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Home My WebLink About199-090MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC L-16A MILNE PT UNIT L-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 L-16A 50-029-22566-01-00 199-090-0 W SPT 4807 1990900 1500 974 982 978 977 181 359 358 354 4YRTST P Kam StJohn 5/23/2024 AOGCC 4 Year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT L-16A Inspection Date: Tubing OA Packer Depth 427 1764 1731 1720IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240524132236 BBL Pumped:1.6 BBL Returned:1.6 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 99 99 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:16:46 -08'00' Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-16A (PTD 199-090) Injection Profile 12/30/2018 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 1990900 E-Set: 34364 Abby Bell 12/09/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-16A (PTD 199-090) Injection Profile 08/26/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 1990900 E-Set: 34363 Abby Bell 12/09/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/17/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU L-16A (PTD 199-090) Injection Profile 08/26/2020 Please include current contact information if different from above. Received by the AOGCC 11/17/2020, re-submittal from 11/13/2020 PTD: 1990900 E-Set: 34250 Abby Bell 11/17/2020 MEMORANDUM TO: Jim Regg*Z10 P.I.--1- - 1)11, ) (01'1( FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 29, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC L -16A MILNE PT UNIT L -1 6A See: Inspector Reviewed By: P.I. Supry '77312 -- Comm Well Name MILNE PT UNIT L -16A API Well Number 50-029-22566-01-00 Inspector Name: Adam Earl Permit Number: 199-090-0 Inspection Date: 5/20/2020 Insp Num: mitAGE200524190406 Rei Insp Num: Packer Well L -16A Type Inj r TVD PTD L 199ogoo Type T� SPT Test psi BBL Pumped: BBL Returned: Interval _ 4YRTST �/F Notes: MIT IA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 4807'ITubinng935 9:7 - 935 934 1500 IA 448 11,82 1656 1648 ' 1.3OA 169 v39 338 - 336 P Friday, May 29, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,May 31,2016 m P.I.Supervisor I\ef ' f i to SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC L-16A FROM: Bob Noble MILNE PT UNIT KR L-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3R2., NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR L-16AAPI Well Number 50-029-22566-01-00 Inspector Name: Bob Noble Permit Number: 199-090-0 Inspection Date: 5/30/2016 Insp Num: mitRCN160530161257 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-16A - Type Ini W'TVD 4807 - Tubing 1300 1300 1300 1300 PTD 1990900 ' Type Test SPT Test psi t 1500 - IA 350 2006 - 1967 - 1956 Interval 4YRTST P/F P ✓ OA 119 349 - 347 - 344 Notes: ---- -_--- - t Tuesday,May 31,2016 Page 1 of 1 RPM -! Regg, 'James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] - 6'4'jt Sent: Sunday, June 03, 2012 8:54 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, OPS M L� OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J Subject: OPERABLE: MPL -16A (PTD #1990900) Passed AOGCC Witnessed MIT -IA Attachments: MIT MPL -16A 6- 3- 12.xls; MIT MPU L -16A 05- 31- 12.xls All, Injector MPL - 16A (PTD #1990900) passed an AOGCC witnessed MIT -IA to 2008 psi on 06/03/2012. The passing test confirms two competent barriers in the well. The well is reclassified 'as Operable. The well may continue on water injection. A copy of the MIT -IA is enclosed for review. «MIT MPL - 16A 6 3 12.xls» F' Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator aai'� JUL 1 2012 Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator aBP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, June 01, 2012 10:08 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike 3; Walker, Greg (D &C); LeBaron, Michael 3 Subject: UNDER EVALUATION: MPL -16A (PTD #1990900) Due for 4 year MIT -IA Compliance Testing All, Injector MPL -16A (PTD #1990900) passed an MIT -IA on 05/31/2012. The passing test confirms two competent barriers in the well. The well is reclassified as Under Evaluation until an AOGCC witnessed test may be performed once the well is thermally stable. The well may resume water injection. Please be aware of the potential on annular fluid expansion once the well begins injection. 1 • • A copy of the MIT -IA is enclosed for review. «MIT MPU L -16A 05- 31- 12.xls» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, March 09, 2012 7:41 AM To: AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Wermager, Chad R; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike 3 Subject: Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) Due for 4 year MIT -IA Compliance Testing and Reclassified as Not Operable All, Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) were due for 4 year compliance testing on 3/7/2012. The wells are currently shut in for rig workovers on MPE -09 and MPL -06 respectfully and are not scheduled to return to injection until approximately May timeframe. The wells have been shut in since January, 2012. The wells have been reclassified as Not Operable until a MIT -IA can be performed prior to resuming injection. Once online, the wells will require an AOGCC witnessed MIT -IA once they are thermally stable. If you have any questions, or require any further information please let me know. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 • 0 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Inte rit Test 9 Y Submit to: jim.reocaalaska.gov; doa .aogcc.prudhoe.bay(Talaska.aov; phoebe.brooksaalaska.gov; tom.maunderaalaska.gov OPERATOR: BP Exploration (Alaska), Inc. 2®,� 1 1 411 v FIELD / UNIT / PAD: Milne Point / MPU / L -Pad ( ! DATE: 05/31/12 OPERATOR REP: Jeff Jones AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPL -16A ` Type Inj. N ' TVD - 4,807 Tubing 1910 1910 1910 1910 - Interval 0 P.T.D. 1990900 ' Type test P " Test psi " 1500 Casing 0 1500 1480 1480 P/F P Notes: Prior to resuming injection startup MIT OA_ 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D._ Type test_ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPU L - 16A 05 - 31 - 12 (2) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recoftalaska.00v; doa.aoacc.prudhoe.bayt alaska.gov; phoebe.brooks(Dalaska.aov; tom.maunderaalaska.aov OPERATOR: BP Exploration (Alaska), Inc. ?_ &'41 / z/ FIELD / UNIT / PAD: Milne Point / MPU / L (( / DATE: 06/03/12 OPERATOR REP: Jeff Jones AOGCC REP: Chuck Sheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPL -16A Type Inj. W TVD - 4,807' Tubing 600 600 600 600 Interval 4 P.T.D. 1990900 - Type test P Test psi . 1500 Casing 396 2050 ' 2017 2008 ' P/F P Notes: 4 year compliance testing OA 47 88 88 88 1.8 bbls pumped to reach pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPL - 16A 6 - - 12 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, March 08, 2012 9:06 PM 5lq /I To: Regg, James B (DOA) �f 1 Cc: AK, D &C Well Integrity Coordinator; AK, OPS MPU Well Ops Coord Subject: Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) Due for 4 year MIT -IA Compliance Testing Shut -In for Adjacent RWOs and Reclassified as Not Operable Jim, Injectors MPE -23 (PTD #1950940) and MPL -16A (PTD #1990900) were due for 4 year compliance testing on 3/7/2012. The wells are currently shut in for ri• workovers on M • -09 and MPL -06 respectfully and are not scheduled to return to injection until approxima e y ay timeframe. The wells have been shut in since January, 2012. The wells have been reclassified as Not Operable until a MIT -IA can be performed. The wells have been added to the Quarterly Not Operable well report. If you have any questions, or require any further information please let me know. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 tit Wes')MAR I a.'Lri- 1 • ~~,~ r~~~~~~~ - , ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 k~~J~- Ui } 8 t RE : Cased Hole/Open Ho{e/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~C 199 _~d 1~-vo ~ t~.C 20'~ - ~~~ c ~on3 ProActive Diagnostic Services, lnc. Attn:. Robert A. Richey. 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907] 245,8952 1) Injection Profile 20Sep-08 MP H-17i 2) Injection Profile 24Sep-08 MP L-16i Signed Print Name: ~.t~-~ ~ ~ I /~ ,~/Wc._ 1 Color Log / EDE 1 Color Log / EOE 50-029-23358-00 50-029-22566-01 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~sd~al7cl~or~~rtca~l~a~rra®ra~log.~~i~ WEBSITE : ww=nr.azae~O~y~d~~saa n~ C:\Documents and Settings\OwneflDesktop\Ttansmit_BP.doc u 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIØJæ{;E' Stimulate 00 0 (9f¡O 2004 W aiver'ÃJa1~~e&~1~[!~~ÇI~H1';;' Re-enter Suspended X'h~íQa~(~ 5. Permit to Drill Number: 199-0900 6. API Number 50-029-22566-01-00 Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development D 45.93 8. Property Designation: ADL-355017 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: MPL-16A 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit Exploratory 0 Service ŒJ Total Depth measured 13435 feet measured 13345 feet true vertical 7391.2 feet Plugs (measured) Junk (measured) None true vertical 7479.7 feet Effective Depth None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# NT80LHE 38 118 38.0 - 118.0 2970 470 Liner 3465 4-1/2" 12.6# L-80 9967 - 13432 4814.2 - 7476.8 8430 7500 Production 10158 7" 26# L-80 33 - 10191 33.0 - 4888.2 7240 5410 Surface 9012 9-5/8" 40# L-80 36 - 9048 36.0 - 4507.1 5750 3090 Perforation depth: Measured depth: 13045 -13115,13140 -13180,13193 -13243 True vertical depth: 7096.98 - 7165.58, 7190.07 - 7229.26, 7242 - 7291.03 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 31 9973 Packers & SSSV (type & measured depth): 3-1/2" Baker S-3 Packer 5" Baker ZXP Liner Top Packer 5" Baker ZXP Liner Top Packer @ 9943 @ 9967 @ 10009 SCANNED NO\! t} S 2004 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13160 -13243 Treatment descriptions including volumes used and final pressure: 10 Bbls 7.5% DAD Acid @ 2965 psig. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 ~~ 0 0 -2934 0 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 Tubing Pressure 2729 2268 Copies of Logs and Surveys run- Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: Signature Garry Catron Garry Catron ):1Y'~ WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-308 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 10/18/04 ,r-,~\' 1\\ 0 B " \,~, \, \ 1--\ L R8DMS BfL. OCT 2 7 2DO¡~ Form 10-404 Revised 4/2004 t 'f" ) ) MPL-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10102/04 CTU #5, FCOI ACID TREAT; WAIT ON REMAINING TANKS TO BE SET. PERFORM WEEKLY BOP TEST. RIH WITH 2.2511 JSN. JET FILL FROM 13030' MD TO 13328' CTMD. CHASE FILL TO SURFACE @ 800/0 WHILE JETTING TBG. RIH AND JET 10 BBLS 7.5% DAD ACID ACROSS PERFS FROM 13160' TO 13243' CTMD (A1 & A2 SANDS) WI WELL ON INJECTION @ 1000 BWPD AS DIVERSION FROM A3 SANDS. RDMO. WELL LEFT INJECTING @ APPROXIMATELY 1000 BWPD. FREEZE PROTECTED WELL MPL-41 FLOWLINE WI 3 BBLS 60/40 MEOH. PAD OPERATOR NOTIFIED OF CONDITION. «<JOB COMPLETE»> FLUIDS PUMPED BBLS 49 374 40 243 10 716 60/40 Methonal XS 2% KCL FloPro XS 2% KCL wi 2% Lubetex 7.5% DAD Acid TOTAL Page 1 r', ~ Æ ð7-:S¿. <i:J h J &:'/Q/~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Stratigraphic D Service Œ] 9. Well Name and Number: MPL-16A 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13345 1345.3 MD TVD 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 0 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 45.93 KB 8. Property Designation: ADL-355011 11. Total Depth MD (ft): 13435 Casing Total Depth TVD (ft): 1419.1 Length Size Conductor 80 Liner 3465 Production 10158 Surface 9012 Perforation Depth MD (ft): 13045 - 13115 13140 - 13180 13193 - 13243 Packers and SSSV Type: 3-1/2" Baker S-3 Packer 5" Baker ZXP Liner Top Packer 5" Baker ZXP Liner Top Packer 12. Attachments: Description Summary of Proposal 0 20" 91.5# NT80LHE 4-112" 12.6# L-80 1" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 1096.98 1165.6 1190.01 1229.3 1242 1291.0 Detailed Operations Program ŒI BOP Sketch 0 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: August 19,2004 Date: Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverD StimulateŒ Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 199-0900 Annular DisposalD OtherD Development D Exploratory D 6. API Number 50-029-22566-01-00 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 38 118 38.0 118.0 2910 9961 13432 4814.2 1416.8 8430 33 10191 33.0 4888.2 1240 36 9048 36.0 4501.1 5150 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 " 9.3 # L-80 31 Packers and SSSV MD (ft): 410 1500 5410 3090 9913 IVEO 9943 9961 10009 13. Well Class after proposed work: AI '. .. . ?:'I14 ,'vaslca 0t1 & ~, ExploratoryD DevelopmentD ÂÍJ~lfèi(! CommÍ88ion 15. Well Status after proposed work: Oil D GasO WAG [!] GINJD PluggedO AbandonedO WINJ D WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature ~ ðJÍ~ Contact Danielle Ohms Title Phone Petroleum Engineer 564-5159 8/5/04 ommlsslon Use Onl Plug Integrity 0 Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test D Location Clearance 0 BOP Test~ ",\ ~ ~ "" ~ () ~ -\<::: ~ -\- 0 \....\ Other: Approved b Form 10-403 Revised 06/2004 BY ORDER OF THE COMMISSION v ORIGINAL :RBDMS BFl AU6'1112IM SUBMIT IN DUPLICATE r---. ~ To: Jerry Bixby/Clint Spence Wells Ops Supervisor Date: July 20, 2004 From: Oanielle Ohms (x5759) lOR: 200 bopd Subject: MPL-16Ai FCO COST CODE: MKWELL16 ESTIMATED COST: $40,000 11 Ic I Wash tbg/ FCO/Perf Acid Wash OBJECTIVES MPL-16Ai needs a FCO to improve injection into the A2 and Al Sands which contain - 50% of the OOIP for this block. The bottom perf is at 13243' MD and ideally the FCO should cleanout to max TD initially reached at 13337' MD, leaving 94' rathole. After the cleanout is complete, jet 10 bbls of 7.5% DAD acid across the Al and A2 Sand perfs only 03160'-13180' MD and 13193-13243 MD') while squeezing away. Try to avoid stimulating the A3 sand 03140' -13160' MD) with acid, as it already takes more injection than desired. BACKGROUND Injector L-16Ai has fill covering the Al and A2 Sands which needs to be cleaned out. A tag on 12/30/03 indicated fill at 13183' MD, indicating the A2 perfs were open. An IPROF performed on 1/12/04 indicated that fill was at 13155', however, thus both the A2 and Al were covered. The A2 sand contains 43% of the OOIP in HU 230, so it is critical to be able to inject sufficient water into this zone to maximize recovery. The 1/12/04 IPROF indicated only 9% injection going below the A3 Sand (assumed into the A2). The Al and A2 Sands combined contain 50% of the OOIP for this HD. The initial FCO on 1/12/00 indicated some tight spots 00800' ctmd) and friction (9900' ctmd). A CTCO to 13337' ctmd was performed. It also noted "evidence of perf mud which had the consistency of cut up silicone". To help improve injectivity into the A2 and Al sands relative to the A3 Sand, a selective perf wash is also requested. A SPFO obtained on 4/8/04 indicated the reservoir pressure at L-16A to be 3686 psi at 7000' TVDss datum. This cleanout will prep the well for an IPROF as well as improve injectivity into the A2 and Al Sands. Getting this IPROF is needed to meet MPU's state reporting requirements for 2004, in addition to the value of the surveillance data. A separate request will be sent out for the IPROF. "..-... ~ Note: *The tbg size is 3-112" and the production liner is 4.5". *Min ID = 2.75" @ 9958'MD (XN Nipple) *Max angle 72.3 deg @ 9600' MD *Max DLS 10.74 deg at 10252' MD (doglegs 3.4 - 10.7 deg from 11300' - 10250' MD) SCOPE 1. RU CT. 2. Jet possible schmoo build-up off tbg. 3. FCO to -13335' MD or deeper. 4. After ensuring fill returns have been sufficiently circulated out, jet 10 bbls of 7.5% DAD acid across Al and A2 Sand perforations only and squeeze away (avoid getting acid above 13160' MD, as much as possible, to keep out of the A3 Sands; increased injectivity there is not necessary). 5. POOH while taking returns to surface (ensure some loss). 6. RD CT. 7. Immediately return well to injection at an initial target rate of 3000 bwpd. r---. ~ Wellhead: FMC Gen 5 w/ 11" 5 M thru bore system. ~ 11" x 3.5" NSCT hng. w/ 3" CIW - H BPVT ~ 11" x 31/8" ESP adapter (dummied off ) and 3 1/8" 5M valves / cross / cap ~31/8" 133/8",48 ppl K-55 Btrc. I 110' MP. Orig. KB elev. = 51.72' (Nabors 27E) Orig. OF elev. = 50.22' (Nabors 27E ) GL. elev. =16.6' HES X-Nipple 2.813" pkg. bore ~ KOP = 400' Max. hole angle = 67-72 deg. from 2876' to 10,200' MO Hole angle acrdss perfs. = 11 deg. 9-5/8" 40 ppl L-80 BTC 19048' Mol 7" 26 ppl, L-80, Btrc. prod. casing (drift 10 = 6.151", cap. = 0.0383 bpI) 2" 2" 2:' 3.5" 9.3 ppl, L-80 NSCT tubing (cap. = 0.0087 bpI, drift = 2.867") HES X-Nipple 2.813" pkg. bore I 9,899' I I 9,943' I 7"x 3.5" Baker S-3 Pkr. 7"x5" SLZXP Pkr & tie back slv.19:967l ~ CPH Pkr. 110,034' 1 HES XN-Nipple 2.813" pkg. bore (2.75" id no-go) 4.5" WLEG 4.5" ELMO 5"x7" ZxP Pkr. tie back slv. 5"x7" HMC Hanger 4.437"id I 9,958' I 7",26 ppl, L-80 btrc. production casing 110,191' I 9,973' 9,973' 10,009' 10,023' I Window cut 10,191'-10,242' I 4.5" 12.6# L-80 IBTM (3.958" id .0152 bpI) Marker joints 2 - 20' joints 112,892'-12,932' I PERFORATION SUMMARY ReI. Log: CBL 01/16/00 Gun PF Interval (TVO) 4 4 4 3,045-13,115' 7097'-7,166' 3.140'-13,180' 7190'-7,230' 3.193'-13,243' 7242' - 7,291' . EZSV Plug 10,450' L-\<o ~~ ~ PBTO I 1- Casing shoe REV. BY MILNE POINT UNIT WELL L-16i API NO: 50-029-22566 6/17/95 11/24/95 12/05/99 7" Casing Run Initial Completion by Nabors 4 ES Sidetrack & compo Nordic#3 & 4 ES OBR/DMR JBF MOO BP EXPLORATION (AK) L-\(P ~\ L-\ <o~\ 50 -() ~. ddSCcto"'öl - VIC File Review Date: March 12, 2004 Subject: BPXA MPU Well L-16A PTD#: 199-090 Sundry: NA Orders: eo 432 B (consolidated orders) AIO lOB and prior versions Reviewers: Tom Maunder, P.E. A~~~ Initiating Action: Successful MIT, however packer set shallow Review Summary 1. This sidetrack was drilled in October 1999. 