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ϭϯ͕Ϯϲϱ͛ ϵ͕ϴϵϮ͛ ϵ͕ϴϵϲ͛ ϱ ϭϭͬϴͬϮϬϮϭ KƉĞŶ ͬͬ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/29/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 4-10A (PTD 202-238) Multi-Finger Caliper 11/10/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/29/2021 By Abby Bell at 4:24 pm, Nov 29, 2021 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 4-10A (PTD 202-238) Perf 11/08/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/22/2021 By Abby Bell at 1:28 pm, Nov 22, 2021 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,860'13,635' Casing Collapse Conductor N/A Surface 2,090psi Production 7,150psi Liner 7,500psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 2,317'13,860' Authorized Signature: 7/9/2021 4-1/2" Perforation Depth MD (ft): 131'30" 10-3/4" 7-5/8" 3,993' 131' BurstMD 11,690' 3,696' 8,841' 10,355' 3,993' 4-1/2" See Schematic 50-029-22464-01-00 N/A 8,430psi 11,690' 3,580psi 3,065 13504, 13,520 & 13,770 131' TVD 8,180psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 202-238 Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 DUCK IS UNIT SDI 4-10A 11,555 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6 / 13CR80 / VAM ACE 13,504' Length Size 10,083' C.O. 462.007 PRESENT WELL CONDITION SUMMARY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. See Schematic 10,355' ENDICOTT / ENDICOTT OIL 7-5/8" x 4-1/2" S-3 & 7-5/8" x 5-1/2" LT ZXP and HES HXO SSSV dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: 11,498 MD / 8,529 TVD & 11,554 MD / 8,565 TVD and 1,530 MD / 1,523 TVD Authorized Title: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 4:59 pm, Jun 25, 2021 321-317 Chad Helgeson (1517) 2021.06.25 16:34:09 - 08'00' DSR-6/25/21MGR30JUN21SFD 6/25/2021 , ADL 0047502 SFD 6/25/2021 10-404 dts 7/1/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.01 11:17:49 -08'00' RBDMS HEW 7/2/2021 Plug Set and Perf Add Well: END 4-10A PTD: 202-238 API: 50-029-22464-01 Well Name:END 4-10A API Number:50-029-22464-01 Current Status:Shut-In, Operable Rig:E-line Estimated Start Date:July 9, 2021 Estimated Duration:1 Day Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:202-238 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Joleen Oshiro (650)-483-4774 (M) AFE: WellEZ Entry Required:Yes Current Bottom Hole Pressure:4,065 psi @ 10,000’ TVDss (Based on BHP taken on 08/09/16) MPSP:3,065 psi (0.1 psi/ft gas gradient) Reference Log:SLB PDC Log GR/CCL dated 28-FEB-2003 Brief Well Summary: Endicott 4-10A is a producer that has open perforations in the K2B and S3A2 sands; it has become marginal/uncompetitive from a GOR standpoint, and it is currently shut in. A production profile log from November 2020 indicated that 96% of the well’s gas is coming from the K2B (lowest set of currently open perfs). Objective: Set plug at 13,400’ MD to shut off the K2B gassy perforations and add up hole S3A3 perforations following interval in table below. Gun Run # Perf Top Perf Bottom Perf Length Formation 1 ±13,260’ ±13,265’ 5’ S3A3 Total 5’ Table 1: END 4-10A Proposed Perf Gun Run Note: Final depths to be confirmed in “Final Approved Perf Sheet” Procedure: Slickline 1. RU SL unit. Pressure test PCE to 250 psi low / 3,500 psi high. 2. Pull 4-1/2” SSSV from 1,530’ MD. 3. Drift with BHA that sufficiently emulates a 4.5’’ CIBP run and a 5’ x 2-7/8’’ perforation gun run a. Target drift depth 13,400’ MD. b. If drift will not get down to target depth, change up BHA length and size. If still does not get down to target depth, contact OE. 4. RD SL unit. Eline (Approved Sundry required prior to proceeding) 5. RU EL unit and pressure test to 250psi low 2,500psi high. 6. RIH and correlate perforation gun run to Tie-In Log. Contact OE (contact info above) prior to perforating for final approval of tie in. 7. Set CIBP at 13,400’ MD. Plug Set and Perf Add Well: END 4-10A PTD: 202-238 API: 50-029-22464-01 8. MU perforating tool string with 5’ x 2-7/8” guns (6 spf, 60deg phasing) 9. Perforate as per Table 1: END 4-10A Proposed Perf Gun Run. POOH. a. Note any tubing pressure change in WSR. b. Ensure Correlation Pass and Shooting Passes have CCL displayed 10. RD Eline. Slickline 1. RU SL unit and pressure test to 250psi low/2,500psi. 2. RIH and pull the 4-1/2” BBE SSSV from 1,530’ md. 3. RD SL unit. ~13,260' MD - 13,265' MD _____________________________________________________________________________________ Revised By: TDF 3/8/2018 SCHEMATIC ENDICOTT Well:END 4-10A Last Completed: 2/22/2003 PTD: 202-238 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30"Conductor N/A N/A Surface 131’ 10-3/4"Surface 45.5 / L-80 / BTC 9.950 Surface 3,993’ 7-5/8”"Production 29.7 / NT95 / NSCC 6.875 Surface 11,690’ 4-1/2”Liner 12.6 / 13Cr80 / Hydril 521 3.958 11,554’13,860’ TUBING DETAIL 4-1/2”Tubing 12.6 / 13Cr80 / VAM-ACE 3.958 Surface 11,555’ JEWELRY DETAIL No Depth Item 1 1,530’4-1/2” HES HXO SVLN – ID= 3.813 GLM Detail: KBG-2 / BK Latch / 1” GLV 2 3,525’ST 6:Port=16, Dev= 36, Vlv= Dome, TVD=3,353’, Date= 2/26/03 3 5,182’ST 5:Port= 0, Dev= 49, Vlv= Dmy, TVD= 4,445’, Date= 2/20/03 4 6,253’ST 4:Port= 20, Dev= 49, Vlv= SO, TVD= 5,161’, Date= 2/26/03 5 6,994’ST 3:Port= 0, Dev= 50, Vlv= Dmy, TVD= 5,626’, Date= 2/20/03 6 7,734’ST 2:Port= 0, Dev= 50, Vlv= Dmy, TVD= 6,107’, Date= 2/20/03 7 8,517’ST 1:Port= 0, Dev= 52, Vlv= Dmy, TVD= 6,606’, Date= 2/20/03 8 11,477’HES X Nipple 9Cr – ID=3.813” 9 11,498’7-5/8” Baker S-3 Production Packer 10 11,522’HES X Nipple 9Cr – ID=3.813” 11 11,542.5’HES XN Nipple 9Cr – ID=3.725”(11552’ ELMD) 12 11,543.4’Baker Liner Tie Back Sleeve 13 11,553.6’’4-1/2” WLEG Fluted 9Cr –Bottom @ 11,555’ 14 11,554’Baker ZXP Packer / HRD Setting Tool 15 11,562’Baker RS Nipple – ID= 4.88” 16 11,565’Baker 7-5/8” x 5-1/2” Flex Lock Liner Hanger 17 11,573’Cross Over 5-1/2” Hydril 521 x 4-1/2” Hydril 563 –ID=3.90” 18 13,504’Weatherford 3.69” WRP – 5/11/2009 19 13,571’Baker 3” IBP – 2/28/2009 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status END Oil 13,336’13,346’9,952’9,960’10 10/29/2016 Open 13,450’13,460’10,041’10,049’10 5/13/2009 Open 13,525’13,535’10,100’10,108’10 3/9/2009 Isolated 13,660’13,690’10,205’10,228’30 2/28/2003 Isolated 13,738’13,748’10,287’10,272’10 7/6/2003 Isolated Ref Log: SWS PDC GR/CCL 2/28/2003 – Angle at Top Perf= 39 Deg. @ 13,450’ OPEN HOLE / CEMENT DETAIL 30"Driven 10-3/4"800 sx PF “E”, 375 sx Class “G” in 13-1/2” Hole 7-5/8”440 sx Class “G” in 9-7/8” Hole 4-1/2”350 sx Class “G” in 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 53 deg. @ 6,600’ TREE & WELLHEAD Tree 4-1/2” Cameron Wellhead 13-5/8” 5K GENERAL WELL INFO API: 50-029-22464-01-00 Original Completion by Doyon 15 – 7/26/1994 Sidetracked and Completed by Doyon 15 –2/28/2003 Set IBP and Sluggits - 3/4/2009 Perf Add - 3/9/2009 Set WRP - 5/11/2009 & Perf Add – 5/13/2016 7-5/8” WINDOW DETAIL 11,690’ TOP / 11,740’ Bottom SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry _____________________________________________________________________________________ Revised By: CAH 6/25/2021 PROPOSED SCHEMATIC ENDICOTT Well: END 4-10A Last Completed: 2/22/2003 PTD: 202-238 TD = 13,860’ (MD) / TD = 10,355(TVD) 30” Marker Jts @ 13,394 & 13,414’ KBE = 55.85’/ BF Elev = 14.5’ 7-5/8” 3 6 4 8 10 5 14 12 13 1 2 11 15 & 16 17 PBTD = 13,770’ELM (MD) / PBTD =10,288’(TVD) 7 Top of Sluggits @ 13,520’ – 3/4/2009 10-3/4” 4-1/2” Fish – Ring Stiffener – 2/4/2009 19 20 Fish – WFD SLE Pkr w/ releasable spear – TOF 13483’ ELMD 5/19/17 Fish – Part of WFD SLE Pkr w/ element, xover, slotted liner and bullnose left in hole on 10/14/17 (OAL ~ 3.5’) TOF ~13479’ ELMD 10/14/17 18 Fish – CIBP Tagged @ 13,440 SLM/ 13,467 ELM 2/18/2018 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor N/A N/A Surface 131’ 10-3/4" Surface 45.5 / L-80 / BTC 9.950 Surface 3,993’ 7-5/8”" Production 29.7 / NT95 / NSCC 6.875 Surface 11,690’ 4-1/2” Liner 12.6 / 13Cr80 / Hydril 521 3.958 11,554’ 13,860’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr80 / VAM-ACE 3.958 Surface 11,555’ JEWELRY DETAIL No Depth Item 1 1,530’ 4-1/2” HES HXO SVLN – ID= 3.813 GLM Detail: KBG-2 / BK Latch / 1” GLV 23,525’ST 6:Port= 16, Dev= 36, Vlv= Dome, TVD= 3,353’, Date= 2/26/03 35,182’ST 5:Port= 0, Dev= 49, Vlv= Dmy, TVD= 4,445’, Date= 2/20/03 46,253’ST 4:Port= 20, Dev= 49, Vlv= SO, TVD= 5,161’, Date= 2/26/03 56,994’ST 3:Port= 0, Dev= 50, Vlv= Dmy, TVD= 5,626’, Date= 2/20/03 67,734’ST 2:Port= 0, Dev= 50, Vlv= Dmy, TVD= 6,107’, Date= 2/20/03 78,517’ST 1:Port= 0, Dev= 52, Vlv= Dmy, TVD= 6,606’, Date= 2/20/03 8 11,477’ HES X Nipple 9Cr – ID=3.813” 9 11,498’ 7-5/8” Baker S-3 Production Packer 10 11,522’ HES X Nipple 9Cr – ID=3.813” 11 11,542.5’ HES XN Nipple 9Cr – ID=3.725”(11552’ ELMD) 12 11,543.4’ Baker Liner Tie Back Sleeve 13 11,553.6’’ 4-1/2” WLEG Fluted 9Cr –Bottom @ 11,555’ 14 11,554’ Baker ZXP Packer / HRD Setting Tool 15 11,562’ Baker RS Nipple – ID= 4.88” 16 11,565’ Baker 7-5/8” x 5-1/2” Flex Lock Liner Hanger 17 11,573’ Cross Over 5-1/2” Hydril 521 x 4-1/2” Hydril 563 – ID=3.90” 18 ±13,400’ Proposed Plug 19 13,504’ Weatherford 3.69” WRP – 5/11/2009 20 13,571’ Baker 3” IBP – 2/28/2009 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status S3A3 ±13,260’ ±13,265’ ±9,892’ ±9,896’ 5 Future Proposed END Oil 13,336’ 13,346’ 9,952’ 9,960’ 10 10/29/2016 Open 13,450’ 13,460’ 10,041’ 10,049’ 10 5/13/2009 Open 13,525’ 13,535’ 10,100’ 10,108’ 10 3/9/2009 Isolated 13,660’ 13,690’ 10,205’ 10,228’ 30 2/28/2003 Isolated 13,738’ 13,748’ 10,287’ 10,272’ 10 7/6/2003 Isolated Ref Log: SWS PDC GR/CCL 2/28/2003 – Angle at Top Perf= 39 Deg. @ 13,450’ OPEN HOLE / CEMENT DETAIL 30" Driven 10-3/4" 800 sx PF “E”, 375 sx Class “G” in 13-1/2” Hole 7-5/8” 440 sx Class “G” in 9-7/8” Hole 4-1/2” 350 sx Class “G” in 6-3/4” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 53 deg. @ 6,600’ TREE & WELLHEAD Tree 4-1/2” Cameron Wellhead 13-5/8” 5K GENERAL WELL INFO API: 50-029-22464-01-00 Original Completion by Doyon 15 – 7/26/1994 Sidetracked and Completed by Doyon 15 – 2/28/2003 Set IBP and Sluggits - 3/4/2009 Perf Add - 3/9/2009 Set WRP - 5/11/2009 & Perf Add – 5/13/2016 7-5/8” WINDOW DETAIL 11,690’ TOP / 11,740’ Bottom SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END SDI 4-10A (PTD 202-238) Injection Profile 11/08/2020 Please include current contact information if different from above. PTD: 2022380 E-Set: 34579 Received by the AOGCC 01/19/2021 Abby Bell 01/19/2021 THE STA'T'E °fALASKA April 24, 2020 GOVL.RNOR MIKE DUNLF.A1'S Mr. David Gorm Operations Engineer Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-20-012 Well Testing and Safety Valve System Changes SDI 4-10A (PTD 2022380) Duck Island Unit Dear Mr. Gorm: Alaska Oil and Gas Conservation Commission 333 West iev, fIn A, nrLa Anchorage. AJUS,:,l 995;;;1 ", Main: ,, ..G':- Fuz: By letter dated March 16, 2020 Hilcorp Alaska, LLC (Hilcorp) requests approval of an alternative well testing methodology and safety valve system changes for Duck Island Unit well SDI 4-10A. The well's flow rate is being artificially restricted with a flowing wellhead pressure of approximately 2,000 psi due to test separator design and flowline erosion velocity limitations. Hilcorp's requests use of a second flowline attached to SDI 4-10A to enable the well to flow at a higher rate into the 300 -psi production header. On April 21, 2020 an AOGCC Inspector observed the recently completed flowline changes at SDI 4-10A noting that Hilcorp has installed all new piping for the `twin" flowline except for the S -riser and low -pressures detection device. The piping configuration is identical to the existing SDI 4- 10A flowline. The new twin flowline system consists of actuated wing valves attached to the production tree flow cross outlets (2). Each flowline is equipped with a choke valve, a low- pressure detection device, and a wye directing produced fluids to two separate production header slots. The SDI 4-10A automatic safety valve system is configured as follows (in the direction of flow): a subsurface safety valve in the tubing, surface safety valve in the vertical run of the production tree, and a low-pressure detection device linked to the existing safety valve control panel located downstream of the choke. Detection of a low-pressure situation in either of the flowlines closes the surface safety valve, the actuated wing valves on both flowlines, and the subsurface safety valve. Performance testing of the SDI 4-10A safety valve system involves independently actuating the low-pressure switches to verify regulatory compliance. As an alternate method of well production testing, Hilcorp proposes the summation of the individual well tests of each of the SDI 4-10A flowlines. Those individual tests will be performed back-to-back to ensure consistent plant conditions and sufficient accuracy for allocation purposes. Docket Number: OTH-20-012 April 24, 2020 Page 2 of 2 The Alaska Oil and Gas Conservation Commission APPROVES Hilcorp's request to use the alternate well testing methodology and to install, maintain, operate, and test the twin flowline safety valve system as described in its application, with the following conditions: - The low-pressure detection devices and surface safety valve for the twin flowlines must be uniquely identified and labeled; - Hilcorp must submit separate test reports for the twin flowline safety salve system tests. Any questions regarding this approval should be directed to Jim Regg at 907-793-1236 (email: iim.regg alaska.aov). Sincerely, Jeremy M. Price Chair, Commissioner Email: AOGCC Inspectors Post Office Box 244027 Anchorage, AK 99524-9524- 4027 Hik.rp Alaska, LLC 3800 Centerpolnt Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 RECEIVED March 16, 2020 Mr. David Roby MAR 19 2020 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 AOGCC Anchorage, AK 99501 Re: DIU SDI 4-10A (PTD # 202-238) Request for Approval of Well and SVS Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 4-10A (PTD # 202-238) in support of a flowline twinning project. Background DIU SDI 4-10A is an Endicott natural flow producer completed in the Kekiktuk formation in K213. The well has been on steady state production since 1994 and is one of the field's top producer with a GOR (75,000 scf/bbl) and Water Cut (-78%). Production is currently restricted at roughly 44 MMSCFD and a flowing tubing pressure of 2000 psi due to test separator design and flowline erosion velocity limitations. To allow the well to flow at a higher rate to the -300 psi production header, we would like to connect a 2nd "twin" flowline to the tree to carry a portion of the production from DIU SDI 4-10A to the flowline of adjacent long term shut-in producer END 3-11 (PTD# 188-087) and to END 4-12 header slot (note: empty header slot, no drilled well). END 3-11 is disconnected and would remain completely isolated from the twinned flowline. Justification Twining DIU SDI 4-10A in this configuration allow for increased production as well as accurate well testing and allocation within the operating limits of the Endicott SDI test separator. Additional well drawdown is expected to encourage additional K2B contribution which will help GOR as FTP decreases. Well Testing Methodology Hilcorp would utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). END 4-10A's well tests would be obtained through a summation of individual tests of the original (4-10A) and twin (4-10A leg B) flowlines. Currently Endicott wells receive a minimum of monthly tests. With the Page 12 addition of testing from the twinned (4-10A leg B) line, a minimum of two tests would be taken to ensure one combined 4-10A well test per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain the same utilizing individual tests and flowline On/Off times as determined by the wing valves' open/closed position. Production values for each flowline would then be combined and reported as a single value for END 4-10A. This methodology would result in no change or disruption to 4-10's well testing or production reporting. Safety Valve System Low Pressure Switch Configuration Hilcorp would operate and test the SVS systems with the addition of a second low pressure switch to protect against a pressure drop in the twinned (4-10A leg B) flowline. The second low pressure switch would be connected from the twinned (4-10A leg B) flowline to END 4-10A's safety valve panel. END 4-10A's surface and subsurface safety valves would remain unchanged, and the overall safety valve system functionality would be unaffected. When the low pressure switch from either flowline was tripped, both END 4-10A's surface and subsurface safety valves would actuate. Additionally, actuated wing valves on either side of the flow cross would close on a low pressure trip. Once installed, this configuration would be function tested and an AOGCC witnessed performance test would be requested. As part of the performance test, each flowline low pressure switch would be tripped independently to verify the correct system actuation pressure for the respective flowline. If you have any additional questions, please contact me at 777-8333 or dgorm@hilcorp.com. reIy, David Gorm Endicott/Northstar Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments - END 4-10A Wellhead Twinning Concept Diagram - END 4-10A & END 4-10A leg B Redlined P&ID's - SDI Wells General Layout 1-29 333 !-" ! 1-41 3 46 }U 331 3-36 3-39 3-43 O D D D D p WELL ROW � A I I OPEN HEADER SLOTS _ OPEN WELL ROW D D D D Db 402 a-0 4-10 4-14 4-18 4-22 ` 26{ 4-3p ). is ! 42 --�--- o-ao 4-04 �4--OHS 4-22 4-16 5-20 4-24 4-1E 432 4-36 �4-44: 11448r--_- L._..3 �n END 4-10A Flowline Twinning - Wellhead Arrangement New flowline to 4-10A leg B flowline & test/production slot 3-11 & 4-12 .Actuated wings close with /trip of either flowline PSL - - ---, Existing flowline to Existing SSV Closes test/production slot 4-10 & 4-16 with trip of either a F flowline PSL New ' Choke i + e I l u W ell Shot 3-11 1 mm TI ' �K-- i New PSL Set P ISOK To Well $lot 4-12 �s VE I m --------------- Existing I +�++��999 •M • .;_...i 11tJ — , --------------------------------------- -' a -- -a. -J -N----- eWing Valve W/ Instrument flange an '_j w downstream ofWlrjg X TI ' �K-- i New PSL Set P ISOK To Well $lot 4-12 �s VE I m --------------- Existing I , , J -------- Existing flowllne AZ :4 1 y //• � 1L ,. •Y.y ri Mw�p•�•�•»!'mow wpy1,Y�ir.W � b•YiiM 4� 06 .�. • owe. -w, w.x �aarws ® • Ml�.•t•M w►Y �\ rI ti• Mi �a To Welt 51ot 4-fo I I I I i To Well Slot 4-15 I ----- --.-.i W ;-----------a'2r3.1ri® v - � POV4 t wsnAm%tAT +DkAmw MEMORANDUM TO: Jim Regg ' 1 P. I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission 417,4 Pzo DATE: 4/21/2020 SUBJECT: Flowline Inspection DIU SDI 4-10A Hilcorp Alaska PTD 2022380 4/21/2020: 1 traveled out to Endicott's SDI drillsite for a walk down of piping changes that are part of Hilcorp's request for approval of twin flowlines on Duck Island Unit SDI 4-10A. The piping changes consist of 2 S -risers attached to the SDI 4-10A production tree flow cross (tubing outlets) that eventually transition to 4 flowlines tying into 4 separate production header slots. This well is currently flow -limited (rate and pressure) due to flowline erosion concerns. The changes will allow Hilcorp to flow SDI 4-10A at a higher rate allowing the tubing pressure to be lower and more oil to be produced. I met with Hilcorp's Endicott Drillsite Operator Larry McBride, the designated person to walk me through the changes and supply me with answers to my questions. The line added to the wellhead was complete and in place except the S -riser and low-pressure switch (LPS) have not yet been connected to the actuated wing valve on the flow cross. The new line is identical to the flowline already in service, routed from S -riser to a production choke, then the sensing port for the LPS, followed by a "Y" in the piping directing the produced fluids from 4-10A into 2 separate header slots. In the direction of flow, the well safety valve system will consist of the existing SSV in the vertical run of the production tree, an actuated wing valve on each tubing outlet of the flow cross, a choke valve, and LPS downstream of the choke valve. If either LPS sees line pressure below 150psi it will trigger and dump the panel, closing both actuated wing valves, the SSV and the SSSV. Based on my observations and discussion with Larry McBride. I believe their well safety valve system is adequate for this configuration. Note that the "twin" flowline configuration will add another component (2nd LPS) that must be tested. Attachments: None 2020-0421_Twin-Flowline_DIU_4-IOA ll.docx Page 1 of 1 Regg, James B (CED) From: David Gorm <dgorm@hilcorp.com> Sent: Friday, April 17, 2020 5:21 PM `e'l a Ili GLu To: Regg, James B (CED) Subject: RE: [EXTERNAL] RE: END 4-10A (PTD: 202-238) Twin Flowline Request Attachments: 4-10 flowline drawing .PDF; 4-10 P&ID.pdf Jim, Please see the attached flowline drawing showing how we would plan to tie 4-10 into the existing empty production header slots. Currently END 4-10 primary production line is split after the choke and PSL and tied into END 4-16 production header slot as shown in the MID in green. We are requesting to add an additional line off of END 4-10 tree to create a second production flow line that would have its own choke and PSL tied to the same SSSV/SSV system for end 4-10. The second flow line would then be split after the choke and PSL to the other two production header slots END 3-11/END 4-12 as shown in the MID in red. The primary flowline as indicated in green on the MID is the only production line online. We have existing infrastructure to allow us to install the second flowline off of END 4-10 tree to tie into the additional choke and PSL, then to the two empty production header slots as shown on the MID in red. Let me know if this helps clarify the request. Thanks, David Gorm Operations Engineer — Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 From: Regg, James B (CED) [mailto:jim.regg@alaska.gov] Sent: Friday, April 17, 2020 3:14 PM To: David Gorm <dgorm@hilcorp.com> Subject: [EXTERNAL] RE: END 4-10A (PTD: 202-238) Twin Flowline Request I am not following the well layout and routing you mention in the request. I see a 2nd flowline from 4-10A to 4-16 header slot (letter indicates 4-12) and nothing tied into 3-11. Please clarify. Has the piping work been done? Well put on production? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reee@alaska.eov. From: David Gorm <daorm@hilcorp.com> Sent: Tuesday, March 17, 2020 9:04 AM To: Roby, David S (CED) <dave.robv@alaska.Rov>; Regg, James B (CED) <iim.regg@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com> Subject: END 4-10A (PTD: 202-238) Twin Flowline Request Dave/Jim, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 4-10A (PTD # 202-238) in support of a flowline twinning project. Attached supporting documents. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer— Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. o � Q O 6 O 3 G z a c �'S i G ¢O og W W E w w w o 3 a S 3 G G Z w w ■ N ■ N ■ o � 3 8 3 G z a c �'S i og n s S w w o 3 a S 3 Nam B o � i -4- + 1•�as � � �'S , i+Jo-361 3 Nam B i ■ . .3a2 -- A i+Jo-361 3 Nam B i+Jo-361 3 Owl' -•--T---- . musty atom D I iA1L7'Mw G�IRt/tM�/Mt `KIICM �- � i t � � � �Y i► 1 Newi r ---+,•---- I ' Choke i p _� ?-" Sam I NellSlot4-10 Well Slot b-16 u Well 51,1ot 3-11 i I Sim -,u-----------e:� ,well Slot y 2 --.. Ne�•—• I" • r. S DO - PPMG - PPWG k MTRUMCk TATCh DA+ RAM Inj 4- T() .m 111112, ' STATE OF ALASKA RECEIVED' AL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 14 2013 1.Operations Abandon U Plug Perforations U Fracture StimulateU Pull Tubing Li 0 ii: o` s wn Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing El Ch. g- ••p'. er ram D Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: Set CIBP&Cement Cap 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development 0 Exploratory ❑ 202-238 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-22464-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 DUCK IS UNIT SDI 4-10A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: 13,504, 13,520& Total Depth measured 13,860 feet Plugs measured 13,770 feet true vertical 10,355 feet Junk measured N/A feet 11,498 Effective Depth measured 13,467 feet Packer measured 11,554 feet 8,529 true vertical 10,050 feet true vertical 8,565 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 3,993' 10-3/4" 3,993' 3,696' 3,580psi 2,090psi Production 11,690' 7-5/8" 11,690' 8,841' 8,180psi 7,150psi Liner 2,317' 4-1/2" 13,860' 10,355' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet SCS True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13Cr80/VAM ACE 11,555' 8,561' Baker S-3 1,530 MD Packers and SSSV(type,measured and true vertical depth) Baker LT ZXP HES HXO SSSV See Above 1,523 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 443 48,852 1,335 1,300 1,873 Subsequent to operation: 262 49,045 2,724 1,750 1,996 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-591 ' Authorized Name: Bo York Contact Name: Taylor Wellman ?-,,/ Authorized Title: Operations Manager Contact Email: twellman(a�hiICorp.corn fril- Authorized Signature: Date: 3/12/2018 Contact Phone: 777-8449 ik 3-25/ BDMS�C, MAR Z Z 2018 Form 10-404 Revised 4/2017 j/64 Submit Original Only • II SCHEMATIC ENDICOTTWelastlCompleted: 2/22/2003 IIile4,r„�,l,,,k.,,IAA: PTD: 202-238 SAFETY NOTE: TREE&WELLHEAD KBE=55.85'/BF Elev=14.5' H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2"Cameron Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 30' OPEN HOLE/CEMENT DETAIL 30" Driven WELL INCLINATION DETAIL 1 10-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole KOP @ 500' 7-5/8" 440 sx Class"G"in 9-7/8"Hole Max Hole Angle=53 deg.@ 6,600' 4-1/2" 350 sx Class"G"in 6-3/4"Hole CASING DETAIL 21 Size Type Wt/Grade/Conn ID Top Btm 10-3/4" 4 30" Conductor N/A N/A Surface 131' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' JEWELRY DETAIL 4 No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail:KBG-2/BK Latch/1"GLV 5 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,ND=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,ND=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-ID=3.813" 7 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-ID=3.813" 11 11,542.5' HES XN Nipple 9Cr-ID=3.725" (11552'ELMD) 12 11,543.4' Baker Liner Tie Back Sleeve 8 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' 14 11,554' Baker ZXP Packer/HRD Setting Tool 15 11,562' Baker RS Nipple-ID=4.88" 10 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger 17 11,573' Cross Over 5-1/2"Hydril 521 x 4-1/2"Hydril 563-ID=3.90" 18 13,504' Weatherford 3.69"WRP-5/11/2009 11 19 13,571' Baker 3"IBP-2/28/2009 12 PERFORATION DETAIL LEn 13 r 14 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status J 17 15&16 13,336' 13,346' 9,952' 9,960' 10 10/29/2016 Open 7-5/8' 13,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open END Oil 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated 72-='-' 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' Marker&@13,394& IC' 13,414'�V Fsn-ciEPTagged @ 18 = As-aa orw os�gow 7-5/8"WINDOW DETAIL GENERAL WELL INFO 13,440 SnAV 13,467 ELM darat•'cover 9etted lira and 2/18/2018 (WInose left)TOhole F^miaid7 11,690'TOP/11,740'Bottom a^1 3s , ,onn API:50-029-22464-01-00 1814/17 OriginalCompletionby Doyon Do on 15-7/26/1994 18 Fish-wfoa.EPia w T �� _ aeasawes Tce Sidetracked and Completed by Doyon 15-2/28/2003 Top Sluggits @ 13463 awns 1s 17 Set IBP and Sluggits -3/4/2009 13,520'-34/2009 19 Perf Add-3/9/2009 Fish-Ring Strfferxx- Set WRP-5/11/2009&Perf Add-5/13/2016 2/4/2009 4.1/7' "1,, TD=13,860'(MD)/TD=10,355(TVD) PBTD=13,770'ELM(MD)/PBTD=10,288'(ND) Revised By:TDF 3/8/2018 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-10A Slickline 50-029-22464-00-00 202-238 1/4/18 2/18/18 Daily Operations: 1/3/2018-Wednesday No activity to report. 