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HomeMy WebLinkAbout201-023 Imag~ roject Well History File Cover [{ ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~)J- ~c~__ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY ROBIN VINCENT SHERYL~._,_.~WINDY~ DATE '~ /SI Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~ WINDY Scanning Preparation x30= + BY: BEVERLY ROBIN VINCENT SHERYL~~LAJlNDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES__ NO III Illllllllll II Ill RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd e e (~, MICROFILMED . 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inscrts\Microfihn _ Marker. doc Memorandum State of Alaska Oil and Gas Conservation Commission To' Re~ Well File 201-023 Expired Permit Action WELL: Milne Pt Unit J-14L1XX Permit Issued: 2/6/2001 DATE February 28, 2003 API# 50-029-23001-60 This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to drill. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting redrills and or multilaterals in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to drill. The well number for a cancelled or expired permit is modified with an appended XX. EXPIRED PERMITS ARE RELEASABLE 2 years from the date on the application was issued by the commission, Unless the operator ask for extended confidentiality. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician AI,ASKA OIL AND GAS CONSERYA~ION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit-MPJ-14L1 BP Exploration (Alaska) Inc. Permit No: 201-023 Sur Loc: 2265'NSL, 3155'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 3081'NSL, 4293'WEL, Sec. 20, T13N, R10E, UM Dear Mr. Archey: 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 govemmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPJ-14, Permit No 201-022, API 50- 029-23001. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by Contacting the Commission petroleum field inspector on the 'North Slope pager at 659-3607. Sincerely, . Daniel T. Seamount Commissioner BY ORDER OF THE COMMISSION DATED this //~ ~ day of February, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 01/29/01 15' 22 FAX 907 564 5193 BP EXPLORATION ~002 · 20 AAC 25.005 · . , I Exploratory [] ~trafigraph[c Test [] Development Oil la. Type of work [] Ddll [] Rednl[ lb. Type of well !'1 Service B [~ Re-Enl~ [] Deepen Development Gas Zone [] Multiple Zone 2. Name of Op'~rator 5. Datum Elev'Mion (DF or KB) 10. Field and Pool BP Exploration (Aiaska) Inc. Planned KBE -- 29.12' Milne Point Unit / Schrader 3. Address 6. P__r_opcrty Designation Bluff P.O. BOX 195612, Anchorage, AI.a.s. ka 99519-6612 ~O;~ ADL 025515 ~p 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 ^AC 25.0P-.5) 2265' NSL: 3155' WEL, SEC. 28, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 2837' NSL, 1366' WEL, SEC. 20, T13N, R10E, UM (0A) MPJ-14L1 Number 2S100302630-277 At total depth §. ApproXimat~,' spud date 3081' NSL, 4293' WEL, SEC. 20, T13N, R10E, UM 01/30/01 Amount $200,000.00 12. Distance to nearest property line ~13. D;i~tance to nearest well 14. Number of acres'i~'pr0perty 15, Proposed depth (MD and TVD) ADL 025517, 3081' M DI MPJ-15 ia 71' AwaY al 5244' MD 2560 11952' MD / 4046' TV.D_ 16. TO be completed for deviated wells 17. An{[cipated pressure {see 20 AAC 25.035 (e) (2)} K[ck Off Depth 8725' Maximum Hole Angle 92 ° Maximum surface 1340 psig, Attotal depth (TVD) 4000' / 1800 , . lB. Casing Program ' Specifications Setting bepth Siz. e Top Bottom ,Q.u. antity..of Cement Hole Casinq Wei.qht .Grade Cou~31incl Length MD l'VD MD TVD (include sta.qe data) 6-1/8" 4.-1/2" 12.6# L-80 IBT-MOD 3227' 8725' 4076' 11952' 4046' Uncemented Slotted Liner . , -- , · 19.' To be completed for Redfil[, Re-entry, and [~eepen 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 'I-VD Structural Conductor 30" 20" 260 sx Arctic Set (Approx.) 115' 115' Surface 9-7/8" 7" 3~S0 cu I~ ^r¢11c Sel: III, $61 mu ft A~i~ ~c, ~ 9035' 4155' Intermediate Production LinerR£C'£1VED JAN 2 9 2001 Perforation depth: measured Alaska 0il & Gas Cons. Commission true ve~ical Anchorage "20. Attachments "[] Filing Fee [] Prope~Pla[ [] BOP Sket¢ll (~ Dlverter Sketch [] Drilling Program [] DHlling Fluid Program [] Time vs Deptl~ Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25,050 Requirements ~°nlact Engin'eer Name/Number: Dan Bourne-, 564-4787 ' Prepared ~y Name/Number. So-n'd~ Stew/nan, 21, I hereby certify that the fo.r~oing is tree and. correct to the best o~-r~y knowledge o . Signed' Pat Archey ~/~r~ ~_,~,~,,._~ Title Senjor Drilllng .... Engineer Date //,~. ~../~ Permit Number I APl Number ...... /-, ! Approval D~qte I See cover letter Is0- oz-?- ' ! Conditions of Approval: Samples Required [] Yes ~i'No Mud Log Required [] Yes ,I~No Hydrogen Sulfide Measures ~[IYes [] No Directional Sun/ay Required ~Yes [] No Required Working Pressure fori~OPE ~2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTIJ Other:. ORIGINAL SIGI',tEL;, U, by or~erof A~pprov.ed By ........ D Taylo[ SeamouFli Commissioner the commission Date ~ .... % ] ¢'--' Form 10-401 Rev. 12-01-85 Submit In Triplicate ORIGINAL Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit 1. Well Plan Summary IWell Name: I MPJ-14 & MPJ-14 L1 Type of Well (producer or injector): I Producer (Sidetrack Multilateral) Surface Location: 2265' FSL (3014' FNL), 3155' FEL (2124' FWL), Sec. 28, T13N, R10E X = 552166.18 Y = 6014663.74 J-14 OB Target Start: 2550' FSL (2729' FNL), 870' FEL (4408' FWL), Sec. 20, T13N, R10E X = 549117.45 Y = 6020207.70 Z = 3843' TVDss I AFE Number: J-14 OB Target End: 3081' FSL (2197' FNL), 4293' FEL (985' FWL), Sec. 20, T13N, R10E X = 545689.40 Y = 6020717.36 Z = 4.0_4__7.~_~V_Dss . --______ .. J-14 L10A Target Start: 1 2837' FSL (2442' FNL), 1366' FEL (3913' FWL), Sec. 20, T13N, R10E I X = 548619.42 Y = 6020491.65 Z = 4031' TVDss J-14 L10A Target End: 3081' FSL (2197' FNL), 4293' FEL (985' FWL), Sec. 20, T13N, R10E X = 545689.40 Y = 6020717.36 Z = 3982' TVDss ~ 1337XXX I I Ri~l: I Nabors 22E I Estimated Start Date: I Jan. 30~n 2001 I Operatin~l days to complete: I XX.X I OAMD 11952' OB MD 11958' OATVDrkb (TD) 4046' OB TVDrkb (TD) 4111' OAMax. Inc. 92° OB Max. Inc. 91 ° J KBE 29.12'J IWell Design (conventional, slim hole, etc.): I Grassroots multi-lateral with extended horizontal I laterals. Electric Submersible Pump completion. Scope: Drill 9 ~" mainbore hole to +/- 9000' MD. Land mainbore hole in OB reservoir. Run and cement 7" casing. Drill out shoe and drill a 2960' 6 ¼" horizontal well in the OB sand. Run 4 Y2" slotted liner with hanger. Set retrievable whipstock at top of OA interval at +/- 8725' MD. Mill window in 7" casing. Drill a 3225' 6 ~" horizontal well in the OA sand. Retrieve whipstock. Run 4 Y2" slotted liner