2. It appears that all drilling operations went well and a 4-1/2" liner was run and successfully cemented. The liner was hung at 10009' md (4830' tvd) with the shoe at 13345' md (7391' tvd). 3. According to the well file, the liner thread was "IBT modified". 4. The attempts to pressure test the liner and.casing was not successful. Diagnostic tests concluded that there was a leak in the liner hanger assembly. 5. BP proposed to restore integrity by setting a 3-1/2" straddle across the liner hanger. Sundry 399- 242 was issued for this work December 3, 1999. 6. During completion operations, a cement bond log was run. The report comment is, "Good cement from PBTD to approximately 11930'. Clear pipe at 11900'. 7. The bond log is not available in the well files. According to the spreadsheet, the theoretical TOe allowing 30% XS would be about 11840'. This is in good agreement with the report statement. 8. The rig performed a MIT during the completion. The annulus was tested to 4500 psi and is reported to have passed. The test was not witnessed. 9. The 407 was filed January 26, 2000. 10. According to the RBDMS injection report, the well has been almost entirely in water injection service since completed, although there has been some MI injection. 11. On March 9, 2004 BP performed a standard MIT on the well. At least to the packer at 9943' md, the wellbore successfully passed the MIT. 12. The liner string does not include any deep nipple to allow testing of the liner above the perforations. Review Conclusions: 1. A significant portion of the wellbore cannot be evaluated performing a standard MIT. 2. Approximately 3300' of 4-1/2" liner exists below the production packer. 3. Similarly equipped wells have been limited to water only and a non-standard MIT has been required in order to demonstrate the integrity of the liner below the packer. 4. These MITs have usually been required more frequently than the normal 4 years. G:\common\UIC File Reviews\2004-0312-MPU _L-16A-file-review.doc ÞCANNED MAR 1 5 2004. Recommendation 1. BP should be notified of our findings with regard to the construction of this well and that that based on the construction of the well, this well is limited to WATER INJECTION ONLY. 2. BP should make arrangements to pressure test the tubing/liner in the well. G:\common\UIC File Reviews\2004-0312-MPU L-16A-file-review.doc Summary by Month: Individual Well Injection / Disposal Well Name: MILNE PT UNIT KR L-16A API: 50-029-22566-01-00 Permit to Drill: 1990900 Operator: BP EXPLORA nON (ALASKA) INC Field/Pool: MILNE POINT, KUPARUK RIVER OIL Sales Cd: 55 Acct Grp: 112 Final Status: W AGIN Current Status: W AGIN 1999 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Wtr Inj Days I Wtr 4 Gas 0 1999 Totals: Water 4 Gas 0 Cum Wtr 4 Cum Gas 0 2000 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Gas Inj Wtr Inj Wtr Inj Wtr Inj Wtr Inj Wtr Inj Wtr Inj Wtr Inj Gas Inj Wtr Inj Wtr Inj Wtr Inj Days 3 29 31 30 31 8 31 31 4 31 30 31 Wtr 50,445 87,498 125,366 156,937 153,812 24,658 115,223 130,868 107,692 103,102 92,426 111,003 Gas 247 0 0 0 0 0 0 0 3,819 0 0 0 2000 Totals: Water 1,259,030 Gas 4,066 Cum Wtr 1,259,034 Cum Gas 4,066 2001 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Wtr Inj Wtr Inj Wtr Ioj Gas Ioj Gas Ioj Gas Ioj Wtr Ioj Gas Inj Wtr Ioj Gas Inj WAG Wtr Inj Days 31 28 31 4 3 3 31 8 29 29 29 31 Wtr 153,103 117,023 144,034 137,396 91,714 112,289 118,393 82,942 119,551 0 114,905 142,008 Gas 0 0 0 2,684 2,648 1,105 0 9,131 6,470 102,777 672 0 2001 Totals: Water 1,333,358 Gas 125,487 Cum Wtr 2,592,392 Cum Gas 129,553 2002 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG Days 31 28 31 30 28 30 31 31 30 31 30 31 Wtr 120,737 67,247 112,627 102,537 106,809 127,540 126,204 108,572 124,179 124,189 121,238 120,907 Gas 0 0 0 0 0 0 0 0 0 0 0 0 2002 Totals: Water 1,362,786 Gas 0 Cum Wtr 3,955,178 Cum Gas 129,553 2003 Jan Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG WAG Days 31 28 31 30 31 30 31 31 30 31 30 31 Wtr 101,312 115,591 133,749 124,806 136,101 115,160 110,258 127,113 118,320 118,694 115,981 101,042 Gas 0 0 0 0 0 0 0 0 0 0 0 0 2003 Totals: Water 1,418,127 Gas 0 Cum Wtr 5,373,305 Cum Gas 129,553 Friday, March 12,2004 Page 1 Summary by Month: Individual Well Injection / Disposal Well Name: MILNE PT UNIT KR L-16A API: 50-029-22566-01-00 Permit to Drill: 1990900 Operator: BP EXPLORATION (ALASKA) INC Field/Pool: MILNE POINT, KUPARUK RIVER OIL Sales Cd: 55 Acct Grp: 112 Final Status: WAGIN Current Status: WAGIN 2004 Jan Wtr Ioj 31 76,250 0 Feb Mar Apr May Jun Jut Aug Sep Oct Nov Dee Meth Days Wtr Gas 2004 Totals: Water 76,250 Gas 0 Cum Wtr 5,449,555 Cum Gas 129,553 Friday, March 12,2004 Page 2 (' ( MEMORANDUM State of Alaska TO: Randy Ruedrich Commissioner Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor 'Rèt[q 3/1; 104- DATE: Wednesday, March lO, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-16A MILNE PT UNIT KR L- I 6A FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-22566-01-00 Insp N mitCS040309205053 Inspection Date: 3/9/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: L-16A Type Inj. P TVD 4827 IA 0 2000 2000 2000 ---- P.T. 1990900 TypeTest SPT Test psi ]206.75 OA ]00 360 360 360 Interval Four Year Cycle P/F Pass Tubing 2400 2400 2400 2400 Notes: The packer in this well is set 3102' above the perferations. Pretest pressures were observed and found stable. ~~òk 3) J~ 104-- - / ( < C \.. r, \ '. ('0' ~!"v() ¿;k,Ô jì e. \ e.,.}¡ e (,,0 5t~LI04 (I\;~t~l r'\0Let-) 'J ¡e,v é~,~ l,:~ ¡\...'\¿ç;( re; k. . 'ì . 5;;;:\ ~'11 Type INJ. Fluid Codes F =FRESH WATER IN]. G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=lntemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle, V=Required by Variance W=Test during Workover O=Other (describe in notes) Wednesday, March 10, 2004 Page 1 of 1 S(C/A¡~W~tl.:J) MA~~ 1 7 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / L-pad 03/09/04 Lee Hulme Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test P Ilf.Jær - fßVlJ - I~ 345 J jvt[) (~e S"C.~~¿) ,,\Jb.:;d;¡ ;,.\' ';..::":'..Å)I ;)':{)"':": 1,-. ~' "~.",,.~~..!:'A'~';'l:AJ~ I. ,1.--',., ":.,1,,,0;..,/:.., ~.. J¡'A~. ,..'.',:1:\' - .,~t:,,':4'i'r£.''..{~~I\:lí~~'' .lM '., '1&::)CI Uj ,~' ..i ...'.'.'.'..,;~.2hn." :~lfš:~. o/r4'3 ; ¡\it [j MIT Report Form Revised: 06/19/02 MIT MPU L 3-9-04.xls 95/8", 40#/ft, L.80 BTC. I 9,048' I 7",2:;:¡;&ì\a¡ ( :;;'" ..~ ~ Top of Section Milled Window 110,191'1 Wellhead: 11" 5M FMC Gen. 5 wI 11" x 3.5" NSCT Tbg. Hng. , 3.5" NSCT threads top and bottom, 3" CIW "H" SPV profile 20" Conductor I 00 3 1/2", 9.3# , L-80, NSCT ~In ~tfll"; I DIRECTIONAL PLAN (PROPOSED PLAN 5A) KOP @ 10,195' Max. hole angle = 700 at KO Window ~\ \1;\ ßk' !JJ.t-- ?e.rfs ( per ID-4o+) : \''3ó4G .. 1:3015' Y\,b \~S-...I~d15"' )l;lD \"3cflS" - 11 II ç \ ~J) 1314D- t ~IW 1 MJ) \;lhD-- ,1, tq.)o ' ,u..ð 13 \tt3- 1-:?2.:Z..3' ¡11b l '3lz..3 13z4-3 I f'\) DATE REV. BY 11/2/99 MTT MPL.16Ai ACTUAL SUSPENSION Cellar Box Elevation: 16.6' Rig RKB Elevation: 30.00' ~è:J;-.<?S: q '1 4~ ¡ A/1 b «çöò->ð<>" ( 41:,01 '-nIb) 5B~ 711.../04- . 110,009'1 7" x 5" Baker ZXP Liner Hanger Pkr Halliburton EZSV 41/2 ", 12.6#/ft, L.80 IBT-Mud BOT 7" SAB.3 Packer WLEG . PBTD ~. HOLE ANGLE at TO: 8.50 PBTD TD , \~e ?(,ziat- ,vb 73>ql L COMMENTS ~ ~ . 9.22 Actual Sus ension RÞ i:YÞI no A Tln"ll ^ It\ (( \~q ~O<=tÒ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jeni Thompson BP Exploration(Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. O. Box 1369 900 East Benson Blvd. Stafford, TX 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 Res. Eva!. CH 1 1 1 MP L-16Ai 1-12-04 Mech. CH J ~ ,~CX (/? Caliper Survey Signed: ~é'\\ :. ~ '.0 0'0 J-.. "'~ Date: RECEIVED . !^ ~.! 2 q ')00 1 Print Name: vi ~! 8 ~ t.. 4- Alaska Oil & Gas Cons.Co~ Anchorage PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail;, pds@memorylog.com Website: www.memorylog.com ~(;Á\NfNE~) FEB 0 2; 2004 ~~~\\\~ ( (J 99-Cf7g) WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage. Alaska 99501 RE : Distribution - Final Print( s J The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration(Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. O. Box 1389 900 East Benson Blvd. Stafford, 1>< 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 MP L-16Ai 1-12-04 Res. Eva!. CH ¡ 0'\ 1 1 1 In ~xJ /J ,,'-" --- - Mech. CH 1 Caliper Survey Signed: ~ \ ~ ~ <.90:,. ~~ ~ Date:-RECEl\lED Print Name: J /\t.l 2 9 2Q04 Alaska Oil & Gas Cons. Comm.an Anchorage PRoAcTivE DiAGNOSTic SERviCES, INC., PO Box 1 ~b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~\~\~\~ DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990900 Well Name/No. MILNE PT UNIT KR L-16A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22566-01-00 MD 13435 TVD 7480 Completion Date 1/16/2000 Completion Status WAGIN Current Status WAGIN UIC Y .~-~-~ £- ~_' ~ 71_ -- -_~--'_~.._-' ~----£ZZ~7_L 72~7~- ............... '2_--'£ ~ _~ '_ _~Z-~.Z£~ ~ '.X~_-- _- '~ '. '-..~_' - .. ~.'-- _.--~ ~ ............. . .................... ~ ~_~ ~Z--' . ~-~'~'~ /-- -..~_~ ~-.' .- REQUIRED INFORMATION Mud Log No Samples No Directional Survey No __ -- __ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log ype Media Format Name Scale ........................... '?i-'L "SCM¥ ................ 5 ' rjr"" DGR/EWR-MD 25 ~/DGR/EWR-'I'VD 25 Log Media . (data taken from Logs Portion of Master Well Data Maint) Run No FINAL FINAL FINAL Interval OH / Dataset Start Stop CH Received Number Comments 9850 13330 CH 2/4/2000 BL(C) UIC 10191 13435 OH 3/712000 4889 7448 OH 31712000 6~''''' 10/25/2000 09820 ...... 12950-13300 D ~SRVY RPT D ~//iNJP FINAL 12950 13300 CH 83 13435 OH 1/26/2000 SPERRY 10096..UIC 10/25/2000 U lC 2/15/2000 09432~ 9776-13340 3/9/2000 09513 ~"-" 10165-13397 Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Q~ ca~s- . ~ Daily History Received? ~ N Formation Tops Receuived? ~/N Comments: Permit to Drill No. 1990900 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. MILNE PT UNIT KR L-16A Operator BP EXPLORATION (ALASKA) INC MD 13435 TVD 7480 ~Completion Date 1/16/2000 Compliance Reviewed By: ..................................... ~ Completion Status WAGIN Current Status Date: AP1 No. 50-029-22566-01-00 WAGIN UIC Y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_ X WAG SWAP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 46 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Miline Point Unit 4. Location of well at surface 1675' FNL, 130' FWL, Sec. 08, T13N, R10E, UM (asp's 544729, 6031793) MPL-16A At top of productive interval 9. Permit number / approval number 381' FSL, 410' FWL, Sec. 33, T14N, R10E, UM (asp's 550218, 6039165) 199-090 At effective depth 10. APl number 429' FSL, 377' FWL, Sec. 33, T14N, R10E, UM (asp's 550184, 6039213) 50-029-22566-01 At total depth 11. Field / Pool 442' FSL, 368' FWL, Sec. 33, T14N, R10E, UM (asp's 550175, 6039225) Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 13432 feet Plugs (measured) true vertical 7477 feet Effective depth: measured 13345 feet Junk (measured) true vertical 7391 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 250 sx Arcticset (approx) 146' 146' Surface 9012' 9-5/8" 1740 sx PF 'E', 250 sx 9048' 4510' 'G', 132 sx PF 'E' Intermediate 10155' 7" 275 sx Class 'G' 10191' 4888' SideTrack Liner 13396' 4-1/2" 196 c.f. Class 'G' 10009' - 13432' 4828' - 7477' .,:' . .-4 ~,~ ~ ~, -,~ ....... Perforation depth: measured Open Perfs 13045'- 13115', 13140'- 13180', 13193'- 13243' '-~" ..... ¢ true vertical Open Perfs 7097'- 7166', 7190'- 7230', 7242'- 7291' Tubing (size, grade, and measured depth) 3-1/2" 9.3 ppf, L-80 TBG to 9943' MD. 3-1/2" Tailpipe to 9973'. Ar~choragr~ Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 PKR @ 9943'; 7" x 5" SLZXP PKR & Tie Back SLV @ 9967'. 5" x 7" ZXP PKR Tie Back SLV @ 10009'; HES 'X' Nipple @ 2210'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 09/28/2001 3548 2789 Subsequent to operation 10/01/2001 4193 4601 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WAG INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~,~~~ Title; Technical Assistant Date October 12, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~~ MPL-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/29/2001 WAG SWAP --- WATER TO GAS. EVENT SUMMARY 09/29/01 SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUED TO SPEC. HB&R PUMPED 20 BBLS METHANOL DOWN THE TUBING. FLUIDS PUMPED BBLS DISCRIPTION 20 METHANOL WATER 20 TOTAL Page 1 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC /~:~~ ~e~ p,Co{)~,'("' ~'~ '~-~ 'g~,VL'"" J~a / 3001 Porcupine St. I% Anchorage, Alaska 99501 bO(~S ~%~-¢.~), 0 5 ~t)~ I~ ~ I~ ~, RE' Distribution- Final Print(s) ~~ ~~ ~t t~ ~& ~ -~~~ ~ The technical da~ listed below is being submi~ed he.with. Please acknowledge receip~y returning a signed copy of this transmi~l le~r to the a~ntion of · Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration[Alaska), Inc. Petro-Technical Data Center MB 3-3 900 East Benson Blvd. Anchorage, Alaska 99508 ,i Los ]J DISlTAL MYLAR / BLUE LINE REPORT WELL J DATE TYPE j OR SEPIA PRINT[S) OR i CD-ROIV! F~LM BLUEL~NE Open Hole 1 1 1 Res. Eval. CH ! 1 I 1 L-16i' j 10-02-00 Mech. CH j t Caliper Survey I I Rpt or J '?d ~,--.-~ ~\~i~ I BL/ I Y Signed ~ Date ,.~.,,~ ! ~ ~'~' ~'~" Print Name: '~_~(~ OiJ & 6~8 CO~S. GOf~B$~o~ ~chorage ProActive Diagnostic Services, Phone:(907) 245-8951 Fax:(907) 245-8952 Inc., 310 K Street Suite 200, ~nchorage, AK 99501 E-mail: pdsanchorage{~memol!,log.com ~Vebsite: ,.' .' '... ~, .-~..:~, ~ _,. ProActive Diagnostic Services, Inc. Pl/,--_L To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration(Alaska), Inc. Petro-Technical Data Center MB 3-3 900 East Benson Blvd. Anchorage, Alaska 99508 ~1 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL 1 DATE TYPE OR SEPIA PRINT(S) OR ~1 CD-ROM FILM BLUELINE Open Hole 1 I 1 l~q. off o ~x-q%'2.o 1,6-~ ¢> L-J fii : 10-02-00 Res. Eval. CH I I 1 I Mech. CH I Signed' Print Name: ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245,8952 E-maih txtsanchorage(~memo .ry. log. com Website: '::. ,... v._. :: ~.:.;':.~=_-..:,'5. To.' WEI J~ LOG TRANSI~HTTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs MPL- 16A, AK-MM-90168 1 LDWG formatted Disc with verification listing. AP!#: 50-029-22566-01 March 9, 2000 P .LE_.4~.qE ACICNOWLEDGE I~CEIPT BY SIG.NKN. G A COPY OF THE. TR.CNS~TTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: MAR 0 9 g_O00 Alaska Oil & Gas Cons. uorumiss~or~ Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed: 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907~273-3535 A Halliburton Company To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Con'an. AttrL' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 I qq.oqO MWD Formation Evaluation Logs - MPL-16A, AK-MM-90168 March 07,2000 MPL-16A: '~" -~ 5" MD Resisti'~dty and ~ ....P~y L ~ ~ ~ .... . ogs: 50~29-22566-01 2"x 5" TVD Resistivity. and Garrana Ray Logs: 50-029-22566-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLE3~SE ACKNOWLEI)GE RECE~ BY SIGNLNG .~ND RETURNING THE ATTACHED COPIES OF Tm~. _TR.a~NS.MITT.ad~. LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: ~ 0 7 9~000 Sign ~aska 0il & Gas Cons. Commissian Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 121155 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date BL Sepia CD MPJ-15 U lC..- 20015 PDC GR '~lE '~-'~/ct~:~'~.~'~ 991119 1 MPL-16A ~ 20055 PDC OR ~ 000116 1 , ~,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 2/3/00 BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED FEB 15 N~ 011 & Gas Cmos. Commission Anchoraoe Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, A~C~ 7'~/ l ~26~OO GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 121128 'Company Alaska Oil & Gas Cons Camm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Color Well Job # Log Description Date BL Sepia Print MPL-16A L,~.,C._. 20052 SCMT 000116 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: FEB 04 _000 !~,lask:~ [')il & !.b::s Co:';',;. Co:nmissior~ Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Receivd~ r - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil 1--1Gas [] Suspended []Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-090 399-22o/399-242 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22566-01 4. Location of well at surface i ":: ' i ' .' .' . 9. Unit or Lease Name 3604' NSL, 5148' WEL, SEC. 8, T13N, R10E, UM ~ // ..~ ,.~! ~~ Milne Point Unit At t,o,p of produ_c?e interval !i .y/'~'//._~..._,.,. i~-~- -~1 ~ 10. Well Number 397 NSL, 375 EWL, SEC. 33, T14N, R10E, UM .,~;!?.'; . MPL-16Ai At total depth i. ~../'f'C., . .