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Home My WebLink About202-1521. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement Squeeze 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,050' 9,034 Fill Casing Collapse Conductor 470psi Surface 3,090psi Production 5,410psi Slotted Liner 'OA'N/A Slotted Liner 'OB'N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Lewis Contact Email: Contact Phone: 303-906-5178 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): MILNE PT UNIT I-15 MILNE POINT Proposed Pools: SCHRADER BLUFF OIL N/A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4,106' 9,034' 4,106' 663 Size 112' 112' Suspension Expiration Date: 202-152 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23106-00-00 Hilcorp Alaska LLC C.O. 477B TVD Burst 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. AOGCC USE ONLY 9.3# / L-80 / EUE 4,688'3-1/2" Authorized Name and Digital Signature with Date: Wells Manager Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 4,042' 3,085' 5,204' Length PRESENT WELL CONDITION SUMMARY 4,849' N/A MD 1,490psi N/A 5,730psi 7,240psi 2,761' 3,968' 8,922' 4,106'4-1/2" Tubing Size: 112' 20" 9-5/8" 7" 3,085' 4-1/2"4,053' ryan.lewis@hilcorp.com 7'' x 3.5'' 26-32# DLH Ret., 7'' x 4'' Tri Point Perma & Baker ZXP LTP and N/A 4,179 MD/ 3,638 TVD, 4,684 MD/ 3,612 TVD & 5,095 MD/ 4,025 TVD and N/A 9,041' Perforation Depth MD (ft): N/A 2/1/2026 See Schematic 3,841' See Schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2026.01.14 11:48:03 - 09'00' Taylor Wellman (2143) 326-027 By Grace Christianson at 12:31 pm, Jan 14, 2026 A.Dewhurst 16JAN26 MGR15JAN2026 10-404 DSR-1/22/26JLC 1/22/2026 01/22/26 Cleanout Well: MPU I-15 Date: 1/9/2026 Well Name:MPU I-15 API Number: 50-029-23106-00 Current Status:Shut in Rig:Coil Estimated Start Date:2/1/26 Estimated Duration:1 days Regulatory Contact:Tom Fouts (907) 777-8398 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure:1017 psi @ 3,535 TVD BHP gauge 5.5 MWE Max. Possible Surface Pressure:663 psi (Based on 0.1 psi/ft. gas gradient) Max Deviation: 90° @ 5,200 MD Min ID:2.75 ID @ 4731 MD Brief Well Summary: The Milne Point I-15 well was drilled as a Schrader Bluff development multi-lateral well that TDd ran 4- 1/2 slotted liners in OB at a depth of 9,050 and in OA at 9,000 in September 2002. The well was initially completed with an ESP. This and subsequent ESPs failed and were replaced in 2008 and 2014. The pump failed in February 2015 and was replaced using the Nordic #3 rig in March 2015. The 7 casing was tested to 1,500 psi down to 4,774. The ESP plugged off in February 2017. A coil tubing cleanout of the tubing was unsuccessful. No scaling or subsidence issues. 2022 this well was converted to JP. During the FCO in 2025 we dragged heavy on short trips until we hit the N sand screens. The working hypothesis is that the N sand screens failed and every time we pulled past them, we dumped all the sand from the lateral in the N sand screen failure. Our plan is to cement the N sand screens and drill it out. Objectives: Cement squeeze the N sand screens. Slickline: 1. RU and pressure test PCE. 2. Make a drift run to XN nipple at 4,731, 2.75 ID No-Go. 3. Set a PXN lock in the XN. 4. Dump bail 10 of sand on top of it. 5. RD. Eline: 1. RU and pressure test PCE. 2. RIH and set the top of the Nine Energy Composite bridge plug at 4,671 MD. a. Correlate to the 3-1/2 Final Completion Tally link below. b."O:\Alaska\Fields\Milne Point\MPU PAD I GATHERING\Wells\MPU I-015\Projects\Archive\MPU I-15 - RWO - 2022 - ESP to JP\Completion Equipment & Tallies FINALS\I-15 3.5'' Final Completion Tubing Tally Draft 8-27-2022.xls" 3. RD Coiled Tubing: 1. MIRU CTU 2. PT PCE according to coil weekly BOP testing. 3. RU Cement Pump equipment 4. RIH with cast iron cement retainer and tag the bridge plug. 5. PU and set the retainer at 4,205 MD 6. Pump 20 bbl Super Flush, 5-10 bbl spacer, and 40 bbls of +-15.8# cement squeeze per the Halliburton recommendations. Cleanout Well: MPU I-15 Date: 1/9/2026 7. Release off the cement retainer. 8. PU 50 and circulate the hole 1.5x bottoms up to ensure a clean hole and tubing. 9. POOH. 10. WOC per lab testing results. 11. RIH with cleanout BHA and mill up the cement and composite bridge plug. 12. RIH and tag up on the plug nubbin and mill the remaining part of the plug. 13. Circulate out the sand down to the prong. POOH. 14. RIH and pull the prong 15. RIH and pull the PXN lock. 16. RIH with Tempress and DJN and cleanout to PBTD in the OB lateral 17. POOH. 18. Bump up, close in and bleed off. 19. RDMO Slickline: 1. RU and Pressure test PCE. 2. Shift open sleeve. 3. Set 3 JP (7B) at 4,081 MD. 4. RDMO Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 1/02/2023 SCHEMATIC Milne Point Unit Well: MP I-15 Last Completed: 8/27/2022 PTD: 202-152 6-1/8 Hole TD @ 9,000 6-1/8 Hole TD @ 9,050 Tag 9,034 CTMD on 9/17/2017TD =9,050(MD)/TD =4,106(TVD) 20 Orig KB Elev.: 62.5 / Orig GL Elev.: 35.0 RKB Elev = 20.0 (Nordic #3) 7 5 & 6 13 1 0 8,9 & 10 15 20 & 21 11 12 16 9-5/8 1 2 1718 19 14 OA Lateral PBTD =9,050(MD) / PBTD = 4,106(TVD) 7 OB Lateral 3 4 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx.) I in 42 Hole 9-5/8" Cmt w/ 919 sx Clas L,225 sx Class G in 12-1/4 Hole 7 Cmt w/ 84 sx AS Lite, 189 sxClass G in 8-1/2 Hole TREE & WELLHEAD Tree 2-9/165M FMC Wellhead 11 5M Gen w/ 2-7/8 EUE T&B Tubing Hanger with CIW H BPV Profile GENERAL WELL INFO API: 50-029-23106-00-00 Drilled and Cased Multi-Lat by Doyon 141 - 9/1/2002 ESP RWO by Nabors 4ES 8/21/2008 ESP Change-out by Doyon 16 5/7/2014 ESP Change-out by Nordic 3 3/29/2015 ESP Change-out by ASR#1 10/5/2017 Convert to Jet pump ASR#1 8/27/2022 LATERAL WINDOW DETAIL Top of OA Window @ 4,849 - 4,861; Well Angle @ Window is 72deg CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded 19.124 Surface 112 9-5/8 Surface 40 / L-80 / Btc. 8.835 Surface 3,085 7" Production 26 / L-80 / BTC-Mod 6.276 Surface 5,204 4-1/2 Sltd Liner OA 12.6 / L-80 / IBT 3.958 4,869 8,922 4-1/2 Sltd Liner OB 12.6 / L-80 / IBT 3.958 5,200 9,041 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / EUE 2.992 Surface 4,688 JEWELRY DETAIL No Depth Item 1 4,081 HES Sliding Sleeve, 3.5'' 2 4,133 BHP Gauge 3.5 3 4,179 7'' x 3.5'' 26-32# DLH Hydraulic Set Retrievable Packer 4 4,231 3.5'' "X" Nipple 5 4,254 Crossover 3.5'' EUE 8RND x 4.5'' Hydril 625 Pin 6 4,255 4.5'' Screen 4.5'' Hydril 625 7 4,667 4.5'' Hydril 625 Box x 3.5'' EUE 8RND Pin Crossover 8 4,681 4 Snap Latch 9 4,682 Ratchet Mule Shoe, Btm @ 4,688 10 4,684 7'' x 4'' Tri Point Perma Pack Permanent Packer 11 4,686 4'' x 5'' Seal Bore 12 4,731 3.5'' "XN" Nipple 2.813'' Profile 2.75" ID NoGo 13 4,767 3 1/2'' WLEG Btm @ 4,767.4 14 4,840 Baker Hook Wall Hanger inside 7 Window (21) 15 4,861 Baker Hook Wall Hanger outside Window (3) 16 4,864 Baker Down Swivel-up Lock sub 17 5,095 Baker Tie Back Sleeve 18 5,102 Baker ZXP Liner Top Packer 19 5,108 Baker 7 x 5 HMC Liner Hanger 20 5,120 7 Halliburton Float Collar 21 5,203 7 Halliburton Float Shoe WELL INCLINATION DETAIL KOP @ 470 Max Hole Angle = 47 deg @ 4,120 MD 60deg, + Past 4,500 MD. Hole Angle through Lateral = 86 deg+ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 4,460 4,490 3,808 3,824 30 8/23/2022 Open NB 4,516 4,546 3,836 3,851 30 8/23/2022 Open NC, NE 4,580 4,684 3,868 3,912 104 8/23/2022 Open _____________________________________________________________________________________ Revised By: RL 1/9/2026 PROPOSED Milne Point Unit Well: MP I-15 Last Completed: 8/27/2022 PTD: 202-152 6-1/8 Hole TD @ 9,000 6-1/8 Hole TD @ 9,050 Tag 9,034 CTMD on 9/17/2017TD =9,050(MD) / TD =4,106(TVD) 20 Orig KB Elev.: 62.5 / Orig GL Elev.: 35.0 RKB Elev = 20.0 (Nordic #3) 7 5 & 6 13 1 0 8,9 & 10 15 20 & 21 11 12 16 9-5/8 1 2 1718 19 14 OA Lateral PBTD =9,050(MD) / PBTD = 4,106(TVD) 7 OB Lateral 3 4 OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset (Approx.) I in 42 Hole 9-5/8" Cmt w/ 919 sx Clas L,225 sx Class G in 12-1/4 Hole 7 Cmt w/ 84 sx AS Lite, 189 sxClass G in 8-1/2 Hole TREE & WELLHEAD Tree 2-9/165M FMC Wellhead 11 5M Gen w/ 2-7/8 EUE T&B Tubing Hanger with CIW H BPV Profile GENERAL WELL INFO API: 50-029-23106-00-00 Drilled and Cased Multi-Lat by Doyon 141 - 9/1/2002 ESP RWO by Nabors 4ES 8/21/2008 ESP Change-out by Doyon 16 5/7/2014 ESP Change-out by Nordic 3 3/29/2015 ESP Change-out by ASR#1 10/5/2017 Convert to Jet pump ASR#1 8/27/2022 LATERAL WINDOW DETAIL Top of OA Window @ 4,849 - 4,861; Well Angle @ Window is 72deg CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded 19.124 Surface 112 9-5/8 Surface 40 / L-80 / Btc. 8.835 Surface 3,085 7" Production 26 / L-80 / BTC-Mod 6.276 Surface 5,204 4-1/2 Sltd Liner OA 12.6 / L-80 / IBT 3.958 4,869 8,922 4-1/2 Sltd Liner OB 12.6 / L-80 / IBT 3.958 5,200 9,041 TUBING DETAIL 3-1/2" Tubing 9.3# / L-80 / EUE 2.992 Surface 4,688 JEWELRY DETAIL No Depth Item 1 4,081 HES Sliding Sleeve, 3.5'' 2 4,133 BHP Gauge 3.5 3 4,179 7'' x 3.5'' 26-32# DLH Hydraulic Set Retrievable Packer 4 4,231 3.5'' "X" Nipple 5 4,254 Crossover 3.5'' EUE 8RND x 4.5'' Hydril 625 Pin 6 4,255 4.5'' Screen 4.5'' Hydril 625 7 4,667 4.5'' Hydril 625 Box x 3.5'' EUE 8RND Pin Crossover 8 4,681 4 Snap Latch 9 4,682 Ratchet Mule Shoe,Btm @ 4,688 10 4,684 7'' x 4'' Tri Point Perma Pack Permanent Packer 11 4,686 4'' x 5'' Seal Bore 12 4,731 3.5'' "XN" Nipple 2.813'' Profile 13 4,767 3 1/2'' WLEG Btm @ 4,767.4 14 4,840 Baker Hook Wall Hanger inside 7 Window (21) 15 4,861 Baker Hook Wall Hanger outside Window (3) 16 4,864 Baker Down Swivel-up Lock sub 17 5,095 Baker Tie Back Sleeve 18 5,102 Baker ZXP Liner Top Packer 19 5,108 Baker 7 x 5 HMC Liner Hanger 20 5,120 7 Halliburton Float Collar 21 5,203 7 Halliburton Float Shoe WELL INCLINATION DETAIL KOP @ 470 Max Hole Angle = 47 deg @ 4,120 MD 60deg, + Past 4,500 MD. 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ŝŶƚĞƌǀĂů͘WƌĞƐƐƵƌĞĐŚĞĐŬĂĨƚĞƌƉĞƌĨƌƵŶηϲ͕ǁĞůůƉƌĞƐƐƵƌĞĂƚϲϱƉƐŝ͘KŶǁĞůůŚĞĂĚŐĂƵŐĞΘŐƌĞĂƐĞŚĞĂĚŐĂƵŐĞ͘/ŶĐƌĞĂƐĞǁĞŝŐŚƚ ŽĨƐŽƵƌĐĞǁĂƚĞƌƚŽϴ͘ϳƉƉŐŝŶƉŝƚƐǁŝƚŚE>͘ƵůůŚĞĂĚĂǁĂǇϭϴϬďďůƐĂƚϯWDǁͬϭ͕ϮϬϬƉƐŝ͘^ŚƵƚĚŽǁŶƉƵŵƉƐĂůůŽǁǁĞůůƚŽ ĨůŽǁďĂĐŬĂĨƚĞƌďƵůůŚĞĂĚ͘&ůŽǁĚŝŵŝŶŝƐŚŝŶŐƚŽŶŽĨůŽǁ͘ŚĞĐŬ/ĨŽƌƉƌĞƐƐƵƌĞϬW^/͘ŽŶΖƚǁŝƚŚǁŝƌĞůŝŶĞŽƉƐ͘ZƵŶƉĞƌĨŝŶƚĞƌǀĂůƐ ΘĐŽƌƌĞůĂƚĞƚŽ>ǁŝƚŚƉĞƌǀŝŽƵƐŐĂŵŵĂŽĨĨƐĞƚĐŽŶĨŝƌŵtͬŐĞŽůŽŐŝƐƚ͘EƐĂŶĚƐZƵŶηϳсϰ͕ϱϮϲΖͲϰ͕ϱϭϲΖ͘EƐĂŶĚƐZƵŶηϴс ϰ͕ϰϵϬΖͲϰ͕ϰϳϬΖͬZƵŶηϵсϰ͘ϰϳϬΖͲϰ͕ϰϲϬΖůůƐŚŽƚƐĨŝƌĞ͕ϲƐŚŽƚƐƉĞƌĨŽŽƚ͘ŚĞĐŬǁĞůůƉƌĞƐƐƵƌĞĂĨƚĞƌĞĂĐŚƉĞƌĨŝŶƚĞƌǀĂů͘tĞůů ƐƚĂƚŝĐ͘ZͬͲůŝŶĞ͕>ͬƚŽŽůƐ͘EͬƐŚŽŽƚŝŶŐĨůĂŶŐĞ͕ΘEͬhĨůŽǁƐƉŽŽůƐ͘WƵůůŚĂŶŐĞƌƚŽĨůŽŽƌ͘ZĂĐŬΘƚĂůůǇ:WĐŽŵƉůĞƚŝŽŶ͕ĐŚĂŶŐĞ ŽƵƚŚĂŶĚůŝŶŐĞƋƵŝƉŵĞŶƚŽŶƌŝŐĨůŽŽƌ͘Z/,tͬ:WĐŽŵƉůĞƚŝŽŶDͬhůĂƚĐŚŝŶŐƐĞĂůĂƐƐǇ͕͘ǆŽ͕ϭϬƐĐƌĞĞŶƐdͬϰϯϮΖ͘ Z/,tͬϳΗƚĞƐƚƉĂĐŬĞƌ&ͬϱϯϯΖdͬϰ͕ϮϱϬΖZ/,ĂƚϵϬ&WD͘,ŽůĞĨƵůů͕hƐŝŶŐĐŽŶƚŝŶƵŽƵƐŚŽůĞĨŝůů͘WͬhtdсϰϮ<ͬ^ͬKtdсϮϱŬ͘^Ğƚ ϳΗƚĞƐƚƉĂĐŬĞƌĂƚϰ͕ϮϱϬΖΘƐĞƚĚŽǁŶϮϬŬŽŶ͕͘WƌĞƐƐƵƌĞƵƉdͬϯ͕ϳϬϬƉƐŝĨŽƌϯϬĐŚĂƌƚĞĚŵŝŶƐ͕;'ŽŽĚdĞƐƚͿZĞůĞĂƐĞƉĂĐŬĞƌ͕Wͬh tdсϰϮŬ͘WKK,tͬϳΗƚĞƐƚƉĂĐŬĞƌ&ͬϰϮϱϬΖDdͬƐƵƌĨĂĐĞ͘hƐŝŶŐĐŽŶƚŝŶƵŽƵƐŚŽůĞĨŝůů͘>ͬƚĞƐƚƉĂĐŬĞƌΘŝŶƐƉĞĐƚ͘EŽĞǆĐĞƐƐ 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his email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Brian Glasheen Cc:David Haakinson Subject:20220830 14:30 Approval to POP without no flow test MP I-15 AOGCC 10-403 Submittal, PTD: 202-152 Date:Tuesday, August 30, 2022 2:30:55 PM Brian, AOGCC will waive the requirement to ‘pass a no-flow test’ to POP this well. Hilcorp is approved to produce this well without a passing no flow test. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. David Haakinson From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Tuesday, August 30, 2022 1:52 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: FW: MP I-15 AOGCC 10-403 Submittal, PTD: 202-152 Mel, Thanks for taking my call. The field is waiting to bring I-15 online. Can you please waive the No flow test that was written in the sundry for this well to allow the team to BOL tonight? Well passed a MIT-IA to 3700 psi yesterday. Thanks Brian Glasheen Operations Engineer 907-545-1144 From: Tom Fouts <tfouts@hilcorp.com> Sent: Wednesday, June 29, 2022 2:54 PM To: aogcc.permitting@alaska.gov Cc: Brian Glasheen <Brian.Glasheen@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: MP I-15 AOGCC 10-403 Submittal, PTD: 202-152 Samantha, Please process the attached 10-403 submittal for MP I-15, PTD: 202-152 Thanks, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 5HJJ-DPHV%2*& )URP$ODVND16$65:HOO6LWH0DQDJHUV$ODVND16$65:HOO6LWH0DQDJHUV#KLOFRUSFRP! 6HQW7XHVGD\$XJXVW$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F$ODVND16$65:HOO6LWH0DQDJHUV 6XEMHFWLLQLWLDO%23(WHVWUHSRUW $WWDFKPHQWVL%23(WHVWUHSRUWLQLWLDO[OV[ dŚĂŶŬǇŽƵ͘ Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 8/20/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2021520 Sundry #322-382 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:807 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1FP Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"P Pressure After Closure (psi)1750 P Check Valve 0NA200 psi Attained (sec)11 P BOP Misc 0NAFull Pressure Attained (sec)50 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2087 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 29 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:4.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/18/22 22:51 Waived By Test Start Date/Time:8/20/2022 17:00 (date) (time)Witness Test Finish Date/Time:8/20/2022 21:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Chart shows on test #4. Low pressure, Fail. Small leak found at FOSV XO. Bleed off & re-tighten. Restart test, passed. C. Pace / J. Werlinger Hilcorp Alaska LLC S. Heim / R. Gallen MPU I-15 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2022-0820_BOP_Hilcorp_ASR1_MPU_I-15 9 99 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ FP Small leak found at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tĞůůŚĞĂĚ ϭϭ͟ϱD'ĞŶǁͬϮͲϳͬϴ͟hdΘdƵďŝŶŐ,ĂŶŐĞƌǁŝƚŚ /t͞,͟WsWƌŽĨŝůĞ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϭϬϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚ DƵůƚŝͲ>Ăƚ ďǇ ŽǇŽŶϭϰϭ Ͳ ϵͬϭͬϮϬϬϮ ^WZtKďǇEĂďŽƌƐϰ^ ʹ ϴͬϮϭͬϮϬϬϴ ^WŚĂŶŐĞͲŽƵƚďǇŽǇŽŶϭϲ ʹ ϱͬϳͬϮϬϭϰ ^WŚĂŶŐĞͲŽƵƚďǇEŽƌĚŝĐϯ ʹ ϯͬϮϵͬϮϬϭϱ ^WŚĂŶŐĞͲŽƵƚďǇ^Zηϭ ʹϭϬͬϱͬϮϬϭϳ >dZ>t/EKtd/> dŽƉŽĨ͞K͟tŝŶĚŽǁΛ ϰ͕ϴϰϵ͛ Ͳ ϰ͕ϴϲϭ͖͛ tĞůůŶŐůĞΛtŝŶĚŽǁŝƐϳϮĚĞŐ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ /dŽƉ ƚŵ ϮϬΗ ŽŶĚƵĐƚŽƌ ϵϮͬ,ͲϰϬͬtĞůĚĞĚ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϭϭϮ͛ ϵͲϱͬϴ͟^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬƚĐ͘ϴ͘ϴϯϱ ^ƵƌĨĂĐĞ ϯ͕Ϭϴϱ͛ ϳΗ WƌŽĚƵĐƚŝŽŶ Ϯϲͬ>ͲϴϬͬdͲDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨĂĐĞ ϱ͕ϮϬϰ͛ ϰͲϭͬϮ͟^ůƚĚ>ŝŶĞƌKϭϮ͘ϲͬ>ͲϴϬͬ/d ϯ͘ϵϱϴ ϰ͕ϴϲϵ͛ϴ͕ϵϮϮ͛ ϰͲϭͬϮ͟^ůƚĚ>ŝŶĞƌKϭϮ͘ϲͬ >ͲϴϬ ͬ/d ϯ͘ϵϱϴ ϱ͕ϮϬϬ͛ϵ͕Ϭϰϭ͛ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯηͬ>ͲϴϬ Ϯ͘ϵϵϮ ^ƵƌĨĂĐĞ цǆ͕ǆǆǆ͛ :t>Zzd/> EŽ ĞƉƚŚ /ƚĞŵ ϭ цǆ͕ǆǆǆ͛ϯͲϭͬϮ͟ ,>^ůŝĚŝŶŐ^ůĞĞǀĞ Ϯ цǆ͕ǆǆǆ͛,W' ϯ цϰ͕Ϯϯϵ͛ϳ͟ ǆϯͲϭͬϮ͟dƌŝƉŽŝŶƚ >, WĂĐŬĞƌ ϰ цǆ͕ǆǆǆ͛ϯͲϭͬϮ͟ ͞y͟ EŝƉƉůĞ ǁŝƚŚZ,͕/ с Ϯ͘ϴϭϯ ϱ цǆ͕ǆǆǆ͛ϰͲϭͬϮ͟ ǆϯͲϭͬϮ͟ ƌŽƐƐŽǀĞƌ ϲ цǆ͕ǆǆǆ͛ϮϱϬDŝĐƌŽŶ ^ĐƌĞĞŶƐ ǁŝƚŚĞŶƚƌĂůŝǌĞƌ ϳ цǆ͕ǆǆǆ͛ϯͲϭͬϮ͟ ǆϰͲϭͬϮ͟ ƌŽƐƐŽǀĞƌ ϴ цǆ͕ǆǆǆ͛ϰ͟ ^ŶĂƉ>ĂƚĐŚ ^ĞĂů ƐƐĞŵďůǇǁͬDƵůĞ^ŚŽĞ ϵ цϰ͕ϳϴϱΖ ϳ͟ ǆϰ͟ WĞƌŵĂƉĂĐŬWĂĐŬĞƌ ϭϬ цǆ͕ǆǆǆ͛ϰ͟ ǆϱ͛ ^ĞĂůŽƌĞ ϭϭ ц ǆ͕ǆǆǆ͛ϯͲϭͬϮ͟ ͞yE͟ WƌŽĨŝůĞEŝƉƉůĞ;Ϯ͘ϴϭϯ͟ WƌŽĨŝůĞ͕Ϯ͘ϲϲϲ͟EŽͲ'ŽͿ ϭϮ цǆ͕ǆǆǆ͛ϯͲϭͬϮ͟ t>'͕ďŽƚƚŽŵĂƚ цǆ͕ǆǆǆ͛ ϭϯ ϰ͕ϴϰϬ͛ĂŬĞƌ,ŽŽŬtĂůů,ĂŶŐĞƌŝŶƐŝĚĞϳ͟tŝŶĚŽǁ;Ϯϭ͛Ϳ ϭϰ ϰ͕ϴϲϭ͛ĂŬĞƌ,ŽŽŬtĂůů,ĂŶŐĞƌŽƵƚƐŝĚĞtŝŶĚŽǁ;ϯ͛Ϳ ϭϱ ϰ͕ϴϲϰ͛ĂŬĞƌŽǁŶ^ǁŝǀĞůͲƵƉ>ŽĐŬ ƐƵď ϭϲ ϱ͕Ϭϵϱ͛ĂŬĞƌdŝĞĂĐŬ^ůĞĞǀĞ ϭϳ ϱ͕ϭϬϮ͛ĂŬĞƌyW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϭϴ ϱ͕ϭϬϴ͛ĂŬĞƌϳ͟ǆϱ͟,D>ŝŶĞƌ,ĂŶŐĞƌ ϭϵ ϱ͕ϭϮϬ͛ϳ͟,ĂůůŝďƵƌƚŽŶ&ůŽĂƚŽůůĂƌ ϮϬ ϱ͕ϮϬϯ͛ϳ͟,ĂůůŝďƵƌƚŽŶ&ůŽĂƚ^ŚŽĞ t>>/E>/Ed/KEd/> <KWΛϰϳϬ͛ DĂǆ,ŽůĞŶŐůĞсϰϳĚĞŐ Λϰ͕ϭϮϬ͛D ϲϬĚĞŐ͕нWĂƐƚϰ͕ϱϬϬ͛D͘ ,ŽůĞŶŐůĞƚŚƌŽƵŐŚ>ĂƚĞƌĂůсϴϲĚĞŐн WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ Eϰ͕ϰϲϬ͛ϰ͕ϰϵϬ͛ϯ͕ϴϬϴ͛ϯ͕ϴϮϰ͛ϯϬ WƌŽƉŽƐĞĚ &ƵƚƵƌĞ Eϰ͕ϱϭϲ͛ϰ͕ϱϰϲ͛ϯ͕ϴϯϲ͛ϯ͕ϴϱϭ͛ϯϬ WƌŽƉŽƐĞĚ &ƵƚƵƌĞ E͕Eϰ͕ϱϴϬ͛ϰ͕ϳϮϬ͛ϯ͕ϴϲϴ͛ϯ͕ϵϮϱ͛ϭϰϬ WƌŽƉŽƐĞĚ &ƵƚƵƌĞ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ RECEIVE= STATE OF ALASKA D ALL OIL AND GAS CONSERVATION COMIRSION OCT 2 6 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon LJ Plug Perforations U Fracture Stimulate LJ Pull Tubing ✓ LJ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:CT FCO w/N2&ESP Swap 0 2.Operator 4.Well Class Before Work: Name: Hilcorp Alaska LLC 5.Permit to Drill Number: Development 0 Exploratory ❑ 202-152 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-23106-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT 1-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 9,050 feet Plugs measured N/A feet true vertical 4,106 feet Junk measured 9,034(Fill) feet Effective Depth measured 9,034 feet Packer measured 5,102 feet true vertical 4,106 feet true vertical 4,026 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 3,085' 9-5/8" 3,085' 2,761' 5,730psi 3,090psi Production 4,849' 7" 4,849' 3,968' 7,240psi 5,410si Slot Liner'OA' 4,053' 4-1/2" 8,922' 4,042' N/A N/A Slot Liner'OB' 3,841' 4-1/2" 9,041' 4,106' N/A N/A Perforation depth Measured depth See Schematic feet True Vertical depth SCANNED JA� 1 i 0 I6 P See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 3,842' 3,387' Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 300 0 Subsequent to operation: 172 15 174 240 210 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-207 Sris Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: iNFB o1/420/1C Date: p U I26 f(.) Contact Phone: 777-8412 Form 10-404 Revised 4/2017 1rt/% '7 L, l/ I'1"7 ® :� i(�Dl .`J U.� r0)vf - 1017 Submit Original Only • • Milne Point Unit II Well: MPI-15 SCHEMATIC Last Completed: 10/5/2017 Hikora Alaska,[d.(: PTD: 202-152 TREE&WELLHEAD Tree 2-9/16"-5M FMC Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with Orig KB Elev.:62.5'/Orig GL Elev.:35.0' CIW"H"BPV Profile RKg Fl )Q(I nrdlic#3) A s OPEN HOLE/CEMENT DETAIL ; L 20" �" 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole 17" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole , WELL INCLINATION DETAIL KOP @ 470' Max Hole Angle=47 deg @ 4,120'MD 60deg,+Past 4,500'MD. Hole Angle through Lateral=86 deg+ 9-5/8"4 i, LATERAL WINDOW DETAIL Top of"OA"Window @ 4,849'-4,861';Well Angle @ Window is 72deg CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 92/H-40/Welded 19.124 Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' 7" Production 26/L-80/BTC-Mod 6.276 Surface 5,204' 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner OB 12.6/L-80/IBT 3.958 5,200' 9,041' 2 TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2..441 Surface 3,842' JEWELRY DETAIL No Depth Item , 1 140' Sta#2:Camco 2 7/8 X 1"Side pocket,W/DOSV • 2 3,670' Sta#1:Camco 2 7/8 X 1"Side pocket,With Dummy GLM 3 3 3,749' 2-7/8"XN Nipple:Min ID=2.205" 4 3,790.8' Discharge Head: FPDIS r i 4 5 3,791.3' PUMP FLEXER SXD H6 6 _ 3,815' Gas Separator:GPINTXAR 5 7 3,816' Upper-Tandem Seal Section:GSB3DBUT SB/SB PFSA 8 3,823' Lower-Tandem Seal Section:GSB3DBUT SB/SB PFSA MI I16 9 3,830' Motor: CL5 XP,100hp/1,820V/34A 10 3,838' Phoenix XT150 w/6 fin Centralizer-Anode:Bottom @ 3,842' 788 11 4,840' Baker Hook Wall Hanger inside 7"Window(21') 12 _ 4,861' Baker Hook Wall Hanger outside Window(3') 3B"SSCapstring �' :1 9 13 _ 4,864' Baker Down Swivel-up Lock sub Check Value 14 5,095' Baker Tie Back Sleeve 1,425psi 15 5,102' Baker ZXP Liner Top Packer bag 16 5,108' Baker 7"x 5"HMC Liner Hanger 10 17 5,120' 7"Halliburton Float Collar C'" 18 5,203' 7"Halliburton Float Shoe GENERAL WELL INFO API:50-029-23106-00-00 c Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 te ESP RWO by Nabors 4ES-8/21/2008 "11 ESP Change-out by Doyon 16-5/7/2014 �4.. 12 ESP Change-out by Nordic 3-3/29/2015 ss 4 � 13 ESP Change-out by ASR#1-10/5/2017 at 3i r 4/- ,s. . ; "OA Lateral 6-1/8"Hole TD @ 9,000' 14t ' '4" 15It' 16 7" 17 8,18 411 ` "OE Lateral 6-1/8"Hole TD @ 9i50' TD=9,050'(MD)/TD=4,106'(TVD) Tag 9,034'CTMD PBTD=9,050'(MD)/PBTD=4,106'(TVD) on 9/17/2017 Revised By:TDF 10/24/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-15 ASR#1 50-029-23106-00-00 202-152 8/28/17 10/5/17 Daily operations: 8/23/2017-Wednesday No activity to report. 8/24/2017 -Thursday No activity to report. 8/25/2017- Friday No activity to report. 8/26/2017-Saturday No activity to report. 8/27/2017 -Sunday No activity to report. 8/28/2017- Monday Continue to move from 1-19 to 1-15. Remove rig floor and spot on well house on 1-15. Back rig carrier into place on 1-15. L/D herculite containment for pipe handling, raise mast and prep rig floor. SIMOPS: N/D BOPE on 1-19 and place in storage trailer. N/U 4-1/16" production tree on 1-19. Greg Ruge on location to test tree void to 500psi low 5,000psi high (Good Test) Service Rig Check Fluids and Grease Continue Rigging up, ASRC Crane Hoisted and Installed Stairs to Rig Floor, Spotted well site Trailer, Spotted Pit Trailer, Cat walk and Pipe Racks, Rigged up Hydraulic Lines to Bop stack From Accumulator Room, Connect all Service lines From pits to Rig, Hang ESP/ E-Trunk Sheave in Derrick, Received 250 bbl. 140 degree sea water, Electrician Rigged up Fire and Gas Detection in pits, Cellar and Rig Floor, Rigged up for well kill Operations, ICP Pumped Down Tubing at 3 Bpm w/psi=130 with 55 bbl. pumped away Got returns to the Flow back tank,Total bbl. Pump 160 FCP w/Pump Rate 3bpm @ 280psi, Blow down all service lines, Greased Choke Manifold Valves, Manual valves on Bop stack Well Head Rep Greg Ruge Tee Bar removed BPV and Install TWC Valve in Hanger Profile Safety meeting MPI-15 Sundry Meeting with IWS Crew Tool Pusher, Company man Rig up Test Equipment Test bop as per sundry,Test with 2-7/8" and 4-1/2" Test Joints all Rams and Valves 250 low/2,500 high 5 min each,Test Annular with 2-7/8"test joint I-BOP and TIW Valves 250 low/2,500 high 5 Min Each, (AOGCC Lou , Laubenstein Waived Bop Test). • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-15 ASR#1 50-029-23106-00-00 202-152 8/28/17 10/5/17 Daily Operations: =a,3ny 8/29/2017 -Tuesday Test BOP as per sundry.Test with 2-7/8" and 4-1/2" test joints to 250psi low/2,500psi high 5 charted min each,Test Annular with 2-7/8" test joint, 1-BOP and TIW Valves 250psi low/2,500psi high 5 Min Each, (AOGCC Rep Lou, Laubenstein Waived Bop Test Witness @ 20:30 8/27/17 ) R/D f/testing BOPE, Greg Ruge on location to pull TWC and R/U to pull TBG Hanger(no pressure seen on the IA or TBG once TWC pulled). P/U landing joint, M/U x-over and TIW to landing joint. BOLDS and verify how far out they are. Pull TBG hanger to the floor. 32klbs to unseat, no drag seen. Clean pull to the floor. Cut ESP cable and L/D hanger, Mix Baraklean w/60bbls of 140deg seawater. Pump 40bbls of the 60bbl baraklean pill down IA to clean pipe. POOH w/ ESP completion on 2-7/8" 6.5ppf EUE pipe f/4,214'md to surface. L/D Baker Centrilift ESP completion. Last 4 joints of 2-7/8" pipe pulled wet. L/D 130jnts of 2-7/8", 2 GLM's w/ pups, and 1 XN nipple. 71 cross collar clamp, 3 half clamp, 5 protectorlizers,Service Rig Check Fluids and Grease Break and Lay down ESP Pump Assembly, Minimum Corrosion on Motor and Gas Separator, Main Shaft Turned Through out lower and Upper Tandem, Seals, Will now if it is parted at Motor when Centrilift Reps break Pump Apart Remove E-Trunk and ESP Sheave From Derrick, Change over Handing Equipment from 2-7/8"to 3-1/2"TIH w/7" 26#Casing Scraper on 3-1/2 Work String to Top Hook Wall Hanger, ASR Rig RKB=16.7 19 ft. in on Joint 121 Tagged set 10k down (Total Depth=4,849.56) P/U/W=47K D/N/W=33K Tooh w/7" 26#Casing Scraper on 3-1/2" Work String f/4,853'. to Surface TIH w/7" 26# RTTS Test Packer on 3-1/2" Work String f/Surface to 3,500'. ® • Hilcorp Alaska, LLC Weekly p Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-15 ASR#1 50-029-23106-00-00 202-152 8/28/17 10/5/17 Daily Operations: 8/30/2017 -Wednesday Continue to RIH w/ Halliburton RTTS PKR f/3,500'md to 4,817'md (28' in on jnt 120) P/U =48KIbs S/O = 32klbs. Set RTTS PKR and test annulus to 1,500psi f/30 charted mins. (Good Test) Release RTTS PKR w/a straight pull (48KIbs). Bullhead 10bb1 Baraklean pill down the TBG and 30bbl Baraklean down the IA to clean up the drill string. POOH f/4,817'md to surface. L/D RTTS running tool (no signs of damage, good shape). Change out handling equipment to RIH w/3.5" 9.3ppf L- 80 EUE velocity string completion. Load and tally all TBG, strap all completion equipment. RIH w/Weatherford retrievable production PKR on 3.5" 9.3ppf L-80 EUE velocity string f/surface to ^2,560'md. Service Rig Check Fluids and Grease RIH w/ Weatherford retrievable production PKR on 3.5" 9.3ppf L-80 EUE velocity string f/2,560'to 4,852'. Space well out, (Total Depth 4,852') Pick up Landing Joint make up in Hanger Land Hanger RILDS, Back out Landing Joint, Closed Blind Rams Flush TBG with sea water 20 bbl., P/U/W=40K D/N/W= 27K Rig up LRS Pump 50 bbl. down IA& 10bb1. down TBG Pick up Landing Joint Make up in Hanger, Drop Ball and Rod, Lay down Landing Joint, Wait 10 min For Ball and rod on seat Rig up Test Equipment,Close Blind Rams,Pressure up on TBG 2,500psi 30 Min Charted, Bleed down to 1,000psi. Pressure up on IA 1,500psi 30 min Charted, (Good Solid Test Both Sides) Well Head Rep Greg Ruge Tee Bar Install BPV in TBG Hanger Profile, (Release Rig at 0200 8-31-17) Blow down and Disconnect all Service Lines, Disconnect Hydraulic Lines From Bop Stack to Accumulator Unit, Transfer 150 bbl. from Pits to Flow back Tank, Electrician Sean Disconnected Fire and Gas System on Rig, Roads and Pads Hauling Rig Equipment to A-PAD, Nipple down and Remove spacer Spools, Nipple down Bop stack to Four Bolts, Removed Hand Railing fromTop of Swivel. 8/31/2017 -Thursday Continue to R/D on 1-15 and warm stack ASR on A pad. Spot 4-1/16" production tree on 1-15 utilizing the loader. Greg Ruge on location at I Pad to test tree and void. 9/1/2017- Friday No activity to report. 9/2/2017-Saturday No activity to report. 9/3/2017 -Sunday No activity to report. 9/4/2017- Monday No activity to report. • • Hilcorp Alaska, LLC WeeklyOperations Summary p Well Name Rig API Number Well Permit Number Start Date End Date MP 1-15 CTU #14 50-029-23106-00-00 202-152 8/28/17 10/5/17 Daily Operations: 9/13/2017 -Wednesday No activity to report. 9/14/2017 -Thursday No activity to report. 9/15/2017 - Friday No activity to report. 9/16/2017 -Saturday MIRU SLB CTU #14 with 2" CT. Perform BOP test. MU BHA for FCO. SDFN. No night activity. 9/17/2017-Sunday On location. PJSM. Hall N2 on site. RU HAL N2 hardline. BHA installed = 2" OD int dimple CTC, 2.13" OD DBPV, 2 x Wt Bars, TJ disconnect (5/8" ball),2" OD Rupture disc sub (6k), 2.13" OD Tempress screen,Tempress,XO, 2.5" OD JSN. OAL= 17.5'. Stab on well, nipple up BOPE. Low PT surface lines and stack to 450 psi -good. Close choke - High PT stack to 3750 psi,T/I/O =40/0/55. RIH with 2.5"JSN for nitrified FCO. Start pumping N2 and fluids at 3645' ctmd. Establish rates of 1.5 bpm fluid and 750 scf/m N2 with 200-300 psi WHP. Clean out from TT(4852' MD) to 9034' ctmd in 300' bites. Lost N2 pump with nozzle at bottom and eventually lost returns temporarily until N2 was re-established. Pumped BU volume. POOH chasing returns. SD fluid pump at 5700'. Well freeze protected with N2. Secure well. RDMO.Job Complete. Final T/I/O = 130/0/240. 9/18/2017 - Monday No activity to report. 