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Home My WebLink About205-1491. 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: ___________________ 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: N/A N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9350' 2290 psi None Casing Collapse Structural Conductor Surface 1540 Intermediate 4750 Production 6290 Liner 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:Jake Flora Contact Email:JFlora@asrcenergy.com Contact Phone:720-988-5375 Authorized Title: Vice President 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 Middle Lake Unit 1A 8995' Surface Surface Exploratory Surface, 2858' & 8550' Subsequent Form Required: Suspension Expiration Date: 27' 27' N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer @ 8768' MD / 8423' TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 205-149 3900 C Street, Suite 701, Anchorage, AK, 99503 50-283-20021-01-00 ASRC Energy Services Alaska, Inc. Proposed Pools: 9338' TVD Burst 2958' 8983' MD 6870 30902947' 8116' 281' 27' 30" 20" 13-3/8" 281' None 7740 5-1/2" ArrowPak Retrievable Packer No SSSV Perforation Depth MD (ft): 5-1/2" 9338' 281' 8563' - 8700' (plugged) 8457' 8910' - 9050' (plugged) 9-5/8"8457' 2958' 2/15/2026 None Perforate PPPerforate New Pool Re-enter Susp Well Reppair Well Exploratory Stratigraphic Development Mechanical Integrity Test Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:41 am, Jan 23, 2026 12:01 pm, Jan 23, 2026 X DSR-2/2/26 See attached conditions of approval. X 10-407 BJM 2/4/26 X SFD 2/4/2026 Requested variance to 20 AAC 25.112(a)(1) is approved. JLC 2/9/2026 02/09/26 Middle Lake Unit 1A (PTD 205-149) Sundry 325-774 Conditions of approval: 1. CT BOP test to 3000 psi. Provide AOGCC 24 hrs notice for opportunity to witness the test. 2. Submit daily reports to AOGCC every day from when rig is being mobilized to the wellsite until the rig has been de-mobilized. 3. adaptor. 4. Submit piping diagram to AOGCC and obtain approval before rig up CT on the wellhead. 5. wellhead, before any cement top job is performed. 6. Be prepared to perform a top job inside each annulus and the inner casing in the 7. Photo-document cut- 8. inspection in summer months after snow has melted. 9. See Variance requests and approvals in section 4.0. January 20, 2026 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request to Plug & Abandon Middle Lake Unit #1A Well (PTD: 205-149 / API: 50-283-20021-01-00) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to permanently plug and abandon the Middle Lake 1A well, located near Point McKenzie on the west side of the Cook Inlet. Please contact Clark Olsen at (907) 252-2248 or Jake Flora at 720-988-5375 with any questions. Sincerely, Doug Cismoski ASRC Consulting & Environmental Services, LLC Sincerely, Application for Sundry Approval (10-403) (P&A of Suspended Well) Middle Lake Unit #1A South Central, Alaska January 2026 Prepared for Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 2 of 12 TABLE OF CONTENTS Page Table of Contents ........................................................................................................................................ 2 1.0 Well Summary ................................................................................................................................ 3 2.0 Scope of Work ................................................................................................................................ 3 3.0 General Well Information .............................................................................................................. 3 4.0 Regulatory Variance / Waiver Requests ....................................................................................... 4 5.0 Proposed P&A Procedure .............................................................................................................. 5 List of Attachments Attachment 1 - Current Wellbore Schematic ................................................................................. 8 Attachment 2 - Proposed P&A Wellbore Schematic ................................................................................ 9 Attachment 3 - Well Head ................................................................................................................ 10 Attachment 4 - CTU-BOP Configuration ................................................................................................. 11 Attachment 5 - Proposed Snow Road Map ............................................................................................. 12 Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 3 of 12 MIDDLE LAKE 1A 1.0 Well Summary Gulf Oil drilled Middle Lake Unit #1 in 1969 to a TD of 9742 MD in the Tyonek formation. 9-5/8 intermediate casing was set at 8879 MD, followed by 8-1/2 production hole drilled to TD at 9742 MD. The production hole was logged and abandoned with 150 sx of cement. The intermediate hole section was perforated and tested from 8856 to 8978 MD before abandoning the wellbore with multiple cement plugs. In 2005, Forest Oil Corporation re-entered and sidetracked the wellbore from the 9-5/8 casing at 8457 MD to a new BHL, changing the well to Middle Lake Unit #1A. A 5-1/2 liner was cemented and perforating from 8910 to 9050 MD and tested only water, the wellbore was once again abandoned with multiple cement plugs in 2006. As part of the State of Alaska AOGCC Orphan Well Program the Middle Lake Unit #1A is being re- entered to finish abandoning the well per current AOGCC regulations. The work plan includes placing an abandonment cement plug at the base of the surface casing shoe at 2958 MD as well as a plug from 150 to surface across multiple casing strings. AES-AK will conduct the P&A as Operator, on behalf of the State of Alaska AOGCC. Operations on Middle Lake Unit #1A are scheduled to begin 1Q of 2026. 2.0 Scope of Work The Middle Lake Unit #1A well site is located approximately 1.3 miles west of where Holstein Ave comes to an end in the Point Mackenzie area. The 1.9 acre well site requires brush clearing, leveling, snow road and bridge construction for access. Coiled tubing (CTU) will mill out an existing surface plug, then clean out to an existing cement plug at 2858 MD in the 5-1/2 casing. CTU will use TCP to perforate the 5-1/2 casing from 2845- 2850 MD to establish circulation with the 9-5/8 X 5-1/2 annulus (IA) and 13 3/8 X 9-5/8 annulus (OA). Cement will be placed by pumping down the 5-1/2 casing while taking returns from the OA and then allowed to u-tube into the IA. Pressure tests of the IA and OA will be performed followed by setting a 5-1/2 CIBP at 160 and perforating at 150 to allow circulating cement to surface in the casing, IA, and OA. The current cellar will be removed to allow well excavation, the wellhead will be cut off at 3 below original grade and an abandonment plate will be installed. A water well exists on the pad that will also be abandoned, however this scope is not included in the sundry. 3.0 General Well Information Status: Suspended Orphan Well: The well has 3 existing cement plugs inside the 5- 1/2 casing with the TOC of highest plug just below surface. A January 2024 site visit found no active leaks or gas detected (0% LEL measured) from around the well. Base of Fresh Water: Estimated at 2700 MD / 2691 TVD Reservoir Pressure: The deepest interval to be exposed during the P&A operation is the open hole section behind the 9-5/8 casing from ~6339 MD to the 13-3/8 casing shoe at 2958 MD. Data obtained from mud logs indicates gas shows from 3700 Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 4 of 12 onwards from coal and sands. The interval down to 6339 MD was successfully drilled with a 10.3 ppg mud through 6100 MD and 10.7 ppg through 6500 MD. MASP: The Maximum Anticipated Surface Pressure is based upon a gas gradient to surface from the deepest section exposed during P&A operations at 6339 MD / 6054 TVD and at a worst-case pore pressure of 10.7 ppg EMW. MASP is calculated as ~2763 psi. BHP = 3368 psi (based on 10.7 ppg mud gradient to 6054 TVD) MASP = 2763 psi (based on BHP minus gas gradient to surface) TD of 5-1/2 casing: 9338 MD Current Plugs TOC: 8545 MD / 2858 MD / ~4 BGL Perforations: 8910 9004 / 9008 9020 / 9030 9050 All intervals have cement above. Wellhead: Vetco Gray 13-3/8 Casing x 13-5/8 5M x 11 5M x 11 10M BOP Configuration: Coiled Tubing 4-1/16, 10M BOP BOP Test Pressure: 3000 psi 4.0 Regulatory Variance / Waiver Requests The uncemented interval behind the 9-5/8 casing from the 13-3/8 surface casing shoe at 2958 to the estimated top of cement at 6339 MD had reported gas shows on the mud log during the original drilling. This interval encompasses the Tyonek Formation with a top at approximately 2300 MD with mud log gas shows being predominantly from coals but also from sands at approximately 3800, 5000, and 5200 MD. The interbedded Tyonek coals and sands are of the same formation and similar in nature and based upon this information, the proposed P&A plan for Middle Lake Unit 1A does not involve operations that will attempt to isolate zones from one another within this uncemented interval. ACES requests a variance to 20 AAC 25.112.(a)(1) to treat this as one common hydrocarbon- bearing strata and design the P&A plug placement to only isolate this interval from any fresh-water stratum above. ACES requests a variance to the requirements of 20 AAC 25.112 (b) to allow moving the cement plug segregating cased and uncased sections of the well up into the casing shoe by ~258, rather than across the casing shoe. This will allow keeping the existing Plug #2 in place within the 5-½ casing and moves the plug out of open hole and further into the shoe, which should improve chances of establishing circulation in the 13-3/8 x 9-5/8 annulus and aid cement plug placement. The base of the proposed plug will start at ~2850 MD, which is below the base of any potential freshwater intervals estimated at 2700 MD. Variance request is approved. -bjm Recommend approving requested variance to 20 AAC 25.112(a)(1). Detailed evaluation of mud log and well log information and the lack of interest by two previous operators indicates these scattered, thin, isolated sands are not significant hydrocarbon accumulations. SFD Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 5 of 12 5.0 Proposed P&A Procedure Pre-CTU Work 1. Notify AOGCC 48 hours prior to equipment arrival. 2. Service and equip the active (those with valves present) wellhead outlets with a redundant valve configuration and check the well for pressure at surface. Bleed pressure as required and monitor for any pressure rebuild. 3. Remove the 2-9/16 Dry hole tree valve. Install a 11-10M X 11-5M DSA, 11-5M X 7-1/16-5M flange, and 2 each 7-1/16 tree valves with Tapped Flange with gauge for monitoring. 4. Remove the corrugated wellhouse from around the well and confirm integrity of the existing well cellar for operations. Repair as required and make any final site preparations for CTU arrival. Coiled Tubing Based Operations 1. Move in and rig up Coiled Tubing and equipment. Provide AOGCC 24 hours advance notice to witness BOPE test. Rig up hardline from pump-in sub to choke manifold and return tank. Locate diffuser tank far enough from CTU to take gas returns while drilling through surface cement plug. 2. Nipple up BOPE and test to 250 psi low / 3000 psi high. 3. Record shut-in surface pressures. 4. Make-up 4-¾ cleanout BHA and proceed to drill out ~210' surface cement plug in 5-½ casing with water. Records indicate a total of 14 sacks cement placed at surface, equating to 230 in the 5-½ casing. The plug was tagged at 4 below ground level. Prepare for the risk of trapped pressure beneath the cement plug using the choke and verify wind direction, ensure gas monitors are being worn. CTU will use hot water for drilling the surface cement plug. 5. Continue running in hole with 4-¾ cleanout BHA to ~2850. Wash and tag second cement plug. In January 2006, a ~200 cement plug was placed on top of a CIBP set at 3058 and therefore, the depth and quality of the plug is fairly certain. The desire is to tag the plug without drilling. If stringers or the plug itself is encountered shallower than expected, clean out to 2850 to ensure space for the upcoming perforation of the 5-½ casing and P&A plug placement at 2700. 6. Perform base-line pressure test of the 5-½ casing (casing) to 3000 psi. A column of 15.3 ppg cement will create a 1037 psi differential across the plug and across the 5-1/2 casing below the plug in the annulus. Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 6 of 12 7. Pull out of the hole, lay down the bit and BHA. 8. MU TCP perforating assembly, RIH, tag TOC for depth correction. Perforate the 5-1/2 casing penetrating through the 9-5/8 casing from ~2845 2850. POOH. 9. With IA closed, establish circulation through perforations, pumping down 5-1/2 casing with returns from 9-5/8 x 13-3/8 annulus (OA) until returns are clean using hot water. 10. With OA closed, establish circulation through perforations, pumping down 5-1/2 casing with returns from 5-1/2 x 9-5/8 annulus (IA) until returns are clean using hot water. 11. Rig up cement unit to pump down CTU flow-cross with returns from IA and OA to return tank. Close 5-1/2 x 9-5/8 IA valve. 12. Mix and pump 40 bbls 15.3 ppg cement down 5-1/2 casing, while taking returns from the 9-5/8 x 13-3/8 annulus. 13. Displace with 56 bbls water leaving TOC in 5-1/2 casing at ~2400 MD. This will leave approximately 450 of cement balanced in both casing and OA. Expected casing/IA/OA surface pressures with well SI should = 0 psi / 150 psi / 0 psi. 14. Jumper casing, IA, and OA at surface. Allow OA to u-tube. This will leave approximately 300 of cement balanced in tubing / IA / OA. 15. WOC. 16. MU CTU nozzle BHA, tag TOC at ~2550. 17. Pressure test IA to 1500 psi. 18. Pressure test OA to 1500 psi. 19. Set 5-1/2 CIBP at 160. 20. Perforate through 5-1/2 casing & 9-5/8 casing at 150 155 on coiled tubing using TCP. 21. Rig up cement unit to pump down CTU flow-cross with returns from IA and OA to return tank. Confirm circulation paths by pumping and taking returns from both IA and OA. 22. Mix and pump 15.3 ppg cement down casing, through perforations and up both IA and OA annuli until good cement returns are witnessed at surface. Estimated volume required is ~21 bbls slurry. 5-1/2 casing volume = ~ 4 bbls 5-1/2 x 9-5/8 annulus = ~ 7 bbls 9-5/8 x 13-3/8 annulus = ~ 10 bbls 23. Flush lines and equipment of cement as required, leaving cement at approximately ground level. Verify pressures are balanced across OA/IA/5-1/2" Casing after U-tube. -bjm Provide 48 hrs notice for AOGCC opportunity to witness cement tag and pressure tests. -bjm Pressure test 5-1/2" casing to 1500 psi. Pressure tests can all be done at once with a combo MIT. -bjm Measure volume returned from IA to verify TOC in IA. -bjm Verified cement calcs. -bjm Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 7 of 12 Final details of cementing surface configuration will be worked with suppliers in detailed planning stage. 24. Rig down and move out CTU and associated equipment. Post-CTU Work 1. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting all casing strings to a minimum depth of 3 ft below ground level for final P&A. Notify AOGCC 24 hours prior to final excavation and top-off of surface cement to allow witnessing of the operations. 2. Top-off 5-1/2 casing and all annuli with cement as needed. Photograph casing and cement. Have a small tubing string on location in event cement is left deeper than can effectively be topped off at surface. 3. Weld marker plate on the outermost casing that meets requirements of 20 AAC 25.120 and includes the below information bead-welded directly to the marker plate. Photograph marker plate. State of Alaska AOGCC PTD 205-149 Middle Lake Unit 1A API 50-283-20021-01-00 4. Perform post-P&A methane monitoring and record results for reporting purposes. 5. Backfill the excavated hole and grade the location to final agreed condition. Remove any remaining debris from the location and dispose of waste materials as required. Note: Contact the AOGCC with 24 hours advanced notice to perform final site clearance inspection after rig down. Site Clearance Work 1. Water well on location will be plugged to ADEC regulations and ACES Sampling Plan. Contact ACES Director of Site Investigation Nick Simmons at (907 339-6305) for more information. 2. Cement block and metal debris will be removed. Post P&A methane monitoring is not necessary because methane was not observed before the P&A. -bjm Perform site clearance work concurrently with P&A to minimize total time on location due to risk of ice road melting before work is complete. -bjm Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 8 of 12 Attachment 1 - Current Wellbore Schematic Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 9 of 12 Attachment 2 - Proposed P&A Wellbore Schematic Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 10 of 12 Attachment 3 - Well Head Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 11 of 12 Attachment 4 - CTU-BOP Configuration Middle Lake 1A (PTD 205-149) Southcentral, Alaska OUR PURPOSE: TO FIND SUSTAINABLE SOLUTIONS FOR A SUSTAINABLE FUTURE ASRC Energy Services, LLC | 3900 C Street, Suite 701, Anchorage, Alaska 99503 | 907.339.6200 | asrcenergy.com Page 12 of 12 Attachment 5 - Proposed Snow Road Map 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: ___________________ 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?N/A Yes No 9.Property Designation (Lease Number): 10. Field: N/A N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9350'2290 psi None Casing Collapse Structural Conductor Surface 1540 Intermediate 4750 Production 6290 Liner 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:William Isaacson Doug Cismoski Contact Email:wisaacson@asrcenergy.com Contact Phone:907-339-6455 Authorized Title: Director of Drilling and Field Mgmt 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 8995' Surface Surface Exploratory Surface, 2858' & 8550' Subsequent Form Required: Suspension Expiration Date: 27' 27' N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer @ 8768' MD / 8423' TVD Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 N/A 205-149 3900 C Street, Suite 701, Anchorage, AK, 99503 50-283-20021-01-00 ASRC Energy Services Alaska, Inc. Proposed Pools: 9338' TVD Burst None 7740 MD 6870 30902947' 8116' 281' 2958' 8983'5-1/2" 9338' 281' 8563' - 8700' (plugged) 27' 30" 20" 13-3/8" 281' 9-5/8"8457' 2958' Middle Lake 1A 2/15/2024 None 5-1/2" ArrowPak Retrievable Packer No SSSV Perforation Depth MD (ft): 8457' 8910' - 9050' (plugged) st: Abandon Plug PerforationsFracture Stimulate Repair We Operations shutdownpair Well Suspend Perforate Other Stimulate Pull Tubing Change Approved Programll Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: r Casing ___________________ : 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: 8. Well Name and Number: n or Conservation Order governs well spacing in this pool?N/A Yes No nation (Lease Number): 10. Field: N/AN/A t): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 2290 psi None Collapse 1540 4750 6290 V Type: Packers and SSSV MD (ft) and TVD (ft): Proposal Summary Wellbore schematic13. Well Class after proposed work: ns Program BOP SketchExploratory Stratigraphic Development Service te for 15. Well Status after proposed work: erations: OILWINJ W DSPL Suspended val: Date: GASWAGGSTOR SPLUG ntative: GINJ Op Shutdown Abandoned Contact Name:William Isaacson Doug Cismoski Contact Email:wisaacson@asrcenergy.com Contact Phone:907-339-6455 Director of Drilling and Field Mgmt roval:Notifyff AOGCC so that a reypresentative may witness Sundryyrr Number:y BOP Test Mechanical Integrity Test Location Clearancey 8995' Surface Surface Exploratory Sf & 27' 27' N/A e a spacing exception due to property boundaries? Current Pools: S ()() tifyff that the foreygoing is true and the procedureapproved herein will not be deviated from without prior written approval. and with Date: TubingSize: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer @ 8768' MD / 8423' TVD Perforation Depth TVD (ft): 205-149 uite 701, Anchorage, AK, 99503 50-283-20021-01-00 rvices Alaska, Inc. Proposed Pools: 9338' TVD Burst None 7740 MD 6870 30902947' 8116' 281' 2958' 8983'5-1/2" 9338' 281' 8563' - 8700' (plugged) 27' 30" 20" 13-3/8" 281' 9-5/8"8457' 2958' Middle Lake 1A 2/15/2024 None 5 1/2 ArrowPak Retrievable Packer No SSSV MD (ft): 8457' gged) Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:41 pm, Nov 15, 2023 Doug Cismoski Digitally signed by Doug Cismoski Date: 2023.11.15 10:38:16 -09'00' 323-619 10-407 X DSR-11/15/23 MHT9300050, MHT9300049 SFD BJM 1/11/24 Abandon Provide 24 hrs notice to witness bridge plug tag and pressure test (step 15). BOP test to 2500 psi. Provide 24 hrs notice for AOGCC witness of cement in well after cutting 3ft below ground level.Provide 24 hr notice for AOGCC witness of final location clearance inspection. XX SFD 1/2/2023JLC 1/11/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.11 14:53:53 -09'00'01/11/24 RBDMS JSB 011624 November 14, 2023 Mrs. Jessie Chmielowski, Commissioner Mr. Greg Wilson, Commissioner Mr. Brett Huber, Sr., Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request to Plug & Abandon Middle Lake 1A Well (PTD: 205-149 / API: 50-283-20021-01-00) Dear Commissioners, ASRC Energy Services Alaska, Inc (AES-AK) hereby requests sundry approval to permanently plug and abandon the Middle Lake 1A well, located near Point McKenzie on the west side of the Cook Inlet. Please contact me at 907-339-7410 or William Isaacson at 907-339-6455 with any questions. Sincerely, Doug Cismoski Director of Drilling and Field Management ASRC Consulting & Environmental Services, LLC Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 1.0 Well Summary – Middle Lake 1A The Middle Lake 1A well is planned for plug and abandonment (P&A) as part of the State of Alaska AOGCC Orphan Well Program. The P&A work will be conducted by AES-AK as Operator, on behalf of the State of Alaska AOGCC. Operations on Middle Lake 1A are scheduled to begin 1Q of 2024. General Well Information Status: Orphan Well – See attached ‘Current Wellbore Schematic’ (Figure 1.1-1) for details. No active leaks were witnessed, or gas detected (0% LEL measured) from around the well during a June 2023 site visit. A wellhead is in place; however, the well was not checked for pressure at surface. Base of Fresh Water: Estimated at 2700’ MD / 2691’ TVD Reservoir Pressure: All intervals below ~5600’ MD / 5450’ TVD will be isolated during the P&A operation. This isolation is provided by cement placed around the 9-5/8” and 5- ½” casing / liners and as P&A plugs within the 5-½” casing string. The interval which may be exposed during the P&A operation is the open hole section behind the 9-5/8” casing from ~5600’ MD to the 13-3/8” casing shoe at 2958’ MD. Data obtained from mud logs within the AOGCC well files from the original drilling of Middle Lake 1 indicate gas shows from 3700’ onwards. The gas shows are from coal and sands. The strata through this interval are expected to exist at pore pressures slightly above normal hydrostatic, and the interval down to 5600’ MD was successfully drilled with a 10.0 ppg mud and 10.1 ppg through 6000’ MD. Abnormal Pressure: As noted above, the intervals with possible hydrocarbons are believed to be at pore pressure slightly above a normal hydrostatic head, however there is uncertainty in the exact value. The interval down to 5600’ MD was successfully drilled with 10.0 ppg mud, therefore defining a worst-case upper limit. MASP: The Maximum Anticipated Surface Pressure is based upon a gas gradient to surface from the deepest section exposed during P&A operations and to possibly contain hydrocarbons at 5600’ MD / 5450’ TVD and at a worst-case pore pressure of 10.0 ppg EMW. MASP is calculated as ~2290 psi. Rig for P&A Ops: Team Snubbing International 340k Hydraulic Workover Unit (HWO) Unit 101 Wellhead: Vetco Gray 13-3/8” Casing x 13-5/8” 5M x 11” 5M x 11” 10M (see Figure 1.1-4 for details) BOP Configuration: 13-5/8” 5M BOPE - Annular/Pipe Rams/Blind/Choke & Kill Line (see Figure 1.1- 5 for details) and 5 Station Accumulator. BOP Test Pressure: 2500 psi Choke Manifold: 4-1/16” 5M (see Figure 1.1-5 for configuration details) Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 Regulatory Variance / Waiver Requests As per the above ‘Reservoir Pressure’ section, the uncemented interval behind the 9-5/8” casing from the 13-3/8” surface casing shoe to the estimated top of cement at ~5600’ MD had reported indication of hydrocarbons shows during the original drilling. The shows were from both minor coals and sands and no one interval is believed to represent a significant hydro-carbon bearing zone. Additionally, strata within the interval are all believed to exist at a pore pressure slightly above normal gradient. Based upon this information, the proposed P&A plan for Middle Lake 1A does not involve operations that will attempt to isolate zones from one another within this uncemented interval. The request is for a variance to 20 AAC 25.112.(a).1 to treat this as one common hydrocarbon-bearing strata and design the P&A plug placement to only isolate this interval from any fresh-water stratum above. Additionally, a variance to the requirements of 20 AAC 25.112 (b) is being requested to allow moving the cement plug segregating cased and uncased sections of the well up into the casing shoe by ~258’, rather than across the casing shoe. This will allow keeping the existing ‘Plug #2’ in place within the 5-½” casing (see Figure 1.1-1, 2 & 3) and moves the plug out of open hole and further into the shoe, which should improve chances of establishing circulation in the 13-3/8” x 9-5/8” annulus and aid cement plug placement. The base of the proposed plug will start at ~2700’ MD, which is at the base of any potential freshwater intervals. 1.1 P&A Procedure – Middle Lake 1A Pre-Rig Work 1. Equip the active (those with valves present) wellhead outlets with a redundant valve configuration and check the well for pressure at surface. Bleed pressure as required and monitor for any pressure rebuild. 2. Once the well is confirmed dead, service wellhead to ensure operability of all lockdowns and that each annulus is equipped with a functioning redundant valve configuration on one side outlet. 3. Prepare access via ice/snow road and location for rig operations. Remove any debris / solid waste specified for clean-up. 4. Remove the corrugated wellhouse from around the well and confirm integrity of the existing well cellar for operations. Repair as required and make any final site preparations for rig arrival. Rig Based Operations 1. Move in and rig up P&A rig and equipment. Note: Notify AOGCC 24 hours prior to commencing P&A operations and for the upcoming BOP test. 2. Nipple down dry hole tree and nipple up BOPE to existing 11” 10M psi tubing head flange using adapter spool. Test BOPE to 250 psi low / 2500 psi high (annular to 2500 psi). 3. Make-up 4-¾” cleanout assembly and drill out surface cement plug in 5-½” casing using snubbing force as required to aid in drilling the plug. x Records indicate a total of 5.3 sacks cement placed at surface, equating to 230’ in the 5-½” casing. The plug was tagged at 4’ below ground level. Variance approved - bjm Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 x To manage the risk of trapped pressure beneath the cement plug, plans are to divert flow from below a closed stripping annular (above the BOP stack) and through the rigs mud gas separator while drilling the surface plug. x Water will be used for drilling the surface cement plug and the well displaced to 10.5 ppg water-based mud on top of the plug at ~2850’. A 10.5 ppg fluid should be adequate for well control, given the well was successfully drilled using 10.5 ppg mud from below the 13-3/8” casing to a depth of ~8800’ (which is well below any exposed and uncemented formations behind the 9-5/8” casing). All other intervals requiring higher mud weights are and will remain isolated throughout the P&A operation. 4. Once the surface cement plug is drilled, continue to RIH with the 4-¾” cleanout BHA to top of the second cement plug in 5-½” casing at ~2850’. Wash down and tag cement plug, drilling any stringers until reaching a minimum depth of 2850’. Displace 5-½” casing to 10.5 ppg mud. Note: In January 2006, this ~200’ plug was placed on a CIBP set at 3058’ and therefore, the depth and quality of the plug is fairly certain. The desire is to tag the plug without drilling, however if stringers or the plug itself is encountered shallower than expected, clean out to 2850’ to ensure space for the upcoming cut and pull of the 5-½” casing and P&A plug placement at 2700’. 5. Perform base-line pressure test of the wellbore by pressure testing both the 5-½” and 9-5/8” casings to 500 psi. 6. Pull out of the hole, lay down bit and BHA. 7. Make-up 5-½” casing cutter assembly on DP and run in hole. Position cutter at 2800’ and cut the 5-½” casing. 8. Close the annular BOP and establish circulation around the 5-½” casing through the casing cut. Displace the 9-5/8” x 5-½” annulus to 10.5 ppg (from current 14.9 ppg) mud. Shut down and monitor to verify the well is dead. Pull out of hole, lay down cutter assembly. 9. Nipple down and set back BOPE. Nipple down and remove 11” 10M x 11” 5M tubing spool and casing pack-off to expose 5-½” casing slip assembly. Tac weld slip assembly to casing. 10. Nipple up BOPE to 11” 5M casing head flange. Function test BOPE as required. 11. Close the blind rams and pressure test wellbore (combo test of 9-5/8” & 5-½”) and the 11” 5M casing head / BOP flange to 500 psi. Note: Due to the age of the well and overall integrity concerns, a full pressure test to 2500 psi on the broken flange and / or BOPE will not be conducted at this time, however, will be done once the 5-½” casing has been pulled from the well. There should be no formations in communication with the open wellbore at this point. 12. Make-up spear assembly for 5-½” casing. Spear casing immediately below the wellhead and pull casing with slip assembly to rig floor. Continue to pull and lay down 5-½” casing to cut point. 13. Set BOP test plug and test flange between wellhead and BOP stack and BOPE as required to 2500 psi. 14. Make up Gator mechanical perforator tool assembly with 9-5/8” bridge plug run below and test packer above. Run in hole and set the bridge plug at the minimum depth to allow perforating with the Gator tool at 2700’. Estimated bridge plug set depth is ~2720’. Note: The bridge plug will be hydraulic set, with the setting ball run in place during deployment. Notify AOGCC 24 hours prior to testing of the plug to allow witnessing of the operations. Provide 24 hrs notice to witness bridge plug tag and pressure test (step 15). -bjm Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 15. Lightly tag bridge plug after releasing to confirm location, and pressure test bridge plug and casing to 1500 psi as per requirements of 20 AAC 25.112.(g).2. 16. Using the Gator mechanical perforator tool, perforate the 9-5/8” casing over a 2’ interval at ~2700’. 17. Close the blind rams and attempt to establish circulation around the 9-5/8” casing through perforations. If successful, displace the 9-5/8” x 13-3/8” annulus to 10.5 ppg (from current 13.1 ppg) mud. Shut down and monitor to verify the well is dead. Once confirmed, continue with step 18 below. If returns cannot be established, an alternative contingency P&A program as shown in Figure 1.1-3 will be executed per the outlined steps below: x Using the Gator tool perforate the 9-5/8” at 2300’. x Attempt to establish circulation through perforations at 2300’ and up 9-5/8” x 13-3/8” annulus, and then also between the perforation intervals using the test packer. If successful with both or only returns to surface via the perforations at 2300’, revise plan to get back on the original plan to cement the entire annulus back to surface. If able to circulate between intervals, proceed with placing deep plugs #3 and #4 as shown and outlined on Figure 1.1-3, performing tag or pressure test as per regulatory requirement. x Set bridge plug at 500’ and perforate the 9-5/8” casing immediately above the bridge plug. x Establish circulation through the perforations at ~500’ and place plug #5 as outlined on Figure 1.1-3. Note: The final plan forward will be dependent upon if and where circulation is established for plug placement. Approval of an alternative plan must be obtained from the AOGCC prior to proceeding with cement operations. 