSURE ! ANNULUS TO 2000 PSI. & MONITOR FOR 30-MIN (GOOD [ TEST) & DROP BALL IN SHORT STRING & PUMP TO SEAT & TEST SAME TO 3000 PSI. FOR 30-MIN OK. & ATTEMPT 16:00 - 17:00 1.00 RUNCO CO ,RIG UP ON LONG STRING & RE-FREEZE PROTECT WITH ,10 BBL. DIESEL. 17:00 - 18:00 1.00 RUNCO ' COMP I~IG'LUBRICATOR & SET BPV'S IN BOTH STRING & SECURE TREE AREA. & RELEASE RIG FOR MOVE TO JVIPE-09 @ 1800 HRS. 10/18/2002 I I I I i I t Printed: 111512002 12:04:22 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate . . . Name of Operator BP Exploration (Alaska) Inc. 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2948' SNL, 3756' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 1569' SNL, 482' WEL, SEC. 33, T13N, R10E, UM At effective depth 2916' SNL, 3691' WEL, SEC. 33, T13N, R10E, UM At total depth 1511' SNL, 125' WEL, SEC. 33, T13N, R10E, UM 6. Datum Elevation (DF or KB) KBE = 7O' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-02 9. Permit Number 190-091 / 302-292 10. APl Number 50- 029-22066-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 6260 feet Plugs (measured) 4312 feet 1025 feet Junk (measured) 1019 feet HES Plug set in 7" Versa-Trieve Packer at 5517' (09/02) HES Champ Plug at 1025' (09/02) Length Size Cemented M D TVD 71' 13-3/8" 500 sx Perma Frost 'C' 106' 106' 2765' 9-5/8" 938 sx Perma Frost 'E', 254 sx 'E' 2800' 2384' 6186' 7" 391 sx Class 'G' 6221' 4283' Perforation depth: measured true vertical Isolated: 5710'-5722',5742'-5758',5775'-5782',5803'-5826',5898'-5940',5982'-6018' Isolated: 3898'-3908',3923'-3934',3948'-3953',3969'-3987',4041'-4073',5004'-5131' Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) 7" Otis 'VST' VERSA-TRIEVE packer at 5517' and a 7" Otis Sump packer at 5863'. 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program I~'S~et~ch 4. Estimated date for commencing operation September 25, 2002 / 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Status of well classifications as: 0CT 0 2 2002 []Oil [] Gas []Suspended Service ~ Oil & Gas Cons. Commission A_n_chomge Prepared By Name/Numben Sondra Stewman, 564-4750 17. I hereby certify th~ is t. rue and correct to th, e~best of my knowledge Signed Robe Drilling Engineer Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form !Q-¢.0~ Rev...0.6/15/8~.. ORIGINAL SIGNED BY D 'r"aylor,Seamounf · ~,,. : ,~ ~ Date I Approval No. Commissioner Submit'In 1-riplicate 1-02 Please find in the following section a brief recap of the operations on 1-02 until the time of suspending operations. Operations was suspended after we concluded that the 7" casing had a leak. There was no 7" casing on the slope on the time of operations, so we suspended operations with the rig over the well until we come back on October 11. We will then fix the casing leak and continue with the planned recompletion as per the Sundry (approval number 302-292) Recap of operations: 1. MI/RU & SAFE OUT EQUIPMENT. 2. RIG LINES TO TREE & TIGER TANK 3. RIG LUB & PULL BPV 4. CIRC WELL BORE INFLUX OUT OF WELL WITH HOT SEAWATER & GET SITP & SICP & DISPLACE WELL WITH 10.2 PPG. BRINE. 5. SET TWC 6. NIPPLE DN TREE 7. NIPPLE UP BOP 8. SAFETY MEETING WITH BP REPS FROM ANCHORAGE. 9. BODY TEST & FUNCTION BOP TO 250/3500 (TEST WAIVED BY JEFF JONES WITH AOGC) 10. PULL TWC 11. POOH WITH ESP COMPLETION LAYING DN TBG. & ESP ASSY. & HEAT TRACE TAPE. 12. RIH WITH HES PLUG & SET IN 7" VERS RETRIEVE PKR @ 5520' & PRESSURE UP TO VERIFY PLUG IN PLACE & INTEGRITY. (NOTE:CSG. LEAK ABOVE PREVENTED POSITIVE TEST AT THIS TIME) 13. POOH & LAY DN SETTING TOOL 14. RIH WITH HES CHAMP PACKER & SET @ 1025' & PSI DOWN TO 5520' VERSA-RETRIEVE PLUG @ 2000 PSI. GOOD INTEGRITY. 15. POOH TESTING & ISOLATED LEAK IN 7" BETWEEN 285' & 463' & HAD POSSIBLE BY LEAK ON CHAMP PKR. 16. RUN CHAMP & ISOLATE INTEGRITY FAILURE BETWEEN 285' & 463' PAKER WAS LEAKING BY VALVE, POOH& CHG. TO 7" CHAMP PKR & ISOLATE INTEGRITY FAILURE OF CSG. TO BE BETWEEN 407' & 422' POOH & LAY DN RTTS. 17. RIH WITH 3.5" DP TO 5500' & MU & SET RTTS @ 55' 4ES KB 18. REVERSE CIRC IN 65- BBL. DIESEL & U-TUBE TO DP. & HAB&R RIG UP & FREEZE PROTECT 7"X 9-5/8" ANNULUS DOWN TO LEAK VIA DP & U- TUBE FLUID AGAIN IN DP TO ENSURE DP FREEZE PROTECTION OK(NOTE :WE WERE UNABLE TO BULL ANY DIESEL DN 7" X 9-5/8" ANNULUS BELOW THE LEAK. 19. PREP RIG FOR WARM STACK / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ 'Operational shutdown _ Re-enter suspended well' '_' Conversion Conversion from Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Prod to Inject Prod to Inject Well Change approved program _ Pull tubing _ Vadance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 70.0 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic __ Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 2948' FNL, 3756' FEL, Sec. 33, T13N, R10E, UM (asp's 551614, 6009447) MPI-02 At top of productive interval 9. Permit number / approval number 1569' FNL, 482' FEL, SEC 33, T13N, R10E, UM (asp's 554875, 6010849) 190-091 At effective depth 10. APl number 1515' FNL, 150' FEL, Sec. 33, T13N, R10E, UM (asp's 555206, 6010905) 50-029-22066-00 At total depth 11. Field / Pool 1511' FNL, 125' FEL, Sec 33 T13N, R10E, UM (asp's 555232, 6010909) Milne Point Unit / Schrader Sands 12. Present well condition summary Total depth: measured 6260 feet Plugs (measured) true vertical 4312 feet Effective depth: measured 6221 feet Junk (measured) true vertical 4283 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 71' 13-3/8" 500 sx Perma Frost 'C' 106' 106' Intermediate 2765' 9-5/8" 938 sx Perma Frost 'E', 2800' 2384' 254 sx 'E' Production 6186' 7" 391 sx C;ass 'G' 6221' 4283' Perforation depth: measured Open Perfs behind Screen 5710'-5722', 5742'-5758', 5775'-5782', 5803 Open Perfs below Sump PKR 5898'-5940', 5982'~6018' true vertical Open Perfs behind Screen 3896'-3905', 3920'-3932', 3945'-3951', 3955'-3~ Open Perfs below Sump PKFI 4038'-4069', 4101'-4129' Tubing (size, grade, and measured depth 2-7/8", 6.5#, L-80 TBG @ 5424' MD. Bottom of EPS pump unit @~,~ ~.:~ ~' Packers & SSSV (type & measured depth) 7" Otis 'VST' VERSA-TRIEVE @ 5517', 7" Otis 'AWD' Sump PKR @ 5863'. 2-7/8" x 1"Camco sidepocket KBMM GLM @ 131' 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: October 16, 2002 16. If proposal was verbally approved Oil _ Gas _ Suspended Name of approver Date approved Service WATER INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Scan Petersen @ 564-5025. Signed ~ ~" ~ Title: Milne Point Production Engineer Date September 06, 2002 Sean Petersen Prepared by DeWaTne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness,IApproval ,o.= Plug integrity_ &OP Test _~, Location clearance__ ~ ~ ¢ Z Mechanical Integrity Test ~ . Subsequent form required 10- Approved by order of the Commission On~lnal Si~Fi~,,~, Commissioner . Date CammvOechsliTavt~ ...... ~GANNED I)i;i A 4 ?AA? ' ' ' Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 06, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for MPI-02 Producer to Injector Recompletion BP Exploration Alaska, Inc. proposes to recomplete MPI-02 from a failed ESP producer (N, OA and OB sands) to a dual string injector (OA and OB Sands) similar to those at S-Pad. MPI-02i will support MPI-04A, MPI-15, MP03, and MPI-07. MPI-02i was drilled, cased, and completed as an Schrader Bluff producer in June 1991 by Nabors 27E. The N ands are behind screens, and the OA and OB sands are perforated without sand control. The last ESP failed in April 2002 after approximately one year of production. MPI-02's location makes it an ideal candidate for a conversion to a dual injector to support the OA and OB multilaterals MPI-04A and MPI-15 (recent grass roots well). These wells are the two major producers in this hydraulic unit, and they will benefit from this injection support. Note: The current injector in the hydraulic unit, MPI-05i, injects into the N, OA and OB sands. The plan for MPI-05i is to isolate the OA and OB sands, making MPI-05i an N-Sand only injector. After this work is completed, will be able to control injection into each sand, which will help in reservoir management. The work package proposal for MPI-05 will be submitted separately. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5025, home 349-3098, or e-mail me at mailto:peterssd(~bp.com Sincerely, 5~- o~ Sean Petersen 0~1 ~ & %%%% Milne Point Unit - Schrader Bluff Production Engine~~~0 Well MPI-02 C, ~nt Status' · Failed ESP Producer since April 2002 Order of Operations: . 2. 3. 4. 5. 6. . 8. 9. 10. 11. 12. 13. MIRU 4ES Kill well Remove ESP completion Mill and pull screens over N-Sands FCC to PBTD Run a CBL to verify sufficient cement for isolation between CA sands, OB sands and surface a. Perform a cement squeeze if necessary Test for channels behind pipe Run Dual Completion Obtain a state witness of MITIA RDMO Work Over Rig. Complete installation of surface facilites Begin injection into the Schrader Bluff sands Injection profiles should not be required since each injection string is injecting into an isolated zone Well MPI-02 k..../rent Status: · Failed ESP Producer since April 2002 Order of Operations: 1. MIRU 4ES /' 2. Kill well / 3. Remove ESP completion 4. Mill and pull screens over N-Sands 5. FCO to PBTD /-~' 6. Run a CBL to verify sufficient cement for isolation between OA sands, OB sands and surface a. Perform a cement squeeze if necessary 7. Test for channels behind pipe 8. Run Dual Completion 9. Obtain a state witness of MITIA 10. RDMO Work Over Rig. 11. Complete installation of surface facilites 12. Begin injection into the Schrader Bluff sands 13. Injection profiles should not be requi~d since each injection string is injecting into an isolated zone SCANNED OCT 0 4 2002 3PUD DATE: ZiG RELEASE· · ~'~C~:CAL T~U~.iT~ ~,.E?OET · DATA Casing: 7 Shoe: ~Zg.t MI) ~.~:'I'VD, DV: ---~ ~ -TV'D Liner: Shoe: ¥~" Tub4~: ~' Packer ::ole Size ~'lZ and iNTEGRITY - PAiRT ~! Annulus Press Test: Co~ents: ; !5 rain ; 30 min iNTEGRITY- PART ~2 Cemen~ Volumes:- Ant. Liner ; Csg 5qJSfL ; DV . Theoretical TOC Cement Bond Log (Yes or No) ~ ; In AOGCC File CBL Evaluation, zone above perfs C 0~ ~'~'u-M, ~'~ ~J Production Log: Type ; Evaluation , .:. coN~:LUSiONS: ':':. · . Part t ' STATE OF ALASKA ALASKA _ .,.. AND GAS CONSERVATION COMIv,,_.,&ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2948' SNL, 3756' WEL, SEC. 33, T13N, R10E, UM MPI-02 At top of productive interval 9. Permit Number / Approval No. 190-091 1569' SNL, 482' WEL, SEC. 33, T13N, R10E, UM 10. APl Number At effective depth 50-029-22066-00 1515' SNL, 150' WEL, SEC. 33, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1511' SNL, 125' WEL, SEC. 33, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 6260 feet Plugs (measured) true vertical 4312 feet Effective depth: measured 6221 feet Junk (measured) true vertical 4283 feet Casing Length Size Cemented MD TVD Structural Conductor 71' 13-3/8" 500 sx Perma Frost 'C' 106' 106' Surface Intermediate 2765' 9-5/8" 938 sx Perma Frost 'E', 254 sx 'E' 2800' 2384' Production 6186' 7" 391 sx Class 'G' 6221' 4283' Liner Perforation depth: measured Open: 5710' - 5722', 5742' - 5758', 5775' - 5782', 5803' - 5826', 5898' - 5940', 5982' - 6018' true vertical Open: 3898' - 3908', 3923' - 3934', 3948' - 3953', 3969' - 3987', 4041' - 4073', 5004' - 5131' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 5474' Packers and SSSV (type and measured depth) 7" Otis 'VST' VERSA-TRIEVE packer at 5517' and a 7" Otis Sump packer at 5863'. 13. Stimulation or cement squeeze summary ! \ L_ V C L.,J Intervals treated (measured) Treatment description including volumes used and final pressure Al~ka Oil & Gas Cons. Commission 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 classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service "i7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Sondra ~,.,~~ ~.%.,..~Titl~"'~~cz~,_( ,.~-~C%-~r~-' Date ~)~L~ q-~ [-'(.._~ [ Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicatetete~ Legal Well Name: MPI-02 Common Well Name: MPI-02 Spud Date: 10/27/1990 Event Name: WORKOVER Start: 4/3/2001 End: 4/6/2001 Contractor Name: NABOR$ Rio Release: 4/6/2001 Group: RIG Ri~ Name: NABOR8 4E8 Rio Number: 4 :::::~: ~/: ~~~ ~~ ~.:.~::~,,,..:,ub~:~:'~'~S~ '~::~::~:.:~: : Phase : ·: ' Description of Operations : ~?::~Od~:.;:: :~::::~::~::~::~:.~ ..::.::::..... · ... 