1/4/2018-Thursday PT PCE 250psi LOW/3,100psi HIGH. PULL 4-1/2" BBE *ser#HBB-458* FROM HXO NIPPLE AT 1,496' SLM (1,530' MD) PULL 4-1/2" EVO AT 13,300' SLM (13,380' MD), EXTENSIVE CORROSION AND EROSION OF ENTIRE EVO. DRIFFTED W/3.60" CENT TO 13,425' SLM (no obstructions). WELL LEFT SHUT IN UPON DEPARTURE NOTIFY DSO. 1/5/2018-Friday No activity to report. 1/6/2018-Saturday No activity to report. 1/7/2018-Sunday Well flowing upon arrival (Eline set cibp/cmt dump). RIH WITH HEAD, ERS, 2.13" WEIGHT, UPCT, BAKER 10 SETTING TOOL, 3.593" BAKER CIBP TO BOTTOM AT WHICH POINT THE TOOLS LOST COMMUNICATION. POOH AND DISCOVERED CONNECTION WAS FLOODED WITH FLUID. 1/8/2018- Monday 2ND RUN - RIH WITH HEAD, ERS, 2.13" WEIGHT, UPCT, BAKER 10 SETTING TOOL, 3.593" BAKER CIBP. SET BAKER CIBP @ 113,420' MID ELEMENT(TOP EST @ 13,419'). STAND BY DUE TO HIGH WINDS. 1/9/2018-Tuesday RAN TWO CEMENT DUMP BAILER RUNS AND DUMPED TOTAL OF 10 GALLONS OF CEMENT ON PLUG AT 13,420' MID ELEMENT. BOTH BAILERS DUMPED NORMALLY AND IN WATER ENVIRONMENT. ESTIMATED TOC @ 13,409' WELL LEFT SHUT IN UPON DEPARTURE- NOTIFIED PAD OP AND ISLAND OF DEPARTURE. C c " /3L/z c: �, S S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-10A Slickline 50-029-22464-00-00 202-238 1/4/18 2/18/18 Daily Operations: 1/10/2018-Wednesday No activity to report. 1/11/2018-Thursday No activity to report. 1/12/2018 Friday WELL SHUT-IN ON ARRIVAL(drift/set sssv). PT PCE 250#-LOW/3,500#-HIGH. DRIFT TBG W/2.50" CENT. &S. BAILER TO TOP OF CEMENT AT 13,363' SLM (13,410' ELM, +47' corr. From 12/10/17 wsr, no sample recovered) (Estimated TOC is @ 13,409'). SET 4-1/2" BBE SSSV(HBB4-7) IN HXO SVLN AT 1,495'SLM (1,530' MD) CHROME X-LOCK, 3 SETS OF STD PKG W/0- RINGS***. PERFORMED SUCCESSFUL DRAWDOWN TEST W/DSO. WELL FLOWING ON DEPARTURE. 1/13/2018-Saturday No activity to report. 1/14/2018-Sunday No activity to report. 1/15/2018- Monday No activity to report. • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-10A Slickline 50-029-22464-00-00 202-238 1/4/18 2/18/18 Daily Operations: 2/14/2018-Wednesday Rig up 2" coil tubing and test BOPs. PT all rams and body to 250psi low/3,500psi high.All passed. 2/15/2018-Thursday ON LOC. WELL ON INJECTION. P)SM. COMPLETE IRON RU. PU INJECTOR, LUB, BOPE. MU BHA#1-3.05" OD CTC, 3.13" OD DBPV, 3.13"JAR, 3.11" DISCO(7/8" BALL), 3.13" DUAL CIRC VALVE (3/4" BALL),3.10" EXTREME MUD MOTOR,3.71" OPTI- CUT MILL. OAL-24.6'. PT PCE to 3,500 PSI-GOOD.;TAG TOP OF CEMENT AT 13,331' (13,403' corrected).WORK DOWN WITH MINOR MOTOR WORK TO 13,346'. MILLED FROM 13,346' (13,419' corrected)TO 13,348' (13,421' corrected)WITH MAJOR MOTOR WORK AND THEN STALLED. POH AND APPEARED TO BE DRAGGING SOMETHING TO 13,325' (13,397' corrected). RAN BACK IN HOLE TO 13,412' (13,484' corrected) (66' BELOW THE CIBP)WHILE CLEARLY PUSHING SOMETHING. STACKED WEIGHT AND SAW MOTOR WORK at 13,412';STOPPED IMMEDIATELY. BELIEVE CIBP HAS BEEN PUSHED ON TOP OF FISH. POH TO 13,325' (13,397' corrected). RBIH TO 13,400' (13,472' corrected) FOR ANOTHER MILLING/CLEANUP PASS.;POH WHILE CHASING 15 BBL GEL PILL. WELL WENT ON VAC @ 2,300'.AT SURFACE,CLOSE SWAB. FP LINES,COIL,AND WELL.Job Complete. TOP OF FISH AT 13,412' (13,484' corrected). 2/16/2018-Friday No activity to report. 2/17/2018—Saturday No activity to report. 2/18/2018=Sunday PT PCE 250psi LOW/3,000psi HIGH. LOCATE TUBING TAIL AT 11,544' SLM (11,571' ELMD) *+27' CORRECTION*,TAG CIBP AT 13,440' SLM (13,467' ELMD).SET 4-1/2" BBE *ser#BD-01 CHROME LOCK* IN HXO NIPPLE AT 1,496' SLM (1,530' MD). 2/19/2018 Monday No activity to report. 2/20/2018-;Tuesday No activity to report. LOF T't 9 • \�11�; s THE STATE• Alaska �_��\I/��,_� Oil and Gas s� s�`�~9� ofAL S Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 01"ALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCAMMED °'A N 3 0 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU SDI 4-10A Permit to Drill Number: 202-238 Sundry Number: 317-591 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ig)( Hollis S. French Chair DATED this Z-1 day of December, 2017. • • RECEIVED STATE OF ALASKA DEC 1 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Af\r�� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set CIBP&Cement Cap El. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ 202-238 • 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-22464-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No ❑., DUCK IS UNIT SDI 4-10A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 ' ENDICOTT/ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,504', 13,520'& 13,860' • 10,355' ' 13,504' 10,083' 2,400 13,770' 13,635' Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 3,993' 10-3/4" 3,993' 3,696' 3,580psi 2,090psi Production 11,690' 7-5/8" 11,690' 8,841' 8,180psi 7,150psi Liner 2,317' 4-1/2" 13,860' 10,355' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/13Cr80/VAM ACE 11,555 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4-1/2"S-3&7-5/8"x 5-1/2"LT ZXP and HES HXO SSSV 11,498 MD/8,529 TVD&11,554 MD/8,565 TVD and 1,530 MD/1,523 TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q ` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/1/2018 OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman 1T1,/ Authorized Title: Operations Manager Contact Email: twellman((7hiIcorp.com Contact Phone: 777-8449 Authorized Signature:"71,------7---- Date: 12/13/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3n . 3C I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No LiEr-'^�"ac's c' ^" 2i-`i,7. Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: 1 O '-LI O 1 APPROVED BY Approved by: d2CLCI----NCOMMISSIONER THE COMMISSION Date: 0-11-1 Submit Form and i‘l•v Form 10-403 Revised 4/2017 o R LINa p e ti n is valid for 12 months from the date of approval. Attachments in Duplicate ,e �,J►-� /.1--;•/ 9 • 411 Well: &Cement Isolation • Well: DIU SDI 4-10A PTD:202-238 Hifrom Ma,ka,Lr' API:50-029-22464-01 Well Name: DIU SDI 4-10A API Number: 50-029-22464-01 Current Status: Online Field: Endicott Estimated Start Date: January 1, 2018 Rig: SL/EL Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 202-238 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: WeIIEZ Input Required? No Current BHP (Ivishak): 4,065 psi @ 10,000' TVD (Based on offset BHP taken on 08/09/16) MPSP: 3,050 psi SI pressure on 05/15/17 Reference Log: SLB PDC Log GR/CCL dated 28-FEB-2003 Brief Well Summary: The DIU Endicott 4-10A well is a strong performing single zone production well from the K2B. Multiple PNL logs (2002-2005) through time have identified the K3SA zone as fluid bearing with indications of oil. The recent RMT-3D log ran in August 2016 has confirmed these readings. 10'of perforations were added which have increased the total production of this well by 400bopd. The well's flowline was also twinned which allowed for increased choke opening. The increased gas roduction has exceeded the current measuring capability of the gas leg of the test separator. The first DH Choke that was set had high erosion and corrosion and caused the choke to fail. Attempts to � -- recoveracker were unsuccessful and resulted in leaving the packer down on top of the WRP below the current open intervals. **Note from the attempted setting of the second DH choke paker: Lower portion (Wireline Adapter Kit)of WFR Non Explosive Setting tool failed to shear off of packer after partial set.Adapter is pinned for a 44k shear. 3 previous attempts with braided line failed to shear after"'4 hrs of total jarring. Good latching on 1.75" FN with 2-12/"JDC but inconsistent PUWs. Well has multiple 10+deg doglegs and braided line action may be hampered by friction in the tubing. Previous Eline attempts to pull out of weakpoint were aided by pumping fluids (dropped force needed to pull out by at least 700lbs)** The DH choke assembly and the packer were recovered from the well and initial look shows minimal damage. Well performance indicated that the packer was never fully set and was the cause of the poor performance. A 3rd DH choke assembly was set 9/11/17 and a blank choke was installed. The setting of both the packer and the choke went textbook and without issue. After installation the well test rates are similar to pre-DH choke rates at 430bo, 2100bw, and 43.8mmscf. Ran a PPROF on 10/04/17 which showed that they DH choke and pkr assembly had fell downhole approx. 10' below the btm set of open perfs. A caliper was run showing the liner to be in good condition so a Halliburton Evo-Trieve plug was set at 13,378' and to fully isolate the lower perfs. This worked for a time in shutting off some of the gas production but gas rates have continued to hold indicating gas production coming from somewhere. A pump in temp survey was run on 12/5/17 which has indicated the Halliburton Evo-Trieve plug has become unseated and moved up to just below the upper perf set at 13,348' md. • II • • CIBP &Cement Isolation Well: DIU SDI 4-10A PTD: 202-238 Bacon)Alaska.LL, API: 50-029-22464-01 Objective: 1. Pull the Evo-Trieve Plug 2. Set CIBP and dump±10' of cement on top of plug Procedure Slickline 1. RU SL unit and pressure test to 250psi low/3,100 psi high. _ �f 2. RIH and pull the Evo-Trieve from 13,348' md. 3. Set SSSV at 1,530' md. a. Description of SSSV pulled on 10/17/17: 4-1/2" BBE (3 sets std. pkg. sec. lockdown steel), SET IN SSSVLN AT 1,494' SLM (1,530' MD) SER#HNBB-58. 4. RD SL unit. Operations 5. Flow well until approvals in place and job is scheduled. Slickline 6. RU SL unit and pressure test to 250psi low/3,100 psi high. 7. RIH and pull the SSSV from 1,530' md. 8. Drift w/3.60" dummy plug past 13,440' md. 9. RD SL unit. E-Line 10. RU EL unit and pressure test to 250psi low 3,100psi high. 11. MU 4-1/2" special clearance CIBP toolstring (max OD=3.60"). 12. RIH and correlate to the Pollard Perf Log Dated: 10-29-16. Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to setting for final approval of tie in. 13. Set the packer(mid-element) at 13,,Aand. 611 14. MU positive displacement cement bailer and load with cement. a. Dump a total of 10gal of cement on top of plug. M." b. Liner volume=0.6384ga1/ft c. 10gal = 15.66' and of cement plug 15. RD Eline. Slickline 16. RU SL unit and pressure test to 250psi low/3,100 psi high. 17. RIH and set 4-1/2" BBE SSSV at 1530' md. a. Description of last SSSV set on 09/12/17: ***SER# HNBB-50*** (3 sets std pkg). See WSR for full details. 18. RD SL unit. Contingency Steps: If the isolation plug hinders overall production Slickline 19. RU SL unit and pressure test to 250psi low/3,100 psi high. 20. RIH and pull the SSSV from 1,530' md. 21. RD SL unit. • • CIBP&Cement Isolation Well: DIU SDI 4-10A PTD: 202-238 Ililcorp Alaska,LUr- �`1 I API: 50-029-22464-01 Coil Tubing 22. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 23. Pressure test BOPE to 250psi low/3500 high, 10 min each test. a. Each subsequent test of the lubricator will be to 3500 psi Hi, 250 Low to confirm no leaks. 24. MU 3.65"-3.70" milling BHA and RIH. 25. Dry tag the TOC at±13,403' md. PU, obtain motor parameters and begin milling cement and CIBP. 26. Mill & push CIBP down to 13,469' md. a. Do not set down excess weight when pushing the milled CIBP to bottom. There is a WFD WRP that is set and isolating further perforations below this point. 27. POOH and F/P well. 28. RD CT Unit. Slickline 29. RU SL unit and pressure test to 250psi low/3,100 psi high. 30. RIH and set 4-1/2" BBE SSSV at 1530' md. b. Description of last SSSV set on 09/12/17: ***SER# HNBB-50*** (3 sets std pkg). See WSR for full details. 31. RD SL unit. ` • • ENDICOTT II Well: END 4-10A SCHEMATIC Last Completed:2/22/2003 Hamm Alaska,LLC PTD:202-238 SAFETY NOTE: TREE&WELLHEAD KBE=55.85%BFEIev=14.5' H2SReading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2"Cameron 3 11 Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 30' OPEN HOLE/CEMENT DETAIL 30" Driven WELL INCLINATION DETAIL 1 10-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole KOP @ 500' 7-5/8" 440 sx Class"G"in 9-7/8"Hole Max Hole Angle=53 deg.@ 6,600' 4-1/2" 350 sx Class"G"in 6-3/4"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm 10-3/4"A 4 30" Conductor N/A N/A Surface 131' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' ' 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' € JEWELRY DETAIL 4 No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail:KBG-2/BK Latch/1"GLV i 5 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,TVD=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,TVD=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-ID=3.813" i 7 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-ID=3.813" 11 11,542.5' HES XN Nipple 9Cr-ID=3.725" 12 11,543.4' Baker Liner Tie Back Sleeve I 8 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' 14 11,554' Baker ZXP Packer 9 15 11,562' Baker RS Nipple-ID=4.88" 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger I 10 17 11,573' Cross Over 5-1/2"Hydril 521 x 4-1/2"Hydril 563-10=3.90" ) n ( c «---may 18 13,380 HES Evo-Trieve(set on 10/16/17) "--.7.r►►i Dr -T - I 11 19 13,504' Weatherford 3.69"WRP-5/11/2009 20 13,571 Baker 3"IBP-2/28/2009 12 IL 13 PERFORATION DETAIL . .' 1 i 15&16 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 17 13,336' 13,346' 9,952' 9,960' 10 10/29/2016 Open 7-5/813,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open END Oil 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated ;t=C.2`"p 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated =- 18-- Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' Maker Jts 13,394& tt I 13,414" F Fish-WFDSLE Fig&N I 7-5/8"WINDOW DETAIL GENERAL WELL INFO Sol.Chcke w/tlank-7OF 13468 ELMD 5'19/17 11,690'TOP/11,740'Bottom API:50-029-22464-01-00 :a ;� Fsh-WFDSEPWw/ �K`� Original Completion by Doyon 15-7/26/1994 19 3483 ELLMo5/19'1177 Sidetracked and Completed by Doyon 15-2/28/2003 Tap of Siuggits@ 13,520'-3/4/2009 ---II* Set IBP and Sluggits-3/4/2009 :. 20 Perf Add-3/9/2009 Fish- Stiffener- Set WRP-5/11/2009&Perf Add-5/13/2016 2/4/2009 - II' 4-1/r a,:,„ TD=13,860'(MD)/TD=10,355(TVD) PBTD=13,770'ELM(MD)/PBTD=10,288'(TVD) Revised By:TDF 12/13/2017 II 0 . ENDT Well: END ICOT4_10A • PROPOSED Last Completed: 2/22/2003 Hilcorp Alaska,LLC PTD: 202-238 SAFETY NOTE: TREE&WELLHEAD KBE=55.85'/BF Elev=14.5' H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2"Cameron IWell Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 30'4I I OPEN HOLE/CEMENT DETAIL 30" Driven WELL INCLINATION DETAIL .,,._ ? 1 10-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole KOP @ 500' J 7-5/8" 440 sx Class"G"in 9-7/8"Hole Max Hole Angle=53 deg.@ 6,600' 4-1/2" 350 sx Class"G"in 6-3/4"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn ID Top Btm 10-3/4"4 6 30" Conductor N/A N/A Surface 131' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' JEWELRY DETAIL 4 No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail:KBG-2/BK Latch/1"GLV 5 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 II 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,TVD=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,TVD=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-ID=3.813" 7 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-I0=3.813" 11 11,542.5' HES XN Nipple 9Cr-ID=3.725" 12 11,543.4' Baker Liner Tie Back Sleeve $ 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' 14 11,554' Baker ZXP Packer/HRD Setting Tool 4 h:, 15 11,562' Baker RS Nipple-ID=4.88" 10 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger 17 11,573' Cross Over 5-1/2"Hydril 521 x 4-1/2"Hydril 563-ID=3.90" 18 ±13,420' CIBP 11 19 13,504' Weatherford 3.69"WRP-5/11/2009 20 13,571' Baker 3"IBP-2/28/2009 12 Lj ma J 13 PERFORATION DETAIL 14 15&16 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 17 13,336' 13,346' 9,952' 9,960' 10 10/29/2016 Open 7-5/8" 13,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open END Oil 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated MaricerJts @13,394& rOC @±14,005' Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' 13,414' 18 --, Fs''-'"FD VTIDI 7-5/8"WINDOW DETAIL GENERAL WELL INFO Sd.CMke W dank-TOF -yaws FimnS/19/17 11,690'TOP/11,740'Bottom ;.� API:50-029-22464-01-00 Flab-INFOSLE Pis vs, Original Completion by Doyon 15-7/26/1994 ►`21�19 releasable spear-TOF Illg Top of Sluggits @ 13483'EUDy " 's"' Sidetracked and Completed by Doyon 15-2/28/2003 13,520-3/4/2009 Set IBP and Sluggits -3/4/2009 -'! 20 Perf Add-3/9/2009 Fish-Rng St ffener- Set WRP-5/11/2009&Perf Add-5/13/2016 2/4/2009 ---10' ',. 4-1/2" .,. TD=13,860'(MD)/TD=10,355(TVD) PBTD=13,770'ELM(MD)/PBTD=10,288'(TVD) Revised By:TDF 12/13/2017 • 2O z-23� • • -2_13 7z. Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 ®��'�/� Anchorage, AK 99503 Ill Y Tele: 907 777-8337 Hilcorp Alaska,11.1A: Fax: 907 777-8510 DATA LOGGED OCT 24 2017 E-mail: doudean@hilcorp.com \o/S1/2o11 ;wl,K.BENDER DATE 10/23/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 4-10A 202-238 Prints: GR/CCL Packer Setting Record CD's i_. Hilcorp SDI 4-10A PACKER 11SEP17_FINAL 9/22/2017 12:34 PM File folder Please include current contact information if different from above. A,'Ai000 FEB 2 8201& Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8m� P"7 Date: STATE OF ALASKA ALTA OIL AND GAS CONSERVATION COMAtION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown LI Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory❑ 202-238 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22464-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED E ADL0312828 DUCK IS UNIT SDI 4-10A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NOV' 21 2016 N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: AOGCC 13,504, 13,520& Total Depth measured 13,860 feet Plugs measured 13,770 feet true vertical 10,355 feet Junk measured 13,635 feet Effective Depth measured 13,504 feet Packer measured 11,498&11,554 feet true vertical 10,083 feet true vertical 8,529&8,565 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' NIA N/A Surface 3,993' 10-3/4" 3,993' 3,696' 3,580psi 2,090psi Production 11,690' 7-5/8" 11,690' 8,841' 8,180psi 7,150psi Liner 2,317' 4-1/2" 13,860' 10,355' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED MAR True Vertical depth See Attached Schematic r ` , 1! Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13Cr80/VAM ACE 11,555' 8,565' 7-5/8"x 4-1/2"S-3 1,530 MD Packers and SSSV(type,measured and true vertical depth) 7-5/8"x 5-1/2"LT ZXP HES HXO SSSV See Above 1,523 ND 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 382 27,030 1,727 1,450 2,559 Subsequent to operation: 649 37,288 1,090 850 2,155 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development"' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-511 Contact Taylor Wellman -1 Email twellman a(�hilcorp.com Printed Name ike Dunn Title Operations Manager Signature Phone 777-8382 Date 11/18/2016 -Y.6- -/ . 4" ' o044 1/1‘1. RBDMS l,t/ NOV 1 8 2016 Form 10-404 Revised 5/2015 Submit Original Only • • ENDICOTT , H Well: END 4-10A SCHEMATIC Last Completed: 2/22/2003 Mean)Alaska,LLC PTD: 202-238 KBE=55.85'/BFEIev 14.5' SAFETY NOTE: TREE&WELLHEAD H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2"Cameron Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 3� OPEN HOLE/CEMENT DETAIL 1 30" Driven ,4410-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole 7-5/8" 440 sx Class"G"in 9-7/8"Hole 4-1/2" 350 sx Class"G"in 6-3/4"Hole 21 WELL INCLINATION DETAIL 10-3/4"4KOP @ 500' Max Hole Angle=53 deg.@ 6,600' CASING DETAIL 3 Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A N/A Surface 131' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' TUBING DETAIL • 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' 5 JEWELRY DETAIL No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 6 GLM Detail:KBG-2/BK Latch/1"GLV I 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 7 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,TVD=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,TVD=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-ID=3.813" 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-ID=3.813" 11 11,542.5' HES XN Nipple 9Cr-MIN ID=3.725" 8 12 11,543.4' Baker Liner Tie Back Sleeve 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' { e-' 9 14 11,554' Baker ZXP Packer/HRD Setting Tool 10 15 11,562' Baker RS Nipple-ID=4.88" 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger MN ID=3.725"@ 17 11,573' Cross Over 5-1/2"Hydril 521 x 4-1/2"Hydril 563-ID=3.90" 11,543' ------0. 11 18 13,504' Weatherford 3.69"WRP-5/11/2009 12 19 13,571 Baker 3"IBP-2/28/2009 L J 13 20 13,860' 4-1/2 Liner Shoe ' 14 PERFORATION DETAIL !i. 15816 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7-5/8' 13,336' 13,346' 9,952' 9,960' 10 10/29/16 Open MarkerJts@13,3948, 13,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open 13,414" END Oil 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated 0. .lig 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated Top ofSluggts@ 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated 13,520'-3/4/2009 1.11:4 Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' Fish-Ring Stiffener- 2/4/2009 --O.' 7-5/8"WINDOW DETAIL GENERAL WELL INFO r�p 11,690'TOP/11,740'Bottom API:50-029-22464-01-00 4-1/2" a` . Original Completion by Doyon 15-7/26/1994 TD=13,860'(MD)/TD=10,355(TVD) Sidetracked and Completed by Doyon 15-2/28/2003 PBTD=13,770'ELM(MD)/PBTD=10,288'(TVD) Set IBP and Sluggits -3/4/2009 Perf Add-3/9/2009 Set WRP-5/11/2009&Perf Add-5/13/2016 Revised By:JCM 11/03/2016 • a Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-10A E-Line 50-029-22464-00-00 202-238 10/27/16 11/1/16 Daily Operations: 10/26/2016 -Wednesday No activity to report. 10/27/2016-Thursday PT 250/2,900 PSI (GOOD TESTS) PULLED 4.5" BBE SER# H-NBB408 @ 1,495' SLM (1,530' MD). RAN A 20' 3.70" WHIP STOCK BUT SIT DOWN AT 11,657' SLM AND UNABLE TO WORK TOOLS PAST. RAN 10' 3.70" WHIP STOCK BUT SIT DOWN IN THE SAME SPOT AS PREVIOUS RUN @ 11,657' SLM, UNABLE TO GET PAST. RAN 3.5" CENT, 5' 1-7/8"TEM, 3.25" CENT, 10' 3" DRIVE DOWN BAILER AND PASSED THROUGH RESTRICTION AND SAT DOWN ON WRP @ 13,448' SLM (13,483' MD) 10/28/2016- Friday No activity to report. 10/29/2016 -Saturday Move in and rig up on END4-10. Pressure test lube to 250psi low/3,500psi high. RIH, correlate to PDC log 28-Feb-2003, and shoot perforations from 13,336' to 13,346' md. Perf guns were 2-7/8" EHC, 6spf, 60 deg phasing. POOH and RD. 10/30/2016-Sunday No activity to report. 10/31/2016- Monday No activity to report. 11/1/2016 -Tuesday CALL PAD OP TO SHUT IN WELL, PT 250/2,800 PSI (GOOD TESTS.) SET 4.5" BBE SER# HBB-493 IN SSSV NIPPLE @ 1,495' SLM (1,530' MD.) ***DRAW DOWN TEST A PASS***. RDMO. • • SOF T4 I y//*4 THE STATE Alaska Oil and Gas 4, --t •�� 7;'411-- Of TT 11A Conservation COlrimlSslOn 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ;.:.. P Main: 907.279.1433 A ALS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400t,�� 1`` } 3 2 n l . Anchorage, AK 99503 Re: Endicott River Field, Endicott Oil Pool, DIU SDI 4-10A Permit to Drill Number: 202-238 Sundry Number: 316-511 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 6day of October, 2016. RBDMS OCT 1 0 2016 • RECEITtu STATE OF ALASKA 'OCT ALASKA OIL AND GAS CONSERVATION COMMISSION -s� / c 6/ 1 6 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ 202-238 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-22464-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes ❑✓ No 0 DUCK IS UNIT SDI 4-10A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 ENDICOTT/ENDICOTT OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,504',13,520'& 13,860' 10,355' 13,504' 10,083' 2,400 13,770' 13,635' Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' WA N/A Surface 3,993' 10-3/4" 3,993' 3,696' 3,580psi 2,090psi Production 11,690' 7-5/8" 11,690' 8,841' 8,180psi 7,150psi Liner 2,317' 4-1/2" 13,860' 10,355' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13Cr80/VAM ACE 11.555 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7-5/8"x 4-1/2"S-3&7-5/8"x 5-1/2"LT ZXP and HES HXO SSSV 11,498 MD/8,529 TVD&11,554 MD/8,565 TVD and 1,530 MD/1,523 ND 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/17/2016 ❑ ❑ WDSPL ❑ Suspended ID Operations: OIL WINJ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman 'Tse„/ Email twellman(khilcorp.co Printed Name Mike Dunn Title Operations Manager , yon-. Signature 4 Phone 777-8382 Date 10/3/2016 COMMISSION USE ONLY Conditions of approv : Notify Commission so that a representative may witness Sundry Number. llo - SII Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes d No ❑ Subsequent Form Required: /O 1Q'-1 RBDMS Lc--- OCT 1 0 2016 APPROVED BY Approved by: a#A7 p7�'q,, COMMISSIONER THE COMMISSION Date: fel—G _ lc. �l lc ,S• /6 ® Ro1 1 Submit Form and Form 10-403 Revised 11/2045 Approved application a n r t e date of approval. Attachmentss in n Duplicate /bh g ms's- /0-`7/6> . • Add Perf/Contingent Patch Well: DIU SDI 4-10A PTD: 202-238 Hilcorp Alaska,Lb API: 50-029-22464-01 Well Name: DIU SDI 4-10A API Number: 50-029-22464-01 Current Status: Online Field: Endicott Estimated Start Date: Oct 17, 2016 Rig: E-Line Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 202-238 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: WeIIEZ Input Required? Yes Current BHP (Ivishak): 4,065 psi @ 10,000' TVD (Based on offset BHP taken on 08/09/16) MPSP: 2,400 psi SI pressure on 8/9/16 Reference Log: SLB PDC Log GR/CCL dated 28-FEB-2003 Brief Well Summary: The DIU Endicott 4-10A well is a strong performing single zone production well from the K2B. Multiple PNL logs (2002-2005)through time have identified the K3SA zone as fluid bearing with indications of oil. The recent RMT-3D log ran in August 2016 has confirmed these readings. Objective: Perforate the following intervals enclosed in the table below. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 ±13,336' ±13,346' 10' S3A2 Total 10' Table 1: END 4-10A Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" r, Non sundried operations G' ✓ >6 Slickline w• �/./� 1. RU SL unit and pressure test to 250psi low/2,500psi. 2. RIH and pull the 4-1/2" BBSV-from 1,530' md. 3. Drift and tag w/3.6"x20' dummy patch. a. Target depth is 13,450' md. b. If dummy patch will not drift, change length and size of drift to confirm what size will reach depth. 4. RD SL unit. Sundried Operations(Approved Sundry required prior to proceeding) E-Line 5. RU EL unit and pressure test to 250psi low 2,500psi high. 6. MU perforating tool string with 10'of 2-1/8" -2-7/8",6spf,guns. 7. RIH and correlate 1St gun run to Tie-In Log. Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to perforating for final approval of tie in. 8. Perforate as per Table 1: END 4-10A Proposed Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. b. Ensure Correlation Pass and Shooting Passes have CCL displayed for contingency future patch setting correlation. • • Add Perf/Contingent Patch Well: DIU SDI 4-10A PTD: 202-238 Hileora Alaska,Lb API: 50-029-22464-01 9. RD Eline. Slickline 10. RU SL unit and pressure test to 250psi low/2,500psi. 11. RIH and set 4-1/2" BBE SSSV at 1530' md. a. Description of last SSSV set on 08/24/16: 3.813"X-LOCK W/ BBE (SER# HNBB-408) 3 sets std pkg w/std o-rings. See WSR for full details. 12. RD SL unit. Operations 13. Bring well online and flow test for 1-2 weeks. Contingency: If the S3A2 negatively impacts oil production from the K2B Slickline 14. RU SL unit and pressure test to 250psi low/2,500psi. 15. RIH and pull the 4-1/2" BBE SSSV from 1,530' md. 16. RD SL unit. E-Line 17. RU EL unit and pressure test to 250psi low 2,500psi high. 18. MU 4-1/2" special clearance X-Span casing patch toolstring and RIH. a. OD=3.6", Length = 15' element to element. b. Follow E-Line company's running procedure to minimize chances for premature set. 19. Set patch from +/-13,334'—+1-13,349' md. loc.LI c. Final depths to be adjusted to cover perforation interval previously shot. d. The closest casing collar is located at 13,361' md. e. Slack off weight on patch post setting. 