Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-021
e e 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. d Q if - 0 ~ l Well History File Identifier Page Count from Scanned File: Õ {¡; (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES ~ Datelfh'¡O~ If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided II 111111111" 111111 RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. ~ D Other, No/Type: D Poor Quality Originals: D Other: NOTES: BY: ~ Datetffq./ot Date " J ~ / 0 fo ~I I 0 Project Proofing BY: CMaria --:> Scanning Preparation BY: Date: Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed 111111111111111111I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: .t\1fJ 151 11111111111111 111I1 151 mf :55 + d.. 5 = TOTAL PAGES (Count does not include cover sheet) 151 1111111111111111111 NO vvtf 151 NO 151 1111111111111111111 ReScanned BY: Maria Date: 151 Comments about this file: III 1111111111111111 Quality Checked 111111111111 1111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA CiriE A SKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS IVED 6 PP 122013 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well A CC ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Jet Pump Conversion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic . 204 - 021 3. Address: IN Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 • 50 029 - 23194 - 60 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025906 v MPG - 18L1 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 8563' feet Plugs:(measured) None feet true vertical 4145' feet Junk: (measured) None feet Effective depth: measured 8563' feet Packer: (measured) 5039' feet true vertical 4145' feet Packer: (true vertical) 3967' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34' - 112' 34' - 112' Surface 3191' 10 -3/4" 35' - 3226' 35' - 2390' 5210 2480 Intermediate 5245' 7 -5/8" 33' - 5278' 33' - 4108' 6890 4790 Production Liner 3263' 4 - 1/2" 5273' - 8536' 4105' - 4145' 8430 7500 Perforation Depth: Measured Depth: Slotted 5380' - 8490' feet True Vertical Depth: Slotted 4157' - 4145' feet Tubing (size, grade, measured and true vertical depth): 4 - 1/2 ", 12.6# L - 5204' 4065' Packers and SSSV (type, measured and true vertical depth): 7 - 5/8" x 4 - 1/2" HES TNT Packer 5039' 3967' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1 Treatment description including volumes used and final pressure: SC N NED APR I P ` 013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 111 38 130 240 184 Subsequent to operation: 0 0 0 0 0 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: - ❑ Exploratory ❑ Stratigraphic IS Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: r IN Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Noel Nocas, 564 -4667 N/A Email: Noel.Nocas @bp.com Printed N. - Joe a tt]fl a Title: Drilling Technologist Signature: n Phone: 564 -4091 Date: 4016 Form 10 -404 R- :d 10/2012 RBDMS APR 15 2013 17/F 44/71 /3 Su mit Original Only 0 • North America - , SK . t.1 31:i - 4 *r .. ' ' ' Operation Summary 000 , Common Well Name: MPG -18 I AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 jX4- 00XF5- E:DRILL (1,785,000.00 ) i Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. ! UWI: Active datum: Kelly Bushing / Rotary Table ©63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (usft) 3/13/2013 1 18:00 - 20:00 2.00 MOB P PRE I PJSM, PREP RIG FOR MOVE I- WARM UP RIG HYDRAULICS, MAKE SPCC ;CHECKS - INSTALL REAR BOOSTER WHEELS ' - M/U HYDRAULIC LINES AND FUNCTION TEST 20:00 - 00:00 4.00 MOB P PRE I- MOVE RIG TO ENTRANCE ON MP F PAD I- CHECK ALL MOVING SYSTEM HYDRAULIC LINES FOR INTEGRITY _ - MOVEFROMMPFPADTOMPGPAD ------ --- ---- - - -- -- -- - -- - -- -- - - - - -- - - -- 3/14/2013 100:00 - 02:30 2.50 MOB P PRE PRE -TOUR MEETING AT RIG CAMP, SPCC I CHECKS - RIG MOVING FROM MP F PAD TO MPG PAD - RIG STAGED AT A PAD ENTRANCE AT MIDNIGHT - CONTINUE ON TO MPG PAD 02:30 - 07:45 5.25 MOB F P PRE ARRIVE MPG PAD - PJSM, BRIDLE DOWN AND SECURE DERRICK. - REMOVE BOOSTER WHEELS - LAY RIG MATS AROUND MP G -18 WELLHEAD - MOVE BOP FROM STAND INTO CELLAR - MOVE NEW 4 -1/2" TREE INTO CELLAR. 07:45 - 09:40 1.92 RIGU P PRE MOVE RIG OVER WELL. SET RIG DOWN AND SHIM TO LEVEL. CHINK ' UP AND BERM CELLAR. RIG UP TOP DRIVE. I AOGCC GIVEN AN UPDATE OF BOP TEST ! TIMING. 09:40 - 12:30 2.83 RIGU P PRE ' START LOADING PITS WITH 8.4 PPG 120 DEG ' 1% KCL WATER. I `* RIG ACCEPTED 10:00 * ** RIG UP CIRCULATION SKID IN CELLAR TO PREP FOR WELL KILL. PRESSURE TEST LINE TO FLOWBACK TANK AND CIRC SKID LINES TO 250 / 3500 PSI, I GOOD. 12:30 - 13:30 1.00 WHSUR P DECOMP LOAD BPV LUBRICATOR TO RIG FLOOR. 13:30 - 14:00 0.50 WHSUR P DECOMP RIG EVAC DRILL WITH DAY SHIFT. ALL PERSONNEL MUSTER AND ARE ACCOUNTED FOR. I MR AFTERWARDS. �\ 14:00 - 15:30 1.50 WHSUR P DECOMP RIG UP AND PRESSURE TEST BPV LUBRICATOR. 0 n I PULL BPV, PUT LUBRICATOR IN PIPE_SHED,--_ %\ Printed 4/1/2013 9:07:17AM • • tra�ian �5amiinary Rep Common Well Name: MPG -18 I AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 iX4- 0OXF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. I UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 18:00 2.50 f WHSUR P DECOMP PJSM THEN KILL WELLAS PER PROGRAM. BLEED OFF IA TO 0 PSI IN 10 MIN, NO FLUID SEEN. \� PUMP DOWN TUBING 8.4 PPG 120 DEG \L WATER, TAKE RETURNS UP THETA. AFTER 6 30 BBLS, NO FLUID'SEEN — , AFTER 30 BBLS, CLOSE CHOKE AND BULLHEAD 30 BBLS AT 3 BPM. FINAL BULLHEAD PRESSURE IS 600 PSI TBG, 420 PSI IA. OPEN CHOKE, CIRC 290 BBLS AT 5 BPM. GET CRUDE RETURNS BACK AT 1050 STROKES, WATER BACK AFTER 3200 STKS. FLUID COMING BACK IS 8.4 PPG. SHUT DOWN AFTER 290 BBLS CIRC. TUBING AND IA BOTH ON VAC. MONITOR FOR 30 MIN. it I i NOTE: HAD TO BLEED THE OA TWICE FROM 1000 PSI. 18:00 - 19:30 1.50 WHSUR P DECOMP RIG DOWN MANIFOLD - BLOW DOWN LINES - RIG DOWN CIRCULATING LINES & KILL I MANIFOLD I - R/U SECONDARY KILL LINE 1 - FILL TUBING AND ANNULUS WITH CHARGE PUMP, 10 BBLS C X 19:30 21:00 1.50 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW (� TO SET TWC - M/U LUBRICATOR & TEST 250 PSI LOW AND 3500 0 Ai 6 R FOR 5 MINS EACH , CHARTED - SET TWC I 21:00 - 23:00 2.00 WHSUR P WHDTRE PRESSURE TEST TWC - ATTEMPT ROLLING TEST BELOW TWC - DOWN IA WIUTH NO RESPONSE FROM GAUGES, SHUT DOWN , REPLACE SENSORS (30 BBLS KWF PUMPED) I CI - PUMP DOWN IA @ 2 BPM AND 560 PSI FOR /\ - � �) 10 MINS, CHARTED (56 BBLS KWF PUMPED) - TEST TWC FROM ABOVE : 250 PSI LOW & 3500 PSI HIGH FOR 5 MINS EACH , CHARTED 23:00 - 00:00 1.00 WHSUR P WHDTRE PJSM TO DRAIN AND NIPPLE DOWN TREE & 4 I N/U BOPE -DRAIN TREE I- NIPPLE DOWN FMC ADAPTER FLANGE & 2 19/16" , 5 M TREE ht h i CONTINUOUS HOLE FILL AT 15 BPH WITH 8.4 PPG KWF LOSSES TO WELL - DURING KILL = 340 BBLS - AFTER KILL = 111 BBLS 3/15/2013 00:00 01:00 1.00 WHSUR P WHDTRE PRE -TOUR MEETING, SPCC CHECKS - NIPPLE DOWN FMC 2 9/16" , 5 M TREE - FMC REP CLEAN AND INSPECT EUE 8RD HANGER THREADS - CONFIRM 9 TURNS BY HAND. 01:00 - 03:00 2.00 P WHDTRE PJSM, NIPPLE UP BOPE I _ - N/U 13 -5/8" BOPE STACK. Printed 4/1/2013 9:07:17AM • • • • ratan anima ry Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- OOXF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table ©63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations 03:00 - 03:30 0.50 WHSUR P WHDTRE RIG EVACUATION DRILL WITH NIGHT SHIFT. - MR - PRIMARY MUSTER AREA WAS ANNOUNCED AS 'COMPRIMISED' - ALL PERSONNEL MUSTER TO SECONDARY AND ARE ACCOUNTED FOR. - GOOD SWEEP THROUGH RIG BY DRILLER / - SCBA'S & LEL MONITORWAS AVAILABLE AND � INSPECTED IN SIGN N TRAILER G� 03:30 - 08:30 5.00 WHSUR P WHDTRE PJSM, TEST THREE PREVENTER BOPE AND Wv RELATED EQUIPMENT - TEST BOPE ACCORD(RG TO AOGCC REGULATIONS AND DOYON PROCEDURES - PERFORM ACCUMULATOR DRAW DOWN TEST. NO FAILURES. WSL WITNESSED TEST. - TEST ANNULAR WITH 2 7/8" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED 1- TEST WITH FRESH WATER - JOHN CRISP OF AOGCC WAIVED STATES RIGHT OF WITNESS BOP TEST 08:30 - 09:30 1.00 WHSUR P WHDTRE ' BLOW DOWN LINES, VAC OUT STACK, RIG DOWN TEST EQUIPMENT. 09:30 - 11:30 2.00 WHSUR P WHDTRE I PICK UP LUBRICATOR, TEST TO 250 / 3500 PSI, GOOD.. _PULL TWC AND LAY DOWN. 1 11:30 - 14:20 2.83 PULL P DECOMP I PICK UP LANDING JOINT. MAKE UP TO TOP DRIVE. BACK OUT _LOCK DOWN SCREWS. "PICK UP 85K TO UNSEAT HANGER, UP WT IS 79K, PULL TO FIRST CLAMP AND CUT CABLE. RUN BACK IN TO PLACE SLICK JOINT ACROSS BOPS. CLOSE ANNULAR AND PUMP 30 BBLS, TAKE RETURNS FROM IA. 14:20 - 16:30 2.17 PULL P DECOMP I OPEN ANNULAR. LINE UP TO FILL WELL ACROSS TOP FROM TRIP TANK. WELL TAKING 10-15 BBL /S HR. I RIG UP SPOOLING UNIT. RIG UP TRUNK THAT CABLE WILL PASS THROUGH. HANG ESP SHEAVE PREFORM TOP DRIVE AND DERRICK INSPECTION 16:30 - 22:00 5.50 PULL P DECOMP 'I POOH W/ 2/ -7/8" EUE 8RD TUBING AND ESP I ASSEMBLY POOH FROM 5,240' MD , REMOVING LASALLE CLAMPS EVERY OTHER JOINT - STAND BACK TUBING - NO CORROSION OR BAD THREADS ON TUBING 21:20 - 1 CUP GLYCOL RELEASED FROM CREW VAN, FAILURE TBD. NOTIFICATIONS MADE TO MP G PAD OPERATOR AND MP ENVIRONMENTAL Printed 4/1/2013 9:07:17AM . • er Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5 -E: DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 2/15 /2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 PULL P DECOMP PJSM TO LAY DOWN ESP ASSEMBLY - PULL ESP TO RIG FLOOR REMOVE ANNODE AND CENTRALIZER - TRACE OF CORROSION AT STAINLEES AND CARBON STEEL INTERFACE RECOVERED 89 LASALLE CLAMPS, 5 PROTECTOLIZERS, 3 FLAT GAURDS CONTINUAL HOLE FILL WITH 8.4 PPG 1% KCL AT 15 BPH I I 234 BBLS KWF LOST FOR THE DAY 3/16/2013 00:00 - 01:00 1.00 PULL P DECOMP SPCC & DERRICK CHECKS PJSM. RIG DOWN ESP TOOLS. - RIG DOWN ESP TOOLS. - RIG DOWN SHEAVE AND SPLASH GUARD FROM DERRICK. - CLEAR AND CLEAN RIG FLOOR 01:00 - 01:30 0.50 EVAL P DECOMP MAKE UP WEAR RING RUNNING TOOL - P/U RUNNING TOOL AND INSTALL WEAR RING, I.D.= 9" 01:30 - 04:30 3.00 EVAL P DECOMP PJSM, PU / MU 7 5/8" HES CHAMP PACKER } PER HES REP. I- WSL, TOOLPUSHER, HES REP. RIG CREW IN ;ATTENDANCE. j - OD. OF HES 7 5/8" CHAMP PACKER = 6.51" i- RIH ON 2 -7/8" EUE 8RD TUBING FROM I DERRICK. !- RIH TO -5130' MD CENTER OF ELEMENT. 04:30 - 05:00 0.50 EVAL P DECOMP SET 7 -5/8" HES CHAMP PACKER - 08'tTII MTAISTERTATTili MD PUW= 68 K , SOW= 62 K - WORK PACKER AT SET DEPTH OF 5130' MD ;- SET DOWN 5' & ROTATE 3 TURNS, PACKER { _ SET AT 5130' MD, CENTER OF ELEMENT 05:00 - 06:00 1.00 EVAL P DECOMP PJSM, MIT -IA, 7 5/8" L -80 29.7 # CSG BY 2 -7/8" TUBING ANNULUS. / /\ 1- CONFIRM VALVEALLIGNMENT PRIOR TO !TEST Q PUMPED 34 STKS (3 BBLS) TO / 3,250 ES) FOR 30 CHARTED MINUTES. - TESTING BEGAN AT 05:30 AM MIT -IA MEETS BP STP CRT- AK -10 -45 CRITERIA f yjVrf SEE ATTACHMENTS ---- -- -- -- 06:00 - 14:30 8.50 EVAL P DECOMP PULL 2 -7/8" 8RD EUE TUBING OUT IN SINGLES, LAY DOWN. - LAY DOWN HES PACKER. - - - - - -- -- - - - - -- -- -- - - - - -- 14:30 - 15:00 0.50 EVAL P DECOMP MAKE UP WEAR RING RUNNING TOOL - P/U RUNNING TOOLAND PULL WEAR RING 15:00 - 16:30 1.50 RUNCOM P RUNCMP _ I�,(IP TO RUN 4 -1/2" COMPLETION. - CLEAN AND CLEAR RIG FLOOR, CHANGE BAILS ON TOP DRIVE - VERIFY RUN TALLY WITH ODE. VERIFY PIPE I COUNT fN SHED. - RIG UP TORQ -TURN. 16:30 - 18:30 2.00 j RUNCOM P RUNCMP RIG UP SCHLUMBERGER EQUIPMENT - PULL SLB I -WIRE SPOOL TO RIG FLOOR I 1- RIG UP I -WIRE SPOOLER AND SHEAVES. Printed 4/1/2013 9:07:17AM • • • ration Summery Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 End Date: 3/18/2013 X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:00 0.50 RUNCOM P RUNCMP PJSM WITH RIG CREW, HALLIBURTON, SCHLUMBERGER, & WSLS - DISCUSS SPECIFIC HAZARDS FOR THE I SCOPE OF WORK - DISCUSS WORKING ON A CROWDED RIG {- FLOOR 19:00 - 20:00 1.00 RUNCOM P RUNCMP j P/U 4 1/2" 12.6# L -8_0 TC -11 JET PUMP I COMPLETION BHA M/U MULE SHOE JOINT, XN WITH RHC -M PLUG, X- NIPPLE - M/U HES 7 5/8" X 4 1/2" HES TNT PACKER BAKER LOCK ALL CONNECTIONS BELOW (PACKER I- SLB INTAKE GAUGE, HES SLIDING SLEEVE, SLB DISCHARGE GAUGE 20:00 - 22:30 2.50 RUNCOM P RUNCMP SCHLUMBERGER INSTALL I -WIRE - M/U AND TIE IN I -WIRE TO INTAKE AND DISCHARGE GAUGES - MAKE SERVICE SPLICES AND TEST TO 5000 PSI 22:30 - 00:00 1.50 RUNCOM P RUNCMP RIH WITH 4 1/2" 12.6# L -80 TC -II JET PUMP COMPLETION - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY OF I -WIRE - RIH FROM BHA TO -600' MD CONTINUAL HOLE FILL WITH 8.4 PPG KWF AT 8 BPH 24 HR LOSSES = 173 BBLS 3/17/2013 00:00 - 02:00 2.00 RUNCOM P RUNCMP PRE -TOUR MEETING, SPCC CHECKS RIH WITH 4 1/2" 12.6# L -80 TC -II JET PUMP COMPLETION - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY OF I -WIRE EVERY 1000' - RIH FROM 600' TO 1200' 02:00 - 02:30 0.50 RUNCOM P RUNCMP KICK WHILE TRIPPING DRILL. - CREW KNEW RESPONSIBILITIES AND THEIR ASSIGNED STATIONS. - SIMULATE I -WIRE CUT - STAB SAFETY VALVE, SIMULATE CLOSING AND SECURING WELL. 02:30 - 06:00 3.50 RUNCOM P RUNCMP RCMP 4 1 /2" 12 L -80 TC -II JET PUMP COMPLETION - INSTALL CANNON CLAMPS ON EVERY COLLAR - CHECK CONTINUITY OF I -WIRE EVERY 1000' RIH FROM 1200' TO 3200' ---- -- - --- - I - -- --- - - - --- 06:00 - 09:15 3.25 RUNCOM P RUNCMP I CONTINUE RIH WITH COMPLETION. MAKE UP LAST JT OF TUBING. UP WT IS 93K, SLACKOFF IS 81K. (NOTE: INCLUDES BLOCK WEIGHT OF 40K) !MAKE UP LANDING JOINT. L I INSTALLED 119 CANNON CLAMPS & 4, ONE -HALF CANNON CLAMPS Printed 4/1/2013 9:07:17AM III • North America - ALASKA - SP ; 7 Operation Summary Report Common Well Name: MPG -18 j AFE No Event Type: WORKOVER (WO) Start Date: 3/13/2013 ' End Date: 3/18/2013 1X4- 00XF5- E:DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date From - To I Hrs Task I Code I NPT NPT Depth I Phase 1 Description of Operations — (hr) i j (usft) 09:15 - 12:20 3.08 i WHSUR P RUNCMP TERMINATE I -WIRE IN HANGER AND TEST, I GOOD. PRESSURE TEST I -WIRE THROUGH HANGER, GOOD. LAND HANGER AND INSTALL LOCK DOWN I SCREWS. BACK OUT LANDING JOINT AND LAY DOWN. 12:20 - 13:00 0.67 WHSUR I P RUNCMP LINE UP TO REVERSE INTO IA TAKING RETURNS FROM THE TUBING. PRESSURE TEST THE LINES THAT WERE RIGGED UP TO THE REVERSE OUT SKID IN _ — THE CELLAR. 13:00 - 14:30 1.50 WHSUR I P I RUNCMP PJSM THEN PUMP 80 BBLS HOT WATER INTO I ANNULUS, FOLLWED BY 140 BBLS INHIBITED I WATER. TAKE RETURNS FROM TUBING. PUMP AT 5 BPM / 390 PSI. AFTER REVERSING, PUMP 3 BBLS DOWN THE TUBING TO CLEAR THE BALL SEAT. ' 14:30 16:10 1.67 WHSUR P RUNCMP I OPEN BLINDS, INSTALL LANDING JOINT. DROP BALL AND ROD WITH ROLLERS INTO I TUBING, LANDS IN XN. PRESSURE UP TO TEST TUBING, 1.7 BBLS TO I i � 3200 PSI. i INITIAL PRESSURE 3240 PSI, 15 MIN 3210 PSI I ! , 30 MIN 3200 PSI, PASS. 1 BLEED OFF TUBING TO 1720 PSI. LINE UP TO PUMP DOWN IA TO TEST. R INTITIAL PRESSURE 3250 PSI, 15 M IN3220 PSI 30 MIN 3210 PSI PASS. 16:10 - 17:00 0.83 WHSUR P RUNCMP REVIEW TEST RESULTS WITH WTL, GET I APPROVAL TO PROCEED WITH WELL PLAN. BLEED OFF TUBING PRESSURE, SHEAR OUT I DCK VALVE. PUMP THROUGH DCK VALVE BOTH WAYS TO CONFIRM SHEAR. PUMP AT 3 BPM AND 1200 PSI 1 17:00 - 18:00 1.00 WHSUR P RUNCMP SET TWO WAY CHECK I ,.FMC REP -S ET 1 I - TEST TO 1000 PSI FROM BELOW 1 1 - TEST FROM ABOVE 250 PSI LOW & 3500 PSI HIGH FOR 10 MINS CHARTED _ 18:00 - 19:00 1 1.00 BOPSUR t P RUNCMP RIG DOWN LINES - VAC OUT STACK - BLOW DOWN LINES & MANIFOLD - RIG DOWN LINES AND MANIFOL 19:00 - 20:00 1.00 BOPSUR P ` RUNCMP PJSM TO CHANGE OUT RAMS 1- ISOLATE & BLEED OFF ACCUMULATER - CHANGE FROM 2 -7/8" x 5" TO 2 -3/8" 20:00 - 21:30 I 1.50 BOPSUR P RUNCMP PJSM NIPPLE DOWN BOP ■ - N/D BOP 1 CLEAN OUT STACK AND BLOW DOWN LINES 21:30 - 00:00 2.50 WHSUR P RUNCMP ' PJSM NIPPLE UP ADAPTER AND TIE IN I -WIRE - CLEAN AND INSPECT ADAPTER AND I HANGER SEALS I _N /U ADAPTER SPOOL I - PASS I -WIRE THROUGH ADAPTER SPOOL PORT AND TERMINATE __ 24 HR LOSSES = 49 BBLS Printed 4/1/2013 9:07:17AM • • , . . . „ „ . . . . :North erica , ALASKA .151:) , I d Operation Summary Report Common Well Name: MPG -18 AFE No Event Type: WORKOVER (WO) I Start Date: 3 /13/2013 i End Date: 3 /18/2013 X4- 00XF5 -E: DRILL (1,785,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name/No.: DOYON 16 Spud Date/Time: 2/15/2004 12:00:00AM Rig Release: 3/18/2013 Rig Contractor: DOYON DRILLING INC. 9 UWI: ' Active datum: Kelly Bushing / Rotary Table @63.70usft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase ! Description of Operations _--1 (hr) H (usft) 3/18/2013 :00:00 - 01:00 1.00 WHSUR P 1 RUNCMP ; PRE-TOUR MEETING, SPCC CHECKS - NIPPLE UP ADAPTER AND TIE IN I -WIRE - SLB TEST I -WIRE CONDUCTIVITY ! I ! I AT 00:00, NOTIFY AOGCC OF UPCOMING BOP TEST ON MPG -02. SUBMIT ONLINE FORM FROM AOGCC WEBSITE. 01:00 - 02:00 1.00 WHSUR P RUNCMP I PRESSURE TEST ADAPTER I- PT HANGER SEALS & VOIDS 250 PSI LOW FOR 5 MINS, 5000 PSI HIGH FOR 30 MINS CHARTED 02:00 - 04:00 2.00 WHSUR P RUNCMP ; PJSM , INSTALL TREE - N/U CAMERON 4- 1/16" 5M TREE TEST TREE 250 PSI LOW AND 5100 PSI HIGH FOR 5 CHARTED MINS EACH 04:00 - 05:30 1.50 WHSUR P ; RUNCMP ' PJSM, RIG UP LUBRICATOR I- STAB ON LUBRICATOR ON TREE ! - PT 250 PSI LOWAND 3500 HIGH FOR 5 MINS I EACH PULL TWO WAY CHECK I- RIG DW ON LUBRICATOR 05:30 - 07:00 1.50 WHSUR P RUNCMP ; PJSM WITH LITTLE RED SERVICES FOR FREEZE PROTECT OF WELL RIG UP LRS PUMP TRUCK AND LINES. I PRESSURE TEST LRS LINES, GOOD. 07:00 - 09:20 2.33 WHSUR P RUNCMP !REVERSE IN 100 BBLS DIESEL INTO IA, !TAKING RETURNS FROM TUBING. CIRC AT 2 BPM / 800 PSI INTIALLY, 2 BPM 1000 PSI FCP. SHUT DOWN AND ALLOW TO U -TUBE FOR 1 HR. 09:20 - 10:20 1.00 WHSUR P RUNCMP ,j INSTALL BPV LUBRICATOR AND PRESSURE TEST 250 / 3500 PSI, GOOD. !SET BPV. 10:20 - 12:00 1.67 WHSUR P RUNCMP ! LRS PRESSURE TEST BPV FROM IA SIDE, !PUT 1000 PSI UNDER BPV. GOOD TEST. I !INSTALL GAUGES ON TREE. ' !CLEAN UP CELLAR AREA, PREP TO MOVE !RIG. ! * ** RELEASE RIG AT 12:00*** ALL FURTHER ENTRIES TODAY ON MPG-02 Printed 4/1/2013 9:07:17AM Tree: 4 1/16" - 5M CIW 0 F elev. = 34.00' (Doyon 14) Wellhead: 5M Gen 5 MPG-18 ! L1 U uL. elev.