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
196-176
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File Complete RESCAN !'1 Color items- Pages: GraYScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type .OVERSIZED .Logs of various kinds Other co....,.: Scanned by'~ve~M~dred. D',reth, Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mik:lred Daretha Nathan Lowell Date: /s/ , STATE OF ALASKA , ALASKA( - AND GAS CONSERVATION COMt\( ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil DGas 181 Plugged 181 Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 0 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 8/22/2003 196-176 303-217 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 02/16/1997 50- 029-22718-00-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Number 'tJ~1 .~ .èJ.7l Surface: 02/23/1997 MPK-21i .. II> 3620' NSL, 2089' WEL, SEC. 03, T12N, R11E, UM 8. Elevation in feet (indicate KB, OF, etc.) 15. Field and Pool Top of Productive Horizon: 2574' NSL, 1930' WEL, SEC. 04, T12N, R11E, UM KBE = 61.29' Milne Point Unit 1 Kuparuk River Sands Total Depth: 9. Plug Back Depth (MD+TVD) 2528' NSL, 2180' WEL, SEC. 04, T12N, R11E, UM 3712 + 3500 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 584468 y- 6005755 Zone- ASP4 9845 + 7432 Ft ADL 375133 TPI: x- 579361 y- 6004653 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 579112 y- 6004604 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes 181 No NI A MSL 1800' (Approx.) 21. Logs Run: MWD , LWD , ESS , SBT/GRlCCL ,GRlJB 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DePTH HOLE' SIZE WT. PER FT. GRADE "Top, BOTTOM,' SIZE, CEMENTING RECORD .. AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 sx Arctic Set I lAoorox.) 9-5/8" 40# L-80 36' 3832' 12-114" 1260 sx PF 'E', 700 sx Class 'G' 7" 26# L-80 3900' 9825' 8-1/2" 460 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and .'" "".., ""':""""'.' , ..",' '", c."c= 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 25. ACID,FRAqtURE,CEMENT SQUEEZE, ETC.' .' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9145' Set EZSV with 25.8 Bbls Class 'G' cement with 5 Bbls on top of EZSV 3950' Set 7" CIBP with 15 Bbls Class 'G' cement 3722' Set 9-5/8" CIBP 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-Bel GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-Bel GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA ta - -- - -- ," Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (aU :~~ ',iiM ~ssary). Submit core chips; if none, state "none".. ,- ,11 Y '.... ...,.- DEC - 3 2003 None ~ ~ .~:'>.~ 't ~ If(Ij 'lJR' I~ fN ~ L Alaska Oil & Gas Cons. Commission ~~~ _o~ Anchorage \-;)(5 ~ Form 10-407 Revised 2/2003 mQ~TINUED ON REVERSE SIDE C::I" h¡~of~rHi:"T' 1!"t.'.X', f1\. G~ Iri,. ..' 2 11.>.', Ò)~{lA\t~II~!t:,ll, ULQ,p Q'j) ~ '. u,,~ ~~ ~BFl 1. DEC ¡j~~ ¡lO3 28. GEOLOGIC MARKERS{ 29. { -ìRMATION TESTS Include and briefly ~"'I nmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Top of Kuparuk 9192' 6945' None KC1 9473' 7160' Top of Kuparuk 'B' 9502' 7182' RECEIVED DEC - 3 2003 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. F-~ - Signed sondrf\..Stewman.x~OÅ",::~r[J Á.Ä ~ Title Technical Assistant MPK-21i 196-176 303-217 Well Number Permit No.1 Aooroval No. Date ld - O~ ~O3 Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ORIGiNAL Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/20/2003 8/21/2003 8/22/2003 ( Page 1 of 3 BP EXPLORATION Operations Summary Report MPK-21 MPK-21 TEMP ABANDON NABORS ALASKA DRILLING I NABORS 4ES From - To Hours 08:00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 02:30 02:30 - 04:30 04:30 - 05:00 05:00 - 06:30 06:30 - 09:00 09:00 - 12:00 12:00 - 13:00 13:00 -14:00 14:00 - 21 :00 21 :00 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 02:30 02:30 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:30 Task Code NPT Phase 4.00 MOB N 1.50 MOB P 0.50 MOB P 8.00 MOB P 1.50 RIGU P 0.50 RIGU P 1.50 RIGU P 0.50 WHSUR P 0.50 KILL P 2.00 KILL P WAIT PRE PRE PRE PRE PRE PRE PRE INTERV INTERV INTERV 0.50 WHSUR P INTERV 1.50 WHSUR P 2.50 BOPSU¡:; P 3.00 BOPSU¡:; P 1.00 BOPSU¡:; P 1.00 PULL P INTERV INTERV INTERV INTERV INTERV 7.00 PULL P INTERV 1.00 PULL P 0.50 REMCM P 1.50 REMCM P 1.00 REMCM P 1.50 REMCM P 4.50 REMCM P INTERV INTERV INTERV INTERV INTERV INTERV 0.50 REMCM P INTERV 1.00 REMCM P INTERV 0.50 REMCM P INTERV 0.50 REMCM P INTERV 1.00 REMCM P INTERV Start: 8/20/2003 Rig Release: 8/25/2003 Rig Number: 4es Spud Date: 2/16/1997 End: 8/25/2003 Description of Operations Wait on matting boards to be set on K-pad access road. Rig down. Scope & lower derrick. Prepare to move. Hold PJSM. Move rig from J-01 to K-21. Spot in sub, pits & pipe shed. R/U tiger tank. Berm around rig. Rig up kill lines & take on fluid. Raise & scope derrick. Accepted rig @ 0100 Hrs, 8/21/2003. M/U lubricator. Pull BPV. & LID lubricator. Hold Pre-spud & PJSM. Test lines to 3500 psi. Ok. Open well. SITP 10 psi, SI annulus pressure 40 psi. Circulate well @ 5 BPM, 550 psi. Recovered 167 Bbls to tiger tank. Pumped total of 355 bbls. SID & monitor well. Well on vacum. Install TWC & test. Pumped down annulus as follows: 1 BPM @ 110 psi, 2 BPM @ 290 psi, 3 BPM @ 430 psi, 4 BPM @ 550 psi. PJSM. Nipple down tree. PJSM. N/U 13 5/8" x 5M BOPE. I/A on vacuum. Conduct full test on BOPE. AOGCC State Rep Jeff Jones given 24 hr notice & waived witnessing test. No failures. PJSM. P/U lubricator, pull 2 way check & LID lubricator. PJSM. Pick up landing joint & screw into tubing hanger. BOLDs. Tubing & I/A on vacuum. Pull to hanger to floor, 80K up wt. LID hanger & pups. PJSM. POOH laying down 3 1/2" EUE 8 rnd tbg, filling hole 2-3x displacement factor. Recovered 299 jts + 15.65' cut off jt. cut looked clean. Clear & clean rig floor. R/U to P/U & RIH w/3 1/2" DP. Install wear bushing. P/U Halliburton EZSV & setting tool. P/U 3 1/2" DP 1x1 & RIH. Con't to P/U 3 1/2" DP & RIH. Adjust drawworks brakes. Repair leak on skate. Con't to P/U 3 1/2" DP & RIH. Lightly tag top of tubing stub @ 9151' DPM, 27' in on jt # 288. 129K up wt, 95K down wt. Rig up cementers. PJSM. WI EZSV @ 9145' & pipe in tension, rotate pipe 35 turns to the right, 6000 ft Ibs torque @ surface. Pick up 15K over up wt to 145K, wait a minute, continue up to 160K, wait a minute & shear brass sleeve on setting tool @ 178K, (49K over up wt). Pull up to 136' DPM, rotate to the right 35 turns & pick up free, OK. PJSM. Pressure test 7" casing from surface to EZSV @ 9145' @ 3000 psi I 15 minutes, charted. Bleed off & sting into EZSV, set down 20K, & establish injection rates of 3 bpm @ 450 psi, 3.5 bpm @ 700 psi, & 4 bpm @ 1100 psi. Visitors on rig. (1/2) hr stand down. Review of safety, attitude & performance of rig. PJSM wI all hands concerned. Review of cementing job & associated hazards. Line up & pump 5 bbls fresh water, pressure test lines to 4000 psi, OK. Pump 5 bbls fresh water @ 3 bpm 1250 psi, followed by 25.8 bbls 15.8 ppg class G cement & 5 bbls fresh water. Displace wI seawater @ 3 bpm I 50 psi. WI 22 bbls away, see seawater catch up to cement, 3 bpm I 175 psi. WI 50 bbls Printed: 9/2/2003 9:59: 13 AM ( BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPK-21 Common Well Name: MPK-21 Spud Date: 2/16/1997 Event Name: TEMP ABANDON Start: 8/20/2003 End: 8/25/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/25/2003 Rig Name: NABORS 4ES Rig Number: 4es Date From - To Hours Task Code NPT Phase Description of Operations 8/22/2003 09:30 - 10:30 1.00 REMCM P INTERV seawater pumped & 5 bbls cement left in DP, see maximum pressure of 730 psi @ 3 bpm. Unsting from EZSV & pick up 10'. Pump 2 bbls cement on top of EZSV & POOH & stand / back (3) stands, letting remaining cement fall out of DP. Approximately 5 bbls cement left on top of EZSV. 10:30 - 11 :30 1.00 REMCM P INTERV PJSM. Close annular preventor & reverse circulate 125 bbls, (2) drill pipe volumes, @ 4 bpm I 1000 psi. Grey water back @ btms up, but no cement, OK. 11:30 -14:30 3.00 REMCM P INTERV POOH laying down 3 1/2" DP & standing back enough for next step in the operation. 14:30 - 16:00 1.50 REMCM P INTERV POOH & stand back stands in derrick. 16:00 - 16:30 0.50 REMCM P INTERV Cut & slip drilling line. 16:30-17:30 1.00 REMCM P INTERV Finish POOH & stand back DP in derrick. LID stinger assy for EZSV. 17:30-18:00 0.50 REMCM P INTERV Clear & clean rig floor. 18:00 - 20:00 2.00 TA P INTERV M/U EZ-BP. RIH on 3 1/2" DP. 20:00 - 21 :00 1.00 TA P INTERV SET EZ-BP @ 3950'. Rotate off & pull 45K to shear out. Slack off 20 k & check set. Pressure up to 3000 psi & test BP for 15 min, OK. 21 :00 - 23:30 2.50 TA P INTERV POOH & LID setting tool. Hold PJSM. M/U mechanical cutter & Circulate thru tool to test same. 23:30 - 00:00 0.50 TA P INTERV RIH wI cutter on 3 1/2" DP. 8/23/2003 00:00 - 04:00 4.00 TA P INTERV Con't to RIH. Took weight wI 24 stands in hole. ( 2328'). Then fell thru. POOH & check cutter. Cutter opened while going in hole & chipped cutter. Replace cutter & wired close. RIH to 3900' 04:00 - 06:00 2.00 TA P INTERV P/U kelly Space out & cut 7" casing. P/U 67K, S/O 64K, Rot 65K. 50 RPMs, Torque 3000 ftllbs, PP 1000 psi, 4.5 BPM. Torque dropped off to 60 amps from 150. Pressure decreased from 1000 to 550 psi. Annulus pressure increased from 10 to 180 psi. Slacked off & got good indication of cut. Monitor well. 06:00 - 07:00 1.00 TA P INTERV PJSM. POOH, stand back 14 stands. Observe well. Very slight flow. 07:00 - 11 :30 4.50 TA N FLUD INTERV Monitor well. PJSM. Attempt to circulate freeze protect out of 7" x 9 5/8" annulus, 2 bpm 1800 psi. No returns. 7" x 9 5/8" annulus = 0 psi. PJSM. Line up to circulate hole volume @ 2700' & circulate @ 4bpm I 300 psi, 100 bbls. Flow up 3 1/2" DP x 7" annulus, & slight flow up DP. Weight up to 9 ppg & circulate @ 3 bpm 1200 psi I 100 bbls. Monitor well. Well is stable with slight migration to 7" x 9 5/8" annulus. 11 :30 - 12:30 1.00 TA N FLUD INTERV PJSM. RIH to 3850'. Monitor well, OK. 12:30 -13:30 1.00 TA N FLUD INTERV PJSM. Circulate 9 ppg around @ 4 bpm I 350 psi I 150 bbls. 9 5/8" x 7" annulus up to 125 psi now. Well stable. 13:30 - 15:30 2.00 TA P INTERV PJSM. POOH & LID 37 jts 31/2" DP & stand back remainder. Well remaining stable. 15:30 - 16:00 0.50 TA P INTERV LID Baker Multi String Cutter Assembly. Blades show wear to 8 1/2" extended....looks like good cut. 16:00 - 16:30 0.50 TA P INTERV Pull wear bushing, set test plug. 16:30 - 18:00 1.50 TA P INTERV PJSM. CIO pipe rams to 7". Test rams @ 250 I 3500 psi, OK. 18:00 -18:30 0.50 TA P INTERV Hold PJSM. BOLDS. Pull & LID pack off. 18:30 - 19:00 0.50 TA P INTERV P/U & M/U spear assy. 19:00 - 20:30 1.50 TA P INTERV Sting into 7" casing & engage spear. P/U & work pipe from Printed: 9/2/2003 9:59: 13 AM I~ \. r ( Page 3 of 3 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-21 MPK-21 TEMP ABANDON NABORS ALASKA DRILLING I NABORS 4ES Date 8/23/2003 8/24/2003 8/25/2003 From - To Hours 19:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 03:30 03:30 - 08:00 08:00 - 08:30 08:30 - 10:00 10:00-12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 -16:00 16:00 - 17:30 17:30 -18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 06:30 06:00 - 09:00 1.50 TA 1.00 TA 2.50 TA 1.50 TA 1.50 TA 0.50 TA 4.50 TA 0.50 TA 1.50 TA 2.00 TA 2.00 TA 0.50 TA 0.50 TA 1.00 TA 1.50 TA 0.50 TA 2.00 TA 1.00 TA 1.50 TA 1.50 TA 0.50 TA 2.50 TA 0.50 TA 0.50 TA 0.50 TA 2.00 TA 3.00 TA Task Code NPT Phase P INTERV P INTERV p INTERV P INTERV P INTERV P P P P INTERV INTERV INTERV INTERV P P INTERV INTERV P INTERV P INTERV P INTERV P INTERV P P P INTERV INTERV INTERV P P INTERV INTERV P P P P P P P INTERV INTERV INTERV INTERV INTERV INTERV INTERV " Start: 8/20/2003 Rig Release: 8/25/2003 Rig Number: 4es Spud Date: 2/16/1997 End: 8/25/2003 Description of Operations 150K up to 280K. Casing stuck no pipe movement. Continue to work pipe. R/U & pump down 7" casing. Pressured up to 800 psi @ 1 BPM. Pressure broke over. 2.4 BPM @ 250 psi. Circulate well 2 BPM @ 200 psi. & work pipe. 1 OOK to 200K. Getting diesel returns, then changed to gray mud returns. P/U & work pipe while circulating. Casing suddenly came free while holding 225K. Move pipe 2-3' & circulate well to even out weights. SID & monitor well. Pull casing mandril to floor w/1 09K. Break out & LID spear. Pull 2 jts of 7" & LID same. Wellbore static wI diesel on backside. R/U & circulate out diesel. Circulate & even out weight to 8.8 ppg. No more diesel. Return fluid gray & dirty. Monitor well. RID circulating equip. POOH & LID 7" casing. Recovered 96 jts & 30.25' of jt #97. ClearlClean rig floor PJSM. Monitor well, well stable. Set 9 5/8" test plug. C/O pipe rams from 7" to 27/8" X 5" variables. Test Plrams @ 250 I 3500 psi, OK. Pull test plug. PJSM. RIH wI mule shoe & 31/2" DP, 122 jts to 3880'. PJSM. M/U circulating head. Circulate down to 3908' inside 7" casing stub. Circulate @ 6 bpm 1800 psi to clean up hole. Rig up cementers. Pumped 500 bbls total, clean returns. PJSM on cementing job. Hazards identified & program reviewed. Pump 3 bbls fresh water. Test lines to 3000 psi, OK. Mix cement & pump 5 bbls fresh water ahead followed by 15 bbls 15.8 ppg class G cement w/1 % Calcium Chloride, 2 bbls fresh water & 18 bbls 8.8 ppg brine. Break off circulating head & stand back (1) stand. Mule shoe now @ 3812', (20' above shoe & 90' below setting depth of 9 5/8" bridge plug). Reverse circulate (2) DP volumes @ 5 bpm I 750 psi. Approximately (6) bbls cement back, leaving (9) bbls in hole. PJSM. POOH wI 3 1/2" DP, strapping out to ensure on depth wI 9 5/8" bridge plug. PJSM. M/U Halliburton 9 5/8" Bridge Plug. RIH on 3 1/2" DP. R/U circulate & space out BP @ 3722'. Set BP & stack 25K on BP. P/U Close in & test plug to 3000 psi for 30 min. POOH & LID 54 jts, 3 1/2" DP @ 2000'. PJSM. R/U 1st Energy & pump 135 Bbls diesel down annulus for freeze protection. 2.5 BPM @ 950 psi. RID circulating equip. & blowout lines. Con't to POOH from 2000' & LID 31/2" DP. Break out & LID setting tool. Fill 9 5/8" wI 10.5 Bbls diesel. Install tbg hanger wI pup jt. RILDS. Set TWC & pressure test to 2500 psi. NID BOPE. N/U tree. Test tree to 5000 psi, OK. Set BPV. Secure well. Rig released @ 09:00 hrs, 08/25/2003. Printed: 9/2/2003 9:59: 13 AM RE: MPK-21i (196-176)(303-217) Subject: RE: MPK-21 i (196-176) (303-217) Date: Mon, 11 Aug 2003 15:40:23 -0500 From: "Odenthal, Robed S" <OdenthRS@BP.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> I will write into the program dumping cement to fill the 7" casing stub above the CIBP @ 3950' (2bbls). Robed S. Odenthal BP Exploration Drilling Engineer Work #' 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, August 07, 2003 8:27 AM To: Odenthal, Robert S Cc: Archey, Pat Subject: Re: MPK-21i (196-176) (303-217) << File: Card for Tom Maunder >> Robert, One further question. Regarding the 7" stub below the 9-5/8" shoe. Will leaving that interval open while you wait on the drilling rig potentially cause you trouble?? You plan to put in a bridge plug and I presume you will be drilling that out and then sidetracking out the "section" below the shoe. When you cement the new 7" I doubt it is planned to bring cement up over the stub. That would risk getting it above the shoe. I need to look at the regulations, but have you considered spotting cement above the retainer back into the 9-5/8"? That might save you the cost of the 9-5/8" bridge plug and give you firm cement to kick off of. I look forward to your reply. Tom Maunder Tom Maunder wrote: Thanks Robert. I will pass the sundry on for approval. Tom "Odenthal, Robert S" wrote: I will bump it up to 20 bbls below the EZSV and 5 on top. Robert S. Odenthal BP Exploration Drilling Engineer Work #: 907-564-4387 Cell #: 907-440-0185 E-ma#: odenthrs@bp, com ..... Original Message ..... From: Tom Maunder [mailto:tom maunderC, admin.state, ak. us/ Sent: Wednesday, August 06, 2003 4:45 PM To: Odenthal, Robert S Subject: MPK-21i (196-176) (303-217) << File: Card for Tom Maunder >> Robert, 8/11/2003 1:47 PM RE: MPK-21i (196-176) (303-217) > > I was looking at the proposed cement volume for the squeeze. You have > > listed 15 bbls on your drawing plus 5 above the retainer. The > > calculations I have done show that you need roughly 13 bblsjust for the > > pipe sections. With the short perf interval the 2 bbls to squeeze might > > be enough. Is this how you were thinking?? > > Thanks, > > Tom Maunder 2 of 2 8/11/2003 1:47 PlY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: I~! Abandon [] Suspend [] Operation Shutdown r"l Perforate [] variance [] Other [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension Plugback for Sidetrack [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 196-176 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22718-00-00 7. KB Elevation (ft): KBE = 61.29' 9. Well Name and Number: M PK-21 i 8. Property Designation: 10. Field / Pool(s): ADL 375133 Milne Point Unit / Kuparuk River Sands ..:.:: :.: :..: .: PRESEN EL COND TION SUM~RY i! ' : .. TW L.: I i ., ...'