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79' &DOF(72& 0' (63$VVHPEO\%RWWRP# 0' 79' 7RSRI7XELQJVWXE,'# 0' 2SWL6OLGLQJ6OHHYH ;3URILOH# 0' :HDWKHUIRUG6WDQGLQJ9DOYH6HDW,'# 0' 8QVXFFHVVIXOMHWFXWV# DQG 0' D D ds ds72/# 0' 79' dŽƉ ĂƐĞ dŽƉ ĂƐĞ / 0' ,' +<' 79' KROH %DNHU0RGHO)3DFNHU# 0' 79' %DNHU0RGHO)3DFNHU# 0' 79' /(8(7XELQJ7DLO,'# 0' 79' ),6+6SHQW7&3*XQV# 0' / 0' ,' +<' 79' KROH 7' 0' 79' 0RWRU0RWRU*DXJH8QLW &HQWUDOL]HU &KHPLFDO,QMHFWLRQ&KHFN9DOYH $QRGH +HPORFN3HUIRUDWLRQV 6HDO$VVHPEO\8SSHU/RZHU6HDOV :058)LQDO:HOOERUH6FKHPDWLF (/(&75,&68%0(56,%/(3803(63 (63)ODW3DFN&DEOH 'LVFKDUJH8QLW$VVHPEO\ 3XPS$VVHPEO\ % % : 88 • 011, V or Ti. ifr\��yyy�� THE STATE Alaska Oil and Gas �, o Conservation Commission _: fALASI�:A 14 333 West Seventh Avenue *� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �� Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov January 10, 2017 Mr. David Kumar Production Manager Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 RE: No-Flow Verification West McArthur River Unit#6SCANNED n CPTD 2001070 ��`�' Dear Mr. Kumar: On December 15, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of West McArthur River Unit#6. The well is operated by Cook Inlet Energy(CIE). The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up on West McArthur River Unit#6 prior to the test. The well performance was monitored for three hours with no observed gas flow at the end of the flow monitoring periods. There was no liquid flow to surface during the no-flow test. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if West McArthur River Unit #6 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter at the West McArthur River Unit Production Facility. Sincerely, 5, Ic' James B. Regg �� l Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA . t . AlA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS No F 2.Z61Le 1.Operations Abandon U PlugPerforationsTubing U vpe'r ,_ U H Fracture Stimulate U Pull ratidns shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RUN ESP ❑I 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: COOK INLET ENERGY,LLC Development ❑., Exploratory ❑ 200-107 3.Address: 601 W.5TH AVE,SUITE 301,ANCHORAGE, Stratigraphic Service ❑ 6.API Number: AK 99501 50-133-20494-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 359111 WEST MCARTHUR RIVER UNIT#6 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A WEST MCARTHUR RIVER OIL POOL 11.Present Well Condition Summary: Total Depth measured 14962 feet Plugs measured N/A feet true vertical 9951 feet Junk measured 14347 feet Effective Depth measured 14347 feet Packer measured 14002&14068 feet true vertical 9534 feet true vertical 9158&9216 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 119' 119' N/A N/A Surface 1926' 13.375" 1926' 1718' 5020 PSI 2260 PSI Intermediate 7504' 9.625" 7504' 5166' 6870 PSI 4750 PSI Production 6056' 7.625" 13342' 8618' 6890 PSI 4790 PSI Liner 1823' 5.5" 14955' 9946' 7740 PSI 6280 PSI Perforation depth Measured depth 14116-14670 feet True Vertical depth 9257-9711 feet ,,4 tMJ , .I�/j-1 f, Tubing(size,grade,measured and true vertical depth) 2 7/8" L80 11320'MD 7284'TVD Packers and SSSV(type,measured and true vertical depth) Baker Model F-1 14,002'&14,068'MD 9158'&9216'TVD 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: 165 39 897 53 3700 Subsequent to operation: 153 36 800 62 42 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas U WDSPL U 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: Contact Stephen Ratcliff Email sratcliff@glacieroil.com Printed Name StephenepRatcliff Title Sr.Drilling Engineer Signature d� -.----C-\----\� Phone 907-433-3808 Date it 12116 Form 10-404 Revised 5/2015 , tZ7 ' 2-�-C� Submit Original Only RBDMS LL-NOV - 7 2016 • GLACIER _ November 2nd, 2016 Ni 1 VMs. Cathy Foerster, Chair 2016 Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: West McArthur River Unit#6 Permit to Drill NO: 200-107 API No: 50-133-20494-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Sundry Completion Report for Sundry 316-334 for pulling the jet pump completion and running a new ESP Completion. Enclosed please find: 1. Well Completion Report(AOGCC Form 10-404) 2. Completion Schematic 3. Daily Summaries If you have any questions,please contact me at(907) 433-3808. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy 10-404 601 W.51h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax WOU-06 Current Wellbore Schematic • 10/13/2016 Version-1.0 Tubing Hanger-2-7/8"EUE Thread-ID-2.441" ...] _ 20" 133#L-80 119'MD ID-18.00" Buttress 119'TVD 13 3/8" 68#L-80 1,926'MD ID-12.25" Buttress 1,718'TVD 2-7/8"6.5#L80 EUE Tubing-ID-2.441" TOL©7,317'MD/5058'TVD Al 9 518" 47#L-80 7,504'MD ': - ID-8.50" Buttress 5,166'TVD • Ld. • } '4. :-i Dual 3/8"Stainless Flat Pack Lines d',. r% ESP Assembly Top @ 11,320'MD/7,284'TVD • ELECTRIC SUBMERSIBLE PUMP(ESP) ESP#1 Flat Pack Cable Discharge Unit Assembly Pump Assembly 1,; Seal Assembly-Upper/Lower Seals I;11111 Motor/Motor Gauge Unit Centralizer f Chemical Injection Check Valve r Anode 1. try " A ( ESP Assembly Bottom @ 11,440'MD/7,357'TVD G' 1 + Top of 2 7/8"Tubing stub-ID 2.441"©11,481'MD 0Opti Sliding Sleeve&X Profile©13,964'MD I'' Weatherford Standing Valve Seat-ID 2.25"©13,968'MD Unsuccessful jet cuts @ 13981'and 13991'MD TOL©13,131'MD/8455'TVD 4' 7 5/8" 29.7#L-80 13,342'MD ' ID-6.875" HYD 521 8,618'TVD ■1 II f Hemlock Perforations Baker Model F-1 Packer©14,002'MD/9158'TVD MD MD TVD TVD „, Baker Model F-1 Packer©14,068'MD/9216'TVD Top Base Top Base �j I 2-7/8"6.5#L80 EUE Tubing Tail-ID 2.441"©14,113'MD/9254'TVD 14,116 14,128 _ 9,257 9,268 l 14,146 14,166 9,284 9,301 L 14,188 14,258 9,320 9,378 _ - 14,267 14,280 9,386 9,398 I . , 14,306 14,314 9,420 9,426 14,322 14,460 9,432 9,543 14,462 14,538 9,544 9,604 14,598 14,670 9,653 9,711 .r7 FISH 1-Spent TCP Guns©14,347'MD x =-_ 5 1/2" 17#L-80 14,955'MD l ID-4.95" HYD 521 9,946'TVD TD 14,950'MD/9,946'TVD • WMRU-06 Daily Operations Summaries PTD: 200-107/API: 50-133-20494-00-00 09/28/2016 Rig Move 09/29/2016 Rig Up 09/30/2016 Rig Up 10/01/2016 Rig Up 10/02/2016 Continue Rig Up. Remove BPV. Rig up to circulate well with 8.4ppg produced water. Circulate down tubing taking returns through rig choke at 1.5 bpm. Returns at surface after 13 bbls pumped. Max H2S seen at flowline of 25 ppm, 10% LEL max. Increase pump rate to 6.3 bpm, 2500 psi, and complete hole volume circulated. Set BPV. ND tree. NU BOPE. 10/03/2016 Continue NU BOPE. Perform shell test, repair leaks. Pressure test BOPE—250 psi low/2500 psi high —good. Witness waived by AOGCC representative, Jim Regg. MU Landing joint. RU Slickline and RIH, knock out kobes in standing valve. POH. RIH with bulldog spear and latch standing valve at 13,952', POH, standing valve came off. Redress spear, RIH, latch standing valve at 13952', POH. RD Slickline. Pump 20 bbls salt pill and spot at pump cavity. Work String to free seals, up to 30K overpull. 126 bbls lost to well. 10/04/2016 RU E-line and RIH with jet cutter, make cut at 13991',,,POH. RIH with 2nd run and make second cut at 13981', POH. RD E-line. Latch onto landing joint and pull 150K, no go. Work tubing 150K up with no movement. RU E-line, RIH with free point tool, determine tubing is hung up at 11850', POH. RIH with jet cutter. 10/05/2016 RIH with jet cutter and cut at 11483', POH and RD E-line. Pull hanger, pipe free, LD Hanger and landing joint. POH and LD 2 7/8"tubing. RU Slickline and RIH with Caliper tool. 10/06/2016 Log with Caliper tool from 11473' to top of 7 5/8" liner, POH. RD Slickline. RU Slickline RIH with 6.5"junk basket to 11480', POH and recover 1 cup of scale. RD Slickline. RIH with Champ Packer • • • on 2 7/8"tubing to 7537' MD. Set Packer and test casing to 1500 psi—good. Continue RIH to 8969'. 10/07/2016 Continue RIH with champ packer to 11473'. Set Packer and test casing for 30 mins to 1500 psi- good. POH with Champ packer. RU to run completion. MU ESP BHA and RIH with 2 7/8" 6.5# L80 tubing to 1676'. 10/08/2016 Continue RIH with ESP BHA on 2 7/8" 6.5# L80 tubing, installing cannon clamps, to 11440'. MU 2 tubing hanger and land hanger with end of tubing at 11440' MD/7357' TVD. RD ESP running equipment. Set BPV and ND BOPE. 10/09/2016 Continue ND BOPE. Test ESP cable and chemical injection lines—good tests. Rig Released. END of WMRU-06 Workover Operations (Sundry 316-334) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,C1 l `-1 DATE: 12/18/2016 P. I. Supervisor FROM: Matt Herrera SUBJECT: No Flow Test Petroleum Inspector WMRU #6 Cook Inlet Energy PTD 2001070 - December 15, 2016: I traveled to West MacArthur River (WMRU) at Trading Bay and met up with Lead Operator Daniel Clark. Went over the set up for the no-flow test to be performed on WMRU #6. They had the tubing and IA twinned to flow into a bleed tank. Also, they had a Brooks MT3810 gas meter and calibrated mirror-back 500psi pressure gauge set up inline to the bleed tank. The Brooks Gas Meter was calibrated 7/18/16, set to measure in standard cubic feet per minute. The mirror back gauge calibration date was 6/24/16. WMRU #6 had been open to bleed approx. 48 hours prior to testing/inspection. Well is equipped with an Electric Submersible Pump (ESP). The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:30 0/0/0 . 0 0 • Intial press reading no liquids 11:00 0/0/0 - Pressure Reading Only 11:30 0.5/0.5/0 - 0 0 - Bleed - No gas -No Fluids - 12:00 0.75/0.75/0 Pressure Reading Only 12:30 0.75/0.75/0 - Pressure Reading Only 13:00 1.0/1.0/0 Pressure Reading Only 13:30 1.0/1.0/0 0 • 0 - Bleed < 2.5 SCFM on Gas meter bled to 0 < min no - liquids 1 Pressures are T/IA/OA Summary: WMRU #6 has the characteristics of a well that meets a passing no-flow test. Attachments: none SCANNED MAY 1 1201? 2016-1215_No-FlowWMRU-6_mh.docx Page 1 of 1 • i of TfJ cv-i0 lI/7 s, THE STATE Alaska Oil and Gas f:: ,;sem 4 of/\ LAsKA Conservation Commission 333 West Seventh Avenue ". ",2 — letis* GOVERNOR BILL WALKER Anchorage,e, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC : ; 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Re: West McArthur River Field, West McArthur River Oil Pool, WMRU 6 Permit to Drill Number: 200-107 Sundry Number: 316-334 Dear Mr. Ratcliff: 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 . Foerster Chair DATED this 23 day of June, 2016. RBDMS , /JUN Z 4 2016 • • RECEIVED STATE OF ALASKA JUN I 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 6 /43 APPLICATION FOR SUNDRY APPROVALS 0 Cr 20 AAC 25.280 1.Type of Request: Abandon IJPlug Perforations III Fracture Stimulate IJ IJ Repair Well Operations shutdownu Suspend Perforate Other Stimulate Pull Tubigg El Change Approved Program Plug for Redrill — Perforate New Pool — Re-enter Susp Well AlterCasingRUN ESP 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy,LLC . Exploratory n Development 200-107 - 3.Address: Stratigraphic �`y Service 6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-133-20494-00-00 7.If perforating: /1/46 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? .L.;-t) -f.-,-y Ct.89 West McArthur River Unit#6 • Will planned perforations require a spacing exception? Yes No / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 359111 West McArthur River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft$ Total Depth TVD(ftLj2� Effective Depth� MD: Effective Depth TVD MPSP(psi): f• Plugs(MD): Junk(MD): /1 1 6� ?is.1 /r l i ti,Y6 (i1- 3 h ".J A i3' p%✓ N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 103 20 119' 119 N/A N/A Surface 1926 13 3/8 1,926' 1718 5020 2260 Intermediate 7504 9 5/8 7,504' 5166 6870 4750 Drilling Liner 6056 7 5/8" 13,342' 8618 6890 4790 production Liner 1823 5 1/2" 14,955' 9946 7740 6280 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): see attached see attached 2 7/8" L-80 14,113 Packers and SSSV Type: no SSSV Packers and SSSV MD(ft)and TVD(ft): Baker Model Fl PKR-14,002'/9,158' 12.Attachments: Proposal Summary I01 Wellbore schematic I01 13.Well Class after proposed work: IN Detailed Operations Program BOP Sketch IXI v Exploratory I I Stratigraphic I I Development IXI, Service 14.Estimated Date for 15.Well Status after proposed work: 25-Jul-16 Commencing Operations: OIL ® . WINJ WDSPL — El 16.Verbal Approval: Date: N/A GAS 1=1 WAG El Suspended GSTOR _ SPLUG Commission Representative: N/A GINJ 0 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. Stephen Ratcliff Contact Email sratcliff@glacieroil.Com Printed Name Title Stephen Ratcliff :: (907)433-3808 Senior Drilling Engineer :: 6-15-16 Signature P\ Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -6\x_ 3 `i Plug Integrity ❑ BOP Test 27 Mechanical Integrity Test ❑ Location ClearanceA �-�--,- /i Other: . 3006 /54.. 6oP/e5r (' z szxra<t ,,S, ,' 1 ...�.rr-� -7 v 7 `` IV- r=lam a F t...4;,+.'.4 k a -,s 1 r=s►' Ce• t 6J ,.:>.. Post Initial Injection MIT Req'd? Yes El No —/ '� Spacing Exception Required? Yes ElLLLJJJ No It' Subsequent Form Required: / 0 Oil RBDMS G"`' JUN 2 4 2016 ✓, APPROVED BY Approved by: apt4 / COMMISSIONER THE COMMISSION Date: -Z3-/4 JQAA `�Ifr iS- ��G/�� Land Cr� �p`�©•-� Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the da of approval. Attachments in Duplicate ORIGINAL < • i GLACIER RECEIVED June 15, 2016 JUN 15 ++2016 Ms. Cathy Foerster, Chair AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: WMRU-06—ESP Conversion Application Cook Inlet Energy: 50-133-20494-00-00 Dear Ms. Foerster, Cook Inlet Energy hereby submits a sundry for WMRU-06, PTD: 200-107 requesting permission to pull the current jet pump completion and run a new ESP Completion. It is also requested that a no flow test will be performed to omit the vent valve, production packer, and sub surface safety valve. If you have any questions, please contact me at 907.433.3808. Sincerely, Stephen Ratcliff Sr. Drilling& Completions Engineer Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 < • • GLACIER 1. WELL NAME—WMRU-06 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing with a jet pump completion. Scope of Work: • Rig up Rig 37 • Pull jet pump completion and tubing • Test Casing above Liner Lap • P/U ESP Completion and RIH to +/- 12,400' MD • N/D BOPE & N/U Production Tree • Turn over to production and flow well General Well Information: Reservoir Pressure/TVD: 0.32 psi/ft 2,910 psi @ 13,957' MD (9,122' TVD) —PT Log (April 27, 2016) MASP: Reservoir Pressure—(Gas Gradient X TVD) (0.32 psi/ft X 9,711' TVD)—(0.1 psi/ft X 9,711') = 3,107 psi —971 psi =221, 36j si Wellhead Type/Pressure Rating: 13 5/8" 5M Wellhead - 3 1/2" 5M tree BOPE: 13 5/8" 5M — Pipe Rams/ Blind Rams/Annular Well Type: Oil Well Estimated Start Date: July 25, 2016 Waivers Requested: The completion will be run with out an SSSV and production packer. A no-flow test will be performed to demonstrate the well will not flow to surface with out the help of artificial lift, in accordance with 20 AAC 25.265 (k). It is requested that a variance to the 5-day period, under section (3), be extended to 2 • • GLACIER /1/4)T> a 60 —period to insure against any potential for infancy failures with the new ESP completion. This will also allow for any near wellbore storage to return to normal production rates while the well was offline during the workover period. Upon turning the well over to production, the surface safety valve will be tested with in 5 days of completing the well and bringing it back online. CIE Drilling Manager CIE Sr. Drilling Engineer CIE Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 3 . < • • GLACIER Program Pre-Rig 1. Conduct pre-job safety meeting with all personnel on location o Review upcoming work and discuss safety first 2. Shut-in WMRU-06 Well 3. Lock out safety systems and power oil 4. Confirm that the SSSV is open 5. Rig up slickline and test lubricator to 3,000 psi 6. RIH and pull jet pump and standing valve 7. Kill well with 8.7 ppg produced water+ KCI 8. Ensure that well is dead Rig Workover 9. Mobilize crew, drilling rig, and equipment to West McArthur Facility 10. Set Two-Way Check Valve in well 11. Rig up on WMRU-06 with Rig 37 12. N/D Production Tree 13. N/U BOPE o Notify AOGCC of start of operations and upcoming BOP Test with 48 hours notice 14. Nipple up and test 13 5/8" BOPE o Test Rams to 3,000 psi o Test Annular Bag t0 psi 15. Pull Two Way Check Valve /_ 16. Confirm well is dead j /'c z' `j( ��c�- 17. R/U E-Line and Lubricator 18. RIH on E-Line to make Tubirut above packer with Jet Cutter o Correlate on Depth o Note—Top Permanent Packer at 14,002' MD 19. Make Cut and POH 20. R/D E-Line 21. P/U Landing Joint and make up to 2-7/8" Tubing Hanger 22. Back out Lock Down screws in Tubing Hanger 23. Pick up while confirming that tubing is free o Max Pull not to Exceed 110,000 lbs • W/O Weight of Blocks 4 . • GLACIER 24. Pull & L/D 2-7/8" Landing Joint and Tubing Hanger 25. Check for Flow and confirm well is dead 26. POH and LID the following: o 2-7/8" Tubing o Opti Sliding Sleeve o Weatherford Jet Pump Cavity o 2-7/8" Tubing 27. P/U 3-1/2" PH6 Work String and RTTS Test Packer for Casing Integrity Test 28. RIH to 13,100' MD 29. Set Test Packer and prepare for 30 minute casing test 30. Pressure up to 1,500 psi and test casing for 30 minutes /C o Note— If test fails then prep to test 9-5/8" X 7-5/8" Liner Lap o Note— ESP BHA will be set above 7-5/8" X 5-1/2" Liner Lap at +/- 12,400' 31. Confirm pressure test success and report to CIE Drilling Engineer prior to moving forward 32. Circulate well clean 33. POH and L/D work string 34. Prep to pick up ESP Completion equipment, spoolers, and tools 35. R/U Summit for ESP Completions o Hold PJSM for ESP Run o Test and confirm that all equipment is on location and ready to RIH o Note that ESP will not enter in to the 5-1/2" liner o Note that the COMPLETION ESP/TUBING WILL NOT BE ROTATED 36. P/U the following completion equipment as follows: ■ NOTE—Setting Depth of ESP BHA at 12,400' ■ Top of 5-1/2" liner at 13,131' — DO NOT ENTER 5-1/2" LINER o Anode & Motor Assembly—Summit Completions ■ Anode • Run Flat Pack Cable F/ Bottom of Anode to Surface ■ Chemical Injection Check Valve ■ Centralizer ■ Motor Gauge Unit (MGU) ■ Motor • No bands to be installed within 3' of motor head or base • Note— ESP Cable and Flat Pack with (2) 3/8" lines will be ran to surface o Seal Assembly—Summit Completions ■ Lower Tandem Seal • (1) Stainless steel band at mid point of seal section • (1) Protectolizers ■ Upper Tandem Seal 5 • • GLACIER • (1) Stainless steel band at mid point of seal section • (1) Protectolizers ■ Adapter Kit o Pump #1 Assembly—Summit Completions ■ Intake ■ Pump #1 • (5) Clamps on each pump section • (3) Protectolizers o Discharge Unit Assembly— Baker Completions ■ Bolt on Discharge Head ■ Discharge Gauge Unit (DGU) o 2-7/8" 6.5# L80 EUE Handling Pup o 2-7/8" 6.5# L80 EUE Tubing to Surface ■ Cannon Clamps at connections for: • Every collar for first 5,000' • Every other collar to surface o Vetco 2-7/8" 6.5# EUE Tubing Hanger ■ Hanger has EUE 8 RD on top & Bottom • Confirm in field for landing joint ■ Verify that tubing hanger has: • Pass through for ESP Cable • (2) 3/8" Ports for Chemical Injection Lines o Confirm prior to starting completion run o 2-7/8" 6.5# L80 EUE Landing Joint 37. RIH to+/- 12,400' o Do not run ESP pump in to 5-1/2" liner at 13,131' . 38. M/U Landing Joint and set completion string in slips 39. Dress hanger and control lines 40. Land tubing hanger and test seals to 5,000 psi through test port 41. Perform final electrical check on cable 42. L/D Landing Joint 43. Set Back Pressure Valve o Observe that well is dead 44. Complete surface ESP Hookup, Installation, and Tie-In 45. Nipple down BOPE 46. Nipple up tree and test to 5,000 psi o Insure that Surface Safety Valve is in place 47. Confirm with production that well is ready to be brought online and turned over to production 48. Turn well over to production it SS�,� ++ems Gl`;` 6 0 • WMRU-06 Current Completion 5/24/16 Version-Final Tubing Hanger-2-7/8"EUE Thread-ID-2.441" ^ 20" 133#L-80 119'MD ID-18.00" Buttress 119'TVD ] , 13 3/8" 68#L-80 1,926'18'TVD MD j ‘' ID-12.25" Buttress 1,7 J ' 1• o-. 2-7/8"6.58 L80 EUE Tubing-ID-2.441" TOL @ 7,317'MD 9 5/8" 47#L-80 7,504'MD -.MIJID-8.50" Buttress 5,166'TVD ea 'B 44 fl. •4' T ,i iki1 A *. r'k ? +ry ......'.'11.' .11 '9 TOL@ 13,131'MD , .'? 7 5/8" 29.78 L-80 13,342'MD s ID-6.875" HYD 521 8,618'TVD f _"x a Jet Pump w/Opti Sliding Sleeve 8 X Profile @ 13,964'MD + F, ''� Weatherford Standing Valve Seat @ 13,968'MD-ID-2.25" ..I Baker Model F-1 Packer @ 14,002'MD Baker Model F-1 Packer @ 14,068'MD Hemlock Perforations • MD MD TVD TVD 2-7/8"6.5#L80 EUE Tubing Tail 14,113'MD-ID-2.441" Top Base Top Base 14,116 14,128 9,257 9,268 _ 14,146 14,166 9,284 9,301 �`f ' 14,188 14,258 9,320 9,378 =.' 14,267 14,280 9,386 9,398 14,306 14,314 9,420 9,426 , xi 14,322 14,460 9,432 9,543 =.r - 14,462 14,538 9,544 9,604 14,598 14,670 9,653 9,711 . " FISH 1-Spent TCP Guns @ 14,347'MD '� 5 1/2" 17#L-80 14,955'MD I. ID-4.95" HYD 521 9,946'TVD TD 14,955'MD/9,946'TVD • • • WMRU-06 Proposed ESP Completion 5/24/16 Version-1.0 Tubing Hanger-2-7/8"EUE Thread-ID-2.441" 20" 133#L-80 119'MD ID-18.00" Buttress 119'TVD JA / i 13 3/8" 68#L-80 1,926'MD 4 L ID-12.25" Buttress 1,718'TVD Z 2-7/8"6.5#L80 EUE Tubing-ID-2.441" TOL @ 7,317'MD -. 9 5/8" 47#L-80 7,504'MD II i -,, ID-8.50" Buttress 5,166'ND li Dual 3/8"Stainless Flat Pack Lines I ESP Assembly Top+/-12,250'MD ', ELECTRIC SUBMERSIBLE PUMP(ESP) ;V... ESP#1 Flat Pack Cable Vr Discharge Unit Assembly F Pump Assembly a`- Seal Assembly-Upper/Lower Seals Motor!Motor Gauge Unit it: Centralizer '� Chemical Injection Check Valve ii° Anode ESP Assembly Bottom+1-12,400'MD 0 t,.,4 4,,, ;,... , , TOL @ 13,131'MD i .. .i ■ 7 5/8" 29.7#L-80 13,342'MD ID-6.875" HYD 521 8,618'TVD Hemlock Perforations MD MD ND ND -Top Base Top Base -....... 14,116 14,128 9,257 9,268 x- 14,146 14,166 9,284 9,301 =, >� 14,188 14,258 9,320 9,378 ='. 14,267 14,280 9,386 9,398 14,306 14,314 9,420 9,426 II 14,322 14,460 9,432 9,543 - 14,462 14,538 9,544 9,604 14,598 14,670 9,653 9,711 =,' FISH 1-Spent TCP Guns @ 14 347'MD 5 1/2" 17#L-80 14,955'MD ID-4.95" HYD 521 9,946'TVD TD 14,950'MD/9,946'TVD • COOK INLET ENERGY 13-5/8" 5M BOPE ( 13-5/8" 5M HYDRIL GK ANNULAR 54-1/8" / r \ f �J i \ , 13-5/8" 5M NOV LXT DBL GATE 31" U4 L_C ODRESSED W/VBR RAMS IN TOP =Cx�z)- -Cx�x)-� DRESSED W/ BLIND RAMS IN BOTTOM ADAPTER SPOOL 19" 13-5/8" 5M X 11" 5M OR 11" 10M -104" TOTAL STACK HEIGHT ANNULAR STYLE BOP FLUID SPECS: - 17.98 gallon close chamber volume - 14.16 gallon open chamber volume LXT BOP FLUID SPECS: -5.14 gallons to close per gate -4.86 gallons to open per gate -6.47:1 closing ratio TOP VIEW OF VALVES BOLTED TO SIDE OUTLETS OF BOP =NEB 0,07„ rm. 1 • OD (d•Caa) eanleaedwal V N 0 Co CO V N 0 CO (O V N 0 o) a) a) co co CO co co I r— r— r— r` r r r r r r r r r r r r o I I I I I I I I I o CD O) O 0 N ti N 4 0 in I-- cd CO (0 V co O in a� CO N (0 d D N LL N L Lo7 Q cc) N E N Y (00p n -0 f .c E m ^ I coa) U i co t c9 CD v CD E EN N N O d CO (0 5 CD I* M W 2 _ f� co ) Lo r` (0 CD in N N N- 45 0 0 0 0 0 0 0 0 0 0 CO N O O 0 0 0 0 0 0 0 0 Q N 0 CO M V N 0 CO (O ,- 13 M M N N N N N a) O 0. (.) N co (eisd) aanssaid ct 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. CAN DIGITAL DATA OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Scanning Preparation x 30 = + = TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~' YES Stage 2 IF NO IN STAGE '1, PAGE(S) DISCREPA/~~ERE FOUND: ~S .__ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON ~ PAGE BASIS ' DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS~ Quality Checked 12/10/02Rev3NOTScanned.wpd • • slar[E 0[F A[LtmA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 24, 2011 Mr. David Hall Cook Inlet Energy 601 West 5 Avenue Anchorage, AK 99501 Re: Safety Valve System Testing` IUr'I 4 Dear Mr. Hall: The Alaska Oil and Gas Conservation Commission (Commission) finalized and readopted revisions to well safety valve system (SVS) regulations — 20 AAC 25.265 — that became effective on December 3, 2010. In conjunction with those regulations, the Commission also published Industry Guidance Bulletin 10 -004 ( "Safety Valve Systems ") dated December 16, 2010. Weblinks to both documents were provided to Cook Inlet Energy (CIE) on December 30, 2010 by electronic mail with a request to establish a single - point -of- contact and to identify for the Commission the months CIE intends to test its well SVS. A response was requested by January 21, 2011. A second reminder was provided to CIE on February 11, 2011. CIE has not responded to the Commission's request. A review of Commission production records indicates the following CIE wells have produced during the first six months of the effective date of the readopted SVS regulations and therefore the SVS should have been tested not later than June 3, 2011: - West McArthur River Unit lA (PTD 1951180) - West McArthur River Unit 2A (PTD 1931550) - West McArthur River Unit 5 LTD 1980470) West McArthur River Unit 6 (PTD 200107 - Kustatan Field f (PTD 2001530) - West Foreland 2 (PTD 2041430) The Commission requests the following not later than July 8, 2011: 1) SVS tests performed on the above - listed wells since December 3, 2010; the Commission provided CIE the proper SVS test report forms by electronic mail dated June 1, 2011; 2) CIE's schedule for testing wells in the West McArthur River, West Foreland, Kustatan, and Redoubt fields; 3) CIE single - point -of- contact for SVS matters. • Mr. David Hall • • June 24, 2011 Page 2 of 2 You are reminded that a functional SVS must be installed, maintained and tested as described in 20 AAC 25.265 for all completed wells except water source wells, disposal injectors, observation wells and those wells that are isolated from the flowline. Performance testing of the well SVS must be conducted semi - annually. Depending on well location, the Commission must be notified at least 24 to 48 hours prior to testing for an opportunity to witness those tests. Failure to comply with the SVS test requirements may result in the Commission pursuing enforcement action. Please direct any questions regarding SVS testing requirements to Jim Regg at 907 - 793 -1236. Sincerely, ill Cathy P Foers er Commissioner l SEAN PARNELL, GOVERNOR ALASKA OIL AATD GAS 333 W. 7th AVENUE, SUITE 100 CONSERTATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Hall CEO Cook Inlet Energy 601 West 5th Avenue, Suite 310 Anchorage, AK 99501 Re: W. McArthur River Field, W. McArthur River Pool, WMRU #6 Sundry Number: 310 -426 Dear Mr. Hall: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 Foerster Commissioner DATED this L day of December, 2010. Encl. 4h- - � b� Iz/rv�2oro STATE OF ALASKA \ ALAS IL AND GAS CONSERVATION COMMISSIO % APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Q r Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Cook Inlet Energy Development Q Exploratory 200 -107 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 601 West 5th Ave., Suite 310 Anchorage, AK 99501 50- 133 - 20494 -0000 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NIA W. McArthur River Unit #6 ' Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 0359111 1 W. McArthur River 11. PRESENT WELL CONDITION SUMMARY Total Depth MDp) p Total Depth TVD( tom ! Eff�ctive Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): Junk (measured): `4- 14,822 9,813 NIA NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 119' 119' NIA N/A Surface 2,204' 13318" 1,926' 1,718' 5,020 psi 2,260 psi Intermediate 6,638' 9518" 7,504' 5,166' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7518" 13,342' 8,618' 6,890 psi 4,790 psi Production Liner 1,748' 5 -1/2" 14,955' 9,946' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 - 14,166', 9,120' - 9,137', 14,188'- 14,258', 9,156'.9,216', 14,267'- 14,280', 9,223' - 9,232', 14,306'- 14,314', 9 9,263', 2 -7/8" L-80 14,113' 14,322'- 14,460', 9,270'- 9,301', 14,462'- 14,538', 9,382' .9,441', 14,598'- 14,670' 9,490' - 9,549' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker F4 @ 14,002' MD /9,090' TVD, Two Baker F -1 Packers, no SSSV l Baker F -1 @ 14,068' MD /9100' TVD 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q r Service ❑ 14. Estimated Date for 12120/2010 15. Well Status after proposed work: � Commencing Operations: Oil Q Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Represent ive: '`,,/ l t �I GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the o oing is true and correct to the best of my knowledge. Contact David Hall 433 -3804 Printed Name David Hall Title CEO Signature Phone Date 12/16/2010 907- 334 -6735 COMMISSION USE ONLY ((�� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: •. 0 I D DEC 16 2010 w Gas Cams. Commis ills Subsequent Form Required: to — 4 0�, Anchorage � APPROVED BY Approved by: v� COMMISSIONER THE COMMISSION Date: 12 orm evi EC 2 2 �ni m t lf� r Cook Inlet Ener WMRU #6 Completion 20" 133 #, L -80 BTC @119' MD, 119' TVD 13 3/8" 68 #, L -80 BTC @ 1926' MD, 1718' TVD TOC @ 7,317' 9 5/8" 47 #, L -80 BTC @ 7504' MD, 5166' TVD TOC @ 13,131' MD 7 -5/8" 29.7 #, L -80 Hyd 521 OPTI SI. Sleeve with X profile @ 13,964'MD @ 13,342' MD, 8618' TVD Weatherford Standing Valve Seat @ 13,968' MD, Min ID — 2.25 ". Backer Model F -1 Packer @ 14,002' MD Backer Model F -1 Packer @ 14,068' MD 2 -7/8" L -80, 6.5# Tbg Tail @ 14,113' MD Perforations: 1 14,116'- 14,128' MD, 14,146'- 14,166' MD Top of Fish @ 14,347' MD (Spent TCP Guns) 14,188'- 14,258' MD, 14,267' - 14,280' MD 14,306'- 14,314' MD, 14,322'- 14,460' MD 14,462'— 14,538' MD, 14,598'— 14,670' MD I 5 -1/2" 17 #, L -80 Hyd 521 14,955' MD, 9,946' TVD w � • Cook Inlet Ener December 16, 2010 4f Mr. Dan Seamount, Chair 1 �r <0/0 A 3 Wes 7`7 Ave., S u Suite 100 s Commission 33 Anchorage, Alaska 99501 Re: Application for Sundry Approval Re- Perforation of WMRU #6 (PTD No. 200 -107) Dear Mr. Seamount, Cook Inlet Energy plans to selectively re- perforate the West McArthur River Unit #6 well due to declining flowing downhole pressure and liquid production. During the past few weeks, a significant liquid production decline from WMRU #6 has been noted and it prompted running a downhole pressure test on December 14. That test indicated that the downhole pressure has decreased from approximately 1,700 psi in late 2008 to about 1,200 psi two days ago. Remedial work involving re- perforating selected intervals is planned in order to bring production back up. We plan to re- perforate the following intervals using 2- 1/16 ", 3406 PJ, 6 spf guns: 14,146' — 14,166' 14,188'— 14,258' 14,267'— 14,280' 14,306'— 14,314' 14,322' — 14,347' (top of fish) Included in this application are a Form 10 -403 Application for Sundry Approval and a current wellbore diagram. If you have any questions, please contact me at 317 -8239 or Natasha Sachivichik at SolstenXP at 264 -6116. Sincerely, David Hall CEO — Cook Inlet Energy 4141 8 Street, Suite 302, Anchorage, Alaska 99503 Phone (907) 677 -6799 or 317 -8239 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 20, 2010 2:05 PM To: 'Barbara Kruk' Subject: RE: Sundry approval needed for Re- Perforation of WMRU#6 (PTD No. 200 -107) Barb, You have verbal approval to re- perforate the well WMRU #6 as outlined in the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Barbara Kruk [ mailto:barb.kruk @cookinlet.net] Sent: Monday, December 20, 2010 2:05 PM To: Schwartz, Guy L (DOA) Subject: Sundry approval needed for Re- Perforation of WMRU #6 (PTD No. 200 -107) Guy, Cook Inlet Energy submitted an Application for Sundry Approval Re- Perforation of WMRU #6 (PTD No. 200 -107) on Thursday December 16,2000. Cook Inlet Energy would like to know the status of this Sundry Request. Do we have approval? Thanks, Barb Cook Inlet Energy, LLC Barbara Kruk Paralegal /Petroleum Tech 601 West 5th Ave, Suite 310 Anchorage, AK 99501 Main Phone: 907 - 334 -6745 x3802 Direct Phone: 907 - 433 -3802 Cell: 907 - 952 -1151 Email: barb.kruk @cookinlet.net I 12/20/2010 Page 1 of 1 ~~ ~ ^ ~ ~ ~ Close Alaska By OGJ editors H{)U5TON, Apr. 5 -Miller Petroleum Inc., Huntsville, Tenn., hiked its Alaska Cook Inlet production to more than 1,100 b/d of oil equivalent with recompletion of the West McArthur River Unit-b well. The well flowed at the rate of 584 hoed after the company replaced tubing and added perforations in previously untapped oil-bearing sands (OGJ Online, Mar. 10, 2010). To access this Article, go to: http://w~vw.ogj,com/ogjlen-usJndea~/article-tools-template.articles.oil-gns-jonranl.explflration- development-2.area-drilling.2010.04.alaska..html ('^ F~(l ~~ b.~.i t. ,c 1 ,• http://www.ogj.com/index/article-tools-template%printArticle/artieles/oil-gas-j ournai/expor... 4/8IZU 1 ft STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS o~~DS6L0t0 MAR ~;~ tl1 call B ArPwwe L'.AITtfIU7i3M1 1. Operations Abandon Repair Well ~ Plug Perforations Stimulate Performed: Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Extension ^ ~ ~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^~ Re-enter Suspended Well ^ 2. Operator Cook Inlet Energy, LLC. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^~ Exploratory 200-107 3. Address: 4141 B Street, Suite 302, Anchorage, Alaska Stratigraphic^ Service ^ .API Number: 99503 50-133-20494-0000 7. Property Designation (Lease Number): ~ 8. Well Name and Number: ADL 0359111 West McArthur River Unit #6 9. Field/Pool(s): West McArthur River Oil Pool 10. Present Well Condition Summary: Total Depth measured 14,955' feet Plugs (measured) N/A feet true vertical 9,946' feet Junk (measured) N/A feet Effective Depth measured 14,876' feet Packer (measured) 14,002' feet true vertical 9,718' feet (true vertical) 8,993' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 20" 119' 119' N/A N/A Surface 2,204' 13-3/8" 1,926' 1,718' - - 5,020 psi 2,260 psi Intermediate 6,638' 9-5/8" 7,504' 5,186' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-5/8" 13,342' 8,818' 6,890 psi 4,790 psi Production Liner 1,748' 5-1/2" 14,956' 9,946' 7,740 psi 6,280 psi Perforation depth: Measured depth: 14,116' - 14,670' rr~, n ~~,, ,A,°.!' ~~~ H ~ ;1 ~ L ~ ~ is . True Vertical depth: 9,094' - 9,547' Tubing (size, grade, measured and true vertical depth): 2-7/8" L-80 14113' 9090' Packers and SSSV (type, measured and true vertical depth): Baker F-1 Packer 14,002' 8,993' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 400 94 585 55 4000 Subsequent to operation: 585 137 536 50 3700 13. Attachments: .Well Class after work: Copies of Logs and Surveys Run Wireline Logs Exploratory^ Development^~ Service ^ Daily Report of Well Operations Yes .Well Status after work: Oil Q Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~~ Contact 907-334-6745 Printed Name David Hall Title CEO c ~ Signature ~ Phone 907-334-6745 Date 3/29/2010 Form 10-404 Revised 7/2009 RBDMS APR 0 2 20ni °~'~ Submit Original Only 01!07!2010 10:28 9072767542 ~ AOGCC ~ PAGE 02 ~,~r ~-- sTArE of ALASKA +sla~>Rro ~ [~O~ ALASKA OIL AND GiAS CONSERVATION COMMISSION. ~~ l ~3{ APPLICATbN FOR SUNDRY APPRCVAL3 ~ `~nj 1. Typs d R~inC A~rtdon BYrprM OpettttlwMi ahutdoant PrrAe~ah tMrwr O0t1I ~-~0 © ~kv~ ® ~? ^ ~ Thrt~ 0~1ubn ~++n0. avwvvad p~+rn ^ Pup 7uwnY ® P llov- Pool (~ R;aotthr huop~wYd WrN Q ~~' ~. Cun+Mtt 1111Y ChM: Patnit to DrM t~nbor cook (fit Dowh~nan! Q , b pb~AOryr (~ 20..A07 . 9. xdati.s; euapr.pl~ ^ s .tila. © A*I Irt.ttd.r: 4'141 @ N.. st4h ~ litnot+srao., roc as~oa iol~.ooa4.peM T. k p~laatlno, aksar! oporotal~ in p~fo? aPMtod by 0w aP~t ee ewMt 0. Vuop Nrna and t~N.n.6w: P~t~PMlY IM Wll~lr OMIt1a1M1Ap er landown~hfp dl0rgas: tWA sa~ro ~oPOon Te.~ttr.d~ Yeas 0 Ro O w. MoMlwr ~nwr tlrtttre • Prover lo. la0 pq: ~~. wr`a~w1t1 ' 100' . w . ~ ~~ wwsarrw~.l. oaNelxitoN wlrw utr ~~.~yr.o Tehl DoOMi MD oEtl D~lh TVD pq: , fIMo1M DMMt MD day 1 aY1: t~luoa 0-~+rortl: ~t~ 14022 l0ta l 80111 NM OwM+O , ~, pl 0~ Ilo TVD ~o Caflduoter 100' 20" 110' ' 110' M/A 01aa 0~ 7.104' 13~IP 1,020' 1.710' 0,Of0 poE ~ pv 1^a"r,Mdldo 4,q0' 04110" 7,000 0.10r aefe p.i 4,700 pMi ar.rnt~.ts lbtor ~' 7.01lr• 11,342' 0.s9r ead P~ 4.T00 pN 1.740' 0.1rr 14,00y' 0.s4r 7.740 p N 0,7~e v.l htk+tolbn W (1t): PrffAMtle11 Oq: Tubielp 8hto' Glltiadr. ~ 14„140'-14,100', ~ `0,120'•0137', 2T17" 1410 >~~• 14~100'~t4,i~', 0.1!10'•0,010', f,2,!!' 14~207'~14~0', 0.712', 0,2es. 14.100'~14,i14'. l,7MS 0,270'• 14.i2'1'rt4,M0'~ 0.201'. 0,3er- 14r402'd4,000, 0,441•, o,ao~- 14.wr•a4,~ro~ st.Nr anal ss0v tioloNS and wQ: IOMtat• 4000'P', Ob sssv /~ ~ Pb at +4,eM'lI~N0,St30~TYD . oawrtpgott tunntry et Prepoal [~] 14. wui wont oaaaa op«.Yoao ~ ^ ssoP t p >~plonemy Q ~ ®~ a«wo. ^ t . o0n,.lad n.a #or -; 10. wal ~tw aMr propoMe ~ c~nrrov..aa,a: ' oq p' oM ^ ~ Aur+don.d O ,Sppagd: Dare!: wAQ ^ GINJ ^ ,MINd Q ,MOSPI, ^ Ooenndtden .: t0, I CaflNy- tfat tht teepohq plea and aorraot to tl1r boot enyr Ce p 2'hNA I+hM !!1.0T46 PAMOd Nana Dwld !W T~ /m~ -r~0 - ~D 334.074E coot t,es~ onl~r CondltlofM of ilppPDV/1: MoWj/ GertNniMiOn !0 tll~t a wpnst~npqur tt1,y vllln!!K N - !1 eN11b01. . j ~ t . '- Pk-0 lY Q dOP Tat ~ Moohanioai InlaOdty Tact ^ Laoatia+ y'~"~t `~1 GIM-ana ^ . , . Gf+oe ~~~~ ~+~ ~ ~ ~D 3,60 ~f.-~ . - ~ J sva~uanc Form Raqulrad: I a ,~ ~ ... p0010NER THE COM1A~f08tON Die: ~~~d/r • _ Cook Inlet Energy_ WMRU #6 Completion 20" 133#, L-80 BTC @119' MD, 119' TVD 13 3/8" 68#, L-80 BTC @ 1926' MD, 1718' TVD TOC @ 7,317' 9 5/8" 47#, L-80 BTC @ 7504' MD, 5166' TVD TOC @ 13,131' MD • 7-5/8" 29.7#, L-80 Hyd 521 - OPTI SI. Sleeve with X profile @ 13,964'MD @ 13,342' MD, 8618' ND Weatherford Standing Valve Seat @ 13,968' MD, Min ID - 2.25". Backer Model F-1 Packer @ 14,002' MD Backer Model F-1 Packer @ 14,068' MD 2-7/8" L-80, 6.5# Tbg Tail @ 14,113' MD Perforations: 14,116' - 14,670" MD Top of Fish @ 14,347' MD (Spent TCP Guns) 5-1/2" 17#, L-80 Hyd 521 14,955' MD, 9,946' TVD u • WMRU #6 COMPLETION SUMMARY Date 3/21/2010 9:07 AM MRF COOk ~rl~et EnE'Tgy WELL : WEST McAURTHER RIVER #6 TUBING SIZE/GRADE/THREAD: 2-718" L80 8rd EUE TUBING wt/ft: 6.5# / ft Middle of Baker F-1 Packer(s): 14,068' 8~ 14,003' KB to Top of Tbg. Hanger: 13.03' KB to Grd Level 15.10' Smallest ID 8~ Depth' 2.250" @ 13968.38' Connections Jt# ITEM Top Bottom OD ID LENGTH TOP BOTTOM Mule Shoe (WLEG) EUE n/a 3.66 2.441 0.71 14,112.16 14,112.87 1 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.88 14,080.28 14,112.16 Seal Bore Crossover Baker EUE 4.43 2.460 0.57 14,079.71 14,080.28 Seal Bore Extension Baker Baker 3.76 3.000 9.35 14,070.36 14,079.71 B-Guide Baker Baker 4.56 3.000 0.57 14,069.79 14,070.36 #1 Baker Model F-1 Packer n/a Baker 4.55 3.000 1.79 14,068.00 14,069.79 Seal Assembly (8.54') w/WLEG EUE WLEG 2.99 2.375 0.00 14,068.00 14,068.00 Stick-up n/a n/a 2.99 2.375 0.50 14,067.50 14,068.00 Locator/Snap Latch EUE n/a 3.50 2.375 0.70 14,066.80 14,067.50 2 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 14,035.15 14,066.80 Pup Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 10.16 14,024.99 14,035.15 Pup Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 10.12 14,014.87 14,024.99 XO SBE EUE 4.438 2.450 0.57 14,014.30 14,014.87 Seal Bore Extension SBE SBE 3.750 3.000 9.38 14,004.92 14,014.30 #2 Baker Model F-1 Packer n/a SBE 4.500 3.000 2.35 14,002.57 14,004.92 Seal Assembly (9.54') wIWLEG Baker WLEG 3.000 2.375 0.00 14,002.57 14,002.57 Stick-up n/a n/a 3.000 2.375 0.50 14,002.07 14,002.57 Locator/Snap Latch EUE Baker 4.000 2.375 0.70 14,001.37 14,002.07 3 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 13,969.69 14,001.37 Weatherford Standing Valve Seat RTS-8 EUE 3.500 2.250 1.31 13,968.38 13,969.69 OPTI Sliding Sleeve RTS-8 RTS-8 3.169 2.313 3.98 13,964.40 13,968.38 XO EUE RTS-8 3.500 2.367 1.00 13,963.40 13,964.40 4 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 13,931.71 13,963.40 5 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 13,900.03 13,931.71 6 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 13,868.36 13,900.03 7 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 13,836.67 13,868.36 8 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 13,805.02 13,836.67 9 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 13,773.32 13,805.02 10 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 13,741.68 13,773.32 11 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 13,709.96 13,741.68 12 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 13,678.29 13,709.96 13 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 13,646.64 13,678.29 14 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 13,614.97 13,646.64 15 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 13,583.27 13,614.97 16 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 13,551.55 13,583.27 17 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 13,519.93 13,551.55 18 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 13,488.23 13,519.93 19 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 13,456.52 13,488.23 20 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 13,424.84 13,456.52 21 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 13,393.19 13,424.84 22 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 13,361.57 13,393.19 23 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 13,329.88 13,361.57 24 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 13,298.23 13,329.88 25 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 13,266.56 13,298.23 26 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 13,234.90 13,266.56 27 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.67 13,203.23 13,234.90 28 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 13,172.23 13,203.23 29 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 13,140.59 13,172.23 WMRU #6 COMPLETION SUMMARY Date 3/21/2010 30 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 13,108.89 13,140.59 31 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.94 13,077.95 13,108.89 32 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 13,046.31 13,077.95 33 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 13,014.65 13,046.31 34 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 12,983.00 13,014.65 35 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 12,951.34 12,983.00 36 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 12,919.72 12,951.34 37 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 12,888.07 12,919.72 38 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 12,856.48 12,888.07 39 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 12,824.76 12,856.48 40 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,793.12 12,824.76 41 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 12,761.43 12,793.12 42 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,729.79 12,761.43 43 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 12,698.16 12,729.79 44 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 12,666.56 12,698.16 45 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.97 12,635.59 12,666.56 46 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 12,603.90 12,635.59 47 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.04 12,572.86 12,603.90 48 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.74 12,541.12 12,572.86 49 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.61 12,509.51 12,541.12 50 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,477.87 12,509.51 51 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 12,446.22 12,477.87 52 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 12,414.64 12,446.22 53 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 12,382.96 12,414.64 54 Joint 2-7/8" 6.5# L-80 Tb EUE EUE 2.875 2.440 31.61 12,351.35 12,382.96 55 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,319.71 12,351.35 56 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 12,288.05 12,319.71 57 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 12,256.40 12,288.05 58 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 12,224.73 12,256.40 59 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 12,193.08 12,224.73 60 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 12,161.41 12,193.08 61 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,129.77 12,161.41 62 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 12,098.14 12,129.77 63 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 12,066.50 12,098.14 64 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 12,035.50 12,066.50 65 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.01 12,004.49 12,035.50 66 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 ..11,972.84 12,004.49 67 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 11,941.19 11,972.84 68 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 11,909.50 11,941.19 69 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 11,877.81 11,909.50 70 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 11,846.10 11,877.81 71 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 11,814.44 11,846.10 72 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 11,782.77 11,814.44 73 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 11,751.11 11,782.77 74 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 11,719.44 11,751.11 75 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 11,687.79 11,719.44 76 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 11,656.15 11,687.79 77 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 11,624.50 11,656.15 78 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 11,592.79 11,624.50 79 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 11,561.09 11,592.79 80 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.77 11,529.32 11,561.09 81 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 11,497.68 11,529.32 82 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 11,466.02 11,497.68 83 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 11,434.35 11,466.02 84 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 11,402.66 11,434.35 85 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 .31.71 11,370.95 11,402.66 86 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.69 11,339.26 11,370.95 87 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 11,307.58 11,339.26 • WMRU #6 COMPLETION SUMMARY Date 3/21/2010 88 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.01 11,276.57 11,307.58 89 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 11,245.55 11,276.57 90 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 11,213.85 11,245.55 91 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 11,182.20 11,213.85 92 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 11,150.54 11,182.20 93 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 11,118.88 11,150.54 94 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 11,087.23 11,118.88 95 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 11,055.64 11,087.23 96 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 11,023.95 11,055.64 97 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,992.28 11,023.95 98 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.81 10,961.47 10,992.28 99 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,929.80 10,961.47 100 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 10,898.14 10,929.80 101 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 10,866.45 10,898.14 102 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,834.78 10,866.45 103 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 10,803.16 10,834.78 104 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 10,771.52 10,803.16 105 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,739.85 10,771.52 106 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 10,708.21 10,739.85 107 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,676.54 10,708.21 108 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 10,644.83 10,676.54 109 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 10,613.11 10,644.83 110 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.01 10,582.10 10,613.11 111 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 10,550.40 10,582.10 112 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 10,518.77 10,550.40 113 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875. 