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Home My WebLink About197-121Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [3 Maps: Grayscale items: [] Poor Quality Originals: [] Other: [] Other. No/Type TOTAL PAGES: 3 ~ NOTES: ORGANIZED BY: BEVERLY BREN~)SHERYL MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing PROOFED BY: BEVERLY BREN(~SHERYL MARIA By: Date: SCANNED BY: BEVERLY BR~ SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: PAGES: Quality Checked (done) Rev I NOTScanned.v4xl ALASKA OIL AND GAS CONSERVATION COMPreSSION TONY KNOWLES, GOVERNOR 333 W, 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 6, 2001 Fritz Gunkel, Manager Drilling BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Cancelled or Expired PTD's. Dear Gunkel: The Alaska Oil and Gas Conservation Commission ("AOGCC") approved the following referenced permit to drills. The AOGCC has a long-standing policy of releasing cancelled or expired permits two years from the date the application was approved by the AOGCC. The following files are scheduled to be released October 1,2001. Permit to Drill No.'s' 97-047 98-019 99-002 97-056 98-050 99-009 97-082 98-135 ,.. 97-090 98-154 97-100 98-155 97-121 98-164 97-159 98-167 97-191 98-177 98-210 98-211 ..... 98-223 98-236 98-257 98-261 Sincerely, Executive Secretary Memorandum Re: State of Alaska Well File: C~f'~ _. ~{~..\ DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission This memo will remain at the from of the subject well fie. 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 the treatment of these kinds of applications for permit to ddll. 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 remair, unchanged. The APl number and in some instances the well name reflect the number of preexistin(, reddiis and or muitilaterats 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 ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95 The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the AP! numbering methods descnbed in AOGCC staff memorancium "Multi-lateral (wetlbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician A~a.~~k.~ea red rvices rilling To: Alaska Oil & Gas Conservation Commission Date: January 28, 1999 From: Subject: Terrie Hubble Technical Assistant Permit To Drill #97-121, MPG-14 Please cancel the Permit to Drill for this well (50-029-22783). It is not economic at this time to drill it. Thank you. /tlh TONY' KNOWLE$, GOVEFtNOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 31. 1997 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit MPG- 14i BPX Exploration (Alaska) Inc. Permit No. 97-121 Sur Loc.' 2015'NSL. 3446'WEL. Sec. 27. T13N. R10E. UM Btmhole Loc.: 2844'NSL, 4648'WEL, Sec. 22. T13N, R10E. UM Dear Mr. Stoltz: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated June l 9. 1997. are in effect tbr this revision. Chairman BY ORDER OF THE COMMISSION dlffEnclosures Department of Fish & Game. Habitat Section W/o encl Department of Environmental Conservation w/o encl ----.. STATE OF ALASKA --~ ALASK. , OIL AND GAS CONSERVATION CL,,,IMISSION PERMIT TO DRILL 20 AAC 25.005 REVISED: 07/16/97 la. Type of work I~ Drill [-I Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil! [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 21 Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 59' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025516 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2015' NSL, 3446' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 2343' NSL, 4549' WEL, SEC. 22, T13N, R10E, UM MPG-14i At total depth 9. Approximate spud date Amount $200,000.00 2844' NSL, 4648' WEL, SEC. 22, T13N, R10E, UM 07/20/97 ,,, i21 DiSt~n'~'~ to nearest property line'113. Dista'nC~ to nearest well ..... 14'. Number 0~ acres in property 15. Proposed depth (MD and TVD) ......A...DL 315848,....632' ..1 ,NO Close Approach .... 2560 8621' MD/.4429' TVD ....... 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) Kick Off Depth 400' Maximum Hole Angle 79.42° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade coU'l~iing 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.) 8-1/2" '-~ 7" 26# L-80 BTC-Mod 8590' 31' 31' 8621' 4429' 1077 sx PF 'E', 219 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 M D TVD Structural Conductor Surface '~i ,~ Intermediate ~6~,, ~. Production -- Liner ~ ~ L ~, '~' '~ ~'~ -. Perforation depth: measured ~~~[~l~i~ ORIGINAL true vertical 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: ~rofka, 564-4809 Prepared By Name/Number: Kathy Campoamor, 564-5122 / 21. I hereby certify that t~ foCgoing is~f/e~¢/C~o/ect to the best of my knowledge Signed Jr //~ /'1 ~ /__ // /~-~ . ~.~y'.. Chip Alvord ~'//~ J.~l,/'/,~ /~ Title Senior Dri!ligg Engineer Date ~r- % Commission Use Only ,,, pe'rmi't"N~lber ..... I Apl Numb~'~ ....... I ' ' See cover letter 97-121 ........... 50-029~22783 ............ 