20. POOH and RD E-Line unit. Slickline 21. RU SL unit and pressure test to 250psi low/2,500psi. 22. RIH and set 4-1/2" BBE SSSV at 1530' md. (4k b. Description of last SSSV set on 08/24/16: 3.813"X-LOCK WI BBE (SER# HNBB-408) 3 sets std pkg ri‘3if w/std o-rings. See WSR for full details. 23. RD SL unit. 11 • ENDOTT Well:ICEND 4-10A SCHEMATIC Last Completed: 2/22/2003 ffilcorp Alaska,LLC PTD: 202-238 SAFETY NOTE: TREE&WELLHEAD KBE=55.85'/BF Elev=14.5' Cameron H25 Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2" Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 30' OPEN HOLE/CEMENT DETAIL -.' 1 30" Driven ,- ;, 10-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole ar b 7-5/8" 440 sx Class"G"in 9-7/8"Hole 4-1/2" 350 sx Class"G"in 6-3/4"Hole 21 WELL INCLINATION DETAIL 10-3/4"4 KOP @ 500' Max Hole Angle=53 deg.@ 6,600' CASING DETAIL 3 Size Type Wt/Grade/Conn ID Top Btm I 30" Conductor N/A N/A Surface 131' 1 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' ir 1 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' TUBING DETAIL v j 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' ■ _r=." 5 JEWELRY DETAIL i No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 Il 6 GLM Detail: KBG-2/BK Latch/1"GLV 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 I 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 ▪ 7 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,TVD=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,TVD=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-ID=3.813" 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-ID=3.813" 11 11,542.5' HES XN Nipple 9Cr-MIN ID=3.725" 8 12 11,543.4' Baker Liner Tie Back Sleeve _ 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' M� Rte9 14 11,554' Baker ZXP Packer/HRD Setting Tool 10 15 11,562' Baker RS Nipple-ID=4.88" 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger MIN ID=3.725"@ 17 11,573' Cross Over 5-1/2"Hydril521x4-1/2"Hydril563-ID=3.90" 11,543' --------+ 11 18 13,504' Weatherford 3.69"WRP-5/11/2009 12 19 13,571 Baker 3"IBP-2/28/2009 L 13 20 13,860' 4-1/2 Liner Shoe j15&16 PERFORATION DETAIL 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7-5/8" 13,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open Marker is@13,394& 9 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated 13,414" END Oil 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated A.M. 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated Top ofSluggits @ -3/4 13,520-'d4/22009 Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' Fish-RingStffene- .�• 7-5/8"WINDOW DETAIL 2/4/2039 --►16 11,690'TOP/11,740'Bottom GENERAL WELL INFO r: 4-1/2' API:50-029-22464-01-00 Original Completion by Doyon 15-7/26/1994 TD=13,860'(MD)/TD=10,355(TVD) Sidetracked and Completed by Doyon 15-2/28/2003 PBTD=13,770'ELM(MD)/PBTD=10,288'(TVD) Set IBP and Sluggits -3/4/2009 Perf Add-3/9/2009 Set WRP-5/11/2009&Perf Add-5/13/2016 Revised By:TDF 9/30/2016 Aft ENDICOTT H • Well: END 4-10A PROPOSED Last Completed: 2/22/2003 Ilileorp Alaska,LLC PTD: 202-238 SAFETY NOTE: TREE&WELLHEAD KBE=55.85'/BF Elev=14.5' H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/2"Cameron Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K 1 3a' OPEN HOLE/CEMENT DETAIL 30" Driven * 1 10-3/4" 800 sx PF"E",375 sx Class"G"in 13-1/2"Hole 7-5/8" 440 sx Class"G"in 9-7/8"Hole 4-1/2" 350 sx Class"G"in 6-3/4"Hole WELL INCLINATION DETAIL 2' 10-3/4"4 KOP @ 500' Max Hole Angle=53 deg.@ 6,600' CASING DETAIL 3 Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A N/A Surface 131' 10-3/4" Surface 45.5/L-80/BTC 9.950 Surface 3,993' 7-5/8"" Production 29.7/NT95/NSCC 6.875 Surface 11,690' 4 4-1/2" Liner 12.6/13Cr80/Hydril 521 3.958 11,554' 13,860' I TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,555' 5 JEWELRY DETAIL No Depth Item 1 1,530' 4-1/2"HES HXO SVLN-ID=3.813 6 GLM Detail:KBG-2/BK Latch/1"GLV I 2 3,525' ST 6:Port=16,Dev=36,VIv=Dome,TVD=3,353',Date=2/26/03 3 5,182' ST 5:Port=0,Dev=49,VIv=Dmy,TVD=4,445',Date=2/20/03 7 4 6,253' ST 4:Port=20,Dev=49,VIv=SO,TVD=5,161',Date=2/26/03 5 6,994' ST 3:Port=0,Dev=50,VIv=Dmy,TVD=5,626',Date=2/20/03 6 7,734' ST 2:Port=0,Dev=50,VIv=Dmy,TVD=6,107',Date=2/20/03 7 8,517' ST 1:Port=0,Dev=52,VIv=Dmy,TVD=6,606',Date=2/20/03 8 11,477' HES X Nipple 9Cr-I0=3.813" 9 11,498' 7-5/8"Baker S-3 ProductionPacker 10 11,522' HES X Nipple 9Cr-ID=3.813" 11 11,542.5' HES XN Nipple 9Cr-MIN ID=3.725" j. ( 8 12 11,543.4' Baker Liner Tie Back Sleeve _ 13 11,553.6" 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,555' ^# iti 9 14 11,554' Baker ZXP Packer/HRD Setting Tool 10 15 11,562' Baker RS Nipple-ID=4.88" 16 11,565' Baker 7-5/8"x 5-1/2"Flex Lock Liner Hanger MIN ID=3.725"@ 17 11,573' Cross Over 5-1/2"Hydril 521 x 4-1/2"Hydril 563-ID=3.90" 11,543' --- o. 11 18 13,504' Weatherford 3.69"WRP-5/11/2009 12 19 13,571 Baker 3"IBP-2/28/2009 L J 13 20 13,860' 4-1/2 Liner Shoe jWii14 PERFORATION DETAIL 15&16 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7-5/8" li, ±13,336' ±13,346' ±9,952' ±9,960' ±10 Future Future MarkerJts@13,394& 13,450' 13,460' 10,041' 10,049' 10 5/13/2009 Open 13,414" END Oil 13,525' 13,535' 10,100' 10,108' 10 3/9/2009 Isolated rm. Top ofSluggits @ I 13,660' 13,690' 10,205' 10,228' 30 2/28/2003 Isolated 13,738' 13,748' 10,287' 10,272' 10 7/6/2003 Isolated 13,520-3/4/2009 i-- Ref Log:SWS PDC GR/CCL 2/28/2003-Angle at Top Perf=39 Deg.@ 13,450' Fish-Ring Stiffener- 2/4/2009 7-5/8"WINDOW DETAIL GENERAL WELL INFO q, 11,690'TOP/11,740'Bottom API:50-029-22464-01-00 4-1/2" Original Completion by Doyon 15-7/26/1994 TD=13,860'(MD)/TD=10,355(TVD) Sidetracked and Completed by Doyon 15-2/28/2003 PBTD=13,770'ELM(MD)/PBTD=10,288'(TVD) Set IBP and Sluggits -3/4/2009 Perf Add-3/9/2009 Set WRP-5/11/2009&Perf Add-5/13/2016 Revised By:TDF 9/30/2016 • • R. €. = ' Post Office Box 244027 ,.. Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 201 Lj 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 �Q �3 Anchorage, AK 99501 ' /OA I `?iD` / �� Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp I • I Orig • l I New API WellNo PermitNumber WellName I WeIlNumber WellNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/135 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/140 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 (,) 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/1<38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/1<34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/1<41 4-50 ) ) 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. ~ O~ - ~3cg Well History File Identifier Page Count from Scanned File: <3' Lf (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: v"'" YEf>. NO Helen( Maria) Date: if 7 0$ Isl nw , ~ If NO in stage 1, page(s) discrepancies were found: YES NO Organizing (done) o Two-sided 11I1111111111111111 R~AN \¥f Color Items: DIGITAL DATA ~skettes. No. I o Other, NolType: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: Helen ... ~ Project Proofing BY: Hele~ Maria ') Scanning Preparation ~1 'D c/-. x 30 =lP BY: HelenÇ.Maria ') Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other::. 1 Date: tf Z OS- Isl mP J/1AQ Date:lf 7 os- /51 , VI + ~ = TCTAL PAGES <?3 (Count ~OjS ,ot ir ~Iude cover sheet) 1/1.11. .p Date: 'í 7. ï Isl .. r , I Date: 151 I II 111111111111111111 Date: 151 Quality Checked 1111111111111111111 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 2.0P-- 2-3 n\/1-7 Mr. Jim Regg , � Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 4 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 4 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) Endicott Row 4 Date: 10/07/10 Corrosion initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na pal END4-02 / 0-28 1880220 50029217890000 0.3 NA 0.3 NA 1.70 9/29/2010 EN D4-04 / T -30 2090190 50029219680100 4 2.0 0.8 922010 3.40 9/29/2010 END4-06A / 0-30 1961680 50029217230100 4 3.0 0.1 9/8/2010 2.55 9/30/2010 EN D4-08 / P -27 1870080 50029216920000 5 3.0 0.8 9/2/2010 6.00 9/30/2010 END4-10A / L -28 2022380 50029224640100 15 12.5 0.5 9/6/2010 1.70 9/30/2010 END4 -14A / S-37 2080120 50029218630100 0.3 NA 0.3 NA 1.70 9/30/2010 END4 -18 / S -30 1881490 50029218960000 7 2.0 0.8 9/2/2010 4.30 9/30/2010 END4 -20 / M-35 1861730 50029216400100 1.5 0.5 0.4 9/6/2010 2.55 10/42010 END4-26 / 0-34 1880720 50029218350000 1.2 NA 1.2 NA 10.20 10/42010 END4 -28 / N -37 1881110 50029218700000 2 1.0 0.5 9/62010 3.40 10/4/2010 END4-32 / K -38 1950690 50029225590000 6 6.0 0.7 9/2/2010 6.80 10/42010 END4 -34 / 0-38 1961550 50029227050000 4 1.0 0.3 9/6/2010 1.70 10/42010 EN D4-38 / K-34 1940740 50029224820000 10 7.0 0.3 9/6/2010 1.70 10/42010 END4 -40 / P-43 1920420 50029222650000 1.5 0.3 0.4 9/6/2010 3.40 10/42010 END4-42 / P -38 1870560 50029217310000 0.5 NA 0.5 NA 3.40 10/42010 END4 -44 / M-44 1920190 50029222540000 1.5 0.3 0.5 9/6/2010 1.70 10/42010 END4 -46 / N-39 1890690 50029219570000 3 2.5 0.8 9/6/2010 5.10 10/4/2010 END4 -48 / K-43 1890970 50029219720000 4 2.0 0.8 9/62010 5.10 10/4/2010 EN D4-50 / K-41 1890440 50029219400000 1.3 0.1 0.3 9/6/2010 , 1.70 10/4/2010 0 • WELL LOG LA S TRANSMITTAL S 11. PROAcrivE DiAgNOnic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. j Petrotechnical Data Center Attn: �� I Attn: Joe Lastufka "0"'' r LR2 - 1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. ^ 93 ( Attn: Robert A. Richey 130 West International Airport Ro.. J090 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - STP 24- Mar-11 4 -10A / L -28 BL / EDE 50 -029- 22464 -01 2) RECEIVED Signed : Date : APR 1 9 2011 Print Name: ° & , =, COM ' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E : pdsanchoraaeWmemorvloa.com WEBSITE : WWW.memoryloa.com C:\Docaments and Settings\Diane Williams \Desktop \ BP_Transinit.docx • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 01, 2009 3:05 PM To: Gary Preble (SAIC) Subject: 4-10A/L-28 ~ e"x ~-~ ~'~ Gary, I am reviewing the 404 for the recent (3/10) perforating work. I note on the "pert' record that there was some BP work in February. Was a 404 submitted to cover that work? I don't show that I have seen any other work on this well. It might be in house and I haven't gotten to it yet. If you haven't filed a 404, it is appropriate to send in the work summary and I will attach it to the 404 I have. Call or message with any questions. Tom Maunder, PE AOGCC .-;.~>;;=~~~ APB ~ ~- ~~~ Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Wednesday, April 01, 2009 3:26 PM To: Maunder, Thomas E (DOA) Subject: Emailing: 4-10A-L-28-WORK SUMMARY-ATTACH.PDF Attachments: 4-10A-L-28-WORK SUMMARY-ATTACH.PDF 4-10A-L-28-WORK SUMMARY-ATTACH.. I searched back to 2/1/09 and found this work that had been done also. The message is ready to be sent with the following file or link attachments: 4-10A-L-28-WORK SUMMARY-ATTACH.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «4-10A-L-28-WORK SUMMARY-ATTACH.PDF» a` STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION '~~~ 2 3 2009 ~-as o9 REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ ~,;~ ~, ,~,~ ~, 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' - Exploratory ~ 2o2-23so 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22464-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 55.67 KB - 4-10A/L-28 8. Property Designation: 10. Field/Pool(s): ADLO-312828 - ENDICOTT Field/ ENDICOTT OIL Poo! 11. Present Well Condition Summary: Total Depth measured 13860 - feet Plugs (measured) None true vertical 10355.36 feet Junk (measured) 13635' 214/09 Effective Depth measured 13770 - feet true vertical 10288.53 - feet Casing Length Size MD TVD Burst Collapse Conductor 94 30" 37 - 131 37 - 131 Surface 3952 10-3/4" 45.5# L-80 41 - 3993 41 - 3696 5210 2480 Production 11649 7-5/8" 29.7# nt-95hs 40 - 116920 40 - 8651 8180 5120 Liner 2317 4-1/2" 12.6# 13cr80 11549 - 13886 8561 - 10359.8 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 11555 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BBE SCSSSV 1530 4-1/2" Baker S-3 Perm Packer 11498 5" Baker ZXP Top Packer 11560 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 371 11158 43 2778 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 3/19/2009 Form 10-404 Revised 04/2006 ~----- ~- ~"• ~ ~~~~ ~ ~ ~~~~ Submit Original Only ff~. ~.. ~"<< 4-10A/L-28 202-238 PERF OTTOCHMENT u • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 4-10AIL-28 12/14/02 AB 13,668. 13,748. 10,211.72 10,272.18 4-10AIL-28 2/28/03 PER 13,668. 13,698. 10,211.72 10,234.59 4-10AIL-28 7/6/03 APF 13,738. 13,748. 10,264.71 10,272.18 4-10AIL-28 2/4/09 BPS 13,540. ~/' 13,668. 10,111.15 10,211.72 4-10AIL-28 2/6/09 BPP 13,540. ~/ 13,668. 10,111.15 10,211.72 4-10AIL-28 2/28/09 BPS 13,580. 13,582. 10,142.72 10,144.31 4-10A/L-28 3/10/09 APF 13,525. 13,535. 10,099.43 10,107.23 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE . ,~ • • 4-1 OA/L-2$ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ATTACHMENT 4-1.-2009 T/110= 29001480/120 Temp= Hot Assist SLB E-line as directed. (Perforating} Pumped 3 bbls neat methanol spear followed by 287 bbks 110* 1 %KCL capped with 17 bbls 70* diesel down TBG, Finai WHP's 0148010 ----SLB still on well on departure----- "Valve position on departure- Swab, Wing= S1 / SSW, Master, IA & OA= Open" __ ......... ._... N .~.. __....... _ ......................v ..._ ...__.~.. __~ _ ...._.... 213/20091***WELL FLOWING ON ARRIVAL*** INITIAL T1110=24501450/0 PSI `'sLRS KILLED WELL WITH 250 BBLS KCL. RIGGING UP FOR CROSSFLOW .CHECK. ***JOB CONTINUES ON 4-FEB-2009*** 21412009;***JOB CONTINUED FROM PREVIOUS DAY*** ?LRS KILLED WELL WITH 250 BBLS KCL. CROSSFLOW DETERMINATION RUN PRIOR TO SETTING BAKER IBP. NO CROSSFLOW Ft~l~Nb~ ;SET BAKER 3 318" IBP AT 13580'. TAGGED TO VERIFY GOOD SET AND ;DEPTH. POOH AND FOUND THAT IBP DID NOT SHEAR AT SHEAR SET POINT BUT RATHER SHEARED AT QUIK DISCONNECT WHICH MEANS ;THAT THE FLOW-THROUGH BYPASS IS NOT SHUT AND THEREFORE WE `DO NOT HAVE A SEALED PLUG. TOP OF IBP TOOL ASSY.13,571.44' AND BOTTOM OF TOOL ASSY AT `13,585.09'. 1.375"JDC FISH NECK ON PULL DISCONNECT AND 1.75"JDC ;FISH NECK ON IBP. 5,500# TO PULL RELEASE. TWO X 6'" LONG SEALING jELEMENTS AND ONE X 1"STIFFENER RING ON PLUG. All VAVLES ;CHECKED FOR CORRECT POSITION, DSO NOTIFIED AND INSPECTED. ~SLlCKLINE WILL NEED TO FISH IBP AND THEN E-LINE TO RESET IBP. i RECOMMEND SETTING 3.0" AS PER PROCEDURE WITH 2-118" CHASSIS AND RUNNING ASSY. WELL LEFT SI. FINAL T/UO = 0/40010 PSI '""~**JOB ATTEMPTED AND NOT COMPLETED***** 21612009;*"* WELL SHUT IN PRIOR TO ARRIVAL ***(pre adperf} FISHED 3-318" E-LINE HEAD &IBP -MISSING BOTH SEAL~~AND 'STIFFENER RING ~3 ATTEMPTS T ECOVER ELEMENTS W/DIFFERENT SPEAR CONFkGURATIONS RAN 3.5"/3.6" BARBELL W/ 3-112" BLB & 3 PRONG SPEAR TO 6963' SLM & JOB CONT ON 2/7/09*** • • 217/20091***JOB CONT. FROM 2/6!09*** (pre adperf} SET 4112" BBE (SER#NBB-58). UNABLE TO COMPLETE DRAW DOWN aTEST. RAN 3.$4 NOGO AND 10' PRONG (ENSURED THAT VALVE FUNCTIONED .AND HAD CONTROL LINE INTEGRITY) *** TURN WELL OVER TO WELL TENDER, UNABLE TO HOOK BAL LINE TO ?PANEL DUE TO MISSING FITTINGS -TENDER NOTIFIED *** 2/22/2009 2/25/2009 ***WELL FLOWING ON ARRIVAL*** {pre adperf 1 IBP} RAN 3.85" GAUGE RING TAGGED 4.5" BBE, PULLED 4.5" BBE FROM 1496' SLM. { SERIAL #NBB-58 }DRIFTED TO 13687' SLM T.D. WITH 3.50" CENTRALIZER 3 3/8" DUMMY GUN, SAMPLE BAILER, OAL OF DRIFT 183". GOT BACK FORMATION SAND AND CEMENT IN BAILER. PULLED 1350 POUNDS OFF of BOTTOM. *** RIGGED DOWN TURN WELL BACK TO WELL TENDER*** ~.. . T11/0=27601470120. Temp=40*. TBG & IA FL's (pre E-Line), TBG FL =well online. IA FL ~ 5182' Sta # 5 (136 bbls}. SV=Closed. WV,SSV,MV,=Open. IA & OA = OTG. 2/26/2009iT/110 - 24601460/0+. Temp = SL TBG FL pre E (below sta #1 }{175 bbls}. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. ne. TBG FL @ 11500' _._...._....._...... ---____....._._.,..~...._._.~....._..._..._ ........................~.....,..._..__......_......._........_._....~...__....._..----.__............_---.__.........._._......_..._.._.~..a,..............._.......,._ 2/27/2009 ~ ***SET IBP**** 'WELL SHUT IN ON ARRIVAL. INITIAL T1110 = 2650142010. 'RIH WITH BAKER IBP, MAX OD 3.04", LENGTH = 37.3'. ATTEMPTED TO ±SET IBP, BUT IT APPEARED THAT THERE WAS NO FLUID AT SET DEP1 ***JOB CONTINUED ON 28-FEB-2009*** " ~ ~ ~ 2127/2009;TlI/O = 2600!450/0+. Temp - SI. _~ & IA FL (pre EL). No At. line. 1' FL @"__..,_.._. 16690' (102 bbl) between Sta #4 {OGLV} & Sta #3 (DGLV), IA FL aQ 5185' {136 ;bbl} Sta #5 {DGLV). WV, SV =closed. SSV, MV =open. IA, OA = OTG. _.. _ _ ._ 2l28/20093T1110=2500/420!0 Assist E-L~ne, Load Tbg {Perfs) Pumped down Tbg with 5 bbls neet meth spear followed by 292 bbls 1 °1o KCL, then 5 bbls neat meth !followed by 25 bbls diesel to iaad welt far E-Line. E-Line on well at time of jdeparture. IA and OA open to gauges. Operator Notified. FWHP's=100146010. 2/28/2009i***JOB CONTINUED FROM 28-FEB»2009*** '':TIl/0 = 2600/420/0. FINISH POOH WITH IBP. BAKER REDRESSED TOOL. LRS KILLED WELL 'WITH 290 BBL 1°lo KCL. RIH WITH BAKER 1BP FOR 2ND ATEMPT. BAKER PUMP FAILED, POOH. PLUG SET ON 3RD RIH. MAX TOOL OD = 3", LENGTH = 37.3'. PLUG SET 'AT 13580' CENTER OF ELEMENT {ELEMENTS = 2 X 6" AND 1 X 1"), TOP OF FISHING NECK AT 13570.9' (FISHING NECK = 1.375" OD 5,500# DSO NOTIFIED OF VALVE POSITIONS ON DEPARTURE IN. FINAL T/l!O =19001450/0. ***JOB COMPLETE"** ***WELL SHUT 1N ON ARRIVAL*** PARTIAL RIG UP, HOLD OFF FOR WEATHER ***GO ON WEATHER TICKET 3/2/2009***CONTINUE JOB FROM 313/09 WSR*** R[GGED UP, WAITED FOR HOT TAP JOB NEAR BY TO FINISH. ABORTED JOB FOR NOW DUE TO LR5 P&A JOB NEAR BY. ***WELL LEFT SJt, JOB INCOMPLETE*** WELL LEFT SHUT 3/312049 3/4/2009 ?009 • *''* WELL SHUT IN PRIOR ARRIVAL **"(pre add perf} _ .......................w.._.._.._...._.....~.... TAGGED IBP (cD 13513' SLM WI 3" DUMP BAILER & DUMPED SLUGGITS '`**JOB CONTINUED ON 3!4/09*** ***JOB CONT. FROM 3/3/49**" DUMP 150# - 3 BAGS OF SLUGGITS ON TOP OF IBP @ 13,520`SLM W/3.4" DUMP BAILER *** TURN WELL OVER TO DSO -LEFT WELL SHUT IN *** Tlll0=3041450/8. Temp-Sl. TIFL -PASSED (close approach to END 4-04). No AL. IA FL aQ 5182' (sta# 5, 136 bbl). Stacked TBG to 1654 psi w/AL gas from well # 14 in 34 min. IA FL unchanged. Monitor 1 hr. !A FL unchanged. Final W HPs=1654/450/8. SV, WV=Closed. SSV, MV=Open. IA&OA=OTG. NOVP. 4-10A/L-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/9/2009 *** JOB START *** WELL SI ON ARRIVAL MASTER OPEN, SWAB CLOSED, IA/OA OTG, INITIAL T/I/O = 850/400/0 PSI. ***JOB CONTINUED ON 10-MAR-09*** 3/10/2009 T/I/O = 850/450/10. Temp = SI. TBG FL, depress TBG FL to - 300'-400' (pre- adperf). No AL. TBG FL @ 180' (3 bbl). DSO lined well up to LP & opened WV, TP decreased to 480 psi, TBG FL rose 50' to 130'. ***SLB in control of well*** SV, WV=Shut. SSV, MV=Open. IA & OA=OTG. NOVP. 3/10/2009 *** JOB CONTINUED FROM 9-MARCH-2009 *** RU ELINE, PERFORATION GUN, 3.38" HSD 6SPF 60 DEG PHASED PJ3406 GUN MEMORY FAST GUAGE, LENGTH = 26', MAX OD = 3.63" AFTER SHOOTING. SHOT 13525'-13535' DEPTH CORRECTED TO PDC LOG DATED 2-28-03. ALL SHOTS FIRED. GOOD DATA COLLECTED FROM FAST-GAUGE. RAW DATA INDICATES BHP = 4285 PSI PRIOR TO SHOOTING AND 4290 PSI AFTER SHOOTING. BURST DATA ALSO COLLECTED. ALL DATA TO BE UPLOADED INTO INTERACT. DSO NOTIFIED WELL READY TO POP, CURRENTLY SHUT-IN. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total 02/24/09 ~1li~'~~~ril-~ri:~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wcll ~..~. u N0.5109 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-43 AZCM-00001 - - FMI ~p« 1y2g/O8 c~ color 1 cu 1 P2-41 AWL9-00009 SCMT - 01/01/09 1 1 MPS-43 AZCM•00001 SONIC SCANNER / 1y2g/Og 1 1 S-26 AYTU-00014 PRODUCTION PROFILE ~ ~ _ `~~ ` 02/16/09 1 1 F-45A AYLF-00018 LDL ~~?J~ ~~ ~/1~~ 02/24/09 1 1 4-04/T-26 12083416 MEM LDL - Co - 02/21/09 1 1 09-34A AZ4l)-00005 USIT - ~- 02/07/09 1 1 W-218 11968975 USIT (REVISED) ~ ~~.( / 12/11/08 1 1 L2-18A 11999063 RST ( 11/29/08 1 1 L2-33 11999065 RST - ~( 12/07/08 1 1 4-10A/L-28 12017518 RST - 09!26/08 1 1 W-218 11968975 CH EDIT PDC GR (USIT) 12/11/08 1 PLEASE ACKNOWLEDGE RE CEIPT Rv SiGNI Nl3 eNn L~CTI lo~u~lr_ n~lo r~nnv ~...., T.,. ~"---°' BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Stree 1 1 00"``x- Anchorage, AK 995~~ ate. ATTN: Beth Received by: • 1~ 02/18/09 ~~~~~m~~h~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,. i. a. s w Wcll _Inh fk 1 .,.. nse....:..~:.... N0.5089 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Ilw~w DI !-..Iw- /~h R-40 AWJI-00012 MEMORY GLS ( - fP 12/12/08 1 P2-35 AWL9-00010 BAKER IBP/CROSSFLOW DETERM - [ 01/02/09 1 1 P2-20 AYTO-00004 PRODUCTION PROFILE - ~ d C 02/05/09 1 1 4-10A/L-28 AYKP-00009 IBP/CROSSFLOW DETERMINATION 02/04/09 1 1 B-36 11999060 RST ( (q/ 11/10/08 1 1 11-32 12071914 RST ~ 11/30/08 1 1 C-23C AXOY-00006 MCNL a 12/11/08 1 1 L2-16 12071912 RST ~- 11/28!08 1 1 L2-32 12113026 RST ~~ ~ '~ .- '-~- 17J07/08 1 1 L2-24 12113025 RST ~ 12/06/08 1 1 F'LCA.7C AVI~IVVVV ~,CUUC FICGt1Y1 CST SlUrvlrvl7 HNU lit! UFSNIIVC9 Urvt GUYT tAGFI 1 U: BP Exploration (Alaska) Inc Petrotechnical Data Center LR~ ' °"~~ I a ;; 900 E. Benson Blvd. .~_ " P'. -~, ~~ k -~ Anchorage, Alaska 99508 Date Delivered: .~ ~l,~~a~~ fig, d._ r'~I~ ~ ,_ .'~ r'' ,mUt~"d~tlt9 I~~'=11 '~\~iY .~. _~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth \ t Received by: t • e e WELL LOG TRANSMITTAL ;;09--;(35 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'11 Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 ) ~L(Jo9 RE: MWD Formation Evaluation Logs 04-lOA / L-28, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 04-1 OA / L-28: LAS Data & Digital Log Images: 50-029-22464-01 1 CD Rom ~Q~o ~ Q g;\Olo e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker.doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# 10679056 11054181 10662951 10942212 10715445 ;to.).. - Â'J,! 4-10AlL-28 ","0 S" ~orJ F-34B IRr- ')...1? H-26 ..2.u,,-d~'8 J-16A /-b} -Ö').~ 07-30A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 3ô Log Description RST MCNL RST MCNL MCNL (PRINT SENT 1/24/05) ~.~\- SCANNED NO\! 0 92D05 Date 02/03/04 05/31/05 09/17/03 05/06/05 12/09/04 09/28/05 NO. 3476 v;a- d-.3 <6 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color CD 1 --- 1-- t '3 '303 1/ 1...... /.3 J 00/ 1-- 1"- 1') 'So r 1 ~ L.... J3]Gfc 1-- 13 )<J7 ~ ~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK L9503 838 ~ ATTN: Beth I ¡-í j Received by: N .. Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well j,/MPF-57A 1.0) . , ti7 ,,' 02-28A /J.... \') li .~ i ft¡ y ..í DS 18-23A \ G\ 3 "- Ie¡ I / OWDW-SE i f:ì C '" 1.) q v E-23B (2 Cc . ({ " ~ v E-23B . I ¡!. ~~ (., P-06A ¡ C( 7 -),). t.-Î ¡/ Y-09A 1 q 7 M ê <~J i/ P2-49 0ì ,1 - c).. ....1 ,- DS 04-23A 1 ~}. I YJ v ·D.S. 16-01 I is () - Y 3 ~ ,/ 4-10A/L-28 .2~ '" .:lJ 3 .,;" 01-49/P-21 f8g- q 73 ...····01-57/R-23 /j"l :~- ¡fL.1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Job# 10672349 10928607 10942206 10893097 10889133 11039119 N/A 10942222 11062633 11051072 1105228 10662991 11072870 11072871 ;~CI,.4N~\!E[ SEP Log Description CHANNEL DETECTION LOG MCNL MCNL RST -BORAX CHANNEL DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG MEM PPROF WIDEFT PRODUCTION PROFILE W/DEFT PRODUCTION LOG WIDEFT INJECTION PROFILE U r èv. RST PRODUCTION PROFILE W/GHOST PRODUCTION PROFILE W/GHOST Date Delivered: ) 0/ clJlJ l,,- _. ""onE n ~:. l U J ~.. t.i" ~ Date 01/24/04 12/11/04 04/20/05 03/25/05 07/16/04 05/08/05 06/04/05 07/14/05 07/02/05 07/13/05 07/21/05 02/05104 07/11/05 07/12/05 08/04/05 NO. 3447 Q o~';r=~'/ð Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 Color CD 1 JJ",q: 1 1'3 ::11 g 1 iJ ,1 :1 CJ ~ 1 1 1 1 1 1 1 1 1 1 1 1 -- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9~.Þ~3~~38 I , I / A TTN: Beth F ! / / í~J5 I I J f\;// . ~/ / / ~ /I Received by: ~~/"f.Þ-1 !v7/,v---6-.l ~~ {/~t/ t .r, v . ~f Permit to Drill 2022380 MD 13860 c/ ---_._~- REQUIRED INFORMATION -------- 1/2. ð r'1ð, ^--~ ç- DATA SUBMJTTAL COMPLIANCE REPORT 3/7/2005 Well Name/No. DUCK IS UNIT SDI 4-10AlL28 Operator BP EXPLORATION (ALASKA) INC TVD 10357./ Completion Date 2/28/2003 / Completion Status i-Oil Current Status 1-01l SC'-V J. Lf filÁ~ ~ '1 AP¡' No. 50-029-22464-01-00 UIC N Mud log No Samples No Directional surveyGJ ~ DATA INFORMATION Types Electric or Other Logs Run: MWD, ,WD, PWD, RES,GR, NEUTRON/DENSITY Well Log Information: Log/ Electr Data Digital Dataset Log Log Type Med/Frmt Number Name Scale Media --- - --- -~ ~ 0 ~02 Rpt ~ '\~ cE1J. C ~ r- 12020 ED C Pds ~20 (data taken from logs Portion of Master Well Data Maint) Run No Interval OH / Start Stop CH ~ Received Comments An H2S Measurement is requi¡ed to be submitted. This record automatically created from Permit to Drill Module on: 1/9/2003. LIS Verification .b!§ Verifi,..ati..A1 3 3 9344 13809 Open 6/12/2003 9344 13809 Open 6/12/2003 ~ ~ ~u.r~'\ ,-tc' ~ ç Cr. C ~ u y? I . I I Directional Survey Directional Survey LIS Verification 11599 11599 8990 13860 Open 4/17/2003 13860 Open 4/17/2003 13777 Case 6/10/2003 Rpr c.t2020 Casing collar locator Casing collar locator 5 8990 13777 Case 6/10/2003 5 Blu 8990 13777 Case 6/10/2003 Sample Set Sent Received Number Comments Well Cores/Samples Information: Name Interval Start Stop A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/9/2003. Wireiine data for Primary Deptn Control, GR, CCl Primary Depth Control, GR, CCl Primary Depth Control, GR, CCl - DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022380 Well Name/No. DUCK IS UNIT SDI 4-10AlL28 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22464-01-00 MD 13860 TVD 10357 Completion Date 2/28/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION yGtJ Chips Received? ~ Y J N Daily History Received? .!i)N Formation Tops ~ Well Cored? Analysis V. I N Received? -------- Comments: --~ ~ Compliance Reviewed By: la Date: ) fJ-p DllJ ( - ~ .-- ) ) c2ð2 - 2:3? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 October 26, 2004 RE: MWD Formation Evaluation Logs: 04-10A / L-28, AK.-MW-2259994 04-10A / L-28: Digital Log Images: 50-029-22464-0 ] 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: I¥i~ x".,.. , STATE OF ALASKA '). ALASKJ-\ ÓIL AND GAS CONSERVATION COIV..",jSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD OtherD Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2380 Name: BP Exploration (Alaska), Inc. Development [][I ExploratoryD 55.67 8. Property Designation: ADL-312828 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 4-10AlL-28 10. Field/Pool(s): Endicott Field I Endicott Oil Pool, Duck Island Unit Service D 6. API Number 50-029-22464-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 13860 feet true vertical 10355.4 feet Effective Depth measured 13770 feet true vertical 10288.5 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 94 30" Conductor 37 131 37.0 131.0 Liner 2317 4-1/2" 12.6# 13Cr80 11549 - 13866 8561.4 10359.8 8430 7500 Production 11649 '1-5/8" 29.7# NT-95HS 41 - 11690 41.0 8651.2 8180 5120 Surface 3952 10-3/4" 45.5# L-80 41 - 3993 41.0 3696.2 5210 2480 Perforation decth: Measured depth: 13668 -13698,13738 -13748 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# 13Cr80 @ 37 11555 @ 1530 @ 11498 @ 11560 RECE\VED JAN 1 5 2004 !"' mfO\SS\OO 0'\ & Gas Cons. \.10 A\aska \ Anc\,Ofsgo True vertical depth: 10211.72 -10234.59,10264.71 -10272.18 4-1/2" BBE SCSSSV 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaae Production or Injection Data Gas-Met Water-Bbl Casing Pressure 11.3 32 600 13 Subsequent to operation: 2454 14.5 42 575 Tubing Pressure 2358 2286 Oil-Bbl Prior to well operation: 2408 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ Service D Contact Garry Catron Printed Name Garry Catron Signature .,21~ Ck-V 16. Well Status after proposed work: Operational Shutdown 0 Oil [][I GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run_ Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Phone 564-4657 Date 1/9/04 Form 10-404 Revised 12/2003 nD'~'~'^J ~:m..,'~!\\.