= 29.70' (Doyon 14) 11" x 11" w/ 4 1/6" TC -II T &B Hanger 4.5" CIW "H" BPV profile A 2' Blast Casing tested to 3250 psi from I 5130' during 3/16/13 RWO. 20' 178 #/ft .875 thick Driven conductor 1 120' l SLB 4 1/2" x 1" KGB -2 2510' 1 Gas lift mandrel 10 3/4" 45.5 ppf L -80 BTC 1 3,226' , ■ KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 4.5 ", 12.6 #, L -80 TC -II Tbg. C SLB NDPG -C Discharge Gauge 4950' I ( cap. = .0152 bpf, id = 3.958) 3.958" ID TVD = 3913' 7 5/8" 29.7 ppf, L -80, BTC -M Casing • • • HES 4 1/2" XD Duro Sleeve 4962 (drift ID = 6.750 ", cap. = 0.0459 bpf) 3.813 Packing Bore ID (cap w/ 4 1/2" Tbg inside = bbf) SLB NDPG -C Intake Gauge 4972' 3.958" ID TVD= 3926' HES 7 5/8" x 4 1/2" TNT Packer 1 5039' LJ HES 4 1/2" X Nipple 5079 I J__ 3.813 Packing Bore ID HES 4 1/2" XN Nipple 5150' I 3.813 Packing Bore ID / 3.725" No -Go ID WLEG (bottom) 1 5204' I Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Hanger outside Wall 7" Window 5,290' Window in 7" Casing @ 5,278' - 5,290' 61/8" Hole td @ 8,563' Well Angle @ window = 54° 4— 75 jts. - 4 1/2" Slotted Liner Ra27 ole OA Upper Lateral 12.6# L -80 IBT (5,380' - 8,490') Btm Baker 4 1/2" Guide Shoe 8,536' Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7 -5/8" x 5 -1/2" HMC Liner Hanger 5,351' - A - Baker 4 1/2" CIBP set @ 5400' 7 5/8" Halliburton Float Collar 5,476' 6 1/8" Hole td @ 8,421' 7 5/8" Halliburton Float Shoe 5,560' 4 OB Lower Lateral 69 jts. - 4 1/2 ", 12.6# L -80, IBT \` Slotted Liner (5,531' - 8,377') Btm Baker 4 1/2" Float Shoe 8,421' DATE REV. BY COMMENTS M I LN E POINT UNIT 04/03/04 MDO Drilled & Completed Doyon 14 WELL MPG-18 05/19/06 MDO ESP RWO Tbg. change out N -3S 6 -9 -08 REH ESP RWO - Nabors 3S API NO: 50 - 029 - 23194 - 8 -31 -08 REH ESP RWO - Nabors 4ES API NO: 50 - 029 - 23194 - 3/16/13 Hulme Covert to Jet Pump - Doyon 16 BP EXPLORATION (AK) STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO SSION 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 Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -® Development ^ Exploratory 204-021 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-60-00 - 7. KB Elevation (tt): KBE = 63 70' , 9. Well Name and Number. . MPG-18L1 - 8. Property Designation: 10. Field /Pool(s): - ADL 025906 - Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8563 - feet true vertical 4145 - feet Plugs (measured) N/A Effective depth: measured 8563 feet Junk (measured) N/A true vertical 4145 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191" 10-3/4" 3226' 2424' 5210 2480 Intermediate Production 5245' 7-5/8" 5278' 4108' 6890 4790 Liner 3263' 4-1/2" 5273' - 8536' 4105' - 4145' 8430 7500 Perforation Depth MD (ft): Slotted 5380' - 8490' Perforation Depth TVD (ft): Slotted 4157' - 4145' 2-7/8", 6.5# L-80 5245' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 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: 8 138 1626 320 219 Subsequent to operation: 10 180 2423 280 228 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well 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 Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist ~ Prepared By Name/Number: Si ature Phone 564-4750 Dat -~-(~~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 Submit Original Only ~~ ~ gam.,, s "" I~ ~ ~ ~ ~ ~~ ~ 1 ~ ~~~~t~ ~ ~ ~ _? Tree: 2-9/16" - 5M FMC • C F elev. = 34.00' (Doyon 14) Wellhead: 5M Gen 5 MPG' 18 O~L. elev.= 29.70' (Doyon 14) 11"x 11" w/ 2-7/8" 8rd T&B Hanger 2.5" CIW "H" BPV profile ~-~r~~ 20` 178 #/ft .875 thick Driven conductor 11 20' I Camco 2-7/8" x 1" w/ BK latch 137` sidepocket KBMM-2 GLM 10 3/4" L-80 Float Shoe 3,226` Camco 2-7/8" x 1" w/ BK latch 4,979' KOP @ 460` sidepocket KBMM-2 GLM 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' ~ 2-7/8" HES XN-Nipple 2.313" bore 5,131' (2.250"no-go) Centrilift ESP 5,184` 10 3/4" 45.5 ppf L-80 BTRC 130-P21/SXD (Drift ID = 9.794, cap. _ .0961 bpf) ° ° Centrilift tandem gas sep. 203' 5 7 5/8" 29.7 ppf, L-80, BTRC-mod production casing , GRSFTXARH6 ( drift ID = 6.750", cap. = 0.0459 bpf) Centrilift tandem seal section 208` 5 4.5", 12.6#, L-80 IBT tbg. , GSB3DBUT SB/SB PFSA ( cap. _ .0152 bpf, id =3.958) GSB3DBLT SB/SB PFSA 2-7/8" 6.5# L-80 EUE 8rd tubing Centrilift KMH series 5,221` (drift ID = 2.347", cap. = 0.0058 bpf) 190 hp. motor, 2415 v/48 amp Centrilift Pumpmate XTO Sensor 5,238` (~ O 6 Fin Motor centrilizer and sacfrificial 5,240' U Anode. Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' Window in 7" Casing @ 5,278' - 5,290' s va° Hole td @ a,5s3' Well Angie @ window = 54° 75 jts. - 4 1/2" Slotted Liner R ~~ ole OA Upper Lateral 12.6# L-80 IBT (5,380`- 8,490') Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1 /2" HMC Liner Hanger 5,351' 7 5/8" Halliburton Float Collar 5,476 7 5/8" Halliburton Float Shoe 5,560 Btm Baker 4 1/2"Guide Shoe 8,536` ~~_ Baker 4 1/2" CIBP set @ 5400' 6 1/8" Hole td @ 8,421' OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT Slotted Liner (5,531'- 8,377') 8tm Baker 4 1/2" Float Shoe 8,421' DATE REV. BY COMMENTS 04/03/04 MDO Drilled & Completed Doyon 14 05/19/06 MDO ESP RWO Tbg. change out N-3S 6-9-08 REH ESP RWO -Nabors 3S 8-31-08 REH ESP RWO -Nabors 4ES MILNE POINT UNIT WELL G-18 API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) 3 ~~.~~~ ''~-~~c.~`s~'o~ ~` Page '1 of 1 • • Well: MPG-18 Well History Well Date Summary MPG-18 8/26/2008 ***WELL SI ON ARRIVAL*** (pre rwo) TRAVELED TO MILNE POINT FROM PRUDHOE ***CONT WST ON 8-27-08*** MPG-18 8/26/2008 T/I/0=200/280/40 Freeze ProtecUlnjectivity Test (Pre-RWO) Pumped 35 bbls diesel down tubing for injectivity test and freeze protect, caught fluid C~ 24 bbls away and established injectivity rate C~ 1.7 bpm C~ 2000 psi. Pumped 2 bbls 60/40 methanol, 3 bbls Diesel, and 2 bbls 60/40 methanol down production and test flowlines. Closed lateral valves and bleed pressure down to 20 psi. FWHP=200/280/40 Swab,wing, ssv closed. Master,lA, and OA open. MPG-18 8/26/2008 ***WELL SI ON ARRIVAL*** (pre rwo) TRAVELED TO MILNE POINT FROM PRUDHOE ***CONT WST ON 8-27-08*** MPG-18 8/27/2008 The Well Support Techs rigged up and removed the wellhouse flowlines and foundation. They then set the BPV after the slicklie work was completed. NOTE: The BPV is IN and the well is ready for the rig!!!!!!!! MPG-18 8/27/2008 ***CONT WSR FROM 8-26-08*** (pre rwo) FISH TOOL STRING FROM 5148' SLM (SWIVELED OFF RIH), RECOVERED ALL TOOLS PULL 1" BK-DMY GLV FROM 4981' MD, LEFT POCKET OPEN PULL 1" BK-DPSOV FROM 139' MD, SET 1" BK-DMY GLV ASSIST VALVE CREW W/BPV ***WELL S/I ON DEPARTURE, NOTIFY DSO*** MPG-18 8/30/2008 ***SURFACE WORK NABORS 4ES*** PULLED 1" BK-DGLV, RESET 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM (marked) SET 1" BEK-DPSOV IN SPM TO BE RUN ON TOP (marked and flagged) ***JOB COMPLETE, NOTIFIED COMPANY REP AND TOOLPUSHER OF MANDREL CONFIGURATION*** MPG-18 9/2/2008 Tfl/0=0/25/0 Freeze Protect (Post RWO) Pumped 25 bbls 60/40 methanol and 15 bbls Dead Crude down tubing. Pumped 9 bbls Neat Methanol and 65 bbls Dead Crude down IA. FWHP=0/20/0 Master, Swab, SSV, and Wing Closed. IA and OA open. MPG-18 9/2/2008 The Well Support Techs rigged up and set the foundation, installed the flowlines and wellhouse. They then pulled the back pressrue valve and leak tested the flowlines to 1150 psi. NOTE: The BPV was left OUT and the Leak test was GOOD!!!! Print Date: 9/25/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Event Name: WORKOVER Start: 8/27/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: i i i ~ I Date ~ From - To I Hours Task I Code I NPT 8/28/2008 102:00 - 04:00 2.00 MOB P 04:00 - 06:00 2.00 MOB N WAIT 06:00 - 10:30 4.50 MOB P 10:30 - 11:30 1.00 RIGU P 11:30 - 15:00 3.50 RIGU P 15:00 - 15:30 I 0.501 RIGU I P 15:30 - 16:30 1.00 WHSUR P 16:30 - 17:00 I 0.501 KILL I P 17:00 - 19:30 I 2.501 KILL I P 20:00 - 21:00 I 1.001 WHSUR I P 21:00 - 23:00 I 2.00 WHSUR P 23:00 - 00:00 I 1.001 BOPSUFi P 8/29/2008 00:00 - 01:00 1.00 BOPSUF~ P 01:00 - 01:30 0.50 BOPSU P 01:00 - 07:30 6.501 BOPSUp P 07:30 - 08:00 I 0.501 WHSUR I P 08:00 - 09:00 I 1.001 PULL I P Page 1 of 3 Spud Date: 2/15/2004 End: Phase Description of Operations PRE PJSM. Scope and lay over derrick. Prepare to move off of MPU H-09. Clear location and prep rig for move. PRE Wait on trucks. PRE Move rig and components from MPF pad to MPG pad. PRE Spot sub over well. Spot pipe shed and pits. PRE PJSM on raising and scoping derrick. Raise and scope derrick. Rigging up circulating lines to tree and I/A and to blowdown tank. "ACCEPT RIG ~ 15:00-HRS.'* PRE Pre-spud meeting to discuss plan forward and scope of workover. DECOMP Make up lubricator to swab valve. P/T lubricator to 500-psi. MPU Well Support pull BPV. lay down lubricator. Take on fluid to pits. DECOMP PJSM -Killing well at MPU. SITP = 450-psi, SICP = 500-psi, OAP = 500-psi. Notified pad operator and MPU Front Desk of gas venting. Bled tubing and IA off to blowdown tank. DECOMP Bullhead 35-bbls 1 %KCI down Tbg ~ 4.0-BPM ~ 110-psi. Bullhead 300-Bbls. 1%KCI down IA ~ 4-BPM ~ 175-psi. Bullhead 35-Bbls. down Tbg ~ 3.6-BPM ~ 70-psi. Monitor well for 30-minutes. Tbg on vac. Bleed IA from 90-psi to 0-psi, OA at 0-psi. DECOMP FMC wellhead tech T-bar in TWC. Test TWC above to 3500-psi. Hold and chart test for 10-minutes. Good test. Attempt to test TWC below to 500-psi. Unable to get any pressure below TWC. Bullhead 40-bbls to formation pumping at 6-bpm with 144-psi. DECOMP PJSM -Lower beaver slide and ND tree. Lower the beaver slide and ND production tree. FMC wellhead tech bleed pressure off of test ports. Move tree out of cellar. Inspect hanger threads. Fill well with 30-BPH while ND tree. DECOMP PJSM - NU BOP stack. NU BOP stack, Choke & Kill lines, Riser. Fill well with 30-BPH while NU Stack. DECOMP Continue NU BOP stack, choke & kill lines, riser. DECOMP RU to test BOPE. MU test jt. Fill BOP stack. Inspect Koomey and choke manifold. PJSM -Testing BOPE. DECOMP Test BOPE per BP and AOGCC procedures. Tested all BOPE components to 250-psi for low pressure test and 3500-psi for high pressure test. Held and charted all tests for 5-minutes. Test 2-7/8" x 5" VBR's and Hydril GX annular preventer using 2-7/8" donut test jt. Witness of BOP test waived by AOGCC rep Chuck Scheve. All tests witnessed by BP WSL and Nabors TP. Troubleshoot pressure bleed off in high pressure tests. Tighten LDS. Rig down BOPE test equipment. DECOMP PJSM -Pull TWC. Make up Lopso-Opso to tubing hanger. Make up lubricator to Lopso-Opso. P/T lubricator/lopso-Opso to 500-psi. MPU Well Support pull TWC. Lay down Lubricator and Lopso-Opso. Tubing and IA on vacuum. DECOMP PJSM -Unland tubing hanger. Make up 2-7/8" 8RD. landing joint w/closed TIW valve. Screw landing joint into tubing hanger. BOLDS. Unland and hoist hanger to floor. P/U wt. _ 50K. Centrilift disconnect ESP cable and FMC pull wellhead penetrator from hanger. Open TIW valve and confirm tubing dead. Break out and lay down hanger, landing joint and TIW Printed: 9/15/2008 3:34:02 PM • • BP EXPLORATION Page 2 of 3 ' Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 8/27/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours' Task ', Code NPT .Phase Description of Operations 8/29/2008 08:00 - 09:00 1.00 PULL P DECOMP 09:00 - 10:30 1.50 PULL P DECOMP 10:30 - 11:00 0.50 PULL N WAIT DECOMP 11:00 - 15:00 4.00 PULL P DECOMP 15:00 - 16:00 1.00 PULL P DECOMP 16:00 - 16:30 0.50 PULL P DECOMP 16:30 - 17:30 1.00 BOPSU P DECOMP 17:30 - 18:00 0.50 BOPSU P DECOMP 18:00 - 19:00 1.00 BOPSU P DECOMP 19:00 - 21:30 2.50 DHB P DECOMP 21:30 - 00:00 2.50 DHB P DECOMP 8/30/2008 00:00 - 01:30 1.50 DHB P DECOMP 01:30 - 03:30 2.00 DHB P DECOMP 03:30 - 04:30 1.00 DHB P DECOMP 04:30 - 06:00 1.50 DHB P DECOMP 06:00 - 06:30 0.50 BUNCO RUNCMP 06:30 - 10:00 3.50 BUNCO RUNCMP valve. Pull ESP cable over cable sheave and through containment hose to cable spooler. POH w/ESP completion standing 2-7/8" tubing in derrick and spooling ESP cable to empty reel in cable spooler. Filling hole at rate of 30-BPH with MPU produced water while POH. BP ESP cable spooler malfunctioning. Repaired same. POH w/ESP completion standing 2-7/8" tubing in derrick and spooling ESP cable to empty reel in cable spooler. Filling hole at rate of 30-BPH with MPU produced water while POH. Centrilift disconnect motor lead flat cable from ESP motor, drain seal sections and stand ESP BHA back in derrick. Attached rope to and pulled ESP cable over cable sheave to cable spooler. Clear and clean rig floor and rig down ESP pulling equipment and tools. Nippled down flow nipple and air boots. Pre-tour safety meeting. Service rig, inspect derrick and check alarms. Nippled up shooting flange to top of annular preventer. Spot E-line unit. PJSM with Schlumberger crew and Baker hand regarding upcoming logging. PU & RU Schlumberger GR/CCL logging tools, gauge ring, junk basket, lubricator and packoff. Fill lubricator and pressure test to 500-psi. Good test. RIH with Schlumberger logging tools, gauge ring and junk basket. Zero tools at rig floor and log going in hole. Identify fluid level at 2050'. Tag OA lateral liner top at 5,255'. Continue in hole and sit down on OB lateral liner top at 5,317'. Unable to pass thru liner top. Discuss with rig leadership and Schlumberger, decide run CIBP with extra centralization and attempt to get thru OB lateral liner top with CIBP. POH, logging to surface for correlation. Schlumberger a-line continue POH, logging to surface. Change out E-line tools. MU 4-1/2" CIBP and setting tool. MU Schlumberger lubricator. RIH with 4-1/2" CIBP on E-line. Identify OA lateral liner top at 5255' (match initial gauge ring log) and OB lateral liner top at 5317' (where gauge ring sat down on initial run). Work a-line tool string into 4-1/2" liner in OB lateral. Able to log down to 5442' (middle of 3rd full jt of blank pipe). PU and position setting tool to set CIBP at 5400' (middle of second blank joint from top of OB lateral liner). Fire setting tool. Tool fired with 21-second delay. Good indication of set with line movement and line tension drop off. Log up to OA lateral liner top for correlation. Schlumberger a-line POH to surface. No plug at surface. RD Schlumberger a-line tools and lubricator. ND shooting flange and NU flow nipple. Pre-tour HSE meeting with day crew. Service rig, daily derrick inspection, check PVT's and environmental walkaround. Centrilift make up and service ESP BHA. Pull ESP cable over cable sheave. Connect cable to motor. Printed: 9/15/2008 3:34:02 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Event Name: WORKOVER Start: 8/27/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/31/2008 Rig Name: NABOBS 4ES Rig Number: ~ ~ ~ ~ Date 'From - To Hours Task Code NPT ___ -_ 8/30/2008 10:00 - 16:00 6.00 ~ BUNCO 16:00 - 17:30 1.50 ~ RUN 17:30 - 18:00 I 0.501 RUN 18:00 - 19:00 I 1.001 RU 19:00 - 20:00 1.001 RU 20:00 - 20:30 I 0.501 RUN 20:30 - 22:00 1.50 BOPSU~ P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 ~ 1.00 ~ WHSUR ~ P 8/31/2008 100:00 - 02:00 I 2.001 WHSUR I P Page 3 of 3 Spud Date: 2/15/2004 End: Phase Description of Operations RUNCMP RIH w/ESP completion on 2-7/8" tubing from derrick per running order. Filling hole at 30-Bbls. per hour, checking ESP cable every 2000' and pumping through ESP. Install 89-LaSalle clamps, 5- Protectrolizers, 3- Armsterguards. PU wt = 43 K-Ibs, SO wt = 34 K-Ibs. RUNCMP MU tubing hanger and landing jt to tubing string w/ closed TIW valve. MU final ESP cable splice. FMC tech install penetrator in tubing hanger. RUNCMP Pre-tour HES meeting with night crew. Service rig, perform derrick inspection, location walkaround and PVT checks. RUNCMP Centrilife complete final ESP cable splice, install in hanger and verify cable is functional. Land tubing hanger in tubing spool. FMC tech RILDS. RUNCMP FMC tech dry rod in TWC. Test TWC from above to 3000-psi for 10-charted minutes. Test TWC from below by establishing stable injection rate. Pump at 3.5-BPM with 50-psi for 10 minutes. Chart test. Both tests good. RUNCMP Safety standdown with Smith's crew, Nabors TP and BP WSL. Focus on BP's 8 golden rules, where they came from, and what they mean to daily operations. RUNCMP Drain BOP stack and ND. Disconnect choke and kill lines. Stand BOP stack back and secure on traveling pedestal. RUNCMP PJSM on PU and NU tree. NU production tree. MPU G-pad operator verify alignment of tree in relation to production lines. FMC wellhead tech test hanger void for 30-minutes to 5000-psi - Good test. Centrilift perform final check of ESP cable -Good test. Fill tree with diesel and test to 5000-psi -Good test. RUNCMP FMC wellhead tech test hanger void for 30-minutes to 5000-psi - Good test. Centrilift perform final check of ESP cable -Good test. Fill tree with diesel and test to 5000-psi -Good test. RUNCMP PU MPU well support lubricator and pressure test to 500-psi. Good test. Pull TWC with lubricator. No pressure under TWC. Lubricate in BPV and test below. Bullhead 37-Bbls of produced water to formation at 4-BPM seeing 50 to 75-psi for 10 minutes. Secure cellar and well. **Release Rig at 0200-hrs on 8/31/08.** Printed: 9/15/2008 3:34:02 PM STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMf~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: j - -; ^ Abandon ®Repair Well - ^ Plug Perforations ®Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ' ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-021 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-60-00 - 7. KB Elevation (ft): KBE = 63.70' 9• Well Name and Number: MPG-18L1 8. Property Designation: 10. Field /Pool(s): ADL 025906 ' Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8563 feet true vertical 4145 ' feet Plugs (measured) N/A Effective depth: measured 8563 feet Junk (measured) N/A true vertical 4145 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191" 10-3/4" 3215' 2424' 5210 2480 Intermediate Production 5245' 7-5/8" 5278' 4108' 6890 4790 Liner 3263' 4-1 /2" 5273' - 8536' 4105' - 4145' 8430 7500 ~~:~N~~ JUL ~ ~ 2008 Perforation Depth MD (ft): Slotted 5380' - 8490' Perforation Depth TVD (ft): Slotted 4157' - 4145' 2-7/8", 6.5# L-80 5246' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Acid Treatment (05/11/2008) Attached Well Service Report and Well History Report. 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: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well 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 'rf C.O. Exempt: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist ~ t d~ __ // Prepared By Name/Number: Si ature ~~ Phone 564-4750 Date~~'l~-(~(Sondra Stewman, 564-4750 n t~ ~~~ ~ avl~ ~ L~ii~ ,~ ;~ ~~_.~ ~ Form 10-404 Revised 04/2006 Submit Original Only '~~~ ~ ~ f3F~ .~~lz ~ ~ 20D6 ~, ~.-8.