18. Continue to circulate and condition the 10.5 ppg mud in preparation for cement operations, working rate up to a predetermined minimum rate for good cement placement. 19. Pull out of the hole and lay down the Gator and test packer assembly. 20. Rig up cement unit. Pump ~286 bbls of cement (final weight to be determined) down 9-5/8” casing, through perforations at 2700’ and out 9-5/8” x 13-3/8” annulus valves. Continue to pump until good cement returns to surface and both casing and annulus are filled to surface. Flush lines and equipment of cement as required, leaving cement at approximately ground level. Note: Final details of cement weight and cementing surface configuration will be worked with suppliers in detailed planning stage. 21. Nipple down BOPE. Rig down and move out P&A rig and associated equipment. Post-Rig Work 1. Remove wellhead and well cellar. Complete excavation as needed around the well to allow cutting all casing strings to a minimum depth of 3 ft below ground level for final P&A. Note: Notify AOGCC 24 hours prior to final excavation and top-off of surface cement to allow witnessing of the operations. 2. Top-off 9-5/8” casing and all annuli with cement as needed. Photograph casing and cement. 3. Weld marker plate on the outermost casing that meets requirements of 20 AAC 25.120 and includes the below information bead-welded directly to the marker plate. Photograph marker plate. State of Alaska If alternative P&A contingency is required, cement plug must be verified post-cementper 20 AAC 25.112(g).-bjm 372 bbls volume minimum required per attached Bill Isaacson email 12/29/23. -bjm Provide notice for AOGCC to witness cement level in the annuli at surface before marker plate is welded on. 68 bbls volume minimum required per attached Bill Isaacson email 12/29/23. -bjm 27 bbls in annulus and 44 bbls inside casingbbls volume minimum required per attached Bill Isaacson email 12/29/23. Does not match cement volume liste dondiagram 1.1-3. -bjm See attached e-mail from Bill Isaacson dated 12/29/23 describing max pressure for circulating.Seek approval from AOGCC before proceeding if circulation is not established after applying 2300 psi. -bjm Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 AOGCC PTD 205-149 Middle Lake Unit 1A API 50-283-20021-01-00 4. Perform post-P&A methane monitoring and record results for reporting purposes. 5. Backfill the excavated hole and grade the location to final agreed condition. Remove any remaining debris from the location and dispose of waste materials as required. Note: Contact the AOGCC with 24 hours advanced notice to perform final site clearance inspection after rig down. Below, Figure 1.1-1 shows the current wellbore schematic, Figure 1.1-2 the proposed wellbore schematic after P&A and Figure 1.1-3 is the wellbore schematic for contingency P&A operations. The use of an LEL monitor in theexcavated hole around the wellis sufficient since methane was notdetected pre-rig. If methane is detectedwith LEL monitor, notify AOGCCimmediately. -bjm Middle Lake 1A (PTD 205-149)Southcentral, Alaska Rev. 0 November 2023 Figure 1.1-1. Current Wellbore Schematic Middle Lake 1A (PTD 205-149) Southcentral, Alaska Rev. 0 November 2023 Figure 1.1-2. Proposed P&A Wellbore Schematic See updated cement volumes inemail from Bill Isaacson 12/29/23.-bjm Middle Lake 1A (PTD 205-149)Southcentral, Alaska Rev. 0 November 2023 Figure 1.1-3. Contingency P&A Wellbore Schematic See updated cement volumes inemail from Bill Isaacson 12/29/23.-bjm Middle Lake 1A (PTD 205-149)Southcentral, Alaska Rev. 0 November 2023 Figure 1.1-4. Wellhead Configuration Middle Lake 1A (PTD 205-149)Southcentral, Alaska Rev. 0 November 2023 Figure 1.1-5. BOP & Choke Manifold Configuration Superseded -bjm TeamSnubbingInternationalUnit101 13Ͳ5/8"5kBOP&SnubbingStack,4Ͳ1/16"10kChokeManifold&LineͲuptoMGS MudTank&Shaker MudTank&Shaker MudGasSeparator(MGS) VentLine MudReturnLine OpenTopTank MudTank&Shaker MudTank&Shaker MiddleLakeUnit1AͲ1 OrphanWellSiteInspectionFormͲ SiteName:MiddleLakeUnit1A API#:50Ͳ283Ͳ20021Ͳ01Ͳ00 DateandTime:TuesdayJune14,2022Ͳ3:30pm. Inspectedby:LisaKrebsͲBarsis,AlenaVoigt,AaronTimian(DNR) Access:ThepropertyisaccessedfromHolsteinAvenue(offPointMackenzieRoad).Vehiclescannot directlyaccessthepropertyandyouhavetotraversethetrailonfootforjustoveramile.Theformer trailtothepadisheavilyvegetated.Nearthebeginningofthetrailitismuckyandnotraisedabovethe surroundingwetlands.Therampontothepadremainsingoodshape.Aroadtothepadwouldneedto beconstructed,requiringclearingandplacementofgravel.Withclearinganduseofmudmatsa trackedvehiclemaybeabletotravers.Thepaditselfhasalargeflatareathatcouldbeusedasastaging areaorahelicopterpad. Drainage:Thepadissurroundedbywhatappearstobejurisdictionalwetlands.Itappearsthatwater mightrunoffthepadonthenortheastcornerofthepad.Therewasnoevidenceofrunofffromthe padtothewetlandsinotherlocationsonthepad.Withinthepadtherearetwolowareas,thepossible closedreservepitinthesouthwestofthepadandthelargersumpedareaonthenorthsideofthepad. VisualObservations:Thepadisraisedabovethesurroundingwetlands.Thesouthsideofthepadwas lightlyvegetatedwithplantscommonindisturbedareasͲgrasses,dandelions,clover,fireweed, plantago.Inthesouthwestcornerofthepadmaybeaclosedreservepit.Itwasseveralfeetlower thanthepad.Alderandequisetumarethedominantvegetationintheclosedpossibleclosedreserve pit.Therewasnostandingwaterinthepossibleclosedreservepitatthetimeofthesitevisit. Atestpitdirectlyoffthepadfrompossibleclosedreservepityieldedsheen.Thesheenhadsoftedges andbrokeupbutseemedtocoalescebacktogetherbutitwasnotobviouslypetroleumorbiogenic sheen.Vegetationinthisareawassimilartothevegetationoffthepadwithsedges,heath,spruce. Smallbirchweresparselypresentaroundtheedgesofthesumpedarea. Spanningmostofthenorthsideofthepadwasalargesumpedareathatmayhavebeenusedasa reservepitaswell.Therewasnotstandingwaterthroughoutmostofthenorthsideatthetimeofthe sitevisit,howevertestpitsforshovelsheentestingfilledimmediatelywithwater.Thisareahadalight layeroffinesedimentandorganicmatunderlainbysandygravel.Nosheenorodorwerepresentin severaltestpits. Onthenortheastsideofthepadtherewasawaterwellpresentwithawatermeterattached. Atthenortheastcornerofthepad,nearthesumpedarea,therewasvisualevidenceofrunofffromthe pad.Therewasnowaterflowingfromthepadatthetimeofthesitevisitbutvegetationlaydownin thatareaandthepresenceofstandingwaterindicatedtheremayberunofffromthepadinthatarea. Nosurfacereleasesorleakingcontainerswereobservedonthepad.Somemetaldebriswasobserved onthepad. MiddleLakeUnit1AͲ2 PIDreadings:Aphotoionizationdetector(PID)wasnotusedtoscreenthewell.Thewelliscompletely encasedincorrugatedmetalpiping. Recommendations:ConsidersamplingthewaterwellͲpetroleumhydrocarbons,volatileorganic compounds,metals,polynucleararomatichydrocarbons.Surfacewatersampling(sameanalyses) suggestedlocationsidentifiedinsitefeaturesfigure.Anadditionalsampleisrecommendedinthe possibleclosedreservepitifwaterispresent.CoordinationwithADFGandpermittingmaybe necessary.Repairoftheroadtothepadmayrequirewetlandspermits. MiddleLakeUnit1ASiteFeatures MiddleLakeUnit1AͲ3 PhotographicLogͲMiddleLakeUnit1A Photograph1:SusitnaFlatsADFGGameRefuge Photograph2:Accessroadnearpadfacingeast MiddleLakeUnit1AͲ4 Photograph3:Corrugatedmetalwellcontainment Photograph4:Sumpedareaonpadfacingwest MiddleLakeUnit1AͲ5 Photograph5:Sumpedareaonpadshovelsheentest Photograph6:Sumpedareaonpadshovelsheentest MiddleLakeUnit1AͲ6 Photograph7:Vegetationinpresumedreservepitfacingnorthwest Photograph8:Shovelsheentestoffthepadwestofthepresumedclosedreservepitfacingthesouth westcornerofthepad MiddleLakeUnit1AͲ7 Photograph9:Shovelsheentestoffthepadwestofthepresumedclosedreservepitfacingthesouth westcornerofthepad Photograph10:Vegetationonthesouthwestpadedge MiddleLakeUnit1AͲ8 Photograph11:Shovelsheentestsouthwestofthesouthwestcornerofthepad Photograph12:Standingwaterontheeastofthepad MiddleLakeUnit1AͲ9 Photograph13:Presumedwaterwell Photograph14:WaterMeter MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: AOGCC Well file DATE: May 6, 2022 FROM: Bryan McLellan AOGCC Sr. Petroleum Engineer SUBJECT: Middle Lake Unit 1 Orphan Well Site Survey Well Names: Middle Lake Unit 1A (PTD 205-149) Operator: None (Orphan Well). Previously Pacific Energy Resources LTD. Objective: Locate and map orphan well and associated debris, reserve pits and other features relevant to future well plugging and site clearance operations. Attachments: • Photos, including Aerial drone images of the site and features are located in the AOGCC wellfile. • DNR survey map with GPS coordinates of wells and other features. Observations: I traveled by car to the access trail at the end of Holstein Rd to locate and assess the Middle Lake Unit 1 Orphan Well in preparation for eventual plug and abandonment. I was met by a survey crew from Alaska DNR (Joe Donohue and Randy Guidu) and the three of us walked ~1.25 miles west through the Susitna Flats State Game Refuge to reach the wellsite. The date of the site visit was selected such that the area would be free of snow cover, but before new vegetation concealed the debris and wells. The access trail was very wet and is not suitable for any kind of vehicle, other than snow machines in winter. The access ramp at the east end of the drillsite is in good condition and the drillsite itself is raised above the surrounding wetlands. It appears suitable as a helicopter landing zone and heavy equipment staging area. The well itself was enclosed in a large , +/-10’ diameter corrugated culvert and was not accessible. There was also a perceived water well located on the drillsite. The site was cleared of most debris, except for some large steel cables. Photos were taken, including aerial drone photos, and a map created showing GPS location of the various features at the drilsite. These photos and map are located in the AOGCC wellfile. Photo looking east shows Middle Lake Unit 1A in the center of the drillsite, with the ~1.25 mile access trail through the wetland to the end of W. Holstein Ave. Left Photo: Enclosure around perceived location of Middle Lake Unit 1A wellhead. Right Photo: Perceived water well on the drill site for Middle Lake Unit 1A. SITE 1: 1.2 MILES DOWN TRAILWEST OF W. HOLSTEIN AVE.TRAILPERCEIVEDPITPERCEIVEDSUMPENDING:SCALE:DRAWN BY:DATE:DATE OF SURVEY:SURVEYOR:BEGINNING:STATE OF ALASKAOIL AND GAS CONSERVATION COMMISSIONANCHORAGE, ALASKACHECKED BY:SHEET:OFDNR, DMLW, SURVEY SECTION550 W. 7TH AVE, SUITE 650ANCHORAGE, AK 99501-357621KB1"=80'05/19/2022JD5/6/20225/6/2022VICINITY MAPScale: 1" = 4 MilesSource:Alaska Mapper - National Map TopoORPHAN WELL SURVEYS POINT MACKENZIE, AKSite 1: 1.2 miles down trailwest of W. Holstein Ave.Site 2: MP 17.6 Knik-Goose Bay RdWGRAPHIC SCALE40 METERS160160 FEET400801 METER = 3.280833 U.S. SURVEY FEET1 U.S. ACRE = 0.4047 HECTARENOTES1. THE INFORMATION SHOWN HEREON IS BASED ON FIELD LOCATES PERFORMED BY THE ALASKA DEPARTMENT OF NATURAL RESOURCES, DIVISION OF MINING, LAND AND WATER ONMAY 6, 2022. THE PURPOSE OF THIS SURVEY IS TO ACQUIRE LOCATION AND CONDITION INFORMATION OF ORPHAN WELLS FOR AOGCC, FOR POSSIBLE FUTURE PLUGGING,REMEDIATION AND RESTORATION WORK.2. THE COORDINATE SYSTEM FOR THIS PROJECT IS ALASKA STATE PLANE ZONE 4, NAD83(2011) EPOCH (2010.0000) IN US SURVEY FEET. THE BASIS OF COORDINATES FOR SHEET 1 ISPOINT NO. 110 "CP MID LAKE" BASED ON AN OPUS SOLUTION PERFORMED ON MAY 17, 2022. POINT NO. 110 - SET 12" SPIKE NORTH OF TRAIL TO MIDDLE LAKE WELL. LATITUDE: N61° 22' 39.32864" LONGITUDE: W 150° 08' 27.62257" THE BASIS OF COORDINATES FOR SHEET 2 IS POINT NO. 120 "CP AK GULF" BASED ON AN OPUS SOLUTION PERFORMED ON MAY17, 2022. POINT NO. 120 - FOUND 2.5" AL. CAP UNDER POWERLINE NORTH OF K.G.B. RD. LATITUDE: N 61° 25' 20.97174" LONGITUDE: W 149° 48' 45.45126"3. THE VERTICAL DATUM FOR THIS SURVEY IS NAVD88 (DERIVED FROM GEOID 12B). THE BASIS OF VERTICAL CONTROL FOR SHEET 1 IS POINT NO. 110 "CP MID LAKE", HAVING A GEOIDHEIGHT OF 105.20', BASED ON AN OPUS SOLUTION PERFORMED ON MAY 17, 2022. THE BASIS OF VERTICAL CONTROL FOR SHEET 2 IS "CP AK GULF", HAVING A GEOID HEIGHT OF120.31', BASED ON AN OPUS SOLUTION PERFORMED ON MAY 17, 2022.4. FIELD WORK AND DRAFTING WAS PERFORMED BY RANDY GUINTU AND JOSEPH DONOHUE. DRAWING WAS REVIEWED BY KEVIN BOW, PLS.LEGENDFOUND WELLGNSS OBSERVATION TAKENEDGE PAVEMENTEDGE TRAILTOP/TOE OF SLOPEEDGE OF PERCEIVED SUMPEDGE LAKEW 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. ©S - ~ ~(~ Well History File Identifier ~rganlZing (done) RE CAN Color Items: ~eyscale Items: ~, ^ Poor Quality Originals: ^ Other .,..~,,d~ uuumuiumu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Re=~a~~eeded iuuiuiAiiuuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Project Proofing BY: Maria ^ Other:: Date: J ~ g Date: ~ ~- v ~np iuuiiiiiiipiiiu m~ Y ~ Scanning Preparation ~~ x 30 = ~ + ~ =TOTAL PAGES (Count does not include cover sheet) ~n l BY: Maria Date: ~ a d n~ /s/ 1 r Production Scanning Stage 1 Page Count from Scanned File: _~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Dater ~-q/erg /s/ I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: lsl Comments about this file: a~ ,«.~,.d iuumuuuiiu 10/6/2005 Well History Fife Cover Page.doc i ~ ., -,~ . ~.R ~ `~ ~ y« .~ . „~~. r 4 t X MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM To: Maunder, Thomas E (DOA); Seamount, Dan T (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA); Williamson, Mary) (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); Colombie, Jody J (DOA); Gary Carlson; Norman, John K (DOA); Foerster, Catherine P (DOA); Laasch, Linda K (DOA); IongmereC~verizon.net Subject: FW: Pacific Energy files chapter-11, it's official!!! FYI. PACIFIC ENERGY RESOURCES LTD. 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter 31 to Facilitate a Restructuring aos-~~~ LONG BEACH, CALIFORNIA, Monday, March 9, 2009 - -Pacific Energy Resources Ltd. (the "Company")(TSX:PFE) announces today that it and its wholly owned subsidiaries have filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Delaware. The filing was precipitated by the dramatic decrease in the market price of oil over the past five months. Combined with the Company's pre-existing level of debt related to past acquisitions and poor capital market conditions, the Company's liquidity and cash flow is insufficient to operate its business and invest in its oil producing assets to increase production. Faced with these constraints, the Company and its subsidiaries filed petitions for reorganization under chapter 11 to facilitate access to an immediate source of liquidity as it works to restructure its debt. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP")financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com: The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS • • PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 d mha l1(a~ pac e nergy. com www.pacenera ~~ ~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051490 Well Name/No. MIDDLE LK UNIT 1A Operator FOREST OIL CORP API No. 50-283-20021-01-00 MD 9350 TVD 8995 Completion Date 1/16/2006 Complet ion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Direction al Surve Yes DATA INFORMATION Types Electric or Other Logs Run: AIT, Spectral Gamma, Density, Sonic, Neutron - CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number N me Scale Media No Start Stop CH Received Comments C 13476 SGS Water Analysis 01-12- / 13 7 ` 06 C 4 5 0 0 cased and open hole I, digital logs ED C 13477 Dir ectional Survey 0 0 2/10/2006 Directional Survey F~ C Pds ~ / 13474 (dement Evaluation 5 BM 1 5000 9245 2/10/2006 Cement Bond Log ~, DSLT/GE/CCL PDS ~ ', F~eS C Pds 13474 '~ressure 5 BM 1 8835 9282 2/10/2006 Modular Dynamic Tester Pressure Tests MDT-GR I ED C Pds 13474 '/ R 5 BM 1 8461 9350 / / PDS , amma ay 2 10 2006 Spectral GR NGT/DSLT/PEX, 5":100' ' IC 12-25-06 PDS I k0 C Pds 13474 Gamma Ray 2 BM 1 8461 9350 2/10/2006 Spectral GR ', NGT/DSLT/PEX, 2":100't/ 12-25-06 PDS /~ ED C Pds 13474`JSonic 2 BM 1 8461 9350 2/10/2006 Platform Express Sonic '~, Spectral GR `~ ', NGT/DSLT/PEX, 2":100' ' 12-25-06 PDS !-~D C Pds 13474c/Ferforation 5 BM 1 8460 8712 2/10/2006 Pertorating Depth Control v Gamma Ray/CCL TCP ' Guns PDS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments L_.! DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051490 Well Name/No. MIDDLE LK UNIT 1A Operator FOREST OIL CORP API No. 50-283-20021-01-00 MD 9350 TVD 8995 Completion Date 1/16/2006 Completion Status SUSP Current Status SUSP UIC N ADDITIONAL INFORMATION (~rrte,,, Well Cored? Y N~ Daily History Received? ~J N Chips Received? -''f'7-M1i"' Formation Tops ~ / N Analysis -~t1V~~ Received? Comments: _ -- - - ~A,` Compliance Reviewed By: ___ ___ __ __ Date ~~Ay F O R E S T O I L C O R P O R A T I O N •' .~~o ~~~~~.~~~ . ~'~ goo Y • C~~r~~aoo~cr~e, C~r~.t/ra; 9950 ~90~~ ,~s8-~6o0 ~90~~ X58-860 ~~%.~~ RECEIVED February 9, 2006 FEB 1 d 2006 Alaska Oil & Gas Cons. Commission Anchorage Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Middle Lake Unit #1-A (PTD No. 205-149) Dear Mr. Norman, Forest Oil Corporation hereby submits it Well Completion Report for the work it performed in drilling its Middle Lake Unit #lA exploration well near Point McKenzie on the west side of Cook Inlet. The well tested only water and has been suspended as a detailed in the attachments. Please find attached the following information for your files: 1) Form 10-407 Well Completion or Re-completion Report. 2) Wellbore Schematic 3) Well Operations Summary 4) Directional Survey 5) Logs If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, Ted Kramer Alaska Production Manager enclosures cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ORIGINAL STATE OF ALASKA - ALASKA AND GAS CONSERVATION COMMISSI~ ~~E~~ 1a. Well Status: Oil Gas Plugged ~ Abandoned Suspended ~ WAG 2oanczs.~os zoaa,czs.iio GINJ^ WINJ~ WDSPL~ No. of Completions 0 Other 1b. Well Class. Development ~~t15It~ ~~~ Service ~ Stratigraphi Te t 2. Operator Name: Forest Oil Corporation 5. Date Comp., Susp., or Aband.: 1/1612006 12. Permit to Drill Number: 205-149 3. Address: 310 K. Street Suite 700, Anchorage, Alaska 99501 6. Date Spudded: December 8, 2005 - 13. API Number: 50-283-20021-01 4a. Location of Well (Governmental Section): Surface: 1923' FNL, 1142"FWL, Sec 22, T15N, RSW, SM 7. Date TD Reached: December 23, 2005 14. Well Name and Number: Middle Lake Unit #1A Top of Productive Horizon: 1671' FNL, 551' FEL, Sec. 21, T15N, RSW, SM 8. KB Elevation (ft): 122' 15. Field/Pool(s): Total Depth: 1625' FNL, 605' FEL, Sec. 21, T15N, RSW, SM 9. Plug Back Depth(MD+TV[3): Surface Exploratory 4b. Location of Well (State Base Plane Coordinates): Surface: x- 472183 ' y- 2695742 ~ Zone- 4 10. Total Depth (MD +TVD): 9,350' MD / 8,995' TVD 16. Property Designation: MHT 9300049 & 9300050 TPI: x- 470479 y- 2696009 Zone- 4 Total Depth: x- 470429 y- 2696064 Zone- 4 11. Depth Where SSSV Set: NIA 17. Land Use Permit: N/A 18. Directional Survey: Yes ~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: NIA C ,/ 21. Logs Run: T/~Ljt SYS'7 ° ~7p f 0 I~~ ` "T7~ AIT, Spectral Gamma, Density, Sonic, Neutron - CBL ~ j,3 w~ 22. CASING, LINER AND CEMENTING RECORD IN WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CAS G ~ TOP BOTTOM TOP BOTTOM PULLED 30" Driven NIA Surface 27' Surface 27' Driven Driven 0' 20" 94# H-40 Surface 281' Surface 281' 26" 425 sx. 0' 13-3/8" 61# K-55 Surface 2,958' Surface 2,947' 17-1/2" 1,253 sx. 0' 9-5/8" 47# N-80 Surface 8,457' Surface 8,116' 12-1/4" 900 sx. 0' 5-1/2" 20# L-80 Surface 9,338' Surface 8,983' 6-3/4" 345 sx. 0' 23. Perforations open to Production (MD +TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None N/A N/A NIA 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 26. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Flowin Date of Test: 1!10/2006 Hours Tested: 8 Hours Production for Test Period Oil-Bbl: 0 Gas-MCF: 0 Water-Bbl: 104 Choke Size: 34/64 Gas-Oil Ratio: N/A Flow Tubing Press. 400 SI Casing Press: 1,100 psi Calculated 24-Hour Rate ~ Oil-Bbl: 0 Gas-MCF: 0 Water-Bbl: 540 Oil Gravity -API (corr): N/A 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ ;,~ ; ~ ~p ~;QDMS ~F~, FES 1 ~ 2D06 V IFIEU ~~ ~: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE WELL COMPLETION OR RECOMPLETION REPORT AND LO 006 Corr~rrM'ssic 28. GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly sum test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". The following perforated intervals were flow tested together in a single test. Flowed only water: 8,910' - 9,004', -9,020' & 9,030' - 9,050' Top Tyonek 3,700' 3,658' MD. ~~L.Y.~ V 6.~® ~Eg 1 0 2006 Alaska Oii & Gas Cons. Commissi Anchal'age 30. List of Attachments: Directional Survey, well Logs, operational summary, wellbore schematic. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bill Penrose 258-3446 Printed Name: Ted Kramer Title: Alaska Production Manager Signature: "'~ ~ ~~ Phone: 907-868-2137 Date: ~ / 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00}. Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool, Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ~ FOREST OIL CORPORATION MIDDLE LAKE # 1A SUSPENSION OF OPERATION SCHEMATIC ' KB Date: 1/12/06 PAD LEVEL Prepared: Roy Smith ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PAD +/- 3' ABOVE ORIGINAL GROUND LEVEL ' DRY HOLE TREE ORIGINAL GROUND LEVEL ---- ------------------ 30" .63" Wall Thickness Drive Pipe I I I CEMENT PLUG I ~ 210' TO 4' BGL ~ 20" 94# H-40 @+/- 281' I I I I 1 I I CEMENT 200' I I I 13 3/8" 61 # K-55 @ +/- 2,958' MD/TVD ~ ~ ~ 5 1/2"CIBP set Q 3,058' w/200' cmt on top t-o-~ fi TOC of 5 1/2"Tieback 7,300' 5 1/2" 17# L-80 Buttress Modified Couplings T/B ~ Top of 5 1/2" Liner @ 7,783' MD/TVD I I 9 5/8" 47# N-80 Whipstock Window Top @ 8,457' MD/TVD 14.9 ppg Water Base Mud CEMENT 200' X200' of cement on top of CIBP tst'd 5,000 psi f5 1/2" CIBP set on top of packer C~ 8,760' 5 1/2" 20#/ft ArrowPak Retrievable packer with TCP gunsSet @ 8,768' wxN 2 7/8" "WXN" Nipple w/4' pups above and 6' below PX Plug set in XN Nipple, Tst'd to 5,000 psi Perforations 8,910-9,004', 9008-9,020' & 9,030-9,050 MD -------,9,254_ PBTD---- 5 1/2" 20#/ft L-80 Hydril 521 @ +/- • r OPERATIONS SUMMARY Forest Oil Corporation Middle Lake Unit #lA December 6, 2005 Finish rigging up on location. Install wellhead. Pressure test wellhead and N/U BOPE. December 7,2005 Finish N/LT BOPE and function test same. Fill and check circulating system on rig. Test BOPE to 250 psi low, 3,000 psi high. M/LT wash-over/fishing assembly. December 8, 2005 Mill over 4-1/2" drill pipe stub in top of well. Make 1.5'. Shut down to install additional accumulator pump to yield acceptable accumulator pressure recovery time. Repair electrical problem on top drive. Continue milling over fish. ~ Fluid level dropped away. Refill hole with 26 bbls of fluid. Monitor well -well static. M/iJ overshot and recover drill pipe stub (2.81' long). M/IJ wash pipe and shoe to wash over 9-5/8" casing. December 9, 2005 Wash over 9-5/8" casing. Tag collar at 40'. L/D wash string, M/U 8-1/2" cement mill. RIH, mill out cement inside 9-5/8" casing to 32.6' - bottom of cement. (Top of 9-5/8" casing is at 20.6' RKB.) POH, L/D mill, M/U spear. RIH, set spear in 9-5/8" casing. Pull 120k lbs, got 7" stretch. Release spear, POH. L/D spear, M/LT 8-1/2" bit. RIH, wash to 310', tag hard cement. Drill cement to 315'. POH, L/D BHA, P/U 8-1/2' watermelon mill and knife blades. RIH and locate collars in 9-5/8" casing. POH, L/D mill and blades, M/U hydraulic backoff assembly. RIH. December 10, 2005 Attempt to back off top joint of 9-5/8" casing - no success. POH and L/D tools. M/U spear assy, RIH, set in 9-5/8" casing. R/U string shot, RIH through spear assy, locate collar. Put lh round of reverse torque in spear assy and shoot string shot. Lost torque. POH w/ e-line and R/D same. Back out 9-5/8" casing and POH w/ same. Recovered 19.23'. Blow down lines, clear floor, P/LT 4" drill pipe, change bails on blocks, P/iJ 9- 5/8" handling tools. December 11, 2005 Screw new joint of 9-5/8" casing into stub looking up and torque to 8,000 ft-lbs. Test 9- 5/8" casing to 2,000 psi - OK. P/U BOP's, set slips, make rough cut on casing, L/D stub, N/D 13-5/8" BOP's. Make final cut on casing and install 13-5/8" x 11" wellhead section. Test void to 2,400 psi. N/LT 11" BOP's. • • December 12, 2005 Finish N/LT BOP's. Test BOPE to 250 psi low, 5,000 psi high. Test witnessed by AOGCC rep. M/U 8-1/2" bit and RIH. Tag cement at 313'. Drill hard cement from 313' to 419. Bit torqueing, POH to check bit. December 13, 2005 RIH with cement mill and junk basket. Mill on junk and cement from 419' to 424'. POH and clean junk basket. Recovered 1/2 cup iron shavings. L/D mill, M/U bit on junk basket and RIH. Drill cement from 424' to 559'. Broke through, lost returns for 1 bbl then regained full circulation. Check for flow -well stable. Wash and ream from 559' to 1,828'. December 14,2005 Wash and ream out 9-5/8" casing from 1,828' to 4,304'. Very thick mud with 20 units gas. Circulate mud through de-gasser. Wash and ream from 4,304' to 4,712'. Tag up at 4,712'. Drill settled-out barite and cement stringers from 4,712' to 4,783'. MW 12.1, Vis 60. C&C mud and POH. Empty junk basket -recovered 1/a cup iron. RIH with 8- 1/2" bit on junk basket while P/U 4" drill pipe off pipe rack. December 15, 2005 P/LT 4" drill pipe and stand back in derrick. Wash and ream from 4,783' to 7,200'. December 16, 2005 Wash and ream from 7,200' to 8,600' without tagging anything. R/U cementing unit, pressure test lines and pressure test 9-5/8" casing to 4,800 psi for 30 minutes. Final pressure 4,600 psi -good test. R/D cementing unit and POH. M/LT 9-5/8" casing scraper and RIH to 8,600'. December 17, 2005 C&C mud - MW in and out 12.2 ppg, vis 45. POH w/ casing scraper. R/iJ e-line and RIH w/ 8-1/2" gauge ring and 5-1/2" junk basket. Tagged up at 556' -could not get past. POH. M/iJ two 1-11/16" sinker bars on e-line assy and RIH. Still could not get past 556'.. POH and R/D e-line. M/U 8-1/2" junk mill and 8-1/2" taper mill. RIH. Ream from 491' to 682'. Excess torque seen from 540' to 550'. Ream several times -cleared up. RIH to 8,600' w/ no problems. C&C mud and POH w/ no problems. December 18, 2005 Finish POH w/ junk mill and taper mill. Junk mill good, taper mill 1/32" under gauge, 2 finger-size pieces of cement in water courses of taper mill. R/U e-line w/ 8-1/2" gauge ring and 5-1/2" junk basket, RIH to 8,600' w/ no problems. POH. M/U 9-5/8" "E-4" CIBP on e-line and RIH. Set CIBP at 8,480', 4' above collar at 8,484'. POH w/ a-line and R/D same. Test annular preventer to 250/3,500 psi, all other BOPE to 250/5,000 psi. M/U 9-5/8" whipstock assy on 4" drill pipe and RIH w/ same. December 19, 2005 RIH w/ 9-5/8" whipstock on 4" drill pipe. Tag CIBP at 8,479'. C&C mud until MW in and out is 12.2 ppg. M/U gyro and RIH surveying every 100' to 8,392'. Orient • • whipstock and set slips. Top of whipstock at 8,457'. POH w/ gyro and rig down same. Establish milling parameters and mill from 8,457' to 8,463'. December 20, 2005 Mill window from 8,463' to 8,485'. C&C mud, balance mud weight in and out at 12.5 ppg. R/U cementing unit, close pipe rams and conduct formation integrity test to 14.2 ppg EMW (720 psi, 12.5 pg MW, 8149' TVD). Displace old 12.5 ppg mud system with new 13.0 ppg mud system. POH w/ window mills. December 21,2005 Finish POH, L/D milling assy. M/IJ 8-1/2" directional drilling assy and RIH. Slide and rotate from 8,490' to 8,772' . December 22, 2005 Slide and rotate from 8,772' to 8,988'. PVT indicated gain of 3 bbls. Shut well in, record pressures - 450 psi on DP, 450 psi on csg. Weight up active system from 13.0 ppg to 14.0. ppg and circulate around. No gas or chloride increase noted. Shut in and check pressures - 0 psi on DP and csg. Open well to observe, well started flowing. Shut in well - 0 psi on DP, 100 psi on csg. Circulate mud around through choke, noted light spots of 13.8 ppg. Well still flowing when pumps shut down. Raise MW to 14.2 ppg and circulate around. Monitor well - 30 psi on DP, 60 psi on csg. Raise MW to 14.4 ppg and circulate around. Monitor well -gain 2.5 bbls in 1 hr, 15 min. December 23, 2005 Monitor well for flow -gained 3.2 bbls in 2 hrs. CBU - no gas or chlorides increase. Pull bit above window and conduct FIT to 16.3 ppg EMW. RIH to bottom, rotate and slide from 8,988' to 9,350'. Make 10 stand wiper trip, hole took 9 bbls. CBU, slug pipe, POH. December 24, 2005 Well started flowing while POH. RIH to 9,350', gained 13.5 bbls. CBU - 625. units gas, mud cut from 14.4 ppg to 9.0 ppg -duration 25 minutes. Circulate while weighting up mud from 14.4 ppg to 14.9 ppg. Check flow, no flow. Pooh to 8,353 -hole took proper fill. RIH to 9,350 w/ no problems. CBU, no gas, no cut mud weight. Check flow, POH. December 25, 2005 Test BOP's -annular to 250/2,500 psi, all else to 250/5,000 psi. R/U Schlumberger, run quad combo to 9,351' WLM, log up to 8,456', POH w. quad combo. L/D logging tools and evaluate logs. M/LT MDT test tool, RIH to 9,350'. Log up ,setting MDT test tool at various depths to obtain 16 sample readings. POH, L/D MDT tool. December 26, 2005 R/D Schlumberger, M/U 6-3/4" bit on packed assy and RIH. Pipe stuck w/ bit at 9,335'. Work pipe free. Ream from 9,275' to 9,338', experience severe torquing. CBU, make 10-stand short trip, no problems. POH for 5-1/2" liner. R/iJ casing running equipment. • • December 27, 2005 M/IJ liner shoe, P/U and run 38 jts 5-1/2", 20#, P-110, Hydril-521 liner w/ Baker HMC liner hanger on 4" drill pipe. Set liner hanger w/ liner shoe at 9,338' and top of liner at 7,783'. Release from liner, R/LJ to cement, test lines. Pump 40 bbls of 15.2 ppg spacer followed by 244 sx (50 bbls) Class G cement w/ additives. Displace w/ 14.9 ppg mud, bump plug OK. Set liner-top packer w/ 40K lbs down weight. Test backside to 2,000 psi - OK. Reverse out, got back 'h bbl cement and cuttings. L/D cementing head, POH w/ liner hanger setting tool. December 28,2005 Finish POH w/ liner hanger setting tool, L/D 41 jts 4" drill pipe and setting tool. M/LT cleanout BHA and RIH while P/U 48 jts 2-7/8" drillpipe. Continue in hole w/ 4" drill pipe. C&C at TOL to balance out mud. Continue in hole to landing collar at 9,253'. Did not tag anything on way in hole. C&C mud, POH to run CBL. December 29, 2005 R/LT Schlumberger, RIH w/ CBL. Log 5-1/2" liner from 9,254' to 7,784' with 1,000 psi pressure applied to wellbore. POH, R/D Schlumberger. M/U polish mill on drill pipe and RIH. Polish tie-back receptacle, CBU. POH laying down 4" drill pipe. December 30, 2005 Offload, drift and strap 5-1/2" casing. Weight up and even out mud in pits to 14.9 ppg while waiting on csg x circulating swedge x-over. M/U tieback seal assy. TIH, P/LT 5- 1/2", 17#, L-80, IBTC casing. December 31, 2005 Finish RIH w/ 5-1/2" tieback liner. Tag TOL at 7,783', P/iJ 10'. Pump 20 bbls 15.8 ppg Class G cement, displace w/ 14.9 ppg mud. Bump plug w/ 500 psi. Bleed off pressure, slack off to engage seals. Estimated TOC at 7,300'. P/[T BOP's, set casing slips, make rough cut. L/D landing jt and stub. Set down BOP's and N/U same. Clear floor, R/U 3- 1/2" handling tools. TIH w/ 1 stand 3-1/2" DC's and 10 stands 2-7/8" DP below RTTS packer. Set RTTS packer and valve 30' below rotary. Commence testing BOPE. January 1, 2006 Test BOPE to 250/5,000 psi except annular to 250/3,500 psi - OK. Unseat storm packer, POH and L/D same. Stand back DC's and DP. Test safety valves and top drive valves to 250/5,000 psi. M/U 4-5/8" cmt mill, RIH w/16 stands 2-7/8" DP out of derrick. P/LT additional 2-7/8" DP while RIH. Tag cmt at 7,662'. Wash and ream to 7,730' (hard cmt at 7,725'). January 2, 2006 Experience difficulty drilling up float insert and cement from 7,745' to 7,750'. Torque fell off. POH, L/D cmt mill -mill jammed up w/ debris. M/LT 4-5/8" bit and RIH. Drilled up float insert and cement from 7,750' to 7,784', fell through. RIH while P/LT additional 2-7/8" DP, tag up at 9,254'. C&C mud, POH. • • January 3, 2005 Finish POH w/bit. M/U casing scraper above bit, RIH to 9,254'. C&C mud, blow down top drive, POH. Remove V-door slide, move catwalk, pull flowline and bell nipple. N/D BOP's. January 4, 2005 N/LT 11", SM x 11", lOM wellhead and test to 5,000 psi. Test BOPE to 250/5,000 psi except annular to 250/3,500 psi. M/LT bit and scraper, RIH to 9,254' PBTD. January 5, 2005 C&C mud. Test casing to 5,000 psi for 30 min - OK. Displace well and pits w/ 10.4 ppg KCl/CaC12 brine. C&C brine in well and until NCU's consistently read 16 - 20. POH w/ bit and scraper. P/LT perf guns and pkr -packer sleeve wrong size, preventing