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203-213
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 05/17/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-87A (PTD 203-213) MFC 03/19/2022 Please include current contact information if different from above. PTD:203-213 T36624 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.18 09:48:21 -08'00' RECENED STATE OF ALASKA • ALA OIL AND GAS CONSERVATION COMMMION Q of REPORT OF SUNDRY WELL OPERATIONS `fir 1.Operations Abandon U Plug Perforations U Fracture Stimulate[ Pull Tubing LI P1 r r hutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair We110 Re-enter Susp Well❑ Other: ESP Change-out 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 203-213 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Ell Service ❑ 6.API Number: AK 99503 50-029-23184-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025509/ADL0355018/ADL0388235 MILNE PT UNIT F-87A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 9,751 feet Plugs measured N/A feet true vertical 7,431 feet Junk measured 9,656 feet Effective Depth measured 9,656 feet Packer measured N/A feet true vertical 7,337 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 4,910' 9-5/8" 4,945' 4,457' 5,750psi 3,090psi Production 9,710' 7" 9,742' 7,422' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet CONE° °. ' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 9,330' 7,019' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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 0 580 0 Subsequent to operation: 159 27 1,634 140 222 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 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ 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: 318-032 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: Date: 3/23/2018 Contact Phone: 777-8333 // atRBDMS.iI APS 0 6 2018 Form 10-404 Revised 4/2017 Submit Original Only • Milne Point Unit Well: MPU F-87A SCHEMATIC Last Completed: 3/7/2018 Ifileorp Alaska,LLC PTD: 203-213 TREE&WELLHEAD Tree 2-9/16" Orig.KB Elev.:45.05'/Cellar box Elev.:11.1' FMC 11"Gen 5 Casing Hanger.FMC 11"x 2-7/8" s a Wellhead Tbg.Hngr.w/EUE 8rd top and bottom and 2.5" 20' ' '� iil ow`H'BPV profile ail + '' OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset I(approx.)in 42"hole rif 9-5/8" 725 sx Class"L",225 sx Class"G"in 12-1/4"hole ' 7" 200 sx Class"G"in 8-1/2"Hole a,< 4 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF «a a 20" Conductor 94/H-80/N/A N/A Surface 112' N/A Lirel 44f. 9-5/8" Surface 40/L-80/BTC 8.835 Surface 4,945' 0.0758 7" Production 26/L-80/BTC-mod 6.276 Surface 9,742' 0.0383 V' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 9,380' 0.0058 4 '' WELL INCLINATION DETAIL 95/8"A KOP @ 1,000' Max Hole Angle=63.4 deg.@ 6,220' Hole Angle through perforations=10 deg. JEWELRY DETAIL No Top(MD) Item 1 134' GLM STA 2:Camco 2 7/8 X 1"Side pocket,W/Orifice 2 9,119' GLM STA 1:Camco 2 7/8 X 1"Side pocket,W/Dummy 3 9,228' 2-7/8"XN Nipple-ID=2.205"No-Go 4 9,271' Discharge Head:GPDIS 5 9,272' Pump:SXD 137P17 6 9,291' Gas Separator:GRSFTXAR H6 7 9,296' Upper Tandem Seal:GSB3DBUTSB/SB PFSA 8 9,303' Lower Tandem Seal:GSB3DBLT SB/SB PFSA CL5 9 9,310' Motor:XP-250 HP/2,505V/61A 10 9,326' Sensor:WeIILIFT E 11 9,328' Centralizer:Bottom @ 9,330' C 2 PERFORATION DETAIL Min ID 2.205"@f. 3 Sands Top Btm Top Btm FT Date Status Size SPF 9,228'MD `{ (MD) (MD) (TVD) (TVD) 4 '" 5 9,467' 9,477' 7,151' 7,161' 10 1/27/2004 Open 3-3/8" 12 Kup.A Sands 9,485' 9,495' 7,169' 7,179' 10 1/27/2004 Open 3-3/8" 12 6&7 9515' 9,525' 7,198' 7,208' 10 1/27/2004 Open 3-3/8" 12 AHI g Ref Log:SWS USIT Primary Depth Control Log Dated:1/8/2004 !i ,9&10 STIMULATION SUMMARY 1 1/30/2004 225K lbs Carbolite behind pipe, t'. 11 CASING PRESSURE TEST p° t, Casing tested to 2,500psi from 9,400'on 11/27/2012 ESP CABLE SPLICE DETAIL �r ESP Cable Spliced at 4,684' A' 13 ,�,, GENERAL WELL INFO I." }KUPASands API:50-029-23184-01-00 Drilled and Set 20"&9-5/8"Casing by Doyon 14-12/12/2003 k A Drilled and Set 7"Casing and Completion by Doyon 14-12/19/2003 4 3 SS ESP bands ESP RWO by Nabors 4ES-4/4/2004 «, * " lost during Sept 2009 RVQ ESP RWO by Nabors 4ES-9/28/2004 7 AtOrn -' ESP RWO by Nabors 4ES-12/26/2005 TD=9,751(MD)/1D=7,43r(TVD) ES P RWO by Nabors 3S-11/13/2008 PBTD=9,656"(MD)/PBTD=7,337'(TVD) ESP RWO by Nabors 4ES-9/13/2009 ESP RWO by Doyon 16-12/29/2012 ESP RWO by ASR#1-3/7/2018 Revised By:TDF 3/23/2018 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-87A ASR#1 50-029-23184-00-00 213-176 3/3/18 3/7/18 Daily Operation ,„ 2/28/2018-Wednesday No activity to report. 3/1/2018-Thursday No activity to report. 3/2/2018- Friday No activity to report. 3/3/2018-Saturday Well kill complete w/8.5ppg 120deg seawater. 150psi pressure seen on TBG and 50psi pressure on IA.Attempt to bleed pressure off fromTBG. No success,TBG pressure began increasing f/ 150psi to 175psi. Decision to weight up and perform well kill w/9.2ppg KWF. Contact I-rig to borrow KWF. PEAK deliver 110bbIs of 9.2ppg KCI,followed by 235bbls f/345bbls total. Perform well kill by pumping 78bbls of 9.2ppg KCI brine down TBG w/80% returns. Decision made to bullhead IA. Shut TBG and line up to pump down IA. Bullhead 266bbIs down the IA. Shut down pumps and allow pressure to fall off. Monitor pressure on TBG and IA. 500psi TBG and 400psi IA when pumps shut down. Pressure bled down to 200psi TBG and 75psi IA after 20mins.TBG holding @ 200psi, IA @ 40psi after 60mins. SIMOPS: blow down lines from circulation trailer back to rig pump. R/D hard line. Well on a vacuum.Wellhead rep on location to set BPV. Roads and Pads on location w/crane to pull tree and set BOPE. 3/4/2018-Sunday Continue to R/U on well F-87.Shuffle equipment over f/well F-18. Set BOPE in place, spot well house, mud boat, back carrier into position, raise mast, set up rig floor. Continue to R/U on well F-87. R/U all interconnect lines and hoses. BOPE hydraulic lines, glycol heating lines, and tarp secure. Perform Sundry meeting.Take on ambient temperature fresh water, fill the BOPE stack and prep to shell test. Contact AOGCC rep Matt Herrera and notify rig is ready to begin testing. 3/5/2018- Monday Cont. shell test repairing deficiencies, shell test t/2,500 good,Test BOPE as per Hilcorp &AOGCC requirements,test was witnessed by AOGCC inspector Matt Herrera,tested with 2-7/8"Ti 250/2,500psi, had 2-FP,test on K-3 &C-6 changed out K- 3 tested good, serviced C-6 tested good,tested accumulator only one pump operated, (electricians were working on system) Electricians cont. w/wiring up heater, troubleshoot reset, change out heaters on starter,test accumulator system good, repair bolt on elevators, p/u retrieving tool for blanking sub, preform accumulator drawdown test good Pull blanking sub, & BPV, m/u landing jt, back out L/D pins Pull hanger @ 18k, strig moving @ 85k, even out @ 81k, pull hanger to floor, fill hole POOH w/ ESP completion on 2-7/8" EUE TBG f/9,380'md to discharge head @ "70'md. Fill hole utilizing double metal displacement. Pump 5bbls down IA once at the discharge head.Junk 190 joints. 103 joints remaining to be run on bottom of completion. L/D ESP as per Baker Centrilift. Recover 1 SS band in a motor protectrolizer from previous ESP swaps. Unload old TBG into pipe tub to make room for new pipe on pipe racks. Plan to run old pipe first in the hole. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-87A ASR#1 50-029-23184-00-00 213-176 3/3/18 3/7/18 Daily Operations: 3/6/2018-Tuesday Cont. L/D esp asst'. Service rig, Load 2-7/8" completion string, 190 jts new& 103 jts used 2 7/8" 6.5# L-80 EUE 8rd tubing. P/U & service ESP assy. test cable good RIH p/u 2 7/8" tubing. testing cable first 1000'then every 2k' after t/"2,000'md Continue to RIH w/ ESP completion on 2-7/8" EUE TBG to —4,500'md (JNT 145) Stop to perform cable splice. Baker Centrilift perform cable to cable splice. ASR crew line up and pump down TBG to verify fluid depth and ensure ESP is clear. 4bbls to catch pressure and 1 bbl for pressure to level off(900psi). Blow down all fluid lines when pumping complete. Continue to RIH w/ ESP completion on 2-7/8" EUE TBG f/"4,500'md to —8,800'md.Verify ESP cable conductivity every 2,000'md. 111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP F-87A ASR#1 50-029-23184-00-00 213-176 3/3/18 3/7/18 Daily Operations: 3/7/2018-Wednesday Cont. RIH t/9179',fill tubing 4bbls break circulation through asst' @ .5 BPM, 540psi, cont,tih t/9,321'test cable good. P/U hanger& landing jt. make hanger penetrator splice &test good. Land hanger placing assy tail @ 9,330', run in L/D pins, set BPV. R/D, prep t/move rig& component's, stage on L-pad. Move pits, camps &TP trailer t/L-49, r/d floor& BOPE, N/U tree &test t/5k good 3/8/2018-Thursday No activity to report. 3/9/2018-Friday No activity to report. 3/10/2018-Saturday No activity to report. 3/11/2018-Sunday No activity to report. 3/12/2018- Monday No activity to report. 3/13/2018-Tuesday No activity to report. ., F T� • • \��\I/W sV THE STATEAlaska Oil and Gas ofALA® Conservation Commission ____ SKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS" Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager �� i li } Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool,MPU F-87A Permit to Drill Number: 203-213 Sundry Number: 318-032 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, 6t3XX ' Hollis S. French Chair DATED this10 day of January, 2018. RETMS S Lam- f 3 - 1 2018 YiElik.oLIVED JAN 201 STATE OF ALASKA Or$ t 30/ (? ALASKA OIL AND GAS CONSERVATION COMMISSION AO CC APPLICATION FOR SUNDRY APPROVALS �✓ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0. 203-213 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23184-01-00 • 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 0 1 MILNE PT UNIT F-87A ' 9.Property Designation(Lease Number): , 10.Field/Pool(s): ADL0025509/ADL0355018/ADL0388235 MILNE POINT/KUPARUK RIVER OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,751' . 7,431' • 9,656' • 7,337'• 1,691 N/A 9,656' Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 112' 112' N/A N/A Surface 4,910' 9-5/8" 4,945' 4,457' 5,750psi 3,090psi Production 9,710' 7" 9,742' 7,422' 7,240psi 5,410psi 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/EUE 8rd 9,380' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/23/2018 Commencing Operations: OIL 0 • WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG 0 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 G\G� Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan(p7hiIcorp.com A Contact Phone: 777-8333 Authorized Signature: Date: 'As l0►h C 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Integrity MD— OS 2 Plug 9 y ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: g 2500 z!✓5�.. Liv /e...5/' Post Initial Injection MIT Req'd? Yes ❑ No ❑ SpacingException Required? o LJ /0 – -/ i1, x?!'°+P4� p q YesNo Subsequent Form Required: (( �;:.-..tee.M LL-1 : - T 2L18 APPROVED BY •� Approved by: COMMISSIONER THE COMMISSION Date: I S b l j fp.8 //lick ,00,1.140 ORIGINAL at r-- 36-& Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Mewl)Alaska,LLQ Well: MPU F-87A Date:1/24/2018 Well Name: MPU F-87A API Number: 50-029-23184-01 Current Status: Oil Well Pad: F-Pad Estimated Start Date: February 23rd, 2018 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-213 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AF m = Ei\I u ber�� � Job SPfiteAtiair _� '� u I Current Bottom Hole Pressure: 2,393 psi @ 7,018'TVD (ESP Gauge 09/19/2017/6.56 ppg EMW) Maximum Expected BHP: 2,393 psi @ 7,018'TVD (No new perfs being added' MPSP: 1,691 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-87A was drilled in December 2003, fracture stimulated in January 2004, and completed as a jet pumped Kuparuk River producer in February 2004. Converted from jet pump to ESP in April 2004. ESP installation history: April 2004 (initial),September 2004, December 2005, November 2008,September 2009, and November 2012. The ESP has failed. Notes Regarding Wellbore Condition C£ • The 7" production casing was tested down to 9400' MD/2500 psi on November 27, 2012. • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. F - ' Objective: Replace failed ESP. Pre-Rig Procedure: ASA 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. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down_ tubing, taking returns up casing to 500 bbl returns tank. ._ 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. dL.. i✓ 9. NU BOPE house. Spot mud boat. • • Well Prognosis Hilcorp Alaska,LL Well: MPU F-87A Date: 1/24/2018 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2 500psi High, annular to 250 psi Low/2.500 psi H'•h (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. '13. 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 test. rrl�' b. With stack out of the test path, test choke manifold per standard procedure s1) 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 Cf 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. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2012 ESP swap was 110K lbs. (40K block weight) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. 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. �, 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used as noted. Lay e- i down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP assembly at±9,378' MD. cje • • Well Prognosis HiLeon)Alaska,LL) Well: MPU F-87A Date: 1/24/2018 a. Upper GLM @ ± 140' MD w/SO b. 2-7/8" tubing c. Lower GLM w/ DGLV d. 3 joints of 2-7/8" tubing e. 2-7/8" XN (2.205" No-Go) f. 3 joints of 2-7/8" tubing g. Base of ESP centralizer @ ±9,378' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull_.BPV,,_., 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form II • • Milne Point Unit Well: MPU F-87A SCHEMATIC Last Completed: 11/29/2012 Hileorp Alaska,LLC PTD: 203.213 TREE&WELLHEAD Tree 2-9/16" Orig.KB Elev.:45.05' Cellar box Elev.:11.1' FMC 11"Gen 5 CasingHanger.FMC 11"x 2-7/8" g / g Wellhead Tbg.Hngr.w/EUE 8rd top and bottom and 2.5" V 44 20'� « t CIW`H'BPV profile OPEN HOLE/CEMENT DETAIL `, 1 a 20" 260 sx of Arcticset I(approx.)in 42"hole p fT 9-5/8" 725 sx Class"L",225 sx Class"G"in 12-1/4"hole r' 7" 200 sx Class"G"in 8-1/2"Hole r CASING DETAIL / 1 Size Type Wt/Grade/Conn ID Top Btm BPF 420" Conductor 94/H-80/N/A N/A Surface 112' N/A qtil « i* 9-5/8" Surface 40/L-80/BTC 8.835 Surface 4,945' 0.0758 7" Production 26/L-80/BTC-mod 6.276 Surface 9,742' 0.0383 14 " TUBING DETAIL 4 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 9,380' 0.0058 WELL INCLINATION DETAIL 9-5/8"a it KOP @ 1,000' Max Hole Angle=63.4 deg.@ 6,220' Hole Angle through perforations=10 deg. JEWELRY DETAIL No Top(MD) Item 5� 1 142' GLM STA 2:2-7/8"x 1"KBMM w/DSOV 2 9,118 GLM STA 1:2-7/8"x 1"KBMM w/Dummy j� 3 9,262' 2-7/8"XN Nipple-ID=2.205"No-Go ks. > 4 9,305' Gauge Unit 2-7/8":WeIILift DGU Otl! 5 9,310' Discharge Head:GPDIS 6 9,310.3' Pump 1:PMSXD 119P23 7 9,328' Pump 2:PMSXD 18P75 8 9,335' Gas Separator:GSTHVEVX 9 9,340' Upper Tandem Seal:GSB3DBUT 10 9,347' Lower Tandem Seal:GSB3LT r 11 9,354' Motor:MSP1-294 HP/2,315V/77A 2 sf 12 9,376' Sensor:WeIILift MGU Min ID g,' AR w13 9,378' Centralizer:Bottom @ 9,380' 2.205"@ p 3 9,262'MD "r PERFORATION DETAIL y 4 , 6 Top Btm Top Btm ,,, Sands FT Date Status Size SPF (MD) (MD) (TVD) (TVD) xr mg 4268`7 9,467' 9,477' 7,151' 7,161' 10 1/27/2004 Open 3-3/8" 12 4 W g Kup.A Sands 9,485' 9,495' 7,169' 7,179' 10 1/27/2004 Open 3-3/8" 12 .n 9&10 9515' 9,525' 7,198' 7,208' 10 1/27/2004 Open 3-3/8" 12 Ref Log:SWS USIT Primary Depth Control Log Dated:1/8/2004 koSTIMULATION SUMMARY 4 1 rii 1/30/2004-225K lbs Carbolite behind pipe, g CASING PRESSURE TEST a , 1z Casing tested to 2,SOOpsi from 9,400'on 11/27/2012 $. 13 :' jai. -KUP A Sands 4,0 GENERAL WELL INFO API:50-029-23184-01-00 g� '.. i„,.,) Drilled and Set 20"&9-5/8"Casing by Doyon 14-12/12/2003 S « 355 ESP bands Drilled and Set 7"Casing and Completion by Doyon 14-12/19/2003 y. u`9 lost during Sept ESP RWO by Nabors 4ES-4/4/2004 "- 2009 RVW 7' cte -W rt ESP RWO by Nabors 4ES-9/28/2004 TD=9,751(MD)/TD=7,43r(TVD) ESP RWO by Nabors 4ES-12/26/2005 PBTD=9,656"(MD)/PBTD=7,337'(TVD) ESP RWO by Nabors 3S-11/13/2008 ESP RWO by Nabors 4ES-9/13/2009 ESP RWO by Doyon 16-12/29/2012 Revised By:PC 1/24/2018 • • Milne Point Unit PROPOSED Well: MPU F-87A Last Completed: 11/29/2012 Hilcorp Alaska,LLC PTD: 203-213 TREE&WELLHEAD Tree 2-9/16" Orig.KB Elev.:45.05'/Cellar box Elev.:11.1' FMC 11"Gen 5 Casing Hanger.FMC 11"x 2-7/8" - kk Wellhead Tbg.Hngr.w/EUE 8rd top and bottom and 2.5" k ow'H'BPV profile 20 ) F OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset I(approx.)in 42"hole 44 ri 4 9-5/8" 725 sx Class"L",225 sx Class"G"in 12-1/4"hole i,n 7" 200 sx Class"G"in 8-1/2"Hole s' ts ;s1; 141 CASING DETAIL 13 1 Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-80/N/A N/A Surface 112' N/A `10 10 tt 9-5/8" Surface 40/L-80/BTC 8.835 Surface 4,945' 0.0758 7" Production 26/L-80/BTC mod 6.276 Surface 9,742' 0.0383 il , TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±9,380' 0.0058 s` WELL INCLINATION DETAIL 9-5/8",11 1 KOP @ 1,000' Max Hole Angle=63.4 deg.@ 6,220' Hole Angle through perforations=10 deg. JEWELRY DETAIL No Top(MD) Item 1 142' GLM STA 2:2-7/8"x 1"w/DSOV 2 ±9,118 GLM STA 1:2-7/8"x 1 w/Dummy 3 ±9,262' 2-7/8"XN Nipple-ID=2.205"No-Go 4 ±9,310' Discharge Head: 5 ±9,310.3' Pump 1: 6 ±9,328' Pump 2: 7 ±9,335' Gas Separator: 8 ±9,340' Upper Tandem Seal: 9 ±9,347' Lower Tandem Seal: 10 ±9,354' Motor: 11 ±9,376' Sensor: k' 2 ,wa 12 ±9,378' Centralizer:Bottom @ 9,380' Min ID 2.205"@ ' -r 3 9,262'MD : PERFORATION DETAIL jgr Zia Top Btm Top Btm Sands (MD) (MD) (TVD) (TVD) FT Date Status Size SPF isi {5&6 9,467' 9,477 7,151' 7,161' 10 1/27/2004 Open 3-3/8" 12 III ;17 Kup.A Sands 9,485' 9,495' 7,169' 7,179' 10 1/27/2004 Open 3-3/8" 12 8&9 9515' 9,525' 7,198' 7,208' 10 1/27/2004 Open 3-3/8" 12 Ref Log:SWS USIT Primary Depth Control Log Dated:1/8/2004 s: ts`i STIMULATION SUMMARY l 10 1/30/2004-225K lbs Carbolite behind pipe, VZ 11 CASING PRESSURE TEST t=t , Casing tested to 2,500psi from 9,400'on 11/27/2012 12 c.': ti a}KUP A Sands GENERAL WELL INFO API:50-029-23184-01-00 A Drilled and Set 20"&9-5/8"Casing by Doyon 14-12/12/2003 /14 3 SS ESP bands Drilled and Set 7"Casing and Completion by Doyon 14-12/19/2003 last during Sept t. E,,, ESP RWO by Nabors 4ES-4/4/2004 7” cl1r4WO ESP RWO by Nabors 4ES-9/28/2004 TD=9,751(MD)/TD=7,43r(TVD) ESP RWO by Nabors 4ES-12/26/2005 PBTD=9,656"(MD)/PBTD=7,337'(TVD) ESP RWO by Nabors 3S-11/13/2008 ESP RWO by Nabors 4ES-9/13/2009 ESP RWO by Doyon 16-12/29/2012 Revised By:PC 1/24/2018 • Milne Point ASR Rig 1 BOPE 2018 110. 11a•kt, •M ; 11" BOPE Stripping Head 4.48' Hydril GK 11" _ 5000 IiI ill it l lii iil l!l I I I tit I!L tim CI _U ittilL 4.54' `1�� Jo ( VBR or Pipe Rams ui 11"-5000 -��1 C� �= Blind ;MU ill Iii iil 111 lil 2 1/16 5M Kill Line Valves 21/16 5M Choke Line Valves III {III!! !!) I!! 2.00' Ii'iIIiIIii r . - • "C r Manual Manual Manual HCR Updated 1/05/2018 • lb � ) 42) CI ƒ � � C ® ° 0 7 /LI0LI 2 U 2 22 § / « � E ® • c o . 'CS (/) % %Yt2 / %f 0. � \ T)- 0. ..._ ± E « m 7 o D0 22 ¢ \ Y � p < a. e'S I C R / a: >03, % .§ ■ m 3 \ k a S § CO / 4- CD 0 4. 4 — 0 k \ Q < \k o > m & /• k % 0 \ Q C / 2 \ 0 o \ � o 0 0 E § 0 0 k0• • C.) i .o a \ / TS 2»y Cl) f m \ \ � st / ° co * o o CL k § ■ as& 13) 4 4 4" m « m / ca 2 w ~ CO k 0 0 ° 0 / R � \ u. 't c & .o o e w o « / co a O O : V E• 0 > as li Q e 0 oco co \ 0 < 2 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Qa. - â.13 Well History File Identifier Organizing (done) D Two-sided III" 11111111111111 D Rescan Needed 1111111111111111111 RESCAN ror Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ~- , "1 Date: :}"J-.~ ch D Other:: W 111111111111111111 j 151 mr 151 Project Proofing BY: (Maria J , f ' Date: d- :w nb / I X 30, = 1 0 Date: d-- ~ Ö.h ( + a..~ = TOTAL PAGES ~¿;-'<6 (Count does not include cover sheet) V1A J 151 , r ~' 1111111111111111111 Scanning Preparation BY: C. Maria) Production Scanning Stage 1 rC' Page Count from Scanned File: 0 (Count does include cover sheet) Page Count Matches Number in Scanping Preparation: V YES ç MariJ Date: ~ ~~, Ob Stage 1 If NO in stage 1, page(s) discrepancies were found: 151 NO . ''Ì yv" .J BY: YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page,doc STATE OF ALASKA ifiKA OIL AND GAS CONSERVATION C•ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® 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 203 -213 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 23184 -01 -00 0 7. Property Designation (Lease Number): WTI 8. Well Name and Number: . 5 ADL 025509 & 355018 0-1421 - MPF - 87A 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 9751' feet Plugs:(measured) None feet true vertical 7431' feet Junk: (measured) -9656' feet Effective depth: measured 9656' feet Packer: (measured) None feet true vertical 7337' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1530 520 Surface 4910' 9 -5/8" 4945' 4457' 6870 4760 Intermediate Production 9710' 7" 9742' 7422' 7240 5410 Liner Perforation Depth: Measured Depth: 9467' - 9525' feet SCANNED FEB 2 8 2013 True Vertical Depth: 7151' - 7208' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 9380' 7067' Packers and SSSV (type, measured and true vertical depth): None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): RECEIVED Treatment description including volumes used and final pressure: DEC 2 1 2012 AOGCC 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 309 53 1613 320 225 Subsequent to operation: 146 72 1859 280 229 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: Sean McLau.hlin, 564 -4387 N/A Email: Sean.McLaughlin @bp.com Printed - - Joe . 121, I( , ` r Title: Drilling Technologist Signature: I ' Phone: 564 -4091 Date: 1 Form 10 -404 Re ed 10/2012 .. F 2 1 MU ge-,\ ,,• Submit Original Only • • Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/24/2012 06:00 - 09:30 3.50 MOB P PRE PJSM. REMOVE SHIMS, MOVE OFF OF MPF -02. - STAGE EQUIPMENT IN CELLAR, MOVE RIG MATS. - CHECK VA PRESSURE ON MPF -87, 1200 PSI. SHUT IN. - MOVE OVER MPF -87. SHIM RIG, SPOT SLOP TANK/FUEL TRAILER. 09:30 - 12:00 2.50 MOB P PRE ,PJSM. RIG UP CIRC LINES IN CELLAR. HARD LINE CREW SPOTTING FLOW BACK TANK. - RIG UP HARDLINE TO FLOW BACK TANK. - CLAMPS AND SAFETY CABLES. RIG ACCEPTED @ 12:00 HRS, 11/24/2012. 12:00 - 13:00 1.00 KILLW P INTERV PJSM. TEST ALL HARD LINE @ 250 / 3500 PSI. - PRESSURE TESTS CONDUCTED WITH DIESEL. 13:00 - 16:00 3.00 KILLW P INTERV PERFORM ESP AND RIG EVACUATION DRILL. - WSL, TOOL PUSHER AND CREW. CONDUCT AAR. 16:00 - 18:00 2.00 KILLW P INTERV PJSM. R/U LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA. CHARTED. PULL BPV. TBG= 1140 PSI. I /A= 1200 PSI. - SHUT IN TREE. R/D LUBRICATOR. 18:00 - 21:00 3.00 KILLW P INTERV PJSM, FILL PITS WITH 120 DEG 11 PPG BRINE. - LOAD PIPESHED WITH 4" DRILL PIPE. 21:00 - 21:30 0.50 KILLW P INTERV PJSM. REVIEW DDI SOP FOR WELL KILL. - IN ATTENDANCE. DAY AND NIGHT WSL, DDI FIELD SUPERINTENDANT, TOOL PUSHER, TOUR PUSHER, MI, SCS, TRUCK DRIVERS, DRILLER AND CREW. - REVIEW WELL KILL PLAN. ROLES AND RESPONSIBILITIES. - USE DETAILED COMMUNICATION. MUSTER AREA LOCATION. Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:30 1.00 KILLW P INTERV WSL AND TOOL PUSHER VERIFY AND SIGN OFF ON VALVE ALIGNMENT. - DRILL SITE OPERATOR AND MILNE PT BASE CAMP NOTIFIED. - WITH CHOKE BLEED GAS OFF VA TO FLOWBACK TANK UNTIL FLUID RETURNS. - SHUT IN CHOKE. SICP= 1100 PSI. LINE UP TO PUMP DOWN TBG TAKING RETURNS OUT VA TO CHOKE. WSL AND TOOL PUSHER VERIFY AND SIGN OFF ON VALVE ALIGNMENT. - AGAINST CLOSED CHOKE. START PUMP. MANIPULATE CHOKE HOLDING CSG PRESSURE CONSTANT AT 1250 PSI. PUMP 55 BBLS 11 PPG KWF DOWN TBG 3 BPM 1650 PSI. - MAINTAIN 1250 PSI ON CSG WITH CHOKE KEEPING 150 PSI DOWNSTREAM OF CHOKE. - TAKING RETURNS TO FLOWBACK TANK. - CLOSE CHOKE INITIALIZING BULLHEAD OPERATION. WSL AND TOOL PUSHER VERIFY AND SIGN OFF ON VALVE ALIGNMENT. BULLHEAD 20 BBLS 120 DEG 11 PPG KWF 5 BPM 2260 PSI DOWN TBG. - PUMPING KWF TO MID PERFS AT 9473' - SHUT OFF PUMP. LINE UP TO PUMP DOWN TBG TAKING RETURNS THROUGH CHOKE TO FLOW BACK TANK. - WSL AND TOOL PUSHER VERIFY AND SIGN OFF ON VALVE ALIGNMENT. - START PUMP. OPEN CHOKE, PUMP 75 BBLS 11 PPG KWF 3 BPM 880 PSI. - MAINTAIN 1250 PSI CSG PRESSURE BY MANIPULATING CHOKE - MAINTAIN 100 - 200 PSI DOWNSTREAM OF CHOKE. TAKING RETURNS TO FLOWBACK TANK. - SHUT DOWN PUMP. SHUT IN VA AT CHOKE. - LET PRESSURES STABILIZE. I /A= 1030 PSI. TBG IS ON A VACUUM. O /A= 0 PSI. - BLOW DOWN LINE TO FLOWBACK TANK. - WSL DIRECTION. STRAP FLOWBACK TANK. 89 BBLS. - VAC OUT FLOWBACK TANK. VERIFY 89 BBLS. 22:30 - 00:00 1.50 KILLW P INTERV WSL AND TOOL PUSHER VERIFY AND SIGN OFF ON VALVE ALIGNMENT. - START PUMP. OPEN CHOKE, PUMP 325 BBLS 11 PPG KWF 3 BPM 700 PSI, HOLDING CASING PRESSURE @ 1100 PSI WHILE ESTABLISHING FCP. - MAINTAIN 700 - 750 PSI TBG PRESSURE BY MANIPULATING CHOKE - MAINTAIN 100 - 200 PSI DOWNSTREAM OF CHOKE. TAKING FLUID RETURNS TO FLOWBACK TANK. Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/25/2012 00:00 - 01:30 1.50 KILLW P INTERV PJSM WITH ONCOMING CREW. CONTINUE PUMPING 325 BBLS 11 PPG KWF 3 BPM 700 PSI. - MAINTAIN 700 - 750 PSI TBG PRESSURE, (FCP), BY MANIPULATING CHOKE - MAINTAIN 150 PSI DOWNSTREAM OF CHOKE. TAKING RETURNS TO FLOWBACK TANK. - 11 PPG KWF AT SURFACE. FCP= 740 PSI. - SHUT DOWN PUMP. SHUT IN CHOKE. TOTAL PUMPED FOR WELL KILL= 475 BBLS. 01:30 - 02:00 0.50 KILLW P INTERV MONITOR SHUT IN TBG AND VA PRESSURES FOR 30 MIN. - TBG AND VA ON SLIGHT VAC. - WELL IS DEAD. - VAC TRUCK RECOVERED 363 BBLS TOTAL FROM WELL KILL. 02:00 - 03:30 1.50 WHSUR P DECOMP BLOW DOWN AND R/D CIRCULATING LINES. - R/U SECONDARY KILL LINE. 03:30 - 06:30 3.00 WHSUR P DECOMP PJSM, R/U LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA. CHARTED. INSTALL TWC. - PERFORM 500 PSI ROLLING TEST UNDER TWC. - PERFORM TEST FROM ABOVE, 250 / 4000.0 PSI, 5 MIN / CHARTED, OK. 06:30 - 08:00 1.50 WHSUR P DECOMP DETERMINE STATIC LOSS RATE APPROXIMATELY 32 BPH. - CONTINUOUS FEED RATE INTO WELL BORE @ 20 BPH, 11 PPG BRINE. - BREAK DOWN LINES IN CELLAR. PJSM. N/D TREE & ADAPTER FLANGE. - CLEAN AND INSPECT HANGER & HANGER THREADS, OK. 08:00 - 10:00 2.00 BOPSUR P -_ DECOMP PJSM. N/U 13 5/8" X 5M BOPE. - FUNCTION TEST, OK. 10:00 - 12:00 2.00 BOPSUR P DECOMP PJSM. CHANGE OUT 3 1/2" X 6" VARIABLE BORE PIPE RAMS. - INSTALL 2 7/8" X 5" VARIABLE BORE PIPE RAMS, TOP AND BOTTOM. - LOSSES TO WELL BORE LAST (12) HOURS = 285 BBLS 11 PPG BRINE. 12:00 - 14:00 2.00 BOPSUR P DECOMP PJSM. CONTINUE TO CHANGE OUT PIPE RAMS. - RIG UP EQUIPMENT TO TEST BOPE. - BOB NOBLE WAIVED THE STATES RIGHT TO WITNESS THE TEST. - 24 HOUR NOTICE GIVEN. Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 19:00 5.00 BOPSUR P DECOMP PJSM. COMMENCE TESTING BOPE. - ALL VALVES AND RAMS TESTED @ 250 / 4000 PSI AS PER BP AND AOGCC REQUIREMENTS. ANNULAR PREVENTOR 130e TESTED @ 250 / 3500 PSI. ,(�V - TEST CHOKE MANIFOLD TO 250/4000 PSI. 5 I v� MIN EA. —. TEST WITH FRESH WATER. - PERFOM ACCUMULATOR DRAWDOWN TEST. ALL TESTS CHARTED 5 MIN EACH AT EACH PRESSURE. CONTINUOUS HOLE FILL DOWN VA 20 BPH 11 PPG BRINE. - WELL CURRENTLY TAKING 15 BPH 19:00 - 19:30 0.50 BOPSUR P DECOMP BLOW DOWN LINES. R/D TEST EQUIPMENT. VAC OUT STACK. 19:30 - 21:30 2.00 BOPSUR ` P DECOMP PJSM. R/U OFF"CENTER LUBRICATOR. - PRESSURE TEST LUBRICAOR TO 250/4000 PSI 5 MIN EA. CHARTED. - PULL TWC. TBG ON VAC. R/D LUBRICATOR. - CONTINUOUS HOLE FILL DOWN VA 20 BPH 11 PPG BRINE. 21:30 - 22:30 1.00 PULL P DECOMP PJSM, M/U LANDING JT WITH FOSV. - CLOSE FOSV. - FMC BOLDS. - HANG ESP SHEAVE. - R/U POWER TONGS. 22:30 - 22:45 0.25 PULL P DECOMP PJSM FOR PULLING HANGER TO RIG FLOOR. - IN ATTENDANCE WSL, TOOLPUSHER, FMC, CENTRALIFT AND CREW. - REVIEW WELL PLAN AND DDI SOP FOR PULLING ESP. REVIEW WELL CONTROL WITH ESP CABLE. - DISCUSS PULLING SPEED AND MAX PULL WT FOR SHEAR TYPE SAFETY JT. - POSSIBLE SWABBING DUE TO CUP PACKER. - POTENTIAL FOR PACKER GAS. 22:45 - 00:00 1.25 PULL P DECOMP UNSEAT HANGER 110K - PULL HANGER AND 1ST JOINT TO RIG FLOOR. - P/U WT= 110K. S/0 WT= 80K. INCLUDES 40K TOP DRIVE WT. - CUT ESP CABLE ABOVE CLAMP AT BOTTOM 1ST JT. - LOWER 1ST JT IN HOLE, CLOSE ANNULAR. LOSSES TO WELL LAST 12 HRS= 123 BBLS 11 PPG BRINE. 11/26/2012 00:00 - 01:30 1.50 PULL P DECOMP PJSM. R/U CIRC HOSE. LINE UP TO TAKE RETURNS TO CHOKE AND GAS BUSTER. - OPEN FOSV. - CBU PUMPING 5 BPM 2000 PSI - NO GAS AT RETURNS. - 71 BBLS LOST TO FORMATION WHILE CBU. OPEN ANNULAR. - MONITOR WELL FOR 10 MIN. STABLE. TBG ON SLIGHT VAC. Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 01:45 0.25 PULL P DECOMP - PJSM FOR PULLING COMPLETION. - IN ATTENDANCE WSL, TOOLPUSHER, FMC, CENTRALIFT AND CREW. - REVIEW WELL PLAN AND DDI SOP FOR PULLING ESP. - REVIEW WELL CONTROL WITH ESP CABLE. - DISCUSS PULLING SPEED AND MAX PULL WT FOR SHEAR TYPE SAFETY JT. - POSSIBLE SWABBING DUE TO CUP PACKER. - POTENTIAL FOR PACKER GAS. 01:45 - 02:00 0.25 PULL P DECOMP L/D LANDING JT AND HANGER. ■ - BLOW DOWN CHOKE AND DRAIN GAS BUSTER. 02:00 - 04:15 2.25 PULL P DECOMP POH WITH 2 7 /8 "'EUE ESP COMPLETION FROM 9400' TO 8152' MD - POH 1 MIN PER STAND. - THREAD ESP CABLE TO REEL. - MONITOR CLOSELY FOR SWABBING. - STAND TBG IN DERRICK. - WHILE POH WELL CONTINUES TAKING FLUID AT 8 BPH. 04:15 - 04:30 0.25 PULL P DECOMP CONDUCT KICK WHILE TRIPPING DRILL. SIMULATE CUTTING ESP CABLE AND SECURING TO PIPE. - LOWER AND POSITION PIPE. SIMULATE CLOSING ANNULAR. - WELL SECURE IN 2 MIN 40 SEC. - AAR. - WITH CUP PACKER DOWNHOLE. USE ✓ CAUTION LOWERING PIPE INTO POSITION. POSSIBLE TO SURGE WELL. - AFTER STABBING TIW AND TIGHTENING. NEED TO LATCH ELEVATORS AND PULL SLIPS. 04:30 - 10:00 5.50 PULL P DECOMP CONTINUE POH FROM 8152' TO 3555' MD. ■ - USE CONTINUOUS HOLE FILL. - HOLE TAKING 9 BPH WHILE POH. 10:00 - 11:00 1.00 PULL P DECOMP PJSM. CIRCULATE BOTTOMS UP @ 5 BPM / 900 PSI. - ACQUIRE SLOW PUMP RATES, 30 SPM @ 240 PSI & 40 SPM @ 400 PSI. - MONITOR WELL FOR (10) MINUTES, FLUID FALLING SLOWLY IN WELL BORE. 11:00 - 12:00 1.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" ESP COMPLETION TO 2806' MD. - CONTINUOUS HOLE FILL WHILE POOH. - FLUID LOST TO WELL = 182 BBLS OF 11 PPG BRINE LAST (12) HRS. - 0/A PRESSURE @ 11:30 HRS = 75 PSI. 12:00 - 13:00 1.00 PULL P DECOMP SERVICE RIG AND INSPECT AND LUBRICATE RIG EQUIPMENT. 13:00 - 14:30 1.50 PULL P DECOMP PJSM. CONTINUE TO POOH F/ 2806' - 1023'. 14:30 - 15:00 0.50 PULL P DECOMP PERFORM WELL CONTROL DRILL. - SIMULATE RIG HYDRAULICS OUT AND SHUT IN WILL WITHOUT HYDRAULICS. - SHUT IN WELL TIME, 2 MIN 17 SEC. GOOD AAR. Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WO RKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 15:30 0.50 PULL P DECOMP PJSM. CIRCULATE BTMS UP, 3 BPM / 110 PSI. - MONITOR WELL, FLUID IN WELL BORE FALLING SLOWLY. 15:30 - 17:30 2.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7!8" ESP COMPLETION TO PUMP ASSEMBLY. RACK 97 STANDS 2 7/8" TUBING IN PIPESHED. 293 DERRICK. JTS TBG 2 TOTASINGLES L. BEFORE PULLING PU IN MP ASSEMBLY FLOWCHECK WELL. STABLE. - DISCUSS PLAN FOR NON SHEARABLES ACROSS BOP. - POSSIBLE TRAPPED PRESSURE. 17:30 - 19:30 2.00 PULL P DECOMP UD PUMP AS PER CENTRALIFT REP. - PUMP SHAFT SEIZED. - E- LASALLE A GUARDSRECOVRED 154 , - 5 PROTECTOLIZERS AND 3 CANNON CLAMPS, 3 HALF FL T CLAMPS. 19:30 - 21:00 1.50 PULL P DECOMP P )SM, UD ESP SHEAVE. - CLEAR AND CLEAN RIG FLOOR. 21:00 - 21:30 0.50 ZONISO P DECOMP _M /U RUNNING TOOL. INSTALL 9" ID WEAR RIN PACG. 21:30 - 00:00 2.50 ZONISO P DECO PJSM, M/U 7" CHAMP PACKER BHA PER HES REP. MP - RIH WITH 53 STANDS 2 7/8" EUE TBG FROM DERRICK. - TORQUE 2 7/8" L -80 6.5# TBG TO OPTIMUM TORQUE 2300 FT LBS. - USE BOL 2000 ON TBG THREADS. RIH 1 MIN PER STAND. SET IN SLIPS EASY. AVOID TURNING PIPE. - RIH TO 4300' MD. - LOSSES TO WELL LAST 12 FIRS= 92 BBLS 11 PPG BRINE - USE CONTINUOS HOLE FILL, STATIC LOSSES AT 8 BPH. 11/27/2012 00:00 - 01:00 1.00 ZONISO P DECOMP PJSM, RIH WITH 53 STANDS 2 7/8" EUE TBG FROM DERRICK FROM 4300' TO 5008' MD. 01:00 - 07:00 6.00 ZONISO P DECOMP PJSM, R/U 4" HANDLING EQUIPMENT. i P/U 4" DRILL PIPE FROM PIPESHED. RIH FROM 5008' TO 9396' MD. U P WT= 132K,100KDOWNWT. - WELL CONTINUES WITH 8 BPH LOSSES. 07:00 - 07:30 0.50 ZONISO P DECOMP PJSM. AQUIRE SLOW PUMP RATES, 20 SPM! 140 PSI. 30 SPM / 310 PSI. - BREAK CIRCULATION @ 3 BPM / 460 PSI. - SET PACKER AS PER HALLIBURTON HAD @ 9400'. Printed 12/10/2012 10:51:03AM 1 % g j Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 07:30 - 09:00 1.50 ZONISO P () DECOMP PJSM. LINE UP VALVES AND DOUBLE CHECK. - CLOSE UPPER PIPE RAMS. - PRESSURE 7" CASING TO 250 PSI / 5 MIN, C' GOOD TEST. - PRESSURE 7" CASING TO 2500 PSI / 30 MINUTES / CHARTED. - GOOD FLAT LINE WITH NO DISCERNABLE BLEED OFF. - NOTIFY WTL OF SUCCESSFUL TEST, RELIEVE PERMISSION TO PROCEED AHEAD AS PER WELL PROGRAM. - BLEED OFF ALL PRESSURE. 09:00 - 09:30 0.50 ZONISO P DECOMP PJSM. RELEASE PAC KER AS PER HALLIBURTON REP. MONITOR WELL AND TEST 2 7/8" FLOOR VALVE, 250 < /4000 PSI- r 5 MIN EACH. 09:30 - 12:00 2.50 ZONISO P DECOMP PJSM. POOH W/ HALLIBURTON CHAMP PACKER. - POOH F/ 9400' 6240'. 85K UP WT, 78K I DOWN WT.;` ALL WEIGHTS INCLUDE 40K TOP DRIVE. 12:00 - 13:00 1.00 ZONISO P DECOIViP SERVICE AND INSPECT RIG EQUIPMENT. 13:00 - 16:00 3.00 ZONISO P ' DECOMP' PJSM. CONTINUE TO POOH W/ HALLIBURTON HAMP PACKER. ,) ` - CONTINUOUS HOLE FILL, WELL TAKING 8 BPH. 16:00 - 16:30 0.50 ZONISO P ® DECOMP L/D CHAMP PACKER - CLEAN CLEAR RIG FLOOR 16:30 - 21:00 4.50 CLEAN P DECOMP PJSM, RIH WITH MULE SHOE - M/U 2 7/8" EUE 8RD MULE SHOE - RIH W/ 2 7/8" EUE 8RD FROM DERRICK FROM SURFACE TO 5017' MD - RIH W 4" DP FROM DERRICK FROM 5017' TO 9546' MD - TAG FILL AT 9546' - CALL TOWN ENGINEER AND DISCUSS 30 / BBL LOSS WHILE RUNNING IN HOLE AND POSSIBLE LOSSES WHILE REVERSING, DECIDE TO PUMP CONVENTIONAL 21:00 - 00:00 3.00 CLEAN P DECOMP PUMP AND WASH DOWN FROM 9546' TO 9596', 6 BPM = 1800 PSI - PUMP 40 BBL HI-VIS SWEEP, 7 BPM = 2000 PSI, RECIPROCATE PIPE - GOOD AMOUNT OF FINE SAND IN SWEEP RETURNED TO SURFACE - PUMP AND WASH DOWN FROM 9596' TO 9656', 6 BPM = 1830 PSI - TAG PBTD AT 9656' MD WITH 4K WOB - PUMP 40 BBL HI-VIS SWEEP, 8 BPM = 2340 PSI, RECIPROCATE PIPE - GOOD AMOUNT OF FINE SAND IN SWEEP RETURNED TO SURFACE - CONT. PUMPING UNTIL CLEAN RETURNS - PUWT = 134K, SOWT = 103K - 24 HOUR FLUID LOSS = 207 BBLS Printed 12/10/2012 10:51:03AM • Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/28/2012 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM, PERFORM SAFETY AND SPCC CHECKS - CONT. CIRCULATION UNTIL CLEAN, 8 BPM = 2190 PSI - POOH FROM 9656' TO 9630' MD - MONITOR WELL 10 MINUTES, WELL IS STATIC IN ANNULUS I BREAK OUT AND BLOW DOWN TOP DRIVE 01:00 - 01:30 0.50 CLEAN P DECOMP R/U TO REVERSE CIRCULATE 1 BOTTOMS UP TO ENSURE MINIMAL SOLIDS CONTENT -5BPM =630 PSI - B /U. LOOKS CLEAN AT SHAKERS - R/D REVERSE LINES AND BLOW DOWN SAME WELL IS OUT OF BALANCE 01:30 - 02:00 0.50 CLEAN P DECOMP CIRCULATE CONVENTIONAL 1 1/2 TIMES THE TUBING VOLUME - 5 BPM = 1100 PSI - MONITOR WELL 10 MINUTES, WELL IS STATIC - SPR, 30 SPM = 280 PSI, 40 SPM = 470 PSI 02:00 - 06:30 4.50 CLEAN P DECOMP PJSM, POOH AND LAY DOWN DRILL PIPE 1X1 LAY DOWN 4" DP FROM 9630' TO 5017' MD 06:30 - 09:00 2.50 CLEAN P DECOMP CONTINUE TO POOH W/ 2 7/8" TBG, STANDING BACK. - CONTINUOUS HOLE FILL, PULL TO SURFACE. LID MULE SHOE. 09:00 - 09:30 0.50 WHSUR P RUNCMP PJSM. PULL WEAR BUSHING. 09:30 - 10:30 1.00 RUNCOM P RUNCMP PJSM. RIG UP SHEAVE FOR ESP CABLE. - STRING CABLE THRU SHEAVE. - PREPARE RIG FLOOR. 10:30 - 12:00 1.50 RUNCOM P . RUNCMP PJSM. PICK UP ESP PUMP ASSEMBLY. - MAKE UP PUMP AND MOTOR ASSEMBLY AS PER CENTRILIFT. - LOSSES TO WELL = 80 BBLS LAST (12) HRS. - 0/A PRESSURE @ 11:30 = 65 PSI. 12:00 - 16:00 4.00 RUNCOM P RUNCMP PJSM. CONTINUE TO MAKE UP ESP ASSEMBLY. - SERVICE ESP PUMP AND MOTOR - INSTALL DISCHARGE HEAD AND ATTACH I WIRE. - INSTALL FLAT GUARD PROTECTORS. 16:00 - 23:00 7.00 RUNCOM P RUNCMP RUN IN HOLE W/ 2 7/8" EUE 8 RND FSP COMPLETION. - RIH FROM SURFACE TO 7859' MD - USING BEST 0 LIFE 2000 PIPE DOPE, MAKE UP TORQUE = 2300 FT /LBS. - BREAKING CIRCULATION EVERY 2000' @ 1/2 - 1 BPM = 730 PSI - CHECKING CONDUCTIVITY OF CABLE EVERY 2000'. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM, CHANGE OUT ESP CABLE REEL AT 7859' MD - SPLICE ESP CABLE AND PERFORM CONDUCTIVITY CHECKS - 24 HOUR FLUID LOSS = 132 BBLS -OA =65 PSI Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4- 00WL3- E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table ©45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/29/2012 00:00 - 04:00 4.00 RUNCOM P RUNCMP PJSM. MAKE SAFETY AND SPCC CHECKS - CHANGE OUT ESP CABLE REEL AT 7859' MD - SPLICE ESP CABLE AND PERFORM CONDUCTIVITY CHECKS - STATIC LOSS RATE = 5 BPH 04:00 - 05:00 1.00 RUNCOM P RUNCMP RUN IN HOLE W/ 2 7/8" EUE 6.5# 8 RD TUBING ESP COMPLETION. - RN FROM 7859' TO 8747' MD USING BEST 0 LIFE 2000 PIPE DOPE, MAKE UP TORQUE = 2300 FT /LBS. - BREAKING CIRCULATION EVERY 2000' @ 1/2 - 1 BPM = 760 PSI - CHECKING CONDUCTIVITY OF CABLE EVERY 2000'. - PUWT = 90K, SOWT= 70K 05:00 - 08:30 3.50 RUNCOM N HMAN RUNCMP ESP CABLE WAS NOT LONG ENOUGH TO - REACH DESIREE) DEPTH - CHANGE OUT ESP CABLE REEL AT 8747' MD SPLICE ESP CABLE AND PERFORM CONDUCTIVITY CHECKS 08:30 - 09:00 0.50 RUNCOM P RUNCMP _CONTINUE TO RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION. RIH F/ 8747' - 9352'. 113K UP WT, 75K DOWN WT. - ALL WT CHECKS INCLUDE 40K TOP DRIVE. 09:00 - 11:00 2.00 RUNCOM P RUNCMP PJSM. P/U LANDING JT W/ FLOOR VAAVE INSTALLED. - M/U TO HANGER & M/U HANGER. - CENTRILIFT TIE IN ESP CABLE TO HANGER, PERFORM CONDUCTIVITY TEST, OK. 11:00 - 11:30 0.50 RUNCOM - P RUNCMP PJSM. LAND HANGER, RILDS. 11:30 - 12:00 0.50 RUNCOM P RUNCMP PJSM. INSTALL TWO WAY CHECK VALVE. - TEST FROM BELOW, 500 PSI F/ 10 MINUTES, OK. 12:00 - 12:30 0.50 RUNCOM P RUNCMP SERVICE RIG AND INSPECT ALL RIG EQUIPMENT. 12:30 - 13:00 0.50 RUNCOM P RUNCMP PJSM. TEST TWO WAY CHECK VALVE FROM ABOVE, 250 / 4000 PSI. - TEST FOR (5) CHARTED MINUTES, GOOD TEST. BLEED PRESSURE. 13:00 - 15:30 2.50 BOPSUR P RUNCMP PJSM. SUCK OUT BOP STACK, BLOW DOWN LINES. - NIPPLE DOWN 13 5/8" X 5M BOPE. 15:30 - 18:30 3.00 WHSUR P RUNCMP PJSM. N/U TUBING HEAD ADAPTER & FLANGE. - NIPPLE UP TREE AND TEST VOID @ 5000 PSI / 30 MIN/ CHARTED/ GOOD. - TEST TREE @ 250 / 5000 PSI 5 CHARTED MIN, GOOD. - ALL TESTS DONE W/ DIESEL. 18:30 - 21:00 2.50 WHSUR P RUNCMP PJSM, R/U DSM LUBRICATOR - TEST LUBRICATOR TO 250 PSI / 4000 PSI, 5 MIN, CHARTED - PULL TWC - SET BPV 21:00 - 22:00 1.00 WHSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW BPV - 1.5 BPM = 450 PSI, 10 MIN, CHARTED - 15 BBLS PUMPED AWAY TO FORMATION - R/D TEST EQUIPMENT Printed 12/10/2012 10:51:03AM Common Well Name: MPF -87 AFE No Event Type: WORKOVER (WO) Start Date: 11/24/2012 End Date: 11/29/2012 X4 -00WL3 E:PREPOST (1,400,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 12/1/2003 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @45.05ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 WHSUR P RUNCMP BLOW DOWN AND RIG DOWN ALL CELLAR LINES - SECURE TREE, INSTALL FLANGES AND GAUGES - CLEAN AND OFF -LOAD PITS AND CUTTINGS TANK - PREP RIG FOR RIG MOVE - 24 HOUR FLUID LOSS = 134 BBLS RELEASE RIG AT 24:00 HOURS - GAVE AOGCC 24 HOUR NOTICE OF BOPE TEST FOR MPF -54 AT 00:30 HOURS 11 -30 -2012 Printed 12/10/2012 10:51:03AM Tree: 2 9/16" • M P F -87a Orig. DB Elev. = 44.10' Wellhead: FMC 11" gen 5 casing Orig. RT to LDS = 30.07' R hanger. FMC 11" x 2 -7/8" hanger. w/ EUE 8rd Top & Bottom 2 - 1/2" CIW - BPV Csg tested to 2500 psi from 9400' during 11/25/12 RWO. Surface casing 20 ", 94# H -80 1 112' I rt SLB 2 -7/8" x 1" KBMG GLM I 142` 1 7 9 -5/8" 40 #, L -80, BTC 1 4945' I A , KOP 8 degrees @1232' :.' " ' Max. hole angle = 63 deg @6220` Hole angle thru' perfs = 10 , SLB 2 -7/8" x 1" KBMG GLM I 9,118' I I 1 2 -7/8" HES XN- Nipple ( 2.250" id) I 9,262' I 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg. WeIILift Discharge Gauge Unit 9,305' I ( drift ID = 2.347 ", Cap. = 0.00592 bpf) Gauge TVD = 6995' Centrilift Tandem SXD Pumps 7" 26 #, L -80, BTC Casing _ - 119 -P23 & 18 -P75 9,310' (drift ID = 6.151, cap.= .0383 bpf) Gas Separator (Cap w/ 2 7/8" Tbg inside = 0.02758 bpf) AINE. GSTHVEVX Coated I 9,335' Centrilift Tandem Seal Section mosook GSB3DB UT /LT SB /SB PFSA 9,340' Centrilift MPS 1 -325F Motor ( 9,354' I 294HP / 2315V / 77A ammo WeIILift MGU Sensor 9,376' I Gauge TVD = 7063' Perforation Summary ( 7) tL USIT Cement bond log dated 1/8/04 k , /4,10/4 IP 4 4° Size SPF Interval (TVD) e l A Sands k-. 3 3/8" 12 9467' - 9477' 7151' - 7161' 3 3/8" 12 9485' - 9495' 7169' - 7178' 3 3/8" 12 9515' - 9525' 7198' - 7208' D -16 Cleaned out to 9,656' during 11/25/12 RWO �� 7" Halliburton Float Collar 9656' 3 steel ESP cable bands lost in hole during 4ES RWO 09 -14 -09 A - 7" Halliburton float shoe 9740' DATE REV. BY COMMENTS 12/20/03 Lee Hulme Drilled & Completed by Doyon 14 JVIILNE POINT UNIT 04/22/04 MDO Convert Jet to ESP Initial 4 -ES WELL No.: MPF -87A 09/29/04 JRC RWO for FCO by 4 -ES 12/29/05 REH RWO by 4ES API : 50 -029- 23184 -01 -00 11/14/08 REH RWO by Nabors 3S 09/14/09 REH RWO by Nabors 4ES 11/25/12 L. Hulme RWO by Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 9 9 �. December 30, 2011 StAtiNEDFEB ci ZU1Z Mr. Tom Maunder I Alaska Oil and Gas Conservation Commission �6�J 333 West 7 Avenue (u'� Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF -41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/12011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A WA N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/12011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/12011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/312011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 "'---> MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~ ~d~o9 1. Operations Performed: ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ~ Puli Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) InC. ~ Development ^ Exploratory 203-213 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23184-01-00 - 7. Property Designation: A,QG O~o~.S~Of O,~~i?,.~5 .d~ 8. Well Name and Number: n ADL 355018 G~ ' MPF-87A- 9. Field / Pooi(s): Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Totai depth: measured g751' - feet true vertical 7431' - feet Plugs (measured) N/A Effective depth: measured 9656' ~ feet Junk (measured) ~9656 ~osnaios~ true vertical 7337' - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' ~`12r....v .., .. ~,. __ 1530 520 Surface 4910' 9-5/8" 4945' 4463' 6870 4760 Intermediate Production 9710' 7" 9742' 7422' 7240 5410 Liner b.~l'40~~ib.j '\ r-~ ,~ ~~* 4 U C~ ~ Perforation Depth: Measured Depth: 9467' - 9525' True Vertical Depth: 7151' - 7208' Tubing (size, grade, measured and true vertical depth): 2-7/$", 6.5# L-80 9427' 7422' Packers and SSSV (type, measured and true vertical depth): 7" , 26#, Cup Packer Assembly 9378' - 9381' 7065' - 7068' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ^ Exploratory ~yDevelopment ^ Service ~ Dail Re ort of Well Operations y 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 N!A if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Title Drilling Technologist ~ '~~°~~ Prepared By Name/Number: D t Si Ph a e ature one 564-4750 Sondra Stewman, 564-4750 Form 10-404 Revised 07/2009 Submit Original Only `~~~.~~.¢ ~~"~.~ .. _ ~ - i~~~~ ~`I~~i Tree:2 9/16" ~ Welihead: FMC 11"gen 5 casing hanger. FMC 11" x 2-7/8" hanger. w/ EUE 8rd Top & Bottom 2-1/2" CIW-H BPV Surface casing 20", 94# H-80 112' MPF-87a ~drig. DB Elev. = 44.10' Orig. RT to LDS = 30.07` Camco 2-7/8" x 1" sidepocket KBMG GLM 139' 9-5/8" 40#, L-80, BTC 4945` KOP 8 degreesC~?1232' Max. hole angle = 63 deg C~6220` Hole angle thru' perfs = 1~ 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf } 7" 26#, L-80, BTC Casing (drift ID = 6.151, cap.= .0383 bpf) I Perforation Summary USIT Cement bond log dated 1/8/04 Size SPF Interval (TVD) A Sands 3 3/8 12 9467' - 9477' 7151 `- 7161' 3 3/8" 12 9485' - 9495' 7169' - 7178' 3 3B" 12 9515' - 9525' 7198' - 7208' I 3 steel ESP cable bands lost in hole during RWO - 09-14-09 DATE I REV. BY ~ . . MME 11/14/08 REH RWO by Nabors 3S 09/14/09 REH RWO by Nabors 4ES Camco 2-7/8" x 1" 147' 9 sidepocket KBMG GLM , 2-7/8" HES XN-Nipple ( 2.250" id ) 9,290' WeIILift Discharge Gauge Unit 9,310' Centrilift ESP 9 313' SXD 119-P23 , Gas Separator ' GRSFTX AR H6 (400 internals) 9,330 Centrilift Tandem Seal Section 33 ' 9 GS63DBUT/LT SB/SB PFSA(FSA CL6 5 ~ Centrilift KMH Motor 9,349' 228HP / 2305V / 60A WeIILift MGU Sensor 9,368' 3~2 9 Shear Type Safety Jnt. . Pinned @ 26,400# Baker 7" 26#, Cup Pkr. Assembly 9,381' 4-1/2" Duragrip Screen - 316L x.20 mic g387' 4-1/2" 12.6# Bull Plug 9426' 4-ES Cleaned out to 9,656` 9/28/04 7" Halliburton Float Collar 9656' 7" Halliburton float shoe 9740` MILNE POINT UNIT WELL No.: MPF-87A API : 50-029-23184-01-00 BP EXPLORATION • • BP EXPLORATION" Page 1 of ~. OperatiQns Summary Report Legal Well Name: MPF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: WORKOVER Start: 9/9/2009 End: 9/14/2009 Contractor Name: NABORS ALASKA DRILLWG I Rig Release: 9/14/2009 ~ Rig Name: NABORS 4ES Rig Number: ' Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2009 15:00 - 17:00 2.00 MOB P PRE Rig down Prepare to move to MPF-87A. 17:00 - 18:00 1.00 MOB P PRE Move off MPF-96 C~ 17:00 hrs. Move to weil MPF-87A. -Witnessed by WSL, TP & Pad Op. 18:00 - 19:00 1.00 RIGU P PRE Move sub over well C~ 18:00 hrs. - Move in & RU Pits & Pipe shed. -Witnessed by WSL, TP & Pad Op. 19:00 - 21:00 2.00 R1GU P PRE Scope derrick up. -Acce t Ri ~ 21:00 hrs. 21:00 - 21:30 0.50 RIGU P PRE Lu ric tor. Test Lubricator to 500 si - Pass. -Pull BPV. RD & LD Lubricator. 21:30 - 23:30 2.00 RIGU P PRE Rig up lines to Tree. -Take on 8.5 ppg Seawater C~? 130 degrees. 23:30 - 00:00 0.50 RIGU P PRE Test lines to 1000 psi. - Pass. 9/11/2009 00:00 - 03:30 3.50 KILL P DECOMP Test lines to 3500 psi. Seawater wt = 8.5 ppg. -O en well Tb = 570 si. Csg = 660 psi. -Circulate through Choke. Pump the long way. -Pump: 2 bpm / 410 psi, then 4 bpm / 1300 psi. -Pump for a total of 1 Tbg volume C~ 55 bbls = 935 stks. -Bullhead 16 bbls C~ 2 bpm / 650 psi = 272 stks. -Continue to pump. Pump the long way. -Pump 4 bpm / 1340 psi for 399 stks. -Total of 471 bbis or 8000 Stks. 03:30 - 04:30 1.00 KILL P DECOMP Continue to circulate 3 bpm / 800 psi. -Losin 5 bbls eve 10 minutes. -Pumped 180 bbls. Lost 30 bbls. -Gonsult w/ Engineers. 04:30 - 06:00 1.50 KILL P DECOMP Monitor well and let pressures stabilize. -Tb 270 si. Cs 250 si. 06:00 - 13:30 7.50 KILL N FLUD DECOMP Wait on Kill fluid. -9.5 ppg NaCI Brine f/ MI Mud Plant. -Service Rig & Pre-tour checks. -Inspect derrick. Perform: After Action review of MPF-96 w/ Crew & R~G. 13:30 - 16:00 2.50 KILL N FLUD DECOMP Displace with Kill fluid: -Displace with 9.5 ppg NaCI Brine. -SI Tbg = 250 psi. S! Csg = 240 psi. -Circulate through Choke. Pump the long way. -Pump: 55 bbls @ 4 bpm / 1,200 psi = 935 stks. -Bullhead: 12 bbls C~ 2 bpm / 350 psi = 205 stks. -Continue to pump. Pump the long way. -Pump 337 bbls C~ 4 bpm / 1,100 psi = 5730 stks. -Total of 402 bbls or 6872 Stks. -Monitor WeII:Tbg and IA on slight Vacuum. 16:00 - 17:00 1.00 BOPSU P DECOMP FMC - Install TWC. -Test from below / Inject C~3 2.5 bpm / 400 psi / 10 minutes. -Test from above to 3500 si / 10 minutes - Pass. 17:00 - 21:00 4.00 BOPSU P DECOMP ND Tree. NU BOP Stack. -RU Test equipment. 