~, '~~li:·' J~¡~llr·L M '1. ,,) lm~ ) ) 4-10A/L-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/04/03 WELL FLOWING UPON ARRIVAL SHUT IN WELL 0830 HRS. PULL SSSV MAKE 2-7/8in DUMMY GUN RUN.T AG TD @ 137161WLM. CORRECTED DEPTH 137561MD NO PROBLEMS ENCOUNTERED RUNNING IN AND OUT OF THE HOLE. RIG DOWN MOVE TO WELL 2-32 RETURN WELL TO PRODUCTION 1330 HRS 07/06/03 Perforate 137381-1374816 SPF FLUIDS PUMPED BBLS o TOTAL Page 1 RT. ELEV = 55.85' BF. ELEV= 14.50' MAX DEV = 54 ' @ 13,700' ) 10.,3/4", 45.5#/ft, L-80,BTC. CSG. I 3,993' I 263JTSA-1/2" 12.~/ft, 13CR L-80 VAMACE TUBING IÞ-A GAS LIFT MANDRELS (CAMCO) KBG2 1"valve BK2 LATCH 1) rvD 3525 3375 . 5182 4442 6253 5150 :8: 6993 5618 7733 6113 ~f 8523 6604 SIDETRACK INFO <XXXX~ <XXXX~ <XXXXI <XXXX <XXX X <XXXX. <XXXX <XXXX_ <~~~ ............ I--IÞ- ~ 1--' SECTION MILL 50' WINDOW 11,690-11,740" 7-5/8" BRIDGE PLUG AT +/-11900' 6-3/4" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TD 13,864' MD, 10,357' TVD PERFORATION SUMMARY REF LOG: SLB GRlCCL 02/28/03 CO. SIZE SPF INTERVAL SWS SWS 27/8 27/8 6 6 13,668-13,698 13,738-13,748 PBTD 7-5/8", 29.7#/ft, NT95HS, NSCC 14,323' 14,409' I , TREE: .4-1/16" 5,000 psi Chrome CIW WELLHEAD: 1? 'J 5,000 psi FMC NS . HES'HXO'$VLN .....-. 3~813"MIN.ID . 1,530" I · -4-1/2" x 1" KBG-2 GAS LIFT MANDRELS I I 4-1/2" 'X' NIPPLE 3.813" ID ~ ......7-5/8" x 4-1/2" BAKER S-3 PACKER 11,498' 4-1/2" 'X' NIPPLE 11,521' k4_1/2" 'XN' NIPPLE ' ::::_,~" x ;-;~~:~EG ':,::. ~-6.42" OD x 5.75" ID TIE BACK SLEEVE 11,549' QS: ....7-5/8"x5-1/2" ZXP LINER PACKER 11,560' ~ 7-5/8"x5-1/2" LINER HANGER 11,570' 11,477' MARKER JOINT 13439-13419 PBTD -13,775' -k- 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" Baker SABL-3 Pkr [ 4-1/2" 'X' NIPPLE (HES) (3.813" ID) I - 4-1/2"'XN' NIPPLE ~ (HES) (3.725" ID) -- 4-1/2" WLEG I 13,527' I 1 13,589' 1 I 13,655' I I 13,713' 1 I 13,723' I I 13,732' I WLEG ELMD TTL LOCATING FINGER. 4-1/2" Long X 1" Wide TOP OF FILL = 14,255' 3/22/99 ~ DATE REV. BY COMMENTS ENDICOTT WELL 4-1 OAlL-28 2-22-03 WRR SIDETRACK-COMPLETION API NO: 50-029-22464-1 2-28-03 RLW PERFORATE COMPLETION DIAGRAM 7-06-03 WRR ADD PERF BP EXPLORATION, INC. 'l~ STATE OF ALASKA "\ ALAS",", ÓIL AND GAS CONSERVATION COf\,.."dSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend D RepairWellD Pull Tubing D Operation Shutdown D Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate D WaiverD OtherD Stimulate ŒJ Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-2380 Name: BP Exploration (Alaska), Inc. Development m ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.67 8. Property Designation: ADL-312828 11. Present Well Condition Summary: StratigraphicD 9. Well Name and Number: 4-10AlL-28 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit Service 0 6. API Number 50-029-22464-01-00 Total Depth measured 13860 feet true vertical 10355.4 feet Effective Depth measured 13770 feet true vertical 10288.5 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 94 30" Conductor 37 131 37.0 131.0 Liner 2317 4-1/2" 12.6# 13Cr80 11549 - 13866 8561.4 10359.8 8430 7500 Production 11649 7-5/8" 29.7# NT-95HS 41 - 11690 41.0 8651.2 8180 5120 Surface 3952 10-3/4" 45.5# L-80 41 - 3993 41.0 3696.2 5210 2480 Perforation depth: Measured depth: 13668 -13698,13738 -13748 RECEIVED True vertical depth: 10211.72 -10234.59,10264.71 -10272.18 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 37 11555 JAN 1 5 2004 Alaska Oil & G C Packers & SSSV (type & measured depth): 4-1/2" BBE SCSSSV @ 1530 as ons C . 4-1/2" Baker S-3 Perm Packer @ 11498 Anch . ommlssion 5" Baker ZXP Liner Top Packer @ 11560 orage 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13668 - 13698, 13738 - 13748 Treatment descriptions including volumes used and final pressure: 75 Bbls 12% Dad Acid 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Prior to well operation: 1741 23.4 36 575 Subsequent to operation: 1774 24.8 37 1700 Tubing Pressure 2621 2363 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ) Service D Copies of Logs and Surveys run_ 16. Well Status after proposed work: Operational Shutdown 0 Oilm GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name EGarry Catron .. Signature ~ C'~, Title Production Technical Assistant Phone 564-4657 Date 1 /9/04 nD1C1f\JAI Form 10-404 Revised 12/2003 _afL JAM 1 ~) 20~ ) ) 4-10AlL-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/09/03 PERFORM 120/0 DAD TUBING ACID WASH AS PER PROGRAM TO CLEAN TUBING PRIOR TO UPCOMING ACID STIMULATION. SAFETY MEETING. REVIEW THA WITH CREW. PRESSURE TEST LINES. PUMP 10 BARRELS OF NEAT MEOH. PUMP 50 BARRELS OF FILTERED SEAWATER. PUMP 12 BARRELS OF 12% DAD ACID. PUMP 192 BARRELS OF FILTERED SEAWATER TO FLUSH. RIG DOWN DOWELL. 10/12/03 T/I/0=2400/360/220. PUMPED 5BBLS METHANOL, 129BBLS INHIBITED SEAWATER, 5BBLS METHANOL, AND 20BBLS DIESEL TO LOAD IA PRIOR TO STIMULUS JOB. FINAL WHP; T/I/O=2400/1060/780. 10/13/03 PUMP 12% DAD ACID STIMULATION SAFETY MEETING. REVIEW THA. PRESSURE TEST LINES. PUMP 5 BARRELS OF MEOH. PUMP 200 BARRELS OF FILTERED SEAWATER. PUMP 75 BARRELS OF 12% DAD ACID. PUMP 172 BARRELS OF FILTERED SEAWATER TO DISPLACE ACID. SHUT DOWN 30 MINUTES TO LET SOAK. PUMP 36 BARRELS OF SEAWATER TO FINISH DISPLACING ACID. PUMP 10 BARRELS OF INHIBITOR TO PROTECT FLOW LINE. POP WELL. 11/21/03 RAN & SET A 3.813 BBEX SCSSSV IN HXO NIPPLE AT 15011 WLM PERFECT SET & PERFECT TEST JOB COMPLETE SCSSSV IN SERVICE (SER# OF SCSSSV IS BB492) FLUIDS PUMPED BBLS 10 Neat Methanal 650 Filtered Sea Water 87 12% Dad Acid 15 100% Methanal 129 Inhibited Sea Water 20 Diesel 10 Inhibitor 921 TOTAL Page 1 RT. ELEV = 55.85' BF. ELEV = 14.50' MAX DEV·= 54 ' @ 13,700' ) 10-3/4",45.5#/ft, L-80, . BTC.eSG. I 3,993' I 263JTS4--1/2~'12,6#/ft,13 CR. L -80 VAM ACE TUBING .A GAS LIFT MANDRELS (CAMCO) KBG2 1"valve BK2 LATCH 1> TVD 3525 3375 . 5182 4442 6253 5150 :8: 6993 5618 7733 6113 ~) 8523 6604 SIDETRACK INFO <XXXX~ <XXXX~ <XXXXI <XXXX <XXX X <XXXX_ <XXX X <XXXX_ <~~ ............. 1-. i. 1-' SECTION MILL 50' WINDOW 11,690 -11,740" 7-5/8" BRIDGE PLUG AT +1-11900' 6-3/4" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TD 13,864' MD, 10,357' TVD PERFORATION SUMMARY REF LOG: SLB GRlCCL 02/28/03 CO. SIZE SPF INTERVAL SWS SWS 27/8 27/8 6 6 13,668-13.698 13,738-13,748 PBTD 7 -5/8", 29. 7#/ft, NT95HS, NSCC 14,323' 14,409' TREE: 4~1/16" 5,000 psi Chrome CIW WELLHEAD: 1:")5,000 psi FMC NS ...- ~ HES 'HXO'SVLN 3;813"MIN.ID 1,530" l · -4-1/2" x 1" KBG-2 GAS LIFT MANDRELS I , 4-1/2" 'X' NIPPLE 3.813" ID 11,477' ::8: ~7-5/8" x 4-1/2" BAKER S-3 PACKER 11,498' 4-1/2" 'X' NIPPLE ./ 3.813" ID ~4_1/2" 'XN' NIPPLE 11,542' ./ 3.725" ID 4-1/2" x 5-1/2" WLEG 11,554' ~-6.42" OD x 5.75" ID TIE BACK SLEEVE 11,549' ~ ....7-5/8"x5-1/2" ZXP LINER PACKER 11,560' ~7-5/8"x5-1/2" LINER HANGER 11,570' 11,521' MARKER JOINT 13439-13419 PBTD -13,775' I , -k- 4-1/2" 'X' .N. IPPLE (HES) (3.813" MIN. ID) 7-5/8" Baker SABL-3 Pkr [ 4-1/2" 'X' NIPPLE (HES) (3.813" ID) I - 4-1/2" 'XN' NIPPLE l (HES) (3.725" ID) -- 4-1/2" WLEG I 13,527' I I 13,589' I I 13,655' I I 13,713' I I 13,723' I I 13,732' I WLEG ELMD TTL LOCATING FINGER. 4-1/2" Long X 1" Wide TOP OF FILL = 14,255' 3/22/99 ~ DATE REV. BY COMMENTS ENDICOTT WELL 4-1 OAlL-28 2-22-03 WRR SIDETRACK-COMPLETION API NO: 50-029-22464-1 2-28-03 RLW PERFORATE COMPLETION DIAGRAM 7-06-03 WRR ADD PERF BP EXPLORATION, INC. ) ) cl.D~-~3'8 , 1SD~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 09, 2003 RE: MWD Formation Evaluation Logs - 4-1 OA / L-28, AJ(-~-2259994 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI< 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22464-01 RECEIVED JUN 1 2 2003 AJaskaŒi & Gas ~~n Anch~ ~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503·5711 A TTN: Beth Well 2-28B/0-19 ;J.Ö:3-œJ{O 2-28B/0-19 ;:}..03 -COlQ 3-17E/K-30~.' ~ ~~Lr- 3-25B/L-27<J 03 ~ 4-10A/L-28 t"'J'ri.- ~ ~ ~ Job# 23205 23204 23292 23256 23321 Log Description PDC GRlCCL RST SIGMA PDC GRlCCL PDC GRlCCL PDC GRlCCL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~t<\~ tv /' (Ò - 03 06/03/03 NO. 2872 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott Color Date Blueline Prints CD 04/12/03 1 1 /~g{~ 04/12/03 1 1 02/25/03 1 1 h~ 04/29/03 1 1 02/28/03 1 1 --' -~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth t:{J~(~E\'VED ~//' Received by: \'\ H\i 1 '-I 2003 .... ,,_, .. I \...; i~aska ;J~.; ::~ :~~;¿2 CQr~s~ i':crnml55iOO f~onGhorltqe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) r.:_~ 1. Status of Well ~ Oil 0 Gas, D Suspended D Abandoned 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2581' NSL, 816' WEL, SEC. 08, T11N, R17E, UM At top of productive interval 5249' NSL, 2555' WEL, SEC. 05, T11 N, R17E, UM X = 268703, Y = 5978799 10. Well Number At total depth 86' NSL, 2617' WEL, SEC. 32, T12N, R17E, UM X = 268645, Y = 5978916 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Endicott Field / Endicott Pool KBE = 55.8' ADL312828 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 2-4-2003 2-16-2003 2-28-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MO+TVD) 19. Directional Survey 13860 10357 FT 13770 10289 FT ~ Yes D No 22. Type Electric or Other Logs Run MWD , LWD , PWD , RES, GR , NEUTRON / DENSITY CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 37' 131' 30" 41' 3993' 13-1/2" 41' 11690' 9-7/8" 11549' 13860' 6-3/4" _~!iOooi~1 1'~V~lEDf 1 D Service : t;': ~I ,; ;~ ,!~~ -.-- ,. r""i' ~~ :"~., ~' 1 ' ~ ~ u ,; , ".f>: tot _ _ ,', 1 1. ..- r I .' .,......,.:--~',... -.. , ~ )di.1tl23 . '~; ~\f r: 1,:~ ~ ;- ~, ';~ . '~.'.:: ,~ ¡¡ ltc ' t,::::.;",:~:,,;··,···,···t 9. , . X = 270221, Y = 5970800 Classification of Service Well 7. Permit Number 202-238 8. API Number 50- 029-22464-01 Unit or Lease Name Duck Island UniVEndicott 4-10A/L-28 15. Water depth, if offshore 16. No. of Completions 6' - 12' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1530' MD 1465' (Approx.) 23. CASING SIZE 30" 10-3/4" 7-5/8" 4-1/2" WT. PER FT. Sturct. 45.5# 29.7# 12.6# GRADE Drive L-80 NT95HS 13CR80 CEMENTING RECORD Driven 800 sx PF 'E', 375 sx 'G' 440 sx Class 'G' 350 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ rvD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD SIZE 4-1/2", 12.6#, CR1380 TUBING RECORD DEPTH SET (MD) 11555' PACKER SET (MD) 11488' 25. MD rvD 13660' - 13690' 10205' - 10229' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 60/40 Methanal 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 28, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 3/3/2003 4 TEST PERIOD 2962 1984 39 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 24-HoUR RATE CHOKE SIZE GAS-OIL RATIO 670 OIL GRAVITY-API (CORR) 21.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~"~ k':""': ~ ff'""" i\ I}: ,....~, ~~ H··-:n 1\ ~ ~I."'"'' ~~. Ii ~ J t: 'l fi:c'~.. .~ E~.i ~ ". .::iI,;~':'-D. ......,...,,~.. No core samples were taken. 'J{, n r¡ 7 C.' ('::" 7, 1't) lot \ {_ ¡ ~'_ ~.' \.~,' "\...' þJa~~ Œ: & (~;EL~.: ~>~;,¡'~~~;. ;~~~"~':"¡~:~~~~';~J' /\;~.};}~·tt:::~: .~. \: } Form 10-407 Rev. 07-01-80 RBDMS 8FL O~~NA:_ ') ,~~~mit In Duplicate ) ) Marker Name Geologic Markers Measured Depth 30. Formation Tests 29. True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. TOP OF KEKIKTUK ZONE 3A 13208' S3A4 13208' TOP OF KEKIKTUK 13208' S3A2 13267' TOP OF KEKIKTUK ZONE 28 13356' TOP OF 2A SHALE 13495' TOP OF ZONE 2A 13574' S2A3 13574' S2A2 13705' S2A1 13736' TOP KEKIKTUK ZONE 1 13777' 9851' 9851' 9851' 9898' 9968' 10075' 10138' 10138' 10240' 10263' 10294' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Pre Rig Summary, Post Rig Summary and a Leak-Off Summary Test. 32. I hereby certify that the fo~going is true and correct to the best of my knowledge Signed so~o~ Title Technical Assistant Date D3 - 2.&-ð::3 4-1 OAlL -28 202-238 Prepared By Name/Number: Sondrs Stewmsn, 564·4750 Well Number Permit No. / Approval No. Drilling Engineer: Fred Johnson, 564-5427 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. I,EM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) Well: Field: API: Permit: Date 4-10A/L-28 Duck Island / Endicott 50-029-22464-01 202-238 Accept: Spud: Release: Rig: 01-25-03 02-04-03 02-22-03 Doyon 15 PRE-RIG WORK 1 0/18/02 LOAD IA WITH 20 BBLS 60/40 MEOH, MIT TO 3000 PSI FOR 30 MINUTES. LOAD OA WITH 1 BBL 60/40 MEOH MIT FOR 30 MINUTES. BOTH IA AND OA PASS 30-MINUTE MIT. 11/10/02 DRIFT TO SSSV WI 3.85 GAUGE. PULL 4-1/2" QOS # QOS- 32. DRIFT TBG & TAG FILL WI 3.625 BARBELL 10' LONG, TEL & SAMPLE BAILER, TAG @ 14,167' WLMD 11/11/02 OOH WI DRIFT (3.625 BARBELL 10' LONG, TEL & SAMPLE BAILER) RECEIVE SAMPLE OF GREEN CEMENT 1 2/09/02 MIRU. KILL WELL WI 526 BBLS 1% KCL. FORMATION TIGHT 2300-PSIINJECTION PRESSURE. TAG @ 14,218' CTMD. MIX AND PUMP 26 BBLS 15.8# CEMENT, LAYING IN 1.2 FOR 1 FROM 14200' TO 13890'. EST 4 BBL SQUEEZED TO FORMATION. EST CMT @ T.T. POOH TO SAFETY @ 12,000'. CLEAN OUT TO 13,730' WITH BIOZAN, JET TO SURFACE AT 80%. FREEZE PROTECT TUBING TO 2000' WITH 60/40 MEOH. 12/14/02 MIT TBG TO 3000 PSI. PASSED TEST. RIH W/1 0' X 3.625" DRIFT TO 2111, WLM, TOOLS COVERED WI PARAFFIN, RIH WI 2.75 CENT SIB TO 13704 SLM, OOH NO SAMPLE BUT CMT ON TOOLS, SWING LUB TO SIDE FOR HOT OIL TO COMPLETE STATE TEST, GOOD, RIH WI BARBELL SET UP. 3.7 SWAGE, 6' STEM, 3.685 SWAGE, S.BLR. DRIFTED THROUGH SPOT AT 2111'. SLOWED DOWN BUT DIDN'T STOP. DRIFTED DOWN PAST BOTTOM MANDREL TO 13350'. POOH.RIH WI 4-1/2 OK-6 KOTW/1-1/4 JDC TO STA 3 AT 12765'. PULLED 1" DGLV, BK LATCH. STA 3 OPEN. 12/1 8/02 PUMPED CIRC-OUT PROCEDURE. PUMP DOWN TUBING TAKING RETURNS UP IA & DOWN THE FLOWLINE OF WELL 4-20. PUMPED 5BBLS NEAT MEOH, 700 BBLS SEAWATER. . 12/19/02 FINISHED PUMPING 703 BBLS SEAWATER. PUMP 3 BBLS NEAT MEOH TO FREEZE PROTECT. PUMPED 90 BBLS DIESEL @ 180* DOWN TUBING 12/26/02 4.5" TUBING CUT @ 12218' WITH 3-5/8" CHEMICAL CUTTER. RAN STRING SHOT PRIOR RUNNING CHC. SHOOT INTERVAL 12205'-12220'. DID NOT TAG TD. TIE-IN TO GLM #3 (12783') AND GLM #4 (11940'). 01/04/03 SET BPV, TUBING PRESSURE = 0, INNER ANNULUS =70, OUTER ANNULUS =150 01/07/03 WELLHEAD PACKOFF TEST, TUBING HANGER TEST PASSED, INNER CASING HANGER TEST PASSED, PPPOT-T PASSED TO 5000 PSI. TORQUED LOS TO 450 FT-LBS, PPPOT-IC PASSED TO 3000 PSI. TORQUED LDS TO 450 FT-LBS. 4-10A/L-28 \ Page 2 ) .)i 01/20/03 PRESSURE TEST BPV TO 1000 PSI PRIOR TO DOYON 15 RIG MOVE. LOOP LIFT GAS FROM ADJACENT WELL AND PRESSURE UP ON IA TO 1000 PSI. HOLD PRESSURE FOR 30 MINUTES. TEST GOOD. BLEED IA TO 0 PSI. 02/20/03 PULL 41/2" DSSSV @ 1535' SL.---EQUALlZE & PULL D-16 CHECK PLUG 02/21/03 DRIFT THROUGH TT TO 11600' SLM, WI 3.60" CENT ---- SET 4 1/2" RHC PLUG BODY 4 X-KEY HIGH PSI LOCK @ 11537' SLM --- RAN CHECK SET (SHEARED) --- SET 4112 DSSSV (2 SETS OF PACKING - 2.60 ID- 37" OAL ) @ 1537' SLM. Well: Field: API: Permit: Date ) ) 01-25-03 02-04-03 02-22-03 Doyon 15 02/25/03 ASSIST DRILL SITE MAINTENANCE TO PULL BPV, PULL D-SSSV @ 1498 WLM, PULL BALL & ROD @ 11477WLM 4-10A/L-28 Duck Island / Endicott 50-029-22464-01 202-238 Accept: Spud: Release: Rig: 02126/03 PULL DGL V ST A # 3 @ 6225 WLM, PULL DCK VALVE FROM ST A # 1 @ 3496 WLM, SET 5/16 SIO IN ST A # 3 SET LGLV IN STA #1 1/4 PORT, 1726 TRO, PULL RHC PLUG BODY @ 11,487' WLM POST-RIG WORK 02/27/03 CIRC WELL OUT - MIRU DS CTU #8. RIH WI 3" JSN- CIRCULATE 10.3 PPG MUD OUT FROM 11560' TO 13754' CTMD AND TAG. PUMPED FLOPRO SWEEP AND 1 COMPLETE BOTTOMS UP WITH SEAWATER. POOH AND LAY IN 21 BBLS OF SEAWATER AND 188 BBLS DIESEL. FREEZE PROTECT COIL WITH 60/40. SECURE WELL, SHUT IN. 02/28/03 LOG GR-CCL (PBMS) AS PDC LOG AN TIE-IN WITH SLB LOG PLUG SETTING RECORD DATED 28-JAN-03 PERFORATE 13,670'-13, 690' WITH 20'X2 7/8 PJ, 6SPF, 60 DEG. TIE-IN TO LWD 17-FEB-03 PERFORATE 13,660'-13, 670' WITH 10'X2 7/8 PJ, 6SPF, 60 DEG. TIE-IN TO LWD. Legal Name: 4-10A/L-28 Common Name: 4-10A/L-28 Test Date 2/4/2003 Test Type FIT Test Depth (TMD) 11,690.0 (ft) BP EXPLORATION Leak-Off -TestSumrnary Test Depth (TVD) 8,651.0 (ft) AMW 9.70 (ppg) Surface Pressure Leak Off Pressure (BHP) 1,100 (psi) 5,459 (psi) EMW 12.15 (ppg) ~/ ~- Printed: 2/24/2003 10:29: 1 0 AM ) ., BPEXPL..ORATIC>N qperati()nsSÛ.rnl1'1ary·..Re.port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10AlL-28 4-1 OAlL -28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From~To Hours TaSk Gode NPT Phase Description of Operations 1/25/2003 00:00 - 11 :30 11.50 RIGU P PRE HELD PJSM. ATTEMPTED TO PRESSURE TEST SURFACE SYSTEM FROM MUD PUMPS TO IBOP IN TOP DRIVE. PRESSURED UP TO 3,000 psi, VALVES ON STAND PIPE FAILED. CONNECTION ON KELLY HOSE FAILED. REPLACED GASKET ON KELLY HOSE. REPAIRED VALVES ON STAND PIPE. ATTEMPTED TO PRESSURE TEST SURFACE SYSTEM FROM MUD PUMPS TO IBOP IN TOP DRIVE. PRESSURED UP TO 3,000 psi, KILL LINE VALVE FAILED, BROKE OUT KILL LINE VALVE AND REPAIRED. 11 :30 - 12:00 0.50 RIGU P PRE HELD PJSM. PRESSURE TESTED SURFACE SYSTEM FROM MUD PUMPS TO IBOP IN TOP DRIVE TO 4,000 psi. SYSTEM HELD WITH NO LEAKS OR PRESSURE LOSS. ALL PRE SPUD ITEMS COMPLETED RIG AUDIT LIST COMPLETED. RIG CREW TRAINING AND ORIENTATION COMPLETED. ACCEPTED RIG @ 1200 HRS 1 / 25 / 2003. 12:00 - 13:30 1.50 WHSUR P DECOMP HELD PJSM FINISHED TAKING ON SEAWATER. R / U TO DISPLACE FREEZE PROTECT FROM WELL. 13:30 - 15:00 1.50 WHSUR P DECOMP DISPLACED FREEZE PROTECT FROM WELL W / SEAWATER. PUMPED DOWN TUBING AND TOOK RETURNS OFF OF IA DOWN HARDLlNE TO WELL 4-02. STAGED UP PUMP AT THE FOLLOWING RATES: RATE PRESSURE TOTAL BBLS PUMPED 2 bpm 500 psi 70 bbls 4bpm 1,000 psi 200 bbls 5 bpm 1,300 psi 240 bbls 7 bpm 1,800 psi 300 bbls SHUT DOWN PUMPS 15:00 - 15:30 0.50 WHSUR P DECOMP SHUT DOWN TO ALLOW ENDICOTT PLANT TO PROCESS FLUID AND TO ALLOW DIESEL TO SETTLE. 15:30 - 16:30 1.00 WHSUR P DECOMP RESTARTED PUMPING TO DISPLACE FREEZE PROTECT FROM WELL AS BEFORE. STAGED UP PUMP AT THE FOLLOWING RATES: RATE PRESSURE TOTAL BBLS PUMPED 2 bpm 500 psi 340 bbls 4 bpm 1,000 psi 420 bbls 7bpm 1,800 psi 525 bbls SHUT DOWN PUMPS 16:30 - 17:00 0.50 WHSUR P DECOMP SHUT DOWN TO ALLOW ENDICOTT PLANT TO PROCESS FLUID AND TO ALLOW DIESEL TO SETTLE. 17:00 - 18:30 1.50 WHSUR P DECOMP RESTARTED PUMPING TO DISPLACE FREEZE PROTECT FROM WELL AS BEFORE. STAGED UP PUMP AT THE FOLLOWING RATES: RATE PRESSURE TOTAL BBLS PUMPED 2bpm 500 psi 545 bbls 4bpm 1,000 psi 585 bbls 7 bpm 1,800 psi 675 bbls SHUT DOWN PUMPS 18:30 - 19:30 1.00 WHSUR P DECOMP MONITORED WELL - WELL STATIC - BLEW DOWN LlNES- RIGGED DOWN LINES 19:30 - 20:30 1.00 WHSUR P DECOMP INSTALLED TWC WITH FMC - TESTED ANNULUS TO 1,000 PSI - TEST GOOD - BLEW DOWN CEMENT LINE AND MUD LINES. Printed: 2/24/2003 10:29:20 AM ) ) Legal Well Name: 4-10A/L-28 Common Well Name: 4-1 OAIL -28 Spud Date: 1/25/2003 Event Name: REENTER+COMPLETE Start: 1/25/2003 End: 2/22/2003 Contractor Name: DOYON Rig Release: 2/22/2003 Rig Name: DOYON 15 Rig Number: 15 Date From-To Hours·· ······Task Code NPT Description of Operations 1/25/2003 20:30 - 22:00 1.50 WHSUR P DECOMP PJSM - NIPPLED DOWN CIW TREE 22:00 - 00:00 2.00 BOPSURP DECOMP PJSM - REMOVED ROOF DOORS ON WELL HOUSE - NIPPLED UP SPACER SPOOL - RISER. 1/26/2003 00:00 - 09:00 9.00 BOPSURP DECOMP PJSM - CONTINUE NIPPLE UP 13 5/8" BOPS 09:00 - 12:00 3.00 BOPSURP DECOMP RIG UP XO VALVES ON TEST JOINT - FILL BOP'S WITH WATER - PREPARE TO TEST 12:00 - 13:00 1.00 BOPSURP DECOMP CONTINUE TO RIG UP TO TEST BOPS - OPEN ANNULUS VALVE 13:00 - 21 :00 8.00 BOPSUR P DECOMP TEST BOPS - ANNULAR 250 LOW 3000 HIGH 5 MINS EACH TEST - 4" PIPE RAMS 3 1/2" X 6" VARIBLE RAMS - BLIND RAMS - CHOKE MANIFOLD - CHOKE HYDRAULIC AND CHOKE MANUAL - KILL HYDRAULIC KILL MANUAL - FLOOR TIW - IBOP - UPPER / LOWER IBOP ON TOP DRIVE - TESTED TO 250 LOW 4500 HIGH - TEST 5 MINS EACH - FLANGE ON CHOKE LINE GRAY LOCK - BLIND FLANGE ON SPACER SPOOL - HCR KILL LINE FLANGE - BOTTOM RAM DOOR GASKET LEAKED - ALL TIGHTEN UP AND RETESTED OK - JOHN SPAULDING WITH AOGCC WITNESSED THE TEST. - RIG DOWN TESTING EQUIPMENT - BLOW DOWN CHOKE LINE - KILL LINE - CHOKE MANIFOLD - TOP DRIVE 21 :00 - 22:00 1.00 PULL P DECOMP PJSM - PICK UP SHOOTING FLANGE - SET IN ANNULAR - PICK UP LUBICA TOR AND EXTENSION RODS - MAKE UP TO SHOOTING FLANGE - RETRIEVE TWC - NO PRESSURE SEEN - RIG DOWN LUBICATOR - LAY DOWN SHOOTING FLANGE 22:00 - 00:00 2.00 PULL P DECOMP RIG UP LANDING JOINT - XO'S - TIW VALVES - SIDE ENTRY - TO PULL HANGER / 4 1/2" TUBING 1/27/2003 00:00 - 00:30 0.50 PULL P DECOMP HELD PJSM. MONITORED WELL FOR FLOW - WELL STATIC - BACKED OUT LOCK DOWN SCREWS - PICKED UP TO 180,000# TUBING FREE - P / U ON TUBING 14 FEET. 00:30 - 02:30 2.00 PULL P DECOMP BROKE CIRCULATION, PUMP RATE 7 BPM, 750 PSI- PUMPED 575 BBLS - SHUT DOWN CHECKED FOR FLOW - WELL STATIC, NO GAS. 02:30 - 03:00 0.50 PULL P DECOMP BROKE DOWN CIRCULATING HOSES - XO SUBS - RIGGED UP CASING TONGS / TOOLS - CAMCO SPOOLING UNIT. 03:00 - 03:30 0.50 PULL P DECOMP PULLED TUBING HANGER TO RIG FLOOR, TERMINATED CONTROL LINES. BROKE OUT AND L / D TUBING HANGER. RIGGED UP TO CONTROL LINE SPOOLING UNIT. BROKE OUT AND L / D LANDING JOINT AND HANGER. 03:30 - 07:30 4.00 PULL P DECOMP PJSM - POOH AND L / D 36 JOINTS OF 41/2" NSCT 12.6# TUBING AND SSSV ASSEMBL Y. SPOOLED UP CONTROL LINE. RECOVERED 35 of 39 SS BANDS. 07:30 - 08:00 0.50 PULL P DECOMP R / D CONTROL LINE SPOOLING EQUIPMENT, CLEARED RIG FLOOR. 08:00 - 12:00 4.00 PULL P DECOMP POOH AND UD 41/2" NSCT 12.6# TUBING 12:00 - 12:30 0.50 PULL P DECOMP PJSM - SPILL DRILL - KICK WHILE DRILLING (D-2) DRILL - TRIPPING (D-1) DRILL - EVACUATION DRILL 12:30 - 13:00 0.50 PULL P DECOMP SERVICE RIG - SERVICE SKATE 13:00 - 14:00 1.00 PULL P DECOMP POOH - UD 41/2" NSCT 12.6# TUBING 14:00 - 16:00 2.00 PULL N RREP DECOMP PJSM. REPAIR PIPE SKATE - REPAIR CHAIN 16:00 - 16:30 0.50 PULL P DECOMP POOH - UD 41/2" NSCT 12.6# TUBING Printed: 2/24/2003 10:29:20 AM ) ) BP EXPLORATION QperatlonsSum>mary · Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-1 OAlL -28 4-10AlL-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From- To Hours Task Code ·NPT 1/27/2003 16:30 - 19:30 3.00 PULL N RREP DECOMP PJSM - REPAIR PIPE SKATE - WELD UP CHANNEL IRON FOR CHAIN TO RUN ON 19:30 - 23:00 3.50 PULL P DECOMP POOH AND L / D 41/2" NSCT 12.6# TUBING AND GLM ASSEMBLIES. TOTAL EQUIPMENT PULLED 293 JOINTS OF 4-1/2" NSCT 12.6# TUBING, 20.18' CUT JOINT, 1 - SSSV ASSEMBLY, 4 - GLM ASSEMBLIES. RECOVERED ONE MORE BAND FOR TOTAL 36 - 3 BANDS NOT ACCOUNTED FOR 23:00 - 23:30 0.50 RIGD P DECOMP RIG DOWN CASING EQUIPMENT / LAY DOWN OFF RIG FLOOR 23:30 - 00:00 0.50 REST P DECOMP INSTALL WEAR RING 1/28/2003 00:00 - 00:30 0.50 EVAL P PROD1 PJSM - CLEAR FLOOR OF XO'S - 41/2" ELEVATORS - 4 1/2" SLIPS 00:30 - 01 :00 0.50 EVAL P PROD1 PJSM - SCHLUMBERGER / RIG CREW - RIGGING UP AND ON RUNNING E-LlNE OPERATIONS 01 :00 - 01 :30 0.50 EVAL P PROD1 RIG UP SCHLUMBERGER E-LlNE TOOLS 01 :30 - 04:00 2.50 EVAL P PROD1 P/U - GR I JB / CCL - RIH TO 12000' 04:00 - 06:00 2.00 EVAL P PROD1 LOGGING UP FROM 12000' TO 8000' - CONTINUE POOH 06:00 - 06:30 0.50 EVAL P PROD1 RIG DOWN JUNK BASKET - NO JUNK IN BASKET 06:30 - 07:00 0.50 EVAL P PROD1 PJSM SCHLUMBERGER - PICK UP 7 5/8" EZSV BRIDGE PLUG - MAKE UP TO SETTING TOOL -(FAIL SAFE SYSTEM RAN) 07:00 - 11 :00 4.00 EVAL P PROD1 RIH WITH EZSV BRIDGE PLUG TO 11900 - SHOOT - LINE WEIGHT 3600 DROPPED TO 3400 - WAIT 3 MINUTES LOST ADDITIONAL 600 - WAIT 5 MINUTES P/U 40' - SLACKED OFF TAGGED PLUG AT 11,900' SET WEIGHT DOWN - SOLID NO MOVEMENT - POOH WITH SETTING TOOL 11 :00 - 11 :30 0.50 EVAL P PROD1 WITH SCHLUMBERGER ON THE BANK - CLOSED BLINDS AND TESTED CASING AND PLUG TO 3000 PSI FOR 30 MINUTES - RECORDED ON CHART - TEST GOOD 11:30-13:00 1.50 EVAL P PROD1 RIG DOWN SCHLUMBERGER TOOLS 13:00 - 16:30 3.50 DRILL P PROD1 CUT 200' OF BAD DRILLING LINE - INSPECT BRAKES - INSTALL - SET - TEST CROWN-O-MATIC 16:30 - 19:30 3.00 DRILL N RREP PROD1 REPOSITION STAND PIPE -INSTALL MOUSE HOLE- KELLY HOSE RIDING ON SERVICE LOOP - REPOSITION KELL Y HOSE 19:30 - 00:00 4.50 DRILL P PROD1 MAKE UP 3 1/2" MULE SHOE - PICK UP 4" XT-39 DRILL PIPE - SINGLE IN HOLE - TOTAL JOINTS PICKED UP 82 1/29/2003 00:00 - 11 :00 11.00 DRILL P PROD1 CONTINUE PICKING UP 4" XT-39 DRILL PIPE - JOINT 82 TO JOINT 383 11 :00 - 12:00 1.00 DRILL P PROD1 BREAK CIRC - TAG BRIDGE PLUG @ 11900 12:00 - 13:00 1.00 DRILL P PROD1 SAFETY WALK THRU 13:00 - 17:30 4.50 DRILL P PROD1 PJSM WITH PRODUCTION BEFORE DISPLACE HOLE TO MILLING FLUID - DISPLACE SEAWATER TO MILLING FLUID - AVG BPM 4 PSI 1600 - SPOT 18 PPG PILL ON BOTTOM- PU 220 - SO 140 - ROT 165 - RPM @ 20 - TQ 12K 17:30 - 18:00 0.50 DRILL P PROD1 LAY DOWN 2 JOINTS 4" DP - BLOW DOWN TOP DRIVE 18:00 - 19:00 1.00 DRILL N RREP PROD1 CHECK OUT ELECTRICAL ASSIGNMENTS ON DRILLING CONSOLE 19:00 - 00:00 5.00 DRILL P PROD1 SET AND TEST CROWN-O-MATIC - POOH TO 6092' 1/30/2003 00:00 - 04:00 4.00 DRILL P PROD1 PJSM - POOH WITH 4" DP FOR SECTION MILLING ASSEMBLY - BREAK OFF 31/2" MULE SHOE - XO 31/2" IF X 4" XT-39 - CHANGE ELEVATORS FROM 4" TO 31/2" Printed: 2/24/2003 10:29:20 AM ') ) BPEXPLORATION Operations Summary Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From - To Hours Task Code NPT Phase Descri ptionof Operations 1/30/2003 04:00 - 06:30 2.50 DRILL P PROD1 PU - MAKE UP BAKER SECTION MILLING ASSEMBL Y - PU 11 4 3/4" STEEL DC'S - 15 JOINTS 4" HWDP 06:30 - 12:00 5.50 DRILL P PROD1 RIH WITH BHA FROM 826' TO 11666' 12:00 - 12:30 0.50 DRILL P PROD1 PJSM - MILLING OPERATIONS - BREAK CIRCULATION 12:30 - 13:00 0.50 DRILL P PROD1 RIG SERVICE 13:00 - 14:00 1.00 DRILL N RREP PROD1 ROSS HILL TECH WORKING ON DRILLERS CONSOLE ASSIGNMENTS 14:00 - 15:00 1.00 DRILL P PROD1 RIH FROM 11666' TO 11900' - TAG BRIDGE PLUG - PULL TO 11690' (210) - BREAK CIRCULATION 15:00 - 00:00 9.00 DRILL P PROD1 MILLING WINDOW @ 11690' TO 11704' - WOB 1 OK - 90 RPM - TQ 10K - 14K - GPM 300 - PP 3400 - PU 220K - SO 150K- ROT 165K 1/31/2003 00:00 - 10:00 10.00 DRILL P PROD1 MILLING WINDOW FROM 11704' TO 11740' - TOTAL CUT 50' - WOB 10 - RPM 90 - TQ 10 TO 15 - GPM 300 - PP 3300- PU 225 - SO 150 - ROT 168 - RECOVERED 800 LBS OF METAL - 50' X 29.7 PPF = 1485 LBS CUT - PUMPED BAROLlFT SWEEP AFTER MILLING 25 FEET - THERE WAS A LITTLE INCREASE OF METAL BACK - PUMPING 2ND SWEEP 15 BBLS - NO TORQUE INCREASE - PICKING UP EVERY 4' NO DRAG INCREASE. 