06/19/97 .... for other requirements Conditions of Approval: Samples Required I-lYes ~'N'~ ......... Mud Log Required []Yes [~'No Hydrogen Sulfide Measures []Yes []No Directional Survey Required ,[~Yes [] No Required Working Pressure for BOPE I~2M; F"I3M; [-15M; I-I10M; F"I15M Other: dnglnal Signea By by order of '~.. c~/_.. Approved By Oavid W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark J. Brofka I MPG-14i Well Plan Summary ISCHRADER BLUFF INJECTOR 564-4809 ISurface Location: Tar~let Location: Bottom Hole Location: 2015 FSL, 3446 FEL, S27 T13N RIOE UM 2343 FSL, 4549 FEL, S22 T13N R10E UM 2844 FSL, 4648 FEL, S22 T13N R10E UM I AFE Number: 1337084 I I Rig: I Nabors22E I Estimated Start Date: 12o July 97 I I Operatin~ days to complete: 16 I MD: I I ITvD: 14,429' I I KBE: 159.0' I Well Desitin: I Schrader Bluff Injector Formation Markers: R~E(~FIVED Formation Tops MD TVDSS TVD (bkb) KOP 400 341 400 JiJL_ 1 '? ~nn'7 Base of Permafrost 1819 1725 1784 . . i,~,~ TOp of Ugnu 6897 3459 3518 ~as_E~ .iD.il & Gas Cons. ~omiTl~S~ Top M Sand 7585 3713 3772 , , ~nr. hnrnncJ Top NA (Target) 7596 3944 4003 Top of Schrader Bluff Sand; (~'~-~pg) NB 8008 3977 4036 NCND 8047 4002 4061 NE 8089 4029 4088 NF 8165 4078 4137 OA 8217 4111 4170 OA4 8268 4144 4203 OB 8326 4281 4240 Top of Seabee 8370 4209 4268 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 8621 4370 4429 TD at 250' MD past base of Schrader Casing/Tul: in~l Program: Hole Size Csg! Wt/Ft Grade Conn. Length Top Bottom Tbs O.D. MD/TVD MDrrVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 8590' 31'/31' 8621' / 4429' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT re¢ MWD from surface to TD LWD (GR/Resistivity/Neutron Density) from top of Ugnu to TD with a controlled drilling speed of no more than 180 ft/hr through the Ugnu and Schrader Bluff intervals from 6,898-8,621' MD. A MAD pass will not be performed on this well. NONE GR/CCL and USIT by the completion rig) uired for this well. MUd Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 20 10 20 9.5 6 ~ (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. A CompletionNVorkover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: i KOP: 1400' MD Maximum Hole Angle: Close Approach Well: t9.420 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP G-14i Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and function test 20" diverter. Build Spud Mud. 5. Drill 8-1/2" surface hole as per directional plan to 8621' MD / 4429' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Neutron Density from the top of the Ugnu to TD, or 6898' to 8621' MD. NOTE: Fill hole with mud and check riser for leaks before spudding in. NOTE: Short trip no deeper than 300' md past the base of permafrost. NOTE: Utilize lubricants as necessary to enhance sliding performance. NOTE: The well will require two insert bits. Drill no deeper than the top of the Ugnu with the first bit, then POOH for a bit change, new MWD tool, and to pick up LWD tools. NOTE: Drill at a controlled rate of no more than 180 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 6. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 7. POOH and LD BHA. 8. Run and cement 7", 26#, L-80, BTC-Mod casing with centralizers appropriately placed as per program. 9. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. Displace STAGE1 cement with seawater at 7.0-8.0 bpm. NOTE: Reciprocate pipe while pumping cement if possible/practical. After opening the ES cementer, circulate seawater a minimum of 2 hours before pumping the STAGE2 cement slurry. Displace the second stage with diesel. 10. N/U FMC Gen 6 Wellhead and Tree. Note that MPG-14i will have 3-1/2" tubing. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-14i. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-14i. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drilling Concerns Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8., Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-14i 7" SURFACE/INJECTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: - 80°F SPACER: 50 bbis fresh water spacer (1307' in 7" casing). STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER' 11.63 gal/sk 377 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6353' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 50% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk), FLOCELE (0.1 #/sk) WEIGHT: APPROX #SACKS: FLUID LOSS: 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 219 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (8621' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6353' MD) + 50% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 700 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/- 350% EXCESS IS EXPECTED FROM THE ES CEMENTER (2050' MD) TO SURFACE. NOTE THAT 100 SACKS WILL BE IN THE 20" x 7" ANNULAR SPACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - one (1) per joint on the bottom forty-six (46) joints of 7" casing (46 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also 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 7.0-8.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is no.~t necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 50% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 50% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: The slurry volume is calculated to cover from the ES cementer to surface with an excess of 350% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry will be pumped until cement returns are seen at surface. Note that approximately 100 sacks will be required just to fill the 20" x 7" annular space. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. Ensure that the seawater has been treated with biocide and is relatively "bug-free." 2. After bumping the plug, quickly check to ensure that the floats aro holding and then shear the ES cementer to the open position. 3. Cimulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns aro seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for rouse on another well. Anadrtll SchLumber~er Alaska Pistrfet 1312 East 80~h Avenue Anchora~e, AK 995LB (907} 349-4Sll ~ 344-2360 D[R~CTIONALW~:LL PLAN for SKARRD SER~CHS DRILLINO Well ......... Pield ........ : M£lne Point, O-Pad Com~utatioa..: Minimum Curvature Units ........ Surface Surface bong,: 149.53368098 W Legal Description Surface ...... = 2015 PSi 3446 FHD S27 T13N R10E UM Tar~et ....... : 2343 PSi 4549 PR~ S22 T13N R10E U~ BHL .......... : 2844 FSL 4648 FBi S22 T13N R10E UM LOCATIONS - AhASKA ~one: X~Coord 557L56.65 556000.00 555896.97 4 Y-Coord 60L4450.44 6020050.00 6020549.39 PROPOSHD WKhh PROFIhH STATION MEASURED [HCL~N DIRHCT30N IDHNTI~ICAT£ON DH~ ARGI~ AZ£M~H KB 0.00 0.00 O.O0 KOP/BUXLD 3/100 400.00 0.00 0.00 500.00 1.00 348.77 600.00 2.00 348.97 BUILD 1,S/ZOO 900.00 3-00 348-79 m~mmmmmmmmmmm V~RT£CAL-D~PTHS TVD SUB-SHA 0.00 -59,00 400,00 34i.00 499.99 440.99 599-96 S40.96 699.86 640.86 mmmmmmmm D~PA/~T 0 .O0 0.00 0.8~ 3.49 7.85 Prepared ..... : 16 JuL 1997 Vert sect az.: 348.78 KB e~evation.~ 59.00 f~ Magnetic Dcln: +28,03~ (~) ScaLe Factor.: 0.99990371 OonYergence..~ +0.4394370 OOORDINATBS -FROH ~SLJ.,HSRD 0.00 0.00 0.86 3.42 7.70 i i, _1, ~m · _ L ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ~ .-.,'.,. ,~,,~, mmmm u==~ A~d~SKA Zone 4 TOOL Db/ X Y FACE 300 0.00 H 557~6.6~ 6014~$0.44 HS 0.00 0.00 H ~57L56.6~ 60344~0.44 11~ 0.00 0.17 ~ ~59L~6.47 601445L.29 11L 1.00 0.68 # 557155.94 6034453.86 31L 1.00 3.~ ~ S~715~.06 6014458.I3 ~1~ 1.00 nUILD 2/100 800.00 4.S0 340.77 900.00 6.00 348.77 LO00-O0 7-50 348.79 1LO0.O0 9.50 348.97 1200.00 IL.50 348.77 799.65 740.65 899.22 840.22 998.53 939.53 1097.42 1038.42 1195.74 1136.74 L4.39 23.54 35.30 50.08 68,30 14.12 23.09 34.62 49.12 66.99 2.80 N 557153.74 6014464.53 llL 4.59 ~ 557151.89 6014473.~9 HS 1.50 6.88 ~ 557349.5l 6014485.00 HS 1.50 9.75 ~ 557346.52 6014499.~0 HS 2.00 13.30 # 557342.83 60145L?.32 H~ 2.00 · I 1300.00 13,50 348.77 14O0.0O 15.50 348.77 (AnadrLL1 (c] 97 MPG14P04 ].0C 9:18 AM P) i293.3'7 ~.34.37 L390.L6 1331.18 89.94 114.98 88,22 112,78 N ~9.52 N 557138.46 6014538.51 HS 2.00 22.40 N 557133.39 6014563.03 HS 2,00 MPG-14 (P04) 16 Jul £997 E>age 2 STAT XON M~D ~NCLN IDH~IPI~TION DH~ ~LH L~O0,O0 1~,S0 L600,00 19,50 1700.00 2L,~0 P~F~ST 1818, ~7 23.28 aUrL,D 3/300 Z 1849.00 23.28 1900.00 24.81 2000.00 27.81 2100.00 30.81 2200.00 33.81 2300.00 36.81 2400.00 39.81 2500.00 42.8l 2600.00 45.8L 2900.00 48.8L 2800,00 51,8L 2900,00 S4,8L 3000.00 57,8L 3100,00 60,B/ 3200.00 63,81 3300.00 66.81 3400.00 69.83 3500,00 ~2.81 3600.00 75.81 3900,00 98,81 HND 3/~00 BU]bD 3920.29 79.42 TOP UGNU 6897,8l 79.42 CURVH 3.5/100 6919.23 79,42 PROPOSED WHLL PROPI]L~ DIRECTION VIIRT ~CAL- DH ~:~THS AZIMUTH TVD SUB- SHA 348.77 1486,O6 ~427.06 3~8.77 1580.88 ~521.88 348.77 16~4.55 1615.55 348.97 1756.83 1697 348.99 1784.00 1725.00 348.77 L8LL.95 1752.95 348.77 1858.52 L799.$2 348,77 1948.~5 ~889,15 348.77 2035.34 1976.34 348,77 2LL9.85 2060.85 348.77 2202.44 2142.44 348.79 2279:90 2220.90 348.77 2355.01 2296.01 348.77 2426.56 2367.56 348~7 2494.3~ 2435.3~ SECT I ON Dt~PA~T m m mmmatam'm m 2L0.13 24 ~. 03 255 267.74 288,52 332,84 38L,78 435,23 493.02 555.01 62L.01 690.86 764.35 COORDiNATES-PROM W]~LHHAD X Y PACH 140.63 N 27,93 W 5~?127.65 6014590.84 TLS 171.75 N 34.11 W SS?~21.23 60~4621.93 ~S 206.10 N 40.93 N 557114.14 6014656.20 ~S 239.35 N 47.53 W 557107,29 6014689.40 ~S 250.82 N 49.81 W 557104.92 6014700.84 8S AI,A,~KA Zone 4 TOOL 2,00 2,00 2.0O 2.00 0,00 262.61 N 52.15 W 557102.49 60~4732.62 282.99 N 56,20 W 55'/098.28 6014732,97 326-46 N 64,83 9t 55'/089.32 6014776.36 374.47 ~1 74,37 91 557079.42 6014824-29 426.89 N 84,78 W 557068.61 6014876.63 483.58 544.37 609.12 677.62 749-71 348.97 2558.21 2499.21 84~,29 825,18 348.99 2617,95 2058.95 921.47 903.82 34~.77 2673.4~ 2614.41 1004,67 985.42 348.77 2724.45 2665,4~ 1090,65 L069.76 348.97 2770.91 271~,9£ ~9,19 1356.60 349.77 2812.68 2753,68 1270,04 3245.71 ,. 348.77 2849.63 2790.63 1362.95 1336.84 348,77 R881.67 2822.67 14~7.66 1429.74 348,77 2908.71 2849.'// 1~53.93 1524.16 348.77 2930.68 2871.68 1671.47 1619.84 348.77 2934.51 2895.51 167L.40 1639-38 348.'7'7 35L8.00 3459.00 4794.88 4703.03 348.77 352L.93 3462.93 4815.94 4'/23.68 0.00 3.00 3.00 3.00 3.00 96.04 W 557056.92 6014933.22 ~S 3.00 108.LL W 557044.38 6014993.92 AS 3.00 120.97 W 557031.02 6015058,55 ~S 3.00 134.58 W 557016.89 6015126.97 ~S 3.00 148.89 W 557002.03 60~5~98.91 HS 3.00 163.88 H ~56986.46 6015274.26 HS 3.00 179,S0 W S5697~.24 6015352.7q RS 3.00 ~95,70 W 556953.41 6035434.24 H9 3.00 2~2.45 W 556936.0Z 60~5518.44 Hg 3.00 229.70 ~ 556918.11 6015605.~4 HS 3.00 247.40 W 556899.73 6015694.30 HS 3.00 265.49 W 556880,94 6015785.08 KS 3.00 283.95 W 556861,78 60158'/?.82 HS 3.00 302.70 W 5~6842,30 6015972,09 ~S 3.00 321.'/0 W 556822.59 6016067.61 ~L~ 3.00 325.58 W 556818.54 60~6087,12 }Lq 3.00 934.02 W 556186.69 60191~5.72 HS 0.00 938.12 W ~56182.42 6OL9~66.34 LS 0.00 "0 i1-1 (AnadrilL (c) 97 M.PGL4P04 3.0C 9:18 AM P) STATION [DENTZFICAT2ON ~ mmmmmmmlmmmmmmm~ I~AS13R~D ~NCLN DRg'L'"4 ANOLB 7000.00 76.59 9100.00 73.09 9200.00 69.59 7300.00 66.09 ~400.00 62:59 7500.00 59.09 TOP ~ SAND 7584.8L 56.12 7600.00 55,59 7.700.00 52,O9 EHgD 3.5/L00 CURVE 7756.L7 5~,~3 DZR~CT£ON %q~RT~CAL-D~PTHS AZIMUTH TVD SUB-SBA 346.7~ ~538,72 3479.72 348.77 3564,66 3505.86 3~8.77 3596.85 3537,85 3~8.77 3634.56 3575,56 348.77 3677.85 36~8,85 S~CT£0N DB~ART 4894,94 4991.4~ 5086,17 5178,77 ~268.90 348.78 3726.5~ 3667.57 $356.2L 348.78 3772.00 3713.00 5427.82 348.78 3780.52 372L.52 5440.39 348.78 3839.52 3780.52 5521.~2 346.98 3874.78 38L5.98 5564-63 CO0]~D~NATRS-~ROM ALASKA Zone 4 T00~ DL/ W~LHHAD X Y PACH 100 480L.17 N 953.S~ N 556L66.44 60k9243.70 bS 3.50 4895.83 N 972.30 W 556[46,92 6019338.20 L8 3.50 4988.75 N 990.$5 W 55612~.77 6019430.96 LS 3.50 5099.57 N 1008.78 W 556109.04 601952[.64 LS ~.50 5167.97 N 1026.33 W 556090.82 6019609.89 LS 3.50 5253.62 N ~043.32 W 556073.17 6019695.40 ~S 3.50 5323.86 N ~057,26 ~ 556058.70 60L9765.52 ~ 3.50 5336.19 N ~059,70 W 556056.16 60L9777.83 ~ 3.50 54LS.37-N 1075.41 W 5560~9.84 60L9856.88 L.9 3.50 5458.25 N 1083.92 W 55603~.01 6019899.69 HS 3.50 TAPJ]HT 7956.