9/19/2017-Tuesday No activity to report. • • VALHilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-15 E-line 50-029-23073-00-00 202-054 8/28/17 10/5/17 Daily Operations: 10, „6,1,- 10/4/2017 w;<10/4/2017 -Wednesday Rigging up ASR Rig on 1-15, Spot cat walk, fill pill tank with 40 bbl.fresh water for testing, Received 200 bbl. sea water 2% KCL Hilcorp Electrician Rigged up and Calibrated Bump Test Fire and Gas Alarms in Pits, Rig Floor, Cellar, Rig Crew Connected Flow Line to Pits, Received 130 joints 2-7/8" 6.5# 1-80 EUE Completion Tubing &2-GLM'S, 1-XN-Nipple Well head Rep Greg Ruge,Tee bar BPV Observed Pressure on BPV Lined up Pumped 15 bbl. down Tubing,Tee Bar Removed BPV & Installed TWC Valve in Hanger profile (Accept Rig @ 1130 on 10-4-17) (PJSM) Rig up Test Equipment Shell test bop 250 psi low/2,500psi high 5 min each, Spot ESP Spooling Unit on Location, Hanger Esp. Sheave in Derrick Test bop as per sundry,Test with 2-7/8" and 3-1/2"Test Joints all Rams and Valves 250 low/2,500 high 5 min each,Test Annular with 2- 7/8" test joint 1-BOP and TIW Valves 250 low/2,500 high 5 Min Each, Record Accumulator Pre-Charge Pressures and Chart Test, (AOGCC Jeff Jones Waived Witness to Bop Test on 10-2-17 at 16:37pm) Well Head rep Tee Bar Removed TWC Valve Make up Landing Joint into Hanger, BOLDS, Pull Hanger to Rig Floor and Un seat at 40k Shear Retrievable Packer at 78k Fill Back side with 18 bbl. well bore filled up shut down on Pumps Well bore went on a Vacuum , Break and Lay down Landing Joint and Hanger TBG showing increasing pressure, climb up to 90psi, annulus presumably on a vacuum. Close pipe rams and bullhead 45bbls down the TBG, swap over to IA and pump 130bbls w/the TBG shut in. Allow pressure to bleed off,TBG and IA on a vacuum.Took 10bbls down the TBG to catch pressure. Order pallet of NaCI to mix KWF in pits. Roads and Pads bring out 130bbls of fresh water, mix in pits to get 8.5ppg fluid across all pits. POOH w/Halliburton retrievable PKR on 3.5" EUE kill string f/4,852'md to surface. Fill hole w/double metal displacement every 15jnts. 152 total joints recovered, 1 X nipple, 1 (4') pup joint, and 10' WLEG (cut joint) R/U to calibrate power swivel TQ w/load cell and a rig tong as a back up, snubbed off to rig floor. Pull test load cell w/lifting eye to ensure no out of sort floor movement. (good test), P/U baker fishing rig tong and a joint of 3.5" NC-31 work string. M/U work sting to power swivel, latch up back up tong w/load cell attached to snub line, work TQ into pipe and compare Prostar digital readout to load cell. Good Test. 10/5/2017-Thursday Service Rig Check Fluids and Grease Continue Calibrate power swivel TQ w/load cell and a rig tong as a back up, snubbed off to rig floor.TQ into pipe and compare Prostar digital readout to load cell.Torque was good (ASR Swivel Test Failed) Capability of over all Total Control(Failed) Pro star was Contacted Plan Forward in Progress Safety Meeting with Rig Crew Recap well Control, and Drills (Conducted Table Top Fire Drill Personal in Position) Pump 20 bbl. 8.6 ppg 2% KCL Down IA Confirm well is Dead, Open Blind Rams, P/U & M/U and Serviced ESP Completion Pump Assembly RIH w/2-7/8" 6.5# L-80 EUE Tubing and ESP Completion Pump Assembly&Control Line f/Surface to 3,200' R/U Pump and Fill Tubing with KWF, Pump and Flush ESP Assembly at Every 1,000' while Checking Cable, LRS Well Kill Ops on 1-19 Continue to RIH w/ ESP completion on 2-7/8" 6.5ppf, L-80 EUE completion pipe f/3200'md to 3840'md as per tally. P/U = 27klbs, S/O = 20klbs. R/U to P/U hanger and perform ESP penetrator splice. SIMOPS: N/D tree on 1-19. Wellhead hand Greg Ruge on location to bleed void on tree. P/U and M/U 2-7/8" x 11" FMC TBG hanger as per wellhead hand Greg Ruge. Run 3/8" control line through TBG hanger. Baker Centrilift rep splice ESP cable into penetrator and set inside TBG hanger. SIMOPS: Wellhead hand Greg Ruge inspect 1-19 TBG hanger threads and function LDS. RIH w/TBG hanger, utilizing 5' stick to verify TBG hanger seats on depth in TBG spool. (On depth, 16.65'floor to LDS). RILDS and set 2-7/8" H type BPV. SIMOPS: N/U 11" BOPE on 1-19. (Release Rig @ 22:30 10/05/17) Begin R/D process on 1-15. Blow down all fluid lines, R/D pipe racks, change out pipe handling equipment in prep for 1-19. Situate rig floor into moving position. ID • yo, r� y .-v,1 yy„�4., THE STATE Alaska Oil and Gas ��, , ALASKA Conservation Commission5 }#2 '� 333 West Seventh Avenue l. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager w, r, Hilcorp Alaska, LLC � �”` �' 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool,MPU I-15 Permit to Drill Number: 202-152 Sundry Number: 317-207 Dear Mr. York: Enclosed is the approved application for 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, 6 '41 Cathy . Foerster Chair DATED this ? day of May,2017. RBDMS lam KAY 3 0 2017 • 10 RECEIVED STATE OF ALASKA MAY 2 2 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALSAOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:CT FCO&ESP Swap Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: N, ey,.., Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 202-152 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 1:1Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23106-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 11 MILNE PT UNIT 1-15 • 9.Property Designation(Lease Number): 10.Field/Pool(s): / / r ADL0025906 ' Al t Arc. 20,44- JCJtd4c �.tr 21t�,tl-i ail 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,050' ' 4,106' • 9,050' ' 4,106' • 982 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 3,085' 9-5/8" 3,085' 2,761' 5,730psi 3,090psi Production 4,849' 7" 4,849' 3,968' 7,240psi 5,410psi Slotted Liner'OA' 4,053' 4-1/2" 8,922' 4,042' N/A N/A Slotted Liner'OB' 3,841' 4-1/2" 9,041' 4,106' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,198' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top and N/A . 5,102'MD/4,026'TVD and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development E s Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/9/2017 Commencing Operations: OIL 0. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Stan Porhola 3119 Authorized Title: Operations Manager Contact Email: sporhola ct7r hilcorp.com Contact Phone: 777-8412 Authorized Signature. Date: 5/19/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: A t(L 3 k " 2-0 l' Plug Integrity ❑ BOP Test m Mechanical Integrity Test ❑ Location Clearance ❑ Other: 7f.2. c'G pz 1. c-) r - Post Initial Injection MIT Req'd? Yes ❑ No 14‘.1 Spacing Exception Required? Yes El No Subsequent Form Required: l 0 '19Oil RBDMS w 3 0 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S'-2.3—/7 '-r 5I f/i- lr 3 G pl N Submit Form and Form 10-403 Revised 4/2017 r I slid for 12 months from the date of approval. Attachmentss in Duplicate • i Well Prognosis Well: MPU 1-15 IIikerp Alaska,LLI Date:5/19/2017 Well Name: MPU 1-15 API Number: 50-029-23106-00 Current Status: Oil Well [Failed ESP] Pad: I-Pad Estimated Start Date: June 9th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-152 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) D uni tO836 j '1 Job Type: ESR Repair Current Bottom Hole Pressure: 1,382 psi @ 4,000' TVD (SBHPS 5/15/27-/6.65 ppg EMW Maximum Expected BHP: 1,382 psi @ 4,000' TVD (No new perfs being added) MPSP: 982 psi (0.1 psi/ft gas gradient) Brief Well Summary: The Milne Point 1-15 well was drilled as a Schrader Bluff development multi-lateral well that TD'd ran 4- 1/2" slotted liners in OB at a depth of 9,050' and in OA at 9,000' in September 2002. The well was initially completed with an ESP. This and subsequent ESPs failed and were replaced in 2008 and 2014. The pump failed in February 2015 and was replaced using the Nordic#3 rig in March 2015.The 7" casing was tested to 1,500 psi down to 4,774'.The ESP plugged off in February 2017.A coil tubing cleanout of the tubing was unsuccessful. No scaling or subsidence issues are expected in this well. Notes Regarding Wellbore Condition • • Casing last tested to 1 50Qpsi_for 30 min 'Amato 4,774' on 3/26/2015. • Max angle 72.0° @ 4,840' in the 7" casing. Max angle 93.0 @ 8,444' in the laterals. • Deviation at ESP is 48.0° and dogleg of 5°/100 ft. • Min ID is 2.25" thru XN profile above ESP. •)c—'t° • Last Fill Depth: 5,670' MD N2 cleanout on 3/27/2015. r` t" • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. ; oe'L' c.,0 39 u A (6.,t. pio b-J Objective: The purpose of this work is to pull the failed ESP, run a kill string, rig down the ASR rig, RU coil and cleanout the lateral, rig up the ASR rig, pull the kill string and run a new ESP. / Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing,taking returns up KtoL, casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. • Well Prognosis Well: MPU 1-15 IIilcorp Alaska,LL) Date:5/15/2017 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV pro i` `ts odd and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP swap wad'66K lbs (,block weight of 36k) b. If needed,circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used based on tubing visual inspection of the connections. Lay down failed ESP. a. Replace bad joints of tubing as necessary and note on tally any new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. • • Well Prognosis Well: MPU 1-15 IIilcora Alaska,LL) Date:5/15/2017 18. RIH with 7" 26#scraper assembly to "'4,840' MD (top of hook wall hanger) on 2-7/8" workstring. Circulate the well clean with 8.5 ppg seawater. 19. POOH and LD 2-7/8" workstring and scraper assembly. " 20. PU seal assembly and RIH on 4-1/2"tubing. Set seals below top of hook wall hanger at±4,850' �tL`� MD. k,_a Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 22. Set BPV. Rig down ASR. Post-Rig Procedure: 23. RD mud boat. RD BOPE house. Move to next well location. 24. RU crane. ND BOPE. 25. NU new 4-1/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 26. RD crane. Move 500 bbl returns tank and rig mats to next well location. 27. Replace gauge(s) if removed. 28. Turn well over to production. RU well house and flowlines. Coiled Tubing Procedure: 29. MIRU Coiled Tubing Unit andspot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 30. Pressure test BOPE t�63,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. cc' 31. RIH w/2.00" coil w/2.5" to 3.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/-9,040' MD. POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/3.0"to 3.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-9,040' MD using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 32. PU to 2,500' and freeze protect well. POOH w/coil. 33. RD Coiled Tubing and ancillary equipment. 34. Turn well over to production. Pre-Rig Procedure: 35. Clear and level pad area in front of well. Spot rig mats and containment. 36. RD well house and flowlines. Clear and level area around well. 37. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 38. Pressure test lines to 3,000 psi. n • • Well Prognosis Well: MPU 1-15 Hilcorp Alaska,LLI Date:5/15/2017 39. Circulate at least one wellbore volume with 8.5 ppg seawater down tubing, taking returns up casing to 500 bbl returns tank. 40. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 41. RD Little Red Services and reverse out skid. 42. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 43. NU BOPE house. Spot mud boat. Brief RWO Procedure: - f,et i<: (( Sfr,J //e/(7 --/ /oft, E /' 44. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 45. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 46. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. fj/ a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. j a Ic. c. Confirm test pressures per the Sundry Conditions of approval. 9r-`1 d. Test VBR ram on 2-7/8" and 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 47. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 48. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 49. MU landing joint or spear and PU on the tubing hanger. a. The PU weight is estimated to be 60k. 50. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. ""51. P0jO_H dd mown the _1/2 " tubing. 52. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±3,800' MD. • • Well Prognosis Well: MPU 1-15 Ililcuru Alaska,LL Date:5/15/2017 a. Upper GLM @ ± 140' MD w/SO b. Lower GLM @ ±3,680' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±3,740' MD d. Base of ESP centralizer @ ±3,800' MD 53. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 54. Set BPV. Rig down ASR. Post-Rig Procedure: 55. RD mud boat. RD BOPE house. Move to next well location. 56. RU crane. ND BOPE. 57. NU previous 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 58. RD crane. Move 500 bbl returns tank and rig mats to next well location. 59. Replace gauge(s) if removed. 60. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Temporary Tree/Wellhead 6. Blank RWO MOC Form 7. Coil BOPE Schematic 8. Nitrogen Operations Procedure 9. Nitrogen &Foam Flow Diagram , 14 0 • Milne Point Unit Well: MPI-15 SCHEMATIC Last Completed: 3/29/2015 lliilcorp Alaska,LLC PTD: 202-152 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig KB Elev.:62.5'/Orig GL Elev.:35.0' 20" Conductor 92/H-40/Welded 19.124 Surface 112' RIQ Elev.=10 0' orclic#3L 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' f n 7" Production 26/L-80/BTC-Mod 6.276 Surface 5,204' 20 a* 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner 08 12.6/L-80/IBT 3.958 5,200' 9,041' 1 TUBING DETAIL 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2..441 Surface 4,218' JEWELRY DETAIL No Depth Item 1 161' Sta#2:2-7/8"GLM 35/8" .a 2 3,986' Sta#1:2-7/8"GLM 3 4,160' 2-7/8"XN Nipple 2.25"Min ID 4 4,171' Discharge Head: FPHVDIS 5 4,171' Upper Tandem Pump: 68P6 PMSXD 6 4,180' Lower Tandem Pump:18P75 PMSXD 7 4,187' Gas Separator:GRSFTXARH6 8 4,192' Upper-Tandem Seal Section:GSB3DBUT SB/SB PFSA 9 4,199' Lowerer-Tandem Seal Section:GSB3DBUT SB/SB PFSA 10 4,205' Motor: MSP1-325,60hp/1,240V/29A 11 4,214' Pumpmate w/6 fin Centralizer-Bottom @ 4,218' 12 4,840' Baker Hook Wall Hanger inside 7"Window(21') 13 4,861' Baker Hook Wall Hanger outside Window(3') 2 14 4,864' Baker Down Swivel-up Lock sub _ 15 5,095' Baker Tie Back Sleeve 16 5,102' Baker ZXP Liner Top Packer - 1 17 5,108' Baker 7"x 5"HMC Liner Hanger 18 5,120' 7"Halliburton Float Collar 19 5,203' 7"Halliburton Float Shoe 3 LATERAL WINDOW DETAIL Top of"OA"Window @ 4,849'-4,861';Well Angle @ Window is 72deg WELL INCLINATION DETAIL II 5&6 KO P @ 470' Max Hole Angle=47 deg @ 4,120'MD 1:11:1: 7 6odeg,+Past 4,500'MD. t i -8&9 Hole Angle through Perf s=86 deg+ � ` OPEN HOLE/CEMENT DETAIL I10 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole 7" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole 11 WELLHEAD Tree 2-9/16"-5M FMC Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with CIW"H"BPV Profile GENERAL WELL INFO API:50-029-23106-00-00 . ' 12 Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 ,,r13 14 „04 Latera 6-1/8"Hole TD @ 9,000' ESP RWO by Nabors 4E5-8/21/2008 ESP Change-out by Doyon 16-5/7/2014 ESP Change-out by Nordic 3-3/29/2015 15 16, 17 4 ..„..... 18&19 ..o6"Udall 6-1/8"Hole TD @ 9,050' 4,41 TD=9,050'(MD)/TD=4,106'(TVD) PBTD=9,050'(MD)/PBTD=4,106'(TVD) Created By:STP 2/07/2017 • • Milne Point Unit 14Well: MPI-15 PROPOSED SCHEMATIC Last Completed: Proposed IIilcarp Alaska.LLC PTD: 202-152 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig KB Elev.:62.5'/Orig GL Elev.:35.0' 20" Conductor 92/H-40/Welded 19.124 Surface 112' RKB Elegy,20 0' ordic#3 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' A 7" Production 26/L-80/BTC-Mod 6.276 Surface 5,204' 20'` if r. 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner OB 12.6/L-80/IBT 3.958 5,200' 9,041' LI 1 L 4. TUBING DETAIL 0 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2..441 Surface ±3,800' cw i. s°` JEWELRY DETAIL 1 No Depth Item 1 ±140' Sta#2:2-7/8"GLM 2 ±3,680' Sta#1:2-7/8"GLM 9-5/8 ea at _ 3 ±3,740' 2-7/8"XN Nipple 2.25"Min ID t 4 ±3,752' Discharge Head: FPHVDIS 5 ±3,753' Upper Tandem Pump: 68P6 PMSXD 6 ±3,762' Lower Tandem Pump:18P75 PMSXD 7 ±3,769' Gas Separator:GRSFTXARH6 t 8 ±3,774' Upper-Tandem Seal Section:GSB3DBUT SB/SB PFSA 9 ±3,781' Lower-Tandem Seal Section:GSB3DBUT SB/SB PFSA 10 ±3,787' Motor: MSP1-325,60hp/1,240V/29A ', 11 ±3,796' Pumpmate w/6 fin Centralizer-Bottom @±3,800' i ( 12 4,840' Baker Hook Wall Hanger inside 7"Window(21') 13 4,861' Baker Hook Wall Hanger outside Window(3') 2 14 4,864' Baker Down Swivel-up Lock sub 15 5,095' Baker Tie Back Sleeve 0 16 5,102' Baker ZXP Liner Top Packer 17 5,108' Baker 7"x 5"HMC Liner Hanger 18 5,120' 7"Halliburton Float Collar u 19 5,203' 7"Halliburton Float Shoe 3 LATERAL WINDOW DETAIL 4 Top of"OA"Window @ 4,849'-4,861';Well Angle @ Window is 72deg re WELL INCLINATION DETAIL 5&6 KOP @ 470' Max Hole Angle=47 deg @ 4,120'MD IIII ,<7 6odeg,+Past 4,500'MD. 8&9 Hole Angle through Lateral=86 deg+ OPEN HOLE/CEMENT DETAIL 1 '' 10 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole a" ;1' 7" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole 11 9p 'a WELLHEAD Tree 2-9/16"-5M FMC Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with 4* ' CIW"H"BPV Profile p ,;, R, GENERAL WELL INFO kk API:50-029-23106-00-00 ",4r:12 Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 y '-13 ESP RWO by Nabors 4E5_ca 8/21/2008 Latera14 ' ESP Change-out by Doyon 16-5/7/2014 u0A�L`. ESP Change-out by Nordic 3-3/29/2015 6-1/8"Hole TD @ 9,000' 1 C 15 6 17 18&19 `CVS* 6-1/8"Hole TD @ 9,050' No TD=9,050'(MD)/TD=4,106'(TVD) PBTD=9,050'(MD)/PBTD=4,106'(TVD) Created By:STP 5/15/2017 • • . tit Milne Point ASR Rig 1 BOPE 11" BOPE Stripping Head 3.98' El ,Shaffer-' 11"- 50001 r 111 lit 161 lil l l iiiiiiia 1111 i!1 Ill iii III IiI 1' \ I CIA -U tali 4.54' - VBR or Pipe Rams �,w 11"-5000 "�� Blind III I- [811 1 i1 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves i e0"Itiii1 ii FF 2.00 ! ® , e ! Mau Mal Manual Manual HCR Updated 8/19/2015 . I/ i • MPU I-is EXISTING TREE/WELLHEAD Wellhead/Tree Hilcairp Alaska,LLG Milne Point Unit 11 Tree Cap is, IMIt 'lam:.1 lifr'' ''41:k Tree Valve 2-9/16" 5M 000 IU lil Tree Cross 2-9/16" 5M tit"' 3 Tree Valve 2-9/16" 5M in lilt SSV 2-9/16" 5M ,� y VP NNE is Tree Valve 2-9/16" 5M :. \ 7 Cr tatmoo it, ESP Cable 'i' "' MI Tubing Adapter i i p' Tubing Head I l— ll 11" 5M Top x11" 5MBtm t . 9 1 i Jell , (11 ;'- D 1. tit til t t;:'.Zjdl l�;lli�lll._ Casing Head l ilk 11 ' 5MTopx11" 5MBtm "'°'' ` #[.04., 4, 111 .ism,� ► i itrw, s . 11 TEMPORARY TREE/WELLHEAD MPU I-15 Wellhead/Tree Alaska,LLC!HiccupMilne Point Unit !Hiccup I Tree Cap aimm ik III`pill..I Tree Valve 4-1/16" 5M (;)(° 0 c) Tree Cross 4-1/16" 5M 11 oro0 Tree Valve 4-1/16" 5M 0 lit a to Tree Valve 4-1/16" 5M iel1 a7 Oho lc') p Tree Valve 4-1/16" 5M R.6i " ' 1111 I. 1J0Tubing Adapter Tubing Head ia, ICI 11" 5M Top x 11" 5M Btm til- RN : 41 1111:1' it I i11" •u — Illi i ii Casing Head .,®l I-Mt iw. 11" 5M Top x11" 5M Btm illir : mow*:Z.,.00 N.i. .. ti :-.1-1")) ;-"'f' . -tto t 5t r` `� C 14_,,, LI ' '''"e144 1-1) Lt 35-.(-) J a) k 0 \ > � � CO 2 / 0 ° _ > o U R / � § / � �a E / q = m % 2 = E Y > J 2 m « 2 2 / p = 0. \ \ « m = 2 0 � u) dk 22 CL ee D. c.,- § 2 < 03 ■ a) 2 \ k k % % CO / - i 0 / 5 0 / , O a0 2 2c ■ m $f ) - R0 70 a) \ / 0 = 0 J % 9 73 S w 0 E § 2 _ O k / 'k o a = / a) k \ / 0) § cc a /cEn� 7 Gp 2 I / \ 7.0 CD �§ co c g 04 0 \a k « m § ° O ECO O _m ° I- =I ° 2 2 \ / & a) / 6 fal 0ii a. w cc 0 / cc 0 « c ' ' kE / U E§ §% co /U k $ /\ < / 0 • 0 • • . li Milne Point Unit COIL BOPE MPU I-15 i ti oom 4.646..1.JA 5/15/2017 MPU I-15 20 x 9% x7x4% Coil Tubing BOP To injection head 1; I 2.00"Double Stripper )1 r Lubricator 5 < MI z 1•',1 Blind =41/1615 ......ii 73 Blind ,I■'1 11) IIitShear :Ire If I,I.I. Slip Slip •I '•\ MN ./ on= Illila 0111111 Pipe � , Pipe L'. Crossover spool 4 1/16 15M X4 1/16 10M 11 mz,Y Crossover spool S SU 4 1/16 10M X 4 1/16 5M n o Pump In Sub §` Y6 `i i'® i .,: Ai - • 1, 41/16 5M r�' 6 ; ; �� M 1502 Union i ono a itili Manual Gate Manual Gate 2 1/8 5M 2 1 8 5M Valve,Swab,WKM-M, / 41/165M FE "1-4,7°;;V � ��O� �>' ''06S \e ,,\ / - '4...., — Ja p,1 i gi`aCr g'i \ . Valve,Upper Master,Baker, , 0 4 1/16 5M FE,w/Hydraulic Valve,Lower Master,WKM-M, � o 4 1/16 5M FE 7----: -RSB Y 7 Tubing Adapter,4 1/16 5Mi MI of • I STANDARD WELL PROCEDURE 1lileorpAlaska,i.u: NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • 0 o« -t x 0 > c U RY W O u Y W O u .. .. w > CO .a c, 03.4002 O 4O Y a . uxzzo r a a • C 0 3 D 7 u J w • Ll E a > > — C7 W o m m o ... • 0 }••.• czU O. > U o E.7. ° o O vva °' 0 S °�' a a Pn a.... z >..•' -a w > c7 oa U 4.- c.) ` UWU ,17,111161 •r r x H w z m m O ■ Y 0 s M1Ye• �.: U / ., AosoitHoim— . E C7 ® LL 1 _ O T O ~ 0 1,y i� mu um m 1 iii ,rc M I j�,':1M JI I ° I1. ;II I! = illi l� Iiia so - tip I n'm .a r a a 111 p !. C O O W Y d N Z LLI W F g LL O t O 0 0 0 m W WI 1_ � 0. a Cli.— a F- W• W Q\Q Q o z • o r F Y x m 2 m K O a co m m 0 0 a 21i. STATE OF ALASKA AL _KA OIL AND GAS CONSERVATION COML SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations H Perforate L] Other U ESP Change-out Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 202-152 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-23106-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB I-15L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT FIELD/SCHRADER BLUFF OIL POOL 11.Present Well Condition Summary: Total Depth measured 9,050 feet Plugs measured N/AY,11x E''' t 9/ Ck4true vertical 4,106 feet Junk measured N/A feet Effective Depth measured 9,050 feet Packer measured 5,102 feet true vertical 4,106 feet true vertical 4,026 feet I\�. G ' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 3,085' 9-5/8" 3,085' 2,761' 5,730psi 3,090psi Production 4,849' 7" 4,849' 3,968' 7,240psi 5,410psi Slotted Liner'OA' 4,053' 4-1/2" 8,922' 4,042' N/A N/A Slotted Liner'OB' 3,841' 4-1/2" 9,041' 4,106' N/A N/A r� u li D MAY 2 02.)1b Perforation depth Measured depth See Attached Schematic Srt.e► True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,198'MD 3,651'TVD 5,102'MD Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A 4,026'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 • Subsequent to operation: 150 5 161 240 203 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic LI Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-158 Contact Chris Kanyer Email ckanverahilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature -‘7.—.._:. --- wl Phone 907-777-8377 Date 5/5/2015 1 RBDM MAY - 6 2015 / 5=-7-is Form 10-404 Revised 10/2012 ,J/4� Submit Original Only Milne Point Unit , 14 Well: MPI-15 SCHEMATIC Last Completed: 5/7/2014 Hilcorp Alaska,LLC PTD: 202-152 CASING DETAIL Size Type Wt/Grade/Conn ' ID Top Btm RKB Eley=25.7 20" Conductor 92/H-40/Welded 19.124 Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' ..-.,ii ; 7" Production 26/L-80/BTC-Mod 6.276 Surface 4,849' }� E 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner OB 12.6/L-80/IBT 3.958 5,200' 9,041' 1 ; TUBING DETAIL 4 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2..441 Surface 4,198' JEWELRY DETAIL 1 No Depth Item .), i 1 141 GLM '" ` 2 3,966' GLM 9-5/8 ``' 4. 3 4,140' XN Nipple 4 4,151' Discharge Head 5 4,151' Upper Tandem Pump 6 4,160' Lower TandemPump 7 4,167' Gas Separator 8 4,172' Upper-Tandem Seal Section 9 4,179' Lowerer-Tandem Seal Section 10 4,185' Motor , 11 4,194' Pumpmate w/6 fin Centralizer-Bottom @ 4,198' 12 4,840' Baker Hook Wall Hanger inside 7"Window(21') IN13 4,861' Baker Hook Wall Hanger outside Window(3') 2 14 4,864' Baker Down Swivel-up Lock sub 15 5,095' Baker Tie Back Sleeve 16 5,102' Baker ZXP Liner Top Packer 17 5,108' Baker 7"x 5"HMC Liner Hanger 18 5,120' 7"Halliburton Float Collar 19 5,203' 7"Halliburton Float Shoe /I3 LATERAL WINDOW DETAIL IIli1 a Top of"OA"Window @ 4,849'-4,861';Well Angle @ Window is 72deg WELL INCLINATION DETAIL I 5&6 KOP@470' Max Hole Angle=47 deg @ 4,120'MD _,I.I_ 7 60deg,+Past 4,500'MD. I .f;8&9 Hole Angle through Perf s=86 deg+ OPEN HOLE/CEMENT DETAIL 10 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole - '' 7" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole 1 11 '; WELLHEAD • Tree 2-9/16"-5M FMC Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with s v CIW"H"BPV Profile i GENERAL WELL INFO ' API:50-029-23106-00-00 12 Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 13 ESP RWO by Nabors 4ES-8/21/2008 s17 " 14 ESP Change-out by Doyon 16-5/7/2014 y, _I "04°Lateral 6-1/8"Hole TD @ 9,000 ESP Change-out by Nordic 3-3/29/2015 15 16; . 17 7 18&19 "OB"Laeral 6-1/8"Hole TD @ 9,050' 111111 TD=9,050'(MD)/TD=4,106(TVD) PBTD=9,050'(MD)/PBTD=4,106'(TVD) Created By:TDF 5/4/2015 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPI-15 50-029-23106-00-00 202-152 3/24/2015 3/29/2015 Daily Operations: 3/18/15-Wednesday No operations to report. 3/19/15-Thursday No operations to report. 3/20/15-Friday No operations to report. 3/21/15-Saturday No operations to report. 3/22/15-Sunday No operations to report. 3/23/15-Monday No operations to report. 3/24/15-Tuesday BOP test waived by AOGCC/Grimaldi. BOP swap from 13-5/8"to 11". Begin rig move, rig off location 10PM, move to 1-15. MIRU accept rig. Berm cellar, spot tanks, run hardline, pull BPV. PT all lines 250psi low/2,500psi high. SITP 270 osi,SICP, 570 psi. Blow down well, line up to kill well and pump 37 bbls 140°8.5ppg seawater down tubing, no returns.Swap over down csg after 23 bbls quick pressure increase and break over. Intermittent gas/oil returns on tbg.Continue and pump to liner top volume+total pumped 244 bbl swap over and pump tubing volume 24 bbls. 119 bbls recovered oil water mix. Monitor well is on vacuum both sides install BPV. Blow down Break all lines.ND Tree, prepare to NU BOPE. Hilcorp Alaska, LLC t,i,,.,,r,, ,,,,,k:,.,,,,,: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPI-15 50-029-23106-00-00 202-152 3/24/2015 3/29/2015 Daily Operations: 3/25/15-Wednesday PJSM. ND tree,inspect hanger and graphite grease surfaces,grooves and recesses. NU BOPE,install TWC. Fill stack, purge lines,shell test BOPE,fix leaks from new NU. BOPE test 250psi low/3,00025i high.Annular 250psi low/2,500psi___ high.All surface valves 250psi low/3,000psi high perform accumulator draw down test,all OK. Drain stack, remove and seal Bell nipple. Re-install and hydro test. Pull TWC,well still on vacuum. MU LND jt, PU 79 K,hanger free. Pull to floor check ESP cable,good. Remove penetrators LD hanger string ESP cable. POOH with completion. LD bad joints identified from caliper log.Continue to POOH. 3/26/15-Thursday -POOH to ESP and examine same. No scale,some pitting on motor body from laying on low side of hole.Assembly is sand packed and froze up. BOLD ESP assy. PU 7" RTTS 7'26#csg packer.RIH to 4,774'set packer. Fill hole w/28 bbls 8.5#SW,test and chart.Test to 1,500psi<30psi bleed off in 30 minute,good test. POOH BOLD packer. Packer in excellent condition.Clean up floor strap and drift. NU adapter spool 11"5M x 7-1/16" 5M on top of annular. Install BIW stripping head. PU 2-3/8" pup to set tong torque and function pressure test annular.Strap and caliper x-overs for 2- 7/8" production string.JSA on planned procedure to reach TOL and clean out same. PU run in hole with 2-3/8" PH-6 muleshoe and stinger assembly and stands from derrick of 2-7/8" L-80 production.Continue RIH very light<2K down through upper window @ 4,840'-5,095' PU 64K down 59k.PU single and RIH lower lateral @ 5,102'did not see liner top light tag and rolling minor junk @ 5,113'.Continue in hole to 5,135'.Secure well for BOP stack centering for stripping head clearance. 3/27/15-Friday Re-align stack @ 5,135'. RIH to 5,'140'tag hard.Set down 6K PU. Install 2-7/8"Stripping rubber and hook up to top drive.Wash to 5,135'through bridge,partial returns then total losses after bridge was removed.Wash down to 5,264'. Drag to 70K down 58K erratic.Wash down to 5,670'call engineer discuss N2 job. Pull 2 jts install dart valve reinstall 2 jts. RU N2 Equipment. Hold PJSM.Secure rig floor. P/T all lines to 2,000psi. SD N2,rig up to pump 35 bbl solvent flush and displace out EOT with 25 bbl 8.5#SW, ICP 1,050psi, FCP 500psi. 150 bbl recovered mostly oil no real visible solids. Allow pill to soak. Hold PJSM identify IA as open and recorded by rig crew. Pump 1,010 gals(106,000 SCF)average rate 1,500 SCFM @ 1,500psi. Pressure build to 1,700psi last 10-15 mintes after 100,000 away. Expect lifting fluid column pump additonal 6,000 SCF pressure not dropping.SD N2 pumping.Open annulus and bleed to kill tank.Circ.down tbg 72 bbls, ICP 1,450psi, FCP 60psi.Continue to bleed off annulus slugging fluid recover 98 bbls. Pump 43bbls down tubing, ICP 560psi, FCP 160psi.Annulus 0 psi.Observe well annulus flowing. Pump 200 bbl 8.5#SW down annulus.ICP 180psi, FCP 60psi.Pull/LD 2 jts tubing through stripper to dart and BO. Pump 20 bbl down tubing. Install tubing bleeder verify no pressure under dart,remove same and Install TIW.Annulus building to 40psi.Pump additional 100 bbl 8.5#SW down annulus. Full hole volume of 310 bbls has now been exceeded by160 bbls.SD observe well annulus and tbg pressure rising. Formation is still N2 charged.SI well to stabilize and observe pressure SICP 170 psi SITP 30 psi. 3/28/15-Saturday PJSM SITP 0-19psi SICP 170 and dropping. Open up tubing light blow then vacuum. Bled casing to 0 psi. Leave open. Monitor pressures while waiting for fluid,awaiting hot SW 8.5#to trip.Offload and pump 21 bbls down tbg and 164 bbls down down csg. Intermittent returns after 112 bbls. POOH slowly standing back 7 stands in derrick and LD 153 jts. ND stripping head and spool.NU riser LD excess pipe in derrick.Well appears stable. PU MU ESP assembly. • 3/29/15-Sunday PJSM. Resume building and servicing ESP assy. Install connector.Check Cable.RIH 2,100'with ESP and 2-7/8" 6.5#L-80 tubing.Check cable,OK,RIH with ESP 2,100'-4,198•PU hanger,install penetrator,make connector splice. Meg check same,OK.RIH land hanger,RI lockdown screws,test cable.Remove landing joint install BPV, ND BOP, NU tree. P/T tree 250psi low/5,000psi.Centralizer 4,198', motor 4,186',Tandem seals 4,171',gas sep 4167',pumps 4,152',discharge head 4,151', PJ,XN nipple 4,139',5 jts tbg, PJ,GLM 3,966', PJ,121 jts tbg,PJ,GLM 141',4 jts tbg, pup/hanger. Dress and clean tree and cellar back over well. Rig released @ 1800. 