21:00 - 00:00 3.00 BOPSU P DECOMP Test BOP's and related equipment. - est to & AOGCC procedures & regulations. -BOP configuration: Printed: 9/17/2009 7:2323 AM • • BP E~ Operations Legal Well Name: MPF-87 Common Well Name: MPF-87 'Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To Hours Task Code NPT 9/11/2009 21:00 - 00:00 3.00 BOPSU P 9/12/2009 100:00 - 03:00 I 3.00 I BOPSUI~ P 03:00 - 04:30 I 1.501 KILL I P 04:30 - 06:30 I 2.001 PULL I P 06:30 - 15:00 I 8.501 PULL I P PLORATION Page 2 of 4' Summary Report I Spud Date: 12/1/2003 Start: 9/9/2009 End: 9/14/2 I Rig Release: 9/14/2009 Rig Number: Phase Deseription of Operatians DECOMP -13 5/8" Hydril GK 5000. -Blind Shear Rams. -Spacer spoof. -2-7/8" X 5" Variable Bore Rams. Test Choke Manifold, Blinds, 2-7/8" X 5" VBR's, -Manual Choke, HCR Choke, Manual Kill, HCR Kill, -Floor Valves. -Test to 250 psi low and 3,500 psi high. -Test Hydril Annular to 250 psi low and 3,500 psi high. -Used 2-7/8" Test Joint on Rams and Annular. -Each test was held for 5 charted minutes. -John Crisp AOGCC waived witness of test. -Test was witnessed by WSL & TP. DECOMP Continue BOP test: Test BOP's and related equipment. -Test to BP & AOGCC procedures & regulations. -BOP configuration: -13 5/8" Hydril GK 5000. -Blind Shear Rams. -Spacer spool. -2-7/8" X 5" Variable Bore Rams. Test Choke Manifold, Blinds, 2-7/8" X 5" VBR's, -Manual Choke, HCR Choke, Manual Kill, HCR Kiil, -Floor Valves. -Test to 250 psi low and 3,500 psi high. -Test Hydril Annular to 250 psi low and 3,500 psi high. -Used 2-7/8" Test Joint on Rams and Annular. -Each test was held for 5 charted minutes. -All test Pass. -Perform Draw-Down test on Koomey System. -Change out Koomey air pump. Re-test Koomey. -Draw down form 3,000 psi to 1,650 psi. -200 psi build up = 41 seconds. -Full pressure = 166 seconds. - 4 Bottles X 1,725 psi. -John Crisp AOGCC waived witness of test. -Test was witnessed by WSL & TP. DECOMP PU & MU Lubricator. -Test Lubricator to 500 psi - Pass. -Pull TWC. LD TWC & Lubricator. DECOMP PU & MU Landing Jt. -Engage Hanger. Pull Hanger to floor w/ 75k PUW. -Test Penetrator. g anger. DECOMP Pull completion: -Snake ESP cable over sheave to Spooler. -Stand 2 7/8" tbg in Derrick. 009 Printed: 9/17/2009 7:23:23 AM ~ • BP EXPLC?RATION Page 3 of 4: Operations Summary R~port Legal Well Name: MPF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: WORKOVER Start: 9/9/2009 End: 9/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/14/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Haurs Task ~ode NPT Phase Description of Operations 9/12/2009 06:30 - 15:00 8.50 PULL P DECOMP -Old splice C~ joint #43 out of hole. 15:00 - 18:00 I 3.001 PULL I P 9/13/2009 9/14/2009 18:00 - 19:30 1.50 PULL P 19:30 - 22:00 2.50 PULL P 22:00 - 00:00 2.00 RUNCO 00:00 - 01:30 1.50 RUNCO 01:30 - 05:00 3.50 RUNCO P 05:00 - 11:00 I 6.001 RU -Pump 45 bbls to clear Tbg string. -Loss rate to formation -18 bph. _. -ESP cable blow-out in old splice C~ 172 jts out of hole DECOMP BO/LD ESP pump and motor assembly. -LD Baker 3-cup packer. LD 40 ft Screen assembly. -Recovered all e ui ment exce t 3 Stainless Steel ban DECOMP LD Pump Motor & Seal assembly. DECOMP RD Elephant trunk. -Remove old Pump & Motor from pipe shed. RUNCMP PU new screen assembl . RUNCMP Service Centrilift Pump & Motor. RUNCMP Pull Motor Lead extension over sheave. -Plug lead into Motor. -Install Protectors, Flat guards & I-wire. -Test I-wire & ESP. RUNCMP Run ESP completion: -Check cable & flush pump every 2,000' md. -Flush pump with 5 bbls of 9.5 ppg NaCI brine. -1 bpm / 1000 psi. 11:00 - 12:00 1.00 RUNCO P RUNCMP MPU PE Shoot fluid levels. -Fluid level @+/- 500' md in Tbg. -Fluid level ~ +/- 1,100' md in . -Per discussion w/ Engineer: -1) Rig #9 stuck in road. -2) Only need a small volume. 12:00 - 14:00 2.00 RUNCO P RUNCMP Continue to RIH with ESP completion. -Total = 81 Stds ran in hole. 14:00 - 18:00 4.00 RUNCO P RUNCMP Centrilift perform a Reel to Reel splice. -Weekly Safety meeting. -Clear & clean Rig floor. -PU & prepare Lasalle clamps. 18:00 - 18:30 0.50 RUNCO RUNCMP Service Rig. Check alarms. Perform Derrick inspection. 18:30 - 20:30 2.00 RUNCO RUNCMP Continue to RIH with ESP completion. -Test ESP every 2,000' md. -Pump 1 bpm / 900 psi for 10 bbls. 20:30 - 21:00 0.50 RUNCO RUNCMP PU Landing Jt. MU Hanger. Install Penetrator. 21:00 - 23:00 2.00 RUNCO RUNCMP Attach Field connectors. -Plug into Penetrator & test. 23:00 - 00:00 1.00 RUNCO RUNCMP Land Tbg w/ TWC installed in Hanger. RILDS. -PUW 70k, SOW 45k. -Ran 166 LaSalle clamps, 5 Protectors. -3 Flat Guards & 2 Canon clamps. -Test TWC f/ the Top 3500 psi / 10 moinutes - Pass. -Test TWC f/ below - ump into annulus 2 bpm 300 psi -Chart all tests. 00:00 - 01:00 1.00 RUNCO P RUNCMP RD & blow down lines. Suck out stack 01:00 - 02:00 1.00 RUNCO P RUNCMP Hold weekly safety meeting. 02:00 - 04:00 2.00 RUNCO P RUNCMP ND BOP stack. 04:00 - 06:00 2.00 WHSUR P WHDTRE NU Tree. RU & test Lubricator. -Pull TWC. Set & test BPV. -Secure Tree & cellar. Printed: 9/17/2009 7:23:23 AM . ,. ~ ~ Legal Well Name: MPF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: WORKOVER Start: 9/9/2009 End: 9/14/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/14/2009 Rig Name: NABORS 4ES Rig Number: BP EXPLORATlO~t Operations Sumrnary Report Date From - To Hours Task Code NPT Phase '' Description of Operations 9/14/2009 04:00 - 06:00 2.00 WHSUR P WHDTRE -Release Rig ~ 06:00 hrs. Printed: 9/17/2009 7:2323 AM STATE OF ALASKA ALA OIL AND GAS CONSERVATION COA~SION REPORT OF SUNDRY WELL OPERATIONS 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 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 203-213 , 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23184-01-00 7. KB Elevation (ft): KBE = 45 05' 9• Well Name and Number: . MPF-87A ' 8. Property Designation: • 10. Field /Pool(s): ADL 355018 Milne Point Unit / Kuparuk River Sands - 11. Present well condition summary Total depth: measured 9751' • feet true vertical 7431' • feet Plugs (measured) N/A Effective depth: measured 9656' • feet Junk (measured) N/A true vertical 7337' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1530 520 Surface 4910' 9-5/8" 4945' 4463' 6870 4760 Intermediate Production 9710' 7" 9742' 7422' 7240 5410 Liner Perforation Depth MD (ft): 9467' - 9525' Perforation Depth TVD (ft): 7151' - 7208' 2-7/8", 6.5# L-80 9431' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 331 84 516 300 254 Subsequent to operation: 458 148 997 320 299 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. W I Status after work: ® Well Schematic Diagram Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 rj/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By NamelNumber: Sig ature Phone 564-4750 Date - l 1- `'~ Sondra Stewman 564-4750 Form 10-40 evised 04/2006 ~ Submit Original Only ' _. ~~, ~;} r ~Z~17 .ltd l2• /S ~ ~ ZQO~ 1 /_ lz//f~~8 Tree:2 9/16" ~ Wellhead: FMC 11" gen 5 casing hanger. FMC 11" x 2-7/8" hanger. w/ EUE 8rd Top & Bottom 2-1/2" CIW-H BPV Surface casing 20", 94# H-80 11~ 9-5/8" 40#, L-80, BTC USIT Cement bond log dated 1/8/04 Size SPF Interval (TVD) A Sands 3 3/8' 12 9467` - 9477' 7151' - 7161' 3 3/8" 12 9485` - 9495' 7169` - 7178' 3 3/8" 12 9515` - 9525' 7198' - 7208' DATE REV. BY COMMENTS 12/20/03 Lee Hulme Drilled & Completed by Doyc 04/22/04 MDO Convert Jet to ESP Initial 4- 09/29/04 JRC RWO for FCO by 4-ES 12/29/05 REH RWO by 4ES 11/14/08 REH RWO by Nabors 3S BP EXPLORATION Orig. DB Elev. = 44.10' Orig. RT to LDS = 30.07` Camco 2-7/8" x 1" sidepocket KBMG GLM 140` Camco 2-7/8" x 1" 9 148' sidepocket KBMG GLM , 2-7/8" HES XN-Nipple (2.250" id) 9,291' WeIILift Discharge Gauge Unit 9,311` Centrilift ESP 314` 9 SXD 119-P23 , Gas Separator ' GRSFTX AR H6 (400 internals) 9,331 Centrilift Tandem Seal Section 336' 9 GSB3DBUT/LT SB/SB PFSA/FSA CL6 , Centrilift KMH Motor 9,350` 228HP/2305V/60A WeIILift MGU Sensor 9,369` 9 374 Shear Type Safety Jnt. , Pinned @ 26,400# Baker 7" 26#, Cup Pkr. Assembly 9,381` I l-1/2" Duragrip Screen - 316E x .20 mic 9390` 9-1/2" 12.6# Bull Plug 9431' 4-ES Cleaned out to 9,656' 9/28/04 7" Halliburton Float Collar 9656' 7" Halliburton float shoe 9740` MPF-87a • BP EXPLORATION Operations Summary Report Page 1 of 3 Legal Well Name: MPF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: WORKOVER Start: 11/9/2008 End: 11/14/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2008 Rig Name: NABORS 3S Rig Number: Date From - To ~ Hours Task ', Code ~ NPT I Phase Description of Operations 11/9/2008 01:00 - 10:00 9.00 MOB P PRE Rig released from MPG-09 C~ 01:00. Prepare rig for move. 10:00 - 12:00 2.00 MOB P PRE Depart MPG pad and travel to MPF pad. 12:00 - 22:30 10.50 RIGU P PRE MIRU on MPF-87A. Derrick up at 21:00 hours. Spot tiger tank, RU burms and handrails. Rig accepted at 22:30 hours 22:30 - 00:00 1.50 KILL P DECOMP RU second annulus valve, Kill manifold and Tiger tank. Fill Pits and Up-right tank with 8.45 ppg seawater. 11/10/2008 00:00 - 01:30 1.50 KILL P DECOMP Test surface lines to 3,500 psi and hard lines to Tiger tank to 500 psi. 01:30 - 02:00 0.50 KILL P DECOMP PJSM with vac truck drivers and crew on Well kill. 02:00 - 02:30 0.50 KILL P DECOMP PU and test lubricator to 500 psi and null TWC with WeIL 02:30 - 06:00 3.50 KILL P DECOMP WHP's Tbq = 380, IA = 450 . OA= 0. Bleed IA down from 450 psi to -0. Pump 60 bbls 8.45 ppg 140 Deg F seawater down tbg through the choke to Tiger tank at 4 bpm / 650 psi. Close choke and pump (bull head) 40 bbls down the tbg into the formation at 4 bpm / 400-700 psi. Stop and observe 15 minutes SITP, Tbq = -10 psi, IA = 200 psi. Pump 285 bbls down the tbg through open choke with returns to Tiger tank. WHP's Tbg = 0, IA = -10 psi. Circulate 135 bbls through the choke to ds. ba and IA on a vacuum. Loss 176 bbls to . 06:00 - 07:00 1.00 KILL P DECOMP Flowcheck well. Tubing and IA on vacuum. Dry rod TWC. Test from above to 3500 si. Chart for 10 minutes. 07:00 - 09:00 2.00 WHSUR P DECOMP ND Tree. FMC bleed hanger void. Inspect top hanger threads - OK. 10 turns to MU 2-7/8" XO. 09:00 - 14:00 5.00 BOPSU P DECOMP NU BOPE. FIII stack. function test all components. 14:00 - 18:00 4.00 BOPSU P DECOMP Test BOPE with 2-7/8" test'oint. Test to 250 psi / 3500 psi. Koomey drawdown test. Per BP / AOGCC Regulations. Tested against the TWC. Test witnessed byBP / WSL and NAD Toolpusher. State's right to witness waived by Lou Grimaldi. 18:00 - 18:30 0.50 BOPSU P DECOMP Crew change, perform pre-tour checks and blow down lines. 18:30 - 20:00 1.50 BOPSU P DECOMP MU Opso-Lopso and lubricator, test to 500 psi. Well support techs pull TWC. Tbg and IA on a vacuum. LD Opso and lubricator. 20:00 - 21:00 1.00 PULL P DECOMP Hang New single ESP sheave and cable trunk in Derrick. 21:00 - 23:00 2.00 WHSUR P DECOMP MU 2-7/8" landing joint with TIW valve, BOLDS with FMC well head tech, unseat tubing hanger ~ 85K, PUW = 80K. Dull to floor. Took 17 bbls to fill IA, calulated top of fluid ~-560 ft rom surface. Cut ESP cable and band to tubing, LD tubing 23:00 - 00:00 1.00 PULL P DECOMP PU 7 singles RIH and tag fill at 9,567'. (42' of RH). POH lay down 7 joints and 10' pup. 11/11/2008 00:00 - 01:00 1.00 PULL P DECOMP Pump 35 bbls 8.45 ppg seawater down tubing at 3 bpm / 480 psi. R/U floor to pull ESP. 01:00 - 06:00 5.00 PULL P DECOMP POH from 9,377' with 2-7/8" 6.4 #, L-80, 8rd, EUE tbg ESP completion assembly and stand in Derrick. Continuous hole fill regulated at - 20 bph. POH slow due to 20 mph wind. Centrilift change out spool at -1,200'. 94 joints out at 05:30 hours. 06:00 - 10:00 4.00 PULL P DECOMP Continue POH w/ ESP completion. 10:00 - 14:00 4.00 PULL P DECOMP LD ESP motor and pump with Centrilift rep. 14:00 - 14:30 0.50 PULL P DECOMP Clean and clear rig floor. Printetl: 12/1/2008 9:43:28 AM BP EXPLORATION Operations Summary Report Page2of3~ Legal Well Name: MPF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: WORKOVER Start: 11/9/2008 End: 11/14/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/14/2008 Rig Name: NABOBS 3S Rig Number: Date ;From - To Hours Task Code NPT Phase Description of Operations 11/11/2008 14:30 - 15:30 1.00 PULL P DECOMP Snake ESP cable over sheave and RD cable trunk. RU floor to run ESP completion. 15:30 - 18:00 2.50 BUNCO RUNCMP PU / MU 4-1/2" Duragrip screen /Baker 7" cup packer with, 18:00 - 00:00 ~ 6.00 ~ RU 11 /12/2008 ~ 00:00 - 03:00 ~ 3.00 03:00 - 09:30 I 6.501 BUNCO 09:30 - 14:30 I 5.00 14:30 - 18:00 I 3.50 18:00 - 18:30 I 0.50) RU 18:30 - 23:00 ~ 4.50 ~ RUN 23:00 - 00:00 1.00 11/13/2008 00:00 - 06:00 6.00 06:00 - 13:00 I 7.00 RUNCMP PU / MU and service ESP pump and motor with Temp and pressure control line. RUNCMP Temp /Pressure control line to ESP gauge unit failed to make up, replace with new. RUNCMP MU 2 pups and XN nipple, 4 joints, KBMG GLM with dummy, RIH with ESP on 2-7/8" tubing from Derrick at reduced speed due to cupped packer. Continuous hole fill regulated at _ 20 b h. Check cable conductity at 2,000' and flush pump with 10 bbls seawater, 1 bpm / 800 psi. RIH 52 stands at 06:00 hours. Stop with 70 stands in 0930 hrs to check the conductivity of the cable. Centrilift rep notifies that the cable is grounding out and it had checked out good the previous stop. Suspects there is something wrong with the ESP Cable. RUNCMP POOH with ESP Assembl standin back 2-7/8" Tubin in the Derrick. Maintain and regulate continuous hole fill at 20 bbls per hour with seawater. RUNCMP On surface with ESP Assembly. Inspect ESP /Cup /Screen BHA for any indications of damage. Recovered 5 of 7 bands that were utilized to anchor the Tech Wire to the ESP Assembly. Of the 5 recovered, 4 of them had been broken off downhole and came back to surface and 1 had to be cut off from around the Motor. 2 bands were lost downhole.; The Motor Lead Extension was kinked and the shape of the damage appeared to coincide with the shape of the damaged bands so suspect that one of the broken bands damaged the MLE while RIH and caused the ESP Cable communication failure. Inspect the Cups and only two small areas had indentions. Inspect the Screen Joint and no damage noted anywhere. Consult with Anchorage Engineering and decision e to re-run the same confi uration a lot slower in the hole. RUNCMP Crew change, perform pre-tour checks. While out of hole, visually inspected inside the BOP stack and tubing spool, saw nothing. RUNCMP RIH with 4-1/2" Dura ri screen /Baker 7" cu acke . Snake new ESP cable over sheave in Derrick. PU / MU and service ESP pump and motor with Temp and pressure control line. RUNCMP RIH from Derrick with 2-7/8" tubing ESP assembly. RUNCMP RIH with ESP on 2-7/8" tubing from Derrick at slow speed due to cupped packer. String taking weight (-0-5K) at 1,100' and 1,172'. PUW = 22K, SOW = 20K. Pick up to 60' (with no drag) and go down past 1,172' freely. Observed -0-2K at 1,202'. Continue RIH slow (-18 stands per /hrs). Maintain and regulate continuous hole fill at 20 bbls per hour with seawater. Check cable conductivity at 1,172' and 2,243' flush pump with 10 bbls seawater, 1/2 bpm / 200 psi. 49 stands run at 06:00 hours. RUNCMP Crew change and pre-tour checks. Continue RIH with ESP Completion on 2-7/8" Tubing from the Derrick. Average running speed of 15 stands per hour. Maintain continuous hole fill with Nrinted: ivveuuts a:as:etsAM .~ BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 11 /13/2008 06:00 - 13:00 MPF-87 MPF-87 WORKOVER NABOBS ALASKA DRILLING NABOBS 3S Hours Task Code NPT 7.00 13:00 - 15:30 2.50 15:30 - 17:00 1.50 17:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 20:30 20:30 - 21:30 21:30 - 22:00 22:00 - 00:00 11/14/2008 00:00 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 06:00 0.50 BUNCO 0.50 BUNCO 0.50 BUNCO 2.00 BUNCO 1.00 BUNCO 0.501 WHSURIP 2.00 BOPSUF~P 3.00 BOPSU~jP 0.50 BUNCO 1.00 WHSUR P 0.501 WHSURIP 1.001 WHSUR I P Spud Date: 12/1 /2003 Start: 11 /9/2008 End: 11 /14/2008 I Rig Release: 11/14/2008 Rig Number: Phase Description of Operations RUNCMP seawater and loco, P~~girla_ 1 hbl~ ner hour- MU Torque on all connections = 2,300 ft-Ibs optimum and using Best-O-Life 2000 Pipe Dope. Check the conductivity of the ESP Cable every 1,000'. Every 2,000' fill the Tubing and flush the pump with 10 bbls of seawater at a rate of 0.5 bpm / 280 psi and 1 bpm / 910 psi. Stop with 122 stands of Tubing in the hole = 7,840'. RUNCMP Perform reel to reel splice with Centrilift reps. Continue feeding the well while splicing. RUNCMP Resume RIH with ESP Completion on 2-7/8" Tubing from the Derrick to joint # 293. Ran 4-1/2" screen, cup packer, ESP pump and motor, XN, KBMG GLM w/dummy, KBMG GLM w/ DSOV, to 9,431', 154 LaSalle clamps, 6 bands, 5 protectolizers, 3 flat guards. RUNCMP MU landing joint with TIW valve. RUNCMP Flush pump with 10 bbls seawater at a rate of 0.5 bpm / 280 psi. RUNCMP MU tubing hanger and penetrators with FMC and Centrilift reps. RUNCMP Perform penetrator splice with Centrilift rep. RUNCMP Final PUW = 82K, SOW = 43K. Land tubing hanger and RILDS with FMC well head tech, LD landing joint. RUNCMP Dry rod TWC with FMC well head tech. Test TWC from above RUNCMP Drain BOP stack and blow down lines. ND BOPE RUNCMP Continue to ND BOPE, LD in shipping cradle and ND 11" X 13 5/8" DSA. RUNCMP Centrilift check conductivity at the penetrator, OK. WHDTRE N/U tubing head adaptor, and production tree, remove second annulus valve. WHDTRE FMC well head tech tested tubing hanger void to 5,000 psi for 30 minutes. Test tree to 5,000 psi with diesel for 10 charted minutes. WHDTRE PU and test luricator to 500 psi, ull TWC and set BPV with Well head techs. Perform final conductivity checks with Centrilift rep. Phase to phase = 3.2 Ohms ,Phase to Ground = 824 Mega-Ohms ,Pressure at intake = 3,043 psi ,Pressure at discharge = 3,017 psi ,Temperature at intake = 169 degF , Temperature at motor = 169.3 degF. The Rig was released at 0600 hrs on 11/14/2008. Printed: 12/1/2008 9:43:28 AM • • -~._ 11 . ~ 11 o3io7i2oos DO NOT PLACE r~~. ~=`~" =~` ,.: ~, -~, ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Micrafilm_Marker. doc . . WELL LOG TRANSMITTAL JD~:x It:!! - 1351 d- JD']- 2}{ 01 ~51~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs MPF-87 & MPF-87 A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPF-87 & MPF-87A: LAS Data & Digital Log Images: 50-029-23184-00,01 I CD Rom ~~Lh 7/ ~j I1/0ÚJ I-- 7 /~fj~ DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2032130 Well Name/No. MILNE PT UNIT KR F-87A Operator BP EXPLORATION (ALASKA) INC MD 9751 -- ,,-- Current Status 1-01L Completion Date 1/27/2004 Completion Status TVD 7431 .-- 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFRlCASANDRA, PWD, ASI, RES, GYRO Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name f;ttJ (A~À.~3 API No. 50-029-23184-01-00 UIC N (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments .~ Log Log Run Scale Media No I i Rpt Directional Survey 4877 9751 1/13/2004 I ! Rpt Directional Survey 4877 9751 1/13/2004 ,.¡-.ro' D 12470 I nd uction/Resistivity 1,2,4 67 9713 3/18/2004 ~:~ -..I "-'V \Ii.. fnd&ettón-~e~sthritY- 1,2,4 67 9713 3/18/2004 : D 12470 Rate of Penetration 1,2,4 67 9713 3/18/2004 Rpt Ratë ur r'coetr:J.tion ~,"-__~__~_r""'_~____________~~~~~~ 1,2-,-4- 67 971'3 3/18~ log Soc Note:; ~ J)L~(l&;h ~. tJIfV\ Olu 1 0 9648 9/22/2001 Log Cement Evaluation 5 Blu 0 9648 Case 11/21/2005 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION c0N Well Cored? ~ Daily History Received? Chips Received? ...~ f:ò/ N Formation Tops Analysis Received? '¥.I-N- MWD GR, EWR4, ROP GR, EWR4, ROP GR, EWR4, ROP GR, t:.WR4, Rap ------ UL TPJ\SONfC ~M^GER - LOG-U~IT~A WITII PRlMARY-S::rTII --- ~NTROL Ultrasonic Imager Log- USIT-A with Primary Depth Control 08-January-2004 ~ Permit to Drill 2032130 MD 9751 TVD 7431 Comments: ,;:; {1 / _ U\I\.{l,' ~.J q. [I ,J '.~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Well Name/No. MILNE PT UNIT KR F-87 A Operator BP EXPLORATION (ALASKA) INC Completion Date 1/27/2004 Completion Status 1-01L Current Status 1-01L f' +iJ... '~.M I. if . 0,' {j i/'>F :Lß %:~: -e 1 f (f ~ ~~;-~ .."" it". ~ f' Jk Date: API No. 50-029-23184-01-00 UIC N I " F -1 þ..t d '-~ r<4~.4 '6 r;~ ~d f0 fJ ~' ~ ) STATE OF ALASKA ) RECEIVED ALASKA v(L AND GAS CONSERVATION CO ,~ISSION REPORT OF SUNDRY WELL OPERATIONsJAN I 1 2006 Alaska Oil & Gas Cons. Commission Anchorage 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): KBE = 45.051 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9751' 7431' 9656' 7337' Casing Length Structural Conductor 781 Surface 4910' Intermediate Production 9710' Liner 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 203-213 6. API Number: 50-029-23184-01-00 99519-6612 9. Well Name and Number: MPF-87A 10. Field 1 Pool(s): Milne Point Unit I Kuparuk River Sands feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 1121 112' 1530 520 9-5/8" 4945' 44631 6870 4760 7" 9742' 7422' 7240 5410 Perforation Depth MD (ft): 9467' - 95251 Perforation Depth TVD (ft): 71511 - 72081 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 9377' N/A N/A Treatment description including volumes used and final pressure: RBDMS BFl JAN 1 1 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure 367 343 420 305 228 430 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact David Reem, 564-5743 13. Oil-Bbl Prior to well operation: 292 Subsequent to operation: 196 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram TubinQ Pressure 339 340 Printed Name Sondra Stewman./ Title Technical Assistant ~~ _, Phone 564-4750 Form 10-404 R~sed 0412004 0 RIG I N A L Prepared By Name/Number: Date (~Î - ) 0- 04- Sondra Stewman, 564-4750 Submit Original Only ') Tree:2 9/16" Wellhead: FMC 11" gen 5 casing hanger. FMC 11" x 2-7/8" hanger. CIW-H BPVT. Surface casing 20", 94# H-80 ~j 9-5/8" 40#, L-80, BTC 14945' I KOP 8 degrees@ 1232' Max. hole angle::= 63 deg @6220' Hole angle thru' petis = 1 c? 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID ::= 2,347", cap. ::= 0.00592 bpf ) 7" 26#, L-80, BTC Casing (drift ID = 6.151, cap.