4/3/2001 15:00 - 23:30 8.50 RIGU PRE MOVE RIG FROM MPG-11 TO MPI-02 & RIG UP SAME. 23:30- 00:00 0.50 KILL DECOMP BERM PITS 4/4/2001 00:00 - 01:00 1.00 KILL DECOMP Berm and spot tiger tank Rig up lines to tree and Tiger Tank 01:00 - 02:00 1.00 KILL DEOOMP Pull BPV and fill pits with 9.3 ppg fluid 02:00 - 05:00 3.00 KILL DECOMP Test lines to 3,500 psi. 390 psi SITP and 480 psi SICP. opened choke and began well kill at 3 BPM. Pumped 31 bbls down tubing, S I Casing and bullheaded 26 bbls at 3 bpm at 2000 psi. Opened choke and continued to circulate. Pumped a total of 245 bbls of 9.3 ppg brine and circulated 180 bbls of oil to the tiger tank. Final circulating pressure 1400 psi at 3 bpm. 05:00 - 06:00 1.00 KILL DECOMP Monitor well 06:00 - 07:30 1.50 WHSUR DECOMP SET ~C & TEST & ND TREE. 07:30 - 10:00 2.50 BOPSUF DEGOMP NIPPLE UP BOP 10:00 - 12:00 2.00 BOPSUR DECOMP PRESSURE TEST BOP TO 250 LOW & 3500 HIGH (TEST WAIVED BY CHUCK SHEVE WITH AOGC) & PULL ~C. 12:00 - 00:00 12.00 PULL DEGOMP PULL HANGER TO FLOOR & CHECK OUT SAME & POOH WITH COMPLETION REMOVING ESP & HEAT T~CE. 4/5/2001 00:00 - 02:30 2.50 PULL DECOMP ~Y DOWN ESP EQUIPMENT. 02:30 - 00:00 21.50 RUNCO~ COMP MAKE UP ESP ASSY & RIH WITH SAME INSTALLING HEAT T~CE & ACCESSORIES. 41612001 00:00 - 03:00 3.00 RUNCO~ COMP CONTINUE TO RIH & SPLICE ESP CABLE & HEAT T~CE & ~ND HANGER & RILDS. 03:00 - 04:30 1.50 BOPSUF COMP SET ~C & TEST & ND BOP 04:30 - 06:00 1.50 WHSUR COMP NIPPLE UP TREE & TEST TO 5000 PSI. & SECURE TRE AREA. RIG RELEASED ~ 0600 HRS. 41612001 Printed: 4/12/2001 9:36:15 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie HeUsser' Commissioner FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: April 22, 2001 Safety Valve Tests Milne Point Unit J& I Pads Sunday Aprj! 22, 20.0t..: I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. Summary: I witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 11wells 22 Components 0 failures MPU I Pad 6wells 12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: FieldfLlnit/Pad: Milne Point / MPU / I Pad . Separator psi: LPS 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI... T.rip Code Code Code Passed GAS or CYCLE i'o~ ' ' ~ ~9oo90o ............... 1-62' 1900910' 140 '100..... 95 '"P P ....... oil 1-03 i 900920 ~ 40~ oo9s P P om ~-'04 ' ' '~900930 ' 'i40 ~00 '~9s p "p ' ' om ~-06 '~97'~950 '~40 "~00 ' 9~P' P ......... 6i~ ~:07' ~9~'i0 '" ~40"i009~' P....... P ' om ~0~ ' ~97i920 ~i40 i00 '9~ 'P P ..... 0m ,, , ,, ~., , , , , , , ~, , , i , , , , , ,, ,,~, ,, , ,, ,, , Wells: :6 Components: 12 Failures: 0 Failure Rate: 0.00% []]90 Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Chuck Scheve Date: 4/22/01 Operator Rep: Lee Hulme Field/Unit/Pad: Milne Point / MPU / J Pad AOGCC Rep: ..... Cl~k Scheve'~ ~ Separator psi: LPS ' ~ 140 '" HPS Well permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI , , . Trip Code ,.,C°de Code Passed GAS or CYCLE J-01A 1991110 140 100 95 P P OIL J-03 1900970 140 100i 951 P P OIL ~,04 1900980~ '140 100 " ~5~' P ' P ........... 0IL ~-'05 1910950' 'i40' 100 '' 9'5 "P" P ...... 0iL J-06'" 1940950'" 140 J'O7 1910970 140 100 95 P P OIL j-08A 199117b 140 100 ' 95' ' P .... P .... oIL j-09A ...... 199'1140 ..... 140 100 110 " p p .... I ..... OIL J-10 1941100 140 100 95 P P OIL J. 1i.. 1941'140 ......................... J-12 1941180 .. J- 18 1972200 J-lVA 1951700 ...... j~2'o ..... 1972150 ......................... J-21 ' "1972000 'i40 !~j-22 1981240 140 100 95 P P OIL J-23 2001200 Wells: . . ~ 11, Components: 22 Failures: 0 Failure Rate: 0.00% [3 9o var Remarks: RJF 1/16/01 Page 1 ofl SVS MPU JPad 4-22-01 CS THE MATERIAL UNDER THIS COVER HAS BEEN M.ICROFILMED ON OR BEFORE OCTOBER 27 2000 E E C:LORBMFILM.DOC PL E W M A T E R IA L U N D ER TH IS M ARK ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown F~ Stimulate I--J Plugging I-~ Perforate [~3 Pull Tubing [] Alter Casing [] Repair Well [~ Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2948' SNL, 3756' WEL, Sec. 33, T13N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-02 9. Permit Number / Approval No. 90-91 10. APl Number 50- 029-22066 At top of productive interval 1568' SNL, 492' WEL, Sec. 33, T13N, R10E At effective depth 1526' SNL, 233' WEL, Sec. 33, T13N, R10E At total depth 1510' SNL, 129' WEL, Sec. 33, T13N, R10E 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 6260' true vertical 4309' Effective depth: measured 6138' true vertical 4218' Casing Length Structural Conductor 71' Surface 2765' Intermediate Production Liner 6186' feet Plugs (measured) feet feet Junk (measured) ~"~ feet Al~ 0il & Gas Cons, Commi~i~ Size Cemented .~1~0E1~¢~ MD TVD 13 3/8" 500 Sxs PermaFrost C 106' 106' 9 5/8" 938 Sxs PermaFrost E/254 Sxs E 2800' 2384' 7" 391 Sxs G 6221' 4280' Perforation depth: measured true vertical 5710' - 5722', 5742' - 5758', 5775' - 5782', 5803' - 5826', 5898' - 5940', 5982' - 6018' (Subsea) 3828' - 3838', 3853' - 3865', 3878' - 3883', 3899' - 3917', 3971' - 4003', 4034' - 4061' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 5407' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) 7" Otis "VST" Versa-Trieve packer at 5517'and a 7" Otis "AWD" Sump Packer at 5863'. Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: E~ Copies of Logs and Surveys run [] Oil [] Gas I'-I Suspended [] Daily Report of Well Operations 17'.' I hereby (~el~'i~ that ihe f0r~going is true and correct t9 the best of my knowledge Jeancj~Vl_. Haas Title Staff Technical Assistant · E~ Prepared By Name/Number: Service Date Jeanne L, Haas, 564-5225 Progress Report Facility M Pt I Pad Well MPI-02 Page 1 Rig Nabors 5S Date 13 April 98 Date/Time 09 Mar 98 06:00-06:15 06:15-18:00 18:00-06:00 10Mar 98 06:00-16:00 16:00-18:00 18:00-18:30 18:30-01:00 11 Mar 98 01:00-03:00 03:00-05:00 05:00-06:00 06:00-09:00 09:00-10:00 10:00-13:00 13:00-14:30 14:30-18:00 18:00-22:00 22:00-02:30 12 Mar 98 02:30-03:30 03:30-06:00 06:00-12:30 12:30-18:00 18:00-19:30 19:30-21:00 21:00-00:15 13 Mar 98 00:15-01:00 01:00-05:00 06:00-07:30 07:30-11:30 11:30-12:30 12:30-18:00 18:00-22:00 22:00-00:15 14 Mar 98 00:15-04:30 04:30-06:00 06:00-08:00 08:00-10:00 10:00-13:00 13:00-18:00 18:00-06:00 15 Mar 98 06:00-13:00 13:00-14:00 14:00-18:00 18:00-20:00 20:00-21:30 21:30-00:15 16 Mar 98 00:15-01:15 01:15-02:00 02:00-06:00 Duration 1/4 hr 11-3/4 hr 12hr 10hr 2hr 1/2 hr 6-1/2 hr 2hr 2 hr 1 hr 3 hr liar 3 hr 1-1/2 hr 3-1/2 hr 4 hr 4-1/2 hr lhr 2-1/2 hr 6-1/2 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr 3-1/4 hr 3/4 hr 4 hr 1-1/2 hr 4 hr 1 hr 5-1/2 hr 4 hr 2-1/4 hr 4-1/4 hr 1-1/2 hr 2 hr 2 hr 3hr 5 hr 12hr 7 hr 1 hr 4 hr 2hr 1-1/2 hr 2-3/4 hr 1 hr 3/4 hr 4 hr Activity Held safety meeting Rig moved 100.00 % Rig moved 100.00 % Held safety meeting Circulated at 5374.0 ft Held safety meeting Circulated at 5374.0 ft Removed Xmas tree Rigged up All rams Tested All rams Tested All rams Removed Tubing hanger Removed Tubing hanger Rigged up Tubing handling equipment Pulled Tubing in stands to 850.0 ft Pulled Tubing in stands to 3150.0 ft Pulled Tubing in stands to 5400.0 ft Laid down 5439.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 0.0 ft (2-7/8in OD) Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 5517.0 ft Circulated at 5517.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing to 660.0 ft (1-1/4in OD) Ran Tubing in stands to 5517.0 ft Circulated at 5517.0 ft Ran Tubing to 5981.0 ft (2-7/8in OD) Ran Tubing to 6115.0 ft (2-7/8in OD) Circulated at 6115.0 ft Pulled Tubing in stands to 0.0 ft Serviced ESP Serviced ESP Ran Tubing in stands to 1952.0 ft Rigged up sub-surface equipment - Other sub-surface equipment Ran Tubing in stands to 2850.0 ft Ran Tubing in stands to 4600.0 ft Ran Tubing in stands to 5452.0 ft Ran Tubing to 5452.0 ft (2-7/8in OD) Ran Tubing to 5452.0 ft (2-7/8in OD) Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 75.000 bbl of Diesel Cleared Flowline Rig moved 0.00 % STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging~ Pull tubing x Alter casing __ Repair well Perforate__ Other__ 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2948' FNL, 3756' FEL, SEC. 33, T13N, RIOE At top of productive interval 1568' FNL, 492' FEL, SEC. 33, T13N, RIOE At effective depth 1526' FNL , 233' FEL, SEC. 33, T13N, R IOE At total depth 1510' FNL, 129' FEL, SEC. 33, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 70' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPI-02 9. Permit number/approval number 90-91 10. APl number 50- 029-22066 11. Field/Pool Kuparuk River / Scrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6260 feet Plugs (measured) None 4308 feet 6138' feet Junk (measured) None 4293 feet Casing Length Size Cemented Structural Conductor 71' 13-3/8" 500 sxs. PermaFC S u rface 2765' 9-5/8" 938 sxs. PermaFE Intermediate Production 6186' 7" 391 sxs. G Liner Perforation depth: measured 5710'- 5722' 5803'- 5826' 5982'- 6018' 5775'- 5782' 5898'- 5940' true vertical 3895'- 3904' 3966'- 3983' 4101'- 4128' 3945'- 3950' 4038'- 4069' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 EuE 5482' MD Measured depth 106' 2800' 6221' True vertical depth 106' 2384' 4280' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 237 9 4 3 250 250 Subsequent to operation 19 7 8 2 16 250 250 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations ~ Oil x Gas__ Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1~' '-' -~ v 06/15/88 ~ ""'"'~ -~''/ Title Wells Operation Superintendent Form Service Date SUBMIT IN DUPLICATE MP 1-02 Operations Summary o , ° o Pre-rig: Install dummy valve in the GLM. Freeze protect the well and install BPV. Remove wellhouse and flowline. MIRU Polar 1 pulling unit. Kill well with heated kill weight fluid before ND_NU. Pull existing 2-7/8" tubing and ESPCP completion. Perform slickline TD tag. To verify no fill. Run a new ESPCP on 2-7/8" L-80 tubing and heat trace through permafrost. Freeze protect well. ND BOP and NU tree. RDMO Polar 1. Put well on production. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~,' Chairman ~ ~ THRU: Blair Wondzell, ~~ FILE NO: P. !. Supervisor ~ I¢,..q96 DATE: jUNE 23, 1996 aw91fwdd.doc FROM: John Spaulding,~r SUBJECT' Petroleum Insp'.'Jean BOPE Test Polar 1 BPX MPU well 1-02 Kuparuk River Field PTD ¢O ~ Oc~/ Sunday June 23, 1996' I traveled this date to BPX's Milne Point Unit to witness the BOPE Test on Polar Energy's rig 1. The AOGCC test report is attached for reference. The rig has been shut down waiting to receive and install the correct gas detection system, both LEL and H2S. I was at the rig and witnessed the final installation and calibration by Mike Kisser of Alaska Petroleum Contractors. Mr. Kisser is certified in the installation and calibration procedures. The calibration forms are attached. The rest of he BOPE test went well with 2 failures observed, 1on the kill line and I floor valve. These items were repaired or replaced and testing was continued. The area around the rig although quite small was well layed out with good access. Summary: I witnessed the BOPE test on Polar rig 1 with 2 failures, 3 hour test time. Attachments: aw91fwdd.xls Calibration forms (APC) Unclassified Confidental (Unclassified if document removed) Confidentai STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X Polar Energy Rig No. BP Exploration MPI.02 X Set @ Weekly 6,260 Other I PTD # Rep.: Rig Rep.: Location: Sec. DATE: Rig Ph.# Dave Hildreth 6/23/96 659-2782 Gordon Ross T. R. Meridian TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign yes Drl. Rig ok Hazard Sec. yes Quan. Test Press. P/F 1 300/2,500 P N/A 250/3,000 1 250/3,000 P I 250/3,000 P 3 250/3,000 P 1 250/3,000 P 2 250/3,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Math Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan Test Pressure 250/5,000 P/F 250/5,000 2 300/3, 000 P 250/5,000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 250/5,000 P 42 250/5, 000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: N/A 3,000 P 2,050 P minutes 15 sec. minutes 58 sec. YES Remote: Need Psig. · ~ TEST RESULTS Number of Failures: 2 ,Test Time: ~ ~ours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within O ~ Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Smafl leak on kill line - repaired and continued testing; Leak on floor valve replaced and continue testing. PVT & flow show was serviced,'"Hydril re-sealed and serviced,"'Accumulator was serviced and K-valve for hydril was repaired. LEL & H2S equipment was installed and certified by APG Fire & Safety (Mike Kisser) 6-23-96 8am Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev. 12/94) AW9LFWDD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging__ Perforate .... Pull tubing x Alter casing m Repair well m 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 2948' SNL, 3756' WEL, SEC. 33, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 70' 7. Unit or Property name Milne Point Unit 8. Well number MPI-02 At top of productive interval 1568' SNL, 492' WEL, SEC. 33, T13N, RIOE At effective depth At total depth 1510' SNL, 129' WEL, SEC. 33, T13N, RIOE 9. Permit number/approval number 90-9 I/Conservation order 347 10. APl number 50- 029-22066 11. Field/Pool Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 6260 feet 4309 feet 6138' feet 4218 feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing w/Centrilifl PC ESP assembly to 5480' MD Packers and SSSV (type and measured depth) "A WD" packer @ 5846' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gravel pack screen assembly w/Otis Versa-trieve packer @ 5517" MD & Otis R _CF. iV rcD APR - 4 1995 ijil & Gas Cons. C0mmissiot~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of WeJJ Operations x 17. I hereby ce~i~ t.