The URL can be used to link to this page

Home My WebLink About204-045w�. ,• °V M N ... � �K .. '�s fie• �.. � � �th!♦s .- 4•� �" p ry4- •a r.. r *w Q r`''.1� Y"�:.:^ • ..T � ®,� L �-"'�1 * 6 a� 1 :.� wa rr' .1 .. n c ,. r ♦ .r • 40 it r ^wfa mv- � .p. mss. •ae!.i.. • '"9 31 ` ;s IL � •�. .e• � �, .e. ,� .� mS �, ,,i a .,. a ., ._ , w \ 1 i �w } - ♦ n,Jg i.c 46. I [ i ,.. � .�• F �' i •'}�N �'� � ,.C+TI�':w rY %T r .. �� F � ....�..M�yu�y,r i �. _..,. "+•` '� p 3 ; ��` 4� ��' � � i 'o„� �_ r a b >'5 sl'`{ .'TA/',4 'i. T•+".+' h.�.�. if- , i nA '�.�, r �..�'� sa r x �.+,�.��•--.rC 6.dyp�''� y'Pt �� > "; � a e� , � �♦��w ... �; ` � .' �. �'� d.♦� r "4`fP ;v�� 'y/�ffiT �� 2.r�� im '�'�- � At -�'.it �h�� ,:. ♦ ~�,�. .^Y# w rh ♦ � 'yY` � '� ` �':,*t / r. �p� �, .,.. _ 5 °'y " .Mi��l ^dr,y+ "^= aw ' f t S� �t y�r��u s f�,-C'g 1` • ,¢ � ' $ � tx yq` � � ' ` � n �' %� V� n '✓� P'.a a � c„ S.rie9' .r ' jg � r r `" � 4 E � v 7< ,g� r � �� <� i `'.'.�.`` y a�` �. U w..s > 9, r e ... - .. tl ✓"v' �q�f 't, p.: x�3 r. .^'wk j'C%. t . � U'a. r., � x� y Abed...•'�� MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i � 5(ZZII 1DATE: May 9, 2019 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandonment Petroleum Inspector MPU E -25A Hilcorp Alaska LLC PTD 204-045; Sundry 319-153 5/8/19: 1 arrived location, met with James Fagnant (Hilcorp) and looked over all the paperwork (approved sundry). We verified there was hard cement to surface, confirmed the correct numbers were on the marker plate, and witnessed the plate being seal - welded in place. We also verified the cut-off depth was more than 3 feet below tundra level. Attachments: Pictures (3) 2019-0508_Surface_Abandon_MPU_E-25 A_bb. docx Page 1 of 3 Surface Abandonment — MPU E -25A (PTD 2040450) Photos by AOGCC Inspector B. Bixby 5/8/2019 2019-0508_Surface_Abandon_MPU_E-25 A_bb.docx Page 2 of 3 71w-� 1 2019-0508—Surface—Abandon—NVU—E-25A—bb.docx Page 3 of 3 MEMORANDUM TO: Jim Regg��31�`� P.I. Supervisor I FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 2, 2019 SUBJECT: Well Bore Plug & Abandonment MPU E -25A Hillcorp Alaska LLC PTD 2040450; Sundry 319-153 Section: 25 Township: 13N Range: 10E Meridian: Umiat - Drilling Rig: NA Rig Elevation: NA Total Depth: 8325 ft MD Lease No.: ADL 025518 Operator Rep: Nick Frazier Suspend: P&A: Yes - Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 20" O.D. Shoe@ 109 - Feet Csg Cut@ Feet Surface: 7" O.D. Shoe@ 2280 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 4 1/2" O.D. Shoe@ 8325 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 2 7/8 x 2 3/8" O.D. Tail@ 7879 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Retainer 6278 ft MD N/A 2085 - T P OA -2 -2 -2 - -1 Initial 15 min 'in min d5 min Rcenlf Tubing 2239 2143 2116 IA 2210 2112 2085 - T P OA -2 -2 -2 - -1 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I arrived at location to witness the combo MIT -T and MIT -IA test to 2000 psi. The pervious plug was verified with CT Tag and pressure test witnessed by AOGCC Inspector Guy Cook 4/28/19. Pert holes where shot in the tubing @ 5450 ft MD in preparation for the upcoming cement job. The CMIT-TxIA was digitally charted by Little Red Services. Attachments: none rev. 11-28-18 2019-0502_Plug_Verification_MPU_E-25A_II MEMORANDUM TO: Jim Regg P.I. Supervisor '\y 'VZ -A17 FROM: Guy Cook z Petroleum Inspector Section: 25 - Township: Drilling Rig: NA Rig Elevation: Operator Rep: Nick Frazier Casing/Tubing Data (depths are MD): State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 28, 2019 SUBJECT: Well Bore Plug & Abandonment MPU E -25A Hilcorp Alaska LLC PTD 204-045; Sundry 319-153 13N Range: 10E Meridian: Umiat NA Total Depth: 8325 ft MD Lease No.: ADL 0025518 Suspend: P&A: X Conductor: 20" O.D. Shoe@ 109 Feet Surface: 7" O.D. Shoe@ 2280 Feet Intermediate: O.D. Shoe@ Cut@ Feet Production: 4.5 O.D. Shoe@ 8325 Feet Liner: O.D. Shoe@ Feet Tubing: 2 7/8" x 2 3/8" O.D. Tail@ 7879 Feet Plugging Data: Test Data: Type Plug Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Retainer 8076 ft MD" 6278 ft MD' 15.8 ppg C.T. Tag Initial 15 min 30 min 45 min RPcidf Tubing 2117 2082 2066 ' IA 0 0 0 P OA 10 11 12 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: The reservoir abandonment cement plug (Tubing and IA) was pumped prior to my arrival. The first cement tag was at 6278 ft MD with coil. They put 5000 pounds down to tag at 6281.6 ft MD. A second coil tag, after the MIT -T, gave the same initial footage of 6278 ft MD. They put 3000 pounds down to establish the top of cement at 6282 ft MD. There is a 16 -ft correction to get the coil back to E -line measurement. Attachments: rev. 11-28-18 2019-0428_Plug_Verification_MPU_E-25A_gc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i� l 5/211 DATE: 4/27/19 P. I. Supervisor FROM: Guy Cook SUBJECT: Plug Verification Petroleum Inspector MPU E -25A Hilcorp Alaska LLC PTD 204-045; Sundry 319-153 4/25/19: 1 arrived on site at 10:00 am and met up with Nick Frazier for verification of the reservoir abandonment plug. A cement retainer was set at 7804 ft MD and cement , circulated down the tubing and up the tubing -casing annulus through perforations in the tubing above the retainer The coil unit operator zeroed out and started into the well for the cement tag. It was estimated that the cement top should be at 7750 ft MD in the tubing. The actual tag occurred at 7804 ft MD indicating that they had tagged the cement retainer (no cement on top of the retainer). Nick told me it may be difficult to get another cement truck out to location quickly to fix the issue. I left location at approximately 12:00 pm and left instructions to contact the AOGCC, by submitting a request for witness, when they were ready to tag cement again. Attachments: None 2019-0425_Plug_V erification_Fail_MPU_E-25A_gc.docx Page 1 of 1 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E -25A Permit to Drill Number: 204-045 Sundry Number: 319-153 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, J Daniel T. Seamount, Jr. Commissioner r DATED this _day of April, 2019. R6DM9qLt/ APR 0 4 1" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.250 MAR 2 7 2019 AOGC 1. Type of Request: Abandon ❑Q • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑✓ 204-045 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22980-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 • Awe 80e -f Will planned perforations require a spacing exception? Yes ❑ No ❑Q MILNE PT UNIT E -25A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025518 MILNE POINT/ SCHRADER BLUFF OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,325' 4,462' 8,279' 4,440' 968 8,279' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 109' 109' N/A N/A Surface 2,251' 7" 2,280' 2,176' 7,240psi 5,210psi Production 6,177' 4-1/2" 8,325 4,462' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" 6.41 L-80 / ST -L & TC -11 7,819' See Schematic See Schematic 2-318" 4.61 L-80 / ST -L & EUE 8rd 7,879' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 5-112" ZXP LTP & 4-1/2" x 2-3/8" FH Ret. and N/A 2,156 MD/ 2,073 TVD & 7,821 MD/ 4,246 and N/A 12. Attachments: Proposal Summary Q Wellbore schematic a 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑ Service ❑r 14. Estimated Date for 15. Well Status after proposed work: CommencingO 4/10/2019 Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAGIN ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q - 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Be York Contact Name: Taylor Wellman TTW Authorized Tile: Operations Manager Contact Email: twellm9D hilcor .COM Contact Phone: 777-8449 Authorized Signature: Date: 3/26!2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - Integrity ❑ Test ❑ Mechanical Integrity Test Location Clearance ❑ [rBOP .--� Other. iF ��,�• #M 1nS'd-1-h0 GNC.2�i/ 7 JYes Post Initial Injection MIT Req'd? ❑ No ❑ RBDMS 0/ APR 0 4 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 -- Y APPROVED BY 2 O / J Approved by: COMMISSIONER THE COMMISSION Date. J / �/ 2017 A � Submitnan Form 10-403 Revised 4 Approved application is valid for 12 months from the date of approval. A 111 ttachments in Duplicate U Hil=p Alaska. Lb Plug and Abandon Well: MPU E -25A Date:03/20/2019 Well Name: MPU E -25A API Number: 50-029-22980-01 Current Status: SI WAG Injector Pad: MP E -Pad Estimated Start Date: April 10, 2019 Rig: Multiple Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 204-045 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 1,368 psi @ 4,000' TVDss (Based on FL shot+fluid column 03/20/19) Maximum Expected BHP: 1,368 psi @ 4,000' TVDss (Based on FL shot+fluid column 03/20/19) MPSP: 968 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPE-25A was drilled and originally completed in December 2000. The well was sidetracked in April 2004 and completed as a WAG injector. Ever since being drilled the well has had low injectivity and abnormally high injection pressure. It is believed to be in a compartmentalized area with little to no support of surrounding proms The well has been shut in since 2009. Notes Regarding Wellbore Condition • The well passed an MIT -IA to 2360psi on 08/17/2008. • The well is a monobore completion with no Outer Annulus. i Objective: To plug and abandon the well in preparation for a slot recovery for an additional drill well on E -Pad. Operations/Well Support 1. Perform an MIT -IA to 2,000psi (charted). Slickline & Pumping 2. RU SL unit and pressure test PCE to 250psi low/ 1,500psi high. 3. Drift and tag bottom. 4. Drift tbg for 2-7/8" cement retainer to 7,808' and (XN nipple). S. RIH and locate 2-3/8" X nipple for depth correction. 6. RIH and mechanically tbg punch 2-3/8" tubing tail at±7,825' md. Pwnv'c TT/tcc� 7. MU 2-7/8" cement retainer. RIH and set retainer at ±7,800' md. 8. RD SL unit. Coil Tubing Procedure: 9. MIRU CT unit and spot support equipment. Fill uprights with produced water. 10. Pressure test BOPE to 250psi low / 2,500psi high, 10 min each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 2,500 psi Hi 250 Low to confirm no leaks. 11. RIH w/ 2-7/8" cement retainer stinger. Sting into retainer and confirm injectivity. H Rif rp Alaska, LL, Plug and Abandon Well: MPU E -25A Date:03/20/2019 a. Apply "'100psi to the backside and monitor backside for signs of pressure communication. 12. Begin to mix cement. Once blend is up 15.8ppg, pump ±11bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. Line up to take returns from the backside. 13. With ±1bb1s of cement in the coil tubing, unsting from the retainer. 14. Allow ^'1/4bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pullout of the cement as the last of the cement exits the nozzle. b. Estimated TOC @ 7.631' md. 15. RIH to±7,750' and circulate excess cement out of the well. 16. Pump sweep around before POOH. 17. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole. 18. RD CT unit. Sp2 Operations/Well Support //(nn 64-A �) 19. Perform MIT -T to 2,000psi(charted). lk� irlEs�✓✓�^ a. Wait on cement to gain 1,000psi compressive strgth (estimated 24hrs). 20. Swap tree out to dry hole tree and pressure test to 250psi/3,000psi. Slickline & Pumping 21. RU SL unit and pressure test PCE to 250psi low/ 1,500psi high. 22. Drift for tbg punch and tag TOC. -1160 23. RIH and mechanically tbg punch 2-7/8" tubingl` at±7,745' md. a. Apply 200-300psi to the tubing above the IA pressure. b. IA has diesel to 1,950' and / 1,950'tvd and 9.2ppg brine below this point. The IA is hydrostatically underbalanced by 85psi above the tubing (assuming 2,000' and freeze protect on the tubing side with diesel). 24. CMIT-TxlAto 2,000psi (charted). 25. RD SL unit. Cementing (�/`-��``�' hZ""-�) 26. RU a15d pressure test lines to 2,500psi. 27. Line up to pump down the tbg while taking returns from the IA to tanks. 28. Begin circulating to fluid pack and confirm 1:1 returns. Circulate tubing and casing cleaning pills. Shut down pumps. J�Z 29. Begin to mix cement. Once blend is up to 15.8ppg, pump ±10bbls of mudpush pill to clean tubing p/ and casing walls followed up ±200bbls of 15.8ppg Class G cement. b a. Wellbore volume to 7,750' and in tbg +annulus to the packer = 151.9bbls. 30. Confirm good cement returns from IA, swap to chase fluid to displace past the tree and shut down. 31. Wash lines clean to tanks and RD. Wellhead Removal 32. Notify AOGCC inspectors 24_hrs rior to cutoff of wellhead and welding marker plate. 33. Excavate cellar, cut off wellhead and casing 3' below natural GL. a. If cement fell back, bring cement toptteve oocu�� b. Photo document the casing cut below natural ground level. H Mimi, Alaska, LU Plug and Abandon Well: MPU E -25A Date:03/20/2019 34. Photograph casing stub before setting marker plate showing casing cut and cement top. 35. Set marker plate, collect GPS coordinates. a. Information to_be-we the top of the marker plate: i. Hilcorp Alaska, LLC PTD :204-045 Well name: MPU E -25A API: 50-029-22980-01 36. Photograph casing _sFub after se itf ng-IM-arker plate. 37. Backfill cellar, close out location. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO Sundry Change Form Tree: 2 9/16" - 5M FMC Wellhead : 11"x 11" 5M Gen 5, Tubing hgr 11" x 2-7/8" EU 8rd Top & Bum thread with 2.5" CIW H -Profile 20" 94 #/ft H40 F 80' Baker Tie back Sleeve Baker 7"x 51/2" "ZXP" Liner top pkr Baker 7"x 51/2" Flex -lock hyd. pkr. 2-3/8", 4.6 #/ft L-80, ST -L tubing (drift id = 1.901, cap =.00387 bpf) 2-7/8" 6.4 ppf, L-80 ST -L / TC -II tbg. ( drift id = 2.347" cap. .00592 bpf ) 4.5" 12.6 #Rt , L-80 , IBT-mod. (drift id = 3.958" , cap = 0.0125 bpf) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Perforation Summary Ref log: SCMT Cement Bond log 4/18/04 Site SPF Intmval I (TVD) 2-7/8" 6 7,978'- 7,958' 4,354 - 4,345' 2-7/8" 6 8,096'- 8,076' 4,305'-4,297' Guns used :2-7/8" HSD, Powerjet, 6 spf MP E -25a KB elev. = 51.75' Doyon 141 DF elev. = 28.55' Doyon 141 GL elev. = 23.20' Doyon 141 11 Iliko...A".. UA: N Z'�lo� z .o34Z 2-7/8" HES X-Nipple(2.313") 1,996' y / G v 3z AeS �y3 z y(V �U ' 131 2-7/8" HES XN-Nipple( 2.250" No Go) 7,808' 2-7/8" x 2-3/8" X -Over F7 819' 4.5"x 2-3/8" Baker FH Retrievable Pkr. Initial completion by Doyon 141 2-3/8" HES X -Nipple ( 1.875"Id F7,846' Baker Hydro -Trip sub F7,867' WLEG 7,879' 4.5" Baker Float Collar 8,236' 4.5" HES Float collar 8,279' 4.5" HES Float shoe 8,325' DATE REV. BY COMMENTS 12/08/00 MOO Initial completion by Doyon 141 04/01/04 MDO De -Completion Nabors 4 -es 04/16/04 MDO Sidetrack Completion Doyon -14 MILNE POINT UNIT WELL E -25a API NO: 50-029-22980-01-00 LLC PROPOSED MP E -25A KB elev. = 51.75'Doyon 141 Tree: 2 9/16- - 5M FMC OF elev. = 28.55' Doyon 141 Wellhead : 11"z 71"SM Gen 5, Tubing hgr 11" x 2-7/8" EU 8rd Top 8 GL elev. = 23.20' Doyon 141 Btm thread with 2.5' CIW H -Profile 20" 94 #/ft H-40 80-' Baker Tie back Sleeve a Baker 7"x 51/2" "ZXP" Liner top pkr Baker 7"x 51/2" Flex -lock hyd. pkr. KOP @ 660' Max wellbore Angle: 70' @ 4040' Hole angle through peas = 64 deg. 2-3/8", 4.6 #/ft L-80, ST -L tubing (drift id = 1.901, cap.