= .0383 bpf) Perforation Summary USIT Cement bond log dated 1/8/04 Size SPF Interval (TVD) A Sands 33/8' 12 9467' - 9477' 7151' - 7161' 33/8" 12 9485' - 9495' 7169' - 7178' 3 3/8" 12 9515' - 9525' 7198' - 7208' MPF-87a . )orig. DB Elev. = 44.10' Orig. RT to LDS = 30.07' Camco 2-7/8" x 1" w/ BK-5 latch side pocket KBMG GLM 138' I ~ Camco 2-7/8" x 1" w/ BK-5 latch sidepocket KBMG GLM I 9,146' I 2-7/8" HES XN-Nipple ( 2.250" id ) 9,290' I Centrilift 122 stg GC2200 I 9,309' I model: GMPTAR 1:1 Centrilift Tandem Seal SE::ction 9,339' GSB3DBUT/L T ILH6PFSAFLASfHSN Centrilift 190 HP, KMH 2415v/48a. 9,352' Pump Mate SIN PCT1138 I 9,369' I 4-ES Cleaned out to 9,656' 9/28/04 .,~ 7" Halliburton Float Collar 7" Halliburton float shoe 9656' 9740' DATE REV. BY COMMENTS Mil NF POINT UNIT 12/20103 Lee Hulme Drilled & Completed by Doyon 14 WFI I No.: MPF-87A 04/22/04 MOO Convert Jet to ESP Initial 4-ES API: 50-0?9-?3184-01-o0 09/29/04 JRC RWO for FCO by 4-ES 12/29/05 REH RWO by 4ES BP EXPLORATION (AK) ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/23/2005 Rig Release: 12/26/2005 Rig Number: Spud Date: 12/1/2003 End: 12/26/2005 Scope and Lower Derrick. Rig down equipment Move Rig from MPL-04 to MPF-87 Spot Sub Base and Modules Raise and scope Derrick. Rig-up kill lines to Tree and Tigar Tank. Test to 3,500 psi. Begin to take on Hot Sea Water in Pits. Rig accepted at 13:00 hrs. Pick-up Lubricator and pull BPV. Lay down same. Test Lines at 3,500 psi. Circulate 8.5 ppg hot seawater at 4 bpm 11000 psi. Monitor Well. Set and teasst TWC. Blow down Lines. Nipple down Tree and Adaptor Flange. Nipple up BOP Stack. PJSM. Test BOPE as per BP/AOGCC procedure at 250 psi low 13500 psi high 5 min charted. Test witnessed by Nabors Tollpusher and BP Rep. State's right to witness test, waived by John Crisp. Finish testing BOPE. Rig down Test Equipment. Blow down Lines. Pick-up Lubricator and pull TWC. Lay down same. Monitor Well dead. Make-up Landing Joint. BOLDS. Pull Tubing Hanger to Rig Floor with no problems. Hanger free at 85K. Pulling normal string weight at 75K. Pull ESP Cable over sheave attach to Spooling Unit Reel. TOH with 2 7/8" ESP Completion. Stop to change-out Cable Reels. Finish TOH with 2 7/8" Tubing (293 Jts). Inspect and lay-down ESP Assembly. Pump worn out. No sign of sand or silt. Clear and clean Rig Floor, Make-up 2 7/8" Mule Shoe. TIH with 293 Jts. Begin to pick-up extra Joints from Pipe Shed. Tagged Fill at 9,566' 4es. Bottom Perforation is at 9,525'. (Note: on 09/27/2004 Fill was tagged at 9,504'). DECOMP Rig-up to Reverse Circulate. Attempt to get returns with 120 bbls at 3.5 bpmlO psi. Discussed lack of returns with MPU Well Ops Sup and Anch Eng. Decission made to abort Fill clean-out. DECOMP Single down extra Joints in Pipe Shed. Continue to TOH, standing back in Derrick. RUNCMP Pick-up-assemble ESP Pump. 5.85" O.D. Centralizer, Pumpmate Sensor, Motor KHM 190, Lower Tandem Seal, Upper Tandem Seal, Gas Seperator, Pump, and Discharge Head. Service Pump. Attach lead flat cable with splice between Discharge Head and 10' handling pup. Install 4 Protectolizers 2 Flat Gaurds. TIH with ESP Pump using La Salle Cast Cable Protectors first 9 Jts. on GLM pups then every other Jt. of 2-7/8" EUE 8rd L-80 Tbg touqued 2100 ft-Ib. TIH new ESP by stands on 2-7/8" EUE 8rd L-80 Tbg, stopping Date From-To' HoÜrs Task Code NPT 12/24/2005 06:00 - 08:00 2.00 RIGD P PRE 08:00 - 10:00 2.00 MOB P PRE 10:00 - 11 :00 1.00 RIGU P PRE 11 :00 - 13:00 2.00 RIGU P DECOMP 13:00 - 14:30 1.50 KILL P DECOMP 14:30 - 15:00 0.50 WHSUR P DECOMP 15:00 - 15:30 0.50 KILL P DECOMP 15:30 - 18:00 2.50 KILL P DECOMP 18:00 - 18:30 0.50 WHSUR P DECOMP 18:30 - 19:30 1.00 WHSUR P DECOMP 19:30 - 21 :00 1.50 BOPSUR P DECOMP 21 :00 - 00:00 3.00 BOPSUPP DECOMP 12/25/2005 00:00 - 00:30 0.50 BOPSUPP DECOMP 00:30 - 01 :30 1.00 BOPSUPP DECOMP 01 :30 - 02:00 0.50 PULL P DECOMP 02:00 - 02:30 0.50 PULL P DECOMP 02:30 - 03:00 0.50 PULL P DECOMP 03:00 - 03:30 0.50 PULL P DECOMP 03:30 - 04:00 0.50 PULL P DECOMP 04:00 - 09:00 5.00 PULL P DECOMP 09:00 - 11 :00 2.00 PULL P DECOMP 11 :00 - 12:00 1.00 PULL P DECOMP 12:00 - 15:30 3.50 CLEAN P DECOMP 15:30 - 16:30 1.00 CLEAN P 16:30 - 20:30 4.00 CLEAN P 20:30 - 21 :30 1.00 RUNCOMP 21 :30 - 23:00 1.50 RUNCOMP RUNCMP 23:00 - 00:00 1.00 RUNCOMP RUNCMP 12/26/2005 00:00 - 03:30 3.50 RUNCOMP RUNCMP , , Pesçriptiöpof Op¢ratiohS Printed: 12/27/2005 8:36:06 AM ) ) BP EXPLORATION Pélge201~ Qperåtions ·SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/23/2005 Rig Release: 12/26/2005 Rig Number: Spud Date: 12/1/2003 End: 12/26/2005 Date From-To Hours Task Code NPT Phase 12/26/2005 00:00 - 03:30 3.50 RUNCOMP 03:30 - 07:00 3.50 RUNCOMP 07:00 - 08:00 1.00 RUNCOMP 08:00 - 10:00 2.00 RUNCOMP 10:00 - 11 :00 1.00 RUNCOMP 11 :00 - 13:00 2.00 BOPSUR P 13:00 - 14:00 1.00 WHSUR P 14:00 - 14:30 0.50 WHSUR P 14:30 - 15:00 0.50 WHSUR P 15:00 - 16:00 1.00 RIGD P 16:00 - 18:00 2.00 RIGD P RUNCMP every 20 stands, flushing pump, checking conductivity of cable. RUNCMP Stop wth 248 Joints ran. Perform Reel to Reel cable splice. Clear and clean Rig Floor. RUNCMP Finish RIH with 2 7/8" ESP Completion. PUW = 85K SOW = 43K. Make-up Tubing Hanger. Install Penetrators. RUNCMP Splice in Field Connection. Check Cable. RUNCMP Land Tubing Hanger. RILDS. Lay down Landing Joint. RUNCMP Install and test TWC. Drain BOP Stack. Nipple-down BOPE. RUNCMP Nipple-up Tree. RUNCMP Test Tubing Hanger and Tree at 5,000 psi. Good. RUNCMP Pick-up Lubricator and pull TWC. Lay down same. Install BPV. RUNCMP Rig down ESP Double Sheve from Derrick. Preform fnal ESP Cable check. RUNCMP Clean Pits. Secure Wellhead and Cellar. Scope down and lower derrick. Release Rig at 18:00. Wait on Sows. Printed: 12/27/2005 8:36:06 AM Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well Job # Log Description Date BL 02-30B 10980587 RST 07/17/05 1 PSI-07 10674389 RST 1 0/27/03 1 PSI-07 10679045 RST 12/26/03 1 L3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F-30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 Z-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNL 10/16/05 1 18-31A 10942210 MCNL 04/28/05 1 H-02A 10928622 MCNL 04/05/05 1 05-24A 10928609 MCNL *(PRINT SENT 1/24/05) * 12/22/04 K-06A 11075903 MCNL 07/30/05 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B-02A 10889169 SCMT 09/22/04 H-05 10674407 CBL 01/21/04 G-13A 10563175 SCMT 06/17/03 E-06A 11051045 SCMT 05/19/05 W-20 10672389 USIT 06103/04 MPF-87A r:205- Q ( 3 10708043 USIT 01/08/04 MPA-03 11058243 USIT 09/07/05 MPF-89 11051088 USIT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: , t .{' \ "'C,A ..- ~"",c:':~""'t\ -{ if :¡ \ '/'1 "-¡~ I , )' . ,,_ ! \.. :\., Û ,u NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage; AK 99501 Field: Prudhoe Bay, Milne pt. Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TIN: Beth Î' r· Received by: ,(J~\.r l/ \.~ 11/17/05 -- ,~ . STATE OF ALASKA ALASKA t AND GAS CONSERVATION CC )ISSION REPORT OF SUNDRY WELL OPE RATIO 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): NOV 0 1 2004 a Repair Well 0 Plug Perforations 0 Stimulate a Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well e~~~·g~~µOi~g" a ,¡QtQP-';' II' :;;¡ ~:'~':~ C-1;¡iIT¡:,m,¡U"''':::!i''' o Time Extension KBE = 45.05' 9751' 7431' 9656' 7337' 78' 4910' 9710' 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 203-213 6. API Number: 50-029-23184-01-00 99519-6612 9. Well Name and Number: MPF-87 A 10. Field I Pool(s): Milne Point Unit I Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 1530 520 9-5/8" 4945' 4463' 6870 4760 7" 9742' 7422' 7240 5410 F~'~ F ~ L",.:"" NOV 0 J 2004 9467' - 9525' 7151' - 7208' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8", 6.5# L-80 9370' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NIA NIA Treatment description including volumes used and final pressure: mws Bft "0'1 U 1 nmi¿lf 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure 79 265 140 351 Oil-Bbl Prior to well operation: 168 Subsequent to operation: 261 14. Attachments: 0 Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram Tubinq Pressure 15. Well Class after proposed work: o Exploratory a Development 0 Service 16. Well Status after proposed work: a Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant - .'η r .;~ . .~ . ?.. .......~. Phone Sijna~ur¥.~.Æe~~"'·· ,~~r-._--'-'-n R I G I N 5^4-5803 Form 1 0-4ð4 Revised 04/2004 U M -? ¡ Prepared By Name/Number: Date 'O-}~..ì '01 Sondra Stewman, 564-4750 Submit Original Only ) ) BPEXPLORA TION Opera,tion$ Summary Report Paget of2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/26/2004 Rig Release: 9/29/2004 Rig Number: Spud Date: 12/1/2003 End: 9/30/2004 Date From - To HoUrs TélSk Code NPT Phase 9/26/2004 04:00 - 07:00 3.00 RIGD P PRE PJSM. Scope down & layover derrick. Rig down. 07:00 - 12:00 5.00 MOB P PRE PJSM. Move rig & rig components from MPG-03 to MPF-87. Approximately 10 mile move. 12:00 - 15:00 3.00 RIGU P PRE PJSM. Spot sub. Raise & scope up derrick. Rig up. Rig Accepted @ 15:00 hrs, 09/26/2004. 15:00 - 16:30 1.50 KILL P DECOMP Rig up lines to tiger tank & wellhead. Take on 125 degree seawater. 16:30 - 17:30 1.00 KILL P DECOMP PJSM. Pick up lubricator. Pull BPV. SITP = 200 psi. UD lubricator. SICP = 810 psi. 17:30 - 18:30 1.00 KILL P DECOMP Pressure test lines to 3000 psi, Ok. Hold PJSM & Pre-Spud meeting wi all hands. 18:30 - 22:00 3.50 KILL P DECOMP Open well. SITP 150 psi, SICP 810 psi. OAP = 500 psi. Circulate & kill well wI 8.5 ppg seawater. Kill @ 4 BPM ,90 psi. Pumped 440 bbls. SID observed well, well dead. Open & circ to pits. good clean returns wi no oil. Lost 2.7 bbls in 5 min. SID monitor well. Prep to install TWC. 22:00 - 22:30 0.50 WHSUR P DECOMP RID lines to tree. Install TWC & test same. 22:30 - 00:00 1.50 WHSUR P DECOMP Bleed off tbg hanger void. NID tree. Check threads in hanger: 27/8" EUE 8RD. Made up w/10 1/4 turns. Threads - good. 9/27/2004 00:00 - 02:00 2.00 BOPSURP DECOMP N/U BOPE. 02:00 - 05:30 3,50 BOPSUP P DECOMP Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones wI AOGCC. RID test equip. 05:30 - 06:00 0.50 WHSUR P DECOMP M/U lubricator, Pull TWC. No pressure. UD lubricator. 06:00 - 06:30 0.50 PULL P DECOMP Maintain & lubricate rig. 06:30 - 08:00 1.50 PULL P DECOMP PJSM. BOLDs. Make up landing joint & pull hanger to floor, 90K to pull free, 87K up wt. ESP cable slipping through clamps, attach tugger. Disconnect cable from hanger. 08:00 - 09:00 1.00 PULL P DECOMP POOH w/2 7/8" EUE 8 rnd tubing & ESP cable. Stand back tbg, double displacing hole. 09:00 - 09:30 0.50 PULL P DECOMP PJSM. Cut cable & change out spools. 09:30 - 12:30 3.00 PULL P DECOMP Continue to POOH w/2 7/8" ESP completion. ESP cable snarled badly in several areas below jt #233. 12:30 - 13:30 1.00 PULL P DECOMP PJSM. Remove flat guards & pull cable over sheave. 13:30 - 15:30 2.00 PULL P DECOMP Inspect pump. Packed full of frac sand. UD ESP pump assembly. 15:30 - 16:30 1.00 CLEAN P DECOMP Clear I clean rig floor. Prep to make clean out run. 16:30 - 20:00 3.50 CLEAN P DECOMP M/U muleshoe on 2 7/8" tbg. RIH wi 97 stands. P/U singles & tag up on fill @ 9504'. 20:00 - 23:00 3.00 CLEAN P DECOMP M/U head pin on tbg. Break circulation & fill hole. Took 38 bbls. Losses were 8.2 bbls in 10 min. P/U singles & wash down to PBTD @ 9656'. Circulate thru fill very easily. Losses 8-12 bbls in 10 min while washing. P/U 60K, S/O 35K. Circ @ 3 BPM 350 psi. 23:00 - 00:00 1.00 CLEAN P DECOMP P/U 5' pump 3- 10 bbl sweeps & circulate out carbolite fill. Circ 4 BPM @ 450 psi. 9/28/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP Con't to reverse circulate & clean up well. 4 BPM @ 450 psi. Hole cleaned up. Recovered much carbolite. 01 :00 - 04:30 3.50 CLEAN P DECOMP POOH wi tbg. UD 17 singles & stand back 97 stands. 04:30 - 05:30 1.00 CLEAN P DECaMP Clear & clean rig floor. 05:30 - 06:00 0.50 RUNCOM? RUNCMP R/U to P/U & run new ESP completion. 06:00 - 06:30 0.50 RUNCOrvP RUNCMP Lubricate rig. Printed: 10/1/2004 9:07:37 AM ') ) BP EXPLORATION Operation$Summary Report Page 2 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/26/2004 Rig Release: 9/29/2004 Rig Number: Spud Date: 12/1/2003 End: 9/30/2004 pate From - To Hours Task Code NPT . Phase Description of Operatioh~ 9/28/2004 06:30 - 09:30 3.00 RUNCOMP RUNCMP PJSM. P/U and M/U ESP components and inspect, service same. Attach, secure, and test cable. 09:30 - 10:30 1.00 RUNCOMP RUNCMP TIH new ESP on 2-7/8",6.5#, EUE 8rd, L-80 tbg from derrick. 10:30 - 14:00 3.50 RUNCOMP RUNCMP Check Cable Armor in Spooling Unit; protective armor smashed. Make repairs and check--good. 14:00 - 17:00 3.00 RUNCOMP RUNCMP Cont TIH; test cable--good. 17:00 - 20:00 3.00 RUNCOMP RUNCMP Remove empty spool from spooling unit; make Reel-to-Reel splice. 20:00 - 21 :30 1.50 RUNCOMP RUNCMP Cont TIH. Cable splice came out exacty on tbg collar. POH stand #85, M/U 8.02' pup jt on top of std #84, complete TIH from derrick. 21 :30 - 22:00 0.50 RUNCOMP RUNCMP M/U pup jts to space out for top cable clamp. P/U landing joint and M/U to tbg hanger. P/U wt 81 K, S/O wt 45K. 22:00 - 00:00 2.00 RUNCOMP RUNCMP Install penetrator and make field connection. 9/29/2004 00:00 - 00:30 0.50 RUNCOMP RUNCMP Re-check penetrator field conn. Okay. 00:30 - 01 :00 0.50 RUNCOMP RUNCMP P/U and M/U landing jt to hanger, land hanger, RILDS. 01 :00 - 02:30 1.50 BOPSUR P RUNCMP Set TWC. N/D BOPE. 02:30 - 03:00 0.50 BOPSUP P RUNCMP Baker Centrilift learned that a penetrator seal integral to the bottom side of the hanger, had not been installed. The BOP stack must be re-assembled in order to pull the hanger to the floor. 03:00 - 05:00 2.00 BOPSUR N HMAN RUNCMP N/U BOPE. P/U lubricator, pull TWC, LID same. Check well, both sides on vacuum. P/U Idg jt, install in hanger, pull to floor. 05:00 - 07:30 2.50 RUNCOI'vN HMAN RUNCMP Disconnect lower BIW connector, install 3-way seal, reinstall BIW conn. P/U and M/U landing jt to hanger, land hanger, RILDS. Lay down Landing Joint. Install TWC. 07:30 - 10:30 3.00 BOPSUPN HMAN RUNCMP Nipple down BOP stack and Valves. 10:30 - 11 :30 1.00 WHSUR P RUNCMP Nipple up Adaptor Flange and Production Tree. 11 :30 - 12:00 0.50 WHSUR P RUNCMP Test Adaptor and Tree at 5K. Good test. 12:00 - 12:30 0.50 WHSUR P RUNCMP Pick up Lubricator. Pull TWC. Lay down same. Install BPV. 12:30 - 13:00 0.50 WHSUR P RUNCMP Blow down lines. Secure Cellar. Release Rig at 13:00 hrs. Printed: 10/1/2004 9:07:37 AM .. STATE OF ALASKA ALASKA ì AND GAS CONSERVATION CO.JISSION . . .. I:::D' REPORT OF SUNDRY WELL OPERATION8ECEIV..:: . MAY 1 8 2004 '. 1, Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 o Waiver Alaskalii~e~as Cons. Commission o Time Extension Chang~ßÇ¡~~mge o Annular Disposal 5. Permit To Drill Number 203-213 6. API Number: 50-029-23184-01-00 o Suspend 0 Operation Shutdown 0 Perforate !HI Repair Well 0 Plug Perforations 0 Stimulate !HI Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service Perforation Depth MD (ft): 9467' - 9525' Perforation Depth TVD (ft): 7151' - 7208' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NIA KBE = 45.05' 8. Property Designation: ADL 355018 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9751' 7431' 9656' 7337' Casing Length Structural Conductor 78' Surface 4910' Intermediate Production 9710' Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9. Well Name and Number: MPF-87 A 10. Field I Pool(s): Milne Point Unit I Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 112' 112' 1530 520 9-5/8" 4945' 4463' 6870 4760 7" 9742' 7422' 7240 5410 2-7/8",6.5# L-80 9379' NIA Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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 David Reem, 564-5743 Printed Name Sondra Stew~~ Title Technical Assistant Phone 1 J I-{)U Prepared By Name/Number: DateOS~ .'-t ~....\Sondra imna", ~-4tmj. : 6, BFL rv-nA -g ('Mi' I 564-5803 ORIGINAl '. ) ) BP EXPLORATION .Ope réttion.~...·Sµrnm a ~y .R~p()rt/ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING.! NABORS 4ES Date Frörn~ To· HOLJrs Task Coqé NPT ;Pbase 4/16/2004 06:00 - 11 :00 5.00 MOB P PRE 11 :00 - 13:00 2.00 RIGU P PRE 13:00 - 15:00 2.00 RIGU P DECOMP 15:00 - 16:00 1.00 KilL P DECOMP 16:00 - 16:30 0.50 KilL P DECOMP 16:30 - 19:30 3.00 KilL P DECOMP 19:30 - 20:30 1.00 KILL P DECOMP 20:30 - 21 :30 1.00 WHSUR P DECOMP 21 :30 - 23:30 2.00 BOPSUP P DECOMP 23:30 - 00:00 0.50 BOPSURP DECOMP 4/17/2004 00:00 - 03:00 3.00 BOPSUP. P DECOMP 03:00 - 04:00 1.00 BOPSUP P DECOMP 04:00 - 04:30 0.50 PULL P DECOMP 04:30 - 06:00 1.50 EVAL C DECOMP 06:00 - 13:00 7.00 MOB C DECOMP 13:00 - 13:30 0.50 FISH C DECOMP 13:30 - 15:00 1.50 FISH C DECOMP 15:00 - 18:00 3.00 FISH C DECOMP 18:00 - 19:00 1.00 FISH C DECOMP 19:00 - 20:00 1.00 FISH C DECOMP 20:00 - 22:00 2.00 FISH C DECOMP 22:00 - 22:30 0.50 FISH C DECOMP 22:30 - 00:00 1.50 FISH C DECOMP 4/18/2004 00:00 - 01 :30 1.50 FISH C DECOMP 01 :30 - 02:00 0.50 FISH C DECOMP 02:00 - 10:00 8.00 FISH P DECOMP 10:00 - 12:00 2.00 FISH C DECOMP 12:00 - 14:00 2.00 FISH C DECOMP 14:00-19:00 5.00 FISH C DECOMP 19:00 - 20:30 1.50 FISH C DECOMP Start: 4/16/2004 Rig Release: 4/22/2004 Rig Number: 4ES Spud Date: 12/1/2003 End: 4/22/2004 .... .". . ···..··bescription of Operations Rig down from MPF-69 and move to MPF-87A. Rig Up on MPF-87A. Accept rig at 1300 hours. H/U lines to tree to enable hot seawater circulation. Pull BPV, test lines. SITP 150 psi, SICP 0 psi. PJSM wi Co Rep, Tool Pusher, and crew. Circulate 3 BPM @ 250 psi for full well kill volume of 325 Bbls (5525 Strokes); returns to pits at 1900 strokes (112 Bbls). SI well ISIPs: TP 0 psi, CP 140 psi. After 10 mins: TP 0 psi, CP 80 psi. At 1930 hours: TP 0 psi, CP 0 psi. P/U and install TWC. Blow down all lines. NID tree, check hanger threads: 4-1/2" TCII, 8 turns. N/U DSA, spacer spool, BOPE. Begin BOPE pressure test. AOGCC rep, Chuck Sheve, waived test witness. Pressure test BOPE 250 psi 13500 psi. Remove test spool, drain BOPE. P/U and install lubricator and pull TWC. P/U landing joint and pull hanger, pull to 170K and slack off several times with no movement. Confer wI engineer, SWS, Baker Fishing Tools. Wait on Schlumberger; service and clean rig. PJSM wi crew, Tool Pusher, Co Rep. R/U SWS, P/U Chem cutter assy and collar locator and prepare to RIH. RIH wi C/l and chem cutter and postion @ 9285.2' (inside Premier Packer cut zone). Fire cutter and POOH. SWS found fluid level at 2914'. RID SWS and P/U landing joint. Pull to 170K several times without packer unseating. Pump 30 Bbls fluid down tubing, monitor well. RID landing joint. M/U new landing jt wi 4-1/2", TC-II pups, P/U wi 130K, set slips w/117K wt. R/U SWS and prepare for M/U Chem cutter and CIL to make a cut in the top 3 feet of the 10' pup jt immediately above the packer, that is: @ +1- 9273'. PJSM wI crew, SWS, TIP, Co Rep. Clear floor and R/U CIL and Chem Cut assy. RIH wi SWS CIL and chem cut assy and position @ 9273' and fire wi good response at surface. POH SWS CIL and chem cutter assy, clear floor, LID SWS W/L equipment and RID SWS surface equipment. Tubing free at 115K. Pull Hanger to Floor. POOH with 4 1/2" L-80 Frac String. Single down in Pipe Shed 240 Jt of 4 1/2" L-80 "mixed threads" of Tbg, 1 GLM, Sliding Sieve, X-Nipple, and a 41/2" Chemical Cut Stub = 3.06'. Chem Cut was clean. Clear and clean Floor. Finish loading Drill Collars in Pipe Shed. Rig up to handle Drill Collars and Drill Pipe. Make up BHA #1 as follows: 61/8" MM Shoe, WP Ext, WP Ext, WP Ext, Boot Basket, XO, Boot Basket, Boot Basket, Bit Sub, Bumper Jar, Oil Jar, 9 ea 4 3/4" Drill Collars. RIH BHA #1 on 3-1/2" DP to Top of Packer @ 9277' to begin W/O operations. P/U Kelly and lower to begin W/O packer, 3 BPM, 100 psi. Printed: 4/30/2004 1 :45:51 PM ) ) BP EXPLORATION .·Op~rations: ·:SUl'1Jnl~ry.Repºr~; DECOMP Torque on 3-1/2" DIP is 9,600 ft-Ibs wi low WOB. Pump 100 Bbls wi no returns; pump 10 addtl Bbls and oil, gas, and diesel to surface. Take returns through gas buster. Stop W/O and circulate out light fluids and mix 1-Bbl EP Mud Lube in pit. Total circ volume 335 Bbls to clean up returns. DECaMP Resume milling and pump 10 Bbls EP Mud Lube mix every 20 minutes. Starting parameters: 4 BPM @ 800 psi, 60 RPM, 2-4K WOB, 300A, 9600 ft-Ibs. By 2300 hrs amperage dropped to 200A, torque to 4500 ft-Ibs. 3-feet of penetration made, but appears it may have been fill. Hard drilling at +1- 9280'. . Continue milling operations with little progress. Continue milling on packer. Fluid loss is averaging 50 Bbls per hour while milling. Confer wi Baker FT and prepare to POOH wi 3-1/2" DIP and BHA #1. TOH and stand back 3-1/2" DP. Lay down BHA #1. Clear and Clean Floor. Make-up BHA #2 as follows: 5 7/8" Overshot w/4.500 BAsket Grapple, Bumper Jar, Oil JAr, 9 ea Drill Collars, Accelerator. RIH w/3 1/2" Drill Pipe (282 jts) and 10-ft Pup Jt. Pick-up Kelly. Tag TOF at 9,274-ft. Latch Fish. Jar Fish loose (1 jar lick). PUH...Fish dragging. Run back in hole past orginal setting depth (9,280-ft) to 9,289-ft. POOH (Fish dragging off bottom) with Drill Pipe, and BHA. Fish at surface. Lay down fish complete... recovered 41/2" Stump, Packer, 2 Pup Jts, XN-Nipple, Pup Jt and Mule Shoe. Clear and clean rig floor. M/U: 6" bit, bit sub, jars, 9--4-3/4" DCs. RIH & tag at 9480' and start cleanout. Mix 40 Bbl Flovis pill. Pump seawater @ 6 BPM @ 1550 down DP to break circulation, realign to rev circ fill from 9480' to 9538'. P/U jt #291; re-establish circulation down DP and move one jt length in and out twice. Line up to rev circ--trouble getting circulation while pressure was building. P/U and DP pulled tight wi 20-30K overpull. DP stuck near mid-perfs @ +1- 9500'. DECOMP Work DP string to 300K. DECOMP Stopped circulating fluids. Worked pipe to 300k numerous times. Pipe stuck near mid-perfs (-9500') by Carbolite Frac Sand when it settled back downhole while making connection to DP jt #290, At 02:30 hrs, stopped working pipe to allow well fluid levels to continue to drop. 03:00 hours, pipe pulled free and came up hole wi full string weight of 145K. Build Flo-Vis System. Circulate 6 BPM, 1000 psi down tubing and swap well over to Vis'd Sea Water ystem. Reverse circulate 4 BPM @ 500 psi, and resume cleanout. Had to rotatelwash to break up Carbolite from 9,508' down to bottom Perforation at 9,525', From bottom Perf down to 9,603' Carbolite washed out easy. Reverse Circulated at 3 bpm/500 psi (fluid loss 1/2 bpm. Note: an increase in rate jumped loss to formation up greatly). Had to pump long way to make any Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From"' Tb ..; HoD rs. Task Go de NPT 4/1 8/2004 19:00 20:30 1.50 FISH C Phase 20:30 - 23:00 2.50 FISH C 23:00 - 00:00 1.00 FISH C DECOMP 4/19/2004 00:00 - 03:00 3.00 FISH C DECOMP 03:00 - 03:30 0.50 FISH C DECOMP 03:30 - 07:30 4.00 FISH C DECOMP 07:30 - 08:30 1.00 FISH C DECOMP 08:30 - 09:00 0.50 FISH C DECOMP 09:00 - 12:00 3.00 FISH C DECOMP 12:00 - 13:00 1.00 FISH C DECOMP 13:00 - 16:00 3.00 FISH C DECOMP 16:00 - 17:00 1.00 FISH C DECOMP 17:00 - 18:00 1.00 FISH C DECOMP 18:00 - 22:00 4.00 CLEAN C DECOMP 22:00 - 23:30 1.50 CLEAN C DECOMP 4/20/2004 23:30 - 00:00 00:00 - 03:00 0,50 CLEAN C 3.00 CLEAN C 03:00 - 04:00 1.00 CLEAN C DECOMP 04:00 - 05:30 1.50 CLEAN C DECOMP 05:30 - 06:00 0.50 CLEAN C DECOMP 06:00 - 11 :00 5.00 CLEAN C DECOMP Page 2of3 Start: 4/16/2004 Rig Release: 4/22/2004 Rig Number: 4ES Spud Date: 12/1/2003 End: 4/22/2004 Printed: 4/30/2004 1 :45:51 PM ") ') BP EXPLORATION ppe ratiQns$ u mmétry· .Report.· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-87 MPF-87 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours· Task· Coqe NPT Start: 4/16/2004 Rig Release: 4/22/2004 Rig Number: 4ES Spud Date: 12/1/2003 End: 4/22/2004 .... . ". . Dèscri ÞFOnQfqperätions DECOMP progress...calculated top of sand on backside + DPV + 10%.. .then reversed calculated vol to surface. Had minor differental sicking two more times befor reaching targeted clean-out depth. Reverse Circulated at 3 bpm/500 psi until well clean Set back Kelly. Lay down 6 Jts of 3 1/2" drill Pipe. Park Bit at -9,400-ft (top Perforation at 9,467'). Wait for clean sea Water to arrive. Reverse circulate & displace well wi clean seawater. RID & blow down circulating lines. Cut & slip drilling line. POOH & LID 3 1/2" DP to 5245'. Rig repair. Backstop on LId machine broken, Remove same & begin repair. Attempt repair on existing stop. Had to modify & replace wi new stop assy. Resume Operations. Single down 3 1/2" Drill Pipe in Pipe Shed. Lay down drill Collars, Oil Jars, and Bit. 4/20/2004 06:00 - 11 :00 5.00 CLEAN C 4/21/2004 11 :00 - 13:00 2.00 CLEAN C DECOMP 13:00 - 13:30 0.50 CLEAN C DECOMP 13:30 - 16:00 2,50 CLEAN C DECaMP 16:00 - 16:30 0.50 CLEAN C DECOMP 16:30 - 17:30 1.00 CLEAN C DECOMP 17:30 - 21 :00 3.50 CLEAN C DECaMP 21 :00 - 00:00 3.00 CLEAN N RREP DECOMP 00:00 - 05:00 5.00 CLEAN N RREP DECOMP 05:00 - 09:00 4.00 CLEAN C DECOMP 09:00 - 09:30 0.50 CLEAN C DECOMP 09:30 - 11 :30 2.00 RUNCOMP CaMP 11 :30 - 14:30 3.00 RUNCOMP COMP 14:30 - 17:00 2.50 RUNCOMP COMP 17:00 - 18:00 1.00 RUNCOMP COMP 18:00 - 00:00 6,00 RUNCOMP COMP 00:00 - 02:00 2.00 RUNCOMP COMP 02:00 - 05:30 3.50 RUNCOMP COMP 05:30 - 07:30 2.00 RUNCOMP COMP 07:30 - 08:00 0.50 RUNCOMP COMP 08:00 - 10:30 2.50 RUNCOMP COMP 10:30 - 11 :00 0.50 RUNCOMP COMP 11 :00 - 13:00 2.00 BOPSUP P COMP 13:00 - 15:00 2.00 WHSUR P COMP 15:00 - 16:00 1.00 WHSUR P COMP 16:00 - 18:00 2.00 WHSUR P COMP 18:00 - 00:00 6.00 DEMOB P POST 4/22/2004 Clear and Clean Floor. Bring ESP Equipment to Pipe Shed. RU to run ESP Completion. P/U & service motor & ESP. RID ESP cable sheave. Repair drip pan & R/U sheave. Plug cable into motor. Secure MLE & Phoneix sensor. P/U 2 7/8' tubing & RIH. Check cable every 2000' & pump thru ESP. Ran 185 jts. Con't to P/U 27/8" tubing & RIH. Ran 257 jts, Make reel to reel cable splice. Check same. Clean on rig. Finished RIH with ESP Assembly, 293 Jt 2 7/8" L-80 Tbg, 2 GLMs, 3 ea. 27/8" Pup Jts, 3 1/2" x 2 7/8" XO. Make up Tbg Hanger. Install Penetrator. Make up Field connector to ESP Cable. Land Tbg Hanger. RILDS. Lay down Landing Jt. Set TWC. Nipple down BOP Stack. Nipple up Adaptor Flange and Production Tree. Test Flange and Tree at 250/5000 psi. Pull TWC. Install BPV. Clear & clean rig floor. Secure well & cellar. RELEASE RIG @ 1800 hrs. RDMO to MPF-57a. Printed: 4/30/2004 1 :45:51 PM ) Tree: 4 1/16" Cameron Wellhead: FMC 11" gen 5 casing hanger. FMC 11" x 4.5" gen 5 tubing hanger. 