~ ~ ~t:~'l~'~;;;~''~iI,~~ 11. Field and Pool 444' NSL, 342' EWL, SEC. 33, T14N, R10E, UM ,5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and ' ' Milne Point Unit / Kuparuk River KBE = 45.93' ADL 355017 Sands 12. Date Spudded10/22/99 113' Date T'D' Roached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°r° 16' N°' °f C°mpleti°nsl 0/25/99 01/16/00 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey ]20. Depth where SSSV set 121. Thickness of Permafrost 13435 7480 FT] 13345 7392 FTI [~Yes []No! (Nipple) 2210' MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, CCL, GR, CBT, Spinner 23. CASING~ LINER AND CEMENTING RECORD CASING SE'I-FING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SiZE CEMENTING RECORD AMO[~N~PHI~LED 20" 91# NT80LHE 38' 80' 30" 250 sxArcticset I (Approx.) 9-5/8" 40# L-80 36' 9048' 12-1/4" 1740 sx PF 'E', 250 sx 'G', 132 sx PF 'E' 7" 26# L-80 33' 10191' 8-1/2" 275 sx Class 'G' 7,, x 5,, 9967, 10009' Liner Tieback Assembly ' ~i~..-~'~ 4-1/2" 12.6# L-80 10009' 13432' 6-1/8" 170 sx Class 'G' /;j~; ;;~ 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 3-1/2", 9.2#, L-80 9973' 9943' MD TVD MD TVD 13045' - 13075' 7097' - 7127' 13075' - 13095' 7127'- 7146' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 13095' - 13115' 7146'- 7166' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13140'- 13160' 7191'- 7210' Freeze Protect with 80 Bbls of Diesel 13160'- 13180' 7210' - 7230' 13193' - 13223' 7242' - 7272' 13223' - 13243' 7272' - 7292' 27. PRODUCTION TEST ¢ r~ i f',~_.' ! ~' I ./~ Date First Production ]Method of Operation (Flowing, gas lift, etc.) i-:. i ~'-?: ! ~ ! ~/..~ January 19, 2000~ Water & Gas Injector ...... : ~ Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .; Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Kuparuk 'D' 12910' 6965' LCU 13042' 7094' Kuparuk 'A' 13134' 7184' Kuparuk 'A3' 13140' 7190' Kuparuk 'A2' 13160' 7210' Kuparuk 'Al' 13190' 7239' Miluveach 13243' 7291' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge M PL-16Al 199-090 399-220 / 399-242 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 17 Oct 99 18 Oct 99 M Pt L Pad Progress Report Well MPL- 16A Page 1 Rig Nordic3 Date 30 November 99 00:00-06:00 00:00-06:00 06:00 06:00-10:00 06:00-08:00 08:00 08:00-10:00 10:00 10:00-17:30 10:00-17:30 17:30 17:30-18:00 17:30-18:00 18:00 18:00-00:00 18:00-00:00 00:00 00:00-02:00 00:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00 06:00-12:00 06:00-12:00 12:00 12:00-06:00 12:00-19:00 19:00 19:00-06:00 Duration 6hr 6hr 4hr 2hr 2 hr 7-1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 6hr 6hr 2 hr 2hr 4hr 4hr 6hr 6hr 18hr 7hr llhr Activity Move rig Rig moved 100.00 % Finish moving rig from ARCO Kuparuk 1 D-Pad to Milne Point L-16A. Spot misc Service Company equipment. Accept rig at 0001 hrs 10/17/99. At well location - Cellar Suspend operations Held safety meeting Shut rig down as directed to prepare for Milne Point orientation. Completed operations Held safety meeting Both rig crews attend Milne Point orientation. Completed operations Move rig Rig moved 100.00 % Spot Baroid, Sperry equipment. R/U lines to circ out freeze protect diesel. Modify cuttings box chute. Finish misc berming. At well location - Cellar Wellhead work Removed Hanger plug R/U lubricator and pull BPV. Equipment work completed Fluid system Circulated at 2388.0 ft Test lines with air. Attempt to circ out freeze protect diesel. Unable to circ. R/U HB&R and pump 25 bbls methanol and thaw out. Circ out diesel with rig pump. Broke circulation Wellhead work Rigged up Xmas tree Set TWC and test to 1000 psi. N/D tree. Equipment work completed Nipple up BOP stack Rigged up BOP stack N/U BOPS and associated lines, bell nipple,and flowline. Equipment work completed Nipple up BOP stack (cont...) Tested BOP stack M/U test joint and test equipment and attempt to start testing BOPS. Getting fluid out of annulus. Change TWC and test from btm OK. Leak from top. Perform preliminary test on choke manifold while lcoating 3 1/2" test jt with donut. Began precautionary measures Suspend operations Held safety meeting Rig crews released for SDD/Nordic training at Milne Point base camp. Completed operations Rig waited · Other delays IM[ 3IllAt LIkJWll lUX Ill[IlL IJ.i~, k.llI ~.bt~4..l. Facility M Pt L Pad Progress Report Well MPL- 16A Page Rig Nordic3 Date Date/Time 19 Oct 99 06:00 06:00-07:00 06:00-07:00 07:00 07:00-10:30 07:00-10:30 10:30 10:30-15:00 10:30-15:00 15:00 15:00-19:30 15:00-19:30 19:30 19:30-21:30 19:30-21:30 21:30 21:30-00:00 21:30-00:00 20 Oct 99 00:00 00:00-05:00 00:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-10:00 06:00-09:00 Duration lhr lhr 3-1/2 hr 3-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 2hr 2hr 2-1/2 hr 2-1/2 hr 5hr 5hr lhr lhr 4hr 3hr Activity 2 30 November 99 Began precautionary measures Suspend operations (cont...) Held safety meeting Rig crews attend MPL-16Ai pre-spud at Milne Point base camp. Completed operations Test well control equipment Tested BOP stack Tempoary test on blinds against the casing to 1000 psi. M/U test joint and test upper rams to 250-3500 psi and Hydril to 250-250 psi. Tests OK. L/D landing joint. These tests were erformed to be able to pull hanger and tubing. AOGCC to witness later. Pressure test completed successfully - 3500.000 psi Pull Tubing, 3-1/2in O.D. Laid down 2358.0 ft of Tubing Pull hanger and L/D 75 jts 3 1/2" 9.3# tubing. NORM same. Completed operations Test well control equipment Tested BOP stack R/U test equipment. Test hydril 250-2500 psi. OK. Test upper rams and all valves to 250-3500 psi. OK. Blind rams failed at high test. Test plug would not seat completely in tubing head. Test jt X-O in lower rams. Pressure test completed successfully - 3500.000 psi Repair Repaired Bottom ram Change seals in bottom rams. Equipment work completed Test well control equipment Tested BOP stack Test rams to 250-3500 psi. OK. Pull test plug. GIH with Baker packer to 50' RKB. M/U top drive on test jts. Set packer and test down test jts between top of packer an dbtm of btm rams. Test OK. Pressure test completed successfully - 3500.000 psi Run Drillpipe, 3-1/2in O.D. Ran Drillpipe to 3530.0 ft (3-1/2in OD) Finish loading pipe shed with an additional 250 jts drill pipe. P/U 111 its (37 stds for open hole) and GIH. On bottom Pull Drillpipe, 3-1/2in O.D. Pulled Drillpipe in stands to 3530.0 ft POOH and start racking back drill pipe in derrick. On second std out icy looking mud started falling out of drill pipe. M/U top and started circulating. Getting thick rubbery looking stuff out of hole. Completed operations Pull Drillpipe, 3-1/2in O.D. (cont...) Circulated at 3330.0 ft 1'1111311 bllU k,/Ut k.,kJlll. OllllllatbU IIILIU. Facility Date/Time 21 Oct 99 M Pt L Pad Progress Report Well MPL-16A Page 3 Rig Nordic3 Date 30 November 99 09:00 09:00-10:00 10:00 10:00-06:00 10:00-06:00 06:00-21:30 06:00-06:30 06:30 06:30-07:00 07:00 07:00-07:30 07:30 07:30-08:00 08:00 08:00-11:00 11:00 11:00-13:00 13:00 13:00-18:00 18:00 18:00-18:30 18:30 18:30-21:00 21:00 21:00-21:30 21:30 21:30-06:00 Duration lhr 20 hr 20 hr 15-1/2 hr 1/2 hr 3hr 2hr 5hr 1/2 hr 2-1/2 hr 8-1/2 hr Activity Obtained clean returns - 100.00 % hole volume Pulled Drillpipe in stands to 3330.0 ft Pump slug. Blow down top drive. Finish POOH and rack back a total of 37 stds (drill pipe to be used for drilling open hole section). Completed operations BHA run no. 1 R.I.H. to 9230.0 ft P/U bit, B/S, F/S, 6-HWDP, Jars, 37 stds D/P, cont to P/U and single in. Circ the hole clean with viscous water every 500'. Change to courser shaker screens for max flow (1-10 bpm). Rotate at 80-100 RPM. Rotary torque 2000-5700. Contaminated mud to btm. BHA run no. 1 (cont...) R.I.H. to 9300.0 ft Continue GIH cleaning out contaminated mud. Stopped: To service drilling equipment Serviced Top drive Service top drive. Equipment work completed R.I.H. to 9626.0 ft Continue GIH to 9626' stopping every -500' to circulate out. Began precautionary measures Circulated at 9626.0 ft Circulate btm up. Same contaminated mud coming out of hole. Obtained clean returns - 100.00 % hole volume R.I.H. to 10181.0 fl Cont GIH. Tag up at 9936'. M/U top drive. Rotate thru with no wt. Cont GIH. Tag up 9956'. M/U top drive. Rotate thru with no wt. Cont reaming down. Tag finn cmt at 10181' RKB. Drill cmt at 80 fph down to 10200' (10' below top of window). On bottom Circulated at 10200.0 ft Circ out contaminated mud. Cmt in returns. Pump spacer sweep and displace hole with new mud. Shut down and clean out possum bellies and shaker pans. Obtained req. fluid properties - 100.00 %, hole vol. Pulled out of hole to 2000.0 fl Pump slug. Blow down top drive. POOH to 2000'. Stopped: To hold safety meeting Held safety meeting Tour change. PJSM. Technical limit discussion. Completed operations Pulled out of hole to 0.0 ft Finish POOH to BHA. At BHA Pulled BHA L/D bit, subs, and jars. BHA Laid out BHA run no. 2 Facility M Pt L Pad Progress Report Well MPL- 16A Page 4 Rig Nordic3 Date 30November99 Date/Time 22 Oct 99 23 Oct 99 24 Oct 99 21:30-22:30 22:30 22:30-01:00 01:00 01:00-02:00 02:00 02:00-04:00 04:00 04:00-05:30 05:30 05:30-06:00 06:00 06:00-06:00 06:00-13:30 13:30 13:30-15:00 15:00 15:00-06:00 06:00-06:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-05:00 05:00 05:00-06:00 06:00 06:00-06:00 06:00-08:00 08:00 08:00-09:30 Duration lhr 2-1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 24 hr 7-1/2 hr 1-1/2 hr 15hr 24 hr 1/2 hr 1/2 hr 22 hr lhr 24 hr 2hr 1-1/2 hr Activity Made up BHA no. 2 P/U bit, motor, FS, and MWD. Orient same. Completed operations Made up BHA no. 2 Load MWD. DM failed. Change out same. Re-load new MWD and orient same. Test OK. Completed operations Made up BHA no. 2 Finish P/U BHA and GIH. BHA no. 2 made up R.I.H. to 2800.0 ft P/U drill pipe singles and GIH to 2800'. Stopped · To service drilling equipment Serviced Block line Slip/cut 49' drill line. Line slipped and cut Serviced Top drive Service top drive, block, and crown. Equipment work completed BHA run no. 2 (cont...) R.I.H. to 10116.0 ft Finish P/U singles and GIH. Start running stds out of derrick. Break circ every 25 stds. Blow down top drive after breaking circ.M/U top drive to break circ and take ECD baseline numbers. On bottom Circulated at 10116.0 ft Circ around EP treated (0.75%) mud while taking ECD baseline numbers. :~! Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 10800.0 ft Start kick-off from 10196' to 10213'. Continue drill/slide from 10213' to 10800'. Max ECD 11.0. Average ECD 10.8. BHA run no. 2 (cont...) Drilled to 10805.0 ft Drill/slide from 10800' to 10805'. Stopped · To service drilling equipment Serviced Top drive Service top drive, blocks, and crown. Equipment work completed Drilled to 11995.0 ft Drill/slide from 10805' to 11995'. Started scheduled wiper trip: due to Footage drilled Circulated at 11995.0 ft Pump sweep and circulate out for wiper trip. Obtained clean returns - 100.00 % hole volume BHA run no. 2 (cont...) Pulled out of hole to 11995.0 ft Made 19 Stds wiper trip to 7" casing window. Hole slick. No problems. At BHA Serviced Top drive Blow down top drive. Service top drive, blocks, and Rpi pi g,' ........ ~' .......... ,._L__,r_ crown, e a r s r n ~,~[,c, u. u, aww~,,~ uta~.c Facility Date/Time 25 Oct 99 26 Oct 99 M Pt L Pad Progress Report Well MPL- 16A Page Rig Nordic3 Date 5 30 November 99 09:30 09:30-11:00 11:00 11:00-12:00 12:00 12:00-06:00 12:00-06:00 06:00-06:00 06:00-13:00 13:00 13:00-14:30 14:30 14:30-17:30 17:30 17:30-18:30 18:30 18:30-23:30 23:30 23:30-00:30 00:30 00:30-02:30 02:30 02:30-03:00 03:00 03:00-04:00 04:00 04:00-06:00 06:00-14:00 06:00-12:00 12:00 12:00-14:00 14:00 14:00-14:30 Duration 1-1/2 hr lhr 18hr 18hr 24 hr 7hr 1-1/2 hr 3hr lhr 5hr lhr 2hr 1/2 hr lhr 2hr 8hr 6hr 2hr 1/2 hr Activity bands. Equipment work completed R.I.H. to 11995.0 ft GIH slow. Hole slick. No prombles. On bottom Circulated at 11995.0 ft Break circulation and stage pumps up to drilling rate. No losses. Obtained bottoms up (100% annulus volume) Drilled to 13000.0 ft Drill from 11995' to 13000'. Drilled to 13000.0 ft Drilled from 13K' to TD @ 13435'. BHA run no. 2 (cont...) Drilled to 13435.0 ft (cont...) Drilled from 13K' to TD @ 13435'. Reached planned end of run - Section / well T.D. Circulated at 13435.0 ft Hi wt/hi vis sweeps. Hole swept with slug - 100.00 % hole volume Pulled out of hole to 10191.0 ft short trip, 34 stds, tight @ 13144' to 13155' worked through same At 7in casing shoe Serviced Top drive blow down & service top drive, blocks & crown. Equipment work completed R.I.H. to 13435.0 ft tagged at 13040' (top Kup C sand). MU top drive break circ, & slowly stage pumps up to rate. Wash / ream thru tight spot. Kick out pumps and rotary and slack off thru tight spot erea. Hole slick. Pre-cautionary wash / ream to bottom On bottom Pulled out of hole to 12955.0 ft At top of check trip interval Circulated at 13435.0 ft Pump high weight / high vis sweep and circulate same. Obtained bottoms up (100% annulus volume) Circulated at 13435.0 ft Drop and pump down Sperry Sun ESS. Hi-Vis mud spotted downhole Circulated at 13435.0 ft Pump and spot 100 bbls lube pill. blow down top drive. Oil spotted downhole Pulled out of hole to 13000.0 ft BHA run no. 2 (cont...) Pulled out of hole to 420.0 ft (cont...) At BHA Pulled BHA BHA Laid out Wellhead work Facility M Pt L Pad Progress Report Well MPL-16A Page 6 Rig Nordic3 Date 30 November 99 Date/Time 27 Oct 99 14:00-14:30 14:30 14:30-16:00 14:30-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-06:00 17:00-18:00 18:00 18:00-23:00 23:00 23:00-23:30 23:30 23:30-04:00 04:00 04:00-06:00 06:00 06:00-09:30 06:00-09:30 09:30 09:30-16:30 09:30-13:00 13:00 13:00-13:30 13:30 13:30-14:00 14:00 14:00-14:15 14:15 14:15-15:00 Duration 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 13hr lhr 5hr 1/2 hr 4-1/2 hr 2 hr 3-1/2 hr 3-1/2 hr 7hr 3-1/2 hr 1/2 hr 1/2hr 1/4hr 3/4hr Activity Removed Wear bushing Pull wear ring. Set test plug. Equipment work completed Well control Worked on BOP - Top ram Change rams to 4.5". Equipment work completed Test well control equipment Tested Top ram Test rams to 250 / 3500-OK. Pressure test completed successfully - 3500.000 psi Wellhead work Installed Wear bushing Pull test plug. Set wear ring. Eqpt. work completed, running tool retrieved Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment RU liner running tools. Work completed - Casing handling equipment in position Ran Liner to 3425.0 ft (4-1/2in OD) Ran total of 81 jts. 4.5", 12.6#, L-80, IBMT liner. MU Baker hanger & liner top packer. Hanger assembly installed Circulated at 3425.0 ft String displaced with Water based mud - 110.00 % displaced Ran Drillpipe on landing string to 10120.0 ft At Window · 10120.0 ft Circulated at 10120.0 ft Circ & cond mud @ 4 bpm w/800 psi. PfO-95k; S/O-65k. Obtained req. fluid properties ~ 120.00 %, hole vol. Run Liner, 4-1/2in O.D. (cont...) Ran Drillpipe on landing string to 13435.0 ft Finish RIH. Wash last stand down. Hole clean. On bottom Cement · Liner cement Circulated at 13435.0 ft Gradually worked rate up to 4.3 bpm w/1240 psi. Reciprocated pipe. Obtained req. fluid properties - 200.00 %, hole vol. Batch mixed slurry - 35.000 bbl PJSM. Continue circ while batch mixing. Batch slurry mixed Mixed and pumped slurry - 35.000 bbl Pumped 15 bbls weighted spacer. Pump 35 bbls Premium ' G' @ 15.8 ppg. Released Dart Displaced slurry - 125.000 bbl Displace w/55 bbls perf pill & 70 bbls mud. Bumped plug w/calculated displacement. Plug bumped Functioned Liner hanger Pressure up to 3500 psi to set hanger. Continue to 4700 psi to set liner top packer. Bled off. Floats lJL, JLI-UI~i., IX. ClCaac llkJlll lldll[~.~l WI L.4, JU3 [k./ tilL, Facility M Pt L Pad Progress Report Well MPL-16A Page 7 Rig Nordic3 Date 30November 99 Date/Time 15:00 15:00-16:30 16:30 16:30-20:00 16:30-20:00 28 Oct 99 20:00 20:00-01:00 20:00-01:00 01:00 01:00-05:30 01:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-14:00 14:00 14:00-16:00 16:00 16:00-17:00 17:00 17:00-19:30 19:30 19:30-20:30 20:30 20:30-23:00 23:00 23:00-02:00 29 Oct 99 02:00 02:00-03:30 Duration 1-1/2 hr 3-1/2 hr 3-1/2 hr 5hr 5hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 24 hr 1/2 hr 7-1/2 hr 2hr lhr 2-1/2 hr lhr 2-1/2 hr 3hr 1-1/2 hr Activity right. Pressure DP to 1000 psi and unsting. Equipment work completed Circulated at 10010.0 ft Set down 40k on top of liner. Circ till clean returns. No cement. Obtained clean returns - 120.00 % hole volume Perform integrity test Tested Liner Test 7" & 4.5" to 3110 psi and broke down. Bled to 1100 psi in 5 min. Suspended pressure test on Liner, observed leak Run Liner, 4-1/2in O.D. Racked back Drillpipe POH. LD running tool. Required components racked in derrick Test well control equipment Tested BOP stack Test BOPE to 250/3500 psi. Pressure test completed successfully - 3500.000 psi 3-l/2in. Communication test string workstring run Rigged up sub-surface equipment - Retrievable packer PU Baker 7" retrievable packer w/5.25" seal stem. Equipment work completed 3-l/2in. Communication test string workstring run (cont...) Serviced Top drive Equipment work completed Ran Drillpipe in stands to 9980.0 ft Tested Casing to 3500 psi @ 4850'. Cont RIH. Stopped · To test equipment Tested Casing Test annulus to 3500 psi @ 9980'-OK. Sting into liner top packer. Tested annulus to 3500 psi-OK. Pressure test completed successfully - 3500.000 psi Tested Liner Attempt to test liner. Pumping away @ 1700 psi. Bled down to 390 psi. Suspended pressure test on Other sub-surface equipment, observed le~ Circulated at 10009.0 ft Circ & cond. Obtained req. fluid properties - 150.00 %, hole vol. Tested Liner Sting into liner top packer. Pressure annulus to 3400 psi. Pump down DP w/1500 psi @ 3.6 bpm. Pressure annulus to 4500 psi f/30 min-OK. 9 5/8" x 7" annulus increased f/20>>790 psi. Injected 130 bbls mud down liner during test. Bled 7" x 3.5" to 3000 Suspended pressure test on Other sub-surface equipment, observed le Tested Liner Bled back 43 bbls. Suspended test, observed returns from wellbore Circulated at 10009.0 ft Circ 40 bbls Barazan, 30 bbls Dirt Magnet, & 45 bbls Barazan. Circ around w/seawater. Hole swept with slug - 150.00 % hole volume Flow check Flow back 2 bbls-Wcll,,~,~,,-'---'. ~' .... ~-' :-~-~,,,, ~,~' .... I [111 lJJ Facility M Pt L Pad Progress Report Well MPL- 16A Page Rig Nordic3 Date 8 30 November 99 Date/Time 30 Oct 99 31 Oct 99 03:30 03:30-06:00 06:00-20:30 06:00-06:30 06:30 06:30-20:30 20:30 20:30-06:00 20:30-06:00 20:30-06:00 06:00-08:30 06:00-08:30 08:30 08:30-16:30 08:30-09:00 09:00 09:00-09:30 09:30 09:30-12:30 12:30 12:30-16:30 16:30 16:30-18:30 16:30-18:30 18:30 18:30-22:30 18:30-22:30 22:30 22:30-23:30 22:30-23:30 23:30 23:30-00:00 23:30-00:00 00:00 00:00-06:00 00:00-02:00 Duration 2-1/2 hr 14-1/2 hr 1/2 hr 14 hr 9-1/2 hr 9-1/2 hr 9-1/2 hr 2-1/2 hr 2-1/2 hr 8hr 1/2 hr 1/2 hr 3hr 4hr 2hr 2 hr 4hr 4hr lhr lhr 1/2 hr 1/2 hr 6hr 2hr Activity down. Observed well static Laid down 2200.0 ft of 3-1/2in OD drill pipe 3-1/2in. Communication test string workstring run (cont...) Serviced Travelling block Service rig, top drive, crown and blocks. Equipment work completed Laid down 11000.0 ft of 3-1/2in OD drill pipe 330 joints laid out Electric wireline work Conducted electric cable operations POOH & R/D Schlumberger Conducted electric cable operations Made first trip to 7670'. Unable to pump down. POOH PU additional weight bar and rollers. 