3/30/15-Monday No operations to report. 3/31/15-Tuesday No operations to report. F 4; Alaska Oil and Gas �/// .4'sTHE STATE ofALAConservation Commission S • t i = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF ^�"4 Mara• 907.279 1433 ALAS Fax: 907.276 7542 www.aogcc.alaska.gov Chris Kanyer Operations Engineer dOg - SD- Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB-15 Sundry Number: 315-158 Dear Mr. Kanyer: Enclosed is the approved application for 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, a)/1 Cathy P. F erster Chair DATED this'day of March, 2015 Encl. . RECEIVED STATE OF ALASKA MAR 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 3 /2%inS APPLICATION FOR SUNDRY APPROVALS lOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑✓ • Change Approved Program 0 Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing Q . Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing 0 Other: ESP Changeout D- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development E. 202-152 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23106-00-00 7.If perforating: 8.Well Name and Number: ``�� What Regulation or Conservation Order governs well spacing in this pool? C.O. 477 - ?�J Will planned perforations require a spacing exception? Yes ❑ No E MILNE PT UNIT SB I-15 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 • MILNE POINT FIELD/SCHRADER BLUFF OIL POOL_ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9,050 • 4,106 - 9,050 - 4,106 % N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' 1,490psi 470psi Surface 3,085' 9-5/8" 3,085' 2,761' 5,730psi 3,090psi Production 4,849' 7" 4,849' 3,968' 7,240psi 5,410psi Slotted Liner'OA' 4,053' 4-1/2" 8,922' 4,042' Slotted Liner'OB' 3,841' 4-1/2" 9,041' 4,106' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic • See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,312 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): ZXP Liner Top Packer and N/A • 5,102'(MD)/4,026'(TVD)and N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development E , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/25/2015 Oil ❑s ' Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer(cilhilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 777-8377 Date 3/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: p 3/S -1 �O Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 14- JCCti /p', = ,(3o P i d Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /(, Li a / APPROVED BY Approved by: � RcietMt COMMISSIONER THE COMMISSION Date:3- ZS--/.5" f_.._ 3-1.3- ///'''�� A A Phi3� /r 0. 3��u41 _ iM /�— Submit Form and Form 10-403(Revis /2012) r I I a d for 12 months from the date of approve( Attachmen Duplicate /n�i3.�5 IS RBDM�\ APR - 3 2015 Well Prognosis • Well: MPI-15 Ililcorp Alaska,LL' Date: 3/20/2015 Well Name: MPI-15 API Number: 50-029-23106-00-00 Current Status: SI Producer Pad: I Pad Estimated Start Date: March 25, 2015 Rig: Nordic 3 Reg. Approval Req'd? March 24, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-152 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: — 1,249 psi @ 4,000' TVD (Last BHP measured 3/6/2015) Maximum Expected BHP: — 1,249 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 40% (0.374psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point 1-15 well was drilled as a Schrader Bluff development multi-lateral well that TD'd ran 4-1/2" slotted liners in OB at a depth of 9,050' and in OA at 9,000' in September 2002. The well was initially completed with an ESP.This and subsequent ESPs failed and were replaced in 2008 and 2014.The recent pump failed in February 2015. Thereds no recent casing pressure test performed and one will be completed during this workover. Due to observed scale issues, a downhole chemical injection line will be run as part of the new completion. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP & run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to250psi low/3L000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure Well Prognosis Well: MPI-15 °'ic""'Alaska,LL Date:3/20/2015 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger,MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 4,312' to surface and lay down same. 6. RIH with tapered cleanout BHA, wash bridges/fill if necessary in OB lateral to+/-9,000'. Contingency: (if unable to gain circulation or solids to surface) a. Circulate well with nitrified fluid, with surfactant and gel sweeps to clear lateral of solids. 7. POOH with tapered cleanout BHA. 8. RIH and set test packer at+/-4,700' (Note: above dual laterals,to test of 7"casing only). 9. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure and POOH with same. 10. MU and RIH with ESP with gas separator and 3/8"chemical injection line on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-4,200'. Land tubing hanger. 11. ND BOP, NU and tree. 12. RDMO workover rig and equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit , Il Well: MPI-15 SCHEMATIC Last Completed: 5/7/2014 Mewl)Alaska,LLC PTD: 202-152 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm RKB Elev=25.7 20" Conductor 92/H-40/Welded 19.124 Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' -� ki. 7" Production 26/L-80/BTC-Mod 6.276 Surface 4,849' le �- 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner OB 12.6/L-80/IBT 3.958 5,200' 9,041' `1 1 I TUBING DETAIL a 2-7/8" Tubing 6.5#/L-80/EUE 8rd 2..441 Surface 4,312' " JEWELRY DETAIL 1 No Depth Item 'b io 1 139' GLM-Camco 2-7/8'x 1"Sidepocket KBMM ' ":42 4,074' GLM-Camco 2-7/8'x 1"Sidepocket KBMM 9-5/g y w 3 4,226' HES 2-7/8"XN Nipple, 2.250 ID 4 4,269' Pump PMSXD/98P8 Armor X 5 4,281' Tandem Gas Separator-GSTHVER M FER 6 4,286' Tandem Seal Section-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA 7 4,300' Motor-84hp,2,210 Volt,23 Amp,Model MSP1/84 8 4,308' Pumpmate w/6 fin Centralizer-Bottom @ 4,312' 9 4,840' Baker Hook Wall Hanger inside 7"Window(21') 10 4,861' Baker Hook Wall Hanger outside Window(3') 11 4,864' Baker Down Swivel-up Lock sub 12 5,095' Baker Tie Back Sleeve 13 5,102' Baker ZXP Liner Top Packer 2 14 5,108' Baker 7"x 5"HMC Liner Hanger 15 5,120' 7"Halliburton Float Collar 16 5,203' 7"Halliburton Float Shoe LATERAL WINDOW DETAIL Top of"OA"Window @ 4,849'- 4,861';Well Angle @ Window is 72deg WELL INCLINATION DETAIL I 13 KOP@470' Max Hole Angle=47 deg @ 4,120'MD 60deg,+Past 4,500'MD. 4 Hole Angle through Perf s=86 deg+ OPEN HOLE/CEMENT DETAIL . 5 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 6Alltit 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole milt7" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole SE ' WELLHEAD s I 517 Tree 2-9/16"-5M FMC x" WE " Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with 8 ,, CIW"H"BPV Profile 1 GENERAL WELL INFO ', API:50-029-23106-00-00 Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 Z 4' ESP RWO by Nabors 4ES-8/21/2008 ESP Changeout by Doyon 16-5/7/2014 to y r .10 y-" # 11 a..,•1 "DA L.a<eral 6-1/8"Hole TD @ 9,000' 12 �)4M4 13 14 7' 15&16 "OB"L.Seral 6-1/8"Hole TD @ 9,050' qiii TD=9,050'(MD)/TD=4,106'(1VD) PBTD=9,050'(MD)/PBTD=4,106'(1VD) Created By:TDF 3/10/2015 Milne Point Unit Well: MPI-15 • '14 PROPOSED Last Completed: 5/7/2014 Ililcorp Alaska,LLC PTD: 202-152 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm RKB Elev=25.7 20" Conductor 92/H-40/Welded 19.124 Surface 112' 9-5/8" Surface 40/L-80/Btc. 8.835 Surface 3,085' 0 k 7" Production 26/L-80/BTC-Mod 6.276 Surface 4,849 ` 4-1/2" Sltd Liner OA 12.6/L-80/IBT 3.958 4,869' 8,922' 4-1/2" Sltd Liner OB 12.6/L-80/IBT 3.958 5,200' 9,041' • 1 TUBING DETAIL 2-7/8" Tubing 6.511/L-80/EUE 8rd 2..441 Surface ±4,200' r. JEWELRY DETAIL No Depth Item 1 ±139' GLM '0 2 ±3,974' GLM 9-5/8" 'a 6" 3 ±4,146' XN Nipple 4 ±4,158' Pump _ 5 ±4,165' Gas Separator 6 ±4,166' Tandem Seal Section 7 ±4,180' Motor 8 ±4,194' Pumpmate w/6 fin Centralizer-Bottom @±4,200' 9 4,840' Baker Hook Wall Hanger inside 7"Window(21') 10 4,861' Baker Hook Wall Hanger outside Window(3') 11 4,864' Baker Down Swivel-up Lock sub 12 5,095' Baker Tie Back Sleeve 13 5,102' Baker ZXP Liner Top Packer 2 14 5,108' Baker 7"x 5"HMC Liner Hanger 15 5,120' 7"Halliburton Float Collar 16 5,203' 7"Halliburton Float Shoe ' LATERAL WINDOW DETAIL Top of"OA"Window @ 4,849'-4,861';Well Angle @ Window is 72deg }} WELL INCLINATION DETAIL 1 3 KOP@470' Max Hole Angle=47 deg @ 4,120'MD 1 17._ 1 60deg,+Past 4,500'MD. Hole Angle through Perf s=86 deg+ 4 OPEN HOLE/CEMENT DETAIL 11:11: 5 20" Cmt w/260 sx of Arcticset(Approx.)I in 42"Hole 6 9-5/8" Cmt w/919 sx Clas"L",225 sx Class"G"in 12-1/4"Hole 7" Cmt w/84 sx AS Lite,189 sx Class"G"in 8-1/2"Hole WELLHEAD 7 Tree 2-9/16"-5M FMC Wellhead 11"5M Gen w/2-7/8"EUE T&B Tubing Hanger with 8 . CIW"H"BPV Profile GENERAL WELL INFO t API:50-029-23106-00-00 Drilled and Cased Multi-Lat by Doyon 141 -9/1/2002 �• ' ESP RWO by Nabors 4ES-8/21/2008 ESP Changeout by Doyon 16-5/7/2014 t 6.4011 ri( #i ' ' "Q4 Lateral 6-1/8"Hole TD @ 9,000' 13, 12 14 7' 15&16 Al "OB"Weal 6-1/8"Hole TD @ 9,050' No TD=9,050'(ND)/TD=4,106'(TVD) PBTD=9,050'(ND)/PBTD=4,106'(1VD) Created By:TDF 3/10/2015 11" BOP Stack I ‘ O O Ill ilii 11111111, Hydril 11" SM Shaffer I' 2 7/8-5.5 J variables C°0 [-\— * 11" 5M = Blinds _71 \__ * __/ J. t--(cy.) . ,FIVEt @I i - ek J v.41g1 3 NOR " ' Q ,p1 , • 11"5M ) ') Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ D.;¿ - ¡ Ò ~ Well History File Identifier Page Count from Scanned File: ¿¿ 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YE,S , NO Helen~ Date:J/ oLf ò!f 151 rnp If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 1111111111111111111 RESCAN DI<rAL DATA \Ç/Õi, skettes No. Lf 0 Other, No/Type: 0 Color Items: 0 Greyscale Items: 0 Poor Quality Originals: [] Other: NOTES: BY: Helen(:M_aria ') Project Proofing BY: Helen~ Scanning Preparation BY: Helen (Maria) . d- hD x 30 = Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: + 0 Other:: 1 Date ló ~ Dlf 151 mP 1111111111111111111 Date t~#¡}'r 151 w¡fJ ,;;z(, = TOTAL PAGES 9: 0 ~a~~J Õ.fno~uQ co~~r ttlP ~ 1111111111111\ 11111 YES NO Date: /s/ I11I1II1I11111111 \ I 1111111111111111111 Date: /s/ Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. -� Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 WOWED FEB 7 ZO Z December 30, 2011 Mr. Tom Maunder iM Pt t, - Alaska OiI and Gas Conservation Commission y ' r 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -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, Q� O Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI -03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI -04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 "--$ MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION j ~ ~' Q ~ 20~~ REPORT OF SUNDRY WELL OPERATION~p~~~a ~~s ~ ~~~ ~~~~ vai11~::~si~r 1. Operations Performed: ~` '"" '~ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. W lass Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. [~ elopment ^ Exploratory 202-152 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23106-00-00' 7. KB Elevation (ft): 62 5'- 9. Well Name and Number: MPI-15 8. Property Designation: 10. Field /Pool(s): ADL 025906 - Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9050 ~ feet true vertical 4106 ~ feet Plugs (measured) None Effective depth: measured 9050 ' feet Junk (measured) None true vertical 4106 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 112' 112' 1490 470 Surface 3057' 9-5/8" 3085' 2761' 6870 4760 Intermediate Production 5179' 7" 5204' 4037' 7240 5410 Liner 3947' 4-1/2" 5095' - 9042' 4026' - 4106' 8430 7500 ,..}.r~ .:co~~LG17~~. d`~!± Ef ~ ~ . r .M ~ Perforation Depth MD (ft): Slotted Liner 5200' - 9041' Perforation Depth TVD (ft): Slotted Liner 4037' - 4106' 2-7/8", 6.5# L-80 4319' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 420 Subsequent to operation: 115 6 251 310 302 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 f~/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number. Si nature ~ Phone 564-4750 Da e~ {~ ondra Stewman 564-4750 Form 10-~'4T2evised 04/~ ~ ~ I ~ ~ )~ ~ ~ < ~~ Submit (Ori~gJinal Only Tree: 2-9/16" - 5M FMC Wellhead: 11" 5M Gen 5 w/ EUE T&B Tubing Hanger with CIW "H" BPV profile 20", 92 #/ft H-40 Welded 112' 9 5/8", 40#/ft BTC L-80 3085' 2 7l8" 6.5 ppf, L-80, 8rd, EUE production tubing ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btc-mod production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) KOP @ 470 ' Max well bore Angle: 47° C~3 4120' MD 60°+ past 4500' MD Hole angle trough perfs = 86°+ Window in 7" Casing @ 4849' - 4861' Well Angle @ window = 72° Baker Tie Back Sleeve 5095` Baker ZXP Liner Top Packer 5102' Baker 7" x 5" HMC Liner Hanger 5108` 7" Halliburton Float Collar 5120` 7" Halliburton Float Shoe 5203' 6 1/8" Hole td @ 9050' OB Lateral 96 jts - 4 1/2", 12.6#/ft. Slotted Liner 12.6# L-80 IBT (5200'-9041') 9042' DATE REV. BY COMMENTS 9/01/02 Lee Hulme Multi-lat and complete Doyon 141 8/21/08 MOM 4-ES ESP RWO MILNE POINT UNIT WELL I-15 API NO: 50-029-23106 API NO: 50-029-23106-60 BP EXPLORATION (AKA M P I ' 15~, `, I Or~L eelev.= 28 50' =;rd Camco 2-7/8" x 1" sidepocket 167' KBMM GLM Camco 2-7/8" x 1" sidepocket 4071' KBMM GLM HES 2.313" 'XN' Nipple 4223' ( 2.250 No-go ID) Tandem Pumps, 137P17 Stg. SXD Coated stages 4265` Tandem Gas Separator 4284' GRSTXBARH6 (513 Internals) Tandem Seal Section 4290' Model GSB3DBUT SB/SB PFSA FSA/CL5 Motor, 114 HP, 2330 volt, 4304' 30 amp, Model KMH Pumpmate Multi-Sensor 4319' w/6 fin Centralizer (6.25' long) Baker Hook Wall Hanger inside 7" Window (21') Top 4840' Baker Hook Wall Hanger outside 7" Window" (3') Baker Down Swivel-up lock sub 4864' 6 1/8" Hole td @ 9000' OA Lateral 103 jts. - 4 1/2" Slotted Liner 12.6# L-80 IBT (4869' - 8922') Btm. 4 1/2"Guide Shoe 8965' Page`1 of 3 • Well: MPI-15 • Well History Well Date Summary MPI-15 3/6/2008 Well Support Techs set BPV, pulled well house, production lines and foundation. Support Techs greased swab, wing, master, IA and OA valves. ***NOTE*** BPV left in hole MPI-15 4/22/2008 ***ARRIV ON LOC WELL S/I*** «« PULLED BACK PRESSURE VALVE »» MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory Gama/CCL in carrier, N. attempt to dry to~could not~o de~eper~than 7837. PUH bring well on with N2 and let stabalize. RIF o Id no ruin-3c ee er tTian T~$brPIIwing i Brent rate and speed. Wind direction changed blowing towar s a equipment. s ut down N2 unit and puh to log interval 5300- 4910 C~ 30 FPM. ***job in progress*'* MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory Gama/CCL in carrier, 2.25" JSN ...Job in progress... MPI-15 4/24/2008 CTU #5 Job Scope: Nitrified Fill Clean Out w. MLT MIRU 1.75" CT MU WF MHA, PDS Memory Gama/CCL in carrier, 2.25" JSN. Ran in hole to 7837' CT appears to go into lock up. PUH bring well on with N2 and let well stabilize. RIH and attempt to get to original tag/lock up depth getting no deeper than 7485' using different rates and speed. Wind direction changed 180 deg. blowing returned gas towards surface equipment. Shut down taking returns and PUH to log from 5300 to 4910. Continued to surface for Agitator Rigged up second return tank farm opposite side of CTU and continue with FCO ...Continue job on 4/25/2008... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator....Job in progress... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator & SafeLube. Log from 4900' to 5300' ~ 30fpm, Had problems with lock up around 7480' -7890' Lubed fluids and continued with clean ...Continue job on 4/26/2008... MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator and safe tube. made another logging pass from 4900 to 5300 C~ 30fpm.~l~~^ ^~~+ ~+^~^~^ +^ ~dQ'. ***job in progress*** MPI-15 4/25/2008 Continue job from 4/24/2008. CTU #5 Job Scope: Nitrofied Clean Out w. Agitator. Continue clean out left off at 7980' CTM at C/O ...Job in progress... MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Scope:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310' ~~^~e cever^I ^ttemnta to clean OR lateral rlee~er than 8336 ~~lith nn Hick due to coil going into lock-up at various Depths. RIH w/PDS memory CCUGama inside carrier and Schlumberger MLT tools. Made logging reference between 5300' and 4900'. Made 10 of 12 positions and index/MLT tool across OA lateral window, on the tenth position noticed pressure change, RIH to investigate. Coil locked u ~ 7827 a eared to be in the OB lateral. PUH and made additional logging pass for reference. and varify that MLT was working and down load data from PDS memory sub. Data confirmed that the tools never left the main bore. RIH w. new configuration on MLT. Start MLT process. ...Continue job on 4/27/2008... MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Scope:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean OB lateral deeper than 8336 with no Igck due to coil going into lock-up at various RIH w/ PDS memory ccl/gr inside carrier and Schlumberger MLT tools. Made logging reference between 5300' and 4900'. Made 10 of 12 positions and index/MLT tool across OA lateral window, on the tenth position noticed pressure change, RIH to investigate. Coil locked up C~ 7827, appeared to be in the OB lateral. PUH and made additional logging pass for reference. ***job in progress*** MPI-15 4/26/2008 Continue job 4/25/2008 CTU #5 Job Space:Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean deeper than 8336 with no luck do to coil going into lock-up at various depths. ...Job in progress... MPI-15 4/26/2008 Continue job 4/25/2008. CTU #5 Job Scope: Nitrofied clean out with MLT «InterAct Publishing» Continue clean out from 8310. Made several attempts to clean deeper than 8336 with no luck do to coil going into lock-up at various depths. ...Job in progress... MPI-15 4/27/2008 Continue job from 4/26/2008 CTU #5 Job Scope: FCO with N2 of OA lateral section Continued with MLT process making 9 passes with each orientation being 30 deg Saw a small indication of what mia t have, keot puma running and dropped down attemotina to enter the OA lateral section. Drifted been the windouX , until CT went into lock up @ 7689' Pulled into tubing tail to verify MLT working. Saw a positive indication that tool was functioning properly. Made three more passes to complete the full 36n (te(7, Orientation process with no apparent entry to the OA lateral. POOH and down loaded data from PDS CCUGama. Page' 2 of 3 Data indicated th~ never left the main bore of the well. RD CTU left~reeze protected to 2500' ***Job Complete* MPI-15 4/29/2008 ***ARRIV ON LOC WELL S/I*** ***R/U EQUIPMENT CONTINUE ON 4/30/08*** MPI-15 4/30/2008 ***CONT FROM 4/29/08*** DRIFT TAG FOR CALIPER RIH W/ 10' 1 7/8 (2.6 " ROLLER) KJ 5' 1 7/8 (2.6" ROLLER) HYD. SSS W/ 2' 1 7/8" ROLLER / 2.76 CENT. TEL / S-BAILER TAG E.O.T. @ 4,699' SLM +13' CORRECTED MD. RAN DOWN TO 5,113' MD. STOP DUE TO DEV. NO RECOVERER IN S-BAILER *** TURN WELL OVER TO DSO *** (WELL TAGGED DONT POP ) MPI-15 4/30/2008 ***ARRIV ON LOC WELL S/I *** CALIPER HELD SAFETY MEETING REV.JSA R/U EQUIPMENT ***CONTINUE ON 5/1/08*** MPI-15 4/30/2008 ***CONT FROM 4/29/08*** DRIFT TAG RIH W/ 10' 1 7/8 (2.6 " ROLLER) KJ 5' 1 7/8 (2.6" ROLLER) HYD. SSS W/ 2' 1 7/8" ROLLER / 2.76 CENT. TEL / S-BAILER TAG E.O.T. @ 4 699' SLM 10' CORRECTION RAN DOWN TO 5,110' CM STOP DUE TO DEV. NO RE -BAILER *** TURN WELL OVER TO DSO *** (WELL TAGGED DONT POP ) MPI-15 4/30/2008 ***ARRIV ON LOC WELL S/I *** HELD SAFETY MEETING REV.JSA R/U EQUIPMENT ***CONTINUE ON 5/1/08*** MPI-15 5/1/2008 ***CONTINUE FROM 4/30/08*** RIH W/ CALIPER TO 4.834' FT COULDN'T GET BELOW THE TOP LATERAL WINDOW. + ***JOB COMPLETED*** MPI-15 5/1/2008 ***CONTINUE FROM 4/30/08*** RIH W/ CALIPER TO 4,834' FT COULDNT GET BELOW THE WINDOW ***JOB COMPLETED*** MPI-15 5/10/2008 ***ARRIV ON LOC WELL S/I *** CALIPER RAN PDS CALIPER FROM 4600' TO 5000' SLM. GOOD DATA ***TURN WELL OVER TO DSO **** MPI-15 7/5/2008 T/I/O = 1220/1220/200. IA FL (Pre Coil). IA FL C~3 -3500'. MPI-15 7/13/2008 CTU #5 1.75" CT Set IBP Interact Publishing Wait on weather ******** Job In Progress ******** MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1(Inte rAct is publishing) Set 3" IBP at 5150' .Walk pressure up in 500 pis increments to set. Ball sheared at 2950 psi. RIH w / PDS GR/CCL & R&R tool"""'""""Job in progress'"'""" MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1(Inte rAct is publishing) Set 3" IBP at 5150' .Walk pressure up in 500 pis increments to set. Ball sheared at 2950 psi, RIH w / PDS GR/CCL & R&R tool After racheting the tool two complete cycles we POOH to reconfigure the tool string. Cut 150' of coil and rehead. MU toolstring to run back in the well.******** Job In Progress******** MPI-15 7/14/2008 CTU #5 1.75" CT Set IBP Interact publishing MU BOP's PU Injector with lubricator MU BOT BHA #1 Continued from 7/13/08 ******* Job In Progress ********** MPI-15 7/15/2008 CTU #5 1.75" CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. RIH w /hydraulic indexing tool. Moved bent sib 6' clnsar t~ nozzle with a little extra bend and it went in the OA lateral the first tnc. Milne point has called a code 99 s ut down all operations STBY. Released to go back to work.POOH change to DJN.Cut coil have X-over built to get from bent sub to DJN. ******* Job In Progress ********* MPI-15 7/15/2008 CTU #5 1.75" CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. RIH w /hydraulic indexing tool. Moved bent sub 6' closer to nozzle with a little extra bend and it went in the OA lateral the first try. Milne point has called a code 99 shut down all operations STBY. Released to go back to work. """""""Job in progress"""""""" MPI-15 7/15/2008 CTU #5 1.75" CT Set IBP Interact publishing MU PDS,R&R tool with MHA to RBIH. POOH to PU BOT tool RBIH attempt to get into lat. again. MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill. MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot @ 5500' Broke thru ~ 5514' STBY for motor & mill Mu BHA RIH attempting to get out window no luck yet """""Job in progress"""""" MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot @ 5500' Broke thru ~ 5514' STBY for motor & mill """"' `Job in progress'"""`"' ` MPI-15 7/16/2008 CTU #5 1.75" CT Set IBP Interact publishing (FCO of OA lateral) RBIH with DJN Tag hard at 5029' start jetting fill Jetting hard spot Cam? 5500' Broke thru @ 5514' STBY for motor & mill Mu BHA RIH attempting to get out window no luck yet """""Job in progress"""""" Page' 3 of 3 MPI-15 7/17/2008 MPI-15 7/22/2008 MPI-15 7/22/2008 MPI-15 7/22/2008 MPI-15 • • CTU #5 1.75" CT Interact Publishing (FCO OA Lateral) RIH with 3.50" mill trying to exit window again. Tried to get in the window with no luck. POOH break off tools RDMO road to L-219. BOT building new bent sub then we will return. *********** Job Incomplete ********** CTU #5 1.75" CT (FCO/Pull IBP) Road from MPL-43 ******* Job In Progress ******* CTU #5 1.75" CT (FCO/Pull IBP) Road from MPL-43 *******Job In Progress ******* CTU #5 1.75" CT (FCO/Pull IBP) Road from MPL-43 RIH with WOT Bent motor and mill on BOT MHA with indexing tool. Work thru window milling ahead. Milled from 5546' to 7319' .******' Job In Progress **.*... 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22/08 WSR Milling at 7318'at midnight. Continued milling to 7506' using 1 % XS KCI and FloPro sweeps. CT began ac mg i e i was stacking out weight up hole. Decision made to pump 15 bbl FloPro sweep and chase to surface. Makeup 3" JSN and cleanout down to IBP. Ran into well without pumpin and entered to~_late~ral. At 5300', PUH to top of window at 4800'.. Jet down u3tlfiZ,j7°r7C5'RC an ag op o TB~P-at3~d'~' ct~Pump 12 bbl FloPro sweep and chase from IBP to surface. Makeup Baker fishing tools and hydraulic overshot. RIH and tag at 4851' ctmd. Attempt to work fishing tools ast u er lateral. *** Job in ogress MPI-15 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22/08 WSR Milling at 7318'at midnight. ****** Job In Progress ******* MPI-15 7/23/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/22/08 WSR Milling at 7318'at midnight. Continued milling to 7506' using 1 % XS KCI and FloPro sweeps. CT began acting like it was stacking out weight up hole. Decision made to pump 15 bbl FloPro sweep and chase to surface. Makeup 3" JSN and cleanout down to IBP. Ran into well without pumpin and entered top lateral. At 5300', PUH to top of window at 4800'.. Jet down usin 1 % XS KCI and to to of IBP at 5141' ctmd. Pump 12 bbl FloPro sweep and chase from I to su ace. a eup a er fishing tools and hydraulic overshot. RIH and tag at 4851' ctmd. Couldn't get past the window area with several attempts with rate and WHP, POOH to inspect Mule Shoe for marks and wait on x-overs for indexing tool. Mule Shoe had a small rolled spot on the shoulder MU Indexing tool and RIH. RIH and tagged -13' high, index tools and try working down. Made it past 4836' after 10 indexes and tagged ~ the window depth again. Could not pass 4851', tried 2 click cycles for 360 deg and 1 click for 360 deg with no luck. POOH to change oo s. ***Job continued on WSR 7/24/08*** MPI-15 7/24/2008 CTU #5 1.75" CT "Interact Publishing " (FCO/Pull IBP) Continued from 7/23/08 WSR Continue POOH can't get past 4851' PU for smaller OD tools and bent sub and cut pipe. Cut off 150' of CT and rehead. PT to 20k and WO Tools. MU tools and tried to PT but had aleak /Ran down and found disconnect was washed out (this disconnect was from the FCO run). Called BTT shop to send out another one. MU BHA and RIH ***Job in Progress*** MPI-15 7/24/2008 CTU #5 1.75" CT Fish Pull IBP. *** Continued from 7/23/08 WSR *** InterACT publishing. Continue POOH to PU smaller OD fishing tools. Cut off 150' of CT and rehead. PT to 20k and WO Tools. MU tools. Disconnect leaked .Wait on Baker for tools. RIH with fishing string with Daily Jar and 1.75" overshot. RIH and saw 2k weight bobble going through upper lateral. En a e IBP at 5145' ctmd. Pull release IBP with 10k overpull. Allow element to relax then pull out of hole. Pulled 5k overpull at upper atera , t en iars it and pulled through. POOH. At surface, IBP recovered_with all rubber elements intact. Freeze protect well with 38 bbls of 50/50 meth. RDM~ ina WHP = 400/1320/300. *** Job complete *** MPI-15 8/15/2008 Set BPV in Hole for rig to move onto I-15 well . MPI-15 8/17/2008 ** RWO Prep** INSTALL DPSOV IN STA #2 MANDREL. SET DUMMY GL IN STA#1 MANDREL. FLAGGED AND TAGGED MANDREL'S. MPI-15 8/18/2008 T/I/0=0/0/0. (Post RWO freeze protect). Freeze protect IA w/ 65 bbls crude. Freeze protect tbg w/ 15 bbls crude. FWHP=0/0/400. MPI-15 8/22/2008 Well Support Techs Pressure tested Flow lines (PROD) and (TEST) to 1150 psi for 10 MIN with diesel. (passed) PT. Then bleed both lines down to 0 psi. MPI-15 8/24/2008 ASRC Test Unit #5, Complete 6 hour test, ***Job complete*** Print Dat e: 9/4/2008 Page 1 of 1 • BP Page 1 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Start: 3/20/2008 Rig Release: 3/24/2008 Rig Number: Spud Date: 8/15/2002 End: 8/18/2008 Date From - To Hours Task I Code ~ NPT Phase Description of Operations 3/21/2008 00:00 -06:00 6.00 MOB P PRE R/D and secure rig floor, load and secure pipeshed for move from MPH-19 to MPI-15. Prep to lay over derrick. Unable to lay derrick over. Ambient temperature -40 degrees. Maximum allowable temperature to lower derrick is -40 degrees. Perform general maintenance while waiting. 06:00 - 11:00 5.00 MOB P PRE Rig maintenance and prep for rig move. 11:00 - 13:00 2.00 MOB P PRE Ambient temperature to -38 de F. Prep camp, shop and auxilliary equipment for move. Lower and scope down derrick. 13:00 - 15:00 2.00 MOB P PRE Blow down steam lines, unhook electrical lines, Jack up modules and prep to move. 15:00 - 16:00 1.00 MOB P PRE Move pit and pipeshed modules. 16:00 - 17:30 1.50 MOB P PRE Move carrier off of MPH-19. Move BOP stack and cradle and load on truck. Move carrier, pits, and pipeshed from MPH pad to MPI pad. 17:30 - 22:00 4.50 MOB P PRE Line up carrier to back over MPI-15. Spot BOP cradle and tree behind well. Lay mats and herculite and spot carrier over MPI-15. Jack and level carrier. 22:00 - 23:00 1.00 MOB P PRE Spot pipeshed, lay herculite and spot pits. 23:00 - 00:00 1.00 MOB P PRE Spot camp shop, generator building and partshouse. Inspect derrick before raising. 3/22/2008 00:00 - 01:00 1.00 MOB P PRE Raise and secure derrick. 01:00 - 04:00 3.00 MOB P PRE Berm rig, spot cuttings and slop tank. Hook up electrical lines, put steam around rig. Rig up floor and pipeshed. Spot tiger tank. 04:00 - 06:00 2.00 KILL P DECOMP R/U secondary annulus valve to IA, R/U lines to tree and hard line to tiger tank. " Rig Accepted at 04:00 hours on 3/22/2008". 