~~mmmm~r~,,.~g~and correct Signed Form 10-404 Rev/36/15/88 16. Status of well classification as: Oil x Gas Suspended to the best of my knowledge. Title Drilling) Engineer Supervisor Service SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIOk, ~ PAGE: 1 WELL: MPU 1-02 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/04/95 08:00 SPUD: RELEASE: 03/08/95 06:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 03/05/95 ( 1) TD: 6260 PB: 6139 NIPPLE UP BOPS MW: 0.0 MOVE RIG FROM J-03 TO 1-02 AND SPOT OVER WELL. BERM AND TRIM HERC. PULL BPV SET AND HOOK LINES TO THRASH TANK AND TEST. LINES. PUMP 8.4 PPG HEATED SOURCE WATER DOWN TBG TAKING RETURNS TO THRASH TANK. CIRC. ND ADAPTER FLG AND TREE. NIPPLE UP BOPS. ACCEPTED RIG @ 2000 HRS ON 03/04/95. 03/06/95 (2) TD: 6260 PB: 6139 RUNNING GR/JB W/ CAMCO MW: 0.0 NIPPLE UP BOPS. TEST BOPS. RIG UP LUBRICATOR FOR OFFSET HGRS AND PULL TWC. M/U LANDING JT IN HGR BOLDS AND PULL HGR TO FLOOR, TEST ESP CABLE W/ SYSTEMS REP AND LAY DOWN 1 - GLM AND 93 JTS 2 7/8" RICE WRAPPED TBG. FOUND ARC DAMAGE TO COLLARS ON JTS. CONTINUE TO PULL TBG STRAP AND DRIFT. STAND BACK 14'STDS. CHANGE OUT 9 COLLARS. LAY DOWN 33 JTS AND HAD 25 GALLED JTS. INSPECT AND LAY DOWN ESP. RIG CAMCO TO RUN GR/JB AND TAG TD. 03/07/95 (3) TD: 6260 PB: 6139 RIH W/ ESP COMP MW: 0.0 CONTINUE RIG CAMCO AND RUN #1 GR/JB TO 5517'. POH AND RIG DOWN CAMCO UNIT. RIG UP ON 7" X 9 5/8" ANNULUS AND TEST WITH DIESEL, OK. CLOSE OFF AND REPLACE FLGS. P/U PCP AND INSP AND RIH W/ SAME PICKING UP TBG FROM SHED. CUT DRLG LINE. CONTINUE TO RIH W/ COMPLETION. RIG UP TO RUN RAYCHEM HEAT TRACE TAPE. CONTINUE TO 'RIH W/ ESP COMP INSTALLING HEAT TRACE TAPE AND FLAT BANDING. 03/08/95 (4) TD: 6260 PB: 6139 RELEASE RIG. TREE SECURE. MW: 0.0 CONT TO RIH WITH PCP ESP COMPLETION INSTALLING HEAT TRACE TAPE.SPACE OUT FOR HGR. & HEAT TRACE. MAKE SPLICE IN ESP CABLE TO HGR. LAND HGR. IN TBG. SPOOL & TEST TO 50000 PSI. SET TWC. ND. BOP'S & ADAPTER. N/U ADAPTER FLG & TREE TEST TREE TO 500 PSI. REPLACE LOCK DOWN PIN GLAND NUTS ON TBG SPOOL & TEST ADPT FLG. TO 5000 PSI & PULL TWC. FREEZE PROTECT W/85 BBL DRY CRUDE DOWN ANNULUS & 12 BBL MECH. IN TBG SET BPV. SECURE TREE & CLEAN PIT. RIG RELEASED AT 0600 HRS 3/8/95. SIGNATURE: DATE: Gas Cons. Commission Anchor; , .~noco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed ,cord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents Core Analysis Report Sidewall Descriptions ~01~? .~.-2 Final Drilling Report C~1.-_~_,~ ,'~1-3 Final Drilling Report ¢~)1~'1 ~!-4 Final Drilling Report (~-,~!-1 Final Drilling Report ¢~1~ ! ~-2 Final Drilling Report C~~ ~1-3 Final Drilling Report -3 No Whole Core or Sidewall Cores taken as noted on completion report. ~l~J I-4 Final Drilling Report 1 t-4A Core Analysis Report 1 ; U-1 Final Drilling Report c~1~I d-1 Core Analysis Report 1 ~-1 Core Description Report ~11.~~ ~ ~-2 Final Drilling Report '~-2 Completion History ¢~)1~'7-. 'Jo'-3 Final Drilling Report O~:~l~~J~-4 Final Drilling Report ~.~ ~ Final Drilling & Completion Report ~:~)~--//E~--:8 Final Drilling & Completion Report 9 Final Drilling & Completion Report C~ f jO/.~_9 C°re Descripti°n Rep°rt - Core Analysis Report RECEIVED & Gas Cons. Commission Anchorage ¢ Signed By Date Transmittal Approved By -'. Instructions: Please rmng second copy. Received By Date Remarks "~June lb;-1-E~3 Transmittal Copy Only To (Jonoco Inc. Anchorage Division hecord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 {907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. MO¥ 5. 1993 3201 C Street~ Suite 200 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers ,Subject Milne Point Well Log Magnetic Tapes I-2, I-3, I-4~ I-4A~ J-l~ J-3~ J-4~ L-7~ L-8~ L-9 Quantity Contents 1 each I-2 Magnetic Tape. ~EDIT; APl #50-029-22066, Log Date: 03-NOV-90, Ref #74175. :::~:...~-,~,i, I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203. g~O-c~ I-4 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-90, Ref #74208. ~l~~ I-4~Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 29-Nov-90, Ref #74229. J-1 Magnetic Tape. Open Hole,APl #50-029-22070, Log Date: .13-Dec-90, Atlas Wireline & LIS listing,c~O-~'~' J-3 Magnetic Tape. O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & LIS listing. J-4 Magnetic Tape. O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting. c~~ L-7 Magnetic Tape. O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350. ~ L-8 Magnetic Tape. Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS Iisting.~o~ll3D L-9 Magnetic Tape. O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467. ¢[O RECEIVED M~Y 0 5 ~iaska 0il & Gas Cons. C0mmlssi0n Anchorage **LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver granted via phone conversation May 5, 1993. {~~~ Signed By Transmittal Approved By ~ Date Instructions: Please ackno~'~ge~°mptly by signing and returning second copy. Received By Date May 5, 1993 Remarks Transmittal Copy Only To STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well __ Plugging __ Time extention Stimulate. Change approved program Pull tubing ..X Variance __ Perforate __ Other Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2948' FNL, 3756' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 1568' FNL, 492' FEL, Sec. 33, T13N, R10E, U.M. At e~fective depth 1526' FNL, 233' FEL, Sec. 33, T13N, R10E, U.M. At total depth 1510' FNL, 129' FEL, Sec. 33, T13N, R10E, U.M. .5. Type of Well: Development X Exploratory __ Stratigraphic __ Service NSB AK NSB AK NSB AK 6. Datum elevation (DF or KB) KB 7O MSL 7. Unit or Property name Milne Point Unit 8. Well number I-2 9. Permit number 90-91 10. APl number 5O-029-22066 11. Field/Pool NSB AK feet Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 6260' feet 4309' feet Plugs (measured) Effective depth: measured 6138 feet true vertical 4218 feet Junk (measured) Casing Length Size Structural Conductor 71' 13-3/8" Surface 2765' 9-5/8" Intermediate Production 6186' 7" Uner Perforation Depth: Cemented Measured depth True vertical depth Surface 106' 106' Surface 2800' 2384' T.O.C.@~ 4000' 6221' 4280' measured 5710'-5722', 5742'-5758', 5775'-5782', 5803'-5826', 5898'-5940', 5982'-6018' true vertica13895'-39o4', 3920'-3932', 3945'-3950', 3966'-3983', 4038'-4069', 4101'-4128' Tubing (size, grade, and measured depth)2-7/8", 6.5#, L-80, 8rd, EuE, 5482' MD R ErE ~VED Packers and SSSV (type and measured depth) None MAR - 6 ~ag~. Alaska 0ii & Gas Cons, Coral 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch Arlch01'a~ 14. Estimated date for commencing operation April 1, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,,~~/~".~-~B. G. Augustine Title Sr. Production Engineer ! FOR COMMISSION USE ONLY Date 3/5/92 Conditions of approval: Notihj Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test Su---'bsequent form required 10-'"' Approved by order of the Commission ORIGINAL SIGNED BY' LONNIE C, SMITH Approval No. Commissioner Date ,-.~- ~- (~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE tissiO~ MILNE POINT UNIT I-Z IEPLACE INOPEI~TIVE E-SUB SU~Y PROCEDURE 1. MIRU slickline unit and pull dummy valve from gas lift mandrel at 5294'. RDMO slickline unit. 2. MIRU workover rig. 3. Kill well with 8.6 ppg NaCl. ND production tree. NU BOPE and test. 4. POOH with tubing to E-Sub (approximately 20'). tubing. LD E-Sub and 1 joint of 5. POOH with 3000' of coated tubing and LD. 6. RIH with 3000' of coated tubing, replacing seal rings. 7. Replace E-sub. 8. RIH with tubing. Land hanger and pressure test. 9. ND BOPE and NU production tree. Pressure test tree. RDMO rig. 10. MIRU slickline unit. RIH and set dummy valve in gas lift mandrel at 5294'. RDMO slickline unit. 11. Return well to production. RECEJVJSD Alaska Oil & Gas Cons. Anchorage AL.~KA OIL. AND ~AS CONSERVATION COMMI~o~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging Pull tubing ~ Alter casing __ Repair well X Pedorate __ Other 2. Name of Operator CONOCO TNC. 3. Address 3201 C St.,Ste.,200 Anchorage, AK 99503 4. Location of well at surface 2948' FNL, 3756' FEL, Sec. 33, At top of productive interval 1568' FNL, 486' FEL, Sec. 33, At effective depth 5. Type of Well: Development X__ Exploratory __ Stratigraphic __ Service __ T13N, R10E, U.M. T13N, RiOE, U.M. Attotaldepth 1510' FNL, 129' FEL, Sec. 33, T13N, RiOE, U.M. 6. Datum elevation(DForKB) 70 KB feet 7. Unit or Property name Milne Point Unit 8. Well number I-2 9. Permit number/approval number 90-91 / ~/-- 2g~- 10. APl number 50--029-22066 11. Field/Pool Kuparuk River/ Schrader Bluff 12. Present well cOndition summary Total depth: measured true vertical Effective depth' measured true vertical 6260 feet 4308 feet 6138 feet 4293 feet Plugs (measured) None None Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 71' 13-3/8" 500 sxs. PermaFC 2765' 9-5/8" 938 sxs. PermaFE 6186' 7" 391 sxs. G measured 5710'-5722' 5775'-5782' truevertical 3895'-3904' 3945'-3950' Tubing (size, grade, and measured depth) 2-7/8", Packers and SSSV (type and measured depth) None Measured depth True vertical depth 106' 106' 2800' 2384' 6221' 4280' 5803'-5826' 5898'-5940' 3966'-3983' 4038'-4069' 6.5#, L-80 EuE 5982'-6018' 4101'-4128' RECEIVED 5482 ' MD FEB 1 992 ,Alaska Oil & Gas Cons. CommissiOn /~nchora_~e 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 15 0 6 0 10 250 250 Subsequent to operation Well down for final surface hook-up & check-out 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. 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/~/Z¢9¢ L.~",~_J~,~-.-,.~'~ Title Form 1~)-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 02-18-91: RIH w/ GR/TDT, log gravel; good pack indicated up to 5662' (top of screens 5698'), GR indicates all lobes taking gravel. R/D Schlumberger. P/U Reda pump assby. RIH w/ pump. Checked pump & cable @ 25 stands - only showing 250 ohms to ground. PSI not indicating pressure. POOH. Found PSI not working; changeout same. RIH checking cable every 10 stands. 02-19-91: Finish RIH w/ 171 jnts of 2-7/8" tbg, & ESP cable. Splice ESP cable to lower pig tail. Land tbg hgr & screw in lockdowns; tested hanger body seals to 5000 psi. N/D BOP; N/U tree; test to 5000 psi. Pull 2-way check. Pump 60 bbls of diesel into 7" x 2-7/8" annulus. Install BPV & pump 12 bbls diesel into tbg. Operations suspended pending well test. Rig released @ 2400 hrs 02-18-91. Milne Point I No. 2 - WORKOVER API No.: 50-029-22066 t,ocation: AFE Number: AFE Amount: Milne Point Field - SCHRADER BLUFF POOL 10-61-1436 Approved: 09/18/91 $400,000 gross Cost to Date: $ 261,080 gross 1~/15/91: Move Rig over to I-2 Well. (unload brine). RU & Hook-up lines & equipment 12/16/91: Continue to rig up lines, etc. Had problems with circulating & offloading - lines were froze up. Off load 400 BBLS of 8.6 NACL with 12% methanol in brine tanks (raise derrick - vac out slop tank). Heat NACL brine to 150° with hot oil truck. Pull BPV out of tubing hanger. Fill boilers with potable water. Work on spooling unit generator. RU to pump NACL 8.6 ppg brine down annulus & return through tubing. Check locks on MC & Reda drive in ESP building. Pump brine at 150° @ 2.75 BBL/min rate. Pumped 240 BBLS reverse circulating - Pump press 300 PSI. Tubing press 150. SD pump - well is dead. 0 PSI TBG & 0 PSI casing. Returns looked clean. Set BPV in TBG hanger. Nipple down tree. Nipple up BOP's. Complete BOP inspection; test press 2500 PSI using diesel. Vac out slop tank. 240 BBLS crude & diesel. RU & run 2-way check. Sting into hanger and lift to rig floor. Breakout hanger & penetrator after resistance checks on both cable & penetrator. Found bad spots in cable at 90' 150' 160' 175' & 214' 4 stands in derrick. 