with Baker "Hook Hanger" system into upper lateral. Freeze protect well. The well will be completed with a 3 1/2" tubin~l ESP completion by Nabors 4ES. RECEIVE[.) J/~N 2 6 Alaska Oil & Gas Cons. Commission Anchorage Version #2, 1/26/2001 m Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit Current Well Information 2,1 2,2 2,3 2.4 General Well Name: MPJ-14 APl Number: MPJ-14 L1 APl Number: Well Type: Current Status: BHP: BHT: MPJ-14 Development - Schrader Bluff Grassroots Multilateral Producer New well, conductor set 1800 psi @ 4000' TVDss Schrader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4020' TVDss Estimated (SOR) Current Mechanical Condition MPJ-14: Nabors 22E: Conductor: Cellar Box above MSL = 35.00' KB / MSL = 64.12' 20", 92 Ib/ft, H-40 Welded set at 115' RKB Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserves 1.7 MMbbl Production rate: 1500 stb/d Production rate: 1000 stb/d Materials Needed Production Casing: 9000' 1 off 1 off 30 off 1 lot 2 off 1 off 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" BTC-M TAM Port Collar 7"x 9 %" Rigid SB Casing Centralizers 7" casing pups 5', 10', 20' 7" Baker Whipstock and Anchor FMC 11" 5M x 3 Y2" Horizontal Wellhead / Tree 2 x Production Liners: 6190' 160 off 4 %" x 5 3,4" x 8" 7" x 4 Y2" 4Y2" 1 assembly 4 Y2", 12.6#, L-80, IBT-Mod Slotted Liner Rigid Straight Blade Centralizers and stop rings Baker liner top hanger with inner string Baker guide shoe, pack off bushing Baker Level 3 "Hook Hanger" Multilateral Equip. L-80 Completion: 8575' 2 ~" ESP 2 ~" Gauge 2 ~" Landing Nipple 2x2%" 1 off 1 lot 2 %" 6.3 Ib/ft, L-80, 8 round EUE tubing Centrilift Electric Submersible Pump Centrilift Pressure Gauge X Nipple Gas Lift Mandrels BIW ESP & Heat Trace Penetrators 2 %" tubing pup joints RECEIVED JAN B 6 ZOO1 Alaska Oil & Gas Cons, Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drillin~l Permit 3. Drillinq Hazards and Contingencies RECEIVED 3.1. Well Control ,JAN 2 6 2001 MANDATORY WELL CONTROL DRILLS: Alaska Oil & Gas Cons. Commission Anchorage Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter N/A N/A D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.1.1. The 6 ¼" horizontals will be drilled with the BOP installed. MPJ-14 is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.65 lb/gal equivalent. The planned mud weight is 9.1 lb/gal, which provides a 0.45 lb/gal overbalance (97 psi). 3.2. Kick tolerance 3.2.1. The kick tolerance for the 6 ¼" horizontal open hole section is infinite assuming an influx at the 11958' MD in the Schrader OB formation. This is a worst case scenario based on an 8.7 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 lb/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.2.2. The 7" casing will be cemented to surface. The top of the 15.8 lb/gal tail cement slurry is planned to be 7600' MD. 3.3. Lost Circulation 3.3.1. Lost circulation has not been encountered while drilling this interval on previous J-Pad wells. Three more recent wells (Sweet 16 wells J-17, J-20, J21) used the same single 7" casing string design. These wells did not experience lost circulation problems while running and cementing casing. Also, last year's Multi-Lateral wells (J-23 & J-24) did not experience any lost circulation. 3.3.2. Clean hole ECD in the 9 ~" surface hole is estimated to be 10.1 lb/gal. Clean hole ECD in the 6 ¼" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. 3.3.3. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Unexpected High Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no off take or injection support. Reservoir pressure is expected to be 1860 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.5. Stuck Pipe 3.5.1. The J-14 directional plan has a 5450' interval of high angle (74°) in the 9 %" surface hole with 3225' and 2960' horizontal intervals in the OA/OB reservoirs. All these hole intervals have massive Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.5.2. 3.5.3. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! A major risk of the J-14 well is running the 7" casing to TD. The 7" casing must be run all the way to TD to allow for the multilateral to be drilled. Sticking the casing off bottom will result in not being able to drill the multilateral as planned. The 9 %" surface hole has a 5450' high angle tangent section that is built to horizontal at TD. Similar wells in the past have experienced problems running the 7" casing to TD due to the high drag and differential sticking. On the previous wells it was necessary to wash the casing to TD and to utilize the top drive weight to help push the casing. Past operations were successful in running the 7" casing using these techniques in additional to liberal use of lubricants and strict attention to hole cleaning and mud/hole conditioning prior to running casing. 3.5.4. There is a risk of differentially sticking the 4 Y2" slotted liners. The 9.1 lb/gal mud will be 0.45 lb/gal overbalanced to the 8.65 lb/gal OA/OB sand reservoir pressure (96 psi differential pressure @ 4111' TVD). The liner should be kept moving as much as possible while running in the open hole. 3.6. Pad Data Sheet RECEIVE_ D 3.6.1. Please Read the J-Pad Data Sheet thoroughly. JAN 2 (; 2001 3.7. Hydrates Alaska Oil & Gas Cons. Commission · Apc[~0rage 3.7.1. Hydrates have not been encountered on previous J-Pad wells and are not expec[eo. However hydrates have been encountered on H-Pad and mud returns should be monitored to determine if hydrates are encountered on this well. 3.7.2. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300 - 400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. 4 Schrader Bluff Tract 14 2001 Program MPJ-14 Drilling Permit i) Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. 3.8. Breathing 3.8.