06:00 - 07:00 1.00 KILL P DECOMP PUMU lubricator, Test lubricator to 500 psi. Pull TWC, T / IA / OA - 450 / 425 / 40 psi. Blow steam through all lines. Continue to finish RU for well kill. 07:00 - 08:00 1.00 KILL P DECOMP PJSM. Take on fluids Pressure test hardline to closed choke to 3500 psi. Test hardline to tiger tank to 500 psi. Bleed gas from IA to Tiger tank. Bleed from 425 psi to 150 psi. 08:00 - 12:00 4.00 KILL P DECOMP Pump 30 Bbls of SW down Tbg, taking gas returns from the IA. Pump rate of 3 BPM, Tbg pressure from 340 psi to 140 psi. Close choke and bullhead 100 Bbls into formatioin ~ 3 BPM, injection pressure of 1140 psi. IA to 940 psi. Open choke and circulate 200 Bbls down Tbg and returns from IA. Get fluid returns after pumping 95 Bbls. Circulate total of 230 Bbls w/ 199 Bbls returns. 12:00 - 13:00 1.00 KILL P DECOMP Shut down pumping. Monitor Tbg and IA. Pressure to 0 psi and then to vacuum on both sides. Blow down all lines. w/ FMC. Measure rod for 1 9/16" for engaging threads on 2 1/2" CIVI/ "H" TWC. 13:00 - 14:30 1.50 WHSUR P DECOMP Test TWC to 3500 psi for 10 minutes from above. Test from Both tests charted. Drain tree, rig down kill lines and prep for ND Tree. 14:30 - 16:30 2.00 WHSUR P DECOMP ND 2 9/16" 5M Tree. Notify AOGCC of upcoming BOPE test. States right to witness BOPE test waived by Lou Grimaldi. 16:30 - 21:30 5.00 BOPSU P DECOMP NU BOPE. Install Koomey lines, choke and kill lines. Install flow riser. Printed: 9/2/2008 11:47:23 AM • • gp Page 2 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 3/22/2008 21:30 - 22:00 0.50 BOPSU P DECOMP Function test BOPE, fill BOP stack and choke manifold with water. 22:00 - 00:00 2.00 BOPSU P DECOMP Test BOPE, choke manifold and floor valves. Test BOPE with 4-1/2 and 2-7/8" test joints. All were tested to 250 psi low and 3,500 psi high. All tests were held for 5 minutes each. Had to retighten body flanges on BOP stack. 3/23/2008 00:00 - 05:30 5.50 BOPSU P DECOMP Test BOPE, choke manifold and floor valves. Test BOPE with 4-1/2 and 2-7/8" test joints. All were tested to 250 psi low and 3,500 psi high. All tests were held for 5 minutes each. State witness of BOP test was waived by Lou Grimaldi. 05:30 - 06:00 0.50 BOPSU P DECOMP R/D test assemblies, blow down lines and drain BOP stack. 06:00 - 07:30 1.50 PULL P DECOMP PUMU Opso-Lopso and screw into tubing hanger. PUMU lubricator with polish rod and pulling tool. Stab onto OL, MU Lo-Torq valve on PI sub of lubricator. Pressure test lubricator and OL to 500 psi w/diesel - OK. 07:30 - 08:30 1.00 PULL P DECOMP BOLD lubricator and OL. PUMU 2 7/8" landing joint and screw into hanger. MU kelly hose to head pin. BOLDS. 08:30 - 11:00 2.50 PULL P DECOMP n er into stack w/ 38K PUW. Circulate SW down tubing, 12 Bbls to bring fluid into stack. Circulate 150 Bbls SW (~ 2 1/2 BPM, 180 psi. Flow check well (stable). RU elephant trunk and Centrilift equipment to floor for pulling completion. Circulate another 50 Bbls. Total volume circulated of 200 Bbls w/ 7 Bbls losses. 11:00 - 18:00 7.00 PULL P DECOMP BOLD tubing hanger. POH run ESP cable over shieve and to spooling unit. POH laying down 2 7/8" Tbg -ESP completion. Continuous hole fill by pumping across the top. 18:00 - 21:00 3.00 PULL P DECOMP UD ESP. 10' handling pup on top of ESP was punched with two 1 "x 1/4" holes. Handling pup and ESP had light corrosion. ESP appeared to have a broken drive shaft. Recovered 131 joints of 2-7/8" tubing in good shape, 1 XN nipple, 2 GLMs, 70 Lassale clamps, 6 protectolizers, 3 flat guards and 1 buster clamp. 21:00 - 22:00 1.00 PULL P DECOMP R/D 2-7/8" handling equipment and remove from rig floor. Remove ESP from pipeshed. 22:00 - 23:00 1.00 PULL P DECOMP R/D ESP sheave and containment trunk. Place containment trunk in storage box, remove sheave from rig floor. 23:00 - 00:00 1.00 BUNCO RUNCMP R/U 4-1/2" tubing handling equipment. 3/24/2008 00:00 - 06:00 6.00 BUNCO RUNCMP P/U 4-1/2" muleshoe assembly and RIH picking up 4-1/2",12.6#, L-80, IBT-M tubin from the i eshed. Use Best-O-Life 2000 pipe dope. M/U torque 3,000 ft/Ibs. Run 93 jts of IBT, XO put joint to 31 joints of 4 1/2" NSCT Tbg. 06:00 - 07:00 1.00 BUNCO RUNCMP Running 4 1/2" NSCT, 112 jts in hole ~ 06:00. Crew change. Continue RIH total of 124 joints of 4 1/2" Tbg, 1 XO pup, 10' XO pups above and below 4 1/2" XN Nip (3.725" ID), WLEG. 07:00 - 08:00 1.00 WHSUR P TUBHGR PUMU 11" x 4 1/2" FMC Tbg hanger on 4 1/2" NSCT landing joint. PUW of 55K, SOW of 33K. Land tubing hanger RILDS 08:00 - 09:30 1.50 WHSUR P WHDTRE Drv rod TWC. Test from above to 3500 psi for 10 minutes test from elow um in ~ 1 BPM 560 si 30 minutes. Chart both tests 09:30 - 14:30 5.00 WHSUR P WHDTRE Drain stack. ND BOPE 14:30 - 16:30 2.00 WHSUR P WHDTRE NU 4 1/16" Tree. Test hanger void to 5000 psi for 20 minutes - OK. Pressure test tree to 5000 psi with diesel for 10 minutes and chart. Printed: 9/2/2008 11:47:23 AM ~ • gp Page 3 of 4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24/2008 Rig Name: NABOBS 3S Rig Number: i Date From - To 'Hours; Task Code NPT Phase Description of Operations 3/24/2008 16:30 - 18:00 1.50 WHSUR P WHDTRE Pu I TWC with lubricator. Run BPV- Normal up tree and cellar. Rig released at *** 18:00 hours*** 8/14/2008 14:00 - 00:00 10.00 MOB P PRE RD and LD derric c. ove rig rom -pad to MPI-15. 8/15/2008 00:00 - 16:00 16.00 MOB P PRE Move rig from GPB to MPI-15. Set herculite & rig mats. 16:00 - 19:00 3.00 RIGU P PRE Spot & berm rig over MPI-15. Spot pits & pipe shed. AOGCC Chuck Scheive waived BOP test witness ~ 17:50 hrs. 19:00 - 21:00 2.00 RIGU P PRE Raise & scope derrick. RU lines to pits. ***Accept Rig ~. 21:00 hrs*** 21:00 - 00:00 3.00 KILL P DECOMP RU lines to tree & Tiger Tank. Take on fluid to pits - 8.45 ppg / 115 degree off truck. 8/16/2008 00:00 - 01:30 1.50 KILL P DECOMP PJSM. P/T lines to 250 psi low / 3500 psi high. Test lines to Tiger Tank to 500 psi. 01:30 - 02:30 1.00 KILL P DECOMP Bleed OA from 200 psi to 0 psi (fluid). Bled TBG from 600 psi to 100 psi thru choke to Tiger Tank all gas. Bled IA from 900 psi to 150 psi all gas. 02:30 - 04:00 1.50 KILL P DECOMP Pump 82 bbls down tubing taking returns thru choke to Tiger Tank. Circulated ~ 5 BPM / 650 psi -crude returns. Shut choke, bullhead 30 bbls ~ 3.5 BPM / 900 psi. Open well and circulate 175 bbls ~ 3.5 BPM / 600 psi -crude returns. 8.43 ppg in, getting 8.45 ppg out. Circulated a total of 286 bbls and lost 52 bbls to formation. 04:00 - 04:30 0.50 KILL P DECOMP TBG 50 psi, IA 50 psi after circulation. Monitor well for 20 min pressures fell to 0 psi on tubing & IA went on vacuum. 04:30 - 06:00 1.50 WHSUR P DECOMP RD lines from tree. Dry rod TWC. Pressure test to 3500 psi on top for 10 min -charted. Test TWC from bottom. Pump 2.5 700 psi. for 10 min. a e same. 06:00 - 06:30 0.50 BOPSU P DECOMP Crew change. Service rig. Inspect derric heck PVT alarms. 06:30 - 08:00 1.50 WHSUR P DECOMP Bleed off hanger void & actuator valve. N/D tree & adapter flange. 08:00 - 10:00 2.00 BOPSU P DECOMP N/U BOPE. 10:00 - 16:30 6.50 BOPSU P DECOMP Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. Tested hydil, LP 250 psi, HP 3500 psi. Used 2 7/8" & 4 1/2" test joints. No failures. BOP test witnessing waived by Chuck Schieve w/ AOGCC. 16:30 - 19:30 3.00 PULL P DECOMP PU 7" lubricator extension. MU DS ri t si. Pull TWC tubin on vacuum. LD lubricator and lubricator extension. 19:30 - 21:00 1.50 PULL P DECOMP MU landing joint. Screw into hanger, BOLDS. Pull hanger to floor, PUW = 60K. Break out and LD hanger. MU circulating head to tubing. 21:00 - 22:30 1.50 PULL P DECOMP CBU ~ 6 BPM / 300 psi. Returned crude and gas to surface while circulating. Circulated 216 bbls and lost 6 bbls. Monitor well for 10 min. a on ac. 22:30 - 00:00 1.50 PULL P DECOMP Run continuous hole fill. LD 4-1/2" tubing. 8/17/2008 00:00 - 03:00 3.00 PULL P DECOMP Cont to LD 4-1/2" tubing w/ continuous ole fill. LD a total of 124 jts, 1 XN nipple ass'y, 1 mule shoe ass'y. Lost 17 bbls while pulling tubing. 03:00 - 04:30 1.50 BUNCO RUNCMP Clean & clear rig floor. Take out rest of tubing from shed. RU .. Bring pump & equipment to shed and rig floor. String ESP cable from spooler to rig floor. 04:30 - 08:30 4.00 BUNCO RUNCMP PJSM. MU ESP pump ass'y. 08:30 - 16:00 7.50 BUNCO RUNCMP in I in hole w/ 2-7/8" ESP com letion. Check conductivity every -2000' -Flush pump w/ 10 bbls (.5 BPM / 650 psi). MU Printed: 9/2/2008 11:47:23 AM gp Page4of4 Operations Summary Report Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: WORKOVER Start: 3/20/2008 End: 8/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/24!2008 Rig Name: NABOBS 3S Rig Number: I ~ Phase Description of Operations Date ' From - To Hours Task Code NPT 8/17/2008 08:30 - 16:00 7.50 BUNCO RUNCMP landing joint &HGR. Cut ESP cable & pull over sheave. -PUW = 4i K, SOW = 40 K. -Ran 133 joints, 1 XN ass'y, 2 GLM ass'y. -Ran 74 LaSalle clamps, 3 Flat Guards & 5 Protectalizers. 16:00 - 17:00 1.00 BUNCO RUNCMP Safety stand down. Review YTD incidents & mitigations. 17:00 - 19:00 2.00 BUNCO RUNCMP Clear rig floor. Make field connector splice. Plug in penetrator & test. 19:00 - 20:00 1.00 BUNCO RUNCMP Land HGR. LD landing jt. RILDS. Clear rig floor. 20:00 - 21:00 1.00 BUNCO RUNCMP Dry rod TWC. Test to 3500 psi from above and rolling test to, 500 psi for 10 min._ 21:00 - 23:00 2.00 BOPSU P RUNCMP ND BOPE. 23:00 - 00:00 1.00 WHSUR P RUNCMP NU Tree. 8/18/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP RU to test tree. Test TBG adapter to 3500 psi for 30 min. Test tree to 5000 psi with diesel. 01:00 - 02:00 1.00 WHSUR P RUNCMP P/T lubricator to 500 psi. Pull TWC. Set BPV. LD {ubricator. o ing test to 500 psi -charted. 02:00 - 03:00 1.00 WHSUR P RUNCMP Safety Standown. Review incidents & mitigations. "`Rig Release ~ 03:00"' Printed: 9/2/2008 11:47:23 AM . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc I o¿:t- Â6b~l DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021520 Well Name/No. MilNE PT UNIT SB 1-15 MD 9050./ TVD 4106 -----/ Completion Date 9/1/2002 ---- ----.----------.-- -'._---~--'--'---- REQUIRED INFORMATION Mud Log No ._.._---____..n______-~- -~.__._-~--_._-~._--- DATA INFORMATION MWD, GR, RES, ABI, IFRlCASANDRA Types Electric or Other Logs Run: Well Log Information: Log! Electr Data Digital Dataset Type Med!Frmt Number Name -_._-_._-~._._..-----_.~- ED ,j:r' ,- Directional Survey Rpt Directional Survey Rpt Directional Survey ED ¿IF Directional Survey ED if Directional Survey Rpt Directional Survey Rpt LIS Verification ~'O/ ~1 LIS Verification ED [,Ø- Directional Survey Rpt LIS Verification ~j¡/Ô e:.U342 US Verification Rpt Directional Survey iErJ C Asc (~1'960 US Verification (Ef) C Pdf ,:::}-1960 Induction/Resistivity .Ef) ./ C Pdf 11960 Induction/Resistivity .iD (/' ~ Asc jJ960 LIS Verification \~D IJ.'- Pdf )-'1960 Induction/Resistivity ¡ø I I?t/Pdf 'Tí960 I nd uction/Resistivity --_._--~-----~~----- Operator BP EXPLORATION (ALASKA) INC 5 ¡? c-1 \~ (" ¡q.4l J ~'-D API No. 60-029-23106-00-00 Completion Status 1-01L Current Status 1-01L UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OHI ~/ Scale Media No Start Stop CH Received Comments 1 5471 9050 Open 1 0/2/2002 1 0 6095 Open 10/2/2002 MWD PB1 5471 9050 Open 10/2/2002 MWD 0 6095 Open 10/2/2002 MWD PB1 5471 9050 Open 1 0/2/2002 MWD 5471 9050 Open 10/2/2002 42 6039 Case 12/6/2002 PB1 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/23/2002. 1 42 8997 Case 12/6/2002 1 0 6095 Open 10/2/2002 PB1 -'-..-7" 1 42 8997 Case 12/6/2002 1 42 6039 Case 12/6/2002 PB1 1 0 6095 Open 10/2/2002 PB1 1,2,3,4 42 9050 Open 6/2/2003 25 Final 112 9050 Open 6/2/2003 MWD - Rap, DGR, EWR - MD 25 Final 112 4106 Open 6/2/2003 MWD - DGR, EWR - TVD 1,2,3 42 6094 Open 6/2/2003 25 Final 112 6095 Open 6/2/2003 MWD - Rap, DGR, EWR- MD 25 Final 112 4088 Open 6/2/2003 MWD - DGR, EWR - TVD Permit to Drill 2021520 DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Well Name/No. MILNE PT UNIT SB 1-15 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23106-00-00 MD 9050 TVD 4106 Well Cores/Samples Information: Name ADDITIONAL INFORMATION YIÐ Well Cored? Chips Received? - Y 1 N ~ Analysis Received? .~-- -.----------------- ---_._--.--~---~---~ Comments: --_._-~-_._--- ---------- Compliance Reviewed By: Completion Date 9/1/2002 ~~\ Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L Sample Set Number Comments (f)N ~/N Date: UIC N .~ 1""\ () ~~.Ô{j ""( , ) ¿;'()f)- /6~ ) ft //9fd:J WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 15, 2003 RE: MWD FOffilation Evaluation Logs: MPI-15, AK-MW-22136 MPI-15: Digital Log Images: 50-029-23106-00 1 CD Rom . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn:Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 RECEIVED BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: JUN 0 2 2003 Alaska On & ~as U)ns. Commie8ion Anchorage :!J-CJ (9, ,- [S?-- Signed~é\\l~N\. ~,o~ -~~\':~ ,,\ ~ ) iÎod-/6~ 11- //9&0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 15, 2003 RE: MWDFormationEvaluationLogs: MPI-15 PBI, AK-MW-22136 MPI-15 PDt: Digital Log Images: 50-029-23106-70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNJNG THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 REceiVED Date:JUN 02 2003 Alaska OK & Gas Cons. Commiseion Anchcnge Signed~O~: N\.~~ àD;~ --\ 'S"d- ,~;''\:~ y,\\ ~ ) dOd - 15;) /13<-1/ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2002 RE: MWDFonnationEvaluationLogs MPI-15, AK-MW-22136 1 LIS fonnatted Disc with verification listing. API#: 50-029-23106-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed:~/~r~ RECEIVED DEC 06 2002 Alaska Od & Gas Cons. C-ommission Anchorage C;;~-19 } I 3 LJc:¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2002 RE: MWD Formation Evaluation Logs MPI-15 PBl, AK-MW-22136 1 LIS formatted Disc with verification listing. Pù?I#: 50-029-23106-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF mE TRANSMITTAL LETTER TO THE ATTENTION OF: S perry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Si~¿Ør- RECE\VED DEC 06 ZOOL þJ, ska or. & Gas Cons. Commission a.. ,Anchoœge I ASP GRID""') ¡;,Z> J.. - (5 J... , - Z""" \ 2'34'41" I I-PAD PLANT) .14 . 13 . 12 . 11 . 8 . 7 . 4 . 6 . 3 . 5 . 2 . 9 .1 . 10 ~ 1-15 LEGEND -+ AS-BUILT CONDUCTOR . EXISTING CONDUCTOR . io N t IM~~ I-PA~ NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.9999031 l- t:> <t ::;: 0. '" ~ g 3. HORIZONTAL CONTROL IS BASED ON MPU I-PAD MONUMENTS 1-1 AND 1-2. 4. PLAN LOCATION OF MPI-15 WAS MOVED TO 25 FT. EAST OF MPI-10 DUE TO PIPING OBSTRUCTIONS. 5. DATE OF SURVEY: AUGUST 7, 2002. 6. REFERENCE FIELD BOOK: MP02-06 PGS. 45-46. <u <u "- .... "- !D '" . ." ~ ~ to ~. L 0 U ~ ." C 0 U '" , ,'-' ,,:I:P AI:>, p~ . ".,~,....,:.,.":,,.,.,:..},3 ~ RIf iU£' .. "', . ". ,", : '.. . ':. PRoJêC¡ AREA';:.;,": ;';: VICINITY MAP SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 7, 2002. LOCATED WITHIN PROTRACTED SEC. 33, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPI-15 Y= 6,009,441.71 N 1,119.49 70'26'11.545" 70.4365404' 35.0' 2,326' FSL X= 551,729.59 E 1,435.00 149'34'41.664" 149.5782400' 3,641' FEL ¡ <u '" "- ..- <u <u ..- t:> <t 0. ..- ::> 0. ::;: ..- ~ 0 8/07/02 ISSUED FOR INFORMATION .;:, NO. DAlE DRA'M'/: REVISION F. Robert l -- 11 i (U~~rn(bo JJC LOH ENOHŒRS "" lAIC> SUR~VCIOS SCALE: BY CHK :':;:... ~A l^:5OJ 1'=150' JACOBS t- CHECKED: I ALLISON \ DAlE: 7/17/02 DRAv"NG: FRB02 MPI 01-03 JOB NO: ObP MILNE POINT UNIT I-PAD AS-BUILT CONDUCTOR WELL MPI-15 SHEET: 10f'1 1. Status of Well Œa Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 23261 NSL, 36411 WEL, Sec. 33, T13N, R10E, UM At top of productive interval 918' NSL, 14121 WEL, SEC. 33, T13N, R10E, UM At total depth 2807' NSL, 4557' WEL, SEC. 34, T13N, R10E, U 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 62.5' ADL 025906 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8-16-2002' 8-25-2002 9-1-2002 . 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9050 4106 FT 9050 4106 FT Œa Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, ABI , IFR 1 CASANDRA ''; p~, CASING SIZE 20" WT. PER FT. 92# 47# 26# 12.7# 9-5/8" 7" 4-1/2" ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 202-152 8. API Number 50- 029-231 06-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPI-15 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 18001 (Approx.) GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 28' 1121 42" 260 sx Arctic Set (Approx.) 28' 30851 12-1/4"919 sx Class ILl, 225 sx Class 'GI 251 5204' 8-1/2" 84 sx AS Lite, 189 sx Class 'GI 5095 9042' 6-1/8" Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ~t1¥f 1) MD 5200' - 9041' 4037' - 41 06' 27. Date First Production September 12, 2002 Date of Test Hours Tested 9-11-2002 12 No core samples were taken. Form 10-407 Rev. 07-01-80 25. TUBING RECORD DEPTH SET (MD) 4262' SIZE 2-7/8",6.5#, L-80 PACKER SET (MD) N/A TVD TVD MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 893 GAs-McF 271 WATER-BBL 893 WATER-BBL CHOKE SIZE GAS-OIL RATIO 304 OIL-BBL GAs-McF OIL GRAVITY-API (CORR) RBDMS 9FL OCT, 4 2002 Alaska OU& Gas Oems. COmmtsslon Anchorage If OCT 0 4 2002 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF1-NB 4514' 38361 SBE4-NC 4581' 3868' SBE2-NE 4621' 3886' SBE1-NF 4736' 3931' TSBD-OA 4843' 3966' TSBC 49531 39971 TSBB-OB 5136\ 4030' TSBB-OB 8564' 4093' TSBB-08 8691' 4094' 31. List of Attachments: Rlc'tVED OCT 0 4 2002 A1ast<a Ol~& Gas COns. comm\ss\on Anchorage Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Integrity Test Summary. 32. I hereby certify that the fore oing is true and correct to the best of my knowledge ~ Signed Sondra ~man - - .. ~~. Titl~ Technical Assistant Datel [) - O~-() 2- MPI-15 202-152 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Matt Green, 564-5581 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. IrEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. IrEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. IrEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced. showing the data pertinent to such interval. IrEM 21: Indicate whether from ground level (GL) or other elevation (OF. KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPI-15 Common Name: MPI-15 Test Date 8/18/2002 8/21/2002 FIT FIT Test Type Test Depth (TMD) 3,112.0(ft) (ft) BP Leak-Off Test Summary Test Depth..(TV[) 2,783.0 (ft) (ft) AMW 9.10 (ppg) (ppg) SurfacePl"eS$ure 370 (psi) (psi) Leak.Off.Pressure..(BHP) 1,686 (psi) (psi) Page 1 of 1 EMW 11.66 (ppg) 11.66 (ppg) ~. '~ Printed: 9/4/2002 10:52:54 AM ) ') E3J? Ope..a~ions SarnmaryReport Page 1 of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/14/2002 20:00 - 21 :00 1.00 MOB P PRE MOVE UTILITY MODULES OFF WELL MPS-31 21 :00 - 21 :30 0.50 MOB P PRE MOVE PIPE SHEDS AND ROCK WASHER OFF WELL 21 :30 - 22:30 1.00 MOB P PRE MOVE SUB OFF WELL MPS-31 22:30 - 23:30 1.00 MOB P PRE MOVE SUB FROM S PAD TO TO MILNE PT ROAD 23:30 - 00:00 0.50 MOB P PRE MOVE PIPE SHEDS - PIT MODULE UP TO MILNE PT ROAD TO FOLLOW SUB TO I PAD 8/15/2002 00:00 - 05:00 5.00 MOB P PRE MOVING SUB - PIPE SHED - PIT MODULES TO I PAD - MOVING PUMP - MOTOR MODULES TO I PAD - SPOT SUB - PIT MODULES - PIPE SHEDS 05:00 - 08:30 3.50 MOB P PRE MOVE AND SPOT PUMP - MOTOR - BOILER MODULES 08:30 - 10:30 2.00 MOB P PRE RIG UP UTILlTIY MODULES - PIPE SHED - PREPARE PITS FOR MUD 10:30 -12:00 1.50 MOB P PRE NIPPLE UP DIVERTER SYSTEM 12:00 - 13:00 1.00 MOB P PRE SET - BERM ROCK WASHER 13:00 -14:00 1.00 MOB P PRE CHANGE OUT SAVER SUB FROM 3 1/2" TO 5" - COMPLETE RIG ACCEPTENCE (ACCEPT RIG @ 14:00 HRS 8/15/2002) 14:00 -15:30 1.50 RIGU P PRE FINISH NI~PLE UP DIVERTER - PANIC LINE AND HOOK UP TO FLOW LINE 15:30 - 18:00 2.50 RIGU P PRE LOAD - STRAP 4500' OF 5" DRILL PIPE IN PIPE SHED - MIXING SPUD MUD 18:00 - 18:30 0.50 RIGU P PRE FUNCTION TEST DIVERTER SYSTEM - ACCUMULATOR TEST - START 3000 END 1950 - 200 PSI 22 SECS - FULL PRESSURE 2 MINS 36 SEC - 16 SECS TO CLOSE ANNULAR AND OPEN DIVERTER VALVE - 6 BOTTLES AVG PRESSURE 2125 PSI - RIGHT TO WITNESS OF DIVERTER FUNCTION TEST WAVIED BY CHUCK SCHEVE 18:30 - 19:30 1.00 RIGU P PRE CHANGE OUT TOP DRIVE PIPE GRABBERS FROM 3.5" TO 5" AND HANDLING TOOLS 19:30 - 23:30 4.00 DRILL P SURF PICK UP 5" DRILL PIPE FROM PIPE SHED - STANDING BACK IN DERRICK - 4500' 23:30 - 00:00 0.50 DRILL P SURF LOAD BHA IN PIPE SHED 8/16/2002 00:00 - 02:30 2.50 DRILL P SURF LOADING BHA ASSEMBLY IN PIPE SHED - STRAP SAME - PICK UP 5" HWDP - FLEX COLLARS - STAND IN DERRICK 02:30 - 03:30 1.00 DRILL P SURF PICK UP BHA - UP LOAD MWD - 03:30 - 04:00 0.50 DRILL P SURF PRE-SPUD MEETING WITH CREW - DO - MUD ENGINEER - MWD 04:00 - 04:30 0.50 DRILL P SURF RIG UP HOWCO SLICK LINE UNIT FOR RUNNING GYRO 04:30 - 05:00 0.50 DRILL P SURF FILL CONDUCTOR - CIRCULATE SURFACE SYSTEM TO CHECK FOR LEAKS 05:00 - 06:30 1.50 DRILL P SURF SPUD WELL IN - DRILL FROM 112' TO 261' - WOB 10K- GPM 400 - PP ON 1000 - OFF 900 - RPM 70 06:30 - 07:30 1.00 DRILL P SURF POH TO 84' - MAKE UP FLEX DC'S - RIH TO 261' 07:30 - 13:30 6.00. DRILL P SURF DIRECTIONAL DRILL FROM 261' TO 816' - WOB 35 - GPM 400 - PP ON 1100 - OFF 990 - STARTED BUILD AT 261'- DRILL TO 818' UNABLE TO ACHIEVE BUILD - CIRC HOLE CLEAN 13:30 - 15:00 1.50 DRILL N DPRB SURF POH - SET MOTOR TO 1.83 DEGREE FROM 1.5 DEGREE - TIH TO 816' 15:00 - 00:00 9.00 DRILL P SURF DIRECTIONAL DRILL FROM 816' TO 1650' - WOB 30K TO 35K - RPM 60 - TO 6K ON - OFF 2K - GPM 500 - PP 2140 ON - OFF 1880 - PU 82 - SO 74 - ROT 78 8/17/2002 00:00 - 08:00 8.00 DRILL P SURF DIRECTIONAL DRill FROM 1650' TO 3092'. WOB 30 - 35K- 60 RPM - TO 6K ON 2K OFF - GPM 500 -PP 2140 ON - OFF Printed: 9/4/2002 10:53:07 AM ') Page 2 of8 BP Operations Summary R.eport Legal Well Name: MPI-15 Common Well Name: MPI-15 Event Name: DRILL +COMPLETE Contractor Name: DOYON Rig Name: DOYON 141 From-To Hours Task Code NPT Phase 8/17/2002 00:00 - 08:00 8.00 DRILL P SURF 08:00 - 09:00 1.00 CASE P SURF 09:00 - 10:30 1.50 CASE P SURF 10:30 - 11 :30 1.00 CASE P SURF 11:30 - 14:00 2.50 CASE P SURF 14:00 - 17:30 3.50 CASE P SURF 17:30 - 19:00 1.50 CASE P SURF 19:00 - 22:30 3.50 CASE P SURF 22:30 - 23:00 0.50 CASE P SURF 23:00 - 00:00 1.00 CASE P SURF 8/18/2002 00:00 - 01 :30 1.50 CASE P SURF 01 :30 - 05:00 3.50 CASE P SURF 05:00 - 07:00 2.00 CASE P SURF 07:00 - 08:30 1.50 CASE P SURF 08:30 - 09:30 1.00 CASE P SURF 09:30 - 11 :30 2.00 CASE P SURF 11 :30 - 12:00 0.50 BOPSURP SURF 12:00 - 14:00 2.00 BOPSURN SFAL SURF 14:00 - 17:00 3.00 BOPSURP SURF 17:00 - 18:00 1.00 BOPSURP SURF Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Description of Operations 1880. PU 82 - SO 74 - ROT 78 (HYDRATES FROM 1880' TO 1980') CIRCULATE HOLE CLEAN AT 3092'.590 GPM AT 2400 PSI. PUMPED OUT OF HOLE TO 810' WITH FULL DRILL RATE. 550 GPM AT 2200 PSI. NO PROBLEMS. RUN BACK IN HOLE TO 3092' WITH NO PROBLEMS. CIRCULATED HOLE CLEAN. STOOD BACK ONE STAND EVERY 30 MINUTES. CIRCULATED BOTTOMS UP 4 TIMES. 590 GPM AT 2200 PSI. PUMPED OUT OF HOLE TO 810'. PULLED OUT HOLE TO SURFACE. LAID DOWN MWD AND MOTOR. RIG UP CASING CREW PJSM - PICK UP AND RUN 74 JOINTS L-80 40# 95/8" BTC CASING - LAND SAME - SHOE 3086' - FIC 3005' - GOOD RETURNS NO LOSSES WHILE RUNNING CASING RIG DOWN FRANK'S FILL UP TOOL - MAKE UP HOWCO CEMENTING HEAD AND CEMENTING LINES BREAK CIRC WITH 25 SPM - STAGING UP TO 77 SPM MAX RATE - CIRCULATE AND CONDITION MUD FOR CEMENT JOB CIRCULATE AND CONDITION MUD FOR CEMENT JOB PUMP 10 BBLS WATER - TEST LINES TO 3500 PSI- DROP BOTTOM PLUG - PUMP 40 BBLS WATER - PUMP 50 BBLS ALPHA WEIGHTED SPACER - START LEAD CEMENT @ 1 :50 AM - PUMPED 919 SXS (680 BBLS) PERMAFROST L CEMENT MIXED AT 10.7 PPG - 20 BBLS GOOD LEAD CEMENT TO SURFACE - PUMPED 225 SXS (46 BBLS) PREMIUM CEMENT + 1% CALCIUM CHLORIDE + .3% HALAD 344 + .2% CFR-3 MIXED IN A 15.8 PPG SLURRY - DISPLACE WITH 30 BBLS WATER HOWCO - 198 BBLS MUD WITH RIG - BUMP PLUG WITH 1650 PSI - BLEED PRESSURE BACK - FLOATS HELD - CIP 05:00 HRS - TOTAL CEMENT TO SURFACE 294 BBLS LAND DOWN LANDING JOINT - FLUSH OUT DIVERTER AND RISER - RIG DOWN CASING CREWS NIPPLE DOWN DIVERTER ORIENT - NIPPLE UP WELL HEAD - TEST TO 1000 PSI FOR 10 MIN - GOOD NIPPLE UP BOP'S RIG UP TEST EQUIPMENT PULL LOWER TEST PLUG - WILL NOT HOLD - PICK UP UPPER TEST PLUG TEST BOP'S - ANNULAR 250 LOW 2500 HIGH - PIPE RAMS UPER I LOWER 250 LOW 4000 HIGH - MANIFOLD 250 LOW 4000 HIGH - HYD CHOKE - KILL HYD 250 LOW 4000 HIGH MANUAL CHOKE - MANUAL KILL 250 LOW 4000 HIGH - UPPER IBOP LOWER IBOP - FLOOR SAFETY VALVES 250 LOW 4000 HIGH - ALL TEST HELD FOR 3 MINS EACH PULL UPPER TEST PLUG - INSTALL NEW LOWER TEST PLUG TEST 250 LOW - 4000 HIGH FOR 3 MINS EACH TEST - PULL LOWER TEST PLUG AND INSTALL LONG BOWL WEAR RING - RIGHT TO WITNESS TEST WAIVED BY CHUCK SCHEVE WITH AOGCC Printed: 9/412002 10:53:07 AM '" ) ) BP Operations. Summary Report Page 3 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From- To Hours Task Code NPT Phase Description of Operations 8/18/2002 18:00 - 18:30 0.50 CASE P SURF PU BHA AND UP LOAD MWD 18:30 - 19:30 1.00 CASE P SURF TIH - SHALLOW TEST MWD - CON'T RIH TO 2990' TAG UP 19:30 - 20:00 0.50 CASE P SURF BREAK CIRC - CIRCULATE CONDITION MUD FOR CASG TEST 20:00 - 20:30 0.50 CASE P SURF TEST 9 5/8" CASING FOR 15 MINS RECORD ON CHART PRESSURE 1500 PSI - DEPTH 2970' 20:30 - 22:30 2.00 CASE P SURF DRILL 14' CEMENT - FLOAT COLLAR@ 3004' -79' CEMENT - SHOE @ 3084' - 22:30 - 23:30 1.00 CASE P SURF DRILL 20' NEW HOLE @ 3112' - CIRCULATE BALANCE MUD WEIGHT TO 9.1 IN AND OUT 23:30 - 00:00 0.50 CASE P SURF PERFORM FIT - DEPTH 3112' MD - 2783 TVD - MUD WEIGHT IN HOLE 9.1 - SURFACE PRESSURE 370 PSI = 11.67 FIT 8/19/2002 00:00 - 15:00 15.00 DRILL P INT1 DIRECTIONAL DRILL FROM 3112' TO 5216' - WOB 20K TO 30K - RPM 80 - TQ ON 9K - OFF 8K - PP 1950' ON - OFF 1700 - GPM 450 - PU 145 - SO 87 - ROT 105 15:00 - 20:00 5.00 CASE N FLUD INT1 CIRCULATE HOLE - RAISE MUD WEIGHT FROM 10.2 TO 10.8 - (GAS CUT FROM 10.1 TO 9.1) ON BTMS UP 20:00 - 20:30 0.50 CASE P INT1 FLOW CHECK WELL - WELL STABLE - CHECK 30 MINS 20:30 - 21 :30 1.00 CASE P INT1 CBU 2 X - LOTS OF OIL COMING OUT - 6% OIL IN MUD - GAS CUT FROM 10.9 TO 10.7 21 :30 - 00:00 2.50 CASE P INT1 PUMP OUT TO 3350' - TIGHT SPOT AT 4368' TO 4345' - WORK PIPE WITHOUT BACK REAMING NO SUCCESS - BACK REAM TIGHT SPOT FROM 4370 TO 4340' - CON'T PUMP OUT HOLE - FLOW CHECK WELL AT 4000' - WELL STABLE - CON'T PUMP OUT HOLE - GPM 400 - PP 1190 PSI 8/20/2002 00:00 - 00:30 0.50 CASE P INT1 CON'T PUMP OUT TO 3000' - MONITOR WELL 15 MINS - WELL STABLE 00:30 - 01 :30 1.00 CASE P INT1 RIH - BREAK CIRC @ 4167' - CON'T RIH - NO TIGHT SPOTS SEEN ON TRIP IN - HOLE IN GOOD SHAPE 01 :30 - 03:30 2.00 CASE P INT1 CIRCULATE / CONDITION MUD - CBU 3.5 X - GPM 450 - RPM 100 - PP 1850 - MUD WEIGHT CUT TO 10.5 FROM 10.9 ON FIRST BOTTOMS UP - MUD WEIGHT WAS STEADY AT 10.8 ON NEXT TWO BOTTOMS UP - MONITOR WELL- WELL STABLE 03:30 - 08:30 5.00 CASE P INT1 PUMP OUT TO SHOE - GPM 400 - PP 1550 PSI 08:30 - 09:00 0.50 CASE P INT1 MONITOR WELL, SLUG PIPE 09:00 - 11 :30 2.50 CASE P INT1 TRIP OUT WITH BHA, LAY DOWN MWD,MOTOR,STABS 11:30 -13:00 1.50 CASE P INT1 CHANGE RAMS IN BOPS TO 7", TEST TO 250-4,000 PSI 13:00 - 14:30 1.50 CASE P INT1 RIG UP CSG TOOLS, PJSM 14:30 - 17:00 2.50 CASE P INT1 RUN 7" 26# L-80 BTC CSG TO 1900' 17:00 - 17:30 0.50 CASE P INT1 CHANGE OUT RUBBER ON FRANKS FILL UP TOOL 17:30 - 19:00 1.50 CASE P INT1 PICK UP CSG TO 3,000 FT 19:00 - 19:30 0.50 CASE P INT1 CIRC @ 3,000' 47 ST/MIN 250 PSI PUMPED 1400 PUMP STKS 19:30 - 20:00 0.50 CASE P INT1 PICKING UP CSG 3,000 TO 5,206 STRING WT 90,000 DOWN 150,000 UP TOTAL JTS RUN 128, SHOE @ 5206, FLOAT @ 5122 20:00 - 22:30 2.50 CASE P INT1 RIG DOWN FRANKS TOOL, RIG UP CEMENT HEAD 22:30 - 00:00 1.50 CASE P INT1 CIRC TO THIN MUD FOR CEMENT JOB, CIR WITH 47 ST/MIN 350 PSI FOR TWO CSG VOLUMES 5,000 PUMP ST. (BOTTOMS UP MUD WAS CUT FROM 10.8 TO 10.6) 8/2112002 00:00 - 00:30 0.50 CASE P INT1 CIRC. TO THIN MUD FOR CEMENT JOB, VIS 48 YP 15 Printed: 91412002 10:53:07 ÞN. ) BP Operations .Sl.ImmaryReport Page 4 of 8 Legal Well Name: MPI-15 Common Well Name: MPI-15 Spud Date: 8/15/2002 Event Name: DRILL +COMPLETE Start: 8/15/2002 End: Contractor Name: DOYON Rig Release: 9/1/2002 Rig Name: DOYON 141 Rig Number: 141 Date From...iTo Hours. . Task Code NPT Description of Operations 8/21/2002 00:30 - 01 :30 1.00 CEMT P INT1 TEST LINES TO 3500 PSI, CEMENT WITH 5 BBlS WATER AHEAD, 20 BBlS ALPHA SPACER 11.0#, 33 BBlS 84 SX CLASS E 12.0#, TAil WITH 39 BBlS 189SX. CLASS G 15.8# MIXED AND PUMP @ 4 BBlS MIN. 450 PSI, KICKED OUT TOP PLUG WITH 5 BBlS WATER. 