~8 Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 11"x 11" w/ 2-7/8" 8rd T&B Hanger 2.5" CIW "H" BPV profile I I Z' 20' 178 #/ft .875 thick Driven conductor 10 3/4" L-80 Float Shoe KOP @ 460` 43+ degree from 1,500' Max hole angle = 63 degree @.2,200` 10 3/4" 45.5 ppf L-80 BTRC (Drift ID = 9.794, cap. _ .0961 bpf) 7 5/8" 29.7 ppf, L-80, BTRC-mod production casing ( drift ID = 6.750", cap. = 0.0459 bpf ) 4.5", 12.6#, L-80 IBT tbg. ( cap. _ .0152 bpf, id =3.958 ) 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap. = 0.0058 bpf ) Window in 7" Casing @ 5,278' - 5,290' Well Angle @ window = 54° Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' 7 5/8" Halliburton Float Collar 5,476' 7 5/8" Halliburton Float Shoe 5,560' MPG- I C~~l~` O~L.eeeev.= 29.070' (Doyon 14) Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) Centrilift ESP 130-P21 /SXD Centrilift tandem gas sep. GRSFTXARH6 Centrilift tandem seal section GSB3DBUT SB/SB PFSA GSB3DBLT SB/SB PFSA Centrilift KMH series 190 hp. motor, 2415 v/48 amp Centrilift Pumpmate XTO Sensor 6 Fin Motor centrilizer Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 6 1/8" Hole td @ 8,563` 139' 4,981 ` 5,132` 5,185' 5,204' 5,209` I 5,223' 5,240` 5,241' 75 jts. - 4 1/2" Slotted Liner RaZ~ ole OA Upper Lateral 12.6# L-80 IBT (5,380`- 8,490') Btm Baker 4 1/2" Guide Shoe 8,536` 6 1/8" Hole td @ 8,421' OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT Slotted Liner (5,531 `- 8,377') Btm Baker4 1/2" Float Shoe 8,421' DATE REV. BY COMMENTS 04/03/04 MDO Drilled & Completed Doyon 14 05/19/06 MDO ESP RWO Tbg. change out N-3S 6-9-08 REH ESP RWO -Nabors 3S MILNE POINT`UNIT WELL G-18\L-~ API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) BP EXPLORATION Page 1 of 2 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 6/7/2008 End: 6/9/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/9/2008 Rig Name: NABORS 3S Rig Number: Date !From - To Hours ~~ Task Code NPT Phase Description of Operations 6/6/2008 6/7/2008 6/8/2008 22:00 - 22:30 0.50 MOB P PRE Rig down floor and prep to lower mast. 22:30 - 00:00 1.50 MOB P PRE Scope down mast, lower mast onto carrier and secure. 00:00 - 02:00 2.00 MOB P PRE Unhook lines between components. Remove berming from around rig and prepare to move rig. 02:00 - 03:00 1.00 MOB P PRE Move pipeshed off of mats and stage on location. Move pits away from carrier. Move carrier off of MPA-02. Pad Operator and WSL were present when moving off well. 03:00 - 04:00 1.00 MOB P PRE Move from MPA-Pad to Tract 14 road to MPG-Pad. 04:00 - 06:00 2.00 MOB P PRE Stage components on MPG-Pad and prep to lay mats and herculite. Spot BOPE Cradle behind the well. 06:00 - 07:30 1.50 RIGU P PRE Lay mats around well slot MPG-18 and herculite for the Carrier. 07:30 - 11:30 4.00 RIGU P PRE Back the Carrier over well slot MPG-18 with the Pad Operator, WSL and Toolpusher present. Repeat several times to allow proper spacing of Pipe Shed and Pits due to tight location and soft pad due to rain and meltwater. Jack and level the Carrier. Lay mats and Herculite and spot the Pipe Shed and Pits. 11:30 - 17:00 5.50 RIGU P PRE Connect the Pipe Shed and Pits to the Carrier. Spot, berm and RU the Tiger Tank with Prudhoe Well Support Techs. Raise and scope the Derrick at 14:00 hrs. RU circulating lines to the Tree. The Rig was accepted at 15:30 hrs on 6/7/2008. Continue rigging up to kill the well. 17:00 - 18:00 1.00 KILL P DECOMP Pressure test surface lines to 3,500 psi. Pressure test hardline to tiger tank to 500 psi. Good test. 18:00 - 19:30 1.50 KILL P DECOMP R/U lubricator and pressure test to 500 psi with diesel. Pull CIW 2-1/2" Type H BPV. 260 psi on the tubing and 240 psi on the IA. 0 psi on the OA. UD lubricator. 19:30 - 20:30 1.00 KILL P DECOMP Bleed off gas, came off quickly. Pump 35 bbls of 140 degree, 8.45 ppg seawater down tubing lined up to take returns out the IA through the choke manifold to the tiger tank. Pump at 3 bpm with 80 psi, no returns. 20:30 - 23:00 2.50 KILL P DECOMP Bullhead 300 bbls of 140 degree, 8.45 ppg seawater down IA at 3 bpm with 70 psi pump pressure. 23:00 - 23:30 0.50 KILL P DECOMP Bullhead 35 bbls of 140 degree, 8.45 ppg seawater down tubing at 3 bpm with 110 psi. 23:30 - 00:00 0.50 KILL P DECOMP Monitor well, 0 psi on tubing, 0 psi on IA and 0 psi on OA. Both tubing and IA are on a vacuum. 00:00 - 00:30 0.50 KILL P DECOMP Blow down and R/D circulating lines. 00:30 - 01:00 0.50 WHSUR P DECOMP FMC tech installed 2-1/2" CIW Type H TWC with T-bar. Test TWC to 3,500 psi for 10 minutes on the chart. 01:00 - 02:00 1.00 WHSUR P DECOMP N/D Tree, clean and inspect wellhead. Inspect hanger threads and lock down screws. Gravity feed IA with 30 bph of seawater. 02:00 - 05:30 3.50 BOPSU P DECOMP N/U 13-5/8" 5M BOP Stack. Hook up choke line, kill line and koomey lines. Hook up turnbuckles and install riser. Gravity feed IA with 30 bph of seawater. 05:30 - 06:30 1.00 BOPSU P DECOMP Function test BOPE, fill stack and choke manifold. 06:30 - 11:00 4.50 BOPSU P DECOMP Pressure test BOPE to 250 / 3,500 psi per BP / AOGCC Regulations. The state's right to witness the test was waived by Chuck Scheve. All tests witnessed by WSL and Toolpusher. The VBR's and Annular were tested with 2-7/8" Test Joint. 11:00 - 12:30 1.50 WHSUR P DECOMP PUMU Opso Lopso with 2-7/8" EUE 8rd XO. PUMU Lubricator and Polished Rod with Well Support Techs. Pressure test to 500 psi with diesel -good. Pull 2" Type "H" TWC -the well is Printed: 7/1/2008 3:07:39 PM BP EXPLORATION Operations Summary Report Page 2 of 2 Legal Well Common W Event Nam Contractor Rig Name: bate Name: ell Name: e: Name: From - To MPG-18 MPG-18 WORKO NABOB NABOB Hours VER S ALASK S 3S Task DRI Code LING II NPT Start I Rig Rig Phase Spud Date: 2/15/2004 : 6/7/2008 End: 6/9/2008 Release: 6/9/2008 Number: Description of Operations 6/8/2008 11:00 - 12:30 1.50 WHSUR P DECOMP on a vacuum. LD Lubricator and Polished Rod. LD Opso Lopso. 12:30 - 14:30 2.00 PULL P DECOMP PU Landing Joint with TIW Valve and screw into the Hanger with 10 turns. BOLDS with FMC rep. Check the IA and it is on a vacuum. Pull the Hanger off seat with 60K and pull to the floor with 55K. Pump 30 bbls (tubing volume) of seawater down the Tubing at a rate of 4 bpm / 150 psi. LD the Hanger and Landing Joint. 14:30 - 20:00 5.50 PULL P DECOMP Cut the ESP Cable at the Penetrator and tie onto rope. Pull the rope over the Sheave. POOH with existing 2-7/8", 6.5#, L-80, EUE 8rd Tubing ESP Completion standing back in the Derrick. Maintain 30 bph fill rate while POOH. Replaced five joints due to galled threads. No indication of scale on any of the Tubing. 20:00 - 22:30 2.50 PULL P DECOMP B/O and VD ESP assembly. There was moderate pitting on ESP body where cable was laying. Maintain 30 bph fill rate. Recovered 89 Lasalle clamps, 5 protectolizers and 3 flat guards. 22:30 - 00:00 1.50 PULL P DECOMP Clear and clean rig floor. R/D containment trunk. 6/9/2008 00:00 - 03:00 3.00 BUNCO RUNCMP P/U ESP assembly, service and fill with oil. Attach power cable to ESP and check conductivity. Maintain 30 bph fill rate. 03:00 - 08:30 5.50 BUNCO RUNCMP RIH with ESP on 2-7/8", 6.5#, L-80, EUE 8rd tubing. Use Best-O-Life 2000 pipe dope. Maintain 30 bph fill rate. Ran a total of 163 Joints of 2-7/8" Tubing, 90 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. 08:30 - 09:00 0.50 BUNCO RUNCMP Flush the ESP a final time at a rate of 0.75 bpm / 300 psi. 09:00 - 09:30 0.50 BUNCO RUNCMP PUMU Landing Joint and Tubing Hanger. Install Penetrator and orient per FMC rep. Cut the ESP Cable and tail over the Sheave. Obtain final PUW = 50K ,final SOW = 33K. 09:30 - 11:00 1.50 BUNCO RUNCMP Perform ESP Penetrator splice with Centrilift rep. 11:00 - 11:30 0.50 BUNCO RUNCMP Land Tubing Hanger and RILDS with FMC rep. 11:30 - 12:30 1.00 WHSUR P RUNCMP PU T-bar and set 2" Type "H" TWC with FMC rep. Pressure test from above to 3,500 psi for 10 charted mins -good. Unable to test from below due to vac. 12:30 - 15:30 3.00 BOPSU P RUNCMP ND 13-5/8" BOPE and DSA. Set in Cradle and remove from Cellar. 15:30 - 18:00 2.50 W HSUR P RUNCMP N/U adaptor flange and 2-9/16" tree. Test hanger void to 5,000 psi for 30 minutes. Test tree to 5,000 psi with diesel. 18:00 - 20:00 2.00 WHSUR P RUNCMP i3/U lubricator and test to 500 psi, pull 2-1/2" CIW Type H TWC and set CIW Type H BPV. Secure well and cellar. Rig released at 20:00 hours on 6/9/2008 Printed: 7/1/2008 3:07:39 PM Digital Well File ~ Page 1 of 1 • Well: MPG-18 Well History Well Date Summary MPG-18 4/26/2008 T/I/0=300/310/40. (MIT T to 2000 psi.). Load tbg w/ 15 bbls diesel. MIT T to 2000 psi. Passed. Lost 10 psi in first 15 minutes & 0 psi in second 15 minutes. Total loss of 10 psi. Bleed tbg pressure down to 300 FWH P=300/310/40. MPG-18 4/26/2008 *** WELL FLOWING ON ARRIVAL **** TUBING TEST PULL DPSOV @ 138' SET DUMMY VALVE @ 138 SLM RAN2.313 CAT STANDING VALVE C~3 5138' SLM PRESSURE UP TO 2000 PSI FOR 30 MIN GOOD TEST PULL CAT PULL DUMMY @ 138' SLM SET DPSOV C~ 138' ***JOB COMPLETED *** MPG-18 5/3/2008 ASRC Test Unit #5, Move unit to MPG-pad, S/B for bed truck, Start R/U, ***Job in progress*** MPG-18 5/4/2008 ASRC Unit #5, 6 hour test **job complete** MPG-18 5/6/2008 T/I/0= 220/200/180 (IA Flush) Pumped 90 bbls Dead Crude down IA while well was online. FWHP= 220/180/280 ** Annulus valves open to gauges ** MPG-18 5/8/2008 ASRC Unit #5, divert well, stabilize, start test **job in progress** MPG-18 5/9/2008 ASRC Unit #5, 6 hour test **job complete** MPG-18 5/11/2008 T/I/0=260/260/280 Acid Treatment Pumped 20 bbls Dead Crude down tubing for infectivity. Followed by 10 bbls 7.5% DAD Acid, 3 bbls 60/40 methanol and 18 bbls Dead Crude for displacement. FWH P=200/180/0 MPG-18 6/3/2008 T/I/0=240/240/240 (Freeze Protect) Pumped 15 bbls Diesel down tubing. Pumped 2 bbls 60/40 methanol, 3 bbls diesel @ 90*F and 2 bbls 60/40 methanol down production and test flowlines. FH W P=240/220/180 MPG-18 6/5/2008 Well Support Techspulled wellhouse, production lines and foundation. Set the BPV with help of the SL unit boom. ******NOTE****** BPV is set. MPG-18 6/5/2008 *** WELL SI ON ARRIVAL *** (pre rwo) PULLED 1" BK-DGLV FROM 4981' MD, LEFT OPEN PULLED 1"BEK-DPSOV FROM 138' MD, SET 1" BK-DGLV WELL SUPPORT SET BPV *** TURN WELL OVER TO DSO *** MPG-18 6/8/2008 ***SURFACE WORK 3S*** VERIFIED 1" BK-DGLV IN SPM TO BE RUN ON BOTTOM SET 1" BEK-DPSOV IN SPM TO BE RUN ON TOP ***JOB COMPLETE*** MPG-18 6/10/2008 T/I/0=0/0/0 Freeze Protect (Post RWO) -Pumped tbg w/15 bbls 100*F crude. Pumped IA w/80 bbls 100*F crude. Verify casing valves open to gauges, tag well & notify operator. Final WHP's=0/0/0 MPG-18 6/17/2008 G-18 Pressure tested. Test and Prod flow -lines to 1150 PSI for 10.min with diesel. Print Date: 7/1/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 7/1/2008 WELL SERVICE REPORT WELL JOB SCOPE UNIT MPG-18 ACID LRS 64 DATE DAILY WORK DAY SUPV 5/11/2008 ACID TREATMENT IVESON COST CODE PLUS KEY PERSON NIGHT SUPV MSGPDWLI8-C LRS-ROBUSTELLINI PERL MIN ID DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY T/I/0=260/260/280 Acid Treatment Pumped 20 bbls Dead Crude down tubing for infectivity. Followed by 10 bbls 7.5% DAD Acid, 3 bbls 60/40 methanol and 18 bbls Dead Crude for displacement. FWHP=200/180/0 Init-> 260 260 280 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 17:00 Start ticket, PU procedure from co rep, road to location 17:30 Arrive & inspect location, spot in support e ui ment, PJSM, UWP, RU to tree ca 18:00 O erator SI well 18:10 C/O Fowler for Robustellini 18:27 PT to 3500 si. 18:45 .75 start crude 80" 450 280 180 Start um in down tubin . 18:47 1 2 450 280 180 increase rate. 18:51 1.30 6 500 280 180 18:59 1.3 16 550 260 140 19:02 1.3 20 650 260 140 Swa to acid. 19:04 1 start acid 20"F 650 260 140 Start acid. 19:06 1.1 2 500 260 140 19:08 1.7 5 900 260 140 19:11 1.7 10 1700 260 140 Shut down. Swa to methanol. 19:13 1. start 60/40 20'F 400 260 140 start 60/40 19:17 1 3 400 260 140 Shut down. Swa to crude. 19:19 1 start crude 80"F 500 260 140 Start crude. 19:21 1.2 3 900 260 100 19:32 1.2 18 1000 260 100 Shut Down. RDMO. 20:59 End Ticket. Final-> 200 180 0 FLUID SUMMARY 38 bbls crude 3 bbls 60/40 methanol 10 bbl acid Page 1 of 1 http://apps2-alaska.bpweb.bp.com/sst_drilling_wells/well_events_query/wellevent_awgs.asg?ID=64025E20... 7/1/2008 • • ~_ MICROFILMED 03!01/2008 DO NOT PLACE -,. _~ ~:a, °. ~' ANY NEW MATE R1AL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\l~licrofilm_Marker.doc n" n .... ,.. ro 1. Operations Performed: 1\11:1:>11.11 UII UL uu" "'......... o Abandon ~ Repair Well o Plug Perforations o Stimulate o AQ~Rfa.osuspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 204-021 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23194-60-00 7. KB Elevation (ft): KBE = 63.70' 9. Well Name and Number: MPG-18L 1 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 8563 feet true vertical 4145 feet Plugs (measured) NIA Effective depth: measured 8563 feet Junk (measured) NIA true vertical 4145 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' Surface 3191" 10-3/4" 3215' 2424' 5210 2480 Intermediate Production 5245' 7-5/8" 5278' 4108' 6890 4790 Liner 3263' 4-1/2" 5273' - 8536' 4105' - 4145' 8430 7500 ./", .'~',·.hC'· ..... ",;c;"::4" Perforation Depth MD (ft): Slotted 5380' - 8490' Perforation Depth TVD (ft): Slotted 4157' - 4145' 2-7/8",6.5# L-80 5247' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram ~Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem. 564-5743 Printed Name Sondra Stewman Title Technical Assistant ;:::5(ttÇ' -~ -- Prepared By Name/Number: ( '.- I) i~ D 1-/ ~ ÜV.sondra Stewman. 564-4750 SI'<}c-, .I..::!Ä-AJJ\.. = Phone 564-4750 Date ~. ". " . . Form 10-404 Revised 04/2006 c. /) '/') STATE OF ALASKA RECEIVED ALAe Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONSJUL 142006 OF<¡ ,» '£-7 A.-. ,-9 <-_-,f "0' RBDMS BFl JUL 1. 4 Z006 Submit Onglnal Only ~ . .\j Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 _ 11"x 11" w/2-7/S" 8rd T&B. Hanger 2.5" CIW "H" BPV profile 20' 178 #/ft .875 thick Driven conductor 120' 103/4" L-80 Float Shoe I 3,226' I KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 103/4" 45.5 ppf L-80 BTRC (Drift 10 = 9.794, cap. = .0961 bpf) 7518" 29.7 ppf, L-80, BTRC-mod production casing (drift 10 = 6.750", cap. = 0.0459 bpf) 4.5", 12.6#, L-80 IBT tbg. ( cap. = .0152 bpf, id =3.958 ) 2-718" 6.5# L-80 EUE 8rd tubing (drift ID = 2.347", cap. = 0.0058 bpf ) Window in 7" Casing @ 5,278' - 5,290' Well Angle @ window = 54° Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5,345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' 7 5/S" Halliburton Float Collar 5,476' 7 5/S" Halliburton Float Shoe 5,560' DATE COMMENTS REV. BY MPG-18\t_\ 0.· F elev.: 34.00' (Doyon 14) ° L. elev,: 29.70' (Doyon 14) Cameo 2-7/S" x 1" wI BK latch side pocket KBMM-2 GLM Cameo 2-7/8" x 1" wI BK latch sidepocket KBMM-2 GLM 2-7/S" HES XN-Nipple 2.313" bore (2.250"no-go) Centrilift GC2200 ESP GPMTAR 1:1122 stages Centrilift tandem gas sep. GRSFTXAR Centrilift tandem seal section GSB3DBUT AB/HSN PFSA GSB3DBL T AB/HSN FSA CL-5 Centrilift KMH 562 series 152 hp. motor, 2325 v/40 amp Centrilift Pump mate sensor 6 Fin Motor centrilizer Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 61/8" Hole td @ 8,563' OA Upper Lateral 75 jts. - 4 1/2" Slotted Liner 12.6# L-SO IBT (5,380'- S,490') I 138' 1 I 4,981'1 15,132'1 15,185' 1 15,205'1 15,210' I 15,224'1 15,238'1 15,243'1 Rat Hole 27' Btm Baker 4 1/2" Guide Shoe 8.536' 6 1/S" Hole td @ S,421 , 04/03/04 05/19/06 MDO MDO Drilled & Completed Doyon 14 ESP RWO Tbg. change out N-3S OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT Slotted Liner (5,531 '- 8,377') Btm Baker 41/2" Float Shoe 8,421' MILNE POINT UNIT WELL G-18 API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) BP EXPLORATION Page 1 of 2 Operatiøns Summary Repent Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 5/15/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 5/17/2006 00:00 - 07:00 7.00 RIGU P DECOMP RIU on MPG-18. 07:00 - 10:00 3.00 RIGU P DECOMP Accept rig. Rig spotted and rigged up. Stabbing board MU in Derrick. RU Flowback tank and hardline. Hang ESP Shieve in the Derrick Fill pits with 140 deg F Seawater. 10:00 - 14:00 4.00 KILL P DECOMP Pull BPV, WHP's T IIA I OA of 425/560 1140 psi. Remove Stack from Tioga Hot Air Heater from Pipe Shed. Wind blew it from its moorings. Pump 40 Bbls 140 deg F Seawater taking returns to Tiger Tank. Shut in choke and Bullhead 60 Bbls down Tubing. Open choke and pump 260 Bbls of 140 deg F Seawater down Tubing taking returns from the Annulus to Tiger Tank. 360 Bbls total pumped, 160 Bbls returns. Well on Vacuum @ 3/4 Bbllmin. Bleed OA from SOO psi to 100 psi.' 14:00 - 23:00 9.00 BOPSUF P DECOMP Set TWC and test to 500 psi and 3500 psi from above. Nipple down Tree. Clean seal bore, screw 27/8" pup joint into landing nipple threads to confirm integrity, OK. NU BOPE, 23:00 - 00:00 1.00 BOPSUF P DECOMP Test BOPE to 250 psi Low I 3500 psi High 5/1S/2006 00:00 - 05:00 5.00 BOPSUF P DECOMP Test BOPE to 250 psi Low 13500 psi High 05:00 - 07:30 2.50 PULL P DECOMP PUMU lubricator. Pull TWC. SITP = 0 psi. SICP=O psi. UD lubricator. PUMU landing jt. Screw into tubing hanger. Unseat hanger with 35K and pull to floor. Load hole with 290 Bbls of 140 deg F Seawater wI no returns. RU elephant trunk and spooler 07:30 - 12:00 4.50 PULL P DECOMP POH laying down 2 7/8", 6.5 #/ft, L-80 Tbg wI Centrilift ESP. Filling hole with Seawater @ double pipe displacement, no returns. 12:00 - 13:00 1.00 PULL P DECOMP Confirm wI BP Stores, 2718" 13 CR tubing for new completion just leaving Fairbanks. 75 joints OOH, shut down and send Derrickman into Derrick to clear ice (ice falling down from above onto rig floor) 13:00 - 16:00 3.00 PULL P DECOMP Continue POH laying down 2 7/8" completion. 90 Jts OOH @ 14:30. Joints 105 - 115 (3300' - 3600') were pitted where ESP cable was against tubing. Appears to be electrolysis. Joints 106, 110. and 115 set aside for sending to Tuboscope and examination from production chemist. 16:00 - 21:00 5.00 PULL P DECOMP Continue POH laying down 2 718" completion. 