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.9, Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3,10. Geosteering 3.10.1. Two rig site geologists are required onsite for accurate geosteering through the thin OA/OB sands 3.10.2. It is critical that we achieve a high percentage of 6 ¼" hole in reservoir zone drilling in the OA/OB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3,11, Hydrogen Sulfide 3.11.1. MPJ Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well J- Well Type H2S Status Date taken 1 SBF Prod <2.00 Feb 2000 2i SBF Inj Injector Feb 2000 3 SBF Prod <2.00 Feb 2000 4 SBF Prod <2.00 Feb 2000 5 SBF Prod <2,00 Feb 2000 6 KUP Prod Shut In Feb 2000 7 SBF Prod <2.00 Feb 2000 8 SBF Prod <2.00 Feb 2000 9 KUP Prod <2.00 Feb 2000 10 KUP Prod <2.00 Feb 2000 1 li SBF Inj Injector Feb 2000 12 Long Term Shut In Feb 2000 13i KUP Inj Injector Feb 2000 15i KUP Inj Shut In Feb 2000 16i Long Term Injector Feb 2000 17i SBF Inj <2.00 April 2000 18 KUP Prod 9.60 April 2000 19 SBF Prod <2.00 Feb 2000 20 SBF Prod Shut In Feb 2000 21 SBF Prod <2.00 Feb 2000 22 SBF Prod <2.00 Feb 2000 RECEIVED JAN ;~ 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit 4. Drilling Program Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: Well MPJ-05 may need to be shut in for the rig move on and off MPJ-14 Close Approach Wells: There are 2 close approach wells, MPJ-15, MPJ-16 Well Name Current Production Precautions Status Priority MPJ-15 Injector Water Inj Shut-in MPJ-16 Injector Abandoned 4.2. Well Control Expected BHP 1800 psi @ 4000' TVD (estimated) Max Exp Surface Pressure 1340 psi (0.115 psi/ft ~las gradient) BOPE Ratin~l 5000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2000/250 psi Rams and Valves 2000/250 psi Annular 4.3. Mud Program 9-7/8" Surface Hole Mud Pro 3erties: Spud - LSND Freshwater Mud Density (ppg) Funnel vis YP I HTHP pH I API Filtrate I LG Solids 8.6 - 9.2 50 - 150 40 -15 I N/A 9.0 - 9.5 I <6 <6.5 6 W' Production Hole Mud Properties: OB/OA KCL - CaCO3 Baradril N Mud Density (ppg) I Funnel visI YP HTHP pHI APl Filtrate LG Solids 9.1 40 - 55 22 - 27 < 10 8.0 - 8.5 4 - 6 < 12 ppb NOTE: See attached Baroid mud recommendation LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1R. 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW (PP~7) Base Permafrost 1920 1800 SV1 Top Ugnu 6700 3353 1509 8.66 Top Ugnu M 7600 3598 1619 8.65 NA 8365 3838 1727 8.65 NB 8400 3865 1739 8.66 NC 8450 3894 1752 8.66 NE 8512 3920 1764 8.65 NF 8625 3969 1786 8.66 Top OA 8775 4009 1804 8.65 RECEIVED J/iN 2, 6 ZOOl Alaska Oil & Gas Cons. Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit Base OA 8825 4047 1821 8.65 Top OB 8970 4084 1838 8.65 Base OB 91 O0 4106 1848 8.65 RECEIVED JAN B 6 2001 Alaska Oil & Gas Cons. Commission Anchorage 4.5. Casing/Tubing Program Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit Hole Size Csg! Wt/Ft Grade Conn. Length Top Bottom Tb~ O.D. MD / TVDrkb MD ! TVDrkb 30" 20" 92# H-40 Welded 80' 35' / 35' 115' / 115' 9 %" 7" 26# L-80 BTC-M 9000' 35' / 35' 9035' / 4155' 6 W' OB 4 1/=,, 12.6# L-80 IBT-Mod 3023' 8935'/4140' 11958'/4111' 6 ~" OA 4 Y2" 12.6# L-80 IBT-Mod 3227' 8725' / 4076' 11952' / 4046' Tubin~l 2 %" ESP 6.3# L-80 EUE-Mod 8540' 35' / 35' 8575'/4010' 4.6. Cement Calculations Casing Size I 7" 26 Ib/ft L-80 BTC-M BasisI 250% excess over gauge hole in permafrost interval & 50% excess over gauge hole below permafrost This cement job will be pumped in 2 stages with a TAM Port Collar placed at 1000' MD The cement volumes will be confirmed by the acoustic caliper to be run whilst drilling the 9 N" hole section Total Cement Volume: Wash Spacer Lead Tail Temp 50 bbl of Newtonian Chemical Wash (CW100) weighted to 8.32 ppg 75 bbl of Viscosified Spacer (Mudpush XL Design) weighted to 10.50 ppg 700 bb110.7 lb/gal Class G Arctic Set III Light 100 bb115.8 lb/gal Class G BHST = 80° F from SOR, BHCT 85° F estimated by Dowell 4.6.1. Casing Spaceout a) Space 7" casing out with pups and long/short joints as required to place the top of a long full joint at the actual top of the OA and OB sands to allow for the windows to be milled just below the top of the sands and in the middle of a full joint of casing. Run full casing joints across the OA and OB sands. Any casing pup joints required for space out should be placed below the base of the sands. b) A radioactive tag should be placed in the casing string at least 100' above the OA sands. c) Emergency 7" casing slips can be used instead of the 7" mandrel hanger if required to achieve the required space out. 4.6.2. 7" String Centralizer Placement a) Do not run centralizers on the 2 joints of 7" casing spaced across the upper OA sand. b) With the exception stated above, 9 %" x 7" straight blade rigid centralizers should be run floating in the middle of each joint of casing from the 7" casing shoe up to 7865' MD (500' MD above NA sand). Zonal isolation with cement is required between the top of the OA and base of the N sands. The centralizer program is subject to change pending modeling and hole condition. c) Install a Bow String centralizer either end of the TAM Port Collar with stop collars placed in the middle of the centralizers. 4.6.3. 4 1/2" Slotted Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint with no stop collar (i.e. free floating across the whole length of the joint) for the whole string. RECEIVED JAN 2 (~ 2001 Alaska 0il & Gas Cons. Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drilling Permit 4.7. Survey and Logging Program 9 ¥8" Hole Section: Open Hole: Cased hole: 6 %" Hole Sections: Cased Hole: MWD / GR/Res I PWD / DDS / Acoustic Caliper - (Res. over production interval only) NB. MWD inclination sensor to be placed directly above motor None MWD / GR/Res / PWD / DDS / ABI I ABGR - (ABGR will be run if available) None 4.8. Bit Recommendations BHA Hole Size Depths (MD) Bit Type Nozzles Max. Hours Number and Section K-Revs 1 & 2 9 %" O, _ 9000' Baker Hughes MX-C1 Roller Cone 3x20, lx10 800 - 3 (OB lat.) 6 ¼" 9000'- 11958' Security FM2643 PDC 3x16 - - 4/OA lat.) 6 ¼" 8725' - 11952' Security FM2643 PDC 3x16 ~ - 4.9. Motors and Required Doglegs Drilling Motor Size and Motor Required Flow Rate RPMs Required Doglegs BHA No. (see 5.2.1) 1 6 3,~,, Sperrydrill 7/8, 3 stg Slow Speed, 1.5° adj. 300 - 450 170 2.5°/100' initial build with 9.6" sleeve gpm (max.) 6°/100' final build 2 6 3,~,, Sperrydrill 7/8, 3 stg Slow Speed, 1.15° adj. 400 - 500 170 6°/100' build with 9.6" sleeve gpm (max.) 3 & 4 4 3,~" Sperrydrill 4/5, 6.3 stg FTC Performance, 250 gpm 100 Maximum build = 10°/100' 1.5° or 1.15° adj with 5.8" sleeve (max.) RECEIVED JAN ,t ~; 2.001 Alaska Oil & Gas Cons. Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drillin~l Permit 5. MPJ-14 Nabors 22E Operations Summary 5.1. Pre-Rig Operations 1. Install 20" conductor 5.2. Procedure . . . 