make- up. Send packer to shop to have sleeve modified. January 6, 2005 Wait on packer modification. P/U and M/U packer and perf guns, RIH. R/U Schlumberger a-line, RIH and set packer/guns on depth. POH w/ e-line, R/D Schlumberger. Drop packer setting ball, pressure up to 2,300 psi, set packer at 8,768' w/ top shot at 8,910' . POH, L/D 2-7/8" work string. January 7, 2005 Finish POH w/ 2-7/8" work string, load on trucks. L/D 4" drill pipe out of derrick, load on trucks. Clear rig floor. Load pipe rack w/ 2-7/8" tubing. Strap and tally same. R/U floor to run production tubing. M/LT seal assy, x-nipple and pups, RIH w/ same on 2-7/8" tubing while drifting same. January 8, 2006 Continue RIH w/ 2-7/8" tubing. Install chemical injection mandrel at 3,000'. Tag packer at 8,768', pressure up backside to 200 psi w/ tubing open - OK. R/U slickline, RIH, set plug in x-nipple at 8,707'. M/U hanger & space-out pups. Test tbg to 5,000 psi with seal assy out of pkr - OK. RIH w/ slickline, pull plug from x-nipple, POH, R/D slickline. Circulate corrosion inhibitor to backside. Drain stack, pump 2 bbls out of annulus to make room for freeze protect diesel. M/LT landing joint, M/U chemical injection line to hanger. Add 2 bbls diesel to annulus. Land hanger, run in hold-down pins. Pressure up backside to 500 psi w/ tbg open to test seals - OK. B/O landing jt, install BPV. January 9, 2006 N/D BOPE, N/U tree. Test hanger neck seals to 8,000 psi. Pull BPV, install 2-way check. Test tree to 250/8,000 psi, pull 2-way check. Test flow line to heater to 250/8,000 psi. Test downstream of 2"d choke to 250/3,500 psi. Test separator to 250/1,000 psi. Secure flowlines and otherwise prepare for well testing. Wait on daylight to fire guns. January 10, 2005 Finish securing flowlines. Test surface safety valves. Pump methanol into chemical injection line. Pressure up to 2,500 psi, then bleed back to 1,500 psi -guns fired. SITP went from 1,850 psi to 2,000 psi. Turn well over to testers. Flow well. Flowed back total of 180 bbls (tbg capacity 52.4 bbls). Started on 12/64 choke w/ tbg pressure at 1,900 • • psi, finished on 25/64 choke w/ tbg pressure at 200 psi. Flowed back 8.3 ppg H2O, chlorides 11,000 ppm. SI well, blow down test equip. SITP 2,000 psi, SICP 750 psi after 1-1/2 hrs. R/U pump lines to tree and test to 3,000 psi. Pump 10.4 ppg completion fluid into well at 2,900 psi. January 11, 2005 Pump down tbg w/ rig test pump while waiting for BJ pumper and crew. Pumper 45 bbls (tbg capacity 52.4 bbls), test pump started leaking. R/LT BJ pumper. SITP 2,036 psi. BJ pumping at 1/z bpm, pressure climbed to 3,870 psi and broke back to 3,612 psi after 4.5 bbls pumped. Pressure climbed to 4,000 psi with 15.6 bbls pumped. S/D pump, pressure declined to 2,300 psi in 17 minutes. Resume pumping at 0.7 bpm, pressure climbed to 5,000 psi. S/D pump, pressure declined to 2,455 psi in 22 minutes. S/I well, R/D BJ. R/U slickline lub, test to 4,000 psi. RIH w/ PX plug and set in x-nipple at 8,787'. POH, P/U check set tool, RIH, verify plug set in profile, POH. P/U prong, RIH, set prong in x- nipple, POH. R/U test line, test PX plug to 5,000 psi for 30 minutes - OK. Bleed tbg pressure to 0 psi and leave well open for 30 minutes - OK. R/D slickline, install BPV, N/D tree. January 12, 2005 N/LT BOP's, install VBR's. Pull BPV, set 2-way check. Test BOP's - no good. Pull test plug and 2-way check, clear debris, reset same. Test BOP's - no good. Determined chemical injection line not plugged. Pull bell nipple, flowline, choke and kill lines and break flange at tbg head. Install plug on chemical injection line. Reinstall everything. Commence testing BOP's to 250/5,000 psi. January 13, 2005 Finish testing BOP's to 250/5,000 psi, Hydril to 250/ 3,500 psi. B/O test jt, M/U landing jt, R/U cmtg unit to attempt to establish injection down 9-5/8" x 13-3/8" annulus using H2O. Pump 2.1 bbls, pressured up to 1,500 psi. Hold pressure for 10 minutes w/ no bleed-off. Release pressure, got back 1.5 bbls. R/D cmtg lines. R/U to handle 2-7/8" tbg. BOLDS, pull tbg hgr to rig floor to pull seals from pkr. Displace hole w/ 14.9 ppg mud. L/D tbg hgr and landing joint. Slug pipe and POH w/ tbg. L/D seal asst', pup and x-nipple. P/LT 5-1/2" CIBP and RIH w/ same on tbg. January 14, 2005 RIH w/ CIBP on tbg to 8,760'. Drop ball, set BP. P/U 2' and circ 1 tbg vol. Pump 5 bbls cmt followed by 47.5 bbls mud. Pull up 4 stands, reverse out 2 tbg volumes. Recd 1 bbl contaminated cmt. Test cmt plug to 5,000 psi for 30 min on chart - OK. Slug pipe, POH. P/U second 5-1/2" CIBP and RIH. Attempt to set -would not set. POH. January 15, 2006 Disassemble CIBP, clean same and reassemble (setting sleeve packed w/ barite). RIH w/ CIBP and set at 3,058'. Pump 4.6 bbls cmt, displace to CIBP w/ mud. Pull up 2 stands and reverse out. POH, L/D tbg. L/D CIBP running tool. RIH w/ tbg f/ derrick and POH L/D same to 210'. Displace hole w/ water f/ 210' to surf. Pump 3.5 bbls cmt f/ 210' to surface. POH 6 jts tbg, pump cmt f/ 19' to surf, displace w/ H2O. R/D cmtrs, handling equip and subs. N/D BOP's. • • January 16, 2006 Finish N/D BOP's. Draw down 40' fluid out of 5-1/2" casing. Drop tape, tag cmt at 71.4'. AOGCC rep requested cmt be brought closer to surface. R/D catwalk and v-door, L/D drill pipe from derrick. Hand-mix 2 drums cement, pour 9 sx into 5-1/2" casing. WOC while cleaning pits and preparing for rig move. Tag cement at 4' below ground level. N/LJ dry hole tree and test to 5,000 psi. Clean pits, r/d pipe racks, unwire top drive. January 17, 2005 Finish demob of rig. Prep and L/D top drive. Load misc equipment on trailers. Clean pits and cellar. Pull cables. Prep to L/D derrick. January 18, 2005 Shut down boiler, blow down steam and water lines. L/D derrick. Hang and unstring blocks. R/D pits and load out same. R/D pump house, load out secondary boiler. Backload misc trailers. Break tour to daylight operations only. S/D demob for night except mud dewatering continuing for 24 hr operations. January 19, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Load out misc loads on trailers. Lay over A-legs. Remove and tarp mud pumps, move to staging area. Remove drawworks skid, move to staging area. Move doghouse and water tank to staging area. S/D for night. January 20, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Break down derrick, demob same. Load out and demob all permit loads. Break down and load out misc rig components. S/D for night. January 21, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Finish loading. out all of Nabors Rig 129. Load out trailers w/ matting boards, clean up location. Load out mechanic's conex, parts house and man lift. P/LJ and recover liner. Prepare toolpusher's trailer for transport. S/D for night. January 22, 2006 Continue 24-hr mud de-watering operation. January 23, 2006 Continue 24-hr mud. de-watering operation. Finish demob of all drilling equipment from site. Mud de-watering will continue for several more days. Final report. s 2/8/2006 Middle Lake Unit #1A, API #50-283-20021-01 Geologic Markers Name Measured Depth TVD Top Tyonek 3,700' 3,658' • • 8-Feb-06 Middle Lake Unit #1A, API# 50-283-20021-01 Oil and Gas Shows Name Measured Depth TVD NONE '~ ~~ ~' ~ ~ ~,, rest Oil Corporat~n Alaska Division 310K.Street, Suite 700 ~~--r~b~~~ Anchorage, Alaska 99501 FEB 1 0 2006 Phone: (907) 258-8600 Fax: (907) 258-8601 Alaska Oil & Gas Cons. Commission DATA TRANSMITTAL Date: February~e 2006 To: John Norman AOGCC From: Barbara Kruk Forest Oil Cor oration 333 W. 7th Ave, Suite 100 310 K Street, Suite 700 Anchora e, AK 99501 Anchora e, AK 99501 Phone: (907) 279-1433 Phone: (907) 868 - 2113 FAX: (907) 258 - 8601 TRANSMITTAL DESCRIPTION Well data for Middle Lake Unit #1A, API#50-283-20021-01 aD5- In accordance with Alaska Statutes AS 31.05.035, we request that confidentiality be extended to all of the following information. Item No. Qty Description 1 1 Well completion report (AOGCC form 10-407) with attachments Attachment -Well Schematic Dia ram - 1 page Attachment -Daily Report of Well Operations (Operations Summary) - 7 pages Attachment -List of formations and other geologic markers encountered - 1 page _ Attachment -List of depth and formation name for oil and as shows - 1 page 2 1 Copy of geochemical and formation fluid analyses and reports if available. SGS -Laboratory Analysis Report (16 pages) 1 CD -Contains Digital file for Item 2 (SGS -Laboratory Analysis report); 1 File; No. CD1 MLU1A 1 Printout for CD1 MLU1A 3 1 Paper and di ital copies of all directional surveys & Directional Survey in ASCII 1 CD -Contains Digital files for Item 3 (Directional Survey)' 2 Files; No. CD2 MLU1A 1 Printout for CD2 MLU1A 4 1 Digital version of well logs in LAS format 1 CD -Contains Digital files for Item 4 (Well Lo sin LAS); 20 Files No. CD3 MLU1A 1 Printout for CD3 MLU1A Transmittals_AOGCC.xIs/MLU1A_2_9_06 Date Modified:2/9/2006 bk ,~~ t~ ~~ ~i '~~ ~, u r, F~rest Oil Corporat~n Alaska Division 310 K Street, Suite 700 Anchorage, Alaska 99501 Phone: (907) 258-8600 Fax: (907) 258-8601 DATA TRANSMITTAL Date: February 9, 2006 Item No. Qty Description Well Middle Lake Unit #1A, API#50-283-20021-01 5 7 Paper and Se pia copy of all Logs run (7 paper copies 7 sepia's (denoted by s in qty column) Log Date Run# Bottom Log Interval Top Log Interval Description S 12/25/05 1 9,282' 8,835' Modular Dynamic Tester, MDT - GR S 12/25/05 1 9,350' 8,461' Spectral GR, NGT-DSLT-PEX, 2" :100' S 12/25/05 1 9,350' 8,461' Spectral GR, NGT-DSLT-PEX, 5" :100' S 12/25/05 1 9,350' 8,461' Platform Exp. -Sonic -Spectral GR, NGT-DSLT-PEX, 2" S 12/25/05 1 9,350' 8,461' Platform Exp. -Sonic -Spectral GR, NGT-DSLT-PEX, 5" S 12/29/05 1 9,245' 5,000' Cement Bond Log, DSLT-GR-CCL S 01/06/06 1 8,712' 8,460' Perforating Depth Control GR/CCL - TCP Guns 1 CD -Contains Files for Item 5 (Well Logs PDS Format); 7 Files No. CD4 MLU1A 1 Printout for CD4 MLU1A CONFIDENTIAL DATA Please sign below to acknowledge receipt. Received By: Date a' Returned to Forest Oil Date Accepted By: Transmittals_AOGCC.xIslMLU1A 2 9_O6 Date Modified:2/9/2006 bk Apparent V'Vater Salinity Plot COMPANY Shell Oil Company WELL Middle River State No.1 API# 9265013320005000 FIELD Mid Grd ShoallTrdng Bay ~ ~ t i _(~ COUNTRY Kenai STATE Alaska ~~ _ T / SECTION 5 TOWNSHIP 10N RANGE 13W LOCATION 1980FSL 1980FWL Permanent Datum GL Elevation 27 Hevation: FC.B. 42 Log Measured from DF 14 Above Permanerk Datum D.F. 41 Driling Measured from DF G.L. 27 Date 5-Mar-1967 Rm 2. Rm Temp 65. Bottom Log Interval 5280 Rmf 1.5 Rmf Temp 75. Tap Log Interval 970 Rmc 1.83 Rmc Temp 72. SP METHOD -ENVIRONMENTALLY CORRECTED SP USED. RMF=1.5~75F USED. RP METHOD -COMPUTED TOTAL POROSITY USED VNTH DEEP RESISTIVITY A=0.62, M=2.15 USED IN COMPUTATION. VALUES COMPUTED FOR CLAY VOLUME L.T.10% ONLY. 5TH ORDER BEST FIT CURVE DISPLAYED FOR SP AND RP METHODS -.. i U 2 ~ v~b00. C '~ 30000. Ti .. ?5000. C 6 a d 20000. 15000. 5IAOU. Middle River State No.1 Fu~maliun Wales Salinity Plut - SP Methud tlkHl/ well Interval plot boo. txs0. tsoo. t7so. 9829 pairAS platta7 aiE cf 20108 pJell 0erths Midda lavar Sake Na.1 254.E ~ 52805E ~ M,dclo Povar Sda No.i 254.E • 52805E Ge. 4000. 4250. • Middle River State No.1 Fmmnliun Walu1 Salinity Plut - RP Melhud 141rtlU well Inter~if pld 8000 5500 6000 4600 X4000 V 2 ~}..$JDik S ~ 3000 ~~ e tai KC x000 1500 1000 5nB ~. I. 1. G 1. I. 1. 1. 1750. 3000. 3250 Tuir. Vr~tlral prlfh (FIJ e~~ ~ 'i, u '~ n n - i o ,~ ~~ u ;.~ pr. .. -' n ~~ ~ ~ U J ! ~l n ;a4' - _ ~ . i ~ ~ t ~t~ }~ :~ O j C ~ _ C: ~I 8------ ~ , a. R ~~ It q d' ~ 0 E c 3soo. ~~se. 4000. 9820 pair4s plcttad o~! d 20108 14>cll Depths MiCde IPovar Saka No.1 254.E ~ 52805E } Midda Rvar S3a Ho.1 254.E • 52805E Scale :1:1200 Middle River State No.1 TVD (599.75FT - 5111.27FTJ 819x200516:56 .,-.. ._,...~ ,_~,., .-_._.__.~._r.._..~_A,,._~~._ _-... . _ _ . _._. _.......,,_..~~- ~ .~. SP CORRECTED (J ~ TVD ~ SHALLCNVRES (OHMM) TOTAL POROSITY (Dec) SP SALINITY (PPM) -100. 0. FT 2. 200.j0.5 0. 0. 100000. CLAY VOLUME (Dec) DEEP RES (OHMM) RP SALINITY (PPM) 0. -----~~--~-•---°1. 2. 200. 0. 100000. FIT RP SALINITY (PPMj 0.~------------100000.: FIT SP SALINITY (PPM) 0. ------------ 100D00.`.., 700 800 90D 1000 1100 1200 1300 1400 1 S00 1600 170D 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 moo 3100 3200 3300 3400 3500 3600 3100 3800 3900 4DD0 4100 „'`~-~,.~.~; SP CORRECTED O TVD ~ SHALLOW RES (OHMM) TOTAL POROSITY (Dec) ~ SP SALINITY (PPM) D• FT ~2• 200.0.5 0.~0. 100000. f^I IIV 1Jfll 1 IhAF fflarl ftFFP RFC fflHhAhAI I RP CIII IAIRV fPphAl • • .- .. RESISTIVIT NOMOGRAPH FOR NaC SOLUTIONS R a ~SZ m) cn T .01 of oC - 50 10 - Conversion approximated by: g/kg Grains/gal. or ®24°C - 60 k PPm or75°F _ 20 (T I+ 6.77 R = R ~F 300 17500 130 0 70 2 I ` T2+ 6.77 (Arps)' 200 0 . 10000 - ao or Ioo 80 5000 90 30 R_ R T 1+ 21.5 o C - ~ ~ 60. 3000 2 I T2+21.5 ' 40 100 30 2000 - 40 20 1000 - 50 = .. 10 , 8 500. 60 400 - 150 6 - 300 _ 4" - ~e 80 ~'; ~ --~ T : ~d. - _ d - <..~ r J ..~ ~--~ -: .. -- .. <~ . . ,loo ~ A ~ loo ~, - Q ,~ e . .r,. r" ,~ ~ 1 50 250 120 8 .6 40 30 - 140 ~`~='a , .r'P .4 _ 20 300. 160 ~.- ~ ~1-ter "'" ~'~~1 ~ ~ ~ ~ .3 2 180 . ' ~! ~~~ t..t.~~= ~ - ©Schlumberger - 400 200 ' ~;.. ,~ - _~ ? 24 0 ^.. \ ~ ~ - 500 260 =, , ~~~-~.. ~ >°'~ : ~.. cr ._ - =.02 Ia - .03 = .04 - .05 -.06 =.os - 0. I - a v -.2 -.3 -.4 -.6 ~ -.8 _ .=,~ c - I.0 ~ =2 -3 = or =4 -5 ~6 ~~ ~8 ~10 3 N 20 r_e.,_o ,~ G P,~ ..5~ G•~SUMc°~.S i ~~ ~Cl ~ 2i • ~ 3 "' ~G O/G C ,/i ~o~t/ j~;7Cs ,iq ~ ~°j l~4/ i~ j ~~J `~ F~,~ •~.5•~~l1rJDsls ~ wriiw ~~ www ~ 2 ~s _ _ x ,,,, cn <n cn .. • 000 u~oo N N N ~ -~ ~ r a ~.,is rQ ~ ° ~Z "- Z~J ~~~ J d ~..~~ / v~~~c 4 ~ z~ 5,.~ a r ~frt Zc3 JZ c.~~ f~~` 3 0 ~ • F O R E S T O I L C O R P O R A T I O N • .370 ~J~r~y/~~~1 • ~~~~te X00 ~S~l~c~io i-...~. , C~~'Y-las~ 9950 • ~907~ ~5~-s6oo ~ X907) X58-860 ~~~aa~ January 24, 2006 ~~~~~ Mr. John Norman, Chair ~ _ (~ JA N ~ ~ ~ O~J6 Alaska Oil and Gas Conservation Commission ~ ~"~ Alaska ~~ ~ ~~~ Cvn~. Co~~>'MSSion 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ~, Anchorage RE: Weekly Report of Operations Middle Lake Unit #1-A Dear Mr. Norman, This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of January 17 through January 23, inclusive. January 17, 2005 Finish demob of rig. Prep and L/D top drive. Load misc equipment on trailers. Clean pits and cellar. Pull cables. Prep to L/D derrick.. January 18, 2005 Shut down boiler, blow down steam and water lines. L/D derrick. Hang and unstring blocks. R/D pits and load out same. R/D pump house, load out secondary boiler. Backload misc trailers. Break tour to daylight operations only. S/D demob for night except mud dewatering continuing for 24 hr operations. January 19, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Load out misc loads on trailers. Lay over A-legs. Remove and tarp mud pumps, move to staging area. Remove draw works skid, move to stagnb area. T:~C~'e ~?oghe'.:se and ~=.'ater taru~ to utabznb urea. C!n fvr :::g?~~. January 20, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Break down derrick, demob same. Load out and demob all permit loads. Break down and load out misc rig components. S/D for night. January 21, 2005 Continue 24-hr mud de-watering operation. Commence work at daylight. Finish loading out all of Nabors Rig 129. Load out trailers w/ matting boards, clean up location. Load out mechanic's conex, parts house and man lift. P/U and recover liner. Prepare tool pusher's trailer for transport. S/D for night. January 22, 2006 Continue 24-hr mud de-watering operation. a Mr. John Norman Page 2 January 23, 2006 Continue 24-hr mud de-watering operation. watering will continue for several more days. Finish demob of all drilling equipment from site. Mud de- Final report. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION ~~~~ ~ Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather • • F O R E S T O I L C O R P O R A T I O N •~ .390 C~~~C?~fxnpt . C~~,cale X00 Y • C~c/w~a~~, Caeca 9950/ X907) X58-~~00 • ~907~ X58-seo~ ~~~~) ~-~ ~- ~~a January 17, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Middle Lake Unit #1-A ~E~a~~VE~ JAN 1 S 2006 Alaska Oil & Cas Cons. Comm~ssi~r~ Anchorage Dear Mr. Norman, This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of January 10 through January 16, inclusive. January 10, 2005 Finish securing flowlines. Test surface safety valves. Pump methanol into chemical injection line. Pressure up to 2,500 psi, then bleed back to 1,500 psi -guns fired. SITP went from 1,850 psi to 2,000 psi. Turn well over to testers. Flow well. Flowed back total of 180 bbls (tbg capacity 52.4 bbls). Started on 12/64 choke w/ tbg pressure at 1,900 psi, finished on 25/64 choke w/ tbg pressure at 200 psi. Flowed back 8.3 ppg H2O, chlorides 11,000 ppm. SI well, blow down test equip. SITP 2,000 psi, SICP 750 psi afte 1-1/2 hrs. R/U pump lines to tree and test to 3,000 psi. Pump 10.4 ppg completion fluid into well at 2,900 psi. January 11, 2005 Pump down tbg w/ rig test pump while waiting for BJ pumper and crew. Pumper 45 bbls (tbg capacity 52.4 bbls), test pump started leaking. R/U BJ pumper. SITP 2,036 psi. BJ pumping at '/z bpm, pressured climbed to 3,870. psi and broke back to 3,612 psi after 4.5 bbls pumped. Pressure climbed to 4,000 psi with 15.6 bbls pumped. S/D pump, pressure declined to 2,300 psi in 17 minutes. Resume pumping at 0.7 bpm, pressure climbed to 5,000 psi. S/D pump, pressure declined to 2,455 psi in 22 minutes. S/I well, R/D BJ. R/U slickline lub, test to 4,000 psi. RIH w/ PX plug and set in x-nipple at 8,787'. POH, P/U check set tool, RIH, verify plug set in profile, POH. P/U prong, RIH, set prong in x-nipple, POH. R/U test line, test PX plug to 5,000 psi for 30 minutes - OK. Bleed tbg pressure to 0 psi and leave well open for 30 minutes - OK. R/D slickline, install BPV, N/D tree. January 12, 2005 N/U BOP's, install VBR's. Pull BPV, set 2-way check. Test BOP's - no good. Pull test plug and 2-way check, clear debris, reset same. Test BOP's - no good. Determined chemical injection line not plugged. Pull bell nipple, flowline, choke and kill lines and break flange at tbg head. Install plug on chemical injection line. Reinstall everything. Commence testing BOP's to 250/5,000 psi. Mr. John Norman Page 2 January 13, 2005 Finish testing BOP's to 250/5,000 psi; Hydril to 250/ 3,500 psi. B/O test jt, M/U landing jt, R/U cmtg unit to attempt to establish injection down 9-5/8" x 13-3/8" annulus using H2O. Pump 2.1 bbls, pressured up to 1,500 psi. Hold'pressure for 10 minutes w/ no bleed-off. Release pressure, got back 1.5 bbls. R/D cmtg lines. R/U to handle 2-7/8" tbg. BOLDS, pull tbg hgr to rig floor to pull seals from pkr. Displace hole ~v/ 14.9 ppg mud. L/D tbg hgr and landing joint. Slug pipe and POH w/ tbg. L/D seal assy, pup ahd x-nipple. P/U 5-1/2" CIBP and RIH w/ same on tbg. January 14, 2005 RIH w/ CIBP on tbg to 8,760'. Drop ball, set BP. P/U 2' and circ 1 tbg vol. Pump 5 bbls cmt followed by 47.5 bbls mud. Pull up 4 stands, reverse out 2 tbg volumes. Recd 1 bbl contaminated cmt. Test cmt plug to 5,000 psi for 30 min on chart - OK. Slug pipe, POH. P/U second 5-1/2" CIBP and RIH. Attempt to set -would not set. POH. January 15, 2006 Disassemble CIBP, clean same and reassemble (setting sleeve packed w/ barite). RIH w/ CIBP and set at 3,058'. Pump 4.6 bbls cmt, displace to CIBP w/ mud. Pull up 2 stands and reverse out. POH, L/D tbg. L/D CIBP running tool. RIH w/ tbg f/ derrick and POH L/D same to 210'. Displace hole w/ water f/ 210' to surf. Pump 3.5 bbls cmt f/ 210' to surface. POH 6 jts tbg, pump cmt f/ 19' to surf, displace w/ H2O. R/D cmtrs, handling equip and subs. N/D BOP's. January 16, 2006 Finish N/D BOP's. Draw down 40' fluid out of 5-1/2" casing. Drop tape, tag cmt at 71.4'. AOGCC rep requested cmt be brought closer to surface. R/D catwalk and v-door, L/D drill pipe from derrick. Hand-mix 2 drums cement, pour 9 sx into 5-1/2" casing. WOC while cleaning pits and preparing for rig move. Tag cement at 4' below ground level. N/U dry hole tree and test to 5,000 psi. Clean pity, r/d pipe racks, unwire top drive. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION ~~~ Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather CUSTOMER FOREST OIL CORPORATION DATE i3-JAN-O6 F.R',. # 276120286 SERV. SUPV. Robert Moore LEASE 8 WELL NAME #1 LOCATION COUNTY-PARISH-BLOCK Kenai Alaska DISTRICT DRILLING CONTRACTOR RIG # TYPE OF JOB OF -C P UR Y I NA-P&A SACKS SLURRY ~ SLURRY OF WGT I YLD CEMENT ~ PPG FT3 ~ ( WATER" PUMP ' GPS ;TIME ~HR:MIN Bbl SLURRY Bbl MIX I WATER MATERUILS FURNISHED BY BJ I ~ ' I I I CaCI brine 10.4 2.1 a Available Mix Water 400 Bbl. Available Displ. Fluid 280 Bbi. TOTAL 2.1 HOLE TBG-CSG-D.P. COLLAR DEPTHS S ° XC S D PT E GT TYP 13.375 61 CSG 2958 ~ 9.625 47 CSG 8500, LAST CASING PKR-GMT RET-BR PL-LINER PERF. DEPTH I TOP CONN I WELL FLUID SIZE I WGT i TYPE !DEPTH BRAND 8 TYPE !DEPTH ma I BTM SIZE .THREAD TYPE I WGT. I ( 15021 WATER BASED M 10 DISPL. VOLUME I DISPL. FLUID CAL. PSI ICAL. MAX PSI ; OP. MAXI MAX TBG PSI MAX CSG PSI ~ MIX VOLUME I UOM TYPE WGT. !BUMP PLUG TO REV. SO. PSI RATED i Operator RATED Operator I WATER 180 , BBLS i 2000' ~ i i IRig EXPLANATION: TROUBLE SETTING TOOL, RUNNING CSG, ETC. PRIOR TO CEMENTING: PRESSURFJRATE DETAIL EXPLANATION TIME PRESSURE -PSI RATE I Bbl. FLUID FLUID SAFETY MEETING: BJ CREW X CO. REP. X HR:MIN. ~ pIPE ANNULUS ~ BPM PUMPED ~ TYPE TEST LINES 2800 PSI I I CIRCULATING WELL -RIG "! BJ 10:27 2800 ~ I ( ( ~ Pressure test. 10:33 ~ .5 ( CAGE Begin inj. test. 10:37 I 1000 j I 1.5 I I Stop pump, watch for a few minutes. No pressure break. 10:39 I 1000 j ; 3 ~ :I Restart pump. 10:41 ~ 1200 ! I 1.7 ~ (Stop pump, watch for a few minutes. No pressure break. ~i 0:43 ; 1200 j .3 I I Restart pump. 10:48 1500 I 2.1 ~ Stop pump, watch for a few minutes. No pressure break. 10:59 I, 1475 ! i i I I i3{eed pressure, 1.5 bbis returned. End yob. PSI TO HUMPED BUMP PLUG PLUG TEST FLOAT EQUIP. BBL.CMT RETURNSI REVERSED TOTAL BBL. PUMPED PSI ' SPOT LEFT ON i TOP OUT ; SERVK:E SUPERVISOR SKiNATURE: I CSG CEMENT ~!1 i i C ®~~ I ~ 1 ~hZ'~ ~lhYdCO-~f~~~'l~ti ~CVU.~VC"~~cj CAIf\ U't1~~'~~~. ~C3 p~~p ~ ~.~~ -~ ~c 5~~~~ t~~/~ ' ~v~~J~v 5 ors Kti~c~\~-_I.c~~ v `, ~'~ A ~c>`s v.Ok- ~Yc~~ ~~~C` ~~ ~`s ~~ ~ ~ r~~ ~f~ a~n~J`v Sl. /i"~!~ t~~`1~~~ Jr8004 ,.^^.?^. e°on: aan-ia-os iiz+.:4e Page `i BJ Services Jo~ster Program Version 3.00 • Job Number: 2761 85 Customer: Forest Oil ~„ ~ ;Well Name: Middle Lake 1 Elapsed Press Time ; (per) Friday, January 13, 2006 0:00:00:05 0 0:00:01:06 0 0:00:02:07 2714 0:00:03:08 2591 ~ ~~ E J~ ! t ~2 c ~ z=5 /' 0:00:04:09 0 0:00:05:10 0 0:00:06:10 390 0:00:07:11 631 0:00:08:13 832 0:00:09:13 1001 f, ~ ~ b L 0:00:10:15 982 0:00:11:16 1044 0:00:12:16 1180 t ~ J- 1 ~~,~ 0:00:13:18 1185 0:00:14:18 1181 0:00:15:19 1272 0:00:16:20 1361 0:00:17:21 1415 0:00:18:21 1465 0:00:19:22 1493 l , t ~ ~ S 0:00:20:23 14$4 0:00:21:24 1480 0:00:22:25 1482 0:00:23:27 1480 0:00:24:27 1479 0:00:25:28 1474 0:00:26:30 1476 0:00:27:30 1471 0:00:28:31 1436 0:00:29:32 0 0:00:30:33 0 2 ~ r•~ :~ ,u c ~ !, S s~ h f .S 0:00:31:34 0 0:00:32:34 0 0:00:33:09 0 X05 - ~`~~ BJ Services Job Start: Friday, January 13, 2006 BJ Seirvices JobMaster Program Version :3.00 Job Number: 276120285 Customer: Forest Oil .,°Y WeN Name: Middle Lake 1 Middle Lake #1 13 3/8 x 9 5/8 ann. inj. test - T T r-T-T~-'~-T~"I- i IT ' I I j i ~~ Pressure test 2800 psi .~ ;;, i I i,_ __,_ \, ~- 1475 psi end test Q , 1500 psi, stop pump ~ I 2.1 bbls pumped -. I _ ~~ ~ 0 psi, stop pump j 1.7 bbls pumped I ,~, ~ ~ ~ ~ \ ~ ~ - 1000 psi, stop pump ~ r~ ~ ~ ~ ~ ~ 1.5 bbls pumpd i ,, /i s i i, i ~- Begin injection test Bleed back 1.5 bbls ~; i ~ ~ I ~ ~ ~ ~ I „ ... BJ Services Job Start: Friday, January 13, 2006 .~ MEMORANDUM TO: Jim Regg ~~ ~ ~31~~~ P. I. Supervisor ~~ FROM: John Spaulding, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 13, 2006 SUBJECT: Middle Lakes Unit 1A PTl3 X149 Forest Oil Corp. Exploration January 10, 2006: I traveled to Forest Oil Corp.'s Middle Lakes Unit 1A well to witness the Christmas tree pressure test. A body or shell test was performed. The tree was rated to 10,000 psi. The test pressures and times are as follows, 300 psi low -held for 5 minutes, 8,200 psi high - held for 15 minutes. The low-pressure test exhibited a straight line on the chart. Several attempts were made to get the air worked out of the tree on the high-pressure test. Once the air was worked out the test held for the 15-minute period with no apparent bleed down. Test chart is attached. January 13, 2006: I once again traveled to the MLU 1A well to witness a possible injectivity test for annular disposal of drilling muds in preparation for plugging and abandoning the well. Attempts were made to establish flow down the 13-3/8 X 9-5/8" annulus. A maximum of 1500 psi was reached with no apparent breakdown of the formation; 2.1 barrels of brine was pumped into the annular area and 1.5 bbls were recovered. The test did not establish any flow rate. Therefore no annular disposal will be attempted. SUMMARY: I witnessed a successful shell test of the MLU #1A production tree, and an unsuccessful attempt to establish injectivity for annular disposal. Attachments: 2 Test Chart -Production Tree Shell Test (2 pgs) BJ Services Injectivity Test Report (3 pgs) . CEMENT J. B REPORT ..fin ~~~~1 ~e.- ~~ X05- (~ CUSTOMER FOREST OIL CORPORATION DATE 13-JAN-O6 F.R. # 276120286 SERV. SUPV. Robert Moore LEASE & WELL NAME LOCATION A ~ ~~ ~ (~ COUNTY-PARISH-BLOCK #1 ~V Kenai Alaska DISTRICT DRILLING CONTRACTOR RK~ # TYPE OF JOB S12 S NA-P&A SACKS SLURRY SLURRY WATER" PUMP Bbl Bbl OF WGT YLD GPS TIME SLURRY MIX CEMENT PPG FT3 HR:MIN WATER MATERUU_S FURNISHED BY BJ CaCI brine I 10.4) I ( 2.1 Available Mix Water 400 Bbl. Available Displ. Fluid 280 Bbl. TOTAL 2.1 HOLE TBG-CSG-D.P. COLLAR DEPTHS S P H O 13.375 61 CSG 2958 9.625 47 CSG 8500 LAST CASING PKR-CMT RET-BR PL-LINER PERF. DEPTH TOP CONN WELL FLUID SIZE I WGT TYPE DEPTH BRAND & TYPE I DEPTH ma I BTM SIZE I THREAD TYPE I WGT. 1502 WATER BASED M 1 DISPL. VOLUME DISPL. FLUID CAL. PSI CAL. MAX PSI I OP. MAXI MAX TBG PSI I MAX CSG PSI MIX VOLUME UOM TYPE WGT. BUMP PLUG TO REV. SQ. PSI RATED Operator RATED Operator WATER 180 BBLS 2000 Ria EXPLANATION: TROUBLE SETTING TOOL, RUNNING CSG, ETC. PRIOR TO CEMENTING: TIME PRESSURE -PSI RATE Bbl. FLUID FLUID SAFETY MEETING: BJ CREW U CO. REP. U HR:MIN. pIPE ANNULUS BPM PUMPED TYPE TEST L-NES 2800 PSI I CIRCULATING WELL -RIG BJ 10:27 2800 ( Pressure test. 1033 .5 I CACL Begin inj. test. 10:37 1000 ~ 1.5 Stop pump, watch for a few minutes. No pressure break. 10:39 ~ 1000 ~ .3 ~ ~ ~ Restart pump. 10:41 1200 1.7 Stop pump, watch for a few minutes. No pressure break. 1 u.43 1200 .3 Restart pump. 10:48 1500 2.1 I Stop pump, watch for a few minutes. No pressure break. 10:59 I 1475 ~ ~ i Bleed pressure, 1.5 bbls returned. End job. PSI TO TEST BBL.CMT TOTAL PSI SPOT BUMPED BUMP FLOAT RETURNSf BBL. LEFT ON TOP OUT SERVICE SUPERVISOR SIGNATURE: PLUG PLUG EQUIP. REVERSED PUMPED CSG CEME ^ ® i~(s~">~ Repoli?!!:leA on: JAN-i bO611 ~+..nn P`~,e ~ Jre004 BJ Services Jo aster Program Version 3.00 ~~< '~ :~ Job Number: 27 285 3~s Customer: Fore Oil ~~,„., ~ Well Name: Middle take 1,A .~ Elapsed Press Time 1 (P~) Friday, January 13, 2006 0:00:00:06 0 0:00:01:06 0 0:00:02:07 2714 0:00:03:08 2591 Pct F:>~5 u ~ c 7z=5 ~' 0:00:04:09 0 o:ee:e5:10 0 0:00:06:10 390 0:00:07:11 631 0:00:08:13 832 0:00:09:13 1001 I, S~ 1 6~ 0:00:10:15 982 0:00:11:16 1044 0:00:12:16 1180 ~ e 7- ~ 0:00:13:18 1185 0:00:14:18 1181 0:00:15:19 1272 0:00:16:20 1361 0:00:17:21 1415 0:00:18:21 1465 0:00:19:22 1493 ,j , 1 5 ~ ~ 0:00:20:23 1484 0:00:21:24 1480 0:00:22:25 1482 0:00:23:27 1480 0:00:24:27 1479 0:00:25:28 1474 0:00:26:30 1476 0:00:27:30 1471 0:00:28:31 1436 0:00:29:32 0 0:00:30:33 0 t2 ~: ~ .e ~ c--: ~ ~. S ~ b t ~ 0:00:31:34 0 0:00:32:34 0 0:00:33:09 0 BJ Services Job Start: Friday, January 13, 2006 ~ ~ ~ BJ Seirvices JobMaster Program Version 3.00 . Job Number: 276120285 Customer: Forest Oil Well Name: Middle Lake 1 Q (~ ~ ~ _ ~ 4~t Middle Lake #1 13 3/8 x 9 5/8 ann. inj'. test ~-~T /- Pressure test ~- 2800 psi \'~ 1500 psi, stop pump 1475 psi, end test ' ~ - 2.1 bbls pumped ~- 1200 psi, stop pump - 1.7 bbls pumped ii f ~ ~ 1000 psi, stop pump ~ A ~ 1.5 bbls pumpd I Begin injection test ' -Bleed back 1.5 bbls • BJ Services Job Start: Friday, January 13, 2006 SGT ~ • Laboratory Analysis Report 200 W. Potter Drive Anchorage, AK 99518-1605 Tel: (907)562-2343 Fax: (907)561-5301 Web: http://www.us.sgs.com Paul Winslow Forest Oil Corporation 310 K Street Suite 700 Anchorage, AK 99501 Work Order: 1060201 Middle Lake lA Released by: Client: Forest Oil Corporation ~~~~ Bryan J. Arnold Report Date: February 03, 2006 ~~ 2006.02.03 Alaska Oivisxm Pnlxs Marw6er 15:06:50 -09'00' Enclosed are the analytical results associated with the above workorder. As required by the state of Alaska and the USEPA, a formal Quality Assurance/Quality Control Program is maintained by SGS. A copy of our Quality Control Manual that outlines this program is available at your request. The laboratory ADEC certification numbers are AK971-OS (DW), UST-005 (CS) and AK00971 (Micro). The laboratory NELAC certification number is 001327. Except as specifically noted, all statements and data in this report are in conformance to the provisions set forth by the SGS Quality Assurance Program Plan and the National Environmental Laboratory Accreditation Program. If you have any questions regarding this report or if we can be of any other assistance, please call your SGS Project Manager at (907)562-2343. PQL Practical Quantitation Limit (reporting limit). U Indicates the analyte was analyzed for but not detected. F Indicates value that is greater than or equal to the MDL. J The quantitation is an estimation. ND Indicates the analyte is not detected. B Indicates the analyte is found in a blank associated with the sample. * The analyte has exceeded allowable regulatory or control limits. GT Greater Than D The analyte concentration is the result of a dilution. LT Less Than ! Surrogate out of control limits. Q QC parameter out of acceptance range. M A matrix effect was present. JL The analyte was positively identified, but the quantitation is a ]ow estimation. E The analyte result is above the calibrated range. Note: Soil samples are reported on a dry weight basis unless otherwise specified. SGS Environmental Services Inc. 1200 W. Potter Dr, Anchorage AK, 99518-1605 t (907) 562-2343 f (907) 561-5301 www.us.sgs.com ~G~ ~ SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1060201001 Forest Oil Corporation Middle Lake lA 158 bbls Other Liquids -.~~ All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 18:20 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Difference 3.2 % SM20 1030E A 02/02/06 KAW Routine Oilfield Water Analysis Alkalinity 1890 100 mg/L SM20 2320B A 01/18/06 PLW Chloride 9360 100 mg/L EPA 300.0 01/17/06 DSH C03 Alkalinity 100 U 100 mg/L SM20 2320B A 01/18/06 PLW HC03 Alkalinity 1890 100 mg/L SM20 2320B A 01/18/06 PLW OH Alkalinity 100 U 100 mg/I, SM20 2320B A 01/18/06 PLW pH 7.13 0.100 pH units EPA 150.1 A 01/16/06 KP Resistivity 0.345 0.0100 ohm-m SM19 2510A A 01/16/06 KP Sulfate 75.3 1.00 mg/L EPA 300.0 A 01/17/06 DSH Dissolved Metals Barium 21.0 0.100 mg/L, EP200.7 Dissolved A 01/23/06 01/30/06 PJH Calcium 383 2.00 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH Iron 0.400 U 0.400 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH Sodium 6430 200 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH Strontium 40.0 0.100 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH Magnesium 43.5 2.00 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH Metals by ICP/MS Potassium 287000 20000 ug/L 200.8 Dissolved A 01/23/06 02/01/06 TK SGS Ref.# 1060201002 Client Name Forest Oil Corporation Pro,jectName/# Middle Lake lA Client Sample ID 145 bbls Matrix Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 18:10 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Difference 0.79 Routine Oilfield Water Analysis Alkalinity 1880 Chloride 9300 C03 Alkalinity 100 U HC03 Alkalinity 1880 OH Alkalinity 100 U pH 7.18 Resistivity 0.323 Sulfate 80.9 Dissolved Metals Barium Calcium Iron Sodium Strontium Magnesium Metals by ICP/MS Potassium SM201030E A 02/02/06 KAW 100 mg/I, SM202320B A 01/18/06 PLW 100 mg/L EPA 300.0 01/17/06 DSH 100 mg/L SM20 2320B A 01/18/06 PLW 100 mg/L SM20 2320B A 01/18/06 PLW 100 mg/L SM20 2320B A 01/18/06 PLW 0.100 pH units EPA 150.1 A 01/16/06 KP 0.0100 ohm-m SM19 2510A A 01/16/06 KP 1.00 mg/L EPA 300.0 A 01/17/06 DSH 20.9 0.100 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH 371 2.00 mg/L EP200.7 Dissolved A 0]/23/06 01/30/06 PJH 0.400 U 0.400 mg/L EP200.7 Dissolved A 01/23(06 01/30/06 PJH 6370 200 mg/L, EP200.7 Dissolved A 01/23/06 01/30/06 PJH 39.8 0.100 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH 43.8 2.00 mg/L EP200.7 Dissolved A 01/23/06 01/30/06 PJH 282000 20000 ug/L 200.8 Dissolved A 01/23/06 02/01/06 TK ~- ~ SGS Ref.