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195-170
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MIT for Milne Point well J-19A Date:Friday, October 28, 2022 12:40:01 PM MPU J-19A (PTD 1951700) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Friday, October 28, 2022 12:08 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne-WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: MIT for Milne Point well J-19A All, Milne Point well J-19A (PTD # 1951700) was not brought on line in time for the regularly scheduled MIT this month. It has been shut in since January 2022. A tag will be hung on the well head, it is classified as inoperable, and will be tested prior to returning to injection. Please call myself or Jerimiah Galloway (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com STATE OF ALASKA ALlikA OIL AND GAS CONSERVATION COMOION c REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown El Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well El Re-enter Susp Well❑ Other: MBE Treatment E 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 195-170 3.Address: Stratigraphic E] Service Q✓ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22607-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ft ADL0025517 MILNE PT UNIT SB J-19A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): JUL 25 2016 N/A MILNE POINT/SCHRADER BLUFF OIL /J 11.Present Well Condition Summary: OGCC Total Depth measured feet Plugs measured feet p 5,750N/A true vertical 4,278 feet Junk measured 5,588(Fill) feet 5,115,5,303& Effective Depth measured 5,588 feet Packer measured 5,482 feet 3,787,3,930& true vertical 4,151 feet true vertical 4,069 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,391' 9-5/8" 3,391' 2,713' 5,750psi 3,090psi Production 5,728' 7" 5,728' 4,260' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic �pp _ c ) scyj��NHE■� FEB 0 LU 1l True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/EUE 5,595' 4,156' 7"x3.5"HES Packers and SSSV(type,measured and true vertical depth) MFA Dual Pkr x 3 N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 813 80 542 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-067 Cre Contact Stan Porhola Email sporhola ct hilcorp.com Printed Name Bo York Title Operations Manager Signature "47-74?------\- Phone 777-8345 Date 7/25/2016 RBDMS W +Ut I b 1016 Form 10-404 Revised 5/2015 Submit Original Only r Milne Point Unit .n 0 • Well: MPJ-19A SCHEMATIC Last Completed: 12/31/2009 Mewl)Alaska,LLC PTD: 195-170 TREE&WELLHEAD Orig.KB Elev.:64.5'/Orig.GL Elev.:35.6' Tree 3-1/8"- 5M FMC RKB-7"Csg Hngr:28.9'` 11"x 3-1/8"5M FMC Gen 5 w/3.5"TC-Il T&B Thread Wellhead FMC Tubing Hanger 3.0"CIW"H"BPV Profile is] :-'20' OPEN HOLE/CEMENT DETAIL 20" 250 sx Arctic Set(Approx.)in a 24"Hole 9-5/8" 674 sx PF`E',250 sx'G',150 sx PF'E'in a 12-1/4"Hole 7" 225 sx Class'G'in a 8-1/2" CASING DETAIL 1 Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 91.1/H-40/N/A 19.124" 18.936" Surface 112' 0.3550 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 3,391' 0.0759 9-5/8" • d 7" Production 26/L-80/BTC 6.276" 6.151" Surface 5,728' 0.0383 TUBING DETAIL TOC©3,396'RKB- 3-1/2" Tubing 9.3/L-80/EUE 2.992" 2.867" Surf 5,595' 0.0087 USIT12/20/09 WELL INCLINATION DETAIL oi ° KOP @ 500' Kicked off original hole at 3,795'MD Max hole angle=61 deg.At 3,750'MD JEWELRY DETAIL No Depth Item 1 2,098' 3.5"HES X-Nipple(2.813"Profile) RA Tag 4,799 NLN 2 5,070' 3.5"HES X-Nipple(2.813"Profile) TvoTx20Marker 3 5,115' 7"x3.5"HES MFA Dual Packer Jts from 4,799'to 4 5,124' 3.5"HES X-Nipple(2.813"Profile) 4,839 ALM — 2 5 5,126' 3.5"NDPG Single Sub#3 3 GLM DETAIL:3.5"x 1.5"Camco w/1.5"RK Latch —` 6 5,189' Sta#5:Valve-Dummy/Date-12/31/2009[MMG GLM] 4 7 5,280' Sta#4:Valve-200 bwpd WFRV/Date-7/17/2016[MMG-W GLM] 5 8 5,303' 7"x 3.5"HES MFA Dual Packer 9 5,312' 3.5"HES X-Nipple(2.813"Profile) 6 10 5,313' 3.5"NDPG Single Sub#2 at -}NB Sands 11 5,376' Sta#3:Valve-Dummy/Date-6/19/2014[MMG GLM] 12 5,465' Sta#2:Valve-450 bwpd WFRV/Date-7/17/2016[MMG-W GLM] 7 13 5,483' 7"x 3.5"HES MFA Dual Packer 14 5,492' 3.5"HES X-Nipple(2.813"Profile) 111.3" 8 15 5,493' 3.5"NDPG Single Sub#1 I 9 16 5,533' Sta#1:Valve-250 bwpd WFRV/Date-7/16/2016[MMG-W GLM] 17 5,562' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go)PXN plug/prong Set 6/19/14 10 18 5,593' 3.5"WLEG—Bottom @ 5,595' 11 4r PERFORATION DETAIL E}OASands Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status I.: 12 1 N 5,231' 5,260' 3,875' 3,897' 29 12 4.5" 6/25/1996 Open 5,275' 5,279' 3,908' 3,911' 4 12 4.5" 6/25/1996 Open L'13 4 OA 5,413' 5,455' 4,014' 4,047' 42 12 4.5" 6/23/1996 Open 14 [ OB 5,498' 5,524' 4,079' 4,101' 26 12 4.5" 6/21/1996 Open 15 Ref Log:GR/CCL/Temp Press—11/8/1995—Perf Guns 4.5"/26 Gram Jumbo Jet @ 135/45 Deg in }Oesands STIMULATION DETAIL 1. Mnimum ID=2.750" 16- N:Frac w/49,000#16/20 Carbolite @5,562' Pk ° OA:Frac w/14,000# 16/20 Carbolite 17 OB:Frac w/5,500#16/20 Carbolite Tag w/2.35'GRat . 18 5�,MD GENERAL WELL INFO 6/18/2014 API:50-029-22607-01-00 , Sidetracked&Cased by Nabors 22E—10/30/1995 7" I .,'' - Frac Pack ESP Completion by Nabors 4ES—6/27/1996 TD=5,750'(MD)/TD=4,277'(TVD) Convert to Injector by Nabors 4ES—12/31/2009 PBTD=5,642'(MD)/PBTD=4,193'(TVD) Downhole Revised:7/17/2016 Revised By:STP 7/25/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP J-19A Slickline 50-029-22607-00-00 195-170 3/15/16 7/1/16 Daily Operations: 3/9/2016-Wednesday No activity to report. 3/10/2016-Thursday No activity to report. 3/11/2016 - Friday No activity to report. 3/12/2016-Saturday No activity to report. 3/13/2016-Sunday No activity to report. 3/14/2016- Monday No activity to report. 3/15/2016-Tuesday RU Slickline and PCE. PT lubricator to 3,500psi Hi/250psi Low. RIH and tag w/2.25" DD bailer to 5,516' SLM (5,547' MD). RIH and pull valve from station #4. RIH and set dummy valve in station #4. RIH and pull valve from station#1. Rig down slickline. SDFN. • ! Hilcorp Alaska, LLC Weekly Operations Summary Well Name _ Rig API Number Well Permit Number Start Date End Date MP J-19A Slickline 50-029-22607-00-00 195-170 3/15/16 7/1/16 Daily Operations: 3/16/2016-Wednesday No activity to report. 3/17/2016-Thursday RU Slickline and PCE. PT lubricator to 3,500psi Hi/250psi Low. RIH and set dummy valve in station #1. RIH and pull valve from station #2. RIH w/2.50" LIB and set down at 5,516' SLM (5,547' MD). Impression of prong. Rig down slickline. Turn well over to production. 3/18/2016- Friday No activity to report. 3/19/2016 -Saturday No activity to report. 3/20/2016-Sunday No activity to report. 3/21/2016- Monday No activity to report. 3/22/2016-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date J-19A Slick Line 50-029-22607-01-00 195-170 3/15/16 7/1/16 Daily Operations: 6/22/2016-Wednesday No activity to report. 6/23/2016 -Thursday No activity to report. 6/24/2016- Friday No activity to report. 6/25/2016-Saturday No activity to report. 6/26/2016 -Sunday No activity to report. 6/27/2016- Monday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 4,000 psi-test OK. Perform injectivity test at 0.75 bpm @ 580 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/29.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 20 bbl of diesel.SD Pumps. Monitor well. Final SITP of 960 psi. RDMO Cement Pump Unit & Little Red Pump Unit. Rig Down. 6/28/2016-Tuesday No activity to report. • . HilcorpAlaska, LLC ililtcorp:llakx,t.1..0 Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPJ 19A Pump 50 029-22607-01-00 195 170 3/15/2016 7/1/2016 Fi �� � � 'I� is ° , ly -1,tions: ! ¢ i ` .ice E 629/16-Wednesday No Operations to Report., v"` -rsit' 1 i� i',.r_. l No Operations to Report. 7/1/16 Friday u���, ����V� ''"Pb" PIIV� ��75 bPm @ I �� MIRU Cement Pump Unit and Little Red Pump Unit.PT lines to 4,000 psi-test OK.Perform injectivity test at 0.75 bpm @ 750 psi.Mix and pump 5 bbl of HEC,10 bbl of 15.8 ppg cement,and 5 bbl of HEC.Drop foam ball.Displace w/25.0 bbl of 1%KCI water.Switch to Little Red Pump Unit and pump 20 bbl of diesel.SD Pumps.Monitor well.Final SITP of 840 psi.RDMO Cement Pump Unit&Little Red Pump Unit.Rig Down. 7/2/16-Saturday �H � �1ub6�_ No Operations to Report. 7/3/16-Sunday, = k ,'' No Operations to Report. JI I No Operations to Report. 7/5/16-Tuesday E 7 No Operations to Report. • t9 5- ti 0 oF 4,1 \ i,,:,� THE STATE Alaska Oil and Gas r „if Conservation Commission +: _��= 333 West Seventh Avenue �,r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 leo . *'� ps Main: 907.279.1433 ALAS n% Fax: 907.276.7542 °� � k www.aogcc.alaska.gov Bo York Operations ManagerD Hilcorp Alaska, LLC 5 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-19A Permit to Drill Number: 195-170 Sundry Number: 316-067 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, v Jo��� Cathy P. oerster Chair DATED this 3 day of February, 2016. RBDMS i'- FEB 0 4 2016 • i RECEIVED STATE OF ALASKA QFEB 0 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 'S APPLICATION FOR SUNDRY APPROVALS O t,.(1‘ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ "-.6 'btl)er Stimulate w�' Pull Tubing ❑ Change Approved Program❑ fh w45r/ Plug for Redd!' ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment 0- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC - Exploratory ❑ Development ❑ 195-170 • 3.Address: Stratigraphic ❑ Service Q, 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22607-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05- Will planned perforations require a spacing exception? Yes ❑ No 2 ./ MILNE PT UNIT SB J-19A ' 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 - MILNE POINT/SCHRADER BLUFF OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 5,750' 4,278' 5,588' 4,151' 3,5 ' N/A 5,588(Fill) Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,391' 9-5/8" 3,391' 2,713' 5,750psi 3,090psi Production 5,728' 7" 5,728' 4,260' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic . See Schematic 3-1/2" 9.3#/L-80/EUE 5,595' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 3.5"HES MFA Dual Pkr x 3 and N/A • 5,115MD/3,787TVD,5,303MD/3,930TVD&5,483MD/4,069TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: 2/12/2016 Commencing Operations: OIL ❑ WINJ ❑✓ . WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ContactStan Porhola • _3 Email sporhola( hilcorD.com Printed Name Bo York Title Operations Manager Signature 7,1‘1)---------- Phone 777-8345 Date 1/2912016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test LK Mechanical Integrity Test ❑ Location Clearance ❑ Other: jl= L( SLU psi, l&.,.P ;54— CCT-'-t Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No f ' Subsequent Form Required: Approved by: P COMMISSIONER THE COMMISSION Date: 3- - / 4/67 APPROVED BY 90 �. � 1 - Submit Form and Form 10-403 Revised 11/2015Op I o alid for 12 months from the date of approval. Attachments in Duplicate RBDMS 1;L- FEB 0 4 2016 1 . 13 • • i Well Prognosis Well: MPU J-19A Hileurp Alaska,LU Date: 1/29/2016 Well Name: MPU J-19A API Number: 50-029-22607-01 Current Status: SI Water Injector Pad: Milne Point J-Pad Estimated Start Date: February 12th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-170 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,909 psi @ 4,000' TVD (Last BHP measured 10/26/2014) Maximum Expected BHP: 1,909 psi @ 4,000' TVD (No new perfs being added, EMW= 9.18 ppg)/ MPSP: 3,500 psi (Based on maximum surface injection pressure) Brief Well Summary: MPU J-19A was sidetracked with Nabors #22E in 1995 as a deviated injector in the Schrader Bluff N, OA, and OB sands and provides support in hydraulic unit 1 for offset producer MPU J-09A (PTD 199-114). The well was frac-packed and completed with an ESP in 1996 with Nabors#4ES.The ESP completion was pulled and the well converted into an injector in 2009 with Nabors #4ES. The well has had several MBE treatments that have been treated with some limited success. Notes Regarding Wellbore Condition • Well is a deviated water injector(max hole angle 61° @ 3,750'). • Last MIT-IA to 2,010 psi on 11/05/2014. • Shut-in water injection due to previous MBE (Matrix Bypass Event). • Confirmed MBE between MPU J-09A(ESPCP Oil Producer) based on increased water cuts in the producer, coming from water injection into the OA sands. ,,'',a • Mandrels to be dummied off in N/OB sands, open pocket in OA sand to treat MBE. Objective: The purpose of this work/sundry is to pump a MBE treatment and place well back on water injection. U.A 5Ct N Brief Procedure: Pumping Procedure: 1. Production to SI offset producers up to 5 days prior to treatment. 2. Production to SI offset injectors up to 2 days prior to treatment. 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 0.75 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5. Mix and bullhead the following fluids with the Cementing Unit: a. +/- 10 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. • • Well Prognosis Well: MPU J-19A IIileorp Alaska,LLI Date: 1/29/2016 b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. 5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) tail spacer pill. d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-29.0 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/0). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#1] 11. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 psi Low. b. RIH and tag cement top. POOH. c. RIH and bail cement. POOH. d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. �4. Contingency: I idual cement exists: ar ' e Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure test BQBE to 4,500 psi Hi 250 psi Low, 10 min each test. i. i AOGCC 24 hrA, ii. es using 60/40 methanol or 8.5 ppg seawater. iii. Each subsequent test of the lubricator will be to 4,000 psi Hi 250 psi Low to confirm no leaks. c. RIH w/2.00" coil w/2-1/8" wash nozzle to cement top. Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to+/-5,562' MD (PXN plug). e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/2.25" OD mill, 2-1/8" motor, and oil jars and cleanout cement to+/-5,562' MD (PXN plug). b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/2-1/8" wash nozzle to+/-5,562' MD (PXN plug). b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. . • Well Prognosis Well: MPU J-19A Hilcorp Alaska,LL) Date: 1/29/2016 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. 20. Fluid-pack and maintain tubing pressure on offset well affected by MBE (MPU J-09A). 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC (hydroxy ethyl cellulose) lead spacer pill. b. +/- 10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt NEC(hydroxy ethyl cellulose) tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-29.0 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (MPU J-09A). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/- 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-20 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing . • Milne Point Unit 14Well: MP J-19A SCHEMATIC Last Completed: 12/31/2009 Hilcorp Alaska,LLC, PTD: 195-170 TREE&WELLHEAD Orig.KB Elev.:64.5'/Orig.GL Elev.:35.6' Tree 3-1/8"- 5M FMC RKB—7"Csg Hngr:28.9' 11"x 3-1/8"5M FMC Gen 5 w/3.5"TC-II T&B Thread j 20Wellhead r FMC Tubing Hanger 3.0"CIW"H"BPV Profile 20 " ,., OPEN HOLE/CEMENT DETAIL 20" 250 sx Arctic Set(Approx.)in a 24"Hole 9-5/8" 674 sx PF`E',250 sx`G',150 sx PF`E'in a 12-1/4"Hole k 7" 225 sx Class`G'in a 8-1/2" CASING DETAIL 1 Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 91.1/H-40/N/A 19.124" 18.936" Surface 112' 0.3550 41 I 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 3,391' 0.0759 9-5/8" 4 g 7" Production 26/L-80/BTC 6.276" 6.151" Surface 5,728' 0.0383 TUBING DETAIL TOC@3,396'RIB;' 3-1/2" Tubing 9.3/L-80/EUE 2.992" 2.867" Surf 5,595' 0.0087 USIT 12/20/09 , WELL INCLINATION DETAIL ,4, KOP@500' � Kicked off original hole at 3,795'MD .._' :x. Max hole angle=61 deg.At 3,750'MD *1 '' JEWELRY DETAIL J No Depth Item ,i 1 2,098' 3.5"HES X-Nipple(2.813"Profile) RATag4,799'WJ4 2 5,070' 3.5"HES X-Nipple(2.813"Profile) TwoTx20 Marker e' 3 5,115' 7"x 3.5"HES MFA Dual Packer Jtsfrom 4,799 to 4 5,124' 3.5"HES X-Nipple(2.813"Profile) 4,839 W..M 1 ` -` 2 5 5,126' 3.5"NDPG Single Sub#3 —t GLM DETAIL:3.5"x 1.5"Camco w/1.5"RK Latch 0 1 �3 6 5,189' Sta#5:Valve-Dummy/Date-12/31/2009 4 7 5,280' Sta#4:Valve-P-15 XJR(190 bwpd)/Date8/10/2015 • 8 5,303' 7"x 3.5"HES MFA Dual Packer to 5 '' 9 5,312' 3.5"HES X-Nipple(2.813"Profile) ,,,.... � 10 5,313' 3.5"NDPG Single Sub#2 6 11 5,376' Sta#3:Valve Dummy/Date 6/19/2014 }NB Sands Ri 7 12 5,465' Sta#2:Valve Dummy/Date 7/24/2015 fl pL�v"'' ' 13 5,483' 7"x 3.5"HES MFA Dual Packer 14 5,492' 3.5"HES X-Nipple(2.813"Profile) f` 8 15 5,493' 3.5"NDPG Single Sub#1 Ib 9 16 5,533' Sta#1:Valve-P-15 XJR(500 bwpd)/Date-8/31/2015 L" 17 5,562' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go)PXN plug/prong Set 6/19/14 10 ,� 18 5,593' 3.5"WLEG Bottom @ 5,595' t't'2— L' tA � PERFORATION DETAIL - OASaxds Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status 12 +a", N 5,231' 5,260' 3,875' 3,897 29 12 4.5" 6/25/1996 Open 5,275' 5,279' 3,908' 3,911' 4 12 4.5" 6/25/1996 Open ''"' ' ' 13 OA 5,413' 5,455' 4,014' 4,047' 42 12 4.5" 6/23/1996 Open 14 t OB 5,498' 5,524' 4,079' 4,101' 26 12 4.5" 6/21/1996 Open Ref Log:GR/CCL/Temp Press—11/8/1995—Perf Guns 4.5"/26 Gram Jumbo Jet @ 135/45 Deg 15 1 STIMULATION DETAIL t ji OB Sands N:Frac w/49,000#16/20 Carbolite Minimum 10=2.750'14 16 y„,Y��'�f @5,562' ' D / OA:Frac w/14,000# 16/20 Carbolite 1,17 OB:Frac w/5,500#16/20 Carbolite :."18 GENERAL WELL INFO Tag w12.35'GR at -'• 5,588'MD API:50-029-22607-01-00 6/18/2014 •1' „ Sidetracked&Cased by Nabors 22E—10/30/1995 7" Frac Pack ESP Completion by Nabors 4ES—6/27/1996 TD=5,750'(MD)/TD=4,277'(TVD) Convert to Injector by Nabors 4ES—12/31/2009 PBTD=5,642'(MD)/PBTD=4,193'(TVD) Revised By:STP 1/12/2016 • 0 II Milne Point Unit COIL 60PE MPU J-19A 1/28/2016 r(arrnrp%Inoks t.r.( MPU J-19 20X9VX7X3A Coil Tubing BOP £ z Lubricator to injection head T . I 2.00"Single Stripper 1 — 41/16101V(1 _J - -- C- Blind/Shear Blind/Shear = vj= 0 I -- Y 0 _ O0 — 41 � p- —— Ella Slip Ella111111% Slip E'® c= Pipe Pipe -0 J cue Crossover spool r 4 1/16 10M X4 1/16 5M rr s, ear - — Pump-In Sub �'.� ? c`� 4 1/16 5M - c• 4. ( 1 11502 Union r r p1 Mtn il ®r MIManual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X3 1/8 5M LI La tty 0. Valve,Swab,WKM-M, „ S\( _} ® �T'n� c. 3 1/8 5M FE � ' mt. l �. NVas 3 y'`b I\ / R MI I C ie / N Wr". Valve,Upper Master,Baker, > 3 1/8 5M FE,w/Hydraulic 611111 -4.4.11 MN Valve,Lower Master,WKM-M, IV11.4% 3 1/8 5M FE v ., ,. IFINNIVETM ev' err Tubing Adapter,3 1/8 5M � ,� ,lr • • 0 • li to 0 2 2. .. E • 0 0 *E g oo coal a -. 8 :: •:. : - &.' . 5 -= ,t15 0 E '" •::„...' r..4 rj 74 E. .7,1 -6' S 'rt 7 4 o 0 F LU LLICe .0 S Z 62 ce Z < ce z — - --i— '4111XZ ZO ,nu" ,e, Illi.L ''''''' •••,.., "... 111111111= 1,-- ' a 0 ...: : Y 0 ..: • ,e, E ; > 74 c. , s•-• ._ 5.7 > (.7 = o a, iiirti 11161 ; 't i 4111 g if) .e 1 NM Ilia PP- <u " A S V o Li+ O : 1— I -. 