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 34. MIRU Nabors 22E, NU diverter on 20" conductor, PU 5" drill pipe MU BHA with 9 %" milltooth bit, 6 3,4" Sperry MWD/LWD(GR-Res)/PWD/ABI/Caliper and 5" drill pipe Drill 9 %" surface hole as per directional plan Tangent angle 74°. Surface hole landed in OB at 79° POOH. Reamer trip with Hole opener to TD Condition mud with lubes and spot casing running lube pill prior to 7" casing run. POOH Run 7" casing (with RA tag @ 100' above Top OA Sand) to TD. Cement casing to surface Install FMC 11" 5m horizontal wellhead NU 13 %" 5m BOP. Test BOP to 2000/250 psi Lay down 5" drill pipe, PU 3 Y2" drill pipe MU BHA with 6 ¼" PDC bit, 4 3A" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe RIH. Drill out float equipment Displace hole to 9.1 lb/gal Bara Drill mud Drill 20' of new hole and perform FIT to > 11.0 lb/gal Drill 2960' 6 ¼" OB lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. POOH. Reamer trip with Hole Opener to TD Displace OB lateral with clean Bara Drill mud Run 4 Y~" slotted liner with inner string to OB lateral TD and hang off 100' inside 7" casing Make up Baker Window Master milling assembly with bottom trip anchor and MWD. RIH. Orient and set whipstock to place window at top of the OA interval. Shear off and mill window thru 7" and 9 %" casing. MU BHA with 6 ~" PDC bit, 4 3,~" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y~" drill pipe RIH. Displace hole to clean Bara Drill mud Drill 3225' 6 ¼" OA lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. POOH. Reamer trip with Hole Opener to TD. Displace OA lateral with clean Bara Drill mud MU whipstock retrieving tool and pull whipstock Run 4 Y~" slotted liner with 2 %" inner string, Baker Hook Hanger and hang off in 7" casing POOH laying down 3 1/~,, drill pipe Run in hole with 2 %" tubing to top of OA liner Displace 7" casing to 9.1 lb/gal completion fluid Land tubing hanger Set tubing plug and BPV ND BOP Install and test tree Pull tubing plug and BPV Freeze protect the tubing and annulus Install BPV and secure the well RD/MO RECEIVED JAN 2, 6 ?001 10 Alaska Oil & Gas Cons. Commission Anchorage Schrader Bluff Tract 14 2001 Pro~lram MPJ-14 Drillin~l Permit 6. MPJ-14 Nabors 4ES Operations Summary 1. MI/RU Nabors 4ES. 2. Circulate out freeze protection with 9.1 ppg brine. 3. Remove tree and install BOP. 4. Pull and stand back the 2 %" tubing. 5. Make up the ESP completion and run in on the 2 %" tubing. Freeze protect the well. 6. Set tubing plug and BPV. Remove the BOP. Install and test the tree. 7. RD/MO. 8. Hook up flowlines and instrumentation. RECEIVED JAN ~ 6 2001 Alaska Oil & Gas Cons. Commission Anchorage 11 'TREE: 'EMC Horizontal 3-1/8" 5M PROPOSED COMPLETION WELLHEAD:FMCHorizonta111",5Mtbg. head ( ....MP J-14 &.J.14 L1 ('KB. ELEV=64.12' 11"x 3-1/2", EUE (btm) __ __.... i . Cellar Box ELEV = 35.00' , FMC tbg. hanger, 'H' BPV profile , I / 1 1 0' 20" 92 Ib/ft, H-40 Welded ~ · · ~/ 2-7/8" x 1" Gas Lift Mandrelt is0, : ' 2-7/8", 6.3 lb/fi, L-80, EUE-M -- Coupling OD: 3.5" Drift/ID' 2.347"/2.441" I i 2-7/8" x 1" Gas Lift Mandrel , 8525' RECEIVED ii X Nipple 2.313" ID AlaSka Oi~ & GaS Coos. Commissior~ I Aoc~orage iii, Centrilift Electric Submersible Pump I 8575" I 7", 26#, 1-80, BTG-M Casing Drift: 6.151" Casing ID: 6.276" Centrilift Pressure Gauge Multi-Lateral Junction I 8725' Baker Hughes Hook Hanger system I Window in 7" casing @ 8725' < - ~,'v~, ~_,/~_ < 'i Well Inclination @ Window = 68 Degrees < -1/8" OA Lateral ID ~ner ald~H~o~Zger_~_. Baker Hughes Conventional Hanger 7" Casing Shoe @ 9000' Well Inclination @ Shoe - 79 Degrees OB Horizontal iill illl i ii i i i i ii 6-1/8" OB Lateral TD [ 11958' 4-1/2" Slotted Liner & Hanger DATE REV, BY COMMENTS Milne Point Unit · WELL: J-14 1/26/2001 Daniel Bourne Level 3 Multi-Lateral, 2-7/8" ESP Completion APl NO: - BP Exploration (Alaska) Calculation Method: Minimum Curvature Error Syslem: ISCWSA Scan Method: Iligh Side + A~muth Error Surface: Ell~ical '. C~slag Wamin~ Method: Rules Based Co-ordinate (N/E) Reference: Well CeaSe: MP$-I4, Tree North Vertical OVD) Reference: MP.LI4 64.12 64.1 Section Q/S) Refe~mce: Slo~ - 14 (0.00,0.00) Mea.su~d Depth Reference: MPJ-14 64.12 64_1 Calculation Method: Mi~num Cutvatu~ SURVEY PROGIL~{ l)epthFm DepthTo Sun~,[P[an 8725.00 11951.54 Planned: MPJ-14LI v, p03 VI Tool M~/D Plan: MPJ. 14LI wp03 (MPJ-14/Plan MPJ-14LI) Created By: Authorised User Date: 1/25/2001 Checked: Dale: Reviewed: Date: ANNOTATIONS No. TVD MD Annotation 1 4075.53 8725.00 Start Dir 10°/100': 8725' MD, 4075.53'TVD 2 4123.59 9002.77 End Dir: 9002.77' MD, 4123.59' TVD 3 4100.74 9540.19 Start Dir 6°/100': 9540.19' MD, 4100.74'TVD 4 4093.00 9780.35 End Dir: 9780.35' MD, 4093' TVD 5 0.00 11951.54 Total Depth: 11951.54' MD, 4046.12' TVD 7000- 9,q£1.[. DEl AIL~; Name ~N~-S~FJ-W Noflhing I~fin/~ latitudeI.~mtdlud¢ Sit,! MPJ-14 124356739.76 6014663.74 552166.18 70~27'02.877N 14~v'34'27.777W 14 TARGE3' I)ETAII.S Name TVD t N~-S ~ I'Y-W N~nlhingI:~.~lin8 Shape MPJ-14LI Tla 4~5.~5853.16 -35~.22 (~2~91.65 M~,19.42 Poinl MPJ-14LI T~ ~3.~ ~39.42 4265.03 ~2~,72.57 ~7859.40 Point MP~I4LI T3a ~.12 ~.39 ~M.g8 (~2071736 M~,89.40 Po~t SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target 8725.00 67.56 298.61 4075.53 5753.78 -3261.11 0.00 0.00 6325.03 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 10.00 -28.02 6577.13 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 0.00 0.00 7053.33 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 6.00 -94.52 7250.15 MPJ-14LI ~,,~ 11951.54 91.24 271.58 4046.12 6099.39 -6434.88 0.00 0.00 8866.24 MPJ-14LI T3a 4000-- ..... ~ .......... ~ ............ ~ ............. ~ ............. ~ .............. ~ ............. i ............. ~ ..................... ~ ......... ~ ....................... ~ ............................ i ...................................................................... ~ -8000 -7000 -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 West(-)/East(+) [1000fi/in] COMPANY DEl'AILS BP Amoco Calculation Melhod: Minimum Crrralure Enor Syslem: ISCWSA Scan Method: High Side + Azimulh Error Surface: Elllplical + Casing Wamin~ Melhod: Rtfles Based ANNOTATIONS No. TVD MD Annotation I 4075.538725.00 Start Dir 10°/100': 8725' MD, 4075.53'TVD 2 4123.599002.77 End Dir: 9002.77' MD, 4123.59' TVD 3 4100.749540.19 Start Dir 6°/100.: 9540.19' MD, 4100.74'TVD 4 4093.009780.35 End Dir: 9780.35' MD, 4093' TVD 5 4046.121 1951.53 Total Depth: 11951.54' MD, 4046.12' TVD 1000- _ 2000~ 3000- 4000- 1000 Coq>rdinate (N]~ Reference: Well Cculxe: MPJ-14, True North Vertical (TVD) Reference: MPJ- 14 64.1264. I Section (VS) Reference: Slo~ - 14 (0.00,0_~) Measured Deplh Re ference: MPJ-14 64.12 64.1 Calculation Method: Minimum Cur,'al~e SURVEY PROGRAM Depth Fm Deplh To Stawey,~lan 8725_00 11951.54 Planne~ MPJ-14LI v,~03 VI Tool MWD Plan: MPJ-14LI wp03 (MPJ-14/Plan MPJ-14LI) Created By: Authorised User Date: 1/2512001 Checked: Date: __ Reviewed: Date: __ WELl. I)EI'AII~~, Name +Nt-S*I:~-W Notlhing I~.~ling I.alilude I.~m~itud¢ Slot MPILI4 1243.56 739.76 6014663.74 55216(,.18 70"2702.877N 149"34'27.777W 14 TARGF/F I)E JAILS Name 'D/D * 1%'-S ~W-W N~nlhin8I:,a.~in g Shap~ MPJ-14LI Tla 4095.00 585.1.16 -3506.22 6020491.65 54~d9.42 Point MPJ-14LI T2a 4093.00 6039.42 -4265.03 (~O20(,72.57 547859.40 Point MPJ-14L1 T3a 4046.12 6099.39 -6454.88 (,020717.M~ 545689.40 I'alnl SECTION DETAILS gec MD Inc Azi TVD N/S E/W DLeg TFace VSec l'arget 8725.00 67.56 298.61 4075.53 5753.78 -3261.11 0.00 0.00 6325.03 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 10.00 -28.02 6577.13 ~ 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 0.00 0.00 7053.33 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 6.00 -94.52 7250.15 MPJ-14LIh_ 11951.54 91.24 271.58 4046.12 6099.39 -6434.88 0.00 0.00 8866.24 MPJ-14LI T3a g, ooo ~ } ~ ~ ~ ~ ~ ~ ~ ~ ?u ~ ~'~'TI~'- ~PJ-14LI I2a ~ MPJ-14LI T3a 2000 3000 4000 5000 6000 7000 8000 9000 10000 Vertical Section at 313.47° [ 1000fl/in] 14am~ m R.