.:.= .,.: ..... .:~ ' . ....... ~ , "Total Depth MD (ft): Total Depth TVD (ft):lEffective Depth MD (ft): ]Effective Depth TVD (ft): Plugs (measured): ' Junk (measured): 9845 7432I 9740I . 7357 N/A N/A ,C,a,,s!n~! ,,, Len~t.h,'... ,.SiZe .... · : ..... ,MD: .' ...... TVD .' Burst Collapse Stru(;;t~ral Conductor 74' 20" 112' 112' 1530 520 Surface 3796' 9-5/8" 3832' 3572' 6870 4750 Intermediate Production 9792' 7" 9825' 7418' 7240 5410 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft):I Tubing Size: Tubing Grade: I Tubing MD (ft): 9476' - 9502' 7162' - 7182' 3-1/2", 9.3# L-80 9519' Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft): 9193' 7" x 3-1/2" Baker SABL-3 Packer 9505' 12. Attachments: 13. Well Class after proposed work: [] Description Summary of Proposal [] BOP Sketch [] Detailed Operations Program [] Exploratory [] Development [] Service 14. Estimated Date for 15. Well Status after proposed work: "~ I~ugg~e Commencing Operations: August 21, 2003 [] Oil [] Gas [] Abandoned 16. Verbal Approval: Date: [] WAG [] GINJ [] WINJ [] WDSPL Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Odenthal, 564-4387 Print~'~ert/,Odenthal ~ Title Drilling Engineer Si ~ ~ Phone 564-4387 Date Sondra Stewman, 564-4750 .......... .,.. .. ' ":: ..... 'comrniSSion ,Use'Only.' ,... ." ..:'.. ,,, :,. '. I Sundry Number:~;~illlll=~,~ ~,~l ~ Conditions of approval: Notify Commission so that a representative may witness ~l, Plug Integrity "~,BOP [] Integrity Test [] Location Clearance Test Mechanical Other: " r'~ ':, ,;' bl,'~] .... ¢[.. i,, ...... J Subsequent form required 10- ~"~ ,,:, . .... :,, BY ORDER OF Form 10-403 Revised ORIG!N , Submit In Duplicate AUG1 1 20fl;: K-21 Decompletion Planned Date of Start of Operations: August 21, 2003 4ES is going to decomplete the well, plug and abandon the existing perforations, cut 3900' of 7" casing and set a bridge plug in he existing 9-5/8" casing. This well will be sidetracked by MPU drilling group in late September or early October. 4ES Operations 1. MIRU. 2. ND tree. NU and test BOPE. 3. Circulate out freeze protection fluid and circulate well with clean seawater to kill well. 4. POOH with existing 3.5 tubing above pre-rig chemical cut. 5. P/U EZSV on drill pipe and RIH to 9145' and squeeze existing perfs. 6. Un-sting from retainer, dump 5 bbls of cement, pull up and circulate. 7. POOH 8. P/U CIBP and set at 3950" 9. POOH. 10. RIH and cut 7" casing at 3900' 11. Remove 3900' of 7" casing and lay down. 12. P/U 9-5/8" CIBP and set at 3720" 13. POOH to 2000' 14. Freeze protect to 2000' MD. 15. POOH 16. Set BPV. 17. RDMO. Tree:FMC 3-1/8" 5M (',_ Origf' Elev.- '(N 27E) Wellhead:11"x 11" 5M FMC,.~en 5 MPU K'21 i Orig. ~L Elev. = 28.5' w/11 "x 31/2" tbg. hng. w/3 1/2"nsct RT To Lock downs =32.7' (N 27E) threads top and btm. 31/8" bpv profile 20" 91.1 ppf, H-40 KOP @ 600' to 4,100' Max. hole angle = 55 deg. @ 6,400' Hole angle thru' perfs = 40 deg. 9 5/8", 40 ppf, L-80 Btrc. I 3,832' I 1 7" 26 ppf, L-80, BTC-Mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 3.5" 9.2 ppf., L-80 tbg. 8rd EUE tbg. f/24' to 9146' with the remainder being NSCT. Stimulation Summary 3.5" HES X-Nipple (2.813" id) I 9,180' Marker Joints ( 9,288' - 9,330' ) Perforation Summary L Ref lo.q: 03116197 GR ! CCL Three jts. 3.5" tbg. Size SPF Interval (TVD) 3.5"xl ll2"Camco"MMU" [ 9,314' 3.5" 4 9,502'-9,476' 7,182'-7,162' One it, of 3.5" tbg. 3.5" High Density deep Penetrating 60 deg. phasing, 4 spf ,34gm, 34" penetration shots 3.5" x 1 1/2" Camco "MMM" 9,377' Three jts. 3.5" tbg. ~ ................. 7"X 3.5" Baker" SABL-3" I 9,505' Pinched tubing at 9401' and 9440'~ Prod. pkr. anchor release I 3.5" RHC plug cannot be pulled until tubing is swaged out or milled. A 2.8" swage has passed through 9401' 3.5"W/LEGI 9r519' but will not go through 9440'. 7" float collar (PBTD) I 9,740' 7" float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 03 -07 97 BDB Cased hole completion 27E WELL K-21i 03-16-97 MDO Add perforations APl NO: 50-029-22718 10/22/97 MDO Completion 5-S BP EXPLORATION ~-ree'~ F~'IMC 3-1/8" 5M Wellhead:11"x 11"5M FMC Gert 5 w/11 '5( 31/2;'tbg. hng. w/3 1/2"nsct threads top and btm. 31/8" bpv profile 20" 91.1 ppf, H-40 KOP @ 600' to 4,100' Max. hole angle - 55 deg. @ 6,400' Hole angle thru' perfs - 40 deg. 9 5/8", 40 ppf, L-80 Btm. I 3,832' Orig. KB Elev. = '(f 'E) Orig. GL Elev. = 28.b' RT To Lock downs =32.7' (N 27E) 9-5~8" CIBP set at 3720' 7" 26 ppf, L-80, BTC-Mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 3~5" 9.2 ppf., L-80 tbg. 8rd EUE tbg. f/24' to 9146' with the remainder being NSCT. Stimulation Summary Marker Joints ( 9,288' - 9,330' ) Perforation Summary Ref Ioq: 03/16197 GR I CCL Size, IS~FI Interval (TVD) 3.5' 9,502'-9,476' 7,182'-7,162' 3.5" High Density deep Penetrating 60 deg. phasing, 4 spf ,34gm, 34" penetration shots X Pinched tubing at 9401' and 9440' 3.5" RHC plug cannot be pulled 2.8" swage has passed through ~40~ but will not ~o through 7" Casing cut @ 3900' 7' ClBP @ 3950' 5 bbls of Cement (15.8 ppg Class G) 7" EZSV @ 9145' Sqz w/15 bbls of 15.8 "G" Cement 3.5" HES X-Nipple (2.813" id) [ 9,180' 7" Baker" S~3" Packer [ 9,193' 3,,.~ tbg, Three its. ' r,, 3,5" x 1 1/2" Camco "MMM" [ 9,314' J One it, of 3.5" tbg. 3,5"x 1 1/2" Camco"MMM" L 9,377' Three jts. 3.5" tbg. 7" x 3.5" Baker" SABL-3" I Prod. pkr. anchor release 9~505' 3.5" HESXN-Nipple (2.750" id) [ 9,5t5' 3,5" W/LEG [ 9~519' 7" float collar (PBTD) [ 9,740' 7" float shoe I 9,825' DATE REV. BY COMMENTS 03 -07 97 BDB Cased hole completion 27E 03-16-97 M DO Add perforations 10/22/97 MDO Completion MILNE POINT UNIT WELL K-21i APl NO: 50-029-22718 BP EXPLORATION (AK) MEMORANDUM State"' f Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair DATE: September 2, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPXA G, K, L Pads. G-09i, G,13i, K-21 i, L-15i MPU Milne Point Field. Packer Depth Pretest Initial 15 Min. 30 Min. I "WellI G-09i I Type,nj.I s I ~.v.~. I~,~ J Tubing I 1300 I 1300 11300 I 1300 J lntervalI 4 I P.T.D.I 1971170 ITypetestJ P ITestpsil 1500 I Casingl 8,~50 11520115O5115051 p/F'I PI Notes: Pre-test press, monitored & stable. ' - I -" We,,I G-13i ITypelnj.I S I T.V.D. 13902 J TubingJ 1450 11450 I 1450 I 1450 I,ntervall 4 p.,._r-).!T I 1971200 ITypetestI P I Testpsil 1500 I CasingI 580 I 1960 I 1910 I 1900 I P/FI _P Notes: Pre-test press, monitored & stable. ----. WellJ K-21i. Typelnj. J S J T.V.D. I 6945 J TubingJ 1100 J 1100 I 1100 J 1100 IlnterVall 4 P.T.D.I 1961760 TypetestI P ITestpsiI 1736 I CasingI 825 1180O1178011780I P/FI P Notes: Pre-test press, monitored & stable. '"'"' We,,I. L-~5, I T p ,nj.I N I ~.V.D. I~,~ I Tubingl 4450 14450 I 4450 I 4450 I lntervall 4 P.T.D.I 1940620ITypetestl P ITestpsil 1737 I Casingl zero 118001176011760I P/F I __P Notes: Pre-test press, monitored & stable. --'-- Type' INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. .c, _- ~ .~ ,.-~ WATER INJ. ~. -- . ' ..~ECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details September 2, 2002: I traveled to BPXA's Milne Point Field to witness 4 year MIT's on water injection wells G-09i, G- 13i, K-21i and L-15i. Jeff Jones was the BPXA representative in charge of the tests. The pre-test pressures were monitored for 15 minutes and the standard annulus pressure test was then performed on each well, with all four wells passing the MIT. I inspected each well house during the tests and no exceptions were noted. Summary: I witnessed successful MIT's on BPXA's Milne Point Field injection wells G-09i, G-13i, K-21i and 1-15i. Four well houses inspected, no exceptions noted. M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 4.5 hrs. cc: ,SCANNED 0C7 O,.'A 2002 MIT repo~ form i ,'-' MIT MPU G-09i,G-13i,K-21i,L-15i 9-2-02 JJ.xls 9/10/2002 5/12/00 _.~. STATE OF ALASKA ALASK"-")IL AND GAS CONSERVATION Cf ..... MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--I Operation Shutdown []Stimulate []Plugging I--JPerforate [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3620' NSL, 2089' WEL, SEC. 3, T12N, R11 E, UM At top of productive interval 2576' NSL, 1928' WEL, SEC. 4, T12N, R11E, UM At effective depth At total depth 2529' NSL, 2177' WEL, SEC. 4, T12N, R11 E, UM 5. Typed well: LJ Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 61.3' 7. Unit or Properly Name Milne Point Unit 8. Well Number MPKo21i 9. Permit Number / Approval No. 196-176 10. APl Number 50- 029-22718 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9845 feet true vertical 7432 feet Effective depth: measured 9740 feet true vertical 7357 feet Casing Length Size Structural Conductor 112' 20" Surface 3799' 9-5/8" Intermediate Production Liner 9792' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx) 1260 sx PF 'E', 700 sx Class 'G' 460 sx Class 'G' MD TVD 145' 145' 3832' 6572' 33'-9825' 33'-7417' Perforation depth: measured ~ 9476'-9485'; 9485'-9502' true vertical 7162'-7169'; 7169'-7181' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 @ 9519' Packers and sSsv (type and measured depth) Packer @' 9505', 9193' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment ECE]VED Treatment description including volumes used and final pressure F,~9 02 2000 Alaska Oil & 8as Cons. Commi~,~u~, 14. Prior to well operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: I-'] Oil i-] Gas [--I Suspended Service Water Injection kf ~¢~"] I r~ . 17. i hereby certify that the foregoing, is true and cor~ct to the best of my knowledge Signed ~,¢~ ~ ^NGELAM. SORRENTINO Title Surveillance Engineer Prepared By Name/Number: Date //,Z.~//~--'2 ~ Michael Williams, $64-4657 Submit In Duplic~ Form 10-404 Rev. 06/15/88 1/13/2000 MPK-21 DESCRIPTION OF WORK COMPLETED Stimulation Operation A Acid Stimulation Treatment was performed using the following fluids: _Milne Point K-21iis an injector which is supplied water from MPK-34 water source well out of the Ugnu formation. A stimulation was performed on K-21i January 13, 2000 with the flowback from an acid job on K-34. Approximately 470 bbls of acid flowback was diverted to K-21i at approximately 800 psi injector head pressure. Fluids Pumped BBLS. Description 470 Acid Flowback 470 Total BBLS AOGCC Geological Materials Inventory PERMIT 96-176 BP EXPLORATION Log Data Sent 7665 ~1~ SCHLUM PDC/GR 5/2/1997 7974 ¢;ff)'~'' SPERRY MPT/GR/RES/CNP/SLD/ROP 5/7/1997 CBL ~ 100-9710 ~>/1~/q t~ 4/24/1997 DGWC~/SLD-MD ~ 3850-9845 4/30/1997 DGWC~/SLD-TVD ~ 3582-7432 4/30/1997 DG~S-MD ~ 3850-9845 4/30/1997 DG~S-TVD ~ 3582-7432 4/30/1997 MMS SR~ ~ SPE~Y 3752.2-9706.7 1/27/1998 MMS SR~ ~PE~Y 0-3752.0 1/27/1998 MWD SR~ ~E~Y 0-9845. 1/27/1998 100-9710 3/i~ 4/24/1997 ~:407 Completion Date { ~/~//~ * Daily well ops ~/ Are d~ ditch samples required? yes ~ no ~d received? Was the well cored? yes ~o Analysis description recieved? ~~ no Are tests required? yes ...... : no Received? Well is in compliance Initial Comments Recieved 5/2/1997 5/7/1997 4/25/1997 4/30/1997 4/30/1997 4/30/1997 4/30/1997 1/29/1998 1/29/1998 1/29/1998 4/25/1997 Box ~-'~ Friday, October 08, 1999 Page 1 of 1 Mp LJ K-2..,1 ; ) . MECHANICAL INTEGRITY REPORT' ) \~~-\'l~ ........ SPUD DATE:,',' : 2-\l6\'11 RIG RELEASE':,. ~1'Z2>1~1 OPER & FIELD 'hTELL NUMB ER cßf>~ ~}l}f l\ gob - Ill-, . WELL DATA .TD:, ~8-1Ç Jill.. 14&2- 46*' Cas ing : ~C;¡f> 1..: ~o Shoe: 3«Õ~2.- MD ~ G? ,. z..t., -!!: . Liner: i I . ~o Shoe: ~~2.ð MD ~ .~~ . ~\~ Tubing: 3'/1" 1-'~ rp acker ðl~oS' MD TVD J PBTD: 9140 MD 13S'~ TVD TVD J DV: MD .TVD TVD ¡TOP: MD TVD TVD ¡ Set a t .q~ I ~ Hole Size 8 '/2- and )¿~ J Perfs '}~=lb ,', to 95c2.. MECHANICAL INTEGRITY - PART '/1, Annulus Press Test: IP J 15 min 30 min Comments: .-/ MECBANICÞ..L INTEGRITY - PART /2 =1" ~ ' Cement Volumes:' Amt. Liner 46D ~ ; Csg \9bO~)( ; DV Cmt vol to cover perfs . J 5"". ~ b.+ . -Sf .8 )" Z6~ ~ . \8~ b L "J& 7./5 .. ~1'" o,\X . I B3b + (9'ß4~-'" <!:)ß zçJ){ .33-bB r L~~;zS'" - q -1t~,)~ . \8 ß ð ~ bO. 1 I .. ~ï2. - .~3-b'ò Theore tical Toe 1~8Yz ~ . \oCß3 ,3b ~ 2- 6""Lf" C) -11 b - [14b'O - bÓ. I . I ,J ~ , 10'&3 - :: pi ~4 . ~ l ~'f~ . Ge..-C.GL) Cement Bond Log (Yes or No) ts ; :In AOGCC File r ~ 1- 1.0(:. CEL Evaluation, zone above perfs ~~A~.sí lÞJ'V'Il6).)7. '#i.i ktV.t;'6NAl-i\~.LI7\.lt£ J\J)~\JAí-E:. ßo~/~G A. &J vf. fEl-r-"S 4 . Produ~tion Log: Type t Evaluation .CONCLUSIONS: SCANNED FEB 2. 2 2G05 Part #1: Part 12: f'J) t 'os \ N,D J LA r ~').~ W}J) -Y410)~ -- rev. OS/20/87 . C. 028 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ .~ [ IV E D WELL COMPLETION OR RECOMPLETION REPORT AND LOG f ~ t tJ ,J ~,~ 1. Status of Well Classification of Servic¢~W~h I-I Oil I-~ Gas [--I Suspended I--I Abandoned [~ Service Water & Gas Injector 2. Name of Operator 7. Permit Nurr~¢~~ 0it ;~ BP Exploration (Alaska)Inc. 96-176 Anchorage 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~'"-,_z~~ 50-029-22718 3620, NSL, 2089, WEL, SEC. 3, T12N, R11E,UMi G/~ji[ i Milne Point Unit At top of productive interval i ~! ....... _.q-_~ 10. Well Number 2576' NSL, 1928' WEL, SEC. 4, T12N, R11E, DM! "/~,;i;'.~;;' :' ~.-.,.~! MPK-21i At total depth~ ......................~ '""~"~' 11. Field and Pool 2529' NSL, 2177' WEL, SEC. 4, T12N, R11 E, UM ................... ¢ Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 61.3'I ADL 375133 12. Date Spudded2/16/97 I 13' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'l15' water depth' if °fish°re I 16' NO' °f cOmpletiOns2/23/97 10/21/97 N/A MSLI One 17. Total Depth (MD+TVD)]18. Plug Back Depth (MD+TVD)]I 9. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9845 7432 FTI 9740 7357 FTI [~Yes I-qNo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, ESS, SBT/GR/CCL, GR/JB 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 SX Arcticset I (Approx.) 9-5/8" 40# L-80 36' 3832' 12-1/4" 1260 sx PF 'E', 700 sx Class 'G' 7" 26# L-80 33' 9825' 8-1/2" 460 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 9519' 9505' MD TVD MD TVD 9193' 9476'-9502' 7162'-7181' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 70 bbls diesel 27. PRODUCTION TEST U ~ I ~1~ t 1~1~ ~ ~ Date First Production I Method of Operation (Flowing, gas lift, etc.) December 8, 1997t On Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 9192' 6944' KC1 9473' 7159' Top Kuparuk 'B' 9502' 7181' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ;/~- 7/,~ ChipAIvord /~"~.~,~-.