=.00387 bpf) 2-7/8" 6.4 ppf, L-80 ST -L / TC -II tbg. ( drift id = 2.347" cap..00592 bpf) 4.5" 12.6 #/ft , L-80, IBT-mod. ( drift id = 3.958" , cap = 0.0125 bpf ) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf) Perforation Summary Ref log: SCMT Cement Bond log 4/18/04 Sc. SPF Interval (ND) 2-7/8" 6 7,978' - 7,958' 4,354' - 4,345' 2-7/8" 6 8,096'- 8,076'1 ,076' 4,305'- 4,297' Guns used :2-7/8" HSD, Poweriet, 6 spf Oriainal well bore notes: Sidetrack bridge plug @ 2370' RA tag @ 6197' 2-7/8" HES X-Nipple(2.313" ) Tubing Punch at +/- 7,745' TOC at +/- 7,750' 2-7/8" Cement Retainer at +/- 7,800' 2-7/8" HES XN-Nipple( 2.250" No Go F7 808' 2-7/8" x 2 -3/8"X -Over F7,819' 4.5"x 2-3/8" Baker FH Retrievable Pkr. F7 821' Tubing Punch at+1-7,825' Initial completion by Doyon 141 2-3/8" HES X -Nipple ( 1.875"id) 7,846' Baker Hydro -Trip sub 7867` WLEG 7,879' 4.5" Baker Float Collar 8,236' 4.5" HES Float collar 8,279' 4.5" HES Float shoe F8,325' DATE REV. BY COMMENTS 12/08/00 MDO Initial completion by Doyon 141 04/01/04 MOO De -Completion Nabors 4 -es 04/16/04 MOO Sidetrack Completion Doyon -14 MILNE POINT UNIT WELL E -25a API NO: 50-029-22980-01-00 COIL BOPE MILNE POINT UNIT MPU E -25A Ililcorp Alaska, LL(', 03/26/2019 Lubricator to injection head Blind/Shear �— '/1610M rBhnd/Shear Pipe---� Pipe Crossover spool 1.5in Single Stripper UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: March 26, 2019 Subject: Changes to Approved Sundry Procedure for Well MPU E -25A Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call" engineer. AOGCC written approval of the change is required before implementing the change. HAK Step Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date 1,000,000 Y 100,000 c 0 CI CIL LL 10,000 u M lii c 1,000 d d LL V_ .0 3 100 v C m N 3 O t i- 10 HILCORP ALASKA LLC, MILNE PT UNIT E -25A (204-045) MILNE POINT, SCHRADER BLFF OIL Monthly Injection Rates Cum. Inj Gas (mcf): 119,683 _ Cum. Inj Liquid (bbls): 594,765 Injected Gas (MCFM) —. Injected Water (BOPI 1,000,000 100,000 w d 10,000 m 0 CM C d 1,000 rD 0 O 3 100 S 10 SPREADSH EET_Prad-Inject_Curves_Well_V319_2040450_MPU_E-25A_20190328.xlsx 3/28/2019 e bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 a,0 Li- a Y5. , . Mr. Tom Maunder M F a 5-fl Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 823/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE-08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 ' MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 MEMORANDUM To: Jim Regg ~~~~ ~(~l Z~~v P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-25A MILNE PT UNIT SB E-25A Src: Inspector NON-CONFIDENTIAL Reviewed Byrn P.I. Suprv -~~tL- Comm Well Name: MILNE PT UNIT SB E-25A API Well Number 50-029-22980-01-00 Inspector Name• Chuck Scheve Insp Num: mitCS080817164228 Permit Number: 2oa-oas-o Inspection Date: 8/17izoo8 Rel Insp Num: ~ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-25A TYPe Inj. ~ TVD 4246 IA 240..:-,.. •- 2500 " 2380 2360 P.T. 2°4°45° TypeTest sPT Test psi t5oo OA Interval 4YRTST Pte, P i Tubing 2300 2300 2300 2300 retest pressures were ob erved and found stable. NOtes• Well is a Schrader Bluff single casing design now on gas injec tio n P s '' ~r ~~ t~yy~~ ~C~td'lI~1~~~ SEP 1 ~.aQ~i Monday, August 18, 2008 Page 1 of I • • .~... r-~ --~ ,~-- - - ~; e ~P -i - • ~ 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc RE: Clarification sought on regul tions concerning low pressure pilot sets for injector E-29 ., _ I Regg, James B (DOA) ... Page 1 of 2 ~~ V ~ / From..... Regg James B (DOA) ~Cf~CI _~I ~Z'a~~7 __ Sent: Wednesday, November 28, 2007 3:19 PM l To: 'Stephenson, John' Cc: Chesher, James R; MPU, Well Operations Supervisor; Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Clarification sought on regulations concerning low pressure pilot setpoints for injector E-29 at Milne Point John - Thank you for providing the Commission with some information about BP's failsafe protection philosophy regarding the MPU E-29 (and presumably MPU E-25A). Commencing the WAG cycle injection {2 months gas, 4 months water) is approved for the small scale enhanced oil recovery {SSEOR) pilot approved by administrative order A40 1 OB.002 dated September 12, 2005. That approval was conditioned on BP gathering information about project performance and objectives, injection performance and FOR response, and technical issues. In addition to the reservoir performance being gathered during this pilot, the Commission expects that BP will also be gathering information about the design and performance of the injection wells' failsafe protection components {total system -plant compressor to well, including downhole). The end of project review expected by the administrative order should include a detailed discussion of philosophy {components used, basis for trip pressures, alarms versus shutdown devices, high and low pressure protection, etc.). Any expansion of the project will require a more detailed assessment of the failsafe system, including a hazard assessment that identifies and addresses the possible failure modes. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~'~~ D~~ ~ ~ Z~Q7 From: Stephenson, John [mailto:John.Stephenson@uk.bp.com] Sent: Tuesday, November 20, 2007 3:06 PM To: Regg, James B (DOA) Cc: Chesher, James R; MPU, Well Operations Supervisor Subject: RE: Clarification sought on regulations concerning low pressure pilot setpoints for injector E-29 at Milne Point iii Jim, I was hoping to obtain an update on where we are with starting gas injection into the Milne Point well MPE-29 {details below). Nf further clarification is required please let me know; as the well is currently shut-in. ff possible, a 60 day dispensation to inject gas at the lower PSL setting would allow us to begin the planned 2 month gas 14 month water WAG cycle, whilst providing time to answer/redress any questions you may have as regards failsafes upstream of the choke, prior to the next gas slug. Thanks for your help, John Stephenson From: Stephenson, John Sent: Tuesday, November 13, 2007 7:47 AM To: 'jim.regg@alaska.gov' 11/28/2007 RE: Clarification sought on regulations concerning low pressure pilot sets for injector E-29 ... Page 2 of 2 Cc: Chesher, lames R • Subject: Clarification sought on regulations concerning low pressure pilot setpoints for injector E-29 at Milne Point Hi Jim, As mentioned in our telephone conversation last friday, I have attached a one slide presentation outlining the philosophy for the failsafe protections on gas injector MPE-29. This is in relation to the request for written permission to lower the PSL within the well house from 2500 to 1500psi .Please let me know if any further clarification is required. Thanks, John Wells and Subsurface Engineer Milne Point, ACT Tel: (907) 964-4354 « File: MPE-29 Safety Isolations.ppt » the file so that changes to the file will be reflected in your item. 11128/2007 Schematic for Failsafe Systems on MPE-29 • PLANT COMPRESSOR • Request to lower PAL to 1500psi from 2500psi downstream of the choke • PSL switch set at 500 psi upstream of the choke designed for catastrophic upstream failure • Relatively low PSL set point, designed to prevent nuisance trips caused by instantaneous pressure variations in header e.g. valves opening and closing for other wells • These represent additional pressure changes not observed at PAL switch • Additional failsafes are present further upstream including PSL at the header and at the compressor discharge • Page 1 of 1 • Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Thursday, November 15, 2007 3:12 PM To: Regg, James B (DOA} Subject: E~ & E-29 ~t~~ ~-2~./~ Jim, I just spoke with Lee Hulme and he confirmed that these wells have SSSSV MCX (flapper) type injection valves. Lou 11 /15/2007 • Page 1 of 1 Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Sunday, October 28, 2007 4:49 PM To: Hulmepl@bp.com Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: Injection LPS setting on MPU E-29i Follow Up Flag: Follow up Flag Status: Red Hi Lee, This e-mail confirms BP's allowance to inject gas into MPU E-29i with a reduced LPS trip setting of 1500 psi. It is understood that the tubing injection pressure will initially be above 2000 psi (approx. 2300 psi) but will come down as the static fluids are cleared from the wellbore. A target tubing injection pressure of 1700-1900 psi will ultimately be obtained and maintained. This will put this reduced LPS trip pressure within 75% of injection pressure, if the tubing injection pressure does not meet the target and stays above 2000 psi adjust this wells LPS trip pressure so it trips within 75% of injection pressure. Also please notify Jim Regg (793-1236) at your earliest convenience of this deviation. This allowance for reduced trip pressure will expire two weeks from today, Sunday, 11/11/07 unless Jim Regg or another Commission representative gives written authorization. I appreciated everyones input into our discussion on LPS placement on injection wells in your area. I urge you and other cognizant BP rep's to consider this issue as it may come to a head soon. As I stated today, to the best of my understanding the wells in your area are not out of compliance at this time and no immediate action is required. I will be discussing this issue with my superviser and as it stands now I feel the LPS shoud be on the other side of the choke, I do not make the final decisions on these matters, only gather information and make reccomendations. If there is more information in the form of calculations or precedents that show there is equal or better protection with the system in place I would appreciate seeing it. As always it is a pleasure working with you and coming into Milne Point, Lou Grimaldi A.O.G.C.C. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~ ~ ic~,R~o7 DATE: October 25, 2007 P. I. Supervisor -~~ FROM: Lou Grimaldi SUBJECT: Growing Casing Petroleum Inspector B.P. Exploration MPU E-25A & E-29 Milne Point Unit October 25, 2007: I inspected two B.P. Exploration injection wells in the Milne Point Unit ("MPU") for reported surface casing growing out of the Conductor. I met Lee Hulme (well op's coordinator) at MPU well pad "E" and we inspected E- 25A and E-29. The following was observed: MPU E-25A is a monobore injector which exhibited approximately 4" of growth of the 7 5/8" production casing out of the conductor hanger. The wellhead had a noticeable lean towards the rear which was most likely caused by the injection flowlines weight pulling back on the tree. The wellhead was easily swayed side to side approximately one inch when pushed upon. I advised that some bracing be applied to take some of the rear force from the flowline off of the 7 5/8" production casing. MPU E-25A pressures observed were - IA 570 psi; Tubing 2400 psi (injecting). MPU E-29 is a standard configured injector which exhibited approximately 8" of growth of the 9 5/8" surface casing out of the Conductor hanger. This wellhead did not exhibit any lean and seamed fairly stable. I did not see any immediate problems with this well other than the casing growth. MPU E-29 pressures observed were - IA 0 psi; OA 600 psi; Tubing 1467 psi (shut-in). Attachments: MPU E-25 wellhead a 10-25-07.jpg MPU E-25 wellhead b 10-25-07.jpg MPU E-25 wellhouse 10-25-07.jpg MPU E-29 wellhead a 10-25-07.jpg MPU E-29 wellhead b 10-25-07.jpg MPU E-29 wellhouse 10-25-07.jpg • MPU E-pad Casing Issues Photos by AOGCC Inspector Lou Grimaldi October 25, 2007 MPU E-25A wellhouse MPU E-25A; fluted hanger of the 7-5/8" casing not landed in conductor casing `~ ~ f ~ ; :~ ~, . ... i `~ ~' _' .\1N • MPU E-25A; wellhead leaning aft (notice fluted hanger of the 7-5/8" casing not centered in conductor casing) MPU_E-25A_E-29_growing csg_2007-1025_Ig.doc i MPU E-pad Casing Issues -continued ~Y t MPU E-29 wellhouse ~, 1a ~: ~: 1~~' ~'~ ~. ~'f~` =! --~ ~~. ~~~ _:~ . ._ _. , ,~ ~~ .• ~~ ~ ~:. • ~. ~~~ MPU_E-25A_ E-29_growing_csg_2007-1025_Ig.doc MPU E-25A; fluted hanger of the 7-5/8" casing not landed in conductor casing 3 Clarification sought on regulations c~erning low pressure pilot setpoints for ' 'ector E-29 at Milne P... Page 1 of 2 Regg, James B (DOA) ~ _ , From: Regg, James B (DOA) ~~~ "~ Sent: Thursday, October 25, 2007 1:17 PM ~~ ~~~~~~ To: 'Chesher, James R' ~ ~~ Cc: DOA AOGCC Prudhoe Bay Subject: RE: Clarification sought on regulations concerning low pressure pilot setpoints for injector E-29 at Milne Point 2000 psi would be consistent with the old and new regulations and would appear to provide the intended protection. I am curious about the relative location of the choke to the manifold, though. What protection is provided for that section of the high pressure supply line? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~`~ ~~~ ~ ~ ~fl~~ From: Chesher, James R [mailto:james.chesher@bp.com] Sent: Tuesday, October 23, 2007 7:12 PM To: Regg, James B (DOA) Subject: Clarification sought on regulations concerning low pressure pilot setpoints for injector E-29 at Milne Point Dear Jim, I work in the Milne Point field, and have a question I'm hoping you can help me with. We have two wells, MPE-25A and MPE-29 set up to inject either gas or water into the Schrader Bluff reservoir, as a pilot gas injection scheme. This was approved by the AOGCC on 9/12105 per administrative approval 477.006 / AIO 106.002. The wellhead injection pressure required to put the desired rate into the relatively low pressure Schrader reservoir is around 2250psi. However, the gas injection system at Milne is designed to inject into the higher pressure Kuparuk reservoir, with a manifold pressure usually around 4600psi. The low pressure pilot has traditionally been set at slightly higher than 50% of the maximum possible manifold discharge pressure - in this case, at 2500psi, in line with all our Kuparuk injectors. However, due to choking the well back to inject the desired rates, this causes the low pressure pilot (which is downstream of the choke) to trip on E-29, shutting in the well. The c{arification I am seeking is regarding the regulations on low pressure pilot setpoints. The current safety valve system regulations state that the LPP should be set at 50% of the primary separator pressure or 25% of the tubing pressure. The proposed new SVS regulations require the setpoint to be "greater than 50 percent of the injection tubing pressure or 50 percent of the compressor discharge manifold pressure, whichever is less". Am 1 right in understanding from either of these regulations that we are OK to operate with a LPP set at ~2000psi? This would be significantly greater than 50% of the wellhead injection pressure, and thus in line with ofd and new regulations. This would not be in line if we were to interpret "primary separator pressure" to mean "manifold discharge pressure". Thank you for your consideration of this request. I look forward to hearing from you. Best regards James ++++++++++++++++++++++ Viscous Oi! Team Leader 10/25/2007 Clarification sought on regulations ~cerning low pressure pilot setpoints fo~ ector E-29 at Milne P... Page 2 of 2 Milne Point team (desk 448C} BF' Expioratian Alaska Inc. 980 East E3enson 131vd Anctiorage, Alaska 985G8 cell: ~-1 (9Q7} 441 5130 fames. chestier@bp, cam 10125/2007 MPE-25A (PTD #2040450) ~ Form Page 1 of 2 • Maunder, Thomas E (DOAj From: NSU, ADW Wel! Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, October 15, 2007 8:48 AM To: Regg, James B (DOA} Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer Subjec~E: f~E: MPE-Z5A (PTD #204045Q} Mtl' Form Jim, . ,..._. The lowest portion of the cement top was measured at 8 feet below the top of the conductor. Thanks, ~~~~ ~V~~~ €~ ~ 2~~7 Andrea Hughes From: Regg, James B (DOA} [mailto:jim.regg@alaska.gov] Sent: Monday, October 15, 2007 8:16 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: MPE-25A (PTD #2040450} MIT Form How far down was the surface x conductor annulus empty? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeHIntegrttyEngineer@BP.com] Sent: Sunday, October 14, 2007 10:53 AM To: Regg, 3ames B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert 3 (DOA} Cc: NSU, ADW Well Integrity Engineer; MPU, Wells Ops Coord; NSU, ADW WI Tech; Engel, Harry R Subject: MPE-25A (PTD #2040450} MIT Form Jim, Tom and Bob, Please see the attached MIT form for the MtTIA performed on MPE-25A (PTD #2040450). The MITIA proved that the wellhead movement observed on surface is not due to downho{e integrity issues. «MIT MPU E-25 10-12-07.xts» The wellhead has been stabilized by placing clean gravel in the surface casing by conductor annulus. Please call with any questions yr concerns. 10/19/2007 a • Email to: Winton_Aubert~admin.state.ak.