2nd run made it to 12670'. Log up while pumping 2 BPM.Leak found in liner top packer/hanger. POOH. Electric wireline work (cont...) Conducted electric cable operations (cont...) Made first trip to 7670'. Unable to pump down. POOH PU additional weight bar and rollers. 2nd run made it to 12670'. Log up while pumping 2 BPM.Leak found in liner top packer/hanger. POOH. Completed logging run with Spinner from 12900.0 ft to 9930.0 ft Run Tubing, 3-1/2in O.D. Serviced Top drive Equipment work completed Removed B ore protector Equipment work completed Flow check Monitor well flowed back 17 bbls. Observed well static Ran Tubing to 2235.0 ft (3-1/2in OD) Run 3.5" NSCT kill string to 2235' Hanger landed Nipple down BOP stack Rigged down BOP stack N/D BOPE Equipment work completed Wellhead work Installed All tree production valves T.P. Adaptder to 5000 psi. T.P tree to 5000 psi Equipment work completed Fluid system Freeze protect well - 84.000 bbl of Diesel Pump 59 bbls diesel down annulus taking returns f/ tbg. Close tbg and inject 25 bbls down annulus. Completed operations Wellhead work Installed Hanger plug Equipment work completed Move rig Rigged down Drillfloor / Derrick Jack up rig move off well, P/U pit liner & clean up ...... ~' .... ' ~-' .... ~' rig ~'~"-' Facility Date/Time M Pt L Pad 02:00 Progress Report Well MPL- 16A Rig Nordic3 Page Date Duration Activity Equipment work completed 9 30 November 99 Facility Date/Time 30 Nov 99 01 Dec 99 M Pt L Pad Progress Report Well MPL- 16A Page 1 Rig Nabors 4ES Date 06 December 99 11:00-12:00 11:00-12:00 12:00 12:00-15:00 12:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-17:00 16:00-17:00 17:00 17:00-18:00 17:00-18:00 18:00 18:00-20:00 18:00-19:00 19:00 19:00-20:00 20:00 20:00-23:30 20:00-23:30 23:30 23:30-02:00 23:30-02:00 02:00 02:00-03:00 02:00-03:00 03:00 03:00-04:00 03:00-04:00 04:00 04:00-05:00 04:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-07:30 06:00-07:30 07:30 07:30-06:00 07:30-23:30 23:30 23:30-00:00 Duration lhr lhr 3hr 3hr lhr lhr lhr lhr lhr lhr 2hr lhr lhr 3-1/2 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr lhr lhr lhr lhr lhr lhr 1-1/2 hr 1-1/2 hr 22-1/2 hr 16hr Activity Move rig Rig moved 100.00 % At well location - Slot Derrick management Installed High pressure lines RIG LINES & HCR TO ANNULUS & TREE & TO FLOW BAC TANK. Equipment work completed Wellhead work Removed Hanger plug Equipment work completed Fluid system Fill pits with Seawater Completed operations Well control Circulated closed in well at 2235.0 ft Circ. freeze protection out with seah20 & monitor same. Hole displaced with Synthetic based mud - 110.00 % displaced Wellhead work Installed Hanger plug install & test twc to 2000 psi. Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Test Witnessed by John Crisp with AOGC Wellhead work Removed Hanger plug Equipment work completed Derrick management Rigged up Tubing handling equipment Equipment work completed Wellhead work Retrieved Tubing hanger Equipment work completed Pull Tubing, 3-1/2in O.D. Pulled Tubing in stands to 1500.0 ft Stopped: To hold safety meeting Pull Tubing, 3-1/2in O.D. (cont...) Pulled Tubing in stands to 0.0 ft Completed operations 3-1/2in. Drillpipe workstring run Ran Drillpipe to 10030.0 ft (3-1/2in OD) Mu Baker Liner hanger patching assy. & rih breaking circ. & drift. & strap pipe On bottom Circulated at 10000.0 ft circ. 2-bbl. ep lube for lubricity.. K Facility M Pt L Pad Progress Report Well MPL- 16A Page 2 Rig Nabors 4ES Date 06 December 99 Date/rime 02 Dec 99 00:00 00:00-01:00 01:00 01:00-04:30 04:30 04:30-06:00 06:00 06:00-17:30 06:00-07:30 07:30 07:30-09:30 09:30 09:30-17:30 17:30 17:30-06:00 17:30-06:00 03 Dec 99 06:00 06:00-17:30 06:00-17:30 17:30 17:30-20:00 17:30-20:00 20:00 20:00-21:00 20:00-21:00 21:00 21:00-23:00 21:00-23:00 23:00 23:00-02:00 23:00-00:00 04Dec 99 00:00 00:00-02:00 Duration lhr 3-1/2 hr 1-1/2 hr 11-1/2 hr 1-1/2 hr 2hr 8hr 12-1/2 hr 12-1/2 hr 11-1/2 hr 11-1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr 2hr 2hr 3hr lhr 2hr Activity String displaced with Seawater - 100.00 % displaced Functioned Internal casing patch Locate & tag XO @ 10030 ' & set dn 40K & test pkr. to 1200 OK. Equipment work completed Installed Setting tools Dropped top packer setting ball & wait on Atlas to rih with wireline to verify ball on seat. Equipment work completed Conducted electric cable operations Rig Atlas & rih with tool string to verify paacker setting ball on seat. Began precautionary measures 3-1/2in. Drillpipe workstring run (cont...) Conducted slickline operations on Slickline equipment - Setting run ran roller to ensure that ball is on seat. Completed run with Setting tools from 0.0 ft to 9978.0 ft Set packer at 9971.0 ft with 3500.0 psi Set 5" x 7" SLZXP baker packer per program & Baker tech. all went as designed. Packer set at 9971.0 ft Laid down 9960.0 ft of 3-1/2in OD drill pipe 321 joints laid out Pull Single completion, 3-1/2in O.D. Ran Tubing to 4000.0 ft (3-1/2in OD) Load tbg. & strap & drift. & mu baker sab & rih with same torque turning connections. Stopped: To hold safety meeting Run Single completion, 3-1/2in O.D. Ran Tubing to 9967.0 ft (3-1/2in OD) Ran baker "S-3" pkr. on 3.5" nsct tbg. & engage into tieback @ 9967' Completed run with Permanent packer to 9967.0 ft Wellhead work Installed Tubing hanger Space out & make up hanger & land same & rilds & enegerize & set twc & test same to 2500 psi. & lay dn tbg. tools. Tie-down bolts energised Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree install tree & test same to 5000 psi & pull twc. Equipment work completed Fluid system Circulated at 9967.0 ft circ. 210 bbl. dn annulus treated with 25-gal inhib, per. 100 bbl. Hole displaced with Inhibited brine - 105.00 % displaced Freeze protect well - 80.000 bbl of Diesel Rig Hb&r & pump 80-bbl. diesel dn annulus & U-tube to tbg. Facility Date/Time M Pt L Pad Progress Report Well MPL-16A Page 3 Rig Nabors 4ES Date 06 December 99 02:00 02:00-05:00 02:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 Duration 3hr 3hr lhr lhr Activity Completed operations Run Single completion, 3-1/2in O.D. Set packer at 9943.0 fl with 4500.0 psi Drop ball & allow to free fall to seat & psi. tbg. to 4300 psi. & monitor 30-min OK. & bleed to 1500 psi. & psi. annulus to 4500 psi. & monitor for 30-min all OK. (Test Waived by John Spaulding with aogc. Packer set at 9943.0 ft Wellhead work Installed Hanger plug Equipment work completed MILNE POINT, ALASKA TO: Bixby/Ketchum FROM: O'Malley Mark WELL# Main Category: Sub Category: Sub Category: Operation Date: IMPL-16i DRLG. Initial Perforations E-Line 01 / 16 / 00 Date: I1 / 16 / 00 I Objective: Conduct a cement bond Icg and perforate 160' of 2" power jet guns. Operation: SWS arrived location, Held pre-job safety meeting, Start in the hole with a 1-11/16" SCMT Bond Icg tagged td @ 13,338 elmd start logging the liner good cement from pbtd to approx. 11,930' continue to Icg to 10,900 clear pipe. shut in tool POH confirm perforation depths with engineer in town, commence perforations RIH with a CCL / Gamma ray with 20' gun. Tagged td POH and Icg perf area. Drop down into the lower section of the zone logged into position 4.7' from gamma ray to top shot. #1 run 20' 2" power jet gun spot gamma 13,218.3 gun fired 13,223' - 13,243' #2 run 30' 2" power jet gun spot CCL (4') to top shot spot gun 13,189' gun fired 13,193' - 13,223' Completed lower section of perforations. Start middle with 20' gun. #3 run 20' 2" power jet gun spot CCL (4') spot gun 13,156' gun fired 13,160' - 13,180' #4 run 20' 2" power jet gun spot CCL (4') spot gun 13,136' gun fired 13,140' - 13,160' Completed middle section of perforations. Start upper section with 30' gun. #5 run 30' 2" power jet gun spot CCL (4') spot gun 13,041' gun fired 13,045 - 13,075' #6 run 20' 2" power jet gun spot CCL (4') spot gun 13,071' gun fired 13,075 - 13,095' #7 run 20' 2" power jet gun spot CCL (4') spot gun 13,091' gun fired 13,095 - 13,115' POH all shots fired completed all perforation operations in one day. Conclusion: Well cement bond log completed good cement throughout the perforation area approx. 1,000' of good cement above perforations. All 160' of 4 spf 2" power jet guns fired well perforated and ready for injection. No fluids pumped. AFE# 337161 9335-070-780 Drlg / Initial perfs / E-Line SWS = $ 42,000 Prudhoe Bay Unit Alaska State Plane Zone 4 Milne Point MPL, Slot MPL- 16 MPL-16A Job No. AKMM90168, Surveyed: 25 October, 1999 ORIGINAL SURVEY REPORT 29 October, 1999 Your Ref: 500292256601 Surface Coordinates: 6031792.71 N, 544729.51E (70° 29' 51.8250" N, 149° 38' 03.1738" W) Kelly Bushing: 45.93ft above Mean Sea Level RECEIVED. JAN 2 6 2000 D R I L I.~ ! N I; , E; (; R V I,.,C: ~ s Survey Ref: svy8885 A HALLIB~T~ Sperry-Sun Drilling Services Survey Report for MPL- 16A Your Ref: 500292256601 Job No. AKMM90168, Surveyed: 25 October, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) 10096.83 70.330 44.320 4810.95 4856.88 10196.15 70.170 45.131 4844.52 4890.45 10252.51 65.070 41.600 4865.97 4911.90 10349.19 64.640 35.310 4907.09 4953.02 10447.04 63.850 31.730 4949.62 4995.55 10542.30 63.390 27.470 4991.96 5037.89 10637.92 63.770 19.880 5034.55 5080.48 10735.66 62.050 10.550 5079.14 5125.07 10833.96 59.340 5.910 5127.27 5173.20 10927.67 53.910 1.520 5178.82 5224.75 11026.10 48.250 354.700 5240.67 5286.60 11123.05 43.120 345.500 5308.46 5354.39 11219.59 39.240 336.770 5381.16 5427.09 11317.54 34.040 331.370 5459.75 5505.68 11415.30 32.270 330.480 5541.59 5587.52 11512.72 31.060 329.700 5624.51 5670.44~ 11609.08 30.100 330.200 5707.47 5753.40 11705.92 29.550 330.550 5791.48 5837.41 11802.78 29.080 330.780 5875.94 5921.87 11898.78 28.490 331.030 5960.07 6006.00 11994.77 26.690 330.990 6045.14 6091.07 12091.47 22.250 327.040 6133.14 6179.07 12191.83 20.930 327.480 6226.46 6272.39 12289.08 21.010 328.060 6317.27 6363.20 12384.62 18.770 327.550 6407.10 6453.03 Global Coordinates Alaska State Plane Zone 4 Milne Point MPL ., 5900.26 N 5596.50 E 6037726.54 N 5966.67 N 5662.28 E 6037793.35 N 6004.52 N 5698.06 E 6037831.41 N 6073.00 N 5752.46 E 6037900.22 N 6146.46 N 5801.12 E 6037973.96 N 6220.63 N 5843.27 E 6038048.39 N 6298.98 N 5877.61 E 6038126.95 N 6382.80 N 5900.46 E 6038210.90 N 6467.59 N 5912.77 E 6038295.76 N 6545.61 N 5917.93 E 6038373.82 N 6622.05 N 5915.59 E 6038450.24 N 6690.26 N 5903.94 E 6038518.37 N 6750.33 N 5883.61 E 6038578.33 N 6802.91N 5858.23 E 6038630.75 N 6849.64 N 5832.26 E 6038677.33 N 6893.97 N 5806.76 E 6038721.50 N 6936.40 N 5782.21 E 6038763.78 N 6978.27 N 5758.40 E 6038805.51N 7019.61 N 5735.17 E 6038846.71 N 7060.00 N 5712.69 E 6038886.96 N 7098.89 N 5691.14 E 6038925.72 N 7133.26 N 5670.64 E 6038959.97 N 7164.32 N 5650.66 E 6038990.91 N 7193.76 N 5632.10 E 6039020.24 N 7221.27 N 5614.79 E 6039047.64 N Dogleg Vertical Eastings Rate Section (ft) (°/lOOft) (ft) 550290.40 E 8073.14 550355.78E 0.785 8165.67 550391.33 E 10.743 8217.39 550445.32 E 5.906 8304.80 550493.54 E 3.393 8392.79 550535.24 E 4.035 8477.47 550569.11 E 7.119 8560.85 550591.46 E 8.676 8641.78 550603.26 E 4.953 8717.21 550607.95 E 6.989 8782.95 550605.15 E 7.877 8842.94 550593.08 E 8.598 8890.77 550572.39 E 7.176 8926.91 550546.69 E 6.241 8954.01 550520.44 E 1.878 8976.06 550494.68 E 1.311 8996.48 550469.87 E 1.031 9015.92 550445.81 E 0.596 9035.36 550422.33 E 0.499 9054.72 550399.61 E 0.627 9073.76 550377.83 E 1.875 9092.15 550357.12 E 4.891 9107.54 550336.96 E 1.325 9120.58 550318.22 E 0.229 9133.17 550300.75 E 2.352 9144.95 RECEIVED Comment Tie On Survey Window Point JAN 2 6 2000 Continued... 29 October, 1999- 14:38 -2- Alaska 0il & Gas Cons. Commission DrillQuest Sperry-Sun Drilling Services Survey Report for MPL-16A Your Ref: 500292256601 Job No, AKMM90168, Surveyed: 25 October, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (fi) (ft) (ft) 12481.27 13.270 323.340 6499.97 6545.90 7243.31 N 5599.82 E 6039069.59 N 550285.63 E 12578.96 12.850 323.660 6595.13 6641.06 7261.05 N 5586.68 E 6039087.25 N 550272.40 E 12675.83 11.770 326.140 6689.77 6735.70 7277.94 N 5574.80 E 6039104.06 N 550260.41 E 12773.07 11.410 324.120 6785.03 6830.96 7293.96 N 5563.63 E 6039120.02 N 550249.15 E 12869.56 11.550 325.240 6879.59 6925.52 7309.63 N 5552.53 E 6039135.63 N 550237,95 E 12965.71 11.460 324.620 6973.81 7019.74 7325.33 N 5541.51 E 6039151.25 N 550226,84 E 13064.09 11.460 325.520 7070,23 7116.16 7341.35 N 5530.32 E 6039167.21 N 550215.55 E 13161.83 11.610 326.530 7165.99 7211.92 7357.56 N 5519.40 E 6039183.35 N 550204,53 E 13258.17 11.070 324.830 7260.45 7306.38 7373.21 N 5508.73 E 6039198.94 N 550193.77 E 13354.12 10.390 325.290 7354.72 7400.65 7387.85 N 5498.49 E 6039213.52 N 550183.44 E 13435.00 10.390 325.290 7434.28 7480.21 7399.84 N 5490.19 E 6039225.46 N 550175.07 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Alaska State Plane Zone 4 Milne Point MPL Dogleg Rate (°/100fi) Vertical Section (ft) Comment 5.813 0.436 1.241 0.558 0.273 0.159 o.182 0.257 0.659 o.714 o.oo0 9153.72 916o.15 9166.62 9172.84 9178.81 9184.85 9191 .o5 9197.56 92o3.77 9209.43 9214.11 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 36.573° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13435.00ft., The Bottom Hole Displacement is 9214.1 l ft., in the Direction of 36.573° (True). RECEIVED JAN 2 6 2000 Alaska 0il & Gas Cons. Commissi0~ Continued... 29 October, 1999 - 14:38 - 3 - DriflQuest Sperry-Sun Drilling Services Survey Report for MPL-16A Your Ref: 500292256601 Job No. AKMM90168, Surveyed: 25 October, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Milne Point MPL Comments Measured Depth (ft) 10096.83 10196.15 13435.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4856.88 5900.26 N 5596.50 E 4890.45 5966.67 N 5662.28 E 7480.21 7399.84 N 5490.19 E Comment Tie On Survey Window Point Projected Survey RECEIVED JAN 26 2000 Alaska 0il & Gas Cons. C0m~ 29 October, 1999 - 14:38 - 4 - DrlllQuest -- STATE OF ALASKA -- ALASKA ~JIL AND GAS CONSERVATION CO,v~MISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon r~ . Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3604' NSL, 5148' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 397' NSL, 375' EWL, SEC. 33, T14N, R10E, UM At effective depth 430' NSL, 351' EWL, SEC. 33, T14N, R10E At total depth 444' NSL, 342' EWL, SEC. 33, T14N, R10E, UM 5. Type of well: [] Development i--1 Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 45.93' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-16Ai 9. Permit Number 199-090 10. APl Number 50- 029-22566-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 13435 true vertical 7480 Effective depth: measured 13345 true vertical 7392 Casing Length Structural Conductor 80' Surface 9012' Intermediate Production 15834' Liner 3423' feet Plugs (measured) feet feet Junk (measured) feet Size 20" 9-5/8" ORIGINAL Cemented MD 250 sx Arcticset I (Approx.) 80' 1740 sx PF 'E', 250 sx 'G', 132 sx PF 'E' 9048' 7" 275 sx Class 'G' (Top of Window) 10191' 4-1/2" 170 sx Class 'G' 10009' - 13432' TVD 80' 4510' 4888' 4830'-7477' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) Kill String: 3-1/2", 9.3#, L-80 to 2234' Packers and SSSV (type and measured depth) 5" x 7" ZXP Tieback Packer at 10009' &~$[(8 0il & 6as Cons. O01f~[fti$$i0fl Anchorage 13. Attachments [] Description summary of proposal I--1 Detailed operations program [] BOP sketch 14. Estimated date for commencing operation November 30, 1999 16. If proposal was verbally approved Tom Maunder Name of approver 11/29/99 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Robert Laule, 564-5195 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the..fere~g~s)ing is true and correct to the best of my knowledge Signed .-'~' /" RobertLau,e ~'~¢-/ ~¢_~.¢,.~.