01 :30 - 02:30 1.00 CEMT P INT1 DISPLACE WITH RIG PUMP AT THE RATE OF (FIRST 1844 STKS 59 SPM, NEXT 296 PUMP STKS 23 SPM, LAST 120 PUMP STKS 12 SPM), FULL RETURNS THRU OUT JOB, BUMP PLUG WITH 1400 PSI @ 0215, FLOAT HELD 02:30 - 03:30 1.00 CEMT P tNT1 LAY DOWN CEMENT HEAD AND LANDING JT. CHANGE OUT BAILS 03:30 - 04:30 1.00 BOPSUR P INT1 INSTALL 7" PACK OFF AND TEST TO 5,000 04:30 - 05:00 0.50 CASE P INT1 FREEZE PROTECT 7' BY 9 5/8 ANNlUS WITH HB&R WITH 60 BBLS DIESEL PUMPED @ 2.5 BBlS MIN 1200 PSI 05:00 - 10:00 5.00 CASE P INT1 LAYING DOWN 5" DRill PIPE OUT OF DERRICK 10:00 - 12:00 2.00 CASE P INT1 CHANGE OUT RAMS IN BOPS TOP 3.5X6 BTM 3.5 12:00 - 13:30 1.50 CASE P INT1 CHANGE OUT SAVER SUB AND GRABBERS ON TOPDRIVE TO 3.5 13:30 - 14:30 1.00 CASE P INT1 CUT DRilLING LINE 14:30 - 15:30 1.00 CASE P INT1 TEST 3.5 RAMS TO 250/4000 PSI FOR 5 MIN. EACH INSTAll WEAR RING 15:30 - 19:00 3.50 CASE P INT1 PICK UP 3.5 MULE SHOE AND 3.5 S-13513.3# DRill PIPE 135 JTS 19:00 - 19:30 0.50 CASE P INT1 CIRC DRill PIPE VOLUME 19:30 - 20:30 1.00 CASE P INT1 TRIP OUT AND STAND IN DERRICK 20:30 - 00:00 3.50 CASE P INT1 PICKING UP 3.5 MULE SHOE AND 3.5 S-13515.5# DRill PIPE 8/22/2002 00:00 - 00:30 0.50 CASE P INn CIRC, DRILL PIPE VOLUME 00:30 - 02:00 1.50 CASE P INn TRIP OUT AND STAND IN DERRICK 02:00 - 04:00 2.00 CASE P INn PICK UP BHA, 6.125 2643 PDC, 4 3/4 SPERRY DRill 1.5 BEND MOTOR, FLOAT SUB, 4 3/4 GRAMMAlRES, 4 3/4 DM, HANG OFF SUB,3 FLEX COlLAR,JAR 04:00 - 06:00 2.00 CASE P INT1 TRIPPING IN TO 5,125 06:00 - 07:00 1.00 CASE P INT1 CIRC, DRill PIPE VOLUME, TEST CSG WITH 3,500 PSI FOR 30 MIN. 07:00 - 08:00 1.00 CASE P INn DRilL CEMENT FROM 5125 TO 5204 08:00 - 09:00 1.00 CASE P INn DISPLACE HOLE WITH 9.5 MUD, MONITOR WEll 09:00 - 10:00 1.00 CASE P INT1 DRill SHOE AND CEMENT AND 30 FT OF NEW HOLE TO 5,246', MONITOR WEll 10:00 - 11 :00 1.00 CASE P INT1 FIT TEST WITH 9.5 MUD 4037 TVD, 490 PSI = 11.8 MUD WT. 11 :00 -13:30 2.50 CASE P INn DISPLACE WEll WITH 9.5 FLOW-PRO MUD 13:30 - 00:00 10.50 DRill P PROD1 DIRECTIONAL DRilL 5246' TO 6000' WITH 70 RPM 250 GALS PER MIN., 1,800 PSI 5/10 BIT WT, TQ 4,000, AST 5 ART 2.75 (ANGLE DROPPING AND CASANDRA CORR. SHOWING US 60 TO THE SOUTH) 8/23/2002 00:00 - 02:30 2.50 DRill N RREP PROD1 WORKING ON TOP DRIVE, CIRC. 02:30 - 03:30 1.00 DRilL N RREP PROD1 PUMPING OUT TO SHOE @ 5204, TO FINISH REPAIRS ON TOP DRIVE 03:30 - 06:00 2.50 DRill N RREP PROD1 WORKING ON TOP DRIVE 06:00 - 07:00 1.00 DRill P PROD1 TRIP TO BOTTOM Printed: 9/412002 10:53:07 AM ) BP Operations Summary Report Page 5 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date FrOm-To Hours Task Code NPT Phase [)escription ofOperatiqns 8/23/2002 07:00 - 08:30 1.50 DRILL P PROD1 DIRECTIONAL DRILL 6000' TO 6095' TVD 4088 WITH 70 RPM 250 GALS PER MIN., 1,800 PSI 5/10 BITWT, TO 4,000, (MOTOR NOT BUILDING OR TURNING RIGHT) 08:30 - 09:00 0.50 DRILL N DFAL PROD1 CIRC 09:00 - 10:00 1.00 DRILL N DFAL PROD1 PUMPING OUT TO SHOE, WITH FULL DRILLING RATE, 10:00 - 10:30 0.50 DRILL N DFAL PROD1 CIRC BOTTOMS UP, MONITOR WELL, SLUG PIPE 10:30 - 12:00 1.50 DRILL N DFAL PROD1 TRIP OUT TO BHA 12:00 - 14:00 2.00 DRILL N DFAL PROD1 UD JARS PULL BHA FOUND SLEEVE ON MOTOR HAD BACKED OFF, LAY DOWN MOTOR 14:00 -18:00 4.00 DRILL P PROD1 PULL WEAR RING, TEST BOPS 250-4,000 PSI FOR 5 MIN. TEST ANNULAR 250-2,500, ACCUM TEST, INSTALL WEAR RING, THE RIGHT TO WITNESS BOP TEST WAS WAVIER BY JOHN SPAULDING AOGCC. 18:00 - 21 :00 3.00 DRILL N DFAL PROD1 PICK UP NEW MOTOR, TRIPPING IN TO 5,500 TO SIDE TRACK WELL 21 :00 - 22:30 1.50 DRILL N DFAL PROD1 ORIENT 150 TO LEFT AND SIDETRACKING WELL 22:30 - 00:00 1.50 DRILL P PROD1 DIRECTIONAL DRILL 5510' TO 5700' WITH 70 RPM 250 GALS PER MIN., 1,900 PSI 5/10 BIT WT, TO 4,OOO,AST 1.25 ART.5 8/24/2002 00:00 - 00:00 24.00 DRILL P PROD1 DIRECTIONAL DRILL 5700' TO 8138' WITH 85 RPM 250 GALS PER MIN., 2600 PSI 5/10 BIT WT, TO 6,000 AST 6.75 ART 7.5 8/25/2002 00:00 - 10:00 10.00 DRILL P PROD1 DIRECTIONAL DRILL 8138' TO 9050' WITH 85 RPM 250 GALS PER MIN., 2800 PSI 5/10 BIT WT, TO 6,000 10:00 -12:00 2.00 CASE P COMP CIRC, THREE BOTTOMS 12:00 -15:30 3.50 CASE P COMP PUMP OUT TO SHOE FULL DRILLING RATE 15:30 -17:30 2.00 CASE P COMP TRIPPING TO BOTTOM, SET DOWN @ 5540 KICK OFF@ 5510, REAM AND WORKED KICK OFF, FROM 5443 TO 5630 17:30 - 19:00 1.50 CASE P COMP TRIPPING TO BOTTOM, HOLE TAKING MUD ON TRIP IN LOSS APP. 20 BBLS ON TRIP 19:00 - 22:00 3.00 CASE P COMP CIRC 4 BOTTOMS UP, WITH 2900 PSI 250 GALS MIN. 100 RPMS, FULL RETURNS 22:00 - 00:00 2.00 CASE P COMP PUMP OUT TO SHOE WITH FULL DRILLING RATE, DISPLACE HOLE WITH NEW MUD. 8/26/2002 00:00 - 01 :00 1.00 CASE P COMP PUMP OUT TO SHOE WITH FULL DRILLING RATE, DISPLACE HOLE WITH NEW MUD. 01 :00 - 05:00 4.00 CASE P COMP TRIP OUT AND LAY DOWN BHA 05:00 - 05:30 0.50 CASE P COMP RIG UP TO PICK UP 4.512.6# L-80 IBT SLOTTED LINER, PJSM 05:30 - 08:00 2.50 CASE P COMP PICKING UP 98 JTS OF 4.5 LINER AND BAKER HMC LINER HANGER, AND BAKER ZXP LINER TOP PACKER 08:00 - 10:30 2.50 CASE P COMP TRIPPING IN WITH LINER 10:30 -11:30 1.00 CASE P COMP DROP BALL ,PRESSURE UP TO 2300PSI,SET HANGER, AND LINER TOP PACKER, LINER TOP 5,094 LINER SHOE 9,042 11 :30 - 12:00 0.50 CASE P COMP CIRC AND DISPLACE HOLE WITH NEW MUD 12:00 - 13:00 1.00 CASE P COMP CUT DRILL LINE 13:00 - 14:00 1.00 CASE P COMP TRIP OUT WITH LINER RUNNING TOOLS 14:00 - 18:00 4.00 CASE P COMP PICK UP 3.5 SPACE OUT JTS, WHIPSTOCK AND MWD TOOLS 18:00 - 20:00 2.00 CASE P COMP TRIP IN WITH WHIPSTOCK 20:00 - 20:30 0.50 CASE P COMP ORIENT WHIPSTOCK 3 DEGREES TO LEFT, AND SET Printed: 9/412002 10:53:07 AM ) ) BP Opera.tiQnsSummaryReport Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From-To Hours. Task Code NPT Phase Description of Operations 8/26/2002 20:00 - 20:30 0.50 CASE P COMP WHIPSTOCK @ 4849 20:30 - 00:00 3.50 CASE P COMP CUTTING WINDOW @ 4849 TO 4867 WITH 250 GALS MIN. 1200 PSI100RPMS TOP OF WINDOW 4849 BOTTOM 4861 8/27/2002 00:00 - 00:30 0.50 CASE P COMP CUTTING WINDOW @ 4867 TO 4879 WITH 250 GALS MIN. 1200 PSI 100RPMS TOP OF WINDOW 4849 BOTTOM 4861 00:30 - 01 :30 1.00 CASE P COMP CIRC, WORK WINDOW, PUMP SWEEPS 01 :30 - 03:30 2.00 CASE P COMP TRIPPING OUT WITH MILLS 03:30 - 04:00 0.50 CASE P COMP LAYING DOWN BHA 04:00 - 04:30 0.50 CASE P COMP WASH OUT BOPS 04:30 - 06:30 2.00 CASE P COMP PICK UP BHA, 6.1252643 PDC, 4 3/4 SPERRY DRILL 1.5 BEND MOTOR, FLOAT SUB, 43/4 GRAMMAlRES, 4 3/4 OM, HANG OFF SUB,3 FLEX COLLAR,JAR 06:30 - 08:30 2.00 CASE P COMP TRIP IN TO WINDOW, WENT THRU WINDOW NO PROBLEM 08:30 - 00:00 15.50 DRILL P PROD2 DIRECTIONAL DRILL 4861' TO 6559' WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000 AST 3.25, ART 6.25 CROSS FAULT @ 5820 8/28/2002 00:00 - 03:30 3.50 DRILL P PROD2 DIRECTIONAL DRILL 6559' TO 6909' WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000, MUD WT. CUT TO 8.5 03:30 - 04:00 0.50 DRILL P PROD2 CIRC BOTTOMS, TO REMOVE CUTTING GAS MUD WENT 8.5 TO 9.0, RAISING MUD WT TO 9.6 04:00 - 04:30 0.50 DRILL P PROD2 DIRECTIONAL DRILL 6909' TO 6930 WITH 85 RPM 250 GALS PER MIN., 2300 PSI 5/10 BIT WT, TO 4,000, 04:30 - 05:00 0.50 DRILL P PROD2 CIRC. TILL WE GET 9.6 AROUND 05:00 - 00:00 19.00 DRILL P PROD2 DIRECTIONAL DRILL 6930 TO 8470' WITH 85 RPM 250 GALS PER MIN., 2600 PSI 5/10 BIT WT, TO 5,000, AST 7, ART 9.5 8/29/2002 00:00 - 04:30 4.50 DRILL P PROD2 DIRECTIONAL DRILL 8470' TO 9000' TO TVD 4042 WITH 85 RPM 250 GALS PER MIN., 2800 PSI 5/10 BIT WT, TO 6,000 ART 3 04:30 - 07:30 3.00 DRILL P PROD2 CIRC, FOUR BOTTOMS UP WITH 3200 PSI WITH 280 GALS MIN 100 RPMS 07:30 - 10:30 3.00 CASE P COMP PUMP OUT TO WINDOW,@ 4849, DISPLACING HOLE WITH NEW 10# MUD 10:30 - 11 :30 1.00 CASE N DPRB COMP CIRC, AND RAISE MUD WT IN CSG TO 10# 11 :30 - 12:00 0.50 CASE N DPRB COMP MONITOR WELL, WELL FLOWING 12:00 - 15:00 3.00 CASE N DPRB COMP CIRC @ 4849 AND RAISE MUD WT TO 10.5 15:00 - 17:00 2.00 CASE N DPRB COMP TRIP BACK TO BOTTOM, TIGHT SPOTS FROM 8000 TO 8800 17:00 - 21 :00 4.00 CASE N DPRB COMP CIRC ON BOTTOM AND RAISE MUD WT TO 10.7, MONITOR WELL, STILL HAD SMALL FLOW, CIRC AND RAISE MUD WT. TO 10.8+ 21 :00 - 00:00 3.00 CASE N DPRB COMP PUMPING OUT TO WINDOW,@ 4849 8/30/2002 00:00 - 00:30 0.50 CASE N DPRB COMP PUMPING OUT TO WINDOW,@ 4849 00:30 - 01 :00 0.50 CASE N DPRB COMP MONITOR WELL, WELL DEAD 01 :00 - 03:00 2.00 CASE P COMP TRIPPING OUT 03:00 - 04:00 1.00 CASE P COMP LAYING DOWN BHA 04:00 - 05:30 1.50 CASE P COMP PICKING UP BHA,#8 WHIPSTOCK HOOK, Printed: 9/412002 10:53:07 AM ~) ) BP Operations Summary Report Page 7 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From- To Hóurs . Tésk Code NPT Phase Description of Oþerations 8/30/2002 04:00 - 05:30 1.50 CASE P COMP 1 HWP,MWD,BUMPER SUB,JAR, 12 DC,15 HWP 05:30 - 06:30 1.00 CASE P CaMP TRIP IN TO TOP OF WHIPSTOCK 06:30 - 07:00 0.50 CASE P CaMP LATCH AND PULL WHIPSTOCK FREE 07:00 - 09:00 2.00 CASE P COMP CIRC, CHECK FOR GAS CUT MUD, NONE 09:00 - 11 :30 2.50 CASE N DPRB CaMP TRY TO PULL WHIPSTOCK WITH OUT SWABBING IN WELL, HOLE NOT TAKING PROPER MUD 11 :30 - 12:30 1.00 CASE N DPRB COMP TRIP BACK TO 4759 12:30 - 13:00 0.50 CASE N DPRB COMP CIRC, AND WORKING PIPE TRYING TO WEAR OUT RUBBER CUP SEAL ON WHIPSTOCK 13:00 - 16:30 3.50 CASE P CaMP TRIPPING OUT WITH WHIPSTOCK, SLOW 16:30 - 18:00 1.50 CASE P COMP BHA AND LAY DOWN WHIPSTOCK 18:00 - 19:30 1.50 CASE N DPRB CaMP TRIP BACK IN WITH DC AND DRILL PIPE TO 4788 19:30 - 20:30 1.00 CASE N DPRB COMP CIRC AND CHECK FOR GAS CUT MUD, NONE 20:30 - 21 :30 1.00 CASE N DPRB COMP TRIPPING OUT, HOLE TAKING PROPER AMOUNT OF MUD 21 :30 - 23:00 1.50 CASE P COMP LAYING DOWN BHA 23:00 - 23:30 0.50 CASE P CaMP RIG UP TO RUN 4.512.6# L-80 IBT SLOTTED LINER, PJSM 23:30 - 00:00 0.50 CASE P COMP PICKING UP, 4.512.6# L-80 IBT SLOTTED LINER 8/31/2002 00:00 - 02:30 2.50 CASE P CaMP PICKING UP, 4.512.6# L-80 IBT SLOTTED LINER, TOTAL 104 JTS, 4093 FT 02:30 - 04:30 2.00 CASE P COMP TRIPPING IN WITH LINER, WENT IN WINDOW NO PROBLEM SHOE @ 8964.66 DOWN WT 60,000 PICKUP WT 110,000 TOP LINER 4839 04:30 - 05:00 0.50 CASE P CaMP DROP BALL AND RELEASE FROM LINER WITH 2500 PSI, SHEAR BALL WITH 3500 PSI 05:00 - 05:30 0.50 CASE P CaMP CIRC BOTTOMS UP 05:30 - 06:00 0.50 CASE P CaMP MONITOR WELL 06:00 - 07:00 1.00 CASE P CaMP CUT DRILLING LINE 07:00 - 10:30 3.50 CASE P CaMP LAY DOWN EXCESS 3.5 DRILL PIPE 10:30 - 15:00 4.50 CASE P COMP PULL WEAR RING, TEST BOPS TO 2504000 PSI FOR 5 MIN. ANNULAR 250-2500 PSI FOR 5 MIN. AND ALL VALVES 2504000 PSI, NO FAILURES, THE RIGHT TO WITNESS TEST WAS WAIVED BY LOU GRIMALDI AOOGC 15:00 - 16:00 1.00 CASE P COMP FLUSH ALL MUD LINES AND PUMPS WITH WATER, SERVICE TOP DRIVE 16:00 - 18:00 2.00 CASE P CaMP TRIP IN HOLE WITH MULE SHOE AND 3.5 DRILL PIPE TO 4800 FT 18:00 - 20:00 2.00 CASE P CaMP CIRC AND DISPLACE WELL TO 11.0 NABR. PUMPED 100 BBLS NABR. FOLLOWED BY 30 BBLS 11.0 SPACER, FOLLOW BY 11.0 NABR. WHEN WE GOT SPACER AND CLEAN NABR. BACK ,SHUT DOWN. 20:00 - 00:00 4.00 CASE P CaMP RIG UP FILTRATION UNIT, CIRC, FILTER BRINE TO 33 NTU 9/1/2002 00:00 - 03:00 3.00 CASE P COMP LAYING DOWN 3.5 DRILL PIPE 03:00 - 05:00 2.00 CASE P COMP PULL WEAR RING AND INSTALL TEST PLUG, CHANGE TOP RAMS TO 2 7/8 AND TEST TO 4,000 05:00 - 11 :00 6.00 RUNCOM=> CaMP RIGGING UP TO RUN 27/8 TUBING AND ESP COMPLETION PICK UP CENTRILlFT MOTOR AND PUMPS 165 HP KME-1 2230 VOLTS 11 :00 -17:00 6.00 RUNCOM=> CaMP PICKING UP TUBING AND PUMPS SET @ 4262, XN NIPPLE 4147,GLM 2821,GLM 168, TOTAL 131 JTS 17:00 - 19:30 2.50 RUNCOM=> COMP PICK UP HANGER, AND TIE IN ESP LINE TO HANGER Printed: 9/412002 10:53:07 AM ') ') BP OperatiøllS.SUmmary'Repørt Page 80t 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-15 MPI-15 DRILL +COMPLETE DOYON DOYON 141 Start: 8/15/2002 Rig Release: 9/1/2002 Rig Number: 141 Spud Date: 8/15/2002 End: Date From-To Hours Task Code NPT Phase DeScriptionot Operations 9/1/2002 19:30 - 20:00 0.50 RUNCOf\tP COMP 20:00 - 22:00 2.00 RUNCOf\tP COMP 22:00 - 23:30 1.50 RUNCOf\tP COMP 23:30 - 00:00 0.50 RUNCOf\tP COMP LAY DOWN LANDING JT., TEST TWO WAY CHECK TO 1000 PSI CHANGE RAMS IN BOPS, NIPPLE DOWN NIPPLE UP, CIW 2 9/16 5,000# TREE AND TEST TO 5,000 PSI PULL TO WAY CHECK WITH DRY ROD AND INSTALL BACK PRESURE VALVE, SECURE TREE, RELEASE RIG FOR RIG MOVE @ 2400 HRS 9/1/2002 Printed: 91412002 10:53:07 AM Well: Field: API: Permit: ) ) MPI-15/ L 1 Milne Point Unit 50-029-23106-00/50-029-23106-60 202-152 / 202-153 Rig Accept: 08/15/02 Rig Spud: 08/16/02 Rig Release: 09/01/02 Drilling Rig: Doyon 141 POST RIG WORK 09/03/02 Approx. 130 bbls of 10.8-11.0 brine recovered from the well. Calculated recoverable brine above the pump was::::: 140 bbls. Well is freeze protected and ready to flow back to a tank for clean out of the rest of the brine. ) ) MILNE POINT. ALASKA TO: FROM: WELL# Main Category: Sub Category: Sub Category: Operation Date: Bixby/Hefley Lee Hulme MPI-15 RWO Brine recovery Pump 9/3/02 Date: 19/3/02 Objective: Recover Brine after rig move. Operation: Arrived location, held pre-job safety meeting. MIRU, pressure tested to 3500 psi. Start down the tubing with source water pressure through the ESP, caught fluid @ 1 bbl. Pumped 7.5 bbls until returns to the surface from the annulus. Regulated back pressure to 50 psi for the tubing volume. Continue pumping @ .35 bpm wI 400 psi as the source water turned the corner (25 bbls) and adjusted back pressure to compensate the weight loss of the fluid. Pumped 134 bbls of source water @ .35-.66 bpm wI 400-800 psi max (100 bbls away). Used well assist once we ran out of water and flowed to the tank until the weight dropped to 9.6. between shakeouts. Recovered to the vac truck ~ 130 bbls of 10.8 - 11.0 brine which was taken to MI for clean up and future use on H-13. RD to get freeze protect fluids. MIRU, PT to 3500 psi. Pumped 15 bbls diesel down the tubing for freeze protection RU to IA. PT to 3500 psi. Freeze protected the annulus with 65 bbls of dead crude. Conclusion: Approx. 130 bbls of 10.8-11.0 brine recovered from the well. Calculated recoverable brine above the pump was = 140 bbls. Well is freeze protected and ready to flow back to a tank for clean out of the rest of the brine. MSU330752 811900 846800 IDiesel RWO / Brine Recover / Pump Fesco = $ 2600.00 = $ 630.00 Diesel Used 115 bbls Methanol Used I None ó?Od-/5~ 30-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,471.47' MD Window / Kickoff Survey 5,510.00' MD (if applicable) Projected Survey: 9,050.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 0 C T C~: ~. C' ,. . Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPI MPI-15 ~ Job No. AKZZ22136, Surveyed: 25 August, 2002 Survey Report 26 September, 2002 Your Ref: API 500292310600 Surface Coordinates: 6009441.71 N, 551729.59 E (70026' 11.5455" N, 149034' 41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '~> Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62. 50ft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevation relative to Structure Reference: 62.50ft Sf-It:::tI'I'Y-5UI! b ~rLçTÑ.G~~~s:næ'TAvTC::^E!1\; A Halliburton Company Survey Ref: svy10189 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 Your Ref: API 500292310600 Job No. AKZZ22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured 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) (1t) (ft) (°/1 OOft) 5471.47 87.600 107.350 3983.07 4045.57 1535.028 2542.22 E 6007924.36 N 554282.40 E 2352.74 Tie On Point 5510.00 87.650 1 07.200 3984.67 4047.17 1546.45 8 2578.98 E 6007913.18 N 554319.24 E 0.410 2387.98 Window Point 5520.27 86.670 105.950 3985.18 4047.68 1549.38 8 2588.81 E 6007910.32 N 554329.09 E 15.454 2397.42 5564.14 86.180 107.560 3987.92 4050.42 1562.00 8 2630.74 E 6007897.99 N 554371.10 E 3.829 2437.65 5613.98 89.570 108.280 3989.76 4052.26 1577.328 2678.12 E 6007883.00 N 554418.59 E 6.953 2483.00 3990.14 1590.95 8 6007869.66 N '~ 5658.35 89.450 107.500 4052.64 2720.34 E 554460.90 E 1.779 2523.41 5705.52 90.310 106.780 3990.24 4052.74 1604.85 8 2765.42 E 6007856.08 N 554506.07 E 2.378 2566.63 5750.05 90.550 106.720 3989.91 4052.41 1617.698 2808.06 E 6007843.54 N 554548.80 E 0.556 2607.55 5799.31 90.430 102.860 3989.49 4051.99 1630.268 2855.67 E 6007831.30 N 554596.50 E 7.839 2653.44 5842.69 88.950 98.890 3989.72 4052.22 1638.448 2898.26 E 6007823.41 N 554639.15 E 9.767 2694.84 5891.21 88.580 95.840 3990.77 4053.27 1644.66 8 2946.37 E 6007817.53 N 554687.29 E 6.331 2741.93 5935.50 88.520 96.230 3991.89 4054.39 1649.31 8 2990.40 E 6007813.18 N 554731.35 E 0.891 2785.16 5985.91 88.030 96.930 3993.41 4055.91 1655.09 8 3040.45 E 6007807.75 N 554781.45 E 1.694 2834.24 6028.36 88.210 92.750 3994.80 4057.30 1658.678 3082.72 E 6007804.46 N 554823.74 E 9.851 2875.83 6076.89 87.290 90.470 3996.70 4059.20 1660.03 S 3131.19 E 6007803.44 N 554872.22 E 5.063 2923.84 6121.34 84.640 88.090 3999.83 4062.33 1659.47 S 3175.52 E 6007804.30 N 554916.54 E 8.004 2967.95 6169.86 84.450 88.530 4004.44 4066.94 1658.05 8 3223.80 E 6007806.06 N 554964.81 E 0.984 3016.08 6214.26 84.640 88.070 4008.67 4071.17 1656.748 3267.98 E 6007807.68 N 555008.98 E 1.117 3060.12 6263.81 84.080 87.520 4013.53 4076.03 1654.848 3317.25 E 6007809.92 N 555058.24 E 1.580 3109.30 6307.98 84.950 84.200 4017.76 4080.26 1651.678 3361 .10 E 6007813.40 N 555102.06 E 7.737 3153.22 6355.92 86.670 81.950 4021.26 4083.76 1645.90 8 3408.55 E 6007819.49 N 555149.48 E 5.898 3201.03 6398.93 87.040 81.960 4023.62 4086.12 1639.898 3451.08 E 6007825.80 N 555191.96 E 0.861 3243.96 6448.03 88.890 81.920 4025.36 4087.86 1633.01 S 3499.66 E 6007833.01 N 555240.49 E 3.769 3293.00 .~ 6491.78 89.260 82.460 4026.07 4088. 57 1627.078 3543.00 E 6007839.26 N 555283.79 E 1 .496 3336.74 6540.25 91.170 79.960 4025.89 4088.39 1619.668 3590.89 E 6007846.99 N 555331.63 E 6.491 3385.16 6585.22 92.220 73.800 4024.56 4087.06 1609.468 3634.65 E 6007857.50 N 555375.31 E 13.889 3429.79 6632.60 89.820 72.110 4023.71 4086.21 1595.58 8 3679.93 E 6007871.69 N 555420.50 E 6.195 3476.35 6678.05 89.690 71.790 4023.91 4086.41 1581.508 3723.15 E 6007886.08 N 555463.62 E 0.760 3520.88 6725.15 90.000 72.610 4024.04 4086.54 1567.10 8 3767.99 E 6007900.78 N 555508.36 E 1.861 3567.06 6770.24 90.680 70.420 4023.77 4086.27 1552.808 3810.75 E 6007915.38 N 555551.02 E 5.086 3611.16 6819.08 90.370 67.390 4023.32 4085.82 1535.238 3856.31 E 6007933.27 N 555596.46 E 6.236 3658.41 6863.66 90.180 63.350 4023.11 4085.61 1516.658 3896.83 E 6007952.12 N 555636.84 E 9.072 3700.77 6912.15 87.840 59.700 4023.94 4086.44 1493.54 8 3939.43 E 6007975.53 N 555679.29 E 8.940 3745.71 6956.37 88.890 56.660 4025.21 4087.71 1470.248 3976.99 E 6007999.09 N 555716.68 E 7.270 3785.65 7006.39 87.170 53.600 4026.93 4089.43 1441.678 4018.00 E 6008027.95 N 555757.49 E 7.014 3829.62 26 September, 2002 - 9:30 Page2of5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI - MPI-15 Your Ref: API 500292310600 Job No. AKZZ22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured 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) (°/1 OOft) 7049.70 87.420 50.660 4028.97 4091.47 1415.11 8 4052.14 E 6008054.74 N 555791.45 E 6.805 3866.55 7098.70 88.890 48.000 4030.55 4093.05 1383.20 8 4089.28 E 6008086.91 N 555828.37 E 6.200 3907.06 7143.07 90.370 46.060 4030.83 4093.33 1352.96 S 4121.75E 6008117.37 N 555860.62 E 5.499 3942.72 7192.64 89.630 41.250 4030.83 4093.33 1317.108 4155.96 E 6008153.46 N 555894.58 E 9.818 3980.76 7235.47 90.180 38.650 4030.91 4093.41 1284.27 8 4183.45 E 6008186.48 N 555921.85 E 6.205 4011.79 7284.87 90.250 35.680 4030.72 4093.22 1244.91 8 4213.29 E 6008226.05 N 555951.42 E 6.014 4045.88 ~' 7327.42 88.460 34.020 4031.20 4093.70 1210.00 S 4237.61 E 6008261.13 N 555975.49 E 5.737 4073.98 7376.05 88.520 30.160 4032.48 4094.98 1168.828 4263.43 E 6008302.49 N 556001.02 E 7.936 4104.28 7419.80 87.170 27.270 4034.13 4096.63 1130.48 S 4284.43 E 6008340.97 N 556021.76 E 7.287 4129.47 7469.99 87.790 23.550 4036.33 4098.83 1085.20 8 4305.94 E 6008386.40 N 556042.95 E 7.507 4155.96 7513.73 86.980 19.250 4038.33 4100.83 1044.53 8 4321.88 E 6008427.18 N 556058.61 E 9.994 4176.39 7566.67 87.410 16.390 4040.92 4103.42 994.198 4338.06 E 6008477.63 N 556074.44 E 5.457 4198.14 7606.45 89.880 15.200 4041 .86 4104.36 955.93 8 4348.88 E 6008515.97 N 556085.00 E 6.892 4213.22 7657.96 90.060 15.920 4041 .89 4104.39 906.31 8 4362.70 E 6008565.68 N 556098.47 E 1 .441 4232.55 7700.66 90.620 13.260 4041. 64 4104.14 864.99 8 4373.46 E 6008607.08 N 556108.94 E 6.366 4247.89 7751.17 90.000 10.370 4041.36 4103.86 815.568 4383.80 E 6008656.58 N 556118.94 E 5.852 4263.75 7791.85 89.020 7.670 4041.71 4104.21 775.38 8 4390.17 E 6008696.79 N 556125.04 E 7.061 4274.62 7843.14 89.080 4.900 4042.56 4105.06 724.41 8 4395.79 E 6008747.80 N 556130.30 E 5.401 4285.95 7885.38 86.240 4.330 4044.29 4106.79 682.358 4399.18 E 6008789.89 N 556133.40 E 6.857 4294.07 7935.43 88.150 1.970 4046.74 4109.24 632.44 8 4401.93 E 6008839.81 N 556135.80 E 6.062 4302.43 7979.08 90.860 0.740 4047.11 4109.61 588.81 8 4402.96 E 6008883.45 N 556136.53 E 6.818 4308.38 8028.86 91.780 0.360 4045.97 4108.47 539.05 8 4403.44 E 6008933.22 N 556136.66 E 1.999 4314.47 8072.03 89.750 359.300 4045.39 4107.89 495.88 8 4403.31 E 6008976.38 N 556136.23 E 5.305 4319.21 ~ 8123.42 90.180 359.330 4045.42 4107.92 444.50 8 4402.70 E 6009027.76 N 556135.26 E 0.839 4324.40 8164.22 90.620 358.870 4045.14 4107.64 403.70 8 4402.05 E 6009068.55 N 556134.34 E 1.560 4328.37 8217.41 91.970 359.230 4043.93 4106.43 350.54 8 4401.17 E 6009121.71 N 556133.09 E 2.627 4333.49 8259.05 91.850 358.610 4042.55 4105.05 308.93 8 4400.39 E 6009163.31 N 556132.02 E 1.516 4337.41 8309.59 92.090 359.000 4040.81 4103.31 258.43 8 4399.33 E 6009213.80 N 556130.61 E 0.906 4342.06 8351.59 91.970 358.830 4039.32 4101.82 216.468 4398.54 E 6009255.76 N 556129.53 E 0.495 4346.01 8402.78 91.660 357.850 4037.70 4100.20 165.32 8 4397.06 E 6009306.89 N 556127.69 E 2.007 4350.31 8444.53 93.020 357.630 4036.00 4098.50 123.648 4395.41 E 6009348.56 N 556125.75 E 3.300 4353.38 8494.92 92.830 356.660 4033.42 4095.92 73.38 8 4392.91 E 6009398.80 N 556122.90 E 1.959 4356.56 8537.62 92.590 356.310 4031.40 4093.90 30.81 8 4390.29 E 6009441.36 N 556119.99 E 0.993 4358.77 8587.99 90.980 356.440 4029.84 4092.34 19.44 N 4387.11 E 6009491.58 N 556116.46E 3.207 4361.27 8628.44 88.830 356.520 4029.90 4092.40 59.81 N 4384.62 E 6009531.93 N 556113.69 E 5.319 4363.36 26 September, 2002 - 9:30 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 Your Ref: API 500292310600 Job No. AKZZ22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured 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) 8681. 90 88.220 356.890 4031 .28 4093.78 113.16N 4381.55 E 6009585.26 N 556110.25 E 1.334 4366.33 8723.24 86.670 356.660 4033.12 4095.62 154.39 N 4379.23 E 6009626.48 N 556107.64 E 3.790 4368.68 8773.07 87.350 356.470 4035.72 4098.22 204.07 N 4376.25 E 6009676.13 N 556104.32 E 1.417 4371.32 8815.85 88.210 356.740 4037.38 4099.88 246.74 N 4373.72 E 6009718.78 N 556101.49 E 2.107 4373.62 8866.40 87.660 357.110 4039.20 4101.70 297.18 N 4371.01 E 6009769.20 N 556098.43 E 1.311 4376.62 8909.17 88.150 357.620 4040.76 4103.26 339.88 N 4369.04 E 6009811.89 N 556096.17 E 1.653 4379.49 ........" 8984.24 89.140 357.250 4042.54 4105.04 414.85 N 4365.68 E 6009886.83 N 556092.29 E 1 .408 4384.61 9050.00 89.140 357.250 4043.53 4106.03 480.53 N 4362.53 E 6009952.49 N 556088. 68 E 0.000 4388.89 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.520° (True). Magnetic Declination at Surface is 25. 733°( 15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9050.00ft., The Bottom Hole Displacement is 4388.91ft., in the Direction of 83.714° (True). Comments Measured Depth (It) Station Coordinates TVD Northings Eastings (It) (ft) (ft) '~' Comment 5471.47 5510.00 9050.00 4045.57 4047.17 4106.03 1535.02 S 1546.45 S 480.53 N 2542.22 E 2578.98 E 4362.53 E Tie On Point Window Point Projected Survey 26 September, 2002 - 9:30 Page 4 of 5 DrillQuest 3.03.02.002 Milne Point Unit Survey tool proqram for MPI-15 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 172.00 0.00 172.00 26 September, 2002 - 9:30 To Measured Vertical Depth Depth (ft) (ft) 172.00 9050.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 Your Ref: API 500292310600 Job No. AKZZ22136, Surveyed: 25 August, 2002 BPXA Survey Tool Description 172.00 Tolerable Gyro(MPI-15 PB1) 4106.03 AK-6 BP _IFR-AK(MPI-15 PB1) '~' '-,/ Page 5 of 5 DrillQuest 3.03.02.002 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 5,471.47' MD Window / Kickoff Survey 5,510.00' MD (if applicable) Projected Survey: 9,050.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) aOd-J5;) 30-Sep-02 r-,!'" 1. ," ,.'~. r ~'. " U \... ¡ \..:!...~ L~" Cl >f)' - ~ rrs Sperry-Sun Drilling Services /~ Milne Point Unit BPXA Milne Point MPI MPI-15 MWD Job No. AKMW22136, Surveyed: 25 August, 2002 Survey Report 26 September, 2002 /~, Your Ref: API 500292310600 Surface Coordinates: 6009441.71 N, 551729.59 E (70026' 11.5455" N, 149034'41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62.5Oft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevation relative to Structure Reference: 62.50ft !5pe1'-'''''Y-I5UI1 D A' L L.' NGS fa... V I è. S A Halliburton Company Survey Ref: svy10190 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 MWD Your Ref: API 500292310600 Job No. AKMW22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5471.47 87.600 107.480 3983.13 4045.63 1494.155 2555.43 E 6007965.32 N 554295.33 E 2370.48 Tie On Point 5510.00 87.650 107.200 3984.73 4047.23 1505.63 S 2592.18 E 6007954.10 N 554332.15 E 0.738 2405.70 Window Point 5520.27 86.670 106.070 3985.24 4047.74 1508.56 5 2602.01 E 6007951.23 N 554342.00 E 14.554 2415.13 5564.14 86.180 107.720 3987.97 4050.47 1521.295 2643.90 E 6007938.80 N 554383.98 E 3.916 2455.32 5613.98 89.570 108.450 3989.82 4052.32 1536.755 2691.24 E 6007923.67 N 554431.42 E 6.957 2500.61 .'~ 5658.35 89.450 107.830 3990.20 4052.70 1550.56 5 2733.40 E 6007910.15 N 554473.68 E 1.423 2540.95 5705.52 90.310 107.150 3990.30 4052.80 1564.745 2778.39 E 6007896.28 N 554518.77 E 2.324 2584.05 5750.05 90.550 106.890 3989.96 4052.46 1577.775 2820.97 E 6007883.54 N 554561.44 E 0.795 2624.89 5799.31 90.430 103.170 3989.54 4052.04 1590.54 5 2868.53 E 6007871.10 N 554609.09 E 7.555 2670.71 5842.69 88.950 99.090 3989.78 4052.28 1598.91 5 2911.09 E 6007863.03 N 554651.70 E 10.005 2712.04 5891.21 88.580 96.040 3990.82 4053.32 1605.305 2959.17 E 6007856.97 N 554699.82 E 6.331 2759.10 5935.50 88.520 96.490 3991.95 4054.45 1610.135 3003.18 E 6007852.45 N 554743.87 E 1.025 2802.28 5985.91 88.030 97.140 3993.46 4055.96 1616.11 5 3053.21 E 6007846.82 N 554793.94 E 1.614 2851.32 6028.36 88.210 92.910 3994.86 4057.36 1619.835 3095.47 E 6007843.39 N 554836.22 E 9.968 2892.88 6076.89 87.290 90.650 3996.76 4059.26 1621.33 S 3143.93 E 6007842.22 N 554884.69 E 5.025 2940.87 6121.34 84.640 88.100 3999.89 4062.39 1620.855 3188.26 E 6007843.01 N 554929.02 E 8.263 2984.97 6169.86 84.450 88.580 4004.50 4067.00 1619.455 3236.54 E 6007844.75 N 554977.28 E 1.060 3033.10 6214.26 84.640 87.970 4008. 72 4071.22 1618.125 3280.72 E 6007846.38 N 555021.45 E 1 .433 3077.14 6263.81 84.080 87.450 4013.59 4076.09 1616.155 3329.99 E 6007848.70 N 555070.71 E 1.539 3126.32 6307.98 84.950 84.130 4017.82 4080.32 1612.92 S 3373.83 E 6007852.23 N 555114.53 E 7.737 3170.25 6355.92 86.670 81.880 4021.32 4083.82 1607.105 3421.28 E 6007858.38 N 555161.94 E 5.898 3218.05 6398.93 87.040 81.840 4023.68 4086.18 1601.025 3463.79 E 6007864.75 N 555204.41 E 0.865 3260.98 .~. 6448.03 88.890 81.680 4025.42 4087.92 1593.995 3512.36 E 6007872.12 N 555252.92 E 3.782 3310.02 6491.78 89.260 82.130 4026.13 4088.63 1587.835 3555.66 E 6007878.58 N 555296.18 E 1.332 3353.75 6540.25 91.170 79.530 4025.95 4088.45 1580.105 3603.51 E 6007886.64 N 555343.97 E 6.656 3402.16 6585.22 92.220 73.380 4024.61 4087.11 1569.58 5 3647.19 E 6007897.46 N 555387.58 E 13.868 3446.75 6632.60 89.820 71.700 4023.77 4086.27 1555.37 S 3692.37 E 6007911.99 N 555432.66 E 6.183 3493.25 6678.05 89.690 71.410 4023.97 4086.47 1540.99 5 3735.49 E 6007926.67 N 555475.67 E 0.699 3537.71 6725.15 90.000 72.230 4024.09 4086.59 1526.29 5 3780.23 E 6007941.67 N 555520.32 E 1.861 3583.83 6i'70.24 90.680 70.110 4023.83 4086.33 1511.745 3822.91 E 6007956.52 N 555562.89 E 4.938 3627.87 6819.08 90.370 67.080 4023.38 4085.88 1493.925 3868.37 E 6007974.66 N 555608.23 E 6.236 3675.06 6863.66 90.180 63.080 4023.16 4085.66 1475.145 3908.79 E 6007993.72 N 555648.52 E 8.983 3717.34 6912.15 87.840 59.450 4024.00 4086.50 1451.84 5 3951.29 E 6008017.31 N 555690.86 E 8.905 3762.20 6B56.37 88.890 56.570 4025.26 4087.76 1428.42 S 3988.78 E 6008040.99 N 555728.18 E 6.930 3802.09 7006.39 87.170 53.580 4026.98 4089.48 1399.81 S 4029.76 E 6008069.89 N 555768.96 E 6.893 3846.04 -----_..~--_._--+.._- .~---.-._._.~._._--- 26 September, 2002 - 10:07 Page 20'5 DrillQlJest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 MWD Your Ref: API 500292310600 Job No. AKMW22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured 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) 7049.70 87.420 50.690 4029.03 4091.53 1373.26 8 4063.91 E 6008096.67 N 555802.93 E 6.690 3882.97 7098.70 88.890 48. 