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195-001
riMkotIVLU STATE OF ALASKA AlIllkA OIL AND GAS CONSERVATION COP SION JAN 0 5 2018 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U PlugPerforations Li Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Convert to GL ❑✓ 2.Operator 4,Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Name: Development a Exploratory ❑ 195-001 r'.°"` 6.5I' 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: _____ - AK 99503 50-029-22541-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 Milne Pt Unit KR E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Pt Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,830 feet Plugs measured 12,245 feet true vertical 7,355 feet Junk measured N/A feet Effective Depth measured 12,116 feet Packer measured 11,576&11,816 feet true vertical 6,980 feet true vertical 6,712&6,830 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/Hydril 533 11,710' 6,777' HES FH 7"x 2-7/8" Packers and SSSV(type,measured and true vertical depth) 7"x 5"LTP N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A JAN9 SCA" Treatment descriptions including volumes used and final pressure: N/A N � 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 380 0 Subsequent to operation: 46 0 1,808 1,867 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas LI WDSPL LI Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: c-?- — S13 Authorized Name: Bo York Contact Name: Taylor Wellman "'1 Authorized Title: Operations Manager Contact Email: twellmarl(C7hiIcorp.com Authorized Signature: "Irr"--4-- Date f/ f1/3/2018 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 � ::r 3 L ' b //�/�,// Submit Original Only H . • Milne Point Unit Well: MPE-11 SCHEMATIC Last Completed: 1/01/16 Hilcorp Alaska., PTD: 195-001 , Orig.KBElev.:53.83'/GLEIev.:24.40 TREE&WELLHEAD RKB Elev=33.55'(Nabors 22E) Tree Cameron 2-9/16"5M Wellhead 13-3/8"x 11"5K w11"x 2-9/16"Tubing 20' ,i) ,,,, t r R' Hanger EUE x Hydril 533,2"CIW H BPV profile OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/370 sks Class"G"in 8-1/2"Hole 5" Cmt w/145 sks Class"G"in 6"Hole ' CASING DETAIL E 95/8 ! Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A 0' 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/BTC 8.835" 0' 3,455' 0.0759 Cementer @ 7" Intermediate 26/L-80/NSCC 6.276" 0' 11,967' 0.0383 6,976' Th. 5" Liner 15/13CR-80/FL4S 4.408" 11,808' 12,830' 0.0189 TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/Hyd 533 2.441" 0' 11,710' 0.00579 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item GLM Detail:Camco KBMM/RK Latch/1" 2 1 6,013' ST 2:Port=16,TRO=2131 psi,VIv=Live,TVD=±4,586',Date=12/17/17 2 11,487' ST 1:Port=20,VIv=S/0,TVD=±6,800',Date=12/17/17 3 11,576' HES FH 7"x2-7/8"Retrievable Packer 4 11,625' X Nipple(I0=2.313") 5 11,667' X Nipple(Min ID=2.313") 6 11,708' WLEG(Bottom at 11,710') 7 11,808' 5"setting sleeve C-2(ID=5.25") 8 11,816' Liner Top Packer.HPLPO , 9 11,821' Liner Hanger.HMC i 10 11,881' 7"Landing Collar 11 11,924' 7"Sealfloat Collar w �� 3 12 11,967' 7"Sealfloat Shoe (�++ 4 13 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 MinID=2.313" > 14 12,697' Baker Landing Collar @11,625' �1 -►L_! 5 15 12,785' Baker Float Collar 16 12,830' Baker Float Shoe 6 PERFORATION DETAIL RA Tag @ 11,877 '» 7,8,8,9 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status r Fill 64'above 7"Al 10 11 Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open topped12 Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 12115ND ;,?2;,. f: GENERAL WELL INFO 12/17/17 1.25 Steal band ,,,,, - API:50-029-22541-00-00 Left In Hole--II.:''�M1f .�., Drilled,Cased and Completed by Nabors 22E -2/02/1995 3/5/2015. 13 Install ESP Completion 4ES-12/16/1997 RWO by Nabors 4E5-10/31/2000&10/31/2006 RWO by Nabors 3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/03/2010 14 RWO by Doyon 16-8/03/2012 5'a 1516 RWO by Doyon 16-6/09/2013 RWO by Nordic 3-6/09/2015 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Nordic 3-1/01/2016 PBTD=12,697'(MD)/PBTD=7,285'(TVD) Convert to Gas Lift ASR#1-12/10/2017 Revised By:TM/12/11/2017 • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-11 ASR#1 50-029-22541-00-00 195-001 12/4/17 12/11/17 Daily Operations: 11/29/2017 Wednesday No activity to report. 11/30/2017-Thursday No activity to report. 12/1/2017- Friday No activity to report. 12/2/2017-Saturday No activity to report. 12/3/2017-Sunday No activity to report. 12/4/2017- Monday Rigging up, install flow line,finish running accumulator lines, r/u handling eq. set pipe skate, & racks.Test Gas alarms w/ AOGCC inspector Brian Bixby, good R/u fill stack&surface Eq., close blinds & shell test, found leaks on manifold valves, repair same, retest good Test BOPS 250psi low 3i000asi huh as ner Hi,_ Irp&AOGCC requirements, test was witnessed by AOGCC inspector Brian Bixby Rig down test equipment, R/U tubing handling equipment for 2-7/8" Unable to circulate through choke and kill. Suspect ice plug in system.Trouble shoot circulation lines to locate freeze up. Locate frozen section of choke and kill line. Apply heat to thaw potential ice.Apply air to system and work obstruction loose. Load and tally 2 rows of 3.5" work string in prep for CSG scraper run. Drain BOPE stack, M/U blanking plug retrieving crossover to 2-7/8" landing joint. Retrieve blanking plug. Wellhead reps on location to pull BPV. M/U landing joint to TBG hanger, BOLDS and pull TBG hanger to rig floor. 67klbs to unseat hanger, 8lklbs to pick up ESP down hole. Centrilift rep remove ESP penatrator and cap string from TBG hanger. Break out TBG hanger and pup from string and L/D. P/U to next cross collar clamp and cut ESP cable/Cap tube. Run in hole until cable-less pipe is across pipe rams.Adjust BOP stack alignment to better center equipment over wellhead. Close pipe rams and R/U to reverse circulate B/U. Reverse circulate 75bbls of 9.2ppg brine through the MGS to ensure no gas was present below the ESP. Circulate @ 3.2BPM w/ 1000psi pump pressure. Continue to POOH w/ ESP completion on 2-7/8" EUE TBG. Pull ESP cable and cap string through sheave and secure on reel in spooling unit. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-11 ASR#1 50-029-22541-00-00 195-001 12/4/17 12/11/17 Daily Operations: 12/5/2017 -Tuesday Continue to POOH w/ ESP completion on 2-7/8" EUE TBG. t/7,817' Change out esp cable spool, Continue to POOH w/ ESP completion on 2-7/8" EUE TBG. t/2845' Perform rig maintenance,verify equipment fluids. Continue to POOH w/ ESP completion on 2-7/8" EUE TBG f/2,845'md to discharge heat @ 62'md. L/D ESP completion as per centrilift rep. R/D ESP pulling equipment and swap over pipe handling equipment to 3.5" in prep to RIH w/3.5" work string.Tally work string on pipe rack. P/U and M/U Baker fishing mule shoe scraper BHA and RIH on 3.5" NC-31 work string f/surface—2,370'md. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date MP E-11 ASR#1 50-029-22541-00-00 195-001 12/4/17 12/11/17 Daily Operations: '1' a " 12/6/2017-Wednesday TIH w/7" scraper assy P/U 3.5" work string f/2,370't/3,690'Troubleshoot& repair elevators Cont.TIH w/7" scraper assy P/U 3.5" work string t/6,613',fighting issues drifting string full of snow. Continue to RIH w/7" scraper assembly on 3.5" work string. Drifting work string w/wire brush assembly to clear ice and snow. Catwalk not functioning properly. Shut down and inspect. Drive cable frayed providing slack in the system. Shut down and swap out drive cable. Continue to RIH w/7" scraper assembly on 3.5" work string down to JNT 294(11,778' md). P/U/W= 105klbs, 5/0/W= 33klbs. P/U jnt 295 and work down looking for tag up. Signs of drag seen while working down. Continue to P/U and break over string weight when drag seen. Set down 25' into jnt 295 (11,802'md)w/ 10klbs.Attempt to P/U. Heavy drag seen (150klbs on weight indicator). Work pipe up to tool joint on joint 294. P/U 5' pup joint to provide room to work pipe, R/U to circulate the long way while pumping. Work circulation rate up to 3.5BPM in 0.5BPM increments=400psi, returns seen @ 0.4bbls away. Work pipe until string weight reduced to 105klbs. Swap line up and reverse circulate 2 x bottoms up= 206bbls until clean fluid is seen. 12/7/2017 -Thursday Cont. reverse circulate @ 3.5 BPM, 910 psi, getting sand in returns, circulated until clean Blow down Lines, POOH Change out BHA I d scraper assy, p/u 7" test packer Rlh w/packerassy p/u 3.5" wk string t/1097' Continue to RIH w/ Baker I.1 retrievomatic packer f/jnt 26 to jnt 250. Stab TIW, Close Annular and wait on weather. 5 12/8/2017- Friday Shut down rig for wind, blowing 40 gusting 45-50, blew down & secured well. Preform maintenance, Wind slowed, cont.tih w/7" Retrievamatic test packer f/10,060't/ 11,660', up wt 106k, do wt 36k, Set packer @ 11,651', set down 20k, ftLU test casing t/3,000psi f/30 min good, bleed down & blow down lines. POOH w/Baker Retrievamatic test packer 1/ 11,651'md to 9,745'md. Hands utilizing plastic to cap thread protectors to prevent snow from entering work string when storing in pipe tubs. Pipe skate cable found to be fraying. Inspect system to locate source of issue. Contact Prostar and discuss te"t� installation. Remove frayed cable and replace following installation guidance. Continue to POOH w/ Baker Retrievamatic , y test packer f/9,745'md to 4,220'. 12/9/2017 -Saturday Cont. to POOH w/ Baker Retrievamatic test packer f/4,220', t/surface, l/d same Prep to P/U GL completion w/2 7/8" 6.5# L-80/ Hyd 533 tubing, load pipe rack, strap &tally same, c/o handling eq. attempt to locate lift plugs for connections. Start prepping for rig move, clear snow& pack up eq. Discuss different running options. Utilize 5' pup joint w/ Hydril 563 pin and collard EUE box as a lifting sub for running the flush joint Hydril 503 TBG. R/U drift assembly (2.35" OD)to verify connections aren't becoming flared from over TQ on M/U. RIH w/ Baker PKR assembly on Hydril 503 TBG f/surface to 3,026'md. M/U connections at max 5RPM to ensure no over TQ. Verify gap between shoulders on all connections are within Hydril recommended tolerances. Lift nubbins from Northern Solutions arrive at 2:30am. Start using lift nubbins instead of pup joint lift sub. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-11 ASR#1 50-029-22541-00-00 195-001 12/4/17 12/11/17 Daily.Operatio ns: ;u ;N -$ 12/10/2017-Sunday Cont. RIH with G/L completion, p/u Hydril 503 TBG f/3,026'. t/6,619' Cont. RIH with G/L completion, p/u Hydril 503 TBG f/6,619',t/11,595', up wt 57k, do wt 22k P/U remaining pipe,TBG hanger w/pup, and M/U on floor. Wellhead reps on location to P/U and M/U TBG hanger as well as BOLDS. Land TBG hanger, RII_DS. placing tubing tail @11,708', Line up to pump corrosion inhibition down TBG taking returns up the IA. LRS on location @ 20:30 in prep to circulate fluids, test TBG and CSG, and circulate freeze protect. LRS take on corrosion inhibition as well as 80bbls of 9.2ppg brine from rig pits. Roll fluids to blend. Pull out fluid lines and rig up to circulate fluids. Pump 80bbs of corrosion inhibition down TBG w/ LRS. Chase fluid w/72bbls of 9.2ppg brine from rig pits. No losses noted. Bleed off pressure from circulation, open blind rams, M/U landing joint, drop ball and rod assembly, wait for ball and rod to reach RHC seat in X nipple, circulate w/rig pump @ lbpm until pressure increase noted. Bleed off pressure and line up LRS to pressure up, set PKR, and test TBG. Attempt to pressure up TBG and set PKR using LRS, recording all pressures on chart recorder. Chart recorder sensor failed. Attempt to replace rubber element on sensor. Issue getting hydraulic fluid into sensor. Decision made to use LRS recorder. LRS pressure up to 3,600psi, setting PKR @11,575'. Hold pressure to test TBG f/30 charted mins. Good Test. Bleed off TBG pressure to 2,000psi Swap over circulating alignment and have LRS pressure up IA to test PKR to 3,000psi f/30sr ed_mins. Good Test. Dump 2,000psi off of TBG to shear DCK valve from IA into the TBG. (Good indication of shear and pressure ('/\Ct� equalization) Line up and circulate 60bbls of diesel freeze protect down IA, open up TBG and allow IA to U-tube w/TBG. 12/11/2017- Monday Cont. monitor u-tube f/freeze protect, pressure eq. @ 190 psi, bleed back 2 bbls t/ pits, shut in annulus, bled tubing down, pumped 5 bbls 9.2 brine down tubing, monitored tubing, static, install BPV. Blow down lines, r/d pipe rack, rig down lines prep rig for move while waiting on weather to die down. 12/12/2017-Tuesday No activity to report. • • OF 41, TfJ 41,Ivj, ,s THE STATE Alaska Oil and Gas OAT A l Conservati®n Commission 5 = == 333 West Seventh Avenue `, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 ., A Main: 907.279.1433 L:sit), � Fax: 907.276.7542 www.aogcc.alaska.gov Bo York ,� � , ..� Operations Manager ���� � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU E-11'` Permit to Drill Number: 195-001 Sundry Number: 317-513 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, tarC\-- Hollis S. French Chair DATED this 6 day of November, 2017. FiEsDbSI ",.,PY - 5267 ti� RECEIVED • • . nil- 3 0 2017 STATE OF ALASKA � ALASKA OIL AND GAS CONSERVATION COMMISSION ° ' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Acid Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to GL ❑�. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q• 195-001 . 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-22541-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.432D • Will planned perforations require a spacing exception? Yes ❑ No 2 / Milne Pt Unit E-11 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 , Milne Pt Field/Kuparuk River Oil Pool , 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): 12,830' - 7,355'• 12,245' 6 7,048' , 2,400 12,245' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic , See Schematic 2-7/8" 6.5/L-80/8rd EUE 11,560' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Liner Top Packer and N/A • 11,816 MD/6,830 TVD and N/A 12.Attachments: Proposal Summary 2 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2 . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/15/2017 Commencing Operations: OIL Q . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman 'J Authorized Title: Oberations Ma er Contact Email: twellman(C�hilcorp.com Contact Phone: 777-8449 Authorized Signature te: 10/27/2017 COMMISSION USE ONLY Conditions of approval:�fy Commission so that a representative may witness Sundry Numbe�3r: �,-,(/ t'rJ �7 / Plug Integrity ❑ BOP Test Mechanical I Integrity - itTest ❑ Location Clearance ❑ Other: 7( 30430 Q''- 6G)P .7;73 j Z..-S--0c/ ,'.s 4 kt n ..tri --/-1-x t--- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No FirSubsequent Form Required: /6-- 1 O LI RE=3 ft S LV LT t - i;; 17 APPROVED BY // 1,--1 Approved by: COMMISSIONER THE COMMISSION Date: I t j fig, .A,:,/,_ , lobo ti /1-3 -/ 7 C.Pc Submit Form and 4') Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate `�� . 13 • • RWO—Convert to GL Well: MPU E-11 Hikcora Alaska,LL) Date:10/11/2017 Well Name: MPU E-11 API Number: 50-029-22541-00 Current Status: SI -Oil Well [ESP] Pad: MPE-Pad Estimated Start Date: November 11, 2017 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-001 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: WeIIEZ Input Required: Yes Current Bottom Hole Pressure: 3,050 psi @ 7,000' TVD (BHP Projected from PBU 09/29/17; EMW= 8.38 ppg) Maximum Expected BHP: 3,050 psi @ 7,000' TVD (BHP Projected from PBU 09/29/17; EMW= 8.38 ppg) Current Shut-In Tbg Pressure: 80 psi Recorded on 10/12/17 Max. Predicted Surf Pressure: 2,400 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: The Milne Point E-11 well was drilled as a Kuparuk development well that TD'd at a depth of 12,830' and ran and cemented 5" liner in February 1995. The well was perforated in the Kuparuk B & C sands and initially completed with an ESP. Subsequent failed ESP change outs occurred in 1997, 2000, 2006, and 2007. A Through Tubing ESP (TTC-ESP) was installed in 2010, with subsequent failures and change outs in 2012 and 2013. An ESP failed in February 2015, after a 5 day run life due to a motor failure. The ESP was replaced in March 2015 and ran until late November 2015. The latest ESP failed early Oct 2017. According to well records, scale and sand production have contributed to ESP failures. Scale Inhibition Treatments (SIT) have been applied to this well in Jan 2016 and July 2017. During each of these SIT's the injectivity into the formation has dramatically reduced each time. Suspected fill up to near the bottom of the ESP is suspected. Mechanical Condition: - 7" casing was pressure tested down to 11,600' and to 3,500psi (charted)on 08/08/2012. - 7" casing was pressure tested down to 11,790' and to 2,500psi (not charted)on 02/03/2015. Objective: The objective is to utilize the ASR#1 to pull the existing completion and run a new gas lift completion. e.5'P Procedure: 61L/J Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Forward circulate at least one wellbore volume with 8ypg sea water down the tubing(thru open GLM pocket @ 11,314' md),taking returns up the annulus to the 500 bbl returns tank. a. Tubing volume from GLM @ 11,314'=66bbls b. Annular volume from GLM @ 11,314' =342bbIs c. Total volume to GLM @ 11,314' =408bbls 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane.Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house.Spot mud boat. • RWO—Convert to GL Well: MPU E-11 Hileorp Alaska,LLD Date:10/11/2017 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. 12. Kill well w/8.5 ppg seawater as needed. Set TWC. 13. Test BOPE to 250 psi Low/3.000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. o�✓ �/ a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. / b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" &3-1/2" test joints. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor ( m^'� the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking r 1114 d. anywhere at surface.) ' I v4 d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint(EUE) and BOLDS. 17. Pull over string weight (landing PU wt= 119k during 1/2/16 RWO)on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH with the ESP completion. a. Note: Observe for any possible holes in the tubing string. b. Note depth and take samples of any scale or solids deposits found. c. Report any abnormalities to Ops Engineer. d. Clamp Count: i. 190 cross collar clamps ii. 2 flat guards iii. 5 protectolizers 19. Change over handling equipment to 3-1/2" and PU 3-1/2"workstring. 20. MU 7" casing scraper assembly and RIH. Reciprocate w/scraper in 7" 26#casing around 11,550'— 11,650'M D. 21. RIH and tag top of 5" liner(10=4.408") and circulate a minimum of 1.5 bottoms up or until returns are clean. 1,1[ IP • RWO-Convert to GL Well: MPU E-11 Hilcorp Alaska,LL) Date:10/11/2017 a. During the Dec'15 RWO,while circulating at the 5" liner top 95%returns were observed while reverse circulating. 22. POOH with casing scraper. L/D scraper assembly. , , 23. MU test packer and RIH on workstring to+/-11,650' md. Kt I 24. Set test packer and pressure test 7"casing to 3000psi for 30 min (charted). I (73.- 25. 7 .25. Unseat test packer and POOH while laying down the workstring. C° 26. RU spoolers and prep to run the 2-7/8"gas lift completion. 27. RIH with 2-7/8" completion with gauge mandrel. 28. Record PU and SO weights prior to spacing out the WLEG to be at±11,710' and ("100' above the 5" liner top packer). a. Packer setting depth is±11,600' md. 29. Reverse circulate 100bbIs of seawater with corrosion inhibitor followed by 250 bbls of seawater. 30. Land the tubing hanger and RILDS. Lay down landing joint. Test tubing hanger packoff to 5,000 psi. 31. Drop the ball & rod and set the packer. Increase the pressure and test the tubing to 3,500 psi for 30 minutes. /Km A 32. Bleed down the tubing pressure to 2000psi and perform an MIT-IA to 3000psi for 30 min (charted). 33. Bleed down the tubing pressure to shear out the shear-out GLV from Station#2 at 6,028' md. Pump 60bbls of diesel down the IA and allow to U-Tube across to the tubing. 34. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 35. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 36. RD mud boat. RD BOPE house. Move to next well location. 37. RU crane. Pull BPV.Set TWC. ND BOPE. 38. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 39. Move 500 bbl returns tank and rig mats to next well location. 40. Replace IA pressure gauge if removed (7"). 41. Turn well over to production. RU well house and flowlines. 42. RU SL and pressure test to 250psi low/2,500 high. 43. Pull ball and rod from the XN nipple at 11,680' md. 44. Pull GLV's from Station#1&2. 45. Set Dome GLV in Station#2 at 6,028' md. 46. Set orifice valve in Station#1 at 11,485' md. 47. Pull RHC plug from XN nipple at 11,680' md. 48. RD SL unit. Note a separate Coil Tubing Procedure will be written for the FCO. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO Changes Form Milne Point Unit • • Well: MPE-11 SC EMATI C Last Completed: 1/01/16 flacon)Alaska,LL( PTD: 195 001 Orig.KB Elev.:53.83'/GL Elev.:24.40 TREE&WELLHEAD RKB Elev=33.55'(Nabors 22E) Tree Cameron 4-1/16"5M FMC 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger 14.i d Wellhead Hydril 521 Top&Btm,3"CIW H BPV profile 20. ti OPEN HOLE/CEMENT DETAIL + 1 1 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/370 sks Class"G"in 8-1/2"Hole ' 0', 5" Cmt w/145 sks Class"G"in 6"Hole CASING DETAIL 3, * Size Type Wt/Grade/Conn ID Top Btm BPF 9-5/8" ; 20" Conductor 91.1/H-40/N/A N/A 0' 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/BTC 8.835" 0' 3,455' 0.0759 Cementer @ 7" Intermediate 26/L-80/NSCC 6.276" 0' 11,967' 0.0383 6,976' "---4,II 5" Liner 15/13CR-80/FL4S 4.408" 11,808' 12,830' 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8RD EUE 2.441" 0' 11,560' 0.00579 WELL INCLINATION DETAIL asSSC emca Injection Line @ KOP @ 1,000' 11,560' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item IV517 1 204' STA#2:2-7/8"x 1"Side Pocket KBMM GLM(SOV) 2 2 11,314' STA#1:2-7/8"x 1"Side Pocket KBMM GLM Mn ID=2250 3 11,487' 'XN'Nipple(2.250"ID) @11,48Y I 3 I. 4 11,498' Discharge Head GPDIS ' t� ------- ---- 5 11,499' Pump-161P11/PMSXD mik 4 6 11,521' Gas Separator GRSFTX 7 11,526' Upper and Lower Tandem Seals 5 8 11,539' Motor MSP1-325/210HP/2145 V/59A ,` 9 11,556' WeIILIFT Sensor -"";I;(;I- '6 10 11,558' Centralizer-Bottom 11,560'/ND=6,704 V 7 11 11,808' 5"setting sleeve C-2(I0=5.25") j 12 11,816' Liner Top Packer.HPLPO ` �C R a 13 11,821' Liner Hanger.HMC 666 Y; I 8 14 11,881' 7"Landing Collar 15 11,924' 7"Sealfloat Collar 9 16 11,967' 7"Sealfloat Shoe :10 n 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 18 12,697' Baker Landing Collar RA Tag @19 12,785' Baker Float Collar 11,877 �� ;, x11,12 8,13 20 12,830' Baker Float Shoe 7" 6 1 15 PERFORATION DETAIL Fill Cleanout to: 16 12,222 ru Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status on 12/30/15 Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open 1.25 Steal band Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated Left In Hole--10..:.., ,.?`�, 3/5/2015. :'!"--7-.+,?' 17 GENERAL WELL INFO API:50-029-22541-00-00 Drilled,Cased and Completed by Nabors 22E -2/02/1995 Install ESP Completion 4ES-12/16/1997 18 RWO by Nabors 4ES-10/31/2000&10/31/2006 5"A 1920 RWO by Nabors 35-3/28/2007 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Nabors 4ES/TTC-ESP Completion-6/03/2010 PBTD=12,697'(MD)/PBTD=7,285'(ND) RWO by Doyon 16-8/03/2012 RWO by Doyon 16-6/09/2013 RWO by Nordic 3-6/09/2015 RWO by Nordic 3-1/01/2016 Revised By:TDF 7/13/2017 • Milne Point Unit Well: MPE-11 PROPOSED SCHEMATIC Last Completed: 1/01/16 'flacon)Alaska,LLC PTD: 195-001 Ori g.KBEIev.:53.83'/GLElev.:24.40 TREE&WELLHEAD RKBElev=33.55' Nabors Tree Cameron 4-1/16"SM FMC t r ; 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger 20 `t,t k Wellhead Hydril 521 Top&Btm,3"CIW H BPV profile OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/370 sks Class"G"in 8-1/2"Hole 5" Cmt w/145 sks Class"G"in 6"Hole CASING DETAIL te Size Type Wt/Grade/Conn ID Top Btm BPF 9-5/8" ' 20" Conductor 91.1/H-40/N/A N/A 0' 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/BTC 8.835" 0' 3,455' 0.0759 Cementer @ ;' 7" Intermediate 26/L-80/NSCC 6.276" 0' 11,967' 0.0383 6,976' \►_ g 5" Liner 15/13CR-80/FL4S 4.408" 11,808' 12,830' 0.0189 �1 TUBING DETAIL 1 2-7/8" Tubing 6.5/L-80/Hyd 533 2.441" 0' 11,700' 0.00579 WELL INCLINATION DETAIL tik " KOP @ 1,000' ry"(r 10 5..' Max Hole Angle=63 deg. f/3,000'too 11,300 ) 5°i' 5- � Hole Angle through perforations=58 deg. '�7 JEWELRY DETAIL No Depth Item GLM Detail:Camco/RK Latch/1-1/2" I 2 1 ±6,028' ST 2:Port=0,Dev=,VIv=Dummy,TVD=±4,586',Date= m 2 ±11,485' ST 1:Port=0,Dev=,VIv=Dummy,TVD=±6,800',Date= 3 ±11,530' X Nipple(ID=2.313") 4 ±11,600' 7"x2-7/8"Retrievable Packer 5 ±11,648' X Nipple(ID=2.313") 6 ±11,680' XN Nipple(Min ID=2,25") 7 ±11,710' WLEG(Bottom at±11,701') 3 8 11,808' 5"setting sleeve C-2(ID=5.25") 9 11,816' Liner Top Packer.HPLPO 10 11,821' Liner Hanger.HMC ,, 11 11,881' 7"Landing Collar r''''.4 ,h;,,Q' 4 12 11,924' 7"Sealfloat Collar - 13 11,967' 7"Sealfloat Shoe 14 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 MnIo=2.250" g mi s'; @±11,670' won. 6 tiMffil ,1 15 12,697 Baker Landing Collar 16 12,785' Baker Float Collar 1 7 I 17 12,830' Baker Float Shoe RA Tag@ ' • 11,877 ,, „ 8,9&10 7": 11'11 12 PERFORATION DETAIL Fill Cleanout to: 13 12,222'ND Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status on 12/30/15 Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Sf'•cr.-r' A 1.25 Steal band <cr Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated •Left In Hole--10. ,,., ` 3/5/2015. 14 GENERAL WELL INFO API:50-029-22541-00-00 Drilled,Cased and Completed by Nabors 22E -2/02/1995 Install ESP Completion 4ES-12/16/1997 15 RWO by Nabors 4ES-10/31/2000&10/31/2006 5"4 1617 RWO by Nabors 35-3/28/2007 TD=12,830'(MD)/TD=7,355'(1VD) RWO by Nabors 4ES/TTC-ESP Completion-6/03/2010 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-8/03/2012 RWO by Doyon 16-6/09/2013 RWO by Nordic 3-6/09/2015 RWO by Nordic 3-1/01/2016 Revised By:TTW 10/26/2017 • Milne Point 2016 ASR Rig 1 Knight Oil Tools BOl' 1 11Q,,.,„ t1,.r., 1.1 t. l w...._ Stripping Head I P affer_. ° 11" - 5000 I1 III III 111111 Adak iv [U1 11 it Iv 27/8" -5" VBR EMIL. C sm. .�- cole. I ulit _ 0 ...,.. Blind nom2" Kill Line 2" Choke Line `tit 1 3 T 1 T f fia _-- - 1 •\ t ; E 0. -4) ; 1 i, ILI [11- .,‘4 111, ,R :;1I1 ! I'&i:1;1 r -1 U a Manual Manual ,,, �_ Manual HCR Updated 2/29/16 • • • MPE-11 Swab Valve Cameron FLS-2 2 9/16" 5K tree with 9/16'"5K,manual gate valve, )1. ili +. EE P512,PR2 27/8"tbg hgr _..m i in PN 141522-31-02-01 iv L e"r • ; Wing valve Cameron FLS-2 y 9/16"5K,manual gate valve, EE P512,PR2 111 PN 141522-31-02-01 I II SSV Cameron FL5-2 9/16" 5K,reverse actuating gate valve,EE.P512,PR2 w/ Cameron actuator PN , 174370-08 I,iti 1,' Assy PN 207043-03-03-01 > is , \\.':-- -v7 mumummw Master Cameron FLS-2 9/ ilmiiimmonio 16"5K,manual gate valve,EE PSL2,PR2 Note,this tbg HGr can be PN 141522-31-02-01 plugged on top for BOPS -° equipment testing. `�.o° Tbg Md adapter FMC 11"5K One ESP cable and lea 3/8" x 2 9/16"5K,rotating control line !.t IIIII flanges,w/tea control line preps and 2ea 81W penetrator preps.Bottom prepped for 2 7/8"seal sleeve. 1 f— ftftt PN 134132-0002 . 141 .i,.-M _ 4 rr`sii s. lel i Is' til i i le. I i-U)CG�j �I 4 11 L.Yrt1"1 1St �i Ari l .1 a i i i i/1 1 ■lM ',f PRF t' 40 41 , . u g < ullElw, 1:0 L..t. T •a ti,= 00 a•P ti. 8 ..t, > 0 `: ',f,id c'4' D i g• -d ." CI P:li e ta 4; 1 ‹ MXg10 1, 1 —024-04 ) gn . .• 13 9 ot . 2 t• . t z P_ , Dc4 L' PolOc4-1x4 . o i r- z 1 Z) G3 TT3 143 0 1/ 6 81 .• , 83 u, a i 'A 81 E ., . A -4 11 i 5 if-j i A i a E , cl•4:1 ,. ,Y M Non0Eni 4.•i...2R0R..1 t G,:;oL."..•'"...•„'.. -.,.•.'".- ...•',.,.,:...-..., - j7r9d_9iQ - - ..•- 1 . ll 8 > 2 5 ea I Di/g>1 i u9 Ill I i i t n 1 i 0 1 I ! • • I.:,•a t; -n ;., > g .g . I <21 H X E 0-1f3C1 GI R.:4—ixxl P J-44 0 — OID 91) "3 R 0 .5 6 > . . x '' . . °1 u, , .2 2 DD04003-904 8 .s '-'' 2 V t- 0 Z) co - z V :', G)VD VT) 4 0 tr s g 0 0 0 ._. 1§, 4 g)01 2 ' o C n e I, L, ii , 0 t .. •_,. d•'til: I ,, ,P r1-7,_ ,---rP < Sunni < ct,._ . r C -14 '• - s' . ,. • : Q ei:el 1 1 ....1.... •: : ;.:...,..,... r6e f 9 v •.Q t a il N 2 ' t 0 i o c c V 0. a x 01 1..4. 0 1. • • a X �p-�aa el 7,-.o OID bol D , o w OIJ 9TJ o fflI o y 1 2 " �( N Q F Uat `r F11 t:A♦ l,bt 2 13 F, z w ZJ +- OJ TTJ 4TJ . a w > V3 m° ¢ a J Q 6 n$ a> 0 Lo m d m V N q 8J U A :7 N • 'C 1 �j 0 6 O 8 U 8 y a S o j 0 fii t — _ 60 Y -. C[ J11f t '. YYz �.r 7��A .• z E y J a c m m T 401 z L2 9N x °a JL A ^rj o. —N- -11 n —r�'- i —11 I-- C U e6 101: -Li 4. � T I 1j . • • STANDARD ELL PROCEDURE !Mori) 111110G EN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets(formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank.Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher.Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the Job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 . 0 • I . I i 1 1 I to 1 M to .. E Eg ta E ill ou' mm 13 7..:'1".• § T i 4. <9 § :: : .. .. — ..:„..: *. f5 65 6 rei Lc7) n 2 n 2 ii-Tr ft) — ...._ - - -4-003--- -44mxzzo 0. ... - . . .. _ % z NI ..-- F." ' I.' WI •0 6 "... 2 .„ ." E L ,0' ° .... • :::. 9 4 8' .g ›-. - R. -.. 0, . , : ... w .-. 7-.• t4 ,.s , s••• ___ ?.• ,._) > 0 co c..., R. 1... . , , t . 1,III*' 41 g 0 - ,... 44 1.04 1,41 116., . I If i ; : I I 2,- g 1 •,. • , Noe ,,, , ....., .1 ,c, 8i.pt _ ialummi If 11•11(4:)111101 0 w-.1, ___ . 1 ii, 1 . I 1 111 T U il It K 0 al w LI 0 o cd tn cy, V JC .1 F-• ..l" Co ; VI 6' 411 • •.. . ! 7 / .0 0 0 c7 \ f \ � ± § I2 \ \ 7 \ ± E • c <- EE 8 a) e 73 f 6 2 ›-..03 > f a �E /0 < cu 0 0 = y §\ t > CU CO 0 3 a I a) Cti c GfIt = e \k /\ I o5 % '- 2 < .oa @ § 7 / m �� _ o "0 \\ L. ± ° 2 k L. \ k § 0 , 2 k \ \. I b 0 2 .o ' c L. =0 n g 0 f \0 § /\ @ w m c g to ] q & k § " > = 2 7 • / /' • \ Q > ® a° 0 I 2 k �0 Eva - & a { o « 0 \ \ § m® CI ) 7 0 / � a / % 7 . w \ / \ ¢ \ f ° � ® 2 % Al ) •a 2 \] k / � 3 / / \ $ < a 0 m f ! I Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday, October 10, 2017 9:49 AM To: 'Taylor Wellman';Schwartz,Guy L(DOA) Cc: Tom Fouts Subject: RE: MPE-11 Acid Stim (PTD#195-001)Sundry Application#317-466 Withdrawal Taylor, Sorry to hear that ESP cratered... AGOCC will withdraw the submitted Sundry 317-466 for acid stimulation as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC < : ,: `NE J NOV 0 9201z 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From:Taylor Wellman [mailto:twellman@hilcorp.com] Sent:Tuesday, October 10, 2017 9:48 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Tom Fouts<tfouts@hilcorp.com> Subject: MPE-11 Acid Stim (PTD#195-001)Sundry Application#317-466 Withdrawal Guy, We would like to withdraw the Sundry Application#317-466 for the acid stimulation on MPE-11(PTD#195-001). During an attempt to flush the ESP,the ESP shorted and is dead. The well will require a RWO. Any acid work that may be considered in the future will be included in a RWO procedure. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com 1 • • RECEIVED STATE OF ALASKA OCT 0 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Acid Stimulate D% Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP hange-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Numb- Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 1• 101 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service El 6.API Ntj�;.4 Anchorage Alaska 99503 vik'N `a-029-22541-00-00 • 7.If perforating: 8.Well Nam,711.4 lumber: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No QQ ✓ Milne Pt Unit E-11 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 Milne Pt Fi N. A.aruk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): s`, Plugs(MD): Junk(MD): 12,830'* 7,355' ' 12,245" 7,048' I 12,245' N/A Casing Length Size MD / f� \ r \� Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Production 11,967' 7" 11,967' � 6,905' 7,240psi 5,410psi Liner 1,022' 5" 1 830 % \ 7,355' 8,290psi 7,250psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 41- \•.) Tubing Grade: Tubing MD(ft): See Schematic/ See Schematic - i.' •� 6.5/L-80/8rd EUE 11,560' Packers and SSSV Type: 'ackers and SSSV MD(ft)and TVD(ft): Liner Top Packer and N/A , 11,816 MD/6,830 TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schem. ' `a 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: 10/15/2017 Commencing Operations: OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR Commission Representative: CI SPLUG CI ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and t . procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name:Taylor Wellman '1'7i,-J Authorized Title: Operations Manager Contact Email: tweliman(' hiIcorD.com Contact Phone: 777-8449 Authorized Signature: Date: 2 c} )3 COMMISSION USE ONLY Conditions of approval: Notify Commis-on so that a representative may witness Sundry Number. ;3/....1 th / Plug Integrity ❑ BIP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Sryle�NNEO N O V 0 9 2017 Post Initial Injection MIT 'eq'd? Yes ❑ No ❑ Spacing Exception Re. ired? Yes ❑ No g Subsequent Form Required: 10- 4/6 APPROVED BY RB D irS Lr, 1::v - 2 2017 Approved by: COMMISSIONER THE COMMISSION Date: iv, ity(eo. ,f4oi477 /0,-/,--/ 7 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for loops IrDtlIe NTArvai. Attachments in Duplicate • •. 11 Acid Stim Well: MPE-11 PTD: 195-001 IIilcorp Alaska,LL) API: 50-029-22541-00 Well Name: MPE-11 API Number: 50-029-22541-00 Current Status: SI—Inflow issue post SIT Rig: Pump Truck Estimated Start Date: Sept 28, 2017 Estimated Duration: 1 days Reg.Approval Req'std? YES Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 202-054 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228(M) AFE Number: Sundry/WeIIEZ Input Req'd: Yes Current Bottom Hole Pressure: —2,991 psi @ 7,000' tvd (Last measured on 02/19/15) Maximum Expected BHP: 50psi (Wellhead pressure on 7/11/17) Max.Anticipated Surface Pressure: 50psi ' (Wellhead pressure on 7/11/17) Brief Well Summary: The Milne Point E-11 well was drilled as a Kuparuk development well that TD'd at a depth of 12,830' and ran and cemented 5" liner in February 1995. The well was perforated in the Kuparuk B & C sands and initially completed with an ESP. Subsequent failed ESP change outs occurred in 1997, 2000, 2006, and 2007. A Through Tubing ESP (TTC-ESP) was installed in 2010, with subsequent failures and change outs in 2012 and 2013. The current ESP failed in November 2014 and the well has remained shut in ever since. According to well records, scale and sand production have contributed to ESP failures. Scale Inhibition Treatments (SIT) have been applied to this well as recently as June 2013. The most recent SIT was pumped down the backside to the formation on 07/09/17. Following the SIT, the well has shown motor spikes and high temps. Slickline drifts with bailers reach the pump and recover no sand/fill on the pump. All indications point to an ipflow problem from the formation. Objective: Perform a matrix acid stimulation of the Kuparuk. Notes: Volumes (all rounded up) Backside volume: 11,558'x 0.0302bpf= 349bb1s Tubing Tail to LTP: 250'x.0383bpf= 10bbls i LTP to Top Perf: 368'x.0189bpf= 7bbls Procedure: Acid Pumping 1. RU pumping unit and hardline to pump from transports down the IA of MPE-11. Pressure test all hardline to 250psi low/4500psi high. 2. Pump the following down the tubing while taking returns to the formation. a. Do not exceed frac gradient. Confirm Max pump pressure with OE prior to pumping job. b. Max pump rate=Sbpm -7 05, (5.{ , c. Last IA fluid level shot was at"2,600'(79bbls) d. Monitor injection rates after"100bbIs of fluids have been pumped away. If well locks up, do not pump acid into the IA. Contact OE for further discussion. e. Monitor IA pressures throughout job to ensure no leakage is observed. • ll • • Acid Stim Well: MPE-11 PTD: 195-001 Hi(cora Alaska,LLD API: 50-029-22541-00 Stage Fluid Action Stage Vol (bbls) Cum Vol (bbls) 1 Seawater Matrix injectivity test 150 150 2 Xylene+ Diesel Solvent 40 190 3 DAD Acid Main acid 8 270 4 Seawater Displacement 355 625 Note:Volumes are approximates and may vary slightly during actual execution. 3. Ensure well is lined up to flow to a flowback tank and start ESP. 4. Check fluid samples of the return fluid for pH until it is acceptable to swap back to flowing the well to the plant. • • Milne Point Unit Ili Well: MPE-11 SCHEMATIC Last Completed: 1/01/16 Ilileorp Alaska,LLC PTD: 195-001 Orig.KBElev.:53.83'/GLEIev.:24.40 TREE&WELLHEAD RKB Elev=33.55'(Nabors 22E) Tree Cameron 4-1/16"5M FMC ., Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger 20lt Hydril 521 Top&Btm,3"CIW H BPV profile OPEN HOLE/CEMENT DETAIL 1 20" Cmt w/250 sks of Arcticset I in 24"Hole r 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/370 sks Class"G"in 8-1/2"Hole 5" Cmt w/145 sks Class"G"in 6"Hole CASING DETAIL '. Size Type Wt/Grade/Conn ID Top Btm BPF 9-5/8" 20" Conductor 91.1/H-40/N/A N/A 0' 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/BTC 8.835" 0' 3,455' 0.0759 Cementer @7" Intermediate 26/L-80/NSCC 6.276" 0' 11,967' 0.0383 6,976' : 5" Liner 15/13CR-80/FL4S 4.408" 11,808' 12,830' 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8RD EUE 2.441" 0' 11,560' 0.00579 WELL INCLINATION DETAIL 3/8"SS Chemical Injection Line @ KOP @ 1,000' 11,560 Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item 1 204' STA#2:2-7/8"x 1"Side Pocket KBMM GLM(SOV) 2 2 11,314' STA#1:2-7/8"x 1"Side Pocket KBMM GLM MnID=2.250II 3 11,487' 'XN'Nipple(2.250"ID) @11,487'--....._4.d 3 4 11,498' Discharge Head GPDIS 11 5 11,499' Pump-161P11/PMSXD Mir 4 6 11,521' Gas Separator GRSFTX 7 11,526' Upper and Lower Tandem Seals 5 8 11,539' Motor MSP1-325/210HP/2145 V/59A ; I° . _9 11,556' WeIILIFT Sensor ;A AiMI I ►6 10 11,558' Centralizer-Bottom 11,560'/TVD=6,704 r* it 4'7 11 11,808' 5"setting sleeve C-2(ID=5.25") '' 12 11,816' Liner Top Packer.HPLPO *A1 IgIF 11 _13 11,821' Liner Hanger.HMC 5-, it 8 _14 11,881' 7"Landing Collar p r. 15 11,924' 7"Sealfloat Collar V 9 16 11,967' 7"Sealfloat Shoe ) 110 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 F# 54 ___8 12,697' Baker Landing Collar RA Tag@ § 19 12,785' Baker Float Collar 11,877' 411,128,13 20 12,830' Baker Float Shoe 7 . 14 15 PERFORATION DETAIL Fill Cleanout to: 16 12,227 MD Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status on 12/30/15 _ Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open lig ,:?- 1.259teelband ^:'.'.'.,sem Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated Left In Hole--►?fi`4. 3/5/2015. 17 GENERAL WELL INFO - API:50-029-22541-00-00 Drilled,Cased and Completed by Nabors 22E -2/02/1995 Install ESP Completion 4ES-12/16/1997 18 RWO by Nabors 4ES-10/31/2000&10/31/2006 5"A 61920 RWO by Nabors 3S-3/28/2007 TD=12,830'(MD)/1D=7,355'(TVD) RWO by Nabors 4ES/TTC-ESP Completion-6/03/2010 PBTD=12,697'(MD)/PBTD=7,285'(ND) RWO by Doyon 16-8/03/2012 RWO by Doyon 16-6/09/2013 RWO by Nordic 3-6/09/2015 RWO by Nordic 3-1/01/2016 Revised By:TDF 7/13/2017 STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMOSION v REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well u Plug Perforations Perforate El Other 0 ESP Changeout Performed: Alter Casing Li Pull Tubing j Stimulate-Frac ❑ Waiver El Time Extension fl Change Approved Program El Operat.Shutdown j Stimulate-Other Li Re-enter Suspended Well LI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q✓ Exploratory 0 195-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ID 6.API Number: Anchorage,Alaska 99503 50-029-22541-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 Milne Pt Unit KR E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Pt Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: fp�� Total Depth measured 12,830 feet Plugs measured 12,245 feet ._ true vertical 7,355 feet Junk measured N/A feet F r_n o I 2016 Effective Depth measured 12,245 feet Packer measured 11,816 feet true vertical 7,048 feet true vertical 6,830 feet'4 Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 2,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Intermediate Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation depth Measured depth See Attached Schematic SCONMED True Vertical depth See Attached Schematic C v '+'. Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 11,560'(MD) 6,704'(TVD) 11,816'(MD) Packers and SSSV(type,measured and true vertical depth) Liner Top Packer N/A 6,830'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 320 0 Subsequent to operation: 97 20 797 120 189 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑I Gas 0 WDSPL GSTOR ❑ WINJ 0 WAG Li GINJ El SUSP Li SPLUG El 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: ,7 _ 315-760 Contact Ted Kramer Email tkramerhilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 907-777-8345 Date 1/29/2016 Form 10-404 Revised 10/2012 3;2_`C RBDMSFEB 0 2 2016 OriginalOnly CL Submit H . • Well:Milne PointMPE-11 Unit , 14 SCHEMATIC Last Completed: 3/6/15 Mean)Alaska,LLC PTD: 195-001 TREE&WELLHEAD Orig.KB Elev.:29.43'/GL Elev.:24.40' Tree Cameron 4-1/16"SM FMC € 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger '44 k! Wellhead 20'� et Hydril 521 Top&Btm,3"CIW H BPV profile 4` I p IP, i OPEN HOLE/CEMENT DETAIL e. 1 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole V, A' 7" Cmt w/370 sks Class"G"in 8-1/2"Hole i 5" Cmt w/145 sks Class"G"in 6"Hole 1 CASING DETAIL <. 9-5/8" ` Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 91.1/H-40/N/A N/A 0 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 0.0759 Cementer @ 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' 0.0383 6,976' 5" Liner 15/13CR80/FL45 4.408" 11,808' 12,830' 0.0189 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 11,560' 0.00579 3/8" Capstring Stainless Steel N/A 0 11,560' N/A 3/8"SS Chemical WELL INCLINATION DETAIL Injection Line @ ±11,550 KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item 1 204' STA#2"2-7/8"x 1"Side Pocket KBMM GLM(SOV) 2 2 11,314' 2-7/8"x 1"Side Pocket KBMM GLM Nin ID=2.250" 3 11,487' 'XN'Nipple(2.250"ID) @11,487'- >.zal, 3 4 11,498' Discharge Head GPDIS ir 5 11,499' Pump-160p11/SSD AR 4 6 11,513' Gas Separator GRSFTX 7 11518' Upper and Lower Tandem Seals 5 8 11,531' Motor MSP1-250/210HP/2145 V/59A 9 11,548' WeIILIFT Sensor 14 I'11 yi 6 10 11,556' Centralizer-Bottom 11,560'/TVD=6,704 7 11 11,808' 5"setting sleeve C-2(ID=5.25") 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC 8 14 11,881' 7"Landing Collar 15 11,924' 7"Sealfloat Collar 9 16 11,967' 7"Sealfloat Shoe 110 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 4!j , 18 12,697' Baker Landing Collar RAT @ # 19 12,785' Baker Float Collar 11,877' *111,12&13 20 12,830' Baker Float Shoe 7"ii X14 15 PERFORATION DETAIL 16 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 125 Steal band = Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Left InHole----y Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 3/5/2015. GENERAL WELL INFO MEM 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 18 RWO by Nabors 4ES-10/31/2000&10/31/2006 5"4 *1920 RWO by Nabors 3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(1VD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(1VD) RWO by Doyon 16-6/9/2013 RWO by Nordic 3-6/9/2015 ESP Change-out by Nordic#3-1/31/2015 Revised By:TDF 1/29/2016 • • Hilcorp Alaska, LLC HilcorpAlaska.LEX 'Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-11 Nordic 3 50-029-22541-00-00 195-001 12/26/2015 12/31/2015 1V2171",Wednesday D d yr.u���N�V� No Operations to Report. 