~ -~ Title Engineering Supervisor Date MPK-21i 96-176 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21; Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ORI61NAL Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 21:56, 12 Dec 97 Page 1 The analysis is from - 09:00, 20 Feb 97 - to - 09:00, 20 Feb 97 Programs in Result Table: MPK-21 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(ecfuivalent mud weight) MPK-21 Event 09:00, 20 Feb 97 09:00, 20 Feb 97 0 hr 0 min Obtained leak off 13.8 Hole Size MDR 8-1/2 Progress Report Facility M Pt K Pad Well MPK-21 Rig Nabors ~cJI~7£ Page 1 Date 12 December 97 Date/Time 14 Feb 97 12:00-14:00 14:00-14:30 14:30-18:00 18:00-21:00 21:00-00:00 15 Feb 97 00:00-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-00:00 16 Feb 97 00:00-00:30 00:30-06:00 06:00-06:30 06:30-15:30 15:30-16:30 16:30-17:00 17:00-20:30 20:30-21:00 21:00-03:30 17 Feb 97 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-10:00 10:00-12:00 12:00-13:30 13:30-14:30 14:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-23:00 23:00-00:00 18 Feb 97 00:00-00:30 00:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-11:00 11:00-13:00 13:00-15:30 15:30-18:00 18:00-18:30 18:30-21:00 21:00-23:00 23:00-00:00 19 Feb 97 00:00-03:00 03:00-03:30 Duration 2hr 1/2 hr 3-1/2 hr 3hr 3hr 4-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 8hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2hr 9hr lhr 1/2hr 3-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr lhr lhr 1/2hr 3-1/2 hr 2hr 1-1/2 hr lhr 1-1/2 hr lhr lhr 1/2 hr 1/2 hr 4hr lhr 1/2 hr 4-1/2 hr lhr 1/2hr 1/2 hr 2hr 2hr 2hr 2-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 2hr lhr 3hr 1/2 hr Activity Rigged down High pressure lines Held safety meeting Rig moved 40.00 % Rig moved 50.00 % Rig moved 50.00 % Rig moved 100.00 % Rigged up High pressure lines Held safety meeting Rigged up High pressure lines Rigged up Divertor Held safety meeting Serviced Standpipe manifold Made up BHA no. 1 Tested Divertor Held safety meeting Drilled to 500.0 ft Held safety meeting Drilled to 2108.0 ft Circulated at 2108.0 ft Pulled out of hole to 1075.0 ft Repaired Draw works R.I.H. to 2108.0 ft Drilled to 3140.0 ft Circulated at 3140.0 ft Pulled out of hole to 1600.0 ft R.I.H. to 3140.0 ft Held safety meeting Drilled to 3703.0 ft Repaired Top drive Drilled to 3850.0 ft Circulated at 3850.0 ft Pulled out of hole to 200.0 ft R.I.H. to 3850.0 ft Circulated at 3850.0 ft Held safety meeting Circulated at 3850.0 ft Pulled out of hole to 0.0 ft Rigged up Casing handling equipment Held safety meeting Ran Casing to 3832.0 ft (9-5/8in OD) Circulated at 3832.0 ft Held safety meeting Circulated at 3832.0 ft Mixed and pumped slurry - 260.000 bbl Circulated at 1316.0 ft Mixed and pumped slurry - 370.000 bbl Serviced Fluid system Rigged down Divertor Held safety meeting Rigged up BOP stack Repaired Brake Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Facility Date/Time 20 Feb 97 21 Feb 97 22 Feb 97 23 Feb 97 24 Feb 97 M Pt K Pad 03:30-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-14:00 14:00-15:00 15:00-18:00 18:00-18:15 18:15-19:30 19:30~20:00 20:00~21:00 21:00-22:30 22:30-02:30 02:30-04:30 04:30-05:00 05:00-05:45 05:45-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15~05:30 05:30-06:00 06:00~06:30 06:30-07:00 07:00-07:30 07:30-18:00 18:00-18:15 18:15-22:00 22:00-23:00 23:00-01:00 01:00-02:00 02:00-03:00 03:00-06:00 06:00~17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00~21:00 21:00-06:00 06:00-12:00 12:00-13:30 13:30-15:30 15:30-16:30 16:30-18:00 18:00-20:00 20:00-00:00 00:00-04:30 04:30-05:00 Duration 2-1/2 hr 1/2 hr 6hr lhr 1/2 hr lhr 3hr 1/4 hr 1-1/4 hr 1/2 hr lhr 1-1/2 hr 4hr 2hr 1/2 hr 3/4 hr 1/4 hr 1-1/2 hr lhr 1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 11-1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/4 hr 3-3/4 hr lhr 2hr lhr lhr 3hr llhr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr 9hr 6hr 1-1/2 hr 2hr lhr 1-1/2 hr 2hr 4hr 4-1/2 hr 1/2 hr Progress Report Well MPK-21 Rig Nabors~7-~ Activity Rigged down BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Installed Wear bushing Serviced Top drive Made up BHA no. 2 Held safety meeting Made up BHA no. 2 R.I.H. to 1316.0 ft Serviced Block line Drilled installed equipment - DV collar R.I.H. to 2421.0 ft Held drill (Stripping) R.I.H. to 2700.0 ft Tested Casing Drilled installed equipment - Float collar Drilled installed equipment - Float collar Circulated at 3870.0 ft Performed formation integrity test Drilled to 5064.0 ft Circulated at 5064.0 ft Pulled out of hole to 3831.0 fi R.I.H. to 5064.0 ft Held safety meeting Drilled to 6565.0 ft Circulated at 6565.0 ft Circulated at 6565.0 ft Pulled out of hole to 4067.0 ft R.I.H. to 6565.0 ft Drilled to 7596.0 ft Held safety meeting Drilled to 7973.0 ft Circulated at 7973.0 ft Pulled out of hole to 3832.0 fi Serviced Top drive R.I.H. to 7973.0 ft Drilled to 8162.0 fi Drilled to 9006.0 fi Circulated at 9006.0 ft Pulled out of hole to 7611.0 fi R.I.H. to 9006.0 ft Drilled to 9120.0 ft Repaired Mud pumps Drilled to 9473.0 ft Drilled to 9845.0 ft Circulated at 9845.0 ft Pulled out of hole to 3811.0 fi Serviced Top drive R.I.H. to 9845.0 ft Circulated at 9845.0 ft Pulled out of hole to 215.0 ft Pulled BHA Rigged down Drillfloor / Derrick Page Date 2 12 December 97 Facility M Pt K Pad Progress Report Well MPK-21 Rig Nabors ~g~'7~ Page Date 3 12 December 97 Date/Time 25 Feb 97 05:00-05:30 05:30-06:00 06:00-06:30 06:30-17:00 17:00-17:30 17:30-22:00 22:00-23:00 23:00-00:30 00:30-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-09:00 09:00-15:30 15:30-21:00 Duration 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 4-1/2 hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr lhr 1-1/2 hr 3hr 6-1/2 hr 5-1/2 hr Activity Removed Wear bushing Rigged up Casing handling equipment Rigged up Casing handling equipment Ran Casing to 9824.0 ft (7in OD) Rigged up Cement head Circulated at 9824.0 ft Cleared Mud pumps Mixed and pumped slurry - 168.000 bbl Tested Casing Serviced Casing handling equipment Serviced Drillfloor / Derrick Installed Wellhead integral components Rigged down BOP stack Installed Xmas tree Laid out 5in drill pipe from derrick SPt BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3752.20 3519.92 3459.42 3992.00 3678.71 3618.21 4087.10 3742.43 3681.93 4181.00 3804.47 3743.97 4275.50 3864.17 3803.67 4367.20 3920.64 3860.14 4462.20 3978.87 3918.37 4555.80 4036.25 3975.75 4650.00 4093.72 4033.22 4743.40 4149.85 4089.35 4837.90 4206.53 4146.03 4932.30 4263.93 4203.43 5025.72 4321.84 4261.34 5119.60 4381.66 4321.16 5214.00 4441.17 4380.67 5307.80 4498.87 4438.37 5399.50 4555.56 4495.06 5494.60 4614.27 4553.77 5588.50 4672.06 4611.56 5682.80 4729.56 4669.06 5776.40 4785.93 4725.43 5869.80 4841.53 4781.03 5962.50 4897.06 4836.56 6056.90 4954.71 4894.21 6150.60 5011.90 4951.40 6244.70 5068.95 5008.45 6338.50 5124.60 5064.10 6433.10 5179.63 5119.13 6527.00 5235.34 5174.84 6622.80 5292.72 5232.22 6715.60 5348.57 5288.07 6809.30 5405.23 5344.73 7183.30 5628.21 5567.71 7276.70 5683.90 5623.40 7370.80 5741.55 5681.05 SUN DRILLING SERVICES ANCHORAGE ALASKA DATE OF SURVEY: 022 MAGNETIC MULTI-SHOT SUS ING LEV. OPE~TOR: BP EXPLO~TION COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 48 47 S 75.83 W .00 155.28S 820.46W 834.9 48 16 S 77.14 W .46 197.28S 995.16W 1014.5 47 34 S 79.43 W 1.93 211.62S 1064.27W 1085.0 49 41 S 80.06 W 2.31 224.17S 1133.60W 1155.5 51 56 S 78.96 W 2.54 237.51S 1205.61W 1228.7 52 2 S 78.29 W .59 251.76S 1276.44W 1301.0 52 21 S 77.96 W .43 267.20S 1349.89W 1376.0 52 2 S 77.43 W .57 282.96S 1422.14W 1450.0 52 45 S 78.19 W 1.00 298.71S 1495.09W 1524.6 53 21 S 78.73 W .79 313.65S 1568.23W 1599.2 52 56 S 78.82 W .45 328.37S 1642.40W 1674.9 52 9 S 78.27 W .95 343.26S 1715.85W 1749.8 51 13 S 78.17 W .99 358.23S 1787.60W 1823.1 49 36 S 77.90 W 1.74 373.23S 1858.38W 1895.4 52 12 S 78.39 W 2.79 388.27S 1930.08W 1968.7 51 52 S 78.62 W .41. 403.01S 2002.55W 2042.7 51 45 S 78.10 W .46 417.56S 2073.15W 2114.7 51 59 S 77.28 W .72 433.51S 2146.24W 2189.5 52 1 S 77.12 W .14 449.90S 2218.41W 2263.5 52 49 S 76.83 W .88 466.75S 2291.22W 2338.2 53 7 S 75.86 W .88 484.38S 2363.83W 2412.9 53 48 S 75.60 W .78 502.88S 2436.56W 2487.9 52 35 S 76.43 W 1.50 520.82S 2508.58W 2562.0 52 7 S 78.09 W 1.48 537.30S 2581.48W 2636.7 52 39 S 78.67 W .76 552.25S 2654.19W 2711.0 52 41 S 79.81 W .97 566.22S 2727.69W 2785.8 54 32 S 79.99 W 1.98 579.46S 2802.02W 2861.3 54 19 S 79.47 W .51 593.17S 2877.73W 2938.2 52 54 S 78.24 W 1.84 607.77S 2951.89W 3013.8 53 30 S 77.92 W .68 623.61S 3026.94W 3090.5 52 29 S 77.62 W 1.12 639.31S 3099.37W 3164.6 53 5 S 77.41 W .67 655.44S 3172.23W 3239.2 53 42 S 77.48 W .16 720.71S 3465.31W 3539.4 53 5 S 78.31 W .97 736.44S 3538.62W 3614.4 51 20 S 77.39 W 2.02 752.08S 3611.31W 3688.7 SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPA-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 022497 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70047 KELLY BUSHING ELEV. = 60.50 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7464.30 5799.67 5739.17 51 47 7557.60 5857.03 5796.53 52 19 7651.20 5913.61 5853.11 53 17 7745.40 5970.45 5909.95 52 29 7839.60 6027.32 5966.82 53 14 S 77.03 W .57 768.30S 3682.73W 3761.97 S 76.22 W .89 785.32S 3754.32W 3835.51 S 76.32 W 1.04 803.02S 3826.75W 3910.01 S 76.34 W .86 820.77S 3899.74W 3985.08 S 76.70 W .86 838.27S 3972.76W 4060.13 7934.30 6084.75 6024.25 52 5 8028.30 6142.00 6081.50 52 52 8122.00 6199.58 6139.08 51 17 8216.80 6258.51 6198.01 51 50 8310.80 6315.93 6255.43 52 51 S 77.29 W 1.32 855.22S 4046.12W 4135.39 S 77.13 W .84 871.72S 4118.82W 4209.92 S 78.11 W 1.88 887.57S 4191.01W 4283.82 S 78.04 W .59 902.92S 4263.66W 4358.07 S 77.80 W 1.09 918.49S 4336.43W 4432.49 8404.20 6373.54 6313.04 50 58 8498.10 6434.23 6373.73 48 29 8593.00 6498.87 6438.37 45 38 8687.90 6566.39 6505.89 43 37 8779.70 6633.55 6573.05 42 18 S 79.25 W 2.35 933.13S 4408.46W 4505.99 S 80.64 W 2.87 945.65S 4478.99W 4577.60 S 81.08 W 3.03 956.69S 4547.58W 4647.01 S 80.31 W 2.19 967.46S 4613.37W 4713.63 S 79.97 W 1.46 978.17S 4675.01W 4776.17 8873.10 6703.58 6643.08 40 31 8965.40 6774.81 6714.31 38 25 9044.70 6836.92 6776.42 38 28 9060.00 6848.89 6788.39 38 31 9151.60 6920.38 6859.88 38 52 S 78.12 W 2.32 989.89S 4735.67W 4837.94 S 78.14 W 2.28 1001.96S 4793.09W 4896.62 S 78.17 W .06 1012.08S 4841.35W 4945.93 S 78.47 W 1.25 1014.00S 4850.67W 4955.45 S 78.80 W .44 1025.29S 4906.82W 5012.72 9246.00 6993.57 6933.07 39 27 9339.60 7065.66 7005.16 39 47 9418.90 7126.34 7065.84 40 21 9433.60 7137.55 7077.05 40 13 9526.50 7208.05 7147.55 41 2 S 78.18 W .75 1037.19S 4965.24W 5072.34 S 77.70 W .49 1049.67S 5023.62W 5132.03 S 78.85 W 1.18 1060.04S 5073.61W 5183.09 S 78.04 W 3.73 1061.94S 5082.92W 5192.59 S 78.74 W 1.01 1074.11S 5142.17W 5253.08 9621.70 7279.13 7218.63 42 21 S 78.29 W 1.42 9706.70 7341.46 7280.96 43 19 S 77.95 W 1.16 1086.73S 5204.23W 5316.40 1098.63S 5260.78W 5374.19 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5374.27 FEET AT SOUTH 78 DEG. 12 MIN. WEST AT MD = 9706 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 258.51 DEG. TIE-IN SURVEY AT 3,752.20' MD LAST SURVEY STATION AT 9,706.70' MD SPt f-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 022497 JOB NUMBER: AK-EI-70047 KELLY BUSHING ELEV. = 60.50 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 3752.20 3519.92 3459.42 155.28 S 820.46 W 232.28 4752.20 4155.10 4094.60 315.03 S 1575.16 W 597.10 5752.20 4771.41 4710.91 479.66 S 2345.06 W 980.79 6752.20 5370.86 5310.36 645.54 S 3127.73 W 1381.34 7752.20 5974.59 5914.09 822.04 S 3904.98 W 1777.61 364.82 383.70 400.55 396.27 8752.20 6613.22 6552.72 974.94 S 4656.79 W 2138.98 9706.70 7341.46 7280.96 1098.63 S 5260.78 W 2365.24 361.37 226.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP[ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 022497 JOB NUMBER: AK-EI-70047 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3752.20 3519.92 3459.42 3813.80 3560.50 3500.00 3964.64 3660.50 3600.00 4113.89 3760.50 3700.00 155.28 S 820.46 W 166.63 S 865.39 W 192.74 S 975.25 W 215.25 S 1083.71 W 232.28 253.30 21.02 304.14 50.85 353.39 49.25 4269.55 3860.50 3800.00 4432.12 3960.50 3900.00 4595.25 4060.50 4000.00 4761.24 4160.50 4100.00 4926.70 4260.50 4200.00 236.61 S 1201.01 W 262.23 S 1326.60 W 289.71 S 1452.51 W 316.45 S 1582.27 W 342.36 S 1711.52 W 409.05 55.66 471.62 62.57 534.75 63.13 600.74 65.99 666.20 65.46 5086.95 4360.50 4300.00 5245.54 4460.50 4400.00 5407.48 4560.50 45.00.00 5569.71 4660.50 4600.00 5734.02 4760.50 4700.00 368.01 S 1834.06 W 393.29 S 1954.49 W 418.85 S 2079.28 W 446.60 S 2203.96 W 476.10 S 2330.96 W 726.45 60.24 785.04 58.59 846.98 61.94 909.21 62.22 973.52 64.32 5901.93 4860.50 4800.00 6066.33 4960.50 4900.00 6230.75 5060.50 5000.00 6400.30 5160.50 5100.00 6568.72 5260.50 5200.00 509.33 S 2461.68 W' 538.83 S 2588.76 W 564.26 S 2716.78 W 588.31 S 2851.54 W 614.55 S 2984.46 W 1041.43 67.90 1105.83 64.40 1170.25 64.43 1239.80 69.55 1308.22 68.41 6735.19 5360.50 5300.00 6901.35 5460.50 5400.00 7068.92 5560.50 5500.00 7237.74 5660.50 5600.00 7401.14 5760.50 5700.00 642.64 S 3114.55 W 671.49 S 3244.07 W 700.73 S 3375.31 W 730.13 S 3508.11 W 757.25 S 3634.43 W 1374.69 66.47 1440.85 66.16 1508.42 67.57 1577.24 68.82 1640.64 63.40 7563.28 5860.50 5800.00 7729.07 5960.50 5900.00 7894.84 6060.50 6000.00 8058.95 6160.50 6100.00 8220.02 6260.50 6200.00 786.39 S 3758.68 W 817.71 S 3887.15 W 848.37 S 4015.75 W 877.16 S 4142.65 W 903.44 S 4266.14 W 1702.78 62.14 1768.57 65.79 1834.34 65.77 1898.45 64.11 1959.52 61.07 8383.50 6360.50 6300.00 8537.27 6460.50 6400.00 8679.77 6560.50 6500.00 8816.11 6660.50 6600.00 8947.13 6760.50 6700.00 930.13 S 4392.66 W 950.33 S 4507.66 W 966.51 S 4607.84 W 982.45 S 4699.12 W 999.62 S 4781.97 W 2023.00 63.48 2076.77 53.77 2119.27 42.50 2155.61 36.34 2186.63 31.02 9074.84 6860.50 6800.00 1015.85 S 4859.73 W 2214.34 27.71 SP[ Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 022497 JOB NUMBER: AK-RI-70047 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9203.19 6960.50 6900.00 1031.64 S 4938.63 W 2242.69 28.35 9332.88 7060.50 7000.00 1048.75 S 5019.42 W 2272.38 29.69 9463.66 7160.50 7100.00 1065.97 S 5101.91 W 2303.16 30.78 9596.49 7260.50 7200.00 1083.28 S 5187.59 W 2335.99 32.83 9706.70 7-341.46 7280.96 1098.63 S 5260.78 W 2365.24 29.26 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 SPE' ' SUN DRILLING SERVICES PAGE 1 ANCHORAGE ALASKADATE OF MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70044 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -60.50 250.20 250.20 189.70 338.00 337.99 277.49 426.90 426.86 366.36 517.80 517.71 457.21 0 0 N .00 E .00 .00N .00E .00 0 14 N 60.76 W .10 .25N .45W .39 1 7 N 77.02 W 1.03 .54N 1.46W 1.32 1 41 N 77.37 W .63 1.02N 3.59W 3.32 1 58 N 77.92 W .32 1.64N 6.44W 5.98 607.92 607.78 547.28 697.90 697.71 637.21 787.70 787.45 726.95 877.50 877.20 816.70 966.70 966.35 905.85 1 55 N 74.34 W .15 2.38N 9.42W 8.76 2 1 N 72.19 W .15 3.27N 12.39W 11.49 1 57 N 73.15 W .09 4.21N 15.38W 14.23 2 0 N 74.38 W .07 5.07N 18.36W 16.98 1 44 N 73.96 W .30 5.87N 21.16W 19.57 1060.00 1059.61 999.11 1153.60 1153.17 1092.67 1245.90 1245.42 1184.92 1258.20 1257.72 1197.22 1340.30 1339.77 1279.27 1 39 N 72.91 W .08 6.66N 23.82W 22.01 1 39 N 84.43 W .36 7.19N 26.47W 24.51 1 59 N 86.70 W .37 7.41N 29.40W 27.34 2 0 N 89.02 W .68 7.43N 29.83W 27.76 1 51 N 77.31 W .52 7.74N 32.57W 30.37 1435.60 1435.02 1374.52 1530.70 1530.09 1469.59 1624.60 1623.94 1563.44 1637.20 1636.54 1576.04 1719.10 1718.39 1657.89 1 41 N 75.28 W .18 8.44N 35.43W 33.04 1 35 N 75.61 W .10 9.12N 38.08W 35.50 1 47 N 67.45 W .33 10.01N 40.70W 37.89 1 46 N 64.61 W .72 10.17N 41.06W 38.21 2 0 N 68.78 W .34 11.24N 43.55W 40.44 1810.80 1810.04 1749.54 1905.90 1905.07 1844.57 1999.50 1998.45 1937.95 2093.80 2092.15 2031.65 2187.20 2184.48 2123.98 1 56 N 70.35 W .10 12.34N 46.51W 43.12 2 22 S 89.86 W .90 12.88N 50.00W 46.43 5 19 S 69.30 W 3.43 11.34N 56.00W 52.62 7 26 S 76.39 W 2.39 8.36N 66.02W 63.03 9 48 S 82.15 W 2.70 5.85N 79.77W 77.00 2279.00 2274.74 2214.24 2372.80 2366.35 2305.85 2468.00 2458.20 2397.70 2561.30 2546.90 2486.40 2655.00 2634.69 2574.19 11 10 S 83.38 W 1.51 3.76N 96.34W 93.66 13 32 S 83.58 W 2.52 1.48N 116.28W 113.65 16 52 S 82.93 W 3.51 1.46S 141.07W 138.53 19 12 S 81.53 W 2.54 5.39S 169.68W 167.36 21 40 S 79.58 W 2.74 10.79S 201.95W 200.06 2748.80 2721.33 2660.83 2842.50 2806.84 2746.34 2937.00 2891.72 2831.22 3031.40 2974.70 2914.20 3124.70 3054.14 2993.64 23 20 S 78.99 W 1.79 17.48S 237.23W 235.96 24 54 S 79.61 W 1.70 24.58S 274.87W 274.25 27 11 S 79.73 W 2.42 32.03S 315.69W 315.74 29 42 S 78.88 W 2.69 40.39S 359.87W 360.70 33 32 S 77.29 W 4.20 50.52S 407.71W 409.60 ORIGINAL SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18 /97 DATE OF SURVEY: 021897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70044 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 3219.70 3132.20 3071.70 35 55 S 75.45 W 2.75 63.30S 460.30W 3313.80 3207.12 3146.62 38 32 S 73.94 W 2.94 78.34S 515.20W 3407.80 3279.05 3218.55 41 34 S 74.20 W 3.24 94.94S 573.37W 3502.30 3348.51 3288.01 43 46 S 75.18 W 2.43 111.85S 635.15W 3564.20 3392.94 3332.44 44 29 S 75.67 W 1.27 122.70S 676.86W 463.68 520.48 580.79 644.70 687.74 3658.20 3459.24 3398.74 45 46 S 75.37 W 1.39 139.36S 741.37W 3752.20 3523.00 3462.50 48 47 S 75.53 W 3.20 156.70S 808.21W 754.27 823.23 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 823.26 FEET AT SOUTH 79 DEG. 1 MIN. WEST AT MD = 3752 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 258.51 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 3,752.00' MD SPE[ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 021897 JOB NUMBER: AK-EI-70044 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -60.50 .00 N .00 E 1000.00 999.64 939.14 6.15 N 22.13 W 2000.00 1998.95 1938.45 11.32 N 56.04 W 3000.00 2947.43 2886.93 37.38 S 344.60 W 3752.20 3523.00 3462.50 156.70 S 808.21 W .00 .36 .36 1.05 .69 52.57 51.52 229.20 176.62 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE] --SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 021897 JOB NUMBER: AK-EI-70044 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -60.50 60.50 60.50 .00 160.50 160.50 100.00 260.50 260.50 200.00 360.51 '360.50 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .07 N .13 W .00 .00 .28 N .49 W .00 .00 .64 N 1.89 W .01 .01 460.55 460.50 400.00 560.61 560.50 500.00 660.67 660.50 600.00 760.73 760.50 700.00 860.79 860.50 800.00 1.24 N 4.56 W 1.95 N 7.88 W 2.87 N 11.13 W 3.94 N 14.49 W 4.92 N 17.80 W .05 .04 .11 .06 .17 .06 .23 .06 .29 .06 960.84 960.50 900.00 1060.89 1060.50 1000.00 1160.93 1160.50 1100.00 1260.98 1260.50 1200.00 1361.04 1360.50 1300.00 5.82 N 20.99 W 6.66 N 23.84 W 7.21 N 26.68 W 7.43 N 29.93 W 7.89 N 33.22 W .34 .05 .39 .04 .43 .04 .48 .05 · 54 .06 1461.09 1460.50 1400.00 1561.13 1560.50 1500.00 1661.17 1660.50 1600.00 1761.23 1760.50 1700.00 1861.29 1860.50 1800.00 8.63 N 36.16 W 9.34 N 38.90 W 10.49 N 41.73 W 11~77 N 44.93 W 12.88 N 48.15 W .59 .05 .63 .04 .67 .05 .73 .06 .79 .06 1961.42 1960.50 1900.00 2061.88 2060.50 2000.00 2162.86 2160.50 2100.00 2264.49 2260.50 2200.00 2366.79 2360.50 2300.00 12.33 N 53.05 W 9.33 N 62.00 W 6.42 N 75.66 W 4.08 N 93.55 W 1.64 N 114.89 W .92 .13 1.38 .46 2.36 .99 3.99 1.62 6.29 2.30 2470.40 2460.50 2400.00 2575.73 2560.50 2500.00 2682.77 2660.50 2600.00 2791.49 2760.50 2700.00 2901.90 2860.50 2800.00 1.55 S 141.77 W 6.12 S 174.43 W 12.65 S 212.04 W 20.71 S 253.90 W 29.17 S 299.90 W 9.90 3.62 15.23 5.32 22.27 7.05 30.99 8.71 41.40 10.41 3015.05 2960.50 2900.00 3132.36 3060.50 3000.00 3254.88 3160.50 3100.00 3383.16 3260.50 3200.00 3518.90 3360.50 3300.00 38.82 S 351.92 W 51.47 S 411.86 W 68.66 S 480.49 W 90.52 S 557.77 W 114.79 S 646.25 W 54 . 