2.440 31.66 10,487.11 10,518.77 114 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,455.44 10,487.11 115 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 10,423.81 10,455.44 116 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 10,392.09 10,423.81 117 Joint 2-7/8" 6.5# L-80 Tbg EUE -EUE 2.875 2.440 31.68 10,360.41 10,392.09 118 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,328.74 10,360.41 119 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 10,297.11 10,328.74 120 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 10,265.43 10,297.11 121 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 10,233.76 10,265.43 122 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 10,202.05 10,233.76 123 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 10,170.36 10,202.05 124 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.73 10,138.63 10,170.36 125 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 10,107.01 10,138.63 126 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 10,075.32 10,107.01 127 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 10,043.66 10,075.32 128 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 10,011.95 10,043.66 129 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,980.28 10,011.95 130 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.61 9,948.67 9,980.28 131 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 9,916.98 9,948.67 132 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.73 9,885.25 9,916.98 133 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,853.58 9,885.25 134 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 9,821.93 9,853.58 135 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 9,790.23 9,821.93 136 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 9,758.52 9,790.23 137 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,726.85 9,758.52 138 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 9,695.22 9,726.85 139 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.80 9,663.42 9,695.22 140 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 9,631.71 9,663.42 141 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 9,600.02 9,631.71 142 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,568.35 9,600.02 143 Joint 2-7/8" 6.5# L-80 Tbg .EUE .875 2.440 31.59 9,536.76 9,568.35 144 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.62 9,505.14 9,536.76 145 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 9,473.50 9,505.14 WMRU #6 COMPLETION SUMMARY Date 3/21/2010 146 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 9,441.80 9,473.50 147 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 9,410.15 9,441.80 148 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 9,379.13 9,410.15 149 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,347.46 9,379.13 150 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,315.79 9,347.46 151 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 9,284.16 9,315.79 152 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 9,252.58 9,284.16 153 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 9,220.90 9,252.58 154 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 9,189.88 9,220.90 155 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 9,158.30 9,189.88 156 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 9,126.63 9,158.30 157 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.61 9,095.02 9,126.63 158 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 9,063.31 9,095.02 159 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 9,031.59 9,063.31 160 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 8,999.90 9,031.59 161 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.08 8,968.82 8,999.90 162 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 8,937.12 8,968.82 163 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 8,905.45 8,937.12 164 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 8,873.78 8,905.45 165 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 8,842.15 8,873.78 166 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 8,810.51 8,842.15 167 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 8,778.88 8,810.51 168 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 8,747.21 8,778.88 169 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.57 8,715.64 8,747.21 170 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 8,683.96 8,715.64 171 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 8,652.31 8,683.96 172 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 8,620.63 8,652.31 173 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 8,588.92 8,620.63 174 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 8,557.24 8,588.92 175 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 8,525.65 8,557.24 176 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 8,494.01 8,525.65 177 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 8,462.35 8,494.01 178 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 8,430.69 8,462.35 179 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 8,399.01 8,430.69 180 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 8,367.34 8,399.01 181 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 8,335.69 8,367.34 182 Joint2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 8,304.05 8,335.69 183 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.57 8,272.48 8,304.05 184 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.88 8,240.60 8,272.48 185 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 8,208.93 8,240.60 186 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 8,177.30 8,208.93 187 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 8,145.70 8,177.30 188 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 8,114.10 8,145.70 189 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 8,082.48 8,114.10 190 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 29.20 8,053.28 8,082.48 191 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 8,021.62 8,053.28 192 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 7,989.95 8,021.62 193 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 7,958.25 7,989.95 194 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 7,926.58 7,958.25 195 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 7,894.91 7,926.58 196 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 7,863.26 7,894.91 197 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 7,831.62 7,863.26 198 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 7,799.92 7,831.62 199 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 7,768.23 7,799.92 200 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 7,736.65 7,768.23 201. Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31..62 7,705.03 7,736..65 202 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.59 7,673.44 7,705.03 203 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 7,641.76 7,673.44 WMRU #6 COMPLETIO N SUMMARY Date 3/21/2010 204 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.57 7,610.19 7,641.76 205 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 7,578.54 7,610.19 206 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 7,546.88 7,578.54 207 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 7,515.19 7,546.88 208 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 7,483.49 7,515.19 209 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.93 7,452.56 7,483.49 210 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 7,420.91 7,452.56 211 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 7,389.22 7,420.91 212 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 7,357.57 7,389.22 213 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 7,325.98 7,357.57 214 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 7,294.29 7,325.98 215 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 7,262.66 7,294.29 216 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.73 7,230.93 7,262.66 217 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 7,199.21 7,230.93 218 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 7,167.53 7,199.21 219 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 7,136.53 7,167.53 220 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 7,104.88 7,136.53 221 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 7,073.88 7,104.88 222 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.57 7,042.31 7,073.88 223 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 7,010.62 7,042.31 224 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 6,978.94 7,010.62 225 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.05 6,947.89 6,978.94 226 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 6,916.24 6,947.89 227 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 6,884.53 6,916.24 228 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 6,852.87 6,884.53 229 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,821.20 6,852.87 230 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 6,789.57 6,821.20 231 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,757.90 6,789.57 232 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 6,726.20 6,757.90 233 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 6,694.54 6,726.20 234 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 6,662.91 6,694.54 235 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 6,631.26 6,662.91 236 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 6,600.24 6,631.26 237 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 6,569.24 6,600.24 238 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 6,537.55 6,569.24 239 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 6,506.55 6,537.55 240 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,474.88 6,506.55 241 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 6,443.20 6,474.88 242 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,411.53 6,443.20 243 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.03 6,380.50 6,411.53 244 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.98 6,349.52 6,380.50 245 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 6,317.88 6,349.52 246 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 6,286.25 6,317.88 247 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,254.58 6,286.25 248 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 6,222.90 6,254.58 249 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 6,191.88 6,222.90 250 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 6,160.21 6,191.88 251 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 6,128.59 6,160.21 252 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 6,096.89 6,128.59 253 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 6,065.30 6,096.89 254 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 6,033.62 6,065.30 255 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 6,001.90 6,033.62 256 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 5,970.22 6,001.90 257 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 5,938.55 5,970.22 258 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 5,906.89 5,938.55 259 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 30.98 5,875.91. 5,906.89 260 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.66 5,844.25 5,875.91 261 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 5,812.53 5,844.25 WMRU #6 COMPLETIO N SUMMARY Date 3/21/2010 262 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 5,780.84 5,812.53 263 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 5,749.14 5,780.84 264 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 5,717.42 5,749.14 265 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 5,685.77 5,717.42 266 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 5,654.12 5,685.77 267 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 5,623.12 5,654.12 268 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.98 5,592.14 5,623.12 269 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 5,560.50 5,592.14 270 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 5,528.88 5,560.50 271 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 5,497.22 5,528.88 272 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 5,465.50 5,497.22 273 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.03 5,434.47 5,465.50 274 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 5,402.77 5,434.47 275 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 5,371.08 5,402.77 276 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 5,339.48 5,371.08 277 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 5,307.78 5,339.48 278 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 5,276.12 5,307.78 279 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 5,244.44 5,276.12 280 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 5,213.44 5,244.44 281 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 5,181.76 5,213.44 282 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 5,150.10 5,181.76 283 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 5,118.43 5,150.10 284 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 5,086.80 5,118.43 285 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 5,055.13 5,086.80 286 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 5,023.45 5,055.13 287 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 4,991.83 5,023.45 288 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 4,960.20 4,991.83 289 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 4,928.52 4,960.20 290 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 4,896.85 4,928.52 291 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.10 4,865.75 4,896.85 292 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 4,834.09 4,865.75 293 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 4,802.41 4,834.09 294 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 4,770.78 4,802.41 295 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 4,739.09 4,770.78 296 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.03 4,708.06 4,739.09 297 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.03 4,677.03 4,708.06 298 Joint 2-7/8" 6.5# L-80 Tbg EU.E EUE 2.875 .2.440 31.65 4,645.38 4,677.03 299 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 4,613.69 4,645.38 300 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 4,582.05 4,613.69 301 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 4,550.40 4,582.05 302 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 4,518.74 4,550.40 303 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 4,487.08 4,518.74 304 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.96 4,456.12 4,487.08 305 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 4,424.48 4,456.12 306 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 4,392.78 4,424.48 307 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 4,361.10 4,392.78 308 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 4,329.46 4,361.10 309 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 4,297.81 4,329.46 310 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 4,266.16 4,297.81 311 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 4,234.50 4,266.16 312 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 4,202.85 4,234.50 313 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 4,171.17 4,202.85 314 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 4,139.47 4,171.17 315 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 4,107.83 4,139.47 316 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 4,076:16 4,107.83 317 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.68 4,044.48 4,076.16 318 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 30.98 4,013.50 4,044.48 319 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 3,981.86 4,013.50 i WMRU #6 COMPLETI ON SUMMARY Date 3/21/2010 320 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 3,950.18 3,981.86 321 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 3,918.51 3,950.18 322 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 3,886.86 3,918.51 323 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 3,855.18 3,886.86 324 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 3,823.56 3,855.18 325 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,791.86 3,823.56 326 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 3,760.18 3,791.86 327 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 3,728.55 3,760.18 328 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.76 3,696.79 3,728.55 329 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 3,665.14 3,696.79 330 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 3,633.47 3,665.14 331 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.61 3,601.86 3,633.47 332 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 3,570.22 3,601.86 333 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,538.52 3,570.22 334 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 3,506.86 3,538.52 335 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.88 3,474.98 3,506.86 336 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 3,443.33 3,474.98 337 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 3,411.70 3,443.33 338 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 3,380.04 3,411.70 339 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 3,348.37 3,380.04 340 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 3,316.68 3,348.37 341 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,284.98 3,316.68 342 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 3,253.33 3,284.98 343 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 3,221.70 3,253.33 344 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,190.00 3,221.70 345 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,158.30 3,190.00 346 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 3,126.60 3,158.30 347 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 3,094.92 3,126.60 348 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 3,063.24 3,094.92 349 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 3,031.59 3,063.24 350 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 2,999.91 3,031.59 351 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 2,968.28 2,999.91 352 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 2,936.58 2,968.28 353 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 2,904.90 2,936.58 354 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.92 2,873.98 2,904.90 355 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 2,842.38 2,873.98 356 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 2,810.80 2,842.38 357 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 2,779.15 2,810.80 358 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 2,747.49 2,779.15 359 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 2,715.89 2,747.49 360 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 2,684.23 2,715.89 361 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 2,652.60 2,684.23 362 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 2,620.92 2,652.60 363 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 2,589.22 2,620.92 364 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 2,557.62 2,589.22 365 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 2,526.02 2,557.62 366 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 2,494.36 2,526.02 367 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.73 2,462.63 2,494.36 368 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 2,431.63 2,462.63 369 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.59 2,400.04 2,431.63 370 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 2,368.38 2,400.04 371 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 2,336.71 2,368.38 372 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 2,305.06 2,336.71 373 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 2,273.38 2,305.06 374 - Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 2,241.78 2,273.38 375 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.67 2,210.11 2,241.78 376 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.68 2,178.43 2,210.11 377 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 2,146.78 2,178.43 WMRU #6 COMPLETION SUMMARY Date 3/21/2010 378 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 2,115.78 2,146.78 379 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.61 2,084.17 2,115.78 380 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 2,052.48 2,084.17 381 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.05 2,021.43 2,052.48 382 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 1,989.73 2,021.43 383 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.04 1,958.69 1,989.73 384 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 1,927.01 1,958.69 385 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 1,895.37 1,927.01 386 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 1,863.66 1,895.37 387 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.52 1,832.14 1,863.66 388 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 1,800.45 1,832.14 389 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 1,768.82 1,800.45 390 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 1,737.13 1,768.82 391 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 1,706.11 1,737.13 392 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 1,674.43 1,706.11 393 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.99 1,643.44 1,674.43 394 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 1,611.74 1,643.44 395 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 1,580.03 1,611.74 396 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 1,549.03 1,580.03 397 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 1,517.35 1,549.03 398 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 1,485.68 1,517.35 399 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 30.04 1,455.64 1,485.68 400 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 1,424.62 1,455.64 401 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 1,392.94 1,424.62 402 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 1,361.29 1,392.94 403 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.61 1,329.68 1,361.29 404 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 1,298.02 1,329.68 405 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 1,266.42 1,298.02 406 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 1,235.42 1,266.42 407 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.00 1,204.42 1,235.42 408 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 1,172.72 1,204.42 409 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 1,141.10 1,172.72 410 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 1,109.44 1,141.10 411 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.50 1,077.94 1,109.44 412 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.57 1,046.37 1,077.94 413 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 1,014.66 1,046.37 414 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 983.00 1,014.66 415 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.62 951.38 983.00 416 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.67 919.71 951.38 417 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 888.11 919.71 418 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 856.41 888.11 419 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 824.71 856.41 420 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 793.03 824.71 421 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 761.31 793.03 422 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 729.66 761.31 423 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 697.96 729.66 424 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 666.24 697.96 425 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.69 634.55 666.24 426 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.58 602.97 634.55 427 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 571.34 602.97 428 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 539.64 571.34 429 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.02 508.62 539.64 430 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 476.92 508.62 431 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.64 445.28 476.92 432 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 413.63 445.28 433 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.63 .382.00 413.63 434 Joint 2-7/8" 6.5# L-80 Tbg EUE .875 2.440 31.60 350.40 382.00 435 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.70 318.70 350.40 WMRU #6 COMPLETION SUMMARY Date 3/21/2010 436 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 287.02 318.70 437 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.72 255.30 287.02 438 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.60 223.70 255.30 439 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.65 192.05 223.70 440 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.68 160.37 192.05 441 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.71 128.66 160.37 442 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.63 97.03 128.66 443 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.66 65.37 97.03 444 Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 31.55 33.82 65.37 Pup Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 6.12 27.70 33.82 Pup Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 10.12 17.58 27.70 Pup Joint 2-7/8" 6.5# L-80 Tbg EUE EUE 2.875 2.440 3.70 13.88 17.58 Vetco Tubing Hanger EUE EUE 10.750 2.407 0.85 13.03 13.88 AWS #1 13.03' RKB to LDS 13.03 (0.00) 13.03 BHA Total Length 14112.87 Notes: #1 Baker F-1 packer was set on SLB a-line but failed to test after landing the completion tubing. Pulled tubing and set another Baker F-1 packer at 14002' on tubing then re-ran 2-7/8" completion string. AWS #1 RKB to LDS = 13.03' to Grd Level 15.10' Ori final KB to GL for ALL to references is 29.90' _~ ~~ Cook Inlet Energy_ West McArthur River Unit #6 Operation Summary U February 27, 2010 -Rig up rig floor for BOP test. Test BOPE. Test witnessed by AOGCC~s Bob Noble. RU Pollard slickline, pull jet pump. Continue to rig up. February 28, 2010 -Rig up and work on punch list. RU to circulate total well volume with Super Slick added to water. Pull on tubing, came free at 118K. LD hanger and pups. Pull seal assembly from Baker F-1 packer. POOH, LD tubing. March 1, 2010 -POOH LD tubing. Found 2 holes in joint # 115 and holes in joint # 372. Finish POOH LD tubing. Clear area of tubing. Load 12 DC~s, new mud motor, jars and bumper sub. Strap, drift and PU/MU Baker packer mill, DC~s, jewelry and RIH. Load P-110 tubing on pipe racks. March 2, 2010 -RIH with 317 joints of P-110 tubing. RIH with 132 joints of 2-7/8"drill pipe. Tag up 10' in on last joint. RU to wash to top of the packer. March 3, 2010 -RIH with packer mill, wash to top of packer at 14,094" MD and mill the same. Pump 35 bbls sweep, chase packer and guns to bottom. Drop steel ball, shear POS, CBU. POOH with milling assembly. Service rig. March 4, 2010 -POOH with milling assembly. BD/LD same. PU/MU fishing spear assembly. TIH, washing joint #142 DP to top of fish, add 1 more single, set 10K on fish to latch. LD 1 single DP, continue POOH 20 stands to get out 5-1/2" liner. Observe well and take weights. POOH with fish to 11,306'. March 5, 2010 -POOH with packer fish, LD fish and fishing tools. Pull bushing, set test plug. MU test joint and floor valves. Test BOPE. .March 6, 2010 -Finish testing BOPE. Test witness waived by AOGCC~s Jim Regg. MU fishing BHA. RIH to top of pert gun fish and latch on. Jar on fish to 145K and pull up to 160K without success. Back off fish and POOH. March 7. 2010 -POOH with fishing assembly, LD same. MU casing scraper BHA, TIH with scraper assembly. March 8, 2010 - TIH to 14,328', observe well. POOH to 13,100' to bring scraper up out of 5-1/2" liner. TIH back to 14,328', mix 80 bbls of Flowzan sweep, pump all the way around. Pump 60 gal biocide and spot at 14,328'. POOH to 6,062'. March 9, 2010 -Continue POOH from 6,062' to mule shoe. LD XOs and scraper assembly. LD 7 joints of DP below scraper. RIH with DC~s and lay down. RIH with DP and POOH, LD. March 10, 2010 -RIH with 60 stands of P-110 tubing and POOH, LD. ND flow lines and flow nipple, NU shooting flange. RU SLB, RIH with 3-3/8" PowerJet, 3406, 6spf gun. Perforate 14,116'-14,128' interval. POH with guns and RD SLB. RD shooting flange and RU drilling flow nipple and flow lines. March 11, 2010 - MU packer and mule shoe on 1 joint of 2-7/8" tubing. MU to SLB Wireline, RIH. Correlate packer depth and set with TOP at 14,067' MD/9,051' TVD. POH with SLB and RD same/ RIH with P-110 work string and POH LD singles, loading on trailers. Pull wear ring. RU Weatherford power tongs. MU seal assembly on bottom of 1 tubing joint with standing valve/sliding sleeve on top of same joint. Load pipe rack to capacity with 92 joints, pull box protectors and strap. March 12. 2010 -Continue RIH with 2-7/8" production tubing to #444 joint. PU joint 445, pump down slacking off. PU joint 446, pump down to packer. Shut off pump, stab in seal assembly, space out. LD joint 445 and 446. MU 4 pup joints and hanger. Land hanger, RD Weatherford and RU to test annulus. March 13, 2010 -Test packer to 1,000 psi, bled off, try again, still leaking. RU Pollard slickline, drop standing valve. Check for surface leaks. Re-test and chart. RIH with slickline, set standing valve. Test tubing to 4,500 psi - OK. Re-test annulus and chart -still bleeding off. Pull tubing hanger, check space out - OK. LD hanger. RIH with slickline, open sliding sleeve. RD slickline. POOH, LD 3 pup joints, then stand back doubles in derrick. March 14. 2010 -POOH with completion string, standing back doubles in derrick. Cut drilling line, work on twist in drilling line. Finish POOH with string. LD standing valve seat, sliding sleeve, seal assembly and 2 joints of tubing. Test BOPE~s. March 15, 2010 -Finish testing BOPE's. Test witness waived by AOGCC's Lou Grimaldi. RU slickline, make 2 runs to set stop and plug in packer tailpipe at 14,101'. MU Champ packer, RIH. Set Champ packer at 14,025', test annulus above packer -leaking. Test several times, finding surface leaks. Check test pump and grease valves. Test down tubing several times -bleeding off. PU and re-set packer 10' higher, test again - OK. March 16, 2010 -Finish testing annulus. Conduct packer test. Un-seat Champ packer. LD 2 singles. Circulate well for 45 minutes. POOH standing back doubles. RU SL, RIH, retrieve tubing plug and stop. March 17. 2010 -POOH with tubing plug on SL. RIH, retrieve plug stop, POOH. RD SL. Clean rig. PU power swivel, replace Kelly valve with saver sub. LD power swivel. RU SL, make several magnet runs then dummy run through seal bore - OK. RDMO SL. March 18, 2010 -Clean rig. MU packer/seal assembly with space-out joint and pups. RIH with 2-7/8" tubing to 9,560'. • March 19. 2010 - RIH with packer, sting into first packer with seal assembly. Check depths. Drop ball, pressure up, set packer at 14,002' MD. Close pipe rams, test annulus to 1,000 psi. Lost 250 psi over 30 minutes. Check all surface valves and confer with management. Release from packer, POOH with setting tools. Pull wear ring, MU new seal assembly on bottom of single of 2-7/8" tubing. March 20, 2010 -RIH with completion string, space out and land. Test annulus with same results. Drop standing valve, chase and set with SL. Pressure test tubing to 4,500 psi for 30 minutes - OK. Open sliding sleeve. POH, RDMO SL. BO landing joint, set BPV. Start cleaning pits, floor and BOP~s. March 21, 2010 -Move out lay-down machine, pipe racks, SL and tubing management equipment. RD floor tongs. Clean out trip tank. Clean pits and slop tank. RD driller's side of sub, ND BOP's. NU tree, align to power oil line. Test tree, finish connecting lines. Pull BPV, drop jet pump. Bring well #6 on line. FINAL REPORT. WMRU #6 WELL COMPLETION . CUSTOMER: FORCENERGY COUNTRY: USA FlELD: MCARTHUR RIVER QUOTATION N0. - WELL N0. 6 DRAWING N0. - APPROVED BY: - DRAWN BY: KEN LUCKEY DATE: 11 /01 /2000 ~ ~~~ Baker Oil Tools MAX. O.D. MIN. LD. SCHEMATIC DESCRIPTION LENGTH DEPTH TOP NABORS RIG 160 RKB TO LDS 27.34' VETCO GREY TBG HANGER .80' TOTAL DEPTH 27.34' 3.668 2.441 PUP JOINT 3.08 28.14 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL• L-80 3.668 2.441 TUBING 31.22 ; 32.18 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL• L-80 3.668 2.441 PUP JOINT 2.02 63.40 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL: L-80 3.668 2.441 PUP JOINT 6.08 65.42 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL• L-80 3.668 2.441 PUP JOINT 9.97 71.5 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL• L-80 3.668 2.441 TUBING JOINTS 3 -440 13978.49 81.47 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL: L-80 . O TRICO PUMP CAVITY 19.78 14059.96 SIZE: THREADS: MATERIAL: PRODUCT N0: ~ 3.668 2.441 TUBING JOINT 2 31.12 14079.74 SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL: L-80 • 3.668 3.938 4.563 3.750 4.375 3.668 2.441 ' 2.375 3.000 3.000 2500 2.441 TUBING JOINT 2 SIZE: 2-7/8 • THREADS: EUE 8 RD MATERIAL: L-80 O S-22 SNAP RELEASE ASSEMBLY SIZE: 40-30 SEAL ASSY THREADS: EUE 89 RD BOX UP MATERIAL• 4140 18-22 RC 80 KSI PRODUCT N0: 444-55 iNAP LATCH ASSEMBLE IS SPACED OUT 2' IS SET ON WIRELING MEASUREMENTS 'TH IS 20.52' DEEPER THAN WIRELINE O F-1 RETAINER PRODUCTION PACKER SIZE: 45-30 MATERIAL• 4140 18-22 RC 80 KSI PRODUCT N0: 413-06 O SEAL BORE EXTENSION 40-30 SIZE: 30 THREADS: MATERIAL• 4140 18-22 RC PRODUCT N0: 499-40 O CROSSOVER SUB SEALHORE SIZE: 40-30 MATERIAL• 4140 18-22 RC 80 KSI PRODUCT NO: 299-69 TUBING SIZE: 2-7/8 THREADS: EUE 8 RD MATERIAL: L-80 O BALANCED ISOLATION TOOL SIZE: THREADS: MATERIAL• PRODUCT N0: O TDF HOUSING SIZE: MATERIAL• PRODUCT N0: O WIRELINE ENTRY GUIDE SIZE: THREADS: MATERIAL: PRODUCT N0: DEPTH BOTTOM 31.12 14079.74 3.82 4110:85 14114.78 1228 2.36 9.32 .60 3220 2.60 260 .85 14106.54 I 14140.98 I 14140.98 14143.58 14144.43 _ ; Cook Inlet Energy_ March 29, 2010 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 Dear Mr. Seamount, RE: Well Workover Completion Report Cook Inlet Energy, LLC. PTD No. 200-107 Sundry No. 309-436 Dear Commissioner Seamount, RECENED MAR ~ , Q 210 ~N~ia~008G'mt~.G~a~ieia- Cook Inlet Energy, LLC hereby submits its Well Workover Completion Report for the work performed in working over its WMRU #6 well in West side of Cook Inlet. Please find enclosed the following information for your files: 1) Form 10-404. 2) Approved Sundry for Work Over Operation. 3) Completion Schematic. 4) 2-7/8" L-80 Tubing Tally. 5) Well Operations Summary. 6) Baker Oil Tool Model F-1 Packer Drawing. If you have any questions or require additional information, please contact me at (907) 334-6745 or Alexey Sachivichik at 264-6100. Sincerely, COOK INLET ENERGY, LLC. „~ fcJ~~ David Hall CEO Attachments Cc: Alexey Sachivichik -Fairweather • • w ,g =~ E ~, ~ 4 g ~ ~ ~F ~` ~ ~ ~ ~ f ~ `~ ~ ~ ~ ~ ~ ~~~, t ~~' } ~ ~ ~ a ~i OVERNOR ~ SEAN PARNELL , i ~k ~ „ ~ ~ p y , pY 4 ALASKA OIL A1~TI) GAS 333 W. 7th AVENUE, SUITE 100 ~' s CO1~T5ERQA'1'IO1~T CODIhII551O1Q ANCHORAGE, ALASKA 99501-3539 ~ SF PHONE (907) 279-1433 FAX (907) 276-7542 Mr. David Hall CEO Cook Inlet Energy 4141 B Street, Suite 302 Anchorage, Alaska 99503 Re: W. McArthur River W. McArthur River Oil Pool ~ ~ ~~ W. McArthur River Unit #6 Sundry Number: 309-436 ~~~ JA~~ ~ 201 Dear Mr. Hall: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~~ day of December, 2009 Encl. r~ • • Cook Inlet Energy 4141 8 Street, Suite 302 Anchorage, Alaska 99503 Phone (907) 334-6745 or 317-8239 December 28, 2009 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: WMRU #6 Pull-Replace Tubing operations Dear Mr. Seamount, ~' •}: , ~ ~ C~ ~`~ ~~ 111r~'tr < , f` "~` ~rra `~~ t; rllssr~r; .. ~~ ~~ The West McArthur River Unit #6 is shut in due to leaking 2-7/8'~production tubing. Cook Inlet Energy plans to use the Aurora Well Services Rig # 1 (AWS # 1) to pull the existing completion and run a new completion as outlined in the attached summary workover procedure. In addition, we plan to add perforations to increase production. ~ If you have any questions, please contact me at 334-6745 or Bill Penrose at Fairweather at 264- 6114. Sincerely, ~~~ ~/~ r David Hall CEO -Cook Inlet Energy Attachments: 10-403 Application'for Sundry Approval Summary workover procedure Current completion schematic 3,0`1 ~~ti ~ ~ r ~~~- STATE OF ALASKA ~s~;o/tpo y ALAS OIL AND GAS CONSERVATION COMMISSI• ~~~ APPLICATION FOR SUNDRY APPROVALS a~3 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^/ Waiver ^ Other ^ Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Cook Inlet Energy Development ^ Exploratory ^ 200-107 3. Address: Stratigraphic ^ Service ^ 6. API Number: 4141 B St., Suite 302, Anchorage, AK 99503 50-133-20494-0000 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ^ No ^ W. McArthur River Unit #6 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 0359111 163' W. McArthur River ~! ~ a / 12. PRESENT WELL CONDITION SUMMARY G ,",2,z~ 9 Total Depth MD (ft): Total Depth ND (ft): , Effective Depth MD (ft): Effective Depth TVD (ff): Plugs (measured): Junk (measured): ` 1g95r5 !~~'~` `~~I 14822 9813 N/A N/A ~f° Casing s 2°~ ,t ength ly-ti~~ Size MD TVD Burst Collapse Structural Conductor 103' 20" 119' 119' N/A N/A Surface 2,204' 133/8" ~ 1,926' 1,718' 5,020 psi 2,260 psi Intermediate 6,638' 95/8" 7,504' 5,166' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7518" 13,342' 8,618' 6,890 psi 4,790 psi Production Liner 1,748' 5-1 /2" 14,955' 9,946' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~ 14,146'-14,166', 9,120'-9137', 2-7/8" L-80 14,094' 14,188'-14,258', 9,156'-9,216', 9,223' 14,267'-14,280', 9,232', 9,256'- 14,306'-14,314', 9,263', 9,270'- 14,322'-14,460', 9,301', 9,382'- 14,462'-14,538', 9,441', 9,490'- 14,598'-14,670' 9,549' Packers and SSSV Type: Pkr: Baker 4530 'F', No SSSV Packers and SSSV MD (ft): Pkr at 14,094'MD/9,239'TVD 13. Attachments: Description Summary of Proposal [.,] 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^./ Service ^ 15. Estimated Date for ~ 16. Well Status after proposed work: Commencing Operations: 12/5 008 Oil Q' Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: - WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Hall 334-6745 Printed Name David Hall Title ~~ _~~" o7Jc? CEO Signature f~ Phone Date ` 334-6745 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. "`t .