# 1060201003 Client Name Forest Oil Corporation Project Name/# Middle Lake lA Client Sample ID 130 Matrix Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 17:40 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container [D Limits Date Date Init Waters Department Chloride 9560 100 mg/L EPA 300.0 A 01/17/06 DSH Resistivity 0.303 0.0100 ohm-m SM19 2510A A 01/16/06 KP Oils Laboratory Density 1.05 ASTM D-287 A 01/26/06 PLW ~G~ ~ SGS Ref.# Client Name Project Name/# Client Sample ID Matrix 1060201004 Forest Oil Corporation Middle Lake lA 115 Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 17:05 Received Date/Time 01/12!2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Waters Department Chloride 9740 100 mg/L EPA 300.0 A 01/17/06 DSH Resistivity 0.313 0.0100 ohm-m SM19 2510A A 01/16/06 KP Oils Laboratory Density 1.04 ASTM D-287 A 01/26/06 PLW ~- ~ SGS Ref.# 1060201005 Client Name Forest Oil Corporation Project Name/# Middle Lake lA Client Sample ID 100 Matrix Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 16:05 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Waters Department Chloride 10200 100 Resistivity 0.313 0.0100 Oils Laboratory Density 1.05 mg/L EPA 300.0 A 01/18/06 DSH ohm-m SM19 2510A A 01!16/O6 KP ASTM D-287 A 01/26/06 PLW ~G~ ~ SGS Ref.# 1060201006 Client Name Forest Oil Corporation Pro,jectName/# Middle Lake lA Client Sample ID $5 Matrix Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 15:15 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Waters Department Chloride 11000 100 mg/L EPA 300.0 A 01/18/06 DSH Resistivity 0.286 0.0100 ohm-m SM19 2510A A 01/16/06 KP Oils Laboratory Density 1.04 ASTM D-287 A 01/26/06 PLW SGT SGS Ref.# Client Name Project Name/# Client Sample ID Matrix • 1060201007 Forest Oil Corporation Middle Lake lA 72 Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 14:30 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date lnit Waters Department Chloride 14300 100 mg/L EPA 300.0 A 01/18/06 DSH Resistivity 0.233 0.0100 ohm-m SM19 2510A A 01/16/06 KP Oils Laboratory Density 1.05 ASTM D-287 A 01/26/06 PLW ~~- • SGS Ref.# 1060201008 Client Name Forest Oil Corporation ProjectName/# Middle Lake lA Client Sample ID 69 Matrix Other Liquids All Dates/Times are Alaska Standard Time Printed Date/Time 02/03/2006 12:13 Collected Date/Time 01/10/2006 14:15 Received Date/Time 01/12/2006 11:24 Technical Director Stephen C. Ede Sample Remarks: Allowable Prep Analysis Parameter Results PQL Units Method Container ID Limits Date Date Init Waters Department Chloride 15200 100 mg/L EPA 300.0 A 01/18/06 DSH Resistivity 0.208 0.0100 ohm-m SM19 2510A A 01/16/06 KP Oils Laboratory Density 1.04 ASTM D-287 A 01/26/06 PLW Operator Well Number Field County State W A T 5 ~~8 Routine Oil Field Water Analysis Report ~a~ Date ~ ~a ~.ly Chem-Lab Ref. Number 1060201001 Approved By Location Sample From Remarks and conclusions: Cations ~ Mea.lL Anions ma/L Mea./L Sodium ................ • 6430 279.71 Sulfate .......... , 75.3 1.57 Potassium .............. 287 ___ 7.34 Chloride ......... , . 9360 263.20 Calcium ................ 383 19.11 Carbonate ............... 0.00 Magnesium ............. 43.5 3.58 Bicarf~onate ........ 1890 37.80 Iron ................... 0 0.00 Hydroxide .......... ...... 0.0 Total Cations .............309.74 Total Anions ........ 302.571 Total dissolved solids ...... 17713 mg/L Specific Resistance @ 68° F.: NaCI equivalent (chloride) 17076 mg/L Observed ............ 0.345 ohm-meters Observed pH ............ 7.13 Calculated ............ 0.41 ohm-meters Barium ................. 21.00 mg/L Strontium ............... 40.00 mg/L -------- Total Iron ............... 0.000 mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit ao /4 /G ~~ ra ro ~ ~ y a ~ N ~ 4 io Ia ~~! IL 1rl a.e ~.$0 Na(XlDO _ (Xfoo~Cl~3 Ca (Xio~ _ ~ua~IC03 3.78 ~$ Mg~XI~ . _.__...._ _ _ _ (X~~SO4~57 Fe _ _ C03 (Na value in above graphs includes Sodium, Potassium and L7] NOTE: mg/L =Milligrams per liter, Meq./L =Milligram equivalent per liter. Soldium Chbride equivalent = by Dunlap & Hawthorne calculation from components. • s Operator Well Number Field County State Routine Oil Field Water Analysis Report Date ~a a' o~ Chem-Lab Ref. Number. ~ 1060201002____ Approved By Location Sample From Remarks and conclusions: Cations ma/L Mea./L Anions mg/L M_ eq.lL Sodium ................. _ 6370 ._. 277.10 Sulfate ............ 80.9 1.68 Potassium .............. 282 7.21 Chloride .......... , 9300 261.52 Calcium ................ 371 18.51 Carbonate .......... ..... 0.00 Magnesium ............. 43.8 _ 3.60 Bicarbonate ........ 1880 37.60 Iron ................... 0 0.00 Hydroxide .......... ...... _ 0.0 Total Cations ............. 306.43 Total Anions ........ 300.800 Total dissolved solids ...... 17576 mg/L Specific Resistance @ 68° F.: NaCI equivalent (chloride) 16940 mg/L Observed ............. 0.323 ohm-meters Observed pH ............ 7.18 Calculated ............ 0.42 ohm-meters Barium ................. 20.90 mg/L Strontium ............... 39.80 mg/L Total Iron ............... 0.000 mg/L Water Analysis Pattern Scale: Milligram equivalents per Unit ab f8 /6 i~ ~; ra g b y 3 0 ,~ ~ b g ro iZ rd /b ~8 ~o a~77 Na(><roo) (Xr~o) CI ~•6~ // ~$5 Ca (Xto) - - _ za~tiC03~~, J~ Fe - C03 (Na value in above graphs includes Sodium, Potassium and L1) NOTE: mg/L =Milligrams per Ifter, Meq./L =Milligram equivalent per liter. Soldium Chloride equivalent = by Dunlap & Hawthorne calculation from components. e • Cation -Anion Balance Calculation Sheet SM 1030 E Prepared by: Karen Waak ~~'"`u ~ Date : 2nr2oos ;~~~~,\a' SGS Sample Number: 1060201001 W 14 T S!o(o-7 Nofe: For the purposes of this caMulation sheets the input values for Si0 $ "2 and Nitrate are mg/L. Silicon fmm ionic Silicon by co/orimetric SM 4500-Si02 undigested. Cations . _.~_ ug/L Meq/L Iron ..........:............ 0 0.00 Aluminum .............. 122000 13.57 Cadmium ............... 0.00 Calcium ............:.... 383000 19.11 Magnesium............ 43500 3.58 Manganese............. 0.00 Potassium .............. 287000 7.34 Sodium ................. 6430000 279.71 Zinc ....................... 0.00 Acidity CaC03mg/L..... 0.00 Total Cations, meq/L = 323.30 Anions .~.. Su Ifate .................. Chloride ............... Nitrate-Nitrogen Fluoride ............... Carbonate CaC03... Bicarbonate CaC03 Hydroxide CaC03 Silicon as Si Si Total Anions, meq/L = 303.41 mg/L Meq/L 75.3 1.57 9360 264.05 0.00 0.00 0.00 1890 37,80 0.00 0.00 Total Dissolved Solids, t~~! = 17835 mg/L Resistivity ~ 68 F = 0.345 ohm-meten3 _ Total Dissolved Solids, t°bsl mg/L Observed pH = 7.13 pH Units Difference = 3.17°~ Note: Carbonate and Bicarbonate Alkalinity are expressed as CaC03. Hydroxide Alkalinity as CaC03. Acidity as CaC03 is reported as a Cation. Acidity is ZERO for pH greater than 8.3. Carbonate Alkalinity is ZERO for pH less than 8:3. Acce tance Criteria Anion Sum Acceptable % Me L Difference 3.0-10.0 +/-2% 10.0 - 800 5°~ IonBalCalc • • Cation -Anion Balance Calculation Sheet SM 1030 E Pre ared b Karen Wa a~~`0~ Date : 2r2noos , '' ~ ~.~ SGS Sampie Number: 1060201002 Note: For the purposes of this calculation sheely the input values for Si0 s "2 and Nitrate are mg/L. Silicon from ionic Silicon by colorimetric SM 4500-Si02 undigested. Cations Anions ~ ~~ ug/L Meq/L Iron ....................... 0 0.00 Aluminum .............. 79.3 0.01 Cadmium ............... 0.00 Calcium ................. 371000 18.51 Magnesium............ 43800 3.60 Manganese............ 0.00 Potassium., ............. 282000 7.21 Sodium ................. 6370000 277.10 Zinc........................ 0.00 Acidity CaC03mg/L..... 0.00 Totai Cations, meq/L = 306.43 Sulfate .................. Chloride ............... Nitrate-Nitrogen Fluoride ............... Carbonate CaC03.., Bicarbonate CaC03 Hydroxide CaC03 Silicon as Si moll Meo/L 80.9 1.68 9300 262.35 0.00 0.00 0.00 -1880 37.60 0.00 0.00 Total Anions, meq/L = 301.64 Total Dissolved Solids, I~,cl = 17576 mg/L Resistivity Q 68 F = 0.323 ohm-meters Total Dissolved Solids, I°b,l = mg/L Observed pH = 7.18 pH Units Difference = 0.79% Note: Carbonate and Bicarbonate Alkalinty are expressed as CaC03. Hydroxide Alkalini as CaC03. Acidify as CaC03 is reported as a Cation. Acidity is ZERO for pH greater than 8.3. Carbonate Alkalinity is ZERO fw pH less than 8.3. Acceptance Criteria Anion Sum Acceptable % Me 2 Difference 0 - 3.0 +/- 0.2 meollL 3.0-10.0 +l-2~° 10.0 - 800 5% IonBalCalc CHAIN OF CUSTODY RECORD (~ ,tae 1Q602~~ •Hawalf SGS Environmental Services Inc. • Maryland • North Carolina ~, 048547 ' CLIENT ~~~.~ ~; , C~ SGS Reference: { PAGE OF CONTACT: ~c.+..-1 ~>,ns~!/t,J PHONENO:(Gj~j'~} ~~~'--Z131 Pres8ire6re PROJECT ,n/1' _" ~C ~~ ~] /t SITE/PWSID#: NC 9~PEE Used REPORTS TO: 1 4L: / 1"I O C- ~ u~ ~ ~ .~`. CAMP FAX NO.:( ) T 3 ~ ~ INVOICETO': QUOTE# A clue ~~ _ ,•~ 2 P.O. NUMBER E ~~" ~ to ~ ~ ~ ` ,f LAB NO. SAMPLE IDENI-iF1CAT10N DATE TIME MATRIX S REMARKS I3~ 'r 17'y~ / ,~ ~ )vo 'r 6 ~f~S' / /~ / ~ ~ +' s~ ts' / / ,~ Collect/e~d/~R,e/tinquished By:(1) Date Time Received By: Relinquished By: {2} Date Time Received By: Relinquished By: (3) ~ Date Relinquished By: O 200 W. Potter Dmre Anolrorape; AK 95540 Tel: (907) 552-2343 Faoc: (907) 5 O 5500 Business Ddve Wlimlepfon, NC 28100 Tel: (910) 350-1903 Fax: {410) Shipping Cartier: Samples Received Cold? {Circle}YES NO Shipping Ticket No: Temperature JC: ; Special Deliverable Requirements: Chain of Custody Seal: (Circle} INTACT BROKEN ABSENT Requested Tumatvund Time and Special Instructions: 01258 Greenlxier Street Charbstcn, YYV 25311 Tek (304j 346-0725 Fax: (soa) 34s-o7st wnlle-Retained byLab Yellow -Returned with Report ~ ~ ~ 1060201 SAMPLE RECEIPT FORM Yes No NA /' Are samples RUSH, priority, or w/n 72 hrs. of hold time? / If yes have you done a-mail notification? -/~ Are samples within 24 hrs, of hold time or due date? / If yes, have you spoken with Supervisor? _~ Archiving bottles- if req., are they properly marked? _~ :Are #here any problems? f'M Notified? _~ Were samples preserved correctly and pH verified? If this is for PWS, provide PWSID, -'' Wiil courier charges apply? Method of payment? ./ Data package required? (Level: 7 / 2 / 3 / 4 ) Notes: ~- Is this a DoD project? (USAGE, Navy, AFCEE) Notes: SGS WO#: Due Date: ~' ~ ~-c~~ Received Date: ~ - l,2 --~ !;, Received Time: 2,~ Is date/time conversion necessary? .~ # of hours to AI< Local T' e: ~----- Thermometer iD: _ ~ ~e~- Cooler ID Tema Blank Cooler Tema -`" °C °C _ °C °C ° °C °C. °C °C °C 'Temperature readings Include thermometer ra Delivery method (circle alt that appl Clien# Alert Courier /UPS / FedEx / USPS / AA Goldstreak ! NAC /ERA / PenAir / Carlile Lynden /SGS /Other: AirbiA # Additional Sample Remarks: (~:fapplicable) Extra Sample Volume? Limited Sample Volume? Field preserved for volatiles? Field-filtered for dissolved? Lab-filtered for dissolved? Ref Lab required? Foreign Soil? Completed by {sign): Login proof {check or ~---~ (print): _ required .performed by: S:doc Form # FD04r15 6/6/5 SAMPLE RECEIPT FORM (page 2) SGS WO#: iosazo~ ,_:~ - - = ~. 1 _ - .. .. ~~ Container Volume Container. T e Preservative # ~ ~ O U ~ Test U ,~ ~ N '-+ N o°o ° Other ~ '~" ~, •.. ~ Other ~ ~ x ~ Z x Other ,2 M~ ~ ~ , ~52~/• S or d Bottle Totals 11ncPCinacf)11ANK (',mnnilatalA„F,1;r1T1C1C`rT11AAAT'I~R(1Ri~RC1~,,,;r.,.,o.71eDF ~nnn,.t c .i.,.. Completed by: Date: (~~~--c5 ~ • Operator: Forest Oil Corporation Grid Correction: 0.00 Job No: 1007011 Field: Wildcat Magnetic Declination: 20.38 AFE No: #N/A Well: MLU lA Dip: 74.23 API No: ??? Rig: Nabors 129 Dogleg per: 100 ft MWD Company: BHI Sarface Location Original VS Plane: 274.62 Parent Well: MLU 1 X: 472183.00 ft View VS Plane: 274.62 RKB Height: 0.00 Y: 2695742.00 ft Start Date: 12/20/05 TD Date: 12/21/05 Meas. Incl. TRUE GRID RKB Coords. - Tme North Coords. -Grid Coords. -ASP or Grid Dogleg Original View Tool Build Tum Course Drilled Depth (ft) Angle (de) Azi. (de) Azi. (de) TVD (ft) TVD (fr) N(+)/S(-) (ft) E(+)/W(-) (ft) N(+)/S(-) E(+)/W(-) (ft) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) De . (X) Severity (°/100 ft) S (274.62° (fl) S (274.62° (ft) Face (de) (°/100 ft) (°/100 fr) Length (fl) Distance (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.23 30.89 30.89 100.00 100.00 0.17 0.10 0.17 0.10 0.17 0.10 0.23 -0.09 -0.09 #DIV/0! 0.23 30.89 100.00 100.00 201.10 0.50 135.21 135.21 201.10 201.10 0.03 0.52 0.03 0.52 0.03 0.52 0.59 -0.51 -0.5] 126 0.27 103.18 101.10 201.10 302.20 i.16 119.49 119.49 302.19 302.19 -0.78 1.72 -0.78 1.72 -0.78 1.72 0.68 -1.78 -1.78 -27 0.65 -15.55 ]01.10 302.20 403.40 1.19 116.93 116.93 403.37 403.37 -1.76 3.55 -1.76 3.55 -1.76 3.55 0.06 -3.68 -3.68 -62 0.03 -2.53 101.20 403.40 504.50 1.16 119.74 119.74 504.44 504.44 -2.75 5.37 -2.75 5.37 -2.75 5.37 0.06 -5.58 -5.58 119 -0.03 2.78 101.10 504.50 605.80 0.90 144.97 144.97 605.73 605.73 -3.97 6.72 -3.91 6.72 -3.91 6.72 0.51 -7.01 -7.01 132 -0.26 24.91 101.30 605.80 706.90 0.73' 181.47 181.47 706.82 706.82 -5.20 7.16 -5.20 7.16 -5.20 7.16 0.53 -7.55 -7.55 126 -0.17 36.10 101.10 706.90 808.00 0.77 180.81 ]80.8] 807.91 807.91 -6.52 7.13 -6.52 7.13 -6.52 7.13 0.04 -7.64 -7.64 -17 0.04 -0.65 IOL10 808.00 909.40 0.68 161.29 161.29 909.30 909.30 -7.78 7.32 -278 7.32 -7.78 7.32 0.26 -7.92 -7.92 -120 -0.09 -19.25 101.40 909.40 1010.20 0.61 145.73 145.73 1010.10 1010.10 -8.79 7.81 -8.79 7.81 -8.79 7.81 0.19 -8.49 -8.49 -119 -0.07 -15.44 100.80 1010.20 1111.40 0.68 139.43 139.43 1111.29 1111.29 -9.69 8.50 -9.69 8.50 -9.69 8.50 0.10 -9.26 -9.26 -49 0.07 -6.23 101.20 1111.40 ]212.80 1.63 114.09 114.09 1212.67 1212.67 -10.73 10.21 -10.73 10.21 -]0.73 10.21 1.04 -11.04 -11.04 -41 0.94 -24.99 101.40 1212.80 1313.80 1.71 114.45 114.45 1313.63 1313.63 -11.94 12.90 -11.94 12.90 -1 194 12.90 0.08 -13.82 -13.82 10 0.08 0.36 101.00 1313.80 1414.80 1.41 149.79 149.79 1414.59 1414.59 -13.64 14.89 -13.64 14.89 -13.64 14.89 0.98 -15.94 -15.94 124 -0.30 34.99 101.00 1414.80 1516.00 1.40 178.75 178.75 1515.76 1515.76 -15.95 15.55 -15.95 15.55 -15.95 15.55 0.69 -16.78 -16.78 105 -0.01 28.62 101.20 1516.00 1617.70 1.94 217.68 217.68 1617.42 ]617.42 -18.56 14.52 -18.56 74.52 -18.56 14.52 1.20 -15.97 -15.97 85 0.53 38.28 101.70 1617.70 1718.00 2.75 229.89 229.89 1717.64 77]7.64 -21.45 11.64 -21.45 11.64 -21.45 11.64 0.94 -13.33 -13:33 38 0.81 12.17 100.30 ]718.00 1819.70 3.47 236.29 236.29 1819.19 1819.19 -24.73 7.22 -24.73 7.22 -24.73 7.22 0.78 -9.18 -9.18 29 0.71 6.29 101.70 1819.70 1920.40 3.71 236.46 236.46 1919.69 1919.69 -28.22 1.97 -28.22 1.97 -28.22 1.97 0.24 -4.23 -4.23 3 0.24 0.17 100.70 1920.40 2021.50 3.96 236.55 236.55 2020.56 2020.56 -31.95 -3.67 -31.95 -3.67 -31.95 -3.67 0.25 1.09 1.09 2 0.25 0.09 101.10 2021.50 2123.20 5.00 243.31 243.31 2121.95 2121.95 -35.88 -10.56 -35.88 -10.56 -35.88 -10.56 1.15 7.64 7.64 30 1.02 6.65 101.70 2123.20 2224.00 6.91 246.06 246.06 2222.20 2222.20 -40.31 -20.03 -40.31 -20.03 -40.31 -20.03 1.92 16.72 16.72 10 1.89 2.73 100.80 2224.00 2324.70 9.26 254.55 254.55 2327.90 2321.90 -44.93 -33.38 -44.93 -33.38 -44.93 -33.38 2.61 29.65 29.65 31 2.33 8.43 100.70 2324.70 2425.80 10.56 254.84 254.84 2421.49 2421.49 -49.52 -50.16 -49.52 -50.16 -49.52 -50.16 1.29 46.Ot 46.01 2 1.29 0.29 101.10 2425.80 2527.10 9.94 251.74 251.74 2521.]7 2521.17 -54.69 -67.42 -54.69 -67.42 -54.69 -67.42 0.82 62.80 62.80 -140 -0.61 -3.06 101.30 2527.10 2628.20 10.78 251.46 251.46 2620.62 2b20.62 -60.43 -84.67 -60.43 -84.67 -60.43 -84.67 0.83 79.53 79.53 -4 0.83 -0.28 101.10 2628.20 2729.20 10.48 251.98 251.98 2719.89 2719.89 -66.27 -102.36 -66.27 -102.36 -66.27 -]02.36 0.31 96.69 96.69 162 -0.30 0.51 101.00 2729.20 2830.30 8.35 250.98 250.98 2819.62 2819.62 -71.51 -118.05 -71.57 -118.05 -71.51 -1]8.05 2.11 111.91 111.91 -176 -2.11 -0.99 101.10 2830.30 2931.40 6.52 248.65 248.65 2919.87 2919.87 -75.99 -130.34 -75.99 -130.34 -75.99 -]30.34 1.83 123.79 123.79 -172 -1.81 -2.30 101.70 2931.40 3032.50 4.80 246.64 246.64 3020.47 3020.47 -79.76 -139.57 -79.76 -139.57 -79.76 -139.57 1.71 132.69 132.69 -174 -1.70 -1.99 101.10 3032.50 3133.70 4.59 245.47 245.41 3121.33 3121.33 -83.12 -147.14 -83.12 -147.14 -83.12 -147.14 0.23 139.96 139.96 -155 -0.21 -1.22 101.20 3133.70 3234.80 4.83 245.36 245.36 3222.09 3222.09 -86.58 -154.68 -86.58 -154.68 -86.58 -154.68 0.24 147.21 147.21 -2 0.24 -0.05 ]01.10 3234.80 3335.90 5.35 246.19 246.19 3322.79 3322.79 -90.26 -162.86 -90.26 -162.86 -90.26 -162.86 0.52 155.07 155.07 9 0.51 0.82 701.10 3335.90 3437.00 6.04 247.41 247.41 3423.39 3423.39 -94.21 -172.09 -94.21 -172.09 -94.21 -172.09 0.69 163.94 163.94 11 0.68 1.21 101.10 3437.00 3538.20 6.72 248.54 248.54 3523.96 3523.96 -98.42 -182.51 -98.42 -182.51 -98.42 -182.51 0.68 173.99 173.99 11 0.67 1.12 10].20 3538.20 3639.30 7.50 249.88 249.88 3624.29 3624.29 -102.85 -194.22 -102.85 -194.21 -102.85 -194.21 0.79 185.30 185.30 13 0.77 1.33 101.10 3639.30 3740.40 8.28 251.78 251.78 3724.43 3724.43 -107.40 -207.33 -107.40 -207.33 -107.40 -207.33 0.81 198.00 198.00 19 0.77 1.88 101.10 3740.40 3841.50 9.03 254.01 254.01 3824.38 3824.38 -111.86 -221.87 -111.86 -221.87 -111.86 -221.87 0.81 212.14 212.14 25 0.74 2.21 101.10 3841.50 3942.60 10.04 255.83 255.83 3924.08 3924.08 -1]6.20 -238.04 -116.20 -238.04 -116.20 -238.04 7.04 227.91 227.91 18 1.00 1.80 101.10 3942.60 4043.80 11.16 258.02 258.02 4023.55 4023.55 -120.39 -256.17 -120.39 -256.17 -120.39 -256.17 1.78 245.64 245.64 21 1.11 2.16 101.20 4043.80 4144.90 12.67 261.08 261.08 4122.47 4122.47 -124.14 -276.70 -124.14 -276.70 -124.14 -276.70 1.62 265.80 265.80 24 1.49 3.03 101.10 4144.90 4246.00 13.60 261.90 261.90 4220.92 4220.92 -127.54 -299.42 -127.54 -299.42 -127.54 -299.42 0.94 288.17 288.17 12 0.92 0.81 101.10 4246.00 • • 4347.10 14.86 263.94 263.94 4318.92 4318.92 -130.58 -324.08 -130.58 -324.08 -130.58 324.08 1.34 312.51 312.51 23 1.25 2.02 101.10 4347.10 4448.20 16.06 265.50 265.50 4416.36 4416.36 -133.05 -350.91 -133.05 -350.91 -133.05 -350.91 1.26 339.06 339.06 20 1.19 1.54 101.10 4448.20 4549.40 17.31 267.00 267.00 4513.30 4513.30 -134.93 -379.91 -134.93 -379.91 -134.93 -379.91 1.31 367.80 367.80 20 1.24 1.48 101.20 4549.40 4650.50 18.62 268.37 268.37 4609.47 4609.47 -136.18 -411.06 -136.18 -411.06 -136.18 -411.06 1.36 398.76 398.76 19 130 ].36 101.10 4650.50 4751.60 20.44 270.12 270.12 4704.75 4704.75 -136.60 -444.85 -136.60 -444.85 -136.60 -444.85 1.89 432.40 432.40 19 1.80 1.73 101.10 4751.60 4852.70 22.27 271.67 271.67 4798.90 4798.90 -136.01 -481.66 -136.01 -481.66 -136.01 -481.66 1.89 469.14 469.14 18 1.81 1.53 101.10 4852.70 4953.90 24.50 273.22 273.22 4891.79 4891.79 -134.27 -521.78 -134.27 -521.78 -134.27 -521.78 2.29 509.27 509.27 16 2.20 1.53 101.20 4953.90 5055.00 26.66 274.78 274.78 4982.97 4982.97 -131.20 -565.32 -131.20 -565.32 -131.20 -565.32 2.24 552.91 552.91 1S 2.14 1.54 101.10 5055.00 5156.10 28.60 276.56 276.56 5072.54 5072.54 -126.55 -611.97 -]26.55 -611.97 -126.55 -611.97 2.09 599.78 599.78 24 1.92 1.76 101.10 5156.10 5257.20 30.24 278.45 278.45 5160.60 5160.60 -120.04 -661.19 -120.04 -66].19 -120.04 -661.19 1.86 649.37 649.37 30 1.62 1.87 101.10 5257.20 5358.30 31.26 280.22 280.22 5247.49 5247.49 -111:64 -712.19 -111.65 -712.19 -111.65 -712.19 1.35 700.88 700.88 42 1.01 1.75 101.10 5358.30 5459.50 32.94 282.05 282.05 5333.22 5333.22 -101.24 -764.95 -101.24 -764.95 -]01.24 -764.95 1.92 754.31 754.31 31 1.66 1.81 101.20 5459.50 5560.60 35.05 283.52 283.52 5417.03 5417.03 -88.71 -820.06 -88.72 -820.06 -88.72 -820.06 2.24 810.25 810.25 22 2.09 1.45 101.10 5560.60 5661.70 36.10 286.05 286.05 5499.27 5499.27 -73.69 -876.91 -73.69 -876.91 -73.69 -876.91 1.79 868.13 868.13 56 1.04 2.50 ]01.10 5661.70 5762.80 37.46 287.56 287.56 5580.24 5580.24 -56.18 -934.85 -56.18 934.85 -56.18 -934.85 1.62 927.29 927.29 34 1.35 1.49 ]0].10 5762.80 5864.00 38.76 288.82 288.82 5659.87 5659.87 -36.67 -994.18 -36.68 -994.18 -36.68 994.18 1.50 988.00 988.00 31 1.28 1.25 101.20 5864.00 5965.10 37.96 288.95 288.95 5739.14 5739.14 -16.37 -1053.55 -16.37 -1053.55 -16.37 -1053.55 0.80 1048.81 1048.81 774 -0.79 0.13 10].10 5965.10 6066.20 35.20 288.89 288.89 5820.32 5820.32 3.17 -1110.54 3.17 -1110.54 3.17 -1110.54 2.73 1]07.18 1]07.18 -179 -2.73 -0.06 10].10 6066.20 6]67.30 32.20 289.24 289.24 5904.42 5904.42 21.48 -1163.55 21.48 -1163.55 21.48 -1163.55 2.97 1]61.50 1161.50 176 -2.97 0.35 LO7.10 6167.30 6268.40 29.64 290.51 290.51 5991.15 5991.15 39.12 -1212.41 39.12 -1212.41 39.12 -1212.41 2.61 ]211.62 1211.62 166 -2.53 1.26 101.]0 6268.40 6369.60 26.41 290.36 290.36 6080.47 6080.47 55.72 -1256.96 55.72 -1256.96 55.72 -1256.96 3.19 1257.36 1257.36 -179 -3.19 -0.15 101.20 6369.60 6470.70 23.56 290.10 290.10 6772.10 6172.10 70.49 -1297.02 70.49 -1297.02 70.49 -1297.02 2.82 1298.48 1298.48 -178 -2.82 -0.26 101.10 6470.70 6571.80 21.32 290.06 290.06 6265.54 6265.54 83.74 -1333.26 83.74 •1333.26 83.74 -1333.26 2.22 1335.67 1335.67 -180 -2.22 -0.04 101.10 6571.80 6672.90 18.50 290.31 290.31 6360.59 6360.59 95.62 -1365.57 95.61 -1365.57 95.61 -1365.57 2.79 1368.84 1368.84 178 -2.79 0.25 101.10 6672.90 6773.00 16.53 290.51 290.51 6456.04 6456.04 106.12 -1393.81 106.12 -1393.81 106.12 -1393.81 1.97 1397.83 1397.83 178 -1.97 0.20 100.10 6773.00 6874.20 14.45 290.37 290.37 6553.56 6553.56 115.56 -1419.13 115.56 -1419.13 115.56 -1419.13 2.06 1423.83 1423.83 -179 -2.06 -0.14 101.20 6874.20 6976.30 12.88 290.53 290.53 6652.77 6652.77 123.98 -1441.73 123.98 -1441.73 123.98 -1441.73 1.54 1447.03 1447.03 179 -1.54 0.16 102.10 6976.30 7077.40 11.71 290.38 290.35 6751.54 6751.54 131.51 -1461.90 131.51 -1461.90 131.51 -1461.90 1.16 1467.75 1467.75 -178 -1.16 -0.15 101.10 7077.40 7177.50 11.50 290.47 290.47 6849.60 6849.60 138.54 -1480.77 138.53 -1480.77 138.53 -1480.77 0.21 1487.12 1487.12 175 -0.21 0.09 100.10 7177.50 7278.70 10.61 292.26 292.26 6948.92 6948.92 145.59 -1498.85 145.59 1498.85 145.59 -1498.85 0.94 1505.70 1505.70 160 -0.88 1.77 101.20 7278.70 7479.90 9.72 292.71 292.71 7146.96 7146.96 159.17 -1531.66 159.17 -1531.66 159.17 -1531.66 0.44 1539.50 1539.50 175 -0.44 0.22 201.20 7479.90 7582.00 9.17 293.83 293.83 7247.68 7247.68 165.78 -1547.05 165.78 -1547.05 165.78 -1547.05 0.57 1555.38 1555.38 162 -0.54 1.10 102.10 7582.00 7683.60 8.44 291.95 291.95 7348.08 7348.08 171.84 1561.37 171.84 -1561.37 171.84 -1561.37 0.77 1570.14 1570.14 -159 -0.72 -1.85 101.60 7683.60 7785.50 7.92 293.25 293.25 7448.94 7448.94 177.41 -1574.76 177.40 -1574.76 177.40 -1574.76 0.54 1583.93 1583.93 161 -0.51 1.28 101.90 7785.50 7886.90 7.45 294.65 294.65 7549.43 7549.43 182.91 -1587.15 182.90 -1587.15 182.90 -1587.15 0.50 1596.73 1596.73 159 -0.46 1.38 101.40 7886.90 7988.00 7.18 295.43 295.43 7649.71 7649.71 188.35 -1598.81 188.35 1598.82 188.35 -1598.82 0.28 1608.79 1608.79 160 -0.27 0.77 101.10 7988.00 8089.00 6.85 299.33 299.33 7749.95 7749.95 194.01 -1609.77 194.01 -1609.77 194.01 -1609.77 0.57 1620.16 1620.16 127 -0.33 3.86 101.00 8089.00 8190.40 6.71 300.34 300.34 7850.b4 7850.64 199.97 -1620.15 199.97 1620.15 199.97 -1620.15 0.18 1630.99 1630.99 140 -0.14 1.00 101.40 8190.40 8291.80 6.32 298.23 298.23 7951.39 7951.39 205.60 1630.18 205.60 -1630.18 205.60 -1630.18 0.45 1641.44 1641.44 -149 -0.38 -2.08 101.40 8291.80 8392.00 5.86 295.69 295.69 8051.02 8051.02 210.43 -1639.65 210.42 -1639.65 210.42 -1639.65 0.53 1651.27 1651.27 -151 -0.46 -2.53 100.20 839290 8457.00 5.86 295.69 295.69 8115.68 8115.68 213.30 -1645.63 213.30 -1645.63 213.30 -1645.63 0.01 1657.46 1657.46 90 0.00 0.00 65.00 8457.00 8560.00 8.25 305.20 305.20 8217.90 8217.90 219.84 -1656.41 219.84 -1656.41 219.84 -1656.41 2.58 1668.73 1668.73 31 2.32 9.23 103.00 8560.00 8656.00 8.82 313.08 313.08 8312.84 8312.84 228.84 -1667.41 228.84 -1667.41 228.84 -1667.41 1.35 1680.43 1680.43 68 0.59 8.21 96.00 8656.00 8752.00 11.10 318.36 318.36 8407.39 8407.39 240.78 -1678.93 240.77 -1678.93 240.77 -1678.93 2.56 1692.87 1692.87 24 2.38 5.50 96.00 8752.00 8848.00 10.70 317.70 317.70 8501.65 8501.65 254.27 -1691.07 254.27 -1691.07 254.27 -1691.07 0.44 1706.06 1706.06 -163 -0.42 -0.69 96.00 8848.00 8946.00 10.87 317.95 317.95 8597.92 8597.92 267.86 -1703.38 267.86 -1703.38 267.86 -1703.38 0.18 1719.42 1719.42 16 0.17 0.26 98.00 8946.00 9039.00 10.96 317.21 317.21 8689.24 8689.24 280.86 -1715.26 280.86 -1715.26 280.86 -1715.26 0.18 1732.31 1732.31 -58 0.10 -0.80 93.00 9039.00 9135.00 10.95 317.77 317.77 8783.49 8783.49 294.31 -1727.59 294.31 -1727.59 294.31 -1727.59 0.11 1745.68 1745.68 96 -0.01 0.58 96.00 9135.00 9230.00 10.15 316.71 316.71 8876.88 8876.88 307.09 -1739.39 307.08 -1739.39 307.08 -1739.39 0.87. 1758.47 1758.47 -167 -0.84 -1.12 95.00 9230.00 9350.00 10.15 316.71 316.71 8995.01 8995.01 322.48 -1753.89 322.48 -1753.89 322.48 -1753.89 0.01 1774.17 1774.17 90 0.00 0.00 120.00 9350.00 • CONFIDENTIAL Forest Oil Co rporation i ~:.:. '~ aRE ~`~ ~ ~ ~ a ry"u r6 O - l Middle Lake Unit #1A Date: 02/09/2006 API: 50-283-20021-01 Middle Lake Unit #1A . We Fluid Analysis 11 Data '~ Contains: 1 File; 554 s Format: PDF KB ;~ CONFIDENTIAL Forest Oil Cor poration O R Fs 4 r~ Yds. ,6 ~; ©I~ Middle Lake Unit #1A Date: 02/09/2006 API: 50-283-20021-01 Middle Lake Unit #1A -Well pats Directional Su~yey Contains: 2 Files; 106 KB Format: *.xls *.txt • volume in drive D is CDZ_MLU1A volume serial Number is D8EC-076D cdl_mlula.dat • Directory of D:\ 02/03/2006 03:08 PM 1 File(s) 567,220 MLU #lA water Analysis.pdf 567,220 bytes Total Files Listed: 1 File(s) 0 Dir(s) 567,220 bytes 0 bytes free Page 1 volume in drive D is volume Serial Number Directory of D:\ 02/09/2006 09:44 AM 02/09/2006 09:38 AM 2 File • cd2_mlula.dat CD2_MLUlA is FD61-6669 9,905 FOC_MLUlA_DirSur.txt 97,280 FOC_MLUlA_Dirsur.xls (s) 107,185 bytes Total Files Listed: 2 File(s) 107,185 bytes 0 Dir(s) 0 bytes free Page 1 cd3_mlula.dat volume in drive D is CD3_MLU1A Volume Serial Number is C4ED-E724 Directory of D:\ 02/09/2006 10:17 AM <DIR> LOGS_Digital 0 File(s) 0 bytes Directory of D:\LOGS_Digital 02/09/2006 10:17 AM <DIR> 02/09/2006 08:25 PM <DIR> .. 02/09/2006 10:17 AM <DIR> Cased hole 02/09/2006 10:17 AM <DIR> MDT~SCII 02/09/2006 10:17 AM <DIR> o en_hole 0 File(s) 0 bytes Directory of D:\LOGS_Digital\Cased_hole 02/09/2006 10:17 AM <DIR> 02/09/2006 10:17 AM <DIR> .. 12/29/2005 01:16 PM 586,583 SONIC_089PUP_9-625_casing.las 12/29/2005 01:16 PM 309,410 SONIC_099PUP_5-5_liner.las 2 File(s) 895,993 bytes Directory of D:\LOGS_Digital\MDT~45CII 02/09/2006 02/09/2006 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 12/26/2005 10:17 AM <DIR> 10:17 AM <DIR> 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 05:12 AM 16 File(s) 30,598 MDT_059LTP.laS 25,918 MDT_060LTP.las 31,408 MDT_061LTP.las 267,478 MDT_062LTP.las 29,788 MDT_063LTP.las 32,848 MDT_064LTP.las 23,038 MDT_065LTP.las 29,968 MDT_066LTP.las 76,138 MDT_069LTP.las 91,798 MDT_070LTP.las 46,618 MDT_071LTP.las 24,388 MDT_072LTP.las 32,038 MDT_073LTP.las 41,128 MDT_074LTP.las 51,388 MDT_075LTP.laS 73,618 MDT_076LTP.las 908,158 bytes Directory of D:\LOGS_Digital\Open_hole 02/09/2006 10:17 AM <DIR> 02/09/2006 10:17 AM <DIR> .. 12/29/2005 06:35 AM 849,932 AIT_TLD_MCFL_CNL_040PUP_Main_Updated.las 12/29/2005 06:35 AM 359,540 AIT_TLD_MCFL_CNL_041PUP_Repeat_Updated.las 2 File(s) 1,209,472 bytes Total Files Listed: 20 File(s) 3,013,623 bytes 12 Dir(s) 0 bytes free Page 1 volume in drive D is CD4_MLUlA volume Serial Number is E676-9F51 Directory of D:\ 02/09/2006 10:15 AM <DIR> 0 File(s) Directory of D:\LOGS_PDS 02/09/2006 02/09/2006 01/06/2006 12/29/2005 12/26/2005 12/25/2005 12/25/2005 12/25/2005 12/25/2005 10:15 AM <DIR> 10:15 AM <DIR> 09:59 PM 01:14 PM 04:41 AM 08:18 PM 08:11 PM 08:17 PM 08:12 PM 7 File(s) Total Files Listed: 7 File(s) 3 Dir(s) cd4_mlula.dat LOGS_PDS 0 bytes 83,771 FOC_MLU#lA_TCP Correlation 6Jan06.PDS 6,700,580 FoC_ML-1_cBL_29-Dec-05.PD5 4,902,178 Foc_ML-1_MDT_25-Dec-05.PD5 366,352 FOC_ML-1_NGT-2_25-Dec-05.PD5 636,332 FoC_ML-1_PEX-5_25-Dec-05.PDs 545,837 FOC_ML-1_PEX-2_25-Dec-05.PD5 397,228 FOC_ML-1_NGT-5_25-D2C-05.PD5 13,632,278 bytes 13,632,278 bytes 0 bytes free Page 1 Modular Dynamic Tester, Pressure Tests m MDT-GR 25-26 December 2005 c y = a i.at: 61.378 deg N, Long: 150.158 deg W Elev.: KB. 122.7 ft x ~ s U IZ 1923 FNL & 1142 FWL at surface G.L. 108 R ~ m ~ 0 iF? I D F ' °-' ~ °-' N v `O ~° ~ U Permanent Datum: __MSL.._. _______ Elev. Oft ~ :: -o .t `z -~`' ~ LL -' Log Measured From: RKB._,.. __ _ _.. 122.7 ft above Perm. Datum c c Drilling Measured From RKB m o ~ --~ -_--- - -- °- ° `~ - o I API Serial No. Section Township RangA ii ~ ?i U 50-283-20021-01 22 15N~ 5W Logging Date ___- _ 5-Dec G005 Run Number 1 Depth Driller y35U ft Schfumberger Depth 9351 R ___ Bottom Log Interval 9292 ft Top Log Interval 8835 ft (asmg Drtllcr S+ze <u) Depth 9.625 in Lt 8456 ft @ Casing Schlumderger _ 8461 ft BRSize 6 750 in - -- - -- Type Fluid In Hole KLAGARD MUD _- - --~ ~ ~ -~~~- --~- i I Density Viscosity t4 916m/gal ~- _....- _~ '-.._ _ . ~ Flwd oss ~ PH 5 2 cm3 i_70 1 _ I __ _. __ - - .._ _.. _ _..._ Source Of Sample Flow Line RM Ca? Measured Temperature -- 0 363 ohm m __ C i 54 degF _ (a7 _ -__ RMF (d Measured Tem rature_ 0 202 onm m _t7r., _ 54 degF _ (6? _ - RMC (a~ Measured Temperature 0 753 ohm m Ca? 55-degF _ _^_ (g1 _ _ Source RMF RMC Fbw Line Flow Line _ T _ __ RM Cc? MRT I RMF <il MRT 0 143 L 748 0.079 Q 148 _ - ~__ Ca? Maximum Recorded Temperatures 148 degF _ ____ _~ _ .- _ ~ _. I- .-___ Grculation Stopped Time ~ 24 Dec 2005 17.0_0 Logger On Bottom ~ Time 25-Dec 2005 _ 23 30 -, _ -- - --r- -- - ---- Unit Number Location 1805 Kenai, AK Recorded B~ __ C. Tannehill -- ~ Spectral GR ~ ~; NGT-DSLT-PEX, 2" :100' ° Q 25 December 2005 ~ m Z m ~ a Lat: 61.378 deg N, Long: 150.156 deg W Elev.: KB. 122.7 ft - i s ~ s L I6 1923 FNL & 1142 FWL at surface G.L. 108 ft ~ `~ p IU D.F. v d ~ N z m v y ~U ~ ~ Elev.: _ 0 ft _ _ Permanent Datum: MSI_ _ ~ ~ ~ ~ ri _ Log Measured From: RKr3, _____ _ 122.7 ft above Perm. Datum I Drilling Measured From: RYB ______ _ _ _ _ "o ~ ~ E API Serial No. Section Township Range m m ILL J 's Cg 50-283-20021-0? 22 15N 5\N i _ Log~ng_Gate __, _ ______.__. 25-De_c-2005 __ _ _ _ - Run Number ---- _._._ _ 1 _.. - -- -- -._. - -. _ Depth Driller 9350 ft _ ___. _ . _ Sfhlumberger Gepth __ - 935f ft - _ ! _ -- _ Bottom Log Inten_al _ - 9350 ft _ - - erva _ n Top Log Casmg Dnller Saze C4~ Depth ~ _ _ _ 9625 in @ 8456 ft _ __ _ -~ `- - _(c) - _ _ CasmgSchlumbe~er_ -- , _~ - - 8461ft _ ~~ _ ~_ ~- -- - ~ - -- ~ - - ert Size H l 6 750 in_ KLAGARD MJD , 1., Type Fluid In o e { Viscosity ~TDensdy 1491bm/gal - -_ PH ~IFIwd Loss J L1D1 s~cm3 S467ft l l t __ 1 _ __, _ _ . _III~-So~rce_Of Sample _ _ -~~ Flow I me .. _ __ _ -_. - _ PM ~a7 Measured Temperature RMF Cc? Measured Temperature _ -- 0 363 ohm m ~a_)_ _ 54 deg 0.202 ohm m__ (d _ 54 d~ _ - - - P.MC (~ Measured TemQerature__ _ 0 753 oh_m m Cr??,~ 55 deb F i RMC_ Source RM FIowLme --Flow Line _ _ RMOMRT L RMF (c?MRT 0126 C4~ 16510071 ta? 16! _ Maximum Recorded Temperatures- -T T 165 degF_ TT" _ 00 17 2 ime CircuWtion Stopped : 4Dec-2005 Logger On Bottom L Time 25 Dec-2005 _rt 117:15 __ _~_Locatton Unit Number 180~__K_enai AK _ ___ -. _ Recorded __ _ C.T_annehdl _______ - Witnessed 8 L. Casarta -^ ~ __.~ J- I _ _ ~-~ :.. ---'- -- i i • ~ • • • • ~ • • • • - - Spectral GR ~, NGT-DSLT-PEX, 5" :100' J a Q 25 December 2005 z ~ `° ~ j a Lat: 61.378 dey N, Long: 150.158 deg W Elev.: KB. 122.7 ft s m ?? Cg Z 1923 FNL & 1142 FWL at surface G.L. 108 ft `~ ~ ~ p C D.F. v w m m - -. .- o a U ~ -o ~ ~ ~ Permanent Datum: MSL___ _ _ Elev.: _0_it,_______,__,.. C ~ -~ ~ °- ~ Log Measured From: _ RI® ____-_ 122.7 ft above Pemi. Datum c c ~ o m Drilling Measured From: _RKB -_ _________ E API Serial No. Section Township Range u ~ $ Cg 50-283-20021-01 22 15N 5W _Loggin-gDate_______- 25-Dec-2005_______- - -~------------ Run Number 1 DepthOriller 935oft _ _ _ __ _ _~ _ -__ Schlumberger Depth __ _ 9351 ft ___ __ __ _ __ __ _ ___ Bottom Log Interval 9350 ft _-___-- ___-__-_______ ___ Top Log Interval _ __ 8461 ft __-____. __ Casing Driller Size @ Depth 9.625 in @ 8456 ft C4? Cash Schlumberger-_-_. 8461 ft ~ -~~--- _ -- ~. ~ ------- -~-~ BR Size 6.750 in __ T e Fluid In Hole KLAGARD MUD _ - --- _ _ - ~o ii Densely ~ ~ VSCOSity _-T --- 1a 9 Ibm/gal __ T _ g Flwd Loss -L PH_.._ _. -- -- - _ ti 2 cm3..