~? S0.k3 348.78 4003.00 3944.00 5718.32 5608.81 N 1113.78 TOP SC~H~ / }iA 7956.37 $0.L3 348.78 4003.00 3944,00 5718.32 5608.81 N 11~3.78 NB 8007.64 50.L3 348.78 4036.00 3979.00 5757.83 5647.56 N 112L.46 NC/i~D 8046.64 S0.~3 ~48.78 4061.00 4002.°0 5787.75 5676,91 N 1127.28 hie 8088.75 50.L3 348.70 4008.00 4029.00 5820,07 5?08.62 N 1L33.57 348.78 4L37.0~ 4078.00 S878.73 5766,L5 N ~L44.98 348.78 4~7D.0~ 4~31.00 5918.23 5804.90 N t152.67 348,78 ~203.00 4~44.00 5957.74 5843.65 N ~60.35 348.78 4240.00 418i.00 6002.03 ~887.~0 N 1368,97 348.78 4268.00 4209.00 6035.55 5919.97 N I175.49 348.98 4429.00 4370.00 6228.28 6L09.02 N ., 348.78 4429.00 4370.00 6~28.~8 6L09.02 N OA 8216,66 50.13 OA4 8268,13 50.~3 OB 8325.84 50.13 IRASB 8CKRA.DBR 8369,52 50.33 7" CASING POINT 8620,65 50.13 TD 8620.65 50.~3 (Anadrill (C)97 MpCI14P04 3-0C 9:18 APt ~) 556000,00 6020050.00 HS 0.00 556000.00 6020050.00 HS 0.00 555992.02 6020088.69 H8 0.00 555985.97 6020L~?.99 HS 0.00 555979.44 6020£~9,64 HS 0.00 555967.59 6020207,09 HS 0.00 555959.61 6020245,77 H8 0.00 555951.63 6020284.46 H8 0.0Q 555942,68 6020327.8~ HS 0.OO 555935,91 6020360.65 HS 0.00 3212.96 W 555896.97 6020549.39 0-00 3212.98 W 555896,97 6020549.39 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN ..%. Z .... SHARED' SER'VI'GES DRILl"IN6 '' II I I I I I I I I · iii ii II I I I II III · MPG- t4 (PO4) VERIICAL SECTION VIEW I I Il I I I [ I! [ TVD Scale,' 1 inch : 800 feet . Oep Scale,' 1 inch: 800 feet 400-- ~ , .... ,' Draun ' 16 Jut 1997 C m-- I I II BOO- . .......... Marker ~dent~f~cation MD BI(B 5ECTN 'INCLN t . A) }(B 0 0 0 0.00 0 ' B] KOP/BUILD ~/t00 400 400 0 0.00 1200- - ¢] BUILD ~.5/~00 700 700 B 3.00 ' ' O) BUILD 2/~00 tO00 999 35 7.50 · E} ENO 2/100 BUILD 17B§ 1757 244 23.2B F] BUILD 3/rOI) t849 ~B~2 26B 23.26 1600* . 61 END 3/100 BUILD 3720 2935 ~67~ 79,42 Fi) CURVE 3.5/100 6919 3522 48~6 79.42 ...... 2000- ' ' J) TARGET 7956 4003 57~8 50.~3 ' ' · K) 7" CA$I~ POINT 662~ 4429 6228 50.~3 ~~' L) TO 862~ 4429 6228 50.~3 . 2400 .... ' ^ '" ,--,,~ qDRII. L ' AK,~ .DPC OVEtD C/~D 2800 ........ OI, ILY '~~~~ ~ PI ~ki ~ .,.~, ~2oo .... 3600 'f~-un¢' ~t~ ._ ~ ................. 't '~~ 'T~"H'~/~k¢'~/~ .................................................. ::::_- ................ _. ::::::::: ,: :: !_-__-:_ = :::::: : ::::: :_- ..... .=~-~:.:'- 4400 ........... L '~' K 4800 · 0 400 800 I,~?00 '1600 2000 ;2400 2800 3;:'00 3600 4000 4400 4800 5200 5600 6000 6400 61100 Section Depa, rtu, re II I II I II I · · (An~r~]i (c)97 I~I~G~ 3.01: 9:18 ~ld P) z i1~ i iii Ii i iiii SHARED SERVTCES' i Marker Iden[ification MD BXB SECTN .INCLN A) fABGET ?956 4003 57i8 50.i3 B) 7" CASING POINI 6621 4429 6228 50.13 C) TD BG2t 4429 6P_28 50.13 DRILLING Anadr.i ] ] ,.,Cch]umberger i i MPG- 14 (PO4) VERTICAL SECTION VIE~ i ! Section at: 3,48,78 ........ l~~ mm'i .... D Scele,: ~ tach: ~00 feet ~Dep Scale.: ~ inch = ]00 leer ,, , ir~a~n, ..... : ~fi, oul aox7 ,, , .... ,~1,,,,.~... ~ a,¢,,,,~.~,.,~. .~ - ~ ....................... ~ .... - ' ' , '- ' ................ ~kll m. '~ " ~N ~"~' ..... ~4- -~, ' ,, . ,... . .. .. , . 5500 5550 5500 5650 5700 5750 5800 ~0 5900 5950 6000 6050 6t~ 6150 6200 6250 6300 6350 6400 Sect ion (Cig'/1~6t4~4 3.(X; 9:~ M Pi ]> z ! .....SHARED SERVICES ~'RILLIN6 I ..,-,..r ,,',..,,,,~,,,,, '"0 "/~ ~'" MPG--'I 4 (P04) A] KB 0 0 N 0 E ~1 ~o~/~u~o u~oo 400 o, o ~ ~ PLAN V I EW E) END 2/100 BUILD t789 2~9 N 4B W CLOSURE ' 6228 feel at Azimuth 348.77 F) BUILD 2/~00 18~9 263 N 52 W G) END ]/100 BUILD 3720 ~63e N 326 W DECLINATION.' +28.031 (E) H) CURVE 3.5/t00 6§t9 4724 N 938 W SCALE ' ~ inch : 1000 feet I) END 9.5/i00 CURVE 7756 5458 N t08~ W J) TARGET 7956 5609 N tt~4 W DRAWN. ' 16 Jul 1997 K) 7' CASING POINT 8621 6109 N 12~3 W . L) TO 862t 6t09 N 121~ W .... __ ~nadrY ]] SchJum~erger 6500 .......... ' .... 6008 .... .~ 5500 ~. ' ' ANI ,D[ILL A~,I~PC t~PPRI)VEE~ ~ooo FORPERIAITi lNG " ONLY .... "°° ~. '. J PLAN ~,~ 4000- 3500 , 3000 . 2500 . 8000 ~ . . t500 ~000 5OO , 3500 3000 2500 2000 1500 tO00 500 · 0 500 1000 1500 2000 2500 3000 3500 <- ~EST ' EAST -> iii i i i il i - (Anaarlll (c)g7 NPGI4P04 3.0= g: 2~ AM P) ID' MPU G-PAD G-7 · 0-6 I 0-5 m G-15 G-14 G-13 o-3 · ~O-ll G-2 · ¢ G-I t 2o<x) NoTEs' i; DATE OF'SURVEY: MAY 20, 1997. 2. REFERENCE FIELO BOOK: M.P97-O~.-.(PGSi 3. ALASKA STATE PLANE COOROINATES -. ARE ZONE 4, ALASKA, .NAD 27. ' 4. PAD :.SCALE FACTOR'. IS 0,9999031.- 5~ HORIZON:TAL/~/ERTICAL 'CONTROL .'IS BASED ON MPU G-PAD MONUMENTS. G'I' AND .G-2;- 6'. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L... MFtY 23'97 7:z16 No.O01 P.02/02 .- ~.,( '~!~ ~-.--./ ! \ ~,¢[~,.1 ~ PAD i i lB m i . .. i VICINITY MAP N.T.S. EXISllNG WELL CONDUCTORS. AS-BUILT WELL CONDUCTORS SURVEYOR'S CERTIFICATE I HEREBY CERTIFY' THAT. I AM. - PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN · THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A. SURVEY.. MADE BY ME .OR UNDER' MY DIRECT · SUPERVISION AND' THAT 'ALL DIMENSIONS AND OTHER. DETAILS' 'ARE. CORRECT AS OF MAY :20, 1997: .LOCATED WITHIN PROTRACTEO SEC; .27, T. 15 N.,' R. 10 E, UMIATi-MERIDIAN, ALASKA. 'WE~'L ' . .A.s.P; .-.. . 'PLANT '' GEO~)ETIC ' .GEODETIC: '.' GROUND SECTION NO.' cOORDINATES COORDINATES POSI'[I..ON(DMS) PO, SITION(D,,.DD)' ELEVATION OFFSETS ' · .'~ ' ' : .1,605':ESL G'g Y--6;014,04i:66'.' N' 2,170:07 70'26'56,'390~- 70.&489972'.' 29.2' · - X= '"557;264;59 E · 1-;184.'66. 149:51~.5...8.175" 149;5528258" :. · 3,342' 'FEL G, Io!Y= 6,014,1'00.85. N' 2,229.81 ' --70~6'56.973" '70:449t592':' '.29.2' 1,665' FSL X= 557,256.42' 'E '.1~185.1'0 '149'31.'58~.400"' !l~9.,532esBg'" .. .. 3,350' FEL ..... .' '1,724" FSL Y= 6,014,160.28 N 2,289;82 · 7.0'26"57;558" 70.44.9'3217~ '.29.3, G'll' X=:':'.557i248.29 'E 1,i85.42 14g;31'58.626"- ;.1.49.5329517''. 