~lec i J~vT. $,] R~km p~ I~lP~JI ~ --53 --45 From CoJour ToMD 0 0 0 200 200 400 40~ F~0 1000 J2~ 200 ' 1500 5~ 1800 8~ ~oo 26~ 120 / t --80 --7O --60 --4O --3O --211 --[0 --0 --2O --3O '-'4O --5O --6O --8O Fcarm Col,u~ To MD O 0 O 3'00 200 400 400 · d00 6OO 80O 800 1000 IZO0 1500 I~00 221,10 9O r---.) o o , · : . . tO (~o_./.]o) ......... · . ~IPJ.~ __ : i ..I I J J ; f f ; ' BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt J Pad Well: MPJ-14 Wellpath: Plan MPJ-14L1 Date: 1/25/2001 Time: 18:43:22 Co-ordinate(NE) Reference: Well: MPJ-14, True North Vertical (TVD) Reference: MPJ-14 64.12 64.1 Section (VS) Reference: Well (0.00E,0.00N,313.47Azi) Plan: MPJ-14L1 wp03 Page: Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: . Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt J Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013415,23 551435,10 Latitude: 70 26 50.647 N Longitude: 149 34 49.503 W North Reference: True Grid Convergence: 0.40 deg Well: MPJ-14 Surface Position: +N/-S 1243,56 ft Northing: 6014663,74 ft +E/-W 739,76 ft Easting: 552166.18 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 1243.56 ft Northing: 6014663.74 ft +E/-W 739,76 ft Eastlng: 552166,18 ft Measured Depth: 64.12 ft Vertical Depth: 64.12 ft Slot Name: 14 Latitude: 70 27 2,877 N Longitude: 149 34 27,777 W Latitude: 70 27 2,877 N Longitude: 149 34 27,777 W Inclination: 0.00 deg Azimuth: 0.00 deg Welipath: Plan MPJ-14L1 Drilled From: Plan MPJ-14 Tie-on Depth: 8725.00 ft Current Datum: MPJ-14 64.12 Height 64.12 ft Above System Datum: Mean Sea Level Magnetic Data: 1/19/2001 Declination: 26.36 deg Field Strength: 57439 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0,00 0,00 0.00 313,47 Plan: MPJ-14L1 wp03 Date Composed: 1/25/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Inel Azim ~ ~:-I-N/.S i.I-E/~W :' DI,S::: 'BUild:.:: .iTurnl TFO Target: ::.' :ft:'::ii : deg.: :deg. : ::iff:: deg/100ftdeg/100ffdog/100ft' deg : ' : 8725,00 67,56 298,61 4075,53 5753,78 -3261,11 0,00 0,00 0,00 0,00 9002,77 92.44 285.95 4123,59 5855.38 -3512,16 10,00 8,96 -4,56 -28,02 9540,19 92,44 285,95 4100,74 6002,94 -4028,42 0,00 0,00 0.00 0,00 9780,35 91,24 271.58 4093.00 6039,42 -4265,03 6,00 -0.50 -5,98 -94,52 MPJ-14L1T2a 11951.53 91.24 271.58 4046.12 6099.39 -6434.88 0,00 0,00 0,00 0,00 MPJ-14L1T3a Section 1 : Start ~MD ' : Incl iAzim TVD :?;:::: +N/'S :+E/;W ' VS ' DLS Build: Turn TFO i:::' .: ' :deg: : 'deg .... = = fi::::: ,fi:: ff deg!lOOft:deg/100ft deg/10Oft deg .... 8725,00 67,56 298,61 4075.53 5753.78 -3261.11 6325,03 0.00 0,00 0.00 0.00 8750,00 69,77 297.36 4084,62 5764,70 -3281,67 6347,47 10,00 8,85 -5.01 -28,02 8800,00 74,22 294,96 4100,08 5785,65 -3324,35 6392,85 10,00 8,90 -4,80 -27,56 8850,00 78,69 292,66 4111.79 5805,26 -3368,81 6438.60 10,00 8,95 -4.60 -26.82 8900.00 83,18 290,43 4119.66 5823,38 -3414,72 6484,39 10,00 8,98 -4,46 -26,28 8950,00 87.68 288,24 4123,64 5839,87 -3461.74 6529,86 10.00 9,00 -4,37 -25.93 9002,77 92,44 285,95 4123,59 5855,38 -3512.16 6577,13 10.01 9.01 -4.35 -25.76 Section 2: Start MD:~: Incl Azim' TVD +N/-S :+E/-W VS DLS BUild Turn TFO " ff deg deg ff ff ff ff degllOOftdegllOOftdegllOOft deg 9100.00 92.44 285.95 4119.45 5882.07 -3605.56 6663.28 0.00 0.00 0.00 0.00 9200.00 92.44 285.95 4115.19 5909.53 -3701.63 6751.89 0.00 0.00 0.00 0.00 9300.00 92.44 285.95 4110.94 5936.98 -3797.69 6840.50 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 112512001 Time: 18:43:22 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPJ-14, True North Site: M Pt J Pad Vertical (TVD) Reference: MPJ-14 64.12 64.1 Well: MPJ-14 Section (VS) Reference: Well (0.00E,0.00N,313.47Azi) Wellpath: Plan MPJ-14L1 p_lan: ........... MPJ-14L1 wp03 ..................... Section 2: Start MD lncl Azim TVD +N/-S +EJ-W VS DLS Build Turn TFO ift deg deg ft ft ft ft degll00ft deg/100ft deg/100ft deg I ~ 9400.00 92.44 285.95 4106.68 5964.44 -3893.75 6929.10 0.00 0.00 0.00 0.00 I 9500.00 92.44 285.95 4102.42 5991.89 -3989.81 7017.71 0.00 0.00 0.00 0.00 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 7053.33 0.00 0.00 0.00 0.00 Section 3: Start MD Incl Azlm TVD +N/-S +E/-W VS DLS Build Turn TFO I ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg i 9550.00 92.39 285.36 4100.33 6005.59 -4037.86 7062.00 6.00 -0.47 -5.99 -94.52 = 9600.00 92.15 282.37 4098.34 6017.56 -4086.36 7105.43 6.00 -0.48 -5.99 -94.54 9650.00 91.91 279.38 4096.57 6026.98 -4135.42 7147.53 6.00 -0.49 -5.98 -94.66 9700.00 91.65 276.39 4095.02 6033.84 -4184.92 7188.17 6.00 -0.50 -5.98 -94.77 L9750.00 91.40 273.40 4093.69 6038.10 -4234.71 7227.24 6.00 -0.51 -5.98 -94.86 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 7250.15 6.01 -0.52 -5.99 -94.93 Section 4: Start 'MD incl ' 'Azim : ~ TVD +N/-S +E/-W' VS DLS Build Turn TFO ' · ft dog deg ft ft ft fl degil00ft deg/100ft deg/100ft deg 9800.00 91.24 271.58 4092.57 6039.96 -4284.67 7264.78 0.00 0.00 0.00 0.00 9900.00 91.24 271.58 4090.41 6042.72 -4384.61 7339.21 0.00 0.00 0.00 0.00 10000.00 91.24 271.58 4088.25 6045.47 -4484.55 7413.64 0.00 0.00 0.00 0.00 ill 10100.00 91.24 271.58 4086.08 6048.23 -4584.48 7488.07 0.00 0.00 0.00 0.00~ c::::) -4684.42 7562.50 0.00 0.00 0.00 0.00 ~, N 10200.00 91 .24 271.58 4083.92 6050.99 10300.00 91.24 271.58 4081.75 6053.74 -4784.36 7636.93 0.00 0.00 0.00 0.00 ,,--,., cz::) 10400.00 91.24 271.58 4079.59 6056.50 -4884.30 7711.36 0.00 0.00 0.00 0.00 ~1~ 10500.00 91.24 271.58 4077.43 6059.26 -4984.24 7785.79 0.00 0.00 0.00 0.00 10600.00 91.24 271.58 4075.26 6062.01 -5084.18 7860.22 0.00 0.00 0.00 0.00 Z 10700.00 91.24 271.58 4073.10 6064.77 -5184.12 7934.65 0.00 0.00 0.00 0.00 10800.00 91.24 271.58 4070.93 6067.53 -5284.05 8009.08 0.00 0.00 0.00 0.00 10900.00 91.24 271.58 4068.77 6070.28 -5383.99 8083.51 0.00 0.00 0.00 0.00 11000.00 91.24 271.58 4066.61 6073.04 -5483.93 8157.94 0.00 0.00 0.00 0.00 11100.00 91.24 271.58 4064.44 6075.80 -5583.87 8232.37 0.00 0.00 0.00 0.00 11200.00 91.24 271.58 4062.28 6078.55 -5683.81 8306.79 0.00 0.00 0.00 0.00 11300.00 91.24 271.58 4060.11 6081.31 -5783.75 8381.22 0.00 0.00 0.00 0.00 11400.00 91.24 271.58 4057.95 6084.07 -5883.69 8455.65 0.00 0.00 0.00 0.00 11500.00 91.24 271.58 4055.79 6086.82 -5983.62 8530.08 0.00 0.00 0.00 0.00 11600.00 91.24 271.58 4053.62 6089.58 -6083.56 8604.51 0.00 0.00 0.00 0.00 11700.00 91.24 271.58 4051.46 6092.34 -6183.50 8678.94 0.00 0.00 0.00 0.00 11800.00 91.24 271.58 4049.29 6095.09 -6283.44 8753.37 0.00 0.00 0.00 0.00 91.24 271.58 4047.13 6097.85 -6383.38 8827.80 0.00 0.00 0.00 0.00 11900.00 11951.53 91.24 271.58 4046.12 6099.39 -6434.88 8866.24 0.00 0.00 0.00 0.00 Survey · i Map ~ .Map <m Latitude --.