4.5" BP\I. TC-II Landing Threads Surface casing 20", 94# H-80 ŒiÐ 9-5/8" 40#, L-80, BTC 14945' I ~ KOP 8 degrees@1232' Max. hole angle = 63 deg @6220' Hole angle thru' perfs = 10° 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26#, L-80, BTC Casing (drift ID = 6.151 cap.= .0383 bpf cap wi 4 1/2" tbg = .0186) Peñoration Summary USIT Cement bond log dated 1/8/04 Size SPF Interval (TVD) A Sands 33/8" 12 9467' - 9477' 7151' - 7161' 33/8" 12 9485' - 9495' 7169' - 7178' 3 3/8" 12 9515' - 9525' 7198' - 7208' DATE 12/20103 04/22/04 REV. BY Lee Hulme MPF-87a II··'·'''''·· ··'m"""QDI"····"·',·'·'·!,,, ';::, ':.;¡ 1:: ,:, '\': ~~'" """,.'.'.... ".~...,.. "", , ::"'", ~ ~ .> Orig. DB Elev. = 44.10' Orig. RT to LDS = 30.0T Camco 2-7/8" x 1" wi BK-5 latch sidepocket KBMG GLM 170' Cameo 2-7/8" x 1" wi BK-5 latch side pocket KBMG GLM I 9,147' I 2-7/8" HES XN-Nipple ( 2.250" id ) 9,259' I Centrilift Tandem GMPTAR 1:1 I 9,304' I GC2200 122 stg./ GC8200 19 stg. ESP series 513 Centrìlift Tandem Gas Separator 9,332' G RSTXBARH6 Centrilift Tandem Seal Section 9,337' GSB3DBUTILH6PFSAFLAS/HSNCL5 GSB3DBL TILH6AFLAS/HSNCL5 Centrilift KMH 562 series, 9,350' 266 hp motor, 2345 v. I 69 amps. Phoenix MS1 Multisensor w/6 fin I 9,379' I Centralizer 4-ES Cleaned out to 9,603' 4/22/04 ~ 7" Halliburton Float Collar 7" Halliburton float shoe 9656' 9740' COMMENTS Orilled & Completed by Doyon 14 Convert Jet to ESP Initial 4-ES MILNE POINT UNIT WELL No.: MPF-8:7A API: 50-029-231840.01-00 MOO BP EXPLORATION (AK) t..: ) ',' «\ ~ ~. cp). )3 s'-'v J J.~ ) c2():;$ c2/3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COl1un. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 , MWD Formation EvaluatiOnl:<>GF-87 A, ::) February 27,2004 RE: AK-MW-2798647 1 LIS formatted Disc with verification listing. API#: 50-029-23184-01 Idvêfl~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~\.,.~ ~~ RECEIVED r' i\ r, .1 0 A!'o04 ".,;., ',,,I ! U· -'11 I ;,,:;~~ '\ I . L_\.} , }\ïð~k,fJj o¡¡ &; Gas Cons. Commission g~~r¡chorage RBDMS RD ... .t( 'MAR 3 0 200_ . -- '1 ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 1/27/2004 .¡ 6. Date Spudded ./ 12/12/2003 21. Logs Run: MWD , GR , IFR/CASANDRA , PWD , ABI , RES, GYRO CASING, LINER AND CEMENTING RECORD I" I',· ....", ., 1..':·1,1.': ·,.,1.1: :1:, ~E"¡""IN"'b' r"icF!mL\:"M" hi i' "~'E"'¡'IMh:"nE' ci"'''',:.¡'''¡'p·· '''''';'1:'·", .,:. . """':"""'. "'.'.' I~:::'" :>\, :'1 'I,~; :'::,!I.I ~:;:I,:¡'::'>:ii·:!':".I;.';;;i'( ,:,;~ . '!'~:::~~';~"'I ,~,',I;~"r ,'Iïi,~:"~,~',, ,~~!!t"'". ~,:~ ":'~':I::~.I;.,',~~.~~ . J:I':lt;'~,I\II.I'IY .",,:.,!"I 11::I,'::~,::!;:I;~:Ql~{e:l:i:il:':i,'" i"'IIIII'!"'~iAAP¡¡:,!,I:,i,::: \1¡:,I:"m~~!:'I'I:I:I;I.I::IBiø1~~M:r!~llil:[OPI'I'::';:'i ·.·B:o:jrrb~::'I'I:I':I:"I,,:IS,.z~I'li'II,li:, H-40 34' 112' 34' 112' 42" 260 sx Arctic Set(Approx.) L-80 35' 4945' 35' 4457' 12-1/4" 725 sx Class 'L', 225 sx Class 'G' L-80 32' 9742' 32' 7422' 8-1/2" 200 sx Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 15, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 2/20/2004 6 TEST PERIOD + 347 Flow Tubing Casing Pressure CALCULATED + OIL-BBL Press. 24-HoUR RATE 1390 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2114' NSL, 2923' WEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 673" NSL, 1181' WEL, SEC. 36, T14N, R09E, UM Total Depth: 712' NSL, 1214' WEL, SEC. 36, T14N, R09E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 541639 / y- 6035565 oj Zone- ASP4 TPI: x- 538202 y- 6039385 Zone- ASP4 Total Depth: x- 538169 I y- 6039423.1 Zone- ASP4 No. of Completions 18. Directional Survey IBI Yes DNo 22. 20" 92# 40# 26# 9-5/8" 7" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3.38" Gun Diameter, 12 SPF MD TVD MD TVD 9467' - 9477' 9485' - 9495' 9515' - 9525' 7151' - 7161' 7169' -7178' 7198' - 7208' 7. Date T. D. Reached 12/15/2003 / 8. KB Elevation (ft): KBE = 45.05' 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-213 13. API Number 50- 029-23184-01-00 14. Well Name and Number: MPF-87A 15. Field I Pool(s): Milne Point Unit I Kuparuk River Sands 9. Plug Back Depth (MD+ TVD) 9656' + 7337' 10. Total Depth (MD+TVD) / I 9751' + 7431' Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL Ft 16. Property Designation: ADL 355018 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) Ytù~ ~rs.r ~ ¥~65""r~ ,:,1. A:M~I:i~:tIIII:" ,','?··,:·fr,,~,·,IIII:¡,I"illlll, I':";·RW~GEØ,I'" SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 9320' PACKER SET (MD) 9280' DEPTH INTERVAL (MD) 9467' - 9525' AMOUNT & KIND OF MATERIAL USED Fractured 'A' Sands with 227000# of 16/20 Carbolite Placed 225000# behind pipe. Freeze Protected with 131 Bbls of Diesel GAs-McF 105 W A TER-BBL o CHOKE SIZE GAS-OIL RATIO 302 GAs-McF 420 W ATER-BBL o OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil,;g.as or wa~ef.(attach ~eparat~she~t;:, if-necessary). Submit core chips; if none, state "none".' ,:'.... '.'.', '. . ,. .... . None , \"1 . ..1-27:6_'1 ~~4Þ:.:'-~ . .. 'r". . t' i, 1~,. ,:.. r ('lV\R 1 8 2004- Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE SIDE MAft 2 ~~100~ G ROOMS BFl 28. ") 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TKGM 9025' 6735' None KLGM 9104' 6806' TKUD 9268' 6960' TKC1 9414' 7100' TKUB 9417' 7103' TKUA 9458' 7143' TKA3 9466' 7150' TKA2 9481' 7165' TKA1 9505' 7188' TMLV 9568' 7250' 1 8 ZOO 30. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Integrity Test Summary, Well Schematic Diagram and a Post Rig Work Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra ~~^-Q.____.Jïtle Technical Assistant DateO~ - l,- OY MPF-87 A 203-213 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Walter Quay, 564-4178 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR\G\NAL ') ) Bp··. OPE!r~tion!;Sl.lmmaryRE!P·()11 Page 1 of9 Legal Well Name: MPF-87 Common Well Name: M PF-87 Spud Date: 12/1/2003 Event Name: DRILL +COMPLETE Start: 11/30/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2003 Rig Name: DOYON 14 Rig Number: 14 Date· Frörn-To Hours Task Code NPT Phase 11/30/2003 09:00 - 12:00 3.00 MOB P PRE Slide rig floor into moving position- Move off of Well F-57 - move and Spot over F-87 conductor 12:00 - 13:30 1.50 MOB P PRE Shim rig and skid rig floor into drill position 13:30 - 14:00 0.50 MOB P PRE Spot rock washer and Rig up floor 14:00 - 16:00 2.00 RIGU P PRE Nipple up 20 diverter system - Accept rig at 1400 hrs 11/30/2003 16:00 - 17:30 1.50 RIGU P PRE Change die in Iron roughneck, Change inserts in Air slip to 4" - Load pipe with 336 jts of 4" drill pipe. 17:30 - 00:00 6.50 RIGU P PRE Pick up 4" 14# S-135 HT -38 drill pipe and stand back in derrick - Rabbit drill pipe - On high line power at 1700 hrs 12/112003 00:00 - 04:00 4.00 RIGU P PRE Continue picking up 4" 14# S-135 drill pipe from pipe shed - Make up torque 18,500 ftllbs 04:00 - 05:30 1.50 RIGU P PRE Pick up 17 jts of 5" Htw and Daily 6 1/4" Hydraulic drilling jar and stand back in derrick - Pick up stand of 6 1/4" flex collars stand back in derrick 05:30 - 07:30 2.00 RIGU P PRE Pick up BHA #1: 12 1/4 Smith bit jetted with 3/15's 1/10, 8" sperry motor set at 1.5 deg bend, MWD/GR 07:30 - 08:00 0.50 DIVRTR P SURF Function test diverter system - Witness of test waived by Mr. John Crisp of AOGCC - Rig up Gyro E-line - Preform derrick inspection 08:00 - 08:30 0.50 DRILL P SURF Spud meeting with drill crew and service personnel on objectives for F-87 08:30 - 09:30 1.00 DRILL P SURF Spud in at 0830 hrs - Drill 112 to 289' with hwt 09:30 - 10:30 1.00 DRILL P SURF Stand back Hwt - Finish picking up BHA 10:30 - 18:30 8.00 DRILL P SURF Drill ahead 289 to 1005' - Art3.5 hrs, Ast .5 hrs - average Rop 223 ftlhr - Magnet interferrence to 821' - MWD survey good at 914' - Suspected MWD tool face reading incorrect when attempting to straighten well bore at 700' - Verify MWD tool face incorrect with gyro tool face at 914' survey depth - MWD 162 deg out from gyro 18:30 - 20:30 2.00 DRILL N DFAL SURF Pump out of hole for MWD failure 20:30 - 22:30 2.00 DRILL N DFAL SURF Check Orientation on MWD, UBHO sub all ok - Change out Sperry 8" survey tool - Up load and orient MWD and UBHO sub - Shallow test at 300' 22:30 - 23:00 0.50 DRILL N DFAL SURF TI H to 722' 23:00 - 00:00 1.00 DRILL N DFAL SURF Gyro survey 210',410',610' to satisfy JORPS - No trust in old mwd surveys 12/2/2003 00:00 - 00:30 0.50 DRILL N DFAL SURF TIH to 1005' - Check shot MWD survey - Ok 00:30 - 14:30 14.00 DRILL P SURF Began kick off at 1005' at 270 deg azimuth building angle at 2 -3 deg 1100' - Pumping 450 gpm, 1600 psi on bottom- Directional Drill from 1005' to 3183' - WOB 35 - GPM 500 - PP 2600 on - off 2400 - RPM 80 - TO on 6K - off 4K - PU 115K - SO 108K 14:30 - 16:30 2.00 DRILL P SURF CBU 3X - RPM 80 - TO 5K - GPM 500 - PP 2400 16:30 - 18:30 2.00 DRILL P SURF Pump out drlg rate 500 GPM to 800' - Hole in good shape 18:30 - 19:30 1.00 DRILL P SURF TIH from 800' to 3183' - No Problems 19:30 - 00:00 4.50 DRILL P SURF Directional Drill from 3183' to 3886' - WOB 35K - RPM 80 - TO on 9K - off 5K - GPM 500 - PP on 2850 - off 2600 - PU 135K- SO 108K - ROT 125K 12/3/2003 00:00 - 13:00 13.00 DRILL P SURF Directional Drill from 3886' to 4953' - T. D. 12 1/4" hole section - WOB 35K - RPM 100 - TO on 8K - off 6K - GPM 500 - PP on 3000 - off 2800 - PU 150K - SO 115K - ROT 130K 13:00 - 16:00 3.00 CASE P SURF CBU 2 X - GPM 500 - PP 2750 - RPM 100 - TO 6K Printed: 12/22/2003 9: 15: 12 AM ) ) BP Operations.. Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PF-87 M PF-87 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 11/30/2003 Rig Release: 12/19/2003 Rig Number: 14 Spud Date: 12/1/2003 End: Date Task Code< NPT Phase Descriþtiqn of Operations 12/3/2003 16:00 - 19:00 3.00 CASE P SURF Pump out to HWT @ 800' - Full drlg rate - @ 1450' large clay ball restriction in riser, flowline - clean out - Con't Pump out to HWT 19:00 - 20:30 1.50 CASE P SURF RIH from 800' to 4953' - fill pipe @ 3500' - No Problems hole in good shape 20:30 - 22:30 2.00 CASE P SURF CBU 2 X - GPM 550 - PP 3120 - RPM 100 - TQ 7K 22:30 - 00:00 1.50 CASE P SURF Pump out to 2800" - Full drlg rate 12/4/2003 00:00 - 01 :00 1.00 CASE P SURF Pump out from 2800' to HWT @ 800' - Full drlg rate - No problems 01 :00 - 03:00 2.00 CASE P SURF Change elevators to 5" - Stand back HWT - 6 1/4" Flex DC's - Lay down 8" BHA - MWD - Break bit - Lay down Motor 03:00 - 04:30 1.50 CASE P SURF Clear floor - Rig up casing tools to run 9 5/8" casing - PJSM on running casing 04:30 - 05:30 1.00 CASE P SURF Pick up shoe joints - make up - Check floats - Run 9 5/8" 47# L-80 BTC-M casing to 1519' - Roughneck running power tongs - Crossed threads - damaged both joints 05:30 - 06:30 1.00 CASE N HMAN SURF Lay down two damaged joints of casing - Replace damaged joints 06:30 - 09:00 2.50 CASE P SURF Con't running 9 5/8" 40# L-80 BTC-M casing from 1519' to 4910' - Total Joints ran 119 - Make up Hanger I Landing joint - Land casing @ 4945' (Shoe @ 4945' - Float Collar 4860') 09:00 - 09:30 0.50 CASE P SURF Lay down Franks fill up tool - Make up Schlumberger cementing head and cementing lines 09:30 - 12:00 2.50 CASE P SURF Circulate I Condition Mud - Hole - BPM 8.5 - PP start 450 psi - PP End 300 psi 12:00 - 12:30 0.50 CASE P SURF Con't circulating - PJSM with all personnel 12:30 - 14:30 2.00 CEMT P SURF Schlumberger Pump 10 bbls CW 100 water @ 3 bpm 290 psi- Test lines to 3500 psi - Pump 20 bbls CW 100 water @ 5 bpm 490 psi - Mix and pump 50 bbs Mud push spacer mixed at 10.2 ppg @ 5 bpm 450 psi (one gallon dye first 5 bbls spacer slurry) - Drop bottom plug last 5 bbls spacer pumped on the fly - Mix and pump 725 sx 'Arctic set Light' Yield 4.27 cflsx 551 bbls of slurry mixed at 10.7 ppg @ 7.2 bpm 775 psi - Mix and pump 225 sx Tail Class 'G' Yield 1.17 cflsx 46 bbls of slurry mixed at 15.8 ppg @ 5.5 bpm 950 psi - Kick out Top plug with 30 bbls of water thru tub - Give to rig for displacement 14:30 - 15:30 1.00 CEMT P SURF Displace cement with rig - Pump 334 bbls of mud @ 8.5 bpm start with 500 psi - End 1400 psi - Slow pump to 4 bpm 1100 psi last 12 bbls pumped - Bump plug with 3347 total stks pumped - Pressure up to 2000 psi - Hold for 15 mins - CIP @ 15:25 hrs - (After 50 bbls displacement - Cement to surface -Total of 287 bbls cement back to surface - Rig pump eft 95.6%) 15:30 - 16:30 1.00 CEMT P SURF Flush stack - Riser - Flow line - Lay down landing joint 16:30 - 17:30 1.00 CASE P SURF Nipple down Divertor System 17:30 - 18:00 0.50 CASE P SURF Nipple up FMC 12" M to M seal bottom X 11" 5K Flange top - FMC 11" x 11" 5K G5 Tubing head - Test to 1000 psi for 10 mins. 18:00 - 19:30 1.50 CASE P SURF Nipple up BOP's 19:30 - 20:30 1.00 CASE P SURF Rig up to test BOP's - Pick up test joint - Open annulus valve - Install test plug 20:30 - 00:00 3.50 CASE P SURF Test BOP's - Annular 250 low - 2500 high for 5 mins each test - Top I Bottom pipe rams - Choke manifold - Hyd kill/ Hyd Printed: 12/22/2003 9: 15: 12 AM ) ') BP Operations SlIl11l11aryR_port Page 3 of9 Legal Well Name: M PF-87 Common Well Name: M PF-87 Spud Date: 12/1/2003 Event Name: DRILL +COMPLETE Start: 11/30/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2003 Rig Name: DOYON 14 Rig Number: 14 From- To Höurs Task Code NPT · Phase 12/4/2003 20:30 - 00:00 3.50 CASE P SURF Choke valves - Manual Kill I Manual Choke valves - Upper I Lower IBOP - Floor Safety valves - 250 low 3500 high 5 mins each test - 12/5/2003 00:00 - 00:30 0.50 CASE P SURF Con't test BOP - Accumulator test - Blind Rams 250 low - 3500 high 5 mins each test - Jeff Jones with AOGCC waived the witness of the BOP test 00:30 - 01 :00 0.50 CASE P SURF Rig down testing equipment - Pull test plug - Install wear ring - Lay down test joint - Close annulus valve 01 :00 - 03:00 2.00 CASE P SURF Make up 8.5" BHA - Hughes 8.5" HCM605 PDC - Sperry Sun Motor set at 1.22 degree - MWD I GR I Res I PWD - RIH with 61/4" Flex DC's - 5" HWT - Shallow pulse test 03:00 - 04:00 1.00 CASE P SURF Con't RIH to 4762' - Filling DP every 25 stands 04:00 - 05:00 1.00 CASE P SURF Cut Drlg line - Service Top drive I Drawworks 05:00 - 06:00 1.00 CASE P SURF Rig up to test 9 5/8" casing to 2500 psi for 30 mins - Recorded on chart - Rig down test line - Blow down lines - Choke Manifold 06:00 - 07:00 1,00 DRILL P SURF Tag Cement 4830' - Drill cement I float equipment from 4830' to 4945' - Clean out rat hole from 4945' to 4953' - Drill 20' new hole from 4953' to 4973' 07:00 - 07:30 0.50 DRILL P SURF Displace hole with new 9 ppg mud 07:30 - 08:30 1.00 DRILL P SURF Preform FIT - rvD 4456' - 9 PPG - Pressure 800 psi = EMW 12.4 08:30 - 16:00 7.50 DRILL P INT1 Directional Drill from 4973' to 5906' 16:00 - 17:00 1.00 DRILL N DPRB INT1 Making connection @ 5902' - Partial pack-off - Circulate hole clean - GPM 500 - PP 2850 - TO 7K 17:00 - 19:30 2.50 DRILL P INT1 Directional Drill from 5902' to 6201' - WOB 17-20 - RPM 120- TO on 9K - off 7K - GPM 500 - PP on 3300 - off 3000 - PU 180 - SO 115 - ROT 140 - Swivel Packing leaking 19:30 - 22:00 2,50 DRILL N SFAL INT1 Pull into shoe @ 4845' - Tight hole from 5420' to 5092' - 50 to 75K overpulls 22:00 - 23:00 1.00 DRILL N SFAL INT1 Change out swivel packing on top drive - Test to 3800 psi - ok 23:00 - 23:30 0.50 DRILL N SFAL INT1 RIH from 4845' to 6100' - Wash from 6100' to 6201'- (precauctionary wash) 23:30 - 00:00 0.50 DRILL P INT1 Directional Drill from 6201' to 6244' - WOB 17-20K - RPM 120- TO on 1 OK - off 7.5K - GPM 500 - PP on 3450 - off 3200 12/6/2003 00:00 - 00:30 0.50 DRILL N MISC INT1 (Turbine down at Milne Pt.) - Switch from Hi-line power to Rig power 00:30 - 04:00 3.50 DRILL P INT1 Directional Drill from 6244' to 6575' - WOB 15K to 20K - RPM 120 - TO on 10K - off 8K - GPM 500 - PP on 3650 - off 3400- PU 190 - SO 120 - ROT 145 - ECD 10.7 04:00 - 04:30 0.50 DRILL P INT1 CBU - Clean hole - GPM 500 - PP 3400 - RPM 120 - TO 8K 04:30 - 00:00 19.50 DRILL P INT1 Directional Drill from 6575' to 8330' - WOB 15 - 25K - RPM 120 - TO on 9K - off 6K - GPM 490 - PP on 3600 psi - off 3300 - PU 180K - SO 137K - ROT 156K - ECD 10.6 12/7/2003 00:00 - 12:00 12.00 DRILL P INT1 Directional Drill from 8330' to 9093' - WOB 15 to 25K - RPM 120 - TO 11 K on - 8K off - GPM 495 - PP on 3900 - off 3600 - PU 177K - SO 126K - ROT 150K - ECD 10. 6 12:00 - 13:00 1.00 DRILL P INT1 Circulate - Co Man and Geologist conver with town - RPM 120 - TO 8K - GPM 495 - PP 3640 13:00 - 15:30 2.50 DRILL P INT1 Directional Drill from 9093' to 9268' - T.D. 8.5" hole 15:30 - 17:30 2.00 DRILL P INT1 CBU 3 X - GPM 495 - PP 3600 - RPM 120 - TO 8K - PU 177K- SO 125K - ROT 150K 17:30 - 00:00 6.50 DRILL P INT1 Pump out Drlg rate 495 GPM - PP 3400 psi - Tight hole - Printed: 12/22/2003 9: 15: 12 AM ) ') BP QperationsSum märyRepo.rt· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PF -87 MPF-87 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date From.;.To Hours Task COde NPT .. Phase 12/7/2003 17:30 - 00:00 6.50 DRILL P INT1 12/8/2003 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01 :00 0.50 DRILL P INT1 01 :00 - 01 :30 0.50 DRILL P INT1 01 :30 - 02:30 1,00 DRILL N RREP INT1 02:30 - 03:30 1.00 DRILL P INT1 03:30 - 05:30 2.00 DRILL N RREP INT1 05:30 - 06:00 0.50 DRILL N RREP INT1 06:00 - 07:00 1.00 DRILL P INT1 07:00 - 08:00 1.00 DRILL N DPRB INT1 08:00 - 09:00 1.00 DRILL N DPRB INT1 09:00 - 10:00 1.00 DRILL N DPRB INT1 10:00 - 11 :30 1.50 DRILL N DPRB INT1 11 :30 - 17:00 5.50 DRILL N DPRB INT1 17:00 - 18:00 1.00 DRILL N DPRB INT1 18:00 - 21 :30 3.50 DRILL N DPRB INT1 21 :30 - 22:00 22:00 - 00:00 0.50 DRILL N 2.00 DRILL N DPRB INT1 DPRB INT1 Start: 11/30/2003 Rig Release: 12/19/2003 Rig Number: 14 Spud Date: 12/1/2003 End: . Description· of Operaticms Packing off from 8592' to 8160' - Back ream @ 100 RPM - TO 10K - Reduced flow rate to 5 to 7 bpm - PP 1250 psi - To prevent packing off with higher GPM - Con't pumping out from 8160' to 5425' at 420 GPM - 2250 psi - Packing off @t 5412'- Back ream from 5415' to 5100 @ 100 rpm - TO 7K - 420 GPM - PP 2200 psi Pump and Back ream out from 5100 to 4818' - GPM 420- RPM 100 - TO 8K - PP 2200 Circulate bottoms up inside 9 5/8 casing- GPM 420 - RPM 80 - TO 6.5K - ICP 2150 - FCP 1950 - Lots of sand & silt coming over shaker - ECD 10.9 - Mud weight coming out 10.2+ - Circulate hole clean - Mud weight 9.8 - ECD 10.2 Blow down top drive - RIH from 4818' to 6002' - Glycol Drawworks cooling pump down POH to repair drawworks cooling pump - POH with out pump - Hole in good condition - start rig repair time at 0130 hrs Cut drlg line - Top drive service - Circulate and condition mud - one hour non rig repair Rebuild drawworks cooling pump RIH from 4849' to 6035' - off rig repair time at 0600 hrs RIH from 6035' to 7377' - Fill DP @ 7281' - tag cutting bed at 7377' Ream from 7377' to 7474' twice, work clean - 424 GPM - 100 RPM - RIH from 7474' to 7954' - taking wt 30k at 7,954'- Ream from 7954' to 8049' - GPM 424 - RPM 100 Circulate bottoms up, gas cut mud, Mud cut 9.6 ppg to 8.3 - GPM 424 - RPM 100 - PP 2500 - TO 10K Attempt to ream in hole from 8,049' pumping 420 gpm - Packing off - stalling top drive - Stand one stand back Circulate and work pipe 8,049 to 7,932' - Increase mud wt 9.6 to 10.0 ppg - GPM 424 - RPM 100 - PP 2500 - TO 11 K - shakers cover with fine shale and silt - lot of gas and oil in returns Make connection - Ream from 8,049' to 8,081' - Packing off - torquing up, slow going - Slow pump to 254 gpm - Work pipe, slower pump working better - ream from 8,049' to 8,140' - hole packing off, stalling top drive, appeared to be sidetracking welbore at 8,135' - RPM 100 - TO 10K - GPM 167 to 251 - PP 1300 -Increase mud wt 10.0 to 10.7 ppg as reaming - mud returns cut 10. 7ppg to 8.5 - 9.5 ppg - shaker not cleaning up, covered with crude oil, 4% crude oil in drilling mud. Packed off at 8,140' - work free. Stand back one stand - Circulate - work pipe from 8,049' to 7,932' while co Man convers with town - RPM 100 - TO 10K- GPM 351 - PP 2250 psi Continue work pipe 8,049 to 7,932' -Condition & Circulate mud - Mud weight 10.7 - (Gas cut on API scale 10.7 to 8.3 ppg - Pressured scale 10.7 to 10.1 ppg) -Increase mud wt 10.7 to 11.0 ppg - ECD 11.55 ppg - GPM 453 - PP 3410 psi - RPM 100 - TO 8K - Full returns - crude oil still in returns Flow check - 5 mins slight flow - 12 mins flow increasing Continue work pipe 8,049 to 7,932' - Increase mud wt. 11.0 to 11.5 ppg - GPM 453 - PP 3400 psi - RPM 100 - TO 8K - (Mud Printed: 12/22/2003 9: 15: 12 AM ') BP .Clperations Summå;ryReport Pagë50f 9 Legal Well Name: M PF-87 Common Well Name: MPF-87 Spud Date: 12/1/2003 Event Name: DRILL +COMPLETE Start: 11/30/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2003 Rig Name: DOYON 14 Rig Number: 14 ... Date Task CodØ ..NPT Description of Operations 12/8/2003 22:00 - 00:00 2.00 DRILL N DPRB INT1 returns gas I oil cut API scale 11.0 to 10.0 ppg - Pressured scale 11.0 to 10.8 ppg) - 4% Crude oil in drilling mud 12/9/2003 00:00 - 00:30 0.50 DRILL N DPRB INT1 Raising mud weight to 11.5 ppg - GPM 450 - PP 3200 - RPM 100 - TQ 8K - ECD 11.8 00:30 - 02:30 2,00 DRILL N DPRB INT1 Lost Returns @ 00:40 hrs - Mud weight in 11.5 ppg out 11.3 ppg - Circulating ECD 11.8 - Slow pump down to 7 bpm 1000 psi - Slow pump down to 3.5 bpm - pp 450 psi - Slow pump to 1.5 bpm - pp 210 psi - No returns - Fluid level dropping - Fill hole across top - losses 100 bph with filling across top and 1.5 bpm going down dp. Shut down pump - losses 40 bph filling across the top - Mixing mud - cutting mud weight from 11.5 ppg in pits back to 11.2+ ppg - Mixed LCM pill 35 bbls @ 20 ppb - loss rate 35 to 45 bph filling hole across the top 02:30 - 05:00 2.50 DRILL N DPRB INT1 POH to shoe from 8049' to 4885' @ controlled speed - Filling hole with trip tank - Avg hole fill 5.96 bbls per 5 stands 05:00 - 05:30 0.50 DRILL N DPRB INT1 Flow check well, hole taking 4 bbl per hr. 05:30 - 10:00 4.50 DRILL N DPRB INT1 Tripping out, hole swabbing, fill hole tru dp. 10:00 - 11 :30 1.50 DRILL N DPRB INT1 Standing back BHA, laying down MWD,Motor 11 :30 - 15:00 3.50 DRILL N DPRB INT1 Pick up Johnny Wacker, Tripping in with drill pipe to 8,120, no returns, hole taking mud, fill across top of hole 15:00 -16:00 1.00 DRILL N DPRB INT1 Spot open hole plug with Schlumberger, test lines to 4,000# pump 15 bbls water a head, 52 bbls cement class G mixed @ 15.8, 3 water behind, displace 5 bbls min. with 73 bbls mud 11.2 +#, with no returns 16:00 - 19:00 3.00 DRILL N DPRB INT1 Poh to csg shoe @ 4,945 hole not taking proper fill, wouldn't flow 19:00 - 19:30 0.50 DRILL N DPRB INT1 Mixed 25 bbls of 42# per bbls LCM pill, hopper wouldn't take any more 19:30 - 20:30 1.00 DRILL N DPRB INT1 Tripping in to 7,000, no returns 20:30 - 21 :00 0,50 DRILL N DPRB INT1 Spot 25 bbls LCM pill @ 7,000, 5 bbls min, 800 psi with app. 20% returns 21 :00 - 23:00 2.00 DRILL N DPRB INT1 POH to csg shoe @ 4,990 hole not proper fill, wouldn't flow 23:00 - 23:30 0.50 DRILL N DPRB INT1 Spot 25 bbls 45# per bbl, LCM pill, 5 bbls min, 600 psi, had 90% return when we started circ. and still had app 90% when we got pill spotted 23:30 - 00:00 0.50 DRILL N DPRB INT1 Trip out to 4,513 above LCM pill 12/1 012003 00:00 - 02:00 2.00 DRILL N DPRB INT1 Circ, @ 4513 circ. bottoms up with 5 bbls min 510 psi full returns lots of oil, little gas, mud cut to 9.0, Raised pump rate to 8 bbls min 1000 psi circ and level out mud wts to 11,0+ 02:00 - 03:00 1.00 DRILL N DPRB INT1 Tripping in to 5,850 good displacement tripping in 03:00 - 04:00 1.00 DRILL N DPRB INT1 Circ bottoms up @ 5850 with 6 bbls min. 730 psi, up to 7 bbls min. 940 psi, full returns, oil and gas cut mud @ bottoms up, level out mud wts to 11.0+ 04:00 - 05:00 1.00 DRILL N DPRB INT1 Tripping in to 7,000 good displacement tripping in 05:00 - 06:30 1.50 DRILL N DPRB INT1 Circ. bottoms up @ 7,000 with 5 bbls min. 06:30 - 07:30 1.00 DRILL N DPRB INT1 Wash 7,000 to 7,796 tag cement @ 7796 with 10,000 # with 5 bbls min 720 psi 07:30 - 08:00 0.50 DRILL N DPRB INT1 Circ and condition mud, flow rate decreasing, started losing mud 08:00 - 09:30 1.50 DRILL N DPRB INT1 Poh to 7280, attemt to eric, no returns 09:30 - 11 :30 2.00 DRILL N DPRB INT1 Poh to 4850, attempt to circ @ 7000 and 6810 no returns, attemp to circ @ 6030 30 % returns, pull to 4850, well breathing when pulling out flow back on both sides Printed: 12/22/2003 9: 15: 12 AM ) .J BP Operations.. Siunlm a ry..