12/24/15-Thursday ,. i' - No Operations to Report. 12/25/15-Friday No Operations to Report. 12/25/15-Saturday i1190016- 0ash Move off MP E-19,Spot rig on MP E-11,Rig accepted @ 15:30 hrs.Note:Complete pre pad inspection for E-11,close out post pad inspection for E-19, Spot tanks and support equipment,winterize cellar.PJSM,pull BPV with well support,280 psi on tubing and I/A,O/A 200 psi.Load 140 deg heated 8.5 ppg seawater in pits.Spot kill tank,R/U lines in cellar and hardline.Test lines to 2500 psi using diesel.Note:AOGCC rep Lou Grimaldi verbally waived witness to E-11 BOP test @ 18:45 hrs on 12/26/2015,Pre well kill spud meeting,bleed I/A and tubing from 280 psi to 0 psi thru choke with returns to kill tank.All gas,no fluid.Line up to reverse circulate taking returns thru choke to kill tank,pump 30 bbls 8.5 ppg heated seawater down tubing 3 bpm,60 • llowed with 25 bbl bara clean 8.5 ppg pill,58 bbls away caught fluid and started getting diesel returns,70 obis away pres sing to 70 psi,mostly crude returns.130 bbls away,tbg pressure increasing to 710 psi w/produced water and mixed gas @ returns,200 bbls away,735 psi see oil returns.445 bbls away,700 psi,dirty seawater returns.Shut in well,monitor on choke 30 min.w/no pressure increase while Vac truck suck out kill tank to handle more returns.Continue to reverse circulate @ 3 bpm,600 psi pumping 127 bbls,returns still dirty with some gas breaking out @ 8.5 ppg,pump another 64 bbls @ 3 bpm,670 PSI down tbg with returns out I/A.(pumped total 636 bbls,561 bbls returned to kill tank,54 bbls to fill hole,21 bbl losses)Note: monitor O/A while circulating,200 psi,Shut in and monitor well for 30 minutes,tubing and I/A on slight vac.Blow down and R/D lines.Install BPV per wellhead rep.Function LDS.PJSM,N/D Tree,inspect hanger threads,2 7/8"8rd,only 6 3/4 turns,#7 thread is damaged,also hanger control line top port is not threaded to install 3/8"npt plug,wellhead rep threaded hanger port and install 3/8"plug,also dress EUE hanger threads,able to get 8 1/4 turns.Note:monitor I/A,continues on slight vac.N/U 11"5M BOPE. 12/27/15- t#ndxl x -Yr aii hi��d �� 6ik W �' . si Continue to NU BOPE.Test BOPE to 250 psi low,3000 psi high f/5 charted minutes each test usin2 7/8"test jt.Test annular to 250 psi low,2500 psi high.Test annular to 250 psi low,2500 psi high using 2 7/8"test jt.Pull 2 7/8"test jt.&install 3 1/2"test jt.-Test top VBR's to 250 psi low,3000 psi high f/ 5 charted min.each test using 3 1/2"test jt.Perform Accumulator draw down test:System press.=3000 psi-After closure=1900 psi-200 psi attained in 18 sec.-Full pressure attained in 96 seconds.Pull TWC per Wellhead Rep.MU landing jt.(8 1/4"turns).BOLDS.Pull hanger free w/120k.Pull hanger to rig floor w/115k up wt.Drop 2.31"drift on wire. L/D pup jt,hanger and landing jt. Note:25 bbls to fill I/A,Pull 1 stand from 11525'11431',string ESP cable and cap line over sheave to spooler.POOH with failed ESP completion from 11431'to 9167'racking 2 7/8"8rd tubing in derrick,SLM same.Note:Hole taking 2 bbls over calculated hole fill every 5 stands.M/U head pin and FOSV, pump down tubing and circulate oil cap out of I/A to help keep ESP cable and floor equipment clean.Continue POOH w/ESP completion from 9167'to 4289'racking 2 7/8"8rd tubing in derrick,SLM same.C/O ESP cable reels in spooler.Continue POOH w/ESP completion from 4289'to 1300'racking 2 7/8"8rd tubing in derrick,SLM same.Note:Hole continues taking 2 bbls over calculated hole fill every 5 stands. i s • Hilcorp Alaska, LLC HilcorpAlaska.LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-11 Nordic 3 50-029-22541-00-00 195-001 12/26/2015 12/31/2015 1228/ Mor 014 Continue to LD ESP assembly.Note:pump shaft locked up and would not turn.Recovered 367 jts and jewelry-190 Cross Collar Cannon Clamps-4 Protectorlizers&3 Flat Guards.Clean/Clear Rig Floor.Set test plug-RILDS to energize same.Change lower rams f/2 7/8"to 3 1/2"solid.Test lower pipe rams to 250 psi low,3000 psi high f/5 charted minutes each test-Good test.Bleed off-Pull test jt&test plug-LD same.Install wear bushing,R/U rig tongs,spinners,C/O handling equipment for 3 1/2"drill pipe.M/U 7"scraper BHA as follows:mule shoe,XO,double pin sub,XO,2 boot baskets,7" scraper,bit sub=20.82',Drift and Single in the hole with 3 1/2"drill pipe to 11788' (387 jts)M/U top drive,wash to TOL @ 11808',tag with XO @ 11808' putting mule shoe @ 11820',P/U to 11791'.Note:lost 24.2 bbls while tripping in the hole.Line up to reverse circulate.close annular.Stage pump up to 4 bpm,1000 psi,see 15%sand and 5%scale at BU,circulate until clean(183 bbls)Shut down pump,open annular,obtain SPR.Flow check well.Blow down top drive.Note:9 bbl losses while circulating.Rack 1 stand back.M/U FOSV and top drive.Cut and slip 65'drilling line. Note:Monitor well with trip tank. 6 I i[. .„ allov-s li ti �J7t ,Vl Erodi, Continue to Slip and Cut 60'Drill Line.Changed out bad stud on Dead Man.POOH standing back 3 1/2"Drill pipe from 11,721'to surface.160K Up wt.Drill string started pulling wet half way out of the hole.Hole fill took 10 bbls over calculated volume.Break down,lay down, clean and inspect BHA.No debris in junk baskets.Did recover partial steel band on blade of scraper.Also found BHA packed off with sand and scale from the bit sub and 1st joint of drill pipe on top of the bit sub.Clean up rig floor and pipe shed area after wet trip.Monitor well on trip.Call for sub Bumper sub and jars.Make up BHA#2:2 3/8'Mule Shoe,XO,Double Pin Sub,2)Boot Baskets,5"CSG scraper,Bit Sub,XO,14)Jts 2 3/8"PH6 WS,XO to 3 1/2"IF,4 3/4"LBS,Jars.Total BHA Length =467.12,RIH with BHA#2 on 3 1/2 drill pipe T/5871' pick up wt.95K,Rig up Circ.hose and circ.1 pipe vol.43bb1. (long way)@ 5bpm 1220 psi.Continue RIH F/5871'T/11,750,P/U 165k S/O 100k,Make up top drive wash F 11750' to the to.of the liner • 11 820' continu- •..• •• . • • ..n A i. i o 12168',Line up to reverse circulate a hi-vis around,close annular.Stage pump up to 5 bpm,1500 psi,see 40%sand and 5%scale at BU,circulate until clean(416 bbls)Shut down pump,open annular,Flow check well(Good).Note:6bbl losses while circulating to the hole,Make up top drive and wash F/12,168' T 12,222'2bpm 340psi ,were we tagged up,setting 15k(solid)pull up to 12,170' Note:while washing through the Perfs.our return rate went from 20%to 0,Line up to reverse circulate,close annular.Stage pump up to 5 bpm,1500+/-,see 15%sand 2 scale at BU,185 bbls.was pumped until it came clean (35bb1.of sea water was lost during circ.),Open annular,flow check(Good),pumped string vol.(90bbl.)to clear pipe.shut down monitor well, Static loss rate 15bph,POOH F/12,170' laying down 3 1/2 drill pipe. • • s Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP E-11 Nordic#3 50-029-22541-00-00 195-001 12/26/15 12/31/16 Daily Operations: 12/30/2015 -Wednesday Continue to„POOH la.King down 3=1/2” drill pipe from 10,710' to BHA. Lay down LBS and Jars. C/O handling equipment and lay down 14 jts PH6 WS. Lay down 5" Scraper and Boot baskets. Recovered about a cup of Metals from boot baskets. Clean and clear rig floor of Drill pipe handling equipment. Pull Wear Ring, Set Test Plug. Change out Lower Pipe Rams to 2-7/8". Test same to 250psi/3,000psi, chart same. Rig down test equipment. Pull test plug. Make up ESP motor Assembly, service motor and seals. Rig up ESP cable and chemical injection line over sheave. Install Cap line to check valve. Fuction test (� (Good)Valve opened @ 4,300psi. Make up MLE & secure to motor. Run in the hole with 2-7/8" ESP completion and cap 1, p line.Test cable every 2,000' for continuity and the Cap Line to 4,600 psi.Test cable @ 2,010' for continuity and the Cap Line V to 4,600 psi (Good). Continue Run in the hole with 2-7/8" ESP completion and cap line F/2,010'T/4,098'. Test cable @ 4,085' for continuity and the Cap Line to 4,600 psi. 12/31/2015 -Thursday Continue to run ESP completion from 4,085' to 7,786'.Testing cable and Cap line every 2,000'.Test Cable and cap line. Change out and make cable splice on 2nd spool. Monitor well on TT while making splice with 4.8 BPH static loss rate.Test cable. Continue to run 2-7/8" ESP completion from 7,786'-To 9,779'.Test ESP cable for continuity (Good). Continue to run 2-7/8" ESP completion from 9,779 to 11,519' (Pick up weight 119k slack off 73k). Make up hanger to landing jnt and install penetrators.Terminate ESP cable and cape injection line from spools. Make up cable and cap line to hanger. Mag.Test (Good). Land Hanger. Run in lock downs. Install BPV. N/D BOP's. N/U Tree. Test to 5,000psi (Good). Note: during the tree N/U, Cape line spool was removed from the floor by crane. Pull BPV. Secure Well. Back rig off E-11 and clean up around cellar area. Nordic 3 released from MP E-11 1/1/2016 @ 4:30. 1/1/2015 - Friday No activity to report. 1/2/2015 -Saturday No activity to report. 1/3/2015 -Sunday No activity to report. 1/4/2015 - Monday No activity to report. 1/5/2015-Tuesday No activity to report. � OF T�� • ," I 1/j,�kV THE STATE Alaska Oil and Gas ti 77 ofA T �Clj Conservation Commission ri- -_- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS FEBFax: 907.276.7542 stite) B 0 ,�j1b www.aogcc.alaska.gov �,9� Bo York '` 001 Operations Engineer , I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR E-11 Sundry Number: 315-760 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, p r)124..,tcze.„\ Cathy P Foerster Chair DATED this 2i day of December, 2015 Encl. RBDMSttDEC 13 2015 I• 0 RECEIVED • STATE OF ALASKA DEC 16 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 9rs 97s !Z/Z f/'.S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E - Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:ESP Change-out 2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC ' Exploratory ❑ Development El - 195-001 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22541-00-00 . 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C. Will planned perforations require a spacing exception? Yes ❑ No 2 / Milne Pt Unit KR E-11 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 - Milne Pt Field/Kuparuk River Oil Pool , 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): 12,830' 7,355' ' 12,245'- 7,048' . 1,585 12,245' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7250 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic , See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 11634 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Liner Top Packer and N/A , 11,816(MD)&6,830(TVD)and N/A 12.Attachments: Proposal Summary RI Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 12/24/2015 ❑ WDSPL ❑ Suspended El Operations: OIL EWINJ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A 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. Contact /Jam' Ted Kramer Email tkramer( hilcorp.com Printed Name Bo York Title Operations Manager I (,, ".)z : t Signature'"-P.--------- Phone 777-8412 Date 12/16/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. -3 /6---1 CP o Plug Integrity ❑ BOP Test [i Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 3 co So Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 ./ '' ' ' APPROVED BY Approved by: P_✓ // COMMISSIONER THE COMMISSION Date: /2_ _ /5- 067 72k6 al iWi -- - Submit OPRvidGlicNiAalloi Submit Form and ��L71./If1G"L �1/�q1� 015 for 12 months om theAat3 of approval. Attachments in Duplicate • • Well Prognosis • Well: MPU E-11 Hilcorp Alaska,LLQ Date: 12/16/2015 Well Name: MPU E-11 API Number: 50-029-22541-00 Current Status: SI Oil Well [Failed ESP] Pad: E-Pad Estimated Start Date: December 24th, 2015 Rig: Nordic 3 Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-001 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,285 psi @ 7,000' TVD (BHP 12/15/2015/6.28 ppg EMW) Maximum Expected BHP: psi @ 7'000' TVD (No new perfs baidnendded)✓ 61-ie el) MPSP: (0.1 psi/ft gas gradient) Brief Well Summary_ The Milne Point E-11 well was drilled as a Kuparuk development well that TD'd at a depth of 12,830' and ran and cemented 5" liner in February 1995. The well was perforated in the Kuparuk B & C sands and initially completed with an ESP. Subsequent failed ESP change outs occurred in 1997, 2000, 2006, and 2007. A Through Tubing ESP (TTC-ESP) was installed in 2010, with subsequent failures and change outs in 2012 and 2013. An ESP failed in February 2015, after a 5 day run life due to a motor failure. The ESP was replaced in March 2015 and ran until late November 2015. According to well records, scale and sand production have contributed to ESP failures. Scale Inhibition Treatments (SIT) have been applied to this well as recently as June 2013. Notes Regarding Wellbore Condition • Casing tested to 3,500 psi for 30 minutes down to 11,600' MD on 8/08/2012. • Casing was pressure tested to 2,500 psi. with no leak off down to 11,790' on 2/3/2015 (not charted). ' Objective: Replace a failed ESP. Note: A planned SIT will be pumped following RDMO of the Nordic#3 rig. Brief RWO Procedure: 1. MIRU Nordic#3 WO Rig. 2. Circulate well clean with 8.5 ppg sea water. 3. Set BPV. ND Tree. NU 11" BOPE. Pull BPV and set TWC. 4. Test BOPE to 250 psi low/3,000 psi high, annular to 250 psi low/2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Nordic 3 BOP Test Procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. • i i Well Prognosis Well: MPU E-11 Ilileorp Alaska.I.L Date: 12/16/2015 d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams and annular with 2-7/8" test joint. 5. Contingency: (If the tubing hanger won't pressure test due to eroded and/or corroded BPV profile and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) ���✓✓✓"" d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 6. Bleed any pressure off tubing and casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 7. MU landing joint or spear and recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 8. POOH and stand back the 2-7/8" tubing. Tubing will be re-used. Lay down failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon#16 tubing runs. c. Evaluate condition of 3/8" external capillary string for re-use. U 9. PU RIH with 7" casing cleanout assembly to top of 5" liner at 11,808' MD. Circulate the well clean. If needed, spot sized salt pill to control losses. POOH. 10. PU RIH W/5" C/O assembly to 12,245'. If needed, spot sized salt pill to control losses. POOH. a. Note: Last C/O tagged up hard at 12,196'. Consult with Operations Engineer if we tag up at same depth. 11. PU new ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing. a. Run Upper GLM @ ±200' w/valve b. Run lower GLM @ ± 11,300' w/valve c. Run 2-7/8" XN profile @ ± 11,475' MD d. Set base of ESP @ ± 11,550' MD e. Run 3/8" capillary string @ ± 11,550' MD 12. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 13. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 14. RU hot oil and freeze protect well to 2100' MD if needed. • Well Prognosis Well: MPU E-11 IliIcor" ink`,LL' Date: 12/16/2015 15. RD Nordic#3 WO Rig. 16. Turn well over to production. 17. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Nordic#3 Flow Diagram 7. Blank RWO Changes Form 1 E4 • • Milne Point Unit Well: MPE-11 ' SCHEMATIC Last Completed: 3/6/15 Hilcorp Alaska,LLC PTD: 195-001 TREE&WELLHEAD Orig.KB Elev.:29.43'!GL Elev.:24.40' Tree Cameron 4-1/16"5M FMC 3 r' 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger k' p i 'i ii Wellhead Hydril 521 Top&Btm,3"CIW H BPV profile 20" ,,: s OPEN HOLE/CEMENT DETAIL 1 1 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole v 7" Cmt w/370 sks Class"G"in 8-1/2"Hole i 5" Cmt w/145 sks Class"G"in 6"Hole 04x CASING DETAIL 9-5/8".' Size Type Wt/Grade/Conn ID Top Btm BPF 3'�C' 20" Conductor 91.1/H-40/N/A N/A 0 112' 0.355 Halliburton ES 9-5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 0.0759 Cementer @ 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' 0.0383 6,976' \►_ I 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' 0.0189 7 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 11552' 0.00579 ) 3/8" Capstring Stainless Steel N/A 0 11,552' N/A t ; 3/8 SS Chemical I ' WELL INCLINATION DETAIL Injection Une @ , 11,550 , KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item 1 202' 2-7/8"x 1"Side Pocket KBMM GLM 2 2 11,308' 2-7/8"x 1"Side Pocket KBMM GLM MnID=2.250" 3 11,479' 'XN'Nipple(2.250"ID) @11,479'-�*sig 3 4 11,490' Discharge Head GPDIS sir 5 11491' Pump-160p11/SSD AR 4 6 11,513' Gas Separator 7 11518' Upper and Lower Tandem Seals 5 n 8 11,531' Motor MSP1-250/210HP iUj1 9 11,548' WeIILIFT Sensor fil 6 /� 10 11,550' Centralizer-Bottom 11,552'/TVD=6,686' 7 11 11,808' 5"setting sleeve C-2(ID=5.25") I 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC *"8 14 11,881' 7"Landing Collar s V 15 11,924' 7"Sealfloat Collar it 'E 0-4 ` 9 16 11,967' 7"Sealfloat Shoe 3. )( q10 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 77, 18 12,697' Baker Landing Collar Tag @ 19 12,785' Baker Float Collar 111,,87T X11,12&13 20 12,830' Baker Float Shoe 7"°e az14 15 PERFORATION DETAIL 16 V Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1.25 Steal band 7=7 = Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Left In Hole ' =1 Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 3/5/2015. ® GENERAL WELL INFO MEM 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 18 RWO by Nabors 4ES-10/31/2000&10/31/2006 5„A„ ,.ii1920 RWO by Nabors 3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 RWO by Nordic 3-6/9/2015 Created By:TDF 12/16/2015 II • • Milne Point Unit Well: MPE-11 PROPOSED Last Completed: 3/6/15 Hilcora Alaska,LLC PTD: 195-001 TREE&WELLHEAD Orig.KB Elev.:29.43'/GL Elev.:24.40' Tree Cameron 4-1/16"5M FMC I Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger �* Hydril 521 Top&Btm,3"CIW H BPV profile 20' ;• OPEN HOLE/CEMENT DETAIL 1 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/370 sks Class"G"in 8-1/2"Hole i 5" Cmt w/145 sks Class"G"in 6"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 9-5/8" 20" Conductor 91.1/H-40/N/A N/A 0 112' 0.355 Halliburton ES ' i, 9-5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 0.0759 Cementer @ 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' 0.0383 6,976' 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' 0.0189 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 ±11,552' 0.00579 3/8" Capstring Stainless Steel N/A 0 ±11,552' N/A 3/8"SSCh&rical WELL INCLINATION DETAIL Injection Une @ ±11,550 KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. JEWELRY DETAIL No Depth Item 1 ±202' 2-7/8"x 1"Side Pocket KBMM GLM 2 2 ±11,308' 2-7/8"x 1"Side Pocket KBMM GLM MnID=2.250 - 3 ±11,479' 'XN'Nipple(2.250"ID) @±11,479' 1,0 3 4 ±11,490' Discharge Head GPDIS lir 5 ±11491' Pump-160p11/SSD AR ik,>, 4 6 ±11,513' Gas Separator 7 ±11518' Upper and Lower Tandem Seals 1 5 8 ±11,531' Motor MSP1-250/21OHP 9 ±11,548' WeIILIFT Sensor III � 6 10 ±11,550' Centralizer-Bottom±11,552'/TVD=±6,686' 7 11 11,808' 5"setting sleeve C-2(ID=5.25") 4w, ft 12 11,816' Liner Top Packer.HPLPO d 13 11,821' Liner Hanger.HMC I . 14 11,881' 7"Landing Collar I #Tj 8 15 11,924' 7"Sealfloat Collar 9 16 _ 11,967' 7"Sealfloat Shoe 11 140 10 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 18 12,697' Baker Landing Collar RATag @ 19 12,785' Baker Float Collar 11,877 d *11,12&13 20 12,830' Baker Float Shoe 1. 1 7"e X14 15 PERFORATION DETAIL 16 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1.25 Steal bandy = _ Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Left In Hole ® = Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 3/5/2015. ® GENERAL WELL INFO MEM 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 18 RWO by Nabors 4ES-10/31/2000&10/31/2006 5„4 161920 RWO by Nabors 3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 RWO by Nordic 3-6/9/2015 Created By:TDF 12/16/2015 • Milne Point Nordic#3 BOP 12/16/15 titl,•„tr Uia.i.a.I•L( f 1 VO 111Ifni irti in in frt int Hydril 11" 5M di Ili III ill 111 / I �_ Shaffer — =:( ' ( r cil)rip __j _* Pipe or VBR Rams r OD 11" 5M -�, Blinds e �® I ' —, 3 1/8 5M Kill Valves / / 3 1/8 5M Choke Valves Manual and HCR III Lijil E Manual and HCR v— r, 1 . 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N+w VAA>°yR y+r_4#+1+ iF Y♦'A t i k RY W•MSM LC 1/S X-7 .,,:.*:-:- .:„: A wVAA A • "A ▪ A n h a V • "' h V V w A '.'"A n w + n v.w x" x.v " r vA A A A m ♦Vero **4'4,...,'V' A VroV A V i 4+n y V +� v V b V t V V k y > V v A .h..A a.A A .a Rv n ., x A .. a A • a n . m A,.J�A . a A . b A w ro A �h A r.H h.+..n n , MPE-11 0 0 Swab Valve Cameron FLS-2 2 9/16" 5K tree with IN, 9/16" 5K, manual gate valve, III EE PSL2,PR2 2 7/8" tbg hgr III �Y' PN 141522-31-02-01 �/ °-• , Wing valve Cameron FLS-2 o;.,. t 'a 9/16" 5K, manual gate valve, EE PSL2,PR2 III t■I in PN 141522-31-02-01 �[�� ►�I SSV Cameron FLS-2 9/16" - 5K, reverse actuating gate / valve, EE.PSL2,PR2 w/ II•• -'•.1 Cameron actuator PN 174370-08 0 Assy PN 207043-03-03-01 Master Cameron FLS-2 9/ „, ,►, 16" 5K, manual gate valve, EE Note, this tbg HGr can be ^` PSL2,PR2 on topfor BOPE 0ilik • 1 , .�' PN 141522-31-02-01 plugged o.. equipment testing c;.: to ci 0', Tbg Hd adapter FMC 11" 5K III all x 2 9/16" 5K, rotating U■► 1.1 flanges, w/2ea control line preps and 2ea BIW penetrator preps. 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(-) C > to _a E < O 0 = CL- >,Ti Q A L •— m a) C L m o v 0 E• D_ Q Q = a) �r I L a >, COCD 2 CO •(i) °' ate+) o a G 0 cn C a> co C U co 0 C U "6 L o o Wsa ) o 03) a 0 C.) r -0 p > co a) 4. w o C C ca � • •` L co ' U m m CDU= -0 U 0 L O C0 L � aQ ° GD E E `m a M oa) 0la -o0 'a, o a) 0I- a = C) co ca a) 3 � = a) C �'L ca = Cr co � o w U a C I 0 L N G1 ro > o rV) O o o d , L - L Q co > R 0 O. O. 1- O CY o E 0 c Q d .I.+ X CO o as C Q .Q 0 X 0 F- ns _a E a•) >C v, .0) U y.+ x O w a) co i oiiw D U co Q li s, O "" .) aU TUm x ; -SE 0 a CO z 0 o cn can Q ° cn ¢ a STATE OF ALASKA • AL.—<A OIL AND GAS CONSERVATION COMM..,„ ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well LJ Plug Perforations L Perforate Lf Other L] ESP Changeout Performed: Alter Casing ❑ Pull Tubing❑r Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: = 5.Permit to Drill Number: Name. Hilcorp Alaska,LLC Development 2 Exploratory ❑ 195-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22541-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 Milne Pt Unit KR E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Pt Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,830 feet Plugs measured 12,245 DECEIVED true vertical 7,355 feet Junk measured N/A Effective Depth measured 12,245 feet Packer measured 11,816 feet P U 2015 true vertical 7,048 feet true vertical 6,830 feet AC)G CC Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20” 112' 112' Surface 2,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Intermediate Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 11,634'(MD) 6,740'(TVD) 11,816'(MD) Packers and SSSV(type,measured and true vertical depth) Liner Top Packer N/A 6,830'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 29 9 771 0 221 Subsequent to operation: 301 79 1,114 260 234 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑� Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-096 Contact Chris Kanyer Email Y ckanyer@hllcorp.com Printed Name )� Chris Kanyer Title Operations Engineer Signature :"CL;,, �/�� / Phone 907-777-8377 Date 4/13/2015 RBDMS�\k APR 1 8 2015 Form 10-404 Revised 10/2012 iv , /5/ Submit Original Only Milne Point Unit Well: MPE-11 SCHEMATIC Last Completed: 3/6/15 Hilcorp Alaska,LLC PTD: 195-001 CASING DETAIL Clog.KBElev.:29.43'/GLEIev.:24.40 Size Type Wt/Grade/Conn ID Top Btm 1 ; 20" Conductor 91.1/H-40/N/A N/A 0 112' 20r .0 9-5/8" Surface 40/L-80/Btc. 8.835" _ 0 3,455' 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' ,, 1 ', 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 _ 11552' 3/8" Capstring Stainless Steel N/A 0 11,552' JEWELRY DETAIL 9-5/8" a 6' No Depth Item 1 202' 2-7/8"x 1"Side Pocket KBMM GLM Halliburton ES 2 11,308' 2-7/8"x 1"Side Pocket KBMM GLM Cementer @ 3 11,479' 'XN'Nipple(2.250"ID) 6,976' 4 11,490' Discharge Head GPDIS 5 11491' Pump-160p11/SSD AR 6 11,513' Gas Separator 7 11518' Upper and Lower Tandem Seals 8 11,531' Motor MSP1-250/210HP BSSChemcal 9 11,548' WeIILIFTSensor Injecticn Line @ 11,550 10 11,550' Centralizer-Bottom 11,552' 11 11,808' 5"setting sleeve C-2(ID=5.25") 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC 14 11,881' 7"Landing Collar 15 11,924' 7"Sealfloat Collar 16 11,967' 7"Sealfloat Shoe III 2 _17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 _18 12,697' Baker Landing Collar 19 12,785' Baker Float Collar 3 20 12,830' Baker Float Shoe 4 PERFORATION DETAIL 5 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open 6 Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated WELL INCLINATION DETAIL ' t 1 KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 i6,8 Hole Angle through perforations=58 deg. 9 OPEN HOLE/CEMENT DETAIL , 110 20" Cmt w/250 sks of Arcticset I in 24"Hole k 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole RA Tag @\ '� +,'� 7" Cmt w/370 sks Class"G"in 8-1/2"Hole 11,877' X111,12813 - -- --- i 5" Cmt w/145 sks Class"G"in 6"Hole r' a X14 15 TREE&WELLHEAD 16 Tree _ Cameron 4-1/16"5M FMC Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger 125 Steal band i = Hydril 521 Top&Btm,3"CIW H BPV profile Left In Hole------"O'3/5/2015. GENERAL WELL INFO AWES 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 RWO by Nabors 4ES-10/31/2000&10/31/2006 5„. X8 8 p9 RWO by Nabors 3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(M))/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 RWO by Nordic 3-6/9/2015 Created By:TDF 4/6/2015 • Hilcorp Alaska, LLC IlileorpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPE-11 195-001 50-029-22541-00-00 3/2/2015 3/6/2015 Daily Operations: 2/25/15-Wednesday No operations to report. 2/26/15-Thursday No operations to report. 2/27/15-Friday No operations to report. 2/28/15-Saturday No operations to report. 3/1/15-Sunday No operations to report. 3/2/15-Monday MIRU for E-11. Rig over well and set down @ 19:30.Accept rig. Prep camp for move, R/U lubricator to pull BPV. Pull BPV. Empty kill tank for removal. Move camp to E Pad. OA @ 200psi, IA @ 300 PSI,tubing @ 300 PSI. Burm cellar. R/U kill tank&lines. Pressure test lines to 3,000psi.Waiting on trucks for seawater. Start to haul rig equipment from L pad to E pad. Continue to R/U. Move kill tank to E pad. Move&spot cuttings tank. Move&spot boiler blow down tank. 3/3/15-Tuesday Wait on second load of seawater. Call out fresh water truck for volume to build 300 bbl of 8.5 ppg brine.Test lines from tree to kill tank to 250psi low/3,000psi high. Blow down lines.Second truck here with seawater. Hook direct to mud pumps.Tubing 250psi,OA @ 280psi. Pump STS maintaining a constant bottom hole pressure. Circ. @3 bpm 1,000psi.Got diesel returns @ 21 bbl away. 160 away 9.2 ppg returns. Finish STS with 800psi. Final pressure with gas&9.2 ppg returns throughout. 270psi on choke. Bled off to 0 on both sides. Pressure came back to 80 psi. Bullhead @ 1 bpm, 6.6 bbl @ 1,180psi &broke over. Leveled out @ 550psi @ 1 bpm injection. Bring pumps to 2 bpm. Final injection psi 1,100 @ 2 bpm. Shut down @ 35 bbl away. Bled down to 0 psi on both sides. Pressure came back to 120psi.Tried again and came back to 120psi. Mix kill weight fluid 9.0 ppg. Pressures 120psi on tubing. Circ. @ 3 bpm 97 bbl. Shut down and bull head @ 200psi 35 bbl @ 1 bpm. Final injection pressure @ 1 bpm 310psi. Finish Circ.9.0 ppg STS @ 600psi. Monitor well.Open up both sides.Well still slight flow on both sides. 1 gal per min.Starting to slow down. Let bleed monitoring flow&flow stopped. Monitor 15 more minutes.Well dead.Set BPV. N/D tree. Install plugs on cap string. Put graphite grease on hanger. PJSM & N/U BOPs. PULL BPV&install a TWC. Annulus on slight vac. Fill stack with water.Shell test. 250psi low/3,000psi high.Good.Test BOP's as per AOGCC. 250psi low/3,000psi high. Witness was waived by AOGCC Jeff Jones @ 4:22 AM on 2-28.An update was given on 3-3 and approval to proceed as planned. • Hilcorp Alaska, LLC ,,,, i,:,.,,,., Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPE-11 195-001 50-029-22541-00-00 3/2/2015 3/6/2015 Daily Operations: 3/4/15-Wednesday Test BOPs to 250psi low/3000psi high. Had a pass fail on 3-1/2"TIW valve. Perform accumulator drawdown test. Good.Test all gas alarms&flow meters.Good. Pull TWC. M/U landing joint with TIW in to hanger. PJSM, BOLD. Pull hanger to rig floor. Hanger came off seat @ 80K. Up wt 108K.Check cable @ penetrator.Grounded out down hole. Terminate cap string.Static loss @ 10 bph. POOH&string cap line over sheaves. POOH F/11,634'T/11,291. Having a hard time keeping cap string tight. Cap string getting kinked. Re rig the sheave at the bottom of the slide.Splice cap string. Continue to POOH F/11,290'. T/8,023'. Well loosing 2.4 BPH.Cut splice off&check ground.Splice good.Still grounded down hole. Continue to POOH 2-7/8"stands F/8,023'T/2,678'+/-. Static loss @ 2.4 BPH. 3/5/15-Thursday POOH with ESP completion F/2,678'T/to ESP assembly.Check motor splice.Good. Motor grounded out. Motor showing signs of wear from low side of hole.Small chip in motor flange. No signes of motor failure. Cap string smashed at motor splice. Steam clean ESP assembly&rig floor.Static losses @ 2.4 bph. L/D all pump,seals&motor. Swap spools in spooler to new cable.String to rig floor. P/U centralizer,sensor,motor, lower seals, upper seals,gas separator,pump#1, pump#2&discharge head.Test cable good.M/U motor leads to motor&test same.Good. Install cap string on motor.Splice cap string&remove damaged cap string. Install protectrolizer clamps on pump. RIH F/80' S P T/2,000'.Check cable. Cable Good. Continue running 2-7/8"completion F/2,000'T/3,910'.Check Cable. Good. Continue running F/3,910'T/5,805'.Check cable.Good. RIH F/5,805 T/7,909'.Test cable. Change spools. 3/6/15-Friday Make cable to cable splice. Test cable.Good.Splice on joint 256 mid joint.Continue to run 2-7/8"completion F/7,805' T/11,024.Test cable every 2,000'.Good.Change out capilary string spool. Make splice. Pump through cap string @ 4,500 psi.Good.RIH F/11,024'T/ 11,509'. Test cable.Good. M/U landing joint and hanger. Make penatrator splice. Install penatrators in hanger.Test.Good.Off load left over fluids from pits&rig. Land hanger.Set BPV. Centralizer @ 11,552,XN Nipple @ 11,479',GLM @ 11,308',GLM @ 202'.Total Joints ran 367. N/D BOPs. N/U tree.Test void to 500psi low/5,000psi high. Pull BPV.Set TWC.Test tree to 250psi low/5,000psi high. Pull TWC&Set BPV. R/D ESP spooler.Total clamps ran, 190 canon,4 protectrolizers,3 flat guards. No bands. Notified State of upcoming BOP Test. Prep for rig move. Rig release @ 22:30. ONE 1.25 STEAL BAND LEFT IN HOLE FROM PULLING THE ASSEMBLY.WE DID NOT RUN ANY BANDS ON THIS COMPLETION. Move rig to F-Pad 3/7/15-Saturday No operations to report. 3/8/15-Sunday No operations to report. 3/9/15-Monday No operations to report. 3/10/15-Tuesday No operations to report. ' S \\°\171//7./1/-e,- CV THE STATE Alaska Oil and Gas 4, ,;,�&• OfALAsKA Conservation Commission __ :31414 -� _ 333 West Seventh Avenue OF w ti" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax• 907.276.7542 www.aogcc.alaska.gov FEBZD 1`i Chris Kanyer SCANNED Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR E-11 Sundry Number: 315-096 Dear Mr. Kanyer: 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, Daniel T. Seamount, Jr. Commissioner DATED thisZ day of February, 2015 Encl. . !.. ECEN ED • STATE OF ALASKA FEB 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑✓ • Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. ESP Change-out ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 195-001 3.Address: Stratigraphic 0 Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22541-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C v Will planned perforations require a spacing exception? Yes ❑ No Q / Milne Pt Unit KR E-11 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028231 Milne Pt Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,830' . 7,355 ' 12,245' • 7,048 • ' 12,245' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 3,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Intermediate Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic' See Attached Schematic 2-7/8" 6.5#/L-80/8rd EUE 11,634 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Liner Top Packer and N/A ' 11,816 MD&6,830 ND and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/27/2015 Oil ❑., , Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kan er Title Operations Engineer Signature ( Phone 777-8377 Date 2/20/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ( Mechanical Integrity Test ❑ Location Clearance ❑ Other: AL 3oath (s: i ' -f -T 1— ( S P SZ�r 5, Spacing Exception Required? Yes ❑ No LILJ Subsequent Form Required: /0 —/0 Li • , APPROVED BY Z r2 -r Approved by./ COMMISSIONER APPROVED / THE COMMISSION ,/ /� Date: 1 S v 2.z%./.5 GuRiaGliaNIAlibr ' `�-' �43/is- ., !///� /"es�' ' mrtFonnand Fo 03 vised 10/2012) 12 mon hs"tom the date of apprOV6r- Attachments in Duplicate RBDMS�� FEB 2 4 2015 Well Prognosis Well: MPE-11 Hilcorp Alaska,Lb Date: 2/20/2015 Well Name: MPE-11 API Number: 50-029-22541-00-00 Current Status: SI Producer Pad: E Pad Estimated Start Date: March 1, 2015 Rig: Nordic 3 Reg.Approval Req'd? February 27, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-001 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 1424017 Current Bottom Hole Pressure: —3,324 psi @ 7,000' TVD (Last BHP measured 6/9/2013) Maximum Expected BHP: — 3,324 psi @ 7,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 526 psi (Based on actual reservoir conditions and water cut of 74% (0.411 psi/ft) with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point E-11 well was drilled as a Kuparuk development well that TD'd at a depth of 12,830' and ran and cemented 5" liner in February 1995. The well was perforated in the Kuparuk B & C sands and initially completed with an ESP. Subsequent failed ESP change outs occurred in 1997, 2000, 2006, and 2007. A Through Tubing ESP (TTC-ESP) was installed in 2010, with subsequent failures and change outs in 2012 and 2013. The recently installed ESP failed in February 2015, after a_5 day run life. The well has remained shut in ever since. Last 7"casing test was performed to 3,500psi on 8/8/2012. According to well records, scale and sand production have contributed to ESP failures. Scale Inhibition Treatments (SIT) have been applied to this well as recently as June 2013. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. RWO Objective: Pull & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater. Monitor well. 3. If necessary, Circulate well with 9.3ppg brine (or appropriate kill weight fluid). Monitor well. 4. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high, annular to 250psi low/1,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 5. Unseat hanger and pull 2-7/8" L-80 8RD tubing and from 11,634', checking for electrical failure (penetrator, cable splice, MLE). Contingency: (Depending on depth of electrical failure found) a. Option#1: [Penetrator failure] POOH and LD one joint, replace penetrator, and land ESP back to +/-11,603' • Well Prognosis Well: MPE-11 llilcarp Alaska,LL Date:2/20/2015 ✓b. Option#2: [Cable failure above splice at 3,862'] Re-splice, test, and run ESP back to+/-11,634'. ✓E Option#3: [Deep cable failure] Service ESP motor and seals, and run ESP back with new cable to+/- 11,634'. d. Option#4: [Deep cable failure with sand in pump] i. LD ESP ii. RIH with 5" x 7"tandem cleanout BHA and circulate well clean to+/-12,245'. POOH with same. iii. Service ESP motor and seals, and run ESP back with new cable to+/-11,634'. 6. ND BOP, NU Tree, test tree. 7. RDMO workover rig and equipment. 8. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPE-11 SCHEMATIC Last Completed: 2/8/15 uacorp Alaska,LLC PTD: 195-001 CASING DETAIL Orig.KB Elev.:29.43'/GL Elev.:24.40' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A 0 112' 20A 9-5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' �I r'j 1 1 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 11,634' 3/8" Capstring Stainless Steel N/A 0 11,634' JEWELRY DETAIL No Depth Item 9-5/8" * 6 1 196' Camco 2-7/8"x 1"Side Pocket KBMM GLM Halliburton ES 2 11,395' Camco 2-7/8"x 1"Side Pocket KBMM GLM Cementer @ 3 11,566' 'XN'Nipple 2.313 ID(2.250"No Go) 6,976' 4 11,577' Discharge Head 5 11,578' Pump-160P11/SSD AR 6 11,595' Gas Separator-GRSFTXAR 7 11,600' Tandem Seals-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA CL5 8 11,614' Motor MSP1-250/210HP,2,380 volts&53 amps 38^SSChenipl 9 11,630' WeIILIFT Sensor InietionUne@ 10 11,632' Centralizer-Bottom @ 11,634' 11,63411 11,808' 5"setting sleeve C-2(ID=5.25") 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC 14 11,881' 7"Landing Collar 15 11,924' 7"Sealfloat Collar 16 11,967' 7"Sealfloat Shoe 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 2 18 12,697' Baker Landing Collar 19 12,785' Baker Float Collar 20 12,830' Baker Float Shoe 3 PERFORATION DETAIL :5.: Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 6 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 ' Hole Angle through perforations=58 deg. s OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole n10 • 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole r. RAA Tag© 7" Cmt w/370 sks Class"G"in 8-1/2"Hole tt,877' 11,12&13 5" Cmt w/145 sks Class"G"in 6"Hole 7' A it 14 15 TREE&WELLHEAD 16 Tree Cameron 4-1/16"5M FMC Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger Hydril 521 Top&Btm,3"CIW H BPV profile = GENERAL WELL INFO MIES 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 RWO by Nabors 4ES-10/31/2000 18 RWO by Nabors 4ES-10/31/2006 5"A 61920 RWObyNabors3S-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 ESP Changeout w/Nordic 3-2/8/2015 Created By:TDF 2/13/2015 Milne Point Unit 11 Well: MPE-11 PROPOSED Last Completed: 2/8/15 Ililcorp Alaska,LLC PTD: 195-001 CASING DETAIL Orig.KB Elev.:29.437 GL Elev.:24.40' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A 0 112' 20° 9 5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' • C1 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' TUBING DETAIL . 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441" 0 ±11,634' $. 3/8" Capstring Stainless Steel N/A 0 ±11,634' JEWELRY DETAIL No Depth Item 9-5/8 1 ±196' Camco 2-7/8"x 1"Side Pocket KBMM GLM Halliburton ES 2 ±11,395' Camco 2-7/8"x 1"Side Pocket KBMM GLM 3 ±11,566' 'XN'Nipple 2.313 ID(2.250"No Go) Cementer @ 6,976' 4 ±11,577' Discharge Head 5 ±11,578' Pump-160P11/SSD AR 6 ±11,595' Gas Separator-GRSFTXAR 7 ±11,600' Tandem Seals-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA CL5 8 ±11,614' Motor MSP1-250/210HP,2,380 volts&53 amps 3'g'SSChemical 9 ±11,630' WeIILIFTSensor Injection line@ 10 ±11,632' Centralizer-Bottom @ 11,634' 11'634 t, 11 11,808' 5"setting sleeve C-2(ID=5.25") 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC 14 11,881' 7"Landing Collar 15 11,924' 7"Sealfloat Collar 16 11,967' 7"Sealfloat Shoe 10- 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 2 18 12,697' Baker Landing Collar 19 12,785' Baker Float Collar 20 12,830' Baker Float Shoe PERFORATION DETAIL 4 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 5 Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated 76 WELL INCLINATION DETAIL KOP @ 1,000' t, Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. ,• 8 r. OPEN HOLE/CEMENT DETAIL ki s _ 20" Cmt w/250 sks of Arcticset I in 24"Hole 10 9-5/8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole RA Tag @ 7" Cmt w/370 sks Class"G"in 8-1/2"Hole 11,877R.11,12&13 5" Cmt w/145 sks Class"G"in 6"Hole 7' • 114 15 TREE &WELLHEAD 16 Tree Cameron 4-1/16"5M FMC Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger Hydril 521 Top&Btm,3"CIW H BPV profile GENERAL WELL INFO Magi 17 API:50-029-22748-00-00 _ Drilled,Cased and Completed by Nabors 22E -2/2/1995 Install ESP Completion 4ES-12/16/1997 RWO by Nabors 4ES-10/31/2000 18 RWO by Nabors 4ES-10/31/2006 g� �19� RWO by Nabors 3S-3/28/2007 RWO by Nabors 4E5/TIC-ESP Completion-6/3/2010 1D=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 ESP Changeout w/Nordic 3-2/8/2015 Created By:TDF 2/20/2015 • MPU BOP Stack J v iiiiii YMis Hydril 13 5/8 5M [111 In IMI-11111 13 5/8 5M j ' Ons 2 7/8"-5-%z" variables upWNW MN - Spacer spool 13 5/8 5M =I C 13 5/8 5M -OM Blinds *-- ‘ ) _ __ —,c11.1111111111 i f I&40,j1 4_ Cl t-e, :1 C [iillhisi — conium Spacer spool 13 5/8 5M 13 5/8" SMX11" 5M DSA 11111 STATE OF ALASKA ALS.—KLA OIL AND GAS CONSERVATION COMM..,SION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ESP Changeout Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑., Exploratory ❑ 195-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22541-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028231 Milne Pt Unit KR E-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Pt Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 12,830 feet Plugs measured 12245 feet true vertical 7,355 feet Junk measured N/A feet FEB 2 0 2015 Effective Depth measured 12,245 feet Packer measured 11,816 feet AOGCC true vertical 7,048 feet true vertical 6830 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' Surface 2,455' 9-5/8" 3,455' 2,943' 3,090psi 5,750psi Intermediate Production 11,967' 7" 11,967' 6,905' 7,240psi 5,410psi Liner 1,022' 5" 12,830' 7,355' 8,290psi 7,250psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 11,634'(MD) 6,740'(TVD) 11,816'(MD) Packers and SSSV(type,measured and true vertical depth) Liner Top Packer N/A 6,830'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SEL , Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 74 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exemp): 314-680 v/ Contact Chris Kanyer Email ckanverat7.hilcorD.com Printed Name Chris Kanyer Title Operations Engineer Signature Ci /1_�/// Phone 907-777-8377 Date 2/20/2015 s� RBDM FR 1 3 1015 Form 10-404 Revised 10/2012 -/ - i .11.-// Submit Original Only !