55 13 . 15 71.86 17.31 94.38 22 .52 122. 66 28.28 158.40 35.74 SPE '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPK-21 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 021897 JOB NUMBER: AK-EI-70044 KELLY BUSHING ELEV. = 60.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3660.00 3460.50 3400.00 3752.20 3523.00 3462.50 139.68 S 742.62 W 199.50 41.10 156.70 S 808.21 W 229.20 29.69 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 !::! I I__1-- I I~ 13 S I::: !::! ~/I 1-- I~: S WELL LOG TRANSMITTAL To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lod Taylor ' ' 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPK-21 RE: AK-MM-70042 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jkn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22718-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 2, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska The following data of the PDC GR for well MPK-21, Job # 97184, was sent to: BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 CH LIS Tape OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape Sent Certified Mail Z 777 937 565 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska';~:9~'_~~ :i.:~;-~'~ i ~i~ i;;:~, :~:.~- Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by:~~ C) !::t I I_L- I IM O~ S I:::: !::! U' I r- EE S WELL LOG TRANSMITTAL To: State of Alaska April 30, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPK-21, AK-MM-70042 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPK-21: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22718-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22718-00 2"x 5" MD Neutron and Density Logs: 50-029-22718-00 2" x 5" TVD Neutron and Density Logs: 50-029-22718-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 4/24/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10967 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU E-14 PERFORATION RECORD 970416 1 I .. ~ PU E-18 PERFORATION RECORD 97041 5 1 1 MPU E-19 PERFORATION RECORD 970414 1 1 MPU F-701 U~-~ C_ CHEMICAL CUTTER 970320 1 1 MPU F-73 GR/CCL 97031 3 1 1 MPU F-73 PERFORATING RECORD 97031 3 I 1 MPU J-09 [~,t ~ CHEMICAL CUTTER RECORD 97041 7 I 1 ~IPU J-09 ~.. CEiL 97041 8 1 1 M P U J-09~ PERF RECORD 97041 8 I 1 K-21 PERF RECORD W/GR 97031 6 1 1 MPK-21 CEIL 97031 6 1 1 MPK-43A H.P.G, GUNS SHOOTING RECORD 97031 9 1 MPK-43A STATIC PRESSURE SURVEY W/CPLT 97031 9 1 1 MPK-43A CBL 97031 9 1 1 ~ M P K-43A ' H.P.G. GUNS PERFORATION RECORD 970321 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Receive d b~(~~i.~"~~¢,( /,~ PAGE 1 BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 SPEP--P~Y-SUN DRILLING SERVICES ALAS DATE 022397 MWD SURVEY JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -61.29 212.00 212.00 150.71 303.00 302.99 241.70 390.17 390.13 328.84 478.92 478.84 417.55 0 0 N .00 E .00 .00N .00E 0 20 S 17.45 E .16 .60S .19E 0 58 N 87.33 W 1.24 .82S .50W 1 45 N 86.46 W .89 .71S 2.57W 1 59 N 85.62 W .27 .50S 5.45W .00 -.07 .65 2.65 5.45 571.08 570.93 509.64 662.30 662.08 600.79 753.11 752.83 691.54 841.28 840.94 779.65 933.23 932.83 871.54 2 21 N 80.92 W .45 .08S 8.92W 2 5 N 75.16 W .38 .64N 12.39W 2 10 N 76.17 W .09 1.48N 15.67W 1 58 N 83.40 W .37 2.05N 18.81W 2 2 N 80.31 W .13 2.51N 22.00W 8.76 12.02 15.06 18.02 21.06 1023.12 1022.67 961.38 1117.20 1116.71 1055.42 1208.74 1208.19 1146.90 1300.19 1299.58 1238.29 1394.38 1393.71 1332.42 1 43 N 74.21 W .41 3.15N 24.88W 1 51 N 73.37 W .14 3.97N 27.71W 2 8 N 89.08 W .67 4.43N 30.84W 2 3 N 86.99 W .12 4.54N 34.19W 1 57 N 78.97 W .32 4.94N 37.45W 23 .75 26.36 29.34 32.60 35.72 1487.52 1486.80 1425.51 1583.36 1582.60 1521.31 1679.21 1678.40 1617.11 1773.96 1773.08 1711.79 1865.52 1864.58 1803.29 1 46 N 79.59 W .19 5.50N 40.42W 1 48 N 75.80 W .13 6.14N 43.35W 1 54 N 64.63 W .39 7.19N 46.25W 2 13 N 71.05 W .42 8.46N 49.4tW 2 5 N 69.21 W .17 9.63N 52.66W 38.52 41.26 43 .89 46.74 49.68 1961.53 1960.45 1899.16 2051.36 2049.84 1988.55 2148.48 2146.02 2084.73 2242.36 2238.50 2177.21 2331.83 2326.14 2264.85 4 15 S 71.28 W 3.08 9.11N 57.67W 6 45 S 73.65 W 2.80 6.55N 65.89W 9 8 S 80.85 W 2.65 3.72N 78.99W 10 39 S 83.70 W 1.70 1.58N 94.99W 12 29 S 84.34 W 2.05 .28S 112.84W 54.69 63.26 76.67 92.77 110.63 2426.88 2418.26 2356.97 2521.10 2508.25 2446.96 2613.64 2595.37 2534.08 2708.36 2683.08 2621.79 2801.57 2768.41 2707.12 15 55 S 84.56 W 3.62 2.53S 136.06W 18 27 S 84.16 W 2.68 5.28S 163.76W 20 58 S 81.41 W 2.90 9.24S 194.71W 23 22 S 78.82 W 2.74 15.42S 229.90W 24 4 S 78.74 W .76 22.71S 266.69W 133.84 161.53 192.65 228.37 265.87 2896.04 2853.66 2792.37 2989.43 2936.21 2874.92 3083.00 3016.88 2955.59 3177.00 3095.09 3033.80 3270.16 3170.21 3108.92 26 57 S 79.85 W 3.09 30.25S 306.68W 28 45 S 79.99 W 1.93 37.89S 349.64W 32 5 S 77.31 W 3.85 47.26S 396.08W 35 16 S 77.01 W 3.39 58.86S 446.91W 37 12 S 75.21 W 2.36 72.09S 500.35W 306.56 350.18 397.56 449.68 504.69 © !G!NAL SPt £-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 MWD SURVEY JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 3365.28 3244.46 3183.17 3460.43 3315.55 3254.26 3554.62 3383.61 3322.32 3647.60 3449.23 3387.94 3743.29 3513.99 3452.70 4O 10 43 7 44 20 45 50 48 57 S 73.67 W 3.28 88.06S 557.61W S 74.71 W 3.18 105.27S 618.44W S 76.52 W 1.86 121.43S 681.51W S 76.59 W 1.61 136.75S 745.56W S 75.71 W 3.32 153.62S 813.94W 563.98 627.02 692.04 757.86 828.23 3881.78 3604.53 3543.24 3976.78 3666.90 3605.61 4073.82 3731.54 3670.25 4169.17 3794.08 3732.79 4263.31 3852.99 3791.70 49 23 48 31 47 56 50 3 52 27 S 77.20 W .87 178.16S 915.81W S 77.98 W 1.10 193.56S 985.79W S 79.25 W 1.15 207.85S 1056.74W S 80.67 W 2.49 220.38S 1127.58W S 78.83 W 2.97 233.46S 1199.83W 932.95 1004.59 1076.97 1148.89 1222.29 4358.42 3911.01 3849.72 4449.81 3966.82 3905.53 4543.68 4024.10 3962.81 4639.02 4081.96 4020.67 4730.89 4136.96 4075.67 52 20 52 22 52 24 52 52 53 34 S 78.44 W .34 248.31S 1273.71W S 78.09 W .31 263.03S 1344.57W S 78.12 W .04 278.36S 1417.34W S 77.49 W .71 294.37S 1491.41W S 77.69 W .78 310.18S 1563.27W 1297.65 1370.02 1444.38 1520.16 1593.73 4823.53 4192.23 4130.94 4918.85 4249.89 4188.60 5012.00 4307.43 4246.14 5104.96 4366.46 4305.17 5199.83 4425.96 4364.67 53 10 52 22 51 19 49 49 52 28 S 79.00 W 1.21 325.20S 1636.08W S 77.96 W 1.22 340.35S 1710.45W S 77.75 W 1.14 355.76S 1782.05W S 78.69 W 1.78 370.43S 1852.34W S 78.72 W 2.79 384.90S 1924.79W 1668.07 1743.97 1817.21 1889.00 1962.89 5294.52 4483.90 4422.61 5388.78 4541.86 4480.57 5480.99 4598.65 4537.36 5574.46 4656.06 4594.77 5671.86 4715.27 4653.98 52 4 52 2 51 56 52 16 52 50 S 78.92 W .46 399.42S 1998.26W S 78.33 W .49 414.08S 2071.14W S 78.12 W .21 428.91S 2142.26W S 77.78 W .45 444.30S 2214.39W S 78.03 W .62 460.51S 2290.01W 2037.78 2112.11 2184.76 2258.52 2335.84 5762.77 4769.94 4708.65 5856.73 4825.74 4764.45 5949.99 4881.45 4820.16 6042.51 4937.82 4876.53 6135.84 4994.68 4933.39 53 53 52 52 52 13 54 44 11 43 S 77.44 W .67 475.94S 2360.98W S 75.21 W 2.04 493.81S 2434.42W S 75.56 W 1.28 512.69S 2506.79W S 77.58 W 1.83 529.73S 2578.13W S 77.06 W .73 545.97S 2650.33W 2408.47 2484.00 2558.67 2631.99 2705.97 6230.74 5052.17 4990.88 6324.76 5107.89 5046.60 6418.05 5162.09 5100.80 6511.11 5217.20 5155.91 6605.55 5273.64 5212.35 52 54 54 52 53 42 35 22 59 35 S 80.40 W 2.80 560.73S 2724.37W S 79.80 W 2.06 573.75S 2798.95W S 78.84 W .87 587.82S 2873.57W S 78.53 W 1.52 602.53S 2947.09W S 77.79 W .90 618.07S 3021.19W 2781.46 2857.15 2933.07 3008.05 3083.76 .Y-SIIN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 MWD SURVEY JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6703.06 5332.24 5270~95 52 31 S 78.52 W 1.26 634.07S 3097.46W 6795.45 5388.00 5326.71 53 13 S 77.74 W 1.02 649.22S 3169.55W 6890.09 5444.24 5382.95 53 50 S 77.77 W .66 665.36S 3243.93W 6982.83 5499.87 5438.58 52 25 S 78.08 W 1.55 680.89S 3316.49W 7076.80 5556.69 5495.40 53 9 S 77.76 W .81 696.55S 3389.67W 3161.69 3235.35 3311.46 3385.65 3460.49 7170.41 5612.19 5550.90 54 7 S 77.51 W 1.07 712.69S 3463.30W 7263.16 5667.20 5605.91 53 6 S 78.44 W 1.36 728.25S 3536.33W 7356.85 5724.55 5663.26 51 24 S 78.57 W 1.83 743.0tS 3608.92W 7450.80 5782.90 5721.61 51 48 S 77.52 W .98 758.27S 3680.95W 7544.55 5840.47 5779.18 52 25 S 77.52 W .65 774.26S 3753.19W 3535.86 3610.52 3684.60 3758.23 3832.21 7636.64 5896.05 5834.76 53 19 S 76.59 W 1.27 790.71S 3824.75W 7729.47 5952.05 5890.76 52 27 S 77.24 W 1.10 807.47S 3896.85W 7824.26 6009.30 5948.01 53 15 S 76.81 W .92 824.43S 3970.47W 7918.24 6066.21 6004.92 52 12 S 77.46 W 1.25 841.09S 4043.37W 8011.04 6122.69 6061.40 52 49 S 75.66 W 1.68 858.20S 4114.98W 3905.60 3979.60 4055.13 4129.88 4203.46 8106.10 6181.18 6119.89 51 13 S 77.61 W 2.33 875.53S 4187.86W 8198.89 6238.86 6177.57 51 55 S 78.20 W .90 890.76S 4258.93W 8298.11 6299.37 6238.08 52 55 S 76.11 W 1.95 908.25S 4335.58W 8391.32 6356.79 6295.50 51 1 S 78.53 W 2.89 924.38S 4407.19W 8485.47 6417.62 6356.33 48 29 S 81.73 W 3.73 936.73S 4477.96W 4278.33 4351.02 4429.61 4503.00 4574.81 8578.96 6481.25 6419.96 45 43 S 82.06 W 2.96 946.39S 4545.77W 8673.94 6548.68 6487.39 43 46 S 81.45 W 2.10 955.98S 4611.94W 8768.56 6617.81 6556.52 42 20 S 82.06 W 1.58 965.24S 4675.87W 8861.12 6687.18 6625.89 40 33 S 79.69 W 2.56 974.94S 4736.35W 8950.45 6756.06 6694.77 38 31 S 80.16 W 2.31 984.89S 4792.33W 4643.19 4709.94 4774.43 4835.63 4892.47 9044.77 6829.84 6768.55 38 32 S 79.96 W .14 995.03S 4850.21W 9139.86 6903.99 6842.70 38 57 S 80.12 W .44 1005.33S 4908.83W 9231.89 6975.24 6913.95 39 34 S 79.81 W .71 1015.48S 4966.19W 9324.81 7046.64 6985.35 39 59 S 78.74 W .86 1026.55S 5024.61W 9418.97 7118.57 7057.28 40 24 S 79.27 W .57 1038.13S 5084.27W 4951.21 5010.72 5068.95 5128.40 5189.17 9513.21 7189.88 7128.59 41 15 S 79.95 W 1.02 1049.24S 5144.86W 9608.77 7261.03 7199.74 42 29 S 79.45 W 1.34 1060.65S 5207.61W 9703.45 7330.27 7268.98 43 30 S 79.71 W 1.09 1072.33S 5271.12W 9778.48 7384.24 7322.95 44 30 S 79.22 W 1.40 1081.86S 5322.36W 9845.00 7431.69 7370.40 44 30 S 79.22 W .00 1090.58S 5368.16W 5250.76 5314.53 5379.08 5431.20 5477.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5477.82 FEET AT SOUTH 78 DEG. 30 MIN. WEST AT MD = 9845 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 258.51 DEG. TIE-IN SURVEY AT 0.00' MD PRO--TECTED SURVEY AT 9,845.00' Sp° Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -61.29 1000.00 999.56 938.27 2000.00 1998.81 1937.52 3000.00 2945.46 2884.17 4000.00 3682.28 3620.99 .00 N .00 E 2.96 N 24.21 W 8.20 N 60.37 W 38.79 S 354.68 W 197.18 S 1002.81 W .00 .44 .44 1.19 .75 54.54 53.35 317.72 263.18 5000.00 4299.93 4238.64 6000.00 4911.75 4850.46 7000.00 5510.34 5449.05 8000.00 6116.02 6054.73 9000.00 6794.83 6733.54 353.78 S 1772.90 W 522.50 S 2545.33 W 683.70 S 3329.80 W 856.03 S 4106.46 W 990.17 S 4822.73 W 700.07 382.34 1088.25 388.18 1489.66 401.42 1883.98 394.32 2205.17 321.19 9845.00 7431.69 7370.40 1090.58 S 5368.16 W 2413 . 31 208 . 14 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPi Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -61.29 61.29 61.29 .00 161.29 161.29 100.00 261.29 261.29 200.00 361.31 361.29 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .31 S .10 E .00 .00 .85 S .21 E .00 .00 .76 S 1.69 W .02 .02 461.36 461.29 400.00 561.43 561.29 500.00 661.51 661.29 600.00 761.58 761.29 700.00 861.64 861.29 800.00 .55 S 4.85 .14 S 8.53 .64 N 12.37 1.56 N 15.98 2.13 N 19.50 W .07 .05 W .14 .07 W .22 .08 W .29 .07 W .35 .06 961.71 961.29 900.00 1061.75 1061.29 1000.00 1161.81 1161.29 1100.00 1261.88 1261.29 1200.00 1361.94 1361.29 1300.00 2.68 N 22.99 3.47 N 26.00 4.37 N 29.11 4.47 N 32.81 4.72 N 36.37 W .42 .06 W .46 .05 W .52 .05 W .59 .07 W .65 .06 1461.99 1461.29 1400.00 1562.04 1561.29 1500.00 1662.09 1661.29 1600.00 1762.16 1761.29 1700.00 1862.23 1861.29 1800.00 5.36 N 39.65 5.97 N 42.69 6.95 N 45.74 8.31 N 48.98 9.58 N 52.55 W .70 .06 W .75 .05 W .80 .05 W .87 .06 W .94 .07 1962.38 1961.29 1900.00 2062.89 2061.29 2000.00 2163.94 2161.29 2100.00 2265.55 2261.29 2200.00 2367.94 2361.29 2300.00 9.09 N 57.72 6.18 N 67.24 3.33 N 81.42 1.11 N 99.25 1.09 S 121.04 W W W W W 1.09 .15 1.60 .52 2.65 1.05 4.26 1.61 6.65 2.38 2471.67 2461.29 2400.00 2577.27 2561.29 2500.00 2684.68 2661.29 2600.00 2793.77 2761.29 2700.00 2904.61 2861.29 2800.00 3.72 S 148.44 7.45 S 182.12 13.67 S 220.81 22.09 S 263.57 30.94 S 310.50 W W W W W 10.38 3.73 15.98 5.60 23.39 7.41 32.48 9.09 43.32 10.83 3018.19 2961.29 2900.00 3135.96 3061.29 3000.00 3258.96 3161.29 3100.00 3387.44 3261.29 3200.00 3523.41 3361.29 3300.00 40.45 S 363.48 53.65 S 424.22 70.36 S 493.80 92.08 S 571.45 116.35 S 660.29 56.90 13.58 74.67 17.77 97.67 23.00 126.15 28 . 49 162.12 35.97 SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3665.02 3461.29 3400.00 3815.38 3561.29 3500.00 3968.31 3661.29 3600.00 4118.24 3761.29 3700.00 4276.93 3861.29 3800.00 139.68 S 757.79 W 166.94 S 866.69 W 192.24 S 979.58 W 214.00 S 1089.14 W 235.55 S 1210.42 W 203.73 41.61 254.09 50.36 307.02 52.93 356.95 49.93 415.64 58.70 4440.75 3961.29 3900.00 4604.78 4061.29 4000.00 4771.84 4161.29 4100.00 4937.52 4261.29 4200.00 5096.94 4361.29 4300.00 261.55 S 1337.55 W 288.46 S 1464.76 W 317.17 S 1595.46 W 343.44 S 1724.91 W 369.22 S 1846.33 W 479.46 63.82 543.49 64.03 610.55 67.06 676.23 65.68 735.65 59.41 5257.73 4461.29 4400.00 5420.36 4561.29 45'00.00 5583.01 4661.29 4600.00 5748.32 4761.29 4700.00 5916.68 4861.29 4800.00 393.84 S 1969.78 419.12 S 2095.52 445.74 S 2221.01 473.42 S 2349.68 506.07 S 2481.10 W 796.44 60.79 W 859.07 62.64 W 921.72 62.65 W 987.03 65.31 W 1055.39 68.36 6080.81 4961.29 4900.00 6245.79 5061.29 5000.00 6416.68 5161.29 5100.00 6584.74 5261.29 5200.00 6750.90 5361.29 5300.00 536.24 S 2607.68 W 562.72 S 2736.17 W 587.60 S 2872.48 W 614.52 S 3004.82 W 641.69 S 3134.69 W 1119.52 64.13 1184.50 64.98 1255.39 70.90 1323.45 68.06 1389.61 66.16 6918.99 5461.29 5400.00 7084.46 5561.29 5500.00 7253.31 5661.29 5600.00 7415.86 5761.29 5700.00 7578.69 5861.29 5800.00 670.31 S 3266.74 697.85 S 3395.66 726.67 S 3528.61 752.35 S 3654.14 780.11 S 3779.61 W 1457.70 68.09 W 1523.17 65.47 W 1592.02 68.85 W 1654.57 62.55 W 1717.40 62.83 7744.63 5961.29 5900.00 7910.21 6061.29 6000.00 8074.34 6161.29 6100.00 8235.26 6261.29 6200.00 8398.45 6361.29 6300.00 810.12 S 3908.57 839.71 S 4037.18 870.22 S 4163.67 896.62 S 4286.96 925.46 S 4412.61 W 1783.34 65.93 W 1848.92 65.58 W 1913.05 64.13 W 1973.97 60.92 W 2037.16 63.18 8550.12 6461.29 6400.00 8691.40 6561.29 6500.00 8827.04 6661.29 6600.00 8957.14 6761.29 6700.00 9085.00 6861.29 6800.00 943.50 S 4525.15 957.77 S 4623.89 970.97 S 4714.55 985.60 S 4796.43 999.40 S 4874.90 W 2088.83 51.68 W 2130.11 41.28 W 2165.75 35.64 W 2195.85 30.09 W 2223.71 27.86 SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPK-21i 500292271800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 022397 JOB NUMBER: AK-MM-70042 KELLY BUSHING ELEV. = 61.29 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9213.79 6961.29 6900.00 1013.44 S 4954.85 W 2252.50 28.80 9343.93 7061.29 7000.00 1028.94 S 5036.66 W 2282.64 30.14 9475.21 7161.29 7100.00 1044.86 S 5120.21 W 2313.92 31.28 9609.12 7261.29 7200.00 1060.69 S 5207.84 W 2347.83 33.91 9746.31 7361.29 7300.00 1077.65 S 5300.22 W 2385.02 37.19 9845.00 7431.69 7370.40 1090.58 S 5368.16 W 2413.31 28.29 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Facility M Pt K Pad Progress Report Well MPK-21 Page 1 Rig Nabors 5S Date 12 December 97 Date/Time 17 Oct 97 18 Oct 97 19 Oct 97 20 Oct 97 21 Oct 97 06:00-12:00 12:00-22:00 22:00-00:00 00:00-03:00 03:00-05:00 05:00-06:00 06:00-13:00 13:00-14:00 14:00-19:00 19:00-22:30 22:30-04:30 04:30-05:00 05:00-06:00 06:00-08:30 08:30-12:00 12:00-01:30 01:30-04:30 04:30-06:00 06:00-08:00 08:00-08:30 08:30-10:30 10:30-14:30 14:30-15:00 15:00-17:30 17:30-17:45 17:45-01:00 01:00-01:30 01:30-03:00 03:00-06:00 Duration 6hr 10hr 2hr 3hr 2hr lhr 7hr lhr 5hr 3-1/2 hr 6hr 1/2hr lhr 2-1/2 hr 3-1/2 hr 13-1/2 hr 3hr 1-1/2 hr 2hr 1/2 hr 2hr 4hr 1/2 hr 2-1/2 hr 1/4 hr 7-1/4 hr 1/2 hr 1-1/2 hr 3hr Activity Rig moved 100.00 % Rigged up Drillfloor / Derrick Fill pits with Brine Removed Accessories Removed Xmas tree Held safety meeting Rigged up BOP stack Removed Accessories Tested All functions Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 0.0 ft (3-1/2in OD) Held safety meeting Ran Tubing to 348.0 ft (3-1/2in OD) Ran Tubing in stands to 704.0 ft Serviced Tubing handling equipment Ran Tubing to 9519.0 ft (3-1/2in OD) Conducted electric cable operations Installed Tubing hanger Installed Hanger plug Held safety meeting Rigged down BOP stack Installed Wellhead primary components Tested Wellhead primary components Removed Hanger plug Held safety meeting Reverse circulated at 9519.0 ft Set packer at 9505.0 ft with 2000.0 psi Tested Hydraulic packer Installed Hanger plug MILNE POINT, ALASKA Main Category: Sub Category: Operation Date: TO: Rossberg/Hill FROM: Mark O'Malley WELL# MPK- 21i GR/CCL, SBT / initial perfs Drlg Marked /Gr. Cci /perf 03 / 16 ! 