~„ n( Plu I t it ^ BO ~ ~ g n egr y P Test Mechanical Integrity Test ^ Location Clearance ^ j ~„, ~;~( , 1.1 L. I %r ?~ EX ~~ ~ . 1' Other: ~ CS~ ~~ p ~ 'f 'O 3000 ~~•i ~}yi ~~^'~ $$ {~' y~ ty ."II~~fE~ €,1~§ [~ ~eGfi Eau.~e S . +J4~~~e~a~ qq pp eg l~xf~i;ab".~3i~'~E'~sa Subsequent Form Required: ' ~ _, APPROVED BY v Approved by: MMISSIONER THE COMMISSION Date: t~f3 ~ 4~~1~ ~~d'6~~o ~ K ~~ -•r ~\ ~ / ~ ~ Submit in Duplicate • West McArthur Unit #6 Tubing Change-Out Workover Summary Procedure 1. Bleed off gas head in tubing and annulus. 2. Fill tubing and annulus with produced water. (BHP in this well is 1,700 psi.) /'~ 3. Insta112-1/8" BPV in the tubing hanger. 4. Nipple down 3-1/2" production tree. 5. Nipple up 11", 3M riser and 11", 3M BOP stack. Test BOP's to 3,000 psi. f~~ 6. Rig up~WS Rig over well. Pull BPV. ~ ~, 7. Unseat tubing hanger and release 2-7/8" tubing at 5-22 Snap-Release assembly above packer. 8. POOH with tubing and lay down for NORM testing and disposal. 9. M/U packer mill and mud motor on workstring and RIH. Mill packer until slips release. POH. ~,. 10. RIH with packer picker on workstring. Catch packer and POH. 11. RIH w/ 5-1/2" casing scraper to 14,100'. CBU and POH. 12. R/U wireline, make gauge rig /junk basket run to PBTD. POH. 13. M/t16-1/8", 6 SPF perforating guns, RIH and perforate the following interval: 14,116' -14,128' 14. POH, P/U new completion assembly and RIH. 15. Land tubing with packer at + 3,340 and set packer. ~~ 16. Set BPV and N/D BOPE and riser. 17. N/U and test 3-1/8" production tree. . 18. Pull BPV and turn well over to production. WMRU #6 Current Completion Schematic 2 7/8" 6.5# L-80 ~JE Tubing 20" 133#, L-80 BTC 13 3/8" 68#, L-80 BTC 9 5/8" 47#, L-80 BTC 7-5/8" 29.7#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 @ 7504' MD, 5166' TVD Trico Jet Pump @14,060' MD, 9,209'TVD 13,342' MD, 8618' TVD Baker Model F Packer @14,094' MD, 9,239' TVD ?erforations - 6 sp£ 14,146' - 14,166' 14,188' - 14,258' 14,267' - 14,280' 14,306' - 14,314' 14,322' - 14,460' 14,462' - 14,538' 14,598' - 14,670' 955' MD. 9946' TVD • • From: Saltmarsh, Arthur C (DOA) Sent: Monday, March 09, 2009 11:08 AM To: Maunder, Thomas E (DOA); Seamount, Dan T (DOA); Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA); Williamson, Mary J (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); Colombie, Jody J (DOA); Gary Carlson; Norman, John K (DOA); Foerster, Catherine P (DOA); Laasch, Linda K (DOA); IongmereCa~verizon.net Subject: FW: Pacific Energy files chapter-11, it's official!!! FYI. aoo-~o`~ PACIFIC ENERGY RESOURCES LTD. 111 West Ocean Blvd., Suite 1240 Long Beach, California 90802 Telephone: (562) 628-1526; Fax: (562) 628-1536 Files for Chapter ii to Facilitate a Restructuring LONG BEACH, CALIFORNIA, Monday, March 9, 2009 - -Pacific Energy Resources Ltd. (the "Company")(TSX:PFE) announces today that it and its wholly owned subsidiaries have filed voluntary petitions for reorganization under Chapter 11 of the U.S. Bankruptcy Code in the U.S. Bankruptcy Court for the District of Delaware. The filing was precipitated by the dramatic decrease in the market price of oil over the past five months. Combined with the Company's pre-existing level of debt related to past acquisitions and poor capital market conditions, the Company's liquidity and cash flow is insufficient to operate its business and invest in its oil producing assets to increase production. Faced with these constraints, the Company and its subsidiaries filed petitions for reorganization under chapter 11 to facilitate access to an immediate source of liquidity as it works to restructure its debt. In connection with the filing, the Company is seeking customary authority from the Bankruptcy Court that will enable it to continue operating its business in the ordinary course of business. The requested approvals include requests for the authority to make wage and salary payments and continue various benefits for employees. In addition, the Company has negotiated a commitment for $40 million in debtor-in-possession ("DIP")financing. The DIP facility wraps and replaces two of the Company's three asset-based credit facilities and is being provided by the lenders of the two credit facilities that are being replaced. Upon Court approval, the DIP financing combined with the Company's operating revenue will provide sufficient liquidity to fund working capital, meet ongoing obligations and ensure that normal operations continue without interruption during its restructuring. About Pacific Energy Resources Pacific Energy Resources Ltd. is an oil and gas exploration and production company based in Long Beach, California, U.S.A. Additional information relating to the Company may be found on SEDAR at www.sedar.com. The Company's web site is www.PacEnergy.com. ON BEHALF OF THE BOARD OF DIRECTORS • PACIFIC ENERGY RESOURCES LTD. Pacific Energy Resources Ltd. 310 K. Street, Suite 700 Anchorage, AK 99507 Office: 907-258-8600 Fax: 907-258-8601 r~ L David Hall Alaska Operations Manager Main: 907-868-2133 Cell: 907-317-8239 dmhall ~,paceneray.com www.pacener~~om • a a o 0 o SARAH PALIN, GOVERNOR ~SRA OII. Al~TD GA5 333 W. 7th AVENUE, SUITE 100 COI1TSFiRQA'I'IO1~T COA'Il~'IISSIOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 David Hall Production Manager Pacific Energy Resources Ltd 310 K. St. , Ste 700 Anchorage AK 99501 ~~~ ~, Re: W. McArthur River, W. McArthur River Unit #6 Sundry Number: 308-468 ~;_, Dear Mr. Hall: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~,/'-G,~~,4~ Cathy P. Foerster Commissioner DATED this ? day of February, 2009 Encl. ~' RE~EIVE~ r 6q ~ ~~~ ~ STATE OF ALASKA ~ 1 ~~ ALA~OIL AND GAS CONSERVATION COMMIS 008 ~.S APPLICATION FOR SUNDRY APPROVAL DEC 2 3 2 __ 20 AAC 25.280 d „s.,g ~, ,,,,,,,;~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ~~a VIrVU~i3e~{~~~u' ~~' ""'dfAB Alter casing ^ Repair well [~~ Plug Perforations ^ Stimulate ^ Time Extensi~([C~tOrage Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pacific Energy ResourcesLtd Development ^ Exploratory ^ 200-107 3. Address: Stratigraphic ^ Service ^ 8. API Number: 310 K St., Suite 700, Anchorage, AK 99501 50-133-20494-0000 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NIA Spacing Exception Required? Yes ^ No ^ W. McArthur River Unit #6 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 0359111 163' W. McArthur River 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14955 9946 14822 9813 NIA NIA Casing Length Size MD ND Burst Collapse Structural Conductor 103' 20" 119' 119' NIA NIA Surface 2,204' 13-3/8" 1,926' 1,718' 5,020 psi 2,260 psi Intermediate 6,638' 9-518" 7,504' 5,166' 6,870 psi 4,750 psi Intermediate Liner 6,468' 7-518" 13,342' 8,618' 6,890 psi 4,790 psi Production Liner 1,748' S-1/2" 14,955' 9,946' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14,146'-14,166', 9,120'-9137', 2-718" L-80 14,094' 14,188'-14,258', 9,156'-9,216', 9,223'- 14,267'-14,280', 9,232', 9,256'- 14,306'-14,314', 9,263', 9,270'-9,301', 14,322'-14,460', 9,382'-9,441', 9,490' 14,462'-14,538', 9,549' 14,598'-14,670' Packers and SSSV Type: Packers and SSSV MD (ft): Pkr: Baker 4530 'F', No SSSV Pkr at 14,094'MD/9,239'ND 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 18. Well Status after proposed work: Commencing Operations: 12/5/2008 Oil ~ Gas ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Hall 868-2133 Printed Name David Hall Title Production Manager ~~ Date Signature ~ . ~, ~ ~ ~ ~ J • ~ 868-2133 ,~c - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Wg ~ ~~~ Plug Integrity ^ BOP Test ~~ MMechanical Integrity Test ^ Location Clearance ^ Other: ~~~(~ PS l ~~~ ~ T~ S~ v _ ~ ~~ ~i ~ ~ ~ Qt £ ~~Q~ Subsequent Form Required: ~\~ ~ A .~!`~ " J . APPROVED BY ~ ~~ MISSIONER THE COMMISSION Date: ~ COM Approved b~ ,~ 4 Pacific Energy Resources Ltd 310 K Street, Suite 700 Anchorage, Alaska 99501 (907) 868-2133 or 776-7108 Fax: (907) 258-8601 or 776-7119 December 18, 2008 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: WMRU #6 Pull-Replace Tubing operations Dear Mr. Dan Seamount, RE~EIVECJ DEC 2 3 2008 Alaska Oil 8 Gas Cons. Commission Anchorage The West McArthur River Unit # 6 producing at reduced rate due to leaking 2-7/8" production tubing. Pacific Energy plans to use a Cudd 340K hydraulic snubbing unit to pull the existing tubing and run new tubing as outlined in the attached workover procedure. In addition, we plan to add perforations to increase production. While the BOP system associated with this hydraulic unit mainly conforms to the specifications set out in the Commissions regulations, there are two characteristics of the choke and kill part of the system that differ and a waiver is requested to enable the system's use as is. The details of the waiver request are attached. If you have any questions, please contact me at 868-2133 or Natasha Sachivichik at Fairweather at 258-3446. ~,/~ ~~~ Sincerely, ~~/ ~ l°~ David Hall Production Manager -Pacific Energy Resources Ltd. Attachments: 10-403 Application for Sundry Approvals Outline procedure Current completion schematic Proposed completion schematic 13-5/8" SM BOP and snubbing unit Schematic Snubbing Circulation Schematic Detailed waiver rationale. Detailed waiver rationale. At variance with 20 AAC 25.035(e)(4)(H) is that the unit does not have a remotely controlled hydraulic choke and, at variance with 20 AAC 25.035(e)(6)(F), the choke and kill lines contain 1502 unions as well as flanged connections rather than being entirely flanged as required. Choke operation on this unit is via two redundant, manually operated chokes located at the choke manifold. Also, due to the small size, portability and adaptability of the unit, the choke line downstream of the outer choke valve and the kill line downstream of the check valve contain 1502 unions. Please refer to the attached BOP system schematic. It is Pacific Energy's position that the unit's choke and kill system as currently configured is sufficient for work on WMRU # due to the under-pressured character of the reservoir. Before commencing the planned work, the well will be displaced with produced water and will remain full due to the LLC valve. The chance of any pressure being observed at the surface is extremely remote and, even if it did occur, it would be of such low pressure and volume that the existing BOP system could handle it safely. Pacific Energy therefore requests variances from the specifications of 20 AAC 25.035(e) (4)(H) and (e)(6)(F) to utilize the choke and kill system configured as described above and on the attached schematic. ~~~~~~ ~pcc ~cC-~SSC~C~,~ . ~~Sp v.~~~. rc~c~-~cJS ~~ c.~O~cS ~ ~ ~,.r~~ a'~ a0O~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, January 21, 2009 8:26 AM To: 'Bill Penrose' Cc: David Hall; Natasha Sachivichik Subject: RE: WMRU #5 and #6 Tubing Changeouts Bill, Thanks much for confirming this information. Tom Maunder, PE AOGCC From: Bill Penrose [maiito:bill@fairweather.com] Sent: Wednesday, January 21, 2009 8:23 AM To: Maunder, Thomas E (DOA) Cc: David Hall; Natasha Sachivichik Subject: RE: WMRU #5 and #6 Tubing Changeouts Tom, I just spoke with a representative at Cudd. The spread on their hydraulic unit that was used on King Salmon Platform is all Cudd's. The choke and kill connections are ail now flanged and they have a remote actuating panel for the BOPs. It would be appreciated if you would continue processing the tubing change-out Sundry Applications for WMRU #5 and #6, but set aside the requests for BOP system waivers on the two topics mentioned above as they no longer apply. Trrhanks and regards T~CPQ j~~t?114d,° Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, January 14, 2009 11:39 AM To: Bill Penrose Cc: David Hall; Natasha Sachivichik Subject: RE: WMRU #5 and #6 Tubing Changeouts Thanks Bill. I will await your next message. If the equipment "spread" is essentially the same that was used on King, I don't foresee there being a problem. !don't have the information as to what equipment is Cudd's and what is Unoeal/Chevron's. Tom From: Bill Penrose [mailto:bill@fairweather.com] Sent: Wednesday, January 14, 2009 11:32 AM To: Maunder, Thomas E (DOA) Cc: David Hall; Natasha Sachivichik 1 /23!2009 Page 2 of 2 • Subject: RE: WMRU #5 and #6 Tubing Changeouts Tom, Sorry I haven't responded an this earlier. I've been working on getting answers from Cudd on any modifications on their hydraulic unit since we last used it on Osprey Platform. The Cudd supervisor I've talked to is pretty sure they've changed the screwed connections on their choke and kill lines to flanged connections and also that they now have a remote activation panel for the BOPS. He asked for a day or two to verify this with his local hand and I'll get back with you as soon as I hear back from him. Pacific Energy requests that the Commission continue the review and approval process for the two workovers. The tubing patch work performed to date has been unsuccessful and the plan forward is to bring the Cudd hydraulic unit across the Inle# to WMRU as soon as ice conditions in the Inlet permit. As soon as I hear back from Cudd, I'll let you know whether the requested waivers are still needed. Regards, f i~ ~eoytaQe Vice President t Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, January 08, 2009 9:59 AM To: Bill Penrose Subject: WMRU #5 and #6 Tubing Changeouts Bill, When last we spoke/messaged on this proposed work it was determined by Pacific that it would not be possible to start the work until after ice leaves the Inlet. Since it looks like the potential start date is probably into April or May, what is Pacific's desire as to handling the sundries? As you know, the Cudd has been used offshore and there has been a concerted effort to reduce/eliminate screwed connections [hammer unions] on the choke and kill lines and choke manifold. Is that "equipment kit" part of what Cudd will bring to the Pacific work? It is also possible that WMRU #5 and #5 could be considered determined not capable of flowing and that might figure into the requirements, although I do not know for sure. Depending on our discussions, it may be appropriate to withdraw the sundries at this time and re-submit closer to the actual work date. Also, are there any plans to try to accomplish the patching since the heavy work is some months down the road? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 1/23/2009 W. McArthur River Unit #6 Pull and Replace Tubing Procedure 1. Bleed off gas head in tubing and annulus. 2. Fill tubing and annulus with produced water. 3. Insta112/18" BPV in the tubing hanger. 4. Nipple down 3-1/8" production tree. 5. Nipple up 13-5/8" SM riser and 13-5/8" SM BOP stack. Test BOPs to 3,000 psi. 6. Rig up snubbing unit. 7. Pull 2-1/8" BPV. 8. Pull tubing hanger. 9. Release 2-7/8" at 5-22 Snap-Release assembly above packet and pull the tubing. 10. PU and run new 2-7/8" tubing. 11. MU and RIH with 2-1/8", 6SPF perf guns and perforate 14,116'-14,128' MD interval. 12..POOH and rig down wireline equipment. 13. Set BPV. 14. Nipple down 13-5/8" BOPE and riser. 15. Nipple up and test 3-1/8" production tree. 16. Pull BPV. 17. Turn over the well to production. C~ WMRU #6 Current Completion Schematic 2 7/8" 6.5# L-80 EUE Tubing 20" 133#, L-80 BTC ~~ ~~ 13 3/8" 68#, L-80 BTC ~. 9 5/8" 47#, L-80 BTC 7-5/8" 29.7#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 @119' MD, 119' TVD @ 1926' MD, 1718' TVD @ 7504' MD, 5166' TVD Trico Jet Pump @14,060' MD, 9,209'TVD 13,342' MD, 8618' TVD Baker Model F Packer @14,094' MD, 9,239' TVD Perforations - 6 spf: 14,146' - 14,166' 14,188' - 14,258' 14,267' - 14,280' 14,306' - 14,314' 14,322' - 14,460' 14,462' - 14,538' 14,598' - 14,670' 955' M D, 9946' TVD • VVMRU #6 Proposed Completion Schematic 2 7/8" 6.5# L-80 EUE Tubing 20" 133#, L-80 BTC 13 3/8" 68#, L-80 BTC 9 5/8" 47#, L-80 BTC 7-5/8" 29.7#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 @119' MD, 119' TVD @ 1926' MD, 1718' TVD @ 7504' MD, 5166' TVD Trico Jet Pump @14,060' MD, 9,209'TVD 13,342' MD, 8618' TVD Baker Model F Packer @14,094' MD, 9,239' TVD Perforations - 6 sp£ 14,116'-14,128' '~ 14,146' - 14,166' 14,188' - 14,258' 14,267' - 14,280' 14,306' - 14,314' 14,322' - ]4,460' 14,462' - 14,538' 14,598' - 14,670' ..,955' MD, 9946' TVD ~D~ 340kJadc Unit Iift Cap:340,000 s~Cap 170,000 Rotary Cap: 9,700 ffi/Ila 11" Bore ~ific Energy WMRU#6 ,Kid Pf~SSIS"e COntrd, Inc. ~r~oeed I~gy~ Ill~sh'ation Nib i~g on Location December 2008 ~~ Jack Unit 288" s~u-~t&v~B~ 13o.s" v~aric Wurbw nevation 6s3.6a' ~sa.4s~ 29' 23.5' 4" Flavlinetc CucTl#ertrr 45.2" 55.8" 23.5' 33.8" 24" 318" 51VIBCPShadc Swivel Spoo113-5/8" SM Drilling Spool 13-5/8" SM Amur BiOP, 13-5/8" SM 3-12"PipeRa~r~ 13-5/8" SNl BlirrU 9~ 1~ 13-5/$' SM F1owCh-~ssy 11" S1VI 3-12"Pipe Rarr~ 13-5/8" SM 1 340k Jack Unit Lift Cap:340,000 Snub Cap:170,000 Rotary Cap: 9,700 ft/Ibs 11" Bore Standpipe 288" Snub Unit & Work B et --~ •~ n 3.88') 130.8" Work Window ation .88" (57.82') 24" 23.5" 4" Flow Line ud Pits ~=~ low Meter 45.2" ~ 55.8" ff 23.5" Blow Down Line k 3 k 2 k 1 33.8" ~ Kill Line IOMChake ~~ f~ , ' a 192'.7" (16.06') =~ ~ ~ 120" ~~ .r Pacific Energy WMRU#6 Cudd Pressure Control, Inc. Proposed Rigup Illustration Without Rig on Location December 2008 ~• Mud/Gas ,Separator 340k Jack Unit 13/8" 5M BOP Stack Swivel Spool 13-5/8" SM ~t 2" 1592 Weco Fill Line Drilling Spool 13-5/8" SM Annular BOP, 13-5/8" SM 3-1/2"Pipe Ram, 13-5/8" SM Blind/ Shear Ram, 13-5/8" SM Flow Cross, 11" SM o-1 o-2 3-1/2"Pipe Ram, 13-5/8" SM Choke Line o-3 Blow Down ine 5' Spaol, 13-5/8" SM 10' Spool, 13-5/8" SM Well Head Choke Line 7' Spool, 13-5/8" 5M Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 24, 2008 11:29 AM To: 'Bill Penrose' Cc: Natasha Sachivichik; David Hall Subject: RE: WMRU #5 & #6 Tubing Change-Outs ~ ~ `~ ~~ Thanks Bill. We will talk on the sundries in the new year. Tom From: Bill Penrose [mailto:bill@fairweather.com] Sent: Wednesday, December 24, 2008 11:24 AM To: Maunder, Thomas E (DOA) Cc: Natasha Sachivichik; David Hall Subject: WMRU #5 & #6 Tubing Change-Outs Tom, 1 just spoke with David Hall at Pacific Energy. The Inlet has locked up with ice over the past few days sufficiently to prevent the Cudd hydraulic unit from being transported to the West MacArthur Field. There's also been some difficulty encountered in obtaining a second string of tubing on such short notice. The upshot of the matter is that these tubing change-outs will now have to be performed in the Spring after the Inlet breaks up. While the Sundry Approvals are still needed from the Commission for this work, there is no longer pressure to expedite them over the holidays. Nave a Merry Christmas and we can resume efforts on this when everyone is back in the saddle. Regards, $''t~ ~e~vtaae Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 12/24/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: A4aunder, Thomas E (DOA) Sent: Wednesday, December 24, 2008 11:03 AM To: 'Bill Penrose' Cc: David Hall; Natasha Sachivichik Subject: RE: WMcRU #6 (200-107) Bill, et al, Not a problem regarding keeping the sundry in reserve. Tom Maunder, PE AOGCC From: Bill Penrose [mailta:bill@fairweather,com] Sent: Wednesday, December 24, 2008 9:12 AM To: Maunder, Thomas E (DOA) Cc: David Hall; Natasha Sachivichik Subject: WMcRU #6 (200-107) Tom, Pacific Energy is in the process of applying for a Sundry approval to change out the tubing in WMRU #~ with a Cudd hydraulic pulling unit in conjunction with similar work to be performed in WMRU #5. The Commission earlier approved a Sundry Application to attempt a tubing patch in this well. With the failure of the attempted tubing patch operation in #5, it has been decided to not attempt it in #6, opting instead for the tubing change-out with the Cudd unit. The approved 403 is therefore still in effect but is not being utilized. Pacific Energy would like to keep the WMRU #6 tubing patch 403 approval available as an option while applying for the 403 for changing out the tubing. The reason is so the tubing patch work can proceed in case something prevents the Cudd unit option from being utilized. Is this acceptable to the Commission? If not, please let me know how you would like to handle the outstanding approved 403. Thanks and regards, ~i~ ~8tyL4de Vice President /Drilling Manager Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 907-258-3446 12/24/2008 • • a a a a 0 SARAH PAL/N, GOVERNOR CUI~TSER A-~0 ~ ~ I ~ 333 W. 7th AVENUE, SUITE 100 ~L•~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 David Hall FAx (so7) z7sasa2 Production Manager Pacific Energy Resources Ltd 310 K St., Ste 700 ~$~ ~~~ K 2~~~ Anchorage AK 99501 ~ ~ ~ +'/ ~(~® / Re: W. McArthur River Oil Pool, W. McArthur River Unit #6 Sundry Number: 308-443 Dear Mr. Hall: Enclosed is the approved Application for Sund A above referenced well. Please note the conditions of approvalrset o ~ in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person ma not a g a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chaiz- DATED this day of December, 2008 Encl. O~ STATE OF ALASKA l~ 1,~,~t' ALA~OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~ ~~ 1, Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate Waiver ^ Other ^ Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pacific Energy ResourcesLtd Development ^ Exploratory ^ 200-107 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: 310 K St., Suite 700, Anchorage, AK 99501 50-133-20494-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ^ No ^ W. McArthur River Unit #6 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): - ADL 359111 - 163' W. McArthur River v/c..~ipC._ 12. PRESENT WELL CONDITION SUMMARY ~y,.g•d$ Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14962'' 9951' - 1 4875' 9717' WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' N/A N/A Surface 1826' 13-3/8" 1926' 1718' 5,020 psi 2,260 psi Intermediate 7504' 9-5/8" 7504' 5166' 6,870 psi 4,750 psi Intermediate Liner 6056' 7-5/8" 13342' 8618' 6,890 psi 4,790 psi Production Liner 1823' S-1/2" 14955' 9946' 7,740 psi 6,280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14146' - 14670' 9120' - 9549' 2-7/8" L-80 14094' Packers and SSSV Type: Packers and SSSV MD (ft): Pkr: Baker 4530'F', No SSSV Pkr at 14094' MD/9239' TVD 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory [] Development Q - Service ^ 15. Estimated Date for 16. Well Status after proposed work: 12/10/2008 Commencing Operations: Oil Q - Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Hall 868-2133 Printed Name David Hall Title Production Manager Signature ~ f / P ne L DaJte p y7 ~ ~ 8 868-2133 / ~ - c COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ '~'~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: "~ c O APPROVED BY / Approved by: ~ ~/~~ COMMISSIONER THE COMMISSION Date: // Form 10-403 Revised 06/2006 "''° ` ~ Submit in Du licate December 8, 2008 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission - 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re : WMRU #6 Tubing Repair PTD No. 200-107 Dear Mr. Seamount, Pacific Energy Resources hereby submits an Application for Sundry Approval to repair the tubing in the West McArthur River Unit #6 by installing a tubing patch across a hole located via spinner and caliper diagnostic work. We would like to perform this tubing repair as soon as possible, in order to bring the well back onto production. Attached please find a Form 10-403, a summary operations procedure, a current wellbore schematic and spinner overlay plot for this well. If you have any questions, please contact me at 868-2133. Sincerely, ~ j~~~ /'~ David Hall Production Manager Pacific Energy Resources Attachments: Form 404 Report of Sundry Well Operations Summary Operations Procedure Wellbore Schematic Spinner overlay .i s a ` _` ~. ~ ~,... Pacific Energy Resources West McArthur River Unit #6 Summary Tubing Patch Installation Procedure 1. Move in and rig up wireline unit with lubricator. Pressure-test lubricator. 2. Make up 2-7/8" tubing patch on wireline and RIH. 3. Set patch's bottom slips and packer ±10' below the hole in the tubing which is located at ll890'MD. 4. Pull up with the tubing patch's designed overpull and set the patch's top slips and packer +10' above the hole in the tubing which is located at 11870' MD 5. Disconnect the tubing patch running tool from the tubing patch and POH. 6. R/D lubricator and release wireline unit. 7. Place well back on jet pump-assisted production. • WMRU #6 Completion Schematic 2 7/8" 6.5# L-80 EUE ~ ,~ Tubing 20" 133#, L-80 BTC ,~:; 13 3/8" 68#, L-80 BTC 9 5/8" 47#, L-80 BTC 7-5/8" 29.7#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 @ 119' MD, 119' TVD @ 1926' MD, 1718' TVD @ 7504' MD, 5166' TVD Trico Jet Pump @ 14,060' MD, 9,209'TVD 13,342' MD, 8618' TVD Baker Model F Packer @ 14,094' MD, 9,239' TVD Perforations - 6 spf: 14,146' - 14,166' 14,188' - 14,258' 14,267' - 14,280' 14,306' - 14,314' 14,322' - 14,460' 14,462' - 14,538' 14,598' - 14,670' ,955' MD, 9946' TVD 11850 11900 11950 12000 ') ) " --......... .!o.~'I\..~........ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiehe\CvrPgs _I nserts\M ierofi 1m _ Marker.doe (' ~ 8 Z Z Forcenergy Inc November 2, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well Completion Report and Log (Form 10-407) West McArthur River Unit #6 Enclosed is Forcenergy's Well Completion Report and Log for the West McArthur River Unit #6 well. Included are form 10-407, well completion schematic, daily report summary and final directional survey. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. RECEIVED ~.,~,::)v ~3 2000 Alaska 0il & Gas Cons. Commission Anchorage RECE ED Cons. ', I STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED ABANDONED: SERVICE: ..~. .................. 2. Name of Operator 7. Permit Number 'i ''JL ...,....:,.. : Forcenergy Inc. 200-107 ~ /¢,--/. ~O 3. Address 310 K Street, Suite 700 : .............. 8. APl Number .~ :.,. :. :.. Anchorage, Alaska 99501 . 50-133-20494-00; A'&'-- .,' - ' .... '~-"~:-- 'r , 4. Location of well at surface ~, , .% :._ __~_.. , r:.. , 9. Unit or Lease Name. ........................ 2395' FNL, 1337' FWL, S16, T08N, R14W, SM ~l~L~'"~'~"~ ~ Vb ~ West McArthur River Unit At Top Producing Interval 10. Well Number 4S0' FNL, 2430' FWL, S10, T0SN, R14W, SM i;.~0V ! ~2000 NO. 6 At Total Depth 11. Field and Pool 10' FSL, 2360' FWL, S03, T08N, R14W, SM A{amkaOi{ ~' ~%,e ~ -~ , · · & ~ uoria. Comml.sslon West Mc, Arthur River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designa~l~l~rial No. West Mc, Arthur River Pool 163 KB ADL 359111 12. Date Spudded7/23/O0 13' Date T'D' Reached { 14' Date C°mp" Susp°r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°ns9/17/00 10J~/00~p n/a feet MSL 1 22. Type Electric or Other Logs Run Quad Combo I UBI ! RST ! USIT I RFT 23. CASING, LINER AND CEMENTING RECORD S~ ~ lING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SI~_E CEMENTING RECORD AMOUNT PULLED 20" 133# K-55 Surf. 119' driven nla None 13 3/8" 68~ L-80 Surf. 1,926' 17 1/2" 2537 cu it None 9 5~8" 47# L-80 Surf. 7,504' 12 1/4" 1105 cu it None 7 5~8" 29.7 # L-80 7,286 13,342' 8 1/2" 190 cu it None m 5 1/2" 17 # L-80 13,132' 14,955 6 3/4" 258 cuft None 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 14,146' to 14,166' MD (9,120' - 9,137' SSTVD) 3 3/8" 6 spf TCP 2 7~8" 14,094' 14,094' 14,188' to 14,258' MD (9,156' - 9,216' SSTVD) 3 3/8" 6 spf TCP 14,267' to 14,280' MD (9,223' - 9,234' SSTVD) 3 3/8" 6 spf TCP 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14,306' to 14,314' MD (9,256' - 9,263' SSTVD) 3 3/8" 6 spf TCP DEPTH INfI=RVAL (MD) AMOUNT & KIND OF MATERIAL USED 14,322' to 14,460' MD (9,270' - 9,301' SSTVD) 3 3~8" 6 spf TCP n/a 14,462' to 14,538' MD (9,382' - 9,441' SSTVD) 3 3~8" 6 spf TCP 14,598' to 14,670' MD (9,490' - 9,549' SSTVD) 3 3/8" 6 spf TCP 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1012100I Hydraulic jet pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/31100 24 TEST PERIOD :> 2150 503 0 n/a{ Initial Estimat® 234 Flow Tubing Casing Pressure CALCULATED OIL-BBL . GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => _28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. "' No coring was done. Hemlock formation consisting of interbedded sands and conglomerates. _ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate 29. ', 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH SSTVD GOR, and time of each phase. G-Zone 13,494' 8,573' Hemlock Bench 1 14,087' 9,070' Hemlock Bench 2 14,104' 9,084' Hemlock Bench 3 14,186' 9,155' Hemlock Bench 4 14,317' 9,265' Hemlock Bench 5 14,558' 9,457' ~ Hemlock Bench 6 14,676' 9,554' i"-.'"'~ iv/ 7 3 2000 West Forelands 14,797' 9,653' ~a~J[~} O~j & Gas Cms.Co-~J',~}~ss~o~ ~ ' ' A~chorage 31. LIST OF A~ I ACHMENTS Well Schematic, Final Directional Survey 32. I hereby ce~rue and correct to the best of my knowledge Signed Title Drilling Manager Date L 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 space 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 productin 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. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lilt, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL WMRU #6 Completion Schematic 2 7/8" 6.5# L-80 EUE ~ Tubing ~ 20" 133#, L-80 BTC 13 3/8" 68#, L-80 BTC ~ 9 5/8" 47#, L-80 BTC 7-5/8" 29.7#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 RECEIVED ,,'J l 5 2000 Alaska Oil &"--,-" - ' · Anchor~e @119' MD, 119' TVD 1926' MD, 1718' TVD 7504' MD, 5166' TVD @ 13,342' MD, 8618' TVD Perforations - 6 spt': 14,146' - 14,166' 14,188'- 14,258' 14,267' - 14,280' 14,306'- 14,314' 14,322' - 14,460' 14,462' - 14,538' 14,598'- 14,670' 14,955' MD, 9946' TVD Trico Jet Pump ~14,060' MD, 9,209'TVD Baker Model F Packer ~14,094' MD, 9,239' TVD 21-Jul-00 22-Jul-00 23-Jul-00 24-Jul-00 25-Jul-00 26-Jul-00 27-Jul-00 28-Jul-00 West McArthur~aoh,,r. ~ ~nRiver Unit #6 (' DRIVE & WELD 20"- FINAL 50BPF-119' I~I~-'-~UT 'O'F'F @ BTM OF ROTARY TABLE- LAY DOWN 20". RIG DOWN HAMMER-LAY OUT HAMMER-WELD PAD EYES FOR TURNBUCKLES-WELD 3" BALL VALVE- RUN HYD. & ELEC. LINES TO TOP DRIVE-PUT UP FLOW LINE FROM PITS TO SUB BASE-ATTACH TURNBUCKLES- R/U WlRELINE UNIT-CIRC. MUD CLEANING EQUIP.-FILL PITS-SET CMT TANK-CHANGE OUT SMALL AIR TUGGER LINE. TUGGER LINE. CUT & WELD FLOW NIPPLE WHILE FILLING PITS, CHECK FOR LEAKS. INSTALL FILLUP LINE, TUGGER CABLES-INSTALL FLOW LINE SENSOR-REMOVE SCAFFOLD AND BRACES. PTSM-MIX MUD TO SPUD-INSTALL SHAKER SCREEN-STRING GERONIMO LINE, DERRICK CLIMBER. ON STANDPIPE FOR SPERRY-SUN-CONNECT ELECT FOR SPERRY-SUN-SET PIPE RACK PTSM-MAKE UP BIT AND XO SUB TO HWDP-CIRC AND TEST TO 1000~ PSI- CLEAN OUT TO 63' PICK UP 5" DP AND 5" HWDP-RABBIT AND STRAP-TAKE SLIDES OFF SHAKERS-SET BRANDT SHAKER TANK-PICK UP BHA- MAKE UP BHA, WHILE WELDING ON SHAKER TANK- RIH W/MOTOR-CLEAN OUT TO 73'-REWIRE BRANT SHAKER MOTOR DRLG. 17 112" HOLE FROM 63' TO 210'. CIRC. AND PULL OUT OF HOLE TWO STDS. INSTALL MWD IN NMDC AND ORIENT GYRO SURVEY @ 93' -SURVEY W/MWD @ 93' -MAG. INTERFERENCE DRLG. 17 1/2" HOLE FROM 210' TO453' ~ECE~VED GYRO SURVEY @ 356' , DRLG. 17 1/2" HOLE FROM453' TO 539' GYRO SURVEY @ 356' ,~.~,, ,r I~ 3 2000 SET STAND BACK AND WORK ON PUMP AND SLOP TANK CLEAN SLOP TANK. FIX SOLIDS EQUIPMENT. ," aska 0il & Gss Co s. Commission DRLG 539' TO 1337'. A~chorage UNABLE TO RECORD MWD SURVEYS DUE TO MAGNETIC INTERFERENCE. RUNNING GYRO ON SLICK LINE EACH 90' CONNECTION. RECORDING MWD SURVEYS AFTER 1261' DRLG 1261' TO 1354' DRLG 1354' TO 1910' MWD AT 90' STATIONS. CIRC HOLE CLEAN POH. SLM. M/U STIFF ASSEMBLY. RIH FOR CLEAN OUT RUN. RIH WITH CLEAN OUT ASSEMBLY DRILL TO CSG DEPTH 1926' CIRC CONDITION MUD. POH. STAND BACK BHA. RIG TO RUN 13 3/8" CSG. RUN PIPE TO 8' OFF BTM CIRC WATCHING FOR FLUID LOSS. HOLE TAKING 2 BBLS HR WHILE RIGGING TO RUN PIPE. LOST 42 BBL FLUID TO HOLE WHILE RUNNING CSG. VERY LITTLE FLUID LOSS WHILE CIRCULATING. RAN 2 SPIRAGLIDERS ON BTM TWO JOINTS. RAN ONE JOINT BETWEEN SHOE AND FLOAT COLLAR. CIRC 13 318" CSG AT 1910'. 5 BBL/MIN BTMS UP. SET CSG ON BTM AT 1926'. LAY DOWN CSG TOOLS. RUN INSIDE CSG WITH DRILL PIPE AND STAB IN TOOL. STAB IN. UNABLE TO CIRC CSG. 4000 PSI MAX. Page 1 of 11 29-Jul-00 30-Jul-00 31-Jul-00 01-Aug-00 02-Aug-00 03-Aug-00 {~" West McArthur River Unit #6 ~ M/U LANDING JOINT. I"/U ON CSG. BREI)J,J~I~CI~,~D WASH TO BTM. I./D LANDING JT. LINE TEST 2500 PSI. 40 BBLS H20, 333 BBLS 12.7# LEAD SLURRY, ( WATER RETURNS AT 256 BBLS PUMPED). SWAP TO 15.7# TAIL WHEN CEMENT RETURNS, 2 BBL WATER SPACER, 21.8 BBL MUD DISPLACEMENT. UNSTING. PUMP WIPER DART. CONDITION MUD INSIDE CSG. WASH UP. POH TEAR DOWN FROM 20" CONDUCTOR. WASH UP FROM CEMENT JOB. CUT 20" RISER. ROUGH CUT OUT 13 3/8" CSG. CENTER 13 3/8" INSIDE 20" AND ROTORY. FINISH CUT 13 3/8". SET IN AND WELD BRADEN HEAD. TEST BRADEN HEAD TO 2000 PSI. GOOD TEST. CLEAN PITS. CLEAN SLOP TANK. CLEAN SAND TRAP. INJECT WASTE FLUID. MADE GOOD USE OF SUPER SUCKER. STARTED NIPPLING UP ON TROLLY. N/U BOP. RIGGED UP ON WMRU #-3RD AND SQUEEZED INTO 10 3/4" X 16" ANNULUS. PUMPED CLASS "G" + 2% CACL + 0.3% CA-32 + 0.5 % FL-33 + 1 GHSFP6L PUMPED TO 500 PSI AND BUMPED PUMP IN MINUTE STAGES SQUEEZING AWAY A TOTAL OF 0.6 BBL STAYING UNDER 500 PSI. STOPPED WHEN CONCERNED WITH QUICK SETTING. N/U BOP TEST BOP 250~3000 PSI SET WEAR RING. RID TEST EQUIP. LAY DOWN 17.5" BHA. P/U BIT #2. BHA. SURFACE TEST MWD. AOGCC WITNESSED BOP TEST. RACK 5" DRILL PIPE TO PICK UP ON THE WAY IN THE HOLE. BHA. TEST MWD. rlh W/BIT ~2. INSTALL DRIP PAN. CLEAN CMT FROM SHAKER VALVE. RIH. PICK UP SINGLES. CIRC HALF WAY IN FOR CONTAMINATED MUD. WASH CMT STRINGER AND TO BTM F/1826 T/1880' TEST CSG TO 3000 PSI. GOOD TEST. DRILL FLOAT EQUIPMENT AND 20' NEW HOLE TO 1946' CIRC AND ATTEMPT F.I.T. TO 12.5 EMW. FAILED. DRILL OUT OF SAND ZONE TO 1976' SPOT LCM PILL AND TEST FORMATION. POH FOR SHOE SQUEEZE. FINISH T.O.H. T. I. H.-FLOW CHECK W/SPERRY(~ 140' DRLG AND SURVEYING 12 1/4" HOLE- HOLE LOADING UP WITH CUTTINGS-PUMP HEAVY WT. SWEEPS- RAISE MUD VIS. 47 TO 50 DRLG 12 1/4" HOLE FROM 2845' TO 3424'. MIX SWEEP-SWAB OUT ON PUMP-WIO PUMP DRLG. FROM 3424' TO 3502' PUMP HI VIS. SWEEP SURVEY-REAM-PUMP PILL POOH-REAM TITE SPOT JUST BELOW SHOE-STOP ABOVE SHOE. P/U 5" D.P.-RIH-SET UP S/S OFF DEAD MAN SENSOR FOR TRACKING DEPTH SURVEY-REAM TO BTM DRLG. 12 1/4" HOLE FROM 3502' TO 3650'. DRLG 12 1/4" HOLE FROM 3650' 3786' PUMP SWEEP, PILL-B/DN. TOP DRIVE TOH RIH W/HWDP-CHG. OUT 1 JT. RIH-REAM LAST STD TO BTM Page 2 of 11 04-Aug-00 05-Aug-00 06-Aug-00 07-Aug-00 08-Aug-00 09-Aug-00 10-Aug-00 11-Aug-O0 12-Aug-00 { West McArthur River Unit DRLG 12 1/4" HOLE F~OM 3786' TO 384~ab°rs 160 DRLG 12 1/4" HOLE FROM 3940' TO 4563'. (WT UP FROM 9.8 PPG. TO 11.2 PPG. W/DRLG) CBU W/REPAIRING PUMP DRIVE CHAIN SHORT TRIP TO 3598' P/U DP FROM WALK AND RIH TO 4563' DRLG 12 1/4" HOLE FROM 4563' TO 4815'ROTATE AND SLID FOR ANGLE DRLG FROM 4815' TO 5284' PUMP SWEEP AROUND SHORT TO 4563' DRLG FROM 5284' TO 5471' CIRC W/~r2 PUMP-WORK ON #1 PUMP MOTOR DRLG F/5471' TO 5517'-SURVEY-BALLED UP BIT CIRC,-MIX AND PUMP SWEEP TO UNBALL BIT-DID NOT WORK DRLG TO 5524' CBU-MIX DRY JOB-FLOW CK-PUMP PILL POOH SLOWLY TO AVOID SWABBING-CLEAN CLAY OFF BHA RIG SERVICE-REPAIR MUD VALVES-DUMP VALVE ON HI-CLUTCH-AG PADDLE FUNCTION TEST RAMS, BAG AND HCR VALVE-OK M/U BHA-TEST MWD-RIH SLOW TO 1915' RIH TO 4850' FILL PIPE-RIH TO 5471' WASH AND REAM TO BTM@5524'-DRLG TO 5428' DRLG 12 1/4" HOLE FROM 5528' TO 6069'-BIT BALLING UP MIX NUTPLUG SOAP, AND DIESEL TO UNBALL BIT AND STBS-ORDERED SAPP AND PUT 1 QT IN DP ON EACH CONN DRLG @ AVE OF 33'/HR PUMP SWEEP AND DRY JOB AT 6094' SHORT TRIP TO 5377'. NO PROBLEMS DRLG F/6094' TO 6194' REPAIR RIG PUMP. SWAB AND OILER. DRLG F/6194' TO 6694' PUMP SWEEPS TO HELP WITH BIT BALLING. DRLG F/6694' TO 6777' DRLG F/6777' TO 6805' INVESTIGATE 300 PSI PRESSURE LOSS AND LOSS OF MWD SIGNAL DRLG F/6805' TO 6815' POH WET. LOOK FOR WASH OUT. FOUND MWD PULSE UNIT EROSION. TEST BOP. AOGCC WAIVED WITNESS. CHANGE MUD MTR, MWD, JARS & RIH W/RR PDC BIT. RIH WITH RR PDC BIT. GOOD HOLE. SLM NO CORRECTION. REAM 6682' TO BTM. DRLG F/6815' TO 6999' DRLG F/6999' TO 7330' DRLG F17330' TO 7401' DRLG F1 7401' TO 7436' DRLG TO TD 7504' CIRC SWEEP. HOLE CLEAN. SHORT TRIP. HOLE IN GOOD SHAPE. CIRC SWEEP. HOLE CLEAN. TRIP OUT. L/D BHA. L/D BHA R/U TO RUN 9 5/8" CSG. RUN CSG TO BTM(CIRCULATED AT SHOE AND 5200') Page 3 of 11 13-Aug-00 14-Aug-00 15-Aug-00 16-Aug-00 17-Aug-00 18-Aug-00 West McArthur. ]U,~ha r._~ .~ c-~3River Unit ~~{. CSG STUCK ON BTM. CIRC 1.5 ANNULAI:~OEUMES AT 8 BBLS. MIl,. RID CSG EQUIPMENT. RIG TO CEMENT. SAFETY MEETING. R/U CEMENTING HEAD. LOAD PLUG. FULL RETURNS WHILE RUNNING IN THE HOLE. PUMP 3 BBLS. H20-TEST LINES TO 3000#1-PUMP 40 BBLS SPACER & MCS-4, DROP PLUG 2 BBL. H20, RELOAD HEAD PUMP 190 BBL. LEAD CMT.@12.5#/GAL.-PUMP TAIL CMT.@15.8#/GAL. & DROP PLUG, 2 BBL. H20 DISPLACE PLUG W/RIG PUMP ~_,8+ BBL./MIN.-PLUG SET @0900-6451 TOTAL STROKES RIG DOWN BOP'S TO SET SLIPS-PUMP OUT PITS-RIG DOWN DRAIN PANS-RIG UP HYD RAMS-NIPPLE DOWN BTM SPOOL-RAISE STACK-CENTER PIPE SET SLIPS W/100,000~ WHILE CLEANING PITS CUT HOLE AND DRAIN CSG-MAKE FINAL CUT AND DRESS STUB-SET STACK DOWN NIPPLE DOWN AND REMOVE ADPT. SPOOL-REMOVE FLOW NIPPLE-INSTALL AND TEST 13 3~8" TBG. 3000# FLAN SLIPS AND PACKOFF TO 3000 PSI FOR 15 MIN FOR 15 MIN NIPPLE UP ADAPTER FLANGE-BOP'S-RISER-FLOW LINE-TRIP TANK & LINES-FILL UP LINES-AND DRIP PANS WHILE CLEANING PITS TEST CHOKE MANIFOLD WHILE NIPPLING UP RIG UP TO TEST BOP-CLEAN PITS TESTING BOP'S-TESTED ALL BOP EQUIPMENT TO 250-5000 PSI-ANNULAR TO 250-3500 INSTALL DRIP PANS & RIG DOWN TEST EQUIPMENT INSTALL WEAR RING 10 1/2" O.D. BY 10" I.D.-MAKE UP SAVER SUB ON TOP DRIVE FINISH INSTALLING DRIP PANS-CLEAN MUD TANKS-STRAP D.P. ON RACKS-FIX WATER PUMP ON CAN/RIG T.D. MOTOR-SEAL RIG FLOOR CONTINUE CLEANING PITS W/SUPERSUCKER-HAUL O.B. MUD AND FULL VOLUME TANK P/U MULE SHOE AND RUN IN HOLE W/HWDP-LAY DOWN 12 JTS. OF HWDP CLEAN MUD PITS. PREP FOR OIL BASE MUD. P/U 5" DRILL PIPE. RIH WITH MULE SHOE. TAG UP ON FLOAT COLLAR AT 7419'. RIG TO DISPLACE. REVERSE CIRC AND DISPLACE WITH OIL BASE MUD. RETURNS TO INJECTION. TEST CSG TO 3000 PSI GOOD TEST. R/D CIRC LINES, POH. PICK UP BHA AND BIT #5. M/U BHA. RIH W/BIT #5. SLOW DUE TO VERY THICK RETURNS. DRILL FLOAT EQUIPMENT AND 20' OF NEW HOLE TO 7524'. CIRC AND PERFORM FORMATION INTEGRITY TEST TO 11 PPG EMW. GOOD TEST. DRILLING FROM 7524' TO 8026' WITH PDC BIT. ADDED 47 BBLS MAPCO 200 TO MUD SYSTEM. 190 BARRELS MORE OF MAPCO 200 DUE IN THIS AM ON BARGE. DRLG FROM 8025' TO 9080'. ADJUSTING ANGLE WITH BIT WEIGHT AND ROTORY SPEED. MADE ONLY ONE SLIDE OUT FROM UNDER SHOE. RACK DRILL PIPE TO PICK UP ON NEXT SHORT TRIP. DRLG FROM 9048' TO 9244' CIRC BTMS UP. PUMP SLUG AND SHORT TRIP TO SHOE. WORK THROUGH TIGHT HOLE AT 8803. TIGHT AGAIN AT 7735. PUMPED SWEEP AND UPREAMED INTO SHOE. SERVICE RIG. SERVICE TOP DRIVE. RIH. PICK UP 48 JOINTS DRILL PIPE. Page 4 of 11 19-Aug-00 20-Aug-00 21-Aug-00 22-Aug-00 23-Aug-00 24-Aug-00 25-Aug-00 " West McArthur River Unit #6 ~,," REAM TIGHT SPOT ',640', 8115', 8336' ~,,~ rrna,vi 9062' TO BOTTOM DRLG FORM 9244 TO 9327' DRLG F/9327 T/9899' CIRC BTMS UP. PUMP SWEEP. CIRC HOLE CLEAN. DRY JOB. SHORT TRIP TO 8500'. HOLE IN GOOD SHAPE. RUNNING BACK TO BTM AT REPORT TIME. HOLE TAKING A LITTLE FLUID. MOST FLUID LOSS AS CUTTING RETENTION. FINISH SHORT TRIP. HOLE IN GOOD SHAPE. DRLG F/9899' TO 10450' HOLE CONTINUES TO TAKE FLUID. LOST APPROX 40 BBLS LAST 24 HRS. SOLIDS STAYING AT 10%. MUD WT STILL AT 9.1 PPg. DRLG. FROM 10450' TO 10485'FINISH SHORT TRIP. CIRC. WORK PIPE AND RECIPROCATE. PUMP SWEEP-MONITOR WELL-PUMP PILL MAKE 10 STD. SHORT TRIP-HOLE IN GOOD SHAPE. DRLG. 8 1/2' FROM 10485' TO 10838' HOLE IS STILL TAKING MUD @ 100 BBLS.+/DAY SOLIDS STAYING AT 10%. MUD WT AT 9 PPG. DRLG. FROM 10838' TO 10965' CIRC. BTM. UP W/HIGH'VIS. SWEEP POOH-PULL TIGHT @ 8593' AND 7949' 40K DRAG. BACK REAM FROM 7870' TO 7863'. POOH TO SHOE-MONITOR WELL-NO PROBLEMS. PUMP PILL POOH TO 6713',WET. MIX AND PUMP PILL #2. POOH TO BHA. PULL WEAR BUSHING AND INSTALL TEST PLUG. TEST BOP. TEST BOPs.-ALL SYSTEMS 250 PSI TO 4000 PSI- HYDRIL TO 3000 PSI. MAKE UP BHA RIH W/BHA AND HWDP-TEST MWD. RIH-P/U 90 JTS. 5" DP OFF CATWALK. SERVICE TOP DRIVE-HOLD SPILL DRILL & SAFETY MEETING W/TOOL PUSHER AND DRLG. SUPT. RIH. ATTEMPT TO FILL PIPE-TOP DR. MUD SAVER VALVE FAILED. REPAIRING MUD SAVER VALVE ON TOP DR. RIG REPAIR- REPAIRING MUD SAVER VALVE ON TOP DRIVE RIH DRLG- ROT. SLIDE AND SURVEY TOOK ~r2 PUMP OFF LINE- REPACING WASH PLATE-DRLG AHEAD W/~I PUMP @ 106 STKS 2150 PSI DRLG FROM 11191' TO 11490' CIRC.-MIX AND PUMP HI-VIS SWEEP WHILE REPAIRING fl2 PUMP. STOPPED DRLG. UNTILL PUMP REPAIRED. DRLG. FROM 11490' TO 11493' SWAB OUT ON #1 PUMP- CIRC. AND ROTATE PIPE WHILE REPAIRING PUMP. DRLG. FROM 11493' TO 11511'. CIRC.-PUMP HI-VIS SWEEP BEFORE SHORT TRIP SIX STD. SHORT TRIP.-PULL TIGHT @ 11268' BACKREAM TO 11304'-HOLE OK DRLG. FROM 11511' TO 11735'-ROTATE SLIDE AND SURVEY Page 5 of 11 26-Aug-00 27-Aug-00 28-Aug-00 29-Aug-00 30-Aug-00 31-Aug-00 01-Sep-00 02-Sep-00 03-Sep-00 West McArthur~,~o~, River160 Unit #6 {i DRLG. 8 1/2" HOLE FROM 11735' TO 119'1~2"°rs CIRC. HI-VIS SWEEP, PUMP IPLL SIX STD. SHORT TRIP - HOLE OK, NO PROBLEMS DRLG 8 1/2" HOLE FROM11912' TO 12095'. GAS UNITS HAVE INCREASED BY 35 UNITS AND MUD LOGGERS HAVE NOT CORRELATED WI WMRU#5 FOR THE LAST 200'. DRLG. 8 1/2" HOLE FROM 11912' TO 12250'. CIRC. HI-VIS SWEEP, PUMP SURVEY UP-PUMP PILL- MONITOR WELL. FIVE STD. SHORT TRIP - HOLE OK, NO PROBLEMS DRLG 8 1/2" HOLE. SWAB WASHED OUT OF #1 PUMP- DRLG W/1 PUMP-110 STKS.-392GPM.-PUMPED HI-VIS-SWEEP. DRLG F1 12350' TO 12426'. CIRC SWEEP AND HOLE CLEAN. POH WITH BIT # 6. P/U BIT # 7. BHA CHANGE . ORIENT MWD. CHECK PULSE. RIH WITH BIT # 7 RIH WITH BIT # 7. TEST MWD. RIH. FILL PIPE AT 10000'. DRLG F/12426' TO 12740' REAMED LAST STAND TO BTM. DRLG FROM 12740' TO 12986'. CIRC SWEEP. SHORT TRIP 600'. NO HOLE PROBLEMS. DRLG FROM 12986' TO 13175' SLIDE 60' ROTORY DRILL 30' EACH CONNECTION. DRLG FROM 13175' TO 13342' CIRC SWEEP AND HOLE CLEAN. SHORT TRIP TO 9 5/8" SHOE. NO HOLE PROBLEMS. CIRC HOLE CLEAN AFTER SHORT TRIP. POH. CLEANED UP 4 TIGHT SPOTS. SLM - NO CORRECTION. LAYED DOWN DIRECTIONAL TOOLS. SAFETY MEETING. RIG UP SCHLUMBERGER. RAN LOG TO BOTTOM. NO PROBLEM. SONIC BOLEHOLE IMAGER. GAMMA RAY. LOGGING AT REPORT TIME. LOG WITH SCHLUMBERGER. LOGGED TO 13300' STOPPED 42' FROM BOTTOM. ULTRASONIC BOREHOLE IMAGER - GAMMA RAY. TEST BOP. AOGCC WITNESSED. ONE FAILURE AT CHOKE MANIFOLD VALVE. REPAIRS TO BE MADE. MAKE UP STIFF BHA AND RIH TO SHOE. BREAK CIRC. CUT DRLG LINE. RIH. STOP AT BRIDGE AT 13272' WASH BRIDGE AND TO BTM. CIRC FOR LOGS. CIRC AT BTM. SHORT TRIP TO 12740' SIX STANDS. NO HOLE PROBLEMS. CIRC HOLE CLEAN. PUMP SWEEP. POH. RACK DRILL STRING FOR CSG JOB. RIG TO RUN PIPE. RUN 7 5/8" CSG. WITH 80' SHOE TRACK. 