~; Bob_ .state.ak.trs; Jan_R .state.ak.us; T~ Maunder(~Aadmin.state.ak.us OPERATOR: BP F~loration (Alaska}, Inc. FIELD /UNIT /PAD: Mitne Pt / MPU t E pad DATE: 1Q/12/07 OPERATOR REP: Andrea Hughes AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test u`~ ~' ~~ Packer Pretest k>itiat 15 N6n. 30 AAn. Well MPE-25A Type In'. G TVD 4246 Tu ' 2300 2300 2300 2300 Interval O P.T.D. 2040450 Type test P Test psi 3000 Casng 0 30t10 2960 2940 P/F P Notes: MIT-IA to eval wellhead movement. OA 0 0 0 0 Well Ty In'. T1lD T Interval P.T.D. Type test Test Casing P/F Notes: OA Well Type Inj. TVD Tu6gtg Interval P.T.D. T test Test psi Caseg P/F Notes: OA Well Type Inj. TVD T Interval P.T.D. Type test Test psi P!F Notes: OA Weli T In'. TVD Tnttirg Interval P.T.D. T test Test Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N = Not injecting W =Water TYPE TEST Codes M = Annrilus i4bnibairg P = SNattdard Pressure Test R = tntemal Radioactive Tracer Survey A = 7emperarure Anoa~}y Suniey D = DiKererdial Tempera&~re Test INTERVAL Codes i =initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other {describe in notes) MIT Report Form BFL 9/1!05 MpT MPU E-2510-t2-07.xls Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA} Sent: Thursday, October 04, 2007 8:40 AM To: 'NSU, ADW Well Integrity Engineer' Subject: RE: MPU E-25A ID~~ ~~~ .!~~~1 Attachments:. MPU_E-25A SVS_2007-0924.pdf Here's the inspector's report Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~ NOV ~ 207 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, October 03, 2007 7:02 PM To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Subject: RE: MPU E-25A Jim - I asked Ron Wilson about it on the off chance he'd heard anything, and he hadn't. I've called Milne Point and they are going to send some techs out to look at the wellhead and will let us know what they find. Thank you - Jack I.. Wfnslow {forAnnc~ Dube} Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, September 28, 2007 2:34 PM To: NSU, ADW Well Integrity Engineer Subject: MPU E-25A Inspector noticed while out witnessing safety valve system tests that Milne Pt E-25A wellhead appeared unstable ("could be moved around while cycling valves for the SVS test"). Copy of Inspector's report is attached. Please check into this and describe what has been or will be done to remedy this situation. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 10/4/2007 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) II Sent: Friday, September 28, 2007 2:34 PM ~~~~~ ~'~~ lG ~ To: 'NSU, ADW Well Integrity Engineer' ~ ~ ~~~ _ ~1~~ Subject: MPU E-25A Attachments: MPU_E-25A_wellhead_issue_2007-0924.pdf Inspector noticed while out witnessing safety valve system tests that Milne Pt E-25A wellhead appeared unstable ("could be moved around while cycling valves for the SVS test"). Copy of Inspector's report is attached. Please check into this and describe what has been or will be done to remedy this situation. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 9/28/2007 Reviewed By: Safety Valve & Well Pressures Test Report P.LSnpr,~~ Comm Pad: MPU_E InspDt: 9/24/2007 Inspected by John Crisp Interval InspNo svsJCr070925145934 Field Name MILNE POINT Operator BP EXPLORATION (ALASKA) INC Operator Rep Lee Hulme ___ Well tiara Pilut.~~ S~S1" S'SSi' Shntlrr Dt li~~ll %jyre Yl'rlI Prr~~~ures -__ Well Permit Separ Set UP Test Test Test Date SI Oi],WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLI?, SI PSI PSI PSI E-25A 2040450 3600 1500 1070 3 P ~ P ~ WAGIN Well was on gas. The pilot line was also plugged. Well shut in until pilot set pressure increased & pilot line ,/' purged. The SB well is single string . casing that had mandrel hanger off seat in conductor. The well head was un stable & could be moved around while cycling valves for SVS test. Comments Performance Wells Components Failures Failure Rate 1 3 1 33.33% • Related Tnsp: Reason Miscellaneous '~ Sre: Inspector ____ Gas hirr t~3'aiver Continents Yes/No Yes/No Thursday, September 27, 2007 Combined SVS Test Results Aug 01, 2007 Through (Excludes Reason = "Retest") C~~a PLT SSV SSS V Insp/ Date Test Retest Failure Well Name Permit # CP /F CP /F CP /F Oper Tested Reason Period Tests Components Failures Rate MILNE PT UNIT KR E-03 1890170 1 0 1 1 1 0 IN 8/12!2007 180 3 1 MILNE PT UNIT KR E-04 1900050 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT KR E-06 1910480 1 0 1 1 0 0 1N 8/12/2007 180 2 1 MILNE PT UNIT KR E-08 1910500 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT KR E-09 1941320 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT KR E-I 1 1950010 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT SB E-15 1941530 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT KR E-19 1970370 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT SB E-20A 2040540 1 0 1 0 0 0 1N 8/12/2007 180 2 0 MILNE PT UNIT SB E-24A 2001860 1 0 1 0 0 0 1N 8/12/2007 180 2 0 MILNE PT UNIT SB E-31 2050720 1 0 1 0 0 0 IN 8/12/2007 180 2 0 MILNE PT UNIT SB E-32 2050650 1 0 1 0 0 0 IN 8/12/2007 180 2 0 . ~, MPU_E 12 25 2 8.00% - (~~ -Z51-~ __ ~c~+~o45c1 1 I ~ D i U ~ 1~n, --- f?1t~e7 l~t_ - _ l 3 - - L3 ~ z~,/ 3 ~~'~`~~ ~lZ~i~~ Friday, September 28, 2007 Page 1 of 1 Combined SVS Test Results Summary Aug 01, 2007 Through (Excludes Reason = "Retest") Date Failure Tested Tests Components Failures Rate 8n2i2oo7 12 2s 2 MPU E 12 25 2 8.00% ~ I~~- ~o ~ t ~ ~ ~'~~~ ~CZ~+~7 ~~~~ ~~~2~t Friday, September 28, 2007 Page 1 of 1 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907 -793-1005 August 28, 2006 RE: MWD Fonnation Evaluation Logs: 1E-104, CD3-302 PB1, 05-20B, 15-46 L1 PBI, MPK-09, MPE-31, MPC-43, MPE-25A. 1E-104 'Jb4- Q'J'f l~o,Sl..( CD3-302 PB1 90<0- 010 Ii-liD' OS-20B v Qol./ -;[34 J4D'9~ 15-46 L1 PB1 J()L{- 10'3 1L.fIC>Û MPK~09 Got)- C /<.{ 1~1 I()~ MPE-31 ga;- - ot-;)/L./, 03 MPC-43 804- 0311 14/od ~PE-2SA VIC- QOL.{-o4S 1'J~15£1 Digital LIS DATA: SCANNED AUG 3 1 2006 1 CD Rom 50-029-23234-00,50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00,50-029-23200-00,50-029-22980-01. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 15/~ojdo Signed: C))/,-- Permit to Drill 2040450 ^ () M~ ~~ \'i ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 $¡1/AJ. IJ..~ ~ Y API No. 50-029-22980-01-00 ~ Directional surv~ ..- Well Name/No. MILNE PT UNIT SB E-25A Operator BP EXPLORATION (ALASKA) INC 4462 /" Completion Date 4/20/2004 /' MD 8325 .-- TVD Completion Status 1WINJ Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, IFRlCASANDRA Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type Log Electr Digital Dataset Med/Frmt Number Name '1, Cement Evaluation ~ Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments -- - 5 Col 1 4700 8205 2/28/2005 scmt cement bond log/scmt-cb/pbms-a 2280 8325 Open 2/22/2006 ROP DGR EWR plus , Graphics , . C Lis D Asc pt I Rpt +4 C Lis Jrög I 13538 Induction/Resistivity Directional Survey Directional Survey LIS Verification 13196 Injection Profile 13196 Injection Profile 5 Blu 5/12/2004 5/12/2004 0 0 6/9/2004 7850 8168 Case 7/14/2005 7850 8168 Case 7/14/2005 Sample . Set Number Comments Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis Received? Daily History Received? ß/N ~N Formation Tops ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040450 Well Name/No. MILNE PT UNIT SB E-25A Operator BP EXPLORATION (ALASKA) INC MD 8325 TVD 4462 ~ Comaletlo, Date 412012004 Compliance Reviewed By: _ Completion Status 1WINJ Current Status WAGIN API No. 50-029-22980-01-00 UIC Y Date: /1 111 ~ . . 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic IJ Stimulate D Other [] Convert to WAG WaiverD Time ExtensionD 1/16/2006 Re-enter Suspended Well D 5. Permit to Drill Number: 3. Address: IJ 204-0450 Pi 6. API Number: 50-029-22980-01-00 9. Well Name and Number: Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 56.95 KB MPE-25A ADL-025518 11. Present Well Condition Summary: 10. Field/Pool(s): Milne Point Field/ Schrader Bluff Oil Pool 8. Property Designation: RECEIVED Total Depth measured 8325 true vertical 4461.53 feet feet Plugs (measured) Junk (measured) None None FED 2 7 2006 Alaska Oil & Gas Cons. Commission Anchorage Effective Depth measured 8279 true vertical 4439.51 feet feet Casing Conductor Production Liner Length 80 2132 6177 Size MD TVD Burst 20" 94# H-40 31 - 111 31 - 111 1530 7" 26# N-80 30 - 2280 30 - 2176.20 7240 4-1/2" 12.6# L-80 2148 - 8325 2066.23 - 4461.53 8440 Collapse 520 5410 7500 Perforation depth: Measured depth: 7958 - 7978 True Vertical depth: 4297.87 - 4305.64 8076 - 8096 4345.78 - 4354.43 Tubing: (size, grade, and measured depth) 2-7/8" 6.4# 2-3/8" 4.6# L-80 L-80 29 - 7819 7819 - 7879 Packers and SSSV (type and measured depth) 5-1/2" Baker LT Packer 4-1/2" Baker FHL Packer 2156 7821 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL MAR 0 ) 2006 Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN 743 2571 15. Well Class after proposed work: Exploratory Development Service Pi 16. Well Status after proposed work: Oil Gas IJ WAG pj WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Contact Sharmaine Vestal Title Data Mgmt Engr Signa Phone 564-4424 Date 2/24/2006 Form 10-404 Revised 04/2004 Submit Original Only . . ú WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 jô5CJS RE: MWD FOffi1ation Evaluation Logs MPE-25A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPE-25A: LAS Data & Digital Log Images: 50-029-22980-01 Vlf-.. è'f{)4- - b15- 1 CD Rom ai~ì ~19trrDlo . :2t)2-00'/ t2#) -I(:>~ .2 Ó '-I ·11::< ~ 'f ~ J..~¿ 2oi/- O<{ð'~ Ao 1-o2ct / ;2.0(- I 'F . 02122105 Schlumberger NO. 3346 Schlumberger-DCS 2525 Gambell S~ Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska 011 & Gas Cons Comm Artn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Milne Point Midnight Sun Well Job # Color Log Description Date BL CD -- MPS-21 10670013 MEM CBL 05/03/04 1 -- MPE-25 L 1 10667675 CBL 03/30/04 1 - MPG-19 10900120 SCMT 11/25/04 1 .MPB-27 10964102 SCMT 11/30/04 1 ~ MPE·25A 10703992 SCMT 04/18/04 1 MPC-42 10830797 SCMT 05/01/04 1 E-102 10672379 RST 05/01/04 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Recei~' Date Oelivered: :¢Ælx v I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~n q Hö4 DATE: Tuesday, August 31, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-25A MILNE PT UNIT SB E-25A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: /,;:ßt2-- P.I. Suprv ,-I . Comm NON-CONFIDENTIAL Well Name: MILNEPT UNIT SB E-25A API Well Number: 50-029-22980-01-00 Inspector Name: John Crisp Insp Num: mitJCr040830 165257 Permit Number: 204-G4 5-0 Inspection Date: 8/28/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well E-25A Type Inj. S TVD 4462 IA 0 2500 2350 2325 P.T. 2040450 TypeTest SPT Test psi 1061.5 OA Interval INITAL PIF P Tubing 1280 1280 1280 1280 Notes: This well is a sidetracked producer w/liner top in surface casing. No OA to monitor. Tuesday, August 31,2004 Page 1 of I RE: MPE-25A e e Subject: RE: MPE-25A From: "Johnson, James H (SIS)" <JohnsoJH@BP.com> Date: Tue, 03 Aug 200415:18:51 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> ./ Jo1f-D'fb Tom When you open the zip, remove the file and place it into another folder. This is standard operating procedures provided to all of our clients by the PAC. This allows us to protect the integrity of the data and the congenitally. Tom if you need any thing else I'm more the happy to help! Regards -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, August 03,2004 2:41 PM To: Johnson, James H (515) Subject: Re: MPE-25A James, Thanks for the log. So others can access this file, how do I remove the password. Is this a new protocol?? I have not received other files encrypted from 808. Tom Maunder Johnson, James H (818) wrote: *********************** Warning: Your file, Combined.zip/Combined.PDS, is password-protected. It was not scanned by InterScan. ***********-*********** Tom The requested data files for MPE-25A is enclosed in this zip file. This file is password protected, I will send you the password via separate e-mail. If you have any problems accessing this data please give me a call. ~1JU41"lÚ «Combined.zip» James Jl Jofmson IData 'Teclinicían IJ?etrotec/inica[ IData Center œœX( (907)564-4091 W( (907)564-4005 'F~ 1 of 1 8/3/20043:29 PM Re: MPC-42 and MPE-25A e Subject: Re: MPC-42 an MPE-25A From: Thomas Maunder maunder admin.state.ak.us> Date: Fri, 23 Ju12004 12:21 :33 -0800 To: Pat Archey <archeypj@bp.com>, Sondra Stewman <StewmaSD@BP.com> .~ fJ·tL-"'.,....,~.. ~, CÃ' ·T·~-;-" .- Pat and Sondra, It would help if you could send the bond log for MPE-25A as well. Thanks, Tom Thomas Maunder wrote: Pat and Sondra, I have just looked at the 407 for MPC-42. Looks like the operatio ell and the precautions of top-set with drilling liner allow well to be successfully drilled. Since this is an injection ,I need to conduct a review/verification of the construction. ast piece I need to complete that review is the bond log run on May hard copy of the bond log may have been submitted, however due llled position our filing is lagging a bit. Is it possible to for me an electronic copy of the SCMT log dated May 1?? Your assistance . be appreciated. I would also like to have an opportunity to discuss e might employ a process I use with Alpine to expedite this review pr ss. Thanks. om Maunder, PE AOGCC 1 of 1 7/23/20041:12 PM e e dùY ....OLt ~ MECHANI CAL INTEGRITY REPORT· .... '-t. ( \ ",,-1'"\ L , ::?UD D.-".::::: _ v ~ ?~G 2E:'.s;_s:;:::· L{/J.ü -a L\ TD: %~d- Ç"MD.. "-\'-\Co)TVD i ::?BTD: ~àl ~ 11]) Y'1l(CrvD OPER & FIELD ß D M'\\~ ?~ M\/E-d-S~ k""ELL NUMBER ~T'i!:.LL DATA Casir;g: Shoe: MD TVD j DV: MD ·T'Yu _=-:>e::-: L\ L J"ð- Shoe: «~) ç MD -=-'-10 i:;g: 'dì{c¿ Packer 'l'6"d \ l1D ::ole Size G\t~ ana I.-\LiQ-TVD j :01': d \Y.~ ~'ill XJGf.o:TD TV1); Set ê. t '\ <is l ~ d-'~-\<.~CI..\~ Perfs "1~5"~ to ~O\Sø l...\ð<1.<6 '-tšS~ ~~~ :-::EC?.Þ...NICl-..L INTEGRITY - PART /l Annulus Press Test: IE 15 min 30 min COŒi!Ilents: /' ~CH.1ÜrICÞ.L INTEGRITY - PART /2 r4 <:Os \0":>' ~o.\<:.J Cù<:''-4. \Cé:ca.~ Cement Volumes:· þ...mt. Liner \()~...,,-\c;,\\; Csg ; DV Cwt ~Jol to cover perfs G ~O(O )...~ <; \ S'f... C\-Qt-'I(tu\"'\- ":.v\tK~'\ ~ <...0'-'<n- \.::. ~ r ~ \'-,) ~ SC:\~ ( Theore tical Toe <: 3c) ~ '/... ~ \Gc.... ~ S'-\ ao M....2) SCt-\. "" '\ 1\<61 C,,-\ Cement Bond Log (Yes or No) ~(~ i In AOGCe File ~~.~ CBL Evaluation, zone aDove perfs ~~I~~~ \'J:ð~\t:)~~~ Produ~tion Log: Type Evaluation CONc.LUSIONS: ?art f1: '""' 'S:: \ '> '\ '~::n =- ~/Rft4 ü ~ .. .. ~{~- ? ar:: f 2 : 'ò .. STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revision: 07/21/04, Start Injection ~ 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ aWINJ D WDSPL No. of Completions One Other D Stratigraphic a Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/20/2004 204-045 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/12/2004 50- 029-22980-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/15/2004 MPE-25A 3708' NSL, 2011' WEL, SEC. 25, T13N, R10E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 4348' NSL, 78' WEL, SEC. 35, T13N, R10E, UM KBE = 56.95' Milne Point Unit / Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 4074' NSL, 266' WEL, SEC. 35, T13N, R10E, UM 8279 + 4440 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 569134 y- 6016245 Zone- ASP4 8325 + 4462 Ft ADL 025518 TPI: x- 565832 y- 6011575 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 565647 y- 6011299 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes aNo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, PWD , IFRlCASANDRA 2. CASING, LINER AND CEMENTING RECORD ~ CÀSING i :S~TTING EP'I'I1MD SETlll1G ij:PTHTVD HOLE SIZE WT.PER FT. ... GRADE. lOP tsOTTOM TOP ¡BOTTOM SIZE 20" 94# H-40 29' 109' 29' 109' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 29' 2280' 29' 2176' 9-7/8" 735 sx AS III, 665 sx Class 'G' 4-1/2" 12.6# L-80 2148' 8325' 2066' 4462' 6-1/8" 92 sx Lite Crete, 115 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ,. USING RECORD i Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 SPF 2-7/8", 6.16#, L-80 7879' 7821' MD TVD MD TVD I~§·/ .Îí."'n .... .ETr: it 7958' - 7978' 4298' - 4306' -.~'w, 8076' - 8096' 4346' - 4354' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1950' Freeze Protected with 59 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 26,2004 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF W A TER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ORIGINAl ·-'BFl 'Jt 2 f:f i. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (yr 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SBF2-NA SBF21 SBF24-MF SBF1-NB SBF-12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBD-OB SBA5 7575' 7600' 7640' 7650' 7696' 7723' 7739' 7763' 7789' 7891' 7954' 8015' 8069' 8120' 4160' 4169' 4182' 4186' 4202' 4211' 4217' 4225' 4235' 4272' 4296' 4320' 4343' 4365' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr Title Technical Assistant Date 07 - z /- 0 ;) MPE-25A Well Number Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 204-045 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . STATE OF ALASKA __ ALAS~IL AND GAS CONSERVATION COMI\ìhSSION WELL COMPLETION OR RECOMPLETION REPORT AND l(M J'" , UN n 9 ')nn/1 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended DWAG A 1b. Well Class: 20AAC 25.105 20AAC 25.110 ., £, b1 a~JèIÓpmé.ht;;.. c uS:,ffi*~!øfatory DGINJ 181 WINJ D WDSPL No. of Completions One Other D Stratifl@ijoiç,Tt¡I,st 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Klumber BP Exploration (Alaska) Inc. 4/20/2004 ¡ 204-045 3. Address: 6. Date Spudded I 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/12/2004 / 50- 029-22980-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/15/2004 ' MPE-25A 3708' NSL, 2011' WEL, SEC. 25, T13N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 4348' NSL, 78' WEL, SEC. 35, T13N, R10E, UM KBE = 56.95' Milne Point Unit 1 Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 4074' NSL, 266' WEL, SEC. 35, T13N, R10E, UM 8279 + 4440 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: 569134 6016245 Zone- ASP4 , 8325 + 4462 Ft ADL 025518 x- y- TPI: x- 565832 y- 6011575 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 565647 y- 6011299 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo N/A MSL 1800' (Approx.) 21. Logs Run: MWD , GR , RES, PWD , IFRlCASANDRA ?2. CASING, LINER AND CEMENTING RECORD ~~~~G SETTING )FPl"'WMK SETTING! EPTI{'I'\4> I·~?-if. -. WT. Pt;R.f"T. \:I~LJI: . TOP. BOTTOM TOP I BOTToM 20" 94# H-40 29' 109' 29' 109' 30" 260 sx Arctic SetTADDrox.)· 7" 26# L-80 29' 2280' 29' 2176' 9-7/8" 735 sx AS III, 665 sx Class 'G' 4-1/2" 12.6# L-80 2148' 8325' 2066' 4462' 6-1/8" 92 sx Lite Crete, 115 sx Class 'G' 23, Perforations open to Production (MD + TVD of Top and 24. TUBING RecORD i' ii ..... . Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SeT (MD) PACKER SeT (MD) 2-7/8" Gun Diameter, 6 SPF 2-7/8", 6.16#, L-80 7879' 7821' MD TVD MD TVD 25. . ÀÇlll, ·î:f'rR·i 7958' - 7978' 4298' - 4306' 8076' - 8096' 4346' - 4354' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1950' Freeze Protected with 59 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press, 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r'[~~;;Pi-rõrp 1dl, 1~~~ ¡ . "" ..._11 'I JlM ORIGINAL I f\r," * None RBf)MS BfL ' :L.i.Q~! i~¡ ~ '.'!.~j',. "Lv _~ : :-~ ~~ > v_.-;i~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 6Y' . , 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SBF2-NA SBF21 SBF24-MF SBF1-NB SBF-12 SBE4-NC SBE41 SBE3-ND SBE2-NE SBE1-NF TSBD-OA TSBC TSBD-OB SBA5 7575' 7600' 7640' 7650' 7696' 7723' 7739' 7763' 7789' 7891' 7954' 8015' 8069' 8120' 4160' 4169' 4182' 4186' 4202' 4211' 4217' 4225' 4235' 4272' 4296' 4320' 4343' 4365' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. . ....-- ~~...,~ Signed S 'd~a Stewm c~itle 204-045 Technical Assistant Date DlC2 - 07 -o~ MPE-25A Well Number Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Walter Quay, 564-4178 Permit NO.1 A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 (ìDI('!",/^ ! Tree: 3-1/8" FMC horizontal. ~: 11" x 11" 5M tbg. vol, Tubing hgr. 11"x 2-7/8" mod. up tbg. Top & 8tm with H-Profile 20" 94 #/ft H-40 æJ Baker Tie back Sleeve Baker 7"x 51/2" "ZXP" Liner top pkr Baker 7"x 51/2" Flex-lock hyd. pkr. 2,148' 2,156' 2,162' KOP@65O' Max wellbore Angle: 700 @ 4040' Hole angle through perfs ~ 64 deg. 2-3/8",4.6 #/ft L-80, ST-L tubing (drift id ~ 1.901, cap.~.00387 bpf) 2-7/8" 6.4 ppf, L-80 ST-L / TC-II tbg. (drift id ~ 2.347" cap. .00592 bpf) 4.5" 12.6 #/ft , L-80 , IBT-mod. ( drift id = 3.958" , cap = 0.0125 bpf ) 7" 26 ppf, L-80, Btrc. production casing (drift ID ~ 6.151", cap. ~ 0.0383 bpf) Perforation Summary Ref log: SCMT Cement Bond log 4/18/04 Size SPF Interval (TVD) 2-7/8" 6 7,978' - 7,958' 4,354' - 4,345' 2-7/8" 6 8,096' - 8,076' 4,305' - 4,297' Guns used :2-7/8" HSD, Powerjet, 6 spf Original well bore notes: Sidetrack bridge plug @ 2370' RAtag @ 6197' MP E-25a DATE REV. BY COMMENTS 12/08/00 MOO Initial completion by Doyon 141 04/01/04 -. MDO De-Completion Nabors 4-es 04/16/04 MDO Sidetrack Completion Doyon - 14 ,. e KB elev. ~ 51.75' Doyon 141 DF elev. ~ 28.55' Doyon 141 GL elev. ~ 23.20' Doyon 141 2-7/8" HES X-Nipple( 2.313") 11,996" 2-7/8" HES XN-Nipple( 2.250" No Go ) 17,808' I 7,819'1 2-7/8" x 2-3/8" X-Over 4.5"x 2-3/8" Baker FH Retrievable Pkr. I 7,821' I 2-3/8" HES X-Nipple ( 1.875"id ) I 7,846' I Baker Hydro-Trip sub I 7,867' I WLEG I 7,879'1 4.5" Baker Float Collar 4.5" HES Float collar 4.5" HES Float shoe 8,236' 8,279' 8,325' MILNE POINT UNIT WELL E-25a API N~ 50-029-22980-01-00 BP EXPLORATION AK) _7.' .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-25 MPE-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 4/20/2004 Rig Number: 14 Spud Date: 11/6/2000 End: 4/10/2004 4/1 0/2004 04:30 - 05:00 0.50 MOB P PRE Skid rig floor 05:00 - 07:00 2.00 MOB P PRE Move of MPC-43 well. spot rig on pad 07:00 - 12:00 5.00 MOB P PRE Install boosters, Remove cellar doors, move rig to road 12:00 - 16:30 4.50 MOB P PRE Move rig and camp to MPE-25A, Remove Boosters, install cellar doors 16:30 - 18:30 2.00 MOB P PRE Spot rig over MPE-25A, slide floor over well, rig up Rig accepted @ 18:30 hrs 4/10/2004 18:30 - 21 :00 2.50 MOB P PRE N/D Tree/Adapter, pull Tbg hanger 21 :00 - 00:00 3.00 RIGU P PRE Nipple up BOPS 4/11/2004 00:00 - 01 :00 1.00 RIGU P PRE Pre-Spud meeting with crews 01 :00 - 02:00 1.00 RIGU P PRE Rig up to Test Bops 02:00 - 05:30 3.50 BOPSU P PRE Test BOPS and Manifold to 250-3500 psi 5 min per test Hydril 250-2500 psi 5 min. per test, the right to witness test was wavier by Jeff Jones AOOGC 05:30 - 06:00 0.50 BOPSU P WEXIT Test csg to 3000 psi for 30 min. 06:00 - 06:30 0.50 BOPSU P WEXIT Install wear ring, rig down Test Equipment 06:30 - 07:30 1.00 STWHIP P WEXIT Pickup 4" pipe to 550' displace diesel out of well with water 07:30 - 16:00 8.50 STWHIP P WEXIT Picking up pipe to 2,000' and standing back in derrick, till we had total of 75 stands in derrick. 16:00 - 17:30 1.50 STWHIP P WEXIT Picking up 61/8 mill assembly, 1-5 hwp,9-4 3/4 dC,15 jts hwp, 17:30 - 18:00 0.50 STWHIP P WEXIT Trip in to top of retainer @ 2,374' 18:00 - 18:30 0.50 STWHIP P WEXIT Displace well with 9.0# LSND mud 18:30 - 19:30 1.00 STWHIP P WEXIT Trip out of hole 19:30 - 00:00 4.50 STWHIP N RREP WEXIT Top Drive repair 4/12/2004 00:00 - 02:00 2.00 STWHIP P WEXIT Slip and cut drill line 02:00 - 03:00 1.00 STWHIP P WEXIT Mobilize Whipstock BHA,PJSM on picking up and setting whipstock 03:00 - 05:00 2.00 STWHIP P WEXIT Picking up space out tubing and BHA #2, Test MWD 05:00 - 05:30 0.50 STWHIP P WEXIT Tripping in with whipstock 05:30 - 06:00 0.50 STWHIP P WEXIT Orient and set whipstock with 25k straight up (high side), top of whipstock window will be @ 2,280 06:00 - 09:30 3.50 STWHIP P WEXIT Mill window top @ 2280 bottom 2292, 270 gals min 860 psi,11 0 rpms, Drill new hole to 2306' 09:30 - 10:00 0.50 STWHIP P WEXIT Circ, work window,pump sweeps 10:00 - 11 :00 1.00 DRILL P WEXIT Fit to 11.5 with 9.0 mud wt, 290 psi, tvd 2175=11.5 11 :00 - 11 :30 0.50 STWHIP P WEXIT Trip out to BHA 11 :30 - 12:30 1.00 STWHIP P WEXIT Laying down BHA and mills 12:30 - 13:00 0.50 STWHIP P WEXIT Pick up Johnny Wacker, flush BOPS 13:00 - 14:00 1.00 DRILL P PROD1 Pick up BHA #3 MGR750X bit with 5x10 jets,5" Sperry drill,stab,float sub,DGH/EWR,HOS,TM,3 flex dc,jars,2 HWP, Test MWD 14:00 - 14:30 0.50 DRILL P PROD1 Trip in hole to whipstock 14:30 - 15:00 0.50 DRILL P PROD1 Orient and slide thru window, clean hole ECD 10.3 15:00 - 00:00 9.00 DRILL P PROD1 Directional Drill 2306 to 3260 with 90 rpms, 250 gals min, 1700 psi AST 4.23,ART 2.05, ECD 11.1 4/13/2004 00:00 - 00:30 0.50 DRILL P PROD1 Directional Drill 3260' to 3323' with 90 rpms, 250 gals min, 1700 psi 00:30 - 01 :30 1.00 DRILL P PROD1 Circ. due to high ECDs up to 11.8, circ 2.5 bottoms up dropped to 11.0 01 :30 - 21 :00 19.50 DRILL P PROD1 Directional Drill 3323' to 5079 ' with 90 rpms, 250 gals min, 1700 psi ECD jump from 11.0 to 11.7 in about 30 ft. of drilling, control drill 75 to 100 ft. hr., till Ecd dropped to 11.1, step rate up to Printed: 4/30/2004 1 :41 :46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-25 MPE-25 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 4/20/2004 Rig Number: 14 Spud Date: 11/6/2000 End: 4/10/2004 4/13/2004 01 :30 - 21 :00 19.50 DRILL P PROD1 150 ft. per hr ECD running 11.25, ECD continued to climb to 11.7 21 :00 - 21 :30 0.50 DRILL P PROD1 Circulate Bottoms Up X 2 21 :30 - 23:00 1.50 DRILL P PROD1 Pump out of hole to window, Pulled tight f/4775' to 3452'-reduced pulling speed to prevent packing off 23:00 - 23:30 0.50 DRILL P PROD1 Circulate Bottoms Up @ window, ECD reduced to 10.25 23:30 - 00:00 0.50 DRILL P PROD1 Orient to high side w/ motor & Run in Hole w/ Drill Pipe to 3000' 4/14/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Run in hole f/3000' to 4890-As Precaution Wash Down Last Stand f/ 4980' to 5079' 01 :00 - 08:00 7.00 DRILL P PROD1 Directional Drill f/5079' to 5450'-Rotating @ 100 RPM, Pumping 250 gpm-1858psi, torque 5000-5500 ftllbs, ECD 11.4 ppg EMW 08:00 - 08:30 0.50 DRILL P PROD1 Pump 10.3 ppg Weighted Sweep to Reduce ECD-Intial ECD 11.63ppg EMW-ECD After Sweep 11.2ppg EMW 08:30 - 00:00 15.50 DRILL P PROD1 Directional Drill f/5588' to 6731 -Rotating @ 90-110 RPM, WOB 0-3K Pumping 250 gpm-1990psi, Torque 5000 ftllbs, ECD 11.4 ppg EMW 4/15/2004 00:00 - 19:30 19.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 6,731' To 8,325' WOB Rotating 2,000# - 5,000#, RPM 100, Motor RPM 192, Torque Off Bottom 7,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 250 gpm, SPP Off Bottom 2,080 psi, On Bottom 2,400 psi. String Weight Up 135,000#, String Weight Down 80,000#, String Weight Rotating 99,000#. ART- 10.09, AST - 3.29. 19:30 - 21 :30 2.00 DRILL P PROD1 Circulate Bottoms Up-Pump Weighted Sweep-Circulate Surface to Surface-ECD 11.55ppg EMW 21 :30 - 23:30 2.00 DRILL P PROD1 Pump Out Of Hole f/ 8325'-6050' @ 2250 GPM-Packing Off Became Problematic @ 6,050' 23:30 - 00:00 0.50 DRILL P PROD1 Backreaming f/ 6,050'-5954 @ 250 GPM & 100 RPM 4/16/2004 00:00 - 02:30 2.50 DRILL P PROD1 Backreaming f/5954'-5600 @ 300 GPM & 110 RPM 02:30 - 03:00 0.50 DRILL P PROD1 Attempted to Pump Out Of Hole f/ 5600'-5460' Packed Off 03:00 - 07:30 4.50 DRILL P PROD1 Backreaming f/5954'-4685' @ 300 GPM & 110 RPM-Pump Out Of Hole f/ 4685'-2270' 07:30 - 08:00 0.50 DRILL P PROD1 Circulate Bottoms Up 08:00 - 10:00 2.00 DRILL P PROD1 Run In Hole to 8325'-Precautionary Reamed 72' to Bottom 10:00 - 12:30 2.50 DRILL P PROD1 Circulate Bottoms Up X 5 While Weighting Up To 9.5ppg 12:30 - 15:30 3.00 DRILL P PROD1 Pump Out Of Hole f/8235' To Window @ 2280' 15:30 - 16:00 0.50 DRILL P PROD1 Circulate Bottoms Up 16:00 - 17:00 1.00 DRILL P PROD1 Pull Out Of Hole To BHA 17:00 - 18:00 1.00 DRILL P PROD1 Lay Down BHA-Clear Rig Floor 18:00 - 19:00 1.00 CASE P COMP PJSM & Rig Up To Run 4.5" Liner 19:00 - 22:00 3.00 CASE P COMP Run In Hole wI 4.5" Liner-Tagged Up @ 3085'-Attempted To Work Past This Spot-No Go 22:00 - 23:00 1.00 CASE P COMP Attempted to Pump Liner Down @ 20-90 SPM & 250-480 psi-Placed Torque In String & Work Liner Through Tight Spot-Would Not Go Past 3085'-PU Wt. 80K-SO Wt. 70K 23:00 - 23:30 0.50 CASE N DPRB COMP Rig Up To Lay Down Liner-Flow Check-Pump Slug 23:30 - 00:00 0.50 CASE N DPRB COMP Lay Down 4.5 Liner 4/17/2004 00:00 - 02:30 2.50 CASE N DPRB COMP Lay Down 4.5 Liner To 755' -Joint #19 02:30 - 03:00 0.50 CASE N DPRB COMP Run In Hole Removing Damaged Centralizer From Joint # 19-Removed Both Centralizers and Stop Rings From Joint #19 & #20-Removed 1 Centralizer and Stop Ring from Joint #21-#23 Printed: 4/30/2004 1 :41 :46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-25 MPE-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 4/20/2004 Rig Number: 14 Spud Date: 11/6/2000 End: 4/10/2004 4/17/2004 03:00 - 04:00 1.00 CASE N DPRB COMP Run In Hole wI 4.5" Liner To Window @ 2280' 04:00 - 04:30 0.50 CASE N DPRB COMP Circulate Bottoms Up @ 50 SPM-370 psi 04:30 - 06:00 1.50 CASE N DPRB COMP Run In Hole With 4.5" Liner f/2280' to 3080' 06:00 - 08:00 2.00 CASE P COMP Run In Hole With 4.5" Liner f/3080' to 6180' 08:00 - 09:00 1.00 CASE P COMP Make Up Hanger & Circulate Liner Volume @ 50 spm-800 psi-P/U 102K-S/0 70K 09:00 - 10:30 1.50 CASE P COMP Run In Hole With 4.5" Liner f/ 6180 to 8300' 10:30 - 11 :00 0.50 CASE P COMP ig Up Cement Head & Hoses-Tag Bottom @ 8325' 11 :00 - 13:30 2.50 CASE P COMP Circulate & Reciprocate-P/U122K S/078K-Stage Pump Up From 28 spm-850psi to 50 spm-1000psi-Batch Mix Cement-PJSM 13:30 - 15:00 1.50 CEMT P COMP Cement Job-Pump 5 bbl H20-Pressure Test Lines to 4500 psi-Pump 15 bbl CW-100 @ 8.34 ppg-Pump 25 bbl Mud Push if @ 10.3 ppg-Pump 42 bbllead Cement @ 12.0 ppg-Pump 21 ;¡ bbI Tail Cement @ 15.8 ppg-Drop Wiper Dart & Displace wI 114 bbl of 9.2 Brine-Latch @ 23 bbl-Bump Plug & Set Hanger @ 114 bbl & 2500-Pressure up to 4500 psi to Set ZXP Packer w/ Hydraulic Setting Tool-Displace Well w/ Seawater @ 12 bbl/min Until Cleaned Up-Displace to 9.2 Brine 15:00 - 15:30 0.50 CEMT P COMP Rig Down Cement Head & Lay Down In Pipe Shed 15:30 - 17:00 1.50 CEMT P COMP Cut Drilling Line & Service Top Drive 17:00 - 18:30 1.50 CEMT P COMP Pull Out Of Hole w/ Drill Pipe & Lay Down Running Tool 18:30 - 21 :00 2.50 CEMT P COMP Lay Down Drill Pipe Out Of Derrick In Mousehoule In Preperation For Rig Move 21 :00 - 21 :30 0.50 CEMT P COMP Pull Wear Bushing-Rig Up to Test BOPE 21 :30 - 00:00 2.50 CEMT P COMP Test BOPE-250psi Lo/3500psi High-AOGCC Witness Waived By Chuck Sheave 4/18/2004 00:00 - 01 :00 1.00 CEMT P COMP Test BOPE-250psi Lo/3500psi High-AOGCC Witness Waived By Chuck Sheave 01 :00 - 02:30 1.50 EVAL P COMP Change Top Pipe Rams to?" For Wireline Lubricator-Full Body Test On BOP To 2500 PSI 02:30 - 05:00 2.50 EVAL P COMP PJSM-Rig Up Schlumberger For Wirelining 05:00 - 06:30 1.50 EVAL N SFAL COMP Diagnose & Repair Logging Tool Failure 06:30 - 08:00 1.50 EVAL N DPRB COMP Run In Hole wI USIT-Could not go past 2805'-Schlumberger Engineer Concluded That The .39" Wireline Was Too Large & Friction In The 64 Degree Well Bore Was Preventing The Tools From Going Down-A Wireline Truck With Small Diameter Line (.23) Was Ordered 08:00 - 09:00 1.00 EVAL N DPRB COMP Rig Down Schlumberger Wireline 09:00 - 10:00 1.00 EVAL P COMP Pressure Test Casing To 4000 psi for 30 Minutes 10:00 - 15:30 5.50 EVAL N WAIT COMP Wait On Schlumberger Wireline Truck w/ .23 Wireline 15:30 -17:00 1.50 EVAL N DPRB COMP Rig Up Schlumberger E-Line w/ .23 Wireline 17:00 - 18:30 1.50 EVAL N DPRB COMP Run In Hole wI CCUGR/Junk Basket/3.781 Gauge Ring-Could Not Go Past Liner Tie Back Sleeve @ 2148' 18:30 - 19:30 1.00 EVAL N DPRB COMP Rig Down CCUGR/Junk Basket/Gauge Ring-R/U SCMT 19:30 - 00:00 4.50 EVAL P COMP Run In Hole wI SCMT On .23 Wireline to 8213' And Log Up To Top Of Cement 4/19/2004 00:00 - 00:30 0.50 EVAL P COMP Rig Down SCMT Logging Tools 00:30 - 02:00 1.50 PERF P COMP PJSM-Pick Up 2 7/8 20' Perforation Guns w/6 SPF-Test lubricator & Packoff To 500 psi 02:00 - 03:30 1.50 PERF ( COMP Run In Hole wI Perforation Guns & Perforate 4.5" Uner fl 8076 to 8096 MD I Pnnted: 4/30/2004 1 :41 :46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-25 MPE-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/10/2004 Rig Release: 4/20/2004 Rig Number: 14 Spud Date: 11/6/2000 End: 4/10/2004 4/19/2004 03:30 - 04:00 0.50 PERF CaMP Observe Well For Flow-No Gains Or Losses Observed-Pull Out Of Hole w/ Perforation Guns 04:00 - 05:00 1.00 PERF P CaMP PJSM-Pick Up 2 7/8 20' Perforation Guns wI 6 SPF-Run #2 05:00 - 07:00 2.00 PERF P CaMP Run In Hole wI Perforation Guns & Perforate 4.5" Liner f/7958 to 7978 07:00 - 07:30 0.50 PERF P CaMP Observe Well For Flow-No Gains Or Losses Observed-Pull Out Of Hole wI Perforation Guns 07:30 - 08:30 1.00 PERF P CaMP Lay Down Perforation Guns-Make Up 3.781 Gauge Ring & Junk Basket 08:30 - 09:30 1.00 EVAL P CaMP Run In Hole wI Gauge Ring & Junk Basket- No Go Past 2748' 09:30 - 10:00 0.50 EVAL P CaMP Duct Tape Found Around End Of Gauge Ring-Remove Centralizer 10:00 - 10:30 0.50 EVAL P CaMP Run In Hole w/3.78 Gauge Ring & Junk Basket-Would Not Go Past Liner Tie Back @ 2148'-Pull Out Of Hole 10:30 - 11 :30 1.00 EVAL N DPRB CaMP Run In Hole wI 3.78 Gauge Ring, Junk Basket & Modified Centralizer-Would No Go Past Liner Tie Back @ 2148'-Pull Out Of Hole 11 :30 - 12:30 1.00 EVAL N DPRB CaMP Run In Hole wI 3.78 Gauge Ring, Junk Basket & Modified Centralizer Moved Closer To Gauge Ring-Would Not Go Past 3890'-Pull Out Of Hole 12:30 - 15:00 2.50 EVAL N DPRB CaMP Change Gauge Ring To 3.75-Run In Hole-Would Not Go Past 3890'-Pulled Out Of Hole 15:00 - 15:30 0.50 EVAL N DPRB CaMP Rig Down Schlumberger E-Line 15:30 - 17:00 1.50 EVAL N WAIT CaMP Wait On Halliburton Slickline 17:00 - 18:30 1.50 EVAL N DPRB CaMP PJSM-Rig Up Halliburton Slickline 18:30 - 21 :00 2.50 EVAL P CaMP Run In Hole wI 3.75 Gauge Ring On Halliburton Slickline To 7850'-Tagged @ 3919'-Beat Down f/3919' To 3970'-Fell Free f/ 3970' To 4333'-Beat Down f/ 4333' To 4382'-Fell Free f/ 4382' To 5364'-Beat Down f/5364' To 6700'-Fell Free To 7850'-Pull Out Of Hole 21 :00 - 21 :30 0.50 EVAL P CaMP Rig Down Halliburton Slickline 21 :30 - 22:30 1.00 RUNCO CaMP Change Top Pipe Rams To 2 7/8-Pressure Test To 250 psi-Lo/3500 psi-High 22:30 - 00:00 1.50 RUNCO CaMP Rig Up To Run 2 7/8 Completion String 4/20/2004 00:00 - 00:30 0.50 RUNCO CaMP Rig Up To Run 2 7/8 STL Tubing w/ Torque Turn 00:30 - 02:00 1.50 RUNCO CaMP Run 2718 STL Tubing wI Torque Turn-Could Not Get Tongs To Torque Pipe @ Low Values Required By This Connection (800-1000 ftIlbs) 02:00 - 03:00 1.00 RUNCO CaMP Rig Down Torque Turn Tongs-Rig Up Manual Tongs 03:00 - 14:30 11.50 RUNCO CaMP Make up 2 3/8" Tail pipe assembly with Baker 4.5 x 2 3/8 'FH' Retrievable Packer, xo above packer to 2 7/8" - RIH w/188 its 27/8" 6.16# L-80 STL + 65 its 2 7/8 6.4# L-80 TCII R-2 Tubing 14:30 - 15:00 0.50 RUNCO CaMP Make up FMC 11" x 2 7/8 TC-1A-ENS tubing hanger - Land tubing string, Run in lock down screws, p/u wt. 75k, s/o wt. 63k, block wt 50k 15:00 - 16:00 1.00 RUNCO CaMP Rig up hot oil truck, Test lines to 4000 psi, Freeze protect annulus to 1950' with 59 bbls of diesel. 