090 4030.61 4093.11 1341.388 4101.09E 6008128.81 N 555839.88 E 6.093 3923.50 7143.07 90.370 46.090 4030.89 4093.39 1311.188 4133.58 E 6008159.24 N 555872.16 E 5.607 3959.20 7192.64 89.630 41.280 4030.89 4093.39 1275.34 8 4167.81 E 6008195.31 N 555906.14 E 9.818 3997.25 7235.47 90.180 38.730 4030.96 4093.46 1242.54 8 4195.34 E 6008228.30 N 555933.45 E 6.091 4028.31 .'-' 7284.87 90.250 35.730 4030.78 4093.28 1203.21 S 4225.22 E 6008267.84 N 555963.06 E 6.074 4062.44 7327.42 88.460 34.100 4031.26 4093.76 1168.328 4249.57 E 6008302.89 N 555987.16 E 5.689 4090.57 7376.05 88.520 30.160 4032.54 4095.04 1127.16 S 4275.42 E 6008344.23 N 556012.73 E 8.100 4120.90 7419.80 87.170 27.390 4034.18 4096.68 1088.85 8 4296.47 E 6008382.69 N 556033.50 E 7.039 4146.13 7469.99 87.790 23.550 4036.39 4098.89 1043.598 4318.02 E 6008428.10 N 556054.75 E 7.743 4172.66 7513.73 86.980 19.410 4038.39 4100.89 1002.94 8 4334.02 E 6008468.86 N 556070.46 E 9.635 4193.14 7566.67 87.410 16.560 4040.98 4103.48 952.65 8 4350.34 E 6008519.26 N 556086.44 E 5.438 4215.04 7606.45 89.880 15.330 4041.92 4104.42 914.41 S 4361.27 E 6008557.57 N 556097.10 E 6.936 4230.21 7657.96 90.060 16.050 4041.95 4104.45 864.82 8 4375.20 E 6008607.25 N 556110.68 E 1 .441 4249.65 7700.66 90.620 13.440 4041.69 4104.19 823.53 8 4386.07 E 6008648.62 N 556121.26 E 6.251 4265.10 7751.17 90.000 10.590 4041 .42 4103.92 774.148 4396.58 E 6008698.09 N 556131.43 E 5.774 4281.12 7791.85 89.020 7.770 4041.77 4104.27 733.98 8 4403.07 E 6008738.28 N 556137.64 E 7.338 4292.10 7843.14 89.080 5.050 4042.62 4105.12 683.03 8 4408.79 E 6008789.28 N 556143.01 E 5.304 4303.54 7885.38 86.240 4.490 4044.34 4106.84 640.97 8 4412.30 E 6008831.36 N 556146.23 E 6.853 4311.78 7935.43 88.150 2.130 4046.79 4109.29 591.07 8 4415.19 E 6008881.28 N 556148.77 E 6.062 4320.27 7979.08 90.860 0.830 4047.17 4109.67 547.448 4416.31 E 6008924.91 N 556149.59 E 6.886 4326.32 8028.86 91.780 0.370 4046.02 4108.52 497.68 8 4416.84 E 6008974.68 N 556149.77 E 2.066 4332.45 .~ 8072.03 89.750 359.300 4045.45 4107.95 454.52 8 4416.71 E 6009017.84 N 556149.35 E 5.315 4337.20 8123.42 90.180 359.910 4045.48 4107.98 403.138 4416.36 E 6009069.22 N 556148.64 E 1.452 4342.65 8164.22 90.620 359.230 4045.19 4107.69 362.338 4416.05 E 6009110.02 N 556148.05 E 1.985 4346.95 8217.41 91.970 359.750 4043.99 4106.49 309.168 4415.58 E 6009163.19 N 556147.21 E 2.720 4352.48 8259.05 91.850 358.940 4042.60 4105.10 267.54 8 4415.10 E 6009204.80 N 556146.44 E 1.965 4356.70 8309.59 92.090 359.210 4040.87 4103.37 217.048 4414.29 E 6009255.29 N 556145.27 E 0.715 4361.59 8351.59 91.970 359.060 4039.38 4101.88 175.07 8 4413.65 E 6009297.26 N 556144.35 E 0.457 4365.70 8402.78 91.660 358.010 4037.76 4100.26 123.928 4412.34 E 6009348.39 N 556142.69 E 2.138 4370.17 8444.53 93.020 357.890 4036.05 4098.55 82.24 8 4410.85 E 6009390.07 N 556140.91 E 3.270 4373.39 8494.92 92.830 356.820 4033.48 4095.98 31.97 8 4408.53 E 6009440.32 N 556138.24 E 2.154 4376.76 8537.62 92.590 356.360 4031.46 4093.96 10.61 N 4405.99 E 6009482.88 N 556135.40 E 1.214 4379.04 8587.99 90.980 356.310 4029.89 4092.39 60.85 N 4402.77 E 6009533.10 N 556131.84 E 3.198 4381.51 8628.44 88.830 356.340 4029.96 4092.46 101.21 N 4400.18 E 6009573.44 N 556128.96 E 5.316 4383.49 -----.- -.----,.- ....___.h-'__~_~---_.'----- 26 September, 2002 - 10:07 Page 3 of5 Dril/Quest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 MWD Your Ref: API 500292310600 Job No. AKMW22136, Surveyed: 25 August, 2002 BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8681.90 88.220 356.540 4031.34 4093.84 154.55 N 4396.86 E 6009626.76 N 556125.28 E 1.201 4386.22 8723.24 86.670 356.310 4033.18 4095.68 195.77 N 4394.29 E 6009667.96 N 556122.41 E 3.790 4388.31 8773.07 87.350 356.050 4035.78 4098.28 245.42 N 4390.97 E 6009717.58 N 556118.76 E 1.461 4390.62 8815.85 88.210 356.380 4037.44 4099.94 288.08 N 4388.15 E 6009760.22 N 556115.64 E 2.153 4392.63 8866.40 87.660 356.790 4039.26 4101.76 338.50 N 4385.14 E 6009810.62 N 556112.28 E 1.357 4395.33 8909.17 88.150 357.300 4040.82 4103.32 381.19 N 4382.94 E 6009853.29 N 556109.78 E 1.653 4397.96 8984.24 89.140 356.940 4042.60 4105.10 456.14 N 4379.17 E 6009928.21 N 556105.49 E 1 .403 4402.67 9050.00 89.140 356.940 4043.58 4106.08 521.80 N 4375.66 E 6009993.85 N 556101.52 E 0.000 4406.59 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.520° (True). Magnetic Declination at Surface is 25.733°(15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 9050.00ft., The Bottom Hole Displacement is 4406.66ft., in the Direction of 83.200° (True). Comments /-, Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5471.47 5510.00 9050.00 4045.63 4047.23 4106.08 1494.15 S 1505.63 S 521.80 N 2555.43 E 2592.18 E 4375.66 E Tie On Point Window Point Projected Survey ----~-~---_._--_._-.-.<_.. .-.--.----..------ 26 September, 2002 - 10:07 Page 4 0'5 DrillQllest 3.03.02.002 Milne Point Unit Survey tool Droaram for MPI-15 MWD From Measured Vertical Depth Depth (ft) (ft) ~. 0.00 172.00 0.00 172.00 26 September, 2002 - 10:07 To Measured Vertical Depth Depth (ft) (ft) 172.00 9050.00 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 MWD Your Ref: API 500292310600 Job No. AKMW22136, Surveyed: 25 August, 2002 BPXA Survey Tool Description 172.00 Tolerable Gyro(MPI-15 PB1 MWD) 4106.08 MWD Magnetic(MPI-15 PB1 MWD) PageS of5 DrillQlIest 3.03.02.002 ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD I M D (if applicable) 6,095.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( 5) 30-Sep-02 ~ O~-J6;¿ O¡''''''T r ,-, I" \". ,,: L" i v~': Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPI MPI-15 PB1 ~ Job No. AKZZ22136, Surveyed: 23 August, 2002 Survey Report 26 September, 2002 Your Ref: API 500292310670 Surface Coordinates: 6009441.71 N, 551729.59 E (70026' 11.5455" N, 149034' 41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62.50ft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevation relative to Structure Reference: 62.50ft SpE1I'I'Y-SUI} ~:n:frCr:: I NG,w!:i'~ ÄvTE~e's A Halliburton Company Survey Ref: svy10161 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 PB1 Your Ref: API 500292310670 Job No. AKZZ22136, Surveyed: 23 August, 2002 BPXA Milne Point Unit Measured 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) e/100ft) 0.00 0.000 0.000 -62.50 0.00 0.00 N 0.00 E 6009441.71 N 551729.59 E 0.00 Tolerable Gyro 172.00 0.240 178.000 109.50 172.00 0.36 S 0.01 E 6009441.35 N 551729.61 E 0.140 -0.03 AK-6 BP _IFR-AK 291.58 0.470 166.210 229.08 291.58 1.09 S 0.14 E 6009440.62 N 551729.74 E 0.201 0.01 382.49 0.870 162.780 319.98 382.48 2.11 S 0.43 E 6009439.61 N 551730.04 E 0.442 0.19 469.23 1.190 161.270 406.71 469.21 3.59 S 0.92 E 6009438.13 N 551730.53 E 0.370 0.50 558.65 3.740 134.320 496.04 558.54 6.51 S 3.30 E 6009435.23 N 551732.94 E 3.056 2.55 ~ 650.23 5.130 130.440 587.34 649.84 11 .25 S 8.55 E 6009430.52 N 551738.22 E 1.552 7.23 741.16 6.140 130.240 677.83 740.33 17.03 S 15.36 E 6009424.79 N 551745.07 E 1.111 13.34 834.40 7.640 124.390 770.40 832.90 23.75 S 24.28 E 6009418.13 N 551754.04 E 1 .774 21.45 927.09 10.600 128.900 861.91 924.41 32.59 S 36.00 E 6009409.37 N 551765.82 E 3.283 32.10 1020.58 14.240 130.160 953.19 1015.69 45.41 S 51.49 E 6009396.66 N 551781.39 E 3.904 46.04 1115.08 17.730 128.170 1044.03 1106.53 61.80 S 71.69 E 6009380.41 N 551801.71 E 3.738 64.26 1208.00 23.070 135.120 1131.10 1193.60 83.46 S 95.68 E 6009358.91 N 551825.85 E 6.301 85.65 1303.40 31.860 138.150 1215.67 1278.17 115.53 S 125.73 E 6009327.06 N 551856.12 E 9.327 111.89 1396.83 31.850 138.190 1295.03 1357.53 152.27 S 158.61 E 6009290.54 N 551889.26 E 0.025 140.42 1491.12 32.260 137.840 1374.94 1437.44 189.47 S 192.09 E 6009253.58 N 551922.99 E 0.477 169.48 1586.53 31.790 138.410 1455.83 1518.33 227.14 S 225.86 E 6009216.14 N 551957.02 E 0.586 198.79 1677.64 31 .650 139.080 1533.33 1595.83 263.15 S 257.45 E 6009180.35 N 551988.86 E 0.416 226.11 1773.51 30.480 135.890 1615.46 1677.96 299.62 S 290.85 E 6009144.12 N 552022.52 E 2.106 255.18 1864.32 29.580 134.340 1694.08 1756.58 331.82 S 322.92 E 6009112.14 N 552054.80 E 1.308 283.41 1959.84 31.320 130.800 1776.43 1838.93 364.52 S 358.58 E 6009079.68 N 552090.69 E 2.616 315.15 2054.97 33.960 128.790 1856.53 1919.03 397.33 S 398.01 E 6009047.15 N 552130.35 E 3.000 350.63 2150.44 34.360 125.030 1935.54 1998.04 429.51 S 440.86 E 6009015.27 N 552173.42 E 2.250 389.57 ,~ j' 2246.36 35.120 118.950 2014.38 2076.88 458.41 S 487.19 E 6008986.69 N 552219.94 E 3.697 432.34 2341.58 36.000 117.980 2091.84 2154.34 484.80 S 535.87 E 6008960.64 N 552268.81 E 1.098 477.73 2436.01 35.890 118.310 2168.29 2230.79 510.94 S 584.74 E 6008934.84 N 552317.86 E 0.236 523.34 2529.00 36.170 117.570 2243.49 2305.99 536.57 S 633.07 E 6008909.54 N 552366.36 E 0.557 568.47 2622.23 36.070 117.670 2318.80 2381.30 562.05 S 681.76 E 6008884.40 N 552415.23 E 0.125 613.97 2715.16 34.400 119.730 2394.71 2457.21 587.77 S 728.79 E 6008859.01 N 552462.44 E 2.205 657.80 2810.13 34.980 120.760 2472.80 2535.30 615.00 S 775.48 E 6008832.10 N 552509.32 E 0.868 701.12 2903.85 35.240 121 .420 2549.46 2611.96 642.84 S 821.64 E 6008804.59 N 552555.67 E 0.491 743.84 2996.62 34.510 122.810 2625.57 2688.07 671.03 S 866.57 E 6008776.71 N 552600.79 E 1.163 785.30 3025.50 34.730 123.380 2649.34 2711.84 679.99 S 880.31 E 6008767.84 N 552614.60 E 1.356 797.95 3088.57 34.340 123.110 2701.30 2763.80 699.59 S 910.21 E 6008748.45 N 552644.64 E 0.664 825.45 3182.46 34.410 122.710 2778.79 2841.29 728.39 S 954.72 E 6008719.96 N 552689.34 E 0.252 866.42 26 September, 2002 - 9:14 Page 2 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 PB1 Your Ref: API 500292310670 Job No. AKZZ22136, Surveyed: 23 August, 2002 BPXA Milne Point Unit Measured 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) e/100ft) 3276.71 34.340 123.030 2856.58 2919.08 757.27 S 999.41 E 6008691.39 N 552734.23 E 0.206 907.57 3371.81 34.510 122.680 2935.02 2997.52 786.44 S 1044.58 E 6008662.54 N 552779.60 E 0.274 949.15 3464.19 34.200 122.400 3011.29 3073.79 814.48 S 1088.52 E 6008634.80 N 552823.74 E 0.377 989.65 3557.50 33.940 122.140 3088.58 3151.08 842.39 S 1132.72 E 6008607.20 N 552868.13 E 0.319 1030.42 3649.70 33.960 122.370 3165.07 3227.57 869.87 S 1176.27 E 6008580.02 N 552911.86 E 0.141 1070.58 3745.36 33.930 120.500 3244.42 3306.92 897.73 S 1221.84 E 6008552.48 N 552957.63 E 1.092 1112.72 --.v 3838.08 34.150 120.830 3321.26 3383.76 924.20 S 1266.48 E 6008526.32 N 553002.45 E 0.310 1154.09 3931 .49 37.770 120.920 3396.85 3459.35 952.34 S 1313.55 E 6008498.50 N 553049.72 E 3.876 1197.68 4024.15 42.320 119.210 3467.77 3530.27 982.16 S 1365.15 E 6008469.04 N 553101.52 E 5.052 1245.59 4117.98 46.880 118.100 3534.56 3597.06 1013.72 S 1422.96 E 6008437.88 N 553159.55 E 4.930 1299.46 4212.10 48.730 118.480 3597.78 3660.28 1046.77 S 1484.36 E 6008405.26 N 553221.17 E 1.988 1356.74 4304.12 52.140 118.460 3656.38 3718.88 1080.58 S 1546.71 E 6008371.88 N 553283.76 E 3.706 1414.88 4400.14 55.760 117.220 3712.88 3775.38 1116.81 S 1615.35 E 6008336.13 N 553352.65 E 3.912 1478.99 4492.41 59.11 0 117.480 3762.54 3825.04 1152.54 S 1684.41 E 6008300.88 N 553421.95 E 3.638 1543.58 4588.37 62.760 116.780 3809.15 3871.65 1190.77 S 1759.05 E 6008263.17 N 553496.85 E 3.857 1613.42 4681.10 66.640 116.380 3848.77 3911.27 1228.27 S 1834.01 E 6008226.19 N 553572.08 E 4.202 1683.68 4777.56 71.160 114.310 3883.49 3945.99 1266.76 S 1915.33 E 6008188.27 N 553653.66 E 5.095 1760.13 4871.05 72.700 113.700 3912.49 3974.99 1302.91 S 1996.51 E 6008152.68 N 553735.09 E 1.760 1836.72 4960.44 76.180 113.420 3936.46 3998.96 1337.33 S 2075.44 E 6008118.81 N 553814.25 E 3.905 1911.25 5056.25 79.240 113.860 3956.85 4019.35 1374.86 S 2161.19 E 6008081.87 N 553900.26 E 3.225 1992.22 5155.11 84.940 116.320 3970.46 4032.96 1416.38 S 2249.82 E 6008040.97 N 553989.18 E 6.270 2075.60 5237.71 84.580 113.550 3978.00 4040.50 1451.05 S 2324.40 E 6008006.82 N 554063.99 E 3.368 2145.79 5283.30 90.000 114.430 3980.15 4042.65 1469.56 S 2365.98 E 6007988.60 N 554105.71 E 12.044 2185.02 .~ 5343.37 89.880 111.170 3980.22 4042.72 1492.84 S 2421.35 E 6007965.70 N 554161.24E 5.431 2237.41 5376.13 89.570 110.850 3980.38 4042.88 1504.58 S 2451.94 E 6007954.17 N 554191.90 E 1.360 2266.47 5427.68 88.090 108.020 3981.43 4043.93 1521.73 S 2500.53 E 6007937.36 N 554240.62 E 6.194 2312.82 5471.47 87.600 107.350 3983.07 4045.57 1535.02 S 2542.22 E 6007924.36 N 554282.40 E 1.895 2352.74 5519.97 87.660 107.160 3985.08 4047.58 1549.40 S 2588.50 E 6007910.31 N 554328.77 E 0.411 2397.10 5565.96 89.380 107.250 3986.27 4048.77 1562.99 S 2632.42 E 6007897.01 N 554372.78 E 3.745 2439.20 5619.66 88.770 105.790 3987.13 4049.63 1578.26 S 2683.89 E 6007882.10 N 554424.36 E 2.946 2488.63 5660.42 88.460 106.200 3988.12 4050.62 1589.49 S 2723.06 E 6007871.15 N 554463.61 E 1.261 2526.28 5708.58 86.920 106.470 3990.06 4052.56 1603.02 S 2769.24 E 6007857.93 N 554509.88 E 3.246 2570.63 5751.73 89.200 104.590 3991.52 4054.02 1614.57 S 2810.78 E 6007846.68 N 554551.51 E 6.847 2610.61 5801.94 88.580 104.320 3992.49 4054.99 1627.10 S 2859.40 E 6007834.48 N 554600.20 E 1.347 2657.50 5843.58 86.490 104.830 3994.29 4056.79 1637.57 S 2899.66 E 6007824.29 N 554640.53 E 5.166 2696.32 26 September, 2002 - 9:14 Page 3 of 5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI - MPI-15 PB1 Your Ref: API 500292310670 Job No. AKZZ22136, Surveyed: 23 August, 2002 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (It) (It) (ft) (It) (It) (It) (It) 5893.56 85.560 99.780 3997.75 4060.25 1648.19 S 2948.35 E 6007814.01 N 554689.30 E 5934.88 83.840 102.920 4001.57 4064.07 1656.28 S 2988.69 E 6007806.20 N 554729.69 E 5984.71 82.100 107.970 4007.67 4070.17 1669.45 S 3036.34 E 6007793.36 N 554777.43 E 6025.95 79.860 116.170 4014.15 4076.65 1684.73 S 3074.05 E 6007778.35 N 554815.25 E 6095.00 79.860 116.170 4026.30 4088.80 1714.70 S 3135.05 E 6007748.79 N 554876.46 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.520° (True). Magnetic Declination at Surface is 25.733°(15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 6095.00ft., The Bottom Hole Displacement is 3573.34ft., in the Direction of 118.676° (True). Comments Measured Depth (It) Station Coordinates TVD Northings Eastings (ft) (It) (It) Comment 6095.00 1714.70 S Projected Survey 3135.05 E 4088.80 26 September, 2002 - 9:14 Page 4 of 5 BPXA Dogleg Rate (o/100ft) Vertical Section Comment 10.250 2743.51 8.636 2782.67 10.647 2828.53 20.373 2864.28 0.000 2921.51 Projected Survey ~/ ~. DrillQuest 3.03.02.002 Milne Point Unit Survey tool program for MPI-15 PB1 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 172.00 0.00 172.00 26 September, 2002.9:14 To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Survey Report for Milne Point MP/. MP/.15 PB1 Your Ref: AP/500292310670 Job No. AKZZ22136, Surveyed: 23 August, 2002 BPXA Survey Tool Description 172.00 6095.00 172.00 Tolerable Gyro 4088.80 AK-6 BP _IFR-AK .~ ~' Page 5 of 5 DrillQuest 3.03.02.002 ~O~,J5 ~ 30-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-15PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD , M D (if applicable) 6,095.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~..... ,~...;' /r~ :E~ î", N \!,< \;¡:..~. ~~, . I 'tJ \i \ ¡Jj.,.",,~. .<"''' OCT 0 2. , \)~ 'lŠ ~ .-..... ) tð c% Sperry-Sun Drilling Services ,~ Milne Point Unit BPXA Milne Point MPI MPI.15PB1 MWD Job No. AKMW22136, Surveyed: 23 August, 2002 Survey Report 26 September, 2002 /--.., Your Ref: APlS00292310670 Surface Coordinates: 6009441.71 N, 551129.59 E (70026' 11.5455" N, 149034'41.6645" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009441.71 N, 51729.59 E (Grid) Surface Coordinates relative to Structure Reference: 347.67 S, 448.48 W(True) Kelly Bushing: 62.50ft above Mean Sea Level Elevation relative to Project V Reference: 62.50ft Elevat(on relative to Structure Reference: 62.50ft sp...........y-su., DRILLING' s'ê:Rvlces A Halliburton Company Survey Ref: svy10170 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 P81 MWD Your Ref: AP/500292310670 Job No. AKMW22136, Surveyed: 23 August, 2002 BPXA Milne Point Unit Measured 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) 0.00 0.000 0.000 -62.50 0.00 O.OON 0.00 E 6009441.71 N 551729.59 E 0.00 Tolerable Gyro 172.00 0.240 178.000 109.50 172.00 0.365 0.01 E 6009441.35 N 551729.61 E 0.140 -0.03 MWD Magnetic 291.58 0.470 165.790 229.08 291.58 1.095 0.14 E 6009440.63 N 551729.74 E 0.201 0.02 382.49 0.870 162.510 319.98 382.48 2.11 5 0.44 E 6009439.61 N 551730.05 E 0.442 0.20 ,~ 469.23 1.190 160.910 406.71 469.21 3.585 0.93E 6009438.13 N 551730.55 E 0.370 0.52 558.65 3.740 133.950 496.04 558.54 6.49 5 3.34E 6009435.25 N 551732.97 E 3.056 2.58 650.23 5.130 130.430 587.34 649.84 11.22 5 8.60E 6009430.55 N 551738.27 E 1.546 7.28 741.16 6.140 130.330 677.83 740.33 17.00 S 15.41 E 6009424.82 N 551745.11 E 1.111 13.39 834.40 7.640 124.490 770.40 832.90 23.74 S 24.32 E 6009418.14 N 551754.07 E 1.774 21 .48 927.09 10.600 129.000 861.91 924.41 32.59 S 36.02 E 6009409.37 N 551765.84 E 3.283 32.11 1020.58 14.240 130.170 953.19 1015.69 45.43 5 51.50 E 6009396.64 N 551781.40 E 3.903 46.04 1115.08 17.730 128.170 1044.03 1106.53 61.82 5 71.70 E 6009380.39 N 551801.71 E 3.738 64.26 1208.00 23.070 134.710 1131.10 1193.60 83.39 S 95.78 E 6009358.99 N 551825.95 E 6.240 85.76 1303.40 31 .860 138.290 1215.67 1278.17 115.40 5 125.88 E 6009327.18 N 551856.26 E 9.371 112.05 1396.83 31.850 137.810 1295.03 1357.53 152.07 5 158.84 E 6009290.74 N 551889.48 E 0.271 140.66 1491.12 32.260 137.120 1374.94 1437.44 188.95 5 192.67 E 6009254.10 N 551923.57 E 0.583 170.12 1586.53 31.790 141.240 1455.84 1518.34 227.21 5 225.74 E 6009216.07 N 551956.90 E 2.342 198.65 1677.64 31 .650 140.410 1533.34 1595.84 264.34 5 255.99 E 6009179.15 N 551987.41 E 0.503 224.53 1773.51 30.480 136.080 1615.47 1677.97 301.25 5 288.89 E 6009142.48 N 552020.57 E 2.630 253.05 1864.32 29.580 134.880 1694.09 1756.59 333.65 S 320.75 E 6009110.29 N 552052.65 E 1.191 281.05 1959.84 31.320 130.730 1776.44 1838.94 366.49 5 356.28 E 6009077.70 N 552088.40 E 2.857 312.64 "~ 2054.97 33.960 128.860 1856.54 1919.04 399.30 5 395.71 E 6009045.16 N 552128.06 E 2.970 348.12 2150.44 34.360 126.000 1935.55 1998.05 431.87 5 438.28 E 6009012.89 N 552170.85 E 1.733 386.74 2246.36 35.120 119.220 2014.40 2076.90 461.26 5 484.27 E 6008983.82 N 552217.05 E 4.103 429.12 2341.58 36.000 118.500 2091.86 2154.36 487.99 5 532.77 E 6008957.43 N 552265.73 E 1.023 474.30 2436.01 35.890 118.520 2168.31 2230.81 514.45 S 581.48 E 6008931.31 N 552314.63 E 0.117 519.71 2529.00 36.170 118.100 2243.51 2306.01 540.38 5 629.64 E 6008905.71 N 552362.96 E 0.402 564.63 2622.23 36.070 118.470 2318.82 2381.32 566.43 5 678.03 E 6008880.00 N 552411.53 E 0.257 609.78 2715.16 34.400 120.430 2394.73 2457.23 592.77 5 724.72 E 6008853.99 N 552458.40 E 2.170 653. 1 9 2810.13 34.980 121.360 2472.81 2535.31 620.52 5 771.10 E 6008826.55 N 552504.97 E 0.827 696.14 2903.85 35.240 121.940 2549.48 2611.98 648.81 5 816.98 E 6008798.59 N 552551.05 E 0.451 738.54 2996.62 34.510 122.830 2625.59 2688.09 677.21 5 861.78 E 6008770.49 N 552596.05 E 0.959 779.85 3025.50 34.730 123.860 2649.36 2711.86 686.23 S 875.49 E 6008761.57 N 552609.81 E 2.165 792.45 3088.57 34.340 125.060 2701.31 2763.81 706.46 S 904.97 E 6008741.54 N 552639.43 E 1.243 819.46 3182.46 34.41 0 122.660 2778.81 2841.31 7aS.99 S 948.98 E 6008712.32 N 552683.65 E 1 .445 859.85 ----~---_._----~-_._--_.- ---_.._-------------.--_.---- - --<--------_.-_..-- .-->+---- 26 September, 2002 - 10:00 Page 20f5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 PB1 MWD Your Ref: API 500292310670 Job No. AKMW22136, Surveyed: 23 August, 2002 BPXA Milne Point Unit Measured 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) (°/1 OOft) 3276.71 34.340 123.930 2856.60 2919.10 765.20 S 993.46 E 6008683.42 N 552728.33 E 0.764 900.75 3371.81 34.510 122.710 2935.05 2997.55 794.73 S 1038.38 E 6008654.20 N 552773.46 E 0.747 942.06 3464.19 34.200 123.390 3011.31 3073.81 823.16 S 1082.08 E 6008626.07 N 552817.35 E 0.534 982.26 3557.50 33.940 122.730 3088.61 3151.11 851.68 S 1125.89 E 6008597.86 N 552861.36 E 0.484 1022.58 ~. 3649.70 33.960 122.640 3165.09 3227.59 879.48 S 1169.22 E 6008570.36 N 552904.88 E 0.059 1062.50 3745.36 33.930 120.590 3244.45 3306.95 907.48 S 1214.71 E 6008542.68 N 552950.56 E 1.197 1104.53 3838.08 34.150 121.040 3321.28 3383.78 934.07 S 1259.28 E 6008516.40 N 552995.32 E 0.361 1145.82 3931.49 37.770 121.150 3396.88 3459.38 962.39 S 1306.24 E 6008488.40 N 553042.47 E 3.876 1189.28 4024.15 42.320 118.970 3467.80 3530.30 992.20 S 1357.85 E 6008458.95 N 553094.29 E 5.138 1237.19 4117.98 46.880 118.220 3534.59 3597.09 1023.71 S 1415.68 E 6008427.85 N 553152.34 E 4.892 1291.11 4212.10 48.730 119.070 3597.80 3660.30 1057.14 S 1476.87 E 6008394.84 N 553213.76 E 2.076 1348.13 4304.12 52.140 118.570 3656.41 3718.91 1091.32 S 1539.02 E 6008361.09 N 553276.14 E 3.729 1406.02 4400.14 55.760 114.860 3712.92 3775.42 1126.16 S 1608.36 E 6008326.74 N 553345.72 E 4.895 1470.99 4492.41 59.110 115.550 3762.58 3825.08 1159.28 S 1678.70 E 6008294.11 N 553416.29 E 3.685 1537.15 4588.37 62.760 115.450 3809.18 3871.68 1195.38 S 1754.40 E 6008258.53 N 553492.24 E 3.805 1608.28 4681.10 66.640 115.120 3848.81 3911.31 1231.17 S 1830.19 E 6008223.26 N 553568.27 E 4.197 1679.55 4777.56 71 .160 111.680 3883.53 3946.03 1266.86 S 1912.76 E 6008188.15 N 553651.09 E 5.746 1757.56 4871.05 72.700 109.410 3912.53 3975.03 1298.04 S 1995.98 E 6008157.54 N 553734.52 E 2.836 1836.73 4960.44 76.180 105.550 3936.52 3999.02 1323.88 S 2078.09 E 6008132.28 N 553816.81 E 5.697 1915.41 5056.25 79.240 106.630 3956.91 4019.41 1349.82 S 2168.03 E 6008106.96 N 553906.93 E 3.378 2001.84 5155.11 84.940 108.940 3970.51 4033.01 1379.73 S 2261.22 E 6008077.70 N 554000.32 E 6.213 2091.06 .- 5237.71 84.580 113.670 3978.06 4040.56 1409.61 S 2337.83 E 6008048.35 N 554077.14 E 5.719 2163.81 5283.30 90.000 114.530 3980.21 4042.71 1428.19 S 2379.38 E 6008030.05 N 554118.82 E 12.037 2203.00 5343.37 89.880 111.350 3980.28 4042.78 1451.60 S 2434.69 E 6008007.03 N 554174.29 E 5.298 2255.32 5:376.13 89.570 111 .000 3980.43 4042.93 1463.44 S 2465.24 E 6007995.41 N 554204.92 E 1.427 2284.33 5427.68 88.090 108.230 3981.49 4043.99 1480.74 S 2513.78 E 6007978.44 N 554253.58 E 6.091 2330.61 5471.47 87.600 107.480 3983.13 4045.63 1494.15 S 2555.43 E 6007965.32 N 554295.33 E 2.045 2370.48 5519.97 87.660 107.300 3985.14 4047.64 1508.64 S 2601.68 E 6007951.15 N 554341.67 E 0.391 2414.80 5565.96 89.380 107.350 3986.33 4048.83 1522.33 S 2645.56 E 6007937.77 N 554385.65 E 3.742 2456.86 5619.66 88.770 105.870 3987.19 4049.69 1537.68 S 2697.02 E 6007922.78 N 554437.21 E 2.981 2506.25 51360.42 88.460 106.250 3988.18 4050.68 1548.95 S 2736.17 E 6007911.78 N 554476.44 E 1.203 2543.88 5'708.58 86.920 106.590 3990.12 4052.62 1562.55 S 2782.33 E 6007898.50 N 554522.69 E 3.275 2588.21 5'751.73 89.200 104.720 3991.58 4054.08 1574.19 S 2823.85 E 6007887.15 N 554564.29 E 6.832 2628.15 5801.94 88.580 104.550 3992.55 4055.05 1586.87 S 2872.42 E 6007874.80 N 554612.95 E 1.280 2674.98 5843.58 86.490 104.990 3994.34 4056.84 1597.48 S 2912.65 E 6007864.48 N 554653.25 E 5.129 2713.75 -- -~-----.~...__._----_._----- 26 September, 2002 - 10:00 Page 3 of5 DrillQuest 3.03.02.002 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 5893.56 85.560 99.830 3997.81 4060.31 5934.88 83.840 102.920 4001.63 4064.13 5984.71 82.100 107.620 4007.73 4070.23 6025.95 79.860 115.790 4014.20 4076.70 6095.00 79.860 115.790 4026.36 4088.86 ~ Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MPI-15 PB1 MWD Your Ref: AP/500292310670 Job No. AKMW22136, Surveyed: 23 August, 2002 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 1608.19 S 2961.32 E 6007854.10 N 554702.00 E 1 0.466 2760.91 1616.30 S 3001.65 E 6007846.27 N 554742.38 E 8.531 2800.07 1629.32 S 3049.35 E 6007833.58 N 554790.17 E 9.991 2845.99 1644.36 S 3087.16 E 6007818.81 N 554828.08 E 20.304 2881.86 1673.93 S 3148.36 E 6007789.66 N 554889.48 E 0.000 2939.33 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 83.520° (True). Magnetic Declination at Surface is 25.733°(15-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 6095.00ft., The Bottom Hole Displacement is 3565.70f1., in the Direction of 117.999° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) /- 6095.00 4088.86 1673.93 S 3148.36 E 26 September, 2002 - 10:00 Comment Projected Survey ----~------ Page 40f5 DrillQuest 3.03.02.002 Milne Point Unit Survey tool program for MPI-15 PB1 MWD From Measured Vertical Depth Depth (ft) (ft) /-' 0.00 172.00 0.00 172.00 - 26 September, 2002 - 10:00 To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Survey Report for Milne Point MPI- MP/-15 PS1 MWD Your Ref: AP/500292310670 Job No. AKMW22136, Surveyed: 23 August, 2002 BPXA Survey Tool Description 172.00 6095.00 172.00 Tolerable Gyro 4088.86 MWD Magnetic --------.---.-----------'- Page 50f5 DrillQuest 3.03.02.002 I TONY KNOWLES, GOVERNOR AI¡ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99510 Re: Milne Point Unit MPI-15 BP Exploration (Alaska), Inc. Permit No: 202-152 Surface Location: 2959 FNL, 3621 FEL, Sec. 33, TI3N, RI0E, UM Bottomhole Location: 2813' NSL, 4555' WEL, Sec. 34, TI3N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above development well. The 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. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, LM~&u¡~~ .~OJ Cammy ~chsli Tayl~r ð~ Chair BY ORDER OF THE COMMISSION DATED thisálÆt day of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 42" 12-1/4" 8-1/2" 6-1/8" ALASKnJIL AND ~:~~g~S~'::':;;ON COMa..1sION PERMIT TO DRILL 20 MC 25.005 1 b. Type of well [] Exploratory [] Stratigraphic Test II Development Oil [] Service [] Development Gas [] Single Zone [] Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 62.1' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 025906 7. Unit or Property Name Milne Point Unit 8. Well Number MPI.15 9. Approximate spud date 08/06/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9080' MD / 4127' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 91 Maximum surface 1543 psig, At total depth (TVD) 3934' / 1943 psig Setting Depth TOD Botom MD TVD MD TVD 30' 30' 112' 1121 30' 30' 3067' 2762' 30' 30' 5100' 4057' 5000' 40331 9080' 41271 \W 'Æ- 7ll>lo L (ffF 7/~/ 1> 2- 1 a. Type of work II Drill [] Redrill [] Re-Entry [] Deepen 2. Name of Operator . BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 9.9519-6612 4. Location of well at surface ~-NSl.,.EJ,~!1 Wt::.L, SEC. 33, T13N, R10E, UM (Approximate) -Z ~n6p '6fpr~c1Ït;r~'rváÍ~ ¿ ,l{k 928' NSL, 1429' WEL, SEC. 33, T13N, R10E, UM At total depth 2813' NSL, 4555' WEL, SEC. 34, T13N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 380109, 28131 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casing WeiÇlht Grade CouDlina 20" 92# H-40 Weld 9-5/8" 47# L-80 BTC 7" 26# L-80 BTC 4-1/2" 12.7# L-80 BTC 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 LenQth 82' 30371 5070' 4080' Quantity of Cement (include staQe data) ~60 sx Arctic Set (Approx.) 559 sx Class 'L', 190 sx Class IG' 172 sx Class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Procjuction Liner Length Size Cemented MD TVD RECEI\fED JUL 23 2002 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch II Drilling Program II Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NameINumber: Matt Green, 564-5581 Prepared By NameINumber: Terrie Hubble, 564-4628 ~'~~~~~0f0~~~'~~~ Permit Numb~r API Number /'" Approval Date. . t See cover letter .zoz - /5"z 50- ð.2. 9-.2. 3/0 ~ 1'~Df\~ for other requirements Conditions of Approval: Samples Required 0 Yes 0 No Mud Log Required 0 Yes 0 No Hydrogen Sulfide Measures 0 Yes 0 No Directional Survey Required 0 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T-e~t- 80 pG ~ 'loth? 1St'. . Gnglnal SIgned By by order of 1 ~~u. (?