__ _ 1G ~1_ . __. _ __ __ _.._.f '__---- 1SourcedtSample FlowLme _ __ RM @ Measured Temperature 0363 ohm m C~~ 54 degF @ _ RMF Cn? Measured Temperature 0 202 ohm _m _ ~n~ _5a de~F _ _ @ _ _RMC @ Measured Temperature _ 0 753 ohm_m r? 55 d F ___ _ _ ~(q~ __ _ _ _ _ __ _ Source RMF RMC _ RMM C? MRT RMF C MRT _ _Flow Lme _ +Fbw Lme_ 0 128 ~a~ 160 071 (~ 165 - _ _ __ @ @____ - Maximum Recorded T_e_mperatures Circulation Sopped -Time T 165 degF - J _ 24-Dec-2005 _77:00 T _ , _ _ _ - _- _ _ _ ~ i Logger On Bottom , Time 17:15 25-Dec-2005 _ _ Unft Number ~ Location_,__ _ _ t805~_F~nai,_AK_~_~~_- _ ___ -~-.-__ _ ~-_ _ ___ Recorded BY _ ~- ----- C. Tannehill _ _-_ - -___.__ __, _ W@nessed B L Casarta k i ~ _ • >• • • • • _ { • • - " • • - - i o Platform Express -Sonic -Spectral GR m NGT-DSLT-PEX, 2" :100' z ~ ~ 25 December 2005 _ w j ~.' Lat: 61 a78 deg N, Long: 150.158 deg W Elev.: KB. 122.7 ft _ s m Y ~ Z 7923 FNL & 1142 F WL at surface G.L. 708 ft otii ~ p ~ D.F. - m m d (( ' ~~ PermanerrtDatum: MSL __ ___ Elev.: Oft ___ ~ ~ ~ LL O Log Measured From: .. RKB _ 1227 ft above Perm. Datum o ~ Drilling Measured From: _RKB -____ - ~ :a ~ _ E API Serial No. Section Township Range ~ ~ ~ (g 50-283-20021-07 22 75N 5W Leo .grog Date ----- -Dec 20D5 -_-- - -- - -, Run Numfier 1 -_,_~ ___ Depth Driller __ 9350ft-- ----_-~ Schlumberger Depth _ 9351 ft -_ - , Bottom Log lrrterval ^.__-__ 9350ft -------..___---- ----- Top Log Interval 8467 k -- - Casing Driller Size C~ Depth __ 9.625 in__ _@-- 8458ft _ . _. @-_-_ ___ Casin Schlumberger 8461 ft ____ art size 6.750 in -- -,-,--- _ ____ "ype FIuId In Hole KdAGARO MUD - ~Density Viscosity 14.91bm/gal i ~ -_I ~ _ I Fluid Loss _ __ r 10_~ - 5.2 cm3 ..-- ----- ` _ Source Of Sample _ Fbw IJne _ ___ - _ __ _ - : RM @ Measured Temperature ___ ___ sad F 0.363 ohm.m (n? @ _ RMF @ Measured Tem rature 0.202 ohm.m @ _ 54 d F _ @ ____ RMC @ Measured Temperature 0.753 ohm.m @ 55 F - @ __ ' Source RMF RMC F w Line Fbw Line _ MRT RMF @MRT RM @ _ 0.128 @ 185 0.07.7 _ @ 165 _ @ _ @ _ Maximum Recorded Tem atures 165 ~ -_ Qrculatfon Slopped Time 2A-Dec-2005 77:00 _-_- Time Logger On Bottom _ 25-Dec-2005 - 17:15 _ _ Unit Number _ ~ Location 1805 Kenai, AK Recorded ~ __- C. Tannehill ___ __.._ Witnessed B L Casarta • • F ~ ~ ~ ~ _ __ ... - y .. - .. - - i , o Platform Express -Sonic -Spectral GR m NGT-DSLT-PEX, 5° :100' a Q 25 December 2005 Z '~ ~ m j a t-at: 61.378 deg N, Long: 150.158 deg W Elev.: KB. 122.7 k - O x m x C7 Z 1923 FNL&1142 FWL at surface G.L. 108ft ~ ~ ~ p o D.F. F - v ~ ~ ~ U _ _ Elev.: Oft PennanentDatum: MSL ~ ~ ii ~ _ Log Measured From: _RKB, ___ ___ 122.7 ft above Perm. Datum Drilling Measured From: RKB _ __ - ' -o ~ - E API Serial No. Section Township Range LL x 3 (g 50-283-20021-01 22 15N 5W ~ Logging Date _ 25-Dec-2005 -- -.- _ -- Run Number ~ 1 ------------ - - - - Depth Driller -- - 9350 ft --- ------- '. - ------_-- ~SchlumbergerDepth -.___ 9351tt _ _`_ Bottom Log interval 8350 ft _ _- ,-. - ;~~Top Log interval _ 8461 ft ._-- iCasing Driller Size Q Depth -- @ 8458 ft 9.625 in @ _. ?Casing Schlumber er _ 8461 ft -- - -- --- ~ _ BR S¢e 6.750 in _ _ _ _ _ _¢ Type Fluid In Hole KLAGARD MUD -_ __-_ _ _. ~~. -~rscosity Density 14.9 Ibm/gal ~_- - G - FWid Loss I PH -_ 5.2 cm3 - 170.1 ,-- ~ --.__-- - --_-- -. ~'. Source Of Sample - Fbw Une -- RM @ Measwed Temperature 0_363 ohm.m @ _54 d F _ _ @ _- -_____ ~ x RMF @ Measured Temperature _ 0.202 ohm.m @ 54 F _ @ RMC @ Measu red Temperature 0.753 ohm.m @ 55 d F @ --- -. Source RMF RMC Flow Line Fbw Line -~ - , ;~ RM @ MRT _ RMF @ MR7 0.128 @ 165 0.071 @ 185 @ -Q-_- Maximum Recorded Temperatures 165degF __ _ l _ .y- ~- Circulation Stopped Time 24-Dec-2005 _- ,7:00 t --_ Logger On BotOom Time 25-Dec-2005 _ 7:15 _ Unit Number- Location _ - 1805 Kenai, AK -~ __-- ~L_-..__..__-- i Recorded B~, C. Tannehill -~-- --- ~ Witnessed By _ L. Casarta ~ Schlumberger ak: +L~; _ ~ Forest OiE Corporation ti. ~~.'. „- ~~4iddie Lake Unit #1A (," - -_ ivliddie Lake ~• + S:a.e. Alaska ': _~ „ _ - MaG-Su :. . .. ~: ~- -11~- _11 Z ~ w o ~ S Lat: 81.378 deg N, Long: 150.158 deg W Elev.: KB. 1227ft '~' s m Y cg 1923 FNL&1142 FWL atsurtace G.L. 108ft z ~ m ~ p O D.F. m m ~ ~ ~ m ~ m U Permanent Datum: MSL rev.: Oft g ~ ~ ~ LL ~ ~g ~ From: RKB 1227 ft above Penn. Datum r ~ ~' i Ddling Measured From: RKB - n a o v ~ >s o API Serial No. Section Township Range '~: _ ~ LL x ~ Cg 50-283-20021-01 22 15N 5W in Date 2g'~-~5 Run Number 1 Depth Dr11er 9253ft "~ Schlum DePfh 82548 ~ Bottom Log Interval ~'~ ft , ~~~. Top Log Interval ~~ ft Casing Fluid Type KLAGARD MUD ah<~.. Satin ~~ w Des 14.91bm1 I "' ~ Fluid Level 10ft _ BIT/CJ6SING(rUBING STRING ~,~• 3 ~ Bit Size 8.750 in ~ ~~ From 'SCR ~ To 93'50 ft ~ Casin uhin Sine 5.500 in Wei M ZOlbm/ft . Grade - f a From 778D ft To ~`~ft - ` Maximum Recorded Temperatures 150 degF ger On Bottom Tane 29-Dec-2005 9:45 Unit Number Location 1805 Kenai, AK ~~ Recorded B C. Tannehill ~`3 Witnessed BY _ J. Bou ue • • m ro N ~ ~ ~ O ~ ' c~ o E `m a m J LL ~ m p 1' C7 0 o N a ~ C ~ m W m W n ~ F ~ O_ ~ N N ~' m r a m Z w m m ~ ~ e ~ ~ ¢ ~ , Z a k ~ O J E E ~ ZO g ~ w x ~ z N ~ N ~ O _ U ._Eo V ~ N K m .x c O E ~ ~ N O Z ~ ~ N Z E o & T Z r~ ~= n `~ m o x n '~ '~i m o ~ ~ '7 W ~ y rn n ~ a m ~$ m O rn m m Z ~ o ~ m ai N o m m ~ w a ~_ m N N a ~ ~ d N /n N a m ~ Z ~ m ~ 4411 m C m p~ N U m ~ m ' E` N LL `° N N t6 ~ C m E ~ c Q O ~(/ Z ¢ i` m F _ C O ~ ~~g aso F- n ~ m s NOIl tlOOI R m m H m ~ E i0'J 1101S 3liOj :Fue dwo0 m ~ Z ~ c g m ~ I(13N'd131 001W :IIaM f0 O a °_' a ~ c 3 Z a ¢ E m a m m m -NSIl ~Z o :uo Z' aS ! leool c_ E o D E E a, o LL ... m .~ ¢ U $ ~ o O ~ E o m g a"i 3Ntll 3l oOIW ~PIe1j c " .-mac ao a p w .c ~ :o ti m m E ~ L v E x p c ~ c J Q ~ U) m { - U tll O tL m {L F U > > C3 IL F ~ J ~ Q ®ui ~~ aar~a7 C®ZiTS~IEa~A7'I®I~T C®1-II~'IIS~I~1~T Ted Kramer Alaska Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Exploratory, Middle Lake # 1 Sundry Number: 306-019 Dear Mr. Kramer: CJ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAx (907) 276-7542 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not. appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisday of January, 2006 Encl. ~~ January 12, 2006 / 1 F O R E S T 0[ L C O R P O R A T I O N .~~0 ~~~CS~t ~.e1` • C~~ rcr,~~ 700 n~a~~-rrir ~e, C~9~//a<~~ 9950 (~07) 258-8600 • ~90~) 258-860 (~~r~/~d Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7`h Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Middle Lake Unit #1-A (PTD No. 205-149) Dear Mr. Norman, Alaska Oii & Gas ~= . Anchora~a ~~~`-r~rission Forest Oil Corporation hereby applies for approval of its plan for a Suspension of Operation on the recently drilled MLU #1-A well. The target interval produced only water with no measurable quantities of hydrocarbons. Please find the attached information in support of this application: 1) Form 10-403 Application for Sundry Approval 2) A proposed Suspension of Operation Plan 3) A current wellbore schematic 4) A proposed wellbore schematic If you have any questions or require additional information, please contact me at 868-2137 or Roy Smith at 936-443-7089. Sincerely, s~ Ted Kramer Alaska Production Manager enclosures JAN Y ~ ;r; cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ~cc,t~VED STATE OF ALASKA ~~ ALA~G4 OIL AND GAS CONSERVATION COM ON ~ 1,~ SAN Y 2 2pps APPLICATION FOR SUNDRY APPROVALS /~ Aiaska Oi! & Gas Cons. ConxnissFo 20 AAC 25.280 ~~ ~/k~~ ~„_L__ 1. Type of Request: Abandon Suspend ~ Operational shutdown Perforate Waiver r Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: / V Forest Oil Corporation Development ^ Exploratory ^~ 205-149 3. Address: Stratigraphic ^ Service ^ 6. API Number: 310 K Street, Suite 700, Anchorage, Alaska 99501 50-283-20021-01 7. KB Elevation (ft): 9. Well Name and Number: 18.3' AGL Middle Lake Unit #1A 8. Property Designation: 10. Field/Pools(s): Mental Health Trust No.s 9300049 and 9300050 Exploratory 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,350' 9,001' 9,350' 9,001' None None Casing Length Size MD TVD Burst Collapse Structural 27' 30" 27' 27' N/A N/A Conductor 281' 20" 281' 281' 1,530 520 Surface 2,958' 13-318" 2,958' 2,953' 3,090 1,540 Intermediate 8,457' 9-5/8" 8,457' 8,457' 6,870 4,750 Production 9,338' 5-1/2" 9,338' 9,338' 9,190 8,830 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,910' - 9,050' 8,910' - 9,050' 2-7/8" P-110 8,858' Packers and SSSV Type: Pkr: Weatherford 5-1/2" ArrowPak @ 8,768' Packers and SSSV MD (ft): Pkr: Weatherford 5-112" ArrowPak 8,768' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory^ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/12/2008 Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date: NIA DSPL ^ W WAG ^ GINJ ^ WINJ Commission Representative: N/A ryy. / ~ S~ ~ ~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3448 Printed Name Ted Kramer Title Alaska Production Manager Signature ~ Phone 868-2137 Date 1/12/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity "~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance '~ Other. 5~~ P~«~ c~ ~C 'CVO ~5~~~~~ Q~S DMS ~F~,. ,~~N ~ ~~ 20DD Subsequent F e 'r APPROVED BY : COMMISSIONER THE COMMISSION Date: ~~ i~~ A d b p ove y Form 10-403 Revised 07/2005 ORIGINAL Submit in Duplicate ~'"'_I i • FOREST OIL CORPORATION Suspension of Operation Procedure -MIDDLE LAKE UNIT # 1A '~ 1 /12/06 I. SUSPENSION OF OPERATIONS PROCEDURE General Information: Casing: 13 318" 61# K-55 Butts @ 2,958' 9 518" 47# L-80 LTC @ 8,500' Sidetrack Point of Whipstock 51/2" 20# L-80 Hydril 521 @ 9,338' with TOL @ 7,783' MD 5121" 17# L-80 Buttress Modified Tieback @ 7,783' MD Tubing: 2 718" 6.5 # P-110 RTS-8 Existing Perforations: 8,910' - 9,004' MD (8,563' - 8,655' TVD) 9,008' - 9,020' MD (8,659' - 8,671' TVD) 9,030' - 9,050' MD (8,680' - 8,700' TVD) Objective: Suspension of Operations 1. Rig-up lines and displace tubing to perforations with 10.4 ppg Kcl/Cacl completion fluid. 2. Attempted to establish sufficient injection rate to squeeze perforations, '/z BPM @ 5,000 psi. AOGCC approved setting PX Plug in nipple at 8,787' 3. Rig up wireline and set PX plug in XN nipple at 8,787'.Pressure test to 5,000 psi for 30 minutes and bleed pressure to 0 psi. 4. Set BPV, nipple down tree, nipple up BOPs and test 250 psi low and 5,000 psi high. Note: After testing BOP.s rig up on 13 3/8" x 9 5/8" annulus and attempt to establish injection rate down annulus following that has been approved by AOGCC and have AOGCC representative on location while attempting to inject into annulus. 5. Screw into tubing hanger and work seals out of packer. Displace wellbore with 14.9 ppg water base POOH UD downhole equipment. ~ ~.S ~~~~~~ `~~.~~, ~~~ 6. Make up 5 %2' CIBP, TIH to 8,760' and set same. Mix and spot a 200' -cement plug on top of CIBP fro 8,760 to 8,560'. Pull above cement top and reverse out. Test cement plug to 5,000 psi for 30 minutes.o ~~ 7. POOH laying down 2 7/8" tubing leaving 3100' of tubing in derrick. ~-~ j h~ SS~~~~pE~ r~J1sYS`~ 8. Make up and run 5'/" CIBP and set same 100' below base of 13 3/8" casing shoe at 3,058. Mix and spot a 200' cement plug on top of CIBP. POOH UD 2 7/8" tubing to 210'. 9. Mix and spot a cement plug from 210' to 10' below original ground level. 10. Pull to 10' below original ground level and displace out with water 11. Nipple down BOP's and nipple up dry hole tree and test. 12. Rigging down Nabors 129 for demobilization back to Kenai. ~~~ ~~ ~~ Page 1 of 1 01/12/06 FOREST OIL CORPORATION MIDDLE LAKE # 1A CURRENT COMPLETION ELEVATION: 14' KB Date: 1/9/06 Prepared: Roy Smith I I 30" .63" Wall Thickness Drive Pipe Set 20" 94# H-40 @+/- 281' Set Already ~ ~ Methanol Injection Mandrel @ I I 2,979' w/ 1/4" Control Line Set Already ~ I 13 3/8" 61# K-55 @ +/- 2,958' MD/TVD I M l:: w{, ':~ .~~ TOC of 5 1/2"Tieback 7,300' l .,} I ~~ . 5 1/2" 17# L-80 Buttress Modified Couplings T/B ;1 `'. ;;<;;~ ~>< Top of 51/2" Liner @ 7,783' MD/TVD 9 518" 47# N-80 Whipstock Window Top @ 8,457' MD/TVD 10.4 ppg KCL/CaCI Completion Fluid 2 7/8" 6.5# P-110 RTS-8 Tubing wx 2 7/8" "X" Nipple with 4'pups above and below set 1 joint above packer 5112" 20#/ft ArrowPak Retrievable packer with TCP gunsSet @ 8,768' 2 718" "WXN" Nipple w/4' pups above and 6' below Perforations 8,910-9,004', 9008-9,020' 8~ 9,030-9,050 MD 9,254' PBTD 51/2" 20#/ft L-80 Hydril 521 @ +/- 9,338' ST OIL CORPORATION MIDDLE LAKE # 1A SUSPENSION OF OPERATION SCHEMATIC Date: 1 /12/06 PAD LEVEL Prepared: Rov Smith 1PAD +/_ 3' ABOVE ORIGINAL GROUND LEVEL _ _ _ _ ~ DRY HOLE TREE ~ ORIGINAL GROUND LEVEL _ 30" .63" Wall Thickness Drive Pipe CEM~N'1::20~`::: . .......................... 20" 94# H-40 @+/- 281' 13 3/8" 61# K-55 @ +/- 2,958' MD/TVD 5 1/2" CIBP set @ 3,058' w/ 200' cmt on top TOC of 5 1/2"Tieback 7,300' 5 1/2" 17# L-80 Buttress Modified Couplings T/B Top of 5 1/2" Liner @ 7,783' MD/TVD 9 5/8" 47# N-80 Whipstock Window Top @ 8,457' MD/TVD 14.9 ppg Water Base Mud CEMENT::: 200' :::: i-200' of cement on top of CIBP -5 1/2" CIBP set on top of packer S 1/2" 20#/ft ArrowPak Retrievable packer with TCP gunsSet @ 8,768' 2 7/8" "WXN" Nipple w/4' pups above and 6' below PX Plug set in XN Nipple, Tst'd to 5,000 psi Perforations 8,910-9,004', 9008-9,020' & 9,030-9,050 MD ' PBTD 5 1 /2" 20#/ft L-80 Hvd ri 1521 Cad +/- Middle Lake # lA • • Subject: Middle Lake ~ 1,~ From: Rov_ Smith _ RLSmith(cr~forestoiLcom> Date: Fri, I ~ J~tn ?OU(i l x:19:1 ~ -000U 'to: Bob Cldcr ~~=RGL Ider~uforestoiLcom==, Ted Kramer ~ _TEKramer«i,forestoiLcom: ~. 'Bill Penr~ose~ hill;~r?lair~~eather.com--., "Tom 19aunder(tom_ iT~aunderrti?admin.state.ak.us)~~ ~'-tom maunderr""u~ac(~»in.state.ak.~as= CC: Cecil Col~wcll ~ ('t~('ol~well~u`fii,r~stoil.eom=--, Leonard Gurule ~~-LCGurulc(u~~forestoil.i;om> Gentlemen Attempts were made to establish injection into the 13 3/8" x 9 5/8" annulus without success. The pressure was gradually applied in .5 bpm increments up to a maximum of 1500 psi with no bleed off. This pressure equates to a 18.6 ppg at the 13 3/8" shoe, assuming 9.0 ppg fluid in the annulus. Therefore the drill fluid still remaining on location will have to be dewatered and hauled off. The attempts to inject into the annulus was witnessed by an AOGCC Representative on location. Roy Smith Office 303-864-6159 Cellular 936-443-7089 1 of 1 1/13/2006 11:27 AM • 'i~ ~ ~~ A~T~v /~~~T n®A~7i~~ ~~y-~~lT Ca-1~51~~t~A7[`I®ld ~L~A1rAl1~EJl~~~lJ~li6 Mr. Ted Kramer Production Manager Forest Oil Corporation 340 K Street Suite 700 Anchorage, AK 99504 Re: Request for Annular Disposal Middle Lake Unit # 1A-205-149 Sundry Number: 305-311 Dear Mr. Kramer: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX {907) 276-7542 Enclosed is your application for annular disposal into Middle Lake Unit # 1A. We are returning this application unapproved. This application is no longer needed since Forest Oil has advised the Commission by elec- tronic mail that it was not possible to pump into the 13-3 / 8" x 9-5/ 8" annulus. DATED this day of January, 2006 Encl. `~~ ,iqN ~ ~ ?pp- b • • , October 11, 2005 • F O R E S T O I L C O R P O R A T I O N .~~0 n~~C~~r~.~! ~ C-~;rr,'te X00 ~?~rzc•~uz.1~a fe, C?~~~:l~r~z 99507 ~90~~ ?5~S'-4600 • (GO%~ ?.~4- 4607 ~~~~~x~ Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Annular Disposal Permit: Forest Oil Corporation Middle Lake Unit #1-A Dear Mr. Norman, ~G~~~~ oc~ ~ ~~a t,~,.. Alask~'_::° __ . ., ~ _ ~...:tt13S1099 Forest Oil Corporation hereby applies for an Annular Disposal Permit to inject used drilling mud and ground cuttings into the Middle Lake Unit # 1-A (MLU # 1-A) re-entry during and after drilling operations. Injection is expected to commence in the first week of November 2005 and last less than 30 days. The MLU #1 was drilled and abandoned by Gulf Oil Corporation in 1969 as anon-productive oil exploration well. Forest Oil believes there may be potential for gas production from one or more zones originally penetrated by the well and has applied under separate cover for a Permit to Drill to allow re-entering the well and sidetracking it to the formations of interest. Forest Oil proposes to dispose of the drilling fluid left in the well by Gulf, any additional working mud volume and ground up rock cuttings generated by Forest Oil down the existing 9-5/8" X 13-3/8" casing annulus. Attached find a Form 10-403RD Annular Disposal Application, casing cementing information for the 13-3/8" surface casing, a proposed wellbore schematic and a formation water salinity analysis for the receiving zone. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, ~~ -~ Ted Kramer Production Manager enclosures cc: Bill Penrose -Fairweather STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~ON ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 ~i V Alaska Oi! ~ Gas Gans. Gar mission 1. Operator Name: Forest Oil Corporation 3. Permit to Drill No: To be assigned ~ 4. API Number: To be assigned 2. Address: 310 K Street, Suite 700 5. Well Name: Middle La it #1-A Anchorage, Alaska 99501 6. Field: Wi cat 7. Publicly recorded wells 8. Stratigraphic descr' ion: a) Interval expo d to Tyonek and Pre-Tyonek sands, shales and a) All wells within one- open annulus• coals quarter mile: None b) Was receiving Tyonek sands zone• b) water wells within one mile: None Confineme Shales within and overlying Tyonek sands 9. Depth to base of 10. Hydr arbon zones permafrost: N/A ~ above aste receiving O zon None d e: 12. Esti urry ity: 11. Previous volume disposed in annulus a~d 13. Maximum anticipated pressure at shoe: n No previous disposal in wel "„/ 10.0 -12.4 ppg (avg. 12.0 ppg) ~ 2,200 psi ~ 14. Estimated volume to be disposed h this re 15. Fluids to be disposed: Approximately 2,2 s Drilling mud, ground cuttings and minor amounts of arctic grade diesel used for freeze protection of the annulus receiving the injection. 16. Estimated start date: First week of No tuber, 2005 17. Attachments: Well Schematic (Inclu a MD and TVD) ^~ Cement Bond Log (if required) ^ FIT Records w/ LOT Graph ^ Surf. Casing Ceme ting Data ~ Other ^ 18. I hereby certify that the f egoing is true and correct to the best of my knowledge. Signature: Title: Alaska Production Manager Printed Phone Name: Ted Kramer Number: 907-868-2137 Date: ~ ~~ ~' Commission Use Onl Conditions of approval: LOT review and `~_` 1 _ ' `f ~ ~ ~~ c RCii~J ~1N4 approval: `.1 v~ t ~ ~ ,~~~~ Subsequent form Approval i re ed ~ ~} ~ -"' ~, b qu r : num er: Approved BY ORDER OF THE by: COMMISSIONER COMMISSION Date: Form 10-403RD Rev.9/2003 ~ ~~., , a t, { INSTRUCTIONS ON REVERSE ,iA~ ~ ~ 200 Submit in Duplicate • • MIDDLE LAKE UNIT #1-A DISPOSAL OF DRILLING WASTE The following information is provided in support of Forest Oil's request for authorization for disposal of waste drilling mud through injection down the 9-5/8" x 13-3/8" annulus in the Middle Lake Unit #1-A well in accordance with AOGCC Regulations in Title 20, Chapter 25, 20 AAC 25.080. 1) Well to receive drilling waste: Middle Lake Unit #1-A (9-5/8" x 13-3/8" annulus. The 13-3/8" casing is set at a depth of 2,958' RKB.) 2) Depth to base of potable freshwater aquifers: The only nearby well that is capable of producing potable fresh water from an aquifer was drilled to a depth of 201'. It is not known how far or if the potable fresh water aquifer extends below this depth. Permafrost does not exist at this location. 3) The interval exposed below the shoe of the 13-3/8" casing will be the top portion of the Tyonek Formation. The top of the 9-5/8" cement is within the mid-to lower Tyonek. The receiving zone will be the upper Tyonek sands. Injection into this interval will be bounded at the top and bottom by shales within and overlying the Tyonek sands. 4) There are no publicly recorded wells within one-quarter-mile of this location. The only publicly recorded water well within 1 mile of this location is a water well that exists on the drilling location, drilled in 1969 by Gulf to provide water for drilling operations. Forest Oil plans to use this or a replacement water well for its operations. 5) The waste to be injected will be used drilling fluid and ground rock cuttings. There may also be a small amount of diesel oil injected that is used as a freeze protect fluid in the annulus receiving the injection. The estimated volume and maximum density is 2,200 barrels and 1.2.4 ppg. This volume is twice the calculated hole volume at TD plus 500 bbls of active mud system in the surface mud system. The excess hole volume calculated reflects the possibility that the mud left previously in the well cannot be incorporated into the active mud system to be used. Also, the drilling fluid density, which could reach as high as 14.0 ppg while drilling, will have to be watered back to 12.0 ppg for injection, increasing its volume. The average slurry density is anticipated to be approximately 12.0 ppg. The maximum volume to be injected under any anticipated circumstances will not exceed 35,000 bbls. 6) Drilling wastes to be injected will be the drilling fluids used for drilling the well and associated rheologic modifiers, minor amounts of excess cementing materials, snow and wash water, and other as allowed under (h)(3) of AOGCC Chapter 25, Regulation 20 AAC 25.080.7). Also, ground rock cuttings from drilling operations will be incorporated in the injected slurry. Finally, minor amounts of freeze protect diesel oil used specifically as part of this disposal process, may be injected. 7) The maximum anticipated pressure at the 13-3/8" casing shoe during disposal operations will be at or near the formation fracture pressure of 1,910 psi (12.4 ppg EMW at the casing setting depth of 2,958 'RKB). The injection pressure during disposal operations may slightly exceed the original fracture pressure at times due to injected fines plugging off established fractures and having to re-fracture or otherwise overcome the tendency of the formation face to sand off. The maximum anticipated surface pressure during disposal operations is calculated as follows: = Fracture Pressure + Friction Pressure Losses -Hydrostatic Pressure _ (2,958') (12.4 ppg) (.052 psi/ft-ppg) + 100 psi - (2,958') (8.6 ppg) (.052 psi/ft-ppg) = 685 psi This calculation is for the worst case (highest pressure): the injection interval depth to be 2,958', maximum friction pressure losses to be 100 psi, and fresh water is the least dense fluid to be injected. 8) The 13-3/8" casing is set at 2,958'RKB. Records indicate that the cement for this casing string was brought to the surface. A. Cementing records for this casing string do not exist. A report submitted to the AOGCC on March 4, 1969 (enclosed with this Application) state the casing was "cemented with 1100 sx Ideal class G with 16% gel and 0.3% HR7, tailed with 157 sx Ideal class G. Job completed at 2330 hours, 19 February 1969. Good cement returns." B. A cement quality log was not run in this casing string and it is not possible to run one now since there is a 9-5/8" casing string run inside of it. However, a formation leak-off test will be conducted down the 9-5/8" X 13-3/8" annulus and the results submitted to the AOGCC before well re-entry operations commence. 9) Casing Safety Factors during Injection below 13-3/8" casing. Injection of fluids will be down the 9-5/8" X 13-3/8" annulus. This will expose the 13-3/8" casing to its maximum bursting stress at the casing shoe (surface injection pressure less friction loss plus the difference between the hydrostatic pressure of the injectant and the formation pore pressure behind the casing just above the shoe). The 9-5/8" casing will be exposed to its maximum collapse pressure at the surface (surface injection pressure with no hydrostatic or backup pressure inside). The 13-3/8" bursting stress and burst safety factor are calculated as follow: Burstin Sg tress = Surf. Injection pressure -friction pressure losses + (hydrostatic pressure of injectant at shoe -formation pore pressure at shoe) = 685 psi -100 psi + (2,958' x .052 x (12.4 ppg - 9.2 ppg)) = 1,077 psi Safety Factor • = Burst rating of 13-3/8" casing -Bursting stress = 3,090 psi _ 1,077 psi = 2.87 • The 9-5/8" collapse stress and collapse safety factor are calculated as follow: Collapse Stress = Surface injection pressure = 685 psi Safet F~ actor = Collapse rating of 9-5/8" casing -Collapse stress = 4,750 psi _ 685 psi = 6.93 10) The downhole pressure obtained during the LOT/FIT at the 13-3/8" casing shoe will be submitted to the AOGCC as soon as it is obtained. 11) Wireline and mud logs indicate there are no hydrocarbon-bearing zones above the top of the cement around the 9-5/8" casing. 12) The duration of disposal in this well is not anticipated to exceed 30 days. 13) No drilling waste has previously been disposed of in this well. 14) All drilling waste to be disposed of in this well will be generated during the re-entry, drilling and evaluation of this well. 15) Forest Oil intends to comply with all limitations established in 10 AAC 25.080(d}. 16) Forest Oil will, to the best of its ability, provide any additional data required by the Commission to confirm containment of the drilling waste. • • ~`'`"~' Forest Oil Corporation ~ ~ MIDDLE LAKE # 1 SEC 22 T15N R5W Antic. Spud Date: 9/1/05 Elevation 111 ft Prop. Total Depth: 9,400 'MD 9,400 'TVD Expected RKB-MWL: 25 ft surf. Loc.: Lat. 61.37832 BH Loc.: Long. 150.1586 objective: Re-entry, Sidetrack off Whipstock, Drill to 9,400' and Evaluate. E Log/ Mud Log/ Directional Info Casing Specs. Drill Depth, Ft. I Referenced to RKB Well Control Dimensions, In. TV Depth, Ft MW, ppg FG, ppg 0 0 0 ****Already Set 30 Drive Pipe 27 Driven 27 ~ - - 0.63 "Wall Thickness 0 I~ 26 1 ~ Diverter Hole Size System *"*"Already Set 20 Conductor 281 281 0.0 0.0 94.0 #, H-40 Buttress 0 17 1/2 Diverter Hole Size System ***"'Already Set 13 3/8 Surface 2,958 2,958 i 0.0 0.0 61.0 #, K-55 Buttress 13 518 5,000 Annular i 13 518 5,000 BOPs 12 114 Hole Size Whipstock @ 8,500' TOL ~ 9 5181ntermediate 8,200 8,500 13.0 16.8 47.0 #, N-80 LTC 13 5l8 5,000 Annular 13 5/8 5,000 BOPS 6 Quad Combo (Ind., Hole Size ~ NGT,Den,Neu,Sonic) Possible MDT Pre-Tyonek 8.880 8,524 SWC 0 0 0 5 1l2 Production 9,400 ~ 9,061 13.2 17.5 20.0 #, L-80 Hydril521/LTC PTD ~...~ ~. . CQNFIDEN~IAI r°r:r` xo. r-.s SATE OF ALASKA svasarr >xr nrrrzcwT~ , a•sa•~r O!L AdVD GAS CONSERVATION COMMITTEE iMONTHI.Y -R[~ORT ~ DRILLIN~ii AND 1NORKOYRR OPERATIONS ~, wsl.t ~ ws .~ ~ osana WILpCAT s""~I.w'fa~91'' nwresa GULF OIL CORPORATION PO. Box-2211, Anchorage, Alaska 99501 1923' South and 1142' Bast of the N,W. Corner tI. $® ,~;~. `s"TTO'~ xat~ Sec. 22, T-15N, R-'3~J, S.A4. I!. T1iRI14IT w ~. d~ CFIANG&8 IN HQI:E &I7LE, CwSIN4 AND CEMTxTINR SQ88 INCLADING AERTH TESTS ARID RE$UI.TS, FIiFIIx(3 Ja88, JIJNK IN HALE AND $ID&•TRJ1CItSA IdQI.1G ' E[OI.E CQx7lITIANi. F>aBRUARY -1969 Rigged down easing tools aad ri$$ed up to drill ahead. Welded 13 3/8" x 20" swage on 20" casing. Installed 13 3/8" casing head, BOP and hydriL. Attempted to.test hydrll and rubber ruptured. Pulled out of hol~a removed swage, casing heed, BOP and hydrll. Installed 20" flange and niggled up 20" hydrll. Went in halve and atteatpted to test hydrll and rubber ruptured. Pulled hydrll for repairs. Repairetd hydrll axed tented casing and hydrll to 300 psi, OK. grilled float collar and 29' cement. Drilled to 3082', conditioned mud and pulled out of hole. Ran Schlumberger Dual Induetion and i~amma~-Sonic logs, Caliper did not function. Went in hole and reamed 12~" hole to ll~", t:o 1463` and drill pipe unscrewed, Fishing fob No, 1 recovered fish, total time lost 16 hours. Reamed to 2069' and drill-pipe unscrewed. Fishing fob No. 2, recovered fish, total time 1®st 10 hours. Reamed to 2960. Conditioned mud and made wiper trip to run 13 3/8 casing. Ran 78 its 13 3/8" OD 61# J-55 ST&C casing with .Baker fleet shoe sat at 2958' and cemented with 1100 ex Ideal class G with 16X gel and o.3X HR7, tailed with 153 sx Ideal class G.. Job eomplete at 2330 hours, 19 February 1969. Good cement returns. Removed 2Q" hydrll and installed 13 3/8" casing head, BOP and hydrll. Tested blind rams to 1500 gsi far 15 minutes OK. Went in hole with two stands of drill pipe .and tested pipe xams and hydrll to 1500 psi for l5 minutes, OK. Drilled hard eetnant from 2480' to '2958'. Conditioned mud and cleaned out to 3082'. Tubaseoped all drill pipe oa location. Drilled to 5876', pulled out of hole, removed rotary table and changed bell nipple. Went in bola, tasted pipe rams to 3000 psi and hydrll to 2000 pei, OK, At 2400 hours, 28 February 1969, running survey at-5999'. G.A, Knowles Ii. ~ ae~av oertitr~W[s,thg,o}~ is true Tsres Scout aw~a•,s 4 March lydy NOTi-R-Rcpart on this form is required far eteh cRlendar month, regardless of the sutus of operptions, end with iht Divictpn of Mine, & Minoral~ by the 25th of the wceeed~ng month, unless otherwl9e directtd. Page 1 of 2 pages. CONFIDENTIAL • ADL-21184 1KIADLE LAKE tJ~1IT MAR 6 19~~ DNIlK1N Q10~IL AND GAS •1~'iSAa4ra • rt~~ I~I I (~~ I ~~~ ~~ W E & P SERVICES, INC. Format~~rt Water Salinity Deternninatien Gulf•Alaskco Middle Lake Unit #1 Company Field Well Date Logged Date Processed Log Analyst Fairweather E&P Services, Inc. Wildcat Gulf-Alaskco Middle Lake Unit #1 14February-1969 (First Run Log) 13-September-2005 Ron Doshier Fairv~ather E&P Services, Inc. 715 `L" Stmt Anchorage, Alaska 99501 (907) 258-3446 All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do npt guarantee the accuracy or correctness ~ any interpretations and we shall not, except in the case of gross negrgerrce on out part, be liable or responsible for any Ices, cost, damages or expenses incurred or sustained by anyone resulting from arty interpretation made by any of air offia~s, agents or employees. • • Fairweather F&P Services, Inc. Log Data: 2-14-69 Field: Wildcat Well: Gulf-Alaskco Middle Lake Unit #1 County Susitna Introduction Fairweather E&P Services, Inc was asked to evaluate the salinity formation water on well Gulf- Alaskco Middle Lake Unit #1, which was spudded by Gulf Oil Company - U.S. in early 19b9. The intervals of interest are from 3,182ft. to 3,188ft. and 3,432ft. to 3,439ft. The data available for this evaluation included a 2" Dual Induction - Laterolo$ with SP and a 2" Borehole Compensated Sonic with SP, and Caliper Survey. The reason for interpretation is to determine if the water salinities of these formation intervals are saline enough for use for annular injection down the 9-518" - 13-3/8" annulus and below the 13-3/8" casing shoe located at 2,958ft. The spontaneous potential (SP) log The spontaneous potential tool measures natural electrical potentials that occur in boreholes and generally distinguishes porous, permeable sandstones from intervening shales. The "Natural Battery" is caused when the use of drilling mud with a different salinity from the formation waters, causes two solutions to be in contact that have different ian concentrations. Ions diffuse from the more concentrated solution (typically formation water) to the more dilute. The ion flow constitutes. electrical current, which generates a small natural potential measured by the SP tool in millivolts. When the salinities of mud filtrate and formation water are the same, the potential is zero and the SP log should be a featureless line. With a fresher mud filtrate and so, more saline formation water, a sandstone will show a deflection in a negative potential direction (to the left) from a "shale base line" which is the zero potential measuremerrt (to the right). The amouirt of deflection is controlled by the salinity contrast between the mud filtrate and the formation water. Clean (shale-free) sandstone units with the same water salinity should show a common value, the "sand line". In practice, there will be drift with depth because of the changing salinity of formation waters. The displacement on the log between the shale and sand lines is the "static self-potential" SSP. The conductivity of the drilling mud filtrate is measured by the logging engineers at the well-site and recorded on the "header" of the log. This information combined with the SSP "battery effect" shown on the log can be used to estimate the conductivity of the formation water. The calculation is made very commonly by petroleum log analysts as an important variable in the search for potential oil or gas zones. When used to evaluate the quality of aquifer waters, care must betaken to ensure realistic conclusions. Although formation water compositions at greater depths tend to be mostly sodium chloride, the ions of calcium, magnesium, bicarbonate and sulfate become more important in shallow, aquifer waters. As a result, the equations used by petroleum log analysts are only approximate and must be adjusted to honor the ionic mix of the local aquifer water. In general, the divalent ions of shallow waters tend to make them appear slightly more saline than they actually are when computed from the SP log. For this reason it is suggested that if water samples have been or will be collected that the resistivity of these samples be recorded for future corrections and transformed to estimates of total dissolved solids. • • Salinity Determination The salinity of the formation water (Rw) was determined by using the SP interpretation technique. This technique assumes the fluid in the formation is water with no hydrocarbons. The charts in thi$ work are included in this report. SP Interpretation SP interpretation consisted of the following steps. 