10:00 - 16:30 6.50 DRILL P PROD1 PUMPED BAROLlFT SWEEP AND CIRCULATED AROUND-RPM 90 TQ 9 TO 10 - GPM 300 - PP 3200 - SO 150 - ROT 170. AFTER PUMPING SWEEP OUT OF HOLE. SHUT DOWN PUMP AND PULLED SECTION MILL 5' ABOVE TOP OF SECTION TO 11685'. NO PROBLEMS. BROKE CONNECTION AND DROPPED BALL AND OPENED CIRCULATING SUB. CONTINUED CIRCULATING AND CLEANING HOLE. INCREASED PUMP RATE TO 380 GPM - RPM 100 - TQ 9 TO 10K - RECIPROCATE AND ROTATE THROUGH WINDOW WHILE CIRCULATING - RECOVERED 100% METAL 1500 + LBS - PUMP DRY JOB - BLOW DOWN TOP DRIVE 16:30 -19:30 3.00 DRILL P PROD1 POOH TO 9835' PULLING TIGHT OVERPULLS 50 TO 60K 19:30 - 20:00 0.50 DRILL N DPRB PROD1 RIH FROM 9835 TO 10075' - HOLE SLICK NO PROBLEMS NO DRAG SEEN 20:00 - 22:00 2.00 DRILL N DPRB PROD1 CIRC 1500 STKS - PUMP OUT TO 9515' - NO OVERPULL SEEN - HOLE GOOD WITH PUMP - GPM 300 GPM 2500 PSI - ATTEMPT TO PULL 30' WITHOUT PUMP - OVERPULL 40K - SLACK OFF ROTATE 10 RPM - SPM 40 -ATTEMPT TO WORK PIPE TROUGH TIGHT SPOT - OVERPULL INCREASE 20K - TORQUE INCREASE 3K TO 8K - SLACK OFF PERPARE TO RIH 22:00 - 23:30 1.50 DRILL N DPRB PROD1 RIH - HOLE SLICK TO 11000' - DISPLACEMENT NOT CORRECT - BREAK CIRC - STRING PARTIAL PLUGGED - 25 STKS 3300 PSI - 23:30 - 00:00 0.50 DRILL N DPRB PROD1 CIRCULATE STRING CLEAN - STAGING UP PUMP AS I STRING CLEANED UP TO 70 STKS @ 3100 PSI 2/1/2003 00:00 - 02:00 2.00 DRILL N DPRB PROD1 CIRCULATE HOLE BTMS UP - STRING CLEAN - 300 GPM- 3100 PSI- PUMP IN HOLE TO 11690' 02:00 - 03:30 1.50 DRILL N DPRB PROD1 RECIPROCATE AND ROTATE - CIRC AT 3400 PSI 340 GPM - RPM 150 - WORK STRING THROUGH TOP WINDOW - ATTEMPTING TO KNOCK BALL OFF MILL- 03:30 - 04:00 0.50 DRILL N DPRB PROD1 ELEVATORS FROZEN SHUT - BREAK OFF SINGLE IN Printed: 2/24/2003 10:29:20 AM ') ) BPEXPLORATION Opératiol1sSUmmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-1 OAlL -28 REENTER+COMPLETE DOYON DOYON 15 Date Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Description of Operations From-To HoUrs ··Task Code.. ·.NPT 2/1/2003 03:30 - 04:00 0.50 DRILL N 04:00 - 04:30 0.50 DRILL N 04:30 - 07:00 2.50 DRILL N 07:00 - 07:30 0.50 DRILL N 07:30 - 12:00 4.50 DRILL P 12:00 - 12:30 0.50 DRILL P 12:30 - 15:00 2.50 DRILL P 15:00 - 17:00 2.00 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 18:30 0.50 DRILL N 18:30 - 21 :30 3.00 DRILL P 21 :30 - 22:30 1.00 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 2/2/2003 00:00 - 03:30 3.50 DRILL P 03:30 - 07:00 3.50 DRILL P 07:00 - 07:30 0.50 CEMT P 07:30 - 08:00 0.50 CEMT P 08:00 - 09:00 1.00 DRILL P 09:00 - 10:00 1.00 DRILL P 10:00 - 13:00 3.00 DRILL P DPRB PROD1 RREP PROD1 DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 MOUSE HOLE - MAKE UP TO STRING - RIH - THAW ELEVATORS - MAKE UP SINGLE PULL STAND INSPECT BREAKOUT SYSTEM ON TOP DRIVE POOH - HOLE DRAG 10 TO 20K OVER - PULLING GOOD WITHOUT PUMP POOH TO 9214' MIX AND PUMP DRY JOB - BLOW DOWN TOP DRIVE CONTINUE POOH WITH MILLING ASSEMBLY FROM 9214' TO 5500' PJSM - H2S DRILL 1 EVACUATION DRILL CONTINUE POOH WITH MILLING ASSEMBLY FROM 5500' TO BHA LAY DOWN 4 3/4" DC'S - MILLING TOOLS - CLEAR FLOOR OF ALL TOOLS NOT NEEDED PICK UP 1 MAKE UP STACK WASHER - FLUSH BOPS- BREAK 1 LAY DOWN CHANGE DRESSER SLEEVE ON FLOW LINE MAKE UP MULE SHOE - XO - TO 4" DP - RIH TO 6000' CIRCUATE BTMS UP -100 RPM - 273 GPM -1400 PSI- MUD RUNNING OVER SHAKERS IF RUN HIGHER GPM - MUD VERY THICK RIH - MUD RUNNING OVER TOOL JOINT GOING IN HOLE CIRC - MIX DRY JOB - PUMP DRY JOB - BLOW DOWN TOP DRIVE PJSM - RIH TO 11680' WITH MULE SHOE - BREAK CIRCULATION - WASH FROM 11680 TO 11840 CIRCULATE AND CONDITION MUD FOR SETTING KICK-OFF PLUG - RPM 110 - GPM 380 - PP 3000. HELD PJSM FOR SETTING BALANCED CEMENT PLUG. RIGGED UP FLOOR FOR CEMENTING JOB. PUMPED 5 BBLS WATER AHEAD - CLOSE LO TORQUE VALVE AND TEST LINES TO 3500 PSI- PUMPED ADDITIONAL 5 BBLS OF WATER - PUMPED 25 BBLS (140 SX) OF CLASS G CEMENT +.2% D-46 DEFOAMER + 1% D65 RETARDER + .15 % D-167 FLUID LOSS AGENT + .05% B155 RETARDER - MIXED IN A 17.0 PPG SLURRY AND WITH 1.0 CFTISX YIELD - FOLLOWED CEMENT WITH 3.5 BBLS OF WATER. SWITCHED TO RIG PUMP AND DISPLACED CEMENT WITH 111 BBLS OF 9.6 PPG MUD AT 9 BPM. CEMENT IN PLACE AT 0800 HRS. PROD1 RIG DOWN SCHLUMBERGER. PULLED OUT OF HOLE SLOWLY WITH 9 STANDS OF DRILL PIPE TO 11000'. PIPE PULLED DRY. PROD1 PUMPED 30 BBLS OF NUT PLUG SWEEP AND CIRCULATED HOLE AT 10 BPM AT 2650 PSI. RECIPROCATED DRILL PIPE A FULL STAND AND ROTATED PIPE 100 RPM. NO CEMENT TO SURFACE. PROD1 CLOSED ANNULAR PREVENTOR AND PERFORMED HESITATION SQUEEZE. PRESSURED UP 200-300 PSI AT A TIME EVERY 10 MINUTES TO 2000 PSI AND HELD FOR 1 HOUR. FINAL PRESSURE DECREASED TO 1800 PSI. PUMPED AT TOTAL OF 6.8 BBLS FOR SQUEEZE. BLEED OFF PRESSURE AND RECOVERED 6 BBLS OF MUD. - BLOW DOWN KILL LINE Printed: 2/24/2003 10:29:20 AM ') -) BP EXPLORATION OperationsS.umrnäry·.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-1 OAlL -28 4-10AlL-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From ~To Hours Task Code NPT 2/2/2003 13:00 - 13:30 0.50 DRILL P PROD1 13:30 -14:00 0.50 DRILL P PROD1 14:00 - 18:30 4.50 DRILL P PROD1 18:30 - 23:30 5.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 2/3/2003 00:00 - 07:30 7.50 DRILL P PROD1 07:30 - 11 :30 4.00 DRILL P PROD1 11:30-12:00 0.50 DRILL P PROD1 12:00 - 13:00 1.00 DRILL P PROD1 13:00 - 15:30 2.50 DRILL P PROD1 15:30-16:00 0.50 DRILL P PROD1 16:00 - 19:00 3.00 DRILL P PROD1 19:00 - 21 :30 2.50 DRILL P PROD1 21 :30 - 22:30 1.00 DRILL N RREP PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 00:00 1.00 DRILL N SFAL PROD1 2/4/2003 00:00 - 03:00 3.00 DRILL N SFAL PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 06:30 2.00 DRILL P PROD1 06:30 - 09:00 2.50 DRILL P PROD1 09:00 - 10:00 1.00 DRILL N RREP PROD1 10:00 - 12:30 2.50 DRILL P PROD1 Description· of Operations PUMP DRY JOB - RIG DOWN PUMP IN SUB - CEMENT LINE RIG SERVICE POOH - BREAK AND LAY DOWN - Xo - MULESHOE OPEN DOORS TO RAMS - CLEAN OUT METAL IN RAM CAVITY'S - LESS THEN A CUP RECOVERED - PICK UP TEST JOINT - PULL WEAR RING -INSTALL TEST PLUG TESTING BOP'S - 250 LOW - 4500 HIGH - 5 MIN EACH TEST - UPPER PIPE RAMS - CHOKE MANIFOLD TESTING BOP'S - CHOKE MANIFOLD - MANUAL CHOKEl MANUAL KILL VALVES - HYDRAULIC CHOKE l HYDRAULIC KILLVALVES - FLOOR TIW l DART VALVES - LOWER PIPE RAMS - BLIND RAMS - ALL TEST 250 LOW 4500 HIGH FOR 5 MINS EACH- ANNULAR 250 LOW 2500 HIGH FOR 5 MINS EACH - ACCUMLATOR TEST START 3000 PSI 1500 END- 200 PSI BUILD UP 27 SEC - 3 MINS 50 SECS FULL CHARGE - 4 BOTTLES NITROGEN 2250 AVG PSI- PULL TEST PLUG -INSTALL WEAR RING - CLOSE ANNULUS VALVE - RIG DOWN TEST JOINT - RIG UP TO TEST UPPER l LOWER IBOP VALVES ON TOP DRIVE - TEST UPPER l LOWER TOP DRIVE IBOP VALVES - RIG DOWN TESTING EQUIPMENT - BLOW MANIFOLD DOWN - AOGCC CHUCK SCHEVE WAIVED THE WITNESS OF THE BOP TEST - ALL TEST WERE GOOD. PICK UP BIT - BHA - ORIENT PICK UP 2 JTS 4" DP SHALLOW TEST MWD @ 70 SPM PJSM - RIG SERVICE PICK UP 40 JOINTS 4" DP WEATHERFORD REP SCHOOL ON PROPER HANDLING 4" XT -39 DP ON RIG FLOOR RIH WITH 4" DP - FILLING EVERY 25 STDS CUT DRILLING LINE WORK ON TOP DRIVE BELL GUIDE - INSPECT SAVER SUB - FILE SHARP EDGES RIH TO 9011' MOTORMAN NOTICED MUD / WATER RUNNING ON WHEELS IN WHEEL HOUSE IN CELLAR UNDER FLOOR - STOPPED OPERATION - NOTIFIED ENVIRNMENTAL TECH (VINCE VOLPE) OF POSSIBLE SPILL - CLEANED UP MUD / WATER FROM CELLAR +- 5 GALLONS - MUD l WATER CONTAINED IN SECONDARY CONTAINMENT - CLEAN DRIP PANS UNDER RIG FLOOR Pre-Job Safety Meeting - Clean Mud And Solids From Rig Floor Containment Drain Pans And Flush Drain Lines Continue To RIH With 4" Drill Pipe From Mast To 10,974' Connect Tesco Top Drive And Wash From 10,974' To Top Of Cement At 11,550' - Record Slow Pump Rates Drill Cement From 11,550' To 11,693' Kick Off Point - Hard Cement Back Over Shakers - Orient Motor To 160 Degrees Left And Slide For Kick Off From 11,623' To 11,721' Pull Into Casing And Blow Down Top Drive - Repair Oiler Pump Control For Derrick Shakers Continue To Drill Cement Kick Off Plug From 11,721' To 11,760' - Take Survey (Check Shot) 48.86 Degrees Inclination Printed: 2/24/2003 10:29:20 AM ) ') BP EXPLORATION OperationsSurnrna ry ··.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From-To Hours Task Code NPT 2/412003 10:00 - 12:30 2.50 DRILL P PROD1 12:30 - 13:30 1.00 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 -16:30 2.00 DRILL P Description of Operations = 11 Degrees Dog Leg Rate Pull Bit To 11,693' - Circulate Bottoms Up And Condition Mud For FIT Hold Pre-Job Safety Meeting - Preform FIT To 12.0 PPG EMW Closed Annular Element And Performed FIT. Strokes Pmp'd Pressure 2 125 psi 4 250 psi 6 350 psi 8 475 psi 10 575 psi 12 700 psi 14 800 psi 16 900 psi 18 1000 psi 20 1050 psi 21 11 00 psi Held Test F/10 minutes wI 90 Psi. Pressure Loss. MW 9.7 ppg, Csg Shoe TVD 8,651' Pressure 1100 psi = 12.15 PPG. EMW. Bleed Pressure To 0 Psi. - Open Annular PROD1 Hold Pre-Job Safety Meeting With All Personal - Displace Hole To Baroid GEM Enhanced Mud At 7 BPM And 80 RPM - Clean Mud Trough And Shaker Possom Belly - Wash Back To Bottom At 11,760' 16:30-17:30 1.00 DRILL P 17:30 - 18:30 1.00 DRILL P 18:30 - 00:00 5.50 DRILL P 2/5/2003 00:00 - 01 :00 1.00 DRILL P 01 :00 - 02:00 1.00 DRILL P 02:00 - 03:00 1.00 DRILL P 03:00 - 05:30 2.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Record Following Drilling Parameters: Before Disp. After Disp. Rotary Torque (Off) 9K 7.5K Rotary Torque (On) 12K 7.5K Rotating Wt. 187K 175K Up Wt 225K 195K Down Wt 145K 155K Pump Press. (Off Bottom) 2500 psi 2050 psi Pump Press. (On Bottom) 2650 psi 2250 psi WOB 20K 15K RPM 50 59 Directional Drill Ahead From 11,760' To 11,783' Circulate Bottoms Up Pull Into 7 5/8" Casing - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive - POH With 4" Drill Pipe Standing Back In Mast For BHA And Bit Change Continue To POH With Bit NO.1 Stand Back BHA Break Bit No.1 - Change Bend On Motor To 1.22 Degrees - Inspect Drip Pans Under Rig Floor Make Up PDC Bit No.2 - Pick Up AGS And MWD I LWD Tools - Space Out Pulser Sub Printed: 2/24/2003 10:29:20 AM ') ) BP EXPLORATION O.perations ..S·LJrnrna·ry··.·Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From -To Hours Task Code NPT Phase Descri ptionofOperations 2/5/2003 05:30 - 07:00 1.50 DRILL P PROD1 Initalize MWD / LWD Tools - Having Hard Time Communicating 07:00 - 08:00 1.00 DRILL P PROD1 Surface Test Mud Motor, AGS, And MWD Tools - Blow Down Top Drive And Surface Equipment 08:00 - 12:30 4.50 DRILL P PROD1 RIH With 4" Drill Pipe From Mast - Fill Drill String Every 25 Stands - Hold Kick Drill While Tripping 12:30 - 13:00 0.50 DRILL N PROD1 Re-wrap Top Drive Service Loop 13:00 - 16:00 3.00 DRILL P PROD1 Continue To RIH With 4" Drill Pipe To 11,693' 16:00 - 16:30 0.50 DRILL P PROD1 Connect Top Drive - Break Circulation - Precautionary Ream Open Hole Section From 11,693' To 11,783' (No Problems) Record ECD Base Line 10.59 At 11,703' (300 GPM) 16:30 - 00:00 7.50 DRILL P PROD1 Directional Drill Ahead From 11,783' To 12,069' *NOTE* While Rotary Drilling ROP 90 To 120 FPH While Slide Drilling ROP At 20 To 60 FPH At Times Unable To Get Much Differential Pressure (150 Psi. WOB 2K) With Out Stalling Out Motor. Bit Very Aggressive With This Formation. Hard To Steer. 2/6/2003 00:00 - 09:30 9.50 DRILL P PROD1 Directional Drill Ahead From 12,069' To 12,243' 09:30 - 10:30 1.00 DRILL P PROD1 Pump 5 % (30 BBL) EP Mud Lube Pill While Reciprocating And Rotating At 90 RPM - To Reduce Casing Drag 10:30-11:30 1.00 DRILL P PROD1 Attempt To Directional Drill Ahead From 12,243' To 12,255' 11:30 -12:30 1.00 DRILL P PROD1 Circulate While Mixing Dry Job - Pump Same And Blow Down Top Drive 12:30 - 16:00 3.50 DRILL P PROD1 POH Slow Thru Open Hole Section From 12,255' To 11,690' - Continue To POH To 10,966' - Mad Pass To 10,866' - POH To 9,430' - Mad Pass To 9,330' 16:00 - 20:00 4.00 DRILL P PROD1 Pump Dry Job And Blow Down Top Drive - POH From 9,330' To BHA At 832' 20:00 - 21 :00 1.00 DRILL P PROD1 POH With BHA Standing Back In Mast - Break Off Bit 21 :00 - 21 :30 0.50 DRILL P PROD1 Change Bend On Motor To 1.50 Degrees - Check Out AGS While Pumping - Orient MWD 21 :30 - 23:00 1.50 DRILL P PROD1 Make Up Bit No.3 - Down Load Data From MWD - Initialize MWD / LWD Tools - Surface Test 23:00 - 00:00 1.00 DRILL P PROD1 RIH With BHA To 832' - Continue To RIH With 4" Drill Pipe From Mast To 1,300' 2/7/2003 00:00 - 00:30 0.50 DRILL P PROD1 Service Tesco Top Drive And Traveling Blocks 00:30 - 06:30 6.00 DRILL P PROD1 Continue To RIH With 4" Drill Pipe From Mast To 11,576' - Fill Drill String Every 25 Stands 06:30 - 08:30 2.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Slip And Cut 110' Of 1 3/8" Drilling Line 08:30 - 09:00 0.50 DRILL P PROD1 Fill Drill String - Blow Down Top Drive - Set Crown Saver 09:00 - 09:30 0.50 DRILL P PROD1 Rig Up Tongs And Load Cell- Check Calibration On Tesco Top Drive (Torque Readings Checked Good) 09:30 - 10:00 0.50 DRILL P PROD1 Continue To RIH To 12,137' 10:00 - 10:30 0.50 DRILL P PROD1 Connect Top Drive And Break Circulation - Precautionary Wash And Ream Last Stand From 12,137' To 12,255' - Record Slow Pump Rates 10:30 - 00:00 13.50 DRILL P PROD1 Directional Drill Ahead Dropping Angle And Turning Left From 12,137' To 12,481' - Weight On Bit 10K To 22K - With Pump Rate At 71 Strokes Or 300 GPM - Off Bottom Pump Pressure At 2300 Psi. & On Bottom Pump Pressure At 2560 Psi. - Top Printed: 2/24/2003 10:29:20 AM ) ') BP EXPLORATION OperationsSumrnàry ...Report Actual Slide Time At 3.31 Hours Actual Rotating Time At 6.62 Hours PROD1 Directional Drill Ahead From 12,481' To 12,527' - Angle Dropped To 32.71 Degrees - Made Hard Set 50 To 70 Left And Angle Dropped To 29.09 Degrees And Walked Left Only .08 On Azimith Circulate Bottoms Up - Consult With Anchorage Drilling Engineer Regarding Directional Problems - Mix Dry Job POH From 12,527' To 11,574' (Wet) - Hole Drag Increased 30K Coming Thru Window - Remainder Of Open Hole Pulled Clean With No Problems Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive And Surface Lines POH With 4" Drill Pipe Standing Back In Mast - Preform Mad Pass For Tie In Log From 11,105' To 10,905' At 150 FPH - Continue To POH To 2,328' Repair Hydraulic Hose On Iron Ruffneck POH With 4" Drill Pipe To BHA At 832' POH With BHA Standing Back In Mast Inspect Bit And Motor Orientation (OK) - Down Load MWD / LWD Tool- Lay Down Motor And Check MWD Tools - Clear Rig Floor Make Up Bit No.4 - Pick Up Motor With ABI And MWD Tools - Initialize MWD RIH With BHA To 841' Continue To RIH With 4" Drill Pipe From Mast From 841' To 8,395' - Fill Drill String Every 25 Stands Continue To RIH With 4" Drill Pipe - Connect Top Drive And Break Circulation Above KOP - Orient Motor And Pass Thru Area With "NO Problems" - Continue To RIH Thru Open Hole Section To 12,490' With "NO Problems" PROD1 Wash And Ream Last Stand To Bottom From 12,490' To 12,537' (No Fill) PROD1 Take Survey With ABI 28.56 Degrees Inclination At 12,537' - Orient Motor 15 Degrees Left Of High Side And Directional Drill Ahead To 12,575' (6 A.M. Depth) - Continue To Drill Ahead Sliding With AGS Closed - ABI Shows Angle Building - Build Angle Up To 36 Degrees - Orient Hard Left And Attempt To Get Turn Very Little Response - Assembly Wanting To Walk Right - Continue To Fight Directional Issues To Get Back On Line To Hit Targets - Consult With Anchorage Drilling Engineer And Sperry Sun Office Regarding Operations - Take Repeated Check Shots Every +/- 30 Feet - Raise Mud Weight With Spike Fluid From 9.8 PPG To 10.3 PPG At 12,798' Above HRZ Formation ECD At 11.19 PPG After Displacement - Record New Slow Pump Rates - Continue To Directional Drill Ahead With Hard Left Tool Face Settings To 12,830' - Survey Taken At 12,753' Showed Inclination At 38.86 Degrees And Azimith At 344.26 Degrees - Currently In Phase 2 Conditions Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Date From - To Hours Task Code NPT Phase 2/7/2003 10:30 - 00:00 13.50 DRILL P PROD1 2/8/2003 00:00 - 03:00 3.00 DRILL P 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 11 :00 5.50 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL N RREP PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 18:30 2.00 DRILL P PROD1 18:30 - 20:00 1.50 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 2/9/2003 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P 03:00 - 00:00 21.00 DRILL P Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Description of ()perations Drive RPM At 50 - Off Bottom Torque At 5K & On Bottom Torque At 7K - String Rotating Weight At 180K - With Pump Off Drag Up At 210K And Drag Down At 160K Printed: 2/24/2003 10:29:20 AM ') ') BP..·EXPLORATION Oþerations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From-To Hours Task Code NPT 2/10/2003 00:00 - 17:30 17.50 DRILL P PROD1 Description of Operations Prepare To POH Above Kekiktuk Formation At Projected Depth At 13,190' MD And 9,825' TVD Circulate Sweep Around And Continue To Circulate Total Of (2) Bottoms Ups Monitor Well Bore (Static) - POH From 13,160' To 11,678' (Wet) With No Problems In Open Hole Section Or KOP While Monitoring Correct Steel Displacement Monitor Well Bore (Static) - Inspect Top Drive And Service - Circulate Across Top Of Hole And Change Out Saver Sub Pump Dry Job - Blow Down Top Drive And Surface LinesContinue To POH With 4" Drill Pipe Standing Back In Mast From 11,678' To 9,936' Continue To POH With 4" Drill Pipe Standing Back In Mast From 9,936' To 3,082' Section Of Clamp On Top Drive "s" Pipe Broke Off - Shut Down Operation Secure Area And Investigate See LCIR NO.2003-IR-433677 - Install Full Opening Safety Valve - Cover Rig Floor Rotary Table Area And Remove Rotary Hose From Top Drive To Repair "S" Pipe Bracket And Clamp - Notify Anchorage Drilling Superintendent Of Incident. MISC PROD1 The Doyon H2S Alarm At Bell Nipple Went Off The Drilling Crew Reset The Alarm And It Again Re-Tripped - The BP ESD H2S Had 1 To 2 PPM And LEL Had 4% - The Tour Pusher Was Notified - The Crew Shut The Well In And Evacuated The Rig To A Safe Briefing Area - All Personnel Were Accounted For At Muster Area - Notify Anchorage Drilling Superintendent - Endicott Fire And Safety Were Notified And Entered Rig To Verify Alarm Status An All Clear Was Given For Rig Personnel To Return To Rig To Resume Operations. Open Up Choke Line And Verify 0 Psi. - Open Up Well And Monitor (Static) - Continue To POH With 4" Drill Pipe To 2,742' - Install Full Opening Safety Valve Hold Pre-Job Safety Meeting - Clear Rig Floor Area - Rig Up And Secure Man Rider Cable To Mast Continue To POH With 4" Drill Pipe To 841' (BHA) -Install Full Opening Safety Valve Hold Pre-Job Safety Meeting - Clear Rig Floor Area - Rig Up And Remove Man Rider Sheave And Cable From Mast Stand Back BHA In Mast - Down Load MWD / LWD Tools - Lay Down AGS And Remove 6 3/4" Bit - Clear Rig Floor Hold Pre-Job Safety Meeting - Remove Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular At 250 Psi. Low And 2,500 Psi. High, Upper And Lower Pipe Rams, Blind Rams, Manual And HeR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 4,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment - Pull Test Plug And Install Wear 17:30 - 19:30 2.00 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 2/11/2003 00:00 - 03:30 3.50 DRILL P PROD1 03:30 - 04:30 1.00 DRILL N RREP PROD1 04:30 - 07:00 2.50 DRILL N 07:00 - 07:30 0.50 DRILL P PROD1 07:30 - 08:30 1.00 DRILL N MISC PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 - 11 :30 1.50 DRILL N MiSe PROD1 11 :30 - 13:30 2.00 DRILL P PROD1 13:30 - 21 :30 8.00 BOPSUR P PROD1 Continue To Directional Drill Ahead From 12,830' To 13,160' - Make Hard Left Sets To Counter 10 Degree Per 100 Right Hand Walk Tendency While Rotating. Printed: 2/24/2003 1029:20 AM ) ') BPEX.PLORATION Operation$ Surnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From - To Hours Task Code NPT Phase Descri ptionof Operations 2/11/2003 13:30 - 21 :30 8.00 BOPSURP PROD1 Bushing - Blow Down Choke Manifold And Kill Lines. 21 :30 - 00:00 2.50 DRILL N MiSe PROD1 Preform Mast Inspection - Remove Varco "s" Pipe From Tesco Top Drive - Install Tesco 45 Degree Long Sweeping Elles - Install Rotary Hose And Safety Cables - Make Adjustments On Mud Line Stand Pipe For Hose Orientation 2/12/2003 00:00 - 04:00 4.00 DRILL N MiSe PROD1 Having Problems With Rotary Hose Orientation Due To Equipment Supplied By Tesco - Make Adjustments On Mud Line Stand Pipe And 45 Degree Elle's For Hose Orientation While Traveling Up And Down Thru Mast. 04:00 - 08:00 4.00 DRILL P PROD1 For Better Well Control Make Decision To RIH To Window And Finalize Orientation At That Point - Held PJSM M I U BHA NO.6 - 6 3/4" Hughes EP4983 Insert Bit Serial Number 5005849, Dressed With 3x16 Jets, 4 3/4" SperryDrill 7/8 - 2.2 Stage Motor With ABI And 1.50 Deg. Bent Housing, 6 1/2" Integral Blade Stabilizer, FEMWD wI GR-Res,- FEMWD wI DM-PWD-TM, 3 x Flex Drill Collars, XIO, 2 x 4" HWDP, Daily Hyd. Drilling Jars And 18 x 4" HWDP, X/O. Total BHA Length - 835.47 - Initalize MWD Tool- M I U Head Pin And Tested MWD Tools At 254 GPM 850 Psi. (OK) 08:00 - 08:30 0.50 EVAL N MiSe PROD1 Test Top Drive And Stand Pipe To 4,000 Psi. (Leaked) 08:30 - 16:00 7.50 DRILL P PROD1 RIH w/6 3/4" Directional BHA On 4" DP To 11,675' - Filled Pipe Every 25 Stands 16:00 - 17:30 1.50 DRILL P PROD1 Test Top Drive And Stand Pipe To 3,800 Psi. - Pumped And Circulated Bottoms Up - Pump Rate 300 GPM , SPP 2,750 Psi. 17:30 - 18:15 0.75 DRILL P PROD1 RIH w/6 3/4" Directional BHA On 4" DP To 13,077' wI No Problems 18:15 - 18:30 0.25 DRILL P PROD1 M/U Top Drive - Wash And Ream As Precaution From 13,077' To 13,160' - RPM 50, Motor RPM 99, Torque 5,000 FtlLbs, Pump Rate 300 GPM, SPP Off Bottom 2,950 Psi. String Weight Up 240,000# String Weight Down 160,000# String Weight Rotating 182,000# 18:30 - 00:00 5.50 DRILL P PROD1 Drilled 6-3/4" Directional Hole By Rotating And Sliding From 13,160' to 13,251'. WOB Sliding 20,000# - 25,000#, WOB Rotating 15,000# - 20,000#, RPM 50, Motor RPM 99, Torque Off Bottom 5,000 ft Ilbs - On Bottom 8,000 ft Ilbs, Pump Rate 300 gpm, SPP Off Bottom 2,750 psi, On Bottom 2,900 psi. String Weight Up 240,000#, String Weight Down 160,000#, String Weight Rotating 182,000#. ART = 1.25 hrs, AST = 3.33 hrs. 2/13/2003 00:00 - 00:30 0.50 DRILL P PROD1 Drilled 6-3/4" Directional Hole By Rotating And Sliding From 13,251' to 13,258' 00:30 - 01 :30 1.00 DRILL P PROD1 Rotate And Reciprocate Drill String While Circulating Bottoms Up At 13,258' - RPM 50, Motor RPM 99, Torque Off Bottom 7,000 ft Ilbs, Pump Rate 300 gpm, SPP Off Bottom 2,750 psi, String Weight Up 240,000#, String Weight Down 160,000#, String Weight Rotating 182,000#. 01 :30 - 02:30 1.00 DRILL N RREP PROD1 Held PJSM Tesco Top Drive Fitting Broke - Set Back One Stand Of 4" Drill Pipe To Repair Fitting - Lay Down (1) Single Of DP With Bad Face Needing Repair - Circulate While Making Repair - Make Up Stand And Take Check Shot Survey 02:30 - 09:00 6.50 DRILL P PROD1 Drilled 6-3/4" Directional Hole By Rotating And Sliding From 13,258' to 13,390'. WOB Sliding 20,000# - 25,000#, WOB Rotating 15,000# - 20,000#, RPM 50 To 75, Motor RPM 99, Printed: 2/24/2003 10:29:20 AM ) Legal Well Name: 4-10A/L-28 Common Well Name: 4-10AlL-28 Spud Date: 1/25/2003 Event Name: REENTER+COMPLETE Start: 1/25/2003 End: 2/22/2003 Contractor Name: DOYON Rig Release: 2/22/2003 Rig Name: DOYON 15 Rig Number: 15 Date From-To Hours Task Code NPT Phase Description of Ope rations 2/13/2003 02:30 - 09:00 6.50 DRILL P PROD1 Torque Off Bottom 7,000 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 300 gpm, SPP Off Bottom 2,750 psi, On Bottom 2,900 psi. String Weight Up 240,000#, String Weight Down 160,000#, String Weight Rotating 182,000#. ART = 2.56 hrs, AST = 2.16 hrs. 09:00 - 10:30 1.50 DRILL P PROD1 Circulate Bottoms Up While Rotating And Reciprocating Drill String - RPM 50, Motor RPM 99, Torque Off Bottom 7,000 ft I Ibs - On Bottom 9,000 ft Ilbs, Pump Rate 300 gpm, SPP Off Bottom 2,750 psi, String Weight Up 240,000#, String Weight Down 160,000#, String Weight Rotating 182,000#. 10:30 - 11 :00 0.50 DRILL P PROD1 Held PJSM - Monitor Well Bore (Static) - Mini-Wiper Trip Thru Coal Section - POH wi 6 3/4" Directional BHA On 4" DP From 13,390' To 12,789' With No Hole Problems Maximum Over Pull 15,000# Average Drag 10,000# 11:00-11:30 0.50 DRILL P PROD1 RIH From Mini-Wiper Trip w/6 3/4" Directional BHA On 4" DP From 12,789' To 13,330' With No Hole Problems - MIU Top Drive And Wash As A Precaution From 13,330' To 13,390' 11 :30 - 15:00 3.50 DRILL P PROD1 Circulate Hole Clean With 3 Bottoms Up While Rotating And Reciprocating Drill String - RPM 50, Motor RPM 99, Torque Off Bottom 7,000 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 300gpm, SPP Off Bottom 2,750 psi, String Weight Up 240,000#, String Weight Down 160,000#, String Weight Rotating 182,000# - Monitor Well Bore (Static) 15:00 - 16:00 1.00 DRILL P PROD1 Held PJSM Blow Down Tesco Top Drive - POH w/6 3/4" Directional BHA On 4" DP From 13,390' To 11,672' With No Hole Problems Over Pull 15,000# Average Drag 10,000# 16:00 - 17:00 1.00 DRILL P PROD1 Monitor Well Bore (Static) - Held PJSM Install Shackles On Tesco Top Drive Unit And Service - While Circulating Across Top Of Hole - Pump Dry Job - Blow Down Circulating Lines 17:00 - 22:00 5.00 DRILL P PROD1 Held PJSM POH wi 6 3/4" Directional BHA On 4" DP From 11,672' To 835' - Stands 35 To 17 Starting Threads Hanging Up When Spinning Out With Iron Ruffneck And Making Metal Shavings Contact Kevin Walker Regarding Issue. 22:00 - 00:00 2.00 DRILL P PROD1 Monitor Well Bore At BHA (Static) - Held PJSM Stand Back BHA NO.6 In Mast - Change Bit P/U 6 3/4" Smith XR20TDGPS Insert Bit Serial Number L Y9625, Dressed With 3x16 Jets - Down Load Sperry Sun MWD/LWD Data 2/14/2003 00:00 - 02:30 2.50 DRILL P PROD1 Held PJSM - M I U BHA NO.7 - MIU 43/4" SperryDrill7/8 - 2.2 Stage Motor With ABI And 1.50 Deg. Bent Housing, 6 1/2" Integral Blade Stabilizer, FEMWD wi GR-Res,- FEMWD wi DM-SLD+CTN-PWD-TM, Initalize MWD/LWD Tools - M I U Top Drive And Tested MWD/LWD Tools At 241 GPM 1,000 Psi. (OK) - Blow Down Top Drive 02:30 - 03:30 1.00 DRILL N HMAN PROD1 Held PJSM - Change Saver Sub On Tesco Top Drive 03:30 - 04:30 1.00 DRILL P PROD1 Held PJSM For Radioactive Sources - Load Sources In BHA NO.7 - RIH wI Remainder Of BHA 3 x Flex Drill Collars, XIO, 2 x 4" HWDP, Daily Hyd. Drilling Jars And 18 x 4" HWDP, XIO. Total BHA Length - 860.92 04:30 - 11 :00 6.50 DRILL P PROD1 Held PJSM - RIH w/6 3/4" Directional BHA On 4" DP To 11,601' - Filled Pipe Every 25 Stands - Clean And Inspect Threads On Box And Pin Ends During Trip In Hole - Slow Down Spin In Speed On IR-3000 Iron Ruffneck And Torque To Recommended Make Up Torque Value Of 20,000 ftIlbs. With Printed: 2/24/2003 10:29:20 AM ') BPEXPLORATION Operations.SÙmrnary ··Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-10A/L-28 4-10A/L-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Torque Wrench A Minimum Of 3" From Top Of Box. Pumped And Circulated Bottoms Up While Rotating And Reciprocating Drill String - Pump Rate 300 GPM , SPP 2,750 Psi. Record ECD Base Line At 11.25 PPG With 10.3 PPG Clean Mud - Record Slow Pump Rates Held PJSM Make Up Top Drive - Slip And Cut 70 Feet Of 1 3/8" Drilling Line Held PJSM - RIH wI 6 3/4" Directional BHA On 4" DP From 11,601' To 13,289' With NO Problems M/U Top Drive· Wash And Ream As Precaution From 13,289' To 13,382' - RPM 50, Motor RPM 99, Torque 7,000 FULbs, Pump Rate 300 GPM, SPP Off Bottom 3,050 Psi. String Weight Up 245,000# String Weight Down 155,000# String Weight Rotating 182,000# - Circulate Open Hole Volume And Prepare To Make Mad Pass Torque Increasing To 18,000# Attempting To Twist Up Drill Line· Trouble Shoot Tesco Top Drive And Emsco Swivel· Determine Swivel Attempting To Lock Up Held PJSM Blow Down Tesco Top Drive - POH wI 63/4" Directional BHA On 4" DP From 13,382' To 11,601' With No Hole Problems Over Pull 15,000# Average Drag 10,000# Observe Well (Static) - Held PJSM And Reviewed Procedure For Rigging Down Swivel Remove Rotary Hose· Rig Up Tongs In Mast And Break Emsco Swivel 6 5/8" Regular Left Hand Connection - Secure Swivel Bale And Traveling Block Becket - Remove Pin From Becket And Lower Swivel Bale - Hoist Traveling Blocks - Back Out Swivel Connection And Lift Emsco Swivel From Quill Shaft And Lower To Rig Floor RREP PROD1 Held PJSM Bring Replacement Swivel To Rig Floor - Change Out Gooseneck Union's On Rotary Hose And Swivel - Pick Up Swivel And Fill With Oil - Make Up Double Box Cross Over Sub Hoist Swivel And Stab Onto Top Drive Quill Shaft - Lower Traveling Blocks To Swivel Bale - Lay In Becket And Secure With Pin - Rig Up Tongs In Mast And Torque 6 5/8" Reg Left Hand Connections - Make Up Rotary Hose And Test To 3,800 Psi. (OK) - Remove Tools From Top Drive And Clear Rig Floor. RREP PROD1 Pumped And Circulated Bottoms Up - Pump Rate 300 GPM , SPP 2,750 Psi. - While Rotating And Reciprocating Drill String - Top Drive Torque At 7,000# With 50 RPM RREP PROD1 Continue To Pump And Circulate Bottoms Up - Pump Rate 300 GPM , SPP 2,750 Psi. - While Rotating And Reciprocating Drill String - Top Drive Torque At 7,000# With 50 RPM - No Problems with Top Drive Or Swivel- Blow Down Top Drive RREP PROD1 Held PJSM - RIH wI 6 3/4" Directional BHA On 4" DP From 11,601' To 13,289' With No Problems RREP PROD1 MIU Top Drive - Wash And Ream As Precaution From 13,289' To 13,382' - RPM 50, Motor RPM 99, Torque 7,000 FULbs, Pump Rate 300 GPM, SPP Off Bottom 3,050 Psi. String Weight Up 245,000# String Weight Down 155,000# String Weight Rotating 182,000# PROD1 Held PJSM Perform Mad Pass For Tie In Log From 13,382' To Date From - To Hours Task Code NPT 2/14/2003 04:30 - 11 :00 6.50 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL P PROD1 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 13:30 1.00 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:30 1.00 EVAL N RREP PROD1 16:30 -18:00 1.50 DRILL N RREP PROD1 18:00 - 19:00 1.00 DRILL N RREP PROD1 19:00 - 21 :30 2.50 DRILL N RREP PROD1 21 :30 - 23:30 2.00 DRILL N 23:30 - 00:00 0.50 DRILL N 2/15/2003 00:00 - 00:30 0.50 DRILL N 00:30 - 01 :30 1.00 DRILL N 01 :30 - 02:00 0.50 DRILL N 02:00 - 03:45 1.75 DRILL P Descri ption of Operations Printed: 2/24/2003 10:29:20 AM ) ') BP EXPLORATION OperationsSummäryReport Legal Well Name: 