/7` 7 Milne Point Unit • • Well: MPE-11 SCHEMATIC Last Completed: 2/8/15 uncoil,Alaska,LLC PTD: 195-001 CASING DETAIL Orig.KB Elev.:29.43'/GL Elev.:24.40' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A 0 112' 20"-� 9-5/8" Surface 40/L-80/Btc. 8.835" 0 3,455' 7" Intermediate 26/L-80/NSCC 6.276" 0 11,967' 1 5" Liner 15/13CR80/FL4S 4.408" 11,808' 12,830' TUBING DETAIL 2-7/8"__ Tubing 6.5/L-80/8rd EUE 2.441" 0 11,634' 3/8" Capstring Stainless Steel N/A 0 11,634' . JEWELRY DETAIL No Depth Item 9-5/8" • 6 1 196' Camco 2-7/8"x 1"Side Pocket KBMM GLM _ Halliburton ES 2 11,395' Camco 2-7/8"x 1"Side Pocket KBMM GLM Cementer @ 3 11,566' 'XN'Nipple 2.313 ID(2.250"No Go) 6,976' 4 11,577' Discharge Head 5 11,578' Pump-160P11/SSD AR 6 11,595' Gas Separator-GRSFTXAR 7 11,600' Tandem Seals-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA CL5 8 11,614' Motor MSP1-250/210HP,2,380 volts&53 amps 36'SSChem;cal 9 _ 11,630' WeIILIFT Sensor _ IrgedimLine I 10 11,632' Centralizer-Bottom @ 11,634' 11,634' ------111 11,808' 5"setting sleeve C-2(ID=5.25") 12 11,816' Liner Top Packer.HPLPO 13 11,821' Liner Hanger.HMC _ 14 11,881' 7"Landing Collar _ 15 11,924' 7"Sealfloat Collar 16 11,967' 7"Sealfloat Shoe 17 12,245' Weatherford Cast Iron Bridge Plug,set 10/26/00 2 18 12,697' Baker Landing Collar 19 12,785' Baker Float Collar ' C 3 20 12,830' Baker Float Shoe PERFORATION DETAIL 4 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status !:, Kup.C Sands 12,176' 12,234' 7,011' 7,042' 31 1/31/1995 Open Kup.B Sands 12,256' 12,310' 7,053' 7,082' 54 1/31/1995 Isolated ",.:,, 6 WELL INCLINATION DETAIL KOP @ 1,000' Max Hole Angle=63 deg. f/3,000'too 11,300 Hole Angle through perforations=58 deg. 8 'ILLs OPEN HOLE/CEMENT DETAIL 10 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-57/„8" Cmt w/665 sks PF"E",250 sx Class"G"in 12-1/4"Hole RA Tag Cmt w/370 sks Class"G"in 8-1/2"Hole . 11,877 -\4211 len12813 5" Cmt w/145 sks Class"G"in 6"Hole j" . 414 15 TREE &WELLHEAD 16 Tree Cameron 4-1/16"5M FMC Wellhead 13-3/8"x 11"5K w11"x 4.5"Tubing Hanger Hydril 521 Top&Btm,3"CIW H BPV profile GENERAL WELL INFO aliEeill 17 API:50-029-22748-00-00 Drilled,Cased and Completed by Nabors 22E -2/2/1995 = Install ESP Completion 4ES-12/16/1997 _RWO by Nabors 4E5-10/31/2000 18 RWO by Nabors 4ES-10/31/2006 5"/ A1920 RWO by Nabors 35-3/28/2007 RWO by Nabors 4ES/TTC-ESP Completion-6/3/2010 TD=12,830'(MD)/TD=7,355'(TVD) RWO by Doyon 16-8/3/2012 PBTD=12,697'(MD)/PBTD=7,285'(TVD) RWO by Doyon 16-6/9/2013 ESP Changeout w/Nordic 3-2/8/2015 Created By:TDF 2/13/2015 • J" r Hilcorp Alaska, LLC 1 Hilcorp LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPE-11 195-001 50-029-22541-00-00 2/2/2015 2/8/2015 Daily Operations: 2/4/15-Wednesday Finish rebuilding the super choke valve stem packing.Test,good. Drain stack. Pull TWC. R/U circ lines to annulus. Pump down tubing 15 bbl to get crude off of annulas. Monitor well.Let U tube.Clean Returns.Well Static.R/U 4-1/2" landing joint with TIW. PJSM,BOLD&pull hanger free. 15K. Pulled ESP free @ 190K.WT fell to 175.P/U 20' hole dragging in 10K. Terminate ESP lines. L/D hanger. Run ESP through sheaves. L/D 4-1/2" Hydril 521 F/11,650'T/2,400'. Bring 2-7/8" pipe in shed while piling pipe.Strap&tally.0 Losses to well. 2/5/15-Thursday L/D 4-1/2" Hydril 521 F/2,400'To Motor.L/D ESP Assembly. Bring 2-7/8"pipe in shed while pulling pipe.Strap&tally. 0 Losses to well.Clean&Clear the rig floor from all esp equipment. M/U Mule shoe,RIH Picking up 15 joints of 2-7/8" EUE tubing T/470'. M/U 7"Scraper&XOs.Continue to P/U 2-7/8" pipe. F/470'T/11,790'. Tag. Work through with up &down. Tag @ 11,810'.0 Total Losses to the well.Close annular&rev circ through tag spot.Clear. RIH F/11,810'T/ 12,036'Tag.Reverse circ @ 2-3 bpm.P/U singles of 3-1/2" DP to strip through annular.Grease joints.Washing sand down @ 2-3 bpm 700-800 psi pump pressre. Lots of sand in returns. MW IN/OUT 9.3/9.3ppg.Total losses to well 0. 2/6/15-Friday Continue to strip through the annular while reverse circulating.Circ @ 2-3 bpm. @ 700-800 psi on the annulus.Getting lots of sand in the returns.F/12,036'T/12,096'+Old RKB Corection of 1.78.Tag abstruction @ 12,196'. Line up down tubing&circ @ 1 bpm.Wash down&tag @ 12,196'. Line up&reverse circ @ 3 bpm.Two BTM up. Came clean after 1.5 btm up.3+BBL total sand returns.°Losses while circulating. Monitor well.Static. Blow down TD. L/D HWDP F/ 12,196'T/12,036'. L/D 2-7/8"Tubing F/12,036'T/11,492'. POOH F/11,492'.With 2-7/8"stands.Straping out of the derrick for the first 30 stands but the winds are to high. Finish POOH& L/D Scraper.Service scraper.Change handling equipment.Pull ESP Cable&Cap String to the rig floor through sheaves. P/U Cent,Sensor, Motor, Lower Seals, Upper Seals,Gas Separator, Pump. HEC Owned,& Discharge head. Test ESP Cable&Cap lines.Cap lines did not test.Check cap string check. 2/7/15-Saturday Test ESP Cable&Cap lines.Cap lines did not test.Take check valve to bench&test.GOOD. Determand to be cold hydraulic fluid.Continue to RIH. M/U XN nipple 5 joints of pipe&First gas lift. RIH with 2-7/8"stands from derrick. Stop and adjust ESP cable on spool.Test cable&line @ 1,964'.First test in hole pumped through cap string at 4,000psi. Good. Meg Cable.Good. Replace btm single on joint 106.Continue running 2-7/8" EUE 6.4#from the derrick. F/1,964' T/7,772'.Testing 3/8"cap string with ESP every 2,000'.Swap spools in unit&make splice in cable.Continue running 2- 7/8" EUE 6.4#from the derrick. F/7,772'T/9,700'.Test ESP cable,good.Test Capline Good.Continue running 2-7/8" EUE 6.4#from the derrick.F/9,700'T/10,200'.No Losses to the well. 2/8/15-Sunday Continue running 2-7/8" EUE 6.4#from the derrick. F/10,200'T/11,606.Sest ESP Cable,Good.Test Cap line Could not pump through @ 6,100psi. Make up hanger&make penetrator splice.Check OK. Install penatrators in well head.No losses to well. Land hanger,verify landing. Back out landing joint.Set TWC.Clamp Count 221-2-7/8"cross collar clamps,3-Flat Guard New,4 Pump protetrolizers, 1 Motor protetrolizer.N/D BOPS. N/U Tree.Orientate as per production operator.Test void to 500psi low/5,000psi high.Test tree to 5,000 psi.Good.Test ESP cable,good. Pull TWC. Release rig @ 2100. 2/9/15-Monday No operations to report. 2/10/15-Tuesday No operations to report. '5 (11'j2Z.v C45'11 :- �t s �1 ,"� ls .elC� Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /(~ ~"-- 001 File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell Date:¢¢;~, 0~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA r ilkSKA OIL AND GAS CONSERVATION COMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ❑Alter Casing IS Pull Tubing ❑Stimulate-Frac ❑Waiver Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc.• ❑Exploratory ❑Stratigraphic 195-001 • 3. Address: ®Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22541-00-00 • 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025518&028231 MPE-11 ' 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point/Kuparuk River Sands. 11. Present well condition summary: Total depth: measured 12830' feet Plugs:(measured) 12245' feet true vertical 7355' feet Junk:(measured) None feet Effective depth: measured 12245' feet Packer: (measured) 11816' feet true vertical 7048' feet Packer: (true vertical) 6830' feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 32'- 112' 32'- 112' 1490 470 Surface 3424' 9-5/8" 31'-3455' 31'-2943' 5750 3090 Intermediate Production 11938' 7" 29'- 11967' 29'-6904' 7240 5410 Liner 1022' 5" 11808'-12830' 6826'-7355' 8290 7250 Perforation Depth: Measured Depth: 12176'- 12310' feet True Vertical Depth: 7012'-7082' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# L-80 11614' 6730' Packers and SSSV(type,measured and true vertical depth): HPLPO Liner Top Packer 11816' 6830' 12.Stimulation or cement squeeze summary: s � Intervals treated(measured): �.� ASS) i\I 0V 0 Treatment description including volumes used and final pressure: WA SS) Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 110 190 446 200 191 Subsequent to operation: 152 33 690 190 186 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: ®Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Noel Nocas,564-4667 N/A Email: Noel.Nocas @bp.com Printed N ' Joe Las Title: Drilling Technologist Signature: Phone: 564-4091 Date: (0/2_i/13 Form 10-404 Re 1 /2012 '/L , 713/ ,`3 0-/i RBDMS JUL — 2 10& r iginal Only • • North America-ALASKA-BP 7:. IIII!ItIIIIIIJItIItI" Operation Summary Report Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12.00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Data From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 5/28/2013 00:00 - 01:30 1.50 MOB P PRE PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -CONTINUE CLEAN AND OFF LOAD PITS -R/D FLOOR AND PREP TO LAY DAERRICK IOVER -R/D CATTLE CHUTE AND MUD MANIFOLD 01:30 - 02:30 1.00 MOB P PRE PJSM TO LAY DERRICK OVER LAY DERRICK OVER AND SECURE ON DERRICK STAND -FUNCTION TEST MOVING SYSTEM AND ESD 02:30 - 03:30 1.00 MOB P PRE PJSM,FOR MOVE OFF OF WELL MPJ-10 VVSL AND TOOLPUSHER PRESENT,PAD OPERATOR NOTIFIED JACK RIG UP AND MOVE OFF OF MPJ-10 -POSITION RIG ON PAD FOR BOP REMOVAL 03:30 - 05:00 1.50 MOB P PRE PJSM,REMOVE BOP FROM CELLAR AND SECURE ON BOP STAND -INSTALL FRONT AND REAR BOOSTERS -FUNCTION TEST AND CHECKALL HYDRAULIC LINES -MOVE RIG TO ENTRANCE OF PAD AND NOTIFY SECURITY. 05:00 - 08:30 3.50 MOB P PRE PJSM,MOVE OFF OF MPJ-PAD -MOVE DOWN TRAC ACCESS ROAD TOWARD MILNE PT SPINE ROAD -ARRIVE ON MPE-PAD AT 0830 HRS. -CLOSE OUT WELL WORK TRANSFER PERMIT WITH MPJ-PAD OPS. 08:30 - 12:00 3.50 MOB P PRE PJSM,SPOT RIG ON MPE-PAD.LAY RIG MATS OVER WELL. -REMOVE REAR BOOSTER TIRES.CHECK MOVING SYSTEM AFTER MOVE. 12:00 - 14.00 T 2.00 MOB P PRE PJSM,COMPLETE WELL AREA PREP. -TEST MOVING ESD. -SPOT RIG OVER WELL.PAD OPERATOR, WSL,DDI SUPERINTENDENT PRESENT. 14:00 - 18:30 4.50 RIGU P PRE PJSM,RAISE DERRICK -BRIDLE DOWN -SPOT RIG COMPONENTS. -RU CELLAR AND RIG FLOOR. -INSTALL 4-1/8"X 1502 UNION FLANGE ON TO THE TREE WING VALVE. -RU KILL MANIFOLD AND CIRC LINES. -LOWER CELLAR DOORS.SECURE CELLAR. -RU SSV REMOTE PANEL ON RIG FLOOR. -I/A=740 PSI.0/A=200 PSI. -RIG ACCEPTED ON MPE-11 AT 18:30 HRS. -COMPLETE HANDOVER FOR MPJ-10 WITH MILNE POINT OPS COORDINATOR. Printed 6/17/2013 9:21:08AM Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: 1X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft Level) Task CLev Date From-To Hrs (above Mean Sea _ NPT NPT Depth Phase Description of Operations (hr) (usft) 1118:30 - 19:00 0.50 WHSUR P WHDTRE PJSM,REVIEW DDI SOP FOR TESTING KILL MANIFOLD. -FLUID PACK KILL MANIFOLD AND LINES WITH FRESH H2O. -PRESSURE TEST KILL MANIFOLD,2 IN LINE CHECK VALVES AND CIRC LINES. -PRESSURE TEST TO 250/3500 PSI 5 MIN -EA.CHARTED. -BLOW DOWN LINES. -FUNCTION SSV FROM RIG FLOOR REMOTE PANEL. -RIG ACCEPTED MPE-11 AT 19:00 HRS 5/28/2013 19:00 - 21:30 2.50 WHSUR P WHDTRE '-OJSM,INSPECT DERRICK,TOP DRIVE AND CROWN. -SERVICE RIG FLOOR EQUIPMENT AND PIPE SKATE. -PRIME MUD PUMP,PRESSURE TEST LINES TO 3500 PSI. 21:30 - 22:00 0.50 WHSUR P WHDTRE CONDUCT H2S RIG EVAC DRILL. -CREW RESPONED TO MUSTER AREA. LOADER OPERATOR BLOCKED PAD ENTRANCE. -DSO NOTIFIED. -SIMULATE NOTIFICATIONS. -AAR: -RIG CREW RESPONDED TO MUSTER AREA. -WITH WIND DIRECTION 2 CREW MEMBERS ON OPPOSITE SIDE OF RIG RESPONDED TO SECONDARY MUSTER AREA AS NOT TO CROSS IN WIND DIRECTION. „' -DRILLER AND SECOND FLOOR HAND BROUGHT AIR PACKS AND PORTABLE GAS MONITOR TO MUSTER AREA. -VERY GOOD RESPONSE. 22:00 - 00:00 2.00 KILLW N WAIT DECOMP WAIT ON DAYLIGHT WELL KILL. -PERFORM DDI WORK ORDERS. -HOUSE KEEPING. O/A=200 PSI. 5/29/2013 00:00 - 00:30 0.50 WHSUB N WAIT WHDTRE CONDUCT H2S RIG EVAC DRILL. -CREW RESPONED TO MUSTER AREA. -SCS VERIFIED HEAD COUNT. -LOADER OPERATOR BLOCKED PAD ENTRANCE. -DSO NOTIFIED. -SIMULATE NOTIFICATIONS. -AAR: -DRILLER AND SECOND FLOORHAND BROUGHT AIR PACKS AND PORTABLE GAS MONITOR TO MUSTER AREA -VERY GOOD RESPONSE. 00:30 - 06:30 6.00 WHSUR N WAIT WHDTRE WAIT ON DAYLIGHT WELL KILL. -OFFLOAD 290 BBLS 9.3 PPG KWF WITH.6% SAFE LUBE. -PERFORM DDI WORK ORDERS. Printed 6/17/2013 9:21:08AM ,o ff,,s r►„ Cn Well Name:MPE-11 AFE No ommo Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 08:30 2.00 WHSUR P WHDTRE PJSM,WITH MPU DSM TO PULL BPV. P/U DSM LUBRICATOR.RU TEST HOSES. -TEST LUBRICATOR TO 250/3500 PSI FOR 5 CHARTED MIN.EACH. I-PULL BPV WITH TESTED LUBRICATOR.SITP =520 PSI. SICP=740 PSI SIOA=200 PSI. L/D LUBRICATOR PER DSM REPS. SECURE TREE. 08:30 - 11:00 2.50 WHSUR N WAIT WHDTRE CONTINUE TO WAIT ON LAST TWO VAC TRUCKS WITH KWF. -CONTINUE TO PERFORM GENERAL RIG MAINTENANCE. -PJSM,WELL OPERATIONS PER DDI PROCEDURES. -BP PRE-SPUD MEETING ON MPE-11. 11:00 - 13:30 2.50 WHSUR P WHDTRE JSM,WELL KILL WITH 9.3 PPG HEATED RINE.0.6 PERCENT SAFE LURE. -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT. -SITP=520 PSI, SICP=820 SIOA=200R E 1 -BLEED GAS FROM IA F/750 T/'100'PSI IN 5 MIN. -PUMPED 180 BBLS 9.3 PPG SAFE LURE 5 WWN THE -ICP=TBG/950 TBG BRINE THRU CHOKE AT SKID BPM TO 900 FLOW BACK TANK PSI ITH IA/3PSI 00 PSI DO -FCP=TBG/750 PSI IA/225 -TBG ON A VACUUM. 185 BBLS OF 100%CRUDE RETURNED. -ATTEMPT TO BULL HEAD:PUMPED 5.2 BBLS AND PRESSURED UP TO 3,000 PSI. SHUT-IN,MONITOR WELL FOR 18 MINUTES. SITP=1260 PSI SICP=1900 PSI 13:30 - 16:30 3.00 WHSUR N WAIT WHDTRE INCORRECT TRUCK FOR THE JOB. -TRANSFER KWF FROM ONE TRUCK TO THE OTHER,OFF LOCATION. CHANGE OUT VAC-TRUCK AND RECOVER 180 BBLS CRUDE FROM FLOW BACK TANK 16:30 - 18:00 1.50 WHSUR P WHDTRE PUMPED HEATED 9.3 PPG KWF AT 5 BPM DOWN THE TBG THRU CHOKE SKID TO FLOW BACK TANK ICP=TBG= 3 BPM/'O'PSI. 5 BPM/10 PSI. =IA=3 BPM/500 PSI. I-ICP -PUMPED 320 BBLS KWF AT 5 BPM AND STARTED TO GET KWF IN RETURNS AFTER PUMPING 164 BBLS KWF. -CLEAN 9.3 PPG KWF AT SURFACE,STOP PUMP. MONITOR 30 MINUTES. -TBG AND IA A G VACUUM AFTER 20 MINUTES. -WELL IS DEAD.ON __mw BLOW DOWNI HARD SLI LINES.HT RED 230 B OF 0%CRUDE, SENT TO MILNE POINT RECYCLE. 18:00 - 19:00 1.00 VV P WHDTRE PJSM,ECOVER BLOW DOWN NAB R/D KILL 10 MANIFOLD AND CIRC LINES. -P/U CELLAR AREA. Printed 6/17/2013 9:21:08AM r i r '' -' � � 7� %.i/ 3r�r �;,/ff rj �%�� �r o^ rk✓ " Common Well Name:MPE-11 l APE No Event Type:WORKOVER(WO) Start Date:5/28/2013 I End Date: X4-OOXF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 21:30 2.50 WHSUR P WHDTRE PJSM WITH DSM.R/U LUBRICATOR. -PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA.CHARTED. INSTALLTWC.PERFORM 500 PSI ROLLING TEST UNDER TWC FOR 10 MIN CHARTED. PUMP.5 BPM 500 PSI.3 BBLS PUMPED..8 'BBLS BLED BACK. PRESSURE TEST ABOVE TWC TO 250/3500 PSI 5 MIN EA.CHARTED. R/D 1-MONITOR LUBRICATOR.I/A.STATIC. 21:30 23:00 1.50 WHSUR P WHDTRE PJSM FOR N/D TREE AND ADAPTOR FLANGE. N/U BOPS. BARRIERS IN PLACE,TESTED TWC AND HANGER SEALS.9.3 PPG KWF. FMC RN HANGER OI I -N/D TREE AND BLED ADAPTOR AN FLANGE. ECT EP HANGER DO THREADS.W 4 1/2V"521 D. -INSP HYDRIL THREAD. -M/U PUP INTO HANGER.6 TURNS BY HAND. -MONITOR I/A.STATIC. 23:00 00:00 1.00 BOPSUR DECOMP VERIFY PENETRATOR LENGTH. N/U 4 PREVENTER BOP STACK WITH 11"X i 13 5/8"ADAPTOR. -BOP CONFIGURATION BOTTOM TO TOP: 2 7/8"X 5"VBR,MUD CROSS,BLIND SHEAR RAM,2 7/8"X 5"VBR,ANNULAR. -MONITOR I/A.STATIC. =160 PSI.POST WELL KILL LOSSES AT 7 BL 9.3 PPG KWF. -PVT=356 BBLS 9.3 PPG BRINE. 5/30/2013 100:00 - 01:00 1.00 BOPSUR P I DECOMP N/U 4 PREVENTER BOP STACK WITH 11"X 13 5/8"ADAPTOR. BOP CONFIGURATION BOTTOM TO TOP: -2 7/8"X 5"VBR,MUD CROSS,BLIND SHEAR RAM,27/8"X 5"VBR,ANNULAR. I-MONITOR I/A.STATIC. 01:00 - 01:30 0.50 BOPSUR P DECOMP R/U BOP TEST EQUIPMENT. FILL STACK WITH FRESH WATER. FUNCTION BOPE. Ili Printed 6/17/2013 9:21:08AM operation Stun s Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) ! Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 05:30 4.00 BOPSUR P DECOMP PJSM,TEST FOUR PREVENTER BOPE AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES. TEST ANNULAR WITH 4"'TEST JOINT TO 250 /3500 PSI 5 MIN EA.CHARTED. TEST UPPER AND LOWER 2 7/8"X 5" VARIABLE RAMS WITH 4"AND 4 1/2"TEST JOINTS TO 250/3500 PSI 5 MIN EA. CHARTED. -TEST BLIND RAMS,FLOOR VALVES,[BOP'S AND CHOKE MANIFOLD TO 250/3500 PSI 5 MIN EA.CHARTED. -TEST WITH FRESH WATER. -PERFORM ACCUMULATOR DRAW DOWN TEST. -BOP TEST WITNESSED BY WSL AND DDI TOUR PUSHER. -MONITOR I/A.STATIC. '-LOU GRIMALDI AOGCC STATE REP WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST ON 05/28/2013 AT 19:31 HRS. 05:30 - 06:00 0.50 BOPSUR R DECOMP t RD BOP TEST EQUIPMENT -BLOW DOWN CHOKE -VACUUM TEST WATER,8.4#H2O FROM BOPE STACK. 06:00 07:30 1.50 BOPSUR P DECOMP PJSM,PULL TWC -P/U DUTCH RISER SYSTEM AND N/U TO IANNULAR. -P/U AND R/U DSM LUBRICATOR -FILL BOP STACK WITH 8.5 PPG KWF. -CLOSE ANNULAR AND PRESSURE TEST T/ 250/3500 PSI AND CHART F/5 MINUTES EACH. PULL TWC AND R/D DSM LUBRICATOR AND EXTENSION. -WELL IS ON A SLIGHT VACUUM. 07:30 - 09:00 1.50 PULL P DECOMP PJSM,PULL TBG HANGER. -DRAIN BOP STACK -M/U 4"DP LANDING JT. -VERIFY NO TRAPPED PRESSURE UNDER HANGER. -FMC REP BOLDS. -PULL TBG HANGER TO FLOOR.PUW/155K OFF,SEAT 165K MAX,150 UP WT. -CUT ESP CABLE AT THE SECOND CLAMP AND L/D LANDING JT -AND TBG HANGER AND 1 JT OF 4-1/2"TBG. -POSITION SLICK PIPE ACROSS THE BOP. 09:00 - 09:30 0.50 PULL N SFAL DECOMP PJSM,ATTEMPT AJUSTMENT OF DERRICK 'A'LEGS. -RIG NOT CENTERED OVER WELL. 09:30 - 10:00 0.50 PULL P DECOMP CIRCULATE A TBG VOLUME THRU GAS BUSTER. R/U TO TOP DRIVE !-CLOSE ANNULAR AND PUMP 176 BBLS KWF (9.3 BRINE) -5 BPM/520 PSI.NO LOSSES/GAINS. Printed 6/17/2013 9:21:08AM • e „Iplp e Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 EVAL P DECOMP ATTEMPT TO ESTABLISH AN INJECTION RATE. PUMPED 60 STKS(5.4 BBLS)AT 1 BPM AND PRESSURED UP TO 3000 PSI. I-LITTLE TO NO INJECTTIVITY. -4 BBLS BLEED BACK. -DISCUSSED OPTIONS WITH ODE. 11:00 - 12:00 1.00 EVAL P DECOMP PJSM,BLOW DOWN CHOKE MANIFOLD AND KILL LINES. BREAK OUT 4 1/2”HYDRIL CROSS OVER FROM STRING.SET TBG HANGER ON STAND. 12:00 - 13:30 1.50 EVAL N SFAL DECOMP PJSM,OFFLOAD KWF FROM PITS TO VAC TRUCK.. -MU LANDING JT TO TBG HANGER WITH FOSV.. INSTALL TWC IN TBG HANGER. I-LAND TBG HANGER IN SPOOL PER FMC REP. -FOLDS.LD LANDING JT. 13:30 - 14:30 1.00 EVAL N SFAL DECOMP PJSM,PERFORM ROLLING TEST FROM BELOW TWC.8 BPM 500 PSI FOR 10 MIN. PUMP @.0846 BPM WITH 500 PSI FOR 10 I CHARTED MIN.2 BBLS PUMPED WITH 0 BBLS BLED BACK. -AT 14:30 LOADER OPERATOR WAS LOADING 12 2 7/8"TEST JTS INTO PIPE SHED. -1 TEST JT ROLLED/SLIDING OFF FORKS. BOX END CONTACTED GROUND. 14:30 - 18:30 4.00 EVAL N HMAN DECOMP STAND DOWN FOR DROPPED OBJECT INVESTIGATION. -WSL/TOOL PUSHER MADE NOTIFICATIONS. BP HSE,DDI HSE,RWO WTLAND SUPERINTENDENT,DDI SUPERINTENDENT NOTIFIED. -TEAM MEMBERS ASSEMBLED AT 16:00 HRS. -CONCLUDE INVESTIGATION MEETING/ DEVELOPE PLAN FORWARD. SUBMIT PLAN FORWARD TO RWO FIELD SUPERINTENDANT. '-LEVEL PIPESHED RAMP. -RECEIVE APPROVAL TO CONTINUE RIG OPS. -SUBMIT IR#2013-IR-4435141 18:30 - 19:30 1.00 EVAL N SFAL DECOMP PJSM,PRESSURE TEST TWC FROM ABOVE I TO 250/3500 PSI 5 MIN EA.CHARTED. 19:30 - 21:00 1.50 MOB N SFAL DECOMP I PJSM FOR R/D TO MOVE RIG FORWARD 3" I TO CENTER OVER WELL. CLOSE BLIND SHEAR RAM.SUCK OUT STACK -R/D FLOWLINE.BOP ANCHORS. 1-SECURE CELLAR AND OUTSIDE EQUIPMENT. -PULL RISER.DISCONNECT BRIDGE CRANE. -BLEED DOWN AND LOTO ACCUMULATOR. REMOVE HCR ACCUMULATOR LINES. JACK UP RIG 2".PULL RIG AHEAD 4" MOVE SHIMS.SET RIG DOWN. • Printed 6/17/2013 9:21:08AM • !' ex Common Well Name:MPE-11 AFE No Event Type:WORKOVER(\NO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point '1 Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 21:00 - 22:00 1.00 MOB N SFAL DECOMP -R/U FLOWLINE.BOP ANCHORS. SECURE CELLAR AND OUTSIDE EQUIPMENT. -INSTALL RISER.RE-HOOK BRIDGE CRANE TO BOP CRADLE. -INSTALL HCR ACCUMULATOR LINES. -PRESSURE UP ACCUMULATOR. FUNCTION BOPE. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM,R/U TEST EQUIPMENT DUE TO 1 CHANGE IN WELL PLAN FOR CLEANOUT RUN. -VERIFY NO PRESSURE BELOW BLIND SHEAR RAM.OPEN RAM. -FILL STACK WITH FRESH WATER. i-PRESSURE TEST UPPER AND LOWER 2 7/8" IX 5"VBR TO 250/3500 PSI. -PRESSURE TEST ANNULAR WITH 2 7/8" TEST JT TO 250/3500 PSI.CHARTED. -PRESSURE TEST 5 MIN EA.CHARTED. -TEST WITNESSED BY WSLAND TOUR PUSHER. -- ;-MONITOR I/A. I-LOSSES TO WELL LAST 12 HRS=2 BBLS 9.3 PPG BRINE. -O/A=160 PSI. 5/31/2013 00:00 - 00:30 0.50 BOPSUR P DECOMP PJSM,R/D TEST EQUIPMENT. -DRAIN BOP STACK 00:30 - 02:00 1.50 BOPSUR N SFAL PECOMP PJSM WITH DSM.R/U DUTCH RISER AND I LUBRICATOR. -PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA.CHARTED. -PULL TWC.MONITOR WELL,STATIC. -L/D LUBRICATOR AND RISER. 02:00 - 03:00 1.00 PULL N SFAL DECOMP PJSM WITH FMC REP. -DRAIN STACK. -M/U LANDING JT WITH FOSV. VERIFY NO PRESSURE UNDER TUBING HANGER. -FMC BOLDS.PULL TBG HANGER TO RIG FLOOR.P/U WT 155K -FLOWCHECK WELL-STATIC. 03:00 - 03:30 0.50 PULL N SFAL DECOMP PJSM WITH CENTRILIFT,CREW,WSLAND TOUR PUSHER. -REVIEW DDI SOP FOR PULLING ESP. REVIEW PLAN FOR WELL CONTROL. R/U ESP SHEAVE AND TRUNK 03:30 - 04:00 0.50 PULL P DECOMP UD LANDING JOINT AND TBG HANGER. -UNDER BALANCED FLUID RUNNING OVER TOP TBG. -R/U AND PUMP 10 BBL DRY JOB. 04:00 - 08:00 4.00 PULL P DECOMP POH WITH 4 1/2"12.6#521 HYDRIL ESP COMPLETION FROM 11620' -L/D TUBING TO PIPESHED 1 X 1. 1 1-SPOOLING ESP CABLE. -F/11620'MD T/9400'MD -CONTINUOUS HOLE FILL 9.3 PPG. 08:00 - 08:30 0.50 PULL P DECOMP PJSM,P/U 5-1/2"POWER TONGS 4-1/2"POWER TONG HAD HYDRAULIC VALVE. -P/U 5-1/2"POWER TONGS. j -WELL IS STATIC. Printed 6/17/2013 9:21:08AM `l/orthAmeric ° ° Afrk' f ` ' Operation Summary�Repor� Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: 1X4-00XF6-E:(2,410,000.00) Project:Milne Point I Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 15:00 6.50 PULL P DECOMP POH WITH 4 1/2"12.6#521 HYDRIL ESP COMPLETION FROM 11620' -L/D TUBING TO PIPESHED 1 X 1. -SPOOLING ESP CABLE. -F/9400'MD T/4530'MD I-CONTINUOUS HOLE FILL 9.3 PPG BRINE. 1 BPH LOSS RATE. 15:00 - 15:30 0.50 PULL P DECOMP PJSM,WITH CREW FROM TOWN DISCUSS WELL PLAN. I-DISCUSS RECENT INCIDENTS. -PERFORM PRE-TOUR CHECKS. 15:30 - 21:30 6.00 PULL P DECOMP POH WITH 4 1/2"12.6#521 HYDRIL ESP COMPLETION FROM 11620' -L/D TUBING TO PIPESHED 1 X 1. SPOOLING ESP CABLE. -F/4530'TO 78' 1-FLOWCHECK WELL FOR 10 MIN-STATIC. -TOTAL 279 JTS 4 1/2"12.6#HYDRIL 521 TBG. -CONTINUOUS HOLE FILL 9.3 PPG.BRINE,1 BPH LOSS RATE. 21:30 - 23:00 1.50 PULL P DECOMP PJSM FOR L/D ESP MOTOR ASSEMBLY. -REVIEW WELL CONTROL PLAN FOR PULLING ESP PUMP. -L/D ESP MOTOR ASSY PER CENTRILIFT REP. CONTINUOUS HOLE FILL 9.3 PPG.BRINE,1 BPH LOSS RATE. -MOTOR AND SEAL FIELD CHECK GOOD. -NO SOLIDS NOTED IN TBG CROSS OVER. -SUSPECT ELECTRICAL PROBLEM IN ESP CABLE. -RECOVERED 279 2'CANNON CLAMPS. -3 PROTECTOLIZERS. 1 CROSS SPLICE CANNON CLAMP. -2 FLAT GUARDS. -TOP SEAL HAD NORMAL MIXED FLUIDS WITH OIL IN TOP CHAMBER. CLEAN OIL THRU REST OF MOTOR AND SEAL ASSY. 23:00 - 00:00 1.00 PULL P DECOMP 1PJSM.R/D ESP SHEAVE AND TRUNK -R/D 4 1/2"TBG EQUIPMENT. -CLEAR RIG FLOOR. -MONITOR WELL.CONTINUE WITH 1 BPH LOSS RATE. -0/A=180 PSI.PVT=256 BBLS. -LOSSES TO WELL LAST 12 HRS= 11 BBLS 9.3 PPG BRINE. 6/1/2013 00:00 - 00:30 0.50 CLEAN P DECOMP PJSM,INSTALL 9"ID WEAR RING. RI 4 LDS. '-LOADING 4"DRILL PIPE INTO PIPESHED. r +MONITOR WELL. Printed 6/17/2013 9:21:08AM • Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) ' 00:30 - 05:30 5.00 CLEAN P DECOMP PJSM,LOAD 380 JTS 4",15.5#DRILL PIPE INTO PIPE SHED. -STRAP AND TALLY SAME. -WHILE LOADING DP P/U 14 JTS 6.5#2 7/8" EUE 8RD TBG WITH 10'MULE SHOE. I-STAND TBG IN DERRICK. STATIC LOSS RATE=1 BPH. 05:30 - 18:30 13.00 CLEAN P DECOMP 'RIH W/2-7/8"MULE SHOE ON 2-7/8"6.5#EUE FROM DERRICK MULE SHOE AND 20 JTS 2-7/8"TBG=463.11 -P/U 357 JTS 4",15.5#DRILL PIPE 1x1 F/PIPE SHED. I-POH AND STAND BACK (7)STANDS 4"DP. -P/U 21 JTS 4"DP,1X1 FROM PIPE SHED. 357 JTS IN AT 11742' ABOVE TOLAT 11808' MD. -PVT=296 BBLS 9.3 PPG BRINE. WELL"WORK TRANSFER PERMIT' COMPLETED FOR GPB S-PAD. 18'30 - 19:45 1.25 CLEAN P DECOMP M/U TOP DRIVE.OBTAIN PARAMETERS BEFORE ENTERING TOLAT 11808' -P/U WT 164K.S/O WT 117K. -OBTAIN SPR 3 BPM AT 145 PSI.4 BPM AT 265 PSI. 1-EST.CIRCULATION PUMPING 8.5 BPM 1800 I PSI. -BREAK OFF TOP DRIVE. RIH TO 12121'WITH 123 STANDS DP IN ■HOLE. 19:45 - 21:00 1.25 CLEAN P DECOMP I M/U TOP DRIVE.PUMP 1 BPM 60 PSI. ESTABLISH RETURNS. -RIH SLOW.TAG AT 12195',SET DOWN 2K. -INCREASE PUMP TO 7.5 BPM 1240 PSI. -P/U 10'ROTATE 1 TURN.RIH WORK PAST TIGHT SPOT. -TAG AT 12205'SETTING DOWN 2K. -P/U 10'ROTATE 1 TURN.RIH WORK PAST TIGHT SPOT. -TAG AT 12215'SETTING DOWN 2K UP TO 8K. -P/U 10'ROTATE 1 TURN.RIH WORK PAST TIGHT SPOT. -VERY LITTLE FILL ENCOUNTERED. -TAG TOP CIBP AT 12245'MD. -SOME SAND AND PARAFIN SEEN AT SHAKER @ BU. ICI Printed 6/17/2013 9:21:08AM • Operation Summary Report":; Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point I Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM 1Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:30 1.50 CLEAN P DECOMP PUMP 20 BBL HI VIS SWEEP 8.5 BPM 1720 PSI. -SWEEP OUT OF TBG TAIL.P/U 10'TO 12235'. -CIRCULATE SWEEP TO SURFACE. 1-SOME SAND AT SWEEP RETURNS. -DUMP SWEEP RETURNS. -FLOWCHECK WELL FOR 10 MIN.SLIGHTLY CHARGED FROM CIRCULATING AT PERFS. FLOWCHECK ANOTHER 10 MIN.WELL !STATIC. I-BREAK OFF AND BLOW DOWN TOP DRIVE. WHILE CIRCULATING: WELL TOOK 22 BBLS 9.3 PPB BRINE. -PVT=218 BBLS. 22:30 - 00:00 1.50 CLEAN P _ DECOMP I POH FROM 12235'LAYING DOWN 16 JTS DRILL PIPE TO ABOVE TOLAT 11805' -USE CONTINUOUS HOLE FILL. -FLOWCHECK WELL FOR 10 MIN ABOVE TOL. STATIC LOSS RATE 1 BPH. -POH L/D 4"DRILL PIPE 1 X 1 TO PIPESHED TO 11332' USE CONTINUOUS HOLE FILL FROM TRIP • TANK. -CONTINUE 1 BPH STATIC LOSS REATE. -0/A=180 PSI.PVT=214 BBLS. 6/2/2013 00:00 - 09:00 9.00 CLEAN P DECOMP POH FROM 11332'WITH 4"DRILL PIPE AND 2 7/8"CLEANOUT BHA TO 5640' -L/D 4"DRILL PIPE 1 X 1 TO PIPESHED. -USE CONTINUOS HOLE FILL WITH 9.3 PPG BRINE. -STATIC LOSS RATE CONTINUES AT 1 BPH. -210 JTS 4"DRILL PIPE L/D. -LD 4"DP 1X1 TO PIPE SHED TO 463'MD. 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM,RU TO LD 2 7/8"EUE TBG. -LD 2 7/8"TBG TO PIPE SHED 1X1. -BO AND LD MULE SHOE. 10:00 - 11:00 1.00 BOPSUB P DECOMP PULL WEAR RING. -CLEAR RIG FLOOR OF 2 7/8"TBG HANDLING TOOLS. -LOAD ESP COMPLETION TOOLS IN PIPE SHED. 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM,MU ESP COMPLETION TOOLS. -PU ESP MOTOR SECTIONS FROM PIPE SHED AND SERVICE MOTORS PER CENTRALIFT REP. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM,PU AND MU ESP MOTOR ASSEMBLY PER CENTRALIFT REP. -WSL,DDI SUPERINTENDANT,TOOL PUSHER,FMC REP,RIG CREW IN 'ATTENDANCE. -DISCUSSED PICKING UP THRU-TBG DUMMY TBG HANGER ASSEMBLY. 12:30 - 14:00 1.50 RUNCOM P RUNCMP CONTINUE TO MU AND SERVICE MOTOR ASSEMBLY. 1-CENTRALIFT REP TO SUPERVISE OPERATION. - --------- Printed 6/17/2013 9:21:08AM I _ m ° ! S $ Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 RUNCOM P RUNCMP ADJUST TORQUE TURN EQUIPMENT PER DDI CASING REP. -MOBILISE ESP CANNON CLAMPS AND CENTRALIFT EQUIPMENT TO RIG FLOOR. 16:00 - 17:30 1.50 RUNCOM P RUNCMP PJSM FOR RUNNING TTESP COMPLETION. -REVIEW RUNNING STEPS FROM WELL PLAN WITH BAKER,FMC AND CENTRILIFT REPS. REVIEW WELL CONTROL PLAN. DRAIN STACK,M/U MOTOR ASSY, CROSSOVER,PUP JT 1 JT 4 1/2"12.6#HYDRIL 521 TO DUMMY HANGER -M/U LANDING JT WITH FOSV.LAND DUMMY HANGER.FMC REP RILDS. -L/D LANDING JT. -MONITOR I/A.STATIC LOSS RATE CONTINUES 1-2 BPH. KEEP WELLBORE FULL AS NEEDEED. 17:30 - 23:00 5.50 RUNCOM P RUNCMP R/U HANDLING EQUIPMENT. M/U 4"GS SPEAR ASSEMBLY WITH 2 JTS 2 7/8"PAC TBG AND XO PER BAKER AND CENTRILIFT. RUN INTERNAL TTC PUMP ASSEMBLY IN 3 STEPS FOLLOWING WELL PLAN. -INSTALL TBG STOP PER WELL PLAN. -CLOSE BLIND SHEAR RAMS. -TEST PACKOFF USING TUBING STOP TO 1000 PSI FOR 5 MIN.CHARTED. BLEED OFF PRESSURE THRU CHOKE. OPEN BLIND SHEAR RAM. RETREIVE TUBING STOP. -MONITOR I/A.FILL AS NEEDED.STATIC LOSS RATE 1-2 BPH. 23:00 - 23:30 0.50 RUNCOM P RUNCMP L/D GS SPEAR ASSY.M/U LANDING JT WITH FOSV. FMC REP BOLDS.PULL DUMMY HANGER TO RIG FLOOR. -L/D DUMMY HANGER AND LANDING JT. 23:30 - 00:00 0.50 RUNCOM P RUNCMP PJSM,R/U ESP SHEAVE. R/U HANDLING EQUIPMENT. -O/A=190 PSI. -MONITOR WELLBORE.1-2 BPH STATIC LOSS RATE. -LOSSES TO WELL IN LAST 12 HRS=25 BBLS — � 9.3 PPG BRINE. Printed 6/17/2013 9:21:08AM �f Operation Summary Report s Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/3/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM FOR RUNNING ESP COMPLETION. -REVIEW RUNNING STEPS FROM WELL PLAN WITH CREWAND CENTRILIFT REP. I- REVIEW WELL CONTROL PLAN. -DISCUSS SPOOLER COMMUNICATIONS AND RUNNING SPEED. -VERIFY OPTIMUM TORQUE. REMOVE TEMPORARY MLE CAP. -PULL ESP CABLE OVER SHEAVE AND M/U CABLE TO MOTOR. -CENTRILIFT CHECK ESP CABLE CONDUCTIVITY. USE CONTINUOUS HOLE FILL.1-2 BPH !STATIC LOSS RATE. 00:30 - 05:30 5.00 RUNCOM P RUNCMP RIH WITH 4 1/2"12.6#521 HYDRIL TBG FOLLOWING WSL TBG TALLY AND WELL PLAN STEPS. M/U TBG WITH DDI TORQUE TURN.USE OPTIMUM TORQUE 4440 FT LBS. -RIH SLOWLY SETTING IN SLIPS EASY. -USE CAUTION NOT TURNING PIPE. -INSTALL CANNON CLAMP ON EVERY JT. CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE EVERY 1000' -FLUSH TBG PUMPING.5 BPM FOR 5 BBLS EVERY 2000' -CONDUCTIVITY OF ESP CABLE FAILED (TEST TO GROUND)AT 2130'MD. -NOTIFY RWO ENGINEER. 05:30 - 10:00 4.50 RUNCOM N DFAL 2,1.30.00 RUNCMP PJSM,CHANGE OF WORK SCOPE. -POH AND L/D 4-1/2"TBG. -POH F/2130'MD T/-ESP ASSEMBLY. -F/FAILED ESP CONDUCTIVITY. -L/D 4-1/2"HYDRIL 521 12.6#TBG. -MAINTAIN CONTINUOUS HOLE FILL. -ESP CABLE DAMAGED WHEN REELING SPEED WAS SLOWER THAN HOISTING SPEED. --3 BPH LOSS RATE,9.3 PPG BRINE. 10:00 - 12:00 2.00 RUNCOM N DFAL 2,130.00 RUNCMP PJSM,PERFORM SERVICE CHECKS ON ESP ASSEMBLY. -CUT MLE LEAD. -CONDUCTIVITY OF MOTOR,PASSED. -CONDUCTIVITY OF MLE CABLE,FAILED. -SERVICE MOTOR WITH NEW OIL. -CENTRILIFT MAKE UP NEW MLE CABLE AT SHOP AND -PERFORM CABLE SPLICE TO REEL. 12:00 - 17:30 5.50 RUNCOM N DFAL 2,130.00 RUNCMP MAKE MOTOR LEAD SPLICE. -CENTRILIFT REP MAKE UP NEW MLE CABLE AT SHOP AND -PERFORM CABLE SPLICE TO REEL. -PJSM,HANG ESP CABLE SHEAVE IN DERRICK. -M/U MLE TO ESP MOTOR ASSEMBLY. -MOTOR FAILED TEST. -NOTIFY ODE ABOUT MOTOR TEST FAILURE. Printed 6/17/2013 9:21:08AM • A r SK f� Operation Summary Repo Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)17:30 - 18:00 0.50 RUNCOM N DFAL 2,130.00 RUNCMP PJSM FOR CHANGE OF WORK SCOPE. -DISCUSS PLAN FORWARD FOR UD TT-ESP MOTOR WITH CREW, WSL,CENTRILIFT AND TOUR PUSHER. -REVIEW WELL CONTROL PLAN FOR NON SHEARABLES. -L/D FAILED MOTOR ASSEMBLY. SECURE PUMP AND MOTOR LEAD ON RIG FLOOR. USE CONTINUOUS HOLE FILL.3.5 BPH 1 STATIC LOSS RATE. 18:00 - 00:00 6.00 RUNCOM N DFAL 2,130.0Q RUNCMP PJSM.BOX UP AND LOAD OUT FAILED MOTOR. CENTRILIFT REP MOBILIZE NEW MOTOR FROM SHOP. WHILE WAITING COMPLETE DDI WORK ORDERS. PERFORM RIG MAINTENANCE. -MONITOR WELLBORE. USE CONTINUOUS HOLE FILL.3.5 BPH STATIC LOSS RATE. PVT=195 BBLS 9.3 PPG BRINE.O/A=180 PSI. -LAST 12 HRS WELL TOOK 43 BBLS. 6/4/2013 00:00 - 02:00 2.00 RUNCOM N DFAL 2,13Q.00 RUNCMP PJSM FOR CHANGE OF WORK SCOPE WITH ONCOMING CREW. -REVIEW WELL CONTROL PLAN FOR NONSHEARABLES IN BOP. -MOBILIZE PUMP TO RIG FLOOR. -P/U NEW ESP MOTOR AND M/U TO EXISTING SEAL ASSEMBLY. -SERVICE MOTOR. -TEST CONDUCTIVITY EVERY 1000' -USE CONTINUOUS HOLE FILL.STATIC LOSS RATE 3.5 BPH. -FLUSH MOTOR EVERY 2000'WITH 5 BBL BRINE. 02:00 - 05:00 3.00 RUNCOM N DFAL 2,130.00 RUNCMP RIH WITH 4 1/2"12.6# 521 HYDRILTBG FOLLOWING WSL TBG TALLY AND WELL PLAN STEPS. -M/U TBG WITH DDI TORQUE TURN.USE OPTIMUM TORQUE 4440 FT LBS. -RIH SLOWLY SETTING IN SLIPS EASY. -USE CAUTION NOT TURNING PIPE. -INSTALL CANNON CABLE CLAMP ON EVERY JOINT. -CENTRILIFT CHECK CONDUCTIVITY OF ESP CABLE EVERY 1000'. -FLUSH TBG AND MOTOR WITH 5 BBL BRINE AT 1/2 BPM EVERY 2000'. -RIH TO 2,130'MD 05:00 - 11:30 6.50 RUNCOM P RUNCMP RIH FROM 2130'MD -RIH WITH 4 1/2"12.6# 521 HYDRIL TBG FOLLOWING WSL TBG TALLY AND WELL PLAN STEPS TO 5453'MD Printed 6/17/2013 9:21•08AM e g 8 Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) L Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00 @42.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 17:00 5.50 RUNCOM P RUNCMP REMOVE 2000'OF DAMAGED ESP CABLE FROM REEL. -RIG UP TO MAKE ESP CABLE SPLICE. -PERFORM SPLICE ON LED COATED FLAT CABLE AT 5453' NOTE:SITE CONTROL SPECIALIST COMPLETED VISUAL INSPECTION OF FLUID STORAGE AND EQUIPMENT STAGING AREA FOR RIVER OUTAGE ON"S"PAD. 17:00 - 00:00 7.00 RUNCOM P RUNCMP 'RIH WITH 4 1/2"12.6# 521 HYDRILTBG FOLLOWING WSLTBG TALLY AND WELL PLAN STEPS -M/U TBG WITH DDI TORQUE TURN.USE OPTIMUM TORQUE 4440 FT LBS. -RIH SLOWLY.SETTING AND PULLING SLIPS SLOWLY TO AVOID JARING THE STRING. -INSTALL CANNON CLAMPS ON EVERY (COLLAR -CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT PUMP 5 BBLS DOWN TUBING EVERY 2000' -PUMP 1/2 BPM AT 250 PSI I RIH TO 9075'MD -24 HOUR FLUID LOSS=63 BBLS 6/5/2013 100:00 - 05:00 5.00 RUNCOM P RUNCMP PRE-TOUR MEETING AND SPCC CHECKS RIH WITH 4-1/2"12.6#HYDRIL 521 TUBING& THROUGH TUBING ESP COMPLETION FROM PIPE SHED. -RIH FROM 9075'MD -TUBING TORQUE=4400 FT/LBS. -INSTALL CANNON CLAMPS ON EVERY COLLAR -CHECK CONDUCTIVITY OF CABLE EVERY 1000 FT -PUMP 5 BBLS DOWN TUBING EVERY 2000' -PUMP 1/2 BPM AT 250 PSI 05:00 - 09:30 4.50 RUNCOM P RUNCMP PJSM,M/U TBG HANGER,R/D CABLES AND SHEAVE. -M/U 11"FMC TBG HANGER TO LANDING JT. AND ORIENT PER FMC REP -FMC REP INSTALL ESP PENETRATOR INTO HANGER. -CENTRILIFT REP MAKE FINAL SPLICE AND TERMINATE CABLE -EXCESSIVE ESP CABLE ABOVE LAST CABLE CLAMP AND HANGER -MAKE 2 WRAPS OF ESP CABLE AROUND TUBING TO AVOID PINCHING CABLE. -ADD 2 CABLE CLAMPS TO SECURE CABLE BELOW HANGER. -CENTRILIFT REP CHECK PENETRATOR FOR CONDUCTIVITY. 09:30 - 10:30 1.00 RUNCOM P RUNCMP LAND TUBING HANGER. -BOTTOM OF PUMP AT 11,613'. -PICK UP WEIGHT 163K,SLACK OFF 100K. -FMC REP RUN IN LOCK DOWN SCREWS. -LAY DOWN LANDING JOINT. Printed 6/17/2013 9:21:08AM - � f Operation Summary Report , Common Well Name:MPE-11 AFE No Event Type:WORKOVER(WO) Start Date:5/28/2013 End Date: X4-00XF6-E:(2,410,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:1/9/1995 12:00:00AM Rig Release:6/5/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:20:11 6/18/1999 15:00©42.5ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 11:30 1.00 RUNCOM P RUNCMP INSTALL 4"TWC. -TEST TWC FROM BELOW TO 500 PSI FOR 10 MINUTES WITH A ROLLING TEST. -PUMPED AT 1.3 BPM AT 500 PSI.PUMPED AWAY 20 BBL. -TEST TWC FROM ABOVE WITH 250 PSI AND 3500 PSI FOR 5 MINUTES EACH. 11:30 - 14:00 2.50 BOPSUR P WHDTRE NIPPLE DOWN BOP FILL IA WITH 1 BBL 9.3 PPG BRINE -BLOW DOWN LINES. -NIPPLE DOWN BOP,BELL NIPPLE AND RISER. -STAND BOP ON STAND IN CELLAR AND SECURE. 14:00 - 15:00 1.00 WHSUR P WHDTRE INSTALL ADAPTOR AND TREE -FMC TECH PREP TREE AND ADAPTOR SPOOL -CENTRILIFT PERFORM FINAL CHECK ON ESP CABLE PENETRATOR ON TUBING HANGER. 15:00 - 19:00 4.00 WHSUR P WHDTRE INSTALL ADAPTOR AND TREE. NIPPLE UP FMC 11"X 4-1/16"DUAL ROTATING FLANGE AND CAMERON 4-1/16" TREE MPU DRILL SITE MAINTENANCE CONFIRM ORIENTATION OF TREE. -FMC TECH TEST ADAPTOR TO 250 AND 5000 PSI FOR 5 MINUTES. 19:00 - 20:00 1.00 WHSUR P WHDTRE PRESSURE TEST PRODUCTION TREE -TEST 4-1/16"CAMERON TREE -250/5000 PSI,BOTH 5 MINUTES CHARTED. PASSED. 20:00 - 22:00 2.00 WHSUR P WHDTRE PJSM,R/U AND TEST DSM LUBRICATOR -TEST 250/3500 PSI, FOR 5 CHARTED MINUTES. -PULL TWC -RETEST LUBRICATOR, INSTALL 4" TYPE H BPV. -PERFORM 500 PSI ROLLING TEST FROM BELOW. -1 BPM/500 PSI,20 BBLS PUMPED. 22:00 - 00:00 2.00 WHSUR P WHDTRE PREP FOR RDMO -FLUSH LINES WITH FRESH WATER -BLOW DOWN/RIG DOWN LINES -CLEAN PITS -R/D SECONDARY KILL AND CEMENT LINES 24 HR LOSSES=65 BBLS KWF -SITP=0 PSI -SICP=0 PSI -OA=180 PSI -RELEASED RIG FROM MPE-11 FOR MOVE TO MPL-04 AT 00:00 HRS,6-06-2013. Printed 6/17/2013 9:21:08AM • • Tree: 4-1/16""-sM FMC MPU E-11 Orig. KB Elev.= 53.83'(N 22E) Wellhead: 13-3/8"x 11"5K Orig.GL Elev.=24.40' w/11"x 4.5"Tubing Hanger RT Tag.Spool=29.43'(N 22E) Hydril 521 Top&Btm,3"CIW H BPV profile 4 r 80' ,,,6k 1 9 ,, ,%of f 20" 91.1 ppf,H-40 -; ,f;%4;',, KOP @ 1000' l''�/1i!%ry/f Max.hole angle=63 deg.f/ i °, ,,f '�% i rf„:'' 3,300'to 11,300' w* < 11 Hole angle thru'perfs=58 deg 9 5/8",40#/ft,L-80 BTC. 3455' A k�' Halliburton ES cementer 6976' N 1.1 D&D Tbg Stop 11,529' ii D&D Packoff Ass Top 11,531' 7"26pf,L-SD,NSCC,productinn casing (tit ID Is 6.151 cep NI 00383 bpi = Centrilift TTC-ESP Top 11,540' Components:Hanger 4 1/2" 12.6 ppf, L-80, 521 Hydril Tubing receptacle w/4""G"Fish Neck, PP Y D-head,tandem ESP,Intake and Drift ID=3.833", cap= 0.0152 _F' Pump eye.(Total Length=36.23') �` TTC Drilled Tbg Crossover 11,576' k 1 Tandem Seal Sections 11,587' f,_'; '1 Model GSB3 DB UT/LT HL H6 PFS I� Motor,RR to 100 HP,2300 volt, 11601' 26 amp,Model KMHG Jr i WeIILift w/4 fin Centralizer 11,611' Gauge ND=6733' (r Maw> ' 7"LaWilOg coOsit Irr,=,, 3r'SlIt �C�!!Va G2 y 7-Sral1]ost collar 11924',a.,.�. (5_25"11))se Iig c nags, 7"Stalinist shoe - Lieta trop Om HPLPO 1 11814' 1 Lisxr1 .alC I 8∎ fir t ids. 04l191N fZCICCL MINI Size SP? Ihtervel (1VD) 12239'RKB(3S-3/16/07) VAat'hid cast)i ibzidfe 1) 3.361 6 12176'-12234' 7011'-7042' Set 10!30M0by4-is. I Lower pais mod. 6 U256'-13310' 7053'-7082' 7304'TYD taz Laadtolllet 12697' BekETlimit voiles 12755' Baker float shoe 12830' IDATE REV.BY COMMENTS MILNE POINT UNIT 12/19/9/ MUU F.\"Can Imm 4t1 6/21/99 M.Lmdcr RWO.=ES WELL S-11 10%31'00 GMH RWO Nabors 4 E 07/04/06 MOR RWO Nabors 4 E API NO: 50-029-22541 03/28/07 REH RWO Nabors 3S 06/03/10 REH RWO Nabors 4ES/TTC-ESP Completion 08/03/12 Hulme RWO-Doyon 16 006/09/13 s.Kruskie RWO-Doyon 16 BP EXPLORATION(AK) STATE OF ALASKA AIKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS AUG 3 12O 12. 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter NieskileaihieGas Cons. Comm1S$1Or ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other Anchorage ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory ° 195 -001 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 22541 - - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025,518 & 028231 MPE -11 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 12830' feet Plugs (measured) 12245' feet true vertical 7355' feet Junk (measured) None feet Effective depth: measured 12245' feet Packer: (measured) feet true vertical 7048' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 32' - 112' 32' - 112' 1490 470 Surface 3424' 9 -5/8" 31' - 3455' 31' - 2943' 5750 3090 Intermediate Production 11938' 7" 29' - 11967' 29' - 6904' 7240 5410 Liner 1022' 5" 11808' - 12830' 6826' - 7355' 8290 7250 Perforation Depth: Measured Depth: 12176' - 12310' True Vertical Depth: 7012' - 7082' Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 11624' 6735' Packers and SSSV (type, measured and true vertical depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 'I -- - i - 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 123 20 494 200 183 Subsequent to operation: 120 21 460 100 182 14. Att ❑Copies of Logs and Surveys run 15. Well Class after work: F ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations 16. Well Status after work: _ ® Oil ❑ Gas ❑ WDSPL i2 Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564 -5683 N/A Printed am Joe ati, a Title Drilling Technologist Signatur ` !► natur � Phone 0 1 Date $ /�1' i� Prepared Lastufka, 5 64 -4091 (i... ,,,.. i . L. _ 9 R i G 1 � > �� `� Jo e Lastufka, 564 -4091 Form 10 -404 Revised 11 :7 MS SEP 0 4 Q ` " 1i4 0 i i g i nal 0nIy • • %7 V f 1;3 XWAT/ sn ire , " 5 ' 0 17; :0; F r 07 '''/Ilk; -3fg, ;4 4704414W04;44A/44 ;.. ; - , 4 4-44WI ?Ptk %4„ *4'; 44 4 . :40g,f4a,'; Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VKO-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/2/2012 05:00 - 08:30 3.50 MOB P PRE WAIT ON PAD PREP ON MPE-11. - EMPLOYEE ON B CREW SENT TO MEDIC FOR FOR IRRITATION IN RIGHT EYE AT 07:30 HRS. - WHILE WORKING ON BOILER GOT SOMETHING IN RIGHT EYE CAUSING IRRITATION. - EYE WAS FLUSHED. RELEASED TO RETURN TO WORK. - WILL GO IN FOR A FOLLOW UP AT 06:30 AM 8/3/12 AS PER MPU MEDIC. 08:30 - 13:00 4.50 MOB P PRE PJSM. LAY MATTING BOARDS AROUND MPE-11. - RECEIVED DRILL SITE OPERATORS PERMISSION TO MOVE. - MOVE OFF OF MPE-14 AND ON TO MPE-11. - DRILL SITE OPERATOR PRESENT DURING OPERATION. - SPOT RIG AND LEVEL UP RIG. - RIG ACCEPTED @ 13:00 HRS, 08/02/2012. 13:00 - 16:00 3.00 KILLW P DECOMP PJSM. RIG UP LINES TO MANIFOLD AND TREE. - RIG LINES UP TO TIGER TANK. SPOT SLOP TANK. 1:00 - 700 1.00 KILLW P DECOMP PJSM, REVIEW DDI SOP FOR WELL KILL. - FILL LINES & MANIFOLD TO TIGER TANK & WELL HEAD. - TEST ALL LINES TO BE USED DURING WELL KILL OPERATION. - TEST ALL LINES @ 250 / 3500 PSI / 5 MIN EACH / CHARTED. 1700 - 8:00 1.00 KILLW P DECOMP PJSM. HANG ESP SHEAVE IN DERRICK. - R/U TRUNK FOR ESP CABLE. 18:00 - 20:00 2.00 KILLW P DECOMP WAIT ON DSM TO PULL BPV. - CLEAN RIG AND PERFORM RIG MAINT. - CLOSE OUT WELL TANSFER PERMIT ON MPE-14A WITH DSO. - LOAD 4" DRILL PIPE INTO PIPE SHED. 20:00 - 21:30 1.50 KILLW P DECOMP PJSM. REVIEW DDI SOP FOR BPV. - WITH WSL, DSM, TOOL PUSHER AND CREW. - R/U AND TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA. CHARTED. - PULL BPV. SECURE TREE- CLOSE ACTUATOR, MASTER VALVE. - R/D LUBRICATOR. - INSTALL TREE CAP. - TBG PRESSURE= 760 PSI. I/A= 820 PSI. 0/A= 200 PSI. 21:30 - 00:00 2.50 KILLW P DECOMP WAIT ON AM WELL KILL WITH RWO FIELD SUPERINTENDANT. - CLEAN AND WORK ON RIG MAINT. - FILL PITS WITH 9.6 PPG BRINE KWF WITH .6% SAFELUBE AS IT ARRIVES. - CONTINUE TO LOAD 4" DRILL PIPE INTO PIPE SHED. Printed 8/27/2012 10:40:49AM , ; ;;41;;V4N1144PM,',46aTig, $ " • !'"/g;;:i':,/,:;')UAWA;:itlE0114::;[;! 61; ' 7i 34 3�j . / 9N<%'.;,1t:Ac,i4;g1ta<:?1 ; <,k$4,: *; 11.'< dA V AAVA§ 40 &'" 4 ""'' ) '" : '/I 1 Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 ©42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/3/2012 00:00 - 05:00 5.00 KILLW P DECOMP WAIT ON AM WELL KILL WITH RWO FIELD SUPERINTENDANT. - CLEAN AND WORK ON RIG MAINT. - FILL PITS WITH 9.6 PPG BRINE KWF WITH .6% SAFELUBE. - FINISH LOADING 4" DRILL PIPE INTO PIPE SHED. 05:00 - 08:00 3.00 KILLW P DECOMP CONTINUE TO WAIT ON CREW CHANGE FOR WELL KILL. - CREW CHANGE @ 08:00. 08:00 - 08:30 0.50 KILLW P DECOMP PERFORM RIG EVACUTION DRILL W/ CREW COMING ON TOUR/ - SIMULATE FIRE IN THE PIPE SHED. - ALL PERSONEL NOTIFIED, INCLUDING TRUCK DRIVERS. - EVACUATED TO WELL SITE LEADER SHACK. - AAR PERFORMED, FINDINGS INCLUDE: - (1) TRUCK DRIVER'S RADIO WAS NOT IN SERVICE. - LOUD AUDIBLE ALARM NEEDED FOR RIG EVACUATIONS. - (1) FIRE EXTINGUISHER MAY BE DEPLOYED, AFTER THAT, IF THE FIRE IS NOT 'CONTAINED, LEAVE THE AREA, CALL THE FIRE DEPARTMENT. 08:30 - 09:00 0.50 KILLW P DECOMP PRE JOB MEETING ON WELL KILL OPERATIONS. - HIGHLIGHTED VALVE ALIGNMENT AND COMMUNICATION. - SSV OPERATIONAL, TASK ASSIGNMENTS, PRESSURE. Printed 8/27/2012 10:40:49AM .4,T; .1• 41111V;;;A04.,',',,v06,"*.e.LoicrAY.4%)/' ; 1 , , ';?;;,%:%‘'; 4' " '"' *9 ;,,•,,,o,;p !.] 7•J ' , — • • „ „ 4~1, , „ • „ , „ Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 11:00 2.00 KILLW P DECOMP LINE UP AND CONFIRM VALVE ALIGNMENT. - ALERT MILNE PT AND DRILL SITE OPERATOR .VENTING GAS. - BLEED GAS OFF OF VA THRU CHOKE TO TIGER TANK. - MOSTLY FLUID COMING BACK AFTER A FEW MINUTES OF BLEEDING. - SHUT IN AND OBSERVE PRESSURE CLIMB TO 500 PSI ON VA. - LINE UP TO PUMP DOWN TUBING & TAKE RETURNS UP VA. - PUMPING 120 DEGREE 9.6 PPG BRINE W/ .6% SAFE LUBE. - TAKING RETURNS THRU THE CHOKE AND TO THE TIGER TANK. - EQUALIZE PRESSURE AND OPEN UP TO THE TUBING. - BRING PUMP ON AND RATE UP TO 5 BPM HOLDING CASING @ 600 PSI. - INITIAL CIRC PRESSURE @5 BPM / 1200 PSI. W/ 9.6 PPG BRINE - PUMP 175 BBLS & CLOSE CHOKE & BULLHEAD INTO FORMATION. - BULLHEAD @7 BPM / 1700 PSI, PRESSURE CLIMBING. - ADJUST RATE TO KEEP PRESSURE UNDER 2000 PSI. - 30 BBLS 9.6 PPG BRINE BULLHEADED, FCP = 5 BPM / 1900 PSI. - OPEN CHOKE AND CIRCULATE @5 BPM / 650 PSI DOWN TUBING. - TAKE RETURNS UP VA, THRU CHOKE AND TO TIGER TANK. - PUMP 75 BBLS AND SHUT DOWN PUMP, CLOSE IN CHOKE. 11:00 - 12:15 1.25 KILLW P DECOMP STRAP TIGER TANK, 225 BBLS FOR A LOSS OF 25 BBLS. - SUCK OUT TANK, TRUCK CALLED IT 240 BBLS. 12:15 - 13:15 1.00 KILLW P DECOMP OPEN CHOKE AND RESUME CIRCULATING @ 5 BPM / 600 - 700 PSI. - WITH 300 BBLS 9.6 PPG BRINE PUMPED AFTER BULLHEADING, TAKE SAMPLES. 