12/17/91: Cut bad spots out of cable in several spots. Called electricians out to work on spooling unit generator. Restored power to unit. Continue out the hole with ESP assembly. Found one more bad spot in cable @ 915' (29th stand). Reach top of pump. Take resistance readings. Remove flatguards and flat cable. Take oil samples. Everything looks good except for top seal section with oil contamination. Motor looks like it may have a flat spot where possibly rubbing and/or overheating. Top of pump looks like (discharge) paint peeled off due to overheating. Pump turns freely & motor turns but with some resistance due to possible flat spot on housing. Disassembled ESP and lay down; Break out 7 bad joints of TBG. PU Otis APR- M2 circulating valve & seal assembly in order to sting into the Otis "VST" packer. Packer is set at 5520' KBM (change out). RIH with 2-7/8" EUE 6.5#/ft. TBG (175 JTS) Otis seal unit, and APR-M2 cir. valve to 5520'. Pick-up 5' and circulate tubing volume. RU slickline unit w/1.5" bailer. RIH & tagged fill at 6063 ' WLM, 45 ' below bottom perf in "O" sands. POOH w/slickline. Found small amount of formation sand. Set up pits to pump wellbore clean out treatment - wait on source H~O. Pressure up annulus to 1400 PSI. Shifted APR-M2 circulating valve. Mix pills of 50 BBL dirt magnet & 25 BBL HEC. Pump down TBG. ~2/18/91: Pumped a total of 290 BBLS of NACL 8.6 PPG down TBG and up annulus. Pumped 6 BBLS of super pickle with 26 BBLS of source water to spot accross APR-M2 cir. valve. Pumped 42 BBLS to clean up. Returns looked good. POOH with 2-7/8" EUE 6.5#/ft. tubing, circ. valve, seal assembly. Lay down 98 JTS of TBG. Leave 2400' or 76 JTS of 2-7/8" EUE in derrick. Move tubing from pipe shed. PU centrilift pump assembly. Pull empty spool from spooling unit & re-spot spooling unit. Move ESP equipment into pipe shed. Move 60 JTS 2-7/8" 8rd rice wrap pipe into pipe shed. Wait on Reda to lay down old ESP equipment. Make up ESP equipment. Wait on centrilift hand to make splice on cable & run ESP equipment. 12/19/91: Waiting on Centrilift hand to make splice on ESP cable. RIH with ESP pump, 4' PUP JT two JTS 2-7/8" EUE 8rd TUB, check valve, two JTS 2-7/8" EUE 8rd TUB 2' PUP JT 2-7/8" x 1-1/2" MMG-P gas lift mandrel, 4' PUP JT & 72 JTS of 2-7/8" EUE 8rd TUB. Pick up & install contactor. RIH with 82 JTS of 2-7/8" EUE 8rd rice wrap TUB. Ran out of ESP cable with 400' ~ to go. Bring in new spool of ESP cable & start making splice. Shut down rig. 12/20/91: Completed making splice on ESP cable at 350' from surface. Continue to RIH. Make up 2-7/8" 8rd EUE crossover sub, PTE E- sub 2' x 2-7/8" EUE 8rd PUP, 2-7/8" x 1" EUE 8rd KBMG-M gas lift mandrel, 3' x 2-7/8" EUE 8rd PUP & tubing hanger. Splice ESP cable to pig tail & hook to tubing hanger. Run continuity test on ESP cable & pig tail. Make up PTI power cable. Land hanger & fish PTI cable out of casing valve. ND BOP's & NU production tree. Test tree to 5000 PSI & hanger to 1000 PSI (ok). Start ~etting rig ready to move. Could not rig down because of -48 weather. Clean mud pits. 12/21/91: Rig down Ewe & support equipment. Wait on trucks to move rig if weather permits. Temperature -45°. Fix and repair rig, also start clean up of rig & location. Rig up HB&R to freeze protect well. Pressure test lines two 2000 PSI. Start pumping @ 1.5 BBLS/min @ 1000 PSI down tubing. Tubing displacement 30 BBLS. Displacement from GLM to perforations 12 BBLS. Pump total of 42 BBLS. Shut down for 10 minutes to let diesel migrate up back side. Continue this process until we pumped a total of 105 BBLS of diesel. Final press 750 PSI @ 1/4 BBL/min. Rig down HB&R & secure well. RECEIVED Alaska Oil & ~a$ Cons. CommissiO~ Anchorage 12/22/91: Wait on trucks to move rig, weather permitting. Temperature is -50o. Can not use crane to move well house off G-7 to. Max operating range for crane is -35° per manufacturer. Continue to clean up rig & make repairs. Trucks to move rig came available. Moved well house off G-7 by cutting door support beam & skidding well house off with two loaders, re-weld. Support beam on well house good as new. Level pad, start moving ri~. Will not raise mast on rig until temperature gets above -35 . We lowered mast on I-2 when temp was -34°. FEB 1,~ 1992 Alaska Oil & Gas Cons. Commission AnChorage. STATE OF ALASKA ALA~r~A OIL AND GAS CONSERVATION COMMIbolON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown Re-enter suspended well Plugging __ Time extention Stimulate Pull tubing X Variance __ Perforate __ Other Name of Operator 5. Type of Well: 6. Conoco Inc. Development X Address Exploratory. 7. 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Service Location of well at surface 8. 2948' FNL, 3756' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 1568' FNL, 486' FEL, Sec. 33, T13N, R10E, U.M. At effective depth At total depth 1510' FNL, 129' FEL, Sec. 33, T13N, R10E, U.M. Datum elevation (DF or KB) 70 KB unit or Property name Milne Point Unit Well number I-2 9. Permit number 90-91 10. APl number 50-029-22066 11. Field/Pool feet Kuparuk River/Schrader Bluff 12. Present well condition summary -Total depth: measured 6260 feet Plugs (measured) None true vertical 4308 feet Junk (measured) None E/fective depth: measured 6138 feet Junk (measured) None true vertical 4293 feet Casing Length Size Cemented Structural Conductor 71' 13-3/8" 500 SXS. PermaF C surface 2765' 9-5/8" 938 sxs PermaF E Intermediate 254 SXS. E Production 6186' 7" 391 SXS. G Liner Perforation Depth: measured 5710'-5722' 5803'-5826' 5982-6018' 5775'-5782' 5898'-5940' true vertical 3895'-3904' 3966-3983' 4101 '-4128' 3945'-3950' 4038'-4069' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 EuE 5476' MD Measured depth 106' 2800' 6221' Packers and $SSV (type and measured depth) None True ve~cal depth 106' 2384' 4280' 13. Attachments Description summary of proposal . .X Detailed operations program BOP sketch 14. Estimated date for commencing operation 10/01/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . Au~lustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Mechanical Integrity Test ~ Location clearance ..... Subsequent form required 10- ~ ~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy Returned Date c1. ~1 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE H~LNE POINT UNiT ~-~ .... . OUT F~LL AlqD RUN NEW L SU~Y PROCEDURE 1. MIRU EWS #4 rig. 2. Kill well with 8.5 ppg NaCl. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with wireline tools. Tag fill. 5. POOH with wireline and RD unit. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 5520'. Pressure test annulus to 500 psi. 7. RU coiled tubing unit. RIH with coiled tubing and circulate out fill to PBTD. 8. POOH with coiled tubing and RD coiled tubing unit. 9. POOH with 2-7/8" tubing and seal assembly. 10. PU new ESP, motor, and cable. RIH with ESP assembly and tubing. Set bottom of pump at 5480'. 11. ND BOPE and NU production tree. RDMO rig. 12. Return well to production. RECEIVED STATE OF ALASKA ALASKA i _AND GAS CONSERVATION CC ,AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL C~] GAS C SUSPENDED i:'~, '"~ ABANDONED 2. Name of Operator CONOCO INC. 3. Address Pouch 340045, Prudhoe Bay, Alaska 99734 4. Location of well at surface SERVICE LJ i¢' t~', ,,,,, 2948'FNLx3756'FEL of Sec. 33, T13N R10E Umiat F[~ridi~n At TOp Producing Interval 1568'FNLx486' FEL of Same Section At Total Depth ~5~0'~Lx~29' ~DL o~ Same Sact$o~ 5. Elevation in feet (indicate KB, DF, etc.) 70' KB Lease Designation and Serial No. ADL - 25906 12. Date Spudded 10-27-90 17. Total Depth (MD+TVD) 6260 + 4308 13. Date T.D. Reached 11-1-90 18.Plug Back Depth'iM~TVD) 6138 + 4293 22. Type Etectric or Other Logs Run DITE, LDT, CNL, NGT, AMS Classification of Service Well 7. Permit Number 90-91 8. APl Number 5o--029-22066 9. Unit or Lease Name Milne Point Unit 10. Well Number ~-2 11. Field and Pool KUPARUK RIVER FIELD 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions ~1 I N / A feet MSL , / ,~ IV 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost YES]i(] NO [] NONE feet MD I + 1800 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP 35 BOTTOM 106 28OO HOLE SIZE 30 ,,12-1/4 CASING SIZE CEMENTING RECORD 500 sxs PermaFrostC 938 sxs PermaFrost E 254 sxs E AMOUNT PULLED NONE NONE WT. PER FT. GRADE 13-3/8 54.5# K-55 36# J-55 35 9-5/8 7 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) N Sand 5710-22 MD, 3903 TVD 12SPF, 24GM,5742-58, 5775-82 5803-26 MD, 3991TVD 12SPF, 24GM 0 Sand 5898-5940 MD, 4046 TVD, 5SPF, 37GM 5982-6018 MD, 4136 TVD, 5SPF, '37GM 26# L-80 35 6221 8-1/2 391 sxs G NONE 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2--7/8 5476 NONE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 5898-6018 82726# 16-20 Hesh 27. PRODUCTION TEST Carbo Lite Proppant I Method of Operation (Flowing, gas lift, etc.) Submersible Pump- Well Unloaded and shut-in DateNAof Test HoursNATested 1TESTPERIOD I~ IPRODUCTION FOR OIL-BBL IGASoMCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED , IOIL-BBL I GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~1~l 28. CORE DATA . '¢- ~.-. '~ "~ '~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ch,ps,~, '~.iti~ ~ , ~¢~.. ~ Date First Production 3-3-91 NONE TAKEN Form 1 O-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. NAME Top of "N" Sand Top of "0" Sandi GEOLOGIC MARKERS MEAS. DEPTH 5710' 5898' TRUE VERT. DEPTH 3903' 4046' r ,~RMATION TESTS Include interval tested, pressure data, alt fluids recovered and gravity, GOR, and time of each phase. NA 31. LIST OF ATTACHMENTS Plat, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S igned~._ _~?_~/~_(~_~/.~,,~ Title Sr. Prod. Foreman Date 4-28-91 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 NOTES: I. STATI~ PLANE[ COORDINATES ARE ZONE 4, 2, ALL GEODETiC POSITIONS AF~E BASED ON N.A-D. 1927, OFFSE:'PS TO SECTION LINES ARE COMPUTED BASED ON Pt~OTEACT~D VALUES OF THf[ SECTION CORNER POSITIONS, I PAD PROPOSED , ----_ _ EXPANSI ON I ~--:~I--~I-5 I-'6 I-7 ,28 ' ~I ! I ~SSERVS P~T i ! ~'l ~IILN[ POINT UNIT ~ ...--'-"~- I PAD ! \, ~ gAY MtLNE PT. VICINITY MAP MILES LEGEND I EXISTING WELL 0 PROPOSED WELL PI j I-3.. $ 87'25'19" E Y 6,009,284,486 410,00' X 551,787,589 AS-BUILT WELL DATA PLANT COORD$ LOCATED WITHIN SECTION 3,3 T. 13 N., R. 10 E., U.M., ALASKA I--1 N 1120.60 Y 6,009,445.29 70' 26' 11.58¢' 2951" FNL E 1580.~6 X S51o6?S.16 1~9' ~4° 4~.261" 5696' FEL i I-2 N 1120.47 Y 6,009,447.85 70' 26° 11.614" 29~8' FNL E 1320.51 X 551,615.27 1~9' 34' 45.019' 3756" FEL !-3 Nl120.1¢ Y 6,009,450.22 70' 26' 11.6¢I" 2945' FNL E 1260.~1 X 551,5§5.2~ 149' ~4.' 46.780' 3816' FEL ,,i, 1-4 N 1119.98 Y 6,009,4,52.80 70' 26° 11.670" 2942' FNL E 1199.66 X 551,~9~.5~ 1~9" 34' ~8.§61" 5876' FEL , ~ II I ..... SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTEREr3 AND LICENSED, TO PRACTICE LAND SURVEYING IN THE STATE OF' ALASKA, AND THAT THIS PLAT REPRESENTS A LOCATiON SURVEY MADE BY ME OR UNDER MY DIR- ECT SUPERVISION,AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, =~:0 ~-VEyED FOR: ._ cconoco) DATE: 3-27-91 - "- DRAWN: STOLL 0 c. Ec~E~:,6..:.o WELL CONDUCT R AS-BUILTS ~o. No.: ~oos~ I-1 I-2, I-,3 & I-- SCALE: 1" - 300' t Milne Point I No. 2 COMPLETION HISTORY Kuparuk River - SBP - North Slope Borough, Alaska W.I. 1.0 Milne Point I No. 2 (P) CONFIDENTIAL AFE 10-61-1256 Location: 2948' FNL, 3756' FEL, Sec. 33, T13N, R10E, U.M. NSB AK Location: Bottom hole, 1456' FNL, 159' FEL, Sec. 33, T13N, R10E Objective: 6110' MD- Schrader Bluff 01-29-91: Rig accepted 0000 hrs 01-29-91. N/D tree, N/U BOP. Test BOP. P/U bit/scraper/4DC. RIH, P/U drill pipe. Tagged bottom @ 6154. Mix & reverse 20 bbls H20 w/ 27 gal of dirt magnet. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,009,617 POOL 102 (0-9-1) Drillinq Foreman: BRADY 01-30-91: Reverse circulate @ 6 bpm to displace 9.2 ppg brine w/ 8.6 ppg. Filter to 2 microns & complete a full circulation. POOH. WOW. R/U Schlumberger, GCT. RIH to 6100' & log up. Clean snow f/ perf guns & attempt to establish continuity - no success. Roads impassable, cannot get more tools. Rest Schlumberger personnel. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,037,521 POOL 102 (0-9-2) Drillinq Foreman: BRADY 01-31-91: WOW. Schlumberger unit inoperative - needs replacement parts. R/D Schlumberger. RIH to 1200, circulate to prevent freezing. WOW. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,058,524 POOL 102 (0-9-3) Drillinq Foreman: BRADY 02/01/91: WOW. POOH, R/U Schlumberger. WOW - road open to MPU & to spine. P/U guns, RIH, tie in w/ open hole GR, shoot 5 SPF, 5 lb, 37 gm shots f/ 6002' - 6018'. P/U next gun w/ CCL. RIH tie-in w/ CCL & perf f/ 5982' - 6002'. POOH w/ gun. RIH w/ gun & tie-in w/ CCL. Perforate from 5918-38' & 5938-40'. POOH w/ gun. RIH w/ gun & tie-in w/ CCL. Perforate from 5898' - 5918'. POOH w/ gun. R/D Schlumberger. P/U 3 jts DP, Champ PKR, Jars & RIH. 02/02/91: RIH w/ Champ PKR to 5698' R/U Dowell Schlumberger. Set PKR @ 5698'. Pressure test blckside to 500 psi. Continue to R/U DS. Prep pumps, engines, turbines for frac job. Pressure test lines to 7500 psi. OK. Pump 100 bbl pre-pad @ 25 bpm. Shut down for 10 min. ISIP - 934 psi. Pump frac job as follows: 340 bbls pad, 15 bbl 2 ppg prop, 32 bbl 4 ppg prop, 35 bbl 6 ppg prop, 50 bbl 8 ppg prop, 60 bbl 10 ppg prop, 70 bbl 12 ppg prop, 56 bbl 14 ppg prop (out of 75 bbls planned) When the pressure immediately increased from ± 3900 psi to 6500 psi. Attempt to displace frac fluid w/ diesel. No success. R/D DS lines on rig floor. R/U to reverse circ. Open bypass ports on Champ PKR. Pressure up on annulus to 1000 psi. Could not reverse circ. 0 psi on DP. Wait on post-fracture treatment as per completion procedure. Milne Point I No. 2 Completion History Page 2 02/03/91: Wait on post frac treatment as per completion procedure. Unseat Champ PKR. POOH. Pipe pulled dry. No sand in DP. P/U bailer assby & TIH. Assby: saw tooth collar, flapper valve, 40 jts 3-1/2" DP, bailer, safety jt, 3-1/2" DP. Tagged sand @ 5345'. Bailed for 1 hr - lost = 30' of hole. Sand still settling out. 02/04/91: Note: Found 2 stand error in pipe talley. Depth sand tagged - 5472' Top of perforations 5898' PBTD - 6148' · , · Est. 676' sand (= 26 bbls sand). Attempt to bail sand. Lost another 30' to approx 5410'. POOH w/ 4-7/8" bailer. Found piece of hydril rubber lodged up against flapper valve. Recovered = 1 bbl sand. Mandrel on bailer stuck in closed position. Could not get open. P/U 2-7/8" bailer & RIH on 3-1/2" DP. Use 30 jts 3-1/2" DP for cavity. Tag sand @ 5395'. Bail 10' to 5405'. Sand began falling in. Lost ± 60' hole to 5350'. Make 5 stand short trip. Tag sand @ 5342'. POOH w/ 2-7/8" bailer. Recovered 3/4 bbl sand. L/D bailer assby. Mandrel stuck in closed position also on 2-7/8" bailer. (Suspect frac sand is causing this). P/U 6" bit w/o jets & TIH to 3014'. Rev circ hole volume. Got back traces of frac sand. Slip & cut drill line. RIH w/ bit to rev circ on bottom. 02/05/91: TIH to 5312'_ccir Tagged sand. R/U to rev circulate. Reverse full hole @ 100 stk/min. Attempt to wash down thru sand. No success. P/U kelly. Rotate ± 30' thru sand, circulating long way. L/D kelly· R/U to reverse circulate. Pump 15 bbl Hi Vis pill. Circ 1 hole volume. Pill returns indicated very little sand· Pump 10 bbl Hi Vis pill. Circ two complete hole volumes. Est top of sand @ ± 5320'. POOH w/ bit. TIH w/ saw tooth collar, flapper valve, 10 stds 3-1/2" DP. M/U 2-7/8" bailer· Observed stem on bailer was twisted & bent near the tool joint. Decision made not to run bailer until stem inspected· L/D bailer· Send in to Tuboscope for inspection. Had bailer Magna-fluxed, straightened out & Magna-fluxed again. Tool check out OK. Send back to rig. P/U bailer assby & TIH. [P/U 10 stds 3-1/2" DP for cavity - 4.2 bbls capacity] Note: 4-7/8" bailer used in prior run is no longer usable. Replacement is scheduled to arrive 2/8/91. Tag sand @ 5324'. Bail sand f/ 5324' - 5371' (47'). 02/06/91: Bail sand f/ 5371 - 5394'. Bailer quit stroking. POOH. Retrieved 2.8 bbls of sand. P/U 2-7/8" bailer. TIH. Tag sand @ 5393'. Bailer not stroking. Attempt for 1-1/2 hrs to get bailer to work. No success. POOH w/ bailer. Prepare to run Baker hydrostatic bailer. P/U notch collar/flapper valve, 48 jts 2-7/8" tbg, Baker master hydrostatic valve, 3-1/2" DP & TIH. RIH w/ 3-1/2" DP dry. Tag sand @ 5403'. Bail f/ 5403' -5598' (195'). POOH w/ bailer assby. Milne Point I No. 2 Completion History Page 3 02/07/91: POOH w/ bailer assby. No sand in tbg cavity. Flapper valves (Baker has dual flappers in their sub) failed to hold sand. Geolograph showed sudden loss in weight in a couple of spots. R/D sand chute. P/U 2-7/8" flapper valve off bulldog bailer & place 1 jt above Baker flapper sub for extra backup. TIH & tag sand @ 5499'. Bail sand f/ 5499' - 5530'. Master hydrostatic valve stopped functioning. Assby quit bailing. Close hydril. Pressure up on annulus to 800 psi. Try to unplug string. No success. POOH w/ bailer assby. Found hydrostatic valve full of frac sand. Retrieved 1-1/2 bbls of sand. P/U mule shoe jt, csg scraper. TIH to 2507'. Rev circ 2 hole volumes. Pump 15 bbl Hi Vis pill around. TIH to 4504'. Rev circ/pump Hi Vis pill. Recovered trace of sand. TIH to TD. Tag @ 5509'. Pump 15 bbl Hi Vis pill. Reverse circ 1-1/2 hole volumes. POOH to P/U hydrostatic bailer. 02/08/91: Finish POOH. P/U Baker notch collar/flapper valve, 1 jt 2-7/8" tbg, backup flapper valve, 47 jts 2-7/8" tbg, master hydrostatic valve, 3-1/2" DP & TIH. Tag sand @ 5512'. Bail f/ 5512' - 5528' Bailer quit bailing @ 5528'. POOH w/ bailer assby. C~uld find nothing wrong w/ assby. Appears that something is on bottom preventing us from bailing. (Possible rubber from annular). Change hydril rubbers. Install new nitrile rubber. Old rubber very damaged. P/U 6" bit, DC's & TIH (Due to weather, could not get any junk baskets out). 02/09/91: Finish TIH. Tag bottom @ 5518'. Rotate on bottom w/ 2000-4000 #'s weight w/o pumps. Attempt to break up any rubber on bottom. R/U to reverse circ. Pump 15 bbl Hi Vis pill. Circulate 3 complete hole volumes. Observed trace of sand/ small pieces of rubber while circulating. P/U kelly & rotate on bottom w/ 2000-4000 #'s weight on bottom w/o pumps. Bit hung up once indicating something hard on bottom. R/U to reverse circ Tag bottom @ 5520'. Pump 20 bbl Hi Vis pill. Circ 2 complete hole volumes @ 5 bbl/min. Observed only trace of sand/rubber @ surface. POOH w/ bit. Found 1 jet plugged w/ rubber. P/U globe basket, DC's & RIH. Tag @ 5521'. Work pipe w/o circulating. Made 1-1/2'. Reverse circ @ 5-6 bbl/min. Work pipe down to 5527' P/U kelly. Make a few rotating runs on bottom. Reverse ~irc @ 6 bbl/min (2 bottoms up). Worked to 5528'. Prepare to POOH for bulldog bailer. 02/10/91: POOH w/ 6" globe basket. No junk in basket. P/U bulldog bailer assby & TIH. Tag sand @ 5528'. Bail sand f/ 5528'-5728' (200'). POOH w/ bailer. Recovered 8 bbls sand (19 stds). TIH w/ bulldog bailer. Tag sand @ 5723'. Bail f/ 5723'-5874' (151'). Milne Point I No. 2 Completion History Page 4 02/11/91: Bail f/ 5874'-5955'. POOH to 4-7/8" bulldog bailer. R/U to dump sand. Found sand 1 stand below bailer. POOH & recover 9 bbls of sand. P/U bailer to service. Bailer came out of hole stuck in open position (upstroke position). Send rod section to Baker machine shop in Deadhorse for evaluation. Rabbit & RIH w/ saw tOoth collar, flapper valve & 23 stds 3-1/2" DP. Found out from Baker that threads were not repairable. Call out Baker 2-7/8" hydrostatic bailer. POOH w/ 3-1/2" DP. M/U sawtooth collar, flapper valve (spring loaded), 42 jts 2-7/8" tbg, Baker drain sub, 8 jts 2-7/8" tbg, safety jt, Baker hydrostatic valve, 3-1/2" DP & TIH. Tag sand @ 5956'. Bail f/ 5956'-6036' (80'). 02/12/91: Bail f/ 6036'-6148 (PBTD). POOH w/ bailer assby. Recovered 15 stds sand (5.5 bbls) w/ traces of crude oil. M/U 6" bit, 11 jts 3-1/2" DP, csg scraper & TIH. Tag bottom @ 6064' (84' off PBTD of 6148'). Tag @ 6055'. Lost 9'. P/U 1 std & go to bottom. Tag @ 6052'. Lost 3'. P/U 1 std & go to bottom. Tag @ 6052'. Circ 8' off bottom @ 1.2 bpm. Pump 90 bbls clean fluid. RIH @ tag bottom @ 6051' (Lost 1'). Did not lose any fluid while pumping. POOH above perfs to 5845'. Clean filters on DE filter press. Circ/Filter fluid @ 5845' Lost = 39 bbls while filtering fluid. RIH to bottom. Tag ~ 6049'. POOH to pickup Baker hydrostatic bailer. 02/13/91: P/U hydrostatic assby & TIH. Tag sand @ 6051'. Bail f/ 6051'-6148'. P/u & wait 15 min. GIH to bottom. No fill. POOH to above perfs. RIH & tag sand @ 6065'. Lost 83'. Bail sand f/ 6065'-6148'. Wait 15 min & re-tag bottom. No fill. POOH w/ bailer. Recovered 3 bbls sand (78' in 7" csg). R/U Schlumberger. RIH w/ junk basket & 6" gauge ring. Could not get past 3893'. POOH. No junk in basket. RIH w/ same. Could not get past 3948'. POOH. Found one small piece of DP hardband in basket. Take off junk basket. RIH w/ 6" gauge ring. Could not get past 3880' POOH & R/D Schlumberger. Wait on boot baskets f/ Tri-State. M/U 6" bit, 3 boot baskets, csg scraper, 5 DC's & TIH on 3-1/2" DP. 02/14/91: TIH to 3800'. Work pipe thru 3750'-3800'. Circ down to 3970'. TIH to 5890'. POOH. Found no junk in boot baskets. R/U Schlumberger. RIH w/ GR, CCL, junk basket, 6" gauge ring, 2 weight bars to 5864'. OK. POOH. M/U sump PKR, GR-CCL. RIH w/ sump PKR. Could not get past 4022' (Angle 69°). POOH. P/U sump PKR, hydraulic setting tool, 2-7/8" PUP jt, XO, 1 std 3-1/2" DP, RA sub. TIH to 5856' on DP. R/U Schlumberger. RIH w/ GR-CCL to correlate PKR setting depth. Milne Point I No. 2 Completion History Page 5 02/15/91: Correlate PKR setting depth w/ Schlumberger 1-1//16" GR-CCL tool. POOH w/ wireline & R/D Schlumberger. Drop 1-7/8" ball. Position PKR @ 5846'. Pressure up on ball to 2200 psi. P/U pipe & set down 10,000 #'s on PKR to verify it set. Press up to 3000 psi to blow ball into ball catcher sub. POOH w/ setting tool. R/U Schlumberger to perforate. Arm & load perf guns (12 SPF, 24 gm). RIH w/ Run #1. Correlate guns w/ GR-CCL. Perforate "N" sand f/ 5803'-5826' (23'). POOH w/ guns. P/U guns for Run #2. Correlate w/ CCL. Perforate f/ 5742'-5758' (12 SPF). POOH w/ guns. P/U guns for Run #3, shoot f/ 5775'-5782', 5710'-5722'. POOH. P/U 3-1/2" OD gun for dummy run, RIH to 5846' and run through sump PKR, no obstructions noted. P/U Re-entry guide/XN nipple/pup/collet guide/XO/Isolation sub/XO/T.T, screen/O-ring sub/2 jnts of 3-1/2", screen - handling sub backed out of screen, dropped screen assby in hole. W.O.T. to fish screens. 02-16-91: W.O.T. P/U O.Shot/B-sub/Jars/DC. RIH tag fish @ 5758' - fish had not fallen inside sump PKR. Work over fish. POOH w/ fish; retrieved entire assembly. L/D top screen; L/D jars/B- sub. P/U gravel pack assby & washpipe. RIH w/ drillpipe. Drop ball. Space out. 02-17-91: Set PKRw/ 1500 psi & pull test to 10,000 lbs over string wt. Pressure to 2800 psi. P/U & shear out of release. Pressure to 4000 psi - shear out ball seat. Locate reverse position, pump 30 bbl high visc sweep down drill pipe & back to surface. Pump pickle solution. Establish rates in squeeze mode 0.9 bpm - 35 psi, 5 bpm - 1420 psi. Pump in squeeze mode @ 8 bpm - 2020 psi. Establish circulating rates 5 bpm = 500 psi. Gravel pack well. Test pack to 2000 psi. OK. R/D Howco, POOH L/D drillpipe. R/U Schlumberger. 02-18-91: RIH w/ GR/TDT, log gravel; good pack indicated up to 5662' (top of screens 5698'), GR indicates all lobes taking gravel. R/D Schlumberger. P/U Reda pump assby. RIHw/ pump. Checked pump & cable @ 25 stands - only showing 250 ohms to ground. PSI not indicating pressure. POOH. Found PSI not working; changeout same. RIH checking cable every 10 stands. 02-19-91: Finish RIH w/ 171 jnts of 2-7/8" tbg, & ESP cable. Splice ESP cable to lower pig tail. Land tbg hgr & screw in lockdowns; tested hanger body seals to 5000 psi. N/D BOP; N/U tree; test to 5000 psi. Pull 2-way check. Pump 60 bbls of diesel into 7" x 2-7/8" annulus. Install BPV & pump 12 bbls diesel into tbg. Operations suspended pending well test. Rig released @ 2400 hrs 02-18-91. OPERATOR: CONOCO MILNE POINT UNIT I-2 FINAL DRILLING REPORT WELL: MPU I-2 CASING: 13-3/8" @ 105' FIELD: Milne Poin~i'a&Ep., ,.'.Y / 7 ,/99~TD: 6,110' " u// &. . 9-5/8" e 2800 7",~~s · CURRENT TD: 6260 PR~'RESS: 0 DATE: 10-28-90: 10-29-90: 10-30-90: 10-31-90: 11-01-90: 11-02-90: 11-03-90: 11-04-90: 11-05-90: 11-06-90: Description of Operations: Move rig from I-1 to I-2 conductor. PU rig @ 2230 hrs 10-27-90. PU BHA, mix spud mud, function test diverter. Drill 105 to 330. Replace hydraulic pump on rig floor. MWD failed. Trip for new MWD. Drill to 1024. Drill 1024 to 1083. Ream 992 to 1083. Drill to 1417. Short trip 10 stds. Drill to 2363. Short trip 10 stds. Drill to 2485. Drill 2485 to 2525. Ream 2363 to 2525. Drill to 2820. C & C. Short trip. C & C. POOH. Run 4 arm caliper on E/L. Unable to get below 1614. RIH w/bit. C & C. POOH to run csg. Run 71 jts, 2753', 9 5/8", 36#, K-55, Butt csg. FS @ 2800' FC @ 2719'. Circ. Cement w/329 BBL Artic cmt & 52 BBL G cmt. Disp cmt & bump plug. ND diverter. Install speed head. NU BOP. Test BOP. MU 8 1/2" drilling assy. RIH. Drillout HOS cmt collar @ 1009. RIH. Drill out cmt to 2718. Test csg to 1500 psi. Drill FC & FS. Drill 2820 to 2830. Run leakoff test to 16.0 PPG EMW. Drill to 4444. Trip for MWD & bit. RIH. Tight hole. Ream 3016 to 3394. Ream 3394 to 4444. Drill 4444 to 5294. Short trip. Drill to 6260. C & C. Short trip. C & C. RU E/L. Unable to get log below 3900'. RIH w/bit. C & C. POOH. RU E/L. Run DITE-LDT-CNL-NGT-AMS f/6256 to 2800. RIH w/bit. C & C. POOH. LD DP & BHA. RU & run 155 jts, 6180', 26#, L-80, Butt csg. FS @ 6221. FC @ 6139. Circ. Cement w/391 sx (80 BBL) G cmt @ 15.8 PPG. DISP w/ 214 BBL 9.2 PPG Brine & 20 BBL diesel. Bump plug. Test csg to 1500 psi. Install packoff. Would not test. Change out packoff. Test OK. ND BOP. NU tree. Clean pits. Finish cleaning mud pits. Released rig @ 0200 hrs 11-05-90 to I-3. Operations suspended. RIG RECEIVED: 10-27-90 SPUD DATE: 10-28-90 RIG:Nabors 27-E DAYS: 9 / 9 FOREMAN: Mountjoy ~UB.