4-10A/L-28 Common Well Name: 4-10A/L-28 Spud Date: 1/25/2003 Event Name: REENTER+COMPLETE Start: 1/25/2003 End: 2/22/2003 Contractor Name: DOYON Rig Release: 2/22/2003 Rig Name: DOYON 15 Rig Number: 15 Date From- To Hours Task Code NPT Phase 2/15/2003 02:00 - 03:45 1.75 DRILL P PROD1 13,289' And From 13,382' To 13,390' At 150 FPH - RPM 50, Motor RPM 99, Torque 7,000 Ft/Lbs, Pump Rate 300 GPM, SPP Off Bottom 3,050 Psi. String Weight Up 245,000# String Weight Down 155,000# String Weight Rotating 182,000# 03:45 - 00:00 20.25 DRILL P PROD1 Drilled 6-3/4" Directional Hole By Rotating And Sliding From 13,390' to 13,790'. WOB Rotating 15,000# - 25,000#, WOB Sliding 20,000#, RPM 50 To 65, Motor RPM 99, Torque Off Bottom 8,000 ft I Ibs - On Bottom 10,000 ft I Ibs, Pump Rate 296 gpm, SPP Off Bottom 3,080 psi, On Bottom 3,180 psi. String Weight Up 245,000#, String Weight Down 160,000#, String Weight Rotating 190,000# ART = 16.06 hrs, AST = 1.33 hrs. 2/16/2003 00:00 - 05:30 5.50 DRILL P PROD1 Drilled 6-3/4" Directional Hole By Rotating From 13,790' to 13,860' *NOTE* Sperry Sun Resistivity Tool Failed At 13,800' Continue To Drill Ahead To TD At 13,860' - WOB Rotating 15,000# - 25,000#, RPM 65, Motor RPM 99, Torque Off Bottom 8,000 ft I Ibs - On Bottom 10,000 ft I Ibs, Pump Rate 296 gpm, SPP Off Bottom 3,080 psi, On Bottom 3,180 psi. String Weight Up 245,000#, String Weight Down 160,000#, String Weight Rotating 190,000# ART 4.66 Hrs. 05:30 - 08:00 2.50 DRILL P PROD1 Pumped And Circulated Sweep - Pump Rate 296 GPM , SPP 3,080 Psi. - While Rotating And Reciprocating Drill String - Top Drive Torque At 8,000# With 65 RPM 08:00 - 10:00 2.00 DRILL P PROD1 Held PJSM Blow Down Tesco Top Drive - POH w/6 3/4" Directional BHA On 4" DP From 13,860' To 11,601' With No Hole Problems Over Pull 15,000# Average Drag 10,000# 10:00 - 10:30 0.50 DRILL P PROD1 Observe Well At 11,601' (Static) 10:30-11:30 1.00 DRILL P PROD1 Held PJSM - RIH w/6 3/4" Directional BHA On 4" DP From 11,601' To 13,756' With NO Problems 11 :30 - 12:00 0.50 DRILL P PROD1 MIU Top Drive - Wash And Ream As Precaution From 13,756' To 13,860' No Fill - RPM 65, Motor RPM 99, Torque 8,000 Ft/Lbs, Pump Rate 296 GPM, SPP Off Bottom 3,080 Psi. String Weight Up 260,000# String Weight Down 170,000# String Weight Rotating 200,000# 12:00 - 16:00 4.00 DRILL P PROD1 Circulate And Condition Mud - Pump Sweep With 4 Bottoms Up While Rotating And Reciprocating Drill String - RPM 65, Motor RPM 99, Torque 8,000 Ft/Lbs, Pump Rate 296 GPM, SPP Off Bottom 3,080 Psi. String Weight Up 260,000# String Weight Down 170,000# String Weight Rotating 200,000# - Monitor Well Bore (Static) 16:00 - 16:30 0.50 DRILL P PROD1 Spot 100 Barrel Liner Running Pill - Monitor Well (Static) 16:30 - 18:30 2.00 DRILL P PROD1 Held PJSM Blow Down Tesco Top Drive - POH wI 6 3/4" Directional BHA On 4" DP (SLM) From 13,860' To 11,513' With No Hole Problems Over Pull 15,000# Average Drag 10,000# 18:30 - 20:00 1.50 DRILL P PROD1 Monitor Well Bore Observe Until Static - Pump Dry Job And Blow Down Tesco Top Drive - Drop 2" Rabbit With 110' Tail 20:00 - 00:00 4.00 DRILL P PROD1 POH wI 6 3/4" Directional BHA On 4" DP (SLM) From 11,513' To 3,191' - Flow Check Well Every 20 Stands 2/17/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Held PJSM POH w/6 3/4" Directional BHA On 4" DP (SLM) From 3,191' To 860' (BHA) - Flow Check Well Every 20 Stands And At BHA - Well Bore Static - *NOTE* .90 Differance In Strap No Change - Calculated Fluid Displacement 75.3 bbls. Actual 92.9 bbls. Printed: 2/24/2003 10:29:20 AM ') ) Legal Well Name: 4-10A/L-28 Common Well Name: 4-10A/L-28 Spud Date: 1/25/2003 Event Name: REENTER+COMPLETE Start: 1/25/2003 End: 2/22/2003 Contractor Name: DOYON Rig Release: 2/22/2003 Rig Name: DOYON 15 Rig Number: 15 Date From~To Hours Task Code NPT Phase Description of Operations 2/17/2003 01 :30 - 04:30 3.00 DRILL P PROD1 Held PJSM POH Standing Back 6 Stands 4" HWDP In Mast - LID Remainder Of BHA NO.7 - Daily Hyd. Drilling Jars, 2x 4" HWDP, X/O, 3 x Flex Drill Collars - Held PJSM For Radioactive Sources - Pull To Floor And Remove Sources In BHA NO.7- Down Load MWD/LWD Tools - LID FEMWD w/ DM-PWD-CTN -SLD-DM,- FEMWD w/ GR-Res - LID String Stab, Break 6 3/4" Smith Bit And Lay Down Sperry Sun Mud Motor - Monitor Well Bore Static 04:30 - 05:00 0.50 DRILL P PROD1 Held PJSM Clear Rig Floor Of 4 3/4" Drilling Tools And Wash Off Same 05:00 - 06:30 1.50 CASE P PROD1 Held PJSM - Rig Up Casing Tools And Equip.To Run 4 1/2" 12.6 lb. Hydril 563 (13 Chrome) Liner 06:30 - 07:00 0.50 CASE P PROD1 Hold Pre-Job Safety Meeting With All Personal Regarding Liner Running Operation 07:00 - 12:00 5.00 CASE P PROD1 P/U And Make Up 53 Jts, 4 1/2" 12.6 lb. 13 Chrome Liner Per Well Program - P/U Shoe Track And Bakerlock, Make Up Torque At 8,560 ftllbs - Verify Floats Holding, RIH With 10 Joints 4 1/2" Liner, P/U 2 Marker Joints, Continue To RIH w/ 53 Total Jts. 12:00 - 13:30 1.50 CASE P PROD1 Held PJSM Change Out Bales On Top Drive - P/U 4" DP Elevators - Rig Down Casing Tools And Equipment 13:30 - 14:00 0.50 CASE P PROD1 P/U Baker Flex Lock Liner Hanger, ZXP Packer w/ HRD Setting Tool, Liner Tie Back Sleeve, And Running Tool - Install X/O, P/U (2) 4" Drill Pipe Pup Joints, RIH w/1 Stand 4" Drill Pipe From Mast 14:00 - 14:30 0.50 CASE P PROD1 Circulate 41/2" Liner Volume At 250 GPM With 300 Psi. - Record Liner Weights- String Weight Up 80,000#, String Weight Down 79,000#, Block Weight 50,000# 14:30 - 21 :30 7.00 CASE P PROD1 Held PJSM RIH w/53 Jts, 4 1/2" 12.6 lb. 13 Chrome Liner On 4" Drill Pipe From 2,436' To 11,625' - Record Pick Up Slack Off Weights And Fill 4" Drill Pipe Every 11 Stands Stand Depth Up Weight Down Weight 1 2,436' 80K 79K 9 3,100' 90K 90K 20 4,150' 100K 97K 31 5,200' 110K 109K 42 6,200' 118K 124K 53 7,250' 139K 122K 64 8,311' 148K 129K 75 9,330' 160K 135K 86 10,375' 175K 140K 99 11,625' 180K 142K 21 :30 - 23:00 1.50 CASE P PROD1 Held PJSM M/U Top Drive Circulate Liner Volume And Annular Volume - Pump Rate 258 GPM With 1,120 Psi. Rotating RPM 15, Torque 5,000 ft / Ibs String Weight Up 180,000#, String Weight Down 142,000#, String Weight Rotating 160,000 - Blow Down Top Drive 23:00 - 00:00 1.00 CASE P PROD1 Held PJSM - M/U Cement Head With 4" DP Pup Joint, Cross Overs, Safety Valve, And Full Joint 4" DP Place On Pipe Lay Down Machine 2/18/2003 00:00 - 01 :00 1.00 CASE P PROD1 Held PJSM Rig Up Line To Fill 4" Drill Pipe On The Fly In Open Hole Section - Blow Thru Cement Lines And Stand Pipe Printed: 2/24/2003 10:29:20 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BPEXPLORAIION QperationsSu01matyReport 4-10A/L-28 4-1 OA/L -28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From-To Hours Task Code NPT 2/18/2003 00:00 - 01 :00 1.00 CASE P 01 :00 - 02:30 1.50 CASE P Description. of Operations 02:30 - 03:00 03:00 - 07:30 07:30 - 09:30 0.50 CASE P 4.50 CASE P 2.00 CEMT P PROD1 Manifold - Rig Up Cement Head Manifold And Wash Up Line PROD1 Held PJSM RIH wI 53 Jts, 4 1/2" 12.6 lb. 13 Chrome Liner On 4" Drill Pipe From 11,625' To 13,838' With No Problems - Fill 4" Drill Pipe On The Fly And Rabbit Stands 115 Thru 123 PROD1 Pick Up Cementing Head And Make Up To Tesco Top Drive - Install Manifold And Circulating Lines - Secure With Safety Lines - Work Casing String And Establish Circulation - Tag Bottom At 13,860' With No Problems. 4-1/2" Liner Set As Follows: Item Length Depth Reamer Shoe 2.39' 13,860.00' 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr 42.38' 13,815.23' Float Collar 1.59' 13,813.64' 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr 42.38' 13,771.26' Latch Collar 1.72' 13,769.54' 8 Jts 4-1/2" 12.6# L-80 Hydril563 Lnr 335.73' 13,433.81' 4-1/2" 12.6# L-80 Hydril 563 Mkr Jt 19.83' 13,413.98' 4-1/2" 12.6# L-80 Hydril 563 Mkr Jt 19.84' 13,394.14' 43 Jts 4-1/2" 12.6# L-80 Hydril 563 Lnr 1,815.76' 11,578.38' Cross Over Bushing 5.25' 11,573.13' Liner Hanger 7.86' 11,565.27' RS Nipple 2.85' 11,562.42' ZXP Packer 7.97' 11,554.45' Tie Back Sleeve 11.04' 11,543.41' PROD1 Stage Up Pump Rates as Follows: Rate Pressure 4.0 BPM 910 psi 5.0 BPM 1,300 psi 5.5 BPM 1,500 psi 6.0 BPM 1,400 psi. String Weight Up 225,000#, String Weight Down 160,000# Continue To Circulate to Cool and Condition the Hole While Reciprocating Casing String Continuously. PROD1 Held PJSM wI Dowell, Peak Truck Driver and Rig Crew. Switched over to Dowell. Pumped 5 bbls of Seawater to Flush the Lines and to Establish Circulation. Shut in Cement Manifold and Tested Lines to 4,500 psi, OK. Pumped 35 bbls of MudPush at 3.5 bpm, 790 psi. Pumped 75 bbls (350 sx) 15.8 ppg Latex Cement wI 0.40% bwoc Dispersant, 0.30% bwoc Retarder, 3.00 gal/sk Expanding Agent, 0.20 gal/sk Antifoam, 2.00 gallsk GASBLOK. Pumped Cement at the Following Rates: Pumped Rate Pressure 20.0 bbls 5.00 bpm 1,050 psi 40.0 bbls 5.00 bpm 875 psi 60.0 bbls 3.00 bpm 280 psi 75.0 bbls 3.00 bpm 250 psi Cleaned up Behind Plug, Dropped Drill Pipe Dart and Pumped out of Manifold wI 5 bbls of Water at 3.00 bpm, 125 psi. Displaced wI 153 bbls of Mud at the Following Rates: Printed: 2/24/2003 10:29:20 AM ) ) BPEXPLORATION Operations Summary .~epol1 Legal Well Name: 4-1 OAlL -28 Common Well Name: 4-10AlL-28 Spud Date: 1/25/2003 Event Name: REENTER+COMPLETE Start: 1/25/2003 End: 2/22/2003 Contractor Name: DOYON Rig Release: 2/22/2003 Rig Name: DOYON 15 Rig Number: 15 Date From-To HoUrs Task Code NPT Phase 2/18/2003 07:30 - 09:30 2.00 CEMT P PROD1 Pumped Rate Pressure 20.0 bbls 5.0 bpm 200 psi 40.0 bbls 6.0 bpm 275 psi 60.0 bbls 5.0 bpm 600 psi 80.0 bbls 5.0 bpm 800 psi 100.0 bbls 5.0 bpm 950 psi 120.0 bbls 5.0 bpm 1 ,200 psi slw'd Pmps to 2.5 bpm 750 psi Drill Pipe Dart hit wI 124.5 bbls pumped, Pressure Increased to 1,100 psi, Wiper Plug Sheared, Pressure Dropped to 750 psi, Increased Rate 140.0 bbls 3.5 bpm 1 ,1 00 psi 150.0 bbls 3.5 bpm 1,350 psi Wiper Plug Bumped wI 158 bbls Pumped. Cement in Place @ 0930 Hrs. 09:30 - 10:00 0.50 CASE P PROD1 Increased Pressure to 2,900 psi to Set Liner Hanger, Bled off Pressure to 500 psi. Slacked off on Liner to Confirm Hanger Set. Pressured up to 4,200 psi to Shear Running Tool off of Liner, Bled Off Pressure. P I U 3' on DP to Confirm Running Tool Released and to Expose Setting Dogs. Set Down on Liner Top wI 50,000# and Observed ZXP Packer Set. Pressure Up on Liner to 1,000 psi, PI U on Drill Pipe 10', Observed Pressure Drop to 0 psi to Reconfirm Liner Running Tool Released from Liner. 10:00 - 11 :00 1.00 CEMT P PROD1 Circulated Bottoms up to Clean Cement out of Hole. Pump Rate 8 bpm, 2,150 psi. Circulated Back 12 bbls of Cement Contaminated Mud. 11 :00 - 11 :30 0.50 CASE P PROD1 Held PJSM. Closed Annular and Pressure Tested Liner Top and Casing to 2,000 psi fl 5 minutes. OK. Bled Down Pressure and Opened Annular. 11 :30 - 14:00 2.50 CASE P PROD1 Displaced the Well wI Clean Seawater. Pump Rate 8 bpm, 1,900 psi. - PUMP 25 BBLS SEA WATER - 75 BBLS DIRT MAGNET - 25 BBLS HI-VIS PILL - DISPLACE WITH SEA - WATER 14:00 - 14:30 0.50 CASE P PROD1 PJSM - RIG SERVICE 14:30 - 15:30 1.00 CASE P PROD1 PJSM - RIG DOWN AND LAY DOWN BAKER ROTATING CEMENT ASSEMBL Y 15:30 - 00:00 8.50 CASE P PROD1 LAY DOWN 4" DRILL PIPE FROM 11530' TO 1214' 2/19/2003 00:00 - 02:00 2.00 CASE P PROD1 LAYING DOWN 4" DRILL PIPE FROM 1,214' - LAY DOWN BAKER RUNNING TOOL 02:00 - 03:00 1.00 CASE P PROD1 MAKE UP MULE SHOE ON HWDP - RUN IN 6 STDS 4" HWDP - 18 STDS 4" DP 03:00 - 05:30 2.50 CASE P PROD1 LAYING DOWN 4" DP - 4" HWDP 05:30 - 06:00 0.50 WHSUR P COMP PULL WEAR BUSHING 06:00 - 07:30 1.50 RIGD P COMP CLEAR FLOOR OF 4" RENTAL TOOLS 07:30 - 09:00 1.50 RIGU P COMP RIG UP COMPENSATOR - TORQUE TURN - 41/2" COMPLETION RUNNING TOOLS 09:00 - 00:00 15.00 RUNCOrvP COMP RUN 41/2" VAM ACE CR-13 L-80 COMPLETION - TESTING EVERY 2,000' RUN TO 3,500 PSI FOR 10 MINS - TOTAL JOINTS RAN 150 - DEPTH 6,508' 2/20/2003 00:00 - 07:30 7.50 RUNCOrvP COMP RUN 41/2" 12.6# CR-13 L-80 TUBING - TESTING STRING EVERY 2000' TO 3500' PSI FOR 10 MINS - TOTAL JOINTS RAN 233 JOINTS Printed: 2/24/2003 1029:20 AM ') ) Bp·EXPLORATION OperationsSumm.ary.. R~port Legal Well Name: 4-10A/L-28 Common Well Name: 4-10A/L-28 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 15 Date From- To Hours Task Code NPT 2/20/2003 07:30 - 09:00 1.50 RUNCOrvP 09:00 - 12:30 3.50 RUNCOrvP 12:30 - 13:30 1.00 RUNCOrvP 13:30 - 15:30 2.00 RUNCOrvP 15:30 - 16:30 1.00 RUNCOrvP 16:30 - 00:00 7.50 RUNCOrvP 2/21/2003 00:00 - 02:00 2.00 RUNCOrvP 02:00 - 05:30 3.50 RUNCOrvP 05:30 - 07:30 2.00 RUNCOrvP 07:30 - 08:30 1.00 RUNCOrvP 08:30 - 09:00 0.50 RUNCOrvP 09:00 - 11 :00 2.00 RUNCOrvP 11:00-11:30 0.50 RUNCOM Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Descri ptionofOperations COMP RIG UP HALLIBURTON CONTROL LINE SPOOL - CONNECT LINES TO SSSV - TEST TO 5000 PSI - FOR 15 MINUTES COMP RUN 41/2" 12.6# CR-13 L-80 TUBING - RUN TO 11559'- TOTAL JOINTS RAN 268 - 37 STAINLESS STEEL BANDS RAN COMP PULL OUT TO 11458' - RIH WITH SPACE OUT PUPS (3.75- 10.22) TO 11554' COMP MAKE UP HANGER AND LANDING JOINT - LAND HANGER - TEST TUBING TO 3500 PSI COMP RIG UP HALLIBURTON SLICK LINE UNIT COMP SLICK LINE WORK - RIH PULL SSSV DUMMY - RIH EQUALIZE D-16 PLUG - RIH RETRIEVE D-16 PLUG COMP PJSM. BROKE OUT AND L / D RETRIEVING TOOLS. M / U 3.60" GAUGE AND BAILER. RIH w/ 3.60" GAUGE RING AND BAILER TO 11,621 " POOH. COMP M / U SETTING TOOL AND RHC SLEEVE. RIH AND SET RHC SLEEVE IN X NIPPLE AT 11,521'. SHEARED OFF OF RHC SLEEVE AND POOH. COMP M / U CHECK SET TOOL AND RIH ON SLlCKLlNE TO VERIFY RHC SLEEVE SET, OK. POOH. COMP M / U SETTING TOOL AND DUMMY SLEEVE. RIH ON SLlCKLlNE AND SET DUMMY SLEEVE IN SSSV AT 1,530'. SHEARED OFF OF SLEEVE AND POOH. COMP R / D HES SLlCKLlNE. COMP PJSM. R / U CIRCULATING SUBS AND HOSES. REVERSE CIRCULATED 300 BBLS OF CLEAN SEAWATER w/ CORROSION INHIBITOR. PUMP RATE 3 BPM, 300 PSI. COMP RILDS AND TORQUED. COMPLETION EQUIPMENT SET AT THE FOLLOWING DEPTHS: ITEM LENGTH DEPTH WLEG 1.34' 11,554.90' XN NIPPLE ASSEMBLY 20.85' 11,532.71' X NIPPLE ASSEMBLY 20.81' 11,511.90' S-3 PACKER ASSEMBLY 23.65' 11 ,488.25' X NIPPLE ASSEMBLY 20.75' 11,467.50' 70 JTS 4-1/2" 12.6# 13Cr VM AC TB 2,934.15' 8,533.35' #1 GLM ASSEMBLY 26.64' 8,506.71 ' 18 JTS 4-1/2" 12.6# 13Cr VM AC TB 756.02' 7,750.69' #2 GLM ASSEMBLY 26.60' 7,724.09' 17 JTS 4-1/2" 12.6# 13Cr VM AC TB 713.81' 7,010.28' #3 GLM ASSEMBLY 26.60' 6,983.68' 17 JTS 4-1/2" 12.6# 13Cr VM AC TB 713.84' 6,269.84' #4 GLM ASSEMBLY 26.58' 6,243.26' 25 JTS 4-1/2" 12.6# 13CrVM AC TB 1,002.02' 5,198.76' Printed: 2/24/2003 10:29:20 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4-10A/L-28 4-10AlL-28 REENTER+COMPLETE DOYON DOYON 15 Page 19 of20 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Description of Operations 2/21/2003 11 :00 - 11 :30 From-To Hours Task Code NPT Phase 26.38' 11 :30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 19:30 19:30 - 20:00 20:00 - 23:30 2/22/2003 23:30 - 00:00 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 10:30 0.50 RUNCOM 2.50 RUNCOrvP 0.50 RUNCOrvP 1.00 RUNCOrvP 1.00 RUNCOrvP 3.00 RUNCOrvP 0.50 RUNCOrvP 3.50 RUNCOrvP 0.50 RUNCOrvP 4.00 RUNCOrvP 1.50 RUNCOrvP 0.50 RUNCOrvP 1.00 RUNCOrvP 0.50 RUNCOrvP 0.50 RUNCOrvP 2.00 RUNCO~ 0.50 RUNCOrvP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP #5 GLM ASSEMBLY 5,172.38' 39 JTS 4-1/2" 12.6# 13Cr VM AC TB #6 GLM ASSEMBLY wi DCK VALVE 47 JTS 4-1/2" 12.6# 13Cr VM AC TB SSSV ASSEMBLY 1,520.26' 34 JTS 4-1/2" 12.6# 13Cr VM AC TB 1,588.60' 26.61' 1,972.36' 22.56' 3,541.79' 3,515.18' 1,542.82' 1,424.29' 95.97" 2-4-1/2" 12.6# 13CrVM AC PUP JTS 13.97' 82.00' 1 JT4-1/2"12.6# 13CrVMACTB 41.98' 40.02' TUBING HANGER 2.97' 37.05' PJSM. DROPPED BALL I ROD, WAITED FOR BALL TO SEAT IN RHC SLEEVE SET IN X NIPPLE AT 11,521'. PRESSURED UP ON TUBING TO 2,500 PSI TO SET PACKER. PRESSURE TESTED TUBING TO 3,500 PSI fl 30 MINUTES, OK. BLED DOWN TUBING PRESSURE TO 1,500 PSI. PRESSURE TESTED 7-5/8" x 4-1/2" IA TO 3,000 PSI fl 30 MINUTES, OK. QUICKLY BLED DOWN TUBING PRESSURE, DCK VALVE SHEARED wi 2,500 PSI DIFFERENTIAL. LINED UP TO PUMP TO ESTABLISH THAT DCK VALVE IS FULLY SHEARED. PUMPED DOWN IA TOOK RETURNS UP TUBING, PUMP RATE 3 BPM, 1,475 PSI. PUMPED DOWN TUBING TOOK RETURNS UP lA, PUMP RATE 3 BPM, 1,575 PSI. RID HOSES AND ALL TESTING EQUIPMENT. BRAKE OUT AND LID LANDING JOINT - SET TWC. ATTEMPTED TO TEST TWC FROM BELOW, FAILED. DRAINED STACK - PULLED TWC - WITH LUBICATOR- RESET TWC - TESTED TO 1000 PSI FOR 10 MINUTES - OK REMOVED TUBING ELEVATORS AND LONG BAILS - LAID DOWN MOUSE HOLE - LUBICA TOR - BLEW DOWN ALL LINES PJSM - NIPPLED DOWN BOP'S (CHANGED TOP DRIVE SAVER SUB FROM 4" XT-39 TO 41/2" IF) INSTALLED CONTROL LINES - TEST TO 5000 PSI NIPPLE UP ADAPTER FLANGE - TREE - TEST ADAPTER FLANGE TO 5000 PSI FOR 1 0 MINUTES WITH FMC ACTUATOR ON WING VALVE WILL NOT CLOSE -INSTALL BLIND FLANGE ON VALVE - TOP CAP ON HOUSING FOR ACTUATOR LEAKING SMALL AMOUNT OF OIL TEST TREE TO 5K FOR 30 MINUTES RIG UP DSM LUBICATOR - PULL TWC RIG UP CIRC LINES TO FREEZE PROTECT WITH LITTLE RED - TEST LINES TO 2500 PSI DISPLACE ANNULUS WITH 65 BBLS DIESEL WITH LITTLE RED U-TUBE DIESEL FROM ANNULUS TO TUBING SUCK BACK ALL CIRC LINES OF DIESEL WITH LITTLE RED Printed: 2/24/2003 10:29:20 AM ) ) BP EXPLORAJIC)N Page20of20 Ope ratio ns8 uml11aryRepo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4-1 OAIL -28 4-10AlL-28 REENTER+COMPLETE DOYON DOYON 15 Start: 1/25/2003 Rig Release: 2/22/2003 Rig Number: 15 Spud Date: 1/25/2003 End: 2/22/2003 Date From-To Hours. Task Code NPT Description <of Operations 2/22/2003 10:00 - 10:30 10:30 - 13:00 0.50 RUNCOrvP 2.50 RUNCOrvP CaMP - BLOW DOWN ALL LINES CaMP SET BPV WITH FMC - SECURE WELL - (INSTALL FLANGE AND GAUGE ON ANNULUS AND TREE CAP). RELEASE RIG 13:00 - 21 :00 8.00 RUNCOrvP CaMP ADDITIONAL 8 HRS RIG TIME CHARGED FOR BOP TESTING DONE ON STUMP FOR INTIAL RIG UP - WHICH WAS AGREED UPON BY BP / DOYON - ACTUAL RIG RELEASE 21 :00 HRS ON 2/22/2003 Printed: 2/24/2003 10:2920 AM ') ¡ ') 26-Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 4-10A/L-28 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,599.87' MD Window / Kickoff Survey: 11,690.00 I MD (if applicable) Projected Survey: 13,860.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 ~nrn ... ,.' '" \.' PJati~a Viii j,; r'a" /'/,>.,.", ,-', '. I..~ \~?~;;.¡ \.....,(, ¡ '. ',r. p·".rn.!bòro.<'! . " ¡.'~' 11... ' ...., ~: i..~.~.~111 linmOrt!'fl'"J; 'Ï,oo,. dO;;),;)Sr Sperry-Sun Drilling Services Alaska State Plane 3 BPXA 4-10A/L-28 ~ Job No. AKMW22205, Surveyed: 16 February, 2003 Survey Report 26 March, 2003 Your Ref: API 500292246401 Surface Coordinates: 5970800.58 N, 270221.35 E (70019' 18.6373" N, 147051'47.4537" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Kelly Bushing: 55. 67ft above Mean Sea Level ~-" spE!r'raY-5UIl pRIL. LINt:r~' S ERvlê:es A Halliburton Company Survey Ref: svy329 Sperry-Sun Drilling Services Survey Report for 4-10A/L-28 Your Ref: API 500292246401 Job No. AKMW22205, Surveyed: 16 February, 2003 BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 11599.87 50.400 349.730 8538.14 8593.81 6779.77 N 1336.08 W 5977618.07 N 269093.47 E 6834.58 Tie On Point MWD Mag netic 11690.00 50.490 349.760 8595.54 8651.21 6848.15 N 1348.45 W 5977686.80 N 269083.20 E 0.103 6903.15 Window Point 11720.59 47.330 349.970 8615.64 8671.31 6870.84 N 1352.51 W 5977709.61 N 269079.84 E 10.343 6925.88 11744.69 46.040 350.710 8632.17 8687.84 6888.12 N 1355.45 W 5977726.97 N 269077.42 E 5.800 6943.15 11777.33 45.050 351.770 8655.03 8710.70 6911.15 N 1359.00 W 5977750.10 N 269074.58 E 3.817 6966.03 -' 11878.33 44.470 347.850 8726.76 8782.43 6981.12 N 1371.56 W 5977820.42 N 269064.16 E 2.792 7036.16 11974.50 44.640 347.330 8795.29 8850.96 7047.02 N 1386.06 W 5977886.73 N 269051.69 E 0.419 7103.10 12066.57 43.680 346.400 8861.34 8917.01 7109.48 N 1400.63 W 5977949.61 N 269039.04 E 1.258 7166.82 12160.34 43.150 342.840 8929.47 8985.14 7171.60 N 1417.71 W 5978012.22 N 269023.87 E 2.670 7231.07 12253.94 41.200 344.290 8998.83 9054.50 7231.86 N 1435.50 W 5978073.00 N 269007.93 E 2.328 7293.81 12348.50 32.710 347.900 9074.33 9130.00 7286.93 N 1449.32 W 5978128.47 N 268995.81 E 9.264 7350.32 12440.83 29.090 347.820 9153.55 9209.22 7333.28 N 1459.29 W 5978175.10 N 268987.26 E 3.921 7397.32 12536.11 27.600 346.470 9237.40 9293.07 7377.38 N 1469.34 W 5978219.49 N 268978.57 E 1.702 7442.24 12626.23 35.690 355.200 9314.10 9369.77 7423.98 N 1476.44 W 5978266.28 N 268972.90 E 10.295 7488.51 12721.78 38.290 346.830 9390.46 9446.13 7480.62 N 1485.52 W 5978323.18 N 268965.55 E 5.926 7544.91 12814.48 35.680 332.920 9464.63 9520.30 7532.76 N 1504.41 W 5978375.87 N 268948.27 E 9.438 7600.37 12907.28 32.710 328.540 9541.39 9597.06 7578.26 N 1529.83 W 5978422.12 N 268924.26 E 4.155 7651.76 13000.02 34.170 335.880 9618.81 9674.48 7623.42 N 1553.56 W 5978467.99 N 268901.92 E 4.634 7702.27 13097.60 29.930 340.790 9701.51 9757.18 7671.45 N 1572.78 W 5978516.59 N 268884.18 E 5.097 7753.97 13134.41 29.920 331.690 9733.43 9789.10 7688.22 N 1580.16 W 5978533.57 N 268877.32 E 12.323 7772.24 13161.65 31.830 327.310 9756.82 9812.49 7700.25 N 1587.26 W 5978545.81 N 268870.59 E 10.824 7785.95 13220.93 37.810 329.310 9805.46 9861.13 7729.05 N 1604.99 W 5978575.15 N 268853.74 E 10.269 7819.04 ~ 13251.40 37.830 330.780 9829.53 9885.20 7745.24 N 1614.32 W 5978591.61 N 268844.91 E 2.959 7837.42 13281.78 37.620 332.090 9853.56 9909.23 7761.57 N 1623.21 W 5978608.20 N 268836.53 E 2.727 7855.79 13317.69 38.640 329.100 9881.81 9937.48 7780.87 N 1634.10 W 5978627.84 N 268826.24 E 5.873 7877.63 13401 .86 38.050 316.190 9947.93 10003.60 7822.21 N 1665.60 W 5978670.12 N 268796.01 E 9.529 7927.15 13496.18 39.590 318.200 10021.42 10077.09 7865.59 N 1705.76 W 5978714.71 N 268757.20 E 2.109 7981.50 13589.95 37.160 326.060 10094.97 10150.64 7911.40 N 1741.52 W 5978761.59 N 268722.87 E 5.809 8036.65 13682.87 40.390 331 .290 10167.42 10223.09 7961.11 N 1771.66 W 5978812.20 N 268694.26 E 4.948 8093.61 13775.42 42.350 332.620 10236.87 10292.54 8015.10 N 1800.41 W 5978867.04 N 268667.18 E 2.321 8154.11 26 March, 2003 - 9:07 Page 2 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 4-10AlL-28 Your Ref: API 500292246401 Job No. AKMW22205, Surveyed: 16 February, 2003 Alaska State Plane 3 Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (tt) (tt) (tt) 13788.45 42.010 332.350 10246.53 10302.20 13860.00 42.010 332.350 10299.69 10355.36 Local Coordinates Northings Eastings (tt) (tt) Global Coordinates Northings Eastings (tt) (ft) 1804.45 W 1826.67 W 5978874.92 N 5978918.00 N 8022.86 N 8065.28 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 340.370° (True). Magnetic Declination at Surface is 26.415°(30-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13860.00ft., The Bottom Hole Displacement is 8269.55ft., in the Direction of 347.239° (True). Comments Measured Depth (tt) Station Coordinates TVD Northings Eastings (tt) (tt) (tt) Comment 11599.87 11690.00 13860.00 8593.81 8651.21 10355.36 6779.77 N 6848.15 N 8065.28 N Tie On Point Window Point Projected Survey 1336.08 W 1348.45 W 1826.67 W 26 March, 2003 - 9:07 Page 30f4 268663.38 E 268642.46 E Dogleg Vertical Rate Section e/100tt) BPXA Comment 2.957 8162.78 0.000 8210.20 Projected Survey - ~ DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 4-10A/L-28 Your Ref: AP/500292246401 Job No. AKMW22205, Surveyed: 16 February, 2003 BPXA Alaska State Plane 3 Survey tool proqram for 4-10A/L-28 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11599.87 0.00 11599.87 8593.81 AK-1 BP _HG - BP High Accuracy Gyro(4-10/M-28) 8593.81 13860.00 10355.36 MWD Magnetic(4-10A/L-28) -' -~ 26 March, 2003 - 9:07 Page 4 of4 DrillQuest 3.03.02.002 ) J --) ,,.-,\ 3Jï') /1/)., .; /7\1 r/,. (/<1" ' {./ / ,-/,...... ! ~~®:r~ ~. w/ru~L ~ ,~ f !Æ~!Æ~~~!Æ FRANK H. MURKOW5KI, GOVERNOR ~ AI,ASIiA. ORAND GAS CONSERVATION COMMlSSION/ 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL NO. 202.40 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Variance Exception for Endicott 4-10/L-28 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated February 19, 2003, requesting a.variance exception for perforating a productive interval within the Endicott 4-1 O/L-28 well. The proposed 4-1 O/L-28 well will be a producer in Subzone 2A of the Kekiktuk Fonnation. Nearby existing well 3-07 A/L-29 is a producer that is completed in this same interval. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the pool." The Commission understands that the interval intended for perforation within 4-1 O/L-28is approximately 700 feet horizontal distance from the producing interval in well 3-07 A/L-29. These two wells lie on opposite sides of the Midfield Fault, which is a sealing fault based on reservoir pressure infonnation. Because these wells lie on opposite sides of a sealing fault, production from Kekiktuk Subzone 2A inwell4-10/L-28 will not interfere with production from well 3- 07 A/L-29. The Commission has detennined perforation of the Endicott 4-10/L-28 well will not promote waste, will enhance recovery, and hereby approves the perforation of the well within Kekiktuk Subzone 2A pursuant to Rule 3 of Conservation Order No. 202. ~~ Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION ) ~lJ~JŒ J} !Æ~!Æ~~!Æ / AI.A.SKA OIL Al'm GAS / CONSERVATION COMMISSION / t FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 4-1 0/L-28 BP Exploration (Alaska), Inc. Permit No: 202-238 Surface Location: 2581' NSL, 816' WEL, Sec. 08, TIIN, R17E, UM Bottomhole Location: 82' NSL, 2564' WEL, Sec. 32, T12N, R17E, UM Dear Mr. Johnson: Enclosed is the approved application for pem1it to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 7!: day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section vJ6,+ .'lr/63 Hole 6-3/411 'l STATE OF ALASKA ~. ALASKA vi AND GAS CONSERVATION COMrW....J~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [J Exploratory [J Stratigraphic Test II Development Oil [J Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool r" KBE = 55.8' Endicott Field / Endicott Pool '" 6. Property Designation ADL312828 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number / 4-10AlL-28 9. Approximate spud datß 01/15/03 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13848' MD /10374' TVD o 17. Anticipated pressure {s!?,-20 AAC 25.035 (e) (2)} 51 Maximum surface 3965 psig, At total depth (TVD) 10248' / 4990 psig Setting Depth TOD Bottom Quantitv of Cement Lenath MD TVD MD TVD linclUde)taae data) 2250' 11600' 8595' 13848' 10374' 294 sx Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work [J Drill II Redrill [J Re-Entry [J Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2581' NSL, 816' WEL, SEC. 08, T11 N, R17E, UM At top of productive interval 5202' NSL, 2497' WEL, SEC. 05, T11 N, R17E, UM At total depth 82' NSL, 2564 WEL, SEC. 32, T12N, R17E, UM 12. Distance to nearest,Jjrop rty line 13. Distance to nearest well /' ADL 04750 ,'82' D 3-09/L-28 is 243' away at 13155' MD 16. To be complete for· "iated wells Kick Off Depth 11758' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casinq WeiÇlht Grade CouDlina 4-1/211 12.6# 13Cr80 Hydril563 Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14425 feet 10265 feet 13370 feet 9883 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD Drive 131' 131' 800 sx PF 'E', 375 sx 'G' 3993' 3696' 440 sx Class 'G' 14409' 10256' RECEIVED Structural Conductor Surface Intermediate Production Liner 94' 3952' 3011 10-3/411 14368' 7-5/811 Perforation depth: measured None DEC 11 2002 20. Attachments Alaska Oil & Gas Cons. Commission Anchma{1Ð a Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch a-Ohlling Program a Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report a 20 AAC 25.050 Requirements Contact Engineer Name/Number: Fred Johnson, 564-5427 Prepared By NamelNumber: Sondra Stewman, 564-4750 21. I hereby certify that the f~Oing i'Þ true n correct to the best of my knowledge Signed Fred Johnson \ J.M.