2500' AT REPORT TIME. Page 6 of 11 04-Sep-00 05-Sep-00 06-Sep-00 07-Sep-00 08-Sep-00 09-Sep-00 West McArthUrNaborsRiver160 Unit ~ RIH W/7 5/8" CSG. SECURE STABBING BOARD-CLEAN OBM FROM ELEVATORS AND RIG DOWN SAME. P/U AND MAKE UP LINER HANGER & RUNNING TOOL-UP CSG. WT. 170K-DOWN CSG. WT. 135K. CLEAN OBM FRON CSG. AND RIG DOWN CSG. EQUIPMENT. MIX GEL AND POUR IN TOP OF HANGER.-RIH W/15 STDS. 5" D.P. RIH TO SHOE. FILL PIPE AND CIRC. M/U CMT HEAD. RIH. CIRC AT 9700. RUN CSG TO 13336'. P/U CMT HEAD. CIRC. WORK PIPE. LINER CAME LOOSE FROM DRILL STRING BUT REMAINED STABBED IN ON BTM @ 13342' CIRC LINER ANNULUS CLEAN AT 4BBL/MIN 1000 PSI. SAFETY MEETING. RIG TO CEMENT. LINE TEST. PUMP 20 BBL H20, 40 BBL PREFLUSH FOLLOWED BY CMT. PUMP 34 BBL. CMT.-DROP WIPER PLUG-DISPLACE W/RIG PUMP-PUMP 402 BBLS. MUD-BUMP PLUG, HOLD 1700 PSI FOR 15 MIN.-CIP @ 0720 HRS.SET DOWN WT. 45-50K. TO CHECK PACKER SET.-UNSTING F/LINER. REVERSE CIRC.-PUMP DRY JOB. LAY DOWN BAKER CMT. HEAD-POOH LAYING DOWN 5" D.P. POOH- STAND BACK 17 STDS.- P/U SINGLE LAY DOWN AND REPLACE 1JT. LAY DOWN RUNNING TOOL. BRING DOWN TP BLOWER HOSE TO REPAIR. RIH W/DC & HWDP. LAY DOWN 5" HWDP, DC &STAB. BREAK STAB. SLEEVES. CLEAN RIG FLOOR,PULL WEAR BUSHING ,CHANGE OUT BOTTOM RAMS,\F/5" TO 3 1/2".-TEST TO 4000 PSI HOLD 1/2 HR. RIG DOWN TEST EQUIP.-SET WEAR BUSHING. TEST CSG. TO 3000 PSI-HOLD 1/02 HR. GOOD TEST. P/U 4 3/4" BHA TO RIG FLOOR-MAKE UP 6 3/4" BIT AND BHA. FINISH PICKING UP BHA-ORIENT AND TEST BHA RIH PICKING UP 3 1/2" DP-(DRIFT PIPE) CHG. TO 5" ELEVATORS-MAKE UP STD.-BREAK CIRC.-CK. MWD. R IH TO 13249' RIH F1 13249' TO 13256'- TAGGED L/C ~ 13256'. DRLG. F/13342' TO 13359'. CIRC. F1 FIT TEST. FIT TEST W/9.2 PPG. @ 11.0 PPG EMW. DRLG F/13359' TO 13626'. ROT. % SLIDE.-PUMPED 30 BBL. SWEEP @ 2230 HRS. CBU-CHECK FOR FLOW-PUMP DRY JOB. POOH- HAD TO ROTATE STRING TO GET THROUGH THE SHOE. POOH W/5" DP MIX AND PUMP DRY JOB FOR 3 1/2" DP. POOH W/3 1/2" DP WORK BHA AND BREAK BIT. CLEAN RIG FLOOR MAKE UP BIT-CHECK ORIENTATION-WORKING ON COMM. W/SS PWD TOOL-SHALLOW TEST MWD. RIH TO 3500'-FILL DP. PJSM-P/U 30JTS. 3 1/2" DP. CUT 140' DRILLING LINE. TRIP IN HOLE REAM AND WASH TO BOTTOM- DRLG. 603/4" HOLE. DRLG. 6 3/4" HOLE FROM 13635' TO 13915' S.P.R.-DRLG. F/13915' TO 13984'- DRILLSTRING TORQUEING UP, 14.3K CIRC.-MONITOR WELL POOH TO SHOE DROP DART- CIRC.- BLOW CIRC. SUB-CHECK FLOW-PUMP DRY JOB POOH GAS SHOWS IN "G" SANDS Page 7 of 11 10-Sep-00 11-Sep-00 12-Sep-00 13-Sep-00 14-Sep-00 15-Sep-00 16-Sep-00 17-Sep-00 West McArthur River Unit #6 Nabors 160 POOH BREAK BIT-DOWNLOAD MWD L/D MWD-L/D STAB-CHECK FLOAT-P/U 3 1/2" SINGLE FOR STANDBACK-PULL DIR. PROBE RIG UP TO TEST BOP TEST BOP,s -HYDRIL TO 3000~-ALL RAMs &VALVES TO 4000# RETRIEVE TEST PLUG-SET WEAR RING-L/D TOOLS- CLEAN RIG FLOOR M/U BIT & STAB-L/D 31/2" SINGLE-LOAD MWD RIH TO TOP OF HWDP- MAKE UP PUMP OUT SUB AND MWD MWD NOT TESTING-WORK ON AND REPLACE TWO TOOLS-THIRD TOOL SENDING SIGNALS TRIP IN HOLE DRLG 6 3/4" HOLE DRLG WITH BIT #11 FI14027' TO 14236" UNABLE TO SLIDE AT 14236'. ClRC POH TO SHOE. NO HOLE PROBLEMS. SHEER OUT ClRC SUB. ClRC AT MAX RATE. ClRC HOLE CLEEN. DRY JOB. TRIP FOR BIT # 11. POH WITH BIT # 11 CHANGE OUT MUD MOTORS/BIT # 12 ORIENT/CHANGE OUT MWD PROBE. TEST MWD TIH TIH/NO HOLE PROBLEMS DRILLING FROM 14236 TO 14407 DRLG. 6 3/4' HOLE (SLIDE AND ROTATE) CIRC. POOH TO SHOE DROP DART -BLOW CIRC. SUB@ 1900 PSI-CIRC. @ GPM-RT. AND WORK PIPE-ClRC 9600 STKS. MONITOR WELL FOR 10 MIN.-PUMP DRY JOB. POOH W/5' DP CLING. TO 3 1/2' EQUIP. POOH MAKE UP BIT #13-CLING. BHA-MOVE STAB-FLOW TEST SIS MTR. RIH CUT AND SLIP DRLG. LINE RIH TO 13340'-FILL PIPE @ SHOE-RIH TO 14367'-WASH AND REAM F/14367' TO 14532'. -SURVEY W/SPERRY SUN. DRLG. 6 3/4" HOLE FROM 14532' TO 14676' DRLG FI 14676' TO 14708'. CIRC. AND WORK PIPE PULL TO SHOE DROP DART, OPEN PUMP OUT SUB-CIRC HOLE @ HIGH VELOCITY MONITOR WELL- PUMP PILL-POOH M/U BIT- CHECK SPERRY SUN MWD- CHANGE OUT PROBE SERVICE RIG TOP DRIVE RIH FILL PIPE-TEST MWD RIH FILL PIPE-SERVICE TOP DRIVE RIH- WASH AND REAM F/1455' TO 14708' DRLG.ClRC AND SURVEY F/14708' TO 14955'-NO SHOWS PAST THE TOP OF THE WESTFORELANDS. DRLG. F1 14955' TO 14963'-TD. Page 8 of 11 18-Sep-00 19-Sep-00 20-Sep-00 21-Sep-00 22-Sep-00 West McArthur River Unit #6 CIRC. AND WORK PIPE-BOTTOMS[ UP. Nabors 160 POOH TO SHOE. CUT AND SLIP DRLG. LINE. RIH ClRC.SWEEP POOH TO SHOE-(SLM) DROP DART-BLOW OUT CIRC. SUB-CIRC. MONITOR WELL-PUMP PILL. POOH-SLM-NO CORRECTION. LAY DOWN BHA. RIG UP SWS TO RUN WIRELINE LOGS. FINISH R/U SCHL, FUNCTION TEST BOP'S WHEN OUT OF HOLE. PJSM W/SCHL ON W/L PROCEDURES. RIH W/L RUN #1, SONIC-RES-DENSITY NEUTRON, MONITORING FLUID LOSSES. LOGGING RUN #1 POH I_/D TOOLS, PICK UP USIT SONIC TOOL, RUN ~r2, COMPLICATIONS W/TOOL, LAY DOWN, P/U SIESMIC-VSP TOOL RUN #3 RIH W/VSP SIESMIC, LOG COMING UP. RIG UP RUN #~ UBI-GR. RIH RUN #~ POH, LOGGING OUT. FINISH LOG RUN ~ UBI-GR, MALFUNCTION, COME OUT OF HOLE & L/D. SWIVEL JOINT CAUSE OF MALFUNCTIONS, PREPARE VSP SEISMIC CHECK SHOT. P/U S.A.T.(VSP) & RIH, LOG RUN #5., TWO HR. DOWNTIME M/V PEREGRINE AIR SUPPLY F/AIR GUN LAY DOWN TOOLS, P/U RUN #5 SONIC- USIB RIH & LOG #5 USIB L/D USIB. RIG UP TO RUN RFT'S. RIH RUN ~ RFT/SGC-SA LOG RUN ~ RFT'S, 31 SETS, 29 SUCESSFUL POH W/RFT TOOLS & LAY DOWN. SET WEAR RING. MAKE UP BHA. RIH, BREAK CIRCULATION (~ 3500'.RIH TO LINER LAP. ClRC & CONDITION MUD @ 7-5~8" LINER LAP @ 7286'. RIH TO 11060'. ClRC & CONDITION MUD @ 11060' RIH TO T.D. @ 14963', HOLE IN GOOD CONDITION, NO FILL. ClRC & CONDITION MUD @ 14963', SLOWLY ROTATING & RECIPROCATING DP. CONTINUE CIRC & CONDITION MUD @ T.D., RECIPROCATING D.P.. POH SLOWLY TO HWDP. LAY DOWN HWDP & BHA, RIG UP VAC TRUCK TO SUCK PIPE CLEAN. PICK UP TEST JT, PULL WEAR RING, M/U FLOOR VALVE & PUMP IN SUB SET. CHANGE TOP RAMS TO 5-1/2 FOR LINER. TEST 5-1/2 RAMS TO 3000, PULL TEST PLUG, REPLACE WEAR RING, FULL BOPE TEST WAIVED BY WONZELL- AOGCC PICK UP CASING EQUIPMENT, RIG UP TO RUN LINER, PJSM. RUN 44 JTS 5-1/2" LINER. PICK UP LINER HANGER ASSEMBLY. CIRCULATE ONE LINER VOLUME. RIG DOWN CASING EQUIPMENT. CHANGE TOP RAMS TO 5" & TEST. PJSM, RIH W/LINER ON 3-1/2" & 5" DRILLPIPE, ClRC EVERY 10 STANDS. Page 9 of 11 23-Sep-00 24-Sep-00 25-Sep-00 26-Sep-00 27-Sep-00 28-Sep-00 t .... West McArthur River Unit ~ ,~,. RIG DOWN TIME. AIR~' LINE BROKE ON I~ll~)[~r~l;1,~ CLUTCH, REPLACED~' SAME. CONTINUE RIH W/LINER ON DRILLPIPE. CIRCULATE AT 7-5/8" LINER SHOE, CONDITIONING MUD WEIGHT & VISCOSITY. RIH F/SHOE TO T.D.. M/U CEMENTING-CIRCULATING HEAD TO DP JOINT, TAGGED BTM @ 14963', CIRCULATED AT 14955' WHILE BATCHING CEMENT. TESTED LINES TO 4000#, PUMPED 50 BBL PREFLUSH, 20 BBL SPACER, 46 BBL CMT, DROPPED PLUG, DISPLACED W/RIG, BUMP PLUG WI2500#, CIP @ 0800 HR., PRESSURED TO 3500# TO RELEASE RUNNING TOOL, P/U 7', 25 KWT LOSS, SLACKED OFF 60 K TO SET LINER TOP PACKER. REVERSE CIRC, SHUT DOWN TO CLEAN CMT F/SHAKERS, POSSUM BELLY & FLOW LINE, ESTIMATE 20 BBL+- EXCESS CEMENT REVERSED OUT. RIG DOWN CEMENT CIRC HEAD W/JT DP & SET IN DOOR. CIRCULATE BOTTOMS UP. POH BREAK SURFACE BREAKS ON CEMENTING HEAD, L/D SINGLE PUP JT, CHANGE ELEVATOR TO 3-1/2" POh W/3-1/2" DP. BREAK BAKER RUNNING-LANDING TOOL & LAY DOWN.. M/U CLEAN OUT ASSY W/4-3/4" MILL & CSG SCRAPER. RIH, P/U 2-7/8" DP F/RACKS, RABBIT EACH JT. CONTINUE RIH RIH W/3-1/2 DP RIH W/3-1/2 DP, TAG LINER TOP AT 13132' NO CEMENT, CONTINUE TO LD(~F__~,~, NO CEMENT. CIRC LINER CLEAN @ 4.5 BPM & 2600 PSI, CONDITIONING MUD. MUD WEIGHT 9.05 PPG. PRESSURE TEST LINER TO 3000 PSI F/30 MIN. GOOD TEST. BLEED OFF PRESS AND RIG DOWN. PUMP PILL. POH W/CLEANOUT ASSY TO LOG. POOH TO LOG W/SWS LAY DOWN 14 JTS. 2 7/8" DP STAND THE REMAINDER IN DERRICK POOH LAY DOWN BHA-RIG UP VAC TRUCK TO SUCK MUD OUT OF DP BEFORE LAYING DOWN PIPE SET SWS WIRELINE UNIT AND SHOP-CLEAN RIG FLOOR(WHILE WAITING ON SWS DUE TO WEATHER) R/U SWS (#1 RUN USIS) RIH W/USIS LOG-LOGGING -POOH W/WIRELINE RIG UP ~ LOG AND RUN IN HOLE WITH WIRELINE (RST) LOGGING W/SWS-LOG ~2-RST LOG CLEAN RIG FLOOR OF EXCESS TOOLS -CLEAR WALK OF SWS TOOLS-PUT 2 7/8" DP ON PIPERACK RIH TO DISPLACE SLIP DRLG. LINE-CHANGE ELEVATORS AND SLIPS RIH RIG UP TO REVERSE CIRC O.B. MUD OUT OF HOLE W/DEAD CRUDE-REVERSE CIRC. RIG UP TO LAY DOWN D.P.-LAY DOWN 5" D.P. LAYING DOWN 5" DP, 3 1/2" DP, 2 7/8" DP-USE VAC TRUCK TO SUCK PIPE FREE OF CRUDE OIL HAUL OB MUD FROM MUD PITS TO ATIGUN STORAGE TANK ON PAD #5 LAYING DOWN 5" DP, 3 1/2" DP, 2 7/8" DP-USE VAC TRUCK TO SUCK PIPE FREE OF CRUDE OIL R/DOWN RIG FLOOR-LAY DOWN EQUIP. AND CLEAN RIG FLOOR PULL WEAR BUSING-PJSM-CHANGE OUT BTM. RAMS FROM 3 1/2" TO 27/8".-TEST DOOR SEALS TO 3000 PSI LAY DOWN TEST PLUG. HOLD PJSM-PICK UP PERF. GUNS RIG UP WEATHERFORD-MAKE UP PACKER ASSEMBLY-RUN 3 JTS. TBG. GET STRAP. Page 10 of 11 29-Sep-00 30-Sep-00 PICK UP 2 7/8" TBG. West McArthur River Unit #6 Nabors 160 PICK UP 2 718" TBG. PJSM-RIG UP SWS RIH W/SWS-CCL-LOG-POOH P/U 10' 2 7/8" PUP AND SINGLE-REPOSITION TBG.-L/DWN 2 7/8" SINGLE RIH W/SWS-CCL-CHECK LOCATION OF RA MARKER-POOH RIG DOWN SWS PICK TO ASSURE PACKER IS SET-PACKER NOT SET PRESSURED UP TO 1500 PSI TO SET PACKER-PACKER SET @ 14094'-ROTATED TO THE RIGHT TO RELEASE RUNNING TOOL FROM PACKER. LAY DOWN 2 7/8" PUP AND 5" PUP. READJUST BAILS F/ELEVATORS DROP RABBIT-POOH W/2 7/8" TBG. AND BAKER RUNNING TOOL-(PULLING TEFLON SEALS & INSPECTING COLLARS- CHANGE OUT COLLARS IF NECESSARY). POOH W/2 7/8" TBG. RETRIEVE RABBIT FROM TOP OF BUMPER SUB-LAY DOWN BUMPER SUB DROP RABBIT-POOH W/2 7/8" TBG.-RETRIEVE RA MARKER & RABBIT.-LAY DOWN PACKER RUNNING TOOL P/U 5" X-O AND 10'2 7/8" PUP, BREAK AND LAY DOWN SAME. CLEAN RIG FLOOR-HOLD PJSM-RIH W/2 7/8" TBG. MAKE UP SEAL ASSEMBLY AND PUMP CAVITY-RIH W/2 7/8" TBG.-CHANGE OUT BAD JTS. CHANGE OUT SPRINGS ON YC ELEVATORS DUE TO EXCESSIVE SNAGGING. RIH W/2 7/8" TBG.-CHANGE OUT COLLARS AND JTS. AS NEEDED. RIH W/2 7/8" TBG. SPACE OUT-MAKE UP TBG. HANGER-LAND 2 7/8" SEAL ASSEMBLY- TEST TBG. HANGER SEALS TO 3500 PSI FOR 5 MIN. LAY DOWN 2 7/8" LANDING JT.-SET B.P.V. 01-Oct-00 02-Oct-O0 FINISH FLUSHING OUT STACK RID FLUSH TOOL F1 TOP DRIVE-SUCK OUT STACK W/VAC TRUCK-REMOVE TURNBUCKLES F/STACK REMOVE HYDRAULIC LINES,FLOWLINES & AIRVALVE TO TRIP TANK-VAC AND WASH MUD FROM FLOW LINES & BOTTOM DRIP PAN-REMOVE TOP DRIP PAN, BELL NIPPLE-STEAM OB MUD OFF BOP-REMOVE CHOKE AND KILL HOSE REMOVE BOPs F/TBG. SPOOL-REMOVE DSA-N.D. BOTTOM SPOOL, BOTTOM RAMS & MUD CROSS, DBL GATE AND HYDRIL-WASH OUT SAME. NIPPLE UP TREE-TEST SEALS TO 2500 PSI REMOVE TROLLEY BRACES R/U TREE-TEST TO 5000 PSI-TESTED OK-MAKE UP PRODUCTION LINES TO TREE RIG UP WIRELINE LUBRICATOR. PJSM-W/RIG CREW, PRODUCTION, HALLIBURTON, POLLARD WIRELINE.-PRODUCTION TESTED LINES TO 4000 PSI. TESTED OK-PRESSURED UP TO 2800PSI TO FIRE PERF. GUNS-RELEASED PRESSURE.- GUNS FIRED @ 0450 HRS.. FINISH RIGGING UP POLLARD WlRELINE-WIRELINE STANDING VALVE IN HOLE. RIH W/STANDING VALVE TO 12630' W/L MEARSURMENT-W/L OOH RIG DOWN W/L & LUBRICATOR-PROD. PREFORMED BUNDLE TEST TO 1500 PSI-RIG UP PROD. LUBRICATOR. PRODUCTION PUMPING DOWN JET PUMP. PRODUCTION STARTING DOWN TBG. TO FLOW TEST WELL. RIG RELEASED @ 1800 HRS. Page 11 of 11 2000 ~.q~. o~OO oo§§o O0 O0 0 ddddd ddd~d ddd~H 0 0 ~ ZZZZZ ZZZZZ ZZZZZ Z~ZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ........ ~ ~..~ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ o ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ..... O0 04 C~3 O) If'3 0 0 ~ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ Z .............. ~ .~q~ ~. o~oo~ ooooo ooooo ~o~o ~ Fommlm lnc WEST McARTHUR RIVER UNIT #6 WEST McARTHUR RIVER FIELD Section lO. T8N-R14W, SM Kenai Borough, Alaska September 17, 2000 John Morris, Sr. Logging Geologist Lees Browne, Jr., Sr. Logging Geologist George Baker, Sr. Logging Geologist EPOCH TABLE OF CONTENTS Forcenergy, Inc. West McArthur River Unit #6 Kenai Borough, Alaska Well Resume Page 1 Daily Activity Summary Page 2 Formation Summary Page 13 Rig Time Distribution Page 54 Days vs. Depth Page 57 Mud Record Survey Record Page 58 Page 60 Bit Record Page 65 Formation Log Appendix 1 Operator Well Name: Location: Coordinates: Elevation: County: State: APl Index: Spud Date: Contractor: Foremen: Rig: Logging Unit: Geologists: Co. Geologist: Log Interval: Dates: Mud Types: Casing Data: Hole Size: WELL RESUME Forcenergy, Inc. West McArthur River Unit #6 Kenai Borough, Alaska Forcenergy, Inc. · West McArthur River Unit #6 Sec. 10, T8N, R14W, SM 2395' FNL, 1337' FWL KB: 163' AMSL Kenai Borough Alaska 50-133-20494-00 7/24~2000 Nabors Alaska Drilling Derry Thompson, Mike Murray #160- Land #14 John Morris, Lees F. Browne, Jr., Dick Ebright, George Baker, Jerry Stafford Art Saltmarsh 63'to 14963' 7/24/2000 to 9/17/2000 Spud Mud to 1926', LSND to 7504', Versaclean (oil base) to 14963' 20" at 120', 13 3~8" at 1926', 9 5/8" at 7504': 7 518" at 13340' 17 ½"to 1926', 12 %" to 7504', 8 ½"to 13342', 6 %"to 4963' RIG ACTIVITIES Forcenergy, Inc. West McArthur River Unit #6 Kenai Borough, Alaska 7125/00 7~26~00 7~7~0 7128100 DRLG. 17 1/2" HOLE FROM 63' TO 210'. CIRC. AND PULL OUT OF HOLE TWO STDS. INSTALL MWD IN NMDC AND ORIENT. GYRO SURVEY (~ 93' -SURVEY WI MWD ~ 93' -MAG. INTERFERENCE. DRLG. 17 1/2" HOLE FROM 210' TO453' GYRO SURVEY ~ 356' DRLG. 17 1/2" HOLE FROM453' TO 539' GYRO SURVEY ~ 356' SET STAND BACK AND WORK ON PUMP AND SLOP TANK CLEAN SLOP TANK. FIX SOLIDS EQUIPMENT. DRLG 539' TO 1337'. UNABLE TO RECORD MWD SURVEYS DUE TO MAGNETIC INTERFERANCE. RUNNING GYRO ON SLICK LINE EACH 90' CONNECTION. RECORDING MWD SURVEYS AFTER 1261' 12 HOURS ON BTM DRILLING 10 HOURS ClRC AND SURVEYS 2 HOURS RIG REPAIR HAULING DRY CUTTINGS ONLY TO DWMA CELL. NO LIQUIDS. DRLG 1261' TO 1354' CHANGE SHAKER SCREENS DRLG 1354' TO 1910' MWD AT 90' STATIONS. ClRC HOLE CLEAN POH. SLM, MlU STIFF ASSEMBLY. EACH STABILIZER NEEDED CLEANING. RIH FOR CLEAN OUT RUN. NO HOLE TROUBLE. TOTAL ROTATE HRS 23 TOTAL SLIDE HRS 11 RIH WITH CLEAN OUT ASSEMBLY DRILL TO CSG DEPTH 1926' ClRC CONDITION MUD. POH. STAND BACK BHA. "RIG TO RUN 13 3~8'"' CSG." RUN PIPE TO 8' OFF BTM CIRC WATCHING FOR FLUID LOSS. HOLE TAKING 2 BBLS HR WHILE RIGGING TO RUN PIPE, LOST 42 BBL FLUID TO HOLE WHILE RUNNING CSG. VERY LITTLE FLUID LOSS WHILE CIRCULATING. RAN 2 SPIRAGLIDERS ON BTM TWO JOINTS. 7129100 7130100 7131100 811100 RAN ONE JOINT BETWEEN SHOE AND FLOAT COLLAR. CIRC 13 3~8" CSG AT 1910'. 5 BBL/MIN BTMS UP. SET CSG ON BTM AT 1926'. LAY DOWN CSG TOOLS. RUN INSIDE CSG WITH DRILL PIPE AND STAB IN TOOL. STAB IN. UNABLE TO ClRC CSG. 4000 PSI MAX. M/U LANDING JOINT. PIU ON CSG. BREAK ClRC AND WASH TO BTM. L/D LANDING JT. LINE TEST 2500 PSI. 40 BBLS H20, 333 BBLS 12.7# LEAD SLURRY, ( WATER RETURNS AT 256 BBLS PUMPED). SWAP TO 15.7# TAIL WHEN CEMENT RETURNS, 2 BBL WATER SPACER, 21.8 BBL MUD DISPLACEMENT. UNSTING. PUMP WIPER DART. CONDITION MUD INSIDE CSG. WASH UP. POH TEAR DOWN FROM 20" CONDUCTOR. HAUL EXCESS MUD TO INJECTION. WASH UP FROM CEMENT JOB. CUT 20" RISER. ROUGH CUT OUT 13 3~8" CSG. CENTER 13 3~8" INSIDE 20" AND ROTORY. FINISH CUT 13 318". SET IN AND WELD BRADEN HEAD. TEST BRADEN HEAD TO 2000 PSI. GOOD TEST. CLEAN PITS. CLEAN SLOP TANK. CLEAN SAND TRAP. INJECT WASTE FLUID. MADE GOOD USE OF SUPER SUCKER. STARTED NIPPLING UP ON TROLLY. NIU BOP. RIGGED UP ON WMRU #3RD AND SQUEEZED INTO 10 314'"' X 16'"' ANNULUS. PUMPED CLASS "G" + 2% CACL + 0.3% CA-32 + 0.5 % FL-33 + 1 GHSFP6L PUMPED TO 500 PSI AND BUMPED PUMP IN MINUTE STAGES SQUEEZING AWAY A TOTAL OF 0.6 BBL STAYING UNDER 500 PSI. STOPPED WHEN CONCERNED WITH QUICK SETFING. OFF LOADED PRODUCTION TANK FROM REDOUBT BARGE. HAUL WITH LOW BOY AND PETERBUILT. N/U BOP TEST BOP 250~3000 PSI SET WEAR RING. PJD TEST EQUIP. LAY DOWN 17.5'"' BHA. PIU BIT #2. BHA. SURFACE TEST MWD. RAN SOLIDS EQUIPMENT TO SALVAGE MAJOR PORTION OF SURFACE MUD. AOGCC WITNESSED BOP TEST. PRODUCTION CONTINUES TO INJECT WASTE FLUID. SHOVING CUTTINGS PILES AWAY FROM DUMP AREA WITH EXTENDED BLADE. RACK 5" DRILL PIPE TO PICK UP ON THE WAY IN THE HOLE. BHA. TEST MWD. RIH WI BIT #2. INSTALL DRIP PAN. CLEAN CMT FROM SHAKER VALVE. RIH. PICK UP SINGLES. ClRC HALF WAY IN FOR CONTAMINATED MUD. WASH CMT STRINGER AND TO BTM FI1826 TI1880' TEST CSG TO 3000 PSI. GOOD TEST. DRILL FLOAT EQUIPMENT AND 20' NEW HOLE TO 1946' ClRC AND ATTEMPT F.I.T. TO 12.5 EMW. FAILED. DRILL OUT OF SAND ZONE TO 1976' SPOT LCM PILL AND TEST FORMATION. POH FOR SHOE SQUEEZE. 8/2/0O 813100 814100 815100 8/6100 8/7700 8/8/00 8/9100 FINISH T.O.H. T.I.H.-FLOW CHECK WISPERRY~140' DRLG AND SURVEYING 12 114" HOLE- HOLE LOADING UP WITH CUTTINGS-PUMP HEAVY WT. SWEEPS-I:~,ISE MUD VIS. 47 TO 50 DRLG 12 %" HOLE FROM 2845' TO 4324'. MIX SWEEP. SWAP OUT ON PUMP---WORK ON PUMP. DRILL FROM 3424' TO 3502'. PUMP HI VIS. SWEEP. SURVEY-REAM-PUMP PILL. POOH, REAM TIGHT SPOT JUST BELOW SHOE. STOP ABOVE SHOE. PIU 5" D.P. RIH, SET UP SIS OFF DEAD MAN SENSOR FOR TRACKING DEPTH. SERVICE RIG, SURVEY, REAM TO BOTTOM. DRILL TO 3650' DRLG 12 114" HOLE FROM 3650' TO 3786'. PUMP SWEEP, PILL-BIDN TOP DRIVE TOH CliNG OUT BHA- COULD NOT PlU PWD(WRONG THREADS) RIH WI HWDP- CHG OUT 1 JT. SEVICE TOP DRIVE RIH- REAM LAST STD TO BTM. DRLG 12 114' HOLE FROM3786' TO 3840' DRILL FROM 3940' TO 4563', WEIGHT UP FROM 9.8 PPG TO 11.2 PPG WHILE DRILLING. CBU WHILE REPAIRING PUM DRIVE CHAIN. SHORT TRIP TO 3598'. PICK UP D.B. FROM WALK AND RIH TO 4563'. DRILL TO 4815'. ROTATE AND SLIDE FOR ANGLE. DRILL FROM 4815' TO 5284'. PUMP SWEEP AROUND. SHORT TRIP TO 4563'. DRILL FROM 5284' TO 5471'. REPAIR RIG, WORK ON PUMP. CIRC. WI #2 PUMP -WORK ON #1 PUMP MOTOR DRLG F/5471' TO 5517'-SURVEY-BALLED UP BIT ClRC,-MIX AND PUMP SWEEP TO UNBALL BIT- DID NOT WORK DRLG TO 5524' CBU-MIX DRY JOB-FLOW CK.-PUMP PILL POOH SLOWLY TO AVOID SWABBING-CLEAN CLAY OFF BHA RIG SERVICE-REPAIR MUD VALVES-DUMP VALVE ON HI-CLUTCH-AG. PADDLE FUNCTION TEST RAMS, BAG AND HCR VALVE -OK MIU BHA-TEST MWD-RIH SLOW TO 1915' PTSM-CUT AND SLIP DRLG. LINE RIH TO4850' FILL PIPE-RIH TO 5471' WASH AND REAM TO BTM ~5524'-DRLG TO 5428' PUMP SWEEP AND DRY JOB AT 6094' SHORT TRIP TO 5377'. NO PROBLEMS. DRLG FI 6094' TO 6194'. REPAIR RIG PUMP. SWAB AND OILER. DRLG FI 6194' TO PUMP SWEEP AND DRY JOB AT 6094' 8/10100 8111100 8112100 8113/00 SHORT TRIP TO 5377'. NO PROBLEMS. DRLG FI 6094' TO 6194'. REPAIR RIG PUMP. SWAB AND OILER. DRLG FI 6194' TO 6694'. LOCATED PLACE FOR MISSING BOLT ON TOP DRIVE. REPLACED. PUMPING SWEEPS TO HELP WITH BIT BALLING. RED DOG BARGE IN WITH MUD PRODUCTS AND 8 1/2" DRLG TOOLS. DEPARTED WITH DUMPSTER AND 1 TRAILER 3 JOINTS DAMMAGED DRILL PIPE. DRLG F16694' TO 6777' REPAIR MUD PUMP SWAB. DRLG FI 6777' TO 6805' INVESTEGATE 300 PSI PRESSURE LOSS AND LOSS OF MWD SIGNAL. DRLG FI 6805' TO 6815' CHECK SURFACE EQUIPMENT. CHARGE PULSATION DAMPNERS. POH WET. LOOK FOR WASH OUT. FOUND MWD PULSE UNIT EROSION. TEST BOP. AOGCC WAIVED WITNESS. CHANGE MUD MTR, MWD, JARS & RIH WI RR PDC BIT. PULLED OVER 40K IN AREAS OF NEW HOLE. CLEAR THEREAFTER. RIH WITH RR PDC BIT. GOOD HOLE. SLM NO CORRECTION. REAM 6682' TO BTM. DRLG FI6815' TO 6999' CHANGE SHAKER SCREENS. DRLG FI 6999' TO 7330'. DRLG FI 7330 TO 7401'. REPAIR MUD PUMP SWAB. DRLG FI 7401 TO 7436'. REPAIR DRIVE CHAIN ON #1 PUMP DRLG TO TD 7504'. ClRC SWEEP. HOLE CLEAN. SHORT TRIP. HOLE IN GOOD SHAPE. ClRC SWEEP. HOLE CLEAN. TRIP OUT UD BHA. PUMP 3BBL. H20-TEST LINES TO 3000~I-PUMP 40 BBL. SPACER & MCS-4 , DROP PLUG 2 BBL. H20,RELOAD HEAD PUMP 190 BBL. LEAD CMT. ~ 12.5#1 GAL-PUMP TAIL CMT. ~ 15.8 #/GAL. & AND DROP PLUG, 2BBL. H20 DISPLACE PLUG W/RIG PUMP ~ 8+ BBL.IMIN..-PLUG SET ~ 0900-6451 TOTAL STROKES. RIG DOWN BOP,s TO SET SLIPS-PUMP OUT PITS-RIG DOWN DRAIN PANS-RIG UP HYD RAMS-NIPPLE DOWN BTM SPOOL-RAISE STACK-CENTER PIPE SET SLIPS WI 100,000~ WHILE CLEANING PITS CUT HOLE AND DRAIN CSG.- MAKE ROUGH CUT-MAKE FINAL CUT AND DRESS STUB-SET STACK DOWN. NIPPLE DOWN AND REMOVE ADPT. SPOOL-REMOVE FLOW NIPPLE-INSTALL AND TEST 13 3~8" TBG. 300C~ FLANGE SLIPS AND PACKOFF TO 3000 PSI FOR 15 MIN. 8114100 8115100 8/16~00 8117100 8118100 NIPPLE UP ADAPTOR FLANGE-BOP,s-RISER -FLOW LINE-TRIP TANK& LINES-FILL UP LINES- AND DRIP PANS WHILE CLEANING PITS. TEST CHOKE MANIFOLD WHILE NIPPLEING UP RIG UP TO TEST BOP- CLEAN PITS TESTING BOP,s-TESTED ALL BOP EQUIP. TO 250-5000 PSI-ANNULAR TO 250-3500 INSTALL DRIP PANS AND RIG DOWN TEST EQUIP. INSTALL WEAR RING 10 112" O.D. BY 10" I.D.-MAKE UP SAVER SUB ON TOP DRIVE FINISH INSTALLING DRIP PANS- CLEAN MUD TANKS-STRAP D.P. ON RACKS-FIX WATER PUMP ON CAN/RIG T.D. MOTOR-SEAL RIG FLOOR CONTINUE CLEANING PITS WI SUPERSUCKER-HAUL O.B. MUD AND FILL VOLUME TANK P/U MULE SHOE AND RUN IN HOLE WI HWDP- LAY DOWN 12 JTS. OF HWDP TEST CHOKE MANIFOLD WHILE NIPPLING UP, RIG UP TO TEST BOPE, CLEAN PITS. TEST BOPS. INSTALL DRIP PANS AND RIG DOWN TEST EQUIPMENT. INSTALL WEAR RING, MAKE UP SAVER SUB ON TOP DRIVE. FINISH INSTALLING DRIP PANS, CLEAN MUD TANKS, STRAP D.P. FIX WATER PUMP ON CANRIG UNIT. CLEAN PITS AND FILL VOLUME TANK WITH OIL BASE MUD. PIU MULE SHOE AND RUN IN HOLE WITH HWDP. LAY DOWN 12 JOINTS OF HWDP. CLEAN MUD PITS. PREP FOR OIL BASE MUD. PIU 5" DRILL PIPE. RIH WITH MULE SHOE. TAG UP ON FLOAT COLLAR AT 7419'. RIG TO DISPLACE. REVERSE ClRC AND DISPLACE WITH OIL BASE MUD. RETURNS TO INJECTION. TEST CSG TO 3000 PSI GOOD TEST. PJD ClRC LINES. POH. PICK UP BHA AND BIT #5. M/U BHA. RIH WI BIT #5. SLOW DUE TO VERY THICK RETURNS. DRILL FLOAT EQUIPMENT AND 20' OF NEW HOLE TO 7524'. CIRC AND PERFORM FORMATION INTEGERTY TEST TO 11 PPG EMW. GOOD TEST. DRILLING FROM 7524' TO 8026' WITH PDC BIT. ADDED 47 BBLS MAPCO 200 TO MUD SYSTEM. 190 BARRELS MORE OF MAPCO 200 DUE IN THIS AM ON BARGE. STILL REMOVING THE REMNENTS OF WATER BASE MUD FROM SOME PARTS OF THE MUD PITS. NABOR'S CENTRIFUGE IS IN SERVICE. PRODUCTION IS WORKING ON INJECTING THE INTERFACE PORTION OF THE DISPLACMENT. DRLG FROM 8025' TO 9080'. ADJUSTING ANGLE WITH BIT WEIGHT AND ROTORY SPEED. MADE ONLY ONE SLIDE OUT FROM UNDER SHOE. RACK DRILL PIPE TO PICK UP ON NEXT SHORT TRIP. CONTINUE TO REMOVE LAST OF WATER BASED MUD FROM SLOP TANK. 8119100 DRLG FROM 9048' TO 9244' CIRC BTMS UP. PUMP SLUG AND SHORT TRIP TO SHOE. WORK THROUGH TIGHT HOLE AT 8803. TIGHT AGAIN AT 7735. PUMPED SWEEP AND UPREAMED INTO SHOE. SERVICE RIG. SERVICE TOP DRIVE. RIH. PICK UP 48 JOINTS DRILL PIPE. REAM TIGHT SPOTS 7640', 8115', 8336' AND FROM 9062' TO BOTTOM DRLG FORM 9244 TO 9327' 8/20100 DRLG FI9327 TI 9899' CIRC BTMS UP. PUMP SWEEP. ClRC HOLE CLEAN. DRY JOB. SHORT TRIP TO 8500'. HOLE IN GOOD SHAPE. RUNNING BACK TO BTM AT REPORT TIME. HOLE TAKING A LITTLE FLUID. MOST FLUID LOSS AS CUTTING RETENTION. 8121/00 FINISH SHORT TRIP. HOLE IN GOOD SHAPE. DRLG FI9899' TO 10450' HOLE CONTINUES TO TAKE FLUID. LOST APPROX 40 BBLS LAST 24 HRS. UNABLE TO RUN MUD CLEANER DUE TO LOW PIT VOLUME. RUNNING CENTRIFUGE CONTINOUSLY. MUD IN VERY GOOD SHAPE. SOLIDS STAYING AT 10%. MUD WT STILL AT 9.1 PPG. FLEW IN 4400 GALS (TWO PLANE LOADS) MAPCO 200. RUNNING THE MAJOR PORTION OF RETURNS OVER FINER SCREENS ON SHAKER. 8122/00 DRLG. FROM 10450' TO 10485'FINISH SHORT TRIP. CIRC. WORK PIPE AND RECIPROCATE. PUMP SWEEP-MONITOR WELL-PUMP PILL MAKE 10 STD. SHORT TRIP-HOLE IN GOOD SHAPE. DRLG. 8 112' FROM 10485' TO 10838' HOLE IS STILL TAKING MUD ~ 100 BBLS.+IDAY UNABLE TO RUN MUD CLEANER DUE TO LOW PIT VOLUME.WILL BUILD VOLUME TODAY. RUNNING CENTRIFUGE CONTINOUSLY. MUD IN VERY GOOD SHAPE. SOLIDS STAYING AT 10%, MUD WT AT 9 PPG. FLYING IN MAPCO 200. EVERTS WILL DELIVER SIX MORE LOADS TODAY. RUNNING THE MAJOR PORTION OF RETURNS OVER FINER SCREENS ON SHAKER. 8/23100 TEST BOPs.-ALL SYSTEMS 250 PSI TO 4000 PSI- HYDRIL TO 3000 PSI. CLEAN RIG FLOOR MAKE UP BHA RIH WI BHA AND HWDP-TEST MWD. RIH-PIU 90 JTS. 5" DP OFF CATWALK. SERVICE TOP DRIVE-HOLD SPILL DRILL & SAFETY MEETING WI TOOL PUSHER AND DRLG. SUPT. RIH. ADJUST LINK TILT ON TOP DR.-PIPE TO TALL ,HITS TOP DR., WOULD NOT LATCH ONTO PIPE. EXT BAILS 6". RIH CUT AND SLIP DRLG. LINE-SERVICE RIG. ATTEMPT TO FILL PIPE-TOP DR. MUD SAVER VALVE FAILED. REPAIRING MUD SAVER VALVE ON TOP DR. 8124100 TEST BOPs.-ALL SYSTEMS 250 PSI TO 4000 PSI- HYDRIL TO 3000 PSI. CLEAN RIG FLOOR MAKE UP BHA RIH WI BHA AND HWDP-TEST MWD. RIH-PIU 90 JTS. 5" DP OFF CATWALK. SERVICE TOP DRIVE-HOLD SPILL DRILL & SAFETY MEETING WI TOOL PUSHER AND DRLG. SUPT. RIH. ADJUST LINK TILT ON TOP DR.-PIPE TO TALL ,HITS TOP DR., WOULD NOT LATCH ONTO PIPE. EXT BAILS 6". RIH CUT AND SLIP DRLG. LINE-SERVICE RIG. ATTEMPT TO FILL PIPE-TOP DR. MUD SAVER VALVE FAILED. REPAIRING MUD SAVER VALVE ON TOP DR. 8125100 RIG REPAIR- REPAIRING MUD SAVER VALVE ON TOP DRIVE RIH DRLG- ROT. SLIDE AND SURVEY TOOK #2 PUMP OFF LINE- REPAClNG WASH PLATE-DRLG AHEAD W/~I PUMP ~ 106 STKS 2150 PSI 8126100 DRLG FROM 11191' TO 11490' CIRC.-MIX AND PUMP HI-VIS SWEEP WHILE REPAIRING f~2 PUMP. STOPPED DRLG. UNTILPUMP REPAIRED. DRLG. FROM 11490' TO 11493' SWAB OUT ON #1 PUMP- CIRC. AND ROTATE PIPE WHILE REPAIRING PUMP. DRLG. FROM 11493' TO 11511'. CIRC.-PUMP HI-VIS SWEEP BEFORE SHORT TRIP SIX STD. SHORT TRIP.-PULL TIGHT ~ 11268' BACKREAM TO 11304'-HOLE OK DRLG. FROM 11511' TO 11735'-ROTATE SLIDE AND SURVEY 8/27/00 DRLG. 8 112" HOLE FROM 11735' TO 11912' CIRC. HI-VIS SWEEP, PUMP PILL. SIX STD. SHORT TRIP - HOLE OK, NO PROBLEMS DRLG 8 112" HOLE FROM11912' TO 12095'. 8/28100 DRILL FROM 11912' TO 12250'. CIRC HI-VIS SWEEP, PUMP SURVEY UP, PUMP PILL MONITOR WELL, FIVE STAND SHORT TRIP--HOLE O.K.--NO PROBLEMS. SWAB WASHED OUT, DRILL WITH I PUMP, PUMP HI VIS SWEEP. 8129100 DRLG FI 12350' TO 12426'. 8~30~00 RIH WITH BIT # 7. TEST MWD. SERVICE RIG. SERVICE TOP DRIVE. HOOK UP CROWN ALARM. RIH. FILL PIPE AT 10000'. DRLG FI 12426' TO 12740' REAMED LAST STAND TO BTM. NO HOLE PROBLEMS. 8/31100 MAJORITY OF FOOTAGE MADE THIS AM IS SLIDING. DRLG FROM 12740' TO 12986'. CIRC SWEEP. SHORT TRIP 600'. NO HOLE PROBLEMS. DRLG FROM 12986' TO 13175' SLIDE 60' ROTORY DRILL 30' EACH CONNECTION. CIRC SWEEP AND HOLE CLEAN. POH WITH BIT # 6. PIU BIT # 7. BHA CHANGE. ORIENT MWD. CHECK PULSE. RIH WITH BIT # 7 911100 DRLG FROM 13175' TO 13342' ClRC SWEEP AND HOLE CLEAN. SHORT TRIP TO 9 5~8" SHOE. NO HOLE PROBLEMS. BACK ON BOTTOM AT REPORT TIME. CIRCULATING FOR LOGS. UNABLE TO FLY IN MAPCO 200 DUE TO AIRPLANE TROUBLE. FLEW IN SCHLUMBERGER LOGGING TOOLS. SLING LOADED LINER HGR INTO BAKER SHOP FOR REPAIRS. CREWS CONDUCTING DRILLS EACH TOUR. FIRE, SPILL, BOP ECT. 9/2100 LOG WITH SCHLUMBERGER. LOGGED TO 13300' STOPPED 42' FROM BOTTOM. ULTRASONIC BOREHOLE IMAGER - GAMMA RAY. TEST BOP. AOGCC WITNESSED. ONE FAILURE AT CHOKE MANIFOLD VALVE. REPAIRS TO BE MADE. MAKE UP STIFF BHA AND RIH TO SHOE. BREAK CIRC. CUT DRLG LINE. RiH. STOP AT BRIDGE AT 13272' 913100 914100 LOG WITH SCHLUMBERGER. LOGGED TO 13300' STOPPED 42' FROM BOTTOM. ULTRASONIC BOREHOLE IMAGER - GAMMA RAY. TEST BOP. AOGCC WITNESSED. ONE FAILURE AT CHOKE MANIFOLD VALVE. REPAIRS TO BE MADE. MAKE UP STIFF BHA AND RIH TO SHOE. BREAK CIRC. CUT DRLG LINE. RIH. STOP AT BRIDGE AT 13272' WASH BRIDGE AND TO BTM. ClRC FOR LOGS. CIRC AT BTM. SHORT TRIP TO 12740' SIX STANDS. NO HOLE PROBLEMS. CIRC HOLE CLEAN. PUMP SWEEP. POH. RACK DRILL STRING FOR CSG JOB. RIG TO RUN PIPE. RUN 7 5~8" CSG. WITH 80' SHOE TRACK. 2500' AT REPORT TIME. 9~5~00 9/6/00 9/7100 919100 9/10100 RIH WI 7 518" CSG. SECURE STABBING BOARD-CLEAN OBM FROM ELEVATORS AND RIG DOWN SAME. PIU AND MAKE UP LINER HANGER & RUNNING TOOL-UP CSG. VVT. 170K-DOWN CSG. WT. 135K. CLEAN OBM FRON CSG. AND RIG DOWN CSG.EQUIPMENT. MIX GEL AND POUR IN TOP OF HANGER.-RIH WI 15 STDS. 5" D.P. RIH TO SHOE. FILL PIPE AND CIRC. MIU CMT HEAD. RIH. CIRC AT 9700. RUN CSG TO 13336'. PIU CMT HEAD. CIRC. WORK PIPE. LINER CAME LOOSE FROM DRILL STRING BUT REMAINED STABBED IN ON BTM ~ 13342' CIRC LINER ANNULUS CLEAN AT 4BBL/MIN 1000 PSI. SAFETY MEETING. RIG TO CEMENT. LINE TEST. PUMP 20 BBL H20, 40 BBL PREFLUSH FOLLOWED BY CMT. DISPLACING AT REPORT TIME. PUMP 34 BBL. CMT.-DROP WIPER PLUG-DISPLACE WI RIG PUMP-PUMP 402 BBLS. MUD- BUMP PLUG,HOLD 1700 PSI FOR 15 MIN.-CIP ~ 0720 HRS.SET DOWN WT. 45-50K. TO CHECK PACKER SET.- UNSTING FI LINER. REVERSE CIRC.-PUMP DRY JOB. LAY DOWN BAKER CMT. HEAD-POOH LAYING DOWN 5" D.P. POOH- STAND BACK 17 STDS.- PIU SINGLE LAY DOWN AND REPLACE 1JT. LAY DOWN RUNNING TOOL. BRING DOWN TP BLOWER HOSE TO REPAIR. RIH WI DC & HWDP. LAY DOWN 5" HWDP, DC &STAB. BREAK STAB. SLEEVES. CLEAN RIG FLOOR,PULL WEAR BUSHING ,CHANGE OUT BOTTOM RAMS,\FI5" TO 3 1/2".- TEST TO 4000 PSI HOLD 112 HR. RIG DOWN TEST EQUIP.-SET WEAR BUSHING. TEST CSG. TO 3000 PSI-HOLD 1102 HR. GOOD TEST. REPOSITION STABBING BOARD- ATTEMPT TO HOOK UP BLOWER HOSE TO TOP DRIVE. P/U 4 3~4" BHA TO RIG FLOOR-MAKE UP 6 3~4" BIT AND BHA. FINISH PICKING UP BHA-ORIENT AND TEST BHA RIH PICKING UP 3 1/2" DP-(DRIFT PIPE) HOOK UP TD BLOWER HOSE IN DERRICK CHG. TO 5" ELEVATORS-MAKE UP STD.-BREAK CIRC.-CK. MWD. RIH TO 13249' INSTALL BLOWER HOSE TO TD. RIH FI 13249' TO 13256'- TAGGED L/C ~ 13256'. 9~8~00 DRLG. F/13342' TO 13359'. CIRC. FI FIT TEST. FIT TEST WI9.2 PPG. ~ 11.0 PPG EMW. DRLG FI 13359' TO 13626'. ROT. % SLIDE.-PUMPED 30 BBL. SWEEP ~ 2230 HRS. CBU-CHECK FOR FLOW-PUMP DRY JOB. POOH- HAD TO ROTATE STRING TO GET THROUGH THE SHOE. POOH, DRY JOB FOR 3 1.2' D.P. POOH, WORK BHA AND BREAK BIT, CLEAN RIG FLOOR. MAKE UP BHA, RIH, PJSM, PICK UP 30 JOINTS 3 ~" D.P. CUT 140' DRILLING LINE. TRIP IN HOLE. REAM AND WASH TO BOTTOM. DRLG. 6 3~4" HOLE FROM 13635' TO 13915' S.P.R.-DRLG. FI 13915' TO 13984'- DRILLSTRING TORQUEING UP, 14.3K CIRC.-MONITOR WELL POOH TO SHOE DROP DART- CIRC.- BLOW CIRC. SUB-CHECK FLOW-PUMP DRY JOB POOH GAS SHOWS IN "G" SANDS 9111100 POOH BREAK BIT-DOWNLOAD MWD L/D MWD-L/D STAB-CHECK FLOAT-P/U 3 1/2" SINGLE FOR STANDBACK-PULL DIR. PROBE RIG UP TO TEST BOP TEST BOP,s -HYDRIL TO 3000#-ALL RAMs &VALVES TO 4000~ RETRIEVE TEST PLUG-SET WEAR RING-L/D TOOLS- CLEAN RIG FLOOR REPAIR LINE ON HIGH CLUTCH MIU BIT & STAB-L/D 31/2" SINGLE-LOAD MWD RIH TO TOP OF HWDP- MAKE UP PUMP OUT SUB AND MWD MWD NOT TESTING-WORK ON AND REPLACE TWO TOOLS-THIRD TOOL SENDING SIGNALS TRIP IN HOLE DRLG 6 3/4" HOLE 9112100 DRLG WITH BIT #11 FI14027' TO 14236" UNABLE TO SLIDE AT 14236'. CIRC POH TO SHOE. NO HOLE PROBLEMS. SHEER OUT ClRC SUB. CIRC AT MAX RATE, ClRC HOLE CLEEN. DRY JOB. TRIP FOR BIT # 11. 9113100 POH WITH BIT # 11 CHANGE OUT MUD MOTORS/BIT # 12 ORIENT/CHANGE OUT MWD PROBE. TEST MWD TIH SERVICE TOP DRIVE AND RIG TIHI NO HOLE PROBLEMS DRILLING FROM 14236 TO 14407 9114/00 DRLG. 6 314' HOLE (SLIDE AND ROTATE) CIRC., POOH TO SHOE. DROP DART -BLOW CIRC. SUB(~ 1900 PSI-CIRC. ~ GPM-RT. AND WORK PIPE-ClRC 9600 STKS. MONITOR WELL FOR 10 MIN.-PUMP DRY JOB, POOH WI 5' DP. CliNG. TO 3 1/2' EQUIP. POOH MAKE UP BIT #13-CHNG. BHA-MOVE STAB-FLOW TEST SIS MTR. RIH 9115~00 RIH CUT AND SLIP DRLG. LINE RIH TO 13340'-FILL PIPE ~ SHOE-RIH TO 14367'-WASH AND REAM FI 14367' TO 14532'. - SURVEY WI SPERRY SUN. DRLG. 6 3/4" HOLE FROM 14532' TO 14676' 9116100 DRLG FI 14676' TO 14708'. CIRC. AND WORK PIPE PULL TO SHOE DROP DART, OPEN PUMP OUT SUB-CIRC HOLE (~ HIGH VELOCITY MONITOR WELL- PUMP PILL-POOH MIU BIT- CHECK SPERRY SUN MWD- CHANGE OUT PROBE SERVICE RIG TOP DRIVE RIH FILL PIPE-TEST MWD RIH 9117~00 FILL PIPE-SERVICE TOP DRIVE RIH- WASH AND REAM FI 1455' TO 14708' DRLG.ClRC AND SURVEY FI 14708' TO 14955'-NO SHOWS PAST THE TOP OF THE WESTFORELANDS. 9118~00 DRLG. FI 14955' TO 14963'-TD. CIRC. AND WORK PIPE-BOTTOMS UP. POOH TO SHOE. CUT AND SLIP DRLG. LINE. RIH ClRC.SWEEP POOH TO SHOE-(SLM) DROP DART-BLOW OUT CIRC. SUB-CIRC. MONITOR WELL-PUMP PILL. POOH-SLM-NO CORRECTION. LAY DOWN BHA. RIG UP SWS TO RUN WIRELINE LOGS. FORMATION SUMMARY 1930 SAND = VERY LIGHT GRAY; CLAST SIZE RANGES FROM FINE UPPER TO MEDIUM LOWER; SUB ANGULAR OCCASIONALLY ANGULAR; POOR TO MODERATE SPHERICITY; SCATTERED CHIPPED AND PITTED GRAINS; OCCASIONALLY POLISHED CONGLOMERATE FRAGMENTS; NO VISIBLE MATRIX MATERIAL DOMINANTLY GRAIN SUPPORT; COMPOSED OF 20-30% QUARTZ, 80-60% CHERT, 0-10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY. 1990 SAND = VERY LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE UPPER; SUBANGULAR POOR TO MODERATE SPHERICITY; MODERATELY TO OCCASIONALLY WELL SORTED; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; NO VISIBLE MATRIX MATERIAL; APPEARS SUB ARENACEOUS; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; GOOD ESTIMATED POROSITY AND PERMEABILITY. 2045 COAL/CARBONACEOUS SHALE AND CLAY = DARK BROWNISH GRAY TO BLACK; GRADES TO CARBONACEOUS SHALE; PREDOMINANTLY FIRM; DULL EARTHY LUSTER; STRIATED TO WOODY TEXTURE OCCASIONALLY SMOOTH IN LIGNITIC COALS; PLATY FRACTURE ALONG LINES OF WEAK CLEAVAGE AND CLAY LAMINATIONS; COMPOSED OF VARIOUS LITHS OF CARBONACEOUS SHALE TO CARBONACEOUS CLAY AND GRADING TO SUB LIGNITIC TO LIGNITIC COAL. 2100 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM FINE UPPER TO VERY FINE UPPER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MODERATE TO POOR SORTING; SCATTERED CHIPPED AND PITTED GRAINS; NON TO VERY WEAK SILICEOUS CEMENT; VERY SLIGHT HYDROPHILIC CLAY MATRIX; DOMINANTLY GRAIN SUPPORT; OVERALL CLEAN SAND; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY. 2150 TUFFACEOUS CLAYSTONE = LIGHT GRAY; VERYSOFT; LUMPY TO CLUMPY; MUSHY; COHESIVE;IRREGULAR FRACTURE; MASSIVE HABIT; MODERATE EARTHY LUSTER; ASHY TEXTURE; MASSIVE BED OF FINE GRAIN SAND AND CLAY; VERY HYDROPHILIC IN NATURE. 2185 CARBONACEOUS SHALE/CLAY = BLACK TO BROWNISH GRAY; FIRM TO SOFT; SLIGHT AMTOF COAL; DULL EARTHY LUSTER; STRIATED TO SMOOTH TEXTURE; COMPOSED OF CARBONACEOUS SHALE, CARBONACEOUS CLAY; GRADES TO LOW GRADE LIGNITE. ]3 2215 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FINE UPPER TO VERY FINE UPPER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MODERATE TO POOR SORTING; SCATTERED CHIPPED AND PITTED GRAINS; ABUNDANT CLAY MATRIX; PREDOMINANTLY CLAY MATRIX SUPPORTED; VERY HYDROPILIC CLAYS; MOST GOING INTO SOLUTION; COMPOSED OF 20% QUARTZ, 70% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; POOR POROSITY AND PERMEABILITY. 2270 TUFFACEOUS CLAYSTONE = LIGHT GRAY; VERY SOFT, MUSHY; SLIGHTLY COHESIVE; PREDOMINANTLY HYDROPHILIC; LUMPY HABIT; OCCASIONALLY FORMS LARGE EXPANSIVE CLUMPS; MASSIVE; ASHY TO CLAYEY TEXTURE; MODERATE EARTHY LUSTER; PROBABLY HAS THIN INTERBEDS OF CARBONACEOUS SHALE AND FINE SAND. 2310 CARBONACEOUS SHALE/CLAY = BLACK TO DARK BROWNISH GRAY; SOFT TO FIRM; DULL EARTHY LUSTER; STRIATED TO MATTE TEXTURE; COMPOSED OF VARIOUS DEGREES OF LIGNITE AND CARBONACEOUS SHALE AND CLAY IN VERY THIN LAMINATIONS AND BEDS. 2345 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM FINE UPPER TO VERY FINE UPPER; SUB ROUNDED TO SUB ANGULAR; MODERATE SPHERICITY; MODERATELY TO POORLY SORTED; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; ABUNDANT CLAY MATRIX ^T2360; DOMINANTLY CLAY MATRIX SUPPORT; VERY HYDROPHILIC; COMPOSED OF 30-40% QUARTZ, 50-60% CHERT, 10% METAMORPHIC, FELDSPAR, TUFF AND VARIOUS LITHIC FRAGMENTS; POOR POROSITY AND PERMEABILITY. 2405 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE UPPER; SUB ROUNDED-SUB ANGULAR; MODERATE SPHERICITY AND SORTING; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT AND MATRIX MATERIAL; PREDOMINANTLY GRAIN SUPPORTED; COMPOSED OF 30-40% QUARTZ, 60-50% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY. 2455 TUFFACEOUS CLAYSTONE = VERY LIGHT GRAY; VERY SOFT; LUMPY TO CLUSTERED; MUSHY;IRREGULAR FRACTURE; MASSIVE TO AMORPHOUS HABIT; MODERATE EARTHY LUSTER; ASHY TEXTURE; MASSIVE BEDS OF GRAD FINE GRAIN SAND AND CARBONACEOUS MATERIAL (LAMINAE). 2490 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE UPPER; SUB ROUNDED-SUB ANGULAR; MODERATE SPHERICITY; MODERATELY TO OCCASIONALLY WELL SORTED; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; PREDOMINANTLY GRAIN SUPPORTED WITH SLIGHT HYDROPHILIC CLAY MATRIX; COMPOSED OF 40% QUARTZ, 50% CH 10% METAMORPHIC, FELDSPAR, TUFF AND VARIOUS LITHIC FRAGMENTS; FAIR TO GOOD ESTIMATED POROSITY AND PERMEABILITY. ]4 2545 TUFFACEOUS CLAYSTONE = VERY LIGHT GRAY; VERY SOFT; LUMPY TO CLUSTERED; MUSHY; AMORPHOUS FRACTURE; AMORPHOUS HABIT; MODERATE EARTHY LUSTER; ASHY TEXTURE; VERY HYDROPHILIC; OCCASIONALLY FINE GRAIN SAND INTERBEDDED AND SCATTERED; COARSE GRAIN SAND/CONGLOMERATE AT 2585-2595. 2585 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE UPPER; SUB ROUNDED TO SUB ANGULAR; MODERATE SPHERICITY; MODERATELY SORTED; PITTED TO CHIPPED TEXTURE; ABUNDANT CLAY PACKED MATRIX BECOMING HYDROPHILIC; MATRIX SUPPORTED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR, TUFF, GREENSTONE AND VARIOUS LITHIC FRAGMENTS; FAIR TO POOR POROSITY AND PERMEABILITY. 2640 TUFFACEOUS CLAYSTONE = VERY LIGHT BROWNISH GRAY; VERY SOFT; LUMPY TOCLUSTERED; CLOTTED TO GELATINOUS; MUSHY; AMORPHOUS FRACTURE AND HABIT; DULL EARTHY LUSTER; WET ASHY TEXTURE; MASSIVE GRAD BEDS OF FINR TO MEDIUM GRAIN SAND AND VERY HYDROPHILIC CLAY. 2680 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE LOWER; SUB ANGULAR-SUB ROUNDED; MODERATE SPHERICITY; MODERATE TO POOR SORTING; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; ABUNDANT CLAY PACKED MATRIX; DOMINANTLY MATRIX SUPPORTED; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC, FELDSPAR, TUFF AND VARIOUS LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY. 2735 TUFFACEOUS CLAYSTONE = VERY LIGHT BROWNISH GRAY; VERY SOFT; LUMPY TO CLUSTERED; CLOTTED TO GELATINOUS; MUSHY; AMORPHOUS FRACTURE AND AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; WET ASHY TEXTURE; MASSIVE HOMOGENEOUS CLAY BEDDING. 2770 TUFFACEOUS CLAYSTONE = VERY LIGHT BROWNISH GRAY; VERY SOFT; LUMPY TO CLUSTERED; CLOTTED TO GELATINOUS; MUSHY; AMORPHOUS FRACTURE AND AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; WET ASHY TEXTURE; MASSIVE HOMOGENEOUS CLAY BEDDING. 2805 COAL = BLACK TO DUSKY BROWN; FIRM; BRITTLE; DULL TO SLIGHTLY RESINOUS LUSTER; SLIGHTLY ROUGH SURFACE TEXTURE; NON CALCAREOUS; LOCALLY COMMON THIN CLAY LAMINATIONS; SCATTERED GAS BUBBLES ON FRACTURE SURFACES. 2835 TUFFACEOUS CLAYSTONE = VERY LIGHT BROWNISH GRAY; VERY SOFT TO SOFT; MUSHY TO STIFF, OCCASIONALLY RUNNY AND GELATINOUS, RARELY POORLY TO FAIRLY INDURATED IRREGULAR SHAPED CUTTINGS; MATTE, EARTHY LUSTER; GRITTY TO SMOOTH TEXTURE; NON TO SLIGHTLY CALCAREOUS; COMMON CARBONACEOUS SPECKS; COMMON ASHY APPEARANCE; LOCALLY COMMON GLASSY SHARDS. 2880 SAND = CLEAR, TRANSLUCENT WHITE, LIGHT GRAY, BLACK, WHITE; CLASTS RANGE FROM VERY FINE TO MEDIUM, DOMINANTLY FINE GRAIN; ANGULAR TO OCCASIONALLY ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 50% QUARTZ, 30% IGNEOUS/METAMORPHIC/VOLCANIC LITHICS 10% WEATHERED FELDSPARS; 10% CHERT; APPEARS GRAIN SUPPORTED CLAY MATRIX INFERRED; NO ACID REACTION; ESTIMATED FAIR VISUAL POROSITY AND PERMEABILITY. 2930 TUFFACEOUS CLAYSTONE = VERY LIGHT TO LIGHT BROWN; VERY SOFT TO RARELY SLIGHTLY FIRM; DOMINANTLY APPEARS AS SOLUBLE, STICKY TO RUNNY CLAY, OCCASIONALLY AS POORLY INDURATED, IRREGULARLY SHAPED CUTTINGS; MATTE, EARTHY LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY GRITTY TEXTURE;NON TO RARELY SLIGHTLY CALCAREOUS; COMMON BLACK CARBONACEOUS SPECKS AND STREAKS; COMMON ASHY APPEARANCE; SCATTERED TO COMMON GLASSY SHARDS. 2980 COAL = BLACK TO DUSKY BROWN; FIRM; BRITTLE; SPLINTERY CUTTINGS; MATTE TO SLIGHTLY SHINY LUSTER; SMOOTH TO SLIGHTLY GRAINY SURFACE TEXTURE; OCCASIONALLY WOODY STREAKS; RARE THIN CLAYSTONE LAMINATIONS; OCCASIONALLY ARGILLACEOUS, GRADING TO CARBONACEOUS SHALE. 3040 SAND = CLEAR, TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, DARK GREEN, BLACK, WHITE; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY FINE GRAINED, TRACE GRANULE SIZE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB-ROUND; POORLY SORTED; COMPOSED OF50% QUARTZ, 30% IGNEOUS/METAMORPHIC/VOLCANIC LITHICS, 10% CHERT, 10% FELDSPARS; COMMON PITTED GRAINS; COMMON BIT SHEARED GRAINS; UNCONSOLIDATED IN SAMPLES; CLAY MATRIX INFERRED; NO ACID REACTION; ESTIMATED FAIR TO POOR VISUAL POROSITY AND PERMEABILITY.. 3110 TUFFACEOUS CLAYSTONE = LIGHT BROWN TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT DOMINANTLY APPEARS AS AMORPHOUS LUMPS; RUNNY TO STIFF; STICKY, COHESIVE; RARELY APPEARS AS IRREGULAR SHAPED POORLY INDURATED CUTTINGS; MATTE, EARTHY LUSTER WITH SMOOTH TO OCCASIONALLY MODERATE GRITTY TEXTURE; NON TO OCCASIONALLY MODERATELY CALCAREOUS IN SELECTED ZONES; COMMON CARBONACEOUS SPECKS; COMMON ASHY STREAKS; SCATTERED TO COMMON VOLCANIC GLASS SHARDS; LOCALLY SLIGHTLY SILTY; STRUCTURELESS. 3170 SAND = CLEAR, TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, MEDIUM TO DARK GREENISH GRAY, BLACK; CLASTS RANGE FROM VERY FINE UPPER TOMEDIUM UPPER; DOMINANTLY FINE GRAIN RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMMON POLISHED GRAINS, COMMON BIT CHIPPED GRAINS; COMPOSED OF 60% QUARTZ, 30% LITHICS, 20% CHERT, SCATTERED FELDSPARS; DISAGGREGATED IN SAMPLES; CLAY MATRIX INFERRED; ESTIMATED FAIR TO POOR VISUAL POROSITY AND PERMEABILITY. 3230 SAND/CONGLOMERATE = CLEAR, WHITE, LIGHT GRAY, MEDIUM TO DARK GREENISH GRAY, BLACK; CLASTS RANGE FROM VERY FINE UPPER TO GRANULE SIZE; DOMINANTLY FINE GRAIN RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; POORLY SORTED; COMMON POLISHED GRAINS, COMMON BIT SHEARED GRAINS; OVERALL GRAIN SIZE INCREASES THROUGH THIS INTERVAL WITH INCREASING DEPTH; COMPOSED OF 70% QUARTZ, 20% IGNEOUS/METAMORPHIC/VOLCANIC LITHICS; 10% CHERT; SCATTERED WEATHERED FELDSPARS; GRAINS ARE LOOSE IN SAMPLE; NO ACID REACTION; GRAIN SUPPORTED INFERRRED; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. 3310 TUFFACEOUS CLAYSTONE = VERY LIGHT BROWN TO PALE YELLOWISH BROWN; VERY SOFT TO RARE SLIGHTLY FIRM; DOMINANTLY APPEARS AS RUNNY TO STIFF AMORPHOUS CLAY, OCCASIONALLY AS SOFT POORLY INDURATED IRREGULAR SHAPED CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATELY GRITTY TEXTURE; DOMINANTLY NON CALCAREOUS, OCCASIONALLY MODERATELY TO VERY CALCAREOUS IN THIN BEDS; ASHY APPEARANCE; COMMON VOLCANIC GLASS SHARDS WITH THE APPEARANCE OF VERY FINE SAND GRAINS; COMMON BLACK CARBONACEOUS SPECKS; OCCASIONALLY SLIGHTLY SILTY. 3375 COAL = BLACK, RARELY DUSKY BROWN; FIRM; BRITTLE; SMALL SPLINTERY, PLATY AND IRREGULAR CUTTINGS; SLIGHTLY SHINY LUSTER; SMOOTH TO SLIGHTLY ROUGH SURFACE TEXTURE; SCATTERED THIN CLAYSTONE LAMINATIONS; RARE CONCHOIDAL FRACTURE SURFACES. 17 3410 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; PITTED TO CHIPPED TEXTURE NON TO VERY WEAK SILICEOUS CEMENT; MODERATE TO ABUNDANT CLAY PACKED MATRIX; GRAIN AND MATRIX SUPPORTED; ALL CLAY IS VERY HYDROPHILIC; SAND COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, TUFF AND VARIOUS LITH FRAGMENTS; POOR TO FAIR ESTIMATED POROSITY AND PERMEABILITY. 3505 SAND = CLEAR, TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, MEDIUM TO DARK GREEN, BLACK, CHALKY WHITE; CLASTS RANGE FROM VERY FINE TO MEDIUM, DOMINANTLY FINE RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 50% QUARTZ, 30% IGNEOUS/METAMORPHIC/VOLCANIC LITHICS, 10% CHERT, 10% FELDSPARS; TRACE MUSCOVITE; GRAINS ARE LOOSE IN SAMPLE; CLAY MATRIX INFERRED; NO ACID REACTION; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. 3565 SAND=CLEAR, TRANSLUCENT, MILKY WHITE, GRAINS RANGE FROM VERY FINE TO MEDIUM DOMINANTLY FINE, ANGULAR TO SUB ROUNDED, DOMINANTLY ANGULAR, MODERATELY SORTED; COMPOSED OF 60% QUARTZ, 30% IGNEOUS/METAMORPHICNOLCANIC LITHICS, 10% CHERT; SAMPLE IS 100% DISAGREGRATED GRAINS, NO ACID REACTION, GOOD VISUAL POROSITY AND PERMEABILITY. 