3,357.' FEE y='.6;014391:14 '..N :.2,530.21 70'26'59.835, '70.44995~.2" ... '29.6. · 1.956'..ESL G-13 X'=., 557,164~45.' .E' i,134.92 149'32'01~036" 149.5336211"... "· .. 3,439' FEL G-i'4 Y~-'6,014,450~4~- N 2;590.02: 'i 70'27'00.4i9" :' ?0.4.501.16~':.. · 2,015' FSL - X=': .'557:,156:.65 E 1,135.'55 149'32'01~25i" .14.9.5336808~- . .29.5' 3;446" 'FEL . G_1'5 Y".6,01~t,509.68; . N' 2,649;94' "'.';~)'27'01:002" · '.'70;~502783' 2,074' 'FSL X=-' 557,'147.69 E i,135:021149'32'01.501" :!,49.5337503' "29.8' 3,455"FEL 'I I- o~',,v,~:.. ST~U. '" c~x~O,.KH ' o^'~r~ - .5/22/97, UPUGAS&9 NO:. I",- 200° BP EXPLORATION UPU G-PAO AS-BUILT WELL CONDUCTORS WELLS 9, 10, 11, 13, 14 & 15 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19. 1997 Tim Schoficld Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ae~ Milne Point MPG-14i BP Exploration (Alaska), Inc. Permit No. 97-121 Sur. Loc: 2015'NSL.3446'WELSEC 27.TI3N.RIOE. UM Btmholc Loc: 3522'NSL.4781 'WEL.SEC 22.T 13N.R 10E. UM Dear Mr. Schoficld: Encloscd is the approvcd application for permit to drill thc above rcfcrcnccd xvcii. Thc permit to drill docs not exempt you from obtaining additional permits required by lax,,' from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. The blowout prevention equipment (BOPE) must bc tested in accordance xxith 20 AAC 25.035: and thc mechanical integrity (MI) of thc injection xvclls nmst bc demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI test before operation, and of thc BOPE test performed before drilling below thc surface casing shoe. must bc given so that a rcprcscntativc of thc Commission may v,'itncss thc tests. Notice ma',' be given bv contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairman xxx..x..~By ORDER OF ~COM MiSSiON dlf/Enclosurc CC~ Dcpamncnt of Fish & Game. Habitat Section xv/o cncl. Department of Environmental Conservation xv/o cncl. ~""-, STATE OF ALASKA .~ ALASKA OI,... AND GAS CONSERVATION COMN,.... }ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work C~] Drill E] Redrill ]lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [-I Re-Entry .~ De.epenI [] Service []...Development Gas [] Single Zone I-'1 Multiple Zone 2"i Name'"0f Op'~rator ................. 5. Datum Elevation (DF or KB) 10. Field a'n'd Pool BP Exploration (Alaska) Inc. Plan RTE = 59' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025516 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2015' NSL, 3446' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Wel'i Nurn'~er Number 2S100302630-277 2343' NSL, 4549' WEL, SEC. 22, T13N, R10E, UM MPG-14i Attotal depth 9; App~°ximate spud date Amount $200,000.00 3522' NSL, 4781' WEL, SEC. 22, T13N, R10E, UM 07/22/97 ~ 2. DiStance ~o nearest proPerty linel i3."'l~'i'~tance to nearest W~il 14."Number of acre~'"'in property 15. Pro~'osed depth (MD'and TVD) A.D...L..31584r.~, .4..9....9.' .I .... N°.Cl°se..A.....ppr0ach 2560 ..... 9149' MD / 43.19' TV.D 16. To be completed for deviated wells 1 '~. An~icipat~'~! pressure {see 20 AAC"~5.035 (e)(2)} Kick Off Depth 400' Maximum Hole Angle 75.28° Maximum surface 1400 psig, At total depth (TVD) 4000' / 1800 psig 18. Casing Program Setting Depth Size Specifications . Top Bottom Quan.tit¥ of Cement 'Hol~ ..... casing Weight Grade Cc;'~pl'ing "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.) 8-1/2" 7" 26# L-80 BTC-Mod 9118' 31' 31' 9149' 4319' 757 sx PF 'E', 222 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 M D TVD Structural Conductor Surface Intermediate LPirn°ed/ctiOnR E C E iV E a Perforation depth: measured ~aska Oil & Gas 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: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Carnpoamor, 564-5122 21. I hereby certify that the foregoingj, s tree an,d~qrrect to the besi of my knowledge Tim Schofield ............. Title......Senior. Drilling..Engin~er Date ....... // ................... Commission Use O,,n,,!,y.. ..... Permit N"~mbei ..... /~,'PI Nun~be'r" ' /~pprpVal"Date See cover letter ....... ~'~-/.2.,/,, I 50-02" ,/~,,- ~'~'~"'~ ~"~ I, tL~O~IC~ ,,, IfOr Other requirements Conditions of Approval: ~"amples Required ................ Ii'Yes J~No Mud Log Rec~uired BYes ~ No Hydrogen Sulfide Measures []Yes J~No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE J~2M; I-'I3M; r-ISM; [] 10M; I-'115M Other: Original Signed By by order of Approved By David W, Johnston Commissioner the commission Date ~ i~ Form 10-401 Rev. 12-01-85 Submit ~n T 'iolicate Shared Services Drilling Contact: I Well Name: IType of Well (producer or injector): Mark J. Brofka I MPG-14i Well Plan Summary ISCHRADER BLUFF INJECTOR 564-4809 Surface Location: 2015 FSL, 3446 FEL, S27 T13N R10E UM Tar~let Location: 2343 FSL, 4549 FEL, S22 T13N R10E UM Bottom Hole Location: 3522 FSL, 4781 FEL, 522 T13N R10E UM I AFE Number: I 337084 I Estimated Start Date: 1 22 July 97 I MD: ]9149' J I Well Desitin: Formation Markers: I Rig: I Nabors22E I Operatin~l days to complete: 19.0 I TVD= 14319' I I KBE= 159.0' 7" Schrader Bluff Injector Formation Tops MD TVDSS TVD (bkb) KOP 400 341 400 Base of Permafrost 1819 1725 1784 Top of Ugnu 5997 3459 3518 Top M Sand 6997 3713 3772 Top NA. (Target) 7906 3944 4003 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 8036 3977 4036 'NCND 8134 4002 4061 NE 8240. 4029 4088 ,, NF 8433 4078 4137 OA 8563 4111 4170 OA4 8693 4144 4203 OB 8838 4281 4240 Top of Seabee 8949 4209 4268 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 9149 4260 4319 TD at 200' MD past base of Schrader CaSin~l/Tub in~l Pro~lram: Hole ~ize ' Csg~ WEFt Grade Conn. Length Top Bottom Tb~l O.D. MD/TVD ,MD/TVD (bkb) 24" 20" 91.1# H-40 Weld 80' 32?32' 112' / 112' 8-1/2" 7" 26# L80 BTC-Mod 9118' 31 '/31' 9149'/4319' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4000' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1400 psi, well below the internal yield pressure rating of the 7" casing. RECEIVED dUN l 1997' 0ii & c0mmissi0. knch0m~0 .Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT re( MWD from surface to TD LWD (GR/Resistivity/Neutron Density) from top of Ugnu to TD with a controlled drilling speed of no more than 180 ft/hr through the Ugnu and Schrader Bluff intervals from 5997-9149' MD. ESS survey tool at TD to correlate with MWD surveys. NONE iGR/CCL and CBL by the completion rig) uired for this well. Mud Program: Spud Mud ISpecial design considerations See "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity , Point gel gel . Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 . . 15 30 10 . 8-10 (final) ... TOP OF SCHRADER BLUFF TO TD: J LSND. freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to ,, 9.3 80 20 10 20 9.5 6 (as required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4', 2000 psi W.P. Diverter with 10" Diverter Line. A Completion/Workover Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be used for the completion and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 400', Build and hold IMaximum Hole Angle: Close Approach Well: 75.28 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. In the event that the bridges are not usable due to breakup, all cuttings will be placed in the Milne Point A-Pad reserve pit. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. If the bridges over the rivers are not usable because of breakup, class 2 waste fluids will be hauled to the Kuparuk injection well and class 1 fluids will be transferred to storage tanks for future disposal after breakup. Annular Injection: No wells on G-Pad have been permitted for annular injection. MP G-14i Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. 5. Drill a 8-1/2" surface hole as per directional plan to 9149' MD / 4260' TVD. Run Directional MWD from surface to TD and run LWD GR/Resistivity/Neutron Density from the top of the Ugnu to TD, or 5997' to 9149' MD. 6. Keep the same BHA when tripping for the second bit. If tool problems are experienced, or battery life or operating hours are a concern, then replace the MWD or motor as deemed necessary. 7. Drill at a controlled rate of no more than 180 ft/hr through the Ugnu and Schrader Bluff sands to ensure good LWD readings. 8. At TD, make a wiper trip to the last bit trip depth and condition the hole, making sure to record any tight spots. 9. Before POOH, drop ESS survey tool at TD. (If two MWD tools were run while drilling, then the ESS will not be required.) 10. POOH and LD BHA. 11. Run and cement 7", 26#, L-80, BTC-Mod casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. 12. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) 13. MIRU completion rig. 14. N/U & Test BOPE. 15. Drill out ES cementer and clean out the well. 16. Run GR/CCL and CBL. 17. Perform completion job. MPG-14i will be an injector. 18. Complete well with 3-1/2" L~80, EUE tubing. 19. Set BPV. N/D BOP stack and N/U X-mas tree. 20. RDMO with completion rig. 21. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. 1. Hydrates: Hydrates have occurred on nearby E and H and there is a possibility that hydrates may be encountered in the drilling of MPG-14i. In the eight wells previously drilled on G-pad, only G-08 encountered gas, but only a minor amount and probably due to a small gas pocket rather than hydrates. If hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-14i. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concern~ Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. 8. Cement Because of the single casing string, the cement jobs will be critical to the success of the Schrader wells. Also, the relatively small 8-1/2" by 7" annulus will require extra attention to pump rates and pressures. Ensure that copies of all of the strip charts from the cement job are sent to the Operations Drilling Engineer. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-14i 7" SURFACE/INJECTION CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP: ~ 80°F SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: FLOCELE (0.25 #/sk) 12.0 ppg YIELD: 2.17 ft3/sk MIX WATER: 11.63 gal/sk 338 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNIJ "M" SANDS (6497' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 222 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30 mins @ 80°F FREE WATER: TAIL CEMENT FROM TD (9149' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6497' MD) + 30% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: TYPE 'E' PERMAFROST ADDITIVES: WEIGHT: APPROX #SACKS: Retarder 12.0 ppg 419 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/- 250% EXCESS IS EXPECTED FROM THE ES CEMENTER (2050' MD) TO SURFACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg APPROX NO SACKS~ 150 YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - two (2) per joint on the bottom fifty-seven (57) joints of 7" casing (114 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 6 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: Ist Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 30% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" San~ls to TD with 30% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: The slurry volume is calculated to cover from the ES cementer to surface with an excess of 250% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry will be pumped until cement returns are seen at surface. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E Will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for reuse on another well. RECEIVED Alaska Oil & Gas Cons. Commission Anadr£ll 8chlumbex~er 111L Eae~ 8Otb Avenue Anchorage, AR 99518 (907) 349-4511 Fa~ 344-2L60 DIRHCTIONAL WHLL PLA~ for SHARED SHRVICSS DR]L/,ING lqell ......... : MPG-14 (PO2) Field ........ : Milne Point, G-Pad Com~utation..: Minimum Curvature Units ........ : P~ST Surface Lat..: 70.45011626 N Surface bon9.: 149 . 53268098 W Lc~al Description Surface ...... : 20~5 ~SL 3446 FEL S27 T£2N RIOH UN Ta~et ....... : 2243 ~SL 4549 FgL S22 TL3N RiO~ UN B~L .......... : 2~29 ~SL 4781 FEL S22 T£3N R10H UN LOCATIONS - AIa%SKA Zone: X-Coord ~57156.6~ 556000,00 555'~56 . 87 4 Y-Coord 6014450.44 6020050.00 602~227.02 PROPOSED STATION M~ASLTR~D INCLN D~RECTION VHRTICAL-DHPT~S IDHNTIFICAT[ON DEPTH ANGL8 AZIMUTH TVD SUB-SEA ~ 0.00 0.00 0.00 0.00 -59.00 KOP/BU~LD 1/100 400.00 0.00 0.00 400,00 ~4~.00 500.00 1.00 348-77 499,99 440.99 600.00 2.00 248.77 599,96 540.96 BUILD 1.5/100 ?00.00 3.00 348.77 699,86 640.86 SBCTION DEPART 0.00 O.O0 O, 87 2.49 7.85 Prepared ..... : 09 Jun 1995 Vert sect az.: 348.$7 KB e~evat~on.: 59.00 f~ Magnetic Dcln: 428.045 (E) Scale Factor.: 0.99990371 Convergence..: +0.438 ;37G$ ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN , · _ ~, _,' _ _ , ALASKA Zone 4 TCX)b X Y FACE 100 0.00 N 0.00 0.00 N 0.00 0.86 N 0.17 3.42 ~ 0-68 7.7O N ].52 557156.65 6014450.44 55~156.65 6014450.44 557156.47 601445L.29 557~55.94 601445~.86 557155.06 6014458.13 HS 0.00 11L 0.O0 11~ 1.00 ~LL 1.00 LLL ~-00 BUZLD 2/zoo 800.00 4,50 348.97 900.00 6.00 348.77 1000.00 9.50 348.77 [~00.00 9.50 348.?~ [200.00 L3-50 799,65 740.65 899,22 840,22 998,53 939,53 £097.42 [038,42 1L95,74 1136,74 14,39 14.L2 N 2.80 W 23.54 23.09 N 4,59 W 35.20 34.62 N 6.87 W 50.08 49.12 N 9,75 W 68.30 66.99 N 13.3 0 lq 557153.74 60L4464.53 LlL L.50 557151.89 60L4473.49 }I~ L.50 557L49.51 60[4485.00 HS 557L46,52 60L4499.4~ HS 2.00 557L~2.84 60~45~7.32 HS 2.00 L300.O0 L3.SO k400,O0 L5.50 348.77 L293.37 1234.37 348.77 1390.L8 ~331.18 89.9i 1L4,98 88.22 N 112.78 N 17.52 W 557138.46 60~4538.51 HS 2,00 21.39 ~ 557533.39 6014563.03 HS 2,00 Z '13 "13 ITl (Anadrill (c)97 MPGliP02 3,0C 9:53 AM P) ~0 ~PO-t4(P02} PROPOSHD WBbb PROFILR 09 Jun ~997 Page 2 STAT ION IDENTIFICATION MEASURI{D ZNCL~I D~PTH ANUI.,H DIRRCT£ON VgRTICAL-DBPTHS AZIMUTH TVD SUB-SEA SECTION DEPART (IiX)RI] INAT RS -WRC~ : ASASKA Zone 4 TOOL Db/ X Y WAC~ £00 s~ 2/lOO SU~D BAS~ P~RMAI;ROST nvl L,D 3/t00 m,'D 3/t00 nuinn 1500.00 17.50 1600.00 19.50 1700.00 21.50 1789.00 23.28 £818.57 23.28 1849-00 23.28 1900.00 24.81 2000.00 27.81 2100.00 30.81 2200.00 33,81 2300.00 36.8£ 2400.00 39.81 2500-00 42.8t 2600.00 45.81 2700.00 48.81 2800.00 51.81 2900.00 54.81 3000.00 57.81 3L00.00 60.81 3200.00 63.81 3300.00 66.8£ 3400.00 69.8[ 3500.00 72.8£ 3582.27 75.28 5997.27 75.28 TOP N RAND 6996.77 75.28 TAI{GET 7905.77 75,28 TOP SCHP, ADRR / ~ 7905.77 75.28 348.77 1486.06 1427.06 348.77 £580.88 1521.88 348.77 1674.55 1615.55 348.77 L756.83 1697.83 348,77 1784.00 1725.00 348.77 1811.95 1752.95 348,77 1858.52 t799.52 348.77 1948.15 L889.]5 348.77 2035.34 1976.34 348,77 2119.85 2060.85 143 .38 175.11 210.13 244.03 255.7]. 267.74 288,52 332,84 381.78 435,23 140.63 N 17L.75 N 206.10 N 239.35 N 250.82 N 262.61 282.99 326.46 374.47 426,89 348.77 2201.44 2142.44 493,02 483-56 348.77 2279.90 2220.90 555.01 544.38 348.77 2355.01 2296.O1 621.01 609.12 348.77 2426.56 2367.56 690.86 677.63 348.77 2494.35 2435.35 764.35 749.71 348.77 2558.21 2499,21 841-29 825.18 348.77 26/7.95 2558.95 921.47 903.83 348.77 2673.4£ 2614.4£ 1004.67 985.43 348.77 2724.45 2665.45 1090,65 1069.77 348.77 2770.91 2711.91 1179.19 L156.61 ]48.77 2812.68 2753.68 1270,04 Z245.72 348.77 2849.63 2790.6~ 1362.95 Z336.85 348.77 2881.67 2822-67 1457.66 1429.75 348.77 2904.29 2845.29 1536.76 1507.]3 ]48_77 3518.00 3459.00 ]872.48 3798.3£ 348.79 3772.00 37L3.00 4839,17 4746.49 348.77 4003.00 3944.00 5718.32 5608.8l 348.77 4003.00 3944-00 5718.32 5608.81 27.93 W 557L27.65 6014590.84 HS 2.00 ]4.LL W 657121-23 60t4621,91 HS 2.00 40.93 ~ 557£14.15 60/4656.20 [iS 2-00 47.53 W 557107,29 6014689.40 HS 2.00 49-81 W 557104,93 6014700.84 H$ 0.00 52.15 W 557102.49 6014712.62 HS 0.OD 56.20 W 557098.29 6014732.97 RS 3.00 64.83 W 557089.33 6014776.36 HS 3.00 74.36 W 557079.43 6014824.30 HS 3.00 84.77 W 557068.62 60£4876.63 lis 3.00 96.03 W 557056.93 6014933.22 HS 3.00 108.£0 ~ 557044.29 6014993.92 HS 3.00 ~20.96 ~ 557031.04 6015058.55 R9 3.00 134.56 W 557016.91 6015126.95 HS ~.0O 148.88 W 557002.04 6015198.92 HS 3.00 163.86 W 556986.48 6015274.26 HS 3,00 Z79-48 W 556970.26 6015352.78 [iS 3,00 195-68 W 556963-43 6015434.24 ~ 3.00 212.43 W 556936.04 6015518.44 H,.q 3.00 229.67 W 556918.13 6015605.]4 HS 3.00 247.]7 W 556899.76 60L5694.10 HS 3.00 26~.47 W 556880.97 6015785.08 HS 3.00 203.91 W 556861.81 60L5877.83 HS 3.00 299-32 W 556845.8~ 6015955.28 HS 3.00 754.25 ~ 5~6373.36 6018242.49 ~S 0.O0 942.54 W 556177,83 6019189.L0 HS 0.00 1113.78 N 556000.00 6020050.00 HS O.00 11t3.78 H 556000.00 6020050-00 I-IS 0.00 (Anadrill_ (c) 97 MPOSiP02 ~.0C 9;53 AM P) Z "U 'U Ml.:~a- ~,1 (Po2) STATION MHASURED [DS~ [ FICATION D~PTH I~B 8035.63 NC/~'D 8L~4.oo NB 8240.25 ~ 84~3.07 CIA 8562.92 INCLN ANGLH 75.28 75.28 75.28 75-28 75.28 PROPOSHD WELL PROPILH 09 Jun ]997 Page 3 QA4 8692.78 75.28 OB 8838.38 75.28 EG~SH SCHRADKR 8948,56 75.28 7" C. AS~I~G POINT 9~48.56 75.28 TD 9148.56 75.28 D£RECTION AZIMUTH 348.77 348,77 348-77 348.77 348.77 ==_-_-==_- ===_-== =~. =-_ VEX{T ICAL- DH PTHS SECTION TVD SUB- SEA DHPART 4036.00 3977.00 5843.92 406t.00 4002.00 5939.06 4088.00 4029.00 6041.82 4L37.00 4078.00 6226.31 4170.00 4111.00 6353.90 COORDINATHS-FROM ALASKA Zone 4 TOOL DL/ WRLLHKAD X Y FAC~ 100 5732.00 N 1138.24 W 555974.60 6020172.99 HS 0.0~ 5825.32 N 1156.77 W 55S955,35 6020266.16 I-IS 0-00 5926.31 N 1L76.78 W 555914.67 6020366.78 lis O.00 6109.03 N L213.11 W ~55896.84 6020549.39 H~ 0.OD 6252.21 N L237.