9.2 HEAVY COMING BACK. - CONTINUE CIRCULATING @5 BPM / 600 - 700 PSI. - W/ 350 BBLS PUMPED SEE 9.5 HEAVY. CIRCULATE 375 BBLS. - 9.6 PPG BRINE COMING BACK. SHUT DOWN AND MONITOR WELL. 13:15 - 14:30 1.25 KILLW P DECOMP STRAP TIGER TANK, 245 BBLS IN TANK LOST 55 DURING THAT CIRCULATION. - TOTAL LOST TO WELL NOT COUNTING BULLHEAD OP = 75 - 80 BBLS. - EMPTY TIGER TANK AND MONITOR WELL. - TUBING AND VA ARE DEAD. SLIGHT VACUUM ON TBG AND VA. - MONITORED 0/A THROUGHOUT OPERATION .. 200 - 250 PSI. 14:30 - 16:00 1.50 KILLW P DECOMP PJSM. BLOW DOWN / RIG DOWN LINES. - PREP TO SET TWO WAY CHECK VALVE. Printed 8/27/2012 10:40:49AM +y „�.r,. �„ ,�„ az �"'.' ? n. . lo, i. �.; wi, r / /.s.' , „" iki ,�. % Y - r> %l/ /'r/ , jib /rD 11/"r e, : -:; g. > >,s " , , r��:,, ,'� o ✓,,l . �, �U. X , , .� r,.4; « /,ayyr ,//, �.aw. � ; � e r /i / ° s ,'':.'S✓ �r - ;i °j:, : � .fj` �' "f.'.`srGi ?r `t; L. .. r. b,., �`,.. %'"N'' �/ r Vr • xi � /., : „s,G t >„ ,� / , i % t, .. G /r,, - ' r o F �r4. ” %hrG YS' 3 ;a „e..•^r f 1 • ,'/ �� v„ r . s,. ,,.,,�i>,. .. ,s,✓ = :'; � ✓3%�: %,r %':. ' 2r� �,��d /r;�.�- ... /G %GO / / „�,.A �' �+� rr /G� �� Common Well Name: MPE -11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4- 00VKO -E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 KILLW P DECOMP WAIT ON WELL SUPPORT, THEY ARE AT DOYON RIG 14. 17:00 - 20:30 3.50 WHSUR P DECOMP PJSM WITH DSM AND CREW. - P/U LUBRICATOR, TEST TO 250/3500 PSI. - SET TWC, L/D LUBRICATOR. • •; : • I, I S � PSI 10 MIN - PUMP 2.5 BPM 500 PSI. FINAL 2 BPM 500 PSI. - TEST ABOVE TWC 250/3500 PSI 5 MIN EA. CHART ALL TESTS. 20:30 - 22:00 1.50 WHSUR P DECOMP PJSM, REVIEW DDI SOP FOR N/U BOP. - R/U AND USE CONTINUOUS HOLE FILL 8 BPH - FMC FUNCTION LDS AND BLEED HANGER VOID. - N/D TREE AND ADAPTOR FLANGE 22:00 - 23:00 1.00 WHSUR P DECOMP FNQQREP INSPECTED 41/2” 521 HYDRIL HANGER THREADS. - ATTEMPTED TO SCREW IN 4 1/2” 521 HYDRIL XO. - COULD ONLY GET 4 TURNS - XO SHOULDER WOULD BOTTOM OUT ON TOP OF HANGER. NOT ALLOWING IT TO MAKE UP THE PROPER AMOUNT OF TURNS. - ORDER 4' X 4 1/2” 521 HYDRIL PUP FROM STORES. 23:00 - 00:00 1.00 WHSUR N WAIT DECOMP WAIT ON PUP JT TO ARRIVE. - LOSSES TO WELL IN LAST 12 HRS= 124 BBLS 9.6 PPG BRINE KWF. 8/4/2012 00:00 - 00:30 0.50 WHSUR P DECOMP CREW CHANGE, MAKE EQUIP CHECKS. - CONDUCT RIG EVAC DRILL, HIGH METHANE GAS IN CELLAR. - AAR: - RIG CREW AND THIRD PARTY PERSONEL RESPONDED TO PRIMARY MUSTER AREA. - DRILLER AND FLOORHAND DONNED SCBA AND SWEPT RIG WITH PORTABLE MONITOR. - ALL PRESENT AT HEAD COUNT BY SCS. - LOADER OPERATOR BLOCKED PAD ENTRANCE. - NOTIFICATIONS BY WSL AND TOOL PUSHER SIMULATED. 00:30 - 01:00 0.50 WHSUR P DECOMP 4 1/2” 521 HYDRIL PUP ON LOCATION. - FMC VERIFY HANGER THREADS AND PROPER M/U 4 1/2 TURNS. 01:00 - 03:00 2.00 BOPSUR P DECOMP PJSM, REVIEW DDI SOP FOR N/U AND TEST BOP. - N/U BOPE. Printed 8/27/2012 10:40:49AM )... !' oltiW '7* Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VKO-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 ©42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 05:30 2.50 BOPSUR P DECOMP PJSM TFST FIOP'S AS PFR nni SIP - M/U 2 7/8" TEST JT. - SHUT OFF HOLE FILL. - FILL STACK WITH FRESH WATER. ( 11/ - TURN ON HOLE FILL, WHEN VA FULL FLUID COMING OUT OF TEST JT. - TURN OFF HOLE FILL, FLUID DRAINING THROUGH POPPET INTO WELLBORE. - ATTEMPT TO TEST LOWER PIPE RAMS - TWC LEAKING BY AT POPPET. TEST FLUID GOING DOWNHOLE. - ATTEMPT TO SEAT TWC WITH MUD PUMP. - ATTAINED 3500 PSI BUT BLEEDS OFF SLOW. - VAC OUT STACK TO CLEAN DEBRIS IN POPPET ON TWC. - FILL STACK. CONTINUE WITH BOP TEST. 05:30 - 10:00 4.50 BOPSUR P DECOMP TEST BLIND / SHEAR RAMS AND CHOKE VALVES @ ao 3500 PSI. - TEST MANUAL AND HCR VALVES ON MUD CROSS AGAINST BLIND RAMS. - PICK UP 2 7/8" TEST JT, TEST ANNULAR PREVENTOR 250 / 3500 PSI. - TEST UPPER AND LOWER VARIABLE BORE PIPE RAMS W/ 2 7/8" TEST JT. 10:00 - 13:30 3.50 BOPSUR N DPRB DECOMP ATTEMPT TO TEST VBRS W/ 4 1/2" TEST JT. - APPEARS TWO WAY CHECK VALVE IS LEAKING BY. - SUSPECT DEBRIS IN POPPET ONCE AGAIN. - PULL TEST JT, DRAIN STACK AND FLUSH W / HOLE FILL PUMP. - RE INSTALL TEST JT, UNABLE TO GET TEST, WORSE NOW. - PULL TEST JT, DRAIN STACK, BLOW OUT CHECK VALVE W/ AIR. - CLOSE BLIND RAMS AND ACHIEVE LOW AND HIGH PRESSURE TEST. 13:30 - 15:00 1.50 BOPSUR P DECOMP REINSTALL 4 1/2" TEST JT AND TEST VAR BORE PIPE RAMS. - TEST UPPER AND LOWER 2 7/8" X 5" VAR BORE P/ RAMS - ALL TESTS DONE a 250 / 3500 PSI / 5 MIN / CHARTFD - TEST SURFACE SAFETY VALVES @ 250 3500 PSI / 5 MIN / CHARTED. - NO FAILURES, AOGCC REP CHUCK SCHEVE WAIVED WITNESSING TEST. - PERFORM DRAWDOWN TEST ON ACCUMULATOR, GOOD TEST. - RIG DOWN TEST EQUIPMENT. 15:00 - 16:00 1.00 BOPSUR P DECOMP PJSM. INSTALL DUTCH RISER, RUN IN LOCK DOWNS. - FILL STACK AND RIG UP LANDING JT. 16:00 - 20:00 4.00 BOPSUR N DECOMP WAIT ON WELL SUPPORT TO PULL TWO WAY CHECK VALVE. - WELL SUPPORT IS AT DOYON 14 PULLING A TWC VALVE. Printed 8/27/2012 10:40:49AM • ; , : 'ee'; " tt••• *.k / A; .Vmt.t O AwAfpe , , , ;'?';:&:, ; • t';:: ::,0,; A ',4-/j-i:'?/,,,i;/0" Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 21:00 1.00 BOPSUR P DECOMP PJSM WITH DSM, WSL, TOOLPUSHER AND CREW. - REVIEW DDI SOP FOR PULLING TWC. - M/U LUBRICATOR TO DUTCH RISER. - TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA. CHARTED. - PULL TWC. TBG ON SLIGHT VAC. - L/D LUBRICATOR AND DUTCH RISER. 21:00 - 22:30 1.50 BOPSUR P DECOMP PJSM WITH FMC, CENTRILIFT, WSL, TOOL PUSHER AND CREW. - REVIEW DDI SOP FOR PULLING HANGER ESP. - REVIEW WELL SHUT IN PLAN WITH HANGER AND ESP CABLE. - M/U 4 1/2" 521 HYDRIL XO ON 4" DP LANDING JT WITH FOSV AND XO. - FMC BOLDS. PULL 11" X 4 1/2 TBG HANGER TO RIG FLOOR. - HANGER BROKE FREE AT 175K DECREASING TO 165K ( INCLUDING 40K TOP DRIVE WT) - P/U TO NEXT JT, CUT ESP CABLE ABOVE CLAMP. LOWER TO RIG FLOOR. - L/D HANGER. 22:30 - 23:45 1.25 BOPSUR P DECOMP M/U HEAD PIN WITH FOSV. R/U TO CIRCULATE. - CLOSE ANNULAR AND LINE UP THROUGH CHOKE VIA GAS BUSTER. - PUMP 5 BPM AT 680 PSI. CBU PLUS 10 BBLS. 23:45 - 00:00 0.25 BOPSUR P DECOMP MONITOR WELL, CONTINUES ON SLIGHT VAC. - WELL TAKING 8 BPH. - 0/A= 100 PSI. - LAST 12 HRS WELL TOOK 57 BBLS 9.6 PPG BRINE. - LAST 24 HRS WELL TOOK 155 BBLS 9.6 PPG BRINE. 8/5/2012 00:00 - 00:30 0.50 PULL P DECOMP CREW CHANGE. CHECK RIG EQUIP. - PJSM WITH CENTRILIFT, WSL, TOOL PUSHER AND CREW. - REVIEW DDI SOP FOR POH WITH ESP COMPLETION. - CONTINUE TO MONITOR WELL. 00:30 - 03:15 2.75 PULL P DECOMP RID CIRC HOSE. L/D FOSV AND HEAD PIN. - P/U WT= 165K. S/O WT= 110K. INCLUDES 40K TOP DRIVE WT. - POH FROM 11627' L/D 3 JTS. - THREAD ESP THROUGH SHEAVE - PULL 5 MORE JTS. SECURE ESP CABLE TO SPOOLER. - POH WITH 4.5" 521 HYDRIL 12.6 # ESP COMPLETION. - SINGLE OUT L/D TBG TO PIPESHED WITH THREAD PROTECTORS.. - SPOOLING ESP CABLE. - CONTINUOUS HOLE FILL, LOSS RATE 8 BPH. - KWF 9.6 PPG BRINE WITH .6% SAFE LUBE. - POH TO 11154' Printed 8/27/2012 10:40:49AM . '7•!':' ,* 1-$ 1.0 o, '40 Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VKO-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:15 - 03:45 0.50 PULL P DECOMP CONDUCT WELL CONTROL DRILL WHILE PULLING ESP COMPLETION. - SIMULATE WELL FLOWING. - P/U TO NEXT JT. SIMULATE SECURING AND CUTTING ESP CABLE - LOWER JT TO RIG FLOOR. INSTALL FOSV. CLOSE VALVE. - SIMULATE CLOSING ANNULAR. - DRILL TIME 3.5 MIN. - AAR - ROUSTABOUT TO GO TO RIG FLOOR TO HELP HOLD ESP CABLE WHILE CUTTING. - CENTRILIFT REMOVING CLAMP WHEN ALARM SOUNDED. RESECURE CLAMP TO CUT CABLE. - DISCUSSED USING ZIP TIES IN THE EVENT CLAMP WAS ALREADY REMOVED. 03:45 - 05:00 1.25 PULL P DECOMP CONTINI1F POH FROM 11145' To 10681' . - SINGLE OUT UD TBG TO PIPESHED WITH THREAD PROTECTORS.. - SPOOLING ESP CABLE. - CONTINUOUS HOLE FILL, LOSS RATE 8 BPH. 05:00 - 12:00 7.00 PULL P DECOMP CONTINUE POH FROM 10681' TO 6831' - SINGLE OUT UD TBG TO PIPESHED WITH THREAD PROTECTORS.. - SPOOLING ESP CABLE. - CONTINUOUS HOLE FILL, LOSS RATE 8 BPH. 12:00 - 13:00 1.00 PULL P DECOMP SERVICE RIG, INSPECT EQUIPMENT. - CONDUCTED WEEKLY SAFETY MEETING PRIOR TO COMING ON TOUR. - SUBJECTS INCLUDED EYE PROTECTION AND DROPPED OBJECTS. - DOYON SAFETY SUPERVISOR AND MIKE POWELL (BP SAFETY) PRESENT. 13:00 - 23:30 10.50 PULL P DECOMP GOILTMEELEDDEAL4 521 TBG FROM 6831' TO PUMP ASSEMBLY - LID TBG TO PIPE SHED WITH PROTECTORS. - CONTINUOUS HOLE FILL, 8 BPH LOSS RATE. - TOTAL CLAMPS RECOVERED FROM TBG= 280 CANNON CLAMPS. -2 EA 5.94" CANNON CLAMPS RECOVERED AT SPLICE. - TERMINATE ESP CABLE. - RECOVERED 2 FLAT GUARD CLAMPS. - 280 JTS PULLED - TBG PUNCH IN JT # 280 Printed 8/27/2012 10:40:49AM • , >, " g „i ,- /i, „_.i / .; : ,.t'.,�y h ","., i i . ; ” . � . 1'.,?' _;G .,! 1 , l H V; / , l jfY`�„i .,iktl ' ral:: , ..J � ; OHj'Y” ;, ,' ' r � . r r ;,✓.. r. .�,.i / /.r r ..�; <> >6,'." �`b' al,r;. /�. ,p ;ur �,, / Y! Yr.- G .,,�.:: %; 15• ';��; ; �: "v;;, ,..�vtzay„ `,ti. ./,6�. i 3 � ���' > :.r. 'i * c , P' „✓ a ai' ., v. ,f ..ys 6 .rid / / ,r�f, , f" "s r � , ,. y s�, 3 , 3 0 y � .. ,.' 4; ,; 'i � ,.ti ✓ i� ' / %/r / .�/ � :. /> '`" %// ,, / �, ,. //r �. � r te, . /;. r'is J �' j?' / //, ,'` ,ry�7' / .1/4 , 2 //.,, e,A /, r. /„_, /, .., r , , /,. </ �� / r ^y 6rr ��, ,,, ;':s.: /n ../i,r %.��ry�,i+', Oa. ^��;>., G... �e cs,,..:f� =. D, /.'��'�rr /, %i� /','mom �'k: , / / / /r /ia r✓ Common Well Name: MPE -11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4- 00VKO -E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:30 - 00:00 0.50 PULL P DECOMP - POH WITH ESP ASSEMBLY TBG. - USE CONTINUOUS HOLE FILL 8 BPH W/ 9.6 PPG BRINE. - LAST 12 HRS HOLE TOOK 91 BBLS 9.6 PPG BRINE. - LAST 24 HRS WELL TOOK 197 BBLS 9.6 PPG BRINE. - CONDUCTED WEEKLY SAFETY MEETING PRIOR TO COMING ON TOUR. - REVIEW EYE PROTECTION , DECONTAMINATION OF WORKER. - REVIEW OSHA REG FOR INDUSTRIAL POWER PLUGS FOR HAND TOOLS. - DDI SAFETY REP BOB MICK PRESENT FOR MEETING. 8/6/2012 00:00 - 01:00 1.00 PULL P DECOMP CREW CHANGE. CHECK RIG EQUIPMENT. PJSM, SPOOL CABLE TO UNIT AND SECURE. - R/D ESP SHEAVE. - LOAD BAKER TOOLS TO RIG FLOOR. 01:00 - 02:30 1.50 PULL P DECOMP PJSM, REVIEW ADDENDUM FOR PULLING ESP PUMP. - WITH BAKER, FMC, WSL, TOOL PUSHER AND CREW. - RIH WITH PUMP AND SINGLE. - RIH WITH 5 JTS 4 1/2" 521 HYDRIL TUBING TO 300' - TORQUE TO 4200 LBS. - M/U TBG HANGER WITH 4 1/2" HYDRIL 521 LANDING JT. - RIH AND LAND HANGER AT 23.12' RKB PUTTING EOP © 323' MD. - FMC RILDS. - R/U AND FILL DOWN VA WHILE HANGER LANDED. 02:30 - 03:00 0.50 PULL P DECOMP R/U AND TEST BAKER 2 7/8" PAC TIW VALVE TO 250/3500 PSI 5 MIN EA. - CHART TEST. - R/D TEST EQUIPMENT. 03:00 - 05:00 2.00 PULL P DECOMP PJSM, M/U XO FOR TOP DRIVE. - M/U 4" GS BHA. - GS , JARS, XO, 8 JTS 2 7/8" PAC DP, XO. 05:00 - 06:30 1.50 PULL P DECOMP PJSM. FISH ON ESP ASSEMBLY PACK OFF. - LATCH UP GS AND OBSERVE OVER PULL. - 42K UP AND DOWN WTS. 40K TOP DRIVE INCLUDED. - PULL TO 75K, NO RELEASE, 3 TIMES. - COCK JARS AND PULL TO 75K, SET JARS OFF. - REPEAT AND AFTER JARS GO OFF PULL TO 100K. - JARS GOING OFF © 33K OVER STRING WT AND PULLING 58K OVER. - REPEAT TWICE MORE AND STOP FOR DISCUSSION. 06:30 - 08:00 1.50 PULL P DECOMP CONSULT ODE. BRING ON PUMP AND DISENGAGE G SPEAR. - POOH W/ 2 7/8" PAC PIPE & LID OLS. - CONTINUOUS HOLE FILL THROUGHOUT, 6 - 8 BPH LOSS RATE. Printed 8/27/2012 10:40:49AM • " ' v' m%%:/vi.rwAvwfwv,,,,x091141r7—''.; ?AM" * • " ;V44 / vo;:g4ke0, * 3 ;'• / Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 PULL DECOMP PJSM. BOLDS. - PULL HANGER TO FLOOR AND UD SAME. 08:30 - 09:30 1.00 PULL P DECOMP PJSM. POOH W/4 1/2" HYDRIL 521 TUBING. - PULL LAST JT AND ESP ASSEMBLY ABOVE ROTARY TABLE. - OPT TO BREAK IT ALL DOWN FROM THE BOTTOM UP. 09:30 - 12:00 2.50 PULL P DECOMP PJSM. I ID MOTC)R / PI IMP ASSFMRI Y PIFCF BY PIFCE - MAKE BREAK ON TOP OF TEN FOOT PUP BELOW JT 280. - DISCUSS WAY FORWARD, IDENTIFY RISKS / HAZARDS. - SECURE ESP ASSEMBLY WHILE PULLING TUBING. - LOSSES TO WELL LAST 12 HRS= 71 BBLS 9.6 PPG BRINE. 12:00 - 12:30 0.50 PULL P DECOMP STOP OPERATIONS FOR CREW CHANGE. - SERVICE AND INSPECT RIG. 12:30 - 13:30 1.00 PULL P DECOMP PJSM. CONTINUE TO UD ESP ASSEMBLY. - SLIDE LAST JT OF TUBING UP W/ ASSEMBLY IN MOUSEHOLE. - UD JT 280 AND UD ESP ASSEMBLY. PACK OFF INSIDE JT 280. 13:30 - 14:30 1.00 PULL P DECOMP CLEAR CLEAN RIG FLOOR. RIG DOWN EQUIPMENT. 14:30 - 15:00 0.50 CLEAN P DECOMP PJSM. M/U WEAR BUSHING 6.5" ID. 15:00 - 17:00 2.00 CLEAN P DECOMP PJSM. P/U DUAL STRING MILL ASSEMBLY. - M/U BULL NOSE, XO, 2- 6.151 STRING MILLS, X0,4 BOOT BASKETS, - BIT SUB, BUMPER SUB, OIL JAR, XO, 6- 4 3/4" DC. 17:00 - 00:00 7.00 CLEAN P DECOMP RIH WITH STRING MILL BHA TO 6720' - SINGLE IN ON 4" DP FROM PIPE SHED. - WELL CONTINUES TAKING 8 BPH. - USE CONTINUOUS HOLE FILL. - 0/A= 200 PSI. - LOSSES TO WELL LAST 12 HRS= 68 BBLS 9.6 PPG BRINE. - LOSSES TO WELL LAST 24 HRS= 139 BBLS 9.6 PPG BRINE 8/7/2012 00:00 - 05:00 5.00 CLEAN P DECOMP RIH WITH STRING MILL BHA FROM 6720' TO 11,700'. 363 JTS - SINGLE IN ON 4" DP FROM PIPE SHED. - UP WEIGHT 170K DOWN WEIGHT 115K - WELL CONTINUES TAKING 8 BPH. - USE CONTINUOUS HOLE FILL. Printed 8/27/2012 10:40:49AM • Y u / ., : ; . n, : , , / � �, .5irlrr.;'�„.�/ ;'� ,'^� � � � u �� «'�'r`%Llf' , . Y//;.i,�� � sY>,' > ^yj'oii� f ; „ %i�%� / /, / /,�o :�!K% + "' Vi ,' � a., t.�„ _���., +�;/'�, s �/�'�''/�✓ E %3;:��� //�% �.,/ ,;.; �. /, / I �.���: ' -: `,� :,`.; q �r .s'/ /.... ��� /,,,,�� ;fix, � � w r /1�,,;i`.F ,� *�:`" /i, /r '� >a i sl r /�!% / //t,, , /, y , a � - t om[ �� s /� '✓/r,"� /� ,;� - ,.,,,,' . / {r ` : :,�, / ,r .�Y� /,.w,?; y i i . R .�,' „ /��4a'� / / /, ✓C' r,..tfi4����rn.� ^��+` /,/' +�F „%�� soi / / /�U",.E� +�f,vfi / Common Well Name: MPE -11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4- 00VKO -E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 06:30 1.50 CLEAN P DECOMP PJSM. CIRCULATE BOTTOMS UP. - AT 11,105', 363 JTS DP IN THE HOLE. - UP WT 175K, DOWN WT 118K, ROTATING WT 140K. - ALL UP AND DOWN WTS INCLUDE 40K TOP DRIVE. - RECIPROCATE AND ROTATE (50) RPM 5 TIMES, 11,705' - 11,650' - NO DRAG OR TAG SEEN WHILE RUNNING IN THE HOLE. - PUMPING 7 BPM © 1200 PSI. MONITORING LOSS RATE. - LOSSES A BIT MUCH, SLOW PUMP DOWN TO 5 1/2 BPM @ 850 PSI. - LOSS RATE 10 - 12 BPH WHILE CIRCULATING BOTTOMS UP. - ACQUIRE SLOW PUMP RATES, 30 SPM @ 250 PSI, 40 SPM @ 420 PSI. - MONITOR WELL / 15 MINUTES, FLUID LEVEL SLOWLY DROPPING. 06:30 - 08:30 2.00 CLEAN P DECOMP PJSM. SLIP AND CUT DRILLING LINE. - SLIP AND CUT 47' OF DRILLING LINE. - CHECK CROWN 0 MATIC. OK. 08:30 - 12:00 3.50 CLEAN P DECOMP PJSM. POOH W/ DRILL PIPE. - POOH & STAND BACK DRILL PIPE. - CONTINUOUS HOLE FILL, LOSING 6 - 8 BPH. - 12 HOUR LOSSES = 148 BBLS OF 9.6 PPG BRINE. 12:00 - 13:00 1.00 CLEAN P DECOMP SERVICE AND LUBRICATE RIG. - INSPECT DERRICK, OK. 13:00 - 15:00 2.00 CLEAN P DECOMP PJSM. CONTINUE TO POOH. - POOH & STAND BACK DP F/ 4224' TO SURFACE. 15:00 - 16:00 1.00 CLEAN P DECOMP PJSM. LAY DOWN BOTTOM HOLE ASSEMBLY. - LAY DOWN (6) DRILL COLLARS & CLEAN OUT ASSEMBLY. - CLEAN JUNK SUBS, RECOVERED 1/2 GAL OF SCALE. 16:00 - 16:30 0.50 CLEAN P DECOMP CLEAR CLEAN RIG FLOOR. 16:30 - 17:00 0.50 CASING P DECOMP PJSM W/ HALLIBURTON REP - M/U CHAMP PACKER, PUP JOINT ANn xn 17:00 - 00:00 7.00 CASING P DECOMP RIH ON 4” DRILL PIPE FROM DERRICK - F/ SURFACE T/ 10439' - PUWT = 156K, SOWT = 112K - OA = 200 PSI - LOSSES TO WELL LAST 24 FIRS= 233 BBLS 9.6 PPG BRINE 8/8/2012 00:00 - 00:30 0.50 CASING P DECOMP PJSM, CHANGE OUT CREWS - SERVICE RIG, SPCC CHECKS 00:30 - 01:30 1.00 CASING P DECOMP RIH WITH CHAMP PACKER, F/ 10439 T/ 11607' - PUWT = 168K, SOWT = 115K 01:30 - 02:00 0.50 CASING P DECOMP ESTABLISH CIRCULATION - SPR, 30 SPM = 240 PSI, 40 SPM = 390 PSI - CIRC AT 5 BPM = 600 PSI - SET PACKER AT 11600' MD, W/ 20 K DOWN WT. Printed 8/27/2012 10:40:49AM !' %y <�; i , n .. .: ;G, " `,:: %' :'✓`'/ ST C .,� d L r '� < „ '!,, :.�i ` x.s , /,v.�,, a . ,,.',,;,;r0. '.;, "; ;;;; :., .;;F::.:S;4..r ,., < ..r / ✓: ,�' dj .9' . �� ,. .,� -,•'A ' • �YSd r, / „ /i' /� /s � v "�:. ` ��/ ,, / / i /! -. d = nc , "rX” :.n^`� ", /'i i /r, „�+,0 .: k`.S"'' i'�5» .f,��'S'"�/. „r. .: (1 F' i':�v./ s. =' %' >r.it w'T::�;F' �p:�. .r,c�4, i :ar;. "r.a, ^.; ,ft =��s. C "a,% ar,6., , <s^� " r °i / >','; "�' ;t- / /., / '.ro��g yid ,/ /i.> ar 0 "^ z ' H y ^� i.c . .:;•,.' � %Y "�'r c: ,,.a , d, ,. ..r, / -" y ,,, r/ r . c,r ,6, r' ; /� /, ,/, rr '• /�.,<* :'r:" i: �''l /.rs . / �/ / „/� y . ; /'; `, :5., ,.,/ ,.�' .7 ,/ G-ri3 r� r fr � r , %;:A'�,' '":.C';,r. .�. � ,:�,.n it /' /,/S,.�l� a ;�a v': r, i E ''.es,.v; # 8 a.:' ' a y. " , � ,: z / ,i,`. , ./% l9, ,r,� ,¢�„ , rti? "� .?>.. ° 9� b d;'t� .'Y�.., f g ` ir 'p.,, „.; /J3'n'' ✓ " ':r3" 4 n' � ^ r •/% H ,` / ..r- _...' % 'l, - ='/. o °r,,. y „ r,'�'r.r ✓,..r, r- r�t' r..�s ...... t,�'.._ .. .. ?�' _,.. l<r......... g �,�< ✓,�r'la „;!!rl.'��r , .�J..r�.. Common Well Name: MPE -11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4- 00VK0 -E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 ©42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:00 1.00 CASING P DECOMP MIT -IA 7” 26# CASING - 250 PSI LOW. 3500 PSI HIGH 30 MINIJTFS,. CHARTED - TEST PASSED ALL CRITERIA - NOTIFIED WTL AND OBTAINED PO AUTHORIZATION TO PROCEED - BLEED OFF PRESSURE, OPEN RAMS, Cr UNSEAT PACKER %t )” - MONITOR WELL 10 MINUTES 03:00 - 12:00 9.00 CASING P DECOMP PJSM, PULL OUT OF HOLE - LAY DOWN DP 1X1 F/ 11600' MD - POOH TO 2825', UP WT = 80K, DOWN WT = 80K. - UP AND DOWN WTS INCLUDE TOP DRIVE, (40K). - 102 BBLS OF 9.6 PPG BRINE LOST TO WELL LAST (12) HRS. 12:00 - 12:30 0.50 CASING P DECOMP TOUR CHANGE, SERVICE RIG. - INSPECT AND LUBRICATE EQUIPMENT. 12:30 - 16:00 3.50 CASING P DECOMP PJSM. CONTINUE TO POOH W/ DP. - POOH AND LAY DOWN DRILL PIPE. - LID CHAMP PACKER AS PER HALLIBURTON REP. - CONTINUOUS HOLE FILL, LOSS RATE = 6 - 8 BPH. 16:00 - 16:30 0.50 CASING P DECOMP PJSM. PICK UP RUNNING TOOL. - PULL 6.5" ID WEAR BUSHING, UD TOOL. 16:30 - 18:00 1.50 RUNCOM P RUNCMP PRFP TO RI IN ESP MOTOR ASSY_ - CLEAR / CLEAN RIG FLOOR - LOAD ESP TOOLS IN PIPE SHED - MOBILIZE PAC PIPE EQUPMENT TO RIG FLOOR 18:00 - 21:30 3.50 RUNCOM P RUNCMP PJSM ON M/U ESP MOTOR - M/U MOTOR AND SEAL ASSEMBLY - SERVICE AND LOAD WITH OIL 21:30 - 22:30 1.00 RUNCOM P RUNCMP M/U #1 JOINT 41/2" 12.6# L -80 521 HYDRILL PIPE - M/U HANGER AND LANDING JOINT - RIH, LAND HANGER IN WELL HEAD, RILDS - LID LANDING JOINT 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJSM, M/U PAC PIPE AND GS TOOL. - R/U 2 7/8" ELEVATORS AND POWER TONGS FOR PAC PIPE - M/U GS SPEAR, 3 1/8" JAR, AND 2 JTS OF PAC PIPE - PU AND STAND OUT OF WAY - OA= 100PSI - LOSSES TO WELL LAST 24 HRS= 157 BBLS 9.6 PPG BRINE Printed 8/27/2012 10:40:49AM • (5544'5' 4'; ; ; 5= 555 ' :' ' ***; ; ; , ,*•1;,;! I , , I*7"aw, 9 ,3 ; ;*;;;44,0 * ** 1-; " t‘ :' ;' 4 ;' ; ''' 45 "" I ;-A: :5;":;4; c , ; , %X5'‘4,fyy 4 450 /4 .%5,4 4' ; ; ;, ,;* 1:I‘,k7: (*,* N- 6:5; ;;:‘,5;;;YA Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VKO-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 ©42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/9/2012 00:00 - 02:30 2.50 RUNCOM P RUNCMP PJSM WITH NEW CREW ON WU ESP PUMP, NON ROUTINE TASKS - PERFORM SPCC AND RIG EQUIP CHECKS - RIH WITH ESP PUMP ON "GS" . - LOCATE AND MATE UP TO SPLINED SHAFT IN MOTOR W/ 2K DOWN WT - DISENGAGE "GS" WITH 1.5 BPM = 380 PSI - POOH AND M/U PACK OFF ASSY - RIH WITH PACK OFF ASSY, SET INTO PUMP WITH 2K DOWN WT - DISENGAGE "GS". - POOH AND IVVU TEST TOOL - RIH WITH TEST TOOL, SET INTO PACK OFF ASSY - DISENGAGE "GS" AND POOH 02:30 - 03:00 0.50 RUNCOM P RUNCMP R/U TEST EQUIPMENT - CLOSE BLINDS - TEST PACK OFF TO 1000 PSI, 5 MINUTES, CHARTED = GOOD TEST - RID TEST EQUIPMENT, BLOW DOWN LINES 03:00 - 04:30 1.50 RUNCOM P RUNCMP RIH WITH "GS" AND LATCH ONTO TEST TOOL - PULL TEST TOOL OUT OF HOLE AND L/D SAME - M/U TUBING STOP ASSY AND RIH TO TOP OF PACK OFF - SHEAR DOWN TO SET TUBING STOP, OBSERVE PINS SHEAR ON WEIGHT INDICATOR - DISENGAGE "GS" AND POOH - L/D "GS" , JAR AND 2 JTS OF 2 7/8" PAC PIPE 04:30 - 06:30 2.00 RUNCOM P RUNCMP PJSM ON RIGGING UP TO RUN ESP - C/O POWER TONG HEADS TO 4 1/2" - HANG SHEAVE IN DERRICK - PULL ESP CABLE FROM SPOOLING UNIT TO RIG FLOOR 06:30 - 07:30 1.00 RUNCOM P RUNCMP PJSM. PULLING TUBING HANGER. - PICK UP LANDING JT, M/U TO HANGER, BOLDS. - PULL HANGER & LAY DOWN SAME. - PULL MOTOR AND PUMP ASSY THRU ABOVE ROTARY TABLE. 07:30 - 08:30 1.00 RUNCOM P RUNCMP PJSM. CENTRILIFT TIES IN ESP CABLE TO MOTOR. - CONTINUITY TEST, OK. 08:30 - 12:00 3.50 RUNCOM P RUNCMP PJSM. RIH W/ ESP AND 4 1/2" 12.6# L-80 HYDRIL 521 TBG. - TORQUE TURN EACH CONNECTION TO 5200 FT/BS. - INSTALL CANNON CLAMPS ON EACH CONNECTION. - CHECK THE CONTINUITY EVERY 1000'. - BREAK CIRCULATION @ 1500', 1 BPM @ 650 PSI. - RIH F/ SURFACE T/ 1708' MD 12:00 - 12:30 0.50 RUNCOM P RUNCMP CHANGE OUT CREWS - SERVICE RIG, INSPECT AND LUBRICATE EQUIPMENT. Printed 8/27/2012 10:40:49AM 7; , „ • ; ;„,,„ „ „.„ „,„ .‘„ Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 16:00 3.50 RUNCOM P RUNCMP PJSM. RIH W/ ESP AND 4 1/2" 12.6# L-80 HYDRIL 521 TBG F/ 170V T/ 7284 MD - TORQUE TURN EACH CONNECTION TO 5200 FT/BS. - USE JET LUBE SEAL GUARD PIPE DOPE. - INSTALL CANNON CLAMPS ON EACH CONNECTION. - CHECK CONTINUITY EVERY 1000' AND PUMP 10 BBLS TO CLEAR STRING - -.1 BPM @ 600 PSI DURING 10 BBL CIRCULATIONS EVERY 2000'. - OA = 100 PSI - LOSSES TO WELL LAST 24 HRS= 113 BBLS 9.6 PPG BRINE 16:00 - 16:30 0.50 RUNCOM P RUNCMP HOLD WELL CONTROL DRILL WHILE RIH W/ ESP COMPLETION. - AAR CONDUCTED POST DRILL. - LIFT NUBBIN NEEDS TO BE TIGHT - CASING TONGS NEED TO BE USED TO TORQUE SAFETY VALVE. - DRILLER DID NOT PICK UP PIPE DUE TO CONCERN FOR ESP CABLE. - ALL HANDS HAVE A GOOD UNDERSTANDING OF THEIR POSITIONS AND RESPONSIBILITIES DURING A WELL CONTROL EVENT. 16:30 - 00:00 7.50 RUNCOM P RUNCMP PJSM. RIH W/ ESP AND 4 1/2" 12.6# L-80 HYDRIL 521 TBG F/ 1708' T/ 7284' MD - TORQUE TURN EACH CONNECTION TO 5200 FT/BS. - USE JET LUBE SEAL GUARD PIPE DOPE. - INSTALL CANNON CLAMPS ON EACH CONNECTION. - CHECK CONTINUITY EVERY 1000' AND PUMP 10 BBLS TO CLEAR STRING - - 1 BPM @ 750 PSI DURING 10 BBL CIRCULATIONS EVERY 2000'. - HOLD IN-DEPTH TABLE TOP KICK DRILL WITH WSL, TOUR PUSHER, AND ALL CREW MEMBERS - OA = 100 PSI - LOSSES TO WELL LAST 24 HRS= 113 BBLS 9.6 PPG BRINE 8/10/2012 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM, CHANGE OUT CREW, PERFORM SPCC AND RIG EQUIP CHECKS - RIH W/ ESP AND 4 1/2" 12.6# L-80 HYDRIL 521 TBG F/ 7284' T/7330 ' MD - TORQUE TURN EACH CONNECTION TO 5200 FT/BS. - USE JET LUBE SEAL GUARD PIPE DOPE. - INSTALL CANNON CLAMPS ON EACH CONNECTION. - CHECK CONTINUITY EVERY 1000' AND PUMP 10 BBLS TO CLEAR STRING - 1 BPM @ 750 PSI DURING 10 BBL CIRCULATIONS EVERY 2000'. Printed 8/27/2012 10:40:49AM • • fOgig)L, Aff$11A;F",",Iffejf, C ,? ' :% ',‘ ' ,At . ' 4:".4Y; ' 4 • 4 7 , „ „, , ' :;;; ' ; 4 % 3 "• • A 3 , 3 y A ;;;;Y:A /4R „ 3,0 "/"/, / AA„•,, , 3 ,3 '3 3 :; 3 '', , '3,A,1•33.;,;::exA, "f; = yv? Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 ©42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 06:30 5.00 RUNCOM P RUNCMP PERFORM CENRILIFT CABLE SPLICE - CIRCULATE 1 BPM = 500 PSI TO CLEAR PIPE - CLEAN CLEAR RIG FLOOR, PERFORM WORK ORDERS 06:30 - 12:00 5.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP ON 4 1/2" HYDRIL 521 TBG. - TORQUE TURNING ALL CONNECTIONS TO 5200 FT/LBS. - USING JET LUBE SEAL GUARD PIPE DOPE. - INSTALLING CANNON CLAMPS ON EACH CONNECTION. - TESTING ESP CABLE EVERY 1000' AND CIRCULATING 10 BBLS. - CIRC RATE = 1 BPM @ 500 PSI. - LOSSES TO WELL = 44 BBLS IN LAST (12) HRS. 12:00 - 14:00 2.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP ON 4 V2" HYDRIL 521 TBG. - TORQUE TURNING ALL CONNECTIONS TO 5200 FT/LBS. - USING JET LUBE SEAL GUARD PIPE DOPE. - INSTALLING CANNON CLAMPS ON EACH CONNECTION. - TESTING ESP CABLE EVERY 1000' AND CIRCULATING 10 BBLS. - CIRCULATION RATE = 1 BPM @ 500 PSI. 14:00 - 14:30 0.50 RUNCOM P RUNCMP CONDUCT A BOP DRILL WHILE RUNNING IN THE HOLE. - DISCUSS EACH RIG HAND RESPONSIBILITIES. - SIMULATE PICKING UP PIPE AND CUTTING ESP LINE. - DISCUSS TORQUING UP SAFETY VALVE. - SHUT IN TIME, 1 MIN 45 SEC. 14:30 - 18:00 3.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP ON 4 'V2" HYDRIL 521 TBG. - TORQUE TURNING ALL CONNECTIONS TO 5200 FT/LBS. - USING JET LUBE SEAL GUARD PIPE DOPE. - INSTALLING CANNON CLAMPS ON EACH CONNECTION. - TESTING ESP CABLE EVERY 1000' AND CIRCULATING 10 BBLS. - M/U HANGER AND LANDING JT W/ TIW VALVE - FINAL CIRC RATE= 1 BPM @ 510 PSI. - PUWT = 158K, SOWT = 106K - 2 CANNON CLAMPS = 279 TOTAL - PROTECTOLIZERS = 3 - CROSS SPLICE CANNON CLAMPS =2 - FLAT GAURDS = 2 18:00 - 19:00 1.00 RUNCOM P RUNCMP RIG DOWN CASING EQUIPMENT - MARK AND CUT ESP CABLE - RID ESP SHEAVE AND CABLE 19:00 - 22:30 3.50 RUNCOM P RUNCMP TERMINATE ESP CABLE AT TUBING HANGER - CHECK CONDUCTIVITY - LAND TUBING HANGER IN WELL HEAD - RUN IN LOCK DOWN SCREWS. Printed 8/27/2012 10:40:49AM : • jp. 'N WAY< v... iA Common Well Name: MPE-11 AFE No Event Type: WORKOVER (WO) Start Date: 8/2/2012 End Date: 8/11/2012 X4-00VK0-E: (1,620,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: DOYON 16 Spud Date/Time: 1/19/1995 12:00:00AM Rig Release: 8/11/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 20 : 11 6/18/1999 15:00 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 23:30 1.00 RUNCOM P RUNCMP INSTALL TWO WAY CHECK - LAY DOWN LANDING JOINT - INSTALL TWC - PERFORM ROLLING TEST ON TWC FROM BELOW TO 500 PSI AT 1.5 BPM FOR 10 MINUTES - TEST TWC FROM ABOVE 250 PSI LOW AND 3500 PSI HIGH FOR 10 MINUTES. CHARTED 23:30 - 00:00 0.50 RUNCOM P RUNCMP RIG DOWN TEST EQUIPMENT AND TOOLS - KEEP IA FULL. - OA PRESSURE = 200 PSI - LOSSES TO WELL LAST 24 HRS = 90 BBLS 9.6 PPG BRINE 8/11/2012 00:00 - 02:00 2.00 BOPSUR P RUNCMP PJSM, CHANGE OUT CREW, PERFORM SPCC AND RIG EQUIP CHECKS - MAINTAIN CONSTANT HOLE FILL THROUGH IA WHILE N/D AND N/U - SUCK FLUID OUT OF STACK - BLOW DOWN CHOKE LINES AND MANIFOLD N/D BOP STACK 02:00 - 05:00 3.00 WHSUR P RUNCMP N/U FMC 11" X 4 1/16" ADAPTER FLANGE AND 4 1/16" CAMERON TREE - CLEAN HANGER AND INSPECT BY FMC REP - CHECK CONDUCTIVITY BY CENTRILIFT REP - N/U ADAPTER FLANGE - ORIENT TREE AND INSTALL - TEST ADAPTER FLANGE SEAL BY FMC REP TO 5000 PSI, 30 MINUTES 05:00 - 06:30 1.50 WHSUR P RUNCMP TEST FMC TREE - FILL TREE WITH DIESEL - TEST TREE TO 250 PSI LOW, 5000 PSI HIGH, 5 MIN, CHARTED 06:30 - 08:00 1.50 WHSUR P RUNCMP PJSM. PICK UP LUBRICATOR. - PRESSURE TEST LUB @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. - PULL TWO WAY CHECK VALVE, WELL ON VACUUM. 08:00 - 10:00 2.00 WHSUR P RUNCMP PJSM. INSPECT RUNNING TOOL THREADS. - MAKE UP BPV AND FILL TREE. - PRESSURE TEST LUBRICATOR @ 250 / 3500 PSI, 5 MIN EA / CHARTED. - SET BPV. 10:00 - 11:00 1.00 WHSUR P RUNCMP PJSM. PERFORM ROLLING TEST ON BPV. - PUMP DOWN VA WITH TUBING WING VALVE OPEN. - ICP = 600 PSI @ 2.5 BPM, FCP = 530 PSI @ 1 BPM / 10 MINUTES / CHARTED. - NO FLOW OBSERVED UP TUBING, GOOD TEST. - BLEED ALL PRESSUE AND RIG DOWN LINE. - TBG = 0 PSI, VA = 0 PSI, 0/A= 200 PSI. 11:00 - 12:00 1.00 WHSUR P RUNCMP CLEAN CELLAR AREA, SECURE WELL. - RIG RELEASED @ 12:00 HRS, 08/11/2012 Printed 8/27/2012 10:40:49AM • i Tree: 4- 1/16 "" - 5M FMC MPU E -11 O rig. KB Elev. = 53.83' (N 22E) Wellhead: 13 -3/8" x 11" 5K Orig. GL Elev. = 24.40' w/ 11" x 4.5" Tubing Hanger RT Tbg. Spool = 29.43' (N 22E) Hydril 521 Top & Btm, 3" CIW H BPV 1 profile Note: This well has an open 20" 91.1 ppf, H -40 80' OA shoe. 2/14/12 KOP @ 1000' Note: Csg test to 3500 psi @ Max. hole angle = 63 deg. f/ 11600' on 8/8/12 3,300'to 11,300' Hole angle thru' perfs = 58 deg tI 9 5/8 ", 40 # /ft, L -80 BTC. 3455' s '' Halliburton ES cementer 6976' 41 IN D &D Tbg Stop 1 11,520` ill 7" 26 ppf, L -S0, NSCC production casing D &D Packoff Assy Top 1 11,522' 1 ( drift ID = 11 151", cip = Centrilift TTC-ESP Top 1 11,531' 1 E. I Components: Hanger ppf, L 80, 521 Hydril Tubing receptacle w /4" "G" Fish Neck, 4 1/2" 12.6 Pp Y g D -head, tandem ESP, Intake and Drift ID = 3.833 ", cap = 0.0152 = Pump eye. (Total Length= 36.50') ••k TTC Drilled Tbg Crossover 1 11,576' • Tandem Seal Sections 1 11 1 Model GSB3 DB UT /LT HL H6 PFS NEGMN Man Motor, 228 HP, 2305 volt, 11,600` 1 , , 1 60 amp, Model KMHG ME EirA WeIILift w/ 4 fin Centralizer 11,620' 1 p Gauge TVD = 6733' Utz RA Titz 1 11871' T'L*ndim collar 11881' 1 5 " c slew L' 3 1 7" Setif - loot so11 11924' 11808' (5.25ID) 7 " Setif - kilt sloe 1 1:196r Liter top p t, I.PO 1 -. 11816' 1 Lserl.1 1, . 1 1821 " 1 Ration: a6r�ar 6 c/CCL size Spy 1 (TVD) `. 12239' RKB (3S 3/16/07) 1 M - c h e a t e d cast ton lar tr 123454 ,3,3/g 6 12176'- 12234' 7D11' -7042' sot 10f3O+'110 Lower pelts isolate . 3-31!$ 6 1335'- 12310' 7053' -7032' E 71104' TVD 1 col 1 11697" 1 Bakarfloatcollar 1 12783' 1 Baker float shoe 12830' I DATE REV. BY COMMENTS MILNE POINT UNIT 12/19/97 MDO ESP Canplc6on 4ES 6'21;99 M L,nda. x\40 7 ES WELL E -11 lo' <o CGMH R �' ' >r.;4F4 0 04 06 N1Ott R.w8 Na ors 4 E;S 03/28/07 REH RWO Nabors 3S API NO: 50 -029 -22541 06/03/10 REH RWO Nabors 4ES/ TTC -ESP Completion 08/03/12 Hulme RWO - Doyon 16 BP EXPLORATION (AK) PTh 193 - G1 MPS 1i MPU IA Gas Vent Simplified Schematic for Illustration IA Gas Swab Valve Production 3 Phase Flow to Facility Piping Wing Valve • Manual Isolation Valve SSV SSV 0 Q 0 Master Valve Flow Line Flow Line High Pressure Low Pressure Pilot Trip Pilot Trip IA Valve 0 • ESP STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO~OF SUNDRY WELL OPERA ONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Change out ESP / 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 195-001 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22541-00-00 7. Property Designation: 8. Well Name and Number: ADL 028231 MPE-11 9. Field /Pool(s): Milne Point Unit / Kuparuk River San ds 10. Present well condition summary Total depth: measured 12830' feet true vertical 7355' feet Plugs (measured) 12245' Effective depth: measured 12245' feet Junk (measured) None true vertical 7048' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3424' 9-5/8" 3455' 2943' 5750 3090 Intermediate Production 11938' 7" 11967' 6905' 7240 5410 Liner 1022' 5" 11808' - 12830' 6826' - 7355' 8290 7250 yl~~}t Iyq~j~7~M r~ I '~ ~'.% 1.. 1d f t °m~'f ~ 'W YYf ~i'r '1iYM1' ~ L' V ..-. Perforation Depth: Measured Depth: 12176' - 12310' True Vertical Depth: 7012' - 7082' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# L-80 11627' 6737' Packers and SSSV (type, measured and true vertical depth): 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~ U ~ ~ ~ Z Treatment description including volumes used and final pressure: A~Btki Qd & G8t Cons. Gotntrtission Anchorage 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 32 3 258 Subsequent to operation: 32 2 186 1,160 194 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ^ Exploratory ®Development ^ Service ® Dail Re ort of Well O erations y p p ® Well Schematic Diagram 15. Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Drilling Technolo ist ` ~ Prepared By Name/Number: Signature ~ Phone 564-462$ Date Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 R6DMS Submit Original Only ~11L 13.2010 ~,~' 7z8-~d North America -ALASKA - BP Page 1 of ~ Operation Summary Report _ Common Well Name: MPE-11 DIMS __ _--- AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/19/2010 End Date: 5/20/2010 X4-0009E-E (150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES ~ Spud DatelTime: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) __ 5/19/2010 12:00 - 16:00 4.00 MOB P PRE RD RIG. SCOPE AND LD DERRICK. 16:00 - 19:30 3.50 MOB P PRE MOVE RIG TO E-11 AND SPOT OVER WELL. JACK AND LEVEL SUBSTRUCTURE. 18:00 HOURS AOGCC REP JEFFF JONES WAIVED WITNESSING THE BOP TEST. 19:30 - 00:00 4.50 MOB P PRE SPOT PIPE SHED. RAISE AND SCOPE DERRICK. --- 5/20/2010 -- 00:00 - 00:30 0.50 RIGU PRE' COMPLETE SLOPING DERRICK. 00:30 - 01:00 0.50 RIGU PRE RU LINES TO PITS AND SPOT FUEL TRAILER 01:00 - 02:30 1.50 RIGU PRE ACCEPT RIG AT 01:00 HOURS. RU LINES TO _ TREE AND TIGER TANK. 02:30 - 04:00 1.50 RIGU PRE FILL PITS. CONTINUE TO RU LINES TO TREE 04:00 - 05:00 1.00 RIGU PRE PU LUBRICATOR AND PULL BPV 1000 PSI ON TUBING 250 PSI IA. Printed 6/11/2010 3:36:56PM North America -ALASKA - BP P~3~z ~ of 12 Operation Summary Report __ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ~ Phase Description of Operations (hr) (ft) _ 5/20/2010 _ 05:00 - 05:30 0.50 WHSUR P DECOMP PJSM ON WELL KILL OPERATIONS. 05:30 - 06:00 0.50 WHSUR P DECOMP TEST SURFACE LINES TO 3,500 PSI 06:00 - 07:30 1.50 KILLW P DECOMP SHUT IN WHP'S, TBG=970 PSI, IA=450 PSI, OA=260 PSI. -BLEED IA DOWN TO 40 PSI AND THE TBG (AILED TO BLEED DOWN. -BLEED TBG DOWN TO 400 PSI, SITP BUILD TO '600 PS4 -PUMP DOWN THE TBG AT 1 BPM / 870 PSI INTO ~ THE FORMATION, WITH NO PRESSURE INCREASE`TOIA. -PUMP DOWN!THE IA 1.64 BBLS AND PRESSURE UP TO 1000 PSI; WITH NO PRESSURE INCREASE TO TBG. -SITP= fi00 PSI,'IA=O PSI. PUMP 1.35 BBLS DOWN THE IA TO 800 PSI AND SI WELL. -ALL FLUID PUMPED WAS 10.4 PPG BRINE. -CONFER WITH ADW RWO ENGINEER ON PLAN .FORWARD. 07:30 - 11:30 4.00 KILLW P DECOMP . .WAIT ON HOT OIL UNIT. -HELD RIG EVACUATION DRILL. -HELD AAR WITH DAY CREW ON MPE-06. -HELD PJSM WITH HOT OIL CREW. 11:30 - 17:00 5.50 KILLW P DECOMP RU HOT OIL UNIT AND TEST ALL LINES TO 3,500 PSI. -PUMPED 65 BBLS OF 140 DEG CRUDE OIL DOWN THE TBG AT 1 BPM / 1400 PSI. WITH IA SHUT-IN WITH 600-800 PSI. -PUMPED 40 BBLS OF 140 DEG CRUDE OIL DOWN THE IA AT 1/2 BPM / 1500 PSI. WITH THE TBG SHUT-IN WITH 1000 PSI. (1800 PSI TO BREAK DOWN ICE PLUG) I ~ -RD HOT OIL UNIT, DURING 1 HR WAIT ON HOT OIL TO WORK. -SITP= 840 PSI, SICP= 900 PSI, OA= 280 PSI. 17:00 - 19:00 2.00 KILLW P DECOMP ~/~/HP'S ~ -SITP= 840 PSI, SICP= 900 PSI, OA= 280 PSI. -PUMP 66 BBLS HEATED 10.4 PPG BRINE DOWN THE TBG AT 2-3 BPM / 680-860 PSI THROUGH THE CHOKE TO TIGER TANK. -CLOSE CHOKE, BULLHEAD DOWN THE TBG IN TO FORMATION AT (1.5 TO 2 BPM / 990 - 1400 PSI) -SITP= 0 PSI, SICP= 1000 PSI. -STOP WELL KILL OPERATIONS AND CLEAR FALLING ICE FROM DERRICK. ~ 19:00 - 20:00 1.00 KILLW P DECOMP CLEAR ICE FROM DERRICK. Printed 6/11/2010 3:37:30PM ~~ r 1 North America -ALASKA - BP P~ye ~ °f ~ ~-' Operation Summary Report Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:30 2.50 KILLW P DECOMP CIRCULATE WELL TO 10.4 PPG BRINE 3 BPM (a). 780 PSI, IA=680-100 PSI. PUMP A TOTAL OF 10,000 STROKES TO GET CLEAN RETURNS. MONITOR WELL. WELL DEAD AND ON VACCUM. INITIAL LOSS RATE 60 BPM. ___ 22:30 - 00:00 1.50 KILLW P ~ DECOMP SET TWC. TEST TWC 500 PSI ROLLING TEST AND 3500 PSI TEST FROM ABOVE. 5/21/2010 ~ 00:00 - 01:00 1.00 WHSUR P DECOMP TEST TWC 500 PSI ROLLING TEST FROM BELOW AND 3500 PSI TEST FROM ABOVE. 01:00 - 03:00 2.00 WHSUR P DECOMP ' ND TREE AND ADAPTER FLANGE. 03:00 - 18:00 15.00 BOPSUR P DECOMP RECONFIGUE STACK TO 4 PREVENTER. NU BOP. ANNULAR, 2-7/8 x5'VBR'S, BLIND SHEARS, MUD CROSS, 2-7/8 X 5 VBR'S._ 18:00 - 20:00 2.00 BOPSUR P DECOMP NU RISER; SPACER SPOOL, DUTCH FLANGE AND CHOKE HOSE. 20:00 - 21:30 1.50 BOPSUR P `DECOMP MU TESTING EQUIPMENT AND PU TEST TOOLS 21:30 - 00:00 2.50 BOPSUR P DECOMP TEST BOP'S. WHILE MAINTENING 14 BBUHOUR LOSSES. WITNESSING BOP TEST WAIVED BY JEFF JONES OF THE AOGCC 18:10 HRS 5-19-2010. TEST CHOKE MANIFOLD 250 PSI LOW AND 3500 PSI HIGH. 5/22/2010 00:00 - 06:00 6.00 BOPSUR P DECOMP CONTINUE TESTING BOP TEST UPPER VBR'S, BLINDS, ANNULAR 250 PSI LOW AND 3500 PSI HIGH. TEST VBR'S WITH 2-7/8" AND 4-1/2 TEST JOINTS. TEST TIW 250 PSI LOW AND 35_00 P_SI HIGH. 06:00 - 06:30 0.50 BOPSUR P DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS. 06:30 - 07:00 0.50 BOPSUR P DECOMP N/U DUTCH SYSTEM. 07:00 - 09:30 2.50 WHSUR P DECOMP DRAIN STACK -M/U AND TEST LUBRICATOR TO 500 PSI WIT DIESEL. -PULL TWC -UD LUBRICATOR _ _ 09:30 - 10:00 0.50 BOPSUR P DECOMP N/D DUTCH SYSTEM AND INSTALL FLOW NIPPLE. __ 10:00 - 12:30 2.50 PULL P ~ DECOMP M/U TIW VALVE AND LANDING JOINT -CONFIRM WELL ON A VACUUM -FMC REP BOLDS -PULL TBG HANGER WITH 15K OVER PULL = 85K , F/-11647' MD T/-11627' MD THEN PUW = 70K. -CUT -45' OF ESP CABLE AND SECURE TO TBG. -UD TBG HANGER AND 10' PUP -M/U LANDING JOINT WITH TIW VALVE. Printed 6/11/2010 3:37:30PM n r~ North America -ALASKA - BP Page 3 of 12 Operation Summary Report Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.Sft (above Mean Sea Level) Date From - To i Hrs Task Code NPT NPT Depth Phase Description of Operations ~ (hr) (ft) 12:30 - 15:00 2.50 PULL _ P DECOMP CIRCULATE BOTTOMS UP -GOT RETURN AFTER 8 BBLS PUMPED. -PUMPED 465 BBLS 10.4 PPG AT 2-4 BPM / 360-1500 PSI -LOST 8 BBLS DURING CIRCULATION. -TBG AND IA ON A SLIGHT VACUUM =PUW=65K, SOW=40K 15:00 - 16:30 1.50 BOPSUR P DECOMP M/U XO's, TEST PLUG ON LANDING JOINT. -SET TEST PLUG -L/D LANDING JOINT AND_M/U 4-1/2" TEST JOINT _ _ 16:30 18:00 __ 1.50 BOPSUR P DECOMP , TEST LOWER VBR's (2-7/8" X 5") WITH 4-1/2" I ~ TEST JOINT -TO 250 PSI AND 3,500 PSI FOR 5 CHARTED MINUTES -KOOMEY TEST -200 PSI INCREASE TO 1800 PSI IN 47 SEC -TO'3,000 PSL IN 190 SEC -(4) BOTTLES AVERAGE = 2.150 PSI. 18:00 - 19:00 1.00 BOPSUR P DECOMP BEST LOWER VBR's (2-7/8" X 5"1 WITH 2-7/8" ~ST.IOINT 19:00 - 20:00 1.00.. PULL P DECOMP pU LANDING JOINT. IA ON VACUUM. PULL TEST PLUG TO FLOOR WITH 64k UP WT. LD TEST PLUG. TUBING ON VACUUM. LD TIW VALVE. 20:00 - 21:30 1.50 PULL P DECOMP FILL WELL WITH 13 BBLS. CIRCULATE BOTTOM UP 4 BPM @ 1500 PSI. NO LOSS DURING - CIRCULATION. 21:30 - 00:00 2.50 PULL P DECOMP POH LD 2-7/8 TUBING. 5/23/2010 00:00 - 03:30 3.50 PULL P DECOMP POH LD 2-7/8 ESP COMPLETION, 2-7/8" 6.5#, TBG, BRD, EUE. PULL A TOTAL OF 123 JOINTS 03:30 - 04:00 0.50 PULL P DECOMP SWAP ESP SPOOLS. 04:00 - 06:00 2.00 PULL P DECOMP CONTINUE TO POH LD 2-7/8" ESP COMPLETION. -155 JOINTS L/D ~ -6-7 BPH LOSS RATE. __ _ _ 06:00 - 08:00 _ 2.00 PULL P _ DECOMP RIG SERVICE AND PERFORM PRE-TOUR CHECKS ( -REMOVE ICE FROM DERRICK 08:00 - 17:00 9.00 PULL P DECOMP ~ CONTINUE TO POH LD 2-7/8" ESP COMPLETION. -FROM JOINTS # 155 TO # 345 -6-12 BPH LOSS RATE. -BUBBLES IN TBG. -CIRCULATE SURFACE TOSURFACE AT -818' MD -3 BPM / 200 PSI. FLOW CHECK, ON A VACUUM. ____ 17:00 18:00 __ 1.00 PULL P DECOMP CONTINUE TO POH LD 2-7/8" ESP COMPLETION. -FROM JOINT #346 TO #361 _ 18:00 - 19:30 1.50 PULL P DECOMP SERVICE SPOOLING UNIT GENERATOR. 19:30 - 21:00 1.50 PULL P DECOMP CONTINUE TO POH TO ESP. CLEAR FLOOR. 21:00 - 23:30 2.50 PULL P DECOMP LD ESP PUMP AND MOTOR. 10' SAND ON TOP PUMP.RECOVERED ALL CLAMPS. 23:30 - 00:00 0.50 PULL P DECOMP CLEAR FLOOR. 5/24/2010 ~ 00:00 - 02:00 ~ 2.00 PULL P DECOMP CLEAR FLOOR. LD PUMP AND MOTOR FRO ~_ _ __ PIPE SHED. RD ELEPHANT TRUNK. Printed 6/11/2010 3:37:30PM North America -ALASKA - BP Page 4 of 12 Operation Summary Report ___ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.Sft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 03:00 1.00 PULL ~ P ~ DECOMP WEEKLY SAFETY MEETING. DISCUSSED HIGH ~ ~ ~ LITES FROM THE WSL FORUM. REVIEWED THE 50-1-50 GOALS AS WELL AS THE FOUR TARGET SUBJECTS, PROCESS SAFETY, PERSONAL SAFETY, DROPPED OBJECTS AND CONTINUOUS IMPROVEMENTS 03:00 - 05:00 2.00 FISH P DECOMP MU FISHING BHA AND NINE 4-3/4" DRILL COLLARS. 05:00 - 14:00 9.00 FISH P DECOMP ` RIH PICKING UP 3-1/2" DP FROM PIPE SHED -TO 11,691' MD -12 BPH LOSS RATE... CONCURRENTLY: WEEKLY SAFETY MEETING. DISCUSSED HIGH LITES'FROM THE WSL FORUM. REVIEWED THE'50-1-50 GOALS AS WELL AS THE FOUR TARGET SUBJECTS, PROCESS SAFETY, PERSONAL SAFETY, DROPPED ~ OBJECTS AND CONTINUOUS IMPROVEMENTS. i LESSONS LEARNED BOOK. _ ~ 14:00 - 20:00 6.00 _ FISH P DECOMP CONTINUE RIH PICKING UP 3-1/2" DP FROM PIPE SHED W/ BHA #1T0 11691'. 20:00 - 21:30 1.50 FISH P DECOMP - .ATTEMPT TO REVERSE CIRCULATE 3 BPM @750 PSI. WHILE STACKING 3-4k. NO PROGRESS. CIRCULATE TO WASH TO PACKER 3 BPM 610 PSI. UP WT 133, DN WT 81. LATCH PACKER. RELEASE PACKER WITH 70k OVER. UP WT 145, DN WT 90. _ 21:30 - 22:00 0.50 __ FISH N DPRB DECOMP ATTEMPT TO POH. W WORK PACKER 30'. SWABBING. PUMP DOWN DP 2 BPM 700 PSI. SWABBED VOLUME. @ APPROX 22:30, 11 BBL GAIN REPORTED.. FOLLOWED BY SLUG OF SAND .WELL SHUT IN WITH 39 BBL GAIN. AFTER FLOWLINE DRAINED ETC 42 BBL GAIN WITH 340 SPI ON CASING 0 ON ~ i TUBING. MAKE NOTIFICATION TO j ~ SUPERINTENDENT ,ANCHORAGE ENGINEER AND i AOGCC. CASING PRESSURE STABILIZED AT 470 PSI. 24:00 HOURS _ 5/25/2010 00:00 - 00:45 0.75 KILLW N DPRB DECOMP DISCUSS PLAN FORWARD FOR CIRCULATING GAS FROM WELL. _ 00:45 - 01:30 0.75 KILLW N DPRB DECOMP CIRCULATE THROUGH CHOKE DRILLERS METHOD. 1 BPM INITIAL IA 470 PSI. PUMP 410 STKS = 2466E IA 0 PSI. SHUT DOWN AND MONITOR WELL. 0 CASING PRESSURE AND 0 TUBING PRESSURE. OPEN WELL. WELL ON VAC. FILL WELL WITH 9 BBLS. j 01:30 - 02:00 0.50 KILLW N DPRB DECOMP FLOW CHECK WELL. WELL REMAINS ON VAC. ~ REFILL WELL WITH 7 BBLS. -___ _ 02:00 10:30 _ 8.50 KILLW N DPRB DECOMP CIRCULATE BOTTOMS UP. 2BPM @ 490 PSI, j 36PM @ 1220 PSI. LOSS RATE 2-3 BBL PER 5 j MINS. Printed 6/11/2010 3:37:30PM n North America -ALASKA - BP Pa;e s or ~ z Operation Summary Report __ _ - Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5!20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ __ _ 10:30 - 13:30 3.00 KILLW N DPRB DECOMP SHUT IN WELL. 10 PSI ON CASING AND 0 PSI ON TUBING. PER DISCUSSION WITH FIELD SUPERTENDENTS WILL BLEED OFF AND MONITOR WELL FOR BREATHING. NO FLOW. NOTIFY FIELD SUPERTENDENT AND DISCUSS PLAN FORWARD. APPROVAL GIVEN TO POH AVOIDING SWABBING. CIRCULATE ACROSS TOP OF WELL. STATIC LOSS RATE 4.5 BPH. WORK PACKER PU SLOW WITHOUT SWABBING BUT PUSHING FLUIDS AWAY ON DOWN STROKE. STATIC LOSS RATE 6 BPH. 13:30 - 14:00 0.50 KILLW P DECOMP CLEAR ICE` FROM DERRICK 14:00 - 14:30 0.50 FISH P DECOMP PJSM FOR TRIP OUT OF HOLE. WILL POH MONITORING FLUID HEIGHT IN WELL FOR SWABBING: WILL .FILL WELL WITH CHARGE ~ PUMP FROM ISOLATED PIT#1. WILL STRAP EVERY STAND. 14:30 - 15:30 1.00 FISH - P -- -- DECOMP POH STANDING BACK DRILLPIPE. PULL THE FIRST 5 STANDS SLOW TO PREVENT - SWABBING. LOST 9.1 BBL. PIPE DISPLACEMENT 3.7 BBLS. 15:30 - 16:30 1.00 FISH P DECOMP PULL SECOND 5 STANDS. LOST 23.5 BBl VERSIS 5.4 BBL DISPLACEMENT. AVERAGE LOSS RATE 9 BPH. 16:30 - 00:00 7.50 FISH P DECOMP CONTINUE TO POH. PULLED 38 STANDS OF 122. LOSSES TO WELL=88.58 BBL + PIPE DISPLACEMENT. AVERAGE HOUR LOSS RATE 9.466E/HR. __ _ _ ____ 5/26/2010 __ _ __ 00:00 - 04:00 __ 4.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 60 OF 122 LOSSES TO WELL=131.5 BBL + PIPE DISPLACEMENT. _ AVERAGE HOUR LOSS RATE 9.7 BBL! HR. _ 04:00 - 06:00 2.00 _ FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 69 OF 122 LOSSES TO WELL=159.8 BBL. AVERAGE HOUR LOSS RATE -10 BBL / HR. 06:00 - 07:30 1.50 FISH P __ DECOMP CREW CHANGE. SERVICE RIG AND PERFORM ENVIRONMENTAL WALKAROUNDS. CHECK AND SET PVT ALARMS. STATIC LOSSES DURING ________~ ~ 07:30 - 09:30 2.00 FISH P __ DECOMP THIS TIME WERE 12 BBLS OR_- 8 BBUHR. CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 80 OF 122 LOSSES TO WELL=195 BBLS. AVERAGE HOUR LOSS RATE -10 BBL / HR. _ 09:30 - 11:30 __ 2.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 90 OF 122 LOSSES TO ~ WELL=222 BBLS. AVERAGE HOUR LOSS RATE -10.5 BBL / HR. __ 11:30 - 13:30 _ 2.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 95 OF 122 LOSSES TO ~ WELL=236 BBL. AVERAGE HOUR LOSS RATE -7 BBL / HR. STOPPED AND FILLED PITS W/ 290 BBLS OF 10.4 BRINE. Printed 6/11/2010 3:37:30PM North America -ALASKA - BP Page 6 or ~ 2 Operation Summary Report __ -- -- __ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: __ Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ( (hr) (ft) _ 13:30 - t5:30 2.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 103 OF 122 LOSSES TO WELL=257.4 BBL. AVERAGE HOUR LOSS RATE -9 66~ / HR. 15:30 - 17:30 2.