0 h 11 N NI = 7P: -74.- '<'"," 0 0 U w O., I ' u , IN me 1111 °21%, 1 1 ter.NSOP i * imor iiniK,A4 ila .. '4.1 - MI 1111 MI MI -I. N Orlee i E. i 0 . w . ...- .0 N Z IL < U.CC uF 0 0 0 m 0 o cc 7 z .:4 . _..- Lfl2 co°1 8 0 4 ..: t XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: ~ianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ I • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 %AWED FEB dr December 30, 2011 Mr. Tom Maunder ' 7 0 Alaska Oil and Gas Conservation Commission CA 333 West 7 Avenue I p Anchorage, Alaska 99501 (V1 , Subject: Corrosion Inhibitor Treatments of MPJ -Pad ` Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA MPJ -05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 '*" MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 • • WELL LOG (- TRANSMITTAL PROAcrivE DiAgrosric SERViCES, INC_ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /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 Benson Blvd. Anchorage, Alaska 99508 and J1 C L - / ProActive Diagnostic Services, Inc. a '� Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ,il . AIMED MAY 2 3 2011 Fax: (907) 245 -8952 1) Injection Profile 15- Apr -11 MPU J -19A BL / EDE 50 -029- 22607 -01 2) Signed : Date : ; A " Will Print Name: , _ - _ . y ,: , - -,. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 1 E-MAIL : �^'c ^3. a . Lafat3et/Du;'?Cs.3'?Y:r4;0' WEBSITE : 'T 'PN.TeiTIO 4 !; %.7.a '^4?' C\Documents and Settings\Diane Williazns \Desktop\BP_Transmit.docx MEMORANDUM 0 State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Friday, November 12, 2010 � ll/t��l� P.I. Supervisor ' \ � G ! SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC J -19A FROM: Jeff Jones MILNE PT UNIT SB J -19A Petroleum Inspector Src: Inspector Reviewed B P.I. Supry ar NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB J -19A API Well Number 50- 029 - 22607 -01 -00 Inspector Name: Jeff Jones Insp Num: mitJJ101108062123 Permit Number: 195 -170 -0 Inspection Date: 11/7/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well J -19A 'TypeInj. W TVD � 3787 ' IA 1120 1710 - 1680 1665 1951700 1 yp SPT Test psi lsoo pA 1zo lzo 1zo lzo In terval INITAL f P/F P I Tubing 2475 I 2475 2475 2475 Notes: 0.5 BBLS diesel pumped. 1 well house inspected, one exception noted: the floor grating is resting on the OA block valve & requires repair. Friday, November 12, 2010 Page I of 1 • PIeoACrive DiAClvosric SeevieES, INC. °~~ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/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 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road Suite C ~_..;..~ ~ i,; ;R ~ ~1'~i ~..'~"_. Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 2) O1,Ju1-10 MPU J-19A I `~ ~`,( _~,~ ; ~ ~~ Signed Print Name: BL / EDE 50-029-22607-01 ~, Date Po PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~s~sar~c~aoracaeCaa~snerr~oryleg.C~sra WEBSITE : ~r~rw.mer~or~loa.com C.1Documznt, an~i SettlngslDiane Williams~Desktop\Transmit_Corwco.~:x STATE OF ALASKA APR ~ 2 2sKA~ AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS _ in ~,...v.ieeuw 1. Operations epair ell ^ Plug Perforations ^ Stimulate ^ Other 0 INJECTION Performed: Alter Cas Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ TEST Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 195-1700 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22607-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: \ ADLO-025517 MPJ-19A 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 5750 feet Plugs (measured) None feet true vertical 4277.51 feet Junk (measured) None feet Effective Depth measured 5642 feet Packer (measured) 5115 5303 5483 true vertical 4193 feet (true vertical) 3787 3930 4069 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 112 SURFACE - 112 1490 470 Surface 3360 9-5/8" 40# L-80 SURFACE - 3391 SURFACE - 2713 2750 3090 Intermediate Production 5699 7" 26# L-80 SURFACE - 5728 SURFACE - 4260 7240 5410 Liner Liner Perforation depth: Measured depth: O 5231 - 5260 O 5275 - 5279 O 5413 -5455 O 5498 - 5524 True Vertical depth: 3874.71 - 3896.78 3908.24 - 3911.3 4014.5 - 4047.1 4080.57 - 4100.85 Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# LL-80 SURFACE - 5595 SURFACE - 4156 Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" HES MFA DUAL PACKERS 5115 3787 7"X3-1 /2" HES MFA DUAL PACKERS 5303 3930 7"X3-1/2" HES MFA DUAL PACKERS 5483 4069 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~v Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 349 1413 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-055 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 4/2/2010 ~~iii ~v-•rvw ncv~c~ ricvva ~ ~ ~' JO ~~ a" ~ ~/c~ \_ J • MPJ-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/27/2010 '**W ELL S/I ON ARRIVAL""" (wfrv c/o) RAN 2.55" CENT, 2' x 1-7/8" stem, 2.65" CENT, 2.25" LIB TO 5,562' MD. REC IMP OF PRONG. ~ SET 1.5" RK P-15 XJR IN ST #1 @ 5,533' MD. RAN 3-1/2" OM-1 W/ 1.7" LIB. TAGGED LATCH IN ST#1 @ 5533' MD. RECOVERED IMP OF LATCH. *"*CONT'D ON 3-28-10*** 3/28/2010*""CONT'D FROM 3-27-10""*(injectivity test) LRS PUMPED 21 BBLS OF 6Q/S1A-MEN IN. INJECTIVITY TEST PULLED 1.5" RK-DGLV FROM ST#2 @ 5465' MD 1 HR INJECTIVITY TEST @ 800 PSI AND 1560 BWPD. 1 HR INJECTIVITY TEST @ 1000 PSI AND 2075 BWPD. 1 HR INJECTIVITY TEST @ 1200 PSI AND 2500 BWPD. ATTEMPTED TO SET WFRV IN ST #2 @ 5,465' MD. SET 1.5" RK P-15 XJR (300 bwpd, 15/64" port, light spring) IN ST #2 @ 5,465' MD. «<well on inj during set & shear off»> RAN 1.70" LIB ON KOT TO ST #2 @ 5,465' MD. REC IMP OF LATCH. WELL LEFT S/I, TURN OVER TO DSO. "**JOB COMPLETE**" 3/28/2010 ***Job In Progress Continued From WSR 03-27-10'`** T/I/0=50/0/140 Assist S- Line (Infectivity Test) Pumped 21 bbls 60/40 methanol down Tbg. Established an infectivity rate of 0.35 bpm @ 800 psi. DSO notified SLB S-Line on well upon LRS departure. FWHP's=50/0/140 FLUIDS PUMPED BBLS 21 60/40 METH 21 TOTAL Tree: 3 1/8" - 5M FMC M PU J-19A Orig. DF. Elev. = 64.5' (N 22E) Wellhead: 11" 5M FMC Orig. GL. Elev. = 35.6' w/ 3 1/8" FMC Tubing Hanger , 3 1/2" RT To 7" Csg Hgr = 28.9' (N 22E) TC-II T&B Thread. 2.5" CIW 'H' BPV profile 20" 91.1 ppf, H-40 115' KOP @ 500' 3.5" HES X-Nipple (2.813" pkg.) 2Q9$' Kicked off original hole at 3795' and Max hole angle = 61 deg. at 3750' 9 5/8", 40 ppf, L-80 BTC. 3391' 3 1/2" 9.3 ppf, L-80, 8rd EUE Tbg ( drift ID = 2.867", cap. = 0.0087 bpf ) 7" 26 ppf, L-80, BTC Csg. ( drift ID = 6.151", cap = 0.0383 bpf ) ( cap w/ 3 1/2" inside = 0.0264 ) Two 7" x 20' marker joints from 4799' ' ' - 3.5" HES X-Nipple (2.813" pkg.) 5Q7Q` to 4839 wlm w/ RA tag at 4799 wlm 7" x 3.5"HES MFA Dual Pkr 5115` 3.5"HES X-Nipple (2.813" pkg.) 5124` 3.5"NDPG Single Sub 5126` 3.5° x 1.5" Camco MMG GLM 5189` 3.5" x 1.5"Camco MMG-W GLM 528Q` 7" x 3.5"HES MFA Dual Pkr 5303` _ 3.5" HES X-Nipple (2.813" pkg.) 5312` 3.5"NDPG Single Sub 5313` 3.5" x 1.5" Camco MMG GLM 5376` Perforation Summary 5465' MMG W GLM 3 5" 1 5" C Ref log:11/08/95 GR/ CCL/Temp./ Press. ~ . x . amco - Size SPF Interval (TVD) ` 7" x 3 5"HES MFA Dual Pkr 5483 'N'Sand . a.s^ 1z 5231' - szso' (3875'-3897') 3.5"HES X-Nipple (2.813" pkg.) 5492` 4.5" 12 5275' - 5279' (3908'-3911') 3.5"NDPG Single Sub 5493 a.5^ 12 'oA' Sand 5413' - 5455' ' ' (cola'-aoa7') 3.5" x 1.5" Camco MMG-W GLM 5533` a.5^ 12 OB Sand 5asa'-5524' (ao79'-4101') 3.5"HES XN-Nipple (2.813" pkg.) 5562` 2 75" No-Go 12 SPF 4-1/2" Jumbo Jet charges 26 GR . 3.5" WLEG 5595` @ 135/45 deg. phasing 5 642' " float collar (PBTD) 7 5 728' " 7 26#, L-80, BTC DATE REV. BY COMMENTS MILNE POINT UNIT 10/31/95 JBF Drilled and Cased by Nabors 22E WELL J -19A 06/26/96 MDO ESP COMPLETION 4 ES API NO: 50-029-22607 - 01 12/30/09 Hulme Convert to injector - N-4ES BP EXPLORATION (AK) • Mr. Keith Lopez Petroleum Engineer BP Exploration (Alaska) Inc P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point Field, Schrader Bluff Pool, MPJ-19A Sundry Number: 310-055 r ~~+~> Ca ~ F s V ~~'~!~~~ Dear Mr. Lopez: `c~5- ~~ ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A rson may not appeal a Commission decision to Superior Court un ss ehearing has been requested. DATED this y~da of February, 2010. - Y t, J Encl. STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 2 2 2010 n 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool ^ Repair Weil ^ Chang~~~~~$d,Program ^ Suspend ^ Plug Perforations ^ Perforate^ Pull Tubing^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^~ Alter Casing ^ Other: Infection Test 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 195-1700 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22607-01-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPJ-19A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-025517 Miine Point Field / Schrader Bluff Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5750 4278 5642 4193 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE 112 SURFACE 112 1490 470 Surtace 3360 9-5/8" 40# L-80 SURFACE 3391 SURFACE 2713 2750 3090 Intermediate Production 5699 7" 26# L-80 SURFACE 5728 SURFACE 4260 7240 5410 Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.3# L-80 SURFACE 5595 Packers and SSSV Tvoe: 7"x3-1/2" HES MFA Dual Packers Packers and SSSV MD and TVD (ft): 5115 3787 7"x3-1/2" HES MFA Dual Packers 5303 3930 7"x3-1/2" HES MFA Dual Packers 5483 4069 12. Attachments: Description Summary of Proposal ^/ 13. Well Class after proposed work: Detailed Operations Program [] BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/1/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ Q GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name I eith Lopez Title petroleum Engineer Signature Phone Date 564-5718 2/22/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY nd Numb S it t t ti ~`~' J 3~~"C/ er: , ,, u ry ve may w ness a represen a Conditions of approval: Notify Commission so tha Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: /D . ~/0 y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: c~3DMS FEB 2 5 1010 ~1 ~ ~ ~ ~ ~ K ~ ~ z •z3 •lo ~~ ~.. z.z~,~ Form 10-403 Revised 12/2009 Submit in Du=ma'y'/L1 MPJ-19A 195-170 PFRF ATTArHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPJ-19A 6/21/96 PER 5,498. 5,524. 4,080.57 4,100.85 MPJ-19A 6/22/96 PER 5,413. 5,455. 4,014.5 4,047.1 MPJ-19A 6/24/96 PER 5,231. 5,260. 3,874.71 3,896.78 MPJ-19A 6/26/96 PER 5,275. 5,279. 3,908.24 3,911.3 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • To: Mark O'Malley /Nathan Leonard Wells Operations Supervisor From: Keith Lopez Milne Point Tract 14 Production Engineer CC: Giovanna Boccardo Milne Point Viscous Team Lead Date: February 18, 2010 Subject: MPJ-19A Second Injection Test and Acid • by l~~S. ~'s~~ IOR: 230-BOPD AFE: MSD331052 Ste Unit Operation 1 S Dumm OA and Pull OB WFRV 2 F Bullhead Acid to OB Zone and injection tests. 3 S Install WFRV's OBJECTIVE The objective of this work is to acidize the OB zone and conduct injectivity tests into both zones. BACKGROUND MPJ-19 was originally drilled in 1995 as a Kuparuk producer but was found to be wet in those sands. It was then side-tracked and completed as a Schrader producer in the N/OA/OB sands. All three zones were completed with separate Frac Pack screen completions. The OA and OB Frac Packs treated very poorly placing 7.6 and 5.5 thousand pounds of sand respectively into the perfs. The N sand Frac Pack placed 49 thousand pounds of sand behind perfs and pipe. This well produced with an ESP fairly uneventfully for the past 12+ years. Recently, the well was converted to a regulated injector by pulling the previous completion and running a tri-zonal injection completion with gas lift mandrels. The rig report noted significant scale buildup on the OB screen section when it was pulled out of the hole. The initial injectivity tests were conducted but IFIX was not showing a rate reading. Then, WFRV's with checks were installed and it was put on injection. The well is currently injecting 330 bwpd at 1000 psig, significantly lower then expected. Evaluation of the downhole pressure gauges suggests that the OA zone is taking the 300 bwpd the valve is rated for and the OB is taking minimal • rate. The evidence for this is that the OA valve is holding a differential pressure of 800 psig, indicating that the valve is actively restricting the flow as designed. The plan forward is to isolate the OA zone and pull the WFRV in the OB. We will then bullhead acid and allow it to soak on the OB perforations (it may be necessary to pump over frac pressure to place the acid). We will then conduct an injectivity test in the OB, replace the WFRV in the OB (re-running the same valve after visually inspecting), pull the dummy in the OA and conduct a second injection test thru the OB WFRV and the OA open pocket. Last we'll replace the OA WFRV (re-running the same valves after inspecting is okay) and place on injection targeting 800 bwpd without exceeding 1000 psig. Both WFRV's (either new or re-run) should have check valves so accurate zonal buildups can be seen with the sandface gauges. Injection Rate: Tubing size and type: Minimum ID and depth: Last TD tag (depth/date): Maximum deviation in well: Last SBHP: SCOPE: 330 bwpd @ 985 psig 3-1/2" 9.3# L-80 8rd EUE 2.750" NoGo XN-nipple @ +/- 5562' MD 5634' MD on 12/27/09 65.45° @ 3205' MD. 1397 psi @ 4000' TVDss on 12/11 /09 1. MIRU SL. 2. RIH & pull WFRV in MMG-W @ 5465' and replace with a dummy. 3. RIH & pull WFRV in MMG-W @ 5533'. 4. MIRU pump truck and pump 5 bbls MEOH spacer. Pump 30 bbls of 12% HCI DAD acid @ 0.5 bpm without exceeding 2000 psig tubing pressure. Pump 5 bbls MEOH spacer. Flush to perfs with 30 bbls of produced water. NOTE: There is a higher then usual max pressure given here due to the poor injectivity of the zone. However, the idea is to bullhead the acid downhole at a reasonable rate at minimum tubing pressure. 5. Allow acid to soak for 2 hours before flushing away into formation. 6. Put well on injection for 1 hour at a stabilized pressure of 800 psig. (Check in control room that IFIX is recording injection rates and pressures) 7. Increase injection pressure to 1000 psig, stabilize and record data for 1 hour. 8. Increase injection pressure to 1200 psig, stabilize and record data for 1 hour. 9. RIH & set WFRV w/ check rated for 500 bwpd in MMG-W @ 5533' (we can re-run the same WFRV after visual inspection). • 10. RIH & pull dummy in the MMG-W @ 5465' MD. 11. Put well on injection (in the commingled zones) for 1 hour at a stabilized pressure of 800 psig recording data. 12.Increase injection pressure to 1000 psig, stabilize and record data for 1 hour. 13.Increase injection pressure to 1200 psig, stabilize and record data for 1 hour. 14. RIH w/WFRV with check valve rated for 300 bwpd and install in the MMG- W @ 5465' (we can re-run the same WFRV after visual inspection). 15. Put the well on injection with targets of 800 bwpd without exceeding max injection pressure of 1000 psig. Contacts: Keith Lopez 564-5718 (W) or 903-5432 (C) Tree: 3 1/8" - 5M FMC Wellhead: 11" 5M FMC w/ 3 1/8" FMC Tubing Hanger , 3 1/2" TC-II T&B Thread. 2.5" CIW `H' BPV profile MPU J-19A 115' KOP @ 500' Kicked off original hole at 3795' and Max hole angle = 61 deg. at 3750' 3 1/2" 9.3 ppf, L-80, 8rd EUE Tbg ( drift ID = 2.867", cap. = 0.0087 bpf) . 7" 26 ppf, L-80, BTC Csg. (drift ID = 6.151", cap = 0.0383 bpf ) ( cap w/ 3 1/2" inside = 0.0264 ) Two 7" x 20' marker joints from 4799' to 4839` wlm w/ RA tag at 4799' wlm - ~. o ~, ~ E Size SPF Interval (TVD) 'N' Sand 4.5" 12 5231' - 5260' (3875'-3897') 4.5" 12 5275' - 5279' (3908'-3911') ~ 'OA' Sand 4.5" 12 5413' - 5455' (4014'-4047') 'OB' Sand 4.5" 12 5498'-5524' (4079'-4101') 20" 91.1 ppf, H-40 9 5/8", 40 ppf, L-80 BTC. 3391' Perforation Summary Ref log:11/08/95 GR/ CCL/Temp./ Press. 12 SPF 4-1/2" Jumbo Jet charges 26 GR @ 135/45 deg. phasing Orig. DF. Elev. = 64.5' (N 22E) Orig. GL. Elev. = 35.6' RT To 7" Csg Hgr = 28.9' (N 22E) 3.5" HES X-Nipple (2.813" pkg.) 209$` 3.5"HES X-Nipple (2.813" pkg.) 5070` 7" x 3.5"HES MFA Dual Pkr 5115` 3.5"HES X-Nipple (2.813" pkg.). 5124` 3.5"NDPG Single Sub 5126` 3.5" x 1.5" Camco MMG GLM 5189` 3.5" x 1.5" Camco MMG-W GLM 5280` 7" x 3.5"HES MFA Dual Pkr 5303` 3.5" HES X-Nipple (2.813" pkg.) 5312` 3.5"NDPG Single Sub 5313` 3.5" x 1.5" Camco MMG GLM 5376` 3.5" x 1.5" Camco MMG-W GLM 5465` 7" x 3.5"HES MFA Dual Pkr 5483` 3.5"HES X-Nipple (2.813" pkg.) 5492` 3.5"NDPG Single Sub 5493` 3.5" x 1.5" Camco MMG-W GLM 5533` 3.5"HES XN-Nipple (2.813" pkg.) 5562` 2.75" No-Go 3.5" WLEG 5595` 7" float collar (PBTD) 5642' 7" 26#, L-80, BTC 5 728' STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO OF SUNDRY WELL OPERA~NS ~,~C~IVED JAN ~ 1 2010 ._ _. 1. Operations Performed: ~~ '~ ~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended~l8~sl'~QA ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Convert from Producer to Injector 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 195-170 3. Address: ®Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22607-01-00 7. Property Designation: ~ 8. Well Name and Number: ADL 025906 & 025517 MPJ-19A 9. Field /Pool(s): ~ Milne Point Unit / Schrader Bluff Oil Pool 10. Present well condition summary Total depth: measured ~ 5750' feet true vertical ~ 4278' feet Plugs (measured) None Effective depth: measured 5642' feet Junk (measured) None true vertical 4193' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' ~ ""1490 470 Surface 3360' 9-5/8" 3391' 2713' 5750 3090 Intermediate Production 5699' 7" 5728' 4260' 7240 5410 Liner ~k~~+D 1ii8~i~ ~ t,.. it f. tiH ~ ~ ~~ Perforation Depth: Measured Depth: 5231' - 5524' True Vertical Depth: 3875' - 4101' Tubing (size, grade, measured and true vertical depth): 3-1 /2", 9.3# L-80 i~ 5595' ~'- ~ ~ Z 4156' 115' TQ~ PK2 3787 Packers and SSSV (type, measured and true vertical depth): 7" x 3-1/2" HES MFA Dual Packers (3) 5303' 3930' 5483' 4069' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing. Pull screen assemblies and packers. Run new 3-1/2" completion. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ^ Development ®Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram ~ Well Status after work: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ®WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 309-358 ~ Printed Name Terrie Hubble Title Drilling Technologist ? 1 Prepared By Name/Number. D t O` (~'' (~ ~ Ph a e Signature one 564-4628 Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 RBDMS JAN 2 2 2010 Submit Original Only I• zZ' id. //_~'/ • • ~` MPJ-19A, Well History (Pre Rig Workover) Date Summary 11/30/2009 T/I/0=600/1250/160 Lateral Flush Pre RWO. Pumped 2 bbls 60/40 methanol, 3 bbls diesel & 2 bbls 60/40 methanol down FL & Test line. DSO notified swab wing ssv shut, master is oa open. FW HP's=600/1250/160 12/1/2009 WELL S/I ON ARRIVAL. DRIFT W/ KJ, 2.13" CENT, 5' x 2" DRIVE DOWN BAILER. SD C~3 5082' SLM, RECOVERED 1 CUP OF SAND. R/D EQUIPMENT. JOB COMPLETED. WELL LEFT S/I. 12/4/2009 WELLSHUT IN UPON ARRIVAL. INITIAL T/I/O: 1200 / 1200 / 200 PSI SHOOT TUBING PUNCH LOADED WITH SMALL CHARGES ACROSS INTERVAL 5054' - 5056'. 