·.Re port Page 6 of9 Legal Well Name: MPF-87 Common Well Name: MPF-87 Event Name: DRILL +COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Dåte From ~ To HOurs Task Code NPT 12/1 0/2003 11 :30 - 13:30 2.00 DRILL N DPRB INT1 13:30 - 19:30 6.00 DRILL N DPRB INT1 19:30 - 20:30 1.00 DRILL N DPRB INT1 20:30 - 21 :00 0,50 DRILL N DPRB INT1 21 :00 - 22:30 1.50 DRILL N DPRB INT1 Start: 11/30/2003 Rig Release: 12/19/2003 Rig Number: 14 Spud Date: 12/1/2003 End: 22:30 - 23:15 0.75 DRILL N DPRB INT1 23:15 - 23:30 0.25 DRILL N DPRB INT1 23:30 - 00:00 0.50 DRILL N DPRB INT1 12/11/2003 00:00 - 00:30 0.50 DRILL N DPRB INT1 00:30 - 01 :30 1.00 DRILL N DPRB INT1 01 :30 - 02:00 0.50 DRILL N DPRB INT1 02:00 - 07:30 5.50 DRILL N DPRB INT1 07:30 - 08:30 1.00 DRILL N DPRB INT1 08:30 - 09:00 0.50 DRILL N DPRB INT1 09:00 - 09:30 0.50 DRILL N DPRB INT1 09:30 - 10:30 1.00 DRILL N DPRB INT1 10:30 - 15:00 4.50 DRILL N DPRB INT1 15:00 - 16:30 1.50 DRILL N DPRB INT1 16:30 - 21 :30 5.00 BOPSURN DPRB INT1 21 :30 - 22:00 0.50 DRILL N DPRB INT1 22:00 - 23:30 1.50 DRILL N DPRB INT1 23:30 - 00:00 0.50 DRILL N DPRB INT1 12/12/2003 00:00 - 00:30 0.50 DRILL N DPRB INT1 00:30 - 01 :00 0.50 DRILL N DPRB INT1 01 :00 - 05:00 4.00 DRILL N DPRB INT1 05:00 - 06:30 1.50 DRILL N DPRB INT1 06:30 - 08:00 1.50 DRILL N DPRB INT1 08:00 - 09:00 1.00 DRILL N DPRB INT1 09:00 - 11 :00 2.00 DRILL N DPRB INT1 11 :00 - 13:00 2.00 DRILL N DPRB INT1 13:00 - 00:00 11.00 DRILL P PROD1 . Pescriþtion ofOþeratiÒns Circ @ 4850 with 30% returns at start slowly improving to 100%, on first bottoms up shaker cover with silt and sand, mud cut 11.0 to 8.8, returns improved as shaker cleaned up Circ and maintain mud wt @ 11.0, mixing LCM pill and loading mud in vac truck for cement job displacement, full returns Trip in to 7,774, good displacement on trip in Spot 25 bbls of 43# LCM pill @7774, 4 bbls min 650 psi, full returns, pull out to 7,583 PJSM Spot cement plug w/ Schlumberger, pump 5 bbls water, test lines to 4,000psi, 10 bbls water- mix & pump on fly 250 sx Class 'G' wi .4% D167 + .3% D65 + .2% D46 + .045% B155- Yield 1.16 CFlsx 52 bbls slurry mixed @ 15.8, followed by 3 bbls water, dispace with 67 bbls 11.0 mud, full returns tru out job, bottom of plug 7583- Est top of plug at 6923' based on 9" hole size POH to 6,335 Circ drill pipe Vol. 50 spm 650 psi, full returns POH to 5854 Circ @ 5,854, PJSM wi Schlumberger Spot 33 bbls 11.0# Form-Plug with Schlumberger @ 5854, displace with 57 bbls 11.0 mud, full returns POH to 4,800 Circ 5 bbls min 475 psi, waiting on Form-Plug to set up, full returns Wash from 4,945 to 5,377 Circ bottoms up 127 gpm 380 psi, full returns Spot cement plug with Schlumberger, 5 bbls water,test lines to 4,000,13 bbls water, 43 bbls 250 sxs. Class G mixed @ 17# yield 1.0, 3 bbls water, displace with 43 bbls 11.0 mud, cement in place 0930 POH to 4,513 Circ and cut mud wt to 10.4 Poh with Johnny Wacker Test Bops and manifold with 250/3500 5 min. per test, Hydrill 250/2500 5 min. per test,install wear ring, the right to witness test was wavier by Chuck Scheve Pickup BHA, Bit MXC1 no jets, 12 HWDP,jars" 5 HWDP RIH to 4288 Slip and cut drill line and service top drive Finish Slip and cut drill line and service top drive Trip in to 4500 Washed 4500 to 4755, Drill cement 4,755 to 4,975 with 10/15 wt 100 rpms, 414 gals per min. 1200 psi (top of cement 4,755') hard cement 4860 to 4975, Circ and condition mud, cut mud wt to 9.6 Trip out to BHA Stand back BHA, clear floor Pick up BHA, Bit HCM605 wi 5x13,7" sperry drill with 1.22 bend,stab,float sub, 6 3/4 GRlRES/PWD, 6 3/4 DM,hang off sub,stab,3 flew DC stab, 12 GWP ,Jars,5 HWP Trip in to 4975 Sidetrack and Directional Drill 4975 to 5860 with 500 gals per min 2800 psi, 120 rpms ECD 10.6 ADT 2.66 AST 4.83 .,¡ / Printed: 12/22/2003 9:15:12 AM ) ) BP Þage 7 of .9 . · O:peratlons Summary Report Legal Well Name: M PF-87 Common Well Name: M PF-87 Spud Date: 12/1/2003 Event Name: DRILL +COMPLETE Start: 11/30/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2003 Rig Name: DOYON 14 Rig Number: 14 Date· Frorn- To· HOUrs Task Code NPT Phase 12/13/2003 00:00 - 05:00 5.00 DRILL P PROD1 Directional Drill 5860 to 6384 with 500 gals per min 2900 psi, 120 rpms, centrifuge down, running lots of water trying to keep wt. down.ECD 11.9 05:00 - 05:30 0.50 DRILL P PROD1 Circ due to high ECD, Ecd dropped to 10.5 05:30 - 06:30 1.00 DRILL P PROD1 Directional Drill 6384 to 6479 with 500 gals per min 2900 psi, 120 rpms, 06:30 - 07:00 0.50 DRILL P PROD1 Hole packed off on backream @ 6400', pipe rotating free, slowly stage pump up to drill rate, backream two times to clean up hole 07:00 - 12:30 5.50 DRILL P PROD1 Directional Drill 6479 to 7033' with 500 gals per min 3000 psi, 120 rpms, ECD 10.6 12:30 - 14:00 1.50 DRILL P PROD1 Circ, three bottoms up, 500 gals per min. 3000 psi, 120 rpms, ECD dropped to 10.2 14:00 - 16:00 2.00 DRILL P PROD1 Pump out of hole to CSG shoe @ 4945 with full drill rate, one tight spot @ 5425 worked twice, cleared up. 16:00 - 16:30 0.50 DRILL P PROD1 Service top drive 16:30 - 17:30 1.00 DRILL P PROD1 Trip to bottom, washed 90 ft to bottom 17:30 - 00:00 6.50 DRILL P PROD1 Directional Drill 7033' to 7632' with 500 gals per min 3000 psi, 120 rpms, ECD 10.3 AST 2, ART 8.43 12/14/2003 00:00 - 03:30 3.50 DRILL P PROD1 Directional Drill 7632' to 8015' with 500 gals per min 3000 psi, 120 rpms ECD 10.4 03:30 - 05:00 1.50 DRILL P PROD1 Circ. Two bottoms up with 120 rpm, 500 gals min. 3000 psi ECD 10.2 05:00 - 06:00 1,00 DRILL P PROD1 Pump out with full drilling rate to 6962 ft. 06:00 - 06:30 0.50 DRILL P PROD1 Trip to bottom, wash 90 ft. to bottom 06:30 - 00:00 17.50 DRILL P PROD1 Directional Drill 8015' to 9454' with 500 gals per min 3600 psi, 120 rpms ECD 10.3 Ast 5.67 Art 8.08 12/15/2003 00:00 - 03:30 3.50 DRILL P PROD1 Directional Drill 9454' to 9751' TD with 500 gals per min 3600 ........ psi, 120 rpms ECD 10.3 03:30 - 06:00 2.50 CASE P PROD1 Circ, three bottoms up with 120 rpms, 500 gpm 3600 psi ECD 10.0 06:00 - 12:00 6.00 CASE P PROD1 Pumping out to csg shoe @ 4945' with full drill rate, Pulling tight @ 5908 to 5748, worked thru , backed ream to 5173 with bit @ 7500 ft getting shale across shakers 12:00 - 12:30 0.50 CASE P PROD1 Circ, bottoms up @ csg shoe 500 gals min. 2300 psi 12:30 -14:00 1.50 CASE P PROD1 Slip and cut drilling line and service top drive 14:00 - 14:30 0.50 CASE P PROD1 Monitor well and put rig back on high line power, weather in Phase 3 for app. one hr. 14:30 - 16:00 1.50 CASE P PROD1 Trip to bottom, no problems 16:00 - 19:30 3.50 CASE N DPRB PROD1 Circ four bottoms up and raise mud wt to 9.8, got gas and oil breaking out in bell nipple and splinter shale on shaker with 1600 pump stks, mud cut to 8.6, total pump stks for bottoms up is 5,600 ECD 10.34 19:30 - 21 :00 1.50 CASE N DPRB PROD1 Pump out to 8000 ft with 450 gals min. no problems 21 :00 - 21 :30 0.50 CASE N DPRB PROD1 Trip to bottom 21 :30 - 00:00 2.50 CASE N DPRB PROD1 Circ, got gas breaking out in bell nipple with 4000 pump stks, mud cut to from 9.8 to 8.6, raise mud wt to 10.0+, ECD 10.5 with 450 gals per min. 3500 psi 12/16/2003 00:00 - 00:30 0.50 CASE N DPRB PROD1 Circ and finish increase mud wt to 10.0+ 450 gals min 3330 psi ECD 10.5 00:30 - 01 :30 1.00 CASE N DPRB PROD1 Pump out 10 stands to 8817 450 gals min 3050 psi 01 :30 - 02:00 0.50 CASE N DPRB PROD1 Trip to bottom 02:00 - 05:30 3.50 CASE N DPRB PROD1 Circ, bottoms up with 450 gpm 3300 psi, at 4,000 pump stks Printed: 12/22/2003 9: 15: 12 AM ) ) BP . . Operati.ons Summary Repo.rt .. PageS of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/16/2003 12/1 7/2003 12/18/2003 MPF-S7 MPF-S7 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 11/30/2003 Rig Release: 12/19/2003 Rig Number: 14 Spud Date: 12/1/2003 End: From -To . Hours Task·. Code ... NPT Phase· Descri ptiönof Operations . 02:00 - 05:30 3.50 CASE N DPRB PROD1 gas breaking out in bell nipple, cut mud wt. 8.9, lasts till we get bottoms up, ECD 10.5, Raising mud wt. to 10.2+ 05:30 - 06:30 1.00 CASE N DPRB PROD1 Pump out to 9100, flow check, slug pipe 06:30 - 08:00 1.50 CASE N DPRB PROD1 Trip out to 4885, hole took normal fill 08:00 - 09:00 1.00 CASE N DPRB PROD1 Monitor well, well flowing slightly 09:00 - 11 :00 2.00 CASE N DPRB PROD1 Trip to 9751, no problems 11 :00 - 14:00 3.00 CASE N DPRB PROD1 Circ, bottoms up with 350 gpm 2400 psi, at 2,400 pump stks gas breaking out in bell nipple, cut mud wt, 8.7, Raising mud wt. to 10.5+, ECD 10.9 14:00 - 15:00 1.00 CASE N DPRB PROD1 Pump out 5 stands, pull 5 stands, flow check, no flow 15:00 - 16:00 1.00 CASE N DPRB PROD1 Trip to bottom 9,751 16:00 - 19:30 3.50 CASE N DPRB PROD1 Circ, bottoms up with 350 gpm 2400 psi, at 5000 pump stks gas breaking out in bell nipple, cut mud wt. 8.9, Raising mud wt. to 10.7+, ECD 11.1, 250 gals min, 1300 psi 19:30 - 21 :00 1.50 CASE N PROD1 Pump out 7 stands to 9,000, trip back to bottom 21 :00 - 23:30 2.50 CASE N PROD1 Circ bottoms up with 250 gals min 1450 psi, bottoms up mud cut to 9.2 @ 5,000 pump stks no gas breaking out and boiling in drilling nipple, mud wt level off @ 10.7 ECD 11.16 23:30 - 00:00 0.50 CASE N PROD1 Pumping out to csg shoe with 250 gals min. 1450 psi tight spot @ 9556 and 9450 00:00 - 05:00 5.00 CASE N DPRB PROD1 Pumping out to csg shoe with 250 gals min, 1450 psi, monitor well 05:00 - 08:00 3.00 CASE P PROD1 Tripping out for csg 08:00 - 10:00 2,00 CASE P PROD1 Laying down BHA 10:00 - 12:00 2.00 CASE P PROD1 Pull wear ring, install test plug, change rams to 4 ,5 X 7" test door seals to 1500 psi 12:00 - 13:00 1.00 CASE P PROD1 PJSM and rig up to run 7" csg 13:00 - 17:30 4.50 CASE P PROD1 RIH with 7" 26# L-80 BTC csg to 3300' with good displacement, 3300' to 3700' loss displacement 17:30 - 18:30 1.00 CASE P PROD1 Circ. 1 bbl min stage up to 2 bbls min 400 psi, regain good returns, circ bottoms up 18:30 - 20:00 1.50 CASE P PROD1 RIH with 7" to 4945 @ 1.5 min. per jt. slowly loss displacement 20:00 - 20:30 0.50 CASE P PROD1 Attemp to circ. with 70% lost returns @ 1 bbl min, lost 30 bbls 20:30 - 00:00 3.50 CASE P PROD1 RIH with 7" csg to 8080' @ 1.5 min. per jt with no displacement, cut mud in pits to 10.2 00:00 - 02:30 2.50 CASE P PROD1 RIH with 7" csg to 9,741 pick up wt 285,000 slack off 160,000 Total jts run 236 shoe @9741, float 9657, landed on hanger with 160,000 02:30 - 03:00 0.50 CASE P PROD1 Rig down Franks tool, rig up cement head 03:00 - 04:30 1.50 CASE P PROD1 Attemp to circ with 1 bbls min up to 4 bbls min, with 10.2 mud approximate 1 % returns didn't improve, loss 300 bbls 10.2 mud attemp to recipocate pull up to 375,000# worked it for 30 min. didn't get any movement 04:30 - 06:30 2.00 CEMT P PROD1 Cement with Schlumberger, 10 bbls CW water,test lines to 3500 psi, 10 bbls water, 30 bbls of mud push mixed @ 11.7, drop bottom plug, 200 sxs 41 bbls Class G mixed @ 15.8, yeid 1.16, drop top plug, wash lines, displace with 8.5 sea water 370 bbls with no returns. Bump plug with 2500 psi, float held, 808 bbls of total mud losses during casing and cement job. 06:30 - 08:00 1.50 CEMT P PROD1 Slight flow from annulus, shut hydrill and monitor annulus pressure, no pressure increase 08:00 - 10:00 2.00 CEMT P PROD1 Flush kill line, and BOPS, lay down landing jt., change out bails and elevators Printed: 12/22/2003 9: 15: 12 AM J ') BP OperatiönsSUrnn1é11}' . Report. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Dåte 12/1 8/2003 12/19/2003 M PF-87 MPF-87 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 11/30/2003 Rig Release: 12/19/2003 Rig Number: 14 Spud Date: 12/1/2003 End: . From..; To Hours Task Code NPT 10:00 - 11 :00 1.00 RUNCOrvP COMP 11 :00 - 11 :30 0.50 RUNCOrvP COMP 11:30-21:00 9.50 RUNCOrvP COMP 21 :00 - 22:00 1.00 RUNCOrvP COMP 22:00 - 22:30 0.50 RUNCOrvP COMP 22:30 - 00:00 1.50 RUNCOrvP COMP 00:00 - 06:00 6.00 RUNCOrvP COMP 06:00 - 06:30 0,50 RUNCOrvP COMP 06:30 - 08:30 2.00 RUNCOrvP COMP 08:30 - 10:30 2.00 RUNCOrvP COMP 10:30 - 12:00 1.50 RUNCOrvP COMP 12:00 - 13:30 1.50 RUNCOrvP COMP 13:30 - 14:30 1.00 RUNCOrvP COMP 14:30 - 15:30 1.00 RUNCOrvP COMP 15:30 - 16:30 1.00 RUNCOrvP COMP 16:30 - 17:00 0.50 RUNCOrvP COMP Descri ptionof Oþeratiöhs Install 9 5/8 X 7" packoff, test to 5,000 psi Safety reflection with company rep. Lay down 4 drill pipe in mouse hole Rig up and test CSG to 4,500 psi for 30 min Rig up to run tubing, PJSM Picking up 4.5 12.6 L-80 TDS tubing with 7 X 4.5 Premier packer and Jewelery Running 4.5 12.6# L-80 tubing, total jts run 240 jts, WL guide 9320, Xn nipple 9307, Packer 9280, X nipple 9269, Sliding sleeve 9242, Glm 2510, PU wt 155 SO wt 110, block wt 50k Install TWC and test to 1000 psi Nipple down BOPS Nipple up Adaptor flange test to 5,000 psi, nipple up 4 1/85,000 Tree test cavity to 4,000 psi Drop ball and rod, rig up circ lines and test Equip. Set packer with 2500 psi, Test Tubing to 4,000 psi for 30 min., Test annulus to 4500 psi for 30 min., shear dck valve with 2500 psi Freeze protect tubing and 7" with 72 bbls diesel freeze 9 5/8 annulus with 59 bbls diesel Safety reflection meeting with crews and let diesel U-tube to tubing Install BPV and test to 1000 psi Secure well and pump out cellar, Rig release for rig move @ 1700 hrs 12/19/2003 Printed: 12/22/2003 9: 15: 12 AM -) ') Well: Field: API: Permit: MPF-87A Milne Point Unit I Kuparuk River Sands 50-029-23184-01-00 203-213 Accept: Spud: Release: Rig: 12/09/03 12/12/03 12/19/03 Doyon 14 POST-RIG WORK 01/06/04 PULLED BPV, PULL BALL & ROD, PULL RHC BODY, PULL SHEAR VALVE, SET DGLV 01/08/04 ULTRASONIC IMAGER LOG (USIT), TOOL = ECRD HEADfTCC-BF/CAL Y/SGT-L/CENTRALlZER/2 KNUCKLES/USIT WITH AN IIAII SUB = 42.6 FT X 3.5611 MAX 00. LOGGED PRIMARY DEPTH CONTROL FROM SURFACE. SET DOWN AT 9648 FT MD. 01/27/04 /....' ..- PERFORATED 9515-9525, 9485-9495 AND 9467-9477' WI 3.38" HSD 12-SPF GUNS LOADED WI PF3412 BIG-HOLE CHARGES. TAGGED TO AT 96451 MD, CORRELATED DEPTHS TO SWS USIT-... PRIMARY DEPTH CONTROL LOG DATED 8-JAN-2004. 01/30/04 FRAC1D A SANDS PERFS 9467'-9525' WI 227K# CARBOLlTE USING YF-130LG SYSTEM. PLACED 225K# BEHIND PIPE, UNDER DISPLACE BY 7 BBLS, LEFT 2050# IN CSG. EST. TOS= 93801 MD. MAX TREAT= 4230 PSI, AVG TREAT=3400 PSI. LOAD TO RECOVER-1310 BBLS, ALL CUPS AND ELEMENTS FROM ISOLATION TOOL RECOVERED. 01/31/04 TAGGED TO @ 9501'WLM (95111 CORRECTED ELMO), APPROXIMATELY 141 OF BOTTOM PERFS COVERED. PUMPED 5BBLS NEAT, AND 35BBLS METH DOWN TBG TO FLUSH ICE ENCOUNTERED WHILE RUNNING SHIFTING TOOL. SHIFTED SSD OPEN @ 9243'MD, AND SET 13-A JET PUMP (SER# BP-1065). 02/10/04 PRESSURE TEST POWER FLUID LINE AND PRODUCTION LINE THEN TEST FLOW BACK LINE FOR APC TEST UNIT ALL TO 3500PSI. 02/14/04 HEAT & PUMP HOT PRODUCED WATER DOWN IA TO WARM WELL FOR FLOW BACK UNIT.(POST FRAC JOB).INITIAL TIIIO = 0/300/100. PUMPED 133 BBLS OF HOT SOURCE WATER & 11 BBLS 60/40 MIX METH DOWN IA FINAL TIIIO = 471/1100/400. OFF LOAD 25 BBLS 60/40 METH TO FLOW BACK UNIT. ) Tree: 41/16" Cameron Wellhead: FMC 11" gen 5 casing hanger. FMC 11" x 4.5" gen 5 tubing hanger. 4.5" BP\I. TC-II Landing Threads Surface casing 20",94# H-80 @Ð. 9-5/8" 40#, L-80, BTC 14945' I J 4.5", 12.6 ppf, L-80 mixed thread Tbg. (cap. = 0.0152 bpf, drift = 3.833") 7" 26#, L-80, BTC Casing (drift ID = 6.151, cap.= .0383 bpf cap w/4 1/2" tbg = .0186) II -not' ~v\~1 ~ l~ro. YYì IJ (j . Perforation Summary USIT Cement bond log dated 1/8/04 Size SPF Interval (TVO) A Sands 33/8" 12 9467' - 9477' 7151' - 7161' 33/8" 12 9485' - 9495' 7169' - 7178' 3 3/8" 12 9515' - 9525' 7198' - 7208' MPF-87+\ n ~............................................... ~ ~ DATE 12/20/03 REV. BY Lee Hulme COMMENTS Drilled & Completed by Doyon 14 ) Orig. DB Elev. = 44.10' Orig. RT to LOS = 30.01' Cameo 4.5" x 1" wi BK latch sidepocket KGB-2 GLM I 2511' I KOP 8 degrees@1232' Max. hole angle = 63 deg @6220' Hole angle thru' perfs = 10° 4S HES "XD" Dura sliding sleeve 3.813" ID ( Opens down) 19243' I 4.5" HES X-Nipple ( 3.813" ) I 9269' I 7" x 4.5" Baker Premier Packer 9280' 4.5" HES XN-Nipple 3,813" Pkg. (No-Go 3.725" id ) 4.5" WLEG - bottom 9308' 9320' ELMD 1/10/04 9324' ~ 7" Halliburton Float Collar 7" Halliburton float shoe 9656' 9740' MILNE POINT UNIT WELL No.: MPF-87 A API : 50-O?9-?3184-O1-00 BP EXPLORATION (AK) Legal Name: Common Name: Test Date 12/5/2003 FIT MPF-87 MPF-87 Test Type Test Depth (TMD) 4,973.0 (ft) Test Depth (TVD) 4,456.0 (ft) AMW 9.00 (ppg) Surface Pressure Leak Off Pressure (BHP) 800 (psi) 2,883 (psi) EMW 12.46 (ppg) ---- .~ Printed: 12/2212003 9:15:04 AM ) AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-87 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 4,877.25' MD Window / Kickoff Survey: 4,955.00' MD (if applicable) Projected Survey: 9,751.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) a03-.d '3 31-Dec-03 RECEIVED JAN 1J 2004 AlaakaOll&GasQIIs.~ AncfIori8a D·.,. .. iN.'~¡ .r as.. . ~ j .: . ~ ... ....." 1 :i t Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-87 A Job No. AKZZ0002798647, Surveyed: 15 December, 2003 Survey Report 30 December, 2003 Your Ref: API 500292318401 Surface Coordinates: 6035564.51 N, 541638.76 E (70030' 29.0992" N, 149039'33.5402" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1035564.51 N, 41638.76 E (Grid) Surface Coordinates relative to Structure Reference: 5550.86 N, 9855.59 E (True) Kelly Bushing Elevation: 45.05ft above Mean Sea Level Kelly Bushing Elevation: 45.05ft above Project V Reference Kelly Bushing Elevation: 45.05ft above Structure Reference 5~'-''-'Y-5U'" t:fFHLL.t NGSER VI c: e s A Halliburton Company E -- c~ Survey Ref: svy1311 Halliburlon Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A Your Ref: API 500292318401 Job No. AKZZ0002798647, Surveyed: 15 December, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4877.25 34.560 324.220 4355.86 4400.91 1115.30 N 1226.91 W 6036672.92 N 540405.61 E 1649.24 Tie On Point - 4955.00 34.310 325.130 4419.98 4465.03 - 1151.17 N 1252.34 W 6036708.64 N 540379.99 E 0.736 1692.92 Window Point 4975.42 33.790 325.820 4436.90 4481.95 1160.59 N 1258.82 W 6036718.02 N 540373.46 E 3.172 1704.26 5072.16 36.090 319.540 4516.23 4561.28 1204.54 N 1292.43 W 6036761.79 N 540339.60 E 4.411 1759.43 5166.22 40.580 315.950 4590.00 4635.05 1247.64 N 1331.71 W 6036804.66 N 540300.08 E 5.327 1817.74 --- 5261.63 44.270 315.350 4660.41 4705.46 1293.65 N 1376.70 W 6036850.42 N 540254.83 E 3.891 1882.03 5357.91 47.850 318.440 4727.22 4772.27 1344.28 N 1424.02 W 6036900.79 N 540207.23 E 4.377 1951.31 5453.92 51.730 320.290 4789.20 4834.25 1399.93 N 1471.73 W 6036956.17 N 540159.21 E 4.301 2024.60 5550.29 55.610 320.850 4846.28 4891.33 1459.89 N 1521.02 W 6037015.85 N 540109.58 E 4.053 2102.15 5646.48 59.920 322.840 4897.58 4942.63 1523.87 N 1571.24 W 6037079.55 N 540059.00 E 4.810 2183.32 5742.29 61.010 323.910 4944.81 4989.86 1590.77 N 1620.97 W 6037146.17 N 540008.90 E 1.496 2266.34 5838.19 60.290 322.950 4991.81 5036.86 1657.91 N 1670.77 W 6037213.03 N 539958.72 E 1.151 2349.58 5933.40 61.690 323.100 5037.98 5083.03 1724.43 N 1720.85 W 6037279.26 N 539908.27 E 1 .477 2432.54 6030.04 62.680 324.390 5083.08 5128.13 1793.35 N 1771.39W 6037347.90 N 539857.35 E 1.563 2517.61 6124.96 62.180 324.350 5127.01 5172.06 1861.74 N 1820.41 W 6037416.02 N 539807.95 E 0.528 2601.26 6219.60 63.370 323.830 5170.31 5215.36 1929.90 N 1869.77 W 6037483.90 N 539758.21 E 1.349 2684.97 6315.17 62.820 324.300 5213.55 5258.60 1998.90 N 1919.78 W 6037552.62 N 539707.80 E 0.724 2769.75 6413.13 62.280 323.310 5258.71 5303.76 2069.06 N 1971.11 W 6037622.49 N 539656.08 E 1.053 2856.26 6509.19 61.560 323.960 5303.93 5348.98 2137.30 N 2021.37 W 6037690.45 N 539605.44 E 0.958 2940.63 6605.24 62.530 321.950 5348.96 5394.01 2205.01 N 2072.48 W 6037757.87 N 539553.95 E 2.106 3025.17 6699.84 62.810 322.050 5392.39 5437.44 2271.24 N 2124.22 W 6037823.80 N 539501.84 E 0.311 3109.03 6796.50 62.180 321.940 5437.03 5482.08 2338.79 N 2177.01 W 6037891.06 N 539448.67 E 0.660 3194.57 6892.02 61.570 321.590 5482.06 5527.11 2404.96 N 2229.15 W 6037956.94 N 539396.17 E 0.716 3278.65 .~ 6988.66 63.020 320.080 5526.99 5572.04 2471.29 N 2283.18 W 6038022.96 N 539341.76 E 2.041 3364.11 7084.98 63.210 320.340 5570.54 5615.59 2537.30 N 2338.16 W 6038088.67 N 539286.41 E 0.311 3449.97 7179.74 62.410 319.990 5613.84 5658.89 2602.03 N 2392.16 W 6038153.09 N 539232.06 E 0.906 3534.21 7275.52 61.570 320.140 5658.82 5703.87 2666.86 N 2446.44 W 6038217.62 N 539177.41 E 0.888 3618.72 7372.36 63.180 319.080 5703.73 5748.78 2732.21 N 2502.04 W 6038282.65 N 539121.45 E 1.925 3704.49 7468.41 62.660 319.700 5747.45 5792.50 2797.13 N 2557.70 W 6038347.26 N 539065.42 E 0.790 3789.99 7564.51 61.900 319.100 5792.15 5837.20 2861.72 N 2613.06 W 6038411.54 N 539009.70 E 0.965 3875.04 7660.32 62.050 319.360 5837.17 5882.22 2925.77 N 2668.29 W 6038475.28 N 538954.11 E 0.286 3959.60 7756.38 61.400 318.940 5882.67 5927.72 2989.77 N 2723.62 W 6038538.96 N 538898.42 E 0.779 4044.19 7852.58 62.060 320.680 5928.24 5973.29 3054.49 N 2778.29 W 6038603.38 N 538843.39 E 1.734 4128.88 7947.81 61.480 321.110 5973.28 6018.33 3119.59 N 2831.22 W 6038668.19 N 538790.10 E 0.727 4212.68 8044.06 60.700 321 .1 00 6019.81 6064.86 3185.17 N 2884.12 W 6038733.46 N 538736.83 E 0.810 4296.83 30 December, 2003 - 14:12 Page 20f4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A Your Ref: API 500292318401 Job No. AKZZ0002798647, Surveyed: 15 December, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8140.38 59.890 320.850 6067.54 6112.59 3250.16 N 2936.80 W 6038798.16 N 538683.79 E 0.871 4380.39 8236.04 56.780 321.260 6117.75 6162.80 3313.48 N 2987.97 W 6038861.19 N 538632.26 E 3.271 4461.70 8332.25 52.950 321.810 6173.11 6218.16 3375.06 N 3036.91 W 6038922.50 N 538582.98 E 4.008 4540.23 8428.26 49.150 321.740 6233.46 6278.51 3433.71 N 3083.10 W 6038980.89 N 538536.46 E 3.958 4614.74 8523.37 45.670 322.160 6297.81 6342.86 3488.84 N 3126.26 W 6039035.77 N 538493.00 E 3.673 4684.60 --- 8619.65 42.810 320.480 6366.79 6411.84 3541.28 N 3168.21 W 6039087.98 N 538450.75 E 3.210 4751.66 8715.60 40.370 318.680 6438.55 6483.60 3589.78 N 3209.48 W 6039136.24 N 538409.21 E 2.831 4815.32 8812.07 38.050 318.660 6513.29 6558.34 3635.57 N 3249.75 W 6039181.81 N 538368.68 E 2.405 4876.30 8908.47 34.930 320.280 6590.78 6635.83 3679.12 N 3287.02 W 6039225.14 N 538331.17 E 3.387 4933.60 9003.54 29.240 322.760 6671.30 6716.35 3718.57 N 3318.49 W 6039264.42 N 538299.47 E 6.142 4983.99 9099.94 23.850 322.090 6757.51 6802.56 3752.72 N 3344.74 W 6039298.42 N 538273.04 E 5.600 5026.93 9195.96 19.610 319.270 6846.69 6891.74 3780.25 N 3367.19 W 6039325.83 N 538250.44 E 4.546 5062.43 9291.98 17.540 320.720 6937.70 6982.75 3803.67 N 3386.86 W 6039349.13 N 538230.63 E 2.209 5093.00 9386.57 15.560 319.230 7028.37 7073.42 3824.31 N 3404.17 W 6039369.68 N 538213.20 E 2.141 5119.92 9482.10 13.310 318.330 7120.88 7165.93 3842.23 N 3419.85 W 6039387.51 N 538197.42 E 2.367 5143.73 9577.72 10.140 322.270 7214.49 7259.54 3857.11 N 3432.33 W 6039402.32 N 538184.87 E 3.417 5163.14 9673.99 8.120 321.350 7309.54 7354.59 3869.13 N 3441.76 W 6039414.28 N 538175.37 E 2.104 5178.38 9684.28 7.930 320.860 7319.73 7364.78 3870.25 N 3442.66 W 6039415.40 N 538174.46 E 1.962 5179.82 &- 9751.00 7.930 320.860 7385.81 7430.86- 3877.38 N 3448.47 W 6039422.50 N 538168.61 E 0.000 5189.01 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-87. Northings and Eastings are relative to MPF-87. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. '- The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from MPF-87 and calculated along an Azimuth of 318.190° (True). Magnetic Declination at Surface is 25.058° (29-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 9751.00ft., The Bottom Hole Displacement is 5189.03ft., in the Direction of 318.351 ° (True). 30 December, 2003 - 14:12 Page 3 of 4 DrillQuest 3.03.05.005 Milne Point Unit Comments Measured Depth (ft) 4877.25 4955.00 9751.00 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A Your Ref: AP/500292318401 Job No. AKZZ0002798647, Surveyed: 15 December, 2003 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4400.91 4465.03 7430.86 Comment 1115.30 N 1151.17 N 3877.38 N Tie On Point Window Point Projected Survey 1226.91 W 1252.34 W 3448.47 W -- Survey tool program for MPF-87 A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 914.00 0.00 913.95 30 December, 2003 -14:12 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 914.00 9751.00 913.95 Tolerable Gyro (MPF-87) 7430.86 AK-6 BP _IFR-AK (MPF-87) --- Page 4 of4 DrillQuest 3.03.05.005 ) ') ~03 --~ )8 31-Dec-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-87A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 4,877.25' MD Window / Kickoff Survey: 4,955.00' MD (if applicable) Projected Survey: 9,751.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 ~~ 2004 AlalkaOil & Gas rAH1s.CommiIion ~ Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPF MPF-87 A MWD --- Job No. AKMW0002798647, Surveyed: 15 December, 2003 Survey Report 30 December, 2003 Your Ref: API 500292318401 Surface Coordinates: 6035564.51 N, 541638.76 E (70030' 29.0992" N, 149039'33.5402" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~. Surface Coordinates relative to Project H Reference: 1035564.51 N, 41638.76 E (Grid) Surface Coordinates relative to Structure Reference: 5550.86 N, 9855.59 E (True) Kelly Bushing Elevation: 45.05ft above Mean Sea Level Kelly Bushing Elevation: 45.05ft above Project V Reference Kelly Bushing Elevation: 45.05ft above Structure Reference =r'-=-r'r-aY-SUf1 DFULCfN-G ---seAVfe: es A Halliburton Company Survey Ref: svy1323 Halliburlon Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A MWD Your Ref: API 500292318401 Job No. AKMW0002798647, Surveyed: 15 December, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4877.25 34.560 324.800 4355.86 4400.91 1120.29 N 1220.56 W 6036677.94 N 540411.94 E 1648.72 Tie On Point 4955.00 34.310 325.130 4419.99 4465.04 1156.29 N 1245.80 W 6036713.80 N 540386.50 E 0.401 1692.38 Window Point 4975.42 33.790 325.950 4436.90 4481.95 1165.71 N 1252.27 W 6036723.19 N 540379.97 E 3.397 1703.72 5072.16 36.090 320.210 4516.22 4561.27 1209.91 N 1285.58 W 6036767.20 N 540346.42 E 4.145 1758.87 5166.22 40.580 316.160 4590.00 4635.05 1253.30 N 1324.53 W 6036810.36 N 540307.23 E 5.468 1817.17 ----- 5261.63 44.270 315.880 4660.41 4705.46 1299.60 N 1369.22 W 6036856.42 N 540262.28 E 3.873 1881.48 5357.91 47.850 318.920 4727.22 4772.27 1350.65 N 1416.09 W 6036907.20 N 540215.12 E 4.358 1950.77 5453.92 51.730 320.530 4789.19 4834.24 1406.60 N 1463.45 W 6036962.88 N 540167.45 E 4.239 2024.05 5550.29 55.610 321 .430 4846.28 4891.33 1466.91 N 1512.31 W 6037022.92 N 540118.25 E 4.096 2101.58 5646.48 59.920 324.220 4897.58 4942.63 1531 .75 N 1561.42 W 6037087.48 N 540068.78 E 5.108 2182.64 5742.29 61.010 325.310 4944.81 4989.86 1599.83 N 1609.51 W 6037155.30 N 540020.31 E 1.508 2265.45 5838.19 60.290 325.110 4991.81 5036.86 1668.48 N 1657.20 W 6037223.68 N 539972.23 E 0.772 2348.41 5933.40 61.690 323.580 5037.99 5083.04 1736.13 N 1705.74 W 6037291.05 N 539923.32 E 2.034 2431.19 6030.04 62.680 324.960 5083.08 5128.13 1805.51 N 1755.64 W 6037360.15 N 539873.02 E 1.626 2516.18 6124.96 62.180 324.210 5127.01 5172.06 1874.09 N 1804.40 W 6037428.45 N 539823.88 E 0.876 2599.80 6219.60 63.370 323.300 5170.31 5215.36 1941.95 N 1854.16W 6037496.04 N 539773.74 E 1.521 2683.55 6315.17 62.820 323.280 5213.56 5258.61 2010.28 N 1905.10 W 6037564.08 N 539722.42 E 0.576 2768.44 6413.13 62.280 324.010 5258.71 5303.76 2080.28 N 1956.64 W 6037633.79 N 539670.49 E 0.861 2854.98 6509.19 61.560 323.820 5303.93 5348.98 2148.78 N 2006.55 W 6037702.01 N 539620.19 E 0.770 2939.31 6605.24 62.530 324.050 5348.96 5394.01 2217.36 N 2056.50 W 6037770.31 N 539569.86 E 1.032 3023.72 6699.84 62.810 324.070 5392.39 5437.44 2285.40 N 2105.83 W 6037838.07 N 539520.16 E 0.297 3107.32 6796.50 62.180 323.210 5437.03 5482.08 2354.44 N 2156.65 W 6037906.83 N 539468.94 E 1.023 3192.67 6892.02 61.570 322.380 5482.06 5527.11 2421.54 N 2207.59 W 6037973.64 N 539417.63 E 0.998 3276.63 '-- 6988.66 63.020 319.990 5526.99 5572.04 2488.19 N 2261.22 W 6038039.99 N 539363.63 E 2.654 3362.07 7084.98 63.210 320.470 5570.55 5615.60 2554.22 N 2316.18 W 6038105.71 N 539308.30 E 0.486 3447.92 7179.74 62.410 320.130 5613.85 5658.90 2619.07 N 2370.02 W 6038170.26 N 539254.10 E 0.903 3532.15 7275.52 61.570 320.520 5658.83 5703.88 2684.16 N 2424.00 W 6038235.04 N 539199.75 E 0.948 3616.65 7372.36 63.180 320.310 5703.73 5748.78 2750.28 N 2478.68 W 6038300.85 N 539144.71 E 1.674 3702.39 7468.41 62.660 320.550 5747.45 5792.50 2816.20 N 2533.15 W 6038366.47 N 539089.86 E 0.585 3787.84 7564.51 61.900 319.770 5792.15 5837.20 2881.52 N 2587.65 W 6038431 .48 N 539035.00 E 1.068 3872.86 7660.32 62.050 320.590 5837.17 5882.22 2946.48 N 2641.81 W 6038496.13 N 538980.48 E 0.772 3957.38 7756.38 61.400 320.530 5882.68 5927.73 3011.81 N 2695.55 W 6038561.17 N 538926.37 E 0.679 4041.91 7852.58 62.060 321.200 5928.24 5973.29 3077.53 N 2749.03 W 6038626.58 N 538872.53 E 0.920 4126.54 7947.81 61.480 320.670 5973.28 6018.33 3142.68 N 2801.90 W 6038691.43 N 538819.29 E 0.782 4210.35 8044.06 60.700 319.190 6019.82 6064.87 3207.15 N 2856.13 W 6038755.60 N 538764.70 E 1.571 4294.56 30 December, 2003 - 14:17 Page 2 of4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A MWD Your Ref: AP/500292318401 Job No. AKMW0002798647, Surveyed: 15 December, 2003 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8140.38 59.890 319.650 6067.55 6112.60 3270.69 N 2910.56 W 6038818.84 N 538709.92 E 0.938 4378.20 8236.04 56.780 321.680 6117.76 6162.81 3333.64 N 2962.17 W 6038881 .49 N 538657.95 E 3.719 4459.53 8332.25 52.950 322.170 6173.12 6218.17 3395.56 N 3010.69 W 6038943.14 N 538609.08 E 4.003 4538.03 8428.26 49.150 323.010 6233.47 6278.52 3454.85 N 3056.05 W 6039002.17 N 538563.39 E 4.016 4612.46 8523.37 45.670 322.990 6297.82 6342.87 3510.76 N 3098.19 W 6039057.85 N 538520.94 E 3.659 4682.22 --- 8619.65 42.810 320.990 6366.79 6411.84 3563.69 N 3139.52 W 6039110.55 N 538479.32 E 3.305 4749.23 8715.60 40.370 318.610 6438.56 6483.61 3612.35 N 3180.59 W 6039158.97 N 538437.97 E 3.029 4812.88 8812.07 38.050 319.270 6513.30 6558.35 3658.32 N 3220.66 W 6039204.72 N 538397.65 E 2.443 4873.86 8908.47 34.930 320.530 6590.79 6635.84 3702.15 N 3257.59 W 6039248.34 N 538360.47 E 3.328 4931.15 9003.54 29.240 323.070 6671.31 6716.36 3741.76 N 3288.87 W 6039287.77 N 538328.97 E 6.150 4981.52 9099.94 23.850 322.790 6757.52 6802.57 3776.13 N 3314.82 W 6039322.00 N 538302.82 E 5.593 5024.44 9195.96 19.610 319.850 6846.70 6891.75 3803.92 N 3336.96 W 6039349.66 N 538280.53 E 4.558 5059.91 9291.98 17.540 320.990 6937.71 6982.76 3827.48 N 3356.46 W 6039373.11 N 538260.90 E 2.189 5090.48 9386.57 15.560 319.320 7028.38 7073.43 3848.18 N 3373.71 W 6039393.72 N 538243.54 E 2.153 5117.40 9482.10 13.310 319.880 7120.89 7165.94 3866.30 N 3389.15 W 6039411.76 N 538228.00 E 2.360 5141.20 9577.72 10.140 321.890 7214.50 7259.55 3881.35 N 3401.44 W 6039426.73 N 538215.62 E 3.342 5160.61 9673.99 8.120 322.030 7309.55 7354.60 3893.38 N 3410.85 W 6039438.71 N 538206.14 E 2.098 5175.85 9684.28 7.930 322.020 7319.73 7364.78 3894.51 N 3411.74 W 6039439.83 N 538205.25 E 1.847 5177.29 9751.00 7.930 322.020 7385.82 7430.87 3901.76 N 3417.40 W 6039447.06 N 538199.54 E 0.000 5186.47 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-87. Northings and Eastings are relative to MPF-87. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ~ The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from MPF-87 and calculated along an Azimuth of 318.190° (True). Magnetic Declination at Surface is 25.057° (29-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 9751.00ft., The Bottom Hole Displacement is 5186.75ft., in the Direction of 318.786° (True). 30 December, 2003 - 14:17 Page 3 of4 DrillQuest 3.03.05.005 Milne Point Unit Comments Measured Depth (ft) 4877.25 4955.00 9751.00 Halliburton Sperry-Sun Survey Report for Milne Point MPF - MPF-87 A MWD Your Ref: API 500292318401 Job No. AKMW0002798647, Surveyed: 15 December, 2003 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4400.91 4465.04 7430.87 Comment 1120.29 N 1156.29 N 3901.76 N 1220.56 W 1245.80 W 3417.40 W Tie On Point Window Point Projected Survey ~ Survey tool program for MPF-87 A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 914.00 0.00 913.95 30 December, 2003 - 14:17 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 914.00 9751.00 913.95 Tolerable Gyro (MPF-87 MWD) 7430.87 MWD Magnetic (MPF-87 MWD) '- Page 40f4 DrillQuest 3.03.05.005 \) ) FRANK H. MURKOWSKI, GOVERNOR A.1/A.~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 P at Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field MPF-87 A BP Exploration (Alaska), Inc. Permit No: 203-213 Surface Location: 2114' NSL, 2923' WEL, Sec. 06, T13N, R10E, UM Bottomhole Location: 4551' SNL, 1224' WEL, Sec.36, T14N, R09E, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does nbt exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations unt il a 11 0 ther required permits a nd approvals ha ve been is sued. In addition, t he Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in· accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Si~ ,/\._ c-----?v>-~JJ----- Sarah Palin Chair - BY ORDER OF THE COMMISSION DATED thisÆ day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 4ld-® STATE OF ALASKA ALASKA l. ) AND GAS CONSERVATION COI\ )SSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class o Exploratory o Stratigraphic Test 0 Service 5. Bond: iii Blanket D Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 9734' .' TVD 7407'; 7. Property Designation: ADL 355018 I z,ççt.-.t:'J4/) 8. Land Use Permit: 19. PRESENT WELL CC>.NDITIONSUMtv1ARY .(Tobecòmpleted forRedriltANDRe~entryOperatioQs) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): 9268' 7162' NIA 9268' 7162' Casing Length Size Cement Volume Structural Conductor Surface Intermediate Production Liner o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2114' NSL, 2923' WEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 4571' SNL, 1208' WEL, SEC. 36, T14N, R09E, UM Total Depth: 4551' SNL, 1224' WEL, SEC. 36, T14N, R09E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-541639 .." y-6035565, Zone-ASP4' 16. Deviated Wells: Kickoff Depth 18.·.. Casingpr,ogram Size Casing 7" Hole 8-1/2" J 1100 ft Maximum Hole Angle SpeCifications' Grade Coupling L-80 BTC-M Weight 26# 112' 4910' 20" 9-5/8" Perforation Depth MD (ft): N/A III Development Oil D~ultiple Zone o Development Gas æ Single Zon~þ 11. Well Name and Number: MPF-87 A 12. Field I Pool(s): Milne Point Unit I Kuparuk River Sands ./ 9. Acres in Property: 2560 13. Approximate Spud Date: 12/10103 .- 14. Distance to Nearest Property: 8700' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): ~~n~~~. feet 1250' away from MPF·13 & MPF-25 17. Anticipated pressure (see 20 AAC 25.035) ,/ Max. Downhole Pressure: 3078" psig. Max. Surface Pressure: 2369 psig SettingDepth .. ... .......,...' ,·Quantity of Cement rop ........ .... ....." . ....... .". . Bottom . '. . (c.f.or.sacks) Length MD TVD MD TVD (including stage data) 9734' Surface Surface 9734' 7407' 200 sx Class 'G' 61 MD Junk (measured): NIA TVD 260 sx Arctic Set (Approx.) 725sx Class 'L', 225 sx Class 'G' 112' 4945' 112' 4463' Perforation Depth TVD (ft): NIA 20. Attachments 181 Filing Fee D BOP Sketch iii Drilling Program D Time vs Depth Plot 0 Shallow Hazard Analysis D Property Plat D Diverter Sketch D Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Contact Walter Quay, 564-4178 Printed Name Pat Archey Signature J¡rr~/L(,.I" L / / Permit To Drill API Number: Number: ;zo3- 2/3 50-029-23184-01-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: ~50(J\,s\ \S\J?~cs-\ Origina' Sign~ By Sa1'8h Palm Approved Bv: Form 10-401 Revised 3/2003 Title Senior Drilling Engineer Prepared By Name/Number: Phone 564-5803 Date / (/1# j,; S Sondra Stewman, 564-4750 Commission Use Only ." .._.. 6:~~it A!~Jj 0 !ci ~1;<ß.~tj~= S!Ys ¥NO Mud Log Re~i~e;¡ , DE!l:~1};) ~At4 ~Yes [J No Directional Survey Required )8l"Yes 'ft~~ . . Alaska Oil & Gas Cons. CommiSSion Anchorage o Rlbì\ïr_ BY ORDER OF THE COMMISSION Date 121/ð!o5 SJb~it In Duplicate ) )e Point MPF-87 Well Permit IWell Name: I MPF-87A Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Frac Producer Kuparuk A Surface Location: 21141 FSL, 29231 FEL, SEC. 6, T13N, R10E E=541638.76 N=6035564.51 4571' FNL, 1208' FEL, SEC.36 , T14N, R9E E=538175 N=6039420 Z=7259' TVD 4551' FNL, 1224' FEL, SEC. 36 T14 N, R9E E=538159 N=6039440 Z=7407' TVD 8700' 1250' Target Location: TOP Kuparuk A3 Target Location: BHL Well TD Distance to Property line Distance to nearest pool I AFE Number: I I Rig: 1 Doyon 14 1 Estimated Start Date: I Dec. 10, 2003 I 1 Operating days to complete: 110 I MD: 19734 I 1 TVD: 17407' I I Max Inc: 161 1 I KOP: 11100' I·· I KBE: 146' I Well Design (conventional, slim hole, etc.): I Slimhole Grass Roots Frac Producer I Objective: I Kuparuk A Sand Mud Program: 12-1/4" Surface Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 8.6 - 9.6 75 - 150 25 - 60 N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 12 8-1/2" Intermediate Hole Mud Properties: Density (pPÇJ) Funnel visc YP HTHP 9.4 75 - 150 25 - 60 N/A LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 LCM Restrictions: Use caC03 as LCM / Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Cement Program: 1 ) ~e Point MPF-87 Well Permit Casin~ Size 19-5/8" 40-lb/ft L-80 BTC Surface Casing Basis I Already Set and cemented to Surface Casin~ Size 17" 26-lb/ft L-80 BTC Intermediate Casing Basis 140% excess over gauge hole. Lead 500-ft MD above top of Kuparuk. Total Cement Volume: 40-bbl Wash 5-bbl water S acer 30-bbI10.2-lb/. al AI ha Spacer AI ha 43-bbl, 200-sx 15.6 Ib/gal Prem G - 1.22 ft Isx (top of lead at 8450-ft MD) BHST ===175°F from SOR Lead Temp Evaluation Program: 8-1/2" Section Open Hole: MWD/GRlRES, PWD IFRlCASANDRA Cased Hole: N/ A .; 2 ) )e Point MPF-87 Well Permit Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* BPRF 1763 1746 738 8.35 TUZC 3705 3446 1476 8.35 SBF2-NA 4372 3991 1713 8.35 SBA5 4721 4276 1837 8.35 KLGM 8975 6689 2885 8.35 TKUD 9146 6844 2953 8.35 TKUB 9383 7064 3048 8.35 TKUA 9456 7134 3078 / 8.35 TKA3 9462 7139 2527 6.85 ./ TKA2 9492 7169 2538 6.85 TKA1 9528 7204 2550 6.85 CasinglTubing Program: Hole Csg WtJ Grade Conn Burst Collapse Length Top Bottom Size Diam Ft MDITVDrkb MDITVDrkb 20-in 92 H-40 Weld 1530 520 112-ft 0 112-ft / 112-ft 12.25-in 9.625-in 40 L-80 BTC-M 5750 3090 49æmft 0 4,945-ft / LtglO' 4,457 -ft 8.5-in 7.0-in 26 L-80 BTC-M 7240 5410 9734 0 9,734-ft / 7,407- ft Recommended Bit Program: BHA Hole Size 8.5-in Depth (MD) 4807 - 9734' Bit Type Nozzle/Flow rate 1 PDC 3 ) ì~e Point MPF-87 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. Intermediate and Production Intervals · Maximum anticipated BHP: 3,078-psi @ 7,090-ft TVDss - Top of Kuparuk A-sand ¡/ · Maximum surface pressure: 2,369-psi @ surface ./ (Based on BHP and a full column of gas from TD @ O.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 12.5-lb/gal will be made at the 9.625-in casing shoe. 1 01-bbl with 9.6 Ib/gal mud and FIT of 12.5-lb/gal @ 9.625-in window. 9.0-lb/gal Brine / 6.8-lb/gal Diesel · Integrity test: · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Lost Circulation · We do not expect losses while drilling this well. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35Ib/gal EMW). ~~ 3 ,'^ ,.L4.,4~,EmlU Pad Data Sheet ~..~ ':~£.< .'" w ~-i to t-~. 'J" ~~,. -"þ · Please read the F-Pad Data Sheet thoroughly. Breathing · Wellbore breathing is a moderate possibility with the relatively high mud density used. Good operating practices to minimize ECD and surge/swab pressures should be employed. Hydrocarbons · Hydrocarbons will be encountered in the Kuparuk sands. The Schrader Bluff will be behind the existing surface casing and will not be exposed. Faults · There is a possible fault crossing, prior to reaching the intermediate casing point. This fault could be linked into MPL-15i well. 4 ) '~e Point MPF-87 Well Permit Hydrogen Sulfide · MPF-Pad is not designated as an H2S Pad, however Standard Operating Procedure for H2S precautions should be followed at all times. Highest Level of H2S on F-Pad 17.7 ppm on MPF-22, Feb 2001 19.9 ppm on MPF-30, Feb 2001 16.4 ppm on MPF-62, Feb 2001 23.5 ppm on MPF-69, Feb 2001 Anti-collision Issues · At 3887' MD, MPF-87 has an anti-collision close approach to MPF-13 that passes the 1/200 minor risk criteria. This well get within 118' center to center distance. 5 :) DRILL & COMPLETION PROCEDURE Procedure )ne Point MPF-87 Well Permit 1. KO plug at - 5000' and Drill 8-1/2" hole to land in top of the TD in Kuparuk-sand as per directional plan. 2. Case and cement 7" production casing. Freeze protect 7" x 9-5/8" annulus. 3. Run4-1/2" completion as per schematic. 4. Land tubing hanger and test. 5. Set BPV. 6. ND BOP. 7. Install and test tree. 8. Pull BPV. 9. Freeze protect thru GLM. 10. Install BPV and secure well. 11. RD/MO. 6 ~ 4-1/16" - SK FMC ) Wellhead: 11" x 4.S" SK Gel , w/4.5" TCII T&B Tubing Hanger CIW "H" BPV profile MPF A P OF elev. = 46-ft -87 ropose( )riQ. GL. elev.= 11.1-ft 20" 91 .1-lb/ft H-40 ... I 112' I 9.62S-in 40-lb/ft L-80 BTC-M casing 14945 1 ~ . 7.0-in 26-lb/ft L-80 BTC-M casing (drift ID = 6.151", cap = 0.0383-bbl/ft) 4.5M 12.6# L-80 IBT-M tubing 111"'~IIgurT\1 II -r' _F", - ~I II ~ , II II r II : r 1 I. : I I I ..... ' .-- 1 Ii,! )1 11,.:.--...£ ~, . i ~':-=-y Perforated Kuparuk A-sands 7.0-in Casing Shoe 9,734' ~ A DATE REV. BY COMMENTS ~ ~.,............. . " ,",,'," -E. ,.,...'. ... ,.' ",...,.,..,.. ",~"", !51: WDQ Proposed Kuparuk Frac Producer 9-Dec-03 .. Cameo 4.SM x 1" wi BK latch sidepocket KGB-2 GLM I 2100' I .. 4.SM HES MXD" Dura sliding sleeve 4.SM HES X-Nipple 7.0M x 4.S" Baker Premier Packer 19,300' I 4.SM HES XN-Nipple WLEG 1 I .. MILNE POINT UNIT WELL MPF-87A API NO: BP EXPLORATION (AK) COMPANY DET All.S Obp speI""r"y-sL.l"1 ø~~~~_IJ:: J Calcu13lioo Method; Minimum CUrvature =~; ~S;vW&^-Nonh Enor SurJãce: Elliplical + Casing Wami~ Method: Rules Based 4200-- -'uuv c ;§ -'uuu o o ~ +' :E" 1:: ~ :E" ;; o VJ 2400-- 1800-- BP Amoco MPG-87 Contingency wpOI - - - - - -------_.-.-. - - -- - --j - - - - - I - ----- - . . - : - - . >. : - - ---- ----- - ---- --- .-- - - - -- -- _,-i- ___J : - . ------ , - - --- -- - - - r ! - - I I I I I I I REFERENCE INFORMATION Co-ordin3Ie (N/E) Reference: Wen Centre: Plan MPF-87, True No<1h VelÜcal (IVD) Reference: ]01: 87 ]1Y1f1997 ]4:58 44_]0 Section (VS) Relèreœe: S1ct. (0.00N,0_00E) Measured~~= ~~4:58 44.10 FORMATION TOP DErAILS No. TVDPath MDPath Formation 1 6534.10 8791.96 THRZ 2 6614.10 8888.22 BHRZ 3 6689.10 8974.94 KLOM 4 6844.10 9146.25 TKUD 5 7064.10 9383.28 TKUB 6 7134.10 9456.33 TKUA 7 7139.10 9461.50 TKA3 8 7169.10 9492.46 TKA2 9 7204.10 9528.38 TKAl CASING DErAILS No. TVD MD Name 1 2 4456.78 7406.82 4945.00 9 5/8" 9734.43 7" SURVEY PROGRAM Depth Fm Depth To SurveyiPlan 4955.00 9734.44 Planned: MPG-87 Cootingeocy "1' COpy "i niT : 5642.09' MD, 4920.84' TVD Nami: -¡-WOOS -¡-FJ-W Nor1IIìng Easting Latitude Loogítude SloI Plan MPF-87 5564.48 9&49.]9 6035564.51 541638.76 7()OJtr29.099N 149"39'33.S40W WA TARGET DETAll.S Nami: 1VD +W-S +FJ-W Northing Easting Shape MPG-87 Cool 7259.10 387524 -3442_42 6039420_02 538175.D2 Point SECI10N DErAILS See MD Inc Azi TVD +N/-S +FJ- W DLeg TFace VSec Target 1 4955.00 34.31 325.13 4465.03 1151.19 -1252.28 0.00 0.00 1692.29 2 5642.09 61.63 320.97 4920.84 1552.59 -1559.26 4.00 -7.96 2196.26 3 8143.73 61.63 320.97 6109.60 3262.36 -2945.53 0.00 0.00 4395.20 Size 4 9105.Q3 23.18 320.97 6806.21 3756.49 -3346.15 4.00 180.00 5030.70 5 9255.03 23.18 320.97 6944.10 3802.35 -3383.33 0.00 0.00 5089.67 9.625 6 9584.44 10.00 320.97 7259.10 3875.24 -3442.42 4.00 180.00 5183.41 MPG-87 Cont 7.000 7 9734.44 10.00 320.97 7406.82 3895.48 -3458.82 0.00 0.00 5209.43 ---" K -2400 I I I I I I I I I I -1800 West(-)Æast(+) [600ft/in] I I I -1200 I I I I I I I 4/100' : 4955' MD, 4465.03TVD I I I -600 I I I I I I Total Depth: 9734.44' MD, 7406.82' TVD __7" _j ~nd Dir : 9584.44' MD, 7259.1' TVD _., ' _Start Dir4/IOO': 9255.03' MD, 6944.ITVD - ----------- ;-End Dir : 9105.03' MD, 6806.21' TVD - 7)00-/ __0 __~ '\ -,;;.-- Plan MPF-87 (RIG MPF-87) 6500 " ~i --- -~! ~ ,'...,' S'm Oi, 41100' , 8143,73' MD, 61 09.6WD '<-~ 1",,\ I ^'- '\ -- ,LIL' "'>'v<.: - : ,,",\ : -: "'\ - - I - -- '\.'\.-- __ _ _ - _ ,\ 'çw - '"\.'\ ,_ ,J:x\ _____ m\",\. ------_.-..._:----.~------ -- q- "'\'\- : , "\I "'\ ,: --~ . -'--- 1200 - ---- - - : - - -- - -3600 Plan: MPG-87 Contingency wpOl (pIanMPF-87/Plan MPF-87 Contingency) Tool CreaIed By: Ken Allen Checked: Date: 121812003 MWJ)i-1FR+MS Date: Reviewed: Date: WElL DETAJI.S o .--, LY " ..................,'-'" I~ I I Irrl I I ,¡I I ~ $000 ~OOO 8000 ~ --J1 / / /000 /" s§> ..../00/1 ~ V COMPANY DETAILS REFERENCE INFORMATION Co-ordinale (NIE) Reference: Wen Centre: Plan MPF-87, Troe Nor1h Vertical (IVD) Reference: 101: 87 1IYV1997 14:58 44.10 Secticn (VS) Relèrence: Slot - (0_00N,0.00E) Measured Depth Reference: 101: 87 1IYUI997 14:58 44.10 CaJcuJatioo Method: Minimum Curwture SURVEY PROGRAM Depth Fm Depth To Suryey/Plan 4955.00 9734.44 PIamed: MPG-87 Cootingeocy wI' ~-sun D"IL.~!~~!I~VIC.. 81' Amoco CalculaÛO!l Method: Minimwn Curvature Error System: ISCWSA Scan Method; Trav Cylinder Nor1h Error Surfuce: Ellip6caJ + Casing Wam~ Method: Rules Based bp FORMATION TOP DErAILS No. TVDPath MDPath Formation 1 6534.10 8791.96 THRZ 2 6614.10 8888.22 BHRZ 3 6689.10 8974.94 KLGM 4 6844.10 9146.25 TKUD 5 7064.10 9383.28 TKUB 6 7134.10 9456.33 TKUA 7 7139.10 9461.50 TKA3 8 7169.10 9492.46 TKA2 9 7204.10 9528.38 TKAl Sec MD Inc 4955.00 34.31 325.13 ';:: ~ o o ::£. .r: õ.. Ö ""§ '-2 > 2 ¡- = _. i\./ Start Dir 4/100' : 4955' MD, 4465.03'lVD CASING DErAILS 2 5642.09 61.63 320.97 3 8143.73 61.63 320.97 =h.