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 113 OF 122 LOSSES TO WELL=280. BBL. AVERAGE HOUR LOSS RATE -10 BBL / HR. 17:30 - 20:30 3.00 FISH P DECOMP CONTINUE TO POH SLOW TO PREVENT SWABBING. STAND 117 OF 122 LOSSES TO WELL=29T. BBL. AVERAGE HOUR LOSS RATE -9.7 BBL / HR.' 20:30 - 22:30 2.00 FISH P DECOMP CONTINUE TO POH SLOW 70 PREVENT SWABBING. STAND 120 OF 122 LOSSES TO WELL=301: BBL, AVERAGE HOUR LOSS RATE -8.9 BBL / HR. 22:30 - 23:00 0.50 FISH P DECOMP FLOW CHECK WELL. NO FLOW - ----- 23:00 - 00:00 1.00 FISH P. DECOMP PULL LAST TWO STAND OF DP. 5/27/2010 00:00 - 03:00 3.00 FISH P DECOMP qT COLLARS STILL ATTEMPTING TO SWAB. PUMP DOWN BACKSIDE 2 BBL AT 500 PSI. SLOW BLEED OFF. PUMP 2 BBL DOWN TUBING. PULL 1ST STAND OF COLLARS. PUMP 10 BBLS. LD TWO COLLARS. STAB TIW. DRAIN STACK. RU CEMENT LINE TO IA. CLOSE ANNULAR. PULL PACKER INTO BOP. SAW A 2K DRAG LOSS WHEN PACKER ENTERED BOP.NO PRESURE UNDER PACKER. WELL ON VAC. NO SCALE ON PACKER OR TAILPIPE. 03:00 - 07:00 4.00 FISH P DECOMP LD PACKER. FILL HOLE 12.5 BBLS. CIRCULATE THRU TAILPIPE 5 BPM AT 330 PSI. LD TAILPIPE.LD SCREENS SECOND SCREEN WAS FILLED WITH SAND AND WAS PUNCHED TO INSURE NO TRAPPED PRESSURE. NONE FOUND. _ 07:00 - 08:00 1.00 FISH P DECOMP SERVICE RIG WHILE MAINTAINING CONSTANT HOLE FILL 08:00 10:00 2.00 CLEAN _ P _ DECOMP CLEAN FLOOR. BLEED IA TO TIGER TANK. 10:00 - 13:30 3.50 BOPSUR P DECOMP SET TEST PLUG. CHECK ANNULAR AND PIPE RAMS CLOSING TIMES. 25 SEC FOR BAG TO CONTACT PIPE AND 157 SEC FOR KOOMEY PUMP TO SHUT OFF. 11 SEC FOR UPPER PIPE RAMS TO TOUCH PIPE AND 53 SEC FOR KOOMEY PUMP TO SHUT OFF. RU CEMENT LINE TO IA. SERVICE MUD CROSS VALVES. MARK ~ TEST JOINT. 13:30 - 14:00 0.50 BOPSUR P _ DECOMP PJSM WITH NABORS SUPERTENDENT. Printed 6111/2010 3:37:30PM North America -ALASKA - BP Page 7 of 12 Operation Summary Report Common Well Name. MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 00:00 10.00 BOPSUR P DECOMP TEST BOP'S. WHILE MAINTENING CONSTANT HOLE FILL. WITNESSING BOP TEST WAIVED BY CHUCK SCHEVE OF THE AOGCC 20:40 HRS 5-26-2010. TEST CHOKE MANIFOLD 250 PSI LOW AND 3500 PSI HIGH. - TEST UPPER VBR'S, BLINDS, ANNULAR 250 PSI LOW AND 3500 PSI HIGH. TEST VBR'S WITH 2-7/8" AND 4-1/2 TEST JOINTS. TEST TIW 250 PSI LOW AND 3500 PSI HIGH. ACCUMULATOR SYSTEM PRESSURE 300 PSI AFTER CLOSING 1800 PSI::. S3 SEC TO ATTAIN 200flS1, FULL PRESSURE ATTAINED JN 214 SEC N2 4 BOTTLES AVE 2130 PSI. 5/28/2010 00:00 - 02:00 2.00 CLEAN P DECOMP PULL TEST PLUG AND CLEAN FLOOR. 02:00 - 03:00 1.00 CLEAN P DECOMP MU BHA#2 CLEANOUT ASSEMBLY. 03:00 - 11:30 8.50 CLEAN P DECOMP -- }~IH WITH BHA #2 WITH DP STANDS FROM DERRICK TO 11680. NO RESTRICTION. 11:30 - 14:30 3.00 CLEAN P DECOMt' CIRCULATE WELL MIX 2 BBL SAFE LUB. CIRCULATE 441 BBLS. 50 BBL LOST TO WELL. 14:30 - 15:00 0.50 CLEAN P DECOMP SAFETY MEETING WITH ADW SUPERTENDENT. _.---- 15:00 - 18:00 3.00 CLEAN - P DECOMP pOH WITH CLEANOUT ASSEMBLY. PULL 50 STANDS. FILLING WELL CONTINUOUSLY EXPECTED FILL =27 BBL, FILL WELL WITH 43 BBLS. 18:00 - 21:00 3.00 ~ CLEAN P DECOMP POH WITH CLEANOUT ASSEMBLY. PULL 122 STANDS. FILLING WELL CONTINUOUSLY EXPECTED FILL =64.8 BBL, FILL WELL WITH 111 BBLS. 21:00 - 00:00 3.00 CLEAN _ P DECOMP LD CLEANOUT ASSEMBLY. CLEAN FLOOR. LOAD TEST PACKER IN PIPE SHED. LOST RATE 9 BBL/HOUR. 5/29/2010 00:00 - 00:30 0.50 DHB P DECOMP MU BHA #3 RBP. 00:30 - 05:00 4.50 DHB P DECOMP RIH WITH RBP WITH CONSTANT HOLE FILL. -STAND# CALCULATED GAIN ACTUAL GAIN 25 16.5 BBL 2 BBL 60 35.4 12 95 54.3 20 115 65.1 25 UP WT 114k 05:00 - 05:30 0.50 DHB P DECOMP SET RBP AT 11011'. PICK UP AND STAND BACK 2 STANDS OF DP IN DERRICK. 05:30 - 06:00 0.50 DHB P DECOMP RU HEAD PIN AND TEST RBP TO 1000 PSI FOR 10 CHARTED MINUTES -GOOD TEST. _ 06:00 - 06:30 0.50 BOPSUR P DECOMP SERVICE RIG. PERFORM PRE-TOUR CHECKS AND ENVIRONMENTAL WALK AROUNDS. Printed 6111/2010 3:37:30PM NOrth America -ALASKA - BP Page 8 of 12 Operation Summary Report Common Well Name: MPE-11_DIMS ~ AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-OOQ9F-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5n (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (nr) (n) 06:30 - 07:30 1.00 DHB P DECOMP MU 7" HES STORM PACKER AND RIH 1 FULL STAND. SET STORM PACKER AT -85'. PU WT = 113K LB, SO WT = 75K LB. STAND BACK 1 FULL STAND AND LD RUNNING TOOL. 07:30 - 08:00 0.50 _ DHB P DECOMP CLOSE BLINDS AND TEST STORM PACKER TO 1000 PSI FOR 10 CHARTED MINUTES -GOOD ( ~ _ TEST. __ _ 08:00 10:30 2.50 BOPSUR _ P DECOMP MU PACK-OFF RUNNING TOOL. BOLDS. ENGAGE ~ PACK-OFF AND PULL PACK-OFF FREE WITH 35K LBS. INSTALL NEW PACK-OFF AND TEST TO 5000 PSI FOR 15 MINUTES. HERB WILLIAMS, ADW HSE ADVISOR AND CARRIE JANOWSKI, WELL SITE LEADER ON SITE AS PART OF THE BPBOP AUDIT TEAM. 10:30 - 11:30 1.00 _ BOPSUR P DECOMP PJSM AND RAISE THE BEAVER SLIDE. PULL THE FLOW RISER AND INSTALL THE SAVER SLEEVE. 11:30 - 12:00 0.50 BOPSUR _ P _ DECOMP PJSM FOR ND THE DUTCH FLANGE AND THE i BOP STACK. ASSIST BP BOP AUDIT TEAM WITH LOCATING AND AUDITING BOP EQUIPMENT AND PRACTICES. 12:00 - 13:00 1.00 BOPSUR P DECOMP NIPPLE DOWN THE DUTCH FLANGE. 13:00 - 21:00 8.00 BOPSUR P DECOMP ND AND STAND BACK THE BOP STACK IN THE ~ CELLAR. __ 21:00 - 22:00 1.00 BOPSUR P DECOMP - f~,.TUBING SPOOL. - - 22:00 - 00:00 ----- 2.00 BOPSUR P DECOMP NU NEW TUBING SPOOL AND TEST MANDREL PACKOFF TO 5000 PSI FOR 30 MIN. NU DOUBLE STUDDED ADAPTER. _ __ 5/30/2010 00:00 - 03:00 3.00 _ BOPSUR P _ DECOMP INSTALL TEST PLUG IN TUBING HANGER. NU ! BOP'S. ____ 03:00 - 04:30 1.50 BOPSUR P _ DECOMP BODY TEST BOP WITH 3-1/2" TEST JOINT. 250 PSI LOW AND 3500 PSI HIGH. __ 04:30 - 07:00 2.50 BOPSUR P DECOMP RD TEST JOINT. PULL TEST PLUG. INSTALL WEAR RING. _ 07:00 - 08:30 1.50 BOPSUR P DECOMP MU RETRIEVING TOOL AND RIH. WASH TOP OF PACKER 5 BPM @ 140 PSI. ENGAGE RTTS WITH 21 TURNS TO RIGHT. EQUALIZE AND RELEASE __ PACKER. MONITOR WELL _ _ 08:30 - 10:30 2.00 BOPSUR P DECOMP SLIP AND CUT 87 ' OF DRILL LINE. 10:30 - 11:30 1.00 BOPSUR P DECOMP pOH WITH RTTS FROM 93'. LD RTTS TEST PACKER. RIH AND ENGAGE7" RBP WITH 3 RH TURNS. PULL 10K OVER TO RELEASE PACKER. EQUALIZE AND RELEASE PACKER. FILL HOLE WITH 9 BBLS. 11:30 - 14:00 _ 2.50 BOPSUR P DECOMP CIRCULATE WELL 26PM @ 340 PSI / 5 BPM @ 2100 PSI. CIRCULATE A TOTAL OF 470 BBLS. LOST 67 BBL TO WELL. FLOW CHECK WELL. 14:00 - 15:45 1.75 BOPSUR P DECOMP POH.LD DP. Printed 6111/2010 3:37:30PM North America -ALASKA - BP Page 9 of 12 Operation Summary Report .. _.._ ........................... . __ _ __ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 ~ End Date: X4-OOQ9F-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:45 - 19:30 3.75 BOPSUR P _ _ DECOMP DIESEL SPILL 3 GAL ON THE RIG NONE TO PAD. INVESTIGATED SPILL. DETERMINED THAT WITH HEATERS AND BOILER NOT OPERATING BECAUSE OF THE WARM TEMPERATURE. THE RETURN LINE WAS UNDERSIZED CAUSING THE DIESEL TO BACK UP THE RETURN LINE TO THE PIPE SHED AIR HEATER AND OVERFLOW THE DAY TANK. TANK WAS ISOLATED AND LOCKED OUT/TAGGED OUT. 19:30 - 00:00 4.50 BOPSUR P DECOMP CONTINUE TO POH WITH THE RBP LAYING DOWN DP: _ _ 5/31/2010 00:00 - 03:30 3.50 BOPSUR P _ ___ DECOMP CONTINUE TO POH LAYING DOWN DP MAINTAINING CONTINUOUS HOLE FILL. _ 03:30 - 04:30 1.00 BOPSUR P DECOMP LD 6 DRILL COLLARS AND RBP. 04:30 - 06:00 1.50 BOPSUR P DECOMP PULL. WEAR RING.. AND CLEAR RIG FLOOR. 06:00 - 06:30 0.50 BOPSUR P 'DECOMP CREW CHANGE -SERVICE RIG. PERFORM ~ ENVIRONMENTAL WALK AROUNDS, CHECK AND j PVTS, AND SERVICE DRAWWORKS. SET 0 360 - 08:00 1.50 BOPSUR P DECOMP _ RD 3-1/2" DP RUNNING AND HANDLING EQUIPMENT. ___ __ __ _____ ___ 08:00 - 09:00 1.00 RUNCOM _ P __ RUNCMP RU TO RUN 4-1/2" TUBING. BRING DOUBLE STACK TONGS TO RIG FLOOR AND RU. RU TORQUE TURN EQUIPMENT. LOAD ESP MOTOR - AND PUMP ASSEMBLIES INTO PIPE SHED 09:00 - 10:30 __ 1.50 RUNCMM P- RUNCMP RU STABBING BOARD. PREP ESP MOTOR AND PUMP ASSEMBLIES IN PIPE SHED. __ 10:30 - 13:00 _ 2.50 RUNCOM _ P _ RUNCMP pJSM. MU CENTRILIFT ESP MOTOR ASSEMBLY i AND SERVICE MOTOR AND SEAL ASSEMBLIES. RU TO RUN ESP, PULL ESP CABLE OVER SHEAVE. ~ SCOTT MCENTYRE AND BRAD YINGST ONSITE TO OBSERVE. 13:00 - 14:30 ____ 1.50 __ RUNCMM _ P _ _ RUNCMP pJSM. MU MLE, ATTACH TO MOTOR AND TEST - GOOD TEST. SECURE ESP CABLE TO MOTOR ASSEBLY. MU 2 JTS OF 4-1/2" HYDRIL 521 ~ TUBING AND HANG OFF IN THE SLIPS. 14:30 - 16:30 ____ 2.00 ~ RUNCOM P ____ RUNCMP CHANGE OUT 4-1/2 ELEVATORS TO 2-7/8". MU PUMP ASSEMBLY 1 & 2. PU BUMPER SUB AND 2 JOINT 2-7/8 PAC. SET PACKOFF AND PUMP OFF ___ _ __ "GS"SETTING TOOL 16:30 - 20:00 ~ 3.50 RUNCMM P RUNCMP CHANGE OUT PACKOFF TEST TOOL. RIH SET ~ TEST TOOL AND TEST PACKOFF TO 1000 PSI ~ ~ FOR 15 MINUTES. 50 PSI LOST IN. PE'S ACCEPTED TEST. RECOVEDER TEST TOOL AND INSTALLED TUBING STOP. 20:00 - 21:00 1.00 RUNCMM P RUNCMP RU TO RUN COMPLETIOM. UNABLE TO USE SINGLE JOINT COMPENSATORS WITH HYDRIL 521. THE SINGLE JOINT ELEVATORS GET STUCK ON THE UP SET ON THE HYDRIL 521. _ 21:00 - 00:00 3.00 RUNCMM P RUNCMP BEGIN RUNNING 4-1/2 HYDRIL 521 COMPLETION. TESTING CABLE EVERY 1000'. Printed 6/11/2010 3:37:30PM North America -ALASKA - BP Page 10 of 12 Operation Summary Report ___ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-OOQ9F-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ ~ (ft) 6/1/2010 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 4-1/2" HYDRIL 521 COMPLETION. ~ -RIH TO JNT 100 OF 280 -TESTING CABLE CONDUCTIVITY EVERY 1000', WHILE PUMPING 5BBLS @ 1 BPM -KEEPING ACCURATE TRIP SHEET -AVG LOSS RATE - 10-12 BPH _ 06:00 - 07:30 1.50 ___ RUNCOM _ P _ _ RUNCMP PTSM: PRE TOUR CHECKS 07:30 - 14:30 7.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 4-1/2" HYDRIL 521 COMPLETION. -RIH TO JNT 177 -TESTING CABLE CONDUCTIVITY EVERY 1000'.WHILE PUMPING 5BBLS @ 16PM _ 14:30 - 17:30 3.00 RUNCOM P _ _ RUNCMP REEL TO REEL-ESP CABLE SLICE -CENTRILIFT REP MAKING & TESTING SPLICE 17:30 - 00:00 6.50 RUNCOM P RUNCMP CONTINUE TO' RIH W/ 4-1/2" HYDRIL 521 ' COMPLETION. -RIH W/ 280 JNTS, USED 280 CANNON CLAMPS - & 1-SPLICE CLAMP -TESTING CABLE CONDUCTIVITY EVERY 1000'.WHILE PUMPING 5BBLS @ 16PM -KEEPING ACCURATE TRIP SHEET -AVG LOSS RATE' 10-12 BPH 6/2/2010 00:00 - 02:00 2.00 RUNCMM P RUNCMP CONTINUE TO RIH W/ 4-1/2" HYDRIL 521 COMPLETION. -RIH W/ 280 JNTS, USED 280 CANNON CLAMPS ~ & 1-SPLICE CLAMP -TESTING CABLE CONDUCTIVITY EVERY 1000'.WHILE PUMPING SBBLS @ 1BPM -KEEPING ACCURATE TRIP SHEET -AVG LOSS RATE - 10-12 BPH 02:00 - 05:30 3.50 RUNCOM -- P --- - RUNCMP MU HANGER AND PENETRATOR.. __ ____ _ __ ~ -FIELD CONNECTOR PIG TAIL SPLICE DONE BY CENTRILIFT. _______ ___ __ _ 05:30 - 06:00 ____ 0.50 _ RUNCMM P RUNCMP LAND 11" X 4-1/2" FMC HANGER -INSTALL BRASS SHIPPING CAP -RILDS -PUW-125K ,SOW-70K -TEST FIELD CONNECTION _____ __ _ _ 06:00 - 06:30 0.50 RUNCOM P RUNCMP SERVICE RIG AND PERFORM PRE-TOUR CHECKS. SERVICE DRAW WORKS AND PERFOM ENVIRONMENTAL WALK AROUNDS. _ 06:30 - 09:00 ~ 2.50 RUNCOM P RUNCMP RD POWER TONGS AND 4-1/2" HANDLING ~ EQUIPMENT. RD ESP RUNNING EQUIPMENT. _ 09:00 - 10:00 1.00 BOPSUR _ P __ WHDTRE INSTALL AND TEST TWC: 1000 PSI FROM ABOVE FOR 10 CHARTED MINUTES -GOOD TEST. 500 PSI FROM BELOW (ROLLING TEST) FOR 10 CHARTED MINUTES -GOOD TEST. PUMPED -41 BBLS AWAY WHILE PERFORMING THE ROLLING TEST FROM BELOW. _ _ __ 10:00 10:30 0.50 BOPSUR P WHDTRE DRAINED THE STACK AND PREPARED THE CELLAR TO RD THE BOPS. Printed 6/11/2010 3:37:30PM r~ North America -ALASKA - BP Page 11 of 12 Operation Summary Report __ _ _ _ Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ____ (hr) (ft) 10:30 - 11:30 1.00 BOPSUR P WHDTRE _ HELD THE WEEKLY SAFETY MEETING WITH DEL BRANDNBURG'S CREW, TOOLPUSHER, AND WSL. DISCUSSED RECENT INCIDENTS FROM ____ _ _ AROUND THE FIELD AND DROPPED OBJECTS. 11:30 - 13:30 2.00 BOPSUR P __ _ WHDTRE ND THE RISER AND THE DUTCH FLANGE. REMOVE THE 2-7/8" X 5" VBR FROM THE TOP SET OF OPERATORS. BUTTON UP THE RAM .OPERATORS AND ND TO REMOVE FROM STACK. _ 13:30 - 14:00 ___ 0.50 BOPSUR P WH©TRE H2S AND RIG EVACUATION DRILL. WELL WAS SECURED 9N 38 SECONDS AND ALL PERSONNEL EVACUATED THE RIG AND ASSEMBLED AT THE SAFE AREA IN 3 MIN AND 20 SECONDS FROM i , WHEN THE DRILL WAS. CALLED. A HEAD COUNT ~ WAS TAKEN AND THE WSL NOTIFIED RWO SUPERINTENDANT THAT A H2S DRILL HAD JUST BEEN HELD. THE MPE PAD OPERATOR WAS ALSO NOTIFIED ALONG WITH THE MPU WELL OPS COORDINATOR. A BRIEF AAR WAS HELD AFTER THE DRILL. SOME OF THE ITEMS THAT CAME OUT OF THE I ~ ' AAR INCLUDED: A RIG HAND FORGOT TO NOTIFY A THIRD PARTY HAND OF THE DRILL, - ' THE LOADER OPERATOR CAME BACK AND FOUND THE OTHER HAND AND MADE SURE HE MADE IT SAFELY TO THE SAFE AREA. TWO HANDS FAILED TO CHECK THE WIND DIRECTION WHEN EXITING THE RIG AND WALKED DOWNWIND OF THE RIG ON THEIR WAY TO THE SAFE AREA. THE DRILLER CALLED OUT THE DRILL ON THE RIG RADIO AND THE RIG PA SYSTEM BUT NOT OVER THE 4ES HARMONY HUB. THE FORKLIFT OPERATOR DID A GOOD JOB OF SECURING THE LOCATION AND MAKING SURE THAT ALL THIRD PARTY PERSONNEL WERE ACCOUNTED FOR. __ 14:00 - 21:00 ___ __ 7.00 BOPSUR _ P ~ _____ ___ WHDTRE CONTINUE TO ND THE 13-5/8" BOP STACK I -HAD TO RAISE THE SUB BASE UP TO ND THE TOP SET OF RAM OPERATORS AND THEN NU THE ANNULAR PREVENTOR TO THE STACK TO RE-CONFIGURE THE STACK BACK TO A 3 PREVENTER STACK. -NU DUTCH SYSTEM LOCK DOWN FLANGE 21:00 - 23:00 2.00 WHSUR P WHDTRE NU 4-1/16" 5M CAMERON TREE -NU SK 11" X 4-1/16" FMC DUAL ROTATING ADAPTER FLANGE : __ 23:00 - 00:00 1.00 WHSUR P WHDTRE PRESSURE TEST WELL HEAD HANGER VOID TO i 5000 PSI FOR 30 MIN. TEST PERFORMED BY (FMC) . -TEST WITNESSED BY WSL , TESTE GOOD -AAR WAS HELD WITH THE NIGHT CREW DURING THE WELL HEAD TEST Printed 6/11/2010 3:37:30PM r~ . -. North Ame?rica -ALASKA - BP Page ~ 2 or 12 Operation Summary R eport Common Well Name: MPE-11 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 5/20/2010 End Date: I X4-0009E-E (2,250,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 1/19/1995 12:0O:OOAM Rig Release: 6/3/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 20:11 6/18/1999 15:00 @42.5ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/3/2010 00:00 - 01:00 1.00 WHSUR WHDTRE TEST TREE TO 5000 PSI FOR 5 MINUTES -GOOD TEST. -CENTRILIFT DOING FINAL CHECKS 01:00 - 02:30 1.50 ~ WHSUR WHDTRE pU MPU WELL SUPPORT LUBRICATOR AND MAKE UP TO TREE. -FILL WITH DIESEL AND TEST TO 500 PSI FOR 5 MINUTES -GOOD TEST. -PULL TWC AND INSTALL BPV. ~ -TEST BPV TO 500 PSI FOR 5 MINUTES -GOOD 02:30 - 03:00 0.50 WHSUR _ WHDTRE CLEAN AND CLEAR RIG FLOOR -SECURE TREE AND CELLAR. *** RIG RELEASE AT 03:00 `'*` Printed 6/11/2010 3:37:30PM Tree: 4-1/16"" - SM FMC Wellhead: 13-3/8"x 11" SK w/ 11"x 4.5" Tubing Hanger Hydril 521 Top & Btm, 3" CIW H BPV profile 20" 91.1 ppf, H-40 80' KOP @ 1000' Max. hole angle = 63 deg. f/ 3,300' to 11,300' Hole angle thru' perfs = 58 deg 9 5/8", 40#/ft, L-80 BTC. 3455' Halliburton ES cementer 6976' 7" 26 ppf, L-80, NSCC production casing ( dint ID = 6.151 ", cap. = 0.0383 bpf ) 4 1/2" 12.6 ppf, L-80, 521 Hydril Tubi Drift ID = 3.833", cap = 0.0152 Tandem Seal Sections 11,595' Model GSB3 DB UT/LT HL H6 PFS Mv-ker RA Tag 11877' 7" Landing collar 11881' 7" Seal float collar 11924' 7" Seal float shoe Motor, 55 HP, 1259 volt, 11,621 ` 26 amp, Model KMHA Siz SP Interval (TVD) 3-3/8 6 12]76'-12234' 7011'-7042' T.n per perfs isolate . 3-3/8 6 12256'-12310' 7053'-7082' PumpMate w/ 4 fin Centralizer 11 625' Perforation Summary Ref lob: 06/18/96 GR/CCL MPU E-11 6/21i9J M. Lfnilei~ ICN'[14~N.J 1013 U00 GIv411 RWO Nabors 4 ES 07,%04%06 MOR RWO Nabors 4 ES 03/28/07 REH RWO Nabors 3S 06/03/10 REH RWO Nabors 4ES/ TTESP Orig. KB~I'ev. = 53.83' (N 22E) Orig. GL Elev. = 24.40' RT Tbg. Spool = 29.43' (N 22E) D&D Tbg Stop 11,540' D&D Packoff Assy Top 11,542' Centrilift TTC-ESP Top 11,550` Components: Hanger receptacle w/4" "G" Fish Neck, D-head, tandem ESP, Intake and Pump eye. (Total Length= 36.72') TTC Drilled Tbg Crossover 11,577' 5" setting sleeve C-2 11808' (5.25"1D) Liner top pkr. HPLPO 11816' Liner hng. HMC 11821 ' 12239` RKB (3S-3/16/07) WeatheiTord cast iron bridge n ' Set lU/30/00 by 4-es. 12245 7304' TVD Baker landing collar 12697' Baker t7oat eallax 12785' Baker float shoe 12830' MILNE POINT UNIT WELL E-11 API NO: 50-029-22541 BP EXPLORATION (AK) • • Regg, James B (DOA) From: Jones, Jeffery B (DOA) ~~~~ ~~ Sent: Tuesday, May 25, 2010 11:31 PM To: Regg, James B (DOA) Subject: FW: MPE-11: Procedure to circulate out packer gas out of the IA FYI -----Original Message----- From: AK, D&C Rig 4E5 Well Site Leader [mailto:AKDCRig4ESWe1lSiteLeaderc~bp.com] Sent: Tuesday, May 25, 2010 9:49 AM To: Jones, Jeffery B (DOA) Subject: FW: MPE-11: Procedure to circulate out packer gas out of the IA Jeff, This is my orders. David Rhodes fix:.:. ~ , t ; ~t C} i !`f -----Original Message----- From: Nadem, Mehrdad Sent: Tuesday, May 25, 2010 12:13 AM To: Rossberg, R Steven; Crane, Lowell R; Miller, Kenneth C; Miller, Kenneth C Cc: AK, D&C Rig 4ES Well Site Leader; Reem, David C Subject: MPE-11: Procedure to circulate out packer gas out of the IA 1- Circulate 10.4 ppg brine through tubing taking returns out through a the choke line until the well is entirley circulated to 10.4 ppg brine in both tubing and IA. 2- Shut in and observe the well. Confirm the well is dead on both __ tubing and IA for 30 minutes. 3- Contact RWO Superintendent, and ensure an approval form Lowell Crane and Steve Rossberg has been received before 4ES proceeds with the .- remainder of this Workover project. 4-Perfrom frequent flow check while POOH with packer. Mehrdad Nadem 696-6649 1 MPE-1l.doc • • Page 1 of 1 Regg, James B (DOA) From.: Jones, Jeffery B (DOA) ~ -~ ,~ ~~'l5-~i( Sent: Tuesday, May 25, 2010 11:17 PM ~~, ~, ~~, ~ To: Regg, James B (DOA) ~~ Subject: FW: MPE-11.doc Attachments: Copy of Copy of SPELL.doc FYI From: AK, D&C Rig 4ES Well Site Leader [mailto:AKDCRig4ESWeIISiteLeader@bp.com] Sent: Tuesday, May 25, 2010 9:32 AM To: Jones, Jeffery B (DOA) Subject: MPE-il.doc «Copy of Copy of SPELL.doc» Jeff, I apologize for being late. We will retest BOPE used, this trip out of hole. Thanks again for the fast call back 5/26/2010 • C~ le 5 -t%L i 5/25/2010 Well (MPE-11) Jeff Jones, While reverse circulate down to retrieve 7" Packer the Drill String became stuck and Packed-off. When the Drill String was pulled free. We believed the new String weight included the 7" Packer and Tailpipe assembly. After letting the elements relax. Then the Drill String was worked to aid in the process. Swabbing was noticed when working the Pipe. The Well was shut in with a Pit gain of ~42 bbls and 350 psi on the Annulus and `0' on the Drill Pipe. Notifications were made. Will circulate KWF surface to surface till Well is dead with 10.4# ppg Brine. Then we will report to ADW RWO Superintendent prior to continuing operation on this Work Over Well. David Rhodes WSL 4-ES 659-4608 :r STATE OF ALASKA • JAN 1 6 ZQ~~ . ALA~A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIC~I'~ ~'~ & Gas Cons. Comtnissior~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~ Ot er cid treatment Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory ®, 195-0010 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22541-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 54 KB ~ MPE-11 8. Property Designation: 10. Field/Pool(s): ADLO-028231 ~ MILNE POINT Field/ KUPARUK RIVER OIL Pool - 11. Present Well Condition Summary: Total Depth measured 12830 feet Plugs (measured) 12245' 11/4/01 true vertical 7355.31 feet (measured) None Jun k ~ 4 ~i ~ `~ 2~~g `')"~~r~~~~ ' ~~ ~v Effective Depth measured 12245 feet - true vertical 7048 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91# H-40 Surface - 112' Surface - 112' 1490 470 Surface 3424' 9-5/8" 40# L-80 Surface - 3455' Surface - 2943' 5750 3090 Production 11938' 7" 26# L-80 Surface - 11697' Surface - 6905' 7240 5410 Liner 1022' 5" 15# 13CR80 11808' - 12830' 6826' - 7355' 8290 7250 Perforation depth: Measured depth: 12176 - 12234 Isolated 12256 - 1231C= _ True Vertical depth: 7011.75 - 7042.21 7053.77 - 7082.15 = _ _ Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 11651' 0 0 - Packers and SSSV (type and measured depth) 7" VERSA TRIEVE PACKER 11691' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 43 3 366 184 Subsequent to operation: 44 ~ 3 365 191 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~~ Development ~ " Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas I-~ WAG GINJ i~'` WINJ IW WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature one 564-4944 Date 1/16/2008 f?h ~ , _ . _ ,: w Form 10-404 Revis d 04/2006 ~i Submit Original Only MPE-11 • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUM 1/3/2008;T/I/0=350/360/300. (Acid treatment). Pump 10 bbls crude down tbg for infectivity ,~ test. Pump 11 bbls 12% DAD acid down tbg. Spot acid at ESP w/ 3 bbls neat 'meth & 56 bbls crude. Let acid set on ESP for 20 minutes. 1/3/2008T/I/0=250/300/300. (Freeze protect). Freeze protect tbg w/ 15 bbls diesel. Freeze protect FL w/ 2 bbls neat meth. Freeze protect test line w/ 2 bbls neat ;`:meth. FWHP=0/280/300. 1/6/2008'ASRC Unit #2, flow and test MPE-11, *job complete* ,~ FLUIDS PUMPED BBLS 66 CRUDE 3 NEAT METH 11 12% DAD ACID 80 TOTAL ~ KI::l"t:IVt:.LJ e STATE OF ALASKA l"t~·ð~ . ALASKA OIL AND GAS CONSERVATION COMM ION MAR 3 0 2007 REPORT OF SUNDRY WELL OPERA TIONSA1aska Oil & Gas Cons. Commission . 1. Operations Performed: o Abandon ~ Repair Well , o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing ( o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 195-001 , 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22541-00-00 - 7. KB Elevation (ft): 54.0 I 9. Well Name and Number: MPE-11 .¡ 8. Property Designation: 10. Field 1 Pool(s): ADL 028231 / Milne Point Unit 1 Kuparuk River Sands ' 11. Present well condition summary Total depth: measured 12830 / feet true vertical 7355 ( feet Plugs (measured) 12245' Effective depth: measured 12245 feet Junk (measured) NIA true vertical 7048 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3424' 9-5/8" 3455' 2943' 5750 3090 Intermediate Production 11938' 7" 11967' 6905' 7240 5410 Liner 1022' 5" 11808' - 12830' 6826' - 7355' 8290 7250 Perforation Depth MD (ft): 12176' - 12310' Perforation Depth TVD (ft): 7012' - 7082' 2-7/8",6.5# and L-80 11651' Tubing Size (size, grade, and measured depth): Sr.rp.p.n Ä!,:!,:p.mhlv ?-7/R" 11RQ()' _ 11RQR' Packers and SSSV (type and measured depth): 7" Versa Trieve packer 11690' 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED APR 1 1 2007 Treatment description including volumes used and final pressure: 13. Representative Daily Avera¡:¡e Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin¡:¡ Pressure Tubin¡:¡ Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Bryan McLellan, 564-5516 Printed Name ·Sondra Stewman Title Technical Assistant - í -=:- ) 7~ Prepared By Name/Number: ~ ~¡;2C:/~ Datl~ë11{) Sandra Stewman, 564-4750 nature ./'0. '7..AA::'O V' 1 ~'). ~ Phone 564-4750 Form 10-404 Revised 04/2006 ~" -,..^ ~ Submit Original Only p 1: i1 ORIGIN,~L .:mDMS BFl AP.\ , lÞ ZOOI /ir,-,,(u 4;;;. Ý.97>.? ';;II!!.- ~/~? Tree: 3-I/S" - 5M FMC Wellhead: 13-3/S"x 3-I/S" 5M FMC wI 3.5" ESP Tubing Hanger, wI 3.5" NSCT Top & Btm. , 3" CIW H BPV profile 20" 91.1 ppf, H-40 80' KOP @ 1000' Max. hole angle = 63 deg. fl 3,300' to 11,300' Hole angle thru' perfs = 5S deg 9 5/S", 40#/ft, L-SO BTC. 3455' Halliburton ES cementer 6976' 27/8" 6.5 ppf, L-SO, S rd EUE tbg.. (drift II) = 2.347", cap. = 0.00592 bpf) 7" 26 ppf. L-80, NSCC production casing (dlift ill = 6151", cap. = 0.0383 bpf) Marker RA Tag I 11877' T' Landing collar I 11881' 7" Seal í10at collar I 11924' 7" Seal t10at shoe I 11%7' Perforation Summary Ref 102: 06/18/96 GRlCCL Siz SP Intelval (TVD) 3-3/8 6 12176'-12234' 7011 '-7042' Lo 'er perfs isolate 3-3/8 6 12256'-12310' 7053'-7082' Mid-peIf= 7047'tvd 12243'Ml) DATE 12/1 97 6/2 ]/99 10/31100 07/04/06 03/28/07 MPU E-ll -- D Iii ti ',., REY.B MDO M. Linder GMH MOR REH COMMENTS ESP Com letion 4-ES RWO 4-ES RWO Nabors 4 ES RWO Nabors 4 ES RWO Nabors 3S On. Elev. = 53.S3' (N 22E) Orig. GL Elev. = 24.40' RT Tbg. Spool = 29.43' (N 22E) Cameo 2 7/S" xl" sidepocket KBMM GLM ) Cameo 2- 7/8" xl" side pocket KBMM GLM 2-7/8" xn nipple 2.205" II) PUMP - PM SXD 1-7 Tandem Gas Separator GRSFTX AR H6 Tandem Seal Section GSB3DBUT AB/HSN PFSA Motor, 225 HP, 2305 volt, 60 amp, Model KMH Phoenix XT-I w/5 íÏn Centralizer Halliburton 7" VersaTrieve Packer J w/dual2 7/8" Halliburton 250 micro PoroMax Screens fit' .,. 5" setting sleeve C-2 . ( 5.25" II) ) Liner top ph. HPLPO Liner hng. HMC 11808' 11816' 11821 ' 200' 11435' 11666' 11';90' 11609' 11614' 11628' 11647' 11691' I 12239' RKB (3S-3/16/07) Weatherford cast iron bridge l' I I Set 10/30/00 by 4-es 12245' Baker landing collar Baker t10at CÙ)\al Baker float shoe 7304' TVD 12697' I 12785' I 12S30' 1- MILNE POINT UNIT WELL E-ll API NO: 5O-029~22541 BP EXPLORATION (AK) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 2/2612007 00:00 - 07:00 7.00 MOB P PRE Scope down and UD derrick. Break electrical and steam connections. Haul BOP Cradle and Stack to E-Pad. Move Pipe Shed and Pits away from Carrier. Prep rig and auxilliary equipment for move to MPE pad. Wait for DSO crew change prior to moving rig off of pad. 07:00 - 10:00 3.00 MOB P PRE Move rig from MPF pad to MPE pad. 10:00 - 18:00 8.00 RIGU P PRE On MPE pad. Spot and rig up Nabors 3S and support equipment. -20 deg F ambient temperature wI 35 mph winds, drifting snow. Necessary to shovel out behind well for BOPE, repeatedly. 18:00 - 00:00 6.00 RIGU N PRE Wait on Weather. Winds blowing in excess of 35 mph. 2/27/2007 00:00 - 15:00 15.00 RIGU N PRE Wait on Weather. Winds blowing in excess of 35 mph. 15:00 - 00:00 9.00 RIGU P PRE Accept rig @ 09:00. Laid Herculite for final rig placement. Wait on winds to subside. 2/28/2007 00:00 - 03:30 3.50 RIGU P PRE Spotted and leveled rig over MPE-11 . 03:30 - 10:30 7.00 RIGU P PRE Spotted and RU fluid pits and pipe shed. Complete hooking up steam and flow lines. Pre-warm hydraulics prior to raising Derrick. 10:30 - 15:00 4.50 RIGU P PRE PJSM. Raise and scope Derrick. Continue installing steam heater in cellar, rigging up tiger tank, flowlines, and manifolding for killing the well. 15:00 - 19:00 4.00 RIGU P PRE Rig up double valve on annulus. Rig up circulation lines on the tree. Blow air and steam through all lines. Scarf and sand pad. Load pits with 8.5 #/gal SW. 19:00 - 20:00 1.00 WHSUR P DECOMP PU lubricator. Pull BPV. T/IAlOA pressures of 700/680/250 psi. 20:00 - 00:00 4.00 KILL P DECOMP Held PJSM. Pressure test lines to 2500 psi. Pump 70 Bbls down tubing, returns from annulus through choke to tiger tank. Tbg pressure 1200 psi, annulus pressure 680 psi @ 2-1/2 BPM. 3/1/2007 00:00 - 01 :00 1.00 KILL P DECOMP Attempted to bullhead seawater into formation. Tbg pressure rose to 2250 psi, csg pressure to 2500 psi @ 1 BPM. Could not bullhead. 01 :00 - 05:00 4.00 KILL P DECOMP Reverse circ 530 bbls of 120 deg F seawater @ 3 1/2 BPM, 1500 psi. No losses to formation. Oil in returns at end. ISIP 300 psi Tbg and IA. OA to 550 psi. 05:00 - 06:00 1.00 KILL P DECOMP Monitor well pressure build up. Wellhead pressure to 340 psi Tbg & IA. Order 580 Bbls of 9.8 #/gal brine. 06:00 - 09:30 3.50 KILL P DECOMP Prep for pulling completion. Wait on 9.8 # brine from MI plant in Deadhorse. 09:30 - 13:00 3.50 KILL P DECOMP 9.8 #/gal brine on location. Load pits. Confirm lines are not frozen. PJSM. Circulate 480 Bbls of 9.8 #/gal brine for kill. Displace SW pumping brine @ 3 1/2 BPM, 900 psi. 13:00 - 14:00 1.00 KILL P DECOMP o psi on tbg and annulus. Monitor well for 30 minutes. Blow down all lines etc. 14:00 - 16:30 2.50 WHSUR P DECOMP T/IAlOA @ 0/0/230 psi. Dry Rod TWC. Attempt to test from below, inject 2 BPM @ 300 psi. Test from above to 3500 psi and chart for 10 minutes. 16:30 - 18:30 2.00 WHSUR P DECOMP Bleed hanger void and ND tree. Screw XO for landing joint into hanger threads wI 7-1/2 turns. 18:30 - 00:00 5.50 BOPSU P DECOMP NU BOPE. 3/2/2007 00:00 - 03:00 3.00 BOPSU P DECOMP Cant NU BOPE. 03:00 - 04:00 1.00 BOPSU P DECOMP Held PJSM on testing BOPE. Function tested blind rams, pipe Prinled: 3/26/2007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 rams, annular BOPE. AOGCC test witness waived by Jeff Jones. 04:00 - 10:00 DECOMP Tested BOPE to 250 psi low 13500 psi high. Tested annular BOPE to 3500 psi. Charted all tests. Had to change out the TIW valve. 10:00 - 12:30 2.50 PULL P DECOMP Drain stack. Blow down choke and lines. PU/RU elephant trunk and shieve 12:30 - 16:30 4.00 PULL DECOMP PUlMU Opso-Lopso wi 31/2" NSCT XO for tubing hanger. Torque up XO. Screw into hanger, MU pump in sub on O-L. PUlMU lubricator. Unable to pull TWC thru XO on OL. Back out of XO and left in hanger. Screw back in, torque up, POOH and re-torque XO. MU OL , Lub and Pull TWC. Wellhead pressuress of 0/0/230 - Tbg/IAlOA. 16:30 - 18:30 2.00 PULL P DECOMP PUMU 3 1/2" IF landing joint wI XO. Unable to screw into hanger because XO hitting penetrator. Lay down 31/2" IF landing jt, PUMU joint of 3 1/2" NSCT tubing. Screw into hanger. Pull hanger to surface wI 60K #'s. Lay down hanger, FMC to re-dress. Load hole wI 7 bbls of 9.8 #/gal brine. 18:30 - 22:30 4.00 PULL P DECOMP POH with 2-7/8" ESP completion. Double displaced while POH. Well taking -7 bblslhour 9.8 ppg brine. Held D1 drill. 22:30 - 00:00 1.50 PULL N DECOMP Waited for delivery of 9.8 ppg brine. 3/3/2007 00:00 - 01 :00 1.00 PULL N DECOMP Cant waiting for delivery of 9.8 ppg brine. 01 :00 - 07:30 6.50 PULL P DECOMP Resume POH with 2-7/8" ESP ass'y. Double displaced tubular volume while POH. Well continuing to take -7 bbls/hr 9.8 ppg brine. 45 stnds OOH @ 0400 hrs. 07:30 - 16:00 8.50 PULL P DECOMP Change ESP cable spool in spooling unit. Losses consistent @ -7 Bbls/Hr. Continue POOH standing back 2 7/8" tubing wI continuous hole fill of 9.8 ppg brine. 110 stands OOH @ 11 :00, 173 stds OOH @ 15:00. 16:00 - 19:30 3.50 PULL P DECOMP Break out and lay down ESP. Recovered 3 flatguards, 194 Lasalle clamps, 5 protectolators. Losses @ -7 Bbls/Hr. 19:30 - 23:00 3.50 CLEAN P CLEAN Clean and clear rig floor. Installed wear ring. PUMU 2 7/8" Muleshoe wI 3.875" straight vanes. Fluid loss -7 bph. 23:00 - 00:00 1.00 CLEAN P CLEAN RIH with 3.875" muleshoe on 2-7/8" tubing. 20 stnds in hole @ 00:00 hrs. 3/4/2007 00:00 - 06:00 6.00 CLEAN P CLEAN Cant RIH with 3.875" muleshoe on 2-7/8" tubing. 90 stnds in hole @ 03:00 hrs. Losses @ -7 Bbls/Hr. Rig crew did Spill Drill. 06:00 - 08:30 2.50 CLEAN P CLEAN Crew change and continue RIH wI 2 18" Tubing. PU singles from pipe shed. Tag @ 12169' MD. 08:30 - 13:00 4.50 CLEAN P CLEAN Circulate @ 3 1/2 BPM, 1050 psi and jet down to 12175'. Reverse circulate @ 3 BPM, 400 psi. losses @ +1- 30 %. POOH and hang up @ 12175' MD. Switch to circulating down tubing, returns up annulus @ 3 BPM, 900 psi. Make connection and jet down to 12206'. Pump 30 Bbl Flo-Vis sweep and displace wI 300 Bbls. lose 8 Bbls. 13:00 - 16:00 3.00 CLEAN P CLEAN Jet down to 12217' MD and tag CIBP. (28 ft correcton to e-line depth of 12245') PU and circulate 30 Bbls Flo-Vis sweep surface to surface. Minimal losses. Very little sand in retums, not enough to catch a sample. Pumped 1150 Bbls and lost 102 Bls of which 20 bbls were lost during reverse circulation. 16:00 - 00:00 8.00 CLEAN P CLEAN POOH from 12217' MD. Hang up and pull40K overpull to pull free. Tag up every 30 ft for first 3 joints, then occasional Printed: 3/2612007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 3/412007 16:00 - 00:00 8.00 CLEAN P CLEAN bobble until see definite bounce as come through the FB packer @ 11802' MD. Fluid level dropping in well as POOH and losses @ -7 BblslHr. 52 stnds out @ 2000 hrs, 128 stnds out @ 0000 hrs. 3/5/2007 00:00 - 03:00 3.00 CLEAN P CLEAN Cont POOH with muleshoe ass'y. Fluid level dropping as POOH and losses stable @ -7 Bbls/Hr. Minor tool marks visible on muleshoe coupling and next tubing collar up. 03:00 - 06:00 3.00 CLEAN P CLEAN PUMU muleshoe, 2 jts of 2-7/8" PAC tbg below no-go, and 7", 26 #/ft csg scraper. 06:00 - 11 :30 5.50 CLEAN P CLEAN Crew change. RIH wI scraper BHA on 2 7/8" tubing from Derrick. 11 :30 - 14:30 3.00 CLEAN P CLEAN Tag FB packer wI no-go I 7" Csg scraper @ 11737' MD. Fluted muleshoe inside 5" liner -10'. Circulate sweep surface to surface @ 3.5 BPM, 1000 psi. Circulate 475 Bbls w/16 Bbls losses. Flow check well. Fluid level dropping slightly. 14:30 - 22:00 7.50 CLEAN P CLEAN POOH wI scraper and muleshoe. Pumping across the top as POOH. 80 stds OOH @ 17:00 hours! 120 stnds OOH @ 19:00 hrs. 22:00 - 23:00 1.00 CLEAN P CLEAN BOLD muleshoe I scraper ass'y. 23:00 - 00:00 1 .00 CLEAN P CLEAN Cleared rig floor. LD tubing handling equipment. 3/6/2007 00:00 - 05:00 5.00 FISH P DECOMP PU kelly, swivel, rotary accessories, DP handling tools. RU for rotary operations and to run 3-1/2" DP. 05:00 - 09:00 4.00 FISH P DECOMP PU packer milling assembly (BHA #3). PUMU 6 ea 4 3/4" DC's 09:00 - 21 :30 12.50 FISH P DECOMP PUMU 3 1/2" DP by singles from pipe shed and RIH wI milling BHA. Continuous hole fill as RIH. 150-jts RIH @ 1730-hrs. All joints from outside the Pipe Shed are filled with blown-in snow and have to be rabbitted in the mouse-hole to remove the packed snow. Held PJSM on DP handling. 205 jts in hole @ 2130 hrs. 21 :30 - 00:00 2.50 FISH P DECOMP Held PJSM on VBR testing. Torque kelly. PUMU test plug and XOs. Load additional 3-1/2" DP into pipe shed. 3/7/2007 00:00 - 08:00 8.00 FISH P DECOMP Continue loading 3-1/2" DP into pipe shed. Test kelly to 250-psi low and 3500-psi high, charting tests. Pulled wear ring. Set test plug in tubing hanger. PU and RIH with 3-1/2" test joint. Test VBR to 250-psi low and 3500-psi high, charting all tests. Test witness waived by R. Noble, AOGCC. 08:00 - 10:30 2.50 FISH P DECOMP POH with test joint. P/U landing joint and RIH and M/U into Test Plug and POH. Break off Landing Joint and Test Plug. Call for additional Wear Ring running tool to reinstall Wear Ring. Wrong W/R Running tool was sent out, so M/U Wear Ring to original running tool and RIH to set. 10:30 - 13:30 3.00 FISH P DECOMP Resume RIH with DP from Pipe Shed, joint #270 at 1245-hours. Stop RIH with 300-jts in the hole to prepare to reverse circulate the Drill Pipe clean. 13:30 - 15:30 2.00 FISH P DECOMP Reverse circulate 90-Bbls at 3-BPM and 220-psi. Lose 23-Bbls to the formation. SI and observe a very slow movement of fluid from the well bore into the flow-line, which stopped within 1/2-hour, then fluid level in well bore slowly dropped. 15:30 - 20:30 5.00 FISH P DECOMP Resume RIH with DP from Pipe Shed. 20:30 - 22:30 2.00 FISH P DECOMP Held PJSM on rotary operations. RU, reverse circulated 100 bbls 9.8 ppg brine @ 2 bpm. Minimal pipe scale in returns. Well stable. Losses 60 bph while reversing. Attempted to rotate string; unable to rotate. Printed: 3/2612007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 3m2007 22:30 - 00:00 1.50 FISH P DECOMP Circ well bore volume the long way @ 4 bpm while adding one drum Safe Lube lubricant to 9.8 ppg brine. 3/8/2007 00:00 - 00:30 0.50 FISH P DECOMP Cont circ the long way while adding one drum Safe Lube lubricant to 9.8 ppg brine. 00:30 - 01 :30 1.00 FISH P DECOMP PUMU two joints 3-1/2" DP. RIH carefully and tagged FB-1 packer @ 11,766'. 01 :30 - 11 :00 9.50 FISH P DECOMP Milling on FB-1 packer. Torque 8000 - 10000 Ib-ft, near DP tool joint limit. Added 2nd drum Safe Lube lubricant to 9.8 ppg brine. PU 121 k Ib, SO 80k Ib, Rot 90k Ib, torque 8000 Ib-ft to 10000 Ib-ft, 60 rpm, 3 bpm, 750 psi. Pump periodic 15-bbl High-Vis sweeps. Make 1-1/2' of headway by 0600-hours. Continue to work pipe and rotate, alternating between drilling "dry" and circulating at 3-BPM, 700-psi, WOB-13K, Rot Wt 90K, 8 to 10K Ib-ft torque. 11 :00 - 13:30 2.50 FISH P DECOMP Confer with Engineer, Baker fisherman, MI engineer, Tool Pusher. Decide to continue with current milling operations. The packer broke free at 1250-hours. continue on for full Kelly, then POH to check for drag and packer is still on PRT. Push packer to top of liner at 11 ,802' and POH to check for drag, packer still on PRT. 13:30 - 16:00 2.50 CLEAN P DECOMP Pump Hi-Vis sweep surface to surface and get about a gallon of scale across shakers. 16:00 - 18:00 2.00 FISH P DECOMP Stand back Kelly and prepare to POH. Monitor well and have very slight flow into flowline. Monitor well. Cal Engineer and decide to displace well to 10.0-ppg NaBr brine. 18:00 - 00:00 6.00 FISH P DECOMP Wait on two truckloads of 10.0-ppg NaBr brine. Circulating 9.8 ppg brine @ 1 bpm - 2 bpm, 300 psi - 750 psi. 3/9/2007 00:00 - 06:30 6.50 FISH P DECOMP Held PJSM. Displaced well to 10.0 ppg NaBr brine @ 1 bpm, 300 psi. Fluid losses initially 40% then increasing to 60%. Displaced about 1/2 of well bore volume @ 0600 hrs. Held Fire Drill. Call Engineer to discuss losses and decide, with input from Baker and Toolpusher, to take weight off packer + P/U 2' to improve communication to annulus. 06:30 - 08:00 1.50 FISH P DECOMP Start pumping at 1-BPM and see immediate returns at surface, but pit level shows -100% loss. Increase to 2-BPM and pits show 2-BPM loss. Converse with ADW and decide to go ahead with BOP test and monitor well. Stop pumping to verify fluid balance and find that 580-Bbls were taken on board versus 449-Bbls inventory after the displacement: 290-Bbls to dirty Vac, 79-Bbls in Tiger Tank, and 80-Bbls in the Pits, for a 131-Bbls fluid loss. Check line-up of Pits and Mud Pump and discover that fluid was being transferred from the returns tank to the Tiger Tank at the same time that we were trying to monitor losses to the well. 08:00 - 10:15 2.25 FISH P DECOMP Order out Storm Valve and RTTS Packer for 7",26# to facilitate BOPE test. Continue to circulate 1-BPM to keep from freezing lines. Pump 78-Bbls of 10-ppg and see 10.0-ppg in the returns. Lose 22-Bbls during the 78-Bbl circulation for 17-BPH loss rate. Stop pumping at 0930-hrs and fluid level starts slowly dropping in the annulus, but a slow flow comes out Drill Pipe. 10:15 - 15:00 4.75 FISH P DECOMP Monitor well and blow down circulating lines while awaiting Storm Valve and RTTS Packer. Well has slowly decreasing flow up tubing and down annulus due to imballance, then Printed: 3/26/2007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 3/912007 10:15 - 15:00 4.75 FISH P DECOMP stopped. Check calculations for using a 7" storm packer to test against and learn we need to use a test plug for BOPE tests, but the Storm Packer will be used to hang off 80-90-% of the weight of the 3-1/2" DP. 15:00 - 16:30 1.50 FISH DECOMP POH and UD 20-joints of 3-1/2" DP through Pipe Shed. 16:30 - 17:30 1.00 BOPSU DECOMP P/U Halliburton SSCV and RTTS packer, RIH and set two joints below Tubing Head. Backoff from SSCV and POH. 17:30 - 19:00 1.50 BOPSU DECOMP P/U and M/U Wear Ring Running Tool to landing joint and RIH to pull Wear Ring. Pulled, LD wear ring. 19:00 - 20:00 1.00 BOPSU DECOMP MU and set test plug. Test plug initially leaked, was reset properly. 20:00 - 00:00 4.00 BOPSU DECOMP Tested BOPE - all components to 250 psi low I 3500 psi high. Tested VBR with 2-7/8" and 3-1/2" test joints. Test witness waived by C. Scheve, AOGCC. 3/10/2007 00:00 - 02:00 2.00 BOPSU DECOMP Continued testing BOPE - all components to 250 psi low I 3500 psi high. Tested VBR with 2-7/8" and 3-1/2" test joints. 02:00 - 03:00 1.00 BOPSU DECOMP Held PJSM. Pulled and LD test plug. 03:00 - 04:00 1.00 BOPSU DECOMP MU RTTS retrieving tool. RIH, screwed into RTTS. Pulled RTTS free with 120k Ib PU. Well fluid level falling, 7 bbls to fill well bore. POH, LD RTTS. 04:00 - 19:30 15.50 FISH P DECOMP POH, LD 3-1/2" DP. 20 jts out of hole @ 0530 hrs. PU was initially 10k Ib - 20k Ib over string weight, but no drag since then. 160-joints OOH at 11 OO-hours. 220-joints @ 1330-hrs. 330-jts @ 1730-hrs. 342-jts @ 1930-hrs. 19:30 - 21:30 2.00 FISH P DECOMP Changeout rig tongs in order to break connections in Kelly. P/U Kelly and M/U to Drill Pipe, RIH and break Kelly connections. Break off Kelly and set back in Kelly Shuck. Changeout rig tongs to resume POH and UD Drill Pipe. 21 :30 - 22:00 0.50 FISH P DECOMP Continue TOH with 3-1/2" DP laying down in the Pipe Shed 1 x 1. 22:00 - 23:00 1.00 FISH P DECOMP On surface with BHA #3. Recovered the bottom of the Packer with a cleanly milled upper section. Break down with Baker rep and lay down in the Pipe Shed. Emptied Boot Baskets and recover -1-3/4 gallons of cuttings and debris. 23:00 - 00:00 1.00 FISH P DECOMP RD 3-1/2" Handling Equipment. 3/11/2007 00:00 - 01 :30 1.50 CLEAN P CLEAN RU to run 2-7/8" Tubing workstring from the Derrick. 01 :30 - 04:00 2.50 CLEAN P CLEAN PU and MU BHA #4 as follows: 2 7/8" Mule Shoe, (15) Joints of 27/8" PAC DP, XO. OAL = 467.17'. 04:00 - 14:00 10.00 CLEAN P CLEAN TIH with BHA #4 on 2 7/8" EUE 8rd Tubing from the Derrick, strapping each row. Inside the top of the liner at 1345-hrs. Continue on in to tag at 12,239' without seeing any indication of fill or unusual drag. 14:00 - 23:00 9.00 CLEAN P CLEAN POH and SIB 2-7/8" tubing in Derrick. At 22:00 hrs, there were 167 stands (334 Jts) in the Derrick. At 23:00 hrs, there were 187 stands (374 Jts) of Tubing stood back in the Derrick. 23:00 - 23:30 0.50 CLEAN P CLEAN PJSM on laying down 2 7/8" Tubing in the Pipe Shed. 23:30 - 00:00 0.50 CLEAN P CLEAN Lay down 9 stands (18 Joints) of 2 7/8" Tubing in the Pipe Shed1x1. 3/12/2007 00:00 - 00:30 0.50 CLEAN P CLEAN Continued laying down single Joints of 27/8" Tubing in the Pipe Shed 1 x 1. 00:30 - 02:30 2.00 CLEAN P CLEAN On surface with BHA #4. Break down and lay down (15) Joints of 2 7/8" PAC DP and Muleshoe with Baker rep. 02:30 - 03:30 1.00 RUNCO RUNCMP PU and MU (2) Joints of Halliburton 2 7/8" 250 Micron PoroMax Printed: 3/2612007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 07:00 - 15:00 8.00 RUNCO Sand Screen Assemblies. RIH with Screen Assemblies on (15) Joints of 2 7/8",6.17#, L-80, STL Tubing. MU Torque on STL Connections = 900 ft-Ibs. RUNCMP RIH with 2-7/8",6.5#, L-80, EUE 8rd Tubing from the Derrick. In with 2 Jts of 2-7/8" and the Packer sets prematurely. The Hand Slips are engaged and therefore can't move downhole. Overpull10K with no movement or able to remove Hand Slips. Stop the job and call Halliburton supervisors to discuss options. Hold meeting at 0615-hrs with Toolpushers, Halliburton Slope Office, Halliburton Field Techs, and WSLs. Decide to use tugger to hold onto hand slips, then P/U on string. The packer failed at 50K on weight indicator, allowing the string to suddenly jump -6', opening the elevators. The stand of 2-7/8" tubing, packer, 15-joints of STL, and the two sections of Sand Screen went downhole. Took 10-Bbls of 10.0-ppg brine to bring fluid to the surface. Fluid level was -260' from surface. STUC RUNCMP Wait on orders for proceeding to retrieve packer and sand screen completion. Wait on crossover for 2-7/8" coupling overshot. Had originally planned for 3-1/2" Drill Pipe to recover fish. Change out Hydraulic control valve in motor control system. STUC RUNCMP M/U Overshot with Grapple and M/U to 2-7/8" tubing stand from Derrick. Adjust drawworks clutch. Check Crown-o-matic. Hold lenghty Pre-tour meeting with night crew to discuss the dropped pipe incident that occurred just after the day tour took over. Fluid loss averaged 4-5-BPH. RIH with Overshot Assembly on 2 7/8" Tubing stands from the Derrick. Stop every 5 stands to get a PUW prior to continuing. RIH slowly to observe closely any changes in weight. Continue RIH with Overshot I Grapple Assembly on 2 7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. In with 165 stands (330 Joints) of 2 7/8" Tubing and stack about 20K down, depth = 10,273'. PU 6' Pup Joint and begin to work pipe up and down per Baker rep until able to RIH without stacking weight. PU on workstring and UW = 50K (previous UW at 160 stands was 45K+). Back out and lay down Pup Joint. PU another stand and attempt to RIH to bottom to ensure we have the Fish. Had to work the pipe up and down several times to bury the stand of Tubing. PU another stand and RIH with the same hangups and able to bury it after working it up and down. Call Anchorage Engineer and discuss, decision made to POOH and see what we have. STUC RUNCMP POOH with Overshot Assembly and fish? standing back 2-7/8" Tubing in the Derrick. 