9 SHOTS TOTAL. T/I/O = 1200 / 1200 / 200 PSI BEFORE FIRING, 1180 / 1250 / 200 PSI AFTER FIRING. FINAL T/I/O: 1180 / 1250 / 200 PSI. JOB COMPLETE. WELL LEFT SHUT IN. 12/5/2009 T/I/0=1300/1200/200. (Injectivity test/ Post tbg shot). Pump 40 bbls diesel/crude mixture down tbg for Injectivity test. Test results = 1.4 bpm C>? 1500 psi. FWHP=1200/1200/200. 12/10/2009 WELL S/I ON ARRIVAL. R/U SLICKLINE EQUIPMENT FOR RIG PREP. 12/11/2009 MPU set BPV with slick-line. BPV installed. 12/11/2009 PULLED 1" DPSOV & SET 1" DGLV C~ 90' MD. RIH W/2.06" CENT,S.S, DUAL SPARTEK GAUGES. MADE 30 MINUTE STOP C~ 4500' SLM & 3 HOUR STOP C~ 5079' SLM. BPV IN HOLE. WELL S/I ON DEPARTURE. DSO NOTIFIED. Page 1 of 1 • - B'P EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date- From - To Hours ..Task Code NPT Phase Description of Operations 12/15/2009 12:00 - 14:30 2.50 MOB P PRE RIG DOWN OPERATION - SCOPE DOWN AND LAY OVER DERRICK. 14:30 - 16:30 2.00 MOB P PRE MOVE PITS, PIPE SHED AND SUB OFF WELL. -PICK UP RIG MATS AND HERCULITE AROUND WELLHEAD. 16:30 - 22:00 5.50 MOB P PRE MOVE RIG COMPONENTS FROM MPL-02 TO MPJ-19 -AOGCC GIVEN 24-HR. NOTICE OF IMPENDING BOPE TEST. -NOTICE GIVEN AT 19:45-HRS. ON 12/15/2009. 22:00 - 00:00 2.00 MOB P PRE SPOT SUB, PITS AND PIPESHED. -HOOK UP LINES BETWEEN SUB AND PITS. 12/16/2009 00:00 - 04:00 4.00 RIGU P PRE SPOT SUB, PITS AND PIPESHED. -HOOK UP LINES BETWEEN SUB AND PITS. -RU, SPOT TIGER TANK AND HOOK UP LINES. -RU CIRCULATING LINES TO TREE WING VALVE AND IA. 04:00 - 06:00 2.00 RIGU P PRE RAISE AND SCOPE DERRICK. 06:00 - 09:00 3.00 RIGU P PRE CONTINUE TO RIG UP. -SPOT AND RU SPOOLING UNIT. -FINISH RU LINES TO TIGER TANK. -THAW OUT SUCTION CONNECTION. -LOWER BEAVERSLIDE. MPU HEAVY EQUIPMENT ON STAND DOWN DUE TO TEMPERATURE. *** RIG ACCEPTED AT 06:00 **** 09:00 - 10:00 1.00 WHSUR P DECOMP PICK UP DSM LUBRICATOR AND FILL WITH DIESEL -TEST TO 500 PSI -PULL BPV AND LAY DOWN NOTED THAT THE SWAB VALVE AND MASTER VALVE ARE LEAKING. 10:00 - 11:00 1.00 KILL P DECOMP PJSM FOR WELL KILL -NABOBS CREW, CH2MHILL TRUCK DRIVERS AND WSL. -DISCUSSED WELL KILL PROCEEDURE. -CONGESTED PAD AND TRUCK STAGING. -WORKING OUTSIDE USING BUDDY SYSTEM. TAKE ON 8.45 PPG, 120 DEG F SEAWATER TO PITS. 11:00 - 13:00 2.00 KILL N RREP DECOMP TROUBLE SHOOT MUD PUMP. -OIL PUMP WOULD NOT TURN ON. -USED STEAM HOSES TO THAW OUT MUD PUMP. 13:00 - 13:30 0.50 KILL P DECOMP TEST CIRCULATING LINES TO CHOKE TO 3500 PSI. TEST LINES TO TIGER TANK W/ AIR TO 250 PSI. -OPEN WELL TAKE PRESSURES -IA=1150 - OA=145 - T=1080 13:30 - 16:00 2.50 KILL P DECOMP WELL KILL -BLEED IA AND TBG THROUGH CHOKE TO TIGER TANK. -PUMPED 30 BBLS. OF 120E SEAWATER DOWN TUBING AT 4.5-BPM -NO RETURNS TO SURFACE. -IA=50 - OA=175 -TBG=80 Nrinted: inuruio rr.'srt~rnn • K Legal Well Name: MPJ-19 BP EXPLORATION Page 2 of 18 Operations Summary Report... Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of,Operations 12/16/2009 13:30 - 16:00 2.50 KILL P DECOMP CLOSED CHOKE AND BULLHEADED 27 BBLS DOWN TBG. -IA=120 -TBG=90 OPENED CHOKE AND CONTINUED CIRCULATING DOWN THE TBG. -PUMPED 130 BBLS AND STARTED GETTING RETURNS. -PUMPED 294 BBLS UNTIL RETURNS CLEANED UP. PUMPED A TOTAL OF 427 BBLS GOT BACK 220 BBLS TO THE TIGER TANK. SHUT DOWN PUMPING AND MONITORED WELL FOR 20-MINUTES. -TBG. AND IA ON VACUUM. OA=300 PSI 16:00 - 20:00 4.00 WHSUR P DECOMP (FMC) SET TWC WITH T-BAR -TESTED FROM ABOVE TO 3500 PSI FOR 10 CHARTED MIN -CONDUCTED ROLLING TEST FROM BELOW INJECTED 61 BBLS, REACHED 500 PSI. 20:00 - 22:00 I 2.001 WHSUR I P 22:00 - 00:00 2.00 KILL P 12/17/2009 00:00 - 03:00 3.00 BOPSU P DECOMP ND PRODUCTION TREE AND ADAPTER FLANGE. -TREE WILL STAY ON LOCATION DECOMP NU BOPE. TEST EQUIPMENT. DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: -CALLED AOGCC AN HOUR BEFORE TESTING BEGAN. DIRECTION WAS GIVEN THAT IF NO CALL BACK WAS MADE THAT THE WITNESS WAS BEING WAIVED -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 3 1/2" TEST JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED KELLY -BOB NOBLE WAIVED AOGCC RIGHT TO WITNESS BOP TESTING AT 11:00-HRS. ON 12/16/2009. 03:00 - 06:00 3.00 BOPSU N WAIT DECOMP OPERATIONS SHUT DOWN DUE TO DIESEL SPILL DURING FUEL TRANSFER BETWEEN BULK TANK AND DAY TANK -DRILLER WAS INSTRUCTED TO SHUT IN BOP TESTING, BLOW DOWN THE LINES AND MONITOR WELL WITH CONTINUOUS HOLE FILL. UNTIL THE DIESEL SPILL COULD BE RESOLVED 06:00 - 09:30 3.50 BOPSU P DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: -CALLED AOGCC AN HOUR BEFORE TESTING BEGAN. DIRECTION WAS GIVEN THAT IF NO CALL BACK WAS MADE THAT THE WITNESS WAS BEING WAIVED -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 2-7/8" AND 3 1/2" TEST Printed: 1/11/2010 12:37:13 PM • BP EXPLORATION- - Page 3 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code ' NPT Phase Description of Operations 12/17/2009 06:00 - 09:30 3.50 BOPSU P DECOMP JOINTS. -TESTED ANNULAR WITH 2-7/8" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED KELLY 09:30 - 11:00 I 1.501 BOPSUR P 11:00 - 12:30 ~ 1.50 ~ BOPSUF{ P 12:30-14:00 ~ 1.50~WHSUR~P 14:00 - 15:30 I 1.501 PULL I P 15:30 - 16:00 0.50 PULL P 16:00 - 00:00 8.00 PULL P 12/18/2009 100:00 - 02:00 I 2.001 PULL P 02:00 - 04:30 ~ 2.50 ~ PULL ~ P 04:30 - 10:00 I 5.50) PULL I P 10:00 - 11:00 I 1.001 PULL I P 200 PSI BUILD UP FROM 1600 PSI = 48 SECONDS. -FULL BUILD UP TO 3000 PSI = 175 SECONDS. -4 BOTTLES x 1670 PSI. -BOB NOBLE WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 11:00-HRS. ON 12/16/2009. DECOMP RU DUTCH SYSTEM RISER -M/U LUBRICATOR AND EXT -TEST LUBRICATOR TO TO 500 PSI FOR FIVE MIN. DECOMP PULL TWC -UD LUBRICATOR -R/D DUTCH SYSTEM. -TAKING ON SEAWATER DECOMP MU LANDING JNT -PULL TBG HANGER. -FMC BACKED OUT LOCK DOWN SCREWS. LLED 2- /8" TUBING HANGER. -PULL OFF SEAT AT 33-K WITH 34-K PUW. -BREAK OUT LAY DOWN HANGER. DECOMP CIRCULATED BOTTOMS UP -CIRCULATED AT 4 BPM ~ 700 PSI -24 BBLS TO FILL , 2617 TOTAL STROKES -LOST 26 BBLS WHILE CIRC -RU E-T-TRUNK SPOOL DOUBLE LINE TO SHEAVE AND DRAIN HOSE DECOMP RIG SERVICE DECOMP P I N ASSEMBLY & CABLE WITH HEAT TRACE -LD PUP JOINTS -RESTORE ROPE IN TRUNK AND SHEAVE -SECURE HEAT TRACE AND ESP TO SPOOLS -LAYING DOWN TO PIPE SHED 2-7/8' TBG. DECOMP POH W/ 2-7/8" ESP COMPLETION ASSEMBLY & CABLE WITH HEAT TRACE -LAYING DOWN TO PIPE SHED 2-7/8' TBG. DECOMP DISCONNECT HEAT TRACE. -REMOVE SPOOL FROM SPOOLER -BUILT BERM ON PAD FOR TUBING DECOMP CONTINUE POH W/ 2-7/8" ESP COMPLETION -LAYING DOWN TO THE PIPE SHED -LD MOTOR -TOTAL OF 160 JNTS -TOTAL OF 1390 BANDS RECOVERED DECOMP CLEAN AND CLEAR RIG FLOOR Printed: 1/11/2010 12:37:13 PM • BP EXPLORATION Page 4 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From -,To Hours Task Code NPT Phase Description of Operations 12/18/2009 10:00 - 11:00 1.00 PULL P DECOMP -LD FLAT GUARDS AND BANDS -RD PIPE HANDLING EQUIPMENT 11:00 - 15:30 4.50 PULL P DECOMP BLEED DOWN IA -CONNECT 2" LINE F/ OA TO THE TIGER TANK. -BLED DOWN FROM 160 PSI TO 0 15:30 - 18:00 2.50 WHSUR P DECOMP PULL 7" PACK OFF THROUGH THE STACK PER FMC. -INTALL NEW 7" PACK OFF PER FMC. -TEST PACK OFF TO 5000 PSI FOR 30 MIN, GOOD TEST 18:00 - 18:30 0.50 WHSUR P DECOMP INSTALL 7.0" I.D. WEAR RING. 18:30 - 00:00 5.50 EVAL P DECOMP PU RIH W/ 3-1/2" DP AND 7" RTTS -PU SINGLES FROM PIPE SHED -RIH W/ 164 JNTS PLUS 24 JNT TO 5,138' -PU 5' SET PACKER AT 5130' -PUW -54 K SOW-47 K -PRESSURE TEST CSG TO 2500 PSI FOR 30 MIN (GOOD TEST) 12/19/2009 00:00 - 01:30 1.50 EVAL P DECOMP PU RIH W/ 3-1/2" DP AND 7" RTTS -PU SINGLES FROM PIPE SHED -RIH W/ 164 JNTS PLUS 24 JNT TO 5,138' -PU 5' SET PACKER AT 5130' -PUW -54 K SOW-47 K -PRESSURE TEST CSG TO 2500 PSI FOR 30 MIN (GOOD TEST) 01:30 - 02:00 0.50 EVAL P DECOMP ONSET RTTS AND ALLOW ELEMENTS TO RELAX -RESET VALVE TO OPEN 02:00 - 04:00 2.00 EVAL P DECOMP POH W/ 3.5" DP STANDING BACK IN DERRICK - 54 STANDS -BREAK OUT AND LD 7" RTTS 04:00 - 07:30 3.50 EVAL P DECOMP CLEAN AND CLEAR RIG FLOOR -RU DUTCH SYSTEM -RU TO RUN WIRELINE, AND USIT LOGS 07:30 - 14:00 6.50 EVAL P DECOMP PJSM WITH CREW AND SLB -SPOTTING WIRELINE EQUIPMENT -SLB CREW CHANGE ~ 08:00 -PJSM W/NEW CREWS -PU / MU USIT LOG TOOLS,WIRELINE BOP, 5K WIRELINE WIPER -PRESSURE TEST GOOD 14:00 - 18:00 4.00 EVAL P DECOMP SIT LOG TOOL -GUAGE RING 6.12" -REACHED BOTTOM AT 5,134' ,TOOL NOT WOKING POSSIBLE SOFTWARE FAILURE -POOH TO CHECK MOTOR, HALF WAY OUT AT 3,830' THE MOTOR REENGAGED DECISION WAS MADE TO GO BACK TO BOTTOM TO GET LOGS. -ON THE WAY BACK TO BOTTOM WAS PUSHING SOMETHING HAD TO PULL BACK UP TWICE ,ONCE ~ 3,500' AND ONCE 4,265' HAD TO PULL 1000 K OVER TO GET OFF. THIS KEPT SHUTTING THE MOTOR DOWN. -CALL WAS MAD TO TOWN ENGINEER AND DECISION WAS MADE TO HAVE A WIRELINE JUNK BASKET Printed: 1/11/2010 12:37:13 PM BP EXPLORATION Page 5 of 1 s Operations-Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2009 14:00 - 18:00 4.00 EVAL P DECOMP BROUGHT OUT AND RIH. 18:00 - 19:30 1.50 EVAL P 19:30 - 00:00 4.50 EVAL P 112/20/2009 100:00 - 01:00 I 1.00 I EVAL I P 01:00 - 04:00 I 3.001 EVAL I P 04:00 - 07:00 ~ 3.00 EVAL P 07:00 - 14:00 I 7.001 EVAL I P 14:00 - 21:30 I 7.50 I EVAL I P 21:30 - 22:30 I 1.001 EVAL I P 22:30 - 00:00 I 1.501 EVAL I P POOH W/ USIT LOG TOOLS DECOMP WAIT ON WIRELINE JUNK BASKET. DECOMP PU AND RIH WIRELINE JUNK BASKET AND GUAGE RING. -RIH TO 5,134' -GUAGE RING 6.12" -HAD ONE BOBBLE ON THE WAY IN HAD TO PULL BACK UP, TOOK 500 OVER TO PULL OFF BOTTOM -FIRST RUN WITH JUNK BASKET RETRIEVED 7 STAINLESS BANDS -RAN BACK IN WITH JUNK BASKET FOR SECOND RUN -SECOND RUN SAW ONE SMALL BOBBLE COMING BACK OUT TOOK 200-300 OVER TO PULL OFF. -SECOND RUN PRODUCED BACK IN FOR THIRD RUN WITH JUNK BASKET RAN SMOOTH TO BOTTOM AND NO BOBBLES ON THE WAY BACK OUT -THE THIRD RUN PRODUCED ONE BAND IN JUNK BASKET. DECOMP FINISHED RIH WITH THIRD JUNK BASKET RUN -RAN SMOOTH TO BOTTOM 5,134' - NO BOBBLES ON THE WAY BACK OUT -THIRD RUN PRODUCED ONE BAND IN JUNK BASKET. -TOH DECOMP RIGGING UP 2ND USIT LOG TOOL. -RIH ON WIRELINE W/ USIT LOG TO 5,100' -PUW 1780K -LOGGED F/ 5,100' TO 100' -TOC ~ 3,396' DECOMP RIGGING DOWN E-LINE -LD USIT AND WIRELINE BOP, LUBRICATOR DECOMP PU, MU RIH W/ HALLIBURTON PACKER PULLING TOOL AND BHS ON 3-1/2" 15.5# DP, -RIH TO JUST ABOVE PACKER ~ 5,151' BHA AS FOLLOWS: -HES 7" VTL RETRIEVAL TOOL -4-3/4" BOWEN BUMPER JAR, OIL JAR -(9)4-3/4" DRILL COLLARS -4-3/4" PUMP OUT SUB DECOMP GATHERED BOTH BP AND NABOBS RIG LEADERSHIP AND BOTH RIG CREWS AT MILNE POINT GYM FOR CHECK SIX SAFETY LEADERSHIP TRAINING. DECOMP PJSM W/ RIG CREW, HALLIBURTON AND BAKER FISHING -PRE TOUR CHECKS -PU/MU KELLY DECOMP CONT RIH W/ 7" VTL PACKER PULLING TOOL -RIH TAG 16' INTO KELLY AT 5,167' -PUW-70K SOW-56K -FILL THE HOLE -PUW-74 K ,SOW-60 K AFTER HOLE FILL. -PULLED UP 10 K OVER TO 84 K TO RELAX THE JARS, WT CAME DOWN F/84K TO 79K IN 6 MIN. Printed: 1/11/2010 12:37:13 PM • • BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT .Phase Description of Operations 12/20/2009 22:30 - 00:00 1.50 EVAL P DECOMP -PU 90K, 16 K OVER TO SHEAR THE PACKER RELEASING SLEEVE. -PU 65 OVER TO 140 K TO SHEAR THE RELEASING TOOL. -PICKED UP OFF THE PACKER -SET BACK DOWN TO THE BUMPER SUB ,MADE 1/4 TURN TO THE LEFT TO LATCH THE PACKER PULLING TOOL IN THE PACKER. -PU 10K OVER AGAIN TO RELAX THE JARS, WAITED SIX MIN. -PU 40K OVER TO 114 K., CIRCULATED 1.5 BPM ~ 750 PSI, SLACKED OFF TO NEUTRAL -REPEATED THIS ACTION ANOTHER THREE TIMES, WAITING - 10 MIN IN BETWEEN. -INCREASED THE PU WT TO 125 K , 50 K OVER, SLACKING OFF TO NEUTRAL WT SEVERAL TIMES. -FINALY INCREASED PU WT TO 140K , 65 K OVER , 12/21/2009 100:00 - 02:00 I 2.001 FISH I P 02:00 - 04:30 ~ 2.501 FISH P 04:30 - 10:00 5.501 FISH ~ P 10:00 - 11:30 I 1.501 FISH I P -PU WT AFTER PACKER SHEAR WAS 88 K. DECOMP CONT RIH W/ 7" VTL PACKER PULLING TOOL -RIH TAG 16' INTO KELLY AT 5,167' -PUW-70K SOW-56K -FILL THE HOLE -PUW-74 K ,SOW-60 K AFTER HOLE FILL. -PULLED UP 10 K OVER TO 84 K TO RELAX THE JARS, WT CAME DOWN F/84K TO 79K IN 6 MIN. -PU 90K, 16 K OVER TO SHEAR THE PACKER RELEASING SLEEVE. -PU 65 OVER TO 140 K TO SHEAR THE RELEASING TOOL. -PICKED UP OFF THE PACKER -SET BACK DOWN TO THE BUMPER SUB. ,MADE 1/4 TURN TO THE LEFT TO LATCH THE PACKER PULLING TOOL IN THE PACKER. -PU 10K OVER AGAIN TO RELAX THE JARS, WAITED SIX MIN. -PU 40K OVER TO 114 K., CIRCULATED 1.5 BPM ~ 750 PSI, SLACKED OFF TO NEUTRAL -REPEATED THIS ACTION ANOTHER THREE TIMES, WAITING _ 10 MIN IN BETWEEN. -INCREASED THE PU WT TO 125 K , 50 K OVER, SLACKING OFF TO NEUTRAL WT SEVERAL TIMES. -FINALY INCREASED PU WT TO 140K , 65 K OVER , SHEARED PACKER FREE FROM SCREEN. -PU WT AFTER PACKER SHEAR WAS 88 K. DECOMP CIRCULATING 2 BOTTOMS UP -PUMPED 270 BBLS ~ 2 BPM AT 1300 PSI -LOST 180 BBLS DURING CIRCULATION - 60 BPH LOSS RATE DECOMP POH WIITH HES PACKER ON 3-1/2" DP -PUW 76-85 K , _ 6-12 K OVER -TOH W/ 52 STANDS, STAND BACK 4-3/4" DRILL COLLARS -LD HALLIBURTON VTL PACKER. DECOMP PU / MU BHA# 2 WASH PIPE ASSEMBLY Printetl: 1/11/2010 12:37:13 PM • • BP EXPLQRATION Page 7 of 1'8' Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code. NPT .Phase Description of_Operations 12/21/2009 10:00 - 11:30 1.50 FISH P DECOMP BHA AS FOLLOWS: -6" X 5" SHOE -4 JNTS OF 5-3/4" TSS WASHPIPE W/ 5.0" I.D. -5-3/4" WASH OVER BOOT BASKET -4-3/4" BOW EN BUMPER JAR -4-3/4" BOWEN OIL JAR -(9) 4-3/4" DRILL COLLARS -4-3/4" BOWEN ACC JAR 11:30 - 15:00 3.50 FISH P DECOMP RIH WITH BHA # 2 ON 3-1/2" DP (51) STNDS -TAGGED UP ~ 5,194' W/ 51 STNDS , LD 1 JNT , PU 24' PUP -PU/,MU KELLY ESTABLISHED CIRCULATION SPR-26PM ~ 70 PSI 15:00 - 19:00 4.00 FISH P DECOMP -WASHED AND ROTATED TO 5,288' PARAMETERS: -WOB 2-5 K -BPM 2-5 -600-800 PSI ROT WT-63 K ,PUW-70 K ,SOW-57 K. 19:00 - 21:00 2.00 FISH P DECOMP CIRCULATED AND CONDITIONED -PUMPED 2 40 BBLS HIGH VIS SWEEPS -3-5 BPM ~ 770 PSI -HAD FULL CIRCULATION DURING SWEEPS W/ -12 BPH LOSS RATE -RETURNED SUBSTANTIAL AMOUNTS OF FRAC SAND -RETURNS CLEANED UP AFTER THE SECOND SWEEP 21:00 - 00:00 3.00 FISH P DECOMP POOH WITH BHA # 2 -PULLED UP TO THE 4-3/4" DRILL COLLARS 12/22/2009 00:00 - 01:00 1.00 FISH P DECOMP CONT TO PULL OUT WITH BHA # 2 -LD COLLARS ,SUBS ,JARS ,BOOT BASKET -SWAP OVER TO THE WASHEPIPE HANDLING EQUIPMENT -LD 4 JNTS OF 5-3/4" WASHPIPE AND SHOE -RETRIEVED 4 PIECES OF STAINLESS BANDS AND ONE ALUMINUM PLATE AND -1 GAL OF FRAC SAND OUT OF THE JUNK BASKET 01:00 - 01:30 0.50 FISH P DECOMP PJSM FOR PU AND RIH WITH OVERSHOT BHA # 3 -PU / MU OVERSHOT 01:30 - 04:00 2.50 FISH P DECOMP RIH WITH BHA # 3 BAKER OVERSHOT ON 3-1/2" DP -TIH W/ 52 STANDS, A SINGLE + 13' TO 5,195' BHA AS FOLLOWS: -5-3/4" OVERSHOT -BUMPER SUB -4-3/4" OIL JAR -3-1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS 04:00 - 09:00 5.00 FISH P DECOMP PU KELLY AND ENGAGE FISH -PUW-80K ,SOW-52K BEFORE MU THE KELLY -PUW-83K ,SOW-52K AFTER KELLY UP. -ESTABLISH CIRCULATION ~ 2.5 BPM ~ 230 PSI -SET DOWN 13' INTO THE KELLY W/ 10K DOWN. Printed: 1/11/2010 12:37:13 PM • BP EXPLORATION Page 8 of 18' Operations Summary Report. Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Spud Date: 10/16/1995 Start: 12/11 /2009 End: Rig Release: 12/31/2009 Rig Number: 4ES Date From - Ta Hours Task Code NPT 12/22/2009 04:00 - 09:00 5.00 FISH P Phase Description of Operations DECOMP -PU TO 95K , 12K OVER -SCREENS PULLED FREE ~ 95K, WITH WT COMING OFF SLIGHTLY THREE DIFFERENT TIMES -SET BACK DOWN 10K AGAIN ,SETTING DOWN 3' HIGHER THIS TIME. -PULLED BACK UP 95K , 12K OVER -ESTABLISH CIRCULATION TO CLEAR PIPE -RACK BACK KELLY, -POOH 08:00 - 11:30 3.50 FISH P DECOMP .OUT OF THE HOLE WITH BHA # 3 AND SCREENS. , -LD 102' OF 3-1/2" SCREENS -LD SCREEN HANDLING EQUIPMENT 11:30 - 17:30 6.00 FISH P DECOMP PU AND MAKE UP BHA # ,4 HALLIBURTON PACKER RETRIEVAL TOOL -RIH ON 52 STANDS -WASH DOWN JNTS 163-166 -KELLY UP -TAGGED UP 13.5' INTO KELLY ~ 5,272' -PUW-82K ,SOW-57K -PULLED UP 10 K OVER TO 92 K TO RELAX THE JARS, WAITED 7 MIN FOR JARS TO RELAX -PU 100K, 18 K OVER TO SHEAR THE PACKER RELEASING SLEEVE. -PU 65 OVER TO 147 K TO SHEAR THE RELEASING TOOL. -PICKED UP OFF THE PACKER 5' -CIRCULATED HIGH VIS SWEEP , 2.5 BPM ~ 1335 PSI 17:30 - 22:30 5.00 FISH P DECOMP LATCH SPEAR INTO PACKER -SET DOWN 10 K ,MAKE 1/4 TURN TO THE LEFT TO LATCH THE PACKER PULLING TOOL IN THE PACKER. -PU 10K OVER AGAIN TO RELAX THE JARS, WAITED SIX MIN. -PU TO 125 K , 43 K OVER, SLACKING OFF TO 80 K A COUPLE OF TIMES. -PU TO 156K , 76K OVER , SO TO 80K -PU TO 162 K , 80 K OVER, SO TO 95K HOLDING 15 K ON THE STRING. -TURNED ON PUMPS TO ESTABLISH CIRCULATION, NOT ABLE TO ESTABLISH CIRCULATION. -UNSTUNG FROM PACKER AND ESTABLISHED CIRCULATION RIGHT AWAY -CIRCULATED BU WHILE WORKING THE PIPE DOWN INTO THE PACKER A FEW TIMES STUNG BACK IN TO PACKER AND RESUMED PULLING -SET BACK DOWN 10 K AND MADE 1/4 TURN TO THE LEFT, GOT STUNG IN. -PULLED 15 K OVER TO RELAX THE JARS, WAITED 6 MIN. -PU 160 K , 80 K OVER --PU 170 K , 90 K OVER -PU 183 K , 100 K OVER -BEGAN WORKING UP AND DOWN - PU 200 K, PACKER PULLED FREE W/ 120 K OVER. -PUMPED THE FIRST JNT OUT 0.5 BPM ~ 275 PSI , PUW-74 K WITH PUMP ON Printed: 1/11/2010 12:37:13 PM C BP EXPLORATION Page 9 of 1 s Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/22/2009 17:30 - 22:30 5.00 FISH P DECOMP -PULLED THE NEXT THREE JNTS WITH NO PUMP ON , LAYING THEM DOWN TO THE PIPE SHED OVER PULL RANGING FROM 4 TO 6 K. 22:30 - 00:00 1.50 FISH P DECOMP ATTEMPTED TO CIRCULATE A BOTTOMS UP. -NOT GETTING GOOD CIRCULATION -PULLED UP 5 STANDS , WTIH NO OVER PULL RESUMED BOTTOMS UP CIRCULATION ~ 1.5 BPM @ 600 PSI PSI ,FINAL CIRCULATING PRESSURE 12/23/2009 00:00 - 01:00 1.00 FISH P DECOMP CONTINUED BOTTOMS UP CIRCULATION ~ 1.5 BPM ~ 600 PSI PSI ,FINAL CIRCULATING PRESSURE 01:00 - 01:30 0.50 FISH P DECOMP RD CIRCULATION EOPT -PJSM FOR PULLING OUT OF THE HOLE WITH DP 01:30 - 04:00 2.50 FISH P DECOMP POOH WITH BHA # 4 -PULLING SECOND PACKER OUT ON 3-1/2" DP. -SLIGHT OVER PULL 5-15 K. 04:00 - 06:00 2.00 FISH P DECOMP LAYING DOWN HALLIBURTON RETRIAVAL TOOL AND SECOND VTL PACKER. 