Ú¿'S\; 5/8" No. TVD MD Name Size 4 9105.03 23.18 320.97 5 9255.03 23.18 320.97 1 4456.78 4945.00 95/8" 9.625 6 9584.44 10.00 320.97 2 7406.82 9734.43 7" 7.000 7 9734.44 10.00 320.97 = --..... ~~ - \ ~ < Dk ,5642,'"' MD, 4920.84'TVD 'uuv - - \-i - - - \nr~ FT C py - \. '" . - - '\ ------~¡ . -- - '\ - , : : 5400- , G- . .~: , - '\ : . - - - - , '\ . - - ---- - - .-õ.... .__h__ ---- UVVU - ", i i: Start Dir4/100' : 8143.73' MD, 6109.6 - - - '" , - : - - -- : . .: . : _ h~ , ~h - - ~ --'\.'- - - hh uu'~; u__ - - - ; : u_u_ LtJ<L.- \".,,1 uuvu - .h ~ ~h. ~o - -- , -- .-.-- : · , --- -- ------ ------ .Iq.G End Dir - --,-------- ---- - - 10«\1' ---.--- -- ----- KllD \ ,/' Start - -- ~-J- _'m_ j - - ;---- ! j - --- - - ~~~ - - Uj. , - - - - · V ~ 7200 : . - , , . ' , 11 - - , : - _h--- - .---- - . : . , 'h U _ - _h' --- -- · : -c-+-7"+-' MP - · · :1_U} - - . · . : . . . . - , : , , : : : : , , : I I I I I I I I I I I I I I I I I 4200 4800 Vertical Section at 318.400 [600ft/in] I I I I I I I I I I I 2400 Plan: MPG-87 Contingency wp01 (plan MPF-87/Plan MPF-87 Contingency) Tool Crealed By: Ken Allen Checked: Dale: 121812003 MWD+IFR+MS Date: Reviewed: Dale: WEU. DEfAlLS Name +NI-S +FJ-W NaIhing Ea<ting Latitude Longitude Slot Plan MPF-87 5564.48 9849.19 603556451 541638.76 70"30'29.099N 149"39'33540W NlA TARGET DETAILS Name TVD +NI-S +FJ-W Norlhing Easting Shape MPG-87 ConI 7259.10 387524 -3442.42 6039420.02 538175.02 Point Azi SECTION DErAILS TVD +N/-S +E/-W DLeg TFace VSec Target 4465.03 1151.19 -1252.28 0.00 0.00 1692.29 4920.84 1552.59 -1559.26 4.00 -7.96 2196.26 6109.60 3262.36 -2945.53 0.00 0.00 4395.20 6806.21 3756.49 -3346.15 4.00 180.00 5030.70 6944.10 3802.35 -3383.33 0.00 0.00 5089.67 7259.10 3875.24 -3442.42 4.00 180.00 5183.41 MPG-87 Cont 7406.82 3895.48 -3458.82 0.00 0.00 5209.43 .y 0.---- 'lVD I , ,I / #, , # ;'" : 9105.03' MD, 6806.21' TVD Dir4l100': 9255.03'MD, 6944.1'lVD End Dir : 9584.44' MD, 7259.I'TVD Total Depth: 9734.44' MD, 7406.82' TVD G-87 Contingency wpOl I I I 5400 I I I I I I I I I I 6000 I I I I I I I I I I 6600 I I I I I I I I I I 7200 spa""""Y-5un DFUL.L.ING seRVices ^ ILU.LJ8I.!ATON t,'OMr"N\' li1~i¡i;i:ff~I~!1J~Bc~>j~'+ .,...' Plan: MPG-87 Contingency wp01 Principal: Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: M pt F Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: Plan MPF-87 )Sperry-Sun - Draft Copy ) KW A Planning bp .~.~, ;"; ~,. . c.. , ';pat~r:j1218/?OÒ3 ....>~¡ :.^~<Tim!t 17:42:37 "', < ,P~ge:.X !tt~i, (eo-p~~lnate(~):Re~e~~IJ~~.¡;" ,'Well: PI~n MPF-87, TrLJ~N9~~ "'".,. >V'ert~¢~I.(T'iq)ReferelÎt:èt~:-;:·!~1() 1. : . 87:1 Ot1~.1~~7;,1.4:q8A111:·· .... ...;. .'. ..', i:" '. ..... ,/:~:W~~¢:f~~f:{¡:~en ::t~:,~\;,'!,~¡~'l~~~O~µiY~i~vti? ~·.~9~~¿;'.:~f8i~þ,i·:.t·<:~··· Date Composed: 12/8/2003 Version: 6 Tied-to: From: Definitive Path . . ~ ....~ , "., ,.....:-..'< ,i , ;.: '~<..:~'/-:".':< ·ã!fffil~' ~:>. ,;-t)Fv/~ . ,'.", '.^ ::( f':':?J"':~' .; , Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 6029958.49 ft 531814.44 ft Latitude: Longitude: North Reference: Grid Convergence: 70 29 34.438 N 149 44 23.616 W True 0.25 deg Slot Name: Well Position: +N/-S 5564.48 ft Northing: 6035564.51 ft Latitude: +E/-W 9849.19 ft Easting: 541638.76 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan MPF-87 Contingency Current Datum: Magnetic Data: Field Strength: Vertical Section: 101 : 87 10/1/1997 14:58 12/8/2003 57541 nT Depth From (TVD) ft 33.00 Casing Points 70 30 29.099 N 149 39 33.540 W Height 44.10 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 RIG MPF-87 4955.00 ft Mean Sea Level 25.00 deg 80.87 deg Direction deg 318.40 +N/-S ft 0.00 4945.00 4456.78 9734.43 7406.82 12.250 8.500 95/8" 7" 9.625 7.000 Formations 8791.96 6534.10 THRZ 8888.22 6614.10 BHRZ 8974.94 6689.10 KLGM 9146.25 6844.10 TKUD 9383.28 7064.10 TKUB 9456.33 7134.10 TKUA 9461.50 7139.10 TKA3 9492.46 7169.10 TKA2 9528.38 7204.10 TKA1 Targets .TVD· . ":: ft 7259.10 MPG-87 Cant -Plan hit target 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . '. +N/-S. +EI-W . ft ft 3875.24 -3442.42 . .M~p~: ~ »":M~p Northing: Easting '~: . 'ft, 6039420.02 538175.02 70 31 7.203 N 149 41 14.978 W ,<...:- . Latitude. ~> <~'Longitude .;..-> . Deg,Min,S~c\' 'J?~ l\{in Sec . sper'1r'1\/-sun DRIL.L.ING seRVices ^ l"l,UmlM;TON (',O~\P"N\' ) ) Sperry-Sun - Draft Copy KW A Planning ...:.:....:..'.....:...'.~.~)..'.'.[w..·:....T.:erl..;.'p(..a·.i. :.t·..:·....h:.l.....·:,.::.::.::·....,·..:.t......~P'........·...·:··.~I~a·~.nn:....t:::...:MF.....·.P:p.~.'....:::..c..:...~.a:....·...n.O..:........::'.taß:··...%.'...·,·..:...~~~ii/,,~¡;¡ . >', :' . " . .:.. : ,f\~. lih~~Jci,t::lÜ~1:J;é:. Plan Section Information ";;:'{{ bp :". :·:t ·:~+;~·œi' u.' .. Da~e:': '.' ::~ 2/~/'2"Qêiá·.·; .'. ·;:~:;!\;î:t:Timeg "01 !i4~:'3i:r?\%! ..... '.' .·ii'··......·· 'ytii"Þage:.·:" :2 .,. ,1; : Cojordi~ateiNÈ);ªetereÌfé~~i3 ;:'~ \¡'\Jer): ~!~hM8þ.-87iiÏru~:N6rth' .' ; ;.; .. . ;; ; . Vertical (1lW):Referencè:\ "'. ': 101:: 87:1 0/111 ~97 ,14:58 44.1 . '., :" ;' ~ i: k? SeëtiQn @'S)¿Re(~rence:~,.;·,y ill>: ~WeJI;(9)q9N.,9.POE,~·~8APAZI) ',', .: *,;: t\ , .'~% ')"éSu-rveyqa!c9Ia!I~~ MetM~;;ql:,'i·.ry1in!rnÇlm;q9;N~tlJre:í-i:f :;:;&:;.Pb':; Pr~çl,~. .;.. ...:~.:,:.~ :".. ^:>. '~ ·¿·:·'::.::7."?~· < : ':~~;~?:~~t: . ~." <:·.\:';//i~::·::iT 4955.00 5642.09 8143.73 9105.03 9255.03 9584.44 9734.44 Survey 34.31 61.63 61.63 23.18 23.18 10.00 10.00 325.13 320.97 320.97 320.97 320.97 320.97 320.97 4465.03 4920.84 6109.60 6806.21 6944.10 7259.10 7406.82 ~:~~:~t1tf~ w"';' . .;'". '" ., 1151.19 -1252.28 1552.59 -1559.26 3262.36 -2945.53 3756.49 -3346.15 3802.35 -3383.33 3875.24 -3442.42 3895.48 -3458.82 " ~ ....:~:;::: p.~~~:;~., :.:'·~~::~.:l~uild: ':;:{ ;;::f=:r~::·::?t*~k;:::~·:. ·:L·:~~f·: 1': y~ ' :d~~/~ (iO~r:d~gi1 oº,~:~'êgl;~ 9q~ttt 0.00 0.00 0.00 4.00 3.98 -0.61 0.00 0.00 0.00 4.00 -4.00 0.00 0.00 0.00 0.00 4.00 -4.00 0.00 0.00 0.00 0.00 0.00 -7.96 0.00 180.00 0.00 180.00 0.00 MPG-87 Cont 4945.00 4955.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5642.09 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8143.73 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8791.96 34.34 325.01 34.31 325.13 36.09 324.71 40.06 323.88 44.03 323.19 48.01 322.58 51.99 322.05 55.97 321.57 59.95 321.14 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320,97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320,97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 61.63 320.97 59.38 320.97 55.38 320.97 51.38 320.97 47.38 320.97 43.38 320.97 39.38 320.97 35.70 320.97 4456.78 4465.03 4501.81 4580.51 4654.76 4724.19 4788.46 4847.25 4900.30 4920,84 4948.35 4995.87 5043.39 5090.91 5138.43 5185.95 5233.47 5280.99 5328.51 5376.03 5423.55 5471.07 5518.59 5566.11 5613.62 5661.14 5708.66 5756.18 5803.70 5851.22 5898.74 5946.26 5993.78 6041.30 6088.82 6109.60 6137.30 6191.20 6250.84 6315.94 6386.17 6461.19 6534.10 4412.68 4420.93 4457.71 4536.41 4610.66 4680.09 4744.36 4803.15 4856.20 4876.74 4904.25 4951.77 4999.29 5046.81 5094.33 5141.85 5189.37 5236.89 5284.41 5331.93 5379.45 5426.97 5474.49 5522.01 5569.52 5617.04 5664.56 5712.08 5759.60 5807.12 5854.64 5902.16 5949.68 5997.20 6044.72 6065.50 6093,20 6147.10 6206.74 6271.84 6342.07 6417.09 6490.00 6036703.95 6036708.55 6036729.69 6036779.54 6036833.15 6036890.26 6036950.60 6037013.86 6037079.74 6037108.18 6037147.57 6037215.60 6037283.63 6037351.66 6037419.68 6037487.71 6037555.74 6037623.77 6037691.79 6037759.82 6037827.85 6037895.88 6037963.91 6038031.93 6038099.96 6038167.99 6038236.02 6038304.04 6038372.07 6038440.10 6038508.13 6038576.15 6038644.18 6038712.21 6038780.24 6038809,99 6038847.85 6038912.95 6038974.99 6039033.66 6039088.68 6039139.78 6039183.09 540383.43 540380.17 540365.15 540328,87 540288.77 540245.03 540197.87 540147.52 540094.22 540070.97 540038.67 539982.87 539927.08 539871.29 539815.50 539759.71 539703.92 539648.13 539592.34 539536.55 539480.75 539424.96 539369.17 539313.38 539257.59 539201.80 539146.01 539090.22 539034.43 538978.64 538922.84 538867.05 538811.26 538755.47 538699.68 538675.28 538644.23 538590.84 538539.96 538491.84 538446.72 538404.82 538369.30 1686.69 1692.29 1718.06 1779.39 1846.08 1917.80 1994.21 2074.93 2159.56 2196.26 2247.16 2335.06 2422.96 2510.86 2598.76 2686.66 2774.56 2862.46 2950.36 3038.26 3126.16 3214.06 3301.96 3389.86 3477.76 3565.66 3653.56 3741.46 3829.36 3917.26 4005.16 4093.06 4180.96 4268.86 4356.76 4395.20 4444.12 4528.24 4608.40 4684.21 4755.30 4821.33 4877.29 0.00 0.00 9 5/8" 0.74 115.85 MWD+IFR+MS 4.00 352.04 MWD+IFR+MS 4.00 352.39 MWD+IFR+MS 4.00 353.03 MWD+IFR+MS 4.00 353.55 MWD+IFR+MS 4.00 353.97 MWD+IFR+MS 4.00 354.31 MWD+IFR+MS 4.00 354.60 MWD+IFR+MS 4.00 354.83 MWD+IFR+MS 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 0.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 MWD+IFR+MS 4.00 180.00 THRZ ^ ILH,tJ",IM'I'n~ ('OMPAN\' ) ) Sperry-Sun - Draft Copy KW A Planning 5per'1r'1~-5Un D RIL.L.ING SERVices >qom'pahy: <Flèld:..· .'.> ::Si.t~r:jy,< ; ~~\~;~h: Survey 'BP.'A6\ôco . " ; r~,L::' . ':/"" : Millîê" Po in!' '. '7.\. :.\....'~ \:. !.;',.:.:'.'.:.:.:.'.:.:,;.'.'~.:;.;.,.. '<.~,;.;... r.;::.;.:·.:·.~.·..'. ...\ '.' ¡' ". :"q (ME?t:Fpad".;, ..,. . ",' ..' ,"~:~~',M~~~,~iiq~ri(1;~b~~.þy:,;:!t~::rS ~,¡;: . ";;c" . ::':.':,;,'.:.:.:;.'" .......' Dà!ê';':12Ié/?Q03;"~;' .}¿:Tiíne: :f17:4?:37:2'\;.. ..' '..~;.:§:~âge:'::; 3.>: . C~t,o'Í'~i~afe(N);)R'efê~~n~#(WEillt' elan M8F..8"1. TriïeNþ(th;i', ',:,\ V ef:t¡çaÜTYD)J{er~r~ºce;'£' :f 1 Ö1~; ª7: 1 0/1'K,199714i5,854j:m): .:l:::}';;; \ . . :.:.:.:...SS·..·.·. euc,'r·..·.*v'.·..·..IOe· 'y·~.',...:.·c·~,.<.·.:.y.·,.·a'...·.·;:.·I...·C~..'.),'.·".·u'.·i.¥......I·.'a,ef;f¡.."eo·. rn·.>.·..·~...,....nM)ee..; '.t,~"h·.. ':,·O·;:d·;.··.··.. ..:'i' W~I,I i,(Q~ÞON, Q·99E,31~·:1Q~j)+;·d;;:;::~.à '; ~,y .. . .. '.' ..' ,.' ' ;: Min(rr@;n,çpr<~J~r;~>:Æj\;;:p~:J;·Ç?ré:t~bl~;:-.;' . ":':-:="/< ;.;) 8800.00 35.38 320.97 6540.64 6496.54 6039186.71 538366.34 4881.96 4.00 180.00 MWD+IFR+MS 8888.22 31.85 320.97 6614.10 6570.00 6039224.46 538335.37 4930.74 4.00 180.00 BHRZ 8900.00 31.38 320.97 6624.13 6580.03 6039229.23 538331.46 4936.91 4.00 179.99 MWD+IFR+MS 8974.94 28.38 320.97 6689.10 6645.00 6039258.09 538307.79 4974.20 4.00 179.99 KLGM 9000.00 27.38 320.97 6711.25 6667.15 6039267.15 538300.36 4985.90 4.00 179.99 MWD+IFR+MS 9105.03 23.18 320.97 6806.21 6762.11 6039301.82 538271.94 5030.70 4.00 179.99 MWD+IFR+MS 9146.25 23.18 320.97 6844.10 6800.00 6039314.37 538261.65 5046.90 0.00 0.00 TKUD 9200.00 23.18 320.97 6893.51 6849.41 6039330.72 538248.24 5068.03 0.00 0.00 MWD+IFR+MS 9255.03 23.18 320.97 6944.10 6900.00 6039347.47 538234.51 5089.67 0.00 0.00 MWD+IFR+MS 9300.00 21.38 320.97 6985.71 6941.61 6039360.65 538223.70 5106.70 4.00 180.00 MWD+IFR+MS 9383.28 18.05 320.97 7064,10 7020.00 6039382.36 538205.89 5134.76 4.00 180.00 TKUB 9400.00 17.38 320.97 7080.03 7035.93 6039386.30 538202.67 5139.84 4.00 180.00 MWD+IFR+MS 9456.33 15.12 320.97 7134.10 7090.00 6039398.48 538192.68 5155.58 4.00 180.00 TKUA 9461.50 14.92 320.97 7139.10 7095.00 §V39399.52 5381 Ç 1.83 5156.92 4.00 180.00 TKA3 9492.46 13.68 320.97 7169.10 7125.00 6039405.43 538186.98 5164.56 4.00 180.00 TKA2 9500.00 13.38 320.97 7176.43 7132.33 6039406.80 538185.86 5166.32 4.00 180.00 MWD+IFR+MS 9528.38 12.24 320.97 7204.10 7160.00 6039411.66 538181.87 5172.61 4.00 180.00 TKA1 9584.44 10.00 320.97 7259.10 7215.00 6039420.02 538175.02 5183.41 4.00 180.00 MPG-87 Cont 9600.00 10.00 320.97 7274.43 7230.33 6039422.11 538173.30 5186.11 0.00 0.00 MWD+IFR+MS 9700.00 10.00 320.97 7372.91 7328.81 6039435.54 538162.29 5203.46 0.00 0.00 MWD+IFR+MS ./ 9734.44 10.00 320.97 7406.82 7362.72 6039440.16 538158.50 5209.43 0.00 0.00 7" 1111 0 5 5 ~ g j III I: 0 ~ . 2 0 j a €1 5 I: o. 2 ? a 9 b 1111 .-- .~~~-~~~J;¡"::'._~',~ - ;-.. .. .. .. I- n . ~..._ . ..... ...... ... ';'~...' _ - L:·;::··:::.:, :'>'-',::"::;·2' .:\:;:;~., , t·2;~¿L·;:· ";L . NOT VALID AFTER 120 DAYS ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 I I TO THE ORDER I OF: I I AMOUNT DATE November 25,2003 *******$100.00******* c:::it B fJ r; ~ "f" Æ. .. . ~.~.t.J, PAY: 055193 No..P 56-389 -¡:¡z NATIONAL CITY BANK Ashland, Ohio BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519~6612 -., CONSOLIDATED COMMERCIAL ACCOUNT --- ------ ~ r..·"[ßI... ~... T:-Œ !\.TTACHED CHECK IS IN PAYMENT Fon ITEMS DESCRIBED ABOVE. !i\ v Cì\~sg('i em ('It Gas, Cons. Comm~s~ion Am;hmðY(~ DEt tt 0 r~JE [) ~;a'1<. ~~v j~ .~ -~ ~-~ PERMIT TO DRilL =EES 11/25/200~ PR 111803C NET VENDOR DISCOUNT GROSS DESCRIPTION INVOICE I CREDIT MEMO DATE -- ---~- CHECK NO. 055193 DATE 11/25/2003 p055193 ) ) TRANSMJTAL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/P ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /7?P!~ ;::8719 PTD# '20 3- ZI3 CHECK WHAT APPLIES ADD-ONS (OPTIONS) M1JL TI LATERAL (If API Dumber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore 'segment of existing well . Permit No, API No. Production, should continue to be reported as a function' of the original API number. stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name OD permit plus PH) and API num ber (50 70/80) from records, data and logs acquired for well (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject ·to full compliance with 20 AAC 25..055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing ,exception tbat may occur. An dry ditch sample sets submitted to the Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample hitervals through target zones. .WËJ...~ ~~~;~ri~ P.HE_<;:KLIS~ Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT KR F-87A Program J;LEV _ Well bore seg D PTD#:2032130 Company J~£...çXPJ.,ºRATI01L(ALA..5-KA)JN.C Initial ClassfType __O_E~LLE.¡;~JL__GeoArea _8_9_0_ __________. Unit JJ_32.8___ On/Off Shore .0.0_____.__ Annular Disposal [] Administration 1 P.ßrrT) it fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ Yes _ _ _ _ .. _ . _ _ . . . . . . . _ . _ _ . _ _ _ . _ _ _ _ _ _ . . . _ _ .. . .. _ _ _ . _ . . . _ .. . _ _ _ . . . . . _ . - . _ .' _ . . _ 2 .Leas.ß.number _app'ropriat~_ _ _ _ _ _ _ _ _ _ _ . _ _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . . . . . _ _ Y.ß$ _ _ _ _ _ _ _ Surface loc LnAD.L_25qO.9, Pa$Se.s.throug.hAD.L..3862_3p,Jop prod interv¡;¡l.anç JO In.AQL.3.55Qt8, _ . . _ _ _ . 3 _U_nique weltn_arne_and lJumb_er _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ . _ _ _ _ _ . _ _ _Y.ß$ . . _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ . _ . _ . _ . _ - - - - - . - - - - - 4 _We.IIJQcated i.n_a_d.efined_pool. . _ _ . _ . _ . . . . . _ _ . . . . . _ . _ . _ .. . . . . _ _ _ _ _ _ _ _ . Y.ß$ . . . _ . _ _ _ _ _ _ _ _ _ . . . _ . . . _ _ _ _ . . _ _ .. _ _ _ _ . _ . _ _ _ _ .. _ _ . . . . . _ _ _ . . - . _ _ - - . - - - . . . .. . 5 _We.IUQcated proper_di.stance.fromdriJling unitb_ound_a(y_ . . . _ . _ . . . . _ . _ _ _ . _ _ _ _ _ _ _ Yes. . . . . _ . KUP.aruk.River:.Oill?o.ol; COA32B,_ _ .. _ _ _ _ _ . _ . _ _ . _ _ _ _ _ . . . _ . _ . .. _ _ . . . . . . . . - - . - .. - - - - - - 6 .WeJUQcated proper .distance. from Qtbe.r weHs_ . . . _ . _ . . . . . . . _ . _ _ . _ _ _ _ _ _ . . . . _ Y.ßs . _ . _ _ _ . _ _ _ . _ . . . . . . _ . . . .. _ _ _ . _ _ .. . .. _ _ . . _ .. . _ . . . _ . _ _ _ _ . . . . . . - - - - - - - - - - - - - - - 7 .S.utficient .acreag_e.aYail.able in.drillilJg unJt _ . _ . . _ _ _ _ _ _ _ . . . . . . _ . _ . . _ . _ . _ _ . _ _ Y.ß$ . _ _ . . _ . _ _ _ _ _ _ _ . _ _ . _ . _ . . . _ . . _ _ _ . _ . _ .. . _ . . . _ _ . . .. _ _ . _ . . _ .. _ _ _ _ _ .. . . . . . . .. - .. . - . .. . . . 8 Jf.deviated, Js. weJlbQre plaUl1cJu.ded _ . _ . _ _ _ . _ _ _ _ _ _ _ _ . . _ . . . _ . _ _ . _ _ . _ _ _ _ _ Y.ßs . . . . . _ _ _ _ . . _ _ _ _ _ . . . . . . . _ . . . _ _ _ _ _ _ _ . _ . . . _ . .. . _ _ _ _ . _ . . . _ _ _ _ _ _ _ . . . . . . - - - - - - - 9 .Qper:.ator only aftected party _ _ _ _ . . _ _ _ _... _ . . . . _ _ _ _ . _ _ _ _ _ _ _ _ .. _ _ . _ . . _ yes . . _ . .. _ _ . . . _ _ . . _ . _ _ _ _ _ _ . _ .. . . . . _ . . . _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ _ - _ _ _ . . . - . - . . . - - - - - - . 10 .Qper_ator bas.appropriate. b.ond inJorce. _ _ . . . _ _ _ . _ . _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ Y.ßS _ _ _ _ _ _ _ _ _ _ . . _ . . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ . . . . _ _ . _ _ _ _ _ _ . . _ _ _ _ . . - . - - - - - - - - - - - . - . - 11 P.ßrrT)il c.a[l be iS$u.ed wjtbQut co_nserva.tion order. _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . Y.ß$ . _ _ _ _ _ _ _ _ _ _ . . _ . . . _ . _. _ _ _ _ _ _ _ . . _ . . . . _ _ _ _ . _ _ _ _ _ _ . . . - - - - - . . - - . - - - - . . - . - - - - .. . - . Appr Date 12 P.ßrrT)il c.an be issued wjtbQut ad_rT)il1is.trati\le_approvaJ _ _ _ .. _ . . _ . _ . . _ . _ . _ . . . _ _ _ _ _ Y.ß$ _ _ _ _ _ _ _ _ - . . - - . . . - - - - - - - - - - - . . . - . . . . - - - - - . - - . . . - . . - - - - - - - . . . . - - . . - - . . - - - . - - . SF!) 12/10/2003 13 Can permit be approved before 15-day wait Yes ) 14 _We.IIJQcaledwithinareaan.d_strata_authorizedby.lojectiooOrder# (put 10# in_c_omm_eots)_(For_ _NA_ _ _ _ _ _... _.... _ _ _ _ _ _ _ _ _ _.. _.. _. _. _. _ _ _ _ _.... _. _. _ _ _ _ _..... _. - - - - - - - - - - - -.... 15 AJI weHs_within Jl4_mile_are.a.of reyiew jd.ßlJtified (For ~ervJc.ß.w.ell only). _ _ _ _ _ _ _ _ . _ . _ . _ _NA _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ . . . _ . _ _ . . . _ _ _ _ _ _ _ _ _ _ . . _ _ . _ _ _ . . . . _ . - . . - - - - - . . . . . - . - . - 16 Pre.-produ.cedi[ljec;tor; dur.atiQn_ofpre-:produGtiolJl.ß$~than.3months_(For_ser:.vLcewellQnJy). _ NA _ _ _ _ _ _ _. _' _ _' _ _ _. _. _ _ _. _ _ _ _ _ _ _.. _. _ _. _ _ _ _. _.... _. _ _ _ _ - _... - - - - -. - - - -. - - - - -- 17 .ACMP_FJnding.of Con.si$terH;;y_h_as bee.nJ~s!.led.fOr.tbiS project _ _ . _ _ . _ _ _ _ _ . _ . . . _ . _ NA. _ . _ _ _ _ _ Sidetrack of.w.ßlI drilled {rom an existilJg pad._ _ _ _ .. _ _ . . . . . _ _ _ _ _ . .. . . . . _ . _ _ _ _ _ _ _ _ ,. _ _ . . . Engineering 18 .C_ondu_ctor string.PJQvided _ . . . _ _ _ _ _ _ . . . _ _ . _ _ _ . _ _ ., . . _ _ _ . . . . . _ _ _ _ . _ _ _NA _ _ .. _ _ . . Con.ductor _seUIJ orjgjn_al we.III;>Qre.. _ . _ _ _ . _ . _ _ _ _ . . _ . . _ _ _ _ . . . . . _ . . _ _ _ _ _ _ _ 19 _S_urjace.ca~ing_pJotec.t~aILknown.l)SQWs _ _ _ _ _ _ _ _ _ .. . _ _ _ _ _ _ . . _ .. .. _ _ _ . . . . . . _NA _ _ . _ _ _ .AII.aq_uifers ex.empted 4Q CFB. :I 47.. t02(.b)(3). _ _ _ _ .. _ _ . _ . . . . _ .. _ _ . _ . . . . _ . . . - . - - - - - - . . . . . . 20 .CMT vol adequ.ate.to circ_ulate_o_n _col1d_uctor:. & $UJ(C$g _ _ _ : _ _ _ _ . _ . . . _ _ _ . . _ . _ _ _ _ _NA _ _ _ _ _ _ _ Surface ca$ing inst.alJe.d.in orig[n·al.weJlbore... . . . . . . _ . . . . . _ _ .. _ _ _ _ _ . ,. . . . _ . _ _ _ _ _ _ _ . _ ,. . _ . . 21 _CMT. vol adequ_ate.to tie-inJQng _string to_surf c~g_ . _ _ _ _ _ _ _ . . _ . _ . . . . . . . . . _ _ _ _ _ .NA _ _ _ _ _ _ _ Surface ca$Lng [nsì.alJe.d.in ori.g[na'-weJlboJe.. _ _ _ . _ _ . . ,. .. _ . _ . _ _ .. _ _ _ _ _ . _ _ . . . _ . _ . . 22 _CMTwill coyer_aJl.klJown.pro_ductiye bQri~on.s_ _ _ . _ _ _ _ . _ . . _ . . . .. ...... _ _ _ _ _ Yes _ _ _ _ _ _ _ _ . . _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ . - - - - . - - - - - - 23 .C_asiog de_signs adeç¡ua.te for C,.T., B _&_ permafr.ost. . _ . . _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.ßs _ _ _ _ . . _ . . . _ _ . _ . . _ _ _ _ _ _ . . . _ _ . _ __ _ _ _ _ _ _ _ _ . . . . - - - - - - . - - . - - - . . . - - - - - . - . - . 24 _Adequ.ate.tan_kage_oJ re.serye pit. . . . . _ _ . _ . . . _ . _ . _ . . . _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ Y.ßs . _ _ _ . . _ Rig js_e.quippe_dwitl1 sleel.pits.. NQ rese_l"\le_pJt.p!a(1IJe.d, A!I waste to_Class JI.weU($)~ . _ _ .. _ _ _ _ . . _ _ _ . . . 25 Jf.a.re-drilt, l1as_a_ 1.0:403 fOJ .abandonment beelJ apPJQved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , .Yes _ _ _ . . _ _ 30_3~3_64 _ _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ - _ - - - - - . 26 Adequ.ate.'^le!lbore. ~eparatjo.n.propo~ed. . _ . _ . _ . _ . _ _ _ . . . . _ . . _ . _ _ _ _ _ _ _ _ . _ _ .Y.ß$ . . _ _ _ . _ CIO$e. appr:.oç¡ch.ide.ntifjed._ Mjtigatiofl .rn.ea$ure.s_ayail.able._ _ _ . _ _ _ . _ _ _ . . _ . . _ _ . _ . _ _ . . . . _ . . _ _ . _ 27 Jf.djver:te.r Je.q.uire.d, dQes jtmeet reguJa.tiol1s_ _ . _ _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ NA . . _ . . _ _ Drilling .below surface ca.sing._ BOP Ìn.pJa.ce._ _ _ _ _ _ . _ . _ . _ _ _ _ . _ _ _ . . . . . _ . . . . _ . . - _ . - . . Appr Date 28 _Drilliog fluid_program sc.hematic.& eq.uipJist.adequate. _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ . _ . Expected BH~ i.nKuparuk 6.85_ EMW._ PlanlJe.d_mu.dweight 9.4. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . TEM 12/10/2003 29 _BOPEs,_do.they meetreguJation _ _ _ _ . _ _ _ _ _ _ _ . . _ _ . _ . _ _ _ . _ . _ _ _ _ _ . _ _ . _ . _ Y.ß$ _ _ _ _ _ _ . _ _ . _ _ . . _ . . _ _ _ . _ _ . _ _ _ _ . _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ .. _ _ _ _ _ . _ _ '1), 1tv1 30 .BOPE_pre.ss ratiog appropriate; .testto.(pu.t psig in .comments). - . - - - - - - - - . - . - . - - - - .Yes _ _ _ . _ _ - CalcuJa.te.d.MASP_ 23ß9 psi._ 3QOO psi.appropri.ate, - - .. - . - - - - . - . - - - . - - - - - - - - . . . . - - - - - . . - - . I ~ 31 _C_hoke_manjfold cQrT)pJie~ w/AP'- R.~-53. (May 84). _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ Y.ßs _ _ _ . _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ . . _ . _ _ _ _ . . - . - - - . - 32 .WQrk will oc;c.u( withoutoperation _sbutdQw.n_ _ _ _ . _ _ _ . _ _ . _ . . _ . . . . . . _ _ _ . . _ . . . .Y.ßS _ _ _ . _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . _ _ _ _ _ _ _ . - - . - . . . - - - - - - - - . - - - . . . . 33 J~ pres.ence_ Qf H2S gas_ prob_able. . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . _ . _ _ _ _ _ _ .. _ _ . _ . _ _ _ No. _ _ _ _ _ _ . _ . . _ . _ _ _ _ _ _ _ _ _ . . _ . . . . . _ _ _ _ . _ _ _ _ . _ _ _ _ _ . . _ . _ _ _ _ _ - _ . _ . . - . - - . - - . . . - - - - - . 34 Mecba_ni.caLcOlJdJtLon o{ we.lIs within AOB. yerified (For_ s.ervice welJ only) _ _ _ . _ _ _ _ _ . _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . _ . . _ _ _ - . - . . . Geology 35 PerrT)itc.ao be issued w!o. hydrogen_s.u!fiçle meaS.!Jres. _ . . . . . . _ . _ _ . _ . . _ . . _ . . . _ . No_ _ . _ . . _ _ MPU F:P.açl weIJs.h_ave. produ.ced. up.to 23.5 ppm H2S._ _ _ . _ . . . _ _ . _ _ _ _ _ . . _ . _ . . _ _ _ _ _ . 36 .D_ata_pre.seoted on pote_ntial ove_rpres_sure .zone$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ Y.ß$ _ _ _ _ _ . _ ~orma'-PJessure gr:.açl.Jo J/.K\.IparUk; Kup_aru_kJeservoir expeGted. to be Ul1d.erpre.ssured at ß,8_ppg EMW.. . Appr Date 37 _Seismic.analysJs. Qf sha.llow gas_zpoe.s_ . . _ _ . . _ _ . _ .. _ _ . . . . _ _ _ _ _ _ . _ _. .. _ . . _ _NA. _ _ _ . _ _ _ Will.b~ .drilled wJtb 9.0 ppg mud.. _ _ . _ _ _ _ _ . . _ _ _ _ . _ _ ~ _ _ _ _ _ _ . .. . . _ _ . . _ _ _ _ _ _ _ _ _ . . SFD 12/10/2003 38 _S.ßabed .condjtiolJ survey .(if off-sh.ore) . . . _ . . . _ _ . . . . _ . . _ _ _ _ _ _ . _ . _ . _ NA. .. _ _ _ _ . . _ _ _ . _ . . _ _ . . . _ _ . . . . . . . . _ _ _ _ _ . _ . _ . . . . . _ . _ _ _ _ _ . _ _ . _ _ . . . . . _ _ _ . _ _ _ . . . 39 _ CQnta.ct namelphoneJor_weekly progre~s_reRort$ [exploratory .only]. . . _ _ . . . _ _ . _ . . . _ _ .NA _ . . _ . . _ . . _ . . _ _ _ _ _ _ . _ _ _ _ _ . . _ . . . _ _ _ _ . _ _ .. . _ . . _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ _ _ _ _ . . _ . /"lrl 0/ V :J J ~;~e/ !J Engineering Commissioner: Date Public Commissioner Date Problems encountered while drilling MPU F-87 necessitate drilling of this sidetrack to a bottom hole location - 1,000' to the southeast of the original F-87 BHL. SFD Geolog ic Commissioner: ~ \~