20-stands out of hole at 0700-hours. 65-stds at 1000-hrs. 140-stands at 1320-hrs. Fish to surface at 1415-hours and only recovered the Halliburton Packer Running Tool. Call Engineer to set up a conference call after the Halliburton folks have a chance to confer. Break off Halliburton Packer Running Tool. STUC RUNCMP Clear and clean Rig Floor. Wait on conference call. Decide to RIH with Halliburton Packer Retrieving Toolan Drill Pipe. STUC RUNCMP Load and tally 3-1/2" DP in Pipe Shed. 05:30 - 07:00 15:00 - 18:00 3.00 FISH N 18:00 - 00:00 6.00 FISH N STUC RUNCMP 3/13/2007 00:00 - 03:30 3.50 FISH N STUC RUNCMP 03:30 - 05:00 1.50 FISH N STUC RUNCMP 05:00 - 15:00 10.00 FISH N 15:00 - 15:15 0.25 FISH N 15:15 - 20:30 5.25 FISH N Printed: 3/2612007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 3/13/2007 20:30 - 21 :30 1.00 FISH N RREP RUNCMP CIO Hydraulic Valve used for operating Tongs. 21 :30 - 22:00 0.50 FISH N STUC RUNCMP MIU HES 3.88 VRA Retrieving Tool (OAL = 7.27') 22:00 - 00:00 2.00 FISH N STUC RUNCMP RIH wI HES Retrieving Toolan 3-1/2" IF DP while P/U singles from the Pipe Shed. 40 jts in @ OOOO-hrs. Losses @ 4 Bbls/hr. 3/14/2007 00:00 - 10:30 10.50 FISH N STUC RUNCMP RIH wI HES Retrieving Tool on 3-1/2" IF DP while P/U singles from the Pipe Shed. Losses continue @ 4 Bbls/hr. 60 jts in @ 0115-hrs. 80 jts in @ 0200-hrs. 120 in @ 0330-hrs. 145 in @ 0430-hrs. Losses have dropped to 3 Bbls/hr. 210 in @ 0800-hrs. 270 in @ 1030-hrs. 10:30 - 11 :30 1.00 FISH N STUC RUNCMP Install head pin and circulating line and circulate 50-Bbls 10.0-ppg NaCl/NaBr brine to clean up running tool and to get parameters. P/U wt 86K, SIO wt 60K, 2-BPM at 190 to 230-psi, max. 11 :30 - 12:30 1.00 FISH N STUC RUNCMP Break off circulating line and rig up to let well U-tube. 12:30 - 19:00 6.50 FISH N STUC RUNCMP Resume RIH with 3-1/2" DP from Pipe Shed. 300 in at 1430-hrs. At 1400-hrs and 15' in on joint #337 at 10,509', quickly lose 8-10K and set the brake. Pull 20K over the P/U wt and the packer broke free. See additional 5K on the P/U weight. Called Engineer. Continue RIH with 3-1/2" DP, checking P/U and SIO wt every 10-jts. Carrying the extra 5K all the way. See a bobble when the screen bullnose enters the liner top at 11,812', 26' in on joint #361. Continue RIH and sink joint #371, push packer to 11,548' at 1700-hrs. P/U wt 120K, SIO wt 78K. Load 7-joints into Pipe Shed and tally. Wait on crew change at 1800-hrs before proceeding. P/U and RIH with jts 372 thru 376 and slowly lose weight 12' in on jt #376, which puts packer at 11,706' with CIBP at 12,237' N3S RKB. Set down 10K and first set of pins shear. P/U 30K over P/U wt and second set of pins shear. Packer is free. Set down the verify depth and lose weight in same spot. Fish is on. Called engineer and prepare to POOH and UD DP through Pipe Shed. 19:00 - 00:00 5.00 FISH N STUC RUNCMP POOH with Packer Retrieving Tool and Packer Assembly. UD DP into Pipe Shed. Losses at 3 Bblslhr. 20-joints out of hole at 2030-hours. 40-jts at 2130-hrs. 120-jts at OOOO-hrs. 3/15/2007 00:00 - 12:00 12.00 FISH N STUC RUNCMP POOH with Packer Retrieving Tool and Packer Assembly and UD DP into Pipe Shed. 160-joints out of hole at 0145-hours. 180-jts at 0245-hrs. 220-jts at 0445-hrs. 250-jts @ 0700-hrs. 325-jts @ 1030-hrs. Fluid loss averaging 3.2-BPH. 358-jts @ 1200-hrs. 12:00 - 13:00 1.00 FISH N STUC RUNCMP Unload pipe shed. Resume POH and UD 3-1/2" DP. Packer to the floor at 1240-hrs. R/U to handle 2-7/8" STL. 13:00 - 14:30 1.50 FISH N STUC RUNCMP POH, break off and UD Halliburton VersaTrieve packer, 15-jts 2-7/8" STL, and inspect 2-jts of Halliburton Poro-Max screen. There was no apparent damage to the packer other than a small 1/2" square by 1/8" thick chunk missing from one tooth of a down-facing slip segment. A picture was taken and sent to the Anchorage Engineer. 14:30 - 16:00 1.50 FISH N STUC RUNCMP Break out and UD 2-7/8" STL tubing. Used Hydraulic Power tongs with backups to break each connection, then used a 24" pipe wrench to complete the backout for each joint. Inspected each joint and found no damage to any of the joint connections. 16:00 - 17:00 1.00 FISH N STUC RUNCMP Break out, inspect and UD both joints of PoroMax screen using Printed: 3/2612007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 3/15/2007 16:00 - 17:00 1.00 FISH N STUC RUNCMP the Halliburton Sand Screen table. The only damage was a 1-inch indentation 6" up from the bottom the second joint of screen. 17:00 - 18:00 1.00 FISH N STUC RUNCMP RIH with two stands of 2-7/8" tubing from Derrick, stab on the floor valves and connect the circulating line to prepare for Slip and Cut Drill Line. 18:00 - 20:30 2.50 RUNCO RUNCMP Slip and Cut Drill Line. 20:30 - 21:15 0.75 RUNCO RUNCMP POH with two stands of 2-7/8" Tubing and SIB in Derrick. R/U to P/U Screens. 21:15 - 00:00 2.75 RUNCO RUNCMP RIH with Halco 250 micron PoroMax Screen Assemblies on (15) Joints of 27/8",6.17#, L-80, STL Tubing. MU Torque on STL Connections = 900 ft-Ibs. 3/16/2007 00:00 - 11 :00 11.00 RUNCO RUNCMP PUMU HES 7" VersaTrieve Packer. Packer was closely inspected by WSL, Toolpusher, and 2 HES hands. RIH with 2-7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. 30 stands in the hole @ 0230-hrs. 80 stds. in @ 0445-hrs. 130-stds @ 0730-hrs. RIH with 6' pup joint and single joint and tag CIBP at 12,237', P/U and verify by slowly RIH and the string gains another 2' to tag at 11,239'. P/U to get parameters: 52K up wt and 36K down wt. 11 :00 - 12:00 1.00 RUNCO RUNCMP Hold PJSM and complete written HACL with Night Tour (they were working over to cover for the new Day Tour arriving -noon). POH and break off the 6' pup to enable safer connection of the TIW valve and circulating line. 12:00 - 13:00 1.00 RUNCO RUNCMP Hold Pre-spud/Pre-Tour meeting with Day Tour, then hold PJSM and complete written HACL on Rig Floor with Day Tour for spacing out and setting Packer. 13:00 - 15:00 2.00 RUNCO RUNCMP Space out bullnose on bottom of screens 6' above the CIBP. This places the Halliburton VersaTrieve packer at 11,690'. Drop 1-1/2" ball into string. P/U and install TIW valve and circulating line and test to 3500-psi. Pump 44-Bbls to chase Ball onto seat. Pressure up to 11 OO-psi and hold 5-minutes. Bleed off to O-psi, P/U to 62K (10K over P/U wt), SIO to 26K (10K under S/O wt), P/U to neutral and pressure up to 2900-psi and hold for 5-minutes. Pressure up to 3100-psi and hold for 5-minutes. Bleed off to O-psi and pressure up annulus to 1000-psi and it holds solid for 5-minutes. Bleed off annulus to O-psi and pressure up tubing to 3250-psi to shear; P/U to 56K and setting tool shears out with pressure immediately dropping to O-psi indicating separation of setting tool from packer. 15:00 - 15:30 0.50 RUNCO RUNCMP POH and SIB 4-stands of 2-7/8" tubing; POH one joint of 2-7/8" tubing to make up to Halliburton Storm Valve and RTTS packer. No drag on tubing, and weight loss of -5000-lbs. Hold PJSM to P/U and M/U Storm Valve and Packer. 15:30 - 16:30 1.00 RUNCO RUNCMP Hold PJSM and complete written HACL to P/U and M/U Storm Valve and RTTS packer. P/U Valve/Packer assembly and M/U to tubing string and RIH 3-joints (91') below Rig Floor and set. Did not want to set this packer in the same spot where the first VersTrieve packer was prematurely set. This is the same spot that the first Storm Valve and RTTS were set before testing the VBRs for the 3-1/2" Drill Pipe. 16:30 - 19:00 2.50 RUNCO RUNCMP Unsting from Valve and Packer assy and POH to prepare for BOP testing. BOP test witness by AOGCC was waived by John Printed: 3/26/2007 10:30:54 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 Crisp and Jeff Jones. Drain Stack. Pull Wear Ring. RIH and set FMC Test Plug without LDS run in. 20:00 - 23:00 RUNCMP Open Ram doors and inspect VBR. Drillerside VBR is smashed downward. Pull VBR and attempt to straighten out bent segment. After being unable to straighten segment, the damaged segment was removed from the VBA. Reinstall VBR and close Ram doors. 23:00 - 00:00 RUNCMP Test BOPE to 250 psi low and 3500 psi high. 3/17/2007 00:00 - 03:00 RUNCMP Test BOPE to 250 psi low and 3500 psi high. 03:00 - 06:00 RUNCMP Pull and UD Test Plug. Install Wear Ring. RIH wI 3-joints of 2-7/8" Tubing and engage RTTS @ 91'. Rotate and pull RTTS. POH and SIB 1-stand tubing in Derrick, UD 1-joint and UD Storm valve and RTTS. Fill hole wI 6 Bbls of 10 ppg brine. Losses to formation on average = 1 Bbls/hr. 06:00 -15:00 RUNCMP POH and SIB 2-7/8" Tubing in Derrick. 55-stds OOH @ 0845-hrs. 70-stds @ 0915-hrs. 90 @ 0945-hrs. Average losses to 0930-hrs since 0600-hrs = 4.8-BPH. 100-stds @ 1020-hrs. 115-stds @ 1100-hrs. Stand # 118 had a bent joint; UD both joints. 125-stds @ 1130-hrs. 130-stds @ 1145-hrs. 184-stds @ 1400-hrs. PJSM to break out and UD 3-joints of tubing and the VersaTrieve packer running tool with pup joint. BIO and UD same. 15:00 - 18:00 3.00 RUNCO RUNCMP P/U landing joint, M/U to Wear Ring pulling tool, RIH and pull Wear Ring. Clear and clean Rig Floor. Hold PJSM with crew and Centrilift Techs. Bring Centrilift tools and clamps to Rig Floor. Prepare to RIH with ESP completion. Hold PJSM 18:00 - 22:00 4.00 RUNCO RUNCMP P/U and M/U ESP per Centrilift recommendations. M/U 3-1/2" EUE 8rd x 2-7/8" EUE 8rd crossover. M/U 8' pup, 2' pup, and XN Nipple. PJSM. Bring ESP Cable over Sheave with a rope. Attach Cable to ESP and RIH. 22:00 - 00:00 2.00 RUNCO RUNCMP RIH wI 2-7/8" 6.5# EUE 8rd L-80 Tubing from the Derrick. Use Best of Life 2000 Pipe Dope. Place LaSalle Clamps on the first 9 joints of Tubing and every second joint thereafter. 3/18/2007 00:00 . 06:00 6.00 RUNCO RUNCMP RIH w/2-7/8" 6.5# EUE 8rd L-80 Tubing from the Derrick. Use Best of Life 2000 Pipe Dope. Place LaSalle Clamps on every other joint while RIH. Checking conductivity of electric cable every 2,000'. 20 stands in @ 0030-hrs. 35 in @ 0130-hrs. 90 in @ 0400-hrs. 112-stds @ 0515-hrs. 06:00 - 09:30 3.50 RUNCO RUNCMP ESP Cable Splice. Fill Tubing with 10-ppg brine. Once Tubing is full, pump 10-Bbls through pump to flush string. 09:30 - 14:00 4.50 RUNCO RUNCMP Continue to RIH with ESP completion on 2-7/8" tubing from Derrick. 135-stds @ 1030-hrs. 150-stds @ 1120-hrs. #184 @ 1330-hrs. P/U single joint of 2-718" tubing from Pipe Shed and M/U to string. P/U 10' 2-718" tubing pup joint and M/U to string. P/U wt 64K, SIO wt 40K. 192 LaSalle Clamps, 5 Protectolizers, and 3 Flatguards were run in total. 14:00 - 16:00 2.00 RUNCO RUNCMP P/U Tubing Hanger and set in Mouse Hole; P/U 3-1/2" NSCT landing joint and makeup to hanger. P/U landing joint and hanger and makeup and torque up to string. Get proper orientation for penetrator. Spaceout for ESP cable splice to Lower Field-Attachable Power Connector. 16:00 - 18:00 2.00 RUNCO RUNCMP Make ESP cable splice to Lower Field-Attachable Power Printed: 3/26/2007 10:30:54 AM , ' ¡. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 2/26/2007 Rig Release: 3/19/2007 Rig Number: Spud Date: 1/19/1995 End: 3/19/2007 19:30 - 22:00 2.50 RUNCMP Connector (CentriliftlEFT nomenclature). RIH and set Tubing Hanger. RILDS. POH and UD Landing Joint. Drain fluid on top the Hanger. Identified one bad LDS. RIH wI Dry Rod, set TWC per FMC recommendations. Line up to test TWC from above and below. Test TWC to 1000-psi from above for 10-minutes and chart. Test is good. Test TWC from below by pumping down IA. Unable to acheive 1000-psi. Injection rate of 2-BPM at 240-psi. Test cancelled. Clear rig floor of unessential equipment. PJSM. N/D BOPE. Conduct After Action Review. PJSM. N/D BOPE. Conduct After Action Review. Replace bad LDS. N/U Lock Down Flange, Tubing Head Adapter, and Tree. PIT Tree to 5,000 psi and chart. Good Test. PIT Tubing Head Adapter to 5,000 psi. Good Test. CentrUift run final conductivity checks. Pull TWC wI Lubricator. Install BPV. RDMO. Released rig at 0600-hours. 3/19/2007 22:00 - 22:30 22:30 - 00:00 00:00 - 02:00 02:00 - 05:00 0.50 BOPSU 1.50 BOPSU 2.00 BOPSU P 3.00 WHSUR P PRODOP POST POST POST 05:00 - 06:00 1.00 WHSUR P POST Printed: 3/26/2007 10:30:54 AM .. STATE OF ALASKA e AL.AWIIrA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED JUL 1 9 2006 1. Operations Performed: Anchorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change-Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 195-001 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22541-00-00 7. KB Elevation (ft): 54.0 9. Well Name and Number: MPE-11 8. Property Designation: 10. Field I Pool(s): ADL 028231 Milne Point Unit I Kuparuk River Sands 11. Present well condition summary Total depth: measured 12830 feet true vertical 7355 feet Plugs (measured) 12245' Effective depth: measured 12245 feet Junk (measured) true vertical 7048 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3424' 9-5/8" 3455' 2943' 5750 3090 Intermediate Production 11938' 7" 11967' 6905' 7240 5410 Liner 1022' 5" 11808' - 12830' 6826' - 7355' 8290 7250 " ...l'\~ ..~~ !,.; i Perforation Depth MD (ft): 12176' - 12310' " Perforation Depth TVD (ft): 7012' - 7082' Tubing Size (size, grade, and measured depth): 2-7/8",6.5# L-80 11764' Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFl .JUl 2 0 2006 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Pri()r to well operation: 126 57 586 240 192 Subsequent to operation: 0 0 0 0 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. - SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Technical Assistant .-1 þ£~....... Prepared By Name/Number: Sig6ature '''b. "'^'- Phone 564-4750 Date D( ~ ¡ q-L~ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 nR\G\~JAL Submit Original Only Tree: 3-1/S" - 5M FMC MPU E 11 Wellhead: 13-318"x 3-1/S" 5M FMC - wI 3.5" ESP Tubing Hanger, w/ 3.5" NSCT Top & Btm. ,3" CIW H BPV profile Orig. KB Elev. = 53.S3' (N 22E) Orig. GL Elev. = 24.40' RT Tbg. Spool = 29.43' (N 22E) 20" 91.1 ppf, H-40 SO' KOP @ 1000' Max. hole angle = 63 deg. fl 3,300' to 11,300' Hole angle thru' perfs = 5S deg 9 5/S", 40#/ft, L-SO BTC. I 3455' Halliburton ES cementer I 6976' 2 7/S" 6.5 ppf, L-SO, S rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-SO, NSCC production casing ( drift 10 = 6.151", cap. = 0.03S3 bpf) Marker RA Tag 11877' 7" Landing collar 7" Seal float collar 11881' 11924' 11967' 7" Seal float shoe Perforation Summary Refloa: 06/18/96 GRlCCL Size SPF Interval (TVD) 3-3/B 6 12176'-12234' 7011'-7042' Low r perfs isolated. 3-3/8 6 12256'-12310' 7053'-7082' Mid-perf = 7047' tvd 12243' MD DATE REV. BY COMMENTS 12/19/97 MOO ESP Completion 4-ES 6121/99 M. Linder RWO 4-ES 10131100 GMH RWO Nabors 4 ES 07/04106 MOR RWO Nabors 4 ES Camco 2 7/8" x 1" sidepocket KBMM GLM 138' Camco 2-7/8" x 1" 11524' side pocket KBMM GLM 2-7/8" xn nipple 2.205" ID 11666' 159 stage GC2900, GPMTAR 11678' 1:1 Intake TVO 6762' Tandem Gas Separator 11719' GRSFXARH6 Tandem Seal Section 11724' Motor, 266 HP, 2345 volt, 69 11738' amp, Model KMH Centrilift PHD w/6 11762' fin Centralizer 5" setting sleeve C-2 ( 5.25" ID ) Liner top pkr. HPLPO Liner hng. HMC 11808' 11816' 11821' Weatherford cast iron bridge plug Set 10130100 by 4-es. 12245' 7304' TVD Baker landing collar Baker float collar 12697' 12785' 12830' Baker float shoe MILNE POINT UNIT WELL E-11 API NO: 50-029-22541 BP EXPLORATION AK e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/30/2006 Rig Release: 7/4/2006 Rig Number: Spud Date: 1/19/1995 End: 7/4/2006 6/30/2006 10:00 - 12:00 2.00 RIGD P PRE PJSM. Scope down & layover derrick. Rig down rig components. 12:00 - 17:00 5.00 MOB P PRE PJSM. Move rig & rig components from MPF-57 to MPE-11. Completed Pre rig inspection, Unit Work Permit & Risk Assessment for Temporary Buildings, (camp & shop). Accept Rig at 18:00 hrs. 17:00 - 18:00 1.00 RIGU P PRE Pre tour safety meeting and change out of crews. Begin to spot Rig Components and spot over well MPE-11. 18:00 - 00:00 6.00 KILL P DECOMP PJSM. After close inspection of wellhead, and conferring with FMC, it has been determined that tubing hanger will not pull through 11" BOPE. Also, as the desire to nipple up wI two sets of pipe rams was motivated by an expected BHP that would be greater than 3000 psi, and as the recent BHP survey, (ran on slickline yesterday), indicates an expected BHP of around 2300 psi, decision made, after conferring wI town engineer & AOGCC rep, to nipple up the 13 518" stack wI one set of pipe rams. Called for and waited on delivery of an extra set ot 13 5/8" x 5M pipe rams to spot behind rig prior to spotting rig over the hole..... just in case. Adjusted rig acceptance time accordingly. 7/1/2006 00:00 - 03:30 3.50 RIGU P DECOMP Take on heated seawater (120 degree) to the pits. Pressure test cellar lines to 3500 psi. PU Lubricator and pull BPV. Lay down BPV. Tbg Pressure = 380 psi, IA Pressure = 420 psi. Bleed pressures to zero and shut in. OA pressure = 250 psi. 03:30 - 06:00 2.50 KILL P DECOMP PJSM. Begin pumping down the tubing with hot seawater at 3 bpm I 400 psi with 30 psi on IA. Hit fluid with 9 bbls away = 1600'. Increase rate to 4 bpm 1950 psi with 50 psi on IA. Pump 70 bbls to evacuate Tubing. Close choke to bullhead. Tubing pressure = 1200 psi when choke closed. Bullhead 20 bbls into formation at 4 bpm. Strap Tiger Tank and have 21 bbls. Open IA and begin circulating hot seawater at 4 bpm /1300 psi. Getting black oil returns. With 50 bbls circulated into lA, shut down and monitor pressures. Tubing pressure = vac , IA pressure = 300 psi, Tiger Tank = 61 bbls. Resume circulating well at 4 bpm maintaining 1300 psi on tubing until clean seawater returns. Shut down and monitor pressures. Tubing pressure = vac , IA pressure = vac. Pumped a total of 470 bbls. Tiger Tank volume = 260 bbls. 06:00 - 06:30 0.50 WHSUR P DECOMP PJSM. Rig down circulating lines, set two way check valve. 06:30 - 09:30 3.00 WHSUR P DECOMP PJSM. Bleed ports & N/D tree. Check hanger threads & Lock down screws, OK. 09:30 - 14:00 4.50 BOPSU DECOMP PJSM. N/U 135/8" x 5M BOPE. Install mud cross valves. 14:00 - 16:00 2.00 BOPSU DECOMP PJSM. Rig up test equipment & perform BOPE test as per AOGCC State requirements. State rep Lou Grimaldi waived witnessing the test, 24 hour notice given. 16:00 - 18:00 2.00 BOPSU N RREP DECOMP Leak discovered on choke manifold. Attempt to remedy by re tightening bolts on leaking flange, no good. Disassemble & replace API ring, reassemble. 18:00 - 00:00 RREP DECOMP Crew change out and pre-tour safety meeting. Ring groove in cushion block is washed out and must be taken apart and replaced. Begin repairing choke manifold. May take up to 12 hrs or more. Conferred wI Milne Pt Supervisors to move spooling unit from MPE-11 to MPG-15 to allow 3S to RIH wI Printed: 7/5/2006 10:11:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 6/30/2006 7/4/2006 Spud Date: 1/19/1995 End: 7/4/2006 their ESP I heat trace completion. They are unwilling to do so at this time. 7/2/2006 00:00 - 05:30 5.50 RREP DECOMP Continue repairing choke manifold. Cushion block located in the middle of the manifold has a washed out API ring groove. Procure a similar cushion block from Doyon. Doyon cushion block is a 5 way, damaged one is a 6 way. Install 5 way cushion block in place of another 6 way cushion block on the manifold, and use that 6 way where the damaged one was. Have to replace (2) valves on choke manifold as well, to accomodate new arrangement. 05:30 - 06:30 1.00 BOPSU N RREP DECOMP PJSM. Resume testing choke manifold @ 250/3500 psi. Discovered leak in 3" valve that was installed last night. Will have to be replaced. This may involve dissassembling part of the manifold. 06:30 - 10:30 RREP DECOMP Work on repairing I replacing valve on choke manifold. Confirmed that ESP spooler in Kuparuk and accompanying gen set is available. NOTE: This spooler is capable of handling only one spool at a time. The spooler here at Milne, currently at 4ES can handle dual spools. 3S is running an ESP cable wI heat trace and needs a spooler wI dual spool capability. 10:30 - 12:00 RREP DECOMP Continue working on choke manifold. 3S & 4ES Well Site Leaders met with Supervisor at Milne. All agreed on a plan forward to take the dual spooler here on 4ES to 3S & get the spooler from Kuparuk for 4ES. Set plan in motion and continue working on choke manifold. 12:00 - 17:30 DECOMP Conduct test on choke manifold & BOPE @ 250 I 3500 psi. Witnessing of test waived by AOGCC rep Lou Grimaldi. 17:30 - 19:00 1.50 WHSUR P DECOMP PJSM. PU Lubricator and pull TWC. Change out crews. Pre-tour safety meeting and perform daily checks. Lay down Lubricator. Clear and clean Rig Floor. Fill up IA with 80 bbls of seawater, fill up tubing with 20 bbls of seawater. Maintain charge pump filling tubing but fluid level dropping faster than charge pump can fill. OA pressure currently reading 210 psi. 19:00 - 20:30 1.50 PULL P DECOMP MU Landing Joint and begin to BOLDs with FMC Representative. Pull on Hanger and came free at 95K. Expected UW should be 80K according to tally, UW after came free is 85K. Pull Hanger to the floor. Unplug cable and break apart Hanger. Lay down Hanger. Cut cable and lay down landing joint. 20:30 - 22:00 1.50 PULL P DECOMP PJSM. Begin RU Spooling Unit. RU Sheave and Elephant Hose to run cable through to unit. Make all electrical checks on Spooling Unit and RU empty reel. Run cable over Sheave and down to the unit. 22:00 - 00:00 2.00 PULL P DECOMP PJSM. Begin POOH with ESP Completion standing back 2 7/8" EUE 8 Round Tubing. Stand back 1 stand (3 joints) of Tubing and lay down GLM. Continue POOH with 2 7/8" Tubing while double displacing the tubing with seawater. 7/3/2006 00:00 - 01 :30 1.50 PULL P DECOMP Continue POOH with ESP Completion while standing back 2 7/8" EUE 8 Round Tubing. Double displacing the well with seawater as POOH. 01 :30 - 02:30 1.00 PULL P DECOMP PJSM. Stop with 41 stands (123 joints) of 2 7/8" Tubing stood back in Derrick and cut cable at the splice. Change out reel to empty reel in Spooling Unit. Splice left on 1 st reel. Total length Printed: 7/5/2006 10:11:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-11 MPE-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/30/2006 Rig Release: 7/4/2006 Rig Number: Spud Date: 1/19/1995 End: 7/4/2006 7/3/2006 01 :30 - 02:30 1.00 PULL P DECOMP of cable pulled to the splice: -4000'. 02:30 - 06:00 3.50 PULL P DECOMP Resume POOH with ESP Completion standing back Tubing in Derrick. Double displace with seawater as POOH. 06:00 - 09:30 3.50 PULL P DECOMP PJSM. Crew change, continue to POOH wI 2 7/8" ESP completion. 09:30 - 10:30 1.00 PULL P DECOMP PJSM. Cut ESP cable, pull over sheave, UD bad clamps. (pretty much all the clamps were bad). Laid down (8) bad joints & changed out (4) bad collars due to galding when RIH. 10:30 - 13:00 2.50 PULL P DECOMP Clear I clean rig floor, rig up to run new ESP assembly. Wait on Centrilift hand. 13:00 - 16:30 3.50 PULL P DECOMP PJSM. UD pump & motor, load same in boxes, change out spools on spooler. 16:30 - 19:30 3.00 RUNCO RUNCMP PJSM. Pick up new ESP assembly, service & test same. 19:30 - 20:00 0.50 RUNCO RUNCMP Pull Motor Lead Extension over Sheave and plug into the Motor. Run initial tests on cable - good. 20:00 - 00:00 4.00 RUNCO RUNCMP PJSM. Begin RIH with new ESP Assembly on 2 7/S" EUE 8 Round Tubing from Derrick. Stopping every 2,000 ft to check cable and pump through to ensure tubing is clear. Check at 2,000 ft - OK. Pumped through pump at a rate of 1.6 bpm I 1800 psi. Check at 4,000 ft - OK , check at 6,000 ft - OK. Continue RIH. 7/4/2006 00:00 - 01 :30 RUNCMP 67 stands (201 joints) of 2 7/S" Tubing in the hole. Power tong unit not functioning correctlly. Break apart and gear shifting pin appears to be broken. Replacement is being retrieved from Nabors 7ES. Replace power unit and check tongs - OK. 01 :30 - 02:00 0.50 RUNCMP Continue RIH with ESP Assembly. 02:00 - 07:30 5.50 RUNCMP PJSM. Stop with 247 joints of 2 7/8" Tubing in the hole. Make reel to reel splice. Depth approximately = 7,600'. 07:30 - 11 :30 4.00 RUNCMP Crew changeout at 06:00 hrs and pre-tour safety meeting. Continue RIH with ESP Assembly on 2 7/8" Tubing from Derrick. PU singles from Pipe Shed. Ran a total of 372 joints of tubing. 11 :30 - 12:30 1.00 RUNCMP PJSM. MU Landing Joint and Tubing Hanger. 12:30 - 14:00 1.50 RUNCMP Splice cable and make Field Connector and attach to Motor. Test - OK. 14:00 - 15:00 1.00 RUNCMP Land Tubing Hanger and RILDs. UW = 86K , DW = 37K. 15:00 - 15:30 0.50 RUNCMP Set Two-Way Check Valve and test to 1500 psi - good. Lay down Landing Joint. 15:30 - 17:00 1.50 BOPSU P RUNCMP PJSM. ND BOPE and set back. RD Test Spool. 17:00 - 20:30 3.50 WHSUR P RUNCMP PJSM. NU Adapter and 3 1/8" 5M FMC Tree. With FMC test voids and Tree to 5,000 psi - good. Perform final check on ESP withe Centrilift Rep - good. RU Lubricator and pull TWC. Set BPV. 20:30 - 00:00 3.50 RIGD P RUNCMP PJSM. Secure Tree and Cellar. Lower Derrick and RD all Rig Components off of MPE-11. Prepare to move to GPB J-28. Secure location and begin to move. Release Rig @ 21 :00 hrs. Printed: 7/5/2006 10:11:41 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M PL W ATE IA L U N D E R TH IS M ARK E R C:LORBMFILM.DOC ,----. STATE OF ALASKA ALASKA . AND GAS CONSERVATION COMMi ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Per/orate [] 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 = 54' [] 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 3684' NSL, 1992' WEL, SEC. 25, T13N, R10E, UM MPE-11 At top of productive interval 9. Permit Number / Approval No. 195-001 2089' SNL, 4851' EWL, SEC. 31, T13N, R11E, UM 10. APl Number At effective depth 50-029-22541 2148' SNL, 4907' EWL, SEC. 31, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2515' SNL, 5244' EWL, SEC. 31, T13N, R11E, urvl Sands 12. Present well condition summary Total depth: measured 12830 feet Plugs (measured) Cast Iron Bridge (Weatherford), Set 10/2000 true vertical 7355 feet Effective depth: measured 12245 feet Junk (measured) true vertical 7048 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3424' 9-5/8" 665 sx PF 'E', 250 sx Class 'G' 3455' 2943' Intermediate 11938' 7" 370 sx Class 'G' 11967' 6905' Production Liner 1022' 5" 145 sx Class 'G' 11808'-12830' 6826'-7355' Perforation depth: measured 12176'-12234' RECEIVED Isolated below ClBP: 12256'-12310' true vertical 7012'-7042' [.: ;~;~' (~': 2,. '~ 3'~"i..:..~ Isolated below ClBP: 7054'-7082' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 11716' ''~(~ (}ii ~: f? ...... -.. Packers and SSSV (type and measured depth) Weatherford Cast Iron Bridge Plug at 11245' __ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ..~¢~¢" ~ Title Technical Assistant III Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate i i : Operations summary Report Legal Well Name: MPE-11 Common Well Name: MPE-11 Spud Date: 1/19/1995 Event Name: REPAIR Start: 10/24/2000 End: Contractor Name: Rig Release: Group: RIG Rig Name: Rig Number: i i~ate ~8:rs:: ,~sk (~oUdbe :pha~e:: of ;: ; :i!: !i!:!,', : i: i Description Operations 1012412000 09:00 - 10:30 1.50 MOB PRE SCOPE DOWN AND LOWER DERRICK 10:30 - 13:00 2.50 MOB PRE MOVE RIG FROM MPU J-05 TO MPU E-11 13:00 - 15:00 2.00 MOB PRE SPOTAND BERM RIG 15:00 - 16:30 1.50 RIGU PRE R/U LINES. SET & BERM TIGER TANK. 16:30 - 18:00 1.50 RIGU PRE RAISE & SCOPE DERRICK. ACCEPT RIG @ 1800 HRS, 10-24-00 18:00 - 20:00 2.00 CONS PRE M/U HCR VALVE & LINES. CONNECT TO TREE. FILL PITS W/10.1 PPG FLUID. PULL BPV. 20:00 - 20:30 0.50 CONS PRE PRESSURE TEST LINES TO 2500 PSI, OK. 20:30 - 00:00 3.50 CONS PRE SlTP 700 PSI, SlCP 2650 PSI. OPEN WELL & BLOW DOWN, PUMP 10.1 PPG KILL FLUID @ 2BPM, 1050 PSI. BEGIN KILLING OPERATIONS. 10/25/2000 00:00 - 04:00 4.00 KILL DECOMP CIRCULATE & KILL WELL W/10.1 PPG FLUID. KILL RATE 3 BPM @ 850 PSI. LOST 112 BBLS TO FORMATION. 04:00 - 04:30 0.50 WHSUR DECOMP SET & TEST TWC VALVE, 3500 PSI, OK. R/D LINES. 04:30 - 06:00 1.50 WHSUR DECOMP N/D X-MAS TREE. 06:00 - 12:30 6.50 BOPSUR DECOMP N/U BOPE.CHANGEOUT BLIND RAMS TO BLIND/SHEAR RAMS. 12:30 - 13:30 1.00 BOPSUF DECOMP PRESSURE TEST BOPE TO 3500 PSI, OK. 13:30 - 14:30 1.00 BOPSUF DEOOMP P/U LUBRICATOR EXTENSION. PULL TWO VALVE. 14:30 - 15:30 1.00 WHSUR DEOOMP M/U LANDING JT. BACK OUT TIE-DOWN BOLTS & PULL HANGER. P/U WT 85K. FILL HOLE MONITOR LOSSES. L/D HANGER. 15:30 - 17:00 1.50 PULL DECOMP MONITOR WELL. WAIT ON 9.9 PPG FLUID. PJU TO PULL COMPLETION. 17:00 - 00:00 7.00 PULL DECOMP PULL COMPLETION. STAND BACK 2 7/8" TBG & SLM. SHOOT FL EVERY 10 STANDS. 1012612000 00:00 - 00:30 0.50 PULL DECOMP CHANGE OUT CONTROL LINE SPOOL @ 3854'. 00:30 - 09:30 9.00 PULL DEOOMP POOH W/COMPLETION STRING. SHOT F/L EVERY 10 STANDS. 09:30 - 11:00 1.50 PULL DECOMP CHECK & L/D ESP. 11:00 - 12:30 1.50 PULL DEOOMP L/D DESANDER & 3 1/2" TBG. PUNCH HOLE IN 3 1/2" TBG. 12:30 - 13:00 0.50 PULL DECOMP CLEAR & CLEAN RIG FLOOR. 13:00 - 16:00 3.00 PULL DECOMP PJU SCHLUMBERGER. RIH W/GR/JB TO 11722'. COULD NOT GET THRU FB-1 PKR W/3.9" GAUGE RING. 16:00 - 21:30 5.50 PULL DECOMP M/U 3.875" ClBP ON WIRELINE. RIH & SET @ 12245'. 21:30 - 22:00 0.50 PULL DECOMP R/D SCHLUMBERGER & FILL HOLE W/18 BBLS. 22:00 - 22:30 0.50 REST DEGOMP PJU & CLEAR FLORR TO RUN ESP. 22:30 - 00:00 1.50 REST DECOMP P/U PUMP. MAKE UP MOTOR LEAD EXTENSION. SERVICE & TEST SAME. R CEIVED · Printed: 11/1/2000 1:01:39 PM STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [~] Pull Tubing []Alter Casing [~ Repair Well [] Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3684' NSL, 1992' WEL, SEC. 25, T13N, R10E, UM At top of productive interval 2092' SNL, 392' WEL, SEC. 31, T13N, R11 E, UM At effective depth 2428' SNL, 5170' EWL, SEC. 31, T13N, R11E, UM At total depth 2512' SNL, 10' WEL, SEC. 31, T13N, R11E, UM Type of well: [~ Development [] Exploratory I-q Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-11 9. Permit Number / Approval No. 95-01 10. APl Number 50-029-22541 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12830 feet true vertical 7355 feet Effective depth: measured 12697 feet true vertical 7285 feet Casing Length Size Structural Conductor 80' 20" Surface 3424' 9-5/8" Intermediate 11938' 7" Production Liner 1022' 5" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx.) 665 sx PF 'E', 250 sx Class 'G' 370 sx Class 'G' 145 sx Class 'G' MD TVD 112' 112' 3455' 2943' 11967' 6905' 11808'-12830' 6826'-7355' Perforation depth: measured 12176'-12234',12256'-12310' true vertical 7012'-7042',7054'-7082' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 11737' Packers and SSSV (type and measured depth) None 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 Iniection Data OiI-Bbl Gas-Mcf Water-Bbl 15. Attachments I--I Copies of Logs and Surveys run [~ Daily Report of Well Operations Casing Pressure Tubing Pressure I16. Status of well classifications as: [~] Oil I-~ Gas [--I Suspended Service !17. I hereby certify that the foregoing .is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 ~ Submit In Duplicat~._~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt E Pad Well MPE- 11 Page 1 Rig Nabors 4ES Date 23 June 99 Date/Time 18 Jun 99 19 Jun 99 20 Jun 99 21 Jun 99 15:05-01:30 01:30-04:30 04:30-06:00 06:00-13:00 13:00-13:30 13:30-14:30 14:30-17:30 17:30-23:00 23:00-01:00 01:00-04:00 04:00-06:00 06:00-08:30 08:30-09:00 09:00-10:30 10:30-12:00 12:00-20:30 20:30-23:30 23:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-11:00 11:00-13:30 13:30-14:00 14:00-16:00 16:00-17:00 17:00-19:30 19:30-22:00 22:00-23:00 Duration 10-1/4 hr 3hr 1-1/2 hr 7hr 1/2 hr lhr 3hr 5-1/2 hr 2 hr 3hr 2hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 8-1/2 hr 3hr 2-1/2 hr 4hr 1/2 hr 1-1/2 hr 3hr 2-1/2 hr 1/2 hr 2hr 1 hr 2-1/2 hr 2-1/2 hr lhr Activity Rig moved 100.00 % Installed High pressure lines Circulated closed in well at 11652.0 ft Circulated closed in well at 11652.0 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Tested BOP stack Serviced Blind ram Serviced Blind / Shear ram Serviced Blind / Shear ram Tested Blind / Shear ram Retrieved Hanger plug Retrieved Tubing hanger Pulled Tubing in stands to 11654.0 ft Conducted slickline operations on Slickline equipment - Tool run Rigged up sub-surface equipment - ESP Ran Tubing in stands to 3500.0 ft Held safety meeting Ran Tubing in stands to 7700.0 ft Serviced ESP Ran Tubing in stands to 11737.0 ft Installed Tubing hanger Serviced ESP Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Freeze protect well - 15.000 bbl of Diesel d, IU: ~ti l<AJL ~IU'! ,'~4 D/~ Ill' IZ..~I'LUIiA'I'IUI] '... . -. G~ ~ &G~ ~'~- ~ ' ' L~ CUT ~F- I P~ LEN~ ~T ~A~ , ' '" ~ ~' ~Z. ~ HO~Z- D~A~ON . '{ RECORD . T~E ~E~O, O~AIL9 ~ 0~9 IN ;EQUENC~ ~ REMA~ F~M . -,,, , ........ ...... ,~: . . ., ~ ' ~ . . .. HOfl~ ~fllZ, ~RI~ ~ O~, ~, ,~ ~. O~ 0~. ~R, ~ O~. OEP~ O~. D:R, ~. ~P, · ' ~ L~ ~p~ " ' ~ ' ~OM ~ ~E ~ENO. D~A~ OF ~ ~ ~E~CE ~D RE~ . -:. , ~ , ~ JS~ ao~ ~'/~ ~ ~ ~/~Y~ DP~/P~J ~ F~:.I,,.,;,.~~ ~+... :'-,, . -:: .. . ..-.-._ ~ -. -.' ..~ -..,. :........ ,,~ -:: · ~.::~?:,.:>......~ ...... . ,. ....... .... ...., . . }~ - . ·" · .~: l-....~.. :, . .- · '.- . ¢ . - ..... ~'~ ~o ;o~o ~' ." ~ ' "-'.'-~. ~' ' ' / -: ~ " ' ~ ~ -. ?o~ ~- "~" ~" ~'~E'"'J'~ ,. ~...~ ~_ ,,~¢.;t, e~, .~ ,~o ~,~ . :~:"?: .. ..-~ '~,., .. .., . .._ - .. .- . :. : .,_ ,,.- .... . .. 0,.~~.~ "I~C-~' ~.cIAL"AILY DRIVING REPOT ~"M-. ' . ~.... ~ .. .: ;>. s.. ~.~.~... · .. ... ! :; :.. · 9.: .... DAlLy DRI~t~"EPORi;'''}': ' REPORT NO. ) LEASE ' [. WELL NO. APl WELL NUMbLn "' WATER OEPI'HI OPERATOR CONTRACTOR.:'. ' " 1 SIGNATURE OF CONTRA~ TOOLPUSHER SIGNA~~P~NTA~IVE ~. REM~ . . ~ MANUF~R~ FUN~ * CO~,N~ / ~ ~ _~,~--~ VlSOOS~ ~PE co...,o.,~. -, , .... / / / .- J~S F~U,'D -- _ _ T~AL DRILLED ~auu & GR~A~ A~ . - - I~ NIPF~ UP B,O P. _, '""~'"*~ P~s m ~ ~:_~2,~i~' .... R~ ~ ,o.,,~,,o,, - ~ ~ &¢; lis _ G~DI~T ---; i; ~. ~e e. , . SERIAL NO. , --- __ ": MUO& ~EMI~ ~O~O . . FROM ~ O~TI~ · --' -~ -' · ,,-~,,.~-~,,u~-,~r,~o~ ~,,.,~,,~ IADC -APl OFFICIAL DALLY DRILLING REPORT FORM ~P~¥EO ~ APPROVEO PRATED IN U,9,A. . . : , ........... R E-C E Alaska Oil & Gas Cons. '6ommlsslor~ Anchorage DAILY DRI, M.ING REPORT REPORT LeAs~ ! WELL"O' APIWE~NU~.~E" SIGNATURE OF CONTRACTOR'~ TOOLPU~HER ~Q~ OF OPERa'S REPR~E~AT~E , I 3. REAMING MANUF~TURER FUNN~ ~' ~ C~OU~ ~ ~ ~ER~L NO, 7. L~R;C~T~ n~ ~ ~ TFA ~ O~F "'~UNe UNE ~ J DEPm ~ 1 ~. ~6 UN~ LOQ~ .; ~AL .D~ED, 13, ~ ~a ~ ~ TOT~ HOURS ~, WA~NCEM~ _ S~HG~D.~. _~ g~ ~C~ ., . . t4. mPPLEUP~D~. K~YDO~ :.~ . . I~, ~ ~.0.~.' ~; - 18, D~ TE~T Y~. OF ~N~ ., 1~, FI~G- 20. ~Y~ - -' ~ TUBING ~lr8 . . O,~A~NG ~" j,.: ' ~- . . BIZE WE;OHT .._, . .. PRE~U~ . O, ~AaB~Q - ~NUFA~URER FUNNEL E,~NG OD - . ,V~O~ . .'~, . . ~. ~ERI~ NO, . ..,. · · ..,.~./ /- - ::?~./, H. . - ,4~ ~UID ,-· '.~ OD '*' ~5~ . ..; *',' ' '-' "~R~'~ ~ ~ .'~ ~URS WI C~, D,P. , . . ' DEPTH IN ' . . ' MUD & CH~CA~ A~ED ~9~O~D.P, . ':'.' ~NDB~D,P~ 'TOTALHO~8. ~PE ~T ~PE AM~ I . . . ; T '-' ~R J ~TER0~, ~N '.- ,. _ ,, ~OM S~ , R~A~ ~R8 ,-. IADC - APl OFFICIAL DAILY DRILLING REPORT FORM O API~IOVED ,~ APPROVED pFill'~mo IN U.S,A, . · '"' ',l': .:.:' ........ ',~.'-' - '. .... .~, ~-.'.~- i -, .'.._.:.; ,': i~: i i? L D:. ,!,.,,.. !i~;'' .. · ' ' , i.~'? - .."'.i i ':I:-., .....::...::i~!:.-:: "~-'" .... ,. ::'~:'.i',:: [..... lJl~ I PRESENT LENCITH :., ~,'~. ~. o.'m~ ~.~(.. DEVIATION RECO~ID TiME LOG DEVIATION RE~ORD TI~E LO<] OL~I'AIL~ C~ OPERAll~$ IN 8EC~UENCE AND REM,LqK~ . . -' IADC · APl OFFICIAL DAILY DRILUNG REPORT FORM · No' 787675 DALLY DRILLING R'~"~PORT REPORT NO. OPERATOR CONTRACTOR' ',. ~ R~NO, ~IGNATOA~ OPERAT~ REPR~gE~ATI~E SIGNATURE OF CONTRACTOR'S TOOLPUSHER , ~ ' , '.~ , ~A o ~ ~ ~u~ ] ! ,.~umo,Tt~ ' ~ · o~ ~ Loss . . / ' ST~S~O.P, ~AL HOURg WPa I A~U~ ~ WPE ~0~ .... ! l ~9. ~SH~ , ' " " A, P~PA~ NO, ~M k~e~ BIT NO. ~MB J O,~NQ V 6GO5~ . ,,. ~ . "r ~'L~ ~;~ Z~'":'"' '''~' ~ · I NOUR~ WI OPn, O.P. T~AL DRILLED .. , MUD _. .- i , TOTAL DA~O R K ' ' NO. OF DAYS ' FRet ~PUD . O1~5 L=P~r'n~J~l a.~tt~1~ ;)r:i'~ C~,~.ec~um IADC - APl OFFICIAL DAILY DRILLING REPORT FORM O APPROVED .j~ APPROVED PRINTED IH U.S.A. : . .?:: ·. :.::.., :: .. !:::. .. ~.,, ~... FI, · IADC - APl OFFICIAL DALLY DRILLING REPORT FORM O ApprOVED" ~. ~PPROVED No. 787874 OPERATOR CONmACTOR , '.:. I ~GNO. . PUMP M~iUFA~UflEfl ~PE ~. ~M~O .... MANU~AC~RER FUNN~ 7, 9, DRiLUHG U~ " 11, raRE ~E LO~ tT. PLUO~ ~. D~. WORK .... E ~S~N~ OD VI8008~ TOTALS (OFRCE U~ ~TAL DA~RK ' ' NO, oF D~YS ' _ PROM ~ - ~OTA~G HOUR8 . lAD OFFICIAl. DALLY DRILLING REPORT FORM APPROVED PRINTED IN'U,S,A, '.='~-:;:-!:':' i: ';~' : : ;',,' ' ; ~.~ -. . ,. ,;?:~ ¢: ~,.., . .Z' " ":'G' ' .... · :: 3' :4~ : . :. ,..., .;'"";.-ii, : ,' ~:"~-:?.~'~,"~?.: ':'"' '"'"" ...... ~EC~D ~ L~ ~P~ CODE NO, , . , , ,, , .. ........ . : .... RECORD , TIME L~ E~PSED ~ENO, OETAIL~ OF OP~O~ ~ SEQUENCE AND ~h~RK~ FRoM TO .... .- · . '...~- ... . , ,, _ . IADC · APl OFFICIAL DALLY DRILLING REPORT FORM , · ,,.~ ~ ' '. ,,,p,o,~,,. ~o,~_7'8 7 6 7 2 ?' i,... ~ ~' ;,~ ~'~ ' :. -::. ~'- ..... .- :~~ '- ,. . .?. ~' · . :~ ~ , .~:.~. · . ~ : :.~:~: ::.~.., · ... .:'~' i?:' . ~:.' u:: :. , ~: .: ~.-~ .,. t1.,j~,~l,~ C~ ...... ' : / · .. ~IU / ~t)Zl. Dl~l ~t' U, AI-'LUI(&'I'IUIN -~ .~kUb~b tF_d uu~ DALLY DRiI~LIN~poR'i'i ' ' .... ~ '* '~ " , , REPORTNO. O~.81ZE V~6HT GRAD~ TOOLJTO. D. TYPETHREAD 8'1'~hl(~NO... PL?PNO. . PL.q,'~PI',LM'IUFAOTURER TYFE_ LENb~.G~ G~.E _ OPERATION I~GF/T DAY ~ UP ~DI ' ' ' I. TEARDOWN . J 8.1' ,~IZ~ WEIGHT I GRADIENT ~. R,~.~ZI~,Ie MNflUFACTUR~R ~-U ~ N E~ 4. CORING OD . - V SOOSITY $, TRIPB OD JET~ FLUI:) 7. LUlaRICATE R[(~ OD LOSa -- ~t,r1' ~F ,. DEPTH OUT , - - 9. DR~LU~ UNE 1~, R~ c4s~o & C~EflT ' TOTAL HOUR9 TYPa AMOUNT TYPE AMOUNT Sr~eCP, L._O.p, ccrmH, STRU~URE KELLY DOWN 1~. DI~LL 81'~,q TF.~? 18, SC~JEEZEOEMENT · . 19. FlSHIN~3 , A PERFOP, ATINQ .... I)IT ~I'ZE WEIOH'T, · MANUFAOTURER FUNNEL / .... . / /. ~, ' JF. T8 .. FLUE) . . e . OB. LOaB ' ' SO,LID8 t'~UR$ ¥'ffI'HOLIT I~,P. gTAND8__O.P, ' TOTAL HOUR8 .TYPE AR/~)UNT TYPE ' AMOUI'~ ..... . . ....... · NO. OF DAYS FROMSPUD CU~ULATiVE ' .. ,:' :~ .ROTA~ NOURS e,~~m~m~ IADC - APl OFFICIAL DALLY DRILLING REPORT FORM APPROVED IAtOC - APl OFFICIAL DAILY DRILLING REPORT FORM A PROVED · :~ 'i ' . : ',.:.::ii~.~.:' ]. , - ::~:~ .,:...' : f~ '; ';I: ' · No. 787673 · . -i . .1 DAILY DRILLING REPORT REPORT NO. r LEAS"~'~ .... I WELL NO, ' APl WELL N~.L.dER- - i WAIER'OEPTH I ' -- ' D~i,'TE OPERATOR .... CONTRACTOR ' ' J e~a NO. SIGNATU~BRAT~ REPR~A~ SI~RE ~ CONTRACTOR'S TOOLPUSHER -- . . , R~ UP ~ [ DR,~R~L '' ,AOC~DE III I11, e~OI;NTPRE~RE 7. L~RiOA~ ~ IFA - LOS8 T~T~ DRILLED 14. NIPPLE ~ g.O.P. ~ .... ~. O~ WORK NO. ~EM L~GTH BlT ~0. TI~ e~ 81ZE WEIO~ MANUFA~ER E ~3 , OD VIBCO91~ I . ~Tg FLUID "0URS W/OP,. 0.,. ' TmAL ORItLED - T~AL HOURS ~PE HD'~ ~AND~ ~NGLE~ ~.P FR~ ~UD .... lAD APl OFFICIAL DALLY DRILLING REPORT FORM f "'' -" ~i. : ........ · . t. . ~ '; . : ....,~ !: :i' : : :i,!' '1'' !," J FELD OR Ol~il:JlgT' ','. ' ']~1- ' J~c)l,-,JJ'~rr~ ' ' WEI~ RKB, TO a~ ~. LINE8 ~NGTH SUPPED ~ HD. ~ ' HO~ HORm ~R~ OE~ - O~. D~ ~O O ~.' ~ ~, O~. ~ DiSP. DE~ OEV,. DIR. ~0. D~A~ON R~ORD .... . ~L~ ~PSED ~EN~ D~A~ OF OP~ON~ IN 8EQU~CE A~ RE~RKS . ... . .. · .. · . ~ . . . · .. . .... .. ,. . · . , . . .% ,.... .... . ....[. -. .. . , . . i- , , DE~ 0~. D~. ~D ~P. D~ ~, ~ ~D DI~P, D~ ~, ~R. ~ ~SP. DEVIA~ ' ' ' -. " ' RE~. . . . * . .. , ~.. .. . . ,' .... :~O~~ ~8~ ~ENO, J D~OP~ON~$EQ~ANDREM~ ~ ~ME .~..;. . . , , , " - . - ,- ', ' g. ' . ' ~1 - .' ''-'.~- J ' ~1 . . · t .- · .. ' .:~ : -' . , ' . " ~ I ~ . .... ~", · '~ .... · - · - '- ~ I ..~- . . o~~~ IADC'- APl OFFICI~ DAILY DR[LING REPO~ F~M . . · · ..'.:. -:i .. Tin~ ~,,,u m~ce ot Incident: December 16, 1997, approximately 2000 hr, Milne Point Unit Nature of Incident: Well Control Personnel Involved: (No Names) · Rig crew, Shared Services Drilling Company Rep Equipment: Workover/completion rig Weather Conditions: Good visibility, -2 deg, 3 mph winds Description of Incident - What happened? (Attach any additional information) While running in the hole with a retrieving tool for an LLCV, an influx of approximately 25 bbls was experienced. The influx was discovered when the pits overflowed, resulting in a small spill on the pad. While addressing the spill clean up, it was noted that the well was continuing to flow into the pits. Flow was then confirmed and the well was shut in. Kill operations proceeded without incident. It was determined that the influx was a brine with minimal oil or gas associated with it. Specific deficiencies included not using trip sheets while RIH, re-setting PVT after indicating an influx without confirming if the well was flowing, ignoring the possibility that the well was flowing when it was reported that the pits were overflowing, the driller leaving the floor to investigate the spill without confirming flow or securing the well. Investigation - Why did it happen? The investigation determined that there were procedures and equipment in place to provide adequate warning in the event of an influx into the wellbore. All indications of well flow were ignored, allowing an unacceptable volume to flow into the wellbore. The rig crew was focused on the mechanics of the trip, rather than hole fill, initially and the spill cleanup operations next, ignoring all indications of the well flowing. Loss Severity Potential Probable Recurrence Rate X Major _ Serious _ Minor _ Frequently _ Occasionally X Rarely Corrective Measures: Well control awareness will be highlighted in several ways - biweekly supervisor meetings, pre-job safety meetings, formal awareness campaign, distribution of SPI, updated procedures with correct trip sheets. The policy requiring use of trip sheets will be emphasised and enforced. Additional training to be provided to the driller. Modifications to the pit system are being considered to improve the sensitivity of kick detection. This SPI is to be read and discussed by all personnel. All supervisors are to sign this report to verify. After signatures, send this report to your Anch. office. SPI-97-22 Operator BP Exploration Field Milne Point Morning Completion. Report Well MPE- 11 Report 7, page 1 Rig Nabors 4ES Date 06:00, 17 Dec 97 Depth MD Plug Back @ Liner Size 5in Torque Est TVD Hold Up @ Liner Depth 12830.0 ft WOB Casing Size 7in Cum Bit Hours Liner Weight 15.00 lbf/ft RPM Casing Depth 11808.0 ft Jar Hours Liner Grade Rot Weight Rotating Time Sliding Time Top Liner 11808.0 ft Pick Up Wt Slack Off Wt Circ Rate Riser Circ Rate Hole AFE 339064 Daily Mud 9194.00 Cum Mud 75120.00 Drilling Prg 0.00 Daily Comp 44739.00 Cum. Comp 281840.00 Cum. Well 0.00 i Pump! Eft (%) 1 97.00 Stroke Rate (SPM) Liner Size (in) 5 Circ Rate (bbl/min) Operator 1 Contractor 20 Service 1 Total 22 Supervisor Engineer Bob Laule · ! I I i i Fluid Type Brine Density 10.1 ppg PV Test Temp Funnel Visc YP Ann Vel DP Ann Vel DC Ann Vel Riser Cum Cuttings Ann Vel Casing Ann Vel Liner Daily Cuttings Storage Site :::.BUIk'~Material: ": :i Res Lith Trip Gas Bgrnd Gas Cxn Gas Pore Press [EMW] Barite 0.00 bbl used:0.00 Bentonite 0.00 bbl used:0.00 Potable Water 0.00 bbl used:0.00 Drill Water 0.00 bbl used:0.00 Base Oil 0.00 bbl used:0.00 Rig Fuel 0.00 bbl used:0.00 Helifuel 0.00 bbl used:0.00 Kill Mud 0.00 bbl used:0.00 Base Fluid 0.00 bbl used:0.00 Cement 1 - 0.00 bbl FIT TVD MAASSP :Pump! Stroke Rate FIT EMW ECD : (SPM) Kick Tol Test Press 1 Casing Test Days Since Last BOP Test 6 Drill Accumulator Kick While Drilling Kick CWell Kill) Kick While Tripping Fire Spill Date Run LTA Today No 23:00, 22 Nov 97 Days Since Last LTA 853 18:00, 04 Dec 97 Accident/Incident Today No 18:00, 07 Dec 97 Days Since Last Acc//nc 21 18:00, 09 Dec 97 Acc/Inc Report Filed No 18:00, 13 Dec 97 Spill Yes 18:00, 14 Dec 97 Spill Type Circ Press Loss (psi) C/L Press Loss (psi) K/L Press Loss (psi) Wind Speed 8.0 m/hr Wind Direction 15.00 deg Visibility 15.0 mile Temperature -23 degF Sea Height Wave Period Sea Direction Max Current Barometer Chill Factor -32 degF Weather State Spill Vol 1.500 bbl Last Safety Mtg Days Since Last Spill 0 Maufacturer Tree Size Morning Completion Report Operator BP Exploration Field Milne Point Well MPE- 11 Rig Nabors 4ES Report 7, page 2 Date 06:00, 17 Dec 97 06:00-20:15 06:00-20:15 BHA run no. 2 R.I.H. to 10160.0 ft RIH with BHA #2 to recover LLCV valve. Guide shoe, Bowl, Top Ext , Circultion sub, Bumper sub, oiljars,9 DC,s Acc Jars, DC = 342.81'. 