06:00 - 07:30 1.50 FISH P DECOMP PU / MU BHA# 5 WASH PIPE ASSEMBLY BHA AS FOLLOWS: -6" X 5" SHOE -5 JNTS OF 5-3/4" TSS WASHPIPE W/ 5.0" I.D. -5-3/4" WASH OVER BOOT BASKET -4-3/4" BUMPER SUB -4-3/4" BOWEN OIL JAR -3 1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS -4-3/4" INTENSIFIER JAR -TBHA= 470.39' 07:30 - 08:00 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECK. 08:00 - 10:30 2.50 FISH P DECOMP RIH WITH BHA #5 FROM DERRICH ON 3 1/2" DP T/ 5,316' MD 10:30 - 13:00 2.50 FISH P DECOMP WASH OVER -P/U KELLY -WASH OVER F/ 5,316' T/ 5,410' MD -3 BPM / 280 PSI -45 RPM / 180 AMPS TO -POW = 82 K, SOW = 56 K, FRW = 66 K. -CBU w/ 40 BBL HI-VIS SWEEP. -RECOVERED 2 YRDS FRAC-SAND 13:00 - 19:30 6.50 FISH P DECOMP CONTINUE TO WASH OVER -F/ 5 410' T/ TOP OF PACKER ~ 5,465' MD -CBU 4 TIMES W/ HI-VIS SWEEPS -RECOVERED 4 YRDS FRAC-SAND 19:30 - 22:30 3.00 FISH P DECOMP POOH W/ BHA # 5 WASH PIPE ASSEMBLY -POH F/5,465' -NO FLUID LOSS DURING TRIP - HAD SMALL AMOUNT OF FRAC SAND AND 5 PIECES OF METAL BANDING IN JUNK BASKET 22:30 - 23:30 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR Printed: 1/11/2010 12:37:13 PM Legal Well Name: MPJ-19 BP EXPLORATION Page 10 of 1 s - Operations Summary. Report Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To ..Hours Task Code NPT Phase Description of Operations 12/23/2009 22:30 - 23:30 1.00 FISH P DECOMP -LD WASH PIPE HANDLING EQUIPMENT 23:30 - 00:00 0.50 FISH P DECOMP PU / MU BHA# 6 OVERSHOT ASSY ASSEMBLY 12/24/2009 100:00 - 00:30 I 0.501 FISH I P 00:30 - 03:30 3.00 FISH P 03:30 - 05:00 I 1.501 FISH I P 05:00 - 06:00 1.00 FISH P 06:00 - 06:30 0.50 FISH 06:30 - 09:00 2.50 FISH P 09:00 - 09:30 0.50 FISH P 09:30 - 11:30 2.00 FISH P 11:30 - 12:00 0.50 FISH P 12:00 - 13:30 1.50 BOPSU P 13:30 - 14:30 1.00 BOPSU~ P 14:30 - 20:00 5.50 BOPSU P BHA AS FOLLOWS: -5-3/4" 150 OVERSHOT -BUMPER SUB -4-3/4" OIL JAR -3-1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS -TBHA = 300.71' DECOMP PU / MU BHA# 6 OVERSHOT ASSEMBLY BHA AS FOLLOWS: -5-3/4" 150 OVERSHOT -BUMPER SUB -4-3/4" OIL JAR -3-1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS -TBHA = 300.71' DECOMP RIH W/ BHA # 6 OVERSHOT ASSEMBLY -RIH W/ 53 STANDS -1 DOUBLE -KELLY UP -TAG UP 10' INTO KELLY ~ 5,316' -PUW - 84K ,SOW - 57 K ,ROT WT - 67K -SET DOWN, ROTATE OVER WITH PUMPS ON SAW A 60 PSI INCREASE --PU TO 95K , 10 K OVER, TAGGED 4' HIGHER. -GOT FISH ,ESTABLISH CIRCULATION. DECOMP POOH WITH 5 STANDS -CIRCULATE BOTTOMS UP. -CIRCULATE l~ 5 BPM C~ 400 PSI. -PREPARE TO SLIP AND CUT DRILL LINE DECOMP SLIP AND CUT DRILL LINE DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. DECOMP POH F/ -4 850' w/ FISH. DECOMP PJSM, L / D SCREEN ASSEMBLY. DECOMP UD 3 BLANK JTS AND SCREEN ASSEMBLY. -TOP OF FISH ~ _ 5,465' -TOT= 156' OF SCREENS DECOMP CLEAN AND CLEAR RIG FLOOR. DECOMP FLUSH BOP STACK -PULL WEAR RING DECOMP INSTALL TEST PLUG -FUNCTION TEST BOPS. DECOMP TEST BOPE PER BP/AOGCC REQUIREMENTS: -TEST TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. -TESTED 2-7/8" X 5" VBR'S WITH 3 1/2" TEST JOINTS. -TESTED ANNULAR WITH 3 1/2" TEST JOINT. -EACH TEST WAS HELD FOR 5 CHARTED MINUTES. -TEST WITNESSED BY WSL & TP. -TESTED KELLY & FLOOR VALVES. Printed: 1/11/2010 12:37:13 PM Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Page 11 of 18 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code. NPT Phase Description of Operations 12/24/2009 ~ 14:30 - 20:00 5.50 ~ BOPSUq P ~ ~ DECOMP 20:00 - 22:00 2.00 RIGD P 22:00 - 23:30 1.50 FISH P 23:30 - 00:00 0.501 FISH I P 12/25/2009 100:00 - 02:00 I 2.001 FISH I P 02:00 - 03:00 1.00 FISH P 03:00 - 03:30 0.50 FISH P 03:30 - 04:30 I 1.001 FISH I P 200 PSI BUILD UP FROM 1700 PSI = 54 SECONDS. -FULL BUILD UP TO 3000 PSI = 178 SECONDS. -4 BOTTLES x 1600 PSI. -BOB NOBLE WAIVED AOGCC RIGHT TO WITNESS BOPE TESTING AT 06:30-HRS. ON 12/23/2009. DECOMP MOVE OFFICE AND KITCHEN FROM OLD CAMP TO REPLACEMENT CAMP. DECOMP PU AND MAKE UP BHA # ,7 HALLIBURTON PACKER RETRIEVAL TOOL BHA AS FOLLOWS: -HES RETRIEVAL TOOL -4-3/4" BUMPER SUB -4-3/4" BOWEN OIL JAR -3 1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS -TBHA= 298.20' INSTALL WEAR RING DECOMP RIH W/ BHA # ,7 HALLIBURTON PACKER RETRIEVAL TOOL. -RIH ON 54 STANDS DECOMP RIH WITH BHA #7 , HALLIBURTON PACKER RETRIEVAL -RIH ON 54 STANDS -WASH DOWN JNT# 165 AND A 24' PUP TO 5,453' DECOMP CIRCULATE BOTTOMS UP -PUMPING 145 BBLS , 2450 STROKES ~ 3 BPM, 1430 PSI DECOMP -KELLY UP -TAGGED UP 10.5' INTO KELLY ~ 5,465' -PUW-92K ,SOW-67K WASHED DOOWN TO ENGAGE PACKER -PULLED UP 10 K OVER TO 102 K TO RELAX THE JARS, WAITED 10 MIN FOR JARS TO RELAX -PU 114K, 20 K OVER TO SHEAR THE PACKER RELEASING SLEEVE. -PU 80 OVER TO 170 K TO ATTEMPT SHEAR THE RELEASING TOOL. -WAS NOT SURE IF WE SAW THE RELEASE SLEEVE OR THE PACKER SAFETY SHEAR SUB. -SET BACK DOWN 10K , PU 180 K , 90K OVER, SEEING ANOTHER SHEAR AND LOOSING WT BACK DOWN TO 125K. -PU 8' ,ESTABLISHED CIRCULATION -PUMPED THE FIRST JNT OUT 1.0 BPM ~ 330 PSI -TIME TO ALLOW PACKER ELEMENT TO RELAX DECOMP CIRCULATING BOTTOMS UP BP EXPLORATION Operations-Summary Report rnntea: ~nvzuiu iz:~r~srnn BP EXPLORATION Page 1';2 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From.- To .Hours Task Code, NPT Phase Description of Operations 12/25/2009 03:30 - 04:30 1.00 FISH P DECOMP -CIRCULATION RANGING FROM 2-3 BPM , AT 1400-1800 PIS -PRESSURE WAS COMING DOWN DURING CIRCULATION. 04:30 - 06:00 1.50 FISH P DECOMP PULLED THE NEXT THREE JNTS (F/ 5,465' T/ -5,370' MD) WITH NO PUMP ON ,LAYING THEM DOWN TO THE PIPE SHED OVER PULL RANGING FROM 4 TO 15 K. 06:00 - 06:30 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 09:00 2.50 FISH P DECOMP CONTINUE POH F/ _5,370' MD TO SURFACE w/ FISH. 09:00 - 10:00 1.00 FISH P DECOMP L/D THE FISHED PACKER -FISH = 156.94 -RECOVERED ONE STEEL BAND. -TO OF FISH f~ -5,494' MD 10:00 - 10:30 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. 10:30 - 12:00 1.50 FISH P DECOMP MU BHA #8 -6" SHOE -2 JTS 5.75" WASH PIPE -BOOT BASKET -BUMPER SUB -OIL JAR -PUMP OUT SUB -9 EC. 4.75" DC's -INTENSIFIER -TBHA = 375.64' 12:00 - 15:00 3.00 FISH P DECOMP RIH w/ BHA #8 -T/ 5,164' MD -WELL IS STATIC 15:00 - 20:30 5.50 FISH P DECOMP RIG CREWS SENT TO MILNE POINT BASE CAMP FOR CHRISTMASS DINNER. 20:30 - 22:00 1.50 FISH P DECOMP PJSM WITH NEW CREW -PLAN FORWARD DISCUSSION, DISCUSSED LESSONS LEARNED FROM PREVIOUS TRIPS RUNS -EXTRA TIME TAKEN TO DO PRE TOUR CHECKS -BREAK CIRCULATION JUST TO ENSURE NOTHING WAS FROZE UP. 22:00 - 23:00 1.00 FISH P DECOMP CONT:RIH WITH BHA # BHA # 8 RIH WITH 54 STANDS ,ONE DOUBLE AND 17' INTO KELLY TO 5,194' PUW-89 K ,SOW- 60 K ,ROT WT-70K ~ 40 RPM 23:00 - 00:00 1.00 FISH P DECOMP WASH AND ROTATE OVER SCREENS -P/U KELLY -WASH OVER F/ 5,194" T/ 5,529' MD -3-5 BPM / 250-600 PSI -40-45 RPM / 200 AMPS TO -POW = 89 K, SOW = 60 K, FRW = 70 K. 12/26/2009 00:00 - 00:30 0.50 FISH P DECOMP WASH AND ROTATE OVER SCREENS -P/U KELLY -WASH OVER F/ 5,194" T/ 5,529' MD -3-5 BPM / 250-600 PSI -40-45 RPM / 200 AMPS TO -POW = 89 K, SOW = 60 K, FRW = 70 K. -TAGGED TOP OF PERMINENT PACKER ~ 5529' Printed: 1/11/2010 12:37:13 PM BP EXPLORATION Page 13 of 18' Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2009 00:30 - 01:30 1.00 FISH P DECOMP CBU W/ 25 BBL HI-VIS SWEEP. -CIRCULATE ~ 3-5 BPM, 250-600 PSI -RECOVERED .5 YRDS FRAC-SAND AND FORMATION SAND 01:30 - 04:00 2.50 FISH P DECOMP POOH W/ BHA # 8 WASH PIPE ASSEMBLY -POH F/5,529' -NO FLUID LOSS DURING TRIP -JUNK BASKET CONTAINED A 2" BY 8" LONG PIECE OF METAL AND A CUP OF FRAC SAND 04:00 - 05:00 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR -LD WASH PIPE HANDLING EQUIPMENT 05:00 - 06:00 1.00 FISH P DECOMP PU / MU BHA# 9 OVERSHOT ASSEMBLY BHA AS FOLLOWS: -5-3/4" 150 OVERSHOT -BUMPER SUB -4-3/4" OIL JAR -3-1/2" PUMP OUT SUB -(9) 4-3/4" DRILL COLLARS -TBHA = 300.71' 06:00 - 06:30 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 09:30 3.00 FISH P DECOMP RIH FROM DERRICK W/ BHA # 9 ON 3 1/2" DP. -PU 2 JTS DP -PU KELLY -~ - 5,180' MD 09:30 - 10:30 1.00 FISH P DECOMP FISH ~ 5,194' MD -ENGAGE FISH ~ 5,194' W/ PUMPS ON AND PRESSURED-UP TO 450 PSI. -SET DOWN W/ 15 K -SHEAR W/ 20 K OVER -PUW = 93 K, SOW = 64 K. -1.5 BPM / 130 PSI -LAY DOWN 2 JTS DP. 10:30 - 11:00 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP -5 BPM / 525 PSI -SET BACK KELLY. -LAY DOWN 2 JTS DP. -SMALL AMOUNT OF SAND IN RETURNS. 11:00 - 13:30 2.50 FISH P DECOMP POH FROM 5,194' MD -T/ BHA -300' 13:30 - 15:30 2.00 FISH P DECOMP BHA # 9 -RECOVERED SCREEN ASSEMBLY -LD 36' OF SCREEN ASSEMBLY -INSIDE OF (TOP OF SCREEN) IS 80% PLUGED OFF WITH SCALE -SCALE ON 30% OF OUTER SCREEN SECTION. -TO OF FISH ~ -5,529' MD. 15:30 - 16:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. 16:00 - 17:00 1.00 FISH P DECOMP PU / MU BHA #10 PACKER MILL ASSEMBLY BHA AS FOLLOWS: -6-1/8" PACKER MILL -(4)-4-3/4" BOOT BASKET Printed: 1/11/2010 12:37:13 PM ~ ~ BP EXPLORATION 'Page 14 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2009 16:00 - 17:00 1.00 FISH P DECOMP -BIT SUB -BUMPER SUB -4-3/4" OIL JAR -PUMP OUT SUB -(9) 4-3/4" DRILL DRILL COLLARS. TOTAL BHA=319.27 17:00 - 21:00 4.00 FISH P DECOMP RIH WITH BHA # 10 PACKER MILL ASSEMBLY -RIH W/ 55 STANDS AND ONE DOUBLE TO 5,512' -KELLY UP -PUW-87K ,SOW-58K ,ROT WT 70K ~ 60 RPM WITH 180 AMPS OR 4000 FT/LB OF FREE TO -ESTABLISH CIRCULATION AT 3 BPM ~ 300 PSI. -RIH TAGGED UP 17' INTO KELLY TO THE TOP OF PACKER AT 5529' 21:00 - 00:00 3.00 FISH P DECOMP MILLING HALLIBURTON TYPE (S) PERM PACKER -5-10 K WOB , ~ 60 RPM -3.5-6 BPM -380 - 850 PSI -6K TO 8K FT/LB TORGUE 12/27/2009 00:00 - 03:00 3.00 FISH P DECOMP MILLING HALLIBURTON TYPE (S) PERM PACKER -MILLING F/ 5,529' TO 5,533' -5-10 K WOB , ~ 60 RPM -3.5-6 BPM -380 - 850 PSI -MILLED -4' AND WAS NOT MAKING ANY MORE HOLE,TRIED MILLING W/O THE PUMP OFF, VARIED WIGHT FROM 5-12 K. -PULLED UP TO 5,510', COULD TELL RIGHT AWAY W E WERE DRAGGING SOMETHING UP SLACKED BACK OFF AND BACK UP TO 5520' AND THE WEIGHT DROPPED OFF. -THOUGHT WE WERE FREE OF THE DEBRIS, WENT TO SLACK BACK OFF AND START MILLING AGAIN AND COULD NOT DROP PAST 5,524' -MILLED AT 5,524' FOR AN HOUR WITH NO PROGRESS -CALLED ADW RWO ENGINEER AND CONSULTED WITH HIM, DECISION WAS MADE TO COME OUT OF THE HOLE AND LOOK AT THE MILL AND PLAN FORWARD FROM THERE. 03:00 - 03:30 0.50 FISH P DECOMP PJSM FOR POH W/ DRILL PIPE -CLEAN AND CLEAR RIG FLOOR -RACK KELLY BACK 03:30 - 06:00 2.50 FISH P DECOMP POH W/ BHA # 10 PACKER MILL ASSEMBLY -POH FOR MILL INSPECTION AND FORWARD PLAN. -33 STANDS OUT. ~ 06:00 - 10:00 4.00 FISH N WAIT DECOMP WAIT ON WEATHER -PHASE II -UNSAFE TO LOWER BLOCKS DURING TRIPPING OPERATIONS. -HELD (1 HR) WEEKLY SAFETY MEETING WITH DAY CREW 10:00 - 13:00 3.00 FISH P DECOMP CONTINUE POH FROM -2,500' MD ', -w/ BHA # 10 Printed: 1/11/2010 12:37:13 PM • BP EXPLORATION Page 15 of t8 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/27/2009 10:00 - 13:00 3.00 FISH P DECOMP -RECOVERED 3 GAL FINE METAL CUTTINGS. -COMFIRM w/ ADW RWO ENGINEERS ON PLAN FORWARD. 13:00 - 14:00 1.00 FISH P DECOMP MU BHA # 11 BHA AS FOLLOWS: -6-1/8" JUNK MILL -(4)-4-3/4" BOOT BASKET -BIT SUB -BUMPER SUB -4-3/4" OIL JAR -PUMP OUT SUB -(10) 4-3/4" DRILL DRILL COLLARS. TOTAL BHA= 349.09' 14:00 - 16:30 2.50 FISH P DECOMP RIH w/ BHA #11 FROM DERRICK ON 3 1/2" DP. -TO 5,524' MD -PJSM (PICK-UP KELLY) 16:30 - 21:00 4.50 FISH P DECOMP TAG FISH ~ 5,522' MD -PU KELLY -TAG ~ 5,524' MD -PUW = 83 K, SOW = 60 K, FRW = 66 K. -ROT RPM = 60, TQ = 5-8 K FT/LB -MILL TORQUED-UP -30 K OVER PULL -MILL 10 MINUTES -AND PUSH T/ _ 5,604' MD -MILL ON FISH ~ 5,604' T/ 5613' -ROTATED AND PUSHED FISH DOWN TO 5,634' 21:00 - 22:00 1.00 FISH P DECOMP CIRCULATED BOTTOMS UP -RACKED KELLY BACK 22:00 - 23:30 1.50 FISH P DECOMP POH W/ DRILL PIPE F/ 5,634' -POH 15 STANDS ABOVE THE PERFS TO 5,164' -SLIGHT OVERPULL OFF BOTTOM -5 K. 23:30 - 00:00 0.50 FISH P DECOMP HELD (1 HR) WEEKLY SAFETY MEETING WITH NIGHT CREW -STOP PROGRAM PEER REVIEW DISCUSSION. -REVIEW OF THE TENANTS OF OPERATIONAL EXCLELENCE. -SAFETY ALERT REVIEWS 12/28/2009 00:00 - 00:30 0.50 FISH P DECOMP CONT:POH WITH BHA # 11 JUNK MILL ASSEMBLY ON 3-1/2" DRILL PIPE F/ 5,634' -POH FROM 5,634' -LD BHA 00:30 - 04:00 3.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR -EMPTY BOOT BASKETS -RETRIEVED - 50 LBS OF METAL CUTTINGS 04:00 - 05:00 1.00 FISH P DECOMP MU BHA # 12 SCRAPER ASSEMBLY BHA AS FOLLOWS: -6-1/8" BIT -7" CASING SCRAPER -(4)-4-3/4" BOOT BASKET -BIT SUB Printed: 1/11/2010 12:37:13 PM BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 ~, Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of.Operations 12/28/2009 04:00 - 05:00 1.00 FISH P DECOMP -BUMPER SUB -4-3/4" OIL JAR -PUMP OUT SUB -(9) 4-3/4" DRILL DRILL COLLARS. TOTAL BHA= 319.51' 05:00 - 06:00 1.00 FISH P DECOMP RIH W/ BHA #12 FROM DERRICK ON 3 1/2" DP. -RIH AND SCRAPED OVER NEW PACKER SETTING DEPTHS (5,122') , (5,296') , 5,470') MD -PU ABOVE THE PERFS AND SWAPPED FLUID IN THE WELL WITH NEW SEA WATER 06:00 - 06:30 0.50 FISH P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 10:00 3.50 FISH P DECOMP CONTINUE 7" SCRAPER RUN. 10:00 - 11:30 I 1.501 CLEAN I P 11:30 - 14:00 I 2.501 CLEAN I P 14:00 - 14:30 0.50 CLEAN N 14:30 - 17:30 3.00 CLEAN P 17:30 - 21:00 3.501 CLEAN P 21:00 - 00:00 I 3.001 CLEAN ~ P 12/29/2009 100:00 - 00:30 0.501 EVAL ~ P 00:30 - 03:00 2.501 EVAL P -RECIPROCATE 7" SCRAP OVER 5,122', 5,296' AND 5,470' MD. -NO DRAG ENCOUNTERED -POH L/D 12 JTS T/ 5,150' MD. -NO DRAG ENCOUNTERED. DECOMP DICPLACE W/CLEAN 8.45 PPG SEAWATER. -PJSM -PUMPED 512 BBLS CLEAN SEAWATER DOWN THE TUBING AND SHIP TO TIGER TANK. -5 BPM / 960 PSI. -LOAD DIRTY VAC-TRUCK -OBSERVE WELL 15 MINUTES. -WELL IS STATIC. DECOMP POH L/D 3 1/2" DP -F/ 5,150' MD -T/ 3,270' MD. DECOMP REPLACE BRAKE-OUT TONG LINE. DECOMP CONTINUE POH L/D 3 1/2" DP -F/ 3,270' MD -T/ SURFACE -BOOT BASKET CONTAINED SMALL AMOUNT OF FRAC AND FORMATION SAND MAYBE 1/2 GAL DECOMP CLEAN AND CLEAR RIG FLOOR -LD BHA -CLEAN OUT BOOT BASKETS -BOOT BASKETS CONTAINED SMALL AMOUNT OF FRAC AND FORMATION SAND MAYBE 1/2 GAL -RU DUTCH RISER. DECOMP PJSM WITH CREW AND SLB -SPOTTING WIRELINE EQUIPMENT -PU E-LINE TOOLS TO RIG FLOOR,WIRELINE BOP, 5K WIRELINE WIPER -PRESSURE TEST GOOD DECOMP CONT: -PU E-LINE TOOLS TO RIG FLOOR, WIRELINE BOP, 5K WIRELINE WIPER DECOMP FIRST RUN W/WIRELINE AND JUNK BASKET -GUAGE RING 6.125" -JUNK BASKET Printed: 1/11/2010 12:37:13 PM BP EXPLORATION Page 17 of 18- Operations Summary Report Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase. Description of Operations 12/29/2009 00:30 - 03:00 2.50 EVAL P DECOMP -SET DOWN ~ 3,080' ,HAD TO WORK THE STRING THROUGH -SET DOWN ~ 5,597' -POH ,HUNG UP AT 3,080' HAD TO WORK UP AND DOWN A FEW TIMES TO GET FREE. -PULLED JUNK BASKET TO SURFACE AND RETRIEVED 2 CUPS OF PACKER RUBBER, NO METAL. 03:00 - 06:00 3.00 EVAL P DECOMP SECOND RUN W/WIRELINE AND JUNK BASKET CHANGED GUAGE RING TO A 5.94 TO SEE IF WE COULD KEEP FROM HANGING UP AND KEEP MORE OF THE DEBRIS IN THE JUNK BASKET. -GUAGE RING 5.94" -RIH TO 5,598' -POH F/5,598' TO SURF -RETRIEVED - 1/2 GAL OF RUBBER AND TWO FLAT PIECES OF METAL -2" LONG -RETURNED JUNK BASKET BACK DOWN FOR ANOTHER PASS. 06:00 - 17:00 11.00 EVAL P DECOMP THIRD RUN W/WIRELINE JUNK BASKET -GUAGE RING 5.94" -RIH T/ 5625' -REOVERED 1 CUP SAND AND 1 PEACE OF RUBBER. FOURTH RUN -GUAGE RING 6.125" -RIH T/ 5,627' -RECOVERED 1 QT OF SAND AND 1 PEACE OF RUBBER. FIFTH RUN -GUAGE RING 6.125" -RIH 5,628' -RECOVERED 1 PINT OF SAND. -10:30 HOURS. RUN #6 -POH AND REMOVE CENTRALIZER. 12:30 HOURS. RUN # 7 -USIT LOG -F/5,728' T/ 5,000' MD. -RD E-LINE EQUIPMENT AND DUTCH SYSTEM. 17:00 - 18:00 1.00 BUNCO RUNCMP CLEAN FLOOR AND LOAD PIPE SHED W/ COMPLETION ASSEMBLY'S 18:00 - 19:15 1.25 BUNCO P RUNCMP RU TORQUE-TURN -STAGE TAILPIPE ASSEMBLY IN SEQUENCE 19:15 - 19:30 0.25 BUNCO RUNCMP PJSM-PUT-WIRE ASSEMBLY 19:30 - 20:45 1.25 BUNCO P RUNCMP RU 'I'-WIRE SHEAVE & SPOOLER 20:45 - 21:10 0.42 BUNCO RUNCMP PJSM -RUNNING COMPLETION -ISSUES W/'I'-WIRE CLAMPS Printed: 1/11/2010 12:37:13 PM • BP .EXPLORATION.. Page 18 of 18 "Operations Summary Report. Legal Well Name: MPJ-19 Common Well Name: MPJ-19 Spud Date: 10/16/1995 'Event Name: WORKOVER Start: 12/11/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/31/2009 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 12/29/2009 21:10 - 00:00 2.83 BUNCO P RUNCMP MU WLEG, XN, GLM, X NIPPLE, #1 PACKER, INSTALL 'I'-WIRE, GLM2, GLM #3, #2PACKER, GLM #4. 12/30/2009 00:00 - 04:30 4.50 BUNCO RUNCMP CONTINUE TO MU COMPLETION -GLM #5 -PACKER # 3, X NIPPLE W/'I'-WIRE -FILL HOLE W/ 5 BBLS SEAWATER -MU 'I'-WIRE AND TEST. 04:30 - 14:00 9.50 BUNCO RUNCMP RUN (160 JTS) 3 1/2" 8 RD, L-80, 9.3# EUE TUBING COMPLETION w /'I'-WIRE. -88 EACH WHOLE 'I'-WIRE CLAMPS -17 EACH HALF 'I'-WIRE CLAMPS 14:00 - 15:30 1.50 BUNCO RUNCMP TUBING HANGER -MU LANDING JOINT W/ XO, SAFETY VALVE, TBG-HANGER. -INSTALL 'i'-WIRE AND TEST T/ 5000 PSI F/ 5 MINUTES. -VOID THE BOP STACK. -PUW = 45 K, SOW = 30 K. -LAND AND R.I.L.D.S. 15:30 - 18:00 2.50 BUNCO RUNCMP DISPLACE -RU T/ REVERSE-CIRCULATE -FMC INSPECT TWC. -PUMP 50 BBLS 120 DEG 8.45 PPG SEAWATER -DISPLACE W/ 150 BBLS 120 DEG INHIBITED SEAWATER -2 BPM / 100 PSI -LD'I'-WIRE SPOOLER 18:00 - 21:00 3.00 BUNCO RUNCMP PJSM. RU LITTLE RED. PT TO 5000 PSI. REVERSE IN 90 BBL DIESEL TO ANNULUS. 21:00 - 22:30 1.50 BUNCO P RUNCMP "U" TUBE DIESEL TO TUBING 22:30 - 22:50 0.33 BUNCO P RUNCMP PU LANDING JOINT. PU 1-5/16 BALL WITH ROLLER STEM. 22:50 - 00:00 1.17 BUNCO P RUNCMP PRESSURE TO 4600PS1 WITH 1.5 BBL LED BACK TO 3500 PSI AND HOLD FOR 30 MIN. BLEED OFF TUBING TO ZERO. LOST 100 PSI IN 30 MIN. TEST BACKSIDE TO 2000 PSI FOR 30 MIN.TOOK 1.5 BBL TO PRESSURE UP ~ ANNULUS. 12/31/2009 00:00 - 00:30 0.50 BUNCO RUNCMP CONTINUE PACKER TEST. LOST 120 PSI IN 30 MIN. 00:30 - 01:00 0.50 BOPSU P RUNCMP SET TWC AND TEST TO 3500 PSI FROM ABOVE FOR TEN MIN, 01:00 - 06:00 5.00 BOPSU P RUNCMP ND BOP . TERNIMATE "1"WIRE IN TUBING HEAD. NU TREE AND TEST TO 5000 PSI ***RELEASE RIG AT 0600 HOURS 12/31/2009*** ~f ,~41 Printed: 1/11/2010 12:37:13 PM • Tree: 3 1/8" - 5M FMC Wellhead: 11" 5M FMC w/ 3 1/8" FMC Tubing Hanger , 3 1/2" TC-II T&B Thread. 2.5" CIW `H' BPV profile 115' KOP @ 500' Kicked off original hole at 3795' and Max hole angle = 61 deg. at 3750' Two 7" x 20' marker joints from 4799' to 4839' wlm w/ RA tag at 4799' wlm M Perforation Summary Ref log:11/08/95 GR/ CCL/Temp./ Press. Size SPF Interval (TVD) 'N' Sand 4.5" 12 5231' - 5260' (3875'-3897') 4.5" 12 5275' - 5279' (3908'-3911') 'OA'Sand 4.5" 12 5413' - 5455' (4014'-4047') 'OB' Sand as" 12 sass'-ssza' (ams'-a1o1') MPU J-19A 20" 91.1 ppf, H-40 9 5/8", 40 ppf, L-80 BTC. 3391' 3 1/2" 9.3 ppf, L-80, 8rd EUE Tbg ( drift ID = 2.867", cap. = 0.0087 bpf ) 7" 26 ppf, L-80, BTC Csg. ( drift ID = 6.151", cap = 0.0383 bpf ) ( cap w/ 3 1/2" inside = 0.0264 ) 12 SPF 4-1/2" Jumbo Jet charges 26 GR @ 135/45 deg. phasing Orig. DF. Elev. = 64.5' (N 22E) Orig. GL. Elev. = 35.6' RT To 7" Csg Hgr = 28.9' (N 22E) 3.5" HES X-Nipple (2.813" pkg.) 209$` 3.5"HES X-Nipple (2.813" pkg.) 5070` 7" x 3.5" HES MFA Dual Pkr 5115` 3.5"HES X-Nipple (2.813" pkg.) 4' 3.5"NDPG Single Sub 5126` 3.5" x 1.5" Camw MMG GLM 5189` 3.5" x 1.5" Camco MMG-W GLM 5280` 7" x 3.5"HES MFA Dual Pkr 5303 3.5"HES X-Nipple (2.813" pkg.) 5312` 3.5" NDPG Single Sub 5313` 3.5" x 1.5" Camco MMG GLM 5376` 3.5" x 1.5" Camco MMG-W GLM 5465` 7" x 3.5"HES MFA Dual Pkr 5483` 3.5"HES X-Nipple (2.813" pkg.) 5492` 3.5"NDPG Single Sub 5493` 3.5" x 1.5"Camco MMG-W GLM 5533` 3.5"HES XN-Nipple (2.813" pkg.) 5562` 2.75" No-Go 3.5" WLEG 5595` 7" float collar (PBTD) 5 642' 7" 26#, L-80, BTC 5 728' DATE REV. BY COMMENTS 10/31/95 JBF Drilled and Cased by Nabors 22E 06/26/96 MDO ESP COMPLETION 4 ES 12/30/09 Hulme Convert to injector - N-4ES MILNE POINT UNIT WELL J -19A API NO: 50-029-22607 - 01 BP EXPLORATION (AK) ~~ - 2~'.* C:iAR2CAL ~,NTEGRITY R~ORT gUD D ~ "'.. ~ OPER ~ FIELD ~ / ~!?/ (' l n ~ Y _~ ct : ~ : - ~.ii.I. NUMBER ~"I 1'- S ~ J ~ (/ ' ..,G n,.....r.._ . n ALL DA?' ~: TD : S~ .. ~fZ7P ~'PD. ; . BTD : ~~ `f~-~ Czsirg: ~',S~ ~ Shoe: `33`1 ~ID Z?