21:00 - 00:00 3.00 CASE P DECOMP RIU Shooting Flange, Riser, SL BOPs, and Lubricator for Junk Basket/Gauge Ring and Caliper Run to 5200' MD. 5/19/2006 00:00 - 05:00 5.00 CASE P DECOMP RIU Shooting Flange, Riser, SL BOPs, and Lubricator for Junk Basket/Gauge Ring and Caliper Run to 5200' MD. PT to 1200 psi. 05:00 - 07:00 2.00 CASE P DECOMP Run SL 6.25" Gauge Ring Drift wI Junk Basket to 5200' MD. 07:00 - 10:00 3.00 CASE P DECOMP MU PDS 40 arm memory caliper on Slickline and RIH to 5200' MD. Caliper to open at 08:00, POH @ 50 fpm logging to surface. Load new completion in pipe shed and strap I rabbit. 10:00 - 13:00 3.00 CASE P DECOMP Look at field data from PDS caliper, and casing looks to be in excellent condition. Send data to PDS Houston for computer analysis. Rig down SLB slickline, clear floor. ND shooting flange, and nipple up riser and pitcher nipple. 13:00 - 16:00 3.00 RUNCm F' RUNCMP Nabors Crew change. Assess Caliper Log, and no significant corrosion or wall loss in 7 5/S· casing from 5200' to surface. Rig up all equipment to run new completion. 16:00 - 22:00 6.00 RUNCm F' RUNCMP Pump 150 Bbls of 120 deg F Seawater into well @ 4 BPM 0 psi. PUMU Centrilift ESP BHA. e e Printed: 5/2212006 11 :56:03 AM BP EXPLORATION Page .2 of 2 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: WORKOVER Start: 5/15/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 5/19/2006 22:00 - 00:00 2.00 RUNcm c RUNCMP LaSalle Clamps will not fit on 2-7/8" VAM TOP tubing. Consult I I with town on plan forward. Decision made to run 2-7/8" EUE I I 8rd tubing throughout the entire completion. Order 2-7/8" EUE 100:00 - 10:00 8rd tubing. 5/20/2006 10.00 RUNCO! RUNCMP Remove VAM TOP tubing from Pipe Shed. Gather jewelry for EUE 8rd completion. Clear rig floor. Strap new 2-7/8" EUE 8rd tubing and load into pipe shed. Steam each joint prior to drifting due to ice inside of Tubing. Pumped 147 Bbls downhole. Pump 5 Bbl seawater in hole every 30 minutes as work on tubulars. 10:00 - 12:00 2.00 RUNCm 1P RUNCMP RIH wI new Centrilift ESP completion. MU ESP RIH. XN-Nipple threads galled. Call stores for new XN nipple wI 2 ; ea 10' 2 7/8" L-80 pup joints. 12:00-21:30 9.50 RUNCm IP RUNCMP MU new XN nipple and pup joints. RIH wI new completion wI torque of 2300 ft-Ib, Checking conductivity of electric cable every 2000' and pumping 10 Bbls thru tubing. 21 :30 - 22:30 1.00 RUNCm IP RUNCMP P/U and M/U Landing Joint to Tubing Hanger. Install Penetrator and dummy plugs. 22:30 - 00:00 1.50 RUNCm IP RUNCMP Space out ESP Cable to Hanger and make electrical connection to the Penetrator. 5/21/2006 00:00 - 01 :00 1.00 RUNCm P RUNCMP Land Tubing Hanger ( SIO = 50k P/U = 32k ), RILDS, and install I test TWC to 2,500 psi. 01 :00 - 05:30 4.50 BOPSUF P RUNCMP N/D BOPE. 05:30 - 09:00 3.50 WHSUR P RUNCMP N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Centrilift run final checks. 2.8 Balanced, 1 Gig phase to ground, temp 71 deg F, BHP 1588 psi. 09:00 - 12:00 3.00 WHSUR P RUNCMP Secure tree and cellar. Wait on Wells Support for pulling BPV. Rig down stabbing board from Derrick. Freeze protection of well to be done by Wells Group. Set BPV 12:00 - 00:00 12.00 WHSUR P RUNCMP Release Rig @ 12:00. RDMO to MPH-09. e e .. Printed: 5/2212006 11 :56:03 AM J ~t?;' l )J.¡~ k DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 5/1 t.i J. J.. ) --U ^ ~ '-f API No. 50-029-23194-60-00 Permit to Drill 2040210 Well NamelNo. MILNE PT UNIT SB G-18L 1 Operator BP EXPLORATION (ALASKA) INC /' Completion Date 3/1/2004 . ~. MD TVD 4145 / 8563 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION .---. ." Dlm"",",1 s"~~,~2_ -"''''''"''',.,..., Mud Log No Samples No _._'----~~--_._"--~--- ---_.....".__._~_..- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFRlCASANDRA, GYRO Well Log Information: Electr Dataset Number Name 12548 Induction/Resistivity Directional Survey Directional Survey Directional Survey Directional Survey (data taken from Logs Portion of Master Well Data Maint Interval . OHI Start Stop CH Received Comments 5418 8500 Open 4/16/2004 EWR4, GR, MI, ROP m 5260 8563 3/18/2004 5260 8563 3/18/2004 5260 8563 3/18/2004 MWD I 5260 8563 3/18/2004 MWD ~ 0 0 4/16/2004 DSN 12548 Log/ Data Digital Typ Med/Frmt C Lis ED D Pdf Log Log Run Scale Media No ~ I ED D Pdf ~ ~ -¡:--~------.__._---_._- LIS Verification ---~--_._._-~--.. Well Cores/Samples Information: Sample Set Number Comments Interval Start Stop Name Sent Received . ADDITIONAL INFORMATION Well Cored? Y Œ> Chips Received? ~ &: Daily History Received? Formation Tops Analysis Received? ~. _._~-- Comments: ~ Date: .2 ~- ~~ Compliance Reviewed By: ·' . WELL LOG TRANSMITTAL ¿)Lì4 - Dd I To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn,: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1~14-- RE: MWD Fonnation Evaluation Logs MPG-18L1, 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 MPG-18 Ll: LAS Data & Digital Log Images: 50-029-23194-60 1 CD Rom ~ 8-{ 9tf C(Q e . WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 08, 2004 RE: MWDFormationEvaluationLogs MPG-18Ll, AK-MW-2917922 1 LIS formatted Disc with verification listing. PùPI#: 50-029-23194~0 # l)j4ð ? Ò'-t - ~~ \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-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: J )J Vl ~ '¿'\"1 Signed: uvt¡ ., .... a STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMr\1I!SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2134' NSL, 3462' WEL, SEC. 27, T13N, R10E, UM Top of Productive Horizon: 2240' NSL, 2238' WEL, SEC. 27, T13N, R10E, (OA) Total Depth: 3013' NSL, 39' WEL, SEC. 28, T13N, R10E, (OA) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 557139 y- 6014569 Zone- ASP4 TPI: x- 558362 y- 6014684 Zone- ASP4 -- Total Depth: x- 555275 y- 6015434 Zone- ASP4 18. Directional Survey 0 Yes 181 No 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , GYRO One Other 5. Date Comp., Susp., or Aband. 3/1/2004 6. Date Spudded 2/25/2004 7. Date T.D. Reached 2/27/2004 8. KB Elevation (ft): KBE = 63.70' 9. Plug Back Depth (MD+ TVD) 8563 + 4145 10. Total Depth (MD+ TVD) 8563 + 4145 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 22. C~~~G Wr/PER·f'r; .GRAP ;;. 20" 92# H-40 10-3/4" 45.5# L-80 7-5/8" 29.7# L-80 4-1/2" 12.6# L-80 CASING, liNER AND CEMENTING RECORD ·..SETTING"!!F'THMD ..::¡errINGD",I>"I;H~HòtÊ TOP IBoTToM TOF'BoTTOMS!lE. 34' 112' 34' 112' 35' 3226' 35' 2390' 33' 5278' 33' 4108' 5273' 8536' 4105' 4145' 23. Perforations op'en to Production (MD + TVD of To[> and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Slotted Liner MD TVD MD TVD 5380' - 8490' 4157' - 4145' 42" 13-1/2" 9-718" 6-1/8" Revised 04/05/04, Start Production 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-021 13. API Number 50- 029-23194-60-00 14. Well Name and Number: MPG-18L 1 15. Field I Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 025906 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) Ap~~~~~ 260 sx Arctic Set (Approx.) ~60 sx PF 'L', 260 sx Class 'G' 420 sx Class 'G' Uncemented Slotted Liner ! 24. T J61NG SIZE DEPTH SET (MD) 2-7/8",6.5# x 12.6#, L-80 5246' PACKER SET (MD) None I ')¡:;: A~ln ..... CT.... I'.... ,.~ ~,~. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Dead Crude 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 18,2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF 3-22-2004 6 TeST PeRIoD .. 381 69 Flow Tubing Casing Pressure CALCULATED ....... OIL-BSL GAs-McF Press. 24-HoUR RATE"'" 1526 277 W A TER-BsL 164 W A TER-BsL 654 CHOKE SIZE I GAS-OIL RATIO 182 OIL GRAVITY-API (CORR) 27. CORE DATA Brief ~escriptio~ of ~ithology, poro~ity, f~actures, apparent dips and presence of oil, gas or wat~~ ~" sheet, if necessary). Submit core chips; If none, staUR I G , N A L REv t: 1 " w::. LJ None APR - 6 2004 RØI)MS I:ItL IIPR , Alaska Oil &. Gas con~: Commissio' Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE r... G r::' J . 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MBZ MB2 MC NA NB NC NE NF OA 4490' 4790' 4807' 4851' 5090' 5123' 5162' 5208' 5242' 5323' 5375' 3572' 3808' 3820' 3850' 3997' 4017' 4040' 4067' 4087' 4132' 4155' None 30. List of Attachments: 31. I hereby certify tha! the forejJoing is Signed Title Technical Assistant Date DLi -C5--0lf 204-021 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. MPG-18L 1 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Matt Green, 564-5581 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 . STATE OF ALASKA . ALASKÄ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ~ Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/1/2004 ' 204-021 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/25/2004 .; 50- 029-23194-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/27/2004 ~ MPG-18L 1 2134' NSL, 3462' WEL, SEC. 27, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2240' NSL, 2238' WEL, SEC. 27, T13N, R10E, (OA) KBE = 63.70' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 3013' NSL, 39' WEL, SEC. 28, T13N, R10E, (OA) 8563 + 4145 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 557139 t y- 6014569 . Zone- ASP4 8563 + 4145 Ft ADL 025906 TPI: x- 558362 y- 6014684 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 555275 . y- 6015434 ' Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost ~Yes ONo N/A MSL 1800' (Approx.) 21. Logs Run: ~7w ~2 78 r rl1þ MWD , GR , RES, IFRlCASANDRA , GYRO '-/tDf/f' n?> 22. CASING, LINER AND CEMENTING RECORD CASING SETTING JEPTH Me SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE lOP I ~OTTOM Top BOTTOM SIZE CEMENTING RECORD PUllED 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 3226' 35' 2390' 13-112" 1460 sx PF 'L', 260 sx Class 'G' 7-5/8" 29.7# L-80 33' 5278' 33' 4108' 9-7/8" 1420 sx Class 'G' 4-112" 12.6# L-80 5273' 8536' 4105' 4145' 6-1/8" Uncemented Slotted Liner 23. Perforations op'en to Production (MD + TVD of Top and 124. ........i 1 uèlNG Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8",6.5# x 12.6#, L-80 5246' None MD TVD MD TVD 25./ A....,... ETC.· 5380' - 8490' 4157' - 4145' / DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Dead Crude 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oil -BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ¡" ~. RfI:IIS 8ft API? () ~ 700h !.3~/~_~ . k ORIGINAL ;zß,,_ ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE G~ 28. GEOLOGIC MARKERS 29. RMATION 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". TUZC MA MBZ MB2 MC NA NB NC NE NF OA 4490' 4790' 4807' 4851' 5090' 5123' 5162' 5208' 5242' 5323' 5375' 3572' 3808' 3820' 3850' 3997' 4017' 4040' 4067' 4087' 4132' 4155' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date tß-I Aj- MPG-18L 1 Well Number 204-021 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Dri/ling Engineer .' Sondra Stewman, 564-4750 Matt Green, 564-5581 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". 0 R \ G \ N A L Form 10-407 Revised 12/2003 Tree: 2-9/16" - 5M FMC Wellhead: 5M Gen 5 . 11"x 11" wi 2-7/8" 8rd T& Hanger 2.5" CIW "H" BP file 20' 178 #/ft .875 thick Driven conductor 120' 103/4" L-80 Float Shoe 13,226'1 KOP @ 460' 43+ degree from 1,500' Max hole angle = 63 degree @ 2,200' 103/4" 45.5 ppf L-80 BTRC (Drift 10 = 9.794, cap. = .0961 bpf) 7518" 29.7 ppf, L-80, BTRC-mod production casing (drift ID = 6.750", cap. = 0.0459 bpf) 4.5",12.6#, L-80 IBTtbg. (cap. = .0152 bpf, id =3.958 ) 2-7/8" 6.5# L-80 EUE 8rd tubing (drift ID =: 2.347", cap. =: 0.0058 bpf ) Window in 7" Casing @ 5,278' - 5,290' Well Angle @ window = 54° Baker Tie Back Sleeve 5,338' Baker ZXP Liner Top Packer 5.345' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 5,351' 75/8" Halliburton Float Collar 5,476' 7 5/8" Halliburton Float Shoe 5,560' DATE REV. BY 04/03/04 MOO Drilled & Completed Doyon 14 COMMENTS MPG-1 e/ll ,I; ~ ),J ~.J]]p C>iG. DF' (Ù)V', ~ 3,l.OCì' (Doyon 1·,l) .CL. 0;OV.o 2~L?() (Doyonl4i Cameo 2-7/8" x 1" w/ BK latch side pocket KBMM-2 GLM Camco 2-7/8" x 1" w/ BK latch sidepocket KBMM-2 GLM 2-7/8" HES XN-Nipple 2.313" bore (2.250"no-go) Centrilift GC2200 ESP GPMTAR 1:1 122 stages Centriijft tandem gas scpo GRSTXBARHS Centriiift tandem sea! section GSB3DBUT /ILH6PFS AFLAS/HSN Centri!ift KMH 562 series 152 hp. motor, 2325 v!40 amp Centrilift Pump mate sensor 6 Fin Motor centriiizer Baker Hook Wall Hanger inside 7" Window 5,273' Baker Hook Wall Hanger outside 7" Window 5,290' 6 1/8" Hole td @ 8.563' OA Upper Lateral 75 jts. - 4 1/2" Slotted Liner 12.6# L-80 IBT (5,380'· 8,490') 1 117' I I 5044'1 15,134'1 5,187' I 15,208' 15,213'1 I 5,227' 1 15,241" 15,246'1 Rat Hole 27' Blm Baker 4112" Guide Shoe 8,536' 61/8" Hole td @ 8,421' 08 Lower Lateral 69 jts. ·4112", 12.6# L-80, IBT Slotted Liner (5,531'· 8,377') Blm Baker 4 112" Float Shoe 8,421' MILNE POINT UNIT WELL G-18\l\ API NO: 50-029-23194-60 API NO: 50-029-23194-00 BP EXPLORATION (AK) BP EXPLORATION Operations Summary Report Start: 2/7/2004 Rig Release: 3/1/2004 Rig Number: 14 Phas~_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 - To Hours Task Code NPT 2/14/2004 20:30 - 00:00 3.50 MOB P PRE 2/15/2004 00:00 - 01 :00 1.00 MOB P PRE 01 :00 - 03:30 2.50 RIGU P PRE 03:30 - 07:30 4.00 RIGU P PRE 07:30 - 09:30 2.00 RIGU N RREP PRE 09:30 - 11 :30 2.00 RIGU P PRE 11:30 - 13:30 2.00 RIGU P PRE 13:30 - 15:30 2.00 DRILL P SURF 15:30 - 17:00 1.50 RIGU P PRE 17:00 - 18:00 1.00 DRILL P SURF 18:00 - 00:00 6.00 DRILL P SURF 2/16/2004 00:00 - 00:00 24.00 DRILL P SURF 2/17/2004 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 04:00 2.00 CASE P SURF 04:00 - 06:00 2.00 CASE P SURF 06:00 - 07:00 1.00 CASE P SURF 07:00 - 09:00 2.00 CASE P SURF 09:00 - 10:30 1.50 CASE P SURF 10:30 - 12:00 1.50 CASE P SURF 12:00 - 12:30 0.50 CASE P SURF 12:30 - 14:00 1.50 CASE P SURF 14:00 - 14:30 0.50 CASE P SURF 14:30 - 18:30 4.00 CASE P SURF 18:30 - 19:00 0.50 CASE P SURF 19:00 - 21 :00 2.00 CASE P SURF 21:00 - 23:30 2.50 CEMT P SURF Page 1 of 6 Spud Date: 2/15/2004 End: 3/1/2004 Description of Operations Move off of MPG-17 and Move to MPG-18 Rig up MP-G18 Rig accept @ 1 :00 2/15/2005 Nipple up Diverter Picking up 4' drill pipe Repair pump on pipe skate Picking up pipe, mix spud mud Picking up HWP and DC and stand in derrick Picking up motor and MWD, Orientate same Diverter test, the right to witness test was waiver by Chuck Scheve AOGCC Spud meeting with crews, fill Diverter and check for leaks, wash to bottom Directional Drill 112' to 515' with 70 rpms, 425 gals min.,1080 psi, AST 1.75, ART 1.25, running GYRO every stand, started Gyro @ 196' Directional Drill 515' to 3000' with 80 rpms, 485 gals min.,2300 psi running GYRO to 723', AST 12.5, ART 4.42, Saw hydrates @ flow line @ 2480' Directional Drill 3000' to 3235' with 80 rpms, 500 gals min.,2300 psi Circ Three bottoms up with 100 rpms, 500 gals min. 2050 psi Pumping out to HWDP with full drilling rate Flow Check - RIH from 725' to 3235' CBU 3 X - RPM 80 - TQ 8K 500 gpm - PP 2100 - PU 10SK - SO 85K - ROT 95K Pump out from 3235' to 725' - 5" HWT - Pump at drilling rate 500 gpm Stand back 5" HWT - Lay down BHA Clear rig floor - Lay down vendors tools Rig up 103/4" casing tools - PJSM on running casing Pick up 1 make up float equipment - Circ through same Run 76 Joints of 103/4" 45.5# L-80 BTC casing to 3149'- Wash last joint down from 3149' to 3190' - Make up Hanger 1 landing joint and land at 3225' - (Tight spot at 2032' circulate - wash down from 2073' to 2156') Rig down Franks fill up tool - Make up Schlumberger cementing head - cementing lines Break circulation - stage up pump from 2 bpm to 9 bpm - Circulate 2 casing volumes - PJSM (cementing casing) Pump 25 bbls water 5 bpm 150 psi - Test lines to 3500 psi - test good - Pump 25 bbls CW 100 @ 5 bpm 220 psi - Pump 75 bbls Mud Push @ 5.6 bpm 250 psi - (1 gallon dye in first 5 bbls pumped) - Drop bottom plug last 5 bbls spacer pumped on fly - Mix and pump 351 bbls 460 sxs Type 'ASL' Yield 4.28 cflsx mixed at 10.7 ppg - Mix and pump Tail cement 260 sxs Class G with .9% S-001 + .4% D-167 + m.3% D-065 + .2% D-046- Yield 1.17 cflsx 54 bbls slurry mixed at 15.8 ppg - Kick out top plug with 30 bbls water with Dowell Schlumberger - Turn to Rig for 268 bbls displacement with mud @ 8 bpm 500 psi - Bump plug with 1000 psi over final pressure 1500 psi - CIP 23:30 Hrs - Bleed off pressure - Check floats - Floats holding - (185 bbs Printed; 31812004 8;35;58 AM W" ~ BP EXPLORATION OperationsSum.ma~yReport Start: 217/2004 Rig Release: 3/1/2004 Rig Number: 14 COde! NPT !Phase I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To Hours Task 2/17/2004 - . 21 :00 - 23:30 2.50 CEMT P 23:30 - 00:00 0.50 CASE P 00:00 - 02:00 2.00 CASE P 02:00 - 03:30 1.50 CASE P 03:30 - 04:30 1.00 CASE P 04:30 - 06:30 2.00 CASE P 06:30 - 07:30 1.00 CASE P 07:30 - 10:30 3.00 CASE P SURF SURF SURF SURF SURF 2/18/2004 SURF SURF SURF 10:30 - 11 :00 0.50 CASE P SURF 11 :00 - 13:00 2.00 CASE P SURF 13:00 - 14:30 1.50 CASE P SURF 14:30 - 15:00 0.50 CASE P SURF 15:00 - 16:00 1.00 CASE P SURF 16:00 - 17:00 1.00 CASE P SURF 17:00 - 18:30 1.50 CASE P SURF 18:30 - 19:00 0.50 CASE P SURF 19:00 - 19:30 0.50 CASE N FLUD SURF 19:30 - 20:30 1.00 CASE P SURF 20:30 - 21 :30 1.00 CASE P SURF 21 :30 - 00:00 2.50 DRILL P INT1 2/19/2004 00:00 - 00:00 24.00 DRILL P INT1 2/20/2004 100:00 - 01 :30 1.50 CASE P COMP 01 :30 - 05:30 4.00 CASE P COMP 05:30 - 07:00 1.50 CASE P COMP 07:00 - 08:30 1.50 CASE P COMP OS:30 - 10:00 1.50 CASE P COMP 110:00 - 11 :00 1.00 CASE P COMP 11 :00 - 11:30 0.50 CASE P COMP 111:30 - 14:30 3.00 CASE P COMP 14:30 - 17:00 2.50 CASE P COMP 117:00 - 19:00 2.00 CASE P COMP Page 2 or6 Spud Date: 2/15/2004 End: 3/1/2004 Description of Operations' .-....... ..--....... ....-. ..-- -.----.- ..-.