3610 SAND=CLEAR, MILKY WHITE, TRANSLUCENT; UPPER FINE TO MEDIUM GRAIN, DOMINANTLY MEDIUM; SUB ANGULAR TO ROUNDED, DOMINANTLY SUB ROUNDED; MODERATELY WELL SORTED; SAND IS COMPOSED OF 70% QUARTZ, 20% DARK LITHIC/METAMORPHIC FRAGMENTS AND 10% LIGHT GRAY CHERT; SAMPLE IS 100% DISAGREGRATED, FLOATING GRAINS; NO ACID REACTION; INFERRED SOLUBLE CLAY MATRIX; GOOD POROSITY. 3665 CLAYSTONE = DOMINANTLY LIGHT BROWN, RARELY MEDIUM GRAY; DOMINANTLY APPEARS AS CLAY IN SAMPLES; RUNNY ,TO STIFF, MODERATE TO GOOD COHESION; STICKY; RARELY APPEARS AS POORLY INDURATED MUSHY IRREGULARLY SHAPED CUTTINGS; MATTE, EARTHY LUSTER WITH SCATTERED MICROSPARKLES; SMOOTH TO MODERATELY GRITTY TEXTURE; NON TO LOCALLY MODERATELY CALCAREOUS; SCATTERED TO COMMON CARBONACEOUS SPECKS AND STREAKS; STRUCTURELESS. 3720 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR TO TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK; CLASTS RANGE FROM VERY FINE TO COARSE, DOMFINE TO MEDIUM RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 70% QUARTZ, 20% VOLCANIC/METAMORPHIC LITHICS, 10% CHERT; RARE MUSCOVITE, GRAINS ARE LOOSE IN SAMPLE; NO EVID OFMATRIX; ESTIMATED FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY. 18 3775 COAL=BROWNISH BLACK TO BLACK; HARD; SPLINTERY, PLATY, ROUGH SURFACE TEXTURE;INTERBEDDED WITH SM AMOUNT CARBONACEOUS SHALE. 3820 SAND=LIGHT GRAY TO MEDIUM LIGHT GRAY; FINE TO MEDIUM GRAINED, DOMINANTLY UPPER FINE GRAINED; SUB ANGULAR TO SUB ROUNDED, DOMINANTLY SUB ROUNDED; WELL SORTED, COMPOSED OF 80% QUARTZ, 10% CHERT, 10% VOLCANIC/METAMORPHIC LITHICS; STRONG ACID REACTION, BUT NO VISIBLE CEMENT; TRACE GREENSTONE; SAMPLE IS 100% DISAGGREGRATED GRAINS; INFER GOOD POROSITY AND FAIR PERMEABILITY. 3875 SAND=LIGHT TO M LIGHT GRAY; FINE TO MEDIUM GRAINED, DOMINANTLY UPPER FINE GRAINED; SUB ANGULAR TO SUB ROUNDED, WITH TRACE ANGULAR; MODERATELY WELL SORTED; COMPOSED OF 80% QUARTZ, 10-15% IGNEOUS/METAMORPHIC/VOLCANIC LITHICS, 5-10% CHERT; VERY WEAK ACID REACTION; INFER GOOD POROSITY, FAIR PERMEABILITY. 3915 COAL = BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; CRUMBLY TO BRITTLE; MATTE TO SLIGHTLY SHINY LUSTER; COMMON VERY SMALL SPLINTERY CUTTINGS, COMMON TABULAR AND BLOCKY CUTTINGS; LOCALLY ARGILLACEOUS; GRADES IN PART TO POORLY INDURATED CARBONACEOUS SHALE; RARE GAS BUBBLES ON FRACTURE SURFACES. 3960 SAND = LIGHT GRAY OVERALL WITH COMMON CLEAR TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK GRAINS; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY FINE RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 70% QUARTZ 20% VOLCANIC/METAMORPHIC LITHICS, 10% CHERT; TRACE MUSCOVITE; UNCONSOLIDATED IN SAMPLE; NO ACID REACTION; PROBABLY FAIR TO GOOD POROSITY AND PERMEABILITY 4015 SAND = LIGHT GRAY OVERALL WITH COMMON CLEAR TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK GRAINS; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY FINE RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 60% QUARTZ, 30% VOLCANIC/METAMORPHIC LITHICS, 10% CHERT; TRACE MUSCOVITE; LOOSE IN SAMPLE; SLIGHTLY ACID REACTION; PROBABLY FAIR TO GOOD POROSITY AND PERMEABILITY. 4070 SAND = LIGHT GRAY OVERALL WITH COMMON CLEAR TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK GRAINS; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY FINE RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 70% QUARTZ, 20% VOLCANIC/METAMORPHIC LITHICS, 10% CHERT; TRACE MUSCOVITE; UNCONSOLIDATED IN SAMPLE; NO ACID REACTION; PROBABLY FAIR TO GOOD POROSITY AND PERMEABILITY. 4125 SAND = LIGHT GRAY OVERALL WITH COMMON CLEAR TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK GRAINS; CLASTS RANGE FROM VERY FINE TOMEDIUM, DOMINANTLY FINE RANGE; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED, MODERATELY SORTED; COMPOSED OF 60% QUARTZ, 30% VOLCANIC/METAMORPHIC LITHICS, 10% CHERT; TRACE MUSCOVITE; UNCONSOLIDATED IN SAMPLE; NO ACID REACTION; PROBABLY FAIR TO GOOD POROSITY AND PERMEABILITY. 4180 SAND = CLEAR, TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, BLACK, LIGHT TO MEDIUM GREENISH GRAY; CLASTS RANGE FROM VERY FINE TO MEDIUM UPPER, DOMINANTLY FINE TO MEDIUM LOWER; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR; MODERATELY SORTED; COMPOSED OF 70% QUARTZ, 20% METAMORPHIC/VOLCANICLITHICS, 10% CHERT; DISSAGREGATED IN THE SAMPLES; NO EVIDENCE OF MATRIX; NO ACID REACTION; ESTIMATED GOOD POROSITY AND PERMEABILITY. 4230 COAL = BLACK TO DUSKY BROWN; FIRM; DOMINANTLY BRITTLE, RARELY CRUMLBLY; SMALL SPLINTERY CUTTINGS WITH SHARP EDGES; MATTE TO SLIGHTLY SHINY LUSTER; SLIGHTLY ROUGH SURFACE TEXTURE; RARE GAS BUBBLES ON FRACTURE SURFACES; RARE CLAYSTONE LAMINATIONS;OCCASIONALLY VERY ARGILLACEOUS, GRADING IN PART TO CARBONACEOUS SHALE. 4275 TUFFACEOUS CLAYSTONE = VERY LIGHT GRAYISH BROWN; VERY SOFT TO RARELY SLIGHTLY FIRM; DOMINANTLY APPEARS AS RUNNY TO STIFF CLAY WITH COMMON AMORPHOUS LUMPS; RARELY AS POORLY INDURATED MUSHY IRREGULAR CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON TO OCCASIONALLY SLIGHTLY CALCAREOUS; COMMON CARBONACEOUS SPECKS AND STREAKS; RARE SILTY ZONES; COMMON ASHY APPEARANCE. 4325 CARBONACEOUS SHALE/COAL = BROWNISH BLACK TO DUSKY BROWN; FIRM OCCASIONALLY HARD; DULL EARTHY LUSTER; STRIATED OCCASIONALLY MATTE TEXTURE; SUB PLATY OCCASIONALLY SUB CONCHOIDAL FRACTURE; COMPOSED OF PREDOMINANTLY VERY CARBONACEOUS SHALE GRADING TO SUB LIGNITE; OCCASIONALLY SCATTERED LAMINAE OF CLAY AND OTHER DETRITAL MATERIAL. 20 4365 SAND = VERY LIGHT GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM VERY FINE UPPER AND INCREASING TO FINE LOWER WITH DEPTH TO MEDIUM LOWER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO MODERATELY SILICEOUS OCCASIONALLY SLIGHTLY CALCAREOUS AND DECREASING WITH DEPTH; SANDS BECOMING CLEAN AND UNCONSOLIDATED BY 4440; DOMINANTLY GRAIN SUPPORTED WITH MINOR SECONDARY MATRIX SUPPORTED AT 4360; COMPOSED OF 30-50% QUARTZ, 60-40% CHERT, 10% METAMORPHIC, FELDSPAR, JASPER, TUFF AND VARIOUS LITHIC FRAGMENTS;MASSIVE SANDS WITH MINOR SANDSTONES AND COARSE GRAIN PEBBLES; THIN LAMINATIONS OF SILT AND CLAY; POOR GRADING TO GOOD POROSITY AND PERMEABILITY. 4450 CARBONACEOUS SHALE, CLAY AND COAL = BROWNISH BLACK MOTTLED BROWN; FIRM; DULL EARTHY LUSTER; STRIATED/WOODY TO MATTE TEXTURE; SUB PLATY TO DRUSY/CRUSTY FRACTURE; COMPOSED OF PREDOMINANTLY VERY CARBONACEOUS CLAY (BROWN) TO VERY CARBONACEOUS SHALE GRADING TO SUB-LIGNITE COAL; VISIBLE BLEEDING CUTS IN FRAGMENTS MINOR LAMINAE OF VERY LIGHT GRAY CLAY AND SILT; TRACE RARE ORANGE AMBER INTERBEDDED. 4500 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM FINE LOWER TO MEDIUM LOWER; SUB ROUNDED-SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; DOMINANTLY GRAIN SUPPORTED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR, TUFF AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY. 4560 CARBONACEOUS SHALE = BLACK TO DUSKY BROWN; FIRM; CRUMBLY TO BRITTLE; SMALL PLATY AND TABULAR CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TEXTURE; NON CALCAREOUS; POOR TO FAIR FISSILITY; THINLY INTERBEDDED TUFFACEOUS CLAYSTONE AND COAL. 4620 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM FINE LOWER TO MEDIUM LOWER; SUB ROUNDED-SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; DOMINANTLY GRAIN SUPPORTED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR, TUFF AND VARIOUS LITHIC FRAGMENTS; GOOD POROSITY AND PERMEABILITY. 4670 TUFFACEOUS CLAYSTONE = VERY LIGHT GRAYISH BROWN; VERY SOFT TO RARELY SLIGHTLY FIRM; DOMINANTLY APPEARS AS RUNNY TO STIFF CLAY WITH COMMON AMORPHOUS LUMPS; RARELY AS POORLY INDURATED MUSHY IRREGULAR CUTTINGS. 4700 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR TRANSLUCENT WHITE, LIGHT GRAY; CLASTS RANGE FROM VERY FINE UPPER TO MEDIUM UPPER, DOMINANTLY FINE RANGE; ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 60% QUARTZ, 20%METAMORPHICNOLCANIC LITHICS, 20% CHERT; TRACE MUSCOVITE; UNCONSOLIDATED IN SAMPLES; NO EVIDENCE OF MATRIX; RARE GRAINS WITH CALCITE CEMENT ON SURFACES; ESTIMATED FAIR VISIBLE POROSITY AND PERMEABILITY. 4755 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR, MILKY WHITE, LIGHT GRAY; CLASTS RANGE FROM VERY FINE UPPER TO MEDIUM UPPER, DOMINANTLY FINE RANGE; ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 60% QUARTZ, 20%METAMORPHIC/VOLCANIC LITHICS, 20% CHERT; TRACE MUSCOVITE; GRAINS APPEAR LOOSE IN SAMPLES; NO EVIDENCE OF MATRIX; RARE GRAINS WITH CALCITE CEMENT ON SURFACES; ESTIMATED FAIR VISIBLE POROSITY AND PERMEABILITY. 4810 COAL = BLACK TO DUSKY BROWN; FIRM; DOMINANTLY BRITTLE, RARELY CRUMLBLY; SMALL SPLINTERY CUTTINGS WITH SHARP EDGES; MATTE TO SLIGHTLY SHINY LUSTER; SLIGHTLY ROUGH SURFACE TEXTURE; RARE GAS BUBBLES ON FRACTURE SURFACES; RARE CLAYSTONE LAMINATIONS;OCCASIONALLY VERY ARGILLACEOUS, GRADING IN PART TO CARBONACEOUS SHALE. 4855 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUB ROUNDED-SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; NO VISIBLE MATRIX MATERIAL; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 20% QUARTZ, 70% CHERT, 10% METAMORPHIC, TUFF AND VARIOUS LITHIC FRAGMENTS; GOOD ESTIMATED POROSITY AND PERMEABILITY. 4905 COAL/CARBONACEOUS SHALE = BLACK TO GRAYISH BLACK OCCASIONALLY VERY DARK BROWN; FIRM; EARTHY OCCASIONALLY RESINOUS LUSTER; MATTE TEXTURE; PATCHY TO IRREGULAR FRACTURE; COMPOSED OF PREDOMINANTLY SUB LIGNITE TO LIGNITE. 4935 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; NON TO VERY SLIGHTLY VISIBLE CLAY MATRIX MATERIAL; DOMINANTLY GRAIN SUPPORT; COMPOSED OF 20% QUARTZ, 70% CHERT, 10% METAMORPHIC, TUFF, AND VARIOUS LITHIC FRAGMENTS; GOOD ESTIMATED POROSITY AND PERMEABILITY. 22 4990 COAL/CARBONACEOUS SHALE = BLACK TO VERY DARK BROWN AND VARIOUS HUES; FIRM; EARTHY LUSTER; MATTE TO STRIATED/WOODY TEXTURE; SUB PLATY TO PATCHY FRACTURE; COMPOSED OF PREDOMINANTLY SUB LIGNITE; VISIBLE BLEEDING GAS FROM COAL CUTTINGS. 5025 TUFFACEOUS CLAYSTONE = GRAYISH ORANGE TO DARK YELLOWISH ORANGE AND VARIOUS HUES OF BOTH; VERY SOFT; CLUMPY TO CLUSTERED; CLOTTED TO GELATINOUS; AMORPHOUS FRACTURE AND HABIT; MODERATE EARTHY LUSTER; WET ASHY TEXTURE; MASSIVE GRAD HYDROPHILIC CLAYS AND FINE GRAIN SAND STRINGERS GRADING TO PREDOMINANTLY SAND. 5070 SAND = VERY LIGHT GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TO FINE UPPER; SUB ROUNDED TO SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; MODERATE TO ABUNDANT CLAY PACKED MATRIX-- VERY HYDROPHILIC; GRAIN AND MATRIX SUPPORTED; COMPOSED OF PREDOMINANTLY QUARTZ AND CHERT WITH MINOR LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY. 5130 CARBONACEOUS SHALE I COAL = DUSKY BROWN TO MODERATELY BROWN, OCCASIONALLY MOTTLED BLACK; FIRM; DULL EARTHY LUSTER; MATTE TO STRIATED TEXTURE; PLANAR TO SUB PLANAR FRACTURE; COMPOSED OF PREDOMINANTLY VERY CARBONACEOUS SHALE GRADING TO SUB LIGNITE; VISIBLE BLEEDING GAS NOTED IN CUTTINGS; TRACE CLAY LAMINATIONS. 5170 TUFFACEOUS CLAYSTONE = LIGHT BROWN TO DARK YELLOWISH ORANGE AND VARIOUS HUES OF BOTH; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; GELATINOUS TO MUSHY; AMORPHOUS FRACTURE AND HABIT; MODERATE EARTHY LUSTER; COLLOIDAL TEXTURE; MASSIVE HOMOGENEOUS BEDDING OF UNIFORM SAND AND CLAY STRUCTURES. $215 SAND = LIGHT GRAY TO VERY LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TOMEDIUM LOWER OCCASIONALLY COARSE LOWER SCATTERED; SUB ROUNDED TO SUB ANGULAR; MODERATE SPHERICITY; MODERATE SORTING; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; MODERATE TO ABUNDANT CLAY PACKED MATRIX / HYDROPHILIC DOMINANTLY MATRIX SUPPORTED WITH SECONDARY GRAIN SUPPORTED; COMPOSED OF PREDOMINANTLY QUARTZ AND CHERT WITH MINOR METAMORPHIC; POOR ESTIMATED POROSITY AND PERMEABILITY. 5285 CARBONACEOUS SHALE I COAL = BROWNISH BLACK TO BLACK; FIRM; DULL EARTHY LUSTER; MATTE TEXTURE; SUB PLANAR TO PATCHY FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE AND LIGNITIC COAL. 5315 TUFFACEOUS CLAYSTONE = PALE YELLOWISH BROWN; VERY SOFT; LUMPY TO CLUMPY; CLOTTED TO GELATINOUS; AMORPHOUS FRACTURE AND 23 HABIT; MODERATE EARTHY LUSTER; COLLOIDAL TEXTURE; MASSIVE HOMOGENEOUS BEDS OF VERY HYDROPHILIC CLAY AND FINE TO MEDIUM GRAIN SANDS; VISIBLE PYROCLASTIC RELICT SHARDS IN CLAY MATRIX. 5360 TUFFACEOUS CLAYSTONE = PALE YELLOWISH BROWN; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED; CLOTTED TO GELATINOUS; AMORPHOUS FRACTURE AND HABIT; MODERATE EARTHY LUSTER; COLLOIDAL TEXTURE; MASSIVE HOMOGENEOUS BEDS OF VERY HYDROPHILIC CLAY; VISIBLE PYROCLASTIC RELICT SHARDS IN CLAY MATRIX. 5405 CARBONACEOUS SHALE I COAL = BROWNISH BLACK TO BLACK; FIRM; DULL EARTHY LUSTER; MATTE TEXTURE; SUB PLANAR TO PATCHY FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE AND LIGNITIC TO SUB BITUMINOUS COAL.. 5480 SAND = CLEAR, LIGHT GRAY TO GRAYISH BLACK; SIZE RANGES FROM UPPER VERY FINE TO UPPER FINE OCCASIONALLY CRUSHED UPPER MEDIUM TO LOWER COARSE FRAGMENTS; DOMINANTLY WELL SORTED; MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED TO OCCASIONALLY WELL ROUNDED; UNCONSOLIDATED SAND; OCCASIONALLY SCATTERED MICACEOUS FRAGMENTS; COMPOSED OF 20% QUARTZ AND 60-70% CHERT AND VARIOUS METAMORPHIC/IGNEOUS LITHIC. 5585 COAL = BLACK TO DUSKY DARK BROWN; GRADING TO SUB BITUMINOUS; OCCASIONALLY BROWNISH CARBONACEOUS LAMINATIONS; DULL RESINOUS LUSTER; IRREGULAR TO CONCHOIDAL FRACTURE; FIRM; BRITTLE; NON TO SLIGHTLY FISSILE; PLANAR TO SUB PLANAR STRUCTURE; VISIBLE GAS BLEEDING ON SURFACES. 5620 SAND = LIGHT GRAY TO CLEAR TO MILKY WHITE, OCCASIONALLY DARK GRAY; VERY FINEN TO FINE TO OCCASIONALLY LOWER MEDIUM; POOR TO MODERATE SORTING; ANGULAR TO SUB ROUNDED; MOSTLY UNCONSOLIDATED WITH NO MATRIX; SLIGHTLY INCREASING CLAYEY MATRIX WITH FINER SAND GRAINS EMBEDDED INTO CLAY LUMPS; COMPOSED DOMINANTLY OF 50-60% QUARTZ, 30-40% CHERT AND REST VARIOUS METAMORPHIC AND VOLCANIC LITHIC; SLIGHTLY LOCALLY CALCAREOUS. 5675 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; VERY SOFT TO SOFT; APPEARS AS CLAY EXPANSIVE WHEN HYDRATED; SLIGHTLY TO MODERATELY CALCAREOUS; SILTY IN PART; COMMON SCATTERED CARBONACEOUS SPECKS; SCATTERED FINE TO LOWER MEDIUM SAND GRAINS EMBEDDED IN SLIGHTLY FIRM CLAYEY LUMPS; DULL EARTHY LUSTER. 5750 SAND = (5750-5760) LIGHT GRAY TO MEDIUM LIGHT GRAY; CLAST SIZE RANGES FROM FINE LOWER TO MEDIUM LOWER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; CHIPPED TO PITTED 24 TEXTURE; NON TO WEAK SILICEOUS CEMENT; NO VISIBLE MATRIX MATERIAL; APPEARS ARENACEOUS IN PART; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHICS, TUFF AND VARIOUS LITHIC FRAGMENTS; DOES NOT APPEAR TIGHT; FAIR ESTIMATED POROSITY AND PERMEABILITY. 5790 CARBONACEOUS SHALE / COAL = BLACKISH GRAY TO BROWNISH BLACK; FIRM; DULL EARTHY LUSTER; STRIATED/WOODY TO MATTE TEXTURE; PLANAR TO SPLINTERY FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE AND SUB-LIGNITIC COAL. 5825 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER; SUB ROUNDEDTO SUB ANGULAR; MODERATE SPHERICITY; MODERATELY SORTED; CHIPPED TO PITTED TEXTURE; NON TO WEAK SILICEOUS CEMENT; SLIGHT TO MODERATELY HYDROPHILIC CLAY MATRIX; PREDOMINANTLY GRAIN SUPPORTED WITH SECONDARY MATRIX SUPPORT; COMPOSED OF 30% QUARTZ, 60% CHERT, 10% METAMORPHIC, TUFF AND VARIOUS LITHIC FRAGMENTS; FAIR TO POOR ESTIMATED POROSITY AND PERMEABILITY. 5885 TUFFACEOUS CLAYSTONE = MODERATE YELLOW-BROWN; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; AMORPHOUS FRACTURE; AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; COLLOIDAL TEXTURE; VERY HYDROPHILIC; INTERBEDDED WITH FINE TO MEDIUM GRAIN SANDS; TRACE TUFFACEOUS SILT AND CONGLOMERATE; ALMOST STRUCTURELESS. 5930 COAL = BLACK, DUSKY BROWN; GRADES TO SUB BITUMINOUS; IRREGULAR PIECES OF SUB ROUNDED SHAPE; SLIGHTLY FISSILE; DULL RESINOUS LUSTER; IRREGULAR TO CONCHOIDAL FRACTURES; BRITTLE; FIRM; RARE TO OCCASIONALLY WOODY CARBONACEOUS LAMINATIONS; SCATTERED CARBONACEOUS SPECKS. 5970 SAND = CLEAR, LIGHT GRAY, LIGHT GREEN TO EMERALD GREEN, OCCASIONALLY MILKY WHITE AND DARK GRAY TO BLAKISH GRAY AND OLIVE GRAY; SIZE RANGES FROM UPPER VERY FINE TO MEDIUM; DOMINANTLY LOWER MEDIUM AND UPPER FINE IN SIZE; MODERATELY TO WELL SORTED; ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; APPEARS TO BE COMPOSED OF 50- 60% CHERT, 30-40% QUARTZ AND REST VARIOUS METAMORPHICNOLCANIC DARKER-COLORED LITHICS; GOOD POROSITY AND PERMEABILITY; PREDOMINANTLY GRAIN SUPPORT, ALSO PARTIAL TUFFACEOUS CLAY MATRIX SUPPORT; TRACE GREENSTONE AND MUSCOVITE MICA. " 6050 COAL = DUSKY BROWN TO BLACK; FIRM TO MODERATELY HARD; CRUNCHY; BRITTLE; SMALL PLATY TO SUB BLOCKY CUTTINGS; DULL RESINOUS LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; OCCASIONALLY THIN 25 LAMINATIONS OF TUFFACEOUS CLAYSTONE; RARE PINPOINT GAS BUBBLES ON FRACTURE SURFACE. 6120 SAND = CLEAR, LIGHT GRAY, LIGHT TO DARK GREEN; BLACKISH GRAY; FIRM TO HARD; NON-FRIABLE; FINE TO LOWER MEDIUM OCCASIONALLY UPPER COARSE CHERT NODULES; MODERATELY TO WELL SORTED; MODERATE SPHERICITY; BOTH MATRIX AND CLAY MATRIX SUPPORT. 6155 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE UPPER OCCASIONALLY COARSE LOWER IN PARTS; SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; PI'r'TED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; NON TO SLIGHT CLAY PACKED MATRIX VERY HYDROPHILIC; DOMINANTLY GRAIN SUPPORTED WITH SECONDARY MATRIX SUPPORT; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; FAIR POROSITY AND PERMEABILITY. 6215 TUFFACEOUS CLAYSTONE = YELLOWISH BROWN; VERY SOFT; LUMPY TO CLUMPY; CLOTTED TO CLUSTERED; AMORPHOUS FRACTURE; AMORPHOUS HABIT; COLLOIDAL TEXTURE; COMPOSED OF 90% HYDROPHILIC CLAY AND 10% FRIABLE SILT AND VOLCANIC PYROCLASTIC MATERIAL. 6250 SAND = LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE UPPER; SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; PITTED TO CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; MODERATE AMOUNT OF TUFFACEOUS CLAY PACKED MATRIX; PREDOMINANTLY MATRIX SUPPORTED WITH MINOR GRAIN SUPPORTED; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC, FELDSPAR, GREENSTONE AND VARIOUS LITHIC FRAGMENTS; POOR POROSITY AND PERMEABILITY. 6310 CARBONACEOUS SHALE I COAL = BLACK OCCASIONALLY BROWNISH BLACK; FIRM; OVERALL DULL EARTHY LUSTER OCCASIONALLY RESINOUS IN PARTS; MATTE TO STRIATED/WOODY TEXTURE; PLANAR FRACTURE IN CARBONACEOUS SHALE; HACKLY FRACTURE IN COALS; COMPOSED OF PREDOMINANTLY VERY CARBONACEOUS SHALE OCCASIONALLY GRADING TO LIGNITIC COAL. ( 6350 TUFFACEOUS CLAYSTONE = YELLOWISH BROWN TO PALE ORANGE BROWN; VERY SOFT; CLOTTED TO CLUSTERED; LUMPY TO CLUMPY; OCCASIONALLY BECOMING GELATINOUS IN PARTS; AMORPHOUS FRACTURE; AMORPHOUS HABIT; MODERATE EARTHY LUSTER; COLLOIDAL TEXTURE; MASSIVE HYDROPHILIC CLAYS BEDS COMPOSED OF 90% CLAY, 10% SILT. 6395 SAND = CLEAR, LIGHT GRAY, OCCASIONALLY MILKY WHITE; RARE LIGHT TO DARK GREEN; OCCASIONALLY DARK GRAY AND OLIVE GRAY; FINE TO LOWER MEDIUM; MODERATELY SORTED; LOW TO DOMINANTLY MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; BOTH GRAIN AND SECONDARY TUFFACEOUS CLAY MATRIX SUPPORT; NON TO LOCALLY SLIGHTLY CALCAREOUS; SOME SAND GRAINS ARE EMBEDDED INTO CLAY LUMPS; COMPOSED OF 70-80% QUARTZ, 10- 20 % CHERT AND REST IS VARIOUS USUALLY DARKER-COLORED METAMORPHIC AND VOLCANIC LITHICS; OCCASIONALLY SCATTERED PIECES OF CARBONACEOUS SHALE AND LOW-GRADE LIGNITE IN SAMPLE; MODERATE POROSITY AND PERMEABILITY. 6500 CARBONACEOUS SHALE/COAL = MODERATE BROWN TO GRAYISH BROWN TO OCCASIONALLY DUSKY BROWN AND BLACK; FIRM TO OCCASIONALLY MODERATELY HARD; SLIGHTLY BRITTLE TO BRITTLE; MODERATELY FISSILE TO FISSILE; APPEARS AS PLATY TO SUB PLATY, SCALY SMALL PIECES; FREQUENT WOODY CARBONACEOUS LAMINATIONS IN SHALE; OCCASIONALLY PIECES OF LOW-GRADE LIGNITE IN SAMPLE; RARE PIECES OF SUB BITUMINOUS COAL; DULL EARTHY TO SLIGHTLY RESINOUS LUSTER; MICROSCOPIC SILTSTONE AND CLAYSTONE INTRUSIONS AND INTERBEDS. 6575 SAND = CLEAR, LIGHT GRAY, OCCASIONALLY MILKY WHITE; RARE LIGHT TO DARK GREEN; OCCASIONALLY DARK GRAY AND OLIVE GRAY; FINE TO LOWER MEDIUM; MODERATELY SORTED; LOW TO DOMINANTLY MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; BOTH GRAIN AND SECONDARY TUFFACEOUS CLAY MATRIX SUPPORT; NON TO LOCALLY SLIGHTLY CALCAREOUS; SOME SAND GRAINS ARE EMBEDDED INTO CLAY LUMPS; COMPOSEDOF 70-80% QUARTZ, 10- 20 % CHERT AND REST IS VARIOUS USUALLY DARKER-COLORED METAMORPHIC AND VOLCANIC LITHICS; OCCASIONALLY SCATTERED PIECES OF CARBONACEOUS SHALE AND LOW-GRADE LIGNITE IN SAMPLE; MODERATE POROSITY AND PERMEABILITY. 6655 CARBONACEOUS SHALE/COAL = MODERATE BROWN TO GRAYISH BROWN TO OCCASIONALLY DUSKY BROWN AND BLACK; FIRM TO OCCASIONALLY MODERATELY HARD; SLIGHTLY BRITTLE TO BRITTLE; MODERATELY FISSILE TO FISSILE; APPEARS AS PLATY TO SUB PLATY SCALY SMALL PIECES; FREQUENT WOODY CARBONACEOUS LAMINATIONS IN SHALE; OCCASIONALLY PIECES OF LOW-GRADE LIGNITE IN SAMPLE; RARE PIECES OF SUB BITUMINOUS COAL; DULL EARTHY TO SLIGHTLY RESINOUS LUSTER; VERY THINLY INTERBEDDED WITH SILTSTONE AND CLAYSTONE. 27 6730 SAND = CLEAR, LIGHT GRAY, OCCASIONALLY MILKY WHITE; RARE LIGHT TO EMERALD GREEN; OCCASIONALLY DARK GRAY AND OLIVE GRAY; FINE TO LOWER MEDIUM; MODERATELY SORTED; LOW TO DOMINANTLY MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; BOTH GRAIN AND SECONDARY TUFFACEOUS CLAY MATRIX SUPPORT; NON TO LOCALLY SLIGHTLY CALCAREOUS; SOME SAND GRAINS ARE EMBEDDED INTO CLAY LUMPS; COMPOSED OF 70-80% QUARTZ, 10-20 % CHERT AND REST IS VARIOUS USUALLY DARKER-COLORED METAMORPHIC AND VOLCANIC LITHICS; OCCASIONALLY SCATTERED PIECES OF CARBONACEOUS SHALE AND LOW-GRADE LIGNITE IN SAMPLE; MODERATE VISUAL ESTIMATED POROSITY AND PERMEABILITY. 6820 TUFFACEOUS CLAYSTONE = LIGHT BROWN TO DARK YELLOWISH ORANGE AND VARIOUS HUES OF BOTH; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; GELATINOUS TO MUSHY IN PARTS; AMORPHOUS FRACTURE; AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; MASSIVE HOMOGENEOUS BEDS OF FINE GRAIN SAND AND VERY HYDROPHILIC CLAY. 6865 CARBONACEOUS SHALE I COAL = BROWNISH BLACK TO DUSKY YELLOWISH BROWN; FIRM; DULL EARTHY LUSTER; STRIATED/WOODY TEXTURE; PLANAR FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE OCCASIONALLY GRADING TO SUB LIGNITE COAL. 6895 SAND = VERY LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM FINE GRAIN TO VERY FINE LOWER; OCCASIONALLY GRADING TO HYDROPHILIC SILT; SUB ROUNDED OCCASIONALLY SUB ANGULAR; MODERATE SPHERICITY; POORLY SORTED; DOMINANTLY CLAY/SILT MATRIX SUPPORTED; CHIPPED TO PITTED TEXTURE; NON TO VERY SILICEOUS CEMENT; COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY.. 6950 TUFFACEOUS CLAY/SILT = LIGHT BROWN TO YELLOWISH ORANGE; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; GELATINOUS TO MUSHY; AMORPHOUS FRACTURE; AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; MASSIVE HOMOGENEOUS BEDS OF UNIFORM CLAY AND FINE TO VERY FINE GRAIN SAND; COMPOSED OF 70% CLAY, 30% SILT. 6995 SAND = VERY LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM VERY FINE LOWER (SOME SILT SIZED) TO FINE LOWER; SUB ROUNDED OCCASIONALLY SUB ANGULAR; MODERATE SPHERICITY; POORLY SORTED; DOMINANTLY CLAY/SILT MATRIX SUPPORT; VERY HYDROPHILIC; CHIPPED TO PITTED TEXTURE COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY. 28 7045 CARBONACEOUS SHALE I COAL = BLACK TO DUSKY BROWN; FIRM; STIFF; PLANAR TO SUB PLANAR FRACTURE; PLATY TO SUB PLATY HABIT DULL EARTHY LUSTER; MATTE TO STRIATED/WOODY TEXTURE; BECOMING INTERBEDDED WITH VERY CARBONACEOUS CLAY (BROWN); MASSIVE BEDS OF HOMOGENEOUS SILTY CLAYS AND VERY FINE GRAIN SANDS. 7090 SAND = VERY LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM VERY FINE LOWER (SOME SILT SIZED) TO FINE LOWER; SUB ROUNDED OCCASIONALLY SUB ANGULAR; MODERATE SPHERICITY; POORLY SORTED; DOMINANTLY CLAY/SILT MATRIX SUPPORT; VERY HYDROPHILIC; CHIPPED TO PITTED TEXTURE COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY. 7140 SAND = LIGHT GRAY, OCCASIONALLY CLEAR, OLIVE GRAY TO DARK GRAY, RARE LIGHT AND EMERALD GREEN AND BROWNISH RED; CLASTS RANGE FROM UPPER VERY FINE TO MEDIUM; MODERATELY SORTED; MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; ALMOST 100% GRAIN SUPPORT; COMPOSED OF 50% QUARTZ, 40% CHERT AND 10% VARIOUS METAMORPHICNOLCANIC LITHIC SEDIMENTS; MODERATE TO GOOD ESTIMATED VISUAL POROSITY AND PERMEABIITY; LOCALLY CALCAREOUS. 7220 CARBONACEOUS SHALE I COAL = BROWNISH BLACKTO DUSKY YELLOWISH BROWN; FIRM; DULL EARTHY LUSTER; STRIATED/WOODY TEXTURE; PLANAR FRACTURE; COMPOSED OF VERY CARBONACEOUS SHALE OCCASIONALLY GRADING TO SUB LIGNITE COAL. 7250 SAND = LIGHT GRAY, OCCASIONALLY CLEAR, OLIVE GRAY TO DARK GRAY, RARE LIGHT AND EMERALD GREEN AND BROWNISH RED; CLASTS RANGE FROM UPPER VERY FINE TO MEDIUM; MODERATELY SORTED; MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED 70% GRAIN SUPPORTED AND 30%CLAY MATRIX SUPPORT; GRAINS EMBEDDED IN AMORPHOUS CLAYEY LUMPS; COMPOSED OF50-60% OF QUARTZ, 30-40% OF CHERT, AND VARIOUS METAMORPHIC/VOLCANIC LITHICS;OCCASIONALLY SCATTERED MUSCOVITE MICA; SCALY FRAGMENTS; SILTY PARTICLES. 7335 SAND = VERY LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM VERY FINE LOWER (SOME SILT SIZED) TO FINE LOWER; SUB ROUNDED OCCASIONALLY SUB ANGULAR; MODERATE SPHERICITY; POORLY SORTED; DOMINANTLY CLAY/SILT MATRIX SUPPORT; VERY HYDROPHILIC; CHIPPED TO PITTED TEXTURE COMPOSED OF 40% QUARTZ, 50% CHERT, 10% METAMORPHIC AND VARIOUS LITHIC FRAGMENTS; POOR ESTIMATED POROSITY AND PERMEABILITY. NOTE SMALL LOOSE NODULES OF PYRITE SCATTERED THRU THE SAND FROM 7290 TO 7350. 7385 TUFFACEOUS CLAY/SILT = LIGHT BROWN TO YELLOWISH ORANGE; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; GELATINOUS TO MUSHY; AMORPHOUS FRACTURE; AMORPHOUS HABIT; DULL TO MODERATE EARTHY LUSTER; MASSIVE HOMOGENEOUS BEDS OF UNIFORM CLAY AND FINE TO VERY FINE GRAIN SAND; COMPOSED OF 70% CLAY, 30% SILT. 7445 COAL/CARBONACEOUS SHALE = BLACK TO BROWNISH BLACK; COMMON DUSKY BLACK TO DUSKY REDDISH BROWN WHEN GRADING TO CARBONACEOUS SHALE; LOW GRADE LIGNITE TO SUB-BITUMINOUS; ABUNDANT GRADING TO CARBONACEOUS SHALE; FIRM; BRITTLE; SMOOTH TO MATTE TEXTURE; DULL EARTHY SUB RESINOUS SOOTY LUSTER; CONCHOIDAL TO PLANAR FRACTURES; OCCASIONALLY CLAST WITH THIN SAND/SILT INTERBEDS. NOTE: FROM 7504' TO TD THE WELL WAS DRILLED WITH OIL BASE MUD. CUTTINGS WERE SA TURA TED AND STAINED WITH HEAVY OIL. THE SAND GRAINS, DESPITE BEING WASHED, ALWAYS HAD AT LEAST A FAINT GREASY FILM OF OIL, AND MADE IT EXTREMELY DIFFICULT, IF NOT ENTIRELY IMPRACTICAL, TO PROPERLY ESTIMATE OIL SHOWS. 7520 TUFFACEOUS CLAYSTONE = MODERATE BROWN; VERY SOFT; CLOTTED TO CLUSTERED; BECOMING GELATINOUS; AMORPHOUS FRACTURE; AMORPHOUS HABIT; MODERATE EARTHY LUSTER; COLLOIDAL TO ASHY TEXTURE; VERY HYDROPHILIC; OCCASIONALLY MEDIUM GRAIN SAND STRINGERS. 7555 TUFFACEOUS CLAYSTONE = PINKISH GRAY; FIRM; SECTILE; STIFF; EARTHY FRACTURE; MASSIVE NODULAR TO SUB NODULAR HABIT; WELL BORE POLISHED CUTTINGS; MODERATE EARTHY LUSTER; ASHY TO GRITTY TEXTURE; VISIBLE RELICT SHARDS IN CLAY MATRIX; COMPOSED OF 75% CLAY, 25% SILT AND DETRITAL MATERIAL. 7595 COAL = BLACK; FIRM; EARTHY OCCASIONALLY RESINOUS LUSTER; MATTE TEXTURE; HACKLY FRACTURE; COMPOSED OF LIGNITE TO SUB BITUMINOUS; APPEARS AS THIN STRINGERS. 7640 TUFFACEOUS CLAYSTONE = PINKISH GRAY; FIRM; SECTILE; STIFF; EARTHY FRACTURE; MASSIVE NODULAR TO SUB NODULAR HABIT; WELL BORE POLISHED CUTTINGS; MODERATE EARTHY LUSTER; ASHY TO GRITTY TEXTURE; VISIBLE RELICT SHARDS IN CLAY MATRIX; COMPOSED OF 75% CLAY, 25% SILT AND DETRITAL MATERIAL. 7680 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO GRAYISH BROWN TO OCCASIONALLY PINKISH BROWN; MODERATELY SOFT TO FIRM; DULL EARTHY TO SLIGHTLY GREASY LUSTER; ASHY TO MODERATELY SMOOTH TO SLIGHTLY GRITTY TEXTURE; LOW TO MODERATE INDURATION; 70-75% CLAY AND 20-25% OF SILT AND VARIOUS DETRITAL MATERIALS; MASSIVE SUB NODULAR TO NODULAR HABIT. 30 7725 COAL = BLACK TO DUSKY BROWN; FIRM TO MODERATELY FIRM; LOW GRADE OF LIGNITE; SUB RESINOUS TO RESINOUS LUSTER; IRREGULAR TO CONCHOIDAL FRACTURES; IRREGULAR SUB PLATY CUTTINGS; VERY SLIGHTLY FISSILE; SILT AND FINE SAND ON COAL SURFACES. 7760 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO GRAYISH BROWN OCCASIONALLY PINKISH BROWN; MODERATELY SOFT TO FIRM; DULL EARTHY TO SLIGHTLY GREASY LUSTER; ASHY TO MODERATELY SMOOTH TO SLIGHTLY GRITTY TEXTURE; LOW TO MODERATE INDURATION; 70-75% CLAY AND 20-25% OFSILT AND VARIOUS DETRITAL MATERIAL; MASSIVE SUB NODULAR TO NODULAR HABIT; NON-CALCAREOUS. 7835 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO GRAYISH BROWN OCCASIONALLY PINKISH BROWN; MODERATELY SOFT TO FIRM; DULL EARTHY TO SLIGHTLY GREASY LUSTER; ASHY TO MODERATELY SMOOTH TO SLIGHTLY GRITTY TEXTURE; LOW TO MODERATE INDURATION; 70-75% CLAY AND 20-25% OF SILT AND VARIOUS DETRITAL MATERIAL; MASSIVE SUB NODULAR TO NODULAR HABIT; NON-CALCAREOUS. 7880 SAND = LIGHT GRAY TO OLIVE GRAY, COMMONLY TRANSLUCENT; CLASTS RANGE FROM FINE TO UPPER MEDIUM OCCASIONALLY COARSE GRAINS; OCCASIONALLY EMBEDDED IN CLAY MATRIX; DOMINANTLY UNCONSOLIDATED SAND GRAINS; LOW TO MODERATE SPHERICITY; POOR TO MODERATE SORTING; ANGULAR TO SUB ROUNDED; COMMON PITTED AND CHIPPED GRAINS; ESTIMATED POOR TO MODERATE VISIBLE POROSITY AND PERMEABILITY (CLAY MATRIX); NON-CALCAREOUS. 7935 COAL = DUSKY BROWN TO DARK GRAY TO BLACK; GRADING FROM LIGNITE TO OCCASIONALLY SUB BITUMINOUS; CRUNCHY TO BRITTLE TENACITY; FIRM SMALL IRREGULAR TO SUB BLOCKY PIECES; DULL TO SUB RESINOUS LUSTER; PINPOINT GAS BUBBLES ON FRACTURES; CONCHOIDAL TO IRREGULAR FRACTURES; SLIGHTLY FISSILE. 7975 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO GRAYISH BROWN OCCASIONALLY PINKISH BROWN; MODERATELY SOFT TO FIRM; DULL EARTHY TO SLIGHTLY GREASY LUSTER; ASHY TO MODERATELY SMOOTH TO SLIGHTLY GRITTY TEXTURE; LOW TO MODERATE INDURATION; 70-75% CLAY AND 20-25% OF SILT AND VARIOUS DETRITAL MATERIALS; MASSIVE SUB NODULAR TO NODULAR HABIT; NON-CALCAREOUS. . 31 8020 COAL = DUSKY BROWN TO DARK GRAY TO BLACK; GRADING FROM LIGNITE TO OCCASIONALLY SUB BITUMINOUS; CRUNCHY TO BRITTLE TENACITY; FIRM SMALL IRREGULAR TO SUB BLOCKY PIECES; DULL TO SUB RESINOUS LUSTER; PINPOINT GAS BUBBLES ON FRACTURES; CONCHOIDAL TO IRREGULAR FRACTURES; SLIGHTLY FISSILE TO NON-FISSILE; FREQUENT SILTY LAMINATIONS ON COAL SURFACES. 8070 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO GRAYISH BROWN OCCASIONALLY PINKISH BROWN; MODERATELY SOFT TO FIRM; DULL EARTHY TO SLIGHTLY GREASY LUSTER; ASHY TO MODERATELY SMOOTH TO SLIGHTLY GRITTY TEXTURE; LOW TO MODERATE INDURATION; 70-75% CLAY AND 20-25% OF SILT AND VARIOUS DETRITAL MATERIAL; MASSIVE SUB NODULAR TO NODULAR HABIT; NON-CALCAREOUS. 8115 SAND = LIGHT GRAY TO OLIVE GRAY, COMMON TRANSLUCENT; CLASTS RANGE FROM FINE TO UPPER MEDIUM TO OCCASIONALLY COARSE GRAINS; OCCASIONALLY EMBEDDED IN CLAY MATRIX; DOMINANTLY UNCONSOLIDATED SAND GRAINS; LOW TO MODERATE SPHERICITY; POOR TO MODERATE SORTING; ANGULAR TO SUB ROUNDED; COMMON PITTED AND CHIPPED GRAINS; ESTIMATED POOR TO MODERATELY VISIBLE POROSITY AND PERMEABILITY (CLAY MATRIX); NON-CALCAREOUS, COMPOSED OF QUARTZ, FELDSPAR AND SOME CHERT AND MINOR VARIOUS METAMORPHIC AND VOLCANIC LITHICS; MODERATE ESTIMATED VISUAL POROSITY AND PERMEABILITY. 8190 COAL = DUSKY BROWN TO BLACK; FIRM; BRITTLE; IRREGULAR BLOCKY TO SUB NODULAR MASSIVE PIECES; IRREGULAR TO OCCASIONALLY CONCHOIDAL FRACTURE; DULL SUB RESINOUS LUSTER; SMOOTH TEXTURE; LOW GRADE LIGNITE TO SUB BITUMINOUS COAL. 8225 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; SOFT OCCASIONALLY FIRM BECOMING STIFF IN PARTS; EARTHY AMORPHOUS FRACTURE; SUB NODULAR WELL BORE POLISHED HABIT; DULL EARTHY LUSTER; SMOOTH TO ASHY/CLAYEY TEXTURE; OCCASIONALLY CARBONACEOUS SPECKS INTERBEDDED; VISIBLE RELICT SHARDS IN MATRIX. 8255+ TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY AND VARIOUS HUES; ABUNDANT OIL BASE MUD STAINING OF SAMPLES; SOFT OCCASIONALLY FIRM; OCCASIONALLY BECOMING SLIGHTLY CRUNCHY; SECTILE TO SLIGHTLY MALLEABLE; SLIGHTLY FLEXIBLE TO ELASTIC; MUSHY TO VERY COHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT WITH ABUNDANT WELL BORE POLISH; DULL EARTHY LUSTER; ASHY TO CLAY TEXTURE; MASSIVE HOMOGENEOUS BEDDING; COMPOSED OF 80% CLAY, 20% SILT; VISIBLE RELICT SHARDS IN CLAY MATRIX. 32 8325 TUFFACEOUS CLAYSTONE = MEDIUM DARK GRAY TO MEDIUM GRAY; FIRM; MALLEABLE TO SECTILE; STIFF; COHESIVE; EARTHY FRACTURE; MASSIVE SUB NODULAR HABIT; DULL EARTHY LUSTER; PDC BIT GROOVED HABIT; SMOOTH TEXTURE; MASSIVE BEDS OF TUFFACEOUS CLAY OCCASIONALLY BECOMING SILTY; VERY THIN LAMINATIONS OF TUFFACEOUS SHALE AND TUFFACEOUS SILT; SOME SOFT SEDIMENT BIT DEFORMATION. 8375 TUFFACEOUS CLAYSTONE = MEDIUM DARK GRAY TO MEDIUM GRAY AND VARIOUS HUES; ABUNDANT OIL BASE MUD STAINING; GENERALLY FIRM OCCASIONALLY SOFT MALLEABLE TO SECTILE; STIFF; BECOMING VERY COHESIVE WITH PDC BIT; MASSIVE SUB NODULAR HABIT DISPLAYING CLASSIC PDC NOTCHING; SMOOTH TEXTURE OCCASIONALLY POLISHED; MASSIVE BEDS OF TUFFACEOUS CLAY WITH THIN LAMINATIONS OF TUFFACEOUS SILT; SOME SOFT SEDIMENT DEFORMATION NOTED. 8430 COAL/CARBONACEOUS SHALE = BLACK TO GRAYISH BLACK OCCASIONALLY MOTTLED BROWNISH GRAY; SOFT TO FIRM; DULL EARTHY OCCASIONALLY RESINOUS LUSTER; MATTE TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; COMPOSED OF VARIOUS GRADES OF SUB LIGNITE TO VERY CARBON SHALE AND SOME CARBONACEOUS CLAYS AT CONTACTS, WHICH BECOME VERY MUSHY. 8475 TUFFACEOUS CLAYSTONE = BROWNISH GRAY AND VARIOUS HUES; HEAVY OIL BASE MUD STAINING; FIRM OCCASIONALLY TOUGH; SECTILE; STIFF; VERY COHESIVE; EARTHY TO GROOVED PDC FRACTURES; SUB NODULAR TO SUB HACKLY PDC HABIT; DULL EARTHY LUSTER; SMOOTH TO SLIGHTLY SILTY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF UNIFORM SLIGHTLY SILTY CLAY. 8525 TUFFACEOUS CLAYSTONE = BROWNISH GRAY; SOFT TO FIRM; SECTILE; MUSHY IN PARTS; SLIMY BECOMING STIFF; VARIOUS CONSISTENCY; HACKLY TO GROOVED PDC HABIT; ERTHY LUSTER; SMOOTH OCCASIONALLY SILTY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF CLAY AND MINOR SILT LAMINATIONS. 8565 COAL I CARBONACEOUS SHALE = BLACK OCCASIONALLY GRAYISH BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE OCCASIONALLY SMOOTH TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; COMPOSED OF BITUMINOUS TO LIGNITIC COAL WITH OCCASIONALLY VERY CARBONACEOUS SHALE AND CARBONACEOUS CLAY AT CONTACTS. 8605 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; VERY SOFT; LUMPY TO CLUMPY; CLOTTED TO GELATINOUS; MUSHY TO PASTY; TACKY TO SLIMY; ADHESIVE TO COHESIVE; VARIOUS CONSISTENCY WITH MUSHY/SOFT OVERTONES; AMORPHOUS FRACTURE AND HABIT; MODERATE EARTHY TO SATIN LUSTER; COLLOIDAL TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS SOFT SEDIMENT BEDDING; VISIBLE RELICT SHARDS IN MATRIX. 33 8660 TUFFACEOUS SILTSTONE = LIGHT BROWNISH GRAY TO PINKISH GRAY; POOR TO MODERATE INDURATION; SECTILE; MUSHY OCCASIONALLY PASTY; TACKY TO SLIMY; COHESIVE; EARTHY FRACTURE; DOMINANTLY PDC HACKLY TO PATCHY HABIT; EARTHY TO GREASY LUSTER; ASHY TO CLAYEY TEXTURE MASSIVE BEDDING OF GRAD SILTS; GENERALLY COMPOSED OF 70% CLAY, 30% SILT WITH CARBONACEOUS LAMINAE THROUGHOUT. 8710 COAL/CARBONACEOUS SHALE = BLACK OCCASIONALLY DARK GRAYISH BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE OCCASIONALLY SMOOTH TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; COMPOSED OF LIGNITE AND SUB BITUMINOUS COALS WITH OCCASIONALLY THIN LAMINATIONS OF CARBONACEOUS CLAY AND GRADING TO TUFFACEOUS CLAY. 8750 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY TO BROWNISH GRAY; SOFT TO FIRM; SECTILE; MUSHY TO TACKY; SLIMY TO STIFF; COHESIVE; EARTHY FRACTURE; SUB BLOCKY TO SUB NODULAR HABIT; MODERATE WELL BORE POLISH ON FRAGMENTS; DULL EARTHY TO STREAKY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONALLY LOOSE COARSE GRAIN SAND INTERBEDDED. 8795 TUFFACEOUS SILTSTONE = LIGHT BROWNISH GRAY TO PINKISH GRAY; POOR TO MODERATE INDURATION; SECTILE; MUSHY OCCASIONALLY PASTY; TACKY TO SLIMY; COHESIVE; EARTHY FRACTURE; DOMINANTLY PDC HACKLY TO PATCHY HABIT; EARTHY TO GREASY LUSTER; ASHY TO CLAYEY TEXTURE MASSIVE BEDDING OF GRAD SILTS-GENERALLY COMPOSED OF 70% CLAY, 30% SILT WITH CARBONACEOUS LAMINAE THROUGHOUT. 8845 COAL/CARBONACEOUS SHALE = BLACK OCCASIONALLY DARK GRAYISH BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE OCCASIONALLY SMOOTH TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; COMPOSED OF LIGNITE AND SUB BITUMINOUS COALS WITH OCCASIONALLY THIN LAMINATIONS OF CARBONACEOUS CLAY AND GRADING TO TUFFACEOUS CLAY, FREQUENT WOODY LAMINATIONS IN COAL. 8890 CONGLOMERATE/SAND -- LIGHT GRAY TO TRANSLUCENT WHITE, OCCASIONALLY OLIVE GRAY; CLASTS RANGE FROM UPPER FINE TO UPPER COARSE; MODERATELY TO WELL SORTED; ANGULAR TO SUB ROUNDED TO ROUNDED FOR FINER CLASTS; LOW TO MODERATE SPHERICITY IN SAMPLE; COMPOSED OF QUARTZ AND MINOR AMT OF CHERT. 8955 TUFFACEOUS SILTSTONE = LIGHT BROWNISH GRAY TO PINKISH GRAY; POOR TO MODERATE INDURATION; SECTILE; MUSHY OCCASIONALLY PASTY; TACKY TO SLIMY; COHESIVE; EARTHY FRACTURE; DOMINANTLY PDC HACKLY TO PATCHY HABIT; EARTHY TO GREASY LUSTER; ASHY TO CLAYEY TEXTURE MASSIVE BEDDING OF GRAD SILTS; GENERALLY COMPOSED OF 70% CLAY, 30% SILT WITH CARBONACEOUS LAMINAE THROUGHOUT. 34 9005 COAL/CARBONACEOUS SHALE = BLACK OCCASIONALLY DARK GRAYISH BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE OCCASIONALLY SMOOTH TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; COMPOSED OF LIGNITE AND SUB BITUMINOUS COALS WITH OCCASIONALLY THIN LAMINATIONS OF CARBONACEOUS CLAY AND GRADING TO TUFFACEOUS CLAY, FREQUENT WOODY LAMINATIONS IN COAL. 9050 CONGLOMERATE/SAND = LIGHT GRAY TO TRANSLUCENT WHITE, OCCASIONALLY OLIVE GRAY; CLASTS RANGE FROM UPPER FINE TO UPPER COARSE; MODERATELY TO WELL SORTED; ANGULAR TO SUB ROUNDED TO ROUNDED FOR FINER CLASTS; LOW TO MODERATE SPHERICITY COMPOSED OF QUARTZ AND MINOR AMOUNTOF CHERT. 9095 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY TO BROWNISH GRAY; SOFT TO FIRM; SECTILE; MUSHY TO TACKY; SLIMY TO STIFF; COHESIVE; EARTHY FRACTURE; suB BLOCKY TO SUB NODULAR HABIT; MODERATE WELL BORE POLISH ON FRAGMENTS; DULL EARTHY TO STREAKY LUSTER; CLAYEY TO SILTY TEXTURE; OCCASIONALLY LOOSE COARSE GRAIN SAND INTERBEDDED. 9140 SAND/CONGLOMERATE =LIGHT GRAY TO OLIVE GRAY; OCCASIONALLY TRANSLUCENT WHITE; CLASTS RANGE FROM UPPER VERY FINE TO UPPER MEDIUM AND OCCASIONALLY UPPER COARSE; MODERATELY SORTED; LOW TO MODERATE SPHERICITY; DOMINANTLY GRAIN SUPPORT; OCCASIONALLY CLAY MATRIX SUPPORTED USUALLY FOR FINER-GRAINED SAND. 9185 CONGLOMERATE = VERY LIGHT GRAY TO LIGHT BROWNISH GRAY; CLAST SIZE RANGES FROM COARSE UPPER TO COARSE LOWER; SUB ANGULAR BIT IMPACTED FRAGMENTS TO SUB ROUNDED; MODERATE TO OCCASIONALLY POOR SPHERICITY; MODERATE SORTING; POLISHED AND CHIPPED TEXTURE; MODERATE CLAY/SILT MATRIX; DOMINANTLY MATRIX SUPPORT; COMPOSED OF 90% CHERT, 10% METAMORPHIC; POOR ESTIMATED POROSITY AND PERMEABILITY. 9250 COAL/CARBONACEOUS SHALE = BLACK; FIRM; EARTHY TO RESINOUS LUSTER; MATTE TO SMOOTH LUSTER TEXTURE; HACKLY TO BLOCKY FRACTURE; LIGNITIC COAL WITH CARBONACEOUS SHALE. 9280 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO LIGHT BROWNISH GRAY; SOFT TO FIRM; OCCASIONALLY SOFT AND MUSHY; IRREGULAR FRACTURE; MASSIVE TO HACKLY HABIT; EARTHY LUSTER; CLAYEY TEXTURE; SILTY IN PART; GRADING TO TUFFACEOUS SILTSTONE. 9315 TUFFACEOUS CLAYSTONE= MEDIUM GRAY TO BROWNISH GRAY; SOFT TO FIRM; IRREGULAR FRACTURE; DULL TO SLIGHTLY WAXY LUSTER; CLAYEY TO ASHY TEXTURE; BECOMING VERY CARBONACEOUS; BECOMING VERY SILTY; GRADING TO SILTSTONE; THINLY BEDDED. 9350 COAL/CARBONACEOUS SHALE = BLACK; FIRM TO SLIGHTLY HARD; IRREGULAR TO BLOCKY FRACTURE; DULL TO SLIGHTLY VITREOUS LUSTER; MASSIVE CUTTINGS; LIGNITE AND SUB BITUMINOUS COALS; WITH VERY CARBONACEOUS SHALES. 9380 TUFFACEOUS CLAYSTONE = MEDIUM GRAY; SOFT; MUSHY IN PART; MASSIVE CUTTINGS; DULL EARTHY LUSTER; CLAYEY TEXTURE; SOME CARBONACEOUS LAMINAE. 9405 TUFFACEOUS CLAYSTONE = MEDIUM GRAY TO GRAY/GREENISH GRAY; SOFT; MUSHY TO PASTY; COHESIVE; IRREGULAR FRACTURE; MASSIVE TO SLIGHTLY NODULAR CUTTINGS; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; SOME SILT-FINE QUARTZ LAMINATIONS. 9440 TUFFACEOUS SILTSTONE = LIGHT BROWNISH GRAY; POOR OCCASIONALLY MODERATE INDURATION; SECTILE; MUSHY TO PASTY; TACKY TO SLIMY; COHESIVE TO SLIGHTLY ADHESIVE; EARTHY FRACTURE; GROOVED AND DEFORMED PDC BIT SOFT SEDIMENT DEFORMATION HABIT; MODERATE TO BRIGHT EARTHY LUSTER SILTY TO CLAYEY TEXTURE; GENERALLY COMPOSED OF 50% CLAY, 50% SILT WITH INCREASING MEDIUM TO FINE GRAIN SANDS. 9490 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM SILT TO FINE LOWER; SCATTERED COARSE GRAIN FRAGMENTS; SUB ROUNDED TO ROUNDED; MODERATE TO WELL DEVELOPED SPHERICITY; POOR SORTING; POLISHED OCCASIONALLY CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; ABUNDANT SILT PACKED MATERIAL COMPOSED OF 30-50% QUARTZ, 60-40% CHERT, 10% METAMORPHIC (ARGILLITE); POOR ESTIMATED POROSITY AND PERMEABILITY. 9540 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO VERY SOFT; SECTILE; FLEXIBLE TO ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; COHESIVE TO ADHESIVE; EARTHY FRACTURE; MASSIVE TO PDC BIT GROOVED HABIT; MODERATE TO BRIGHT OCCASIONALLY SATIN LUSTER; SILTY/CLAYEY TO GRITTY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF GRAD SILTS AND CLAYS; EXPANSIVE. 9590 CARBONACEOUS SHALE/COAL = BLACK; FIRM; EARTHY OCCASIONALLY RESINOUS LUSTER; SMOOTH TO MATTE TEXTURE; PLANAR FRACTURE IN SHALES TO SPINLTERY/HACKLY FRACTURE; PREDOMINANTLY VERY CARBONACEOUS SHALE WITH SOME SUB LIGNITE COAL STRINGERS. 9625 CONGLOMERATE = VERY LIGHT GRAY; CLAST SIZE RANGES FROM COARSE LOWER TO COARSE UPPER; SUB ANGULAR BIT IMPACTED FRAGMENTS TO SUB ROUNDED; MODERATE TO POOR SPHERICITY MODERATE TO COARSE GRAIN SORTING WITH POOR TO MEDIUM TO FINE GRAIN BIMODAL SORTING; GENERALLY MATRIX SUPPORTED WITH SECONDARY GRAIN SUPPORTED; COMPOSED OF CHERT WITH SECONDARY QUARTZ AND TRACE METAMORPHIC, JASPER AND VARIOUS LITHIC FRAGMENTS; TRACE POOR POROSITY AND PERMEABILITY. 9685 TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY TO BROWNISH GRAY; VERY SOFT OCCASIONALLY FIRM; SLIGHTLY SECTILE; SOME FLEXIBLE TO ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; COHESIVE TO ADHESIVE; EARTHY FRACTURE; SUB BLOCKY HABIT; MODERATE EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; THICK BEDS OF GRAD SILT SAND CLAYS INTERBEDDED WITH SAND. 9730 CARBONACEOUS SHALE/COAL = BLACK TO BLACKISH GRAY; FIRM; BRIGHT EARTHY LUSTER; MATTE TEXTURE; HACKLY FRACTURE; COMPOSED OF VARIOUS GRADES OF CARBONACEOUS SHALE AND SUB BITUMINOUS COAL. 9760 CONGLOMERATE = LIGHT BROWNISH GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM UPPER TO PREDOMINANTLY COARSE UPPER TO LOWER; ANGULAR BIT IMPACTED FRAGMENTS TO SUB ROUNDED; POOR TO MODERATE SPHERICITY; POLISHED; OCCASIONALLY CHIPPED TEXTURE; MODERATELY CLAY PACKED MATRIX; DOMINANTLY MATRIX SUPPORTED WITH SECONDARY GRAIN SUPPORT; COMPOSED OF PREDOMINANTLY CHERT WITH SECONDARY QUARTZ AND MINOR METAMORPHIC, JASPER AND VARIOUS LITHIC FRAGMENTS; FAIR TO POOR POROSITY AND PERMEABILITY. 9820 TUFFACEOUS CLAYSTONE = LIGHT BROWNISH GRAY; SOFT TO FIRM; SLIGHTLY SECTILE; FLEXIBLE TO ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; COHESIVE TO SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB BLOCKY TO HACKLY HABIT; MODERATE EARTHY LUSTER; CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF UNIFORM CLAY; GENERALLY COMPOSED OF 80% CLAY, 20% SILT AND OTHER DETRITAL MATERIAL. 