20:15 Stopped : To flowcheck well : Number 3 pit over flowing. Well control Flow check In 2.50 hr had 25.000 bbl Gain - closed in well Shut in well with 430 psi on the DP and 1060 psi on the annulus. Notify Envir ~1 of 1.5 bbl over flow of pits on to pad. Notify pad operator of kick taken. Notify Drilling Superintendent. Monitor wellbore pressures Shut in on annular. Cleaned up spill. RU shut in pipe rams to circulate kick out. Observed pressures - string: 430.000 psi, annulus: 1060.000 psi Circulated closed in well at 10160.0 ft Circulate at 2BPM 520 psi . Circulate Drillers method. Casing pressure rapidly decreased from 1060 to 400 psi during the first 400 strokes Circulated Bottom up. No gain. Complete full circulation · Total losses during circulation 19 bbls Influx At surface Monitor wellbore pressures Monitor well . Bleed of both sides. Open up well and monitor. No Flow Began precautionary measures Circulated at 10160.0 ft at 5 BPM and 1400 psi. Obtained clean returns - 100.00 % hole volume BHA run no. 2 R.I.H. to 11734.0 ft Continue to RIH to recover LLCV Began precautionary measures Circulated at 11734.0 ft Circulate bottoms up at 5 BPM 1500 psi. 20:15-03:00 20:15-20:30 20:30 20:30-22:00 22:00 22:00-01:30 01:30 01:30-02:00 02:00 02:00-03:00 03:00 03:00- 03:00-04:00 04:00 04:00-06:00 STATE OF ALASKA [ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate BOP Configuration Change 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [~ Development I--I Exploratory I--I Stratigraphic [--I Service 4. Location of well at surface 3684' NSL, 1992' WEL, SEC. 25, T13N, R10E, UM At top of productive interval 2092' SNL, 392' WEL, SEC. 31, T13N, R11E, UM At effective depth 2428' SNL, 5170' EWL, SEC. 31, T13N, R11E, UM At total depth 2512' SNL, 10' WEL, SEC. 31, T13N, R11E, UM 6. Datum Elevation (DF or KB) KBE = 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-11 9. Permit Number 95-01 10. APl Number 50-029-22541 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 12830 feet true vertical 7355 feet Effective depth: measured 12697 feet true vertical 7285 feet Plugs (measured) Junk (measured) Casing Length Size Cemented MD TVD Structural BKB BKB Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 3424' 9-5/8" 685 sx PF 'E', 250 sx Class 'G' 3455' 2943' Intermediate 11938' 7" 200 sx Class 'G' 11967' 6905' Production Liner 1022' 5" 145 sx Class 'G' 11808'-12830' 6826'-7355' Perforation depth: measured true vertical 12176'-12234',12256'-12310' 7012'-7042' 7054'-7082' ORIGINAL Tubing (size, grade, and measured depth) 2-7/8" 5.46#/ft HS-70CM Coiled Tubing to 11650' Packers and SSSV (type and measured depth) LLCV at 11773'; Baker 'F' Packer at 11778' 13. Attachments [~ Description summary of proposal f--I Detailed operations program [--I BOP sketch 4. Estimated date for commencing operation November 22, 1997 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Bob Laule, 564-5195 15. Status of well classifications as: [~ Oil [--[ Gas I--1 Suspended Service Date approved Omar Nur, 564-5627 Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ch,p~,,ord ~ ~ ~ Title Senior Drilling Engineer Commission Use Only Date l~' Form 10-403 Rev. 06/15/88 I Approval No.~O ,- Conditions of Appro.v, al: Notify Commission so representative may witness _^ Oo9'~ Plug integrity __ BOP Test ~ Location clearance ~99~O~,~e~ _ Mechanical Integrity Test Subsequent form required 10- ~e~ - Uti ~nal 5~gn~u ~ Appr ommission David W. Johnston Commissioner Date Submit I~ g~plicate OBJECTIVE: A remedial rig workover is requested for well MPU E-11 to replace a failed CT deployed ESP. E-11 is a perforated Kuparuk B and C sand producer and the ESP has failed. Surface facility upgrades will be done in conjunction with the workover. Please raise an expensed AFE to fund the downhole work, with a specific AFE sub-component of $100M to fund the surface upgrades. SCOPE: Pre-rig scope: · Punch tubing as deep as possible and run Amerada pressure survey as per Shared Services Drilling. · Install BPV Rig scope: · Circulate well to brine to provide 75 psi overbalance · Retrieve existing coiled tubing deployed ESP assembly · Cut and lay down coiled tubing for disposal · Report any scale or ESP problems on the morning report · Record the number of cable bands lost downhole. · RIH and reverse out cable bands · Retrieve Camco Liquid Level Control Valve LLCV · RIH with slickline to check for fill inside the 5" casing. Document TD tag on daily drilling report. Minimum ID restriction in the 7" casing is a Baker Model FB-1 packer with 4.00" bore at 11,779' BKB MD. Reverse out cable bands and fill from the wellbore as necessary. Note that it is requested to get a TD tag on this well in order to determine ff there has been any formation sand production from the Kuparuk B and C sands. Use MPU kill pill ff losses are encountered. · Run ESP completion with GC 4100 ESP on 2-7/8" tubing and set PHD at +_11,650 ' MD. Set one GLM at _+ 120 ' MD. · Freeze protect well to 2000'MD. RDMO. BACKGROUND: E-11 was drilled in December 1994 and completed with a coiled tubing deployed ESP in February 1995. The ESP shutdown November 25, 1996. The ESP was free flowed for two weeks in February 1997. Attempted to start the well on Feb. 18, but the ESP went down on overload. Electrical checks of the system indicate one phase is grounded and the ESP completion has failed after a 727 day run life. The well produces from the Kuparuk B and C sand and receives injection support from surrounding injectors. ' 3-26-97 ; 13:40 ' BPX-MILr~ POINT~ STATE OF ALASKA ALASKA ,.,IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY. WELL OPERATION8 907 276 7542;# 2/ 2 1. UlCerations perfermed; [] Operation Shutdown L9 ~imulale [] Plugging [3 Perforate 2. Nallle Of Operator BP Exploration (Alaska} InC. [] Pull TuBing [] Alter easing [] Repair Well r-] Other / ~ Day, opine ~ E~lomfo~ ~ ~tratigraphic 3. Addre~,= i=.0, BOX lg6612, Anchorage, Alaska 4, Location of well at surface ................. ~ --. ~ ......... 1~-. ~.~.- _ ~. P~'~t w~l ~nd~mn eumma~ Total de,h: ~evU~d 12830 feet ~l~e (measured) true ve~lcai 7855 f~t E~ive de~; measured 12897 feet JUnk [measured) tree V~oal 728~ feet Datum '{~i~a-t~O-n (DF or KB] KBE - 54; ~',-,- U~-O-?-Frol~-erty Nm'ne '- - Milne Point Unit /' 'Approval' N~', 3~7-001 11. F~ld and Pool Milr~ Point Unit / Kuparuk River 8an~la CMing Length $l=,e Cemented Gudac~ 3~B~' g-~6' cO5 ~x PF 'E', 2BO ex Ol~t IMe~iate 11967' 7" 2~ ;x Class 'a' Pradu~1on Liner 1022' G" 1~ ~ Claes ~G~ MD TVD BKB BKB sO' 80' ~444' 2938' 11~87' 685g' 12830' 7E85' Perforation deFIh: mva~ured 1~.176~-12310' true vedical TulOiqg (az.e, grade, and Paeke~ and gggV (type and ~eaeur~d depth) N/A .... ..: -...~ ~: --.;-..:- .~. :13, 8timulalion or aement squeeze summary Inter/ab tmamd (measured) Treatment deaeriptiw~ including valumee used and final pre~aure 14, Prio~ to well operation: Off-Bbi' - - Ga~,,M~f ....... Wat~r-Bbl Oaeing Prat. sure Tubing Preaeure _~ubsequent lo oper.a, lJ2.n:,.' ~ Cop~we of ~ and 8u~ r~ t ~ ~ Daily qepO~ ~ We~ Oper~ona ~ Oa ~ ~$ ~ Suspended 8e~loe i17, I hereby ~ify ~at~e ~regoing is.~e and eo~e~t ~o 1he b~t of ~ knowle~ Signed ~].~ ~ ~ ~/ . -~s~ ~ ~ ~...~~ .... ~!l.e. Well O~ FO~ 10-404 R~. 0~I ~ 8ubmJt In Duplicate BP EXPLORATION (ALASKA) PRODUCTION ENGINEERING PRUDHOE BAY, ALASKA FAX # (907) 659-4655 ISFX-~I 1 LINE ffglR'l'~ ,. - Message No. TELECOPY LOCATION: FROM: LOCATION: PAGES TO FOLLOW: DATE: ~-~/o~(et/..f 7- 'I'IME: (excluding this cover) ,5' OPERATOR:_ · SECURITY. CLASSIFICATION (BP America Guidelines) Non-Classified Secret Confidential Private IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALl. ONE OF THE FOLLOWING NUMBERS: (907) 659-4654 (907) 659-4660 "BPA NET" 621-4654/4660 ~AC553:6/{)0 · 1- 6-97 ; 1,5'02 · BPX-MII..~ POINT-' t~07 27~d 7-3~t2;~ 2:/ STATE OF ALASKA ,~LASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon . Suspend Al[er [,~slng Repair well Chan.q~ epproved plograrn ... 2. Name of Operator BP Ex, loration (Alaska) Inc. 3, Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Operation Shutdown ___ Re-miter suspend0d well ~ Plug[ling ~. Time emnslun Stimulate Pull tubing Variance ~ P'~rato O~er x 5, Type of Well: 6. Datum elevation (DF'or D~elopment ~ . 54 ExpIomtu~ ~. StmtlFap~c _. 7. Un~ or Propedy name Service ~ Mi/ne Point Unit 4. Location of well at surface 3684' NSL lg92'WEL SEC 25 T13N RIOE At top of productive interval 2092'SNL 392' WEL SEC 31 T13N R11E At effective depth At total depth 2512' SNL I0' WEL SEC 31 T13N R11E -- §. Well number MPE. 11 9. Permit number 95-01 10. APl number 50- 022-22541 11. Field/Pool KupanJk River Pool feet 12. Present well condition summary Total depth: measured true vertical 12,830' fact 7355' feet Effective depth: measured 12,697'pbtd feet true vertical 7286' feet Pluga (measured) Junk (measured) Casing Length Size Structural Conductor 112' 20" Su dace 3455 9 5/8" Intermediate 119.67 7' Production Liner 1022 5" Perforation depth: measured 12,176-12,310 true vertical 695~;.7080 Cemented Measured d~,~ True vertical depth BKB 250 sx arctic set 80 80 685 sx PF "E" 250 sx "G" 3444 2936 200 SX CLASS "G" 11,967 6839 t45 sx Class "G" 12, ~30 7285 ORIGINAL Tubing (size, grade, and measured depth) 2 7/8 COIL TUBING 5.4f//FT 11,650 Packers and SSSV (type and measured depth) NO SSSVOR PACKER 13. Attachments Description summary of proposal -X.-. JAN 0 7 1997 AJaska Oil & Gas Cons. Commission An~,hn~q/'IR Detailed operations program BOP sketch 14, Estimated date for commencing operation 16. If proposal was verbally approved Name of approvar Date approved 15. Status of well classification as: Oil ×_ Gas__.. Susponded .~ Service 17. I h~reby ce~lify that the foregoing is true and correct to the best of my knowledge. "-" ' FOR COMMISSION USE ONLY Condition8 of approval: Notify Commission so represontatlve may wilness Plug integrity ..... BOP Test Location clearance ..... Mechanical Integrity Test ~ subsequent form required 10- ~01,¢ i Approw, ,o..?,¢' 7 / Approved by order of the Commission Form 10-403 Rev 06/15/88 David W. Commissioner Apprr>v:;:..'! r-3Ot:Y Returne6 / ._. ,SUBMIT IN TRIPLICATE Memorandum To: Blair Wondzell/AOGCC o.t.: 1/2/97 Fro,,,: Jerry Bixby/MPU Well Ops Application. for Sundry, for E-11 Annular Vent Attached you will find our application for Sundry approval and two drawings for our proposed annular vent system. The sole intent is to bleed IA gas into the production tree and down the flow line. Figure Cf1 will be the most common used with Figure #2 used if room permits in our well houses. Every effort will be made to put the Actuated valve as close as possible to the manual annulus valve. After talking with Bobby Foster on 12/30/96 Milne Point plans on getting a vent system built and put on well E-11. We will invite all inspectors out to take a look at the system when it is installed. We appreciate you help and considerations in this manner. Bixby MPU Well OPS Coordinator 0 o 1997 Alaska Oil & ~ Cons, Commission Ancttorage · 1- 3-87 ' 9:08 ; BPX-~ILNE ?OINT~ Propos=d annular vent:Figure #1 Notes: The hydraulic control pressure for the SSV would be tapped to supply pressure to the annular vent actuator, Both actuators would then trip simultaneously if needed closing in the well. ~07 276 2" welded pipe Check valve ,~/ SSV Annular vent actuator fiFX-IVlI-'OC ; 1- B-87 ; B:OB ; BE×-MILINE EOIN'I~ ~0¥ 2YO '/~2;g o/ o Proposed annular vent:Figure #2 Notes: The hydraulic control pressure for the SSV would be tapped to supply pressure to the annular vent actuator, Both actuators would then trip simultaneously if needed closing in the well. 2" welded Check valve jSSV Annular vent actuator P E R N I T aa 5 ..... 00 '1 6725 z-,'~r~ 'i 208 S "~ i 2790 R L L /G R r,,/' E W R / R "-",.. F:' ~ >f 'i C' 8 ./' 0.. ©~. / ~:.q 5 9 S '" 00 '~ D ,s :' / --- ' "' .. ......... ri, EWRA ~12'i20 128'i8 HD 'i 0t~/0~:/ 9 9S'~001 C'6R/EWR4 ...~6983-7355 'i (')8/02/95 ~.. 3500~.-i2800 9,~: .... 0 0 '/ T',/D/GR ~ 3000 .... 7300 Ar'e dr'y d'¥'tch samp'ies r'.equ'¥r'.ed? yes ~And Was ~he wei i cor'ed? yes ~ Anaiy:'¥s &. descr'Spt'¥on r'ece'¥ve,J'? ._~° Are ~>/e i i tests r'-equi: r'ed? yes ~ Race'i: red? II We J i -¥5 -¥n comp J 5aj--~ce ...... i n ~ t '¥ a 'i ' .~~~ ' ~ _~.~~.~ ~.7~Z6= ............... ~ ............. ~ ...................... :~?_Z.~: ...................... ~_L~ A ~ ..... ~_.=~_a_._~_~:~ ....................................................... :~l~/r~ ........................ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Comervation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 August 1, 1995 RE: MWD Formation Evaluation Logs - MP E-11 AK-RB-950105 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 1 Blueline 1 Folded Sepia 1 Magnetic Tape w/LDWG Lis~~j~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Schlumberger ~ GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) March 30, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth Corrected MWD GR & MWD GR TVD for well J~, Job # 95096 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 2 Film 1 Depth Shift Monitor Pict State .ofAiaSka A!.aCka Oil & Gas Conservation Comm. ~.ttn: Larry Grant 300,1 Porcupine Drive AnchO'rage....Alaska 99501 1 OH LIS Tape' ........ 1 Blueline each '") 1 RF Sepia each ._.~-~/' OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail P 905 127 803 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: Date Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Received By: ~~,/~/~/? ~~!~'%~ STATE OF ALASKA [ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-01 3. Address 8. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-22541 4. Location of well at surface ........ 9. Unit or Lease Name 3684' NSL, 1992' WEL, SEC. 25, T13N, RlOEi".-.iiii~..~?~-..:~::?i:.;;;?'? !! .... ~'-'~.:.*,:::.~ ~ Milne Point Unit At Top Producing Interval i ";;"-/."i; '~)'" ~ :;;~ .... ~ .... 10. Well Number 2092 SNL, 392 WEL, SEC. 31, T13N, R11E ,:.. ,. ,: MPE-11 -' : 11. Field and Pool At Total Depth -~ ~ ~ ';~"~'~'-*'~-~ '~" -' Milne Point Unit - Kuparuk River Sands 2512' SNL, 10' WEL, SEC. 31, T13N, R11E ~ .~ .. ~' i: ~ % 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 54' ADL 28231 12.1/9/95Date Spudded 13.1/25/95Date T.D. Reached 14.2/2/95Date Comp., Susp. or Aband. 15. Water Depth,N/A iffeetOffshoreMSL 16.oneNO. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 12830' MD/7355' TVD 12697' MD/7285' TVD YES [] NO [] None feet MDI 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/NEU/DEN 23. CASING, LINER AND CEMENTING RECORD SE-I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 3455' 12-1/4" 665 sx PF "E"/250 sx "G" 7" 26# L-80 29' 11967' 8-1/2" 370 sx Class "G" 5" 15# 13CR80 11808' 12830' 6" 145 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 2-7/8", HS-70 11650' None MD TVD 12176-12234' 7012'-7042' W/ ESP 12256'-12310' 7054'-7082' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/22/95 ESP Date of Test Hours Tested IEsT=RODUCTIONpERIOD FORi~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. S~,bmE~t MAR -2 1995 ^l~ska 0il & Gas Cons. Commission Anchora. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 3O. GEOLOGIC MARKERS i-uHMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Top Kuparuk 11772' 6808' TKC l 12158' 7002' TKB7 12265' 7058' RECEIVED MAR -2 ]995 Alaska Oil & Gas Cons. Commission ~rlPhn.~ p 31. LIST OF A-I-rACHMENTS ......... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢ , ("" ~'~'/'~'~,. TitleOrillingEnginoerSuoervisor Date '"~ '~ '~" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MP E-ii BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/09/95 10:00 SPUD: RELEASE: 02/02/95 09:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: 01/10/95 (1) TD: 1375' ( 0) 01/11/95 ( 2) TD: 3259' (1884) 01/12/95 (3) TD: 3475' ( 216) 01/13/95 ( 4) TD: 4112'( 637) DRILLING MW: 0.0 VIS: 0 FINISH MOVING RIG OVER MP E-ii. HOOK UP POWER, BUILD BERMS, AND R/U AIR, WATER AND MUD LINES. R/U DIVERTER AND FLOW LINES. TAKE ON WATER IN MUD PITS. FUNCTION TEST DIVERTER. STRAP, STEAM, P/U AND ORIENT BHA #1. DRILL 12 1/4" HOLE FROM 106 - 1375'. ACCEPT RIG @1000 HRS 01/09/95. DRILLING MW: 0.0 VIS: 0 DRILL F/ 1375 - 1938'. CIRC BOTTOMS UP. SHORT TRIP TO JARS. SHORT TRIP TO JARS. LEVEL RIG. RIH. REAM LAST STAND TO BOTTOM. NO PROBLEMS. DRILL F/ 1939 - 2256' CIRC AND WEIGHT UP TO 10.0 PPG. DRILL F/ 1938 - 2315'. GAS CUT MUD. CIRC AND INCREASE MUD WT TO 10.3 PPG. DRILL FROM 2315 - 2391' GAS CUT MUD TO SURFACE. CIRC AND INCREASE MUD WT TO 10.5 PPG. DRILL FROM 2391 - 2599' CIRC BOTTOMS UP. SHORT TRIP 10 STANDS. NO PROBLEMS. DRILL F/ 2599 - 3259'. R/U TO PUMP TOP JOB MW: 0.0 VIS: 0 DRILL F/ 3259 - 3475'. CIRC BOTTOMS UP. SHORT TRIP TO HWDP. NO PROBLEMS. CIRC AND CONDITION MUD TO RUN CASING. POH TO RUN 9 5/8" CASING. LD BHA. CLEAR RIG FLOOR, CHANGE BAILS AND R/U TO RUN CASING. RUN 86 JTS 9 5/8" 409 L-80 BTC CASING SHOE @ 3455'. CIRC AND COND MUD. NO LOSSES. TEST LINES. DROP TOP PLUG. BUMP PLUG. FLOATS HELD. L/D LANDING JT AND N/D 20" DIVERTER. R/U HOWCO TO PUMP TOP JOB. DRILLING MW: 0.0 VIS: 0 MIX AND PUMP 150 SX TOP JOB. INSTALL SPEED HEAD AND TEST. N/U 13 5/8" 5M BOPE. MODIFY FLOWLINE. INSTALL TEST PLUG AND TEST BOPE. PULL TEST PLUG AND INSTALL WEAR RING. SERVICE TOP DRIVE. LOAD RIG FLOOR W/ BHA AND STEAM SAME. M/U BHA #2, ORIENT AND TEST MWD. P/U "E" DP AND RIH TO FC. TEST CASING, OK. DRILL FC, CEMENT, FS AND 10' NEW FORMATION TO 3485'. CIRC BOTTOMS UP. RUN LOT. DID NOT BREAK DOWN FORMATION. DRILL 8 1/2" HOLE FROM 3485 - 4112'. RECEIVED MA~ -'2 1995 A!aska Oil & Gas Cons. Commissio~ Anchora ¢, WELL : MP E-ii OPERATION: RIG : NABORS 22E PAGE: 2 01/14/95 ( 5) TD: 6000'(1888) 01/15/95 ( 6) TD: 7070' (1070) 01/16/95 ( 7) TD: 9490' (2420) 01/17/95 ( 8) TD:10894' (1404) 01/18/95 (9) TD:l1781' ( 887) 01/19/95 (10) TD:11985' ( 204) SHORT TRIP MW: 0.0 VIS: 0 DRILL F/ 4112 - 4770' CIRC BOTTOMS UP. SHORT TRIP TO CASING SHOE. BACK REAM F/ 4488 - 4207'. RIH. REAM F/ 4107 - 4488'. CIRC BOTTOMS UP. R/U WESTERN ATLAS AND GYRO DATA. RUN GYRO. R/D. DRILL F~ 4770 - 6000'L, CIRC BOTTOMS UP. SHORT TRIP TO 4110 . BACK REAM w/ 4960 - 4110'. DRILLING MW: 0.0 VIS: 0 CHECK MWD SURVEY WITH GYRO. RIH. NO PROBLEMS. DRILL 8 1/2" HOLE F/ 6000 - 6947' CIRC SWEEP AROUND. MONITOR WELL. PUMP PILL. POH. WORK THRU TIGHT SPOTS F/ 6567 - 6000' LD MOTOR. MU NEW 8 1/2" 417G BIT AND 7 1/4" TURBINE AND RIH WITH BHA. TEST MWD AND SERVICE TOP DRIVE. RIH. PU 30 JTS "E" DP. IN HOLE REFERENCE WITH MWD @ 4110'. NO HOLE PROBLEMS. DRILL 8 1/2" HOLE WITH TURBINE F/ 6947 - 7070'. DRILLING MW: 0.0 VIS: 0 DRILL 8 1/2" HOLE WITH TURBINE F/ 7070 - 8584' CIRC BOTTOMS UP. MONITOR WELL. PUMP PILL. SHORT TRIP TO CASING SHOE. TIGHT SPOTS @ 6423, 6340, 6250 AND 5640' RIG. NO PROBLEMS. DRILL 8 1/2" HOLE WITH TURBINE F/ ~584 - 9490'. DRILLING MW: 0.0 VIS: 0 DRILL 8 1/2" HOLE WITH TURBINE F/ 9490 - 9905' CIRC BOTTOMS UP. MONIOTR WELL. PUMP PILL. SHORT TRIP TO 8580' NO PROBLEMS. SERVICE TOP DRIVE WHILE QUADCO INSPECTED SAME. RIH. NO PROBLEMS. DRILL 8 1/2" HOLE WITH TURBINE F/ 9905 - 10894'. DRILLING MW: 0.0 VIS: 0 DRILL 8 1/2" HOLE W/ TURBINE F/ 10894 - 11321'. CIRC BOTTOMS UP. MONITOR WELL. PUMP PILL. SHORT TRIP TO 9430' TIGHT SPOT @ 10820 - 10650'. RIH. DRILL 8 1/2" HOLE ~/ TURBINE F/ 11321 - 11781 CIRC AND CONDITION MUD MW: 0.0 VIS: 0 DRILL 8 1/2" HOLE W/ TURBINE F/ 11781 - 11790' CHANGE OUT WASH PIPE. DRILL F/ 11790 - 11985'. CIRC SWEEP AROUND. MONITOR WELL. PUMP PILL. POH TO CASING SHOE. TIGHT SPOTS @ 11506 - 11413', 11132 - 10944', 10755 - 10700', 7922 - 7732', 5183 - 5145' SLIP AND CUT DRILLING LINE. SERVICE TOP DRIVE. CIRC AND CONDITION MUD TO RUN CASING. PUMP LO/HI VIS SWEEP AROUND. RECEIVED MAR -2 1995 Oil & Gas Cons. Commission Anchora ,-~ WELL : MP E-Ii OPERATION: RIG : NABORS 22E PAGE: 3 01/20/95 (11) TD:11985' ( 0) 01/21/95 (12) TD:11985' ( 0) 01/22/95 (13) TD:12029' ( 44) 01/23/95 (14) TD:12486' ( 457) RUNNING 7" CSG MW: 0.0 VIS: 0 CIRC AND CONDITION MUD TO RUN 7" CASING. MONITOR WELL. PUMP PILL. POH. LD BHA. PULL WEAR RING. CHANGE TOP RAMS TO 7" AND TEST SAME. R/U 7" CASING TOOLS. RUN 7" 26# L-80 NSCC CASING. TOTAL OF 225 JTS OUT OF 290 RUN IN HOLE. CIRC B/U @ SHOE WITH NO MUD LOSSES WHILE CIRC OR RIH. PU 3 1/2" DP MW: 0.0 VIS: 0 FINISH RUlVNING 290 JTS 7" 26# L-80 NSCC CASING. SHOE @ 11967'. CIRC AND COND MUD TO CEMENT. NO MUD LOSSES. TEST LINES. OPENED CEMENTER. CIRC BOTTOMS UP. PUMPED 200 BBLS WITH NO LOSSES. PUMP 75 BBLS WATER, 70 BBLS ALPHA SPACER, MIX AND PUMP 200 SXS "G" @ 15.8 PPG. PUMP 5 BBLS WATER AND DISPLACE WITH RIG PUMPS. BUMP PLUG. FLOATS HELD. LD LANDING JT, CLEAR RIG FLOOR AND CHANGE BAILS AND ELEVATORS. PU STAND OF 5" HWDP AND RIH WITH PACKOFF. INSTALL SAME AND TEST. CHANGE OUT BRAKE BANDS AND 3 1/2" RAMS. CHANGE TOP FRIVE TO 3 1/2". INSTALL TEST PLUG AND TEST BOPE. PULL TEST PLUG AND INSTALL WEAR RING. STEAM, CALIPER AND STRAP BHA. PU 3 1/2" DP AND RIH. DRILLING MW: 0.0 VIS: 0 PU 3 1/2" DP AND RIH TO ES CEMENTER @ 6975' DRILL ES CEMENTER. CIRC BOTTOMS UP. PU 3 1/2" DP AND RIH. REPAIR BUSTED HYDRAULIC HOSE ON SKATE. CONTINUE PU 3 1/2" DP AND RIH. TAG LANDING COLLAR @ 11881' TEST CASING. DRILL LANDING COLLAR, FLOAT COLLAR, FLOAT SHOE AND 10' NEW FORMATION TO 11995'. CIRC AND WT MUD UP TO 11.8 PPG. RUN LOT WITH 11.8 MUD. BROKE DOWN. DRILL FROM 11995 - 12029' DRILLING DRILL 6" HOLE FROM 12029 - 12486' MW: 0.0 VIS: 0 01/24/95 (15) TD:12664' ( 178) 01/25/95 (16) TD:12800'( 136) RUNNING WIRELINE LOGS MW: 0.0 VIS: 0 DRILL 6" HOLE FROM 12486 - 12542' CHANGE OUT WASH PIPE. DRILL 6" HOLE FROM 12542 - 12664' PUMP LO/HI VIS SWEEP AROUND. BACK REAM 8 STANDS TO SHOE, NO PROBLEMS. CIRC BOTTOMS UP. MONITOR WELL, PUMP PILL. POH TO RUN LOGS. RU ATLAS TO RUN LOGS. RUN #1 TRIPLE COMBO - GR/RES/NEU/DENS. WORKED LOGGING TOOLS BUT COULD NOT GET GELOW 12184' POH TO RUN SPERRY SLIM TOOL OR DRILL PIPE CONVEYED TOOLS. DRILLING MW: 0.0 VIS: 0 POH WITH TRIPLE COMBO. RUN #2 GR/RES. COULD NOT GET BELOW 12190' POH AND RD ATLAS. MU BHA #5 WITH SPERRY'S GR/RES TOOL AND TEST MWD. RIH TO 12120' MAKE LOGGING PASS FROM 12120 - 12420'. DRILLING F/ 1266~ - 12800' RECEIVED Alaska Oil & I~as Cons. Commission A~chora ,- WELL : MP E-Ii OPERATION: RIG : NABORS 22E PAGE: 4 01/26/95 (17) TD:12830' ( 30) 01/27/95 (18) TD:12830' ( 0) 01/28/95 (19) TD:12830' ( 0) 01/29/95 (20) TD:12830' ( 0) 01/30/95 (21) TD:12830' ( 0) LD BHA MW: 0.0 VIS: 0 DRILL 6" HOLE F/ 12800 - 12830' CIRC AND PUMP HI/LO VIS SWEEPS. SHORT TRIP 10 STANDS. MAD PASS 12770 - 12450', NO PROBLEMS. CIRC AND CONDITION MUD. POH 10 STANDS. NO PROBLEMS. SERVICE TOP DRIVE WHILE WAITING ON WEATHER. RIH, NO PROBLEMS. CIRC AND CONDITION MUD. PUMP PILL. DROP RABBIT. POH. SLM. LD BHA. NO CORRECTION IN STRAP. CEMENT LINER MW: 0.0 VIS: 0 FINISH LD BHA. DOWN LOAD LWD. CLEAR FLOOR. RU LINER EQUIP WHILE PROCESSING LOG DATA. PU AND RIH W/ 23 JTS 5" 15# 13 CR FL4S LINER. MU BAKER HANGER AND PKR. RIH W/ LINER TO SHOE ON 3 1/2" DP, FILL PIPE EVERY 10 STDS. BREAK CIRC. MU DP MANIFOLD. RIH W/ LINER TO 12830'. NO FILL OR TIGHT HOLE. CIRC AND CONDITION MUD FOR 3 ANNULAR VOLUMES. HAD PROBLEMS W/ PACKING OFF. FINAL CIRC RATE. TEST LINES. PREP TO TEST BOP MW: 0.0 VIS: 0 FINISH LINER CEMENT JOB. BUMP PLUG AND PRESS DP TO SET LINER HANGER AND PKR. RELEASE FROM HANGER. POH W/ 15 STDS DP. PUMP PILL. CONTINUE POH. SERVICE WEAR BUSHING. CLEAR FLOOR. MU BIT AND SCRAPER. RIH TO 5000'. CUT AND SLIP DRLG LINE. ADJUST BRAKES. RIH TO 11450' BREAK CIRC. WASH TO TOC @ 11525'. DRILL HARD CEMENT TO 11610' WASH TO 11694' DRILL RATTY CEMENT TO TOL AT 11808' cIRc AND CONDITION MUD, PUMP PILL. BLOW DOWN LINES. POH. PULL WEAR BUSHING. INSTALL TEST PLUG. FILTER BRINE MW: 0.0 VIS: 0 RU TO TEST BOPE. TEST BOPE. RD BOP TEST EQUIPMENT. BLOW DOWN LINES AND CHOKE MANIFOLD. RU 2 7/8" EQUIPMENT. PU AND RIH W. BHA. RIH W/ BHA ON 3 1/2" DP TO TOL AT 11808' DRILL OUT 10' CEMENT IN TOP OF LINER. WASH AND REAM TO 12649' DRILL OUT HARD CEMENT F/ 12649 - 12697' CIRC AND CONDITION MUD. BLOW DOWN TOP DRIVE. TEST CSG AND LINER LAP. PUMP H20 AND SWEEPS, DISPLACE WELL TO 11.8 BRINE. ROTATE AND RECIPROCATE PIPE. CIRC AND FILTER BRINE. CORRELATE PERF GUNS MW: 0.0 VIS: 0 CIRC AND FILTER BRINE. MONITOR WELL. PUMP PILL. DROP RABBIT. POH. LD BHA. CLEAR FLOOR. RU TBG EQUIP. PU AND RIH W/ ATLAS TCP ASSY, 2 7/8" TBG, HALLIBURTON PKR ASSY AND 3 1/2" DP TO 12310'. RABBIT ALL EQUIP. CHANGE BAILS. RU ATLAS WL. RIH W/ 1 11/16" GR/CCL TO CORRELATE DEPTHS RECEIVED --2 1995 Oil & t~as i~o~s. ~;omm/ssion WELL · PiP E-Ii OPERATION: RIG : NABORS 22E PAGE: 5 01/31/95 (22) TD:12830' ( 0) 02/01/95 (23) TD:12830' ( 0) 02/02/95 (24) TD:12830' ( 0) 02/03/95 (25) TD:12830' ( 0) POH W/ TCP GUNS MW: 0.0 VIS: 0 FINISH WL CORRELATION. RD ATLAS. SPACE OUT GUNS. RU HALLIBURTON AND BJ. TEST ALL LINES. SET PKR. OPEN BYPASS. DISPLACE DP W/ N2. SET PKR. PRESS ANNULUS. PRESSURE DP TO FIRE GUNS. MONITOR PRESS. OPEN BY PASS. REVERSE OUT N2 TO TEST TANK. CIRC CONVENTIONAL THROUGH RIG CHOKE. MONIOTR WELL. LET N2 F/ RAT HOLE MIGRATE. CBU THROUGH CHOKE. MONITOR WELL. STATIC. RELEASE PKR. LD 1 JT DP. CIRC WELL THROUGH FLOW LINE TO REMOVE N2. MONITOR WELL. STATIC. CHANGE BAILS. BLOW DOWN LINES. PUMP PILL. POH SLOW TO 2000' CIRC TO REMOVE N2 MIGRATING F/ GUNS. BLOW DOWN LINES. POH. TEST RBP MW: 0.0 VIS: 0 FINISH POH. LD DC'S AND HALLIBURTON CHAMP PKR ASSY. LD 2 7/8" TBG AND TCP GUNS. ALL SHOTS FIRED. CLEAR FLOOR. MU BAKER FB-1 PKR. RIH W/ PKR ON 3 1/2" DP. TAG TOL @ 11808' SPACE OUT PKR 30' ABOVE TOL. DROP BALL AND PUMP SAME D~WN. SET PKR @ 11778'. CBU TO REMOVE N2. PUMP PILL. BLOW DOWN LINES. STD BACK 49 STDS DP. CONTINUE POH LD 3 1/2" DP AND SETTING TOOL. MU AND RIH W/ BKAER WL RETRIEVABLE BRIDGE PLUG TO 4490' DROP BALL. PUMP DOWN SAME. TEST RBP. LD 5" DP F/ DERRICK MW: 0.0 VIS: 0 FINISH POH LD 3 1/2" DP TO 2015' DISPLACE WELL AT 2015' W/ 75 BBLS DIESEL. POH LD REMAINING DP. CLEAR FLOOR. PULL WEAR BUSHING. INSTALL FALSE BOWL AND BPV. CHANGE RAMS TO 5" ND BOPE. NU HOLD DOWN FLANGE AND 2 7 1/16" FMC VALVES. TEST FLANGE. CHANGE IRON ROUGHNECK AND TOP DRIVE TO 5" PULL BPV. TEST CSG AND TREE. INSTALL BPV. SECURE WELL. INSTALL MOUSE HOLE. LD 5" DP F/ DERRICK. RELEASE RIG MW: 0.0 VIS: 0 FINISH LD HWDP F/ DERIICK. RD MOUSE HOLE. RELEASE RIG @ 0900 HRS ON 02/02/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED lAt:i .... 2.. 1995 Oil & t~as Cons. (;ommission Anohor~ -- PAGE *****'.+*** ANA~ILL ********** ********* SCHLUMBErgeR ***.******~ ********* ****~**** *************************************************** COMPANY BP WELL NAME MPE- 11 LOCATION 1 MILNE F13INT LOCATION 2 ALASEA MAGNETIC DECLINATION 28.?9 GRID CONVERGBqCE A~]LE 0.00 DATE: 09-JAN-~5 WELL NL~B~ 0 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FROM ROTARY TABLE TO TARGET iS TIE IN POINT(TIP) : MEASAMED DEP~ 0.00 TRUE VERT DEPTH 0,00 INCLINATION 0.00 AZIMUTH 0~00 LATITUDE(N/-S) 0.00 DEPAR~ORE(&Z-W) 0.00 DF2(EY-W) 0,00 129,00 ************* ANADRILL ************~ ~RV~ CAI..C1]I~TION$ ************* CIRCULAR ARC METHOD******** TARGI=:T S%ATION AZIMUTH LATITUDE SECTION INCLN, bl/-S ft deq deo ft 0,00 0,00 0,00 0,00 0,13 0,49 20i,96 -0,40 0,41 0,48 ,o' ~ ,-,~.,c.,_ -1,19 0,61 0,48 213,~ -1,95 0,48 0,62 237,31 -2,59 bEF'ARTURE DI:PLACEM£NT st E/-W ft ft 0,00 -0,!6 0,43 -C,,44 1 ,~'~ -0,79 2,t0 -1,48 AZIMUTH 0,00 ~ .. 200,27 202,H 209,71 DLS de.~ l(X~ft 0,49 0,03 0,!3 0,27 500.00 10,0.0 499,98 600,00 100.0 5'~.97 700,00 t00.0 699.97 800.00 100,0 799,96 900,00 100,0 899,9~ 0,25 0,67 224,66 -3,30 0.16 0,59 223,54 -4,09 0,i5 0,~ 215,87 -5,02 0.94 0,99 159,04 -6,40 3,01 !,62 149,t5 -8,42 z2,34 4,04 -3,11 5,13 -3.97 7.53 -2,94 8,92 215,40 217,27 A~ 2!7,.~ 211,84 t99.24 0,15 0,08 0,23 0,87 0,~7 lo00,00 1100,00 12®,00 1300,00 I00,0 999,85 100,0 1099,~ 100,0 1199,14 I¢YJ,O 100,0 1~6,82 6,79 2,85 138,68 -11,50 -0,57 11~.51 13,33 4.70 13!,77 -16,09 4,13 16,61 23,24 6,./-8 126,12 -22,25 11,88 25.23 36,44 8,54 !24,01 -~,84 ~,73 37,51 53,~5 10,83 117,81 -~,37 37,20 53,45 182,85 165,A. 2 151, 142,69 1.35_, 1,29 1,?0 2,06 1,88 2,51 !500,O0 1600,00 i700,00 1900,00 lC~,O 1494,66 100,0 !591,52 !00,0 1,~-7,31 100,0 1782,26 100,0 1876,01 73,39 13~02 119,48 -~,30 97,92 15,72 121,05 -60,83 i26,37 17,62 122,46 -75,95 157,51 18,95 121,45 -92~54 192,10 2!,78 124,19 -111,44 55,32 73,44 131,12 2,22 /.,74 97.~2 128,41 2,73 101,!1 126,46 126,91 1,94 127,74 157,74 125,~ 1,37 156,94 192,48 125,38 2,99 200t.;,o0 2100,00 2200,00 2300,00 2400,00 100,0 1967,68 100,0 2¢~6,58 100,0 2142,82 100,0 2227,06 100,0 2308.7! 231,~ 25.,2~ 128,00 -135,02 277,69 29,18 128,55 -1~,37 328,28 31.64 131,82 -196,06 382,12 33,~ 131,13 -231.74 4~,77 36,92 131,87 -269,99 189,13 232,38 125,52 3,81 225,03 278,08 125,98 3,91 263.65 328,56 126,64 2,94. 304,03 382,28 127,~ 347,24 439.55 127,87 3.37 2500,00 2600,00 27O0,® 2800,00 2900,00 1~),0 2387,09 I00.0 2461.82 100,0 2532,33 100.0 2598,76 lC~,O 2&61,37 501,76 39,65 132,39 -31!,65 567,92 43,43 135,51 -357,79 636,32 46,67 135,94 -408,55 712,47 49,87 136,46 -462,49 789,58 s2,60 138,J. -519,90 393,28 501,79 441,05 567.93 490.53 6~8,38 542,25 712,70 594,~ 790,14 125 12~,05 129,79 !30,46 131,i5 2,95 4,14 3.45 3,03 3,11 3000,00 3100,00 ~O0,00 3400.00 100,0 27:.,12 I(D,0 t00,0 2824,92 100,0 28,72,25 lC~.O 29t8,13 869,80 55,45 134,60 -578,53 650,73 870,72 953,34 58,43 !3~,15 -6~5,05 711,&6 954,47 1039,71 61,23 130,50 -693,12 776,59 1040,91 1127,80 62,~ 1~7,77 -748,71 844,91 1128,91 !216,59 ~.09 126,02 -802,04 915,97 1217,49 131.64 131,79 131,~ 131,55 131.21 4,17 3.62 3,14 2,63 !,75 3450.cX) 3470,00 3510,~ 3540,00 3570,00 50,0 ?B40,96 20,0 2950,i0 40,0 2968,13 30,0 2981,61 30,0 2995,18 1261,04 62,58 127,80 -828,75 1278,81 ~,03 125,98 -839,43 13!4,48 ^3,38 1~.,84 -860,62 !341,26 ~3,22 126,70 -876,67 1368,00 62,W¢ 127,00 -892,71 951,54 1261,85 965,77 t279,59 994,50 1315,18 1015,97 1341,92 1037,3~ 156~,61 131,05 131,00 130,87 130,79 130,71 8,40 2,11 1,18 ******..~ea*** ANADRILL **.*******.***** S~¥~ CALCULATIONS ************* CIRCULAR ARC MEASURED DEPTH ft 3630,00 3660,00 36.,?0 3720,00 INTEE~L VERTICAL DB~TH ft ft 30,0 3008,81 30,0 3022,35 30,0 3035,~ 30,0 3049,34 -30,0 TARG~ STATION AZIMUTH LATITUDE SECTION INC~, N/-S ft de9 deo.. ft 1374,7! 62,?8, I77,00 -70~,80 1421,47 o3,.o 127,20 -924,':/5 1448,~5 63,23 127,44 -941 1475,03 63,22 127,54 -957,50 !501,73 62,63 127,b'5 -?73,77 I)EPAR?URE DIS~'LAC~MENT at ft ft !058,7S !395,28 1060,06 1422,00 1101,37 1448,7~ 1122,64 1475,51 1143,82 1502,19 AZIMUTH deo t3Q,64 130,56 13Q,52 130,46 130,41 lOOft 0.09 1.40 0,84 0,32 t.97 3750,00 3810.0C. 3840,00 3870.00 .30,0 3076,74 30,0 3C80,~? ~,0 3104,07 ~,0 3117,72 30,0 3131,?1 1528,~ 62,64 127,70 -~0,05 1555,I0 63,02 127,88 -1006,42 1581,80 62,76 12~,01 -I0~,64 1608,40 62,21 128,38 -1039,27 1634,94 62,20 12~,60 -1055,85 116~,94 1528,~2 1~?.36 1186,05 1555,51 130,32 1207,1! 1582,19 130,28 1228,02 1608,78 130.24 1248,77 1635,31 130,21 0,83 0,81 2,14 1,24 3~?0,.00 ~30,00 3760,00 3990,00 4020,® 30,0 3145,95 30,0 3160,16 30,0 3188,85 1661,45 61,?? 12~,37 -1072,56 I687,67 6i,4B 129,58 -1087,36 1714,22 61,42 127,76 -11(~,1B 1740,56 61,41 129,75 -1123,03 1766,91 61,45 129,64 -1139,86 1269,34 1661,81 130,20 1289,74 1688,23 130,17 1310,02 1714,59 130,18 1330,28 1740,93 1~),17 1350,55 1767,27 130,16 i,82 1,81 0,36 4050,00 4080,00 4142,26 4~ O~ 4329,03 30,0 32t7,56 62.3 ?0,7 ~6,37 96,t 3353.91 1793,~ 61,37 12B,69 -1156o49 1817,56 61,17 129,00 -1t72,?? 1674.06 61,04 129,77 -1207,58 1953,18 60,48 130,59 -1258,63 2036,64 .,~,20 130,47 -1312,89 1370,97 1793,61 130,15 1391,46 1819,91 130,13 1433,59 1874,41 1~),11 1494,05 1953,55 [30.11 1557,51 2037,03 1~3,13 2,79 !,12 1,10 1 0,31 4515,59 4~)9,54 470t,53 4600,C~ 94,0 3400.~ 92,6 3444,23 ~,9 o487,4/ ?2,0 ~30,43 98,5 :677,05 2118,36 60,65 129,46 -1365,38 2199,85 62,69 I27,03 -1416,94 2283,25 ~" - .~,4y 128,59 !469,21 2~,4,~D 61,83 129,43 -1520,41 245!,38 61,68 1~,43 -1575,54 1620,15 2118,76 130,12 1663,26 2200,25 130,07 1748,25 2283,63 130,04 1811,46 ~64,96 130,01 1878,50 2451,75 1,05 0,47 1,08 0,i5 4894,72 4990,i0 5083,88 52~,20 94,7 36-22,20 ?5,4 ..%6'7,41 93,8 3710,51 94,4 3753,44 89,9 37?4,60 2534,5? 61,35 130,36 -1628,?1 2618,56 62,06 128,87 -1682,45 2701,85 63,22 129,44 -1735,04 2785,96 62,7! 130,23. -1788.93 ~86_,85 62,78 12~,14 -1839,94 1942,34 2534,?6 129,78 2007,04 2618,94 127,97 2071,62 2702,22 129,75 2136.,~ 27_A6.,0~ 2197,70 2866,23 I29,94 1,56 1,35 0,?2 5364,36 5459,16 5~4..04 5648,37 5744,45 y6,~ .3838,74 94,6 S~82,53 94°? 3~'26,05 94,3 3968,64 96,1 .4012,11 2951,27 62,58 1~,26 -1874,51 3035,~ 62,40 I2~,58 -1947,?0 3119,66 63,00 128,07 -2000,19 3203,82 63,31 129,28 -2052,78 3289,49 62,~ 128,~ -2106,67 ~63,43 2~51,66 2328,38 3035,73 1~','~ 2394,53 3120,02 129,87 2460,23 3204,16 2526.84 32~9,~ 1,06 1,58 0,80 1,!9 0,73 5839,68 5?32 ~A 6027,69 6122,26 62~,06 95,2 40~5,63 95,1 4142,35 94,6 4186,,~ 3374,20 62,74 129,01 -2159,79 3456,72 a .... ~ .:,o2 1~8,6. -22!1.53 3541,01 62,15 129,20 -2264,48 3624,45 61.73 130,78 -~18,11 3712,22 61,56 131,20 -2375,72 2592,83 3374,53 2657,I1 3457,04 129,77 2722,69 3541,31 129,75 2786,63 3624,77 129,76 2852,72 3712,57 127,79 0,37 0,71 1,54 0,41 ************* CIRCL%AR AB.{: METHOD******** MEASURED INTERVAL VERTIF~L DEPTH DEP.~ ft ft ft 6310,66 ~,6 4275,0? 6407,4! ?6,7 4318,33 64.'v?,t9 91,8 4359,62 6595,~ 96,4 4403,31 6691,76 "Y6,~ 4447.34 TAF~ET STATION AZ!MLr~H LATITUDE SECTI~ INCLN, Tt deq dea ft o~~n.~n¢,...~. ~A3,53 130,24 -2427,0~ 3877,33 63,37 1~,28 -2482,93 3~59,29 A3.iA 129.50 -~,50 4045,16 62~93 130,?0 -2590,94 4130,67 62,5~ 130,03 -~*A DEPARTURE r ..... c~ '~ ,_,I.:~ LA,~.M~NT at E/-W ft ft 2¥1~,~0 379!,.17 2?78,55 3877.7~ 3041,45 3959,70 3107,05 4045,58 017~,13 4!31,11 AZIMUTH 129,50 129,81 129.82 129,82 129.84 deo/ tOOft 2,43 0,17 0.79 t,31 0,87 6785.64 .~79,70 $792,16 7083,48 7172,34 ~.9 4490,43 !l.'.J 4585.71 ?1,3 4628,44 8~,9 4670,34 4214.07 62,78 l:~O,O1 -2700,09 4297.61 62,56 130.58 -2754,13 4397,24 62,24 t~,13 -2818,67 4477,~ 61,77 130.17 -2870,71 ~,.., £~ .. ~' ~,- ~36,00 4214,52 129,84 0,21 3299,73 4298.08 129,85 0,55' 3375,67 4397.74 129.86 0.46 3437, ~,., ~4478,44 129,~~ ,. 0,30 3497,14 4556,80 129,87 0,34 7267,45 7361,i5 7455.20 7549,76 7643,91 95,1 4715.62 ~,7 4760,45 94,0 4805,25 94,6 4850,!8 94,1 48~,08 46~,89 61,38 130,34 -2975,57 4722,15 61,47 13~,16 -~28,73 4804,8J 6i,64 128.23. 4888,03 61,62 128,25 -3132.49 4970,78 61,41 128,20 -3183,69 3560,85 4A40,44 129 3623,65 4722,72 129,89 '~A7,73~, .,-_. 4805,40 129,58 3753,08 48~,57 t~,85 3818,09 4971.29 129~82 0,41 i,82 0,04 0.~ 7738,48 7832,?7 7927,5i 8021,12 8!!4,14 94,6 4940,48 94,5 4986,01 94,6 5031,65 93,5 5076,69 '~,0 S121,47 5053,73 6!,21 128,44 -32~,13 5136,53 61,1~ 12~,73 -~28,,34 52t?,43 61,16 125.¢,49 -~340,20 5362,91 61,~ !~',67 -3442,86 3883,18 ~r,~ z~ 3947,45 5137,02 129,79 4011,:32 52i9,92 129,78 4075,12 5301,~ ~ 129,77 4138,52 5383,3~ !29.76 0,31 1,19 0 ~q !,17 t,34 8208,36 8396,74 8493,62 8588,82 94,2 5!66,90 ?4,5 5212,59 73,? 52~,73 96,9 5.304,10 95,2 5348,87 5465,44 61,14 129,76 -3495,62 5548,20 6I,~ 128,~ -3548,06 56~,,48 61,44 129 ~ ,~. -~'~,93 5715,54 6!,37 !Z7,97 -3653,01 57?9,54 62,52 ' ~ ~ ~2~,5~ '3705,02 4202,02 5465,92 12r,/. 4266,03 55,48,67 129,75 4~9,91 5630,95 !29,74 4396,58 571,5,00 129,72 4462,35 57??,98 129,70 0,11 0,53 t,15 !:31 8681,78 8776,8~ 8?64,9? ?060.09 ~,1 5436,0? '~,4 5478.70 95,7 5522,40 95,1 5565,72 ~o81,94 ~? 34 129,56 -3756,93 5966,15 62,28 127,64 -3809,46 ~048,17 62~83 128.~ -3859.81 61~,26 62,81 128,06 -3912,30 5217,72 62,?? 127,2~ -3965,16 4526, ~.. 5882 ,37 129,A?. 4592.16 5966,57 129,68 4656,93 6048,56 129.65 ~ ' ~ A~ 129,63 4790,05 6218,28 129,62 1,79 0,74 0,02 1,10 '~ ~ O ~1~6,2., ~4~,27 934!,46 9435.01 96,2 5609,44 93,0 5651,68 92,2 56~,68 ~,6 5736,78 92,1 5779,51 ,.~3,60 62,94 127,69 -4019,61 6386,43 63,03 1~,~ -4072,34 6468,50 62,77 129.58 -4124,53 655!.52 62,37 127.86 -4176,47 · 6634,25 63,01 129,40 -4228,12 4856,21 6303,?6 129,62 4920,08 6386,80 129,61 4983,42 6468,87 129,61 5048,20 6551,88 129,60 5112,82 6634,60 12'7,5'7 0,44 1,62 .~4.61 9720.10 9814,E4 '~07,33 10003,20 ?6,5 5823.44 95,5 5866,3~ ?4,6 5~8,44 92,7 594?,8? 95.9 59~.89 6720,i5 62,82 127,88 -4282,92 ,.~05,34 63,73 i33,25 -4~?,51 6889,87 63,48 131,66 -4396,69 6~92,A~ 63,38 ~ ~ -4452,06 7058,~ 63,32 !31,57 -4509.24 5!78,95 6720,51 ~¢~,;,..~ 6805,73 129,61 5305,24 6890,31 129,65 5366,91 6973.13 129.68 5430,73 7058,76 !29,70 0,49 3,29 t 0,~. 0,54 gyro/data B.P. EXPLORATION MILNE POINT.FIELD, WELL NO. MPE-11 NORTH SLOPE, ALASKA Gyro Multishot Survey in 4.5" drill pipe Survey date: 13 January, 1995 Job number' AK0195G249 ~.\~-~'~ 0~, & Gas 6o~s.. 6omm'~ss'~or~ SR249.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 January 31, 1995 Ms. Marian Sloan B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, Ak 99508 Re' Dear Ms. Sloan, Milne Point Field, Well No. MPE-11 North Slope, Alaska Enclosed please fred one (1) original and ten copies (9) of the completed survey of Well #MPE-11 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future.. Sincerely Robert Shoup Assistant Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER' AK0195G249 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LIST1NG 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR249.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR249.DOC gyro/data DISCUSSION JOB NUMBER: AK0195G249 Tool 710 was mn in MPE-11 on ATLAS 7/32" Wireline inside 4.5" drill pipe. without problems. The survey was run SR249.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0195G249 The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Gyrodata Limited, and are true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a true and correct directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR249.DOC gyro/data 2. SURVEY DETAILS SR249.DOC gyr data SURVEY DETAILS JOB NUMBER: AK0195G249 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT WELL: MPE-11 LATITUDE: 70.455 N LONGITUDE: 149.5 W SURVEY DATE: 13 JANUARY, 1995 SURVEY TYPE : MULTISHOT IN 5" drill pipe DEPTH REFERENCE: ROTARY TABLE EVELATION MAX. SURVEY DEPTH: SURVEY TIED ONTO: SURVEY INTERVAL: N/A 100' 30' in open hole UTM CO-ORDINATES: TARGET DIRECTION: 129.82 GRID CORRECTION: CALCULATION METHOD: SURVEYOR: 0.0 MINIMUM CURVATURE STODDARD SR249.DOC gyro/data 3. OUTRUN SURVEY LISTING SR249.DOC A Gyroda t a D i r e c t i ona i Surve~ for B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, ALASKA Job Number: AK0195G249 Run Date: 13-Jan-95 15:25:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 53.83 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 129.820 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro data D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, Job Number: AK0195G249 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -53.8 0.00 0.0 0.0 0 - 4100 FT. GYRO SURVEY RUN IN 4.5" DRILLPIPE . MEASURED DEPTHS REFERENCED TO AN R.K.B. HEIGHT~OF 53.83 FT. ABOVE SEA LEVEL. Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .49 201.96 100.0 .1 46.2 .49 .4 202.0 200.0 .48 196.82 200.0 .4 146.2 .05 1.3 200.3 300.0 .48 213.22 300.0 .6 246.2 .14 2.1 202.2 400.0 .62 237.31 400.0 .5 346.2 .27 3.0 209.7 500.0 .67 224.66 500.0 .3 446.2 .15 4.0 215.4 600.0 .59 223.54 600.0 .2 546.1 .08 5.1 217.2 700.0 .80 215.87 700.0 .2 646.1 .23 6.3 217.6 800.0 .99 159.04 800.0 1.0 746.1 .87 7.5 211.8 900.0 1.62 149.15 899.9 3.1 846.1 .66 8.9 199.2 1000.0 2.85 138.68 999.9 6.9 946.0 1.30 11.5 182.8 1100.0 4.70 131.77 1099.6 13.5 1045.8 1.90 16.6 165.6 1200.0 6.68 126.12 1199.1 23.4 1145.3 2.06 25.2 151.9 1300.0 8.54 124.01 1298.3 36.6 1244.4 1.88 37.5 142.7 1400.0 10.83 117.81 1396.8 53.1 1343.0 2.51 53.4 135.9 1500.0 13.02 119.48 1494.7 73.4 1440.8 2.21 73.4 131.1 1600.0 15.72 121.05 1591.5 97.9 1537.7 2.73 97.9 128.4 1700.0 17.62 122.46 1687.3 126.3 1633.5 1.94 126.5 126.9 1800.0 18.95 121.45 1782.3 157.4 1728.4 1.37 157.7 125.9 1900.0 21.78 124.19 1876.0 191.9 1822.2 2.98 192.5 125.4 2000.0 25.28 128.00 1967.7 231.~ 1913.8 3.82 232.4 125.5 .40 S .16 W 1.20 S .44 W 1.95 S .79 W 2.59 S 1.48 W 3.30 S 2.34 W 4.08 S 3.10 W 5.02 S 3.87 W 6.39 S 3.97 W 8.41 S 2.93 W 11.49 S .57 W 16.09 S 4.13 E 22.24 S 11.88 E 29.83 S 38.37 S 37.21 E 48.29 S 55.32 E 60.82 S 76.74 E 75.93 S 101.11 E 92.53 S 127.74 E 111.43 S 156.95 E 135.01 S 189.13 E A Gyrodata B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE LocatiOn: E PAD, MILNE POINT, Job Number: AK0195G249 ALASKA Dire c t i on a 1 S u rve ~ Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 29.18 128.55 2056.6 2200.0 31.64 131.82 2142.8 2300.0 33.58 131.13 2227.1 2400.0 36.92 131.87 2308.7 2500.0 39.85 132.39 2387.1 277 328 381 439 501 .5 .1 .9 .6 .6 20'02.7 2089.0 2173.2 2254.9 2333.3 3.91 278.1 126.0 2.97 328.6 126.6 1.97 382.3 127.3 3.37 439.9 127.9 2.95 501.8 128.4 163.36 S 225.04 E 196.05 S 263.66 E 231.74 S 304.04 ~ 269.98 S 347.25 311.64 S 393.28 E 2600.0 43.43 135.51 2461.8 2700.0 46.87 135.94 2532.3 2800.0 49.87 136.46 2598.8 2900.0 52.60 138.36 2661.4 3000.0 55.45 134.60 2720.1 567 638 712 789 87O .9 .4 .6 .9 .3 2408.0 2478.5 2544.9 2607.5 2666.3 4 . 13 567 . 9 129 . 0 3 .46 638.4 129.8 3 .02 712.7 130.5 3 .11 790.1 131.1 4 . 17 870 . 7 131 . 