-. cement to surface) Rig down Dowell Schlumberger Cementing head - Cementing lines Flush Divertor - Lay down landing joint - Flush flow line - Lay down casing tools - Lay down Dowell Schlumberger cementing head Nipple down Divertor System Nipple up casing head - Tubing spool - Test casing head to 1000 psi for 10 mins - test good Nipple up BOP's Rig up to test BOP's - Install test plug - Open annulus valves - Test Annular 250 low 2500 high each test 5 mins - Pipe rams- Blind rams - HCR Choke - HCR kill - Manual Choke - Manual kill- Choke manifold - Upper I Lower IBOP - Floor safety valves - Perform Accumulator test - All test good - Chuck Scheve with AOGCC wavied witness of BOP test Rig down testing equipment - pull test plug - Install Wear ring - Close Annulus valves Make up - Orient 9 7/8" BHA - Surface test MWD Change out elevators and slips from 5" to 4" - RIH to 3050' - Wash to Float collar @ 3142' CBU 1 X - GPM 375 - PP 800 psi - RPM 50 Cut drlg line - Con't circ @ 2.5 bpm while cutting drilling line Blow down top drive - Rig up to test 103/4" casing - Test casing to 2500 psi for 30 mins on chart Drill out Float equipment to 3235' Drill 20' new hole from 3235' to 3250' Mud aired up - Pump not primed - Prime pump - Con't drill to 3255' PJSM - Displace well with 8.9 ppg LSND mud Blow down top drive - Rig up test equipment - FIT - Mud weight 8.9 - MD 3235' TVD 2388' Surface pressure 390 psi - EMW 12.04 ppg Directional Drill 9 7/8" hole from 3255' to 3599' - WOB 25K - RPM 100 - TO on 5K - off 5K - GPM 450 - PP on 1500 - off 1400 - PU 125K - SO 90K - ROT 95K Directional Drill from 3599' to TD 9 7/S" Hole @ 557S' - WOB 25K - RPM 100 - TO on 10K - off 9K - GPM 500 - PP on 2760- off 2540 - PU 180K - SO 95K - ROT 120K Top of NB sand 5175' Top of OA sand 5377' Top of OB sand 5512' CBU 3 X - GPM 500 - PP 2800 - RPM 120 - TO 10K Pump out - Pulling @ 400 fph for Mad pass log as per Geologist - from 5573 to 4500' - Pump at drlg rate Pump out to shoe at Drlg rate from 4500' to 3220' CBU - (Clay balls) - Flow check - well stable - Pump dry job POH to BHA Lay down BHA Make up Hole opener BHA RIH to 5578' - Hole in good shape CBU 3 X - GPM 525 - PP 2250 - RPM 120 - TQ 10K Pump out to shoe from 5578' to 3220' - Pump at drlg rate Printed: 31812004 8:35:58 AM ~ .~ '< .. BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 F·S"'~u::vul'" Task !cödeINPr! Phase ;> i i. . . .. _ ~ _ ... ..:. i 19:00 - 19:30 0.50 CASE P COMP 2/20/2004 19:30 - 20:00 0.50 CASE P COMP 20:00 - 21 :30 1.50 CASE P COMP 21 :30 - 00:00 2.50 CASE P COMP 2/21/2004 00:00 - 02:30 2.50 CASE P COMP 02:30 - 03:00 0.50 CASE P COMP 03:00 - 05:00 2.00 CASE P COMP 05:00 - 07:30 2.50 CASE P COMP 07:30 - 08:30 1.00 CEMT P COMP 08:30 - 09:30 1.00 CEMT P COMP 09:30 - 10:00 0.50 CEMT P COMP 10:00 - 10:30 0.50 CEMT P COMP 10:30 - 11:00 0.50 CASE P COMP 11 :00 - 13:00 2.00 CASE P COMP 13:00 - 13:30 0.50 CASE P COMP 13:30 - 15:00 1.50 CASE P COMP 15:00 - 15:30 0.50 CASE P COMP 15:30 - 17:30 2.00 STWHIP N HMAN PROD1 17:30 - 19:30 2.00 STWHIP N HMAN PROD1 19:30 - 20:00 0.50 STWHIP N HMAN PROD1 20:00 - 21 :00 1.00 STWHIP N HMAN PROD1 21 :00 - 21 :30 0.50 STWHIP N HMAN PROD1 21 :30 - 00:00 2.50 STWHIP N HMAN PROD1 i Page 3 of 6 Start: 2/7/2004 Rig Release: 3/1/2004 Rig Number: 14 I Spud Date: 2/15/2004 End: 3/1/2004 Description of Operations ....--.--. . .. ... ..._n .. .. .. . . CBU at shoe - GPM 525 - PP 1460 - RPM 120 - TO 5K - Flow check - Well stable - Pump dry job POH from 3220' to BHA 625' Lay down BHA Change Top rams to 7 5/8" - Pull wear ring - Install test plug -Test door seals to 1500 psi - Pull test plug - Rig up casing tools PJSM (Running casing) - Pick up I make up float equipment - Check floats - Pick up and run 80 joints of 7 5/8' casing to 3203' Circulate 1 casing volume - 1500 stks @ 60 spm - PP 450 Con't Run 7 5/8' 29.7# L-80 BTC-M casing from 3203' to 5538' - Make up landing joint I hanger - RIH from 5538' to 5570' land casing - Lay down Franks fill up tool - Make up Schlumberger cementing head - cementing lines Break circulation staging up pump to 60 spm @ 420 psi - Circulate 2 casing volumes - 5700 strokes - condition mud for cement job Held PJSM with rig crew and service hands. Pumped 5 bbls of CW-100 chemical wash - test lines to 4000 psi - 5 bbls of CW-1oo - 15 bbls of 11.1 ppg Mud Push - 420 sxs (86 bbls) Class G cement + .3% D065 Dispersant + .4% D167 Fluid Loss + .5% S001 Accelerator + .2% D046 Antifoam mixed in a 15.8 ppg slurry with a yield of 1.16 cfVsx. Washed cementing lines and kicked out top plug with 5 bbls of water. Displaced cement with rig pumps at 6.0 bpm. Had full returns and good pressure increase as cement was pumped up annulus. Final pumping pressure 780 psi. Bumped plug at 0915 hrs 2-21-2004 with 3500 psi. Pressure tested annulus to 3500 psi for 30 minutes. Recorded on chart. Bled off pressure and float held. Rigged down cementing head and landing joint. Flushed wellhead with water. Install 7-5/8' casing mandrel packoff and tested to 5000 psi for 10 minutes. Remove 7-518' rams and installed 2 7/8' X 5' VBR rams - Full body test on BOP's to 2500 psi - Test Rams to 3500 psi Pull test plug close annulus valves - Install wear ring - Change casg bails to drlg bails on top drive Pick up 4 314' DC's and 3 1/2' HWT up from pipe shed - Run in hole - Circulate pipe volume POH Make up Baker Whipstock - MWD - Orient same - BHA - Surface test MWD @ 52 spm @ 600 psi RIH to 2800' - Fill pipe every 25 stds Rig service - Top drive service RIH to 5408' - Fill pipe every 25 stds Orient whipstock to 4R high side - Tag float collar @ 5474' slack off on whipstock 25K - Anchor set @ 10K - PU 10K over to confirm anchor set - Slack off 35K to shear brass bolt - Work down number of times to shear off bolt Milling window @ 5418' to 5427' - WOM 5 - RPM 90 - TO on 5K - off 8K - GPM - 284 - PP 1330 - PU 160 - SO 88 - ROT 105 Printed: 3/812004 8:35:58 AM , ~ W' ~ BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPG-18 Common Well Name: MPG-18 Spud Date: 2/15/2004 Event Name: DRILL+COMPLETE Start: 2/7/2004 End: 3/1/2004 Contractor Name: DOYON DRILLING INC. Rig Release: 3/1/2004 Rig Name: DOYON 14 Rig Number: 14 Date Hours Task Code NPT Phase Description of Operations . 2/21/2004 21 :30 - 00:00 2.50 STWHIP N HMAN PROD1 2/22/2004 00:00 - 02:30 2.50 STWHIP N HMAN PROD1 Mill window from 5427' to 5442' - (TOW 5418' - BOW 5430') - WOM 5 - RPM 100 - GPM 285 - PP 1400 02:30 - 04:30 2.00 STWHIP N HMAN PROD1 Pump Hi Vis sweep surface to surface - saw some increase of metal - (Displace LSND with 10.9 Flo Pro) - Pump Hi Vis spacer - Followed by 10.9 Flo Pro mud - Monitor well- Well Stable - Pump dry job 04:30 - 06:00 1.50 STWHIP N HMAN PROD1 POH with Baker Milling assembly to BHA 06:00 - 07:00 1.00 STWHIP N HMAN PROD1 Stand back HWT - DC's - Lay down Baker Mills and tools - Down load MWD 07:00 - 07:30 0.50 STWHIP N HMAN PROD1 Make up stack washer - Flush BOP's - Pick up bha to rig floor 07:30 - 09:30 2.00 CASE P COMP Make up - BHA - Orient Up Load MWD - Make up flex DC's - Shallow pulse test MWD 09:30 - 11 :30 2.00 CASE P COMP RIH to 5401' 11 :30 - 12:00 0.50 CASE P COMP Orient BHA - Slide out window - Drill from 5442' to 5452' 12:00 - 13:00 1.00 CASE P COMP Pull into casg - Perform FIT - MD 5418' TVD 4183 - Mud Wt 10.8 - Surface pressure 370 psi = EMW 12.5 13:00 - 14:00 1.00 CASE N DFAL COMP MWD failure - GAB motor not working - Attempt to diagnose Problem - No success 14:00 - 14:30 0.50 CASE N DFAL COMP Pump EP mud lube pill - Mix dry job 14:30 - 16:30 2.00 CASE N DFAL COMP Flow check - Pump dry job - POOH to BHA 16:30 - 19:00 2.50 CASE N DFAL COMP Handle BHA - Down Load MWD - Change out DM - Up load MWD - Make up BHA - Surface test MWD 5.7 bpm - @ 1300 psi 19:00 - 20:30 1.50 CASE N DFAL COMP RIH to 5390' 20:30 - 21 :30 1.00 CASE P COMP Slip cut drlg line - Rig service - Top drive service 21 :30 - 00:00 2.50 DRILL P PROD1 Orient - Slide through window - Directional Drill from 5452' to 5620' - WOB 10K - RPM 80 - TO on 8K 8K - off 5K - GPM 250 - PP on 1800 - off 1650 - PU 135 - SO 85 - ROT 105 2/23/2004 00:00 - 23:30 23.50 DRILL P PROD1 Directional Drill from 5620' to TD 6 3/4" OB Lateral Hole @ 8421' - WOB 5 to 10 - RPM 90 - TO on 7.5K - off 8K - GPM 254 - PP on 2900 - off 2630 - PU 135K - SO 78K - ROT 100K- ECD 12.5 23:30 - 00:00 0.50 CASE P COMP CBU 3 X - GPM 270 - PP 2500 2/24/2004 00:00 - 02:00 2.00 CASE P COMP CBU 3 X - GPM 270 - PP 2500 - ECD 12.3 02:00 - 04:00 2.00 CASE P COMP Pump out from 8421' to 5450' - Pump at drlg rate - Pull through window from 5450' to 5400' with out pumping - 10K to 15K over pull @ 5426' to 5423' 04:00 - 05:00 1.00 CASE P COMP CBU 1 X - Monitor well - well stable - Pump dry job 05:00 - 06:30 1.50 CASE P COMP POH to BHA from 5305' to BHA at 215'. 06:30 - 07:00 0.50 CASE P COMP Laid down BHA 07:00 - 07:30 0.50 CASE P COMP Clear floor. Rig up to run 4.5' slotted liner. Service top drive and PJSM on running slotted liner. 07:30 - 10:00 2.50 CASE P COMP Picked up float joint, 69 jts of 4-1/2' slotted liner, 4 jts of 4-1/2' solid joints and Baker 7-5/8' X 5-1/2' HMC hanger with ZXP packer. 10:00 - 12:00 2.00 CASE P COMP Run in hole with liner on 4' drill pipe to TD at 8421'. PU weight 140K SO weight 90K. PU and pulled the liner in tension. 12:00 - 13:00 1.00 I CASE P COMP Broke circulation at 2.5 bpm at 400 psi. Dropped 29/32' ball down drill pipe. Pumped down drill pipe 112 drill pipe capacity at 5 bpm slowed down pumps to 2 bpm. Ball on seat. Pressure up to 3500 psi and set hanger and ZXP packer. Held pressure for ¡ 5 minutes. Bled pressure off of drill pipe. Pressure tested I Printed: 3/812004 8:35:58 AM 5 of 6 BP EXPLORATION Operations Sljml11aryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To Hours Task Code NPT I Phase 2/24/2004 12:00.. 13:00 1.00 CASE P COMP 13:00.. 16:00 3.00 CASE N RREP COMP 16:00 - 16:30 0.50 CASE P COMP 16:30 - 18:30 2.00 CASE P COMP 18:30 - 19:30 1.00 CASE P COMP 19:30 .. 22:00 2.50 CASE P COMP 22:00 .. 22:30 0.50 CASE P COMP 22:30 - 00:00 1.50 STWHIP P PROD2 2/25/2004 00:00 .. 01 :00 1.00 STWHIP P PROD2 01 :00 .. 03:00 2.00 STWHIP P PROD2 03:00 - 06:00 3.00 STWHIP P PROD2 06:00 - 07:30 1.50 STWHIP P PROD2 07:30.. 09:00 1.50 STWHIP P PROD2 09:00 - 10:00 1.00 STWHIP N RREP PROD2 10:00 - 10:30 0.50 STWHIP P PROD2 10:30.. 11:00 0.50 STWHIP P PROD2 11 :00 - 11 :30 0.50 STWHIP P PROD2 11:30 - 13:30 2.00 STWHIP P PROD2 13:30 - 00:00 10.50 DRILL P PROD2 2/26/2004 00:00 - 00:00 24.00 DRILL P PROD2 2/27/2004 00:00 - 16:00 16.00 DRILL P PROD2 16:00.. 18:00 2.00 CASE P COMP 18:00 - 21:00 3.00 CASE P COMP 21:00 .. 22:00 1.00 CASE P COMP 22:00 - 00:00 2.00 CASE P COMP 2/28/2004 00:00 - 00:30 0.50 CASE P COMP 00:30 .. 01 :30 1.00 CASE P COMP 01 :30 - 02:30 1.00 CASE P COMP 02:30 - 03:30 1.00 CASE P COMP Start: 2/7/2004 Rig Release: 3/1/2004 Rig Number: 14 Spud Date: 2/15/2004 End: 3/1/2004 Description of Operations annulus to 1500 psi. Bled off annulus and rotated out of liner hanger. Pulled out seal assembly and stood back 2 stands. Blow down top drive and installed Floor valve in string. Monitor well on trip tank. Change out oil pump and high speed drive chain on draworks Service Top drive Pump Dry job - POH - Lay down Baker Liner running tools Pull wear ring - Install test plug - Open annulus valves - Rig up tst equipment Test Annular to 250 low.. 2500 high.. 5 mins each test.. Top / Btm Rams - Blind Rams - Choke Manifold - HCR Choke / Kill valves - Manual Choke / Kill valves - Upper I Lower IBOP- Floor safety valves.. 250 low - 3500 high - 5 mins each test - Accumulator test - All test good - John Crisp with AOGCC waived witness of BOP test Rig down test equipment.. Pull test plug.. Install wear ring - Close annulus valves PJSM - Pick up Baker Whipstock - Make up Whipstock assembly - Orient MWD with whipstock Con't make up Whipstock assembly - Shallow test MWD RIH with Baker whipstock from 910' to 5225 - Orient Whipstock 1 R High side - RIH to 5347' - tag up - Set WhiPS~K. k -. Shear off with 32K down wei9!!!. . . .... .. ~'~:~~tl Lc.À+~1 :l Mill OA window :'fow 527ã7tõBÕW5296'-~" C-óñ'f"drnf ._..,,~--- formation to 5302' Clean up window - CBU Hi Vis sweep surface to surface - Flow check - Pump dry job POH from 5302' to BHA 909' Change out hydralic hose on skate Lay down BHA Flush BOP's with stack washer Make up 6 3/4" Drlg Assembly - Orient - Shallow pulse test RIH from 217' to 5200' Orient motor to 0 deg - tum off pump - Slide through window - Directional Drill from 5302' to 5779' .. WOB 12K to 15K - RPM 80.. TO on 8K - off 6K - GPM 254.. PP on 1800 - off 1600.. PU 140.. SO 95 - ROT 110 Directional Drill From 5779' to 7565' .. WOB 2k TO 10k .. RPM 90.. TO on 7k - off 6.5k - PP on 2250.. off 2100 PU 140 - SO 80.. ROT 102 Directional Drill from 7565' to 8563' TD OA Lateral - WOB 10K - RPM 80 .. TO on 7K - off 5K .. GPM 254 .. PP on 2440 - off 2220 - PU 125 - SO 82 - ROT 102 CBU 3 X - RPM 100.. TO 5K - GPM 280 - PP 2750 Pump out @ Drlg rate GPM 254 .. From 8563' to 5320' - Pull through window with out pump from 5380' to 5250' CBU 1 X - GPM 280 - PP 2200 - RPM 100 - TO 3K .. Flow Check.. Pump Dry job POH from 5200 to 217' @ BHA Lay down BHA Pick up Baker Whipstock Retrieving assembly - MWD .. Orient Down load - Up Load MWD - Surface test MWD RIH to with 4.75" spiral DC's - 31/2" HWDp.. Shallow test Printed: 3/612004 8:35:58 AM .., --,..-,......- BP EXPLORATION Op~rations Su 11"1 rnary Report Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-18 MPG-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 2/7/2004 Rig Release: 3/1/2004 Rig Number: 14 Spud Date: 2/15/2004 End: 3/1/2004 Date From - To Hours Task Code NPT Phase Description of Operations ___.M__.___. 2/28/2004 02:30 - 03:30 1.00 CASE P COMP MWD - Good test 03:30 - 05:00 1.50 CASE P COMP RIH from 867' to 5183' - Fill DP @ 3267' 05:00 - 06:00 1.00 CASE P COMP Cut Drlg Une - Top Drive Service 06:00 - 06:30 0.50 CASE P COMP RIH to 5280' - Orient high side - Engage hook slide - Pull 80K over pick up weight - Slide free - Pick up weight gained 5K - Observe well- Well static - Pump dry job 06:30 - 09:00 2.50 CASE P COMP POH from 5280' to 867' - @ controlled speed 09:00 - 11 :00 2.00 CASE P COMP Lay down 3.5" HWT - 4.75" Dc's - MWD - Baker Whipstock slide assy - Tail pipe assy 11 :00 - 12:00 1.00 CASE P COMP Clear rig floor - Lay down Baker tools - MWD tools 12:00 - 15:00 3.00 CASE P COMP PJSM - Pick up 78 joints 41/2" L-80 12.6# IBT Slotted liner- Make up Baker hanger - Baker Hook wall assy 15:00 - 18:00 3.00 CASE P COMP RIH with 41/2" slotted liner to 8260' - Two attempts to exit liner in OA Lateral 18:00 - 19:30 1.50 CASE P COMP Hook liner to bottom of window @ 5290' on fourth attempt- Slack off 40K to confirm hook was set - Drop ball and pump down to liner running tool - 40 spm @ 700 psi - Ball on seat - Pressure up to 3000 psi to release running tool - Pick up 30' - Lost 20K weight - pressure up to 4600 psi shear out ball I seat out of running tool 19:30 - 22:00 2.50 CASE P COMP Flow check - Pump dry job - POOH from 5290' to 3150' - Lay down remaining 4" drill pipe 22:00 - 00:00 2.00 COMP Make up mule shoe - RIH to 5225' 2/29/2004 00:00 - 01 :00 1.00 COMP PJSM - Flush surface lines with fresh water 01 :00 - 02:00 1.00 COMP Displace 10.8 Flo Pro mud with 10.9 Brine - Pump viscosified 10.9 brine sweep - followed by 10.9 brine - GPM 500 - PP 2000 - RPM 120 02:00 - 06:00 COMP PJSM - Lay down all 4" DP from 5225' 06:00 - 06:30 COMP Pull wear ring - Clean and clear rig floor 06:30 - 07:00 COMP PJSM with - Centrilift Tech, Crew, Co Man, - Rig up to run 2 7/8" tubing 07:00 - 10:30 COMP Make up pump and motor - Fill motor with oil - Connect ESP cable - Clamps - Check ESP continuity - Good 10:30 - 13:00 COMP PJSM with Centrilift techs on running tubing and ESP - Run 2 7/8" L-80 6.5# 8 rd tubing to 1727' 13:00 - 19:30 RREP COMP Pipe Skate - Repair Hydraulic pump on skate 19:30 - 00:00 COMP Con't Run 2 7/8" ESP completion to 5215' 3/1/2004 00:00 - 00:30 COMP Fill tubing - Pump 10 bbls down tubing - @ 42 spm @ 1250 psi - Install TWC- Ran 88 LaSalle ESP cable clamps - PU 85K - SO 75K 00:30 - 02:30 COMP Install Hanger Penetrators - splice ESP cable - Connect ESP cable to penetrators - Test ESP continuity - Good test 02:30 - 03:00 0.50 RUNCO COMP RIH from 5215' to 5246' landing tubing on hanger - RILDS 03:00 - 03:30 0.50 RIGD P COMP Test TWC to 1000 psi from above - Test good 03:30 - 04:30 1.00 RIGD P COMP Nipple down BOP's - Stand back on stump - Secure same 04:30 - 06:00 1.50 RIGD P COMP Nipple up FMC 11" X 29/16" tubing head adapter - Test ESP cable continuity - Good - Test tubing packoff to 5000 psi for 10 mins - good test 06:00 - 07:00 1.00 RIGD P COMP Nipple up CIW 2 9/16" 5K Tree - Test to 5000 psi for 10 mins good test 07:00 - 07:30 0.50 RIGD P COMP Pull TWC with dry rod - Install BPV with Dry rod 07:30 - 08:00 0.50 RIGD P COMP Remove 1502 pump-in sub flange - Install wing valve flange - Secure well - Release Rig @ 08:00 hrs Printed: 31812004 8:35:58 AM WELL,SERVICE REPORT ........ ".,..",,,..,,,,, WELL JOB SCOPE UNIT,,- / MPG-18 NEW WELL POST UNKNOWN DATE DAILY WORK DAY SUPV 3/1/2004 FREEZE PROT O'MALLEY AFE KEY PERSON NIGHT SUPV MSD337374 UNKNOWN UNKNOWN MINID I DEPTH TTL SIZE 0" OFT 0" - DAILY SUMMARY Freeze Protect TBG and IA Init-> 0 325 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 12:37 Travel 1 Standby for RiQ Move 13:45 Load Dead Crude 14:14 Load Diesel 14:36 PT TBG to 3800 psi 14:39 1 start crude 450 Down TBG 14:50 .9 10 " 1700 14:56 .9 15 " 1700 Shut Down Switch to IA 15:04 1.5 start " 800 Down IA 15:13 1.5 15 " 850 15:23 1.45 30 " 900 . 15:38 1.48 50 " 975 15:49 1.48 65 " 1025 Shut Down 16:11 RDMO 1 Travel Final-> 575 575 I FLUID SUMMARY 80 bbls Dead Crude SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL BP $0 $0 FESCO $1 170 $1,170 TOTAL FIELD ESTIMATE: $1 170 $1,170 Legal Name: MPG-18 Common Name: MPG-18 Test Date 2/18/2004 2/22/2004 FIT FIT BP EXPLORATION Leak-Off. Test Summary Test Type i Test Depth (TMD) I Test Depth (TVD) . ...____.. .. - .~~---._ n.. ." ___..___ ___._...._ . . ._.__..._.___.. _.._.._. 3,225.0 (ft) 2,388.0 (ft) 5,559.0 (ft) 4,183.0 (ft) AMW 8.90 (ppg) 10.80 (ppg) Surface Pressure 390 (psi) 370 (psi) Leak Off Pressure (BHP) ; . . .. .._ .....__.__..L.._ ._ 1 ,494 (psi) 2,717 (psi) Page 1 of 1 EMW 12.04 (ppg) 12.50 (ppg) Printed: 3/8/2004 8:35:36 AM . . {JO'-l-ÔCJ , 16-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITVE Re: Distribution of Survey Data for Well MPG-18L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,260.08' MD 5,278.00' MD 8,563.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Sign~\~t JY""'.~'....Q ~~G'~ Date Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) f','~; ;~, +j n ¡ill1A . 1 I, "~' ...~l~V'''i' t'·NC.'.^.~. . ., ¡ '.,;UI¡;;', \JíJmm¡~!(tn RBDMS RD MAR 3 0 2004 Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18L 1 Job No. AKZZ2917922, Surveyed: 27 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319460 Surface Coordinates: 6014569.32 N, 557139.33 E (70027'01.5895" N, 149032'01.7335" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63. 