97 Date: 103-17-97 I Objective: Run magnetic marked line gr/ccl and peff 26' of Kuparuk C sand. Operations: 10:00 RU SWS arrived location, Pre job operational and safety meeting. 11:00 RIH with GR / CCL / SBT on magnetic marked line. run in to TD. Tag TD at 9,726' MDBKB. POH logging SBT / GR / CCL. Cement job looks real good from shoe through the perforation intervals. Found top of the cement @ 5,600' mdbkb Shut down SBT. Continue with GR / CCL until above the 9-5/8" shoe @ 3,700', Continue out of the hole logging with the marked line. 13:00 Obtain radio silence on pad. Pre perforating operational and safety meeting. PU 17', 3.5" perf gun, ccl. Pressured tested lubricator to 2,500 psi RIH with guns 10.3 brine in well. Logged guns into position. Had to make 2' deeper depth shift from the perforation depths on the MWD log. 15:30 Tie in with 3/16/97 SWS GR / CCL. Some difficulty obtaining collars never really able to catch any, Tag TD at 9,726'. Correct with TD tag and GR to get on depth. Perforated MD. 9,502' - 9,485' spotted CCL @ 9,477.5' md 7.5' from CCL to top shot. Guns fired. Log off. Well went on a vacuum. POH. 16:00 RIH with 9' gun. Tie in with 3/16/97 SWS GR / CCL. Same difficulty obtaining collars never really able to catch any, Tag TD at 9,726'. Correct with TD tag and GR to get on depth. Perforated MD. 9,485' - 9,476' spotted CCL @ 9,470.7' md 5.3' from CCL to top shot. Guns fired. Log off. POH. 21:00 OOH. RD. SIWHP=0psi. Summary: Magnetic marked SBT/GR/CCL run from PBTD of 9,726' MDBKB to 9 5/8" shoe at 5,600' MD. SBT run; good compressive strength throughout. Perforated 9,502'-9,476' MDBKB reference to 3/16/97 SWS gr/ccl with 3.5" Gun with 34 gm 34"Penetrating charges, 4 spf, 0.37" EHD, 60 deg phasing. Did not depth shift any logs to match LWD logs. No problems getting down hole on either run. Will get pressure survey with slickline at later date. TONY KNOWLE$, GOVERNOR ~[~SKA 01~ ~ G3~ CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 24, 1997 Randy Thomas Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPKo21i BP Exploration (Alaska) Inc. 96-176 3620~SL, 2089'WEL, Sec 3, T12N, R11E, UM 2514~'SL, 2240'WEL, Sec 4. T12N, R11E, UM Dear Mr. Thomas: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated October 30, 1996 are in effect for this revision. · BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section- w/o encl Dept of Environmental Conservation- w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED 01/14/97 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 60.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025i''' 3620' NSL, 2089' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2563' NSL, 2000' WEL, SEC. 4, T12N, R11E MPK-21i .. Attotal depth 9. Approximate spud date Amount $200,000.00 2514' NSL, 2240' WEL, SEC. 4, T12N, R11E 02/10/97 12. Distance to nearest property line113. Distance to nearest well i14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028231, 2766'I No Close Approach 2560 9945' MD / 7507' TVD .... 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 52.35° Maximum surface 2956 psig, At total depth (TVD) 7039' / 3660 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3776' 31' 31' 3807' 3561' 942 sx PF'E', 718 sx'G' 8-1/2" 7" 26# L-80 Btrc 9914' 30' 30' 9945' 7507' 256 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor SurfaceRECEIVED Intermediate Production Liner JAN '17 1997 0RI 61~,J~L Alas. Oil&GasCons. Commission Anchorage Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed S '""~'-% (/"~ 6'/ RandyThom2 ~"~'"-"" Title Drilling Superintendent Date Commission Use Only 96-176 50-029-22718 10/30/96 for other requir.e, ments Conditions of Approval: Samples Required [] Yes ,~ No Mud Log Required [] Yes ,~ No Hydrogen Sulfide Measures ,~Yes [] No Directional Survey Required '~ Yes [] No Required Working Pressure for DOPE [] 2M; []3M; ~ii~5M; [] 10M; [] 15M Other: ¢! ~g~nal Signed By by order of Approved By [~.vid W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: Lance Spencer J Well Name: IMP K-21i (Kuparuk) l Well Plan Summary 564-5042 I Type of Well (producer or injector): I Kuparuk Injector Surface Location: 3620 NSL 2089 WEL Sec 03 T12N R11E UM., AK Kuparuk Target 2563 NSL 2000 WEL Sec 04 T12N R11E UM., AK Location: Bottom Hole 2514 NSL 2240 WEL Sec 04 T12N R11E UM., AK Location: IAFE Number: 1337053 I I Ri~l: I Nabors 27-E IEstimated Start 10 Feb 97 Operating days to I 1 2 Date' complete: I IWell Design (conventional, slimhole, I Milne Point Ultra Slimh,,ole Longstring 9- etc.)' I 5/8", 40# Surface X 7, 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1,862 1,861 8.3 ppg, 803 psi NA 5,082 4,341 8.3 ppg, 1874 psi (::A 5,278 4,461 8.3 ppg, 1925 psi CB 5,393 4,5 31 8.3 ppg, 1956 psi Base OB 5,442 4,5 61 8.3 ppg, 1969 psi Top HRZ 8,742 6,5 96 8.6 ppg, 2950 psi Base HRZ 9,003 6,786 8.6 ppg, 3035 psi TKLB 9,068 6,8 36 10 ppg, 3555 psi TKUP/UD 9,264 6,986 10 ppg, 3633 psi OWC 9,41 3 7,1 0 0 10 ppg, 3692 psi TKUC 9,421 7,106 10.0 ppg, 3695 psi TKCl/TARGET 9,564 7,21 6 10.0 ppg, 3752 psi TKUB/B8 9,629 7,266 10.0 ppg, 3778 psi TKB7 9,656 7,286 10.0 ppg, 3789 psi Total Depth +9,945 7,507 10.0 ppg, 3904 psi Casinq/Tubing Pro! ram: Hole (~sg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 3776 31/31 3807/3561 8- 1/2" 7" 2 6 # L-80 btrc 991 4 30/30 9945/7507 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKUP/UD at _+ 7039 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7039 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3660 psi is 2956 psi, well below the internal yield pressure rating of the 7" casing. Logging Program Open Hole Logs: Surface MWD Directional from surface to TD. Intermediate N/A Final Cased Hole Logs: Mud Logging MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. MWD GR: EWR4: CNP: SLD: ROP: Directional: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Program: Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on K-Pad. Prior to spudding a complete review of the K-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the surface hole. HYDRATES Hydrates are present on K-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on K-Pad. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 50 35 1 5 30 1 0 1 5 Intermediate Mud Pro)erties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 1 0 3 7 8.5 6 - 8 to to to to to to to 10.2 50 1 5 1 0 20 9.5 4-5 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:300' Maximum Hole Angle: 52.35° Close Approach Well: (No Shut In Wells) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be-opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations 1. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are _+10 wells on Milne Pt. 'K' Pad. quarter mile distance from the subject well. located within one mile of the project area. There may be additional unidentified wells within one There are no domestic or industrial water use wells 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". The cement design for this well ensures that annular pumping into hydrocarbon zones will not Occur. . . . . . . . . . 10. 11. 12. 13. 14. MP K-21i(Kup) Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. Run 9-5/8" casing. Space out ES Type H Cementer to 1300', Perform Two Stage cement. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+- 2 1 0 0' MD). Test casing to 4000 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. DRILLING HAZARDS AND RISKS: GAS HYDRATES Every well on K-Pad has encountered hydrate sections while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on K-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. The measures are necessary to lessen to effects of gas hydrates: 1. Increased mud weights 2. Low drilling fluid temperatures 3. Reduced ROP's for control drill rates 4. Controlled circulating and drilling fluid rates 5. Utilization of Lecithin Close Approaches There are no close approaches associated with the drilling of MP K-21i however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annular Injection Currently annular injection is not permitted injected into the K-17 annulus defore . Gas Injection No gas injection wells are present on K-Pad Lost Circulation: on K-Pad. A total R E~,6~H~ ~l~[~vere JAN ]7 '1997 J~aska 0JJ & Gas Cons. Commission Anchorage Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. K-05 experienced lost circulation while drilling the 12-1/4" surface hole at 2250 Md. K-02 , K-05 and K-06 experienced losses while circulating to condition mud while running 7" casing. K-05 and K-06 experienced lost circulation while cementing 7" csg. In many instances were losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Stuck Pipe Potential: Running gravel's, (K-17, K-38); sticky clays, (K-02, K-05, K-38, K-39); tight coal sections (K-17); tight hole and bridging, (K-17, K-25, K-38); and stuck pipe, (K-17); occured while drilling the 12 1-4" surface holes on K-Pad. Excessive amounts of reaming were required wile drilling K-17 and K-25. While running 9-5/$" casing the flowing problems were experienced: K-05, hole packing off; tight hole and bridging, K-2, K-39. The 9-5/6" casing was stuck in K- 05. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. Increased torque and drag have been experienced after drilling into Kuparuk so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. While drilling K-34 (deep set surface) additional time was spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the Kuparuk formation in balance. Formation Pressure: KUPARUKSAND 7000' TVD 3600 PSI 9.9 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKUP/UD at +_ 7039 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7039 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3660 psi is 2 9 5 6 psi. The maximum expected pore pressure for this well is 10.0 ppg EMW (3,660 psi @ 7,039' TVDss). There has been injection in this region since MP K-17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. MP K-21i(Kuparuk Injector) 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840' TVDSS. TWO STAGE CEMENT PROGRAM: Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before switching to DISPLACEMENT. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. This volume may exceed the annular capacity and the 250% estimated excess. 1. The ES Cementer is located at 1300' md. 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Only a Lead slurry is pumped in the second stage. 5. Dye shall be introduced into the weighted spacer before the first stage and into the water before the second stage in order to obtain an estimate of annular capacity so that if required additional cement can supplied and adequate excess can bepumped. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize large flow area float shoe. 9. Use weighted spacer before first stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the water spacer before the second stage to assist in determining the annular volume. 1 1. Incorporate "Celloflakes" into ONLY the First Stage cement lead and tail slurries. Caution: 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPING DISPLACEMENT. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulation. Note: First Stage. SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Permafrost E ADDITIVES: 0.15#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 285 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Flocele WEIGHT: APPROX #SACKS: 718 FLUID LOSS: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 4.9 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 Second Stage: SPACER: 75 bbls Water 2nd LEAD CEMENT TYPE:' Permafrost E ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.55 gal/sk 6 5 7 THICKENING TIME: Greater than 4 hrs at 50° F. Wellhead Stability Cement CEMENT TYPE: Permafrost E ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk Centralizer Placement: 1. Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade TURBULATOR Centralizers per joint on the 9-5/8" casing on from 2200-2700 feet to cover the top hydrate intervals (required). Place all centralizers in middle of joints using stop collars. Surface Cement Volumes: , First Stage Lead Cement Volume = Interval from1300-1862' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer at 1300' md to the Base of the Permafrost at 1862' md + 30% EXCESS. , First StageTail Cement Volume = Interval from1862-3807' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the Base of the Permafrost at 1862' md to surface TD at 3807' md (3561' TVDbkb) plus 30% Excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40#casing. 3, Second Stage Tail Cement Volume = Interval from 0-1300 md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 1300' MD (1299' TVDbkb) to surface plus 250% excess, , The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to Pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. 2. After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well to improve changes of getting cement to surface. If the cement falls back, do a wellhead stability cement job. MP K-21i (Kuparuk Injector) Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON This cement program is proposed only if the Schrader Bluff formations are NOT hydrocarbon bearing. In the event the Schrader Bluff formations proves to be hydrocarbon bearing a revised cement program will be submitted. Casing Size: 7" 26# L-80 SINGLE STAGE CEMENT JOB: SPACERs: CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. Cement from TD to 1000' above KUPARUK TKUP/UD. 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 256 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. 2. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME: Interval 8264-9945' md 1. Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. Well ......... : MPK-21(P4) Field ........ : MILNE POINT,KPAD Anadrill Sch~u~k~r~er Alaska District !121 East 80th Avenue Anchorage, AK 99518 {907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Prepared ..... : 30 Dec 1996 Vert sect az.: 258.51 Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.42565271 N KB elevation.: 60.50 ft Magnetic Dcln: +28.262 (E) Scale Factor.: 0.99990810 Surface Long.: 149.31168133 W Convergence.,: +0.64854256 LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 3620 FSL 2089 FEL SOB T12N RllE UM 584467.62 6005755,35 TARGET ....... : 2563 FSL 2000 FEL S04 T12N RllE UM 579291,00 6004642.00 BHL .......... : 2514 FSL 2240 FEL S04 T12N RllE UM 579051.88 6004590.57 PROPOSED WELL PROFILE FOR STUDY ONLY STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE KB 0.00 0,00 NUDGE-BUILD 1/100 300.00 0.00 400.00 1.00 500.00 2.00 600.00 3.00 END 1/100 BUILD DROP 1/10O 700.00 4,00 900.00 4,00 1000.00 3.00 1100.00 2.00 1200.00 1.00 END 1/100 DROP 1300.00 0.00 BUILD 2/100 1700.00 0.00 (Anadrill (c196 MPK21P4 3.0C 5;13 PM P) DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 0.00 0.00 -60.50 0.00 300.00 239.50 258,51 399.99 339,49 258.51 499.96 439.46 258.51 599.86 539.36 258.51 699,68 639.18 258.51 899.19 838.69 258.51 999.00 938.50 258,51 11098.90 1038.40 258.51 1198,87 1.138.37 0.00 1298.86 1238,36 0.00 1698.86 1638,36 SECTION COORDINATES-FROM DEPART WELLHEAD l=~== ........ 0.00 0,00 N 0.00 -0.00 0,00 N 0.00 0 . 87 O. 17 S O. 86 3.49 0.70 S 3,42 7.85 1.56 S 7.69 13.96 2.78 S 13.68 W 27,91 5.56 S 27.35 W 34.01 6.77 S 33.33 W 38,37 7.64 S 37,61 W 40 . 99 8 . 17 S 40,17 W 41,87 8.34 S 41.03 W 41.87 8.34 S 41,03 W ALASKA Z°ne 4 X Y ........... ~=~nm~ 584467.62 6005755.35 584467.62 6005755.35 584466.77 6005755.17 584464.21 6005754,62 584459,94 6005753.70 TOOL FACE HS 101L 101L 101L 101L DL/ lO0 0. O0 0.00 1.00 1.00 1.00 584453,98 6005752.42 101L 1.00 584440.34 6005749.48 101L 0.00 584434.37 6005748,20 101L 1.00 584430.11 6005747.28 101L 1.00 584427.55 6005746.73 HS 1.00 584426.69 6005746.55 HS 1.00 584426.69 6005746.55 101L 0.00 u) '0 0 STAT I ON IDENTIFICATION END 2/100 BUILD BASE PERMAFROST BUILD 2.5/100 9-5/8" CASING POINT END 2.5/100 BUILD MEASURED INCLN DEPTH ANGLE 1800.00 2.00 1822.00 2.44 1861.71 2.44 1902.00 2.44 2000.00 4.89 2100.00 7.39 2200.00 9.89 2300 00 12,39 2400 O0 14.89 2500 00 17.39 2600 00 19.89 2700.00 22.39 2800,00 24.89 2900.00 27.39 3000.00 29.89 3100.00 32.39 3200.00 34.89 3300.00 37.39 3400.00 39,89 3500.00 42.39 3600.00 44.89 3700.00 47.39 3800.00 49.89 3807.00 50.07 3898.25 52.35 NA 5081.50 52.35 OA 5277.94 52.35 OB 5392.53 52.35 PF, CPi. SED %;E'_.L PROFILE =~mn~um= .......... mm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 258.51 1798.84 1738.34 258.51 1820.83 1760.33 258.51 1860.50 1800.08 258.51 1900.75 1840.25 258.51 1998.55 1938.05 SECTION DEPART 43.61 44.46 46.15 47.87 54.13 _.-_==== _-===============~=~= ==== COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD 8.69 S 8.86 S 9.19 S 9.53 S 10.78 S X Y FACE 100 42.74 W 584424.99 6005746.18 101L 2.00 43.57 W 584424.16 6005746.00 101L 2.00 45.23 W 584422.50 6005745.65 101L 0.00 46.91 W 584420.83 6005745.29 101L 0.00 53.05 W 584414.70 6005743.97 101L 2.50 258.51 2097.96 2037.46 64.83 12.91 S 63.53 W 258.51 2196.82 2136.32 79.85 15.90 S 78.25 W 258.51 2294.93 2234.43 99.17 19.75 S 97.18 W 258.51 2392.10 2331.60 122.75 24.45 S 120.29 W 258.51 2488.15 2427.65 150.54 29.99 S 147.53 W 258.51 2582.90 2522.40 182.50 36.35 S 178.85 W 258.5! 2676.16 2615.66 218.57 43.54 S 214.19 W 258.51 2767.76 2707.26 258.66 51.52 S 253.48 W 258.51 2857.53 2797.03 302.71 60.30 S 296.65 W 258.53 2945.29 2884.79 350.64 69.84 S 343.62 W 258.51 3030.87 2970,37 258.51 3114.12 3053.62 258.51 3194.87 3134.37 258.51 3272.97 3212.47 258.51 3348.28 3287.78 402.35 457.74 516.71 579.15 644.94 80.14 S 91.18 S 102.92 S 115.36 S 128.46 S 394.29 W 448.57 W 506.36 W 567.95 W 632.01 W 584404.25 6005741.72 NS 2.50 584389.56 6005738.56 HS 2.50 584370,68 6005734.50 HS 2.50 584347.63 6005729,54 HS 2.50 584320.45 6005723.70 HS 2.50 584289.21 6005716.98 HS 2.50 584253.96 6005709.40 HS 2.50 584214.76 6005700.97 HS 2.50 584171.70 6005691.71 HS 2.50 584124.85 6005681.63 HS 2.50 258.51 3420.64 3360.14 713.94 142.21 S 699.64 W 258.51 3489.92 3429.42 786.04 156.57 S 770.29 W 258.51 3556.00 3495.50 861.09 171.52 S 843.84 W 258.51 3560.50 3500.00 866.46 172.59 S 849.09 W 258.51 3617.67 3557.17 937.57 186.75 S 918.78 W 258.51 4340.50 4280.00 1874.37 373.35 S 258.51 4460.50 4400.00 2029.89 404.33 S 258.51 4530.50 4470.00 2120,62 422.40 S 584074.30 6005670.76 HS 2.50 584020.15 6005659.11 HS 2.50 583962,50 6005~46.71 MS 2.50 583901.47 6005633.59 HS 2.50 583837.16 6005619.76 ES 2.50 583769.70 6005605.25 HS 2.50 583699.22 6005590.09 HS 2.50 583625.85 6005574.31 HS 2.50 583620.61 6005573.18 HS 2.50 583551,09 6005558.23 HS 2.50 1836.81 W 582635.32 6005361.27 HS 0.00 1989.22 W 582483.29 6005328.57 NS 0.00 2078.12 W 582394.60 6005309.50 HS 0.00 0 ee 'g (Anadrill (c)96 MPK21P4 3.0C 5:13 PM P) STATION IDENTIFICATION BASE OB DROP 2/100 THRZ MEASURED INCLN DEPTH ANGLE 5441.64 52.35 8385.46 52.35 8400.00 52.06 8500.00 50.06 8600.00 48.06 8700.00 46.06 8744.65 45,16 8800.00 44.06 8900.00 42.06 9000.00 40.06 BHRZ 9002.78 40.00 END 2/100 DROP 9002.78 40.00 TKLB 9068.05 40.00 TKUP/UD 9263.86 40.00 OWC 9412.68 40.00 TKUC 9420.51 40.00 TARGET 9564.11 40.00 TKC1 956~.11 40.00 TKUB/B8 9629.38 40.00 TKB7 9655.48 40.00 DZRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 258.51 4560.50 4500.00 258.51 6358.85 6298.35 258.51 6367.76 6307.26 258.51 6430.61 6370.11 258.51 6496.14 6435.64 TKB6 9694.65 40.00 TKB5 9720.75 40,00 7" CASING POINT 9944.65 40.00 TD 9944.65 40.00 SECTION DEPART 2159.50 4490.18 4501.66 4579.43 4654.96 258.51 6564.26 6503.76 4728.16 258.51 6595.50 6535.00 4760.07 258.51 6634.90 6574.40 4798.94 258.51 6707.97 6647.47 4867.20 258.51 6783.37 6722.87 4932.88 COORDINATES-FROM WELLHEAD 430.1~ S 211~.22 W 894.38 S 4400.20 W 896.67 S 4411.46 W 912.16 S 4487.67 W 927.20 S 4561.69 W 941.78 S 948.14 S 955.88 S 969.48 S 982.56 S 258.51 6785.50 6725.00 4934.67 982.91 S 258,51 6785.50 67~5.00 4934.67 982.91 S 258.51 6835.50 6775.00 4976.62 991.27 S 258.51 6985.50 6925.00 5102.49 1016.34 S 258,51 7099.50 7039.00 5198.15 1035.39 S 25B.51 7105.50 7045.00 5203.18 1036.40 S 258.51 7215.50 7155.00 5295.48 1054.78 S 258.51 7215.50 7155.00 5295.48 1054.78 S 258.51 7265.50 7205.00 5337.44 1063.14 S 258.51 7285.50 7225.00 5354.22 1066.48 S ALASKA Zone 4 X Y =-- 582356.60 6005301.33 580078.23 6004811.31 580067.00 6004808.90 579990.98 6004792.55 579917.14 6004776.67 ==== TOOL DL/ FACE 100 __ HS 0.00 LS 0.00 LS 2.00 LS 2.00 LS 2. 00 258.51 7315.50 7255.00 5379.39 1071.50 S 258.51 7335.50 7275.00 5396.17 1074.84 S 258,51 7507.01 7446.51 5540.09 1103.50 S 258.51 75'07.01 7446.51 5540.09 1103.50 S 4633.42 W 579845.59 6004761.28 LS 2.00 4664.69 W 579814.39 6004754.57 LS 2.00 4702.78 W 579776.40 6004746.40 LS 2.00 4769.67 W 579709.66 6004732.04 LS 2.00 4834,03 W 579645.46 6004718,24 LS 2.00 4835.79 W 579643.71 6004717.86 HS 2.00 4835.79 W 579643.71 6004717.86 HS 2.00 4876.90 W 579602.70 6004709.04 HS O.00 5000.24 W 579479.66 6004682.58 HS 0.00 5093.98 W 579386.15 6004662.46 HS 0.00 5098.92 W 579381.23 6004661.41 HS 0.00 5189.37 W 579291.00 6004642.00 HS 0.00 5189.37 W 579291.00 6004642.00 HS 0.00 5230.48 W 579249.99 6004633.18 ~S 0.00 5246.93 W 579233.58 6004629.65 HS 0.00 5271.60 W 579208.97 6004624.36 HS 0.00 5288.04 W 579192.57 6004620.83 HS 0.00 5429.08 W 579051.88 6004590.57 0.00 5429.08 W 579051.88 6004590.57 0,00 0 I 0 I 0 .d 0 O (Anadrill (c)96 MPK21P4 3.0C 5:13 PM P) 'Dec-30-96 04:41P Anadrqll DPC 907 344 2160 P.02 SHARED SF_R~/ICES 1LID¥ ONLY DRILLING i MPK-21 (P4) VERTICAL SECTION VIEW s~C~io~ ~' ~5~.5~ TVO Sca)e.' ! inch : 1000 feet. c.-i , I ' AnadrJ]]-Sc ]umberger D ~ 'I , , Marker Identification I~O BK8 SECTN INCLN A} KB 0 0 0 0.00 ,I B] NUDGE-BUILD 1/t00 300 300 -0 0.00 Et - ! I C] END i/tO0 BUILD 700 700 14 4..00 ........ ~ ....... i i .......J D) DROP 1/t00 900 899 28 4,00 i ] E) END i/lO0 DROP 1300 1299 42 0.00 F - ~ ! F) BUILD 2/100 1700 1699 42 0.00 I 2.44 / · H) BUILD 2,5/~00 t902 190~ 48 2.44 I I1 9-5/8" CASING POINT 3807 3560 866' 50.07 i J) END 2.5/t00 BUILD 3898 3618 938 52.35 I ...... K) DROP 2/~00 8385 6359 4490 52.35 ,~--. I I - L) END 2/100 DROP 9003 6785 4935 40.00 'l i N] TARGET 9564 7215 5295 40.00 ' i N] 7' CASING POINT 9945 7507 5540 40.00 i O) TD 9945 7507 5540 40, O0 ~ RECEIVED ~ ' JAN 17 1997! ...... J .... i '" AlaSka il &'Gas t;ons: ........ ~ -- , - . 'e~ ....... ._ . :;. _, ...... ._.:: - Oep Scale' 1 inch : 1000 feet 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 SectiOn Departure [lnaOrJI] (cj96 NPK2~P4 3.0£ 5; Ig I°N PJ I 0ec-30-96 04:41P Anadr~ll DPC 9O7 ~44 2160 P .03 [' SHAt:lED SI-RVTCES DRILLING J ,oo , , MPK-'2 (P4) ~ ! IVERTICAL SECTION VIEW I i· 5900--- r/~r~" " :SeCt-,on ~ I TVD Sca)e ' ~ inch = 200 feet ~ '~ ' ! ~ . Oep Sca]e· ~ inch = 200 fee~ eoo0 ....... ~ Dra~n ' 30 Dec ~996 i . i ' ~nadrJ]] SCh]umberger ~ Marker Identification MD BKB $ECTN INCLN 6200 ] A) DROP 2/100 8385 6359 4490 52.35 · I 8) ENO 2/I00 DROP '9003 6785 4935 40.00 m i C) TARGET 9564 7215 5295 40.00 6300-- ,_ ....... ~ - , ~ ......... D) 7" CASING POINT 9945 7507 5540 40.00 E) TD 9945 7507 55~0 JO. O0 T A ' I V 6400 ' i , I . . ' D 6500-- '~ : ~ l I ---.--i ........... L ....... 5600 ~, o~· "] $700 ...... ~ ....................... ' 1 ~00 '~r -~ ...... , 8 X · -' ---.- [-~ m_ ~ __ _!' m -- m I i m m i i m ~ ' ~u~ ' ~ ....................... , 6~oo- - ~ ...... i ~ '. 7000~m- ~ ......... ' .... ~ , I : ........ ....... . .. 't~e~ - D~ 7400- ; 75oo .......... ~ ........................ 4200 ~30o d400 4500 4600 4700 4800 ~900 5000 5~00 5200 5300 5400 5500 5ecL~on DePantune m m m m mm m (AnaUri)) (c)~6 ~K21P4 3,0£ 5:29 PM PJ SHARED SERVTCES Narker Identif]caLlun NB N/$ E/W A) KB 0 0 N 0 E B) NUDGE-BUILD 1/100 300 0 N ,0 E C) END 1/100 BUILD 700 3 S 14 W D) DROP 1/100 900 6 S 27 W E) END l/lO0 DROP 1300 8 S 41 W F) BUILD 2/lOD ~700 B S 41 W G) END 2/100 BUILD 1822 9 S 44 W H) BUILD 2.5/100 1902 JO S 47 W I) g-5/B" CASING POINT 3807 173 S 849 W J) END 2.5/100 BUILD 3698 lB7 S 9t9 W K) DROP 2/100 6365 894 S 4400 W L) END 2/I00 DROP 9003 963 S 4636 W M) TARGET 9564 1055 S 5iBg W N) 7" CASING POINT 9945 il04 S 5429 W O) TD 9945 1104 S 5429 W DRZLLTNG ii i i AnadrJ ]] $£hYumberger iiimm i m MPK-2 (P4) PLAN VIEW CLOSURE ..... : 5540 feet at Azimuth 258.5~ DECLINATION.: +28.262 (E) SCALE ....... : 1 inch : 800 feet D~AWN ....... : 30 Dec ~g§6 FOR STUDY ONLY · i ' jl e ' , · ,i , . ; · 6800 6400 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 t600 1200 BO0 400 0 400 <-'WEST ' EAST -> (Anadr~ll [C]~ NPK2~P4 3.0C 5:29 P~4 PI 0 ~0 0 0 'Dec-30-96 04:42P Anad~ll DPC 907 344 2160 P.05 L-t.n ...... C;i~.,~= .............. : BP EXPLORATION Well Nnme ....... : MPK-21 (PO4) Fiekl ................: MILNE POINT C:o.nt¥ /State..: BEECHEY POINT, ALASKA APl// ................ : 50-029-96064-00 A~,,,Iri, ~D# ...... : 500299606400P0403 Alaska District Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS . INCLUDING ELLIPSES OF UNCERTAINTY Planned Well Survey Program Date Calculated ..... : 12/30/96 14=32 Start End Type Interval Date Plotted .......... : 12/30196 14:33 o 9945 MEWD 93 KBE ..................... : 60.50 Grid X ......... .' ........ : 584467.62 Grid Y .................. ; 6005755.35 Grid Zone ............ .: ASP ZONE 04 II Z O · 600-- Overlap ..... , ........ 1800- - 8400 ,o~oo-- ' i" T. . 8-- -50 -25 0 225 250 25 60 75 100 125 NORMAL PLANE SEPARATION 150 175 200 ('~" = 5o TD 9944.65 1111 East 80th Avenue * Anchorage. Alaska 99518 * Telephone: (907) 349-4511 * FAX: (907) 3¢4-2160 ~De¢-30-96 O4:42P Anad~411 _ _ _ Cli(:ltt .............. : BP EXPLORATION w,ii Name ....... : MPK-21 (PO4) F~.l~ ................ : MILNE POINT c..o~,~t¥ / State..: BEECHEY POINT, ALASKA ^ F'l# .......... ...... : 50-029-96064-00 A~;tdrill ID# ...... : 500299606400P0403 DPC 907 344 2160 Alaska C)istrict Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS INCLUDING ELLIPSEs OF UNCERTAINTY Planned Well Survey Program Da~e Calculated ..... : 12/30/96 14:32 Start End .Tvpe Interval Date Plotted ..... : ....: 12/30/96 14:34 0 9945 MEWD 93 KBE .............. ; ......: 60.50 Grid X ................ ;.: 584467.62 Grid Y ..................: 6005756.35 Grid Zone .... ; ........ : ASP ZONE 04 P .06 OFFSET WELL MPK-25 MIN. FLOWING i ELLIPSE ' SURVEY SAFETY '1' SEP. SEP. SEP.m! 16.1 25,5 28,8 28.8 32.0 52.4 l 124.9 120.6 ; 89.1 109.1 112.5 179.2 123.5 123.7 124.0 140.3 161.6 161.6 161.6 163.6 161.3 1630.6 1531.4 MPK-17 MPK-13 MPK-37 MPK-05 MPK-33(P04) MPK-22(P02) MPK-18(P05) MPK-02 MPK-30(D02) MPK-30 MPK-14(P01 ) MPK-34(D02) MPK-O6(P04) MPK-G(P05) MPK-06(P07) MPK-38 MPK-O6(P03) 19.8 411 · 98.3 99.2 80.1 102.7 106.2 169.2 117.9 118.0 118.4 135.3 156,0 166.0 156,0 158.0 156.1 CA$CAD 1AiDO~I ) 1524.6 (;ASCADE1 (D0t) 1525,6 S4.4 134.6 128.2 92.3 111.3 114.8 185,7 125.5 124.7 125.9 142,0 163.6 163.6 163.6 165.5 163.2 1532,8 1532.4 MD : TVD I 624 624 599 :599 753 753 1774 1773 1425: 1423 598: 598 422 I 422 421i 421 668! 668 376' 376 376 376 372 372 328 328 373 373 373 373 373 373 373 373 349 349 401 401 382 382 FLOWING i PLUGGED SAFETY I SAFETY DIST, DIST. 9,4 9.0 11.3 26.6 . 21,4 9.o 6.3 8.3 10.0 · 4.9 ~,2 6,0 1.6 1.5 ~.9 4.4 3.6 1.5 1,1 1,1 1.7 0.9 0.9 0.9 0.~ 0.9 ! 0.9 0.9 0.9 0.9 1.0 1.0 ENTER ;ENTER PLUE [ NO DRILL ZONi I ZONE MD · MD EXIT EXIT NO DRILL PLUG ZONE ZONE MD MD I CLOSE :APPROACH STATUS FLOW FLOW FLOW FLOW · FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW FLOW NOTES: All depths & (listen=e. are in FEET All depth, era referenced fram well MPK-21(P04) Min Rowing Safety Sap. in amount of additional clearance from flowing safety line. I 1 I 1 East BOth Avenue * Anchorage, Alaska 99518' - Telephone: (907) 349-4511 ' .FAX: (907) 344-2160 EXPLORATION Januaw 2, 1197 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RECEIVED fAN 17 1997 Naska 0ii & Gas Cons. Commission Anchorage Subject: Before Spud Changes to Approved Application for Permit to Drill #96-'176 Dear Mr. Johnston, In order to improve fracture efficiency and well productivity is it necessary to modify the well profile from the one submitted and approved in the Permit to Drill #96-176 on October 30, 1996. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.015, Changes to Drilling Permit, (a) For a proposed change in a drilling permit ...... before the start of actual drilling operations. It has been proposed by the BPX Milne Point Reservoir Group that a more optimal wellbore trajectory for fracture stimulation and well productivity will be achieved if the well profile is changed so that the tangent angle through the Kuparuk interval in ti~'e well K-21i be at approximately 40.0 degrees of inclination at the planned azimuth of 258.51 degrees. The revised well profile for K-21i, incorporating this modification to the well trajectory is included in this request for change in a effort to validate the model used to determine fracture efficiency and well productivity in deviated wells. AS a result of the proposed wellbore trajectory modification requested' .. the following changes are . . 1. The well profile be modified. 2. The location At Total Depth be changed to 2514 ' NSL, 2240' WEL, Sec. 04, T12N, R11E, UM. 3. The first stage tail cement excess volume be increased from 200% to 250%. 4. The second stage lead cement excess volume be increased from 200% to 250%. Also, be advised that rig Nabors 27E will drill the well instead of Nabors 22E. Thank-you for your consideration in this mater and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill #96-'176 please contact me in Anchorage at 564-5042. Respectfully, Lance J. Spencer Drilling Operations Engineer Shared Services Ddlling BPX TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 30, 1996 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well Name Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPK-21 i BP Exploration (Alaska), Inc. 96-176 3619~NSL, 2089'WEL, Sec 03, T12N, R11E, UM 2500~NSL, 2310'WEL, Sec 04, T12N, R11E, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the e North Slope pager at 659-3607. David W Johnston ~ -' ~,,~~ Chairmanx,x ~ .... ~ BY ORDE F THE C MMISSION dlffencl c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA'OiL AND GAS CONSERVATION COM-' ISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen I [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE - 57.