9870 . TUFFACEOUS CLAYSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO FIRM; OCCASIONALLY MUSHY TO PASTY; COHESIVE; IRREGULAR FRACTURE; HACKLY TO MASSIVE HABIT; DULL EARTHY LUSTER; CLAYEY TEXTURE; SLIGHTLY SILTY AND CARBONACEOUS. 9935 TUFFACEOUS SILTSTONE = LIGHT MEDIUM GRAY; SOME BROWNISH GRAY; FIRM; MODERATELY INDURATED; IRREGULAR TO BLOCKY FRACTURE; MASSIVE CUTTINGS TO PDC RIDGE MARKINGS; SILTY TEXTURE; ABUNDANT THIN CARBONACEOUS LAMINATIONS; OCCASIONALLY VERY COALY. 37 9970 CARBONACEOUS SHALE~COAL = BLACK TO DARK BROWN; SOFT TO MODERATELY HARD; BLOCKY TO IRREGULAR FRACTURE; SLIGHTLY PLATY CUTTINGS HABIT; DULL EARTHY TO SLIGHTLY VITREOUS LUSTER; LIGNITETO SUB BITIUMINOUS COALS. 10000 CONGLOMERATE (10045) = LIGHT GRAY; CLAST SIZE RANGES FROM COARSE UPPER TO VERY COARSE UPPER WITH POSSIBLE PEBBLE; PREDOMINANTLY SUB ROUNDED BECOMING ANGULAR WITH BIT IMPACTED FRAGMENTS; MODERATE TO POOR SPHERICITY; MODERATE SORTING; POLISHED WITH CHIPPED TEXTURE; SLIGHT OCCASIONALLY MODERATELY CLAY/SILT PACKED MATRIX-HYDROPHILIC; PROBABLY GRAIN AND SOME MATRIX SUPPORT; COMPOSED OF CHERT WITH MINOR METAMORPHIC; POOR POROSITY AND PERMEABILITY. 10055 CARBONACEOUS CLAY/SILT = DARK GRAY TO GRAYISH BLACK; POOR TO MODERATE INDURATION; MUSHY TO STIFF; SUB PLANAR FRACTURE; SUB BLOCKY TO SUB PLATY HABIT; DULL EARTHY LUSTER; GRITTY TO SILTY TEXTURE GRAD VERY CARBONACEOUS CLAY AND SILT. 10090 TUFFACEOUS CLAYSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY BECOMING LIGHT BROWNISH GRAY AT 10140; FIRM; SLIMY TO STIFF; PDC GROOVED BIT FRACTURE; HACKLY TO SUB PATCHY HABIT; DULL EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; THIN TO THICK BEDS OF TUFFACEOUS CLAY COMPOSED OF 80% CLAY, 20% SILT. 10135 SAND/CONGLOMERATE = VERY LIGHT GRAY; CLAST SIZE RANGES FROM COARSE LOWER TO MEDIUM LOWER; SUB ROUNDED; MODERATE SPHERICITY; MODERATE SORTING; POLISHED OCCASIONALLY CHIPPED TEXTURE; NON TO VERY WEAK SILICEOUS CEMENT; SLIGHT TO MODERATELY CLAY-SILT PACKED MATRIX; HYDROPHILIC; GRAIN AND MATRIX SUPPORTED; COMPOSED OF 80% CHERT, 10% QUARTZ, 10% METAMORPHIC; FAIR TO POOR ESTIMATED POROSITY AND PERMEABILITY. 10190 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO MEDIUM GRAY; SOFT; SLIGHTLY FLEXIBLE TO ELASTIC; MUSHY TO TACKY; SUB EARTHY FRACTURE; SUB BLOCKY TO SUB NODULAR HABIT; DULL EARTHY LUSTER; CLAYEY OCCASIONALLY ASHY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF UNIFORM CLAY COMPOSED OF 90% TUFFACEOUS CLAYAND 10% VARIOUS DETRITAL SILT. 10235 SAND/CONGLOMERATE = LIGHT GRAY; CLAST SIZE RANGES FROM COARSE LOWER TO MEDIUM LOWER; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; MATRIX SUPPORTED WITH CLAY-SILT MATRIX; TRACE AMOUNTS OF GRAIN SUPPORTED WITH SILICEOUS CEMENT; COMPOSED OF 90% QUARTZ AND CHERT WITH 10% METAMORPHIC. 10275 SAND/CONGLOMERATE = PREDOMINANTLY LOOSE GRAINS; CLAST SIZE RANGES FROM COARSE LOWER TO MEDIUM LOWER; SUB ANGULAR; LOW TO MODERATE SPHERICITY; MODERATE SORTING; TRACE AMOUNTS OF MATRIX SUPPORTED WITH SILT-CLAY MATRIX; 90% CHERT AND QUARTZ. 10315 CARBONACEOUS SHALE/COAL = BLACK; FIRM TO SLIGHTLY HARD; SPINLTERY TO BLOCKY CUTTINGS; BLOCKY TO PLANAR FRACTURE; EARTHY TO RESINOUS LUSTER; SMOOTH TEXTURE; LIGNITE COAL STREAKS. 10345 TUFFACEOUS CLAYSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY;OCCASIONALLY MODERATELY CARBONACEOUS; MASSIVE CUTTINGS; OCCASIONALLY SOME PDC GROOVED MARKINGS; SILTY TO ASHEY TEXTURE; ABUNDANT SILT; SOME THIN BLACK CARBONACEOUS LAMINATIONS. 10380 CARBONACEOUS SHALE~COAL = BLACK; FIRM TO SLIGHTLY HARD; SLIGHTLY PLATY TO BLOCKY; DULL EARTHY LUSTER; PLANT IMPRESSIONS IN SUB BITUMINOUS COAL; SMOOTH TO MATTE TEXTURE. 10410 COAL~CARBONACEOUS SHALE = BLACK; MODERATELY HARD; BLOCKY TO CONCHOIDAL FRACTURE; SHALE IS SPLINTERY TO HACKLY FRACTURE; SMOOTH, SLIGHTLY VITREOUS LUSTER IN COAL SPECIMENS; DULL EARTHY IN CARBONACEOUS SHALE; SOME SHALY LAMINATIONS IN COALY SPECIMENS; THINLY BEDDED; TRACE PLANT IMPRESSIONS. 10455 CONGLOMERATE/SANDSTONE = PREDOMINANTLY LOOSE GRAINS; CLAST SIZES RANGE FROM UPPER COARSE TO UPPER MEDIUM; TRACE AMOUNTS OF LIGHT GRAY MATRIX SUPPORTED SPECIMENS; SUB ANGULAR TO SUB ROUNDED; FAIR SORTED; LOW TO MODERATE SPHERICITY; ANGULAR BIT IMPACTED FRAGMENTS; CHERT 30%; QUARTZ 60% 10% METAMORPHIC; FAIR POROSITY AND PERMEABILITY 10520 CONGLOMERATE~SAND = ABUNDANT LOOSE GRAINS; CLAST SIZE FROM UPPER COARSE TO LOWER MEDIUM; SOME LIGHT GRAY MATRIX SUPPORTED SPECIMENS WITH SILT CLAY MATRIX; 90% CHERT/QUARTZ; LOW TO MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; ABUNDANT CARBONACEOUS MATERIAL IN MATRIX 10565 CONGLOMERATE = PREDOMINANTLY LOOSE GRAINS; UPPER COARSE TO UPPER MEDIUM GRAINED; SOME SHARP BIT IMPACTED COARSE GRAINS; ANGULAR TO SUB ANGULAR; MODERATE SPHERICITY; TRACE MATRIX SUPPORTED SPECIMENS W/SILT CLAY MATRIX; 20% CHERT, 60% QUARTZ; 20% METAMORPHIC-IGNEOUS; TRACE JASPER; SOME CARBONACEOUS MATERIAL 10610 CARBONACEOUS SHALE = DARK GRAY TO BLACK; FIRM; IRREGULAR TO PLANAR FRACTURE; FLAKY TO PLATY CUTTINGS; DULL EARTHY TO SLIGHTLY RESINOUS LUSTER; CLAYEY TEXTURE; THINLY BEDDED; WITH TRACE TO MINOR AMOUNTS OF SUB BITUMINOUS COAL 10645 CONGLOMERATE~SANDSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; FIRM; UPPER COARSE TO LOWER MEDIUM GRAINED; CRUMBLY; ANGULAR TO SUB ANGULAR; LOW TO MODERATE SPHERICITY; LIGHT GRAY SILT MATRIX WITH VARIABLE AMOUNTS OF CARBONACEOUS MATERIAL 10685 TUFFACEOUS SILTSTONE = LIGHT TO MEDIUM GRAY; FIRM; CRUMBLY; IRREGULAR FRACTURE; MASSIVE TO SLIGHTLY PLATY CUTTINGS; SILTY TEXTURE; VERY THIN CARBONACEOUS LAMINATIONS; THICKLY BEDDED 10715 CARBONACEOUS SHALE = BLACK; FIRM; CRUMBLY; HACKLY TO SPLINTERY FRACTURE; SCALY TO PLATY CUTTINGS; DULL LUSTER; CLAYEY TEXTURE; SOME SLIGHTLY VITREOUS LUSTER ON SUB BITUMINOUS COALY PARTINGS; THINLY BEDDED 10750 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY; SOFT; MUSHY IN PART;IRREGULAR FRACTURE; MASSIVE CUTTINGS; DULL MATTE LUSTER-OCCASIONALLY SLIGHTLY VITREOUS; VERY FINE SILTY TEXTURE; NON TO VERY SLIGHTLY CALCAREOUS; SOME ASH LAMINATIONS; SCATTERED CARBONACEOUS SPECKS 10785 SANDSTONE = PREDOMINANTLY LOOSE GRAINS; CLASTS RANGE FROM LOWER COARSE TO UPPER MEDIUM GRAINED; MODERATELY SORTED; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; TRACE MATRIX SUPPORTED SPECIMENS WITH SILT-CLAY MATRIX; 30% CHERT, 60% QUARTZ, 10% METAMORPHIC; VARIABLE AMOUNTS OF CARBONACEOUS MATERIAL IN MATRIX 10830 TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; VERY SOFT TO MUSHY; MASSIVE BEDDING, ABUNDANT PDC RIDGE MARKINGS; MASSIVE CUTTINGS; SILTY TO CLAYEY TEXTURE; EARTHY LUSTER; NON CALCAREOUS; COMMOM CARBONACEOUS SPECKS; OCCASIONALLY SCATTERED QUARTZ GRAINS. 10865 COAL = BLACK; DENSE AND BRITTLE; FIRM; RESINOUS TO EARTHY LUSTER; BLOCKY TO CONCHOIDAL FRACTURE; WITH VARIOUS GRADES OF CARBONACEOUS SHALE; WITH ABUNDANT LOOSE SAND GRAINS. 40 10895 CONGLOMERATE = LIGHT BROWNISH GRAY TO LIGHT GRAY; CLAST SIZE RANGES FROM MEDIUM TO OCCASIONALLY COARSE UPPER TO LOWER; ANGULAR BIT IMPACTED FRAGMENTS TO SUB ROUNDED; POOR TO MODERATE SPHERICITY; POLISHED; OCCASIONALLY CHIPPED TEXTURE; SILT-CLAY MATRIX; REPRESENTED BY ABUNDANT LOOSE SAND GRAINS. 10950 CONGLOMERATE = LIGHT GRAY TO LIGHT BROWN GRAY; CLAST SIZE RANGES FROM MEDIUM TO COARSE; ANGULAR BIT IMPACTED FRAGMENTS TO SUB ROUNDED; POOR TO MODERATE SPHERICITY; POLISHED OCCASIONALLY CHIPPED TEXTURE; WITH OCCASIONALLY LOOSE SAND GRAINS. 10985 COAL = BLACK TO BROWN BLACK; DENSE AND BRITTLE; FIRM TO OCCASIONALLY HARD; BRIGHT LUSTER; BLOCKY TO CONCHOIDAL FRACTURING; WITH VARIOUS GRADES OF CARBONACEOUS SHALE. 11010 SAND = VERY LIGHT GRAY; CLAST SIZE RANGE FROM SILTY TO FINE GRAINED; SCATTERED COARSE; SUB ROUNDED TO ROUNDED; POOR SORTING POOR ESTIMATED POROSITY AND PERMEABILITY. 11040 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM BROWNISH GRAY; SOFT; MUSHY TO CRUMBLY;IRREGULAR FRACTURE; MASSIVE CUTTINGS; DULL MATTE LUSTER-OCCASIONALLY SLIGHTLY SHINY; VERY FINE SILTY TEXTURE; NON-TO VERY SLIGHTLY CALCAREOUS; OCCASIONAL ASH LAMINATIONS; SCATTERED CARBONACEOUS SPECKS. 11075 TUFFACEOUS SILTSTONE = PALE YELLOWISH BROWN TO MODERATE BROWN, RARELY LIGHT TO MEDIUM GRAY; SOFT TO RARELY SLIGHTLY FIRM; CRUMBLY TO OCCASIONALLY SLIGHTLY BRITTLE; MATTE, EARTHY LUSTER WITH SCATTERED SPARKLES; GRAINY, ABRASIVE TEXTURE; NON TO OCCASIONALLY SLIGHTLY CALCAREOUS; SCATTERED TO COMMON CARBONACEOUS SPECKS; SCATTERED TO COMMON VOLCANIC GLASS SHARDS; OCCASIONAL BLEBS OF ASH; INTERBEDDED WITH AND GRADING TO TUFFACEOUS CLAYSTONE. 11125 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR, TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY; VERY FINE TO MEDIUM, DOMINANTLY FINE GRAIN; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; 70% QUARTZ, 20% LITHICS, 10%CHERT; RARE JASPER; ESTIMATED FAIR VISUAL POROSITY AND PERMEABILITY. 11165 COAL = BLACK; FIRM- SLIGHTLY HARD; BLOCKY TO SPLINTERY; BLOCKY TO CONCHOIDAL FRACTURE RESINOUS TO DULL LUSTER; COMPOSED OFSUB BITUMINOUS COAL WITH SOME CARBONACEOUS SHALE 11195 COAL = BLACK; SLIGHTLY HARD; SPLINTERY TO BLOCKY HABIT; BLOCKY FRACTURE; SLIGHTLY VITREOUS TO RESINOUS LUSTER; SOME PLANT IMPRESSIONS; SUB BITUMINOUS COAL. 41 11225 SAND = PREDOMINANTLY LOOSE GRAINS; CLEAR TO TRANSLUCENT; MEDIUM TO FINE GRAINED; FAIRLY WELL SORTED; SUB ROUNDED; MODERATE SPHERICITY; 70% QUARTZ AND CHERT, 30% METAMORPHIC; TRACE LIGHT GRAY PRESERVED SPECIMENS WITH LIGHT GRAY TUFFACEOUS CLAY MATRIX; MATRIX SUPPORTED. 11265 COAL = BLACK; FIRM TO SLIGHTLY HARD; BLOCKY TO PLATY CUTTING; IRREGULAR TO BLOCKY FRACTURE; GRADING TO CARBONACEOUS SHALE; TRACE HARD VITREOUS COAL PARTINGS; DULL TO RESINUOUS LUSTER; CARBONACEOUS IN PART. 11315 SAND = PREDOMINANTLY LOOSE GRAINS; LOWER COARSE TO LOWER MEDIUM CLAST SIZES; CLEAR TO TRANSLUCENT; FAIR SORTING; LOW TO MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; NO VISIBLE MATRIX PRESERVED; ABUNDANT CHERT AND QUARTZ GRAINS;INCREASE IN CARBONACEOUS MATERIAL. 11360 COAL = DUSKY BROWN TO BLACK; FIRM TO VERY FIRM; BRITTLE; IRREGULAR BLOCKY TO SUB NODULAR MASSIVE PIECES; OCCASIONALLY CONCHOIDAL FRACTURES; DULL SUB-RESINOUS LUSTER; SMOOTH TEXTURE; LOW GRADE LIGNITE TO SUB BITUMINOUS COAL. 11400 SAND = LIGHT GRAY TO CLEAR; CLASTS RANGE FROM FINE TO UPPER MEDIUM OCCASIONALLY COARSE GRAINS; DOMINANTLY UNCONSOLIDATED SAND GRAINS; LOW TO MODERATE SPHERICITY; POOR TO MODERATE SORTING. 11435 TUFFACEOUS CLAYSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY; SOFT TO OCCASIONALLY FIRM; MALLEABLE TO SECTILE; STIFF; EARTHY; SUB NODULAR HABIT; PDC BIT GROOVED HABIT;OCCASIONALLY BECOMING SILTY. 11465 SAND = LIGHT GRAY TO CLEAR; CLAST RANGE FROM VERY FINE TO COARSE; DOMINANTLY FINE RANGE ANGULAR TO SUB ROUNDED; MODERATELY SORTED; UNCONSOLIDATED IN SAMPLE; NO ACID REACTION. 11505 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR LIGHT TO MEDIUM GRAY, BLACK, OCCASIONALLY MEDIUM TO DARK GRAYISH GREEN; CLASTS RANGE FROM FINE TO COARSE, DOMINANTLY FINE TO MEDIUM GRAIN; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR; MODERATELY SORTED; COMPOSED OF 70% QUARTZ~ 30% METAMORPHIC/VOLCANIC LITHICS; GRAINS APPEAR LOOSE IN SAMPLES; OCCASIONAL GRAINS WITH CALCITE CRUST ON SURFACES. 42 11555 TUFFACEOUS CLAYSTONE = PALE YELLOWISH BROWN TO OCCASIONALLY MODERATE BROWN, RARELY MEDIUM GRAY; SOFT; MUSHY TO CRUMBLY; AMORPHOUS TO OCCASIONALLY SLIGHTLY BLOCKY CUTTINGS; MATTE, EARTHY LUSTER TO RARELY SLIGHTLY SHINY LUSTER; SMOOTH TO OCCASIONALLY SLIGHTLY GRITTY TEXTURE; NON TO RARELY SLIGHTLY CALCAREOUS; LOCALLY COMMON GLASSY SHARDS; SCATTERED TO COMMON ASHY STREAKS AND BLEBS; COMMON CARBONACEOUS SPECKS. 11605 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM GRAY TO BROWNISH GRAY; VERY SOFT TO FIRM; MASSIVE CUTTINGS TO SLIGHTLY PLATY; MUSHY TO CRUMBLY; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; MODERATE TO VERY SILTY; ASHY STREAKS; SOME THIN CARBONACEOUS MATERIAL. 11645 COAL~CARBONACEOUS SHALE = BLACK; FIRM TO MODERATELY HARD; SPLINTERY TO IRREGULAR CUTTINGS; SLIGHTLY RESINOUS LUSTER; SMOOTH TEXTURE; ARGILLACEOUS AT TOP-GRADING TO CARBONACEOUS SHALE; TRACE CONCHOIDAL FRACTURES ON COALY PIECES. 11685 SAND = LOOSE GRAINS ONLY; CLEAR TO TRANSLUCENT GRAINS; FINE TO UPPER MEDIUM GRAINED; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; FAIR SORTING. 11720 SAND = LOOSE GRAINS ONLY; LIGHT GRAY TO CLEAR TO TRANSLUCENT; FINE TO UPPER MEDIUM GRAINED; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; FAIR SORTING; NO PRESERVED MATRIX. 11755 COAL = BLACK; FIRM TO MODERATELY HARD; SMALL IRREGULAR; PLATY; TABULAR CUTTINGS CONCHOIDAL FRACTURE SURFACES; RESINOUS LUSTER; SMOOTH TO OCCASIONALLY GRAINY TEXURE; SCATTERED TUFFACEOUS CLAYSTONE LAMINATIONS. 11785 CARBONACEOUS SHALE = DUSKY BROWN TO BLACK; MODERATELY SOFT TO HARD; SMOOTH TO ROUGH SURFACE TEXTURE; DOMINANTLY ROUGH; SPLINTERY TO BLOCKY; THIN TUFFACEOUS CLAYSTONE LAMINATIONS INTERBEDDED WITH COAL. 11820 TUFFACEOUS CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY; DOMINANTLY AMORPHOUS LUMPS; SOFT TO OCCASIONALLY SLIGHTLY FIRM; DULL MATTE LUSTER; NON CALCAREOUS; COMMON CARBONACEOUS SPECKS; SILTY TO SLIGHTLY GRITTY TEXTURE; FINE TO MEDIUM GRAIN SAND EMBEDDED IN CLAY. 11855 CARBONACEOUS SHALE/COAL = DUSKY BROWN TO BLACK; MODERATELY SOFT TO HARD; SMOOTH TO ROUGH TEXTURE; SPLINTERY TO BLOCKY;THIN TUFFACEOUS CLAYSTONE LAMINATIONS INTERBEDDED WITH COAL; ABUNDANT LOOSE FINE GRAINED SAND. 43 11900 SAND/SANDSTONE = LIGHT GRAY OVERALL; VERY FINE TO MEDIUM, DOMINANTLY FINE GRAINED; SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 80% QUARTZ, 20% METAMORPHIC/VOLCANIC LITHICS; CLAY MATRIX; LIGHT CALCITE CEMENT; ESTIMATED FAIR POROSITY AND PERMEABILITY. 11935 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM GRAY; FIRM TO SOFT; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL MATTE LUSTER; SILTY TO GRITTY TEXTURE; SOME BLACK CARBONACEOUS STREAKS; SOME SCATTERED VERY FINE TO FINE QUARTZ GRAINS IN MATRIX. 11970 COAL~CARBONACEOUS SHALE = BLACK; FIRM TO MODERATELY HARD; SPLINTERY TO BLOCKY CUTTINGS; IRREGULAR TO SPLINTERY FRACTURE; SMOOTH TO GRITTY TEXTURE; DULL TO RESINOUS LUSTER; GRADING TO CARBONACEOUS SHALE; SUB BITUMINOUS / LIGNITE. 12010 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM GRAY; FIRM; SPLINTERY TO SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; SILTY TEXTURE; DULL LUSTER; CARBONACEOUS IN PART; WITH VERY FINE QUARTZ GRAINS 12040 SANDSTONE = LIGHT GRAY TO GRAY; VERY FINE TO FINE GRAINED; SUB ANGULAR TO SUB ROUNDED; SOME ANGULAR; LOW TO MODERATE SPHERICITY; POOR SORTING; VERY SLIGHTLY CALCAREOUS; TUFFACEOUS CLAY MATRIX; NO VISUAL POROSITY. 12075 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM GRAY; SOFT TO OCCASIONALLY SLIGHTLY FIRM; DOMINANTLY APPEARS AS LUMPY CLAY; MATTE LUSTER; SMOOTH TO GRITTY TEXTURE; NON TO SLIGHTLY CALCAREOUS; COMMON CARBONACEOUS LAMINATIONS PRESENT. 12110 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM GRAY; SOFT TO SLIGHTLY FIRM; LUMPY TO MALLEABLE TENACITY; SMOOTH TO SLIGHTLY GRITTY TEXTURE; COMMON CARBONACEOUS LAMINATIONS; SUB RESINOUS LUSTER; SAND GRAINS COMMONLY EMBEDDED IN LUMPS. 12145 SAND = LIGHT GRAY; DOMINANTLY TRANSLUCENT WHITE TO MEDIUM GRAY; COMMONLY CLEAR; CLASTS RANGE FROM VERY FINE UPPER TO COARSE LOWER; DOMINANTLY FINE TO MEDIUM GRAINED; POORLY SORTED; ANGULAR TO SUB ROUNDED; DOMINANTLY CLAY MATRIX; LOOSELY UNCONSOLIDATED. 12185 COAL = BLACK; FIRM TO HARD; SMOOTH TO ROUGH SURFACE TEXTURE; SPLINTERY TO BLOCKY TO TABULAR CUTTINGS; THIN TUFFACEOUS CLAYSTONE LAMINATIONS. 44 12210 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO MEDIUM GRAY; SOFT TO SLIGHTLY FIRM; LUMPY TO MALLEABLE TENACITY; SMOOTH TO SLIGHTLY GRITTY TEXTURE; COMMON CARBONACEOUS LAMINATIONS; SUB RESINOUS LUSTER; SAND GRAINS COMMONLY EMBEDDED IN LUMPS. 12255 COAL~CARBONACEOUS SHALE = BLACK; FIRM TO MODERATELY HARD; SPLINTERY TO TABULAR CUTTINGS; IRREGULAR TO PLANAR FRACTURE; SMOOTH TO GRITTY TEXTURE; NON CALCAREOUS; DULL TO SLIGHTLY RESINUOUS LUSTER; GRADING TO SUB BITUMINOUS COAL. 12295 SAND = LIGHT GRAY TO MEDIUM GRAY; DOMINANTLY TRANSLUCENT; CLASTS RANGE FROM VERY FINE UPPER TO MEDIUM GRAINED; FAIR SORTING; ANGULAR TO SUB ROUNDED; DOMINANTLY CLAY MATRIX; COMMONLY LOOSELY UNCONSOLIDATED. 12330 SAND = CLEAR TO TRANSLUCENT WHITE TO LIGHT GRAY; CLASTS RANGE FROM VERY FINE UPPER TO MEDIUM UPPER; DOMINANTLY FINE TO MEDIUM; MODERATELY SORTED; SUB ANGULAR TO SUB ROUNDED; COMMONLY UNCONSOLIDATED. 12380 COAL = DARK BROWN TO BLACK; FIRM TO MODERATELY HARD; TOUGH, BRITTLE TO; SMOOTH TO ROUGH SURFACE TEXTURE; BLOCKY TO SPLINTERY TO TABULAR CUTTINGS; THIN TUFFACEOUS CLAYSTONE LUMPS AND CARBONACEOUS SHALE INTERBEDDED WITH COAL. 12420 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM GRAYISH BROWN; VERY SOFT TO SOFT; MUSHY TO CRUMBLY; MATTE, EARTHY LUSTER; SMOOTH TO OCCASIONALLY MODERATELY GRITTY TEXTURE; NON-TO OCCASIONALLY MODERATELY CALCAREOUS; COMMON GLASSY SHARDS; COMMON CARBONACEOUS SPECKS AND STREAKS; COMMON ASHY STREAKS AND BLEBS. 12460 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR, LIGHT TO MEDIUM GRAY, MEDIUM TO DARK GREEN, BLACK; FINE COARSE, DOMINANTLY FINE GRAINED; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 70% QUARTZ, 30% METAMORPHIC/VOLCANIC LITHICS; TRACE JASPER; APPEARS AS LOOSE GRAINS IN SAMPLES; FEW GRAINS WITH THIN CALCITE CRUSTS ON SURFACES; ESTIMATED FAIR VISUAL POROSITY AND PERMEABILITY. 12515 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR, LIGHT TO MEDIUM GRAY, MEDIUM TO DARK GREEN, BLACK; FINE TO MEDIUM, DOMINANTLY FINE GRAINED; ANGULAR TO ROUNDED, DOMINANTLY SUB ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 80% QUARTZ, 20% METAMORPHIC/VOLCANIC LITHICS; TRACEACE JASPER; TOTALLY UNCONSOLIDATED IN SAMPLES. 45 12555 COAL~CARBONACEOUS SHALE = BLACK; FIRM TO MODERATELY HARD; BLOCKY TO SPLINTERY; DULL TO SLIGHTLY RESINOUS TO VITREOUS LUSTER; IRREGULAR TO PLANAR FRACTURE; SMOOTH TO SLIGHTLY GRITTY TEXTURE; GRADING TO SUB BITUMINOUS COAL 12590 SAND = CLEAR TO TRANSLUCENT; SOME WHITE; SOME LIGHT GRAY TO BLACK GRAINS; LOWER FINE TO LOWER MEDIUM GRAINED; MODERATELY WELL SORTED; MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED 80% QUARTZ 20% METAMORPHIC. 12630 SAND = PREDOMINANTLY LOOSE GRAINS; UPPER FINE TO UPPER MEDIUM GRAINED; SOME DARK CHERT GRAINS; SUB ANGULAR TO SUB ROUNDED; LOW TO MODERATE SPHERICITY; MODERATELY WELL SORTED; RARE MATRIX SUPPORTED SPECIMENS; CLAY/SILT MATRIX; 90% QUARTZ, 10% CHERT/METAMORPH ICS. 12870 TUFFACEOUS CLAYSTONE = LIGHT TO MEDIUM GRAY; FIRM TO SLIGHTLY HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; SILTY TO GRITTY TEXTURE; DULL EARTHY LUSTER; SOME VERY FINE QUARTZ GRAINS; OCCASIONALLY CARBONACEOUS; WITH ABUNDANT SAND AND CARBONACEOUS SHALE. 12710 CONGLOMERATE = PREDOMINANTLY LOOSE GRAINS; LOWER COARSE TO LOWER MEDIUM GRAINS; SUB ROUNDED TO SUB ANGULAR; PREDOMINANTLY SUB ROUNDED; SOME RED AND GREEN CHERTS; MODERATE SPHERICITY; ABUNDANT CARBONACEOUS MATERIAL IN MATRIX. 12750 COAL/CARBONACEOUS SHALE = BLACK; MODERATELY FIRM TO MODERATELY HARD; BLOCKY TO CONCHOIDAL FRACTURES; SHALE IS SPLINTERY TO HACKLY FRACTURES; SMOOTH; VITREOUS LUSTER IN COAL; DULL EARTHY IN CARBONACEOUS SHALE; SOME SHALY LAMINATIONS IN COAL CUTTINGS; THINLY BEDDED. 12790 SAND = LIGHT GRAY TO WHITE TO CLEAR; DOMINANTLY CLEAR; CLASTS RANGE FROM FINE LOWER TO MEDIUM UPPER; MODERATELY WELL SORTED; SUB ANGULAR TO SUB ROUNDED; DOMINANTLY UNCONSOLIDATED IN SAMPLE. 12820 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO LIGHT GRAY TO MEDIUM GRAY; VERY SOFT TO OCCASIONALLY FIRM; DOMINANTLY APPEARS AS AMORPHOUS LUMPS;OCC FIRM TABULAR CUTTINGS; DULL LUSTER; SMOOTH TO GRAINY TEXTURE; NON TO SLIGHTLY CALCAREOUS; GRADING IN PART TO CARBONACEOUS SHALE. 46 12860 CONGLOMERATE = PREDOMINANTLY LOOSE GRAINS; CLEAR TO FROSTED; CLAST SIZE FROM UPPER COARSE TO LOWER MEDIUM; MODERATE SPHERICITY; SUB ANGULAR TO SUB ROUNDED; FAIR TO POOR SORTING; ANGULAR BIT IMPACTED FRAGMENTS; RED TO GREEN CHERT; OCCASIONAL CARBONACEOUS MATERIAL IN MATRIX. 12905 SANDSTONE = PREDOMINANTLY LOOSE GRAINS; CLASTS RANGE FROM LOWER COARSE TO UPPER MEDIUM GRAINED; MODERATE SORTING; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; VARIABLE AMOUNTS OF CARBONACEOUS MATERIAL. 12940 ASH FALL TUFF = LIGHT GRAY TO WHITE, OCCASIONALLY LIGHT TO MEDIUM GRAY, RARELY WITH SLIGHTLY GREENISH OR BLUISH HUES; VERY SOFT TO SLIGHTLY FIRM; MUSHY TO OCCASIONALLY MODERATELY BRITTLE; MATTE TO SLIGHTLY RESINOUS LUSTER; DOMINANTLY SMOOTH TO OCCASIONALLY MODERATELY GRITTY TEXTURE; NON TO OCCASIONALLY MODERATELY CALCAREOUS; COMMON GLASS SHARDS; COMMON BLACK SPECKS; SOME PIECES WITH FAINT PALE YELLOW PALE YELLOWISH BLUE MINERAL FLUORESCENCE. 13000 TUFFACEOUS CLAYSTONE = MEDIUM TO LIGHT GRAY; FIRM; MASSIVE PIECES; IRREGULAR FRACTURE; ROUGH TO GRITTY TEXTURE; ASHEY IN PART; MATTE LUSTER; VERY FINE QUARTZ; SOME SCATTERED CARBONACEOUS MATERIAL. 13035 SANDSTONE = PREDOMINANTLY LOOSE GRAINS; WHITE TO LIGHT GRAY TO TRANSLUCENT GRAINS; CLASTS RANGE FROM FINE TO UPPER MEDIUM; MODERATELY WELL SORTED; ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; NO MATRIX PRESERVED; COMPOSED OF 80% QUARTZ AND CHERT, 20% METAMORPHIC. 13075 SANDSTONE = PREDOMINANTLY LOOSE GRAINS; TRACE LIGHT GRAY; ABUNDANT TRANSLUCENT GRAINS; UPPER MEDIUM TO FINE GRAINED; ANGULAR TO SUB ROUNDED; MODERATELY WELL SORTED; MEDIUM GRAY CLAY~SILT MATRIX; 90% QUARTZ AND CHERT; 10% METAMORPHIC. 13115 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO LIGHT TO MEDIUM GRAY; VERY SOFT TO OCCASIONALLY FIRM DOMINANTLY APPEARS AS AMORPHOUS ASHY CLUMPS; DULL EARTHY LUSTER; SMOOTH TO GRAINY TEXTURE; NON TO SLIGHTLY CALCAREOUS; COMMON FINE TO MEDIUM SAND GRAINS EMBEDDED IN CLUMPS OF CLAY; LOCALLY VERY CARBONACEOUS; GRADING TO OCCASIONALLY SILTSTONE. 47 13160 ASH FALL TUFF = WHITE TO LIGHT GRAY; OCC MEDIUM GRAY; VERY SOFT TO OCCASIONALLY HARD; DOMINANTLY APPEARS AS AMORPHOUS VERY SOFT LUMPS;OCC AS HARD TOUGH SUB BLOCKY CUTTINGS; DULL LUSTER; SMOOTH TO SILKY TEXTURE; NON CALCAREOUS. 13195 TUFFACEOUS CLAYSTONE = BROWNISH GRAY TO MEDIUM GRAY; VERY SOFT TO OCCASIONALLY FIRM; DOMINANTLY APPEARS AS AMORPHOUS ASHY CLUMPS; OCCASIONALLY AS MODERATELY INDURATED SUB BLOCKY CUTTINGS; DULL EARTHY LUSTER; SMOOTH TO MODERATELY GRAINY TEXTURE; NON CALCAREOUS; FINE TO MEDIUM GRAINED SAND EMBEDDED IN CLUMPS OF CLAY; LOCALLY VERY CARBONACEOUS; OCCASIONALLY GRADING TO SILTSTONE. 13245 CARBONACEOUS SHALE = DUSKY BROWN TO BLACK; FIRM TO MODERATELY HARD; MODERATELY TOUGH; SPLINTERY; TABULAR AND BLOCKY IN PART; SMOOTH TO ROUGH TEXTURE; SCATTERED TUFFACEOUS CLAY LAMINATIONS. 13275 COAL = BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; TOUGH; DENSE; BRITTLE TENACITY; SPLINTERY TO TABULAR TO SUB BLOCKY CUTTINGS; RESINOUS LUSTER; SMOOTH TO SLIGHTLY ROUGH SURFACE TEXTURE; OCCASIONAL STREAKS OF TUFFACEOUS CLAYSTONE. 13310 SAND = LIGHT GRAY OVERALL, DOMINANTLY TRANSLUCENT WHITE LIGHT GRAY; FINE TO MEDIUM, DOMINANTLY FINE GRAINED; ANGULAR TO SUB ROUNDED; COMPOSED OF 80% QUARTZ, 20% METAMORPHIC/VOLCANIC LITHICS; FEW GRAINS WITH THIN CALCITE RIND ON SURFACES. 13355 SAND = CLEAR TO TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY; CLASTS RANGE FROM FINE LOWER TOCOARSE UPPER; DOMINANTLY FINE TO MEDIUM GRAINED; MODERATELY SORTED; ANGULAR TO SUB ROUNDED; APPARANTLY FAIR VISUAL POROSITY AND PERMEABILITY. 13390 SAND = LIGHT GRAY TO CLEAR TO TRANSLUCENT; CLAST SIZES RANGE FROM FINE GRAIN LOWER TO COARSE UPPER; DOMINANTLY FINE TO MEDIUM; POOR SORTING; ANGULAR TO SUB ROUNDED; CLAY MATRIX; COMMONLY UNCONSOLIDATED; OIL INDICATORS OBSCURED BY OIL BASE MUD 13425 SAND=LIGHT GRAY TO CLEAR; CLAST SIZE RANGES FROMEDIUM FINE LOWER TO MEDIUM DOMINANTLY UPPER FINE; ANGULAR TO SUB ROUNDED; MODERATELY SORTED; COMPOSED OF 70% QUARTZ 20% CHERT 10% DARK METAMORPHIC/LITHIC/VOLCANIC CLASTS; TRACE PEBBLE SIZED CLASTS SHOWING EVIDENCE OF BIT CHIPPING; SLIGHTLY CALCAREOUS WITH SLOW ACID REACTION; SAMPLE IS 100% DISAGREGATED SAND GRAINS; OIL INDICATORS OBSCURED BY OIL BASE MUD. 48 13480 SAND=CLEAR TO VERY LIGHT GRAY, TRACE MILKY WHITE; CLAST SIZE LOWER FINE TO MEDIUM DOMINANTLY UPPER FINE; SUB ANGULAR TO SUB ROUNDED WITH A TRACE ANGULAR DOMINANTLY SUB ANGULAR; MODERATELY SORTED; COMPOSED OF 70% QUARTZ 20% CHERT 10% DARK VOLCANICS; SLOW ACID REACTION. 13520 COAL=BLACK TO VERY DARK GRAYISH BLACK; FIRM TO HARD; GENERALLY BRITTLE AND CRUNCHY WITH SHARP EDGES; PLATY AND EXHIBITS A FISSILE HABIT; SHINY LUSTER; HACKLY TO SEMI CONCHOIDAL FRACTURE. 13555 SAND=CLEAR TO VERY LIGHT GRAY; LOWER FINE TO MEDIUM GRAIN DOMINANTLY UPPER FINE; SUB ANGULAR TO SUB ROUNDED DOMINANTLY SUB ROUNDED; COMPOSED OF 60-80% QUARTZ 20-30% CHERT 10% DARK LITHIC/VOLCANIC/METAMORPHIC GRAINS; SLIGHTLY CALCAREOUS WITH SLOW ACID REACTION; MATRIX CLAY IS PALE BROWN, STIFF, GELATINOUS; OIL INDICATORS MASKED BY OIL BASE MUD. 13600 COAL = BLACK TO DUSKY BROWN; FIRM TO MODERATELY HARD; BRITTLE TO MODERATELY TOUGH; SPLINTERY; TABULAR AND BLOCKY CUTTINGS; SMOOTH TEXTURE; RESINOUS LUSTER. 13625 SAND = CLEAR TO TRANSLUCENT WHITE TO LIGHT GRAY, OCCASIONALLY REDDISH ORANGE; CLASTS RANGE FROM FINE LOWER TO COARSE LOWER, DOMINANTLY FINE TO MEDIUM GRAINED; MODERATELY SORTED; ANGULAR TO SUB ROUNDED; OIL INDICATORS OBSCURED BY OIL BASE MUD. 13660 SAND = LIGHT GRAY TO TRANSLUCENT WHITE TO CLEAR; CLAST SIZE RANGES FROM FINE GRAIN LOWER TO COARSE LOWER; DOMINANTLY FINE TO MEDIUM; POOR TO FAIR SORTING; ANGULAR TO SUB ROUNDED; COMMONLY UNCONSOLIDATED; OIL INDICATORS OBSCURED BY OIL BASE MUD. 13700 SAND = CLEAR TO TRANSLUCENT WHITE TO LIGHT GRAY; SOME REDDISH ORANGE TO LIGHT GREENISH GRAY; VERY FINE TO MEDIUM COARSE GRAINED; DOMINANTLY FINE TO MEDIUM GRAINED; POORLY SORTED; ANGULAR TO SUB ROUNDED; NON CALCAREOUS; POOR TO FAIR VISUAL POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 13750 SAND=CLEAR TO MILKY WHITE TRANSLUSCENT TO VERY LIGHT GRAY; FINE TO UPPER MEDIUM GRAINED DOMINANTLY FINE; SUB ROUNDED TO SUB ANGULAR DOMINANTLY SUB ROUNDED; COMPOSED OF 80% QUARTZ 10% CHERT; TRACE OFMODERATELY REDDISH BROWN JASPER; 10% MIXED DARK METAMORPHIC/LITHICNOLCANIC CLASTS; VERY SLOW ACID REACTION INDICATING SOME CALCAREOUS CEMENT; OIL INDICATIONS MASKED BY OIL BASE MUD. 49 13810 COAL=BLACK TO VERY DARK GRAYISH BLACK; FIRM TO HARD; GENERALLY BRITTLE AND CRUNCHY WITH SHARP SOMETIMES JAGGED EDGES; PLATY AND FISSILE OCAASIONALLY BLOCKY; RESINOUS LUSTER; EXHIBITS POOR CONCHOIDAL TO HACKLY FRACTURE. 13845 SAND=CLEAR TO VERY LIGHT GRAY MILKY WHITE; VERY FINE GRAINED TO FINE GRAINED, DOMINANTLY LOWER FINE GRAINED; GENERALLY SUB ROUNDED; GRADING TO SUB ANGULAR; MODERATELY TO WELL SORTED; COMPOSED OF 80% QUARTZ 10-20% CHERT AND VERY MINOR DARK LITHIC/METAMORPHICNOLCANIC DEBRIS TRACE OF REDISH BROWN JASPER; SLIGHTLY CALCAREOUS WITH VERY SLOW ACID REACTION; SAMPLE IS 100% DISAGGREGATED GRAINS SO INFERRED FAIR POROSITY AND PERMEABILITY; OIL INDICATIONS MASKED BY OIL BASE MUD. 13910 SAND=CLEAR TO VERY LIGHT GRAY TO MILKY WHITE; GENERALLY VERY FINE GRAINED TO FINE GRAINED WITH OCCASIONAL CLASTS MEDIUM GRAINED; SUB ROUNDED TO SUB ANGULAR DOMINANTLY SUB ROUNDED; WELL SORTED; SAMPLE IS 80-90% QUARTZ 10% GRAY CHERT; LESS THAN 10% LITHIC DEBRIS NO RED JASPER PRESENT; VERY SLIGHTLY CALCAREOUS; OIL INDICATIONS MASKED BY OIL BASE MUD. 13955 SAND = CLEAR TO TRANSLUCENT WHITE TO LIGHT GRAY; TRACE GREENISH GRAY; VERY FINE TO MEDIUM GRAINED UPPER; DOMINANTLY FINE TO MEDIUM GRAINED; POORLY SORTED; ANGULAR TO SUB ROUNDED; MATRIX OF ASH FALL TUFF; ESTIMATED FAIR VISIBLE POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 13995 COAL = BLACK TO GRAYISH BLACK; FIRM TO MODERATELY HARD; BRITTLE TENACITY; MODERATELY TOUGH; SPLINTERY AND TABULAR CUTTINGS; DULL TO SLIGHTLY RESINOUS LUSTER; DOMINANTLY SMOOTH TO SLIGHTLY ROUGH SURFACE TEXTURE; GRADING IN PART TO CARBONACEOUS SHALE. 14030 SAND = CLEAR TO TRANSLUCENT WHITE TO LIGHT TO MEDIUM GRAY; VERY FINE TO OCCASIONALLY COARSE GRAINS; DOMINANTLY FINE TO MEDIUM GRAINS; POORLY SORTED; ANGULAR TO SUB ROUNDED; ASH FALL TUFF MATRIX; POOR TO FAIR VISUAL POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 14070 COAL = BLACK; FIRM TO MODERATELY HARD; BRITTLE TENACITY; MODERATELY TOUGH; SMALL SPLINTERY AND TABULAR CUTTINGS; RESINOUS LUSTER; DOMINANTLY SMOOTH SURFACE TEXTURE; GRADING IN PART TO A CARBONACEOUS SHALE 50 14100 SAND/CONGLOMERATE = CLEAR TO TRANSLUCENT WHITE TO LIGHT TO MEDIUM GRAY; VERY FINE TO GRANULE FRAGMENTS; DOMINANTLY FINE TO MEDIUM GRAINED; ANGULAR TO SUB ROUNDED; POOR SORTING; FAIR TO GOOD VISUAL POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 14140 SAND/CONGLOMERATE=CLEAR TO LIGHT GRAY TO MILKY WHITE; FINE TO GRANULE SIZED CLASTS; ROUNDED TO ANGULAR DOMINANTLY SUB ROUNDED; COMPOSED OF 50% QUARTZ 40% LIGHT GRAY TO MILKY CHERT AND 10% DARK LITHIC DEBRIS; SLIGHTLY CALCAREOUS WITH A SLOW ACID REACTION; CONGLOMERATE IS GRANULE AND LARGER SIZE WITH ABUNDANT PIECES EXHIBITING BIT IMPACT GENERATED CONCHOIDAL FRACTURE AND SHARP HACKLY EDGES; INFER FAIR TO GOOD POROSITY AND PERMEABILITY; OIL SHOWS OBSCURED BY OIL BASE MUD. 14210 SAND/CONGLOMERATE = CLEAR TO MILKY LIGHT GRAY; LOWER FINE TO PEBBLE SIZE, LOWER SUB ROUNDED TO ROUNDED; POORLY SORTED; UNCONSOLIDATED WITH VERY SLOW ACID REACTION; COMPOSED OF40% QUARTZ, 50% CHERT AND 10% DARK LITHIC DEBRIS; CONGLOMERATE IS COMPOSED OF BIT SHATTERED CLASTS OF QUARTZ SHOWING FRESH SHARP EDGES, SEMI CONCHOIDAL FRACTURE AND HACKLY TEXTURE; INFERRED FAIR POROSITY AND PERMEABILITY; OIL SHOWS OBSCURED. 14265 SAND=CLEAR WHITE LIGHT GRAY; VERY FINE TO MEDIUM GRAINED DOMINANTLY FINE; SUB ANGULAR TO SUB ROUNDED, DOMINANTLY SUB ANGULAR; COMPOSED OF40% QUARTZ 50% CHERT 10% DARK LITHIC DEBRIS; SLIGHTLY CALCAREOUS; DOWNWARD DECREASE IN CONGLOMERATE FROM ABOVE; WITH TUFF; LIGHT TO MEDIUM GRAY; SAMPLE IS 100% UNCONSOLIDATED; INFER FAIR POROSITY AND PERMEABILITY; OIL INDICATORS MASKED BY OIL BASE MUD. 14320 SAND/CONGLOMERATE = CLEAR TO TRANSLUCENT WHITE TO LIGHT GRAY; CLAST SIZE RANGE VERY FINE TO GRANULE FRAGMENTS; POORLY SORTED; ANGULAR TO SUB ROUNDED; DOMINANTLY SUB ANGULAR; ASH FALL TUFF MATRIX; FAIR VISUAL POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 14360 ASH FALL TUFF = WHITE TO VERY LIGHT GRAY TO GREENISH GRAY; SOFT TO SLIGHTLY FIRM; OCCAS SMALL IRREGULAR LUMPS; OCCASIONALLY SMOOTH TEXTURE; SOME GRITTY; THIN BEDDING STRUCTURE INTERBEDDED WITH SAND. 14390 SAND/CONGLOMERATE = CLEAR TO TRANSLUCENT WHITE TO MEDIUM GRAY; CLASTS RANGE FROM VERY FINE TO GRANULE FRAGMENTS; DOMINANTLY FINE TO MEDIUM GRAINED; POORLY SORTED; ANGULAR TO SUB ROUNDED; COMMON BIT SHREADED GRAINS; SAND IS UNCONSOLIDATED IN SAMPLE; ESTIMATED FAIR VISUAL POROSITY AND PERMEABILITY; OIL INDICATORS OBSCURED BY OIL BASE MUD. 14435 ASH FALL TUFF = WHITE TO VERY LIGHT GRAY; SOFT TO OCCASIONALLY FIRM; OCCURS AS SMALL IRREGULAR LUMPS OCCASIONALLY SMOOTH TO DOMINANTLY GRITTY TEXTURE; NON CALCAREOUS; THIN BEDDED STRUCTURE INTERBEDDED WITH SAND. 14470 SAND/CONGLOMERATE = CLEAR TO LIGHT GRAY TO TRANSLUCENT WHITE; CLASTS RANGE FROM VERY FINE TO GRANULE FRAGMENTS; DOMINANTLY MEDIUM; COMMON BIT SHREADED GRAINS; OIL INDICATORS OBSCURED BY OIL BASE MUD. 14500 SAND = LIGHT GRAY OVERALL, DOMINANTLY CLEAR-LIGHT GRAY; FINE TO MEDIUM, DOMINANTLY FINE; SUB ANGULAR TO SUB ROUNDED DOMINANTLY SUB ANGULAR; COMPOSED OF 40% QUARTZ 50% CHERT 10% DARK LITHIC DEBRIS; SLIGHTLY CALCAREOUS; DOWNWARD DECREASE IN CONGLOMERATE FROM ABOVE; WITH TUFF; LIGHT TO MEDIUM GRAY; SAMPLE IS 100% UNCONSOLIDATED; INFER FAIR POROSITY AND PERMEABILITY; OIL INDICATORS MASKED BY OIL BASE MUD. 14555 SAND = LIGHT GRAY TO PALE YELLOWISH BROWN; CLAST SIZE RANGES FROM MEDIUM LOWER TO FINE LOWER OCCASIONALLY COARSE IN PART; SUB ANGULAR TO SUB ROUNDED; MODERATE SPHERICITY; CHIPPED AND PITTED GRAINS; SLIGHT TO MODERATE VOLUME OF TUFFACEOUS ASH MATRIX; DOMINANTLY GRAIN SUPPORTED WITH SECONDARY MATRIX SUPPORT; COMPOSED OF PREDOMINANTLY CHERT WITH SECONDARY QUARTZ, FAIR POROSITY AND PERMEABILITY; OIL SHOWS MASKED BY OIL BASE MUD. 14610 TUFF/ASH = PALE YELOWISH BROWN; VERY SOFT; MUSHY; COHESIVE; MODERATELY EARTHY LUSTER; ASHY TEXTURE; VERY HYDROPHILIC; OCCURS AS MATRIX MATERIAL. 14640 SAND = LIGHT GRAY; FINE TO MEDIUM GRAINED OCCASIONALLY COARSE; SUB ROUNDED TO SUB ANGULAR; POOR TO OCCASIONALLY MODERATELY SORTED; POLISHED T.O PITTED OCCASIONALLY CHIPPED GRAINS; COMPOSED OF 40% QUARTZ 50 % CHERT 10%DARK LITHIC FRAGMENTS; SLIGHTLY CALCAREOUS; GRAIN. SUPPORTED IN MATRIX OF PALE YELLOWISH BROWN TUFF; WHERE VISIBLE FAIR TO POOR POROSITY AND PERMEABILITY; OIL INDICATORS MASKED BY OIL BASE MUD. 14695 COAL = BLACK TO OCCASIONALLY GRAYISH BLACK; FIRM TO MODERATELY HARD; BRITTLE; OCCURS AS SPLINTERY AND TABULAR CUTTINGS THAT BREAK ALONG BEDDING PLANES WHEN CRUSHED; RESINOUS LUSTER. 14725 SAND = CLEAR, LIGHT GRAY, MILKY WHITE DOMINANTLY LIGHT GRAY; VERY FINE TO FINE GRAINED GRADING DOWNWARD TO VERY FINE TO MEDIUM GRAINED; ANGULAR TO SUB ROUNDED WITH MOST BEING SUB ANGULAR; MODERATE SORTING; VERY LITTLE CONGLOMERATE AT TOP GRADING DOWNWARD TO OCCASIONAL CONGLOMERATE AT 14760; COMPOSED OF 50% QUARTZ 40% CHERT 10% LITHIC DEBRIS; MATRIX OF LIGHT YELLOWISH TUFF; OIL INDICATORS MASKED BY OIL BASE MUD. 14780 CARBONACEOUS SHALE = DARK BROWN TO BLACK; FIRM TO MODERATELY HARD; BRITTLE, MODERATELY TOUGH; DULL TO OCCASIONALLY SLIGHTLY SHINY LUSTER; SMOOTH TO SLIGHTLY GRAINY TEXTURE; NON CALCAROUS; COMMON ASHY LAMINATIONS; COMMON INTERLAMINATIONS OF CARBONACEOUS MATTER AND CLAYSTONE; IRREGULAR AND BLOCKY CUTTINGS; OIL INDICATORS MASKED BY OIL BASE MUD. 14825 TUFFACEOUS CLAYSTONE = MEDIUM GRAYISH BROWN; SOFT TO FIRM; CRUMBLY TO SLIGHTLY BRITTLE; SMALL FLAKY AND BLOCKY CUTTINGS; MATTE LUSTER; SMOOTH TO SLIGHTLY GRITTY TEXTURE; NON CALCAREOUS; COMMON CARBONACEOUS LAMINATIONS AND SPECKS; SCATTERED ASHY STREAKS. 14860 TUFF / ASH = PALE YELLOWISH BROWN; VERY SOFT; VERY HYDROPHILIC; ASHY TO COLLOIDAL TEXTURE; OCCURS AS MATRIX MATERIAL OF SAND; DULL TO MODERATE EARTHY LUSTER; OCCASIONALLY THIN INTERBEDS OF TUFFACEOUS CLAY. 14890 SAND = LIGHT GRAY OCCASIONALLY PALE YELLOWISH BROWN; CLAST SIZE RANGES FROM MEDIUM UPPER TO FINE LOWER; SUB ROUNDED TO SUB ANGULAR; MODERATE SHPERICITY; INCREASING ASH CONTENT WITH DEPTH; GRAIN SUPPORTED TO BECOMING MATRIX SUPPORTED AT 14960; SILTY IN PART; COMPOSED OF 20% CHERT, 70% QUARTZ, 10% METAMORPHIC, FELDSPAR AND VARIOUS LITHIC FRAGMENTS; FAIR TO POOR ESTIMATED POROSITY AND PERMEABILITY; OIL INDICATORS MASKED BY OIL BASE MUD. RIG HOURS FORCENERGY WEST MCARTHUR RIVER WMRU ~ Z Z 0 ~ o ,.,,,, w <,:~ ~: o a. ~> ~ < z o a. "' ~ "' ' 7/25100 '13.00 6.50 1.00 " '3.50 24.00 7/26/00 12.'00 10.00 2.00 24.00 17i27,,00 14.50 9.50 ' ' ' 24.00 7/28100 '0.50 5.'504.50 ' 8.00 '5.50 24.00 . 7/29100 3.50 20.50 24.00 7~30~00 12.00 ' ' ' 12.00 24~00 , ,. 7/31/00 4.00 13.00 7.00 24.00 ~ , 8/1/00 3,00i 1.50 9,00 8.50 2.00 24.00 r .8/2/00 12.50 1.50 3.00 ..... 5.00 2.00 24.00 8/3/00 10.25 3;50 . . 8.00 2'~25, :~4.00 8/4/00 6.60 7.00 1.20 7.70 1.501 24.00 8/5/0014:50 6.50 1.00 2.00 24.00 8/6/0013.25 2.90 1.00 6.851 24.00 8/7/002.50 4~00 4.25 7.7~ 15.501 24.00 . ~ ,,,, .... 818100. 19.00 3.25 0.95! 0.801 24.00 . . 8/9/00 16~73 1~68 1.25 1.50 2.84. 24.00 8/10100 4'.17 13.00' 0.83: '' 14.'00 2.00 24.00 8/11100 i8.66 '' 4.00 · 0;50' 0.84 24100 , . . 8/12/001 6.08 5.5 8.5 3.92 24.00 ,,, . 6/13/00 3;00 t~5 15 4.5 24.00 i 8/14/00 3.00 1.50 15.00 4.50 24.00 '81151001 3.00 ' 5.50 :~50 i2;00124100 8/16/001 5.50 14;00 ' 1.00 3.50 24.00 6/17/00 13.50 ..... 9.00 i.50 '" 24.00 8/18/00 18.50 '5.50' 24.00: 6/19/00 ' " 9.00 1.23 0.50 il.77 i.50 .... 24,00 8/20/00 15.32 2.18 4100 2.50 ' 24.00 .. 8/21100 21.40 2.10 0.50 ' ' ' 24.00I 8/221001 17.50 4.75 . . 1.50 0.25 [. 24.001 8/23/00 17.50 4.75' .1.50, 0.25 24.00' 8/24/00 14.50; 8.00 1.50 24.00 .... ~ , , 8/25/00 16.00 ' 4.50' 3.50 24.00 8/26/00 16.40 2.75 1.05 3,80 ....... 24.00 8/27/00 2.1.001.90 1.10i . .. ' " " 24.00 8/28/00 18.40 3.40 1.001 2.20 25.00 8/29/00 6,33 0.67 2.75t14.25! ' 24.00 8130100 13.38 7.751 0.20 2.67 24.00 8131100 17.29 2.33 1.00 3.38 24.00 c~/1100 12.50 2.50 9.00 24.00 9/2/00 4.00 14.00 6.00 24.00 913100 2.00 10.50' 5.50 6.00 24.00 9~4~00 5.50 7.50 11.00 24.00 915100 3.00 21.00 24.00 i 9/6/00 1.50 15.00 2.50 1.50 3.50i24.00 9/7/00 4.00 3.00 14.50 1.00 1.50 24.00. 9/8/00 18.66 3.26 1.33 0.42 0.33 24.00 919100 0.50 18.75 1.50 3.25 24.00 9/10/00 14.10 3.90 6.00 24.0b 9/11/00~ 2.00 12.00 0.50 1.75 ' 2.50 5.25,1 24.00 9112/00 17.50 2.50 4.00 24.00 9113100 2.00 9.00 1.50 11.00 0.50 ' ' 24.00 9114100 1.25 8,60 1,32 11.75 1.08 2'4.00 9115100 11.50 1.75 8.25 1.00 1.50 24.00 9116100 1.50 3.672.58 15.75 0,50 ...... 24.00 9117100 0.40 18.10 1.30 2.25 0.201 1.75 24.00 iii 9118/00 1.00 0.50 7~90 12.10 1.50 1.00 24~00 Z Z 0 U,,! -- ~ I-. ' o- - o_ ~ o z = a ~ o "" ~ '"" "" ,"'"'n',, , z,-, ~ ~ · 03 I,.0 C~, r-- os ~ o=0 ~ o ~ o o ~o o ~0 o o o~ ,- o ~ o ~ ,- ~ ~ TOTAL 0 0 0 1 Hours 0 0 0 0 O~ 0 0 0 0 DEPPTH (MD) 1 3 5 7 9 ~? :EC 35 Z 4'! 45 45 fil $3 §1 6~ FORCENERGY WEST MACARTHUR RIVER WEST MACARTHUR RIVER UNIT #6 SPERRY-SUN SURVEY DATA i E/W NIS Vertical Depth Inclir~tion Azimuth TVD . Departure be,p~arture SeC (fi) (deg) (deg) (ft) (ft) (fi) (fi)' 90.00: 0.75 164.00 90.00 0.11~ -0.57 -0.33 ' '1'81100 ' '0.50 "212.00 180.99 ' 0.~'2 '1.48 -1.05 I I 267.00 0~30 273.00 266.99 -0.31 '1.78 -1.56 356.00 '0.50 ' 21.00 355.99 ' -'0.~,0 ' '-1.~,1 -1.34 · . I III 455.00 1.00 40.00 454.98 0.31 -0.34 '0.06 534.00 1.75 36.50 53~.96 "' 1.47 '~1.16 1.83 622.00 2'.50 48.50 6~1.90 3.71 ' '3'.51 '5.07 · 711.00 4.50 50.50 710.73 '~.85' 7.01 '10.42 800.00 7.25 41.50 799.25 ' ~4,27 13.44 19.47 889.00 ' 8.50 3'/.~0 887.41 22.00" 22,87 31.66 ' "9~8.0'0 ' '8.$0 ' '4~.50 975.44 30.61 32.78 44~79 1067.00 10.00 44.00 1'06~.28 ' 40.59 43,03 ~9.06 11'56.00 12,25 4~t.50 1 ~ 50.60 52.58 55.32 76~ 18 . 1229.00 12.58 46.84 1221.89 63.81 66.29 91.80 . 26~..~t .... 1275.00 13.16 ~,9.60 1 . 71.45 73,11 101.94 1369.00 14.56 49,29 '1:~57'.99 88.56 8i.75 ' 124.16 1465.00 17.10 44.26 1450.35 lb7.57' 105.74 ~50.16 1558.00 20.85 42.86 1538.28 '~28.38 127.'68 ~'80,34 1652.~0 22.95 " 44.47 1625.~t9 ~152.60 '' 153.02 '215.33 1744.00 '23.96 4'5.94 1709.89 178.59 178.81 251.80 1833.00 25.32 46.34 1790.78 205.:~4 204~".'5~ 288.70 1930.00 '25.77 46.7~ 1878.30 235.71 233.29 33b':28 2024.00 28.43 47.20 1961.97 267.0; ' 262.49 372.76 2117,00 ' 3'0.84 46.87 ' 2042.80 300.67 '293.83 418;40 '2210.00~ 33.7~ ' 45.01 2121.41 336.35 328.40 ~467.8~ 2305.00 37.29 43.80 2198.72 374'.9~4 '367.85 522.85 2397.00 40.01 43,59 2270.56 '~,14.63 409.39 580,20 2489.00 41.73 '44.87 23~t0.13 456.63 452151 640.23 2582.00 '44.89 46.72 2407.79 50~'.:~7 496.96 703.69 '2674.00 ' 48.00' 47.98 2471.18 551.41 " 54~i'12 '769.82 2767.00 50.49 47.37 2531.89 6o:~'.48 589.58 839.64 2860.00 53.28 46.79 2589,29 657.05'639.39 912.25 2955.00 56.48 47.07 2643.93 713.81 '692.4~4 989~39 3049.00 58.49 46.60' "2694.46 771.61 '~46.67 1068'.1o 3144.oo '58.78 " ~t6.15 2743.91 ' 830'.33 802.64 1'148~73 · , I I Forcenergy, Inc. W. McArthur River Unit # 6 3239.00 58.30 45.54 2793.49 888.46 859.09 1229.35 3330.00 58.60 45.76 2841.11 943.91 913.30 1306.53 3426.74 58.16 45.08 2891.83 1002.59 971.12 1388.55 3518.74 58.27 45.98 2940.28 1058.40 1025.90 1466.40 , 3612.26 58.78 45.42 2989.11 1115.48 1081.61 1545.77 3707.41 58.76 46.53 3038.45 1173.98 1138.15 1626.70 3803.02 58.83 46.93 3087.99 1233.53 1194.20 1707.92 3897.06 57.33 4'~.09 3137.72 1291.91 1248.62 1787.15 3989.71 56~79 46.67 3188.10 1348.66 1301.77 1864.36 4085.72 56.72 46.47 3240.74 1406.97 1356.98 1944.14 41~8.51 56.60 45.98 3291.73 1462.94 1410.61 2021.21 4271.89 56.73 45.44 3343.05 151~.78 1465.09 2098.84: 4367.43 54.85 ' ~45.35 3396.76 '1575.d3 1520.56 2177.51 4460.27 51.97 46.03 3452.10 1628.36 1572.641 2251.69 4550.41 52.17 46.51 3507.51 1679.~4 1621.78 2322.37 4643.41 ' 5~.2~ 46.2'1 '3563.2b 1733.63 1673.18 2396.39 4738.47 54.10 45.90 3618.85 1789.12 1726.67 -2473'.05 '4832.13 53.63 46.03 3674.08 1843.50' 1779.25 2548.29 I 4924.38 54.25 45.07 3728.38 1896.73 1831.47 2622.52 '5020.84 54.33 44.74 3784.69 1952.~2 1886.94 2700.56 5114,57 54.77. 44.85 3839'.05'2005.82 1941.12 2776.65 5206,15 55.27 45.17' 3891.56' 2058.89 1994.17 2851.41 5302.23 ' 56.02 44.81 ~945.78 2114.97 2050.26 2930.44 539~t.08 56.97 '44,43 3996.48 2168.76 210~.78 3006.78 '5489.:~2 58.~,0 44.25 4047.39 2225.01 216'2.35 3087.05 5581.61 58.22 43.59 4095.87 2279.49 2218.91 3165.40 I 5677.42 58.74 43.15 4145.96 2335.57 2278.28 3246.94 5767.97 58.82 43.30 4192.90 '2388'.~1 2334.'70 3324.'~5 5864.47 59.:~4 43.21 ' 4242.49 '2445'.34 2394.99 3406'.'91 I I II II 5955.97 58.19 44.47 4289.94 2499.52 2451.43 3484,97 . 6051.52 57.12 45.50 4341.06 2556.57 ' '2~08'.53 3565.40 '6141.45 ' 57~4 44.99 4389.67 2610.~0 2561.80 3640.75 I I I I I 6233.98 57.18 45.88 4439.64 2665.78 2616.44 3718.28 632?.47 5~5.5~ I,, 46.79 4491.45 2722.07 2670.17 3795~63 64'18.01 '5'5.84 4Y.46 45~2.49 '~7~6.88 '2721.05 3869.85 6510.13 56104 47.26 4594.08 2833.02 2772.75 '3945.55 6604.75 55.23 ~45,3~ '4647.49 2889.48 :2826.71 4023.19 6697.00 55.25 ' 45.24 4700.08 29J,3,34 '2880.03 4098.67 6794',95 54,47 45.32 '4756.~6 3000.26 2936.39 4178.~4'3 6889.7~, '54.79 ' 45.38 ~811.33 3055.25 2990.71 4255.40 6985149 53.91 ' 46.'89 4867.14 3'111.~4 3044.62 4332~6 '~07~.29' '~.,~ 46,09 '4919.0~ 3163.59 3094.22 4J,04.36 7167.57 54.76 ~6.07 4973.02 3218.39 3147.00 4480.02 726~1.90 55.27 46.02 5027.10 3274.03 3200.65 4556.89 I 7358.99 55.24 45.30 5082.43 3331.09 3256.41 4636~29 7428.51 54.96 45,80 5122.20 ' 3:~7'~.79 3296.34 4693.05 7477.45 54.63 45.62 5150'.42 3400.~1 3324.26 4732.84 I 7572.25 56.43 45.53 5204.07 3456.22 3378.97 4810,63 7661.09 56.49 45.85 5253.16'3509.21 :~t30.69 4884.33 I I I II I Forcenergy, Inc. W. McArthur River Unit # 6 I 7750.45 56.36 45.91 5302.58 3562.65 3482.53 4958.39 7~51.53 '56.49 45.73 5358.48 3623.05 3541.22 5042.19 7943.17 {~6.79 45.93 5408.87 3677.9~i 3594.55 5118.34 8033.58 57.03 45.67 5458.23 3732.25 3647.36. 5193.71 I 8128.18 57.19 45.45 5509.60 3788.96 3702.98 5272.78 I I 8219.20 57.27 45.531 5558.87 3843.54i 3756.64 5348.97 I 8315.38 57.31 45.75 5610.84 3901.41 3813.22 5429.52 8406.47 57.45 45.75 5659.94 3956.36 3866.75 5505.86 8503.92 57.28 45.94 5712.50 4015.24 3923.91 5587.51 8596.69 57.16 45.90 5762.7~3 4071.27 3978.17 5665.10 8690.13 56.95 46.23 5813.55 4127.73 ~032.58 5743.09 I III 8784.79 56.69. 46.53 5865.35 4185.09 4087.24 5821.83 8876.68 56.65 46.5~ ~915.85 4240.79 4140.b7 5898.12 i 8971.02 56,45 46.49 5967.85 4297.89 4194.25 5976.34 9064.99 56.41 46.61 6019.81 4354.'73 4248.10 6054.13 9154.90 56.36 46~07 6069.59 4408.8{t 4299.79 6128.56 '9219.47 56.36'46.41 6105.36 ~1447.72 4~36.96 6182.00 9261.75 56.?5 ' 46.55 6128.66 4473.3b '4361.26 6217.06 9354.81 56.36 46.26 6179.98 4529.54 4414.80 6294.23 {)446.27 ~.09 46,34 6230.80 4584.50 4467.32 6369.81 '9538.43 56.46 46.34 628'i.97 4639".96 4520.2~ 6446.d0 9630.75 56.1'4 46.56 6333.20 '4695.62 4573.15 6522.33 9722.86 56.49 46.09 6384.29 4751.06 4626.0E~ 6598.~1 9810~6~ '56.11 '44.53 6433.01 ;t802.99 4677.45 667~.25 9910.96 56,14 44.22 6488.91 "4861.22 4736.97 6754.28 10004.83 56.11 44.23 6541.24 4915.58 4792.82 6832.02 10099.55 55.76 44.55 6594.29 4970.47 ~,848'.'8'9 6910.26 10194.12 56.05 43.97 6647.30 '50:25.12 4904.98 6981~'.37 10284.97 56.10 ' 43.36 669~.00 50Y7'.17 4959~52 7063.6~3 10379.30 56.30 43.13 6750.48 5130.'~7 $016.62 7141'.8~ 10473.65 55.97 43.51 6803.05 51t~t.62 507:~.62 ?220.09 10568.64 '56143 4:~187 6855.89 5239,15 5130.69 7298.87~ 10661.19 56.36 '43~91 690¥.12 5292.59 5186.2~5 7375.78 · I I I .I I i 10757,81 56.33 43.83 6960.66 5348.33 5244.22 7456.03 10854~23 56.68 43.90 '7t~;1"3.'871 '~' 5404,05 5302.20 7536.26 109;t0.29 57.01 '~3.47 70~0.