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Home My WebLink About197-220 111/ • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday,January 18, 2018 8:19 AM To: Wallace, Chris D (DOA); Schwartz, Guy L(DOA) Cc: Stan Porhola Subject: MPJ-18 (PTD#1972200) Below Packer Tubing Leak Attachments: MP J-18 SCHEMATIC 8-29-2017.doc Chris, As discussed briefly yesterday, Milne Point Injector MPJ-18(PTD#1972200)was recently identified to have a leak at a water flood regulating mandrel that is located below the tubing packer.The well is completed to allow selective or multizone injection into the Schrader Bluff NB, OA and OB sands(schematic attached).The leak itself is to a permitted interval/perforations and does not affect the well's integrity or ability to pass an MIT-IA.The well is on a 2 year MIT cycle (single casing)with a passing MIT-IA on 8/15/16. The well currently has an open sundry(#317-552)for a patch of the leak however it requires a coil cleanout. Until we are able to patch the leak and manage injection through the water flood valves alone, our plan is to return the well to injection. Injection through the leak is into the NB sand and is desired for reservoir management.The well will be treated as a multizone injector with associated injection profile logging requirements until the leak is repaired. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANED 1 vo • • �s� THE STATE Alaska Oil and Gas �r�►,,`s-d��_ ofALA Conservati®n Commission Witt 333 West Seventh Avenue �_ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 11 `7:rt�� Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager �`V6 HilcorpAlaska, LLC SCANNED 'l 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil POol, MPU J-18 Permit to Drill Number: 197-220 Sundry Number: 317-552 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, • Hollis S. French Chair J DATED this 3° day of November, 2017. i 0 RECEIVED NOV 2 0 20}7 STATE OF ALASKA 0'i <</2/ l i7 ALASKA OIL AND GAS CONSERVATION COMMISSION AOG CC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set Retrievable Patch Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 197-220 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-029-22834-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No D MILNE PT UNIT J-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025515 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): 12,457' 7,423' 8,109' 4,200' 1,583 8,109' 7,937' Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' N/A N/A Surface 8,214' 9-5/8" 8,245' 4,262' 5,750psi 3,090psi Production 12,395' 7" 12,425' 7,393' 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" 9.2#/L-80/TC-II 8,041' Packers and SSSV Type: Packwncj SSSV MD(ft)and ND(ft): (2)9-5/8"x 4.5"Baker Premier&9-5/8"x 4.5"Baker S-3 and N/A 7..40MD/4,037TVD,7,698MD/4,023TVD&7,913MD/4,114TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑, 14.Estimated Date for 15.Well Status after proposed work: Operations: 12/8/2017 CommencingOIL ❑ WINJ Q 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. Authorized Name: Bo York Contact Name: Stan Porhola STP Authorized Title: Operations Manager Contact Email: sporhola(C77hilcorp.com ...............9Contact Phone: 777-8412 Authorized Signatur-: //, Date: Z O r\brr t1 COMMISSION USE ONLY Conditions of approval: y Commission so that a representative may witness Sundry Number: 511 • SS Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test u Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 111 No Subsequent Form Required: R ED'�'"S :- APPROVED BY Approved by: da2Cf----------.'' COMMISSIONER THE COMMISSION Date: it t 1-4. //-.?7- ORIGINAL .�'"G , i,e,/,,,�1 -7 Submit Form and Form 10-403 Revised 4/2017 Approved application isrvali or 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU J-18 Hileoru Alaska,LL Date: 11/13/2017 Well Name: MPU J-18 API Number: 50-029-22834-00 Current Status: SI Water Injector Pad: Milne Point J-Pad Estimated Start Date: December 8th, 2017 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-220 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 dumber: 'Fri ` s = n'., Job' ype: - Tubing Patch , Current Bottom Hole Pressure: 1,983 psi @ 4,000' TVD (Last BHP measured 1/21/2014) Maximum Expected BHP: 1,983 psi @ 4,000' TVD (No new perfs being added, EMW= 9.53 ppg) MPSP: 1,583 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU J-18 was drilled in 1997 using Nabors 22E and completed as a producer in the Kuparuk. Nabors 5S ran the initial ESP in May 1998. Nabors 4ES ran a new ESP in February 2000 and in May 2001. The well was plugged back and converted to an injector in the Schrader Bluff NB/OA/OB sands in August 2005 using Nabors 4ES. The well has been determined to have a tubing leak at 7,359' MD (GLM Station .) after performing a leak-detect log. #= Notes Regarding Wellbore Condition • Max deviation is 75.0°at 3,697' MD. • Deviation at the NB interval is 68.0°. • Deviation at the OA interval is 65.0°. • Deviation at the OB interval is 64.0°. • Casing last tested to 2,000 psi for 30 min down to 7,330' on 8/15/2016. • All Stations dummied off as of 8/29/17. • Min ID is 2.813"thru X-profile at 7,307' MD. • Leak-detect log found tubing leak at 7,359' MD (GLM Station#6). • Last Fill Depth: 7,915' CTM tagged on 10/19/2017. • Schmoo encountered at 7,626' SLM on 11/02/2017. • Lost fish (1-1/2" DGLV w/ RK latch). • Lost fish (Toolstring to pull a SPMG; approx.40.12' long). Objective: The purpose of this work is to patch the tubing with 1 each wireline set/retrievable patch. Brief Procedure: Wireline Procedure: 1. MIRU Wireline and PCE (Press Control Equip) PT lubricator to 3,000 psi Hi 250 Low. • • Well Prognosis (,� Well: MPU J-18 Mktg")Alaska,LLI1.7.44)' " b,v kti Date:11/13/2017 is 6� 2. RIH w/tubing patch to cover hole at+/-7,359' MD with the following items: a. Paragon II Packer/Anchor Latch/1.42" ID Spacer Pipe/Paragon II Packer(Bottom to Top). 3. RD Wireline and PCE. 4. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic • 0 Milne Point Unit Well: MP 1-18 • SCHEMATIC Last Completed: 8/18/2005 Iiilcarp Alaska,LLC PTD: 197-220 Orig.KBElev.:63.83Orig.GLElev.:35.2' TREE&WELLHEAD '/ RKB—Tbg Hngr:20.15'(Nabors 4ES) Tree 3-1/8"- 5M FMC 11"x 3-1/8"5M FMC Gen 5 w/3.5"TC-II T&B Thread Wellhead FMC Tubing Hanger 3.0"CIW"H"BPV Profile �,. OPEN HOLE/CEMENT DETAIL 20" 250 sx Arctic Set(Approx.)in a 24"Hole ` 1 9-5/8" 1,935 sx PF'E',575 sx'G',in a 12-1/4"Hole 7" 250 sx Class'G'in a 8-1/2" HES Cementer 2 CASING DETAIL @2,220 • Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 92/H-40/N/A19.124" 18.936" Surface 115' 0.3550 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 8,245' 0.0759 7" Production 26/L-80/BTC-MOD 6.276" 6.151" 8,114' 12,425' 0.0383 TUBING DETAIL Two&5/8"x20 3-1/2" Tubing 9.2/L-80/TC-II 2.992" 2.867" Surf 8,041' 0.0087 Marker Jts from 6,313'to6,354'R1(13t, taw. WELL INCLINATION DETAIL KOP @ 400' s `. Max hole angle=75 deg.At 3,697'MD Damaged? , ' , ,4 t S JEWELRY DETAIL 1I v �� 61_444- No Depth Item ti .1 1 2,004' 3.5"HES X-Nipple(2.813"Profile) GLM DETAIL:3.5"x 1.5"Camco w/1.5"RK Latch Broken Latch 2 2,086' Sta#7:Valve-Dummy/Date-8/18/2005[MMG GLM] jw 3 7,307 3.5"HES X-Nipple(2.813"Profile) fi 4 7,330' 9-5/8"x 4.5"Baker Premier Packer r 5 7,359' Sta#6:Valve-Dummy/Date-11/18/2016[MMG-W GLM]Broken Latch y 7 6 7,637' Sta#5:Valve-Dummy/Date-10/02/2014[MMG GLM] 7 7,698' 9-5/8"x 4.5"Baker Premier Packer 8 7,738' Sta#4:Valve-Dummy/Date-10/03/2014[MMG-W GLM] 9 7,851' Sta#3:Valve-Dummy/Date-8/29/2017[MMG GLM] 10 7,913' 9-5/8"x 4.5"Baker S-3 Packer Damaged? 1 I 11 7,939' Sta#2:Valve-Dummy/Date-10/04/2014[MMG-W GLM] r }OA Sands 12 7,999' Sta#1:Valve-Dummy/Date-10/03/2014[MMG GLM] 13 8,029' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go)PXN plug/prong Set 11/17/14 14 8,040' 3.5"WLEG—Bottom @ 8,041' "�" x•10 15 8,109' 9-5/8"EZSV Retainer `Ij 16 11,530' 7"Cement Retainer Y 11 j PERFORATION DETAIL Fish @7,937SLM;, 12 ToolstringLost ' Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT SPF Size Date Status 11/19/16 + 13 .6 NB 7,400' 7,420' 3,904' 3,914' 20 5 4.5" 8/16/2005 Open NLnimum IC,2.750" 1 , OA 7,760' 7,780' 4,045' 4,057' 20 5 4.5" 8/16/2005 Open @8,029' y 14 . OA 7,804' 7,824' 4,067' 4,076' 20 5 4.5" 8/16/2005 Open OB 7,942' 7,952' 4,126' 4,131' 10 5 4.5" 8/16/2005 Open — 15 OB 7,962' 7,972' 4,136' 4,139' 10 5 4.5" 8/16/2005 Open ti:1_ " .; KUP Multiple—Plugged Off Isolated 9-5/8 Jt `, Ref Log:USIT—8/16/2005—Perf Guns 4.5"5 spf 4505 Jet @ 72 Deg 1s GENERAL WELL INFO r', t . Kuparuk API:50-029-22834-00 Drilled&Cased by Nabors 22E—12/22/1997 " Converted to Injector by Nabors 4ES—8/18/2005 TD=12,457'(MD)/TD=7,423'(TVD) PBTD=8,109'(MD)/PBTD=4,200'(WD) Revised By:STP 8/29/2017 0 * Milne Point Unit Well: MPJ-18 , 14PROPOSED Last Completed: 8/18/2005 flacon)Alaska,LLC PTD: 197 220 Orig.KB Elev.:63.83'/Orig.GL Elev.:35.2' TREE&WELLHEAD RKB—Tbg Hngr:20.15'(Nabors 4ES) Tree 3-1/8"- 5M FMC l' 11"x3-1/8"5M FMCGen5w/3.5"TC IIT&B Thread id Wellhead FMC Tubing Hanger 30"CIW"H"BPV Profile 20.. OPEN HOLE/CEMENT DETAIL r1 20" 250 sx Arctic Set(Approx.)in a 24"Hole 1 9-5/8" 1,935 sx PF'E',575 sx'G',in a 12-1/4"Hole 7" 250 sx Class'G'in a 8-1/2" HESCemente 2 CASING DETAIL @2,220 ►O Size Type Wt/Grade/Conn ID Drift Top Btm BPF 20" Conductor 92/H-40/N/A 19.124" 18.936" Surface 115' 0.3550 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 8,245' 0.0759 7" Production 26/L-80/BTC-MOD 6.276" 6.151" 8,114' 12,425' 0.0383 p TUBING DETAIL Two 9-5/8"x 20' 3-1/2" Tubing 9.2/L-80/TC-II 2.992" 2.867" Surf 8,041' 0.0087 Marker Jls from 6,313'to6,354'RI13.0WELL INCLINATION DETAIL 3 KOP @ 400' Max hole angle=75 deg.At 3,697'MD Damaged? ., 4 JEWELRY DETAIL Tubing Patch '' No Depth Item +7'350' -- i• 11 5 1 2,004' 3.5"HES X-Nipple(2.813"Profile) E GLM DETAIL:3.5"x 1.5"Camco w/1.5"RK Latch Broken Latch- 2 2,086' Sta#7:Valve-Dummy/Date-8/18/2005[MMG GLM] 6 }NB Sands 3 7,307' 3.5"HES X-Nipple(2.813"Profile) 4 7,330' 9-5/8"x 4.5"Baker Premier Packer 5 7,359' Sta#6:Valve-Dummy/Date-11/18/2016[MMG-W GLM]Broken Latch - Ax. "' ...7 6 7,637 Sta#5:Valve-Dummy/Date-10/02/2014[MMG GLM] 7 7,698' 9-5/8"x 4.5"Baker Premier Packer 8 7,738' Sta#4:Valve-Dummy/Date-10/03/2014[MMG-W GLM] is 9 7,851' Sta#3:Valve-Dummy/Date-8/29/2017[MMG GLM] Damaged? " 10 7,913' 9-5/8"x 4.5"Baker S-3 Packer 11 7,939' Sta#2:Valve-Dummy/Date-10/04/2014[MMG-W GLM] • OA Sands 12 7,999' Sta#1:Valve-Dummy/Date-10/03/2014[MMG GLM] x 13 8,029' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go)PXN plug/prong Set 11/17/14 )i ' 14 8,040' 3.5"WLEG—Bottom @ 8,041' 1 .. . 10 15 8,109' 9-5/8"EZSV Retainer 16 11,530' 7"Cement Retainer , 11 /" P, i 06 sans PERFORATION DETAIL Fish @ 7,937 SLM - n 12 ,* ToolstringLost' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status 11/19/16 .' '' �'�." 13 ;s NB 7,400' 7,420' 3,904' 3,914' 20 5 4.5" 8/16/2005 Open Minimum ID=2.750 @8029' 14 OA 7,760' 7,780' 4,045' 4,057' 20 5 4.5" 8/16/2005 Open OA 7,804' 7,824' 4,067' 4,076' 20 5 4.5" 8/16/2005 Open ',. 'a '" OB 7,942' 7,952' 4,126' 4,131' 10 5 4.5" 8/16/2005 Open 15 N... 0B 7,962' 7,972' 4,136' 4,139' 10 5 4.5" 8/16/2005 Open i ii _ii KUP Multiple—Plugged Off Isolated 9-5/8"v,J L� Ref Log:USIT—8/16/2005—Perf Guns 4.5"5 spf 4505 Jet @ 72 Deg '1 i 16 GENERAL WELL INFO «t. Kuparuk API:50-029-22834-00 L. « Drilled&Cased by Nabors 22E—12/22/1997 7" "' Converted to Injector by Nabors 4ES—8/18/2005 TD=12,457'(MD)/TD=7,423'(1VD) PBTD=8,109'(MD)/PBTD=4,200'(TVD) Revised By:STP 11/13/2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. DATE: Thursday,August 25,2016 Jim Regg V ZS ll(o P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-18 FROM: Chuck Scheve MILNE PT UNIT SB J-18 Petroleum Inspector Src: Inspector Reviewed By: a P.I.Supry.J>e>)2-- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB J-18 API Well Number 50-029-22834-00-00 Inspector Name: Chuck Scheve Permit Number: 197-220-0 Inspection Date: 8/15/2016 Insp Num: mitCS160816084947 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-18 ' ,Type Inj ' TVD 3880 Tubing 1093 1115 - 1105 1105 - PTD 1972200 Type Test SPT Test psi 1500 IA 177 1993 - 1935 - 1923 - Interval OTHER P/F P ✓ OA Notes: Monobore well on 2 year test cycleSCANNED. ✓ MAY I. 92017. Thursday,August 25,2016 Page 1 of 1 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. //~",,?-' ..,O ~ ~) File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Odginai- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type -OVERSIZED [] Logs of various kinds n Other Complete COMMENTS: Scanned by: ~evedy Mildred Daretha~~Lowell TO RE-SCAN Date.: ~/'! Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 December 30, 2011 fi DFEB2 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 1 333 West 7 Avenue / Q Anchorage, Alaska 99501 114 3- 1`1 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 • 0 • 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 i-- 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 TE OF ALASKA F (7 IVES ALASKA OIL AND S CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NO '` 7011 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Mira El , ,�R6GHMiCfl Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ TREATMENT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ " 197 -2200 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99519 -6612 f 50- 029 - 22834 -00 -00 8. Property Designation (Lease Number) : r' 9. Well Name and Number: ADLO- 025515 a MPJ -18 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER PLUFF POOL 11. Present Well Condition Summary: Total Depth measured 12457 feet Plugs (measured) 8109,11320 (TOC) feet true vertical 7422.64 feet Junk (measured) None feet Effective Depth measured 12337 feet Packer (measured) 7330 7698 7913 feet true vertical 7313.23 feet (true vertical) 3880 4023 4114 feet 1 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H-40 32 - 112 32 - 112 1490 470 Surface Production 8214' 9 -5/8" 40# L -80 31 - 8245 31 - 4262 5750 3090 Liner 4311' 7 "26# L -80 8114 - 12425 4202 - 7393 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ - - Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -80 30 - 8040 30 - 4170 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker Premier Packer 7330 3880 4 -1/2" Baker Premier Packer 7698 4023 4 -1/2" Baker S-3 Perm Packer 7913 4114 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 477 1,073 Subsequent to operation: 812 1,106 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 . Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ El • WAGE] 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: NA Contact Joe Lastufka Printed Name Joe Lastu a , , Title Petrotechnical Data Technologist Signatu - ng1 Phone 564 -4091 Date 11/15/2011 cli 6), 7 4 Form 10 -404 Revised 10/2131 '7DMS NOV 16 all / `. `( Submit Original Only AO /6/t MPJ -18 . 197 -220 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPJ -18 3/25/98 PER 12,076. 12,096. 7,078.08 7,095.9 MPJ -18 5/28/01 APF 12,015. 12,029. 7,023.9 7,036.31 MPJ -18 5/28/01 APF 12,036. 12,046. 7,042.52 7,051.4 MPJ -18 5/28/01 APF 12,110. 12,130. 7,108.39 7,126.27 MPJ -18 8/15/05 SQZ 12,015. 12,130. 7,023.9 7,126.27 MPJ -18 8/16/05 APF 7,984. 7,994. 4,145.15 4,149.51 MPJ -18 8/16/05 APF 7,964. 7,974. 4,136.44 4,140.79 MPJ -18 8/16/05 APF 7,422. 7,442. 3,912.98 3,920.49 MPJ -18 8/16/05 APF 7,782. 7,802. 4,058.46 4,066.94 MPJ -18 8/16/05 APF 7,826. 7,846. 4,077.14 4,085.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 IIII • • MPJ -18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/14/2011'T/1/0=1100/200/0 Temp =Hot (Brightwater Reservoir Sweep Mod) Start pumping brightwater chemicals down TBG while on water injection @ 500 bwpd. Pumped 0 gal. EC9660A ( Surfactant) Average of 0 gph for 24 hrs. Pumped a total of 0 gal. since start of project. Pumped 0 gal. EC9408A ( Polymer) Average of 0 gph for 24 hrs. Pumped a total of 0 gal. since start of project. 10/15/2011 TT /I /0= 1100/200/0 Temp =Hot (Brightwater Reservoir Sweep Mod) 'Pumped 54 gal EC9660A ( Surfactant) Average of 4.6 gph for 24 hrs. Pumped a ;total of 54 gal since start of project. Pumped 170 gal EC9408A ( Polymer) Average of 12.25 gph for 24 hrs. Pumped a total of 170 gal since start of project 10/16/2011 T/I/0= 1000/30/130 Temp =Hot (Brightwater Reservoir Sweep Mod) Continue pumping Brightwater chemicals down TBG while on water injection @ 500 bwpd. Pumped 102 gal EC9660A in 24 hrs ( Surfactant) Average of 4* gph for 24 hrs. 'Pumped a total of 156 gal since start of project Pumped 393 gal EC9408A in 24 hrs ( Polymer) Average of 16* gph for 24 hrs. Pumped a total of 563 gal since start of project * *Safety Drill ** 10/17/2011 T /I /0= 1045/80/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continue pumping Brightwater chemicals down TBG while on water injection @ 500 ` • bwpd. Pumped 101 gal EC9660A ( Surfactant) Average of 3.6 gph for 24 hrs. Pumped 373 gal EC9408A ( Polymer) Average of 15.6 gph for 24 hrs. Pumped a total of 257 gal since start of project EC9660A ( Surfactant ) Pumped a total of 936 gal since start of project EC9408A ( Polymer ) 10/18/2011!T/K0=1045/80/200 Temp=Hot (Brightwater Reservoir Sweep Mod) Continue pumping Brightwater chemicals down TBG while on water injection @ 500 `bvvpd. ! ' | . !Pumped 83 gal EC8O0OA( Surfactant ) Average of 2.7 gph for 24 hrs. Pumped a ;total of 320 gal since start of project :Pumped 369 gal EC9408A( Polymer ) Average of 15.4 gph for 24 hrs. Pumped a total of 1305 gal since start of project 10/19/2011;T/1/0=1059/175/275 Temp=Hot (Brightwater Reservoir Sweep Mod) ! ' Continue pumping Brightwater chemicals down TBG while on water injection @ 500 � . ! � / ;Pumped 13S gal EC800OA( Surfactant ) Average of 4 gph for 24 hrs. Pumped a ;total of 459 gal since start of project 'Pumped 413 gal ECS4O8A( Polymer ) Average of 16 gph for 24 hrs. Pumped a 'total of 1718 ga since start of project ' ( i 10/20/2011il7N0=1060/ 00/380 Temp=Hot Reservoir Sweep Mod) Continue pumping Brightwater chemicals down TBG while on wate @ 500 | bwpd. ,Pumped 102 EC9660A Average Pumped ' ' ( ' gph hrs. ' ! ;total of 561 gal since start of project /Pumped 384 gal EC9408A ( Polymer ) Average of 16 gph for 24 hrs. Pumped a ! • :total of 2102 gal since start of project . ' '_ L '-_ -_-' -_---- __--__-------'---- -''----� ' ----' -' -''-' --- -- Temp=Hot (Brightwater 10/21/2011,T/1/0=1060/180/280 - ~ Sweep Mod) | ;Continue pumping Bhghbwatmr chemicals down TBG while onwater injection @5OO bwpd. � i ! ;Pumped 74 gal ECSG8OA( Surfactant ) Average of 3.1 gph for 24 hrs. Pumped a ;total of 635 gal since start ofnro�ct ' � .Pumped 3G7 gal EC84O8A( Polymer ) Average of 15.3 gph for 24 hrs. Pumped a total of since 1O/2210/22/2011,T/I/0=1065/220/320 Temp=Hot U]r�hbwotmrRaaanxoir Sweep Mod) � { / :ConUnuopumping chemicals down TBG while on water injection @ 500 :bwpd. Pumped 1O2 gal EC8OOOA( Surfactant ) Average of4.25gphfor 24 hrs. Pumped a total of 737 gal since start of project ;Pumped 4O4 gal EC84O8A( Polymer ) Average of 16.8 gph for 24 hrs. Pumped a total of 2873 gal since start of project ' ! . - • • 10/23/2011' T/I/0= 1093/300/400 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Continue pumping Brightwater chemicals down TBG while on water injection @ 500 bwpd. 'Pumped 40 gal EC9660A ( Surfactant) Average of 4.8 gph for 8.3 hrs. Pumped a 'total of 777 gal since start of project Pumped 130 gal EC9408A ( Polymer) Average of 17.33 gph for 7.5 hrs. Pumped a total of 3003 gal since start of project FLUIDS PUMPED GALS 777 EC9660A (SURFACTANT) 3003 EC9408A (POLYMER) 3780 TOTAL a 111 Tree: 2- 9/16" - 5M M PJ - 1 8 Orig. DF Elev. = 63.83' (N 22E) Wellhead: 11" 5M FMC Gen 5A Orig. GL Elev. = 28.73' Tbg. Hgr: 7- 1/16" x 11" FMC w/ 3" L DF to 7" Csg Hgr = 30.13' (N 22E) Acme Top 2 -7/8" EUE Btm. and 2.5" CIW H BPV profile 20" 91.1 ppf, H ( 115' I 3.5" HES X- Nipple (2.813" pkg.) 1 2004' Note: 7" emergency equipment 3.5" x 1.5" Camco MMG GLM 1 2086' I installed when casing replaced on 03/22/98. KOP @ 400' 3.5" HES X Nipple (2.813" pkg.)I 7307' Max. hole angle = 70 to 75 deg. f/ 3500 to 7200' - - - - -- - - 9 5/8" x 4.5" Baker Premier I 7330' I Hole angle thru' perfs = 25 deg. 3.5 Packer " x 1.5" Camco MMG -W GLM ll 7359' ill 3.5" x 1.5" Camco MMG GLM I 7637' I 9 5/8" 40 ppf, L -80 BTC. surface Csg (cap. = 0.0758 bpf, drift ID = 8.599 ") — 9 5/8" x 4.5" Baker Premier I 7698' I (cap. with 3 1/2" tbg inside 0.0613) ,' . Packer 3 1/2" 9.2 ppf, L - 80, TC - Tbg 3.5" x 1.5" Camco MMG - W GLM I 7738' I ( drift ID = 2.845 ", cap. = 0.0087 bpf ) 3.5" x 1.5" Camco MMG GLM I 7851' I Perforation Summary Ref log: Sperry Sun MWD 12/08/97 9 5/8" x 4.5" Baker S -3 Packer 1 7913' Size SPF Interval (TVD) NB Interval 3.5" x 1.5" Camco MMG -W GLM I 7939' 4.5" 5 7,400' - 7,420' 3,904' - 3,914' OA Interval 3.5" x 1.5" Camco MMG GLM I 7999' 4.5" 5 7,760' - 7,780' 4,045' - 4,057' 4.5" 5 7,804' - 7,824' 4,067' - 4,076' 3.5" HES XN- Nipple (2.813" pkg.f 8029' 2.750" No -Go ID OB Interval 3.5" WLEG I 8040' 4.5" 5 7,942' - 7,952' 4,126' - 4,131' 4.5" 5 7,962' - 7,972' 4,136' - 4,139' - .x 9 5/8" EZSV I 8109' Top of 7" Casing I 8114' Valves in SPM: 9 5/8" Casing Shoe I 8245' Arrangement as of 04 -28 -11 Top of cement I 11320' Perforation Summary - ' 7 1 $ "' Ref log_ 03/25/98AWS OR / CCL 7" Cement Retainer I 11530' I • Si. - SP Interval (TVD 7" 26 ppf, L -80, Mod. BTC prod. casing K u 3 3/8 - *" 6 12,01 R (7024' - 7036') 7` landing collar (PBTD) 12337' 3 3/8 " ^' 6 1 • 6•-12046' •42' - 7051') 9 4.5"" 12,076' - 12096' (70 - 7072') 12339' 3 . ' 6 12,110' - 12130' (7108' - .') 7" float collar Perfs squeezed during RWO 8/18/05 7" float shoe 12425' DATE REV. BY COMMENTS MILNE POINT UNIT 12/22/97 MDO Drilled and Cased by Nabors 22E WELL MPJ - 08/18/05 MDO 4 -ES Converted to Injector API NO: 50 - 029 - 22834 BP EXPLORATION (AK) ~ • STATE OF ALASKA ALASKQ OIL AND GAS CONSERVATION COMMISSION Mechanical Inl~egrity Test Email to:jim.regg~alaska.gov; tom.maur~er~alaska.gov;bob.flecke-rstein~ai~kaegov;d~.aogcc.prudhoe.bay~a4aska.gov OPERATOR: FIELD / UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Ex~aratior~ (ARaska), I~c. Miline Poi~t l 14iPU ~ J Pad 10105~09 Anna [3u~~9 9v~on Jeff Jones Packer Fre~~t Init~al 15 Min. 3Q Min. Well MPJ-18 T In. W TVD 3,~" T` 1„2(~k ' 1,20f2 1,20U 1,200 Interval 4 P.T.D. 1972200 T test R Test ' 15EH? C" d Z,Q2~ 1,98Q 1,96d P/F P Notes: MIT-tA For 4 year reguYatwy~an~ DA Monobore, no OA. Weli T 1n'. ~WD T' Intervai P.T.D. T kest T+est ' P/F Notes: UA Well T In . TVQ T~ Irrterval P.T.D. T test Test ~ Casi P/F Notes: ~~ Well T In _ 'i1~1 T' Irrterval P.T.D. T test Test ' PiF Notes: OA Well T in'. TVQ~ T' Interval P.T.D. T test Test ' P!F Notes: t3A TYPE INJ Codes D = Driliing Waste G=Gas I = Industria! W~slewaYsr N =1Vot injecting W = Water TYPE TEST Codes M = Mnulus 1{Aonitaing P = Sfar~ciard Pre~t~ee TesE R= le-terv~l R. • Tracer Surarey A = 7~n S~rwey D = ' ' 3 7asr ~r~. ,E i!i ~ /(~ f?~ ;` ,~~'~U'1~~`~,~ ia~~~ ~'~" ~~ - rh ! t~?+JJ ~~~~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (descdbe in notes) MIT Report Form BFL 11/27lD7 MIT MPU J-1810-05-09.x1s . STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED NOV 2 1 2005 AIAlkA PiI at a" Cons. CommisSiÐ Anchorage 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ 181 WINJ D WDSPL No. of Completions One Other D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to DriU Number BP Exploration (Alaska) Inc. " 8/18/2005 197-220·· 305-219 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/3/1997 50- 029-22834-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/12/1997 MPJ-18i 2262'FSL, 3312'FEL, SEC. 28, T13N, R10E,UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 1158' FSL, 1472' FEL, SEC. 20. T13N, R1OE, UM 63.83 Milne Point Unit 1 Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 4329' FSL, 2286'FEL, SEC. 20, T13N,R10E,UM 8109 + 4200 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 552009 y- 6014660 Zone- ASP4 12457 + 7423 Ft ADL 025515 -- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 548530 y- 6018812 Zone- ASP4 Total Depth: x- 547685 y- 6021977 Zone- ASP4 NIA MD n___ -- -- .-- __n -- --~-- -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No NI A MSL 1800' (Approx.) 