16:00 - 18:00 2.00 RUNCO CaMP Drop 1.75" ball. Wait on ball to fall and bullhead ball to seat in Hydro-trip sub. Pressure up with hot oil truck to 4,000 psi to set packer @ 7,820' MD and test tubing to 4,000 psi for 30 minutes on chart. Pressure up and blow ball seat with 4,700 psi. Bleed off presure. Printed: 4/30/2004 1:41 :46 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-25 MPE-25 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 4/1 0/2004 4/20/2004 14 Spud Date: 11/6/2000 End: 4/10/2004 19:00 - 21 :00 2.00 COMP Set Two way check - test from above - Nipple down and set back Bop stack Nipple up FMC 11 x 2 9/16 5k Tubing head adapter and CIW 2 9/16 5000k Tree - Test hanger pack-off to 5000 psi, Test tree to 4000 psi -ok - Pull Two way check with lubricator, no pressure on well. Rig up hot oil truck, Test 7 x 2 7/8 annulus to 4000 psi for 30 minutes on chart - Bull head 12 bbls of diesel down tubing for freeze protection to 2073' - Rig down hot oil truck Set CIW 2 1/2" type 'H' BPV with lubricator - Secure well, Clear cellar - Rig Released at 2400 hrs 4/20/04 21 :00 - 23:00 COMP 23:00 - 00:00 1.00 RIGD P COMP Printed: 4/30/2004 1 :41:46 PM 11/19/2000 6,740.0 (ft) 4,332.0 (ft) 9.10 (ppg) 430 (psi) 2,478 (psi) 11.01 (ppg) 11/27/2000 (ft) (ft) (ppg) (psi) (psi) 11.01 (ppg) 11/19/2000 6,699.0 (ft) 4,434.0 (ft) 9.10 (ppg) 430 (psi) 2,526 (psi) 10.97 (ppg) 4/10/2004 1.0 (ft) 1.0 (ft) 1.00 (ppg) (psi) o (pSi) 1.00 (ppg) 4/12/2004 2,280.0 (ft) 2,175.0 (ft) 9.00 (ppg) 283 (psi) 1,300 (psi) 11.50 (ppg) Printed: 4/30/2004 1 :41 :33 PM Halliburton Sperry-Sun DEFINITIVE Milne Point Unit BPXA Milne Point MPE MPE-25A e Job No. AKZZ3017307, Surveyed: 15 April, 2004 Survey Report 4 May, 2004 Your Ref: API 500292298001 Surface Coordinates: 6016244.97 N, 569134.13 E (70· 27' 17.0704" N, 149· 26' 08.9914" W) ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1016244.97 N, 69134.13 E (Grid) Surface Coordinates relative to Structure Reference: 2449.03 N, 283.88 W (True) Kelly Bushing Elevation: 56. 95ft above Mean Sea Level Kelly Bushing Elevation: 56. 95ft above Project V Reference Kelly Bushing Elevation: 56. 95ft above Structure Reference SP'E!!I'""'I'""')J-SU:1'1 DRILLING 5ERVlt:e5 A Halliburton Company Survey Ref: svy1386 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A Your Ref: API 500292298001 Job No. AKZZ3017307, Surveyed: 15 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 2253.60 33.300 219.970 2097.10 2154.05 379.43 S 297.84 W 6015862.80 N 568839.82 E -382.17 Tie On Point 2280.00 33.320 219.280 2119.16 2176.11 390.59 S 307.09 W 6015851.54 N 568830.68 E 1.437 -393.43 Window Point 2312.76 36.190 219.190 2146.07 2203.02 405.06 S 318.90 W 6015836.97 N 568819.00 E 8.762 -408.00 2409.96 41 .220 218.910 2221.90 2278.85 452.25 S 357.17 W 6015789.43 N 568781.17 E 5.178 -455.54 2502.39 46.510 216.950 2288.52 2345.47 502.78 S 396.48 W 6015738.53 N 568742.33 E 5.908 -506.44 e 2598.44 53.400 214.020 2350.29 2407.24 562.66 S 439.06 W 6015678.26 N 568700.31 E 7.543 -566.71 2697.64 59.220 213.040 2405.29 2462.24 631.45 S 484.61 W 6015609.05 N 568655.40 E 5.924 -635.92 2792.44 64.610 214.000 2449.90 2506.85 701.14 S 530.79 W 6015538.94 N 568609.87 E 5.755 -706.03 2889.43 69.100 213.250 2488.02 2544.97 775.38 S 580.16 W 6015464.24 N 568561.19 E 4.684 -780.73 2986.42 69.440 214.520 2522.35 2579.30 850.69 S 630.73 W 6015388.47 N 568511.32 E 1.274 -856.50 3081.78 68.850 214.920 2556.30 2613.25 923.93 S 681.48 W 6015314.76 N 568461.25 E 0.732 -930.21 3176.23 70.040 215.940 2589.46 2646.41 995.99 S 732.75 W 6015242.23 N 568410.65 E 1.616 -1002.74 3271.31 69.910 216.810 2622.02 2678.97 1067.91 S 785.73 W 6015169.81 N 568358.34 E 0.871 -1075.16 3369.35 68.650 216.450 2656.71 2713.66 1141.50 S 840.44 W 6015095.72 N 568304.32 E 1.330 -1149.25 3463.80 69.630 216.370 2690.34 2747.29 1212.53 S 892.83 W 6015024.21 N 568252.59 E 1.041 -1220.76 3560.02 69.160 216.660 2724.20 2781.15 1284.91 S 946.42 W 6014951.33 N 568199.67 E 0.564 -1293.64 3656.42 69.910 216.770 2757.90 2814.85 1357.31 S 1000.41 W 6014878.43 N 568146.35 E 0.785 -1366.54 3752.89 69.110 217.320 2791.67 2848.62 1429.44 S 1054.85 W 6014805.81 N 568092.59 E 0.986 -1439.16 3849.25 69.500 217.080 2825.73 2882.68 1501.24 S 1109.35W 6014733.50 N 568038.76 E 0.467 -1511.47 3943.67 70.950 215.950 2857.67 2914.62 1572.65 S 1162.22 W 6014661.60 N 567986.56 E 1.904 -1583.37 4040.55 70.430 215.510 2889.71 2946.66 1646.87 S 1215.61 W 6014586.89 N 567933.86 E 0.687 -1658.08 4135.56 69.890 215.550 2921.95 2978.90 1719.60 S 1267.54 W 6014513.68 N 567882.60 E 0.570 -1731.29 e 4230.78 69.630 215.350 2954.89 3011.84 1792.38 S 1319.36 W 6014440.43 N 567831.46 E 0.337 -1804.54 4327.09 69.380 214.450 2988.62 3045.57 1866.37 S 1370.98 W 6014365.96 N 567780.53 E 0.913 -1879.01 4422.96 69.890 214.450 3021.98 3078.93 1940.48 S 1421.82 W 6014291.38 N 567730.38 E 0.532 -1953.59 4519.03 70.890 215.110 3054.22 3111.17 2014.81 S 1473.44 W 6014216.58 N 567679.45 E 1.226 -2028.39 4613.84 70.540 214.910 3085.53 3142.48 2088.10 S 1524.78 W 6014142.81 N 567628.79 E 0.419 -2102.16 4710.34 70.560 215.280 3117.67 3174.62 2162.55 S 1577.10W 6014067.87 N 567577.17 E 0.362 -2177.10 4806.01 69.690 215.800 3150.19 3207.14 2235.77 S 1629.39 W 6013994.18 N 567525.55 E 1.043 -2250.79 4900.50 70.110 215.650 3182.66 3239.61 2307.80 S 1681.21 W 6013921.67 N 567474.41 E 0.469 -2323.30 4997.52 69.840 216.240 3215.89 3272.84 2381.60 S 1734.71 W 6013847.38 N 567421.59 E 0.636 -2397.59 5094.27 69.500 215.710 3249.50 3306.45 2455.02 S 1788.01 W 6013773.47 N 567368.98 E 0.622 -2471.50 5190.17 70.420 215.630 3282.36 3339.31 2528.21 S 1840.54 W 6013699.79 N 567317.13 E 0.963 -2545.18 5286.13 70.290 216.030 3314.62 3371.57 2601.48 S 1893.45 W 6013626.03 N 567264.91 E 0.415 -2618.94 5382.71 69.120 216.160 3348.12 3405.07 2674.68 S 1946.81 W 6013552.35 N 567212.22 E 1.218 -2692.62 4 May, 2004 - 18:01 Page 2 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A Your Ref: API 500292298001 Job No. AKZZ3017307, Surveyed: 15 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5478.41 69.360 215.730 3382.04 3438.99 2747.12 S 1999.34 W 6013479.41 N 567160.37 E 0.489 -2765.56 5572.98 69.510 214.730 3415.26 3472.21 2819.45 S 2050.41 W 6013406.62 N 567109.97 E 1.003 -2838.35 5669.41 70.630 215.240 3448.13 3505.08 2893.72 S 2102.39 W 6013331.87 N 567058.68 E 1.263 -2913.10 5764.67 69.770 215.100 3480.40 3537.35 2966.98 S 2154.02 W 6013258.13 N 567007.73 E 0.913 -2986.84 5860.77 70.170 214.700 3513.32 3570.27 3041.03 S 2205.68 W 6013183.60 N 566956.77 E 0.571 -3061.37 e 5955.11 70.230 214.950 3545.27 3602.22 3113.90 S 2256.37 W 6013110.27 N 566906.76 E 0.257 -3134.70 6049.80 69.640 214.970 3577.76 3634.71 3186.79 S 2307.33 W 6013036.91 N 566856.47 E 0.623 -3208.06 6147.97 69.580 215.180 3611.96 3668.91 3262.10 S 2360.21 W 6012961.11 N 566804.29 E 0.210 -3283.86 6243.23 68.920 214.660 3645.71 3702.66 3335.14 S 2411.20 W 6012887.60 N 566753.98 E 0.861 -3357.37 6339.07 68.920 214.240 3680.18 3737.13 3408.88 S 2461.79 W 6012813.39 N 566704.08 E 0.409 -3431.58 6434.71 69.960 215.740 3713.77 3770.72 3482.24 S 2513.14 W 6012739.56 N 566653.41 E 1.827 -3505.41 6531.21 69.500 216.460 3747.21 3804.16 3555.38 S 2566.47 W 6012665.93 N 566600.76 E 0.847 -3579.04 6627.01 69.840 216.960 3780.49 3837.44 3627.40 S 2620.17 W 6012593.42 N 566547.73 E 0.605 -3651.55 6722.51 70.420 216.880 3812.95 3869.90 3699.20 S 2674.12 W 6012521.11 N 566494.45 E 0.612 -3723.86 6820.20 69.630 217.180 3846.32 3903.27 3772.50 S 2729.42 W 6012447.31 N 566439.84 E 0.859 -3797.66 6916.55 70.580 215.410 3879.11 3936.06 3845.52 S 2783.04 W 6012373.79 N 566386.89 E 1.989 -3871.18 7012.27 70.170 216.310 3911.26 3968.21 3918.59 S 2835.85 W 6012300.24 N 566334.76 E 0.984 -3944.73 7108.33 69.890 215.860 3944.07 4001.02 3991.55 S 2889.03 W 6012226.79 N 566282.26 E 0.528 -4018.18 7204.98 69.510 216.790 3977.60 4034.55 4064.58 S 2942.72 W 6012153.26 N 566229.25 E 0.984 -4091.71 7300.32 68.770 215.100 4011.55 4068.50 4136.70 S 2995.02 W 6012080.66 N 566177.62 E 1.829 -4164.31 7396.42 71.000 213.840 4044.60 4101.55 4211.09 S 3046.08 W 6012005.79 N 566127.25 E 2.627 -4239.18 7492.55 71.020 213.880 4075.88 4132.83 4286.57 S 3096.73 W 6011929.85 N 566077.31 E 0.045 -4315.12 e 7588.63 70.180 214.360 4107.79 4164.74 4361.60 S 3147.56 W 6011854.35 N 566027.18 E 0.993 -4390.62 7684.60 69.760 215.050 4140.66 4197.61 4435.72 S 3198.90 W 6011779.76 N 565976.53 E 0.805 -4465.21 7780.54 68.990 215.870 4174.46 4231.41 4508.86 S 3250.98 W 6011706.14 N 565925.12 E 1.133 -4538.83 7876.71 67.900 214.940 4209.79 4266.74 4581.76 S 3302.80 W 6011632.76 N 565873.98 E 1.447 -4612.21 7971.66 67.1 00 214.140 4246.13 4303.08 4654.02 S 3352.54 W 6011560.05 N 565824.92 E 1.147 -4684.92 8067.61 64.880 214.810 4285.17 4342.12 4726.27 S 3402.15 W 6011487.34 N 565775.98 E 2.400 -4757.63 8163.47 62.340 214.650 4327.77 4384.72 4796.83 S 3451.07 W 6011416.32 N 565727.72 E 2.654 -4828.65 8245.10 61.410 215.220 4366.25 4423.20 4855.85 S 3492.29 W 6011356.92 N 565687.05 E 1.295 -4888.05 8325.00 61.410 215.220 4404.49 4461.44 4913.17 S 3532.75 W 6011299.23 N 565647.12 E 0.000 -4945.74 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 4 May, 2004 - 18:01 Page 3 of4 DríllQuest 3.03.06.002 .. Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A Your Ref: API 500292290001 Job No. AKZZ3017307, Surveyed: 15 April, 2004 ~. BPXA Milne Point Unit The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.5320 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8325.0OfI., The Bottom Hole Displacement is 6051.41f1., in the Direction of 215.7180 (True). Comments e Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 2253.60 2280.00 8325.00 2154.05 2176.11 4461.44 379.43 S 390.59 S 4913.17 S 297.84 W 307.09 W 3532.75 W Tie On Point Window Point Projected Survey Survey tool program for MPE-25A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 8325.00 4461.44 MWD Magnetic - MWD+I/FR+MS (MPE-25A) e 4 May, 2004 - 18:01 Page 4 of4 Dri/lQuest 3.03.06.002 e . 07 -May-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPE-25 A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 2,253.60' MD 2,280.00' MD 8,325.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1L.J. /7/1 I Signed I( f UiW , Date Please call me at 273-3545 if you have any questions or concerns. Regards, ;{.. ð c(- 0 L(f- William T. Allen Survey Manager RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cens. Commission Anchorage Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPE MPE-25A MWD e Job No. AKMW3017307, Surveyed: 15 April, 2004 Survey Report 7 May, 2004 Your Ref: API 500292298001 Surface Coordinates: 6016244.97 N, 569134.13 E (70027' 17.0704- N, 149026' 08.9914- W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1016244.97 N, 69134.13 E (Grid) Surface Coordinates relative to Structure Reference: 2449.03 N, 283.88 W (True) Kelly Bushing Elevation: 56.95ft above Mean Sea Level Kelly Bushing Elevation: 56. 95ft above Project V Reference Kelly Bushing Elevation: 56.95ft above Structure Reference speraray-suf'l CRfL.LfNG SH5RVU::es A Halliburton Company Survey Ref: svy1387 ^ - Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A MWD Your Ref: API 500292298001 Job No. AKMW3017307, Surveyed: 15 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2253.60 33.300 219.970 2097.10 2154.05 379.43 S 297.84 W 6015862.80 N 568839.82 E 482.17 Tie On Point 2280.00 33.320 219.280 2119.16 2176.11 390.59 S 307.09 W 6015851.54 N 568830.68 E 1.437 496.65 Window Point 2312.76 36.190 219.190 2146.07 2203.02 405.06 S 318.90 W 6015836.97 N 568819.00 E 8.762 515.30 2409.96 41.220 219.090 2221.90 2278.85 452.19 S 357.25 W 6015789.49 N 568781.09 E 5.175 576.00 2502.39 46.510 217.110 2288.52 2345.47 502.60 S 396.71 W 6015738.71 N 568742.10 E 5.912 640.00 e 2598.44 53.400 214.190 2350.29 2407.24 562.36 S 439.46 W 6015678.56 N 568699.91 E 7.540 713.46 2697.64 59.220 213.170 2405.29 2462.24 631.02 S 485.19 W 6015609.47 N 568654.82 E 5.929 795.86 2792.44 64.610 214.050 2449.90 2506.85 700.64 S 531.48 W 6015539.43 N 568609.18 E 5.744 879.36 2889.43 69.1 00 213.260 2488.02 2544.97 774.86 S 580.88 W 6015464.75 N 568560.46 E 4.689 968.40 2986.42 69.440 214.780 2522.35 2579.30 850.05 S 631;63 W 6015389.10 N 568510.41 E 1.507 1059.03 3081.78 68.850 215.140 2556.30 2613.25 923.08 S 682.69 W 6015315.60 N 568460.03 E 0.712 1148.10 3176.23 70.040 216.320 2589.46 2646.41 994.86 S 734.34 W 6015243.33 N 568409.06 E 1.719 1236.53 3271.31 69.910 216.850 2622.02 2678.97 1066.60 S 787.58 W 6015171.11 N 568356.48 E 0.541 1325.86 3369.35 68.650 216.000 2656.71 2713.66 1140.38 S 842.03 W 6015096.83 N 568302.72 E 1.520 1417.56 3463.80 69.630 216.180 2690.34 2747.29 1211.70 S 894.02 W 6015025.03 N 568251.39 E 1.053 1505.81 3560.02 69.160 216.480 2724.20 2781.15 1284.25 S 947.38 W 6014951.98 N 568198.71 E 0.569 1595.88 3656.42 69.910 216.570 2757.91 2814.86 1356.83 S 1001.13 W 6014878.91 N 568145.63 E 0.783 1686.19 3752.89 69.110 217.030 2791.67 2848.62 1429.19S 1055.26 W 6014806.05 N 568092.18 E 0.942 1776.56 3849.25 69.500 216.910 2825.73 2882.68 1501.21 S 1109.47W 6014733.53 N 568038.64 E 0.421 1866.69 3943.67 70.950 215.670 2857.67 2914.62 1572.82 S 1162.05 W 6014661.43 N 567986.72 E 1.971 1955.54 4040.55 70.430 215.520 2889.71 2946.66 1647.17 S 1215.27 W 6014586.59 N 567934.20 E 0.556 2046.96 4135.56 69.890 215.460 2921.95 2978.90 1719.94 S 1267.15 W 6014513.35 N 567882.99 E 0.571 2136.31 e 4230.78 69.630 215.300 2954.90 3011.85 1792.78 S 1318.88 W 6014440.03 N 567831.94 E 0.315 2225.64 4327.09 69.380 214.590 2988.62 3045.57 1866.73 S 1370.56 W 6014365.61 N 567780.95 E 0.738 2315.82 4422.96 69.890 214.610 3021.98 3078.93 1940.71 S 1421.59 W 6014291.15 N 567730.61 E 0.532 2405.64 4519.03 70.890 215.280 3054.22 3111.17 2014.89 S 1473.43 W 6014216.50 N 567679.46 E 1.231 2496.10 4613.84 70.540 214.930 3085.53 3142.48 2088.10 S 1524.89 W 6014142.81 N 567628.68 E 0.508 2585.57 4710.34 70.560 215.420 3117.67 3174.62 2162.48 S 1577.31 W 6014067.95 N 567576.95 E 0.479 2676.53 4806.01 69.690 215.910 3150.19 3207.14 2235.57 S 1629.77 W 6013994.37 N 567525.18 E 1.029 2766.50 4900.50 70.110 215.770 3182.66 3239.61 2307.50 S 1681.72 W 6013921.96 N 567473.89 E 0.466 2855.22 4997.52 69.840 216.370 3215.89 3272.84 2381.18 S 1735.39 W 6013847.78 N 567420.91 E 0.644 2946.37 5094.27 69.500 215.780 3249.50 3306.45 2454.51 S 1788.81 W 6013773.97 N 567368.17 E 0.671 3037.09 5190.17 70.420 215.630 3282.36 3339.31 2527.67 S 1841.39W 6013700.32 N 567316.27 E 0.971 3127.18 5286.13 70.290 216.090 3314.62 3371.57 2600.91 S 1894.33 W 6013626.59 N 567264.01 E 0.471 3217.55 5382.71 69.120 215.950 3348.12 3405.07 2674.18 S 1947.60 W 6013552.84 N 567211.42 E 1.219 3308.13 4 May, 2004 - 18:06 Page 2 of4 DrillQuest 3.03.06.002 '. Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A MWD Your Ref: API 500292298001 Job No. AKMW3017307, Surveyed: 15 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5478.41 69.360 215.510 3382.04 3438.99 2746.82 S 1999.86 W 6013479.71 N 567159.84 E 0.498 3397.60 5572.98 69.510 214.510 3415.26 3472.21 2819.34 S 2050.66 W 6013406.72 N 567109.72 E 1.003 3486.11 5669.41 70.630 215.130 3448.13 3505.08 2893.76 S 2102.42 W 6013331.82 N 567058.65 E 1.309 3576.73 5764.67 69.770 215.030 3480.40 3537.35 2967.11 S 2153.93 W 6013258.00 N 567007.82 E 0.908 3666.33 5860.77 70.170 214.750 3513.32 3570.27 3041 .17 S 2205.58 W 6013183.47 N 566956.87 E 0.498 3756.58 e 5955.11 70.230 214.950 3545.27 3602.22 3114.01 S 2256.30 W 6013110.16 N 566906.82 E 0.209 3845.30 6049.80 69.640 215.040 3577.76 3634.71 3186.87 S 2307.31 W 6013036.83 N 566856.49 E 0.629 3934.21 6147.97 69.580 215.290 3611.96 3668.91 3262.10 S 2360.30 W 6012961.11 N 566804.20 E 0.246 4026.21 6243.23 68.920 214.820 3645.71 3702.66 3335.02 S 2411.47 W 6012887.72 N 566753.71 E 0.832 4115.26 6339.07 68.920 214.400 3680.19 3737.14 3408.62 S 2462.26 W 6012813.65 N 566703.60 E 0.409 4204.63 6434.71 69.960 215.760 3713.77 3770.72 3481.89 S 2513.73 W 6012739.90 N 566652.82 E 1.719 4294.15 6531.21 69.500 216.630 3747.21 3804.16 3554.95 S 2567.18 W 6012666.35 N 566600.04 E 0.971 4384.67 6627.01 69.840 217.120 3780.49 3837.44 3626.81 S 2621.09W 6012594.00 N 566546.81 E 0.597 4474.50 6722.51 70.420 217.110 3812.95 3869.90 3698.43 S 2675.29 W 6012521.88 N 566493.28 E 0.607 4564.31 6820.20 69.630 217.310 3846.32 3903.27 3771.55 S 2730.81 W 6012448.24 N 566438.44 E 0.831 4656.12 6916.55 70.580 215.530 3879.11 3936.06 3844.45 S 2784.59 W 6012374.84 N 566385.33 E 1.997 4746.71 7012.27 70.170 216.370 3911.26 3968.21 3917.44 S 2837.52 W 6012301.37 N 566333.08 E 0.931 4836.86 7108.33 69.890 215.590 3944.07 4001.02 3990.50 S 2890.56 W 6012227.82 N 566280.72 E 0.817 4927.14 7204.98 69.510 216.160 3977.60 4034.55 4063.95 S 2943.68 W 6012153.88 N 566228.29 E 0.679 5017.78 7300.32 68.770 214.720 4011.55 4068.50 4136.53 S 2995.34 W 6012080.83 N 566177.30 E 1.611 5106.85 7396.42 71.000 213.080 4044.60 4101.55 4211.42 S 3045.66 W 6012005.47 N 566127.68 E 2.820 5196.99 7492.55 71.020 212.800 4075.88 4132.83 4287.71 S 3095.08 W 6011928.73 N 566078.97 E 0.276 5287.71 e 7588.63 70.180 213.860 4107.79 4164.74 4363.43 S 3144.88 W 6011852.55 N 566029.88 E 1.359 5378.19 7684.60 69.760 214.980 4140.67 4197.62 4437.81 S 3195.84 W 6011777.70 N 565979.61 E 1.181 5468.29 7780.54 68.990 215.840 4174.46 4231.41 4510.99 S 3247.86 W 6011704.04 N 565928.26 E 1.161 5558.07 7876.71 67.900 214.770 4209.79 4266.74 4583.98 S 3299.56 W 6011630.57 N 565877.25 E 1.535 5647.49 7971.66 67.100 214.010 4246.13 4303.08 4656.36 S 3349.11 W 6011557.73 N 565828.37 E 1.121 5735.15 8067.61 64.880 214.820 4285.17 4342.12 4728.67 S 3398.64 W 6011484.97 N 565779.52 E 2.439 5822.73 8163.47 62.340 214.850 4327.77 4384.72 4799.15 S 3447.68 W 6011414.04 N 565731.13 E 2.650 5908.56 8245.10 61.410 215.450 4366.25 4423.20 4858.01 S 3489.13 W 6011354.79 N 565690.23 E 1.311 5980.53 8325.00 61.410 215.450 4404.49 4461.44 4915.16S 3529.82 W 6011297.27 N 565650.07 E 0.000 6050.67 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. 4 May, 2004 - 18:06 Page 3 of 4 DrillQuest 3.03.06.002 ~... Halliburton Sperry-Sun Survey Report for Milne Point MPE - MPE-25A MWD Your Ref: API 500292298001 Job No. AKMW3017307, Surveyed: 15 April, 2004 BPXA Milne Point Unit The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 216.520° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8325.00ft., The Bottom Hole Displacement is 6051.31ft., in the Direction of 215.684° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) e Comment 2253.60 2280.00 8325.00 2154.05 2176.11 4461.44 379.43 S 390.59 S 4915.16S 297.84 W 307.09 W 3529.82 W Tie On Point Window Point Projected Survey Survey toolproQram for MPE-25A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 8325.00 4461.44 MWD Magnetic (MPE-25A MWD) e 4 May, 2004 - 18:06 Page 4 of4 DrillQuest 3.03.06.002 . . AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPE-25A BP Exploration (Alaska) Inc. Permit No: 204-045 Surface Location: 3708' NSL, 2011' WEL, SEC. 25, T13N, RlOE, UM Bottomhole Location: 4002' NSL, 310' WEL, SEC. 35, T13N, RlOE, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ness any required test. Contact the Commission's North Slope petroleum field inspector at 59- 607 (pager). Sin BY ORDEl\.~F THE COMMISSION DATED this.1- day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA . · ALA~ OIL AND GAS CONSERVATION COMMISSION MAR 0 ·4 200~ PERMIT TO DRILL 20 MC 25.005 k ~/r;- o Drill III Redrill 1 a . Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3708' NSL, 2011' WEL, SEC. 25, T13N, R10E, UM . Top of Productive Horizon: 4283' NSL, 111' WEL, SEC. 35, T13N, R10E, UM Total Depth: 4002' NSL, 310' WEL, SEC. 35, T13N, R10E, UM 4b. Location of Well (State Base Plane -9oqrdinates): Surface: x-569134' y-~' Þ~Zone-ASP4 16. Deviated Wells:. bOlb2-'f5 Kickoff Depth 2300 ft Maximum Hole Angle 11tCasing Program .......... -' Size" .. Casinç¡ Weiç¡ht 4-112" 12.6# "1b. Current Well Class 0 Exploratory o Stratigraphic Test III Service 5. Bond: !HI Blanket 0 Single Well Bond No. 2S100302630-277. 6. Proposed Depth: MD 8429' TVD 4512" 7. Property Designation: ADL 025518 / o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: MPE-25A 12. Field / Pool(s): Milne Point Unit I Schrader Bluff 8. Land Use Permit: 13. Approximate Spud Date: 03/31/04 14. Distance to Nearest Property: 11080' 9. Acres in Property: 2560 70° 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plann:1.:.aE = feet 2400' from MPE-25 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 1831' psig Surface: 1406" psig ~..Hin.... or _ Tc 0'" (c.f.· Lenath MD TVD MD TVD (includinç¡ staç¡e data) 6229' 2200' 2109' 8429' 4512' 95 sx LiteCrete, 103 sx Class 'G' Hole 6-1/4" Grade L-80 Couplinç¡ TCII 119. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 10550 4375 NIA 10550 4375 I N/A . .' '. . . Mn. .' .' Tvn C+~, ,..+, or~1 Conductor 80' 20" ?60 sx Arcttic Set (Approx.) 109' 109' ~ Intermediate Produc:tion Liner Liner (OB) 6670' 3819' 2089' 7" 4-112" 4-112" 735 sx AS III, 665 sx Class 'G' Uncementd Slotted Liner Uncementd Slotted Liner 6699' 6599' - 10418' 6367' - 8456' 4434' 4421' - 4372' 4368' - 4355' Perforation Depth MD (ft): Slotted Liner 6702' - 10396' (OA) IPerforation Depth TVD (ft): Slotted Liner 4435' - 4371' (OA) Slotted Liner 6458' -8454' (OB) I Slotted Liner 4376' - 4355' (OB) 20. Attachments !HI Filing Fee 0 BOP Sketch !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program !HI 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Date: Contact Walter Quay, 564-4178 ( . /. Prepared By Name/Number: 564-5803 Date '5/V/ðf/ Sondra Stewman, 564-4750 ..:.g."~;" ........j... ...~.. .......ii.;.~. ::j...... (.i.;·;· I Permit Approvan.J\1. See cover letter for ~ Date: n ~ other requirements Conditions of Approval: Samples Required 0 Yes ~NO Mud Log Requirel:l 0 Yes KNo HYdro9/ulfide Measures p¡rYes 0 No Directional Survey RE quired ~Yes 0 No Other: \\ \--~~ 11~;( /; Q. ~\.l-\-¡ ~. 3~ ~~, ßt>¡:> ~-\- fV\ \.....:, "" '-'M. ~ /J. f / / BY ORDER OF ~ /f? .~r/ Aooroved Bv: . ~ í1/( " f1 I (' t ~, ^ I THE COMMISSION Date (./10 I fiV- Form 10-401 ~d ~ '-"""'" U ;\ , \.J , ~ \J r\ L... Su6mit (n Dupficate Siç¡nature P's (l,,, /' J!..4 ~ . '. / .'. Permit To Drill . / ' ..1 API Number: Number: 2.0'7 -Dsß-l50-029-22980-01-00 Phone . . MPE-25A ¡Well Name: MPE-25A Drill and Complete Plan Summary / I Type of Well (service / producer / injector): I Schrader Bluff Injector / Surface Location: 3708' FSL, 20~1' FEL, SEC. 25, T13N, R10E ~ E=569134.13 =6016244.97 Target Location: 4283' FSL, 111' FEL, SEC. 35 , T13N, R10E MidOA E=565800 N=6011510 Z=4255' TVD SS Target Location: 4002' FSL, 310' FEL, SEC. 35 , T13N, R10E '" BHL Well TD E=565603 N=6011227 Z=4455' TVD SS Distance to Property line 11 080' Distance to nearest pool 2400' from MPE-25 (OriQinal Well) Mud Program: 6-1/8" Intermediate/Production Hole 2300 -- 8429' : Densit PV YP HTHP H 9.0-9.3 10-20 25-30 10-119.0-9.5 LSND API Filtrate LG Solids < 6 < 15 LCM Restrictions: No Restrictions. / Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 7 . . MPE-25A Cement Program: Casin Size 4.5" 12.6Ib/ft L-80 TCII Production Liner B . 500' above OA with Tail Slurry (-7500' MD). 500' above TUZC with Lead Slurry aSls -5730' 40% Excess in 0 en Hole Sections Total Cement Volume: 61 bbl Wash 5-bbl water S acer Lead Tail Tern Evaluation Program: 6-1/8" Section Open Hole: MWD/GRlRES/PWD ./ IFRlCASANDRA Sperry InSite Cased Hole: Cement Evaluation Log 8 . . MPE-25A Formation Markers: Formation Tops BPRF TUZC Ugnu-MA Ugnu-MB1 Ugnu-MB2 Ugnu-MC SBF2-NA SBF1-NB SBE4-NC SBE2-NE SBE1-NF TSBD(Top OA) TSBC(Base OA) TSBB(Top OB) SBA5(Base OB) MDrkb ft -1630 6236 6921 6979 7125 7475 7606 7682 7746 7798 7920 8005 8093 8151 8201 TVDrkb (ft) Pore Pr~ssure Sl 1607 -673 3698 -1580 3933 -1683 3953 -1691 4003 -1713 4123 -1765 4168 -1785 4194 -1796 4216 -1805 4234 -1813 4276 -1831 4305 -1789 4337 -1802 4361 -1812 4384 -1822 / CasingITubing Program: Estimated EMW Ibl al * 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.35 8.10 ./ 8.10 8.10 8.10 Hole Csg WtJ Grade Conn Burst Collapse Length Top Bottom Size Diam Ft MDrrVDrkb MDrrVDrkb 6.125 4.5-in 12.6 L-80 TCII 8,340 7,500 6229' 2,200'/2109 8,429'/4,512' TubinQ 4.5-in 12.6 L-80 TCII 8,430 7,500 2200' 0 2200'/2109' TubinQ 2.875 6.4 L-80 ST-L 10,570 11 ,160 5625' 2200'/2109' 7825'/4276' Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 6.125" 2300' -8429' PDC 9 . . MPE-25A Well Control: Intermediate/Production hole: / · Maximum anticipated BHP: 1 ,831-psi @ 4,275-ft TVDrkb - SBE1-NF · Maximum surface pressure: 1 ,406~psi @ surface (Based on BHP and a full column of gas from TD @ O.I-psi/ft) · Planned BOP test pressure: 3,000-psi. · Integrity test: An FIT to 11.0-lb/gal at the 7" window/shoe. Kick tolerance: 8.I-bbl with 9.0-lb/gal mud. · Planned completion fluid: Seawater / 7.0-lb/gal Diesel (1 ,800-ft tvd). Drilling Hazards & Contingencies: · Hydrates have been encountered on E-Pad in the 2000' to 2500' interval. To date these were not a significant problem. The original well, E-25 did not report hydrates. · Sticky hole, running gravels/sands have been problematic on E-Pad. Maintain adequate viscosity(100+ vis). Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · Not expected or predicted. Pad Data Sheet · Please Read the C-Pad Data Sheet thoroughly. Breathing · Not expected or predicted. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · A fault intersection is predicted at 7695' MD in the Upper N Sand. Hydrogen Sulfide · MPE Pad is not designated as an H2S Pad. E-Pad wells <50-ppm H2S reported. Anti-collision Issues · MPE-25E passes the Major Risk Criteria. 10 . . MPE-25A Distance to Nearest Property · MPE-25A is 10,080 -ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPE-25A is 2,400' from the Schrader Bluff sand penetration in MPE-25. 11 . . MPE-25A DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. 4ES - P&A E-25 with CIBP @ 2350' in 7" casing. Drillina 1. MIRU Doyon 14, ND Tree/NU BOP. 2. Drill 6.125" hole to Interval TD as per directional plan. 3. Rig up and run 4.5" Liner and cement in place. 4. RU and Run 4.5/2.875" Completion. 5. ND BOP/NU Tree 6. Freeze Protect, Set packer, 7. RDMO Doyon 14. Post Ria 1. Run cement evaluation log. 2. Perforate. 12 Tree: 4 1/16" 5M Wellhead: 11" x 11" 5M tbg. spool, 11" x 41/2" TCII Top & Bottom 20" 94 ppf H-40 80' :rwmw 41/2" 12.6 ppf, L-80, T 10 = 3.958" , cap = (0.0152 bpf) Drift =3.833" 7"x5"BakerZXP 1-2280"1 compo liner top packer Baker 7" x 5" flex lock liner hanger Whipstock ~~~~'~.4 ppf, L-80,ST-L 7" CIBP ~2350' 1 (ID = 2.441", cap = (0.0 bpf) Drift = 2.347" ~ 7" 26 ppf, L-80, Mod. Btrc. prod. casing (drift ID = 6.151", cap. = 0.0383 bpf) Top of Cement 1-6250' 1 7" EZSV Cement Retainer 1-6300' I DATE REV. BY 03/02/04 wdq Proposed Mono-bore Injector MPE-25Ai Proposed KB elev. = 51.75' Doyon 141 DF elev. = 28.55' Doyon 141 GL elev. = 23.20' Doyon 141 4 1/2" HES X-Nipple (3.813" pkg. bore) -XXX)( 4 1/2" HES X-Nipple (3.813" pkg. bore 4-1/2"X 2-7/8" X-Over XXX)( Window cut 1-2300'1 .I..i.nfU: 4.5" 12.6 ppf, L-80 TCII 10 = 3.958~ cap = .0152 bpf) Drift = 3.833" 2-7/8" X-Nipple 4.5" shoe 1 8429' 1 ./ COMMENTS MILNE POINT UNIT WELL MPE-25A API NO: XX-XXX-XXXXX-XX BP EXPLORATION (AK) Tree: 4 1/16" 5M Wellhead: 11" x 11" 5M tcg. spool, 11" x4 1/2" TCII Top & Bottom 20" 94 #/ft H-40 ~ KOP@' Max well bore Angle: 79.68° @ 5031' MD Hole angle through perfs = 90 deg. 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) RA tag at 6197' 3 Short joint 6,197'-6,321' Milled window from 6347'-6359' 1jt of slotted liner (20') 8434'-8454' 91jts. of slotted liner (1975') (6457'-8,433') Baker pack-off bushing 8,433' Baker 4.5" flow guide stock w/2.375" id Baker HR setting sleeve Baker 7" ML torque master pkr 600-47 Baker HR setting sleeve Baker HMC liner hanger Halliburton float collar Halliburton float shoe Mid-Lateral TVD @ 4356' 4·1/2" SLOTIED INTERVALS 08- 8434'-8454' MD (20') 08- 6457-8433' MD (1975') OA- 6701-10,396' MD (3694') DATE REV. BY 12/08/00 MOO Initial completion by Doyon 141 MILNE POINT UNIT WELL E,.z¿5 API NO: 50-029-22980-06 ESP Completion - Nabors 4ES 12/20/00 GMH COMMENTS MPE-25 Propose KB elev. = 51.75' Doyon 141 DF elev. = 28.55' Doyon 141 GL elev. = 23.20' Doyon 141 6350' I -2350' I Top of Cement Cap I -6250' I 7" EZSV Cement Retainer -6300" 6367' 6380' 6599' 6607' 6614' 6699' 4.5" 12.6#, L-80 IBTtubing. Baker Float shoe at 10418' Baker pack-off bushing 10,396' 97jts. of Slotted liner (3694') (6701'-10395') BP EXPLORATION AK . ~o>.Q '?O\~~ ~\\..~~ ~--- + E-PAD 3 8 . . · 33 · 2 10 . . 4 22. . 1 13 . .5 I .30 ~ · 6 I .21 I .7 18 . · 16 20 . .23 24. · 19 14. .29 15. · 17 o o Ó o o w N 1800.00 + o o Ó o <.D o ~'<;- '<;- :<i" CD "'J W + N 2600.00 I- Z « ....J a.. -~- I VICINITY MAP N.T.S. NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD '27. 2. GEODETIC COORDINATES ARE NAD '27. 3. MEAN PAD SCALE FACTOR = 0.9999054. 4. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS CFP-3 AND E-1. 5. ELEVATIONS ARE BASED ON BPX MILNE POINT DATUM (M.S.L.). 6. DA TE OF SURVEY: OCTOBER 25, 2000. 7. REFERENCE FIELD BOOK: MPOO-01, PG. 57. WELL SLOT 25 REVISION NOTE THIS AS-BUILT DRAWING IS A REISSUE OF A PREVIOUS AS-BUILT DRAWING FOR CONDUCTOR E-225. CONDUCTOR 25 HAD BEEN PREVIOUSLY NAMED E-225. LEGEND -$- AS-BUILT WELL CONDUCTOR . EXISTING WELL CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCA TED WITHIN PROTRACTED SEC. WELL ASP. PLANT NO. COORDINATES COORDINATES E-25 Y= 6,016,244.97 N. 2,100.05 X= 569,134.13 E. 1 292.01 25, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA GEODETIC GEODETIC CELLAR SECTION POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 70'27'17.070" 70.4547418" 3,708' FSL ' 149'26'08.991" 149.4358309' 23.2 2,011' FEL ./ it DRAWN: JB ObP CHECKED: BP EXPLORA TION JJC DATE: 02-07000 DRAWING: SHEET: MPE-AB E-25 MILNE POINT UNIT - E-PAD i ~~~rnœo JOB NO: JJC .B SCALE: AS-BUILT WELL CONDUCTOR .B JJC ENGINEEIISN.