~ Cam"1y ~sli T~. C..ommis. ~io.ne.r A. the commission Date l) I~ç I G i ¡\J. L Submit In Triplicate Approved By Form 10-401 Rev. 12-01-85 ') IWell Name: MPI-15 Drill and Complete Plan Summary )ne Point MPI-15 Well Permit I Type of Well (service I producer I injector): I Multi Lateral Producer "OA" & "OB" Surface Location: Target Location: TOP "OA" Target Location: BHL "OA" Well TD Target Location: TOP "OB" Target Location: BHL "OB" Well TD 399T FNL, (1282' FSL), 5135' FEL, (1451 FWL), SEC. 33, T13N, R10E E=550245.83 N=6008388.01 4352' FNL, (9281 FSL), 1429' FEL, (38501 FWL), SEC. 33, T13N, R10E E=553955.00 N=6008060.00 Z=4002' TVD 246T FNL, (28131 FSL), 4555' FEL, (7241 FWL), SEC. 34, T13N, R10E E=556090.00 N=6009960.00 Z=4072' TVD 4352' FNL, (9281 FSL), 1429' FEL, (3850' FWL), SEC. 33, T13N,R1 OE E=553955.00 N=6008060.00 Z=4057' TVD 2467' FNL, (28131 FSL), 4555' FEL, (7241 FWL), SEC. 34, T13N,R1 OE E=556090.00 N=6009960.00 Z=4127' TVD 1 AFE Number: 1 MSD337294 I Estimated Start Date: 16 Aug 2002 1 MD: 19080 I I TVD: 14127 1 1 Rig: I Doyon 141 1 I Operating days to complete: 120.4 1 I Max Inc: 191 I I KOP: 1300 I I KBE:162.1 I I Well Design (conventional, slim hole, etc.): I Conventional Grass Roots ML Producer I I I Objective: I Sch rader OB Sand Mud Program: ,,/ Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 6.5 12.25-in Surface Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 8.6 - 9.0 75 - 150 25 - 60 N/A ~ntermediate Hole Mud Properties: Dcngfty (ppg) Funnel visc YP HTHP 9.0 - 9.3 75 -150 25 - 60 N/A LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 6.5 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density (ppg) Funnel visc YP HTHP pH API Filtrate LG Solids 8.6 - 9.3 40 - 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 Cement Program: ) ~ Jne Point MPI-15 Well Permit ~ Casin~ Size 9.625-in 47-lb/ft L-80 BTC Surface Casing Basis 1250% excess over gauge hole in permafrost interval 400/0 excess over gauge hole below permafrost Total Cement Wash 50 bbl t Volume: 453-bbl - wa er Spacer Lead Tail Temp 50-bbl Viscosified Spacer (Alpha) weighted to 10.5-lb/gal 559-sx (414-bbl) 10.7Ib/gal Class L - 4.15 cuft/sx (cement to surface) 190-sx (39-bbl) 15.8 Ib/gal Prem G - 1.15 cuft/sx (top of tail at 2,522-ft BHST ~ 80°F from SOR, BHCT 85°F estimated by Halliburton Casin~ Size 17.0-in 26-lb/ft L-80 BTC Intermediate Casing Basis 140% excess over gauge hole. Tail 500-ft MD above top of N-sand. Total Cement Volume: 35-bbl Wash 50-bbl water Spacer Tail Temp Evaluation Program: 12.25-in Section Open Hole: Cased Hole: 8.5-in Section Open Hole: Cased Hole: 6.125-in Section Open Hole: 50-bbl Viscosified Spacer (Alpha) weighted to 10.50 ppg 172-sx (35-bbl) 15.8 Ib/gal Prem G - 1 .15 cuft/sx (top of tail at 4046' BHST ~ 80°F from SOR, BHCT 85°F estimated by Halliburton MWD/GR/RES IFRlCASANDRA N/A MWD/GRlRES IFRlCASANDRA N/A MWD/GRlRES ABI/IFRlCASANDRA 2 ) Formation Markers: Jne Point MPI-15 Well Permit Estimated EMW (Ib/gal)* 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 9.5 MOrkb (ft) 1,888 3,673 4,265 4,454 4,513 4,577 4,623 4,768 4,871 4,962 5,100 TVDrkb (ft) 1,787 3,262 3,712 3,822 3,852 3,882 3,902 3,957 3,992 4,022 4,057 4,077 4,127 Pore Pressure (psi) 852 1,581 1,803 1,857 1,872 1,887 1,897 1,924 1,941 1,956 1,974 1,983 Formation Tops Base Permafrost Top Ugnu Bottom Ugnu NA NB NC NE NF Top OA Base OA Top OB Base OB TO 9,080 *Based on sub-surface depths. CasinglTubing Program: Hole Csg/ WtlFt Grade Conn Length Size Tbg O.D. 42-in 20-in* 92# H-40 Weld 82-ft 12.25-in 9.625-in 47# L-80 BTC 3,037-ft 8.5-in 7.0-in 26# Top M D / TVDrkb 30- ft 30- ft Bottom M D / TVDrkb 112-ft / 112-ft 3,067 -ft / 2,762-ft 5,1 OO-ft / 4,057 -ft 9,080-ft / 4,127-ft 9,073-ft / 4,072-ft 30-ft L-80 BTC 5,070-ft 5,000-ft / 4,033-ft 4,872-ft / 3,993-ft 6.125-in 4.5-in 12.7# L-80 BTC 4,080-ft OB 6.125-in 4.5-in 12.7# L-80 BTC 4,201-ft OA *The 20" casing is insulated Recommended Bit Program: Nozzle/Flow rate Hughes MXC-1 3-15 & 1-10 Smith ER6050 3-15 & 1-10 Security 3 -12 FM2643 Depth (MD) 0 - 3,067-ft 3,067 - 5,1 OO-ft 5,100-ft - TO Bit Type BHA Hole Size 12.25-in 8.5-in 6.125-in 1 2 3 3 ') )Ine Point MPI-15 Well Permit Well Control: Surface Interval . The surface hole will be drilled with a diverter. Intermediate and Production Intervals . Maximum anticipated BHP: 1,943-psi @ 3,934-ft TVDss - Top of OA-sand . Maximum surface pressure: 1,543-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) . Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 4,000-psi high. An FIT to 11.5-lb/gal will be made on the 7.0-in casing shoe. 25.5-bbl with 10.0-lb/gal mud and FIT of 11.4-lb/gal @ 9.625-in casing shoe. 9.2-lb/gal NaCI / 6.8-lb/gal Diesel . Integrity test: . Kick tolerance: . Planned completion fluid: Drilling Hazards & Contingencies: Hydrates . Minor hydrates have been observed on 1-05 @ 1 ,773-ft TVD and 1-10 at 2,390-ft TVD. Hydrates have also been observed on H-03, H-06 and H-07. Hydrates generally occur just below the permafrost (+/- 1 ,800-ft TVDss), but may be present in shallower SV sands and also as deep as 3,000-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates; maintain cool mud « 60°F); limit ROP and reduce pump rate while drilling hydrates; circulate connections thoroughly. See Well Program and Recommended Practices for specific information. . Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation . We do not expect losses while drilling this well. . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. 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 . Reservoir pressure is expected to be 9.5-lb/gal EMW. In this well, the Schrader Bluff formation will be drilled with 10.0-lb/gal mud. 4 ') )Ine Point MPI-15 Well Permit Pad Data Sheet . Please read the I-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults . N/A Hydrogen Sulfide . MPI Pad is not designated as an H2S Pad. Anti-collision Issues . MPI-15 will pass 127-ft from MPI-01 at 6,295-ft MD. Based on 1/200 Minor Risk Criteria, this wellbore passes the BP anti-collision requirements. 5 ) DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure )"e Point MPI-15 Well Permit 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 12.25-in surface hole as per directional plan. 3. Case and cement 9.625-in surface casing. 4. NO diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 8.5-in hole to top OB-sand as per directional plan. 7. Case and cement 7.0-in intermediate casing. 8. Perform FIT. 9. Drill 6.125-in OB-sand lateral as per directional plan. 10. Run 4.5-in uncemented slotted liner and hang off 100-ft inside 7.0-in casing. 11. Set whipstock and mill window at top of OA-sand. 12. Drill 6.125-in OA-sand lateral as per directional plan. 13. Pull whipstock. 14. Run 4.5-in uncemented slotted liner with Baker Hookwall Hanger and hang off in 7.0- in casing. 15. Displace drilling mud to brine. 16. Run 2.875-in ESP completion as per schematic. 17. Land tubing hanger and test. 18. Set BPV. 19. NO BOP. 20. Install and test tree. 21. Pull BPV. . . 23. Test 7.0-in x 2.875-in annulus 24. Freeze protect thru GLM. 25. Install BPV and secure well. 26. RD/MO. 6 TREE: Cameron 4-1116" 5M WELLHEAD: FMC Gen 5 11",5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger ~HUPU~i=U GUMPLi= IIUI\I) .JlP,I-ta PI-1fi L. KB. ELEV = 62.1' Cellar Box ELEV = 34.5' 1121 Y ~ 20" 92 Iblft, H-40 Welded .... Insulated Diesel freeze protect to 750' MD 9.625", 47-lb/ft, L-80, BTC Coupling aD: 10.62511 Casing Drift: 8.525" Casing ID: 8.681" 3,0671 ... 2.87511, 6.4-lb/ft, L-80, EUE 8rd Coupling 00: 3.50011 Tubing Drift: 2.347" Tubing I D: 2.441" Window in 7" casing @ 4,872' MD Well Inclination @ Window = 70 Degrees 7.0" 26.0#, L-80, BTC-M Casing Drift: 6.151" Casing ID: 6.276" Coupling 00: 7.656" Burst: 7,240-psi Collapse: 5,410-psi 5,1001 2 .. Well Inclination @ Shoe = 78 Degrees DATE 22 Jul 02 REV. BY MDG COMMENTS Level 3 Multi-Lateral, 2.875" ESP Completion . ~.5. Hole , \\, . "-- ......-- ---- ,I I ,I I I I I I I I I I I I I I I I I I I I I I I" I I I I I I I I I I I.. ... 42" Hole 2.875" x 1.0" Gas Lift Mandrel @ 2,000' MD , 2,000' TVD, RP shear valve open position ~ Centrilift NO.2 Cable wI cable clamps 2.875" HES XN nipple, 2.205" ID Centrilift GC 1700 ESP, Series 513, GPMTAR, 123 STG Tandem gas separator Centrilift GST3DBHl seal Centrilift KME1 562 Series, 165 hp, motor, 2230V 143 amp. Centrilift PHD \~ Multi-Lateral Junction 4,8721 6-1/8" OA Lateral TO 9,073' ........ ......... ----- - - OA Horizontal 6-1/8" hole r...... -- - ----- - - 4-1/2" Slotted Liner W/Hookwall hanger 6-1/8" OB Lateral TO I 9,080' I ----- - - 08 Horizontal 6-1/8" hole - - 4-1/2" Slotted Liner & Hanger Milne Point Unit WFJ . : MPI-1S API NO: BP Exploration (Alaska) bp REFERENCE INFORMATION COMPANY DETAILS IW Amo~o CO-Qroinale (NÆ) Reference: Wen Centre: Plan Mpl-15. True North Vertical (TVD) Reference: 62.10' 62.10 Seclion (VS) Reference: Slot. (O.OON,O.OOE) Measured Deplh Reference: 62.10' 62.10 Calculation Method: Minirnmn Curvature Calculation Method: Minimwn ('wvnturc ~~~ ~~~~ ~~:~~~ndcr North EITor Surra~c: Elliptical'" Casing Waminp, Method: Rules Based CASING DETAILS 700 No. TVD MD Name 1.5/ I 00' : 300' MD, 300'TVD : 433.33' MD, 433.31 'TVD 2762.10 3067.16 95/8" 4057.10 5099.72 7" 4127.10 9080.33 41/2" FORMATION TOP DETAILS SURVEY PROGRAM Plan: MPI-15 wp05 (plan MPI-15/Plan MPI-15) Depth Fm Deplh To SwveylPlan Tool Created By: Ken Allen Date: 7/2212002 27.60 500.00 Planned: MpI.15 wp05 VI4 CB-GYRO-SS Checked: Date: 500.00 908034 Planned: MPI.15 wp05 VI4 MWD+IFR+MS Reviewed: Date: WELL DETAILS Name +N/-S +EI~W Northing Easting Latitude Longitude Slot Plan MpI.15 1038.70 1511.43 6009436.77 551750.08 70026'11.496N 149°34'41.064W N/A TARGET DETAILS Name TVD +N/.S +E/-W Northing Easting Shape MpI-OIA Tlh 4057.10 -1392.17 2195.53 6008060.00 553955.00 Point MpI.OIA T2h 4072.10 .1611.53 2819.08 6007845.00 554580.00 Point MpI.OIA Db 4097.10 -1675.66 3413.71 6007785.00 555175.00 Point MpI.OIA Poly 4112.10 -1749.62 2109.03 6007702.00 553871.00 PolY8on MpI.OIA T4b 4112.10 -1563.50 3824.53 6007900.00 555585.00 Point MpI.OIA T5b 4112.10 .1026.93 4328.32 6008440.00 556085.00 Point MpI.OIA T6b 4127.10 .317.33 4398.25 6009150.00 556150.00 Point MpI-OIA T7b 4127.10 493.15 4343.87 6009960.00 556090.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 27.60 0.00 0.00 27.60 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 433.33 2.00 148.00 433.31 -1.97 1.23 1.50 148.00 1.00 4 1475.53 28.00 135.00 1431.45 -193.70 IR7.07 2.50 346.09 Ir,~.03 - 5 1789.79 32.00 130.00 1703.60 -299.44 ," \.09 1.50 325.81 :c, :'.37 6 1916.44 32.00 130.00 1811.00 -342.58 I' ~.50 0.00 0.00 'I \.59 7 2081.84 34.43 122.10 1949.43 -395.64 ~: 7.73 3.00 -64.00 1~o).37 8 3850.59 34.43 122.10 3408.26 -927.08 I: "'.00 0.00 0.00 1 I r._~.29 9 4749.96 70.01 115.00 3950.82 -1251.51 IV' \.88 4.00 -11.40 I :~o).62 10 4899.96 70.01 115.00 4002.10 -1311.09 :": 1.63 0.00 0.00 I ~r.'1.84 II 5099.72 78.00 115.00 4057.10 -1392.17 : 1"';.53 4.00 0.00 :"~ ~.47 MPI-OIA Tlb 12 5209.34 89.68 108.90 4068.85 -1432.77 : ~"r;.41 12.00 -27.81 :1:'1.13 13 5733.44 89.68 108.90 4071.77 -1602.57 ~ "'-'..24 0.00 0.00 :'.'~ \.64 14 5761.74 89.00 108.00 4072.10 -1611.53 ::, 1'¡.08 4.00 -126.96 >"".30 MPI-OIA T2b 15 6278.27 86.59 87.46 4092.17 -1680.66 ": 7.74 4.00 -97.02 '1Ir;.92 16 6309.15 86.59 87.46 4094.00 -1679.30 "";(.53 0.00 0.00 1 I~ 7.67 17 6364.53 87.00 85.00 4097.10 -1675.66 .~ I \.71 4.50 -80.69 1:":..90 MPI-OIA T3b 18 6495.89 87.16 78.43 4103.80 -1656.76 . ~ \.45 5.00 -88.77 "i 1.95 19 6531.96 87.16 78.43 4105.59 -1649.53 " ";(.75 0.00 0.00 . ,r.'~.83 20 6793.26 90.00 63.00 4112.10 -1563.50 ",:~.53 6.00 -79.82 ".~ ;.76 MPI-OIA T4b 21 6864.65 90.79 58.79 4111.61 -1528.78 "~r;.89 6.00 -79.38 'r.~'1.63 22 6916.49 90.79 58.79 4110.89 -1501.93 ," il.22 0.00 0.00 .7 ";.71 23 7547.00 89.00 21.00 4112.10 -1026.93 ~ '::,.32 6.00 -92.65 ~ I :''¡.85 MPI-OIA T5b 24 8148.14 88.61 354.55 4124.84 -436.73 ~ ~ "S.90 4.40 -91.10 ~ . '1.49 25 8214.87 88.61 354.55 4126.46 -370.31 ~~"-:.56 0.00 0.00 ~'i:..69 26 8268.04 90.00 356.16 4127.10 -317.33 ~ "'S.25 4.00 49.34 ~ "~.38 MPI-OIA T6b 27 9080.34 90.00 356.16 4127.10 493.15 ~:~.I.87 0.00 0.00 ~-' 71.77 MPI-OIA T7b Size 9.625 7.000 4.500 No. TVDPath MDPath Formation I 2 3 4 5 6 7 8 9 10 II I "'S.26 .., ¡. \.38 ~.:'r.'¡.67 ~ ~ '.¡.32 .~'.I \.34 .~', ;";.99 ~'._~..70 ~ 7..:..;.3 3 ~~ :0).71 ~"'.:..20 >""".72 I i~ 1.10 ':'.2.10 ': 12.10 ,~:2.1O '~".~.IO '''1:,.',,10 ""'-',,10 ,"'.7.10 ,""2.10 .~": -'..10 ~,,'. 7.10 Dir 1.5/100': 1475.53' MD, 1431.45'TVD 1400 : 1789.79' MD, 1703.6' TVD Dir 3/100': 1916.44' MD, 1811'TVD c ~ 0 0 ...... ::; 2100 Q.. Ö ~ '€ > Dir : 2081.84' MD, 1949.43' TVD BPRF TUgnu BUgnu SBF2-NA SBFI-NB SBE4-NC SBE2-NE SBEI-NF TSBD-OA TSBC TSBB-OB All TVD depths are ssTVD plus 62.1 '.forRKBE. Total Depth: 9080.34' MD, 4127.1' TVD End Dir : 4749.96' MD, 3950.82' TVD End Dir : 8268.04' MD, 4127.1' TVD Start Dir 4/100' : 4899.96' MD, 4002.1'TVD Start Dir 4/100' : 8214.87' MD, 4 I 26.46'TVD Start Dir 12/100': 5099.72' MD, 4057.I'TVD .. \: End Dir : 5209.34' MD. 4068.85' TVD I Start Dir 4/100' : 5733.44' MD, 4071.77'TVD llldDir :8148.I4'MD ~1.'~x~'TVD , ..... DII.H/I ':7547',MD,411: "J\'[J ;: "'" ~ . , ' "" mr"w~+ ~tim ~~[~ :;::~.7.0.'.!}...:~~j.!'~..,$?ß.....'.'..'.1"...../...7[........i.II'" fr" ff..'.,'.,.'- ~.']¡4;;' E lid Dir 95[89' ;..to 410 'VD¡ I I S,"n Di 9'TV[J . 1 . . I ,''', ,", ;....;En<-::, .: '~D ~III ,61' I VO, 2100 2800 3500 Vertical Section at 83.52° [700ft/in] 2 ¡- 2800 3500 4200 0 700 1400 4200 61. . L ,); 1[/ I,' , I ' . ~ I.' .' .'.' ./~/l:.. .f ,..:/'J ~,~1 .I' I --,1 .. I .........t.. j ~'"n [III "¡¡I (III' \X50.5~' II.~[I. ,- i "', I .... d.m......... StartDir4.4/100':7547'MD,4112.1'TVD .\;I(~; I;L ~.. _m¡ i /1 I ! I I I I 700 1400 4900 W est( - )/East( + ) [700ft/in] bp COMI'ANY DETAILS REFERENCE INFORMA nON UP Amoco Co-ordillatc (NÆ) Reference: Welt Centre: Plan MPI-15, True North' ('a1culation Method: Mininnun CUMturo Vertical (TVD) Reference: 62.10' 62.10 Section (VS) Reference: Slot. (O.OON.O.OOE) ~:;~ ~~~~~}: ~I~:~~~n(kr North Measured Depth Reference: 62.1 0' 62.10 Calcularion Method; Minimum Curvature Em1r Surface: Elliptical -I. Casing Wnminp. Method: Rules Based SECTION DETAILS See MD 1nc Azi TVD +N/-S +E/-W DLeg TFaee VSec Target I 27.60 0.00 0.00 27.60 0.00 0.00 0.00 0.00 0.00 2 ""1.00 0.00 0.00 300,00 0.00 0.00 0.00 0.00 0.00 3 ..¡ . 1.33 2.00 148.00 433.31 -1.97 1.23 1.50 148.00 1.00 4 I"¡ :'i.53 28.00 135.00 1431.45 -193.70 I'. /.07 2.50 346.09 164.03 5 I ~"'.79 32.00 130.00 1703.60 -299.44 '" \.09 1.50 325.81 267.37 6 I" 1';.44 32.00 130.00 1811.00 -342.58 " ~.50 0.00 0.00 313.59 7 :"~ 1.84 34.43 122.10 1949.43 -395.64 J.' 7.73 3.00 -64.00 380.37 8 ';;'.'1.59 34.43 122.10 3408.26 -927.08 I: ¡';.OO 0.00 0.00 1162.29 9 .¡ ;01".96 70.01 115.00 3950.82 -1251.51 I.," \.88 4.00 -11.40 1740.62 10 '¡;""'.96 70.01 115.00 4002. I 0 -1311.09 :"-'1.63 0.00 0.00 1860.84 II '.11"".72 78.00 115.00 4057.10 -1392.17 .1" ;.53 4.00 0.00 2024.47 MPI-01A Tlb 12 '-'11".34 89.68 108.90 4068.85 -1432.77 ::",;.41 12.00 -27.81 2120.13 13 ',; 1\.44 89.68 108.90 4071. 77 -1602.57 -- 7', .~.24 0.00 0.00 2593.64 14 ',7'.(.74 89.00 108.00 4072.10 -1611.53 :~ 1'1.08 4.00 -126.96 2619.30 MPI-OIA T2b 15 ..-' ~"".27 86.59 87.46 4092.17 -1680.66 ,': 7.74 4.00 -97.02 3116.92 16 .. \11".15 86.59 87.46 4094.00 -1679.30 ".~L53 0.00 0.00 3147.67 17 ..II."¡.53 87.00 85.00 4097.10 -1675.66 'J I \.71 4.50 -80.69 3202.90 MPI-01A nb 18 ....'I';.89 87.16 78.43 4103.80 -1656.76 I'... \.45 5.00 -88.77 3333.95 19 .... '1.96 87.16 78.43 4105.59 -1649.53 "'-/"".75 0.00 0.00 3369.83 20 ..',., 1.26 90.00 63.00 4112.10 -1563.50 IS: ~.53 6.00 -79.82 3623.76 MPI-01A T4b 21 . .~". ~.65 90.79 58.79 4111.61 -1528.78 '~~'¡.89 6.00 -79.38 3689.63 22 ..."...49 90.79 58.79 4110.89 -1501.93 ,'1 I 1.22 0.00 0.00 3736.71 23 ;'."¡ !.OO 89.00 21.00 4112.10 -1026.93 ...¡ ':"".32 6.00 -92.65 4184.85 MPI-01A T5b 24 "1"¡¡'.14 88.61 354.55 4124.84 -436.73 -I-I1I;{.90 4.40 -91.10 4331.49 25 ~: 1"¡.87 88.61 354.55 4126.46 -370.31 "'¡..II-'..56 0.00 0.00 4332.69 26 "':";;.04 90.00 356.16 4127.10 -317.33 .¡ "';(.25 4.00 49.34 4334.38 MPI-01A T6b 27 '''-'~11.34 90.00 356.16 4127.10 493.15 "'¡_''¡_\.87 0.00 0.00 4371.77 MPI-OIA T7b 700- '2 ~ 0 0 r::. +' 1: t:: ~ 1: ;:; 0 (I) 1.5/IOO";3fj()' 11.' D. )1I(\'TVD"'Tm Dir 2.5/100' 4J \ 3 r MD."¡ \.UqTVD All TVD depths are ssTVD plus 62.1'for 1.5flOl1' 1"¡7~ ~J Mq, 1431 45'1\'D I ~~N 7'}' 11.1 [1,"1103:(,' 1 VD [III ~llllll' 19Icl,44!MD. 18] I'TVD End qir 21)~1 8~'Mp, ]'~".4r1VD I ' I .1, I J.511!J . ~'7- I I I I I I I 0 SURVEY PROGRAM Plan: MPI-I5 wp05 (plan MPI-15/Plan MPI-15) Depth Fm Depth To SwveylPlan 27.60 500.00 PlalU1ed: MPI.15 wp05 VI4 500.00 9080.34 Planned: MPI.15 wp05 V14 Tool Created By: Ken Allen Checked: Date: 7/22/2002 CB-GYRO.SS MWD+IFR+MS Date: Reviewed: Date: FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 I :'~ 7.10 1888.26 BPRF 2 '-".-~.1 0 3673.38 TUgnu 3 ,~ I .~.1 0 4264.67 BUgnu 4 ,:,.- .~.10 4454.32 SBF2-NA 5 .:. .2.10 4513.34 SBF]-NB 6 '~~!..10 4576.99 SBE4-NC 7 c'JlI_~.l 0 4622.70 SBE2-NE 8 ,T'.7.10 4768.33 SBE1-NF 9 ""'.:.10 4870.71 TSBD-OA 10 '¡": -:.10 4962.20 TSBC 11 01,,:.7.10 5099.72 TSBB-OB TARGET DETAILS Name lVD +NI-S +E/.W Northing Easting Shape MP1-01A Tlb MPI.OIA T2b MPI.OlA Db MPI-O IA Poly MPI.OIA T4b MPI.OIA T5b MPI.OIA T6b MPI.OIA T7b 4057.10 .1392.17 219553 4072.10 -1611.53 2819.08 4097.10 .1675.66 3413.71 4112.10 .1749.62 2109.03 4112.10 .156350 3824.53 4112.10 .1026.93 4328.32 4127.10 .317.33 439825 4127.10 493.15 4343.87 6008060.00 6007845.00 6007785.00 6007702.00 6007900.00 6008440.00 6009150.00 6009960.00 553955.00 Point 554580.00 Point 555175.00 Point 553871.00 PoIY8on 555585.00 Point 556085.00 Point 556150.00 Point 556090.00 Point CASING DETAILS No. TVD MD Name Size 1 2762.10 3067.16 95/8" 9.625 2 4057.10 5099.72 7" 7.000 3 4127.10 9080.33 4 1/2" 4.500 WELL DETAILS Name +N/-S +E/.W Northing Basting Latitude Longitude Slot Plan MPI.15 1038.70 1511.43 6009436.77 551750.08 70026'11.496N 149°34'41.064W NlA ......" MPI-15 wp05 Depth: 9080.34' MD, 4127.1' TVD ~ MPI-01A T7b .j...' End Dir : 8268.04' MD, 4127.1' TVD ,. MPI-01A T6b ~ "3 Start ~ir 4/100': 8~14.87' MD, 4,126.46'TVD --1 End Dlr : 8148.14 MD, 4124.84 TVD .-../ I 5600 ) BP My Planning Report MAP Company: Field: Site: Well: Wellpath: Field: BP Amoco Milne Point M Pt I Pad Plan MPI-15 Plan MPI-15 Date: 7/22/2002 Time: 11 :40:36 Page: Co-ordinate(NE) Reference: Well: Plan MPI-15, True North Vertical (TVD) Reference: 62.10' 62.1 Section (VS) Reference: Well (0.00N,O.00E,83.52Azi) Sun'ey Calculation Method: Minimum Curvature Db: 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: M pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 6008388.01 ft 550245.83 ft Latitude: Longitude: North Reference: Grid Convergence: Well: Plan MPI-15 Slot Name: +N/-S 1038.70 ft Northing: 6009436.77 ft +E/-W 1511.43 ft Easting: 551750.08 ft Position Uncertainty: 0.00 ft Well Position: Latitude: Longitude: Wellpath: Plan MPI-15 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 62.10' 7/15/2002 57494 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 62.10 ft Plan: MPI-15 wp05 Date Composed: Version: Tied-to: Principal: Yes Casing Points ') Oracle Alaska, Zone 4 Well Centre BGGM2002 70 26 1.282 N 149 35 25.422 W True 0.39 deg 70 26 11.496 N 149 34 41.064W Well Ref. Point 0.00 ft Mean Sea Level 25.76 deg 80.80 deg Direction deg 83.52 7/18/2002 14 From Well Ref. Point TV]) Diameter ft in 3067.16 2762.10 9.625 12.250 95/8" 5099.72 4057.10 7.000 8.500 7" 9080.33 4127.10 4.500 6.125 41/2" Formations MD TV]) Litholögy J)iþAngle J)¡pl)irecti~n ft ft deg ~eg 1888.26 1787.10 BPRF 0.00 0.00 3673.38 3262.10 TUgnu 0.00 0.00 4264.67 3712.10 BUgnu 0.00 0.00 4454.32 3822.10 SBF2-NA 0.00 0.00 4513.34 3852.10 SBF1-NB 0.00 0.00 4576.99 3882.10 SBE4-NC 0.00 0.00 4622.70 3902.10 SBE2-NE 0.00 0.00 4768.33 3957.10 SBE1-NF 0.00 0.00 4870.71 3992.10 TSBD-OA 0.00 0.00 4962.20 4022.10 TSBC 0.00 0.00 5099.72 4057.10 TSBB-OB 0.00 0.00 Targets Map Map <~ Latitude --:> <-..Longitude.-> Description TV]) +N/-S +E/-W Northing Easting Deg Min. See Deg . Min Sec Dip. Dir. ft ft ft ft ft 4057.10 -1392.17 2195.53 6008060.00 553955.00 70 25 57.801 N 149 33 36.641 W 4072.10 -1611.53 2819.08 6007845.00 554580.00 70 25 55.641 N 149 33 18.347 W MPI-01A T1b MPI-01A T2b ) BP My Planning Report MAP ') Company: BP Amoco Field: Milne Point Site: M Pt I Pad Well: Plan MPI-15 Wellpath: Plan MPI-15 Targets Date: 7/2212002 Time: 11 :40:36 Page: Co-ordinate(NE) Reference: Well: Plan MPI-15, True North Vertical (TVD) Reference: 62.10' 62.1 Section (\'S) Reference: Well (0.00N,0.00E,83.52Azi) Sun:ey Calculation ,Method: Minimum Curvature Db: Oracle 2 Map Map <-- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPI-01A T3b 4097.10 -1675.66 3413.71 6007785.00 555175.00 70 25 55.008 N 149 33 0.900 W MPI-01A Poly 4112.10 -1749.62 2109.03 6007702.00 553871.00 70 25 54.285 N 149 33 39.182 W -Polygon 1 4112.10 -1749.62 2109.03 6007702.00 553871.00 70 25 54.285 N 1493339.182W -Polygon 2 4112.10 -1759.20 3203.1 0 6007700.01 554965.00 70 25 54.187 N 149 33 7.081 W -Polygon 3 4112.10 -1628.84 4163.12 6007837.02 555924.00 70 25 55.465 N 149 32 38.910 W -Polygon 4 4112.10 -1134.09 4496.58 6008334.02 556253.99 70 26 0.329 N 149 32 29.117 W -Polygon 5 4112.10 551.90 4527.27 6010020.02 556272.98 70 26 16.910 N 149 32 28.187 W -Polygon 6 4112.10 562.43 4162.30 6010028.01 555907.98 70 26 17.015 N 149 32 38.899 W -Polygon 7 4112.10 -904.24 4089.13 6008561.01 555844.99 70 26 2.592 N 149 32 41.070 W -Polygon 8 4112.10 -1331.20 3210.06 6008128.01 554968.99 70 25 58.397 N 149 33 6.871 W -Polygon 9 4112.10 -1331.67 2123.93 6008120.00 553883.00 70 25 58.396 N 149 33 38.741 W MPI-01A T4b 4112.10 -1563.50 3824.53 6007900.00 555585.00 70 25 56.109 N 149 32 48.844 W MPI-01A T5b 4112.10 -1026.93 4328.32 6008440.00 556085.00 70 26 1.384 N 149 32 34.053 W MPI-01A T6b 4127.10 -317.33 4398.25 6009150.00 556150.00 70 26 8.362 N 149 32 31.989 W MPI-01 A T7b 4127.10 493.15 4343.87 6009960.00 556090.00 70 26 16.333 N 149 32 33.571 W Plan Section Information MD hid TVD +N/.;S OLS Build Turö TFO ft d~g ft ft d~gl1QQft deg/100ftdegl10Oft qeg 27.60 0.00 0.00 27.60 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 433.33 2.00 148.00 433.31 -1.97 1.23 1.50 1.50 0.00 148.00 1475.53 28.00 135.00 1431.45 -193.70 187.07 2.50 2.49 -1.25 346.09 1789.79 32.00 130.00 1703.60 -299.44 303.09 1.50 1.27 -1.59 325.81 1916.44 32.00 130.00 1811.00 -342.58 354.50 0.00 0.00 0.00 0.00 2081.84 34.43 122.10 1949.43 -395.64 427.73 3.00 1.47 -4.78 -64.00 3850.59 34.43 122.10 3408.26 -927.08 1275.00 0.00 0.00 0.00 0.00 4749.96 70.01 115.00 3950.82 -1251.51 1893.88 4.00 3.96 -0.79 -11.40 4899.96 70.01 115.00 4002.10 -1311.09 2021.63 0.00 0.00 0.00 0.00 5099.72 78.00 115.00 4057.10 -1392.17 2195.53 4.00 4.00 0.00 0.00 MPI-01A T1b 5209.34 89.68 108.90 4068.85 -1432.77 2296.41 12.00 10.66 -5.56 -27.81 5733.44 89.68 108.90 4071.77 -1602.57 2792.24 0.00 0.00 0.00 0.00 5761.74 89.00 108.00 4072.10 -1611.53 2819.08 4.00 -2.41 -3.20 -126.96 MPI-01A T2b 6278.27 86.59 87.46 4092.17 -1680.66 3327.74 4.00 -0.47 -3.98 -97.02 6309.15 86.59 87.46 4094.00 -1679.30 3358.53 0.00 0.00 0.00 0.00 6364.53 87.00 85.00 4097.10 -1675.66 3413.71 4.50 0.73 -4.45 -80.69 MPI-01A T3b 6495.89 87.16 78.43 4103.80 -1656.76 3543.45 5.00 0.12 -5.00 -88.77 6531.96 87.16 78.43 4105.59 -1649.53 3578.75 0.00 0.00 0.00 0.00 6793.26 90.00 63.00 4112.10 -1563.50 3824.53 6.00 1.09 -5.90 -79.82 MPI-01A T4b 6864.65 90.79 58.79 4111.61 -1528.78 3886.89 6.00 1.11 -5.90 -79.38 6916.49 90.79 58.79 4110.89 -1501.93 3931.22 0.00 0.00 0.00 0.00 7547.00 89.00 21.00 4112.10 -1026.93 4328.32 6.00 -0.28 -5.99 -92.65 MPI-01 A T5b 8148.14 88.61 354.55 4124.84 -436.73 4408.90 4.40 -0.06 -4.40 -91.10 8214.87 88.61 354.55 4126.46 -370.31 4402.56 0.00 0.00 0.00 0.00 8268.04 90.00 356.16 4127.10 -317.33 4398.25 4.00 2.61 3.03 49.34 MPI-01 A T6b 9080.34 90.00 356.16 4127.10 493.15 4343.87 0.00 0.00 0.00 0.00 MPI-01A T7b ) BP ") My Planning Report MAP Compan)': BP Amoco Date: 7/22/2002 Time: 11 :40:36 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-15, True North Site: M Pt I Pad Vertical (TVD) Reference: 62.10' 62.1 \V ell: Plan MPI-15 Section (VS) Reference: Well (0.00N.0.00E.83.52Azi) Wellpath: Plan MPI-15 Surve)' Calculation Method: Minimum Curvature Db: Oracle Survey MO Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 27.60 0.00 0.00 27.60 -34.50 6009436.77 551750.08 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 37.90 6009436.77 551750.08 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 137.90 6009436.77 551750.08 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 237.90 6009436.77 551750.08 0.00 0.00 Start Dir 1.5/100' : 300' MD, 400.00 1.50 148.00 399.99 337.89 6009435.66 551750.78 0.56 1.50 CB-GYRO-SS 433.33 2.00 148.00 433.31 371.21 6009434.81 551751.33 1.00 1.50 Start Dir 2.5/100' : 433.33' M 500.00 3.64 141.68 499.89 437.79 6009432.17 551753.27 2.62 2.50 CB-GYRO-SS 600.00 6.13 138.58 599.52 537.42 6009425.72 551758.82 7.35 2.50 MWD+IFR+MS 700.00 8.62 137.27 698.68 636.58 6009416.27 551767.50 14.84 2.50 MWD+IFR+MS 800.00 11.12 136.54 797.20 735.10 6009403.85 551779.31 25.08 2.50 MWD+IFR+MS 900.00 13.62 136.08 894.87 832.77 6009388.4 7 551794.21 38.04 2.50 MWD+IFR+MS 1000.00 16.12 135.76 991.51 929.41 6009370.17 551812.19 53.69 2.50 MWD+IFR+MS 1100.00 18.61 135.52 1086.95 1024.85 6009348.99 551833.20 72.02 2.50 MWD+IFR+MS 1200.00 21.11 135.34 1180.99 1118.89 6009324.95 551857.21 92.98 2.50 MWD+IFR+MS 1300.00 23.61 135.20 1273.46 1211.36 6009298.12 551884.17 116.54 2.50 MWD+IFR+MS 1400.00 26.11 135.08 1364.19 1302.09 6009268.53 551914.03 142.65 2.50 MWD+IFR+MS 1475.53 28.00 135.00 1431.45 1369.35 6009244.39 551938.47 164.03 2.50 Start Dir 1.5/100' : 1475.53' 1500.00 28.30 134.56 1453.02 1390.92 6009236.32 551946.72 171.25 1.50 MWD+IFR+MS 1600.00 29.56 132.87 1540.54 1478.44 6009203.14 551981.92 202.23 1.50 MWD+IFR+MS 1700.00 30.84 131.31 1626.97 1564.87 6009169.70 552019.48 235.52 1.50 MWD+IFR+MS 1789.79 32.00 130.00 1703.60 1641.50 6009139.47 552055.21 267.37 1.50 End Dir : 1789.79' MD, 1703.6 1800.00 32.00 130.00 1712.25 1650.15 6009136.02 552059.37 271.10 0.00 MWD+IFR+MS 1888.26 32.00 130.00 1787.10 1725.00 6009106.21 552095.41 303.31 0.00 BPRF 1900.00 32.00 130.00 1797.06 1734.96 6009102.24 552100.20 307.59 0.00 MWD+IFR+MS 1916.44 32.00 130.00 1811.00 1748.90 6009096.69 552106.91 313.59 0.00 Start Dir 3/100' : 1916.44' MD 2000.00 33.17 125.88 1881.42 1819.32 6009069.31 552142.58 345.73 3.00 MWD+IFR+MS 2081.84 34.43 122.10 1949.43 1887.33 6009044.15 552180.50 380.37 3.00 End Dir : 2081.84' MD, 1949.4 2100.00 34.43 122.10 1964.41 1902.31 6009038.76 552189.24 388.40 0.00 MWD+IFR+MS 2200.00 34.43 122.10 2046.88 1984.78 6009009.05 552237.34 432.61 0.00 MWD+IFR+MS 2300.00 34.43 122.10 2129.36 2067.26 6008979.34 552285.45 476.81 0.00 MWD+IFR+MS 2400.00 34.43 122.10 2211.84 2149.74 6008949.63 552333.55 521.02 0.00 MWD+IFR+MS 2500.00 34.43 122.10 2294.32 2232.22 6008919.92 552381.66 565.23 0.00 MWD+IFR+MS 2600.00 34.43 122.10 2376.80 2314.70 6008890.21 552429.76 609.44 0.00 MWD+IFR+MS 2700.00 34.43 122.10 2459.27 2397.17 6008860.50 552477.87 653.64 0.00 MWD+IFR+MS 2800.00 34.43 122.10 2541.75 2479.65 6008830.78 552525.97 697.85 0.00 MWD+IFR+MS 2900.00 34.43 122.10 2624.23 2562.13 6008801.07 552574.08 742.06 0.00 MWD+IFR+MS 3000.00 34.43 122.10 2706.71 2644.61 6008771.36 552622.18 786.27 0.00 MWD+IFR+MS 3067.16 34.43 122.10 2762.10 2700.00 6008751.41 552654.49 815.95 0.00 95/8" 3100.00 34.43 122.10 2789.19 2727.09 6008741.65 552670.29 830.47 0.00 MWD+IFR+MS 3200.00 34.43 122.10 2871.66 2809.56 6008711.94 552718.39 874.68 0.00 MWD+IFR+MS 3300.00 34.43 122.10 2954.14 2892.04 6008682.23 552766.50 918.89 0.00 MWD+IFR+MS 3400.00 34.43 122.10 3036.62 2974.52 6008652.52 552814.60 963.09 0.00 MWD+IFR+MS 3500.00 34.43 122.10 3119.10 3057.00 6008622.81 552862.71 1007.30 0.00 MWD+IFR+MS 3600.00 34.43 122.10 3201.57 3139.47 6008593.10 552910.81 1051.51 0.00 MWD+IFR+MS 3673.38 34.43 122.10 3262.10 3200.00 6008571.30 552946.12 1083.95 0.00 TUgnu 3700.00 34.43 122.10 3284.05 3221.95 6008563.39 552958.92 1095.72 0.00 MWD+IFR+MS 3800.00 34.43 122.10 3366.53 3304.43 6008533.68 553007.02 1139.92 0.00 MWD+IFR+MS 3850.59 34.43 122.10 3408.26 3346.16 6008518.65 553031.36 1162.29 0.00 Start Dir 4/100' : 3850.59' MD 3900.00 36.37 121.44 3448.53 3386.43 6008503.76 553055.80 1184.77 4.00 MWD+IFR+MS 4000.00 40.31 120.27 3526.95 3464.85 6008472.35 553109.27 1234.10 4.00 MWD+IFR+MS 4100.00 44.25 119.28 3600.92 3538.82 6008439.37 553167.88 1288.35 4.00 MWD+IFR+MS 4200.00 48.20 118.43 3670.09 3607.99 6008404.99 553231.35 1347.26 4.00 MWD+IFR+MS 4264.67 50.76 117.93 3712.10 3650.00 6008382.08 553274.85 1387.70 4.00 BUgnu ) BP ) My Planning Report MAP Company: BP Amoco Date: 7/22/2002 Time: 11 :40:36 Page: 4 Field: Milne Point Co-ordinate{NE) Reference: Well: Plan MPI-15, True North Site: M Pt I Pad Vertical (TVD) Reference: 62.10'62.1 Well: Plan MPI-15 Section (VS) Reference: Well (0.00N,0.00E,83.52Azi) Wellpath: Plan MPI-15 Survey Calculation Method: Minimum Curvature Db: Oracle Survey !