21. Logs Run: MWD, EMSS 122. c..ASING, LINER AND CEMENTING RECORD CASING ~ETTING UEPTH MD ~ETTING UEPTH TVD HOLE AMOUNT SIZE WT.PËR FT. GRADË .... PULLED TOP BOTTOM TOP I BOTTOM SIZE 20" 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arctic Set I (Approx.) 9-5/8" 40# L-80 31' 8245' 31' 4262' 12-1/4" 1935 sx PF 'E', 575 sx Class 'G' 7" 26# L-80 8114' 12425' 4202' 7373' 8-1/2" 250 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TlJBINâRecoRD .... ...... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 SPF 3-1/2",9.2#, TCII \ L-80 8041' 7330',7698',7918' MD TVD MD TVD NB Sands NB Sands 25. ACID,FRActURE,CEMËNT$QUE~E,EtC; 7400' - 7420' 3905' - 3912' OA Sands OA Sands DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7760' - 7780' 4049' - 4058' 7804' - 7824' 4068' - 4076' 11530' Set 7" Cement Retainer squeezed 35 Bbls ' G' OB Sands OB Sands Lay in 8 Bbls 'G' on top of Retainer 7942' - 7952' 4127' - 4131' 7962' - 7972' 4136' - 4140' 8109' Set 9-5/8" Cement Retainer with 12.3 Bbls of 'G' Freeze Protected with 155 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 24, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD .. ." -.--... Flow Tubing Casing Pressure CALCULATED ... Oil -BSl GAs-McF W ATER-Bsl Oil GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief ~escriptio~ of ~ithology, porosity, fractures, apparent dips and presen~~~oLc:!!1..~ or water (attach separate sheet, if necessary). Submit core chips; If none, state "none". ~FGCiiJ~):~::iO¡i ¡ $ iÛ~.ti1: i None RBDMS 8Ft NOV :2:3 2005 r:B--J.&~ ¡~ \ fl, \L \ t, &...> ....::::::.:.1 --, -.. . . A . Form 10-407 Revised 12/2003 U K ILJ 11\1 A~UED ON REVERSE SIDE SCANNED DE C 1 9 2005 ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None'. NAME MD TVD SBF21 7335' 3882' None SBF1-NB 7404' 3906' SBE4-NC 7495' 3941' TSBB-OA 7776' 4056' TSBB-OB 7952' 4131' Top of Kuparuk Top of Kuparuk 'B' Top of Kuparuk 'A' 11845' 6874' 11977' 6990' 12074' 7076' Top of Miluveach 12191' 7181' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date MPJ-18i Well Number 197-220 305-219 Permit NO.1 A roval 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. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 David Reem, 564-5743 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None'. ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: 2-9/16" - 5M Wellhead: 11" 5M FM<A 5a Tbg. Hng: 7-1/16" x 1 ~C wi 3" L Acme Top 2-7/8" EUE Btm. and 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 115' Note: 7" emergency equipment installed when casing replaced on 03/22/98. KOP @ 400' Max. hole angle = 70 to 75 deg. fl 3500 to 7200' Hole angle thru' perfs = 25 deg. 9 5/8" 40 ppf, L-80 BTC. surface Csg (cap. = 0.0758 bpf, drift ID = 8.599") 7" 26 ppf, L-80, Mod. BTC prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf) 31/2" 9.2 ppf, L-80, TC-II Tbg ( drift ID = 2.845", cap. = 0.0087 bpf) Perforation Summary Ref log: Sperry Sun MWD 12/08/97 Size SPF Interval (TVD) NB Interval 4.5" 5 7,400' - 7,420' 3,904' - 3,914' OA Interval 4.5" 5 7,760' - 7,780' 4,045' - 4,057 4.5" 5 7,804' - 7,824' 4,067' - 4,076 OB Interval 4.5" 5 7,942' -7,952' 4,126' -4,131 4.5" 5 7,962' - 7,972' 4,136' - 4,139 MPJ·18 ~lf:~r!Í_ I l DATE 12/22/97 08/18/05 REV. BY MDO MDO COMMENTS Drilled and Cased by Nabors 22E 4-es Converted to Injector Or~g. DWV': 63.8~' (N 22E) Ong. ~v. - 28.73 OF to 7" csg. hng. = 30.13' (N 22E) 3.5" HES X-Nipple (2.813" pkg.) 2004' 3.5" x 1.5" Cameo MMG GlM 2086' 3.5" HES X-Nipple (2.813" pkg.) I 7307' 7" x 3.5" Baker Premier 7330' Packer 3.5" x 1.5" Cameo MMG"W GlM I 7359' 3.5" x 1.5" Cameo MMG GLM 7637' 7" x 3.5" Baker Premier Packer 7698' 3.5" x 1.5" Cameo MMG-W GlM I 7738' 3.5" x 1.5" Cameo MMG GlM 7851' 7" x 3.5" Baker S-3 Packer 7913' 3.5" x 1.5" Cameo MMG-W GlM I 7939' 3.5" x 1.5" Cameo MMG GlM I 7999' 3.5" HES XN-Nipple (2.813" pkg.~ 8029' 2.750" No-Go 10 3.5" WlEG 8040' 9 5/8" EZSV I 8109' I I 8114' I I 8245' I I 11320' I I 11530' I Top of 7" Casing 9 5/8" Casing Shoe Top of cement 7" Cement Retainer 7" landing collar (PBTD) 7" float collar 7" float shoe 12337' 12339' 12425' MILNE POINT UNIT WELL MPJ-18 API NO: 50-029-22834 BP EXPLORATION (AK) e BP EXPLORATION Operations Summary Report Start: 8/9/2005 Rig Release: 8/18/2005 Rig Number: 4ES ! Code I NPT : Phase I Description of Operations ... I Pp . -. PPRREE ._.u RID MO fr;~··~PL-7 & -~ove to J_Pad.--n. I Set mats & Herculite. Spot in Rig, Pipe Shed & Pits over MPJ-18. P PRE Raise & scope up derrick. P DECOMP ACCEPTED RIG @ 1000 hrs. Spot tiger tank & R/U lines to tree. PfU lubricator & pull BPV. UD lubricator. Take on seawater & test lines to 3500 psi, Ok. Hold PJSM & Pre-spud meeting wi all hands. SITP 1020 psi, SICP 1050 psi. Circulate well wi hot seawater, 4 BPM @ 1400 psi. Pumped total of 600 bbls. SI well & monitor pressures. TP built ot 800 psi, Ordered 600 bbls & 11.0 ppg NaBr kill fluid. Wait on fluid & monitor well. Wait on 11.0 ppg kill fluid & monitor well. Excessive waiting for 11.0 ppg kill fluid. Due to Hot Water Plant problems and MI mixing problems. Also Spine Road in terrible shape. First load arrived on location at 05:00 hrs. However, we can not start final "kill" until second truck arrives. DECOMP Take on second load of 11.0 Ib/gal Brine. Displace Well bore with 11.0+ Brine at 4 bpm/1950 psi. Close in Choke and Bullhead 20 bbls from Open GLM pocket at 11,667' down to - bottom perforation. Open choke and circulate out remaining Sea Wter with 11.0+ Brine. Monitor Well dead. Install and test TWC. N/D X-mas tree. N/U BOPE. Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi. HP 4000 psi. BOP test witnessing waived by Jeff Jones wi AOGCC. Test Annular to 3500 psi. DECOMP P/U kelly & pressure test. LP 250 psi, HP 4000 psi. RID test equip. DECOMP Blow down lines. Set back kelly. P/U lubricator & pull TWC. UD lubricator. M/U landing ¡t into hanger. BOLDS. DECOMP Pull hanger to floor, tubing came free @ 90K. UD Landing Jt & hanger. Cut cable & pull over sheave & attach to reel. DECOMP POOH & UD 2 7/8" ESP completion. 180 jts out. DECOMP Finished POOH wtih 2 7/8" ESP completion. Single down a total of 377 Jts of 2 7/8" Tubing, 2 ea GLMs, XN-Nipple, Pup Jts, Tubing Hanger. DECOMP Remove ESP Cable from ESP Assembly and disconnect from Motor. Pull Cable over ESP Sheave. DECOMP Lay down ESP Assembly sections and load out in shipping boxes. DECOMP Clear and Clean rig Floor. DECOMP P/U BHA #1 as follows: 6 1/8" bit, scraper & X-over. (6.11') P/U 3 1/2" DP & RIH. Ran 383 jts. DECOMP Tag up on fill @ 12115'. Wash to 12135'. (5' below bottom perf) DECOMP Close annular & reverse circulate 400 bbls. Pumped 3 BPM @ 650 psi. lost 64 bbls. Had small amount of frac sand inreturns@ bottms up, then well cleaned up. Lost 64 bbls. DECOMP Monitor well. Well flowing up DP & annulus. Approx 4 BPH. Pump long way 1 DP Volume & monitor well. DP not flowing, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPJ-18 MPJ-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To . Hours; Task -----. ....-... 8/9/2005 ------. ..------ 00:00 - 08:00 08:00 - 09:00 8.00 MOB 1.00 RIGU 09:00 - 10:00 10:00 - 13:30 1.00 RIGU 3.50 RIGU 13:30 - 17:00 3.50 KILL P DECOMP 17:00 - 00:00 7.00 KILL !p DECOMP I 8/10/2005 00:00 - 01 :00 1.00 KILL P DECOMP 01 :00 - 11 :00 10.00 KILL N WAIT DECOMP 11 :00 - 13:00 2.00 KILL P I I 13:00 - 13:30 0.50 KILL P 13:30 - 14:30 1.00 WHSUR P 14:30 - 15:30 1.00 WHSUR P 15:30 - 17:00 1.50 BOPSUF P 17:00 - 20:30 3.50 BOPSUF P 20:30 - 22:00 1.50 BOPSUF P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 PULL P 8/11/2005 00:00 - 06:00 6.00 PULL P 06:00 - 12:00 6.00 PULL P 12:00 - 12:30 0.50 PULL P 12:30 - 14:30 2.00 PULL P 14:30 - 15:30 1.00 PULL P 15:30 - 00:00 8.50 CLEAN P 8/12/2005 00:00 - 00:30 0.50 CLEAN P 00:30 - 03:00 2.50 CLEAN P 03:00 - 05:00 2.00 CLEAN P I DECOMP DECOMP DECOMP DECaMP DECOMP Page 1 of 5 Spud Date: 12/2/1997 End: 8/18/2005 _n.__. ,... Printed; 8/22/2005 11; 19;54 AM e Page 2 of 5 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPJ-18 MPJ-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Code 8/12/2005 03:00 - 05:00 2.00 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:30 2.50 CLEAN P 08:30 - 09:00 0.50 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 - 15:00 5.00 PXA P 15:00 - 16:00 1.00 PXA P 16:00 - 16:30 0.50 PXA P 16:30 - 17:30 1.00 PXA P 17:30 - 18:00 0.50 PXA P 18:00 - 19:00 1.00 PXA P 19:00 - 19:30 0.50 PXA P 19:30 - 20:30 1.00 PXA P 20:30 - 23:30 3.00 PXA P 23:30 - 00:00 0.50 PXA P 8/13/2005 00:00 - 02:00 2.00 WHSUR P 02:00 - 03:00 1.00 WHSUR P 03:00 - 04:00 1.00 WHSUR P 04:00 - 08:00 4.00 WHSUR P 08:00 - 08:30 0.50 WHSUR P 08:30 - 09:00 0.50 WHSUR P 09:00 - 11 :00 2.00 PXA P 11 :00 - 12:00 1.00 PXA P 12:00 - 12:30 0.50 PXA P 12:30 - 15:30 3.00 PXA P 15:30 - 16:00 0.50 PXA P 16:00 - 19:00 3.00 19:00 - 19:30 0.50 PXA P 19:30 - 20:00 0.50 PXA P 20:00 - 22:00 2.00 PXA P 22:00 - 22:30 0.50 PXA P Start: 8/9/2005 Rig Release: 8/18/2005 Rig Number: 4ES liii. I NPT Phase i Spud Date: 12/2/1997 End: 8/18/2005 Description of Operations ._.__~.__... _._____m___. _ ....._._... ____.__ _ ..________ ._. DECOMP I slight flow in annulus. Well breathing. DECOMP I POOH & UD 17 excess jts of DP. Coming dry. Annulus falling. DECOMP Finish POOH standing back 31/2" Drill Pipe in Derrick. DECOMP Lay down BHA #1. DECOMP I Clear and Clean Rig Floor. DECOMP Pick-up Halco 7" EZSV Cement Retainer and RIH. DECOMP Circulate Well at 3.0 bpm/700 psi. Work Pipe. Set Cement Retainer at 11,530'. Unsting from Retainer. Circulate at 3.0 bpm/700 psi. DECOMP Sting back into Retainer and perform injection test at 1.0 bpm/750 psi x 3 minutes. Inject at 3.0 bpm/1750 psi x 5 minutes. DECOMP Hold PJSM. Test lines at 4,000 psi. SWS Pump Cement as follows: 5 bbl Fresh Water Spacer. mix and pump 43 bbls of 15.8 ppg Class "G" Cement followed by 5 bbls Fresh Water. End SWS. Bring Rig pump on line and displace with 11.0 Brine as follows: 35 bbls of cement below Retainer at 3.25 bpm/2200 psi with a final of 1.0 bpm/2900 psi. Un· sting from Retainer. Displace the 8 remaining barrels of Cement left in the Drill Pipe in a balanced plug above the Retainer. Est TOC = 11,322'. DECOMP UD 1 single & pull 5 stands of DP. DECOMP Reverse circulate Drill Pipe clean at 4.0 bpm/1200 psi. Recovered - 2 bbls of cement colored water. DECOMP POOH & stand back 5 stands. DECOMP Cut & slip 84' of drilling line. DECOMP POOH & stand back 31/2" DP to 2500'. DECOMP P/U Storm Packer, RIH & set @ 32'. Test to 1000 psi, OK. UD running jt. DECOMP Prep for Wellhead work. Drain stack. N/D BOP Stack. DECOMP Bleed pack off. N/D & remove Gen 5a Tubing Spool. Pull pack off. DECOMP Weld slip segments to 7" casing. Re-install pack off. DECOMP N/U new Gen 5 Tubing Spool, adapter flange & BOPE. DECOMP Body test BOP Stack and Gen 5 Tubing Spool at 3,500 psi/10 min. Good. DECOMP Release, pull, and lay down Halco RTTS Storm Packer. DECOMP Continue POOH and single down remaining 3 1/2" Drill Pipe. DECOMP Clear and clean Rig Floor. DECOMP Make-up BHA #2 as follows: Multi-String Cutter with 8 3/81230" max sweep blades, 6 1/8" Stablizer. DECOMP TIH with BHA #2 and 3 1/2" Drill Pipe (255 jts). DECOMP Pick-up Kelly. Locate Casing Collar at -8,103'. Drop down to 8,114'. Begin cut at 16:02 hrs with 80 rpm, 180 amps, 3 bpm/725 psi. Cut complete at -16:40 hrs. Tag top of Casing 1-ft deeper. Pump down the 7" and confirm circulations up the 95/8" Annulus at 3.0 bpm/300 psi. DECOMP Circulate 9 5/8" x 7" annulus clean. Pump 3 BPM @ 300 psi. DECOMP Monitor well. DECOMP Ud 36 jts of excess 3 1/2" DP. DECOMP POOH & stand back 73 stands of 31/2" DP.UD cutter & stabilizers. I DECOMP Clear & clean rig floor. Printed: 8/22/2005 11:19:54 AM ~ ~ Page 3 of 5 BP EXPLORATION Operations Summary Report Legal Well Name: MPJ-18 Common Well Name: MPJ-18 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES I ,I! i ~:::---~:O~~O:: . Ho~r:o!·~:~~·~·r!~odl Nf'T :.::: 8/14/2005 00:00 - 00:30 0.50 PXA P I DECOMP I 00:30 - 01 :30 1.00 PXA P I DECOMP I I i I 01 :30 - 02:00 02:00 - 12:00 12:00 - 13:30 13:30 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 20:30 20:30 - 22:00 8/15/2005 22:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 15:00 15:00 - 15:30 0.50 PXA P 10.00 PXA P 1.50 PXA P i I i 1.50 PXA P I i i I 1.00 PXA P I I 1.00 PXA P I i I 3.50 PXA P ! I 1.50 PXA t ! ¡ I I I 2.00 PXA P I 0.50 PXA P 1.00 PXA P i I i 2.50 PXA P I I 2.00 PXA P I I 0.50 PXA P 4.00 PXA P 1.00 PXA P 0.50 PXA P 3.00 PXA P 0.50 PXA P 15:30 - 16:00 0.50 PXA P 16:00 - 16:30 0.50 PXA P 16:30 - 18:00 1.50 PXA P Set test plug. Change out pipe rams for 7" casing. Test 7" pipe rams. LP 250 psi, HP 3500 psi. Pull & UD test plug. R/U 7" handling tools. M/U spear Assy as follows: Bull Nose, Pack Off, 2X Spear, Ext. Stop Sub, X-over. TL = 18.15'. DECOMP Engauge spear in 7". BOLDS. P/U & pull?" casing to rig floor. Pulled free @ 240K, then con't out @ 160K. DECOMP Pull out of hole and single down 7" 261b/ft L-80 Mod BTC Casing. Total Jts = 202 plus a 12.20' Stub. DECOMP Pick-up Joint with spear. Release Spear. Break-out XOs. Lay down same. DECOMP Install test plug. Change out rams to 2 7/8" x 5" variables. Pressure test same, 2501 4000 psi. Pull test plug. I DECOMP Install Wear Bushing. R/U DP handling tools. DECOMP M/U BHA as follows: Bit, Scraper, 2' Junk Baskets, Bit Sub, X-Over. TL = 14.82'. DECOMP RIH wI Bit & scraper on 3 1/2" DP to 8114'. DECOMP I Close in annular & reverse 2 bottoms up. 3 BPM @ 550 psi. . ' Losses were approx .5 BPM. SID & monitor well. Well U-tubing. Reversed out oil, sand & black heavies. POOH & stand back DP. Finish POOH wI Bit & Scraper. UD Bit & Scraper. Clear & clean rig floor. Clean out junk baskets, Recovered, scale, dope, & sand. DECOMP P/U 95/8" RTTS & RIH on 3 1/2" DP. DECOMP Set RTTS Packer at 7,365'. Test lines. Test 9 5/8" Casing from Packer back to surface at 4,000 psi/30 min. Good. Recorded test on chart. Perform injection test down Drill Pipe at 1 bpml750, 2 bpm/950 psi. Note: injecting by 9-518" Shoe. Release Packer. POOH with 3 1/2" Drill Pipe and RTTS Packer. Lay down Packer. Clear and clean Rig Floor. Bring Cement Retainer to Floor. Make-up Halco 9 5/8" EZSV Cement Retainer. TIH with Retainer and 3 1/2" Drill Pipe. 255 Jts + 20' of Jt 256. Circulate at 2.0 bpm/300 psi. Set Cement Retainer at 8,109' dd. = 8,089' KB depth. (Planned Completion WLEG depth = 8,040' KB). Pick-up and shear Tension Sleeve. DECOMP Sting back into Cement Retainer and perform injection rate at 1.0 bpm/725 psi. Sting back out. Close Bag. Line up manifold to Choke. DECOMP PJSM with All. SWS test lines to 3,500 psi. DECOMP SWS pump 5 bbls Fresh Water, 12.3 bbls of Class G Cement at 15.8 Iblgal. Maintian back pressure with Choke at -1,100 psi. Displace with with a total of 53.3 bbls of Fresh Water as follows: Continue to maintian back pressure at -1,100 psi 37.0 bbls displacement total have lead Fresh Water to Retainer. Shut down SWS. Close Choke, Sting into Retainer. Open Choke and bleed Annulus to "0". Open Bag. Bring SWS back on 1.0 bpm. Displacement total 41.4 bbls have Cement at Retainer. Displacement total 53.3 bbls end Cement with a total of 12.3 bbl pumped below Retainer. SD SWS. Un-Sting from DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Start: 8/9/2005 Rig Release: 8/18/2005 Rig Number: 4ES Spud Date: 12/2/1997 End: 8/18/2005 Description of Operations .-----.- .......-.- Printed: 8/22/2005 11: 19:54 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: From - To .--.---. 8/15/2005 16:30 - 18:00 18:00 - 19:00 19:00 - 23:00 8/16/2005 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 09:30 09:30 - 13:00 13:00 - 16:30 16:30 - 20:30 BP EXPLORATION Operations Summary Report Page 4 of 5 MPJ-18 MPJ-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours! Task ,Code I NPT 1----·-- . 1.50 I PXA I P I 1.00, PXA 4.00 PXA Start: 8/9/2005 Rig Release: 8/18/2005 Rig Number: 4ES Spud Date: 12/2/1997 End: 8/18/2005 P P i Phase ì , . _ ...._-1._. __._______ . .. __ ... .__. _____n_. I DECOMP I Retainer and pick-up 5-ft. Reverse circulate Drill Pipe clean x 2 with Rig I Pump. -3 bbls of gray water returns in first bottom up. DECOMP I Clean pits. Mix Hi-Vis sweep. Clean out manifold valves_ DECOMP I Pump 20 bbl Hi-Vis sweep & displace hole hole to clean 8.4 I ppg KCI. Pumped 4 BPM @ 1000 psi. pumped total of 635 bbls. POOH wi 3 1/2" DP. POOH, stand back 3 1/2" DP & UD stingerlsetting tool. Clear & clean rig floor. R/U logger's equip. P/U & M/U logging tools. Calibrate & test same. RIH wi US IT & log cement. N/D bell nipple. N/U shooting flange. R/U lubricator. Change out firing head on E-line. M/U & arm guns for Run #1. RIH & correlate depths. Perforate as follows: 7962-7962' & 7942-7952'. Total of 102 holes in 2-10' intervals., 41/2" csg gun wi 5 JSPF_ POOH & UD guns. All shots fired. M/U & arm guns for Run #2. RIH & correlate depth. Perforate 7804-7824'. Total of 101 holes in 20" interval. 4 1/2" csg gun wi 5 JSPF. POOH & UD guns. All Shots fired. OTHCMP Re-head E-line. M/U & arm guns for Run #3. RIH & correlate depth. Perforate 7760-7780'. Total of 101 holes in 20' interval. 4 1/2" csg gun wi 5 JSPF. POOH & UD guns. All Shots fired. Description of Operations Ip I 1.50 PXA IP 0.50 PERFO~ P 1.00 PERFO P 3.00 PERFO P 3.50 i PERF09 P 3.50 I PERFO~ P I I 3.501 PERF09 P I I 4.00 I PERFOJ P 1.00 PXA I DECOMP II DECOMP OTHCMP I' OTHCMP OTHCMP OTHCMP 10THCMP , 10THCMP 20:30 - 22:00 OTHCMP M/U & arm guns for Run #4. RIH & correlate depth. Perforate 7400'-7420'. Total of 101 shots in 20' interval. 41/2" csg gun w/5 JSPF. POOH & UD guns. All shots fired. 22:00 - 00:00 2.00 OTHCMP RDMO SWS E-line equipment. N/D shooting flange and N/U flow nipple. 8/17/2005 00:00 - 00:30 0.50 RUNCMP Load, tally & M/U bit & scraper assy. 8 1/2" bit, 2 . Boot Baskets, 95/8" scraper, X-over. 00:30 - 03:00 2.50 RUNCMP RIH wi Bit & scraper to 8109' & scrape casing. 03:00 - 05:00 2.00 RUNCMP Close in annular & reverse circulate hole clean. 4 BPM @ 700 psi. reversed 3 Bottoms up & cleaned hole. 05:00 - 06:00 1.00 RUNCO RUNCMP POOH & UD 3 1/2" DP. 06:00 - 06:30 0.50 RUNCO RUNCMP Service rig. 06:30 - 11 :00 4.50 RUNCO RUNCMP Con't to POOH & UD 31/2" DP. 11 :00 - 12:00 1.00 RUNCO RUNCMP UD Bit & scraper assy. Pull wear bushing. Clear & clean rig floor. 12:00 - 02:00 14.00 RUNCO RUNCMP P/U & R/U tubing tools to run 3 1/2" TCII tubing. R/U Torque Turn equip_ Hold PJSM & review completion running procedure. 02:00 - 04:00 RUNCMP P/U & M/U Tail Pipe Assy. RIH wi Packers, GLMs & Nipple assys. Baker lok all connections below S-3 Packer. Torq turn all connection 04:00 - 00:00 20.00 RUNCMP RIH wi 31/2" 9.2#, L-80, TCII completion. Torque Turn all connections. 8/18/2005 00:00 - 01 :00 1.00 RUNCO RUNCMP Continue RIH wi 3 1/2" 9.2#, L-80, TCII completion. Torque Turn all connections. 01 :00 - 02:00 1.00 RUNCO RUNCMP P/U hanger and landing joint. Clear and clean rig floor 01 :30 - 06:30 5.00 RUNCO RUNCMP Reverse circulate 150 bbls. hot 3% KCL water @ 3 bpm @ 300 psi. Switch to 600 bbls. hot 3% KCL water containing 110 Printed: 8/22/2005 11: 19:54 AM MPJ-18 MPJ-18 WORKOVER Start: 8/9/2005 NABORS ALASKA DRILLING I Rig Release: 8/18/2005 NABORS 4ES Rig Number: 4ES I . I I : ~T~'Hour~__ Task.l cOd~j NP~_' . Phase 01 :30 - 06:30 5.00 I RUNCO RUNCMP 06:30 - 07:00 0.50 RUNCO RUNCMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/18/2005 07:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 14:30 14:30 - 15:30 16:30 - 18:00 e BP EXPLORATION Operations Summary Report Page 5 of 5 Spud Date: 12/2/1997 End: 8/18/2005 Description of Operations .-----.--.. gallons of corrosion inhibitor and reverse circulate fluid to bottom of tubing tail @ 3 bpm @ 300 psi. Land 3 1/2" Completion @ 8041'. P/U Wt = 50K. S/O Wt = 30K. UD landing jt RILDS. Drop ball/rod. RUNCMP Pressure up on tubing to 2500 psi. & set Baker S-3 packer. Hold for 30 min. Pressure up on tubing to 4200 psi & set 2 - Premier Packers. Hold & test tubing for 30 min. Bleed off tubing to 2000 psi & SI. Pressure up on annulus to 4000 psi & hold for 30 min. Bleed off tubing pressure & shear DCR-SV. Equalize & Bleed off pressure. Pump thru DCR-SV both ways, 3 BPM @ 350 psi. equip tested good. Charted entire test R/D testing equip. Set TWC & test to 3500 psi. N/D BOPE. N/U adapter flange & X-mas tree. Test to 5000 psi, Ok. Hold PJSM. Pressure test lines to 3000 psi. Pump 155 bbls of diesel down annulus for freeze protection. 2 BPM @ 500 psi. I RUNCMP Install BPV and test Secure cellar and prep to HDMO to I I MPC-43. Release rig at 18:00 hrs. 0.50 RUNCO 1.00 BOPSU P 2.50 I WHSUR P 1.00 WHSUR P I 1.50 WHSUB P RUNCMP RUNCMP RUNCMP RUNCMP Printed: 8/22/2005 11:19:54 AM MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg )2 tlft/,Ii Il(O.i rb P.I. Supervisor ~ \ '9 DATE: Tuesday, October 11,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I-18 MILNE PT UNIT KR I-18 ...~ {.)11../ \~\ FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv JI3e.. Comm Well Name: MILNE PT UNIT KR J-18 Insp Num: mitJS051007213107 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22834-00-00 Permit Number: 197-220-0 Inspector Name: John Spaulding Inspection Date: 10/7/2005 Well I-18 Type Inj. w P.T. 1972200 TypeTest SPT Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. TVD 3880 IA I 0 2000 1950 1950 Test psi 970 OA P Tubing 820 850 850 850 Interval INITAL PIF Notes Monobore completion!!!! I am under the impression that the AOGCG frowned on these. In the past they did not comply with regs. Do they now or am I missing something. W Q.,\L~ lí5 rteJ-. (t A,'lCf\D k\j"'e L~,~þ ìßh..¿,~ ,-J E E. It I bl 0;- \ ,\I 1 1 ?J)G5 ~CANNEl NO,t/ Tuesday, October 11,2005 Page I of I Re: FW: J-18 USIT Logs ) ) Sühject:Re:FW:.T-18lJS~T]jºgs .. .. . . . ..... . ~tRlJ1:....·.TÞÔt#~~...N1aWd~t...~tp11}~iri.aWd7r(@a<hniµ.·st~~e·.·ak~t1S~.·· ... ~~t~:~?l1; 22Aµg20Q$.Q9;43~?