ÐLAND5UR'o£YCRS SLOT E-25 1 OF 1 8(11 'III£ST FlRE'II&D lANE '"=200' BY CHK ANCMORACE. Al.ASl<A Ø503 01 2-07-01 REVISED WELL NAMED E-225 TO E-25 DO 11 3 00 ISSUEO FOR INFORIIAllON NO. DAlE REVISION COMPANY DETAILS ~ BPAmoco Calculation Method: Minimum Curvature = ~=~ ~;V~;~nderNortb Error Surface: Elliptical + Casing Wandn Metboct Rules Based REFERENCE INFORMATION Co-ordinate (NIB) Reference; Well Centre; MPE-2S, True North Vertical (TVD)Reference: 57.50'5750 Se£lion (VS) Reference; Slot - (O.OON,O.OOE) M~~:~e= ¡:~~~ CASING DETAILS No. TVD MD Name Size 4512.37 8429.01 41/2" 4.500 FORMATION TOP DErAILS No. TVDPath MDPath Formation I 3697.50 6236.24 ruzc 2 3932.50 6921.01 Ugnu-MA 3 3952.50 6979.29 Ugnu-MBl 4 4002.50 7124.98 Ugnu-MB2 5 4122.50 7474.66 Ugnu-MC 6 4167.50 7605.78 SBF2-NA 7 4193.50 7681.54 SBFI-NB 8 4215.50 7745.65 SBE4-NC 9 4233.50 7798.10 SBE2-NE 10 4275.50 7920.49 SBEI-NF 11 4304.50 8004.99 TSBD (Top OA) 12 4336.50 8093.24 TSBC (Base OA) 13 4360.50 8150.57 TSBB (Top OB) 14 4383.50 8200.50 SBA5 (Base OB) 210 Start Dir 121100': 2300' MD, 2t92.91TVD Start Dir 6/100' : 2320' MD, 2209.38'TVD End Dir : 2891.56' MD, 2549.68' TVD c :¡¡ o o t:. ..c 15. Ö " y ',:: .;; ~ 700 1400 2100 2800 Vertical Section at 215.66" [700ft/in] SURVEY PROGRAM Depth Pm Depth To SurveyIPlan 2300.00 8429.02 Planned: MPE-25A wpm V3 Plan: MPE-25A wp02 ()ÆPE-25/Plan MPE-25A) Tool Created By: Ken Allen Checked: Date: 2/1912004 MWD+lFR+MS Date: Reviewed: Date WELL DETAll.S N"", +Ni-S +E/.W Northing Easting Latitude Longitude Slot MPE-2S 2449.27 ·283.81 6016244.97 569134.13 70"2T17.070N 149°26'08.991W NiA TARGET DETAILS N"", 1VD +N/-8 +EI-W Northing ""'""" Shape MPE-25A TI 4312.50 -4704.27 -3378.24 6011510.00 565800.00 Circle (Radius; 120) SECTION DETAILS Sec MD lnc Azi TVD +N/-S +EI-W DLeg TFace VSec Target I 2300.00 33.34 218.97 2192.91 -398.85 -313.87 0.00 0.00 507.04 2 2320.00 35.73 218.61 2209.38 -407.68 -320.97 12.00 -5.00 518.36 3 2891.56 69.93 215.33 2549.68 -767.89 -588.36 6.00 -5.48 966.90 4 8028.30 69.93 215.33 4312.50 -4704.27 -3378.24 0.00 0.00 5791.61 MPE-25A T1 5 8229.02 59.89 215.33 4397.50 -4852.39 -3483.22 5.00 180.00 5973.15 6 8429.02 49.89 215.33 4512.37 -4985.71 -3577.71 5.00 180.00 6136.56 . "" v... v.... ....:'~. " " " ¿¡ " Start Dir 5/100': 8028.3' MD, 4312.5TVD Total Depth: 8429.02' MD, 4512.37' TV 3500 4200 4900 5600 7000 REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: MPE-25, True North Vertical (TVD) Rererence: 57.50' 57.50 Secüoo (VS) Reference: Slot - (O.OON,O.OOE) Measu~Pc:fa~~e~~~ ~~~~ COMPANY DETAILS SpIr'I'"'\I-1Ln BP Amoco a.ln¡;,:."'-l!!l"."::.:.....1\Yl~1I]! Calcu]ation Method: Minimum Curvature :~:~=; ~;~~~rNortb Error Surface: Elliptical + Casing Wamio Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 3697.50 6236.24 TUZC 2 3932.50 6921.01 Ugnu-MA 3 3952.50 6979.29 Ugnu-MBI 4 4002.50 7124.98 Ugnu-MB2 5 4122.50 7474.66 Ugnu-MC 6 4167.50 7605.78 SBF2-NA 7 4193.50 7681.54 SBFI-NB 8 4215.50 7745.65 SBE4-NC 9 4233.50 7798.10 SBE2-NE 10 4275.50 7920.49 SBEI-Nf II 4304.50 8004.99 TSBD (Top OA) 12 4336.50 8093.24 TSBC (Base OA) 13 4360.50 8150.57 TSBB (Top OB) 14 4383.50 8200.50 SBA5 (Base OB) CASING DETAILS No. TVD Name Size MD 4512.37 8429.01 41/2" 4.500 'ë' â 8 ~ +' ~ ~ ~ o '" -100 -200 -4000 -3000 -1000 -2000 West(-)Æast(+) [IOOOft/in] SURVEY PROGRAM Plan: MPE·25A wp02 (MPE·251PIan MPE·25A) Created By: Ken Allen Date: 2/19/2004 Depth Fm Depth To SurveyiPIan 2300.00 8429.02 Planned MPE-25A wp02 V3 Tool MWD+IFR+MS Checked: Date Reviewed: Date WELL DETAILS Name +N/-S &sting 569134.13 Latitude Lougitude Slot 70Q27'17.070N 149"26'08.99IW N/A +EI-W Northing 6016244.97 MPE-25 244927 -283.81 TARGET DETAILS N~ TVD +Ni-s +EI-W Northing Easting s..", MPE-25A T1 431250 -4704.27 -337824 6011510.00 565800.00 Circle (Radius: 120) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TF ace VSec Target I 2300.00 33.34 218.97 2192.91 -398.85 -313.87 0.00 0.00 507.04 2 2320.00 35.73 218.61 2209.38 -407.68 -320.97 12.00 -5.00 518.36 3 2891.56 69.93 215.33 2549.68 -767.89 -588.36 6.00 -5.48 966.90 4 8028.30 69.93 215.33 4312.50 -4704.27 -3378.24 0.00 0.00 5791.61 MPE-25A Tl 5 8229.02 59.89 215.33 4397.50 -4852.39 -3483.22 5.00 180.00 5973.15 6 8429.02 49.89 215.33 4512.37 -4985.71 -3577.71 5.00 180.00 6136.56 I l l ;' I ;' I I " " ;' " , " , ø # ;" # . ~ v~ -/~ '~.... , " '" "' , <# #, ... o . . Sperry-Sun - Draft Copy KW A Planning Spe!..........y-sun DRIL.L.ING SERVICES AKU.lJMTRTOl'I(,QMf'AN\' Yes Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: M pt E Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6013798.68 ft Latitude: 70 26 52.982 N 569440.72 ft Longitude: 149 26 0.655 W North Reference: True ./ Grid Convergence: 0.53 deg Slot Name: 6016244.97 ft / Latitude: 70 27 17.070 N 569134.13 ft / Longitude: 149 26 8.991 W Well: MPE-25 MPE-25 Well Position: +N/-S 2449.27 ft Northing: +E/-W -283.81 ft Easting: Position Uncertainty: 0.00 ft Wellpath: Plan MPE-25A +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 MPE-25PB 1 2300.00 ft Mean Sea Level 25.09 deg 80.87 deg Direction deg 215.66 Current Datum: Magnetic Data: Field Strength: Vertical Section: 57.50' 1/15/2004 57556 nT Depth From (TVD) ft 57.50 Height 57.50 ft Casing Points 6236.24 3697.50 TUZC 0.00 0.00 6921.01 3932.50 Ugnu-MA 0.00 0.00 6979.29 3952.50 Ugnu-MB1 0.00 0.00 7124.98 4002.50 Ugnu-MB2 0.00 0.00 7474.66 4122.50 Ugnu-MC 0.00 0.00 7605.78 4167.50 SBF2-NA 0.00 0.00 7681.54 4193.50 SBF1-NB 0.00 0.00 7745.65 4215.50 SBE4-NC 0.00 0.00 7798.10 4233.50 SBE2-NE 0.00 0.00 7920.49 4275.50 SBE1-NF 0.00 0.00 8004.99 4304.50 TSBD (Top OA) 0.00 0.00 8093.24 4336.50 TSBC (Base OA) 0.00 0.00 8150.57 4360.50 TSBB (Top OB) 0.00 0.00 8200.50 4383.50 SBA5 (Base OB) 0.00 0.00 Targets MPE-25A T1 -Circle (Radius: 120) -Plan hit target 4312.50 -4704.27 -3378.24 6011510.00 565800.00 70 26 30.797 N 149 2748.163 W spe""""y-sun DRIL.L.ING SERVICES A 1:tALLJIWliliTØN(COI.tf'.\N'I· . e Sperry-Sun - Draft Copy KW A Planning 2300.00 33.34 218.97 2192.91 -398.85 -313.87 0.00 0.00 0.00 0.00 2320.00 35.73 218.61 2209.38 -407.68 -320.97 12.00 11.96 -1.79 -5.00 2891.56 69.93 215.33 2549.68 -767.89 -588.36 6.00 5.98 -0.58 -5.48 8028.30 69.93 215.33 4312.50 -4704.27 -3378.24 0.00 0.00 0.00 0.00 MPE-25A T1 8229.02 59.89 215.33 4397.50 -4852.39 -3483.22 5.00 -5.00 0.00 180.00 8429.02 49.89 215.33 4512.37 -4985.71 -3577.71 5.00 -5.00 0.00 180.00 Survey 2500.00 46.49 217.20 2344.81 2287.31 6015740.37 568745.39 636.44 129.51 6.00 355.35 MWD+IFR+ 2550.00 49.48 216.90 2378.28 2320.78 6015710.52 568723.29 673.57 166.65 6.00 355.59 MWD+IFR+ 2600.00 52.47 216.62 2409.76 2352.26 6015679.19 568700.34 712.40 205.49 6.00 355.79 MWD+IFR+ 2650.00 55.46 216.36 2439.16 2381.66 6015646.47 568676.61 752.83 245.92 6.00 355.96 MWD+IFR+ 2700.00 58.46 216.12 2466.42 2408.92 6015612.44 568652.15 794.74 287.83 6.00 356.12 MWD+IFR+ 2750.00 61.45 215.90 2491.45 2433.95 6015577.20 568627.03 838.01 331.11 6.00 356.25 2800.00 64.45 215.69 2514.19 2456.69 6015540.85 568601.33 882.54 375.63 6.00 356.36 2850.00 67.44 215.49 2534.57 2477.07 6015503.48 568575.11 928.19 421.28 6.00 356.45 2891.56 69.93 215.33 2549.68 2492.18 6015471.73 568552.98 966.90 460.00 6.00 356.54 2900.00 69.93 215.33 2552.57 2495.07 6015465.22 568548.46 974.83 467.92 0.00 0.00 3000.00 69.93 215.33 2586.89 2529.39 6015388.09 568494.86 1068.75 561.85 0.00 0.00 3100.00 69.93 215.33 2621.21 2563.71 6015310.97 568441.27 1162.68 655.78 0.00 0.00 3200.00 69.93 215.33 2655.53 2598.03 6015233.84 568387.68 1256.60 749.70 0.00 0.00 3300.00 69.93 215.33 2689.84 2632.34 6015156.72 568334.08 1350.53 843.63 0.00 0.00 3400.00 69.93 215.33 2724.16 2666.66 6015079.59 568280.49 1444.46 937.56 0.00 0.00 3500.00 69.93 215.33 2758.48 2700.98 6015002.46 568226.89 1538.38 1031.49 0.00 0.00 3600.00 69.93 215.33 2792.80 2735.30 6014925.34 568173.30 1632.31 1125.41 0.00 0.00 3700.00 69.93 215.33 2827.12 2769.62 6014848.21 568119.71 1726.23 1219.34 0.00 0.00 3800.00 69.93 215.33 2861.43 2803.93 6014771.09 568066.11 1820.16 1313.27 0.00 0.00 3900.00 69.93 215.33 2895.75 2838.25 6014693.96 568012.52 1914.08 1407.19 0.00 0.00 4000.00 69.93 215.33 2930.07 2872.57 6014616.84 567958.93 2008.01 1501.12 0.00 0.00 4100.00 69.93 215.33 2964.39 2906.89 6014539.71 567905.33 2101.93 1595.05 0.00 0.00 4200.00 69.93 215.33 2998.71 2941.21 6014462.59 567851.74 2195.86 1688.97 0.00 0.00 4300.00 69.93 215.33 3033.02 2975.52 6014385.46 567798.14 2289.78 1782.90 0.00 0.00 4400.00 69.93 215.33 3067.34 3009.84 6014308.34 567744.55 2383.71 1876.83 0.00 0.00 4500.00 69.93 215.33 3101.66 3044.16 6014231.21 567690.96 2477.63 1970.76 0.00 0.00 4600.00 69.93 215.33 3135.98 3078.48 6014154.09 567637.36 2571.56 2064.68 0.00 0.00 4700.00 69.93 215.33 3170.30 3112.80 6014076.96 567583.77 2665.49 2158.61 0.00 0.00 4800.00 69.93 215.33 3204.61 3147.11 6013999.84 567530.17 2759.41 2252.54 0.00 0.00 4900.00 69.93 215.33 3238.93 3181.43 6013922.71 567476.58 2853.34 2346.46 0.00 0.00 5000.00 69.93 215.33 3273.25 3215.75 6013845.59 567422.99 2947.26 2440.39 0.00 0.00 5100.00 69.93 215.33 3307.57 3250.07 6013768.46 567369.39 3041.19 2534.32 0.00 0.00 5200.00 69.93 215.33 3341.89 3284.39 6013691.33 567315.80 3135.11 2628.24 0.00 0.00 5300.00 69.93 215.33 3376.20 3318.70 6013614.21 567262.21 3229.04 2722.17 0.00 0.00 5400.00 69.93 215.33 3410.52 3353.02 6013537.08 567208.61 3322.96 2816.10 0.00 0.00 5500.00 69.93 215.33 3444.84 3387.34 6013459.96 567155.02 3416.89 2910.03 0.00 0.00 5600.00 69.93 215.33 3479.16 3421.66 6013382.83 567101.42 3510.81 3003.95 0.00 0.00 5700.00 69.93 215.33 3513.47 3455.97 6013305.71 567047.83 3604.74 3097.88 0.00 0.00 5800.00 69.93 215.33 3547.79 3490.29 6013228.58 566994.24 3698.66 3191.81 0.00 0.00 . . Sperry-Sun - Draft Copy KW A Planning spa"''''v-sun DRILLING seRVices A H.U.tJMrJITON COMP.\NV 5900.00 69.93 215.33 3582.11 3524.61 6013151.46 566940.64 3792.59 3285.73 0.00 0.00 MWD+IFR+ 6000.00 69.93 215.33 3616.43 3558.93 6013074.33 566887.05 3886.52 3379.66 0.00 0.00 MWD+IFR+ 6100.00 69.93 215.33 3650.75 3593.25 6012997.21 566833.45 3980.44 3473.59 0.00 0.00 MWD+IFR+ 6200.00 69.93 215.33 3685.06 3627.56 6012920.08 566779.86 4074.37 3567.51 0.00 0.00 MWD+IFR+ 6236.24 69.93 215.33 3697.50 3640.00 6012892.13 566760.44 4108.40 3601.55 0.00 0.00 TUZC 6300.00 69.93 215.33 3719.38 3661.88 6012842.96 566726.27 4168.29 3661.44 0.00 0.00 MWD+IFR+ 6400.00 69.93 215.33 3753.70 3696.20 6012765.83 566672.67 4262.22 3755.37 0.00 0.00 MWD+IFR+ 6500.00 69.93 215.33 3788.02 3730.52 6012688.71 566619.08 4356.14 3849.29 0.00 0.00 MWD+IFR+ 6600.00 69.93 215.33 3822.34 3764.84 6012611.58 566565.49 4450.07 3943.22 0.00 0.00 MWD+IFR+ 6700.00 69.93 215.33 3856.65 3799.15 6012534.46 566511.89 4543.99 4037.15 0.00 0.00 MWD+IFR+ 6800.00 69.93 215.33 3890.97 3833.47 6012457.33 566458.30 4637.92 4131.08 0.00 0.00 MWD+IFR+ 6900.00 69.93 215.33 3925.29 3867.79 6012380.20 566404.70 4731.84 4225.00 0.00 0.00 MWD+IFR+ 6921.01 69.93 215.33 3932.50 3875.00 6012364.00 566393.44 4751.58 4244.74 0.00 0.00 Ugnu-MA 6979.29 69.93 215.33 3952.50 3895.00 6012319.05 566362.21 4806.32 4299.48 0.00 0.00 Ugnu-MB1 7000.00 69.93 215.33 3959.61 3902.11 6012303.08 566351.11 4825.77 4318.93 0.00 0.00 MWD+IFR+ 7100.00 69.93 215.33 3993.93 3936.43 6012225.95 566297.52 4919.69 4412.86 0.00 0.00 MWD+IFR+ 7124.98 69.93 215.33 4002.50 3945.00 6012206.68 566284.13 4943.16 4436.32 0.00 0.00 Ugnu-MB2 7200.00 69.93 215.33 4028.24 3970.74 6012148.83 566243.92 5013.62 4506.78 0.00 0.00 MWD+IFR+ 7300.00 69.93 215.33 4062.56 4005.06 6012071.70 566190.33 5107.55 4600.71 0.00 0.00 MWD+IFR+ 7400.00 69.93 215.33 4096.88 4039.38 6011994.58 566136.73 5201.47 4694.64 0.00 0.00 MWD+IFR+ 7474.66 69.93 215.33 4122.50 4065.00 6011937.00 566096.72 5271.59 4764.76 0.00 0.00 Ugnu-MC 7500.00 69.93 215.33 4131.20 4073.70 6011917.45 566083.14 5295.40 4788.56 0.00 0.00 MWD+IFR+ 7600.00 69.93 215.33 4165.52 4108.02 6011840.33 566029.55 5389.32 4882.49 0.00 0.00 MWD+IFR+ 7605.78 69.93 215.33 4167.50 4110.00 6011835.87 566026.45 5394.75 4887.92 0.00 0.00 SBF2-NA 7681.54 69.93 215.33 4193.50 4136.00 6011777.44 565985.84 5465.91 4959.08 0.00 0.00 SBF1-NB 7700.00 69.93 215.33 4199.83 4142.33 6011763.20 565975.95 5483.25 4976.42 0.00 0.00 MWD+IFR+ 7745.65 69.93 215.33 4215.50 4158.00 6011727.99 565951.49 5526.12 5019.30 0.00 0.00 SBE4-NC 7798.10 69.93 215.33 4233.50 4176.00 6011687.54 565923.38 5575.39 5068.56 0.00 0.00 SBE2-NE 7800.00 69.93 215.33 4234.15 4176.65 6011686.08 565922.36 5577.17 5070.35 0.00 0.00 MWD+IFR+ 7900.00 69.93 215.33 4268.47 4210.97 6011608.95 565868.76 5671.10 5164.27 0.00 0.00 MWD+IFR+ 7920.49 69.93 215.33 4275.50 4218.00 6011593.15 565857.79 5690.34 5183.52 0.00 0.00 SBE1-NF 8000.00 69.93 215.33 4302.79 4245.29 6011531.83 565815.17 5765.02 5258.20 0.00 0.00 MWD+IFR+ 8004.99 69.93 215.33 4304.50 4247.00 6011527.98 565812.50 5769.71 5262.89 0.00 0.00 TSBD (Top 8028.30 69.93 215.33 4312.50 4255.00 6011510.00 565800.00 5791.61 5284.78 0.00 0.00 MPE-25A T 8093.24 66.68 215.33 4336.50 4279.00 6011460.46 565765.58 5851.93 5345.11 5.00 180.00 TSBC (Bas 8100.00 66.34 215.33 4339.20 4281.70 6011455.37 565762.04 5858.13 5351.31 5.00 180.00 MWD+IFR+ 8150.57 63.82 215.33 4360.50 4303.00 6011417.72 565735.88 5903.99 5397.17 5.00 180.00 TSBB(Top 8200.00 61.34 215.33 4383.26 4325.76 6011381.69 565710.84 5947.86 5441.04 5.00 180.00 MWD+IFR+ 8200.50 61.32 215.33 4383.50 4326.00 6011381.33 565710.59 5948.30 5441.48 5.00 180.00 SBA5 (Bas 8229.02 59.89 215.33 4397.50 4340.00 6011360.92 565696.41 5973.15 5466.33 5.00 180.00 MWD+IFR+ 8300.00 56.34 215.33 4434.98 4377.48 6011311.44 565662.03 6033.41 5526.59 5.00 180.00 MWD+IFR+ 8400.00 51.34 215.33 4493.96 4436.46 6011245.17 565615.97 6114.13 5607.31 5.00 180.00 MWD+IFR+ 8429.01 49.89 215.33 4512.37 4454.87 6011226.75 565603.18 6136.55 5629.73 5.00 180.00 41/2" ,,-8429.02 49.89 215.33 4512.37. 4454.87 6011226.75 565603.17 6136.56 5629.74 5.00 180.00 MWD+IFR+ ANTI-COLLISION SETIINGS COMPANY DETAILS BP Amoco WELL DETAILS Name +N/-S +EJ-W Northing Eastiug Latitude Longitude Slot MPE-ZS :2449.27 -283.81 6016244.97 569134.13 70Q27'17.070N 149"26'08.991W NlA 256 40 200 160 120 0 270 40 80 120 Interpolation Method:MD Interval: 25.00 Depth Range From: 2300.00 To: 8429.02 Maximum Range: 1037.15 Reference: Plan: MPE·25A wp02 Calculation Method: Minirrnun CUrvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warning Method: Rules Based - ""'L'" ::::;!.....~ ~%:\y 0 ::.;::\:::\::~ ~ :":I:::'\::<:<»~ ~,/:~ :<: t:.::: ~ $:~ / / r;ØI.~."'.,j ~~ ~~ :« ~ ~ ~J!;;¡ .<:::~~<'j~ ~ ~~~: ~ ~~ .,.::~: r....'j ...... !:::'>~/ \:\' \. '/ ~ ..'" ,lit !;) >,::'::: '" x: ':\ \\. >// k~:: :xS'::>~:> \ ;·\,>-60 ;,< /<: />; ://~7-L ~ ~ ~:>~:\ ~~!/:\ / Ii: <;/ <~;;.:¿,?~) , ./ >R.:: ::i: >: ~\~~\ i~/;íW'.liWf~ ~. ~~~~~~ ~\' \\:~ //1/1/1 ~//tll/ y:¡ II! ø~ ;:;,\<~/'~,::~ ~~~\'\/~ ,\ \\\\\?\,\\\!//~ \\\\\~~Ið /i U. UU/ili//~~/i?/?/t/-f,i //?'ll/í(í/¿;f¿," // ¡\X/\\\\>\\\\i\\/\\://\f\ r/' " I: Ii II Ii 'f '/1 Nil / '~'\/\ \/,/,\\,\\/\,H ,II ' .i , i \ I, : i ,'I' I " I I: : / Ii f (/i!U /i ii',/>:';/'; \\'1' /\ \ ::, \ I'. ','I '¡ "j :: JI ',' J~,;/ I., . \"~\II 'Ii Ij !//' Well MPE-25, MPE-25PBl, MPE-25BP2,:¿;/?~:;/ ¡lip iii//;')///i '/ MPE-25BP3, MPE-25Ll and MPE-25LIPB ~?>;j\?//)i//iIW¿ il/! r/ plotte~ with. "no errors" forclarity":::.:.:II~;;:/ ~j/.. II 11// 'i rill 11/ \ " 2.0 '" Q.</«>:/i!./ ! i 11 <.,~«~'-..~~~.:.::<, .'i;/~~ /~l :i i\" ~\\\\«::~~'«~ ...... ........~~_:>'/~~ / »> \':< "·::/I:>/. ) \\\\' \~ ;~~ ~~' :<s:::::~~ ~!~!: ................... .............!.... .:f ~\ 'hI. 71 iip; '/ \S'). ~;~ ~<:~<>! ~:: ~/ /;/ 1// 240\ ~.. \~~ ~~~~~!".~,i.. .,. ;::¡ ~\;\/\Y. '/ ,/'/120 " :>\"'~'< /~/\~:-: i <>:fi~Z\> (cj: !~/ ;I;;J 0 :/ ~:~/:<\:< 'if Y ,,~f:t '\J/- ,,;///¿,<: 'i ).~!~/7 ~\.~:...)i':::~<) "..·....>'81;; 'l »"/ ~~u' ·,t ./:!//~?~ ~~ ~>~ .. ;:;:} '. i::/": 21 v ~~ ,þ Ii:;;;;; 50 3311< ~ ~~.' -:ÁI~. / ~',. /. ~ /' ;'.-cl" /. i/< / )XZ; I,,! 300/'/'/ !