$7 W 555871.44 6020672.38 HS 0.00 348-77 4203.00 4L44.00 6479.50 6355.40 N 1262.03 348,77 4240.00 4LSL.00 6620-31 6493.52 N 1289.46 348.77 4268.00 4209.00 6726_88 ~598.05 N 1310.2~ 348.77 4318.63 4259.83 6920.33 6787.78 N 1347.~9 348.77 4318.83 4259.83 6920.31 6787.78 N 1345.89 ANADRILL APPROVED FOR PERMITTING ONLY PLAN 555846.04 6020795.36 HS 0.00 555817,55 6020933.26 HS 0.00 555796.00 6021037.61 HS 0.00 555756.87 6021227.03 0.00 555756.87 6021227.03 0.00 (Anadrill (c)97 MPG14P02 3.0C 9:53 AN P) i .......... SH"A"RED SERVICE¢BRIE'L' I 'G ............ I ii ii i ii m i i · iiiii . !im i i i i ii iiii i ! I I III I iii ii iii ii L I I ii iiiii i I I ii iii _ II I I I i ii i _. Marker Identification MD OKB SEClN INCLN A) KB 0 0 0 O.O0 B) KOP/BIIILD 1/t00 400 400 0 0.00 C) BUILD t.5/100 700 ZOO B 3.00 D) BUILD 2/100 1000 999 35 7.50 E) END 2/100 BUILD 1789 1757 244 23.2B F) BUILD 3/tOO tB49 tBS2 268 23.28 G) END 3/i00 eUItO 3582 L~04 i537 75.~8 H) IARGET 7906 4003 5718 75.~8 [) 7' CASING POINT 9t49 4319 6920 75.28 J) lO 9149 43~9 6920 75.28 n i iiiii ii nlllllmm m AnadrY II Sch]umberger ii imm i i · i mi i i ii ii i in l i I i _ iii iii ii mb LJ im I MPG- 14 (PO2) VERTICAL SECTION VIEW m ii m ilmm II L _ Section ~t: 348,77 lVO Scale.' I mch = lOOO feet Oep Scale ' ~ inch: 1000 feet Orawn .... · 09 Jun 1997 -- --B'ml ...... ~ AN _ AKA,DPC~ , .PPROVE D O)ILY .... PLAN ..... ~ ........... ~ ~',l~ __ .......... ...... ~~ '' ,, , , ,, , , , , , ~r~-,= ........................ ~- ~~ ........ -- [ ........... ] . , l II,. I .... I i... ,,1 l, I 0 500 ~000 1500 2000 2500 3000 3500 4000 4500 5000 55o0 ~000 6500 7000 7500 8000 esoo Sec tion D,e, parture · m n imllln inl iii mi ii i ii mi III m I _ II I I i ira i ii i i m mI IIII Z 06/09/1997 11'17 907-344-2160 ~N~DRILL DPO PAGE 12 iml - ES DRILLING [ SHARED- SERVI'c A! KB 0 0 N 0 E B) KOP/BUILO ~1]00 400 D N 0 ~ PLAN VIEW BUILD ~.§/[00 700 El , 8 W i! END 2/100 BUILD 1789 239 N 48 W CLOSURE ' 6920 feet at AZimuth 348.77 BUILD 2/t00 tO00 35 N ? W ' ' §UZLB 3/~,00 18,49 863 N 52 W ~l END 3/t00 BUILO 3582 ~507 N 299 W DECLINATION,' +28.045 (El H) T~kRGET 7906 5609 N t~14 W SCALE ' ! inch = 1200 feet Il 7" CASING POINT 9149 6788 N 1348 N J) TD 9149 6788 N t348 W DRAWN · 09 Jun 1997 · mm Anadri 11 Schlumberger m 7800 7200 ~ · ..... ~°° AI~PROVED 6go0 , · ~g ' ' ' 5400 - ~ ~ ~ ~ ,, , , 4800 q~O0 '- ' ' ' I 3500 __ , 3000 -~ ~00 , 1800 ¢ 8oo ....... .. o ~ $00 a~O0 35~0 3000 2~00 t800 1200 ~00 0 800 ~00 ~800 2dO0 3000 (Ana~"~ll (c)g7 NPGi4POa 3.0C q' ~4 ~t4 P) iiii 4nad£.i]] Schlumberger ! i1! i iiiiiii iiiiii i i MPG- i 4 (PO2) VERTICAL SECTION VIEW ' SHAiqED SERVICES DRTLLING ii i ! i ! iii iiii ii i ii ii ii i ii i }4arXer Identilicalion ~ BKB SECTN INCLN A) TARGET 7906 4003 5716 75.28 B} 7" CASING PO[Nf 9149 4319 6920 75.26 C) lO 9t49 43t9 6920 75.;)8 Sect ion at: 348 77 I J APIADRIL[ AiO,.D~ TVD Scale.' ! inch = JO0 feet , Dep Scale.' I ~nch : 100 feet -- ,.. ., APPi[OVED Dra,n..., · 09 Jun ~997 FOI~ PEI;,MiTTIN(,~ ... Ot4LY ...... PLt~N .~~.~ ~,, . . · ,. _~-~ ........... ~ ................ ~ ............. '~~-~-- ~~~ .......... .... ,,. .. CAna~i]t {c)97 Nl~l~02 3.0C 9~ 56 AH PJ 6100 6150 6200 6250 6300 6350 6400 6450 6500 6550 6600 6550 6700 6750 6BO0 6850 6900 6950 7000 Section Departure i iiiii_ i .,,j '13 rtl · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ 2 ~'1 ~'{~ INIT CLASS WELL NAME GEOL AREA PROGRAM: exp [] dev [] redrll [] serv ~ wellbore seg u ann.. disposal para req I~:1 q ~ UNIT# ....... ! J % 2 ~:~ ON/OFF SHORE O V'~ ADMINISTRATION A~ DATE 1. Permit fee attached ....................... ~LI:~J~ 2. Lease number appropriate ................... ~;N 3. Unique well name and number .................. ,.~ N 4. Well located in a defined pool ................ ~ N 5. Well located proper distance from drilling unit bou~(~ary .... ~ N 6. Well located proper distance from other wells .......... (~ N 7. Sufficient acreage available in drilling unit ............ (~ N 8. If deviated, is wellbore plat included ............... N 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 ........... N ENGINEERING 14. Conductor string provided ................... N 15. Surface casing protects all known USDWs ........... N 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... ,~-Y--N-A)'/-/ 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ~,..~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ 31. Data presented on potential overpressure zones ~ Y N of shallow 32. Seismic analysis ga~ ..... Y N condition ............. 33. Seabe su~hore) Y N 34. Cont one for we.eklyprog, ress reDo. rts ....... Y N lexpora~ory on~yj REMARKS 7 GEOL?pY: RPC ~ ENGINEERING: COMMISSION: B E W~.,~7/2"8 DV~c~,~~ JDH ~ RN Comments/Instructions: HOWlljt - A:\FORMS\cheklist rev 07/97 WELL PERMIT CHECKLISToo Y INIT CLASS PROGRAM: exp[] dev [] redrl[] serv~wellbore seg[] ann disp para req[] ,, ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 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 ....... N ENGINEERING REMARKS 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. i.~ N 17. CMT vol adequate to tie-in long string to surf csg . N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ .~N~,~ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... ~ N ~/_~'" 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to .. ~ psig~_ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . / . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97