1. Determine temperature at the zone of interest (Tzone = 40 + 0.013 X Depthj 2. Determine Rmf at temperature of zone (Chart Gen-9) 3. Determine Rmfeq (Chart SP-2) 4. Determine SP deflection from shale baseline 5. Determine constant K (K=61 + (0.133 x Temperature)) b. Determine Rweq from formula SP deflection = k x log (Rmf/Rweq) (Chart SP-1) 7. Determine Rw (Chart SP-2) 8. Determine salinity (Chart Gen-9) Zone 3,432ft. to 3,439ft. 1. Temperature at zone = 85F 2. Rmf at 85 F temperature = 4.40ohm-m 3. Rmfeq = I.40 ohm-rn 4. SP deflection = -42 my 5. K = 72.3 6. Rweq = 0.085 ohm-m 7. Rw = 0.1 ohm-m 8. Salinity = 61,000 ppm Zone 3,182ft. to 3,188ft. 1. Temperature at zone = 82F 2. Rmf at 82 F temperature = 4.56ohm-m 3. Rmfeq = 1.48 ohm-m 4. SP Deflection = -35mv 5. K = 71.9 6. Rweq = 0.095 ohm-m 7. Rw = 0.13 ohm-m 8. Salinity = 48,000 ppm • Estimation of Formation Temperature Linear gradiP.nt asstarea ® Temperature gratierrt carwersials: i °Ffi oo ~= i i°~1~ oo m i °C,Ji oo m = o.s48e° Ffi oo ft Amual mean surface tgnperatune I Temperawte ('°~~ i t 2 iC '~ i; 3 ~! # G ,S s~ +2i s ea• i oo ~ so a~oo Asa 1~nval mean Temperature {" ~ surface ~mperawre s~t~~,~.e, ~~ l::~Y r„r~7/c': Bottomhole temperature (Bl IT) at 11,000 fl - 200°F (Point A) Temperature at 8000 ft = 167°F (Point B) goo Asa • Resistivity of NaCI Solutions Gen-9 8 6 5 4 3 2 1 0.8 ~ 0.6 E 0.5 0 ~ 0.4 0 ~' 0.3 0 ~~ 0.2 o~ .~ 0.1 0.08 0.06 0.05 0.04 0.03 0.02 0.01 ..Schltenberger Conversion approximated by R2 = R1 ((T1 + 6.77)/(TZ + 6.77)]°F or Rz = R1 [(T1 + 21.5)/(T2+ 21.5)]°C 10 t= a a I Flo ~b fib` sGO, )~ . ~` 1~ 1~ lq~ ~~~ ~b ~b ~O~ ~?~ ~4~ '~~ dab 3O'~b qo~ ~~ ~~ , r?o°rb lqp~ ~~O SAD ~v,~ 807 °F 50 75 100 125 150 200 250 300 350 400 °C 10 20 30 40 50 60 70 80 90 100 120 140 160 180 200 i i ~ ~ i i i i i r i i i i ~ ~ i i Temperature (°F or °C) 0 m ~, c .~ C7 I 10 15 20 25 30 40 50 O~ to c .~ rn 100 `o E a 150 a zoo ~;~ 250 300 400 U m 500 Z looo 1500 2000 2500 3000 aooo 5000 10,000 15.000 20.000 Gen 1-5 ~ • 1 11 1 ~1 I RWeq Determination from ESSP Clean formations This chart and nomograph calculate the equivalent forma- /.:rum/~/r: SSP - 100 mV at 250°F tion water resistivity, R„~.y, from the static spontaneous R,,,, - 0.70 ohman at 100°F potential, Esst~, measurement in clean formations. or 0.33 ohm-m at 250°F in mV, turning through Enter the nomograph with Essp Therefore, Rn,i~y - 0.85 x 0.33 ° the reservoir temperature in For C to define the - 0.28 ohm-m at 250°F' R,,,i~y/R„ ~.y ratio. From this value, pass through the R,,,i~y value to define R„~y. R„~y - 0.025 ohm-m at 250°F For predominantly NaCI muds, determine Rmliy as Essr - -K~ log(R,,,i~yi R„~y 1 follows: Kc - 61 - 0.133 "r r a. If R,,,, at 75°F' (24°C) is greater than 0.l ohm-m, Kc - 65 ~ 0.24 T ~ correct R,,,, to formation temperature using Chari Gen-9, and use Rmtcy - 0.85 Rm~: b. if Rmf at 75°F (24°C) is less than 0.1 ohm-m, use Chart SP-2 to derive a value of Rm~~y at formation temperature. 0.3 0.4 0.5 0.6 0.8 1 2 ;: tr m ' 3 E 4 0 5 6 8 10 20 30 ao 50 Schl,ntd,erga Rm~y /R,,,,ey 03 Formation 0.4 0.6 0.8 1 2 4 6 8 10 20 40 +50 0 -50 -100 -150 -200 Esc, static spontaneous potential (mV) Rmf~ (ohm-m) 0.01 0.02 0.04 0.06 0.1 0.2 0.4 0.6 1 2 4 6 10 20 40 60 100 SP-1 R,vey (ohm-m) _ 0.001 . 0.005 . 0.01 . 0.02 . 0.05 _ 0.1 _ 0.2 0.5 _ 1.0 . 2.0 2-5 SP Rw versus RWeq and Formation Temperature SP_2 (English) 0.001 0.002 0.005 0.01 0.02 E s 0 m 0.05 E >_ O ~ 0.1 0.2 0.5 1.0 Schluri~~ger 2.0 0.005 5 0 0°F ~ 400°F 300°F I - ~ _ 200°F _150°F - ° - F _100 - 75°F Saturation : - - _ r- ~. I l I~I {{ -I ~ .. ~ + - ~ ti \ ~ '~ ~ 1 \ ~ ~ ~ ~ --- F. _ 2 \~ ~° ` ~ i I ' ~ r~so ', ~ ~gb R 0.01 0.02 0.03 0.05 0.1 0.2 0.3 0.5 1.0 2 3 4 5 RW or Rmf (ohm-m) These charts convert equivalent water resistivity, RW~y, from Chart SP-1 to actual water resistivity, RW. They may also be used to convert R~,f to Rm~y in saline muds. Use the solid lines for predominantly NaCI waters. The dashed lines are approximate for "average" fresh formation waters (where effects of salts other than NaCI become signifi- cant). The dashed portions may also be used for gyp-base mud filtrates. 1:.~~rnr/~1~~: K„~y - 0.025 ohm-m at 120°C From chart, RW = 0.031 ohm-m at 120°C Special procedures for muds containing Ca or Mg in solution are discussed in Reference 3. Lime-base muds usually have a negligible amount of Ca in solution; they may be treated as regular mud types. z-s a~-~- "~' ~ ~~g t ~,~' ~ . ~ ~ (. ,.,~ ~ ~ ~ ! ~~ ~ a FRANK H- MURKOWSKI .~, .,~.r .,,, `t„s ~.,~'~'~ ,GOVERNOR ~f 1~r -~re~1w~ ®~1~~~ ~+ t~ ° 333 W. T" AVENUE, SUITE 100 ~~~~~r~~A1E~l1ai C®i'a1rAi~~7lzp~ ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 Ted Kramer FAx (907) 276-7542 Alaska Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, AK 99501 Re: Exploratory, Middle Lake Unit # lA Sundry Number: 306-O1 l Dear Mr. Kramer: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2006 Encl. • F O R E S T O I L C O R P O R A T I O N •~ . ~ X90 C~~C~~~-eet • ~~,t X00 Y ~~ncl ow, ~~a~; c~ 9950 • ~907~ .z58-86ao • ~9o7J w58-SSO~ ~~~x~ January 11, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval: Middle Lake Unit #1-A (PTD No. 205-149) Dear Mr. Norman, RE~E~~,E~ JA N Y 1 ?006 Alaska Oil & Gas Cans. C°~ssion Anchorage Forest Oil Corporation hereby applies for approval of its plan to plug and abandon the recently drilled MLU #1-A well. The target interval produced only water with no measurable quantities of hydrocarbons. Please find the attached information in support of this application: 1) Form 10-403 Application for Sundry Approval 2) A proposed P&A Plan 3) A current wellbore schematic 4) A proposed wellbore schematic If you have any questions or require additional information, please contact me at 868- 2137 or Bill Penrose at 258-3446. Sincerely, Ted Kramer Alaska Production Manager enclosures cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ~~pp~~~,,~1~-~ REC~I~~~- STATE OF ALASKA ~1''J J~~ ALAS OIL AND GAS CONSERVATION COMMI N, ~~ ,IAN 1 1 2QOfi APPLICATION FOR SUNDRY APPROVALS 20 AAC Zs.2so Alaska Oil & Gas Cnns. C+mnmissinn 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate Waive Ct UCrl~6 Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Forest Oil Corporation Development ^ Exploratory Q 205-149 3. Address: Stratigraphic ^ Service ^ 6. API Number: / 310 K Street, Suite 700, Anchorage, Alaska 99501 50-283-20021-01 7. KB Eievation (ft): 9. Well Name and Number: 18.3' AGL Middle Lake Unit #1A 8. Property Designation: 10. Field/Pools(s): Mental Health Trust No.s 9300049 and 9300050 Exploratory 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft}: Plugs (measured): Junk (measured): 9,350' 9,001' 9,350' 9,001' None None Casing Length Size MD TVD Burst Collapse Structural 27' 30" 27' 27' NIA N/A Conductor 281' 20" 281' 281' 1,530 520 Surface 2,958' 13-318" 2,958' 2,953' 3,090 1,540 Intermediate 8,457' 9-5/8" 8,457' 8,457' 6,870 4,750 Production 9,338' 5-1@" 9,338' 9,338' 9,190 8,830 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,910' - 9,050' 8,910' - 9,050' 2-718" P-110 8,858' Packers and SSSV Type: Pkr: Weatherford 5-1/2" ArrowPak @ 8,768' Packers and SSSV MD (ft): Pkr: Weatherford 5-1/2" ArrowPak @ 8,768' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^~ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/11/2006 Oil ^ Gas ^ Plugged ^ Abandoned Q 16. Verbal Approval: Date: NIA WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446 Printed Name Ted Kramer Title Alaska Production Manager Signature -~',. ~~ ~~'~--- Phone 868-2137 Date 1/11/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '~ ,.. ~~ Plug Integrity '~ BOP Test ~ Mechanical Integrity Test ^ Location Clearance Other: rI.TC~ V.~ITt~SS Cfc. iC~M`Ci~~S ZR p~~L~v~~ ~ ~tAN ~ ,~ 20Q~ Subsequent Form O APPROVED BY ¢-~ Approve ~ //~ COMMISSIONER THE COMMISSION Date: V Form 10-403 Revise 05 ~® ~-- Submit in Duplicate r~ u r1 U Plug and Abandonment Procedure Forest Oil Corporation Middle Lake Unit #1-A 1. Displace a sufficient quantity of cement down the existing tubing to cover the interval from 100' below the perforated interval up to the packer located 142' above the topmost perforation and leaving cement in the tubing 50' above the packer. ~:~0 S,F ~t~bbis s~~c~~~C> 2. WOC. 3. Pressure test the tubing and cement plug inside of it to 2,300 psi. ~S~,e,~\~4~c~w~~~~~css~r) 4. Set a BPV, N/D tree, N/U BOP's and pressure test same to 250/5,000 psi. 5. After notifying the AOGCC so they can provide a witness, attempt to pump down the 9-5/8" x 13-3/8" annulus. Obtain a leakoff value and conduct a 4-point ~(~~ test required to qualify the annulus for annular disposal. --~5~~~`~ ~~ ~~-~r6y~ ~/ ~ 10_y~3 ~~ ~~ ~E~~~~~~ 6. Cut the tubing as deeply as possible (this will be approximately 50' above the packer). Establish circulation. 7. Pressure test down the tubing to 2,300 psi to re-test the cement plug and the packer. 8. With the cut-off 2-7/8" tubing still in the well, displace the well with 14.9 ppg ~ mud. 9. POH with the cut off 2-7/8" tubing and lay it down. 10. If the 9-5/8" x 13-3/8" annulus can be used for annular disposal, pump all excess mud and completion brine down annulus, following it with sufficient cement to fill the annulus from the 13-3/8" shoe to surface. 11. Cut and pull the 5-1/2" production casing from 200' RKB. 12. Seta 9-5/8" bridge plug at 200', just above the 5" casing stub. -~Slc~~s~~~cWe~+~~ss 13. Set a cement plug from the bridge plug at 200' to 10' below ground level. ~, 'lam s~ C ~'-1 b~~s~ 14. M/U 9-5/8" casing cutter, RIH and cut 9-5/8" casing at 10' below ground level. 15. POH and L/D casing cutter. Retrieve and L/D 9-5/8" stub. • • 16. Rig down and release the drilling rig. 17. Use a backhoe to excavate around the well head to 7' below the surrounding ground level (not pad level). 18. Cut off all strings of casing at least 5' below ground level. Ensure all annuli are filled with cement. `` \ ~i ~~` ~DEvJ~~~~~ 19. Weld marker plate onto the outermost casing stung with the required h identification information bead-welded onto it. 20. Bury the well marker, bringing the fill level to the surrounding pad and mounding a little extra to compensate for settling. 21. Clean up the pad and obtain well close-out approval from the AOGCC representative. FO EST OIL CORPORATION MIDDLE LAKE # 1A CURRENT COMPLETION ELEVATION: 14' KB Date: 1/9/06 Prepared: Ro Smith I 1 I 1 30" .63" Wall Thickness Drive Pipe Set 1 20" 94# H-40 @+/- 281' Set Already ~ ~ Methanol Injection Mandrel @ 2,979' w/ 1/4" Control Line Set Already I I I 13 3/8" 61# K-55 @ +/- 2,958' MDITVD I nn I I TOC of 5 1/2"Tieback 7,300' I I I 5112" 17# L-80 Buttress Modified Couplings T/B I Top of 5 1/2" Liner @ 7,783' MDITVD 9 5/8" 47# N-80 Whipstock Window Top @ 8,457' MD/TVD 10.4 ppg KCL/CaCI Completion Fluid 2 7/8" 6 5# P 110 RTS 8 T bi - . - u ng wx 2 7l8" "X" Nipple with 4'pups above and below set 1 joint above packer 5 1l2" 20#/ft ArrowPak Retrievable packer with TCP gunsSet @ 8,768' wxN 2 718" "WXN" Nipple w/4' pups above and 6' below Perforations 8,910-9,004', 9008-9,020' 8~ 9,030-9,050 MD 9,2 ----------- 54' P ------- BTD ----------- 5 1/2" 20#/ft L-80 Hydril 521 @ +/_ 8,338' FOREST OIL CORPORATION MIDDLE LAKE # 1A Proposed Plug and Abandonment Date: 1 /11 /06 Re: Middle Lake # lA • . Subject: Re: Middle Lake # lA From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 11 Jan 2006 16:52:12 -0900 To: Roy Smith <RLSmith@forestoil.com> CC: John Spaulding <john_spauldng@admin.state.ak.us>, Jim Regg <jim_regg@admin.state.ak.us> Roy, Thank you for checking. In further reviewing your plan, one additional plug will be needed. Since there is fresh water in the shallow strata out there a plug is needed in the 5-1/2" proximate to the surface casing shoe. 20 AAC 25.123(c)(3) requires such a plug. It is your option to set cement on a retainer as allowed by (B) or spot a balanced plug (A). If a balanced plug is set, it will be necessary to tag it as required by (g) (1). If you set a retainer, that accomplishes the tag. Good luck with your operations. Please make sure the Company Man stays in contact with Inspector John Spaulding for the witness activities. Tom Maunder, PE AOGCC Roy Smith wrote, On 1/11/2006 4:42 PM: Tom We checked the daily reports and on 1/5/06 the 5 1/2" was tested to 5,000 psi with 14.7 spotty to 14.9 mud weight in hole. I have no problem testing the wireline plug nor cement plug to 5,000 psi. Thanks Roy -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, January 11, 2006 6:27 PM To: Roy Smith Subject: Re: Middle Lake # lA Roy, If I remember your summary reports, I don't believe that you have tested the wellbore to 5000 psi with the 14.9 ppg fluid in the hole. Is that correct?? Your maximum pressure test with the heavy mud in the hole should not exceed what you have previously done. I hope you are still on line to get this. I may try to call you. Please reply. Tom Maunder, PE AOGCC Roy Smith wrote, On 1/11/2006 4:19 PM: Tom As a follow up to our discussions, attempts were made to establish a adequate injection rate into the current perforations, at 1/2BPM with pressures continuing to increase up to 5,000 psi. Based on this low injection rate and high pressure, I recommend not attempting to squeeze cement into the perforations. As an alternative program, I propose the 1 of 2 1/11/200b 4:52 PM Re: Middle Lake # lA • • ', ' follow operation for your consideration. ', I will await your e-mail response before proceeding with setting of the plug. ', Thanks Tom ', ~, Rig up wireline and set a positive plug in the XN nipple located below the ', ', production packer. ', Test the plug to 5,000 psi for 30 minutes ~ ', Bleed to tubing pressure to 0 !, Assuming pressure bleeds to 0, set BPV, nipple down tree and nipple you BOP ~', ' and test 250 low/5000 high. i I ', Pull seals out of packer and displace 5 1/2" casing with 14.9 ppg water l base mud. Mix and spot a 200' cement plug on top of production packer. Pull above cement top and reverse out. WOC Pressure test cement plug to 5,000 psi. Then proceed to previous plugging program. 2 of 2 1!11/2006 4:52 PM • January 10, 2006 F O R E S T O I L C O R P O R A T I O N ~?~~ruu~o~~, O~~aii/uz 9950/ ~.~a~J ass-~eoo • ~907~ ~s~-s6o~ ~~~r) Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Rliddle Lake iJnit #1-A Dear Mr. Norman, ~~~~I~ JAN 1 ~ 206 AiASk6 qlf $ Gtr: i-QA~. ~ttt~IMtt1011 An~horl ,~05-19~i This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of January 3 through January 9, inclusive. January 3, 2005 Finish POH w/ bit. M/U casing scraper above bit, RIH to 9,254'. C&C mud, blow down top drive, POH. Remove. V-door slide, move catwalk, pull flowline and bell nipple. N/D BOP's. January 4, 2005 N/U 11 ", SM x 11 ", l OM wellhead and test to 5,000 psi. Test BOPE to 250/5,000 psi except annular to 250/3,500 psi. M/LJ bit and scraper, RIH to 9,254' PBTD. January 5, 2005 C&C mud. Test casing to 5,000 psi for 30 min - OK. Displace well and pits w/ 10.4 ppg KCl/CaC12 brine. C&C brine in well and until NCU's consistently read 16 - 20. POH w/ bit and scraper. P/U perf guns and pkr -packer sleeve wrong size, preventing make-up. Send packer to shop to have sleeve modified. January 6, 2005 Wait on packer modification. P/LJ and M/U packer and perf guns, RIH. R/U Schlumberger e-line, RIH and set packer/guns on depth. POH w/ e-line, R/D Schlumberger. Drop packer setting ball, pressure up to 2,300 psi, set packer at 8,768' w/ top shot at 8,910'. POH, L/D 2-7/8" work string. January 7, 2005 Finish POH w/ 2-7/8" work string, load on trucks. L/D 4" drill pipe out of derrick, load on trucks. Clear rig floor. Load pipe rack w/ 2-7/8" tubing. Strap and tally same. R/U floor to run production tubing. M/LJ seal assy, x-nipple and pups, RIH w/ same on 2-7/8" tubing while drifting same. Mr. John Norman Page 2 r~ ~~ January 8, 2006 Continue RIH w/ 2-7/8" tubing. Install chemical injection mandrel at 3,000'. Tag packer at 8,768', pressure up backside to 200 psi w/ tubing open - OK. R/U slickline, RIH, set plug in x-nipple at 8,707'. M/U hanger & space-out pups. Test tbg to 5,000 psi with seal assy out of pkr - OK. RIH w/ slickline, pull plug from x-nipple, POH, R/D slickline. Circulate corrosion inhibitor to backside. Drain stack, pump 2 bbls out of annulus to make room for freeze protect diesel. M/LT landing joint, M/U chemical injection line to hanger. Add 2 bbls diesel to annulus. Land hanger, run in hold-down pins. Pressure up backside to 500 psi w/ tbg open to test seals - OK. B/O landing. jt, install BPV. January 9, 2006 N/D BOPE, N/U tree. Test hanger neck seals to 8,000 psi. Pull BPV, install 2-way check. Test tree to 250/8,000 psi, pu112-way check. Test flow line to heater to 250/$,000 psi. Test downstream of 2"a choke to 250/3,500 psi. Test separator to 250/1,000 psi. Secure flowlines and otherwise prepare for well testing. Wait on daylight to fire guns. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION ,~ -mac Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ~ i F O R E S T O I L C O R P O R A T I O N •~ . ~ ~ .3/O - ni ~~~~~/ • C~.~~;/e 700 Y C~S~nc~ir~*a~e, C>5~/~~r~~~ .950'/ • (90T~ ?58-8600 • (907 ?58-860% (n~'ax> January 3, 2006 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Middle Lake Unit #1-A Dear Mr. Norman, ~~ ~~ 4 ?CJDfa Alaska Ash ~ (;,~~ ~~~~ ~'a~rt~r~;ificoy~s ArlChot~p~ ~~5-- i~~ This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of December 27 through January 2, inclusive. December 27, 2005 M/tJ liner shoe, P/U and run 38 jts 5-1/2", 20#, P-110, Hydril-521 liner w/ Baker HMC finer hanger on 4" drill pipe. Set liner hanger 'w/ liner shoe at 9,338' and top of liner at 7,783'. Release from liner, R/U to .cement, test lines. Pump 40 bbls of 15.2 ppg spacer followed by 244 sx (50 bbls) Class G cement w/ additives. Displace w/ 14.9 ppg mud, bump plug OK. Set liner-top packer w/ 40K lbs down weight. Test backside to 2,000 psi - OK. Reverse out, got back'/z bbl cement and cuttings. L/D cementing head, POH w/ liner hanger setting tool. December 28, 2005 Finish POH w/ liner hanger setting tool, L/D 41 jts 4" drill pipe and setting tool. M/LT cleanout BHA and RIH while P/U 48 jts 2-7/8" drillpipe. Continue in hole w/ 4" drill pipe. C&C at TOL to balance out mud. Continue in hole to landing collar at 9,~~3'. Did not tag anything on way in hole. C~iC-mud, POH to run CBL. December 29, 2005 R/U Schlumberger, RIH w/ CBL. Log 5-1/2" liner from 9,254' to 7,784' with 1,000 psi pressure applied to wellbore. POH, R/D Schlumberger. M/U polish mill on drill pipe and RIH. Polish tie-back receptacle, CBU. POH laying down 4" drill pipe. December 30, 2005 Offload, drift and strap 5-1/2" casing. Weight up and even out. mud in pits to 149 ppg while waiting on csg x circulating swedge x-over. M/LT tieback seal assy. TIH, P/U 5-1/2' ; 17#, L-80,1BTC casing. • Mr. John Norman Page 2 • December 31, 2005 Finish RIH w/ 5-1/2" tieback liner. Tag TOL at 7,783', P/iJ 10'. Pump 20 bbls 15.8 ppg Class G cement, displace w/ 14.9 ppg mud. Bump plug w/ 500 psi. Bleed off pressure, slack off to engage seals. Estimated TOC at 7,300'. P/U BOP's, set casing slips, make rough cut. L/D landing jt and stub. Set down BOP's and N/LT same. Clear floor, R/U 3-1/2" handling tools. TIH w/ 1 stand 3-1/2" DC's and 10 stands 2-7/8" DP below RTTS packer. Set RTTS packer and valve 30' below rotary. Commence testing BOPE. January 1, 2006 Test BOPE to 250/5,000 psi except annular to 250/3,500 psi - OK. Unseat storm packer, POH and L/D same. Stand back DC's and DP. Test safety valves and top drive valves to 250/5,000 psi. M/U 4-5/8" cmt mill, RIH w/16 stands 2-7/8" DP out of derrick. P/U additional 2-7/8" DP while RIH. Tag cmt at 7,662'. Wash and ream to 7,730' (hard cmt at 7,725'). January 2, 2006 Experience difficulty drilling up float insert and cement from 7,745' to 7,750'. Torque fell off. POH, L/D cmt mill -mill jammed up w/ debris. M/U 4-5/8" bit and RIH. Drilled up float insert and cement from 7,750' to 7,784', fell through. RIH while P/U additional 2-7/8" DP, tag up at 9,254'. C&C mud, POH. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION ~ilYd ~ ~ Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ~' 9 • J 1 ~ ~ ~ ~ ~ ~ a ~ ~ ~ J ~ ~ ~ ~ f» r ALASSA OIL A11TD GA.S COI~TSERQA~'I011T CO1rIIfII55I011T Roy Smith Drilling Supt Forest Oil Corporation 310 K Street Ste 700 Anchorage, AK 99501 Re: Middle Lake Unit # lA 305-396 Dear Mr. Smith: • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-1542 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of December, 2005 Encl. `f~-~ ~, AL STATE OF ALASKA / ~ /~/ ASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~~ ~~ ~~~~ ~ vv ,--V-lv GJ.LUV 1. Type of Request Abandon Suspend Operational shutdown Perforate Waiver Other Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program 0 Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Weil Class; 5. Permit to Drill Number . _ / Forest Oil Corporation Development ^ Exploratory ^ 205-149 V/ 3. Address; SVatigraphic u Service ^ 6. API Number: 310 K Street, Sui#e700, Anchorage, Alaska 99501 50-283-20021.01 7. KB Elevation (ft}t 9. Well Name and Number. 18.3' AGL Middle Lake Unit #1A 8. Properly Designation: 10. Field/Pools(s): Mental Health Trust Nos 9300049 and 9300060 Exploratory ~~~~~~ 11. PRESENT WELL CONDITION SUMMARY ~ : , Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured)•. ~~ ~t_ JuraK (measured);,<~ 9,350' 9,001' 9,350' 9,001. ~it~~None,~, . Ali ' ~~Re Casing Length Size MD TVD Burst `~~~ Collapse ~ Structural 2T 30" 2T 2T NIA`r ° ~~' iN1A,~ Conductor 281' 20" 291' 281' 1,530 , 520 Surface 2,958' 13-3l8" 2,958' 2,953' 3,090 1,540 Intermediate 8,880' 9-5/B" 8,880` 8,545' 6,870 4,750 Production Liner Perforation Depth MO (ft): Perforation Depth TVD (ft}: Tubing Size: Tubing Grade: Tubing MD (ft): N!A NIA NIA N/A NIA Packers and SSSV Type: None Packers and SSSV MD (ft): None 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12128!2005 Oil ^ Gas ~ Plugged ^ Abandoned [] 16. Verbat Approvaii Date: NIA WAG ^ GINJ ^ W1NJ ^ WDSPL ^ Commission Representative: NIA 17. 1 fiereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bill Penrose 258-3446 ~~~ Printed Name %'~_- ,~ ~~ Roy Smith Title Drilling Supt. Si nature ~" -°~`~ 1`~.~- ~~ Phone 303-864-6159 Date f212712005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. t.l C ~ ~ ~r Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ( ~~, ~~ ~L'~~~~i~`L li \VJ~~~~~ ~~~~ ~~.~j~ , ~ ~~7~~~ ~ 5ubsequentFor ed: Ct.~ ~~ ~~ '~4 ~~ "t4=tA.A~ F~"~F.- ,1~1fv ~ e~ ~~~~6 APPROVED BY Approv COMMISSIONER THE COMMISSION Date: ~Z ~ f"~ Form 10-403 Revisad 07/2005 U ~ I f ~~ Submit in Duplicate E~ill Penrose From: Roy Smith [RLSmith@forestoil.com] Sent: Tuesday, December 27, 2005 2:12 PM To: Bill Penrose SubJect: Signature approval Bill You have my one time approval to sign. the sundry notice f_or the middle lake ## 1. Thanks Roy Sent from my BlackBerry Wireless Handheld 1 OPERATIONS SUMIVTARY Forest Oil Corporation Middle Lake Unit #1-A December 6 2005 Fizzish rigging up on location. lnstai] wellhead. Pressure test wellhead and N/IJ ROPE. December 7.2005 Finish N/IJ ROPE and function test same. Fill and check circulating system on rig. Test BODE to 2S0 psi low, 3,000 psi high. M/U wash-overlfishing assembly. December 8, 2005 Mill over 4-1/2" drill pipe stub in top of well. Make 1.5'. Shut down to install additional accumulator pump to yield acceptable accumulator pressure recovery time. Repair electrical problem on top drive. Continue milling over fish. Fluid level dropped away. Refill hole with 26 bbls of fluid. Monitor well -well static. M/U overshot and recover drill pipe stub {2.81' long). M/U wash pipe and shoe to wash over 9-5/8" casing. December 9 2005 Wash over 9-S/$" casing. Tag collar at 40'. L/D wash string, M/U 8-1/2" cement mill. RIH, mill out cement inside 9-5/8" casing to 32.6' -bottom of cement.. (Top of 9-5/8" casing is at 20.6' RKB.) POH, L!D mill, M/U spear. RIII, set spear in 9-5/8" casing. Pull 120k Ibs, got 7" stretch. Release spear, POH. LID spear, M(U 8-1/2" bit. RIH, wash to 310', tag hard cement. Drill cement to 315'. POl-I, L/D' BHA, P/t.~ 8-1/2' watermelon mill and knife blades. RIH and locate .collars in 9-5/8" casing. POH, L/D mill and blades, M/LJ hydraulic backoff assembly. RIH. December 10, 2005 Attempt to hack off top joint of 9-S/8" casing - no success. POH and LID tools. M/U spear asst', RIH, set in 9-5/8" casing. R/U string shot, RIl-I through spear asst', locate collaz•. Put % round of reverse torque in spear asst' and shoot string shot. bast torque.. POH w/ e-line and R/D same. Back out 9-5/8" casing and POH w/ same. Recovered 19,23:'. Blow down lines, clear floor, P!U 4" drill pipe, change bails on blocks, P!U 9- 5/8" handling tools, December 11.2005 Screw new joint of 9-5/8" casing into stub looking up and torque to 8,000 ft-Ibs. Test 9- 5/8" casing to 2,000 psi ~- OK. PIU BOP's, set slips, make rough cut on casing, L/D stub, N/D 13-518" BOP's. Make f nal cut on casing and install 13-5/8" x 11 ".wellhead section. Test void to 2,400 psi. N/U 11" BOP's. December 12, 2005 Finish Iv/U BOP's. Test BOPE to 250 psi low, 5,000 psi high. Test witnessed by AOGCC rep. M/U 8-1/2" bit and R1I4. Tag cement at 313'. Drill hard cement from 313' to 419. Bit torqueing, POH to check bit. December 13, 2005 R]H with cement mill and junk basket. Mill on junk and cementfrozn 419' to 424'. POH and clean juzllc basket. Recovered''/2 cup iron shavings. UD mill, M/Ll bit on junk basket and RIH. Drill cement from 424' to 559'. Broke through, lost returns for 1 bbl then regained full circulation. Check for flow -well stable. Wash and ream from 559' to 1,828'. December 14 2005 Wash and ream out 9-5/8" casing from 1,828' io 4,304'. Very thick mud with. 20 units gas. Circulate mud through de-gasser. Wash and ream from 4,304' to 4,712'. Tag up at 4,712'. Drill settled-out barite and cement stringers from 4,712' to 4,783'. MW 12.1, Vis 60. C&C mud and POH. Empty junk basket -recovered '/~ cup iron. .RII-I with 8- 1/2"bit on junk basket while P/U 4" drill pipe off pipe rack. December 15 2005 P/U 4'' drill pipe and stand back in derrick. Wash and ream from 4,783' to 7,200'. December 16 2005 Wash and ream from 7,200' 'to 8,600' without tagging anything. `RIU cementing unit, pressure test lines and pressure test 9-5/8" casing to 4,800 psi far 30 minutes. Final pressure 4,600 psi -good test. R/D cementing unit and POH. MI(J 9-5/8" casing scraper and RIH to 8,600'. December 17, 2005 C&C mud - MW in and out I2.2 ppg, vis 45. POH w/ casing scraper. R/U e-line and RIfLw/ 8-1/2" gauge ring and 5-112" junk basket. Tagged up at 556' -could not get past. POH. M/U two 1-11/16" sinker bars on e-line assy and RIIi. Still could not get past 556'. POH and R/D e-line. M/LJ 8-1/2" junk mill and 8-h./2" taper mill. RTH. Ream from 491' to 682'. Excess torque seen from 540' to 550'. Ream several times -cleared up. R1H to` 8,600' w/ no problems. C&C mud and POH w/ no problems. December 18, 2005 Finish POH w/ junk mill andtaper mill. Junk mill good, taper mill 1/32" under gauge, 2 finger-size pieces of cement in water courses of taper mill. R/U e-line w/ 8-1/2" gauge ring and 5-1/2" jw~k basket; 1ZiH to 8,600' w/ no problems. POH. M/L7 9-5/8" "E-4" CIBP on e-line and RIH. Set CIBP at 8,480', 4' above collar at 8,484'. POH w! e-line and RtD same. Test annular preventer to 250/3,500 psi, all other BOPS to 250/5,000 psi. MII19-5/8" whipstock assy on 4" drill pipe and ]ZII-i w/ same. Decembez 19.2005 RIH w/ 9-5/8" whipstock on 4" drill pipe. Tag CIBP at 8,479'. C&C mud until MW in and out is 12.2 ppg. M/U gyro and RIH surveying every 100' to 8,392'. Orient whipstock and set slips. Top of whipstock at 8,457'. POH w/ gyro and rig down same. Establish milling parameters and mill from 8,457' to 8,463'. December 20 2005 Mill window from 8,463' to 8,485'. C&C mud, balance mud weightnn and out at 12.5 ppg. R!U cementing tout, close pipe rams and conduct formation integrity test io 14.2 ppg )/MW {720 psi, 12.5 pg MW, 8149' TVD). Displace old 12.5 ppg mud system with new 13.0 ppg znud system. POH w/ window mills. December 21,2005 Finish POH, L/D rnilling assy. M/U 8-1/2" directional drilling assy and R[H. Slide and rotate from 8,490' to 8,772'. December 22, 2005 =-~ ~'~~ ~~ ~v v Slide and rotate from 8,772' to 8,988'. PVT indicated gain of 3 bbls. Shut well in, record pressures - 450 psi on DP, 450 psi on csg. Weight up active system from 13.0 ppg to 14.0 ppg azid circulate around. No gas or chloride. increase noted.. Shut in and check pressures - 0 psi on DP and csg. Open well to observe, well started flowing. Shut izt well. - 0 psi on DP, 100 psi on csg. Circulate mud around through choke, noted light spots of 13.8 ppg. Well still flowing when pumps shut dot~rz. Raise MW to 14.2 ppg and circulate around. Monitor well - 30 psi on DP, 60 psi on csg. Raise MW to 14.4 ppg and circulate around. Monitor well -gain 2.5 bbls in 1 hr, 1 S min. December 23, 2005 Monitor well for flow -- gained 3.2 bbls in 2 hrs. CBU - no gas or chlorides increase. Pull bit above window and conduct F1T to 16.3 ppg EMW. RLEI to bottom, rotate and slide from 8,988' to 9,350'. Make 10 stand wiper trip, hole took 9 bbls. CBU, slug pipe, POH. _December 24 2005 Well started flowing while POH. RIH to 9,350', gained 13.5 bbls. CBU - 625 units gas, mud cut from 14.4 ppg to 9.0 ppg -duration 25 minutes. Circulate while weighting up mud from 14.4 ppg to 14.9 ppg. Check flaw, no flow. Pooh to 8,353 -hole took proper fill.. RIEI to 9,350 w/ no problems. CBU, no gas, no cut zttud weight. Check flow, POH. December 25, 2005 e ~~ Test BOP's -annular to 250/2,500 psi, all else to 250/5,000 psi. RNLI Schlumberger, run `~ ~~~ quad combo to 9,351' WLM, log up to 8,456', POH w. quad combo. L/D logging tools and evaluate logs. M/U MDT test tool, RIH to 9,350'. Log up ,setting MD"C test tool at various depktts to obtain 16 sample readings. POH, L/D MDT tool. December 26. 2005 R/D Schlumberger, M/U 6-3/4" bit on packed assy and R1H. Pipe stuck w/ bit at 9,335'. Work pipe free. Ream from 9,275' to 9,338', experience severe torquing. CBU, make lU-stand short trip, no problems. POH for 5-1/2" liner. R/U casing running equipment. i Plan Forward: Run 5 1/2" liner to 9,350' Circuiat.e and condition fluid prior to cementing. Cement 5 1/2" liner, set liner-top packer. POOH with running tool. Lbt~n~~4~1C cJ PU 4-3/4" bit/mill, 5-1/2" scraper, 3-1/8" DC, 2-7/8" DP stinger and trip in hole cleaning out 5-Z/2." liner to landing collar.. Circulate out and test 5-1/2" liner. `_yv ~..~~`.~>~~~~~~~ C~Jr-t~~L~c`.~~ ~~~`CcS~c POOH. Rig up Schlumberger and run CBL log. ~~`" ~~~`~ ~~` ~Ca~~M~~~~7 ~ (If Squeeze operation is needed, change out the .stack to 10K, perform the squeeze operation and drill .out same. Squeeze operation will be W performed after running tieback string, installing the 10K tubing spool and installing the lOK BOP stack.) Trip in hole with polishing mill and polish out liner tieback seal bore. Circulate aut. POOH, LD 4" DP & BHA. Rig up and run 5-1/2" tieback string. Circulate out and cement the. 5-1/2" tieback casing, bringing cement up 400 - 500' above the liner top. Nipple down the BOP's, install 11" 5M x 11" lOM tubing spool and 2-7/8" pipe rams. /' ' Test BOP's `/" ~~0 ~ ` ~~ ~~ ~Ce.~c- ~ c.~'hhe~ ~oc-~b1~-..s~c~.c.~._. ~a~~4 Assuming the lOK BOP's are not needed, TIH PU 4-3/4" mill, 3-1/8" BHA, 2-7/8" DP and clean aut through the 5-1/2" tieback assembly. Test tieback string. Finish in hole to top of landing collar and circulate out. Displace out liner with 10.4 ppg KCL/CaCl fluid and filter same. ~~ ~~~ y~~~~ '~ h ~ ,.t +rc;C ~ ~c:~c3. v~ ~~ vzti \ ~ a ~~~ C~ Ue. p~~~~ ~~ ~ Rip up electric line, make GR/JB run to landing collar. ...i , -~ ~~~ ~s ~ MU and run perforating guns and production packer assemb7.y (on e-line if. possible, otherwise on work string}. Tie in same and seta POOH laying down work string or R/D e-line ag necessary. TIH, PU 2-7/8" production string. Space out same, add corrosion inhibitor and: land tubing hanger. ND BOP's, NU and test lOM WP tree. Perforate and test well. ., °°r,~,.,.. ` ~~ ~~ 1..~2~~ a rroces~ S `c,.~•s, t s ~~ c.c~t~...; F ~S~J`cs`~d ~. $~~` ~-'' so w~. ~~nrr o C ', r~ ~ `fC s~C~t~S~ ccc ...,.rr ~.