-->. <--- Longitude ---> iiMD Incl ' Azim TVD' +N/-S +E/-W NOrthing . Easting Deg Mia Sec DegMin : ft deg. : deg .;: ft ' fl · 'ff ff .' 8725.00 67.56 298.61 4075.53 5753.78 -3261.11 6020394.00 548865.20 70 27 59.457 N 149 36 3.626 W 8750.00 69.77 297.36 4084.62 5764.70 -3281.67 6020404.78 548844.56 70 27 59.564 N 149 36 4.231 W 8800.00 74.22 294.96 4100.08 5785.65 -3324.35 6020425.42 548801.75 70 27 59.770 N 149 36 5.485 W 8850.00 78.69 292.66 4111.79 5805.26 -3368.81 6020444.71 548757.15 70 27 59.963 N 149 36 6.792 W 8900.00 83.18 290.43 4119.66 5823.38 -3414.72 6020462.51 548711.12 70 28 0.141 N 149 36 8.142 W 8950.00 87.68 288.24 4123.64 5839.87 -3461.74 6020478.68 548663.99 70 28 0.303 N 149 36 9.524 W 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 6020493.83 548613.47 70 28 0.455 N 149 36 11.006 W 9100.00 92.44 285.95 4119.45 5882.07 -3605.56 6020519.87 548519.89 70 28 0.717 N 149 36 13.752 W 9200.00 92.44 285.95 4115.19 5909.53 -3701.63 6020546.65 548423.64 70 28 0.987 N 149 36 16.576 W 9300.00 92.44 285.95 4110.94 5936.98 -3797.69 6020573.43 548327.40 70 28 1.256 N 149 36 19.400 W 9400.00 92.44 285.95 4106.68 5964.44 -3893.75 6020600.20 548231.16 70 28 1.526 N 149 36 22.224 W 9500.00 92.44 285.95 4102.42 5991.89 -3989.81 6020626.98 548134.91 70 28 1.795 N 149 36 25.048 W 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 6020637.76 548096.24 70 28 1.904 N 149 36 26.183 W 9550.00 92.39 285.36 4100.33 6005.59 -4037.86 6020640.34 548086.78 70 28 1.930 N 149 36 26.460 W , BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt J Pad Well: MPJ-14 Wellpath: Plan MPJ-14L1 Date: 1/25/2001 Time: 18:43:22 Co-ordinate(NE) Reference: Well: MPJ-14, True North Vertical (TVD) Reference: MPJ-14 64.12 64.1 Section CVS) Reference: Well (0.00E,0.00N,313.47Azi) Plan: MPJ-14L1 wp03 Page: 3 Survey Map Map <-- Latitude ---> <-- Longitude ---> MD lncl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec fl deg deg fl fl fl fl fl 9600.00 92.15 282.37 4098.34 6017.56 -4086.36 6020651.97 548038.20 70 28 2.047 N 149 36 27.886 W 9650.00 91.91 279.38 4096.57 6026.98 -4135.42 6020661.05 547989.08 70 28 2.140 N 149 36 29.328 W 9700.00 91.65 276.39 4095.02 6033.84 -4184.92 6020667.55 547939.54 70 28 2.207 N 149 36 30.783 W 9750.00 91.40 273.40 4093.69 6038.10 -4234.71 6020671.47 547889.72 70 28 2.248 N 149 36 32.247 W 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 6020672.58 547859.40 70 28 2.261 N 149 36 33.138 W 9800.00 91.24 271.58 4092.57 6039.96 -4284.67 6020672.98 547839.76 70 28 2.266 N 149 36 33.715 W 9900.00 91.24 271.58 4090.41 6042.72 -4384.61 6020675.04 547739.81 70 28 2.293 N 149 36 36.652 W 10000.00 91.24 271.58 4088.25 6045.47 -4484.55 6020677.09 547639.87 70 28 2.319 N 149 36 39.590 W 10100.00 91.24 271.58 4086.08 6048.23 -4584.48 6020679.15 547539.92 70 28 2.346 N 149 36 42.527 W 10200,00 91,24 271.58 4083.92 6050.99 -4684.42 6020681.21 547439.98 70 28 2.372 N 149 36 45.465 W 10300.00 91.24 271.58 4081.75 6053.74 -4784.36 6020683.27 547340.03 70 28 2.399 N 149 36 48.403 W 10400.00 91.24 271.58 4079.59 6056.50 -4884.30 6020685.32 547240.09 70 28 2.425 N 149 36 51.340 W 10500.00 91.24 271.58 4077.43 6059.26 -4984.24 6020687.38 547140.14 70 28 2.452 N 149 36 54.278 W 10600.00 91.24 271.58 4075.26 6062,01 -5084.18 6020689.44 547040.19 70 28 2.478 N 149 36 57.215 W 10700.00 91,24 271.58 4073.10 6064.77 -5184.12 6020691.49 546940.25 70 28 2.505 N 149 37 0.153 W 10800.00 91.24 271.58 4070.93 6067.53 -5284.05 6020693.55 546840.30 70 28 2.531 N 149 37 3.090 W 10900,00 91,24 271.58 4068.77 6070.28 -5383.99 6020695.61 546740.36 70 28 2.558 N 149 37 6.028 W 11000.00 91.24 271.58 4066.61 6073.04 -5483.93 6020697.66 546640.41 70 28 2.584 N 149 37 8.965 W 11100.00 91.24 271.58 4064.44 6075.80 -5583.87 6020699.72 546540.47 70 28 2.610 N 149 37 11.903 W 11200.00 91,24 271.58 4062.28 6078.55 -5683.81 6020701.78 546440.52 70 28 2.637 N 149 37 14.840 W 11300.00 91.24 271.58 4060.11 6081.31 -5783.75 6020703.83 546340.57 70 28 2,663 N 149 37 17.778 W 11400.00 91.24 271.58 4057,95 6084.07 -5883.69 6020705.89 546240.63 70 28 2.689 N 149 37 20.715W 11500.00 91.24 271.58 4055.79 6086.82 -5983.62 6020707.95 546140.68 70 28 2.716 N 149 37 23.653W 11600.00 91.24 271.58 4053.62 6089.58 -6083.56 6020710.00 546040.74 70 28 2.742 N 149 37 26.590W 11700.00 91.24 271.58 4051.46 6092.34 -6183.50 6020712.06 545940.79 70 28 2.768 N 149 37 29.528W 11800.00 91.24 271.58 4049.29 6095.09 -6283.44 6020714.12 545840.85 70 28 2.795 N 149 37 32.465W 11900.00 91.24 271.58 4047.13 6097.85 -6383.38 6020716.17 545740.90 70 28 2.821 N 149 37 35.403W 11951,53 91.24 271.58 4046.12 6099.39 -6434,88 6020717.35 545689.39 70 28 2.836 N 149 37 36.917.W__[__ Targets =. ii' :: , , ~ :., .Map Map <--=Latitude .__> <--~.:LOngitude --> Name . DesCripti°n TVD · +N/-S : +E/-W :::: i Northing' Easting :Deg::Min ~:iSeC Deg Min Sec ~ : ft": ff ft:' ::: = ~: :ft ~ MPJ-14L1Tla 4095.00 5853.16 -3506.22 6020491.65 548619.42 70 28 0.433 N 149 36 10.832W MPJ-14L1T2a 4093.00 6039.42 -4265.03 6020672.57 547859.40 70 28 2.261N 149 36 33.138W MPJ-14L1T3a 4046.12 6099.39 -6434.88 6020717.36 545689.40 70 28 2.836 N 149 37 36.917W RF_.GEIV Alaska Oil & Gas ConS. commiss~o~ A~ch0~age BP Amoco Planning Report- Geographic Company: BP Amoco Date: 1/25/2001 Time: 18:43:22 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: Well: MPJ-14, True North Site: M Pt J Pad Vertical (TVD) Reference: MPJ-14 64.12 64.1 Well: MPJ-14 Section (VS) Reference: Well (0.00E,0.00N,313.47Azi) Wellpath: Plan MPJ-14L1 Plan: MPJ-14L1 wp03 Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: M Pt J Pad TR-13-10 UNITED STATES · North Slope Site Position: Northing: 6013415.23 ft Latitude: 70 26 50.647 N From: Map Easting: 551435.10 ft Longitude: 149 34 49.503 W Position Uncertainty: 0.00 ft North Reference: True ~_~_r~.un_d__L_e_v_el~.' .............. __0._0?~__ff.__ Grid Convergence: 0.40 deg Well: MPJ-14 Slot Name: 14 Surface Position: +N/-S 1243.56 ft Northing: 6014663.74 ft Latitude: 70 27 2.877 N +E/-W 739.76 ft Easting: 552166.18 ft Longitude: 149 34 27.777 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 1243.56 ft Northing: 6014663.74 ft Latitude: 70 27 2.877 N +E/-W 739.76 ft Eastlng: 552166.18 ft Longitude: 149 34 27.777 W Measured Depth: 64.12 ft Inclination: 0.00 deg VerticaIDepth: 64.12 ft Azimuth: 0.00 deg Wellpath: Plan MPJ-14L1 Drilled From: Plan MPJ-14 Tie-on Depth: 8725.00 ft Current Datum: MPJ-14 64,12 Height 64.12 ft Above System Datum: Mean Sea Level Magnetic Data: 1/19/2001 Declination: 26.36 deg Field Strength: 57439 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ........................................... _ft_ ................................................. ~ ............................. f__t ........................ 