~~H?0Q . ~q;H!:'It~ . ;~Qm; Kristin, \ q 'I. - d d ~O Based on the message trail here, the only thing I can believe still needed is documentation of the pressure test conducted by the rig on the inner annulus when they ran the tubing. Successfully accomplishing that test along with the bond log assessment fulfills the regulatory requirements. Once the well is "in service" and warmed up, a formal MIT with the Inspector present needs to be accomplished. I hope this answers your question, message back if more is needed. Tom Maunder, PE AOGCC Krom, Kristin L wrote, On 8/22/2005 9:37 AM: SCJ:\NNED AUG 2 2 2005 Hi Tom- Now that the rig work is complete, I wanted to check in with you. What other information do you need from me, and În what form (officìal application, emaìl, etc.), in order for the Application for Injection to be approved? I want to make sure that I've got everything in order so when the surface hookups and varÎous downhole work is finished we can put the well on injection. Thanks, Kristi.n 564-5850 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, August 16, 2005 3:27 PM To: Ohms, Danielle H Cc: Steve Davies; Krom, Kristin L; Elmore, Gary 0 (Schlumberger) Subject: Re: FW: J-18 USIT Logs Danielle, et al: Thanks for the information. That you had checked with SOS is important. On that basis, I concur with the assessment of isolation. Good luck with completion. Tom Maunder, PE AOGCC Ohms, Danielle H wrote, On 8/16/2005 2:16 PM: Tom, I had the same question at first, so talked with Gary Elmore at length this morning to get a clearer picture. He pointed out that if that "green section" (micro debondíng) above the NB sand were blue (indicating water) there would be greater concern of a channel. The micro-debonding is a representation produced by the tool processing which indicates that it is not a hard cement (>2.6 lof3 8/22/2005 11 :58 AM Re: FW: J-18 USIT Logs ) ) MRAY) , but not fluid either. While a channel cannot be conclusively ruled out, the opinion from Schlumberger is that it is most likely not conductive up and downhole in this case. This is also based in part by the amplitude echo image, which appears to indicate that there is possibly some cement on the pipe which correlates to the micro debonding. This could be causing the appearance of micro debonding shading in the cement image track. He also pointed out that this well was cemented with an extended slurry cement (not class G), which tool modeling calculations (done prior to this job) suggested a cement threshold of 2.1 - 2.3 MRA Y could be used VS. the 2.6 standard threshold used in processing BP US IT logs when logging class G. Based on this, the image presented by Schlumberger in the previously enclosed log should represent the most pessimistic view. I I I I In consideration of the entire image, this does not appear to be anything movable nor squeezable. Please let me know what you think as soon as possible. The NB perfs will be behind a selective so we should have options if there are any issues. Thanks. Danielie 564-5759 From: Thomas Maunder [mailto:tom.. .maunder@admin.state.ak.us] Sent: Tuesday, August 16, 2005 12:56 PM I To: Ohms, Danielle H Cc: Steve Davies Subject: Re: FW: J-18 USIT Logs Thanks Danielle, I really appreciate getting such logs so soon after running. Steve Davies and I have looked at the cement log and we would concur regarding isolation for the proposed OA and OB perforations. With regard to the NB, there appears to be a persistent channel from below the proposed depths I to well above them. There are sections below and above with average impedance> 4 MRA Y, but the right hand track shows that "green section" throughout. It is absent around the OA and OB. What is BP's assessment regarding that?? Look forward to your reply. Tom Maunder, PE AOGCC Ohms, Danielle H wrote, On 8/16/2005 12:29 PM: Tom, I'm helping to cover for Kristen on J-18 while she's on Jury duty. We got the USIT on J-18 this morning (field copy enclosed). Perfs are planned for later today and then selective completion to finish off this well as a Schrader injector. Perfs are planned for: 7400 -7420' MD (NB Sand) 7760' - 7780' MD, 7804 - 7824' MD (OA) 7942' - 7952' MD and 7962' - 7972' MD (08) We believe we have good cement bond, sufficient to convert to injection (average acoustic impedance of 4 MRA Y or greater above and below all planned perfs). Since you've gotten 20f3 8/22/2005 11 :58 AM Re: FW: J-18 USIT Logs ) familiar with this well already, thought I'd run it by you to get concurrance as we are planning to move ahead with the well plan. Thanks! Danielle (564-5759) From: Chan, Paul (PRA) Sent: Tuesday, August 16, 2005 8:50 AM To: Ohms, Danielle H; Krom, Kristin L; Reem, David C Subject: FW: J-18 USIT Logs Thanks Paul x5254 From: Hinkel, Lee M (Orbis) Sent: Tuesday, August 16, 2005 8:48 AM To: Chan, Paul (PRA) Subject: J-18 USIT Logs «USL Cement_025. PDS» «USI_ Composite_025. PDS» Regards, 3 of3 8/22/2005 11 :58 AM :~~',U ?, I " ,iA\"'~i \. '17 i-F,:;:}J \,,\"'" ! ; ,II \, I I ' ~ '. !, ! i\ " I "0), I!! i , f! ! ¡ I' I, / I ,I I I ~ ~, ¡,J I! ,\ W ~ ._-~ I r' I I !jF l ¡ ) M8/ \11 ;1 ~il\\" \ (ëù ¡ìl¡IIf),','l h/"¡i.~\ I, '! \ " ,I I I '\''0, 'lj\' 'u'\\ I /, \: I I I' " I, iUI '¡- ¡¡,I. \, ì I, /1 I /{¡I UI I L......, :! ~ 'I p~) I 1, I In '~ //J ~ i I U~" . ~l I J U ) AlASKA OIL AlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~o \Q1'ð-- Re: Milne Point MPl-18 Sundry Number: 305-219 SCJ-\NNEf) }~UG 11 2005 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd y following the date of this letter, or the next working day if the 23rd day falls on 01' day or weekend. A person may not appeal a Commission decision to Superio u unless rehearing has been requested. DATED this JL day of August, 2005 Enc!. 1. Type of Request: C(2J to -:11- oS- ) STATE OF ALASKA ,Þd }///ð REC~IV>-~ ALASKA OIL AND GAS CONSERVATION COMMISSION AU - f!D;¡1\ APPLICATION FOR SUNDRY APPROVAL G04 20~ 20 AAC 25.280 Alaska Oil & Gas Gons. CO~m¡$$íOn Anchoranù o Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 1m Other Con.ver!.!~ Injectbr o Alter Casing 0 Repair Well ~Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program }llPUII Tubing ~perforate New Pool 0 Waiver 0 Time Extension 1r~ trJ\ ~( S- 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: III Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 197-220 6. API Number: 50- 029-22834-00-00 99519-6612 63.83 9. Well Name and Number: MPJ·18 8. Property Designation: ADL 025515 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands ,,/ .' ',PRES~NT\lYE(tGQNDFrI0NI;$IWMM~R)'¡:'::I'I'I::,,~::II.¡ ",,:1:1,:11;, . Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12338 7314 N/A MD TVD Burst 11,~ 1 Total Depth MD (ft): 12457 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 7423 Length Size Junk (measured): N/A . Collapse 80' 8214' 20" 9-5/8" 112' 8245' 112' 4262' 1490 5750 470 3090 12395' 7" 12425' 7373' 7240 5410 Perforation Depth MD (ft): 12015' - 12130' Packers and SSSV Type: N/A Perforation Depth TVD (ft): 7024' - 7126' Tubing Size: 2-7/8",6.5# Tubing Grade: L-80 Packers and SSSV MD (ft): N/A Tubing MD (ft): 11879' 12. Attachments: III Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development III Service 16. Verbal Approval: Commission Representative: 17. I hereby certif that the foregoing is true and correct to the best of my knowledge. Printed Na e David Reem Title Drilling Engineer r~~ August8,2005 Date: 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged III WINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Signature Phone 564-5743 Commission Use Only Date Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness 'tfrlug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance Sundry Number: 30Yd.-/1' Other: \f-~ \SO V ~~\- RBDMS BFL AUG 1 5 2005 COMMISSIONER APPROVED BY THE COMMISSION Date 1tt~u~te "- nR\G\NAL ~....,' ') ) MPJ-18 Planned Conversion '\ ~,J,-9 \\ \\ \ \ -c> J-08 \,. \ \~.25mile \ \ \. II \ \ \ 1\\". \ \ \ \ \ \\ "':J-15 II[ 4MPJ-18 \ \ \ ,,{ I \ '\ \\ \ \J, ·..1 "\ \ \ -MPJ-' '\ \ \\ \ \ \ \~ \ \ I ~, ~ ' \ \ ~ ~~ '" \ I ~ ~ ~ ~ \, I ~~ ~ --- -------- ~~(8A ~ \ \ ¡ ____ .~:09~-'-~ '..... ,'," '\ - ,'::¡" J-OBA '\ \ \ \\ l ---. ~"..... '", "\. \ \ I, ----.......-~ .......~-...... ~ "'" ~\.,\ ,,\19 \ \r ________ ~~ \ "" \ ~1-19\ \ \ ---..... -.........~. . '. \ \ \ 1/4 Mile Buffer From Top N sands to Base 0 sands o 800 I I 1 :9,600 ASP Zone 4 NAD 27 Well Status 1600 Feet. Abandoned [;j Gas Injector Injecting [;j Miscible Injector Op.ating o Nllscible Injector Shut-In . Not Vet Completed 1 Td Not Vet Reached. o NuDAlnknown . 011 Produc. . Oil Producer flowing ;jr 011 Producer Gas Uft .. Oil Producer Hydraulic Pump * 011 Producer Shut-In () Oil Produclf SubmersiÞle . 011 SUspended o Oil Wel <> Plugged Bade For Redril [) Suspended [) Water Injector .. NB Markers + oø Markers Townships Section ) ) Project: Convert MPl-18 from a Kuparuk ESP producer to a Schrader Bluff injector 1. MIRU 4ES. Pull BPV, set and test TWC. ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)/4000 psi (high) per BP and AOGCC regulations. 2. Kill Well 3. Pull existing ESP 4. Run 6" bit and 7" scraper to PBTD. 5. Set 7" EZSV cement retainer at -11,500'md. Squeeze -35 bbls cl. G cement below retainer, unsting from retainer and place -200' ft of cement on top of retainer (-8 bbls). 6. Lay in kill weight brine from top of cement to surface. 7. Punch holes in the 7" casing and circulate kill weight brine into 7" x 9-5/8" annulus. 8. Cut & pull 7" casing from -8100'MD 9. Set 9 5/8" CIBP at -8080'md and lay in 8 bbls cl. "G" cement on CIBP. 10. Run USIT log to evaluate cement bond quality over Schrader Bluff intervals * Depending on cement bond quality, may need to perforate, cement squeeze, FCO, and re-perforate. If cement is poor, may stop job and leave well for completion at later date, with possible sidetrack. 12) Perforate Schrader bluff intervals (NB, OA, & OB). 13) Run selective single completion. 14) Install and test to 5000 psi a new 3-1/8" tree 15) RDMO 4ES MPl-18 status: Kuparuk Pressure: 4/19/05 3963 psi @ 6792'TVDss = 0.58 psi/ft (11.1 ppg) Schrader Bluff pressure: (MPI-19 OA & OB producer) 1/26/05 1330 psi @ 3777'TVDss = 0.35 psilft (6.8 ppg) NB perf depths: 7400' - 7420'md I Oa perf depths: 7760' - 7780' md and 7804' - 7824'md I Ob perfs: 7942' - 7952'md and 7962' - 7972'md Tree: 2-9/16"- 5M M PU J 18 Wellhead: 11" 5M FMC. ), 5a - Tbg. Hng: 7-1/16" x 11" FMC w/ 3" U- Acme Top 2-7/8" EUE Btm. and 2.5" CIW H BPV profile Or~g. DFI=)lev.: 63.8~' (N 22E) Ong. ( _ ev. - 28.73 OF to 7" csg. hng. = 30.13' (N 22E) 20" 91.1 ppf, H-40 I 115' I II Note: 7" emergency equipment installed when casing replaced on 03/22/98. KOP @ 400' Max. hole angle = 70 to 75 deg. f/ 3500 to 7200' Hole angle thru' perfs = 25 deg. 95/8" 40 ppf, l-80 Btrc. surface csg. A (cap. = 0.0758 bpf, drift 10 = 8.599") 7" 26 ppf, l-80, Mod. Btrc. prod. casing (drift 10::: 6.151", cap. ::: 0.0383 bpf) 27/8" 6.5 ppf, l-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf ) 7" short joint from 11,820' to 11,861' md. Stimulation Summary 03/26/98 - Kup. 'A' Sand:160.2 M# of proppant behind casing. 20/40 Carbolite was tailed in w/ 54.4 M# of Proplok resin coated 16/20 Carbobite (resin was dyed blue). Perforation Summary Ref log: 03/25/98AWS GR / CCl Size SPF Interval (TVD) Kup. 'B' Sand Kup. 'A' Sand 33/8"·* 6 12,015'-12029' (7024' - 7036') 33/8"** 6 12,036'-12046' (7042'-7051') - 4.5"* 6 12,076'-12096' (7054' - 7072') 33/8"** 6 12,110'-12130' (7108'-7126') .. Atlas Jumbo Jet ('big hole') charges ""Perfed on 5/28/01, 60 deg phasing J Camco 2 7/8" x 1" sidepocket KBMM GlM o 9 5/8" 'ES' Cementer 12220' md I I 95/8" Casing Shoe 1 8245' md 1 Camco 2 7/8" x 1" sidepocket KBMM GlM Hes XN-Nipple (2.25"id ) Centrilift 159 stg. GC1150 GPMT AR 1:2 I 167' I I 11,667' I I 11,808'\ 11,824' I Tandem Gas Separator GRSTXBAR H6 (TVO 6870') 11,842' I Tandem Seal Section GSB3 DB UT/L T IL H6 PFS Aflas/HSN I 11,84 T I Centrilift 171 hp KMH motor, 2390 volt / 44 amp 11 ,861 ' I Centrilift PHD w/ 6 fin centralizerl 11,878' I 7" landing collar (PBTD) 1 7" float collar ~ 7" float shoe DATE REV. BY COMMENTS 12/22/97 MOO Drilled and Cased by Nabors 22E 04/11/98 MOO Frac & Completion Nabors 5S OS/23/98 M.Linder RWO Nabors 4-ES 02/10/00 GMH RWO Nabors 4-ES 02/19/00 M.Linder RWO Nabors 4-ES 02/10/00 BMH RWO Nabors 4-ES 12,337' 12,339' 12,425' MILNE POINT UNIT WELL J-18 API NO: 50-029-22834 BP EXPLORATION (AK) Tree: 3-1/8" - 5M Wellhead: 11" 5M Fr Tbg. Hng: MPJ-18 )en 5a Proposed Orig. OF Elev. ::: 63.83' (N 22E) Or; \l Elev. = 28.73' ".n ' DF tv fIr csg. hng. '= 30.13' (N 22E) 20" 91.1 ppf, H~40 1 115'· Note: 7" emergency equipment Installed when casing replaced on 03/22/98. KOP @ 400' Max. hole angle::: 70 to 75 deg. fl 3500 to 7200' Hole angle thru' perfs:: 25 deg. 9 5/8" 40 ppf, l-80 Btrc. surface csg. (cap. ::: 0.0758 bpf, drift ID ::: 8.599") p,{"~?"J$pC\ Dp,(.,f'I,;::- \ loaJ \..) 3 1/2" 9.3 ppf, L-80, TCII tbg.. ( drift 10 = 2.867", cap. = 0.0087 bpf) ....-....~-..~~,............._.......... I ~~... l{~ eX) --1,'''\ì}J I t'-'\ 1) r~ '- ---)""7 (p'C}-', ';:rl ~ ' )'" {V\ l) "7('¿ 0 L( ..,:'Ft?,) "f " IV\ r\ ! ,J """ .' ),) (y> -- -)~:" ( :,,¡ .'. 't., ''':-Y:r:::~'' ~,' f'J\}) "') 1.:\ i.á"L:, <"¡ ·~';'·i, _I 9 5/8" Casing Shoe 18245' md I 7" 26 þpf, L-80, Mod. Btrc. prod. casing ( drift 10 = 6.151", cap. = 0.0383 bpf ) Perforation Summary Ref loq: 03125198AWS GR I eCL Size SPF Interval (lVD) Kup. 'B' Sand Kup. 'A' Sand 3316'" 6 12.015'.12029' (7024'·7036') 3316"" 6 12,036'-12046' (7042'-7051') 4.5ft. 6 12.076'-12096' (7054' - 7072') 3318"" 6 12,110'·12130' (7108'-7126') * Atlas Jumbo Je't ('big 'hole') charges *:,P~rfed()n 5/?8/0.1. ,60,ºègphasing DATE REV. BY 12/22/97 MDO 04/11/98 MDO OS/23/98 M.Linder HES X-Nipple (2.813") Camco 3 1/2" x 1 1/2" ~idepocket MMG SPM 9 5/8" 'ES' Cementer HES X-Nipple (2.813") 95/8" X41/2" HES..!PHI:-' Pkr . 3 1/2' X 1 1/2" MMG SPM -w 31/2' X 11/2" MMG SPM 1-2000' I -210?;] 12220' md I J XXXX' I ~, ''',].1:~ ?(;' I )\!¡ 't I.xxxx' I .'- /) 1> ~S 0 l Å'\ ìJ l xxxX' I. .." ~~g Õ l \ ]V}, I~XX'I .....:J.1....,¡ ¿ , ,,", I "iU '1IV\ 0. 9 5/8" X11/2ft'HE5-!PH~' Pkr r XXXX' 11 s DO ~ lJ 3112' X 1112" ~~ SPM I~' ] 7'60 I) J.-\Jj 31/2' X 1 1/2" MMG SPM 1>o<x~·..I 7-ß ç () N\!\ JJ 95/8" Xt1/2"·HE-S-'.f2Ft1d Pkr I XXXX' I --:Vl CO (j'\/\ c\ 31/2' X 11/2" MMG SPM I XXXX' 1 ...1(.\<-·~\..) //\1\\'\ -vV U 31/2' X 11/2" MMG SPM r~>?<'1 ,t,C/.)b }./\ 'r) HES XN-Nipple 2.75" Min. id XXXX·. ." ~;':~H () 3 1/2" WlEG xxxx' ··'ß,oI..\O XXXX' I )\J¡ 'D '¡V\D ~u....c.\':"" . . ._.._~.-..--.......- ~ :" ,,", .' " ., '<·.t:>: ~< .:::-: (.~>:, ".~:'.. . l~" .",. ".....: ';'. ~ .' ;', ,Kill,."" ; : Weighf;':')" " :-;:; '::~I:~I~:;', .: '..... ,.' ";' :";':~' .:.:' ~' ~: .:'- ~ ' ' , '".. ~-- --..~' :~. xx ~ t~'.(~y.;· ~'"~;':''' -J r - ~.~!! . ~ ~. .,' SJ. . , 7"EZSV r landing collar (PBTD) 7" float collar , ~7" float shoe .. COMMENTS MILNE POINT UNIT WELL J-18 API NO: 50-029-22834 Drilled and Cased by Nabors 22E Frac & Completion Nabors 5S RWO Nabors 4-ES 02/10100 GMH 02/19/00 ,M.Linder 02/10/00 BMH RWO Nabors 4-ES RWO Nabors 4-ES RWO Nabors 4-ES BP EXPLORATION (AK) _x~~ ).' ... ... . I XXXX' I 12,337' 12.339' 12;425'. :,', \, J \ ( , . (' I' ' ~,-\"b ~ " - -', \ \ \ J' " \ d ~ '-l V\I\. \ V T~~ o...~ t'O ~<ð"\Q.\~~'cço..~ ~ h t/\ \ /" ~\\C£: o~ ~ \S .~\' \ "'- \-\~~-\~. ~~ ~()Q \~~~~C? \~~~,~~Ð~ - 6QJo - 5500 MPU f-11 ~~ - :"000 - 6500 MPU f-08 -- _ (i!:ß -ssoo MPU 1-0lA: . -4500 - sooo MPU 1-06 - -- ~--- Åt£- ~ ~IG -0 ç- - ~~ MPU 1-~ 1-0SA ~~-~~~- ~ ( ~" CD o ú) o o 0-J I Oì ~ « I ~ - 3000 MPtr 1-01 MPUI-17 8 ~I I ~ I p § ~ ~~ I' Hi I ; ~ ~ U I I \ I I I I I'r I ~ \:XI ~ I ~o- ï 0 u ,--- -"- 0-J OJ n ú) ~ 0 j25cxJ U --.C ---.!. '. ~ I \ ) ) Memorandum State of Alaska Oil and Gas Conservation Commission To: MPU 1-18 File - 197-220 August 11, 2005 Fm: JackHartz §- Subj: MPU 1-18 Recompletion Evaluation MPU J -18 is a Kuparuk Pool producer located on the southern edge of the pool. It has produced approximately 370 MBO since completion in 1998. GOR and water cut were about 1600 cflbbl and 95.5% toward the end February 2004 when it was shut-in. It was POP briefly in October 2004. The last test was 89 BOPD, 10 MSCF/D and 89% water cut. Decline analysis (attached) indicates approximately 28 MBO reserves left in the drainage area, assuming unconstrained production, to a limit of 50 BOPD. BPX provided an estimate of 1100 BO reserves to an unknown limit based on Milne Point Field economics. The effective economic must be greater than 50 BOPD. While the reserve estimates differ, it appears the well has nearly depleted its area and a redrill or sidetrack may be unwarranted. MPU 1-18 is being recompleted as an Schrader Bluff Pool injector. No other obvious alternatives are apparent. Conclusion: MPU 1-18 appears to be depleted. Recommend approval of the MPU 1-18 recompletion as an injector in the Schrader Bluff Pool. jdh 8/11/2005 SCANNeD ;~UG 1 I 200.5 1000 - MILNE POINT, KUPARUK RIVER OIL 500 - 100- :!2 :ë 50- .c 0- e:. Q) ..... ctI c:: ð 10 - 5 - J-18 Working Forecast Parameters Phase : Oil Case Name : MPU J-18STEval b :0.122167 Di : 0.302425 A.e. qi : 77 bbl/d ti : 06/01/2005 te : 08/31/2006 Final Rate : 49.2339 bbl/d Cum. Prod. : 397.182 Mbbl Cum. Date : 10/15/2004 Reserves : 28.2536 Mbbl EUR : 425.436 Mbbl Forecast Ended By : Rate DB Forecast Date : 08/11/2005 '~ . &AA &àA A,éåA AAA åA ~ 1 - , , , , , I' , , , , I' , , , , I ' , , , , I' , , , , I ' , , " "'" I I I , , I I' , , , , I I , , I , I' , I I , I ' , I " '" I I I I , , , , I' , , I , I I , I I , I ' , I , , I ' , , , , 1998 99 2000 01 02 03 04 05 06 DATE MIL \JE POINT, KUPARUK RIVER OIL 1 J-18 1-01L 029228340000: 100 Oil Rate (CD) ( bbl/d ) ...- ~... Water Rate (CD) ( bbl/d ) Water Inj Rate (CD) ( Mbbl/d ) · , Gas Rate (CD) ( MMcf/d ) · · Gas I Oil Ratio ( cf/bbl ) 5 10 :: I I 029228340000: 100 Cum Oil Prod ( MMbbl ) Cum Gas Prod ( MMMcf ) ---/' Cum Water Prod ( MM? ~ / ~ ' 0.5 4 10 ~ · -r14 Wp 103 ~ 0.1 2 10 ~ 0.05 1 10 ~ .- o 10 ~ --.-/ 0.01 10_~~ _~: 10 ~ A 0.005 , -3 10 . ""'I""'I""'I""'I""'I""'I""'I""'""'I"'" ""'1"111 ""'1""'1""'1"'" 0.001 1998 2000 02 04 III IIIIIII1 I III III II II I II II I' I III III IIIII I I I I 1111' III I I I I I III I I I I I I I '1111 II III I I I' I II I 1998 2000 02 04 1.0 5000 . 0.8- 4000 - "~ . . 0.6- 3000 - 0.4- 2000 - 0.2- 1000 "" 'I"'" I" "Ii"'" '" I '1'1 '" I' "" II "" I"" 'I" "" 'I "" i"'" 1"1' 'I" I'" 2000 02 04 0.0 ""'1""'1""'1'"'1'1"'"'1""'1'" I 'I' ""1""'1""'1""'1 I ""1'" I 'I"'" '" "I I"" 1998 2000 02 04 I I I I I I' I I II 1998 RE: Milne Point 1-18 additional sundry information ) ) Subject: RE: Milne Point J-18 additional sundry information From: "Engel, Harry R" <EngeIHR@BP.com> Date: Thu, 11 Aug 2005 08:44:59 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> \C\ 1./ '}~D Tom... The number is correct. It is based upon our economics for Milne Point. Thanks, Harry From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, August 11, 2005 7:01 AM To: Engel, Harry R Subject: Re: Milne Point J-18 additional sundry information Harry, Thanks for the note and information. On item 3, are a few "zeros" missing from the reserves amount?? Tom Maunder Engel, Harry R wrote, On 8/10/2005 5:06 PM: Tom, This is a follow up to our telephone conversation earlier today regarding the subject sundry application. Listed below is the information you have requested. 1. Purpose of planned well operations: Conversion of Kuparuk producer to Schrader Bluff injector 2. Mechanical condition of original wellbore: MP J-18 is a normal well with no identified integrity issues. The well has been shut in for approximately one year due to high water cut and low oil rate. 3. Current performance: Last well test conducted February 17, 2004: 89 bopd, 548 bwpd, 10 MSCFD, Estimated remaining reserves approximately 1100 barrels of oil. 4. Reserves of parent wellbore are not currently planned to be accessed by any new wellbores. Please let me know if you require additional information. Nabors 4 ES is on the well and P&A operations are anticipated to begin late tomorrow. I appreciate your timely response. Regards, Harold R. Engel (Harry) GPB Staff Engineer 907 -564-4194 office 907-564-5510 fax SC,ANNECì 14UG 1 1 2005 1 of 1 8/11/2005 8:50 AM RE: Change to MPl-18 program ,) ) Subject: RE: Change to MPJ-18 program From: "Reem, David C" <ReemDC@BP.com> Date: Tue, 09 Aug 2005 09:01 :44 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Krom, Kristin L" <Kristin.Krom@BP.com> o ~ð- \~.y Tom, that kind of info will have to come from Kristin and not this workover engineer. Also, the MITOA did FAIL so we will be setting a retainer instead of a bridge-plug in the 9-5/8" just above the 7'1 stub. We will sqz 10 bbls clas "G" cement under the retainer as we had discussed earlier. Thanks! From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, August 09, 2005 8:50 AM To: Reem, David C; Krom, Kristin L Subject: Re: Change to MPJ-18 program Dave or Kristin, Have you had any success regarding the reserves question for MP 1 -18?? Thanks, Tom Maunder, PE AOGCC Thomas Maunder wrote, On 8/5/2005 1: 19 PM: SCANNED AUG 11 2005 Dave and Kristin, One other item (as if there aren't enough). A letter was sent from the Commissioners a while back that requested an assessment of the remaining reserves and how they might be recovered when a well was being plugged back for redrill. The redrill part doesn't apply in this case, but it would be appreciated if you all (or someone over there) could look into Kuparuk situation with regard to MPl-18. I haven't been able to dig up an electronic copy of the letter, but you might check with some of your Prudhoe counterparts regarding what is prepared for their redrill wells. Thanks, Tom Maunder, PE AOGCC Reem, David C wrote, On 8/5/2005 10:02 AM: Tom, as we discussed 08/05/2005, we will be unable to stack cement on top of the 9-5/8" CIBP due to proximity of proposed tubing tail. We will do a pre-RWO MIT-OA to 2000 psi to confirm a competent 9-5/8" shoe. Should this MIT-OA fail, then we will substitute a 9-5/8" cement retainer for the CIBP and squeeze -10 bbls cement below this retainer (set at -8080'md). We will not stack add'l cement on the retainer. Hope this helps to clarify our intent. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) 1 of 1 8/9/2005 9:27 AM Re: MPJ-18 Conversion--questions ) ) ~~Rject:Re;.·~~J~t8."..~O.~¥~f~i?~~~questi~~s....,.'........".,..'...,'.:....'... ...,.,....,). ",,"'.... :....,.....'... ~~~~,:.' ..tl1?~~$.·.l\II~\l~~~r .~tqtl}__111~~~er~~dffi~~;,~~~t~..'~..~~,:? :Qª~~:..:F:ti,Q5.fN;µg ·QQ507:38:12:::0S0Q·,. ,,'..' ' Thanks Kristin. I can write in that data. On other person you might talk to regarding the area of review if Matt Green. He is working on the Schrader Pilot EOR project on E pad. He has quite a "nest" of wells to look at similar to yours around 1-18. As you look at wells within the 1/4 mile radius, it is important that any plug backs, open hole sidetracks and lost hole sections be considered in the analysis. Tom Maunder, PE AOGCC Krom, Kristin L wrote, On 8/4/2005 4:34 PM: SCANNED AUG 11 2,005 Tom- Here1s the report from the 9th of December as you requested. The sundry should have been submitted this afternoon, although it won't mention the verbal approval given via the email. Thanks, Kristin 564-5850 From: Thomas Maunder [mailto:tom, maunder@admin.state.ak.us] Sent: Thursday, August 04, 2005 2: 11 PM To: Krom, Kristin L Cc: Reem, David C Subject: Re: MPJ-18 Conversion--questions Kristin and Dave, Starting the rig operations is acceptable. Be sure the company rep contacts the Inspector for BOP witness. I will look forward to receiving the sundry. Thanks for the drilling report. Is it possible to supply one day earlier. The detail on the report you send is much greater than on the "summary reports" filed with the 407. Essentially the summary report has "one line" descriptions of the operations. Tom Maunder, PE AOGCC Krom, Kristin L wrote, On 8/4/2005 11 :53 AM: Tom- Ok, 've gathered my info and am prepared to answer questions. 1) I thìnk the only data I have available on the surface casìng cement job is what you already have, but I'm attaching the reports just in case it's not the same. 10f3 8/9/2005 8:55 AM Re: MPJ-18 Conversion--questions ) ) 2) Dave Reem has put together a slightly more detailed scope of work which you will receive with \r{l/þ'VV the actual application which details putting cement through the 9-5/8" retainer. '""\ , 3) The title for the schematic is incorrect. It was put together by a different engineer a year ago when this conversion was initially discussed and as I said I don't have the correct application to alter it. I have attached the same scanned schematic with the A crossed out. Sondra has put together the application with the area of review and we'll get it to you soon. We do anticipate being on the well on Monday. Will you be able to give us verbal approval to begin rig operations? Sorry for all the questions! I haven't been involved in this aspect of conversions previously. Please let me know if you have further questions. Thanks, Kristin 564-5850 SCANNED AUG 1, 1 2.005 From: Thomas Maunder [mailto:tom, maunder@admin.state.ak,us] Sent: Thursday, August 04, 2005 8:35 AM To: Krom, Kristin L Subject: Re: MP]-18 Conversion--questions Kristin, You have an ambitious work program planned. A couple of questions. 1. I have looked at the files we have and the original drilling detail is the "DEAP" summary report. Not much information regarding the surface casing cementing operation. Can you provide more detailed information?? 