~URFACE DIRECTIONAL ~URVEY ORIGINAL I~UIDANCE ~]ONTINUOUS ~IOOL Company Well Name CONOCO, INC. MPU I-2 (2948' FNL, 3756' FEL, SEC 33, T13N, RIOE) FleldlLocatlon SCHRADER BLUFF, NORTH SLOPE, ALASKA Job Reference No. 74326 Loo(:ed 8¥: BARNARD SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 29-JAN-91 ENGINEER: K.BARNARD METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. Aver&geO deviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF NORTH 67 DEG 58 MIN EAST COMPUTATION DATE: 5-FEB-91 PAGE CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 29-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.O0 100.00 200.00 300 00 400 00 500 00 600 O0 700 00 800 O0 900 00 0.00 99.95 199.95 299.95 399.95 499.94 599.80 699.43 798.71 897.32 -70. O0 0 0 N 0 0 E 29.95 0 4 N 83 43 W 129.95 0 0 5 50 54 W 229.95 0 7 N 44 26 W 329.95 0 6 N 68 48 E 429.94 1 9 N 68 54 E 529.80 4 14 N 65 18 E 629;43 5 44 N 65 3 E 728.71 8 1 N 65 37 E 827.32 1'1 9 N 63 11 E 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E -0.39 0.00 0.45 N 0.60 W 0.75 N 52 58 W -0,46 0.00 0.46 N 0.68 W 0.82 N 55 59 W -0,43 0,32 0.55 N 0.68 W 0.88 N 51 7 W -0.44 0.28 0.54 N 0.70 W 0.88 N 52 17 W 0.09 3.53 0.84 N 0.25 W 0.88 N 16 25 W 5. 19 1.44 2.84 N 4.45 E 5.28 N 57 29 E 13.66 1.84 6.41 N 12.15 E 13.73 N 62 10 E 25.58 2.03 11.37 N 22.99 E 25.65 N 63 41 E 42.13 3.57 18.53 N 37.94 E 42.23 N 63 58 E 1000.00 994.66 924.66 14 47 1100.00 1091.17 1021.17 15 57 1200.00 1186.48 1116.48 19 23 1300.00 1279.23 1209.23 23 46 1400.00 1370.08 1300.08 25 2 1500.00 1459.63 1389.63 28 16 1600.00 1546.52 1476.52 31 27 1700.00 1630.43 1560.43 33 21 1800.00 1713.44 1643.44 33 55 1900.00 1796.20 1726.20 35 4 N 62 39 E 64.83 1.20 N 62 6 E 90.91 3.53 N 60 22 E 120.89 4.54 N 61 44 E 157.95 2.81 N 61 38 E 199.48 1.40 N 62 13 E 243.68 3.07 N 62 32 E 292.92 5.02 N 63 39 E 347.10 0.83 N 64 50 E 402.75 1.36 N 64 9 E 458,77 2.84 28.92 N 58.24 E 65.02 N 63 35 E 40.93 N 81.51 E 91.21 N 63 20 E 55.72 N 107.86 E 121.41 N 62 41 E 73.68 N 140.57 E 158.71 N 62 20 E 93.46 N 177.37 E 200.49 N 62 13 E 114.48 N 216.55 E 244.95 N 62 B E 137.37 N 260.41 E 294.42 N 62 11 E 162.12 N 308.84 E 348.80 N 62 18 E 186.23 N 359.11 E 404.53 N 62 35 E 210.43 N 409.75 E 460.63 N 62 49 E 2000.00 1875.69 1805.69 40 23 N 63 18 E 519.20 2100.00 1949.77 1879.77 43 26 N 63 32 E 586.14 2200.00 2020.40 1950.40 46 43 N 63 31 E 656.70 2300.00 2087.05 2017.05 49 38 N 63 20 E 731.02 2400.00 2149.80 2079.80 51 34 N 61 2 E 808.41 2500.00 2212.18 2142.18 51 16 N 61 36 E 886.04 2600.00 2273.68 2203.68 53 3 N 62 7 E 964.44 2700.00 2331.22 2261.22 57 24 N 62 30 E 1045o79 2800.00 2383.56 2313.56 58 38 N 63 3 E 1130.65 2900.00 2433.97 2363.97 62 6 N 65 24 E 1216.79 6.41 3.04 3.58 4.43 1.65 0.93 1.75 4.74 2.10 5,68 237.23 N 464.10 E 521.22 N 62 56 E 267.33 N 524.14 E 588.38 N 62 59 E 298.92 N 587.47 E 659.14 N 63 2 E 331.95 N 654.28 E 733.67 N 63 6 E 368.86 N 722.82 E 811.50 N 62 58 E 406.29 N 791,43 E 889.63 N 62 50 E 443.53 N 860.93 E 968.46 N 62 45 E 481.51 N 933.33 E 1050.22 N 62 43 E 520.53 N 1009.07 E 1135.42 N 62 43 E 558.08 N 1086,81 E 1221.72 N 62 49 E 3000.00 2477.36 2407.36 65 23 3100.00 2517.26 2447.26 66 38 3200.00 2557.70 2487.70 66 44 3300.00 2595.22 2525,22 68 22 3400.00 2633.77 2563,77 66 6 3500.00 2677.04 2607.04 63 2 3600.00 2720.34 2650.34 65 5 3700.00 2762.37 2692.37 65 39 3800.00 2800.40 2730.40 69 17 3900.00 2836.07 2766.07 69 3 N 66 21 E 1306,81 N 67 1 E 1398.47 N 65 32 E 1489.91 N 62 24 E 1582.31 N 63 26 E 1674.20 N 64 49 E 1764.13 N 65 45 E 1854.16 N 66 23 E 1944.84 N 64 34 E 2037.21 N 65 5 E 2130.49 3,73 2.89 5.17 2,35 4.54 2.58 O. 64 3.63 1.34 0.53 594.74 N 1169.08 E 1311.67 N 63 2 E 631.18 N 1253.22 E 1403.19 N 63 16 E 667.12 N 1337.32 E 1494.48 N 63 29 E 708.37 N 1420.31 E 1587.15 N 63 30 E 750.49 N 1502.39 E 1679.41 N 63 27 E 789.88 N 1583.46 E 1769.54 N 63 29 E 827.55 N 1665.34 E 1859.63 N 63 35 E 864.37 N 1748.27 E 1950.28 N 63 41 E 902.93 N 1832.31 E 2042.70 N 63 46 E 942.64 N 1916.87 E 2136.11 N 63 49 E COMPUTATION DATE: 5-FEB-91 PAGE 2 CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE. ALASKA DATE OF SURVEY: 29-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2871.55 2801.55 69 29 N 65 23 E 2223.88 4100 O0 2906.49 2836.49 69 25 N 65 41 E 2317.49 4200 O0 2941.47 2871.47 69 24 N 65 59 E 2411.11 4300 O0 2979.02 2909.02 65 34 N 65 56 E 2503.71 4400 O0 3022.88 2952.88 62 13 N 66 5 E 2593.51 4500 O0 3072.50 3002.50 58 23 N 68 48 E 2680.28 4600 O0 3126.42 3056.42 56 5 N 72 5 E 2764.41 4700.00 3184.22 3114.22 53 40 N 74 35 E 2845.61 4800.00 3244.33 3174.33 52 3 N 75 33 E 2924.93 4900.00 3307.13 3237.13 49 29 N 76 19 E 3002.00 0.80 981.77 N 2001.78 E 2229.57 N 63 52 E 0.29 1020.59 N 2087.06 E 2323.24 N 63 56 E 0.80 1059.00 N 2172.51 E 2416.87 N 64 1 E 4.63 1096.66 N 2257.16 E 2509.47 N 64 5 E 5.21 1133.27 N 2339.22 E 2599.28 N 64 9 E 3.62 1166.95 N 2419.20 E 2685.95 N 64 15 E 4.44 1195.32 N 2498.48 E 2769.69 N 64 26 E 1.40 1218.44 N 2576.72 E 2850.28 N 64 42 E 1.94 1239.13 N 2653.91 E 2928.94 N 64 58 E 4.48 1258.13 N 2729.36 E 3005.38 N 65 15 E 5000.00 3373.43 3303.43 48 15 N 76 31E 3076.04 5100.00 3440.04 3370.04 48 5 N 76 54 E 3149.77 5200.00 3508.27 3438.27 44 48 N 76 57 E 3221.93 5300.00 3561.78 ~3511.78 40 53 N 76 30 E 3288.93 5400.00 3658.07,e~_.3588.07 40 6 N 76 45 E 3352.85 5500.00 3734.49~-w 3664.49 40 7 N 78 5 E 3416.49 5600.00 3811.15~ 3741.15 39 59 N 79 1E 3479.59 5700.00 3887.60~ 3817.60 40 17 N 79 35 E 3542.79 5800.00 3963.68 3893.68 40 36 N 80 18 E 3606.29 5900.00 4039.37 3969.37 41 6 N 80 38 E 3670.08 0.25 1275.68 N 2802.13 E 3078.85 N 65 31 E 0.90 1292.87 N 2874.7~ E 3152.06 N 65 47 E 5.49% 1309.24 N~2945.94 E 3223.77 N 66 2 E 2.87~ 1324.86 N~3011.89 E 3290.40 N 66 15 E 0.35~ 1339.89 N~3074.76 E 3354.02 N 66 27 E 1.17~ 1354.05 N~3137.69 E 3417.39 N 66 39 E 0 60~ 1366 71N 3200.64 E 3480 23 N 66 53 E 0 44 ~1378 64 N~3263.98 E 3543 19 N 67 6 E 0.45 1390.04 N 3327.87 E 3606.51 N 67 20 E 0.52 1400.83 N 3392.33 E 3670.18 N 67 34 E 6000.00 4114.50 4044.50 41 23 N 80 41 E 3734.47 6100.00 4189.53 4119.53 41 34 N 61 7 E 3798.98 6200.00 4264.35 4194.35 41 34 N 81 7 E 3863.58 6260.00 4309.24 4239.24 41 34 N 81 7 E 3902,35 0.60 1411.55 N 3457.45 E 3734.49 N 67 48 E 0.00 1421.94 N 3522.83 E 3798.98 N 68 1 E 0.00 1432.19 N 3588.38 E 3863.63 N 68 15 E 0.00 1438.33 N 3627.71 E 3902.44 N 68 22 E CONOCO INC. MILNE POINT UNIT SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 5-FEB-91 PAGE 3 DATE OF SURVEY: 29-JAN-91 KELLY BUSH[ND ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVER[TY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -70.00 0 0 N 0 0 E 0.00 1000.00 994.66 924.66 14 47 N 62 39 E 64.83 2000.00 1875.69 1805.69 40 23 N 63 18 E 519,20 3000.00 2477.36 2407.36 65 23 N 66 21 E 1306.81 4000.00 2871.55 2801.55 69 29 N 65 23 E 2223,88 5000.0D 3373.43 3303.43 48 15 N 76 31 E 3076.04 6000.00 4114.50 4044.50 41 23 N 80 41 E 3734.47 6260.00 4309.24 4239.24 41 34 N 81 7 E 3902.35 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1.20 28.92 N 58 24 E 65.02 N 63 35 E 6.41 237.23 N 464 10 E 521.22 N 62 56 E 3.73 594.74 N 1169 OB E 1311.67 N 63 2 E 0.80 981.77 N 2001 78 E 2229.57 N 63 52 E 0.25 1275.68 N 2802 13 E 3078.85 N 65 31 E 0.60 1411.55 N 3457 45 E 3734.49 N 67 48 E 0.00 143B.33 N 3627.71 E 3902.44 N 68 22 E COMPUTATION DATE: 5-FEB-91 PAGE 4 CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE. ALASKA DATE OF SURVEY: 29-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -70.00 0 0 N 0 0 E 70.05 70.00 0.00 0 5 N 78 39 W 170.05 170.00 100.00 0 1 S 71 7 W 270.05 270.00 200.00 0 7 N 8 2 E 370.05 370.00 300.00 0 2 S 41 22 E 470.06 470.00 400.00 0 20 N 52 31 E 570.13 570.00 500.00 3 41 N 66 4 E 670.43 670.00 600.00 5 10 N 65 13 E 771.03 770.00 700.00 7 23 N 65 39 E 872.20 870.00 800.00 10 10 N 63 56 E 0.00 0.00 O.O0 N -0.35 0.12 0.45 N -0.46 0.27 0.46 N -0.43 0.35 0.50 N -0.47 0. 17 0.54 N -0.30 1.87 0.68 N 3. 12 2.39 1.98 N 10.86 2.23 5.23 N 21 .71 2.46 36.99 2.97 0.00 E 0.00 N 0 0 E 0.56 W 0.72 N 51 20 W 0.68 W 0.82 N 55 52 W 0.67 W 0.83 N 53 16 W 0.73 W 0.91 N 53 25 W 0.60 W 0.91 N 41 21 W 2.56 E 3.24 N 52 17 E 9.60 E 10.93 N 61 25 E 9.77 N 19.46 E 21.78 N 63 20 E 16.24 N 33.34 E 37.08 N 64 2 E 974.52 970.00 900.00 14 16 N 62 46 E 58.45 1078.01 1070.00 1000.00 15 23 N 62 40 E 84.99 1182.57 1170.00 1100.00 18 39 N 60 14 E 115.26 1289.94 1270.00 1200.00 23 29 N 61 41 E 153.95 1399.91 1370.00 1300.00 25 2 N 61 38 E 199.44 1511.80 1470.00 1400.00 28 34 N 62 19 E 249.29 1627.72 1570.00 1500.00 32 44 N 62 39 E 307.58 1747.55 1670.00 1600.00 34 2 N 64 25 E 373.40 1868.15 1770.00 1700.00 34 14 N 64 17 E 440.69 1992.50 1870.00 1800.00 39 57 N 63 19 E 514.33 2.91 1 .60 3.79 2.92 1 .40 2.54 3.87 1.68 2.34 7.16 25.98 N 52.54 E 58.61 N 63 41 E 38.18 N 76.24 E 85.26 N 63 24 E 52.91 N 102.93 E 115.73 N 62 48 E 71.78 N 137.03 E 154.69 N 62 21 E 93.44 N 177.34 E 200.45 N 62 13 E 117.11 N 221.54 E 250.59 N 62 8 E 144.15 N 273.48 E 309.15 N 62 12 E 173.66 N 332.54 E 375.16 N 62 26 E 202.55 N 393.44 E 442.52 N 62 46 E 235.03 N 459.73 E 516.33 N 62 55 E 2128.08 1970.00 1900.00 44 20 N 63 30 E 605.55 2273.89 2070.00 2000.00 48 46 N 63 51 E 711.31 2432.40 2170.00 2100.00 51 17 N 61 20 E 833.55 2593.88 2270.00 2200.00 52 57 N 62 4 E 959.57 2773.89 2370.00 2300.00 58 48 N 62 51 E 1108.41 2982.42 2470.00 2400.00 65 8 N 66 17 E 1290.85 3231.76 2570.00 2500.00 67 46 N 64 4 E 1519.14 3484.42 2670.00 2600.00 63 10 N 64 36 E 1750.25 3718.80 2770.00 2700.00 66 24 N 66 8 E 1962.02 3995.57 2870.00 2800.00 69 27 N 65 22 E 2219.73 3.39 2.86 0.96 1 .81 0.47 2.11 5.19 2.90 4.88 0.70 276.01 N 541.57 E 607.85 N 63 0 E 323.15 N 636.58 E 713.90 N 63 5 E 381.07 N 745.01 E 836.81 N 62 55 E 441.24 N 856.61 E 963.57 N 62 45 E 510.37 N 989.20 E 1113.10 N 62 43 E 588.33 N 1154.47 E 1295.73 N 63 0 E 679.55 N 1363.82 E 1523.75 N 63 31 E 783.95 N 1570.89 E 1755.64 N 63 29 E 871.29 N 1763.99 E 1967.44 N 63 43 E 980.05 N 1998.01 E 2225.42 N 63 52 E 4277.69 2970.00 2900.00 66 44 N 65 57 E 2483.32 4495.18 3070.00 3000.00 58 32 N 68 38 E 2676.17 4675.89 3170.00 3100.00 54 0 N 74 15 E 2826.27 4841.48 3270.00 3200;00 51 30 N 75 46 E 2957.22 4994.85 _3370.00 3300.00 48 14 N 76 30 E 3072.24 5144.64 3470.00 3400.00 47 31 N 77 8 E 3182.45 5284.39 3570.00 3500.00 41 22 N 76 37 E 3278.80 5415.60 3670.00 3600.00 40 7 N 76 50 E 3362.78 5546.35 3770.00 3700.00 39 53 N 78 38 E 3445.78 5676.94 3870.00 3800.00 40 12 N 79 30 E 3528.19 5.79 1088.35 N 2238.53 E 2489.08 N 64 4 E 3.97 1165.44 N 2415.38 E 2681.85 N 64 15 E 2.29 1213.21 N 2557.97 E 2831.10 N 64 38 E 1.77 1247.20 N 2685.48 E 2960.97 N 65 5 E 0.28 1274.78 N 2798.40 E 3075.07 N 65 31 E 2.34 1300.31 N 2906.96 E 3184.53 N 65 54 E 3.66 1322.47 N 3001.93 E 3280.32 N 66 13 E 0.59 1342.19 N 3084.54 E 3363.91 N 66 29 E 0.62 1360.04 N 3166.86 E 3446.55 N 66 46 E 0.39 1375.94 N 3249.33 E 3528.65 N 67 3 E CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 5-FEB-91 PAGE 5 DATE OF SURVEY: 29-JAN-91 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTZCAL VERTZCAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IOO FEET FEET FEET DEG 5808.32 3970.00 3900 O0 40 37 N 80 21 E 3611.58 5940.70 4070.00 4000.00 41 17 N 80 40 E 3696.23 6073.97 4170.00 4100.00 41 31 N 81 4 E 3782.13 6207.55 4270.00 4200.00 41 34 N 81 7 E 3868.46 6260.00 4309.24 4239.24 41 34 N 81 7 E 3902.35 0.34 1390.95 N 3333.21 E 3611.79 N 67 21 E 0.30 1405.19 N 3418.77 E 3696.29 N 67 39 E 1.03 1419.30 N 3505.72 E 3782.13 N 67 58 E 0.00 1432.96 N 3593.33 E 3868.51 N 68 16 E 0.00 1438.33 N 3627.71 E 3902.44 N 68 22 E CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READ[NG GCT DRILLERS TD COMPUTATION DATE: 5-FEB-91 PAGE 6 DATE OF SURVEY: 29-JAN-gl KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2948' FNL & 3756' FEL, SEC33 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6080.09 4174.5B 4104.58 1419.93 N 3509.73 E 6260.00 4309.24 4239.24 1438.33 N 3627.71 E COMPUTATION DATE: 5-FEB-91 PAGE 7 CONOCO INC. MILNE POINT UNIT I-2 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 29-JAN-91 KELLV BUSHING ELEVATION: 70.00 FT ENGINEER: K.BARNARD *****e****** STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2948' FNL & 3756' FEL, SEC33 T13N RIOE MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST READING GCT DRILLERS TD 6080.09 4174.58 4104.58 1419.93 N 3509.73 E 6260.00 4309.24 4239.24 1438.33 N 3627.71 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 6260.00 4309.24 4239.24 3902.44 N 68 22 E SCHLUMBEROER O I AEC T I ONAL SURVE Y COMPANY CONOCO INC. WELL MILNE POINT UNIT I-2 FI ELD SCHRAOER BLUFF COUNTRY USA RUN ONE DATE LOOOEO 29 - JAN - 9i REFERENCE ?4326 WELL:· MP, U I-2 (2948'' FNL, 3756' FEL, SEC 33, T13N, RIOE) HORIZONTAL PROJECTION 4OOO 10{30 -2OOO ~ou'rH -3000 -2000 SCALE = l/10130 IN/FT ~ I I i i ~ i ~ ~ ~ T"i r~--~-~---~-~+-+?"