70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63.70ft above Structure Reference spef""'f""'V-su", DRILLING SeRVn:eS A Halliburton Company EFINlrlVE . . Survey Ref: svy1351 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 Your Ref: API 500292319460 Job No. AKZZ2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit Measured True 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) 5260.08 54.630 282.420 4033.90 4097.60 84.17 N 1320.26 E 6014663.61 N 558458.91 E -1148.37 Tie On Point 5278.00 54.650 282.160 4044.27 4107.97 - 87.28 N 1305.98 E 6014666.61 N 558444.60 E 1.189 -1134.18 Window Point 5351.90 63.940 282.850 4081.96 4145.66 101.04 N 1244.02 E 6014679.90 N 558382.54 E 12.597 -1072.49 5401.22 71.130 283.250 4100.80 4164.50 111.33 N 1199.65E 6014689.85 N 558338.09 E 14.597 -1028.12 5447.50 77.110 283.600 4113.45 4177.15 121.66 N 1156.38 E 6014699.85 N 558294.74 E 12.942 -984.72 . 5495.02 83.250 283.940 4121.56 4185.26 132.80 N 1110.92E 6014710.64 N 558249.20 E 12.940 -939.00 5543.75 89.880 284.280 4124.47 4188.17 144.66 N 1063.77 E 6014722.13 N 558201.96 E 13.623 -891.45 5592.80 93.950 285.600 4122.83 4186.53 157.29 N 1016.42 E 6014734.40 N 558154.51 E 8.723 -843.37 5641 .42 92.840 285.850 4119.96 4183.66 170.44 N 969.70 E 6014747.19 N 558107.69 E 2.340 -795.63 5689.06 92.660 286.350 4117.67 4181.37 183.64 N 923.98 E 6014760.04 N 558061.88 E 1.114 -748.77 5737.29 92.970 285.790 4115.30 4179.00 196.98 N 877.69 E 6014773.02 N 558015.48 E 1.326 -701.34 5781.63 93.090 284.060 4112.96 4176.66 208.38 N 834.91 E 6014784.09 N 557972.62 E 3.906 -657.90 5832.00 92.530 282.130 4110.49 4174.19 219.78 N 785.91 E 6014795.12 N 557923.53 E 3.985 -608.89 5879.84 91.360 281.400 4108.86 4172.56 229.53 N 739.10 E 6014804.51 N 557876.65 E 2.882 -562.57 5926.96 91.540 282.970 4107.67 4171.37 239.47 N 693.06 E 6014814.09 N 557830.53 E 3.353 -516.86 5973.83 90.740 282.370 4106.74 4170.44 249.75 N 647.34 E 6014824.02 N 557784.74 E 2.133 -471.28 6022.48 90.680 282.140 4106.14 4169.84 260.07 N 599.80 E 6014833.98 N 557737.12 E 0.489 -424.05 6067.64 90.370 281.270 4105.72 4169.42 269.23 N 555.59 E 6014842.80 N 557692.83 E 2.045 -380.32 6118.97 92.040 281.730 4104.64 4168.34 279.46 N 505.30 E 6014852.65 N 557642.47 E 3.375 -330.66 6168.01 92.470 281.210 4102.71 4166.41 289.21 N 457.28 E 6014862.02 N 557594.37 E 1.375 -283.25 6215.23 92.720 280.930 4100.58 4164.28 298.26 N 410.98 E 6014870.73 N 557548.01 E 0.794 -237.70 6266.78 93.080 279.640 4097.97 4161.67 307.46 N 360.33 E 6014879.53 N 557497.29 E 2.595 -188.17 . 6310.95 92.840 278.500 4095.69 4159.39 314.41 N 316.77 E 6014886.15 N 557453.68 E 2.634 -146.00 6360.73 93.770 279.540 4092.82 4156.52 322.20 N 267.69 E 6014893.56 N 557404.54 E 2.800 -98.50 6407.67 93.210 280.650 4089.96 4153.66 330.41 N 221.56 E 6014901.42 N 557358.35 E 2.645 -53.47 6454.80 92.710 281.540 4087.53 4151.23 339.47 N 175.37 E 6014910.13 N 557312.09 E 2.164 -8.01 6502.83 94.020 282.180 4084.71 4148.41 349.32 N 128.45 E 6014919.62 N 557265.10 E 3.035 38.46 6553.07 92.590 283.350 4081.81 4145.51 360.41 N 79.54 E 6014930.33 N 557216.10 E 3.675 87.26 6599.16 92.470 282.610 4079.77 4143.47 370.75 N 34.67 E 6014940.32 N 557171.15 E 1.625 132.10 6651.81 90.120 281.340 4078.59 4142.29 381.67 N 16.82 W 6014950.85 N 557119.58 E 5.073 183.13 6695.42 89.940 281.080 4078.56 4142.26 390.15 N 59.60 W 6014959.00 N 557076.74 E 0.725 225.27 6745.82 89.940 280.210 4078.61 4142.31 399.46 N 109.13 W 6014967.93 N 557027.14 E 1.726 273.85 6791.26 90.060 281.060 4078.61 4142.31 407.84 N 153.79 W 6014975.97 N 556982.42 E 1.889 317.64 6842.23 90.120 280.660 4078.53 4142.23 417.45 N 203.85 W 6014985.19 N 556932.29 E 0.794 366.81 6887.34 88.210 280.760 4079.19 4142.89 425.83 N 248.16 W 6014993.23 N 556887.91 E 4.240 410.29 15 March, 2004 - 8:52 Page 20f4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 Your Ref: API 500292319460 Job No. AKZZ2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit Measured True 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) 6935.46 88.020 282.480 4080.78 4144.48 435.51 N 295.27 W 6015002.56 N 556840.73 E 3.594 456.85 6983.29 87.840 282.440 4082.50 4146.20 445.83 N 341.94 W 6015012.51 N 556793.98 E 0.386 503.30 7032.78 87.340 282.590 4084.58 4148.28 456.54 N 390.21 W 6015022.86 N 556745.63 E 1.055 551.36 7078.27 87.840 283.550 4086.50 4150.20 466.82 N 434.48 W 6015032.80 N 556701.28 E 2.378 595.63 7129.87 86.790 283.150 4088.91 4152.61 478.72 N 484.63 W 6015044.31 N 556651.04 E 2.177 645.90 . 7174.20 88.580 282.850 4090.70 4154.40 488.69 N 527.79 W 6015053.94 N 556607.81 E 4.094 689.04 7226.21 88.460 281.830 4092.05 4155.75 499.80 N 578.58 W 6015064.67 N 556556.93 E 1.974 739.53 7269.13 90.430 282.990 4092.46 4156.16 509.02 N 620.49 W 6015073.57 N 556514.95 E 5.326 781.22 7319.09 91.050 283.810 4091.82 4155.52 520.60 N 669.09 W 6015084.77 N 556466.27 E 2.058 829.95 7365.62 91.850 283.800 4090.64 4154.34 531.70 N 714.26 W 6015095.52 N 556421.01 E 1.719 875.40 7416.88 91.850 284.480 4088.99 4152.69 544.21 N 763.94 W 6015107.66 N 556371.24 E 1.326 925.51 7461.25 91.910 284.670 4087.53 4151.23 555.37 N 806.86 W 6015118.49 N 556328.23 E 0.449 968.96 7508.67 91.420 283.570 4086.15 4149.85 566.93 N 852.83 W 6015129.70 N 556282.18 E 2.539 1015.33 7557.56 90.800 283.460 4085.21 4148.91 578.36 N 900.35 W 6015140.76 N 556234.57 E 1.288 1063.03 7610.32 90.430 283.450 4084.64 4148.34 590.63 N 951.66 W 6015152.64 N 556183.17 E 0.702 1114.50 7653.60 91.240 283.700 4084.01 4147.71 600.79 N 993.73 W 6015162.47 N 556141.02 E 1.959 1156.74 7705.40 91.360 283.200 4082.83 4146.53 612.84 N 1044.10W 6015174.13 N 556090.57 E 0.992 1207.27 7750.58 91.980 282.860 4081.52 4145.22 623.02 N 1088.09 W 6015183.98 N 556046.49 E 1.565 1251.26 7801.44 92.650 283.470 4079.46 4143.16 634.59 N 1137.58W 6015195.17 N 555996.92 E 1.781 1300.78 7847.28 90.490 285.040 4078.21 4141.91 645.87 N 1181.98W 6015206.11 N 555952.43 E 5.824 1345.62 7896.27 90.120 285.690 4077.95 4141.65 658.85 N 1229.22 W 6015218.73 N 555905.09 E 1.527 1393.75 7943.56 89.940 289.980 4077.92 4141.62 673.34 N 1274.23 W 6015232.87 N 555859.98 E 9.080 1440.53 . 7990.37 90.490 291.350 4077.75 4141.45 689.85 N 1318.03 W 6015249.05 N 555816.05 E 3.154 1487.13 8039.72 91.480 292.650 4076.90 4140.60 708.34 N 1363.77 W 6015267.18 N 555770.17 E 3.311 1536.34 8087.31 92.350 293.060 4075.31 4139.01 726.81 N 1407.60 W 6015285.32 N 555726.20 E 2.021 1583.83 8135.69 89.440 292.820 4074.55 4138.25 745.66 N 1452.15 W 6015303.83 N 555681.51 E 6.035 1632.12 8184.64 88.640 292.000 4075.37 4139.07 764.32 N 1497.39 W 6015322.14 N 555636.12 E 2.340 1680.96 8231.53 89.140 290.340 4076.28 4139.98 781.25 N 1541.11 W 6015338.73 N 555592.28 E 3.697 1727.67 8281.68 89.320 289.220 4076.95 4140.65 798.22 N 1588.29 W 6015355.34 N 555544.96 E 2.262 1777.51 8328.61 87.530 288.640 4078.24 4141.94 813.44 N 1632.67 W 6015370.22 N 555500.47 E 4.009 1824.05 8378.14 88.700 287.640 4079.87 4143.57 828.85 N 1679.71 W 6015385.27 N 555453.32 E 3.107 1873.07 8423.99 89.320 287.410 4080.66 4144.36 842.66 N 1723.42 W 6015398.74 N 555409.50 E 1.442 1918.40 8469.25 89.070 284.990 4081.30 4145.00 855.28 N 1766.88 W 6015411.03N 555365.95 E 5.375 1962.97 8518.73 90.000 284.230 4081.70 4145.40 867.76 N 1814.76 W 6015423.14 N 555317.97 E 2.427 2011.46 8563.00 90.000 284.230 4081.70 4145.40 "- 878.64 N 1857.67 W 6015433.69 N 555274.98 E 0.000 2054.78 Projected Survey ... 15 March, 2004 - 8:52 Page 3 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 Your Ref: API 500292319460 Job No. AKZZ2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 Well and calculated along an Azimuth of 296.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8563.00ft., The Bottom Hole Displacement is 2054.98ft., in the Direction of 295.313° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5260.08 5278.00 8563.00 4097.60 4107.97 4145.40 84.17 N 87.28 N 878.64 N 1320.26 E 1305.98 E 1857.67 W Tie On Point Window Point Projected Survey Survey toolproQram for MPG-18L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 642.00 0.00 640.36 642.00 8563.00 640.36 Tolerable Gyro (MPG-18PB1) 4145.40 AK-6 BP _IFR-AK (MPG-18PB1) 15 March, 2004 - 8:52 Page 4 of 4 DrillQuest 3.03.06.002 . . !90i-!-{)(9 I 16-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPG-18L 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,260.08' MD 5,278.00' MD 8,563.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 "!"~,:-,'::'." ,'. '" <:''''' Signed'R ~,~ 'r-J. . V'\.' ,\\~ ( ~ l""- .:~(', /rv'\. Date Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED AUachment(s) ", '." '1 () {~;"I;"I ,1 t"- "'< t () L:).H.}¿~ RBDMS RD MAR 3 0 2004 Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPG MPG-18L1 MWD . Job No. AKMW2917922, Surveyed: 27 February, 2004 Survey Report 15 March, 2004 Your Ref: API 500292319460 Surface Coordinates: 6014569.32 N, 557139.33 E (70· 27' 01.58958 N, 149· 32' 01.73358 W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1014569.32 N, 57139.33 E (Grid) Surface Coordinates relative to Structure Reference: 2836.97 N, 763.91 E (True) Kelly Bushing Elevation: 63.70ft above Mean Sea Level Kelly Bushing Elevation: 63.70ft above Project V Reference Kelly Bushing Elevation: 63.70ft above Structure Reference SpElF'""F'""Y-SUI'1 DR1L..L.INGSeRVICes A Halliburton Company Survey Ref: svy1356 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 MWD Your Ref: API 500292319460 Job No. AKMW2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit Measured True 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) 5260.08 54.630 283.310 4033.91 4097.61 95.78 N 1322.20 E 6014675.24 N 558460.76 E -1145.00 Tie On Point 5278.00 54.650 282.160 4044.28 4107.98 99.00 N 1307.95 E 6014678.35 N 558446.48 E 5.235 -1130.78 Window Point 5351.90 63.940 240.090 4083.26 4146.96 88.43 N 1247.59 E 6014667.31 N 558386.21 E 50.139 -1081.25 5401.22 71.130 288.100 4103.09 4166.79 84.43 N 1203.98 E 6014662.98 N 558342.62 E 90.638 -1043.85 5447.50 77.110 298.130 4115.77 4179.47 101.92 N 1163.14 E 6014680.16 N 558301.65 E 24.514 -999.48 . 5495.02 83.250 279.280 4123.95 4187.65 116.79N 1119.00 E 6014694.69 N 558257.40 E 41.142 -953.30 5543.75 89.880 280.870 4126.86 4190.56 125.30 N 1071.13 E 6014702.83 N 558209.47 E 13.990 -906.58 5592.80 93.950 285.930 4125.22 4188.92 136.65 N 1023.47 E 6014713.82 N 558161.72 E 13.233 -858.79 5641 .42 92.840 284.100 4122.34 4186.04 149.22 N 976.60 E 6014726.03 N 558114.75 E 4.396 -811.16 5689.06 92.660 284.970 4120.06 4183.76 161.17 N 930.53 E 6014737.62 N 558068.60 E 1.863 -764.55 5737.29 92.970 285.100 4117.69 4181.39 173.66 N 884.01 E 6014749.76 N 558021.98 E 0.697 -717.27 5781.63 93.090 280.810 4115.35 4179.05 183.59 N 840.87 E 6014759.35 N 557978.77 E 9.665 -674.17 5832.00 92.530 282.090 4112.88 4176.58 193.57 N 791.56 E 6014768.96 N 557929.39 E 2.771 -625.50 5879.84 91.360 281.220 4111.25 4174.95 203.23 N 744.74 E 6014778.26 N 557882.49 E 3.047 -579.21 5926.96 91.540 282.040 4110.06 4173.76 212.73 N 698.60 E 6014787.40 N 557836.28 E 1.781 -533.60 5973.83 90.740 281.210 4109.13 4172.83 222.17 N 652.70 E 6014796.49 N 557790.31 E 2.459 -488.23 6022.48 90.680 280.200 4108.52 4172.22 231.21 N 604.90 E 6014805.16 N 557742.44 E 2.080 -441.34 6067.64 90.370 279.380 4108.11 4171.81 238.89 N 560.40 E 6014812.50 N 557697.88 E 1.941 -398.00 6118.97 92.040 279.570 4107.03 4170.73 247.33 N 509.79 E 6014820.55 N 557647.20 E 3.274 -348.83 6168.01 92.470 279.640 4105.10 4168.80 255.51 N 461.47 E 6014828.36 N 557598.83 E 0.888 -301.85 6215.23 92.720 280.760 4102.96 4166.66 263.86 N 415.05 E 6014836.36 N 557552.34 E 2.428 -256.49 6266.78 93.080 278.000 4100.36 4164.06 272.25 N 364.26 E 6014844.36 N 557501.49 E 5.393 -207.20 . 6310.95 92.840 278.130 4098.07 4161.77 278.44 N 320.58 E 6014850.21 N 557457.77 E 0.618 -165.26 6360.73 93.770 279.610 4095.20 4158.90 286.10 N 271.48 E 6014857.50 N 557408.61 E 3.507 -117.80 6407.67 93.210 278.750 4092.35 4156.05 293.58 N 225.23 E 6014864.62 N 557362.30 E 2.183 -72.98 6454.80 92.710 281.320 4089.91 4153.61 301.78 N 178.88 E 6014872.46 N 557315.90 E 5.548 -27.76 6502.83 94.020 281.330 4087.09 4150.79 311.20 N 131.87E 6014881.52 N 557268.81 E 2.728 18.60 6553.07 92.590 282.920 4084.20 4147.90 321.73 N 82.84 E 6014891.68 N 557219.70 E 4.253 67.27 6599.16 92.470 281.050 4082.16 4145.86 331.29 N 37.80 E 6014900.89 N 557174.59 E 4.062 111.91 6651.81 90.120 280.190 4080.97 4144.67 340.99 N 13.93 W 6014910.19 N 557122.78 E 4.753 162.63 6695.42 89.940 279.710 4080.95 4144.65 348.53 N 56.89 W 6014917.40 N 557079.77 E 1.176 204.52 6745.82 89.940 278.540 4081.00 4144.70 356.52 N 106.65 W 6014925.01 N 557029.95 E 2.321 252.72 6791.26 90.060 281.000 4081.00 4144.70 364.23 N 151.43 W 6014932.38 N 556985.12 E 5.420 296.31 6842.23 90.120 279.610 4080.92 4144.62 373.35 N 201.57 W 6014941.11 N 556934.90 E 2.730 345.35 6887.34 88.210 279.980 4081.58 4145.28 381.02 N 246.02 W 6014948.44 N 556890.40 E 4.313 388.64 15 March, 2004 - 8:52 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 MWD Your Ref: API 500292319460 Job No. AKMW2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit Measured True 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) 6935.46 88.020 284.570 4083.16 4146.86 391.24 N 293.00 W 6014958.30 N 556843.34 E 9.542 435.32 6983.29 87.840 280.070 4084.89 4148.59 401.44 N 339.69 W 6014968.14 N 556796.58 E 9.410 481.73 7032.78 87.340 279.010 4086.97 4150.67 409.63 N 388.45 W 6014975.96 N 556747.75 E 2.366 529.12 7078.27 87.840 280.330 4088.89 4152.59 417.27 N 433.25 W 6014983.25 N 556702.89 E 3.101 572.71 7129.87 86.790 282.920 4091.30 4155.00 427.65 N 483.73 W 6014993.25 N 556652.33 E 5.411 622.60 . 7174.20 88.580 282.090 4093.09 4156.79 437.24 N 526.97 W 6015002.51 N 556609.02 E 4.450 665.65 7226.21 88.460 284.800 4094.44 4158.14 449.33 N 577.54 W 6015014.21 N 556558.37 E 5.214 716.37 7269.13 90.430 282.330 4094.85 4158.55 459.39 N 619.25 W 6015023.95 N 556516.58 E 7.361 758.26 7319.09 91.050 286.870 4094.21 4157.91 471.98 N 667.58 W 6015036.17 N 556468.15 E 9.171 807.20 7365.62 91.850 284.340 4093.03 4156.73 484.50 N 712.38 W 6015048.34 N 556423.26 E 5.701 852.93 7416.88 91.850 281.690 4091.38 4155.08 496.03 N 762.29 W 6015059.49 N 556373.26 E 5.167 902.82 7461.25 91.910 283.490 4089.92 4153.62 505.70 N 805.57 W 6015068.83 N 556329.91 E 4.057 945.93 7508.67 91.420 282.180 4088.54 4152.24 516.23 N 851.78 W 6015079.00 N 556283.61 E 2.948 992.06 7557.56 90.800 282.220 4087.59 4151.29 526.56 N 899.56 W 6015088.96 N 556235.76 E 1.271 1039.51 7610.32 90.430 281.670 4087.03 4150.73 537.48 N 951.17W 6015099.49 N 556184.06 E 1.256 1090.66 7653.60 91.240 283.300 4086.40 4150.10 546.83 N 993.42 W 6015108.52 N 556141.74 E 4.205 1132.71 7705.40 91.360 280.030 4085.22 4148.92 557.30 N 1044.13 W 6015118.60 N 556090.95 E 6.315 1182.85 7750.58 91.980 279.270 4083.91 4147.61 564.87 N 1088.65 W 6015125.83 N 556046.38 E 2.170 1226.16 7801.44 92.650 280.120 4081.85 4145.55 573.43 N 1138.75W 6015134.00 N 555996.22 E 2.127 1274.90 7847.28 90.490 282.450 4080.60 4144.30 582.40 N 1183.68W 6015142.62 N 555951.22 E 6.929 1319.19 7896.27 90.120 284.690 4080.33 4144.03 593.89 N 1231.30W 6015153.75 N 555903.52 E 4.634 1367.01 7943.56 89.940 284.580 4080.31 4144.01 605.84 N 1277.05 W 6015165.35 N 555857.67 E 0.446 1413.35 . 7990.37 90.490 282.970 4080.13 4143.83 616.98 N 1322.51 W 6015176.14 N 555812.12 E 3.635 1459.08 8039.72 91.480 289.530 4079.28 4142.98 630.78 N 1369.86 W 6015189.58 N 555764.67 E 13.441 1507.66 8087.31 92.350 282.750 4077.69 4141.39 644.00 N 1415.52 W 6015202.44 N 555718.91 E 14.355 1554.48 8135.69 89.440 284.910 4076.94 4140.64 655.56 N 1462.48 W 6015213.65 N 555671.86 E 7.490 1601.74 8184.64 88.640 277.710 4077.76 4141.46 665.15 N 1510.44 W 6015222.87 N 555623.83 E 14.797 1649.02 8231.53 89.140 278.550 4078.67 4142.37 671.78 N 1556.85 W 6015229.14 N 555577.37 E 2.084 1693.61 8281.68 89.320 280.810 4079.34 4143.04 680.21 N 1606.28 W 6015237.20 N 555527.88 E 4.520 1741.70 8328.61 87.530 283.990 4080.63 4144.33 690.28 N 1652.09 W 6015246.92 N 555481.99 E 7.773 1787.27 8378.14 88.700 282.870 4082.26 4145.96 701.78 N 1700.24 W 6015258.04 N 555433.76 E 3.269 1835.56 8423.99 89.320 285.380 4083.05 4146.75 712.97 N 1744.69 W 6015268.89 N 555389.22 E 5.638 1880.40 8469.25 89.070 283.620 4083.69 4147.39 724.30 N 1788.51 W 6015279.88 N 555345.32 E 3.927 1924.73 8518.73 90.000 284.960 4084.09 4147.79 736.51 N 1836.45 W 6015291.73 N 555297.28 E 3.296 1973.15 8563.00 90.000 284.960 4084.09 4147.79 747.94 N 1879.22 W 6015302.83 N 555254.43 E 0.000 2016.59 Projected Survey 15 March, 2004 - 8:52 Page 3 of 4 DrillQuest 3.03.06.002 . Halliburton Sperry-Sun Survey Report for Milne Point MPG - MPG-18L 1 MWD Your Ref: API 500292319460 Job No. AKMW2917922, Surveyed: 27 February, 2004 BPXA Milne Point Unit All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 Well and calculated along an Azimuth of 296.120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8563.00ft., The Bottom Hole Displacement is 2022.59ft., in the Direction of 291.703° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5260.08 5278.00 8563.00 4097.61 4107.98 4147.79 95.78 N 99.00 N 747.94 N 1322.20 E 1307.95 E 1879.22 W Tie On Point Window Point Projected Survey Survey too/prOf/ram for MPG-18L 1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 642.00 0.00 640.36 642.00 8563.00 640.36 Tolerable Gyro (MPG-18PB1 MWD) 4147.79 MWD Magnetic (MPG-18PB1 MWD) 15 March, 2004 - 8:52 Page 4 of4 DrillQuest 3.03.06.002 . . FRANK H. MURKOWSKI, GOVERNOR AItASIiA OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Mile Point Unit MPG-18Ll BP Exploration (Alaska), Inc. Permit No: 204-021 Surface Location: 2134' NSL, 3462' WEL, Sec. 27, T13N, RIOE, UM Bottomhole Location: 3051' NSL, 50' WEL, Sec. 28, TI3N, RI0E, OA Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska), Inc. assumes the liability of any protest to the spacing exception that may occur. 