2. On your drawing of the Schrader injector, is there any plan to put cement through the 9-5/8" retainer?? Y our drawing appears to show something in the 7" annulus near the shoe. 3. On the drawing, the well name 1 -18A is used. Normal convention that I am aware of is that the well name and API number remains the same when the work simply plugs back the well. If a sidetrack is necessary, that is usually when the name and API number gets changed. Tom Maunder Krom, Kristin L wrote, On 8/4/2005 8: 11 AM: Sorry about that. I'm not sure what happened there. Here are the actual attachments (I hope!). I'll talk with Sondra this morning about the 403. She had mentioned yesterday that she thought we could get verbal approval and then submit the hard copies within 3 days? I'll also get with Skip or Dave about the AOR. No one had mentioned that aspect of the sundry to me! Thanks, ,Kristin 564-5850 From: Thomas Maunder [mailto:tom maunder@admin,state.ak.us] Sent: Thursday, August 04, 2005 8:02 AM 20f3 8/9/2005 8:55 AM Re: MPJ-18 Conversion--questions ) To: Krom, Kristin L Subject: Re: MP]-18 Conversion--attachment problem ./ d-YO \<\1 Kristin, Not sure what is up with the documents you sent, but all I appear to have are the "images" of the-icons. There does not appear to be any attachments. Would you please resend?? Thanks, Tom Maunder Krom, Kristin L wrote, On 8/3/2005 4:54 PM: Hi Tom- Sorry for the late notice but I'd like to request verbal approval for the conversion of MPJ-18 from a Kuparuk producer to a Schrader Bluff injector. We anticipate being on the well with Nabors 4ES as early as Monday. I am attaching the scope of work, the current completion schematic, and a proposed schematic. The proposed schematic will have rough depths handwritten as I do not currently have access to the program required. I hope that is not too inconvenient. Please contact me if you have any questions. MPJ-18 scope,doc MPJ-18 current,pdf MPJ-18 proposed (32 KB) (158 KB) completion. tif . , . Thanks, Kristin Krom ACT Production Engineer 907-564-5850 30f3 8/9/2005 8:55 AM ) --'C.\.· ~-I.':'·"· Morning Drilling Report Operator BP Exploration Field Milne Point ) Well MPJ-lS Rig Nabors 22E Report 7, page 1 Date 06:00, 09 Dec 97 Depth MD Est TVD Casing Size Casing Depth Rotating Time 12-1/4in ROP won RPM (Surface) RPM (On bottom) Rotating Wt Torq On Btm Torq Off Btm {::~~.'(.:: 'ÒÓštf('.û.s~b.öIUífr\r? ~"'Liì ~~1~~~,~~,~7.\f~i,Vifr-à;~.;1:eüñi~lStáttîsj~~ffiJW}'ii!1;·~.~W~t~~' {¡~~~i\!(j.ftï.~~r.¡'~¡:iê9rš~~~hl!li~.~~:.~:.ø~~~}l~~l\k ..~, l~,,, .,......"""'=.. ~~'I·..1" ""·I~_·'" ~1...'I.'h ~r, ,,\'f.,':~".I~¡~~r.r-~? .t\....·I.I~r;:...,_,,,·,,..,,,..~,.,..;~~~.~~!-1"~.~1'~;(!,·ùrjo!J.. J~.4.lJ 1f:~O~·"8'v/ft.y.1j ;.~tf~mt~...~u.,..i·;<Cj:/~..f;>'"f'lI.~fN"~Jtrl..:~t~~~~ AFE 337108 PumPi EfT 1 Stroke Rate i Liner Size \ Cire Rate Operator 1 Contractor 24 Daily Mud 5627.52 I (%) I (SPM) ! (in) 1 (bbllnùn) Service to Total 35 Cum Mud 69552.18 1 I 96.00 I ! 6 l Supervisor Paul Lockwood Daily Well 203945.00 2 I 96.00 ! ! 6! Engineer Cum We1I 690587.00 :! ! ! !~~?f-j~~:~¡~lti!t~~'V~£~ n...u ". :,1i{{ID'~1't~\f;fi-~11?i:M~},.~~,;1;~?1.~¥**í3ii' . , .~~~~~~ ' , t"'....-""..~.il,~~.!j;'~~~j¡'.11~.,'.;~)· . ..}t~~·:~£o~~,/f:~~I~N~'?~~'¡;';.'~";~:~1:!.~,.!.1" , , ~wr~~·'!".~),'1.~~~ ... '. No. ¡Size ! Type! I Serial No. ! Nozzles ! TFA I I l 0 I D 1 LIB i G i 0, R '\ MDND !Progress Hours! ¡ (in) ¡ Manufacturer i i ¡ (in^2) \ I! : I ¡(iolI6)1 I Out (Ct)! (rt) I TBR 2¡I2-1I4IM05SC jLG8969 i3xllCxll .O.3712.2!3IcrIM.E: 1.01BR!PTDI 8265.01 5278.0, 23.5 · ! SMITH I î !! !. I!! ! ¡ ! 4300 5 i I ! _ I I i_I I I! I: : _ i 1 . · ! ''t''.J.?I'.', ,,<i;-¡~~'~KW!.m:·~)¡'~1:-Jj·ßIt#.~.&1':-<'U. ,~'1!~~~1f.I.'¡".>:\!'~'¡;~···I'~' "i:"'..';i '--'r~iI' ·,·~W_~'t··", "'~"'··'*olI{,u1T.~~' '",'wl~;·\i:e··~~~,:; ";.\:ij"~"<¡";;'''"\~~~~ ·"·i~'~'n~ll'-"~~tfi~'tt~J£~~t. ~{,~:r.~,:~f{i'!;~::'·t-1(l~·~~i~rJ!f~1wt1~\~:}f~¡~{~~~\~':~~~)~it~~~::'~:í:;:\:\~"j't!~~;l:~!:~~~ß,~,~~~~~':Xí~~L~. ~ffr~~~~~f.~W¿¡\.rÑ~1%1P~;;,:·~lf.l~~~~*!~f~$~~~~{~:W-::?<;· No.! Type ¡ Weight ¡Wt Below! Depth! Rotatel ! Jar ¡ Description ¡ ¡ (klb) ! Jar (kIb) ¡ Out (Ct)! Slide (ft) ¡Hours! 2!Drllling i 56.81 ¡ 30.75! 8265.0 i 4668.0! 12.9 [ 12" 114 It B IT - 9-5/8"STEER MTR(1.50deg)- ! : ¡ ! ¡ 610.0 ¡ ¡ 8"NMSDC - 12-1I4"NMSLEEVE - 8"NMMWD- i ¡ ¡ : ! ! ¡ 12-1/4"NMSLEEVE - 2xS"NMDC - 8"NMSLEEVE .. : : ì ! I :: 8'INMDC-7..1I2"XQ-5"HWDP...6-1/4"JAR- ! ! ! ¡ ¡ ! ¡ 16x5"HWDP - 6-7/16"ACCL - 5xS"HWDP.. 5"DP ~ i ',_ ,,' ,I , 8265.0 ft 4272.0 ft 9-S/8in 8244.0 ft Hole Size Progress Cum Bit Hours Jar Hours Sliding Time i '1 o Pick Up Wt Slack Off Wt Circ Rate Riser Circ Rate Hole Circ On Dtm Circ OffBtm Fluid Type Oil based Mud Ann Vel DP Ann Vel Casing Density Funnel Vise PV yp Ann Vel DC Ann Vel Liner 10 Sei: gels 10 min gels Solids ESV Chlorides HTHP Fluid HTHP Cake Cum Cuttings Storage Site Ann Vel Riser Daily Cuttings 1 ' Barite 1000.00 bbl Bentonite 0.00 bbl Potable Water 0.00 bbl Drill Water 1050.00 bbl Base Oil 0.00 bbl Rig Fuel 80.00 bbl Heü£uel 0.00 bbl Kill Mud 0.00 bbl Base Fluid 0.00 bbl Cement 1 . Neat 0.00 bbl ~ '.i~¡ '~:m~'t.~'U'~J-»f~1 ~Fš-"i}.J',¡ii'~(j.;~'~;i1\~" i.~;¡:·\i,;:\':r,;'fof1':'\·':";f;,'I."?"~'lVJt"<;~V¡~ II{èv-t\;fr\"ï~~~~~';!I:~"'~;~;·oK~f.~~1;t9¡'~;']¡;'\1"'~:~'\~~~lft.i5~JJ~~ '')'~'I:¡:~ !!'" ...~." -j!,l;.'.:.::t*1f'~~~~.,~'.:~è'jr:£.:j~:j~l~p}~V;-~J',~. "":~i:o 1.-~, ,tì?:~~,t .:~;~. :'" ..,g. _)" :'~"" ,rJJ.,Y;:-~1~~i-:'W~~~~'.'~~~~ fiQ,,:, .t~ ~',.1r-~·'Ì-~,~; 'r:\.:i:::;~;Fili.~,'f.},~..5 J~~Wf FIT TVD MAASSP ¡Pump! Stroke Rate ¡ Cire Press Loss i CIL Press Loss ì K/L Press Loss FIT EMW ECD :! (SPM) ¡ (psi) ¡ (psi) ¡ (Psi) Kick Tol Test Press I 1 ¡ ¡ ! i Casing Test i :2 ¡ ¡ i i Days Sj~ce Last BOP Test ¡ ~ i t i Prim Lith Trip Gas Cm Gas See Lith BgrndGas Pore Press [EMW] ~~ usOO:O.OO usOO:O.OO used:O.OO used:O.OO usOO:O.OO U8OO:0.00 used:O.OO used:O.OO usOO:O.OO ) ) ..If"' Morning Drilling Report "VI~\:.' Operator BP Exploration Field Milne Point Well MPJ-18 Rig Nabors 22E Report 7. page 2 Dat~ 06:00» 09 Dee 97 Drill Accumulator Diverter Fire H2S Kick While Drilling Kick While Tripping Date Run LTA Today 03:00,27 Oct 97 Days Since Last LTA 11:00,07 Dee 97 AccldentlIncldent Today 15:30. 04 Dee 97 Days Since Last AcclInc 12:00,06 Dee 97 Accllnc Report Filed 01:00, 19 Nov 97 SpiJI 02:30, 19 Nov 97 Spill Type Spill Vol Last Safety Mtg Days Since Last Spill No Wind Speed 568 Visibility No Sea Height Sea Direction No Barometer No Weather State 15.0 mlhr Wind Direction 8.0 mile Temperature Wave Period Max Current 29,550 in.Hg Chill Factor Mostly cloudy 45.00 deg 1 degF -29 degF 719 Depth 1 Inel ¡ Azimuth ¡North ¡ East ! TVD ¡ DLS . o ¡ 0 ! 0 I ! 0 ~~~ffl , ".I >. LI ' ." , "' , . fl;.!!;~,¡¡''J!ti?\í:''\i(.'f!~8'-.~<&;/~~'ll.Þt..''''C''~';~1::'·:"~~$'Jit~~'¥.~'Wit~¡¡¡.:_· ~~~,,~j~~~~~~ ~·-i ' , -- ~ ~~.y^\'~'t~;\: 'í.t;'\~~~l,¡kWi:~~ï,~i~~j,;~\\:t~iW~j.~~!;Œ:~"I)~,to.gm:~~-IJ.'.I~~~~:~q,if(.!¡ ,"~~~ ,'L. .." ~~J};I»m.~~q,~'~· r ,. . _ f', , . ~ It' . No.! Head I From i To ! Diam ¡ Time ! Rec ¡ Rec Current Operation: Pumpmg 1st stage cement job. No. ¡ 0 ¡ 0 I 0 ¡ 0 I 0 î (%) No accidents - No spills - 568 DSLTA 719 DSLS ¡ ! ¡ ! ¡ ! I PTSM - ~TOP. R/U casing tools. Running casing. : : I I: ! ¡ Cementing. ! ¡ ¡ i i ¡! PJSM - Tripping. UD BRA. RIU casing tools. Running i ! ¡ ! ¡ ! l casing. Cementing. i ! l i ì ; i Drills .. ~ ) ) ~"\::\\L ...:~:,,' - ¡VL'" . ._-_'U__ ..If:_r1,__ \..__,1\\"-.-"1:: Morning Drilling Report x::.:-·'.. .. : ,~,.. , )1/\:: I; 0" - ¡,rlf,I'X.I,\',:I"..'"".. Operator BP Exploration Field Milne Point Well MPJ-18 Rig Nabors 22E Report 7, page 3 Date 06:00, 09 Dee 97 06:00-14:00 06:00-07:00 07:00 07:00-11:00 11:00 11:00-14:00 14:00 14:00-00:00 14:00-15:00 15:00 15:00-15:30 15:30 15:30-00:00 00:00 00: 00- 00:00-01:00 01:00 01:00-03:00 I ~ ~ 03:00 03:00-03:30 03:30 03:30- ..:'i: ?" BRA run no. 2 Circulated at 8265.0 ft Circulate and condition mud for running 9 5/8- casing. Obtained req. fluid properties - 200.00 %, hole vol. Pulled out of hole to 925.0 ft POOH to BHA. Hole slick. No problems. At BRA Pulled BHA Down load MWD. LID BaA. Clear rig floor. BHA Laid out Run casing( 9-5/8in O.D. Rigged up Casing handling equipment R/U 9 5/8" casing tools. Equipment work completed Held safety meeting Hold pre-job safety meeting for running casing. Completed operations Ran Casing to 8244.7 ft (9-S/8in OD) Run a total of 198 jts 9 5/8" 40# L-80 BTC casing. Shoe at 8244.69', FIC at 8201.77', LIC at 8160.46'. Hole slick. No problems. Hanger landed Cement : Casing cement Rigged up Cement head RID casing fill up tool. Blow down top drive. R/U cement head. Equipment work completed Ci~culated at 8244.0 ft Break circulation. Stage pump rate up to 13 BPM. Obtained req. fluid properties - 200.00 %, hole vol. Held safety meeting Hold pre-job safety meeting for cementing with all personnel associated with job. Completed operations Mixed and pumped slurry - 508.000 bbl 1st Stage - Lead: 771 sks, 298 bbls, Wt 12.0, Yield 2.17. Tail: 575 sks, 210 bbls, Wt 13.1, Yield 2.05. Displacing with fresh water. ') 0) Morning Drilling Report Operator BP Exploration Field Milne Point Well MPJ-18 Rig Nabors 22E Report 8, page 1 Date 06:00, 10 Dee 97 .~ii'ifS'~~·· , lw{{':~~~ ROP WOB RPM (Surface) RPM (On bottom) Rotating Wt Torq On Btm Torq Off Dtm ~;"'.. ~. -':;'cd " t"tti S~ Dõíïä~lti~W"¡'~ ' iIit."*,l'l'~4'-i~ (~ij~~w~m'·';;'i~V~p'·Hf¡{;. St' t ,;";,,,~t· f'''liJi,:':'~', ;·:J.¡t-;;i.~'h\X,~,(&-.:J!.: ..., '5'~i"'~'¡:'¡i>~:~,~ ~!~i\j¡'i!f~""ÔIDtlìi;:~~\1::; ,tWil~;:í~m!~\ii ~)~\':I' .,... -.~".~ ,.",.~~.""'''~~! ¡r.:1~}ft· '~~~~i.;¡t;;'t'f{~ç~,~>~",~.P..k",~.,~~r.,t:'~?'?\~';¡·M:\'i~~~ti!ü'~:¡-!\~~i ;$~~~~...l~~~~'r.~.c~"?~~~~(>1~~ AFE 337108 Pumpj Err ¡ Stroke Rate ¡ Liner Size ¡ Circ Rate Operator I Contractor 24 Daily Mud 4420.18 ; (%) I (SPM) ! (in) j (bbllmin) Serviee 10 Total 35 Cum Mud 73972.36 1 i 96.00 ¡ I 6 \ Supervisor Paul Lockwood Daily Well 205715.00 2 ! 96.00 ! ¡ 6 ¡ Engineer Cum Well 896302.00 ¡ i ! ! . ~\P.~~rl}í,*ik'fiFi~~{'~(k~:-"~ . '_-"~";.:., 'JÎ'~<I··ii'~"·-~'·~':!"¡'·<':t.m~''''¡~~~'·- .¡~~~..~'< ~ ' ,"0. '~' ':1~"\>;'" '.;.:,.','..: ." ~, .:":;'Ç/.'¡~N.":¥:P',,,,,.~,,~r":l~.~r,' 1 , . !.: ", ., 1;:~\!"11:.¡r¡,1~'~~ J~!t..~~Œ{.,~:~..~. ¡I,V;¿&; , '! .' '" .' '¡I '" .' ::. .' · ..- f"(_,,,,,,\.._'R'~. ' , Y. _ .' '~'''''''''~f'fî!r¡~.. .'"', """,<>W.¡1" '. I'!\~ . .'J\. '....' 1 . 'I .. . .. ... . No. ! Size i Type! I Serial No. ! Nozzles ¡ TF A j I ¡ 0 i D ! L ì B! G I 0: R ! MDIVD ¡Progress! Hours! : (in) I Manufacturer i! ¡ (in^2) ¡ : ¡ i: !(in/16)1 ¡ ! Out (ft) I (£t) I TBR 31 8-112\ 0517 ¡ 1900519 : 3x13 2x15 10.7340 ¡ ¡ ¡ ¡!! ¡ ¡! ! ! · , HUGHES:! I' " " I " I 1 !! I I ;! ¡ ¡ ¡ ¡ ¡ 1 ¡: ! ¡ -J:~~~~,~:i)Lr;~;~i~1'!:i~\i;~tJI~\;ì'W~t%~]fJX~~[~~l~tè~Wt41(h~~~~¿!JJ!~t~jjø.~tt;f~·t1tl;!~·~;t~~~'~f.~~~t~.i,;?~f.~~~~1£i*-~~~'~~~~~~~i~i No.¡Type ! Weight !WtBelow! Depth i Rotate! ¡ Jar ¡ DescriptiQn ¡ 1 (klb) ¡ Jar (klb)! Out (ft) ¡ Slide (ft) ¡Hours] 3] Drilling ! 54.90! 26.40! ¡ ! 106.4 ¡ 8-112"BIT - 6-3/4"STEER MTR(1.50deg) . i ¡ ¡ ¡ i ¡! 8-3/8"NMSLEEVE - 2x6-3/4"NMSDC - 6-3/4'NMMWD : : 1 : I I: - 8-3/8'·SLEEVE - 3x6-3/4ItNMDC - 7-1I16"XQ - ¡ ! ¡ ! i ! i 5"HWDP - 6-1/4"JAR - 16x5"HWDP - S"ACCL- ! ! j : ¡ !! 5x5'·HWDP - S"DP . , ". ,r,fìif gOt "~.'" 8.3 ppg 10 see gels 28 see/quart 10 min gels Solids Depth MD Fßt TVD Casing Size Casing Depth Rotating Time 8265.0 ft 4272.0 ft 9-5/8in 8244.0 ft Hole Size Progress Cum Bit Hours Jar Hours Sliding Time o Pick Up Wt Slack Off Wt Circ Rate Riser Circ Rate Hole Circ On Btm Circ orr Btm ~ ¡gj\}ill{;M} ,~~T.~1 FIT TVD FIT EMW Kick Tol Casing Test Days Since Last BOP Test Density Funnel Vise PV yp Ann Vel DC Ann Vel Liner Ann Vel Riser Daily Cuttings Fluid Type Water Based Mud LSND Ann Vel DP Ann Vel Casing Prim Lith Trip Gas Cxn Gas See Lith ßgrndGas Pore Press [EMW] Barite Bentonite Potable Water Drill Water Base Oil Rig Fuel Helifuel Kill Mud Base Fluid Cement 1 - Neat , , ,e1~~tQï - ~.æ-~~'i1f!'>\: '¥'i Stroke Rate' Circ Press Loss (SPM) (psi) U8OO:0.00 usOO;O.OO used:O.OO used:O.oo U5OO;0.00 used:O.OO u5OO:0.00 usOO:O.oo used:O.OO ", I . KIL Press Loss i (psi) , \ i t ) ,.."w;,~t.,w_- Morning Drilling Report Operator BP Exploration Field Milne Point Well MPJ-18 Rig Nabors 22E ) Report 8, page 2 Date 06:00, 10 Dee 97 Date Run LTA Today 03:00,27 Oct 97 Days Since Last LTA 11 :00, 07 Dee 97 Accidentllnc:ident Today 15:30,04 Dee 97 Days Since Last AcclInc 12:00, 06 Dee 97 AccJInc Report Filed 05:30, 30 Jan 97 Spill 01:00, 19 Nov 97 Spill Type 02:30,19 Nov 97 Spill Vol 14:00, 09 Dee 97 Last Safety Mtg Days Since Last Spill 720 'l¡;~,:·'1t'\,,;r~·~ti~ A .t~¡;f..t:'I'::~';~~\fF1~~;.,q~F.!í~!":¡.··~,...·~~t~~~;~~\.,S- ·~;¡if.;-~r;,"I:Þ-ð~:'II"" " ~~Æ.:JJi'í¡}:;<~~~~~-i~~,'j;:~~.;.-~ ¿¡¡,~~~*··'f¡æ!s.;;f"î0,'?,i~¡¡\wrw'~~;~~~~?,f.µ,\r~r!ft;",:BjÞ'!.,~_.J.~~,~.~AAI~, . ! Azimuth! North ! East ¡ TVD i DLS ¡ I j 0 ~degll00ft) Drill Accumulator Diverter Fire H2S Kick (Well Kill) Kick While Drilling Kick While Tripping Spill No.! Head ! No. . \ i j Rec i Rec ! 0 ! (%) ! ¡ \ I l i.. ~ " .. , ... No Wind Speed 569 Visibility No Sea Height Sea Direction No Barometer No Weather State ',m ~ 22.0 mlhr Wind Direction 6.0 mile Temperature Wave Period Max Current 29.950 in.Hg Chill Factor Cloudy. Blowing snow. -45 degF 68.00 deg -5 degF , 'r. ~~ "':" ~ Survey Type Current Operation: Finishing testing BOPS. No accidents w No spills w 569 DSL T A 720 DSLS PTSM - STOP. Cementing. NfD diverter. Lockout I tagout. PJSM - Cementing. NID. NfU. Changing rams. BOP testing. Drills - Fire - 2:05 ", * ~ ;.~ "'(: L·~ .'~,:\ ~:.:~: ?:'~t~;. ~~.~.';' ) Morning Drilling Report _..,..,..~~...:.. ... \ or"" Operator BP Exploration Field Milne Point Well MPJ~18 Rig Nabors 22E Report 8, page 3 Date 06:00, 10 Dee 97 06:00-12:30 06:00-06:30 06:30 06:30-10:30 10:30 10: 30-12: 30 12:30 12:30-15:30 ~2:30-15:30 15:30 15:30- 15:30-01:30 01:30 01:30-02:30 02:30 02:30-03:30 03:30 03:30-06:00 06:00 Cement : Casing cement Mixed and pumped slurry - 508.000 bbl Finisg displacing 1st stage cement with fresh water. Bump plug with 2000 psi. Check BPV's. OK. Open ES cementer with 2520 psi. Cement pumped Circulated at 2220.0 it Circulate thru ES cementer. SO bbls cement returns from 1st stage cement job. Wait on all guzzlers trucks to return to start 2nd stage cement job. Obtained clean returns - 400.00 % hole volume Mixed and pumped slurry - 462.000 bbl 2nd Stage Cement - Permafrost E, 1195 sks, 462 bbls, Wt 12.0, Yield 2.17. Displace with fresh water. 16B bbls cement returns. Bump plug and close ES cementer with 1500 psi. Check flow. No flow. Cement pumped Nipple down Divertor Rigged down Divertor Blow down top drive and mud lines. Flush Hydril. LID landing joint. N/D diverter system. Equipment work completed Nipple up All functions Rigged up BOP stack N/U FMC GenSA 11M Sk wellhead and test metal seals to 1000 psi. OK. N/U drilling spool, BOP stack, bell nipple, and flowline. Open ram doors and inspect same. OK. Change top rams to 5- and bottom rams to 3 1/2- x 6- VBR's. Continue cleaning pits. Equipment work completed Tested BOP stack PIU and set test plug. Test Hydril to 250-3500. Begin testing rams. Note: 1 of 2 control line terminating sleeve check valves on the drilling spool started leaking. Suspended pressure test on Wellhead equipment, observed leak serviced BOP stack Discuss leak problem with FMC. Install 1/2- plug in terminating control line sleeve. Equipment work completed Tested BOP stack Finish testing rams, choke manifold, floor valves, and top drive valves to 250-5000 psi. Test OK. Blow down top drive and choke manifold. Function test completed satisfactorily STATE OF ALASKA ALASK, _ AND GAS CONSERVATION COMM-~.¢ION F..,.~ORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 63.83' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM MPJ-18 At top of productive interval 9. Permit Number / Approval No. 197-220 4153' NSL, 2318' WEL, SEC. 20, T13N, R10E, UM 10. APl Number At effective depth 50-029-22834-00 4280' NSL, 2295' WEL, SEC. 20, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4328' NSL, 2286' WEL, SEC. 20, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 12457 feet Plugs (measured) true vertical 7422 feet Effective depth: measured 12338 feet Junk (measured) true vertical 7314 feet Casing Length Size Cemented MD TVD Structural 'Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 8214' 9-5/8" 1935 sx PF 'E', 575 sx Class 'G' 8245' 4262' Intermediate Production 12395' 7" 250 sx Class 'G' 12425' 7393' Liner Perforation depth: measured 12015'- 12029', 12036' - 12046', 12076' - 12096', 12110' - 12130' true vertical 7024' - 7036', 7043' - 7051', 7078' - 7096', 7108' - 7126' Tubing (size, grade, and measured depth) 2-7,8", 6.5#, L-80 to 11879' RECEIVED Packers and SSSV (type and measured depth) N/A JUN 2, 0 2.001 13. Stimulation or cement squeeze summary Alaska Oil & Gas Cons. Commission Intervals treated (measured) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .__~Title Technical Assistant Date ~ Prepared By Name/Number: Sondra Stewman, 564-4750 ....... :~. . i Form 10-404 Rev. 06/15/88 ~ P I [f"'~ I r\l A I submit In Duplicate BP EX~E~RATI~N~ i~ ~ Page OperatiOns ~Summ2~Repo Legal Well Name: MPJ-18 Common Well Name: MPJ-18 Spud Date: 12/2/1997 Event Name: WORKOVER Start: 5/25/2001 End: 5/29/2001 Contractor Name: NABORS Rig Release: 5/29/2001 Rig Name: NABORS 4ES Rig Number: Date From-To Hours ActivitylCode NPT~I,~Phase~!: !~ ):i~ 5/25/2001 03:00 - 08:30 5.50 RIGU PRE MI/RU 08:30 - 19:00 10.50 REST POST CHANGE OUT CONSOLE & ADD NEW PVT SYSTEM TO PITS. 19:00 - 00:00 5.00; KILL DECOMP TAKE ON 9.9 PPG. BRINE & RIG UP WELL KILL EQUIPMENT. & TEST & PULL TWC TBG. 1050 PSI. ANN 1050 PSI. 5/26/2001 00:00 - 08:00 8.00 KILL DECOMP CIRC WELL BORE WITH 9.9 PPG. BRINE (CIRC RESTRICTED TO SLOW RATE DUE TO SHEAR OUT VALVE IN MANUAL) 08:00 - 12:00 4.00! KILL DECOMP MONITOR WELL & TAKE SHUT IN PRESSURE TBG. 140 PSI. ANNULUS 100 PSI. & BUILD WT TO 10.2 PPG. & CIRC WELL BORE AT SLOW RATE. & SHUT IN & TAKE PRESSURE TBG. 70 PSI. ANNULUS 70 PSI. 12:00 - 15:00 3.00 KILL DECOMP CIRC. WELL BORE WITH 10.4 PPG. BRINE & SHUT IN PRESSURES 20 PSI. & CONTINUE TO FLOW (RESTRICTED CIRC. DUE TO SHEAR OUT VALVE. 15:00 - 19:00 4.00 KILL DECOMP CIRC WELL BORE WITH 10.7 PPG. & WELL STATIC. 19:00-21:00 2.00 WHSUR DECOMP SET TWC & ND TREE 21:00 - 23:30 2.50 BOPSUFt DECOMP NIPPLE UP BOP 23:30 - 00:00 0.50 BOPSUF~ DECOMP PRESSURE TEST BOP TO 250 LOW & 3500 HIGH (TEST / WAIVED BY JEFF JONES WITH AOGC) 5/27/2001 00:00 - 03:30 3.50 BOPSUF~ DECOMP PRESSURE TEST BOP TO 250/3500 TEST WAIVED BY JEFF JONES WITH AOGC. 03:30 - 05:30 2.00 PULL DECOMP PULL TWC & PULL HANGER & LAY DN SAME. 05:30 - 18:30 13.00 PULL DECOMP POOH & LAY DN ESP ASSY & CLEAN RIG FLOOR. 18:30 - 00:00 5.50 EVAL COMP RIG HES SLICK LINE & RIH WITH 2.5" DRIVE DN BAILER & 3.62" SWEDGE & TAG @ 12180' 5/28/2001 00:00 - 02:00 2.00 EVAL COMP POOH & RIG DOWN HES SLICKLINE 02:00 - 04:00 2.00 PERF COMP WAIT ON SWS 04:00 - 14:30 10.50 PERF COMP RIG SWS & RIH & GET ON DEPTH WITH GR/CCL & MAKE 3-RUNS TO PERF INTERVALS PER PROGRAM. 14:30 - 00:00 9.50 RUNCOI~ COMP MU ESP COMPLETION & RIH WITH SAME. 5/29/2001 00:00 - 04:00 4.00 RUNCOI~ COMP RIH WITH COMPLETION & MAKE ESP CONNECTOR SPLICE & MU UP HANGER & LAND.SAME & RILDS 04:00 - 06:00 2.00 BOPSUR COMP SET TWC & NIPPLE DOWN BOP'S 06:00 - 08:00 2.00 WHSUR COMP NIPPLE UP TREE & TEST SAME. 08:00 - 09:00 1.00 WHSUR COMP PULL TWC & SET BPV & SECURE TREE AREA. RIG RELEASED @ 0900 HRS. 5/29/2001 Printed: 6/4/2001 1:27:56 PM Well compli-an e Report File on Left side of folder 197-220-0 . MIS' 12457. T Name L 8372 MILNE POINT HiT J-18 ......... 50- 029-22834'00 BP EXPLORATION · 07422 ~_.~mpletion Date: 4/9/98 Completed Status: 1-OIL Current: Interval SCHLUM OR/CCL Sent Received T/C/D CH 5/12/98 5/14/98 L DGR/CNP/SLD-MD L DGR/CNP/SLD-TVD L DGP, JEWR4-MD L DGR/EWR4-TVD L GR/CCL T 8378 Daily Well Ops/Ot0?-- q~0Jqt~ Was thewell cored? yes ~ Comments: tF.~A L 220-12455 OH 5/27/98 5/28/98 F~AL 290-7421 OH 5/27/98 5/28/98 jlNAL 220-12455 OH 5/27/98 5/28/98 L~NAL 290-7421 OH 5/27/98 5/28/98 cFI~AL 8200-12326 /~lt~[q00 CH 3/25/98 4/1/98 ~ SPERRY MPT/GRC/EWR4/CNP OH 5/20/98 5/21/98 Are Dry Ditch Samples Required? yes ~And Received? Analysis Description Receiv, y. edC-~-eg--~6~" SampkrSet-# ........ Monday, May 01,2000 Page 1 of 1 -( _THE MATER/AL UNDER THIs coVER MICROFILMED ON'OR BEFORE ----- N D R C:LORI~t~ILM. DOC STATE OF ALASKA ALASI', ;IL AND GAS CONSERVATION CON 3SION Rt=PORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP !2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 63.83' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM MPJ-18 9. Permit Number/ Approval No. At top of productive interval ..... ~ 197-220 4153' NSL, 2318' WEL, SEC. 20, T13N, R10E, UM 10. APl Number At effective depth ~---4 50-029-22834-00 4280' NSL, 2295' WEL, SEC. 20, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4328' NSL, 2286' WEL, SEC. 20, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 12457 feet Plugs (measured) true vertical 7422 feet Effective depth: measured 12338 feet Junk (measured) true vertical 7314 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 8214' 9-5/8" 1935 sx PF 'E', 575 sx Class 'G' 8245' 4262' Intermediate Production 12395' 7" 250 sx Class 'G' 12425' 7393' Liner Perforation depth: measured 12076' - 12096' MAR O l 2OOO true vertical 7078' - 7096' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 11883' , Anch0i'age Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGl~tAL 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e ../,~~,_, ~,~ Title Technical Assistantlll Date 0'~,~,,~..9-(~~) : Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt J Pad Well MPJ- 18 Rig Nabors 4ES Page 1 Date 21 February 00 Date/Time 17 Feb 00 14:00-00:00 14:00-00:00 18 Feb 00 00:00 00:00-04:00 00:00-01:30 01:30 01:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-09:30 08:00-09:30 09:30 09:30-12:30 09:30-12:30 12:30 12:30-22:00 12:30-14:00 14:00 14:00-17:00 17:00 17:00-21:30 19 Feb 00 21:30 21:30-22:00 22:00 22:00-23:30 22:00-23:30 23:30 23:30-01:00 23:30-01:00 01:00 01:00-06:00 01:00-02:00 02:00 Duration 10hr 10hr 4hr 1-1/2 hr 2-1/2 hr 2hr 2hr 2hr 2hr 1-1/2 hr 1-1/2 hr 3hr 3hr 9-1/2 hr 1-1/2 hr 3hr 4-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 5hr lhr Activity Move rig Rig moved 100.00 % Move rig from K-pad to J-pad & rig up & safe out equipment. At well location - Slot Wellhead work Removed Hanger plug pull bpv & rig lines to tiger tank Equipment work completed Rigged up Fluid system rig lines to tiger tank & tree & test to 2500 & take on 10.3 ppg. brine Equipment work completed Well control Circulated closed in well at 11791.0 ft circ closed in well with 10.3 ppg. brine & monitor same static. Influx Out of hole Wellhead work Rigged down Xmas tree set twc & nipple dn tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi Wellhead work Removed Tubing hanger pull twc & MU Landing jr. & pull hanger to floor Equipment work completed Tested Accessories check out esp equipment & find that failure is in the eft connector to the penetrator & take to shope & separate & investigate. Began precautionary measures Installed Tubing hanger lay dn 1-jt. tbg & pick up 16' of pups & make up hanger & install eft connector & land hanger & & rilds. Equipment work completed Tested Hanger plug Pressure test completed successfully - 2500.000 psi Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Wellhead work Installed Hanger plug pull twc & install bpv & secure tree. Equipment work completed STATE OF ALASKA ALASKa- _,..