~-- Title Operations Drilling Engineer Date Commission Use Only IConditions of ~pproval: Notify Commission so representative may witness I Approval No. ~,~/~-o,~ [Approved by order of the Commission Robert N. Christen,o, Commissioner Date/O~,- Form 10-403 Rev. 06/15/88 Submit In Triplicate A . ka ea red rvices rilling To: Alaska Oil & Gas Conservation Commission Date: November 29, 1999 Fro rn: Subject: Robert Laule Operations Drilling Engineer Procedure to Complete MPL-16Ai (Suspended Well) Scope for the repair and completion of MPL-16Ai: , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. MIRU Work Over Rig Pull BPV. Circulate and bullhead kill well. Set TWC. ND Tree, NU BOP and test. Retrieve kill string. PU liner straddle assembly, setting tool and collars. RIH with straddle assembly on 3-1/2" DP. Locate straddle in liner hanger to liner XO and set lower packoff with 40,000 # down weight. Pressure up to 1000psi to confirm straddle location. Drop ball for setting tool if necessary chase ball to bottom with wireline. Set upper packer ,release setting tool. Slack off 50,000# on packer. Test casing and straddle to 4500 psi. POH. Run 3-1/2" packer completion. Install TWC. ND BOP and NU and test the tree. Freeze protect annulus. Set packer and test. Test to be witnessed by AOGCC. RDMO Work Over Rig. .... ' STATE OF ALASKA ALASKA L)IL AND GAS CONSERVATION CO~v~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing []Operation Shutdown []Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Plugging 4. Location of well at surface []Alter Casing [] Repair Well [] Other [] Perforate Suspension Operation 5. Type i_e_f] well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 45.93' 7. Unit or Property Name Milne Point Unit 8. Well Number 3604' NSL, 5148' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 397' NSL, 375' EWL, SEC. 33, T14N, R10E, UM At effective depth 430' NSL, 351' EWL, SEC. 33, T14N, R10E At total depth 444' NSL, 342' EWL, SEC. 33, T14N, R10E, UM MPL-16Ai 9. Permit Number / Approval No. 199-090 399-220 10. APl Number 50- 029-22566-01 11. Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 13435 feet true vertical 7480 feet Effective depth: measured 13345 feet true vertical 7392 feet Casing Length Plugs (measured) Junk (measured) Size Cemented Structural Conductor 80' 20" Surface 9012' 9-5/8" Intermediate Production 15834' 7" Liner 3423' 4-1/2" 250 sx Arcticset I (Approx.) 1740 sx PF 'E', 250 sx 'G', 132 sx PF 'E' 275 sx Class 'G' (Top of Window) 170 sx Class 'G' MD TVD 80' 80' 9048' 4510' 10191' 4888' 10009'-13432' 4830'-7477' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) Kill String: 3-1/2", 9.3#, L-80 to 2234' Packers and SSSV (type and measured depth) 5" x 7" ZXP Tieback Packer at 10009' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure !9.99 6~.~ (,0n~. 60mmJssJor~ Anchorage 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 5. Attachments i--I Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: I--I Oil F-I Gas [] Suspended Service 7. I herebY certify that the foregoing is true and correct to the best of my knowledge Signed ~ . ~ Terrie Nubble' i~,'~/,,__,,_ Title Technical Assistant III Prepared By Name/Number: Submit In Duplicate"~,~.~ Form 10-404 Rev. 06/15/88 Facility Date/Time 17 Oct 99 18 Oct 99 M Pt L Pad Progress Report Well MPL-16A Page 1 Rig Nordic3 Date 30 November 99 00:00-06:00 00:00-06:00 06:00 06:00-10:00 06:00-08:00 08:00 08:00-10:00 10:00 10:00-17:30 10:00-17:30 17:30 17:30-18:00 17:30-18:00 18:00 18:00-00:00 18:00-00:00 00:00 00:00-02:00 00:00-02:00 02:00 02:00~06:00 02:00-06:00 06:00 06:00-12:00 06:00-12:00 12:00 12:00-06:00 12:00-19:00 19:00 19:00-06:00 Duration 6hr 6hr 4hr 2hr 2hr 7-1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 6hr 6hr 2 hr 2hr 4hr 4hr 6hr 6hr 18hr 7hr llhr Activity Move rig Rig moved 100.00 % Finish moving rig from ARCO Kuparuk 1D-Pad to Milne Point L-16A. Spot misc Service Company equipment. Accept rig at 0001 hrs 10/17/99. At well location - Cellar Suspend operations Held safety meeting Shut rig down as directed to prepare for Milne Point orientation. Completed operations Held safety meeting Both rig crews attend Milne Point orientation. Completed operations Move rig Rig moved 100.00 % Spot Baroid, Sperry equipment. R/U lines to circ out freeze protect diesel. Modify cuttings box chute. Finish misc berming. At well location - Cellar Wellhead work Removed Hanger plug R/U lubricator and pull BPV. Equipment work completed Fluid system Circulated at 2388.0 ft RECEIVED Naslia Oil & Gas eons. Comm Anchorage Test lines with air. Attempt to circ out freeze protect diesel. Unable to circ. R/U HB&R and pump 25 bbls methanol and thaw out. Circ out diesel with rig pump. Broke circulation Wellhead work Rigged up Xmas tree Set TWC and test to 1000 psi. N/D tree. Equipment work completed Nipple up BOP stack Rigged up BOP stack N/U BOPS and associated lines, bell nipple,and flowline. Equipment work completed Nipple up BOP stack (cont...) Tested BOP stack M/U test joint and test equipment and attempt to start testing BOPS. Getting fluid out of annulus. Change TWC and test from btm OK. Leak from top. Perform preliminary test on choke manifold while lcoating 3 1/2" test jt with donut. Began precautionary measures Suspend operations Held safety meeting Rig crews released for SDD/Nordic training at Milne Point base camp. Completed operations Rig waited · Other delays Rig shut down for -:-~-' as ~': ..... " Ill,IlL UllGk~tGU, Facility Date/Time 19 Oct 99 20 Oct 99 Progress Report M Pt L Pad Well MPL-16A Page 2 Rig Nordic3 Date 30 November 99 Duration Activity 06:00 06:00-07:00 06:00-07:00 07:00 07:00-10:30 07:00-10:30 10:30 10:30-15:00 10:30-15:00 15:00 15:00-19:30 15:00-19:30 19:30 19:30-21:30 19:30-21:30 21:30 21:30-00:00 21:30-00:00 00:00 00:00-05:00 00:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-10:00 06:00-09:00 lhr lhr 3-1/2 hr 3-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 2hr 2hr 2-1/2 hr 2-1/2 hr 5hr 5hr 1 hr lhr 4hr 3hr Began precautionary measures Suspend operations (cont...) Held safety meeting Rig crews attend MPL-16Ai pre-spud at Milne Point base camp. Completed operations Test well control equipment Tested BOP stack Tempoary test on blinds against the casing to 1000 psi. M/U test joint and test upper rams to 250-3500 psi and Hydril to 250-250 psi. Tests OK. L/D landing joint. These tests were erformed to be able to pull hanger and tubing. AOGCC to witness later. Pressure test completed successfully - 3500.000 psi Pull Tubing, 3-1/2in O.D. Laid down 2358.0 ft of Tubing Pull hanger and L/D 75 jts 3 1/2" 9.3# tubing. NORM same. Completed operations Test well control equipment Tested BOP stack R/U test equipment. Test hydril 250-2500 psi. OK. Test upper rams and all valves to 250-3500 psi. OK. Blind rams failed at high test. Test plug would not seat completely in tubing head. Test jt X-O in lower rams. Pressure test completed successfully - 3500.000 psi Repair Repaired Bottom ram Change seals in bottom rams. Equipment work completed Test well control equipment Tested BOP stack Test rams to 250-3500 psi. OK. Pull test plug. GIH with Baker packer to 50' RKB. MFU top drive on test · jts. Set packer and test down test jts between top of packer an dbtm of btm rams. Test OK. Pressure test completed successfully - 3500.000 psi Run Drillpipe, 3-1/2in O.D. Ran Drillpipe to 3530.0 ft (3-1/2in OD) Finish loading pipe shed with an additional 250 its drill pipe. P/U 111 jts (37 stds for open hole) and GIH. On bottom Pull Drillpipe, 3-1/2in O.D. Pulled Drillpipe in stands to 3530.0 ft POOH and start racking back drill pipe in derrick. On second std out icy looking mud started falling out of drill pipe. M/U top and started circulating. Getting thick rubbery looking stuff out of hole. Completed operations Pull Drillpipe, 3-1/2in O.D. (cont...) Circulated at 3330.0 ft 1'1111311 ~..IIL.. ULIL L..UIILO. IIIIII~I.I. GLI lllUt-l. Progress Report Facility M Pt L Pad Well MPL-16A Page 3 Rig Nordic3 Date 30 November 99 Date/Time Duration Activity 21 Oct 99 09:00 09:00-10:00 10:00 10:00-06:00 10:00-06:00 06:00-21:30 06:00-06:30 06:30 06:30-07:00 07:00 07:00-07:30 07:30 07:30-08:00 08:00 08:00-11:00 11:00 11:00-13:00 13:00 13:00-18:00 18:00 18:00-18:30 18:30 18:30-21:00 21:00 21:00-21:30 21:30 21:30-06:00 lhr 20 hr 20 hr 15-1/2 hr 1/2 hr 1/2 hr 3hr 2hr 5hr 2-1/2 hr 8-1/2 hr Obtained clean returns - 100.00 % hole volume Pulled Drillpipe in stands to 3330.0 ft Pump slug. Blow down top drive. Finish POOH and rack back a total of 37 stds (drill pipe to be used for drilling open hole section). Completed operations BHA run no. 1 R.I.H. to 9230.0 ft P/U bit, B/S, F/S, 6-HWDP, Jars, 37 stds D/P, cont to P/U and single in. Circ the hole clean with viscous water every 500'. Change to courser shaker screens for max flow (1-10 bpm). Rotate at 80-100 RPM. Rotary torque 2000-5700. Contaminated mud to btm. BHA run no. 1 (cont...) R.I.H. to 9300.0 ft Continue GIH cleaning out contaminated mud. Stopped: To service drilling equipment Serviced Top drive Service top drive. Equipment work completed R.I.H. to 9626.0 ft Continue GIH to 9626' stopping every -500' to circulate out. Began precautionary measures Circulated at 9626.0 ft Circulate btm up. Same contaminated mud coming out of hole. Obtained clean returns - 100.00 % hole volume R.I.H. to 10181.0 ft Cont GIH. Tag up at 9936'. M/U top drive. Rotate thru with no wt. Cont GIH. Tag up 9956'. M/U top drive. Rotate thru with no wt. Cont reaming down. Tag firm cmt at 10181' RKB. Drill cmt at 80 fph down to 10200' (10' below top of window). On bottom Circulated at 10200.0 ft Circ out contaminated mud. Cmt in returns. Pump spacer sweep and displace hole with new mud. Shut down and clean out possum bellies and shaker pans. Obtained req. fluid properties - 100.00 %, hole vol. Pulled out of hole to 2000.0 ft Pump slug. Blow down top drive. POOH to 2000'. Stopped ' To hold safety meeting Held safety meeting Tour change. PJSM. Technical limit discussion. Completed operations Pulled out of hole to 0.0 ft Finish POOH to BHA. At BHA Pulled BHA L/D bit, subs, and jars. BHA Laid out BHA run no. 2 Facility Date/Time 22 Oct 99 23 Oct 99 24 Oct 99 Progress Report M Pt L Pad Well MPL-16A Page 4 Rig Nordic3 Date 30 November 99 21:30-22:30 22:30 22:30-01:00 01:00 O1:00-02:00 02:00 02:00-04:00 04:00 04:00-05:30 05:30 05:30-06:00 06:00 06:00-06:00 06:00-13:30 13:30 13:30-15:00 15:00 15:00-06:00 06:00-06:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-05:00 05:00 05:00-06:00 06:00 06:00-06:00 06:00-08:00 08:00 08:00-09:30 Duration lhr 2-1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 24 hr 7-1/2 hr 1-1/2 hr 15hr 24 hr 1/2 hr 1/2 hr 22 hr lhr 24 hr 2hr 1-1/2 hr Activity Made up BHA no. 2 PFLI bit, motor, FS, and MWD. Orient same. Completed operations Made up BHA no. 2 Load MWD. DM failed. Change out same. Re-load new MWD and orient same. Test OK. Completed operations Made up BHA no. 2 Finish P/U BHA and GIH. BHA no. 2 made up R.I.H. to 2800.0 ft PFU drill pipe singles and GIH to 2800'. Stopped · To service drilling equipment Serviced Block line Slip/cut 49' drill line. Line slipped and cut Serviced Top drive Service top drive, block, and crown. Equipment work completed BHA run no. 2 (cont...) R.I.H. to 10116.0 ft Finish P/U singles and GIH. Start running stds out of derrick. Break circ every 25 stds. Blow down top drive after breaking circ.M/U top drive to break circ and take ECD baseline numbers. On bottom Circulated at 10116.0 ft Circ around EP treated (0.75%) mud while taking ECD baseline numbers. Obtained req. fluid properties - 100.00 %, hole vol. Drilled to 10800.0 ft Start kick-off from 10196' to 10213'. Continue drill/slide from 10213' to 10800'. Max ECD 11.0. Average ECD 10.8. BHA run no. 2 (cont...) Drilled to 10805.0 ft Drill/slide from 10800' to 10805'. Stopped · To service drilling equipment Serviced Top drive Service top drive, blocks, and crown. Equipment work completed Drilled to 11995.0 ft Drill/slide from 10805' to 11995' Started scheduled wiper trip: due to Footage drilled Circulated at 11995.0 ft Pump sweep and circulate out for wiper trip. Obtained clean returns - 100.00 % hole volume BHA run no. 2 (cont...) Pulled out of hole to 11995.0 ft Made 19 Stds wiper trip to 7" casing window. Hole slick. No problems. At BHA Serviced Top drive Blow down top drive. Service top drive, blocks, and fl, ~_-'-- ' 1 ........ ..-1 .......... 1.~ L-~I.~ crown. ~.~.wpan spring ~C,~l_,W u. maw WUl~ marc Progress Report Facility M Pt L Pad Well MPL- 16A Rig Nordic3 Page 5 Date 30 November 99 Date/Time 09:30 09:30-11:00 11:00 11:00-12:00 12:00 12:00-06:00 12:00-06:00 25 Oct 99 06:00-06:00 06:00-13:00 13:00 13:00-14:30 14:30 14:30-17:30 17:30 17:30-18:30 Duration 1-1/2 hr lhr 18hr 18hr 24 hr 7hr 1-1/2 hr 3 hr lhr Activity bands. Equipment work completed R.I.H. to 11995.0 ft GIH slow. Hole slick. No prombles. On bottom Circulated at 11995.0 ft Break circulation and stage pumps up to drilling rate. No losses. Obtained bottoms up (100% annulus volume) Drilled to 13000.0 ft Drill from 11995' to 13000'. Drilled to 13000.0 ft Drilled from 13K' to TD @ 13435'. BHA run no. 2 (cont...) Drilled to 13435.0 ft (cont...) Drilled from 13K' to TD @ 13435'. Reached planned end of run - Section / well T.D. Circulated at 13435.0 ft Hi wt/hi vis sweeps. Hole swept with slug - 100.00 % hole volume Pulled out of hole to 10191.0 ft short trip, 34 stds, tight @ 13144' to 13155' worked through same At 7in casing shoe Serviced Top drive blow down & service top drive, blocks & crown. 26 Oct 99 18:30 18:30-23:30 23:30 23:30-00:30 00:30 00:30-02:30 02:30 02:30-03:00 03:00 03:00-04:00 04:00 04:00-06:00 06:00-14:00 06:00-12:00 12:00 12:00-14:00 14:00 14:00-14:30 5hr lhr 2hr 1/2 hr lhr 2hr 8hr 6hr 2hr 1/2 hr Equipment work completed R.I.H. to 13435.0 ft tagged at 13040' (top Kup C sand). MU top drive break circ, & slowly stage pumps up to rate. Wash / ream thru tight spot. Kick out pumps and rotary and slack off thru tight spot erea. Hole slick. Pre-cautionary wash / ream to bottom On bottom Pulled out of hole to 12955.0 ft At top of check trip interval Circulated at 13435.0 ft Pump high weight / high vis sweep and circulate same. Obtained bottoms up (100% annulus volume) Circulated at 13435.0 ft Drop and pump down Sperry Sun ESS. Hi-Vis mud spotted downhole Circulated at 13435.0 ft Pump and spot 100 bbls lube pill. blow down top drive. Oil spotted downhole Pulled out of hole to 13000.0 ft BHA run no. 2 (cont...) Pulled out of hole to 420.0 ft (cont...) At BHA Pulled BHA BHA Laid out Wellhead work Facility Date/Time 27 Oct 99 M Pt L Pad Progress Report Well MPL-16A Page 6 Rig Nordic3 Date 30 November 99 14:00-14:30 14:30 14:30-16:00 14:30-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-06:00 17:00-18:00 18:00 18:00-23:00 23:00 23:00-23:30 23:30 23:30-04:00 04:00 04:00-06:00 06:00 06:00-09:30 06:00-09:30 09:30 09:30-16:30 09:30-13:00 13:00 13:00-13:30 13:30 13:30-14:00 14:00 14:00-14:15 14:15 14:15-15:00 Duration 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 13hr lhr 5hr 1/2 hr 4-1/2 hr 2hr 3-1/2 hr 3-1/2 hr 7hr 3-1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr Activity Removed Wear bushing Pull wear ring. Set test plug. Equipment work completed Well control Worked on BOP - Top ram Change rams to 4.5". Equipment work completed Test well control equipment Tested Top ram Test rams to 250 / 3500-OK. Pressure test completed successfully - 3500.000 psi Wellhead work Installed Wear bushing Pull test plug. Set wear ring. Eqpt. work completed, running tool retrieved Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment RU liner running tools. Work completed - Casing handling equipment in position Ran Liner to 3425.0 ft (4-1/2in OD) Ran total of 81 jts. 4.5", 12.6#, L-80, IBMT liner. MU Baker hanger & liner top packer. Hanger assembly installed Circulated at 3425.0 ft String displaced with Water based mud - 110.00 % displaced Ran Drillpipe on landing string to 10120.0 ft At Window · 10120.0 ft Circulated at 10120.0 ft Circ & cond mud @ 4 bpm w/800 psi. PFU-95k; S/O-65k. Obtained req. fluid properties - 120.00 %, hole vol. Run Liner, 4-1/2in O.D. (cont...) Ran Drillpipe on landing string to 13435.0 ft Finish RIH. Wash last stand down. Hole clean. On bottom Cement · Liner cement Circulated at 13435.0 ft Gradually worked rate up to 4.3 bpm w/1240 psi. Reciprocated pipe. Obtained req. fluid properties - 200.00 %, hole vol. Batch mixed slurry - 35.000 bbl PJSM. Continue circ while batch mixing. Batch slurry mixed Mixed and pumped slurry - 35.000 bbl Pumped 15 bbls weighted spacer. Pump 35 bbls Premium ' G' @ 15.8 ppg. Released Dart Displaced slurry - 125.000 bbl Displace w/55 bbls perf pill & 70 bbls mud. Bumped plug w/calculated displacement. Plug bumped Functioned Liner hanger Pressure up to 3500 psi to set hanger. Continue to 4700 psi to set liner top packer. Bled off. Floats Facility M Pt L Pad Progress Report Well MPL- 16A Page 7 Rig Nordic3 Date 30November 99 Date/Time 28 Oct 99 29 Oct 99 15:00 15:00-16:30 16:30 16:30-20:00 16:30-20:00 20:00 20:00-01:00 20:00-01:00 01:00 01:00-05:30 01:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-14:00 14:00 14:00-16:00 16:00 16:00-17:00 17:00 17:00-19:30 19:30 19:30-20:30 20:30 20:30-23:00 23:00 23:00-02:00 02:00 02:00-03:30 Duration 1-1/2 hr 3-1/2 hr 3-1/2 hr 5hr 5hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 24 hr 1/2 hr 7-1/2 hr 2hr lhr 2-1/2 hr lhr 2-1/2 hr 3hr 1-1/2 hr Activity right. Pressure DP to 