6 357.78 S 441.05 E 408.53 S 490.53 E 462.48 S 542.25 E 519.89 S 594.99 E 578.51 S 650.72 E 3100.0 58.43 132.15 2774.7 3200.0 61.23 130.50 2824.9 3300.0 62.29 127.77 2872.3 3400.0 63.09 126.02 2918.1 3450.0 62.58 127.80 2941.0 953 1040 1128 1217 1261 .9 .3 .4 .1 .5 2720.9 2771.1 2818.4 2864.3 2887.1 3.62 954.5 131.8 3.14 1040.9 131.7 2.63 1128.9 131.5 1.76 1217.5 131.2 3.34 1261.8 131.1 636.04 S 711.65 E 693.10 S 776.57 E 748.69 S 844.90 E 802.03 S 915.96 E 828.74 S 951.53 E 3470.0 63.03 125.98 2950.1 3510.0 63.38 126.84 2968.1 3540.0 63.22 126.70 2981.6 3570.0 62.99 127.00 2995.2 3600.0 62.98 127.00 3008.8 1279 1314 1341 1368 1395 .3 .9 .7 .4 .1 2896.3 2914 · 3 2927.8 2941.4 2955.0 8.39 1279.6 131.0 2.11 1315.2 130.9 · 67 1341.9 130.8 1.18 1368.6 130.7 .03 1395.3 130.6 839.42 S 965.76 E 860.62 S 994.4~ 876.66 S 1015.9t ~ 892.71 S 1037.37 E 908.79 S 1058.72 E 3630.0 63.36 127.20 3022.4 3660.0 63.23 127.44 3035.8 3690.0 63.22 127.54 3049.3 3720.0 62.63 127.55 3063.0 3750.0 62.84 127.70 3076.7 1421.9 1448.6 1475.4 1502.1 1528.7 2968.5 2982.0 2995.5 3009.2 3022.9 1.38 1422.0 130.6 . 83 1448 . 7 130 . 5 .32 1475.5 130.5 1 . 95 1502 . 2 130 . 4 .83 1528.8 130.4 924.94 S 1080.07 E 941.19 S 1101.38 E 957.49 S 1122.63 E 973.77 S 1143.81 E 990.05 S 1164.93 E A~Gy r o da t a D i r e c t i on a i S u rv e y B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, Job Number: AK0195G249 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3780.0 63.02 127.88 3090.4 3810.0 62.76 128.01 3104.1 3840.0 62.21 128.38 3117.9 3870.0 62.20 128.80 3131.9 3900.0 61.99 129.37 3146.0 1555.4 3036.6 .81 1555.5 130.3 1582.1 3050.2 .96 1582.2 130.3 1608.7 3064.1 2.12 1608.8 130.2 1635.3 3078.1 1.24 1635.3 130.2 1661.8 3092.1 1.81 1661.8 130.2 1006.42 S 1186.04 E 1022.84 S 1207.10 E 1039.29 S 1228.01 E 1055.84 S 1248.75 't 1072.56 S 1269.33 ~ J 3930.0 61.48 129.58 3160.2 3960.0 61.42 129.76 3174.5 3990.0 61.41 129.75 3188.9 4020.0 61.45 129.64 3203 .2 4050 · 0 61 · 37 128 · 69 3217 · 6 1688.2 3106.3 1.80 1688.2 130.2 1714.5 3120.7 .56 1714.6 130.2 1740.9 3135.0 .02 1740.9 130.2 1767.2 3149.4 .37 1767.3 130.2 1793.6 3163.7 2.78 1793.6 130.1 1089.36 S 1289.73 E 1106.18 S 1310.01 E 1123.03 S 1330.26 E 1139.86 S 1350.54 E 1156.49 S 1370.96 E 4080.0 61.17 129.00 3232.0 4100.0 60.58 126.11 3241.7 1819.9 3178.1 1.11 1819.9 130.1 1837.3 3187.9 12.95 1837.4 130.1 1172.99 S 1391.45 E 1183.64 S 1405.30 E Final Station Closure: Distance: 1837.35 ft Az: 130.11 deg. A Gyroda t a D i r e c t i ona I Survey for B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, ALASKA Job Number: AK0195G249SS Run Date: 13-Jan-95 15:25:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 53.83 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 129.820 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, Job Number: AK0195G249SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -53.8 0.00 0.00 0.0 0.0 0.00 0 - 4100 FT. GYRO SURVEY RUN IN 4.5" DRILLPIPE. MEASURED DEPTHS REFERENCED TO AN R.K.B. HEIGHT'OF 53.83 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 0.0 0.00 N 0.00 E FT. ABOVE SEA LEVEL. 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 100.0 .48 199.19 153.8 .3 .25 200.0 .48 205.65 253.8 .5 .10 300.0 .56 226.19 353.8 .6 .21 400.0 .6'4 230.50 453.8 .4 .20 500.0 .62 224.06 553.8 .3 .11 00.0 .70 219.41 653.8 .2 .16 00.0 .90 185.26 753.8 .7 .58 00.0 1.33 153.71 853.8 2.2 .76 00.0 2.28 143.50 953.8 5.2 1.00 00.0 3.85 134.94 1053.8 10.5 1.62 00.0 5.78 128.69 1153.8 18.9 1.98 00.0 7.71 124.96 1253.8 30.6 1.96 00.0 9.83 120.51 1353.8 45.9 2.24 00.0 12.10 118.78 1453.8 65.0 2.34 00.0 14.67 120.44 1553.8 88.4 2.53 00.0 16.95 121.97 1653.8 116.4 2.22 00.0 18.55 121.75 1753.8 148.1 1.54 00.0 21.11 123.54 1853.8 183.7 2.60 00.0 24.75 127.42 1953.8 225.7 3.69 00.0 29.06 128.53 2053.8 276.0 3.90 1.3 201.1 2.1 201.3 3.0 206.2 4.0 212.8 5.1 216.4 6.3 217.4 7.5 214.5 8.9 205.0 11.5 190.4 16.6 173.5 25.2 158.1 37.5 146.8 53.4 138.8 73.4 133.1 97.9 129.5 126.5 127.4 157.7 126.2 192.5 125.5 232.4 125.5 278.1 126.0 .83 S .31 W 1.60 S .63 W 2.30 S 1.16 W 2.97 S 1.94 W 3.72 S 2.75 W 4.59 S 3.51 W 5.76 S 3.92 W 7.48 S 3.41 W 10.07 S 1.66 W 13.98 S 2.49 E 19.44 S 8.35 26.43 S 17.87 34.64 S 30.89 44.15 S 47.76 55.95 S 68.40 70.65 S 92.59 87.56 S 119.77 106.96 S 150.04 131.45 S 184.27 162.48 S 223.93 E E E E A Gyrodat a Di re c t i ona I Survey B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, Job Number: AK0195G249SS ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. VERTICAL VERTICAL DOGLEG CLOSURE DEPTH SECTION SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 31.89 131.73 2200.0 34.67 131.38 2300.0 38.60 132.17 2400.0 43.04 135.18 2500.0 47.84 136.11 2153.8 335.1 2.84 382.3 126.7 2253.8 400.8 2.43 439.9 127.5 2353.8 475.3 3.13 501.8 128.2 2453.8 560.8 4.01 567.9 129.0 2553.8 662.4 3.32 712.7 130.0 200.71 S 268.94 E 244.28 S 318.21 E 293.96 S 373.75 E 352.84 S 435.94 E 425.99 S 507.27 E 2600.0 52.27 138.13 2700.0 57.29 133.09 2800.0 61.88 128.84 2900.0 63.10 126.16 3000.0 63.03 127.54 2653.8 780.6 3.10 790.1 131.1 2753.8 921.9 3.83 954.5 131.7 2853.8 1094.1 2.83 1128.9 131.6 2953.8 1286.7 7.09 1315.2 131.0 3053.8 1484.2 .85 1502.2 130.4 512.96 S 588.63 E 614.05 S 688.36 E 727.05 S 818.29 E 843.80 S 971.70 E 962.83 S 1129.59 E 3100.0 61.71 129.49 3187.9 60.58 126.11 3153.8 1676.4 1.80 1688.2 130.2 3241.7 1837.3 12.95 1837.4 130.1 1081.87 S 1280.64 E 1183.64 S 1405.30 E Final Station Closure: Distance: 1837.35 ft Az: 130.11 deg. gyro/data 4. QUALITY CONTROL SR249.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MPE-11, 4.5" DRILLPIPE Location: E PAD, MILNE POINT, ALASKA Job Number : AK0195G249 / AK0195G249 INRUN/OUTRUN Comparison INRIIN OUTRUN INRUN , Depth Inc Inc Delta Az 1000.0 2.41 2.85 -.437 131.93 1100.0 4.59 4.70 -.107 127.31 1200.0 6.57 6.68 -.113 124.04 2000.0 25.02 25.28 -.259 127.76 3000.0 55.38 55.45 -.071 134.25 4100.0 60.59 60.58 .001 126.18 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.1096 deg. Average Azimuth Difference = -.1740 deg. OUTRUN Az 138.68 131.77 126.12 128.00 134.60 126.11 Delta -6.752 -4.460 -2.076 -.238 -.350 .066 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0195G249 TOOL NUMBER: 710 MAXIMUM GYRO TEMPERATURE: 74.0 c MAXIMUM AMBIENT TEMPERATURE: 30.0 c MAXIMUM INCLINATION: 67.20 AVERAGE AZIMUTH: 130.1 WIRELINE REZERO VALUE: REZERO ERROR / K: no correction n/a CALIBRATION USED FOR FIELD SURVEY: 21-december94 CALIBRATION USED FOR FINAL SURVEY: 21-december-94 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECKt: CONDITION OF SHOCK WATCF]ES -.47 -..00 -.26 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL REPORT 4100 60.58 126.11 3241.3 -1183.43 1405.07 4100 60.58 126.11 3241.7 -1183.64 1405.30 SR249.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0195G249 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2700 46.87 46.87 46.87 46.87 46.87 AZIMUTH M.D. ff I 2 3 4 5 2700 137.16 137.17 137.18 137.1 137.17 SR249.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR249.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0195G249 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 710 GYRO SECTION A0036 DATA SECTION A0002 POWER SECTION A0052 BACKUP TOOL No. 046 GYRO SECTION A0083 DATA S ECTI ON A0025 POWER SECTION B0044 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0032 A0079 A0071 A0122 A0074 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32 RUNNING GEAR 2 ¼" System using 2 ¼ "eccentric weight bar TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 24.5 feet 2.5 INCHES TOTAL WEIGHT OF TOOL: 300Lbs SR249.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0195G249 1/13/95 O845 LEAVE FOR MILNE POINT O945 ARRIVE LOCATION, MU TOOL 130O STANDBY 1545 PU TOOL. MU PUMP DOWN SUB. START INRUN SURVEY. 1645 PUMP TOOL DOWN. 1700 4100. START OUTRUN SURVEY. 1745 3400 casing. 1845 LD AND BD TOOL. 1945 RTN TO ATLAS. 2145 POST RUN CHECK. FAX SURVEY. 2300 RTN MILNE POINT FOR TICKET. 1/14/95 0100 RTN ATLAS. CHRONOLOGICAL REPORT JOB NUMBER: AK0195G249 SR249.DOC LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 1 February 1995 Transmittal of Data ECC #: 6352.02 Sent by: MAIL Data: GR/CCL Dear Sir/Madam, References MPE-11 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Filmsg i GR/CCL FINAL BL+RF Run # I .. Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please siEn and [)/~/ ......~en~on Boulevard Date ~g .... ,..., .~-. Z__ OXY USA, INC. Attn. ERMA GALINDO P. O. BOX 50250 MIDLAND TX, 79710. Date: RE: 1 February 1995 Transmittal of Data ECC #: 6352.02 Sent by: FED-EX Data: GR/CCL Dear Sir/Madam, Reference: BP MPE-11 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: i GR/CCL FINAL BL+RF Run # i Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: RECEIVED Y:~ ~ .... ' '1 '~ ':~"'~ ~''') ' ' .... ~ ~7 ......... ~'.'~~ .- . Date FEB 0 8 199 Alaska 011 & Ga9 Con~, bi;illitlJ~ll;F Anchorag~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPE-11 MILNE POINT NORTH. SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Date: 30 January 1995 RE: Transmittal of Data ECC #: 6352.00 Sent by: MAIL Data: GR/CCL Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, ~ 99518 Or F~ to (907) 563-7803 Received by: ~~ . Date: RECEIVED FEB 2 Alaska 0il & Gas Cons. Commission Anchorage Please sf~n and return ~ ~ot~n~,u~ cal Data Cente~ Received b_r~ - ~ RECEIVED FEB 02 995 Alaska Oil & Oas Cons. CommJs~Jo~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 27 January 1995 Transmittal of Data ECC #: 6352.00 Sent by: MAIL Data: GR/CCL Dear Sir/Madam, Reference: BP MPE-11 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 DIFL/GR/SP FNL BL+RF ZDL/CN/GR FNL BL+RF Run # 1 Run # 1 Please ~i~n and re¢urn to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and metu~n pet:.roteclm, ical Data Cente~' BP tS~rn].o~:a'bion (Alaska) In~ Da'be MEMORAND .M TO: David Jo~ Chairm~n/.~ Blair Wondzeli,-&l~,~ P. I. Supervisor ,fi,~ FROM: Jerry Herring, ~ ~: SUBJECT: Petroleum lnsi:Yector State AlasKa Alaska Oil and G~ ,onservation Commission DATE: January 19, 1995 FILE NO: awokalcd, doc BOPE Test - Nabors 22E BPX Milne Point Unit MPE-11 PTD # 95-01 Thursday, January. 12, 1995: I traveled to BPX's Miine Point Unit to witness a B.O.P.E. test on Nabors rig 22E. The B.O.P.E. Test Report is attached. On this trip, I was accompanied by Commissioner Tuckerman Babcock. The test began at 1:00PM and lasted for (4) hours. There were (4) failures. A choke line flange leaked, one choke manifold valve leaked, and various problems with the mud control panel were found. Otherwise the dg was found to be in good shape. Summary: I witnessed a B.O.P.E. test on Nabors 22E drilling well MPE-11, MPU. The test lasted for (4) hours and there were (4) failures. Attachment: awokaicd.xls C: TUckerman Babcock, Commissioner STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: __ Drlg Contractor: Nabors Alaska Drilling, Inc. Operator: BPX Well Name: MPE-11 Casing Size: 9-518" Set'@ Test: Initial X Weekly Rig No. 22E PTD# Rep.: Rig Rep.: 3,455' Location: Sec. Other 95-01 25 T. DATE: 1/12/95 Rig Ph.# 659-6475 Jimmy Pyr,on Terry Hanna 13N R. 10E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK, (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250 / 3500 P 1 250/5000 P 1 250/5000 P I 25015000 P 2 25015000 P I 250/5000 P 1 250/5000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK N/A Pit Level Indicators OK F Flow Indicator OK F Methane Gas Der. NT NT H2S Detectors NT NT FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure 1 250 / 5000 250/5000 1 250/5000 1 250/5000 P/F CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 17 250/5000 P 36 250/5000 P I P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8 Bottles 1800 Ave. 3,100 P 1,600 P 0 minutes 32 sec. minutes 15 sec. OK Remote: OK Psig. Number of Failures ~ Test Time 4-0 Hours Number of valves tested 25 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. I. Supervisor at 279-1433 REMARKS: Minor leaks repaired on choke line flange and a valve in choke manifold. Audio alarms not functioning correctly on mud control console. PTD to be posted on rig. Gas detection system not tested. Otherwise, rig was in good condition. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: ?~f ~'~, ~¢.^~? FI-021L (Rev. 2/93) AWOKALCD.XLS MEMORAND, TO: State ..... 'Alaska David John'/n, Chairma~~ Blair Wondzeli, ~ P. I. Supervisor FROM: Jerry Herring, ~,1~ SUBJECT: Petroleum Inspector Alaska Oil and Gas Conservation Commission DATE: January 17, 1995 · FR,E NO: eaxkancd.doc Diverter Test - Nabors 27E BPX, Milne Point Unit MP L-17 PTD # 95-001 .Tuesday~ January 17, 1995: ! traveled to BPX's Milne Point Unit to witness a diverter test on Nabors 27E drilling well MP L-17. The Diverter Test Report is attached. · ~ The diverter function test went smoothly. Nabors 27E is utilizing a 10" bifurcated line. The rig was in good condition and is drilling the first well in over ~ years because it was stacked out. Summary: I witnessed a diverter test on Nabors 27E drilling well MPU L-17. Attachment: ewqaqcd.xis STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Nabors Alaska Drillin¢, Inc. Operator: BPX MPU Well Name: MP L-17 Location: Sec. 8 T. 13N R. Operation: Development X Date: Exploratory: 1/17/95 Rig No. Oper. Rep.: 27E PTD # 94-169 Rig Ph. # 659 - 4384 J. E. Robertson Rig Rep.' Brian Busby 10E Merdian Umiat MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: N / A Flare Pit: N / A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 Vent Line(s) Length: Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES in. in. 86 & 136 ft. ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: 0 Systems Pressure Attained: 1 Nitrogen Bottles: 8 Bottles 2300 Ave. 3000 psig 1700 psig min. 26 sec. min. 46 sec. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: hiT hiT psig NORTH g Drawing Not To Scale N.C. ii-~ 56' (2) 10" Mechanically !! ] _ Linked Knife Valves ~! ~ Mud System Motor Module Pipe Shed 20" Annular Preventer With 10" FO Hydraulic Knife Valve Non Compliance Items 0 Repair Items Withir 0 Day (s) And contact the Inspector @ 659-3607 Remarks: The rig was found to be in good condition. The Gas Detection Guidelines dated 12115/94 was left with the company rep. Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c- Inspector AOGCC REP.: FI-022 (Rev. 7/93 EWQKAQCD.XLS MEMORANDUM TO: iaska David Joh~~ THRU: FROM' Blair Wondzeli, ~ P. I. Supervisor Bobby Fos~l~ Petroleum Inspector State of Alaska Oil and Gas Conservation Commission DATE: January 9, 1995 FILE NO: EWOIAICD.doc SUBJECT: Diverter Inspection BPX - MPU - E-11 PTD #95-01 Kuparuk River Field Monday, January 9, 1995: ! traveled this date to BPX's MPU well E-11 and inspected the diverter system. As the attached AOGCC Diverter System Inspection Report shows.,the system was installed in accordance with AOGCC policy. ! witnessed the testing of the components of the system and all operated properly. The rig was clean and all equipment seemed to be in good working order. The location was crowdedwith a workover rig and a wireline unit on the same pad, but access to all equipment and the rig was good. Summary: I inspected and witnessed the diverter test on Nabo~E rigged up on BPX's MPU well E-11. ~ Attachment: I~WOIAICD.XLS Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA AT~SKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Date: 1/9/95 Operation: Development X Explor~*,~' Nabors Rig No. 22E PTD # OS-ti Rig Ph. # fi~0-6~75 BPX Oper, Rep.: JIMMY PYRON MPE - 11 Rig Rep.: TERRY HANNA 25 T. 13N tL 10E Merdian UM TEST DATA MISC. INSPECTIONS: Gen.: OK Well OK aping: OK (G mrlg--~-- e Pit: N/A Flat N/A DI~RTERSYSTEMINSPECTION: Diverter Size: 20' in, Divert Valve(s) Full Opeaiag: 3 Valve(s) Auto & Simultaneous; Wear Liae(s) r~mgth: Line(s) Bifurcated: 1 Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: N lA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: ~ ' ' are: Nitrogen nomes: 3000 psig l-/uo psig 2 min. 2~ sec, ,. MUD SYSTEM INSPECTION: Flow Monitor. Light Alarm YES YES Light Alarm YES YES YES YES GAS DETECTORS: Methane Hydrogen Sulfide: North ors Shed Prevailing Winds Non Compliance Items 0 Repair Items Withi N lA Day (s) Amd contact the Inspector @ 659-3607 c- naspector .-_oeec_-=_-.: BOBBY D. FOSTER OPERATOR REP.: JIMMY P YR ON EWOIAICD. XLS DVTRINSP. XLT (REV. 1/94) ALASKA OIL AND GAS · CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR '.. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (90?) 279-1433 FAX: (gO7) 276-7542 January 6, 1995 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPE-11 BP Exploration (Alaska), Inc. Permit No. 95-01 Sur. Loc. 3684'NSL, 1992'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc. 2921'NSL, 0017'WEL, Sec. 31, T13N, RllE, UM Dear Mr. Clark= Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the N . David W. Johnston Chairman ~,~~._ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASr,^ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill'[] Redrillr-lJlb. Type of well. ExploratoryE3 Stratigraphic Test 1-1 Development OilEi Re-Entry [] DeepenFII 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. KBE = 54' feet Mi/ne Po/nt- Kuparuk River 3. Address 6. Property Designation Sands P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28231 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~e 20 ^^c 25.o25) 3684' NSL, 1992' WEL, SEC. 25, T13N, RIOE MIIne Point Unit At top of productive interval 8. Well number Number 3200' NSL, 0350' WEL, SEC. 31, T13N, R11E MPE-11 2S100302630-277 At total depth 9. Approkimate spud date Amount 2921' NSL, 0017' WEL, SEC. 31, T13N, R11E 1/8/95 $200,000.00 !i2. Distance to nearest 13'. Distance to nearest well 14. Number of acres in property lb. Proposed depth(MDa,d'rVD) property line ADL 380110-2921 feet No close approach feet 2560 12703'MD/7220' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A~C 25.035 (e)(2)) Kickoff depth 900 feet Maximum hole angle62.5 o Maximum sudace 3520 psig At total depth (TVD) 6994'/4220 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 30" 20" 91.111 NT60 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12.25" 9-5/8" 401t L-80 BTRC 3328' 31' 31' 3359' 2910' 665 sx PF"E'/250 sx"G"/250 sx PF"E" 8.5" 7" 26tt L-80 NSCC 11944 30' 30' 11974' 6884' 3475x Class 6" 5" 151t 13CR FL4S 879' 11824' 6815' 12703' 7220' 145 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 Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate JAN - 4 1995 Production Liner Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchora. :. -true vertical 20. Attachments Filing fee [] Property pla{ [] BOP Sketch [] Diverter Sketch [] Drilling program [] ,Dr)llin9 fluid program.,R"l Time vs depth pict [] Refraction analysis[] Seabed reportl-'l 20 AAC 25.050 requirementsl--I 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~¢'~rc~.'~,-.~(~,. ~~..,,.' Title Dri//in~l En~TineerSupe,rv/sor Date Commission Use Only Permit Uum'ber IAPI number IApproval date ISee cover letter Conditions of approval Samples required [] Yes J~ No Mud Icg required 'El Yes I~ No Hydrogen sulfide measures [] Yes J~ No Directional survey required [] Yes [] No Other:Required working pressure forJ3OP. E .urlglrla,_.~.._~n2nM~.b_.,i~~3M;' J~.bM; I-I10M', r'-]l bM; ~ by order of Approved by David W. dohnston Commissioner me commission DateI Form 10-401 Rev. 12-1-85 ij Submit iri triplicate [Well Name: [ MPE- 1 1 Well Plan Summary Type of Well (producer or injector): [ Kuparuk Producer ] ISurface Location' Target Location: Bottom Hole Location: 3684 NSL 1992 WEL Sec 25 T13N R10E UM., AK. 3200 NSL 0350 WEL Sec 31 T13N RllE UM., AK. 2921 NSL 0017 WEL Sec 31 T13N RllE UM., AK. [ AFE Number: [ 330066 [ Estimated Start Date: [ 1/8/93 [MD: [12703 [ [TVD: [ Well Design (conventional, slimhole, etc.): [ Rig: [ Nabors 22-E [ Operating days to complete: [2O 17220 bkb I [54' ] Milne Point Ultra Slimhole 9-5/8"/7"/5" Liner Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1764 1754 NA 6359 4294 Top of Schrader Bluff Sands (8.3 ppg) . OB 6792 4494 (8.3 ppg) Seabee Shale 6911 4549 Base of the Schrader Bluff Sands HRZ 11236 6544 High Resistivity Streak Top Kup 11757 6784 Kuparuk Cap Rock Top C1 Sand--Target 12212 6994 Target (11.6 ppg) Top B7 Sand 12342 7054 (11.6 ppg) Total Depth 12703 7220 Casing/Tubing Program: Hole ~,ize - Csg/~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.14/ H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 404/ L-80 btrc 3328 31/31 3359/2910 8 1/2" 7" 26# L-80 nscc 11944 30/30 11974/6884 6" 5" 15# 13CR80 FL4S 879 11824/6815 12703/7220 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 4220 psi is 3520 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional Only DLS (Directional and GR Only) LWD Sperry Sun (Recorded GR and RES Only) GR/CCL will be run in 7" casing to coincide with ROPE Perforation Operations -- Tubing Coveyed Perforations. RECEIVED JAN - 4 1995 Oil & Gas Cons. Commission Anchora. ': Mud Program: I Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to tO to to to to 9.6 90 35 15 30 10 15 Intbrmediate Mud Properties: N/A Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Production Mud Properties: ] None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 11.6 40 10 3 7 8.5 6-8 to to to to to to 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: !mOP: !900 Maximum Hole Angle: 62.5 degrees Close Approach Well: None Disposal: Cuttings Handling: CC2A Fluid Handling: All drilling and completion fluids can be annular injected -- the permit was submitted; therefore, do not annuluar inject into the MPE-11 Annulus without checking with the Point Contact. Annular Injection: The MPE-11 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AR'EA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED VOL (BBLS) (BBLS) Milne Point MPE-09 1500 35,000 6/1/94 to 12/31/94 Milne Point MPE-10 2000 35,000 6/1/94 to 12/31/94 Milne Point MPE-11 0 35,000 Submitted FREEZE PROTECTION: Pay close attention to annuli being used for disposal so to avoid freezing. Sometimes the annuli are kept open by ensuring-that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. dAN -' 4 1995 0ii & Gas Cons. Commission Anchom.-.* MPE-11 Well Plan PAGE 2 JDP 1/3/95 MPE-11 Proposed Summary of Operations , . 3. . 5, Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. RECF. IVED MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. JAN -,4 1995 Alaska 0il & Gas Cons. Commission Anchore. .-, MU 12-1/4" bit and MWD (Dir), drill surface hole, and run and cement 9-5/8" casing. 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. . RIH w/ Insert bit on a motor with DLS (Dir/GR), Test 9-5/8" casing to 3000 psig for 30 minutes, Drill out float equipment and 10 feet of new formation, Perform a FIT -- 13.5ppg. 8, Drill 8.5 hole through the Schrader formation into the Seabee (Colville) Shale. POOH and Lay down the motor and Insert bit. 9~ MU PDC bit and turbine with DLS (Dir/GR). Drill 8.5" hole to +100' tvd above the C1 Kuparuk Sand, POOH, and LD the PDC bit and turbine. 10. Wiper Trip, POOH and LD BHA, Change Top Rams to 7", and Run and Cement 7" casing, Bump the plug, check the floats, and pressure test the casing to 3500 psig for 30 minutes. 11. MU the 6" bit and Sperry LWD (Recorded GR and RES) drill to TD. Wiper Trip to the 7" casing shoe. Drop Rabbit and POOH. 12. RU and Run the 5" liner on 3-1/2" drill pipe. Cement 5" Liner. 13. RIH with 6" bit and scraper to clean off the Top of the 5" liner top packer. POOH. 14. RIH with 4.25" mill and clean out the liner to the landing collar. Test Casing to 4500 psig for 30 minutes. Displace drilling mud with brine and filter. 15. POOH & PU Drill Pipe Conveyed Perforating Guns. RIH and Set Champ Packer. Displace tubing with the recommended volume of diesel, and RU BJ and ROPE perforate the well. Kill well while circulating kill weight brine. 16. POOH and MU the 7" Retrievable Bridge Plug, set at 45.00' md. 17. POOH while LD 3-1/2" Drill Pipe -- Freeze Protect Well while POOH. 18. ND BOPE & NU the False Bowl. NU and test the Dry Hole Tree to Prepare Well for Running ESP with Coil Tubing at later date. 19. RDMO Nabors 22E drilling rig to drill next well. Drilling Hazards and Risks: 1. There was evidence of shallow gas/hydrates in the E-Pad area (E-7 and E-8 wells); therefore, the MW schedule requires 9.3 ppg by 2000' tvd. This practice was applied on the MPE-09 well and there was no evidence of hydrate problems 'while drilling the surface hole. e The MPE-09 encountered pore pressure in the Kuparuk that was 1.7 ppg above what was expected (11.6 ppg vs 10.1). This resulted trouble time and costs associated with the well kill incident being complicated with the Schrader Bluff sand exposed. As a result, the MPE-11well design has been modified to top set the Kuparuk Reservoir with 7" intermediate casing. 3. No other drilling hazzards or risks have been identified for this well. MPE-11 Well Plan PAGE 3 JDP 1/3/95 MPE-11 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 75 deg F at 4500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 665 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hfs at 50° F. TAIL CEMENT TYPE; Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaCI2 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 250 FLUID LOSS: 100-150 cc MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP ,.lOB CEMENT TYPE: Permafrost ADDITIVES: Retarder WEIGHT: 15.6 ppg APPROX NO SACKS: 250 E YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint on bottom 10 joints of 9-5/8" casing. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: 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 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to sudace with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPE-I! Well Plan PAGE 4 JDP 1/3/95 MPE-09 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: 140°F BHST 170 deg F at 7040' TVDSS. S P A C E R: 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: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 158 FLUID LOSS: < 50cc/30 rain @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 112 - 4 112 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE !1 CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Hallibudon specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MiX WATER: 11.63 gal/sk APPROX #SACKS: NONE TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk THICKENING TIME: Greater than 4 hrs at 50° F' jAt -' 4 995 MIX WATER' 5.0 gal/sk A~ch°f~ ~ APPROX # SACKS: 189 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- one per joint on the bottom 10 joints of 7" Casing (10 total). 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one above and below the ES Cementer and one per joint from Seabee Shale Top to the 300' above the top of the NA Schrader Bluffs Sand (25Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 36. OTHER CONSIDERATIONS: Pedorm 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 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME: 1. Stage I cement volume is calculated to cover 1000' md above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 500' above the NA Top with 30% excess. Get the Depths of these formations from the Point Contact. MPE-11 Well Plan PAGE 5 JDP 1/3/95 MPE-11 5" PRODUCTION LINER CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140° F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg gal/sk YIELD: 1.15 cu ft/sk MIX WATER: 5.0 APPROX # SACKS: 145 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F angle. FREE WATER: 0cc @ 45 degree CENTRALIZER PLACEMENT: 1. 5-1/8" x 5-7/8" RH Turbulators -- two per joint on all joints except None on the joint which will be reciprocated across the 7" casing shoe. 2. Estimated total RH Turbulators needed is 42. OTHER CONSIDERATIONS: 1. 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 4 - 6 bpm. This job requires that the cement be batch mixed. CEMENT VOLUME: 1. The cement volume is calculated for 30% excess in the openhole and 300' of cement in the 7" above the liner lap. RECEIVED JAN - 4 1995 0il & Gas Cons. Commission ;Anchora:. ~- MPE-11 Well Plan PAGE 6 JDP 1/3/95 WELL PERMIT CHECKL FIELD & POOL ADMINISTRATION ENGINEERING 1. Permit fee 2. Lease numbi 3. Unique wel2 4. Well lo=atl 5. Well locat~ 6. Well locat, 7. Sufficient 8. If deviate~ 9. Operator o 10. Operator h 11. Permit can 12. Permit can 13. Can permit 14. Conductor 15. Surface ca 16. CMT vol ad 17. CMT vol ad 18. CMT will c~ 19. Casing des 20. Adequate t 21. If a re-dr 22. Adequate w 23. If diverte 24. Drilling f 25. BOPEs adeq' APPR D~T~/ 26. BOPE press. 27. Choke mani 28. Work will 29. Is presenct GEOLOGY ~ 30. Permit can 31. Data presel 32. Seismic an 33. Seabed cont /~~ 34. Contact n~ GEOLOGY: HOWOo - A:~ORMS~hekli~ rev 03/94 SERv ICE'S 'OR ILL I'NG Anadr] ] / $£h !umberger ' i ] Jill II NPE-I'I ~ I ~ i SCALE .......: ~i inch = ~1200 feet. I i i DRAI~IN ' 01/04/95 t ....... ' ....... I~arker Idenl:ificat~on ND N/S E/N B) BUILD rtl00 900 ,~. c~ BUILD i.§/~O0 looo t i I .... I D) BUILD 2/100 120O 6 7 E) BUILD 3/~00 ~500 3o 35 I I ~ F) ENO OF 3/~ CURVE 325i 670 803 i ~ G) 9-5/8~ CASING PDINf 7128 2B73 3446 , ....... : ........... ~ H) ....... [AA~T ....... I2212 576i 6910 ~ I) ~O "' ~ ' ' ~ ~ ~A~R '~'L...L]'.. -'"' ' '''~ .... ,: ', AKA-DPC , FE/,SIB[ _ITM P~ .......... ' .... i . ' ' ..... NOT AP'F'RO~ED [:OR' EXE(:UTIbN '" j P't.AN' . ~. ~ ......... [ . ~. i j ! ~ 200 600 . .0 600 1200 ...1800. . 2400 3000 3600,. 4200 4800 5400 600~ 66~0 7~00 /800 840¢ 9~0 ~O0 10200 <- ',ES~ ' esr -> ..... PLAN V CLOSURE ' 9432 feet at Azimuth 129.82 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED AIask~ Oil & ' ~- Anchorage Center J C T., [~ CP T ,~- F 3 6 7, '! i 9 ': ? ~ 3 , ,~t'; 50-029-2254!-0() 50-029-22541 :t 2,7 5 0 PAGE: eu, rve$; o. 5 i':~ 0 (': al.,1 b:~t ruos merqed. f) 6 I PAGg: (; P, a i< - 999,2. 5 ;J I)!~'f:''~. ¢.Uf~(,~.,'.)O!.) ¢RW,,,:./:,~,f) 1 ,.. 'l . C'vO GF::I'f't.,,~.'~'D 103. O(J(! (::.4 V;'. ,.: P - 9 a '-'). 25 C, 12. ,i 0 0 28.6O0 !2.664 8.5. !87 81.100 109.900 152.000 66.10{:) 84.100 262°800 325. 200 2.!2.400 149.201 bis ~'a~e Veri.t'icati..on f:istinq :;Ch]..un'.~'.erc4~I" A.!. a.~k:.e C.:~,'np,.~t;inO Center D F: t:' 'r o 4, S 0 ("1 o 000 G ~;:. P ;4 o ~,'~ w [;, GP. GR -999.2~0 F'lbr'' - 9 9 9.9 5 0 C F-, ? !,,~. !,,.:i W D 66.4, 9 .~; 52.252 4,,5. 000 97.999 004 6 5.0 0 0 PAGE: 9,1.395 343.711 339.563 82.797 358.563 299.399 234.900 .,rS Tape Ver!filcat.i. oD ; c b .1 u m h e r ~'-] e r A ]. 6~ $ k. a C o r,~ ~.:, u t: I n q C p. r', t e ,T:' PAGE~ Curves ond loc! h.~a¢ler data for v E ~'i Ti.> 0 R TO !/.1 [,, C ('i r": 15 o, 5 (': o o E ~i ('.} [., g a i';} I..) C ;\ S ! r,i c; [) A T A 0 P E: ~',! 5! 0 L ~,..', /.,-:~, ( 'i' 5 ~' Z 5,.i'i ¢ i ~.i ) [,,I9ILL, ERS CASiiiC; f'.',r.'~P~TH (i:T):: ~1 F.', I T '..? F~ l,q. i~,i ": .~ i'R I .X" ,.,." ~ ..... T P .I x' .P F; ~.' S T T y ,- ,~:[l [, T;: C U R ~,: Fi C 'r .I. 0 ;, C !'l ~,; T & 1' !,, 5 m ,~i Fi each bit run i.n separate files, P i.!.: A b-' '.l.' !, i~,'i ~ 1 2 a 3 0. ¢~ 3 4 5 55.0 1 2 7 6, ~!;. 0 .1. 2.2 ::30 3455.0 ' Ii 8 "raPe vcr. i. fli, catIor~ i,:j. stinc~ 0 (; '7 Y ? E C .L,/~ ~; S , ")!:;', ",~ U ;v! ;;..; S ~ :.'t P. E [,, E' ?; C !'..10 t~; f H E: X ) ;""';;; ............. ; .... ';' ...... T ....... ; .... ; ...... ..... 0 () '; ~ ., .4,. 8 ~ f'? {~ 000000 0 00 ~'.'~ 00 ;' 2 i I 4 68 .¢,. ,r) 000 (,) 0000 n OOO O0 ' 2 I. ! /,, 6f,~ 000()000000 o C, 00 0 r~ '.' 2 '! !. 4 68 C~ <) (; U 000000 0 c., () o 0 0 2 I i 4 6 A () C.' 0 <) 0 0 0 0 0 0 0 0 (..~ 0 (,, ci , 2 .1. 1 4 6 8 ('! ~) 0 t.) 0 L) 0 0 0 0 O. ~') L.; 0 00 ' 2 ] ! 4 6 S C:. ~; 0 ('~ 000000 -999.250 7355.30O ~chlui~ber!.]:~e!' Al, asKa ("omput.,.i.r~C3 Cent.,o.l" . 90 il) F F' T. ? 0 (; t). 0 f) j.'~ fZ p T o 6 ..,50 t), 00 (' · 't- . . f) ,r,' 2 "r 5 0 o, O. U C' t~ P, PpF. p k;.,~ 43/3..~ 9,,., i.)r"-Pq, 4U(~(I.O0,~ 2 ! . ~ ,:,] ,:';, t ,'" "(,; (5 R {.'; 'P ~;' ~,'l ;4 ~'f "5 .. '?: D 1 l.~ 9.9 00 R [,l P h,:. M W .d 87.70 (} G P., ~;;'~ ;;,t D - 999.2 b (.) G P,. ~'4 w L) 60.8 00 G 51,. 200 G 325.2 u 0 P 3 g. 400 GR. MWl,.~ 2 i ~. 4, t,~ 0 R -9~o. 250 Gt'<. awI.~ ! 49.2 00 -09o. 2bO 9 1.4 g () 3 43.7 {) f: P r) P F.',. 339.6(,o ~OPk.. ~,,~w ~ ~ggq. 250 3 'l 2. ], t., 0 P I..7) P ~:. ~, ;', H 52 · 5 b (.: O 3bi~.SO(', RCPL. - 9 '9 q 14. 127. 8 5.30 -999. 250 81.100 115.000 170.000 152.000 -999. 250 66.1 O0 117,000 8,4.100 9~,000 262.800 103,000 325.200 't 4.. 000 212.40O -999.250 -999.25o 91.. 4OO -999. 250 343.7u0 -99~. 250 339.5U0 -999. 250 82.800 -999. 372. ~0(', 9 F:, 0 358. P, 2 ,, 000 7,t82,200 102. 500 6920.90() 127,000 6675.101 203,500 6441.500 11.5.000 621,6,400 1,70.000 5991.500 1,77 500 5766:601 117.000 5538.300 98,000 5307.101 103.000 5066,500 74,000 a826,,5oo 95,, 500 45fl9,400 6,5.500 4360.000 39.000 4129,500 52.250 3901.300 45.000 3672.000 56.000 3436.800 96.000 3351.200 :, :.t. $ q' a t', e V e r I fl .I e a t i. o n [.., i s t:: ,i.. n .q 5¢hltl~,h, er e.r A!.asK8 Com}'.:',tlt:~i,:c'~cf Cept:e¥ PAGE 2.. 99 ' "0., .40 (; 6 5,0 ¢) 0 2..,34,900 6, .000 30~5,400 65, ~996.1,00 50-029=22541 -00 .. ~'ape Subfile 2 is type: LIS 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: MWD RUN 1 6462.00 R. KRELL J. PYRON 500292254100 BP EXPLORATION (ALASKA) INC. 26-JUL-95SPERRY-SUN DRILLING SERVICES0~/~~ MWD RUN 2 25 13N 10E 3684 ELEVATION(FTKELLY BUSHING: FROM MSL ~G 0 ~ i99~ 53.83 DERRICK FLOOR: ~aska 0~i ~ ......... ~,~,~,ll$$ion 24 40 GROUND LEVEL: - . ~An¢~om-~ WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 11966.0 6.000 12818.0 MWD - DGR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUN 3 ONE RECORDED SLIM PHASE 4 RESISTIVITY/GAMMA RAY RUN WHICH INVOLVED: 1) ONE MAD PASS OVER PRODUCTION ZONE WHILE TRIPPING IN THE HOLE (MAD PASS IN: 12100 - 12400'). 2) ONE DRILLED SECTION (MWD RUN 1: 12600 - 12800') 3) ONE MAD PASS OVER THE "A" SAND ZONE WHILE PULLING OUT OF THE HOLE (MAD PASS OUT: 12425 - 12750'). ALL MWD DATA WAS DEPTH SHIFTED TO WIRELINE PER GEOLOGIST. THE "MAD PASS OUT" WAS DEPTH SHIFTED TO THE MWD DRILLED DATA. DEPTH SHIFTS WERE SINGLE BLOCK SHIFTS AS FOLLOWS: "MAD PASS IN" & "MWD RUN 1" WERE SHIFTED UP 12'. "MAD PASS OUT" WAS SHIFTED UP 6'. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12616.0 12782.0 RP 12623.0 12789.0 $ BASELINE CURVE FOR SHIFTS: open hole GR dated 24-JAN-95 (WALS) CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BIT RUN NO MERGE TOP 1 12653.0 MERGE BASE 12818.0 MWD MAIN PASS (NO MAD DATA). ALL DATA HAS BEEN BLOCK SHIFTED UP 12' TO WIRELINE PER GEOLOGIST'S INSTRUCTIONS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR M~ND 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 995 99 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE~ 0) 998 BYTES * Total Data Records: 20 Tape File Start Depth = 12900.000000 Tape File End Depth = 12600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4809 datums Tape Subfile: 2 111 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RP $ MERGED DATA SOURCE PBU TOOL CODE GR GR RP RP $ REMARKS: CN WN FN COUN STAT .5000 START DEPTH 12085.0 12092.0 STOP DEPTH 12740.0 12747.0 MAD RUN NO. MAD PASS NO. MERGE TOP 1 1 12085.0 1 2 12415.0 1 1 12092.0 1 2 12422.0 MERGE BASE 12376.0 12740.0 12383.0 12747.0 MERGED MAD PASS. "MAD PASS IN" (PASS 1) HAS BEEN BLOCK SHIFTED UP 12'. "MAD PASS OUT" (PASS 2) HAS BEEN BLOCK SHIFTED UP 6'. $ : BP EXPLORATION (ALASKA) : MPE-11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX MAD 68 1 OHMM 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 4 95 995 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 43 Tape File Start Depth = 12900.000000 Tape File'End bepth = 12000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10807 datums Tape Subfile: 3 72 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 12628.0 EWR4 12635.0 $ 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: STOP DEPTH 12794.0 12801.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 26-JAN-95 MWD 2.19A SP4 1.12 MEMORY 12818.0 12665.0 12818.0 0 57.8 58.9 TOOL NUMBER P0002SP4 P0002SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 11966.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: GEL/PAC/XANVIS 12.20 48.0 10.0 1000 4.8 2.100 69.0 .940 164.0 1.600 69.0 3.200 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT "MWD RUN 1" (BIT #5). $ : BP EXPLORATION (ALASKA) : MPE-11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API . Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 995 99 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 20 Tape File Start Depth = 12900.000000 Tape File End Depth = 12600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9618 datums Tape Subfile: 4 85 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE S~RY VENDOR TOOL CODE START DEPTH DGR 12097.0 EWR4 12104.0 $ 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: STOP DEPTH 12388.0 12395.0 26-JAN-95 MWD 2.19A SP4 1.12 MEMORY 12818.0 12134.0 12424.0 0 57.8 58.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0002SP4 P0002SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): 6.000 11966.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: GEL/PAC/XANVIS 12.20 48.0 10.0 1000 4.8 2.100 69.0 .940 164.0 1.600 69.0 3.200 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN)' .0 EWR FREQUENCY (H~) : 0 REMARKS: "MAD PASS IN". $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 2 RPX MAD 68 1 OHMM 3 RPS MAD 68 1 OHMM 4 RPM MAD 68 1 OHMM 5 RPD MAD 68 1 OHM/~ 6 ROP MAD 68 1 FPHR 7 FET MAD 68 1 HR 4 95 995 99 1 4 95 120 46 1 4 95 120 46 1 4 95 120 46 1 4 95 120 46 1 4 95 810 01 1 4 95 180 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 30 998 BYTES * Tape File Start Depth = 12450.000000 Tape File End Depth = 12000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18016 datums Tape Subfile: 5 96 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 12421.0 EWR4 12428.0 $ 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: STOP DEPTH 12746.0 12753.0 26-JAN-95 MWD 2.19A SP4 1.12 MEMORY 12818.0 12457.0 12780.0 0 57.8 58.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0002SP4 P0002SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 11966.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: GEL/PAC/XANVIS 12.20 48.0 10.0 1000 4.8 2.100 69.0 .940 164.0 1.600 69.0 3.200 69.0 NEUTRON TOOL MATRIX' MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) · .0 EWR FREQUENCY (H~): REMARKS: "MAD PASS OUT". $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE-11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MAD 68 1 AAPI 4 2 RPX FLAD 68 1 OHMS4 4 3 RPS MAD 68 1 OHMM 4 4 RPM MAD 68 1 OHMM 4 5 RPD MAD 68 1 OHMM 4 6 RATE MAD 68 1 FPHR 4 4 95 995 99 1 4 95 120 46 1 4 95 120 46 1 4 95 120 46 1 4 95 120 46 1 4 95 995 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 12800.000000 Tape File End Depth = 12400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15226 datums Tape Subfile: 6 89 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS 95/ 7/25 01 **** REEL TRAILER **** 95/ 7/26 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 26 JLY 95 8:08a Elapsed execution time = 3.95 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6352.00 J. DAHL COOK/PYRON OPEN HOLE MPE - 11 500292254100 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 27-JAN-95 RUN 2 RUN 3 25 13N 10E 3684 1992 53.83 53.83 24.40 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 PRODUCTION STRING 6.000 REMARKS: DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 2000, 23-JAN-95. 11966.0 12664.0 REPEAT SECTION NOT LOGGED DUE TO HOLE CONDITIONS. UNABLE TO REACH TD. LOGGED FROM DEEPEST POINT REACHED. GAMMA RAY RECORDED IN CASING FOR DEPTH REFERENCE. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. TOOL APPEARS TO HAVE TURNED 90 DEGREES FROM UP/DOWN HOLE GEOMETRY. EXCESSIVE CORRECTION/PE RESPONSE SHOWS MUDPATH/MUDBALL IN THE MEASURING WINDOW OF THE TOOL. BARITE PRESENT IN THE MUD SYSTEM (10.5%) WILL EFFECT PE RESPONSE. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH LL8 11963.0 11975.5 11985.0 11986.5 11987.0 11994.0 12009.5 12013.0 12015.5 12018.0 12043.5 12056.5 12062.0 12062.5 12073.0 12090.5 12091.0 12102.5 12104.5 12122.5 12123.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL SDN 2435 $ REMARKS: depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 11960.0 12106.0 11960.0 12161.0 11960.0 12130.0 11960.0 12112.0 EQUIVALENT UNSHIFTED DEPTH ILD NPHI RHOB 11963.0 11975.0 11986.0 11987.5 11986.0 11988.0 12010.5 12008.5 12009.5 12056.5 12056.5 12062.0 11987.5 11994.0 12009.5 12013.0 12015.0 12018.0 12043.5 12057.0 12062.5 12062.5 12074.5 12073 . 5 12073.5 12074.0 12090.5 12091.5 12123.5 12104.0 12106.0 12091.5 12105.5 12123.5 RUN NO. PASS NO. MERGE TOP 1 1 11960.0 1 1 11960.0 1 i 11960.0 1 1 11960.0 OPEN HOLE portion of MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LLS. ILM, SP, RT, & DI WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. all runs merged; MERGE BASE 12106.0 12161.0 12130.0 12112.0 no case / ? ?MATCH1. OUT / ? ?MATCH2. OUT CN WN FN COUN STAT / ? ?MATCH3. OUT / ??MATCH4. OUT $ : BP EXPLORATION (ALASKA) : MPE - 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 2 LL8 DIL 68 1 OHMM 3 ILM DIL 68 1 OHMM 4 ILD DIL 68 1 OHMM 5 RT DIL 68 1 OHMM 6 DI DIL 68 1 IN 7 SP DIL 68 1 MV 8 MTEM DIL 68 1 DEGF 9 TEND DIL 68 1 LB 10 TENS DIL 68 1 LB 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 i IN 15 NPHI 2435 68 1 PU-S 16 FUCT 2435 68 1 CPS 17 NUCT 2435 68 1 CPS 4 4 55 965 57 0 4 4 50 746 76 1 4 4 50 746 76 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 34 Tape File Start Depth = 12196.000000 Tape File End Depth = 11960.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8515 datums Tape Subfile: 2 167 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11400.0 $ STOP DEPTH 11960.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 MTEMGR 68 1 DEGF 3 TEND GR 68 1 LB 4 TENS GR 68 1 LB 4 4 21 990 60 6 4 4 45 987 88 5 4 4 10 579 41 1 4 4 10 579 41 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 24 Tape File Start Depth = 11960.000000 Tape File End Depth = 11372.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5886 datums Tape Subfile: 3 51 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 1 .2500 VENDOR TOOL CODE START DEPTH GR 11400.0 DIFL 11947.0 ZDL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 11940.0 11940.0 STOP DEPTH 12130.0 12186.0 12154.0 12132.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL TEMP PCM DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 24-JAN-95 FSY JlV2 BETA RELEASE 4 2000 23-JAN-95 510 24-JAN-95 12664.0 12164.0 11960.0 12161.0 1500.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 2806XA 3506XA 1503XA 6.000 11966.0 11960.0 XANVI S GEL 12.20 46.0 10.3 5.0 161.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPE - 11 : MILNE POINT : NORTH SLOPE : ALASKA 1.760 .847 1.690 .000 2.930 .000 THERMAL SANDSTONE 2.65 .000 1.5 74.0 161.0 70.0 .0 68.0 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN VILD DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 67 456 14 5 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 04 903 06 0 4 06 213 78 0 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 4 78 867 34 0 4 78 867 34 0 4 13 331 34 0 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 4 83 368 34 1 84 * DATA RECORD (TYPE# 0) Total Data Records: 300 974 BYTES * Tape File Start Depth = 12196.000000 Tape File End Depth = 11372.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 81050 datums Tape Subfile: 4 380 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 5 is type: LIS 95/ 1/27 01 **** REEL TRAILER **** 95/ 1/27 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 27 JAN 95 3:52p Elapsed execution time = 6.20 seconds. SYSTEM RETURN CODE = 0