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3619' NSL, 2089' WEL, SEC. 3, T12N, R11E (Not Final,As-staked) Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2563' NSL, 2000' WEL, SEC. 4, T12N, R11E MPK-21i At total depth 9. Approximate spud date Amount $200,000.00 2500' NSL, 2310' WEL, SEC. 4, T12N, R11E 10/29/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028232, 2780'I No Close Approach 2560 9999' MD / 7470' TVD 161 To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 2000' Maximum Hole Angle 50.74° i Maximum surface 3005 psig, Attotal depth (TVD) 7155' / 3720 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) lJ~-1/4" g-5/8" 40# L--80 Btrc 3785' 31' 31' 3816' 3500' 821 sx PF 'E', 724 sx'G', 150 sx PF'E' 8-1/2" 7" 26# L-80 Btm 9969' 30' 30' 9999' 7470' 326 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Liner Production RECEIVED OCT 2 5 1996 Perforation depth: measured Alaska 0il & 8as Cons. Commission true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing isltrue anld ~correct to the best of my knowledge Signed '"/'~'~ ~-~"_ ,~, Tim Schofield Title Senior Drilling Engineer Date I / Commission Use Only Permit Number I APl Number I Approval Date I S~e cov~r,~ttor ,,~'~/.~'~" 50- O Z.~ - ~ 2. '~//¢ / 0 -'~'"~ t.,, for other requirements Conditions of Approval: Samples Required [] Yes '~ No Mud Log Required [] Yes .,~ No Hydrogen Sulfide Measures ~l~Y~s [] No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; I~ 5M; [] 1OM; [] 15M Other: d!-'lglnal $igp,8o. i¢y by order of Date/0 Approved By r~,,,,;~ ttti Ir~knofnn Commissioner the commission Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: James E. Robertson I We~ Name: IMP K-2~i I Well Plan Summary 564-5159 IType of Well (producer or injector)' IKuparuk Injector Surface Location: 3619 NSL 2089 WEL Sec 03 T12N R11E UM., AK Target Location: 2563 NSL 2000 WEL Sec 04 T12N RllE UM., AK Bottom Hole 2500 NSL 2310 WEL Sec 04 T12N R11E UM., AK Location: IAFE Number: 1337053 J I Rig: I Nabors 22-E IEstimated Start 29 OCT 96I Date' IOperating days to I 1 0 complete' JWell Design (conventional, slimhole, I Milne Point Ultra Slimh,,ole Longstring 9- etc.)' I 5/8", 40# Surface X 7, 26# Longstrin~l Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,85 8 1,85 7 Top Schrader Bluff 5,0 4 9 4,3 3 7 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 5,3'9 6 4,55 7 Base of Schrader Bluff Sands (8.3 ppg) HRZ 8,61 2 6,5 92 High Resistivity Zone Top Kuparuk 9,2 2 8 6,98 2 Kuparuk Cap Rock Target (Kuparuk 9,591 7,212 Kuparuk 'C' Sand (10.0 ppg) 'C1' Sand) Base of Kuparuk 9,749 7,312 Kuparuk B6 (10.0 ppg) Total Depth 9,999 7,470 250' beloW' base of Kuparuk (8.6 ppg) uaslng/~u~ng ~,ro,(ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 3785 31/31 3816/3500 8- 1/2" 7" 2 6 # L-80 btrc 9969 30/30 9999/7470 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at +_7155 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3720 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. Logging Program' Open Hole Logs: Surface MWD Directional surface to TD. Intermediate N/A Final Cased Hole Logs: MWD Directional and LWD (GR/CDR/CDN). N/A Mudloggers are NOT required for this well. RECEIVED Mud Program: ISpecial design IN°ne'SPUD MUD I considerations Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 1 00 1 5 8 1 0 9 8 to to to to to to to 11.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 9.0 40 1 0 3 7 8.5 6 - 8 to to to to to to to 11.0 50 15 10 20 9.5 4-5 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP.' 12000' I Close Approach Well' (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. 1. The base of the Permafrost for all wells located in the Milne Point Unit is +1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 2. There are +7 wells on Milne Pt. 'K' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 3. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 4. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. MP K-21 i Proposed Summary of Operations , , , , , . , o , 10. 11. 12. 13. 14. 15. 16. Drill and Set 20" Conductor. Weld a starting head on conductor as well as a nipple to aid in performing potential wellhead stability cement job. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to 12-1/4" TD. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LOT. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3000 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E. Perforate and Stimulate in absence of rig. Displace well with appropriate weight brine and set a wireline retrievable bridge plug. MIRU a completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and put the well on production. DRILLING HAZARDS AND RISKS: Seethe updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates: We will have hydrates on K Pad. Mud weight should be at 10.2 PPG in conjunction with the addition of "LECITHIN" to the mud system by 2000 feet. Use the coldest mix water available to minimize warming of the interval and thereby breakout of the hydrtes. Use 7-3/4" mud motors to allow lower flow rates and therefore a cooler mud system. Control flow rates to below 600 GPM when hydrates are present to again keep mud temperatures to a minimum. Minimize circulation times. The addition of lecithin to the mud system in surface is expected to minimize destabilization of the hydrates. Close Approach: There are no close approaches associated with the drilling of MP K-21i. Shallow Set Casing: MP K-21i will incorporate a shallow set casing design with casing being set above the Schrader Bluff at 3,816' md.. With shallow set casing there are increased risk for stuck pipe and lost circulation, especially while running casing. The casing program will include running centralizers over both the Kuparuk and Schrader Bluff, and cemented in a single stage. The rig team will need to be more careful on these wells to fully realize the cost benefits. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Be prepared to treat these losses while drilling initially with LCM treatments. This will become even more prevalent in the production hole when we shallow set surface casing. Weighting up before entering the reservoir will be the most likely time we would lose circulation Stuck Pipe Potential: There have been no cases of stuck pipe at 'K' pad to date IN SURFACE HOLE. However, well M P F- 53 was stuck coming out on the short trip at surface casing point. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. In the 8-1/2" hole section here have been several cases of stuck pipe occuring at the top of the Kuparuk - with both the intervals above and below the Schrader Bluff open. The stuck pipe intervals and short trip guidelines on the Pad Data Sheet should be followed to avoid stuck pipe incidents. Running casing should be as smooth and quickly as possible to avoid stopping casing and possibly getting stuck. Formation Pressure: Schrader Bluff SAND Kuparuk SAND 4280' TVD SS 7155' TVD SS 1869 PSI 372O PSI 8.4 PPG EMW 10.0 PPG EMW The maximum expected pore pressure for this well is 10.0 ppg EMW (3720 psi @ 7155' TVD SS). Reservoir pressure is not expected to exceed this estimate. MP K-21i 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE' 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls fresh water (ADD DYE TO SPACER). LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder + (CELLO-FLAKES (1/4 WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx lb/sack) in first stage only) MIX WATER: 11.63 gal/sk STAGE1 LEAD: ANUULAR VOLUME FROM BASE OF PERMAFROST TO STAGE COLLAR AT 1300' MD + 200% EXCESS + 80'md 9-5/8", 40# capacity for float joints. 258 SACKS THICKENING TIME: > 4 hrs at 50° F. STAGE2 LEAD: FROM STAGE COLLAR AT 1300' MD TO SURFACE + 200% EXCESS 563 SACKS THICKENING TIME: > 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3,0.2% HALAD-344, 2.0% CaCI2 + CELLO-FLAKES WEIGHT: 15.8 ppg APPROX #SACKS: 7 2 4 FLUID LOSS: 100-150 CC YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TAIL CEMENT FROM TD TO BASE OF PERMAFROST + 30% EXCESS WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP K-21i Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK & SCHRADER BLUFF INTERVAl: CIRC. TEMP' 115° F SPACER: 50 bbls fresh water BHST 170© F at 7040' TVDSS. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX#SACKS: 0.2% CFR-3, 30 LB/SACK SILICATE, 1.25% Halad 344 YIELD: 2.81 cu ft/sk MIX WATER: 16.0 gal/sk 326 SACKS FLUID LOSS: THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 45cc/30 min @ 140© FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 17 joints of 7" casing (4 0). This will cover +300' above the KUPARUK C1 Sand. Two per joint from 1 20' below base of Schrader Bluff to 120' above top of Schrader Bluff (+14) Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, CEMENT VOLUME' , Stage 1 cement volume is calculated to cover 500 FT MD above the Schrader Bluff Sand with 30% excess. Anadrili Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 uiRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPK-21(P2) Field ........ : MILNE POINt, KPAD Computation.,: Minimum Curvature Units ........ : FEET Surface Lat..: 70.42565224 N. Surface Long,: 149.31168094 W Legal Description Surface ...... : 3619 FSL 2089 FEL S03 T12N RllE UM TARGET ....... : 2563 FSL 2000 FEL S04 T12N RllE UM 'BHL .......... : 2500 FSL 2310 FEL S04 T12N'Rl'lEUM STATION IDENTIFICATION KB ~z-~IL~ i/ioo Z~m 1/iOO BUILD LOCATIONS- ALASKAZone: 4 X-Coord Y-Coord 584467.67 6005755.18 579291.00 6004642.00 578982.20 6004575.60 MEASURED 'INCLN DIRECTION DEPT~ ANGLE AZIMUTH 0.00 0.00 .0.00 300.00 0.00 0.00 400.00 1.00 258,51 500.00 2.00 258.51 600.00 3.00 258.51 PROPOSED WELL PROFILE. Prepared ..... : 22 Oct 1996 Vert sect az.: 258.51 KB elevation.: 57.50 ft Magnetic Dcln: +0.000 (E) Scale Factor.: 0.99990810 Convergence..: +0.64854~ ANADRILL VERTICAL-DEpT~s TVD SUB-SEA SECTION DEPART COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 0~00 -57'.50 300.00 242.S0 0.00 -0.00 0.87 3.49 7.85 0.00 N 0.00 N 0.17 S '0.70 S 1.56 S AKALDPC APPROVED FOR PERMITTING ONLY PLAN TOOL DL/ FACE 100 0.00 E 584467.67 6005755.18 0.00 E 584467.67 6005755,18 0.86 W 584466.82 6005755.00 3.42 W 584464.26 6005754.45 7.69 W '584459.99 6005753.53 HS 0.00 101L 0.00 101L 1.00 101L 1.00' 101L 1,00 DROP 1/100 800.00 3.00 258.51 900.00 2.00 258.51 1000.00 1.00 258.51' END 1/100 DROP 1100.00 0.00 i0.00 BASE PERMAFROST 1858.05 0.00 0.00 799.59 742,09 899.49 841.99 999.46 941.96 1099,45 1041.95 1857.50 1800.00 18.32 22.68 25.30 26.17 26.17 3.65 S 4.52 S 5.04 S 5.21 S 5,21 S 17.95 W 584449.76 6005751.33 22.23 W 584445.50 6005750.41 24.79 W 584442.94 6005749.86 25.65 W 584442.09 6005749.68 25.65 W ..5~4442.09 6005749.68 101L 0.00 101L 1.00 HS 1.00 HS 1.00 HS 0.00 BUILD 3/100 2000.00 0.00 2100.00 3.00 0.00 1999.45 1941.95 258.51 2099.41 2041.91 26.17 28.79 5.21 S 5.73 S 25.65 W 584442.09 6005749.68 101L 0.00 28 . 21 W 584439 . 53 6005749 . 13 101L 3 . 00 -0 0 I 0 ee (Anadrill (c)96 MPK21P2 3.0b.07 2:56 PM P} MPK-21(F2: STATION .'...: .,I i......-~, MEASURED DEPTH .. 2200.00 2300.00 2400.00 2500.00 2600.00 INCLN ANGLE .. 6.00 9.00 12.00 15.00 18.00 2700.00 21.00 2800.00 24.00 2900.00 27.00 3000.00 30.00 3100.00 33.00 END 3/100 BUILD 9-5/8" CASIN¢ NA OA OB 3200.00 36.00 3300.00 39.00 3400.00 42~00 3500.00 45.00 3600.00 48.00 3691.17 50.74 3816.59 50.74 5049.00 50.74 5238.60 50.74 5349.20 50.74 BASE OB 5396.60 50,74 THRZ 8611.93 50.74 BHRZ 8912.13 50.74 TKLB 8991,13 50,74 TKUP/UD 9228.13 50.74 PROPOSED WELL PROFILE OWC 9408 25 50,74 i'KUC 9417.73 50.74 TARGET 9591.53 50.74 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 258.51 2199.09 2141.59 258.51 2298.22 2240.72 258.51 2396.53 2339.03 258.51 2493.76 2436.26 258.51 2589.63 2532.13 258.51 258.51 258.51 258.51 258.51 2683.88 2626.38 2776.26 2718.76 2866.51 2809.01 2954.38 2896.88 3039.64 2982.14 258.51 258.51 258.51 258.51 258.51 3122.04 3064.54 3201.37 3143.87 3277.40 3219~90 3349.93 3292.43 3418.75 3361.25 258.51 258.51 258.51 258.51 258.51 258.51 258.51 258.51 258.51 258.51 3478.12 3420.62 3557.50 3500.00 4337.50 4280.00 4457.50 4400.00 4527.50 4470.00 4557.50 4500,00 6592,50 6535.00 6782.50 6725.00 6832.50 6775.00 6982.50 6925.00 258.51 258.51 258.51 7096.50 7039.00 7102.50 7045.00 7212.50 7155.00 22 Oct 1996 Page 2 SECTION DEPART COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 ~=ii .... 7.30 S 35.90 W 584431.86 6005747.48 HS 3.00 9-89 S 48.69 W 584419,10 6005744.74 H$ 3.00 13.52 S 66.55 W 584401,29 6005740.91 HS 3.00 18.17 S 89.42 W 584378.47 6005736.00 HS 3.00 23.83 S 117.25 W 584350.7'1 6005730.03 HS 3.00 36.63 49.69 67.91 91.25 119 ..65 153.02 191.29 234.33 282.04 334.29 390.92 451.79 516.73 585.56 658.09 '30.48 S 149.96 W 584318.08 6005723.01 HS 3~00 38.10 S 187.46 W 584280.67 6005714.97 HS 3.00 46.67 S 229.64 W 584238.59 6005705.92 HS 3.00 56~17 S 276.39 W 584191.95 6005695.89 HS 3.00 66.57 S 327.59 W 584140.88 6005684.91 HS 3.00 77.85 S 89.98'S 102.91 S 116.62 S 131.06 S 383.09 W 584085 442.74'W 584026 .506.38 W 583962 573.83 W 583895 644.90 W 583824 .52 6005673.00 HS 3.00 .02 6005660.21 HS 3.00 ~'54 6005646.56 HS 3.00 ~2S 6005632.09 ~S 3.00 .35 6005616.84 HS 3.00 727.27 824.37 1778.54 1925.33 2010.96 144.84 S 712.70 W 583756 164.18 S 807.86 W 583661 354.20 S 1742.91W 582729 38'3'.445 1886.77 W 582585 400.49 S 1970.68 w 582501 .72 6005602.30 HS 3.00 .79 6005581.89 HS 0.00 .04 6005381.31 HS 0.00 .54 6005350.45 'MS 0.00 .83 6005332.45 ~S 0.00 2047.66 4537.06 4769.48 4830.64 5014.14 407.80 S 2006.65 W 582465.95 6005324.74 HS 0.00 903.57 S 4446.17 W 580032.42 6004801.43 MS 0.00 949.85 S 4673.94 W 579805,21 6004752.57 HS 0.00 962,04 S 4733,88 W 579745.42 6004739.72 MS 0.00 998.58 S 4913.70 W 579566,04 6004701.I4 HS 0.00 5153.59 5160.93 5295.49 1026.35 S 5050.36 W 579429.72 6004671.83 HS 0.00 1027.81 S 5057.55 W 579422.54 6004670.29 HS 0.00 1054.61 S 5189.42 W 579291.00 6004642.00 H$ 0.00 .0 I I 0 0 '4 (Ar. adrill (c)96 MPK21P2 3.0b,07 2:56 PM P) ~PK-21{?2i STATION MEASURED INCLN IDENTIFICATION DEPTH A/WGLE =========~a= mmmmmamm m~aa:= TKC! 9591.53 50.74 TKUB/B8 9670.53 50.74 TK]37 9702.14 50.74 TKB6 9749.54 50.74 TKB5 9781.14 50.74 7" CASING POINT TD 9999.54 50.74 9999.54 50.74 PROPOSED WELL PROFILE ............. mmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 258.51 7212.50 7155'.00 258.51 7262.50 7205.00 258.5L 7282.50 7225.00 258.51 7312.50 7255.00 258.51 7332.50 7275.00 SECTION DEPART mimimmi~ 5295.49 5356.66 5381.12 5417.82 5442.29 258.51 7470.73 7413.23 5611.38 258.51 7470.73 7413.23 5611.38 22 Oct 1935 Page 3 COORDINATES-FROM ALASKA Zone 4 TOOL WELLHEAD X Y FACE 1'054.61 S 5189.42 W 579291.00'6004642.00 ~S 1066.79 S 5249.36 W 579231.21 6004629.14 HS 1071.67 S 5273.33' W 579207.'29 6004624.00 HS 1078.97 S 5309.30 W 579171.42 6004616.29 HS 1083.85 S 5333.27 W 579147.50' 6004611.14 HS 1117.52,S 5498.98 W 578982.20 6004575.60 1117.52 S 5498.98 W 578982.20 6004575.60 DL/ 100 O.O0 0.00 0.00 0.00 0.00 0o00 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ' ON'L¥ PLAN 'z -0 ri. I I Cb 0 ..6 ~0 0 ,q (Anadrill (c)96 MPK21P2 3.0b.07 2:56 PM P) Oct-22-g6 03:15P Anadrill DPC 907 344 2160 P.02 i,iN i _ ; SHARED SERVI S DRILL 6 AN,,~,D,RiLLAKA-DPt" · NPK-2 ~,~ ROVED VERTICAL SECTION VIEW '[ FOB-.PERMITTING Section at: 258.5J , TVD Sca]e.' 1 inch = J000 feet :~ O~L~ Dep Scale.' J tnch= J000 feet~ <KB>O- A ~~. __ ~~'~ Orawn ' 220ct 1996 500 ............ ' ' c ~- . ~nadrl ]] Schlumberger I ....... O '- . Marker Identification MD BKB SECTN INCLN ~000 ~ A) KB 0 0 0 0.00 E'- B) NUDGE-BUILD ~/100 300 300 -0 0.00 C) END ~/~00 BUILD 600 600 8 3,00 1500 ............................... D) DROP t/100 800 800 18 3.00 : E) END ~/~00 DROP ~00 1099 26 0.00 F) BUILD 3/100 2000 J999 26 0.00 ~ .......... = ................ 3~~'~ ~) END 3/~00 BUILD 369J 3478 727 50.7~ 2000 ~) TARGET 9592 72J3 5295 50.7a d] 7' CAKNG POINT ' ~0000 747J 56~J 50.74 2500--- .... ..... -.. K) T0 ~0000 747J 5Bi J 50.74 3ooo 3500 .......................... ~ ................... qO00 ....... 5000 · . ' ' : 5500 ......................... ~ .... ~ ...... ; ....... 6000 I ssoo ............. 2~2-:. ...... 2 2'2 _. 7 ............ ~r - g~................ ~ - .. : ..... . ~ooo -,~- ~ ~- . .. ..... '~g~ ....... : :r22_" .... 7500 .............. ' ....... . . ~000' m I . I i o 500 looo ~500 ~000 ~500' 3000 3500 4000' ~500 ¢00 5500 sooo ssoo Sect ion I ii i I I i i I i Ill I I II feet :. ; · ., Oct-22-g6 03:16P Anadrill DPC 907 344 2160 P.03 i i [ . SHA-RbD SbRVICES BRTLLTNG ~ ~'c.s~.o.o~.~ ~oooo ~, s6~ so.~ VERTICAL SECTION VIEW c~ ~ ~oooo 7~ ~,~ so.~ .... , , , ..- ' ANADRILL AKA-DPC : Sect ion at: 258 51 , TVD Scale.' 1 inch = 200 feet t APPROVED. _ Dep Scale.' ~ inch : 200 feet 6200 ' ~l , ) Drawn 22 Oct 1996 t FO~ PERMI ~l !~ · 6~oo-- . ~-~ _~ Anadril] SchYumberger ~oo - ' I "I - ~' ' ". · ~ . ~ X . ~ .............. - ........................ fi~O0 6600 ' ~700- : ............. ¢ ....... . s¢o '~"-"~ - ' ' .... '-- ' .... ~ - ~ ...... ~..... ~ ' ' ................................ 6g007000 ...... . =. . ~ J '~ " I . 7~00 .... ~ " ,. 