1000 psi and unsting. Equipment work completed Circulated at 10010.0 ft Set down 40k on top of liner. Circ till clean returns. No cement. Obtained clean returns - 120.00 % hole volume Perform integrity test Tested Liner Test 7" & 4.5" to 3110 psi and broke down. Bled to 1100 psi in 5 min. Suspended pressure test on Liner, observed leak Run Liner, 4-1/2in O.D. Racked back Drillpipe R ~ C E ~ ~;~ ~.. POH. LD running tool. Required components racked in derrick Test well control equipment D~C C, Tested BOP stack Test BOPE to 250/3500 psi. ~ 0]1 & Pressure test completed successfully - 3500.000 psi 3-1/2in. Communication test string workstring run Rigged up sub-surface equipment - Retrievable packer PU Baker 7" retrievable packer w/5.25" seal stem. Equipment work completed 3-1/2in. Communication test string workstring run (cont...) Serviced Top drive Equipment work completed Ran Drillpipe in stands to 9980.0 ft Tested Casing to 3500 psi @ 4850'. Cont RIH. Stopped · To test equipment Tested Casing Test annulus to 3500 psi @ 9980'-OK. Sting into liner top packer. Tested annulus to 3500 psi-OK. Pressure test completed successfully - 3500.000 psi Tested Liner Attempt to test liner. Pumping away @ 1700 psi. Bled down to 390 psi. Suspended pressure test on Other sub-surface equipment, observed le~ Circulated at 10009.0 ft Circ & cond. Obtained req. fluid properties - 150.00 %, hole vol. Tested Liner Sting into liner top packer. Pressure annulus to 3400 psi. Pump down DP w/1500 psi @ 3.6 bpm. Pressure annulus to 4500 psi f/30 min-OK. 9 5/8" x 7" annulus increased f/20>>790 psi. Injected 130 bbls mud down liner during test. Bled 7" x 3.5" to 3000 Suspended pressure test on Other sub-surface equipment, observed le Tested Liner Bled back 43 bbls. Suspended test, observed returns from wellbore Circulated at 10009.0 ft Circ 40 bbls Barazan, 30 bbls Dirt Magnet, & 45 bbls Barazan. Circ around w/seawater. Hole swept with slug - 150.00 % hole volume Flow check Facility M Pt L Pad Progress Report Well MPL- 16A Page Rig Nordic3 Date 8 30 November 99 Date/Thne 30 Oct 99 31 Oct 99 03:30 03:30-06:00 06:00-20:30 06:00-06:30 06:30 06:30-20:30 20:30 20:30-06:00 20:30-06:00 20:30-06:00 06:00-08:30 06:00-08:30 08:30 08:30-16:30 08:30-09:00 09:00 09:00-09:30 09:30 09:30-12:30 12:30 12:30-16:30 16:30 16:30-18:30 16:30-18:30 18:30 18:30-22:30 18:30-22:30 22:30 22:30-23:30 22:30-23:30 23:30 23:30-00:00 23:30-00:00 00:00 00:00-06:00 00:00-02:00 Duration 2-1/2 hr 14-1/2 hr 1/2 hr 14hr 9-1/2 hr 9-1/2 hr 9-1/2 hr 2-1/2 hr 2-1/2 hr 8hr 1/2 hr 1/2 hr 3hr 4hr 2hr 2hr 4hr 4hr lhr lhr 1/2 hr 1/2 hr 6hr 2hr Activity down. Observed well static Laid down 2200.0 fl of 3-1/2in OD drill pipe 3-1/2in. Communication test string workstring run (cont...) Serviced Travelling block Service rig, top drive, crown and blocks. Equipment work completed Laid down 11000.0 ft of 3-1/2in OD drill pipe 330 joints laid out Electric wireline work Conducted electric cable operations POOH & R/D Schlumberger Conducted electric cable operations Made first trip to 7670'. Unable to pump down. POOH PU additional weight bar and rollers. 2nd run made it to 12670'. Log up while pumping 2 BPM.Leak found in liner top packer/hanger. POOH. Electric wireline work (cont...) Conducted electric cable operations (cont...) Made first trip to 7670'. Unable to pump down. POOH PU additional weight bar and rollers. 2nd run made it to 12670'. Log up while pumping 2 BPM.Leak found in liner top packer/hanger. POOH. Completed logging run with Spinner from 12900.0 ft to 9930.0 fl Run Tubing, 3-1/2in O.D. Serviced Top drive Equipment work completed Removed Bore protector Equipment work completed Flow check Monitor well flowed back 17 bbls. Observed well static Ran Tubing to 2235.0 fl (3-1/2in OD) Run 3.5" NSCT kill string to 2235' Hanger landed Nipple down BOP stack Rigged down BOP stack N/D B OPE Equipment work completed Wellhead work Installed All tree production valves T.P. Adaptder to 5000 psi. T.P tree to 5000 psi Equipment work completed Fluid system Freeze protect well - 84.000 bbl of Diesel Pump 59 bbls diesel down annulus taking returns f/ tbg. Close tbg and inject 25 bbls down annulus. Completed operations Wellhead work Installed Hanger plug Equipment work completed Move rig Rigged down Drillfloor / Derrick Jack up rig move off well, P/U pit liner & clean up RECEIVEI G~ Cons. Anchorage Facility M Pt L Pad Progress Report Well MPL- 16A Rig Nordic3 Page 9 Date 30 November 99 Date/Time 02:00 Duration Activity Equipment work completed RECEIVED ~E¢ ~ 1 1999' Alas~ 011 & Gas Cons. comm~ Anchorage Oil Re: Milne Point Request for verbal approval of ¢----)pe of work for MP L-16ai ¢ Subject: Re: Milne Point Request for ~rbal approval of Scope of work for MP L-16ai Date: Mort, 29 Nov 1999 16:20:59 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Laule, Robert B" <LauleRB@BP.com> CC: Blair Wondzell <blair_wondzell@admin.state.ak. us>, John Crisp <john_crisp@admin.state.ak. us>, Lou Grimaldi <lou_grimaldi@admin.state.ak. us> Bob, Thanks for the note regarding the newwork on L-16Ai. We look forward to receiving the paperwork tomorrow as you indicate. In the meantime, ~u have approval to begin the work as you outlined. As noted in our call, please notify the slope inspectors so they may witness the BOP test. Thanks. Tom Maunder Petroleum Engineer AOGCC "Laule, Robed B" wrote: Scope: for the repair and completion of Milne Point Weft L-16ai official 403 to follow tomorrow. 1. MIRU Work Over Rig 2. Pull BPV. 3. Circulate and bullhead kill well. 4. Set TWC. 5. ND Tree, NU BOP and test. 6. Retrieve kill string. 7. PU liner straddle assembly, setting tool and collars. 8. RIH vcth straddle assembly on 3-1/2" DP. 9. Locate straddle in liner hanger to liner XO and sgt Iower packoff with 40, 000 # down weight. 10. Pressure up to l O00psi to confirm straddle location. 11. Drop ball for ~tting tool if necessary chase ball to bottom with wireline. 12. Set upper packer ,release setting tool. Slack off 50,000# on packer. 13. Test casing and straddle to 4500 psi. POH. 14. Run 3-1/2" packer completion. 15. Instafl TWC. ND BOP and NU and test the tree. 16. Freeze protect annulus. Set packer and test. Test to be witnessed by AOGCC. RDMO Work Over Rig. Tom Maunder <tom maunderC, admin.state.ak, us> Petroleum Engineer IAlaska Oil and Gas Conservation Commission I of 2 11/30/99 8:08 AM d rvices riiling BP Exploration / ARCO Alaska Inc. MPL-16Ai Suspension Report Nordic 3 Mr. Wondzell/Maunder: This letter is in regards to the condition in which we have suspended MPL-16Ai and the remedial plan forward. The condition of the well and the plan forward have been discussed previously via Brent Reeves with AOGCC (Blair Wondzell) on 10/30/99 at 11:45 am, at which time received verbal approval as follows: Condition update to AOGCC: Nordic 3 had just completed running spinner surveys and confirmed that leak was in the liner hanger equipment. The well is static with SW completion fluid. All indications are that the integrity of the cement job will satisfy the injection requirements and we will confirm cement compliance prior to injection. Plan forward ' To Temporarily suspend the well in order for us to develop repair plans for either CTU or N4ES. To run a 3-1/2" kill string (2,234'+_) and freeze protect below the permafrost +1900 tvd. Install and test tree and leave well with BPV in hanger prior to moving the rig. STATE OF ALASKA ALASKA u~L 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 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 3604' NSL, 5148' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 433' NSL, 4855' WEL, SEC. 33, T14N, R10E, UM (As Planned) At effective depth 431' NSL, 351' EWL, SEC. 33, T14N, R10E (Not Final) At total depth 445' NSL, 342' EWL, SEC. 33, T14N, R10E, UM (Not Final) . Datum Elevation (DF or KB) Plan KBE = 46.6' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-16Ai 9. Permit Number 199-90 10. APl Number 50- 029-22566-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 13435 true vertical 7480 Effective depth: measured 13345 true vertical 7392 Casing Length Structural Conductor 80' Surface 9012' Intermediate Production 15834' Liner 3423' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" 9-5/8" ii 4-1/2" 250 sx Arcticset I (Approx.) 1740 sx PF 'E', 250 sx 'G', 132 sx PF 'E' 275 sx Class'G' (Top of Window) 170 sx Class 'G' MD TVD 80' 80' 9048' 4510' 10191' 4888' 10009' - 13432' 4830' - 7477' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) ORIGINAL Kill String: 3-1/2", 9.3#, L-80 to 2234' Packers and SSSV (type and measured depth) ..... ?,.s' Con,., 5" x 7" ZXP Tieback Packer at 10009' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: October 31, 1999 16. If proposal was verbally approved [] Oil [] Gas [] Suspended Blair Wondzell 10/30/99 Service Name of approver Date approved Contact Engineer Name/Number: Prepared By Name/Number: ,~,,~. Mik Trio/o, 56~74 17. I hereby certify that th~foretC~ing i~.r~e~n'=~d correct to the best of my knowledge · % · '. / ~.,. - .~ S~g.~ed I;~¢,.(~.~,,~&~ /~. , · ~' CharlesMallary f ~/f'~:~'~-'~-"--'-..~ Title Senior Drilling Engineer /"L~ --) Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test__ Location clearance __ Terrie Hubble, 564-4628 Date I Approval No. ~,~ ~'~,:2~ t~ Mechanical Integrity Test Subsequent form reauired 10- ~-"~..~'~ ORIGINAL SIGNED BY ,~,~,o~o,!ed ~o,0%' · . . - r~¢- ., ~f~.,~,~ f/ Approved by order of the Commission Robert N. Chnstenson ~,¢t; ~, ~f,j I Commissioner Form 10-403 [:lev. 06/15/88 Date /~-/)-~1 Submit In Triplicate Wellhei~d: 11" 5M FMC Gen. 5 w/11" x 3.5" NSCT Tbg. Hng., 3.5" NSCT threads top and bottom, 3" ClW "H" BPV profile MPL-16Ai ACTUAL SUSPENSION Cellar Box Elevation' 16.6' Rig RKB Elevation: 30.00' 20" Conductor 31/2", 9.3#, L-80, NSCT circ string I 2,234' 9 ~/8", 4o#/~, ~.8o aTC. I ~,o~' I II 7 , 26#, L-80, BTC of Section Milled Window 110,191'1 Top DIRECTIONAL PLAN (PROPOSED PLAN 5A) KOP (~ 10,195' Max. hole angle - 70° at KO Window 41/2 ", 12.6#/ft, L-80 110,009'1 7" x 5" Baker ZXP Liner Hanger Pkr 0,200'I Cement KO Halliburton EZSV 5,2391 Baker PBR Seal Assy. BOT 7" S-3 Packer 5,362'I BOT 7" SAB-3 Packer Theoretical TOC: 11,800' md WLEG PBTD DATE REV. BY 11/~99 MTT HOLE ANGLE at TD: 8.5 o PBTD TD COMMENTS Actual Suspension 13,345' 13,435' MILNE POINT UNIT Well L-16Ai APl No: 50-029-22566-0.1, BP EXPLORATION Correction: Milne Point Well L-16Ai .---~ ? c) ,. C)L) C,) Subject: Correction: Milne Point Well L-16Ai Date: Fri, 29 Oct 1999 20:41:10 -0400 From: "Mallary, Charles R (ARCO)" <MallarCR~BP.corn> To: "'blair_wondz¢ll~admin. stat¢.ak.us"' <blair_wondzell~admin.state.ak.us> CC: "Cocking, David A" <CockingD~BP.com>, "Reeves, T Brent" <RecvesTB~BP.com>, "Triolo, Mike T" <TrioloMT~BP.com>, "Collins, Patrick J" <CollinsP~BP.com> Mr. Wondzell, It was just pointed out to me that I referenced the wrong well in my previous email. I am referring to well L-16Ai, not C-12Ai. I apologize for any confusion this may have caused. Chuck Mallary Sr. Drilling Engineer, WNS/ENS Shared Services Drilling (907)564-5061 From: Mallary, Charles R (ARCO) Sent: Friday, October 29, 1999 4:35 PM To: 'blair wondzellSadmin.state.ak.us' Cc: Cocking, David A; Reeves, T Brent; Triolo, Mike T; Collins, Patrick J Subject: Milne Point Well L-16Ai Importance: High Mr. Wondzell , The purpose of this email is to update you regarding our forward plans on Milne Point well L-16Ai. At this writing, the 4-1/2" liner has been run and cemented in place. The liner top packer and 7" casing have been successfully pressure tested to 4500 psi. We have determined that a leak is present somewhere between the 4-1/2" liner hanger and the liner shoe. Our forward plan this weekend is to run a spinner log to ascertain the location of the leak. This log will also help us to determine if remedial work is required and whether or not it can be performed through 3-1/2" completion tubing. If we determine that (a) the leak requires repair and (b) the repair can be accomplished through tubing, then we plan to run the completion tubing and move the drilling rig off the well. Remedial work would then ensue through tubing. If we determine that (a) the leak requires repair and (b) the repair cannot be accomplished through tubing, then we plan to move the rig off without running the completion tubing. Post rig remedial action would thus precede running the completion tubing. regards, Chuck Mallary Sr. Drilling Engineer, WNS/ENS Shared Services Drilling (907) 564-5061 1 of 2 11/19/99 9:52 AM TON Y KNO WL ES, GO VERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 29. 1999 Charles Mallarv Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Milne Point Unit MPL-16Ai BP Exploration (Alaska) Inc. Permit No: 99-90 Sur Loc: 3604'NSL. 5148'WEL. Sec. 8. T13N. R10E. UM Btmhole Loc. 561'NSL. 49195,VEL, Sec. 33, T14N. R10E. UM Dear Mr. Mallarv: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. enson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. , -- STATE OF ALASKA .... ALASKA',..,,L AND GAS CONSERVATION COk ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work l-] Drill I~Redrill lb. Typeofwell I'-IExploratory r-IStratigraphicTest I--IDevelopmentOill [] Re-Entry [] Deepen []Service I'"i Development Gas [-ISingle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 46.6' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355017 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3604' NSL, 5148' WEL, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 433' NSL, 4855' WEL, SEC. 33, T14N, R10E, UM MPL-16Ai At total depth 9. Approximate spud date Amount $200,000.00 561' NSL, 4919' WEL, SEC. 33, T14N, R10E, UM 10/02/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047434, 561'I No Close Approach 4480 13364' MD / 7458' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 10200' MD Maximum Hole Angle 70° Maximum surface 2200 psig, At total depth ('FVD) 7215' / 3060 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3320' 10045' 4844' 13364' 7458' 367 sx Class 'G' 19. To be completed for Redrili, Re-entry, and Deepen Operations. Present well condition summary TOC f/Abandon Perfs: 15298' Total depth: measured 15910 feet Plugs (measured) TOC f/Kick Off Plug: 10173' - 10450' (EZSV) true vertical 7716 feet Effective depth: measured 15779 feet Junk (measured) true vertical 7613 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 80' 80' Surface 9012' 9-5/8" 1740 sx PF 'E', 250 sx 'G', 132 sx PF 'E' 9048' 4510' Intermediate Production 15834' 7" 275 sx Class 'G' 15867' 7685' Liner (Section Milled 10184' - 10235') .. measured Sqzd: 15478'-15601'ORIGINAL -"_,' .... . Perforation depth: true vertical Sqzd: 7376' - 7472' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch ... [] E)rilling Program.: [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC'25.05ORequirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Torrid Hubble, 564-4628 21.1 hereby,ce~if~/'~..a.tjuhe f~'~ng is true and correct to the best of my knowledge Signed k,~ ../~.,.' Char,~Ma,.a~y Title Senior Drilling En~lineer Date / ~ Commission Use Only Permit¢~j~be~,/..~ I APl Number Approval Date See cover letter "I 50-029-22566-01 ~ ~ r~" ~ 4¢ for other requirements Conditions of Approval: Samples Required []Yes I~'No Mud Log Required []Yes ,~No Hydrogen Sulfide Measures []Yes [~No Directional Survey Required J:~[Yes~[] No Required Working Pressure for BOPE I--I 2K; ,l~r3K; I-I 4K; I--I 5K; I-I 10K; I--I 15K Other: ORIGINAL SIGNED t~Y by order oft,~,~"~ Approved By I~r~t-u:~_rt N. 6hristen$on Commissioner the commission Date 77 Form 10-401 Rev. 12-01-85 Submit In Triplicate FWell Name: I MPL-16Ai Well Plan Summary Type of Well (producer or injector): Surface Location: Target Start: Intermediate Target End: I IWAG Injector 3604' NSL, 5148' WEL, Sec. 8, T13N, R10E, UM X = 544,729.51 Y = 6,031792.71 433' NSL, 4855' WEL, Sec. 33, T14N, R10E, UM X = 550,231.00 Y - 6,039,217.00 Z = 7,150' TVDss 561' NSL, 4919' WE[L, Sec. 33, T14N, R10E, UM X = 550,165.88 Y = 6,039,344.27 Z -- 7,412' TVDss I AFE Number: I 337161 I I Rig: I Nordic 3 Estimated Start Date: I Oct. 2, 1999 I I Operating days to complete: I 14 IMD I 13,364'I ITvDrkb: I7,458' I I KBE: 146.60' IWell Design (conventional, slim hole, etc.)' IConventional Sidetrack Injector Objective: Sidetrack out of existing 7" csg into the Seabee Formation, directionally drill 6 1/8" hole thru HRZ, Kalubik, Upper Kuparuk formations to Kuparuk 'A' sands target, TD well 180' into the Miluveach Shale Formation. Run, cmt and test 4 1/2" solid liner, complete with 3 W', L-80, premium thread tubing. Current Well Information Well Name: APl Number: Well Type: Current Status: Last H2S Sample: Cement: TD / PBTD: BHP: BHT: Is this well frac'd? Mechanical Condition: MPL-16 Wellhead: Nordic 3: Tubing: Liner: Casing: Casing Head: Casing Hanger: 7" Packoff: Tubing Head Adapter: Tbg. Hanger: Tree: Open Perfs: Tubing Fluids: Annulus Fluids: MP L-16 50-029-22566 IWAG Injector P & A'd all open perforations by CT. Section Milled the 7" casing from 10,184' to 10,235' by Nabors 4 ES TOC tagged at 10,173', spotted 200' below bottom of window by 4 ES 0 ppm TOC outside the 7" casing, estimated by volume calculation 13, 567'. 15,867' / 15,779' MD 3,000 psi Kuparuk'B' Estimated from offset wells 170°F@ 7,500' ss Estimated No Cellar Box MSL = 16.6' KB / MSL -- 46.6' 3-1/2", 9.3# L-80 NSCT Tubing None Conductor: 80', 20" conductor pipe Intermediate: 9, 048', 9-5/8", 40#, L-80 BTC Production: 15,867', 7", 26#. L-80, BTC FMC 11" 5M FMC 7" mandrel Tested to 5000 psi during pre-rig work (Mandrel hanger) FMC 11", 5M x 3 1/8" A-5-EC FMC 11" x 3 ¼" NSCT TC-E-BC C.I.W. 