/3 TvD; DY: -SID ~?'~fD ~7 g.. - --r-/~- /~ Pro~• _i:1e~ :~ Shae : ~ /ZO !MD ~~i ; ~~p . Cam„, ~ .rSL._.,.~'~l :`uoi.^.g : .~~~ ~~ Picker .s~.~ TVD , Set st ~S/I.~ ~ nc o. r.e......._ _.____ ::ale S; to ~~ ~ and Perfs SZ 3 ~ to ~Z Y•~•~' ~.~.N i C~.L iNTEGR?'1'y - ? 9RT # ? ~c Z T =~ I~ r Z Annulus Press Test: Mp ~o~~; 15 min `~ ~0 min C omiaen t s : ~ 4- ~ ~ 1''~~..~ 3 S~ P ~ ~- 3~ -~.-~- ~ o,~ • .. -TJ"-. '~iECiiANIC?.I, YNTEGRIT~ -PART i 2 . Cement Volumes r Amt, i..:~aar7,t~,~. Gag- -~ DVS. Cmt vvl to cove. per:.s ~~s s~s ,~ ~C~~ss _~~ ~ ~~~ ~~'~sk ~.~...~ ~---r ~ - ~ ~ ~ ' • v ?° ,L,~e-.rte-r Theoretical TOC S7Z~ _. 2-~' `~ N - rG . C /. hr(.C ~1.~.:D ~V~' C G...r..~- D .:.r.,,9'l.; sue., ,F~et ) ~3 ~.q.~.~o Cement Bond Log Ye or No)._____+; In AOGCC File,__-,____ ~~~, ~s'/ T C$L .v8luation, zone ebove perfs V_ e,,,~_ ~~~ < ~~~ ~ /(~~ /~ ~ Production Log: Type ~ t Evaluation ~CONCLU5iQNS: ~ . __- _ n ~ ax w ~ ¢ 2 . - ~ ~xC~~Lao(- t ~ wi L n ~ ~ ~ _ ~co~V~ ~(G a~ z, ~ s . r° ~`'l~~~s`~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 ATTN: Beth Well Job k Loa Description NQ. 5378 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C~ C~ .~~~i 4'~~ °~ ~Ea ~. ~ ~.4~C -. -~r~.+~auvn tniaana) mG. Petrotechnical Data Center LR2-1 Alaska Data & Consulting Services 900 E. Benson Blvd. 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i" t/ Schl~nt~erger aska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 7N: Beth Well Job # Log Description Date BL Color CD N0. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 02-31A 17-09 12-30 17-09 13-27A JX-02A MPJ-19A L-103 W-217 8146-00087 B3S0-00042 69RH-00003 AWJB-00047 BALL-00009 AWJI-00065 AP30-00075 BALL-00010 AYKP-00056 SCMT - ( - TBG. CUT/FLOW DETECTION _ LDL MEM LDL USIT MEM LDL - USIT _ RST/WFL - C CH EDIT PDC USIT _ 12124!09 01/05/10 12/26/09 01/03/10 12/31/09 12/29/09 12/29/09 01/06/10 11/27/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 12-05AL1 V-224 D-14A 11-27 3-27/M-33 B2NJ-00025 AYKP-00059 AWJM00060 AP30-00068 B8K5-00012 MCNL CH EDIT PDC USIT MCNL - C ~ RST ~ RST 09/29/09 12/14/09 11/15/09 11/06/09 11/18/09 1 1 1 1 1 1 1 1 1 ASE ACKNOWLEDGE REC EIPT BY SIC;Nw r, eNn acn IQNIN!_ nue ~.,o.. ~...~ t... :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r / • • ~ ~ y_r ~ u~ ~, "~ ~~~' S";~ ~~ ~ ~'s ~~f' ~`',` y' ~v @ ~ qp ~7 ~ ry ` V: ~h p ` b ~. ~ t ~1 ~ K F f 1 ~~ ~~y ~ ~. p ~ k p p Qk i q £ H t~ ~~t ~i A I~ . , B E ~` `F ` F y , ~ P h ~ SEAN PARNELL, GOVERNOR , w ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~µ ~' ~ ,~ ~ ~ ~ ~ ~~~ Y M ~ ~ ~i ~~ F ~~ ~ ;~. ~' :" ~'~ ?, ~,,~ ~~ ~ ~~~ ,~~~~c ~ ~~~ ~ ~~ c"~-,~ °~ _~ , ,~~ tzas~t~S~A ~IL ~~ ~.7 ~'~ 333 W. 7th AVENUE, SUITE 100 Co~SE~avATio~ corn-~SSIOr~ p`N ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907)276-7542 Mr. David C. Reem Engineering Team Leader BP E~loration (Alaska), Inc. h P.O. Box 196612 S t V Anchorage, AK 99519-6612 „ ~ ~ .. ~ Re: Milne Point Field, Schrader Bluff Oil Pool, MPJ-19A Sundry Number: 309-358 ;~~~~,~~~~; ~y~`~ ~ ~ 2lMC}~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Comznission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~~da of October 2009 - Y ~ Encl. ~ ~ ~~ ~ ~ STATE OF ALASKA ~ ~ ~'~SKA OIL AND GAS CONSERVATION COMMIS~ION ~ .ti ~ ~° APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~EIVED OCT 2 2 2Q09 ~i~s~~ Did ~ ~a~ C~ns. Commission 1. Type of Request: ~RChOfB~}@ ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended Well ^ ARer Casing ^ Repair Well ^ Plug PerForations ^ Stimulate ~ Other • Specify: ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Time Extension Convert from Producer to injector • 2. Operator Name: 4. Current Well Class: 5. Perrnit To Drill Number BP Exploration (Alaska) Inc. ~ Development •^ Exploratory 195-170 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22607-01-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest . Well Name and Number: property line where ownership or Iandownership changes: MPJ-19A . Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. Field / Pool(s): ~ ~/h` ~D~ ~i~ S'~, r. ~$~iti~ ~ ADL 025906 & 025517 ~ eF-Peel v/c /ia~- ~'radhvErB'~y-F+9{d I~JL ~ ~• PRESENT WELL CONDITION SUMMARY /O• 2 t• v1 Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): EffeCtive Depth ND (ft): Plugs (measured): Junk (measured): 5750' ' 4278' • 5642' 4193' None None Casin Len th Size MD ND Burst Colla Structural Conductor 0' " 11 ' 11 ' 14 4 0 Surface 3360' 9-5/ " 3 91' 2713' 7 0 3090 Intermediate Production 7" 7' 4 ' 7 4 1 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5231' - 5524' 3875' - 4101' 2-7/8", 6.5# L-80 5139' Packers and SSSV Type: Screen Assembly: 7" 26#, HES VTL Packer (3) Packers and SSSV 5164' / 3824' MD (ft) and ND (ft): 5288' / 3918' 5465' / 4055' 72. Attachments: 13. Well Class aRer praposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 25, 2009 ~ ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ~ WINJ •^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify , at the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick 564-5891 Printed Name avid .em Tit~e Engineering Team Leader Prepared By NamelNumber Signature Phone 564-5743 Date ~e~ ~ z~~ Terrie Hubble, 564-4628 Commi~ion Uss Onl Conditions of approval: No ' Commission s at a representative may witness Sundry Number: 3~y~ ,3,5~ ^ Plug Integriry OP Test echanical Integriry Test ^ Location Clearance ~ 3s~ ,~~~, ,~ P ~ys t- Other: ~ ~ ~~ ~.SC. ~-w~h ~°'~ ~s f ` ~' I ~~Cj Io,l~ i ~ ~ w - G~C~ f~.~ ~. ~~~ ~~~ ~. ~ ~. ~~~ Subsequent Form Required: / ° _7 APPROVED BY / J Z7 ~ Approved By: COMMISSIONER THE COMMISSION D e Form 10-403 Revised 072000 ~(~~~A(1~ C~~ ~~~ Submit In Duplicate 0 R I G I~iA L ~~.~. ~~~.,,~ ,~ ;~. .~3.~~ ~~~.,~ ~ . ~ ~ ~ ~ ~ ~ • Milne Point J-19 Capital Rig Workover: Converting Producer to Injector Scope of Work: Converting Producer to Injector: Pull 2-7/8" L-80 ESP completion, retrieve 3 Halliburton "VTL" packers and screens. Run new 3-1/2" L-80 single select completion. - MAASP: 1200 psi Well Type: Producer con Estimated Start Date: November 25'h, 2009 Production Engineer: Keith Lopez Intervention Engineer: Mackie Derrick Pre-Rip Work Reauest: S 1 Tubin Punch above ESP C~ -5099' MD. Obtain SBHPS. W 2 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time . PPPOT-T & IC. W 3 Set a BPV in the tubin han er. O 4 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 2-7/8" x 5" VBR. Pressure test to 3500 psi. Circulate well to warm clean seawater. If unable to circulate wellbore clean, bullhead 1.5 wellbore volume of seawater into formation. 2. Pull 2-7/8" completion w/ ESP 3. RIH w/ scraper to top of screen completion C~ 5164'. ,~ 4. RIH w/ 7" RTTS and set as close top packer as possible. PT casing to 2500 psig (MIT}. Release RTTS and POOH. 5. RU WL and run USIT Cement Bond log from as close to top packer as possible to ~4000' MD, to confirm quality cement above the injection zones. RD WL. 6. RIH and mill/pull/retrieve 3 packers and 3 X 3.5" screen system 7. RIH w/ casing scraper and scrape past packer setting depths & tag PBTD. POOH. 8. RU WL and run USIT Cement Bond log from PBTD to TOC to evaluate zonal isolation. RD WL. 9. Run 3.5" L-80 8rd EUE tubing and XO for MMG & MMG-W Mandrels, 3x3.5" NDPG subs, and 3x3.5"x7" single feed-thru packers 10. RDMO • ~', ~S ~~~ ~ Tree: 2 9/16" - 5M FMC Wellhead: 11" 5M FMC _ w/ 2 7/8" FMC Tubing Hanger , EUE lift threads, 2.5"" CIW H BPV profile 20" 91.1 ppf, H-40 115' KOP @ 500' Kicked off original ho~e at 3795' md ax hole angle = 61 deg. at 3750' 9 5/8", 40 ppf, L-80 Btrc. 3391' 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf Two 7"'x 20' markerjoints from 4799' to 4839' wlm w/ RA tag at 4799' wlr (~IPII J-19A ~ Stimul8tl0f1 Sumfl7dry: 'N' Frac Pack - 06/24196 - 49 M# Ibs. 16-20 Carbolite behind perfs and behind screer 'OA' Frac Pack - 06l23/96 - 7.6 to14 Ni Ibs. 16-20 Carbolite behind perts and 5000 lbs. behind screer 'OB' Frac Pack - 06/22/96 - 5500 Ibs. 16-20 Carbolite behind perfs and 8900 Ibs. behind screer Perforation Summarv Ref loa:11/08/95 GR/ CCL/Temo./ Press. Size SPF Interval (TVD) 'N' Sand . 4.5" 12 5231' - 5260' (3875'389T) 4.5" 12 5275' - 5279' (3908'-3911') 'OA' Sand 4.5" 12 5413' - 5455' (4014'-4047') 'OB' Sand 4.5" 12 5498'-5524' (4079'-4101') 12 spf. 4-1/2" Jumbo Jet charges 26 gr. @ 135/45 deg. phasing Orig. DF. efev. = 64.5' (N 22E) Orig. GL. elev = 35.6' RT To 7" csg. hng. = 28.9' (N 22E) Camco 2 7/8" x 1" 90~ sidepocket KBMM GlM Centrilift FC-925 ESP, 5,099' series 400, FPMTARC, 17 Stg. Centrilift GST-DB 5,116' seal section ~ntake 3789' ND Centrilift KME1 562 series, 5,129' Centrilift PHD 5,139' I 7" # 26 HES " VTL" pkr. Bottom 5, ~ 64' Upper Ext. Seal 6ore Ext. 3.5' .012 ga. 304ss all weld scr. 5,226' - 5,288' 3.5" HES X-Nipple (2.75' id) 5 289, Seal ext. Collet Muleshoe Shoe 7" # 26 HES " VTL" pkr. 5,288' Bottom Sub Upper Ext. Seal Bore Ext. 3.5" .020 ga. 304ss all weld scr. 5,403' - 5,465' 467~ 5 3.5" HES X-Nipple (2.75" id) , Seal exf.Collet Muleshoe Sho ' 7" # 26 HES " VT~" pkr. 5,465 Bottom Sub Upper E#. Seal Bore Ext. 3.5° .Q20 ga. 304ss all weld scr. 5,494' - 5,529' Seal ext. Collet Muleshoe Shoe 5,529' 7" HES "S WD" Perm. pkr. 5 642' 7" float collar (PBTD) " 5 728' 7 26#, L-80, Btrc. 10l31/95 JBF Drilled and Cased by Nabors 22E 06/26/96 MDO ESP COMPLETION 4 ES MILNE POINT UNIT WELL J -19A API NO: 50-029-22607 - 01 BP EXPLORATION (AK) 4-1/16" x 11" - 5M FMC iead: 11" 5M FMC Gen. 5 20" 91.1 ppf, H-40 115' KOP @ 5Q0' Max. hole angle in original at 3795` Max hole angle = 61 deg at 3750` 9 5/8", 40 ppf, L-80 Btrc. 3391 ` 7", 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.038 Two 7" x 20" markerjoints from 4799` to 4839' wlm w/RA tag at 4799' wlr Qof ~.,.,• 3raioa ewc ..ri....~ Si~e ~PF Ir~terval. ND N Sand 4.5' 12 5231'-5260 3873-3& 4.5' 12 5275'-5273 390g~9' Qa$~1[~ 4.5' 12 541~-5455 4014-40~ OBSand 4.5" 12 5498'-5624 4079-41t 5,529" PBTD ~qr 7" float 5~28, 7" float shoe DATE ~ REV.BY ~ COMMENTS Orig. DF Elev. = 64.5 ( Orig. GL Elev. = 35.6' RTto 7" Csg Hanger =28.9' 2152` 3-1/2" HES X Nipple 34' 3-1/2" x 7" FeedThru Packer 2" x 1-1/2' MMG 2' NDPG multi-sensor 2' x 1-1/2" MMG-W ~20 3-1/2" x 7" FeedThru Packer 2" x 1-1/2' MMG ~2' NDPG multi-sensor l2' x 1-1/2" MMG-W 73' 3-t/2" x 7" FeedThru Packer 3-1/2' NDPG multi-sensor 3-1/2' x 1-1/2" MMG-W 3-1/2" HES XN Nipple 3-1/2" WLEG MILNE POINT UNIT WELL J-79A API NO: 50-029-22607-01 BP EXPLORATION (AK) ~ MP~f9A Proposed ~ ~ • Area of Review - Milne Point J-lAA (A512o) Prior to the conversion of well MPJ-i9A to a water injector an Area of Review (AOR) is required. This AOR discuss the wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of well bore completion. Four other wellbores enter the Schrader Bluff formation in the AOR. The following table illustrates the well within the AOR, its distance from MPJ-i9A, completions detail, and any annulus integrity comments based on an in-depth review of each well. Figure i: Wells within AOR Figure 2: Completion Detail Well MPJ-22 (PTD 98124) was completed in July i998. The completion crossed the Schrader Bluff formation at 4,985' MD. A 5-12" casing string was run to 5~738~ MD and cemented with i9o bbls of foamed ColdSet III cement and 3o bbls of class "G" cement. Since this well has no surface casing, the cement was circulated to surface. A Cement Advisor log was run on ~/29/g8 and showed cement bond from 2i5' MD to TD. This well was plugged and abandoned on 4/2/04 with a cement retainer (4,600' MD) squeeze of the production interval and capped with 5 bbls of cement. A bridge plug was also set in the 5-i/2" casing at 300' MD and well bore filled with i5.8 ppg cement to surface. Well MPJ-25 (PTD 204073) was completed in July 2004. The completion crossed the Schrader Bluff formation at 4,305' MD. A ~-5/8" casing string was run to 4,037' MD and cemented with 59 bbls of 15.8 ppg class `G' cement with no recorded losses One lateral was drilled out of the well shoe into the Schrader ~ ~ Bluff N sand. This was lateral was tied back to the ~-5/8" casing with a liner top packer and hanger. Well MPJ-o8A (PTD i99ii~) was completed in August 1994• The completion crossed the Schrader Bluff formation at 4,905' MD. A ~" casing string was run to 6,i31" MD and cemented with 45 bbls of i5.8 ppg class `G' cement. This well was plugged back to 4,89o and sidetracked into the Schrader Bluff OB sand thru a window at 4,866'-4,880' in December i999• Well MPJ-o9A (PTD i99ii4) was completed in February 1995• The completion crossed the Schrader Bluff formation at 5,406' MD. A ~" casing string was run to io,84o" MD and cemented with 82 bbls of i5.8 ppg class `G' cement. This well was plugged back to 5,360' and sidetracked into the Schrader Bluff OA sand thru a window at 5~334'-5~346' in January 2000. The liner was cemented in place from the Liner Top Packer @ 5,i99' to the cement valve at 6,013' with i2.~ bbls of class `G' cement. This cement isolates the Schrader Bluff from the ~" annulus that does not have a calculated TOC above the pool. . L.~J i ina the A4 N ~, '~~ MPJ-08A '; ~ ~~ . • __ MPI-19L1 `~~. `,. ~- ~--.._ _.__. .. __ . ~ \ _ -~~-.. PJ-25 .. _, _ -- _ ~ PJ-O~~A. ., ,. ____-_ --.. ',~ - .. _ --- _ , _ _ . ,. ~ _ ~ ~ .- - - ~ ~t _..- ~MP~ 19 ,. l i _ ~ '` ~" ~ _~-~ ~ . _ ~~~ ,.14 -~, ~ '_ MPJ-19A M~?J-26 ~" ~ MPJ-~6L1 MPJ-17 '~ ~ P~1PJ-2GL" ~ '~.1 ._ _ ,, ~ _ , ~~.; ~~ ~ ~, - ~ ~ _ - _._---- ~ - -_ .~ _-----~--__..... _.._.__.~..._.____.___ _~. - - ------ --- - -~ --- 4~~-- - -- ---a---.~~-- -- ti 7. •~- - f~ . PJ-22'~ ~--- . ~IVIPJ-20 : _ ~ - , . -.. w ~ ._. _.. 1000 0 1000 2000 R Top Schrader &uff Form~on Structure grld ( feet} •90Z~ •4550 -d090 -3610 -3t25 Tnp Schrader @luff Furtna~on IrRercept ~+nth well p~~~ ~~e dslarce aovd MPJ- 191A al top of Schrader BlilF Famation oR BEFO PERMIT 95-170 95-170 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS GR/CCL/PERF GR/CCL/PERF ~EPIA' 5200-5435 ~EPIA 4963 -5273 Page: 1 Date: 06/09/98 RUN RECVD 1 07/12/96 1 07/12/96 95-170 GR/CCL/PERF/SET ~EPIA 5350-5550 1 07/12/96 95-170 95-170 95-170 7364 CDR CDR - TVD bDR - 1 08/08/96 FINAL 08/08/96 FINAL 08/08/96 95-170 GYRO MULTI SHOT R DRILL PIPE SCHLUM 100 & 30 12/30/97 95-170 DIR SRVY ~R-'SCHLUM 112-5750 10-407 ~OMPLETION DATE ~ /)~ /q~/ 12/15/97 DAILY WELL OPS R )4 /~.~/~37 TO ~ /~, /?~/ Are dry ditch samples required? yes ~_~And received? y Was the well cored? Are well tests required? , y~s ~' , In,ztzal COMMENTS yes ~ .... Analysis & description received? ~[ ReCeived? ~-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well [~Oil I~Gas i--]Suspended I~Abandoned [--] Service ~:~.C 1~ 5 '[99 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 95-170 3. Address 8. APl Number Anchorage P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22607-01 4. Location of well at surface ~ 9. Unit or Lease Name 2234' NSL, 3301' WEL, SEC. 28, T13N, R10E, UMiu';''~r~a~m Milne Point Unit '~:~'::';';:'~' ...... ;~:' :' ~ .~ ~ 10. Well Number At top of productive interval ; ;ii':~i//~-, i 2,~.~;~ MPJ-19A 3580' NSL, 579' WEL, SEC. 29, T13N, R10E, UM At total depth ! ~---~-'.?~-¢-~ ii:. H~ k 111. Field and Pool 3790' NSL, 863' WEL, SEC. 29, T13N, R10E, UM ! '~:~ :~ ~-' -" .... ' "~"~ ' 5. Elevation in feet (indicate KB, DF, etc.)KBE = 65.6' ]6' Lease Designati'~ac'r~'serial N°'ADL 025517 Milne Point Unit / Schrader Bluff , 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 16. No. of Completions 10/27/95I 10/28/95I 06/27/96] N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey ]20. Depth where SSSV set ]21. Thickness of Permafrost 5750 4277 FT 5642 4193 FTt [~Yes I~No] N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, RES, GR/CCL, Pressure, Temp 23. CASING, LINER AND CEMENTING RECORD CASING SE'FrING DEPTH HOLE SiZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 3391' 12-1/4" 674 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26# L-80 29' 5728' 8-1/2" 225 sx Class 'G' ,,, 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 5139' N/A MD 'I-VD MD -I-VD 5231 '-5260' 3875'-3897' 5275'-5279' 3908'-3911' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5413'-5455' 4015'-4047' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5498'-5524' 4081'-4101' Freeze protect w/72 bbls diesel 5164'-5288' Frac-pac w/49000# 16/20 Carbolite behind perfs/screen 52 88'-5465' Frac-pac ,14000# 16/20 Carbolite behind perfs & 5000# behind 5465'-5529' iFrac-pac,5500# 16/20 Carbolite behind perfs & 8900# behind screen 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) July 4, 1996I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF :WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-BEE OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL 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 Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. (Subsea) NA Sands 5192' 3781' NB Sands 5232' 3811' NC Sands 5275' 3844' CA Sands 5413' 3950' OB Sands 5498' 4016' RECEIVED 31. List of Attachments ~f~k~ 0il & Gas 00,s. C0mfl'li8810~ Summary of Daily Drilling Reports, Surveys Afl(~tiol'a~a 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAlvord ,~~.. ~'. ~ Title Senior Drilling Engineer Date Iz-(r5-{2q MPJ-19A 95-170 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 2?: 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 WELL - MPJ-19~ OPERATION: RIG : NABORS 22E PAGE: 3 · 10/28/95( 14): TD :: 5635' ( 0) 10/29/95 (15) TD: 5750' ( 115) 10/30/95 (16) TD: 5750' ( 0) 10/31/95 (17) TD: 5750' ( 0) DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 : TIME DRILL & KICK OFF PLUG @ 3795'. DRILL & SURVEY 8-1/2" HOLE T/5635'. CONTROL DRILL THRU SCHRADER BLUFF SANDS. RUNNING 7" CASING MW: 0.0 VIS: 0 DRILL 8-1/2" HOLE F/5635' T/5750' TD. PUMP LO/HI VIS SWEEP AROUND. MONITOR WELL. PUMP PILL. POOH TO CASING SHOE. LD DP. OK. SERVICE TOP DRIVE. TIH. OK. CIRC & COND MUD TO RUN CASING. MONITOR WELL. PUMP PILL. POOH. LD DP. OK. DOWNLOAD LWD TooLs & LD BHA. ERIC DIXON APPROVED RUNNING CASING WITH ONLY THE RES/GR LOGS. NO DENSITY LOGS. CHANGE RAMS TO 7". RU CASING EQUIP. RUNNING 7" CASING. ND BOPE MW: 0.0 VIS: 0 FINISH RUNNING CASING. SHOE @ 5728'. CIRC & COND MUD. TEST LINES. MIX & PUMP CEMENT. BUMP PLUG. TEST CASING. OK. BLEED OFF, FLOATS HELD. LD LANDING JT & CASING EQUIP. INSTALL 7" PACKOFF & TEST. CHANGE TOP RAMS & CHANGE OUT TOP DRIVE. MU BIT, 2 SCRAPERS, DRILL COLLARS & TIH. PU DP TO FLOAT COLLAR. PUMP SWEEPS & DISPLACED WELL. POOH. LD DP & BHA. DISPLACE TOP WITH DIESEL. CLEAR RIG FLOOR, CHANGE RAMS & ND BOPE. FINAL REPORT MW: 0.0 VIS: 0 CHANGE TOP DRIVE & ELEVATORS TO 5". ND BOPE. INSTALL TUBING HANGER, ADAPTER & TREE. TEST TREE & ADAPTER. INSTALL BPV. RIG RELEASED @ 1200 HRS., 10/30/95, MPJ-19A. SIGNATURE: (drilling superintendent) ( DATE: SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPJ-19A Rig Name: N-4ES AFE# 330168 Accept Date: 06/19/96 Spud Date: - Release Date: 06/27/96 June 20, 1996 MIRU. Raise & scope derrick & level same. Rig