7500-' -[ .............. : ....... : ............... ~ ~, , oo ' j I o¢:2 ~' ~ ......... 7700~ ...... [ ......................... I ,. 7800 ' 4400' 4500 4600. 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 SeC~t ion Dep~,rture t mm m m mm m m /.4,na~r,i]/ (cig6 I, iPK2~P2 3.0b.07 2:57 PN PI _ , SHARED.____SLRVICES DRILLING ,v-- .=.~ - lUU~U.r ..... ; 30]] feet at Az]mur. n dbU.b £'~ ~ z-= IDECLINATION.: +0.000 (E) ' o ................. , i ~ ~ ~ ~' SCALE .......: ~ inch = BO0 feet "' .... I ~ ' ~ ~ ~ ~ ,,. - DRANN ....... : 22 Oct ~996 · I ~ c~ ~ ~ ~ - ~ ~ , , ~ ..... :- ~P ~"~ A) KB 0 0 N 0 E ~ ' ~ B~ NUQGE-DU~LO ~/100 300 ON 0 E , I ~ ~ C) END I/tO0 BUILD 600 2 S 8 W 0-- ' '"' '~ D) DRDP 1/~00 BOO 4 S 18 W m ~ ~ E) END J/lO0 DROP ~00 5 S 26 W ' F) BUILD 3/100 20DO 5 S 26 W ' G) END 3/~00 BUILD 369J ~45 S 7~3 W ~ ' : K) ID ID000 1118 S 5499 W ~ .... ,. ' .......... ' I "~'I: ......... ~" ..... ~ .... ~~' ......... ~ ~ · '~ -' 'i " ~ .... ' ~' ' ' ' ' ' ,-~ ..... I .... i I F9R p~MiiTT!~!G , i I ' )N'LY ~m ' ~ ' ... _. . . ~ ..... _ ....... ~ ' ~ i $800 ~00 riO00 5~00 ~00 ~gO0 ~00 4000 ~[00 ~200 2~00 240C 2000 ~fiO0 1200 ~00 ~00 0 aO0 <- ~[SI' [~SI -> (Ana~ril] (c)~ N~21P2 3.~,07 2:28 PN P) WELL PERMIT CHECKLISToo , : WELL NAME FIELD & POOL ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... y Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. . Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... N N N N N N N N N N N N .) ENGINEERING GEOL AREA PROGRAM: exp[] der [] redrl~] serywellbore segD ann disp para req[] ~3, UN:~# /Jj~_ ON/OFF SHORE ~d~_ REMARKS ' " / ............. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ }Y I N CMT vol adequate to circulate on conductor & surf csg. .IY 1 CMT vol adequate to tie-in long string to surf sag . . .~1~ CMT will cover all known productive horizons ...... ~Y ! N Casing designs adequate for C, T, B & permafrost .... tY :t N Adequate tankage or reserve pit ............. If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... FY~ N If diverter required, is it adequate .......... ~Y N Drilling fluid program schematic & equip list adequate .{Y i N BOPEs adequate ..................... ~Y I N BOPE press rating adequate; test to 5~l,~ psig.lY ~' N Choke manifold complies w/API RP-53 (May 84) ...... ~% N Work will occur without operation shutdown ....... t.5 N Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y~/ 31. Data presented on potential overpressure zones ..... Y/ N 32. Seismic analysis of shallow gas zones ......... ./ N 33. Seabed condition survey (if off-shore) ....... ./ Y N 34. Contact name/phone for weekly progress reports . . ./.. Y N [exploratory only] GEOLOp.Y,:, ENGINEERING: COMMISS ION: JDH ~/ mcmax_3 Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 IFIELd'I & POOL · WELL PERMITCHECKLISTCOMPANY ,/~P WELLN~E~/~/' .......... " ADMINISTRATION .......... 1. Permit fee attached ....................... ~ N 2. Lease number appropriate ................... IY')N 3. Unique well name and number ................. I Y/N 4. Well located in a defined pool .................. I Y ] N 5. Well located proper distance from dflg unit boundary ..... I.YI N 6. Well located proper distance from other we/is ......... ~'YI N 7. Sufficient acreage ~vaJlable in drilling unit. .......... t Y I N 8. If deviated, is wellbore plat included .............. ~YI N 9. Operator only affected party ................... I Y I N 10. Operator has appropriate bond in force ............ I Y I N 11. Permit can be issued without conservstion order ...... t Y /N AP~R DA, TE / 12. Permit can be issued without administrate approvaJ .... I- Y IN -GEOLOGY AP~'~F[ DA];E 14. Conductor string provided .................. 15. Surface casing protects all known USDWs ......... ~1 16. CMT vol adequate to circulate on conductor & surf csg . . .(,~--/N 17. CMT vol adequate to fie-in long sbing to surf csg ...... (~..,N 18. CMT will cover all known productive horizons ........ 19. Casing designs adequate for C, T, B & permafrost. ..... ~.N 20. Adequate tankage or reserve pit. .............. 21. If a re~dll, has a 10-403 for abndnmnt been approved....--.y---N--,m~ 22. Adequate wellbore separa~on proposed ............ ' N 23. If diverter required, is it adequate ................ t N 24. Drilling fluid program schemsUc & equip list adequate .... 25. BOPEs adequate ....................... 26. BOPE press rating adequate; test to .~ psigl N 27. Choke manifold complies w/APl RP-53 (May 84) ....... N 28. Work will occur without operaUon shutdown. . N 29. Is presence of H2S gas probable ...... '. '. '. '. '. '. '. '. '. ,,, 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~" 31. Data presented on poten~al overpressure zones ....... Y,,~ 32. Seismic analysis of shallow gas zones ............. /Y' N - 33. ~ condition survey (if off-shore) ........... /Yv ~N 34. Contact name/phone for weekJ~ progress repo~ .. ...... Y N lexpioratory ontyj UNIT# /,//~'0 , ON/OFF SHORE,~:~_~__. REMARKS GEOLOGY: ENGINEERING: COMMISSION: BEW ~0/~ DWJ JDH ~ JDN. '' Comments/Instructions: HOW4~ - A.",FORMS"che~st rev 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Mar 01 10:17:46 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ...... ~ ...... LISTPE Date ..................... 99/03/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPER3ITOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RJkNGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-70042 G. TOBIAS P. WILSON M C OFILMED MPK-21 ~g~)~ 500292271800 BP EXPLOP~ATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 01-M_AR-99 4 12N lie 2514 2240 .00 61.30 27.50 i.; r .'[ ', & Gas Cons. WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 12.250 9.625 3832.0 8.500 9845.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDP~AULICS IS CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR/SGRC) UTILIZING GEIGER MUELLER TYPE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PH3~SE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD) . 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9845'MD, 7432'TVD. SROP = SMOOTHED P~ATE 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 (RESISTIVITY SENSOR). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3783.0 9783.0 FCNT 3792.5 9737.0 NCNT NPHI FET RPD RPM RPS RPX DRHO RHOB PEF ROP $ 3792 5 3792 5 3792 5 3792 5 3792 5 3792 5 3792 5 3828 0 3828 0 3828 5 3842 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3783.0 3794 0 3796 3903 3989 3996 4044 4049 4054 4065 4102 4215 4246 4250 4262 4266 4276 4288 4291 4295 4299 4306 4333 4336 4344 4367 4384 4396 4459 4463 4466 4470 4473 4475 4478 4491 4612 4622 4693 4735 0 5 5 0 0 0 5 0 0 5 0 5 0 5 5 0 5 0 0 0 0 0 0 5 0 5 5 5 0 0 0 5 0 0 0 0 0 0 GR 3791 0 3802 0 38O4 0 3911 5 3998 0 4003 0 4052 5 4057 0 4063 0 4074 0 4113 0 4216 5 4257 0 4260 5 4273 0 4276 5 4287 0 4299 5 4302 0 4307 5 4309 0 4318 0 4344 0 4347 0 4355 0 4376 0 4393 5 4405 0 4471 0 4474 5 4477 0 4479 0 4482 0 4486 0 4489 5 4501 0 4622 5 4634 0 4704 5 4739 0 9737 0 9737 0 9763 0 9763 0 9763 0 9763 0 9763 0 9772 0 9772 0 9772 5 9842 5 EQUIVALENT UNSHIFTED DEPTH 4749 4867 4875 4948 5027 5036 5131 5136 5207 5248 5347 5352 5366 5554 5796 5799 6054 6283 7045 7049 7139 7143 7154 7157 7160 7582 7583 7585 7756 7773 7776 7858 7880 7890 7916 7942 7946 7955 7973 7997 7999 8090 8164 8173 8178 8182 8191 8271 8274 8282 8283 8293 8304 8308 8312 8316 8320 4759 4875 4883 4958 5032 5042 5136 5142 5214 5254 5353 5358 5371 5558 5799 5803 6059 6288 7049 7052 7144 7147 7158 7160 7165 7584 7585 7587 7757 7776 7779 7859 7881 7890 7916 7948 7951 7959 7972 8001 8003 8089 8176 8181 8184 8186 8197 8270 8274 8283 8286 8293 8307 8310 8313 8317 8321 0 0 0 5 5 0 5 0 0 5 5 5 5 5 5 0 0 0 5 0 0 0 5 0 0 0 5 5 5 5 0 5 5 5 0 5 5 0 5 5 0 5 5 5 5 5 5 5 5 5 5 0 0 0 0 5 5 8345 5 8487 5 8490 5 8493 5 8507 0 8508 0 8509.5 8511 0 8518 0 8544 5 8547 5 8549 5 8556 0 8561 0 8570 5 8573 5 8586 5 8597 0 8598 5 8608 0 8615 0 8618 0 8619 0 8620 5 8622 5 8625 5 8627 0 8634 0 8639 0 8641 5 8644 5 8646 5 8648 0 8651 0 8653 0 8654 5 8660 0 8661 5 8662 5 8666 0 8675 5 8677 0 8682 5 8684 5 8688 0 8699 5 8702 5 8705 0 8706 5 8709 0 8712 5 8714 0 8716 0 8720 5 8722 0 8723 5 8725 0 8347 0 8489 5 8492 5 8495 0 8508 0 8510 0 8511 5 8514 0 8519 0 8545 0 8549 0 8551 0 8559 0 8563 5 8572 0 8575 0 8587 5 8598 0 8599 5 8609 0 8616 5 8619 0 8620 0 8622 0 8623 5 8626 0 8628 0 8635 5 8639 5 8642 0 8645 0 8647 0 8650 0 8652 5 8655 5 8656 5 8660 5 8662 5 8663 5 8666 5 8676 5 8677 5 8682 5 8684.5 8689 0 8700 5 8702 5 8704 0 8706 0 8708 0 8716 5 8718 0 8719 0 8721 0 8722 0 8723 5 8725 0 8727 8731 8733 8736 8745 8748 8750 8752 8754 8759 8760 8761 8763 8765 8772 8775 8787 8790 8829 8831 8833 8835 8839 8841 8854 8899 8972 8975 9012 9014 9022 9074 9083 9142 9144 9154 9187 9189 9191 9194 9241 9255 9275 9327 9337 9417 9431 9440 9452 9454 9474 9490 9501 9511 9514 9537 9539 8727 0 8731 5 8733 5 8736 5 8745 5 8748 5 8750 5 8752 5 8754 0 8759 0 8759 5 8761 5 8764 0 8766 5 8773 0 8776 5 8789 0 8791 0 8830 5 8832 0 8834 0 8835 5 8839 5 8841 0 8855 5 8900 5 8972 5 8976 0 9012 0 9014 0 9022 0 9074 5 9082 5 9141 0 9142 0 9152.5 9186 0 9188 0 9190 0 9192 5 9239 5 9253 5 9273 0 9325 0 9335 5 9416 0 9429 5 9439 5 9451 0 9453 0 9474 5 9490 5 9500 5 9512 5 9514 5 9537 0 9539 0 9548 5 955O 9560 9636 9638 9667 9669 9842 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 9548 0 9549 5 9561 0 9636 5 9639 0 9670 5 9671 5 9845 0 BIT RUN NO MERGE TOP MERGE BASE 2 3850.0 9845.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 3783 9842.5 ROP 1.7159 980.74 GR 13.9972 468.994 RPX 0.0593 32.4653 RPS 0.0639 2000 RPM 0.0668 2000 RPD 0.05 2000 Mean Nsam 6812.75 12120 191.229 12002 95.3614 12001 3.84092 11942 4.61203 11942 6.07596 11942 15.3065 11942 First Reading 3783 3842 3783 3792.5 3792.5 3792.5 3792 . 5 Last Reading 9842.5 9842.5 9783 9763 9763 9763 9763 FET 0.1611 68.443 1.56658 11942 NPHI 14.7455 72.0615 38.6007 11862 NCNT 2008 3752 2609.6 11890 FCNT 404 1265.19 623.754 11862 RHOB 1.2431 2.8089 2.30094 11889 DRHO -0.101 0.6109 0.0623902 11889 PEF 1.4173 12.4138 2.58514 11889 3792.5 3792 . 5 3792.5 3792.5 3828 3828 3828.5 9763 9737 9737 9737 9772 9772 9772.5 First Reading For Entire File .......... 3783 Last Reading For Entire File ........... 9842.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/01 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 ....... 99/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FCNT NCNT NPHI FET RPD RPM RPS RPX DRHO RHOB PEF 2 .5000 START DEPTH 3791 0 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3836 0 3836 0 3836 5 STOP DEPTH 9785.5 9739 5 9739 5 9739 5 9765 5 9765 5 9765 5 9765 5 9765 5 9774 5 9774 5 9775 0 ROP 3850.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA R_AY EWR4 CNP SLD $ 9845.0 ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 23-FEB-97 4.96 CIM 5.46 MEMORY 9845.0 3850.0 9845.0 38.5 54.6 TOOL NUMBER P0660CRDGP6 P0660CRDGP6 P0660CRDGP6 P0660CRDGP6 8.500 8.5 PAC/GEL 10.20 41.0 9.2 700 4.8 3.000 1.500 2.600 3.200 72.2 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 AAPI 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 NCNT MWD 2 CNTS 4 1 68 36 10 FCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BA/~N 4 1 68 52 14 Name Min Max Mean Nsam DEPT 3791 9845 6818 12109 ROP 1.7159 980.74 191.051 11991 GR 13.9972 468.994 95.4335 11990 RPX 0.0593 32.4653 3.83842 11931 RPS 0.0639 2000 4.60959 11931 RPM 0.0668 2000 6.07479 11931 RPD 0.05 2000 15.3139 11931 FET 0.1611 68.443 1.56528 11931 NPHI 14.7455 72.0615 38.5821 11851 NCNT 2008 3760 2609.89 11879 FCNT 404 1265.19 623.846 11852 RHOB 1.2431 2.8089 2.30159 11878 DRHO -0.101 0.6109 0.0623567 11878 PEF 1.4173 12.4138 2.58651 11878 First Reading 3791 3850 3791 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3800 5 3836 3836 3836.5 Last Reading 9845 9845 9785 5 9765 5 9765 5 9765 5 9765 5 9765 5 9739 5 9739 5 9739 5 9774 5 9774 5 9775 First Reading For Entire File .......... 3791 Last Reading For Entire File ........... 9845 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 99/03/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File ALASKA COMPUTING CENTER ....... SCHLUMBERGER Ai~..'~ Oil & Gas Co,'~, COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPK-21 FIELD NAIVE : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22718-00 REFERENCE NO : 97184 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: **** REEL HEADER **** SERVICE NA~iE : EDIT DATE : 97/04/28 ORIGIN : FLIC REEL NAME : 97184 CONTINUATION # : PREVIOUS REEL : COf~4El~f : B.P. EXPLORATION, MILNE POINT, MPK-21, API #50-029-22718-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/04/28 ORIGIN : FLIC TAPE NAME : 97184 CONTINUATION # : 1 PREVIOUS TAPE : COf4~F2~f : B.P. EXPLORATION, MILNE POINT, MPK-21, API #50-029-22718-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPK- 21 API NUMBER: 500292271800 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-APR-97 JOB NUMBER: 97184 LOGGING ENGINEER: DANIEL PAI~fE OPERATOR WITNESS: MARK O'MALLE SURFACE LOCATION SECTION: 3 TOWNSHIP: 12 RANGE: 11 FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 61.29 DERRICK FLOOR: 61.29 GROUND LEVEL: 27.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS ~Tape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUPIBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTEDDEPTH BASELINE DEPTH $ REMARKS: No depth adjustments were made to this data because it is the PDC log for this well. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTIM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9714.0 3694.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH REMARKS: Data is GR and CCL from the PDC log (CBT) for this well $ LIS ~ape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553834 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 553834 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 553834 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9714.000 GRCH. GR 99.465 CCL.GR -0.025 DEPT. 9000.000 GRCH. GR 86.632 CCL.GR 0.028 DEPT. 8000.000 GRCH. GR 114.258 CCL.GR -0.066 DEPT. 7000.000 GRCH. GR 70.959 CCL.GR -0.033 DEPT. 6000.000 GRCH. GR 55.351 CCL.GR -0.203 LIS ?rape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: DEPT. 5000.000 GRCH. GR DEPT. 4000.000 GRCH. GR DEPT. 3694.000 GRCH. GR 14.615 CCL.GR 35.801 CCL.GR 41.110 CCL.GR 0.166 -0. 040 -0. 058 ** END OF DATA ** **** FILE TRAILER **** FILE NAME .. EDIT .001 SERVICE . FLIC VERSION . O01CO1 DATE : 97/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION ' 0 O1 CO1 DATE · 97/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE StC4MARY VENDOR TOOL CODE START DEPTH GRCH 9739.0 $ LOG HEADER DATA DATE LOGGED: SOF~WARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 3693.0 16-MAR-97 8C0-609 1100 16-MAR-97 9740.0 9726.0 3694.0 9714.0 2400.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~g~A RAY $ TOOL ~ER SGT-L 1379 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 8.500 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE / DIESEL 10.20 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAI~): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUN~ RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH CONTROL PROCEEDURES APPLIED CBTE RAN CENTRALIZED. BOND LOG SHOWS GOOD CEMENT TO 5600 DATN READING LOW IN SOME WELL CEMENTED ZONE DUE TO VERY LO CEMENT BOND LOG RAN TO 3600. $ LIS FORMAT DATA LIS ~fape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553834 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 553834 O0 000 O0 0 2 1 1 4 68 0000000000 CCL LOG V 553834 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. DEPT. DEPT. DEPT. DEPT. DEPT. 9738 500 9000 000 8000 000 7000 000 6000 000 5000 000 OR.LOG 99.465 CCL.LOG -0.026 GR.LOG 86.632 CCL.LOG 0.028 GR.LOG 114.258 CCL.LOG -0.066 GR.LOG 70.959 CCL.LOG -0.033 OR.LOG 55.351 CCL.LOG -0.203 GR.LOG 14.615 CCL.LOG 0.166 DEPT. 3693.000 OR.LOG 40.605 CCL.LOG -999.250 DEPT. 4000.000 GR.LOG 35.801 CCL.LOG -0.040 LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 28-APR-1997 15:08 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 97/04/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/04/28 ORIGIN : FLIC TAPE NAi~E . 97184 CONTINUATION # : 1 PREVIOUS TAPE : COfZk~-~Ff : B.P. EXPLORATION, MILNE POINT, MPK-21, API #50-029-22718-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/04/28 ORIGIN : FLIC REEL NAME : 97184 CONTINUATION # : PREVIOUS REEL : CO~4~IENT : B.P. EXPLORATION, MILNE POINT, MPK-21, API #50-029-22718-00