-~T+~ ~ ~.~-..~..LI..~_ ~ ~.~ -,.L.~-L..~..~..~ ~ i ~ : ~ ~ ~ :. ~ ~ ~ *. ' ' ~ ' ' ' ~ ~ ~-~ -: ~ i ' ~ ~ ~ ~ ' '"'~"' '*T'~'"*"~ .... ~ ............. t*"~-~ ~-~- ] ~ ~ ~ { I : t i ~ ~ ] ~ : : i : : i i . f . i [', : ~ ~ ; - · ;~-~ ~ ~ ~ ~ ' '..,.~_~. :.: : . : ~ : ~ ~ ~ : ~ ; , . 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CONTACT check off or list data as it is received.*list received date for 407. if not rcouired list as NR * ~-i drillin~ histo~-~ survev well tests core descri I LOG ~.,nc, ,r- ' i RUN INTERVALS SCALE NO. {to thc nearest foot) {inchl100'] , i ~1 I i , ,, . ................... [i8! ~ , SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLCX~Y CORPORATION HOUSTON. TEXAS 77251-2 t 75 PLEASE REPLY TO ~'~ ! 3 1991 SCHLUMBERGER WELL SERVICES Pouch 340069 ?rudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger Gentlemen: Enclosed are 2 BLprints of the Company CONOCO, Inc. Completion Record, Run 1, 2/14/91 on: Well Milne Point Unit I-2 Field Milne Poipt /Schrader Bluff Additionolprintsare beingsentto: 1BL nrints CONOC6, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope State 1BL prints, 1RF Sepia CONOCO, Inc. 1000 South Pine Alaska Ponca City, OK 74603 Attn: Glenn Welch 7360RDW 1 BL mrints, 1 RF Sepia OXY U' S.A., Inc. 5 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) 1BL prints, 1RF Sepia Chevron U.S.A. 11Ill South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) ~I~sk~ Oil & Gas Gouserv~Xbion 3001 Porcupine Drive chora~e.-AK 99501 The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints ~prints prints Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SWS--I327.F CONOCO, Inc. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725! -2 ! 75 PLEASE REPLY TO SCHLUMBERGER WELL SERVICES ......... ~ Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber~er Gentlemen' Enclosed ore 2 BLprintsof the Company CONOCO, Inc. Gravel Pack Log, Run 1, 2/17/91 on: Well Milne PointUnit I-2 Field Milne Point Additional prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER .County North Slope ..... State 1 BL prints. 1 RF Sepia CONOCO, Inc. 1000 South Pine Alaska Ponca City, OK 74603 Attn: Glenn Welch 7360gDW 1 BL prints, I RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) 1BL prints, I RF Sepia Chevron U.S.A. 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) A!ask~ Oil & Gas ConservationXx Commission . ~ __3001 Porcupine Drive . ~ ~.~_Anchorage, AK 99501 A~: John Boyle ~/ The film is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints prints prints Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SWS-- ! 327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 FEB 0 3 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~SE REPLY TO BCHLUMBERGER WELLBERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernle/Shelley Gentlemen: Enclosed ore_2_BL_prints of the GCT, Run 1, 1/29/91 Company CONOCO, [nc, Well Milne Point Unit I-2 on: Field Milne Point/Schrader Bluff Additional prints are being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 201~ PER ... County North Slope State Alaska _L_]~rints, 1RF Sepia CONOCO; ThC, 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7~6ORDW I BL prints, 1RF Sepia OXY U.S.A., Inc. § Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) __[_J~rints, 1 RF Sepia Ghevron U.S.A. _ 11111 South Wilcr~_.~t_ __ Hnu.~tnn: T~w~ .q 77f}qq Attn: Priscilla MacLeroy ,.'713/561-3652 ~ts, 1 RF Sepia~ Alask~a Oil & Gas Conservation CommJ ssi on 3001 Porcupine Drive~ Anchorage, AK 99501~ x-~t t n: John Boyle ~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints ReceJ ved by: Date-_~r''v~//~ "' , , Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SW$-- 132 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUE~TON. TEXAS 77251-2 175 FEB 0 ~ lg91 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~UIE REPLY TO sc~uus~£~ W~LS~,C£SPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_Z_SL_prints of the. Compony CONOC0, Inc, Well Milne Point Unit I-2 Perforating Record, Run 1, 1/31/91 .on: Field Milne PoJnt/Schrader Bluff Additionol prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Atgn: George Lomb - OF 2018 PER County Nartb Slope Stote Alaska _l_JlL_prints, 1RF Sepia CONOCO: Tnc~ 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7360~DW I BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5600) _l_Jlb_prints, 1RF Sepia Chevron U.S.A. 11111South._Wilcrmmr_ . _Houston: Towa~ 77DqO Attn: Priscilla MacLeroy ,'713/561-3652 /A~as~a Oil & Gas Conservat~gon /- Commission / 3001 Porcupine Drive [ Anchorage, AK 99501 \ Attn: John Boyle film is returned to Conoco, Log LJbrary. We oppreciote the privilege of serving you. prints prints prints ReceJ ved bv: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER Sw$-- 1327.F STATE OF ALASKA - ~,i ~; . ALASt'~ OIL AND GAS CONSERVATION COMMISo~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing m Repair well Change approved program Operation shutdown Re-enter suspended well __ Plugging __ Time extention __ Stimulate X Pull tubing~ Variance Perforate X Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 2948' FNL, 3756' FEL, Sec. 33, T13N, R10E, U.M. At top of productive interval 1680' FNL, 700' FEL, Sec. 33, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory Stratigraphic Service NSB AK NSB AK At total depth 1456' FNL, 159' FEL, Sec. 33, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' AGL 7. Unit or Property name Milne Point Unit Well number I-2 9. Permit number 90-91 10. APl number 50-029-22066 11. Field/Pool Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 115' Surface 2800' Intermediate Production 6221' Uner Perforation Depth: measured 6256' feet 4309' feet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet feet Plugs (measured) Junk (measured) Size Cemented 13-3/8" Surface 9-5/8" Surface 7" T.O.C. @ 4000' Measured depth 115' 2800' 6221' True ve~ical depth 115' 2400' 4285' RECEIVED JAN 1] ]99I Alaska.Oil & Gas Cons. C0mmissl( ; ulch0raga 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 1/27/91 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby cert!fy that the foregoing is true and correct to the best of my knowledge. SigneC_~,(~'~ ~~ Lineberger Title Sr. Production Engineer ~: _~_ ___~_ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date 1/9/91 Plug integrity ~ BOP Test Mechanical Integrity Test Approved by order of the Commission Location clearance Subsequent form required 10- ~ 7 UI~IG]NAL SIGNED BY LONNIE C. S~]TH feet Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT I-2 WELL PROPOSED COMPT.F. TION PROCEDURE - SUMMARY 1/7/91 - CVL NOTE: Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on I-2 well. Test BOP's. 2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean. 3. RU electric line. Run Gyro survey (if necessary). Correlate with open hole logs and perforate "0" sands at 5 SPF over 5898'-5940' and 5982'-6018'. RD electric line. 4. GIH with squeeze packer and set above top perf. 5. MIRU frac equipment. Pressure test all lines. Pump frac job to stimulate "O" sand perf's. RD frac equipment. 6. Clean out proppant from wellbore, if necessary. 7. RU electric line and set gravel pack sump packer above "0" sand perf's and below proposed "N" sand perfs. 8. Perforate "N" sands at 12-24 SPF over 5710'-22', 5742'-58', 5775'-82' and 5803'-26' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 20 bbls. Kill well and POOH. 9. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack 10. Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. 11. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. 12. Leave well shut in until surface equipment installation is complete. RECEIVED JAN 1 1 19,91 ,Oil .& Gas Cons. Anchoraoja STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown .X_ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance ~._ Perforate __ Other __ 2. Name of Operator Conoco Inc. 3. Address 99503 3201 C Street, Suite 200, Anchorage, AK 4. Location of well at surface 2948' FNL, 3756' FEL, Sec. 33, At top of productive interval 1680' FNL, 700' FEL, Sec. 33, At effective depth T13N, RIOE, T13N, RIOE At total depth 1456' FNL, 159' FEL, Sec. 33, T13N, RIOE 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service __ U.M. N.S.B., AK 6. Datum elevation (DF or KB) KB 35 AGI, 7. Unit or Property name Mille Point Unit 8. Well number [-2 9. Permit number 90-91 10. APl number 50-- 029-22066 11. Field/Pool Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 6256 feet 4309 feet Plugs (measured) Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 115 ' 13-3/8" Surface 2800' 9-5/8" Intermediate Production 6221 ' 7" Liner Perforation depth: measured true vertical Cemen~d Surface Surface T.O.C. @ 4000' Measureddepth 115' 2800' 6221' ~ueverticaldepth 115' 2400' 4285' RECEIVED Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) DEC 1 1 1990 Alaska 0il & 6as Cons. Comm'tss'tot~ Anchorage 13. Attachments Description summary of proposal X Shutdown drilling rig operations pending 14. Estimated date for commencing operation 2/9]. 16. If proposal was verbally approved com Detailed operations program __ BOP sketch __ )letions with workover rig. 15. Status of well classification as: Oil X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~,,..b..~, ,..~. Title sr. Drilling Engineer ~teve Rossber~ - ~-"- FOR COMMISSION ~USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical IntegrityTest__ Subsequent form required 10- ~ ORIGINAL SIGNED B'~' Approved Copy LONNIE C g~.~TU Rclurnpd. ~"~ i' Approved by order of the Commission ~.. JOk!C- ?Jll~---~ommissioner Date ].2/7/90 JApproval ¢,~ '--'~'7 / No. /, , Date Form 10-403 Rev 06/15/88 SUBMIT I~ TRII~LICATE SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 NOV 0 6 10g0 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger I~t. EASE REPLY TO SCHLUMBERGER WELL SERVICES?ouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: DIT-E, NGT, CNL(PORO), CNL(RAW). Enclosed ere2 Bl. prints of the Cyberlook, Run 2, 11/O3/90 Company CONOCO, Inc Well Milne Point Unit I-2 on: Field Milne Point/Schrader Bluff Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 201~ PER County North Slope State _L_BL_prints, 1RF Sepia CONOCO, Tnt, 1000 South Pine Alaska Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc 6 Pe~Y~_Dx!xe Midland, TX 79710 Atgn: John Carrol *(915/685-5600) _lJlL_prints, 1RF Sepia Chevron U.S.A. _11111 South.WJlcrmmt_ . :_Houston; TPw~ 770qq Attn: Priscilla MacLeroy .~713/561-3652 1 BL 1 RF Se " A1 0il & Gas :zon -~'C ommi s s i on )1 Porcupine Drive. Anchorage, AK 99501 Attn: John Boyle The film is returned to Conoco, Log Library. prints prints r {CEIVED NOV 0 9 1990 Naska 0il & Gas Cons. Commlesion Anchorage Received by:~ ~ Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DIETRICT MANAGER 5W$-- t 327-F TO: THRU: FROM: MEMORANUUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMM_ISSION Lonnie C. Smi DATE: November 8, 1990 Commissioner · FILE NO: JT. DA. 118 TELEPHONE NO: SUBJECT: Diverter Test Conoco's MPU I-2 Well Permit No. 90-91 Kuparuk Rv Field r e ._ ro I eu~--~n s p e c t or e_.t 28, 1990: I traveled this date from BPX PBU to Conoco's --'%o inspect the diverter system and witness the function test. i found all components of the diverter system to be in compliance. However, I did have Conoco representative, Joe Polya, add a 40' section of !0" pipe to the vent line paralleling the rig so that the end of the line extended past the pipe shed. I stopped by the rig later this date and confirmed this addition. In sun, nary: I conducted an inspection of the diverter system at Conoco's MPU 1-2 well on Nabors Rig 27E. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 I-2175 OC T 3 ! 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberger ~$E REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore2 P,l. prints of the Company CONOCO, Inc. Milne Point Unit I-2 Well BGT, Run 1, 10/30/90 on: Field Milne PoJ. nt Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER ,,County North Slope __State. Alaska _l_BL_prints, 1RF Sepia CONOCO; Tnc~ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 PC_s_t~._P_~_i~e . Midland, TX 79710 Attn: John Carrol *(915/685-56OO) _l__]tL_prints, 1 RF Sepia Chevron U.S.A. §O01 Bollinger Canyon Road San Ramon: CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-to00) lB L~Se pi a~""~ A~k~a Oil & Gas Conservatio~ J Commission _ 3001 Porcupine Dri~~[ Anchorage, ~ 995~ ~ ,,, ~Attn: John Boyle ,.,~~:~ ~ ..... Gas Cons. commission The film ~o¢ ~Jb~ar~. We appreciate the privilege of serving you. prints prints prints Date:/ Very truly yours, SCHLUMBERGER WELL SERVICES SWS-- 13274:* David M, Saalwaechter DISTRICT MANAGER July 27, t990 Telecopy: (907)276-7542 David L. MountJoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Milne Point Unit No. 1-2 Conoco Inc. Permit No. 90-91 Sur. Loc. 2948'FNL, 3756'FEL, Sec. 33, T13N, R10E, UM. Btmhote Loc. 1456'F~, 159'FEL, Sec. 33, T13N, R10E, UM. Dear Mr. MountJ oy: 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 pe~itting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very truly yours, Davi~d W. John~$on Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,,. .