~ ~~l~e- \\v~.ee .~ ~' co~c.c~~x~`~ ~ v,.~la4,~c-o e.t~4~ ors vi~~r~...oJ ~- pQt~o~~~w.5 ~wc~\` . ~~- ~~~~c' cccw~c~~n ~S 1 ~ ~~ ~;t,,l~'t:'~4, },~,rt; r.C7~- aS Svcs_e.~~.,~ c~.s c~eS`~ re~ key ~.~v~c~. c~.c.G.~~~~ llecember 27, 2005 ~ v~E~hC~.ti\C.~\ <`~^~~ (2~~~C~T-) iSO~u~lOr~. 'r~ 1C7~..C~O~ Z 5 ~~~ ~ ~'~C~ ~t~~~ ~,ir-~~Av.~~Ot~ Mr. John Norman, Chair pc+rc~vc~CS hV..7\v~` 3 ~-~j,~,,^S. C r„~P~oy1v~ a~~C,.M.s Alaska Oil and Gas Conservation Conuiiission uS ~~~ ~ ~ O C~ 333 West 7th Ave., Suite 100 ('~ ~ SE Sho~~c~ ~oF Sv~ictcr~~- Anchorage, Alaska 99501 RE: Application for Sundry Approval ~ ~ c~~+,,,` IVliddle Lake Unit #1-A (PTD No. 205-149) ~ ~'P~~OV4~ ~~ ~CC~.~~S P~Qo~.~~ Dear Mr. Norman, G~~ ~--~~~~~ ~a~a5-oS Forest Oil Corporation hereby applies for approval of a change to the previously- approved plans to drill a sidetrack of the MLU #1 well which was drilled and subsequently plugged and abandoned in 1969 by Gulf Oil Corporation. Unexpectedly high pore pressures in the targeted formations near TD have resulted in the need to set a different size liner in the open hole and tie it back to the surface to keep the formation pressure off of the existing 9-5/8" casing. Also, the order of same completion steps has been changed in order to ensure that the SDK psi WP BOPS being used do not get exposed to any open-hole pressures after the liner and tie-back are sel. lOK BOPE are proposed for use if the wellhore is to be opened to the formation before comple~i of the well. -''~` Since tying back the liner to surface was not originally participated, an additional casing spool will be required in the wellhead in which to land it. This wi11 result in the wellhead being too high to allow the BOP stack in its current configuration to fit under the rig floor. Authorization is therefore being requested to reduce the current A-BR-PR-PR configuration to one of A-BR-PR. Since there would be only one set of pipe rams in this configuration, Forest Oil will ensure that only one size of pipe will be nut through them on any individual trip and that the rams will be sized to the pipe being run. Please find attached information far your review: 1) Form 10-403 Application for Sundry Approval. 2) A note authorizuig the undersigned to sign this Application for the Operatar. 3) A summary of well operations to date. 4) A proposed Plan Forward. 5) A sketch showing the wellheadBOP stacking measurements under the rig. ~C~©~ fast ~$th ~~~~ni~e • .Rnc~ara~e ,4s~,,k~ ~95t1'~ • {~3r~ ~ .%~8-?~~ir ~ ~~,;:. (~C17j ~i 9.~7 ~t~ ~BQ P~dt~rtr~ ~~a~ Flc~t~ston P~r?~t+~~~Y ~~ t, ~ ~!it~ ~~~ ~ Ho~rstor~, 7Era:3~7~C~~~J ^ (2~1) ~~#~-~~ 1t ~ ~'~,~,~28~1`j ~s~:~'tr,8 f~#~~'",tl" ,dr~ Mr. John Norman - Page 2 If you have any questions or require additional information, please contact me at 258- 3446. Sincerely, FAIRWEATHI;R.E&P SERVICES, INC. ,~ ~. ,~`" t~ ~. -, t Bill Penrose Vice President /Drilling Manager enclosures cc: Roy Smith - Foresk Oil Ted Kxamer -- Forest Oil Re: Forest Oil MLU #lA BOP Test Preesur Subject: Re: Forest Oil MLU #lA BOP Test Preesure From: Thomas Maunder <tom maunder~~r`admin.state.ak.us> Date: ~fhu, 2~) Dec-~'i~O~ --8:59:09 -0900 To: Bill P~nr~sc ~=billi~i!fairwcather.conl> C'C: IZLSmith(~r'~f~~restoil.coi71 Bill and Roy, Thanks for providing this information. Based on the well data available, that test pressure should be sufficient. I would expect that the tree test would also be to 7000 at a minimum. Please note we would like to have an Inspector present for the l OK BOP test (if installed) and the tree test. I will finish my review of the sundry and move it forward recommending approval. Call or message with any questions. Tom Maunder, PE AOGCC Bill Penrose wrote, On 12/29/2005 8:43 AM: Tom, If 10K BOPE are installed on the MLU #1A well, it is Forest Oil's intention to use a 7,000 psi test pressure when testing them. This is safely in excess of the 5,740 psi maximum anticipated surface pressure resulting from the measured formation pressure and assuming an evacuated wellbore with a gas gradient. Regards, Bill 1 of 1 12/29/2005 9:06 AM Waste Disposal at MLU #lA ~ ~ Subject: Waste Disposal at :~~1 L,~i ;~ l ,~ From: Bill Penrose billi~clairweathce.com> Date: Thu, 2~) Dcc 2~iU5 I ~:=t?: I ~ -(i9OO To: tong «~~~underlci adi~lin.statc.~zk.us Tom, p~~ ~ ~ ~ ~~ I spoke with Bob Elder at Forest Oil this afternoon. He mentioned that they're currently disposing of their MLU #1A cuttings at the Mat-Su Borough landfill and the waste mud at the AWWU intake at Turpin and the Glenn Highway. He says it's working so well that there's a good chance they won't be pursuing the annular disposal option any farther than they have already. Thought you'd want to know. Also of interest, they submitted three samples of the old mud from shallow, medium-deep and deep parts of the well for metals analysis. Two samples had no detectable levels of chromium and one exhibited 3 units (don't know if it's ppm, mg/I or what) and the maximum allowable is 5 units, so they're okay that way. Bob says they're pretty sure from the analysis that it was a Cr-ligno mud, but the majority of the chromium must have altered or become sequestered somehow over the past 35 years. Something to remember. Regards, Bill 1 of 1 12/29/2005 4:00 PM Re: Forest Oil MLU #lA BOP Test Preesure • • Subject: Re: Forest Oil MLU #1:~ BOP Test Preesure From: Roy Smith <RLSmith ~forestoil.com> Datc: Thu, 2~) Dcc 2005 17:29:45 -t)?U~> ~~ ~ ~ - ~~-~~ TO: r~~10111 111EjUl1C{Cl~l(1-'7C~I11111.S1~il0.c`L}~.115~~~ '~ tQil1 llldU1lC~t,1~1,(1'~1C~C171I7.5t~ltC.il~.Uti-' Tom Bond log is good, we do not need to squeeze according to Schlumberger. -------------------------- Sent from my BlackBerry Wireless Handheld -----Original Message----- From: Roy Smith To: 'tc;ztt maur~derc=~adrr~..n.state.ak.us' Sent: Thu Dec 29 13:17:58 2005 Subject: Re: Forest Oil MLU #lA BOP Test Preesure Thank you! Hopefully we will have good bonding, should know something later today. Roy -------------------------- Sent from my BlackBerry Wireless Handheld -----Original Message----- From: Thomas Maunder To: Roy Smith Sent: Thu Dec 29 13:02:01 2005 Subject: Re: Forest Oil MLU #lA BOP Test Preesure Thanks Roy. I think this has all been resolved. The reasons for the change could be good news. Hopefully the bond log shows the desired isolation and no shots need be fired prior to being treed up. Good luck, Tom Maunder, PE AOGCC Roy Smith wrote, On 12/29/2005 10:58 AM: Thanks Tom and I will notify the rig of having a AOGCC representative on location during these test. Roy -------------------------- Sent from my BlackBerry Wireless Handheld -----Original Message----- From: Thomas Maunder To: Bill Penrose CC: RLSmith2forestoil . c;o;~: Sent: Thu Dec 29 10:59:09 2005 Subject: Re: Forest Oil MLU #lA BOP Test Preesure Bill and Roy, Thanks for providing this information. Based on the well data available, that test pressure should be sufficient. I would expect that the tree test would also be to 7000 at a minimum. Please note we would like to have an Inspector present for the lOK BOP test (if installed) and the tree test. I will finish my review of the sundry and move it forward recommending approval. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 2 12/29/2005 4:11 PM Re: Forest OiI MLU #lA BOP Test Preesure • • Bill Penrose wrote, On 12/29/2005 8:43 AM: Tom, If lOK BOPE are installed on the MLU #lA well, it is Forest Oil's intention to use a 7,000 psi test pressure when testing them. This is safely in excess of the 5,740 psi maximum anticipated surface pressure resulting from the measured formation pressure and assuming an evacuated wellbore with a gas gradient. Regards, Bill 2 of 2 12/29/2005 4:11 PM i F O R E S T O I L C O R P O R A T I O N •~ .3~0 C~ C~~~i*ne~ • C~~rfi~ X00 Y ,.~/ C~S~i/ar c~i,~t~~P , QxGta~Tr 9950 • ~JO~~ ,~58-8600 • ~00%) 2.8-86(/9 ~<?~a.r~ December 20, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7"' Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Middle Lake Unit #1-A a~~ - ~ ~~ Dear 1VIr. Norman, FZEC~!'~"~~: DEC 21 2005 Alaska Oil & Gas Cons.. ~;~~sa';4y.,-. Ancht3raga This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of December 13 through December 19, inclusive. December 13, 2005 RIH with cement mill and junk basket. Mill on junk and cement from 419' to 424'. POH and clean junk basket. Recovered `/z cup iron shavings. L/D mill, M/U bit on junk basket and RIH. Drill cement from 424' to 559'. Broke through, lost returns for 1 bbl then regained full circulation. Check for flow -well stable. Wash and ream from 559' to 1,828'. December 14, 2005 Wash and ream out 9-5/8" casing from 1,828' to 4,304'. Very thick mud with 20 units gas. Circulate mud through de-gasser. Wash and ream from 4,304' to 4,712'. Tag up at 4,712'. Drill settled-out barite and cement stringers from 4,712' to 4,783'. MW 12.1, Vis 60. C&C mud and POH. Empty junk basket -recovered '/4 cup iron. RIH with 8-1/2" bit and junk basket while P/U 4" drill pipe off pipe rack. December 15, 2005 P/LT 4" drill pipe and stand back in derrick. Wash and ream from 4,783' to 7,200'. December 16, 2005 Wash and ream from 7,200' to 8,600' without tagging anything. R/LJ cementing unit, pressure test lines and pressure test 9-5/8" casing to 4,800 psi for 30 minutes. Final pressure 4,600 psi -good test. R/D cementing unit and POH. M/U 9-5/8" casing scraper and RIH to 8,600'. December 17, 2005 C&C mud - MW in and out 12.2 ppg, vis 45. POH w/ casing scraper. R/U e-line and RIH w/ 8-1/2" gauge ring and 5-1/2" junk basket. Tagged up at 556' -could not get past. POH. M/U two 1-11/16" sinker bars on e-line assy and RIH. Still could not get past 556'. POH and R/D e-line. M/U 8-1/2" junk mill and 8-1/2" taper mill. RIH. Ream from 491' to 682'. Excess torque seen from 540' to 550'. Ream several times -cleared up. RIH to 8,600' w/ no problems. C&C mud and POH w/ no problems. December 18, 2005 Finish POH w/ junk mill and taper mill. Junk mill good, taper mill 1/32" under gauge, 2 finger-size pieces of cement in water courses of taper mill. R/U e-line w/ 8-1/2" gauge ring and 5-1/2"junk basket, RIH to 8,600' w/ no problems. POH. M/U 9-5/8" "E-4" CIBP on e-line and RIH. Set CIBP at 8,480', 4' above collar at 8,484'. POH Mr. John Norman Page 2 • • w/ e-line and R/D same. Test annular preventer to 250/3,500 psi, all other BOPE to 250/5,000 psi. M/U 9-5/8" whipstock assy on 4" drill pipe and RIH w/ same. December 19, 2005 RIH w/ 9-5/8" whipstock on 4" drill pipe. Tag CIBP at 8,479'. C&C mud until MW in and out is 12.2 ppg. M/U gyro and RIH surveying every 100' to 8,392'. Orient whipstock and set slips. Top of whipstock at 8,457'. POH w/ gyro and rig down same. Establish milling parameters and mill from 8,457' to 8,463'. If you have any questions or require additional information, please contact me at 868-2137 or Bill Penrose at 258- 3446. Sincerely, FOREST OIL CORPORATION ~~~ ~~~~ Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather ! ~- • • F O R E S T O I L C O R P O R A T I O N .3/0 ~~C~t~~~l • C~~urt~ X00 X907) ._~ ,-~~-a~6oo • ~.~or~ X58-~60~ ~~~:x 1 December 14, 2005 _ '~ ~~ Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 a ~ ~ ~ ~~~ Anchorage, Alaska 99501 RE: Weekly Report of Operations 1Vliddle Lake [Jnit #i-A Dear Mr. Norman, ®EC ~ ~ 2.005 Alaska Oil & Gas Cons. Co-nmissi Anchorage This is a report of Forest Oil Corporation's well operations on Middle Lake Unit #1-A for the week of December 6 through December 12, inclusive. December 6, 2005 Finish rigging up on location. Install wellhead. Pressure test wellhead and N/U BOPE. December 7,2005 Finish N/LJ BOPE and function test same. Fill and check circulating system on rig. Test BOPE to 250 psi low, 3,000 psi high. M/U wash-over/fishing assembly. December 8, 2005 Mill over 4-1/2" drill pipe stub in top of well. Make 1.5'. Shut down to install additional accumulator pump to yield acceptable accumulator pressure recovery time. Repair electrical problem on top drive. Continue milling over fish. Fluid level dropped away. Refill hole with 26 bbls of fluid. Monitor well -well static. M/LJ overshot and recover drill pipe stub (2.81' long). M/U wash pipe and shoe to wash over 9-5/8" casing. December 9, 2005 Wash over 9-5/8" casing. Tag collar at 40'. L/D wash string, M/U 8-1/2" cement mill. RIH, mill out cement inside 9-5/8" casing to 32.6' - bottom of cement. (Top of 9-5/8" casing is at 20.6' RKB.) POH, L/D mill, M/U spear. RIH, set spear in 9-5/8" casing. Pull 120k lbs, got 7" stretch. Release spear, POH. L/D spear, M/U 8-1/2" bit. RIH, wash to 310', tag hard cement. Drill cement to 315'. POH, L/D BHA, P/U 8-1/2' watermelon mill and knife blades. RIH and locate collars in 9-5/8" casing. POH, L/D mill and blades, M/U hydraulic backoff assembly. RIH. December 10, 2005 Attempt to back off top joint of 9-5/8" casing - no success. POH and L/D tools. M/U spear assy, RIH, set in 9-5/8" casing. R/IJ string shot, RIH through spear assy, locate collar. Put %2 round of reverse torque in spear assy and shoot string shot. Lost torque. POH w/ e-line and R/D same. Back out 9-5/8" casing and POH w/ same. Recovered • • Mr. John Norman Page 2 19.23'. Blow down lines, clear floor, P/LT 4" drill pipe, change bails on blocks, P/LT 9- 5/8" handling tools. December 11, 2005 Screw new joint of 9-5/8" casing into stub looking up and torque to 8,000 ft-lbs. Test 9- 5/8" casing to 2,000 psi - OK. P/U BOP's, set slips, make rough cut on casing, L/D stub, N/D 13-5/8" BOP's. Make final cut on casing and install 13-5/8" x 11" wellhead section. Test void to 2,400 psi. N/U 11" BOP's. j December 12, 2005 Finish N/LT BOP's. Test BOPE to 250 psi low, 5,000 ,psi high. Test witnessed by AOGCC rep. M/LT 8-1/2" bit and RIH. Tag cement at 313'. Drill hard cement from 313' to 419. Bit torqueing, POH to check bit. If you have any questions or require additional information, please contact me at 868- 2137 or Bill Penrose at 258-3446. Sincerely, FOREST OIL CORPORATION ~~~_ Ted Kramer Alaska Production Manager cc: Roy Smith -Forest Oil Bill Penrose -Fairweather r~r •, . ~ ~ ~ #~ ~ ~ ( ; , ~ ~~ FRANK H. MURKOWSKI, GOVERNOR 3~~ L>•is[f~-7~ OIL oisil Vr0-7 i~ 333 W. T" AVENUE, SUITE 100 COI~TSFiRQA'1'I011T CO1~I1~II55IOR ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Ted Kramer FAx (so7) 27s-7542 Alaska Production Manager Forest Oil Corporation 310 K Street, Suite 700 Anchorage, Alaska 99501 Re: Middle Lake Unit # lA Forest Oil Corporation Permit No: 205-149 Surface Location: 1923' FNL 8a 1142' FWL, Sec. 22, T15N, RSW, SM Bottomhole Location: 1764' FNL 8v 723' FWL, Sec. 21, T15N, RSW, SM Dear Mr. Kramer: Enclosed is the application for permit to redrill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Please note the following: 1. Samples and a mud log are not required for Middle Lake Unit # lA since this information was acquired in the original well. 2. Under separate cover an application has been made for annular disposal of drilling waste. Annular disposal of drilling wastes cannot be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. In order to acquire the necessary information, it is Forest's intent to pump into the 9-5/8" x 13- 3 / 8" annulus once the re-entry has commenced. Please have your representative contact the Commission's Inspector so that a witness may be present for that operation. 205-149 • 3. The blowout prevention equipment testing frequency for an exploration drilling operation is "less than 7-days". Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). BY ORDER OF THE COMMISSION DATED this day of November, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA5' OIL AND GAS CONSERVATION COMMI ION PERMIT TO DRILL ~•, 20 AAC 25.005 ~~~ rR''~ REC~li~6 ocr o z zoos ~~i`o 1 a. Type of Work: Drill Redrill Q Re-entry ~ 1 b. Current Well Class: Exploratory Deve I S 01081 f Oin Stratigraphic Test ~ Service ~ Develo ment Gas ~ Zone 2. Operator Name: Forest Oil Corporation 5. Bond: Blanket ~ Single Well ~ Bond No. ~~.~ ~ /~• C~• 11. Well Name and Number: Middle Lake Unit #1 i} 3. Address: 310 K Street, Suite 700, Anchorage, AK 99501 6. Proposed Depth: MD: 9,400' TVD: 9,050' ~ 12. Field/Pool(s): ~ _ ~~=~~' °r'`' 4a. Location of Well (Governmental Section): Surface: 1923' FNL, 1142' FWL, Sec 22, T15N, R5W, SM 7. Property Designation: ~'/~ ~~ ~ A 84 Q'3 Exploratory Top of Productive Horizon: 1824' FNL, 623' FEL, Sec 21, T15N, R5W, SM 8. Land Use Permit: 'C ~ N/A t~. 13. Approximate Spud Date: 11/1/2005 Total Depth: 1764' FNL, 723 FEL, Sec 21, T15N, R5W, SM 9. Acres in Property: 5,760 14. Distance to Nearest Property: -3.25 miles 4b. Location of Well (State Base Plane Coordinates): Surface:x- 472183 ' y- 2695742 Zone- AK-04 10. KB Elevation GL = 108' AMSL (Height above GL): 18.3 feet 15. Distance to Nearest Well Within Pool: N/A 16. Deviated wells: Kickoff depth: 8,550 feet ~ Maximum Hole Angle: 11.25 degrees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 6,216 psi Surface: 4,369 psi 18. Casing Program: Size Specifications Setting Depth Top Bottom Quantity of Cement c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6-3/4" 5-1/2" 20# L-80 Hyd. 521 1,200' 8,200' 7,869' 9,400' 9,050' 173 sx Class H 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 9,742 Total Depth TVD (ft): 9,403 Plugs (measured): See attached schem. Effect. Depth MD (ft): 0 Effect. Depth TVD (ft): 0 Junk (measured): N/A Casing Length Size Cement Volume MD TVD Structural 27' 30" Driven 27' 27' Conductor 281' 20" 425 sx 281' 281 Surface 2,958' 13-3/8" 1253 sx 2,958' 2953 Intermediate 8,880' 9-5/8" 900 sx 8,880' 8545 Production Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot ~ Shallow Hazard Analysis Property Plat ~ Diverter Sketch ~ Seabed Report ~ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name / Ted Kramer Title Alaska Production Manager Signature ~ ~~-- Phone 888-2137 Date 10/6/2005 Commission Use Only Permit to Drill ~ / Number: ~~~~'/7 ~ API Number: 50- ~~~ ~•~~Z-~ "" d~ Permit Approval Dafe: • ~~ ~ Q See cover letter for other requirements. Conditions of approval : rJ ,~ l ~Q~ ~~~ G ~ ~`~,~ ~ ~~ ~t~'S~C4~~~°\~'iCi~'~S~•~~ 'S'tC Sa ple re~uired Yes ~ No mud lag requires Yes ~ No ro n sulfide measures Yes ~ No ~ Directional survey required Yes ~' No Other: APPROVED BY ApNro THE COMMISSION Date: `~" ~ ~ Form 10-401 Revised 06/2004 "~' " UKI~INAL Submit inDuplicate Re: Shallow Salinity Profile, Middle Lake #1 Concerning Annular D... Subject: Re: ShallowSalinity Profile, Middle Lake r 1 Co~lc~i-nin~r ~~nnularI)isposal .application From: Stephen Davies -'stc~~cdavies a.,adir~instate.al:.us~= Date: Mon, ~ 1 Oct ?OOH 1 ~:02:~4 -0900 To: Thomas i~~launder ~~~~totn maunder(~i,admin.state.ak.us== CC: Daniel Se~monnt <dan seamount~u admin.statc.ak.us= Tom, In response to Forest's application for annular disposal in the Middle Lake Unit No. 1 well, I took a quick look at the salinity distribution in the shallow sands. Forest's petrophysicist analyzed salinity in only the two target injection sands (3,182 to 3,188 feet and 3,432 to 3,439 feet) using the SP curve. Forest's analysis indicates that the salinity in these two sands exceeds 10,000 ppm TDS, but their analysis did not mention that gas was present in the mud and cuttings below 2660' measured depth ("MD"). As you know, gas can affect well log readings and calculated salinity values. To confirm their findings, I took a slightly different approach and used both the SP and Rwa methods to calculate salinity in 8 sand intervals between 1728' and 3736' MD. I utilized the available dual induction and sonic well logs as well as the mud log. I concur with Forest's findings. My analysis indicates that the salinity of all sands below 2700' MD exceeds 3,000 ppm TDS, and in all likelihood the salinity of the target injection sands exceeds 10,000 ppm TDS. In addition, gas indicated on the mud log from 2660' MD to the total depth of the well indicates that none of the sands below 2660' MD could be reasonably expected to supply a public drinking water system. Please let me know if you have additional questions. Thanks, Steve Davies Thomas Maunder wrote: ', Reply from Bill. Another message to follow. -------- Original Message -------- Subject: RE: Middle Lake #lA--annular disposal application Date: Tue, 11 Oct 2005 16:26:48 -0800 From: Bill Penrose <bill~fairvaeather.com> To: Thomas Maunder <tom maunder.~admin.state.ak.us> CC: TE~ramer~forestoil.c~om, RLSmith~forestoil.com, Bob Elder <RGEldert~;forestoi.l.. corn> Tom, 1. See the attached mud weight curves from the original MLU #1 and offsetting well Bell Island Unit #1. On them I've drawn a frac gradient curve that I used for the frac pressure at the MLU #1 13-3/8" shoe. To draw them, I assumed conservatively that the pressure jump typically seen at the top of the Bell Island sand goes up to close to the frac gradient at that depth and I drew a characteristic curve from there to the surface. I checked the values on the curve against the frac gradients being seen in Aurora Gas' fields around Tyonek and with Forest Oil's West Foreland Unit. Aurora's frac gradients are abnormally high and didn't agree at all. The West Foreland information correlated very well. All-in-all, I decided that my original approach and its agreement with West Foreland justified the rejection of the comparison with the anomalous Aurora data. This approach also yields a more conservative frac gradient than Aurora's. 2. The possibility of needing to use diesel in the annulus comes from my using an abundance of caution. If Forest has the annulus full of flush 1 of 3 10/31/2005 2:47 PM Re: Shallow Salinity Profile, Middle Lake #1 Concerning Annular D... • • water used to chase mud and cuttings down to the shoe, then has to shut down the rig for a significant period of time during the planned winter operations, they may feel it prudent to freeze protect once or twice. '. Probably won't happen, but they don't want to get in trouble for injecting an un-authorized fluid. 3. See the attached Location Clearance wherein LCS (Lonnie Smith?) indicates that the wellhead was cut off and a marker post installed. Also see the photo showing the estimable Mr. Pat Prout standing next to said marker post. 4. The attempt to pump into the 9-5/8" x 13-3/8" annulus will occur at some point before rigging up on the well so that Forest will know if AD is an option. The exact timing is not known right now, however. The wellhead will have to be obtained and access with that equipment will have to wait until the ground is frozen. The site is accessible by foot, but vehicular traffic would tear up a boggy area the original road has settled into. 5. We have not attempted to calculate salinities anywhere else in the well, but could do so providing the necessary log data exists across those additional intervals. 6. The other plan for waste disposal is to de-water the cuttings and test them and the liquid phase for acceptability at the Mat-Su landfill and sewage processing facility, respectively. If they fail the testing, both phases will be transported to Forest's permitted West Foreland facility for disposal. The ability to pump into this annulus after all this time is a question large in everyone's mind. However, on the chance that it can be done is too good an option to pass up - hence this application. If Forest can't gain access through this annulus, you'll be the first to know and can drop everything. On the other hand, if Forest is successful in establishing injection, again you'll be the first to know and we'll be sure to top off your data needs at that time so there's not too much more work permit-wise. to do at the last minute. Regards, Bill -----Original Message----- From: Thomas Maunder [mailta:tom maunder~admin.sta~e.ak.us] Sent: Tuesday, October 11, 2005 2:00 PM To: Bill Penrose; Ted Kramer Subject: Middle Lake #lA--annular disposal application Bill and Ted, I am examining the sundry application for annular disposal. A couple of questions and an observation. 1. How was the formation pressure determined at the 13-3/8" shoe? I have looked at the file and do not see a value noted in it. 2. Diesel is mentioned for "freeze protection". Will it be necessary to freeze protect when the well is operating? 3. was the well head ever removed? Based on the file as I read it, the shallowest cement plug in the well is at 150' and I cannot find any notation that the wellhead was ever cut off. By the regulations, that makes the well actually suspended however that is not an issue for you all. 4. When will an attempt be made to pump in to the 13-3/8" x 9-5/8" annulus? Is the location accessible now? 5. Has the salinity been calculated at depths other than the 2 intervals provided? Do you have any information on the depth where salinity goes above 2 of 3 10/31/2005 2:47 PM Re: Shallow Salinity Profile, Middle Lake # 1 Concerning Annular D... • • 10000 ppm? 6. What is your contingency plan for waste disposal? Cleaning out the 9-5/8" casing and performing the sidetrack as you plan is something that can reasonably expected to be accomplished. Pumping into an annulus that from all available information I have reviewed hasn't been "touched" since late 1st Q 1969 and by the reports had 13.1 ppg mud in the hole when the 9-5/8" casing was set is not so certain. Reclaiming or reactivating "old" annuli has not generally been a successful operation in the few wells where it has been attempted. Tom Maunder, PE AOGCC 3 of 3 10/31 /2005 2:47 PM • ~ PLUGGING & LOCATION CLE~~CE REPORT State .of Alaska ALASKA OIL t cA3 CONSERVATION COI~II2ZSSION File: a\lc-apfm Rev.: 24may95 PTD No.G 8- ll0 Lease /~f,~. 2~(~L~- Memorandum To File: API No. 2~~3 - 2~~~i - ~O Well Name /~jid CJ / !Q L.ak~, ~pUl_c~ ~ Operator ~~ r-~ ~~ ~ o- ,p Location _ _~~ ~ 2 2, , 7-~ ~= S Abnd Date ~~ Spud : f' ~ 0 ~ , TD : 97y 2 , Completed __~~-$ Note casing size, wt, depth, emt vol, 6 procedure. sfc csq: ~3 '~/~ 6/ ~) @ 2 ~.~ ~r~ f Z-5 ~ ~~ s Long Csg: ~ ~~ ~f- `z ~[j! ~ 8 ~~9d . ~~ ~ ~.. Liner: Perf intervals - tops : ' • ®~ Y C7 ~ Big } Aj 7v/ (,~ t Aeview the well file, and comment on plugging, well head status, and location clearance -provide loc. clear. code. Plugs : ~j ~ r~ ~ ~ 3©0` r~,~ is~U ~~ "7'©c ~ 8 ~ T ~ ` -rte' LE-S dc5 - ~ 3 Z>J ~ ~foo ~l.S-o Well head cut off : tl ~S Marker poet or plate: ~.~o~ Location Clearance : L.G ~Jv G, C S I ~/(6 <'7/ Conclusions : Lc~o I i. (~/b Code G ') Signed ~ ~+ '~~ Date ~2''fl~S- r • •' October 6, 2005 F O R E S T O I L C O R P O R A T I O N .3~0 ~~~CS~t~.e~ . C-?Suite X00 ~~r~c~io~~~e, C~~-~a,~cc~ 9950'/ ~90~~ z58-86ao • ~9o7J X58-860 ~~ax~ Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ~~ T ~ ' Alaska ~ 2005 Oil $ Oas Cons, An~~~aAe Ca~tnissl~rr RE: Application for Permit to Drill: Middle Lake Unit #1-A (Sidetrack of MLU #1) Dear Mr. Norman, Forest Oil Corporation hereby applies for a Permit to Drill an onshore gas exploration well near Point McKenzie, opposite Anchorage. The well is planned as a re-entry and sidetrack of the existing MLU #1 wellbore which was drilled and subsequently plugged and abandoned in 1969 by Gulf Oil Corporation. While Gulf had been searching for oil and the well proved a disappointment, Forest Oil sees gas production potential in the logs of some of the deeper horizons penetrated by Gulf. Forest Oil will noty be penetrating any formations not previously drilled by Gulf in the original well. The sidetrack proposed here is intended to provide access to some of .the same intervals undamaged by 36 years of exposure to the original drilling fluid. The anticipated date of commencement of operations on MLU # 1-A is approximately November 1, 2005. ~ Coil'{ ~~ t~,\7 The MLU # 1-A sidetrack will be kicked off in the existing ~9-5/8" cemented casing at a depth of 8,500'MD. ° A 6~,/~' hole will be directionally drilled to a TD of 9,400'MD in the Lower Tyonek Formation and a 5-1/2" liner set and cemented. r Waste drilling fluids and ground cuttings will be disposed of via annular injection down -- the 9-5/8" X 13-3/8" annulus. An Annular Disposal Application will be submitted under separate cover. If for some reason injection down that annulus proves to be not possible, the drilling fluids and cuttings will be disposed of at a permitted facility. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill. 2) Fee of $100.00 payable to the State of Alaska. 3) A plat showing the surface location of the well. 4) A Time versus Depth plot. 5) A directional plat and listing showing the well's proposed surface and bottomhole locations and intended wellbore path. 6) Diagrams and descriptions of the BOP equipment to be used. • • Mr. John Norman Page 2 7) A complete proposed casing program. 8) The cementing program. 9) The drilling fluid program. 10) The proposed drilling program. 11) A Summary of Drilling Hazards. 12) Schematic of the existing wellbore. 13) Schematic of the proposed wellbore and completion. 14) Forest Oil does not anticipate the presence of H2S in the formation to be r encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during sidetracking, drilling and completion operations. 15) The following are Forest Oil's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Roy Smith, Drilling Superintendent (20 AAC 25.070) (303) 864-6159 2) Geologic Data and Logs Larry Casarta, Senior Geologist (20 AAC 25.071) (907) 868-2142 If you have any questions or require additional information, please contact me at (907) 868-2137 or Bill Penrose at (907) 258-3446. Sincerely, FOREST OIL CORPORATION .~i/ ~ "~_ Ted Kramer Alaska Production Manager enclosures cc: Roy Smith -Forest Oil Bill Penrose -Fairweather • • • • Forest Oil Corporation MLU #1-A Redrill Sidetrack Procedure Prior to moving in drilling rig, excavate around casing stubs and install cellar. Check for pressure in all casing annuli, hot-tapping if necessary. Trim casing stubs and install casing head. Test casing head to 50% of collapse rating of 13-3/8" casing. 2. Move in, rig up drilling rig. Spear 9-5/8"casing stub and pull up into wellhead. Install slips and packoff. Install 13-5/8" X 11", SK tubing spool and test to 50% of collapse rating of 9-5/8" casing. 3. N/U 11", SK BOPE. Test annular to 3,500 psi and all rams to 5,000 psi. Mix new 13.1 ppg mud system. ~ `~ ~~,.-~~-~5.~ .fin ~~~~ ASS 4. P/U an 8-1/2" cleanout assembly and RIH. Clean out 9-5/8" casing to 8,550' MD, isolating old mud left in wellbore for disposal. Test 9-5/8" casing to 3,000 psi and POH. 5. Make scraper run to 8,550'. POH. Make gauge ring /junk basket run to 8,550'. i5r a- 1 POH 6. Set CIBP 4' above casing collar closest to 8,550'. Run cased-hole gyro. 7. M/LJ whipstock /milling assembly and RIH. Tag CIBP, orient and set down to set whipstock. Shear out milling assembly. 8. Mill window in 9-5/8" casing using 6-1/2" starter and watermelon mills, deflecting off whipstock. POH. 9. M/LJ 6" bit on directional drilling assembly and RIH. Conduct leakoff test at the casing window. 10. Using water-base mud system, directionally drill6 ~4" hole from 8,550' to 9,400' MD, TD. ` 11. Run open-hole logs. 12. Run and cement 5-1/2", 20#, L-80, Hydri11521 / LTC liner at 9,400' MD with TOL at approximately 8,200' (350' of lap). Set the liner-top packer. • • 13. Make clean-out runs in the 9-5/8" casing and the 5-1/2" liner. Run cement bond log `" in 5-1/2" liner. 14. Complete well as a gas producer. 15. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig. • • Forest Oil Corporation Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks Middle Lake Unit #1 Drilling Fluid Properties: 6-3/4" Hole Section (8,500' - 9,400' MD) 8,167' - 9,061' TVD Density 10.4 - 14.0 l YP 15 - 25 API Fluid Loss 5 - 8 Chlorides <1,000 H 9.0 Drilling Fluid System: Two Derrick Shale Shakers Pit Level Indicator Visual and Audio Alarms Desander, Desilter, Mud Cleaner Tri Tank Centrifu a Fluid Flow Sensor De asser Fluid A itators Maximum Anticipated Surface Pressure: 6-3/4" Hole Section The maximum anticipated surface pressure (MASP) for the 6-3/4" hole section in this sidetrack will be the lesser of the formation pore pressure (less a full gas column to the surface) at the 5-1/2" liner setting point or the formation fracture pressure at the window in the 9-5/8" casing (less a full gas column to the surface). Based on previous drilling data in this well, the highest formation pressure expected in this 6-3/4" hole section is 6,220 psi at the section. TD of 9,061' TVD (or 0.686 psi/ft). `An FIT conducted in this well when it was originally drilled indicates a minimum fracture gradient at 8,167' TVD (the 9-5/8" window depth) is 0.645 psi/ft. Complete evacuation of the wellbore, except fora 0.11 psi/ft gas gradient, is assumed. 