§~ 5453.81 '5354.30 7608.17 11034.43 54.93 44.94 7113.62' ' ~5'508'.1954i0.23 7685.97 1112'8.48 ' 53.33 45.66 7168.73 ' '5562.3~ 5463.84 7761.87 11223.83 53.02 45.68 7225.88' 5616.96 5517.17 7837.83 11316.18 52.:~2 45.81! '728~.88 5669~55 5568.41 ' 7910.90 11413.57 51.70 45.55! 7341.83 5724.47 5622.04 7987.28 11505,04 52.45 45.60 7398105 5776.00 5672.53 8059.10 11597.27 " 53.49 45.81~ 7453.60 5828.?0 5723.95 81~32~3Y I . 11690.51 53.58 46.26. 7509.01 5882.67 5776.00 8206.95 11786.02 ~)4.18 '46.24. 7565.31 5938.40'5829.35 1~28~.65 11878.7'2 ' 55.83 45.52 '7618.47 5992.'91 ' 588z22 8:~59.20 11972.65 55.23 45.00 7671.64 6047.921 5936.'73 8~t36.:~2 '12065.45 5~.$7 44,41 7725.00 6101.~3 ~990.69 8511.99 12161.37 " 53.54 42,9~i 'Y781.30 6154.96 6{)46.85 '8589.49 I I I II I II I I Forcenergy, Inc. W. McArthur River Unit # 6 12252.98 51.74 41.66 7836.88 6203.98 6100.69 8662.25 12344.36 50.48 40.25 7894.25 6250.60 6154.40 8733.36 12438.81 49.91 38.30 7954.72 6296.54 6210.56 8805~91 12531.31 47.47 33.92 8015.79 6337.51 6~66.64 887~5.20 12623.46 45.06 27.42 8079.53 6371.50 6323.80 8940.82 12714.56 43.62 22.31 8144.70 6398.29 6381.51 9002.23 128~11.71 42.32 16.43 8215.81 6420.27 6~143.91 9064.14! 12905.81 ' 41.76 1'0.65 8285.72 6435.03 ~505.12 9120.47 12999.52 41'.48 6.22 8355.~9 6444.161 6566.65: 9173.44 1:~)93.31 40.17 2.97 6426.77 6449.09 6627175 '9223.37 13145.74 39,56 ' ' 1.1~ 8467.02 6450.29 6661.33' 9249.64 13186.35 39.66 359.52 6498.30 6450.43 6687.22 9269.75 13255.08 ' 39.71 3~54.12 t~551.2'1 '6448.00 '6731.01 '~301.69 13373.86' 39.13 350.06' 8642.98 6437.64 '6805.68 {)352.16 iii 13469.11 38.76 349.77 8717.06 6427.15 6864.63 9390.53 '13559.52 35.82 348.33 8788.98 6416.77 6'91~,41''9424.99 13627.25 34.81 348.67'8844.25 "6408.97 6956.77' 9449.33 13664.~30 ~3:~.83 3~48.94 8874~.85'6404.91 6977.26' 9462.40 ~13757.77 3~.29 '~48.68 89~2.74 6394.88 Y027.95 9494.73 13850'.73 32.03 '" 349.17 903~.00 6385.24 7077.18 9526.20 1':~917.27 31.43 34~.~2 " 9087.59 '6378.48 711'~.51 9548.12 13943.60 31.49 349.50 9110.06 6375.86 7125.00 9556.75 14033.85 " 30.~2 '350.72 9187.25 6367'.82 7171.06 '~586.83 · . 14080.32 31.09 350.18 9227.08 6363.85 7194.67 9602,33 14124.8~t 30.70 350.92 '§265,28 6360.10 7217.21 9617.17 '~4173.'92 31.b5 351.47 9307141 6356.'24 ~242.10 9633.74 1'~t21'5.72 ' 31.40 35'~.68 '9343.15 6353.06 '7263.54 9648.10 1~t307.40 ' 33'.1~ ' 351.89 9420.66 6346,07 7312.00 9680.68 14406.29 ' '3?.13 '350.65 9501'.50 6;~37.40 7368.26 {)718.15 14467.0;4 39.64 349.57 9549.12 6330.91 '7405.41'9742.41 I I 14500.47 38.71 351.80 9575.03 6327.49 7426,25 9756.15 14~89.89 35.13 '' 355.29 9646.51 6321.39 ' 7479.59 9793.04 14685.53 34.87 356,51 9724.86'6317.46 7534.31 9'8:~2.:~9 14776.90 35.06 357.37 9799.74 6314;67'7586.59 9870.60 '~48~1.93 34.79 0.31 9877.66'6313.56 7640.97 9911.50 14908.10 ' 34.9~4 0.39 9907.3~ 6313.69 766~.·65 9927'.41 14962.00 34;94 0.39 9951.52 6313.89 '7692.52 9951.16 II II I Forcenergy, Inc. W. McArthur River Unit # 6 MEMORANDUM TO: Dan Seamount Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 2, 2000 THRU: Blair Wondzell P.I. Supervisor FROM: Chuck Schev~e Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 160 Force Energy WMRU #6 200-107 WMRU Operator Rep.: Mike Murray Contractor Rep.: Al Lunda Op. phone: 776-5580 Op. E-Mail: Rig phone: Rig E-Mail: Test Pressures MISC. Location Gen.: Housekeeping: PTD On Location Standing Order: Rams: 250~3000 INSPECTIONS: PIF P/F P Sign: P P Rig cond: P P Hazard:..P ....p . . Annular: 250/2500 Choke: 250~5000 TEST DATA FLOOR VALVES: MUD SYSTEM: Quantity PIF Trip Tank Upper Kelly 1 P Pit Level Indicators Lower Kelly 1 P Flow Indicator Ball Type I P Meth Gas Detector Inside BOP 1 P H2S Gas Detector BOP STACK: Visual Alarm .P P P P P P p .,.....'.p p :~p Quantity Size PIF ACCUMULATOR SYSTEM: Annular Preventer 1 13 518 P CHOKE MANIFOLD: Time/Psi PIF Pipe Rams 1 13 518 P Quantity PIF System Pressure 3000 P Lower Pipe Rams 1 13 518 P No. Valves 13 PIF After Closure 1500 P Blind Rams 1 13 518 P Man. Chokes 2 P 200 psi Attained 30 sec P Choke Ln. Valves 1 4" P Hyd. Chokes 1 P Full Pressure 3 min P HCR Valves I 4" P Blind Covers (All Stations): P Kill Line Valves 2 3" P N2 Bottles (avg): 4~ 2200 Check Valve NIA '~ Test's Details I arrived on location and found the rig tripping out of the hole for logs. Upon completion of the logging nm the BOP testing process began. After some difficulty retrieving the wear bushing the testing went well with all BOP components functioning correctly and holding their pressure tests with the exception of one valve on the choke manifold. The first valve upstream of the hyd choke failed to pressure test. This valve is to be repaired after cementing the liner on this well. Total Test Time: 4' Number'0f'f~iiiures: ~_ cc.' Attatchments: None Vvcs8eah.xls 9/5/00 Re: WEST MCARTHUR RIVER UNIT #6 Subject: Re: WEST MCARTHUR RIVER UNIT #6 Date: Fri, 25 Aug 2000 17:17:05 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Rob Stinson <RStinson@forcenergy. net> Rob, Thanks for the information. Having all the potential 33nes covered by your liner should improve the opportunity to complete any or all of them without having to incorporate a larger packer or consider a workover. Good luck. Tom Maunder Rob Stinson wrote: > Tom, > Forcenergy has decided to change the 7 5/8" drilling liner casing point to 13, 400' MD. This locates the G-zone behind the same liner as the Hemlock. There are no potential engineering or operational problems associated with this change. In addition, due to the fact that we will have all of our zones of interest in the next hole section (6 3/4"), we are not planning on running anything other than an oil based dipmeter, tool in the 8 1/2" hole ~ection. Please call me at 868-2133 if you have any questions. > > Rob Sties Tom Maunder <tom maunder~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 8/28/00 7:59 AM NOTE TO FILES 200-107 AND 200-088 SPACING EXEMPTION WEST MACARTHUR RIVER UNIT #3R° AND #6 On June 22, 2000, AOGCC approved the application for the permit to drill for the West MeArthur River Unit (WMRU) #3RD oil well. That approval included a statement that the "Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Foreenergy, Inc. will assume the liability of any protest to the spacing exception that may occur." A spacing exception was required because the proposed target of 600'FNL, 2420 FWL, Sec. 10, T8N, R14W, SM lies 950 feet from the producing zone in the WMRU #5 well, a violation of 20 ACC 25.055 (a)(3) which specifies a 1,000 foot-limit. On June 16, 2000, Foreenergy notifies the DNR that an application would be submitted for the WMRU #3RD. On June 20,2000, Forcenergy submitted to AOGCC the documentation for a spacing exception. On June 29,2000, A notice of Public Hearing was published in the Anchorage Daily News. On July 13, 2000, Blair Wondzell and Tom Maunder of AOGCC was informed that Forcenergy discovered that casing had collapsed in the WMRU #3 well, and that it was unusable to drill a sidetrack well to the proposed bottom hole location for WMRU #3RD. July 14, 2000, Forcenergy submitted a permit to drill application for WMRU #6, a new well to be drilled to the same proposed target and bottom hole location as originally proposed for the WMRU #3RD. On July 21, 2000, AOGCC approved the application for the permit to drill for the WMRU #6 well, which also included the contingency statement that "Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Forcenergy, Inc. will assume the liability of any protest to the spacing exception that may occur." August 1, 2000, AOGCC received an application for exemption for the provisions of 20 ACC 25.055, Drilling Units and Well Spacing, West MeArthur River Unit #6. Because the intent of Foreenergy remains the same, to drill the same target and bottom hole location in WMRU #6 as originally proposed for WMRU #3RD, and because correlative rights are not jeopardized, all supporting documentation originally submitted for the WMRU #3RD is carried over, and adequate to support the spacing exemption application for the WMRU #6 well. Re: WMRU #6 Formation Integrity Test - - PERMIT TO DRILL 200-107 Subject: Re: WMRU #6 Formation Integrity Test- - PERMIT TO DRILL 200-107 Date: Tue, 01 Aug 2000 15:54:18-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Paul White <PWhite~forcenergy.net> Paul, No problem with the calls to my home. Hope everything continues to go well. Thanks for the update. Blair Paul White wrote: > ** High Priority ** > > Blair, Following up our conversation regarding FIT on 13 3/8" surface casing we drilled out of sand into a clay zone at 1975'. There we mixed LCM and spotted it on bottom. We re-tested formation integrity, (shoe bond) the leak off was much slower and we went to a maximum of 450 psi at surface which equates to 13.7 ppg with 9.2 ppg mud in hole. (TVD at shoe 1925') The leak off was constant. The formation below the shoe is sand and there are no good shales immediatly below the shoe. Because of the excellent cement returns and good circulation of cement on surface we believe that fluid is leaking off in sand section and additional drill solids will heal the leakoff. If you have any questions or comments please give me a call. > > I apologize for calling you at such odd hours at home and I appreciate your assistance. > > Regards, > Paul White 1 of 1 8/1/00 3:54 PM ALASKA OIL AND GAS Paul White CONSERVATION COPl~ISSION Forcenergy, Inc. 310 K Street, Suite 700 Anchorage, AK 99501 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ West McArthur River Unit No. 6 Forcenergy, Inc. Permit No: 200-107 Sur Loc: 2395'FNL, 1337'FWL, Sec. 16, T08N, R14W, SM Btmhole Loc. 180'FNL, 2375'FWL, Sec. 10, T08N, R14W, SM Dear Mr. White: Enclosed is the approved application for permit to drill the above referenced well. 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. Forcenergy will assume the liability of any protest to the spacing exception that may occur. Annular disposal of drilling wastes from this drilling operation have not been approved. If a Class II disposal well becomes unavailable, and a request for annular disposal is necessary, a complete request must be submitted with an Application for Sundry Approval (Form 10-403) and all of the .necessary information required by 20 AAC 25.080. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION ,DATED this ~' ! $'~ day of July, 2000 dlffEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Forcenergy Inc July 13, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Application for Permit to Drill (Form 10-401) West McArthur River Unit//6 Enclosed is the Application for Permit to Drill West McArthur Rive~ Unit//6, in the West McArthur River Field. A waiver is being requested to drill the surface 17 a~" hole without a diverter and to eliminate the surface and intermediate log runs in this developed field. This well is planned as a Hemlock producer in the WMRU//5 fault block. The targets and wellpath through the proposed production zones are identical to the information supplied in the WMRU //3Rt~ Application for Permit to Drill. Due to the problems encountered in de-completing WMRU//3ST, we now plan to reach these targets with this grassroots well. We have not altered the targets in order to allow the Application for Spacing Exception to WMRU//3RD to be transferred to this new wellbore. If there are any questions, please contact me at 258-8600. Paul White Drilling Manager Forcenergy Inc. RECEIVED llJI. 14 2000 Alaska 0il & Gas Cons. Commission .Anchorage HEADQUARTERS Forcenergy Center 2730 SW 3rd Avenue Suite 800 Miami, Florida 33129-2237 TELEPHONE 305/856-8500 FAX 305/856-4300 REGIONAL OFFICE 310 K Street Suite 700 Anchorage, Alaska 99501 TELEPHONE 907/258-8600 FAX 907/258-8601 STATE OF ALASKA A'ASKA PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: X Redrill: I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: x Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Forcenergy Inc. 163' KB feet West McArthur River Field 3. Address 310 K Street. Suite 700 6. Property Designation West McArthur River Pool Anchorage, Alaska 99501 ADL-359111 4. Location of well at surface / /~. ~'D 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2395' FNL, 1337' FWL, Sec,,,1,0, T08N, R14W, SM West McArthur River Unit At top of productive interval 8. Well number Number Statewide #RLB0001940 600' FNL, 2420' FWL, Sec 10, T8N, R14W, SM West McArthur River Unit #6 At total depth 9. Approximate spud date Amount $200,000 180' FNL, 2375' FWL, S10, T08N, R14W, SM 20-Jul-00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) :)roperty line 2815 feet 950 feet 4,175 14,685' MD / 9,763' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 400' feet Maximum hole angle: 56 Maximum surface 3271 psig At total depth (TVD) 4394 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 20" 129# X-56 N/A 120' 0 0 120' 120' n/a 17 1/2" 13 3/8" 68# L-80 BTC 1,900' 0 0 1,900' 1,845' 2406 cu. Ft. 12 1/4" 9 5/8" 47# L-80 BTC 7,500' 0 0 7,500' 5,128' 644 cu. Ft. 8 1/2" 7 5/8" 29# L-80 Hyd 521 6,537' 7,300' 5,015' 13,837' 9,033' 191 cu. Ft. 6 3/4" 5 1/2" 17# L-80 Hyd 521 1,048' 13,637' 8,872' 14,685' 9,763' 140 cu. Ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth StructuralRECEIVED Conductor ' Surface Ipnrt°erdum:id~ante0 R IGINAL 000 Liner Alarm Oil & Gas Cats. Coam~ Perforation depth: measured Anchorage true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: X Drillin~ program: X Time vs. depth plot: Refraction analysis: Seabed report: 20'AAC 25.050 requirements: X 21. I herby c~rti~at the foregoing is true and correct to the best of my knowledge: Signed: ~ ~,~_,,~N~,v',,~.-..--,~- Paul White Title: Drilling Manager Date: Commission Use Only Permit Number I API number d..~)I Approval_date_. I See cover letter .2.~-- jr O'~ . 50- J ~.~'~"' ,~2,~ ~ ,'~ ~'~Z, jr ..- ~) ~ for other requirements Conditions of approval Samples required: [ ] Yes ~VNo Mud Icg required: [ ] Yes [~ No Hydrogen sulfide measures [ ] Yes ~No Directional survey required ~].Yes [ ] No Required working pressure for BOPE []2M; []3M; [X]5M; []10M; []15M Other: Approved by ...... ,.nf Commissioner the Commission Date: ,. D ~..aylor S~a,'¢~' Form 10-401 Rev. 12-1-85 Submit in triplicate WMcr #6 Casing Test Pressures Subject: WMcr #6 Casing Test Pressures Date: Tue, 18 Jul 2000 15:38:40 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Rob Stinson <rstinson@forcenergy. net> 1 of 2 Rob, This is further to our latest conversation. I have spoken to Blair and we will be looking more closely at this issue in the morning. Below are what I have determined with regard to the subject. The comments are based on the text copy I presently have and the 2 emails as applicable. In the procedure, all casing/liner lap tests are planned to 2000 psi with the exception of the 5-1/2" liner which calls for a 3000 psi test. This last test will subject the 9-5/8", 7-5/8" and 5-1/2" to 3000 p~i. It would seem prudent to initially test each string to the maximum that it will ultimately be tested to. I have also calculated the required surface pressures necessary to achieve the FIT values you specify. The required pressures based on the minimum section mud weights are: 13-3/8"--12.5 EIVIVV on 9.0 ppg at 1845' 'rVD requires 335 psi 9-5/8"---14.5 EIVI~/on 9.0 ppg at 5128' 'rVD requires 1466 psi 7-5/8"---14.5 EMVV on 9.0 ppg at 8835' 'rVD requires 2526 psi It seems a certainty that the 9-5/8" and 7-5/8" s~rings will be subjected to higher pressures than you plan to test to. I have also looked at the MASP calculated for each string. These are: 13-3/8" 1717 psi 9-5/8" 3026 psi 7-5/8" 3271 psi Again, there is a potential, much less likely than the LOT/FIT case, to subject the 9-5/8" and 7-5/8" s~rings to higher pressures than you plan to test to. >From our discussion I also understand that the tubing conveyed guns will be fired by pressuring up on the 9-5/8", 7-5/8" and 5-1/2" (asing/liners (annulus pressure fire) on top of a crude column. This is another case which could result in an ultimate EMW in excess of any pressure test you have planned. Please have a look at these issues. As I indicated Blair and I will be looking more closely at this in the morning. Thanks for your attention to this. If you'd like to discuss, please call. Tom Tom Maunder <tom maunder~admin.state.ak, us> j P-~rol~eer Alaska Oil and Gas Conservation Commission 7/1 3:40 PM 8/00 .~ -.Revised outline summary Subject: WMRU #6 - Revised outline summary Date: Thu, 20 Jul 2000 16:35:31 -0500 From: "Rob Stinson" <RStinson@forcenergy. net> To: tom_maunder@admin.state.ak, us CC: PWhite@forcenergy. net, wmru@gci.net Tom, The attached word file is the revised outline summary for WMRU #6. This indicates the changes in the Leak off Tests and Casing Pressure tests. Please call if you have any furthur questions. Rob Stim~ i~: , ! ........ Name: New Outline WMRU #6.doc ..................................... 1 ~New Outline WMRU #6,doci Type: unspecified type (application/octet-stream)! l..E. ncoding: base64 J 1 of 1 7/20/00 3:12 PM West McArthur River Unit #6 Casing Design 20" 129~, X-56 13 3/8" 68~, L-80 B _ 9 518" 47#, L-80 B 7-5/8" 29~, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 I~120' MD, 120' TVD IBil @1900' MD, 1845' T VD 7500' MD, 5120' TVD OO~:~ID ~,~.", c.q-e-,,o~%~ 13,600' MD, 8835' T VD. %bc~<, ~..~-.c,,.,.~\ ,JUL 14 200(:} '""-'" Alaska 0ii & Gas Cons. Commission ~ O O~b Anchor~e 14,685' MD, 9,763' TVD WEST MCARTHUR RIVER UNIT #6 OUTLINE PROCEDURE 1. Move Rig, Rig Up Nabors Rig 160 2. Drive 20" conductor to 120'. 3. Rig flow line, Pick up BHA, Spud Well. 4. Clean out conductor and drill to 400' Kick Off Point. 5. Directionally drill 17 '/2" hole to 1,900' MD / 1,845' TVD. 6. Run 13 3/8" casing to 1,900', cement to surface. 7. Install wellhead, Nipple up and Test 13 5/8" 5m BOP stack and equipment 8. Pick up 12 ¼" BHA, Run in hole. Test easing to 2000 psi. 9. Clean out casing and drill 20' of new hole. Perform Formation Integrity Test to 12.5 ppg EMW. 10. Directionally drill 12 ¼" hole to 7,500' MD / 5,128' TVD. 11. Run and cement 9 5/8" casing, r,/~.,,,~,...k -,.~ ~>~,e,~.~°;3 .~.e~ be- ~,a~ $~..~ 12. Nipple down BOPE. Install casing slips and packoff. 13. Nipple up and Test 13 5/8" 5m BOP stack and equipment. ~o ~ooC~ ~,q,. .14. Pick up 8 1/2" BI-IA, Run in hole. Test casing to 2000 psi. 15. Clean om casing and change over to Oil Based Mud. 16. Drill 20' of new hole. Perform Formation Imegrity. Test to. 14.5 ppg EMW. test. 17. Directionally drill 8 ½" hole to 13,837' MD / 9,033' TVD. 18. Run intermediate log suite. 19. ConditiOn hole, Run and cement 7 5/8' liner from 7,300' MD to 13,837' MD. 20. Test 13 5/8" 5m BOP stack and equipment. ~ u~oc~f3 ~',. 21. Pick up tapered drill string / BHA and nm in hole. 22. Clean om liner and test lap to 2000 psi. 23. Clean out shoe track, drill 20' of new formation'and Perform Formation Integrity r~k". Test to 14.5 pPg EMW. 25'. Directionally drill 6 ~A" hole to TD at 14,865'MD / 9,763' TVD. 26. Condition hole and nm log suite as follows: Triple combo, FMI, OBDT and Check Shot (be prepared to mn drill pipe conveyed logs) 27. Condition'hole for liner. 28. Run and cement 5 ½" liner from 13,637' to 14,865'. 29. Clean out liner and test lap to 3000 psi. 30. Run Cement Bond logs 31. Run TUbing Conveyed Performing guns and Production packer on drill pipe. 32. Stab 2 7/8" completion into liner hanger polished bore.-~" ~'~ ~"~\'-~ '33. Nipple down BOPE and Nipple up Production tree. 34. Swap well over to crude, fire guns and.bring well online. ,JUL 1 4 000 .~,, · oas Cons. Commission Anchorage WEST MCARTHUR RIVER UNIT//6 DRILLING FLUID PROGRAM Interval Hole size = Casing Size = Mud type = 0' - 1,900' 171/2" 13 3/8" Fresh Water Bentonite Drilling Fluid Parameters: JUL 1 4 2000 Weight: 8.8 - 9.0 ppg PV: 5- 10 cps YP: 15-25 lb/100ft2 API Fluid Loss: n/c - 12cc HPHT Fluid Loss n/a' AlaSKa U, ~, Gas Cons. Commission Anchorage This interval may be drilled with a mud system built with fresh water, bentonite, polymer extender, barite, soda ash and caustic. . With an estimated 32 degree angle at casing point, cuttings beds should not be a problem. A polymer may be added to the mud system for fluid loss control just prior to running the casing. Interval 1,900' - 7,500' Hole size: 12 ~A" Casing Size = 9 5/8" Mud type = PHPA Polymer Drilling Fluid Parameters: Weight: 9.0- 9.2 ppg PV:. 10- 12 cps YP: 12-25 lb/100ft2 API Fluid Loss: 4 - 6cc HPHT Fluid Loss n/a Use the existing surface system for this interval. Treat and condition for cement contamination with Bicarb. Build additional volume as required. After treating for cement contamination, add bentonite, PHPA, and Resinex for viscosity: inhibition, and fluid loss. Potential problems that exist .include, hole cleaning, tight hole, gas kicks, bit balling, and sloughing coal. In addition to the above, products, add Flovis, Soltex, and a lubricant for hole cleaning, hole stability and reduction of torque and drag as needed. Interval Hole size -- Casing Size = Mud type = 7,500' - 14,685' 8~h' 7 5/8' and 5 1/2' Flush Joint Invert Oil Base Drilling Fluid Parameters: Weight: 9.0- 9.2 ppg PV: 15- 18 cps YP: 10-30 lb/100f-t2 API Fluid Loss: n/a HPHT Fluid Loss < 8 ce Oil / Water Ratio 80/20 This interval will be drilled with a diesel based invert oil mud. After running 9 5/8" casing, circulate and condition hole, reducing surface volume of water .based mud. ' After eememing, drop top cemem plug and 'displace cemem with oil based mud. Clean active mud 'and fill with oil based mud. Condition oil based mud while drilling cement, float collar, and shoe. Oil based mud's viscosity and properties will stabilize as fluid temperatures increase. Utilize all solids control equipment.. Maintain low shear rate viscosity to ensure good hole cleaning. JUL 14 tooo Alaska Oil & Gas Cons. Commission Anchorage WEST MCARTHUR RIVER UNIT #6 PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the West McArthur River Unit g5. The pore pressure gradient information was obtained from the original bottom hole pressure surveys and RFT surveys on West McArthur River Unit gl,g2A and g3. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit g 1, g2A and g3. WMRU g2A, P= 4304 psi 9567' TVD from DST (as per 407 Comp Report, Il/93) WMRU gl, P= 4362 psi @ 9724' TVD from RFT (as per 407 Comp Report, 2/92) WMRU g3, P = 3680 psi @ 9400 from. static. BHP survey 7/2/95 The most conservative (highes0 formation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point and a gas. gradient to the surface. 1) ASP = ((FG x .052) - 0.115) x D ' where: ASP = Anticipated Surface Pressure in .psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.115 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR 2) ASP= where: FPP-(0.115' x D) FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) dUL 14 000 ~a,~a co..il ~ Ga~ Cons. Commission Anchorage ASP Calculations Drilling below Surface Casing (13 3/8") ASP OR = ((FG x .052)- 0.115) x D = ((12.5 x .052) - 0.115) x 5128' = 2743 psi ASP = (5128' x .45)- (.115 x 5128') = 1717 psi Drilling below Intermediate Casing (9 5/8") ASP OR = ((FG x .052)- 0.115) x D = ((14.5 x .052) - 0.115) x 9033' = 5772 psi ASP = (9033' x .45)-(.115 x 9033') = 3026 psi. Drilling below Drilling Liner (7-5/8") ASP OR =.((FG x .052)-0.115) x D = ((14.5 x .052) - 0.115) x 9763' = 6239 psi ASP = (9763' x .45) - (.115 x 9763') = 3271 psi RECEIVED ,JUL 4 2000 AI~,~, u, ~ Gas Cons. Commission Anchorage Re:'[F~vd?WMRU #6] Subject: Re: [Fwd: WMRU #6] Date: Tue, 18 Jul 2000 16:45:28 -0500 From: "Rob Stinson" <RStinson@forcenergy. net> To: tom_maunder@admin.state.ak, us CC: PWhite@forcenergy. net Tom, I am currently writing up the Hazards page and it will follow this e-mail. In reference to your other questions: High Pressure Sand - We intend on increasing our mud weight from 9.2 to 10.8 ppg at approximately 4870' MD (3700' TVD), which is 200'+ TVD above the highest known overpressure depth. Once the 9 5/8" casing is cemented in place, we will drill out with 9.2 ppg oil based mud. In reference to the change in casing design, our safety factor on the 9 5/8" ~ollapse goes from a 2.8 as listed in the 10-401 to a 2.1. This is based of full casing evacuation. 1 of 1 7/18/00 2:22 PM WMRU #6., Subject: WMRU #6 Date: Mon, 17 Jul 2000 18:43:32 -0500 From: "Paul White" <PWhite@forcenergy. net> To: tom_maunder@admin.state.ak, us CC: RStinson@forcenergy. net ** High Priority** Tom, Thanks for your inquiry regarding drilling permit application for our WMRU #6 well. 1. BOP testing. We would like to test BOP's to 80% of their rated working pressure (4,000 psi) This exceeds the maxium antidpated surface pressure. 2. Cuttings disposal and fluids handling. We plan to dispose of solid waste (cuttings, cement) in the DWMU (Drilling waste management unit) that ~e have permitted on the drill site. The liquids we will dispose of in the disposal well (4D). We also would like to retain the option of using the annular injection permit which we have for WMRU #5. 3. Cemedting 9 5/8" casing. Following your query we looked again at the charged sand issue. Our couclusion was we need to extend the cement as follows. The charged sand is 3905' - 4300' TVD. The 9 5/8' casing is 5,168' TVD this allows adequate protection on the lower side of the sand, however we have decided to bring the top of cement to 4,870' (3,700' -rVD) this will more completely isolate the problem. We are planning to use 1104 cu.ft, of cement (this is gauge hole plus 30%) Thank you, if you have any questions please give me a call. Regards, Paul White 1 of 1 7/17/00 4:13 PM West McArthur River Unit #6 Casing Design 20" 129~, X-56 ~ 13 318" 68#, L-80 BTC 9 5~8" 47#, L-80 BTC 7-5~8" 29~, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 al 1~120' MD, 120' TVD m @1900' MD, 1845' TVD 7500' MD, 5128' TVD (~ 13,600' MD, 8835' TVD ~JUL 14 2000 Alaska 0ii & Gas Cons. Commission Anchor~e 14,685' MD, 9,763' TVD West McArthur River Unit Unit Boundary Plat Proposed WMRU #6 T8N, R14W, Seward Meridian ,JUL 1 4 2000 Alaska u~l & Gas Cons. ~n~mis~on Anchor~e W. McArthur River Unit Forcenergy ADL 359111 17 CIRI 5 i 4 29 32 #6 · WF-1 · 22 Fomenergy A-035017 28 27 Cook Inlet Bluff 33 34 11 14 WMRU Forcenergy ADL 359112 23 26 35 13 24 36 1" = 1 mile Attachments 1. Waiver Requests 2. Outline Procedure 3. Well Plan schematic 4. Unit Maps 5. Drilling Fluids Program 6. Pressure Information 7. Casing Design 8. Cement Calculations 9. Directional Information 10.Wellhead Schematic 11.Nabors BOP schematic 12.Nabors BOP equipment list 13.Nabors Drilling Fluid System Description RECEIVED ,JUL 14 ~ooo Alaska Oil & Gas Cons. Commiss',~n Anchorege West McArthur River Unit//6 Request for Diverter Waiver Forcenergy requests that the diverter requirements in 20 AAC 25.035 be waived for West McArthur River Unit//6 because West MeArthur River Unit #1,//2, #3, #4, #5, #D1 and West Forelands Unit //2 were all drilled from the same general surface location without encountering any shallow gas. Previous waivers~were granted for WMRU//2, #3, #4, #5 and #D1. Mud weights planned for the surface interval are 8.5 ppg at spud, building to 9.2 ppg at the 13 3/8" casing depth, due to drilled solids. These mud densities are consistent with the five prior wells· Request to Eliminate Logging Runs at Surface and Intermediate Casing Points Forcenergy requests a waiver for ~ppen hole wireline logging required by 20 AAC · · 18' , .... 25_.07,~ at the surface casing pmnt o~cX~TVD and at the intermediate casing pmnt o~t~~VD. West McArthur R~ver lf~t Wells #1,//2, #D1 and West Forelands Unit//2 l~xTe previously logged these intervals and it does not seem necessary to incur the added expense for more logs in this area over these shallow intervals. Previous waivers for the surface and intermediate hole logging requirements were granted for West McArthur River Unit #3, #4 and #5. RECEIVED IUL 14 2000 Gas Cons. Commission Anchorage ( (' West McArthur River Unit #6 Summary of Drillin_~ Hazards POST THIS NOTICE IN THE DOGHOUSE No shallow gas is expected in this well. Over-pressured disposal zone from 3905' TVD to 4300' 'I'VD will require mud weight of 10.8 to control water influx and drilling difficulties. Lost circulation is unlikely, however lost circulation potential increases when crossing faults. 12 ¼" and 8 ~" hole section inclination angles will necessitate constant pipe movement and good hole cleaning to reduce the buildup of cuttings beds. H2S is not present in the West McArthur River Field. CONSULT THE WELL PLAN FOR ADDITIONAL INFORMATION 07/18/00 rs ( ( WEST MCARTHI~ RIVER UNIT OUTLINE PROCEDURE RECEIVED dUL 20 2OOO 1. Move Rig, Rig Up Nabors Rig 160 2. Drive 20" conductor to 120'. Alaska 0il & Gas Cons. Commission 3. Rig flow line, Pick up BHA, Spud Well. Anchorage 4. Clean out conductor and drill to 400' Kick Off Poim. 5. Directionally drill 17 72" hole to 1,900' MD / 1,845' TVD. 6. Run 13 3/8" casing to 1,900', cement to surface. 7. Install wellhead, Nipple up 13 5/8" 5m BOP stack and equipment. Test to 4000 psi. 8. Pick up 12 IA" BHA, Run in hole. Test casing to 3000 psi. 9. Clean out casing and drill 20' of new hole. Perform Formation Imegrity Test to 12.5 ppg EMW. 10. Directionally drill 12 ¼" hole to 7,500' MD / 5,128' TVD. 11. Run and cement 9 5/8".casing. 12. Nipple down BOPE. Install casing slips and packoff. 13. Nipple up 13 5/8" 5m BOP stack and equipment. Test to 4000 psi. .14. Pick up 8 1/2" BHA, Run in hole. Test casing to 3000 psi. 15. Clean om casing and change over to Oil Based Mud. 16. Drill 20' of new hole. Perform Formation Integrity Test to 11.0 ppg EMW. 17. Directionally drill 8 ½" hole'to 13,837' MD / 9,033' TVD. 18. Run intermediate log suite. 19. Condition hole, Run and cement 7 5/8' liner from 7,300' MD to 13,837' MD. 20. Test 13 5/8" 5m BOP stack and equipment to 4000 psi. 21. Pick up tapered drill string / BHA and run in hole. 22. Clean out liner and test lap to 3000 psi. 23. Clean out shoe track, drill 20' of new formation and perform Formation Integrity ' Test to 11.0 ppg.EMW. 24. Directionally drill 6 ~A" hole to TD at 14,865'MD / 9,763' TVD. 25. Condition hole and nm log suite as follows: Triple combo, FMI, OBDT and Check Shot (be prepared to run drill pipe conveyed logs) 26: Condition hole for liner. 27. Run and cement 5 ½" liner from 13,637' to 14,865'. 28. Clean out liner and test lap to 3000 psi. 29. Run Cement Bond logs 30. Run Tubing Conveyed Perforating guns and Production packer on drill pipe. 31. Pressure up drill pipe to set packer. POOH with drill pipe. 32. RIH and stab 2 7/8" completion into packer polished bore. 33. Nipple down BOPE and Nipple up Production tree.. 34. Swap well over to crude, fire guns with 2,500 psi to 2,800 psi and bring well online. 07/20/00 Rev (1) West McArthur River Unit #6 Casing Design 20" 129~, X-56 13 3~8' 68~, L-80 B 9 5/8" 47#, L-80 BTC 7-5~8" 29#, L-80 Hyd 521 5-1/2" 17#, L-80 Hyd 521 al (~1120' MD, 120' TVD Ilil @1900' MD, 1845' TVD 7500' MD, 5128' TVD 3,600' MD, 8835' TVD 14,685' MD, 9,763' TVD RECEIVED ,JUL 14 2000 .q~as~,a U~ & Gas Cons. Commission Anchorage West McArthur River Unit Unit Boundary Plat Proposed WMRU #6 T8N, R14W, Seward Meridian RECEIVED ,JUL 14 2000 Alaska 0, ~ Gas Cons. Commission Anchorage ~ 8 i CIRI I 17 10 11 12 15 14 13 WMRU Forcenergy ADL 359112 f WF-1 21 22 ! ,~ 1 A-035017 29 28 ~ Cook Inlet Bluff i 32 33 1 23 27 26 24 25 34 35 36 1' = 1 mile 24g0000 24-88000 2486000 2484000 0 0 0 ~o 0o --F 0 0 0 00 00 I + + /ER D- I 0 0 0 0 I + CMRU- lA ~'MRU- 1-J- RIVER + + ~EST McARTHUR RIVER #2 + + + 0 0 0 FORELAND 1- 0 0 ~h OI AC 2000' 4000' 1" = 2000 feet RECEIVED WEST MCARTHUR RIVER UNIT #6 DRILLING FLUID PROGRAM Interval Hole size = Casing Size = Mud type = 0'- 1,900' 17~,, 13 3/8" Fresh Water Bentonite Drilling Fluid Parameters: Weight: 8.8 - 9.0 ppg PV: 5- 10 cps YP: 15-25 lb/100~ API Fluid Loss: rdc - 12cc HPHT Fluid Loss n/a This interval may be drilled with a mud system built with fresh water, bentonite, polymer extender, barite, soda ash and caustic. With an estimated 32 degree angle at casing point, cuttings beds should not be a problem. A polymer may be added to the mud system for fluid loss control just prior to running the casing. Interval 1,900' - 7,500' Hole size = 12 Casing Size = 9 5/8" Mud type = PHPA Polymer Drilling Fluid Parameters: Weight: 9.0- 9.2 ppg PV: 10- 12 cps YP: 12-25 lb/100fta AP1 Fluid Loss: 4 - 6cc HPHT Fluid Loss n/a RECEIVED JOL 000 Alaska 0il & ~as Cons. Commission Anchorage Use the existing surface system for this interval. Treat and condition for cement contamination with Bicarb. Build additional volume as required. After treating for cement contamination, add bentonite, PHPA, and Resinex for .viscosity, inhibition, and fluid loss. Potential problems that exist include, hole cleaning, tight hole, gas kicks, bit balling, and sloughing coal. In addition to the above products, add Flovis, Soltex, and a lubricant for hole cleaning, hole stability and reduction of torque and drag as needed. Interval Hole size = Casing Size = Mud type = 7,500' - 14,685' 81/~' 7 5/8" and 5 ¥~' Flush Joint Invert Oil Base Drilling Fluid Parameters: Weight: 9.0 - 9.2 ppg PV: 15- 18 cps YP: 10-30 lb/100ft2 API Fluid Loss: n/a HPHT Fluid Loss < 8 cc Oil / Water Ratio 80/20 This interval will be drilled with a diesel based invert oil mud. After running 9 5/8" casing, circulate and condition hole, reducing surface volume of water based mud. After cementing, drop top cement plug and displace cement with oil based mud. Clean active mud and fill with oil based mud. Condition oil based mud while drilling cement, float collar, and shoe. Oil based mud's viscosity and properties will stabilize as fluid temperatures increase. Utilize all solids control equipment. Maintain low shear rate viscosity to ensure good hole cleaning. RECL' IVED JUL 14 2000 ,~,, o. ~as Cons. Commission Anchorage WEST MCARTHUR RIVER UNIT//6 PRESSURE INFORMATION The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the West McArthur River Unit//5. The pore pressure gradient information was obtained from the original bottom hole pressure surveys and RFT surveys on West McArthur River Unit gl,g2A and g3. The fracture gradient information was obtained from formation integrity tests below casing points on the West McArthur River Unit g 1, g2A and g3. WMRU g2A, P= 4304 psi 9567' TVD from DST (as per 407 Comp Report, 11/93) WMRU gl, P= 4362 psi @ 9724' TVD from RFT (as per 407 Comp Report, 2/92) WMRU g3, P = 3680 psi @ 9400 from static BHP survey 7/2/95 The most conservative (highest) formation pressure gradient of 8.65 ppg or .45 psi/ft was used in these calculations. Procedure for Calculating Anticipated Surface Pressure ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the easing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point and a gas gradient to the surface. 1) ASP = ((FG x .052) - 0.115) x D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.115 = gas gradient in psi/ft D = true vertical Depth of casing seat in ft RKB OR RECEIVED ,JUL 14 2000 Alas~,a Oil & Gas Cons. Commission ~omge 2) ASP= FPP-(0.115 x D) where: FPP = Formation Pore Pressure at the next casing point which is tied back to surface or at TD (total depth) ASP Calculations Drilling below Surface Casing (13 3/8") ASP OR ASP = ((FG x .052)- 0.115) x D = ((12.5 x .052) - 0.115) x 5128' = 2743 psi = (5128' x .45)- (.115 x 5128') = 1717 psi Drilling below Intermediate Casing (9 5/8") ASP OR ASP = ((FG x .052)- 0.115) x D = ((14.5 x .052) - 0.115) x 9033' = 5772 psi = (9033' x .45) - (.115 x 9033') -- 3026 psi Drilling below Drilling Liner (7-5/8") ASP OR ASP = ((FG x .052)- 0.115) x D = ((14.5 x .052) - 0.115) x 9763' = 6239 psi = (9763' x .45)- (.115 x 9763') = 3271 psi REC.,.._tVED ilVL 14 ooo Alaska Oi~ & Gas Cons. Commission Anc~orafle Proposed Casin~ WEST MCARTHUR RIVER UNIT CASING DESIGN Size Specifications Hole Casing, Weight Grade Coupling Driven 20" 129 K-55 N/A 17 1/2" 13 3/8" 68 L-80 BT&C 12 1/4" 9 5/8" 47 L-80 BT&C 8 1/2" 7 5/8" 29 L-80 Hy 521 6 ~A" 5 ~A" 17 L-80 Hy 521 ,JUL 14 000 ~, ~ ~as Cons. Commission ~chorage Setting Depth Top Length MD TVD MD 120' Surf. Surf. 120' 1900' Surf. Surf. 1900' 7500' Surf. Surf. 7500' 6537' 7300' 5015' 13837' 1048' 13637' 8872' 14685' Bottom TVD 120' 1845' 5128' 9033' 9763' Casing Joint Strength Body Strength Burst Collapse K lbs K lbs Psi Psi 20" 129//X-56 N/A N/A N/A N/A 13 318' 68# L-80 1545 1556 5050 2260 9 5/8" 47# L-80 1122 1086 6870 4760 7 5~8' 29// L-80 566 683 6890 4790 5 1/z' 17# L-80 338 397 7740 6290 Desien Criteria -- Tension Burst Straight Hook Load - Ignoring Deviation and Buoyancy Full Colunm of Gas against deepest formation pressure Except for liners where a 3000 psi test pressure on top of 9.6 ppg fluid is backed on the outside by a fresh water gradient of 0.43 psi/ft. Collapse Full evacuation on the inside backed by expected formation gradient of 0.45 psi/ft on the outside. 13-3/8" Surface Casing 68//L-80 BT&C ~ 1900' MD/1845' TVD Tension = 1900' x 68// Rated = 1545 K = 129.2 K Safety Factor = 11.6 Burst = (5128' x 0.45)-(0.115 x 5128') Rated = 5050 psi = 1718 psi Safety Factor = 2.9 Collapse = (1845' x 0.45)-(0.115 x 1845') Rated = 2260 psi = 6! 8 psi Safety Factor = 3.7 9 5/8" Intermediate Casing 47# L-80 BT&C (~ 7500' MD/5128' TVD Tension = 7500' x 47# Rated = 1086 K = 352.5 K Safety Factor = 3.1 Burst = (9763' x 0.45)-(0.115 x 9763') Rated = 6870 psi = 3271 psi Safety Factor = 2.1 Collapse = (5128' x 0.45)-(0.115 x 5128) Rated = 4760 psi = 1718 psi Safety Factor = 2.8 7-5/8" 29.0#. Hydril 520 liner @13'837' MD/9,033' TVD Tension = 6537' x 29# Rated = 566K = 189.6 K Safety Factor = 3.0 Burst = ((9033 x 0.4992) + 3000)- Rated = 6890 psi (9033 x 0.43) Safety Factor = 1.9 = 3625 psi Collapse = (9033 x 0.45)-(0.115 x 9033) Rated = 4790 psi = 3026 psi Safety Factor = 1.6 5-1/2"17# L-80 Hydril 521 liner 13,685' MD/9,763' TVD Tension = 1048' x 17# Rated = 338 K = 17.8 K Safety Factor = 19.0 Burst = ((9763 x 0.4992) + 3000)- Rated = 7740 psi (9763 x 0.43) Safety Factor = 2.1 = 3676 psi Collapse = (9763 x 0.45)-(0.115 x 9763) Rated = 6290 psi = 3271 psi Safety Factor = 1.9 REC, L: VED ,JUL 14 0oo Alam~a Oil & Gas Cor~s. Commission Anchor~e Operator Name: Forcenergy Ga~ ..... "qoration Inc Well Name: WMR ~6 Job Description: WMR 6 Surface Date: July 12, 2000 Proposal No: 179651018A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) . .. 18.750 CASING 17.500 HOLE DEPTH(ft) · MEASURED' I TRUE VERTICAL 120 I 120 1,900 I 1,845 SUSPENDED PIPES [. ~:.;!':.?' '!':.': .'.:.:.'i.' .i"i .'":.'!'.'..'!'DIAME~R..;'(in):'.' '.';i., '".'?"."". '.i..'.' .':...: ...~. i WEIGHT'[./. ''':: 'i,' ,'~'.: i:,,,.,.'... :.'i..' '. ?'.'i'."DEPTH(ft);".'"..'.' '.;' I"../..'....i:...'' ';?'i '..,'O.D':..'.'.".:"..;. i.' .'.~ .'," :'.':":!:. '."' '"':'"';"':' :~',.".liD..".".";?.'.. ?..' '?'i ',l',.,. ::(lbS.).., I:.:i~:.':,'.':. ' MEA$:URED.'.' "~"~".'".1 ".".TRUE I '1 "'q2.4 s '1 I ..... a, o0' '1' ' Float Collar set ~} 1,820 It Mud Density 9.20 ppg Mud Type Water Based Est. Static Temp. 95 ° F Est. Circ. Temp. 88 ° F VOLUME CALCULATIONS 120 It x 0.9418 cf/It 1,280 It x 0.6946 cf/It 500 ff x 0.6946 cf/ff 80 ff x 0.8407 cf/ft with 0 % excess = with 80 % excess = with 80 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 113.0 cf 1600.4 cf 625.2 cf 67.3 cf (inside pipe) 2405.9 cf 429 bbls ~JUL 1 4 2000 Ala~a Oil& - ' ' · Gas Cons. Commsslon Anchorage July 13, 2uuu 8:45 AM Gr4115 Operator Name: Forcenergy Ga~'"'--Dloration Inc Well Name: WMR ~6I,... Job Description: WMR 6 Surface Date: July 12, 2000 Proposal No: 179651018A FLUID SPECIFICATIONS Pre-flush VOLUME VOLUME FLUID CU-FT FACTOR Lead Slurry 1713 I 2.1 Tail Slurry 692 I 1.17 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) 40.0 bbls Water (~ 8.4 ppg AMOUNT AND TYPE OF CEMENT 817 sacks Class G Cement + 2% bwoc Sodium Metasilicate + 0.4% bwoc CD-32 + 0.5% bwoc Calcium Chloride + I gals/100 sack FP-6L + 97% Fresh Water 592 sacks Class G Cement + 0.25% bwoc CD- 32 + 1% bwoc Calcium Chloride + 1 gals/100 sack FP-6L + 36.3% Fresh Water 272.5 bbls Mud (~ 9.2 ppg SLURRY SLURRY NO. 1 NO. 2 12.50 15.70 2.10 1.17 10.94 4.09 11.94 5.09 RECL-,IVED JUL 14 2000 ~ .a..sKa 0il & Gas Cons. Comn~issio~ Report Printed on: July 13, 2000 8:45 AM Gr4129 Operator Name: Forcenergy Ga~'"' 'nloration Inc Well Name: WMR ~ Job Description: WMR 6 Intermediate Date: July 12, 2000 Proposal No: 179651018A WELL DATA ANNULAR GEOMETRY ANNULAR I.D. (in) I MEASURED 12.415 CASING I 1,900 12.250 HOLE I 7,500 DEPTH(ft) TRUE VERTICAL 1,845 5,128 SUSPENDED PIPES ~.~2s I s.~s~ I 47I ~,s0~ I s,~2s 1 Float Collar set ~ 7,420 ft Mud Density 10.00 ppg Mud Type Water Based Est. Static Temp. 121 ° F Est. Circ. Temp. 106 ° F VOLUME CALCULATIONS 1,000 ff x 0.3132 cf/It 500 It x 0.3132 cf/It 80 It x 0.4110 cf/It with 30 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 407.1 cf 203.6 cf 32.9 cf (inside pipe) 643.6 cf 115 bbls ,JUL 14 2000 mas~a Oi~& Gas Cons. Commission Ar~c~orage Report Printed on: July 13, 2000 8:46 AM GH.115 Operator Name: Forcenergy Ga~-""-oloration Inc Well Name: WMR ~6 . Job Description: WMR 6 Intermedi;ite Date: July 12, 2000 FLUID SPECIFICATIONS Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Lead Slurry 407 I 2.1 Tail Slurry 236 I 1.15 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Proposal No: 179651018^ 40.0 bbls MCS-4D + 119 Ibs/bbl Barite + 6 Ibs/bbl MCS-D + 30.2 Ibs/bbl Bentonite @ 10.5 PPg AMOUNT AND TYPE OF CEMENT 194 sacks Class G Cement + 2% bwoc Sodium Metasilicate + 0.4% bwoc CD-32 + 0.5% bwoc Calcium Chloride + I gals/100 sack FP-6L + 106% Fresh Water 206 sacks Class G Cement + 0.25% bwoc Calcium Chloride + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 44.1% Fresh Water 543.2 bbls Mud ~ 10 ppg SLURRY SLURRY NO. 1 NO. 2 12.50 15.80 2.10 1.15 11.95 4.97 11.96 4.98 ,JUL 4 000 Alaska U~ & Gas Cons. Commission A,'~chorage Report Pr;,r,~, on: July 13, 2000 8:46 AM Gr4129 Operator Name: Forcenergy Gas I~¥r)1¢" qon Inc Well Name: WMR ~ Job Description: WMR 6 7 5/8" Liner Date: July 12, 2000 WELL DATA Proposal No: 179651018A ii ANNULAR GEOMETRY .ANNULAR I.D. (in) CASIN~ 8.681 HOLE 8.500 SUSPENDED PIPES · . DEPTH(fi) . MEASURED ' I TRUE VERTICAL 7,500 I 5,128 13,837 I 9,033 I I '7'625 I 6"S78'I29.7 I 13,837 I 9,033 ] Float Collar set ~ 13,757 fl Mud Density 10.00 ppg Mud Type Oil Based Est. Static Temp. 152 ° F Est. Circ. Temp. 132 ° F VOLUME CALCULATIONS 1,700 It x 0.0770 cf/it 80 It x 0.2578 cf/It with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 170.1 cf 20.6 cf (inside pipe) 190.7 cf 34 bbls R ....... , ~t~ ,. ,a, ~'"'.