--,~ STATE OF ALASKA ALASK OIL AND GAS CONSERVATION 5MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ,~. Redrill -'[ lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Development Oil Re-Entry _ DeepenEI Service '- Developement Gas ~ Single Zone~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. KB 35' AGL feet KUPARUK RIVER 3. Address 6. Property Designation Pnuch 34OO4.~. Pf'udhoe Bay, AK 99734 ADL-25906 FIELD . 4. Location of well' at surface 7. Unit or property Name 11. Type Bond ~see 2o AAC 25.025) 2948 FNL, 3756' FEL, SEC. 33, T13N, R10E MILNE POINT UNIT BLANKET At top of productive interval U,M,, NSB, AK 8. Well number Number 1680' FNL, 700' FEL, SEC. 33, T13N, RIOE I-2 8086-15-54 At total depth 9. Approximate spud date Amount 1456' FNL. 159' FEL, SEC. 33~ T13N~ RIOE OCTOBER 4~ 1990 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line I 3600 'FSL feet! 60'F/I-1 ~ 500' feet 2560 6,58' MD, 4237' TVDf~et 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 630 Maximum surface 1900 psig At total depth fTVD) 2000 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing WeightlGradelCoup,inglLength MOI TVOl MD] TVD (include stago data) '~n, 1~ ~t/~ /1~.~ IH_/t¢~l I,/l:'lrt I Rr~, ~R, I ~R, i 11R, I 11R, 4-4R.~ ..~K.~ PFRHAFRO.~T C 9 5/8 .4~ I;~-.4~1 RTRS 13~E' 35' i .~.~' l~-2-5-0' I 2500' +773 SKS PERMAFROST E ,+333 SKS.,,.CLASS G 10. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) D0~NSQUEEZE trUe vertical feet +_355 SKS PERMAFROST C +60 BBLS DEAD CRUDE Effective depth: measured feet Junk (measured) true vertical feet Length Size Cemented Measured depth True Vertical depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical PIT SKETCH X 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch X~. Drilling program ~_~ Drilling fluid program ;~ Time vs depth plot ;~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge .. ~. ~ .-'¢ ... , ~ ,~-2-;..,~-" SR DRILLING FOREMAN Signed ..~ Title · Date ~ ~"-Commission Use Only Permit Number APl number Approval date See cover letter ¢O -- ~/ 50- O ~ ?- ~ ~ (E' ~" 0 7 / 2 7 / 9 0 for other requirements i Conditions of approval Samples required ~ Yes /,~ No Mud log required ~ Yes ~No Hydrogen sulfide measures ~ Yes'~2M'~'N°; Directional survey required ~Yes ~ No t Required working pressure for BOPE ~ 3M; .~ 5M; [] 10M; [] 15M Other: ~~' ' by order of Approved Commissioner the commission Date ?,. Form 10-401 Rev. 1~5 --'- ~ "' " Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT I-2 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program ae The 13-3/8" conductor will be set at ±80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Bo The 9-5/8" surface casing will be cemented with ±773 sacks of Permafrost "E" cement followed by ±261 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±129 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±333 sacks of Class "G" cement. The secondary cement job will consist of ±355 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program ao 0' - 3250' 9.0 ppg freshwater spud mud. B. 3250' - 5246' 9.2 ppg low solids non-dispersed. C. 5246' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is I-1 with a closure of 60 feet at a depth of 500'. The well will not be completed or tested at this time. ao Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to ±2500' TVD 3250' MD and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to ±4237' TVD to 6158' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3289 4890 "K" Sand 1-1-4 9.2 25 15 35 10 3539 5246 "M" Sand 1-1-4 9.4 25 15 35 10 3755 5528 "N" Sand 1-1-4 9.4 25 12 35 05 3937 5766 "0" Sand 1-1-4 9.4 25 12 35 05 4237 6158 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. NOTES: t STATE PLANE COORDINATES ARE ZONE 4 2, ALL GEODETIC POSITIONS ARE BASED ON N.A.D, 1927 3. OI::I:SET$ TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUE8 O1:: THE SECTION CORNIER POSTION$ 500' i ., ~rGRAVEL ROAD t I -PAD MILN~ POINT UNIT ~3WYDY~ BAY MILNE PT, VICINITY MAP o ~ ~ MILE8 LOC^TION IN ,SEC. 33, T13N, R1OE, UMIAT MERIDIAN WELL I::ROM EAST LINE FROM NORTH LINE 1--1 3696' 29(~1' I-2 $756' 2948' 1'"'8 3816' 2944' I-4 3876' 2941' ,~TATE PLANE COOEDINATE3-ZONE 4 WELL Y X I-1 6,009,444,70' 551,674`68' I---2 6,009,447.40' 561,614.74' 1-3 6,009.460.10' ~8L5~4,81' I-4 6,009,462.80' 55L494JlS' ~.~ ,~ l?o' _,_, lo' _GEODETIC PO$ITIO..NS NAD 1~27 ~',L .' ...... [ 1 ~ I+ I-1 70'2611.67a7' "i49'~4;4~3.270"" ~ I-4 70'25'11.~705' 149' 34'48.551' 'TYPICAL 3ECTIO~No ~CALE ~ "'J .... lmm _ mm -- [_mm m _ ~[ll,, -- . mm1 i ~ - - ~ATE OEO. ",,,, ,,," FIELD sC,~L~ !',20rD' JOB t,;o, 87033 ...... III ' ~ I ...... _ _ m_ _ mm . . T13NRgE CJ~c'~RON O 23 24 ,M~L.-25514 2560 AC T13N RIOE CHEVRON ~ CONOCO ET Al. (~ 6 4 0 · 0 .10 - A.D~-25509 2533 JKC ADL"47434 2560 AC v ( CHEVRON 18 17 16 18 2 11 T 12 ~ ADL-4T433 2 AC 13 30 29 24 2560 AC CHEVRON 26 · 25 T13NR11E ET AL ~) CONOCO 6' 6 ADL-3197 1265 AC CONOCO' ET AL 7 3 AC CONOCO ET q- MILNE POINT UNIT (D Denotee tract numbaro Total Area In Unit 35,744 Ac Mm,, Unit Boundary ADL Lam ~ 10 ADL-47438 2544 CONOCO. 30 29 31 3 03 34 A1~.-25517 ~2 KC~ADL-25~ 2560 AC _2235 AC __ / II,~ I I I IJ CHEY. AnCO BP IOHIO ~DL-25518 II I I III I 6/04 CONOCO ET AL (D_ 21 22 39 ADL-3 J5846 1280 AC .1280 AC · EXHIBIT A MILNE POINT UNIT AREA Bleed on Umlat Meridian,Alaska o 1 MIlle I .... t 5call CONOCO INC,--NABORS RIO 27E 13-5/8" 58888 Fill Line API 13-,5/8' 5M A~ 1~5~8'5M F lo w Llne Annular Preventor Ram R~m Ram A~ ~3-s~ ~ × u' ~ Tubing Spool w/ 2"-5000~t APl 11" 5H Casing Spool w/ 3"-5000~t Tl~e~ded ComecHon 9-5/8" C'hoke Line, 3" 5000~ Manual & 3" HCR VALVE Kill Line, Two 3" 5000~ Manual Valves Side Outlets Side Outlets Surf ace Casing 13-3/8" Conductor Casing BOP GaTe SYSTEM Valve Gale l, BOP STACK S]ZE RATING MEETS APl RP53 & SPEC 8A FOR CLASS 5H 2, BOPE TO BE OPERATED EACH TRlP AND TESTED W'EEKL'f, 3, BOP HYDRAULIC CONTROL SYSTEH TO INCLUDE (5) STAT]ON CONTROL HAN]FOLD LOCATED REI"IOTE WITH 168 GALLON ACCUHULATOR, RESERVOIR UNIT, & AUX]LIAR'f ENERGY SOURCE FOR SYSTEH ACT]VAT]ON, 4, MINIMUM ONE SET BLIND RAMS & TWO SETS APPROPRIATE PIPE RAMS, 5, CHOKE & KILL HANIFOLDS SHOWN SEPARATELY TO HEET API RP 53 CLASS 5H REOUZREHENTS, KILL MANIFOLD FROM REWROTE HIGH PRESSURE PUMP --*" ~OT£: !. N~ULI¢ CONTROL SYSTEI,I FOR 8~ ~C~ ~ CHO~ ~N:FOLD TO ~NCLU~[ (5] STATI~ CONTROL MAN~FO~ L~TED REgOTELT ~JTX ~o PSI ~CCUUULATOR 8 1~0 ~. ~E~E~R 8 ~UX. E~ER~ SOURCE. STA ~NTROL ~A~IF~ PLUS VARIABLE CHOKE ~NT~L TO BE ~CATE0 O~ RIG ELOOR. Z K~L & CNG~ gAN~FOLDS ~ MEET A~ RPS] ~. 5e ~. KILL ~ANIF~D SIZE- RATING ~"- 5000 ~ CHO~E ~ANIFO~ SIZE-RATING 3"-5~0 J FRON M, 2U~P RE.~IOTE PRESSURE [;AGE SENSC~ HYDRt. ULIC CONTROLLED REMOTE OPERATED DRILLING SPOOL REMOTE PRESSURE GAGE SENSOR ADJUSTABLE CHOKE CHOKE ADJUSTABLE I~ANIFOLD CHOKE -- VARIABLE CHOKE CONTROL BLEED LINE TO PIT l TO ATMOSPHERIC MUD/GAS SEPARATOR ---,i. TO SHALE SHAKER CHOKE 8 KILL ~ANtFOLDS FOR 9s/8'~ & 7" OD C'' AS,NG BOP STACK BOP I,IANIFOLD LAYOUT - CONOCO, INC. , C C CONOCO, INC. IdlLN[ POINT UNIT DIVERTER STACK FOR 13 ,318' CONDUCTOR $,t V [ III '$U! _ STARTI~O I~[AD .. ?.. ': ': :. . ; ~ ~ .' 1. The hydraulic control syste~ will be in accordar~ze with API specifications and A{~G43C requiremer~ts. 2. The HCR valve will open when the preventer closes. A single I0" relief line will pun off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the te~ will b~ full opentn~] and linked together to enablQ one to always be open and the. other to be closed. :4 MuD CL£ANER w~,T E.R ~ i i lak,~.t,~ 2 pul,~p 2 . o FLOw SHEET A. XELSEN INDUSTRIES LTD. ~b¥~LU~t'lbl~ I ~bLL WELL NAME: MP.L~-~-2 15--Jan--90 CONDUCTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODUCTION CASING DEPTH (OR TD): 80 3233 0 6110 DEPTH OPERATION: 0 1 RIG MOVE: 0 2 RIG-UP; SET CONDUCTOR: (3,233) 3 DRL/SURVEY SURFACE HOLE: (3,~o~) 4 SURFACE HOLE LOGGING: (3,233) 5 CONDI]'IONING TRIP: (3,233) 6 RU/RUN SURFACE CASING: (3,233) 7 RU/CEMENT SURFACE CASING: (3,233) 8 CHNG BOPs; PU BHA; RIH: (3,333) 9 DRL OUT; TEST; TOOH; RIH: (3,333) 10 DRILL INTERMEDIATE HOLE: CUM HOUR DAYS DAYS 6 0.25 0.25 12 0.50 0.75 57 ~.° 39 3. 14 0 0.00 3.14 o 0.13 o.7 27 10 0 42 ~ . 0.69 6 0.25 3.94 9 0.38 4.33 10 0.41 4.74 0 0.00 4.74 (3,333) 11 LOGGING OPERATIONS: 0 (3,333) 12 CONDITIONING TRIP: 0 (3,333) 13 RU/RUN INTERMEDIATE CASING: 0 (3,333) 14 RU/CEMENT INTERMEDIATE CASING: 0 (3,333) 15 CHNG BOPs; PU BHA; RIH 0 (3~333) 16 DRL OUT; TEST; TOOH; RIH 0 (6,!10) 17 DRILL PRODUCTION HOLE: 64 (6,110) 18 CORING OPERATIONS: 0 (6~i10) 19 LOGGING OPERATIONS (MWD ONLY): 0 (6,110) '~' CONDITIONING TRIP: 10 (6,1i0) ~'i nU/RUN PRODUCTION CASING: 16 (6,110) ==°¢) RU/CEMENT PRODUCi'ION CASING: 6 (6,110) o] ~ RD DRLG RIG 12 (6,110) 24 RU COMPLETION RIG: 1~ (6,110) 25 RD DRLG RIG 12 (6~110) 26 RU COMPLETION RIG: 12 (6,110) 2Z RD DRLG RIG 12 (6~110) 28 RU COMPLETION RIG: 12 (6,110) 29 RD DRLG RIG 12 (6,i10) 30 RU COMPLETION RiG: 12 O. O0 4.74 -' 0. O0 4.74 O. O0 4.74 O. O0 4.74 0. O0 4.74 O. O0 4.74 ~' 66 "~ 7 40 O. O0 7.40 (}. 00 7.40 0.42 7.82 0.65 8.47 0.25 8.73 0.50 9.23 · ..,d, 0.50 ~----) 0..~t 1. O0 0.50 1.50 O. 50 2. O0 0 50 2 0.50 3.50 11:./ CONOCO, Inc. Pad [, Well No, 2 Yll Ins Point Unit, Revleecl Proposal North SI ope, Al asea 0 . RKB ELEYAT[ON~ 3E' KOP TVD=500 TMD=500 DEP=O MAXI MUM ANGLE :~ 62 DEG 40 MI N 1000 _ ~, is ' 21 BUILD 3 DE(3 -27 PER I00 Fl' %'~55~EOB TVD 2197 TlqD 2589 DEP 1033 2OOO ' CSG PT Tva=2500 TlqD=3250 DEP=1620 , ;3000_ BEGIN ANGLE DROP 6°54~ TVD=3070 TMD=4491 DEP=2723 DROP 3 DEG -'48 'Xx K SNDS TVD=3289 TMD=48=90 DEP=30=56 ~i~' 160-~ 4.2 ~ TARGET / I`1 SNDS TVD 3539 TlqD 5246 DEP=3309 TARGET ANGLE 40 DEG 5000., I I I I 0 1000 2000 3000 4000 VERTICAL SECTION HORIZONTAL SCALE 1 IN. PROJECTION -- 1000 FEET z SURFACE LOCAITON~ 2948' FNL. 3756' FEL SEC, 33. T13N. RIOE 2OOO 1000 1000 CONOCO, Inc, Pad I. Well No= 2 Mi lne Poln'l: Unit:. Revised Proposal North Slope. Alaska 1000 0 I WEST-EAST 1000 2000 :3000 I ! I SURFACE ( / H SNDS / TVD-3$39 / THD=5246 ~./ DEP-3309 · NORTH 1268 EAST 3056 TARGET LOCATION, 1680' FNL. 700' FEL SEC, :$3. TI3N. RIOE TD LOCATION, 1436' FNL. 159' FEL SEC, ::$3. T13N. RIOE N 67 DEG 28 MI N E 3309' (TO TARGET) :3950 :3900 :3850 :3800 :37'50 :37'00 ;3650 :3600 :3550 2800 _ 2850 _ 2900 _ 2950 _ ;3000 _ ,7050 _ :3100 _ I ! t / / / / / ~' 1100 / / / / / ? 900 / / )' 7'OO · 500 500 ~700 \ I ! I I I I ~900 \ \ \ ', 1100 \ \ \ \ \ \ ~°"~00 ~'1 / 100 I i I :3950 3900 3850 3800 3750 3700 3650 3600 3550 _ 2800 285O 2900 2950 3000 3050 :3100 CHECK LIST FOR NEW WELL PERMITS ITeM APPROVE DATE ----- (j thru 8) (8) (3) Admin /~'_ 7~F '(f9 thru~'j)" ' (10 and 13) (4) 7--ao- o (14 thru 22) (5) BOPE (23 thru 28) Company Lease & Well No. NO 1. Is the permit fee at:ached .......................................... e 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. Is well td be located in a defined pool ............................. Is well located proper dis:ante from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is we!lbore plat included ................ Is operator the only affected parry ................................. Can permit be approved before fifteen-day wait ...................... YES Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... . Is cdnductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface amd intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is :his well to be kicked off from an existing wellbore ............. __ Is old we!Ibore abandor~ment procedure included on 10-403 ............ Is adequate weilbore separation proposed ............................ "~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate-~Z~f Are necessary diagr~w~ and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~m psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. ~'oo/ thru (6) Add: ,, .. 7-2o-?o Geology: Engineering: DWJ ~ LCS BEW rev: 01/30/89 6.011. Fo r 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented :/ Additional requirements ............................................. ~ Additional Remarks:' INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS A/LEA NO. SHORE /- o.'/ /cf ,, __