accepted 06/19/96 @ 1200 hrs. Check pressure on wellhead & ND adapter flange & tree. BOLDS & pull hanger. NU BOP's w/3-1/2" rams. Test BOP's. Test waived by John Spaulding AOGCC. MU BHA #1 & RIH t/1600'. Circ diesel cap off well to TT. Cont RIH w/3-1/2" tubing. June 21, 1996 Cont RIH w/bit & scraper t/5844'. Circ & filter brine. Change out brine in pits & wellbore. Test csg t/4500 psi, ok. POOH. ND flowline & ND perf flange. Rig Atlas & test lub t/1000 psi. RIN w/gun & log into position GR/CCL & perf 5524'-5498', 12 spf. POOH & LD guns. Made 3 runs w/6" GR/JB t/5570'. Picking up gun debris on 4th run. June 22, 1996 Cont POOH w/junk basket. MU BWD pkr & RIH & get on depth & set at 5529'. POOH & FID Atlas. RD perf flange & RU flowline. MU gravel pack assy & RIH on 3-1/2" tbg. Tag pkr & space out. Drop ball & rig lines to set pkr. Test tbg & ann. Ball shear at 2500 psi. Psi tbg to 3000 psi & shear off pkr w/8K over reverse out setting ball. Cont w/rig in Dowell & test lines t/5000 psi & pickle tbg w/47 bbl hec & perform data frac & send info to town for design. Frac well as design got 5500# perf & 8913# screen & reverse out 14413#. Attempt to stress screen several times. No success. Job done. Monitor well & RD Dowell. Circ & balance fluids for TOOH to prepare to prep zone #2. June 23, 1996 POOH w/frac-pac tool. MU JP plug & RIH & set at 5474'. Test plug t/1000 psi & spot 100# of sand on plug. POOH. ND flow nipple & rig shooting flange. Rig Atlas & test lub t/1000 psi. RIH w/20' gun & get on depth with GR/CCL & perf 5435-5455'. POOH. RIN w/28' gun & perf 5413'-5435'. POOH. RD Atlas & shooting flange & rig flow nipple. MU pkr ret tool & scraper & RIH. Spot 20 bbl Zanvis sweep in annulus @ 5270'. Cont RIH t/5474'. RU & rev circ sand & gun debris off plug & pull plug. POOH w/plug & scraper. Page June 24, 1996 Cont TOH w/scraper & JP plug. MU middle frac pac assy. TIH w/frac pac assy & engage pkr @ 5474'. Drop 2" ball & rig frac head set pkr 5297' w/3000 psi @ 500 psi increments. Test ann t/1500 psi. Ball sheared at 1800 psi & test tbg t/3200 psi & shear off pkr 4K over string wt reverse out ball. Rig Dowell & test lines t/5200 psi. Perform data frac & send infor to Anch. Perform frac. Had 14000# behind pipe, had 8 ppg at perf when s/o stressed screen t/2300 psi several times. Rev circ excess sand t/TT. RD Dowell & monitor well. TOH & LD frac tool. MU JP plug & RIH & set & test t/1000 psi @ 5297'. Spot sand. POOH w/JP setting tool. June 25, 1996 Cont POOH w/JP running tool. ND flow nipple & NU shooting flange. Rig Atlas & test lub t/1000 psi. RIH w/gun #1 & get on depth & perf 5275'-5279'. POOH & PU gun #2 & RIH & perf 5231 '-5260'. POOH & RD Atlas. RD shooting flange & NU flowline. MU HES JP pulling tool & 7" scraper & RIH & spot 25 bbl of Zanvis sweep on back side & gun debris from well bore & release plug @ 5279' & rev bottoms up. POOH & LD JP plug. MU HES frac pac assy & RIH & sting into pkr & space out. Drop ball & set pkr t/3000 psi & test annulus t/3000 psi. Rev circ ball to surface. June 26, 1996 Test lines t/5500# & perform inj test & data frac. Send data t/town & wait on info. Pump 59 bbl HEC pad & follow w/sand. Pumped a total of 65349# up to 12# per ga. 49000# behind pipe & reverse out 16349# after screen out & restress screen t/2000# & RD Dowell. LD frac head & monitor well. POOH & LD HES frac tools. Change rams t/2-7/8" & test same. MU & service ESP assy. RIH w/ESP compl to jt #90. RU heat trace equip. RIH w/ESP compl assy installing heat trace. June 27, 1996 Finish running in hole w/ESP assy installing heat trace. Space out for heat trace, MU hanger w/TWC installed. Install LJ & complete splice in ESP cable. ND BOP's. NU adapter flange & tree. Test hanger & tree t/5000 psi, ok. Pull TWC & install BPV. Freeze protect. Bullheaded 60 bbls diesel down annulus & 12 bbls down tbg. RD lines & secure wellhead. Rig released 06/27/96 @ 0300 hrs. Page 2 P~I~ COMPANY BF' WELL NAME MPJ-19A LOCATIOH 1 MILNE POINT LOCATION 2 ALASI(A MAGNETIC DECLINATION 28.77 GRID CO~',GENCE ANGLE 0.00 DATE: 27-0CT-95 API ~ 50-029-22607-01 JOB NUMBER 36738 WELL H~AD LOCATION: LAT(H/-S) 0.00 AZINLrfH FROM ROTARY TABLE TO TARGET IS TIE IH POIHT(TIP) : MEASURED DEPTH 112,00 TRUE VERT DEFgM 112.00 IHCLIHATIOH 0.00 AZIMUTH 0.00 LATITUDE(N/-S) 0,00 D~'AR~URE(E/-W) 0.00 DEP(EI-W) 305,18 ************* ANAJ}RII.I. ************** SUE¥£Y CALCULATIONS ************* CIRCLP~R ARC M£ASUR~ INT~gAL V~TICAL TARGET STATION AZIMUTH LATII'UI)E I)£Fq'H D~'IH SECTION INCLN. N/-S it ft ft ft deg. d~ it 112,00 0,0 ll2,P.X) 0,00 0.00 0.00 0.00 205,00 93,0 205,00 0,15 0,36 4,60 0,29 305,00 lOO.O 305,00 0,56 0,44 353,63 0,99 405,00 100,0 404.~ 0,90 0,64 26,94 1,87 505,00 100,0 504,98 1.73 0,~ 326,77 3,04 605,00 705,00 805,00 855,00 955,00 100,0 100.0 100,0 50.0 100,0 DEPARll]RE DISPLAC~MI~4T at AZIMUTH DLS E/-W deo/ ft ft deg. 100ft 0,00 0,00 0,00 0,00 0,02 0.29 4,60 0,39 0.01 0,99 0,35 0,10 0.22 1,88 6,62 0,36 0,02 3,04 0,47 0,83 604,95 4,42 2,24 297,19 4,61 -2,16 5,09 334,93 704,80 9,75 3,97 294,03 6,92 -7,06 9,88 314,42 804,43 18.01 5,74 291,49 10,16 -14,87 18,01 304,33 854.11 23,50 7,25 291,25 12,22 -20,14 23,56 301,24 953,04 37,36 9,49 284,80 16,61 -33,99 37,84 296,04 1,50 1.74 1,78 3,02 2,43 1005,00 1055,00 1105,00 1155,00 1205.00 50,0 50,0 50.0 50,0 50.0 1002,27 45,56 10,65 264,94 18,86 -42,44 46,44 293.95 1051,30 54.61 12,00 280,47 20.99 -52,02 56,10 291,98 1100,03 64,69 13,L:E) 279,02 22,87 %3,02 67,04 289,95 1148,47 75+78 14,~ 278,29 24,73 -75,28 79,24 288.19 1196,56 87,87 16+87 276,22 26,45 -88,86 92,72 286,57 2,32 3,~ 3,~ 2,27 4,06 1255.00 1305,00 1355,00 1405,00 1455.00 50,0 1244,15 101,15 18,83 274,35 27,85 50,0 1291,11 115,86 21,26 274,32 29,14 50,0 1337,34 131,96 23,54 271,52 30,09 50,0 1~2,98 148,91 24,69 271,01 30,54 50,0 1428,28 166,42 25,39 271,01 30,91 -104,12 107,78 284,97 -121,21 124,67 283,52 4,86 -140,24 143.43 282.11 5,03 -160,66 163,54 280,76 2,34 -181,82 184,43 279,65 1.40 1505,00 lSSS.Oo 1605.00 1655,00 1705,00 50,0 1473,37 184,27 25,78 270,88 31,27 50,0 1516,07 203,01 27,45 273,04 32,05 50,0 1562,30 222,55 28,15 271,19 ~.90 50,0 1606,05 243,07 29,81 274,96 34,22' 50,0 1649+29 264.47 30+44 272.52 35,85 -203,41 205,80 278,74 0,79 -225.79 228,05 278,08 -249,09 251,25 277,52 2,22 -273,27 275,40 277,14 4,~ -298,30 300,45 276,85 2,75 1755,00 1805,00 1855,00 1905,00 1955,00 50.0 1692.16 286,17 31,54 272.71 37.03 50,0 1734,50 308,73 32,72 273,70 38,52 50,0 1776,39 332,14 33,47 274,71 40,52 50,0 1817,73 356,64 34,98 276,89 43,37 50,0 1858,59' 382,07 35,41 277,33 46,94 -324,02 326,13 276,52 2,21 -350,57 352,68 276,27 2,58 -377,80 -405,77 408,08 276,10 3,89 -434,37 4~,89 276,17 1,00 2005.00 2055,00 2105,00 2155.00 2205.00 50,0 1699,18 408,04 36,05 278,60 50,99 50,0 193%18 435,09 37,67 280,58 56,00 50,0 1978.51 463,35 38,61 282.21 62,10 50.0 2017.26 492.53 39.79 283.00 69,00 50.0 2055.34 522.72 41,00 264+82 76.79 -463,28 466,08 276,28 1.96 -492,85 496,02 276,48 4,02 -523,11 526,79 276.77 2,~ -553.95 b-58+23 277.10 2.56. -585,40 590.42 277,47 3,38 2255,00 2305,00 2355.OO 2405,00 2455.00 50.0 2092,58 554.26 42.71 287.50 86,09 50.0 2128,88 587.14 44.33 288.38 96.70 50.0 2164,26 621,02 45.44 289,55 108,17 50,0 2198,81 655,94 47,14 290,97 120,69 50.0 2232,43 691,88 48,37 291,63 134,14 -617,43 623,41 277,94 4,95 -650,19 657,34 278,46 3,46 -6e.3,55 692,06 278,99 2,77 -717.45 727,53 279.55 3,97 -751.94 7/:~,81 280+11 2,65 SURVEY CALCULATIONS ************* HI~q~ULAR KC MT~ASL~£D IN~RYAL U~TICAL l~l~l STATION AZI~ ~TIT~ D~'~ D~H S~I~ INC~. ft ft ft it ~ ~eg ft ~05.00 ~.0 ~64.80 729.1~ ~.94 294.16 148.97 ~.~ ~,0 ~6,~ 767.42 5~,59 294,62 ~65 26~,~ ~.0 ~6,52 ~.59 53,43 ~7,~ 182,56 26~,~ ~.0 2~6,01 846.59 54,26 2~,18 ~1.14 U~.~ ~,0 ~4,75 ~7.U ~,59 ~1.18 ~1,09 D~ARTURI~ DISPLAC~EHT at ft ft -787.03 ~01,00 -822,55 638,95 -B~.16 877.36 -894,00 916.34 -929.71 95'5.63 280.72 281 282.01 282.68 263.38 DLS d. eq/ tOOft 6,43 1.49 6.03 1.8,1 7.07 2755.00 50.0 2412.60 920.69 56.73 309.74 242.45 2805,00 50.0 2439.59 970.71 57.94 303.15 264.73 2905.00 100.0 2491.48 1056.10 59.53 302.22 310.88 3005,00 1®,0 Z541.48 1142,60 60,48 302,44 357,20 3105.00 100.0 2568.84 1230.54 62.97 301,87 404.06 -965,~ 9W3,30 284.10 -1001,03 1035,44 284,01 -1072,97 1117,10 206,16 -1146,15 12(X),52 207,31 -1220,71 1285.84 280,31 2,39 4.72 1,78 0,97 2,54 3?.05,00 100,0 2632,36 13~0,51 65,45 304,98 453,67 3305,00 100,0 2674,81 1411,05 64,31 305,54 505,93 3405.® 100,0 2719,78 1500,36 62,24 305,8~ 558,06 3505.00 100.0 2768+13 1587,85 59,~ 307.46 610.32 3605,00 100,0 2017.71 1674.64 60.64 306,96 662,83 -1295,82 1372,94 289.30 -1369,75 1460,20 290.27 -1442.27 1546,47 291.15 -1512.48 1630,97 -1581,65 1714,~ t~2,74 3,74 2.70 0,84 3705.00 1®.0 2866.7'3 1761.74 60.63 307.18 715.37 374.6.32 41.3 2866.97 1797.75 60.76 307.61 737.25 3646.~ 100.6 2~7.18 1884.63 59.24 306.95 7~.03 3937.24 90.3 2985..03 1961.41 56,6~ 307.31 636.27 4034.69 97.7 3039.74 2042,23 55.18 307.73 885,54 -1651,18 1799,49 293.42 -1679,61 1~4,48 -1749,15 1919,~ 294,31 -1B10,24 1994,07 294,80 -1874.39 2073.05 295,29 0.19 0.96 1.52 2.96 1.58 4129.66 95.0 3094.~ 2119.71 54.18 304.69 931.33 4~3.92 94.0 3151.05 2194.96 52.13 304.91 974.28 4318.30 94.4 ~10.33 2266,33 50,06 301,28 1014.~ 4413,27 f5,0 3272,70 2339,81 47,64 302,06 1051,98 4505.75 96.5 222~.13 2409.67 45.12 302.19 1089.18 -1936,91 2149,19 295.68 -199~,71 2223,52 295,99 -2060,20 2.296,39 296,21 -2121,15 2367,~ 296,~ -2180,40 2437,30 296.54 2,62 2,19 3.71 2.41 2.82 4604.81 95.1 340~6.96 2476,12 43.81 301.01 1124.06 4696.94 94.1 3475.56 2540.46 42.63 302.41 1157.95 4794.55 95.6 3546.67 2604.32 41.26 203.95 11~.91 4892,87 98,3 3620,69 2669,04 41,07 304,76 1229,43 4982.73 69.9 3668.33 272B,20 41.28 305.78 1263.59 -2237.10 2503.63 296.68 -2291.95 2567.85 296.60 -2345.44 2631.37. 296.96 -2298.67 2695.S6 297.14 -2447o17 2754.14 297,31 · 1,63 1,62 1,79 0.57 0,79 5082.10 ~.4 3762.77 2794.01 41.69 306.84 1302.57 5178.73 96.6 3635.20 2857.95 41.2~ 206.W 1340.W,' 5273.20 94.5 2906.85 2919.48 40.11 306.46 1377.80 5368,48 95,3 ~80,06 2980.44 ~.48 306.79 1414,18 5464,24 95.8 4054,27 3040,94 38,91 306.46 1450.28 -2500.21 2819.17 ~7.52 -2551.36 2882.30 297.73 -2609.69 2943.11 297.91 -2649.64 3003.41 298.09 -2698.21 3063.27 298.26 0.82 0,50 1.23 0,70 0.63 5559.49 95.3 4126.55 3100.55 28.59 306.37 1485.6& -?.746.19 5653.65 94.2 4202.16 3159.26 26.57 206.44 1520.53 -27~.45 298.41 298.56 0.34 0,05 **~m-~e************************* FTU]JECT~ TO TD ************~:~.~***** 5750.00 96.3 4277.49 3219.31 3~.57 306.44 1556.21 -2841.77 **~,~******* **************** 3239.97 298.71 0.03 gyro/data B.P. EXPLORATION J-PAD, MPJ-19 MILNE POINT, ALASKA Gyro Multishot Survey in 5" Drillpipe Survey date · 20 October, 1995 Job number · AK1095G301 SR301 .DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 October26, 1995 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Aa~chorage, AK 99519-6612 Re; J-Pad, MPJ-19, Milne Point, Alaska Enclosed please find one (1) original mxd six copies (6) of the completed survey of Well #MPJ-19 We would like to take this opportunity to thank you for using Gyrodaata and we look forward to serving you in the future. Sincerely Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation _gyro/data CONTENTS JOB NUMBER :AK1095G301 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR301 .DOC ~ gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR301.DOC gyro/data DISCUSSION JOB NUMBER ' AK1095G301 Tool 080 was run in J-pad well number MPJ-19 inside of 5" drillpipe on Atlas 15/32 wireline. The survey was run without problems. SR301 .DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK1095G301 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR301 .DOC gyro/data 2. SURVEY DETAILS SR301.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK1095G301 CLIENT: B.P. EXPLORATION RIG: NABORS RIG 22E LOCATION: Milne Point WELL: MPJ-19 LATITUDE: 70.450 LONGITUDE: W SURVEY DATE: 20-Oct.,1995 SURVEY TYPE : MULTISHOT IN 5" drillpipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 64.5 asl 5195.0 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' and 30' UTM CO-ORDINATES: TARGET DIRECTION: 303.53 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE S U RVEYOR: STODDARD SR301.DOC gyro/data 3. OUTRUN SURVEY LISTING SR301 .DOC A Gyroda t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301 Run Date: 20-Oct-95 06:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 64.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 303.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 0.0 -64.5 0.00 0.0 0.0 0.00 N 0.00 E 0 - 5195 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO THE NABORS RIG 22E R.K.B. A DEPTH CORRECTION OF 5 FT. WAS MADE TO THE FINAL SURVEY. AT 64.5 FT. ABOVE S 105.0 .16 348.26 105.0 .1 40.5 .16 205.0 .36 4.60 205.0 .4 140.5 .21 305.0 .44 353.63 305.0 .8 240.5 .11 405.0 .64 26.94 405.0 1.1 340.5 .37 505.0 .93 326.77 505.0 1.9 440.5 .83 .2 .6 1.3 2.2 3.4 348.3 356.8 357.7 4.2 359.5 .15 N .60 N 1.30 N 2.19 N 3.37 N .03 W .03 W .05 W .16 E .03 W 605.0 2.24 297.19 604.9 4.6 540.4 1.51 705.0 3.97 294.03 704.8 9.9 640.3 1.74 805.0 5.74 291.49 804.4 18.2 739.9 1.78 855.0 7.25 291.25 854.1 23.8 789.6 3.01 905.0 8.33 289.34 903.6 30.4 839.1 2.22 5.4 10.2 18.3 23.8 30.5 335.8 315.5 305.1 301.8 299.3 4.94 N 7.25 N 10.49 N 12.55 N 14.89 N 2.22 W 7.12 W 14.94 W 20.21 W 26.57 W 955.0 9.49 284.80 953.0 37.8 888.5 2.71 1005.0 10.65 284.94 1002.3 46.1 937.8 2.33 1055.0 12.00 280.47 1051.3 55.2 986.8 3.22 1105.0 13.80 279.02 1100.0 65.4 1035.5 3.66 1155.0 14.92 278.29 1148.5 76.7 1084.0 2.26 38.1 46.6 56.3 67.2 79.4 296.8 294.6 292.5 290.4 288.6 17.14 N 19.39 N 21.53 N 23.41 N 25.27 N 33.97 42.42 52.00 W 63.00 W 75.27 W 1205.0 16.87 276.22 1196.6 89.0 1132.1 4.06 1255.0 18.83 274.35 1244.1 102.5 1179.6 4.09 1305.0 21.26 274.32 1291.1 117.4 1226.6 4.86 1355.0 23.54 271.52 1337.3 133.8 1272.8 5.04' 1405.0 24.69 271.01 1383.0 151.1 1318.5 2.33 92.9 107.9 124.8 143.5 163.6 286.9 285.3 283 .8 282.3 280.9 26.99 N 28.38 N 29.68 N 30.63 N 31.08 N 88.85 W 104.11 W 121.20 W 140.23 W 160.65 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 1455.0 25.39 271.01 1428.3 1505.0 25.78 270.88 1473.4 1555.0 27.45 273.04 1518.1 1605.0 28.15 271.19 1562.3 1655.0 29.81 274.96 1606.0 168.9 1363.8 1.39 184.5 279.8 187.1 1408.9 .81 205.9 278.9 206.2 1453.6 3.85 228.1 278.2 226.1 1497.8 2.22 251.3 277.6 247.0 1541.5 4.94 275.5 277.2 31.45 N 181.81 W 31.80 N 203.40 W 32.58 N 225.77 '~ 33.44 N 249.09 .,? 34.76 N 273.26 W 1705.0 30.44 272.52 1649.3 1755.0 31.54 272.71 1692.2 1805.0 32.72 273.70 1734.5 1855.0 33.47 274.71 1776.4 1905.0 34.98 276.89 1817.7 268.8 1584.8 2.76 300.5 277.0 290.8 1627.7 2.20 326.2 276.6 313.8 1670.0 2.60 352.7 276.4 337.6 1711.9 1.86 380.0 276.2 362.5 1753.2 3.89 408.1 276.2 36.39 N 298.30 W 37.56 N 324.01 W 39.05 N 350.56 W 41.06 N 377.79 W 43.91 N 405.76 W 1955.0 35.41 277.33 1858.6 2005.0 36.05 278.60 1899.2 2055.0 37.67 280.58 1939.2 2105.0 38.61 282.21 1978.5 2155.0 39.79 283.00 2017.3 388.3 1794.1 .99 436.9 276.2 414.6 1834.7 1.97 466.1 276.3 442.1 1874.7 4.02 496.1 276.5 470.7 1914.0 2.75 526.8 276.8 500.2 1952.8 2.57 558.3 277.2 47.48 N 434.35 W 51.52 N 463.27 W 56.53 N 492.84 W 62.64 N 523.11 W 69.54 N 553.94 W 2205.0 41.00 284.82 2055.3 2255.0 42.71 287.50 2092.6 2305.0 44.33 288.38 2128.8 2355.0 45.44 289.55 2164.3 2405.0 47.14 290.97 2198.8 530.7 1990.8 3.38 590.5 277.5 562.5 2028.1 4.95 623.5 278.0 595.7 2064.3 3.46 657.4 278.5 629.8 2099.8 2.77 692.1 279.0 665.0 2134.3 3.98 727.6 279.6 77.33 N 585.39 86.63 N 617.43 97.24 N 650.18 W 108.71 N 683.55 W 121.23 N 717.45 W 2455.0 48.37 291.63 2232.4 2505.0 50.94 294.16 2264.8 2555.0 51.59 294.62 2296.1 2605.0 53.43 297.63 2326.5 2655.0 54.26 297.18 2356.0 701.2 2167.9 2.64 763.9 280.2 738.6 2200.3 6.43 801.1 280.8 777.2 2231.6 1.49 839.0 281.4 816.5 2262.0 6.02 877.5 282.0 856.6 2291.5 1.82 916.5 282.7 134.68 N 751.93 W 149.52 N 787.02 W 165.62 N 822.54 W 183.10 N 858.15 W 201.68 N 893.99 W A Gy r o da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 2705.0 55.59 301.18 2384.8 2755.0 56.73 300.74 2412.6 2805.0 57.94 303.15 2439.6 2905.0 59.53 302.22 2491.5 3005.0 60.48 302.44 2541.5 3105.0 62.97 301.87 2588.8 3205.0 65.45 304.98 2632.4 3305.0 64.31 305.54 2674.8 3405.0 62.24 305.88 2719.8 3505.0 59.92 307.46 2768.1 3605.0 60.64 306.96 2817.7 3705.0 60.63 307.18 2866.8 3805.0 61.58 305.48 2915.1 3905.0 62.57 306.82 2961.9 4005.0 63.71 305.31 3007.1 4105.0 65.20 304.98 3050.2 4205.0 64.48 304.41 3092.7 4305.0 63.47 303.95 3136.6 4405.0 65.30 304.44 3179.8 4505.0 66.91 304.15 3220.3 4535.0 67.18 304.36 3232.0 4565.0 66.91 304.29 3243.7 4595.0 66.92 304.52 3255.5 4625.0 67.08 303.91 3267.2 4655.0 67.28 303.67 3278.9 897.4 938.9 981.0 1066.4 1153.0 1241.1 1331.1 1421.6 1510.8 1598.2 1684.9 1771.9 1859.3 1947.6 2036.7 2126.9 2217.3 2307.2 2397.4 2488.8 2516.4 2544.0 2571.6 2599.2 2626.9 SUBSEA DEPTH feet 2320.3 2348.1 2375.1 2427.0 2477.0 2524.3 2567.9 2610.3 2655.3 2703.6 2753.2 2802.3 2850.6 2897.4 2942.6 2985.7 3028.2 3072.1 3115.3 3155.8 3167.5 3179.2 3191.0 3202.7 3214.4 DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 7.07 955.7 283.~ 2.40 995.4 284.1 4.72 1035.6 284.8 1.78 1117.2 286.2 .97 1200.7 287.3 2.55 1286.0 288.3 3.74 1373.1 289.3 1.25 1460.4 290.3 2.10 1546.7 291.2 2.70 1631.2 292.0 .85 1715.1 292.8 .19 1799.7 293.4 1.77 1885.1 294.0 1.54 1971.6 294.6 1.77 2059.1 295.1 1.52 2148.0 295.5 .88 2237.4 295.9 1.08 2326.3 296.2 1.88 2415.6 296.5 1.63 2506.3 296.8 1.12 2533.6 296.8 .93 2561.0 296.9 .71 2588.4 297.0 1.95 2615.8 297.1 1.00 2643.3 297.1 Page 3 HORIZONTAL COORDINATES feet 221.63 N 929.69 243.00 N 965.31 265.27 N 1001.02 311.42 N 1072.96 357.74 N 1146.13 404.60 N 454.20 N 506.47 N 558.60 N 610.85 N 663.37 N 715.90 N 767.76 N 819.89 N 872.40 N 924.33 N 975.85 N 1026.33 N 1077.01 N 1128.52 N 1144.07 N 1159.65 N 1175.25 N 1190.77 N 1206.15 N 1220.69 W 1295.81 W 1369.74 W 1442.26 W 1512.46 W 1581.63 W 1651.17 W 1721.70 W 1793.04 W 18'65.15 W 1938.93 2013.34 2087.68 W 2162.26 W 2237.80 W 2260.63 W 2283.44 W 2306.21 W 2329.05 W 2352.03 W A Gyr oda t a D i r e c t i o n a 1 Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4685.0 67.10 303.62 3290.5 4715.0 67.44 303.66 3302.1 4745.0 67.48 303.94 3313.6 4775.0 67.21 304.13 3325.1 4805.0 67.87 304.27 3336.6 2654.5 3226.0 .64 2670.7 297.2 2682.2 3237.6 1.15 2698.2 297.3 2709.9 3249.1 .86 2725.8 297.3 2737.6 3260.6 1.07 2753.3 297.4 2765.3 3272.1 2.24 2780.8 297.5 1221.48 N 2375.05 W 1236.80 N 2398.09 W 1252.22 N 2421.11 1267.71 N 2444.05 1283.30 N 2466.99 W 4835.0 67.49 304.41 3348.0 4865.0 67.13 304.50 3359.6 4895.0 66.79 304.27 3371.3 4925.0 66.67 304.38 3383.2 4955.0 66.07 304.55 3395.2 2793.1 3283.5 1.36 2808.4 297.6 2820.8 3295.1 1.23 2835.8 297.6 2848.4 3306.8 1.32 2863.3 297.7 2875.9 3318.7 .52 2890.6 297.7 2903.4 3330.7 2.05 2917.9 297.8 1298.95 N 1314.61 N 1330.20 N 1345.74 N 1361.29 N 2489.90 W 2512.72 W 2535.51 W 2558.27 W 2580.93 W 4985.0 66.43 304.46 3407.3 5015.0 66.43 304.37 3419.3 5045.0 66.09 304.44 3431.3 5075.0 66.16 304.34 3443.5 5105.0 66.38 304.14 3455.5 2930.9 3342.8 1.22 2945.2 297.9 2958.3 3354.8 .29 2972.5 297.9 2985.8 3366.8 1.15 2999.8 298.0 3013.2 3379.0 .40 3027.1 298.0 3040.7 3391.0 .94 3054.4 298.1 1376.85 N 1392.39 N 1407.91 N 1423.41 N 1438.86 N 2603.56 W 2626.24 W 2648.90 W 2671.53 W 2694.24 W 5135.0 66.26 304.01 3467.6 5165.0 66.19 303.34 3479.7 5195.0 66.55 303.87 3491.7 3068.2 3403.1 .58 3081.7 298.2 3095.6 3415.2 2.04 3109.0 298.2 3123.1 3427.2 2.01 3136.4 298.3 1454.25 N 1469.47 N 1484.69 N 2716.99 2739.84 2762.73 Final Station Closure: Distance: 3136.40 ft Az: 298.25 deg. A Gyro d a t a D i r e c t i on a i Survey for B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301SS Run Date: 20-0ct-95 06:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 64.