~ AND GAS CONSERVATION Cb-~-MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [~ Pull Tubing i--IAIter Casing [~ Repair Well E~Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM At top of productive interval 4154' NSL, 2336' WEL, SEC. 20, T13N, R10E, UM At effective depth 4282' NSL, 2295' WEL, SEC. 20, T13N, R10E, UM At total depth 4329' NSL, 2305' WEL, SEC. 20, T13N, R10E, UM Type ¢i~] well: Development I~ Exploratory E~ Stratigraphic F-] Service 6. Datum Elevation (DF or KB) KBE = 63.83' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-18 9. Permit Number / Approval No. 197-220 10. APl Number 50-029-22834-00 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12457 feet true vertical 7422 feet Effective depth: measured 12338 feet true vertical 7314 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 8214' 9-5/8" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 1935 sx PF 'E', 575 sx Class 'G' 12395' 7" 250 sx Class 'G' MD TVD 112' 112' 8245' 4262' 12425' 7393' Perforation depth: measured 12076' - 12096' true vertical 7078' - 7096' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 11899' Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the fo, regoing is true and correct to the best of my knowledge Signed Terrie Nubble _ . _ Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 ~ Submit In Duplica~ Form 10-404 Rev. 06/15/88 Facility Date/Time 08 Feb O0 09 Feb 00 M Pt J Pad Duration 9 hr 9 hr 12:00-21:00 12:00-21:00 2 hr 2 hr 21:00 21:00-23:00 21:00-23:00 23:00 23:00-02:30 23:00-00:00 00:00 00:00-02:00 02:00 02:00-02:30 3-1/2 hr 1 hr 2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 02:30 02:30-06:00 02:30-06:00 5-1/2 hr 1/2 hr 06:00 06:00-11:30 06:00-06:30 5 hr 06:30 06:30-11:30 11:30 11:30-13:00 11:30-12:00 12:00 12:00-13:00 13:00 13:00-15:00 13:00-15:00 15:00 15:00-17:30 15:00-17:30 17:30 1-1/2 hr 1/2 hr 1 hr 2 hr 2 hr 2-1/2 hr 2-1/2 hr 2 hr 1 hr 1 hr 10-1/2 hr 10-1/2 hr Progress Report 17:30-19:30 17:30-18:30 18:30 18:30-19:30 19:30 19:30-06:00 19:30-06:00 10 Feb 00 06:00 Well MPJ- 18 Page 1 Rig Nabors 4ES Date 14 February 00 Activity Move rig Rig moved 100.00 % lower derrick & move over J- 18 & rig up raise derrick & safe out equipment, etc. At well location - Slot Fluid system Fill pits with Brine take on brine & rig up tiger tank & hard lines to same. Completed operations Wellhead work Removed Hanger plug Equipment work completed Installed High pressure lines install hcr valve to well head & rig hard liines Equipment work completed Held safety meeting test lines to 2500 psi. & hold well kill PJSM. Completed operations Well control Circulated closed in well at 11801.0 ft Kill well with 9.9 PPG. Brine (Monitoring well bore at report time. Hole displaced with Brine - 100.00 % displaced Well control (cont...) Monitor wellbore pressures Monitor well bore & well continue to flow with well displaced with 9.9 PPG. Observed pressures - string: 10.000 psi, annulus: 20.000 psi Circulated closed in well at 11820.0 ft circ. well bore with 10.1 ppg. brine & reduce pump rate to reduce ecd to prevent loss into formation while doing so. & monitor same well static. Hole displaced with Brine - 100.00 % displaced Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test waived by John Spaulding. with AOGC Wellhead work Removed Hanger plug Equipment work completed Removed Tubing hanger Equipment work completed Pull Single completion, 2-7/8in O.D. ~.~ Pulled Tubing in stands to 2350.0 ft Stopped' To hold safety meeting~_~g0i Facility M Pt J Pad Progress Report Well MPJ- 18 Page Rig Nabors 4ES Date 2 14 February 00 Date/Time 06:00-08:00 06:00-08:00 08:00 08:00-06:00 08:00-14:00 14:00 14:00-02:30 llFeb00 02:30 02:30-06:00 06:00 06:00-07:00 06:00-07:00 07:00 07:00-08:00 07:00-08:00 08:00 08:00-09:00 08:00-09:00 09:00 09:00-06:00 09:00-10:00 10:00 Duration 2 hr 2 hr 22 hr 6 hr 12-1/2 hr 3-1/2 hr 1 hr 1 hr 1 hr 1 hr 1 hr 1 hr 21hr 1 hr Activity Pull Single completion, 2-7/8in O.D. (cont...) Rigged down sub-surface equipment - ESP Equipment work completed Run Single completion, 2-7/8in O.D. Functioned ESP mu esp & servvce same & splice esp flat lead twice due to damage while installing flat guards over. Equipment work completed Ran Tubing in stands to 11890.0 ft rih with esp & make mid-line splice On bottom Installed Tubing hanger Install hanger & make splice to same & land same & rilds. Equipment work completed Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Test well control equipment Tested Xmas tree Pressure test completed successfully - 5000.000 psi Wellhead work Installed Hanger plug pull twc & set bpv & rig down & secure tree area. Equipment work completed STATE OF ALASKA ALASKA~'IL AND GAS CONSERVATION C0~i~7MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [-]Alter Casing [] RepairWell [~Other ESP Changeout 6. Datum Elevation (DF or KB) KBE = 63.83 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-18 9. Permit Number / Approval No. 97-220 10. APl Number 50- 029-22834 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development I'-I Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM At top of productive interval 4154' NSL, 2336' WEL, SEC. 20, T13N, R10E, UM At effective depth 4281' NSL, 2313' WEL, SEC.20, T13N, R10E, UM At total depth 4329' NSL, 2305' WEL, SEC. 20, T13N, R10E, UM 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12457 feet 7422 feet 12337 feet 7314 feet Length Size 86' 20" 8216' 9 5/8" 12396' 7"' Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1935 sx PF' E', 575 sx Class 'G' 250 sx Class 'G' MD TVD 115' 115' 8245' 4198' 12425' 7330' Perforation depth: measured true vertical 12076' - 12096' (Subsea) 7014' - 7032' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 set at 11849' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [~.Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the foregoing, is tr..u,e/and correct to the best of my knowledge Sig necl(~-~z:~~ ~ .,,~¢nne L. Haas ' Title Staff Technical Assistant Date Prepared By Name/Numben Jeanne L. Haas, 564-5225 Facility Date/Time 20 May 98 21 May 98 22 May 98 23 May 98 24 May 98 M Pt J Pad Progress Report Well MPJ- 18 Rig Nabors 5S Page Date Duration Activity 06:00-06:15 06:15-14:30 14:30-20:30 20:30-22:30 22:30-00:00 00:00-06:00 06:00-06:15 06:15-10:15 10:15-10:45 10:45-13:00 13:00-15:00 15:00-17:00 17:00-19:30 19:30-00:00 00:00-06:00 06:00-06:15 06:15-11:30 11:30-12:30 12:30-19:30 19:30-21:00 21:00-05:00 05:00-06:00 06:00-06:15 06:15-14:00 14:00-02:00 02:00-04:00 04:00-06:00 06:00-06:15 06:15-07:30 07:30-11:00 11:00-12:00 12:00-13:00 13:00-14:30 14:30-16:00 16:00-06:00 1/4 hr 8-1/4 hr 6 hr 2 hr 1-1/2 hr 6 hr 1/4 hr 4 hr 1/2 hr 2-1/4 hr 2 hr 2 hr 2-1/2 hr 4-1/2 hr 6 hr 1/4 hr 5-1/4 hr 1 hr 7 hr 1-1/2 hr 8 hr 1 hr 1/4 hr 7-3/4 hr 12hr 2 hr 2 hr 1/4 hr 1-1/4 hr 3-1/2 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 14hr Held safety meeting Rig moved 100.00 % Rig moved 100.00 % Removed Hanger plug Bleed down well Monitor wellbore pressures Held safety meeting Circulated at 11801.0 ft Monitor wellbore pressures Installed Hanger plug Installed BOP stack Tested All rams Removed Hanger plug Circulated at 11720.0 ft Pulled Tubing in stands to 4240.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Serviced Travelling block R.I.H. to 12193.0 ft Reverse circulated at 12193.0 ft Rigged up Swivel Rigged down Swivel Held safety meeting Pulled BHA Ran Tubing in stands to 9000.0 ft Installed Electric cable Ran Tubing in stands to 11912.0 ft Held safety meeting Ran Tubing in stands to 11912.0 ft Conducted electric cable operations Ran Tubing on landing string to 11912.0 ft Removed BOP stack Installed Xmas tree Displace treatment Rig moved 100.00 % 1 10 June 98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil F-~ Gas E] Suspended l--I Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-220 398-079 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22834 4. Location of well at surface :. ......... ~ 9. Unit or Lease Name 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM i 0~...-~:~ ':: ::Tr? "~ Milne Point Unit At top of productive interval ¢~~_~.i~.~_¢.¢_._ ;, ~!. . 'i 0. Well Number 4154' NSL, 2336' WEL, SEC. 20, T13N, R10E, UM. ~.": /~,, ,~ MPJ-18 At total depth ; ~/,~.Jc;,: , - ,,~:~' ~ 11. Field and Pool 4329' NSL, 2305' WEL, SEC. 20, T13N, R10E, UM ~-.¢~-.-~' Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designati0~'a;i~d Serial No. Sands KBE = 63.83'I ADL 025515 12. Date Spudded12/3/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of cOmpletiOns ''12/12/97 4/9/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)t19. Directional Survey 120. Depth where SSSV set121. 12457 7422 FT1 12338 7314 FTI [~Ves [--]No, N/A MD, i'¢'.,l~(j~pbr~x.~'~-~ 22. Type Electric or Other Logs Run 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE ...... SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD 20" 91.1# H-40 32' 112' 24" _~50 SX Arcticset I (Approx.) 9-5/8" 40# L-80 31' 8245' 12-1/4" 1935 sx PF 'E', 575 sx Class 'G' 7" 26# L-80 30' 12425' 8-1/2" 250 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, 6 spf 2-7/8", 6.5#, L-80 11912' MD TVD MD TVD 12076'-12096' 7078'-7096' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 4-1/2 bbls diesel Frac, 12076'-12096' 105800# 20/40 Carbolite behind pipe Proplokfrac, 12076'-12096' 54400# 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 25, 1998I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 11821' 6853' Top Kuparuk 'B' 11952' 6968' Top Kuparuk 'A' 12042' 7048' TMLV 12164' 7157' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certifyD, b~t~e foreg,e~~rue and c~rrect to the best of my knowledge Title Drilling Engineering Supervisor Date / I~1PJ-18 97-220 398-079 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No./Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,~ Shut-In, Other-explain. :;;~ ?' ~'~-'~ \',.! "'4:, ? ITEM 28: If no cores taken, indicate 'none'. ~% ~" ,., ~.~,t.,~,~ Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 00:22, 02 Jun 98 Page 1 The analysis is from - 04:30, 11 Dec 97 - to - 04:30, 11 Dec 97 Programs in Result Table: MPJ-18 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPJ-18 Event 04:30, 11 Dec 97 04:30, 11 Dec 97 0 hr 0 min Obtained leak off 14.0 Hole Size MDR 8-1/2 Progress Report Facility M Pt J Pad Well MPJ- 18 Rig Nabors :~,~,R~' Page 1 Date 01 June 98 Date/Time 02 Dec 97 09:00-10:00 10:00-10:30 10:30-12:00 12:00-13:00 13:00-16:00 16:00-21:00 21:00-22:00 22:00-05:00 03 Dec 97 05:00-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-11:00 11:00-14:00 14:00-14:30 14:30-20:00 20:00-02:30 04 Dec 97 02:30-04:00 06:00-14:00 14:00-15:30 15:30-06:00 05 Dec 97 06:00-07:00 07:00-08:30 08:30-11:30 11:30-14:30 14:30-15:30 15:30-18:00 18:00-03:30 06 Dec 97 03:30-04:30 04:30-05:00 05:00-06:00 06:00-14:00 14:00-15:30 15:30-17:30 17:30-18:00 18:00-20:30 20:30-05:00 07 Dec 97 05:00-06:00 06:00-07:00 07:00-07:30 07:30-19:00 19:00-21:00 21:00-01:30 08 Dec 97 01:30-04:30 04:30-06:00 06:00-07:00 07:00-11:00 11:00-14:00 14:00-15:00 15:00-15:30 15:30-00:00 09 Dec 97 00:00-01:00 01:00-03:00 03:00-03:30 Duration lhr 1/2 hr 1-1/2 hr lhr 3hr 5hr lhr 7hr lhr 2hr 1/2 hr 1/2 hr 2hr 3hr 1/2 hr 5-1/2 hr 6-1/2 hr 1-1/2 hr 8hr 1-1/2 hr 14-1/2 hr lhr 1-1/2 hr 3hr 3hr lhr 2-1/2 hr 9-1/2 hr lhr 1/2 hr lhr 8hr 1-1/2 hr 2hr 1/2 hr 2-1/2 hr 8-1/2 hr lhr lhr 1/2 hr 11-1/2 hr 2hr 4-1/2 hr 3hr 1-1/2 hr lhr 4hr 3hr lhr 1/2 hr 8-1/2 hr lhr 2hr 1/2 hr Activity Rig moved 10.00 % Held safety meeting Rig moved 20.00 % Rig moved 20.00 % Rig moved 50.00 % Rig moved 100.00 % Rig moved 100.00 % Rigged up Divertor Made up BHA no. 1 Made up BHA no. 1 Tested Divertor Held safety meeting Made up BHA no. 1 Drilled to 202.0 ft Pulled out of hole to 50.0 ft Made up BHA no. 1 Drilled to 722.0 ft Pulled out of hole to 112.0 ft Rigged down High pressure lines R.I.H. to 722.0 ft Drilled to 2894.0 ft Drilled to 2987.0 ft Circulated at 2987.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 2 Serviced Top drive R.I.H. to 2987.0 ft Drilled to 4340.0 ft Circulated at 4340.0 ft Pulled out of hole to 2915.0 ft R.I.H. to 4340.0 ft Drilled to 5759.0 ft Circulated at 5759.0 ft Pulled out of hole to 925.0 ft Serviced Top drive R.I.H. to 5759.0 ft Drilled to 7093.0 ft Circulated at 7093.0 ft Pulled out of hole to 5660.0 ft R.I.H. to 7093.0 ft Drilled to 8265.0 ft Circulated at 8265.0 ft Pulled out of hole to 925.0 ft R.I.H. to 8265.0 ft Circulated at 8265.0 ft Circulated at 8265.0 ft Pulled out of hole to 925.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 8244.7 ft (9-5/8in OD) Rigged up Cement head Circulated at 8244.0 ft Held safety meeting Progress Report Facility M Pt J Pad Well MPJ- 18 Rig Nabors :~ ~ Page 2 Date 01 June 98 Date/Time 03:30-06:00 06:00-06:30 06:30-10:30 10:30-12:30 12:30-15:30 15:30-01:30 10Dec 97 01:30-02:30 02:30-03:30 03:30-06:00 06:00-07:30 07:30-09:00 09:00-12:30 12:30-14:00 14:00-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-22:30 22:30-23:30 23:30-00:00 11 Dec 97 00:00-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-14:00 14:00-15:00 15:00-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-06:00 12 Dec 97 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-18:00 18:00-18:30 18:30-23:00 23:00-00:30 13 Dec 97 00:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-07:00 07:00-13:00 13:00-15:00 15:00-16:30 16:30-18:00 18:00-18:45 18:45-01:30 14 Dec 97 01:30-02:30 Duration 2-1/2 hr 1/2hr 4hr 2hr 3hr 10hr lhr lhr 2-1/2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr lhr lhr 1-1/2 hr 8hr lhr 1/2 hr 1/2 hr 1/2hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2hr lhr 1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 2hr 1/2 hr lhr 2hr lhr 6hr 2hr 1-1/2 hr 1-1/2 hr 3/4 hr 6-3/4 hr lhr Activity Mixed and pumped slurry - 508.000 bbl Mixed and pumped slurry - 508.000 bbl Circulated at 2220.0 ft Mixed and pumped slurry - 462.000 bbl Rigged down Divertor Rigged up BOP stack Tested BOP stack Serviced BOP stack Tested BOP stack Tested Blind / Shear ram Serviced Top drive Made up BHA no. 3 R.I.H. to 2219.0 ft Drilled cement to 2219.0 ft R.I.H. to 4500.0 ft R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 7500.0 ft Serviced Block line R.I.H. to 8160.0 ft Circulated at 8160.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float collar Circulated at 8285.0 ft Performed formation integrity test Drilled to 8458.0 ft Drilled to 9791.0 ft Circulated at 9791.0 ft Pulled out of hole to 8244.0 ft Serviced Top drive R.I.H. to 9791.0 ft Drilled to 9982.0 ft Held safety meeting Drilled to 11221.0 ft Circulated at 11221.0 ft Pulled out of hole to 9317.0 ft Serviced Top drive R.I.H. to 11221.0 ft Drilled to 11983.0 ft Held safety meeting Drilled to 12457.0 ft Circulated at 12457.0 ft Pulled out of hole to 8244.0 ft Serviced Top drive R.I.H. to 12457.0 ft Circulated at 12457.0 ft Circulated at 12457.0 ft Pulled out of hole to 952.0 ft Pulled BHA Rigged up Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 8200.0 ft (9-5/8in OD) Circulated at 8200.0 ft Facility M Pt J Pad Progress Report Well MPJ- 18 Rig Nabors ~_ ~ Page Date 3 O1 June 98 Date/Time 15 Dec 97 02:30-05:30 05:30-06:00 06:00-08:00 08:00-08:30 08:30-10:00 10:00-11:00 11:00-11:30 11:30-14:00 14:00-15:30 15:30-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-06:00 06:00-13:00 Duration 3 hr 1/2 hr 2 hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 2-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 6-1/2 hr 7 hr Activity Ran Casing to 12425.0 ft (7in OD) Circulated at 12425.0 ft Circulated at 12425.0 ft Held safety meeting Mixed and pumped slurry - 52.000 bbl Displaced slurry - 386.000 bbl Tested Casing Rigged down Additional services Rigged down BOP stack Installed Casing spool Held safety meeting Installed Casing on landing string Removed Additional services Laid down 12000.0 ft of 5in OD drill pipe Laid down 12400.0 ft of 5in OD drill pipe Facility M Pt J Pad Progress Report Well MPJ- 18 Rig Nabors 5S Page Date 1 01 June 98 Date/Time 16 Mar 98 17 Mar 98 18 Mar 98 19 Mar 98 20 Mar 98 06:00-15:00 15:00-17:00 17:00-18:00 18:00-19:30 19:30-21:00 21:00-00:15 00:15-02:30 02:30-06:00 06:00-07:00 07:00-10:00 10:00-12:00 12:00-13:00 13:00-14:00 14:00-18:00 18:00-22:30 22:30-23:00 23:00-00:15 00:15-00:30 00:30-01:30 01:30-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:15 06:15-13:00 13:00-18:00 18:00-18:15 18:15-00:00 00:00-02:30 02:30-05:00 05:00-05:30 05:30-06:00 06:00-06:15 06:15-08:30 08:30-09:00 09:00-12:30 12:30-13:30 13:30-16:30 16:30-18:00 18:00-18:15 18:15-18:30 18:30-21:00 21:00-22:30 22:30-00:00 00:00-03:00 03:00-04:30 04:30-06:00 06:00-06:15 06:15-08:30 08:30-16:30 16:30-18:00 18:00-18:15 18:15-19:30 19:30-20:30 Duration 9hr 2hr 1 hr 1-1/2 hr 1-1/2 hr 3-1/4 hr 2-1/4 hr 3-1/2 hr 1 hr 3 hr 2 hr lhr lhr 4 hr 4-1/2 hr 1/2 hr 1-1/4 hr 1/4 hr 1 hr 1/2 hr 1 hr lhr 2hr 1/4 hr 6-3/4 hr 5 hr 1/4 hr 5-3/4 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/4 hr 2-1/4 hr 1/2 hr 3-1/2 hr 1 hr 3hr 1-1/2 hr 1/4 hr 1/4 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 3 hr 1-1/2 hr 1-1/2 hr 1/4 hr 2-1/4 hr 8 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1 hr Activity Rig moved 100.00 % Rig moved 100.00 % Rig moved 100.00 % Fill pits with Seawater Removed All tree valves Installed BOP stack Tested BOP stack Tested All rams Tested All rams Rigged up Drillstring handling equipment Singled in drill pipe to 378.0 ft Circulated at 378.0 ft Pulled Drillpipe in stands to 0.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 378.0 ft Pulled Drill collar in stands to 0.0 ft Ran Drillpipe to 378.0 ft (3-1/2in OD) Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe to 378.0 ft (3-1/2in OD) Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe to 378.0 ft (3-1/2in OD) Ran Drillpipe to 0.0 ft (3-1/2in OD) Pulled Drillpipe in stands to 0.0 ft Held safety meeting Rig waited · Assessed situation Ran Tubing to 2300.0 ft (1-1/4in OD) Held safety meeting Circulated at 2385.0 ft Pulled out of hole to 0.0 ft Circulated at 512.0 fi Pulled out of hole to 0.0 fi Installed Logging/braided cable equipment Held safety meeting Pulled out of hole to 0.0 ft Rigged up High pressure lines R.I.H. to 550.0 ft R.I.H. to 600.0 ft Circulated at 600.0 ft Circulated at 600.0 ft Held safety meeting Pulled out of hole to 0.0 fi Ran Tubing to 2163.0 ft (1-1/4in OD) Circulated at 2163.0 ft Worked stuck pipe at 2163.0 fi Worked stuck pipe at 2163.0 ft Worked stuck pipe at 2137.0 ft Laid down 2000.0 ft of Tubing Held safety meeting Laid down 300.0 ft of Tubing Removed BOP stack Ran Drillpipe to 120.0 ft (3-1/2in OD) Held safety meeting Installed Swivel Pulled out of hole to 0.0 fi j i~J Progress Report Facility M Pt J Pad Well MPJ-18 Page 2 Rig Nabors 5S Date 01 June 98 Date/Time 20:30-22:00 22:00-23:30 23:30-00:30 21 Mar 98 00:30-01:30 01:30-03:00 03:00-04:30 04:30-06:00 06:00-06:15 06:15-12:00 12:00-14:00 14:00-16:30 16:30-20:15 20:15-22:30 22:30-02:30 22 Mar 98 02:30-06:00 06:00-06:15 06:15-07:30 07:30-13:30 13:30-15:00 15:00-18:30 18:30-18:45 18:45-19:30 19:30-06:00 23 Mar 98 06:00-17:00 17:00-20:00 20:00-06:00 24 Mar 98 06:00-06:00 06:00-06:15 06:15-10:30 10:30-20:00 20:00-22:00 22:00-00:00 25 Mar 98 00:00-04:30 04:30-06:00 06:00-06:15 06:15-11:30 11:30-13:00 13:00-21:00 21:00-22:30 22:30-04:30 26 Mar 98 04:30-06:00 06:00-06:15 06:15-23:00 23:00-01:00 27 Mar 98 01:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-11:30 11:30-12:00 12:00-14:00 14:00-18:00 18:00-18:15 Duration 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/4 hr 5-3/4 hr 2 hr 2-1/2 hr 3-3/4 hr 2-1/4 hr 4 hr 3-1/2 hr 1/4 hr 1-1/4 hr 6 hr 1-1/2 hr 3-1/2 hr 1/4 hr 3/4 hr 10-1/2 hr llhr 3hr 10hr 24 hr 1/4 hr 4-1/4 hr 9-1/2 hr 2 hr 2hr 4-1/2 hr 1-1/2 hr 1/4 hr 5-1/4 hr 1-1/2 hr 8 hr 1-1/2 hr 6 hr 1-1/2 hr 1/4 hr 16-3/4 hr 2hr 2 hr 1-1/2 hr 1 hr 1/2 hr 1/4 hr 5-1/4 hr 1/2 hr 2 hr 4hr 1/4 hr Activity Ran Drillpipe to 120.0 ft (5in OD) Laid down 100.0 ft of Casing Ran Drillpipe to 120.0 ft (Sin OD) Conducted electric cable operations Rigged up Drillstring handling equipment Conducted electric cable operations Pulled out of hole to 380.0 ft Held safety meeting Stripped over wireline at 380.0 ft Laid down 590.0 ft of Casing Conducted slickline operations on Slickline equipment - Tool run Ran Casing to 590.0 ft (7in OD) Space out tubulars Installed Casing hanger & seal assembly running tool Installed Casing hanger & seal assembly running tool Held safety meeting Installed Tubing head spool Installed BOP stack Tested Casing - Via string Displace treatment Held safety meeting Laid down 400.0 ft of 3-1/2in OD drill pipe Ran Tubing to 6000.0 ft (4-1/2in OD) Ran Tubing to 12315.0 ft (4-1/2in OD) Circulated at 12315.0 ft Laid down 4000.0 ft of Tubing Laid down 4000.0 ft of Tubing (cont...) Held safety meeting Laid down 10815.0 ft of Tubing Repaired Tubing handling equipment Laid down 1500.0 ft of Tubing Rigged up sub-surface equipment - Production logging tools Conducted electric cable operations Perforated Held safety meeting Perforated from 12076.0 ft to 12096.0 ft Ran Tubing to 1000.0 ft (4-1/2in OD) Ran Tubing to 5500.0 ft (4-1/2in OD) Retrieved Tubing Ran Tubing to 11328.0 ft (4-1/2in OD) Rigged up High pressure lines Held safety meeting Rig waited: Materials Displace treatment Injectivity test - 228.000 bbl injected at 4600.0 psi Monitor wellbore pressures Displace treatment Monitor wellbore pressures Held safety meeting Monitor wellbore pressures Backflow Monitor wellbore pressures Monitor wellbore pressures Held safety meeting Progress Report Facility M Pt J Pad Well MPJ- 18 Rig Nabors 5S Page 3 Date 01 June 98 Date/Time 18:15-19:15 19:15-23:00 23:00-01:15 28 Mar 98 01:15-06:00 06:00-06:15 06:15-06:45 06:45-14:30 14:30-20:00 20:00-21:30 21:30-23:00 23:00-05:00 29 Mar 98 05:00-05:30 05:30-06:00 06:00-06:15 06:15-07:30 07:30-08:00 08:00-12:00 12:00-14:00 14:00-15:00 15:00-15:30 15:30-17:00 17:00-18:30 18:30-02:00 30 Mar 98 02:00-06:00 06:00-06:15 06:15-07:00 07:00-13:00 13:00-15:30 15:30-17:00 17:00-18:00 18:00-18:15 18:15-22:00 22:00-06:00 31 Mar 98 06:00-06:15 06:15-08:00 08:00-10:30 10:30-16:00 16:00-17:00 17:00-01:00 01 Apr 98 01:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-12:00 12:00-16:30 16:30-18:00 18:00-23:30 23:30-06:00 02 Apr 98 06:00-17:00 17:00-18:00 18:00-02:00 03 Apr 98 02:00-06:00 Duration lhr 3-3/4 hr 2-1/4 hr 4-3/4 hr 1/4 hr 1/2 hr 7-3/4 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr 6hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 4hr 2 hr 1 hr 1/2 hr 1-1/2 hr 1-1/2 hr 7-1/2 hr 4 hr 1/4 hr 3/4 hr 6hr 2-1/2 hr 1-1/2 hr 1 hr 1/4 hr 3-3/4 hr 8 hr 1/4 hr 1-3/4 hr 2-1/2 hr 5-1/2 hr 1 hr 8 hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 5-1/2 hr 6-1/2 hr llhr 1 hr 8 hr 4hr Activity Circulated at 11328.0 ft Monitor wellbore pressures Circulated at 11328.0 ft Monitor wellbore pressures Held safety meeting Circulated at 11328.0 ft Monitor wellbore pressures Circulated at 11328.0 ft Ran Tubing to 11860.0 ft (4-1/2in OD) Circulated at 11860.0 ft Washed to 12270.0 ft Circulated at 12270.0 ft Washed to 12315.0 ft Held safety meeting Circulated at 12270.0 ft Washed to 11323.0 ft Circulated at 11323.0 ft Circulated at 11323.0 ft Laid down 872.0 ft of Tubing Serviced Crown block Laid down 1701.0 ft of Tubing Serviced Tubing handling equipment Laid down 9750.0 ft of Tubing Tested All rams Held safety meeting Tested Annular preventor Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Held safety meeting Conducted electric cable operations Ran Tubing to 2632.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 3562.0 ft (2-7/8in OD) Rigged up Swivel Pulled Tubing in stands to 3717.0 ft Rigged down Bell nipple Ran Drillpipe to 3638.0 ft (3-1/2in OD) Installed Swivel Ran Drillpipe to 3760.0 ft (3-1/2in OD) Circulated at 3730.0 ft Circulated at 3730.0 ft Repaired Swivel Pulled Drillpipe in stands to 3730.0 ft Pulled Drill collar in stands to 240.0 ft Ran Drillpipe in stands to 3678.0 ft Repaired Swivel Singled in drill pipe to 4535.0 ft R.I.H. to 7840.0 ft R.I.H. to 12290.0 ft R.I.H. to 12290.0 ft Circulated at 12050.0 ft Laid down 1050.0 ft of Drillpipe Progress Report Facility M Pt J Pad Well MPJ- 18 Rig Nabors 5S Page 4 Date 01 June 98 Date/Time 06:00-09:00 09:00-17:00 17:00-00:30 04 Apr 98 00:30-04:30 04:30-05:30 05:30-06:00 06:00-12:00 12:00-15:00 15:00-16:30 16:30-18:00 18:00-06:00 05 Apr 98 06:00-11:30 11:30-18:00 18:00-19:30 19:30-03:00 06 Apr 98 03:00-06:00 06:00-11:30 11:30-16:30 16:30-23:30 23:30-01:30 07 Apr 98 01:30-04:00 04:00-06:00 06:00-17:00 17:00-18:00 18:00-20:30 20:30-06:00 08 Apr 98 06:00-07:30 07:30-10:00 10:00-11:00 11:00-15:00 15:00-18:00 18:00-23:00 23:00-01:30 09 Apr 98 01:30-06:00 06:00-07:30 07:30-09:30 09:30-10:30 10:30-12:30 12:30-13:30 13:30-15:30 15:30-18:00 18:00-20:30 20:30-21:30 21:30-22:00 22:00-00:00 10Apr 98 00:00-06:00 Duration 3hr 8 hr 7-1/2 hr 4 hr lhr 1/2 hr 6 hr 3 hr 1-1/2 hr 1-1/2 hr 12hr 5-1/2 hr 6-1/2 hr 1-1/2 hr 7-1/2 hr 3 hr 5-1/2 hr 5hr 7hr 2 hr 2-1/2 hr 2 hr llhr 1 hr 2-1/2 hr 9-1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 4hr 3 hr 5hr 2-1/2 hr 4-1/2 hr 1-1/2 hr 2 hr 1 hr 2hr 1 hr 2 hr 2-1/2 hr 2-1/2 hr lhr 1/2 hr 2hr 6 hr Activity Pulled Tubing in stands to 4536.0 ft Laid down 4536.0 ft of 3-1/2in OD drill pipe Conducted electric cable operations Ran Tubing in stands to 4773.0 ft Circulated at 4773.0 ft Ran Tubing in stands to 5400.0 ft Ran Tubing in stands to 12100.0 ft Circulated at 12100.0 ft Pulled Tubing in stands to 11850.0 ft Pulled Tubing in stands to 10200.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 5375.0 ft Ran Tubing in stands to 5896.