~m ,JUL 14 2000 ~as~a Oil & '~ · Gas Cons. C0mm~sa0n An~or~e Report Pi;n~:~ on: July 13, 2000 8:46 AM 6Hl15 Operator Name: Forcenergy Gas .Expl.,e-~tion Inc Well Name: WMR ~ ( ~, Job Description: WMR 6 7 5/8" Liher Date: July 12, 2000 FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Cement Slurry 191 I 1.15 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Estimated Pumping Time - 70 BC (HH:MM) Estimated Pumping Time - 100 BC (HH:MM) Free Water (mis) (~ 180 ° F ~ 90 ° angle Free Water (mis) ~ 180 ° F ~ 45 ° angle Fluid Loss (cc/30min) at 1000 psi and 130 ° F Proposal No: 179651018A 40.0 bbls MCS-4D + 119 Ibs/bbl Barite + 6 Ibs/bbl MCS-D + 30.2 Ibs/bbl Bentonite + 100% Fresh Water (~ 10.5 ppg AMOUNT AND TYPE OF CEMENT = 166 sacks Class G Cement + 0.6% bwoc FL-33 + 0.3% bwoc CD-32 + 0.05% bwoc R-1 + 1 gals/100 sack FP-6L + 43.7% Fresh Water 393.4 bbls Mud @ 10 ppg SLURRY NO. 1 15.80 1.15 4.93 4.94 3:10 3:13 0.0 0.0 40.0 RECb:.,V,_D ,JUL 14 20o0 Ala,~a Oil & Gas Cons. Commission Ar~chorage Report Printed on: July 13, 2000 8:46 AM Gr4129 Operator Name: Forcenergy Gas F~,,nl¢'-' *ion Inc Well Name: WMR Job Description: WMR 6 5 1/2" Production Liner Date: July 12, 2000 WELL DATA Proposal No: 179651018A ANNULAR GEOMETRY ANNULAR I.D. (in) 6.875 CASING 6.750 HOLE DEPTH(ft) . MEASURED ' I ' TRUE VERTICAL 13,837 I 9,033 14,685 I 9,763 SUSPENDED PIPES I:,...i'...?:.'...:. '~.:'. '.':'. "'.~"..':'.''".",DIA:M.E]=E.R' (i.,)'.."'...? ."..:.'' ',:.". :'i':...,'.'t. WE!OHTi'.'.,:,':... :...."......:?..'.."...:.':.....:: :.'." .'..:, ,. ,DEPTH(ft):.:. '.: ...': '...'....., .,. :.' .,. :' ':,, .,...-I I!' ..~i:.. :'" .." '. i./O,.D~: .' ,':'." .' ~"."' :": '.: '!:.'.':' .."i.".."' :' i .':... 'l'iD..:." ':/...:,' ~...:,"...':.'..'i.':1..." (!bs.'./.ft)...`,!. 'i."i. '...:'......M.EA$:U R;n :...:.:' ,'.".I'..'./,TRU. E'VERTiCAL: '.'i.'1 I 5.soo I4.802 I 17I 14,685 I 9,703 1 Float Collar set {~} 14,605 ff Mud Density 9.80 ppg Mud Type Oil Based Est. Static Temp. 158 ° F Est. Circ. Temp. 137 o F VOLUME CALCULATIONS 400 ff x 0.0928 cf/It 848 ft x 0.0835 cf/It 80 ff x 0.1305 cf/ff with 0 % excess = with 30 % excess = with 0 % excess = TOTAL SLURRY VOLUME = 37.1 cf 92.1 cf 10.4 cf (inside pipe) 139.6 cf 25 bbls ,JUL 14 2000 ~tasKa Oil & Gas Cons. Commission Anchorage Report Printed ~n: July 13, 2000 8.~6 AM c~115 Operator Name: Forcenergy Gas ExDl?.-~tion Inc Well Name: WMR ~6 ( ~. Job Description: WMR 6 5 1/2" PrOduction Liner Date: July 12, 2000 FLUID SPECIFICATIONS Pre-flush Weighted Spacer VOLUME VOLUME FLUID CU-FT FACTOR Cement Slurry 140 I 1.16 Displacement CEMENT PROPERTIES Slurry Weight (ppg) Slurry Yield (cf/sack) Amount of Mix Water (gps) Amount of Mix Fluid (gps) Proposal No: 179651018A _ 50.0 bbls MCS-4D + 119 Ibs/bbl Barite + 6 Ibs/bbl MCS-D + 30.2 Ibs/bbl Bentonite + 9 Ibs/bbl Potassium Chloride @ 10.5 ppg AMOUNT AND TYPE OF CEMENT -- 120 sacks Class G Cement + 2% bwow Potassium Chloride + 0.9% bwoc BA-10A + 0.5% bwoc CD-32 + 0.15% bwoc Sodium Metasilicate + 0.1% bwoc R-1 + 1 gals/100 sack FP-6L + 43.8% Fresh Water 198.5 bbls Mud (~ 9.8 ppg SLURRY NO. 1 15.80 1.16 4.94 4.95 Report Printed on: July 13, 2000 8:46 AM Gr4129 I Forcenerav: ~ TARGET DETAILS o. '~ +N/-S +F.J-W Nmthing Eastlng Targel 8633.00 6817.03 6458.49 2489590.00 193900.01 WMRU #3RD T1 REFERENCEINFORMA'RON ~IB~I~ 9033.00 7085.59 6401.31 2489859.99 193850.0t WMRU03RDT2(Hen~Iock) 9763.00 7503.36 6312.t4 2490279.99 193772.01 WMRU 03RD T4 Co~rdmate (N/E} Reference: Well Centre: West Mc.Nthur River Unit #6, True North 9543.00 7354.16 6344.13 2490129.99 193800.01 WMRU 03RD T3 (West Forela~) Vo~ical (I~D} Reference: Nabom 160 163.0 above Mean Sea Level / Seclion(VS} Reference: Slot- (0.00,0.00) Measured Del~ Reference: Nabors 160 163.0 above Mean Sea Level Celculation Id~thod: Minimum Cuw~ture WELLPATH DETNL$ WMR #6 WPs Vertical Section Ongm: Slot- (0.00,0.00) Ve~ical Section Angle: 40.07* Rig: Depfl~ Reference: Nabors 160 16~.00R - 1000- 2000- 3000- 4000- 5000- 6000- 7000- 8000- 9000- 10000- 7500- 6250 5000 3750 2500 1250 ;5,0§tart Dir l°/100': 400' MD, 400'rVD Start Dir 1 .SVI00': 700' MD, 699.86TVD · 14)RQtrt Dir 2°/100': 1000' MD, 998.53'I'VD Dh- 3°/100': 1300' MD, 1293.37TVD 200O 2500 :2706.04'MD, 2424.9'TVD 3500 ' 5" ' 'is0' 'Zs'o0' '37's0' 'So'oo' '61s0' 'gs'oo West(-)/East(+) [2500ft/inl 5000 $000 6500 7000 7500 8000 8500 9000 dUL 14 2000 Gas Cons. Commission Anchorage 10000 10500 11000 1500 lir 3.5°/100': 12121.63' MD, 7733 13000 ~Dfl': 13410.99' MD, 8681.. Start Dh- 3.5°/] 00': ] 3676.26' ! LDh': 13955.22'lVID, 9'13 Start Dir 3.5°/100': 14167.95 Dir: 14417.2'MD, 954 Total Depth: 14684.93'ME '' I''''1''''1''''1''''1'''' I'''' I .... I .... I .... I .... I .... I .... I ''' 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 1O000 11000 12000 Wellpalk (Weal McAr~ River Unl g6/WMR #6 WPs) Vertical Section at 40.07° 12000fl'/inL~]~ : _ Date: .... Dale: Sperry-Sun Drilling Alaska Planning Report - Geographic · Company: Forcenergy. - · ... Field:. COOK INLET ' ' . Site: West Mc, Arthur. River Unit Well: West Mc. Arthur River Unit #6 Wellpatb: WMR #6WPs Dare:" 0711412000 .... Time:" 11:59:14 ]F~e~. Co-ortUuate(NE)'Referen%: Well: West Mc/tathur River Unit 06 Vertical (TVD) Reference: Nabors 160 163.0 above Mean. Sea Level' Section (vs) Reference: . Well (0.00E,0,00N,40.07Azi) Plan: · . . .. Plan #1 . ... ''1 . Field: COOK INLET Alaska USA Map System: US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) S),,~ Datum: Mean Sea Level Map Zone: Alaska. Zone 4 Coordinate System: Well Centre Geomagnetic Model: Bggmg9 Site: Wast Mc, Arthur River Unit West McArb~ur River Unit Site Position: Northing: 2482933.00 ff From: Map F, asting: 187276.00 ff Position Uncertainty.: 0.00 ff Ground Level: 0.00 ft Latitude: 60 47 5.096 N Longitude: 151 45 0.255 W North Reference: True Grid Convergence: -1.53 deg ',Veil: West McArthur River Unit 06 Slot Name: Surface Position: +N/-S 14.12 ft Northing: 2482947.50 ff Latitude: +E/-W -14.38 ft Fasting: 187262.00 ff Longitude: Position UncertainD,: 0.00 ff Reference Point: +N/-S 14,12 fl: Easting: 2482947.50 ff Latitude: +E/-W -14.38 ft Northing: 187262.00 ff Longitude: MeasnredDepth: 163.00 ff Inclination: Vertical Depth: 163.00 ff A~lmuth: 6O 47 5.235 N 151 45 0.545 W 60 47 5.235 N 151 45 0,545 W 0.000 dog 0.000 dog Wellpath: WMR #6 WPs Drilled From: Well Ref. Point Tie-on Depth: 0.00 ff Current Datm: Nabors 160 Height 163.00 ft Above System Datum: Mean Sea Level Mape~c Data: 07/12/2000 Declination: 21.07 dog Field Strength: 55204 nT Mag Dip Angle: 73.46 dog Vertical Section: Depth From (TVD) +NI-S +E/-W Direction ff ft ff dog 0.00 0.00 0.00 40.072 Plan: Plan #1 Date Composed: 07/12/2000 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section In.formation 163.00 0.000 0.000 163.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.000 0.000 400.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 3.000 45.453 699.86 5.51 5.60 1.00 1.00 0.00 45.45 1000.00 7.500 45.453 998.53 24,76 25.15 1.50 1.50 0.00 0.00 1300.00 13.500 45.453 1293.37 63.09 64.10 2.00 2.00 0.00 0.00 2706.04 55.681 45.259 2424.90 611,95 618.76 3.00 3.00 -0.01 -0.24 12121.53 55.681 45.259 7733.39 6085.85 6142.31 0.00 0.00 0.00 0.00 13352.00 34.000 350.000 8633.00 6817.03 6458.49 3.50 -1.76 -4.49 -137.70 13410.99 35.469 347.453 8681.48 6849.98 6451.91 3.50 2.49 -4.32 -45.70 13676.26 35.459 347.453 8897.52 7000.23 64t 8.47 0.00 0.00 0.00 0.00 13837.37 30.000 350.000 9033.00 7085.59 6401.31 3.50 -3.39 1.58 166.93 13955.22 26.022 347.673 9137.03 7139.89 6390.67 3.50 -3.38 -1.97 -165.66 14167.95 26.022 347.673 9328.19 7231.06 6370.74 0.00 0.00 0.00 0.00 14417.20 34.745 347.899 9543,00 7354.16 6344.13 3.50 3.50 0.09 0.85 14684.93 34.745 347.899 9763.00 7503.36 5312.14 0.00 0.00 0.00 0.00 WMRU #3RD T1 (G-Zone) WMRU 03RD T2 (Hemlock) WMRU ~3RD T3 (West Forela WMRU #3RD T4 (TD) Section 1: Start 163.00 0.000 0.000 163.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.000 0.000 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.000 0.000 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.000 0.000 400.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Sperry-Sun Drilling Alaska Planning Report- Geographic C~y: Farcenenjy. · ... Field: COOK INLET Si~e: West McArthur. River Unit Well: West..McArthur Ri~er Unit #6 Wellpath: WMR #6 WPs · . Section 2: Start MI) !n~! .' ' Azlm 'T~D +NFS.' +E/-W 'VS "i)I~ ' 'Bafld"' Tara Tl~O.' " "ft'. . deg.'." .deg" · 'ff' ft" .. ft ' ' ' ft .' · "decj/1OOft deg/lOOft, dag/iOoft' .. clag .. ,, . . .......... 500,00 1,000 45,453 499,99 0,61 0,62 0,87 1,00 1,00 0,00 0,00 600.00 2.000 45.453 599.96 2.45 2.49 3.47 1.00 1.00 0.00 0.00 700.00 3.000 45,453 699.86 5.51 5.60 7.82 1.00 1.00 0.00 0.00 Section 3: Start 800,00 4.500 45,453 799,65 10,10 10.26 14,33 1,50 1,50 0.00 0.00 900.00 6.000 45,453 899,22 16,51 16.78 23.44 1,50 1.50 0,00 0,00 1000,00 7,500 45,453 998,53 24,76 25,15 35,14 1,50 1,50 0,00 0,00 See~on 4: Start 100,00 9,500 45,453 1097,42 35,13 35,69 49,86 2,00 2,00 0,00 0,00 200,00 11,500 45,453 1195,75 47,91 48.67 68.00 2,00 2.00 0,00 0,00 300,00 13,500 45,453 1293.37 63,09 64.10 89,64 2,00 ZOO 0,00 0,00 Section 5: Start 1400.00 16,500 45,409 1389,95 81,25 82,53 115.31 3.00 3,00 -0.04 -0,24 1500.00 t9.500 45,378 1485.05 102,95 104,53 t46,08 3.00 3,00 -0,03 -0,20 1600,00 22,500 45,355 1578.39 128.13 130,63 181,76 3,00 3,00 -0,02 -0,17 1700,00 25,500 45.337 1669,74 156,71 158,96 222,25 3,00 3.00 -0.02 -0.15 1800,00 28.500 45,323 1758.83 188,62 191,24 267.46 3.00 3,00 -0.01 -0,13 1900.00 31.500 45.311 1845.42 223.78 226.79 317.24 3,00 3.00 -0,01 -0.12 2000,00 34,500 45,301 1929,28 262,08 265.50 371.47 3,00 3,00 -0.01 -0.11 2100.00 37.500 45,293 2010,17 303,42 307,27 430.00 3,00 3,00 -0,01 -0,10 2200,00 40,500 45,285 2087,88 347.69 351,99 492.66 3.00 3.00 -0.01 -0,09 2300.00 43.500 45.279 2162,18 394,77 399.53 559,29 3,00 3,00 -0.01 -0.09 2400,00 46,500 45,273 2232,88 444,52 449,77 629,70 3,00 3,00 -0,01 -0,08 2560,00 49,500 45,267 2299,79 496.82 502,56 703,70 3.00 3,00 -0.01 -0.08 2600,00 52,500 45.263 2362,72 551.51 557,76 781,09 3,00 3.00 0.00 -0,07 2706,04 55.681 45.259 2424.90 611.95 6t 8,76 866.61 3,00 3.00 0,00 -0,06 Section 6: Start 2800,00 55,681 45,259 2477,88 666.57 673,88 943,90 0,00 0,00 0,00 0.00 2900,00 55,681 45,259 2534,26 724,71 732,55 1026,15 0,00 0,00 0,00 0,00 3000.00 55.681 45.259 2590.64 782,85 791.21 1108,40 0,00 0.00 0,00 0,00 3100.00 56,681 45,259 2647,02 840,98 849,87 1190.66 0.00 0.00 0.00 0,00 3200,00 55,681 45.259 2703,39 899, t2 908,64 1272,91 0.00 0,00 0,00 0,00 3300.00 55.681 45.259 2759.77 957,26 967,20 1355,16 0,00 0.00 0.00 0,00 3400,00 55,681 45,259 2816,15 1015,39 1025,87 1437,42 0,00 0,00 0,00 0,00 3500,00 55,681 45.259 2872,53 1073.53 1084.53 1519,67 0,00 0.00 0,00 0.00 3600,00 55,681 45,259 2928.91 1131.67 1143.19 1601.92 0.00 0.00 0.00 0,00 3700.00 55.681 45.259 2985.29 1189,80 1201.86 1664.17 0.00 0.00 0.00 0.00 3800.00 55,681 45,259 3041,67 1247,94 1250.52 1766.43 0.00 0,00 0,00 0,00 3900,00 55,681 45.259 3098,05 1306.08 1319,18 1848.68 0.00 0.00 0,00 0,00 4000,00 55,681 45,259 3154,43 1364.21 1377.85 1930,93 0,00 0,00 0,00 0.00 4100.00 55.681 45,259 3210.81 1422,35 1436.51 2013,19 0.00 0,00 0.00 0.00 4200,00 55,681 45,259 3267,19 1480,49 1495,18 2095,44 0.00 0,00 0.00 0,00 4300.00 55.681 45,259 3323.57 1538.62 1553.84 2177.69 0.00 0,00 0,00 0,00 4400,00 55.681 45.259 3379.95 1596,76 1612,50 2259,95 0,00 0,00 0,00 0.00 4500,00 55,681 45,259 3436,33 1654,90 1671.17 2342,20 0.00 0,00 0.00 0,00 4600.00 55,681 45.259 3492,71 1713,03 1729,83 2424,45 0,00 0,00 0,00 0,00 4700,00 55.681 45.259 3549.09 1771.17 1788,50 2506,71 0,00 0,00 0,00 0,00 4800,00 55,681 45,259 3605,47 1829,30 1847,16 2588,96 0,00 0.00 0,00 0,00 Sperry-Sun Drilling Alaska Planning Report- Geographic Fiel~ COOK INLET Site:' West McArthur. River Unit Well: West McArthur R'nter Unit #6 Welloath: W/MR ~ WPs . . Section 6: Start · ' MI) lnel '"' Azfla . '1'IR) +NFS ~ClE/-W '¥S D~" ~ld' ~.m ~ '.. .. ...~... ~." d~ .... ~" .....~. ~ ' ' :~. '.'~~i~~~ d~'- . . ])ate:' 07/14/2000 T. ae:" 11:59:t4 ]~'.~. e: CO-ordinate(NE)'lgeference: Well: West McArthur River Unit/t6 Vertical ('l'Vl)) Ret'erenee:Nabors 160 163.0 above Mean. Sea Level Section O/S) Refereace: , Well (O,OOE,0.00N,40.07Azi Pisa: ..Plan #1 .... 4900.00 55.681 45.259 3661.85 1887.44 1905.82 2671.21 0.00 0.00 0.00 0.00 5000.03 55.681 45.259 3718.23 1945.68 1964.49 2753.46 0.00 0.00 0.00 0.00 5100.00 55.681 45.259 3774.61 2003.71 2023.15 2835.72 0.00 0.00 0.03 0.00 5200.00 55.681 45.259 3830.99 2061.85 2081.82 2917.97 0.00 0.00 0.00 0.00 5300.00 55.681 45.259 3887.37 2119.99 2140.48 3000.22 0.00 0.00 0.00 0.00 5400.00 55.681 45.259 3943.75 2178.12 2199.14 3082.48 0.00 0.00 0.00 0.00 5500.00 55.681 45.259 4000.13 2236.26 2257.81 3164.73 0.00 0.00 0.03 0.00 5500.00 55.681 45.259 4056.51 2294.40 2316.47 3246.98 0.00 0.00 0.00 0.03 5700.00 55.681 45.259 4112.89 2352.53 2375.14 3329.24 0.00 0.00 0.00 0.00 5800.00 55.681 45.259 4169.27 2410.67 2433.80 3411.49 0.00 0.00 0.00 0.03 5900.00 55.681 45.259 4225.65 2468.81 2492.46 3493.74 0.00 0.00 0.03 0.00 6000.00 55.681 45.259 4282.03 2526.94 2551.13 3575.99 0.00 0.00 0.03 0.00 6100.00 55.681 45.259 4338.41 2585.08 2609.79 3658.25 0.00 0.00 0.00 0.00 6200.00 55.681 45.259 4394.79 2643.22 2668.45 3740.50 0.00 0.00 0.00 0.03 6300.00 55.681 45.259 4451.17 2701.35 2727.12 3822.75 0.00 0.00 0.03 0.00 6400.00 55.681 45.259 4507.55 2759.49 2785.78 3905.01 0.03 0.00 0.03 0.00 6500.00 55.681 45.259 4563.93 2817.63 2844.45 3987.26 0.03 0.00 0.00 0.00 6600.03 55.581 45.259 4620.31 2875.76 2903.11 4069.51 0.00 0.00 0.03 0.00 6700.00 55.681 45.259 4676.69 2933.90 2961.77 4151.77 0.00 0.00 0.00 0.00 6800.00 55.681 45.259 4733.07 2992.04 3020.44 4234.02 0.00 0.00 0.00 0.00 6900.00 55.681 45.259 4789.45 3050.17 3079.10 4316.27 0.00 0.00 0.00 0.00 7000.00 55.681 45.259 4845.83 3108.31 3137.77 4398.53 0.03 0.00 0.00 0.00 7100.00 55.681 45.259 4902.21 3168.45 3196.43 4480.78 0.00 0.00 0.00 0.00 7200.03 55.681 45.259 4958.59 3224.58 3255.09 4563.03 0.00 0.00 0.00 0.00 7300.00 55.681 45.259 5014.97 3282.72 3313.76 4645.28 0.00 0.00 0.00 0.00 7400.00 55.681 45.259 5071.35 3340.85 3372.42 4727.54 0.03 0.00 0.00 0.00 7500.00 55.681 45.259 5127.73 3398.99 3431.09 4809.79 0.00 0.00 0.00 0.03 7600.00 55.681 45.259 5184.11 3457.13 3489.75 4892.04 0.00 0.00 0.00 0.00 7700.00 55.681 45.259 5240.49 3515.26 3548.41 4974.30 0.00 0.00 0.00 0.00 7800.00 55.581 45.259 5296.87 3573.40 3607.08 5056.55 0.00 0.00 0.00 0.00 7900.00 55.681 45.259 5353.25 3631.54 3665.74 5138.80 0.00 0.03 0.03 0.00 8000.00 55.681 45.259 5409.63 3689.67 3724.41 5221.06 0.00 0.00 0.00 0.00 8100.00 55.681 45.259 5466.01 3747.81 3783.07 5303.31 0.00 0.00 0.00 0.00 8200.00 55.681 45.259 5522.39 3805.95 3841.73 5385.56 0.00 0.00 0.00 0.00 8300.00 55.681 45.259 5578.77 3564.08 3900.40 5467.81 0.03 0.00 0.00 0.00 8400.03 55.681 45.259 5635.15 3922.22 3959.05 5550.07 0.03 0.00 0.03 0.03 8500.00 55.681 45.259 5691.53 3980.36 4017.72 5632.32 0.00 0.00 0.00 0.00 8600.00 55.681 45.259 5747.91 4038.49 4076.39 5714.57 0.00 0.00 0.00 0.00 8700.00 55.681 45.259 5894.29 4096.63 4135.05 5796.83 0.00 0.00 0.00 0.00 8800.00 55.681 45.259 5860.67 4154.77 4193.72 5879.08 0.00 0.00 0.00 0.00 8900.00 55.681 45.259 5917.05 4212.90 4252.38 5961.33 0.00 0.00 0.00 0.00 9000.00 55.681 45.259 5973.43 4271.04 4311.04 6043.59 0.00 0.00 0.03 0.00 9100.00 55.681 45.259 6029.81 4329. t8 4369.71 6t25.84 0.00 0.00 0.00 0.00 9200.00 55.681 45.259 6086.19 4387.31 4428.37 6208.09 0.00 0.00 0.00 0.00 9300.00 55.681 45.259 6142.57 4445.45 4487.04 6290.34 0.00 0.00 0.00 0.00 9400.00 55.681 45.259 6198.95 4503.59 4545.70 6372.60 0.00 0.00 0.00 0.00 9500.00 55.681 45.259 6255.33 4561.72 4604.38 6454.85 0.00 0.00 0.03 0.00 9600.00 55.681 45.259 6311.7t 4619.86 4663.03 6537.10 0.00 0.00 0.00 0.00 9700.00 55.681 45.259 5368.09 4678.00 4721.69 6619.36 0.00 0.00 0.00 0.00 9800.00 55.681 45.259 6424.47 4736.13 4780.36 6701.61 0.00 0.03 0.00 0.00 9900.00 55.681 45.259 6480.85 4794.27 4839.02 6783.86 0.00 0.00 0.00 0.00 10000.00 55.681 45.259 6537.22 4852.40 4897.68 6866.12 0.00 0.00 0.00 0.00 10100.00 65.681 45.259 6593.60 4910.54 4956.35 6948.37 0.00 0.03 0.00 0.00 10200.00 55.681 45.259 6649.98 4968.68 5015.01 7030.62 0.00 0.00 0.00 0.00 10300.00 55.681 45.259 6706.38 5026.81 5073.68 7112.88 0.03 0.00 0.00 0.00 10400.03 55.681 45.259 6762.74 5084.95 5132.34 7195.13 0.00 0.00 0.03 0.03 10500.00 55.681 45.259 6819.12 5143.09 5191.00 7277.38 0.00 0.00 0.00 0.00 10600.00 55.681 45.259 6875.50 5201.22 5249.67 7359.63 0.00 0.00 0.00 0.00 10700.00 55.681 45.259 6931.88 5259.36 5308.33 7441.89 0.00 0.00 0.00 0.03 10800.00 55.681 45.259 6988.26 5317.50 5366.99 7524.14 0.00 0.00 0.00 0.00 10900.00 55.681 45.259 7044.64 5375.63 6425.66 7606.39 0.00 0.00 0.00 0.00 11000.00 55.681 45.259 7101.02 5433.77 5464.32 7688.65 0.00 0.00 0.00 0.03 11100.00 55.681 45.259 7157.40 5491.91 5542.99 7770.90 0.00 0.00 0.00 0.00 11200.00 55.681 45.259 7213.78 5550.04 5601.65 7853.15 0.00 0.00 0.00 0.00 Sperry-Sun Drilling Alaska Planning Report- Geographic Mdd: ' . COOK INLET Site: . ' West Mc. Arthur. River Unit Well: West MCArthur R't~er Unit ~6 WellPath: WMR#6 WPs .. " ]).ate: ' 07114/2000 ' ' 'Time:' t1:59:14 P~e: '4 · Co-ordinate(NE)Reference: Welt: West Mr, Arthur River Unit #6' vertical (TN~) Reference: Nabors 160 163.0above Mean. Sea Level Section (VS) Reference: . Well (0.00E,0~00N~40.07A~') : Plan: .. Plain #1 . .. .. : Section 6: Start Nfl) ' 'ln~l."' Azim . .TVD . +N/-S' .+E/-W ' VS DLS · Build" 'Turn 'TFO. " "ft deg' ' deg".....'ft', ft ..... ' ft ..' ' .. ft.. "deg/lOOft deg/lOOft deg/lOOft .dag.'. ' ..' 11300,00 55,681 45,259 7270,16 5608,18 5660,31 7935,41 0,00 0,00 0,00 0.00 11400.00 55.681 45.259 7326.54 5686.32 5718.98 8017.66 0.00 0.00 0.00 0.00 11500.00 55.681 45,259 7382.92 5724,45 5777.64 8099.91 0.00 0.00 0.00 0.00 11600,00 55.681 45.259 7439,30 5782.59 5836,31 8t82,16 0.00 0.00 0,00 0.00 11700.00 55,681 45.259 7495.68 5840.73 5894.97 8264.42 0.00 0.00 0.00 0.00 11800,00 55,681 45,259 7552,06 5898,86 5953,63 8346,67 0,00 0.00 0,00 0.00 11900,00 55.681 45.259 7608.44 5957,00 6012,30 8428,92 0.00 0.00 0,00 0,00 12000.00 55.681 45,259 7664.82 6015.14 6070.96 8511.18 0,00 0.00 0,00 0.00 12100,00 55.681 45.259 7721.20 6073.27 6129,63 8593,43 0,00 0.00 0.08 0.00 12121.63 55.681 45.259 7733.39 6085.85 6142.31 8611.22 0,00 0.00 0.00 0.00 Section 7: Start 12200,00 53,6?3 42,968 -/778,71 6131,74 6186,83 8674,99 3,50 -2.56 -2,92 -137,70 12300,00 51,179 39,869 7839,69 6191,13 6239,27 8754,21 3,50 -2.49 -3.10 -136,37 12460,00 48,773 36,549 7904,01 6251,26 6286,65 8830,72 3,50 -2,41 -3.32 -134,48 12500.00 46,469 32,981 7971.42 6311.90 6328.79 8904,25 3.50 -2,30 -3,57 -132,35 12600,00 44,285 29,137 8041,67 6372,82 6365,53 8974,52 3,50 -2,18 -3,84 -129.94 12700,00 42,240 24.991 8114,50 6433,80 6396,74 9041,27 3,50 -2,05 -4,15 -127,24 12800,00 40.356 20,520 8189,65 6494,60 6422,30 91 04.26 3.50 -1,88 -4,47 -124,22 12900,00 38,658 15,708 8266,82 6555,01 6442,11 9163,24 3.50 -1,70 -4,81 -120.86 13000.00 37.171 10,549 8345,73 6614,80 6456,10 9217,99 3,50 -1,49 -5,16 -117.15 13100,00 35.923 5,056 8426,09 6673,73 6464.22 9268.32 3.50 -1.25 -5,49 -113,08 13200,00 34.939 359,260 8507,59 6731.61 6468.44 9314,03 3.50 -0.98 -5.80 -108,66 13300,00 34,244 353.216 8589.93 6788.20 6462,74 9354.96 3,50 -0,70 -6,04 -103.94 13352,00 34,000 350,000 8633,00 6817,03 6458.49 9374,29 3,50 -0.47 -6.18 -99,03 Section 8: Start 13400,00 35,191 347.914 8672,51 6843,77 6453,27 9391,39 3.50 2,48 -4,35 -45.70 13410,99 35,469 347,453 8681,48 6849,98 6451,91 9395,27 3,50 2,53 -4,19 -43,99 Section 9: Start 13500,00 35,469 347,453 8753.97 6900.39 6440,69 9426,62 0,00 0.00 0,00 0,00 13600,00 35,469 347.453 8835.41 6957.03 6428.08 9461.65 0.00 0.00 0.00 0.00 13676.26 35.469 347.453 8897.52 7000,23 6418,47 9488,72 0,00 0.00 0.00 0,00 Section 10: Start 13/00,00 34.660 347.763 8916.95 7013,55 6415,55 9497,03 3,50 -3.41 1,39 166,93 13800,00 31,264 349,339 9000,85 7066,86 6404,73 9530,86 3,50 -3,40 1,56 166,66 13837.37 30,000 350.000 9033,00 7085,59 6401.31 9542,99 3,50 -3.38 1,77 165.36 Section 11: Start 13900.00 27.881 348.839 9087.81 7115,38 6395,75 9562,21 3,50 -3,38 -1.65 -165,66 13955,22 26,022 347,673 9137,03 7139,89 6390,67 9577,69 3,50 -3.37 -2,11 -164,64 Sperry-Sun Drilling Alaska Planning Report- Geographic . Co~,v: F~cenerg¥ .... Meld:' COOK INLET S~te: West McArthljr. River Unit We~l: · West Mc, Arthur Ri,~r Unit #6 Wellpath: WMR#6 WPs Date:.' 07114/2000 Time:' t1:59:t4 Page: Co-eraiaate(NE)'Reference: Well: West McArthUr River Unit ~6 Vertical (TVD) Reference: Nabors 160 163.0 above Mean. Sea Level Sectien O/S) Reference: . Well (0.00E,0,00N,40.07Azi) Plan: : Plan 01 .. Section 12: Start MD lnel ' Azim 'TVD +NFS' +E/-W 'VS OLS ' Bm'id' '[~lrn TFO " "" ft . 'deg:, deg.'.' "ff".. .ff' "' 'ff ' . . ".ft "deg/!ooft deg/lOOff, deg/1.0Oft.., d;ag' ':" .. 14000.00 26.022 347.673 9177,27 7159,08 6386.47 9589.68 0.00 0.00 0.00 0.00 14100.00 26.022 347.673 9267.13 7201.94 6377.11 9616.44 0.00 0.00 0.00 0.00 14167,95 26.022 347.673 9328.19 7231.06 6370.74 9634.63 0.00 0.00 0.00 0.00 Sec~on 13: Start ".'"." '.. ' :' . ." ;,........ ' ' '...".'.' " :...." .:' '..'..'. -.".,'"' ;._~: .3.".....'..'.. ~.. ?..'...:.". ~.'...'...:.."'.'..'..; ..':.'.' :..:,......,..¥ .:.;....-.'-.... '.'.;.:....:...... :.:..'..'.. :..,...: .'..'..~.:..".'.-....,..:...'.:'.'..:.',. ::'.~..:L. :u':fu('A.,.::?'/~ 14200.00 27.143 347.709 9356.85 7245.07 6367.69 9643.39 3.50 3.50 0.11 0.85 14300.00 30.643 347.807 9444.39 7292.29 6357.45 9672.92 3.50 3.50 0.10 0.82 14400.00 34.143 347.886 9528.82 7344.65 6346.17 9705.74 3.50 3.50 0.08 0.73 14417.20 34.745 347.899 9543.00 7354.16 6344.13 9711.70 3.50 3.50 0.07 0.68 Section 14: Start 14500.00 34.745 347.899 9611.04 7400,30 6334.24 9740.64 0.00 0.00 0.00 0.00 14600.00 34.745 347.899 9693.21 7456.03 6322.29 9775.59 0.00 0.00 0.00 0.00 14684.93 34.745 347.899 9763.00 7503.36 6312,14 9805.28 0.00 0.O0 0.00 0.00 Survey [~i:~(~;~!:?::~!~;:~:~::f~'~)~!~:~..~.:~i~`~::!~i!:(~:~ ~ki~;:~:~!;..f~!:~;~:~(~!~:i~;~:~`~?((~:~:~!~i~:~:~'~(.~..:!~....~.~i~.`..~:~;!(~::~!~::~:~fi[i~``~:~!~i:~.~..~:~A~:.":~i~;..((;~.;i?~.!~i:~i.f.;?'~i~::.!i:!..:~?..!.!~`[~:.!:~..!¢?.:.~?~.f..~::.!ic`[fi:!;~`~:.~.~...:~:..~:;''?!.!~:ici......~??!:i~:~.`~:~!:~.:~.~::.:i~`:.~t:.`~:(::i~.?~.:~?;'j;.::..`?~`~/.j;..'<:c~.!!.~.::~::;i.:.!:;i;j~:~.j;..::f~?;.:!f.:.~?!.~;;`;.::.ff.~`::~::!!~.i.:~.:;`j~;/;``;.~2.;::..~`:f.!;.i.:?i:':;.::..:;~(`t:j;~j:.;(.~.:!;...::;:~;~? 163.00 0,000 0.000 163.00 0.00 0.00 2482947.50 187262,00 60 47 5.235 N 151 45 0.545 W 200.00 0.000 0.000 200.00 0.00 0.00 2482947.50 187262.00 60 47 5.235 N 151 45 0.545 W 300.00 0.000 0.000 300.00 0.00 0.00 2482947.50 187262.00 60 47 5.235 N 151 45 0.545 W 400.00 0.000 0.000 400.00 0.00 0.00 2482947.50 187262.00 60 47 5.235 N 151 45 0.545 W 500.00 1.000 45.453 499.99 0.61 0.62 2482948.10 187262.64 60 47 5.241 N 151 45 0.532 W 600.00 2.000 45.453 599.96 700,00 3.000 45.453 699.86 800.00 4,500 45.453 799.65 900,00 6.000 45.453 899.22 1000,00 7.500 45,4,53 998.53 2.45 2.49 2482949.88 187264.55 60 47 5.259 N 151 45 0.495 W 5.51 5.60 2482952.86 187267.74 50 47 5.289 N t51 45 0.432 W 10.10 10.26 2482957.32 187272.52 60 47 5.334 N 151 45 0.338 W 16.51 16.78 2482963.56 187279.21 60 47 5.397 N 151 45 0.207 W 24.76 25.15 2482971.58 187287.81 60 47 5.479 N 151 45 0.038 W 1100.00 9.500 45.453 1097.42 35.13 35.69 2482981.66 187298.61 60 47 5,58t N 151 44 59.826 W 1200.00 11.500 45.453 1195.75 47.91 48,67 2482994,10 187311.94 60 47 5.707 N 151 44 59.565 W 1300.00 13.500 45.453 1293.37 63.09 64.10 2483008.86 187327.76 60 47 5.856 N 151 44 59.254 W 1400.00 16.500 45.409 1389.95 81.25 82.53 2483026.53 187346.67 60 47 6.035 N 151 44 58.883 W 1500.00 19.500 45.378 t485.05 102.95 104.53 2483047.63 187369.24 60 47 6.249 N 151 44 58.439 W 1600;00 22.500 45.355 1578.39 128.13 130.03 2483072.12 187395.40 60 47 6.496 N 151 44 57.926 W 1700.00 25.500 45.337 1669.74 156.71 158.96 2483099.92 187425.08 60 47 6,778 N 151 44 57.343 W 1800.00 28.500 45.323 1758.63 ", 188.62 ....191.24 2483130.96 187458.21 60 47 7.092 N 151 44 56.693 W 1900.00 3t.500 45.311 1845.42 223.78 226.79 2483165.16 187494.68 50 47 7.438 N 151 44 55.977 W 2000.00 34.500 45.301 1929.28 262.08 265.50 2483202.41 187534.40 60 47 7.816 N 151 44 55.197 W 2100.00 37.500 45.293 2010.17 303.42 307.27 2483242.63 187577.26 60 47 8.223 N 151 44 54.356 W 2200.00 40,500 45.265 2087.88 347.69 351.99 2483285.69 187623.14 60 47 8,659 N 151 44 53.455 W 2300.00 43.500 45.279 2162.18 394.77 399.53 2483331.48 187671.92 60 47 9.122 N 151 44 52.497 W 2400.00 46.500 45.273 2232.88 444.52 449.77 2483379.88 187723.46 60 47 9.612 N 151 44 51.485 W 2500.00 49,500 45.267 2299.79 496.82 502.56 2483430.75 187777.63 60 47 10.127 N 151 44 50.422 W 2600.00 52,500 45.263 2362.72 551.51 557.76 2483483.95 187834.27 60 47 10.666 N 151 44 49.310 W 2706.04 55.681 45.259 2424.90 611.95 618.76 2483542.74 187896,86 60 47 11.261 N 151 44 48.081 W 2800,00 55.681 45,259 2477.88 666,57 673.88 2483595.88 187953.42 60 47 11.799 N 151 44 46.970 W 2900.00 55.681 45.259 2534.26 724.71 732,55 2483652.43 188013.61 60 47 12,371 N 151 44 45.789 W 3000.00 55,681 45.259 2590.64 782.85 791.21 2483708.98 188073.81 60 47 12.944 N 151 44 44.607 W 3100.00 55.681 45.259 2647.02 840.98 849.87 2483765.54 168134.00 60 47 13.516 N 151 44 43.42,5 W 3200.00 55.681 45.259 2703.39 899.12 908.54 2483822.09 168194.20 60 47 14.088 N 151 44 42.243 W Sperry-Sun Drilling Alaska Planning Report- Geographic co.~,.y: .?%r""'~ .... ,, '.' Field: COOK INLET Sitet West McArthur. River Unit Well: West Mc, Arthur Ri~er Unit #6 Wellpath: WMR ~ WPs ])ate: '" 07114/2000 Time:' 11:59:t4 t~ag. e: Co-er~)'ReferenCe: Welt: West.Mc, Arthur River Unit 06 YerOca~ (TYD) Reference: Nabors 160 163,0 above Mean. Sea Level SeCtion OrS) Reference: . Well (0,00E,0.00N,40.07Azi) Pl~: · Plan #1 ...... .. Su~ey "' " ' . "Mai)..' Map . ~ Latitude --~ <-- LOngitude'---> ..... MD . . Inel .. ' ' .AZim' .. ' TVD ... +NFS" +E/-W Northi~g Easting' . Deg'Min "Sec '. ' . Deg.. Mtn .See.'.' ' · "ff ..deg.. deg.... ' 'ft ..... .ft' · .' ' .ft' ' .iff "' "''fi" " . ., .'.'-' ....... 3300.00 55.681 45.259 2759.77 957.26 967.20 2483878.64 168254.39 60 47 14.661 N 151 44 41.061 W 3400,00 55.681 45.259 2816,15 1015.39 1025.87 2483935.19 188314,58 60 47 15.233 N 151 44 39.879 W 3500.00 55.681 45.259 2872,53 1073,53 1084.53 2483991,75 188374.78 60 47 15.806 N 151 44 38.698 W 3600,00 55,681 45,259 2928,91 1131,67 1143,19 2484048,30 188434,97 60 47 16,378 N 151 44 37,516 W 3700.00 55.681 45.259 2985.29 1189.80 1201,86 2484104,85 188495,16 60 47 16.951 N 151 44 36.334 W 3800.00 55.681 45.259 3041.67 1247.94 1260,52 2484161,40 188555.36 60 47 17,523 N 151 44 35,152 W 3900.00 55.681 45,259 3098.05 1306.08 1319,18 2484217.96 188615,55 60 47 18,096 N 151 44 33,970 W 4000.05 55.681 45,259 3154.43 1364.21 1377,85 2484274.51 168675,74 60 47 18.668 N 151 44 32.788 W 4100,00 55.681 45.259 3210,81 1422,35 1436.51 2484,331.06 188735.94 60 47 19.240 N 151 44 31,606 W 4200.00 55,681 45,259 3267.19 1480,49 1495,18 2484387,61 188796,13 60 47 19,813 N 151 44 30,424 W 4800,00 55,681 45.259 3323,57 1538.62 1553,64 2484444,17 168856,33 60 47 20.385 N 151 44 29,242 W 4400.05 55.681 45,259 3379,95 1596.76 1612.50 2484500.72 188916.52 60 47 20,958 N 151 44 28,080 W 4500,00 55,681 45,259 3436,33 1654,90 1671,17 2484557,27 188976,71 60 47 21,530 N 151 44 26,878 W 4600,00 55,681 45.259 3492.71 1713.03 1729,83 2484613,82 189036,91 60 47 22.103 N 151 44 25,696 W 4700,00 55.681 45.259 3549.09 1771,17 1788,50 2484670,38 189097,10 60 47 22,675 N 151 44 24.514 W 4800,00 55.681 45,259 3605,47 1829,30 1847,16 2484726,93 189157,29 60 47 23,247 N 151 44 23.332 W 4900.00 55.681 45,259 3661,85 1887,44 1905,82 2484783,48 189217,49 60 47 23.820 N 151 44 22,150 W 5000,00 55.681 45,259 3718.23 1945.58 1964,49 2484840,03 189277.68 60 47 24,392 N 151 44 20,968 W 5100.00 55,681 45.259 3774,61 2003.71 2023,15 2484896,59 189337,87 60 47 24,965 N 151 44 19,786 W 5200.00 55,681 45,259 3830,99 2061.85 2081.82 2484953,14 189398,07 60 47 25,537 N 151 44 18,604 W 5300,00 55,681 45,259 3887,37 2119,99 2140,48 2485009,69 189458,26 60 47 26,109 N 151 44 17,422 W 5400,00 55.681 45.259 3943,75 2178,12 2199,14 2485068,25 189518,46 60 47 26,682 N 151 44 16.240 W 5500,00 55,681 45,259 4000,13 2236,26 2257.81 2485122,80 189578,65 60 47 27,254 N 151 44 15,058 W 5600,00 55,681 45,259 4056,51 2294,40 2316,47 2485179,35 1.89638,84 60 47 27,827 N 151 44 13,876 W 5700,00 55,681 45.259 4112.89 2352,53 2375,14 2485235.90 189699.04 60 47 28,399 N 151 44 12.694 W 5800.00 55.681 45.259 4169.27 2410.67 2433,80 2485292.48 189759,23 60 47 28,971 N 151 44 11,512 W 5900,00 55,681 45.259 4225,65 2468,81 2492,46 2485349,01 189819.42 60 47 29.544 N 151 44 10.329 W 6050,05 55,681 45.259 4282.03 2526.94 2551.13 2485405.56 189879.62 60 47 30,116 N 151 44 9,147 W 6100,00 55,681 45,259 4338,41 2585.08 2609.79 2485462,11 189939,81 60 47 30.688 N 151 44 7,965 W 6200,00 55,681 45.259 4394,79 2643,22 2668,45 2485518.67 190000.01 60 47 31,261 N 151 44 6,783 W 6300,00 55.681 45.259 445t,17 2701.35 2727,12 2485575.22 190060,20 60 47 31.833 N 151 44 5.601 W 6400,00 55.681 45.259 4507,55 2759,49 2785,78 2485631.77 190120.39 60 47 32.405 N 151 44 4,418 W 6500.,00 55,681 45,259 4563,93 2817,63 2844,45 2485688,32 190180,59 60 47 32,978 N 151 44 3,236 W 6600.00 55,681 45.259 4620.31 2875.76 2903,11 2485744.88 190240,78 60 47 33,550 N 151 44 2.054 W 6700.00 55.681 45,259 4676,69 2933,90 2961,77 2485801,43 190300.97 60 47 34. t23 N 151 44 0.872 W 6800,00 55,681 45.259 4733,07 2992.04 3020,44 2485857,98 190361,17 60 47 34,695 N 151 43 59,690 W 6900,00 55,681 45,259 4789,45 3050,17 3079,10 2485914,53 190421,36 60 47 35,267 N 151 43 58,507 W 7000,00 55,681 45.259 4845,83 3108,31 3137,77 2485971,09 190481,55 60 47 35,840 N 151 43 57.325 W 7100.05 55.68t 45,259 4902,21 3166,45 3196,43 2486327.64 190541.75 60 47 36.412 N 151 43 56,143 W 7200.00 55.681 45.259 4958,59 3224,58 3255,09 2486084.19 190601,94 60 47 36.984 N 151 43 54.960 W 7300,00 55,681 45,259 5014,97 3282,72 3313,76 2486140,74 190662,14 60 47 37,557 N 151 43 53,778 W 7400,00 55,681 45.259 5071,35 3340,85 3372.42 2486197,30 190722.33 60 47 38,129 N 151 43 52.596 W 7500.00 55,681 45.259 5127.73 3398,99 3431,09 2486253.85 190782,52 60 47 38,701 N 151 43 51.413 W 7600.00 55,681 45.259 5184.11 3457,13 3489,75 2486310,40 190642,72 60 47 39,274 N 151 43 50,231 W 7700,00 55,681 45,259 5240,49 3515,26 3548,41 2486366,95 190902,91 60 47 39,846 N 151 43 49,049 W 7800.00 55,681 45,259 5296,87 3573,40 3607,08 2485423.51 190963.10 60 47 40,418 N 151 43 47,866 W 7900.00 55.681 45,259 5353.25 3631,54 3665.74 2486480,06 191023,30 60 47 40.991 N 151 43 46,684 W 8000,00 55,681 45,259 5409,63 3689.67 3724.41 2486536,61 191083,49 60 47 41,563 N 151 43 45,502 W 8100,00 55,681 45,259 5466,01 3747,81 3783,07 2486593,16 191143,68 50 47 42,135 N 151 43 44,319 W 8200.00 55,681 45.259 5522,39 3805.95 3841.73 2486649,72 191203,88 60 47 42.708 N 151 43 43,137 W 8300,00 55,681 45,259 5578,77 3864,08 3900,40 2486706,27 191264,07 60 47 43.280 N 151 43 41,954 W 8400,00 55,681 45.259 5635,15 3922,22 3959,06 2486762,82 191324,27 60 47 43,852 N 151 43 40.772 W 8500,00 55,681 45,259 5691,53 3980,36 4017,72 2486819,37 191384,46 60 47 44,424 N 151 43 39,589 W Sperry-Sun Drilling Alaska Planning Report- Geographic · com~.y: ~%rce"er~. . .. Fldd: COOK INLET . Site: West Mc, Arthur, River Unit Well: West Mc, Arthur River [ Init Wellpath: WMR ~ WPs .Date:' 07114/2000 ' ' Trine:' 11:59:14' ' ' P.i~e: Co-erdiaat~CE)'Ref, re~,ce: Well: West MC, Arthur Riv~r'Unit #6 Vertical (TV])) Reference:' Nabors 160 163.0 above Mean, Sea Level Section O/S) Refereace: '. Well (0.0OE.0,00N,40.07Azi) Plan: . .' .Plan #1 .... SuFvey · :. . . · '. 'Map " MaP <,=- Latitude .-~ <-- LongitUde'-=-> · MD. Ind.' ' .AMni'. .TVD +NI-S .... +F,/:W Northing FaSting Beg'Min "Sec ' " Deg. M'm Sec ' ft. .deg.. .. deg.., fL' . .fi ' · fi: .... lt., .. ' ..'fl: ' ' ' .:' ' . .'.:' ".."..'"."i'/ .... 8600.00 55.681 45.259 5747.91 4038.49 4076.39 2486875.93 191444.65 60 47 44.997 N 151 43 38.407 W 8700.00 55.681 45.259 5804.29 4096.63 4135.05 2486932.48 191504.85 60 47 45.569 N 151 43 37.225 W 8800.00 55.681 45.259 5860.67 4154.77 4193.72 2486989.03 191565.04 60 47 46,141 N 151 43 36.042 W 8900,00 55.681 45.259 5917.05 4212.90 4252.38 2487045.58 191625.23 60 47 46.714 N 151 43 34.860 W 9000.00 55,681 45.259 5973.43 4271.04 4311.04 2487102.14 191685.43 60 47 47.286 N 151 43 33.677 W 9100.00 55.681 45.259 6029,81 4329.18 4369.71 2487158.69 191745.62 60 47 47.858 N 151 43 32.495 W 9200,00 55.681 45.259 6086.19 4387.31 4428.37 2467215.24 191805.81 60 47 48.430 N 151 43 31,312 W 9300.00 55.681 45.259 6142.57 4445.45 4487.04 2487271.79 191866,01 60 47 49.003 N 151 43 30.129 W 9400.00 55.681 45.259 6198.95 4503.59 4545.70 2467328.35 191926.20 60 47 49.575 N 151 43 28.947 W 9500.00 55.681 45.259 6255.33 4561.72 4604.36 2467384.90 191986,40 60 47 50.147 N 151 43 27.764 W 9600.00 55.681 45,259 6311.71 4619.86 4663,03 2487441.45 192046.59 60 47 50.720 N 151 43 26.582 W 9700.00 55.681 45.259 6368.09 4678.00 4721.69 2467498.00 192106.78 60 47 51.292 N 151 43 25.399 W 9800.00 55,681 45.259 6424.47 4736.13 4780.36 2467554.56 192166.98 60 47 51.864 N 151 43 24.217 W 9900.00 55.681 45.259 6480.65 4794.27 4639.02 2467611.11 192227.17 60 47 52.436 N 151 43 23.034 W 10000.00 55,681 45.259 6537.22 4852.40 4897.68 2487667.66 192287,36 60 47 53.009 N 151 43 21.651 W 10100.00 55.681 45.259 6593.60 4910.54 4956,35 2467724.21 192347.56 60 47 53.581 N 151 43 20.669 W 10200.00 55.681 45.259 6649.98 4968.68 5015.01 2467780.77 192407.75 60 47 54.153 N 151 43 19.486 W 10300.00 55.681 45.259 6706,36 5026.81 5073.68 2487837.32 192467.94 60 47 54,725 N 151 43 18.303 W 10400.00 55.681 45.259 6762.74 5064.95 5132.34 2487893.87 192528.14 50 47 55,298 N 151 43 17.121 W 10500.00 55.681 45.259 6819.12 5143.09 5191,00 2487950.42 192588.33 60 47 55.870 N 151 43 15.938 W 10600.00 55,681 45.259 6875.50 5201.22 5249.67 2488006,98 192648.53 60 47 56.442 N 151 43 14.755 W 10700,00 55.681 45.259 6931.88 5259.36 5308.33 2488063.53 192708.72 60 47 57.014 N 151 43 13.573 W 10800.00 55.681 45.259 6988.26 5317.50 5366.99 2488120.08 192768.91 60 47 57.587 N 151 43 12.390 W 10900.00 55,681 45.259 7044.64 5375.63 5425.66 2488176.63 192829.11 60 47 58,159 N 151 43 11.207 W 11000.00 55.681 45.259 7101.02 5433,77 5484.32 2488233.19 192689.30 60 ~,7 58.731 N 151 43 10.024 W 11100.00 55.681' 45.259 7157.40 5491.91 5542.99 2488289.74 192949.49 60 47 59.303 N 151 43 8.842 W 11200,00 55,681 45,259 7213.78 5550.04 5601.65 2488346.29 193009.69 60 47 59.876 N 151 43 7.659 W 11300.00 55.681 45.259 7270.16 5608.18 5660.31 2488402,85 193069.88 60 48 0.448 N 151 43 6.476 W 1.1400.00 55,681 45.259 7326.54 5666.32 5718.98 2488459.40 193130.07 60 48 1.020 N 151 43 5.293 W 11500.00 55.681 45.259 7382.92 5724.45 5777.64 2486515.95 193190.27 60 48 1.592 N 151 43 4.111 W 11600.00 55.681 45.259 7439.30 5782.59 5836.31 2468572.50 193250.46 60 48 2.164 N 151 43 2.928 W 11700.00 55.681 45.259 7495.68 5840.73 5894.97 2488629.06 193310.66 60 48 2.737 N 151 43 1.745 W 11800.00 55.681 45.259 7552.06 5898.86 5953.63 2488685.61 193370.85 60 48 3.309 N 151 43 0.562 W 11900.00 55.681 45.259 7608.44 5957,00 6012,30 2488742.16 193431.04 60 48 3.881 N 151 42 59.379 W 12000..00 55.681 45.259 7664.82 6015.14 6070.96 2488798.7t 193491.24 60 48 4.453 N 151 42 58.196 W 12100.00 55.681 45.259 7721.20 6073.27 6129.63 2468855.27 193551.43 60 48 5.025 N 151 42 57.013 W 12121.63 55.681 45.259 7733.39 6085.85 6142.31 2488567.50 193564.45 60 48 5.149 N 151 42 56.758 W 12200.00 53.673 42.968 7778.71 6131.74 6186.83 2468912,19 193610.17 60 48 5.601 N 151 42 55.860 W 12300.00 51.179 39.869 7839.69 6191.13 6239.27 2488970.16 193664.18 60 48 6.186 N 151 42 54.803 W 12400.00 48.773 36.549 7904.01 6251.26 6286.65 2489029.01 193713.15 60 48 6.777 N 151 42 53.847 W 12500.00 46.469 32.981 7971.42 6311.90 6328.79 2489088.50 193756.89 60 48 7.374 N 151 42 52.997 W 12600.00 44,285 29,137 8041.67 6372.82 6365.53 2489148.42 193795.24 50 48 7.974 N 151 42 52.256 W 12700.00 42.240 24.99t 8114.50 6433.80 6396,74 2489208.55 193828.07 60 48 8.574 N 151 42 5t.626 W 12800.00 40.356 20.520 8189.65 6494.60 5422.30 2469268.65 193855.24 60 48 9.173 N 151 42 51.111 W 12900.00 38.658 15.708 8266.82 6555.01 6442.11 2489328.51 193876.65 60 48 9.768 N 151 42 50.711 W 13000.00 37,171 10.549 8345.73 6614,80 6456.10 2489387.90 193892~.3 60 48 10.356 N 151 42 50,428 W 13100.00 35.923 5.056 8426.09 6673.73 6464.22 2489446.60 193901.92 60 48 10.937 N 151 42 50.264 W 13200,00 34.939 359.260 6507.59 6731.61 6466.44 2489504.39 193905.68 60 48 11.507 N 151 42 50.218 W 13300.00 34.244 353.216 6589.93 6788.20 6462.74 2469561.06 193903.49 60 48 12.064 N 151 42 50,292 W 13352.00 34,000 350.000 8633.00 6817.03 6458.49 2489590,00 193900,01 60 48 12,348 N 151 42 50J!78 W 13400.00 35.191 347.914 8672.51 6843.77 6453.27 2489616.87 193895.50 60 48 12.611 N 151 42 50.483 W 13410.99 35.469 347.453 8681.48 6849,98 6451.91 2489623.11 193894.31 60 48 12.672 N 151 42 50.510 W Sperry-Sun Drilling Alaska Planning Report - Geographic Field: COOK INLET ~ite: West Mc. Arthur. River Unit Well: West ~ur R'Ner Unit Wellpath: WMR ~6 WPs Date:' 07114/2000 Time:. 11~59:14 '' Co~ordinate(IN~E)'Reference: 'Well: West. McArthur River Unit #6 Vertical (T~) Reference: Nabors 160 163,0 above Mean. Sea Level Section (VS) Reference: , Well (0.00E,0.00N,40.07Azi) Plan: . Plan #1 '8 Survey 'Mnp Map <---- Latitude --~ <-- Longitude'--> ' MI). 'Iuci Azbn- .. TVD ' +~I-S" . +E/.W . lqorthin~" . Easting · Beg NVm "Sec' . ' Deg MJn' Sec':' . · · ...ft, . .' deg . ..deg' . 'ft., .',ft..' .' , 'ft'. ft.. .'..'.' ft'. ." . "' ."'." . .. .... ,' . '..'.', ""..'., · .. 13500.00 35.469 347.453 60 48 13.169 N 151 42 50.735 W 13600.00 35.469 347.4.53 60 48 13.727 N 151 42 50.989 W 13676.26 35.469 347.453 60 48 14.152 N 151 42 51.182 W 8753.97 6900.39 6440.69 2489673.81 193884.44 8835.41 6957.03 6428.08 2489730.77 193873.35 8897.52 7000.23 6418.47 2489774.20 193864.89 13700.00 34.660 347.763 8916.95 7013.55 6415.55 2489787.60 193862.32 60 48 14.283 N 151 42 51,241 W 13800.00 31.264 349.339 9000.85 7066.86 6404.73 2489841.18 193852.92 60 48 14.808 N 151 42 51.458 W 13837.37 30.000 350.000 9033.00 7085.59 6401.31 2489859.99 193850.01 60 48 14.993 N 151 42 51.527 W 13900.00 27.881 348.839 9087.81 7115.38 6395.75 2489889.92 193845.25 50 48 15.286 N 151 42 51.639 W 13955.22 26.022 347.673 9137.03 7139.89 6390.67 2489914.55 193840.82 60 48 15.528 N 151 42 51.741 W 14000.00 26.022 347.673 9177.27 7159.08 6386.47 2489933.85 193837.14 60 48 15.717 N 151 42 51.825 W 14100.00 26.022 347.673 9267.13 7201.94 6377.11 2489976.94 193828.92 60 48 16.139 N 151 42 52,014 W 14167.95 26.022 347.673 9328.19 7231.06 6370.74 2490006.23 193823.33 60 48 16.426 N 151 42 52.142 W 14200.00 27.143 347.709 9356.85 7245.07 6367.69 2490020.32 193820.65 60 48 16.563 N 151 42 52.203 W 14300.00 30.643 347.807 9444.39 7292.29 6357.45 2490067.79 193811.67 60 48 17.028 N 151 42 52,409 W 14400.03 34.143 347.886 9528.82 7344.65 6346.17 2490120.43 193801.80 60 48 17.544 N 151 42 52.636 W 14417.20 34.745 347.899 9543.00 7354. t6 6344. t3 2490129.99 193800.01 60 48 17.638 N 151 42 52.677 W 14500.00 34.745 347.899 9611.04 7400.30 6334.24 2490176.38 193791.35 60 48 18.092 N 151 42 52.876 W 14600.00 34,745 347.899 9693.21 7456.03 6322.29 2490232.41 193780.89 60 48 18.641 N 151 42 53.116 W 14684.93 34.745 347.899 9763.03 7503.36 6312.14 2490279.99 193772.01 60 48 19.107 N 151 42 53.3_o0 W West McArthur River Unit #6 Well Head Schematic 13 5/8' 3 Iq ~.0' Casing 13 318' Casing i i 9 S/8' Casing I ~ ?. 718' Tubing 2000 Nabors Rig #160 13-5/8" 5000 psi BOP Stack 3" Kill Line 1 = HCR Valve 2 = Gate Valv~ 5000 psi Annular Preventer I ! 5000 psi Pipe Rams I I 5000 psi Blind Rams Ddlling Spool 5000 psi Pipe Rams ~ 3" Choke Line 2 I 13-5/8'x 11 11" 5M Wellhead 10-3/4" ! Casing ,JUL 3 4 ~ooo U~i & Gas Cons, ~mmission BLOWOUT PREVENTION EQUIPMENT NABORS RIG NO. 160 13-5/8" BOP Equipment 1 ea 1 ea 1 ea 13-5/8" x 5000 psi wp ram type preventers, double (Shaffer) 13-5/8" x 5000 psi wp ram type preventers, single (Shaffer) 13-5/8" x 5000 psi wp annular preventer (Hydril) 1 ea 13-5/8" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on both choke and kill lines. 1 ea BOP accumulator, Valvcon, 300 psi w/12 bottles, 180 gallons, and (1) 80 gallon Valvcon accumulator. Accumulator pump, Gardner-Denver Triplex, Model PQ 172, air pump Model G7E. 8 bottles nitrogen backup. 1 ea Valvcon, 6 station, remote control panel Iea Thornhill Craver, automatic choke 3"- 10,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. DRILLING FLUID SYSTEM DESCRIPTION Mud Pumps 2 ea Continental Emsco F-1300 triplex mud pumps 7" x 12, 1300 HP with (2) C-E pulsation dampeners, Model M822, each pump equipped with (2) 752 GE traction motors, cooled with ambient air. Each pump charged by a 5 x 6 Mission Magnum I with 50 HP AC motor. Mud Tank System (1035 bbls Total Volume) Tank #1 (shaker tank) appx. 270 bbls. Three compartments which include desander, desilter suction compartment and cutting trap compartment equipped with shale shakers, degasser, poor boy degasser, and mud guns in top skidded section. Tank #2 (volume tank) appx. 460 bbls. One compartment equipped with desander, desilter, mud cleaner, mud guns and mud agitators in top skidded section. Tank//3 (suction tank) appx. 305 bbls. Three compartments, two of which are pill pits, 1 thru 65 bbls; one 55 bbl equipped with mud guns, mud agitators, mud mixing hopper, and chemical barrel in top skidded section. Mud System Equipment 1 ea 1 ea 1 ea 1 ea 4 ea 4 ea Iea 6 ea Derrick dual tandem shale shaker Swaco 518 high speed centrifuge Drilco degasser Picenco 16 cone desilter Pioneer sidewinder mud mixer Brandt 7-1/2 HP mud agitators Mission Magnum pumps, 5' x 6' centrifugal with 50 HP GE Electric Motors Pioneer desander, 2 cone, Model S-2-12 Dahlory 3" mud guns JUL 14 2000 ,-uasKa Oil & Gas Cons. Commission Anchorage FORCENERGY I1~.' 310 K ST SUITE 700 ANCHORAGE, ALASKA 99501-2043 PAY TO THE ORDER OF INorthrim 6ank Downtown Financial Center 4224 89-9311252 inClucIod. JDotallS on OBCIC~ WELL PERMIT CHECKLIST C~'"MPANY ~ ~ ellbore seg ann. disposal para req A_..DMINISTRATION 1. Permit fee attached ....................... N NGINEERING 2. Lease number appropriate ................... N 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wellsP~ ....... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... DATE 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg... '.. 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~L--',~,.,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... (~ N j-- 31. Data presented on potential overpressure zones ....... ,, ~ 32. Seismic analysis of shallow gas zones ........... '-A.J'~ Y N 33. Seabed condition survey (if.off-shore) ....... '. · .~,~.." Y N 34. Contact name/phone for weekly progress reports [e~51oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N. APPR DATE (B) will not contaminate freshwater; or cause drilling.. Y N to surface; . / ~. (C) will not impair mechanical integrity of the well/used for disposal; Y N /,(O)-will not damage p ' marion or imp Y N / pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ~: UlC/.~nnular Y N COMMISSION: c:~nsoffice\wordian~diana\checklist (rev. 02117100) Comments/Instructions: m Z .--I -1-