0.00 0,00 0.00 313.47 Plan: MPJ-14L1 wp03 Date Composed: 1/25/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Inel Azim :. TVD +N/-S +E/-W DLS Build Turn TFO Target .................. i....ff.....i......i....:; .......... .d..~g deg . ft 'ft ft deg/100ft deg/100ft deg/100ft deg ........................................................................................................... 8725.00 67.56 298.61 4075,53 5753.78 -3261.11 0.00 0.00 0,00 0.00 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 10.00 8.96 -4,56 -28,02 9540.19 92,44 285.95 4100.74 6002.94 -4028.42 0.00 0.00 0.00 0.00 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 6.00 -0.50 -5.98 -94.52 MPJ-14L1 T2a 11951.53 91.24 271.58 4046.12 6099.39 -6434.88 0.00 0.00 0.00 0.00 MPJ-14L1 T3a Section 1 : Start MD lncl Azim TVD +N/-S.' +E/-W VS DLS Build TUrn ' TFO · ..... ............. ............ :.: ......... .................. ...................... .f._t.....i ............................ ....................... _f._t. .............................. f.t ...................... ............. .............................................................. 8725.00 67.56 298.61 4075.53 5753.78 -3261.11 6325.03 0.00 0.00 0.00 0.00 8750.00 69.77 297.36 4084.62 5764.70 -3281.67 6347.47 10.00 8.85 -5.01 -28.02 8800.00 74.22 294.96 4100.08 5785.65 -3324.35 6392.85 10.00 8.90 -4.80 -27.56 8850.00 78.69 292.66 4111.79 5805.26 -3368.81 6438.60 10.00 8.95 -4.60 -26.82 8900.00 83.18 290.43 4119.66 5823.38 -3414.72 6484.39 10.00 8.98 -4.46 -26.28 8950.00 87.68 288.24 4123.64 5839.87 -3461.74 6529.86 10.00 9.00 -4.37 -25.93 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 6577.13 10.01 9.01 -4.35 -25.76 Section 2: Start MD lncl Azim TVD +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg ...................................................................................................... 9100.00 92.44 285.95 4119.45 5882.07 -3605.56 6663.28 0.00 0.00 0.00 0.00 9200.00 92.44 285.95 4115.19 5909.53 -3701.63 6751.89 0.00 0.00 0.00 0.00 9300.00 92.44 285.95 4110.94 5936.98 -3797.69 6840.50 0.00 0.00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 1/25/2001 Time: 18:43:22 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPJ-14, True North Site: M Pt J Pad Vertical (TVD) Reference: MPJ-14 64.12 64.1 Well: MPJ-14 Section (VS) Reference: Well (0.00E,0.00N,313.47Azi) Wellpath: Plan MPJ-14L1 Plan: MPJ-14L1 wp03 Section 2: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO i ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 9400.00 92,44 285.95 4106.68 5964.44 -3893.75 6929.10 0.00 0.00 0.00 0.00 9500.00 92.44 285.95 4102.42 5991.89 -3989.81 7017.71 0.00 0.00 0.00 0.00 ~ 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 7053.33 0.00 0.00 0.00 0.00 Section 3: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 9550.00 92.39 285.36 4100.33 6005.59 -4037.86 7062.00 6.00 -0.47 -5.99 -94.52 9600.00 92.15 282.37 4098.34 6017.56 -4086.36 7105.43 6.00 -0.48 -5.99 -94.54 9650.00 91.91 279.38 4096.57 6026.98 -4135.42 7147.53 6.00 -0.49 -5.98 -94.66 9700.00 91.65 276.39 4095.02 6033.84 -4184.92 7188.17 6.00 -0.50 -5.98 -94.77 9750.00 91.40 273,40 4093.69 6038.10 -4234.71 7227.24 6.00 -0.51 -5.98 -94.86 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 7250.15 6.01 -0.52 -5.99 -94.93 Section 4: Start 9800.00 91,24 271.58 4092.57 6039.96 -4284.67 7264.78 0.00 0,00 0.00 0.00 9900,00 91.24 271,58 4090.41 6042.72 -4384.61 7339.21 0.00 0.00 0.00 0.00 10000.00 91.24 271.58 4088.25 6045.47 -4484.55 7413,64 0.00 0.00 0.00 0.00 10100.00 91,24 271.58 4086.08 6048.23 -4584.48 7488.07 0.00 0.00 0.00 0.00 10200.00 91.24 271.58 4083.92 6050.99 -4684.42 7562.50 0.00 0.00 0.00 0.00 10300.00 91.24 271.58 4081.75 6053.74 -4784.36 7636.93 0.00 0.00 0.00 0.00 10400,00 91.24 271.58 4079.59 6056.50 -4884.30 7711.36 0.00 0.00 0.00 0.00 10500,00 91.24 271.58 4077.43 6059.26 -4984.24 7785.79 0.00 0.00 0.00 0.00 10600.00 91.24 271.58 4075.26 6062.01 -5084.18 7860.22 0.00 0.00 0.00 0.00 10700.00 91,24 271.58 4073.10 6064.77 -5184.12 7934.65 0.00 0.00 0,00 0.00 10800.00 91.24 271.58 4070.93 6067.53 -5284.05 8009.08 0.00 0.00 0.00 0.00 10900.00 91.24 271.58 4068.77 6070.28 -5383.99 8083.51 0.00 0.00 0.00 0.00 11000,00 91.24 271.58 4066.61 6073.04 -5483.93 8157.94 0.00 0.00 0.00 0.00 11100.00 91,24 271.58 4064.44 6075.80 -5583.87 8232.37 0.00 0.00 0.00 0.00 11200.00 91.24 271.58 4062.28 6078.55 -5683.81 8306.79 0.00 0.00 0.00 0.00 11300.00 91.24 271.58 4060.11 6081,31 -5783.75 8381.22 0.00 0.00 0.00 0.00 11400.00 91.24 271.58 4057.95 6084.07 -5883.69 8455.65 0.00 0.00 0.00 0.00 11500.00 91.24 271.58 4055.79 6086.82 -5983.62 8530.08 0.00 0.00 0.00 0.00 11600.00 91.24 271.58 4053.62 6089.58 -6083.56 8604,51 0,00 0.00 0.00 0.00 11700.00 91.24 271.58 4051.46 6092.34 -6183.50 8678.94 0.00 0.00 0.00 0.00 11800.00 91.24 271.58 4049.29 6095.09 -6283.44 8753.37 0.00 0.00 0.00 0.00 11900.00 91.24 271.58 4047.13 6097.85 -6383.38 8827.80 0.00 0.00 0.00 0.00 11951.53 91.24 271.58 4046.12 6099.39 -6434.88 8866.24 0.00 0.00 0.00 0.00 Survey '. Map" 'Map <--- Latitude -----> <-- Longitude ---> · MD Incl · Azim TVD +N/-S +E/-W Northing Easting Deg Min' Sec Deg Min 'Sec ft deg deg 'ft ft · ft ft · ft .......................................................................................................................... -....: ............. '___..: ................................................................................................................................................... - ............................................................................ - ......................................... : 8725.00 67.56 298.61 4075.53 5753.78 -3261.11 6020394.00 548865.20 70 27 59.457 N 149 36 3.626W 8750.00 69.77 297.36 4084.62 5764.70 -3281.67 6020404.78 548844.56 70 27 59.564 N 149 36 4,231W 8800.00 74.22 294.96 4100.08 5785.65 -3324.35 6020425.42 548801.75 70 27 59.770 N 149 36 5.485W 8850,00 78.69 292.66 4111.79 5805.26 -3368.81 6020444.71 548757.15 70 27 59.963 N 149 36 6,792W 8900.00 83.18 290.43 4119.66 5823.38 -3414.72 6020462.51 548711.12 70 28 0.141N 149 36 8,142W 8950.00 87.68 288.24 4123.64 5839.87 -3461.74 6020478.68 548663.99 70 28 0.303 N 149 36 9.524W 9002.77 92.44 285.95 4123.59 5855.38 -3512.16 6020493.83 548613.47 70 28 0.455 N 149 36 11.006W 9100.00 92,44 285.95 4119.45 5882.07 -3605.56 6020519.87 548519.89 70 28 0.717 N 149 36 13.752W 9200.00 92.44 285.95 4115.19 5909.53 -3701,63 6020546.65 548423.64 70 28 0.987 N 149 36 16.576W 9300.00 92.44 285.95 4110.94 5936.98 -3797.69 6020573.43 548327.40 70 28 1.256 N 149 36 19.400W 9400.00 92.44 285.95 4106.68 5964.44 -3893.75 6020600.20 548231.16 70 28 1.526 N 149 36 22.224W 9500.00 92.44 285.95 4102.42 5991.89 -3989.81 6020626.98 548134.91 70 28 1.795 N 149 36 25.048W 9540.19 92.44 285.95 4100.74 6002.94 -4028.42 6020637.76 548096.24 70 28 1.904 N 149 36 26.183W 9550.00 92.39 285.36 4100.33 6005.59 -4037.86 6020640.34 548086.78 70 28 1.930 N 149 36 26.460W BP Amoco Planning Report- Geographic Company: BP Amoco Date: 1/25/2001 Time: 18:43:22 Page: Field: Milne Point Co-ordinate(NE) Reference: Well: MPJ-14, True North Site: M Pt J Pad Vertical (TVD) Reference: MPJ-14 64.12 64.1 Well: MPJ-14 Section (VS) Reference: Well (0.00E,0.00N,313.47Azi) Wellpath: Plan MPJ-14L1 Plan: MPJ-14L1 wp03 Survey Map MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min ft deg deg ft ft ft ft ft 9600.00 92.15 282.37 4098.34 6017.56 -4086.36 6020651.97 548038.20 70 28 2.047 N 149 36 27.886W 9650.00 91.91 279.38 4096.57 6026.98 -4135.42 6020661.05 547989.08 70 28 2.140 N 149 36 29.328W 9700.00 91.65 276.39 4095.02 6033.84 -4184.92 6020667.55 547939.54 70 28 2.207 N 149 36 30.783W 9750.00 91.40 273.40 4093.69 6038.10 -4234.71 6020671.47 547889.72 70 28 2.248 N 149 36 32.247W 9780.35 91.24 271.58 4093.00 6039.42 -4265.03 6020672.58 547859.40 70 28 2.261 N 149 36 33.138W 9800.00 91.24 271.58 4092.57 6039.96 -4284.67 6020672.98 547839.76 70 28 2.266 N 149 36 33.715W 9900.00 91.24 271.58 4090.41 6042.72 -4384.61 6020675.04 547739.81 70 28 2.293 N 149 36 36.652W 10000.00 91.24 271.58 4088.25 6045.47 -4484.55 6020677.09 547639.87 70 28 2.319 N 149 36 39.590 W 10100.00 91.24 271.58 4086.08 6048.23 -4584.48 6020679.15 547539.92 70 28 2.346 N 149 36 42.527W 10200.00 91.24 271.58 4083.92 6050.99 -4684.42 6020681.21 547439.98 70 28 2.372 N 149 36 45.465W 10300.00 91.24 271.58 4081.75 6053.74 -4784.36 6020683.27 547340.03 70 28 2.399 N 149 36 48.403W 10400.00 91.24 271.58 4079.59 6056.50 -4884.30 6020685.32 547240.09 70 28 2.425 N 149 36 51.340W 10500.00 91.24 271.58 4077.43 6059.26 -4984.24 6020687.38 547140.14 70 28 2.452 N 149 36 54.278 W 10600.00 91.24 271.58 4075.26 6062.01 -5084.18 6020689.44 547040.19 70 28 2.478 N 149 36 57.215W 10700.00 91.24 271.58 4073.10 6064.77 -5184.12 6020691.49 546940.25 70 28 2.505 N 149 37 0.153W 10800.00 91.24 271.58 4070.93 6067.53 -5284.05 6020693.55 546840.30 70 28 2.531N 149 37 3.090W 10900.00 91.24 271.58 4068.77 6070.28 -5383.99 6020695.61 546740.36 70 28 2.558 N 149 37 6.028W 11000.00 91.24 271.58 4066.61 6073.04 -5483.93 6020697.66 546640.41 70 28 2.584 N 149 37 8.965W 11100.00 91.24 271.58 4064.44 6075.80 -5583.87 6020699.72 546540.47 70 28 2.610 N 149 37 11.903W 11200.00 91.24 271.58 4062.28 6078.55 -5683.81 6020701.78 546440.52 70 28 2.637 N 149 37 14.840W 11300.00 91.24 271.58 4060.11 6081.31 -5783.75 6020703.83 546340.57 70 28 2.663 N 149 37 17.778W 11400.00 91.24 271.58 4057.95 6084.07 -5883.69 6020705.89 546240.63 70 28 2.689 N 149 37 20.715W 11500.00 91.24 271.58 4055.79 6086.82 -5983.62 6020707.95 546140.68 70 28 2.716 N 149 37 23.653W 11600.00 91.24 271,58 4053.62 6089.58 -6083,56 6020710.00 546040.74 70 28 2.742 N 149 37 26.590W 11700.00 91.24 271.58 4051.46 6092.34 -6183.50 6020712.06 545940.79 70 28 2.768 N 149 37 29.528W 11800.00 91.24 271.58 4049.29 6095.09 -6283.44 6020714.12 545840.85 70 28 2.795 N 149 37 32.465W 11900.00 91.24 11951.53 91.24 271.58 4047.13 6097.85 -6383.38 6020716.17 545740.90 70 28 2.821 N 149 37 35.403W 271.58 4046.12 6099.39 -6434.88 6020717.35 545689.39 70 28 2.836 N 149 37 36.917W Targets · .. " ' Map .Map <--- Latitude ----> <--- Longitude -->. Name Description ' TVD · '+N/-S +E/-W Northing Easting Deg' Min..Sec Deg Min Sec: ft ft ft ft :' ft MPJ-14L1 Tla 4095.00 5853.16 -3506.22 6020491.65 548619.42 70 28 0.433 N 149 36 10.832 W MPJ-14L1T2a 4093.00 6039.42 -4265.03 6020672.57 547859.40 70 28 2.261N 149 36 33.138 W MPJ-14L1 T3a 4046.12 6099.39 -6434.88 6020717.36 545689.40 70 28 2.836 N 149 37 36.917 W Alaska Oi~ & GaS Cons. comm'~ssio~ Anchorage DATE I CHECK NO. VENDOR ALASKAO I LA OD DATE INVOICE / CREDff MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122100M 100. O0 100. O0 PYMT :OMMENTS: Pee~ait to d~ill ~ee HANDLING INST: S/H - Sondea X4' HE ATFACHED CHECK IS IN PAYMENT FOR i~MS DESCRIBED ABOVE. ~[e]~!lm ~ 1 OO. OD 100- O0 ~:. :,BP.EXPLORATION (ALASKA)~. INC.., i:,::~ ?~.o;::::~b::x,,,1966,12 ?!'::~':.,:~?~;:~,:~: :.::~.,:,: :,, 'AN~:HO~AG~E;!:A~S~i!: 99519-6612 :FI..RST N. ATIO~E,iBAN~ :~F ASHJ~AND '::.:~NA~ION~::plTY,:B~K ," ' ~' :.-' :CEEVELA~D, OHIO ' ' :, 412 PAY OIL AND:?0AS"~:'.:.;,,. :, ~:~:'iCONS~R VAT I ON,: ",C ~M~i SS I ON' :'.~:..;:333 :.~EsT 7TH '";'~ENUE?;:' :' iHu~RE6;i; &',~ ;i~./! 00..'~'****-~*~*~"*:********.~,.~:*~:**:.~* ~" DOLLAR ?~::~:,:,:: ...... ' ~,'.';,'.:::':::'~:;' :,,:, ,.,.,DATE . NO~NALID A~ER 120 DAYS ,' ............... ANCHORAOE AK 99501 , , WELL PERMIT CHECKLIST FIELD & POOL -~--~---~/~"'(~ INIT CLASS ~)~'L,/' ,,~)/~..... ADMINISTRATION 1. Permit fee attached:~.'.. .... :, .............. 2. Lease number appropriate. ~.,~/".~.'~;,./~.- :~,~// 3. Unique well name and number .................. A~ DATE WELL NAME-,=/ '/5//_ / PROGRAM: exp dev EOL ENGINEERING 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can.be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... , , v" redrll serv wellbore sag v/ ann. disposal para req UNIT# 4~),//..-~)~~ ON/OFF SHORE (~,/-~' Y N ,' Y N ' ~" ._ GEOLOGY A~ DATE /.,..,.- ANNULAR DISPOSAL35. APPR DATE 22. Adequate wellbore separation proposed ............. Y N 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... .(~ N. . 25. BOPEs, do they meet regulation .......... __. ..... (.~ N -- A . ~. _ ,-.. , . 26. BOPE press rating appropriate; testto ~O~,L..~ psig. ~ N '~l~C-~> ~-~c_,?~:~ ~ \--~-~.~ ~:~ ~ . 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N - · 28. Work will occur without operation shutdown ........... ' ~Y(~),~. -- ' '- ' %-"" ',xJ ~ ~,, I _, 29. Is presence of H2S gas probable Y ................. _~- , / ~ ., -/T'¥ , .~',./ .. ~ '~¥ -'7'_. ~ ... .,,.~ (J-i~/ ' 30. Permit can be issued w/o hydrogen sulfide measures ..... Y(_.~' dZ.c:~ ~ ~ ¢:~~.'~"~ '~-"~,/~ 7~f~ ~:~,/-/~,. ,,,,~ 31. ~Da!a p. resen!ed on.po, tent/al overpressure zones ....... (~.N 32. ~e~sm,c analysis ot snallow gas zones ............. 33. Seabed condition survey (if off-shore) ........... _:..../U/'~ Y N ' " ' ~ ' ' 34. Contact name/phone for weekly progress reports [ex~g~a'tory only] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the Well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E). will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: ' Z .-I -l- rrl c:\msoffice\wordian~iana\checklist (rev. 11/011100)