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 303.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, Job Number: AK1095G301SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet -64.5 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.00 N 0.00 E 0 - 5195 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO THE NABORS RIG 22E R.K.B. A DEPTH CORRECTION OF 5 FT. WAS MADE TO THE FINAL SURVEY. AT 64.5 FT. ABOVE S 100.0 .28 357.98 164.5 .3 .19 200.0 .41 358.07 264.5 .6 .15 300.0 .56 13.45 364.5 .9 .26 400.0 .81 205.38 464.5 1.6 .64 500.0 1.71 309.16 564.5 3.5 1.23 .6 353.3 1.3 357.3 2.2 1.6 3 .4 1.4 5.4 345.4 .42 N .03 W 1.02 N .04 W 1.83 N .12 E 2.89 N .08 W 4.31 N 1.33 W 600.0 3.27 295.30 664.5 7.8 1.64 700.0 5.03 292.51 764.5 14.9 1.76 800.0 7.48 290.84 864.5 25.2 2.85 900.0 9.76 284.83 964.5 39.7 2.62 1000.0 12.49 280.08 1064.5 58.0 3.34 10.2 323.7 18.3 309.3 30.5 301.3 46.6 296.3 67.2 291.9 6.32 N 5.14 W 9.19 N 11.81 W 13.04 N 21.54 W 17.67 N 35.94 W 22.04 N 54.98 W 1100.0 15.57 277.60 1164.5 80.8 2.86 1200.0 19.89 274.34 1264.5 109.0 4.42 1300.0 24.23 271.22 1364.5 144.1 3.43 1400.0 25.71 270.90 1464.5 183.5 .92 1500.0 28.23 271.38 1564.5 227.2 2.36 92.9 288.0 124.8 284.6 163.6 281.5 205.9 279.1 275.5 277.6 25.84 N 79.79 W 28.95 N 111.52 W 30.90 N 152.39 W 31.73 N 199.16 W 33.50 N 250.30 W 1600.0 30.83 272.59 1664.5 276.6 2.56 1700.0 33.26 274.42 1764.5 330.8 2.07 1800.0 35.50 277.51 1864.5 392.1 1.13 1900.0 38.28 281.63 1964.5 460.5 3.20 2000.0 41.42 285.48 2064.5 538.5 3.76 326.2 276.8 380.0 276.2 466.1 276.3 526.8 276.7 623.5 277.6 36.80 N 307.42 W 40.49 N 370.06 W 48.07 N 438.56 W 60.46 N 512.32 W 79.62 N 593.28 W A Gyroda t a D i r e c t i o n a i Survey B.P. EXPLOP~ATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 2100.0 45.45 289.56 2164.5 630.1 2200.0 50.92 294.14 2264.5 738.3 2300.0 54.65 298.36 2364.5 868.7 2400.0 58.70 302.70 2464.5 1022.0 2500.0 61.69 302.16 2564.5 1195.8 2.78 727.6 279.'0 6.39 801.1 280.8 3.37 955.7 282.9 3.31 1117.2 285.5 1.74 1286.0 287.8 108.79 N 683.78 W 149.38 N 786.70 W 207.57 N 904.53 W 287.43 N 1035.55 W 380.51 N 1182.36 W 2600.0 64.59 305.41 2664.5 1399.6 2700.0 60.09 307.34 2764.5 1591.6 2800.0 60.63 307.17 2864.5 1767.9 2900.0 62.63 306.74 2964.5 1952.7 3000.0 64.96 304.78 3064.5 2157.3 1.85 1460.4 290.1 2.65 1631.2 291.9 .22 1799.7 293.4 1.56 2059.1 294.6 1.30 2237.4 295.6 493.77 N 606.92 N 713.49 N 822.90 N 941.64 N 1351.78 W 1507.17 W 1647.97 W 1797.18 W 1963.92 W 3100.0 64.65 304.27 3164.5 2365.4 3200.0 67.04 304.05 3264.5 2592.8 3300.0 66.99 304.40 3364.5 2832.4 3400.0 66.29 304.04 3464.5 3061.1 3427.2 66.55 303.87 3491.7 3123.1 1.60 2415.6 296.4 1.66 2615.8 297.1 1.27 2863.3 297.6 .67 3081.7 298.1 2.01 3136.4 298.3 1059.03 N 1187.17 N 1321.17 N 1450.30 N 1484.69 N 2135.80 W 2323.75 W 2522.31 W 2711.15 W 2762.73 W Final Station Closure: Distance: 3136.40 ft Az: 298.25 deg. gyro/data 4. QUALITY CONTROL SR301 .DOC Quality Control Comparisons B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number : AK1095G301 / AK1095G301 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 505.0 .87 .93 -.057 329.18 1005.0 9.99 10.65 -.667 286.26 1505.0 25.93 25.78 .146 271.51 2205.0 40.75 41.00 -.247 283.86 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.2559 deg. Average Azimuth Difference = .33417 deg. OUTRUN Az 326.77 284.94 270.88 284.82 Delta 2.408 1.321 .634 -.953 gyro/daia QUALITY CONTROL REPORT JOB NUMBER · AK1095G301 TOoL NUMBER' 080 MAXIMUM GYRO TEMPERATURE · MAXIMUM AMBIENT TEMPERATURE ' 74.4c 22.6 c MAXIMUM INCLINATION' 67.87 AVERAGE AZIMUTH · 298.25 WIRELINE REZERO VALUE · 5 feet REZERO ERROR/K' n/a CALIBRATION USED FOR FIELD SURVEY' cALIBRATION USED FOR FINAL SURVEY' 8/21/95 8/21/95 PRE JOB MASS BALANCE OFFSET CHECK · .19 POST JOB MASS BALANCE OFFSET CHECK] · CONDITION OF SHOCK WATCHES -.04 USED .00 UPON ARRIVAL AT RIG · OK UPON COMPLETION OF SURVEY ' OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 5195 66.55 303.87 3491.7 1484.69N 2762.73W FINAL SURVEY 5195 66.55 303.87 3491.7 1484.69N 2762.73W SR301 .DOC gyro/data FUNCTION TEST JOB NUMBER: AK1995G301 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2205 40.45 40.45 40.45 40.45 40.45 AZIMUTH M.D. ff I 2 3 4 5 2205 284.2 284.2 284.1 283.99 283.86 SR301.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SP,3Ol .DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1095G301 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0098 DATA SECTION A0032 POWER SECTION A0027 COMPUTER A0153 POWER SUPPLY A0074 PRINTER A0079 INTERFACE A0071 BACKUP TOOL No. 731 GYRO SECTION A0054 DATA SECTION A0025 POWER SECTION A0052 COMPUTER A0122 POWER SUPPLY A0074 PRINTER A0082 INTERFACE A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 15/32 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: 17.5 feet MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 190 Lbs SR301 .DOC Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 7, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ,~a¢~ Oil & Gas Cons. 6om~i~io~ The following data of the Depth shifted CDR, CDR TVD for well MPJ-19A Job # 95362 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each 1 Depth shift display State. of Alaska .-'Alaska Oil & Gas Conservation Comm. Attn: Larry Grant :- 3001 Porcupine Drive Anchorage, Alaska 99501 1 OH-.LIS Tape I Blueline each 1 RF Sepia each oxY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each I RF Sepia each Sent Certified Mail Z 777 937 429 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER. MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE. ALASKA 99518-1199 HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP. AGE AK, 99501. Date: 28 June 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~ PFC/PERF FINAL BL+RF ~ PFC/PERF FINAL BL+RF ~PFC/PERF FINAL BL+RF ~I'"PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # I ECC No. 6517.01 6517.02 6517.03 6714.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please s iqD and return ~. Pe~cechnieal Da~a.-Cen .~ BP ~Prora~ion (Alaska)" I~ dUk' 1 2 199S .~,..~ ~ns. commission Anchorage LARRY GRANT · Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1' LDWG TAPE+LIS I LDWG TAPE+LIS Date: 4 December 1995 RE: Transmittal of Data Sent by: HAND CARRY ECC No. 'Run-'#' 1 - 6516,00- -- Run # 1 6517.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 /9 Anchorage, AK 99518 RECE VED Alaska Oil & ~ Cons. ~ommi~i~, LARRY GRANT ~ Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION I PFC/PERF FINAL BL&RF 1 PFC/PERF FINAL BL&RF 1 PFC/PERF FINAL BL&RF 1 SBT FINAL BL & RF 1 PLS FINAl, BL & RF 1 PLS FINAL BL & RF ECC No. Run $ 1 6511.01 Run # 1 6512.01 Run # 1 6516.00 Run # 1 Run # 1 6517.00 Run # 1 6518.00 Please sign and return to: Attn. Rodney D. Paulson ,. Suite 201 Anchorage, AK 99518 Atlas Wireline Services 5600 B Street . .. -. o'6' P.1 BP EXPI.OR.M'iON Date: To: From: Subject; November ;3, 1995 Alaska Oil & Gas Conservation Commission Attn: Bob Crandall Kathy Campoamor Technical Assistant Permit to Drill, MPJ-ISA (Permit #95-170) Memorandum The Permit to Drill for MPJ-19A was submitted with an inoorrect surface location. The original error was simply a "typo" on the Permit, the Well Plan Summary, and was also reflected on the permit letter. We request that you change your records according to the following. The iqcorr.eot surface Iocatipn.wa, s_submitte_d_as.: 2334' NSL, 3301' WEL, SEC. 28, T13N, R10E The_correct surface location shou_l.cl_.b_e:_ 2234' SNL, 3301' WEL, SEC, 28, T13N, R10E Thank you for your assistance in this matter, Kathy Campoamor ~t0V 0 7 ~995 A~ast~ Uii .& Gas Cons. Commissiot~ Anchorage TONY KNOWLE$, GOVEF~NOF~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 26, 1995 Randy Thomas, Drilling Supervisor BP Exploration (Alaska), inc. P O Box 196612 Anchorage, AK .99519-6612 Re: Milne Point Unit MPJ-19A BP Exploration (Alaska), Inc. ~_~/¢.,~...,Permit No 95-17(~31.f Surf Loc. -,,2~N~L, 3301 'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 3818'NSL, 889'WEL, Sec. 29, T13N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by co petroleum field inspector 659-3607. ?!o w. Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrillrqllb. Type of well. Exploratoryf-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE= 64.5 feet Milne Point Unit/Schrader Bluff 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025517 4 Locatirm. of well at surface 7. Unit or property Name 11 Type Bond(see 20 AAC 25.025) .~-.~,~- Er4-~: · "~¢:¢gb' AISL, 3301' WEL, SEC 28, T13N, RIOE Milne Point Unit ~ At top of productive interval 8. Well number Number 3589' NSL, 566' WEL, SEC29, T13N, RIOE MPJ-19A 2S100302630-277 At total depth 9. Approximate spud date Amount 3818' NSL, 889' WEL, SEC 29, T13N, RIOE 10/27/95 $200,000. O0 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MP and TVa) property line ADL 025906 889 feet No Close Approach feet 2555 5818' MD/4327' TVD feet 16. To be completed for deviated wells '17. Anticipated pressure (see 20 AAC 25.035 (e)(2}) Kickoff depth 3790 feet Maximum hole angle 61.4 o Maximum surface 1635 psig At total depth (TVD) 4210'/1817 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I-VD M D TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3369' 31' 31' 3391' 2708' 526 sx PF'E', 250 sx 'G', 250 sx PF'E' 8-1/2" 7" 26# L-80 Btrc 5788' 30' 30' 5818' 4327' 271 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~._, L, i Present well condition summary Total depth: measured feet Plugs (measured) 0CT 2_ 5 1995 true vertical feet Effective depth: measured feet Junk (measured) ~85_~a, ~Jk .& Gas Cons. C0_mrrlissi_QL~ ....... --',., Anchorage" true vertical feet "--' Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[-] 21. I hereby certify that the foregoing is true and correct to the best. of my knowledge Signed ~~...,,.~,~, Title ~ Date ~f~ ~- Commission Use Only Permit Number APl number IApproval date See cover letter /~0-"--..,//~4:~ 50-¢'.2.?- ~ ,2_, ~'O ~'"'C:)/I /O/'Z.~/~'"'-" for other requirements Conditions of approval Samples required [] Yes 1~ No Mud log required []Yes .[~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ];~ Yes [] No Required working pressure,,.f_or. BOPE 1~2M; FI3M; 1-15M; I--IIOM; I-I15M; Other:urJglllal Signer] By by order of Approved by D~.-.,,~u W. JollllStOR Commissioner [ne commission Date Form 10-401 Rev. 12-1-85 Submit in' Oate: October 25, 1995 To: From: Subject: Blair Wonzell, Senior Petroleum Engineer, AOGCC Randy Thomas, Drilling Superintendent, SSD MPJ-19A Permit for Sidetrack The attached Permit Package is being submitted due to the unforseen results of the original MPJ-19 well, i.e the Kuparuk Sands were wet. As is the case with most wells in the MPJ area the considered viable alternative in this case is to salvage at least the Schrader Bluff Sand package. The sidetrack is necessary because in the original well (J-19) the Schrader Bluff package was penetrated at an angle of approximately 67° which makes completion with ESP equipment not practicable. A lower angle (40° - 45°) through the section is required. To this end the attached Package is being submitted for your approval at your earliest convenience. Further, a summary of operations, or planned operations, to the point of actually sidetracking out of the existing MPJ-19 wellbore follows. (Verbal approval from Jack Harts and yourself for the following procedure) 1) 2) 3) 4) Drilled 8.5" hole to 13087' md. LWD showed the target Kuparuk sands to be wet. Decision made to sidetrack and make the well a Schrader Bluff producer. Plan submitted to AOGCC for P&A of existing J-19 wellbore as follows: Set P&A Plug #1 from TD (13087') to 200' above the Kuparuk B sand or 12590' to solate the Kuparuk Sands. This plug would not be tagged; Set P&A Plug #2 in two stages from 50' below the OC Sands to 200' above the MA sands to isolate the Schrader Bluff Package in the original wellbore. This plug will be tagged and the AOGCC Representative notified to witness the tag, if applicable; Set P&A/Sidetrack Plug #3 in one stage from 4290' to 3790' - the planned KOP for MPJ19A. Once P&A plugs are inplace the top cement plug will be dressed off to 3790' and the well kicked-off to the new Schrader Bluff target as noted in the APD. OCT 2 5 1995 .Oil .& Gas Cons. Commission Anchorage I Well Name: I MPJ-19A Well Plan Summary IType of Well (producer or injector): ISchrader Bluff Producer I Surface Location: 2334 NSL 3301 WEL Sec 28 T13N R10E UM., AK. Target Location: 3589 NSL 0566 WEL Sec 29 T13N R10E UM., AK Bottom Hole Location: 3818 NSL 0889 WEL Sec 29 T13N R10E UM., AK AFE Number: I 330168 I Estimated Start Date:I 10/27/95 I 1 818' I I vD: Well Design (conventional, slimhole, etc.): ling: I Nabors 22-E Operating days to complete: [ 3 14327' bkb I [KBE: [ 65' I Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1961 1864 MA 4866 3586 Top of Schrader Bluff Sands NA 5185 3834 NA Sands Target Sands 5185 3834 Target Sands OB Base 5533 4105 OC Base 5668 4210 Base of Schrader Bluff Sands Total Depth 5818 4327 TD Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3369 31/31 3391/270~ 8 1/2" 7" 26# L-80 btrc 5788 30/30 5818/432; Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 4210' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 1817 psi, is 1635 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional DSS Intermediate N/A Final 1. PDC Bit f/Prince Creek to TD w/MWD Dir and LWD (GR/CDR/CDN). Cased Hole Logs: Mudloggers are NOT required for this well. Alaska Oil & Gas Cons. CommissioD Anchorage Mud Program: Special design considerations I None Surface Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Intermediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PP G) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 13790' (Using existing wellbore to KOP) Maximum Hole Angle: 161.4° Close Approach Well: I <No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MPJ-19: 1. Approval is requested for Annular Pumping into the MPJ-19 and MPJ-13 9-5/8" x 7" casing annuli. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 3391' md (2722' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 3100 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BEES) (BBLS) Milne Point MPJ-13 4935 0 1995 Milne Point MPJ-19 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. OCT 25 i995 .~a_sJ~, O~il & Gas Cons. Commission -'-~-~ Anchorage , , 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. . MPJ-19A Proposed Summary of Operations MU a PDC bit on a motor, with a Directional MWD and LWD CDR/CDN (G R/RES/Density/Neutron). RIH to top of P&A cement plug in existing MPJ-19 wellbore. Dress off top of plug to planned KOP at 3790' md. Kick-off well on same Azimuth as original well MPJ-19. Drill 8.5" hole to TD as per directional plan. Circulate to condition hole for casing. Run 7" casing to TD. Circulate to condition mud/hole for cement. Cement 7" casing as per program. RIH while PU 3-1/2" drill pipe and tandem 7" 26# scrapers and bit. Drill the ES Cementer and RIH to PBTD, perform a casing wash while displacing the hole with source water. Filter source water to 2 micron absolute. Freeze Protect Top 2000' of hole with diesel. Pressure test above the plug to 3500 psig. POOH LD remainder of 3-1/2" drill pipe. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Perform Casing Wash. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: The original well MPJ-19 had a FIT run when the 9-5/8" surface casing was dril out. The FIT was conducted to, and held 12.5 ppg EMW. There are no identifiable drilling hazards or risks on this well other than obserl good drilling practices. MPJ-19A Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: NONE FLUID LOSS: < 50cc/30 min @ 140° F YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/s THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60°F BHST 80° F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 271 FLUID LOSS: 100-150 cc CENTRALIZER PLACEMENT: 1. . MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from CC Base Sand to 200' above Sand (50 Total). Run 2 each Straight Blade Ridgid Centralizers inside the 9-5/8" surface casing shoe. Total number of 7"x 8-1/4" Straight Blade Centralizers required = 52 each. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Cement volume is calculated to cover from the CC Base to 500' above the MA Top with 30% excess. r'r'T 2 1995 Gas Cons. C0mmissi~ ~~95 11:48 Anadr ~'11 DPC 907 344 2160 P.04 ! SHARE0- SERV I Cb.S' DR I L'L I N6 ,. ....... i ii i i A} TIE-INSURVE' 3705 2867 "762 60.63 I'l/U ~ t/~ BI TOP~"INDOW 37~5 ~gO~ '"3~ ~'3~ VERTICAL SECTION VIEW ~) ~o,/~u,,~ ~/,oo 3,~o ~,o, ,,~ ~,.,, ........ D) END 2/~00 CURVE 492] ~28 2698 ~8.82 E) TARGET 5~B5 3834 2864 38.82 Section at: 305.~8 F) T8 5B]8 4327 326~ 38.82 TVD Scale.' ~ ~nch = 600 feet Dep Scale · 1 inch : 600 feet <KB> o .. - J "-~ Drawn ' 10/25/95 300 ...... ' ' " i i 600 , ' '" ~ .... ,, , ' . .NADR EL '~ NO~AP>ROX/ED.: :OR ~ ~oo ' ~ EXE~u, ~,'* ~m .... ~ · ', PLAN ¢ ]~'. ~ ,' i500- - '~, b ' - ............. - .... --- ' ~ -: ~, :~ I~:U 2400 ' ~ Cmnmj~ ..... " 2700 ........... ,~ ~ _ ..... _ .... eelnm .:': 3000 ........ ~ ~.. _ 3300- ~ .... . .. ,: - ...... ~oo_'~_~_'~n_ ....... 25~25 ~ ~ .... ~ ............................. x ........ 1 .~a~-~ ~---~ .... 7 ........ 2 ...................... . ~800 ...... 0 ~00 riO0 ~00 1~00 1500 1~00 ~00 ~00 8700 ~000 3lBO ~$00 ~flO0 Section Departure (~nad¢~]] (c)95 I~PJ~gAPl 2.5b.0-~ 11:15 A~ P) i. ~m MPJ- gA PLAN VIEW CLOSURE · 3280 feet at Azimuth 298.88 ' lOECLINATION.: +27.728 IE) ISCALE .......: ! inch : 300 ,feet '7~'~ '~ I ..... 10/25/95 ..... '~ ., rker I~enti~ation MD N/S E/W "~ ,.,. ,,, 11 TIE-IN SURVEY ~, 3705 715 1651 BI TOP OF WINDOW ~ 3785 757 1707 C) KOP/C~VE 2/100 '~3790 760 171t ,. .~:~_ ,~. DI END 2/~00 CURVE ~I ~260 2~3 ..... ,,.. , El TARGET 5]~, 1356 2548 " ,. . ' . ANADR LL A-DP~ , ..~ . A~ ~ ~ FE/,SIB! _IT~ PL/~N '~ qOi APF~RO~'ED i-u~ ,~oo i m '" I ' Pi.AN [~.._/" .... I ' ; ' i ~'~ ' , '.. '-. !