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 permit 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 witness any required test. Contact the Commission's North Slope petroleum fie . ecto t 659-:}607 (pager). '/ BY ORDE~~; THE COMMISSION DATED thO day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~Gt\- ' /2. Z-/ ? c!)c:;>f 1 a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 1 00302630-277 MPG-18L 1 3. Address: 6. Proposed Depth: 12. Field I Pool(s): .. P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8517 ' TVD 4129 Milne Point Unit I Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 025906 / 2134' NSL, 3462' WEL, SEC. 27, T13N, R10E, UM . B. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: tt 2308' NSL, 2650'WEL, SEC. 27, T13N, R10E, (OA)Ûf\'l 02/05/04 Total Depth: ,n 9. Acres in Property: 14. Distance to Nearest Property: 3051' NSL, 50' WEL, SEC. 28, T13N, R10E, (OA) 'Vh\ 2560 8020' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-557139' Zone-ASP4 (Height above GL): PLANNED KBE feet 160' from Schrader Penetration Sand in MPG-12 y-6014569 . =63.8' 16. Deviated Wells: f 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) 0 Kickoff Depth 5318 ft Maximum Hole Angle 96 Downhole: 2146 psig Surface: 1750 "psig 18. . Casing Program ii ......... SêttingDêpth i 'QlIántítybfCêri1ent Size TOD Bottom (c.f. or sacks) Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (includinQ staae data) 6-1/8" 4-1/2" 12.6# L-80 BTC 3198' 5318' 4166' 8516' 4129' Uncemented Slotted Liner 19; PRS$SNT WSI..I..QONDITIONSPMMARY <ToQØ·CômpJeted for RedrillANoge.-!!Itltry operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 8525 4193 NIA 8525 4193 NIA 'i.i.; ii i.!>i·'iii'·Siz'é-;·i..···.··· ii..ii·;i!,;.i;;. ~i .'i'; ·ii·ii;· .!.M!,..t··..·...·.·. i.ii. i··iii ··.·i;i; Ct·· .,... ..~I ConcllJr.tnr 112' 20" 260 sx Arctic Set (ADProx.) 112' 112' ~ . 3215' 10-3/4" 76 sx PF 'L', 261 sx Class 'G' 3215' 2424' Int PrnnlJr.tinn 5508' 7-5/8" 06 sx Class 'G' 5508' 4234' Linp.r 3167' 6-1/8" Uncemented Slotted Liner 5358' - 8525' 4184' - 4193' Perforation Depth MD (ft): None perfOration Depth TVD (ft): Nonve 20. Attachments a Filing Fee o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Green, 564-5581 Printed Name Pat Archey Title Senior Drilling Engineer f1sÆ Ii V&.VtH¡ Prepared By Name/Number: Sianature .~ Phone 564-5803 Date Sondra Stewman, 564-4750 ii 'r ............ .... . UsêÔ¡'I~ Permit To Drill. .v" I API Number: Z-3lq~ -be) Permit APprovazj-:;> _ l I II See cove~etter for Number:;;LO -() 2 I 50- Q 2- c¡ - Date: ..J.."t"e, I ments Conditions of Approval: Samples Required o Yes ~o Mud Log Requir£d\ ..., -~es~~ HWe Measu,.. o Yes No Directional Survey Rj~~e~ ~4 No Othe, Te.~'f<í. Alaska Oil & Gas Cons. ComrmsslOfJ Anchorage ~//.Jð~1 Aooroved Bd ~ I / nD/",,,, II BY ORDER OF / THE COMMISSION Date Form 10-401 "ReVised '~':> -i\ICJlfVn! Sfbmit yf Duplfcate .. STATE OF ALASKA .. ALASKA OI!llAND GAS CONSERVATION COM~SION PERMIT TO DRILL 20 MC 25.005 e Milne POi.PG-18 L 1 Well Permit ¡Well Name: IMPG-18 L1 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Multi Lateral Producer "OA" & "OB" Surface Location: 3146' FNL, (2134' FSLj, 3462' FEL, (1817' FWL), SEC. 27, T13N, R10E E=557139.24" N=6014569.14 Target Location: 2971' FNL, (2308' FSL),2650'''FEL, (2630' FWL), SEC. 27, T13N, R10E TOP "OA" E=557950 N=6014750 Z=4125'TVD Target Location: 2228' FNL, (3051' FSL); 50' FEL; (5229' FWL), SEC. 28, .T13N, R10E BHL "OA" Well TD E=555263 N=6015472 Z=4065' TVD Target Location: 3016' FNL, (2264' FSL), 2429' FEL, (2850' FWL), SEC. 27, T13N, R10E TOP "OB" E=558171 N=6014707 Z=4170'TVO Target Location: 2228' FNL, (3051' FSL), 50' FEL, (5229' FWL), SEC. 28, T13N, R10E BHL "OB" Well TO E=555263 N=6015472 Z=4130'TVO I AFE Number: 1 TBD I Estimated Start Date: 15-Feb-2004 eM[] 8,517'1 I TVD: 14,129 I I Rig: I Doyon 14 I Operating days to complete: 113.6 I I Max Inc: ~ I KOP: 153181' I KBE: 163.81 I I I Well Design (conventional, slimhole, etc.): I Conventional Grass Roots ML Producer I Objective: I Schrader Bluff OA & OB Sand M dP u rogram: 13.5-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density -, Funnel Vis VP HTHP pH API Filtrate LG Solids 8.6- 9.2 75 - 150 25 - 60 N/A 9.0-9.5 <12 < 6.5 9.875-in Intermediate Hole Mud Properties: LSND Freshwater Mud Density , PV VP HTHP pH API Filtrate LG Solids 8.8 - 11.0 ~ 10 - 20 25 - 30 10-11 9.0 -9.5 <6 <15 6.125-in Production Hole Mud Properties: KCI-CaC03 FloPro Density , PV VP HTHP pH API Filtrate MBT 10.8 - 11.0 ... 10 - 20 25 - 30 10-11 9.0 - 9.5 <6 <7 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation 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 lR. 1 e Milne POi.laPG-18 L 1 Well Permit C t P emen rogram: Casing 1 0.75-in 45.5-lb/ft L-80 BTC-M surface casing Size Basis 100% over gauge hole. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 406-bbl Spacer 50-bbl 10.3-lb/gal un-viscosified Alpha spacer Lead 352-bbl, 476-sx 10.7-lb/gal Permafrost L - 4.15 ff/sx (cement to surface) Tail 54-bbl, 261-sx 15.8-lb/gal Premium G - 1.15 fr'/sx (top of tail at 2,715-ft MD) ¡¡¡iB)@»:;ß':-.-.-.-.-,-.-,-.-'---'-' Temp BHST :::: 55°F from SOR, BHCT 60°F estimated by Schlumberger Casing 7.625-in 29.7-lb/ft L-80 BTC-M intermediate casing Size Basis Top of lead cement 500-ft above top of Ugnu-sand. 0% excess over gauge. To of tail cement 500-ft MD above top of N-sand. 40% excess over gauge. Total Cement Wash 5-bbl Water Vol: 88-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Tail 88-bbl, 406-sx 15.6-lb/gal Premium G - 1.15 ft;j/sx (top of tail at 3,932-ft MD) Temp BHST :::: 80°F from SOR, BHCT 70°F estimated by Schlumberger Evaluation Program: 13.5-in Hole Section: Open Hole: MWD/GR, IFRlCASANDRA Cased Hole: N/A 9.875-in Hole Section: Open Hole: MWD/GRlRES,IFRlCASANDRA Cased Hole: N/A 6.125-in Hole section: Open Hole: MWD/GRlRES, ABI/IFRlCASANDRA Cased Hole: N/A 2 e Milne PO¡_PG-18 L 1 Well Permit Formation Markers Formation Tops M Orkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (lb/gal)* Base Permafrost 2292 1864 TUZC 4432 3579 1526 8.35 NA 5046 4024 2146 10.42 NB 5098 4054 2162 10.42 NC 5142 4079 2175 10.42 NE 5169 4094 2184 10.42 NF 5257 4139 2208 10.42 Top OA 5323 4169 2224 10.42 Base OA 5427 4209 2246 10.42 Top OB 5508 4234 2259 10.42 Base OB 5646 4259 2273 10.42 r * Based on SS depths c IT b" p aSln~ u In 9 rogram Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb M D / TVDrkb 42-in 20-in* 92# H-40 Welded 80-ft O-ft 112-ft/ 112-ft 13.5-in 10.75-in 45.5# L-80 BTC-M 3,215-ft O-ft 3,215-ft / 2,424-ft 9.875-in 7.625-in 29.7# L-80 BTC-M 5,508-ft O-ft 5,508-ft I 4,234-ft 6.125-in 4.5-in 12.6# L-80 BTC 3,167-ft 5,358-ft / 8,525-ft / OB Slotted 4,184-ft 4,193-ft 6.125-in 4.5-in 12.6# L-80 BTC 3,198-ft 5,318-ft / 8,516-ft / OA Slotted 4,166-ft 4,129-ft * The 20-in conductors are insulated. R d d S"t P ecommen e I rogram BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5-in O-ft - 3,215-ft Hughes 3-15 & 1-1 0 MX-C1 2 9.875-in 3,215-ft - 5,508-ft Smith 3-15 & 1-1 0 FGXiCPS 3 6.125-in 5,508-ft - TO Secu rity 3-12 FM2643 4 6.125-in 5,318-ft - TO Secu rity 3-12 FM2643 3 e Milne POi_PG-18 L1 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: . Maximum anticipated BHP: · Maximum surface pressure: 2,146-psi @ 3,960-ft TVDrkb - Top of "NA" 1 ,750-psi @ surface .,., (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) 3,500-psi. An FIT to 12.0-lb/gal will be made on the 10.75-in casing shoe. 14-bbl with 10.9-lb/gal mud. 9.7-lb/gal brine / 7.0-lb/gal Diesel (1 ,800-ft MD). · Planned BOP test pressure: · Integrity test: · Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates , · Light to moderate hydrates were encountered on several of the previous G-Pad wells. No drilling problems related to the hydrates were reported. · Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas "" and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. · Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · Maximum reservoir pressure is expected to be (10.42 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 10.9-lb/gal mud. ,.. Pad Data Sheet · Please Read the G-Pad Data Sheet thoroughly. 4 e Milne POi_PG-18 L1 Well Permit Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · A 20-ft DTE fault is expected at 4,700-ft MD in the Ugnu. · A 15-ft DTE fault is expected at 5,900-ft MD in the Schrader. Hydrogen Sulfide · MPG Pad is not designated as an H2S Pad. All G-Pad wells had <2-ppm H2S on the 2001 report. Anti-collision Issues · The abandoned wellbore MPG-06 is risk based at 1/200 to pass anti-collision scan. Distance to Nearest Property · MPG-18 is 8,020-ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPG-18 is 160-ft from the Schrader-sand penetration in MPG-12. ."-,, 5 e Milne PO¡ePG-18 L 1 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20-in insulated conductor is installed 2. NU diverter Procedure 1. MI/RU Doyon 14 2. Function test diverter, PU 4.0-in drill pipe 3. Drill 13.5-in surface hole 4. Run and cement 10.75-in casing 5. ND diverter, install wellhead, NU BOPE and test 6. Drill 9.875-in intermediate hole 7. Run and cement 7.625-in casing 8. Drill 6.125-in OB horizontal production hole 9. Run 4.5-in slotted liner 10. Run whipstock and mill window for OA lateral 11. Drill 6.125-in OA horizontal production hole 12. Retrieve whipstock 13. Run 4.5-in slotted liner and hang off in 7.625-in casing 14. Displace drilling mud to brine 15. Run 4.5-in jet pump completion 16. ND BOPE / NU tree 17. Freeze protect well 18. RD/MO 6 TREE: Cameron 2-9/16" 5M WELLHEAD: FMC Gen 5 11", 5M Tubing Heâd: FMC 11-in x 2.875-in 114' 20" 92 Ib/tt, H-40 Welded Insulated 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 2.875-in 6.5-lblft, L-80, 8rd, EUE Tubing ID: 2.441-in Tubing Capacity: 0.00579-bbl/ft Tensile (100%): 145-k.lbf Burst: 10,570-psi Collapse: 13,870-psi 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi -..-. .. .... _...]:l.}''''l.:;I.ItI-:.]~I~.::I.[.]~.. . Window in 7-5/8" casing @ 5,318-ft MD Well Inclination @ Window = 64 Degrees 4.5-in liner top @ 5,358-ft MD (150-ft lap) KB. ELEV =63.8-tt Cellar Box ELEV = 29.7-tt 42" Hole 2.875-in x 1.0-in Gas Lift Mandrel @ 116-ft TVD 10-3/4"@ 3,215' MD, 2,424' TVDrkb 2.875-in x 1.0-in GLM I I I I I I I I I I 2-7/8" XN nipple (ID 2.205") Pump, 122 stg. GC2200 Tandem Gas Separator Tandem Seal Section I GSB3 DB UT/L T IL H6 PFS Aflas/HSN Motor, 171 HP KMH 2390 volt, 44 amp PumpMate Sensor w/6 fin Centralizer r- 7.625" Casing Shoe @ 5,508-ft MD, 4,234-ft TVD Well Inclination @ Shoe = 81 Degrees DATE 19 Jan 2004 REV. BY MDG Level 3 Multi-Lateral, 2.875-in ESP Completion COMMENTS 6.125-in OA Lateral a,517-ft MD ....... ....... - - - - -- - -- - - - - - - 4.5-in Slotted Liner w/Hookwall hanger 9.875-in Hole 6.125-in OB Lateral a,525-ft MD - -- ---- - - -- - - 4.5-in Slotted Liner & Hanger Milne Point Unit WELL: MPG-18 API NO:50-029-????? ~ ð~~~ 360 'ë' ~ 8 :!. .c Õ. ¿) -¡; 400 u .~ > ~ COMPANY DETAILS REFERENCE INFORMA nON BP Amoco tip Co..ordinate (NÆ) Reference: Well Cenlre: Plan Moe 0.18, Troe North Vertical (IVD) Reference; 0-14 (343 + 29.5 GL) 63.80 Section (VS) Reference: Slot· (O.OON,O.OOE) Measu~~ra~~=~ ~~~~~~Gt.) 63.80 Calculation Metbod: Minimum CUl'YlÚ\.Lre ~r:r ~~=; ~;v~~~nœrNorth Error Surface: Elliptical + Casing Wamin Method: Rules Based o # IrI l I I pJ I ¡ß ~t/ I <000 <5"00 ~/<I:t> ;J3'" '..5"00 Start Di, 121100': 5318' MD, 4166.45'TVD ~ StartDIr 14/100': 5338' MD,4174 69TVD End DIr : 5545.23' MD, 4205.37' TVD Start Dlr6/100': 5662 99' MD 4193.27'TVD I I I Start Dlr4/100': 5727.95' MD, 4188,8'TVD T~¡¡;)~T,'" 0.-\ .' ¡ ! &! ._~~~i_,d.J. ;...~.:.::~~;.:..._~~~~_.. ':. ~: nv ;\11 End Dir : 7449.73' MD, 4133.8' TVD StartDir4/100' : .... . ... --. . ..... '''(~ur) - _u_... -.- .... _.......:.. ....-... ..... .... ....-... .-.... ... . .. - -1200 -800 -400 400 800 Vertical Section at 296.14" [400ftlin] 2400 SURVEY PROGRAM Depth Fm Depth To SurveylPtun SJ18.00 8516.60 Planned: MPG-18L1 wpOl V3 Plan: MPG·!8LI wpOl (Plan MoeG-181P1an MPG-18LI) Created By: Ken Allen Date: 12J12noo3 Tool MWD+IFR+MS Checked: Date:_ Date:_ Reviewed: WELL DETAll.S N"", +W-S +EI·W Northing Ea.'¢ing Latitude Longitude Slot Plan Moo G·18 2837.13 763.59 6014569.13 557139.22 70027'01.588N 149°32'01.737W WA TARGET DETAILS Nomo TVD +N/...s +FJ·W -"" WI"'" S"'PO MooLl T3 4128.80 917.32 -1869.42 6015472.00 555263.00 Point MœLITI 4133.80 557.57 ·865.05 6015120.00 556270.00 Point MœLIPoIy 4168.80 412J5 ·708.15 6014976.00 556428.00 Polygon MooLl T1 4188.80 174.66 81222 6014750.00 557950.00 Point MoeFault 1 4218.80 ·325.96 1146.43 601425200 558288.00 Polygon SECTION DETAILS Sec MD Inc A2i TVD +N/-S +EJ-W DLeg TFace VSec Target 1 5318.00 64.49 281.00 4166.45 96.06 1207.34 0.00 0.00 -1041.57 2 5338.00 66.89 281.00 4174.69 99.54 1189.45 12.00 0.00 -1023.98 3 5545.23 95.90 281.35 4205.37 138.85 990.59 14.00 0.72 -828.13 4 5662.99 95.90 281.35 4193.27 161.91 875.74 0.00 0.00 -714.87 5 5727.95 92.00 281.35 4188.80 174.66 812.22 6.00 -179.96 -652.22 MoeLl T1 6 5756.27 91.92 282.48 4187.83 180.51 784.53 4.00 94.11 -624.79 7 7264.47 91.92 282.48 4137.34 506.26 -687.21 0.00 0.00 839.96 8 7449.73 90.27 289.71 4133.80 557.57 -865.05 4.00 102.78 1022.22 MoeLl T2 9 8516.60 90.27 289.71 4128.80 917.32 -1869.42 0.00 0.00 2082.36 MoeLl T3 CASING DETAILS No. TVD MD Name Size 4128.80 8516.59 4 1/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Fonnanon 4093.80 5169.13 SBE2-NE 4168.80 5323.52 TSBD-Top OA DRAF c Total Depth: 8516.6' MD, 4128.8' TVD _... ........::\ ~IP(ì.!,q.\ "I":: /' 1200 1600 2000 ·pIIn"y-s.n ;r1.\lt.~~.~Yl1:." COMPANY DETAn..S BP Amoco CalculalÏOD Method: Minimum Curvature == ~~~iodetNor1b Enor Surfàce: Elliptical + Casing Warn! Method: Rules Based I:Jp REFERENCE INFORMATION Co.ordinate{NÆ)Refereoœ: Well Centre: Plan MoeG-18, True North VertiC!>IiT'\!T\\Qal'a......... n,'df'ld.........o"n. \.(')91\ Sect . ... Measur. "'. 'i3.80 . . .~. I SURVEY PROGRAM Depth Fm Depth To SurveylPlan 5318.00 8516,60 Planned: MPO-I8Ll wpOl V3 Tool MWD+IFR+MS Plan: MPG~18Ll wpOl (Plan Mae O-I8lPlan MPG-18LI) Created By: Ken Allen Date: 121t2l2003 Checked: Date:_ Reviewed: Date. 100 WELL DETAIlS I ¡riP l ,I ,I 1/ I .I .I , 1 / ,# ;" # ;< #' W""" +NI-S +FJ-W Northing Eutin. lAt.... Longi1ud< Slot Pian Moe G-t8 2837.13 763.59 6014569.13 557139.22 70"27'OI.588N 149°32'01.737W NiA TARGET DETAILS ...... TVD +N/-S +FJ·W Northing Basting Shap' MoeLt T3 4128.80 91732 -1869.42 6015472.00 555263.00 Point MoeLt 12 4133.80 551.57 -865.05 6015120.00 556270.00 Point MoeLl Poly 4168.80 41235 -708.15 6014976.00 556428.00 Polygon MoeL I TI 4188.80 174.66 812.22 6014150,00 557950.00 Point MoeFaultl 4218.80 ·325.96 1146.43 6014252.00 558288.00 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec Target I 53 I 8.00 64.49 281.00 4166.45 96.06 1207.34 0.00 0.00 -1041.57 2 5338.00 66.89 281.00 4 I 74.69 99.54 I I 89.45 12.00 0.00 -1023.98 3 5545.23 95.90 281.35 4205.37 138.85 990.59 14.00 0.72 -828.13 4 5662.99 95.90 281.35 4193.27 161.91 875.74 0.00 0.00 -714.87 5 5727.95 92.00 281.35 4188.80 174.66 812.22 6.00 -179.96 -652.22 MoeLl II 6 5756.27 91.92 282.48 4187.83 180.51 784.53 4.00 94.11 -624.79 7 7264.47 91.92 282.48 4137.34 506.26 -687.21 0.00 0.00 839.96 8 7449.73 90.27 289.71 4133.80 557.57 -865.05 4.00 102.78 1022.22 MoeLl 12 9 8516.60 90.27 289.71 4128.80 917.32 -1869.42 0.00 0.00 2082.36 MoeLl T3 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 4093.80 5169.13 SBE2-NE 2 4168.80 5323.52 TSBD-Top OA DRAFT COpy ONLY CASING DETAILS No. TVD MD Name 4128.80 8516.59 41/2" Size 4.500 ë ;§ o ~ 50 :;:- 1[ t ~ 1[ " o '" -2500 -2000 -1500 -1000 -500 o West(-)Æast(+) [500ft/in] 500 1000 1500 2000 spel"""l"""y-sun DRIL.L.ING SERVICES 'perry-Sun - Draft Copy e KW A Planning "HoU.UIIt.1JI"IOCOMI"AJ't'I" "'c~~p~ny';'¡'; '.. Field;'.~ >' . isittt' ;""" , . "'Ì}:;~~~: ptan: "im~rri~q~::,::·:::" .; "t§PJgj':8 ;, Plan: MpG-18L 1 MPG-18L1 wp01 Principat: Yes Fietd: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level : " . -- bp ;~~I'~JI:i;~i~~~~~i~~:, ~. ''"\'', ..... . Site: M pt G Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6011726.58 ft From: Map Easting: 556397.19 ft Position Uncertainty: 0.00 ft Ground Levet: 0.00 ft Welt: Plan Moe G-18 Planned Well Surface from Joe C. Welt Posttion: +N/-S 2837.13 ft Northing: 6014569.13 ft +E/-W 763.59 ft Easting: 557139.22 ft Position Uncertainty: 0.00 ft Weltpath: Plan MPG-18L 1 Current Datum: Magnetic Data: Ftetd Strength: Verticat Section: D-14 ( 34.3 + 29.5 GL ) 12/9/2003 57547 nT Depth From (TVD) ft 34.30 Casing Points .. _ __ __ _. ____ _on. ..__ .. . . . - ----.--------.- - -- . Height 63.80 ft +N/-S ft 0.00 :\1\) TV I) ft ft ..-------. 8516.59 4128.80 Uiamctel' Hole Size !\amc in in .. . __nn__.. __ 4.500 6.125 41/2" Formations fohriiltions SBE2-NE TSBD-Top OA TSBC-Base OA ...... , '.;:. ':; """'" ~~;;~iPtiO?,Dir: TVD ft 4128.80 4133.80 4168.80 4168.80 4168.80 4168.80 4168.80 4168.80 4168.80 4188.80 MoeL 1 T3 MoeL 1 T2 MoeL 1 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 MoeL 1 ,T1 :::": ...... . . . ..... .. . ... . . .. .. '+N{::S . ..' . ·ft· 917.32 557.57 412.35 412.35 -17.47 191.32 616.12 1129.89 894.29 174.66 +E/-W ft -1869.42 -865.05 -708.15 -708.15 1347.82 1379.42 -674.58 -2070.82 -2127.63 812.22 Date Composed: Version: Tied-to: 12/11/2003 3 From: Definitive Path Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Latitude: 70 26 33.685 N Longitude: 149 32 24.162 W North Reference: True Grid Convergence: 0.43 deg Slot Name: Latitude: 70 27 1.588 N Longitude: 149 32 1.737 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angte: +E/-W ft 0.00 Plan MPG-18 5318.00 ft Mean Sea Level 25.08 deg 80.85 deg Direction deg 296.14 n'__________ ._____n ____,.. _ ........_. ..,·;..Lithology . Dip Angle . deg 0.00 0.00 0.00 . ~~:~~~"Ë~:;i~g . . ft ft', .'.." 6015472.00 555263.00 . <-- Latitude---> J:)~gMtn Sec 70 27 10.607 N 6015120.00 556270.00 6014976.00 556428.00 6014976.00 556428.00 6014562.00 558487.00 6014771.00 558517.00 6015180.00 556460.00 6015683.00 555060.00 6015447.00 555005.00 6014750.00 557950.00 70 27 7.071 N 70 27 5.643 N 70 27 5.643 N 70 27 1.415 N 70 27 3.468 N 70 27 7.647 N 70 27 12.697 N 70 27 10.380 N 70 27 3.305 N ] - --.,--.--.--- --- - ----- --- .--- Dip Direction deg 0.00 0.00 0.00 <- Longitude --> Deg Min Sec 149 32 56.645 W 149 32 27.144 W 149 32 22.535 W 149 32 22.535 W 1493122.154W 149 31 21.224 W 149 32 21.550 W 149 33 2.562 W 149 33 4.229 W 149 31 37.883 W spel""'l""'Y-sun DRILLING SERVIC:ES AoK.U.U"'raTON('()MP~ ~perrY-Sun - Draft Copye KW A Planning Company: BR. Amoco ,.'". ,~::~~: ·,~i~f ~,~~~:,~~¡::.: ::~~;:.