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 5700.0 ft Ran Tubing in stands to 7075.0 ft Pulled Tubing in stands to 0.0 ft Ran Drillpipe to 0.0 ft (3-1/2in OD) Serviced Block line Singled in drill pipe to 0.0 ft Singled in drill pipe to 2000.0 ft Ran Drillpipe to 9050.0 ft (3-1/2in OD) Repaired Draw works Ran Drillpipe to 11960.0 ft (3-1/2in OD) Laid down 10750.0 ft of 3-1/2in OD drill pipe Laid down 11960.0 ft of 3-1/2in OD drill pipe Laid down 0.0 ft of 3-1/2in OD drill pipe Worked on BOP - Pipe ram Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 2450.0 ft Ran Tubing in stands to 9000.0 ft Serviced Other sub-surface equipment Ran Tubing in stands to 11892.0 ft Installed Tubing hanger Rigged down All rams Rigged up Xmas tree Tested Xmas tree Rigged down Xmas tree Rigged up All rams Removed Tubing hanger Rigged down All rams Installed Xmas tree Tested Tubing hanger Tested All tree valves Rig moved 25.00 % MILNE POINT, ALASKA TO: B. Hill FROM: L.M. Hinkel Well Name: MPJ-18 Main Category: Initial Completion Sub Category: Operation Date: Date: 103/25/98 Note: The Kuparuk "B" was not perforated during the initial completion 'due to carb-o-lite and debris on the Iow side of the hole which would not allow the perforating gun to be run to the proper depth. Decision not to try further attempts was made by BH/LH. Tie in log/date: Western Atlas GR/CCL 03/25/98 TD Tag: None Charge type: Jumbo Jet Big-Hole .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Dia. Shot Density KUPARUK "A" 12076 12096 4.5" 6 Orientation Phasing 90° Random TO: FROM: DATE: BP EXPLORATION (ALASKA) INC. Milne Point Unit Bill Hill / Trina Cooper J. Fox 03/26/98 RE: J-18 DATA FRAC, SCALE INHIBITION TREATMENT, SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak MPU FILE COPY JOB SUMMARY AND FI{AC 160.2 M# of proppant was placed behind casing of which 105,800 was 20/40 Carbolite, followed by 54.4 M# of 16/20 Carbolite. All of the 16/20 was coated with Halliburton PropLok resin coating at 0.375 gal. / 100 lbs. of proppant. The treatment went through design (136.8 M#) and into excess (until 16/20 was gone) and saw little or no net pressure build. The slurry was underdisplaced by 10 bbl. There was 440 psi of pressure build in the last 9 minutes of pumping but this coincided 'with the 90 ppt HEC gel hitting the formation and is suspected to be some sort viscosity effect and not actual TSO. 228 bbl. 40 ppt XL guar gel was pumped into the formation as a injectivity test. It was displaced to the perforations at max rate of up to 30 bpm. Once the gel reached the perforations the pump was reduced to and maintained at 20 bpm. The initial ramp was slow due to high pressures. Once the formation parted the well treated at a relatively high 0.87 psi / ft fracture gradient. Near wellbore friction pressure was 320 psi and a scour treatment was deemed unnecessary. Once the fracture had a chance to close a 300 bbl. XL gel data frac was performed at 20 bpm. The falloff was analyzed and the original design was used. Notes: · The PropLok resin was dyed blue. · Adomite regain was used as FLA in both the data frac and frac pad at 40 ppt. · 550 gal of B-34 scale inhibitor was used in the displacement of the data frac. · Unable to get fluid out of the #6 tank. Valves worked fine. There appears to be some sort of blockage (ice plug?) in the snorkle. Did not cause a problem as we had extra fluid on location. · Annulus was loaded with 9.8 ppg brine initially. This might have got thinned out with time. The 90 ppt HEC was measured at the MI Drlg Fluid plant before shipping out at 204 (300 rpm and 80 deg.) · Once PropLok was started the gel was switched to a 90 ppt HEC gel to prevent incompatibility of PropLok surfactant with guar. It was intended that approx. 20,000 lbs of 16-20 would be pumped before switching to HEC however due to a miscommunication HEC and PropLok was started at the beginning of the 16/20 proppant. · The shut down just prior to going into the perforations with the data frac gel was inadvertently omitted. · Wellbore fluids had to be weighted up to 10.9 ppg even 30 hrs after the end of the frac. · Job was delayed approx. 13 due to lack of vac trucks, and another 6 hrs. due Dowell crew change out. 04/03/98 9:01 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL PUMP ~UMMARY ~-~MMENTS INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm psi psi psi/ft max. / 20 228 30.3 2833 2510 320 0.86 DATA FRAC Bbls Bbls XL gel Time XL gel on Final lAP, ISIP, NWB friction, Treat grad, Pumped to Perfs perfs psi psi psi : psi/ft 320 300 16:15 2716 2521 195 0.87 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind pipe, behind pipe, - Liner Sand, rubber left in Job was M# M# M# M# M# hole? /size /size Flush 163,100 105,800 54,400 160,200 2900 not appl. 20/40 Carbo 16/20 Carbo Ft of sand Estimated Final ISIP, psi ISIP Incr Actual TSO, design, TSO, in Pipe. sand top lAP, psi over datafrac sand:pad min Nolte ratio Plot 400' 11,937' 3122 3021 600 26.6 n/a DATE/TIME OPERATIONS SUMMARY 03/25/98 temp = +2 deg., ENE 10 mph wind, -15 deg WC. ,2315 Pre-job safety meeting. 03/16/98 0017 PT - one slight leak 0056 Re-PT to 8500 psig. 0106 Start pumping injectivity test 0127 S/D pumps and monitor pressure falloff. 0217 Start Data Frac. 0234 Go to flush. 0243 S/D pumps and monitor pressure falloff. 0422 Start frac 0522 Go to flush 0532 S/D pumps and monitor pressure falloff TIME RATE ANNP WHP STAGE BPM PSIG PSIG BBL 03/26/98 PUMPING SUMMARY CUM COMMENTS BBL INJECTIVITY TEST DISPLACEMENT = 199.9 BBLS 0107 0 0 36 0 0 Start pumping. i0108 4.0 0 2320 4 4 0110 25 304 5474 21 21 0111 25.5 3009 5447 58 0112 27 2956 5374 88 No. 1 pump inoperable - brake wouldn't release. 0113 28.6 2930 5117 115 0114 29.6 2919 4352 142 0115 29.9 2919 4550 177 0116 30/20 2886 200 Slow rate down as gel reaches perfs. 0117 19.9 3077 4499 228 / 0 228 Switch to slick KCl water 0119 20.1 3045 4527 262 0121 20.1 3000 4458 302 0124 20.2 2945 4156 320 0126 19.9 2895 4010 403 0127 20.1 /0 2833 3946 200.3 428.3 S/D pumps. Monitor pressure falloff. IA ISlP = 2510 psig, Tbg. = 2960 psig 0129 0 2388 2856 0133 0 2276 2742 0137 0 2183 2655 0140 0 2124 2586 0145 0 2042 2504 0150 0 1974 2435 0200 0 1822 2279 PUMPING SUMMARY TIME RATE ANNP ~IP STAGE CUM ~C~'~MENTS BPM PSIG PSIG BBL BBL 0210 0 1639 2096 DATA FRAC 0217 0/20 1584 2037 428.3 Start datafrac. 0218.5 20.2 2796 3909 11 439 Atrate 0220 20.1 2668 3767 480 0222 20.1 2674 3744 516 0224 19.9 2694 3813 556 0226 20.2 2670 3790 600 0228 20.1 2655 3808 640 0230 20.1 2698 3872 675 0232 20.1 2736 4015 715 0234 19.9 2724 4101 320 748 Goto slick KCI waterflush (w/scaleinhibitor added) 0236 20.1 2731 4033 793 0240 20.1 2716 3959 875 0242 20.2 2723 3845 914 0243 20/0 2740 3827 929.1 S/D pumps- monitorpressurefalloff, lA ISIP = 2521 psi 0245 0 2502 2971 0250 0 2403 2879 0255 0 2335 2806 0300 0 2256 2728 0310 0 2135 2600 0320 0 2024 2481 FRAC 0422 0 1377 1831 0 0 Prepare to start pumping 40 ppt XL gel pad. 0425.5 20 2776 3810 11 11 At rate. 0427 20.4 2696 3744 48 48 0430 20.1 2557 3662 104 104 0434 12 / 20 2516 3925 159 Pumps had to be slowed down to get proper suction now coming back up to rate. 0436 19.9 2513 4010 200 200 Pad on perfs. 0439.5 20.6 2657 3982 266 266 Start proppant ,0442 20.1 2705 3822 43 316 0445 20.2 2661 3904 378 0448 19.9 2679 4179 440 0450 20.1 2685 4248 473 Sand on perfs. Start of 2 ppg at surface. PUMPING SUMMARY TIME RATE ANNP ~w-~P STAGE CUM ~COMMENTS BPM PSIG PSIG BBL BBL 455 20.2 2760 4472 574 457 19.7 2795 4551 615 459 20.1 2811 4527 650 502 20.1 2811 4495 709 4 ppg on perfs. 506.5 19.9 2807 4509 807 6 ppg on perfs. 509 19.9 2804 4509 864 7 ppg on perfs. . 513 19.6 2815 4623 933 Start 90 ppt HEC gel and PropLok. 517 19.7 2844 4902 1005 519 19.9 2826 5275 1055 10 ppg on perfs. 522 19.9 2800 1122 Call flush 524 19.7 2837 5740 1160 526.5 19.9 2897 5474 1196 527.5 20.2 2936 5259 1219 528.5 79.9 2991 4925 1242 530 20.2 3020 4853 1262 0531 20.23 3053 4788 1290 0532 20 / 0 3122 4779 1311.4 S/D pumps. IA ISIP = 3021 psi. 0533 0 2981 3474 1311.4 0534 0 2939 3433 0535 0 3401 2904 Page 6 ' FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 929 Bbls FRAC: 1311 Bbls 224O FLUID ADDITIVES TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME YF140D used for the majority of the frae. Additives: 9.2 gpt J877 guar LGC, 1 gpt F75N surfactant, 0.3 lbs/mgal M275 bactericide, 5 gpt J899 activator, 2.2 Lbs/mgal L 10 Boric acid, and 1 lbs/mgal J218 AP breaker. ~ Last 57.3 M# of prop was 16/20 carbolite mixed or coated with Halliburton PropLok 12 on the fly. Carrying fluid for this was 90# HEC with 0.5 gpt J-134 enzyme breaker. DS surfactant F75N was stopped 1 mgal before the Halliburton surfactant ES5 was began at 2 gpt. Halliburton PropLok 12 was added at 3/8 gal per 100# of proppant. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 MWD SURVEY JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/t00 NORTH/SOUTH EAST/WEST SECT. .00 .00 -63.83 0 0 N .00 E .00 .00N .00E .00 112.00 112.00 48.17 0 0 N .00 E .00 .00N .00E .00 154.22 154.22 90.39 0 7 N 43.37 E .29 .03N .03E .02 239.60 239.60 175.77 0 9 S 65.34 E- .20 .05N .20E -.01 331.89 331.89 268.06 0 27 N 39.06 E .49 .28N .55E .11 422.60 422.59 358.76 1' 7 N 9.69 E .83 511.63 511.58 447.75 2 0 N 5.10 W 1.08 602.39 602.21 538.38 3 58 N 15.96 W 2.26 693.15 692.61 628.78 5 56 N 20.14 W 2.19 787.15 785.93 722.10 7 43 N 20.92 W 1.91 1.44N .93E 1.10 3.84N .94E 3.40 8.45N .07W 8.09 15.89N 2.55W 15.93 26.36N 6.48W 27.10 877.82 875.57 811.74 9 28 N 24.54 W 2.01 969.35 965.59 901.76 11 18 N 30.49 W 2.32 1063.57 1057.59 993.76 13 37 N 36.93 W 2.87 1154.23 1145.16 1081.33 16 17 N 38.29 W 2.97 1247.60 1234.06 1170.23 19 16 N 39.33 W 3.21 38.84N 11.76W 40.58 53.42N 19.44W 56.78 70.26N 30.80W 76.22 88.79N 45.11W 98.14 lll.00N 63.00W 124.63 1338.92 1319.36 1255.53 22 31 N 41.34 W 3.63 1430.72 1403.26 1339.43 25 21 N 41.82 W 3.09 1522.76 1485.98 1422.15 26 38 N 40.34 W 1.58 1614.89 1568.05 1504.22 27 23 N 40.54 W .81 1706.64 1648.77 1584.94 29 21 N 41.18 W 2.16 135.80N 84.11W 154.55 163.65N 108.83W 188.45 194.07N 135.33W 225.32 225.92N 162.48W 263.76 258.88N 191.00W 303.66 1800.15 1729.67 1665.84 30 49 N 40.62 W 1.60 1892.39 1808.23 1744.40 32 22 N 42.84 W 2.10 1984.29 1884.27 1820.44 35 57 N 43.92 W 3.95 2078.46 1958.30 1894.47 40 22 N 40.70 W 5.16 2171.20 2027.41 1963.58 43 15 N 39.98 W 3.14 294.31N 221.69W 346.55 330.36N 253.86W 390.47 367.84N 289.31W 436.73 410.90N 328.40W 489.40 458.03N 368.41W 546.23 2263.68 2093.39 2029.56 45 43 N 43.70 W 3.89 2355.92 2157.05 2093.22 46 58 N 43.92 W 1.37 2448.36 2218.70 2154.87 49 19 N 43.22 W 2.60 2540.72 2277.97 2214.14 50 49 N 40.85 W 2.54 2632.61 2334.83 2271.00 52 42 N 38.97 W 2.61 506.26N 411.66W 605.06 554.43N 457.87W 664.69 604.32N 505.31W 726.34 656.92N 552.71W 790.57 712.28N 599.00W 857.11 2723.81 2388.38 2324.55 55 22 N 39.71 W 3.00 2815.78 2438.81 2374.98 58 6 N 37.'72 W 3.48 2908.76 2486.69 2422.85 59 54 N 37.51 W 1.93 2972.85 2518.84 2455.01 59 52 N 38.17 W .89 3062.76 2561.89 2498.06 62 54 N 35.81 W 4.07 769.36N 645.80W 925.45 829.37N 693.87W 996.96 892.50N 742.52W 1071.61 936.29N 776.53W 1123.47 999.33N 823.99W 1197.70 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 MWD SURVEY JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3154.38 2603.43 2539.60 3246.16 2643.69 2579.86 3338.07 2680.94 2617.11 3429.89 2714.95 2651.12 3522.27 2745.83 2682.00 COURS INCLN DG MN 63 10 64 47' 67 23 69 7 71 48 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N 36.51 W .74 1065.26N 872.17W N 35.98 W 1.84 1131.77N 920.93W N 36.76 W 2.93 1199.42N 970.75W N 36.37 W- 1.94 1267.91N 1021.55W N 36.90 W 2.95 1337.77N 1073.50W VERT. SECT. 1274.89 1352.82 1432.14 1512.56 1594.62 3616.04 2773.15 2709.32 3707.68 2797.47 2733.64 3800.75 2821.96 2758.13 3891.27 2846.24 2782.41 3983.78 2871.49 2807.66 ' 74 18 74 55 74 33 74 19 74 0 N 36.59 W 2.67 1409.63N 1127.15W N 39.46 W 3.10 1479.22N 1181.58W N 38.27 W 1.30 1549.13N 1237.92W N 41.79 W 3.76 1615.89N 1293.99W N 41.46 W .49 1682.42N 1353.11W 1679.09 17 61.62 1845.03 1925.34 2006.33 4075.88 2897.19 2833.36 4170.33 2925.30 2861.47 4261.19 2953.32 2889.49 4353.09 2981.02 2917.19 4444.90 3008.87 2945.04 73 35 71 45 72 19 72 35 72 4 N 42.49 W 1.16 1748.16N 1412.26W N 42.69 W 1.96 1814.54N 1473.27W N 41.98 W .97 1878.43N 1531.48W N 41.78 W .37 1943.67N 1589.97W N 42.58 W 1.00 2008.50N 1648.71W 2086.58 2167.98 2246.18 2325.76 2405.01 4537.08 3037.68 2973.84 4632.91 3066.81 3002.98 4726.19 3093.70 3029.87 4821.54 3121.48 3057.65 4917.21 3150.14 3086.31 71 30 73 5 73 23 72 43 72 24 N 42.46 W .64 2073.04N 1707.89W N 41.86 W 1.77 2140.70N 1769.16W N 41.59 W .42 2207.37N 1828.61W N 41.49 W .70 2275.64N 1889.09W N 42.23 W .81 2343.62N 1950.00W 2484.12 2566.83 2648.04 2731.10 2814.00 5012.57 3178.26 3114.43 5107.89 3205.85 3142.02 5202.92 3233.88 3170.05 5299.15 3263.03 3199.20 5394.42 3292.72 3228.89 73 18 73 3 72 37 72 7 71 33 N 40.46 W 2.01 2412.02N 2010.18W N 40.-40 W .26 2481.47N 2069.35W N 40.70 W .55 2550.46N 2128.38W N 40.80 W .53 2619.94N 2188.25W N 40.50 W .66 2688.62N 2247.22W 2897.10 2980.90 3064.22 3148.24 3231.24 5490.62 3321.98 3258.15 5586.08 3349.61 3285.78 5681.23 3377.41 3313.58 5776.87 3406.27 3342.44 5872.35 3434.59 3370.76 73 1 73 19 72 41 72 10 73 19 N 39.86 W 1.64 2758.63N 2306.34W N 39.46 W .52 2828.97N 2364.65W N 39.35 W .67 2899.28N 2422.42W N 39.77 W .69 2969.58N 2480.49W N 39.61 W 1.22 3039.74N 2538.72W 3315.56 3399.96 3484.17 3568.45 3652.65 5968.14 3462.17 3398.33 6063.51 3490.14 3426.31 6158.94 3518.82 3454.99 6253.90 3547.81 3483.98 6347.23 3576.66 3512.83 73 13 72 40 72 20 72 6 71 52 N 38.62 W 1.00 3110.91N 2596.59W N 38.94 W .66 3181.99N 2653.69W N 39.18 W .42 3252.66N 2711.05W N 39.07 W .27 3322.81N 2768.11W N 39.07 W .25 3391.72N 2824.05W 3737.71 3822.45 3906.88 3990.73 4073.06 SPERRY-SUN DRILLING SERVICES ANCHORAGE 'ALASKA PAGE 3 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 MWD SURVEY JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6441.94 3604.83 3541.00 73 30 N 38.67 W 1.77 3462.12N 2880.79W 4157.04 6537'.42 3632.29 3568.46 73 3 N 38.86 W .51 3533.42N 2938.04W 4242.05 6632.78 3660.23 3596.40 72 52 N 38.09 W .80 3604.80N 2994.77W 4326.96 6727.69 3688.23 3624.40 72 48 N 38.81 W- .73 3675.82N 3051.16W 4411.44 6822.19 3716.40 3652.57 72 30 N 38.83 W .32 3746.10N 3107.71W 4495.26 6918.87 3745.60 3681.77 72 19 N 38.74 W .21 3817.94N 3165.44W 4580.92 7015.31 3775.19 3711.36 71 55 N 38.54 W .46 3889.63N 3222.75W 4666.31 7109.21 3805.22 3741.39 70 46 N 38.50 W 1.24 3959.24N 3278.16W 4749.15 7205.33 3837.18 3773.35 70 22 N 38.70 W .45 4030.08N 3334.71W 4833.51 7300.21 3869.45 3805.62 69 50 N 38.44 W .62 4099.84N 3390.34W 4916.56 7395.48 3903.11 3839.28 68 46 N 36.99 W 1.82 4170.33N 3444.86W 4999.98 7490.70 3939.22 3875.39 66 39 N 35..41 W 2.70 4241.42N 3496.90W 5083.24 7586.43 3977.59 3913.76 66 4 N 35.59 W .63 4312.82N 3547.83W 5166.47 7681.24 4016.27 3952.44 65 46 N 35.70 W .34 4383.16N 3598.27W 5248.56 7776.89 4056.15 3992.32 64 56 N 33.42 W 2.33 4454.74N 3647.58W 5331.49 7872.48 4096.83 4033.00 64 40 N 33.70 W .40 4526.82N 3695.40W 5414.45 7968.09 4138.07 4074.24 64 13 N 33.14 W .71 4598.81N 3742.91W 5497.24 8063.50 4179.86 4116.03 63 49 N 34.04 W .94 4670.26N 3790.36W 5579.50 8159.17 4222.67 4158.84 63 0 N 34.81 W 1.12 4740.83N 3838.72W 5661.19 8189.86 4236.65 4172.82 62 47 N 34.92 W .79 4763.25N 3854.34W 5687.21 8292.29 4284.30 4220.47 61 45 N 34.07 W 1.25 4837.97N 3905.69W 5773.74 8390.90 4331.65 4267.82 60 50 N 32.35 W 1.79 4910.33N 3953.06W 5856.84 8486.79 4379.14 4315.31 59 46 N 30.99 W 1.67 4981.21N 3996.80W 5937.46 8582.25 4428.02 4364.19 58 37 N 29.01 W 2.15 5052.20N 4037.79W 6017.38 8677.91 4479.26 4415.43 56 35 N 28.35 W 2.19 5123.06N 4076.56W 6096.50 8773.56 4533.05 4469.22 54 57 N 26.61 W 2.29 5193.20N 4113.05W 6174.28 8869.18 4589.01 4525.18 53 24 N 25.31 W 1.96 5262.89N 4146.99W 6250.88 8964.81 4646.61 4582.78 52 31 N 23.30 W 1.91 5332.45N 4178.42W 6326.61 9059.06 4704.75 4640.92 51 17 N 21.61 W 1.93 5400.99N 4206.75W 6400.45 9154.47 4765.30 4701.47 49 54 N 19.84 W 2.04 5469.92N 4232.85W 6474.02 9249.20 4827.04 4763.21 48 45 N 18.98 W 1.40 5537.68N 4256.73W 6545.81 9345.35 4891.19 4827.36 47 31 N 16.49 W 2.31 5605.87N 4278.55W 6617.39 9441.13 4956.14 4892.31 47 4 N 18.18 W 1.38 5673.06N 4299.52W 6687.78 9536.84 5021.53 4957.70 46 43 N 17.'49 W .64 5739.59N 4320.93W 6757.66 9631.81 5087.87 5024.04 44 37 N 17.35 W 2.21 5804.41N 4341.27W 6825.60 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 MWD SURVEY JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9725.42 5154.98 5091.15 43 46 N 14.42 W 2.36 5867.16N 4359.14W 6890.83 9821.20 5225.11 5161.28 42 3 N 14.22 W 1.80 5930.35N 4375.27W 6955.96 9916.51 5296.78 5232.95 40 23 N 12.78 W 2.02 5991.41N 4389.94W 7018.64 10012.06 5369.92 5306.09 39 43 N 12.68 W .70 6051.38N 4403.49W 7079.94 10106.52 5442.57 5378.74 39 43 N 11.07 W 1.09 6110.45N 4415.91W 7140.05 10202.28 5516.76 5452.93 38 42 N 9.00 W 1.73 6170.06N 4426.47W 7200.13 10297.94 5591.77 5527.94 38 0 N 6.30 W 1.90 6228.88N 4434.38W 7258.66 10393.23 5667.16 5603.33 37 24 N 3.54 W 1.88 6286.92N 4439.39W 7315.60 10487.83 5742.84 5679.01 36 20 N 1.13 W 1.90 6343.61N 4441.72W 7370.47 10583.10 5819.86 5756.03 35 46 N 1.64 E 1.81 6399.67N 4441.48W 7423.97 10677.99 5896.92 5833.09 35 35 N 4.88 E 2.00 6454.92N 4438.33W 7475.84 10766.42 5968.77 5904.94 35 43 N 7.64 E 1.82 6506.15N 4432.71W 7523.14 10869.23 6052.16 5988.33 35 52 N 9.63 E 1.14 6565.59N 4423.68W 7577.29 10964.47 6129'.73 6065.90 35 3 N 13.33 E 2.41 6619.72N 4412.71W 7625.78 11059.38 6207.75 6143.92 34 22 N 12.62 E .84 6672.39N 4400.57W 7672.54 11153.59 6285.71 6221.88 33 55 N 12.15 E .55 6724.03N 4389.23W 7718.56 11248.67 6364.82 6300.99 33 28 N 12.12 E .46 6775.61N 4378.14W 7764.58 11343.83 6444.57 6380.74 32 37 N 10.79 E 1.17 6826.47N 4367.82W 7810.15 11437.51 6523.73 6459.90 32 1 N 11.20 E .69 6875.65N 4358.27W 7854.32 11533.70 6605.76 6541.93 30 56 N 10.18 E 1.25 6925.00N 4348.95W 7898.74 11630.07 6688.29 6624.46 31 14 N 10.98 E .53 6973.92N 4339.81W 7942.80 11727.54 6772.07 6708.24 30 13 N 10.68 E 1.06 7022.83N 4330.45W 7986.79 11823.30 6855.21 6791.38 29 16 N 9.98 E 1.06 7069.57N 4321.93W 8028.94 11919.01 6938.95 6875.12 28 38 N 10.-19 E .67 7115.19N 4313.81W 8070.15 12011.30 7020.31 6956.48 27 41 N 9.66 E 1.06 7158.10N 4306.30W 8108.94 12108.63 7106.85 7043.02 26 46 N 9.94 E .95 7201.98N 4298.72W 8148.64 12202.57 7191.15 7127.32 25 36 N 10.01 E 1.25 7242.81N 4291.54W 8185.54 12295.85 7275.53 7211.70 24 52 N 10.18 E .79 7281.96N 4284.57W 8220.90 12390.53 7361.67 7297.84 24 8 N 10.57 E .78 7320.59N 4277.50W 8255.74 12455.00 7420.50 7356.67 24 8 N 10.57 E .00 7346.52N 4272.66W 8279.09 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8498.65 FEET AT NORTH 30 DEG. 10 MIN. WEST AT MD = 12455 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 342.87 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 12,455.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -63.83 1000.00 995.61 931.78 2000.00 1896.93 1833.10 3000.00 2532.27 2468.44 4000.00 2875.97 2812.14 .00 N .00 E .00 58.70 N 22.70 W 4.39 4.39 374.57 N 295.73 W 103.07 98.68 954.92 N 790.99 W 467.73 364.65 1694.10 N 1363.43 W 1124.03 656.31 5000.00 3174.65 3110.82 6000.00 3471.36 3407.53 7000.00 3770.44 3706.61 8000.00 4151.95 4088.12 9000.00 4668.02 4604.19 2402.85 N 2002.37 W 3134.75 N 2615.63 W 3878.25 N 3213.68 W 4622.87 N 3758.62 W 5358.10 N 4189.46 W 1825.35 701.31 2528.64 703.29 3229.56 700.92 3848.05 618.49 4331.98 483.94 10000.00 5360.64 5296.81 11000.00 6158.81 6094.98 12000.00 7010.31 6946.48 12455.00 7420.50 7356.67 6043.86 N 4401.80 W 6639.58 N 4408.00 W 7152.92 N 4307.18 W 7346.52 N 4272.66 W 4639.36 307.37 4841.19 201.83 4989.69 148.51 5034.50 44.81 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -63.83 .00 N .00 63.83 63.83 .00 .00 N .00 163.83 163.83 100.00 .05 N .04 263.83 263.83 200.00 .02 N .26 363.83 363.83 300.00 .49 N .71 E .00 E .00 .00 E .00 .00 E .00 .00 E .00 .00 463.85 463.83 400.00 2.27 N 1.05 563.92 563.83 500.00 5.88 N .67 664.21 663.83 600.00 13.07 N 1.52 764.84 763.83 700.00 23.56 N 5.41 865.91 863.83 800.00 37.06 N 10.95 E .02 .02 E .09 .07 W .38 .29 W 1.01 .63 W 2.08 1.07 967.56 963.83 900.00 53.12 N 19.27 1070.00 1063.83 1000.00 71.50 N 31.74 1173.72 1163.83 1100.00 93.17 N 48.58 1279.25 1263.83 1200.00 119.27 N 69.87 1387.34 1363.83 1300.00 150.15 N 96.79 W 3.73 1.64 W 6.17 2.45 W 9.89 3.71 W 15.42 5.53 W 23.51 8.09 1497.98 1463.83 1400.00 185.60 N 128.14 1610.14 1563.83 1500.00 224.26 N 161.06 1723.92 1663.83 1600.00 265.26 N 196.58 1839.92 1763.83 1700.00 309.78 N 234.95 1959.20 1863.83 1800.00 357.33 N 279.24 W 34.15 10.64 W 46.31 12.16 W 60.09 13.78 W 76.09 16.00 W 95.37 19.28 2085.76 1963.83 1900.00 414.51 N 331.50 2221.77 2063.83 2000.00 484.49 N 391.45 2365.86 2163.83 2100.00 559.66 N 462.91 2518.33 2263.83 2200.00 643.79 M 541.36 2681.28 2363.83 2300.00 742.58 N 623.69 W 121.93 26.55 W 157.94 36.01 W 202.03 44.09 W 254.50 52.47 W 317.45 62.94 2863.29 2463.83 2400.00 861.32 N 718.57 3067.02 2563.83 2500.00 1002.41 N 826.21 3294.72 2663.83 2600.00 1167.43 N 947.02 3581.60 2763.83 2700.00 1383.01 N 1107.39 3955.97 2863.83 2800.00 1662.38 N 1335.41 W 399.46 82.01 W 503.19 103.73 W 630.89 127.70 W 817.77 186.88 W 1092.14 274.38 4295.79 2963.83 2900.00 1902.94 N 1553.53 4622.67 3063.83 3000.00 2133.40 N 1762.62 4962.57 3163.83 3100.00 2375.67 N 1979.02 5301.76 3263.83 3200.00 2621.82 N 2189.87 5635.46 3363.83 3300.00 2865.49 N 2394.70 W 1331.96 239.82 W 1558.84 226.87 W 1798.74 239.90 W 2037.93 239.20 W 2271.63 233.70 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 7 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5973.91 3463.83 3400.00 6305.97 3563.83 3500.00 6645.01 3663.83 3600.00 6978.68 3763.83 3700.00 7283.88 3863.83 3800.00 3115.23 N 2600.04 3361.28 N 2799.33 3613.99 N 3001.98 3862.39 N 3201.05 4087.83 N 3380.81 W 2510.08 238.45 W 2742.14 232.06 W 2981.18 239.04 W 3214.85 233.67 W 3420.05 205.21 7552.49 3963.83 3900.00 7795.04 4063.83 4000.00 8027.15 4163.83 4100.00 8249.01 4263.83 4200.00 8456.38 4363.83 4300.00 4287.59 N 3529.77 4468.46 N 3656.64 4643.23 N 3772.10 4806.39 N 3884.32 4958.69 N 3983.27 W 3588.66 168.60 W 3731.21 142.55 W 3863.32 132.11 W 3985.18 121.86 W 4092.55 107.38 8649.88 4463.83 4400.00 8826.91 4563.83 4500.00 8993.12 4663.83 4600.00 9152.18 4763.83 4700.00 9304.82 4863.83 4800.00 5102.46 N 4065.45 5232.21 N 4132.47 5353.08 N 4187.30 5468.28 N 4232.25 5577.20 N 4270.07 w 4186.05 93.50 w 4263.08 77.03 w 4329.29 66.21 w 4388.35 59.06 w 4440.99 52.64 9452.42 4963.83 4900.00 9598.01 5063.83 5000.00 9737.68 5163.83 5100.00 9873.17 5263.83 5200.00 10004.14 5363.83 5300.00 5680.91 N 4302.10 5781.73 N 4334.18 5875.37 N 4361.25 5963.96 N 4383.66 6046.45 N 4402.38 W 4488.59 47.60 W 4534.18 45.59 W 4573.85 39.67 W 4609.34 35.48 W 4640.31 30.98 10134.16 5463.83 5400.00 10262.48 5563.83 5500.00 10389.03 5663.83 5600.00 10513.89 5763.83 5700.00 10637.29 5863.83 5800.00 6127.79 N 4419.30 6207.18 N 4431.99 6284.37 N 4439.23 6359.05 N 4442.02 6431.31 N 4440.30 W 4670.33 30.02 W 4698.65 28.32 W 4725.20 26.55 W 4750.06 24.85 W 4773.46 23.40 10760.33 5963.83 5900.00 10883.63 6063.83 6000.00 11006.11 6163.83 6100.00 11127.22 6263.83 6200.00 11247.49 6363.83 6300.00 6502.63 N 4433.18 6573.91 N 4422.27 6642.97 N 4407.21 6709.65 N 4392.32 6774.97 N 4378.27 W 4796.50 23.04 W 4819.80 23.30 W 4842.28 22.48 W 4863.39 21.11 W 4883.66 20.27 11366.70 6463.83 6400.00 11484.76 6563.83 6500.00 11601.46 6663.83 6600.00 11718.00 6763.83 6700.00 11833.18 6863.83 6800.00 6838.59 N 4365.51 6900.18 N 4353.45 6959.35 N 4342.63 7018.12 N 4331.34 7074.33 N 4321.09 W 4902.87 19.21 W 4920.93 18.06 W 4937.63 16.70 W 4954.17 16.54 W 4969.35 15.18 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80033 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11947.35 6963.83 6900.00 12060.44 7063.83 7000.00 12172.28 7163.83 7100.00 12282.96 7263.83 7200.00 12392.89 7363.83 7300.00 7128.56 N 4311.41 W 4983.52 14.17 7180.60 N 4302.47 W 4996.61 13.09 7229.92 N 4293.82 W 5008.45 11.84 7276.62 N 4285.53 W 5019.13 10.68 7321.54 N 4277.32 W 5029.06 9.94 12455.00 7420.50 7356.67 7346.52 N 4272.66 W 5034.50 5.44 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA . PAGE 1 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 9/98 DATE OF SURVEY: 121397 Y~GNETIC SINGLE SHOT SURVEY JOB NUMBER: AKEI80051 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11533.70 6606.07 6542.24 30 56 N 10.18 E .00 6925.29N 4349.10W 7899.06 11630.07 6688.53 6624.70 31 23 N 11.07 E .67 6974.30N 4339.90W 7943.20 12295.80 7275.49 7211.66 24 48 N 9.66 E .99 7282.45N 4283.11W 8220.95 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8448.62 FEET AT NORTH 30 DEG. 27 MIN. WEST AT MD = 12295 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 342.87 DEG. TIE-IN SURVEY AT 11,533.70' MD CHECKSHOT AT 11,630.07' MD CHECKSHOT AT 12,295.80' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 9/98 DATE OF SURVEY: 121397 JOB NUMBER: AKEI80051 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR.COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11533.70 6606.07 6542.24 12295.80 7275.49 7211.66 6925.29 N 4349.10 W 4927.63 7282.45 N 4283.11 W 5020.31 92.