'H' type BPV profile Cameron 5M, 3 1/8" P&A'd on pre-rig. Seawater with diesel cap down to -2000' Seawater with diesel cap down to -2000' A a_al ka are. d .ces r, ll,ng BP Exploration / ARCO Alaska Inc. MPL-16Ai Conventional Sidetrack Injector Nordic 3 AFE Number: 337161 Days: 14 Estimated Spud: October 2, 1999 AFE Amount: $1.829M Prepared By: Bob Kaluza FOUR OBJECTIVES FOR WELL: 1. NO ACCIDENTS 2. NO SPILLS OR ENVIRONMENTAL VIOLA TIONS 3. NO POLICY OR REGULATORY VIOLATIONS 4. MEET OR EXCEED COST AND QUALITY OBJECTIVES No portion of this work is so urgent that the time cannot be taken to do it without injuring yourself or others Approved By: Ops. Drilling Engineer Date Distribution: D. Cocking - MB 5-1 C. Mallary - MB 5-1 Fred Johnson - MB 5-1 Field Geologist Team Leader - MB 4-1 BPX Drilling Stores - N/S J-1 Well File Rig Nordic 3 Sperry Sun - Mail Slot Baker- Mail Slot Baroid - Mail Slot Dowell- Mail Slot Nordic- Mail Slot MPU-Well Ops Coordinator Contacts Drlg. Superint. Sr. Drlg. Engr. Ops. Drlg. Engr. Co. Rep. Geologist Reservoir Engr. Name Dave Cocking Chuck Mallary Bob Kaluza Paul Lockwood Katie Nitzberg Brian Huff Senior Drilling Engineer Date 21 Copies, 1 original 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy & E -Mail Original 8 Full copies 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy 1 Copy Work 564-5219 546-5026 546-5486 564-4531 564-5110 Pager 275-4356 275-0157 275-1014 Drilling Superintendent Date Attachments: Sundry Permit Drilling Permit Baroid Mud Program Directional Plan Proposed BHAs Statement of Requirements Original Tubing Detail Original 7" Liner Detail Original 9-5/8" Casing Detail Gyro Survey's Kick Tolerance Geological Cross Section(s) Depth - Time/Cost Curves Wellhead Description Emissions summary Home 348-6683 345-7848 563-9059 348-8903 345-3899 345-9484 Cell Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Materials Needed: L-80 Intermediate: Injector to sweep 1,290 MSTBO Injection rate 'most likely': 1,500 b/d L-80 Production: L-80 Completion: 3,315' 7" x 4-1/2" 4-1/2" 4-1/2" 30 - 4-5/8" x 8 1/4" 10,000' 7"x 3-1/2" Will run 'X' nipple 1 -3W' 2 - 3-1/2" 3-1/2" 2 Each - 3-1/2" 4.5", 12.6#, L-80, IBT-Mod liner Baker liner top hanger / packer Halliburton float collar Halliburton HPDJ float shoe Rigid Centralizers 3.5", 9.3#, L-80 NSCT tubing Baker 'S-3' production packer SSSV, NSCT threads 'XN' nipple 'X' Nipple WLEG t0', 8', 6', 4', 2' NSCT space out pups Drilling Hazards and Contingencies 1) Well Control MANDITORY WELL CONTROL DRILLS: · D1 and D2 drills should be held at least once per week per crew as appropriate. · D1, Should only be conducted inside the casing string. · D2, May be conducted either in cased or open hole - if done in open hole THE WELL WILL NOT BE SHUT IN! · D3, Should be completed before spudding the well and with each crew during the tophole section of the well · D4, Should be conducted prior to every well spud or workover, and at least every 30 days in the event of rig stacking or delays to the program. It should also be implemented if intrusive work has been carried out on the accumulator or its associated system. · D5, Should be carried out prior to drilling out or working in the intermediate or production casing strings, IT SHOULD NEVER BE IMPLEMENTED WHEN FORMATIONS ARE OPEN TO THE CASING (i.e. perfs damaged casing or open hole.) · IN ALL CASES, ENSURE THAT THE DRILLS ARE CAREFULLY CARRIED OUT AND DO NOT EXPOSE EQUIPMENT, CASING OR FORMATION TO EXCESSIVE PRESSURES AND LOADS. 2) Hydrogen Sulfide · MP L Pad is not designated as an H2S Pad. 3) Kick tolerance · The kick tolerance for the 6 1/8" open hole section would be 38.6 bbls assuming an influx at the 12,640' at the top of the Kuparuk formation. This is a worst case scenario based on a 9.0 ppg pore pressure gradient in the top of the production section and a fracture gradient of 12.0 ppg below the 9 5/8" surface casing shoe with a 9.2 ppg mud in the hole. 4) Breathing · There has been several instances of 'breathing' under L pad. On Well L-25 'breathing' occurred in the HRZ and Kalubik shales, Well L-21i 'breathing' occurred in the Kuparuk 'A' sands and 'breathing occurred on Well L-28. 'Breathing' occurred while milling the section on this Well. Read and follow the 'breathing' RP to handle any 'breathing' problems. 5) Lost Circulation · There is a high potential for lost circulation in the L-pad area. The Kuparuk and other shallower zones are highly faulted. Lost circulation while cementing production liners has been a problem on many wells. · Follow the LOST CIRCULATION DECISION MATRIX if fluid losses occur while drilling. Break circulation slowly and get up to recommended circulating rate slowly prior to cementing. 6) Faults · This Well is sub-parallel to a fault within the target interval. Do not cross into MPL-21 fault block (approx. 400' standoff from planned TD), it is high pressured to > 5,000 psi.. 7) Hydrocarbons · Will be kicking off in the Seabee interval, therefore the first hydrocarbon zone will be the Kuparuk 'C' sands at @ 12,850" MD, 6,965' TVDss. 8) Unexpected High Pressures · It is unlikely there will be unexpected overpressure when drilling into the Kuparuk formation on this well but them is a possibility of encountering unexpected higher pressures due to injection well communication under L pad when drilling into the Kuparuk Zone. Hold a D2 kick drill prior to drilling into the Kuparuk Formation. 9) Shale Sticking and Bit Bailing · Possible bit bailing problems in the lower Seabee due to high clay content. One technique to get the bailing off the bit, is to PU off bottom about one foot and rotate the bit at over 100 RPM's. Possible shale sticking problems in the Kalubik and 'D' shales under 'L' pad and also possible shale sticking problems drilling the rat hole in the Miluveach Shale. If shale sticking does occur use whatever time necessary to circulate the hole clean, wiper trip through the shale if needed and condition the mud as needed. 10) Pad Data Sheet · Please Read the Pad Data Sheets Thoroughly. Drilling Program Overview Surface and Anti-Collision Issues Surface Shut-in Wells: Well L-20 will need to be shut-in for rig move on and off the L-16Ai well. · Well L-20 (north) is spaced 30' from MP L-16Ai. Close Approach Wells: NONE - All wells may flow. Well NameNone I Current Status I Pr°ducti°n Pri°rity IPrecauti°ns I Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 3,000 psi, 7,060' TVDss (estimated) Max Exp Surface Pressure 2,200 ps~ (.115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (entire stack & valves) Planned BOPE Test Pres. 3,500/250 psi Rams and Valves 2,500/250 psi Annular Mud Program Production Mud Properties: LSND I 6 1/8" hole section Density (ppg) J Funnel vis I YP I HTHP pH 9.2 - 9.6 35 - 45 10 - 20 10 - 12 8.5-9.0 APl Filtrate I Solids 4-6 J <6% NOTE: See attached Baroid mud recommendation LCM Restrictions: None Waste Disposal: Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready Formation Markers Formation Tops MD TVDss Pore Psi EMW (ppg) Comments THRZ 12,435 6,660 Possible 'breathing' in the HRZ and MK-19 BHRZ 12,554 6,700 MK-19 12,640 6,750 TKUD 12,799 6,915 Possibility of encountering unexpected high TKUB 7,060 3,000 8.17 pressure entering the Kuparuk Sand TKUA 13,067 7,150 3,025 8.14 TKA3 13,079 7,160 3,030 8.14 TKA2 13,101 7,180 3,040 8.14 TKA1 13,141 7,215 3,060 8.16 M iluveach 13,215 7,270 Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 6 1/8" -4 1/2" 12.6# L-80 IBT-Mod 3,320' 10,045'/4,844' 13,36477,458' Tubing 3 1/2" 9.3# L-80 NSCT 10,015' 30?30' 10,045'/4,844' Cement Calculations ILiner Size 14 Y2" IBT-Mod I Basis 80' shoe jts, 30% excess in open hole (6 1/8" hole), 150' liner lap (7" casing) & 200' above liner top (3 W' dp) I u 13,364' MD (7,458 TVDrkb), Window at 10,195' (4,889'), Liner top at 10,045' (4,839') TOtal CementVolume: I Spacer I 30 bbls of B45 Viscosified Spacer Weighted to '5 PPg above mud weight' Tail 367 sxs, Class 'G' + .37%D65 + 3%D53 + .1 gps D135 + 2.0 gps D600 + 0.14% D800 + 0.2 gps D47 Temp BHST-170° F from SOR, BHCT 130° F estimated by Dowell Centralizer Placement: 1. Run (1) rigid straight cetralizer per joint first 1,000'. 2. Do not run stop collars, let the centralizer slide on the casing joint. Other Cement Considerations: 1. Mix all slurries 'on the fly'. Survey and Logging Program 6 1/8" Section: Open Hole: MWD I GR / Res / PWD - Over entire interval. Ask for temperature / depth surveys from Sperry. Will use temperature information for future well planning. Sample Catchers - None required Cased Hole: CCL / GR / CBT - static pressure Perforating: Will be perforated Post-Rig via CT conveyed 2 ½" guns. AFE'd for 250' of guns. Locations Perf Interval: Gun Size / Type: Delivery: Under Balance: BHP: BHT: Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzle / Flow Rate K-Rev's Hours Number and Section 1 6 1/8" 10,200' - 12,000' STR-03D 13-13-13: 250+ gpm 300-350 30 2 6 1/8" 12,000'- 13,364' STR-09D 12-12-12: 250+ gpm 300-350 35-40 PDC Bits: May run PDC bit as the second bit rather than the STR - 09D. Motors and Required Doglegs BHA Motor Size and Motor Flow Rate RPM's Required Doglegs Number Required 1 4 %" Sperrydrill 7/8, 2.2 stg Slow 250 - 300 gpm 75 mtr, 50 rotate 6° drop out of the window Speed, 1.15° adj w/5.8" pad 2 4 %" Sperrydrill 7/8, 2.2 stg Slow 250 - 300 gpm 75 mtr, 60 rotate Hold 29° tangent to TD (insert) Speed, 1.15° adj w/5.9" sleeve 3 4 %" Sperrydrill 4/5, 6.3 stg Slow 250 - 300 gpm 75 mtr, 60 rotate Hold 29° tangent to TD (PDC) Speed, 1.15° adj w/5.9" sleeve MPL-16Ai Operations Summary Pre-Rig Operations 1. WSA P & A'd all open perfs prior to 4ES rig move. 2. MIRU Nabors 4ES 3. ND Tree, NU Stack and Test. 4. POOH w/3 ¼" tbg. to 15,230'. Spotted 10.2 ppg mud pill to 10,450'. (PBR sheared at 15,239') 5. Cont. POOH, laid down old tbg. NORM inspected. Saved 80 its to be left in hole for circulating string. 6. Tested casing to 3,500 psi. 7. Set EZSV on DP @ 10,450' and tested to 2,000 psi. 8. Displaced wellbore to milling fluid, spotted 18 ppg mud pill from EZSV to 10,250'. 9. RIH with BOT 7" milling assy. Mill 51' section from + 10,184' to 10,235'. 10. Spotted cement plug from 100' below section to 200' above section. Hesitation squeezed. 11. POOH 12. WOC. RIH tag cmt top (hard top at 10,173'). POOH 1000'. Tested casing to 1,228 psi. (13.0 ppg EMW) 13. RIH w/2,400' 3 ½" circulating string. Freeze protected. Landed hanger. 14. ND BOPE, NU Tree & Test. Move off. Snapshot of Well Proqram 1. MIRU Nordic3 2. Circulate out freeze protect, pull and lay down the 3 ¼", 2,400' circulating string. 3. MU 6 1/8" BHA #1, RIH tag cement, dress cmt to KO point, KO drill to bit exhaustion. 4. MU BHA #2, drill to planned TD. Need 150' rat hole in Miluveach. 5. Run, cement and test 4 W' liner. 6. Run E-line CBL. 7. Run and test 3 %" NSCT completion assy. 8. ND BOPE, NU tree, Move to MPC-12Ai. 9. Perforate Post Rig Release Wellhead:FMC Gen 5 wi 11" 5 M thru bore system. Hanger: 11" x 3.5" NSCT hng. w/3" CIW - H BPVT Tree: 11" x 3 1/8" ESP adapter (dummied off ) and 3 1/8" 5M valves / cross / cap Actuaton3 1/8" 20" Conductor 9-5/8" 40 ppf L-80 BTC 9048' MD KOP - 400', "S" shape profile Max. hole angle - 67-72 deg. from 2876' to 13,260' MD Hole angle across perfs. = 38 deg. MP L-16i Decompletion Orig. KB elev. - 51.72' (Nabors 27E) Orig. DF elev. = 50.22' (Nabors 27E ) GL. elev. =16.6' 2,400' I 3.5", 9.3 ppf, L-80, NSCT tbg. MD I Circulating/Kill string 10,173' MD I Top of Hard Cement 10,184' - 10,235' MD I Section Milled Window Minimum ID in completion string is 2.75" no-go in tbg. tail 'XN' npl. 7", 26 ppf, L-80 btrc. production casing PERFORATION SUMMARY Ref. Log: AWS SBT / GR / CCL - 7/25/95 Gun SPF Interval (TVD) 4.5" 5 15,478'-15,601' (7383'-7481 ') 2.0 4 15,478'-15,601 Re-Perf 12/25/95 Alpha Jet charges, EHD = 0.48", TTP = 22.8" 10,450' MD J Halliburton EZSV 7" short joint from 15,150' to 15,170' wlm Baker 80-40 PBR Seal Assy. (20' eft. stroke) Baker 7" S-3 Packer HES 3.5" (2.81" PB)'X' npl. Two 0.25" equalization ports HES 3.5" (2.81" PB)'X' npl. Baker special overshot (swallow 3.5" chem cut stub) Baker 7" SAB-3 packer HES 3.5" 'XN' npl. (0.813" pb, 2.75" ng) I15,239' md I15,280' md I15,296' md 15,297' md 15,309' md 15,329' md 15,362' md 15,377' md 115~381' md WLEG Open perfs P&A'd via CT PBTD Casing shoe 15,779 MD I 15'867 MD I DATE REV. BY COMMENTS MILNE POINT UNIT 6/17/95 DBR/DMR 7" Casing Run ]~EJ.J,_J.~'- ' 11 / 24 / 95 JBF Initial Completion by Nabors 4 ES APl NO: 50-029-22566 09 / 07 / 99 RMK P&A via CT and Decompletion via 4ES BP EXPLORATION (AK) Wellhead: 11" 5M FMC Gen. 5 w/11" x 3.5" NSCT Tbg. Hng., 3.5" NSCT threads top and bottom, 3" ClW "H" BPV profile MPL-16Ai PROPOSED COMPLETION Cellar Box Elevation' 1 6.6' Rig RKB Elevation: 30.00' 20"Conductor I $0' I Note: The completion tubing will be used for IWAG service. 31/2", 9.3~, L-80, NSCT 9 5/8", 40#cfr, L-80 BTC. 19,048' I 7", 26:~, L-80, BTC 2,000' 9,973' [ I 9,993' I Top of Section Milled Window [ lO, 184'I DIRECTIONAL PLAN (PROPOSED PLAN 5A) KOP (i~ 10,195' Max. hole angle = 70° at KO Window Hole angle thru' perfs = 29° 41/2 ", 12.6#¢ft, L-80 IBT-Mud PERFOPA~ ZC~4E KUPARUK 'A' SANDS 31/2"'X' nipple, ID 2.750" 31/2" 'X' nipple, 2.750" ID ?'x 3 1/2" Baker Production Pkr 0,023' I 31/2" 'XN' nipple, 2.635" ID 1 lO,O45'I 7" x 4 1/2" Baker Liner Hanger Pkr Note: 3 1/2" WLEG will be stabbed into the 4 1/2" liner top. [ 10,200' [ Cement KO Halliburton EZSV 15,239'I Baker PBR Seal Assy. BOT 7" S-3 Packer [ 15,362'[ BOT 7" SAB-3 Packer DATE 8/13/99 REV. BY RMK HOLE ANGLE at TD: 29 o COMMENTS Pro )osed Com )letion PB-rD J 13,28o' J TO 13,364' MILNE POINT UNIT Well L-16Ai APl No: 50-029-~56601 BP EXPLORATION I DrillQuest' Current Well Properflel ReL ~ Coor~nales: 6031792.71 N, 54472g.51 E Re~. ~xuc~um Re~-~: 1997_19 N, ZII~5 E Re~. Ge~grap~k~ ~: 70' Zg' 51.8250' N, 149' 3~' 03.1738' W Reference: True Nor~ : Feel I .Single Well Target Data for MPL-16Ai WPs J MPL-16Ai TI EnL~ Po~t 71 ~0.1~ 71~.60 739l.O N 5546.07E N)39217.00 N 550231.0~E gRAFT ONLY Ch:lc J 7600 - 7200 - c~ 6800 - 0 Z 6400 - 6000 - 5600 - Scale: linch = 400ft 5200 I Eastings 5600 6000 6400 I I I 6800 Ltner- 13383.88 MD, 7458.23 TVD : 13363,88fl MD, 7458.23ff TVD 5200 Scale: linch = 400ft ~' m ...%/ .,~ '"Tie-On, S(att git O 6.000'llO0ft: 10200.OOft MD, / , , , I ../ 5600 6000 6400 6800 Eastings Reference is True North - 7600 - 7200 - 6800 m 0 Z - 6400 - 6OO0 II - 56oo 8 Shared Services Well: MPL-16Ai Wp5 I DrillQuest MPL-16Ai WP$ 6031/92.71 N, 544~r2~.5t E 1992.19 N. 211.95 E 70' 2g' 51.8250" N, f4~ 3~ 03.1~38' W 46.60fl abe~e St'uc~re Refen~ce Tree N~lh RAFT ONLY P~posal Data for MPL-I~AI Wp5 ._ Vedical ~ De~: MPL-16N Vett~al Secion ~: 0.00 N,0.O0 E 102O0.{X) 70,1614:$.i:$8 4891.7~ ~969.2.3 N 5~:~4 J~9 E 81~.71 I 1~7.t8~ ~ ~1831 ~.~N ~ E 8~.~ 6.~ 13~.~ ~ ~ 71~.~ ~1.~ N' 5~.~ E 9~.~ 0.~ 13213~ ~ ~32~ ~ 7~.48 N 5514.10 E 9~.~ 0.~ 13~ ~ ~3~ 74~ 7518.71 N 5~1 .~ E 9~.~ 0.~ 4800 - 5200 - 5600 - 6ooo - 6400 - ~7200 11267.18ff MO, 5~18.31ft TVD Ba~[, IIRZ- 674~.~¢1 TI.'D MK[9 - 6821.fd1 TVD TK(/D- 69~1.61l TKUC- 7fl86.~1 TI'O ........... TKU.4 - 7 I96. fdt TrD ...TK.,L! - 7~fl6~l TI'D ................................................ MPL'-I~gtfTI'.'t'~3~# ................ TK/12 722n.~ TI'D .................................................. Yl~14~'/'F'O ................................. TK.41.72fU.~I Ti'D ................................................. 7'~'9'l"eJ'h'"J"J'~"qT"~"" MILUYE4Cll- 7.~2n.f~l TI/D : 13383.88fl MD, 74.58.2:3ft TVD "~ ~ i t i - 8000 8400 8800 9200 9600 Scale: linch = 400ft Vertical Section section Azimuth: 36,095° (True Nodh) Sperry. Sun Drilling Services Proposal Report for MPL-16Ai WPs - MPL-16Ai Wp5 Revised: 23 August, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10200.00 70.161 45.158 4845.13 4891.73 10300.00 65.022 41.807 4883.25 4929.85 10400.00 59.965 38.164 4929.43 4976.03 10500.00 55.018 34.134 4983.17 5029.77 10600.00 50.222 29.594 5043.88 5090.48 10700.00 45.629 24.387 5110.90 5157.50 10800.00 41.311 18.323 5183.49 5230.09 10900.00 37.370 11.177 5260.85 5307.45 11000.00 33.940 2.717 5342.15 5388.75 11100.00 31.193 352.791 5426.48 5473.08 11200.00 29.325 341.457 5512.92 5559.52 11267.18 28.654 333.250 5571.71 5618.31 11300.00 28.654 333.250 5600.51 5647.11 11400.00 28.654 333.250 5688.26 5734.86 11500.00 28.654 333.250 5776.01 5822.61 11600.00 28.654 333.250 5863.77 11700.00 28.654 333.250 5951.52 11800.00 28.654 333.250 6039.27 6 11900.00 28.654 333.250 6127.03 61 12000.00 28.654 333.250 6214.78 6261.38 12100.00 28.654 333.250 6302.53 6349.13 12166.46 28.654 333.250 6360.85 6407.45 12200.00 28.654 333.250 6390.29 6436.89 12300.00 28.654 333.250 6478.04 6524.64 12400.00 28.654 333.250 6565.79 6612.39 Local Coordinates Global .~:;o~[o'l~j[ates Northings Eastings Northings'~l~.~ings 6104.12 N 5785.52 E . 