~00 3750 3600 ~a~n ~nn a,cn ~nnn .o50 2700 ~50 ~400 2250 2100 ~950 ~800 ~650 1500 1350 ~200 <- 1800 1650 _.._,_- PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev [] redrll~ serv [] II32- , ADMINISTRATION ENGINEERING 11. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party ............. . N Operator has appropria%e bond in force ........ ' N Permit can be issued without conservation order .... ' N Permit can be issued without administrative approval. N Can permit be approved before 15-day wait ....... N 14. Conductor string provided ............... 15. Surface casing protects all known USDWs'. ....... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CM~ vol adequate to tie-in long string to surf csg . . 18. CMTwill cover all known productive horizons ...... 19. Casing designs adequate for C, T, B'& permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ N ~~~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable . . ~ ......... / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y /N 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ./~ N 34. Contact name/phone for weekly progress reports . . . ./. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Z 0 ~-~ 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 simp!ify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. R CEIVED AUG 0 8 199~ At~ Oil & ~ Con~. Anchor~e * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : B.P. EXPLORATION WELL NAME : MPJ-19A FIELD NAME : MILNE POINT BOROUGH · NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22607-01 REFERENCE NO : 95362 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NA~E : B.P. EXPLORATION WELL NAlViE : MPJ-19A FIELD NAM~ : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22607-01 REFERENCE NO : 95362 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:56 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 7 ORIGIN : FLIC REEL NA~E : 95362 CONTINUATION # : PREVIOUS REEL : COFff4ENT · BP EXPLORATION (ALASKA) , MILNE POINT MPJ-19A, API #50-029-22607-0 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 7 ORIGIN : FLIC TAPE NAME : 953 62 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : BP EXPLORATION (ALASKA), MILNE POINT MPJ-19A, API #50-029-22607-0 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPJ- 19A 500292260701 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 7-AUG-96 BIT RUN 1 ......... 953 62 ST. AMOUR PYRON BIT RUN 2 BIT RUN 3 28 13N IOE 2234 3301 64.50 64.50 35.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 3390.0 LIS Tape V=_~fication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:56 3RD STRING PRODUCTION STRING REM_ARKS: Well drilled 27-0CT through 28-0CT-95 with CDR only. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAlViE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMF2TT: 0.5000 FILE SUM~zARY LDWG TOOL CODE .............. $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEAS~DEPTH) START DEPTH STOP DEPTH 3674.5 5750.0 BASELINE DEPTH 88888.0 5609.0 5596.5 5584.5 5569.5 5550.5 5529.5 5515.5 5495.0 5453.5 5424.5 5415.5 5400.0 5373.5 5367.0 5300.5 5286.0 5277.0 5258.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88888.5 5609.5 5596.5 5585.0 5569.5 5549.5 5529 0 5516 0 5495 5 5453 5 5424 0 5414 5 5399 5 5373.0 5367.0 5300.0 5285.0 5276.5 5257.5 LIS Tape V=_~fication Listing Schlumberger Alaska Computing Center 5248.5 5243.5 5239.5 5237 5 5193 5 5185 0 5168 5 5157 5 5139 0 513 6.5 5129.0 5117.5 5074.5 5065.5 5051.0 5047.5 5045.5 5040.5 5031.0 5008.5 5004.5 4985.0 4961.5 4952.0 4948.0 4933.0 4915.0 4885.5 4876.5 4868.0 4856.0 4837.5 4832.5 4829.5 4820.0 4814.5 4809.5 4801.5 4792.5 4780.5 4775.0 4766.5 4752.5 4735.5 4733.0 4727.0 4722.5 4681.0 4668.5 4637.5 4611.0 4602.0 4589.5 4583.5 4569.5 5248.5 5242.5 5238.5 5237.0 5193 0 5185 0 5168 5 5158 5 5140 0 5137 0 5129 5 5117 5 5074 0 5066 0 5051 5 5047.5 5045.0 5038.5 5032.0 5008.0 5003.5 4985.0 4962.0 4952.5 4948.0 4933.5 4916.0 4888.5 4876.5 4869.0 4855.0 4839.5 4834 5 4832 0 4820 0 4815 0 4809 5 4803 0 4792.5 4780.5 4776.0 4768.5 4754.0 4737.0 4734.0 4728.5 4723.5 4683.5 4670.0 4639.0 4613.0 4604.5 4591.5 4585.0 4570.5 7-AUG-1996 10:56 PAGE: LIS Tape V=__fication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:56 PAGE: 4567.0 4548.5 4503.5 4494.0 4471.0 4463.5 4432.5 4424.5 4417.0 4401.0 4379.5 4372.5 43 68.5 4366.5 4358.0 4354.0 4315.5 4300.0 4279.5 4227.0 4209.5 4157.0 4132.0 4117.5 4083.0 4069.0 4060.0 4050.0 4024.0 3994.0 3963.5 3946.5 3936.5 3928.5 3918.0 3913.0 3893.0 3874.5 3865.5 3859.5 3854.5 3852.0 3833.5 3815.0 3774.5 3768.0 3762.0 3757.5 3748.5 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE 4567.5 4550.0 4505.0 4493.0 4472.5 4465.0 4434.5 4426.5 4419.0 4401.0 4381.5 4373.5 4367.5 4365.0 4359.5 4354.0 4316.0 4299.5 4279.5 4225.5 4207.0 4155.0 4128.0 4114.0 4079.5 4064.5 4057.5 4047.5 4022.5 3992.5 3962.0 3945.5 3934.0 3927.0 3919 0 3912 0 3890 5 3871 5 3862 5 3855 0 3848.5 3847.0 3830.5 3812.5 3774.0 3763.5 3758.5 3753.0 3743.5 95.0 BIT RUN NO. MERGE TOP MERGE BASE LIS Tape V= _£ication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:56 PAGE: REM_ARKS: The depth adjustments shown above reflect the MWD GR to the CH GR logged by Atlas. All other MWD curves were carried with the GR. This file also contains the Very Er~hanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~k4 630352 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~4M 630352 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~4~ 630352 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ 630352 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~4~ 630352 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630352 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630352 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630352 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TIE GAPI 630352 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:~6 PAGE: ** DATA ** DEPT. 5750.000 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD FET.MWD -999.250 GRCH. TIE -999.250 DEPT. 4800.000 RA.MWD 10.363 RP.MWD VRP.MWD 12.012 DER.MWD 10.893 ROP.MWD FET.MWD 0.222 GRCH. TIE 359.346 DEPT. 3674.500 RA.MWD -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD FET.MWD -999.250 GRCH. TIE 27.837 -999.250 143.617 11.070 208.639 -999.250 -999.250 -999.250 -999.250 11.577 36.470 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCRE~IF2PT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 3679.5 5749.5 $ LOG HEADER DATA LIS Tape Ve~=£ication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:~6 PAGE: 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 ......................... CDR RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT ~IEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 28-0CT-95 FAST2.5 4.0 MEMORY 5750.0 3681.0 5750.0 65 38.7 60.6 TOOL NUMBER RGS051 8.500 3390.0 LSND 9.60 47.0 1.410 55.0 1.100 50.0 REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 3820' - 5750' HOLE ANGLE AT TD = 38.57 DEG @ 5750' RES TO BIT: 46.18'; GR TO BIT: 56.60' NEUT TO BIT: 108.18'; DENS TO BIT: 101.20' TD WELL @ 08:45 28-0CT-95 MAX DEVIATION 60.63 AT 3725 CDN TOOL FAILED PRIOR TO RECORDING DATA $ LIS FORMAT DATA 20000 LIS Tape Vez~£ication Listing Schlumberger Alaska Computing Center 7-AUG-1996 10:~6 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID OPUDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 Otff4M630352 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~ff~630352 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 OBT~M 630352 O0 000 O0 0 2 1 1 4 68 0000000000 PSVR LW1 0HI4~4630352 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OP~4M 630352 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 630352 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630352 O0 000 O0 0 2 1 1 4 68 0000000000 TAB LW1 HR 630352 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 5749. 500 ATR. LWl -999. 250 PSR. LW1 - 999. 250 ATVR. LW1 PSVR.LWl -999.250 DER.LW1 -999.250 ROPE.LW1 143.617 GR.LW1 TAB. LW1 -999. 250 DEPT. 4800. 000 ATR. LW1 9. 800 PSR. LW1 8. 912 ATVR. LW1 PSVR.LW1 9. 075 DER.LWl 9. 131 ROPE.LW1 208. 639 GR. LW1 TAB. LW1 O. 225 -999.250 -999.250 8.877 41.402 LIS Tape Ve~=fication Listing Schlumberger Alaska Computing Center 7-AUG-1996 lO:b6 PAGE: DEPT. 3 679. 500 ATR . LW1 PSVR . LW1 -999. 250 DER. LW1 TAB. LW1 -999. 250 -999. 250 PSR. LW1 -999. 250 ROPE. LW1 -999. 250 ATVR. LW1 - 999. 250 GR. LW1 -999.250 5. 425 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 96/08/ 7 ORIGIN : FLIC TAPE NAME : 95362 CONTINUATION # : 1 PREVIOUS TAPE COf~iENT : BP EXPLORATION (ALASKA), MILNE POINT MPJ-19A, API #50-029-22607-0 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 7 ORIGIN : FLIC REEL NAME : 95362 CONTINUATION # : PREVIOUS REEL : COf~4ENT · BP EXPLORATION (ALASKA), MILNE POINT MPJ-19A, API #50-029-22607-0 ~ Anchorage / / ~ : ':'5'E:: : '-'-"~,. :.... :::.:::~::' ',':'"".:>','?..-- il' ~ [ ~i~ .~ 51t I~ - ll: ' - I: Tl I I r l( I : I I - ]' ': ~'-l' - ' '': ...... ' :' "' ' ' ¢ · , ..... ¢ : ,-'~----:--.~-,:~--*-'5'::-*'-:.- .. - ~ .~U _ ...:~. ~ . i~ : .... ;:~=- ": - 'l.5~- ; '}:':. ::~::.~ : .- ' - ,~ ~ ~ ~-~ ..i'::',: '.:" '::. - ~ ---~ . -'-- ~ ~: ,~-~s;,&~-~,z..~ . /¢..~-;::::,::.tt -~,-,:,:/-.-:_::-:;::;._ .:.'. ~ / ~._. I -. ~: ..~:: ,r--~- 2 /~-,%:-~':~:::~ ~:--'.L-- :~;:~-:; :'---¢ : _::.. .: ./: ~ · ~ ~ - '~ ~ ~,~'~ /-' :"-':~'>:' ..--": -¢ ...... --- :-':~'-'-: ' · ~ke -'~ - '~ ~ ~: .... . ......... . ....,~;;.:-- ,:,;;~;; ....... ~' ~, -,:'r~'~/ , ,~ :-t:::;-::::.:.~:;'::;';':': ". ':~ ::::::::::::::::::::::: Run 1: .-% ~:~,~ / ....-. ,~'-:? ::::::::::::::::::::::::: ..... ::_::::~:_~ : ~_ ¢~ - . ~: :': :---:-~ ...... --':>-:',:~:.::.:._::.--: 08 - NOV - 1995 , -. ::-.;.... I - c '.:-.~ Z:-:L:-:-:-: ~:~ ~- ~ . I~ -::-;:.:~.:,-~-, :---.-_:.-_,.,-,:,-_.-..-.,-~--.~arRed L, ne G~ ~~~::- /-' -. :: -,::-::::.::.~ -:::-:-:~.. --::.: ~.~ : ~.- -~ -_: - _ ~: ..~-..' .,,.. - :..~: 3600 5630 WESTERN ATLAS Logging Services pe Subfile 2 is type LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: 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 MPJ- 19A 500292260701 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 02-DEC-95 6517.00 K. RICHARDS J. FOX 28 13N 10E 2234 3301 64.50 35.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 20.000 115.0 3RD STRING 9.625 3391.0 PRODUCTION STRING 7.000 5728.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 1 1 08-NOV-95 WESTERN ATLAS LOGGING SERVICES ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MARKED LINE GRCH. MAGNETIC MARKS USED FOR DEPTH CONTROL. LINE WAS LAST MARKED ON 14-OCT-95 REMARKS: 91.10 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH - GRCH 3585.0 5630.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : BP EXPLORATION : MPJ - 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI * DATA RECORD (TYPE# 0) Total Data Records: 33 API API API API Log',Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1022 BYTES * Tape File Start Depth = 3580.000000 Tape File End Depth = 5635.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8223 datums Tape Subfile: 2 126 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes ~pe Subfile 3 is type. LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 4745.0 BASELINE DEPTH GRCH 4746.5 4747.0 4754.5 4754.5 4768.5 4768.5 4770.0 4770.0 4771.0 4770.5 4773.0 4772.5 4774.0 4773.0 4774.5 4774.0 4775.0 4774.5 4788.5 4789.0 4792.5 4793.0 4793.5 4793.5 4805.0 4805.0 4825.5 4825.5 4835.5 4836.0 4842.5 4843.0 4853.5 4853.5 4873.5 4874.0 4896.0 4896.5 4906.5 4907.0 4907.0 4907.5 4909.5 4909.0 4910.0 4910.0 4913.0 4912.5 4915.5 4915.5 4917.0 4917.5 4917.5 4918.0 4930.0 4930.0 4933.5 4934.5 4944.0 4944.5 4962.0 4962.5 4967.0 4967.0 4976.5 4977.5 4980.0 4980.5 4985.5 4986.0 4986.0 4987.0 4987.5 4988.5 4988.5 4989.0 STOP DEPTH 5025.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 4989.0 4998.0 5004.0 5004.5 5011.0 5021.5 $ REMARKS: 90.0 4999.5 5OO5.5 5006.0 5012.0 5022.5 PASS 2 (REPEAT PASS). CN WN FN COUN STAT / ??MATCH2A. OUT $ : BP EXPLORATION : MPJ- 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 * DATA RECORD (TYPE# 0) Total Data Records: 1022 BYTES * Tape File Start Depth = 4740.000000 Tape File End Depth = 5030.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1163 datums Tape Subfile: 3 80 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes ~'ape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3582.0 $ LOG HEADER DATA STOP DEPTH 5635.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR SBAR PCM CCL GR P/T $ SINKER BAR SINKER BAR SINKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMARAY PRESSURE/TEMPERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 08-NOV-95 FSYS REV. J001 VER. 1.1 1906 08-NOV-95 5642.0 5634.0 3600.0 5630.0 2400.0 YES TOOL NUMBER 8250EA 8248EA 8262XA 8255XA 0.000 5728.0 0.0 SOURCE WATER 8.40 0.0 84.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0 0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPJ - 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 165 Tape File Start Depth = 3580.000000 Tape File End Depth = 5635.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49329 datums Tape Subfile: 4 242 records... Minimum record length: 62 bytes ~mum record length. 1006 bytes ~'ape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4741.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (PT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR SBAR SINKER BAR PCM CCL GR P/T $ STOP DEPTH 5027.0 PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY PRE S SURE / TEMPERATURE 08 -NOV- 95 FSYS REV. J001 VER. 1.1 1851 08-NOV-95 5642.0 5634.0 3600.0 5630.0 2400.0 YES TOOL NUMBER 8250EA 8248EA 8262XA 8255XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 5728.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SO.CE WATER 8.4O 0.0 84.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0-~ TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPJ- 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 GAPI 4 4 F/MN 4 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 4740.000000 Tape File End Depth = 5030.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6969 datums Tape Subfile: 5 101 records... Minimum record length: 62 bytes ~mum record length: 1006 bytes pe Subfile 6 is type~ wiS 95/12/ O1 **** REEL TRAILER **** 95/12/ 1 01 Tape Subfile: 6 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes End of execution: Fri 1 DEC 95 10:37a Elapsed execution time = 11.54 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) MPJ - 19A 500292260701 BP EXPLORATION (ALASKA_) INC. WESTERN ATLAS LOGGING SERVICES 02-DEC-95 6517.00 K. RICHARDS J. FOX 28 13N 10E 2234 3301 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING 64.50 35.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 20.000 115.0 91.10 9.625 3391.0 40.00 7.000 5728.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 1 1 08-NOV-95 WESTERN ATLAS LOGGING SERVICES BASELINE DEPTH $ REMARKS: MARKED LINE GRCH. EQUIVALENT UNSHIFTED DEPTH MAGNETIC MARKS USED FOR DEPTH CONTROL. LINE WAS LAST MARKED ON 14-OCT-95 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 WAS NOT DEPTH SHIFTED SINCE PASS 1 IS THE DEPTH REFERENCE FOR THIS WELL. ALE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 3585.0 5630.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : BP EXPLORATION : MPJ- 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 33 1022 BYTES * Tape File Start Depth = 3580.000000 Tape File End Depth = 5635.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8223 datums Tape Subfile: 2 126 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes x'ape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: START DEPTH 4745.0 BASELINE DEPTH 4746.5 4754.5 4768.5 4770.0 4771.0 4773.0 4774.0 4774.5 4775.0 4788.5 4792.5 4793.5 4805.0 4825.5 4835.5 4842.5 4853.5 4873.5 4896.0 4906.5 4907.0 4909.5 4910.0 4913.0 4915.5 4917.0 4917.5 4930.0 4933.5 4944.0 4962.0 4967.0 4976.5 4980.0 4985.5 4986.0 4987.5 4988.5 STOP DEPTH 5025.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 4747.0 4754.5 4768.5 4770.0 4770.5 4772.5 4773.0 4774.0 4774.5 4789.0 4793.0 4793.5 4805.0 4825.5 4836.0 4843.0 4853.5 4874.0 4896.5 4907.0 4907.5 4909.0 4910.0 4912.5 4915.5 4917.5 4918.0 4930.0 4934.5 4944.5 4962.5 4967.0 4977.5 4980.5 4986.0 4987.0 4988.5 4989.0 4989.0 4998.0 5004.0 5004.5 5011.0 5021.5 $ REMARKS: '~0.0 ~_~9.5 5005.5 5006.0 5012.0 5022.5 PASS 2 (REPEAT PASS). CN WN FN COUN STAT / ??MATCH2A. OUT $ : BP EXPLORATION : MPJ - 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 5 Tape File Start Depth = 4740.000000 Tape File End Depth = 5030.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1163 datums Tape Subfile: 3 80 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes ~pe Subfile 4 is type. LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3582.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 5635.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR SBAR PCM CCL GR P/T $ SINKER BAR SINKER BAR SINKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY PRESSURE/TEMPERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 08-NOV-95 FSYS REV. J001 VER. 1.1 1906 08-NOV-95 5642.0 5634.0 3600.0 5630.0 2400.0 YES TOOL NUMBER 8250EA 8248EA 8262XA 8255XA 0.000 5728.0 0.0 SOURCE WATER 8.40 0.0 84.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RA.:.~ NORMALIZATION IN OIL ZONb TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPJ- 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 1 1 F/MN 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 165 Tape File Start Depth = 3580.000000 Tape File End Depth = 5635.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49329 datums Tape Subfile: 4 242 records... Minimum record length: 62 bytes ~imum record length: 1006 bytes ~pe Subfile 5 is type~ ~IS FILE HEADER FILE Nb~BER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4741.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 5027.0 08-NOV-95 FSYS REV. J001 VER. 1.1 1851 08-NOV-95 5642.0 5634.0 3600.0 5630.0 2400.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR SBAR PCM CCL GR P/T $ SINKER BAR SINKER BAR SINKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY PRESSURE/TEMPERATURE TOOL NUMBER 8250EA 8248EA 8262XA 8255XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 0.000 5728.0 0.0 SOURCE WATER 8.40 0.0 84.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RA~E NORMALIZATION IN OIL ZONe. TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION : MPJ- 19A : MILNE POINT/SBP : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 '1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 4740.000000 Tape File End Depth = 5030.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6969 datums Tape Subfile: 5 101 records... Minimum record length: 62 bytes ~ximum record length: 1006 bytes £ape Subfile 6 is type: LIS 95/12/ 1 01 **** REEL TRAILER **** 95/12/ 1 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 1 DEC 95 10:37a Elapsed execution time = 11.54 seconds. SYSTEM RETURN CODE = 0