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING MPU / MPJ-18 500292283400 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 9/98 DATE OF SURVEY: 121397 JOB NUMBER: AKEI80051 KELLY BUSHING ELEV. = 63.83 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11533.70 6606.07 6542.24 11601.13 6663.83 6600.00 11717.87 6763.83 6700.00 11833.29 6863.83 6800.00 6925.29 N 4349.10 W 4927.63 6959.51 N 4342.80 W 4937.30 9.67 7018.63 N 4331.29 W 4954.04 16.74 7075.23 N 4320.48 W 4969.46 15.42 11947.42 6963.83 6900.00 12060.35 7063.83 7000.00 12172.17 7163.83 7100.00 12282.94 7263.83 7200.00 12295.80 7275.49 7211.66 7129.29 N 4310.38 W 4983.59 14.13 7180.92 N 4300.95 W 4996.52 12.94 7230.17 N 4292.17 W 5008.34 11.82 7277.12 N 4284.03 W 5019.11 10.77 7282.45 N 4283.12 W 5020.31 1.20 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL Wo~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPJ-18, AK-MM-80033 May27,1998 MPJ-18: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22834-00 2" x 5" TVD ResistiviW and Gamma Ray Logs: 50-029-22834-00 2" x 5" MD Neutron & Density Logs: 50-029-22834-00 2" x 5" TVD Neutron & Density Logs: 50-029-22834-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING THE ATrACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. .~chorage, Alaska 99519-6612 Date: 5/2~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser industries, Inc. WELL LOG TRANSMITTAL To: State of Alaska May 20, 1998 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 6~r} ~ MWD Formation Evaluation Logs MPJ- 18, AK-MM-80033 1 LDWG formatted LIS tape with verification listing. API#: 50-029-22834-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: ~'/'~ '/~'~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11164 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 5/12/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPJ-18 .~ _~"~1'-")_,~ 98209 GPJCCL 980325 I -- -- -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~~~ State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 25-Mar-98 Well Name Services : Bluelines R/F Sepia Film q ,-1_ ,,o,,~ O MPJ-18 GR/CCL MARKED LINE : 1 1 0 :. Received by: i~ -- ( Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. STATE OF ALASKA ALAS~ .....OIL AND GAS CONSERVATION C-~MMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: r-lAbandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: I~ Development I--J Exploratory I-'] Stratigraphic I-1 Service 4. Location of well at surface 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM At top of productive interval 4161' NSL, 2298' WEL, SEC. 20, T13N, R10E, UM At effective depth 4281' NSL, 2313' WEL, SEC. 20, T13N, R10E, UM At total depth 4329 NSL, 2305' WEL, SEC. 20, T13N, R10E, UM 6. Datum Elevation (DF or KB) Plan KBE = 63.83' 7. Unit or Property Name Milne Point Unit 8, Well Number MPJ-18 9. Permit Number 97-220 10. APl Number 50-029-22834 11, Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Totaldepth: measured 12457 feet true vertical 7359 feet Effective depth: measured 12337 feet true vertical 7294 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 86' 20" 8216' 9 5/8" 12396' 7" Plugs (measured) Junk (measured) Cemented MD TVD Driven 115' 115' 1935 sx PF 'E', 575 sx Class 'G' 8245' 4198' 250 sx Class 'G' 12425' 7330' Perforation depth: measured Not perforated true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None ORIGINAL RECEIVED MAR 24 1998 Alaska Oil & Gas Cons. COBlfllsSion Anchorage 13. Attachments [] Description summary of propoSal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 3/2O/98 16. If proposal was verbally approved Chuck Sheevy Name of approver Contact Engineer Name/Number: John Hendrix, 564-5288 3~20/98 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Jeanne L. Haas, 564-5225 17. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed Jea,n,, L. Haas ~;¢-'/?~/~... ~>~' Title Staff Technical Assistant Commission Use Only Condition~,~(;~roval: Notify Commission so representative may w~j:ms~- ' ~,,4¢J _eG,; Plug integrity BOP Test ~ Location clearance ~::~ ¢~C~'~/' Mechanical Integrity Test Subsequent form required 10- [)aVid tN Johnston Commissioner kp~by order of the Commission ' Date ...,~.~._~/¢~ t Approval No.~ MPJ-18 Change of Approved Program 3/20/98 Verbal approval to proceed 3/20 by Chuck Sheevy of the AOGCC. Mechanical cut 7" at 120 ft. Speared and pulled casing. Speared casing stub with 5" drill pip. RU SWS and back off at 590 ft. POOH LD casing Drift run 5.9" to 3300 ft. PU new 7" and screw back into existing 7" at 590md. PT 7" to 3000 psig. PU BOP stack and set emergency slips with 150,000 # tension. Make rough cut and laydown casing stub. Install packoff and make final cut. InStall original tubing head and test. NU and test BOP PT casing to 4500 psig for 45 min. Please note casing failed at 380-384 feet and 480-483 feet. MEMORANDUM TO: · David Johns ,~ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 9,1997 THRU: Blair Wondzeil, ,~5~ FILE NO: P. I. Supervisor t~2e FROM: Larry Wade, ~. SUBJECT: Petroleum ~nsp~tor December 9,1997 awogljee.doc Confidential: Yes _, NoX, Attachment Only . BOP test I traveled to Milne Point to do a BOP test on Nabors 22E. The location was laid out in an orderly fashion. House keeping on the rig looked good. We started to test the stack but encountered a small leak on the FMC casing head where the control line ports are located. Called the FMC rep. and repaired as per his recommendation. That and a new driller created a 6 hr long test. SUMMARY: I witnessed a BOP test on Nabors 22E. 6hrs 0 failures Attachment:awogljee "' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors Rig No. Operator: BPX Well Name: MPJ-18 Casing Size: 9 5/8 Set @ 4,272 Test: Initial Weekly X Other 22E PTD# 97-220 Rep.: Rig Rep.: Location: Sec. 20 T. DATE: 12110197 Rig Ph.# 659-4374 Paul Lockwood Larry. Wurdeman 13N R. 10E Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: 'ok PTD On Location yes Standing Order Posted (Gen) . y.e.s FLOOR SAFETY VALVES: Well Sign ok Upper Kelly / IBOP Drl. Rig ok Lower Kelly / IBOP Hazard Sec. yes, Ball Type , Inside BOP Quan. Pressure 1 250/5,000 ,, , 1 250/5,000 250/5,0O0 250/5,00O P/F P P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 1 250/2500 I 250/5,000 1 250/5,000 I 250/5,000 I 250/5,000 I 250/5,000 I 250/5,000 na 250/5,000 P/F P P P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok. ok Flow Indicator ok ok Meth Gas Detector ok ok .. H2S Gas Detector ok ok ' CHOKE MANIFOLD: No. Valves 18 ~ No. Flanges 38 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure 250/5,000 250/5,000 Func§oned Func#oned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 1800 3,200 I P 1,750 P minutes 23 sec. minutes I5 sec. yes Remote: yes. Psig. Number of Failures: ,Test Time:,"6.0 'Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 ! I ! I I I I I I III II I I REMARKS: Had a gland nut stud/control line port leak. Called FMC rep. And Repa. ired. Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNES~ RI~QUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Lawrence Wade F1-021L (Rev.1?J94) AWOGLJEE.xls TONY KNOWLE$, GOVERNOt~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 26. 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-I 8 BP Exploration (Alaska) Inc. Permit No: 97-220 Sur. Loc.: 2262'NSL, 3312'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc: 4370'NSL, 2235'WEL, Sec. 20, T13N, R10E, UM Dear Alvord: 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. Blo~vout 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 ~vitness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnk~ton N "-'""-- -~ ' Chairnlan ~BY ORDER OF THE~SSION dlf/enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA~ ~.-,L AND GAS CONSERVATION CO'~I~vlISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [-] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []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 KBE = 64.6' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025515 ¢~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2262' NSL, 3312' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4161' NSL, 2298' WEL, SEC. 20, T13N, R10E, UM MPJ-18 At total depth 9. Approximate spud date Amount $200,000.00 4370' NSL, 2235' WEL, SEC. 20, T13N, R10E, UM .~ ~ 11/28/97 12. Distance to nearest property line113. Distance to nearest well;~ , 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 315848, 2235'I No Close Approach i"~ "::" 2544 12448' MD / 7363' TVD 16. To be completed for deviated wells ~:~" 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 72.54° Maximum surface 3059 psig, At total depth CI'VD) 6940' / 3753 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 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 BTC 8160' 31' 31' 8191' 4193' 2041 sx PF 'E', 575 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 12418' 30' 30' 12448' 7363' 225 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production LinerRECEIVED ORIGINAL PeRoration depth' measured true vertical AJaska Oil & Gas Cons. CommissJ0tl 20. Attachments [] Filing Fee [] Property Plat [] BOP Ske~h0[agt~ [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAlvord ~ ~ (~ Title Senior Drilling Engineer Date Oommi$$ion Use Only Permit Number APl Number App~val DatejSee cover letter c~ '~ .. ~, ),. 0 50- O ;;;[ c/ _ ~ 2. o° 3'Y // ._~, ~ -- ~"~, for other requirements Conditions of Approval' Samples Required []Yes [~No Mud Log Required []Yes I~No Hydrogen Sulfide Measures []Yes [~No Directional Survey Required J~Yes []No Required Working Pressure for BOPE []2M; 1--13M; .[~5M; [--I10M; [-115M Other: gi'lgil'tS.l olgi"~uu dy by order of Approved By David W. J0hflstOfl Commissioner the oommission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): James E. Robertson IMP J-18 Weft Plan Summary IKUPARUK PRODUCER 564-5159 Surface Location: 2262 FSL, 3312 FEL, S28 T13N R10E UM Target Location: 4161 FSL, 2298 FEL, $20-1'13N R10E UM Bottom Hole Location: 4370 FSL, 2235 FEL, S20 T13N R10E UM I AFE Number: I 337XXXXX I Estimated Start Date: I 28 Nov 97 I I MD: ] 12448' I I Well Desitin: Formation Markers: I Rig: I Nabors22E Operating days to complete: I 12.0 ITvD: 17363, I KBE: 164.6ft I Kapurak Producer Formation Tops MD TVDSS KOP 300 300 Base of Permafrost 1961 1800 . Top of Ugnu Top M Sand 6262 3480 Top NA (Target) 7195 3760 Top of Schrader Bluff Sands (EMW 8.6 ppg) OA 7723 3930 Top of Seabee 7952 4020 Base of Schrader Bluff Sands (EMW 8.3 ppg) Top of H RZ 11504 6476 MK-19 11679 6626 Top of Kuparuk 'D' 11761 6696 Kuparuk Cap Rock Top of Kuparuk 'C' 11913 6826 Top of Kuparuk 'B' 11924 6836 Top of Kuparuk 'A3' 12046 6940 Top of Kuparuk 'A2' 12073 6963 Top of Kuparuk 'Al' 12138 7019 Base of Kuparuk 12167 7044 Top of Miluveach Shale TD 12448 7363 TD at 300' MD past base of Schrader Casing/'l'ubin~l Program: Hole ~ize Csg~ WtJFt Grade Conn. Length Top Bottom Tb~l O.D. MD/I'VD MD/I'VD (bkb) 24" 20" 91.1 # H-40 Weld 80' 32'/32' 112' / 112' 12-1/4" 9-5/8" 40.0# L80 BTC 8160' 31 '/31' 8191' / 4193' 8-1/2" 7" 26# L80 BTC-MOD 12418' 30'/30' 12448' / 7,363' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at +6940' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 3753 psi (10.4 ppg EMW), is 3059 psi, well below the internal yield pressure rating of the 7" casing. MP J-18 Well Plan PAGE 3 11 Nov 97 Logging Program: Open Hole Logs: MWD and GR/RES from surface to 12-1/4" TD MWD and LWD (GR/Resistivity/Density/Neutron/ROP) from top of Kuparuk to TD with a controlled drilling speed of no more than 200 ft/hr from the top of the Kuparuk 'D' to TD Cased Hole Logs: NONE Mudloggers are NOT required for this well. Mud Program: I Special design considerations I None-SPUD MUD I Surface Mud Properties: I Density Marsh ~' Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 15 8 10 9 8 to to to to to to to 9.4 80 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 10.0 50 20 10 20 9.5 4-6 Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Also 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. A CompletionNVorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' MD Maximum Hole Angle: Close Approach Well: Waste Management: t72.54 NONE Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on J-Pad have been permitted for annular injection. MP J-18 Well Plan PAGE 4 1 1 Nov 97 MP J-18 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and function test 20" diverter. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to TD. 6. Run and cement 9-5/8" casing. 7. ND 20" diverter. NU and test 13-5/8" BOP. 8. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. 9. Drill 8.5" hole to TD as per directional plan. 10. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. 11. Test casing to 3500 psig for 30 min. 12. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 13. MIRU completion rig. NU & Test BOPE to 5000 psig. 14. Complete well with 2-7/8" tubing. 15. Install Surface Lines and Wellhouse and turn well over to production. (End of Nabors 22E operations) MP J-18 Well Plan PAGE 5 1 1 Nov 97 DRILLING HAZARDS AND RISKS: See the latest Milne Point j-Pad Data Sheet prepared by Pete Van Dusen for information on J pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: NO HYDRATES HAVE BEEN ENCOUNTERED ON ANY WELLS DRILLED AT MILNE POINT 'J' PAD TO DATE. If hydrates are encountered the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MP J-18. 3. Lost Circulation: 7 Schrader Bluff wells have been drilled on Milne Point 'J' pad since 1990 and none of them experienced any problems associated with lost circulation. In an effort to continue this trend maintain slow, steady running speeds while running casing and ensure mud is in good shape before POOH to run casing. LCM should be kept on hand, particularly if the mud is weighted up to counteract gas cut mud due to hydrates. 4. Stuck Pipe Potential: No stuck pipe incidents have been associated with the drilling of Schrader Bluff wells on Milne Point 'J' Pad to date. Some tight hole on trips has been encountered in the 2000' TVD to 3500' TVD range. Once tripped through the tight hole problems went away. The wells on Milne Point 'H' Pad drilled during the summer of 1997 encountered severe tight hole problems; especially swabbing problems while POOH. We will also break circulation at the first indication of swabbing on short trips. All of these problems were associated with 8-1/2" or 9-7/8" hole. The problem is not anticipated in 12-1/4" hole, If heavy gravels are encountered while drilling the surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: THE KUPARUK IS EXPECTED TO BE OVERPRESSURED. There has been injection in the area around MP J-18. The expected pore pressure for this well is 10.4 ppg EMW (3753 psi @ 6940' TVDSS) in the KUPARUK sands. A good estimate of expected pressure will be obtained from Milne Point production before penetrating the KUPARUK reservoir. 6. Directional Drillinq Concerns Care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 7. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. A 'C' cement for the second stage tail cement will be incorporated into the cementing program only if hydrates are encountered. MP J-18 Well Plan 1 1 Nov 97 MP J-18 9-5/8" SURFACE/PRODUCTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9/58" CIRC. TEMP: ~ 80°F SPACER: 50 BBL water STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 771 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 5762' MD TO THE ES CEMENTER STAGE TOOL (2200' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 575 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F TAIL CEMENT FROM TD (8200' MD) TO 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6262' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. EST TOC 5762' MD SPACER: 50 BBL water STAGE2 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg 1270 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM ES CEMENTER TOOL AT 2200' MD TO SURFACE +300% EXCESS. STAGE2 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'C' PERMAFROST Retarder 15.6 ppg YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk 000 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. MP J-18 Well Plan PAGE 7 11 Nov 97 WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLFJPRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers- one (1) per joint on the bottom thirty-one (31) joints of 7" casing. Run two centralizers on the bottom joint of casing and on the top centralized joint of casing as well. (31+2 = 33 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: , Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with water a volume equal to the capacity of the 7" casing from TD up to the ES Cementer at 2200' md followed by mud at TD mudweight. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate mud through the ES cementer for a minimum of two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. MP J-18 Well Plan PAGE 8 11 Nov 97 MP J-18 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170° F at 7040' TVDSS. 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: CENTRALIZER PLACEMENT: 1. 2. 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 225 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. . '" ' '"' ':'":':"'"' '"=" ' ""'"::'::; ............ 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 20 joints of 7" casing (40). This will cover +300' above the KUPARUK 'C' Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility pri0r..~0 pu.~ping. job. Ensure thickening times are adequate relative to pumping job requirement. ~i~b~:.;i!:~ti;:iii8~:~::i;::i: bpm. Batch mixing is not necessary. CEMENT VOLUME: Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. MP J-18 Well Plan PAGE 9 11 Nov 97 Aaadr£L[ Schlumberger Alaska District £211 Bast 80th Avenue Anchora~e, AK 99538 (907) 349-4511 Fax 344-2160 DIRECTIONAL ~LL PLAN for SHARED SBRV]CB$ DRILLING WeLl ......... ', MDJ-18 (P04) Field ........ : Mllne Po[ut Co~ukatlo~..: Minimum CHrvature Units ......... ~urface Lat...: $O.45079~£7 Surface bun~..: 149.57566768 LOC~T~ONS- A~KA Zone: 4 LeGal Description Surface ....... : 2262 FSL 33/2 PHL S28 T13N RIOB OM Schrader T gr.: 1020 FSL I338 FEL $20 TI3N R£0E OM Kuparuk T~t..: 4161 FS~ 2298 FHL' S20 T~3N R/0E OM BH~ .......... : 4379 PS[ 2248 PHL ~20 T13N R10H UM STATIOR" M~ASUR~D [NC~ D£RECT£O~ IDHI~TI FICATION D~ ~/q~ ANGLE ~r~TH T~ E~-~ DHP~T ~P / SUrbO l/t00 300.00 0.OO 320.61 300.00 235.40 0.00 ~UILD 2/100 500-00 2.50 ~20,61 499.9~ 435.35 3.63 600.00 3.~5 320.6L 599.~9 535.19 8.68 Prepared ..... : 17 Nov 3997 Vert sect az.: 342.87 K~ elevat£on,: 64,60 ft MagnetLc Dci.: +2V.846 ScaLe Factor.: 0.99990307 Conv~r~ence..: +0.39987227 X-Coord ¥ =Coord AKA-DPC I ^ A U'APPROVED 548665.00 60Lg675.00 FOR PERMITTING oNLY P~POS~D W~LL PROPr~ .~~~~~ ~RTZ~h-DH~HS S8~ION ~RDI~T~S-FR~ ~E~ Zone 4 ~b Db/ WELLHI~AD X Y FAC~ ~00 O.00 N 0.O0 ~ 552008.70 6014659.73 39L O.00 0.00 N 0.00 ~ 552008.70 60~4659,73 39L 0.00 0.6? N D.55 ~ 552008.14 6014660.40 ~9~ 1,00 3.03 N 2-49 ~ 552006.19 60L4662.75 39~ 1.SO 7.25 N 5,95 W 562002.?0 6014666.94 39L Z BU~r,D 2.'S/~00 700,00 5,00 320.61 699.S0 634,90 35.74 800.00 ?.50 320.6~ 798-90 734,30 25.8L 900-00 L0.00 320.61 897.73 833.33 39.89 1000.00 12.50 3~0.6L 995.80 93~-20 ~7.94 1100.00 15.00 320.61 1092.92 [028.32 79.94 13.L4 N L0.79 q 55~997.82 6024672.80 39b 1.25 21.56 N 17.70 ~ 55L990.85 60L~68L.16 H$ 2.~0 33.32 N 27.3~ W 55L981.32 60L4692.85 HS 2.50 48.39 N 39.73 W 5~1968.64 6014707.84 HS 2.50 66.76 N 54.81 W 551953.43 60~4726.10 H~ 2.50 2200.00 /7.50 320.61 LL8B.92 L/24.32 /05.84 8g.39 N 72.56 W 55L935.53 60La747.60 KS 2.S0 MPJ-la [PO4) mm~ s ~m~mmmmm~ STATEO~ ' £ DEI~T I FICAT I ON s~u~ 2.s/[oo ~u~~° BASE PHHMAFROST suzu~ 2,v$/lo° f~ASURBD I~CLN DH~TH 1300.00 20.00 1400.00 2~.~0 2500.00 25.00 3600.00 ~7.~0 1700.00 30.00 PROPOSHD WELL DIR~CTION V~RTICAb~D~PTH$ AZIIVRJ'T~ TVD 310.6~ 1283.6~ ~219.01 320.61 1376.80 [312.20 320.61 1468.32 L403,72 ~20.61 1558.01 1493,41 320.61 1645.67 158£.07 1800.00 32.50 320.6L 173L.L6 1666.56 1900,00 35.00 32D.6L 1814.30 1749.90 1912.60 35,32 320.6I 1624.60 1760.00 1961.62 15.12 320.61 1664,60 LSO0.OO [966,~3 35.32 320.61 1884.60 1820,00 2000.00 35.70 320.61 1895.89 1831,29 2100.00 30.45 320.6/ 1975.67 1911,07 2200.00 41.20 320.61 2052.47 1987'.87 2300.00 43.95 320.61 2~26.~0 2061.50 2400.00 46.70 320.61 2196.41 2131.81 2500.00 49.45 320.61 2263.22 2198.62 2600.00 52.20 320.61 2326.39 226£.79 2700.00 54.95 320.61 238S.77 2321.L7 2800.00 57.70 320.61 2441.21 2376.6~ 2900.00 60.45 320.61 2492.61 24~8.0~ m==~mmm $~CTION D~PART 13~.58 £69.12 206.39 247.32 29~.03 Nov 1997 Page 2 ==mmmmr=~= amm==gmmm= ~ = = m=== mm== COORDINATBS-PROM ALASKA Zone 4 TOO~ DL/ WEI.,LHHAD X Y FAC~ lO0 113.23 N 92.96 ~ 551914,96 60147~2.30 ~S 2.50 141.24 R 115.96 W 55£891.7~ 6014800.t4 RS 2.50 172.36 ~ 141.51 W 551866,00 6014831.09 HS 2.50 206.54 N 369.5? W S5~837.71 6014865.O7 HS 2.50 243.72 N 200.09 W 5~1806.93 6014902.02 HS 2.50 339.84 283.81 N 233.G1 W 551773.~4 6014941.08 HS 2.$¢ 391,25 326.75 N 268.26 ~ 55~738.20 6014984.5~ HS 2.5C 397,9~ 332.3~ N 272.86 ~ 551733.S5 6014990,~4 HS 2.56 424.19 354.26 N 290.84 W $517~.42 6015011.91 HS 0.0( 437.31 365.21 N 299.83 W 551706.35 6035022.80 444.~6 371.43 N 304.94 W 551701.20 6015028.99 HS 2.7E 500.54 418.02 ~ 343.19 ~ 551662.63 6015075.30 HS 2.75~ 559;80 469.51 N 383.82 W 551621.66 6015124.50 HS 2.75~ 622.4l 519.79 N 426.75 W 55L578,38 6015L76.48 HS 2.?~.' 688.21 574.74 N 471~86 W S5L532.89 601523[.11 HS 757.05 632.~4 N 5L9.06 ~ 551485.29 6015288.27 HS 2.75! . 828,79 692.L5 ~ 568.25 ~ 551435-69 6015347.83 HS 2.75i 903.24 754.33 ~ 619.30 W 551384.21 6015409.64 HS 2.75! 980.25 838,64 N 672.L0 W 551330.97 6015473,58 HS 2.75~ 1059.63 884.93 N ?26.52 W 5S1276.09 6015539.48 HS 2.75~ ~> BUILD 3000.00 63.20 120.61 2539-82 2475.22 1141.20 953.05 N 782.45 ~ 55~219.69 6015607.21 HS 2.75 3100.00 65.95 320.61 2582-76 2518.16 /224.77 1022.85 ~ 839.75 W 55~161.91 6015676.59 HS 2.75 3200.00 68.70 320.61 2621.3£ 2556.7L L310.16 1094.15 N 898.29 W $5LL02.88 60~5747.48 ~ 2.75 3300.00 71.45 320.61 265'5,39 2590,79 1397.16 L166.01 N 957.94 W 551042.73 6015819.73 FIB 2.75 3339.77 72.54 320.6~ 2667.69 2603.09 1432.~6 ££96.04 N 98~.94 ~ 5510t8.53 6015848.77 HS 2..75 H SANDS 6262.43 72.54 320.61 3544.60 3480.00 4012,38 3350.66 N 2751.04 W 549234.61 6017990.99 HE 0.00 NA 719~.64 72.54 320.61 382~,60 3~60.00 4836.25 4038.90 N 3315.92 W 548665.00 60~8675.00 lis 0.00 SCKRADHR TAR~ 7195.64 72.54 320.61 ~824.60 3760.00 4836.25 4038.90 N $31~.92 W 548665.00 60~8675.00 [iS 0.00 m {Anadr/L/ (c397 NpWISP04 3.2b.02 7:49 Ali P) (ID · ............... ---- ................. ,,i ...................... '""~ ............ :-'--' ................................................................................... Cn STATION ZU~ FF £ F1 CAT[ON CURV~ L.75/100 OA BASE OB 9 -5/8" C_ASYX~)C] }'0121{T 8}rD 1.7~;/100 C~V]{ CURVE 1.5/1,00 MHABURED INC"La/ D~PTH 7395.64 72.54 7400.00 72.47 ~500.00 ?0.9~ 7600.00 69,4~ ~700.00 67.97 PROPOSHD ~EG~ PROFI~K DI,P,.~CTI0~ V]IRT£CAL-DHPTHS AZ~4UTH TVD ~UB-SHA 320.61 3884.61 3820.01 320.6~ 3885,92 3821,32 ~2L'.59 3917.28 3852.68 ~22.55 395~.13 3886.53 323.52 3987.42 3922.82 ].'7 Nov 1997 SSCTION 0OORDINATES-FROM PART 50L2.82 5016.67 5104,86 5192,83 5290.46 77L9.02 67.69 323,7£ 3994.60 3930.00 5297.08 7800.00 66,48 324,52 4026.