603~e~r.53 N 550478.19 E 6369.48 N ~~ 6038197.79 N 550627.30 E 6430.64 N __ i~[59~0~ 6038259.05 N 550643.20 E 6488.35 ¢ "~1 E 6038316.81 N 550650.07 E 6541.97 ~i~.. ~5957.78 E 6038370.42 N 550647.82 E N 5946.74 E 6038419.30 N 550636.48 E 2 N 5934.25 E 6038449.22 N 550623.81 E 5927.17 E 6038463.23 N 550616.64 E '9 N 5905.58 E 6038505.92 N 550594.80 E N 5884.00 E 6038548.61N 550572.96 E 6763.43 N 5862.42 E 6038591.30 N 550551.12 E 6806.25 N 5840.83 E 6038633.99 N 550529.28 E 6849.07 N 5819.25 E 6038676.68 N 550507.44 E 6891.89 N 5797.67 E 6038719.36 N 550485.60 E 6934.71N 5776.09 E 6038762.05 N 550463.76 E 6977.53 N 7005.98 N 5754.50 E 6038804.74 N 550441.92 E 5740.16 E 6038833.11N 550427.40 E 7020.35 N 5732.92 E 6038847.43 N 550420.08 E 7063.17 N 5711.34 E 6038890.12 N 550398.24 E 7105.99 N 5689.75 E 6038932.81 N 550376.40 E Alaska State Plane Zone 4 Milne Point MPL Dogleg Rate (°/~00ft) 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section (ft) 8160.71 8252.34 8340.78 8425.05 85O4.25 8577.49 8643.98 8702.99 8753.87 8796.07 8829.12 8846.00 8853.18 8875.06 8896.95 8918.83 8940.72 8962.60 8984.49 9OO6.37 9028.26 9042.80 9050.14 9072.03 9093.91 Comment Tie-on, Start Dir ¢~. 6.000°/100ft: 10200.00ff MD, 4891.73ft TVD End Dir: 11267.18ft MD, 5618.31ft TVD Sail ('~. 28.654° Inclination on 333.250° Azimuth Continued... September, ~999- 23:37 - 1 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPL-16Ai WPs - MPL-16Ai Wp5 Revised: 23 August, 1999 Prudhoe Bay Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 12500.00 28.654 333.250 6653.55 6700,15 12552.93 28.654 333.250 6700.00 6746.60 12600.00 28.654 333.250 6741.30 6787.90 12638.40 28.654 333.250 6775.00 6821.60 12700.00 28.654 333.250 6829.06 6875.66 12797.94 28.654 333.250 6915.00 6961.60 12800.00 28.654 333.250 6916.81 6963.41 12900.00 28.654 333.250 7004.56 7051.16 12940.38 28.654 333.250 7040.00 7086.60 13000.00 28.654 333.250 7092.32 7138.92 13065.73 28.654 333.250 7150.00 7196.60 13077.13 28.654 333.250 7160.00 13099.92 28.654 333.250 7180.00 13100.00 28.654 333.250 7180.07 13139,81 28.654 333.250 7215.00 13200,00 28.654 333.250 7267.82 13213.88 28.654 333.250 7280.00 13300.00 28.654 333.250 7355.58 13363.88 28.654 333.250 7411.63 7206.60 ~5.~ 7226.60 7226.67 ~4~.72 N 7261.60 7 N 7454.48 ~ 7491.36 N 7518.71 N Local Coordinates Northings Eastings (ft) (ft) 7148.80 N 5668.17 E 7171.47 N 5656.75 E 7191.62 N 5646.59 E 7208.07 N 5638.30 E 7234.44N 5625.00%~6039060.87N 7276.38N 5603.~039102.68N 7277.26N 5604~2~ ~i039103.56N 7320.08N ,~~ v6039146.25N 7337.37 N ~12~ 6039163.49 N 7362.90~ ~6E 6039188.94N 7391.05V5546.07E 6039217.00N Global~o~d~tes N o ~hi n g s'~.~l~tin g s 6~'8t~ 550354.56E ~89g~9~ 550343.00E 6~01~N 550332.72E 603~8N 550324.33E 550310.88 E 550289.49 E 550289.04 E 55O267.2O E 550258.38 E 550245.36 E 550231.00 E 5543.61 E 6039221.86 N 550228.51 E 5538.69 E 6039231.59 N 550223.53 E 5538.67 E 6039231.63 N 550223.52 E 5530.08 E 6039248.62 N 550214.82 E 5517.09 E 6039274.32 N 550201.68 E 5514.10 E 6039280.24 N 550198.65 E 5495.51E 6039317.00 N 550179.84 E 5481.72 E 6039344.27 N 550165.88 E Alaska State Plane Zone 4 Milne Point MPL Dogleg Ve~ical Rate Section Comment (°/100~) (~) 0.000 9115.80 0o000 9127.38 Base HRZ 0.000 9137.68 0.000 9146.08 MK19 0.000 9159.56 0.000 9181.00 TKUD 0.000 9181.45 0.000 9203.33 0.000 9212.17 TKUC 0.000 9225.22 0.000 9239.60 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 9242.10 9247.09 9247.10 9255.81 9268.99 9272.03 9290.87 9304.85 TKUA Tarqet- MPL-16Ai T1 200.00 Radius. ' TKA3 TKA2 TKA1 MILUVEACH Total Depth: 13363.88ft MD, 7458.23ffTVD 4 1/2" Liner Continued... 1 September, 1999 - 23:37 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPL-16Ai WPs - MPL-16Ai Wp5 Revised: 23 August, 1999 Prudhoe Bay Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPL-16Ai. Northings and Eastings are relative to MPL-16Ai. Magnetic Declination at Surface is 27.165° (23-Aug-99), The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPL-16Ai and calculated along an Azimuth of 36.095° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13363.8~"~ The Bottom Hole Displacement is 9304.85ft., in the Direction of 36.095° (True)...~~ Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10200.00 4891.73 5969.23 N 5664.89 E 11267.18 5618.31 6620.92 N 5934.25 12166.46 6407.45 7005.98 N 5740.1, 13363.88 7458.23 7518.71N Start Dir @ 6.000°/100ft: 10200.00ft MD, 4891.73ft TVD Dir: 11267.18ft MD, 5618.31ft TVD ',ail @ 28.654° Inclination on 333.250° Azimuth Total Depth: 13363.88ft MD, 7458.23ft TVD Alaska State Plane Zone 4 Milne Point MPL Continued... September, ~999 -23:37 - 3 - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPL-16Ai WPs - MPL-16Ai Wp5 Revised: 23 August, 1999 Prudhoe Bay Unit Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (~) (~) (~) (~) 12552.93 6746.60 6700.00 7171.47 N 12638.40 6821.60 6775.00 7208.07 N 12797.94 6961.60 6915.00 7276.38 N 12940.38 7086.60 7040.00 7337.37 N 13065.73 7196.60 7150.00 7391.05 N 13077.13 7206.60 7160.00 7395.93 N 13099.92 7226.60 7180.00 7405.69 N 13139.81 7261.60 7215.00 7422.77 N 13213.88 7326.60 7280.00 7454.48 N Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) <Run-TD> <Run-TD> Eastings (ft) 5656.75 E 5638.30 E MK19 5603.87 E TKUD 5573.12 E TKUC 5546.07 E TKUA 5543.61 E 5538.69 E,~lll~ T~ 5530.08 I~ T'~I 5514.10 E~%UVEAOH Formation N ame()~ Base HP, Z. etail f2" Liner Alaska State Plane Zone 4 Milne Point MPL Continued... September, ~999 - 23:37 - 4 - DrillQuest DATE [ CHECK NO. ~ H 1544G2 I VENDOR ALASKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0720c~c~ CK07209c~C 100. O0 100. O0 HANDL[NO IN~l: ~/H TEERI HUBRLE X4&28 i THE All'ACHED CHECK IS IN PAYMEm FOR IT~=: DESCRi~E.b ABOVE. ml[t]llF-'ll :~ 100. OO 100, O0 ' FiRsT':~ATIoNA:L BANK :bF ASHLAND i'' !' ;:Afd:~,I~IEIATF_.~ :::i:": ' · i:;:!:: ...... ':CJiEVI~.ND, 0HI° :' '::' 'ii :::;: ;' .:ii:i;":"i$~:389. :;"::,' :::i,,, :, :: ." 412 PAY ::'i :' :!i i:: : "' '':'!'':: NOTVALID AFT'ER 120 DAYS:'. : ':", ' ;::. · .. WELL PERMIT CHECKLIST COMPANY /'~/~ WELL NAME /¢~,,~__/_//~'"~7/ PROGRAM: exp ~ dev ~ redrll ..'~' serv __ wellbore seg ann. disposal para req __ FIELD & POOL ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ....... ..... 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING INITCLASS //-" /_.~,.'~ GEOLAREA Y N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ UNIT# .~'"/~,~.-~_ ON/OFF SHORE N N N N N N N N N N N N Y N N N N DATE GEOLOGY ANNULAR DISPOSAL APPR DATE 26. BOPE press rating appropriate; test to ~ 0OC) psig. (~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~.. N 28. Work will occur without operation shutdown ........... Y(.~ .1~ 29. Is presence of H2S gas probable ................. YNL 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N // 7~"''~''~/~ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. Y 33. Seabed condition survey (if off-shore) ............. /Y' N 34. Contact name/phone for weekly progress reports [exploratory only,]'Y N 35. With proper cementing r, C4cords, this plan ~ ~,r..4~ ~z(~, (A) will contain was_re i~a suitable receiving zo' ne; ....... (B) will not contamir)~te freshwater; or cause ddlling waste... to surface; (C) will not impair mechanical integr~used for disposal; · ' ' , fr~rn :~ (D) will not damage producing formatJon or imp~,, rccc;'cni ...... pool; and (E) will not circumvent 20 AAC 25.252 or~,O AAC 25.412. GEOLOGY_: ENGINEERIN.G: UI C/An_.~__.~ COMMISSION: JDH ~ CO ~ 'a/~3- Y N Y N Comments/instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi ,. No special 'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Mar 08 15:18:14 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NLTMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-90168 G. GRIFFIN P. LOCKWOOD RECEIVED MAR 09'2000 ~L-:].6A Anchorage 500292256601 BP Exploration (Alaska) Inc. Sperry Sun 08 - lVLA_,P. - 0 0 MAD RUN 1 AK-MM- 90168 G. GRIFFIN P. LOCKWOOD 8 13N 10E 3604 5148 45.93 45.93 16.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 10191.0 6.125 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING R~MARKS: 1. ALL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESSS OTHERWISE NOTED. 2. MWD RUN 10 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLE TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. A MADPASS WAS PERFORMED WHILE PULLING OF OF HOLE FROM 13031'MD (7084'TVD) 13292'MD (7340'TVD) . 4. MWD RUN 1 IS LABELED MWD RUN 10. MAD PASS 1 ON MWD RUN 1 IS LABELED MAD RUN 11. 5. DIGITAL AND LOG MWD DATA ARE DEPTH-CORRECTED TO THE PDC GR LOG OF 01/16/00 WITH KBE = 45.93' A.M.S.L. THIS WELL KICKS OFF FROM MPL-16A AT 10196'MD, ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUN 10 REPRESENTS WELL MPL-16A WITH AN API# 50-029-22566-01. THIS WEL A TOTAL DEPTH OF 13435'MD, 7480'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH "M#" SUFFIX DENOTES MADPASS (MEASUREMENT AFTER DRILLING) DATA. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP .5000 START DEPTH 10165.0 10186 0 10186 0 10186 0 10186 0 10196 0 10203 5 STOP DEPTH 13397.0 13401 0 13401 0 13401 0 13401 0 13401 0 13438 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED BASELINE 10159 0 10162 0 10169 5 10192 5 10195 0 10197 5 10224 0 10232 0 10243 0 10272 0 10281.5 10330 5 10334 0 10334 5 10343 5 10348 5 10351 0 10354 0 10381 5 10390 5 10398 5 10401 0 10403 0 10414 0 10419 0 10422 5 10433 5 10444 5 10452 0 10461 5 10464 5 10477 5 10483 5 10501 5 10504 0 10512 5 10518 0 10532 5 10539 0 10579 5 10587 5 10603 0 10605 5 10618 5 10621 5 10633 0 10639 0 10650 5 10657 0 10669 5 10714 5 10736 5 10742 0 10786 5 10792 5 10801 0 10816 5 10842 5 10852 0 10869 0 10879 0 10889 5 DEPTH DEPTH) EQUIVALENT UNSHIFTED GR 10153.0 10156.0 10164.0 10188.5 10190.5 10194 0 10224 0 10231 0 10241 5 10269 5 10280 5 10329 5 10334 0 10335.0 10344 5 10349 0 10352 5 10355 5 10381 5 10390 5 10397 5 10399.5 10401 0 10412 5 10418 5 10422 0 10435 0 10445 0 10453 0 10461 0 10463 5 10476 0 10482 5 10500 0 10503.0 10510 5 10515 5 10529 0 10535 5 10575 5 10586 0 10599 0 10602 0 10617 0 10619 0 10631 0 10636 0 10646 0 10651 5 10665 0 10709 0 10730 5 10735 5 10779 0 10790 0 10798 5 10811 5 10837 0 10846 0 10864 5 10874 5 10885 0 DEPTH 10954.5 10996.5 11001.5 11009.5 11041.0 11059.0 11121.0 11131.0 11154 5 11209 5 11213 5 11219 5 11245 0 11269 5 11277 0 11316 0 11368 5 11375 0 11381 0 11560 0 11591 0 11597 5 11606 5 11692 0 11699.5 11723 5 11755 0 11779 5 11786 0 11805 5 11842 5 11874 0 11889 0 11892 5 11905 5 11934 5 11960 5 11978.5 11991 5 12010 0 12021 5 12024 5 12086 0 12101 5 12104 5 12114 5 12124 5 12130 5 12139.0 12182 0 12189 5 12211 0 12216 0 12225 0 12230 5 12233 0 12235 5 12245 0 12253 0 12262.5 12271 0 12276 0 12283 0 12289 0 12294 0 12304 5 12311 0 12322 5 10950 0 10992 0 10995 5 11004 5 11037 5 11056 5 11119 0 11127 5 11151 5 11205 5 11209 0 11218 5 11240 5 11267 5 11274 0 11307 0 11363 0 11369 0 11375 0 11553 0 11582 5 11588 0 11597 5 11692 0 11699 5 11724 0 11754 0 11777 0 11785 0 11804 0 11842 0 11873 0 11887 0 11891 0 11903 5 11933 5 11960 0 11976 0 11989 0 12008 5 12020 0 12021 0 12082 0 12099 5 12101 5 12114 0 12124 5 12129 5 12137 5 12183 0 12190.0 12211 0 12215 5 12225 5 12230 5 12234 0 12236 0 12245 0 12254 0 12263 0 12270 5 12276.0 12282 5 12289 5 12293 5 12306 0 12312 0 12323 5 12337 5 12342 0 12371 0 12380 5 12382 5 12388 5 12390 5 12410 0 12414.5 12415 5 12427 5 12429 5 12434 5 12438 0 12446 5 12452 5 12459 5 12464 0 12477 5 12481 5 12486 5 12489 5 12492 5 12500 5 12508 0 12511 5 12517 0 12523 5 12526 5 12535 0 12537 5 12541 0 12556 0 12560 0 12562 5 12564 0 12568 0 12570 5 12576 5 12582 0 12592 5 12602 0 12603 0 12614 5 12618 0 12620 5 12623 0 12628 0 12634 0 12644 5 12649 0 12654.0 12658 5 12664 5 12666 0 12667 5 12675 0 12677 0 12681 0 12684 5 12687 5 12689.5 12695.0 12700.5 12703.5 12706.0 12708.0 12710.5 12339 12343 12371 12381 12382 12389 12391 12411 12414 12415 12427 12429 12434 12438 12446 12451 12460 12463 12476 12479 12485 12487 12489 12499 12506 12510 12517 5 12524.0 12525.5 12533.5 12536 5 12539 0 12553 0 12556 5 12558 0 12559 5 12563 5 12567 0 12573 0 12579 0 12589 0 12598 0 12599 5 12611 5 12615 5 12619 0 12622 0 12627 5 12633 0 12643 0 12649 0 12653 5 12657 5 12662 0 12663 5 12666 5 12673 5 12675 5 12679 5 12682 0 12685 5 12687 0 12693 5 12699 5 12703 5 12705 0 12708 0 12710 0 12713 12716 12721 12723 12733 12741 12751 12754 12759 12768 12770 12772 12778 12783 12792 12792 12795 12806 12812 12815 12818 12820 '12821 12823 12827 12830 12833 12838 12845 12850 12856 12862 12866 12870 12872 12874 12881 12883 12889 12908 12926 12944 12953 12957 12965 12967 12969 12971 12976 12988 12996 13016 13023 13032 13033 13034 13039 13048 13054 13057 13058 13061 13064 13067 13070 13074 13077 13080 .0 5 0 5 5 5 0 5 5 5 0 5 5 0 0 5 0 0 0 5 0 5 5 5 0 5 5 5 5 5 0 0 5 5 5 5 5 5 5 0 5 0 0 5 0 0 0 5 5 0 5 5 0 0 5 5 0 5 0 0 5 0 5 0 5 0 5 0 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 13 711.5 715.5 720.5 724.0 733 0 741 0 750 5 753 0 758 0 767 5 769 5 772.0 778.0 782.0 790.0 791.0 793 5 805 5 811 5 814 5 816 5 819 5 820 5 823 5 825 0 828 0 832 0 838 5 844 5 849 5 855 0 862 0 866 0 870 0 872 0 873 5 881 5 884 0 889 5 907 0 926 5 943 0 952 5 957 0 964 5 966 5 968 0 970 0 975 5 987 0 996 0 015 0 022 0 031 5 033 0 035 0 039 5 048 0 054 0 056.5 058.5 061.0 064.0 066.5 069.5 073.0 076.0 080.5 13089 13092 13096 13102 13105 13107 13109 13118 13122 13126 13128 13132 13136 13138 13141 13145 13149 13157 13170 13180 13184 13188 13189 13197 13217 13219 13228. 13234 13242 13245 13247 13256 13300 13309 13311 13315 13317 13322 13438 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 13089.5 13092.0 13095.0 13102.5 13104.5 13108.5 13110 0 13117 0 13121 5 13125 0 13129 0 13131 5 13134 0 13136 5 13139 5 13144 5 13148 0 13156 5 13168 5 13178 5 13182 0 13185 5 13187 0 13196 0 13215 5 13217 5 13226 5 13233 5 13240 5 13243 0 13248 5 13256 5 13298 5 13307 5 13309 0 13313 5 13314 5 13320 0 13435 0 BIT RUN NO MERGE TOP MERGE BASE 10 10165.0 13438.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 24 28 Name Service Unit Min Max DEPT FT 10165 13438 ROP MWD FT/H 8.67 4995.29 GR MWD API 32.66 210 RPX MWD OHMM 0.88 1503.9 RPS MWD OHMM 0.73 1527.96 RPM MWD OHMM 0.77 2000 RPD MWD OHMM 0.88 2000 FET MWD HOUR 0.1943 7.6356 Mean 11801.5 109.87 109.001 3.50207 3.52299 7.1526 5.68126 0.778567 N s am 6547 6470 6464 6431 6431 6431 6431 6411 First Reading 10165 10203.5 10165 10186 10186 10186 10186 10196 Last Reading 13438 13438 13397 13401 13401 13401 13401 13401 First Reading For Entire File .......... 10165 Last Reading For Entire File ........... 13438 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RPX FET RPD RPS RPM RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: START DEPTH 12996.5 13003.5 13003.5 13003.5 13003.5 13003.5 13038.0 STOP DEPTH 13251 5 13258 0 13258 0 13258 0 13258 0 13258 0 13298 0 MAD RUN NO. MAD PASS NO. 11 1 MERGED MAD PASS. $ MERGE TOP 12996.0 MERGE BASE 13296.5 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 12996.5 13298 RAT MAD FT/H 0 957 GR MAD API 31.43 142.24 RPX MAD OHMM 1.76 82.52 RPS MAD OHMM 1.74 102.93 RPM MAD OHMM 1.68 102.04 RPD MAD OHMM 1.69 75.65 FET MAD HOUR 17.4611 22.7909 Mean 13147.3 262.359 91.8699 7.71183 7.87339 7.72411 7.10872 19.7381 Nsam 604 521 506 508 508 508 508 508 First Reading 12996.5 13038 12996.5 13003.5 13003.5 13003.5 13003.5 13003.5 Last Reading 13298 13298 13251.5 13258 13258 13258 13258 13258 First Reading For Entire File .......... 12996.5 Last Reading For Entire File ........... 13298 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10153 0 10181 5 10181 5 10181 5 10181 5 10191 5 10200 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13391 0 13398 0 13398 0 13398 0 13398 0 13398 0 13435 0 TOOL STRING (TOP TO BOTTOM) \FENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 26-0CT-99 Insite 0 Memory 13435.0 10.4 65.1 TOOL NUMBER P1353GRV4 P1353GRV4 6.125 Water Based 9.60 44.0 9.0 500 4.5 2.750 1.549 2.800 1.950 68.0 126.0 68.0 68.0 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 10153 13435 ROP MWD010 FT/H 8.67 4995.29 GR MWD010 API 32.66 210 RPX MWD010 OHMM 0.88 1503.9 RPS MWD010 OHMM 0.73 1527.96 RPM MWD010 OHMM 0.77 2000 RPD MWD010 OHMM 0.88 2000 FET MWD010 HOUR 0.1943 7.6356 Mean 11794 109.989 108.942 3.26726 3.2843 7.21289 5.51026 0.78711 N s am 6565 6470 6475 6434 6434 6434 6434 6414 First Reading 10153 10200.5 10153 10181.5 10181.5 10181.5 10181.5 10191.5 Last Reading 13435 13435 13391 13398 13398 13398 13398 13398 First Reading For Entire File .......... 10153 Last Reading For Entire File ........... 13435 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12996.0 STOP DEPTH 13252.0 FET 13002.5 RPD 13002.5 RPM 13002.5 RPS 13002.5 RPX 13002,5 P~AT 13038.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 13258 0 13258 0 13258 0 13258 0 13258 0 13296 5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 26-0CT-99 Insite 0 Memory 13435.0 10.4 65.1 TOOL NUMBER P1353GRV4 P1353GRV4 6.125 Water Based 9.60 44.0 9.0 500 4.5 2.750 1.549 2.800 1.950 68.0 126.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 P~AT MAD011 FT/H 4 1 68 4 GR MAD011 API 4 1 68 8 RPX MAD011 OHMM 4 1 68 12 RPS MAD011 OHMM 4 1 68 16 RPM MAD011 OHMM 4 1 68 20 RPD MA/D011 OHMM 4 1 68 24 FET MAD011 HOUR 4 1 68 28 Channel 1 2 3 4 5 6 7 8 Name Service Unit Min Max Mean DEPT FT 12996 13296.5 13146.3 R_AT MAD011 FT/H 0 957 262.039 GR MA/D011 API 31.43 142.24 92.1884 RPX MAD011 OHMM 1.76 82.52 7.71437 RPS MAD011 OHMM 1.74 102.93 7.85457 RPM MAID011 OHMM 1.68 102.04 7.70576 RPD MAD011 OHMM 1.69 75.65 7.10231 FET MA_D011 HOUR 17.4611 22.7909 19.7336 First Last Nsam Reading Reading 602 12996 13296.5 517 13038.5 13296.5 509 12996 13252 510 13002.5 13258 510 13002.5 13258 510 13002.5 13258 510 13002.5 13258 510 13002.5 13258 First Reading For Entire File .......... 12996 Last Reading For Entire File ........... 13296.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File