Æ}. Title Senior Drilling Engineer ;.,,~~þß·~:~(Y":.". true vertical None Date I ~ It ~ /o'Z. Permit Number 202- -.2 3ð' Conditions of Approval: API Number 50- 029-22464-01 Samples Required 0 Yes JE] No Hydrogen Sulfide Measures gJ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: ·Të("~·t- ~~E ~ 4-~oo e ç."I. ORIGINAL SIGNED BY M L Bill Appr?val Date See cover letter '/7/(; 3 for other requirements Mud Log Required 0 Yes J8I No Directional Survey Required ~ Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 ;.~-) ~'lGQ~~~~i~~e~ .' ¡; ~ \<) ,':.'\ L,", by order of the commission Date I , /712) 3 Submit In Triplicate ') ) Endicott 4-10AlL-28 Well Program IWell Name: Endicott 4-1 OA/L-28 I /' Drill and Complete Plan Summary I Type of Well (service I producer I injector): Surface Location: Target Location: TOP "K2B" Target Location: TO P "K2A" Target Location: TOP "K1" Target Location: Well TD I AFE Number: I Estimated Start Date: 1 MD: 113,848' I I K2A Producer 25811 NSL, 8161 WEL, SEC. 08, T11 N, R17E E=270221 N=5970800 5114' NSL, 2459' WEL, SEC. 05, T11 N, R17E E=268795 N=5978661 Z=9960' TVD 5202'NSL,2497'WEL, SEC. 05, T11N, R17E E=268760 N=5978750 Z=1 01 07' TVD T NSL, 2332' WEL, SEC. 32, T12N, R17E Er2?8727 N=5978835 Z=1 0248' TVD té~;f\JSL, 2564' WEL, SEC. 32, T12N, R17E ~=268697 N=5978911 Z=10374' TVD I END72711 0 I Rig: I Doyon 15 .,,/ I 18.5 I 155.8' I January 15, 2003 I /. I Operating days to complete: 1 TVD: 110,374' I I Max Inc: 151 I I KOP: 111,758' 1 1 KBE: Well Design (conventional, slimhole, etc.): I Target Objective: Well Objectives: Conventional Slim hole 7-5/8" Sidetrack. Chrome liner and chrome completion. Kekiktuk K2A Lower Subzones .~,/ · No recordable injuries. No spills.·.."""--') · Drill and complete well successfully. NOiTrain~Øs . Run 4-1/2" liner to TO \."."....::::;:::... · Cement liner successfully to obtain zonal isolation across Kekiktuk sands Overview: P&A existing perforations in pre-rig work. MIRU Doyon 15. Pull 4-1/2" L-80 tubing. Cut 50' section in 7-5/8" casing at 11750'. Set cement plug for kickoff. Kickoff and drill 6-3/4" hole to 13,848' TO. Obtain triple combo LWD logs across Kekiktuk while drilling. Run and cement 4-1/2" rotatable liner. Run 4-1/2" chrome tubing completion. ./ Version 1.0 10 Dee 2002 ) ) Endicott 4-10AlL-28 Well Program Formation Markers: Formation Tops M Drkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1506 1500 8.65 KOP in Seabee 11758 8695 3910 8.65 Top Tuffs 12190 9012 4054 8.65 Top HRZ 12848 9543 4962 10.0 \0. ~ Base HRZ/LCU 13170 9806 5099 10.0 Top K3A 13170 9806 4792 9.5 P3 Coals 13252 9874 4471 8.8 K2B 13355 9960 4508 8.8 K2A 13530 10107 4272 8.2 K1 13698 10248 4933 9.3 Mud Program: 7-5/8" Section Milling Mud Properties: (11 ,750'MD) Density (Ib/gal~ Funnel visc YP HTHP 9.7 20-300 >70 N/A Freshwater Bentonite Milling Fluid pH API Filtrate LG Solids 8.5 - 9.5 < 8 N/A 6-3/4" Production Hole Mud Interval Density (Ib/gal) KOP - THRZ 9.7 I Properties: (11,750' - 13,848') I Freshwater GEM Enhanced LSND PV YP TAUO 10' Gel API! HTHP pH LG Solids 1 0 - 15 27 - 32 4-7 10 6-10 8.5 - 9.5 <5 Top HRZ - TD 10.3/' 10 -15 20 - 25 3-7 10 <41 <10 8.5 - 9.5 <5 LCM Restrictions: Minimize use of organic LCM products in the Kekiktuk Waste Disposal:NO ANNULAR INJECTION. Waste mud and drill cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Be aware of Sag River Bridge load restrictions. Alternative mud disposal at Endicott is being reviewed. Cement Program: Casin~ Size 14-1/2" 12.6 Ibltt 13 Chrome 80 Hydril563 liner ..../'] Basis 50% excess over gauge hole in open hole interval. TOC )217ß' (1000' md above Kekiktuk) (/". Total Cement Volume: 63-bbl Wash Spacer Lead Tail Temp 35;bbI11.5-lb/gal Mudpush XL r)fune /..) ~)¿sx (63-bbl) 15.8 Ib/gal Prem G - ~ cuft/sx (top of tail at 12178-ft BHST ::::: 2150 F from SOR, BHCT 1650 F estimated by Dowell None Version 1.0 2 of 20 09 Dec 2002 ) ') Endicott 4-10AlL-28 Well Program Evaluation Program: 6-3/4" Hole Section: KOP to Top Kekiktuk: Kekiktuk MWO/GR/PWO Real Time and Recorded, INSITE Cased Hole: Cement bond log - post rig work MWO/GR/Res/Neutron/Oensity/PWO LWO Real Time and Recorded, INSITE Casing/Tubing Program: Hole Csgl WtlFt Grade co~ Length Top Bottom Size Tbg O.D. / MD I TVDrkb M D I TVDrkb 6-3/4-in 4 1/2-in 12.6 # 13Chr80 Hydril563 2250-ft 11,600' MOl 13,848' M 0/ 8,595' TVO 10374' TVO Tubing 4 V2 -in 12.6# 13Chr80 VAM ACE 11,600-ft GL 11,600' MOl 8,595- TVO Recommended Bit Program: BHA Hole Size 6 %" 6 3,4" 6 3,4" 1 Contingency Contingency Directional Plan KOP: 111,758' MO Maximum Hole Angle: Close Approach Well: Survey Program: Version 1.0 Depth (MD) 11758' KOP Tuffs H RZlKekiktuk Bit Type Nozzles 6 Blade PDC 437/517 Roller Cone 6-7 Blade PDC 6x11 (.57TFA) .57 TFA .57 TFA -Original wellbore is a 50° slant well design -Maximum inclination 53° in original well bore at -8940' MD. /' -Sidetrack drops inclination from 50° at KOP to 33° at TO There are two close approach issues: (1 )There is a deep close aæ;ach to the P&A'd 3-09/L-28 wellbore with a center to center distance of 4 /at a ,/ planned depth of 13155'. (2)The closest well to the 4-10A/L-28 -4-10/M-28 original well at the 11758' KOP. The planned well passes the Major Risk scan at 12470'. MWO surveys from kick-off to TO. 3 of 20 09 Oec 2002 Well Control: Production Intervals BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure Casing Test Pressure (7-5/8" x 4-1/2") Planned completion fluids ) ') Endicott 4-10AlL-28 Well Program 13-3/8", 5M, Double ram with annular (Hydril- GK) 4990-psi (9.3-lb/gal @ 10248-ft TVD) 3965-psi (0.1-psi/ft gas gradient to surface) /' Infinite L/S()g W6A- Rams test to §fi<)'(f-psi/250-psi. Annular test to 3,500-psi/250-psi 3,000-psi (max jet pump pressure) /' 8.5 Seawater & Diesel packer fluid 4-10A/L-28 is being drilled as a K2A producer. The 10.3 Ib/gal recommended mud weight for the HRZ is the controlling mud weight requirement. All of the prognosed Kekiktuk intervals should be overbalanced with this mud weight. Kick tolerance The Kick Tolerance for the 7-5/8" production casing at the KOP, based on the 9.5-lb/gal expected pore pressure is infinite with an FIT of 11.50-lb/gal EMW. Waste Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all exempt drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Classl wastes to Pad 3 for disposal · Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Be aware of Sag River Bridge load restrictions. Alternative mud disposal at Endicott is being reviewed. Version 1.0 4 of 20 09 Dec 2002 '') ) ) Endicott 4-10A/L-28 Well Program Sidetrack and Completion Procedure Summary Pre-RiQ Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Test the FMC 7-5/8" mandrel hanger packoff and tubing hanger seals to 5000 psi for 30 minutes. COMPLETE (10/10/01): Casing packott passed test to 3000 psi, Tubing hanger passed test to 5000 psi. All tubing hanger lock-down screws functioned. 2. RU slickline, drift tubing and tag PBTD. Tubing drifted on 11/10/02 w/3.625" OD to 14,167'. Dummy off all GLM's 2/26/01. Test the integrity of the IA by applying -3000 psi on the annulus. IA x tubing annulus tested to 2900 psi on 10/18/02. 3. RIH with CTU and perform a cement P&A using 15.8 Ib/gal cement. Use adequate cement volume to fill the 7-5/8" casing from PBTD (14251') up to +/-13750' in the 7-5/8" casing. Squeeze 2 additional bbls into the perforations 4. RU slickline. Tag and document top of cement and drift tubing to 3.625" for upcoming tubing cut. 5. Test the integrity of the cement plug and casing by simultaneously pressure testing both the tubing and annulus to 3000 psi for 30 minutes. Increase tubing pressure prior to the 7-5/8" annulus to avoid possibility of tubing collapse. 6. Pull one of the lower DGLV. Displace the well to clean seawater by circulating down the tubing. Freeze protect the top 2000' md. 7. Cut the 4 Y2", 12.6Ib/ft L-80 tubing at approximately 12,200' MD. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 9. Prep the well house, cleanout cellar, and rig down the flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: /' 1. MIRU Doyon 15. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree. Alignment marks should be made before removinq the old tree. Nipple up and test BOPE to 250 /..5-QOO'psi. Pull TWC. t/5oo ~,~ /" 4. Pull and lay down 4-1/2" tubing from E-line cut at 12,200'. /' 5. RU e-line. Make GRJB run to 12000'. Run and set brid~e g-an eline at +/-11950' 6. MU 7-5/8" window section milling assembly and RIH wi 4"9Pto top of bridge plug. Displace well to milling fluid. - 7. Spot a balanced 18.0 ppg mud pill from 11 ,950' »::·11,750'. 8. Section mill 50' window from 11,750' to 11,800'. POOH. 9. MU cementing mule-shoe and TIH to 11,900'. Circulate and condition. 10. Mix and pump cement kickoff plug. POOH. /" 11. MU 6-3/4" PDC drilling assembly including MWD/GR. RIH to top of cement. Clean out cement to kick-off point.,/ ~- 12. Kick-off and drill the 6-3/4" hole section as per directional plan to TD at +/-13,8~D (10,379' TVD). Trip .r' for triple combo LWD prior to the Kekiktuk. Condition hole for running liner, spot liner running pill, and POOH. ~~ 13. Run and cement a 4-1/2", 12.6 Ib/ft 13 Cr-80 production liner. Release from liner and set liner top packer. Test wellbore to 2000 psi to verify liner top packer i~et. Displace well to seawater. 14. Run 4-1/2", 12.6 Ib/ft 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie-back sleeve. RU slickline and make drift run thru liner hanger to verify proper spaceout. ~ 15. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect to 2000' MD and secure the welV' 18. Rig down and move off. Post-RiQ Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. Install gas lift valves. 2. RU e-line. Perforate -50' of Kekiktuk interval with 2-7/8" guns. Version 1.0 5 of 20 09 Dec 2002 ') ) Endicott 4-10AlL-28 Well Program Job 1: MIRU Hazards and Contingencies ~' ~ Three wells, 4-06A (producer), 4-08 (water injector) and 4-14 (shut in injector) will require shut-in before the 4-10A rig move. The 4-10A well is located -10' from 4-08 and 20' from 4-06A and 4-14. These wells will need to be shut-in at both the SSV and the SSSV, and the master, swab, and wing valves. All /' surface flowlines and gas lift lines will be de-pressured to header pressure. Gas lifted wells will have the inner annulus fluid packed. These offset wells will need to be secured during both rig moves and ND/NU BOP. Review the "Endicott Operations Simultaneous Operating Guidelines". Discuss the move at a pre- job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ SOl is designated as an H2S site. Follow Standard Operating Procedures for H2S at all times. Recent H2S data from the pad is as follows: WeIl4-10/M-28 Last H2S reading: 20 PPM (6/19/2002) Adjacent producers~t rf ce: 4-06A Max: 50 m (5/25/99), Last: 275 ppm (10/24/02) 4-08 Unk - ... - H2S readings not taken on water injectors 4-14 Unknown - H2S readings not taken on water injectors The maximum recorded level of H2S on the pad was 2000+ ppm from 3-43 on June 19, 1999. >- Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ~ Note: A new 4" chrome tree will be installed on this well. Load the new tree into the subbase prior to moving on the well. Job 2: De-complete Well Hazards and Contingencies ~ The existing perforations should be isolated by the pre-rig cement squeeze. The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static prior to pulling the completion. ",.- Seawater could be underbalanced to the Kekiktuk reservoir pressures. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC New Standard Slim Hole and has a tubing hanger with 4 1/2" NSCT landing thread. Utilize a 4" type 'H' BPV. Verify the hanger type and connection. Be prepared with necessary equipment to remove. ~"~'~'~~:>:''»»~»1~'~'''_~''~<~oI'''''r.>;._.,~,:,~,~,_:...~,.«-,>",»>>>,:'''~:~~":"~~~'»':-'_~''':'~''''1o:~O:O»1~~Y''''':':''''':«<~'.»~~~''':>I'-.:''~<o:I'o~;~",~:"~'':~~Y',~:I:,·<...»~~~·.,,,,;:,:~,...,~,,~»:.~,:,,,~:->·~,,~;·''fM'~''''':M':~~'~_~~~~'~"~:'»"~~"-':"'»>';>''''''!o'<'''~'''':I-I:'''''~',"'~)~~~'~'~'''~;':'~'~ Job 4: Section Mill Hazards and Contingencies ~ Ensure that the Baker section mill is dressed with the older style 3-arm cutters. ~ Ensure that the milled cuttings are being cleaned from the hole. Adjust mud and milling parameters as required to provide for good hole cleaning. ? The 9.7 Ib/gal high viscosity milling fluid is expected to have a clean hole ECD of 12.5 Ib/gal at 330 gpm. ~ Once section milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ""11I01"" .~.-.~ '_"' ,..: III ,._. -'I >!~·'_·_·__""""'..__.I_! I ,,_'.... Version 1.0 6 of 20 09 Dec 2002 ') ) Endicott 4-10AlL-28 Well Program Job 7: Drill 6 3/4" Production Hole Hazards and Contingencies ) The well will kick off in the lower Seabee with a 9.7 Ib/gal mud. The mud weight will be increased to 10.3 Ib/gal prior to drilling the HRl. The 10.3 mud weight requirement for the HRl should result in being overbalanced to all of the Kekiktuk reservoirs. Follow all shale drilling practices to minimize potential problems. ) The 4-10A well path will drill full sections of the Tuffs and HRl shales, and both formations have been troublesome in the Endicott area. The Tuffs is typically slow and erratic drilling, which can wipe out a PDC bit if proper drilling parameters are not maintained. The HRl on the other hand has shown severe hole instability problems if insufficient mud weight is used. Follow all (1) shale drilling practices, (2)ECD management to limit high ECD's, and (3) maintain proper mud weights and shale stabilizers in the drilling fluid. ) The P-3 coal sections should be encountered at the top of the Kekiktuk interval in this well. These coals have caused packoff and stuck pipe problems in the past. Follow good coal drilling practices. ../ ) Differential sticking is the largest operational risk in this well. Differential sticking will be a problem if the drill string or liner is left stationary for any period of time across the high permeability Kekiktuk Sands. The GEM enhanced LSND drilling mud must be kept in excellent shape when drilling the Kekiktuk to provide good filter cake properties. The Kekiktuk K2A reservoir pressure is expected to be 4300 psi (8.2 ppg EMW) at the 4-10A bottom hole location. The 10.3 Ib/gal mud required for HRZ stability will be 2 Ib/gal over balanced to the Kekiktuk. This 1200 psi pressure differential creates a severe differential sticking risk. ) No major fault crossings are planned in the drilling of this well. The well path will cross over the major Midfield Fault but this fault does not extend upwards into the wellbore path. The directional plan will need to followed closely in the target interval to prevent hitting the smaller faults to the south and north of the target. ) The Kick TOI~~e for the 6-3/4" open hole section at the KOP, based on the 9.5 Ib/gal expected pore pressure iGnfin.i ' with an FIT of 11.5 Ib/gal EMW. Prior to penetrating the reservoir, hold a Pre- Reservoir ..ety Meeting to raise awareness and communicate individual well control responsibi lies to all members of rig team. ) Drilling Close Approach: All wells pass BP Close Approach guidelines. The nearest close approach well is the P&A'd 3-09/L-28 well which is 243' away center to center at the planned depth of 13155' md and passes under Minor Risk rules. _______«<.:o)__~<_»~_*_~:«+»:_~.__«<'»>:>:_'*_~~~<_:««o_~~__«<__.;.¡_:« ~:~_~_(o)~__.:.c.¡,¡,_(.__~:«<O:':O_.~__««.;.¡_...¡.:«<'>'«_(o1o,~_~~__ Job 9: Install 4Y2" Production Liner Hazards and Contingencies ) Long shale intervals and thick coal intervals will be exposed while running the liner. Rotation of the liner may be necessary if downward progress is not possible due to sloughing. To minimize ECD spikes and associated shale stability problems, bring pumps on slow and control downward surges with pipe. ) Differential sticking of the liner across all of the thick high perm Kekiktuk reservoirs is a very serious concern. There will be a 1000-1200 psi differential pressure across the Kekiktuk reservoirs. It is critical to minimize the time the pipe is left stationary while running, circulating, and cementing the liner. );- Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. / ... _'1'\"'1_-....."'__-,-..--- .. .___......; ~.. _"'. ..._........."'.........___......... II. n Version 1.0 7 of 20 09 Dec 2002 ) ') Endicott 4-10AlL-28 Well Program Job 12: Run Completion Hazards and Contingencies ) Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. ~~~~~~~~~:::O:::ffl~~~~~~~~~~~~~~:~~~~~~~<I.'fo~~~«~:~~~~~~,m~~~~¡~~~ffl<m~~~~~~~~~i:~::::~~~~~...'?I~wm~~::::::~~;"'::M~~~~:m'~'>i:I:~~. Job 13: ND/NU/Release RiQ Hazards and Contingencies ) Endicott wells are on 10' centers with the wellhouses are installed. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Offset wells under the substructure that have been returned to operation will need to be secured as per the Endicott Simops requirements prior to ND BOP and rig move. Version 1.0 8 of 20 09 Dec 2002 ö COMPANY IJI·I AILS UP ,\m.,X.1 ("akuutiofl M~d).)(1: Minimum CurV~IIII"I: Error S}'s.t....n: ,sews A Sc-an Mdhod: fra\' Cylia.L.-r North Enor Surf.aco!: El1ipt-.:31 - Casing Waminp: Mc:thod: Rub n~~1 All TVD depths are ssTVD plus 55.8'for RKBE. ,J- ~- ·'l r~ 120< 0 ~ ~___ \_->~d Die : 12145.27' MD, 8975.47' TVD ",,- ',,- , ~ .......,...., '''---..... '''-,....,,- Start Dir 2/100': 12709.4lJ<-MD,9431.15TVD /' ~ 8700 9000 ----t L__ I I --- i ---¡-- I - - -- ___ ----L I 9300 ì c 2 o ~ ~ ö fj '1:: ;; 2 f-o ~-j-~ I 9600 , --+ I l ~-+ 9900 ¡ __-Í- 10200 Start Dir4!IOO': 11758' MD, 8694.47'TVD Top Tu T~ ----------~- _c_ i I -- - ---- --- T-- I ¡ i _._--~~ ~ I ------- - -¡ I ¡ . REFERENCE INFORMATION SURVEY PROGRoV-I Plan: 4-10"'1.-28 "p07 (4-101M-28tJ'lan 4-IOAlL-28) Co-ordinak': IN'E) Ref.ereoce: Wdl Cffitre: 4-1().M-28. True North Vati!,.'31 (TVD) Refcrt.---nœ: 13: 10 6-27/1994 00:00 55_80 Section (VS) Refer=<: Slot - 10 (O.OON.O.OOE) Measured Depth Rel<reoc<: 13: 10 6'27/1994 00:00 55.80 Cakulatioo Methxi.: Minimwn CUJ\"atur~ [)"pth Fm D<pth To S",,~)",P¡'n 11758.00 13848.00 PIanœd: 4-HhL-28 \\p07 VI6 Tool Üeated By: Ken Allen Date: 11120'2002 MWD Checked: Date: Re'áewed: Date: CASING DETArLS WElL DETAILS No. TVD MD Size Narœ -'N'-S -FJ-W Northing Easting Latituœ longitude Slo' 4-1fi1l!-28 1415.88 -205453 5970799.97 270221.25 7tì'19"18.631N 147'51"47.456W 10 TARGET DETAILS Name lVD ~NJ-S ~Ef-W Nonhing Eaõting Shape L-283 K2B 9959.80 7814.03 -1666.74 5978661.05 26879458 Polygon L-283 1K2A 10106.80 790 1.89 -1704.Q.I 5978750.01 268759.99 Cin:1e (Radiu5: 125) L-28KI 10247.80 7986.19 -1739.82 597883536 268726.81 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 11758.00 50.60 349.78 8694.47 6899.72 -1357.76 0.00 0.00 7030.33 2 12145.27 36.13 341.64 8975.47 7156.91 -1420.66 4.00 -161.80 7295.03 3 12709.44 36.13 341.64 9431.15 7472.62 -1525.42 0.00 0.00 7625.88 4 12847.96 36.48 337.00 9542.80 7549.30 -1554.37 2.00 -84.66 7706.98 5 13311.68 33.00 337.00 9923.80 7792.50 -1657.60 0.75 180.00 7966.67 6 13529.88 33.00 337.00 10106.80 7901.89 -1704.04 0.00 0.00 8083.48 L-28a TK2A 7 13698.00 33.00 337.00 10247.80 7986.18 -1739.82 0.00 0.00 8173.48 8 13848.00 33.00 337.00 10373.60 8061.38 -1771.74 0.00 0.00 8253.78 ~ Name 10373.59 13847.99 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 2 3 4 5 6 7 90 I [:SO 9542.80 9805.80 9873.80 9959.80 10106.80 10247.80 12190.25 12847.96 13170.12 13251.90 13354.60 13529.88 13698.00 Top Tuffs THRZ BHRZlTKJA P3 TK2B TK2A TKl ~rt D"." 1 00' , 12847.9& 'ffk~::" 1~1 "~ 4-10/M-28 (4-10/M-28't, '-' o /~<2 Vo /O.s; ~O 9000 ~OO 6000 4' '$00 ~ ..YOOO /' /$00 End Die : 13311.68' MD, 9923.8' TVD ¡ ¡TKl..!. i I I i i ¡ ¡ ~41/2" T ulJll [Ie> h . 13~8' Iv 1). 10 \7] .6' T\ D 4-lOa/L-28 wp07 L-28 KI 7500 7800 Vertical Section at 347.60° [300ft/in] 8100 I I I 8400 .../~ !S' ""O..n rfjjS v 7200 Plan: 4-IOalL-28 wp07 (4-IOIM-28'Plan 4-IOAIL-28 Created By: Ken Allen SURVEY PROGRAM D<plb Fm IRptb To SrnwyPlan Tool llï58.00 1384S.00 PJamOO: 4-IOaL-28 "pOi Vl6 MWD REFERENCE INFORMATION Wdl Caltre: 4-1o.M·28. fro¿ Nort 1J , 10 6'2ï!1994 00;00 55.80 SloI - 10 (O.OON,OJlOEI 13 : 10 6·27/1994 00:00 55.81 Minimwn Curvature Cù-Clrdinak;' (N'E) R¿f¿r-.;n.:~: Vertical (n'D¡ R~f~erk.~: &''1ion (V$) Referenc~: Me<b-ur<.'d I).:plh Ref.""",e: Cakularion Melbod: bp o Date: NaIr~ --N'-S -E/-W Noohing E.asIing latituœ Longitude Slot 4-HH 1415.88 -205453 5970799.97 27022125 70"19'18,631N 147'51'47,456W 10 TARGET DETAILS Name n'D "N'-S "E/-W Northing Easting Shop" L-28a K28 9959.80 7814,03 ·1666.74 5978661.05 26819458 Pol)"gon L-28o TK2A 10106.80 7901.89 -1704JJ4 5978750,01 268159.99 Cilde (RBdius: 1 L-28KI 10247.80 7986,19 -1739,82 597883536 268126.81 Polygoo SECTION DETAILS See MD Ine Azi TVD +N/-S +PJ-W DLeg TFaee VSee Target 1 11758.00 50.60 349.78 8694.47 6899.72 -1357.76 0.00 0.00 7030.33 2 12145.27 36.13 341.64 8975.47 7156.91 -1420.66 4.00 -161.80 7295.03 3 12709.44 36.13 341.64 9431.15 7472.62 -1525.42 0.00 0.00 7625.88 4 12847.96 36.48 337.00 9542.80 7549.30 -1554.37 2.00 -84.66 7706.98 5 13311.68 33.00 337.00 9923.80 7792.50 -1657.60 0.75 180.00 7966.67 6 13529.88 33.00 337.00 10 106.80 7901.89 -1704.04 0.00 0.00 8083.48 L-28a TK2A 7 13698.00 33.00 337.00 10247.80 7986.18 -1739.82 0.00 0.00 8173.48 8 13848.00 33.00 337.00 10373.60 8061.38 -1771.74 0.00 0.00 8253.78 ~ Checked: Reviewed: WEll DETAILS FORMATION TOP DETAILS TVDPath MDPath Fonnation Top Tuffs THRZ BHRZffK3A P3 TK2B TK2A TK1 No. 1 2 3 4 5 6 7 CASING DETAILS No. TVD MD Name Size 10373.59 13847.99 4 1/2' 4_500 (4-10/M-28 10373.6' TVD 13311.68' MD, 9923.8' TVD !'- 4-10/M-28 \ Î \ : ~ 3848' MD, Dept C.lkublklO M.:-II¡¡1I!: MmllnulU Cmvarur\:' Ern'( S}'st,-"m: rSCWSA Scan Mr:tho..l: 1 r.1\' (\'III»:r North I:nur Surb'~: I'Jli("tjcål .- ('asing W3mio¡æ Mct1x-..t: Ruko.s Ih~...t 8200- 8000 7800 C__' /~ /~ ~ <S;~ ~ '.5òo ~~ ~O /~ 12190.25 12847.96 13170.12 13251.90 13354.60 13529.88 13698.00 9011.80 9542.80 9805.80 9873.80 9959.80 10106.80 10247.80 145.27' MD, 8975.47' TVD 9431.15'TVD .2 \ \- \ ,.1\" 0.751100' , '2847.96 MD. 9542.8TVD 950X \ \_ Sta\Di: 2'100': 12709.44' \\ \ \ \\ 9(OC\ \ End Di '\\ , MD, 7600 7400 7200 ~ è2 o ~ +" f o ~ ~ o C/J 8694.47'TVD I 1000 MD, 1758' I I I -1200 I I S~ Ü;T 1 00' I RKBE. ./ II ! ! -1600 -1400 West(-)Æast(+) [200ft/in] == All TVD depths are =- ssTVD plus 55.8'for --i+tt-tt, I ! -2000 800 7000 ) ') BP KW A Planning Report MAP Company: Field: Site: Well: Wellpath: Date: 11/20/2002 Time: .. ·10:45:04 ... ... . Page: Co~rdinåtè(NElR.~(ere..ce: vvell:4-1Q/M-28, True North Yerti~al (f~)R~(e....,nee: 13:.106/27/199400:0055.8 Seetion(VS) R.efe..~ne~: Well (O.OON,O.OOE,34 7 .60Azi) Survey Calculatiøn Method: Minimum Curvature Db: Oracle BP Amoco Endicott End SDI 4-10/M-28 Plan 4-1.0AlL·28 Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: End SDI TR-11-17 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 14.50 ft 5969322.46 ft 272231.79 ft Well: 4-10/M-28 4-10/M-28 Well Position: +N/-S 1415.88 ft Northing: 5970799.97 ft +E/-W -2054.53 ft Easting: 270221.25 ft Position Uncertainty: 0.00 ft Wellpath: Plan 4-10AlL-28 Current Datum: Magnetic Data: Field Strength: Vertical Section: 13 : 10 6/27/1994 00:00 6/25/2002 57576 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 55.80 ft Plan: 4-10a/L-28 wp07 Principal: Yes Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: Latitude: Longitude: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Date Composed: Version: Tied-to: Alaska, Zone 3 Well Centre BGGM2002 70 19 4.709 N 147 50 47.497 W True -1.74 deg 10 70 19 18.631 N 147 51 47.456 W 4-10/M-28 11758.00 ft Mean Sea Level 26.65 deg 80.93 deg Direction deg 347.60 11/20/2002 16 From: Definitive Path Casing Points MD TVD Diameter Hole Size Name ft ft in in 13847.99 10373.59 4.500 6.750 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 12190.25 9011.80 Top Tuffs 0.00 0.00 12847.96 9542.80 THRZ 0.00 0.00 13170.12 9805.80 BHRZ/TK3A 0.00 0.00 13251.90 9873.80 P3 0.00 0.00 13354.60 9959.80 TK2B 0.00 0.00 13529.88 10106.80 TK2A 0.00 0.00 13698.00 10247.80 TK1 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft L-28a K2B 9959.80 7814.03 -1666.74 5978661.05 268794.58 70 20 35.480 N 147 52 36.149 W -Polygon 1 9959.80 7888.53 -1813.69 5978740.01 268650.00 70 20 36.212 N 147 52 40.443 W -Polygon 2 9959.80 7664.75 -1606.73 5978510.00 268850.00 70 20 34.012 N 147 52 34.395 W -Polygon 3 9959.80 7830.10 -1434.71 5978670.00 269026.99 70 20 35.638 N 147 52 29.371 W -Polygon 4 9959.80 8064.12 -1633.97 5978910.00 268835.00 70 20 37.939 N 147 52 35.194 W -Plan hit target L-28a TK2A 10106.80 7901.89 -1704.04 5978750.01 268759.99 70 20 36.344 N 147 52 37.240 W -Circle (Radius: 125) -Plan hit target L-28 K1 10247.80 7986.19 -1739.82 5978835.36 268726.81 70 20 37.173 N 147 52 38.286 W ) BP ) KW A Planning Report MAP Company: BP Amoco Date: ..··.·11/20/2002 Time: .·1Ö:45:04 .... . ... .. ....Page: 2 Field: Endi.cott C()"o~dinåte(N;E)Re~~"~nce: Well: 4~1O/N1-2a, True North Site: End SDI Vertical (TVD) Reference: 13:106/27/199400:0055.8 Well: 4~ 1 0/M-28 Section (VS) Reference: Well (0.00N,0.00E,347.60Azi) Wellpath: Plan4-10NG-28 Survey Calculation Method: Minimum Curvature Db: Oracle Targets lV,hap Map ~--"-Latitude~~> <-:--Longitude---> Name TVD fE/-W N9rthio,g Easting Peg .1\1in ... ·&ec. DègMinSec ft ft . ft.···· ft -Polygon 1 10247.80 -1538.50 5978730.01 268925.00 70 20 36.197 N 147 52 32.403 W -Polygon 2 10247.80 -1732.61 5979030.01 268739.99 70 20 39.090 N 147 52 38.076 W -Polygon 3 10247.80 -1987.60 5978870.01 268479.99 70 20 37.438 N 147 52 45.525 W -Polygon 4 10247.80 -1783.19 5978560.00 268674.99 70 20 34.450 N 147 52 39.551 W -Plan hit target Plan Section Information MD Incl Aiim TVD -t-N/:'S +E/-W ÐJ.$. ..... .··.JJuild .... .·101-11 IFO l'arg~t ft deg deg ft .. ft· ft deg/10Qftdeg/1 OOft. .·døg/1OOft ~eg 11758.00 50.60 349.78 8694.47 6899.72 -1357.76 0.00 0.00 0.00 0.00 12145.27 36.13 341.64 8975.47 7156.91 -1420.66 4.00 -3.74 -2.10 -161.80 12709.44 36.13 341.64 9431. 15 7472.62 -1525.42 0.00 0.00 0.00 0.00 12847.96 36.48 337.00 9542.80 7549.30 -1554.37 2.00 0.25 -3.35 -84.66 13311.68 33.00 337.00 9923.80 7792.50 -1657.60 0.75 -0.75 0.00 180.00 13529.88 33.00 337.00 10106.80 7901.89 -1704.04 0.00 0.00 0.00 0.00 L-28a TK2A 13698.00 33.00 337.00 10247.80 7986.18 -1739.82 0.00 0.00 0.00 0.00 13848.00 33.00 337.00 10373.60 8061.38 -1771.74 0.00 0.00 0.00 0.00 Survey MD Ind Áiim TVD SysTVD . ·lVfåpN l\t~pç VS DLS .TFQ Tool/Comment ft deg deg ft ft ft ft ft deg/1 OOft·· deg 11758.00 50.60 349.78 8694.47 8638.67 5977737.74 269075.42 7030.33 0.00 0.00 MWD 11800.00 49.01 349.08 8721.57 8665.77 5977769.44 269070.50 7062.40 4.00 198.20 MWD 11900.00 45.23 347.28 8789.61 8733.81 5977841.58 269057.74 7135.66 4.00 198.65 MWD 12000.00 41.49 345.23 8862.30 8806.50 5977908.73 269043.52 7204.28 4.00 199.88 MWD 12100.00 37.79 342.85 8939.30 8883.50 5977970.56 269027.92 7267.93 4.00 201.37 MWD 12145.27 36.13 341 .64 8975.47 8919.67 5977996.72 269020.43 7295.03 4.00 203.20 MWD 12190.25 36.13 341 .64 9011.80 8956.00 5978022.14 269012.85 7321.41 0.00 180.00 Top Tuffs 12200.00 36.13 341 .64 9019.68 8963.88 5978027.65 269011.21 7327.12 0.00 180.00 MWD 12300.00 36.13 341.64 9100.45 9044.65 5978084.15 268994.36 7385.77 0.00 180.00 MWD 12400.00 36.13 341.64 9181.21 9125.41 5978140.65 268977.51 7444.41 0.00 180.00 MWD 12500.00 36.13 341.64 9261.98 9206.18 5978197.15 268960.67 7503.05 0.00 180.00 MWD 12600.00 36.13 341.64 9342.75 9286.95 5978253.65 268943.82 7561.69 0.00 180.00 MWD 12709.44 36.13 341.64 9431.15 9375.35 5978315.49 268925.38 7625.88 0.00 180.00 MWD 12800.00 36.34 338.60 9504.20 9448.40 5978366.34 268908.73 7678.93 2.00 275.34 MWD 12847.96 36.48 337.00 9542.80 9487.00 5978393.01 268898.79 7706.98 2.00 277.80 THRZ 12900.00 36.09 337.00 9584.75 9528.95 5978421.71 268887.63 7737.25 0.75 180.00 MWD 13000.00 35.34 337.00 9665.94 9610.14 5978476.11 268866.48 7794.62 0.75 180.00 MWD 13100.00 34.59 337.00 9747.89 9692.09 5978529.52 268845.72 7850.95 0.75 180.00 MWD 13170.12 34.06 337.00 9805.80 9750.00 5978566.37 268831.39 7889.81 0.75 180.00 BHRZlTK3A 13200.00 33.84 337.00 9830.59 9774.79 5978581.92 268825.34 7906.21 0.75 180.00 MWD 13251.90 33.45 337.00 9873.80 9818.00 5978608.73 268814.92 7934.48 0.75 180.00 P3 13300.00 33.09 337.00 9914.01 9858.21 5978633.31 268805.36 7960.41 0.75 180.00 MWD 13311.68 33.00 337.00 9923.80 9868.00 5978639.25 268803.06 7966.67 0.75 180.00 MWD 13354.60 33.00 337.00 9959.80 9904.00 5978661.04 268794.59 7989.65 0.00 0.00 L-28a K28 13400.00 33.00 337.00 9997.88 9942.08 5978684.08 268785.63 8013.95 0.00 0.00 MWD 13500.00 33.00 337.00 10081.74 10025.94 5978734.84 268765.89 8067.48 0.00 0.00 MWD 13529.88 33.00 337.00 10106.80 10051.00 5978750.01 268759.99 8083.48 0.00 0.00 L-28a TK2A 13600.00 33.00 337.00 10165.61 10109.81 5978785.60 268746.16 8121.02 0.00 0.00 MWD 13698.00 33.00 337.00 10247.80 10192.00 5978835.35 268726.82 8173.48 0.00 0.00 L-28 K1 13700.00 33.00 337.00 10249.48 10193.68 5978836.36 268726.42 8174.55 0.00 0.00 MWD 13800.00 33.00 337.00 10333.34 10277 .54 5978887.12 268706.69 8228.09 0.00 0.00 MWD 13848.00 33.00 337.00 10373.60 10317.80 5978911.49 268697.21 8253.78 0.00 0.00 MWD RT. ELEV = 55.85' BF. ELEV = 14.50' MAX DEV = 54 ' @ 13,700' ') 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 3,993' I 4-1/2" 12.6#/ft, 13 CR 80 VAM ACE TUBING, GAS LIFT MANDRELS (CAMCO) 'KBMG' w.1" 'RK' LATCH NO. MU-~K~ I VU-SS #7 #6 #5 #4 #3 #2 #1 SECTION MILL 50' WINDOW KICK OFF CMT PLUG AT 11750' 7-5/8" BRIDGE PLUG AT +/-11950' 4-1/2" TUBING CUT AT +/-12,200' TREE: 4-1/2" 5000 psi Chrome CIW WELLHEAD: 1'")' 5000 psi FMC NS .