~~i~'/",l:~::·~·;~Þ~1~~1 Dii.te:, 12/121200:r;.·:;';i:·~'i,;:Timër'13:32:25.. .' '. ..( .,f~g~:; .. Co-ördinate(NE)llefetence: . ""Well: Plari'MoeG-.18,True North .i. . Vcrticä1·(TVD}:.Re:(~re.6.c~;:.,::: P~1.4.( ·34~3.·.+·29;;g::ß~;)·63..8...:· ,", ...:/.;.:<::::.;;:::'....:;~:> :', ',": Section (VS) Rcre~~nc¢.·:··· '::,":' . Well (0400N. O.oo.E~2ge..14Azì)··· ....::.....,. :,.:":'"". n: ._,___._~~~~~italculaÙ~9·1,VI~thod:_.~:.~~~mum ~ûrvature,,;:, "Db: . Oraële' .':" :,:',' Name -- Moe Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 ·'.·~~~rW~·~?~')riir. Plan Section Information ':OMD. .Jt·; 5318.00 5338.00 5545.23 5662.99 5727.95 5756.27 7264.47 7449.73 8516.60 Survey ··::}¡\;t~D. . ..",:.". 5169.13 /5318.00 5323.52 5325.00 5338.00 5350.00 5375.00 5400.00 5425.00 5450.00 5475.00 5500.00 5525.00 5545.23 5600.00 5662.99 5700.00 5727.95 5756.27 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 <',',;)::~~~:"" ; 64.49 66.89 95.90 95.90 92.00 91.92 91.92 90.27 90.27 .'. AZim··· . , deg 281.00 281.00 281.35 281.35 281.35 282.48 282.48 289.71 289.71 ..I~~:'::' 57.04 64.49 65.15 65.33 66.89 AZiin , deg 281.00 281.00 281.00 281.00 281.00 68.57 281.02 72.07 281.07 75.57 281.11 79.07 281.16 82.57 281.20 86.07 281.24 89.57 281.28 93.07 281.32 95.90 281.35 95.90 281.35 95.90 281.35 93.68 281.35 92.00 281.35 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 91.92 282.48 6900.00 91.92 282.48 7000.00 91.92 282.48 . ". . "}~:>.' "':." '. ':::> rirD " . ····:ft..· 4218.80 4218.80 4218.80 4218.80 4218.80 4166.45 4174.69 4205.37 4193.27 4188.80 4187.83 4137.34 4133.80 4128.80 " :··,t~~~;,;'}:;;, 96.06 99.54 138.85 161.91 174.66 180.51 506.26 557.57 917.32 '+Ni;;S .:ft -325.96 -325.96 117.80 775.47 117.80 +E/-W ·ft 1146.43 1146.43 -1162.46 -2413.58 -1162.46 +E/-W ft 1207.34 1189.45 990.59 875.74 812.22 784.53 -687.21 -865.05 -1869.42 ·TVD·'·"·'··' ii,' .·.:1t;i}'~"::', 4093.80 4166.45 4168.80 4169.42 4174.69 ~~s ~VD::,,;~:!j:'i':¡":',:MriN" . . 4030.00 6014650.64 4102.65 6014674.43 4105.00 6014675.35 4105.62 6014675,60 4110.89 6014677.77 4179.23 4187.65 4194.62 4200.11 4204.10 4206.57 4207.53 4206.95 4205.37 4199.74 4193.27 4190.18 4188.80 4187.83 4186.37 4183.02 4179.67 4176.32 4172.98 4169.63 4166.28 4162.93 4159.59 4156.24 4152.89 4115.43 4123.85 4130.82 4136.31 4140.30 4142.77 4143.73 4143.15 4141.57 4135,94 4129.47 4126.38 4125.00 4124.03 4122.57 4119.22 4115.87 4112.52 4109.18 4105.83 4102.48 4099.13 4095.79 4092.44 4089.09 6014679.81 6014684.14 6014688.58 6014693.10 6014697.70 6014702.35 6014707.04 6014711.75 6014715.56 6014725.87 6014737.74 6014744.72 6014750.00 6014755.63 6014764.75 6014785,60 6014806.44 6014827.29 6014848.14 6014868.99 6014889.83 6014910.68 6014931.53 6014952.38 6014973.23 4149.54 4085.74 6014994.07 4146.19 4082.39 6015014.92 bp . . M . ",' J\1:ip <..,- Latitude"'~.·:7> < Lo 't d Nort·ahP,·ng . D·-eg··:·:.:.M.···..?ng.·..I.uS····e"ce ~> <;'Easting ... ,Deg Min See ft '<'ft·.·,··' 6014252.00 558288.00 6014252.00 558288.00 6014678.00 555976.00 6015326.00 554720.00 6014678.00 555976.00 70 26 58.381 N 70 26 58.381 N 70 27 2.745 N 70 27 9.210 N 70 27 2.745 N DLS ".' ·BUi.ld,...:.. Turn,.·, deg/1 OOft ,d~9110Oft~egI100ft ' 0.00 12.00 14.00 0.00 6.00 4.00 0.00 4.00 0.00 0.00 12.00 14.00 0.00 -6.00 -0.29 0.00 -0.89 0.00 0.00 0.00 0.17 0.00 0.00 3.99 0.00 3.90 0.00 '1'1'0·...· ·....:deg 0.00 0.00 0.72 0.00 -179.96 94.11 0.00 102.78 0.00 M~PE ":;\":";".~~'" ·'.:.;d~~b~ 558473.28 -1166.88 0.00 558345.68 -1041.57 5.00 558340.77 -1036.75 12.00 558339.44 -1035.45 12.00 558327.76 -1023.98 12.00 558316.85 558293.72 558270.13 558246.17 558221.92 558197.49 558172.96 558148.42 558128.62 558075.13 558013.61 557977.40 557950.00 557922.26 557879.52 557781.79 557684.05 557586.32 557488.58 557390.85 557293.11 557195.37 557097.64 556999.90 556902.17 556804.43 556706.70 -1013.26 -990.53 -967.35 -943.80 -919.96 -895.92 -871.78 -847.62 -828.13 -775.45 -714.87 -679.21 -652.22 -624.79 -582.32 -485.20 -388.08 -290.96 -193.84 -96.72 0.40 97.51 194.63 291.75 388.87 485.99 583.11 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 0.00 0.00 6.00 6.00 4.00 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 TFO.. deg 0.00 0.00 360.00 0.00 0.00 0.67 0.67 0.67 0.67 0.00 0.00 180.04 180.04 94.11 0.00 149 31 28.070 W 149 31 28.070 W 149 32 35.877 W 149 33 12.627 W 149 32 35.877 W MoeL 1 T1 MoeL 1 T2 MoeL 1 T3 SBE2-NE MWD+IFR+MS - MoeL 1 Poly MWD+IFR+MS MWD+IFR+MS 0.72 0.72 0.70 0.69 0.68 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MoeL 1 T1 MWD+IFR+MS MWD+IFR+MS 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 0.00 MWD+IFR+MS 0.00 MWD+IFR+MS .\ U4WM'ltTON ("()fIoU"o!,N\ 'perry-Sun - Draft Copy e KW A Planning bp 5peí'í'y-sun DRILLING seRVices [company:sp Amoco Field: Milne Point Site: M pt G Pad _~;:_:~~th:. ";Þ::~~Þd~-J~1 Survey Date: 12/12/2Ó03i.Tr¡rÖr';:h:32:~5. Page: 3 Co-ordinate(NE) Reference: .' ·'Wëll: Plan Moe G-18, True North Vertical (TVD)n.~ferenêè:.. . .0-14 (34.3 + 29.5 GL) 63.8 .... S'êcti.on (VS}.Refer",nc",.:;; . "Well (0.00N,O.00E,296.14Azi) ., ..... . SUr:V:ey"CalClitatiön Methòd: Minimum CU~~_~~~~._~:_._9racle __ .......,,::: v____ _._.~__._ __M__ 1\1D Ine! Azim···..·· .TVD Sys 1'VD;" 1\1apN MapE VS.;... .... DLS 1'1<"0 ".1'001 ft deg deg······· . ft '. ft n':', ,Jt ft . ··'·ft ..;.:....... .. deg/100n deg ...... ..:.i.::.:..... ~___w__ --.--.--. 7100.00 91.92 282.48 4142.85 4079.05 6015035.77 556608.96 680.22 0.00 0.00 MWD+IFR+MS 7200.00 91.92 282.48 4139.50 4075.70 6015056.62 556511.23 777.34 0.00 0.00 MWD+IFR+MS 7264.47 91.92 282.48 4137.34 4073.54 6015070.06 556448.21 839.96 0.00 0.00 MWD+IFR+MS 7300.00 91.60 283.87 4136.25 4072.45 6015077.88 556413.58 874.56 4.00 102.78 MWD+IFR+MS 7400.00 90.71 287.77 4134.23 4070.43 6015104.39 556317.21 972.90 4.00 102.82 MWD+IFR+MS 7449.73 90.27 289.71 4133.80 4070.00 6015120.00 556270.00 1022.22 4.00 102.90 MoeL 1 T2 7500.00 90.27 289.71 4133.56 4069.76 6015136.59 556222.55 1072.17 0.00 0.00 MWD+IFR+MS 7600.00 90.27 289.71 4133.10 4069.30 6015169.58 556128.16 1171.54 0.00 0.00 MWD+IFR+MS 7700.00 90.27 289.71 4132.63 4068.83 6015202.57 556033.77 1270.91 0.00 0.00 MWD+IFR+MS 7800.00 90.27 289.71 4132.16 4068.36 6015235.57 555939.39 1370.28 0.00 0.00 MWD+IFR+MS 7900.00 90.27 289.71 4131.69 4067.89 6015268.56 555845.00 1469.65 0.00 0.00 MWD+IFR+MS 8000.00 90.27 289.71 4131.22 4067.42 6015301.56 555750.61 1569.02 0.00 0.00 MWD+IFR+MS 8100.00 90.27 289.71 4130.75 4066.95 6015334.55 555656.22 1668.39 0.00 0.00 MWD+IFR+MS 8200.00 90.27 289.71 4130.28 4066.48 6015367.54 555561.83 1767.76 0.00 0.00 MWD+IFR+MS 8300.00 90.27 289.71 4129.82 4066.02 6015400.54 555467.44 1867.13 0.00 0.00 MWD+IFR+MS 8400.00 90.27 289.71 4129.35 4065.55 6015433.53 555373.05 1966.50 0.00 0.00 MWD+IFR+MS 8500.00 90.27 289.71 4128.88 4065.08 6015466.52 555278.66 2065.87 0.00 0.00 MWD+IFR+MS " 8516.60 90.27 289.71 4128.80 . 4065.00 6015472.00 555263.00 2082.36 0.00 0.00 MoeL 1 T3 Löcation SFD 1/22/2004 '-J <::) (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. we II 20 MC 25.005 PERMIT TO DRILL e e e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRJATELETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME m/~u G,-/g ¿I 2£-) c¡ -02- / PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function of the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject -to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issu~nce of a conser¡ation order~ving a ~/ spacing exception. (Company Name) assumes the liability of any protest to the spacinge:xception that may occur. DRY DITCH AU dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample h:itervals through target zones. Rev: 07110/02 C\jody\templates ()f;) ) LÍ(4- SPACING EXCEPTION NEEDED: CO 477 allows spacing rule modifications by Administrative Approval. Well may be drilled but not perforated or produced until such approval is granted. SFD Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date Appr SFD Date 1/22/2004 35 36 37 38 39 S~abed .conditioo survey (if CQntact namelphoneJorJl\le~kly progress reports [explQratory .only] off-sh.ore) Y~s Yes NA .NA NA .S~tsmicanalysjs Qf sbaJlow gas.z.ooes Expectect r~servoir ~re.ssure ts.1 0.<4 ppg EMW; w Hydrates. have be.en eocountered tn .G-Pad. wejls. be drjlled with t Mitigation disc!Jss.ed in Orillin.9.Hazards se.ctio.n, Geology Appr ~ Date 1/22/2004 22 23 24 25 26 27 28 29 30 31 32 33 34 P~(I1' it .D.ata.PJesentect on. pote.ntial .oveJpressure .zones can be issued 'ilIa hydrogen. s.ulfide meas.ures Js presence Mecba.nicaLcondjtton o{ wells wilhin ~OR verifiect (for. s.ervice weIJ onJy) Qf H2S gas probable test to (puJ .Choke manifold cQmpJies w/API R~-53 (May 64) Work will occ.ur without .BOPE.press raliog appropriate; psig tn.comments) .DJiLliog BOPEs,d.oJhey meet reguJation flujd. program schematic&. eq.uip Ra.re-drilt has. a tO~03 fQr abandonment Adequate weHbore separ¡;¡tio.n ~roposed it be~o ¡;¡PPJoved .AdequateJankage.oJ re.serye pit .C.asing designs acteQuale f.or C.T, B.&permafrost .CMT. v.ol adequate. to circ.ulateoncond.uctor & su.rf.csg .CMT. vol adequate. to tie-tnJQng .string to.surf csg .eMT. will COyer aU I<oQwnprQductiYe bQrizons 18 19 20 21 .C.ondu.ctor .S.urface casing pJotecls all.known. USQWs NA NA NA NA No. Y~s Y~s NA y~s NA Y~s y~s Y~s .Y~s Y~s No. NA 0,9. ppg mud.. .operation .shutdown Test t.o3500. psi. .MSP 17.50 psi.. Rdjverler Jeq.uired, dQes meet reguJations ist adequat~ Sidetrack. Max. MW. t1,Oppg. Ooy.oo 14. La.teral. Slotte.d, Engineering Appr e Date 1/22/2004 IQcated pr.oper .distance. Administration 12 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 string.pJovided only) Pre-produ.cect injector; J:luratiQn.of pre-proJ:luGlion I~ss than 3 montbs (For.serytce well onJy) .ACMPJ:ïndingof Consistencyh.as been Jssued. for this project. 15-day wait WellJQcated within area and. strata authorized by. .Ajl wells.within.114.mile.area.of review id~otified (F.or servic.ewe Pe(l1' it Permit Can permit be approved before InjeGlioo Ord~r # (put 10# in c.omm~nts). (For can be issued witbQut co.nservation order can be issued witbQut ad.mioistratille.appr.ovaJ .Oper.ator bas. appropriate. bond tnJorce .S.ufficient Jf.deviated, .O~er.ator only affected party js. wejlboJe plaUocJuJ:lect .acreage.aYailable from QtbeJ wells in.dJiLliog unit Well Well Well IQcat~d pr.oper .distance. P~rmit fee attacbeJ:l leas~number .appropriate. .U.nique welln.am~.and oumber IQcat~d in.a. d.efined ~ool from drijling unitbound.ary NC Initial ClassfType .NA y~s .Y~S Y~s Y~s N.o. No. Y~s Yes Y~s Y~s No Yes NA .NA NA NA LaJeraldrilled fromexistlng pact. SF>ACINGEXCEPTION NE.EDED; Well is Jo.cated less than 200'. from O-S¡;¡nd. perforations in.M~U G-12 (ioactille.PJQd.uceJ), DEV Well PEND Name: MILNE PT UNIT SB G-18L 1 GeoArea 890 Unit Per .20 MC .25.005. (~l fee iswaived {or mvltilaterat 11328 Program DEV On/Off Shore On Well Annular Disposal bore seg ~ o e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infomlation. Sperry-Sun Drtlting Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 07 12:45:01 2004 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Tape Header Service name............ .LISTPE Date.................... .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA e # / 2~'--c-t ¥ ). ~ \.., - D ). I Scientific Technical Services Scientific Technical Services MPG-18 Ll 500292319460 BP Exploration (Alaska) I Inc Sperry-Sun Drilling Services 07 -APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002917922 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002917922 T. MCGUIRE E. VAVGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0002917922 C.A. DEMOSKI E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 27 13N 10E 2134 3462 63.70 29.70 # WELL CASING RECORD OPEN HOLE CASING DRILLERS MWD RUN 6 MW0002917922 C.A. DEMOSKI E. VAUGHN 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT sta 13.500 9.875 6.750 e (IN) SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 3225.0 5278.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS MPG-18 AT 5278'MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MWD RUN 6 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND MILL WINDOW. THE TOP OF THE WHIPSTOCK WAS AT 5278'MD AND THE BOTTOM WAS AT 5290'MD. ONLY SROP DATA ARE PRESENTED. 7. MWD RUN 7 COMPRISED DIRECTIONAL WITH DGR¡ EWR4¡ AND AT-BIT-INCLINATION (ABI) . 8. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 3/4/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 9. MWD RUNS 1, 2, 6, 7 REPRESENT WELL MPG-18 L1 WITH API#: 50-029-23194-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8563'MD/4145'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 e e and clipped curves; all bit runs merged. .5000 START DEPTH 70.5 112.5 3200.0 3200.0 3200.0 3200.0 3200.0 STOP DEPTH 8500.0 8563.0 8507.0 8507.0 8507.0 8507.0 8507.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 6 7 MERGED MAIN PASS. $ MERGE TOP 70.5 3235.0 5278.5 5302.0 MERGE BASE 3235.0 5278.0 5302.0 8563.0 # Data Format Specification Record Data Record Type.... ............ ..0 Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units... ....... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 8563 4316.75 16986 70.5 8563 ROP MWD FT/H 0.02 2132.39 212.094 16902 112.5 8563 GR MWD API 9.05 124.39 68.8631 16860 70.5 8500 RPX MWD OHMM 0.06 1623.29 8.30504 10615 3200 8507 RPS MWD OHMM 0.12 2000 15.1307 10615 3200 8507 RPM MWD OHMM 0.1 2000 15.3967 10615 3200 8507 RPD MWD OHMM 0.08 2000 20.4629 10615 3200 8507 FET MWD HOUR 0.12 135.87 1.04961 10615 3200 8507 e e First Reading For Entire File......... .70.5 Last Reading For Entire File.......... .8563 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/04/07 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 70.5 112.5 STOP DEPTH 3189.0 3235.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-FEB-04 Insite 66.37 Memory 3235.0 112.0 3235.0 .0 63.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 155790 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 .0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): SPUD MUD 8.90 200.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: e e 9.5 400 12.8 .000 .000 .000 .000 .0 75.2 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... .......0 Data Specification Block Type. ....0 Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point......... .... . Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value....... ............. ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 70.5 3235 1652.75 6330 70.5 3235 ROP MWD010 FT/H 0.97 1302.06 231.05 6246 112.5 3235 GR MWD010 API 22.55 124.39 67.7197 6238 70.5 3189 First Reading For Entire File......... .70.5 Last Reading For Entire File.......... .3235 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record~5535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 3189.5 3200.0 3200.0 3200.0 3200.0 3200.0 3235.5 STOP DEPTH 5278.0 5278.0 5278.0 5278.0 5278.0 5278.0 5278.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 20-FEB-04 Insite 66.37 Memory 5278.0 3235.0 5278.0 7.1 67.1 TOOL NUMBER 149205 136749 9.875 3225.0 LSND 10.80 55.0 8.5 1200 4.8 1. 900 1. 260 1. 700 2.400 68.0 105.8 68.0 68.0 REMARKS: e e $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. ................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3189.5 5278 4233.75 4178 3189.5 5278 ROP MWD020 FT/H 2.47 2132.39 234.093 4086 3235.5 5278 GR MWD020 API 9.05 113.62 62.0357 4178 3189.5 5278 RPX MWD020 OHMM 0.06 75.68 8.32832 4157 3200 5278 RPS MWD020 OHMM 0.12 2000 11.0648 4157 3200 5278 RPM MWD020 OHMM 0.1 2000 12.9288 4157 3200 5278 RPD MWD020 OHMM 0.08 2000 25.4892 4157 3200 5278 FET MWD020 HOUR 0.12 43.79 1.20662 4157 3200 5278 First Reading For Entire File......... .3189.5 Last Reading For Entire File.......... .5278 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name........ .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ e e header data for each bit run in separate files. 6 .5000 START DEPTH 5278.5 STOP DEPTH 5302.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 25-FEB-04 Insite 66.37 Memory 5302.0 5278.0 5302.0 54.6 54.6 TOOL NUMBER 6.750 5278.0 FLO-PRO 10.80 47.0 9.5 155000 5.2 .000 .000 .000 .000 .0 77.0 .0 .0 _e e Name Service Order Units Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD060 FT/H Min 5278.5 2.9 Max 5302 77.04 First Reading 5278.5 5278.5 Last Reading 5302 5302 Mean 5290.25 38.3358 Nsam 48 48 First Reading For Entire File........ ..5278.5 Last Reading For Entire File.......... .5302 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ....04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/07 Maximum Physical Record..65535 File Type. ............ ...LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 5278.5 5278.5 5278.5 5278.5 5278.5 5278.5 5302.5 STOP DEPTH 8507.0 8507.0 8507.0 8507.0 8500.0 8507.0 8563.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 27-FEB-04 Insite 66.37 Memory 8563.0 5302.0 8563.0 MINIMUM ANGLE: MAXIMUM ANGLE: e # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ....Feet Data Reference Point......... .... .Undefined Frame Spacing. .................. ..60 .1IN Max frames per record............ . Undefined Absent value... .................. .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 54.7 94.0 TOOL NUMBER 160796 148574 6.750 5278.0 FLO-PRO 10.80 46.0 8.5 130000 5.6 .200 .160 .130 .550 78.0 99.7 74.0 80.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5278.5 8563 6920.75 6570 5278.5 8563 ROP MWD070 FT/H 0.02 1251. 02 181.437 6522 5302.5 8563 GR MWD070 API 41. 97 116.48 74.3965 6444 5278.5 8500 RPX MWD070 OHMM 0.5 1623.29 8.29005 6458 5278.5 8507 RPS MWD070 OHMM 2.09 2000 17.7479 6458 5278.5 8507 2._ ft RPM MWD070 OHMM 2000 16.9853 6458 5278.5 8507 RPD MWD070 OHMM 2.67 2000 17.2274 6458 5278.5 8507 FET MWD070 HOUR 0.25 135.87 0.948532 6458 5278.5 8507 First Reading For Entire File......... .5278.5 Last Reading For Entire File.. ........ .8563 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/04/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .04/04/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments...... .......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