/Í~ y "/ :/> ,;/!: I <:",,<:-""I?I' c\) 18 From o 300 600 1000 1500 2000 3000 5000 7000 10000 s" I 2300.00 2 2320.00 3 2891.56 4 8028.30 5 8229.02 6 8429.02 SURVEY PROGRAM Depth Fm Depth To SurveylPlan 2300.00 8429.02 Planned: MPE-2SA wp02 VJ Colour ToMD 300 600 1000 1500 2000 3000 5000 7000 10000 13000 90 , Tool MWD+IFR+MS WELLPATHDETAILS Plan .MPE-25A pareutWellpatb: Tie 00 MD: MPE-ZSPBl 2300.00 Rig: Ref. Datum: 57.5()' 57.5()\ V.Section Origin Origin Starting Angle +W-S +EI-W From TVD 215.66° G.on 0.00 51.50 LEGEND - MPB-15(MPE-IS),MajorRisk - MPE-ZO (MPE-20), Major Risk -== MPE-20 (MPE-20A (OA Lat.», Major Risk MPE-10 20ALI (NB Lat.) OLD), Major Risk MPE-10 20AL I (NB», Major Risk - MPE-24 Risk - MPE-24 - MPE-24 - MPE-2S MPE - MPE-25 (MPE - MPE-25 (MPE-25PBl), NOERRORS - MPE-25 (MPE-25PB2), NOERRORS - MPE-25 (MPE-2SPB3), NOERRORS = ~~~~~~~i~~:l~~~~FORS = MPE-29 (MPE-29), Major Risk - MPE-19 (MPE-29PBl), Major Risk - Plan MPE-25A .......... MPE-2SA wp02 . spEll"T"v-&Un CiAILLINCI SERvIC.. ~1!.U.I.UI<1toNÇ,,"1I'4N\" SECTION DETAILS t", Azi TVD +N/-S +EI-W DLeg TFace vs" Target 3334 218.97 2192.91 _398.85 -313.87 0.00 0.00 507.()4 35.73 218.61 2209.38 -407.68 -320.97 12.00 -5.00 518.36 69.93 215.33 2549.68 _767.89 -588.36 6.00 -5.48 966.90 69.93 21533 4312.50 4704.27 -3378.24 0.00 0.00 5791.61 MPE·25A Tl 59.89 21533 4397.50 4852.39 -3483.22 '.00 180.00 5973.15 49.89 21533 4512.37 4985.71 -3577.71 '.00 180.00 6136.56 MD . . Sperry-Sun - Draft Copy Anticollision Report spe""""y-sun DRIL.L.ING SERVIC:ES Auu,uM!RTON("OMf'.\NY GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 2300.00 to 8429.02 ft Maximum Radius: 1037.15 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/15/2004 Validated: No Planned From To Survey ft ft 116.50 2300.00 2300.00 8429.02 Version: 0 Toolcode Tool Name MPE-25PB1 (116.50-5775.50) (3) Planned: MPE-25A wp02 V3 MWD+IFR:AK MWD+IFR+MS MWD + IFR [Alaska] MWD + IFR + Multi Station Casing Points M Pt E Pad MPE-15 MPE-15 V1 2315.40 2400.00 154.74 57.49 97.25 Pass: Major Risk M pt E Pad MPE-20 MPE-20 V1 2300.00 2500.00 527.80 38.37 489.44 Pass: Major Risk MPtEPad MPE-20 MPE-20A (OA La!.) VO P 2300.00 2500.00 526.41 38.41 488.00 Pass: Major Risk M pt E Pad MPE-20 Plan MPE-20AL 1 (NB Lat 2300.00 2500.00 526.69 38.88 487.80 Pass: Major Risk M pt E Pad MPE-20 Plan MPE-20AL 1 (NB) VO 2300.00 2500.00 526.41 38.38 488.03 Pass: Major Risk M pt E Pad MPE-24 MPE-24 V12 2329.92 2300.00 424.95 60.82 364.13 Pass: Major Risk M pt E Pad MPE-24 MPE-24A V9 2300.96 2275.00 416.55 59.59 356.96 Pass: Major Risk M pt E Pad MPE-24 MPE-24AL 1 V5 2300.96 2275.00 416.55 59.59 356.96 Pass: Major Risk MPtEPad MPE-25 MPE-25 V1 2305.50 2300.00 0.03 No Reference Casings MPtEPad MPE-25 MPE-25L 1 V1 2305.50 2300.00 0.03 No Reference Casings M Pt E Pad MPE-25 MPE-25PB1 V1 2305.50 2300.00 0.03 No Reference Casings M pt E Pad MPE-25 MPE-25PB2 V1 2305.50 2300.00 0.03 No Reference Casings M pt E Pad MPE-25 MPE-25PB3 V1 2305.50 2300.00 0.03 No Reference Casings M pt E Pad MPE-25 MPE25L1PB1 V4 2305.50 2300.00 0.03 No Reference Casings M pt E Pad MPE-26 MPE-26 V23 2300.00 2475.00 523.43 34.46 488.97 Pass: Major Risk M pt E Pad MPE-29 MPE-29 V2 2323.22 2300.00 216.31 37.00 179.31 Pass: Major Risk MPtEPad MPE-29 MPE-29PB1 V16 2323.10 2300.00 216.59 37.12 179.47 Pass: Major Risk Site: MPtEPad Well: MPE-15 Rule Assigned: Major Risk Wellpath: MPE-15 V1 Inter-Site Error: 0.00 ft 2315.40 2205.64 2400.00 2284.32 4.90 7.22 345.15 126.46 154.74 57.49 97.25 Pass 2335.30 2221.73 2425.00 2303.03 4.92 7.42 343.09 124.62 163.94 58.67 105.28 Pass 2355.55 2237.85 2450.00 2321.57 4.93 7.62 341.30 123.01 173.52 59.79 113.73 Pass 2375.71 2253.64 2475.00 2339.94 4.95 7.82 339.73 121.62 183.43 60.87 122.55 Pass 2395.80 2269.11 2500.00 2358.10 4.97 8.03 338.34 120.40 193.57 61.93 131.64 Pass 2415.81 2284.24 2525.00 2376.02 4.99 8.23 337.10 119.31 203.90 62.95 140.95 Pass 2435.74 2299.04 2550.00 2393.70 5.02 8.42 335.98 118.35 214.39 63.95 150.44 Pass 2455.59 2313.51 2575.00 2411.16 5.04 8.62 334.99 117.49 225.05 64.94 160.11 Pass 2475.35 2327.61 2600.00 2428.51 5.07 8.83 334.14 116.78 235.97 65.94 170.03 Pass 2494.98 2341.35 2625.00 2445.80 5.10 9.03 333.44 116.20 247.13 66.91 180.22 Pass 2514.49 2354.71 2650.00 2463.01 5.13 9.23 332.85 115.74 258.54 67.87 190.67 Pass 2533.85 2367.68 2675.00 2480.15 5.16 9.43 332.38 115.39 270.17 68.83 201.34 Pass 2550.00 2378.28 2700.00 2497.28 5.19 9.64 332.02 115.12 282.06 69.75 212.32 Pass 2572.10 2392.44 2725.00 2514.39 5.23 9.83 331.74 114.97 294.16 70.72 223.44 Pass 2590.95 2404.21 2750.00 2531.48 5.27 10.02 331.56 114.89 306.50 71.64 234.86 Pass 2609.59 2415.56 2775.00 2548.55 5.31 10.20 331.45 114.88 319.10 72.51 246.59 Pass , I 00 VI I ' , I I ' 1 VI 1 26 VI , I ' 2 I 1 16 VI VI "-I o I'V cu DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE 1/6/2004 CHECK NO. 055228 VENDOR DISCOUNT NET H PR010504L PERMIT TO DRILL rr¡µ~ - J--lA TOTAL ~ THE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DeSCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 8···..·.··. P tf. ~ 'j"r (11/;1 .. . . ~..jr.. fWl STATE OF ALASKA AOGCC 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 055228 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$100.00****** n- 0 5 5 2 2 B II- I: 0... ¡. 2 0 ~ B ~ 5 I: 0 ¡. 2 ? B ~ b II- . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /YI ¡:?tf. E r ~ ¡:] WELL NAME PTD# 2-D~'-O~ Exploration Stratigraphic / Development v/ Service CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new wellboresegmentof LATERAL existing wen . Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (SO - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH An dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample intervals tbrougb target zones. Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB E-25A Program SER Well bore seg D PLORATION (ALASKA) INC Initial ClasslType SERIPEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal D , Administration Permit fee attached - - - - ~ - - - - - - - - - - - - - - - _ _ Ye$ - - - - - - - - - - - - - - - 2 _Leas_enumber _approwiSlte_ _ _ - - - - - - - - - - - - - - - Y~$ - - - - - - - - - - - -- - - - - - - - - - - - - - - 3 _U_nlqueweltn_arnß_aod O~lTJb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - ~ - - - - - - - - - - - - 4 WeUJQcSlt~d [n_a_defineJ:Lppol _ Y~$ CO iJ,Tl, MPU -ScbrSlde.r aluffOjl ppol_ _ - - - - - - - - - - - - - - 5 We.IIJQCSlt~d prpperdistance_ from driJling unitb_oundary - - - - - -- Y~$ Ooly well io NE1l4_Seç35. - - - - - - - - - - - - - - - - - - 6 We.ll JQc¡;¡t~d pr_oper _dlstanceJrom Qtbe.r wells_ _ _ _ _ Ye$ QUartßr-qu_arter~q!JçHter gQv~(nrneot¡;¡Ls~cUon .(nornjnaI10eacre) drjllinguoits, Nearest well>200Œ away, _ 7 _SutficienLacreageaYailSlble indriUiog unjL _ _ - - - - - - Ye$ - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - 8 Jtd~viated, js_ weJlbQre plaUncJu_ded _ - - - - Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 9 _Operator onl}! affected party _ - - - - - - - - - - - - - - - Ye$ WelJ IpC3_ted ne¡;¡r ~eoter Qf APL 0255J 6 _ - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - 10 _OJ>!H_ator bas_apprppriateJ).ond inJQrce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~$ - - - - - - - - - - - - - -. . . - - - - - - - - - - - - - - - - - - . . - - - - - - - - - - - - - - - - - - - - - - - - - - - -. 11 P~rlTJit ~ao be iS$~ed witbQut COMerva_tion order. . . . . _ . _ . . . . . . . - - - - Ye$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . Appr Date 12 P~rmit ~ao be iS$~ed witbQut ~d.lTJilJistratille.aJ>prpvaJ . - - - - . . . . . .Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ SFD 3/5/2004 13 Can permit be approved before 15-day wait Yes 14 Well JQc¡¡t~d within ~rea ~ndstrata .authQrized by.lojectioo Ord~r # (put. 10# in c.ornrn~ots) (For .Y~s Area Injeçtio.n.Order Np. tOeS. _ . . . . . . . . . . _ . . . . . . _ . _ _ - - - - - - - - - - - - - - - - - 15 AJI W~I!s.wit!1i.n.1l4.mite_are.a_of reyi~w id~oUfied (For servjc.e.w.eJ OOly). . . . . _ . . _ . . . . .Y~$ MPU E~2.5 .and IYIPU .Ee25L 1: _ both Qf w!1iJ::b ar~ .being PM'd. _SFP. . . . . . . . . . . . . . . . . . . - - - . . . . . 16 Pre-produçed iojector; .durationof pre-J>roJ:luctiolJ I~$s. than. 3 montbs (Forservi.ce well QnJy) No. - - - - - ~ - - - - - ~ - - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - 17 ACMP finding .of CQnsi,StenGY. h_a$ been Jssued. for. tbi$ Project. _ NA Wedd. dri!led from existing. pad. . . - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 .C_ooductor $tril'lg.prQvid~d . . . . . _ . ~ - - - - - - - - ~ Y~$ Set jn. QriginalweJQore~ . _ . _ . . . . . . . _ . . . . . . . _ - - - - - - - -- - - - - - - - - - - - - - - - ~ 19 .S.urf~c~.casingprQte~ts all.known USDWs . _ - - - - - - - - NA All aq.uifers ex~mpted 40 CfR 147.. t02(b)(3) . . . . . _ . - - - - - - - - - - - - - - - - - 20 .CMT v.ol ad~Quate. to circ.ulate.oncond.uçtpr 8< $u.rf.csg . _ _ - - - - -- Y~$ Cemented tQ $u.rface. io orjgil'lal wellbQre.. . . . _ . . . . . . . . . . _ - - - - - - - - - - - - - - - - - - - - - 21 .CMT vol adeQu_ate to tie-in JQngstring to.surf C$g. . - - - - - - - - - - - No. - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - -- 22 CMT will coyeral! klJow.nproduGtiye hQrizQn.s. . . . . . Y~$ - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 .C.asiog desigos ~d.eQuate fPr C,.T~ B_&perruafrpst . . . . . . . . . . .Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 .AJ:lequSlte.t~nkageoJ re.seI'Ye pit. . . . . _ . . . . . . . . . . - - - - - - .Y.e$ Rig js equippe.d.with steel.pits. _ NQ r~$eJlle.pjt-planoed, Wa.steto an ap-proyecl disPP$al well. . . . . . _ 25 Ka.re-J:lrilL has_a 10-403 fQr Slbandon.me.nt be~o ¡;¡pprQved . . . . . . . . Y~$ Sioce. tbere is .a.ITJQtherbore and .aJater2s!Jodri~$ wer~ approv.ed.. 3Q4-053 , 304-054. . - - - - - - 26 AJ:lequSlte.we!lbore.separatio.n.proJ>oseJ:l. . . _ . . . . _ _ . . . . . . _ . . .Y~$ TraveJilJg Gylin.d~r: plQt il'lcluded, _S~ve.ral.O.H. weJI.seGtiplJs. io $and$.. CQllisioo/inteJseJ::t risk low, _ . . . . . . . . 27 Kdiverter reqµire.d, does it meet reguJatiolJs. . . . . . . . . . . . . NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . Appr Date 28 .DriUiog fluid progralTJ $~hemat[c.& eqµip Jistadequ¡;¡te. . . . . . _ . Y~s Maximum expected BHf> 8.2 EMW. . f>l~nned MW 9.0 ~ 9.3 PP!} . . . . . . . - - - - - - - - - - - - - - - - T~2004 29 BOPE$,.d.othey meetreguJation . . . . . . . . . . . . _ _ _ .Y~$ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - ~ - - 30 .BOPEpres$ ratiog apJ>roPriate; .test to (pu.t psig i.n .comment$)_ . Y~$ CaIGuJa.ted.MASf> 1.406 psi. ProPQsal. to test to 30QO.psL AdequSlte.prQvided te$t.pressures arel'l'thig!1er, . ';/5 31 _Choke manifold CQlTJpJies w/API. Rf>-53 (May 84) - - - - - - .Y.e$ . . fu.rthertQ ~rea oUevje.w.. .E.-25.et ¡;¡I.had J plug baGk.and 3 ppe.n.hpl~sidetracks withintbe sands. .f>B1 32 WQrk will PGC!Jr without.operatjonsbutdo.w.n. _ - - - - - - .Y~$ . . did pen~trate the çonfioiog zo_ne,b.ut W¡;¡S cemented. The.OH $idetracks.are horQzontaUn the $nds/sbales 33 Js presence_ Qf H2S g~s. proQable. . . . . . . _ - - - - - - - - - - - - No. Mud should preclude H2S o.n.tbe_ rig, .Rjg. i$ eQujpJ>ed with s.eosors and .alarms.. . _ - - - - - - - 34 MeçbanicalCOlJdjUoo pt well$ within AOR verified (Forservic~ w~1J onJy) Y~$ The.apprpvedabandpoment pl¡;¡n $h.ould saUstactprily isolat~Ee2.5.and E~25L t.See note _abQv~. Geology 35 P~rmit. cao be iS$~ed wlo. hydrogen sulfide meaS!Jres. . . . . . No Maturjng.w.aterflood ar~a;no H2S d~ta PrOyidedto Cpmrnissipn $io~e.2/2_000. . . . . . . . . . . - 36 .D.atapreseoted on. pote.ntial overpres.sur~ .zones. . . . _ _ .Y~$ SGhrader. Sluff re$eJlloir preS$ure expected. to be 6.1 ppg E:MW; wi!1 be drilled with 9.0 - 9.3 ppg, . _ Appr Date 37 S.eismicanalysjs_ Qf shaJlow gas.zpoes NA tfydrates_ are a kn.owo problemJrorn.2.000 - 2500'00 E~f>ad. OriginaJ E-.25 didnpt. enCQunter them. SFD 3/5/2004 38 S~abed _conditioo $urvey -<if off-Sh.ore) _ NA - - - - - -- 39 . CQntact namelphonefor.weekly progress_report$ [e)(pIQratoryooIYl NA - - - - Geologic Date: Engineering Date Commissioner: Commissioner 3{ ~ 14- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drtlting Services LIS Scan Utility e dO 1- ð 15 $Revision: 3 $ LisLib $Revision: 4 $ Fri May 14 07:56:04 2004 >\3~ jYl Reel Header Service name........ . . . . .LISTPE Date.................... .04/05/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .04/05/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-25A 500292298001 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 14-MAY-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003017307 T. MCGUIRE D. GREEN MWD RUN 2 MW0003017307 T. MCGUIRE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 13N 10E 3708 2011 MSL 0) 56.95 23.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 2280.0 RECEIVED JUN 0 9 2004 # AJaica Oil & Gas O)fI;;..,...,~>" ~Ì' REMARKS: e e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THIS RUN WAS TO SET THE WHIPSTOCK AND MILL THE WINDOW. THE TOP OF THE WINDOW IS 2280'MD AND THE BOTTOM OF THE WINDOW IS 2292'MD. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) ¡ PRESSURE WHILE DRILLING (PWD) ¡ AND AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP) , DATED 5/13/04. 6. MWD RUNS 1 & 2 REPRESENT WELL MPE-25A WITH API#: 50-029-22980-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8325'MD/4461'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 2239.0 2270.0 2270.0 2270.0 2270.0 STOP DEPTH 8275.5 8268.5 8268.5 8268.5 8268.5 FET ROP $ 2270._ 2280.0 8268.5 8325.0 e # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 2239.0 2257.5 MERGE BASE 2306.0 8325.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2239 8325 5282 12173 2239 8325 ROP MWD FT/H 0.05 677.38 138.092 12091 2280 8325 GR MWD API 5.07 134.05 68.9833 12074 2239 8275.5 RPX MWD OHMM 0.6 2000 11.6376 11998 2270 8268.5 RPS MWD OHMM 0.24 2000 12.3372 11998 2270 8268.5 RPM MWD OHMM 0.23 2000 12.9009 11998 2270 8268.5 RPD MWD OHMM 0.15 1883.36 13.0271 11998 2270 8268.5 FET MWD HOUR 0.14 10.48 0.773563 11998 2270 8268.5 First Reading For Entire File......... .2239 Last Reading For Entire File.......... .8325 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 e Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 2239.0 2280.0 STOP DEPTH 2257.0 2306.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 12-APR-04 Insite 66.37 Memory 2306.0 2280.0 2306.0 .1 33.3 TOOL NUMBER 62456 5.625 2280.0 Water Based 9.00 57.0 9.5 100 9.2 74.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): e e # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2239 2306 2272.5 135 2239 2306 ROP MWD010 FT/H 1.37 45.35 21.1451 53 2280 2306 GR MWD010 API 37.46 55.89 50.4773 37 2239 2257 First Reading For Entire File......... .2239 Last Reading For Entire File.......... .2306 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 3 header data for each bit run in separate files. 2 .5000 START DEPTH STOP DEPTH GR RPD RPM RPS RPX FET ROP $ 2257._ 2270.0 2270.0 2270.0 2270.0 2270.0 2306.5 8275.5 8268.5 8268.5 8268.5 8268.5 8268.5 8325.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e 15-APR-04 Insite 66.37 Memory 8325.0 2306.0 8325.0 33.3 71.0 TOOL NUMBER 62456 130910 6.125 2280.0 LSND 9.15 54.0 9.0 300 7.8 3.000 2.610 3.500 3.200 66.0 76.8 66.0 66.0 e e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2257.5 8325 5291.25 12136 2257.5 8325 ROP MWD020 FT/H 0.05 677.38 138.607 12038 2306.5 8325 GR MWD020 API 5.07 134.05 69.0402 12037 2257.5 8275.5 RPX MWD020 OHMM 0.6 2000 11.6376 11998 2270 8268.5 RPS MWD020 OHMM 0.24 2000 12.3372 11998 2270 8268.5 RPM MWD020 OHMM 0.23 2000 12.9009 11998 2270 8268.5 RPD MWD020 OHMM 0.15 1883.36 13.0271 11998 2270 8268.5 FET MWD020 HOUR 0.14 10.48 0.773563 11998 2270 8268.5 First Reading For Entire File........ ..2257.5 Last Reading For Entire File.......... .8325 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/14 Maximum Physical Record. .65535 File Type............... .LO Next File Name........ ...STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/05/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .04/05/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... . . . . . .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF e e End Of LIS File