-4 . HES 'HXO' SVLN .-- (3.813" MIN. ID) . W/SSSV MIN I.D. is 2.0" I 1518" _ 4-1/2"X1" KBMG GAS LIFT MANDRELS . I ~~ 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" BAKER S-3 PACKER 1+/-11580' J ~~ 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 4-1/2" MULESHOE I 7-5/8"x5-1/2" BAKER FLEXLOCK LINER HANGER + LTP AT 11600' 6-3/4" HOLE X 4-1/2" LINER 13 CR HYDRIL 563J'tJER' TD +/- 138~m, 1'037/TVD X I ! 4-1/2" 'X' NIPPLE (HES) I 13,527' I , (3.813" MIN. ID) I ---r::=7_5IS" Baker SABL-3 Pkr I 13,589' 4-1/2" 'X' NIPPLE I I (HES) (3.813" ID) 13,655' - 4-1/2" 'XN' NIPPLE I 13,713' I (HES) (3.725" ID) PERFORATION SUMMARY --- 4-1/2" WLEG REF: LOG: SBT-GR (7/25/94) <XXX X) I 13,723' I CO. SIZE SPF INTERVAL <XXX X) I I WLEG ELMD 13,732' <XXX X SWS 27/8 4 13898-13903 Sqzd <XXX X SWS 27/8 4 14134-14139 Sqzd <XXX X SWS 27/8 6 14190-14220 Sqzd <XXX X ATLAS 3-3/8" 4 14116-14136 SQZD <XXX X 3-3/8" 4 14156-14186 SQZD <XXX X SWS 3-3/8" 6 14186-14206 SQZD <~~ TTL LOCATING FINGER. 4-1/2" Long X 1" Wide . .. .. .. ., ... TOP OF FILL = 14,255' PBTD I 14,323' I~~ 3/22/99 7-5/8", 29.7#/ft, ~ NT95HS, NSCC I 14,409' I~ DATE REV. BY COMMENTS ENDICOTT WELL 4-10A/L-28 7/27/94 MDM PERFORATIONS API NO: 50-029-22464-1 10/12/97 RAC ADD-PERFS COMPLETION DIAGRAM 3/21/99 U~ SULll-'ost Sqz I-'erts 11/14/02 FJ Proposed Completion BP EXPLORATION, INC. I II. 4-1/2" 'X' NIPPLE (HES) I , ~ (3.813" MIN. ID) ~7-5/8" Baker SABL-3 Pkr 1 r 4-1/2" 'X' NIPPLE (HES) (3.813" ID) I I - 4-1/2" 'XN' NIPPLE 1 ~ (HES) (3.725" ID) -- 4-1/2" WLEG <XXXX) I <XXX X) <XXXXI <XXXX <XXXX <XXXX <XXXX <XXXX_ < -r ~þ< fill ..........~ 1--.. ~ ,-. RT. ELEV = 55.85' BF. ELEV = 14.50' MAX DEV = 54[]' @ 13,700' ) 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 3,993' I þÞA 4-1/2" 12.6#/ft, 13 CR 80VAM ACE TUBING, - GAS LIFT MANDRELS (CAMCO) 'KBMG' w. 1"'RK' LATCH NO. MU-jKj I VU-SS #7 #6 #5 #4 #3 #2 #1 x- X: SECTION MILL 50' WINDOW X: KICK OFF CMT PLUG AT 11750' X : X 7-5/8" BRIDGE PLUG AT +/-11950' 4-1/2" TUBING CUT AT +/-12,200' PERFORATION SUMMARY REF: LOG: SBT-GR (7/25/94) CO. SIZE SPF INTERVAL SWS 2 7/8 4 SWS 2 7/8 4 SWS 2 7/8 6 ATLAS 3-3/8" 4 3-3/8" 4 SWS 3-3/8" 6 13898-13903 Sqzd 14134-14139 Sqzd 14190-14220 Sqzd 14116-14136 SQZD 14156-14186 SQZD 14186-14206 SQZD PBTD 7-5/8", 29.7#/ft, NT95HS, NSCC I 14,323' I 14,409' TREE: 4-1/2" 5000 psi Chrome CIW WELLHEAD: 13 .") 5000 psi FMC NS . HES 'HXO' SVLN .......-. (3.813" MIN. ID) ~ W/SSSV MIN I.D. is 2.0" I 1518" - 4-1/2"X1" KBMG GAS LIFT MANDRELS I I ~~ 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" BAKER S-3 PACKER 1+/-11580' ~f l 4-1/2" 'X' NIPPLE (HES) (3.813" 10) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 4-1/2" MULESHOE I 7-5/8"x5-1/2" BAKER FLEXLOCK LINER HANGER + L TP AT 11600' 6-3/4" HOLE X 4-1/2" LINER 13 CR HYDRIL 563 LINER TO +/-13853'MD, 10370'TVD WLEG ELMD 13,527' I 13,589' , I I I I 13,655' 13,713' 13,723' I 13,732' TTL LOCATING FINGER. 4-1/2" Long X 1" Wide TOP OF FILL = 14,255' 3/22/99 ~ DATE REV. BY COMMENTS ENDICOTT WELL 4-10AlL-28 7/27/94 MDM PERFORATIONS API NO: 50-029-22464-1 10/12/97 RAC ADD-PERFS COMPLETION DIAGRAM 3/;¿ 1/9H Uj SULll-'ost sqz I-'erts 11/14/02 FJ Proposed Completion BP EXPLORATION, INC. II- 0 5 .... g b .... II- .: 0... . 2 0 ~ B g 5.: 0 ¡. 2 '( B g b II- NOV. 18, 2002 *****$100.00**** N~~:~:~f.:~~~S::~~~~·~~·~:.~::\~;i.~~:;~{:}~2~ ..... .~... .......... ...... ...... ...... .....' ~~:.~.}.: ,..' .' ....::~::::..~ :'~.' :~~""~";- ¿ :~>.:::..:: ::;;::·:·:·::i::.. :.~:~:.:~.::~::\~;~;:.¡:~:; ~~~~:::~~~.:~:~ ~~~':;¿L;~j ALASKA OIL & GAS CONSERVATION COMMISSION 333 W.7th AVE, STE. 100 ANCHORAGE,AK 99501 TO THE ORDER OF AMOUNT DATE 8 P F:'.··.J........l..J.'.·.· JI1III) /flUI·,.j'} ..'''.'':11 r.!h Iii_. -., t~ - - !:Jut 1uI' t 1~ ". . .. . .. mµl l!tll' .HII". 4t."n· "'n ~, PAY CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4'12 NATIONAL CITY BANK Ashland, Ohio BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 No. P 054964 TOTAL .... THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. RECE 1\'EO OEC '\ '\ 2002 ~ ou.& Gas Gens. liomffi\SS\O\ Anchorag~ ¿ ¡ - f I'JA '\L_-- JP, 'ì ,\._- \ ,.-J ---- PERMIT TO DRILL FEE 11/18/02 INV# CK111~'~E H NET VENDOR DISCOUNT GROSS DESCRIPTION INVOICE I CREDIT MEMO DATE CHECK NO. P054964 DATE 11/18/02 P054964 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ,If fJ Y WELL NAME 0/ Vf ¥ -¡Ø A)...z<jPROGRAM: Exp _ Dev ~ Redrll X- Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL:z.. z..o,.l C)~ INIT CLASS /)p~JJ / -~ 1./ GEOL AREA <;-7 è UNIT# /0 c..¡- ç- ~ ON/OFF SHORE o/ù ADMINISTRATION 1. Permit fee attached. ............. ..... ~ N 2. Lease number appropriate. . . . . . . . . .. ..... Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ,_ J ) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ &:IJII...o,<- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Y.Þ( IU J A.. (Service Well Only) 14. All wells wlin Y4 mile area of review identified. ÝN ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥--N- 16. Surface casing protects all known USDWs. . . . . . . . ~ I\.Ì/A 17. CMT vol adequate to circulate on conductor & surf csg. . . ~ 18. CMT vol adequate to tie-in long string to surf csg. . . . . . .¥-+J- t 19. CMT will cover all known productive horizons. . . .. . . . .. . Ñ2 N Ad,( ~ £.t ..Á· ( oV:--e-e('~ ç . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . ~N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . &.. N Ù,Q;t1 tV:-- t5, 22. If a re-drill, has a 10-403 for abandonment been approved. . . è?LN- J ( l ð 2./ () L . 23. Adequate wellbore separation proposed.. . .. . . . . . . . . . N 24. If diverter required, does It meet regulations. .' . . . . . . . Ai/A:- . 25, Drilling fluid program schematic & equip list adequate. . . . . N ¡UQ./<?- /11 j).J' j 0, ~ P P1 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 27. BOPE press rating appropriate; testto L/5"OD psig. N rVl~ f) 31 &.5 pS.l. 28'. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . 'Z'JN , I 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . .~N lo r p""""'" tt"L ç . 31. Mechanical condition of wells within AOR verified. . . . . . . .¥-N N/Æ-, 32. Permit can be issued wlo hydrogen sulfide measures. . . .. } 33. Data presented on potential overpressure zones. . . . . . . . Y 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y.· N IV ..AI 35. Seabed condition survey (if off-shore). . ; . . .; ...... 36. Contact namelphone for weekly progress reports. ...... Y . N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE APPR DATE j¡JGA- I I ielo 3 (Service Well Only) GEOLOGY APPR DATE ,ffr: 12./;102- (Exploratory Only) Rev: 10/15/02 UIC ENGINEER TEM JDH JBR SFD_ WGA /' MJW G:\geology\permits\checklist.doc COMMISSIONER: COT DTS 0/07(03 MLB ó,/c:y:.,3 { ( Commentsllnstructions: ) ) Well History File APPENDIX Inforrnation of detailed nature that is not particularly germane to the Well Pennitling Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) ~a-~-¡8 l' cab?' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 06 07:18:34 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number... ...01 Previous Reel Name.... ...UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Tape Header Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF' Comment Record TAPE HEADER Endicott MWD/MADLOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 4-10A/L-28 500292246401 BP Exploration Inc. Sperry-Sun Drilling Services 05-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002259994 D. HAWKINS E. VAUGHN MWD RUN 2 MW0002259994 J. PITCHER E. VAUGHN MWD RUN 3 MW0002259994 J. PITCHER E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002259994 J. 'PITCHER E. VAUGHN MWD RUN 5 MW0002259994 J. PITCHER C. GALLOWAY MWD RUN 6 MW0002259994 J. PITCHER C. GALLOWAY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 6 MW0002259994 J. PITCHER C. GALLOWAY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 llN 17E 2581 816 55.67 16.60 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 11690.0 ') ') 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO CUT THE WINDOW - ONLY RUN 1 SROP DATA ARE PRESENTED. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 5 & 6 COMPRISED DIRECTIONAL; DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND ABI. MWD RUN 6 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD). 4. GAMMA RAY DATA FOR THREE SHALLOWER INTERVALS (FOR TIE-IN PURPOSES) WERE ACQUIRED WHILE RIH FOR RUNS 2 AND 3. THESE DATA ARE MERGED WITH RUN 2 DATA. 5. RESISTIVITY AND POROSITY DATA FOR THE LOWER PART OF THE RUN 5 INTERVAL (13283'MD-13390'MD BIT DEPTHS) WERE ACQUIRED WHILE RIH FOR RUN 6. THE POROSITY DATA ARE MERGED WITH THE RUN 6 DATA. THE RESISTIVITY DATA ARE DISPLAYED AS A SEPARATE MAD PASS PRESENTATION. 6. THE EWR4 TOOL FAILED 66' FROM TD. DURING A SHORT TRIP AFTER REACHING TD, THE TOOL BRIEFLY AND INTERMITTANTLY FUNCTIONED OVER THE INTERVAL OF MISSING DATA. THESE FIELD DATA WERE RECOVERED, PRELIMINARILY CORRELATED AND DEPTH CORRECTED TO THE MWD RUN 6 DATA, AND PROVIDED TO THE CUSTOMER. UPON FURTHER INSPECTION OF THESE DATA, IT WAS DECIDED THAT THERE IS NO UNEQUIVOCAL CORRELATION, SO THESE DATA ARE NOT INCLUDED HERE. 7. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 23 FEBRUARY 2003, PER E-MAIL INSTRUCTIONS FROM D. SCHNORR DATED 30 MAY 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 8. MWD RUNS 1- 6 REPRESENT WELL 4-10A/L-28 WITH API#: 50-029-22464-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13860'MD/10355'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY ( SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . ) ) SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. CURVE MNEMONICS WITH AN 'M' SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.75" BIT SIZE MUD WEIGHT: 10.3 PPG MUD SALINITY: 1200 PPM CHLORIDES FORMATION WATER SALINITY: 16800 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPX RPM FET RPS FCNT NPHI NCNT RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9344.5 11700.0 13116.0 13116.0 13116.0 13116.0 13116.0 13197.0 13198.0 13198.0 13214.0 13214.0 13214.0 STOP DEPTH 13809.0 13867.0 13750.0 13750.0 13750.0 13750.0 13750.0 13771.5 13771.5 13771.5 13788.5 13788.5 13788.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9344.5 9354.0 9356.0 9358.5 9363.5 9370.5 9375.5 10858.5 10876.0 10880.5 10885.0 10892.0 GR 9341.5 9351.0 9354.0 9356.0 9361.5 9367.5 9373.0 10848.5 10866.0 10870.5 10874.5 10881. 5 ~ ) ) 10900.0 10889.5 10904.0 10893.5 10914.5 10903.0 10920.5 10908.5 10926.0 10915.5 10937.0 10926.0 10946.5 10935.5 10949.0 10938.5 10958.5 10948.0 10964.5 10953.0 10968.0 10957.5 10976.5 10965.0 10993.5 10981. 0 10995.0 10982.0 11002.0 10988.5 11012.0 10997.5 11017.0 11002.0 11023.5 11010.5 11031.5 11018.5 11038.0 11024.5 11051.5 11038.5 11753.5 11746.5 11756.0 11749.5 11 763.0 11755.5 11790.0 11784.0 11806.0 11799.0 11809.0 11801.5 11830.0 11823.5 11852.0 11842.0 11862.0 11852.5 11871.5 11860.0 11877.0 11866.0 11879.5 11868.0 11892.5 11882.5 11895.0 11885.5 11921. 0 11910.0 11939.5 11931.0 11959.5 11951.5 11973.0 11965.0 12031.0 12022.0 12037.0 12028.0 12052.5 12043.5 12069.0 12062.0 12077.0 12069.5 12083.5 12075.5 12093.0 12081. 5 12124.0 12114.5 12129.0 12119.0 12146.5 12135.5 12166.5 12155.0 12173.0 12163.0 12190.0 12182.5 12220.5 12215.0 12227.0 12221. 5 12245.5 12238.0 12248.5 12241.0 12264.0 12256.5 12270.0 12261. 5 12275.0 12268.5 12278.5 12271.0 12282.0 12272.5 12290.0 12284.0 12301. 0 12293.0 12308.0 12300.5 12316.5 12308.5 12320.0 12311. 5 12324.5 12316.0 12328.0 12319.5 12334.0 12325.5 12338.0 12330.5 12346.5 12338.0 12354.0 12345.5 12371.5 12365.5 12379.0 12372.5 12410.0 12402.0 12420.5 12413.0 ) ') 12430.0 12435.0 12442.0 12456.0 12460.5 12466.0 12472.5 12478.0 12487.0 12489.5 12493.0 12506.0 12508.0 12513.5 12520.5 12528.0 12533.5 12547.5 12553.0 12557.5 12590.5 12613.5 12636.0 12638.5 12645.5 12652.5 12664.0 12692.0 12705.5 12711.0 12713.5 12738.0 12764.0 12770.0 12792.0 12800.5 12817.5 12831. 0 12849.0 12852.0 12860.5 12871. 5 12882.5 12892.0 12899.0 12909.5 12922.5 12928.5 12932.5 12939.5 12947.0 12958.5 12979.5 12990.5 12995.0 13000.5 13005.0 13012.5 13015.5 13018.5 13020.5 13025.5 13037.0 13048.5 13057.0 13060.0 13072.0 13078.5 13087.5 13094.0 13096.0 13097.5 13101. 0 13113.5 13125.5 13127.5 12422.0 12427.0 12433.5 12448.0 12452.5 12459.5 12468.0 12472.0 12481.0 12483.5 12489.5 12501.5 12504.5 12510.0 12516.0 12525.0 12529.5 12543.5 12549.0 12552.5 12585.5 12608.5 12628.5 12633.0 12638.5 12644.0 12657.0 12685.5 12698.5 12706.0 12709.0 12733.5 12758.0 12764.0 12786.5 12796.0 12810.5 12820.5 12840.0 12842.0 12852.0 12862.0 12878.0 12886.0 12892.5 12903.0 12915.0 12921.0 12924.0 12931. 0 12937.5 12948.5 12970.0 12982.0 12986.5 12991. 5 12996.0 13003.0 13006.0 13008.0 13011.0 13017.0 13028.0 13041. 0 13050.0 13052.0 13065.5 13072.0 13080.5 13087.0 13088.5 13091. 0 13094.0 13107.0 13118.0 13120.5 ) ) ,.' 13136.5 13144.0 13154.5 13163.0 13190.5 13197.0 13202.0 13212.5 13219.5 13227.5 13231.5 13238.5 13253.5 13269.5 13273.0 13276.0 13286.0 13292.5 13300.5 13304.0 13306.5 13331. 0 13350.0 13356.5 13375.5 13406.5 13427.0 13483.5 13489.5 13492.5 13495.5 13501.5 13534.5 13541.0 13547.0 13552.5 13556.0 13562.5 13568.0 13572.0 13588.0 13592.0 13603.0 13605.5 13608.0 13616.0 13620.5 13631.0 13640.5 13646.0 13648.0 13652.0 13655.0 13658.0 13660.5 13666.0 13683.5 13702.0 13707.5 13711. 0 13712.5 13720.5 13722.5 13729.5 13733.0 13738.5 13747.0 13752.0 13758.0 13763.5 13867.0 $ 13134.5 13143.0 13151.5 13158.5 13186.0 13192.5 13197.5 13205.0 13208.5 13218.0 13221.5 13229.0 13245.5 13264.5 13266.5 13268.5 13279.0 13288.5 13295.0 13297.0 13298.5 13325.0 13341. 5 13348.5 13369.0 13400.0 13419.5 13478.5 13484.5 13486.5 13488.0 13494.5 13528.5 13534.0 13540.0 13545.0 13549.5 13555.0 13561. 0 13564.5 13581. 5 13585.0 13596.0 13598.5 13600.0 13607.0 13613.0 13624.0 13632.5 13637.5 13640.0 13644.5 13647.0 13650.0 13653.0 13657.5 13675.0 13694.0 13699.5 13703.0 13704.0 13712.5 13714.5 13721. 0 13725.0 13729.0 13738.0 13743.5 13749.5 13756.5 13860.0 # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11692.5 11783.0 MWD MWD MWD MWD MWD $ # REMARKS: ') ) 2 3 4 5 6 11783.0 12255.0 12537.0 13160.0 13390.0 12255.0 12537.0 13160.0 13390.0 13860.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.... .......... ...Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Nsam 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9344.5 13867 11605.8 9046 9344.5 13867 ROP MWD FT/H 0.12 435.5 42.015 4335 11700 13 867 GR MWD API 9.9 410.52 120.037 4620 9344.5 13809 RPX MWD OHMM 2.1 858 78.9121 1269 13116 13750 RPS MWD OHMM 2.06 1692.39 134.82 1269 13116 13750 RPM MWD OHMM 2.02 1838.71 169.585 1269 13116 13750 RPD MWD OHMM 2.13 1080.03 130.343 1269 13116 13750 FET MWD HOUR 1. 53 53.4101 10.0972 1269 13116 13750 NPHI MWD PU-S 7.23 80.12 21.7947 1148 13198 13771.5 FCNT MWD CNTS 82.5 1679 727.389 1150 13197 13771.5 NCNT MWD CNTS 13396 37212 27890.3 1148 13198 13771.5 RHOB MWD G/CM 1. 25 2.64 2.21185 1150 13214 13788.5 DRHO MWD G/CM -0.148 0.312 0.0699661 1150 13214 13788.5 PEF MWD BARN 1. 74 10.68 3.99726 1150 13214 13788.5 First Reading For Entire File......... .9344.5 Last Reading For Entire File...... ... ..13867 File Trailer Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/06/06 Maximum Physical Record..65535 File Type........ ...... ..LO Next File Name....... ... .STSLIB.002 Physical EOF File Header ) ') Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/06/06 Maximum Physical Record. .65535 File Type........... .... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SEXP SFXE SEDP SESP SEMP SRAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 13239.5 13246.0 13246.0 13246.0 13246.0 13246.0 13292.0 STOP DEPTH 13345.0 13808.0 13352.0 13352.0 13352.0 13352.0 13401.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 6 1 13192.5 MERGE BASE 13860.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..... ... ..........0 Data Specification Block Type.....O Logging Direction.... ... ...... ... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing............... ..... .60 .1IN Max frames per record...... ...... .Undefined Absent value.............. ....... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13239.5 13808 13523.8 1138 13239.5 13808 RAT MAD FT/H 4.82 2735.08 175.674 219 13292 13401 GR MAD API 14.98 143.83 45.1716 212 13239.5 13345 RPX MAD OHMM 2.73 420.51 58.4358 276 13246 13808 RPS MAD OHMM 3.04 1930.91 155.264 213 13246 13352 RPM MAD OHMM 3.17 2000 202.473 213 13246 13352 RPD MAD OHMM 3.41 1938.65 149.421 213 13246 13352 FET MAD HOUR 43.38 51.18 46.3966 213 13246 13352 First Reading For Entire File. ........ .13239.5 Last Reading For Entire File........ ...13808 File Trailer Service name.. ........ ...STSLIB.002 ') Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type........ ...... ..LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name...... ..... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 ') header data for each bit run in separate files. 1 .5000 START DEPTH 11692.5 STOP DEPTH 11783.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 30-JAN-03 Insite 3.3 Memory 11784.0 11690.0 11784.0 47.3 50.5 TOOL NUMBER 6.750 11690.0 Water 9.65 64.0 8.3 550 6.4 Based .000 .000 .000 .000 .0 137.0 .0 .0 ') REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction........ ...... ...Down Optical log depth units.. ...... ...Feet Data Reference Point..... ...... ...Undefined Frame Spacing.. .......... ...... ...60 .1IN Max frames per record.... ...... ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 11692.5 1. 25 Max 11783 152.56 First Reading For Entire File...... ... .11692.5 Last Reading For Entire File.......... .11783 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type...... ......... .LO Next File Name. ......... .STSLIB.004 Physical EOF File Header Service name........... ..STSLIB.004 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 Mean 11737.8 40.0706 Nsam 182 182 '\ ) First Reading 11692.5 11692.5 Last Reading 11783 11783 header data for each bit run in separate files. 2 .5000 START DEPTH 9341.5 11783.5 STOP DEPTH 12200.0 12255.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 06-FEB-03 Insite 66.37 Memory 12255.0 11784.0 12255.0 ) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.... .......Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........ .... .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O ) 43.2 45.1 TOOL NUMBER 151107 6.750 11690.0 Water 9.60 62.0 11. 5 550 6.2 Based 4.250 1. 780 4.500 6.500 63.0 159.8 63.0 63.0 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9341.5 12255 10798.3 5828 9341. 5 12255 ROP MWD020 FT/H 0.12 240.9 87.3828 944 11783.5 12255 GR MWD020 API 25.33 135.68 92.432 1411 9341.5 12200 First Reading For Entire File....... ...9341.5 Last Reading For Entire File.. ... .... ..12255 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name.......... .STSLIB.005 ) Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 ) header data for each bit run in separate files. 3 .5000 START DEPTH 12200.5 12255.5 STOP DEPTH 12482.0 12537.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 08-FEB-03 Insite 66.37 Memory 12537.0 12255.0 12537.0 29.1 41.2 TOOL NUMBER 151107 6.750 11690.0 Water 9.70 46.0 9.2 250 3.8 Based 4.200 1. 870 4.450 6.550 69.0 163.0 69.0 69.0 ) ) Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value................ ..... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 units Size Nsam Rep Code Offset Channel FT 4 1 6 8 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12200.5 12537 12368.8 674 12200.5 12537 ROP MWD030 FT/H 2.38 435.5 29.8818 564 12255.5 12537 GR MWD030 API 68.42 266.8 171.957 564 12200.5 12482 First Reading For Entire File....... ...12200.5 Last Reading For Entire File.......... .12537 File Trailer Service name.... ........ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 4 .5000 START DEPTH 12482.5 12537.5 STOP DEPTH 13102.5 13160.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG ll-FEB-03 Insite 66.37 Memory 13160.0 12537.0 13160.0 ) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type.....O Logging Direction......... ...... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.... ........ .Undefined Absent value...... ............... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 27.6 38.3 TOOL NUMBER 151107 6.750 11690.0 LSND 10.30 46.0 9.2 300 2.6 2.050 1. 030 2.350 2.200 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) 69.0 143.6 69.0 69.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12482.5 13160 12821. 3 1356 12482.5 13160 ROP MWD040 FT/H 2.12 114.7 24.0907 1246 12537.5 13160 GR MWD040 API 96.06 410.7 195.797 1241 12482.5 13102.5 First Reading For Entire File........ ..12482.5 Last Reading For Entire File....... ....13160 File Trailer Service name...... ...... .STSLIB.006 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.... ...03/06/06 Maximum Physical Record. .65535 File Type................ LO Next File Name...... .... .STSLIB.007 ) Physical EOF File Header Service name.. .......... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/06/06 Maximum Physical Record. .65535 File Type.......... ..... .LO Previous File Name. .... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 ) header data for each bit run in separate files. 5 .5000 START DEPTH 13103.0 13109.5 13109.5 13109.5 13109.5 13109.5 13160.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # STOP DEPTH 13332.5 13339.5 13339.5 13339.5 13339.5 13339.5 13390.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S); MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3); RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY; HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 13-FEB-03 Insite 66.37 Memory 13390.0 13160.0 13390.0 29.9 37.8 TOOL NUMBER 62456 73634 6.750 11690.0 LSND 10.30 45.0 9.0 300 2.6 2.100 .880 2.350 2.250 70.0 176.0 70.0 70.0 ) ') REMARKS: $ # Data Format Specification Record Data Record Type..... ... ...... ....0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point.. ...... .... ..Undefined Frame Spacing......... ...... ......60 .1IN Max frames per record...... .......Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13103 13390 13246.5 575 13103 13390 ROP MWD050 FT/H 2.68 166.54 37.9512 460 13160.5 13390 GR MWD050 API 14.21 357.79 106.512 460 13103 13332.5 RPX MWD050 OHMM 2.1 858 53.2583 461 13109.5 13339.5 RPS MWD050 OHMM 2.06 1692.39 86.0211 461 13109.5 13339.5 RPM MWD050 OHMM 2.02 1838.71 98.0356 461 13109.5 13339.5 RPD MWD050 OHMM 2.13 1080.03 63.926 461 13109.5 13339.5 FET MWD050 HOUR 1. 9682 53.4101 14.5341 461 13109.5 13339.5 First Reading For Entire File.... ..... .13103 Last Reading For Entire File.......... .13390 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name........... ..STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT 8 header data for each bit run in separate files. 6 .5000 START DEPTH 13192.5 STOP DEPTH 13764.5 ') NPHI NCNT RHOB DRHO PEF GR RPD RPX RPM FET RPS ROP $ 13193.5 13193.5 13206.0 13206.0 13206.0 13333.0 13340.0 13340.0 13340.0 13340.0 13340.0 13390.5 13764.5 13764.5 13781. 5 13781.5 13781. 5 13802.0 13741.5 13741.5 13741.5 13741.5 13741.5 13860.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ .... ..0 Data Specification Block Type. ....0 Logging Direction................ . Down Optical log depth units.... .... ...Feet Data Reference Point....... ... ... .Undefined Frame Spacing................... ..60 .1IN Max frames per record.. ....... ....Undefined Absent value..................... .-999 Depth Units.............. . . . . . . . . . Datum Specification Block sub-type...O ) 14-FEB-03 Insite 66.37 Memory 13860.0 13390.0 13860.0 37.2 42.4 TOOL NUMBER 62456 154268 110041 73634 6.750 11690.0 LSND 10.30 42.0 8.9 300 2.6 1.620 .650 1. 500 3.700 69.0 183.2 69.0 69.0 ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13192.5 13860 13526.3 1336 13192.5 13860 ROP MWD060 FT/H 0.76 147.01 28.7735 940 13390.5 13860 GR MWD060 API 9.9 171.43 36.31 939 13333 13802 RPX MWD060 OHMM 5.32 235.87 96.0186 804 13340 13741.5 RPS MWD060 OHMM 5.66 759.24 167.814 804 13340 13741.5 RPM MWD060 OHMM 5.5 1465.33 216.244 804 13340 13741.5 RPD MWD060 OHMM 6.03 627.85 172.215 804 13340 13741.5 FET MWD060 HOUR 1. 53 44.9 8.00558 804 13340 13741.5 NPHI MWD060 PU-S 7.23 80.12 21. 8517 1143 13193.5 13764.5 FCNT MWD060 CNTS 82.5 1679 728.84 1145 13192.5 13764.5 NCNT MWD060 CNTS 13396 37212 27920.7 1143 13193.5 13764.5 RHOB MWD060 G/CM 1. 25 2.64 2.20843 1152 13206 13781. 5 DRHO MWD060 G/CM -0.148 0.312 0.0695165 1152 13206 13781.5 PEF MWD060 BARN 1. 74 10.68 3.99707 1152 13206 13781.5 First Reading For Entire File......... .13192.5 Last Reading For Entire File.......... .13860 File Trailer Service name. ........... .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name. ........... .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/06 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE SGRC SFXE SEDP 9 header data for each pass of each run in separate files. .5000 6 1 START DEPTH 13230.0 13237.0 13237.0 STOP DEPTH 13337.0 13343.5 13343.5 ) SEMP SESP SEXP SRAT $ 13237.0 13237.0 13237.0 13288.0 13343.5 13343.5 13801. 0 13394.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... .... ..Down Optical log depth units.... ...... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.............. ....... .-999 Depth Units....................... Datum Specification Block sub-type...O ) 14-FEB-03 Insite 66.37 Memory 13394.5 13288.0 13394.5 37.2 42.4 TOOL NUMBER 62456 154268 110041 73634 6.750 11690.0 LSND 10.30 42.0 8.9 300 2.6 1.620 .650 1. 500 3.700 69.0 183.2 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD061 FT/H 4 1 68 4 2 GR MAD061 API 4 1 68 8 3 RPX MAD061 OHMM 4 1 68 12 4 RPS MAD061 OHMM 4 1 68 16 5 RPM MAD061 OHMM 4 1 68 20 6 RPD MAD061 OHMM 4 1 68 24 7 ) ) y FET MAD061 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13230 13801 13515.5 1143 13230 13801 RAT MAD061 FT/H 4.82 2735.08 165.679 214 13288 13394.5 GR MAD061 API 14.98 143.83 43.3018 215 13230 13337 RPX MAD061 OHMM 2.73 420.51 59.5936 277 13237 13801 RPS MAD061 OHMM 3.04 1930.91 159.766 214 13237 13343.5 RPM MAD061 OHMM 3.17 2000 212.665 214 13237 13343.5 RPD MAD061 OHMM 3.41 1938.65 155.419 214 13237 13343.5 FET MAD061 HOUR 43.38 51.19 46.5599 214 13237 13343.5 First Reading For Entire File......... .13230 Last Reading For Entire File.......... .13801 File Trailer Service name........... ..STSLIB.009 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.. .... .03/06/06 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... . UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File