\'ID Incl Azim TVD Sys TVD l\'lapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 4300.00 52.16 117.67 3734.11 3672.01 6008369.37 553299.38 1410.53 4.00 MWD+IFR+MS 4400.00 56.12 116.99 3792.68 3730.58 6008332.68 553371.62 1477.87 4.00 MWD+IFR+MS 4454.32 58.28 116.64 3822.10 3760.00 6008312.38 553412.50 1516.04 4.00 SBF2-NA 4500.00 60.09 116.37 3845.50 3783.40 6008295.12 553447.73 1548.94 4.00 MWD+IFR+MS 4513.34 60.62 116.29 3852.10 3790.00 6008290.05 553458.15 1558.69 4.00 SBF1-NB 4576.99 63.14 115.92 3882.10 3820.00 6008265.70 553508.73 1605.99 4.00 SBE4-NC 4600.00 64.06 115.79 3892.33 3830.23 6008256.85 553527.33 1623.40 4.00 MWD+IFR+MS 4622.70 64.96 115.67 3902.10 3840.00 6008248.08 553545.85 1640.74 4.00 SBE2-NE 4700.00 68.03 115.26 3932.93 3870.83 6008218.06 553610.05 1700.89 4.00 MWD+IFR+MS 4749.96 70.01 115.00 3950.82 3888.72 6008198.55 553652.41 1740.62 4.00 End Dir : 4749.96' MD, 3950.8 4768.33 70.01 115.00 3957.10 3895.00 6008191.36 553668.10 1755.34 0.00 SBE1-NF 4800.00 70.01 115.00 3967.93 3905.83 6008178.97 553695.16 1780.72 0.00 MWD+IFR+MS 4870.71 70.01 115.00 3992.10 3930.00 6008151.31 553755.57 1837.39 0.00 TSBD-OA 4899.96 70.01 115.00 4002.10 3940.00 6008139.87 553780.57 1860.84 0.00 Start Dir 4/100' : 4899.96' MD 4962.20 72.50 115.00 4022.10 3960.00 6008115.34 553834.14 1911.10 4.00 TSBC 5000.00 74.01 115.00 4032.99 3970.89 6008100.27 553867.05 1941.97 4.00 MWD+IFR+MS 5099.72 78.00 115.00 4057.10 3995.00 6008060.00 553955.00 2024.47 4.00 MPI-01A T1 b 5125.00 80.69 113.57 4061.77 3999.67 6008049.94 553977.71 2045.82 12.00 MWD+IFR+MS 5150.00 83.35 112.17 4065.25 4003.15 6008040.48 554000.58 2067.40 12.00 MWD+IFR+MS 5175.00 86.02 110.79 4067.56 4005.46 6008031.53 554023.81 2089.38 12.00 MWD+IFR+MS 5200.00 88.68 109.42 4068.72 4006.62 6008023.11 554047.31 2111.71 12.00 MWD+IFR+MS 5209.34 89.68 108.90 4068.85 4006.75 6008020.11 554056.15 2120.13 12.00 End Dir : 5209.34' MD, 4068.8 5300.00 89.68 108.90 4069.36 4007.26 6007991.34 554142.12 2202.04 0.00 MWD+IFR+MS 5400.00 89.68 108.90 4069.92 4007.82 6007959.60 554236.93 2292.39 0.00 MWD+IFR+MS 5500.00 89.68 108.90 4070.47 4008.37 6007927.86 554331.75 2382.73 0.00 MWD+IFR+MS 5600.00 89.68 108.90 4071.03 4008.93 6007896.12 554426.57 2473.08 0.00 MWD+IFR+MS 5700.00 89.68 108.90 4071.59 4009.49 6007864.38 554521.39 2563.43 0.00 MWD+IFR+MS 5733.44 89.68 108.90 4071.77 4009.67 6007853.77 554553.10 2593.64 0.00 Start Dir 4/100' : 5733.44' MD 5761.74 89.00 108.00 4072.10 4010.00 6007845.00 554580.00 2619.30 4.00 MPI-01A T2b 5800.00 88.81 106.48 4072.83 4010.73 6007833.92 554616.60 2654.32 4.00 MWD+IFR+MS 5900.00 88.33 102.51 4075.32 4013.22 6007809.57 554713.53 2747.65 4.00 MWD+IFR+MS 6000.00 87.85 98.54 4078.65 4016.55 6007792.01 554811.89 2843.21 4.00 MWD+IFR+MS 6100.00 87.39 94.56 4082.80 4020.70 6007781.31 554911.20 2940.53 4.00 MWD+IFR+MS 6200.00 86.94 90.58 4087.75 4025.65 6007777.53 555010.98 3039.14 4.00 MWD+IFR+MS 6278.27 86.59 87.46 4092.17 4030.07 6007779.40 555089.08 3116.92 4.00 End Dir : 6278.27' MD, 4092.1 6309.15 86.59 87.46 4094.00 4031.90 6007780.98 555119.86 3147.67 0.00 Start Dir 4.5/100' : 6309.15' 6364.53 87.00 85.00 4097.10 4035.00 6007785.00 555175.00 3202.90 4.50 MPI-01A T3b 6400.00 87.04 83.22 4098.94 4036.84 6007788.87 555210.20 3238.32 5.00 MWD+IFR+MS 6495.89 87.16 78.43 4103.80 4041.70 6007804.79 555304.60 3333.95 5.00 End Dir : 6495.89' MD, 4103.8 6500.00 87.16 78.43 4104.00 4041.90 6007805.65 555308.62 3338.04 0.00 MWD+IFR+MS 6531.96 87.16 78.43 4105.59 4043.49 6007812.27 555339.84 3369.83 0.00 Start Dir 6/100' : 6531.96' MD 6550.00 87.35 77.36 4106.45 4044.35 6007816.17 555357.43 3387.77 6.00 MWD+IFR+MS 6600.00 87.89 74.40 4108.53 4046.43 6007828.69 555405.78 3437.27 6.00 MWD+IFR+MS 6650.00 88.43 71.45 4110.13 4048.03 6007843.69 555453.44 3486.39 6.00 MWD+IFR+MS 6700.00 88.98 68.50 4111.27 4049.17 6007861.12 555500.28 3534.98 6.00 MWD+IFR+MS 6750.00 89.52 65.55 4111 .92 4049.82 6007880.95 555546.16 3582.91 6.00 MWD+IFR+MS 6793.26 90.00 63.00 4112.10 4050.00 6007900.00 555585.00 3623.76 6.00 MPI-01A T4b 6800.00 90.07 62.60 4112.10 4050.00 6007903.12 555590.97 3630.06 6.00 MWD+IFR+MS 6850.00 90.63 59.65 4111.79 4049.69 6007927.56 555634.57 3676.28 6.00 MWD+IFR+MS 6864.65 90.79 58.79 4111.61 4049.51 6007935.14 555647.11 3689.63 6.00 End Dir : 6864.65' MD, 4111.6 6900.00 90.79 58.79 4111.12 4049.02 6007953.66 555677.21 3721.73 0.00 MWD+IFR+MS 6916.49 90.79 58.79 4110.89 4048.79 6007962.30 555691.25 3736.71 0.00 Start Dir 6/100' : 6916.49' MD ) BP ) My Planning Report MAP Compao,': BP Amoco Date: 7/2212002 Time: 11 :40:36 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-15. True North Site: M Pt I Pad Vertical (TVD) Reference: 62.10' 62.1 Well: Plan MPI-15 Section (VS) Reference: Well (0.00N,O.00E,83.52Azi) Wellpath: Plan MPI-15 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 6950.00 90.70 56.78 4110.46 4048.36 6007980.36 555719.47 3766.89 6.00 MWD+IFR+MS 7000.00 90.55 53.78 4109.91 4047.81 6008009.11 555760.36 3810.93 6.00 MWD+IFR+MS 7050.00 90.41 50.79 4109.49 4047.39 6008039.96 555799.69 3853.68 6.00 MWD+IFR+MS 7100.00 90.27 47.79 4109.20 4047.10 6008072.83 555837.35 3895.01 6.00 MWD+IFR+MS 7150.00 90.12 44.79 4109.02 4046.92 6008107.62 555873.25 3934.82 6.00 MWD+IFR+MS 7200.00 89.98 41.80 4108.98 4046.88 6008144.24 555907.28 3972.99 6.00 MWD+IFR+MS 7250.00 89.84 38.80 4109.06 4046.96 6008182.59 555939.34 4009.42 6.00 MWD+IFR+MS 7300.00 89.69 35.80 4109.26 4047.16 6008222.56 555969.36 4044.01 6.00 MWD+IFR+MS 7350.00 89.55 32.81 4109.60 4047.50 6008264.05 555997.25 4076.66 6.00 MWD+IFR+MS 7400.00 89.41 29.81 4110.05 4047.95 6008306.94 556022.93 4107.29 6.00 MWD+IFR+MS 7450.00 89.27 26.81 4110.63 4048.53 6008351.11 556046.33 4135.82 6.00 MWD+IFR+MS 7500.00 89.13 23.82 4111.33 4049.23 6008396.44 556067.39 4162.15 6.00 MWD+IFR+MS 7547.00 89.00 21.00 4112.10 4050.00 6008440.00 556085.00 4184.85 6.00 MPI-01A T5b 7600.00 88.96 18.67 4113.05 4050.95 6008489.96 556102.63 4208.34 4.40 MWD+IFR+MS 7700.00 88.88 14.27 4114.94 4052.84 6008586.00 556130.30 4247.31 4.40 MWD+IFR+MS 7800.00 88.81 9.87 4116.96 4054.86 6008683.88 556150.51 4279.10 4.40 MWD+IFR+MS 7900.00 88.74 5.47 4119.10 4057.00 6008783.02 556163.16 4303.52 4.40 MWD+IFR+MS 8000.00 88.68 1.07 4121.35 4059.25 6008882.84 556168.16 4320.44 4.40 MWD+IFR+MS 8100.00 88.63 356.67 4123.69 4061.59 6008982.74 556165.49 4329.74 4.40 MWD+IFR+MS 8148.14 88.61 354.55 4124.84 4062.74 6009030.69 556161.47 4331.49 4.40 End Dir : 8148.14' MD, 4124.8 8200.00 88.61 354.55 4126.10 4064.00 6009082.26 556156.19 4332.42 0.00 MWD+IFR+MS 8214.87 88.61 354.55 4126.46 4064.36 6009097.05 556154.67 4332.69 0.00 Start Dir 4/100' : 8214.87' MD 8268.04 90.00 356.16 4127.10 4065.00 6009150.00 556150.00 4334.38 4.00 MPI-01A T6b 8300.00 90.00 356.16 4127.10 4065.00 6009181.87 556147.64 4335.85 0.00 MWD+IFR+MS 8400.00 90.00 356.16 4127.10 4065.00 6009281.58 556140.25 4340.45 0.00 MWD+IFR+MS 8500.00 90.00 356.16 4127.10 4065.00 6009381.30 556132.86 4345.06 0.00 MWD+IFR+MS 8600.00 90.00 356.16 4127.10 4065.00 6009481.02 556125.47 4349.66 0.00 MWD+IFR+MS 8700.00 90.00 356.16 4127.10 4065.00 6009580.74 556118.08 4354.26 0.00 MWD+IFR+MS 8800.00 90.00 356.16 4127.10 4065.00 6009680.45 556110.70 4358.86 0.00 MWD+IFR+MS 8900.00 90.00 356.16 4127.10 4065.00 6009780.17 556103.31 4363.46 0.00 MWD+IFR+MS 9000.00 90.00 356.16 4127.10 4065.00 6009879.89 556095.92 4368.06 0.00 MWD+IFR+MS 9080.33 90.00 356.16 4127.10 4065.00 6009959.99 556089.98 4371.75 0.00 MPI-01A T7b 9080.32 90.00 356.16 4127.10 4065.00 6009959.98 556089.98 4371.75 0.00 Total Depth: 9080.34' MD, 412 9080.34 90.00 356.16 4127.10 4065.00 6009960.00 556090.00 4371.77 0.00 MWD+IFR+MS ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME hP / -/.~ PTD# ..2-0 :2.- - J 5 2- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation. order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. H 206980 DATE INVOICE I CREDIT MEMO 7/1/02 CK062602B DATE 7/01/02 CHECK NO. H206980 DESCRIPTION GROSS VENDOR DISCOUNT NET PERMIT TO DRILL FEE ('01Ç>\,\S ~LI THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP,' EXPLORATION~\(AL.ASKA) .INC. P.O. BOX 196612 "i} . ANCHORAGE, ALASKA 99519..6612 PAY TO THE ORDER OF ALASKA STATE ALASKA OIL & GAS 333, W 7TH AVE ANCHORAGE, AI<.; . flAST 't4ft'OON"L..I;SAN"ØF"$IiLANP, A" Àff'JUATE)OF ' NATIONAL CITY BANK CLeVl;~P, OHIO Itl 20 b q 8 0 III I: 0... ~ 20 j 8 q 5 I: 00 a ...... ~ q III . I H '.-" WELLPERMITCHECKLlST COMPANY L1/'Æ WELLNAME/o//J-/S PROGRAM: Exp- DevARedrll- Re-Enter- Serv- Wellboreseg- .FIELD&POOL 52.5"/7"0 INITCLASS /}r-...v /-0// GEOLAREA ~7o UNIT# //32 ~ ON/OFFSHORE øN .ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . , . . . . R N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number.. . . . . . . . . . . . . . . . Y N 4, Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, iswellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . , . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y I N 11. Permit can be issued without conservation order. . . . . , . . W N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #- N . (Service Well Only) 14. All wells w/in X mile area of review identified. . . . . . . . ., Y N / ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ø NN 1,0'/@{-I'Z.. 16. Surface casing protects all known USDWs. . . . . . . . . . . éi2 17. CMT vol adequate to circulate on conductor & surf csg. . . . . tJ) N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y (Ii l..d' 19. CMT will cover all known productive horizons. . . . . . . . . . :L.... IjJ S'cl(~J. 20. Casing designs adequate for C, T, B & permafrost. . . . . , . (.J(N- 21. Adequate tankage or reserve pit... . . . . . . . . . . . . . . éi! N i)~ fill'- 1'-/.1. 22. If a re-drill, has a 10-403 for abandonment been approved. . . Y N - tV/A- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N 25. Drilling fluid program schematic & equip list adequate. . . . . N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . NN I JJ {' P. J~;J z nSl'~' APPR DATE 27. BOPE press rating appropriate; test to '-1000 psig. ,,,'It> -:> "t :;J r {I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N VJ.~Å 1 1,f IJL- 29. Work will occur without operation shutdown. . . . . . . . . . . I !;.." 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . <JW 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ AI/It- 32. Permit can be issued w/o hydrogen sulfide measures. . . . . ø N 33. Data presented on potential overpressure zones. . .. .. .. .. ., .. y: N~ A /J. /ì, 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . / I..' H 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~ TEM JDH~?¡f~S- JBR APPR DATE ~/Æ1h2- (Service Well Only) GEOLOGY APPR DATE #J¿ ~þ~ (Exploratory Only) Rev: 07/12/02 SFD- WGA \¡J6Á-" MJW G: \geology\permits\checklist.doc COMMISSIONER: COT DTS 7/ '2-( /' Comments/Instructions: ') ) Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 03 09:11:37 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 12 / 0 3 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. .............. . UNKNOWN Continuation Number..... .01 Previous Tape Name. ..... . UNKNOWN Comments................ .STS LIS ) a Oóì-l.:5;) 11341 Library. Scientific Technical Services Writing Library. Scientific Technical Services JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22136 J. STRAHAN E. VAUGHN Physical EOF Comment Record TAPE HEADER Milne Point MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MW-22136 J. STRAHAN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MPI-15 500292310600 BP Exploration (Alaska), Inc Sperry-Sun Drilling Services 03-DEC-02 MWDRUN 2 AK-MW-22136 J. STRAHAN E. VAUGHN 33 13N 10E 2326 3641 62.50 35.00 MWDRUN 3 AK-MW-22136 J. STRAHAN E. VAUGHN ) ) # WELL CASING RECORD 1ST STRING 2ND STRING 3 RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 12.250 8.750 6.125 CASING SIZE (IN) 20.000 9.625 7.000 DRILLERS DEPTH (FT) 112.0 3084.0 5204.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SEGMENT IS AN OPEN-HOLE SIDETRACK FROM THE MPI-15 PB1 WELL BORE , THE KICK-OFF POINT (KOP) BEING 5510'MD/4047'TVD. 4. MWD RUNS 1, 2, 3, AND 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3 AND 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1, 2, PART OF 3, AND 4 REPRESENT WELL MPI-15 WITH API#: 50-029-23106-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9050'MD/ 4106'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. 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. ..... .02/12/03 Maximum Physical Record..65535 File Type. ...... ....... ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ ) 1 ) clipped curves; all bit runs merged. .5000 START DEPTH 42.5 86.0 90.5 90.5 90.5 90.5 90.5 STOP DEPTH 8997.0 9050.0 9004.0 9004.0 9004.0 9004.0 9004.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 42.5 3092.0 5216.0 5510.5 MERGE BASE 3092.0 5216.0 5510.0 9050.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............ .... . Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing...... .............. .60 .1IN Max frames per record....... ......Undefined Absent value. ............ ~....... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . 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 42.5 9050 4546.25 18016 42.5 9050 ROP MWD FT/H 1.92 1776.88 245.488 17929 86 9050 GR MWD API 13.53 133.81 69.5499 17910 42.5 8997 RPX MWD OHMM 0.06 1191.14 16.3481 17677 90.5 9004 RPS MWD OHMM 0.17 1191.17 20.6139 17677 90.5 9004 ) ) RPM MWD OHMM 0.15 2000 25.9143 17677 90.5 9004 RPD MWD OHMM 0.1 2000 29.1964 17677 90.5 9004 FET MWD HOUR 0.0683 70.8397 0.590405 17677 90.5 9004 First Reading For Entire File..... .... .42.5 Last Reading For Entire File. ......... .9050 File Trailer Service name. ...... ..... .STSLIB.001 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.. ... ..02/12/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...... .STSLIB.002 Physical EOF File Header Service name......... ....STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ..... .02/12/03 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.001 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP RPX RPS RPM RPD FET $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 42.5 86.0 90.5 90.5 90.5 90.5 90.5 STOP DEPTH 3050.0 3092.0 3041.5 3041.5 3041.5 3041.5 3041.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL ( FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17-AUG-02 Insite 66.37 Memory 3092.0 112.0 3092.0 .0 36.2 # TOOL STRING (TOP TO BOTTOM) ) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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.... ..............0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units.......... .Feet Data Reference Point.... ......... . Undefined Frame Spacing. ........... ........ .60 .1IN Max frames per record.... ....... ..Undefined Absent value. ................. ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) TOOL NUMBER 136694 134760 12.250 112.0 Water 9.15 211.0 7.5 900 10.1 Based 6.000 5.500 7.000 4.500 66.0 72.6 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42.5 3092 1567.25 6100 42.5 3092 ROP MWD010 FT/H 20.19 1235.55 246.022 6013 86 3092 GR MWD010 API 13.53 117.52 58.5865 6016 42.5 3050 RPX MWD010 OHMM 0.33 301.11 25.7147 5903 90.5 3041.5 RPS MWD010 OHMM 0.18 653.35 36.6394 5903 90.5 3041.5 RPM MWD010 OHMM 0.15 2000 50.1451 5903 90.5 3041.5 ') RPD MWD010 OHMM FET MWD010 HOUR 0.13 0.0683 2000 2.1393 ) 58.2868 5903 0.466831 5903 First Reading For Entire File.. ... ... ..42.5 Last Reading For Entire File.... .... ...3092 File Trailer Service name.... ........ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..02/12/03 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..... ..02/12/03 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 GR RPS FET RPD RPX RPM ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3050.5 3084.5 3084.5 3084.5 3084.5 3084.5 3092.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL ( FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 5179.5 5172.0 5172.0 5172.0 5172.0 5172.0 5216.0 19-AUG-02 Insite 66.37 Memory 5216.0 3092.0 5216.0 34.3 84.9 TOOL NUMBER 90.5 90.5 3041.5 3041.5 ') DGR EWR4 $ 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... .......... .....0 Data Specification Block Type. ....0 Logging Direction.......... ...... . Down Optical log depth units.......... .Feet Data Reference Point... ....... ....Undefined Frame Spacing............. ..... ...60 .1IN Max frames per record. ....... .... . Undefined Absent value.... ....... ....... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 136694 134760 8.750 3084.0 Water 10.15 53.0 7.8 600 7.2 Based 9.000 6.190 9.500 7.000 65.0 97.5 65.0 65.0 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 3050.5 5216 4133.25 4332 3050.5 5216 ROP MWD020 FT/H 13.05 756.55 307.451 4248 3092.5 5216 GR MWD020 API 21.68 118.41 70.756 4259 3050.5 5179.5 RPX MWD020 OHMM 0.06 301.11 13.639 4176 3084.5 5172 RPS MWD020 OHMM 1.24 201.6 13.2271 4176 3084.5 5172 RPM MWD020 OHMM 0.93 2000 13.9874 4176 3084.5 5172 RPD MWD020 OHMM 0.1 2000 16.285 4176 3084.5 5172 ) FET MWD020 HOUR 0.0803 40.3652 ) 0.50566 4176 3084.5 5172 First Reading For Entire File. ........ .3050.5 Last Reading For Entire File.. ....... ..5216 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.003 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5180.0 5205.5 5205.5 5205.5 5205.5 5205.5 5216.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 5510.0 5510.0 5510.0 5510.0 5510.0 5510.0 5510.0 23-AUG-02 Insite 66.37 Memory 5510.0 5216.0 5510.0 79.9 90.0 TOOL NUMBER 151107 ) EWR4 $ 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...... ..... .......0 Data Specification Block Type.....O Logging Direction....... .... ......Down Optical log depth units. ......... .Feet Data Reference Point............. . Undefined Frame Spacing..................... 60 .1IN Max frames per record.. ..... ......Undefined Absent value........ .... ......... .-999 Depth Uni t s. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 156401 6.125 5204.0 Flo-pro 9.55 50.0 9.1 68000 4.8 .090 .070 .080 .100 70.0 87.8 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5180 5510 5345 661 5180 5510 ROP MWD030 FT/H 7.32 810.11 201.414 588 5216.5 5510 GR MWD030 API 33.71 94.58 72.1402 661 5180 5510 RPX MWD030 OHMM 0.15 1191.14 13.2604 610 5205.5 5510 RPS MWD030 OHMM 0.17 1191.17 15.0059 610 5205.5 5510 RPM MWD030 OHMM 5.56 2000 28.6 610 5205.5 5510 RPD MWD030 OHMM 7.18 1763.99 22.5207 610 5205.5 5510 FET MWD030 HOUR 0.1851 70.8397 3.69702 610 5205.5 5510 ) First Reading For Entire File......... .5180 Last Reading For Entire File... ..... ...5510 File Trailer Service name... ..... .... .STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/12/03 Maximum Physical Record..65535 File Type.............. ..LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/12/03 Maximum Physical Record. .65535 File Type.... ..... ...... .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 5 ) header data for each bit run in separate files. 4 .5000 START DEPTH 5510.5 5510.5 5510.5 5510.5 5510.5 5510.5 5510.5 # 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: # STOP DEPTH 9004.0 9004.0 9004.0 9004.0 8997.0 9050.0 9004.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis'. 4 25-AUG-02 Insite 66.37 Memory 9050.0 5510.0 9050.0 84.1 93.0 TOOL NUMBER 151107 156401 ) ) $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 5204.0 # 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: Flo-pro 9.60 57.0 9.6 54500 6.0 .190 .150 .120 .110 74.0 98.6 74.0 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ......... ......0 Data Specification Block Type... ..0 Logging Direction......... ... ... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing............... ..... .60 .1IN Max frames per record.......... ...Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5510.5 9050 7280.25 7080 5510.5 9050 ROP MWD040 FT/H 1.92 1776.88 211.517 7080 5510.5 9050 GR MWD040 API 46.34 133.81 78.0254 6974 5510.5 8997 RPX MWD040 OHMM 2.64 55.92 10.3244 6988 5510.5 9004 RPS MWD040 OHMM 4 80.81 11.9804 6988 5510.5 9004 RPM MWD040 OHMM 4.25 46.14 12.3388 6988 5510.5 9004 RPD MWD040 OHMM 5.13 31.44 12.9212 6988 5510.5 9004 FET MWD040 HOUR 0.1564 30.2673 0.488664 6988 5510.5 9004 ) First Reading For Entire File....... ...5510.5 Last Reading For Entire File..... ..... .9050 File Trailer Service name..... ..... ...STSLIB.005 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/12/03 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name... ....... .STSLIB.006 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/03 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. . . . . . . . . . . . . . . . . . . . . 02/12/03 Origin. . . . . . . . . . . . . . . . ... . STS Reel Name...... .... .... ..UNKNOWN Continuation Number. .... .01 Next Reel Name... .... ... . UNKNOWN Comments..... .... ....... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) ó? oà-j ~ 1/3V Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 02 13:38:25 2002 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/02 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 Da te. . . . . . . . . . . . . . . . . . . . . 02/12/02 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-15 PBl 500292310670 BP Exploration (Alaska), Inc Sperry-Sun Drilling Services 02-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22136 J. STRAHAN E. VAUGHN MWDRUN 2 AK-MW-22136 J. STRAHAN E. VAUGHN MWDRUN 3 AK-MW-22136 J. STRAHAN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2326 3641 62.50 35.00 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.750 9.625 3084.0 ) 3RD STRING PRODUCTION STRING 6.125 7.000 5204.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1, 2, AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/29/02. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1, 2, AND 3 REPRESENT WELL MPI-15 PBl WITH API#: 50-029- 23106-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6095'MD/4089'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name........... ..STSLIB.OOl Service Sub Level Name... Version Number.... .... ...1.0.0 Date of Generation.... ...02/12/02 Maximum Physical Record..65535 File Type........ .... ....LO Previous File Name... ... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD 1 clipped curves; all bit runs merged. .5000 START DEPTH 42.5 86.0 90.5 90.5 STOP DEPTH 6039.5 6094.5 6046.5 6046.5 ) RPM RPS RPX $ 90.5 90.5 90.5 6046.5 6046.5 6046.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 42.5 2 3092.0 3 5216.0 MERGE BASE 3092.0 5216.0 6094.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type... ..0 Logging Direction..... ..... ...... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing............. ...... ..60 .1IN Max frames per record..... ....... . Undefined Absent value....... ... ..... ...... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42.5 6094.5 3068.5 12105 42.5 6094.5 ROP MWD FT/H 7.32 1235.55 261.845 12018 86 6094.5 GR MWD API 13.53 118.41 65.1545 11995 42.5 6039.5 RPX MWD OHMM 0.06 1191.14 19.3823 11762 90.5 6046.5 RPS MWD OHMM 0.17 1191.17 24.9599 11762 90.5 6046.5 RPM MWD OHMM 0.15 2000 32.759 11762 90.5 6046.5 RPD MWD OHMM 0.1 2000 37.4372 11762 90.5 6046.5 FET MWD HOUR 0.0683 70.8397 0.721517 11762 90.5 6046.5 First Reading For Entire File........ ..42.5 Last Reading For Entire File....... ....6094.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 ) Date of Generation...... .02/12/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.002 physical EOF File Header Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/02 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 RPD RPM RPS RPX FET $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 42.5 86.0 90.5 90.5 90.5 90.5 90.5 # 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: # STOP DEPTH 3050.0 3092.0 3041.5 3041.5 3041.5 3041.5 3041.5 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): 17-AUG-02 Insite 66.37 Memory 3092.0 112.0 3092.0 .0 36.2 TOOL NUMBER 136694 134760 12.250 112.0 Water Based 9.15 211.0 ') ) MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 7.5 900 10.1 6.000 5.500 7.000 4.500 66.0 72.6 66.0 66.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point........ ..... . Undefined Frame Spac ing. . . . . . . . . . . . . . . . . . . . . 60 . 1 IN 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 42.5 3092 1567.25 6100 42.5 3092 ROP MWD010 FT/H 20.19 1235.55 246.022 6013 86 3092 GR MWD010 API 13.53 117.52 58.5865 6016 42.5 3050 RPX MWD010 OHMM 0.33 301.11 25.7147 5903 90.5 3041.5 RPS MWD010 OHMM 0.18 653.35 36.6394 5903 90.5 3041.5 RPM MWD010 OHMM 0.15 2000 50.1451 5903 90.5 3041.5 RPD MWD010 OHMM 0.13 2000 58.2868 5903 90.5 3041.5 FET MWD010 HOUR 0.0683 2.1393 0.466831 5903 90.5 3041.5 First Reading For Entire File.... ..... .42.5 Last Reading For Entire File.......... .3092 File Trailer Service name... ..... .... .STSLIB.002 Service Sub Level Name. . . Version Number. .... ..... .1.0.0 Date of Generation...... .02/12/02 ) 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...... .02/12/02 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 GR FET RPD RPM RPS RPX ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 3050.5 3084.5 3084.5 3084.5 3084.5 3084.5 3092.5 # 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: # STOP DEPTH 5179.5 5172.0 5172.0 5172.0 5172.0 5172.0 5216.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 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: 19-AUG-02 Insite 66.37 Memory 5216.0 3092.0 5216.0 34.3 84.9 TOOL NUMBER 136694 134760 8.750 3084.0 Water Based 10.15 53.0 7.8 ) 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: 600 7.2 9.000 6.190 9.500 7.000 65.0 97.5 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. .... ............0 Data Specification Block Type.....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 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 3050.5 5216 4133.25 4332 3050.5 5216 ROP MWD020 FT/H 13.05 756.55 307.451 4248 3092.5 5216 GR MWD020 API 21.68 118.41 70.756 4259 3050.5 5179.5 RPX MWD020 OHMM 0.06 301.11 13.639 4176 3084.5 5172 RPS MWD020 OHMM 1.24 201.6 13.2271 4176 3084.5 5172 RPM MWD020 OHMM 0.93 2000 13.9874 4176 3084.5 5172 RPD MWD020 OHMM 0.1 2000 16.285 4176 3084.5 5172 FET MWD020 HOUR 0.0803 40.3652 0.50566 4176 3084.5 5172 First Reading For Entire File... ...... .3050.5 Last Reading For Entire File.......... .5216 File Trailer Service name.... ....... ..STSLIB.003 Service Sub Level Name. . . Version Number. .... ......1.0.0 Date of Generation..... ..02/12/02 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.. ...... ...STSLIB.004 Physical EOF File Header Service name. ... ..... ... .STSLIB.004 Service Sub Level Name... Version Number.. ..... ... .1.0.0 Date of Generation... ... .02/12/02 Maximum Physical Record. .65535 File Type.... ... ........ .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 5180.0 5205.5 5205.5 5205.5 5205.5 5205.5 5216.5 # 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 $ STOP DEPTH 6039.5 6046.5 6046.5 6046.5 6046.5 6046.5 6094.5 23-AUG-02 Insite 66.37 Memory 6095.0 5216.0 6095.0 79.9 90.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 151107 156401 # 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): 6.125 5204.0 Flo-Pro 9.55 50.0 9.1 68000 ) ) 4.8 .090 70.0 .070 87.8 .080 70.0 .100 70.0 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....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 MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5180 6094.5 5637.25 1830 5180 6094.5 ROP MWD030 FT/H 7.32 810.11 205.732 1757 5216.5 6094.5 GR MWD030 API 33.71 99.9 74.2571 1720 5180 6039.5 RPX MWD030 OHMM 0.15 1191.14 11.4229 1683 5205.5 6046.5 RPS MWD030 OHMM 0.17 1191.17 13.1072 1683 5205.5 6046.5 RPM MWD030 OHMM 5.44 2000 18.3563 1683 5205.5 6046.5 RPD MWD030 OHMM 6.37 1763.99 16.7933 1683 5205.5 6046.5 FET MWD030 HOUR 0.1851 70.8397 2.21026 1683 5205.5 6046.5 First Reading For Entire File.... ..... .5180 Last Reading For Entire File........ ...6094.5 File Trailer Service name. .... ....... .STSLIB.004 Service Sub Level Name. . . Version Number... ....... .1.0.0 Date of Generation.. .... .02/12/02 Maximum Physical Record. .65535 File Type................LO ) Next File Name.... ..... ..STSLIB.005 physical EOF Tape Trailer Service name...... ... ....LISTPE Date.................... .02/12/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number. .... .01 Next Tape Name. ......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name.. ...... .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/12/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ... ....... .... . UNKNOWN Continuation Number..... .01 Next Reel Name.... ... ....UNKNOWN Comments..... ...... ..... .STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services