6-3/4" hole section MASP (pore pressure) _ MASP (fin breakdown) _ (9,061 ft)(0.686 - 0.11) = 5,219 psi (8,167 ft)(0.645 - 0.11) = 4,369 psi ` Therefore, MASP in the 6-3/4" open hole section is 4,369 psi and the 5,000 psi BOPE system to be used will be adequate. • • Well Proximity Risk: The closest wellbore to this one is the plugged and abandoned Susitna State #1 located approximately 3-1/2 miles to the ENE. There are no wellbore proximity risks presented. Drilling Area Risks: Since the MLU #1 sidetrack will penetrate the same strata in the same place as the original wellbore, there is little risk of encountering unexpected conditions. 'The most significant risk indicated during the drilling of the original well is the rapid increase in pore pressure from +10.4 ppg to +14.0 ppg at the bottom of the Bell Island sand at 9,000'. The drilling crews will be advised to expect this and have been trained to react to It. r Disposal of Muds and Cuttings: --. An annular injection permit is being sought separately for disposal of waste fluids and ground cuttings down the 9-5/8" X 13-3/8" annulus. Drilled cuttings will be ground at the drilling location and injected down the annulus as will all waste wellbore fluids. If for some reason injection down that annulus proves to be not possible the drilling fluids and cuttings will be disposed of at a permitted facility. c, M \ ~ v,1. S~J~`~ ~ ~ ~~ ~ • • Forest Oil Corporation Cementing Program Middle Lake Unit #1 The 5-1/2", 20#, L-80, Hydril 125 / LTC liner will be cemented as: 350' of 5-1/2" X 9-5/8" lap 850' of 5-1/2" X 6-3/4" open hole 80' of cemented 5-1/2" shoe track Spacer 50 bbls Mudpush II at 16.5 ppg Cement 173 sacks of Class H + fluid loss additives + retarder, mixed with fresh water Cement Properties Weight 16.4 ppg Yield 1.07 cf/sx Water 4.01 gaUsx Pump Time 4:00 hrs Water Loss <100 cc Free Water <1% Compressive Strengths 12 hours 1,500 psi 24 hours 2,750 psi Excess 25% in open hole only Forest Oil Corporation Middle Lake Unit #1 Casing Performance Properties Size Weight in. l~ b/ft) Grade Cnxn 9-5/8 47 5-1/2 20 N-80 BTC L-80 H521 Casing Properties and Design Verification Internal Collapse Tensile Strength Yield Resistance Joint Body TVD MD Design Safety Factor* si si 1 OOO lbs f ft RKB~ (ft RKB) T B C 6,870 4,750 1,161 1,086 8,167 8,500 N/A 1.57 N/A 9,190 8,830 428 466 9,061 9,400 21.17 6.01 1.58 * Tensile design safety factor for 5-1/2" liner is calculated using pipe weight less buoyancy. Tension safety factor for 9-5/8" casing is not calculated because it is already cemented in place. Burst design safety factor for the 5-1/2" liner is calculated at the depth of the 9-5/8" casing window using the expected normal pore pressure at the 9-5/8" window on the outside and maximum expected mud weight to be used at TD on the inside. Burst safety factor for 9-5/8" casing is calculated at the surface using zero backup on the outside and MASP on the inside. Collapse design safety factor for the 5-1/2" liner is calculated at the 5-1/2" shoe using the maximum expected mud weight to be used at TD on the outside and the entire cased hole evacuated except for a gas gradient on the inside. Collapse safety factor for 9- 5/8" casing not calculated because it is already cemented in place. Casing Setting Depth Rationale • 5-1/2" 9,400'MD / 9,061'TVD Production liner to stabilize producing interval for production operations. 11 " 5k PSI GK ANNULAR BOP SCREWED HEAD FLANGED BOTTOM CONNECTION 2-1/16' GATE VAi 2" CHOKE LINE 2-1/16" #5000 GATE VALVE 11 " 5k PSI DOUBLE GATE PREVENTOR 2-1/16" #5000 STUDDED CONNECTION GATE VALVE ___ _ _ 11 " 5000# API 2" KILL LINE ~ FLANGED MUD CROSS 11 " 5k PSI HYDRAULIC RAM SINGLE GATE STUDDED CONNECTION 2-1/16" #5000 GATE VALVE i i" BLOW-OUT PREVENTOR `~~C ~~-~, ~~ ~~ ~ `~ 3 RAM STACK CONFIGURATION J i ~E C Get J XL UJN J XL VJA Middle Lake Unit #1-A Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE ~ The 6-3/4" hole section will be drilled through the Lower Tyonek Formation which in this area contains elevated pore pressures as high as 14.0 ppg. Higher mud weights will be used in this interval to control the well. ~I There are no other wells nearby to interfere with this wellbore. ~I There is no H2S risk anticipated for this well. CONSULT THE MLU #1-A WELL PLAN FOR ADDITIONAL INFORMATION ', ~; 10 Middle Lake # 1 9/15/2005 MIDDLE LAKE # 1 DAYS VS DEPTH i I' ', DAYS o~ 500 - 1000 - 1500 r 2000 2500 i 3000 -} 3500 -~ ICI 4000 -~ ~ 4500 ~i '"' I = 0 500 H W 5500 ~ f7 ~ 6000 ~ , 6500 ~ - - 7000 I 7500 8000 7 ~ R ig up, cle an out 9 5 /8" an d s et Whi pst ock 85 0 0 9000 ~ ~ TD ~ 9,400' MD/ 9,061'ND 9500 10000 - i 0 5 10 15 20 25 30 35 -PLAN FACTUAL : <. ~.;, _ __ ......., ,. FOREST OIL CORPORATION • • ~~~cJ • • ~~~° Forest Oil Corporation ~'~ MIDDLE LAKE # 1 SEC 22 T15N R5W Antic. Spud Date: 9/1/05 Elevation 111 ft Prop. Total Depth: 9,400 'MD 9,400 'TVD Expected RKB-MWL: 25 ft surf. Loc.: Lat. 61.37832 BH Loc.: Long. 150.1586 objective: Re-entry, Sidetrack off Whipstock, Drill to 9,400' and Evaluate. E Logl Mud Log/ Drill Depth, Ft. Dimensions, TV Depth, MW, Directional Info Casing Specs. Referenced to RKB ', Well Control I In. Ft ppg FG, ppg 0 0 0 **"'Already Set 30 Drive Pipe 27 Driven 27 - - 0.63 "Wall Thickness 0 i 26 Diverter Hole Size Set ~ 20 Conductor 94.0 #, H110 Buttress Set 13 318 Surface 61.0 #, K-55 Buttress 8,500' 9 5181ntermediate 47.0 #, N-80 LTC Quad Combo (Ind., NGT,Den,Neu,Sonic) Possible MDT 281 281 0.0 0.0 0 Diverter ~ 17 1/2 i Hole Size System I 2,958 2,958 i 0.0 0.0 13 5I8 5,000 Annular 13 5/8 5,000 BOPS 12 1/4 Hole Size TOL 8,200 I 8,500 13.0 16.8 13 5/8 5,000 Annular 13 518 5,000 BOPS ~ ', Pre-Tyonek 8,880 0 0 5 112 Production 9,400 20.0 #, L-80 Hydril521/LTC PTD 6 i/9r Hole Size 8,524 0 9,061 13.2 17.5 Forest Oil Corp. Location: West Cook Inlet, Alaska Slot: Slot #1 Field: Sec 22, T15N, RSW, SM Well: Middle Lake River Unit #1 Installation: Middle Lake River Unit #1 Wellbore: Middle Lake River Unit #1 St #1 Scale 1 cm = 20 ft East (feet) -> -1920 -1880 -1840 -1800 -1760 -1720 -1680 -1640 -1600 240 ~ 7900 u E U .- 8000 U ~ 8100 8200 8300 8400 8500 - ..~ t fl. 8600 - d ~ - ~ 8700 - V ~ 8800 d ~ - L ~ 8900 - V 9000 9100 9200 9300 9400 9500 t S f f I Top of Whipstock Milled Depth EOC Top of Sands Gg~u ~~\`L ~~ ~y'L ~...w.s., a5 5a° °~ o`` y~~o, ,~oQ Ga ~,~\`L ~ ~~ .~ G~5` _ ~~0 y~c 0 .:..Q 200 160 n 120 C 3 80 ~D 40 m 0 n 3 I N O -40 x WELL PROFILE DATA PoIM MD Inc Azi ND North East degl100R V. Sec[ Tie on 8500.00 6.60 291.26 8166.84 60.79 -1700.33 0.00 1699.70 End of Build/Tum 8520.00 8.85 300.95 8186.66 62.00 -1702.72 12.93 1702.18 End of Build 8600.00 11.25 300.95 8265.42 69.17 -1714.69 ~ 3.00 1714.69 End of Hold 8950.00 11.25 300.95 8608.70 104.28 -1773.23 0.00 1775.87 T.D. & End of Hold 9400.00 11.25 300.95 9050.06 149.41 -1848.50 0.00 1854.53 r~.~ BAKER HUGHES INTFQ Created by: Planner Date platted : 23SeP~2005 Plot reference is Mitldle lake River Unit #t St #1. Ref wellpath is Middle Lake River Unit #1 St #1 Vers/ #1 A. Coordinates are in feet reference Slot #1. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Nabors #129 Rig Datum to Mean Sea Level: 108.00 ft. Plot North is aligned to TRUE North. 1600 1700 1800 1900 2000 2100 2200 Scale 1 cmy~f f~lcai Section (feet) -> Azimuth 274.62 with reference 0.00 N, 0.00 E from Slot #1 Forest Oil Corp.,Slot #1 Middle Lake River Unit #1, Sec 22, T15N, R5W, SM,West Cook Inlet, Alaska • #1 Wellpath: Middle Lake River Unit #1 St #1 Vers/ #1A INTEQ Date Printed: 23-Sep-2005 Wellbore Name Created - Las Revised - Middle Lake River Unit#1 St #1 15-Au -2005 31-Au -2005 Well Name Government ID Las Revised Middle Lake River Unit #1 12-Au -2005 Slot Name Grid Northin Grid Eastin Latitude Lon itude North t Slot #1 2695741.6965 472182.7707 N61 22 41.5600 W150 9 30.9600 O.OON 0.00E Installation Name Eastin Northin Coord S stem Name North Ali merit Middle Lake River Unit #1 472182.7707 -= 2695741.6965 AK-4 on NORTH AMERICAN DATUM 1927 datum True ' ..Field Name Eastin Northin Coord S stem Nam North Ali nmenf Sec 22 T15N R5W SM 472182.7707 2695741.6965 AK-4 on NORTH AMERICAN DATUM 1927 datum True C - -- --- - omments All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and ND's are from Rig (Nabors #129 108.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 274.62 degrees Bottom hole distance is 1854.53 Feet on azimuth 274.62 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated C7 Forest Oil Corp.,Slot #1 Middle Lake River Unit #1, Sec 22, T15N, R5W, SM,West Cook Inlet, Alaska • #1 Wellpath: Middle Lake River Unit #1 St #1 Vers/ #1A Date Printed`. 23-Sep-2005 ~i/~ 1NTEQ Well ath G rid Re ort MD(ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East(ft] Dogleg.. de 7100ft Vertical S coon ft Fasting Northing 8500.00 6.60 291:26 8166.84 60.79N 1700.33W 0.00 1699.70 470482.77 2695806.61 8520.00 8.85 300.95 8186.65 62.OON 1702.72W 12.93 1702.18 470480.38 2695807:82 8600.00 11.25 300.95 8265.42 69.17N 1714.69W 3.00 1714.69 470468.43 2695815.03 8700.00 11.25 300.95 8363.50 79.20N 1731.41 W 0.00 1732.17 470451.73 2695825.10 8800.00 11.25 300.95 8461.58 89.23N 1748.14W 0.00 1749.65 470435:03 2695835.17 8900.00 11.2 300.95 8559.66 99.26N 1764.87W 0.00 1767.13 470418.33 2695845.24 8950.00 11.25 300.95 $608.70 104.28N 1773.23W 0.00 1775.87 470409.98 2695850.27 9000.00 11.25 300.95 8657.74 109.29N 1781.59W 0.00 1784.61 470401.63 2695855.31 9100.00 11.25 300.95 8755.82 119.32N 1798.32W 0.00 1802.09 470384.93 2695865.38 9200.00 11.25 300.95 8853.90 129.35N 1815.05W 0.00 18.19.57 470368.23. 2695875.45 9300.00 11.25 300.95 8951.98 139.38N 1831.78W 0.00 1837.05 470351.52 2695885.52 9400.00 11.25 300.95 9050.06 - 149.41 N 1848.50W 0.00 1854.53 470334.82 2695895.58 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nabors #129 108.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 274.62 degrees Bottom hole distance is 1854:53 Feet on azimuth 274.62 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hugheslncorporated Forest Oil Corp.,Slot #1 Middle Lake RiverUnit #1, Sec 22, T15N, R5W, SM,West Cook Inlet,. Alaska ~~ #1 Wellpath: Middle Lake River Unit #1 St #1 Vers/ #1A Date Printed: 23-Sep-2005 INT)EQ Comments MD TVD N rth ft East ft Comment 8500.00 8166.84 60.79N 1700:33W To of Whi stock 8520.00 8186.65 62.OON 1702.72W Milled De th 8600.00 8265.42 69.17N 1714.69W EOC 8950.00 8608.70 104.28N 1773.23W To of Sands 9400.00 9050.06 149.41 N 1848.50W Est. TD / 5 1/2" CS Hole Sections 'Diameter Start Start Start Start End End End Start Wellbore in MD ft TVD ft North ft East ft MD ft TVD ft North ft East ft 6 1/2 8500.00 8166.84 60.79N 1700.33W 9400.00 9050.06 149.41 N 1848.50W Middle Lake River Unit #1 St #1 Casin s Name Top MD$ Top TVD ft Top North ft Top East ft Shoe MD ft Shoe TVD ft Shoe North ft Shoe East ft Wellbore 30" Conductor 0.00 -312.69 27.00 -285.76 Middle Lake River Unit #1 20" Casin 0.00 -312.69 281.00 -32.45 Middle Lake River Unit #1 13 3/8" Casin 0.00 -312.69 2958.00 2637.25 Middle Lake River Unit #1 9 5/8" Casin 0.00 -312.69 9742.00 9402.77 93.19N 1815.90W Middle Lake River Unit #1 5 1/2" Casing 8300.00 7968.29 51.08N 1678.45W 9400.00 9050.06 149.41 N 1848.50W Middle Lake River Unit #1 St #1 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nabors #129 108.Oft above Mean Sea Level ) Vertical Section is from O.OON 0.00E on azimuth 274.62 degrees Bottom hole distance is 1854.53 Feet on azimuth 274.62 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Middle Lake River Unit#1 St #1 Vers/ #1A, Middle Lake River Unit #1 St #1 Slot #1, Middle Lake River Unit #1 • CLEARANCE LISTING Page 1 Date Printed: 23-Sep-2005 Sec 22, T15N, R5W, SM, West Cook Inlet, Alaska Ellipse separations are reported ONLY if BOTH wells have uncertainty data Ellipse error terms are CORRELATED across ties between tools of the SAME CLASS Cutoff i5 calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casings ARE included Hole size/Casings ARE subtracted from Centre-Centre distance Ellipses scaled to 2.OOstandard deviations. Closing Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0:00) Report uses Revised: (D-C)/E Factor Calculation itty It >r.~ Wellbore Name Created Last Revised Middle Lake River Unit #1 St #1 15-Au -2005 31-Au -2005 Well Name G vemment ID Last Revis d Middle Lake River Unit #1 12-Au -2005 Slot Name Grid Northin Grid Eastin Latitude Lon itude North East Slot #1 2695741.6965 472182.7707 N61 22 41.5600 W150 9 30.9600 O.OON 0.00E Installation Name Eastin Northin Coord S stem.Name N Ai m Middle Lake River Unit #1 472182.7707 2695741.6965 AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Eastin Northin Goord S stem Name ort li nm nt Sec 22 T15N R5W SM 472182.7707 2695741.6965 AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance Summa Offset Offset Offset Offset Minimum MD(ft] Diverging Ellipse Ellipse Clearance Clearance WeIlName Wellbore Slot Structure Distance From[ftJ Separation. MD[ft]• Factor MD[ft] ft ft Middle Lake Middle Lake Slot #1 Middle Lake -0.67 8500.00 8500.00 River Unit #1 River Unit #1 River Unit #1 All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Nabors #129 108.Oft above Mean Sea Level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Casings Included Prepared by Baker Hughes Incorporated • Middle Lake River Unit#1 St #1 Vers/ CLEARANCE LISTING Page 2 ~~~ #1A, Middle Lake River Unit #1 St #1 Date Printed: 23-Sep-2005 Slot #1, Middle Lake River Unit #1 Sec 22, T15N, R5W, SM, West Cook INTEQ Inlet, Alaska C learance Data Reference Reference Reference Reference. Offset Well Offset Offset Offset Offset Angle Closest Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Approach Separation Highside Distance (ft] de 8500.00 .8166.84 60.79N 1700.33W Middle Lake 8500.00 8166.84 60.79N 1700.33W 159.4 -0.67 River Unit #1 8520.00 8186.66 62.OON 1702.72W Middle Lake 8519.99 8186.70 61.64N 1702.41W -161.8 -0.20 River Unit #1 8600.00 8265.42 69.17N 1714.69W Middle Lake 8599.78 8265.92 63.99N 1711.47W -152.8 5.45 River Unit #1 8700.00 8363.50 79.20N 1731.41W Middle Lake 8698.89 8364.37 65.55N 1722.75W -153.2 15.52 River Unit #1 8800.00 8461.58 89.23N 1748.14W Middle Lake 8798.78 8463.76 67.96N 1732.39W -157.4 25.89 River Unit #1 8900.00 8559.66 99.26N 1764.87W Middle Lake 8897.25 8561.75 69.27N 1741.86W -158.3 37.19 River Unit #1 8950.00 8608.70 104.28N 1773.23W Middle Lake 8948.26 8612.48 70.02N 1746.88W -158.5 42:72 River Unit #1 9000.00 8657.74 109.29N 1781.59W Middle Lake 8997.55 8661.54 71.86N 1751.26W -159.9 47.66 River Unit #1 9100.00 8755.82 119.32N 1798.32W Middle lake 9096.61 8760:14 74.49N 1760.36W -161.1 58.24 River Unit #1 9200.00 8853.90 129.35N 1815.05W Middle Lake 9196.20 8859.25 77.48N 1769.57W -162.1 68.52 River Unit #1 9300.00 8951.98 139.38N 1831.78W Middle Lake 9297.09 8959.66 81.44N 1778.55W -163.5 78.38 River Unit #1 9400.00 9050.06 149.41 N 1848.50W Middle Lake 9395.41 9057.49 83.17N 1788.11 W -163.3 89.28 River Unit #1 Offset Wellbore Surve Tool Pro rams Well Wellbore Surve Name MD ft Surve Tool Error Model Middle Lake River Middle Lake River Unknown Survey <2965 - 9742'> 9742.00 No Tool No Model Unit #1 Unit #1 All data is in Feet unless otherwise stated Coordinates are from Slot and ND's are from Rig (Nabors #129 108.Oft above Mean Sea Level ) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 95.45 (1 D) Casings Included Prepared by Baker Hughes Incorporated ~i.~ w ~ vow Forest Oil Corp. Location: West Cook Inlet, Alaska Slot: Slot #1 Field: Sec 22, T15N, RSW, SM Well: Middle Lake River Unit #1 Installation: Middle Lake River Unit #1 Wellbore: Middle Lake River Unit #1 St #1 Createtl by Planner Date plottetl: 23Seµ2005 Plot reference ~ Mitl01e LaKe River Unit#7 St#1. Ref vellpath is MitlCle Lake River Unn #1 St #1 Vers/#1A Coordinates are in feet reference Slot #7. True Vertifal Depths are reference Rig Datum. Measuretl Depths are reference Rig Datum. Rg Datum: Nabors #129 Rg Datum to Mean Sea Level'. 108.00 ft. Plot North is ahgnetl to TRUE North. 340 290 280 270 1 260 250 350 TRUE NORTH 0 100 10 70 80 90 100 110 200 160 190 180 170 Normal Plane Travelling Cylinder -Feet All depths shown are Measured depths on Reference Well 20 Y Directional Plan for Forest Oil Middle Lake 1 A Re-drill • Subject: I)ircctio~ral Plan for Forst Oil Middle Lake 1 A Re-drill From: Grc•~; Kirkland <GLKirkland@fo3~~~toil.com> D:~tc: 7 hu, U3 ~'<,~~ '_'005 7 R:36:-~'' -0?00 "1'0: "'Stc~~c da~it,~adrni~~.statc..~k.uti"' ~=~te~c ~ia~ie~<<i~adminstat~.ak.u5> CC: 1 ~onard Gur-ule <LCGuruletcr!I~ore~toil.c~~m>, I arrY CaSar~a ~~"LJCa~aita,u:~for~~toiL~:~nn-~. Pahl b1'n~slow ~~~P~1~~~'in51o~~~u, orestoil.com:=~..lim :lriin~~tun ~~.ID~~rlin~,ton(~i~ti~restoiL~~~nn= Steve, Relative to our telephone conversation of 11/3/05, this is to confirm that Forests plan for the new hole section is to bypass the lower section of hole drilled in Gulfs Middle Lake Unit No. 1. A window is to be milled at approximately 8500' and the hole deviated a minimal distance in order to get away from the original hole. A slight angle +-15 degrees will be built and maintained over the planned 900' M.D. interval to be drilled to the new TD of 9400'. During the drilling of this new hole it is expected that the hole will not deviate more than 150' away from the original hole. Intent is to get away from the invaded zone in the original wellbore and drill virgin section in the 8800' Gas bearing sand. If you require additional information or documentation please advise. Respectfully, Greg Kirkland Senior Geologist Forest Oil Corp. 907-868-2141 1 of 1 11 /3!2005 5:04 PM FW: Rig 129 11" BOP Stack, et al Subject: FW: Rig 129 11"BOP Stack, et al From: Bill Penrose <bill@fairweather.com> Date: Fri, 28 Oct 2005 16:32:20 -0800 To: tom maunder@adminatate.ak.us CC: TEKramer@forestoil.com, RLSmith@forestoil.com Tom, To aid in keeping mi% answers to your questions straight. 1've x~ritten Forest Oil's ~°esponses below the relevant questions. I've also colored them red and italicised /horn, not knolving how it's going to come across in e-mail. 1. In the permit document, 2 values for Maximum Anticipated Surface Pressure (MASP) are provided. 5219 psi is calculated according to 20 AAC 25.005(c)(4)(A). A lower value of 4369 psi is also provided based on the minimum fracture gradient at the 9-5/8" window. This lower-value is listed on the 401 sheet. Is it Forest's expectation the 4369 psi is the "maximum ...pressure [the BOP] may be subjected [to]" as specified at 20 AAC 25.035(e)(3)? Yes, it's Forest Oil's expectation that the maximum pressure the BOP's could see is 1,369 psi. Any pressure higher than this ~+-ould break down the formation at the 9-S/8 "window. 2. Based on the original well record, it is Forests expectation that the hydrocarbon resource in this well is high pressure gas. When the well is produced, the higher MASP value of 5219 psi could be expected at surface. If true, this value exceeds the stated test pressure (and possibly the API rating) of the tree (step 15). Forest should address this inconsistency. The formation pressures used in the _~~qSP calculations for this well are actually the mud weights used to drill the formations because That is the onh~ indicater available ofpore pressure. The actual pore pressures are probably beloN~ those indicated by the mud weights used and MASP is probably less. How much less, hoi~never, is unknown and for this reason Forest Oil proposes to test the proposed nominal S, 000 psi i~VP well head mzd production tree to whatever maximum formation pressure exists as determined via an I~1DT tool run in the open hole after TD is reached less a gas gradient. 3. The potential production MASP is also well in excess of your planned 9-5/8" casing test. Please comment on this pressure difference and mitigation strategies should the casing be subjected to pressures in excess of 3000 psi surface pressure. Forest Oil proposes to test the 9-S'8 "casing to whatever maximum formation pressure exists as determined via an MDT tool run in the open hole after- TD is reached less a gas gradient. 4. In step 14, it stated, "Complete well as a gas producer". Forest is requested to provide additional information with regard to the envisioned completion (tubing size, weight, connection, jewelry, etc). It is recognized that Forest does not have all information that would go into that decision, however providing the base plans would be appreciated. Forest Oil tentatively plans to complete MLU ~1 as a single gas producer with a 2-7/8", 6.S#, P-110, RTS-8 tubing string. This tubing string will be stung into a permanent packer with TCP perforating 1 of 2 11/10/2005 10:5] AM FW: Rig 129 11" BOP Stack, et al guns suspended below it. 7bere will be landing nipples installed betva~een the guns and the packer and just above the packer. 5. Based on the high expected pressures and the location of the well being relatively more accessible to the public, the Commission is considering the need for surface and sub-surface safety valves. Has the provision of either such valve been considered thus far? According to the regulations, a hearing is required if the Commission intends to require such valves. Forest Oil intends to equip this well with a surface safety valve. If the Commission decides a subsurface safety valve is also r~eyuired, Forest Oil will of course comply. 6. When the required API stack rating is > SK 2 sets of pipe rams are required for the tubulars (except BHA) in use. VBRs which have been indicated are not available usually provide flexible OD coverage for the various tubulars employed. If Forest is planning on running tubulars with only 1 properly sized pipe ram, that operation should be identified and a variance requested according to 20 AAC 25.035(h)(1). The BOP stackproposed,for use on this well by Forest Oil is a ~Kstack containing two pipe rams and a blind ram in addition to the annular preventer. The two pipe rams are anticipated to be sufficient for handling all anticipated pipe sizes. Please let me know i f I can provide any additional information. Regards, Bill 2 of 2 11/10/2005 10:51 AM Rig 129 11" BOP Stack i • Subject: Rig 129 11" BOP Stack Fram: Bill Penrose <bill@fairweather.com> Date: 'Thu, L3 Oct 2005 09:6:19 -t~800 To: tone maunderiri!ad~~lin.state.ak.us CC: ~IEKramer<<z?Corestoil.com Tom, Attached as promised is a diagram of Rig 129's 11" BOP stack. As mentioned earlier, all components are Schaffer. Please replace the diagram in the MLU #1-A PTD application with this one. Thanks and regards, Bill Content-Description: 129_11-BOP_3RAM.pdf 129_11-BOP 3RAM.pdf Content-Type: application octet-stream Content-Encoding: base64 1 of 1 10/13/2005 10:54 AM 11 " Sk PSI SCRAPPER ANNULAR BOP SCREWED HEAD FLANGED BOTTOM CONNECTION 3" #50~ HCR VAL 3" CHOKE LINE GATE VALVE 11 " 5k PSI DOUBLE GATE PREVENTOR 3-1/8" #5000 STUDDED CONNECTION GATE VALVE _ _ _ _ _ 11 " 5000# API 3" KILL LINE - _ FLANGED MUD CROSS 11 " 5k PSI HYDRAULIC RAM SINGLE GATE STUDDED CONNECTION 3-1/8" #5000 GATE VALVE 1 1 - T` C ~ RE: Middle Lake Rig • a Subject: RE: Middle Lake Ri~~ From: Bill Penrose <bll Er fair~~~~ather.com> Date: Thu, 13 Oct 2005 Oz):4O:57 -0800 I'o: Thomas Maunder 'tong maunder(~r,adrnin.state.ak.us=>~ CC: ~I~EKramer~~i'forestoil.com Tom, Sorry for the confusion. The rig to be used is Nabors 129, but I sent you the BOP specs for the 11" stack on 265. Nabors is sending me the diagram for the 11" stack on Rig 129 which I'll forward to you when I get it. All components in that stack are Schaffer. There are no VBR's. The rig's drill pipe is 4" and the pipe rams in the stack will be sized accordingly. Regards, Bill -----Original Message----- From: Thomas Maunder [mailto:tom maur_der~~admin.state.ak.~s] Sent : Thursday, October 13 , 2005 9 : 04 -p,NI__......__._......_....._......_...__.._..._ ..................._. _._.__-_ To: Bill Penrose Cc: Ted Kramer Subject: Middle Lake Rig Bill, According to the BOP drawing you provided, Forest plans to use Nabors 26S to reenter Middle Lake and accomplish the sidetrack. I know this rig has been doing workover operations on the Kenai and is now at the Forest facility on the West Side for a couple of workovers. Has this rig actually drilled some hole in Alaska?? I checked our rig files and I don't find a lot there on 26S. Last correspondence had to do with an inspection in advance of really cold weather operations and at that time Unocal and Nabors were awaiting winterization supplies awhile back. I presume the rig is "ready/equipped" for cold weather. What size drill pipe is planned?? Will the BOP be equipped with VBRs?? I see the annular is a Hydril, are the rams Hydril as well?? would you contact Nabors to see about providing some drawings of the pits and the other BOPS (choke manifold, gas buster, accumulator). Thanks in advance, Tom Maunder, PE AOGCC 1 of 1 11/10/2005 10:50 AM FW: Middle Lake #lA--annular disposal application Subject: F~V":~~liddle Lake #lA--annular disposal application From: Bill Penrose ~~~bill(a)faiitiveather.com Date: ~~'ed, 12 Oct ?00~ 07:? 1: 7 -OSOO 'To: tom maunder(~l~admin.state.ak.us Tom, FYI. Bill • -----Original Message----- From: Roy Smith [mailto:RLSmith~forestoil.com] Sent: Wednesday, October 12, 2005 6:22 AM To: Bill Penrose Cc: Ted Kramer; Bob Elder Subject: RE: Middle Lake #lA--annular disposal application Bill We excavated around the well last month and I have attached some pictures of the casing stub with no wellhead. Just for clarification, we will not be able to attempt annular injection until we nipple up on the well. Regarding the sampling of cutting and disposing of the cuttings at the landfill and you give me an idea of what the values need to be based on the Glennallen cutting testing and also what was the company that did the testing for that well? Thanks! Content-Description: picture of all strings.JPG :picture of all strings.JPG Content-Type: image/jpeg Content-Encoding: base64 1 of 1 10/13/2005 735 AM picture of al] strings.JPG (JPEG Image, 1536x2048 pixels) • ] of 2 10/13/2005 7:34 AM RE: Middle Lake #lA--annular disposal application • Subject: RE::~1ic3clle Lake #lA--annular disposal application From: B11 Penrose <bill('~r~faiiweathei-.coi~1 Date: Tuc, I 1 Oct 2005 lCi:2(i:~S -000 To: 'Thomas viaundct~ <toni_nlaunder~i',adn~in.state.ak.us== C'C: TEKramer«i;;forestoiLcom, RLSmith(u?forestoil.com, Bob Eder ~RGElder(ci'ForestoiLcom~= Tom, 1. See the attached .mud weight curves from the original MLU #1 and offsetting well Bell Island Unit #1. On them I've drawn a frac gradient curve that I used for the frac pressure at the MLU #1 13-3/8" shoe. To draw them, I assumed conservatively that the pressure jump typically seen at the top of the Bell Island sand goes up to close to the frac gradient at that depth and I drew a characteristic curve from there to the surface. I checked the values on the curve against the frac gradients being seen in Aurora Gas' fields around Tyonek and with Forest Oil's West Foreland Unit. Aurora's frac gradients are abnormally high and didn't agree at all. The West Foreland information correlated very well. All-in-all, I decided that my original approach and its agreement with West Foreland justified the rejection of the comparison with the anomalous Aurora data. This approach also yields a more conservative frac gradient than Aurora's. 2. The possibility of needing to use diesel in the annulus comes from my using an abundance of caution. If Forest has the annulus full of flush water used to chase mud and cuttings down to the shoe, then has to shut down the rig for a significant period of time during the planned winter operations, they may feel it prudent to freeze protect once or twice. Probably won't happen, but they don't want to get in trouble for injecting an un-authorized fluid. 3. See the attached Location Clearance wherein LCS (Lonnie Smith?) indicates that the wellhead was cut off and a marker post installed. Also see the photo showing the estimable Mr. Pat Prout standing next to said marker post. 4. The attempt to pump into the 9-5/8" x 13-3/8" annulus will occur at some point before rigging up on the well so that Forest will know if AD is an option. The exact timing is not known right now, however. The wellhead will have to be obtained and access with that equipment will have to wait until the ground is frozen. The site is accessible by foot, but vehicular traffic would tear up a boggy area the original road has settled into. 5. We have not attempted to calculate salinities anywhere else in the well, but could do so providing the necessary log data exists across those additional intervals. 6. The other plan for waste disposal is to de-water the cuttings and test them and the liquid phase for acceptability at the Mat-Su landfill and sewage processing facility, respectively. If they fail the testing, both phases will be transported to Forest's permitted West Foreland facility for disposal. The ability to pump into this annulus after all this time is a question large in everyone's mind. However, on the chance that it can be done is too good an option to pass up - hence this application. If Forest can't gain access through this annulus, you'll be the first to know and can drop everything. On the other hand, if Forest is successful in establishing injection, again you'll be the first to know and we'll be sure to top off your data needs at that time so there's not too much more work permit-wise to do at the last minute. Regards, 1 of 2 10/13/2005 7:35 AM RE: Middle Lake #lA--annular disposal application • Bill -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin.state.ak.us] Sent: Tuesday, October 11, 2005 2:00 PM To: Bill Penrose; Ted Kramer Subject: Middle Lake #lA--annular disposal application Bill and Ted, I am examining the sundry application for annular disposal. A couple of questions and an observation. 1. How was the formation pressure determined at the 13-3/8" shoe? I have looked at the file and do not see a value noted in it. 2. Diesel is mentioned for "freeze protection". Will it be necessary to freeze protect when the well is operating? 3. Was the well head ever removed? Based on the file as I read it, the shallowest cement plug in the well is at 150' and I cannot find any notation that the wellhead was ever cut off. By the regulations, that makes the well actually suspended however that is not an issue for you all. 4. When will an attempt be made to pump in to the 13-3/8" x 9-5/8" annulus? Is the location accessible now? 5. Has the salinity been calculated at depths other than the 2 intervals provided? Do you have any information on the depth where salinity goes above 10000 ppm? 6. What is your contingency plan for waste disposal? Cleaning out the 9-5/8" casing and performing the sidetrack as you plan is something that can reasonably expected to be accomplished. Pumping into an annulus that from all available information I have reviewed hasn't been "touched" since late 1st Q 1969 and by the reports had 13.1 ppg mud in the hole when the 9-5/8" casing was set is not so certain. Reclaiming or reactivating "old" annuli has not generally been a successful operation in the few wells where it has been attempted. Tom Maunder, PE AOGCC Content-Description: Mud -Frac Curves.PDF Mud -Frac Curves.PDF Content-Type: application/octet-stream Content-Encoding: base64 _ __ Content-Description: Loc Clearance.PDF Loc Clearance.PDF Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: Prout on Loc.ppt Prout on Loc.ppt': Content-Type: application/vnd.ms-powerpoint Content-Encoding: base64 2 of 2 10/13/2005 7:35 AM i • ~. ;;: ~ ' . Vic: .~. ~ ~ . 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O O O O .: O r r n.i _T !n rL 1 D -i o O Q ._ ~ W 2 rn.. to D ~ ~ N a> r o ~ W o N D Cr N ~ ~ m D r n N i i i i a i i i i i D O ', ~' z N ~ o -~ ~ I~ o.. ~ _. S ecurity FeaturesJncluded. ~ Detail s on back. W • r~ TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN T~R/A~NS/MIT/TAL/LE/TTER~, / ,!~ WELL NAME ~" l f c~(G~l~ !~ 1~ C't 4i~~`' ~~/ PTD# ~`~ ~7" / ~~' __ ~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (ply 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). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and groduce/infect 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. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\jody\transmittal_checklist • • ^^ o •~ : wit ~; _ ~, ~ D a,, o. a ~ ( a m O ~ _ ;~ , o a~ ~~ Vl ._: ~ G .C, ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ Vl N~ ~ C N p c ~ Z, O Z~ ~~ d O ~~ O ~ ~ N~ ~ ~ ~ T O, -p~ ~ N O~ N, ~, N ~ ~ .c~ ~, ~~ N. ~ ~ ~ ~ U• ~ ~ ~ Y~ ~ ~ O c6 N, ~ ~ m O C a C V N ~ ~ ~ W ~ ~ p ~ ~~ C' ~ ~ ~, O: O. ~ ~ ~ ~ O c• y O O. ~ ~ a: b ~ a~ 0 N C Q: ~ ~ ~ ~ ~ ~ ~ ~ y, Qy O ~ ~ M N~ ~ ~ ~~ y O~ ~ ~ V Z+ ~ ~ ~ ~ S, C .' V r o. c. ~ ~: ' O. s m. 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