[4 3961.54 5367.91 7900.00 65.00 325.53 4067.23 4002,63 5454.48 7940.64 64.39 325.95 4084.60 4020,00 5489.59 8000.00 63.52 326.58 4~10.66 4047,06 5540.$0 4186.36 N 3436.98 4189.57 N 3439.62 42'63.49 N 3499.2£ 4337.70 N 3557.05 4412,15 H 3613109 4426,32 N 3623.~3 4486.75 N 3667.26 456i.45 N 3719,~2 459L.82 N 3740.20 4636.L7 ~ 3769.82 8100.00 62,05 327.64 4L56.40 409L.80 5626.27 47~0.83 N 38L8-11 8190.64 60.92 328.64 4199.80 4135.20 5703,23 4778.41 N 3860.12 8190.64 60.72 328.64 4199.80 4125.20 5703.23 4778.41 N 3860.12 8290.64 60.72 328.64 4248.7L 4~84.1~ 5787.78 4852.90 N 3905.5L 8300.00 60.6~ 328.73 4253.29 4188.69 5795.68 4859.87 N 3909,75 8400,00 59,36 329.69 4303.31 4238.71 5879.82 4934.25 N 3954.08 8500.00 58.L3 330.69 4355,20 4290.60 S963.22 5008,42 N 3996.57 8600.00 56.90 331.71 4408.9l 4344.3L 6045.81 5D82.33 N 403~.~2 8700.00 55,67 332.7~ 4464.42 4399.82 6127.56 5£55,92 N 4075.98 8800.00 54.46 333.83 4521.68 4457.08 6208.40 5229.L5 N 4LZ2.83 8900.00 53.26 334.94 4580.65 45L6,05 6288.27 9000.00 52.07 336.09 464L,30 4576-70 6367.12 9200.00 50.89 33~.27 4703.57 4638.97 6444.90 9200.00 49,72 338,50 4767.44 4702.84 652L,55 9300.00 48.57 339.76 4832.86 4768.26 6597.02 5301.97 N 4149.75 5374.33 N 4180.70 5446.17 N 4211.68 ~S£7.45 N 4240.65 5588.%2 N 4267.60 Page AXJ~S~ Zone 4 TOOL D~/ X Y PAC~ 200 548~42~92 6018821,59 i~0R 0,00 548540.27 6018824.79 S48480.16 149R L.?5 548421.81' Z49R L,.TS 548365.26 L49R 1.75 548354.72 548310.58 548257.80 '5~82~.~ 548206.98' 60~8898.28 6018972.08 6019046.13 ,. 60£9060~23 60L9~20 6019194,67 60192~4.89 L49R, 1.95 148R 1.75 ' 148R' 1.75 148R, 6039269.02 'L4'gR 548158,18'60£9343.35 548115.71 60L9430.63 548115.7L 6019410.63 548069.806019484,78 S48065.51 6019491.72 548020.67 60L9565.78 547977.66 60L9639.65 5479'36.50 6019713.26 .6,~ ' o.oo{ Z '~ 146R 1.501 !.46R 1.50L 145R 3.50C 145R 1.50 547897.24 6019786.58 ]44R 1.50 547859.88 6019859.54 244R L.SO 547824,46 6019932.L1 ].43R 1.50 547791.00 6020004.23 142R 547759.53 6020095.84 141R L,50 547730.06 6020146.91 141R /.S0 547702.6'2 6020217.38 [40R 1.,50 9400.00 47.43 341.08 4899.77 4835.~9 6671.26 9500.00 46.30 342.44 4968.L4 4903,54 6744.22 9600.00 45.20 343.85 5037.92 4973.32 68L5.84 (Anadril3 (c}97 MPO18P04 3.2b.02 7:49 ]~l P) ........................................ ~--~-~--- ...................................................................................... 5658.12 N 4292,53 5727.43 N 4315.36 5795,97 N 4336.14 547677,22 6020287.21 139R ~.50 ' 547653.89 6020356.35 138R /.50 547632.64 6020424.q4 137R L.50 STAT~O~ IDI'~TXF~CAT~ON MER~ORHD ]NCL,N DEPTH ~NG~ 9700.00 44.££ ~800.00 43.04 9900.00 41.99 L0000.00 40.96 10300.00 39.96 10200.00 38.99 10300.00 38.04 10400.00 37.13 L0500'.00 36.24 k0600,O0 35,40 10700.00 34=59 10800.00 33,82 E0900.00 33,10 1~000.00 32.43 END 1.5/L00 CU'RVE 11074.20 31.96 TOP H.R~ 11479,02 3i.96 I~S~ I4RZ L2549.72 31,96 MK-L9 li655.80 31,96 TKUD 11738.30 3~,96 TKIIC 1189~,52 3L,96 EROPOSED NBbL PROP]LB D£RECT£ON VBRTICAb-D~P~ AZUMUTH TVD SU~-S~A 345.32 5109,06 5044.46 346.84 518L.5~ 5~]6.9L 348.43 5255.22 5]90.62 350.08 5330.15 5265.SS 35L,80 S406,23 534~.63 ~ECT]ON D~PART 6886.09 6954,90 7022.24 7088.06 7352.3l 17 Nov 1997 OOORDIH'ATES-~RO~ H~LI.,HEAO 5863.72 N 4354.83 S930.62 R 437L,42 S996.62 N 4385.90 6061.68 N 4398,25 6125.76 N 4408.48 353.60 5483,42 54L8;82 7214,95 6L85.81 N 44i6.56 355.47 556L.67 5497.07 7275.93 6250.79 N 4422.51 357.42 5640,92 5576,32 7335.21 63L1.66 ~ 4426.30 359.45 5721.11 5656,51 7392.76 6371.37 N 4427,95 1.56 5802.20 5~3~,60 7448.54 6429,89 N 4427.45 3;77 S884.L2 5819.52' 7502.49 6487.16 N 4424.79 6.06 5966.83 5902.23 7554.60 6543.17 N 44L9.99 8.44 6050.25 5985.65 7604,82 6597,86 N 4413.04 10.92 6134.35 6069.75 7653..tL 6651.L9 N 4403.95 12.83 6/97.14 6L32,54 7687.69 6689.87 ~ 4395.83 12,8L 6540.60 6476,00 7873,35 6898.80 N 4348,31 ~2,81 6600,60 6536.00 7905.78 6935.29 N 4340,00 12,81 6690,60 6626,00 7994,44 6990-04 N 4327,55 12,81 6760,60 6696,00 7992,28 7032.62 N 4317.87 12,81 6890,60 6826,00 8062,55 7~31.70 N 4299.88 Page 4 ALASKA Zone 4 547613,48 6020492.35 547596.42 6020559,12 547581.49 602062~,01 547568,68 6020689,98 547558,01 6020753,98 547549.48 6020816,97 547543.L1 60208~8.90 547538.89 6020939.73 547536.82 6020999.42 547536.92 6021057.94 547539.17 6021115.23 547543.59 602/171.26 547550.L5 602/22S.99 S47558.87 6021279.38 947S66.72 60213~8.11 5476/2.78 6023527.34 547620.82 6021563.89 547632.89 602t618.72 S47642.28 602166~.36 S47659,71 6021740,55 TOOb PACH 100 136R L.50 135R L.50 L34R L,50 L$3R l. 50 L3/R 1.50 130R 1.50 ~?KU~ L1903.31 3/.96 L2.0[ 6900.60 6836.00 8067,96 7LL7,?8 N 4298.50 W 54366L.05 6023746.65 HS 0.00 KUPARUK TARCIHT 12025.89 31,96 12,81 7004,60 6940,00 8124.L8 718L,04 N 4284,22 ~ 547675.00 602/810.00 H9 0.00 TKA3 12025.89 ~1,96 12.81 7004.60 6940.00 8~24,~8 7181.04 N .4284,~2.W S47675,00 60218~0.00 HS 0,00 TKA2 12053,00 3L196 12,8L 7027,60 6963,00 8236.6~ 7195.03 N 4280,92 W S47678.08 6021824.02 HS 0.00 TKAL 22119.00 3[.96 22,8L 7083.60 7019.00 8L66.88 7229,10 N 4273.18 W 547685.59 6023858./3 HS 0.O0 TNLV 12148.46 31.96 12.81 7108,60 7044.00 8180.40 7244.30 N 4269.72 W 547688.95 602L873.35 RS 0,00 TI) / 7~ CASING POINT 12448.46 ~-96 12.8~ 7363.13 7298'.53 8317,99 7399,L3 N 4234.50 W 547723.08 6022028.41 0.00 (Anadrill (c)97 MPJLBP04 3.2b.02 9:49 AM g) . . ........................................................................................ ?j ........ 'SHARED SERVTCES i i i iii . i i i i i i DR 'LL'I NG" ' I iii i i ii i i i i AnadrJ 11 Schlumberger MPJ-18 (PO4) <KB> " VERTICA[ SECTION VIEW 1401 :LN . 32 T 2801 32 D 72 72 7~ ,, , A.D · '. YL, II J.D/4L dbb I lull ¥ /.LFI , ANADRILL AK PC , ,. Section aL: 342.87' , APPitOVED TVD Scale' ] inch= ]400 feet ~". ' FOiL PEI',MIITIN(; a~p s~e.' ~ ~,~,': ~4oo ~ .~ v grain · ~7 Nov ~907 , . . ,. .~ .- ' ~a~k~P ]denLif~ca~iDn ~D ~G SECIN INC[ " A) KB 0 0 0 0.( '" ' ' ......................... 1~~'~ B) KOP /.BUZLD I/lOg 300 .300 0 0.1 __ C] BUILD ~.5/]00 400 400 ~ . ' ~ ~ " . D) BUILD 2/~00 500 500 ' '4 2.~ E) BUILD ~.5/100 700 700 16 5.( '~ "F) END 2.5/100 ~ILD 19J3 ~825 39B 35.: ~ ~ ..' ~ G) .BUILD 2.75/100 ~986 1885 437 35. . H) END 2.75/~00 BUILO 3340 2~8 ~43E 72.~ l) SCH~DERTARGET 7196 ~25 4a36 72J ~~~ ~ CeE ~.7U:O0 Z3m 3ee~ ~3 ~.~ . ~- ~ ~---~ -- ' K) 9-5/8" CASING PAINT 8~9~ 4200 5703 60.' ' ~~~ ~-I~_ ~u~2~O fee, ~)E, ,.75/,00 cURVE B,9, 4200 5703 60.' '~'~~~" · ' H) CURVE ~.5/100 829t 4249 57ce 60.' ~~¢.._ ........ .. -. 2[ L~ N) END 1.5/~00 CURVE 1~074 6t97 . 7686. K~ O) KUPA~UK TA~ET 12026 7005 e184 P) fO / 7" CASING POINT ~244B 7363 e~e , ,,,, .... .. .~ ::: :: _., --::: :::--:,:::::. ~l;aa;,,a~ . ......----~..... . ..... ' .............. . ...; ..... ..... ;;;a~.:;maa;:m; .......-, P , . . . . ........ z7 ...... ~ .... ~TZ:~'-Y ..... ....................................... , ...................................... B4gO Sect ion Departure " i i ]11 i ii i iii iii ii ii i ii _ ~o_._ .................. ~o. ,~ ',~ VERTICAL, SECTION, VIEW X - I'$ection at: 342.87 ~TVD Scale.: ~nch -- 100 feet oo-= % ~Oep Scale.: ~ inch : ~00 feet . ...... ~,,z- ~ ~Dnawn ..... : ~TNov ~997 ~ Ana~JJ1 S~h4u~aerger' )o-- X A~PRC'V~D ONkY .. ~ . . 7800 7850 7900 7950 8000 8050 8 I00 8:~50 8200 8250 8300 8350 8400 ' 8450 Sec t ~ on De ~arture · ! · MPJ-J. 8 (PO4) PLAN VIEW CLOSURE ..... : 8525 feet ~ Azimuth 330.I 2 +27.846 (E) ,1 inch = ~.200 feet 17 Nov 1§97 DECLINATION.' SCALE ...... - DRAWN. · AnaUr i l l i :00 I )0 ! ! I 7800 7200 6600 6000 5400 4800 4200 3600 3000 (~m¢il] (c)$7 ~dll)P04 3.~.~ 7:9 ~ @) i m ~400 ~800 m 1200 O( 600 o (5o0 <- WEST' EAST -> i oo H1283G4 VENDOR AL ASIz, AST 14 O0 I DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 1 O0197 CK 1 O01971 100. OO ~ oo. oo PYMT 20MM£NTS' pe~nit to d~ill application HANDL[NO INST- s/h ~athy Campoalno~, x51~ y Cj~jq 1 o~ H 'HE AI'rACHED CHECK IS IN PAYM I · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ¢&'"2 ¢.~/0¢--~ INIT CLASS WELL NAME /~ P ,,.) -' l" 0 ,' I GEOL AREA PROGRAM: exp [] dev.j~r'redrll [] serv [] wellbore seg C ann. disposal para req [] 0 UNIT# ) I 3AF ON/OFF SHORE ~ ! ADMINISTRATION DATE 1. Permit fee attached ....................... ~ N 2. Lease number appropriate ................... t~ N 3. Unique well name and number .................. /I~ N 4. Well located in a defined pool .................. ~ N 5. Well located proper distance from drilling unit boundary .... ~ N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ~)N ENGINEERING APPR~ ~-1~ 14 Conductor string provided ................... N 151 Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... -~ 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ............ N 29. Is presence of H2S gas probable ................. N GEOLOGY AP~.B~ DATE 30. Permit can be issued w/o hydrogen sulfide measures. :...,...~.~-----Y N 31. Data presented on potential overpres_s~.~~ . . . Y N 32. Seismic analysisof shaltow~.~~. ............ Y N 33. Seabed co~(if off-shore) ............. Y N 34. Contagtll~me/phone for weeklyjorog, ress repo, rts ....... Y N lexp~oratory on~yj REMARKS IV/d ' GEOLOGY: RPC ~ ENGINEERING: COMM. ISSION: BEW (2~ ,¢Z¢' DWJ ~ JDH ,. ~ RNC~ ' ' co co'IF. Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09197 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed May 13 15:56:44 1998 Reel Header Service name ............. LISTPE Date ..................... 98/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION MWD RUN 1 AK-MM-80033 PIEPER LOCKWOOD (FT FROM MSL 0) M C OF LM D MPJ-18 500292283400 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 13-MAY-98 MWD RUN 2 MWD RUN 3 AK-M~4-80033 AK-MM-80033 PIEPER PIEPER LOCKWOOD JAYE 28 13N 10E 2262 3312 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 63.80 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 8242.0 8.500 12455.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 5. ALL MWD RUNS REPRESENT MPJ-18 WITH API# 50-029-22834-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12455'MD, 7421'TVD. SROP: SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC: SMOOTHED GAMMA RAY COMBINED. SEXP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP: SMOOTHED PAHSE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP: SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE: SMOOTHED FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. SPSF: SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE) SNNA: SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA: SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC: SMOOTHED BULK DENSITY-COMPENSATED. SCOR: SMOOTHED STANDOFF CORRECTION. SNPE: SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 190.5 12414.0 RPD 200.5 12393.5 RPM 200.5 12393.5 RPS 200.5 12393.5 RPX 200.5 12393.5 FET 252.0 12393.5 ROP 253.5 12484.5 FCNT 8226.5 12368.0 NCNT 8226.5 12368.0 NPHI 8226.5 12368.0 PEF 8265.5 12402 . 5 DRHO 8265.5 12402 . 5 RHOB 8265.5 12402 . 5 $ BASELINE CURVE FOR SHIFTS: Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .S000 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 190 5 8265 8288 8308 8317 8331 8366 8725 8747 8845 8937 9007 9038 9049 9146 9636 9689 9973 10026 10133 10451 10717 10831 10923 11080 GR 168.0 8242.5 8266.0 8287.0 8299.5 8313.0 8349.0 8705.0 8725.0 8827.5 8918.0 8986 5 9016 0 9031 0 9127 5 9617 5 9670 0 9954.5 10004.5 10112 0 10431 5 10697 0 10809 5 10900 5 11057 0 11083 5 11132 0 11191 5 11244 0 11250 5 11271 0 11297 0 11311 5 11472.0 11479.0 11495.0 11500.5 11522.5 11540.5 11543.5 11558.0 11569.0 11641.0 11683.5 11698.5 11702.0 11705.0 11720.0 11802.5 11814.0 11846.5 11891.0 11901.0 11937.0 11977.5 12017 0 12026 5 12042 0 12047 0 12074 5 12086 0 12099 5 12122 5 12131 0 12251 5 12312 5 12334 0 12484 5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 11061 11113 11169 11220 11227 11251 11273 11289 11449 11456 11472 11480 11501 11519 11521 11534 11545 11617 11658 11674 11684 11695 11706 11778 11790 11821 11866 11876 11912 11952 11992 12001 12015 12020 12041 12057 12071 12095 12104 12222 12285 12304 12454 5 0 5 0 '0 5 5 5 .5 .5 .0 .5 .0 .0 .5 .0 .0 .5 .5 .5 .5 .0 .0 .5 .5 .5 .5 .0 .0 .5 .0 .5 .0 .0 .5 0 0 0 0 5 0 0 5 BIT RUN NO 1 2 3 MERGED MAIN PASS. $ Data Format Specification Record MERGE TOP 220.0 2984.0 8267.0 MERGE BASE 2984.0 8267.0 12455.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0' Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 190.5 12484.5 6337.5 24589 ROP 7.9522 2461.54 283.764 24463 GR 12.6086 231.718 70.1478 24448 RPX 0.0545 2000 10.2876 24387 RPS 0.1638 2000 13.0699 24387 RPM 0.1401 2000 17.5383 24387 RPD 0.0856 2000 22.7543 24387 FET 0.0585 81.4546 1.06831 24284 RHOB 1.7836 3.0257 2.3776 8275 DRHO -0.082 0.2139 0.0423969 8275 PEF 1.7012 7.1654 2.40807 8275 N?HI 15.0785 66.9183 36.2199 8284 NCNT 2136 3776 2670.98 8284 FCNT 402 1049 640.783 8284 First Reading 190.5 253.5 190.5 200.5 200.5 200.5 200.5 252 8265.5 8265.5 8265.5 8226.5 8226.5 8226.5 Last Reading 12484.5 12484.5 12414 12393.5 12393.5 12393.5 12393.5 12393.5 12402.5 12402.5 12402.5 12368 12368 12368 First Reading For Entire File .......... 190.5 Last Reading For Entire File ........... 12484.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 168.0 RPD 178.0 RPM 178.0 RPS 178.0 RPX 178.0 FET 229.5 ROP 231.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM]ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ STOP DEPTH 2921.5 2931.5 2931.5 2931.5 2931.5 2931.5 2984.0 05-DEC-97 5.07 5.46 MEMORY 2984.0 220.0 2984.0 .0 59.9 TOOL NUMBER P0851CGR8 P0851CGR8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12.250 12.3 SPUD 8.60 150.0 9.5 1000 .0 3.100 3.110 2.900 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMS4 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 23.9 First Name Min Max Mean Nsam Reading DEPT 168 2984 1576 5633 168 GR 12.6086 114.849 53.4364 5508 168 Last Reading 2984 2921.5 RPX 0.2128 82.3581 22.9721 RPS 0.173 155.99 33.0274 RPM 0.1401 2000 47.5845 RPD 0.0856 2000 58.8192 ROP 24.0132 2136.5'1 306.871 FET 0.0585 14.8645 0.661924 5508 5508 5508 5508 5507 5405 178 178 178 178 231 229.5 2931.5 2931.5 2931.5 2931.5 2984 2931.5 First Reading For Entire File .......... 168 Last Reading For Entire File ........... 298'4 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: S O FTWARE START DEPTH 2922.0 2932 0 2932 0 2932 0 2932 0 2932 0 2985 5 STOP DEPTH 8205.0 8215.0 8215.0 8215.0 8215.0 8215.0 8267.5 07-DEC-97 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.07 5.46 MEMORY 8267.0 2984.0 8267.0 59.9 74.9 TOOL NUMBER P0851CGR8 P0851CGR8 12.250 12.3 SPUD 9.20 67.0 9.5 1000 5.8 3.200 2.970 2.900 4.600 34.5 Name Servi DEPT GR MWD 2 RPX MWD 2 RPS MWD 2 RPM MWD 2 RPD MWD 2 ROP MWD 2 FET MWD 2 ce Order Units Size Nsam FT 4 1 API 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 FT/H 4 1 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 2922 8267.5 GR 14.4451 110.482 RPX 1.8116 50.9132 RPS 1.3463 93.5399 RPM 1.0811 111.157 RPD 1.1282 70.5318 ROP 7.9522 2461.54 FET 0.0798 10.4205 Mean Nsam 5594.75 10692 57.0962 10567 8.91108 10567 10.229 10567 10.5126 10567 11.1449 10567 296.734 10565 0.590065 10567 First Reading 2922 2922 2932 2932 2932 2932 2985.5 2932 Last Reading 8267.5 8205 8215 8215 8215 8215 8267.5 8215 First Reading For Entire File .......... 2922 Last Reading For Entire File ........... 8267.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE S~RY VENDOR TOOL CODE START ~DEPTH FET 8066.5 RPD 8066.5 RPM 8066.5 RPS 8066.5 RPX 8066.5 GR 8088.0 ROP 8158.0 FCNT 8204.0 NCNT 8204.0 NPHI 8204.0 PEF 8243.0 DRHO 8243.0 RHOB 8243.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 12363.5 12363.5 12363.5 12363.5 12363.5 12384.0 12454.5 12338.0 12338.0 12338.0 12372.5 12372.5 12372.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 12-DEC-97 5.07 5.46 MEMORY 12455.0 8267.0 12455.0 24.9 61.8 TOOL NUMBER P0900CRLGM6 P0900CRLGM6 P0900CRLGM6 P0900CRLGM6 8.500 8.5 LSND 10.20 48.0 9.0 1200 3.8 2.300 1.380 53.9 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/~DOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.200 4.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 NPHI MWD 3 P.U. 4 1 68 24 7 ROP MWD 3 FT/H 4 1 68 28 8 FET MWD 3 HOUR 4 1 68 32 9 FCNT MWD 3 CNTS 4 1 68 36 10 NCNT MWD 3 CNTS 4 1 68 40 11 RHOB MWD 3 G/CC 4 1 68 44 12 DRHO MWD 3 G/CC 4 1 68 48 13 PEF MWD 3 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading DEPT 8066.5 12454.5 10260.5 8777 8066.5 GR 30.4979 231.718 96.1581 8593 8088 RPX 0.0545 2000 3.7953 8595 8066.5 RPS 0.1638 2000 3.94235 8595 8066.5 RPM 0.2872 2000 25.0335 8595 8066.5 RPD 0.05 2000 70.8968 8595 8066.5 NPHI 15.0785 66.9183 36.2164 8269 8204 ROP 14.8345 1982.81 252.636 8594 8158 FET 0.2174 81.5578 4.67037 8595 8066.5 FCNT 402 1049 640.706 8269 8204 Last Reading 12454.5 12384 12363.5 12363.5 12363.5 12363.5 12338 12454.5 12363.5 12338 NCNT 2096 3776 2671.33 8269 RHOB 1.7836 3.0257 2.37724 8260 DRHO -0.131 0.2139 0.0424457 8260 PEF 1.7012 7.1654 2.40665 8260 8204 12338 8243 12372.5 8243 12372.5 8243 12372.5 First Reading For Entire File .......... 8066.5 Last Reading For Entire File ........... 12454.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER ****************************** . ............................ ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : BP EXPLORATON WELL NAME : MPJ-18 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 500292283400 REFERENCE NO : 98209 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/04/29 ORIGIN : FLIC REEL NAME : 98209 CONTINUATION # : PREVIOUS REEL : CO~k4ENT : BP EXPLORATION, MILNE PT., MPJ-18, API #50-029-22834-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/04/29 ORIGIN : FLIC TAPE NAME : 98209 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT . BP EXPLORATION, MILNE PT., MPJ-18, API #50-029-22834-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPJ- 18 API NUMBER: 500292283400 OPERATOR: BP EXPLORATON LOGGING COMPANY.. WESTERN ATLAS TAPE CREATION DATE: 29-APR-98 JOB NUMBER: 98209 LOGGING ENGINEER: R. ECK OPERATOR WITNESS: THACKERAY SURFACE LOCATION SECTION: 28 TOWNSHIP: 13N RANGE: 10E FNL : FSL : 22 62 FEL: 3312 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 63.80 GROUND LEVEL: 28.73 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 20. 000 115.0 90. O0 2ND STRING 9. 625 8245. 0 40. O0 3RD STRING 7. 000 12425.0 26. O0 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH .............. $ REM_ARKS: CONTAINED HEREIN IS THE GR/CCL DATA ACQUIRED ON BP EXPLORATION WELL MPJ-18 BY WESTERN ATLAS ON 3-25-98. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. NO AVERAGE PASS DATA IS PRESENTED AS AN AVERAGING OF THE MAIN AND REPEAT PASSES WAS NOT PERFORMED. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3MBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~ULgY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12326.0 8198.0 CCL 12326.0 8198.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE REMARKS: THIS FILE CONTAINS GR/CCL MAIN PASS DATA AT .5' SAMPLE RATE. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 51 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 NUP~ SAMP ELEM CODE (HEX) DEPT FT 189751 O0 000 O0 0 1 1 i 4 68 0000000000 GRCH GR GAPI 189751 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 189751 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 189751 O0 000 O0 0 1 1 1 4 68 0000000000 CVEL GR F/HR 189751 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12326.000 CVEL.GR 2639.736 GRCH.GR 51.561 TENS. GR 1457.771 CCL.GR 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: DEPT. 8198.000 CVEL.GR 2939.706 GRCH. GR 29. 986 TENS. GR -48.957 CCL.GR 43.680 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12326.0 11794.0 CCL 12326.0 11794.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CCL LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: REMARKS: THIS FILE CONTAINS GR/CCL REPEAT DATA AT .5' SAMPLE RATE. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 20 1 0.5 FT 51 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NTJFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 189751 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH GR GAPI 189751 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 189751 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 189751 O0 000 O0 0 2 1 1 4 68 0000000000 CVEL GR F/HR 189751 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12326.000 CVEL.GR 1677.336 DEPT. 11794.000 CVEL.GR 2457.259 GRCH. GR 54.551 TENS.GR 1165.437 CCL.GR GRCH. GR 77.991 TENS.GR -2.119 CCL.GR 0.000 20.280 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 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 SU~E4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12353.0 8185.25 GR/CCL $ LOG HEADER DATA DATE LOGGED: 25-MAR-98 SOFTWARE VERSION: JO01 VER. 1.1 TIME LOGGER ON BOTTOM: 12:15 TD DRILLER (FT) : 12337.0 TD LOGGER (FT) : 12334.0 TOP LOG INTERVAL (FT) : 8200.0 BOTTOM LOG INTERVAL (FT) : 12326.0 LOGGING SPEED (FPHR) : O. 0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: CCL COLLAR LOCATOR GR GAM~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS 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) : CCL GR 12425.0 BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG WAS RUN WITH MARKED LINE TO ESTABLISH TRUE DEPTH. TOOLSTRING WAS ZEROED TO ORIGINAL D. F. = 63. 83 '. MAXIMUM DEVIATION = 75 DEG. $ 1/2" ROLLERS USED TO CONVEY TOOLSTRING. CCL QUALITY POOR DUE TO TOOL BEING CENTRALIZED BY ROLLERS. THIS FILE CONTAINS THE RAW MAIN PASS DATA @ .25' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: 8 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUNiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 189751 O0 000 O0 0 3 1 1 4 68 0000000000 GR LOG GAPI 189751 O0 000 O0 0 3 1 1 4 68 0000000000 TEN LOG LB 189751 O0 000 O0 0 3 1 1 4 68 0000000000 CCL LOG V 189751 O0 000 O0 0 3 1 1 4 68 0000000000 SPD LOG F/HR 189751 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12353.000 SPD.LOG 0.000 DEPT. 8185.250 SPD. LOG 0.000 GR.LOG GR.LOG 0.000 TEN. LOG -500.000 CCL.LOG 0.000 TEN. LOG -500.000 CCL.LOG 25.000 8.970 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 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: 0.25000 FILE SU~9~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................... 12349.0 11749.25 GR/CCL $ LOG HEADER DATA DATE LOGGED: 25-MAR-98 SOFTWARE VERSION: JO01 VER. 1.1 TIME LOGGER ON BOTTOM: 12:15 TD DRILLER (FT) : 12337.0 TD LOGGER (FT) : 12334.0 TOP LOG INTERVAL (FT) : 8200.0 BOTTOM LOG INTERVAL (FT) : 12326.0 LOGGING SPEED (FPHR) : O. 0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GA~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... CCL GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: 10 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12425.0 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) : BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS) '. NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG WAS RUN WITHMARKED LINE TO ESTABLISH TRUE DEPTH. TOOLSTRING WAS ZEROED TO ORIGINAL D.F. = 63.83'. MAXIMUM DEVIATION = 75 DEG. 5 1/2" ROLLERS USED TO CONVEY TOOLSTRING. CCL QUALITY POOR DUE TO TOOL BEING CENTRALIZED BY ROLLERS. THIS FILE CONTAINS THE RAW REPEAT PASS DATA @ .25' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: 11 TYPE REPR CODE VALUE 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189751 O0 000 O0 0 4 1 1 4 68 0000000000 GR RPT GAPI 189751 O0 000 O0 0 4 1 1 4 68 0000000000 TEN RPT LB 189751 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RPT V 189751 O0 000 O0 0 4 1 1 4 68 0000000000 SPD RPT F/HR 189751 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12349.000 SPD.RPT 0.000 DEPT. 11749.500 SPD.RPT 0.000 GR.RPT GR.RPT 0.000 TEN. RPT -500.000 CCL.RPT O. 000 TEN. RPT -500. 000 CCL.RPT 25.000 86.970 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 98/04/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifi~cation Listing Schlumberger Alaska Computing Center 29-APR-1998 11:54 PAGE: 12 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/04/29 ORIGIN : FLIC TAPE NAME : 98209 CONTINUATION # : 1 PREVIOUS TAPE : CO~E4ENT : BP EXPLORATION, MILNE PT., MPJ-18, API #50-029-22834-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/04/29 ORIGIN : FLIC REEL NAME : 98209 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION, MILNE PT., MPJ-18, API #50-029-22834-00